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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout194-080Nolan Vlahovich Hilcorp Alaska, LLC
Geotech 3800 Centerpoint Drive, Suite 1400
Anchorage, AK 99503
Tele: (907) 564-4558
E-mail: nolan.vlahovich@hilcorp.com
Please acknowledge receipt by signing and returning one copy of this transmittal.
Received By: Date:
Date: 09/10/2025
To: Alaska Oil & Gas Conservation Commission
Natural Resource Technician
333 W 7th Ave Suite 100
Anchorage, AK 99501
SFTP DATA TRANSMITTAL T#20250910
Well API #PTD #Log Date Log
Company Log Type AOGCC
E-Set#
BRU 213-26T 50283202040000 225038 6/14/2025 AK E-LINE CBL
MPU C-21 50029207530000 182081 7/8/2025 AK E-LINE Caliper
MPU M-62 50029237440000 223006 6/23/2025 READ Caliper Survey
PBU 01-13A 50029202700100 225052 8/17/2025 BAKER MRPM
PBU 01-30A 50029216060100 225050 8/7/2025 BAKER MRPM
PBU 07-24A 50029209450100 225045 8/3/2025 BAKER MRPM
PBU N-12 50029205570000 181014 8/5/2025 BAKER SPN
PBU PSI-09 50029230950000 202124 7/17/2025 HALLIBURTON WFL-TMD3D
Please include current contact information if different from above.
T40860
T40861
T40862
T40863
194-080
T40864
T40865
T40866
T40867
MPU C-21 50029207530000 182081010110 7/8/2025 AK E-LINE Caliper
Gavin Gluyas Digitally signed by Gavin Gluyas
Date: 2025.09.10 11:27:53 -08'00'
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender
and know the content is safe.
From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: NOT OPERABLE: Injector MPU C-21 (PTD# 1940800) Anomalous IA Pressure
Date:Monday, March 14, 2022 3:04:37 PM
Attachments:image001.png
image002.png
image003.png
From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>
Sent: Tuesday, March 8, 2022 1:25 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com>
Subject: NOT OPERABLE: Injector MPU C-21 (PTD# 1940800) Anomalous IA Pressure
Mr. Wallace,
WAG Injector MPU C-21 (PTD# 1940800) is currently on MI service beginning 1/13/22, prior to which the well was offline. The inner annulus was initially bled on 2/6/22 due to what
appeared to be a thermal increase. On 2/9/22 the inner annulus was bled again from 1980 psi to 620 psi, the composition of the bleed was freeze protect fluid. The last AOGCC
witnessed MIT-IA passed to 3770 psi on 9/11/20. A PPPOT-T passed on 2/13/22 to 5000 psi. A MIT-IA failed on 2/18/22 and the well was shut in. The well is now classified as NOT
OPERABLE for tubing by annulus communication.
Plan Forward
1. Set TTP
2. CMIT-TxIA
3. MIT-IA
4. Engineer to evaluate further diagnostic and repair
Jerimiah Galloway
MPU/Islands Well Integrity Engineer
Email: jerimiah.galloway@hilcorp.com
O: (907)564-5005
C: (828)553-2537
From: Jerimiah Galloway
Sent: Wednesday, February 9, 2022 1:18 PM
To: Wallace, Chris D (CED <chris.wallace@alaska.gov>; Regg, James B (CED <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com>
Subject: UNDER EVALUATION: Injector MPU C-21 (PTD# 1940800) Anomalous IA Pressure
Mr. Wallace,
WAG Injector MPU C-21 (PTD# 1940800) is currently on MI service beginning 1/13/22, prior to which the well was offline. The inner annulus was initially bled on 2/6/22 due to what
appeared to be a thermal increase. On 2/9/22 the inner annulus was bled again from 1980 psi to 620 psi, the composition of the bleed was freeze protect fluid. The last AOGCC
witnessed MIT-IA passed to 3770 psi on 9/11/20. Recent MI injection rate and pressure changes make the source of the IA pressure unclear at this time and additional monitoring is
required. The well is now classified as UNDER EVALUATION for anomalous inner annulus pressure. The well will remain online in steady state while initial diagnostics are conducted.
It is now on a 28 day clock for diagnostics and resolution.
Plan Forward:
1. PPPOT-T
2. Monitor and evaluate Inner Annulus repressurization rate.
3. Engineer to evaluate additional diagnostics
Jerimiah Galloway
MPU/Islands Well Integrity Engineer
Email: jerimiah.galloway@hilcorp.com
O: (907)564-5005
C: (828)553-2537
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message.
While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate.
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From:Wallace, Chris D (OGC)
To:AOGCC Records (CED sponsored)
Subject:FW: UNDER EVALUATION: Injector MPU C-21 (PTD# 1940800) Anomalous IA Pressure
Date:Wednesday, February 9, 2022 1:40:26 PM
Attachments:image001.png
image002.png
From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com>
Sent: Wednesday, February 9, 2022 1:18 PM
To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com>
Subject: UNDER EVALUATION: Injector MPU C-21 (PTD# 1940800) Anomalous IA Pressure
Mr. Wallace,
WAG Injector MPU C-21 (PTD# 1940800) is currently on MI service beginning 1/13/22, prior to which the well was offline. The inner annulus was initially bled on 2/6/22
due to what appeared to be a thermal increase. On 2/9/22 the inner annulus was bled again from 1980 psi to 620 psi, the composition of the bleed was freeze protect
fluid. The last AOGCC witnessed MIT-IA passed to 3770 psi on 9/11/20. Recent MI injection rate and pressure changes make the source of the IA pressure unclear at this
time and additional monitoring is required. The well is now classified as UNDER EVALUATION for anomalous inner annulus pressure. The well will remain online in steady
state while initial diagnostics are conducted. It is now on a 28 day clock for diagnostics and resolution.
Plan Forward:
1. PPPOT-T
2. Monitor and evaluate Inner Annulus repressurization rate.
3. Engineer to evaluate additional diagnostics
Jerimiah Galloway
MPU/Islands Well Integrity Engineer
Email: jerimiah.galloway@hilcorp.com
O: (907)564-5005
C: (828)553-2537
The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this
message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender'sphone number is listed above, then promptly and permanently delete this message.
MEMORANDUM
TO: Jim Regg
P.I. Supervisor 71er C]� C-4/zoo
FROM: Matt Herrera
Petroleum Inspector
Well Name MILNE PT UNIT C-21
Insp Num: mitMFH2O0912084429
Rel Insp Num:
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Wednesday, September 16, 2020
SUBJECT: Mechanical Integrity Tests
Hilcorp Alaska, LLC
C-21
MILNE PT UNIT C-21
API Well Number 50-029-22486-00-00
Permit Number: 194-080-0
Packer Depth Pretest Initial
Well'T C-21 Type Inj w '1TVD 7017 Tubing 2565 2567
PTD 1940800 :Type Test, SPT' Test psi 3500 IA 1191 3846
BBL Pumped: li 4.6 IBBL Returned: 4.4 Op �ss3 895 -
Interval INITAL P/F P
Notes: Well is a Producer converted to Injector Initial MIT performed to 3500 psi Per Sundry 320-193
Src: Inspector
Reviewed By:
P.I. Supry
Comm
Inspector Name: Matt Herrera
Inspection Date: 9/11/2020
15 Min 30 Min 45 Min 60 Min
2568 - 2566
3790 3772 - �-
890 885 ,
Wednesday, September 16, 2020 Page 1 of I
MEMORANDUM
TO: Jim Regg�,
P.I. Supervisor [ 111
FROM: Jeff Jones
Petroleum Inspector
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Monday, September 14, 2020
SUBJECT: Mechanical Integrity Tests
Hilcorp Alaska, LLC
C-21
MIINE PT UNIT C-21
Src: Inspector
Reviewed By:
P.I. Supry
Comm
Well Name MILNE PT UNIT C-21 API Well Number 50-029-22486-00-00 Inspector Name: Jeff Jones
Insp Num: mitJJ200911113045 Permit Number: 194-080-0 Inspection Date: 9/7/2020 -
Rel Insp Num:
Packer Depth Pretest
Initial 15 Min 30 Min 45 Min 60 Min
Well C-21
_ -_ _—_ _
- "T ype InJ w • ITVD 1 7017 Tubing 2596-
�T
_ _ _
2600 -L 2599 - � 2600 -
PTD i 19aosoo
a Testr—
yP Test psi 1754 IA 1164
— — --
3215 3146 • 3]28'
BBL Pumped
3.8 ` ;BBI. Returned: __-3.8 A 706
966 954 944
L
OTHERnterval, �P/F L P
_1
- ---
Notes' I well inspected. Post -conversion to injector test as per Sundry 320-193; did not meet test criteria of 3500 psi.
6W t heyeg-
Monday, September 14, 2020 Page I of 1
MEMORANDUM
TO: Jim Regg��
P.I. Supervisor
FROM: Jeff Jolles
Petroleum Inspector
NON -CONFIDENTIAL
State of Alaska
Alaska Oil and Gas Conservation Commission
DATE: Thursday, August 20, 2020
SUBJECT: Mechanical Integrity Tests
Hilcorp Alaska, LLC
C-21
MILNE PT UNIT C-21
Sre: Inspector
Reviewed By:
P.I. Supry
Comm
Well Name MILNE PT UNIT C-21 API Well Number 50-029-22486-00-00 Inspector Name: JeffJones
Permit Number: 194-080-0 Inspection Date: 7/7/2020
Insp Num: mitJJ200720105315
Rel Insp Num:
Packer Depth Pretest Initial
15 Min 30 Min 45 Min 60 Min
Well C-21 Type Inj N -'TVD 7017 Tubing' 178 179 -
179 - 179 -
PTD
! 1940800
Type yp Test SPT
Test psi
3500
IA
158
� 3703 -
3619
3588 -
BBL Pumped. 6.9 BBL Returned: 6.9 OA 0 44
45 - 43
Interval INITAL IP/F P ✓
Notes: Conversion to injection; 3500 psi test per Sundry 320-193
Thursday, August 20, 2020 Page 1 of I
1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown
Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program
Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Convert to Injector
Hilcorp Alaska Development Exploratory
Stratigraphic Service 6. API Number:
7. Property Designation (Lease Number): 8. Well Name and Number:
9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s):
11. Present Well Condition Summary:
Total Depth measured 12,862 feet 12,755 feet
true vertical 7,601 feet 12,352 feet
Effective Depth measured 12,755 feet 12,201 & 12,356 feet
true vertical 7,602 feet 7,017 & 7,153 feet
Perforation depth Measured depth See Schematic feet
True Vertical depth See Schematic feet
2-7/8" 6.5 / L-80 / EUE 8rd 12,252' 7,062'
Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3 / L-80 / EUE 8rd 12,386' 7,179'
Baker S-3
Packers and SSSV (type, measured and true vertical depth) Baker Model D N/A See Above N/A
12. Stimulation or cement squeeze summary: N/A
Intervals treated (measured):
Treatment descriptions including volumes used and final pressure: N/A
13.
Prior to well operation:
Subsequent to operation:
15. Well Class after work:
Daily Report of Well Operations Exploratory Development Service Stratigraphic
Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL
Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG
Sundry Number or N/A if C.O. Exempt:
Chad Helgeson
Contact Name:
Authorized Title:Operations Manager
Contact Email:
Contact Phone:
2. Operator Name
Senior Engineer: Senior Res. Engineer:
Collapse
N/A
3,090'
Burst
N/A
5,750'
7,240'
777-8343
13-3/8"
9-5/8"
7"
4,769'
7,582' 5,410'
Casing
Conductor
Length
112'
8,002'
12,812'
Surface
Production
MILNE PT UNIT C-21
14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283)
0
Gas-Mcf
750
Casing Pressure Tubing Pressure
0
N/A
measured
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
320-193
0
Authorized Signature with date:
Authorized Name:
David Haakinson
dhaakinson@hilcorp.com
710
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
194-080
50-029-22486-00-00
Plugs
ADL0047434 & ADL0355017
5. Permit to Drill Number:
MILNE POINT / KUPARUK RIVER OIL
Junk measured
3800 Centerpoint Dr, Suite 1400
Anchorage, AK 99503
3. Address:
4. Well Class Before Work:
0
Representative Daily Average Production or Injection Data
00
0
Oil-Bbl
measured
true vertical
Packer
Size
N/A
WINJ WAG
0
Water-Bbl
MD
112'
8,032'
12,841'
TVD
112'
Form 10-404 Revised 3/2020 Submit Within 30 days of Operations
By Jody Colombie at 8:54 am, Jul 23, 2020
Chad A Helgeson
2020.07.23
08:34:54 -08'00'
MGR23JUL2020 DSR-7/23/2020 RBDMS HEW 7/23/2020
_____________________________________________________________________________________
Revised By: TDF 7/22/2020
SCHEMATIC
Milne Point Unit
Well: MP C-21
Last Completed: 1/1/2003
PTD: 194-080
TD =12,862’ (MD) / TD =7,601’(TVD)
Initial KB Elev.: 46’
RKB – THF: (29.00’ for Nabors 4ES)
7”
4
8
9
10
16
15
12 & 13
9-5/8”
2
11
15
MIN ID = 2.2 05”
@ 12,239’
FISH:8/14/1996
2 Flat guards,
±15 flat bands &
1 preformed guard.
PBTD =12,755’(MD) / PBTD =7,506’(TVD)
6
13-3/8”
7
1
3
5
FISH:6/07/2008
2.0” roller bogey
wheel & pin lost
off of slickline
KUP C1/B6
KUP B6/A3/A2/A1
14
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8” Conductor 54.5# / K-55 / N/A N/A” Surface 112’ N/A
9-5/8" Surface 40# / L-80 / BTC 8.835” Surface 8,032’ 0.0758
7" Production 26# / L-80 / BTC 6.276” Surface 12,841’ 0.0383
TUBING DETAIL
2-7/8" Tubing 6.5# / L-80 / EUE 8rd 2.441” Surface 12,252’ 0.0058
3-1/2" Tubing 9.3# / L-80 / EUE 8rd 2.992” 12,352 12,386’ 0.0087
JEWELRY DETAIL
No Depth Item
GLM Detail –2-7/8” x 1” KBMG w/ BK Latches
12,562’STA 7: Port= 0, Dev.= 52, TVD= 2,263’,DGLV 4/18/2020
25,836’STA 6: Port= 0, Dev.= 63, TVD= 3,784’,DGLV 4/20/2020
38,415’STA 5: Port= 0, Dev.= 65, TVD= 4,930’,DGLV 4/20/2020
4 10,197’STA 4: Port= 0, Dev.= 63, TVD= 5,712’,DGLV 4/22/2020
5 11,259’STA 3: Port= 0, Dev.= 47, TVD= 6,276’,DGLV 4/22/2020
6 11,758’STA 2: Port= 0, Dev.= 37, TVD= 6,647’,DGLV 4/22/2004
7 12,131’STA 1: Port= 0, Dev.= 31, TVD= 6,956’,DGLV 4/22/2020
8 12,189’ 2-7/8” X Nipple, ID= 2.313”
9 12,201’ Baker S-3 Packer, ID= 3.875”
10 12,239’ 2-7/8” XN Nipple,Min ID= 2.205”
11 12,251’ 2-7/8” WLEG -Bottom @12,252’
12 12,352’ 3-1/2” Camco LLC Valve w/ Baker Model E Seal Assembly (stabbed in pkr)
13 12,356’ Baker Model D Packer Size 84-32, ID = 2.406”
14 12,362’ 3-1/2” Baker Weld Screen (20’ long, 20 gauge)
15 12,383’ 3-1/2” Camco D Nipple, ID = 2.750”
16 12,385’ 3-1/2” WLEG -Bottom @12,386’
PERFORATION DETAIL
KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Status Size
C1/B6 12,370’ 12,420’ 7,165’ 7,209’ 50 7/94 Open 3-3/8”
B6/A3/A2/A1 12,502’ 12,626’ 7,282’ 7,391’ 124 7/94 Open 3-3/8”
Ref Log: DIL 7/5/1994. Guns: 5spf as per 10-407 sundry
OPEN HOLE / CEMENT DETAIL
13-3/8" 250 sx Arcticset I in 24” Hole
9-5/8" 1,542 sx PF ‘E’ & 250 sx ‘G’ in 12-1/4” Hole
7” 210 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 350’
Max Hole Angle = 63° to 65° f/ 3,200’ to 10,400’
Max Hole Angle thru perforations= 62.8°
TREE & WELLHEAD
Tree 2-9/16” – 5M FMC
Wellhead 11” 5M FMC Actuator
GENERAL WELL INFO
API: 50-029-22486-00-00
Drilled and Cased – 7/1/1994
Completed – 7/28/1994
RWO ESP Nabors 4ES - 8/14/1996
Completion - CTU – 8/14/2000
Convert to GL by Nabors 4ES – 1/1/2003
Convert to WAG by LRS – 7/7/2020
STIMULATION SUMMARY
7/12/94 – 416,200lbs, 60M# of 20/40 followed by
356,200lbs, 16/20. Job went to full flush
CAUTION
2.0” Roller and 1-1/2” x .375 roll pin lost in wellbore.
Depth unknown. Drawing in well file, 6/7/2008
Well Name Rig API Number Well Permit Number Start Date End Date
MP C-21 LRS 50-029-22486-00-00 194-080 6/24/2020 7/7/2020
6/26/2020 - Friday
No operations to report.
6/24/2020 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
Circ IA/MIT-IA to 3,500 psi (Producer to Injector) (Pressure test equipment 250/4,000 psi) Pump 285 bbls 1% Corrision Inb.
Water and 75 bbls Dsl down IA taking returns up Tbg down Flowline. Pump 10 bbls Dsl down IA// Did not reach test
pressure. Bleed Tbg down to 514 psi. Monitor for 30 Min. 1st 15 Min TxIA gained 2 / 23 psi. 2nd 15 Min TxIA Tbg lost 0 psi
and IA lost 3 psi. Bleed IA/ All gas.
6/25/2020 - Thursday
No operations to report.
No operations to report.
No operations to report.
6/27/2020 - Saturday
No operations to report.
6/30/2020 - Tuesday
6/28/2020 - Sunday
WELL S/I ON ARRIVAL, NOTIFY PAD-OP, PT PCE 250L/4,000H. BLED IA TO 0 & ASSISTED LRS MIT THE IA (pass).
RAN 2.1" CENT, 2-7/8" GS CORE, 2-7/8" X-EQ PRONG & EQUALIZED XXN PLUG @ 12,232' SLM (12,239' MD), SAW 2,400psi
PRESSURE DROP ON TUBING, CLEAR RING ON EQ PRONG. PULLED 2-7/8" XXN PLUG FROM XN NIPPLE @ 12,232' SLM
(12,239' MD), BOTH NUBBINS RECOVERED, MISSING 1.5" PEICE OF V-PACKING. WELL S/I ON DEPARTURE, DSO NOTIFIED.
6/29/2020 - Monday
Well Name Rig API Number Well Permit Number Start Date End Date
MP C-21 LRS 50-029-22486-00-00 194-080 6/24/2020 7/7/2020
7/3/2020 - Friday
No operations to report.
7/1/2020 - Wednesday
Hilcorp Alaska, LLC
Weekly Operations Summary
No operations to report.
7/2/2020 - Thursday
No operations to report.
AOGCC Witnessed (Jeff Jones)MIT IA. (Pressure test equipment 313/3,672 psi) MIT IA pass @ 3,588. Pumped 6.9 bbls diesel
down IA to achieve test pressure. 1st 15 min lost 84 psi. 2nd 15 min lost 31 psi, Bled back ~ 6.9 bbl. Hang tags.
No operations to report.
7/4/2020 - Saturday
No operations to report.
7/7/2020 - Tuesday
7/5/2020 - Sunday
No operations to report.
7/6/2020 - Monday
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown
Suspend Perforate Other Stimulate Pull Tubing Change Approved Program
Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to Injector
2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number:
Hilcorp Alaska LLC Exploratory Development
3. Address: Stratigraphic Service
6. API Number:
3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503
7. If perforating:8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
Will planned perforations require a spacing exception? Yes No
9. Property Designation (Lease Number): 10. Field/Pool(s):
11.
Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD):
12,862'12,352'
Casing Collapse
Conductor N/A
Surface 3,090psi
Production 5,410psi
Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft):
12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work:
Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service
14. Estimated Date for 15. Well Status after proposed work:
Commencing Operations: OIL WINJ WDSPL Suspended
16. Verbal Approval: Date: GAS WAG GSTOR SPLUG
Commission Representative: GINJ Op Shutdown Abandoned
Chad Helgeson Contact Name: Stan Porhola
Operations Manager Contact Email:
Contact Phone: 777-8412
Date: 5/5/2020
Conditions of approval: Notify Commission so that a representative may witness Sundry Number:
Plug Integrity BOP Test Mechanical Integrity Test Location Clearance
Other:
Post Initial Injection MIT Req'd? Yes No
Spacing Exception Required? Yes No Subsequent Form Required:
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:
Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng
Authorized Signature:
5/15/2020
2-7/8"
Perforation Depth MD (ft):
See Schematic
Baker S-3 & Baker Model D and N/A
N/A
Tubing Size: Tubing Grade:
8,002'
12,812'
5,750psi
112' 13-3/8"
12,755'
MILNE PT UNIT C-21
PRESENT WELL CONDITION SUMMARY
112' 112'
See Schematic
Perforation Depth TVD (ft):
9-5/8"
7" 12,841'
12,252'
MDLength Size
7,240psi
4,769'
7,582'
8,032'
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
20 AAC 25.280
ADL0047434
194-080
COMMISSION USE ONLY
Authorized Name:
7,601' 12,755' 7,602' 575
6.5# / L-80 / EUE 8rd
12,201MD / 7,017TVD & 12,356MD / 7,153TVD and N/A
Authorized Title:
17. I hereby certify that the foregoing is true and the procedure approved herein will not
be deviated from without prior written approval.
50-029-22486-00-00
C.O. 432D
MILNE POINT / KUPARUK RIVER OIL
Tubing MD (ft):
sporhola@hilcorp.com
TVD Burst
Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval.
Chad A Helgeson
2020.05.05
19:21:38 -05'00'
By Samantha Carlisle at 4:58 pm, May 05, 2020
320-193
10-404
DLB 05/06/2020
DSR-5/6/2020
; ADL0355017 (T.D.)
WAG
pre/post injection MITsX
AOR included in attachments. DLB
X
Convert to Injector
DLB
gls 5/6/20
Comm
q Yes
5/7/2020
dts 4/7/2020
JLC 5/7/2020
Well Prognosis
Well: MPU C-21
Date: 05/05/2020
Well Name:MPU C-21 API Number:50-029-22486-00
Current Status:SI Oil Well Pad:C-Pad
Estimated Start Date:May 20
th, 2020 Rig:N/A
Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd:
Regulatory Contact:Tom Fouts Permit to Drill Number:194-080
First Call Engineer:Stan Porhola (907) 777-8412 (O) (907) 331-8228 (M)
Second Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M)
AFE Number:2021800 Job Type:Convert to WAGInjector
Current Bottom Hole Pressure: 1,275 psi @ 7,000’ TVD (SBHPS 4/09/2020 / 3.50 ppg EMW)
Maximum Expected BHP:1,275 psi @ 7,000’ TVD (No new perfs being added)
MPSP:575 psi (0.1 psi/ft gas gradient)
Brief Well Summary:
MPU C-21 was drilled and completed in July 1994 as an ESP lifted Kuparuk producer completed with
perforations in the Kuparuk C1/B6/A3/A2/A1 sands. A workover in August 1996 replaced the ESP. A workover
in August 2000 installed a coil tubing ESP inside the existing ESP. The coil tubing ESP and tubing ESP were
replaced in January 2003 with Nabors 4ES and a gaslift completion was installed.
Notes Regarding Wellbore Condition
x 7” casing tested to 3,500 psi for 30 minutes down to the packer on 01/01/2003.
x 2-7/8” tubing test to 2,800 psi for 30 min down to tbg tail plug on 4/12/2020.
x Max deviation at 8,223’ MD is 65.39°.
x Well has a history of hydrates that affects freezing off of the tubing while on gaslift.
x Packer is less than 200’ MD from perforations per 20AAC25.412(b).
x All GLMs will be dummied off.
AOR (status of wells within 1/4 mile radius of injection zone):
API Well No Permit Well Current
Status Zonal isolation (method)
50-029-22486-00-00 194-080 MPU C-21 Idle
Producer
Estimated TOC (calculated) at 11,500’MD
~890’ above Kuparuk C1 sand
Objective:
The purpose of this work/sundry is to convert this well from a SI Kuparuk producer to a Kuparuk WAG (Water
Alternating Gas) injector to provide waterflood and gasflood support for offset producers MPU C-09 (PTD 185-
036) and MPU C-43 (PTD 204-039).
Surface Procedure:
1. MIRU Little Red Pumping Unit. PT lines to 4,000 psi.
2. Test 7” casing to 3,500 psi for 30 min (charted).
I concur, the well produced continuously until early 2017 at which
time production was ~40 BOPD. Several attempts to produce the
well since then have had similar results. DSR-5/6/2020
Well Prognosis
Well: MPU C-21
Date: 05/05/2020
a. Notify AOGCC Inspector at least 24 hours prior to conducting pre-injection MIT-IA.
b. Record on 10-426 form.
c. Email to sporhola@hilcorp.com for submission to AOGCC.
3. MU surface lines from injection header to existing tree. PT lines to 4,000 psi.
a. Pressure test lines at existing water injection header pressure (3,500 psi).
b. Pressure test lines at existing gas injection header pressure (4,000 psi).
c. Setup SSV system for water and gas injection.
4. Turn well over to operations for injection startup.
5. After stabilized injection, conduct an MIT-IA to 3,500 psi.
a. Notify AOGCC Inspector at least 24 hours prior to conducting MIT-IA.
b. Record on 10-426 form.
c. Email to sporhola@hilcorp.com for submission to AOGCC.
Attachments:
1. Proposed Schematic
2. Area of Review (AOR) Summary
3. Area of Review Map
4. Surface Owner Affidavit
5. Surface Map Exhibit A
Notify AOGCC Inspector at least 24 hours prior to conducting pre-injection MIT-IA.
Notify AOGCC Inspector at least 24 hours prior to conducting MIT-IA.
_____________________________________________________________________________________
Revised By: STP 5/05/2020
PROPOSED
Milne Point Unit
Well: MP C-21
Last Completed: 1/1/2003
PTD: 194-080
TD =12,862’ (MD) / TD =7,601’(TVD)
Initial KB Elev.: 46’
RKB – THF: (29.00’ for Nabors 4ES)
7”
4
8
9
10
16
15
12 & 13
9-5/8”
2
11
15
MIN ID = 2.2 05”
@ 12,239’
FISH:8/14/1996
2 Flat guards,
±15 flat bands &
1 preformed guard.
PBTD =12,755’(MD) / PBTD =7,506’(TVD)
6
13-3/8”
7
1
3
5
FISH:6/07/2008
2.0” roller bogey
wheel & pin lost
off of slickline
KUP C1/B6
KUP B6/A3/A2/A1
14
CASING DETAIL
Size Type Wt/ Grade/ Conn ID Top Btm BPF
13-3/8” Conductor 54.5# / K-55 / N/A N/A” Surface 112’ N/A
9-5/8" Surface 40# / L-80 / BTC 8.835” Surface 8,032’ 0.0758
7" Production 26# / L-80 / BTC 6.276” Surface 12,841’ 0.0383
TUBING DETAIL
2-7/8" Tubing 6.5# / L-80 / EUE 8rd 2.441” Surface 12,252’ 0.0058
3-1/2" Tubing 9.3# / L-80 / EUE 8rd 2.992” 12,352 12,386’ 0.0087
JEWELRY DETAIL
No Depth Item
GLM Detail –2-7/8” x 1” KBMG w/ BK Latches
1 2,562’STA 7: Port= 0, Dev.= 52, TVD= 2,263’,DGLV 4/18/2020
2 5,836’STA 6: Port= 0, Dev.= 63, TVD= 3,784’,DGLV 4/20/2020
3 8,415’STA 5: Port= 0, Dev.= 65, TVD= 4,930’,DGLV 4/20/2020
4 10,197’STA 4: Port= 0, Dev.= 63, TVD= 5,712’,DGLV 4/22/2020
5 11,259’STA 3: Port= 0, Dev.= 47, TVD= 6,276’,DGLV 4/22/2020
6 11,758’STA 2: Port= 0, Dev.= 37, TVD= 6,647’,DGLV 4/22/2004
7 12,131’STA 1: Port= 0, Dev.= 31, TVD= 6,956’,DGLV 4/22/2020
8 12,189’ 2-7/8” X Nipple, ID= 2.313”
9 12,201’ Baker S-3 Packer, ID= 3.875”
10 12,239’ 2-7/8” XN Nipple,Min ID= 2.205”
11 12,251’ 2-7/8” WLEG -Bottom @12,252’
12 12,352’ 3-1/2” Camco LLC Valve w/ Baker Model E Seal Assembly (stabbed in pkr)
13 12,356’ Baker Model D Packer Size 84-32, ID = 2.406”
14 12,362’ 3-1/2” Baker Weld Screen (20’ long, 20 gauge)
15 12,383’ 3-1/2” Camco D Nipple, ID = 2.750”
16 12,385’ 3-1/2” WLEG -Bottom @12,386’
PERFORATION DETAIL
KUP Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) FT Shot Date Status Size
C1/B6 12,370’ 12,420’ 7,165’ 7,209’ 50 7/94 Open 3-3/8”
B6/A3/A2/A1 12,502’ 12,626’ 7,282’ 7,391’ 124 7/94 Open 3-3/8”
Ref Log: DIL 7/5/1994. Guns: 5spf as per 10-407 sundry
OPEN HOLE / CEMENT DETAIL
13-3/8" 250 sx Arcticset I in 24” Hole
9-5/8" 1,542 sx PF ‘E’ & 250 sx ‘G’ in 12-1/4” Hole
7” 210 sx Class “G” in 8-1/2” Hole
WELL INCLINATION DETAIL
KOP @ 350’
Max Hole Angle = 63° to 65° f/ 3,200’ to 10,400’
Max Hole Angle thru perforations= 62.8°
TREE & WELLHEAD
Tree 2-9/16” – 5M FMC
Wellhead 11” 5M FMC Actuator
GENERAL WELL INFO
API: 50-029-22486-00-00
Drilled and Cased – 7/1/1994
Completed – 7/28/1994
RWO ESP Nabors 4ES - 8/14/1996
Completion - CTU – 8/14/2000
Convert to GL by Nabors 4ES – 1/1/2003
STIMULATION SUMMARY
7/12/94 – 416,200lbs, 60M# of 20/40 followed by
356,200lbs, 16/20. Job went to full flush
CAUTION
2.0” Roller and 1-1/2” x .375 roll pin lost in wellbore.
Depth unknown. Drawing in well file, 6/7/2008
NOTE: all GLM
with DV installed
MIT-IA
3500 psi
WAG injector
Area of Review Summary – Milne Point Unit C-21 (PTD 194-080)
This Area of Review is required prior to the conversion of well MPU C-21 from a producer to a
water-alternating gas (WAG) injector. This AOR discusses wells with ¼ mile of the well’s entry
point into the Kuparuk Formation C1 sand (top of the injection zone) to the bottom of MPU C-21
well bore completion.
Figure 1: Map showing wells within ¼ mile radius from MPU C-21.
The list of all operators and surface owners within ¼ mile of MPU C-21 is below:
# Operators # Surface Owners
1 Hilcorp Alaska, LLC 1 Alaska Department of Natural Resources (ADNR)
Table 1: List of operators and surface owners
An affidavit has been submitted to the following operators and surface owners:
# Operators # Surface Owners
1 N/A 1 Alaska Department of Natural Resources (ADNR)
Table 2: List of operators and surface owners receiving an affidavit
No other wellbore enters the Kuparuk formation just outside this area of review. The wellpath of
MPU C-25 (PTD 196-001) penetrates the ¼ mile circle, but well above the Kuparuk Reservoir in
the Colville Shales between 5,409’ to 6,131’ TVD (as noted on the blue line in Figure 1). The
tables below illustrate the completion details, and annulus integrity/cement conditions based on
in-depth review of just MPU C-21:
Well Name PTD Distance
(Feet)
Annulus Integrity
MPU C-21 194-080 0 TOC estimated at 11,500’ MD –based on volume pumped
Table 3: Distance and annulus integrity of wells within AOR
Well
Name
Casing Hole
Size
Vol. of Cement Kuparuk depth
(MD)
Kuparuk depth
(TVDss)
MPU C-21 7” 8-1/2” 43 bbls 12,390’ 7,137’
Table 4: Completion Detail
Well MPU C-21 was completed in July 1994. The completion enters the Kuparuk C-sand at
12,390’ MD. A 9-5/8” surface casing was run to 8,032’ MD and cemented the casing with 250 sks
of Class “G” cement. No returns of cement were seen at surface after the plug was bumped. A top
job with 93 sks of Class “C” was performed. Before drilling out the float collar and shoe track, the
casing was tested to 2,500 psi for 30 minutes. A 7” production casing string was run from surface
to 12,841’ MD. The production casing string was cemented with 43 bbls of 15.8 ppg Class “G”
cement. Plugs bumped with floats holding, and the estimated top of cement at 11,500’ MD. The
7” production casing was tested to 3,500 psi for 30 minutes most recently after setting a gaslift
completion string during a workover in 2003.
The injection zone is bracketed by a north-south fault to the east and an east-west fault to the north,
isolating this pattern from the rest of the field (See Figure 1).
Withdrawal and injection volumes and reservoir pressures indicate this area is hydraulically
isolated. This hydraulic unit is referred to as HU-4L (BP Nomenclature) or Block A3 (Hilcorp
Nomenclature).
The original reservoir pressure in this hydraulic unit was 10.0 ppg EMW as of 1985 from well
MPU C-08 (PTD 185-014), in the southern part of the hydraulic unit. This well is currently an
active WAG injector.
CBL was
not run.
ppgg
The production casing string was cemented with 43 bbls of 15.8 ppg Class “G”p g g ppg
cement. Plugs bumped with floats holding, and the estimated top of cement at 11,500’ MD. The
7” production casing was tested to 3,500 psi for 30 minutes
The current reservoir pressure in MPU C-21 as of April 2020 is approximately 3.5 ppg EMW,
based on a recent static survey, showing significant depletion at the eastern edge of this hydraulic
unit.
The offset producer MPU C-09 (PTD 185-036) current reservoir pressure as of May 2019 was 5.2
ppg EMW.
The other offset producer MPU C-43 (PTD 204-039) current reservoir pressure as of August 2019
was 3.85 ppg EMW.
34
3 7777007
757755
74507
4
2
5
74
0
0
00
7
37573757350
73257300
72
7
572757 2 5 0
72257 2 0 0
7 1 7 5
7 1 50
712 5 72-7,059-6 ,9 6 6
-7 ,1 9 0-7 ,0 3 6
-7 ,1 3 7
-7 ,2 5 4
-7,243
-7 ,1 3 9-7 ,1 4 1
-7,231
7777
7
7 ,1 3 737711737711717777777177777717777177711
77777777555
C-04
C-07
C-09
C-12
C-19
C-21
C-25
C-25A
C-43
3L1-01
L-16
HILCORP ALASKA LLC
Milne Point
AOR MAP - WELL MPU C-21
0.25 MILE RADIUS CIRCLE IN RED
KUPARUK C TOPS (TVDSS)
POSTED WELL DATAWell Number
SYMBOL HIGHLIGHT
WELL SYMBOLS
Active Oil
D&A
INJ Well (Water Flood)
Abandoned Injector
Shut In INJ
By: RAG
FEET
01,500
March 17, 2020
PETRA 3/17/2020 9:51:11 AM
0.25 mile circle radius centered at top Kuparuk
reservoir marker in well C-21 (12,390' MD / -7,137'
TVDSS).
Intersects C-25 well path (blue highlight) in the
Colville Shale, between:
- Point A (top) 10,844' MD / -5,409' TVDSS
- Point B (base) 12,891' MD / -6,131
Point A
Point B
Hilcorp Alaska, LLC Post Office Box 244027
Anchorage, AK 99524-4027
3800 Centerpoint Drive
Suite 1400
Anchorage, AK 99503
Phone: 907/777-8412
sporhola@hilcorp.com
May 5, 2020
Tom Stokes, Director
Division of Oil & Gas
Alaska Department of Natural Resources
550 W. 7th Avenue/Ste. 1100
Anchorage AK 99501-3563
Re: Notice of Conversion to Injection Operation – Milne Point Unit MPU C-21
Dear Mr. Stokes,
Hilcorp Alaska, LLC (“Hilcorp Alaska”), as Operator of the Milne Point Unit, has recently submitted
an application to the Alaska Oil and Gas Conservation Commission (“AOGCC”) to allow for the
conversion to injector of Milne Point Unit Well MPU C-21. The surface of the well is located on ADL
047434 and the bottom hole location falls on ADL 047434.See attached map (Exhibit A).
Hilcorp and our joint working interest owner, BP Alaska Exploration, Inc. (“BPXA”), own all
applicable leases within the MPU. The State of Alaska, Department of Natural Resources is the sole
landowner and surface owner. There are no other affected landowners, owners or operators within a
¼ mile radius of the well.
Sincerely,
Chad Helgeson, Operations Manager,
HILCORP ALASKA, LLC
Attached – Exhibit A
CC: John Dittrich, BPXA (via email John.dittrich@bp.com)
Landowner Notification Letter
MPC-21
Page 2 of 2
VERIFIATION OF NOTICE
PER 20 AAC 25.402(c)(3)
MILNE POINT UNIT
MPU C-21
I, Chad Helgeson, Operations Manager do hereby verify the following:
I am acquainted with Hilcorp Alaska, LLC’s application for sundry approval to the
Alaska Oil and Gas Conservation Commission to convert well MPU C-21 to an
injector.
Pursuant to pending regulation 20 AAC 25.402(c)(3), I assert that all owners,
landowners, surface owners, and operators within a one-quarter mile radius of the
current wellbore trajectory have been provided notice of Hilcorp Alaska, LLC’s
proposed operations.
DATED at Anchorage, Alaska this __day of May, 2020.
______________________
Chad Helgeson, Operations Manager
Hilcorp Alaska, LLC
STATE OF ALAKSA )
) ss
THIRD JUDICIAL DISTRICT )
SUBSCRIBED TO AND SWORN before me this __day of May, 2020
___________________________________
NOTARY PUBLIC IN AND FOR
THE STATE OF ALSKA
My Commission expires: ______________
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!!
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!!
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!!
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!!
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!!!!
!!!
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0
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MPC-21 BHL
MPC-21 SHLMPU C
U013N010E
U014N010E
Sec. 3
Sec. 10Sec. 9
Sec. 4 Sec. 2
Sec. 11
Sec. 34Sec. 33 Sec. 35
Sec. 15Sec. 16 Sec. 14
ADL047434 ADL047433
ADL355017
ADL025516
ADL315848 ADL047437
MILNE POINT UNIT
C-28
C-23
C-26 C-20
C-01
C-43
C-42
C-39
C-21
C-19
C-12
C-15
C-14
C-11
C-09
C-10
C-08
C-07
C-05
C-02
C-04
C-03
C-15A
C-28A
C-25A
C-12A
C-26L1
C-43L1
C-47PB3
C-47PB2
C-12APB1
C-26L1PB3
C-26L1PB2
C-26L1PB1
C-43L1-01
149°29'30"W149°30'0"W149°30'30"W149°31'0"W149°31'30"W149°32'0"W149°32'30"W149°33'0"W149°33'30"W149°34'0"W
70°31'0"N70°31'0"N70°30'30"N70°30'30"N70°30'0"N70°30'0"N70°29'30"N70°29'30"NMap Date: 4/16/2020
Milne Point Unit
MPC-21 Well E0 750 1,500
Feet
Legend
!MPC-21 Surface Holes (SHL)
0 MPC-21 Bottom Holes (BHL)
MPC-21 Well Path
Quarter-Mile Radius
(Around SHL and BHL)
!Other Surface Holes (SHL)
$)Other Bottom Holes (BHL)
Other Well Paths
Oil and Gas Unit Boundary
Pad Footprint
C-25
XHVZE
Pages NOT Scanned in this Well History File
This page identifies those items that were not scanned during the initial scanning project.
They are available in the original file and viewable by direct inspection.
File Number of Well History File
PAGES TO DELETE
Complete
RESCAN
[] Color items - Pages:
Grayscale, halftones, pictures, graphs, charts-
Pages:
Poor Quality Original - Pages:
[] Other- Pages:
DIGITAL DATA
[] Diskettes, No.
[] Other, No/Type
OVERSIZED
[] Logs of vadous kinds
[] Other
COMMENTS:
scanned b~Dianna
Vincent Nathan Lowell
[] TO RE-SCAN
Notes:
Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si
• •
bp
BP Exploration (Alaska) Inc.
Attn: Well Integrity Coordinator, PRB -20
Post Office Box 196612
Anchorage, Alaska 99519-6612
December 30, 2011
Mr. Tom Maunder OA �±
Alaska Oil and Gas Conservation Commission
333 West 7 Avenue
Anchorage, Alaska 99501
Subject: Corrosion Inhibitor Treatments of MPC -Pad
Dear Mr. Maunder,
Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad
that were treated with corrosion inhibitor in the surface casing by conductor annulus.
The corrosion inhibitor is engineered to prevent water from entering the annular space
and causing external corrosion that could result in a surface casing leak to atmosphere.
The attached spreadsheet represents the well name, API and PTD numbers, top of
cement depth prior to filling and volumes of corrosion inhibitor used in each conductor.
As per previous agreement with the AOGCC, this letter and spreadsheet serve as
notification that the treatments took place and meet the requirements of form 10 -404,
Report of Sundry Operations.
If you require any additional information, please contact me or my alternate, Gerald
Murphy, at 659 -5102.
Sincerely,
arm
Mehreen Vazir
BPXA, Well Integrity Coordinator
r ,. .,xrt"."" - .>a:.,: -t.,, ,rne;, .^• .�¢... .- «.a:wt*Y':..aw3: .. -�
• I
BP Exploration (Alaska) Inc.
Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off
Report of Sundry Operations (10 -404)
MPC -Pad
10/9/2011
Corrosion
Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/
Well Name PTD # API # cement pumped cement date inhibitor sealant date
ft bbls ft gal
MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA
MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA
MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA
MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA
MPC-05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA
MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA
MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA
MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011
MPC-09 1850360 50029212990000 Tanko conductor NA NA NA NA NA
MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA
MPC-11 1850590 50029213210000 Tanko conductor NA NA NA NA NA
MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA
MPC-13 1850670 50029213280000 Tanko conductor NA NA NA NA NA
MPC-14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011
MPG-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA
MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA
MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA
MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA
MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA
MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA
- afr MPC-21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011
MPC -22A 1951980 50029224890100 38 NA Need top job
MPC-23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011
MPC-24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011
MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011
MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011
MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011
MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011
MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011
MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011
MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011
MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011
MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011
14-
PR0A~Ci1VE DAGNOSTIC SERVICES, INC.
~~L
~~~/ ~f~l ~~L
To: AOGCC
Christine Mahnken
333 W. 7th Ave
Suite 100
Anchorage, Alaska 99501
(907) 793-1225
•
RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT)
The technical data listed below is being submitted herewith. Please acknowledge receipt by returning
a signed copy of this transmittal letter to the following
BP Exploration (Alaska, Inc.
Petrotechnical Data Center
Attn: Joe Lastufka
LR2-1
900 Benson Blvd.
Anchorage, Alaska 99508
and
ProActive Diagnostic Services, Inc.
Attn: Robert A. Richey
130 West International Airport Road ~ ~~®
Suite C
Anchorage, AK 99518 l ~ 2~ ~
Fax: (907) 245-8952 ~ _~~
1) Gas Lift Survey
2)
Signed
Print Name:
0~-Noc-06 MPU C-21
r.,,,l ~n
i ~.
BL / EDE 50-029-22486-00
Date ~~ ~ ~ `d
PROACTIVE DIAGNOSTIC SERVICES, INC., 130 w. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518
PHONE: (907)245-8951 FAx: (907)245-88952
E-MAIL: - __.--_ --- __--« _~. WEBSITE a _.__~
Cf~Documents and Setlines`Diane `Nilliams'~Desktop~Cransm{t_BP-doei
F\V: I\IPC -~ I and I\IPC-~6
Subject: FW: lYIPC -2 ~ ,and l'vIPC -26
Frortt: "Green. -~,~"~tt~b" <Greenl'v1?~:'~P.com>
Date: Ì1ìe-,-2TJ ul 2004 09:29: 13 -0800
To: "Tonl IVlaunder (E-mail)..<tom_maunder@admin.state.ak.us>
CC: "Frazier, Nicholas B" <fraznb@'BP.com>
Tom,
Attached is the wellwork history on these two wells.
I hope that this is what you are after!
If you need any further information, please let me know. I am charged
with looking after the C-Pad wells at the moment, hence the reply from
myself!
Cheers,
Matc.
-----Original Message-----
From: Thomas Maunder [rnc11.l. t:"ì: torn
Sent: Monday, July 19, 2004 1:36
To: Frazier, Nicholas B¡ Cubbon,
Subject: MPC -21 and MPC-26
f1wurtdé-:"('!',.:-¡dm"¡ n. stal"':':. ,;¡K. U'2]
PM
John R¡ Reem, David C
I am not sure who might be around, so the shotgun approach applies.
It is planned to perform a workover and convert and convert MPF-17 to an
injection well.
In discussions with John and Lea on the North Slope, it was indicated
that a coil jet pump
was similarly retrieved from the two subject wells. I have looked at
our well files and don't
find any mention of this work in the documents there.
I am requesting that a "summary listing" of the work performed on these
wells be submitted.
I am not sure if "summary listing" is the proper term, however a while
back I believe that Sean
Peterson had pulled some information on other wells and sent it in. The
report I am referring to
is essentially a daily 1 or 2 line summary of the well work performed.
Thanks in advance for your assistance in the matter.
Tom Maunde1.-, I?E
AOGCC
:C-21 and C-26 History.xls
Content-Description: C-21 and C-26 History.xIs
Content-Type: application/vnd.ms-excel
Content-Encoding: base64
I of I
7/27:200... I~: 12 PM
l\tIPC-21
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Comments. . ,. . "'. '.' '. 't' '. , , '.'.',','. ,c, . ,.. ..:~..,''5:}: 8H~'~', :;)'[-:: .::. " -~
( HOT OIL TREATMENT ) HEAT DIESEL TO 180 DEGREES AND purvtP DOWN TBG. 160
BBLS DIESEL. IWHP=800/1240/0. FWHP=0/1240/400
PUMP 75 BBLS OF 180 DEGREE DIESEL DOWN TUBING TO MELT PARAFFINS.
INITIAL- T /UO=900/ 1220/ 1 00
FINAL- T/I/O= 150/1300/600
'~~J':":i>a.1,~ðt1i~::".'~:;;:¡o: '.
Hot Oi I
Treatments
MPC-21 07/02/04 HOT
MPC-21 06/09/04 HOT
MPC-21 04/23/04 GLV
MPC-21 04/22/04 GLV
MPC-21 04/20104 GLV
MPC-21 04/20/04 HOT
MPC-21 01/24/04 HOT
1\tlPC-21 01/22/04 STA
MPC-21 01/20/04 TBW
MPC-21 01/17/04 TBW
MPC-21 01/09/04 LVL
1\tlPC-21 10/11/03 MSP
JvIPC-21 09/13/03 TBW
MPC-21 07/08/03 STA
Hot Oil
Treatments
Gas Lift Valve
Work
Gas Lift Valve
Work
Gas Lift Valve
Work
Hot Oil
Treatments
Hot Oil
Treahnents
Static Pressure
Survey
Tubing Wash
Tubing Wash
AC-Fluid Level
Submersible Pump
l\1aintenance Freeze protect do to facility gas handling
Tubing Wash Flushed tbg w/20 bbls meth
Static Pressure
Survey
Station 1
Station 1.2,3.4,5.6,7
Station 1.2.3
HOT BOIL TBG. IWHP= 800/1200/175. FWHP= 200/1300/450
HOT OIL TUBING WITH 30 BBLS DIESEL
PERFOR1\tfED SBHP SURVEY AT 11742' MD 1 6631 TVD 2358 PSI, AND 12250' rvtD 1 7052 TVD
2512 PSI. GOOD DATA. APPEARED TO BE P ARIFFIN FROM HANGER TO 2214' WLrv1.
MPC-21 FRZ. PROTECT FOR TURBINE WORK
FREEZE PROTECT TUBING WITH 20 BBLS METH
MPC-21 06/27/03 TB\V
JvIPC-21 06/01/03 HOT
JvIPC-21 04/30/03 HOT
MPC-21 03/06/03 DSO
JvIPC-11 02/28/03 PMD
rv1PC-21 02/26/03 GLV
MPC-21 02/24/03 OTH
MPC-21 02/22/03 OTH
1vIPC-21 02/13/03 GL V
J\1PC-21 02/11/03 ANN
JvIPC-21 02/11/03 LDL
JvIPC-21 02/11/03 PI\1D
Tubing Wash
Hot Oi I
Treatments
Hot Oil
Treatments
Field Operations
Relevant To Well
Work
Profile
IVlodification
Gas Lift Valve
Work
Found tubing to be highly restricted wlhydrates. Flushed tbg w/MeOH and scraped to 3500' wlm. Hot
diesel did not thaw the hydrates in tubing. The sample of paraffin was given to Craig Graff. In the past
\ve have done hvo hot diesel flushes which improved production for a short period. It appears that the
problen1 is hydrates and not so nluch asphaltines/paraffin as first thought.
Found obstnlction close to surtàce while pumping hot diesel. Pressure went from 950 to 2000 psi before
breaking back and pun1ping away.
Flushed tbg w/80 bbls 180* dsI due to low production rate
Freeze protect for 2" sun1p line pin hole leak repair
Pulled choke and installed it in lYIPC-O 1
Station 7
Other Work (New,
Rare Or Unique) Perfonned gas lift survey (appears lift gas entering from top nlandrel)
Other Work (New.
Rare Or Unique) Verified orifice dian1eter and detennined correct fàctors in control systen1
Gas Lift Valve
Work
Annular
Conllllunication
Work
Set GL V (@ sta#5 and OV ([P. sta# 1.5
Circ 10.1 brine out of IA & tbg~ 1: 1 returns
Circ brine out of IA & tbg~ 1: 1 retunlS. rigged up hose from tree cap to the IA to "U" tube Up. leak
Leak Detect Log tested flow & choke to 3000 psi, good test
Profile
l\10dification Installed new 4" Schaffer choke and tnodified spool piece; completed wino problems
lYIPC-21 02/11/03 PRO
:tvIPC-21 02/05/03 GLV
l'v{PC-21 02/05/03 PMD
:tvIPC-21 01/28/03 PRO
MPC-21 0 I /08/03 GLV
l'vtPC-21 01/06/03 GLV
l'vtPC-21 01/03/03 GLV
l'vIPC-21 01/01/03 RWO
MPC-21 12/04/02 DSO
:tvIPC-21 11/27/02 FSH
:tvIPC-2111/26/02 FSH
1vIPC-21 11/24/02 DSO
IvIPC-21 11/23/02 ANN
Misc. Pressure
Test
Gas Lift Valve
Work
Profile
f\10dification
f\1isc. Pressure
Test
Gas Lift Valve
Work
Gas Lift Valve
Work
Gas Lift Valve
Work
Rig W orkover
Field Operations
Relevant To Well
Work
Fishing
Fishing
Field Operations
Relevant To Well
Work
Annular
COBllnunication
Work
Rigged up a hose froB1 the tree cap to the IA to "U" tube f/p; leak tested flow & choke to 3000 psi. good
test
Pulled Sta # 1, left open
Set 2.31'1 CAT standing vlv (33" long) to 12212' \VIm
Oaslift supply line tested to 2000 psi, punlped 3 bbls meoh
Station 4
Station 7,6.5.4
Pulled BPV, pull ball & rod. pulled stations 1,2,3
Change out tubing frorn ESP completion to a Gas Lift completion
Pull the rest of the coil and seal section out along w/renl0ving the Petcor hanger: back pressure vlv was
set and installed vlv above the tubing hanger
Pooh w/1.5" fish/string, keep hole full w/dsl, coil stopped. pipe did not fàll, rih w/3.5" nozzle, push pipe
to top oftlo\Vcross, n10ves easy but will not fàll, work coil dn to swab vlv. pu nozzle. push coil to
pedcor hanger, close swab & Blaster, blo\v dOWll reel
Drift 1.5" coil w/3/4" ball, BOP test, make up 2.375" nma and 2.125" G spear, latch fish (~! hanger, pu
shear assy. appr to drop string, relatch fish. in pgrs
Shop for reel conversion to 1.5" coiL prep for completion string pull on mpc-21
Kill well, flp w/dsl and coil cormector installed for CTlJ to remove coil string - 10 bbls salt pill settled
at the screens supporting the fluid column plus 1270 psi
1'vIPC-21 11/20/02 DSO
MPC-21 11/15/02 DSO
J\tIPC-21 10/23/01 PSP
J\tIPC-21 10/23/01 STA
IvIPC-21 10/20/01 PSP
IvlPC-21 10/14/0 I SSP
IvIPC-21 09/20/01 OTH
IvIPC-21 07/06/01 PSP
IvIPC-21 03/15/01 SSP
IvIPC-21 02/18/01 PTA
IvIPC-21 02/15/01 DSO
MPC-21 02/14/01 IvISP
Set ESP w/SBHP gauge installed
Aborted re-conlpletion attempt due to high surface reservoir pressures indicating that the weJl would
Other Work (Ne\v, require 10.2 ppg brine as opposed to the seawater that was originally used to kill the well in August
Rare Or Unique) 2000.
Pull Subnlersible
Punl p
Set Subrnersible
Punlp
Pressure Test
Annulus
Field Operations
Relevant To Well
Work Second well test indicates that \vell is just circulating power fluid.
Subn1ersibIe Pump
Maintenance Jet pump re-deployed, and well lifted with -400bwl1d @3000psi power fluid pressure.
Field Operations
Relevant To Well
Work
Field Operations
Relevant To Well
Work
Pull SubrnersibIe
Pump
Static Pressure
Survey
Pull Subnlersible
Pump
Set Subrnersible
Punl p
The salt pill didn't lock up the forrnation, the 9.9 brine \vas not intended to kill the \vell. The pressure
after the frz protection indicate a BHP pressure of 3865 psi. will continue shoot fluid levels and monitor
annulus to see if the frornation relaxes and the BHP drops.
Prep \vell for upcoming kill job. help deterrlline kill fluid for \vell: Result \vas distorted. unable to push
gas back into fom1ation and well swapped back to fast. Using 900 psi, and the full column of C-H20
EMW was pushing II pounds per gallon. Will continue to shoot fluid level to help determine kiJl
fluids. A size salt pill rnay be the direction we need to look to\vards.
Retrieve jet punlp & gauge
Extrapolated pressure (@ rnid perfs 3277 psi 7276' TVD
Attempt to retrieve ESP unsuccessful.
Pull Dun1Jny ESP
Set a "plugged" jet punlp to test coil tubing integrity. Coil tubing tested good and coil tubing to tubing
annulus leaked off Either packer, seal assenlbly or tubing is leaking.
Pressured up CT annulus and pressure leaked otT..
JvIPC-21 02/13/01 l'VISP
JvIPC-21 10/04/00 DSO
JvIPC-21 08/15/00 TBW
JvIPC-21 08/14/00 COM
JvIPC-21 08/13/00 ANN
JvfPC-21 08/13/00 STA
JvIPC-21 07/11/00 RWO
MPC-21 07/07/00 RWO
JvlPC-21 OS/26/00 TB\V
JvIPC-21 05/18/00 FSH
IvfPC-21 05/ 10/00 PTT
MPC-21 02/14/00 STA
JvIPC-21 02/25/99 STA
1v1PC-21 12/07/98 MSP
MPC-21 12/06/98 HCL
JvlPC-21 11/26/98 HCL
JvfPC-21 10/18/98 TB v.,r
MPC-21 09/28/98 PBU
Subnlersible Pump Deployed jet pump and began circulating power fluid. booster pump \vent down after 45mins and on
lYlaintenance start up the jet pun1p appeared plugged. (pun1p retun1ed to surface for inspection).
Field Operations
Relevant To Well
Work
Tubing Wash
Completion
Annular
Conununication
Work
Static Pressure
Survey
Rig W orkover
Rig W orkover
Tubing Wash
Fishing
Pressure Test
Tubing
Static Pressure
Survey
Static Pressure
Survey SBHP. 1480psi at 7000'.
Submersible Pump
l'Vlaintenance ESP failed. Downhole short.
Hcl Acid
Stimulation
Hcl Acid
Stin1ulation
Tubing Wash
Pressure Buildup
Activation screws on Pedcor CT Hanger re-torqued to 11 Ofp.
Well freeze protected.
Installed jet-pun1p recompIetion.
Killed well \vith sea water in preparation for coil workover.
SBHP: 2463psi at 6885'tvd
Re-punched holes in 2-7/8" tubing benveen 12032 and 12036'.
Shot 10 holes from 12032' to 12036'. bottom 4 shots went through the heavy wall section of the carrier.
Failed atten1pt to free-flow, well freeze protected.
Fished 0+0 packoff element.
Gague nm and pressure tested tubing above 11668' using a 0+0 tool. (Lost 0+0 pack off element).
SBHP. 2150 at 7000'.
ESP acid wash. Pumped locked again after surfacing 30 bbl.
ESP acid wash. Pump binding during re-start.
Flowing Scrape to 2500' wln1.
PBU analysis, kh = 1430, k = 42. S = -5, p* = 1021 at 12.036' tvfD
MPC-21 06/29/98 HCL
MPC-21 08/1 0/96 RWO
MPC-21 08/01/96 MSP
MPC-21 07/27/94 COl\¡I
Jv1PC-21 06/01/94 FRC
Hcl Acid
Stimulation Acidize ESP.
Rig Workover Polar 1 RWO to changeout ESP
Submersible PUll1p
Maintenance ESP failure. Cable fàilure due to excessive heat - low flo\v
Conlpletion Initial Conlpletion. LLCY installed Initial oil production 11 OObopd, 360GOR
Hydraulic Fracture
Stim Initial Perforations. Fracs across the Kuparuk A and C/B sands
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate
[] Pull Tubing [] Alter Casing [] Repair Well [] Other Convert from Jet/ESP to Gas Lift
2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB)
BP Exploration (Alaska) Inc. [] Development KBE = 46'
3. Address [] Exploratory 7. Unit or Property Name
[] Stratigraphic Milne Point Unit
P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service
4. Location of well at surface 8. Well Number
1139' NSL, 2226' WEL, SEC. 10, T13N, R10E, UM X = 558233, Y = 6029422 MPC-21
At top of productive interval "~.~ 9. Permit Number / Approval No.
5060' NSL, 3324' WEL, SEC. 03, T13N, R10E, UM X = 557048, Y = 60386,13 ~,J 194-080
10. APl Number
At effective depth ,~ 50-029-22486-00
5237' NSL, 3250' WEL, SEC. 03, T13N, R10E, UM X = 557020, Y = 6038790 11. Field and Pool
At total depth Milne Point Unit / Kuparuk River
5' NSL, 3358' WEL, SEC. 34, T14N, R10E, UM X = 557012', Y = 6038838 Sands
12. Present well condition summary
Total depth: measured 12862 feet Plugs (measured)
true vertical 7601 feet
Effective depth: measured 12755 feet Junk (measured) Fish - 2 Flat Guards, 15 Flat Bands and I Per-formed
true vertical 7506 feet guard (8/96)
Casing Length Size Cemented M D TVD
Structural
Conductor 80' 13-3/8" 250 sx Arcticset 1 (Approx.) 112' 112'
Surface 8002' 9-5/8" 1542 sx PF 'E', 250 sx Class 'G' 8032' 4769'
Intermediate
Production 12812' 7" 210 sx Class 'G' 12841' 7582'
Liner
Perforation depth: measured 12370' - 12420', 12502' - 12626'
true vertical 7165' - 7209', 7282' - 7391'
Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 tubing to 12252' and 3-1/2", 9.3#, L-80 tubing from 12356' to 12385'
Packers and SSSV (type and measured depth) Baker S-3 Packer at 12200', Baker Model 'D' Packer at 12356', 20', 3.5" 20 GA
Bakerweld Screen and a 3.5" Camc(~ D°Nipple with a 3.5" A-Z Blanking Plug.
13. Stimulation or cement squeeze summary
Intervals treated (measured)
Treatment description including volumes used and final pressure
14. Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure
Prior to well operation:
Subsequent to operation:
15. Attachments 16. Status of well classifications as:
[] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service
[] Daily Report of Well Operations
17.1 hereby cert~e f,p~.~going~ correct to the best of'my knowledge
Si!;;Ined Sol~ra~ '"~'~ ~-'~'-~Stewman ! Title Technical Assistant Date (~)C~- ~c~- (~) ~
, ' i PreparedByName/Number: Son(lra Stewman, 564-4750
Form 10-404 Rev. 06/15/88 EBBN$ BFL FEB 12 2003 '. _.~ , -~ ~'~ ~ ~:~ -.~ Submit In Duplicate
BP EXPLORATION Page 1 of 2
Operations Summary Report
Legal Well Name: MPC-21
Common Well Name: MPC-21 Spud Date: 9/7/1982
Event Name: RECOMPLETION Start: 12/29/2002 End:
Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/1/2003
Rig Name: NABORS 4ES Rig Number:
Date From - To HOurs Task Code NPT Phase Descript!On of-Operations
12/29/2002 00:00 - 03:00 3.00 MOB P PRE MOVE RIG AND EQUIPMENT FROM MPJ PAD TO MPC-21.
03:00 - 04:30 1.50 MOB P PRE SPOT SUB AND MODULES.
04:30 - 06:00 1.50 MOB P PRE FINISH RU. RAISE AND SCOPE DERRICK. ACCEPT RIG
AT 06:00 HRS...12/29/2002...LMH
06:00 - 07:30 1.50 MOB P PRE SPOT AND RU LINES TO TIGER TANK. RU LINES TO TREE
TO CIRCULATE WELL.
07:00 - 08.30 1.50 WHSUR P DECOMP PU LUB AND PULL BPV, WELL DEAD, RECEIVE 10.1 BRINE
INTO PITS
08:30 - 12:30 4.00 WHSUR P DECOMP TEST LINES TO TREE,3500 PSI. PRE SPUD MEETING W /
NAD / BP. REV CIRC DIESEL OUT OF TBG TO OPEN TOP
TANK. SWITCH TO CIRC 10.1 BINE DOWN TBG TO
RECOVER 11 4 BRINE TO RIG PITS. APP 380 BBLS
RECOVERED WHEN 10.1 HIT SURFACE.
12:30 - 13:30 1.00 WHSUR P DECOMP MONITOR WELL, SET / TEST TWC 3500 PSI. RD LINES
FROM TREE
13 30 - 14:00 0.50 WHSUR P DECOMP ND TEMPORARY TREE
14:00 - 15:30 1.50 BOPSUF P DECOMP NU BOPE, GREASE CHOKE MANIFOLD
15:30 - 18:30 3.00 BOPSUF P DECOMP TEST BOPE TO AOGCC / BP PROCEDURES, 250 / 3500
WITNESS OF BOPE TEST WAIVED BY AOGCC INSP. JOHN
CHRISP.
18:30- 19:30 1.00 BOPSUF P DECOMP DRAIN STACK, PU LUB AND PULL TWC
19:30-20:30 1.00 PULL P DECOMP PULANDINGJT,BO/LDS, PRE SPUD MEETING W / NAD,
CENTRILIFT, BP. PU HGR AT 70 K UW- BOUNCED TO 90 K
UW, SETTLED AT 75 K UW. PULL HGR TO FLOOR, CABLE
ATTACHED.
20:30 - 21:00 0.50 PULL P DECOMP RU TO PULL ESP COMPLETION ASSY.
21:00-00:00 300 PULL P DECOMP PULL AND LD 2 7/8 TBG AND ESP CABLE.
12/30/2002 00:00 - 01:00 1 00 PULL P DECOMP CONTINUE TOOH WITH ESP ASSY...LAY DOWN 2 7/8"
TBG
01:00 - 02:00 1.00 PULL N SFAL DECOMP BP SPOOLING UNIT REPAIRS...DIESEL FUEL GELLED.
(-85 DEGS WIND CHIL).
02'00 - 04'00 2 00 PULL P DECOMP CONTINUE TOOH WITH ESP ASSY. STOP FOR REEL
CHANGE.
04'00 - 04:30 0 50 PULL P DECOMP CHANGE OUT CABLE REELS.
04:30 - 06:00 1 50 PULL P DECOMP CONTINUE TOOH WITH ESP ASSY.
06:00 - 09:00 3.00 PULL P DECOMP CREW CHANGE. PJSM. CeNT LD TBG / ESP CABLE
09:00 - 10:30 1 50 PULL P DECOMP INSPECTAND LD ESP ASSY.
10:30-11:30 1.00 PULL P DECOMP RD TBG AND ESP PULLING EQUIP. RUTORUNDP
11:30 - 18:00 6.50 PULL P DECOMP MU 6" BIT, 7" SCRAPPER, 2-BOOT BASKETS PU GRADE E
DP AND RIH
18:00 - 20:00 2.00 PULL P DECOMP CREW CHANGE PJSM, CeNT PU DP AND RIH
20:00-21:30 1.50 PULL P DECOMP LOAD PIPE SHED W / 'G' DP AND SLIP / CUT 80' DRLG
LINE.
21:30-23:30 2.00 PULL P DECOMP CONTRIHW/SCRAPPERANDPUDPTO12318'. PUW=
160K. SOW = 65K.
23:30 - 00:00 0.50 PULL P DECOMP RU TO REV CIRC, NO RETURNS AT 1,2,3 BPM -1100 PSI.
RU PUMP DOWN DP WITH GOOD RETURNS AT 1,2,3,4
BPM - 4 BPH LOSS.
12/31/2002 00:00 - 01:00 1.00 PULL P DECOMP LD 4 JTS,RU TO REV CIRC.1,2,3 BPM GOOD RETURNS.
STARTED LOOSING RETURNS. LOST RETURNS. SD
PUMP.
01:00 - 04:30 3.50 PULL P DECOMP POH TO PU RTTS, STAND DP BACK.
04:30 - 06:00 1.50 PULL P DECOMP CREW CHANGE, PJSM-MU RTTS AND SET AT 27' TEST
Printed 1/2/2003 I 21 37 PM
BP EXPLORATION Page 2 of 2
Operations Summary Report
Legal Well Name: MPC-21
Common Well Name: MPC-21 Spud Date: 9/7/1982
Event Name: RECOMPLETION Start: 12/29/2002 End:
Contractor Name: NABORS ALASKA DRILLING I Rig Release: 1/1/2003
Rig Name: NABORS 4ES Rig Number:
Date From - To Hours Task Code NPT Phase Description of Operations
12/31/2002 04:30 - 06:00 1.50 PULL P DECOMP RTTS.
06:00 - 08:00 2.00 WHSUR P DECOMP BLEED ANN.MU PO PULLING TOOL AND PULL PO.-PUW
25K. INSTALL NEW PO TEST TO 5000 PSI. GOOD TEST.
08:00 - 09:00 1.00 WHSUR P DECOMP RETRIEVE RTTS, MONITOR WELL
09:00 - 10.00 1.00 WHSUR P DECOMP POH ,STAND DP BACK-LD RTTS, SCRAPPER, BIT,CLEAR
FLOOR. MU CHAMP PKR.
10:00 - 11'30 1.50 WHSUR P DECOMP CLEAN RIG
11.30-15.00 3.50 CASE P DECOMP TIHW/PKRTO12200',PUW165K-SOW65K.
15:00 - 16:30 1.50 CASE P DECOMP SET AT 12200' AND TEST 7"CSG TO 2000 PSI 30 MIN,
GOOD TEST
16.30 - 18 00 1.50 CASE P DECOMP POH LD 3 1/2 DP
18.00 - 00 00 6.00 CASE P DECOMP CREW CHANGE, PJSM - CONT POH LD DP.
1/1/2003 00:00 - 01:00 1.00 CASE DECOMP CONTINUE TO LID DP. LID CHAMP PACKER.
01:00 - 02:30 1 50 RUNCOr~ COMP CLEAN / CLEAR FLOOR. RIG UP TO RUN 2 7/8"
COMPLETION STRING.
02:30 - 13:00 10 50 RUNCOI~ COMP PJSM. M/U BHA & PACKER ASSEMBLY. RIH W/2 7/8" EUE
COMPLETION STRING TO 12,245'.
13:00 - 14.00 1.00 RUNCQ~ COMP M/U LANDING JOINT 65K UP WT, 35K DOWN. M/U
HANGER & LAND TBG. RILDS SET 2 WAY CHECK & TEST
@ 2500 PSI.
14:00 - 15:30 1.50 WHSUR COMP NIPPLE DOWN BOPE.
15:30 - 17:00 1.50 WHSUR COMP NIPPLE UP ADAPTER FLANGE & TREE.
17:00 - 17'30 0.50 WHSUR COMP PICK UP LUBRICATOR, PULL 2 WAY CHECK.
17:30 - 19:30 2 00 RUNCOI~ COMP DROP BALL / ROD. R/U HARDLINES TO TREE & PT TO
3500 PSI, OK. PRESSURE UP TUBING TO 3000 PSI, SET
PACKER. ATTEMPT TO TEST TUBING, ISOLATE ALL
VALVES & DETERMINE LEAK IS BY ROD / BALL.
PRESSURE UP ANNULUS TO 3500 PSI, KEEPING
1500-2000 PSI ON TUBING. TEST 7" x 2 7~8" ANNULUS @
3500 PSI / 30 MINUTES, CHARTED, 100 PSI BLEED
OFF...GOOD TEST. BLEED OFF TUBING & SHEAR RP
VALVE.
19:30 - 21:00 1.50 RUNCOI', COMP PJSM. R/U HBR & TEST LINES TO 3000 PSI. PUMP 85 BBLS
DIESEL DOWN ANNULUS, R/D HBR & ALLOW DIESEL TO U
TUBE BACK INTO TUBING, EFFECTIVELY FREEZE
PROTECTING TUBING & ANNULUS TO 2200'.
21:00 - 22:00 1.00 WHSUR COMP P/U LUBRICATOR, SET BPV, SECURE WELL. RIG
RELEASED @ 22:00 HRS, 01-01-03.
Printed 1/2/2003 1 21 37 PM
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of request: Temp Abandon_ Suspend_
ESP Changed to//Alter casing _ Repair well _X
Gas Lift Change approved program _
Operational shutdown _ Re-enter suspended well _
Plugging _ Time extension _ Stimulate _
Pull tubing _X Variance _ Perforate _
Other _
2. Name of Operator
BP Exploration (Alaska), Inc.
3. Address
P. O. Box 196612
Anchorage, AK 99519-6612
4. Location of well at surface
4140' FNL, 2227' FEL, Sec. 10, T13N, R10E, UM
At top of productive interval
221' FNL, 3340' FEL, Sec. 03, T13N, R10E, UM
At effective depth
43' FNL, 3350' FEL, Sec. 03, T13N, R10E, UM
At total depth
5274' FNL, 3358' FEL, Sec. 34, T14N, R10E, UM
5. Type of Well:
Development
Exploratory __
Stratigraphic __
Service__
(asp's 558233, 6029422)
(asp's 557032, 6038611)
(asp's 557020, 6038790)
(asp's 557012, 6038838)
6. Datum elevation (DF or KB feet)
RKB 46.0 feet
7. Unit or Property name
Milne Point Unit
8. Well number
MPC-21 i'
9. Permit number / approval number
194-080 /
10. APl number
50-029-22486-00
11. Field / Pool
Miline Point Unit / Kuparuk River Pool
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length
Conductor 112'
Surface 8002'
Production 12812'
12862 feet Plugs (measured)
7601 feet
12755 feet Junk (measured)
7506 feet
Size Cemented
13-3/8" 250 sx ArcticSet I (aprox)
9-5/8" 1542 sx PF 'E', 250 sx 'G'
7" 210 sx Class 'G'
Perforation depth:
measured Open Perfs 12370'-12420', 12502'-12626'
true vertical Open Perfs 7165'-7209', 7282'-7391'
Measured Depth True ve~icalDepth
144' 144'
8032' 4769'
12841' 7582'
RECEIVED
DEC 0,4 2002
Alaska 0il & Gas Cons. C0mmissi0n
Anchorage
Tubing (size, grade, and measured depth 2-7/8" 6.5# L-80 to 12058". ESP @ 12099'. 3-1/2" Screen Assembly from 12356' - 12385'.
Packers & SSSV (type & measured depth) 7" Baker Model D Isolation Packer @ 12356'.
2-7/8" X 1" Camco sidepocket w/dummy valve GLM @ 142'.
13. Attachments Description summary of proposal __X Detailed operations program __
BOP sketch
14. Estimated date for commencing operation 15. Status of well classification as:
- ,"; CVC, ,'~,D C~r, ~,.,,, ,--
16. If proposal was verbally approved Oil __ X
Name of approver ! ~ Date~pproved Service
17. I hereby certify that the fo;7,~/d ~nowledge.
SlgnedMichael Aivano '~~~~,~'_./,~, ~ v ~:cMi(~nrv~;trs°lslU(~NEn[~i;e;rONLY
Gas __ Suspended _
Questions? Call Michael Aivano @ 564-5943.
Date December 04, 2002
Prepared by DeWayne R. Schnorr 564-5174
Conditions of approval; Notify Commission so representative may witness
Plug integrity __ ~:)P Test__ Location clearance
Mechanical Integrity Test ~ Subsequent form required 10-
Approved by order of the Commission
Form 10-403 Rev 06/15/88 ·
ORIGINAL SIGNED BY commissioner
YL. Bill
DEC
Date
9 2002
SUBMIT IN TRIPLICATE
bp
BP Exploration (Alaska) Inc,
900 East Benson Boulevard
P. O. Box 196612
Anchorage, Alaska 99519-6612
(907) 561-5111
December 04, 2002
Winton Aubert
Alaska Oil & Gas Conservation Commission
333 West 7th Avenue Suite 100
Anchorage, AK 99501
Dear Winton'
Re' Sundry Notice for MPC-21 --- Change out Jet Pump / ESP and
replace with Gas Lift.
BP Exploration Alaska, Inc. proposes to convert well MPC-21 from a failed ESP j
/ Jet Pump producer to a Gas Lifted producer as part of the Milne Point Kuparuk
Water/MI Flood Development project.
MPC-21 was drilled and completed in June of 1994. The well has had two ESP
pumps installed with run times being 736 and 841 days. At the time of failure of
the second pump (12/7/98) the well was producing only 200 bopd and it was
considered uneconomic to recomplete. In August of 2000 a 1-1/2" coil tubing jet
pump was installed inside the current 2-7/8" tubing and an attempt was made to
produce the well. The well produced for a short while, in February 2001 during
a pressure test of the coil string a leak was found in the coil tubing by tubing
annulus and the well was shut-in again.
/
A RWO is planned for around the 10th of December 2002, the scope of work is
to pull the 1-1/2" coil tubing string and the 2-7/8" ESP completion, replace the
pack off around the wellhead, and install a 2-7/8" Gas Lift completion.
If you have any questions concerning this Sundry Application please feel free to
call me at 564-5943 or e-mail at aivanomj @ bp.com.
Michael Aivano
Milne Point Unit
Petroleum Engineer
TREE FMC MPC 21 CTU
WELLHEAD: 11" 5M FMC m KB. ELEV = 46'
KOP ~ 350' sidepocket w/dummy
~ ~~ Retrievable packer w/l~'lD
; series 5J 3, FPMTARC,
~ ~ 178 Stg.
~ ~ ~ seaJ section
,~' ~ CentrJli~ KME1 562 sedes
'~ 82 hp motor, 1230 v. / 38
- ~c Centriliff ~ 12099
~imulation Summa~: ~ ~
07/12/94 - 416,200 lbs. (60M ~ of ~' 20 7 ~J nt
went to full flush. / ~ ~ / ~COLLC 12352
PERFO~TION suMMARY 20' 3.5", 20 GA
~//~ 35" C~CO X N PPLE
3 3/8 6 12370'12420
DA~ ~BY . C~ME~S MILNE POINT UNIT
7/1/94 DBR ~ 7 ' WELL C~1
7/28/94 DBR IN~ ~ ~1 NO: 50-029~2486
FMc Proposed MP
WELLHEAD: 11" 5M FMC
ACTUATOR:
kOP ~ 350'
MAX HOLE Angle 63-
65 DEG 3200-10400
2 7/8". 6.5~, EUE 8RD, [
I
L-80 TUBING
Camco glm. kbmm. w/bklatchi
# md tvd dg
7 12172 7000
6 11776 6700
5 11272 6318
4 10216 5744
3 8410 4921
2 5828 3769
1 2553 2172
Stimulation Summary:
07/12/94-416,200 lbs. (60M # of
20/40
followed by 356.2M lbs. 16/20), job
went to full flush,
Fish: 8/f4196 Lost 2 fiat guards, +/- 18 Flat
bands. 1 pre formed guard during ~[WO
PERFORATION SUMMARY
REF: LOG: 7/5/cJ4 AWS OR/CCI
3acker set at 12225' md
WLEG set at 12250'md
20' -7" Short Joint
Camco LLC Valve
Baker Model D Packer
3,5" Camco X Nipple
WLEG
PBT~ I12755,
DATE RE~ BY COMMI~iTS I
. MILNE PO NT UNIT
71tl94 DBR RAN 7
7~28~94 DBR INmAL ~ON APl NO: 50-029-22486
8/14/96 M. Linder RWO Polar dg
Milne Point 2001 Shut In Wells
Date Reason for Future Utility Plans &
Sw Name Shut-In Well Shut-In ~ :Current Mechanical Condition of Well2 Possibilities3 Comments
MPB-07 Jul-97 A No known problems I High GOR well, Facilities can not handle
gas. Possible production after gas
expansion P.roject.
MPB-08 May-94 E No known problems 3 Futher use as an i. njector not required ..
MPB-13 Jan-86 B GL well that was shut in due to high 3 Wellhouse and flowiines removed
water cut. Possible channel into water
zone.
MPB-17 Jan-96 E No mechanical proble~ns. Quick 3 Wellhouse and flowlines removed
communication with producer
MPB-19 Jul-91 B GL well. High water cut producer. 3 Wellhouse and fl°wlines removed
Possible' frac into water zone
MPC.-11 Feb-96 E No known problems 3 Further use as an injector not'required
while associated producer shut-in
,
MPC-12 / Jan-O0 E Fish in hole, drilling problems 3 Suspended due to drilling problems.
12a
MPC.-16 Aug-93 A High GOR well, perfs and completion 3 Wellhouse'and flowlines removed
abandoned
MPC-17 May-O0 D Leak in 9 5/8" casing t° surface I Evaluating possible plans for'solution to
problem.
MPC'20 Apr-O0 B High water cut well, no mechanical I Evaluating 'po'ssible plans for solution to
problems problem.
~2:1~.i!i;i ~ Feb-02 D Problems wi~h Jet Pump Completion I Evaluating possible plans for solution to
.problem.
MPD-01 Dec-90 C Dead ESP completion, no support to I Evaluating possible plans for solution to
block problem. Possible alternative uses for
wellbore
MPD-02./ Aug-99 B Dead ESP completion, very high water I Evaluating possible plans.
02a cut well
iMPE-02 Jun-05. C No known problems 2 . R'ecomplete to upper gup zone .' .
MPE-19 Au~-99 C Failed ESP on tubing string . 2 Well brought on line in 20.02
MPL-01 Feb-O0 B High water cut well, no mechanical I Evaluating possible plans
problems dead ESP in hole ·
M. PL-lO Feb-99 E No proof that is supports other wells I Evaluating side track possibilities
MPL-17 Apr-O0 B No menchanical problems, dead ESP I [Evaluating side track possibilities
,
MPL-21 0ct-98 E High-pressure-block ~ $O00psi, no I Possible use for injection'when pressure
support needed for producers lowers
MPL-37a . Nov-99 C Dead ESP,-no-other. mechanical I Evaluating 'possible side track plans Or
issuses recomp, l. etions
MPL-39 Jan-99 E Could not inject gas into well, no use I Evaluating possible'side track plans or
for it. recomp.l, etions
, ,
.....
*Note - Wells were shut in 100% during 2001
,SCANNED JUN '4 2002
Milne Pt Shut In Wells 2001 .xls
.
.
MEMORANDUM
State of Alaska
Alaska Oil and Gas Conservation Commission
TO: Dan Seamount 0.7:) DATE: July 12, 2000
Commissioner' O/Ic:/bc.;:)
THRU: Blair Wondzell, Q1~
P. I. Supervisor . êf ~{é:i:J
FROM: ~dtl
Jeff Jones ..-'" SUBJECT: Safety Valve Tests
Petroleum'l sp c /r Milne Point Unit
B & C Pads
July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System
tests on MPU 8 & C Pads.
Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles.
Seven failures were witnessed. MPU 8-22 SV failed to hold DP. MPU C-04 SV
failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold
DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28
SV failed to test because the tree cap a-ring leaked. The AOGCC test reports
are attached for reference.
Well house inspections were done on 21 well houses. All well houses inspected
were clean and in satisfactory condition.
SUMMARY: I witnessed SVS tests on 8P's MPU 8 & C pads.
MPU B Pad, 9 wells, 18 components tested, 1 failure. 5.5% failure rate.
MPU C Pad, 12 wells, 23 components tested, 6 failures. 26% failure rate. ;3 Jv1O... r-<-~5i-
21 well houses were inspected, no failures. --.-11"
Attachments: SVS MPU B-PAD 7-9-00 JJ
SVS MPU C-PAD 7-9-00 JJ
cc;
NON-CONFIDENTIAL
SVS MPU B & C PADS 7-12-00 JJ.doc
.
.
Alaska Oil and Gas Conservation Commission
Safety Valve System Test H.eport
Operator: BPX
Operator Rep: Larry Niles
AOGCC Rep: Jeff Jones
Submitted By: Date:
FieldlUnit/Pad: Kuparuk River/MPU/C-Pad
Separator psi: LPS 140 HPS
7/9/00
~
./
>. ,'.. .,¿ ,: ~-' " ..." , ,.'.. ...,.' ""..:<" ,; '... ,. '. ..' "" : \-:3::!::',~:;';,¡:,: "'; ..". , ...., . ?::'./(¡~ :~' :'i0'\~~~~~
'Jrell Data " ., Pilo'ls" .\!S.V? ',S~IV,',; '~YelL Type,':,..
. .
Well Permit Sepal' Set LIP Test Test Test
Number Number PSI J>SI Trip Code Code Code Oil, WAG, GIN.J,
GAS or CYCLE
. @..O ,} ~'f,\' (~,,/ 1811430 140 100 95 P P OIL
\; " .',. ¡"..'"
C-03 1820500 140 100 95 P P OIL
C-04 1821260 140 100 100 P 4 OIL
C-05A 1842430 140 100 100 P 4 OIL
C-07 1850020 140 100 100 P P OIL
C-08 1850140
C-09 1850360 140 100 120 P 4 OIL
C-13 1850670
C-14 1850880 140 100 100 P P OIL
C-15 1851030
C-17 1852630
C-20 1890150
C-21 1940800
C-22A 1951980 140 100 95 P P OIL
C-23 1960160
C-25A 1960210 4000 2000 2000 P 4 WAG
C-26 1952060
C-28 1960290 4000 2000 2000 P 43 WAG
C-36 1980010
C-39 1972480
C-02 1821940 4000 1900 P P WAG
C-06 1842410 4000 1900 P 4 WAG
12 Components:
23 Failures:
6 Failure Rate: 26.00/0090 Day
Wells:
ReJnarks:
Wells # C-02 & C-06 are listed as water injection wells, and are not in this database
Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked.
The SV on well # C-07 recorded a slow closing time;(2:27).
Larry Niles, the BP representative, said he would have these iteITIS corrected.
8/7/00
Paoe 1 of 1
b
VI v7irqm.xls
ON OR BEFO
W
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed: Operation shutdown __ Stimulate__ Plugging__
Pull tubing X Alter casing __ Repair well __
Perforate__
Other__
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P. O. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
1139' NSL, 2226' WEL, SEC. 10, T13N, RIOE
At top of productive interval
5079' NSL, 3330' WEL, SEC. 3, T13N, RIOE
At effective depth
N/A
At total depth
5260' NSL, 3351' WEL, SEC. 3, T13N, RIOE
5. Type of Well:
Development X
Exploratory __
Stratigraphic __
Service __
6. Datum elevation (DF or KB)
KBE = 46' feet
7. Unit or Property name
Mi/ne Point Unit
8. Well number
MPC-21
9. Permit number/approval number
94-80
10. APl number
50- 029-22486
11. Field/Pool
Mi/ne Point- Kuparuk River
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length
Structural
Conductor 80'
Surface 8002'
Intermediate
Production 12810
Liner
Perforation depth:
7422 feet Plugs (measured)
4508 feet N/A
12755 feet Junk (measured)
7503 feet N/A
Size Cemented
13-3/8" 250 sx ArcEcset (Approx.)
9-5/8" 1542sx Class 'E'
250sx Class 'G"
7" 43 bbls Class 'G'
measured SAME AS WHEN COMPLETED (NO CHANGE)
true vertical SAME AS WHEN COMPLETED (NO CHANGE)
Tubing (size, grade, and measured depth) 2 7/8", 6-5 PPF, L-80 TO 12,058'MD
Packers and SSSV (type and measured depth) NOT APPLICABLE
Measured depth
True vertical depth
112 112'
8032' 4769'
12840' 7579'
RECEIVED
SEP 1 7 1996
Alaska 011 & Gas Cons. Commission
Anchorage
13. Stimulation or cement squeeze summary NONE PERFORMED
Intervals treated (measured)
Treatment description including volumes used and final pressure
-iYNIglaO
14.
Prior to well operation
Subsequent to operation
Representative Daily Average Production orlnjection Data
OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure
430 80 0 320
600 116 4 320
Tubing Pressure
27O
27O
15. Attachments
Copies of Logs and Surveys run __
Daily Report of Well Operations __
16. Status of well classification as:
Oil X Gas__ Suspended
Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
Si~lned ~,/'~2-~,~1~~----~~ Title Wells Operation Superintendent
Form 10-404 Rev 06/15/88
Date 9/9/98
SUBMIT IN DUPLICATE
MPU C-21
OPERATION SUMMARY
· Pre-rig: Perforate, frac A sand down 7" casing, clean out frac sand with coiled tubing. Sand back across A
sand, frac B sand down 7" casing. Clean out to PBTD with coiled tubing. Install Baker model D packer
assembly and LLC. Circulate well to kill weight brine, Verify zero pressure on 7" casing and annuals. Set
BPV. Prepare pad for rig.
· MIRU Nabors 4ES workover rig. Pressure test 7" casing to 3500 psi.
· Run completion as shown in tubing running order and wellbore schematic.
· RDMO Nabors 4ES. Place well on production.
RECEIVED
SEP 1 7 199(;
Ala$~ 0tl & fins eons. gommi~.io~;
Anchomg,9
'AOGCC; Indi:vi'dua'J \,',lei i
Geolog'¥ca'J Piater'i'a J s Inw:sntor'y
PEEHtT DATA T DATA._PL US
94~080 ~i 87
(
34--- 0,~ 0 6/6286
9~.~,--.--080 C~7
9a..---080
9/+-'-080 ~JRVEY
9~,~ ~,. 080 ~DN
T 9755,-12768 CH~-GR
L 8000'-12800
g~"-080 ~Aff~,N L ~700~7600 TVD
9a."~080 L~.;'R L 8000'-12800
94"~080 ~/DC L ~?00"--7600 TVD
9a-~-080 ~g~,:/C[.. L 9760~-12766 1
9a-.080 ~/'GR/CL L 12360-.~127~1 '1
9a.-..-080 ~>FC/'GR/CL L I2i00--~12a53 1
Da~Ee~ 06/08/96
-'," '" ..... ,2VD
R LIN l¢ A F ~:. Fi: E
07/15t"9z~
i 1 O/i h/9h
09/1 ~/'9a-
09/" '13/9a
09/"13/'9!~
i 1 O~ 1al 9a
I 0 '1 / 10 / 95
i 1 O~ i a/
comp 01/'10/95
0//z..../9h
0'?/'25/9h
07/' 2 7/' 9 a.
dr'y di'tch samp'ies r'equi'r'ed? yes ~_~c] r'ece~'ved? ~
APe
~,,/,~s the we'i 'i cor'ed? yes no Ana'iys:fs & ~'~ . ~.
, C~;~dCl"'¥~3~'Oiq r'ece'¥ veds' ',les no
Ar'e weJ'J tests r'equ'¥r'edl?/ yes ~ce~'ved? yes no ~
~Je i 'i 'i s ~' n comp i '¥ance ...~_ 7
~n~' t:i'a I
COHIqENTS
TO:
Schlumberger - GeoQuest
A Division of Schlumberger Technologies Corporation
500 W. international Airport Road
Anchorage, Alaska 99518- 1199
(907) 562-7669 (Bus.)
(907) 563-3309 (Fax)
Januaw 9,1995
BP Exploration (Alaska) Inc.
Petrotechnical Data Center, MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
The following data of the LWD DEPTH CORRECTED CDR & ADN TVD for well MPC-21 , Job # 94389
was sent to:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center, MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
3 Bluelines
1 Film
/A-tCska O'd &Gas Conservation Comm.
Attn: Larry Grant _
3001 Porcupine Drive
ka 99501
1 Blue~
1 RFolded Sepi~~
OXY USA, Inc
Attn: Erma Galindo
P.O. Box 50250
Midland, Texas 79710
1 Blueline
1 RFolded Sepia
Sent Certified Mail P 905 127 757
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EAC~,.L~TO:
BP EXPLORATION (ALASKA)INC. SCHLUMBERGER GEOQUEST
PETROTECHNICAL DATA CENTER, MB3-3 500 WEST INTERNATIONAL AIRPORT ROAD
900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99518-1199
ANCHORAGE, ALASKA 99519-6612
Schh~mhergc, r (':.~ ~rier: Date Delivered: Received By:
500 W. International Airpod Road
Anchorage, Alaska 99518-1199
(907) 562-7669
October 14, 1994
TO:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center, MB3-$
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
The following data of the I,,WD DEPTH CORRECTED CDR & ADN for well MPC-21 , Job # 94265
was sent to:
BP Exploralion (Alaska) Inc.
Petrotechnical Data Center, MB3-3
900 E. Benson Blvd.
Anchorage, Alaska 99519-6612
1 OH LIS Tape
1 Depth Shift Monitor Plot
3 Bluelines
1 Film
Returning CDR, ADN, CDR & ADN - TVD
Field Film
State of Alaskaj
Alaska O~l--&'~~servation Comm.
Attn: ~,~ry~ant
300~tPor(~upine Drive
Ancl~orag~%,~&Laska 99501
Tape
l~Sepia
OXY
Attn: Erma Galindo
P.O. Box 50250
Midland, Texas 79710
1 OH LIS Tape
1 Blueline
1 RFolded Sepia
-.2.,,..:
PLEASE ACKNOW NING AND RETURNING ONE COPY EACH TO:
BP EXPLORATION (ALASKA) INC.
PETROTECHNICAL DATA CENTER, MB3-3
900 F. AST BENSON BLVD.
ANCHORAGE, ALASKA 99519-6612
SCHLUMBERGER GEOQUEST
500 WEST INTERNATIONAL AIRPORT ROAD
ANCHORAGE, ALASKA 99518-1199
Schlumberger Courier:
Date Delivered:
Received By:
" STATE OF ALASKA [
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMP LETION REPORT AND LOG
1. Status of Well Classification of Service Well
OIL [] GAS [] St. ISPEt,~cD [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
BP Exploration (Alaska) Inc. 94-80
3. Address 8. APl Number
P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22486
4. Location of well at sudace 9. Unit or Lease Name
1139' NSL, 2226' WEL, SEC. 10, T13N, RIO ~i~i'ii--;.'~i~ i~ ~/.~~ Milne Point
, -.- ~. . ~ ~[ ._~ · ,
At Top Producing Interval ~ ....,.~AT'E, ,~ ii ;~I~.-~ 10. Well Number
221, SNL, 3340' WEL, SEC. 3, T13N, RIOE
MPC-21
,~ .Z~_~-~t '-. r,2u ! ...!~ 11. FieldandPool
At Total Depth
4' NSL, 3374' WEL, SEC. 34, T14N, RIOE
5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No.
KBE = 46' ! ADL 355017
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. j15. Water Depth, il offshore j16. No. of Completions
6/19/94 6/27/94 6/25/94I N/A feet MSL I One
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+'t'VD 19. Directional Survey ~20. Depth where SSSV set J21. Thickness of Permafrost
12862' MD/7601' TVD 12755' MD/7506' TVD YES [] NO [] ~LLC @ 12400 feet MD ! 1800' (Approx.)
22. Type Electric or Other Logs Run
LWD
23. CASING, LINER AND CEMENTING RECORD
SE'l-rING DEPTH MD
CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
13-3/8" 54.5# K-55 32' 112' 24" 250 sx Arcticset I (Approx.)
9-5/8" 40# L-80 30' 8032' 12-1/4" 1542 sx PF "E"/250 sx "G"
7" 26# L-80 29' 12841' 8-1/2" 210 sx Class "G"
23,~ Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD)
Gun Diameter 3 -3/8" 5 spf 2-7/8", L-80 11945' 11850'
MD TVD
12370'-12420' 7165'-7209'
12502:12626' 7282'-7391' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
Freeze protected annulus w/20 bbls
diesel
27. PRODUCTION TEST
Date First Production IMethod of Operation (Flowing, gas lift, etc.)
8/15/94 J ESP
Date of Test Hours Tested PRODUCTION FOR OIL-BBL ~S-MCF WATER-BBL iCHOKESIZE IGAS-OIL RATIO
TEST PERIOD
I
Flow Tubing Casing Pressure 2,ALCULATED OlL-BBL GAS-MCF ~/ATER-BBL OIL GRAVITY-APl (corr)
iPress. 24-HOUR RATE
28. CORE DATA
Brief description of lithology, porosity, fractures, apparent dips, and presence o! oil, gas or water. Submit core chips.
£Cr IV rr.D
~sV, a Oit & Gas Cons. ~ommissio~
Anchorage
Form 10-407
Rev. 7-1-80
CONTINUED ON REVERSE SIDE
Submit in duplicate
· 30.
GEOL~ MARKERS - FORMATION TESTS
NAME Include interval tested, pressure data, all fluids recovered and gravity,
MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase.
Subsea
Top C 12371' 7120'
Top B 12371' 7120'
Top A 12537' 7246'
31. LIST OF A'I-rACHMENTS
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed ~ Title Drillino Engineer Suoorvisgr Date
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 cement-
ing and the location of the cementing tool.
Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In-
jection, Gas Injection, Shut-in, Other-explain.
Item 28: If no cores taken, indicate "none". R E C ~IV E D
Form 10-407
SEP ] 1994
~,~aska 0il & Gas Cons. Commission
Anchoraua
MP C-21
06/18/94
MOVING RIG TO C-21
06/19/94 385'
MOVED RIG TO 5-21 AND RU. ACCEPTED RIG @2000 HR'S ON 06/18/94.
NU DIVERTER AND MIXED MUD. PU AND STOOD BACK HWDP, FUNCTION
TESTED DIVERTER, PU BHA. DRILLED 100-292'. POH AND PU DC'S.
DRILLED 292-385'.
06/20/94 3,448'
DRILLED FROM 385-2414'. CBU. MADE WIPER TRIP TO 1091'. NO
PROBLEMS. DRILLED FROM 2414-3448'.
06/21/94 5,000'
PUMPED LO VIS/HI ViS SWEEP, DROPPED EMS, PUMPED DRY JOB. POH,
RETRIEVED EMS, CHECKED BIT, ADJUSTED MOTOR EMS CONFIRMED
MWD. RIH, PUSHED BALL F/2322-2302', HAD TO ALIGN TOOL FACE. OPEN
WISE HOLE WAS IN GOOD SHAPE, REAMED LAST STAND, NO FILL.
DRILLED F/3448-4490'. PUMPED LO/HI VIS SWEEP AND (;IRC OUT.
SHORT TRIPPED 11 STANDS, NO PROBLEMS. DRILLED FROM 4490-4603'.
ROP DROPPED TORQUE ON BTM INCREASED. PUMPED DRY JOB, POH.
CHANGED BIT AND STAB BLADE, RIH, BRIDGE AT 4483', WASHED TO
BO'i-I'OM, BIT HAD WASHED NOZZLE TUBE AND CENTER JET WAS
PLUGGED, BALLED UP. DRILLED FROM 4603-5000'.
06/22/94 7,422'
DRILLED FROM 5000-5625'. CIRC AND SHORT TRIPPED 11 STANDS,
REAMED 60' PRECAUTION. DRILLED FROM 5625-6665'. SHORT TRIPPED
11 STANDS, NO PROBLEMS. DRILLED FROM 6665-7422'.
06/23/94 8,056'
DRILLED FROM 7422-7611'. SHORT TRIPPED 11 STANDS, NO PROBLEMS.
POH TO BHA. RIH, LEDGES AT 2301 AND 2390, ROTATED STRING TO HIGH
SIDE, OK. CIRC LO/HI VIS PILL AND COND MUD. POH, OVERPULL. LD BHA
AND CLEARED FLOOR. RU TO RUN CASING.
06/24/94 8,056'
REC£ V£C
SEP ~ 5 1994
oil & Gas Cons. Commission
Anchorage
RU TO RUN CASING, CHANGED OUT TONGS, CHANGED OUT ELEVATORS.
RAN 191 JTS 9 5/8" 40# L-80 BTC CASING. CIRC. PUMPED 75 BBL'S H20,
TESTED LINES, MIXED AND PUMPED 250 SK G WITH ADDITIVES,
DISPLACED WITH 5 BBL'S H20, 697 BBL'S MUD, BUMPED PLUG, FLOATS
HELD, DISPLACEMENT AT 10 BPM, RETURNS THROUGHOUT JOB, NO CMT
TO SURFACE. RU AND DID TOP JOB W/93 SKS TYPE C CMT TO SURFACE.
NIPPLED DOWN DIVERTER AND NIPPLED UP BOP. SET TEST PLUG AND
TESTED BOP.
06/25/94 8,877'
TESTED BOPE AND INSTALLED WEAR RING. PU BHA AND 3 JTS E DP,
TESTED MWD. SLIPPED ON NEW DRLG LINE. SERVICE TOP DRIVE. RIH
PU 117 JTS E DP. TESTED CASING. DRILLED OUT FC, CEMENT AND
SHOE. MADE 10' TO 8066'. CBU AND LOT, 12.5 EMW. DRILLED FROM
8066-8877'.
06/26/94 10,554'
DRILLED FROM 8877-9087'. PUMPED LO/HI VIS SWEEP, CBU. DROPPED
EMS, POH TO 2115', RETRIEVED EMS. RIH, NO PROBLEMS. DRILLED
FROM 9087-10053'. SHORT TRIPPED 11 STANDS, NO PROBLEMS.
DRILLED FROM 10053-10554'.
06/27/94 12,112'
DRILLED FROM 10554-11087'. SHORT TRIPPED 12 STANDS, NO
PROBLEMS. DRILLED FROM 11087-12017'. SHORT TRIPPED 10 STANDS,
NO PROBLEMS. DRILLED FROM 12017-12112'.
06/28/94 12,862'
DRILLED FROM 12112-12862'. POH 4 STANDS AND MADE MAD PASS @60
FPH FROM 12560-12720'. POH TO SHOE WIPER TRIP. NO PROBLEM. RIH.
06/29/94 12,862'
FINISH SHORT TRIP TO 12862'. 5' FILL. PUMP LOW/HIGH VIS SWEEPS.
POH. L/D 162 JTS DP AND BHA. NO CORRECTION ON SLM. PULL WEAR
RING, CHANGE TOP RAMS TO 7", AND R/U FLOOR TO RUN CASING.
RUNNING 7" 26#, L-80 BTC MOD. TOTAL OF 317 JTS TO BE RUN. BROKE
CIRC @ 9 5/8" SHOE WITH NO FLUID LOSS.
06/30/94 12,862'
CIRC AND COND MUD. R/U HOWCO. TEST LINES. PUMP 20 BBL'S WATER
AND 70 BBL'S 11.2 SPACER. DROP BTM PLUG. PUMP 43 BBL'S CMT 15.8
PPG CLASS "G" AND DROP TOP PLUG. DISPLACE CEMENT WITH RIG
PUMPS. BUMPED PLUG. TEST CASING. BLED OFF PSI, L/D CMT HEAD
RECEIVE
Gas Cons. Commission
Anchoragc~
AND LANDING JT. CHANGE OUT BALLS AND INSTALL PACK OFF. TEST
SAME. CHANGE RAMS TO 3 1/2" AND TEST DOORS. P/U BIT, SCRAPER, (3)
4 3/4" DC AND 412 JTS 3 1/2" DP. TAG FC @12755'. RU TO REVERSE CIRC.
PUMP 100 BBL'S FRESH WATER, 25 BBL'S HI-VIS PILL, 50 BBL'S DIRT
MAGNET, 25 BBL'S HI VIS PILL AND DISPLACE WELL W/9.8 BRINE. FILTER
AND PUMP CLEAN BRINE.
07/01/94 12,862'
CIRC AND FILTER BRINE. ADDED CORROSION INHIBITOR ON LAST CIRC.
FINAL NTU READINGS 12 IN AND 40 OUT. PUMPED A TOTAL OF 1200 BBL.
RETEST 7" CASING. POH. L/D 3 1/2" DP AND 4 3/4" DC. FREEZE PROTECT
7" WITH 20 BBL'S DIESEL. L/D MOUSE HOLE AND CHANGE PIPE RAMS TO
5". ND BOPE. INSTALL 7 X 11" FMC TUBING HANGER W/2 WAY CHECK
AND N/U WATER DISPOSAL TREE. TEST FLANGE AND TREE. PULL 2 WAY
CHECK AND INSTALL BPV. FREEZE PROTECT 7" X 9 5/8" ANNULUS WITH
60 BBL'S DIESEL. RELEASE RIG @0200 HR'S ON 07/01/94.
07/26/94 12,840'
MOVE RIG FROM L-05 TO C-21 AND SET OVER WELL. ND TREE AND
ADAPTER FLANGE. NU BOPS. TEST BOPS. RIG DOWN TEST EQUIPMENT.
LOAD DRIFT AND STRAP 380 JTS 2 7/8" 6.5# L80 8RD. EUE TBG. INSTALL
SEAL RINGS IN MODIFIED. 159 JTS OF MODIFIED. 221 JTS 8RD. EUE. RIG
UP TO RUN TBG. TEST CSG. PU ESP WITH CENTRILIFT AND SERVICE
AND RIH W/SAME.
07/27/94 12,840'
CONTINUE TO RIH WITH ESP COMPLETION STRING. MAKE MID RUN
SPLICE IN ELECTRIC LINE. CONTINUE TO RIH WITH ESP COMPLETION
STRING. 350 JTS IN HOLE.
07/28/94 12,840'
SERVICE RIG. CONTINUE RIH W/ESP ON 2 7/8" COMPLETION STRING.
CUT ELECTRIC LINE, SPLICE IN PIG TAIL, AND MU TO HANGER. LAND
HANGER, RILDS. BOLDS. PULL HANGER TO FLOOR. TURN HANGER.
RELAND. RILDS. FREEZE PROTECT ANNULUS AND TBG W/TOTAL OF 60
BBLS MEOH AND 30 DIESEL. LD LANDING JT. PUMP OUT LINES AND
BOPE. SET TWC. ND BOP. CHECK CONNECTION ON E-LINE. NU TREE.
TESTED ADAPTER AND TREE. OK. RELEASE RIG @1800 HRS ON 07/27/94.
RECEIVED
SEP 1 5 1994
~ska b~l & Gas Cons. Commission
Anchora,~j~
TIE tN POINT(TIP) :
{~k.qt.iRt3~ I)EFTH 112.00
~ VI~% DEPTH 112.00
I~CLI~TIOH
~II~'IM 137,74
I~TITL~E(H/-S) 0.~
353.08
RECEIVED
SEP ~ 5 ]994
Aiaska Oil & Gas Cons. Commission
Anchorau~
DP'lB
ft
!12.00
2t3
269,63
:~.1,80
454,96
ft ft
0:0
101,0
56.6
~,2' 454.9i
DB:'CC~.~.~E DI.7-.$~,.~E~tEf~ at AZIMUTH
E1-W
ft ft d~9
0.00 o.0~ 0.00
0.~ 0,05 137.74
0,I0 0,10 92,73
0.29 1,10 15.47
0.37 4.07 5,25
11(K:ft
0.29
1,18,
~7:06
826.27
917
1011.~
1104.69
!sJ)0.86
1294,07
t~9,.77
96,0 642,69
89,3 731,49
93.9 ~"' ~
91.5 914.91
93,~ 1~7,76
96,2 t190,00.
~,2 1~.97
~,7 1~,91
&.4~.. 3,21 ~4..96 8.41 -0,67 5.44 ¢.¢,.~ 45 _1.47
15,(5 4.81 354,12 !4,~0 -2,!4 15.~ 35i,84 2.06
51 ,'.~. 9 ,be 350,16 54~. 47 -°.34. 51.35 34? .SD 1
~.,45 11,51 5~1,45 67.48 -12,09 &8.~
89,54) 14.62 ~ ~ 88,~ 89'
~o,Z6 -14,85 ,59 350,~. 3.37
d6,.,/ 18,29 ~2.73 ~.~c -tS,lB 116.74 ~1.04 3.73
147.47 20.~) 354.19 145.9~ -21.^v., 147 .~
182,74 ~.89 3~,,02 t81.09 -24.65 182.76 ~2,25 2.70
1485.07
1579.~
1674,59
!768.72
1864,68
95.3 !453,~
94.8 15~.,51
94.7 16!7.0I
94.1 16~.11
96,0 1772,88
222,81 26.B? ~1,90 ~0,%; -26+77 2~2.82 [.~2,53 4,57
26~,~ ~J,50 354,r~. 266.,11 -34,49 2~.34 352,62 3,%
318,19 39.06 254.45 315.73 -29,47 3I~.I? 352,87 2,70
37Q,~ 34,81 35_.7,82 368,14 -42,98 370,~ ~_~,34 2,73
426,73 36,9I 355,60 424.~ -46,~ 426,76 353,78 2,57
1960,06
205.,I,65
2147,20
2241 ,~9
~,4 1847.83
91.6 1917.47
94,7 20~,42
9'2,0 2117,ii
~5.~ 35',49 355.42 4E_J,04 -~. ~: ~5.71 ~3.%' 2.71
..,v 41,52 254.~8 ~2,~ -56.02 5~5~I9 ~W,lO 2,~'
~D9,99 44,07 353,81 606.87 -62.57 ~,v,~"~' ' 3~,11 2.73
677,12 %5,18 353,57 673.&9 -6q.95 677.22 354.07 2.24
744.40 ,. ,- ~ .~
· , ~/,~/ 351,79 74u,ao -78,53 7~,49 353,94
2426,~
2521,11
2613,41
270~¢,43
2805.24
2899,12
2993,57
3086.05
3179,85
32~.93
~67,69
3462,54
3556,94
3650,70
8746,71
93,0 2178,37
94,2 ~,17
92,3 2294,61
96,0 2~,9t
95,8 2405,09
93,9 2456,26
94,4 2505.36
94,5 2552,27
91,8 2596,12
96,I 2641,39
814.[~' 49.75 252.73
~7.13 51.42 251.42 681,75
960.15 53.18 252.74 954,~
t037,91 55,02 ~1,23 1031,09.
1116,85 56,11 349.92 I109,C~
1195,47 5'7,82 250,~ 1186,64
1276,09 59.52 351,32 12~.,34
1358,03 60.94 350.09 134.7,27
143~,59 62.00 250,63 1426,78
1523,25 61,76 350,24 1510,35
91,8 2684.25 1604,28
94,9 2727,81 1668,40
94,4 2770,93 1772,26
93,8 2813,56 1855,71
96.0 2856,46 1941,59
62.53
62.79
62.~,
63,07
-87,96 814.45 353.60
-98.00 667.18 253.66.
-10&.05 960,19 353,54
-llB,9O 1037.~ 353,42
-131,85 1116,~6 353.22
-145,02 1195,47 353,03
-157,b-5 1276,10 352,91
-170,BO 1256,05 352,78
-184,~ 1476,~: 352+64
-198,38 1523.32 35.2,52
350,14 1590,~ -212,20 1.~,~ 252,40
349,48 1673,22 -227,11 1688,57 252,27
350.62 1755,94 -241.62 1772,49 252,17
251+32 1838,41 -2F:M,73 1855,98 252,11
353.02 1923,~ -266.43 1941,87 352,11
2,16
2.~
2,~
1,~
1,98
1,88
1
0,43
O,B?
0..~
1,oe.
0,70
1,78
MEA.9]R~ tN"IEF~J~ "~.~SIC~
DEPTH gE"tH
ft ft ~t
4124,74 93,3 "~
DEF'~L~q:£ DISPL~]~E'4? at
ft ft
-275,74 2026,10
-285,5'? --,-~ ,",l
f.. J,. i. Z, r ..,.
-?-7¢,07 2i77,02
-335,2i
-3t4,04 234,6,?4
AZI~]%H
.52£.20
352
~2.31
DLS
lOOit
I
1.78 ·
1
0.52
43!4 ~
·
~'~ _.
4~J~+17
~,'.~,4~
48433.88
4979,20
~)74.47
94,9 31~w,77
~,5 3!45,98
97,1 3188,39'
93.8 37_7i
95,0 3313.97
95,4 3%~-j6.26
f5.3
95,3 3442,03
c[3,9 3484,41
2452.18 ,63.P.4 354,26243i,02
2536,13 63,85 ~3.~.-', 25.-!4,53
~""'~ -" A4.37
,...,,'..,,,4/ . . . ~..,'.,,41 2601,44
27(.m,_' ,. 40 E$,.A6 ~5,06
Z7~2,30 63.43 355,77' 2769.75
2877,15 ~:.57, 357., ,21 28~ .58.
2%2.50 63.81 35~.37
~47,~4, ~:.06 355.14 3025,,00
3132+~ &3,09 t~.,07 31(F,;.56
3216.30 63.24 ~5,54 3192.98
-32~,56 2452,~ 352,44
-331,24 25%,2~ 352,50
-340,17 2623,.,,~g 35_2,55
-347,% 2705,4? 352,62
-354,67 L~92.3~. 352,70
-~¢,86 28.77,1~ 352,81
29.~.~ 352,~
-370,9~ 3(.~7.~ 353,01
-378,q7 313%,57 353.05
-S~6,55 ~I6.~ .-'353,10
0.74
0.77
0.72
1.40
1,40
5261.t~,
5356.13
545i.23
5543J6
5638,89
94,8 3567,18
~5.t 3b~)8.65
95.3 36yo.6..,
32~¢.C~ 63,68 253,94 3'2..'5,93
~-L.~,81 ~,38 353,..~, ~.~),~
3470..~.'. &3.9I ~5,58 ~45,87
~2,91 62.98 ~.13 ~28,i3
~7.61 62,~ 353.33 ~12.33
-~¢4,20 3"27~.56 353.14
-403.47 ~4,81 353,15
-411.57 3470.36 353,19
-41~,97 [552.92 353,23
-428,22 3637,63 ~3,24
1,~
0.¢3
1
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5733.65
5828,!1
5923,35
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94,8 3737,42
94,5 3780.74
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99.9
372i.65 62.~ 354,16
3805.58 62,~ 553.76 3,'77.9.35
~).22 62,55_, 351.80 ~.'$,.31
~. ~+C~. 62,27 ~2,24 3~47.37
405B.It 62.0! 352.-~,' 4029,65
-437,~ 3721,E4, 353,25
-446.'_,22 3,?:4~,~) 353.27
-454,.B6 3890,23 353.26
-479,81 4055,12 353,2~
0,78
0,52
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0.50
0,28
6~6.63
6301.~
6395,63
6490,.'-77
6583.78
93.6 3q56.64
9%1 4001.33
93.9 4046.19
95.3 4091.6!
92+8 4134.54
4140,71 61,92 3~3,17 4111,6Q
4224,70 62.05 353,69 4195,03
4307,14 60.85 ?J2.51 4276.88
4[~:/0.95 62,25 354.~0 4360.19
4473,Z~ 62,65 353,~ 4442,09
-490,25 41~,72 353.20
-499,66 4224,71 353,20
-509,76 4307.15 353,20
-518,95 4~0.96 353,2)
-526,92 . .7o.~4 353,24
0,83
1,69
2.65
0.97
~-q4K),24
6773.43
~,71.22
6965,38
7059,79
96.5 4179.21
93.2 4222.60
97.8 4267.36.
94.2 4309.42
94.4 4350.78
4556,71 62,17 352,63 4527,00
.4641,15 .62,33 350,67 4608,59
4728,04 63,19 351,65 4694,50
4812,26 63.75 352,49 4777.93
4897.12 64.:30 351,41 4~4.1 +97
-5~,B7 4556.72 353,24
-548,85 4641.16 353,21
-562.21 4726.04 353,17
-573,84 4812,27 ~3.15
-585,73 4897.12 353,13
1.35
1.07
1.25
1,00
1.lB
7153,22
7246,10
7341,07
7436,04
752~,15
93.4 4390,84
92,9
~5.0 4470,B7
9%0 4511,50
93,1 4551,42
4981.52 ~.93 352.73 4945.57
5065.58 64,75 351.78 5026.B7
5151.44 64,64 352.59 5113.q5
5237,2B 64.70 ~4.00 51~,20
5321.36 64,52 355.30 5282,95
-597.37 4981.52 353,11
-60B,70 5065'56m" 353'10
--620'~ 5151'44 353'08
-&.~O,40 5237,28 353.09
-638,25 5321,36 353,11
1.44
0.94
0.79
1.~
1,~
DEF?H
ft it
7625.~ 96.2 45~.26
~19,~. 94,5
7614.65 94.8 4676.68
7976.47. _ ~.~[']'. ~ 4745.87
T~I;~T STATIL~ AZIML.%~
it d~ dee it
~.,,7/ 5367,29
~27.89 63.91 ~:
545~,49 ~;,67 266.~' 5453,98
5664:,53 ~.~: 359.27
5722,73 AS,Oa ~,;, i~
it it
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-649.40 ~92,51
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. ._': :'
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8316.43
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8978.40
150.7 $~:,?. 14
~.4 4M6.94
4967.5.~
94.7 SO. Il.71
94.2 5053.22
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97.5 51~.8i
92,6 5175,65
5858,82 65,~;-'. 358:84 5522,14
6031
6201,81 ~:.~ 3%.20 61~.. 17
62~.51 63.83 ~..,6.14 62.54.9
6370,~ E.~:.91 L'~_,. 9.-7 6.%335.42
~53.76 64.14 ~" ......
6~I,~ 64,60 356,31
6624.96 64,43 353.66 6569,28
-656,50 58_59,04
%58,82 5945,44
· ...?) ,",~-,
--._-:t,_~ + 1 o
-672,&5 6287.~' 353,PZ
-677,~ 637i .59 353.87
-6~2,28 ~5.4.47 ~3.93
-~.~7. ~) 6~2, ~ 353.97
-65.'4.~ ~.78
0.25
0.72
0.45
1.11
1.65
0,81
0,79
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9177,53
9273,10
c~C~,',,94
944.7,52
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100,6 5~,7,57
6718,59 ~.~, 3_,:_,,52 6682,54
.56,33.67 64.04 Si6.(~ 6767,49
~B,9',72 64..,51 352.28 /:~53.1 i
6974.~ ~.91 353,6i 6927,31
7065,5~. 64.77 350,~ 7027,~)
-703,22 671~.44
-709,46 6804.57 3..4.02
-718.~ /.~_,90.64 ~4.02
-728,~ 69~,47
-740,96 7~,~.
1.64
0.70
3.59
1.35
r 5
9656,92
9757:26
9853,79
7151.65 ~,89 353.10 71i2.74
7~...59 ~.68 ~2,97 7197,05
7.~6,49 63.61 351,52 7256,14
o%.18 7~7,,74
7412,85 63.37 ~ ~ ~ ~
7494.76 63.44 351,31 7452,90
-~2,%' 7152.49 355.96
-763.2$' 7237.42 353.95
-T75.42 ~"Y~ ~ 3'33.93
· .
-766,91 7413.62 353,91
-797,97 745.5.50
2.15
1,~9
1.30
1,55
1,BS
l(X)Zg,89
10123,85
10218,44
10313,27
10412.97
1O510,35
1O6O4,89
10701,7~
1O795,03
10~7.~
84.5 5635.81
94.0 5678.68
94.6 5721,54
94.8 57_/,,4.20
~.7 5~4)9,29
97.4 5053,83
94,5 5098.44
96,9 5946.49
'5'3.2 55.'94.75
92.8 6044.92
7569.99 62,76 .348.74 ~2Z,11
7653,38 62.95 2~9,13 7609,16
7737,58 63,16 350,89 7692,21
7822,14 63,37 349.01 7775,59
7910.87 62.~. 349.63 7~,2.97
7997,17 62,73 346,94 7947,77
EK)BO.07 ~,95 247,48 ~29,04
8163,~ 59.56 348,62 8111,~
8243.41 50.07 348.46 8189.54
8321.t8 S6.46 346,1~ 8265.96
-811,02 ~70..~. ~3,85
-827,06 7653,98 ~2,60
-841,69 ?/35.12 353.76
-856,47 7822.62 353.71
-872.95 7911.2~
-890,53 7997,51 353,61
-905,99 (K~).33 3'33,54
-926.42 8164.06 353.46
-942.27 8243,57 ~3.~
-956,07 6321.S~3
2.82
0,42
1,68
1,79
0.76
2.47
1,95
i .74
1,63
1,76
10979.75
11062,14
11156,46
11~52,49
11345,71
92.0 6097,46
82.4 6147, .44
94,3 6207,61
96.0 6271,~0
93.2 6336,41
8396.~ 348 .TM 8339
8461.6~ ~9.2Q 8404,11
8534.11 248.48 i)475.27
&~73.36 349.74 8545.50
~72.49 ~2.07 8611 °03
53.81
51.52
49.20
46.9t
45.33
-973,30 8396,45 253.34
-985,95 8461,75 353.31
-1000,00 0534,16 353.27
-1013.51 8605,39 353,24
-1024,14 ~72,51 353.2",'
2.89
2.86.
2.52
2.56
2.47
D?c.w DEPTW.
ft ft ft
11628,64
!1722,7~ 94,! 66i8,29
11517,56 94,~ ' 6694,S~,
*****::::~.:~ ANADHLL **************
SI$..".,'Y ~O]LATI~;
TARGET ~ATD~ AZI~ ~TI~
S~:Tt~.~ I~. N/-S
ft 6e.~ ~eq
8736,5~ 43.77 ~1.~ 6677.18
8?76,?2 35.76 ~'~, ,72 8715
DEPARTL~ DIoPL~ at
I i910,65
l;vv .... i8
12299,55
12~4,60
12478.i8
12~., ~ .~:,
12~6,77
12761
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9S.9 893t
94,5 7012,8.?
94,0
94,0
94,2~
94.4:74~50
94,7 7511
.34.,37 ?,0,90 89~.53
'" ~ "' ~"'
3i.i6 S48,21 ~70,68
~c,,4 352,16
27,96 SSI ,47 9750,04
27,64 ~,~,43
27,52 352,48
27.16 ~I.13. 7379.71
9494.65 27,I6 351 ,!3 94~,03
da~
353,20
353,19
-two,a7 90~.39 .353,17
-10&2,56 9085.:¥' 353,15
-1072,66 9136.~ ~3,13
-I108,4! ?~8,81 355,10
-1120,99 7317.72 355.0?
-Ii27,90 7361,60 o~ n~
-1134,35' 9465.~ 353,07
-I140.59 9445.80 353,07
-1147,66 94?4.65 353,06
DLS
1M~ft
1,75
2,53
2,~
2,03
1.5;7
1,50
2.20
1,i3
0,49
0,62
l,O1
0,76
ALASKA OIL & GAS CONSERVATION COMMISSION
Attn. LARRY GRANT
3001 PORCUPINE DR.
ANCHORAGE
AK, 99501. USA
Date: 1 August 1994
RE: Transmittal of Data
ECC #: 6239.02
Sent by: U.S. MAIL
Data: NONE
Dear Sir/Madam,
Reference:
BP
MPC - 21
MILNE POINT
NORTH SLOPE, AK
Enclosed, please find the data as described below:
Prints/Films:
Prints/Films:
1 COLLAR/PCKR FINAL BL Run # 1
1 COLLAR/PCKR RF SEPIA Run # 1
Please sign and return to: Atlas Wireline Services
5600 B Street
RECEIVED
Anchorage, AK 99518
~~~.. _ l/°dney D' Paulson AUG'O31994
Received by: /_~~~ / / ].W~,/~--~-----~~ 'Alaska Oil & ~as Cons. Commission
Please s~_~n, and return to:
Petrotechnical Data Center
BP Exploration (Alaska)
900 East Benson Boulevard
Anchorage, A~e~tl~a 99~08
Received
--
I I Ill, I I
Date
ALASKA OIL & GAS CONSERVATION COMMISSION
Attn. LARRY GRANT
3001 PORCUPINE DR.
ANCHORAGE
AK, 99501. USA
Date: 19 July 1994
Transmittal of Data
Sent by: ANCHORAGE EXPRS
Dear Sir/Madam,
Enclosed, please find the data as described below:
WELL # DESCRIPTION
MPC - 21
MPC-22
~ PFC/PERF FINAL BL
! PFC/PERF RF SEPIA
G /CCL FINAL BL
~ GR/CCL TCP FINAL BL
i GR/CCL FINL.RF SEPIA
1 GR/CCL TCP- RF SEPIA
ECC No.
Run ~ 1 6239.01
Run # 1
Run # 1
Run ~ 1
Run ~ 1
Run # 1
6242.01
Please sign and return to: Atlas Wireline Services
5600 B Street
Suite 201
Anchorage, AK 99518
Attn. Rodney D. Paulson
Received by:
Please sign and return to:
Petrotechnical Data Center
BP Exploration (Alaska) Ino
900 East Benson Boulevard
Anchorage, Alas~a 99908
Date:
~.~ ~ved by
ALASKA OIL & GAS CONSERVATION COMMISSION
Attn. LARRY GRANT
3001 PORCUPINE DR.
ANCHORAGE
AK, 99501. USA
Date:
RE:
ECC #:
Sent by:
Data:
13 July 1994
Transmittal of Data
6239.00
LDWG
Dear Sir/Madam,
Reference:
BP
MPC - 21
MILNE POINT
NORTH SLOPE, AK
Enclosed, please find the data as described below:
1 /~L%RKED LINE GR RF
1 PFC/PERF FINAL BL
1 M_ARKED LINE GR-BL
Please sign and return to: Atlas Wireline Services
5600 B Street
Suite 201
Anchorage, AK 99518
Attn. Rodney D. Paulson
Prints/Films:
Run # 1
Run # 1
Run # 1
Run ~ 1
Received by:
Date:
Ple~-:~st- .~..~. and return to:
Pe~:r~?.ec~ical Data Center
BP Exploration (Alaska) Inc
900 East Benson Boulevard
Anchorage, Alaska 99508
Received by
Date
ALASKA OIL & GAS CONSERVATION COMMISSION
Attn. LARRY GRANT
3001 PORCUPINE DR.
ANCHORAGE
AK, 99501. USA
Date: 12 July 1994
RE: Transmittal of Data
ECC #: 6239.00
Sent by: U.S. MAIL
Data: LDWG
Dear Sir/Madam,
Reference: BP
MPC - 2 !
MILNE POINT
q~~ NORTH SLOPE, AK
Enclosed, please find the data as described below:
Tapes/Diskettes:
Prints/Films:
/MARKED LINE GR TAPE Run # 1
/
1 / MARKD.LINE GR LISTE n # 1
/
Please sign and return to: Atlas Wireline Services
5600 B Street
Suite 201
Anchorage, AK 99518
Attn. Rodney D. Paulson
Received by: Date:
Please s ig~n and return to:
Petrotechnical Data Center
BP Exploration (Alaska) Inc
900 East Benson Boulevard
Anchorage, Alaska 99508
Received by
Date
MEMORANDUM
TO:
THRU'
State of Alaska
Alaska Oil and Gas Conservation Commission
David John~.~~ DATE: July 25, 1994
BI !, ~~ FILE NO: AWQIGXBD.doc
P. !. Supervisor -r/~s
FROM: Bobby Fost~ ~-~'- SUBJECT:
Petroleum In~pe(~tor
BOPE Test - Nabors 4ES
BPX - MPU - C-21
PTD # 94-t6-3
Milne Point Field
Monday, July.2.5, 1994: I traveled this date to BPX's Milne Point Field well C-21
and witnessed the BOPE test on Nabors rig 4 ES.
As the attached BOPE Test Report shows, there was 1 failure. A flange on the choke
line leaked. This flange was tightened and test OK~
The rig was fairly clean and all the equipment seemed to be in good working order.
This rig was just mobilized to began completion work on wells that were drilled, but
not completed.
.S. um .ma.ry: I witnessed the BOPE test on Nabors rig 4ES - test time 2.5 hours - 1
failure.
Attachment: AWQIGXBD.XLS
STATE OF ALASKA
OIL AND GAS CONSERVATION COMMISSION
BOPE Test Report
OPERATION: Drlg:_____ Workover:
Drlg Contractor: NABORS
Operator: .. _ BPX
Well Name: C-2Y
Casing Size: 7" Set ~
Test: Initial X Weekly
Rig No. 4ES PTD#
Rep.:
Rig Rep.:
f2,840 Location: Sec.
Other
94-123
DATE: 7/25/94
, ,
Rig Ph.# 65g-2234
LARRY MA'~'ERS
DANNY HEBERT
10 T. Y3N R. IOE Meridian UM
Test
MIEC. INSPECTIONS: FLOOR SAFETY VALVES: Quan. Pressure
Lecatlon Gen.: OK Well Sign OK Upper Kelly / IBOP 1 ] 500/5,000
Housekeeping: OK (Gen) Dri. Rig OK Lower Kelly / IBOP 'f. i't500/5,000
Reserve Pit N/A Ball Type ~ 500/5,000
' " Inside BOP "1 ' 500/5,000--
BOP STACK: Quan.
Annular Preventer f
Pipe Rams 1
Lower Pipe Rams
Blind Rams f
Choke Ln. Valves ~
HCR Valves 1
,
Kill Line Valves 2
Check Valve N lA
Test
Pressure P/F Test
30Q/3,000 P Pressure
0 P 500/5,000
· ,
MUD SYSTEM: V'sual Alarm
Trip Tank N lA NO
Pit Level Indicators YES UGHT
Flow Indicator YES UGHT
Meth Gas Detector ' No ~ NO
H2S Gas Detector YES YES
, · ~
P/F
P
P
P
L
P
CHOKE MANIFOLD:
No. Valves 8'
No. Flanges ~6'
Manual Chokes ' ~'
Hydraulic Chokes '/
Funclfoned
Functioned
P/F
P
P
P
,
ACCUMULATOR SYSTEM:
System Pressure
Pressure After Closure
,,
200 psi Attained After Closure
System Pressure Attained
Blind Switch Covers: Master:
Nitgn. atrs
2200
minutes 30 sec.
~
minutes 41 sec.
YES Remote: YES
_. . J.l L~ ..... 11 I · · IL I I . _ ! _ ~ ~ ,
Number of Failums: I ,TestTk~e: 2.5 Hours. Number of v;a'lves tested 1~" Repair or Replacement 0f Failed
Equipment will be made within' 0 days. Notify the lnspect~ and follow with Wdtten or Faxed verification t~
the AOGCC Comm~ Office ~c Fax No. 276-7542 Inspector North Slope Pager No. 659~607 or 3687
If your call is not returned by the inspector within 12 houm please contact the P. i. Supervisor at 279-1433
I I. II I III I L I I · , I~ ~ I I
REMARKS:
orig-Weli File
c - OperJP, ig
c - Database
c- Trip Rpt F~e
c- Inspector
STATE WrTNE~S REQ0 D? '
YES X NO
24 HOUR NOTICE GIVEN
YES X NO
!
I I
By:.
BOBBY D. FOSTER
FI.-021L (Rev. 7/19) ArVVQi~D~
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSICh~I
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
Abandon __ Suspend __ Operation Shutdown __ Re-enter suspended well __
Alter casing Repair well~ Plugging ~ Time extension__ Stimulate x
Change approved program x Pull tubing__ Variance Perforate x Other__
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P. O. Box 196612, Anchorage, Alaska 99519-6612
4. Location of well at surface
1139' NSL, 2226' WEL, SEC. 10, T13N, RIOE
5. Type of Well:
Development X
Exploratory __
Stradgraphic __
Service
6. Datum elevation (DF or KB)
KBE = 46' feet
7. Unit or Property name
Milne Point Unit
8. Well number
MPC-21
At top of productive interval 9.
5079' NSL, 3330' WEL, SEC. 3, T13N, RIOE
At effective depth 10.
N/A
At total depth ~ -~ .' :' ~:
5260' NSL, 3351' WEL, SEC. 3, T13N, RIOE ' ~ /'' 'i ?
Permit number
94-80
APl number
50- 029-22486
11. Field/Pool
Mi/ne Point - Kuparuk River
12. Present well condition summary
Total depth: measured
true vertical
Effective depth' measured
true vertical
Casing Length
Structural
Conductor 80'
Surface
Intermediate
Production
Liner
Perforation depth: measured None
7422 feet Plugs (measured)
4508 feet
feet Junk (measured)
feet
Size Cemented
13-3/8" 250 sx Arcticset (Approx.)
true vertical None
Tubing (size, grade, and measured depth) None
Packers and SSSV (type and measured depth) None
Measured depth
True vertical depth
112'
112'
REC£IVF. D
Gas 6OHS. Commission
Anchorage
13. Attachments
Description summary of proposal x Detailed operations program
BOP sketch
14. Estimated date for commencing operation
7/1/94
16. If proposal was verbally approved Oil x
Name of al)prover Date approved Service
17. I hereby cert~y that the foregoing is true and correct to the best of my knowledge.
15. Status of well classification as:
Gas
Suspended
Title Drilling Engineer Supervisor
IAppr°va'N --? /
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity BOP Test~ Location clearance ~
Mechanical Integrity Test~ Subsequent form required 10- ~¢ 1'
Approved by order of the Commission
Original Signed By
David W. Johnston
Form 10-403 Rev 06/15/88
Commissioner
~pprovea Copy
Returned
·
Date Cf'Z~f¢'?
SUBMIT IN TRIPLICATE
Milne Point C-21 Completion
Obiective:
The objective of the following work is to complete the well as a Kuparuk ESP
producer. The well is to be drilled with Nabors 22E and 7" casing run and
cemented. A temporary 6" working or frac tree consisting of 3 manually
operated valves will be installed to allow hydraulic fracturing down the 7" casing
with the use of a tree saver to protect the wellhead. Following the hydraulic
fracture treatment and sand cleanout, Nabors 4ES will be used to complete the
well. Note that a liquid level control valve set in the packer/tailpipe assembly
below the ESP will be used in this well in place of a typical production packer
and SSSV.
Work Outline:
.
,
.
.
.
.
RU wireline and perforate the Kuparuk sands. RD wireline.
RU frac equipment and perform hydraulic fracture treatment down the 7"
casing. RD frac equipment.
RU coiled tubing and cleanout frac sand to PBTD. Displace wellbore to
kill weight brine and verify well is dead. RD coiled tubing.
RU wireline and install Baker Model D packer with short tailpipe and wire
wrapped screen below it. Liquid level control valve is to be installed in
this assembly.
MIRU Nabors 4ES and complete well with 2 7/8", 6.5 #/ft, L-80 tubing and
electrical submersible pump. Pressure test tubing. RDMO 4ES.
Place well on production.
RECEIVED
/-,.!asi.',a Oii & Gaf:. Con~. Commission
,Anchorage
June 22, 1994
STATE Of ALASKA ~-'
ALASKA OIL AND GAS CONSERVATION COMMISSION
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
Abandon__ Suspend __ Operation Shutdown __ Re-enter suspended well
Alter casing __ Repair well Plugging __ Time extension __ Stimulate __
Change approved program x Pull tubing__ Variance__ Perforate __ Other__
2. Name of Operator
BP Exploration (Alaska) Inc.
3. Address
P. O. Box 196612, Anchorage, Alaska 99519-6612
5. Type of Well:
Development x
Exploratory __
Stratigraphic
Service
4. Location of well at surface
1139' NSL, 2226' WEL, SEC. 10, T13N, RIOE
At top of productive interval
5079' NSL, 3330' WEL, SEC. 3, T13N, RIOE
At effective depth
N/A
At total depth
5260' NSL, 3351' WEL, SEC. 3, T13N, RIOE
6. Datum elevation (DF or KB)
KBE = 46' feet
7. Unit or Property name
Mi/ne Point Unit
8. Well number
MPC-21
9. Permit number
94 -8O
10. APl number
5O- O29-22486
11. Field/Pool
Mi/ne Point - Kuparuk River
12. Present well condition summary
Total depth: measured
true vertical
Effective depth: measured
true vertical
Casing Length
Structural
Conductor
Surface
Intermediate
Production
Liner
Perforation depth: measured
true vertical
Tubing (size, grade, and measured depth)
Packers and SSSV (type and measured depth)
feet Plugs (measured)
feet
feet Junk (measured)
feet
Size Cemented
Measured depth
True vertical depth
RECEIVED
JUN 'i6 1994
Aj~$ka 0il & Gas Cons. Commission
Anchorage
13. Attachments
Description summary of proposal x
Detailed operations program
BOP sketch
14. Estimated date for commencing operation
6/15/94
16. If proposal was verbally apprOved Oil x
Name of a. ppr~/ver Date approved Service
17. I hereby ce.,~ ~,~t t/~~oin/g iTue and correct to the best of my knowledge.
Signed
15. Status of well classification as:
Gas
Suspended~
Title Drilling Engineer Supervisor
Date
FOR COMMISSION USE ONLY
Conditions of approval: Notify Commission so representative may witness
Plug integrity__ BOP Test__ Location clearance__
Mechanical Integrity Test ~ Subsequent form required 10- ~(o 7
Original Signed By
Approved by order of the Commission David W. ,lnh_n._~to.n.
--orm 10-403 Rev 06/15/88
Commissioner
Approved Copy
Returned
I Approval No.
Date
SUBMIT IN TRIPLICATE
BP EXPLORATION
To:
From:
Date:
Subject:
David W. Johnston, AOGCC
Joe Polya, Prudhoe Bay Drilling
June 13, 1994
Request to Change to 9-5/8" Surface Casing
Depth for the MPC-21 Well.
Mr. Johnston,
BPX received an approved permit for the MPC-21 well which will
probably be spudded aroung June 16, 1994. In an effort to reduce
driling costs, we would like to change the 9-5/8" surface casing depth to
3600 feet md/2839 feet tvd.
BP recently set shallow surface casing on the MPL-15 well at 3505'
md2740' tvd. That well is currently planned to TD the 8.5" hole section
today. Conoco had successfully set a shallow surface casing at +/-2500
tvd on two previous L Pad wells (MPL-03 and MPL-12). With the F Pad
project coming up, this could amount to a significant cost savings spread
out over a dozen or more wells.
BPX will run GR/Res LWD through the Ugnu and Schrader Bluff sands
on this well. If hydrocarbons are present, a two stage cementing tool will
be employed to place cement 500' above the top oil bearing formation.
Thank you for your time and cooperation concerning this matter. I can be
contacted at 564-5713 (or pager 275-4447) if you have any questions.
Respectfully,
Joe Polya, Consultant
Prudhoe Bay Drilling
BPX
RECEIVED
JUN 1 6 1994
Ai~ska Oil & Gas Cons. Commission
Anchorage
Name:
MPC-21
Well Plan Summary
] Type of Well (producer or injector): I Producer
ISurface Location:
Target Location:
Bottom Hole Location:
1139' NSL 2226' WEL Sec 10 T13N R10E UM., AK.
5079' NSL 3330' WEL Sec 03 T13N R10E UM., AK.
5260' NSL 3351' WEL Sec 03 T13N R10E UM., AK.
I AFE Number: 1330023 I
IEstimated Start Date: I June 15,
1994 !
I Rig: I Nabors 22E
IOperating days to complete: 120
IMD: I 12774' I ITVD: 17436'ss I IKBE: 146'
Well Design (conventional, slimhole, etc.): I Slimhole
Formation Markers:
Formation Tops MD TVD (BKB)
base ,permafrost 1874' 1796'
MA 6439' 4076'
NA 7013' 4326'
OA 7403' 4496'
OB 7494' 4536' ~ E C [:IV ~ D
OG 7919' 4721' "~ ~' ~'
HRZ 11660' 6546'
TopKup 12055' 6861' JU,N i ~ 1534
Top LZ 12225' 7006' t,i~..qka 0i~ & Gas Cons. Commi.q~qir
Target 12410' 7166' ^~h0ra_~
Total Depth 12774' 7482'
Casing/Tubin: Program:
Wt/Ft
Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm
Tbg O.D. MD/TVD MD/TVD
24" 13 3/8" 54.5# K-55 weld 80 32/32 112/112
12 1/4" 9 5/8" 40g L-80 btrc 3569 31/31 3600/2798
8 1/2" 7" 26g L-80 btrc 12744 30/30 12774/7482
Internal yield pressure of the 7" 20g casing is 7240 psi. Worst case surface pressure would occur
with a full column of gas to the reservoir at 7040 TVDSS. Maximum anticipated surface
pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the
internal yield pressure rating of the 7" casing.
Logging Prog
]Open Hole Logs:
Surface
Intermediate
Final
[Cased Hole Logs:
ram:
LWD GR/Resistivity (DPR) Optional
None
LWD GR/~Resistivity/Neutron/Density, Possible RFT
GR/CCL/Cement Bond Log only if necessary
Mud Program:
] Special design considerations ] None- LSND freshwater mud
Surface Mud Properties: ]
Density Marsh Yield 10 sec 10 rain pH Fluid
(PPG) Viscosity Point §el gel Loss
8.6 50 15 8 10 9 8
to to to to to to to
9.6 90 35 15 30 10 15
Intermediate Mud Properties: N/A ]
Density Marsh Yield 10 sec 10 rain pH Fluid
(PPG) Viscosity Point §el gel Loss
Production Mud Properties:
Density Marsh Yield 10 sec 10 rain pH Fluid
(PPG) Viscosity Point gel gel Loss
9.0 40 10 3 7 8.5 6-8
to to to to to to to
10.4 50 15 10 20 9.5 4-6
Well Control:
Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer
will be installed and is capable of handling maximum potential surface pressures.
Diverter, BOPE and drilling fluid system schematics on file with AOGCC.
Directional'
·
[KOP: 1350'
IMaximum Hole Angle:
Close Approach Well:
64.0 degrees ]
None
Disposal:
Cuttings Handling: CC2A / Central Reserve Pit During Break-up.
Fluid Handling: All drilling and completion fluids can be annular injected. Haul dLJ~q 1 $ 1994
to CC2A / Annular Injection During Break-up.
~,.i~,ska Oil & Gas Cons. Commission
Annular Injection: There are presently no Injection Wells availabe on C-Pad for Anchorage-
injection; however, the MPC-21 annulus in permitted.
DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS.
AREA WELL PREV VOL PERMII-FED PERMITTED DATE
INJECTED VOL
(BBLS) (BBLS)
n/a Well Name 0 35,000 XX/X/XX-X/X/×
n/a Well Name 0 35000 XX/X/XX-X/X/×
n/a Well Name 0 35000 XX/X/XX-X/X/X
MPC-21 WELL
9-5/8" SURFACE CASING
CEMENT PROGRAM - HALLIBURTON
CASING SIZE: 9-5/8"
CIRC. TEMP 50 deg F at 2500' TVDSS.
SPACER: 75 bbls fresh water.
LEAD CEMENT TYPE:
ADDITIVES: Retarder
WEIGHT: 12.0 ppg
APPROX #SACKS: 710
Type E Permafrost
YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk
THICKENING TIME: Greater than 4 hrs at 50° F.
TAIL CEMENT TYPE:
ADDITIVES: 2.0% CaCI2
WEIGHT: 15.8 ppg
APPROX #SACKS: 250
FLUID LOSS: 100-150 cc
Premium G
YIELD:1.15 ft3/sx MIX WATER: 5.0 gal/sk
THICKENING TIME: Greater than 4 hrs at 50° F.
WAYne: o R E C E IV E D
TOP ,,lOB CEMENT TYPE: Permafrost C
ADDITIVES: Retarder
WEIGHT: 15.6 ppg
APPROX NO SACKS: 250
YIELD: 0.96 cu ft/sk.
d U [~l '1 6 1994
oil & Gas Cons. Commission
Anchorage
MIX WATER: 3.7 gal/sk
CENTRALIZER PLACEMENT:
1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 10 joints of casing (10 required).
2. Place all centralizers in middle of joints using stop collars.
OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and
ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to
pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is not necessary.
CEMENT VOLUME:
1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30%
excess.
2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30%
excess and from 1500' md to sudace with 100% excess.
4. 80'md 9-5/8", 40# capacity for float joints.
5. Top Job Cement Volume is 250 sacks.
ALASKA OIL AND GAS
· CONSERVATION COMMISSION
WALTER J. HICKEL, GOVERNOR
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
TELECOP¥; (907) 276-7542
June 10, 1994
Adrian Clark
Drilling Engineer Supervisor
BP Exploration (Alaska), Inc.
P O Box 196612
Anchorage, AK 99519-6612
Re:
Milne Point MPC-21
BP Exploration (Alaska), Inc.
Permit No. 94-80
Sur. Loc. l139'NSL, 2226'WEL, Sec. 10, T13N, R10E, UM
Btmnhole Loc. 5260'NSL, 3351'WEL, Sec. 3, T13N, R10E, UM
Dear Mr. Clark:
Enclosed is the approved application for permit to drill the above
referenced well.
The permit to drill does not exempt you from obtaining additional
permits required by law from other governmental agencies, and does not
authorize conducting drilling operations until all other required
permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with
20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE
test performed before drilling below the surface casing shoe must be
given so that a representative of the Commission may witness the test.
Notice may be given by contacting the Commission petroleum field
inspector on the North Slope pager at 659-3607.
Chairma2 ~ .
BY ORDER OF THE COMMISSION
dlf/Enclosures
cc:
Department of Fish &-Game, Habitat Section w/o encl.
Department of Environmental Conservation w/o encl.
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
PERMIT TO DRILL
2O AAC 25.005
la. Type of work Drill [] RedrillF']llb. Type of well. ExploratoryF-] Stratigraphic Testl-! Development Oil[]
Re-Entry [] DeepenF11 Service [] Development Gas [] Single Zone [] Multiple Zone []
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
BP Exploration (Alaska) Inc. KBE = 46' feet Milne Point Unit-Kuparuk Sands
13. Address 6. Property Designation
P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 47434
4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025)
1139'NSL, 2226' WEL, SEC. 10, T13N, RIOE Milne Point
At top of productive interval 8. Well number Number
5079'NSL, 3330' WEL, SEC. 3, T13N, RIOE MPC-21 2S100302630-277
At total depth 9. Approximate spud date Amount
5260'NSL, 3351' WEL, SEC. 3, T13N, RIOE 6/15/94 $200,000.00
12. Distance to nearest !13. Distance to nearest well 4. Number of acres in property15. Proposed depth(MDa, dTVD)
property line
ADL 355017-20' feet No close approach feet 2560 12774'MD/7482' TVD feet
16. To be completed for deviated wells 17. Anticipated pressure (~e 2o AAC 25.035 (e)(2))
Kickoff depth 350 feet Maximum hole an~lo ¢,, o Maximum surface 3330 psig At total deplh (TVD) ~00'/4~9(~ psi¢
18. Casing program Setting Depth
s~ze Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data)
24" 13-3/8" 54.5# K-55 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.)
12-1/4" 9-5/8" 40# L-80 BTRC 8002' 31' 31' 8033' 4771' 1542 PF 15"/250 sx "G"/250 sx PF "C"
8-1/2" 7" 26# L-80 BTRC 8002' 30' 30' 12774' 7482' 210 sx Class "G"
19. To be completed for Redrill, Re-entry, and Deepen Operations.
Present well condition summary
Total depth: measured feet Plugs (measured)
true vertical feet
Effective depth: measured feet Junk (measured)
true vertical feet
Casing Length Size Cemented Measured depth True Vertical depth
Structural
Conductor RECEIVED
Surface
Intermediate
Production JU~'~ -6 1994-
Liner
~ ~'-,-"'" Oil & Gas Cons. Commission
Perforation depth' measured '~\:~-°'"~
true vertical Anchorage
20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[]
Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[]
hereby ce~fy/j'h~t ~,l~e,,forego'.lcg is true and correct to the best of my knowledge
Signed /~ L.~ ~'~77-/ '/ /'/ //" - '~ Title Drilling Engineer Supervisor Date ~/,~/~L/-
Commission Use Only
Permit Number IAPI number Approval date ISee cover letter
- - ~-'/O - ¢' cf, Ifor other requirements
Conditions of approval Samples required [] Yes J~ No Mud Icg required []Yes [],No
Hydrogen sulfide measures [] Yes ~ No Directional survey required ~ Yes [] No
Required working pressure for BOPE [] 2M; F-13M; [-15M; I-I10M; B15M;
Other: Original Signed By by order of
_Approved by David W, Johnston Commissioner [ne commission Date
Form 10-401 Rev. 12-1-85 Submit in tril
I Well Name: [MPC-21
Well Plan Summary
I Type of Well (producer or injector)' ] Producer
ISurface Location:
Target Location:
Bottom Hole Location:
1139' NSL 2226' WEL Sec 10 T13N R10E UM., AK.
5079' NSL 3330' WEL Sec 03 T13N R10E UM., AK.
5260' NSL 3351' WEL Sec 03 T13N R10E UM., AK.
]AFE Number: i 330023 I
I Estimated Start Date: I June 15, 94 I
[MD: [ 12774' [ [TVD:
I Well Design (conventional, slimhole, etc.):
I Rig: I Nabors 22E
I Operating days to complete: 1 20
1743~' ss I IKBE:
I 46'
I Slimhole -
Formation Markers:
Formation Tops MD TVD (BKB)
base permafrost 1874' 1796'
MA 6439' 4076'
NA 7013' 4326'
OA 7403' 4496'
OB 7494' 4536'
OG 7919' 4721'
HRZ 11660' 6546'
Top Kup 12055' 6861'
Top LZ 12225' 7006'
Target 12410' 7166'
Total Depth 12774' 7482'
Casing/Tubin: ' Prog ram:
Wt/Ft
Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm
Tbg O.D, MD/TVD MD/TVD
24" 13 3/8" 54.5# K-55 weld 80 32/32 112/112
12 1/4" 9 5/8" 40# L-80 btm 8002 31/31 8033/4771
8 1/2" 7" 26g L-80 btm 12744 30/30 12774/7482
Internal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur
with a full colunm of gas to the reservoir at 7040 TVDSS. Maximum anticipated surface
pressure in this case assuming a reservoir pressure of 3550 psi is 2850 psi, well below the
internal yield pressure rating of the 7" casing.
RECEIVED
i994
Gas Cons. Commission
Anchorage
Logging Pro
I Open Hole Logs:
Surface
Intermediate
Final
I"Cased Hole Logs:
LWD GR/Resistivity (DPR) Optional
None
LWD GR/Resistivity/Neutron/Density, Possible RFT
GR/CCL/Cement Bond Log only if necessar7
A gamma ray log will be obtained from surface to TD. Mud Logging is not required.
Mud Program:
[ Special design considerations [None- LSND freshwater mud
Surface Mud Properties:
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
8.6~. 50 15 8 10 9 8
tO tO tO tO tO tO tO
9.6 90 35 15 30 10 15
Intermediate Mud Properties: N/A
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
Production Mud Properties:
Density Marsh Yield 10 sec 10 min pH Fluid
(PPG) Viscosity Point gel gel Loss
9.0 40 10 3 7 8.5 6-8
tO tO tO tO tO tO tO
10.4 50 15 10 20 9.5 4-6
Well Control:
:
Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer
will be installed and is capable of handling maximum potential surface pressures.
Diverter, BOPE and drilling fluid system schematics on file with AOGCC.
Directional:
[moP: 1350'
Close Approach Well:
Maximum Hole Angle: 64.0 degrees
None
Gas Cons. Commission
Anchorage
MPC-21 Proposed
Summary of Operations
.
,
.
.
.
o
.
o
10.
11.
12.
Drill and Set 13-3/8" Conductor. Weld a starting head on conductor.
Prepare location for rig move.
MIRU Nabors 22E drilling rig.
NU and test 20" Diverter system. Build Spud Mud.
Drill a 12-1/4" surface hole and run and cement 9-5/8" casing. This hole
section will be logged LWD with DPR (Res/Gr).
ND 20" Diverter, NU and Test 13-5/8" BOPE.
RIH w/PDC bit on a turbine, Test 9-5/8" casing to 3500 psig, Drill out float
equipment and 10 feet of new formation, Perform a LOT.
Drill 8.5" hole to TD, POOH, and Run and Cement 7" casing. This hole
section will be logged LWD with Triple Combo (GR/Res/Neu/Dens).
RIH while PU 3-1/2" drill pipe with 7" 26# tandem bit and scraper to PBTD
and perform a casing wash while filtering brine to 2 micron absolute.
POOH L/D 3-1/2" drill pipe. Freeze protect the well.
ND BOPE, NU and Test Tree. Set BPV.
RDMO Nabors 22E drilling rig to drill MPC-22.
RECEIVED
j[Ji'4 ~- 6 1994
j~,i~;st~a 0fi & Gas 6orls. 60rr~mission
Anchorage
MPC-21 WELL
9-5/8" SURFACE CASING
CEMENT PROGRAM - HALLIBURTON
CASING SIZE: 9-5/8"
CIRC. TEMP 75 deg F at 4500' TVDSS.
SPACER: 75 bbls fresh water.
LEAD CEMENT TYPE:
ADDITIVES: Retarder
WEIGHT: 12.0 ppg
APPROX #SACKS: 1542
Type E Permafrost
YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk
THICKENING TIME: Greater than 4 hrs at 50° F.
TAIL CEMENT TYPE: Premium G
ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2;0% CaCI2
WEIGHT: 15.8 ppg
APPROX #SACKS: 250
FLUID LOSS: 100-150 cc
YIELD:1.15 ft3/sx
THICKENING TIME: Greater than 4 hrs at 50° F.
FREE WATER: 0
TOP JOB CEMENT TYPE: Permafrost C
ADDITIVES: Retarder
WEIGHT: 15.6 ppg
APPROX NO SACKS: 250
YIELD: 0.96 cu ft/sk.
MIX WATER: 5.0 gal/sk
RECEIVED
/-,,i~;k~ (J[i & Gss Cons. Commission
Anchorage.
MIX WATER: 3.7 gal/sk
CENTRALIZER PLACEMENT:
1. 1 Bowspring centralizer per joint of 9-5/8" casing from the FS to the NA Sand (25 required).
2. Place all centralizers in middle of joints using stop collars.
OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and
ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to
pumping job requirement. Displace at 12 bpm. Mix slurry on the fly -- batch mixing is .not necessary.
CEMENT VOLUME:
1. The Tail Slurry volume is calculated to cover 500' md above the 9-5/8" Casing Shoe with 30%
excess.
2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30%
excess and from 1500' md to sudace with 100% excess.
4. 80'rnd 9-5/8", 47# capacity for float joints.
5. Top Job Cement Volume is 250 sacks.
MPC-21
7" PRODUCTION
CEMENT PROGRAM-
CASING
HALLIBURTON
CIRC. TEMP:
140o F
BHST 170 deg F at 7040' TVDSS.
SPACER:
20 bbls fresh water.
70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0
ppg above current mud weight.
CEMENT TYPE: Premium G
ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344
WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk
APPROX # SACKS: 210
FLUID LOSS: < 50cc/30 min @ 140° F
MIX WATER: 5.0 gal/sk
THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F
FREE WATER: 0cc @ 45 degree angle.
CENTRALIZER PLACEMENT:
1. 7-1/8 .... x 8-1/4" RH Turbulators -- two per joint on the bottom 14 joints of 7" Casing (28 total),
This will cover 200' above the LK1.
2. 7-1/8 .... x 8-1/4" RH Turbulators -- 1 per joint on next 8 joints (8 total).
3. Run two 7-1/8" x 8-1/4" RH Turbulators inside the 9-5/8" casing shoe.
4. Total 7-1/8 .... x 8-1/4" RH Turbulators needed is 38.
OTHER CONSIDERATIONS: Pedorm lab tests on mixed cement/spacer/mud program and
ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to
pumping job requirement. Displace at 8-10 bpm. Batch mixing is not necessary.
CEMENT VOLUME:
1. The cement volume is calculated to cover 1000' md above the LK1 with 30% excess.
RECE!VEt
Anchorage
PRUDHOE
....
BAY
DRILLIN8
6ROUP
,4nadri}] Schlumberger
MPC-2 (P6)
VERTICAL SECTION
VIEW
Section at: 353.08
:fro Scale.: 1 inch = 1500 feet
Dep Sca]e.': 't ~nch = 1500 fee~
Dra¥~n ..... : 05/~3/94
Marker ]denl:ificat~on t,~0 BKB SECfN IN£IN
A) KB O 0 0 D. O0
8) KOP IJUILD i.5/lO0 350 350 0 0.00
C) BUILIJ 2/100 550 551) 5 3.00
D) BI)ILO 2.5/100 950 9,17 54
E) BIJILO 2.3/100 1450 t423 202 23.50
Fi Ef~ OF 2.3/~0f] BUII.D 3218 26/2 140t 64.16
6) 9-5/8" CS6 POINf 8033 4771 5735 64.16
. ~ll §I~RT 2/16.0 I]ROP J0502 5B47 7956 64.
]t I._'[iO 01-' 2/100 DROP 12210 6993 'gtBB
Jl :,:x~;~ TARE{[ ~.~>~ J2410 7156 928B 30.00
KI lO ]2774 7,182 9,17J 30.0.)
Gss Co~s. 6omm ;sion . '
I
750 1500 2250 3090 .. 3750
,4500 525O 6009
Sect ion Departure
!
Il ! ! 'I!l
6758 7500 []250 9000 9750 10500
25O
illlll ii.
12000
12750
I/¥]adrjI} (c)93 Nl'*:211h5 Rt.52 '.2:.23 Pa 1)
PRUDHOm BtqILLTN6 ' I6ROUP'' I
· i i i ilii .......... J · ·
c~ ~u=o ~/,oo ~o ~ , PL AN V I EW
D)
BUILD ~.5/~00 950 54 6 ........... . .....
El BDiLD 2.3/'~0~ ~450 200 24 CLOSURE ' 947] fee[ at Azimuth 353 OB
Fl ENO OF 2.3/i00 8~ZLD 3~8 2390 ~69 '
6) 9-5/8" CSg POINT 8033 ~G93 69~ DECLINATION.' 30.O0O E
HJ START 2/100 DROP t0502 7898 958 SCALE
I) END OF 2/JO0 DROP ~8~0 9~21 ~07
K~ TD ¢877~ 9a02
'----i i ...... illll
~nadrill Schlumberger
· , ,,
i ~ 300 ~ ~A~s ,
~ooo- - i ~ '~ ~ ;
, I ~ ' '
~ I , . ,
, , ...... ,,, ,
8250 ................ = ....... , ..........................
, , i · i
7500 -, I I
--
~ ,
s750-- ~
I .
~ 0 0 0 ~ ~ ~ .... ~ -: _ ~ - . ~~ . ......
5250- - I ~ ~ ~................
'-1 ..................... i i
, i' ~ I !
. I ...... : .... ,, i
i ,. ~ ,
i, i
3750 ...... i I
I ; i ................. ! ......
' ~ i
30002 .... i ' "' - . "' i .......
2250 .............. ~ ........
...... . ...... I .....
' i
i .
~500 .... '
' i . , ,
750 ........ i I
I i .
i i ~ I .
0
I
~ ' I i I ~ ,
I I I,I ' I I I
750- I i ~ ,, .
5250 4500 3750 3000 2250 ~500 750 0 750 ~500 2250 3000 3750 4500 5~50
<- WEST' EAST ->
vvF_LL PERMIT CHECKLIST
INIT CLASS
UNIT#
PROGRAM: exp [] dev/~ redrll [] aery []
ADMINISTRATION
ENGINEERING
1. Permit fee attached ..................
2. Lease number appropriate ...............
3. Unique well name and number ..............
4. Well located in a defined pool .............
5. Well located proper distance from drlg unit boundary..
6. Well located proper distance from other wells ......
' 7. Sufficient acreage available in drilling unit .....
8. If deviated, is wellbore plat included ........
9. Operator only affected party ..............
10. Operator has appropriate bond in force .........
ll. Permit can be issued without conservation order ....
12. Permit can be issued without administrative approval..
13. Can permit be approved before 15-day wait ........
N
N
N
N
N
N
N
N
N
N
14. Conductor string provided ............... ~.Y~/N
15. Surface casing protects all known USDWs ........ ~ N
16. CMT vol adequate to circulate on conductor & surf csg.'9 N
17. CMT vol adequate to tie-in long string to surf csg . . . Y
18. CMT will cover all known productive horizons ......
19. Casing designs adequate for C, T, B & permafrost ....
20. Adequate tankage or reserve pit ............. ~ N
21. If a re-drill, has a 10-403 for abndnmnt been approved.
22. Adequate wellbore separation proposed .......... ~ N
23. If diverter required, is it adequate .......... ~ N
24. Drilling fluid program schematic & equip list adequate .(~ N
25. BOPEs adequate ............. / ....... ~ N
26. BOPE press rating adequate; test to ~'~ psi~.~ N
27. Choke manifold complies w/API RP-53 (May 84) ...... ~-~----~/~
28. Work will occur without operation shutdown ....... ~ N
29. Is presence of ~2S gas probable ............. Y
GEOLOGY
/
30. Permit can be issued w/o hydrogen sulfide measures .... Y N /
31. Data presented on potential overpressure zones ..... Y / ~ )~
32. Seismic analysis 9f shallow gas zones ..........
33. Seabed condition survey (if off-shore) .........
34. Contact name/phone for weekly progress reports .... /. Y N
[exploratory only]
~EOL~:
ENGINEERING: COMMISSION:
TAB t F ~' '
Comments/Instructions:
z
HOW~o - A:~FORMS~cheklist rev 03/94
Well HistorY File
APPENDIX
Information of detailed nature that is not
particularly germane to the Well Permitting Process
but is part of the history file.
To improve the readability of the Well History file and to
simplify finding information, information of this
nature is accumulated at the end of the file under APPENDIX.
No special effort has been made to chronologically
organize this category of information.
Tape Subfile 2 is type: LIS
TAPE HEADER
MILNE POINT UNIT
CASED HOLE WIRELINE LOGS
WELL NAME:
API NUMBER:
OPERATOR:
LOGGING COMPANY:
TAPE CREATION DATE:
JOB NUMBER:
LOGGING ENGINEER:
OPERATOR WITNESS:
SURFACE LOCATION
SECTION:
TOWNSHIP:
RANGE:
FNL:
FSL:
FEL:
FWL:
ELEVATION(FT FROM MSL 0)
KELLY BUSHING:
DERRICK FLOOR:
GROUND LEVEL:
WELL CASING RECORD
MPC - 21
500292248600
BP EXPLORATION (ALASKA) INC.
ATLAS WIRELINE SERVICES
il-JUL-94
6239.00
J. DAHL
J. KETCHUM
10
13N
10E
1139
2226
46.00
46.00
16.60
OPEN HOLE CASING DRILLERS CASING
BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT)
1ST STRING
2ND STRING
3RD STRING 9.625 8032.0
PRODUCTION STRING 7.000 12841.0
CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH)
BASELINE CURVE FOR SHIFTS
GR
GRCH
1
2
05-JUL-94
ATLAS WIRELINE SERVICES
PBU TOOL CODE:
PBU CURVE CODE:
RUN NUMBER:
PASS NUMBER:
DATE LOGGED:
LOGGING COMPANY:
EQUIVALENT UNSHIFTED DEPTH
BASELINE DEPTH
$
REMARKS: GR, Marked Line.
40.00
26.00
LOG REFERENCED TO MAGNETIC MARKS.
THE MAIN PASS GAMMA RAY IS THE DEPTH REFERENCE FOR THIS
WELL.
FILE HEADER
FILE NUMBER: 1
EDITED CURVES
Depth shifted and clipped curves for each pass in separate files.
PASS NUMBER: 2
DEPTH INCREMENT:
FILE SUMMARY
PBU TOOL CODE
GRCH
$
.5000
START DEPTH
9755.0
STOP DEPTH
12766.0
CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH)
BASELINE CURVE FOR SHIFTS
PBU CURVE CODE:
PASS NUMBER:
EQUIVALENT UNSHIFTED DEPTH
BASELINE DEPTH
$
REMARKS: MAIN PASS.
CN
WN
FN
COUN
STAT
: BP EXPLORATION (ALASKA)
: MPC - 21
: MILNE POINT
: NORTH SLOPE
: ALASKA
* FORMAT RECORD (TYPE# 64)
ONE DEPTH PER FRAME
Tape depth ID: F
1 Curves:
Name Tool Code Samples Units
1 GRCH GR 68 1 GAPI 4
API API API API
Log Crv Crv
Size Length Typ Typ Cls Mod
4 21 990 60 6
* DATA RECORD (TYPE# 0) 1022 BYTES *
Total Data Records: 48
Tape File Start Depth = 12786.000000
Tape File End Depth = 9754.000000
Tape File Level Spacing = 0.500000
Tape File Depth Units = Feet
**** FILE TRAILER ****
LIS representation code decoding summary:
Rep Code: 68 12131 datums
Tape Subfile: 2 134 records...
Minimum record length: 62 bytes
Maximum record length: 1022 bytes
Tape Subfile 3 is type: LIS
FILE HEADER
FILE NUMBER: 2
RAW CURVES
Curves and log header data for each pass in separate files; raw background
pass in last file.
PASS NUMBER: 2
DEPTH INCREMENT: .2500
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 9754.0
$
LOG HEADER DATA
DATE LOGGED:
SOFTWARE VERSION:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT):
TD LOGGER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
LOGGING SPEED (FPHR):
DEPTH CONTROL USED (YES/NO):
STOP DEPTH
12783.0
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
SWVL
SB
SB
CCL
GR
$
SWIVEL
SINKER BAR
SINKER BAR
PCM/CASING COLLAR L.
GAMMA RAY
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE(IN):
DRILLER'S CASING DEPTH (FT):
LOGGER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS FLUID TYPE:
FLUID DENSITY (LB/G):
SURFACE TEMPERATURE (DEGF):
BOTTOM HOLE TEMPERATURE (DEGF):
FLUID SALINITY (PPM):
FLUID LEVEL (FT):
FLUID RATE AT WELLHEAD (BPM):
WATER CUTS (PCT) :
GAS/OIL RATIO:
CHOKE (DEG):
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
05-JUL-94
FSYS REV. J001 VER. 1.1
1232 05-JUL-94
12756.0
12771.0
9760.0
12766.0
3600.0
YES
TOOL NUMBER
3913NA
8250/8248XA
8220XA
.000
12841.0
.0
SEAWATER/DIESEL
.00
.0
.0
0
.0
.000
.000
.000
.0
.00
.000
BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE
TOP NORMALIZING WINDOW (FT):
BASE NORMALIZING WINDOW (FT):
BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER
FAR COUNT RATE LOW SCALE (CPS): 0
FAR COUNT RATE HIGH SCALE (CPS) : 0
NEAR COUNT RATE LOW SCALE (CPS): 0
NEAR COUNT RATE HIGH SCALE (CPS): 0
TOOL STANDOFF (IN) :
.0
REMARKS: MAIN PASS.
$
CN
WN
FN
COUN
STAT
: BP EXPLORATION (ALASKA)
: MPC - 21
: MILNE POINT
: NORTH SLOPE
: ALASKA
.0
.0
* FORMAT RECORD (TYPE# 64)
ONE DEPTH PER FRAME
Tape depth ID: F
5 Curves:
Name Tool Code Samples Units
API API API API
Log Crv Crv
Size Length Typ Typ Cls Mod
1 GR GR 68
2 FLTM GR 68
3 CCL GR 68
4 TEN GR 68
5 SPD GR 68
1 GAPI 4
1 DEGF 4
1 4
1 LB 4
1 F/MN 4
4 21 990 60 6
4 66 264 36 0
4 26 165 19 6
4 10 579 41 1
4 76 115 41 1
20
* DATA RECORD (TYPE# 0) 1014 BYTES *
Total Data Records: 289
Tape File Start Depth = 12786.000000
Tape File End Depth = 9754.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = Feet
**** FILE TRAILER ****
LIS representation code decoding summary:
Rep Code: 68
72775 datums
Tape Subfile: 3
364 records...
Minimum record length:
Maximum record length:
62 bytes
1014 bytes
Tape Subfile 4 is type: LIS
FILE HEADER
FILE NUMBER: 3
RAW CURVES
Curves and log header data for each pass in separate files; raw background
pass in last file.
PASS NUMBER: 1
DEPTH INCREMENT: .2500
FILE SUMMARY
VENDOR TOOL CODE START DEPTH
GR 12474.0
$
LOG HEADER DATA
STOP DEPTH
12782.0
DATE LOGGED:
SOFTWARE VERSION:
TIME LOGGER ON BOTTOM:
TD DRILLER (FT) :
TD LOGGER (FT):
TOP LOG INTERVAL (FT):
BOTTOM LOG INTERVAL (FT):
LOGGING SPEED (FPHR):
DEPTH CONTROL USED (YES/NO):
TOOL STRING (TOP TO BOTTOM)
VENDOR TOOL CODE TOOL TYPE
SWVL
SB
SB
CCL
GR
$
SWIVEL
SINKER BAR
SINKER BAR
PCM/CASING COLLAR L.
GAMMA RAY
BOREHOLE AND CASING DATA
OPEN HOLE BIT SIZE(IN):
DRILLER'S CASING DEPTH (FT):
LOGGER'S CASING DEPTH (FT):
BOREHOLE CONDITIONS FLUID TYPE:
FLUID DENSITY (LB/G):
SURFACE TEMPERATURE (DEGF):
BOTTOM HOLE TEMPERATURE (DEGF):
FLUID SALINITY (PPM):
FLUID LEVEL (FT):
FLUID RATE AT WELLHEAD (BPM):
WATER CUTS (PCT):
GAS/OIL RATIO:
CHOKE (DEG):
NEUTRON TOOL
TOOL TYPE (EPITHERMAL OR THERMAL):
MATRIX:
MATRIX DENSITY:
HOLE CORRECTION (IN):
05-JUL-94
FSYS REV. J001 VER. 1.1
1219 05-JUL-94
12756.0
12771.0
9760.0
12766.0
3600.0
YES
TOOL NUMBER
3913NA
8250/8248XA
8220XA
.0OO
12841.0
.0
SEAWATER/DIESEL
.00
.0
.0
0
.0
.000
.000
.000
.0
.00
.000
BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE
TOP NORMALIZING WINDOW (FT):
BASE NORMALIZING WINDOW (FT) :
BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER
FAR COUNT RATE LOW SCALE (CPS): 0
FAR COUNT RATE HIGH SCALE (CPS): 0
NEAR COUNT RATE LOW SCALE (CPS): 0
NEAR COUNT RATE HIGH SCALE (CPS): 0
TOOL STANDOFF (IN):
.0
REMARKS: REPEAT PASS.
$
CN
WN
FN
COUN
STAT
: BP EXPLORATION (ALASKA)
: MPC - 21
: MILNE POINT
: NORTH SLOPE
: ALASKA
.0
.0
* FORMAT RECORD (TYPE# 64)
ONE DEPTH PER FRAME
Tape depth ID: F
5 Curves:
Name Tool Code Samples Units
API API API API
Log Crv Crv
Size Length Typ Typ Cls Mod
1 GR GR 68
2 FLTM GR 68
3 CCL GR 68
4 TEN GR 68
5 SPD GR 68
1 GAPI 4
1 DEGF 4
1 4
1 LB 4
1 F/MN 4
4 21 990 60 6
4 66 264 36 0
4 26 165 19 6
4 10 579 41 1
4 76 115 41 1
20
* DATA RECORD (TYPE# 0) 1014 BYTES *
Total Data Records: 30
Tape File Start Depth = 12785.000000
Tape File End Depth = 12473.000000
Tape File Level Spacing = 0.250000
Tape File Depth Units = Feet
**** FILE TRAILER ****
LIS representation code decoding summary:
Rep Code: 68
19626 datums
Tape Subfile: 4
105 records...
Minimum record length:
Maximum record length:
62 bytes
1014 bytes
Tape Subfile 5 is type: LIS
94/ 7/11
01
**** REEL TRAILER ****
94/ 7/11
01
Tape Subfile: 5 2 records...
Minimum record length: 132 bytes
Maximum record length: 132 bytes
End of execution: Mon 11 JLY 94 4:16p
Elapsed execution time = 6.97 seconds.
SYSTEM RETURN CODE = 0
COMPANY NA~E
FIEbD NAME
STATE
~EFERE~C~
: MPC-~I
~ 94~6550'0~922496-00 ~¢~¢
I8 Ta~e verlflcat],om [,ist~.na
chlumberqer Alaska Computin~ Center
IP-~CT-~ 994 14:52
PA~E~
**** REEL HEADER ****
D~TE !
O~I~IW : ~LTC
REEL ~A~M : 94~65
COMMENT ~ BP EXPLORATIO~i, ~IL~E POINT, ~PC-2~, API 50-0~9-22486-00
**** TAPE ~EADER ****
DATE : 94/10/~2
P NWINLi~TIO~ # : 1
~EVIOUS TAPE :
COMmEnT
: BP EXPLO~AWION, ~qIL~,!E POINT, ~,IPC-21, APl 50-029-22486-00
M7LNE POINT
MWD/MAD LOGS
#
API NUMBER:
OPE~ATr)~:
LOG~I~G
T~P~ CREATIr]M DATE:
jOB D~T~
SURFAC~
SECTiON~
TOWNSMIP:
R~N~E:
FSL:
F~L ~
FwI~
FI~FVATI~M(FT FRO~+ ~8g O)
~ELLY BUSHI~G ~
CROU~D LMVFL:
WELY, CASI~G RECORD
~6T STRI~G
~o ~TRI~G
BIT RUN
94265
~ICObS/ST
~ILL
500292~48600
BP EXPLORATION
SCHLUMBERGER !~MLL SERVICES
12-UCT-94
BIT RUN 2
lO
1139
2226
4
16,60
giT SIZE (iN) SIZE (IN) OEPTIi tFY)
~.500 9.625 803~,q
I~ ~ame Verification ~ist~no
chlumber~er Alaska Comi:Ut~no Cente~
i2-0CT-~99~ 14;52
ADN RP TO BIT: !26,S3 FT
I)mlLL~iD i~TERVAL ~0]2 TO 12~62 FT
~ASUDO~,N INTERV~b 1~560 Tr~ ~272~ FT
$
bis
LIS F'OR~A? n,A~h
PAGE:
**** F;LE MEaDER ****
FILE t)A~E : E~IT .00i
SERVICE ~ FLIC
VERSION : 00ICO1
D~TF ~ 94/Io/!2
MIX REC $IZ~ : 10~4
FTLW TYPE
b~SW ~II~E
FTLF NU~B~R: 1
EDITED ~C~GMD MWD
De,th sh~fted add cl~pmed curve~; all bit run~ meroed.
D~PTH INCREMENT: 0.5000
#
F%LF SU~MARY
TDWG TOO!,, CODE
CDP
BASFL)NE r~l])~VE FOR SHIFTS: GRC~
CURVE S)'{IFT DA't'~ (NE~ISURED DEPT~i)
~2740.0
1258~,0
~2~,0
~2~9~.5
~7~.0
!2163,0
~2o6!,0
START DEPTM
~275~.O
~281g.0
STOP DEPTH
8040,0
8048,0
.......... E~[)IVAt~E~,!T UNSHIFTEL DEPTH----------
~Sgl~.0 88911.0
~763.0 1276~.0
t2704,c ~2704.0
!260~oO 12608,0
1243¢.5 !2434,5
1230q,0 t2309.0
t2~g4,0 ~2~94.0
1.2236.5 12236.5
12180.5 12180.5
t2n77.0 12077.0
~1990,5 ~1990.5
IS Tape Verification bistlt~a l?-OCT-1994 14:52
chlumberger AlasKa Computlnq Center
!lgiI.5 11929.5 11929,5
~I~7~.o 11894.5 i1~94.5
~I~4R.0 ll~6a.O
!1B0~.5 11e19.5 11819,5
~70Q.5 ~!72~.0 ~1728.0
~161m. S 11637.5 ~i637'5
~1~6~,5 11479.5 11479.5
~134z~.5 !,1358,0 11355.0
~ 0990.5 ~ 101~.0 J 10i8.0
0924' ~ ~0~4~.0 ~0943.0
~0~9~:5 ~000~.5 JOgOg,5
~074~ 5 ~076S,0 ~.0765 0
o44 :s o466.e ~0466:0
N~R~ED DA~A SnURC~
[.DWG TOO[, CODE BIT ~U~~ NO. ~ERGE TOP
~EPGM BASE
THE CASED HOLE ¢:R ~AS USED AS A BASE CURVF., THE SHIFTED
CURVE ~AS T ~E MWD CP, AND ALL CDk AND ADN ~URVES WERE
$~IFTED %~TTg THE ~,D GR, T~E CASED HObE GR bOGGED UP
TO 9754, A BLgCk SHIFT OF 19,0 FT WAS APPLIED FRO~
975~ TO 8040 FT.
LIS FORMAT DATA
PAGE~
DATA FORMAT OPECYFICAT!O~ ~ECORD **
SET TYPE - 64E~ **
T P. C[.DE~ VALUE
1 66 0
2 6~
3 73 76
,4 6~
5 66
6 73
7 65
8 ~8 0,5
9 65
IS Tape Ver~ftcatlon [,tstlno
chlumberger AlasKa Computin~ Center
12-0CT-1994 14,'.52
PAGE:
i4 65
15 66 68
i6 66
O 66
NA['tW $ RV I E h I A I A gP E NUf~B NUMB SIZE REPR PROCES~
---------------------------------------------------------------------------------------DF~ ET O0 O0 0 0 1 1 1 4 68 0000000000
O0 000 On 0 1 1 !. 4 68 0000000000
GR ,WD GAPI
ROP ~ND FPHR O0 060 O0 0 1 I ! 4 68 0000000000
R~ ~!~ ON~ O0 OCO O0 0 I 1 ~ 4 68 0000000000
RP ~w~ O~U O0 000 O0 0 1 1 ! 4 68 0000000000
V~A ~Wr, 0~ O0 OOO O0 0 1 1 1. 4 68 O0000000OO
V~P ~r~ ~ O0 OOO OO 0 1 1 ~ 4 68 000000o000
DER ~D OEgu O0 000 O0 0 ! 1 ~ 4 68 00000000o0
FET ubP MR O0 000 O0 0 1 I 1 4 68 0000000000
C~LN ~Wh I~ O0 000 O~ 0 I ! 1 4 68 0000000000
PFF ~O BNtE OD 000 O0 0 I 1 ~, 4 68 0000000000
NPHI ~Wr) PU-S O0 000 O0 0 1 I 1 4 68 0000000000
D~HO ~' G/C3 O0 000 O0 0 1 1 ~ 4 68 O00000000u
RHO~ ~'~V G/C3 O0 000 OO 0 1 1 !, 4 68 O00000000c
ROB~ uwD G/C3 OD {'}00 O0 0 i 1 1 4 68 .O00000000o
ROB~ ~W~ G/C3 O0 DO0 O0 0 1 1 ! 4 68 0000000000
ROB¢ ~w~ G/C3 OD 000 O0 0 1 1 i 4 68 0000000000
ROBI, ~ G/C3 O0 o00 O0 0 I 1 i 4 68 00000000o0
GgCN AT~, GAPI O0 000 O0 0 1 I I 4 68 0000000000
D~PT 1~885 00~, GR,,MWD -999 5,0 ROP.MWD 4 1.882 RA MWD
RP'~i~P -9°9'250 VFA'MWD -999:50 VRP,NWD -99 .~50 DER:~WD
' .]'i '
- ~NO -999.~50 PEF ~WD -999.250 NPHI.~WD
D~Hn,~[,-999'~50.250 CALN'~{~;DRHOB. -099.~50 ROBU.~!WD -999.~50 ROB¢. ~WD'
ROBn.~9 -9o9,25t~ ~OBL'NWD -990.250 GRCH.AT5 -999.250
-999.250
-999.250 DER.~'4WD
_-999 250 NPHI
-999.250
-999.2,0
'999,2~0
'999'250
'999'250
-99g,. 250
:999.. 250
.999:, 250
999.250
I8 Tane Veri£~cat~on ListJ. no
Chlumberq~.r AlasKa Co,,put.~nq Certe['
12-0CT-~994 '!4:52
PAGE:
FTLF ~[A~E' : ~DII .002
SFRVlCE : WLIC
VERSION : oO~COl
M~X RMC SIZE : 10~4
F!LF TYPE : LO
L.~ST FI~,E
FILF NONBRR: 2
EDITED ~E~GED NAD
De~th sh~fted and cl~Pped curvesl all bit ru~s merged.
D~PTH I~C~E~E~T: 0.5000
#
LDWG TOOL CODE SI,~,RT DEPT}4
A D N ~26009.
CDP 12673.0
B~S-.LTh~ CURVE FOR SHIFTS
CURVE SHIFT DATA (~EASI...~PED DEPT~)
~ASELiNE D~P~H
n888~ 0 ~8006,5
12589,5 !260~.n
~RG~]D DATA ~r]URCF
T,DWG T[]IDT., COD[<
RFPi~RKS:
STOP DEPTH
----- ..... [':{~I]IVALENT UNSgIFTED DEPTH----------
88906.5
~. 260~ 0
2:..52~
tl~.5
PI, iN HO. ~EPGE TOP
T~'~E C.ASED bOLF (,,',R ~,,A,S USED AS A BaSE CURV:~ ~, E SMIFTED
C,~RV[: ~,~S T~4E M~D GR. ~f~]D ALL CDR &ND ADH C~RVES WERE
IS TaPe Verification l, ist~.nq
cblumberc~r alaska Computino Center
12-0CT-1994 14:52
PAGE{
$
#
L?$ F'OR~,~T ~ATA
** DATA F~R~AT SPECIFICaTIOn3 RECORD **
** SET TYPE - 64EB **
TYPE REPR CODE VALUE
2 66 0
3 73 68
4 ~6
5 66
6 73
7 65
9 65
11 66
1~ 66 0
1~ 65 PT
I5 ~6 68
16 ~6
0 65
NAMF SERV UNIW SE~VIC[{ API APl API API FILE NUMB NUMB SIZE REPR P OCES8
~D ORDE~ ~ LOG TYPE Cb~S ~OD ~U~B $,A~P ~LEM CODE (HEX)
.............. .................................................................
FT O0 000 O0 0 2 ~ I 4 68 0000000000
GR ~WD GAPI Oo 000 O0 0 2 1 1 4 68 0000000000
ROB AWO FPHR O0 000 O0 0 2 1 !. 4 68 0000000000
RA ~D OH~ O0 O00 00 0 2 1 ~ 4 68 0000000000
RD uy~9 {.>Py~u OO 000 00 0 2 I 1 4 68 00n0000000
VRA ~D ~:~H~ O0 000 O0 0 2 1 i 4 68 0000000000
V~P ~Wo O~ O0 OOO O0 0 2 1 1 4 68 O000000000
D~R u~o O~a~ On 000 O0 0 2 1 I 4 68 0000000000
CaL~ ~W~ IN O0 o00 O0 o 2 I I 4 68 0000000000
P~F ~n B~/E L~o 000 OD 0 2 ~ 1. 4 68 0000000000
NPH~ ~D pI;-$ O0 000 O0 0 2 1 1 4 68 0000000000
D~HO ~W9 G/C3 00 o00 On 0 2 ! 1 4 68 0000000000
RHO~ ~{~n G/C3 0o 000 0o 0 2 I I 4 68 00000000o0
ROBI; ~D (;/C3 00 o00 00 0 2 t ~ ~ 6B 0000000000
ROB~ N~C G/C3 0o 000 00 0 2 1 i 4 68 0000000000
ROBF w~r G/C3 o0 000 00 O 2 ! I 4 68 0000000000
ROBt, ~w9 G/C~ 0n 000 O0 0 2 ! ~ ~ 68 0000000000
IS Tape Yerff{.caC~o~, l, lstin~
chlumber¢:er AlaSKa Co,,;,utino Center
t~-OCT-JW94 !4:52
17.740.000
-9~9.2~C VR A. iv~D -999.250
-909.25(>
-ggg.~50 ROP.MWD
-999.250 VRP.MwD
3.~ MPMI.MWD
~o410 ROBR,~WD
76.276 RA.~D
-999.250 DER."~D
-999.250 DRHO.g~n
-999.250 ROBB.~D
-999.250 RA.MWD
-999.250 DER.~D
31.600
~.466 ROBB.~D
PAGE:
-999.250
999.~50
-999.250
-999.250
-999.250
0.102
2.479
**** FILF ~RAI{,EP
FILF NA~E :KDIT .002
SFRVICE : FLTC
VKRSIO~ : O01COI
DATF
N~X RFC SIZ~ : 102~
FILF TYPE :
LAST FI;,E
**** FILE ~EA[)K~ ****
SERVICE : FLTC
VERSIO~ : O01CO1
D~TF :
N~X R~C SIZE : ~0~
FILE TYPE
L~S· FIL~ :
Curves and loq 4~ea4er data for each bit run Jn separate
BIT RUN Nt)~BE~; i
FILf
$
STOP DEPTH
fi,les.
IS Ta~e %er~f.icatJon l.,lstlr~,~
cblumbercfer Alaska Comp;~tir~q CeDtel
l~-OCT-T994 I4:52
PAGE:
DATA TYP~ f~W~OfiY or
TD DPI[,bER
~OP LOG TNTE~V~L
POTTO~ LOG INTFRYA[, {FT):
~IT ~OTATI~G SPEED
~OLE INCLIt~ATION (DFC)
#
LCGOS ?0.4
F~ST 2.5
12862.0
8040.0
1281~.0
~5
27.?
TOOL ST~ING (TOP TO BOTTOM)
VFt"~nOR TOOL COI,)F TOOL TYPE TOoL
AOt~ Z UT~AT~ DENSITY NEUTRON ADN001
CmR CO~P DUAl,, RESISTIVITY ~GS059
~O~EHOLE AND C~,SING DATA
v'JPE~,t HOLE BIT SIZK (IN): 8.500
DRTLLEPS CASI{,~(; DEPTH (FT): 8032.0
ROPEHOI, E CONDITIONS
~aUD TYP~:
~UD DENSITY (LB/G): i0'40
~4UD VISCOSITY (S): 43,00
MUD CHLORIDES (PP~):
FLUID LOSS {C3):
, '3 '~ ~ ~ · I
~4AXT~tU~ RECORDE. TENPERATURE (DEGF): 15B O
RESISTIVITY (Og~) ~T TEMPERATURE (DEGF):
~,~UP AT ~,!EASURED TE~PERATURE (NT): 2,150
~'~UD AT H~X CTRCULATING TE~PERATURF :
~UP FI!.,,TPATE AT (H'I'): ~.340
~Ur) CAKE AT (~,~w): 0,000
~ATP!X: SANDSTONE
~4 ~'l;P I Y DENSITY; 2.65
{.)F[~;SITY T~ BIT ~30.13 MT
i ,RYAL ~)~2 TO 12~62 FT
~,'~SHDO~;~.~ Ti'JTEPV~I~ 12560 TO !2720 FT
S
67.0
67 0
Tame Verifi. cat~on Listfno
chlum.ber~ter AlasKa ComDutiao Center
LIS FC.,R~AT DATA
12-0CT-1994 I4:52
PAGE:
DATA F~RUAT SPFCIF'TCATI{)N PECORD **
** SE~ mypc - 64ER **
~yPF: R~R CODE
I 66 0
2 66 0
3 73 68
4 66
6 73
7 65
~ 68 0,5
9 65 FT
11 66
1~ 6~
13 66 0
14 65 FT
I5 66 68
i~ ~6 1
0 66
** SET TYPE - C~!A[t **
NI!Nt~ . IT SE C. aPI AP APl AP1 FIt,E NUMB .~)UMB SI RE P C
ID ORDE~ ~ L,(, TYPE (.bASS ~40D NU~B SA~P EbE~ CODE (HEX)
D~PT Fg' O0 O0000 0 3 ~ 1 4600008 0 0 0 000
IS ~a~e Ver~ication I,ist~,nc~
Chlumberqer AlasKa Computfnq Center
D~PT. t2864.500
ROBD.I,~,,1 -999'250
PEw.~,a'! -999.250 OCAL.!,wi
D~PT 7995.000
?AD.LW! -999.250
E~D OF D~TA
t2-DCT-1994 14:52
-999.250 R~BO.bWl
-999.250 DPHI.LWI
-999.250 TNPH.LW!
-99~.~50 ~OP~.bWl
2 ~06 ~OBU.bW1
I: 74 DPWI.LWl
n.467 TN~H.bWl
0.098 RO~E.bWl
-999.250
-999.250
-999 ~50
48~87
2.008
-6.750
60.950
-999.~50
ROBR.LW!
DRHO.L.!
ATR.LWl
GR.DW!
ROBR.LW1
ATR.LWl
GR.~,Wl
PAGE:
-999.250
-999.250
-999.2~0
-999.250
2,074
'0.621
0,095
41.461
10
**** FILM
SERVICE
VERSION
D~TF
M~X REC STZE
FIL~ TYPE
TRAILER ****
: EDIT .003
: O0!COl
~ O411O112
~ ~024,
**** FILF
VMRSIC~
DATW
N~X RFC $IZ~
FIL? TYPE
LAST FII,E
NEADER ****
FDIT ,004
O0~CO1
941t0/12
~024
Curves and
DEPTH I NCPE~E~,~q~ ~
FILF $[J~ ~R'Y
!,DWG TOOl, CODE
4
i~eader data
1
0.50o0
for
START DEPTN
I,~2815.n
each
mit run ~.n separate
STOP DEPTH
12436,0
files.
IS ?a~e Ver~.flcation !,istlno
cblU~beroer Alaska Comput.~.no Center
994 !4:52
PAGE:
LOG HEA~ER
PATE i.,OGC~Er~:
SURFACE SOFT~ARE VERSIU~:
DATA TYPF ({'4E~'~ORY or
WD DRII,LER (VT):
~OTIO,~ L-~, I~:'rERVAL (FT):
PIT ROTATI~G SPEED
~Ot~E IMCLI~ATI~N (DEC)
~TNTVUM ANGLE:
#
..98-J!!N-94
LOGUS ~0.4
FAST 2.5
12~62.0
8040.0
12~t9.0
TOOL ST~IMG (TOP TO BOTTOm)
VMN~O~ TOnb CODE TOOL ~YPE TOOL
CnR CO~P D{]Ab RESISTIVITY RGS059
S
~OREMOLE AND CASING DATA
OmEN NOLE BIT SIZ~ (IN): 8.500
~RILLERS CASING I)EPTM (FT): 8032.0
BOREMO[,E CONDIT] oi~!S
AUD TYPF:
M~!D DENSITY ([,B/G): !0.40
~'D V!SCUSITY (S): 43.00
~UD
~UD C~LDRIDES (PP~):
FLUID LOSS
MAXIMUM RECORDED TE~PMRAT{~R~ (DEG.): 155.0
RESISTIVITY (OH~N) ~T TEMPEPATURE (DEGF):
MUD AT MEAS[!PED TEmPERaTURE (MT): ~,150
~UD AT FAX CTPCbLATING T~NPERATURE :
~!JD FI!,,TPAT~{ AT (HT)~ 2.340
~UQ CAKE AT (~!?): 0.000
~E~TRO~! ~OOb
M~T~I×: SANDST~]NE
~ATP!× DERSITY: 2.65
i'IObE CODR~CTIOiJ (IN): 8.500
TOOL STAWD~FF (IN)~ 0.875
~WP FRFOUE~C¥'
****~*~***** PU~ 1 *************
ADN RP mO BIT: t26.53 FT
DFN$IT¥ T~ DIT 130.~3 MT
~FL!TRfT~~ Tn BIT ~34.41 FT
D~I[,,I~Ft:? INTeRVAl, ~032 TO 1286~ FT
~,~SFlbOta I't;~gPVAL 17560 TO 12720 PT
67.0
67 0
o:o
IS TaPe Verification Y, lstir~q
cblumberQer AlasKa Con, putln~ Center
12-OCT-1994 14:52
PAGE:
12
2 66
3 73 64
~ 66
5
6 ~3
7 65
9 65
1~ 66 16
I~ 68
1~ 66
14 65
I5 6~ 68
16 6~
0 66
,
NAMF SERV U~,:I~ S~VTCF APl APl: APl APl FILE ~U~B NUmB GIZE REPR P OCES$
ID ORDER ~ bOG TYP~ CLASS MOD NUMB SA}.:P ELEM CODE [HEX)
DEPT FT 0004000 0 0 ! 1 4 68 00000000
oo
1 4 68 0000000000
! 4 68 0000000000
! 4 68 0000000000
1 4 68 0000000000
1 4 68 0000000000
1 4 68 0000000000
1 4 68 0000000000
1 4 68 0000000000
1 4 68 0000000000
1 4 68 0000000000
1, 4 68 0000000000
1 4 68 0000000000
! 4 68 0000000000
1 4 68 0000000000
!. ~ 68 0000000000
IS Ta~ Yer~ficstJ. on !lstl?,c
ChlUmherqer Alaska Co,r..puti. no Cemter
12-0CT-~9~4 14:S2
PAGE:
13
D~Pw. 127~0.c00
RPEF.~D! -Dg~.25Q DCAL.~D!
4.749 DC~b.~Pi
-9q9.250 DER.~D~
-999.~50
-99g.250
-990.250 TNPH,~D!
].305
2.435
0.8~2 TNPH,MD1
-999.250 ROGR.MD~
-999.250 DRHO.~D!
-999.250 ~TR,~D1
1303.825 GR.~D~
9.700
30.300 AT~.~D1
-999.250 GR.~D1
-999.250
-999.250
93.519
2,452
0,080
.-999,250
999.250
ENO OF DATA **
**** FILE TRAILE~ ****
FILF ~A~E : EDIT
S~RVICE : wbIC
VERglON : O01CO1
DATE ~ 94/10/12
MAX RMC SIZE ~ 1024
FILW TYPE : LO
**** TAPE TRAILER ****
$~RVICE NA~E ~ EDIT
D~TF : g4/10/12
O~ICIN :
T~PF ~A~E : 9426~
CON ~U~TYO~,~ ~
P~EVIOUS TAPE
CO~ENT ~ BP EXPLORATION, ~'lI~E POINT, ~PC-21, APl 50-0~9-2~4~6-00
* ALASKA COMPUTIMG CENTER
*
******************************
******************************
BP EXPLORATION
~ILNE POINT
50-0~9-2~486-00
,IS Ta~e Verl. f]eat].on List~o
.chlumberqer Alask. a ~ompt.lt~.no Centex-
lP-OCT-~994 14:52
O~ICI,~ : WbTC
REEL ~A~g : 9~?~5
CONTInUaTION ~ :
P~EVIOU$ ~EEL
CON~E~!T : BP EXPLORATION, ~lb~E POI~?, NPC-2~, API 50-0~9-2~486-00
CO~UE~T
: ~P EXPbORA~ION, MIb~g POINT, gPC-21, APl 50-029-22486-00
APl NU~nE~:
LOGGING CON~AN¥~
T~P? CREATION
JOS
2ND OT~I~G
~PC-21
50029224~600
BP EXPLORATION
SCHLUMBERGER ~Ebb SERVICES
~2-UCT-94
94265
N!COb$/ST AN
BIT RUN 2
RUN 3
1!,39
2226
46 O0
46i00
16 6o
OPgq HO~,~; CA$IhG
~TT STZF ¢i~-') SIZE (!M)
IS TaRe Yerif!.catl. on Listtnq
chlumberqer Alaska Com~',~.]ti.n{~ Center
i2-OCT-!gg4
I4:52
PAGE~
**** FrLE WEbbER
SFRVICE : FLIC
VFRSIO~ ~ O0~CO1
DATF ~ 94/~o/~2
M~X REC $IZM :
F~LF ~YPE ~
bASW tilde
FTLF ~U~BMR: 1
EDITED ~EPGED
Depth shifted a~d cl~Doed curves;
DFPTH I~CRE~E~T~ 0.5000
FYbF SU~RY
!DWG TOO~, CODE
CDP
BaS~[,~E ~I~PV~ FOP SHIFTS: ~RCH
CURVE $;{IFT DaT~ fNF~SUR£D DEPTH)
all bit runs merned.
START DE~TH STOP DEPTH
!275~.0 8040,0
1281g.0 8(~48,0
~8~8S.0 ~8911.0
12740,0 12763.0
~2684,5 !2704,a
125B~,0 3260~.0
12414,0 1243-'~.5
1229~.5 l~3Oq,O
~2276,0 ~2294,0
1271~o~ 12236.5
~206!.0 ~2077.0
~1a74,0 ~1990,5
12763.0
12704.0
12609.n
~2434.5
!2~94.0
12236.5
~2077,0
11990.5
'.,IS Ta,me Ver~flcati. on Listl~;:~
,~chlUmberger ^la$~ ComputlnO Center
I?-0CT-1994 t~:52
!t01i,5 11929,5 11929.5
! IR79,0 11894,5 11894,5
~170q.5 !!72~.0 11728.0
~16Iq.5 11637'5 11637.5
.146~,5 11479,5 11479.5
!13z~$,~ !1358,0 11.35B,o
!0990,5 ~.nlg,O llOj. 8,o
!0~24,~ 10043,0 ~.0943,0
~0748,5 10765,~ ~0765.~
~044~,5 ~.0466,0 t0466.0
10331.,0 10347,5 10347,5
M~RO.E~ ~A~A SnURCE
[,DWG TOOl, CODE 8I~' RU~-~ NO, ~ERG~ TOP
.
BASE
TWE C.~$EO .HOLE 6R ~S USED AS A BASE CU.RVK. TME SHIFTED
CURVE .';AS THE MWD CP, AND ALL CDR AND ADH CURVES WERE
S~IFTED WITH THE ~'~WD GR, THE CASED HOLE GR LOGGED UP
'fO 975~. A 5LOCF. SHIFT OF 19.0 FT WAS APPLIED FROM
9754 ~'i) 8040 FT,
#
PAGE:
Fr~R~A· SPFCTFICAT!O~~ PECURD **
Tape Verification Ltstinq
chlumberqer AlasKa Comuut],nq Center
I2-0CT-~994 14:52
PAGE:
** SEv' TYPL{ - CHAN **
N ~ FRV $ ¥ CE PI A~.~ API ~P% FI[,E NU~,4B NUMB
l'O ~RDE~ ~ L~G TYPE CLASS ~OD NU~8 SA~P ELMM
DFPT FT OeO00l O0 0 ~ 1 4
GR ~WD GAPI 00 000 0o 0 1 ~ ~. 4 68
ROP MWD FPF~R O0 060 O0 0 1 l ~. 4 68
RP '~,~W P OW~¢ ~ O0 000 O0 0 I ~. ! 4 68
V~P M ~ 'f', OMq~ O0 OOO O0 0 1 J ~.. 4 68
DER ~wP 0~?~u O0 ~00 O0 0 i ~. ~ 4 68
C~ b~.3 ~wr, l~ OO o0o Oa 0 1 ! 1 4 68
NPH~ ~Wr~ pU-$ O0 OOO OD 0 1 ! 1 4 68
RW0~ ~* w f'~ G/C~ O0 000 OD 0 1 ~, !, 4 68
ROBt~ ~O G/C3 O0 000 O0 0 1 ~ 1 4 68
ROBP ~W~ G/C3 O0 000 OO 0 1 .~ ~, 4 68
ROB~ ~W~ G/CB O0 000 O0 0 1 ~ ! 4 68
ROBt. ~4 ~ r, G/C3 O0 o0~ O0 0 1 1 I 4 68
GPCN ~TL GaPT O0 000 O0 0 1 I ! 4 68
E R OC SS
CODE (HEX)
0'000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
0000000000
O00000000u
O00000000O
'O00000000o
0000000000
0000000000
0000000000
0000000000
-m-m~#~mm~m~m~mm~m~m~mmmmmmmmmmmmmmmmm~mmm~mm---m~m--mmm~-m--mmm~m~#mm#mmmm-mmm-!
-999. 5'0 VCA.MWD 99 250 V~P.MWD -999 2,50 DER.WWD
-909.25o CALN,~!,,O 99 250 PFF.MWD -999 250 NPHI MWD
-999,25o RHOB. NI,;D -999.~50 ROB~i. MWD -999 250 ROBR:M~D
-9o9,25¢ ~OBL, ~WD -99~,250 GRCH. ATL -999 250
. ;,~%~O -999,250 ROP MWD 999 250 RA.MWD
DFPT. ~9~7 009 C,R. .. .- .
R P. ,~, r~ r~ -909.2~. o VPA, b:%,:D -999.2b0 VPP.HWD 999.250 DER.M~D
FET.'~,v~ -909.250 C Ab~',,!. ~ D '4,208 PEF.M~D -999.250 NPHT.~WD
D~Hm ~,;~ -oc~q.2~ pHn~ ~,:VO -999.750 ROPU.,,-,,,D -999.250 ROBR.MWD
RODU. ~,:~p -9e9.25·) ~ OP, b. ~,'~w b -g9q.~LO gRCd. Aq,'b -999.250
0
-999,
-999,2~0
-999,250
-999,250
-999,250
-999.250
-999.250
** E~"'~T;' OM f'"'Aq~'A **
.,IS ~ra~e Ver!.f:f, cat~,on Listlnq
;chlumberqer AlasKa Co~put~.pq Certe['
!2-OCT-1994 14:52
PAGE:
SERVICE
FILE TYP~
S~RVIC~ : FLIC
VERSION
~X ~EC StZ~ : !024
FILF t~U-~BRR: 2
~e~th shi~ted and clipped curves~ all bit runs merqed.
#
FILW oU ~'qA~Y
[,DWG TOU!, CODE START DEPT}4
.................~[)~, ~ 260
C I;> p 't 2673. o
B~SFLTbF CURVE FOR SHTFT8: GRCIi
CURVE S~iFT DATa (~,i~ASL)PED DEPT~)
~ASEblNE DEPTH
.......
8~8 n8~06,5
12589.5 !260~.n
~2534.~ !2552.5
~oo.e t 18,5
NFROEn DATA ~NURCF
STOP DEPTH
12448.0
!,2510,0
----- ..... ~:~IlVALENT L;NSgIFTED DEPTH----------
88906.5
! 260~ 0
!.18,5
ThE CASED bObF CR ¥,AS USf,. AS h B~SE CURVE. THE SHIFTED
C'~RVE', w~S THC M~D (JR. A~,,ID ALL CDR AND ADH C~!RVES WErE
SHIW'rEL) ~YT~ THE r,~AD GR.
IS WaDe Verlficati. on Listing
chlt]n~b, erq~rn ].aska Co~put~,nq Center
l~-OCT-19gg 1~:52
PAGE:
$
TYPE - 64E~ **
--~;-. .... ~.......,~,~ ..... ~ -------
E ~PR CLDE, VALUE
2 66 0
3 73 6b
4 66
5 66
6 73
7 65
9 65
11 66
I~, 65 ~T
16 ~6
9 6~
N~MF S~RV ~tNIV SE~VICM ~PI APl APl ~PI !~ MU SIZE REPR P OCES$
!D ORDE~ . I, OG TYPE CbASS ~OD NUmB S~P ~SEM CODE (HEX)
0000000000
0o00000000
0000000000
0000000000
OOnO000000
0000000000
0000o00000
0000o00000
0000000000
0000oo00o0
0000o00000
O00000oO00
00000000o0
0000000o00
OOO0000UO0
o000000000
00o0o00oo0
.,IS Taoe VerlffcatJon [,istln¢l
;chlumberqer AlasKa Computino Center
g~U OF DATA
t~-0CT-1.994 14:52
-g99.250 ROP.aWD
-999.250 YRP,MWD
-999.~50 MP~I.MwO
-999.~50 PO~R.MWD
76.276
-999.250
-999.~50
-999.250
-999.250
-999.250
31.600
2.466
DER.~D
ROBB.~wD
RA.MWD
OER.~WD
DRHO.~D
ROBB.gWD
PAGE:
'999,250
'999,250
"999,250
-999.250
-999.2150
-999.250
0.102
2.479
F!LF NA~E
S~RVICE : FLTC
VERSION : oOICOI
DATF : g4!1(~/12
F!L~ TyPE :
LAST FILE
**** FILM wEADFR ****
FTb~ NA~E : ~DTT ,003
SERVICE : FL!C
DATF
~(aX RFC STZE : ~02~
FILF TYPE
b~Sm FILE :
Curves and
BIT RUN ~,~BEP;
DMPm~l
FIbE
I OVG ~COI,
3
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i
START DEPTH
......
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hit run in separate
STOP DEPTH
~007.0
i.ies.
Tape VerJflcat~ion l.:lstlr'~o
~chltlmberg!er Alaska Comp.tlpg Cente~
1~-OCT-1994 14:52
PAGE:
hOG HEADf~ DATk..
TD DPIt,L~R (mT):
TOP [,OO TNTEPV~b
PCTTOY LOG
~IT ~OTATING SPEED
~[~LE I~.iCI~I~.~ATImN (
FLUID LO
v{j~ C
~< ATRI Y D
#
28-JUi~94
LOgOS 20.4
F~ST 2,5
MEMORY
~2~62.0
8O40.0
12~lq,O
~5
6s,4
TbOb NI. JMBE~
AZNUTHAT DENSITY NE'[ITRO~,~ ADNoOI
CO~P DUlL RESISTIVITY RG8059
T STZ~ (IN): 8,500
CAS'f/'~(; DEPTN (FT): 8932.0
ITY (LB/G): 10,4,0
OSI~Y ($): 43.00
SS ¢C3):
R E C 0" . ~,";
~DED q'E PE ,~TURE (DEGF): 1,55,~
ITY (~H~) ~T T~MPERATU~E (DEGF):
T ~.~F,ASLJ~ED TEMPERATURE (NT): ~.150
T bi. aX CTRe'dI, hTING ~'EMPE~ATURF :
II, TPAT~] AT f?4T) I 2.340
AKE AT (toT): 0.000
b
SA~DSTONE
EN$IT¥; 2.65
RFC~IOI.! (T~): 8.500
fiN): 0.875
f Pi7 ):
************ PUN 1 *************
AF, N RP m(~ ~;T. nP: 126.~3 FT
DF!,:$Iq"¥ ';'~ ~IT ~30.13 FT
D~II, LF, O !~T('FRVAL 86B2 TO 1286~ FT
~.~SNOO,.:~~ Ti'tTEPVAb 12560 TO 12720
S
FT
67.0
67.0
0.0
LIS ?ape Veri. fJ. CatJon LiSting
Schlumberger AlasKa Computing Center
LIS FOR~,~AT DATA
12-0CT-1994
14:5o
PAGE:
2
4
5
6
7
9
1,
1
1
i
{)
66
65
68 0.5
66 15
67
65
66
66
;;mm;mm ..... mmmmmmmm~m, mmm, mmm ......... mmmmm,mmmmmmmmmmm~)~,~;~mmmm
PI AP1 FII, E NUMB HUMB SIZE REPR P~
PR CLASS t~OD NUmB SA~P EbEM CODE {HEX)
O0 O0 0 3 1 I 4 68 0000000000
O0 O0 0 3 I 1 4 68 0000000000
O0 O0 0 3 1 ! 4 68 0000000000
90 O0 0 3 1 J 4 68 0000000000
O0 O0 0 3 ~ 1 4 68 0000000000
O0 O0 0 3 1 1 4 68 0000000000
OO O~ 0 3 1 1 4 68 0000000000
Om O0 0 3 1 J. 4 68 0000000000
O0 O~ 0 3 1 J 4 68 0000000000
~0 on 0 3 1 1 4 68 O00OO00000
O0 O~ 0 3 J. I 4 68 0000000000
O0 O0 0 3 J. 1 4 68 0000000000
o,~ O0 0 3 1 1 4 68 0000000000
O0 O0 O 3 I !, 4 68 O000000OO0
OO O0 0 3 I 1 4 68 0000000000
Co O0 0 3 1 ~. 4 68 0000000000
O0 On O 3 1 ~. 4 68 0000000000
,IS ~a~e Verification !istl. no
ichlu~berqer AlasKa ComputinO Center
D~PT. 12864.500
T~. LW ~ -9o9.25u
** E,~J"D OF DATA
t2-0CT-I994 14:52
-999.250
-999.250
-999.250
-999.250
RO~U.DNI
DPHI.LWI
%NOH.LW!
~OBU,bWI
DBWI,SW1
TNPH,LW1
ROPE'b~t
1.t, 74
0.467
0.098
-999.250
-999.250
-999.250
48')87
2 008
60.950
-999.~50
ROBR.LWl
DRHO,L~!
ATR.L~I
GR.LW1
ROBR.LW1
DRHO.L~I
ATR.LWl
GR.T~Wl
PAGE: 10
-999'250
-999,250
-999,2~0
-999,250
,
FILF ~AUg : EDIT .0o3
VERSION :OO!COl
DAT? : 04110112
~AX REC STZE
FILF TYPE
LAST FILE
FIL~ NA~E :FDIT .004
SFRVICE : FI.~C
VERSIC~,~ !OO!COi
PATw : 04/lo/12
MAX RFC STZP
FTLw TYP~ : I.O
LAST FI[,E
FIb~
Curves and log r, eader data for
BTT R;~ ~!;~gEP:
DEPTH !NCREUEP~: 0.5000
FILF
TDWG TOOl, C{JPg START DEPTN
I.iI..i.iiii.i
~DN i2753.0
CDP 12015.0
each
bit run :tn
STOP DEPTH
T "'l ....
... 375 0
J. 2436,0
separate
files.
~IS Ta~e ve~.r~c~t.tor, ~,istlnO
.,,chl, t~mherqer Alaska Compt~t~n~ Center
12-O6T-!994 14:52
PAGE{
LOG
SI.,R~'A. CE SOFT~{t~Rf.7 VFRS!U~,~:
DOv~:~.~iOL, F SOF'iWAPE V~RSION:
LOG I~TERVAL
~OTATING SPEED
I~CI.,Ir:Aq'I~; (DEC)
TOOL STPlNG (TOP TO
VENDOP TOOL COD~ TOOL TYPE
S
BOREHOLE AND CASING DATA
OPEN NOI,E BIT SIZF (IN):
COiqP D!Itb RESISTIVITY
BO~E,qOf.,E
aUD TYPF:
~{f~b VYSCUSITY
MUD PH:
~,~UD CHbORTDES
FLUIO LOSS lC3):
MAXI~!UNi RFCOEDED ~EMP~RA'rI~RE (DEG,):
RESISTIVITY (Of.f~.~) ~'1' TENPE~ATURE (DEGF):
~UD AT ~FASUPEP TE~PER~TUR~
}~ljf) AT ?AX CTRCi.¢LATI~IG TFNPERATURE
~U~ FILTDATE AT
~¢U~ CAKE AT
N$IiY:
#
NEI!TR[~! mOaL
MaTP!×:
¢¢AT~iX DE
HnbE COPR
#
TOOL .STAt, TL)nFF (IN),'
************ PUN I *************
Af)N RP .~{3 ~.T: 126.53 FT
DF~.]SIT¥ TO R!T 130.~3 FT
NFUTRn~ Tn ~IT J34,41 FT
I)PI[,LFP INTERVAl, ~032 TO 128b~ FT
:,~SHL)O~,N ]'i~EPVA!., 1~560 TO 12720 FT
LUGOS 20,4
FAST 2.5
1.2B6~.0
8040 0
TOOL NUMBER
RGS059
8 5O
10,40
43,00
~3000
155.0
2,150
2,340
0,000
SANDSTF]NE
2.65
~,500
0,875
67.0
67 0
o;o
Tame verltication Listinq
;cblu~berqer Al. as~<a Con~pt]tln~ Center
lP-OCT-1994 14:52
PAGE:
12
~'YPZ REPR CODE VALUE
3 73 64
~ 66
6 73
7 65
66
13 66
14 65 FT
i5 65 68
** SMm TYPE - CMA~t **
~ SER¥ ~Iq:' V APl' API h ~ F L ~B NUmB SIZE REPR P~OCES$
1t3 ~RDER ~ bOG TYPE CL~5S ~OD NUMB $.A~P ELEM CODE fHEX}
DEpT FT O0 000 O0 0 4 I l 4 68 0000000000
RMO~ ~D~ G/C? O0 OOfl O0 0 4 i 1 4 68 0000000000
ROBU ~1)1 G/C3 O0 000 O0 0 4 ~ ! 4 68 0000000000
ROBp ub1 G/C3 oO 00~ O0 0 4 ! ~ 4 68 0000000000
ROB~ ~'i)~ G/C? O0 000 O0 0 4 ~ 1 4 68 0000000000
RO8~, ~D~ G/C3 O0 OOO O0 0 4 ~ 1 4 68 0000000000
D~H]' ~ PH O0 000 On 0 4 ~ 1 4 68 0000000000
D~HO ~bl. G/C] O0 000 O0 o 4 ~ 1 4 68 0000000000
P~F ~'D! ~;/E O0 OOo O0 0 4 ~ 1 4 68 0000000000
DCAL ~D1 IY O0 O00 O0 ¢) 4 ~ 1 4 68 0000000000
TNpu ~)1 P!~ O0 O00 O0 0 4 I 1 4 68 O00000OO00
ATR ~D~ 0~~? O0 OOO O0 0 4 ~ ! 4 68 0000000000
PSR ~b! U~,~ O0 000 OA O 4 ~ 1 4 68 0000000000
DER ~pt f!u~ O0 OOn OO 0 4 ~ ~ 4 68 0000000000
ROpw "bt Flt;~ O0 000 OO 0 4 ~ 1 4 68 0000000000
G~ ~D1 GA?T O0 OOO O0 0 4 ~ 1 ~ 68 0000000000
mmmm~mmm~mmmmmmmmm~mmmm~mmmm~mmmmmmmmmmmmmmmmmmmmmm~mmmmmmmmmmm~mmmmmmmmmmmmmmm#mmm~mm
** F:aTa **
ver~ f~.cat~.on !,istfna
AlasKa Co,.',p.t~no Center
12-OCT-~gq4 14:52
PAGE:
13
D~PT. 12375.009
-999.'2,50
-99c~.250
-99g.250 T~'~PH, HD1
2.435 ~OBU,~D1
0,SB~ TNPH,~DI
-990.~5n PODE,~DI
999 250
-'999:250 DRHO.
-999.250
-ggg' o
-9gg.250
3,137
93.519
2.4,37 ROBR.~DI 2,452
9.700 DRHO,uD1 0,080
30.300 ~T~.~DI -999~250
-999.250 GR.~D1. -999.250
DATA **
FIL~ NA~E : EDIT .004
SERVICE : ~bTC
VER~!ON : O0~,COi
DAT~
~lX ~EC SIZE
FIL~ TYPE
L~$T FILE
**** TAPE TRAILER
D~TF : q4/!o/12
O~ICt~ : WbTC
PREVIOUS TA~E
C~F~? ~ ~P E×PbORAwIO~ M!b~ POIMT. MPC-2~. APl
**** RRgT, mR^II, ER ****
S~RVlCY N~ : EDIT
DATF : q4/10112
OPI~I~ : Fb!C
REE[ ~'A~E : 947~5
CON?INUaTIO~.~ ~ :
P~EVlOU~ REEL
C~M~EN~ : PP E~PLOPATiON, .~TL~)E POINT, MPC-~I, APT 50-029-22486-00
