Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout202-230Post 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-115 202230 500292313000 4 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
Operator Name:2.
Development Exploratory
Service
5
Permit to Drill Number:202-230
6.50-029-23130-00-00
PRUDHOE BAY, AURORA OIL
Hilcorp North Slope, LLC 5.
Well Name and Number:8.
10.Field/Pools:
Well Class Before Work4.
Present Well Condition Summary:11.
Total Depth: measured feet
feet
Plugs measured feet
feet
Effective Depth: measured feet
feet
Packer measured feet
feettrue vertical true vertical
7600
7487
6857
None
None
None
None
Casing: Length: Size: MD: TVD: Burst: Collapse:
Structural
Conductor 80 34" x 20" 29 - 109 29 - 109 1490 470
Surface 3220 7-5/8" 29 - 3248 29 - 2936 6890 / 8180 4790 / 5120
Intermediate
Production 7559 5-1/2" x 3-1/2" 26 - 7585 26 - 7585 7000 / 10160 4990 / 10530
Perforation Depth: Measured depth: 7250 - 7400
feet
True vertical depth:6621 - 6771 feet
Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# L-80 24 - 5399 24 - 4803
Packers and SSSV (type, measured and
true vertical depth)
No Packer
Liner
12. Stimulation or cement squeeze summary:
Intervals treated (measured):
N/A
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
2421246943937
12191259 1448
805
1027 250
Representative Daily Average Production or Injection Data
Prior to well operation:
Subsequent to operation:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name:
Contact Email:
Brian Glasheen
brian.glasheen@hilcorp.com
Authorized Name:Stan Golis
Authorized Title:
Authorized Signature with Date:Contact Phone:(907)564-5277
Treatment descriptions including volumes used and final pressure:
13.
Operations Manager
Operations Performed1.
Abandon Plug Perforations Fracture Stimulate Pull Tubing
GSTOR WINJ WAG GINJ SUSP SPLUG
16. Well Status after work:Oil 5 Gas
Exploratory Development 5 Stratigraphic
15. Well Class after work:
Service
WDSPL
14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283)
Daily Report of Well Operations
Copies of Logs and Surveys Run
true vertical measured6970
Sundry Number or N/A if C.O. Exempt:
320-370
No SSSV Installed
Junk
Packer
Printed and Electronic Fracture Stimulation Data
5
Tubing Punch with GL
Operations shutdown
Change Approved Program
5
N/A
Senior Pet Engineer:Senior Res. Engineer:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Suspend Perforate Other Stimulate Alter Casing
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well
3.Address: 3800 Centerpoint Dr, Suite
1400, Anchorage, AK 99503
7.Property Designation (Lease Number):ADL 028257 & 028258 PBU S-115
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
Stratigraphic
Other:
API Number:
Form 10-404 Revised 03/2020 Submit Within 30 days of Operations
By Samantha Carlisle at 11:25 am, Nov 02, 2020
Digitally signed by Stan Golis
DN: cn=Stan Golis,
ou=Users
Date: 2020.11.02 08:52:29 -
09'00'
Stan Golis
RBDMS HEW 11/2/2020 SFD 11/3/2020DSR-11/2/2020MGR13NOV2020
ACTIVITY DATE SUMMARY
10/16/2020
***WELL S/I ON ARRIVAL***
SET NIPPLE REDUCER ON 3.81" X LOCK @ 5451' MD (1.781" R NIPPLE).
RAN CHECK SET TO CONFIRM GOOD SET.
SET 1.781" RR PLUG IN NIPPLE REDUCER @ 5451' MD.
MITT 1550 PSI (PASSED).
***WSR CONTINUED ON 10-17-20***
10/17/2020
***WSR CONTINUED FROM 10-16-20***
TAGGED X NIPPLE @ 2201' MD W/ 2.84" GAUGE RING. FLAGGED WIRE.
SET 3 1/2" AD2 STOP @ 2973' MD.
RAN KINLEY PERFORATOR; PUNCHED HOLE & INSTALLED 16/64" CHECK
INSERT @ 2970' MD.
RAN KINLEY PERFORATOR; PUNCHED HOLE & INSTALLED 16/64" CHECK
INSERT @ 2968' MD. (SAFETY RELEASE SHEARED ON PERFORATOR).
MADE MULTIPLE ATTEMPTS TO RETRIEVE PERFORATOR, W/O SUCCESS.
UNABLE TO WORK THROUGH X NIPPLE @ 2201' MD. LIGHT JARRING
DOWWARD TO REGAIN DOWNWARD MOVEMENT.
***WSR CONTINUED ON 10-18-20***
***3 1/2" KINLEY PERFORATOR LEFT IN HOLE @ 2973' MD (91" OAL).
10/18/2020
***WSR CONTINUED FROM 10-17-20***
RECOVERED KINLEY PERFORATOR FROM 2973' MD. ALL COMPONENTS
ACCOUNTED FOR.
MITT 1500 PSI (PASSED).
PULLED 3 1/2" AD2 STOP FROM 2973' MD.
EQUALIZED & PULLED 1.781" RR PLUG FROM 5451' MD.
***WELL TURNED OVER TO DSO***
10/18/2020
T/I/O = 400/125/0. Temp = SI. MIT-T **PASS** (post Kinley). ALP = 1500 psi, ALP
SI @ casing valve. T FL @ surface. Pumped 0.6 bbls of diesel to achieve test
pressure of 1550 psi. TP lost 100 psi in 1st 15 min, TP lost 11 psi in 2nd 15 min for a
30 min total of 92 psi.
Pollard wire line in control of well upon departure. 17:30
10/19/2020
T/I/O= 890/760/0. Rate verification (gas lift for rate) Pump 50 bbls of crude down the
IA at 0.5 bpm to test new GLV's. . Final T/I/O= 875/840/0.
Daily Report of Well Operations
PBU S-115
Operator Name:2.
Exploratory Development
Service
5
Permit to Drill Number:202-230
6.API Number:50-029-23130-00-00
PRUDHOE BAY, AURORA OIL
Hilcorp North Slope, LLC 5.
Field/Pools:9.
Well Name and Number:
ADL 028257 & 028258
Property Designation (Lease Number):10.
8.
PBU S-115
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
Operations shutdown
Tubing Punch with GL
Op Shutdown
GAS
GSTOR WAG
SPLUG
Abandoned
Oil 5 WINJ
Exploratory Development 5Stratigraphic Service
WDSPL
12. Attachments:
PRESENT WELL CONDITION SUMMARY
7600
Effective Depth MD:
L-80
11.
9/15/2020
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:
5OtherAlter 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):
6970
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:
Change Approved Program
29 - 3248 29 - 2936
14. Estimated Date for Commencing Operations:
BOP Sketch
29 - 109
Structural
Proposal Summary 13. Well Class after proposed work:
No Packer
7250 - 7400 6621 - 6771 3-1/2" 9.2# L-80 24 - 5399
Production
5451 4852 5451
29 - 109 470
Contact Phone:(907)545-1144
Date:
80 149034" x 20" Conductor
4790 / 5120
GINJ
5
Post Initial Injection MIT Req'd? Yes No
5
Comm.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
Surface 3220 6890 / 8180
Intermediate
7559 5-1/2" x 3-1/2" 26 - 7585 26 - 6955 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.
7-5/8"
By Jody Colombie at 4:15 pm, Sep 08, 2020
329-370
Digitally signed by Stan Golis
DN: cn=Stan Golis,
ou=Users
Date: 2020.09.08 15:41:05 -
08'00'
Stan Golis
DSR-9/8/2020
320-370
SFD 9/9/2020
DLB 09/08/20
SFD 9/9/2020
X
MGR17SEP20
1767
10-404Yes n Required?
Comm.
9/18/2020
dts 9/18/2020 JLC 9/18/2020
RBDMS HEW 9/21/2020
Well Name: S-115 API Number: 500292313000
Current Status: SI liquid loaded Rig: SL
Estimated Start Date: September 2020 Estimated Duration: 1-5 Days
Reg.Approval Req’std? Yes Date Reg. Approval Rec’vd:
First Call Engineer: Brian Glasheen 9075451144
Second Call Engineer: Dave Wages 7133809836
Current Bottom Hole Pressure: 2437 psi @ 6700’ TVD SBHP Survey 08/29/2014
Maximum Expected BHP: 2437 psi @ 6700’ TVD
Max. Anticipated Surface Pressure: 1767 psi Gas Column Gradient (0.1 psi/ft)
Max Inc: 36° @ 2853’
Max DLS: 5°/100 ft @ 1516’ MD
Max Sand face Treatment Pressure: 4355 psi
Brief Well Summary
S-115 had a cement squeeze completed 4-12-2020 to address the IAXOA communication. The squeeze worked
and we no longer have IAXOA. We have confirmed we do not have communication from the IA down to ST 3
GLM due to residual cement left in the IA. We have also confirmed there is a flow path from St 3 to ST1 in the
IA. We have also confirmed that the IA below the residual cement holds pressure via 15-minute pressure-
bumps (~3300 psi) on the tubing x lower IA in attempts to break down the residual cement which was not
successful. These tests were performed pumping down the tubing, through the open GLM pockets of ST 3 and
ST1 against a tubing tail plug set below. This program is designed to TBG punch with GL insert with a TIFL. If
that fails we propose to punch above and below residual cement and patch.
Notes Regarding Wellbore Condition
x CMIT-TXIA passed to 2515 psi on 06/07/20
Objective:
x SL Kinley TBG punch with GL orifice
x TIFL
x POP well with GL
x Contingent if TIFL fails. TBG punch above and below cement doughnut and patch well to allow GL down
IA.
Sundry Procedure (Approval Required to Proceed:
Slickline and or Eline
1. MIRU SL
2. Pressure test to 300 psi low and 2,500 psi high
3. Set Nip reducer with 1.781” R Lock at 5451’ ( This is insurance if the Check valve below does not allow a
full 3-1/2” plug drift)
4. Set plug in nipple reducer
5. MITT to 1500 psi
6. RIH with Kinley perforator and install 2 16/64’’ check valve inserts at 2990’ and 2988’ MD
7. Pull plug from nipple reducer
8. TIFL to ensure check valves have integrity
9. POP with GL
(Optional per AOGCC)
, and MIT-T to 1500 psi
per AOGCC. 30 min
charted test.
Well Prognosis
Well: S-115
Date: 09/03/2020
Well Name: S-115 API Number: 500292313000
Current Status: SI liquid loaded Rig: SL
Estimated Start Date: September 2020 Estimated Duration: 1-5 Days
Reg.Approval Req’std? Yes Date Reg. Approval Rec’vd:
First Call Engineer: Brian Glasheen 9075451144
Second Call Engineer: Dave Wages 7133809836
AFE: 2053401 WellEZ Entry Required: Yes
Current Bottom Hole Pressure: 2437 psi @ 6700’ TVD SBHP Survey 08/29/2014
Maximum Expected BHP: 2437 psi @ 6700’ TVD
Max. Anticipated Surface Pressure: 1767 psi Gas Column Gradient (0.1 psi/ft)
Max Inc: 36° @ 2853’
Max DLS: 5°/100 ft @ 1516’ MD
Max Sand face Treatment Pressure: 4355 psi
Brief Well Summary
S-115 had a cement squeeze completed 4-12-2020 to address the IAXOA communication. The squeeze worked
and we no longer have IAXOA. We have confirmed we do not have communication from the IA down to ST 3
GLM. We have also confirmed there is a FLOW PATH from St 3 to ST1. This program is designed to TBG punch
with GL insert with a TIFL.
Notes Regarding Wellbore Condition
x CMIT-TXIA passed to 2515 psi on 06/07/20
Objective:
x SL Kinley TBG punch with GL orifice
x TIFL
x POP well with GL
Sundry Procedure (Approval Required to Proceed:
Slickline and or Eline
1. MIRU SL
2. Pressure test to 300 psi low and 2,500 psi high
3. Set Nip reducer with 1.781” R Lock at 5451’ ( This is insurance if the Check valve below does not allow a
full 3-1/2” plug drift)
4. RIH with Kinley perforator and install 2 16/64’’ check valve inserts at 2990’ and 2988’ MD
5. TIFL
6. POP with GL
Superceded
Well Prognosis
Well: S-115
Date: 09/03/2020
Cement Bond Log
Superceded
Superceded
David Douglas Hilcorp Alaska, LLC
GeoTechnician 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: 907 564-5256
E-mail: david.douglas@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
DATE: 8/25/2020
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Ste 100
Anchorage, AK 99501
DATA TRANSMITTAL
S-115 PTD(202-230))
Radial Cement Bond Log
Please include current contact information if different from above.
Received by the AOGCC 08/25/2020
PTD: 2022300
E-Set: 33685
Abby Bell 08/25/2020
Operator Name:2.
Development Exploratory
Service
5
Permit to Drill Number:202-230
6.50-029-23130-00-00
PRUDHOE BAY, AURORA OIL
BP Exploration (Alaska), Inc 5.
Well Name and Number:8.
10.Field/Pools:
Well Class Before Work4.
Present Well Condition Summary:11.
Total Depth: measured feet
feet
Plugs measured feet
feet
Effective Depth: measured feet
feet
Packer measured feet
feettrue vertical true vertical
7600
7487
6857
No Packer
None
None
No Packer
Casing: Length: Size: MD: TVD: Burst: Collapse:
Structural
Conductor 80 34" x 20" 29 - 109 29 - 109 1490 470
Surface 3220 7-7/8" 29 - 3248 29 - 2936 6890 / 8180 4790 / 5120
Intermediate
Production 7559 5-1/2" x 3-1/2" 26 - 7585 26 - 6955 7000 / 10160 4990 / 10530
Perforation Depth: Measured depth: 7250 - 7400
feet
True vertical depth:6621 - 6771 feet
Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# L-80 24 - 5399 24 - 4803
Packers and SSSV (type, measured and
true vertical depth)
No Packer
Liner
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
6KXW,Q
Representative Daily Average Production or Injection Data
Prior to well operation:
Subsequent to operation:
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Contact Name:
Contact Email:
Worthington, Aras J
Aras.Worthington@bp.com
Authorized Name:/DVWXIND-RVHSK1
Authorized Title:
Authorized Signature with Date:Contact Phone:+1 907 564 4102
12. Stimulation or cement squeeze summary:
Intervals treated (measured):2$6XUIDFH
Treatment descriptions including volumes used and final pressure:6/%SXPSHGWKHIROORZLQJGRZQ,$Z2$UHWXUQVWR277 EEOVSSJ0XG3XVK6SDFHU
EEOVRISSJ&ODVV*&07EEOVIUHVKZDWHUGLVSODFHPHQW6/%SXPSHGDVIROORZV EEOVRISSJ0XGSXVK,,VSDFHUIROORZHGE\EEOVRISSJ
FODVV*FHPHQWIROORZHGE\EEOVRI):
7UHDW2$ZLWK:HOORFN 3XPSHGaJDORISSJ:HOO/RFNDQGVWDUWHGJHWWLQJGLHVHO0:UHWXUQVIURPDQQXOXV&RQWLQXHWRILOOZ:HOORFNDQGGLVSODFHIUHHOLTXLG
JRRGFOHDQ:HOORFNUHWXUQVDIWHU JDODZD\3DXVHIRUPLQWRDOORZVZDSRXWRIDQ\FRQWDPLQDWHGIOXLG$IWHUDWRWDORIJDOORQVRI:HOORFNDZD\JRRG
FOHDQUHWXUQV5HULJDQG6TXHH]HWRSVL:HOORFNVDPSOHKDVVHWXS)LQDO3UHVVXUHV 2$ SVL,$ SVL7%* SVL
13.
6,06SHFLDOLVW
Operations Performed1.
Abandon Plug Perforations Fracture Stimulate Pull Tubing
GSTOR WINJ WAG GINJ SUSP SPLUG
16. Well Status after work:Oil 5 Gas
Exploratory Development 5 Stratigraphic
15. Well Class after work:
Service
WDSPL
14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283)
Daily Report of Well Operations
Copies of Logs and Surveys Run
true vertical measured6970
Sundry Number or N/A if C.O. Exempt:
319-569
No SSSV Installed
Junk
Packer
Printed and Electronic Fracture Stimulation Data
5
5
Senior Pet Engineer:Senior Res. Engineer:
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Suspend Perforate Other Stimulate Alter Casing
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5
3.Address: P.O. Box 196612 Anchorage,
AK 99519-6612
7.Property Designation (Lease Number):ADL 028257 & 028258 PBU S-115
9. Logs (List logs and submit electronic and printed data per 20AAC25.071):
Stratigraphic
Operations shutdown
Change Approved Program
Other:2A Cement Squeeze
API Number:
Form 10-404 Revised 03/2020 Submit Within 30 days of Operations
By Samantha Carlisle at 1:18 pm, Jun 30, 2020
Joseph N Lastufka Digitally signed by Joseph N Lastufka
Date: 2020.06.30 11:49:02 -08'00'
RBDMS HEW 7/1/2020
MGR02JUL2020 DSR-6/30/2020
ACTIVITYDATE SUMMARY
2/20/2020
***WELL S/I ON ARRIVAL*** (cement squeeze)
RAN 3 1/2" BRUSH, 2.80" GAUGE RING TO 3,500' SLM
SET 3 1/2" SLIP STOP CATCHER @ 3,388' SLM
PULLED INT-DGLV FROM ST#3 @ 3,336' MD
SET INT-FLOW SLEEVE IN ST#3 @ 3,336' MD
PULLED EMPTY SLIP STOP CATCHER FROM 3,388' SLM
***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS***
****DRIFTED W/ 20' x 2.70" DUMMY WHIPSTOCK TO 2,500' SLM FOR SUBSIDENCE
SURVEILLANCE****
2/23/2020
T/I/O = 250/250/250. Bleed T/IA/OA to 0psi, monitor for 1hr. No Flow. RD 2" OA valve and RU
2" Integrol with block valve and Viton High temp O-Rings. Torque to API specs. RDMO ***Job
Complete*** SEE LOG FOR DETAILS Final T/I/O = 0/0/0 MV = O. SSV/WV/SV = C. IA/OA
OTG. Note: OA Valve left in wellhouse.
3/12/2020
T/I/O = 10/30/60. Temp = SI. Bleed WHPs to 0 psi (valve replacement). ALP = 0 psi, SI @
CV. FL's @ near surface. Bled WHPs to flowback tank to 0 psi in 1 hr gas. Blew down
hardline w/AL gas. Monitored for 1 hr with no flow observed, replaced in kind OA 1/4 turn bock
valve. Final WHPs = 0/0/0.
SV, WV, SSV= C. MV = O. IA, OA = OTG. 13:40.
3/17/2020
T/I/O=0/0/20 Circulate Test (Cement Squeeze) Attempt to pump down the OA taking returns
up IA to tank. OA pressured up to 2000 psi with 2 BBL's of crude (no returns to tank). Pumped
15 BBL's of crude down the TBG taking returns up the IA to tank Good returns at 3 BPM &
1470 psi on the TBG. Pump 20 BBL's of crude down the TBG taking returns up the OA. Good
returns @ 2.8 BPM & 1480 psi on the TBG. Pumped 4.65 BBL's of crude down the OA taking
returns up the IA to tank. No returns & the OA pressured up to 2000 psi. Bled OAP to starting
pressure. FWHPs=vac/vac/25.
3/20/2020
T/I/O=0/0/80 LRS Unit #76 Circ-Out (CEMENT SQUEEZE (OA/IA DWNSQZ) Pumped 1.2
BBL's of crude down OA in attempt to get communication with IA. OA locked up at 2000 psi.
Bled OAP to 0 psi. Pumped 81 BBL's of crude down IA taking returns up the OA to OTT.
Pumped a total of 4 BBL's of crude down the OA taking returns up the IA to OTT before
locking up at 2000 psi. Pumped a total of 50 BBL's of 1.25 ppb power vis gel and 180 BBL's of
1% KCL down IA taking returns up the OA to the OTT tank in 5 BBL gel incriments followed by
20 BBL KCL flushes (see log for details). Over flushed with 130 bbls 1% KCL down the IA
taking returns up the OA to OTT.Attempt to pump down OA up IA to OTT, OA pressures up to
2000 psi after 2 BBL's. FWHP= 0/0/0 SV/WV= Closed SSV/MSTR=Open IA/OA =
OTG.
4/9/2020
T/I/O=0/0/0 Assist Cement crew (Cement Squeeze) Pump 3 bbsl 60/40 down tbg taking
returns up IA, pump 2 bbls 60/40 down Tbg taking returns up OA to confirm flow path, Flush all
surface lines w/ 60/40 to confirm flow. Job postponed. FWHP=0/0/0 SV,WV shut
SSV,MV,IA,OA Open.
Daily Report of Well Operations
PBU S-115
Daily Report of Well Operations
PBU S-115
4/12/2020
SLB Cementers - Circ CMT into OA
***LRS in control of well upon arrival. Full Pump schedule details on LRS AWGRS on
4/12/20***
LRS displaced TxIA to freshwater then pumped Surfactant Pill down IA with OA returns.
SLB pumped the following down IA w/ OA returns to OTT: 5 bbls 13.5 ppg Mud Push Spacer,
67 bbls of 15.8 ppg Class G CMT, 35 bbls freshwater displacement. RDMO SLB. LRS swept
TxIA w/ Powervis followed by freshwater then displaced TxIA to to diesel while holding
backpressure on choke to prevent cement OA CMT from inflowing into IA.
OA TOC @ surface
OA BOC @ 3250' MD
4/12/2020
T/I/O=14/51/51 temp=SI LRS unit 46 assist cement crew (CEMENT SQUEEZE (OA/IA
DWNSQZ) Heated Diesel transport #30019 to 90*. Pumped 4 bbls diesel to SLB cement crew
to flush coils. Pumped 2 bbls 60/40 to perform a leak tight test on all hardline. Pumped 10 bbls
60/40, followed by 80 bbls of 80* FW down tbg taking returns up IA to IOTT, followed by 10
bbls of 60/40. Pumped 20 bbls of surfactant down tbg, followed by 5 bbls 60/40 taking returns
to IOTT. **SLB pumped as follows: 5 bbls of 13.5 ppg Mud push II spacer, followed by 65 bbls
of 15.8 ppg class G cement, followed by 35 bbls of FW**. Pumped 4 bbls 60/40 to flush out
wash up loop. SLB rigs down. Pumped 24 bbls of Power Vis, followed by 100 bbls of FW,
followed by 5 bbls 60/40, followed by 80 bbls of 90* dsl down tbg taking returns up IA to OOTT.
Pumped 9 bbls of dsl to flush out choke trailer and all hardline to IOTT. DHD on well at LRS
departure. FWHP = 1172/1172/51
**Fluid packed tags hung on IAV and WV**
**AFE sign in place on arrival**
4/15/2020
T/I/O = Vac/180/10. Temp = SI. Strap TOC in OA (OA cement squeeze). AL spool
disconnected. IA FL @ surface, OA FL @ near surface. Bled IAP to BT from 180 psi to 0+ psi
in 6 minutes (0.05 bbls), held open bleed. Bled OAP from 10 psi to 0 psi in 6 minutes (all gas),
monitor for 1 hour for no observable flow. Removed hard line & block valve from OA, removed
uncured cement from integral & VR profile. Strapped TOC in OA @ ~20' (0.3 bbls), OA FL @
bottom of VR profile. Reinstalled hard line & block valve on OA. Final WHPs = Vac/0+/0.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:15
4/16/2020
T/I/O = Vac/Vac/0. Temp = SI. WHPs (post bleed). AL spool disconnected. OA cemented to
surface. TP unchanged, IAP decreased from 0+ psi to a Vac, OAP unchanged overnight.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30
5/4/2020
T/I/O = SSV/Vac/Vac. Temp = SI. Strap OA TOC (pre Wellock). No AL. OA TOC @ 20.6',
0.3 bbls void with 18' of fluid.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30
5/5/2020
Job Scope: Install 1/4" hose to clean out fluid in OA. Unable to get hose past 1.5' in OA.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30
5/7/2020
Job Scope: Attempt to remove free liquid in OA. Attempted to insert 1/4" SS tubing, 3/8"
copper tubing, 1/4" SS tubing w/ home made cork screw end, 3/8" tygon tubing. Successfully
able to insert electricians fish tape to bottom @ 20'. Attempt to insert fish tape with 3/8" tygon
tubing.
5/8/2020
Job Scope: Install 3/8" tygon tubing to ~3'. Using tubing to evacuate ~1 quart of fluid from OA.
Heater installed in well house with well house vent open.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00
Daily Report of Well Operations
PBU S-115
5/10/2020
Job Scope: Treat OA with Wellock. 5-1/2" x 7-5/8" OA void is 20' to TOC. Top 3' of annulus is
dry and there's 12 gallons (17') of diesel/MW mixture below that. Have 3/8" tygon tubing
inserted ino annulus to 3'. Pumped ~4 gal of 10 ppg WellLock and started getting diesel/MW
returns from annulus. Continue to fill w/ Wellock and displace free liquid. good clean Wellock
returns after 19 gal away. Pause for 30 min to allow swap out of any contaminated fluid. After a
total of 21 gallons of Wellock away - good clean returns. Re-rig and Squeeze to 2500 psi.
Cont on WSR 5/11/20
5/11/2020
Cont from WSR 5/10/20. Squeezed 1.3 galons of Wellock into OA. Monitored OAP and
wellhead temp while Wellock began to set up. See log for details. Monitored wellhead @
14:30 IAP = 2100 psi, WH temp = 88°. Adjusted heater trunk in wellhouse.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00
5/12/2020
T/I/O = SSV/Vac/1150. Temp = SI. WHPs (post Wellock). Wellock sample beginning to set
up. OAP decreased from 2100 psi to 1150 psi overnight. Heater working properly in well
house. WH temp = 85°.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 08:30
5/13/2020
T/I/O = SSV/Vac/970. Temp = SI. WHPs (Post Wellock). Wellock sample is not set up. WH
temp at OA level = 68°. Heater working. OAP decreased 180 psi overnight.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:50
5/13/2020
T/I/O = SSV/0/1120. Temp = SI. WHPs (post Wellock). Wellock sample not set up, has the
consistency of molasses. WH temp = 65°. Heater working properly. OAP increased 150 psi
from 10:50 hrs.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 20:30
5/14/2020
T/I/O = SSV/0/1150. Temp = SI. WHPs (post Wellock). Wellock sample is not set up and has
the consistancy of warm honey. WH Temp at OA = 90° @ 12 o'clock and 110° @ 6 o'clock.
Pulled heater hose back about a foot. OAP increased 30 psi since 20:30 hrs last night. Placed
manifold and 50' CNG hose on OA. Pressured up CNG hose to 1700 psi from AL on S-122
per Arvill Bass. CNG hase capped and rolled up to well. The CNG hose was left open to OA
to act as a lubricator.
5/15/2020
T/I/O = SSV/0/1800. Temp = SI. WHPs (post Wellock). Wellock sample is not set up, has the
consistency of honey. WH temp = 86°. OAP increased 100 psi from when CNG was installed.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:00
5/15/2020
T/I/O = SSV/0/1760. Temp = SI. WHPs (Post Wellock). Wellock sample is not set up. WH
temp = 74°. Heater working. OAP decreased 40 psi since 04:00 this morning.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:40
5/16/2020
T/I/O = SSV/0/1550. Temp = SI. WHPs (Post Wellock). Wellock sample has set up. WH
temp = 70°. Heater working. Wellhouse door is open. OAP decreased 220 psi since 00:30
this morning.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:10
5/16/2020
T/I/O = SSV/0/1770. Temp = SI. WHPs (post Wellock). Wellock sample is not set up,
Wellock does not pour when tipped but is still soft enogh to squeeze easily. WH temp = 92°.
Opened man door. OAP decreased 30 psi in 16 hrs 30 min.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 00:30
5/17/2020
T/I/O = SSV/0/1720. Temp = SI. WHPs (Post Wellock). Wellock sample has set up. WH
temp = 78°. Heater working. Opened wellhouse door. OAP increased 170 psi overnight.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:15
5/19/2020
T/I/O = SSV/0/1550. Temp = SI. WHPs (Post Wellock). WH temp = 72°. Heater working.
OAP decreased 170 psi since 5/17/20.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30
Daily Report of Well Operations
PBU S-115
5/22/2020
T/I/O = SSV/0/1400. Temp = SI. Bleed OAP (Post Wellock). WH temp = 60°. Heater
working. Pulled 50' CNG hose, being used as an acumulator, off of OA. Bled OAP from 1400
psi to 0 psi in15 sec. OAP unchanged in 30 min. FWHPs = SSV/0/0.
SV, WV, SSV = OTG. MV = O. IA, OA = OTG. 11:00
5/23/2020
SSV/0/0. Post well lock. RD 2" 5000 O/A integral. RU 2" FMC O/A valve. Torqued to API spec.
Job Complete. See log. Final WHP,s SSV/0/0.
5/24/2020
T/I/O = SSV/VAC/0. Temp = SI. WHPs (post Wellock). AL disconnected. No Heater. OAP
unchanged overnight.
SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:00
6/6/2020
T/I/O= 13/16/15 Well shut in on arrival (CMIT-TxIA - Post OA treatment) Rigged up.
...Continued on 06/07/2020...
6/7/2020
...Continued from 06/06/2020... (CMIT-TxIA - Post OA treatment)
CMIT-TxIA PASSED to 2,515psi, Max Applied = 2,750psi, Target = 2,500psi. Pressure up T/IA
to 2,715/2,744psi with 1.06 bbls diesel. After first 15 min T/IA lost 136/49 psi. In the second 15
mins T/IA lost 64/20. T/IA lost 200/69 in 30 mins. OA pressure remained at 15psi during test.
Bleed back 1 bbls of diesel.Tags hung AFE sign hung. Well shut in upon departure.
MV/IA/OA= Open WV/SSV/SV=Shut. FWHPs 1/8/15.
***Job Complete***
6/18/2020
***WELL S/I ON ARRIVAL*** (squeeze)
SET 3-1/2" WHIDDON CATCHER @ 7148' SLM.
ATTEMPT TO PULL INT-DGLV FROM STA #2(5088' MD)
****CONT WSR ON 6-19-20****
6/19/2020
****CONT WSR FROM 6-18-20****(squeeze)
PULLED INT-FLOW SLV FROM STA #3 (3336' MD)
MADE 3 ATTEMPTS TO PULL STA #2 @ 5,088' MD (possible stripped f.neck)
SET INT-DGLV IN STA #3 @ 3,336' MD
PERFORMED PASSING PRESSURE TEST OF TUBING TO 918psi (see log)
PULL INT-DGLV FROM STA #15269' MD) & STA #3(3336' MD)
SET INT-LGLV IN STA #3(3336' MD, INT-OGLV IN STA #1(5269' MD)
PULL EMPTY WHIDDON CATCHER FROM 7140 ' SLM.
PULL PXN-PLUG FROM 7171' MD
***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED ****
6/24/2020
T/I/O = 290/1890/10. Temp = 90°. TIFL - ATTEMPT - (Eval TxIA). ALP = 1890 psi, open @
CV. OA cemented to surface. IA FL @ 100' (1.2 bbls). Confirmed with OPS that AL is open
from skid to CV, PCC confirmed that GL rate has been 0 mmscfpd since well was POP'd. Did
not perform TIFL.
SV = C. WV, SSV, MV = O. IA, OA = OTG. 21:30
6/25/2020
T/I/O = 320/1800/0+. Temp = 83*. Warm TIFL - Passed - (Post GLC C/O). AL open @
casing valve (1800 psi). IA FL @ 120' (1.4 bbls). SI the wing valve and stacked out the TBG
to 1490 psi w/ AL gas. SI the AL and bled the IAP from 1800 psi to 300 psi in 10 minutes
(production, #115). During the IA bleed the IA FL decreased to 110' (pipe contraction). TBG
FL @ 5650' (419' below #1 S/O). The IAP, IA FL and TBG FL remaeind unchanged and the
TP increased 40 psi in the 1 hour monitor. Well returned to Ops to POP. FWPs =
1530/300/0+.
SV, WV = C. SSV, MV = O. IA, OA = OTG. 1150.
THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Aras Worthington
Interventions & Integrity Engineer
BP Exploration (Alaska), Inc.
PO Box 196612
Anchorage, AK 99519-6612
Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-115
Permit to Drill Number: 202-230
Sundry Number: 319-569
Dear Mr. Worthington:
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www. a ogcc. o laska.g o v
Enclosed is the approved application for the sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely, Ier m . Price
it
DATED this day of January, 2020.
BBDMS ' JAN 0 3 2020
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
1iv1�.� �5ED
/STS 1113 /20
DEC 16 9nto
Form 10-403 Revised 04/2017
er1atinons shutdown ❑
1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well RlOp�&(gtlQ
A
Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ RfiY0AIy�ram ❑
Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other OA Cement Squeeze 0 '
2. Operator Name: BP Exploration (Alaska), Inc
4. Current Well Class:
Exploratory ❑ Development Q
5. Permit to Drill Number: 202-230
3. Address: P.O. Box 196612 Anchorage, AK
99519-6612
Stratigraphic ❑ Service ❑
6. API Number: 50-029-23130-00-00 '
T If perforating:
What Regulation or Conservation Order governs well spacing in this pool?
B. Well Name and Number.
Will planned perforations require a spacing exception? Yes ❑ No 0
PBU S-115 '
9. Properly Designation (Lease Number):
10, Field/Pools:
ADL 028257 & 028258 °
PRUDHOE BAY. AURORA OIL
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD (ft):
Total Depth ND(fl): Effective Depth MD: Effective Depth TVD:
1
MPSP (psi):
Plugs (MD): Junk (MD):
7600
6970 7171 6478
O
7171 None
Casing
Length Size MD TVD
Burst Collapse
Structural
Conductor
60 34" x 20" 29-109 29-109
1490 470
Surface
3220 7-7/8" 29-3248 29-2936
6890/8180 4790/5120
Intermediate
Production
7559 5-1/2" x 3-1/2" 26-7585 26-6955
7000 / 10160 4990/10530
Liner
Perforation Depth MD (ft):
Perforation Depth TVD (ft):
Tubing Size:
Tubing Grade:
Tubing MD (ft):
7250 - 7400
8621 - 6771
3-1/2" 9.2# L-80
L-80
1 24-5399
Packers and SSSV Type: No Packer
Packers and SSSV MD (ft) and TVD (ft): No Packer
No SSSV Installed
No SSSV Installed
12. Attachments: Proposal Summary EI Wellbore Schematic p
13. Well Class after proposed work:
Detailed Operations Program ❑ BOP Sketch ❑
Exploratory ❑ Stretigraphic ❑ Development EI Service ❑
14. Estimated Date for Commencing Operations: 12/25/2019
15, Well Status after proposed work:
Oil El WINJ ❑ WDSPL ❑ Suspended ❑
16. Verbal Approval: Date:
GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
Commission Representative:
GINJ ❑ Op Shutdown ❑ Abandoned ❑
17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Aras J
be deviated from without prior written approval.
Contact Email: Aras.Worthington@bp.com
Authorized Name: Worthington, Aras J
Contact Phone: +1 907 564 4102
Authorized Title: Interventi Integrity Engineer
Authorized Signature: Date:
COMMISSION USE ONLY
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 1319-5609
Other
MMS JAN 0 3 2020
Post Initial Injection MIT Req'd? Yes ❑ No ❑
ception Required? Yes ❑ No l� Subsequent Form Required: lG —t�/Q y
APPROVED BYTHE 1''j //n
LAppmvedby: r COMMISSIONER COMMISSION I 7 -(�V
Date:
Form 10-403 Revised 04/2017
ORIGINAL
;Z1"7
)'�j�G--21§Z dt11�PS� Submit Form and
Attachments in
Approved application is valid for 12 months from the date of approval. Duplicate
by
Z
S-115 OA Cement Squeeze
Well Interventions Engineer: Aras Worthington (907) 440-7692
Pad Engineer: Alex Youngmun (907) 564-4864
Estimated Start Date: 12/25/2019
History
S-115 is a 2002 Aurora microbore well.
During a tubing thaw operation pumping down the IA, rapid IA x OA communication was observed.
A subsequent IC PPPOT-T/IC passed as well as an MITT and a CMIT TxIAxOA.
Current Status
The well is currently classified as "Not Operable" due to the IA x OA communication.
Objective
Perform an OA down -squeeze to fully cement the OA and seal off the IA x OA communication.
Procedural steps
Fullbore
1. Establish injectivity rate and pressure with diesel or crude oil down the OA and into formation. Max OA
pressure 4000 psi. Note that burst strength of 7-5/8" casing is 6890 psi and the collapse strength of the
5-1/2" casing is 4990 psi.
2. Pump —70 bbls of 15.8 ppg Class G cement down the OA to fully cement the OA from surface to the
Surface Casing Shoe. Pump the following schedule at maximum rate below 4000 psi treating pressure:
➢ 10-bbls of 60/40 or 10 bbls neat MEOH
➢ 30 bbls hot (180 deg) freshwater + surfactant; 2 gal/bbl F103 and 2 gal/bbl U067
➢ 10 bbls of 13.5 ppg MUDPUSH II Spacer
➢ 20 bbls of neat cement
➢ 30 bbls of cement with 15 -ppb aggregate
➢ 20 bbls of neat cement
Volumes:
top bot volume
MD MD S 7P In hhlc/ff Cf tihi'
Ppg:
15.8 ppg Class G Unislurry — Mix on the fly
Slurry Temperature:
7-5/8"
6.875"
40 - 200 cc (20-100cc/30min)
Thickening Time:
Minimum 4 hours
7-5/8" x 5-1/2" annulus
0
3258'
5-1/2" 15.5#
x 5.5"
0.0165
3258'
54
Ppg:
15.8 ppg Class G Unislurry — Mix on the fly
Slurry Temperature:
between 800 and 110°F
API fluid loss:
40 - 200 cc (20-100cc/30min)
Thickening Time:
Minimum 4 hours
Compressive Strength:
2000 psi in 24 — 48 hours
Cement thickening time: Mix on the tiv
Activit
Time hours
Shearing time, quality control, PJSM
0
Cement displacement
2
Cement contamination
0
Safety
2
Minimum required thickening time:
4
Special Projects
1. Strap the TOC in the OA.
2. Fill and squeeze the remaining void in the OA with well lock, squeezecrete, or similar product (if
needed). Squeeze to 4000 psi.
DHD/Operations
1. CMIT TAA to 2500 psi.
2. Re-classify well as Operable.
Slickline
1. Pull TTP and POP.
TREE= 3-10SMD1W
VItLL.F£AD=
11'FMC
ACTUATCIR=
N4
DIB. BEV =
BF. ELEV =
T5
63 —9
KOP—
- 500'
Max Anje =
36' 6 2853'
DatummY= ._.
7394'
DawmND=
67DO SS
Minimum ID =2.813" @ 2201'
3.112" HES XN NIPPLE
3-12" TBG, 92#, L-80,.0087 6pf, D= 2.992"5399'
PERFORATION SUMMARY
REF LOG:
ANGLE ATTOP PERF: 28'@7250-
SIZE
8'@7250'
SIZE
SPF INTERVAL OWSm SHOT
SOZ
242'
6 I725a-7280 C 0127)03
2-12'
6 7280-7310 C 10&)09!15
2-12'
6 7360-74001 C 0127703
SAFETY NDTEB:—MICOP BORE WILL- TXFA
S-115 Current 1
AN500P1
gLWRIESSUNGH0&M1 SDToSL
PBTD 748r "
MD N_D' DEV TYPE VLV LATC
3336 3010 33JKBG2d DMV M
5088 1 4512 22 KBG2-9 I DMY I NT
_"R D=4.08'
3-12' HIS X NP, D= 2.813'
3-12' H6 X FP, D=2.813'
MARKERJT W/ RA TAG
MARKER JT W/ RA TAG
412'HES X NP, D=2.813'
f-12'PX PLUG !10291191
a 112130/02
AURORA UNIT
WELL: S-115
PERMIT No: '1022300
API No: 50-02923130-00
BP Expkwatim (Alaska)
3
TREE - 3-1/8"FErY
NOTES- `"'MICOR-BOREWAL-TXIA
WALFfAD 11"FMC
Note: Refer ID Production DB brhisto ical perrdab
S12E
SPF
INTERVAL
z
5115 Proposed FFERENTIAL PRFSSUESHOULD BE KEPT LESS
-
ACfINTOR-
2-12"
6
N 500 PSI DURING HOTS B MIT'S DIE TO SEAL
'�- �'1•
0127103
_,� BORE FU;EPTACLE COMPLETION"'
Fully Cemented OA
rIE
Minimum ID =2.813"
3-1/2" HES XN NIPPLE
3-12" TBG, 9.2#, L-80 .0087 5pr, D= 2.992" 5399'
5 -1/2 -CSG. 15.5#. L-80. D=4.950' —F—o—aF-1
PERFORATION SUMMARY
REF LOG:
ANGLE ATTOP PERF: 28' @ 7250'
Note: Refer ID Production DB brhisto ical perrdab
S12E
SPF
INTERVAL
z
SHOT
SOZ
2-12"
6
7250-7280
C
0127103
KaDMY M
2-12"
6
7280-7310
C
0809/15
KBG2b DMY M
2-12"
6
7380-7400
C
012203
PBTD7487'
D=6.875"
x
STMD
ND
DEV
TWE I VLV I LATCH
I PORT
I DATE
3
333fi 3010
33
KBG241 DMY M
0
10%3W9
2
5088 4512
22
KaDMY M
0
12/30/02
1
5269 4fi81
20
KBG2b DMY M
0
10/30/19
TBR, D=4.OD'
3-12" /iES X NP, D-2.81
3-1/2' FES X NP, D=2.81.
MARKER JT W/ RA TAG
MARKH2 Jr V✓/RA TAG
1-12'HES X NP. D=2.813•
D=2.813'
4
DATE
REV BY COMMENTS
AURORA UNIT
WELL: S-115
PERMD No:x1022300
APIM: 50-029-23130-00
SEC 35 TI 2N, Rl2E 4406 FSL 84499'FEL
DATE REVBY i OMMENTS
12/30/02 JLM/KK ORIGINALCOMPLEMll
08113M5 MRD1JMD ADPERFS 0809115
092909 RO/SV CORRECTIONS CARE
10131119 LLG/JMD SETPXPLUG 1029119
1211909 BSE/SV SETWRP 082509
10/31/19 MWJMD GLVCIO 10/30119
0204/10 PJP/PJC DRAWf4G CORRECTION
11M4/14
JMM/JMD PULLED VO•tP 1108/14
BP Exp1mbon(Alaska)
0727/15 JMGPJC ADD SAFETY NOTE_
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STATE OF ALASKA
• ALASKA OIL AND GAS CONSERVATION COM ON
• REPORT OF SUNDRY WELL OPERATIONS
1. Operations Performed
Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0
Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program 0
Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0
2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 202-230
3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0
AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23130-00-00
7. Property Designation(Lease Number): ADL 0028258 8. Well Name and Number: AURA S-115
9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools:
PRUDHOE BAY,AURORA OIL
11.Present Well Condition Summary: RECEIVED
Total Depth: measured 7600 feet Plugs measured None feet
true vertical 6970 feet Junk measured None feet AUG 2 4 2 015
Effective Depth: measured 7357 feet Packer measured None feet
true vertical 6728 feet Packer true vertical None feet
AOGCC
Casing: Length: Size: MD: TVD: Burst: Collapse:
Conductor 80 20"91.5#11-40 29-109 29-109 1490 470
Surface 84 7-5/8"29.7#L-80 29-113 29-113 6890 4790
Surface 1018 7-5/8"29.7#5-95 113-1131 113-1126 8180 5120
Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Intermediate 5376 5-1/2"15.5#L-80 27-5403 27-4807 7000 4990
Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Perforation Depth: Measured depth: 7250-7280 feet 7280-7310 feet 7380-7400 feet
True vertical depth: 6621-6651 feet 6651-6681 feet 6751-6771 feet
Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 24-5400 24-4804
Packers and SSSV(type,measured and
true vertical depth)
12.Stimulation or cement squeeze summary:
Intervals treated(measured): NOVTreatment descriptions including volumes used and final pressure: SCONE 1 NO 1� 1 2 2015
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 704 1524 476 1714 208
Subsequent to operation: 0 0 0 0 0
14.Attachments:(required per 20 AAC 25 070.25.071,&25.283) 15.Well Class after work:
Daily Report of Well Operations IZ Exploratory ❑ Development m Service 0 Stratigraphic 0
Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0
Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0
17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
N/A
Contact Summerhays,Nit- (WIPRO Technologies) Email Nita.Summerhays@bp.com
Printed Name Su er.:ys, ta lippai
(WIP_RO Technolo.'-s) Title Petrotechnical Data Manager
.AIISignatur iJj':`*'� � �i Phone +1 907 564-4035 Date 08/24/2015
Form 10-404 Revised 5/2015 i!T L !i Z 1 t..3 R B DM AUG 2 4 2015 Submit Original Only
•
Daily Report of Well Operations
AURA S-115
ACTIVITYDATE SUMMARY
***WELL S/I ON ARRIVAL***(adperf)
PULLED P-PRONG FROM 7142'SLM
PULLED P-BODY FROM 7147'SLM/7171' MD
DRIFTED W/30'x 2.50" DUMMY GUN & 1.75"S. BAILER TO TD @ 7357'SLM (empty bailer)
8/8/2015 ***WELL LEFT S/I ON DEPARTURE***
***WELL S/I UPON ARRIVAL***(SLB ELINE- PERFORATE)
INITIAL T/I/0=280/420/160 PSI
RIH WITH HEAD/ERS/UPCT/30'X 2.5" HSD GUN LOADED WITH PJ HMX CHARGES.
CORRELATE TO SLB PERFORATING DEPTH CONTROL LOG DATED 26-JAN-2003.
PERFORATE INTERVAL=7280'-7310'
FINAL T/I/O=280/440/150 PSI
WELL LEFT SHUT IN- NOTIFIED PAD OP OF WELL STATUS
8/9/2015 ***JOB COMPLETE***
Fluids Summary
BBLS Type
2 DIESEL
2 Total
• •
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TIEE= 3-1/8'5FA aw
IAELLI-16AD= 1.1*RIC • SAFETY NOTES: MICOR-BORE WELL-TXIA
ACR1ATOR= S-1 1 5 DIFFERBMAL PRESSURE SHOULD BE KEPT LESS
THAN 600 PSI DURING HOTS&errs DUE TO SEAL
OKB.ELB/= 64.1'
BORE RECEPTACLE COMPLETION
BF.R.B/= 53.50'
KOP= 50U
'(4 2853'
I 1 100, —17-5/8'TAM PORT COLLAR D=6.875
Max Angle= 36 "
"
!Ilium = 7394'.
Datum TVD= 6700'SS2201' H3-1/2FES X NIP,13=2.813"
17-5/8CSG,29.7#,S-95/1-80, =6.875" H 3248'
GAS LFT MANDRELS
ST II) ND CB/ TYPE VLV LATCH TORT [ATE
Minknum ID =2.813" 2201'
3 3336 3010 33 103G2-9 DOME INT 16 02/03/03
3-1/2" HES XN NIPPLE 2 5068 4512 22 KBG2-9 DMY NT 0 12/30/02
1 5269 4681 20 KBG2-9 SO NT 20 02/03/03
6367' H3-1/2"BKR SLD SLV,D=2.81r
I I
TsG,9.2 ,L-80,.0087 bpf,D=2.992- H 6399' L
6381'-54021_13-1/r BKR SEAL ASSY,D=3.00' .1
5-1/2 CSG,15.50,L-80, =4.950" H 5382'
5402' H5-1/2-X 3-1/2"XO,ID=3.000*
6383' D=4.00"
• 645V H3-1/2'FES X NIP,0=2.813'
PERFORATION SLWARY
REF LOG: I 6989' I—3-1/2-I-ES X NIP,D=2.813'
ANGLE AT TOP PEW: 28'fa 7250'
!tote:Refer to Production DB for historical perf data 60009 HMARCER ST'N RA TAG
SIZE SIT MTERVAL Opn/Sqz SHOT SQZ
2-1/2' 6 7250-7280 0 01/27/03
7141' H MARKER JT VW RA TAG
2-1/2' 6 7280-7310 0 08109/15
2-1/2" 6 7380-7400 0 01/22/03
7171' H3-1/7'FES X NV,13=2.813'
P610 •Vrt'fl
**0.1
.1.01
*00
3-1/2'CSG,92t,L-80,13=2.99T ]-1 7686' I•••44
DATE TEV BY COMENTS DATE REV BY COMIAENTS AURORA UNIT
121=02 JuAnce ORIGINAL COMPLETION 08/13/15 keD/J143 ADFERFS(08/09/15) KELL S-115
09/29/09 RO/SV CORRECTIONS(CARE) JrPERNo: 2022300
12/19/09 BSE/SV SET IMIP(08125/03) AR No: 50-029-23130-00
02/04/10 PJP/PJC DRAWING CORRECTIONS SEC 35,T12N,R12E 4406'FSL&4499'Fa
11/14/14 JIA4:110 FULLED WRP(11/08/14)
07/27/15 JIAG1PJC ADD SAFETY NOTE BP Ekploration(Alaska)
RECEIVED
STATE OF ALASKA
A. _KA OIL AND GAS CONSERVATION COMA, .ION APR 0 1 2014
, REPORT OF SUNDRY WELL OPERATIONS AOGGC
1.Operations Abandon U Repair Well Lf Plug Perforations u Perforate U Other k Sly IA-4Z j7
Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time ExtensionD -Lp 6722 l i 4
Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑
2.Operator 4.Well Class Before Work: 5.Permit to Drill Number:
Name: BP Exploration(Alaska),Inc
Developments Exploratory ❑ 202-230-0
3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number:
Anchorage,AK 99519-6612 50-029-23130-00-00
7.Property Designation(Lease Number): 8.Well Name and Number:
ADL0028258 • AURA S-115
9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): R
PRUDHOE BAY,AURORA OIL
11.Present Well Condition Summary:
Total Depth measured 7600 feet Plugs measured 7316 feet
true vertical 6970.37 feet Junk measured None feet
Effective Depth measured 7316 feet Packer measured None feet
true vertical 6686.61 feet true vertical None feet
Casing Length Size MD TVD Burst Collapse
Structural None None None None None None
Conductor 80 20"x 30" 30-110 30-110 0 0
Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Intermediate None None None None None None
Production 5374 5-1/2"15.5#L-80 28-5402 28-4805.83 7000 4990
Liner 2203 3-1/2"9.2#L-80 5382-7585 4786.87-6955.38 10160 10530
Perforation depth Measured depth 7250-7280 feet 7380-7400 feet
True Vertical depth 6620.68-6650.65 feet 6750.55-6770.53 feet
SCANNED JUN 1 1 2 014
Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 27-5383 27-4787.82
Packers and SSSV(type,measured and true vertical depth) None None None Packer
None None None SSSV
12.Stimulation or cement squeeze summary:
Intervals treated(measured): RGDMS MAY 1 4 2014
Treatment descriptions including volumes used and final pressure: ,
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation: 1405 2539 284 1388 209
Subsequent to operation: 980 1952 184 1262 218
14.Attachments: 15.Well Class after work:
Copies of Logs and Surveys Run Exploratory❑ Development Service❑ Stratigraphic ❑
Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPIJJ
1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑
17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:
N/A
Contact Nita Summerhays Email Nita.Summerhaysbp.com
Printed Na 1---Nita.-Suriimeri2ais r Title Data Coordinator
Sig '-tu ../444r!..,7/ ' L'�il/ Phone 564-4035 Date 3/31/2014
_-._------>- V&F 572_2,1!,_
s`ZL/,G
Form 10-404 Revised 10/2012 7 Submit Original Only
Daily Report of Well Operations
ADL0028258
. ., ... ., SUMMARY a`
BRUSH Aqi. 7r >„r,„
PULL 3-1/2”X-LOCK W/ PETREDAT GAUGES FROM XN NIP @ 7153' SLM
PULL 3-1/2"WFD WRP W/GAUGES FROM 7328' SLM/7246' MD
SET 3 1/2"WFD WRP@ 7316' MD
***WELL S/I ON DEPARTURE, READY TO POP***
11/04/09: WFD WRP MONTHLY RENTAL FOR 09/25/09 - 10/24/09. MO 2 (RPC)
12/23/09: WFD WRP MONTHLY RENTAL FOR 10/25/09 - 12/14/09. MOS 3 &4 (RPC)
01/24/10: WFD WRP MONTHLY RENTAL FOR 12/25/09 -01/23/10. MO 5 (TLH)
02/22/10: WFD WRP MONTHLY RENTAL FOR 01/24/10 -02/22/10. MO 6 (CD)
03/24/10: WFD WRP MONTHLY RENTAL FOR 02/23/10 -03/21/10. MO 7(CD)
04/23/10: WFD WRP MONTHLY RENTAL FOR 03/22/10 -04/20/10. MO 8 (CD)
05/29/10: WFD WRP MONTHLY RENTAL FOR 04/21/10 -05/20/10. MO 9 (PJC)
06/26/10: WFD WRP MONTHLY RENTAL FOR 05/21/10 -06/20/10. MO 10 (PJC)
07/25/10: WFD WRP MONTHLY RENTAL FOR 06/21/10 -07/20/10. MO 11 (PJC)
08/28/10: WFD WRP MONTHLY RENTAL FOR 07/21/10 - 08/19/10. MO 12 FINAL
(PJC)
8/25/2009
T/I/0=1240/1240/0 Brush and Flush Pumped 5 bbls neat methanol and 50 bbls diesel
@ 180*F down tubing to assist with brush and flush. FWHP=0/1240/200 IA and OA open.
8/25/2009 Slickline in control of well upon departure.
FLUIDS PUMPED
BBLS
50 DIESEL
5 METH
55 TOTAL
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TREE=. 3-1/8"5M CM/
WELLHEAD= 11"FMC AFETY NOTES:
ACTUATOR= NA S-115
KB.ELEV= 82.2'
BF.ELEV= 53.50'
KOP= 500'
Max Angle= 36 @ 2853' 1006' H 7-5/8"TAM PORT COLLAR, ID=6.875"
Datum MD= 7394'
Datum TVD= 6700'SS
I I 1 2201' —3-1/7 HES X NIP,ID=2.813"
7-5/8"CSG,29.7#,S-95/L-80, ID=6.875" — 3248' I--A
GAS LIFT MANDRELS
Minimum ID = 2.813" @ 2201' ST MD TVD DEV TYPE VLV LATCH PORT DATE
3-1/2" HES XN NIPPLE 3 3336 3010 33 KBG2-9 DOME INT 16 02/03/03
2 5088 4512 22 KBG2-9 DMY INT 0 12/30/02
1 5269 4680 20 KBG2-9 SO INT 20 02/03/03
ITTI 5357' I-13-1/2"BKR CMD SLIDING SLV, ID=2.813"
3-1/2"TBG,9.2#,L-80,.0087 bpf,ID=2.992" 5399' 5381' -BKR LOC SEAL ASSY,ID=3.00" I
5-1/2"CSG, 15.5#,L-80, ID=4.950" — 5382'
5383TOPOFBKRPBR ID= LA
5-1/2"X3-1/2"XO, ID=3.000" — 5402' 5402'' (4BTM OF 3-1/2"BKR SEAL ASSY,ID=3.00"
t 5451' I—3-1/2"HES X NIP,ID=2.813" I
PERFORATION SUMMARY
REF LOG: ' 5989' —3-1/2"HES X NIP,ID=2.813"
ANGLE AT TOP PERF: 28 @ 7250'
Note:Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE • 6000' —MARKER JT W/RA TAG
2-1/2" 6 7250-7280 0 01/27/03
2-1/2" 6 7380-7400 0 01/22/03 ■ 7141' H MARKER JT W/RA TAG
7171' —3-1/2"HES X NIP,ID=2.813"
7316' -j3-1/2"WFD WRP(08/25/09)
PBTD —I 7487'
111111
3-1/2"CSG,9.2#,L-80, ID=2.992" —I 7585' 1.1.•.1.1.1.
DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT
12/30/02 JLM/KK ORIGINAL COMPLETION 09/29/09 RO/SV CORRECTIONS(CARB) WELL: S-115
01/21/03 MH/TP C/O GLV 12/19/09 BSE/SV SET WRP(08/25/09) PERMIT No:°2022300
01/22/03 BM/TP ADD PERF 02/04/10 PJP/PJC DRAWING CORRECTIONS API No: 50-029-23130-00
01/27/03 DV/DM/TP ADD PERF,CARB/CaCO3 TOP SEC 35,T12N, R12E,4406'FSL&4499'FEL
02/03/03 RWL/tlh GLV UPDATE
04/09/03 DRS/TP TVD/MD CORRECTIONS BP Exploration (Alaska)
~ ~
Anchorage, Alaska 99519-6612
June 25, 2009 ~ ~~ ~.~~-~~~~~~~~.~
Mr. Tom Maunder JUL ~~. 2009
Alaska Oil and Gas Conservation Commission ~~p~~~ ~~~~ ~~~~ ~~~~m ~~~m~~~i~~
333 West 7th Avenue ~n~~~a~~a~~
Anchorage, Alaska 99501
Sub"ect: Corrosion Inhibitor Treatments of S-Pad ~b °~- ~~
1
~- ~~~
Dear Mr. Maunder,
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,
~'' ~~~~ ~iU~ ~ `' ~~)C~
~~~~
Torin Roschinger
BPXA, Well Integrity Coordinator
~
BP Exploration (Alaska ) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
RepoR ot Sundry Operations (10-404)
S-pad
~
Dffie
6/25/2009
Well Name
PTD S
Initial top of
cement
Vol. of cement
um ed
Final top of
cement
Cement top off
date
Cortosion
inhibitor Corrosion
inhibitod
sealant date
ft bbls ft na al
S-01B 1952020 025 NA 0.25 NA 2.6 5/30/2009
S-02A 1941090 025 NA 025 NA 1.7 5/25l2009
S-03 1811900 1325 NA 1325 NA 92.65 5/20/2009
S-Oa 7830790 0 NA 0 NA O.s 5/25/2009
S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009
5-06 1827650 0 NA 0 NA O.s 5/26I2009
S-o7A 1920980 0 NA 0 NA o.s 5/26/2009
S-OeB 2010520 0 NA 0 NA O.eS 5/27l2009
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-11B 1990530 025 NA 025 NA 1.7 5/27/2009
S-72A 1851930 025 NA 025 NA 1.7 6/1/2009
S-13 1821350 8 NA 8 NA 55.3 6/1/2009
S-15 1840170 025 NA 025 NA 3 6/2/2009
S-17C 2020070 025 NA 025 NA 2.6 6/t/2009
S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009
S-19 1861160 0.75 NA 0.75 NA 22 5/79/2009
S-20A 2070450 025 NA 025 NA 1.3 5/19/2009
5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009
S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009
S-23 1901270 025 NA 025 NA 1.7 5/25/2009
S-24B 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
5-278 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-29AL1 1960120 0 NA 0 NA 0.85 5/27/2009
5-30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009
S-31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009
5-32 1901490 0.5 NA 0.5 NA 3.a 5/31/2009
S-33 1921020 0.5 NA 0.5 NA 4.3 5/26I2009
S-3a 1927360 0.5 NA 0.5 NA 3.a 5/37/2009
S35 1921480 0 NA 0 NA .85 in 5/31/2009
S36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009
5-37 1920990 t25 NA 125 NA 11.9 5/27/2009
5-38 1921270 0.25 NA 025 NA 102 5/27/2009
5-41 t960240 1.5 NA 1.5 NA 11.t 5/30/2009
S-a2 1960540 0 NA 0 NA O.s 5/30/2009
5-43 1970530 0.5 NA 0.5 NA t.7 5/28/2009
S-ad 1970070 025 NA 0.25 NA i.7 5/28/2009
S~700 2000780 2 NA 2 NA 21.3 5/29/2009
S-101 2001150 125 NA 125 NA 77.s 5/29/2009
5-102L7 2031560 725 NA 125 NA 11.1 5/31/2009
5-103 2001680 7.5 NA 1.5 NA 11.9 5/18/2009
S-t0a 20079fi0 1.75 NA 1J5 NA 15.3 5/20/2009
S-7o5 2001520 4 NA 4 NA 32.7 5/20/2009
5-106 2070720 1625 NA 1625 NA 174.3 6/2/2009
S-107 2011130 225 NA 225 NA 28.9 5/18/2009
S-to9 2011W0 3.5 NA 3.5 NA a0 5/30/2009
S-109 2022450 2 NA 2 NA 21.3 5130/2009
5-110 2011290 11.75 NA 11.75 NA 98.6 5/30/2009
5-17 t 2050510 2 NA 2 NA 19.6 5/30/2009
S-112 2021350 0 NA 0 NA O.i 5/30/2009
5-113 2021430 1.75 NA 1.75 NA 22.t 5/18~2009
5-114A 2021980 125 NA 125 NA 102 5/30/2009
5-115 2022300 2.5 NA 2.5 NA 272 5/29/2009
S-716 2031810 1.5 NA 1.5 NA t3.6 5/28/2009
&177 2030120 1.5 NA 1.5 NA 15.3 5/29/2009
S-118 2032000 5 NA 5 NA 76.5 5/28/2009
5-119 2041620 1 NA 1 NA 52 5/30/2009
S-t20 2031980 5.5 NA 5.5 NA 672 5/29/2009
S-127 2060470 4.5 NA 4.5 NA 53.6 5/28/2009
S-722 2050810 3 NA 3 NA 27.3 5/29/2009
S-72s 2041370 1.5 NA 1.5 NA 20.4 5/26/2009
S-124 2061360 1.75 NA 1.75 NA 71.9 5/26/2009
S-125 2070830 225 NA 225 NA 20.a 5/28J2009
S-726 ~20710970 125 NA 125 NA 15.3 6/t/2009
5-200 1972390 1.25 NA 1.25 NA 1d.5 5/28/2009
5-201 2001840 0 NA 0 NA 0.85 6/19/2009
S-2i3A 2042730 2 NA 2 NA 73.6 5/29/2009
5-2/5 2021540 2 NA 2 NA 78.7 6/1/2009
S-2t6 2001970 4.75 NA 4.75 NA 51 5/29/2009
5-217 2070950 025 NA 025 NA 1.7 6/7/2009
5-400 2070740 2 NA 2 NA 9.4 5/28/2009
S-407 2060780 16 NA i6 NA 99.5 6/2/2009
5-504 0 NA 0 NA 0.85 5/28/2009
~
P.l. Suprv ~ ~- Z ZYO ~
Safety Valve & Well Pressures Test Report ReviewedB~ l
Comm
Pad: PBU_s InspDt: 2/18/2008 Inspected by John Crisp Interval InspNo svsJCr08022114U934 Related Insp:
Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Rich Vincent Reason 180-Day `~
_ ._. _._
Well Data
~ _
Fi
lo£s
Well Permit Separ Set L/P
Number Number PSI PSI Trip
5-100
_ _
2000780
_ _ _
~
153 ~
i __
125 _ _--
~ 125
S-103 .--
2001680 -
__
-
-
i 153 ~
_.
125
--__...
120
- --- ---a- _ _- ~.. --
S-105 2001520 1I153 125 i 110
5-106 i
'
~ __ ----F- ---t-.
2010120 i L53 1
~
~
j
125 ~ _ _
40
5
S-108
--~- 2011000
-- 153
- -
- 125
-- - I 2l
I
-----
S-109
- - 2022450
-- - ,
_~3 i
125 1 125
S 1136 ~
2021430
~
153
125 - -
~ 125
___-~S-115 ~ 2022300 i 153 ~ T25
---
120
S-117 ~ -
2030120 -~
~ - -
153 ~
125
135
S-l2i ~ 2060410 ~ 153 j 125 ]25
- - -- -
S-122
_-
-
2050810
153
125
-- __
110
___
S-125 ~ ---
_2070830
~ 153
~-
125
115
S-17C '
-
I 2020070
~ 153 ~ 1 25 ~
i 110
-
S-! 8A
---- -
2021630
- -
~ f-
- -
153 i - --
t 25 I ---
100
S-
A
~ 2042130 ~ 153 ~
~ 125 i 125
_
-__.
--
-
5-44
i_ .. ----------- -~ -
1970060
----- _
-_ ~ -
153 i
----'- --
125
-- --
100
~--
j SSV ~ SSSV Shutln
Test Test Test Date SI
Code Code Code
_ - __ _ _ _
It WellType_ -_ _ _ Well Pressures
OiI,WAG,GINJ, Inner Outer Tubing
GAS,CYCLE, SI PSI PSI PSl
Src: Inspector
_ _ _ _ _ _ _
~ Gas Lif£ Waiver ~ Comments ~
Yes/No Yes/No
-- -
- - __~
-
-~
-- - -- --
-____I
-.___ _.___.__..__.
-- -------- i
- -1
Comments
~~~~ ~~~~~~ a~ ,
~~ ~~~1 ~ AR ~ ~ 2001;
•
Performance
Wells Components Failures Failure Rate
_ 16 - -. 32- -- -- --i-- - __ __ 3.12%_ _
Monday, February 25, 2008
e
e
MICROFILMED
07/25/06
DO NOT PLACE
ANY NEW MATERIAL
UNDER THIS PAGE
F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc
;2 J.- ~l/~ )..n't (--
DATA SUBMITTAL COMPLIANCE REPORT
2/1/2005
Permit to Drill 2022300
Well Name/No. PRUDHOE BAY UN AURO S-115
Operator BP EXPLORATION (ALASKA) INC
- ~-
-------------
TVD 6970;../" Completion Date 1/22/2003 / Completion Status 1-01L
Current Status 1-01L
UIC N
MD 7600 v
- --- -._----
REQUIRED INFORMATION
Mud Log No
-~- -- ---~-
----------
DATA INFORMATION
Types Electric or Other Logs Run: MWD, GR, PWD, PEX, BHC Sonic, SCMT
Well Log Information:
Log/
Data
Type
",,-~ -
J\. ,LOg
kLog
~
I
¿o
Electr
Digital Dataset
Med/Frmt Number Name
------ -- -----
r Caliper log
l--Sonic
v-'Gamma Ray
U525 See Notes
C
'/Log
~.
~/
L/Log
'~
; Rpt
~·C
~g
~ensity
ec-ement Evaluation
See Notes
./Neutron
Gamma Ray
Directional Survey
'1-r526 See Notes
Induction/Resistivity
: Et) 0
~g
{09
: Log
c.Difectional Survey
See Notes
C' Pressure
tTemperature
Samples No
fn~¿ À4j ~- À...ó-{) À....
r
API No. 50-029-23130-00-00
Directional Survey Yes
(data taken from Logs Portion of Master Well Data Maint)
Log Log Run Interval OH/
Scale Media No Start Stop CH
25 Blu 1 .]3030 7510 f5Pen
25 Blu [,.3030 7510 !open
25 Blu jVð 109 7600 Open
3040 7511 Open
25 Blu
5 Co I
25 Blu
25 Blu
25 Blu
3030 7510 Open
5220 7440 Case
ìf/~ 3030 7510 Open
3030 7510 Open
FA J) 109 7600 Open
0 7600 Open
110 7600 Open
3030 7510 Open
25 Blu
--
Received Comments
217/2003 [;latfOrm Express
217/2003 latform Express
217/2003 ~mposite final Print
217/2003 tDWG edit in .tif format
with final PDS graphics
217/2003 --Platform Express
217/2003 ~
217/2003 l/'Triple combo
217/2003 ....Platform Express
217/2003 teõ-mposite final Print _
1/21/2003
2/7/2003 VDWG edit in .tif format
with final PDS graphics .~
217/2003
- 1 0 7600 Open 1/21/2003
25 Blu M]) 3030 7510 Open 217/2003 v;riple combo
5 Blu 6840 7086 Case 4/14/200~tatic Bottom-Hole
Pressure Survey wrremp,
R,CCL
5 Blu 6840 7086 Case 4/14/2003 L Static Bottom-Hole
Pressure Survey wrremp,
GR, CCL
DATA SUBMITTAL COMPLIANCE REPORT
2/1/2005
Permit to Drill 2022300
Well Name/No. PRUDHOE SAY UN AURO S-115
Operator BP EXPLORATION (ALASKA) INC
API No. 50-029-23130-00-00
MY'
1-/ --
¿VLog
7600
TVD 6970
Completion Date
1/22/2003
Completion Status
5 Blu
1-01l
Current Status 1-01l
UIC N
-- --------
Casing collar locator
6840
7086 Case 4/14/2003 ....static Bottom-Hole
Pressure Survey wlTemp,
GR, CCl
- ---- -----"---
Well Cores/Samples Information:
Name
Interval
Start Stop
Sent
Received
Sample
Set
Number Comments
'-,~/
Well Cored?
ADDITIONAL INFORMATION
Y~
Daily History Received?
t£)¡N
G/N
Chips Received? Y / N
Analysis ~
Received?
Formation Tops
--------- --- -------
-. -"-- -_.~-----~
Comments:
------ --~ -~-----
Compliance Reviewed By:
~
'-'
Date:
~)~. ('v1õV\. Jvt~ )--"
.-- "--- ---~---
~
Schlumllergel'
Alaska Data and Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
A TTN: Beth
Well
Log Descñption
Job#
L-112 ~O,;¿ _ - ~~j
S-115 ().Od él ~C~
SBHP SURVEY
SBHP SURVEY
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center LR2-1
900 E Benson Blvd.
Anchorage AK 99508-4254
Ko \}', /V\.~,Q_C"':''\/''/V\
Date Delivered:
RECEiVEr)
14 2003
tJ)R
Alaßhe. ü¡'¡ ~), Gs.$ Con~. Cúmm!$~n
An~~
04/03/03
NO. 2735
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Borealis
Aurora
Date
Sepia
Color
CD
BL
02/19/03
03/12/03
------ .
Schlumberger DCS
3940 Arctic Blvd Suite 300
Anchorage AK 99503-5789
A TTN: Beth
Received by:
-
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
Revised: 04/04/03,
, .\
')
)
Put on Production
1. Status of Well
IBI Oil 0 Gas D Suspended D Abandoned D Service ,f:t:::;t:~:~ffij~~~š'T
2. N:;~xOpfl~~:~~to(~laSka) Inc. .)~~~r.;::i);' .. :j' 7. ~~~~3~umber
,~,.,;.{~,".,"~"
3. Address l:;::~~~~\ 8. API Number
P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23130-00
4. Location of well at surface 9. Unit or Lease Name
4406' NSL, 4500' WEL, SEC. 35, T12N, R12E, UM X = 618930, Y = 5980610 Prudhoe Bay Unit
At top of productive interval
4730' NSL, 1674' WEL, SEC. 34, T12N, R12E, UM X = 616470, Y = 5980896 10. Well Number
At total depth
4743' NSL, 1667' WEL, SEC. 34, T12N, R12E, UM X = 616477, Y = 5980909
11. Field and Pool
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Aurora Pool
KBE = 64.1' ADL 028258 (Undefined)
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions
12/20/2002 12/2612002 1/22/2003 NIA MSL One
17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost
7600 6970 FT 7488 6858 FT IBI Yes 0 No (Nipple) 2022' MD 1900' (Approx.)
22. Type Electric or Other Logs Run
MWD, G R, PWD, PEX, BHC Sonic, SCMT
23.
CASING
SIZE
3411 X 2011
7-5/8"
5·1/2" x 3·1/2"
CASING, LINER AND CEMENTING RECORD
SETTING DEPTH HOLE
Top BOTTOM SIZE
Surface 109' 4211
29' 3248' 9-7/8"
26' 7585' 6-3/4"
CEMENTING RECORD
~60 sx Arctic Set (Approx.)
497 sx PF 'L', 161 sx Class 'G'
193 sx LiteCrete, 194 sx Class 'GI
WT. PER FT.
91.5#
29.7#
15.5# 19.2#
GRADE
H-40
NT -95
L-80
24. Perforations open to Production (MD+ TVD of Top and
Bottom and interval, size and number)
2-1/211 Gun Diameter, 6spf
MD TVD MD TVD
7250' - 7280' 6621' - 6651'
7380' - 7400' 6751' - 6771'
25.
SIZE
3-1/211, 9.2#, L-80
26.
Classification of Service Well
8-115
AMOUNT PULLED
TUBING RECORD
DEPTH SET (MD)
5400'
PACKER SET (MD)
None
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze Protect with 60 Bbls of Diesel
7380' - 7400'
7250' - 7280'
Frac'd; Placed 98,000 Ibs of 16/20 Carbolite Behind Pipe
Frac'd; Placed 197,7761bs of 16/20 Carbolite Behind Pipe
27. PRODUCTION TEST
Date First Production Method of Operation (Flowing, gas lift, etc.)
March 22, 2003 Flowing
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF WATER-BBL
4/3/2003 4 TEST PERIOD 3,217 4,386 462
Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBl
Press. 283 24-HoUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
No core samples were taken.
Form 10-407 Rev. 07-01-80
OR G ~ AL
RBDMS 8FL
vì=
CHOKE SIZE
830
Oil GRAVITY-API (CORR)
GAS-Oil RATIO
1,363
APR 7
Submit In Duplicate
')
29. Geologic Markers
Marker Name Measured True Vertical
Depth Depth
Ugnu 4120' 3656'
Ugnu M Sands 5292' 4702'
Schrader Bluff N Sands 5499' 4898'
Schrader Bluff 0 Sands 5609' 5004'
HRZ 7210' 6581'
Kalubik 7242' 6613'
Kuparuk C 7246' 6616'
I
Kuparuk B 7324' 6695'
Kuparuk A 73ß9' 6740'
Miluveach 7438' 6809'
31. List of Attachments:
)
30.
Formation Tests
Include interval tested, pressure data, all fluids recovered and
gravity, GOR, and time of each phase.
R: ,:i)E""·~('~'Eí"""'iV'I·E·~~D
-"" 1'._8 ,
APR 04 2003
Alaska 00 & GiS Gm¡¡. Ccmm¡~ion
A~1C~:1ÓÌ1j1:)
I'" I
Summary of Daily Drilling Reports and Post-Rig Work, Surveys
32. I hereby certify that the foregoing is true· and correct to the best of my knowledge
Signed TerrieHubble ~A1\.ÌR_~ Title Technical Assistant Date Ot¡·Olf'D3
S-115 202-230 Prepared By Name/Number: Terrie Hubb/e, 564-4628
Well Number Permit No.1 Approval No. Drilling Engineer: Rob Tirpack, 564-4166
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.
ITEM 1: Classification of Service Wells: Gas injection; water injection, steam injection, air injection, salt water disposal, water supply for injection, observation,
injection for in-situ combustion.
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any
attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the
producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data
pertinent to such interval.
ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
ORIGINAL
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMPLETION REPORT AND LOG
)
)
1. Status of Well Classification of Service Well
2. ~~; of ~::r 0 Suspended 0 Abandoned rD §>!!",ice f1ll!fl! ~l 7. Permit Number
3. A:~;::~:::1:I:k:~::e, Alaska 99519-6612 L~~~ \~ 8. ;~:~~~r»oo
\".,,..1'"0'-"11:"
4. Location of well at surface 9. Unit or Lease Name
4406' NSL, 4500' WEL, SEC. 35, T12N, R12E, UM X = 618930, Y = 5980610 Prudhoe Bay Unit
At top of productive interval
4730' NSL, 1674' WEL, SEC. 34, T12N, R12E, UM X = 616470, Y = 5980896 10. Well Number
At total depth
4743' NSL, 1667' WEL, SEC. 34, T12N, R12E, UM X = 616477, Y = 5980909
11. Field and Pool
5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Aurora Pool
KBE = 64.1' ADL 028258 (Undefined)
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions
12/20/2002 f 12/26/2002' 112212003 NIA MSL One
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost
7600 6970 FT 7488 6858 FT 181 Yes 0 No (Nipple) 2022' MD 1900' (Approx.)
22. Type Electric or Other Logs Run
MWD, GR, PWD, PEX, BHC Sonic, SCMT
8-115
23.
CASING
SIZE
34" X 20"
7-5/8"
5-1/2" x 3-1/2"
WT. PER FT.
91.5#
29.7#
15.5# I 9.2#
GRADE
H-40
NT -95
L-80
CASING, LINER AND CEMENTING RECORD
SETIING DEPTH HOLE
Top BOTIOM SIZE
Surface 109' 42"
29' 3248' 9-7/8"
26' 7585' 6-3/4"
CEMENTING RECORD
260 sx Arctic Set (Approx.)
497 sx PF 'L" 161 sx Class 'G'
193 sx LiteCrete, 194 sx Class 'G'
AMOUNT PUllED
24. Perforations open to Production (MD+ TVD of Top and
Bottom and interval, size and number)
2-1/2" Gun Diameter, 6 spf
MD TVD
7250' - 7280' 6621' - 6651'
7380' -7400' 6751' - 6771'
SIZE
3-1/2",9.2#, L-80
TUSING RECORD
DEPTH SET (MD)
5400'
PACKER SET (MD)
None
25.
MD
TVD
26.
ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze Protect with 60 Bbls of Diesel
7380' - 7400'
7250' - 7280'
Frac'd; Placed 98,000 Ibs of 16/20 Carbolite Behind Pipe
Frac'd; Placed 197,776Ibs of 16/20 Carbolite Behind Pipe
27.
Date First Production
Not on Production
Date of Test Hours Tested
PRODUCTION TEST
Method of Operation (Flowing, gas lift, etc.)
NIA
PRODUCTION FOR Oll-BSl
TEST PERIOD
GAs-McF
WATER-Bsl
CHOKE SIZE
GAS-Oil RATIO
Flow Tubing Casing Pressure CALCULATED
Press. 24-HoUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips.
Oll-Bsl
GAs-McF
WATER-BSl Oil GRAVITY-API (CORR)
No core samples were taken.
G'¡-
'!I r
Form 10-407 Rev. 07-01-80
RBOMS BFl
FER .? Li ?n¡,p
Submit In Duplicate
')
)
29.
Geologic Markers
30.
Formation Tests
Marker Name
Measured
Depth
True Vertical
Depth
Include interval tested, pressure data, all fluids recovered and
gravity, GOR, and time of each phase.
Ugnu
4120'
3656'
Ugnu M Sands
5292'
47021
Schrader Bluff N Sands
54991
4898'
Schrader Bluff 0 Sands
5609'
5004'
HRZ
7210'
6581'
Kalubik
7242'
6613'
Kuparuk C
7246'
66161
Kuparuk B
7324'
6695'
Kuparuk A
7369'
6740'
Miluveach
7438'
6809'
31. List of Attachments:
Summary of Daily Drilling Reports and Post-Rig Work, Surveys
32. I ~erebY certify that the for~in~ is true and correct to the best of my knowledge
Signed Terrie Hubble ~.o ÀJ\.1.l- ~ Title Technical Assistant Date O~· ~ . Q~
S-115 202-230 Prepared By Name/Number: Terrie Hubb/e, 564·4628
Well Number Permit No.1 Approval No. Drilling Engineer: Rob Tirpack, 564-4166
INSTRUCTIONS
GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.
ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation,
injection for in-situ combustion.
ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any
attachments.
ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the
producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data
pertinent to such interval.
ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.).
ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool.
ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain.
ITEM 28: If no cores taken, indicate 'none'.
Form 10-407 Rev. 07-01-80
Legal Name:
Common Name:
Test Date
12/24/2002
LOT
8-115
8-115
Test Type
Test Depth (TMD)
3,248.0 (ft)
BP
Leak-Off·TestSummary
TestDepth(TVD)
2,936.0 (ft)
AMW
9.70 (ppg)
SUrface.·Pressure LeakOffPrés$lIre(IiJHP)
700 (psi) 2,179 (psi)
EMW
14.29 (ppg)
~
'~.
Printed: 1/2/2003 1:28:06 PM
)
)
BP
Operations Summary Report
Page 1 of 5
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-11 5
S-11 5
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 12/20/2002
Rig Release: 12/30/2002
Rig Number: 9ES
Spud Date: 12/20/2002
End: 12/30/2002
Date From - To Hours Task Code NPT Phase Description of Operations
12/19/2002 00:00 - 14:00 14.00 MOB P PRE Move Rig & all associated equipment from V-113 to S Pad.
14:00 - 18:30 4.50 MOB P PRE Raise Derrick, R/U Floor & Bridle down while waiting for HES
wire line to complete work on S-102
18:30 - 19:30 1.00 MOB P PRE Move rig over to S-115. While moving over well it was
observed that the rig, when jacked down, would hit the roof of
the S-1 00 wellhouse. This wellhouse will have to be removed.
19:30 - 23:30 4.00 MOB P PRE Load into Pipe Shed and strap 4" DP for surface hole while
S-100 well house is being moved.
23:30 - 00:00 0.50 MOB P PRE Spot rig over S-115.
12/20/2002 00:00 - 02:00 2.00 MOB P PRE Spot Sub on S-115, Spot Pit Complex, Hook up lines & start
taking on Water. RIG ACCEPTED @ 02:00 HRS.
02:00 - 08:30 6.50 RIGU P PRE Mix Spud Mud. N/U Riser, Install all valves. Change out Drilling
Nipple to 20".
08:30 - 11 :00 2.50 DRILL P SURF P/U 4" DP. Found Ice in Conductor @ 39'. M/U Bit on HWDP.
Fill Riser & check for leaks - OK. Wash through ice to 90'.
POH, B/O Bit.
11 :00 - 14:30 3.50 DRILL P SURF Pick up 105 Jts. 4" DP & Stand back in Derrick.
14:30 - 16:00 1.50 DRILL P SURF P/U HWDP, Jars & Collars - Stand back in Derrick.
16:00 - 17:30 1.50 DRILL P SURF Cut & Sip Drilling line. Inspect Brakes, Drawworks. Service Top
Drive & Crown.
17:30 - 19:30 2.00 DRILL P SURF M/U BHA #1. Orient Tools & UBHO for Gyro.
19:30 - 20:00 0.50 DRILL P SURF Pre -Spud Meeting with Crew & all Service Personnel.
20:00 - 20:30 0.50 DRILL P SURF P/U SWS Sheaves & Gyro-Data Tool. R/U for Gyro.
20:30 - 23:30 3.00 DRILL P SURF M/U Top Drive, wash down & Tag Cement @ 108'.
Spud in at 2100 hrs and drill from 108' to 359'. 550 GPM @
880 psi. Gyro survey each stand. AST = 0.3 Hrs. ART = 0.5
Hrs.
23:30 - 00:00 0.50 DRILL P SURF Stand back 2 stands, P/U Jar stand and go back to bottom.
12/21/2002 00:00 - 15:30 15.50 DRILL P SURF DRILL FROM 359' TO 1771', 600 GPM @ 2270 PSI. TQ =
5000
PU = 89K, DN = 68K, ROT = 79K, WOB = 30 TO 35K
AST = 5.83 HRS, ART = 2.87 HRS
15:30 - 16:00 0.50 DRILL P SURF CBU FOR BIT TRIP, INADVERTENTLY SIDETRACKED @
1700'
16:00 -17:30 1.50 DRILL P SURF DRILL FROM 1700' TO 1867' TO GET BACK ON TARGET
LINE.
DRILLING PARAMETERS SAME. 1 HR. - ALL SLIDE.
17:30 - 18:30 1.00 DRILL P SURF CIRCULATE HOLE CLEAN FOR BIT TRIP.
18:30 - 20:00 1.50 DRILL P SURF POH, NO SWABBING - NO TIGHT SPOTS.
20:00 - 20:30 0.50 DRILL P SURF DROP OFF UBHO SUB, CHANGE OUT BIT.
20:30 - 22:00 1.50 DRILL P SURF RIH, TAKING WEIGHT FROM 1050' TO 1800'. WORK
THROUGH WITHOUT PUMPS - OK. WASH LAST STAND
TO BOTTOM.
NO FILL.
22:00 - 23:00 1.00 DRILL P SURF DRILL FROM 1867' TO 2056'. 650 GPM @ 2880 PSI. TQ =
4300
PU = 90K, DN = 65K, ROT = 80K. WOB = 30 -35K
ALL ROTATE - 0.52 HRS.
23:00 - 00:00 1.00 DRILL N WAIT SURF HI-LINE POWER WENT DOWN. START RIG MOTORS &
EQUIP.
RE-BOOT MWD COMPUTERS.
12/22/2002 00:00 - 05:30 5.50 DRILL P SURF DRILL FROM 2056' TO 3263'.650 GPM @ 3250 PSI. TQ =
Printed: 1/2/2003 1 :28: 15 PM
)
)
BP
Operations Summary Rep.ort
Page 2 of5
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-11 5
S-11 5
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 12/20/2002
Rig Release: 12/30/2002
Rig Number: 9ES
Spud Date: 12/20/2002
End: 12/30/2002
Date From - To Hours Task Code NPT Phase Descri ption· of Operations
12/22/2002 00:00 - 05:30 5.50 DRILL P SURF 4300
PU = 108K, DN = 75K, ROT = 89K.
AST = .27 HRS. ART = 3.95 HRS.
05:30 - 06:30 1.00 DRILL P SURF CIRCULATE HOLE CLEAN.
06:30 - 13:30 7.00 DRILL P SURF POH. INTERMITTENT DRAG & SWABBING. BACKREAM
FROM 2915' TO 1960'. PULL DRY TO 1769'. BACKREAM TO
1480'. PULL DRY TO SURFACE, CLEAN EXCESSIVL Y
BALLED UP BIT & STABILIZER.
13:30 - 15:30 2.00 DRILL P SURF RIH. WORK PIPE THROUGH OCCASIONAL TIGHT SPOTS -
DID NOT HAVE TO PUMP.
15:30 - 17:00 1.50 DRILL P SURF CIRCULATE HOLE CLEAN - ROTATE & RECIPROCATE 10'.
17:00 - 19:00 2.00 DRILL P SURF POH w/DP. NO PROBLEMS.
19:00 - 20:30 1.50 DRILL P SURF LID BHA
20:30 - 21 :00 0.50 DRILL P SURF CLEAR & CLEAN FLOOR
21 :00 - 22:30 1.50 CASE P SURF RIU TO RUN 7 5/8" CASING, C/O TO LONG BAILS, MAKE
UP FRANKS TOOL, MAKE DUMMY RUN WI HANGER &
LANDING JT., RIU TONGS & PLATFORM.
22:30 - 00:00 1.50 CASE P SURF PJSM WITH ALL HANDS. MIU SHOE TRACK, BAKER-LOC
CONNECTIONS. PUMP THROUGH wI FRANKS TOOL -
CHECK FLOATS - OK. CONTINUE RIH.
12/23/2002 00:00 - 04:00 4.00 CASE P SURF RUN TOTAL 80 JTS. 75/8" CASING TO 3248'
04:00 - 04:30 0.50 CEMT P SURF R/D FRANKS TOOL, RIU CEMENT HEAD.
04:30 - 07:00 2.50 CEMT P SURF BREAK CIRCULATION & STAGE UP PUMPS TO 8 BPM @
825 PSI. C & C MUD TO FV -50, YP - 16, GELS - 7/9.
PRESSURE DOWN TO 545 PSI.
07:00 - 09:30 2.50 CEMT P SURF PJSM with all Hands. Switch to HOWCO. Pump 10 bbls. water,
Test lines to 3500 psi., Pump 10 bbls water. Pump 75 bbls 10.5
ppg Alpha Spacer. Drop bottom plug then pump 350 bbls (495
sx) 10.7 ppg, Permafrost' L' lead Slurry followed by 30 bbls.
(160 sx) 15.8 ppg Premium' G' Tail Slurry. Drop Top Plug and
allow Howco to displace lines w/1 0 bbls water. Switch to Rig
pumps and displace wI 136 bbls Mud. Bump Plug wI 1500 psi.
Check Floats - OK. 30 bbls. good Cement to surface.
09:30 - 11 :00 1.50 CEMT P SURF LID CEMENT HEAD & LANDING JT., LID CASING EQUIP.
11 :00 - 14:00 3.00 BOPSUR P SURF NID RISER & DIVERTER SPOOL - STAND BACK IN CELLAR
14:00 - 18:30 4.50 WHSUR P PROD1 MOVE CASING & SPEED HEAD INTO CELLAR, C/O RISER
BOOT TO 16", NIU CASING HEAD, SPEED HEAD & BOPE.
TEST METALI METAL SEAL TO SPEED HEAD TO 1000 PSI.
18:30 - 22:00 3.50 BOPSUR P PROD1 TEST ALL BOPE COMPONENTS TQ 250 / 3500 PSI.
WITNESS OF TEST WAIVED BY CHUCK SHEVE, AOGCC.
22:00 - 22:30 0.50 WHSUR P PROD1 RID TEST EQUIP., INSTALL WEAR BUSHING.
22:30 - 00:00 1.50 DRILL P PROD1 PIU 45 SINGLES OF 4' DP & STAND BACK IN DERRICK.
12/24/2002 00:00 - 01 :00 1.00 DRILL P PROD1 RIH w/4" DP, POH STAND BACK TOTAL 35 STANDS IN
DERRICK.
01 :00 - 01 :30 0.50 DRILL P PROD1 SERVICE TOP DRIVE & CROWN.
01 :30 - 03:30 2.00 DRILL P PROD1 PU & MU BHA # 3. FLOW TEST MWD - OK.
03:30 - 05:30 2.00 DRILL P PROD1 RIH, PICKING UP SINGLES TO 3020'.
05:30 - 06:00 0.50 DRILL P PROD1 PERFORM TRIP & STRIPPING DRILLS.
06:00 - 06:30 0.50 DRILL P PROD1 CBU FOR CASING TEST.
06:30 - 07:30 1.00 CASE P PROD1 TEST 7 5/8" CASING TO 3500 PSI FOR 30 MINUTES.
07:30 - 10:00 2.50 DRILL P PROD1 WASH DOWN - TAG CEMENT@ 3134'. DRILL CEMENT,
SHOE TRACK & 20 FT OF NEW HOLE TO 3683'.
10:00 - 10:30 0.50 DRILL P PROD1 DISPLACE OLD MUD WITH NEW 9.7 PPG LSND MUD.
Printed: 1/2/2003 128:15 PM
)
)
sF>
Operations Summary .Report
Page 3 of 5
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-11 5
S-11 5
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 12/20/2002
Rig Release: 12/30/2002
Rig Number: 9ES
Spud Date: 12/20/2002
End: 12/30/2002
Date From - To Hours Task Code NPT Phase Description of Operations
12/24/2002 10:30 - 11 :30 1.00 DRILL P PROD1 PERFORM LOT TO 14.28 ppg EMW. TAKE ECD BASELINE
READINGS & SLOW PUMP RATES.
11 :30 - 00:00 12.50 DRILL P PROD1 DRILL FROM 3683' TO 4750'.330 GPM @ 2470 PSI
TO = 4.5 K, WOB = 5 TO 15 K, RPM = 80.
PU = 116 K, DN == 89 K, ROT = 99 K.
CALC ECD = 11.87PPG DRILLING ECD = 11.5 TO 11.9 PPG.
AST = 2.37 HRS, ART = 3.81 HRS.
PUMPING SWEEPS EVERY 200'.
DRILLING: THIS ASSEMBLY BUILDING @ 1 DEG. PER 100'.
SLIDING TO OFFSET BUILD.
12/25/2002 00:00 - 00:00 24.00 DRILL P PROD1 DRILL FROM 4750' TO 6660'.330 GPM @ 2920 PSI
TO = 8 TO 8.5K, WOB 7 TO 15K, ROT @ 80 RPM.
PU = 160K, DN = 109K, ROT = 129K.
DRILLING ECD = 0.6 TO 0.9 PPG. OVER CALCULATED
ECD.
SWEEPING HOLE EVERY 200 FT& BACKREAMING EACH
STAND @ 110 RPM.
12/26/2002 00:00 - 06:00 6.00 DRILL P PROD1 DRILL FROM 6660' TO 7314'.330 GPM @ 3010 PSI
TO = 9000, WOB = 10 TO 15K, ROT = 80 TO 100 RPM
PU = 175K, DN = 113K, ROT = 140K.
DRILLING ECD = 0.5 TO 0.7PPG OVER CALCULATED ECD.
HI-VIS SWEEPS EVERY 200 FT.
IN DRILLING BREAK IMMEDIATELY AFTER DRILLING
THROUGH A HARD STRINGER, DRILLER NOTICED A 3 %
INCREASE IN FLOW RATE.
06:00 - 06:30 0.50 DRILL P PROD1 SHUT DOWN PUMPS, PULL TOOLJOINT ABOVE ROTARY,
OBSERVE WELL TO BE FLOWING SLIGHTLY. SHUT WELL
IN AND MONITOR FOR PRESSURE - NO PRESSURE
INCREASE IN 15 MINUTES. CRACK CHOKE OPEN - NO
FLOW. OPEN WELL. FLUID LEVEL 2 FT. DOWN.
ESTABLISH CIRCULATION AND WORK PIPE. MUD
INITIAL Y GAS - CUT TO 9 PPG. BACK UP TO 10.3 PPG.
PREPARE TO RESUME DRILLING.
06:30 - 09:30 3.00 DRILL P PROD1 DRILL FROM 7314' TO 7600' - TD. 330 GPM @ 3205 PSI.
TO = 9500, WOB = 15 K, ROT @ 80 TO 100 RPM
PU = 180K, DN = 116K, ROT = 142K.
ECD PARAMETERS SAME. AST = 0.60 HRS. ART = 5.64
HRS
09:30 - 11 :00 1.50 DRILL P PROD1 CIRCULATE HI-VIS SWEEP @ 330 GPM W/11 0 RPM.
11 :00 - 14:30 3.50 DRILL P PROD1 WIPE HOLE TO SHOE. PULLED TIGHT ( 15K OVER) @
5200',3830',3750', & 3450'. WORKED THROUGH DRY.
14:30 -15:00 0.50 DRILL P PROD1 CBU @ SHOE (3248').
15:00 - 15:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE & CROWN.
15:30 - 17:30 2.00 DRILL P PROD1 RIH TO 7510'. WASH LAST STAND TO BOTTOM @ 7600'.
NO OBSTRUCTIONS - NO FILL.
17:30 - 21 :00 3.50 DRILL P PROD1 C & C MUD FOR LOGGING. CIRCULATE TAMDEM HI-VIS
SWEEPS @ 330 GPM & 110 RPM TO OBTAIN TRIPPING
ECD OF < 0.3 PPG. HOLE ECD = 11.65 PPG.
CALCULATED ECD = 11.44 PPG.
21 :00 - 00:00 3.00 DRILL P PROD1 POH WET 10 STANDS TO 6660'. NO SWABBING & NO
OVER PULLS. PUMP SLUG & CONTINUE POH TO SHOE.
NO PROBLEMS- DISPLACEMENT CORRECT - HOLE
Printed: 1/2/2003 1 :28: 15 PM
)
)
BP
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-115
S-115
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
NPT Phase
12/26/2002 21 :00 - 00:00 3.00 DRILL P PROD1
12/27/2002 00:00 - 01 :00 1.00 DRILL P PROD1
01 :00 - 01 :30 0.50 DRILL P PROD1
01 :30 - 03:30 2.00 DRILL P PROD1
03:30 - 04:30 1.00 EVAL P PROD1
04:30 - 06:00 1.50 EVAL P PROD1
06:00 - 07:00 1.00 EVAL P PROD1
07:00 - 07:30 0.50 EVAL P PROD1
07:30 - 08:00 0.50 EVAL N DPRB PROD1
08:00 - 09:00 1.00 EVAL N DPRB PROD1
09:00 - 11 :00 2.00 EVAL N DPRB PROD1
11 :00 - 13:30 2.50 EVAL N DPRB PROD1
13:30 - 14:00 0.50 EVAL N DPRB PROD1
14:00 - 17:00 3.00 EVAL N DPRB PROD1
17:00 - 19:30 2.50 EVAL N DPRB PROD1
19:30 - 20:30 1.00 EVAL N DPRB PROD1
20:30 - 00:00 3.50 EVAL P PROD1
12/28/2002 00:00 - 02:00 2.00 CASE P PROD1
02:00 - 02:30 0.50 CASE P PROD1
02:30 - 03:30 1.00 CASE P PROD1
03:30 - 05:30 2.00 CASE P PROD1
05:30 - 07:00 1.50 CASE P PROD1
07:00 - 09:00 2.00 CASE P PROD1
09:00 - 09:30 0.50 CASE P PROD1
09:30 - 13:30 4.00 CASE P PROD1
13:30 - 14:30 1.00 CASE P PROD1
14:30 - 15:30 1.00 CASE P COMP
15:30 - 16:30 1.00 CASE P COMP
16:30 - 21 :00 4.50 CASE P COMP
21 :00 - 22:00 1.00 CASE P COMP
22:00 - 00:00 2.00 CASE P COMP
12/29/2002 00:00 - 11 :00 11.00 CASE P COMP
Page 4 of 5
Start: 12/20/2002
Rig Release: 12/30/2002
Rig Number: 9ES
Spud Date: 12/20/2002
End: 12/30/2002
Description of Operations
CLEAN
POH to BHA from 7 5/8" casing shoe at 3248'. No swabbing,
no over pull, correct displacement.
Stand back Drilling Jars and HWDP.
Lay down bit and BHA #3
PJSM with Schlumberger crew and rig crew. Rig up wireline
unit.
Run PEX, AITH Induction, CNL Compensated Neutron, TLD
Density, BHC Sonic logs. Unable to pass 6400'. Work tools
with no success. POH E-line.
Rig down logging unit.
Service Top Drive and Crown.
Make up 6 3/4" hole opener and RIH with HWDP.
RIH with hole opener to 7 5/8" casing shoe at 3248', fill pipe.
RIH to 6400', pipe taking weight, 25K. Work pipe through tight
spot several times, RIH to 7600' and tag up.
Circulate and condition mud. Pump around high vis sweep, no
significant cuttings on bottoms up.
POH to 7437'. Tight hole, 35K over pull. Work pipe through
tig ht spot.
RIH 2 stands. Back ream from 7600' to 6098'
POH from 6098'. Stand back HWDP and lay down hole
opener.
PJSM with crews. Rig up Schlumberger E-line unit.
Run PEX, AITH Induction, CNL Compensated Neutron, TLD
Density, BHC Sonic logs to 7560'. Tools taking weight. Log
from 7560' to 7 5/8" casing shoe. POH and lay down tools.
MU Porcupine hole opener. RIH with HWDP & DP to 7 5/8"
shoe.
Service top drive & blocks.
Slip/cut 84' drilling line. Chk COM.
RIH to 7600' - TD. No problems or obstructions.
Circ & clean hole. Pump visc sweep around at 325 GPM and
110 RPM. Saw some splintery shale from bottoms up - appears
to be Miluveach, but not excessive amount.
Monitor well- OK. POH. Lay down drill pipe up to 5900'.
Spot SteelSeal pill in open hole from 5900' up to casing shoe at
3248' - across Schrader. Pump dry job.
POH. Lay down drill pipe.
Lay down 6 3/4" hole opener and jars. Stand back HWDP.
Pull wear bushing. Flush stack. Make dummy run with landing
joint and casing hanger.
Rig up to run 3 1/2" x 51/2" casing. PJSM with all hands.
Run 3 1/2" floats and check same. Run 68 joints 3 1/2" 9.2#
L-80 IBT-M tubing.
Change casing running tools to 5 1/2". Rig up fill up tool.
Pick up Baker PBR assembly and one joint casing. Circulate
50 bbl mud. RIH 5 1/2" 15.5# L-80 BTC-M casing. Fill every
joint and break circulation every 15 joints run.
Continue running 5 1/2" casing. Circ 15 min every 15 joints run.
CBU at 4500' and 5900'. Continue running casing. MU hanger
and landing joint. Land casing - OK.
Lost approx 10 bbl mud while running casing.
Printed: 1/2/2003 1:28:15 PM
) )
BP Page 5 of5
Operations Summary Report
Legal Well Name:
Common Well Name:
Event Name:
Contractor Name:
Rig Name:
S-115
S-115
DRILL +COMPLETE
NABORS ALASKA DRILLING I
NABORS 9ES
Start: 12/20/2002
Rig Release: 12/30/2002
Rig Number: 9ES
Spud Date: 12/20/2002
End: 12/30/2002
Date From - To Hours Task Code NPT Phase Description of Operations
12/29/2002 11:00-11:15 0.25 CASE P COMP RD Franks casing fill tool. RU cement head & lines.
11:15 -14:00 2.75 CEMT P COMP Break circ at 2 BPM. Stage up rate to 4 BPM. Losing 30 bph
initially dropping to 15-20 bph at end of circulating and not
improving further. Lost -70 bbl while circ & cond mud.
14:00 - 14:45 0.75 CEMT P COMP Pump 5 bbl CW 100. Test lines to 4000 psi. Pump 5 bbl CW
100 followed by 45 bbl Mudpush XL at 11.3 ppg.
Mix & pump 81 bbl (205 sx) LiteCRETE lead slurry at 12 ppg. 4
bpm @ 500 psi.
Batch mix & pump 40 bbl (190sx) Premium Class G with
additives at 15.8 ppg. 4 bpm @ 300 psi.
14:45 - 15:45 1.00 CEMT P COMP Wash up lines down Tee to flowline. Switch to rig pump and
displace with seawater at 5 bpm. Saw good pressure rise as
cement came up in annulus. Lost -25 bbl while displacing
cement. Bump plug as calculated with 2000 psi. Bleed off
pressure - floats holding. CIP at 15:45 hrs.
15:45 - 18:00 2.25 CEMT P COMP Rig down cement head and lines. Rig down casing running
tools.
18:00 - 18:30 0.50 WHSUR P COMP Install FMC 5 1/2" casing pack off, run in lock down screws and
test to 5000 psi.
18:30 - 19:30 1.00 RUNCOrvP COMP Rig up to run 3 1/2" completion. Make dummy run with tubing
hanger landing joint. PJSM with crew.
19:30 - 00:00 4.50 RUNCOrvP COMP RIH with 3 1/2" 9.2# L-80 IBT-M completion as per program.
12/30/2002 00:00 - 03:30 3.50 RUNCOrvP COMP RIH with 3 1/2" 9.2# L-80 IBT-M completion as per program.
03:30 - 04:30 1.00 RUNCOrvP COMP Space out completion string. Make up tubing hanger and
landing joint and position WLEG 10' above PBR.
04:30 - 05:00 0.50 RUNCOrvP COMP Reverse circulate 80 bbl clean sea water followed by 30 bbls
corrosion inhibited sea water.
05:00 - 06:00 1.00 RUNCOrvP COMP Land completion string. Run in lock down screws.
06:00 - 07:30 1.50 RUNCOrvP COMP Test tubing to 4000 psi for 30 minutes. Bleed pressure to 2500
psi and hold. Test 3 1/2" x 51/2" annulus to 4000 psi for 30
minutes. Bleed both sides down to 0 psi. Pressure up annulus
to 2800 psi. Shear DCK valve in GLM at 5269'
07:30 - 08:00 0.50 RUNCOrvP COMP Remove landing joint. Install trwo way check and test to 2800
psi.
08:00 - 09:30 1.50 BOPSUR P COMP Nipple down BOP.
09:30 - 13:30 4.00 WHSUR P COMP Nipple up FMC 3 1/8" 5000 production tree and adaptor flange.
Test to 5000 psi.
13:30 -14:00 0.50 WHSUR P COMP Rig up lubricator, pull two way check and rig down lubricator.
14:00 - 16:00 2.00 WHSUR P COMP Rig up hot oil lines and test to 3500 psi. Freeze protect well
with 60 bbl diesel and allow to 'U' tube.
16:00 - 17:00 1.00 WHSUR P COMP Rig up lubricator, install back pressure valve and test to 1000
psi from below. Rig down lubricator.
17:00 - 21 :00 4.00 WHSUR P COMP Secure well. Prepare rig for move.
Rig released at 21 :00 hrs 12/30/2002
Printed: 1/2/2003 1 :28: 15 PM
)
)
Well:
Field:
API:
Permit:
Date
S-11 5
Prudhoe Bay Unit / Aurora Pool
50-029-23130-00
202-230
Accept:
Spud:
Release:
Rig:
12/20/02
12/20/02
12/30/02
Nabors 9ES
PRE-RIG WORK
01/21/03
WELL SHUT IN ON ARRIVAL. SET 3.5" X C-SUB. PULL STA# 1 DCK SHEAR VLV @ 5266' WLM - CIRC
DIESEL DOWN IA. SET 1" DGLV (INT) IN STA# 1.
01/22/03
MIT-IA TO 3000# - PASSED. PULL C-SUB - DRIFT 2.5" SPENT PERF GUN TO 7481' CORR. NOTIFY PAD
OPERATOR OF WELL STATUS. WELL TO REMAIN SHUT IN.
SLIM CEMENT MAPPING TOOL AND INITIAL 2-1/2" POWERFLOW PERFORATIONS. LOG REFERENCE TO
SLB BHCS LOG DATED 27-DEC-2002. TAG BOTTOM AT 7452'. LOG SCMT WITH 1800 WHP. SHOOT ZONE
FROM 7380'-7400' WITH 2-1/2" POWERFLOW HSD GUN. (6SPF - 60 DEG RANDOM - PEN 4.8" - EHD .66" -
WHP 450 PSI WHE SHOT). PAD OPERATOR NOTIFIED WELL LEFT SHUT IN. MIT IA WITH SLICK LINE.
01/24/03
FRAC'D THE A SD PERFS 7380'-7400' WITH YF125LG SYSTEM AND 114 K# OF 16/20 CL. PRESSURED OUT
130 BBLS INTO THE 7 PPGA STG TO 8310 PSI. PLACED 98 K# CL IN THE FORMATION AND LEFT 15 K# (24
BBLS) IN THE CSGITBG. SAND SLURRY LEFT IN TBG TO SURFACE. MAX TREAT - 8310 PSI, AVG TREAT-
7000 PSI, LOAD TO RECOVER IS 1281 BBLS. THE TBG IS NOT FREEZE PROTECTED, HEATERS LEFT ON
THE TREE AND TUBULAR HEAD. EQUIPMENT RIGGED BACK FOR CTU ACCESS. ALL TREESAVER CUPS
RECOVERED.
01/25/03
RIH & CLEAN OUT TO 7350' CTM. REVERSE OUT TO 7360' CTM. POOH. FREEZE PROTECT TBG TO 2700'
CTM. RIH WI GR - CCL . TAGGED HIGH @ 6730'. POOH. REMOVE LOGGING TOOLS. RIH W/2" NOZZLE TO
REV OUT. TAG FILL @ 6460'. JET DOWN TO 6721'. PUMP 5 BBL FLOPRO SWEEP. REVERSE OUT.
01/26/03
REVERSE DOWN TO 7360'. RETAG, SAME. FP WELLBORE TO 2000'. FP COIL AND PUMP 1.25" BALL
THROUGH CT. RIH WI GR-CCL MAINTAINING 1000 PSI WHP. MAKE TIE-IN PASS FROM TD TO 6800'. FLAG
COIL @ 7200'. RIH WI 2.5" BALL DROP NOZZLE. DEPTH CORRECT @ FLAG. TAG TD @ 7357' (UP). LAY IN
600# CAC03 FROM BTM. 1 HR TAG IS 7337'. 2 HR TAG IS 7332'.
01/27/03
3 HR TAG IS 7325' (UP). 4+ HR TAG IS 7322' (UP). WASH DOWN FROM 6200' TO 7275'. TAG IS 7317' (UP).
WAIT 2 HRS, GOT TAG OF 7309' (UP) 151" OF CAC03 FILL. CIRC WELL TO CLEAN WATER. FREEZE
PROTECT TBG TO 3000'. POOH. RIH WI 30' X 2.5" POWERFLOW GUNS. (2506PJ - HMX 10.5 GM, 6 SPF, 60
DEGREE PHASING, RANDOM ORIENTATION) PERFORATE FROM 7250' - 7280' MD. POOH. ALL SHOTS
FIRED. TRAP - 1150 PSI ON TBG. TBG FREEZE PROTECTED TO 3000'. RDMO. WELL TO REMAIN SHUT IN.
01/30/03
PUMP 175 BBL YF125LG DATA FRAC @ 25 BPM (PAD TO PERFS @ 10 BPM). FLUSH WI 63 BBL WF130. SID
ISIP=1855 PSI. ESTIMATE FLUID EFF @ 49%, CLOSURE TIME 12.7 MIN. START DH W/125 BBLS YF125LG
PAD. STEP 16/20 CARBOLlTE FROM 1 TO 12 PPA. PUMPING @ 25 BPM. AVERAGE PRESSURE 4950 PSI.
PRV WENT OFF @ 7835 PSI (8 BBLS INTO FLUSH) WITH 197,776# BEHIND PIPE (12 PPA ON FORMATION)
AND 19707# IN PIPE. PUMP A TOTAL OF 217,483#. WELL HEAD CIRCULATED WI DIESEL. BOTTOM CUP OF
TREE SAVER LEFT IN WELL.
8-115, Post Rig Work
Page 2
)
)
01/31/03
RETRIEVED APPROX. 50% OF TREE SAVER ELEMENT FROM 350' SLM - UNABLE TO GET DEEPER.
CLEAN OUT FRAC PROP TO 7170' CTD, GETTING 1:1 RETURNS AT 2.7 BPM, TAKING 1000 FT BITES.
APPEARED TO HAVE HIT PROPPANT AT - 400'.
02101/03
CONTINUE CLEANING OUT FRAC PROPPANT FROM 7170' TO FINAL DEPTH OF 7450' CTMD. MADE 2,10
BBLS HEC SWEEPS FROM 7450'. SAW ABOUT 4% LOSSES AFTER CLEANING THRU PERFS THEN
STARTED GETTING SOME GAS AND CRUDE RETURNS AFTER PERFS WERE OPENED UP. RETURNS
WENT TO 130%. POOH, AND FREEZE PROTECT WELL TO 3000' WITH 60/40 METH. LEFT WELL SHUT IN.
NOTIFY PAD OPERATOR OF WELL STATUS. FINAL T/I/O = 80/1700/300 PSI. JOB COMPLETE.
ATTEMPTED TO DRIFT A 2.685" CENT. SET DOWN ON ICE @ 652' SLM. ATTEMPTING TO PUMP UP WI
METH TO THAW ICE. JOB IN PROGRESS.
02102103
UNABLE TO PERFORM GLW DUE TO HYDRATES IN TBG. MAKE HOLE TO 1822' SLM. RETRIEVE BAILER
PACKED FULL OF HARD HYDRATES. WELL LEFT SI.
02103/03
JET ICE PLUG. RIH WITH 2" DJN TO 5300'. NO SIGN OF ANY ICE PLUGS. PUH TO 3000' (MADE WASH
PASSES AT GLV'S). UNABLE TO INJECT INTO WELL. RBIH TO 7280' AND DRY TAG. POOH, START LAYING
IN 30 BBLS NEAT METH AT 3000' TAKING 1:1 RETURNS THRU CHOKE. AT SURFACE, CLOSED CHOKE AND
WAS ABLE TO INJECT LAST 3 BBLS AT 1.3 BPM/850 PSI WHP. WELL FREEZE PROTECTED TO 3000'.
WELL LEFT SHUT IN. RDMO NOTIFIED PAD OPERATOR OF WELL STATUS. JOB COMPLETE.
PULL DGLV'S FROM STA 1 & 3. SET BL-LGLV (1/4" PORT, 1931 TRO) IN STA-3. SET BL-OGLV (5/16" PORT)
IN STA-1. WELL RELEASED AND LEFT SI FOR S-PAD SHUT DOWN.
ANADRILL
SCHLUMBERGER
Survey report
Client...................: BP Exploration (Alaska) Inc.
Field. . . . . . . . . . . . . . . . . . . .: Aurora
Well. . . . . . . . . . . . . . . . . . . . .: S-115
API number...............: 50-029-23130-00
Engineer. ... .... ., ...... .: E. Roux
COUNTY: . . . . . . . . . . . . . . . . . .: Nabors 9ES
STATE: .,. .. . . . . . ... .... ..: Alaska
----- Survey calculation methods-------------
Method for positions. _...: Minimum curvature
Method for DLS. . . . . ... . ..: Mason & Taylor
----- Depth reference -----------------------
Permanent datum..........: Mean Sea Level
Depth reference.. . .. . .. ..: Drill Floor
GL above permanent.......: 35.60 ft
KB above permanent.......: Top Drive
DF above permanent.......: 64.10 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: 277.02 degrees
[(c)2002 Anadrill IDEAL ID6_1C_10]
26-Dec-2002 13:27:50
Spud date................:
Last survey date. . . . . . . . . :
Total accepted surveys...:
MD of first survey.......:
MD of last survey........:
Page
1 of 4
20-Dec-02
26-Dec-02
82
0.00 ft
7600.00 ft
-~
----- Geomagnetic data ----------------------
Magnetic model...........: BGGM version 2001
Magnetic date............: 20-Dec-2002
Magnetic field strength..: 1150.00 HCNT
Magnetic dec (+E/W-).. ...: 25.98 degrees
Magnetic dip.............: 80.81 degrees
----- MWD survey Reference
Reference G. . . . . . . . . . . . . . :
Reference H.......... ....:
Reference Dip............:
Tolerance of G...........:
Tolerance of H...........:
Tolerance of Dip.........:
Criteria ---------
1002.68 mGal
1150.00 HCNT
80.81 degrees
(+/-) 2.50 mGal
(+/-) 6.00 HCNT
(+/-) 0.45 degrees
----- Corrections ---------------------------
~./
Magnetic dec (+E/W-).....:
Grid convergence (+E/W-).:
Total az carr (+E/W-)....:
(Total az corr = magnetic dec
Sag applied (Y/N)........: No
25.85 degrees
0.00 degrees
25.85 degrees
- grid conv)
degree: 0.00
<"",
ANADRILL SCHLUMBERGER Survey Report
--------
--------
Seq Measured
# depth
(ft)
------ -------
------ -------
Incl
angle
(deg)
Azimuth
angle
(deg)
26-Dec-2002 13:27:50
------ -------- -------- ----------------
------ -------- -------- ----------------
Course
length
(ft)
TVD
depth
(ft)
Vertical
section
(ft)
Displ
+N/S-
(ft)
Displ
+E/W-
(ft)
Page
---------------
---------------
Total
displ
(ft)
At
Azim
(deg)
-------- ------ ------- ------ -------- -------- ---------------- ---------------
-------- ------ ------- ------ -------- -------- ---------------- ---------------
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
1
2
3
4
5
0.00
78.00
172.00
267.00
360.00
452.00
544.00
636.00
728.00
822.00
916.00
1040.93
1136.44
1231.28
1327.07
1420.55
1516.20
1611.56
1709.24
1804.27
1896.60
1992.83
2088.80
2184.49
2280.10
2375.12
2470.99
2565.97
2661.71
2756.90
0.00
0.22
0.81
1.99
2.15
1.71
1.49
1.95
3.88
6.08
8.28
11.85
13.32
14.35
16.82
20.04
25.18
26.11
30.23
33.99
33.66
33.07
32.86
34.53
35.06
35.10
34.60
34.73
34.12
33.91
0.00
125.57
123.58
109.03
130.21
159.89
196.53
240.59
270.82
277.55
283.95
288.79
298.52
294.61
290.70
288.02
287.03
284.41
281.75
278.68
278.12
278.36
275.32
273.52
274.17
273.89
273.67
273.73
273.56
273.46
0.00
78.00
94.00
95.00
93.00
92.00
92.00
92.00
92.00
94.00
94.00
124.93
95.51
94.84
95.79
93.48
95.65
95.36
97.68
95.03
92.33
96.23
95.97
95.69
95.61
95.02
95.87
94.98
95.74
95.19
0.00
78.00
172.00
266.97
359.91
451.86
543.82
635.78
727.67
821.31
914.56
1037.55
1130.78
1222.87
1315.13
1403.81
1492.08
1578.04
1664.14
1744.62
1821.32
1901.69
1982.22
2061.83
2140.35
2218.11
2296.78
2374.90
2453.88
2532.78
0.00
-0.13
-0.88
-3.10
-6.14
-8.21
-8.64
-7.18
-2.82
5.32
17.01
38.51
58.35
79.72
104.50
133.38
169.53
210.32
256.16
306.57
357.95
410.87
463.07
516.09
570.57
625.10
679.80
733.73
787.76
840.91
0.00
-0.09
-0.56
-1.47
-3.12
-5.52
-7.96
-9.88
-10.60
-9.90
-7.61
-1.31
7.10
17.21
27.06
36.79
47.83
59.00
69.36
78.24
85.75
93.33
99.56
103.63
107.29
111.13
114.74
118.22
121.67
124.93
0.00
0.12
0.82
2.94
5.80
7.59
7.72
6.02
1.54
-6.58
-18.08
-38.96
-57.92
-78.20
-101.96
-129.85
-164.92
-204.64
-249.55
-299.25
-350.10
-402.48
-454.31
-507.23
-561.67
-616.14
-670.80
-724.71
-778.73
-831.88
0.00
0.15
0.99
3.29
6.59
9.39
11.09
11.56
10.71
11.88
19.62
38.98
58.35
80.07
105.49
134.97
171.71
212.97
259.01
309.31
360.45
413.16
465.09
517.71
571.82
626.08
680.55
734.29
788.18
841.21
0.00
125.57
124.24
116.54
118.29
126.05
135.87
148.65
171.73
213.59
247.16
268.07
276.99
282.41
284.86
285.82
286.17
286.08
285.53
284.65
283.76
283.06
282.36
281.55
280.81
280.22
279.71
279.27
278.88
278.54
2 of 4
DLS
(deg/
100f)
0.00
0.28
0.63
1.29
0.84
1.17
1.12
1.48
2.61
2.42
2.49
2.93
2.70
1.47
2.80
3.56
5.39
1.54
4.41
4.31
0.49
0.63
1.74
2.03
0.68
0.17
0.54
0.14
0.65
0.23
------
------
Srvy
tool
type
Tool
qual
type
------
------
TIP
GYR
GYR
GYR
GYR
GYR
GYR
GYR
GYR
GYR
"'-~'
GYR
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
--,
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
ANADRILL SCHLUMBERGER Survey Report
--------
--------
Seq Measured
# depth
(ft)
------
------
Incl
angle
(deg)
------- ------
------- ------
Azimuth
angle
(deg)
Course
length
(ft)
26-Dec-2002 13:27:50
Page
-------- -------- ---------------- ---------------
-------- -------- ---------------- ---------------
TVD
depth
(ft)
Vertical
section
(ft)
Displ
+N/S-
(ft)
Displ
+E/W-
(ft)
Total
displ
(ft)
At
Azim
(deg)
-------- ------ ------- ------ -------- -------- ---------------- ---------------
-------- ------ ------- ------ -------- -------- ---------------- ---------------
31
32
33
34
35
2852.90
2947.99
3043.78
3139.57
3200.64
36
37
38
39
40
3260.81
3355.20
3450.35
3545.98
3641.66
41
42
43
44
45
3737.51
3833.49
3929.24
4024.58
4120.28
46
47
48
49
50
4216.21
4311.89
4407.23
4502.41
4597.75
51
52
53
54
55
4693.97
4790.83
4886.68
4982.17
5077.84
56
57
58
59
60
5172.98
5268.34
5364.26
5459.90
5554.21
36.17
35.54
34.90
34.11
34.09
32.61
33.27
34.56
35.82
34.93
34.57
35.77
34.44
32.68
33.44
31.70
30.13
29.80
28.66
27.41
26.94
26.03
24.97
23.85
22.54
21.61
20.23
18.91
17.69
16.24
272.98
273.94
273.66
273.53
273.86
272.58
270.73
270.11
270.14
271.26
273.94
273.53
273.55
275.68
275.51
275.12
272.77
274.25
277.29
279.05
282.17
281.27
281.58
284.20
285.71
283.99
283.81
282.46
282.15
282.63
96.00
95.09
95.79
95.79
61.07
60.17
94.39
95.15
95.63
95.68
95.85
95.98
95.75
95.34
95.70
95.93
95.68
95.34
95.18
95.34
96.22
96.86
95.85
95.49
95.67
95.14
95.36
95.92
95.64
94.31
2611.37
2688.44
2766.70
2845.64
2896.21
2946.47
3025.68
3104.64
3182.80
3260.82
3339.58
3418.04
3496.37
3575.82
3656.02
3736.86
3818.95
3901.55
3984.61
4068.76
4154.37
4241.06
4327.57
4414.53
4502.46
4590.63
4679.71
4770.08
4860.89
4951.09
895.90
951.49
1006.65
1060.81
1094.99
1128.00
1179.09
1231.83
1286.54
1341.58
1396.04
1451.23
1506.19
1558.84
1611.03
1662.64
1711.72
1759.25
1805.70
1850.50
1894.34
1937.39
1978.53
2017.78
2055.10
2090.51
2124.30
2156.25
2186.14
2213.53
128.02
131.37
135.04
138.44
140.65
-886.91
-942.50
-997.62
-1051.78
-1085.95
142.51 -1118.97
143.99 -1170.27
144.37 -1223.35
144.49 -1278.46
145.16 -1333.84
147.63 -1388.40
151.23 -1443.57
154.63 -1498.53
158.85 -1551.05
163.94 -1603.01
168.72 -1654.43
172.13 -1703.46
175.04 -1750.98
179.69 -1797.21
186.04 -1841.57
194.12 -1884.75
202.90 -1927.04
211.07 -1967.49
219.86 -2005.95
229.57 -2042.35
238.74 -2076.90
246.92 -2109.94
254.23 -2141.23
260.63 -2170.56
266.53 -2197.43
896.10
951.61
1006.72
1060.85
1095.02
1128.01
1179.09
1231.84
1286.60
1341.72
1396.23
1451.47
1506.48
1559.16
1611.37
1663.01
1712.13
1759.71
1806.17
1850.94
1894.72
1937.69
1978.78
2017.96
2055.21
2090.58
2124.34
2156.27
2186.15
2213.53
278.21
277.94
277.71
277.50
277.38
277.26
277.01
276.73
276.45
276.21
276.07
275.98
275.89
275.85
275.84
275.82
275.77
275.71
275.71
275.77
275.88
276.01
276.12
276.25
276.41
276.56
276.67
276.77
276.85
276.92
3 of 4
DLS
(degf
100f)
2.37
0.89
0.69
0.83
0.30
2.72
1.27
1.40
1.32
1.16
1.63
1.27
1.39
2.22
0.80
1.83
2.07
0.85
1.97
1.57
1.56
1.03
1.11
1.63
1.50
1.20
1.44
1.45
1.29
1.53
-----
------
------
Srvy
tool
type
Tool
qual
type
------
------
MWD IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
-
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
--
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
MWD_IFR_MSA
}-\P
Le... .J 5-115
SchlumbergBr
Survey Report - Geodetic
Report Date: 26-Dec-03 Survey I DLS Computation Method: Minimum Curvature I Lubinski
Client: BP Exploration Alaska Vertical Section Azimuth: 277.840°
Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 fI
Structure I Slot: Sop AD / 5-115 TVD Reference Datum: KB
Well: 5-115 TVD Reference Elevation: 64.100 ft relative to MSL
Borehole: 5-115
UWVAPI#: 500292313000 Magnetic Declination: +25.850°
Survey Name I Date: 5-115 / December 26, 2002 Total Field Strength: 57522.954 nT
Tort I AHD / DDI / ERD ratio: 108.566° / 2530.69 ft / 5.476 / 0.363 Magnetic Dip: 80.819°
Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: December 24, 2002 '-
Location LatlLong: N 70.35567722, W 149.0341496E Magnetic Declination Model: BGGM 2002
Location Grid N/E Y/X: N 5980609.740 ftUS, E 618929.710 ftUS North Reference: True North
Grid Convergence Angle: +0.90964535° Total Corr Mag North -> True North: +25.850°
Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head
Grid Coordinates Geographic Coordinates
Station ID MD Incl Azim TVD VSec N/-5 EI-W DLS Northing Easting Latitude Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 o Oft) (ftUS) (ftUS)
0.00 0.00 0.00 0.00 0.00 0.00 0.00 5980609.74 618929.71 N 70.35567722 W 149.03414968
78.00 0.22 125.57 78.00 -0.13 -0.09 0.12 0.28 5980609.65 618929.83 N 70.35567699 W 149.03414869
172.00 0.81 123.58 172.00 -0.89 -0.56 0.82 0.63 5980609.19 618930.54 N 70.35567570 W 149.03414300
267.00 1.99 109.03 266.97 -3.11 -1.47 2.94 1.29 5980608.32 618932.67 N 70.35567321 W 149.03412580
360.00 2.15 130.21 359.91 -6.17 -3.12 5.80 0.84 5980606.71 618935.56 N 70.35566870 W 149.03410258
452.00 1.71 159.89 451.86 -8.27 -5.52 7.59 1.17 5980604.34 618937.39 N 70.35566213 W 149.03408805
544.00 1.49 196.53 543.82 -8.73 -7.96 7.72 1.12 5980601.90 618937.56 N 70.35565548 W 149.03408698
636.00 1.95 240.59 635.78 -7.31 -9.88 6.02 1.48 5980599.96 618935.88 N 70.35565024 W 149.03410082
728.00 3.88 270.82 727.67 -2.97 -10.60 1.54 2.61 5980599.17 618931.42 N 70.35564827 W 149.03413717
-'
822.00 6.08 277.55 821.31 5.16 -9.90 -6.58 2.42 5980599.74 618923.29 N 70.35565018 W 149.03420307
916.00 8.28 283.95 914.57 16.87 -7.61 -18.08 2.49 5980601.84 618911.75 N 70.35565642 W 149.03429649
1040.93 11.85 288.79 1037.55 38.42 -1.31 -38.96 2.93 5980607.81 618890.78 N 70.35567364 W 149.03446605
1136.44 13.32 298.52 1130.78 58.34 7.10 -57.92 2.70 5980615.92 618871.69 N 70.35569662 W 149.03461996
1231.28 14.35 294.61 1222.87 79.82 17.21 -78.20 1.47 5980625.71 618851.25 N 70.35572425 W 149.03478468
1327.07 16.82 290.70 1315.13 104.70 27.06 -101.96 2.80 5980635.17 618827.34 N 70.35575114 W 149.03497762
1420.55 20.04 288.02 1403.81 133.66 36.79 -129.85 3.56 5980644.47 618799.30 N 70.35577774 W 149.03520410
1516.20 25.18 287.03 1492.08 169.90 47.83 -164.92 5.39 5980654.94 618764.07 N 70.35580789 W 149.03548882
1611.56 26.11 284.41 1578.04 210.77 59.00 -204.64 1.54 5980665.47 618724.18 N 70.35583839 W 149.03581138
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Grid Coordinates Geographic Coordinates
Station /D MD Incl Azim TVD VSec N/·S EI-W DLS Northing Easting Latitude Longitude
(ft) n n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS)
1709.24 30.23 281.75 1664.14 256.68 69.36 -249.55 4.41 5980675.12 618679.11 N 70.35586669 W 149.03617608
1804.27 33.99 278.68 1744.62 307.13 78.24 -299.25 4.31 5980683.21 618629.28 N 70.35589095 W 149.03657967
1896.60 33.66 278.12 1821.33 358.52 85.75 -350.10 0.49 5980689.91 618578.32 N 70.35591146 W 149.03699253
1992.83 33.07 278.36 1901.69 411 .44 93.33 -402.48 0.63 5980696.67 618525.84 N 70.35593217 W 149.03741784
2088.80 32.86 275.32 1982.22 463.64 99.56 -454.31 1.74 5980702.06 618473.92 N 70.35594916 W 149.03783874
2184.49 34.53 273.52 2061.83 516.63 103.63 -507.23 2.03 5980705.29 618420.94 N 70.35596028 W 149.03826848
2280.10 35.06 274.17 2140.35 571.05 1 07.29 -561.67 0.68 5980708.09 618366.46 N 70.35597027 W 149.03871051
2375.12 35.10 273.89 2218.11 625.54 111.13 -616.14 0.17 5980711.06 618311.94 N 70.35598074 W 149.03915286
2470.99 34.60 273.67 2296.78 680.19 114.74 -670.80 0.54 5980713.81 618257.23 N 70.35599060 W 149.03959674
2565.97 34.73 273.73 2374.90 734.07 118.22 -724.71 0.14 5980716.44 618203.27 N 70.35600011 W 149.04003450 .--
2661.71 34.12 273.56 2453.88 788.05 121.67 -778.73 0.65 5980719.02 618149.21 N 70.35600949 W 149.04047311
2756.90 33.91 273.46 2532.78 841 .14 124.93 -831.88 0.23 5980721.43 618096.02 N 70.35601839 W 149.04090470
2852.90 36.17 272.98 2611.37 896.08 128.02 -886.91 2.37 5980723.65 618040.96 N 70.35602681 W 149.04135154
2947.99 35.54 273.94 2688.44 951.61 131.37 -942.50 0.89 5980726.12 617985.32 N 70.35603596 W 149.04180298
3043.78 34.90 273.66 2766.70 1006.72 135.04 -997.62 0.69 5980728.91 617930.15 N 70.35604595 W 149.04225059
3139.57 34.11 273.53 2845.64 1060.83 138.44 -1051.78 0.83 5980731.45 617875.96 N 70.35605522 W 149.04269035
3200.64 34.09 273.86 2896.21 1094.98 140.65 -1085.95 0.30 5980733.12 617841.76 N 70.35606124 W 149.04296779
3260.81 32.61 272.58 2946.47 1127.95 142.51 -1118.97 2.72 5980734.46 617808.72 N 70.35606632 W 149.04323595
3355.20 33.27 270.73 3025.68 1178.97 143.99 -1170.27 1.27 5980735.12 617757.40 N 70.35607033 W 149.04365251
3450.35 34.56 270.11 3104.64 1231.61 144.37 -1223.36 1.40 5980734.66 617704.32 N 70.35607136 W 149.04408359
3545.98 35.82 270.14 3182.80 1286.22 144.49 -1278.46 1.32 5980733.90 617649.22 N 70.35607166 W 149.04453109
3641.66 34.93 271 .26 3260.81 1 341 . 18 145.16 -1333.85 1.15 5980733.70 617593.84 N 70.35607347 W 149.04498083
3737.51 34.57 273.94 3339.57 1395.58 147.63 -1388.42 1.64 5980735.30 617539.25 N 70.35608019 W 149.04542392
3833.49 35.77 273.53 3418.03 1450.72 151.23 -1443.58 1.27 5980738.02 617484.03 N 70.35608999 W 149.04587189
3929.24 34.44 273.55 3496.36 1505.63 154.63 -1498.54 1.39 5980740.55 617429.03 N 70.35609925 W 149.04631816
4024.58 32.68 275.68 3575.81 1558.24 158.85 -1551.07 2.22 5980743.93 617376.45 N 70.35611074 W 149.04674470 -~...,/
4120.28 33.44 275.51 3656.01 1610.40 163.94 -1603.02 0.80 5980748.20 617324.42 N 70.35612462 W 149.04716661
4216.21 31.70 275.12 3736.85 1661.99 168.72 -1654.44 1.83 5980752.17 617272.94 N 70.35613767 W 149.04758414
4311.89 30.13 272.77 3818.94 1711.03 172.13 -1703.47 2.07 5980754.79 617223.87 N 70.35614694 W 149.04798227
4407.23 29.80 274.25 3901.54 1758.51 175.04 -1751.00 0.85 5980756.95 617176.31 N 70.35615486 W 149.04836821
4502.41 28.66 277.29 3984.60 1804.94 179.69 -1797.23 1.97 5980760.86 617130.01 N 70.35616753 W 149.04874362
4597.75 27.41 279.05 4068.75 1849.74 186.04 -1841.58 1.57 5980766.51 617085.57 N 70.35618486 W 149.04910379
4693.97 26.94 282.17 4154.36 1893.62 194.12 -1884.76 1.56 5980773.90 617042.27 N 70.35620690 W 149.04945445
4790.83 26.03 281.27 4241.05 1936.72 202.90 -1927.05 1.03 5980782.01 616999.84 N 70.35623086 W 149.04979789
4886.68 24.97 281.58 4327.56 1977.90 211.07 -1967.50 1.11 5980789.54 616959.28 N 70.35625315 W 149.05012635
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Grid Coordinates Geographic Coordinates
Station 10 MO Incl Azim TVD VSec Nt-S EI-W DL5 Northing Easting Latitude Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS)
4982.17 23.85 284.20 4414.52 2017.20 219.86 -2005.96 1.63 5980797.71 616920.68 N 70.35627712 W 149.05043870
5077.84 22.54 285.71 4502.45 2054.59 229.57 -2042.37 1.50 5980806.84 616884.13 N 70.35630362 W 149.05073433
5172.98 21.61 283.99 4590.62 2090.07 238.74 -2076.92 1.19 5980815.46 616849.44 N 70.35632865 W 149.05101495
5268.34 20.23 283.81 4679.69 2123.93 246.92 -2109.97 1.45 5980823.11 616816.26 N 70.35635098 W 149.05128335
5364.26 18.91 282.46 4770.07 2155.92 254.23 -2141.26 1.45 5980829.93 616784.87 N 70.35637093 W 149.05153740
5459.90 17.69 282.15 4860.87 2185.86 260.64 -2170.59 1.28 5980835.86 616755.44 N 70.35638840 W 149.05177566
5554.21 16.24 282.63 4951.07 2213.29 266.54 -2197.47 1.54 5980841.34 616728.47 N 70.35640449 W 149.05199393
5649.69 14.97 281 .50 5043.03 2238.90 271.91 -2222.59 1.37 5980846.31 616703.28 N 70.35641917 W 149.05219787
5744.88 13.85 279.08 5135.23 2262.56 276.16 -2245.89 1.34 5980850.19 616679.92 N 70.35643075 W 149.05238708
5840.46 14.11 278.74 5227.98 2285.65 279.74 -2268.70 0.29 5980853.41 616657.05 N 70.35644050 W 149.05257233 '-
5935.86 13.09 279.92 5320.70 2308.07 283.37 -2290.83 1.11 5980856.68 616634.86 N 70.35645040 W 149.05275209
6030.21 13.00 279.94 5412.61 2329.36 287.04 -2311.81 0.10 5980860.02 616613.83 N 70.35646041 W 149.05292244
6126.26 11.91 280.98 5506.40 2350.05 290.79 -2332.18 1.16 5980863.45 616593.41 N 70.35647065 W 149.05308787
6221.87 11.92 279.76 5599.95 2369.77 294.34 -2351.60 0.26 5980866.69 616573.94 N 70.35648034 W 149.05324555
6316.34 10.65 278.09 5692.59 2388.25 297.23 -2369.86 1.39 5980869.28 616555.64 N 70.35648820 W 149.05339382
6412.82 9.56 279.97 5787.58 2405.17 299.87 -2386.57 1.18 5980871.66 616538.88 N 70.35649540 W 149.05352958
6508.53 8.36 282.58 5882.12 2420.05 302.76 -2401.19 1.32 5980874.32 616524.22 N 70.35650329 W 149.05364830
6604.49 6.83 285.53 5977.23 2432.65 305.81 -2413.50 1.64 5980877.17 616511.87 N 70.35651160 W 149.05374825
6701.67 5.04 286.99 6073.89 2442.60 308.60 -2423.15 1.85 5980879.81 616502.17 N 70.35651923 W 149.05382662
6796.58 4.91 284.73 6168.44 2450.74 310.85 -2431.07 0.25 5980881.94 616494.22 N 70.35652537 W 149.05389090
6891.97 5.02 282.38 6263.47 2458.96 312.79 -2439.09 0.24 5980883.74 616486.17 N 70.35653064 W 149.05395607
6987.80 5.07 288.00 6358.93 2467.31 314.99 -2447.21 0.52 5980885.82 616478.02 N 70.35653667 W 149.05402203
7083.22 3.76 303.81 6454.07 2474.27 318.04 -2453.82 1.86 5980888.76 616471.36 N 70.35654498 W 149.05407572
7178.70 2.38 4.96 6549.43 2477.18 321.76 -2456.25 3.50 5980892.44 616468.87 N 70.35655513 W 149.05409546
7274.18 2.66 28.15 6644.82 2476.51 325.68 -2455.04 1.10 5980896.38 616470.02 N 70.35656586 W 149.05408559
7369.13 2.52 30.91 6739.68 2474.93 329.42 -2452.92 0.20 5980900.15 616472.08 N 70.35657607 W 149.05406846 ~
7465.69 2.35 29.39 6836.15 2473.37 332.96 -2450.86 0.19 5980903.73 616474.08 N 70.35658576 W 149.05405172
7544.54 2.14 35.75 6914.94 2472.09 335.57 -2449.21 0.41 5980906.36 616475.69 N 70.35659287 W 149.05403830
7600.00 2.14 35.75 6970.36 2471.12 337.25 -2448.00 0.00 5980908.06 616476.88 N 70.35659746 W 149.05402848
S-115 ASP Final Surveys. xis
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()
1?
~
^
,-
S-115 Schlumberger
Survey Report - Geodetic
Report Date: 26-Dec-03 Survey I DLS Computation Method: Minimum Curvature / Lubinski
Client: BP Exploration Alaska Vertical Section Azimuth: 277.840°
Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft
Structure I Slot: Sop AD I S-115 TVD Reference Datum: KB
Well: S-115 TVD Reference Elevation: 64.100 ft relative to MSL
Borehole: S-115
UWVAPI#: 500292313000 Magnetic Declination: +25.850°
Survey Name I Date: S-115 / December 26, 2002 Total Field Strength: 57522.954 nT
Tort I AHD I DDII ERD ratio: 108.566° 12530.69 ft 15.4761 0.363 Magnetic Dip: 80.819°
Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: December 24, 2002
Location LatlLong: N 70.35567722, W 149.0341496E Magnetic Declination Model: BGGM 2002
Location Grid NIE Y/x: N 5980609.740 ftUS, E 618929.710 ftUS North Reference: True North
Grid Convergence Angle: +0.90964535° Total Corr Mag North -> True North: +25.850°
Grid Scale Factor: 0.99991607 Local Coordinates Referenced To: Well Head
Grid Coordinates Geographic Coordinates
Station ID MD Incl Azim TVD VSec N/-S EJ-W DLS Northing Easting Latitude I Longitude
(ft) (0) n (ft) (ft) (ft) (ft) (0/1 OOft) (ftUS) (ftUS)
0.00 0.00 0.00 0.00 0.00 0.00 0.00 5980609.74 618929.71 N 70.35567722 W 149.03414968
78.00 0.22 125.57 78.00 -0.13 -0.09 0.12 0.28 5980609.65 618929.83 N 70.35567699 W 149.03414869
172.00 0.81 123.58 172.00 -0.89 -0.56 0.82 0.63 5980609.19 618930.54 N 70.35567570 W 149.03414300
267.00 1.99 109.03 266.97 -3.11 -1.47 2.94 1.29 5980608.32 618932.67 N 70.35567321 W 149.03412580
360.00 2.15 130.21 359.91 -6.17 -3.12 5.80 0.84 5980606.71 618935.56 N 70.35566870 W 149.03410258
452.00 1.71 159.89 451.86 -8.27 -5.52 7.59 1.17 5980604.34 618937.39 N 70.35566213 W 149.03408805
544.00 1.49 196.53 543.82 -8.73 -7.96 7.72 1.12 5980601.90 618937.56 N 70.35565548 W 149.03408698
636.00 1.95 240.59 635.78 -7.31 -9.88 6.02 1.48 5980599.96 618935.88 N 70.35565024 W 149.03410082
728.00 3.88 270.82 727.67 -2.97 -10.60 1.54 2.61 5980599.17 618931.42 N 70.35564827 W 149.03413717
822.00 6.08 277.55 821.31 5.16 -9.90 -6.58 2.42 5980599.74 618923.29 N 70.35565018 W 149.03420307
916.00 8.28 283.95 914.57 16.87 -7.61 -18.08 2.49 5980601.84 618911.75 N 70.35565642 W 149.03429649
1040.93 11.85 288.79 1037.55 38.42 -1.31 -38.96 2.93 5980607.81 618890.78 N 70.35567364 W 149.03446605
1136.44 13.32 298.52 1130.78 58.34 7.10 -57.92 2.70 5980615.92 618871.69 N 70.35569662 W 149.03461996
1231.28 14.35 294.61 1222.87 79.82 17.21 -78.20 1.47 5980625.71 618851.25 N 70.35572425 W 149.03478468
1327.07 16.82 290.70 1315.13 104.70 27.06 -101.96 2.80 5980635.17 618827.34 N 70.35575114 W 149.03497762
1420.55 20.04 288.02 1403.81 133.66 36.79 -129.85 3.56 5980644.47 618799.30 N 70.35577774 W 149.03520410
1516.20 25.18 287.03 1492.08 169.90 47.83 -164.92 5.39 5980654.94 618764.07 N 70.35580789 W 149.03548882
1611.56 26.11 284.41 1578.04 210.77 59.00 -204.64 1.54 5980665.47 618724.18 N 70.35583839 W 149.03581138
,,-.
S-115 ASP Final Surveys.xls
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Page 2 of 3
S-115 ASP Final Surveys.xls
Grid Coordinates Geographic Coordinates
Station ID MD Incl Azim TVD VSec N/-S E/-W DLS Northing Easting Latitude Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (°/1 DDft) (ftUS) (ftUS)
1709.24 30.23 281.75 1664.14 256.68 69.36 -249.55 4.41 5980675.12 618679.11 N 70.35586669 W 149.03617608
1804.27 33.99 278.68 1744.62 307.13 78.24 -299.25 4.31 5980683.21 618629.28 N 70.35589095 W 149.03657967
1896.60 33.66 278.12 1821.33 358.52 85.75 -350.10 0.49 5980689.91 618578.32 N 70.35591146 W 149.03699253
1992.83 33.07 278.36 1901.69 411 .44 93.33 -402.48 0.63 5980696.67 618525.84 N 70.35593217 W 149.03741784
2088.80 32.86 275.32 1982.22 463.64 99.56 -454.31 1.74 5980702.06 618473.92 N 70.35594916 W 149.03783874
2184.49 34.53 273.52 2061.83 516.63 103.63 -507.23 2.03 5980705.29 618420.94 N 70.35596028 W 149.03826848
2280.10 35.06 274.17 2140.35 571.05 1 07.29 -561.67 0.68 5980708.09 618366.46 N 70.35597027 W 149.03871051
2375.12 35.10 273.89 2218.11 625.54 111.13 -616.14 0.17 5980711.06 618311.94 N 70.35598074 W 149.03915286
/- 2470.99 34.60 273.67 2296.78 680.19 114.74 -670.80 0.54 5980713.81 618257.23 N 70.35599060 W 149.03959674
2565.97 34.73 273.73 2374.90 734.07 118.22 -724.71 0.14 5980716.44 618203.27 N 70.35600011 W 149.04003450
2661.71 34.12 273.56 2453.88 788.05 121.67 -778.73 0.65 5980719.02 618149.21 N 70.35600949 W 149.04047311
2756.90 33.91 273.46 2532.78 841 .14 124.93 -831.88 0.23 5980721 .43 618096.02 N 70.35601839 W 149.04090470
2852.90 36.17 272.98 2611.37 896.08 128.02 -886.91 2.37 5980723.65 618040.96 N 70.35602681 W 149.04135154
2947.99 35.54 273.94 2688.44 951.61 131.37 -942.50 0.89 5980726.12 617985.32 N 70.35603596 W 149.04180298
3043.78 34.90 273.66 2766.70 1006.72 135.04 -997.62 0.69 5980728.91 617930.15 N 70.35604595 W 149.04225059
3139.57 34.11 273.53 2845.64 1060.83 138.44 -1051.78 0.83 5980731.45 617875.96 N 70.35605522 W 149.04269035
3200.64 34.09 273.86 2896.21 1094.98 140.65 -1085.95 0.30 5980733.12 617841.76 N 70.35606124 W 149.04296779
3260.81 32.61 272.58 2946.47 1127.95 142.51 -1118.97 2.72 5980734.46 617808.72 N 70.35606632 W 149.04323595
3355.20 33.27 270.73 3025.68 1178.97 143.99 -1170.27 1.27 5980735.12 617757.40 N 70.35607033 W 149.04365251
3450.35 34.56 270.11 3104.64 1231.61 144.37 -1223.36 1.40 5980734.66 617704.32 N 70.35607136 W 149.04408359
3545.98 35.82 270.14 3182.80 1286.22 144.49 -1278.46 1.32 5980733.90 617649.22 N 70.35607166 W 149.04453109
3641.66 34.93 271.26 3260.81 1 341 . 1 8 145.16 -1333.85 1.15 5980733.70 617593.84 N 70.35607347 W 149.04498083
3737.51 34.57 273.94 3339.57 1395.58 147.63 -1388.42 1.64 5980735.30 617539.25 N 70.35608019 W 149.04542392
3833.49 35.77 273.53 3418.03 1450.72 151.23 -1443.58 1.27 5980738.02 617484.03 N 70.35608999 W 149.04587189
/- 3929.24 34.44 273.55 3496.36 1505.63 154.63 -1498.54 1.39 5980740.55 617429.03 N 70.35609925 W 149.04631816
4024.58 32.68 275.68 3575.81 1558.24 158.85 -1551.07 2.22 5980743.93 617376.45 N 70.35611074 W 149.04674470
4120.28 33.44 275.51 3656.01 1610.40 163.94 -1603.02 0.80 5980748.20 617324.42 N 70.35612462 W 149.04716661
4216.21 31.70 275.12 3736.85 1661.99 168.72 -1654.44 1.83 5980752.17 617272.94 N 70.35613767 W 149.04758414
4311.89 30.13 272.77 3818.94 1711.03 172.13 -1703.47 2.07 5980754.79 617223.87 N 70.35614694 W 149.04798227
4407.23 29.80 274.25 3901.54 1758.51 175.04 -1751.00 0.85 5980756.95 617176.31 N 70.35615486 W 149.04836821
4502.41 28.66 277.29 3984.60 1804.94 179.69 -1797.23 1.97 5980760.86 617130.01 N 70.35616753 W 149.04874362
4597.75 27.41 279.05 4068.75 1849.74 186.04 -1841.58 1.57 5980766.51 617085.57 N 70.35618486 W 149.04910379
4693.97 26.94 282.17 4154.36 1893.62 194.12 -1884.76 1.56 5980773.90 617042.27 N 70.35620690 W 149.04945445
4790.83 26.03 281.27 4241.05 1936.72 202.90 -1927.05 1.03 5980782.01 616999.84 N 70.35623086 W 149.04979789
4886.68 24.97 281.58 4327.56 1977.90 211.07 -1967.50 1.11 5980789.54 616959.28 N 70.35625315 W 149.05012635
1/16/2003-4:28 PM
Page 3 of 3
S-115 ASP Final Surveys.xls
Grid Coordinates Geographic Coordinates
Station ID MD Incl Azim TVD VSec NI-S EJ-W DLS Northing Easting Latitude I Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS)
4982.17 23.85 284.20 4414.52 2017.20 219.86 -2005.96 1.63 5980797.71 616920.68 N 70.35627712 W 149.05043870
5077.84 22.54 285.71 4502.45 2054.59 229.57 -2042.37 1.50 5980806.84 616884.13 N 70.35630362 W 149.05073433
5172.98 21.61 283.99 4590.62 2090.07 238.74 -2076.92 1.19 5980815.46 616849.44 N 70.35632865 W 149.05101495
5268.34 20.23 283.81 4679.69 2123.93 246.92 -2109.97 1.45 5980823.11 616816.26 N 70.35635098 W 149.05128335
5364.26 18.91 282.46 4770.07 2155.92 254.23 -2141.26 1.45 5980829.93 616784.87 N 70.35637093 W 149.05153740
5459.90 17.69 282.15 4860.87 2185.86 260.64 -2170.59 1.28 5980835.86 616755.44 N 70.35638840 W 149.05177566
5554.21 16.24 282.63 4951.07 2213.29 266.54 -2197.47 1.54 5980841.34 616728.47 N 70.35640449 W 149.05199393
5649.69 14.97 281.50 5043.03 2238.90 271.91 -2222.59 1.37 5980846.31 616703.28 N 70.35641917 W 149.05219787
/""""'" 5744.88 13.85 279.08 5135.23 2262.56 276.16 -2245.89 1.34 5980850.19 616679.92 N 70.35643075 W 149.05238708
5840.46 14.11 278.74 5227.98 2285.65 279.74 -2268.70 0.29 5980853.41 616657.05 N 70.35644050 W 149.05257233
5935.86 13.09 279.92 5320.70 2308.07 283.37 -2290.83 1.11 5980856.68 616634.86 N 70.35645040 W 149.05275209
6030.21 13.00 279.94 5412.61 2329.36 287.04 -2311.81 0.10 5980860.02 616613.83 N 70.35646041 W 149.05292244
6126.26 11.91 280.98 5506.40 2350.05 290.79 -2332.18 1.16 5980863.45 616593.41 N 70.35647065 W 149.05308787
6221.87 11.92 279.76 5599.95 2369.77 294.34 -2351.60 0.26 5980866.69 616573.94 N 70.35648034 W 149.05324555
6316.34 10.65 278.09 5692.59 2388.25 297.23 -2369.86 1.39 5980869.28 616555.64 N 70.35648820 W 149.05339382
6412.82 9.56 279.97 5787.58 2405.17 299.87 -2386.57 1.18 5980871.66 616538.88 N 70.35649540 W 149.05352958
6508.53_ 8.36 282.58 5882.12 2420.05 302.76 -2401.19 1.32 5980874.32 616524.22 N 70.35650329 W 149.05364830
6604.49 6.83 285.53 5977.23 2432.65 305.81 -2413.50 1.64 5980877.17 616511.87 N 70.35651160 W 149.05374825
6701.67 5.04 286.99 6073.89 2442.60 308.60 -2423.15 1.85 5980879.81 616502.17 N 70.35651923 W 149.05382662
6796.58 4.91 284.73 6168.44 2450.74 310.85 -2431.07 0.25 5980881.94 616494.22 N 70.35652537 W 149.05389090
6891.97 5.02 282.38 6263.47 2458.96 312.79 -2439.09 0.24 5980883.74 616486.17 N 70.35653064 W 149.05395607
6987.80 5.07 288.00 6358.93 2467.31 314.99 -2447.21 0.52 5980885.82 616478.02 N 70.35653667 W 149.05402203
7083.22 3.76 303.81 6454.07 2474.27 318.04 -2453.82 1.86 5980888.76 616471.36 N 70.35654498 W 149.05407572
~, 7178.70 2.38 4.96 6549.43 2477.18 321.76 -2456.25 3.50 5980892.44 616468.87 N 70.35655513 W 149.05409546
7274.18 2.66 28.15 6644.82 2476.51 325.68 -2455.04 1.10 5980896.38 616470.02 N 70.35656586 W 149.05408559
7369.13 2.52 30.91 6739.68 2474.93 329.42 -2452.92 0.20 5980900.15 616472.08 N 70.35657607 W 149.05406846
7465.69 2.35 29.39 6836.15 2473.37 332.96 -2450.86 0.19 5980903.73 616474.08 N 70.35658576 W 149.05405172
7544.54 2.14 35.75 6914.94 2472.09 335.57 -2449.21 0.41 5980906.36 616475.69 N 70.35659287 W 149.05403830
7600.00 2.14 35.75 6970.36 2471.12 337.25 -2448.00 0.00 5980908.06 616476.88 N 70.35659746 W 149.05402848
Schlumberger
Alaska Data and Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
ATTN: Beth
Well
Job #
Log Description
V.10~-dD~
V-103 ~()~-1<'?~
S-115 aO;J,;J 3u
STATIC BH SURVEY
TEMPERATURE SURVEY
23058 SCMT
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center LR2-1
900 E Benson Blvd.
Anchorage AK 99508-4254
Date Delivered:
RECEIVED
FEB 0 7 2003
Ala8fœ on & Gas Cons. Commiaeion
Anchorage
01111/03
01106/03
01/22/03
NO. 2845
02/06/03
Company: Alaska Oil & Gas Cons Comm
Attn: Usa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Borealis
Aurora
Date
BL
Sepia
Schlumberger DCS
3940 Arctic Blvd Suite 300
Anchorage AK 99503-5789
ATTN: ~ '
Rece"d by: ./ ~
Color
CD
-~'
G.O~
-'
Schlumberger
Alaska Data and Consulting Services
3940 Arctic Blvd, Suite 300
Anchorage, AK 99503-5711
A TTN: Beth
Well
L-112"'~-~;J£1
L-112
L-112
L-112
L-112
L-112
L-112 '- /
S-115 ....JO~- ~.5 0
S-115
S-115
S-115
S-115
S-115
S-115
S-115 ~
S-115
S-115
Job#
Log Description
23029 OH EDIT PEX,AIT,BHC (PDC)
23029 PEX-AIT
23029 PEX-BHC
23029 PEX-NEUTRON/DENSITY
23029 PEX-TRIPLE COMBO MD
23029 PEX-TRIPLE COMBO TVD
23029 CALIPER LOG
23028 OH EDIT LWD GR & ROPS
23028 MD IMPULSE GR
23028 TVD IMPULSE GR
23035 OH EDIT PEX,AIT,BHC (PDC)
23035 PEX-RESISTlVITY
23035 PEX-NEUTRON/DENSITY
23035 PEX-SONIC
23035 PEX-TRIPLE COMBO MD
23035 PEX-TRIPLE COMBO TVD
23035 CALIPER LOG
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO:
BP Exploration (Alaska) Inc.
Petrotectnical Data Center LR2-1
900 E Benson Blvd.
Anchorage AK 99508-4254
Date Delivered:
~RC: (' ~ 1"\ ¡ ~ 1~"'f\
.! t - ~ . -.r¡ :0-' k..J
- ~~!o.~" _ :Joo't'_
FES 071,DC3
;).1.:--: ::."J.: ~~-.~
AJ2~~ c:; 1. ~;,;.:.:- :.>,,:.:, '--'~;;;...~'::'::~':.::.
01109/03
01109/03
01109/03
01/09/03
01/09/03
01/09/03
01/09/03
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
12/27/02
01/28/03
NO. 2829
Company: Alaska Oil & Gas Cons Comm
Attn: Lisa Weepie
333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Borealis
Aurora
Date
Color
Sepia
BL
CD
'-~'
Schlumberger DeS
3940 Arctic Blvd Suite 300
Anchorage AK 99503-5789
ATTN: Beth
R~;~(J1p~
-/
)
)
ao~- a~
MWD/LWD Log Product Delivery
Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie
Well No S-115 Date Dispatched: 14-Jan-03
Installation/Rig Nabors 9ES Dispatched By: Nate Rose
Data No Of Prints No of Floppies
Surveys
2
RECEr/ED
~ .. . / nf1r. __ )Please sign and return to:
Received ByC ../ ~ . ~
JAN 2 1 2003
AIaaka Oii & Gea Con4. Commillion
. -~I ~ç
James 1-t.~~·ri'Sõii
BP Exploration (Alaska) Inc.
Petrotechnical Data Center (LR2-1)
900 E. Benson Blvd.
Anchorage, Alaska 99508
Fax: 907-564-4005
e-mail address:johnsojh@bp.com
LWD Log Delivery V1.1, Dec '97
)
)
bp
To:
Winton Aubert, AOGCC
Date: Dec. 10, 2002
From: Rob Tirpack
"2~t? l ... "2.. ~O
Subject: Dispensation for 20 AAC 25.035 (c) on 8-115 - already permitted
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, support the rationale for the request.
To date, none of the 40-plus Ivishak wells at S-pad, nor the recent Aurora/Polaris wells
have experienced pressure control or shallow gas problems above the surface' casing
depth, apart from minor and inconsequential hydrate shows. The first ten surface holes
for the Aurora/Polaris development were drilled no deeper than the shale underlying the
SV-l sands; S-115 is planned to TD in the shallower SV-3 shale, as did the most recent
wells (apart from S-106 where a diverter was installed). The shale underlying the SVl is
the deepest planned surface casing setting depth for future pad development wells. This
casing point is ±700' 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-115 is planned to reach 9.5 ppg mud weight
before TD at 2,924' TVDss. Supporting surface hole gas detection information is on file
with the AOGCC from recently drilled S-105.
If the wavier can not be granted, work is in progress to install the diverter line with
several direction changes. Discussions between Lou Gramaldi and the Nabors ges rig
team have led to the planned installation of "Targeted T's" for the direction changes in
the diverter line. It is BP's preference to pursue the diverter wavier rather than install the
diverter line with direction changes. Z. '^- 900 Co v'- Vl c-... .
Your consideration of the waiver is appreciated.
Sincerely,
uAn;y ~
./' ~--t9;;~
Rob Tirpack
GPB Rotary Drilling Engineer
564-4166
RECEIVED
DEC 11 2002
Alaska Oil & Gas Cons. Commission
Anchorage
AI,ASIiA. OIL AND GAS
CONSERVA.TION COMMISSION
Lowell Crane
Senior Drilling Engineer
BP Exploration (Alaska), Inc.
PO Box 196612
Anchorage, AK 99519
')
/
/
TONY KNOWLES, GOVERNOR
)
~j!ÆJŒ QJ~ !Æ:fÆ~[«fÆ
333 W. "JTH AVENUE, SUITE 100
ANCHORAGE, ALASKA 99501-3539
PHONE (907) 279-1433
FAX (907) 276-7542
Re: Prudhoe Bay Unit S-115
BP Exploration (Alaska), Inc.
Permit No: 202-230
Surface Location: 4406' NSL, 4499' WEL, Sec. 35, T12N, R12E, UM
Bottomhole Location: 4704' NSL, 1645' WEL, Sec. 34, T12N, R12E, UM
Dear Mr. Crane:
Enclosed is the approved application for pennit to drill the above referenced development well.
This permit 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 permits and approvals have been issued. In addition, the Commission
reserves the right to withdraw the permit 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 terms and conditions of this permit may
result in the revocation or suspension of the permit. 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,
~~
Michael L. Bill
Commissioner
BY ORDER OF THE COMMISSION
DATED this 9!?'day of December, 2002
cc: Department ofFish & Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
itJ6A- / l /4-/0 'L.
Hole
42"
9-7/8"
6-3/4"
6-3/4"
\ STATE OF ALASKA .....
ALASKÁ ~1L AND GAS CONSERVATION COMI\.. lSION
PERMIT TO DRILL
20 AAC 25.005
1 b. Type of well 0 Exploratory 0 Stratigraphic Test a Development Oil
o Service 0 Development Gas 0 Single Zone 0 Multiple Zone
5. Datum Elevation (DF or KB) 10. Field and Pool //
Plan KBE = 64.1' Prudhoe Bay Field I Aurora
6. Property Designation Pool (Undefined)
ADL 028258
7. Unit or Property Name
Prudhoe Bay Unit
8. Well Number /
5-115
9. Approximate spud date
12/15/02/ Amount $200,000.00
14. Number of acres in property 15. Proposed depth (MD and TVD)
2560 75951 MD 16985' TVD
o 17. Anticipated pressure {s~ 20 AAC 25.035 (e) (2)}
34 Maximum surface 2687 psig, At total depth (TVD) 6560' I 3343 psig
Setting Depth
Top Bottom
MD TVD MD TVD
Surface Surface 109' 109'
Surface Surface 3236' 2924'
Surface Surface 5285' 4711'
5285' 4711' 7580' 6969' 223 sx Class IGI, 176 sx Class IG'
11. Type Bond (See 20 AAC 25.025)
1 a. Type of work a Drill 0 Redrill
ORe-Entry 0 Deepen
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P.O. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
4406' NSL, 4499' WEL, SEC. 35, T12N, R12E, UM (As Staked)
At top of productive interval
47041 NSL, 1645' WEL, SEC. 34, T12N, R12E, UM
At total depth
4704' NSL, 1645' WEL, SEC. 34, T12N, R12E, UM
12. Distance to nearest property line 13. Distance to nearest weill
ADL 028257, 1645' MD S-101 is 9' away at 400' MD
16. To be completed for deviated wells
Kick Off Depth 250' MD Maximum Hole Angle
18. Casin~ Program Specifications
Size
Casina Weiaht Grade Couplina
34" x 20" 91.5# H-40 Weld
7-5/8" 29.7# NT-95 NSCC
5-1/2" 15.5# L-80 BTC-M
3-1/2" 9.2# L-80 IBT-M
Number 2S 100302630-277
Lenath
80'
3208'
5257'
2294'
Quantitv of Cement
(include staae data)
260 sx Arctic Set (Approx.)
407 sx PF ILl, 161 sx Class 'G'
5-1/2" x 3-1/2" Cement Listed Below
,,/
/
19. To be completed for Red rill , Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing
Length
Size
Cemented
MD
TVD
Structural
Conductor
Su rface
Intermediate
Production
Liner
RECEIVED
DEC 032002
Perforation depth: measured
true vertical
masRa Oil·& Gas Cons. Commission
&1chorage
20. Attachments
a Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch a Drilling Program
a Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements
Contact Engineer Name/Number: Rob Ti k, 564-4166
21. I hereby certify that the/ore g is true a99 correct to the best of my ~nowl~~ge .
Signed Lowell Crane ~ /é..--C___ Title Senior Drilling Engineer
Commission. Use;·Only·
Prepared By Name/Number: Terrie Hubble, 564-4628
Date
J--~-0J-
Permit Number
.2. ð-Z.. - ...2. :3 c:::>
Conditions of Approval:
API Number
50-02.'7 - 23/30
Samples Required 0 Yes ~ No
Hydrogen Sulfide Measures 0 Yes ~ No
Required Working Pressure for BOPE 0 2K
Other: Té ~t t')PE fo ŠS'Oo pt~.
ORIGINAL SIGNED BY
M I Rill ¡l P ~~~~~r~r ~
'.. I,,,. U I, \. { \ t,~.
APP'rA~~ )R~ See cover letter
j }\ Y l,",.f'--.,. for other requirements
Mud Log ReqJired 0 Yes Œ:I No
Directional Survey Required 181 Yes 0 No
o 3K D4K D5K D10K D15K 0 3.5K psi for CTU
Approved By
Form 10-401 Rev. 12-01-85
by order of
the commission
Date
,,~Cì O~
Subm t In 'Triplicate
)
)
IWell Name: 18-115
Drill and Complete Plan Summary
I Type of Well (service / producer / injector): I Producer
Surface Location:
As-Built
Target Location:
Top Kuparuk
Bottom Hole Location:
x = 618,929.71' Y = 5,980,609.74'
4406IFSL,4500'FEL,Sec.35,T12N,R12E
X = 616,499.98' Y = 5,980,870'
47041 FSL, 16451 FEL, Sec. 34,T12N, R12E
X = 616,499.98' Y = 5,980,870'
47041 FSL, 16451 FEL, Sec. 34,T12N, R12E
1 AFE Number: I AUD5M0020 I
1 Estimated Start Date: 112/15/2002 I
I Ria: I Nabors 9ES /
I Operatina days to complete: 112.0
I MD: 17580' I I TVD: 16969' I 1 GL: 135.6' I
1 RKB: 128.5' I
I KBE: 164.1'
I Well Desian (conventional, slim hole, etc.): I Microbore (Iongstring) /
I Objective: 1 1) Kuparuk Formation 2) Schrader Bluff .,/
Mud Program:
9-7/8" Surface Hole (0-3236'):
Fresh Water Surface Hole Mud
Initial
below Permafrost
interval TD
Densitv
(ppg)
8.5- 9.2
9.0 - 9.5 /
9.5 max
Viscosity
(seconds)
250-300
200
150-200
Yield Point
(lb/1 OOft~)
50 - 70
30 - 45
20 - 35
Tau 0
>20
>15
>15
APIFL
(mls/30min)
15-20
<8
<8
PH
8.5-9.5
8.5-9.5
8.5- 9.5
6 3A" Intermediate / Production Hole (3236' - 7580'):
Interval Density Tau 0 YP PV
(ppg)
9.7
10.3/
pH
Fresh Water LSND
API HTHP
Filtrate Filtrate
6-10
Upper
Interval
Top of HRZ
to TD
4-7
27 -32
1 0-15
8.5-9.5
3-7
17-25
1 0-1 5
8.5-9.5
4-6 <10 by
HRZ
8-115 Permit to Drill
) )
Hydraulics:
Surface Hole: 9 7/8"
Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA
GPM Pipe (fpm) ppg-emw ("/32) (in2)
0-2011 ' 550 4" 17.5# 130 1600 10.2 N/A 18,18,18,16 .942
2011 '-3236' 600 4" 17.5# 150 2600 10.4 N/A 18,18,18,16 .942
Production Hole: 6 %"
Interval Pump Drill Pipe AV Pump PSI ECD Motor Jet Nozzles TFA
GPM (fpm) ppg-emw ("/32) (in2)
3236'-7580' 330 4" 17.5# 210 1700 - 2500 11.1 N/A 5X12 .552
Hole Cleaning Criteria:
Interval Interval ROP Drill Pump Mud Hole Cleaning Condition
Pipe GPM Weight
Rotation
110'-3236' Surface Superior hole cleaning practices at
to SV-2 connections will greatly enhance
cuttings transport particularly in sliding
mode
210 60 500 9.5 Acceptable
250 60 600 9.5 Acceptable
300 60 700 9.5 Acceptable
250 90 500 9.5 Acceptable
315 90 600 9.5 Acceptable
300 90 700 9.5 Acceptable
3236' -5857' To Base ROP's greater than 400'/hr must be
Schrader accompanied by a GPM of 330 and fully
reamed connections to maintain
minimum hole cleaning requirements
250 80 330 9.7 Marginal
250 100 330 9.7 Acceptable
300 80 330 9.7 Marginal/Poor
300 100 330 9.7 Marginal/Manageable
400 80 330 9.7 Very Poor
400 100 330 9.7 Poor
5857' - TD Base ROP's greater than 200'/hr must be
Schrader accompanied by maximum pump rates
toTD and fully reamed connections to
maintain minimum hole cleaning
requirements
150 80 330 10.1 Acceptable
200 80 330 10.1 Marginal
S-115 Permit to Drill
)
Directional:
Ver. Anadrill P7; Slot #7
KOP: 250'
Maximum Hole AnQle:
Close Approach Wells:
Survey Program:
Lo~~in~ Pro~ram:
Surface
Production Hole
Formation Tops
SV6
Base Permafrost
SV5
SV4
SV3
SV2
SV1
UG4
UG4A
UG3
UG1
Ugnu Ma
Top Schrader Na
Schrader Oa
Schrader Obd
Schrader Obf
Base Schrader
CM 1 Colville Shale
THRZ
BHRZ (Kalubik)
TKUP
Kuparuk C
LCU Kuparuk B
Kuparuk A
TMLV (Miluveach)
TD Criteria
Formation Markers:
MD
1664'
2011'
2397'
2645'
3115'
3254'
3677'
4077'
4124'
4491'
5015'
5208'
5435'
5551'
5727'
5815'
5857'
7195'
7195'
7215'
7235'
7235'
7325'
7360'
7430'
7580'
)
34 degree~ at 1802' MD
All wells pass close approach. However, S-101 has a center
to center distance of 9' at 400' MD.
Gyro: 0 - 1,200'
Standard MWD surveys+IFR+MS: 1,200' to TD
Drilling: MWD / GR
Open Hole:
Cased Hole: None
Drilling: MWD / GR / PWD
Open Hole: e-line PEX/BHC Sonic
Cased Hole: SCMT after rig departure
TVDss
1555'
1845'
2165'
2370'
2760'
2875'
3225'
3560'
3600'
3920'
4395'
4575'
4790'
4900'
5070'
5155'
5195'
6520'
6520'
6540'
6560'
6560'
6640'
6685'
6755'
6905'
Estimated Pore Pressure
8.8 ppg
Hydrocarbon Bearing, 8.8* ppg
Hydrocarbon Bearing, 9.0 ppg
Hydrocarbon Bearing, 9.0 ppg
Hydrocarbon Bearing, 9.2 ppg
Hydrocarbon Bearing, 8.8 ppg
Hydrocarbon Bearing, 8.8 ppg
Hydrocarbon Bearing, 8.8 ppg
Hydrocarbon Bearing, 8.8 ppg
Hydrocarbon Bearing, 9.8 ppg
Hydrocarbon Bearing, 9.8 ppg
ro,~
Hydrocarbon Bearing, 9.8 ppg
150' MD below Miluveach top
*A kick occurred at S-200PB1 in UG4a sands that required 10.3-10.5 ppg MW to control.
*A thin lower UG4a coal at S-201 showed an RFT of 10.1 ppg EMW.
8-115 Permit to Drill
)
)
CasingJTubin~ Program:
Hole Csgl WtlFt Grade Conn Length Top Btm
Size T~ / ./ MDITVD MDITVD bkb
42" I ulat ,./ 91.5# H-40 WLD 80' GL 109/109
" 0"
9-7/8" 7 5/8" 29.7# NT -95 NSCC 3208' GL 3236'/2924'
6-3/4" 5-1/2" 15.5# L-80 STC-m 5257' GL 5285'/4711 '
6-3/4" 3-1 /2" 9.2# L-80 1ST-mod 2294' 5285'/4711' 7580'/6969'
Tubing 3-1/2" 9.2# L-80 1ST-mod 5257' GL 5285'/4711 '
Integrity Testing:
Test Point Depth Test Type EMW
Surface Casing Shoe 20' min from LOT 12.7 ppg (minimum for a 25
surface shoe bbl kick tolerance)
Cement Calculations:
The following surface and production cement calculations are based upon a single stage job.
Casinq Size 17 -5/8" Surface I
Basis: Lead: Based on 2011' of annulus in the permafrost @ 250% excess and 629' of open
hole from top of tail slurr~ to base permafrost @ 30% excess.
Lead TOe: To surface ./
Tail: Based on 596' MD open hole volume + 30% excess + 80' shoe track volume.
Tail TOe: At -2640' MD /ì
Total Cement Volume: Lead 301 bbl/ 1690 ft" /.~r¡/SkS of Halliburton Permafrost L at
10.7 ppg and 4.15 "k.
Tail 33 bbl I 185 fe I ß,9" sks of Halliburton Premium 'G' at
15.8 ppg and 1.~'cf/sk.
Casing Size 5-1/2"x3-1/2" Production
Longstring
Basis: Lead: Based on TOe 500' MD above the top of the UG4A formation + 300/0 excess and
base of cement 500' MD above top of Kuparuk formation.
Tail: Based on TOe 500' MD above top of Kuparuk formation + 30% excess + 90' shoe
track volume. Tail TOe @ -6735' MD. ./ /l
Total Cement Volume: Lead 93 bbl I 522 fe I¡¿~ sks of Halliburton Premium 'G' at
12.5 ppg and 2.~sk.
Tail 36 bbl I 202 fe I t7,¥ sks of Halliburton Premium 'G' (KUP
Latex Design) at-:f5.8 ppg and 1.15 cf/sk.
8-115 Permit to Drill
')
):
Well Control: /
Surface hole will be drilled with diverter. The intermediate hole, well control equipment
consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer
will be installed and is capable of handling maximum potential surface pressures'.J,ased upon
the information listed below the BOP equipment will be tested to 3500 psi.
Diverter, BOPE and drilling fluid system schematics on file with the AOGCC.
Production Interval-
· Maximum anticipated BHP:
· Maximum surface pressure:
=3 ~rpsi (9.8 ppg EMW@6560'TVDss-TKUP)
687 p'si @ su rface
sed on a full column of gas @ 0.10 psi/ft)
· Planned BOP test pressure:
· Planned completion fluid:
/
3500 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" wastes to DS-
04 for disposal. Haul all Class I wastes to Pad 3 for disposal.
H2S:
· H2S readings are listed below. S-Pad is not designated as a H2S pad, however
Standard Operating Procedures for H2S should be followed at all times.
#1 Closest SHL
#2 Closest SHL
#1 Closest BH L
#2 Closest BH L
Max Reading on Pad
Well Name
S-1 03
S-1 04
S-1 00
S-101
S-40
H2S Level
8 ppm
8 ppm
8 ppm
8 ppm
70 ppm
8-115 Permit to Drill
')
)
DRILL AND COMPLETE PROCEDURE SUMMARY
Pre-Rig Work: /::r~'7
The 20" insulated conductor will be installed Decemb~
1. Weld a FMC landing for the FMC Ultra Slimhole wellhead on the conductor.
2. If necessary, level the pad and prepare location for rig move.
Rig Operations:
1. MIRU Nabors 9ES on Slot #7. / /.:J
2. Nipple up diverter spool and riser. PU~ as required and stand back in derrick. /'
3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to 3236' MD/2924' TVD.
Actual TD will be approxim~ly 100' TVD below the SV3 sands (see Anadrill directional plan).
4. Run and cement the 7-5/8", 29.7# surface casing back to surface. A Tam port collar will be run at
1000' as a contingency on the chance that cement returns are not seen at the surface.
5. ND diverter spool and NU casing I tubing head. NU BOPE and test to 3500 psi. /'
6. MU 6-3/4" drilling assemjW' with MWD/GR/PWD and RIH to float collar. Test the 7-5/8" casing to
3500 psi for 30 minutes.
7. Drill out shoe joints and displace well to 9.7 ppg LSND drilling fluid. Drill new formation to 20' below 7-
5/8" shoe and perform Leak 0'!yTest.
8. Drill ahead to 7580' MD/6969' TVD following the directional and mud programs. Actual TD will be
-150' of rat hole into the Miluveach formation.
9. Perform open hole logging program. PEX/BHCSonic (e-line conveyed). If the logging run is
unsuccessful on the first e-line attempt, the logs are to be run on drill pipe.
1 O. Condition hole for running longstring and POOH. This step may be done when pulling the drill pipe
out after reaching TD at the Company Representatives discretion.
11. Run and cement the tapered production casing as required from TD to 500' above UG4a. Displace /'
the casing with filtered seawater during cementing operations and freeze protect the 5 V2" x 7-5/8"
annulus as required.
12. Test 5-1/2" X 3-1/~roduction casing to 3500 psi. I"
13. Run the 3-1/2",9.2#, L-80 gas lift completion assembly. Circulate around corrosion inhibitor. Sting seal
assembly into tieback receptacle and test to 3500 psi for 30 minutes both the tubing and annulus.
Release tubing pressure and shear RP valve.
14. Install TWC and test from below to 1000 psi. Nipple down the BOPE. Nipple up and test the tree to
5000 psi. Remove TWG.
15. Freeze protect the well to -2200' and secure the well.
16. Rig down and move off. /'
S-115 Permit to Drill
)
}
5-115 Drilling Program
Job 1: MIRU
Hazards and Contingencies
~ 8-Pad is not designated as an H28 site. Review H28 table above. As a precaution,
Standard Operating Procedures for H2S precautions should be followed at all times.
~ The closest surface location will be 8-101, which is -15' wellhead to wellhead. The well is
expected to be on injection and will require a surface shut-in during move in.
~ Check landing ring height on 8-115, the BOP nipple up may need review.
Reference RPs
.:. "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure"
I::mi:i::m--::II:::I'::I IWIJI:_:lanlm:lmll:llm~ll.Immlm:mwml:ma llmmmmnmll~'I!:I:-:m:WrD:IIIIII:C::lal:llllllm:ml'lm:mllllmlmmllllmlmmll'lmm~mllalllmllll:mlla:m1l1111Ia!mm':~lmmrmmcrl lllmalm:I'Clmla'IUllm:'¡~'lIIm!:--I!
Job 2: Drillinq Surface Hole
Hazards and Contingencies
~ No faults are expected to be penetrated by 8-115 in the surface interval.
~ Drilling Close Approach: All offset wells pass BP anti collision guidelines. However, 8-101 will
have a center-center distance of approximately 15' at the surface and 9' at 400' MD. A gyro will
be required until the interference from 8-101 has dissipated (Estimated to be -1200' MD).
~ The 8V4 sand may contain gas hyrdrates, though little or none have been encountered thus far in
recent 8-pad developments. Hydrates will be treated at surface with appropriate mud products
and adjustment of drilling parameters. Refer to Baroid mud recommendation
~ Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will
tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate
viscosity.
Reference RPs
.:. uPrudhoe Bay Directional Guidelines"
.:. UWell Control Operations Station Bill"
,:IA:¡I,:U,:, ,-I Jlml.ll.II~ ,~a,I¡\:IIAI.I~Ui:,~m,~;,; 'I; U,iml,~Ml.'Ulll¡\llHUUlUl.I.m-¡-l ,II,:¡,~I.mHl~lll_~IH,Ur-.Io.-'-:,:.I:.-TllUU.IWUlml,1,;IIJIUI;~au;.rI-_I-':,llIT,U,U.;U'-","'lll'l:.r.r.Hm.-.I_-,W,-1-.' -.II,:,. :1.I JI,¡ .lI, ,I.lI,~I,I,!,Qlml.lI.lI,I,^,^,;, ,QlmQ,Q,~l~,1I,~I.I ,';.; ,"l'~ .I'II,I'II,"I ,':~-,;I,'-.;)'.lI,ml,I:m·: : ::,I'~ ,I'.;:,:I.I;'-';)I:,~I,I,I ,I,IR:',II','!.I'm,l,l-l'U,I,','I,I. nl,'Q¡I'.I ml,"'I,~ , I, :.lI,J.lI.I~:,11
Job 3: Install Surface Casina
Hazards and Contingencies
~ It is critical that cement is circulated to surface for well integrity. Plan 250% excess cement
through the permafrost zone and 30% excess below the permafrost. A 7-5/8" port collar will be
positioned at ±1 OOO'MD to allow a secondary circulation should cement to surface not be
achieved.
Reference RPs
.:. "Casing and Liner Running Procedure"
.:. "Surface Casing and Cementing Guidelines"
.:. "Halliburton Cement Program"
.:. "Surface Casing Port Collar Procedure"
8-115 Permit to Drill
')
).
ImAAl.:,lm¡,:.m.lm,t,W.:,I;J,I;J,l.:mmw,WJ¡,:.I¡¡,U¡,IJAI.!¡,-rJ.I;¡.wW¡¡';,:Jm~m-'J.-u,I;µ,-".I,;AIJ,-.I.I.I»mJAI.:.M.l.lu:)nJ.:m.IJ,:;mJWmm~JKJ,:.I)lfm,:m,1J,:mm,IJOO.lJAAlJ.IJAI;mm¡,llI>mm¡m¡,l.I.Wm.w¡,I;/,IAAl,lmmmmm.mm.l.WJ,I,:.).I.-,:,1;.-, ¡n),:,\-".."t".-,-',-¡,-i,-,~_,:"m,l~
.-¡"-,),lmf.,\ m"·!,I_a',I.I;":'-",,'-II,!~.I,:,IJ.'1'i,\!.~IIK>!,~.Ommm,I.:Þ!,:"';mJ,~.I¡',~;,-,:,:,::¡.,-:m;.-'-,.-'-!'-'-,,,.,,'-'-.\'!Þmm,I¡"~;,W.I),I!
Job 7: DrillinQ Production Hole
Hazards and Contingencies
~ KICK TOLERANCE: The reservoir pressure of the Kuparuk has been estimated to be 9.8 ppg.
Assuming gauge hole, a fracture gradient of 12.7 ppg at the surface casing shoe, 10.3 ppg mud in
the hole the kick tolerance is 25 bbls. An accurate LOT will be required as well as
heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 12.7
ppg.
~ Two faults are expected to be penetrated by the S-115 production hole. Fault #1 is located in the
lower Ugnu UG1 at 4550' TVDss. The throw is estimated at -100' to the West and is considered a
moderate risk for lost circulation while drilling. Fault #2 is located in the Lower Coleville at 6025'
TVDss. The throw is estimated at -75' to the West and is considered a moderate risk for lost
circulation while.
~ Losses may be encountered when running the production casing string if adequate precautions
are not taken including running speed, staging in and optimal mud properties.
~ There are no "Close Approach" issues with the production hole interval of S-115.
Reference RPs
.:. Standard Operating Procedure for Leak-off and Formation Integrity Tests
.:. Prudhoe Bay Directional Guidelines
.:. Lubricants for Torque and Drag Management.
.:. "Shale Drilling- Kingak & HRZ"
'1_111I1111111:111~11~llmll!I::I'lmI111:llml:IIII~II~11nlmlnlml~I~lmmUO~U~OOtmIO!IIIIIOllmnOU~OOIIOUltlr:llllllmt~mltOlllllllllmlllOUIOllOllomlHlttllmllCllllltllllOllUlmlllmmlI!Cllmllllllll~:I_IIII'-lm:IO:I:I:~-.mOOlltCiIOII~nl:IIOmlltIIIOOI¡;;¡~;';!_III:IIIOII:II:IOOII~II!II:IIIIIIIOOII~1:Ulnlll::ln¡:II::nl:II!IIOllmlllll_~_IOI:I! IIOII__1OI_II_:_I_-:I:;_:I:I;IIII;} mlmIOI!l!lIII~II>llllmlll_I_:::111111
Job 8: LOQ Production Hole
Hazards and Contingencies
~ Ensure the hole is in optimal condition prior to logging to ensure a successful logging program.
Review the use of lubricant pill across logging interval.
~ If logging time is excessive or hole conditions dictate, perform a clean out run prior to running the
5 Y2" x 3 Y2" longstring casing.
Reference RPs
.:. Follow Schlumberger logging practices and recommendations.
.:. "Drillpipe Conveyed Logging"
Job 9: Case & Cement Production Hole
Hazards and Contingencies
~ The 5-1/2" X 3-1/2" production casing will be cemented to 500' above the top of the UG4A with a
single stage-two slurry cement. Due to the small annular spacing, a two stage job is not an
option. Getting casing to bottom while maintaining returns is a critical operation.
~ Considerable losses during the running and cementing of the production casing has occurred on L
and V-Pad. A casing running program will be jointly issued by the ODE and Drilling Supervisor
detailing circulating points and running speed. In addition, a LCM pill composed of "Steel Seal" will
be placed across the Schrader and Ugnu to help arrest mud dehydration.
8-115 Permit to Drill
)
)
~ Ensure the upper production cement has reached at least a 7)BC thickening value prior to freeze
protecting. After freeze protecting the 7-5/8" x 5-1/2"" casing outer annulus with dead crude to
2200' MD, the hydrostatic pressure will be 7.7 ppg vs 8.8 ppg EMW of the formation pressure
immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the
cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping
the dead crude as the hydrostatic pressure of the mud and crude could be 165 psi underbalance
to the open hole.
~ Ensure a minimum hydrostatic equivalent of 10.1 ppg on the Kuparuk formation during pumping of
cement pre flushes/chemical washes. Loss of hole integrity and packing off has resulted from a
reduction in hydrostatic pressure while pumping spacers and flushes.
~ The well will be under-balanced after displacing the cement with sea-water. Verify that the floats
are holding before continuing operations and hold pressure on the well if they are not holding.
~ The X- Nipples, with 1.0. of 2.813" is the tightest tolerance for the Weatherford Dual- Plug
system, (tapered cement plugs to be used in the 5 Y2" X 3 11!" tapered casing string.) Caliper and
confirm the 1.0. of all X-Nipples prior to make-up to ensure conformity with proposed design. The
By-Pass plug head has been milled down to an 0.0. of 2.5". Caliper to confirm, prior to use.
Note: Based on ongoing studies relating to wiper plug failures, drop the top and
bottom plug together prior to displacement of cement.
Reference RPs
.:. "Intermediate Casing and Cementing Guidelines"
.:. "Halliburton Cement Program" Attached.
.:. "Freeze Protecting an Outer Annulus"
Job 12: Run Completion
Hazards and Contingencies
~ Watch hole fill closely and verify proper safety valves are on the rig floor while running this
completion. The well will be under-balanced if there is a casing integrity problem.
~ Shear valves have been failing at lower than the 2500 psi differential pressure. When testing
annulus maintain no more than a 1500 psi differential. Avoid cycling pressure prior to activating
shear valve as this is thought to cause shearing at lower pressures.
Reference RPs
.:. "Completion Design and Running"
.:. "Freeze Protection of Inner Annulus"
1_ .11:ln:'IIWI_LI_IILIIILlIIIIIIIIII':ILC'UIII_ ,,-- _I. -;-.111111111I11
Job 13: ND/NU/Release Ria
Hazards and Contingencies
~ No hazards specific to this well have been identified for this phase of the well construction.
Reference RPs
.:. Standard practices apply.
.:. Freeze Protection of Inner Annulus.
S-115 Permit to Drill
)
')
S-115 Well
Summarvof Drillina Hazards
POST THIS NOTICE IN THE DOGHOUSE
Surface Hole Section:
· Gas hydrates have occasionally been encountered near the base of the
Permafrost and in the SV sands. No other shallow gas has been reported.
· Gravel beds below the Permafrost will tend to slough in when aerated (hydrate
cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to
avoid stuck pipe situations.
Production Hole Section:
· Expect the Ugnu Intervals to contain hydrocarbons.
· All though unexpected, pressure is possible in the UG4A. S-200PB 1 required
10.3-10.5 ppg mud to control a kick and S-201 shows a RFT pressure of 10.1
ppg EMW. Subsequent drilling has been done on S pad without problems in the
UG4A.
· Lost circulation while drilling has not been problematic at S-Pad. However, two
fault crossings are expected to be crossed. In the event of lost circulation,
consult the LCM Decision Tree.
· The production section will be drilled with a recommended mud weight of 10.3
ppg to ensure shale stability in the HRZ shale and to cover the Kuparuk 9.8 pore
pressure.
· Kick tolerance is low: 25 bbls. Hold a pre-reservoir meeting. Do not hesitate to
shut in the well if flow is suspected after observing minor pit gains.
HYDROGEN SULFIDE - H2S
. This drill-site not designated as an H2S drill site. Recent tests indicate a
very low concentration of H2S. As a precaution, Standard Operating
Procedures for H2S precautions should be followed at all times.
/
CONSULT THE S-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL
INFORMATION
8-115 Permit to Drill
)
S-PAD
N 1100-"
/
N 1010
10
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.................
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(/)(/)(/)(/)(/)(/)(/)(/)~(/)~(/) (/)(/)(/)
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LEGEND
-+ AS-BUILT CONDUCTOR
. EXISTING CONDUCTOR
NOTES:
1. DATE OF SURVEY: NOVEMBER 27, 2002
2. REFERENCE FIELD BOOK: W002-14 PAGES 44-46.
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 EXPLORATON MEAN SEAL LEVEL DATUM.
~)
21
26 25
S PAD
~
36
jJ
34
3
T.12N.
T.11N.
2
~
VICINITY MAP
N.T.S.
(\
~Ny
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 27, 2002.
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
Y= 5,980,609.74 N. 1009.79 70°21 '20.438" 70.3556772° ,4,406' FSL
S-115 X= 618,929.71 E. 245.21 149°02'02.939" 149.0341496° 35.6 4,500' FEL
S-117 Y= 5,980,579.93 N. 1010.20 70°21 '20.145" 70.3555958° 35.9' 4,377' FSL
X= 618,930.14 E. 275.02 149°02'02.940" 149.0341501° 4,500' FEL
F. ROb' DRAWN: Obp
JACOBS
l~-- I CHECKED:
AlliSON
~ ~ ... DAlE:
DRAWING:
FRB02 WOA-S 08-00 WOA S-PAD SH EET:
¡ ffi~~rnœo JOB NO:
SCALE: AS-BUlL T CONDUCTOR
o 11/29/02 . ISSUED FOR INFORMAl1ON JJC K'Mi (:HCIrrt[(RS AN) LAHO SJ"'tt'I"ORS 1"· 150' WELLS 5-115 & 5-117 1 OF ,
801.ur f1III::1II([D LAN(
NO. DATE REVISION BY CHK AHOiORAŒ. ALASKA NKU
) )
8-115 Proposed Completion
TREE: 3-1/8" - SM CIW L-80
WELLHEAD: 11" - SM FMC GS
Cellar Elevation = 35.6'
Nges KB = 28.5'
RKB = 64.1'
I
.
3-1/2" 'X' Landing Nipple with 2.813" seal bore. 12200' MD I
7-5/8", 29.7 #/ft,
NT-95, NSCC
~
... 13236' MD 1
--.-.---.-
----,.--..
--.,.--
GAS LIFT MANDRELS
TVD Size
----..!::
#
3
2
1
---.--.-.
3-1/2" 9.3# IBT-Mod L-80
3000'
4500'
2 jts above
seal bore
3.5" X 1"
3.5" X 1"
3.5" X 1"
Valve Type
DCK Shear
DV
DV
--,--.--.-----
. "--.,-->.--,,-.,...----
5-1/2",15.5 #/ft, L-80, BTC- _
Mod (reduced clearance cplg)
· ..
3-1/2" 'X' Landing Nipple with 2.813" seal bore
5243' MD
/i
/3-1/2" Seal Assembly/4" ID Seal Bore Casing Recepticle
1/ 5-1/2"x3-1/2" XO placed at +/-150' above the Schrader Ma Sand
¡ 3-1/2" 'X' Landing Nipple with 2.813" seal bore (@ top SB)
5273' MD
5285' MD
5435' MD
·
. 3-1/2" 'X' Landing Nipple with 2.813" seal bore (@ base SB)
5857' MD
Short Marker Joint (1 jt below base SB)
5887' MD
Short Marker Joint (2 jts above top Kuparuk)
7175' MD
· . 3-1/2" 'X' Landing Nipple with 2.813" seal bore (50' above top Kup)
7185' MD
3-1/2",9.3 #/ft, L-80, IBT-Mod Top Kuparuk
7235' MD
Total Depth
7~MD
7580' MD
Plug Back Depth
Date
11/18/02
Rev By Comments
RBT Proposed MicroBore Completion (wp07)
Aurora
WELL: 5-115
API NO:
BP Alaska Drilling & Wells
õ
I
KBE
KOP Ndg 1.5/100
Crv 2/100
Crv 3/100
Report Date:
Client:
Field:
Structure t Slot:
Well:
Borehole:
UWI/API#:
Survey Name t Date:
Tort t AHD t DDII ERD ratio:
Grid Coordinate System:
Location LatlLong:
Location Grid N/E Y/X:
Grid Convergence Angle:
Grid Scale Factor:
8-115
Proposed Well Profile - Geodetic Report
November 18, 2002 Survey t DLS Computation Method: Minimum Curvature 1 Lubinski
BP Exploration Alaska Vertical Section Azimuth: 277.020°
Prudhoe Bay Unit - WOA (Drill Pads) dy Vertical Section Origin: N 0.000 ft, E 0.000 ft
S-PAD/PlanS-115 _ty stu TVD Reference Datum: KB
S-115 I- b _III TVD Reference Elevation: 64.1 ft relative to MSL
S-115 Feas Sea Bed I Ground Level Elevation: 0.000 ft relative to MSL
50029 Magnetic Declination: 25.854°
S-115 (P7) 1 November 18,2002 Total Field Strength: 57522.784 nT
74.220° 12459.66 ftl 5.298 1 0.352 Magnetic Dip: 80.819°
NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: December 20, 2002
N 70.35567779, W 149.03414795 Magnetic Declination Model: BGGM 2002
N 5980609.950 ftUS, E 618929.920 ftUS North Reference: True North
+0.90964698° Total Corr Mag North -> True North: +25.854°
0.99991607 Local Coordinates Referenced To: Well Head
Schlumberger
---
Grid Coordinates Geographic Coordinates
MD Incl Azim TVD VSec I Nt-S EI·W I DLS Northing I Easting Latitude I Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS)
0.00 0.00 150.00 0.00 0.00 0.00 0.00 0.00 5980609.95 618929.92 N 70.35567779 W 149.03414795
250.00 0.00 150.00 250.00 0.00 0.00 0.00 0.00 5980609.95 618929.92 N 70.35567779 W 149.03414795
300.00 0.75 150.00 300.00 -0.20 -0.28 0.16 1.50 5980609.67 618930.08 N 70.35567702 W 149.03414665
400.00 2.25 150.00 399.96 -1.77 -2.55 1.47 1.50 5980607.42 618931.43 N 70.35567082 W 149.03413601
450.00 3.00 150.00 449.91 -3.15 -4.53 2.62 1.50 5980605.46 618932.61 N 70.35566541 W 149.03412667
500.00 2.07 158.24 499.86 -4.37 -6.50 3.61 2.00 5980603.51 618933.63 N 70.35566003 W 149.03411863
600.00 0.90 231.40 599.83 -4.69 -8.67 3.66 2.00 5980601.34 618933.72 N 70.35565410 W 149.03411823
700.00 2.31 290.23 699.79 -2.18 -8.46 1.16 2.00 5980601.51 618931.21 N 70.35565468 W 149.03413853
788.31 4.00 300.00 787.97 2.39 -6.30 -3.18 2.00 5980603.60 618926.84 N 70.35566058 W 149.03417377
800.00 4.32 297.97 799.63 3.17 -5.89 -3.92 3.00 5980604.00 618926.09 N 70.35566170 W 149.03417978 ~
.",/
900.00 7.17 288.24 899.12 12.81 -2.17 -13.18 3.00 5980607.57 618916.78 N 70.35567186 W 149.03425497
1000.00 10.10 284.08 997.97 27.64 1.91 -27.61 3.00 5980611.42 618902.29 N 70.35568301 W 149.03437214
1100.00 13.07 281.78 1095.93 47.61 6.36 -47.19 3.00 5980615.56 618882.64 N 70.35569516 W 149.03453113
1200.00 16.05 280.32 1192.71 72.68 11.14 -71.86 3.00 5980619.95 618857.90 N 70.35570822 W 149.03473145
1300.00 19.03 279.31 1288.05 102.78 16.26 -101.55 3.00 5980624.59 618828.13 N 70.35572221 W 149.03497254
1400.00 22.02 278.57 1381.69 137.81 21.69 -136.18 3.00 5980629.47 618793.42 N 70.35573704 W 149.03525374
1500.00 25.01 278.00 1473.37 177.70 27.43 -175.66 3.00 5980634.59 618753.86 N 70.35575272 W 149.03557432
1600.00 28.00 277.54 1562.85 222.32 33.45 -219.88 3.00 5980639.90 618709.56 N 70.35576916 W 149.03593339
Station ID
5-115 (P7) report.xls
Page 1 of 3
11/18/2002-11 :22 AM
Grid Coordinates Geographic Coordinates
Station ID MD I Incl Azim TVD I VSec N/-S E/-W DLS Northing I Easting Latitude I Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS)
SV6 1664.29 29.93 277.29 1619.10 253.45 37.46 -250.75 3.00 5980643.42 618678.63 N 70.35578011 W 149.03618406
1700.00 31.00 277.16 1649.88 271.55 39.74 -268.71 3.00 5980645.42 618660.64 N 70.35578634 W 149.03632990
1800.00 33.99 276.85 1734.21 325.27 46.28 -322.03 3.00 5980651.11 618607.22 N 70.35580420 W 149.03676287
End Crv 1801.84 34.05 276.84 1735.73 326.30 46.41 -323.05 3.00 5980651.22 618606.20 N 70.35580456 W 149.03677115
Base Perm 2011.07 34.05 276.84 1909.10 443.44 60.36 -439.36 0.00 5980663.32 618489.69 N 70.35584265 W 149.03771560
SV5 2397.28 34.05 276.84 2229.10 659.67 86.11 -654.05 0.00 5980685.66 618274.64 N 70.35591295 W 149.03945893
SV4 2644.69 34.05 276.84 2434.10 798.19 102.61 -791.59 0.00 5980699.97 618136.87 N 70.35595800 W 149.04057579
SV3 3115.38 34.05 276.84 2824.10 1061.72 133.99 -1053.24 0.00 5980727.19 617874.78 N 70.35604363 W 149.04270047
7-5/8" Csg pt 3236.07 34.05 276.84 2924.10 1129.29 142.04 -1120.33 0.00 5980734.18 617807.57 N 70.35606560 W 149.04324527
SV2 3254.17 34.05 276.84 2939.10 1139.43 143.25 -1130.40 0.00 5980735.23 617797.49 N 70.35606890 W 149.04332704 ~
SV1 3676.59 34.05 276.84 3289.10 1375.93 171.41 -1365.22 0.00 5980759.65 617562.27 N 70.35614572 W 149.04523387
Drp 1/100 3830.00 34.05 276.84 3416.21 1461.82 181.64 -1450.50 0.00 5980768.53 617476.84 N 70.35617363 W 149.04592638
3900.00 33.35 276.84 3474.45 1500.66 186.27 -1489.06 1.00 5980772.54 617438.22 N 70.35618626 W 149.04623951
4000.00 32.35 276.84 3558.46 1554.90 192.73 -1542.91 1.00 5980778.15 617384.28 N 70.35620387 W 149.04667679
UG4 4077.37 31.57 276.84 3624.10 1595.85 197.61 -1583.57 1.00 5980782.38 617343.55 N 70.35621718 W 149.04700697
4100.00 31.35 276.84 3643.41 1607.66 199.01 -1595.30 1.00 5980783.59 617331.80 N 70.35622100 W 149.04710222
UG4A 4124.20 31.11 276.84 3664.10 1620.21 200.51 -1607.76 1.00 5980784.90 617319.32 N 70.35622509 W 149.04720341
4200.00 30.35 276.84 3729.26 1658.94 205.12 -1646.21 1.00 5980788.89 617280.80 N 70.35623766 W 149.04751564
4300.00 29.35 276.84 3815.99 1708.71 211.05 -1695.63 1.00 5980794.04 617231.30 N 70.35625383 W 149.04791695
4400.00 28.35 276.84 3903.58 1756.96 216.79 -1743.53 1.00 5980799.02 617183.32 N 70.35626948 W 149.04830593
UG3 4491 .10 27.44 276.84 3984.10 1799.57 221.87 -1785.84 1.00 5980803.42 617140.94 N 70.35628334 W 149.04864951
4500.00 27.35 276.84 3992.00 1803.67 222.36 -1789.91 1.00 5980803.85 617136.86 N 70.35628467 W 149.04868256
4600.00 26.35 276.84 4081.22 1848.83 227.73 -1834.75 1.00 5980808.51 617091.94 N 70.35629931 W 149.04904668
4700.00 25.35 276.84 4171.22 1892.43 232.93 -1878.04 1.00 5980813.02 617048.58 N 70.35631349 W 149.04939822
4800.00 24.35 276.84 4261.96 1934.44 237.93 -1919.76 1.00 5980817.35 617006.79 N 70.35632712 W 149.04973701
4900.00 23.35 276.84 4353.42 1974.87 242.75 -1959.90 1.00 5980821.54 616966.58 N 70.35634026 W 149.05006297 ~
5000.00 22.35 276.84 4445.57 2013.70 247.37 -1998.45 1.00 5980825.54 616927.97 N 70.35635285 W 149.05037602
UG1 5014.62 22.20 276.84 4459.10 2019.24 248.03 -2003.95 1.00 5980826.12 616922.46 N 70.35635465 W 149.05042068
5100.00 21.35 276.84 4538.39 2050.92 251.80 -2035.40 1.00 5980829.39 616890.95 N 70.35636493 W 149.05067608
5200.00 20.35 276.84 4631.84 2086.50 256.04 -2070.73 1.00 5980833.06 616855.56 N 70.35637648 W 149.05096298
Ma 5207.74 20.27 276.84 4639.10 2089.19 256.36 -2073.40 1.00 5980833.34 616852.89 N 70.35637736 W 149.05098466
5300.00 19.35 276.84 4725.90 2120.45 260.08 -2104.44 1.00 5980836.57 616821.80 N 70.35638750 W 149.05123672
5400.00 18.35 276.84 4820.54 2152.76 263.93 -2136.52 1.00 5980839.91 616789.66 N 70.35639799 W 149.05149723
Na 5435.33 17.99 276.84 4854.10 2163.78 265.24 -2147.46 1.00 5980841.04 616778.70 N 70.35640156 W 149.05158607
5500.00 17.35 276.84 4915.72 2183.41 267.58 -2166.95 1.00 5980843.07 616759.18 N 70.35640794 W 149.05174434
8-115 (P7) report.xls
Page 2 of 3
11/18/2002-11 :22 AM
Grid Coordinates Geographic Coordinates
I Station ID MD I Incl Azim I TVD VSec Nf-S I Ef-W DLS Northing Easting Latitude I Longitude
(ft) (0) (0) (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS)
Oa 5550.61 16.84 276.84 4964.10 2198.29 269.35 -2181.72 1.00 5980844.61 616744.39 N 70.35641276 W 149.05186429
5600.00 16.35 276.84 5011.43 2212.39 271.03 -2195.73 1.00 5980846.07 616730.35 N 70.35641734 W 149.05197806
5700.00 15.35 276.84 5107.63 2239.70 274.29 -2222.84 1.00 5980848.90 616703.20 N 70.35642622 W 149.05219821
OBd 5727.43 15.07 276.84 5134.10 2246.89 275.14 -2229.99 1.00 5980849.63 616696.03 N 70.35642854 W 149.05225627
5800.00 14.35 276.84 5204.29 2265.32 277.34 -2248.28 1.00 5980851.54 616677.71 N 70.35643453 W 149.05240480
OBf 5815.29 14.19 276.84 5219.10 2269.09 277.79 -2252.02 1.00 5980851.93 616673.97 N 70.35643576 W 149.05243517
Base OBF 5856.51 13.78 276.84 5259.10 2279.05 278.97 -2261.92 1.00 5980852.95 616664.05 N 70.35643898 W 149.05251556
5900.00 13.35 276.84 5301.38 2289.26 280.19 -2272.04 1.00 5980854.01 616653.91 N 70.35644230 W 149.05259774
6000.00 12.35 276.84 5398.87 2311.49 282.84 -2294.12 1.00 5980856.31 616631.80 N 70.35644952 W 149.05277705
6100.00 11.35 276.84 5496.74 2332.02 285.28 -2314.51 1.00 5980858.43 616611.37 N 70.35645617 W 149.05294263 -"
6200.00 10.35 276.84 5594.95 2350.84 287.52 -2333.19 1.00 5980860.37 616592.66 N 70.35646227 W 149.05309432
6300.00 9.35 276.84 5693.48 2367.94 289.56 -2350.17 1.00 5980862.14 616575.65 N 70.35646783 W 149.05323221
6400.00 8.35 276.84 5792.29 2383.32 291.39 -2365.44 1.00 5980863.73 616560.36 N 70.35647282 W 149.05335621
6500.00 7.35 276.84 5891.35 2396.98 293.02 -2379.00 1.00 5980865.14 616546.77 N 70.35647726 W 149.05346633
6600.00 6.35 276.84 5990.64 2408.90 294.44 -2390.84 1.00 5980866.37 616534.91 N 70.35648113 W 149.05356248
6700.00 5.35 276.84 6090.11 2419.09 295.65 -2400.95 1.00 5980867.42 616524.79 N 70.35648443 W 149.05364458
6800.00 4.35 276.84 6189.76 2427.54 296.66 -2409.34 1.00 5980868.30 616516.38 N 70.35648718 W 149.05371271
6900.00 3.35 276.84 6289.53 2434.25 297.46 -2416.01 1.00 5980868.99 616509.70 N 70.35648936 W 149.05376688
7000.00 2.35 276.84 6389.40 2439.22 298.05 -2420.94 1.00 5980869.51 616504.76 N 70.35649096 W 149.05380691
7100.00 1.35 276.84 6489.35 2442.44 298.43 -2424.14 1.00 5980869.84 616501.56 N 70.35649200 W 149.05383290
CM11 THRZ 7194.76 0.40 276.84 6584.10 2443.89 298.60 -2425.57 1.00 5980869.98 616500.12 N 70.35649246 W 149.05384451
7200.00 0.35 276.84 6589.34 2443.92 298.61 -2425.61 1.00 5980869.99 616500.08 N 70.35649249 W 149.05384484
BHRZ I Kalubik 7214.76 0.20 276.84 6604.10 2443.99 298.62 -2425.68 1.00 5980870.00 616500.01 N 70.35649252 W 149.05384540
Target 7234.76 0.00 276.84 6624.10 2444.03 298.62 -2425.71 1.00 5980870.00 616499.98 N 70.35649252 W 149.05384565
TKUP / Kup C 7234.77 0.00 276.84 6624.11 2444.03 298.62 -2425.71 0.00 5980870.00 616499.98 N 70.35649252 W 149.05384565
LCU I Kup B 7324.76 0.00 276.84 6714.10 2444.03 298.62 -2425.71 0.00 5980870.00 616499.98 N 70.35649252 W 149.05384565
KupA 7359.76 0.00 276.84 6749.10 2444.03 298.62 -2425.71 0.00 5980870.00 616499.98 N 70.35649252 W 149.05384565 ----
7429.76 0.00 276.84 6819.10 2444.03 298.62 -2425.71 0.00 5980870.00 616499.98 N 70.35649252 W 149.05384565
TMLV 7429.77 0.00 276.84 6819.11 2444.03 298.62 -2425.71 0.00 5980870.00 616499.98 N 70.35649252 W 149.05384565
7578.76 0.00 276.84 6968.10 2444.03 298.62 -2425.71 0.00 5980870.00 616499.98 N 70.35649252 W 149.05384565
TD I 5-1/2" Csg Pt 7579.76 0.00 276.84 6969.10 2444.03 298.62 -2425.71 0.00 5980870.00 616499.98 N 70.35649252 W 149.05384565
LeQal Description: NorthinQ eV) fftUSl EastinQ eX) fftUSl
8urface : 4406 F8L 4499 FEL 835 T12N R12E UM 5980609.95 618929.92
Target: 4704 F8L 1645 FEL 834 T12N R12E UM 5980870.00 616499.98
BHL: 4704 F8L 1645 FEL 834 T12N R12E UM 5980870.00 616499.98
8-115 (P7) report.xls Page 3 of 3 11/18/2002-11 :22 AM
....-
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VERTICAL SECTION VIEW
Client:
Well:
Field:
Structure:
Section At:
Date:
BP Exploration Alaska
S-115 (P7)
Prudhoe Bay Unit - WOA
S-PAD
277.02 deg
November 18, 2002
Schlumberger
0-
I KOP Ndg 1.Loo
-;/ 250 MD 250TVD
¡..........................................................~~~~~~~~Oj;~............. .............
Cry 2/100
______ 450 MD ~50 TVD
______ . 3.00' 15C.00" az
·3 departu'e
_---- ;; ~~ 00788 TVD
-- 4.00' 300.00" az
2 departure
1000 -
End Cry
1802 MD 1736 TVD
34.05" 276,84" az
326 departure
-SV61664MD16T9TVD -
--------
---------/-
Hold Angle 34.05°
-------
2000 -
-SeSePem, 2õ11MD 1909Ï\tD-
-SV52397 MÕ 2229 TVD -
-0-
-s\I42645 MlJ 2ð11"Jb -
-S~ 3n5~ 2~41'\1D-
=...s'll...3~..MD....2~QJÿO=..
---------
J~
-SV13677 MD 3289 ñÏD -
=
=ilèiÃ4ffi&3~=
--------
""""''''''''''',,,,,,,,,,,,,,,,,,,,,,,,,,.,,,,,,,.,,,,.,,...,..,,,.,,,,,,,,,...
""'UG3'4,iiiiMcr3984lVD ,.,...·1==··0
ð···=····=·······=·······=·····=·=····=····=····=·····.=......=
\J(jf" 5<m M1J 4459 TVD -
5000 ~
1
1
±
1
I
::.
""a~208"Mcr4639ìW
ìNa"-5435"Mcr4854TV1J
joa~O:-496<r1V¡::r......=
.jOSõ 5727 MD" 5~ TVD = j
r~Pò8~~l
I
I
i
. ::O~._O ..~.,=.=
6000 --
i
I
I
i
I
. i
I Target
/ 7235 MD 6624 TVD
I 000" 27684" az
2444 departure
"'"""","',.."""""""-,.,.... ""ib ....""""'Ji,F.,,~ ~ ì= ~ " ::, :: " " " -
=Lc::/~s:32~~7~ ~A~D:p~ = = = = = = = - -
-TMCV'"7430MD681~Õ - - -X I - TD/5-1/2"CsgPt
_ . II. '" ___ m,"".__ . .__. 1580.MD_..696H\lD
Hold Angle 0,00° 000" 276.84" az
1 12444 departure
2000 3000
-
=
7000 -
1
-1 000
1
o
1
1000
Vertical Section Departure at 277.02 deg from (0.0, 0.0). (1 in = 1000 feet)
500
I
o
-1000 -500
EAST »>
-2000 -1500
«< WEST
I
-2500
I
-3000
--1000
-1000 -
True North
Mag Dee ( E 25.850
1000 - - -1000 .--"
^ 3830 MD 3416TVD ~
^ 34.05° 276.84° az
^ ~ ~ _... "'" "~,, '~"'''~ N.·
I :\ ~ i~ / ~~~~ .
I-
~ 500- rli' .\ \- -\...../. ~_n·-l-_n. -500
Z: ¡ EndCrv Crv3/100
. .: 1802 MD 1736 TVD 788 MD 788 TVD
34.05° 276.84° aZ 4.00- 300.00' az
/46N 323W ¡ 68 3W
TD/5-1/2"CsgPI ~"":.. V .--:....'..:. ~",.:,..: / \ ~........... \ ~.:,:..'..,.
7580 MD 6969 TVD . : . ~ . : Cry 2/100
0.00' 276.84' az; : .~ : I! 450 MD
0- , ,,''''''W , . .. 1 un L \. >-ul-\n\ u n=~_n ; . . :~',: -0
I~ KOP Ndg 1.51100
250 MD 250 TVD
I 299 N 2426 W ~.~o 0 ~5O.000 az
I-
:J
o _
C/)
V -500 - - -500
V
V
500
I
o
I
-500
-1000
-1500
I
-2000
-2500
I
-3000
,
Schlumberger
PLAN VIEW
Client: BP Exploration Alaska
Well: 8-115 (P7)
Field: Prudhoe Bay Unit - WOA
Structure: S-PAD
Scale: 1 in = 500 ft
Date: 18-Nov-2002
d
Company:
Field:
Reference Site:
Reference Well:
Reference Wellpath:
BP Amoco
Prudhoe Bay
PB 8 Pad
Plan 8-115
Plan 8~115
)
Schlumberger
Anticollision Report
NO GLOBAL SCAN: Using user defined selection & scan criteria
Interpolation Method: MD Interval: 50.00 ft
Depth Range: 28.50 to 7579.76 ft
Maximum Radius: 3000.00 ft
Survey Program for Definitive Wellpath
Date: 6/19/2002 Validated: No
Planned From To Survey
ft ft
28.50 1200.00 Planned: Plan #7 V1
1200.00 7579.76 Planned: Plan #7 V1
Casing Points
MD
ft
3236.55
7579.76
Summary
<--..-..--....
Site
PB 8 Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB 8 Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
PB S Pad
TVD
ft
2924.50
6969.10
Diameter
in
7.625
5.500
HoleSize
in
Name
9.875
6.750
7 -5/8"
51/2"
- - . Offset W ellpath. ----..~-----..---~->
Well WeUpath
Plan S-109
Plan S-116
Plan S-117
Plan 8-118
S-01A
8-01
8-03
8-100
S-101
S-102
8-102
S-103
S-104
S-105
S-106
S-106
8-107
S-108
S-110
S-111
8-112
8-113
S-113
S-113
S-114
S-114
S-200PB 1
S-200
S-201
8-201
S-202
S-213
S-214
S-216
8-22A
8-22
S-41 L 1
S-41PB1
S-41
8-42PB 1
S-42
S-43L 1
S-43
Plan 8-109 VO Plan: SI
Plan S-116 VO Plan: 8-
Plan S-117 V1 Plan: S-
Plan S-118 VO Plan: S-
S-01A V1
S-01 V1
S-03 V1
S-100 V10
S-101PB1 V9
S-102 V11
8-102PB1 V14
S-103 V6
8-104 VO
8-105 V5
S-106 V2
S-106PB1 V12
8-107 V35
S-108 V6
S-110V18
Plan S-111 V1 Plan: S-
8-112V19
S-113V13
8-113A V2
S-113BV5
S-114V13
S-114A V6
S-200PB1 V4
8-200 V2 Plan: Undefin
S-201 V2
S-201PB1 V11
Plan S-202 VO Plan: S-
S-213 V6
Plan S-214 V1 Plan: 8-
S-216 V1
S-22A V1
S-22 V1
S-41 L 1 V1
S-41PB1 V1
S-41 V1
S-42PB 1 V1
8-42 V2
8-43L 1 V2
S-43 V3
Date: 11/18/2002
)
Time: 11 :57:55
.Page:
Co-ordinate(NE) Reference:
Vertical (TVD) Reference:
Well: PlanS-115, True North
8-115 Plan 64.1
Version:
Toolcode
CB-GYRO-8S
MWD+IFR+MS
Reference
MD
ft
342.83
495.45
544.64
444.41
6813.80
6736.39
5114.31
249.45
399.14
249.89
249.89
1003.32
297.06
1100.00
243.93
243.93
292.70
341.40
392.18
339.84
642.96
243.76
243.76
243.76
291.89
291.89
994.15
994.15
249.68
249.68
298.12
697.74
599.26
452.59
7554.11
7553.84
971.62
971.62
971.62
736.70
736.70
789.89
789.89
Offset
MD
ft
350.00
500.00
550.00
450.00
7200.00
7100.00
5650.00
250.00
400.00
250.00
250.00
1000.00
300.00
1100.00
250.00
250.00
300.00
350.00
400.00
350.00
650.00
250.00
250.00
250.00
300.00
300.00
1000.00
1000.00
250.00
250.00
300.00
700.00
600.00
450.00
7500.00
7500.00
1000.00
1000.00
1000.00
750.00
750.00
800.00
800.00
Reference:
Error Model:
Scan Method:
Error Surface:
Db: 8ybase
Principal Plan & PLANNED PROGRAM
ISCW8A Ellipse
Trav Cylinder North
Ellipse + Casing
Tool Name
Camera based gyro single shots
MWD + IFR + Multi Station
Ctr..Ctr No-Go
Distance· Area
ft ft
61.04 8.04
42.88 10.17
24.33 11.36
12.72 9.75
711.93 457.32
510.45 301.95
801.48 113.33
30.66 5.18
10.66 9.11
46.96 5.65
46.96 5.65
175.53 15.85
240.59 6.60
235.26 18.07
196.04 6.25
196.04 6.33
150.59 6.70
104.10 6.91
73.88 8.98
211.02 8.29
68.59 12.98
136.03 6.00
136.03 5.85
136.03 5.85
211.58 6.82
211.58 6.66
92.93 15.63
92.93 15.74
180.39 5.27
180.39 5.35
90.22 7.35
53.81 10.72
70.27 10.09
90.27 9.56
815.16 116.98
814.52 117.00
241.59 17.08
241.59 17.08
241.59 17.08
218.58 12.84
218.58 12.84
180.07 13.28
180.07 13.36
Allowable
. DeviatIon
ft
53.00
32.72
12.97
2.97
258.73
208.86
694.66
25.48
1.56
41.31
41.31
159.68
233.98
217.20
189.79
189.71
143.88
97.21
64.90
202.73
55.62
130.03
130.19
130.19
204.77
204.93
77.48
77.37
175.13
175.04
82.87
43.14
60.19
80.72
701.02
700.35
224.52
224.52
224.52
205.76
205.76
166.83
166.74
Warning
../
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Pass: Major Risk
Company: BP Amoco
Field: Prudhoe Bay
Reference Site: PB 8 Pad
Reference Well: Plan S-115
Reference Wellpath: Plan 8- t 15
Summary
<~.
Site
----- Offset Wellpatb ~
Well
PB S Pad
PB S Pad
PB S Pad
S-44L 1 PB 1
S-44L 1
S-44
)
. ~ ~->
Wellpatb
8-44L 1 PB 1 V3
8-44L 1 V5
8-44 V10
Schlum berger
Anticollision Report
')
Date: 11/18/2002
Time: .11 :57:55
Page:
2
Co-ordinate(NE) Reference:
Vertical (TVD) Reference:
Well: Plan~~115, True North
8..,115 Plan 64; 1
Db: Sybpse
Reference Offset . Ctr-Ctr No-Go Allowable
MD MD Distance Area Deviation Warning
ft ft ft ft ft
744.46 750.00 153.69 11.95 141.76 Pass: Major Risk
744.46 750.00 153.69 12.04 141.68 Pass: Major Risk
744.46 750.00 153.69 12.04 141.68 Pass: Major Risk
Site: PB S Pad ')
Drilling Target Con£: 99~
Description:
Map Northing: 5980870.00 ft
Map Easting : 616500.00ft
Latitude: 70°21 '23.373N
Shape: Circle
-
Target: S-115 Tl
WeB: Plan S-115
\sed on: Planned Program
Jertical Depth: 6560.00 ft below Mean Sea Level
Local +N/-S: 298.62 ft
Local +E/-W: -2425.69 ft
Longitude: 149°03'13.844W
Radius: 125 ft
500
500
ltOO
300
200
100
0 CJ CJ CJ CJ CJ CJ
o 0 CJ CJ CJ CJ CJ CJ
o 0 ~ LD Ln -=f- (1) N
0 o ( ~ N N N N N N
0 ~ ~ I I I I I I
~ ~
~
H 207134
DATE
INVOICE I CREDIT MEMO
9/20/02 INV# CK091602
(I
cJ-llLJ
THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE.
BP EXPLORATION, (ALASKA) INC.
P.O. BOX 196612
ANCHORAGE, ALASKA 99519·6612
PAY
TO THE
ORDER
OF
DESCRIPTION
PERMIT TO DRILL FEE
TOTAL ~
GROSS
VENDOR
DISCOUNT
RECEIVED
DEC 0 J 2002
IIaslCa Dil & Gas Cons. Commission
Anchorage .
FIRST NATIONAL BANK OF ASHLAND
AN AFFlUATE OF
NATIONAL CITY BANK
CLEVELAND, OHIO
56-389
"""412
B p..... r; ....,.." ,IIßl1fflb. '''l ..""11 ./:,
.. . __ , . . t I' ( 1·1..., 1,.... 'I"
. . ..' - :lJ.J.. IIII' UII" -"',.. .....11. "..,
DATE
SEPT. 20, 2002
DATE
9/20/02
CHECK NO.
H207134
NET
No. H 207134
CONSOLIDATED COMMERCIAL ACCOUNT
AMOUNT
****$100.00****··
~.::J{~'~~~f\t::;~b '/.:DJ;~~'~*;...:~....:.~:\..:.:~...;.:2:~;:/f.:.:~.:.~/~~
-:.... .:. .. .... ~ ·.··~v;;:-····....· :~~.':"",
~{\·.:<:X(. .·':;~?f~\1~PÆj{0~i¡}t;~:;\i
ALASKA OIL & GAS CONSERVATION COMMISSION
333 W. 7th AVE. STE 100
ANCHORAGE, AI< 99501
II· 20 ? ~ 3 ~ II· I: 0 ~ ~ 20 3 a 11 51: 00 a ~ ~ ~ 11 II·
H
-
"'-~
~
)
)
I
TRANSMITAL LETTER CHECK LIST
CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO
BE INCLUDED IN TRANSMITTAL LETTER
WELL NAME
PTD#
CHECK WHAT
APPLIES
ADD-ONS
(OPTIONS)
MULTI
LATERAL
(If API number
last two (2) digits
are between 60-69)
PILOT
(PH)
"CL DE"
The permit is for a new wellbore segment of
existing well
Permit No, API No.
Production should continue to be reported as
a function of the original API number stated
above.
HOLE In accordance with 20 AAC 25.005(f), all
records, data and logs acquired for the pilot
hole must be clearly differentiated in both'
name (name on permit plus PH)
and API number (50
70/80) from records, data and logs acquired
for well (name on permit).
SPACING
EXCEPTION
DRY DITCH
SAMPLE
Rev: 07/10/02
C\jody\templates
The permit is approved subject to full
compliance with 20 AAC 2"5.055. Approval to
perforate and produce is contingent upon
issuance of a conservation order approving a
spacing exception.
(Company Name) assumes the liability of any
protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the .
Commission must be in no greater than 30'
sample intervals from below the permafrost
or from where samples are first caught and
10' sample intervals through target zones.
WELL PERMIT CHECKLIST COMPANY ð fJ X WELL NAME!'ßu S ,.11. ~ PROGRAM: Exp _ Dev £.. Redrll _ Re-Enter _ Serv _ Wellbore seg _
FIELD & POOL C; Gjo/ J- C) INIT CLASS L)~ / ~1 GEOL AREA p- J r~ UNIT# I) t:. r 0. ON/OFF SHORE ~
ADMINISTRATION 1. Permit fee attached. .................. f0 N
2. Lease number appropriate. . . . . . . . . . . . . . . . Y N
3. Unique well name and number. . . . . . . . . . . . . . . . . Y N
4. Well located in a defined pool.. . 0 . . . . . . . . . . . . . 0 Y N
5. Well located proper distance from drilling unit boundary. Y N
6. Well located proper distance from other wells.. . . . . . . . . Y N
7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N
,_ J_} 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N
~ /.4L2,â:~2- 9. Operator only affected party.. . . . . . 0 . . . . . . . . . . . Y N
10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N
11. Permit can be issued without conservation order. . . . . . . . Y N
12. Permit can be issued without administrative approval.. . . . . \J/ N
(Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ Y Y ¡1J A,
(Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . 00 Y N
ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . 0 . . ® N~
16. Surface casing protects all known USDWs. . . . . . .
17. CMT vol adequate to circulate on conductor & surf csg.
18. CMT vol adequate to tie-in long string to surf csg. . . . . 0 . Y gj)
19. CMT will cover all known productive horizons. . 0 . . . . . . @. N
20. Casing designs adequate for C, T, B & permafrost. . . . . . . TJL N .~
21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . (2 N III . 0 h '7 IE ç
22. If a re-drill, has a 10-403 for abandonment been approved. . . ~. ;~/Ir
23. Adequate wellbore separation proposed.. . . . . . . . . . . . Y N
24. If diverter required, does it meet regulations. . . . . . . . . . ( . N /M ..../Ð ~
25. Drilling fluid program schematic & equip list adequate. . . . . N Wi a...y- ",'¡¡J .~. P Pc)
26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ,
27. BOPE press rating appropriate; test to '~500 p sig. N IU <; P Z & -If? 'f Lv ,
~.¡j 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N
W6Á- I ¿Ii¡ 0 l- 29. Work will occur without operation shutdown. . . . . . . . . . . N
30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N -ß ~ 7 () ffO ~ .
(Service Well Only) 31. Mechanical condition of wells within AOR verified. . . . . . . . ~ iJ/k;-
GEOLOGY 6)N
APPR DATE 51
Y. .~ /v.,4J
¡fIL Izh~7
(Exploratory Only)
APPR
DATE
APPR
DATE
32. Permit can be issued wlo hydrogen sulfide measures. . . . .
33. Data presented on potential overpressure zones. . . . . . . .
34. Seismic analysis of shallow gas zones. . . . . . . 0 0 0 . . .
35. Seabed condition survey (if off-shore). . . . . .. ......
36. Contact namelphone for weekly progress reports. ......
GEOLOGY:
RP~
PETROLEUM ENGINEERING:
TEM
RESERVOIR ENGINEERING
JDH
UIC ENGINEER
JBR
COMMISSIONER:
COT J9'/q ~ .;(
DTS /<¡{/O~
MLB /o/~/02....
Rev: 10/15/02
SFD_
/
MJW
WGA
G:\geology\perm its\checklist.doc
(
,
0"
Comments/Instructions:
