Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout192-067PBU 07-04A
Hilcorp North Slope, LLC
3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503
192-067
50-029-20292-01-00
9900
9213
80
2687
7760
2290
20"
13-3/8"
9-5/8"
7"
8700
38 - 118
37 - 2724
35 - 7795
7610 - 9900
38 - 118
37 - 2724
35 - 7635
7469 - 9213
9749
9215, 9611
1490
4930
6870
7240
8911 - 9644
4-1/2" 12.6# 13Cr80 33 - 8722
8476 - 9020
4-1/2" Otis MHR Packer
8664
8300
Bo York
Operations Manager
Jerry Lau
jerry.lau@hilcorp.com
907-564-5280
PRUDHOE BAY, PRUDHOE OIL
ADL 0028309
33 - 8341
N/A
N/A
346
Well Test Not Available
59110 59 9
628
1501
0
N/A
PRUDHOE OIL
No SSSV Installed
8664, 8300
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
REPORT OF SUNDRY WELL OPERATIONS
Digitally signed by Bo York
(1248)
DN: cn=Bo York (1248)
Date: 2025.05.21 10:30:52 -
08'00'
Bo York
(1248)
9215
By Grace Christianson at 12:39 pm, May 21, 2025
DSR-6/3/25
RBDMS JSB 052325
JJL 6/13/25
ACTIVITY DATE SUMMARY
5/18/2025
***WELL S/I ON ARRIVAL***
RAN 3.85" GAUGE RING TO DSSSV @ 2,195' MD
PULLED 4-1/2" HRQ DSSSV FROM SVLN @ 2,195' MD
DRIFTED w/ 10' x 3.70" DUMMY WHIPSTOCK FOR HEX PLUG TO TOP OF IBP @
9,592' SLM
***WELL S/I ON DEPARTURE***
5/19/2025
***WELL SI ON ARRIVAL*** (PERF AND HEX PLUG)
MIRU AK ELINE
PT: 250/3000 FUNCTION TEST WLVS
LOG CORRELATED TO SLB PPROF LOG DATED 03-OCT-2014
PERF INTERVAL: 9164-9178' CCL STOP: 9151.4' CCL-TS: 12.6'
INTERWELL HEX 363-700 MID ELEMENT: 9220' CCL STOP DEPTH: 9205.1'
CCL-ME: 14.9' CCL-TOP: 9.4'
TOP OF PLUG: 9214.5'
RDMO
***WELL LEFT SHUT IN ON DEPARTURE*** (JOB COMPLETE)
Daily Report of Well Operations
PBU 07-04A
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Wallace, Chris D (DOA)
From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com>
Sent: Thursday, May 24, 2018 1:16 PM
To: Regg,James B (DOA)
Cc: Wallace, Chris D (DOA);AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well
Information
Subject: NOT OPERABLE: Producer 07-04A (PTD#1920670) IA casing pressure above NOL,
DSSSV out of hole
Mr. Regg,
Producer 07-04A(PTD#1920670) has known TxIA communication via the SSSV nipple and requires a dummy SSSV.The
well was made Not Operable on 10/17/16 after the dummy SSSV was pulled. On 11/08/16 a dummy SSSV with plug
assembly was reinstalled to secure the well.On 05/22/18 Slickline pulled the DSSSV and plug assembly for upcoming
Eline Perforating work.With the plug and dummy SSSV out of hole,the inner annulus casing pressure broke NOL on
05/23/18.The T/I/O pressures were 2390/2330/10 psi.
Plan forward:
1. Eline: Perforate
2. Slickline: Re-set DSSSV to mitigate known TxIA
Please respond if in conflict.
Andrew Ogg
Well Integrity Engineer
BP Global Wells Organization-Alaska
Office:907-659-8110
sCANNED MAY 3 4r flI
1
II 40
v of 7.41
g .-1///,•w. THE STATE Alaska Oil and Gas
...41
- �, o T A K A Conservation Commission
� 5}#� �� 333 West Seventh Avenue
'$ ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572
,
(4'
ti*.',. -»-� Main: 907.279.1433
ALAS Fax: 907.276.7542
www.aogcc.alaska.gov
David Wages
Well Interventions Engineer 1- ) 2 32.017"4
BP Exploration(Alaska), Inc. �� z.
I.JP.O. Box 196612
Anchorage, AK 99519-6612
Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07-04A
Permit to Drill Number: 192-067
Sundry Number: 316-413
Dear Mr. Wages:
Enclosed is the approved application for sundry approval relating to the above referenced well.
Please note the conditions of approval set out in the enclosed form.
As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further
time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC
an application for reconsideration. A request for reconsideration is considered timely if it is
received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if
the 23rd day falls on a holiday or weekend.
Sincerely,
../ P4644._
Cathy '. Foerster
//// Chair
/ f�-
DATED this {t day of October, 2016.
RBDMS 0-- OCT 1 1 2016
:.: 1
VED
STATE OF ALASKA A U tG 0 9 2016
40 ALASKA OIL AND GAS CONSERVATION COM ON
APPLICATION FOR SUNDRY APPROVALS
,,��,,,,,,✓✓//// 20 MC 25.280 AOGCC
1. Type of Request: Abandon 0 Plug Perforations VFracture Stimulate 0 Repair Well ❑ Operations shutdown 0
Suspend El Perforate Perforate ((#Other Stimulate 0 Pull Tubing 0 Change Approved Program 0
Plug for Redrill 0 Perforate New Pool 4`13e-enter Susp Well 0 Alter Casing 0 Other Set Scab Liner I! •
2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 192-067
3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0.
99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20292-01-00
7. If perforating: 4 (./ 8. Well Name and Number:
What Regulation or Conservation Order governs well spacing in this pool?
��
Will planned perforations require a spacing exception? Yes 0 No 0 PBU 07-04A i
9. Property Designation(Lease Number): 10. Field/Pools:
ADL 0028309 - PRUDHOE BAY,PRUDHOE OIL -
11. PRESENT WELL CONDITION SUMMARY
Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): v lugs(MD): Junk(MD):
G�
9900 ' 9213 ` 9611 8995 Z 3 i v 9611 9749
Casing Length Size MD TVD Burst Collapse
Structural
Conductor 80 20"91.5#H-40 37-117 37-117 1490 470
Surface 2691 13-3/8"72#N-80 39-2730 39-2730 4930
2670
Intermediate
Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment
Liner 2290 7"26#13Cr80 7622-9912 7479-9222 7240 5410
Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft):
See Attachment See Attachment 4-1/2"12.6#13Cr80 13Cr80 32-8721
Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment
4-1/2"RQ-DSSSV 2207, 2207
12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work:
Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development Il • Service 0
14.Estimated Date for Commencing Operations:
t!�q/j/I 15. Well Status after proposed work:
Oil I3 • WINJ 0 WDSPL 0 Suspended 0
16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0
Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0
17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Wages,David
be deviated from without prior written approval.
Email David.Wages@bp.com
Printed Name Wages,David Title Well Interventions Engineer
Signature tj—V
ixi/kPhone 907.564.5669 Date
COMMISSION USE ONLY k/9 A h
Conditions of approval:Notify Commission so that a representative may witness Sundry Number:
Integrity Z kl_Q— " l
Plug 9 ty 0 BOP Test V Mechanical Integrity Test 0 Location Clearance 0
Other: [30/p 1--C•5 /- p1---e-'55vvG -to 4000 p5 t`
✓tr�vrvlarprel��vcf�✓ h— 5t 2k7SS��:' f� ZSo �� 5t.;" w�✓ �'� �2�QcQ-
lnrW 1145),,..C61-1 o>7 f>'-o(BGG `a r to 2
Post Initial Injection MIT Req'd? Yes 0 No 0 t...fjSF. iO+ I
-/ a 110
Spacing Exception Required? Yes 0 No Lad' Subsequent Form Required: l D -'4 04-
APPROVED
4'APPROVED BYTHE
Approved by: COMMISSIONER COMMISSION
Date:/0- 7/-//6
1/7-1. 10/11 /IL,
ORIGINAL '0/07
RBDMS (,c,—OCT 1 2 201616 F. 9 //,
Submit Form and
Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate
• •
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• •
Summary of Proposed Work
BP Exploration Alaska (BPXA)
07-04 Scab Liner
PTD - 1920670
API No. - 50-029-20292-01
Engineers:
Eric Dickerman (907) 564-4277
Dave Wages (907) 564-5669
Michael Hibbert (907) 564-4351
Paulina Meixuerio (907) 564-5971
Well History:
07-04 is a slanted well drilled in 8/92 and completed in Z2. An IBP was set in 8/96 and
seemed to have SI -500 bwpd. In 9/03 an MCNL identified a lens -20' TVD thick in
Z2C. Oil production started declining at a faster pace in 2007. By 8/08 the well was
making -240 bopd, 6 mmscfd (25K GOR), so 10' of perforations were added to access
the lens in 10/08. This resulted in 730 bopd, 15 mmscfd (20K GOR). Gas rates steadily
increased since then. The 2013 RST shows the lens at less than 10' TVD thick. By
9/2014 the well reached 50 mmscfd and was experiencing downtime due to high GOR.
A 10/14 PPROF was run in the 7" liner, which suggests 53% of the gas coming from
the Z2C lens. Low oil contribution is expected to be coming from the top perf. The gas
composition analysis also indicates the gas is lean. The plan is to SI the top perf to
reduce the GOR of this well and make it competitive again.
Objective:
Shut off gas production from upper set of perforations by running and cementing a
scab liner. Reperforate target production intervals.
• •
The procedure includes the following steps:
1 . Slickline Drift. Pull DSSSV. Pull IBP. Drift.
2. Valve Shop Remove swab valve, leaving flow cross and two master valves.
Coiled Tubing /
3. Wellwork Drift. Well Kill. Make up 3-1/2" scab liner. Deploy liner. Cement
Platform liner. Cleanout cement.
4. Valve Shop Install swab valve.
5. Fullbore WOC 3 days_ Pressure test TRC and scab liner.
6. Slickline Drift to TD. Set Dummy Subsurface Safety Valve.
7. Eline Perforate target injection zones. 4 ' I- Ce t•-vi-15cf�
• •
Loepp, Victoria T (DOA)
From: Wages, David <David.Wages@bp.com>
Sent: Wednesday,August 10, 2016 10:20 AM
To: Loepp,Victoria T(DOA)
Cc: Meixueiro, Paulina; Dickerman, Eric
Subject: RE: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner
Follow Up Flag: Follow up
Flag Status: Flagged
Victoria,
Below is the MPSP for our list of wells(in order of priority)
Y
1) 3-12: Reservoir pressure @ 8800'TVD: 3300 psi, MSPS:2420 psi
2) 9-19: Reservoir Pressure @ 8800'TVD: 3400 psi, MPSP: 2520 psi
3) 7-04: Reservoir Pressure @ 8800'TVD: 3270 psi, MPSP: 2390 psi
Per BP's standing orders:
The BOP rams will be tested to 4000 psi every time on every well
The Annular will be tested to MPSP
Thank you, please let me know if you need anything else.
David Wages
o. 907.564.5669
c. 713.380.9836
W I E-AK
From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov]
Sent: Wednesday,August 10, 2016 9:25 AM
To: Meixueiro, Paulina
Cc: Wages, David
Subject: RE: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner
MPSP is the maximum potential surface pressure based on a pressure gradient to surface of 0.1 psi per foot of TVD
depth. See 20 AAC 25.280(b)(4)for definition. BOP schematic for BOP intended to use.
From: Meixueiro, Paulina [mailto:paulina.meixueiro@bp.com]
Sent: Wednesday, August 10, 2016 9:09 AM
To: Loepp, Victoria T(DOA)
Cc: Wages, David
Subject: RE: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner
Hi Victoria,
We will get you the post-work schematic and the more detailed procedure.
Can you elaborate more on the MPSP and the BOP schematic? I want to make sure we understand what's the request.
Thanks,
1
• •
Paulina Meixueiro
Production Engineer
(907)564-5971
From: Loepp, Victoria T(DOA) [mailto:victoria.loepp()alaska.gov]
Sent: Wednesday, August 10, 2016 9:03 AM
To: Meixueiro, Paulina
Cc: Wages, David
Subject: RE: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner
I have not heard back on this. Please also provide a BOP schematic, MPSP and BOP test pressure.
From: Loepp, Victoria T(DOA)
Sent:Thursday,July 28, 2016 11:22 AM
To: 'paulina.meixueiro@bp.com'
Subject: PBU 07-04A(PTD 192-067, Sundry 316-363) Scab Liner
Paulina,
Please provide a post-work schematic. The setting depths for the liner are not clear. Please provide this as well as a
detailed word procedure.
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil&Gas Conservation Commission
333 W.7th Ave
Anchorage,AK 99501
Work: (907)793-1247
Victoria.Loepp at alaska.00v
CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation
Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged
information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended
recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to
you,contact Victoria Loepp at(907)793-1247 or Victoria.Loerx @alaska.gov
2
bp • •
1,040
Ilk it
07-04 GSO with Scab Liner
loot
Wellwork Procedure Request
To: T. Norene/L.Seymour:Well Services TL Date: 09/12/2016
J. Middendorf/R. Liddelow: Wireline Team Lead
AFE: APBNRWOS
From: Michael Hibbert IOR:
Est. Cost: $415K
Subject: 07-04 GSO with scab liner
Revision:
Job Sequence
WBL Steps Completed
(mm/dd/yy)
1. S Drift. Pull DSSSV. Pull IBP. Drift.
2. C/WWP Drift.Well Kill. Make up liner. Deploy liner. Cement liner.
3. F WOC 3 days. Pressure test.
4. S Drift. Set DSSSV.
5. E Perforate.
Job Objective:
Specific Well Objective
1 Shut off gas production from upper set of perforations contributing to 53% of gas production and
low oil production.
2 Reperf target production zones at 9,630'—9640' MD and 9,595'—9,610' MD.
Program Contacts:
Work Phone Mobile Phone
Eric Dickerman 564-4277 307-250-4013
Paulina Meixuerio 564-5971 907-306-6173
• •
1 Scope of Work
1.1 Well Summary
07-04 is a slanted well drilled in 8/92 and completed in Z2. An IBP was set in 8/96 and seemed to
have SI —500 bwpd. In 9/03 an MCNL identified a lens —20' TVD thick in Z2C. Oil production
started declining at a faster pace in 2007. By 8/08 the well was making —240 bopd, 6 mmscfd
(25K GOR), so 10'of perforations were added to access the lens in 10/08. This resulted in 730
bopd, 15 mmscfd (20K GOR). Gas rates steadily increased since then. The 2013 RST shows the
lens at less than 10' TVD thick. By 9/2014 the well reached 50 mmscfd and was experiencing
downtime due to high GOR. A 10/14 PPROF was run in the 7" liner, which suggests 53% of the
gas coming from the Z2C lens. Low oil contribution is expected to be coming from the top perf.
The gas composition analysis also indicates the gas is lean. The plan is to SI the top perf to
reduce the GOR of this well and make it competitive again.
Well:04-07 Version: FINAL 2
Operations Program
•
2 Critical Issues
2.1 Tree Configuration
1. Due to height restraints, the swab valve will need to be removed from the tree prior to
rigging up the Klondike.
2.2 Key Risks and Mitigation Strategy
2. Well has confirmed tubing and packer integrity by passing MIT-IA on 09/26/2014. It
has 2 annuli, IA and OA. Do not exceed 1000psi on the OA, or 2000psi on the IA.
3. Adjacent Well Shut-in Requirements: NONE — The adjacent wells, 07-03 and 07-05,
are on 120' spacing. There is adequate room to rig up the Klondike without removing the
well houses from 07-03 and 07-05. Supporting injectors do not have to be shut in.
2.3 Pressure Prediction
1. Reservoir pressure — BHP is expected to be 3270 psi (7.2 ppg) @ 8800' TVDss.
Maximum surface pressure with gas (0.10 psi/ft) to surface is 2390 psi. A full column of
1% KCI (8.4 ppg)will provide a —565 psi static overbalance.
2. Fracture pressure — For the PBU main area the FG is estimated to be 0.65 psi/ft. This
equates to 5,720 psi.
Well:04-07 Version: FINAL 3
Operations Program
• •
3 Well Specific Information
3.1 Wellbore Volumes
Top Bottom Size ID Capacity Volume
MD MD
TBG 0 8709 4-1/2" 12.6# 3.958" 0.0152 bbl/ft 132 bbl
LNR 8709 9848 7"29# 6.276" 0.0383 bbl/ft 44 bbl
IA 0 7600 9-5/8"47# x 4-1/2" 12.6# - 0.0535 bbl/ft 407 bbl
IA 7621 8651 7"29#x 4-1/2" 12.6# - 0.0175 bbl/ft 18 bbl
Total IA Volume 425 bbl
3.2 Cement Requirements
1. Cement Volume
Volume Note
7"29# LNR x 3-1/2" 9.3#scab liner 30bbI Volume from PBTD to TBG tail (9848'—
annular fill up volume 8696')
Total cement to pump 40bbl 30%excess
2. Cement Properties
Ppg 15.8 ppg Glass G. Field blend to be+/-0.1 ppg of lab blend.
Slurry Temp Between 80deg F and 110 degF
API Fluid loss 40-200 cc
Thickening Time 6 hrs
Compressive strength 2000psi at 24 hrs
Batch mix
3. Cement Thickening Time
Activity Time(hrs)
Shearing time, quality control, PJSM 1
Cement displacement 1
Cement contamination 3
Safety 1
Minimum required thickening time 6
4. Cement Ramp
Time Temp (deg F) Pressure
0:00 90 0
1:00 90 0
1:30 135 3000
2:00 180 4000
2:30 195 3000
3:30 205 3000
6:00 205 3000
Well:04-07 Version: FINAL 4
Operations Program
•
4 Procedures
Reference Documents
• Well Entry SOP
• Coiled Tubing `Klondike' Overview RP
• CTU Operations-Squeeze Cementing RP
• CTU Operations—Cleanout Procedures RP
• Operational Procedure for 450-325 ORC Composite Cementing Valve
4.1 Slickline — Drift. Pull DSSSV. Pull IBP.
1. Drift to DSSSV.
2. Pull DSSSV at 2,195' MD.
3. Drift to IBP. (Confirm IBP Type prior to fishing)
4. Pull IBP at 9,611' MD.
5. Drift and tag TD with S.Bailer.
• If tag is above 9800' a FCO will be performed.
6. Drift to XN for 3-1/2" liner(Max OD of liner 3.785").
Well:04-07 Version: FINAL 5
Operations Program
i i
4.2 MIRU Klondike and CTU
Well Barriers
Tubing MV, SSV
Inner Annulus Tubing/packer, Production casing, IA casing valve
7. MIRU Klondike.
8. ND tree cap flange. NU 7-1/16 BOPE to swab flange per attached BOP diagram.
9. Function and pressure test BOPE per SWS Klondike BOP test procedure.
10. Rig up the remaining CT equipment and pressure test PCE against the top of the SSV.
Well:04-07 Version: FINAL 6
Operations Program
O
4.3 Well Kill
Well Barriers after CT RU
OOH at surface In hole
Tubing Primary: MV, SSV Primary: DFCVs, Lubricator,
Stripper, Kill line check valve
Secondary: BOPs
Secondary: Inner reel valve, BOPs,
Choke line HCR
Inner Annulus Tubing/packer, Production casing, IA casing valve
11. If SL tagged high while drifting to TD, perform a FCO to a target depth of -9840' then
move on to step 23.
12. If FCO is not necessary, RIH for drift to PBTD. Bullhead -230bb1 1% KCI for well kill
while RIH. After 230bb1 please note injectivity rate at 0.5, 1.0, and 2.0bpm.
• Monitor"in"and "out" micro motion rates and note any loss rate in AWGRS.
13. Dry tag TD, PUH 10' and if loses are not sustainable, begin laying in a 150,000 LSRV gel
pill across perforations.
14. POOH pumping displacement.
15. Flow Check Well - After bullheading, shut down and monitor for losses. If well is on
losses keep well full and assess static loss rate. If well is not on losses, perform a 10 min
flow check as planned. If the well is flowing, RIH and circulate a bottoms up, then lay in
another LSRV pill.
16. Lay down injector and install slip bowl.
Well Barriers after laying down injector
Tubing MV, SSV
Inner Annulus Tubing/packer, Production casing, IA casing valve
Well:04-07 Version: FINAL 7
Operations Program
O •
4.4 Make Up Liner
17. Open MV and SSV, and flow check well for loss rate to determine hole fill up volumes.
Well Barriers during Flow check
TBG Fluid column, BOPE
Inner Annulus Tubing/packer, Production casing, IA casing_valve
18. Make up 3-1/2" liner assembly, according to Northern Solutions specifications. Ensure
liner has been drifted and tallied prior to RIH. Record ID's, OD's, lengths, and relevant
fishing specs of all equipment.
• Ensure Mechanical stage collar is installed in the"Open" position.
Well Barriers while MU liner
Liner Fluid column, BOPE, Safety joint/TIW valve
Inner Annulus Tubing/packer, Production casing, IA casing valve
19. After liner has been made up, close the 3-1/2" pipe/slip rams on the Deployment Joint
(not deployment sleeve).
20. Pick up injector and lubricator, make up BHA to CT as follows:
a) 3-1/8" CTC
b) 3-1/8" MHA
c) 4" Hydraulic release G Spear with 3"Seal Unit
Well:04-07 Version: FINAL 8
Operations Program
r •
Liner BHA
Nom Size Item lb/ft Material Thread Notes
2-7/8" Baker Bull Nose Guide Shoe N/A L80 STL TD at-xxxx' MD
2-7/8" Baker Float Collar N/A L80 STL
Can be
2-7/8" 30'joint(or pup joint) 6.5 13Cr-85 STL cementralized or
non-cementralized
2-7/8" Baker Float Collar N/A L80 STL
3-1/2" XO 9.3 9CR-80 STL 3-1/2"STL Box x 2
7/8"STL Pin
3-1/2" NS 350 ORCA Cementing N/A 13Cr-85 STL Place above shoe
Valve track.
-xxxxx' MD
3-1/2" 30'joints as needed 6.5 13Cr-85 STL Can be
cementralized or
non-cementralized
3-1/2" Pup joint 9.3 13Cr-85 STL Shop Made up for
Handling
TBD-above loss
3-1/2" 2.81 NS Stage Cementing N/A 9CR-80 STL zone. Place in
Sleeve inverted section if
possible.
3-1/2" Pup joint 9.3 13Cr-85 STL Shop Made up for
Handling
3-1/2" Pup joint 9.3 13Cr-85 STL Shop Made up for
Handling
3.813" 3.813 NS No-Go Seal Sub 9.3 9CR-80 STL Depth TBD
6'x 3.00" Baker Seal Bore 8,200' MD(based on
3.70" Deployment Sleeve w/4" GS N/A 13Cr-85 STL CCL depth)
Profile
Liner Running Tools
Baker 4.0 Hydraulic GS Spear 2/3.00" Nose Seal
Baker Disconnect(3/4"ball)
Rig-Landing Joint-2-3/8" Reg Box x Pin
Baker Dual Back Pressure Valve
XO-2-7/8"PAC Box x 2-3/8" Reg Pin
Baker 2-7/8"PAC Locking Swivel(not the 2-3/8"swivel)
Baker XO (5 pitch x 2-7/8" PAC)
Baker External slip CTC for 2-3/8"coil (5 pitch ACME)
Well:04-07 Version: FINAL 9
Operations Program
•
4.5 Deploy Liner
21. Position injector, strip over the liner and make up the CT to the liner, and make up QTS.
• Liner weight is approximately 10,695Ibs in air.
• Liner weight is approximately 9320Ibs in 1%KCI.
Well Barriers after CT RU
OOH at surface In hole
Tubing Primary: MV, SSV Primary: DFCVs, Lubricator,
Stripper, Kill line check valve
Secondary: BOPs
Secondary: Inner reel valve, BOPs,
Choke line HCR
Inner Annulus Tubing/packer, Production casing, IA casing valve
22. RIH at 60fpm getting good up/down weights and land Baker Deployment Sleeve on No-
Go in XN Nipple at 8,696' MD. Paint flag.
23. Pressure up down the CT backside to test seals in polished bore.
24. Establish circulation down CT and PU to release Hydraulic Spear. Confirm weight loss.
• This will put TOL at 8,591'. (Note circulation path will be bullheading into
formation during release).
25. POOH.
Well:04-07 Version: FINAL 10
Operations Program
i •
4.6 Cement Liner
26. Make up cement stinger BHA as follows
• NS Snap Latch Cement Stinger
• NS 2-1/8"Weight Bar— 1-1/2" MT
• NS 2.75" Centralizer— 1-1/2" MT
• Hydraulic disconnect(5/8" ball)— 1-1/2" MT
• Baker Weight Bar— 1-1/2" MT
• Baker HB-3 Shifting Tool -(Set for Mechanical Up— Brass Pins)— 1-1/2" MT
• Baker Weight Bar— 1-1/2" MT
• Baker 2.70-2.75 Centralizer— 1-1/2" MT—(Maximize flow by area)
• Hydraulic disconnect(3/4" ball)— 1-1/2" MT
• Baker External CTC w/ 1-1/2" MT threads
27. Displace CT to diesel at surface prior to RIH.
28. RIH watching for flag indicating TOL with ORCA Cementing Stinger Assembly while
pumping —100bbl (1.0x backside volume to stage collar) of diesel down CT backside to
maintain positive baseline WHP (should give 100psi of WHP).
29. Continue to RIH and get good up and down weights about 100' above ORCA Valve.
While stopped, establish circulation rates at 0.5 and 1 BPM and note pressures. Shut
down pumps.
30. RIH at 30'/min tag ORCA valve and slack off 5000#, hold set down weight for remainder
of cementing operation. Paint flag indicating bottom of liner
• Refer to attached OP for specific functions regarding the ORCA.
31. Pressure up to 2,500psi to rupture disk and regain circulation, indicating correct valve
engagement cement circulation path. Note any circulation variances from previous
baseline circulation.
32. Batch mix 40bbl of 15.8ppg Glass G cement.
33. Establish 1:1 returns up the CT backside before cement reaches ORCA Cementing
stinger.
34. Cement liner maintaining 1:1 returns (if possible)
• If cement top reaches stage collar with cement still at nozzle, shut in CT backside and
attempt to squeeze the rest of the cement away. If a squeeze is achieved, the squeeze
pressure will need to be trapped on the backside for the remainder of the job to prevent
pushing the liner up hole (example: squeeze pressure is -I500psi, maintain 1500psi WHP
for the remainder of job). If the well locks up while attempting squeeze, unstinq and lay in
remaining cement while pulling up hole to shift stage collar closed
• Worst case top of cement(no cement behind 3-1/2" liner) =6,722'
35. Unsting from cementing valve with -2bbls of cement left in the CT. Weight check to
confirm unstung from ORCA Valve and released from liner.
36. PUH and shift mechanical stage collar closed with HB-3.
37. RBIH to 5' short of flag indicating the bottom of liner and circulate/contaminate excess
cement with freshwater spacer and PowerVis.
38. POOH at 80%.
Well:04-07 Version: FINAL 11
Operations Program
! !
4.7 Cement Cleanout
39. RIH with 2.50" — 2.70" JSN to —6,700' and make three passes (down, up, down) from
WCTOC (6,722') to flag indicating bottom of liner, contaminating with 1.25ppb PowerVis,
taking returns up the CT backside.
40. At bottom, POOH at 80% making repeat passes across all jewelry, tree, and BOPE.
41. Freeze protect well with 40bbl of diesel.
42. RDMO CTU and Klondike.
4.8 Fullbore —WOC 3 days. Pressure test.
43. WOC 3 days, then pressure test TBG and 3-1/2" scab liner to 2000psi.
4.9 Slickline — Drift. Set DSSSV.
44. Drift and tag TD.
45. Set RQ DSSSV in nipple at 2,195' MD.
4.10 Eline — Perforate
46. Contingent SCMT if CTU had trouble tracking TOC during cement job.
47. Perforate from 9,630'—9,640' MD per Perforating form in SOR.
48. Perforate from 9,595'—9,610' MD per Perforating form in SOR.
Well:04-07 Version: FINAL 12
Operations Program
• •
TF1FF= 5'PAC 1,0 PWFFTY ICYrFFI.5F4/FRF 93'.AI FHIl 11 M 10 GI Ma we
44H1HE4D= GRAY' 3 W5 PF VICED LOG oansr96^'CHROME TUG&LI
ACUATOR= BAKER 07-04A 'n
FNrAL KB.ELE 64"
BF.BEV=
MD Al = 48'Q8995
Clrtmnt�D- &13g' i 2155' H4 117OTISI Po@SI_Nh.F.D-3.813'
Datum TVD- 80064 5 02195` H4-'2' DSSSV.D=2.62"11X7&14)
13 3119'CSG,724,N 80,L-12 24T H 2724' I GAS JT M4P10
IEta
R1) IVI) 11-V' IYH- VIV I IAIr11 PORI 1)A II-
AWE 30..444 I 'II-IC.I4) I*OY FIC O O1,67i%B3
5620 5619 3 TE TGR? CMI' 146 D Otlf.2 009
Minimum 10=2.62" r. 2195' , WI 8597 8575 22 T6TGR? CRM 1110 3
4-712 RQ DSSSV € 7440 732l 7R TF=T11141"OMY's RK O IliO:1117
7562 7426 26 i TE-TC-FD CMI' S 34: 3
rAT1ON$4-CMY HAS 1311131:433 PACKING
!OP UI PLM2 H ?GOO* I e ! 54.41"MLLUU11816D 7W(47.944)/!9.'''-i0bi
I S 5'6'CSG,470,N ETt.,D-0.001' H 7796' I
ITO,OFCDADIr H 3600' I
,44',.
•X41, 6625' H 172'OTIS X t,0?D-3.81'4'
4444E
4141',
4444• 9681" HT'7 X41t70TL5PERM PKRD-3.875'
11444`,
4444'
414344%
4444N,
44#444444444t;' 8648' 1-14-1,-.---/mix Hp.u..3.417 I
4444/4V
44444444
1 +4444'
44 ,
44444444440144' 969E --f4-It7O11SXN4P.D-3.725"1
♦44444*444444COO,,
4444444 4
=4./H 0030• 4.aai._ r`..,
I sip" Ha tn'14410.0-1.9yr I
44;4*4'Y4ii4444�4:f44,r ` 8687' Ia.k..OTTLOGGED 0&Po4192
444 i.e44 dial
I 4-102"TBG.128N,13CR80..3152/IVT,10-9.956' H 6706'
PERFORATION SillAt4RY
1 C)Cr ni KS ON 0844:1490
AMADLCATTOP RTC.42 9433 $611' HEP(0812a88)I
Me:Hater 83 I todacho n L03 for Maui pert data
8¢C SPT NTCR1'AL Cpr'Sgc I SHOT 50Z
:3-341' 6 9495-.5435 0 1 10iDW0F3 APIPP
3.3/0' 1 C433-8435 0 i 02'1595 97 F-ca v
3-3011' 3 14,44-91'53 V 1031I/2193
3 4 MEM-9!./04 0 IA02193 1001.'33)
:118-
3 318" 4 9594 9604 0 11104/92 \ `
:1-'1'13- 4 USIA-9131:1 IA ;1Ch11MJ'!
33'0' 4 0630-9644 C IOW 7102 ,�y,{..4,�•r,
PBTD 9845 +8,1'4011.;),
V LNR.28a-I3CF480...0383 4r,0-8.276' 1--1 8600' I
c m rs-v BY S DATE rRLV BY =maws MEMO BAY UNIT
P 89178 1 ORIGINAL COMPLETION 0011400:JF-0"1..H GLV D:IfIRECTUaS(2/20071V111L 07 09A
08(0982 ,MCETR ACK COMPLE11061 04409/09 S%'.OYTLII GLV o. &2013
C(09) TW P ?Mu.1920E70
011'20101 RYYTP OC411112CTICItS 04103/1311 .913 118:E00103/16/13) AR^#/.50 029 20282 Cl
If Cr:Alf IA•VWI911441 V(211 111416114 jJ Ki'KK .^4-I IL.NSV 3 IH::1J,111N hr141-..1,71 I-1-/K JiK Ma
0211E/07 70164),40 PLLL PXN T?44718596
111(1 JCI11 HHI YRK Iii b-S(112),4113) MP BtPmratlon FAIL I a)
Well:04-07 Version: FINAL 13
Operations Program
• •
Current Wellbore Configuration
1RFF 5'FXC:170 FIAFFIN M irPa•gwtl !ICAO Ffael rsP gg Gi ra se
ACTUATORAELLtEAD- BAKER GRAY
! 0 'J—04A 10.5 P5LY50BG]LOG 6874 6 CHROME TUGS LPR.
PIEAL K&Ell 64'
8F.a_ =
KCI-'= Kalil
duiti
W g
Cki Arnie *3 w I 2194 -In 1,2`OTE LROSVLNN4 43 3.613'I
atum1V0- emuss1 ` 2195' H4-112'RCC1355V,V=262';10i1&1.411
113 we-r�1:T211,14 80,ID-12.24T H 2724 I- '
GAS t11T 1.61.140'ILL3
PS) I'/I) ilivIY
NH.- VIV 1 IAIZII Ft/IIT 110,IF
: : 1 I II--WM I4 , NEa o
139 5819 3 TEICH) DAY PK 0 138125110
Minimum ID=2.&2 2195' LI 0997 13575 2z TSTGFD CMM PE6
4912"RQ QSSSif h 744e 7:1737n ,TF-TORI"•naer Far n 01129817a 7562 7429 26 I T> TGR) Cox R( 0
rATlON 44-C*I f HAS E3LTETVED PACI9!•1G
1
i TOP OF r"LM4 H ?663' 1 5-LuW h4LOIJ*VIAN)OW 197-44A1(fEC-.111.V
I a aw CSG,4740,N 49, 3061' H ' I
ITOP 41F CEMENT H 7800' I I
ilk
4;• \44 19 H4lir OT1SXM3,D-3.413-1
V. , I A6$1" HrX4.1/2`011SF 1FICR,D-3.875- I
44,444
4+4.44'•
444#.4.
414.414'.-:
441444.4441445', 1 8578' 1--147,3"umix ow,U-o.417
44+44+#
.0.0 4 ,
'44+4414►', 4 UTO SXNMP,D-3.725"
414+41!14'
.#0,10.04140*,
44.#44 4I )
.44#4H#44TN
I E7SV H $1730' Y.l..i, ..
1 6709' H 4.1,2'WA.Cfi1.D-3.959"I
t.11444,4fx i 1 \+ I 9697' --la I TT LOGGE canon I
xi..ii..ii .
14-1. -TEIG,12.6g,13CR88,111521ml,ID-2.g5" I-1 '
N.
REFIKRATIGH&WARY
IFF'I.OG Flt KS ON OW5192
ANGLIA/TOPPER".42 rit 9433 11611' HELP{0 0446)I
Nae:hieter l0 Iroduc9an 1.13 for 11t3104C6I pert data
SIZE SPF NIUWAL C71ud5gz SHOT S0Z
3-W 6 9475-8495 0 101 111133 Apr
3-3f6 1 9433-9435 0 02193.5
3-313' 3 9'718-9683 0 (T1021032740.' F13f-a v
:3-813' 4 Rae-84,91 0 41 8393 015.01.93)
3 318` 4 0594 9604 0 11,14092 '
'5-1 4 i4i1J4-1111:t a 1th11Wd7
3-fifer 4 N30 9044 G G541718Z
��w
FSTD 8948' ; �. k,
�►b.i►►
DATE RV SY COM14MTS DATE 1 P V BY 03304341S Rm DE9AY IJ4T
P earn 01404P AL.COMPLETION 10511-009.94011-H CLW 2 01av3,I LING(2,26071 WELL 07 NA
04101SIOETRACKCOMPLETION 09419M)9SiU1C,1U1GLV CID pa,2u(69) FI734TNo.'1924W70
09120101 Pa4'TP CORREETICHS .04033013 T414.94E)11SEC00{03/14,13) AR Na.50029 20292 01
LIIV:nlr 11x./111 I t3I V 1211 ,111rcI414,11til RE t*l 174.5;;,/ NI.I.;11-3,111x{KIP-,1.r1 1-H It 1311144
132115ar Jr38P14C PAL L PKN TP@ 6696'
1(1(1316 HMI YP C;14-111;S{10/CNUo!g E"61pbbraUon lAlaskal
S 0
Planned Wellbore Configuration
Ira
- 7 FUG 120 1 SAFETY MOTHS: SP/ERE SCALE SULOW Q GUIs 64
IN—I i ----7------7(GRA It 1/6 PER VIDEO LOG NOM"*"CHROME Teal UN
ACTIPTCR- BAKER 07-04A I
NTIAL KR ELE 541
SI REV
rKOP• 8207
1fto Analo= 4,a 101581
Datum fiCI.. 9131Y
0
m IVO- mat-
Iti ....,.....,:„...„. ; 2111F rttia-OTIS F1R2 SY LN.4P C-3 117
21W _I-14-1rr N2 RISEN,V-2.62'(101011114) I
113-318-C30.T210,5F410 ID•1234T H Z724'
OAS LOT NANXIi5
1 143 Tv° CEV TYPE VLV I LATCHVOI
30DATE
81 3093 1 TE-TOFEI OW : RK10 0920101
I
ID= "
562015619 3 1E-TDFD OW ! 111( i 0 0512009
Minimum 2.92tjj 219V 1
I ifoi 1627s Ti 11-fl ) now , Foc ! it
1 7445 7323 ZS It T( "01111Y. FIK , 0 01/2141/2"RQ DSSSV
/426 M 1E-BIM OW ; RK 0
rAnow Ill-MN 1MS MIMED PACKING
, t
NoH I 9-ser batourIANDOW(07-04AI TT* *56 I
e OF r-Lte T9017
rtk 59-C80,47*.N-80.0=f1.061"1--I 7791, 1.
T-IFP tocisetif-1-f
1
V4
tit . NW H4-In cms X NP E3=3 817
I*,,
\
II••
11 Olt
nor Hrx4-1.rr CMS MIR 3 077 1
11144
•••••
14.1114 \
644140
1410•041
114.1•45 WM 1,14-12-are 2 F*,13=3.217
••••••4,
••••••is
111014411
4.1•44X1W• \\911W____ 144-107 0113 IN NP,13
1044 0411
"WOW..
•• • 1
1.44.0•464011
USN 1 1 sow i
--.00.--4.11..-- ' 3343-i
4111'•teessee.••••Y I 88.7 I 1:.ELK/ri LOGGED°WNW 1
44.•••••••
I 4.1rr leo.12*.ISC/1416, 0152 WI 0 3 sar 871111'
VOIL.
4
PBIFORA11C9 SUMNARI
REF LOG 911:5 ON 01906/112 Run and cement
AMBIENT TOP FERF 42 a 11433' 3-12"scab liner _14-11,j-tOP 02(72.4pe):
Nolo Rotor to FIoduclbo LE tor*lofts!port di* Repertorate
SZE' SIT NIERVAL OprdSoz i 9.112T SIX
target production / ,
3-3,6" ti 9425-9435 0 19011131
3-31ir 1 9433.94.15 0 li02115005 zones_ ----,
9 7 411 lifiH GIN 1
3-3AT 3 I 9540-9550 0 103102193
33.0'' 4 ases-9591 0 0300250 , 00511031
3-W-
I
3-3.47 4 9694 9604 0 1101032
3-341-, 4 9004 *10 0 191992
3-387 4 9630 9644 C 108/1192
LI .00;
f mrio 1--l' 9646* ; ,44;4114I.
liZIZIP!.
,11..
LIVR.2521 13CICS4. 0302 bpi' 13-4 276- !--• 91100' .
DATE REV BY COME:NTS r DATE REV BYCONIENTS_j MIJOHDE BAY LINT
r OMNI OFIGINAI.COMPLETION te401::.11,211,44(XV CORFISCiicon i3/2007) WELL 97 04A
01901112 •SIDETRACK COMMET1C44 511T,../TIF GLV CO(00/2908) MINT No 1020670
090091 FIN/1P OGRRECTIONS 4:1441124111'=PAC ITV-m(13118013) MIND 50-039-20292-01
,
01,73.07 CAV(T1..h.OLV CO '108*(14I AG/PX-SET 05S5V 1 MC 33,T1144 R14E.1727 FEL 8 F5IF PI_
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02116437 JIGNPAG FILL PXN TWO***
ii
1 ;INTIM AFORE FERFS(10006418) 9PISeploratIoto(Plooka)
• •
BOP rig up—with utilization of safety joint/TIW stabbing valve during open hole deployment
,,...t.---------...— Platform Floor
Riser to platform floor
Annular
1
I 1
1
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lie I! ,IUII�! Blind/Shear
Hydraulically Actuated V lye t! � +��'. 11.�'
ili' ��,'1� Coil Pipe/Slip
+ 1
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.T_
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+ ��Itl �
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s.
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will
et% Master Valve
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....MIilIii*A.411I 'all Tubing Head
u= ,2 IN
Ground Level
STATE OF ALASKA
i• ALASKA OIL AND GAS CONSERVATION COMMOON
• • APPLICATION FOR SUNDRY APPROVALS
20 MC 25.280
1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0
Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0
Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Scab Liner m•
2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class:
5. Permit to Drill Number: 192-067 '
3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0.
99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20292-01-00 •
7. If perforating:
What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Num.-r
Will planned perforations require a spacing exception? Yes 0 No ® PBU 07-0 / `�' ECEIVED
9. Property Designation(Lease Number): 10. Field/Pools: J U L 3 i r 2 016
ADL 0028309 • PRUDHOE BAY,PRUDHOE t, J I
11. PRESENT WELL CONDITION SUMMARY AOGCC
Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): lugs(MD): Junk(MD):
9900 • 9213 • 9611 8995 9611 9749
Casing Length Size MD Burst Collapse
Structural
Conductor 80 20"91.5#H-40 37-117 it -117 1490 470
Surface 2691 13-3/8"72#N-80 39-2730 39-2730 4930
2670
Intermediate ,
Production See Attachment See Attachment See Attach See Attachment See Attachment See Attachment
Liner 2290 7"26#13Cr80 7622-9912•' 7479-9222 7240 5410
Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: / Tubing Grade: Tubing MD(ft):
/
See Attachment See Attachment 4-1/ .• Cr80 13Cr80 32-8721
Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment
4-1/2"RQ-DSSSV 2207, 2207
12.Attachments: Proposal Summary 0 Wellbore Sche• 0 13.Well Class after proposed work:
Detailed Operations Program a Stk..,-tch ❑ Exploratory ❑ Stratigraphic 0 Development 0• Service 0
14.Estimated Date for Commencing Operations: ' 15. Well Status after proposed work:
Oil El WINJ 0 WDSPL 0 Suspended 0
16.Verbal Approval: oat:.
(1,9 GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑
Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0
17.I hereby certify that the foregoing is true and t e' ocedure approved herein will not Contact Meixueiro,Pauling
be deviated from without prior written approv-I.
Email paulina.meixueiro@bp.com
Printed Name Meixueiro,Pauling Title Production Engineer-
Signature -r a....),.-9 JA.A.A.14 Phone +1 907 564 5971 Date - /12/140
COMMISSION USE ONLY
—.........0....."' n-
Conditions of approval:Notify Commis.ion so that a representative may witness Sundry Number:
Plug Integrity 0 :OP Test 0 Mechanical Integrity Test 0 Location Clearance 0
Other:
pp�� i i\ l r lir?,
Post Initial Injection MIT R:.'d? Yes 0 No ❑ oJ 3°'(1
Spacing Exception Requ'ed? Yes 0 No ISS Subsequent Form Required:
APPROVED BYTHE
Approved by: COMMISSIONER
ONER
COMMISSION .
Date.
ORIGINAL
de ZS%
Z52016
7 �
�DW AUG
Submit Form and
Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate
• •
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• •
1 Packers and SSV's Attachment 1
PBU 07-04A
SW Name Type MD TVD Depscription
07-04A SSSV 2207.3 2207.29 4-1/2" RQ-DSSSV
07-04A PACKER 7628.13 7485.11 7" Liner Top Packer
07-04A TBG PACKER 8663.2 8299.5 4-1/2" Otis MHR Packer
•
ALASKA WELL ACT•Y STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15)
General Information
Well Name: 07-04A Well Type: Natural Flow Producer
API Number: 50-029-20292-01 Well Activity Conventional 3
Classification:
Activity Description: Scab liner Cost Code/AFE: APBNRWOS
Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR,
bopd:
Job Type: Profile Modification Estimated Cost,
$K:
AWGRS Job Scope: SCAB LINER Other regulatory
requirements?
Sundry Form 10-403
Required? Yes
Sundry Form 10-404
Required? Yes Primary Secondary
Engineer: Pauling Meixueiro Contact numbers: (907)564-5971 (907)306-6173
Well Intervention Engineer: Eric Dickerman Contact numbers: (907)564-4306 (307)250-4013
Lead Engineer: Mark Vandegon Contact numbers: (907) 564-4049 (907) 748-1807
Date Created: June 9, 2016
Revisions (date,who,what changed):
Current Well Status Information
Water Rate or Gas Rate or
Oil Rate In Rate Gas Injection GOR FTP or Injection
I
Date Choke Setting Gas Lift Rate Pressure
(bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day)
Cut(%) (Mscf/Day) (psi)
5/27/2016 457 41.98 bwpd,
WC 8.42% 54,170 99,999 83 0 1,242
Current Status: Operable Shut In Inclination>700 at Depth(ft) N/A
Recent H2S (date,ppm) 4/10/2014 10 ppm Maximum Deviation(Angle and 48° 8,595' MD
Depth)
Datum depth,ft TVDss -8,800'TVDss Dogleg Severity(Angle and Depth) 7° 6,100' MD
Reservoir pressure(date,
psig) Estimated 3,270 psi Minimum ID and Depth 2.620" 2,195' MD
Reservoir Temp, F 207°F Shut-in Wellhead Pressure 2,390 psi
Known mech. integrity
problems(specifics) None
Last downhole operation (date,
operation) 10/8/2014 SL set DSSSV in sleeve at 2195'MD
Most recent TD tag(date,depth, SL w 3-3/8"x 10'dummy gun,TEL, sample bailer(no
toolstring OD) 9/9/2015 9,596' MD sample)
If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig
Surface Kit Fit-for-Service? YES If No,Why?
Surface Equipment Checklist.
Comments,well history, Slanted well drilled in 8/92 and completed in Z2.An IBP was set in 8/96 and seemed to have SI -500
background information, bowpd. In 9/03 an MCNL identified a lens -20' TVD thick in Z2C. Oil production started declining at a faster
etc: pace in 2007. By 8/08 the well was making -240 bopd, 6 mmscfd(25K GOR),so 10' of perforations were
added to access the lens in 10/08. This resulted in 730 bopd, 15 mmscfd(20K GOR). Gas rates steadily
increased since then. The 2013 RST shows the lens at less than 10'TVD thick. By 9/2014 the well reached
50 mmscfd and was experiencing downtime due to high GOR.A 10/14 PPROF was run in the 7"liner,
which suggests 53% of the gas coming from the Z2C lens. Low oil contribution is expected to be coming
from the top perf. The gas composition analysis also indicates the gas is lean.The plan is to set a scab liner
all the way to TD and then re-perforate the section with the highest stand off to gas with the intent of
lowering the GOR of this well and make it competitive again.
. Well Intervention Details •
Please contact the SOR author if
1.There is a change in work scope to the approved SOR
2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%.
Suspected Well Problem: HGOR
Specific Intervention or Well Objectives:
1 Run and cement scab liner.
2 Produce from 9595'-9610' and 9630`-9640' intervals
3
Key risks,critical issues: Mitigation plan:
1 No dedicated GL line to this well and might require GL for KO. Set live GLV's for PBGL if needed
2
3
Summary
Step# Service Line Activity
1 S Drift. Pull DSSSV. Pull IBP. Drift.
2 V Install BPV and test dart.
3 C/WWP Drift. Make up liner Deploy liner. Cement liner.
4 V A/CT- Pull test dart and BPV
5 F WOC 3 days_ Pressure test
6 S Drift. Set LGLV's as per GLE. Set DSSSV.
7 E Jewelry log. Re-perf.
Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR):
1 See following Word document for detailed procedure
2
3
Performance Expectations(may be NA if no change anticipated due to the intervention)
BOPD: 450 MMSCFD: 30 BWPD: 900
Expected Production Rates:
FTP(psi): 1000 Choke setting: 83 PI (bfpd/psi dp)
Post job POP instructions: Pop in HP DSO discretion to use PGBL for KO
Attachments-include in separate excel worksheets
Required attachments: Current wellbore schematic
As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead
info,etc
Approvals
Management Approval: Date:
Wells Approval: Date:
• •
07-04A
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TREE= 5"FMC 120
WELLHEAD= GRAYIII NOTES: Sl_VFRESCALE BULDUP@ GLMS#4
�
. VIDEO LOG os/OS/sfi"' CI-ROME E TBG&LNR
ACTUATOR= BAKER C 07-04A
'MALKB_Fl F 64'
BF ELEV= - -
KOP= 6200'
Max Angle= 48°@ 8595'
Datum MD= 9436 2195' 1-14-112"OTIS HRQ SV LN Nom,D=3.813'
Datum TVD= 8800'SS Q
2195' I-4-1/2"RD DSSSV,D=2.62"(10/08/14) I
[13-3/8'CSG,72#,N-80,D=12.34T H 2724' Ili,
GAS UFT MANDRH-S
MD TVD DEV TYPE VLV LATCH PORT DATE
3086 3086 1 TE-TGPD OMY FE 0 08/20/09
5620 5619 3 TE TGPD DMK RK 0 08/20/09
Minimum ID =2.62" @ 2195' LI6597 6575 22 TE TGPD DM' RK 0
4-1/2" RQ DSSSV 7446 7323 28 TE TGFD "DMY RIK 0 01/23/07
7562 7426 26 TE-TGR) DMY RK 0
TA TION#4-DM HAS EXTENDED PACKING
TOP OF T'LNR — 7600' 1
9-5/8"MLLOUT WINDOW (07-04A)7795'-7855'in
9-5/8"CSG,47#,N-80,I)=8.681" —f 7795' I
I TOP OF CEMENT H I 7800'
1
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44
004 8626' H4-1/2"O11S X NP,D=3.813" I
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......•1.11.1..1.4
r 4-1/2"TBG,12.6#,13CR-80,.0152 bpf,D=1958" H 8709'
IPERFORATION SUMMARY
REF LOG:BHCS ON 08/05/92 r
ANGLE AT TOP FERE:42 @ 9433' X 9611' BP(08/28/96)
Nate:Refer to F oduction DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz SHOT SOZ
3-3/8" 6 9425-9435 0 10/08/08
3-3/8" 1 9433-9435 0 02/15/95
irll
3-3/8" 3 9548-9550 0 03/02/93 9749' FISH-GLV
3-3/8" 4 9589-9594 0 03/02/93 I(05/01/93) I
3-3/8" 4 9594-9604 0 11/14/92 •
3-3/8" 4 9604-9610 0 10/19/92
3-3/8"I 4 9630-9644 C 08/17/92 ,
I PBTD I—f 9848' 140
`404414►
7"LNR,26#,13CR-80,.0383 bpf,D=6.276" I--, 9900' , ��
DATE REV BY COM4,9dTS DATE REV BY COMNBI'TS PRU HOE BAY UNIT
09/78 ORIGINAL COMPLETION 06/14/09 JPK/TLH GLV CORRE{-'TIONS(2/2007) WELL 07-04A
08/09/92 SIDETRACK COMPLETKIN 09/09/09 SVYC/TLH GLV CJO(08/20/09) PERMIT No:1920670
09/20/01 RN/TP CORRECTIONS 04/03/13 TRR'JMD TREE C/0(03/18/13) API No: 50-029-20292-01
01/23/07 DAV/TL H GLV C1O 10/08/14 JTG/PJC SET DSSSV SEC 33,T11N,R14E, 1723'FEL&756'FN.
02/15107 JGIWPAG FULL PXN TTP @ 8696'
10/13/08 RRDIPJC PERES(10/08/08) BP Exploration(Alaska)
s •
Loepp, Victoria T (DOA)
From: Loepp, Victoria T (DOA)
Sent: Monday,August 15, 2016 11:07 AM
To: Carlisle, Samantha 1 (DOA)
Subject: FW: PBU 07-04A(PTD 192-067); PBU 09-19(PTD 177-040)
Please handle.
From: Wages, David [rnaitto:David.Wages@bp.corn]
Sent: Monday, August 15, 2016 8:45 AM
To: Loepp, Victoria T(DOA)
Subject: RE: PBU 07-04A(PTD 192-067); PBU 09-19(PTD 177-040)
Sounds good to me!
Thanks,
David Wages
o. 907.564.5669
c. 713.380.9836
W I E-AK
From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov]
Sent: Thursday, August 11, 2016 10:27 AM
To: Wages, David
Subject: PBU 07-04A(PTD 192-067); PBU 09-19(PTD 177-040)
Dave,
Please confirm withdrawal of the following sundries since replacement sundries were submitted:
PBU 09-19 (PTD 177-040,Sundry 316-365)Scab Liner
PBU 07-04(PTD 192-067,Sundry 316-363)Scab Liner
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil&Gas Conservation Commission
333 W.7th Ave
Anchorage,AK 99501
Work: (907)793-1247
Victoria.Loepp(cilalaska.gov
CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation
Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged
information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended
recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to
you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov
1
,~ ~ STATE OF ALASKA
ALA OIL AND GAS CONSERVATION COM ION
REPORT OF SUNDRY WELL OPERATIONS
~~G~~
/v;~2?• oY
1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other
Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension
Change Approved Program ~ Operat. Shutdown ~ Perforate Q , Re-enter Suspended Well
2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number:
Name: Development ' Exploratory 192-0670
3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number:
Anchorage, AK 99519-6612 50-029-20292-01-00'
7. KB Elevation (ft): 9. Well Name and Number:
64 KB - PBU 07-04A
8. Property Designation: 10. Field/Pool(s):
ADLO-028309 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool
11. Present Well Condition Summary:
Total Depth measured 9900 ~ feet Plugs (measured) 9611
true vertical 9213.03 _ feet Junk (measured) 9749
Effective Depth measured 9848 feet
true vertical 9174 feet
Casing Length Size MD TVD Burst Collapse
Conductor 110 20" Surface - 110 Surface - 110
Surface 2660 13-3/8' 72# N-80 Surface - 2724 Surface - 2723 4930 2670
Production 7731 9-5/8" 47# N-80 Surface - 7795 Surface - 7640 6870 4760
7240 5410
Liner 2300 7" 26# 13-CR-80 7600 -
7
4
6
0 - 9213
9900
~~
(~''`~
ppp~~~yy ~; ~' pp
~a
;\
~^
Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _
True Vertical depth: _ _ _ _ _
Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 SURFACE - 8709'
0 0 -
Packers and SSSV (type and measured depth) 7"X4-1/2" OTIS PERM PKR 8651'
0 0
0 0
0
12. Stimulation or cement squeeze summary:
Intervals treated (measured): Ql, ~ ~ ~Q~~
- iJr~ti~y~~ ~+
~~D(i"iR11SSIQfi
iS~(8 alb t~t
~~ ~t3sia
~r
13
,
c
Treatment descriptions including volumes used and final pressure:
~f1C~'10[~7~E
13. Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure
Prior to well operation: 312 6327 192 635
Subsequent to operation: 693 14175 470 587
14. Attachments: 15. Well Class after proposed work:
Copies of Logs and Surveys Run Exploratory ~' Development ~" - Service "~''
Daily Report of Well Operations X 16. Well Status after proposed work:
Oil - Gas i"l, WAG GINJ WINJ WDSPL
17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt:
N/A
Contact Gary Preble
Printed Name Gary Preble Title Data Management Engineer
Signature Phone 564-4944 Gate 10/15/2008
Form 10-404 Rev' d 04/2006 1 ' ,r' ~ .k,,,, Submit Original Only «/G
07-04A
192-067
PERF ATTACHMENT
•
Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base
8/17/92 PER 9,630. 9,644. 9,009.09 9,019.58
10/19/92 PER 9,604. 9,610. 8,989.61 8,994.11
11/14/92 APF 9,594. 9,604. 8,982.13 8,989.61
3/2/93 APF 9,548. 9,550. 8,947.73 8,949.23
3/2/93 APF 9,589. 9,594. 8,978.39 8,982.13
2/15/95 APF 9,433. 9,435. 8,861.9 8,863.39
8/29/96 BPS 9,611. 9,848. 8,994.85 9,173.37
9/10/06 MIS 8,696. 9,611. 8,322.35 8,994.85
2/14/07 MIR 8,696. 9,611. 8,322.35 8,994.85
10/8/08 APF 9,425. 9,435. 8,855.93 8,863.39
AB ABANDONED PER PERF
APF ADD PERF RPF REPERF
BPP BRIDGE PLUG PULLE D SL SLOTTED LINER
BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED
FCO FILL CLEAN OUT SPS SAND PLUG SET
FIL FILL SQF SQUEEZE FAILED
MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE
MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED
MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN
OH OPEN HOLE
•
:]
07-04A
DESCRIPTION OF WORK COMPLETED
NRWO OPERATIONS
EVENT SUMMARY
ACTIVITYDATE SUMMARY
10/6/2008:"""WELL FLOWING ON ARRIVAL***
:INITIAL T/IA/OA: 650/1000/460. (JOB CANCELED E-LNE ADPERFS). ':
RIH WITH 3-3/8" GUN, MAX TOOL OD = 3.625", LENGTH = 24.5'.
:TAGGED TD AT 9588'. DID NOT PERFORATE WELL BECAUSE WELL
BORE WAS ALL GAS AND GUN CANNOT BE FIRED IN GAS.
'FINAL T/IA/OA: 2300/1000/460 PSI, DSO NOTIFIED OF VALVE
:POSITIONS. WELL LEFT SHUT-IN.
***JOB INCOMPLETE***
10/7/2008 T/I/0=1050/980%~~~ __. - _ ___, _..__ _.._ ~ ,_
580 Load Tbg (Pre E-Line) ***Job In Progress Continued On
WSR 10-08-08***
10/8/2008
****WELL SHUT-IN ON ARRIVAL**** (E-LINE ADPERFS). INITIAL T/IA/OA:
200/920/540
RIH W/ 10' GUN, GR/CCL, HEAD. PERFORATE 9425 - 9435 FT. 3 3/8" HSD
POWERJET 3406 API DATA38.6" ETRATON 0.45" ENTRANCE HOLE,
60 DEG PHASING, 6 SPF.
FINAL T/I/O = 460/900/550. MASTER OPEN, WING CLOSED, SSV OPEN,
VALVES OPEN TO GAUGES.
***JOB COMPLETE***
FLUIDS PUMPED
BBLS
1 diesel
1 Total
02/12/2007
Schlumberger
NO. 4131
Alaska Data & Consulting Services
2525 Gambell Street, Suite 400
Anchorage, AK 99503-2838
ATTN: Beth
108-0Co7
Company: State of Alaska
Alaska Oil & Gas Cons Comm
Attn: Christine Mahnken
333 West 7th Ave, Suite 100
Anchorage. AK 99501
Field: Prudhoe Bay
D
CI
CD
BL
Well Job# Log Description ate oor
L5-25 11538589 LDL 12128106 1
Y-16 11626467 LDL 01/19/07 1
L-04 11603118 MEM LDL 12130/06 1
11-24A 11638611 USIT 01124/07 1
1-33 11631645 USIT 01109107 1
A-05A 11533393 USIT 01104107 1
DS 05-10B 11626469 SCMT 01122107 1
W-29 11536193 USIT 01105107 1
R-15A 11626266 USIT (CEMENT EVALUATION) 01111107 1
R-15A 11626266 USIT (CORROSION) 01111107 1
MPF-99 11637306 CEMENT EVALUATIONICBL 01114107 1
R-12 11414757 RST 09101106 1 1
NK-38A 40011271 OH EDIT MWDILWD 03/11/05 3 1
NK-38A PB1 40011271 OH EDIT MWDILWD 02126/05 2 1
MPC·28A 11649937 MEM INJECTION PROFILE 01105107 1
DS 07-04A 11533394 LDL 01105107 1
F-23A 11626066 LDL 01108/07 1
P2-19 11630449 LDL 01/14/07 1
Y -09A 11630450 . LDL 01/16/07 1
PLEASE ACKNOWLEDGE RECEIPT BY SS~T~~r:tE 2ßn,?EACH TO:
BP Exploration (Alaska) Inc.
Petrotechnical Data Center LR2-1
900 E. Benson Blvd.
Anchorage, Alaska 99508
iVE
Alaska Data & Co
2525 Gambell Street,
Anchorage, AK 99503-2838
ATTN: Beth
FEB 2 0 Z007
Date Delivered:
Received by:
Oil &. Ga,~ Cons. CommissiQn
Ancl'!oo'lge
JC]
.
.
11/26/03
Schlumberger
NO. 3050
Alaska Data & Consulting Services Company: State of Alaska
3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-5711 Attn: Lisa Weepie
ATTN: Beth 333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Prudhoe Bay
Color (
Well Job # Log Description Date Blueline Prints CD
A-02 -::::¡. I-"()~ i 10674401 PSP LDL 11/24/03 1
D.S. 06-02 r~7'-(')-"f~ 10674399 PSP PROD PROFILE 11/22/03 1
D.S. 07 -04A ï '1;), '""Olo 1- 10687646 PRODUCTION PROFILE 09/19/03 1
J-06 " '""7 1- O~() 10563124 PRODUCTION PROFILE 11/10/03 1
16-21 . W)-;~ ¡ ~ 10563125 PROD PROFILEIDEFT 11/11/03 1
N-18 ~?J""C I ~ 10674395 SBHP SURVEY 11/03/03 1
C-24 1~ '-I i- 10703945 LDL 10/30/03 1
R-19A í cri--I-='- \ 10703949 SBHP SURVEY 11/03/03 1
D.S.15-01A 19~ "";~'-:\ 10703946 SBHP SURVEY 10/31/03 1
2-40/S-22 í C( L. '-It:=);:Q 10703952 PROD PROFILE/DEFT 11/21/03 1
NK-62A I~"~-Ol:..\ '-1- 10572999 MEM INJECTION PROFILE 05/30/03 1
D.S.15-20B -t-:lo...~-~( n 10669980 MEM PROD PROFILE 10/12/03 1
D.S.18-06A \ C(-=t ~"'I '1- 10715358 MEM PPROF & IPROF 10/30/03 1
I
" -
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO:
BP Exploration (Alaska) Inc. Schlumberger GeoQuest
Petrotechnical Data Center LR2-1 3940 Arctic Blvd, Suite 300
900 E. Benson Blvd.,..,,,,, /~. ::';~"", :\~ \ .¡r-t: :D" Anchorage, AK 99503-5711
, "u"" .~'" ,
Anchorage, Alaska 99508 {'J'" ¿, ? ~t í/ '.:1 ',....... . . ATTN: Beth
',':..L:r..."'WI ~¿\..~ :"'A""~
~.~' ~
Date Delivered: ;¡¡~:\: Z. 2. 2003 Received by: .,,\ ~ ;v--..... \~\.C ~~~"'(~
:<.; fj2.iS u:ms. vornmisSon
~\;\1f;~~~'f~(le
~C¡~lN~E~) JAN 2 @ 2004 . . ." '.'
11/18/03
Schlumberger
NO. 3045
Alaska Data & Consulting Services Company: State of Alaska
3940 Arctic Blvd, Suite 300 Alaska Oil & Gas Cons Comm
Anchorage, AK 99503-5711 Attn: Lisa Weepie
ATTN: Beth 333 West 7th Ave, Suite 100
Anchorage, AK 99501
Field: Prudhoe Bay
Color "
Well Job # Log Description Date Blueline Prints CD (
F-23A , q q - () -q. L 10558573 MCNL 09/07/03 1 1 I,::;. ?rJ(')
G-04A ) Ci P; - I I ¡",~-:J." 10563450 MCNL 06/05/03 1 1 l~r~r~.. \
7-14B .~ ()~ ~ i 1-\ o;..':i-- 10669982 MCNL - 10/15/03 1 1 IJ,~ .~~ d
A-06 ì''":::f ~ -CJ \ c;.Y 10568460 RST-SIGMA 06/27/03 1 1 119. -~\ -:.c
07-04A " q ëj. "'0 l n ~1- 10687646 RST-SIGMA 09/19/03 1 1 U;, ~~;:;( 1.\
05-04A Q t r, Yt'\,~ c¡ 10558553 MCNL 06/14/03 1 1 I~.~rç~9
. -
(
PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO:
BP Exploration (Alaska) Inc. Schlumberger GeoQuest
Petrotectnical Data Center LR2-1 3940 Arctic Blvd, Suite 300
900 E. Benson Blvd. S-d-C. E' I\I/ED Anchorage, AK 99503-5711
Anchorage, Alaska 99508 f"'1}"" ,. .. , A TIN: Beth
oJ -1. ~~
.... .... ,,=:.
Date Delivered: n~-:-r ?? IOO~ Received b~\ '}~ Y\.~(C (~~('.~
Þi811k~ Oil & Gas c;ons. U)mmi~$on
¡"~ldj¡)r~ge
~~#ì~~E['; JB~N 2 @ 2004
~~~IV\ ~
GeoQuest
500 w. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO.9296
Company:
3/2/95
Alaska Oil & Gas Cons Corem
Attn' Larry Grant
3001 Porcupine Drive
Anchorage, AK 99501
- -- Field: Prudhoe Bay
_ .
Floppy
,~. Well Job # .. .... Log Description Date BL RF Sepia Mylar Disk
,
D.S. 1-25~,~ LEAK DETECTION 021995 I 1
D.S. 4-1-'2~) 'TUBG PUNCHER RECORD 021 895 I 1
D.S. ~~k RESERVOIR SATURATION 0221 95 I 1
O.S. 4-19 PERF RECORD 021 7 9 5 I 1
D.S. 4-~3~'''~ PERF RECORD 021 995 I 1
D.S. 4-48````0 PERFRECORD 021 395 I 1
D.S. 6-3N~-~ PRODUCTION LOG 0221 951 I 1
D.S. 7-4A~,,~ PERF RECORD 021 595; I 1
D.S. 9-2,,~'~-,~ ~ INFLATABLE BRIDGE PLUG 021 795 I 1
D.S. 9-11'"'-,3 PERF RECORD 021895 I 1
D.S. 9-45 ~ ,PERFRECORD 022095 I 1
D.S. 13-20-'~-~ INFLATABLE BRIDGE PLUG 021 795 I 1
D.S. 11-4A~,~ PROD PROFILE 022095 I 1
D.S. 15-11-,~ _~ PRODPRORLE 022095 I 1
D.S. 18-1,~ ~ DUAL BURST TDT-P 021895 I 1
'D.S. 11-0~ 95058 DUAL BURST TDT-P 021195 1
D.S. 4-t-94~-q5 95057 DUAL BURSTTDT-P 020595 I
Please sign and return one copy of this transmittal to Sherrie at the above address.
RECEIVED
~E: ~ !995
Alaska 011 & Gas Cons. Commission
Thank you. Anchorage
GeoQuest
500 w. International Airport Road
Anchorage, AK 99518-1199
ATTN: Sherrie
NO. 9139
Company:
Alaska Oil & Gas Cons Comm
Attn' Larry Grant
3001 Porcupine Drive
Anchorage, AK 99501
12/30/94
Field: Prudhoe Bay
Floppy
Well Log Description BL RR Sepia RF Sepia Mylar Disk
.,~.S. 6-7 7_/~ O2--~ DUAL BURST TDT-P (7-13-94)
D.S. 6-8 "~. O-~-~-. DUAL BURST TDT-P (6-15-94)
D.S. 6-12A"-/~' -(~ F DUAL BURST TDT-P (5-29-93)
D.S. 6-13 ~d~ ~43~) DUAL BURST TDT-P (4-27-93)
D.S. 6-14A~ ~) ~" DUAL BURST TDT-P (5-7-93)
9.S. 6-14A 7/"' (~ ~ 7 DUAL BURST TDT-P (4-8-94)
D.S. 6-14A CNTD (2-14-93)
D.S. 6-22A C~ _63 -7 CNTD (5-22-94)
D.S. 7-4A ~/~- - ~3 (~'7 CNTD (5-21-94)
D.S. 7-17 ~--C>2-~ DUAL BURST TDT-P (8-5-94)
D.S. 7-18 ~' ~- - ~ CNTD (5-21-94)
D.S. 9-32 ~.~ C/ ~ ,, c/ CNT. D (5-10-93)
D.S. 9-32 ~' ~ L) "i J 0 DUAL BURST TDT-P (7-7-94)
D.S. 9-37i ~ c'/'d'J _ ~p-~ CNTG (8-27-94)
D.S. 9-37i ~ 0 [ '- O 7LJ DUAL BURST TDT-P (8-31-94)
'%S. 11-29i ~ ,,.)/j _.,,,.-,~ CNTG (5-31-94)
~).S. 11-29i // -~ -! ~ ~;J ~) 'Z---- DUAL BURST TDT-P (5-31-94)
D.S. 11-33 ~ ~//_~-(~ ~) DUAL BURST TDT-P (8-25-94)
D.S. 14-3 7 ~' - (5.~'~---- CNTD (3-28-94)
S I G N E D~~
Please sign and retrun one copy
DATE:
95
A/aska Oil & Gas Cons. Commission
Anchorage
Page 3
ARCO Alaska, Inc.
Date'
June 14, 1994
P.O. Box 100360,
...... ,chorage, AK 99510,d~~
Transmittal#: 94045 '~ ~'
Subject:
From/Location:
Telephone:
To/Location:
ARCO Cased Hole Finals
John E. DeGrey/ATO-1529
(907) 263-4310
Distribution
R C IV'ED
,JUN ~ ('~ ~994
0!! & Gas Cons. C0mrnission
Well i Log Date i Tool Type I Run,
Number! (M-D-Y) I [ Scale
Contractor j
1-10A i 06-02-94 ]/ USiT i 1,
5"
2-33 [ 05-22-94 J f CNL i 1, 5"
3-18A I 05-19-94 1, 5"
1, 5"
3-27 i05-24-94
[ 05-26-94
4-07ST ~
4-1 lA 06-04-94
4-19 05-25-94
4-46 06-04-94
5-3A i06-02-94
6-3 j06-03-94
6-10 i05-22-94
6-16 ~06-05-94
6-22A !05-22-94
7-4A 05-21-94
7-6 05-21-94
7-7A i 05-20-94
7-18 ! 05-21-94
.
7-23 [ 05-24-94
7-26 i 05-21-94
7-28 i05-26-94
9-13 !05-25-94
9-44 !05-20-94
9-50 i 05-20-94
11-291 i 05-31-94
11-291 i 05-30-94
11-291 i 05-31-94
11-291 i05-30-94
11-35 f05-31-94
11-35 i05-31-94
11-36 f05-23-94
14-3 ! 06-03-94
14-12 j05-28-94
14-12 i05-28-94
14-20 !06-01-94
14-34 i06-01-94
16-13 ! 05-24-94
17-12 I 06-05-94
17-19 i 05-26-94
18-1 J 06-04-94
18-1 i 06-04-94
COL
!,,.--' PERF REC
1' INJ PROFILE
]/ USiT
?Production Profile!
1/ CCL
i/ PERF REC
~P~atch Settin9 Reci
YTub~in9 Puncher!
/ CNL
'~ CNL
~roduction Profile i
'/ Pref Rec
-- CNL
! 5II
SCH
1, 5" SCH
SCH
1 et'
1,1"5"
1 5"
1 5"
1 5"
1 5"
1 5"
1 5"
1 5"
1 5"
COL i 1, 1"5"
Prod Profile f 1, 5"
v/' Perf Rec i 1, 5"
· " Bridge Plug
1~ 5tl
','Production Profile i 1, 5"
.Production Profile j 1, 1" 5"
/ CNL i 1, 5"
.- USIT ! 1, 5"
/" TDT-¢ i 1,5II
i/ CBT f 1, 5"
'/ USlT I 1, 5"
--" CBT i 1, 5"
/ CBT ! 1 5"
,-" PERF REC
f GR LOG
"Production Profile
ly' PERFREC
PERF REC
"Baker IBP Rec
1-' Leak Detection
1 5"
1 5"
1 5"
1 5"
1 5"
1 5"
1, 1" 2" 5"
i / PERFREC ! 1, 5"
k' Pack Off Gas Lift
t/Tubing Puncher
511
! 5II
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
,,
SOH
SCH
SCH
¢
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
SCH
ARCO AlasKa, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany
ARCO ,~-lnskn, Inc.
P.O.Box 100360
Anchorage, Alaska 99510
DATE: 5-6-93
REFERENCE:
~' */1-24A 2-7-93
~.~/~3-20 4-6-93
~~2~2001 4-1S-93
4-28-G3
0A 4-28-93
5A 4-23-93
-~o 77~ ~ ~-~.,a
-~ ~ ~F 4-so-~s
~-31A ~-r~ 4-16-03
**~2-148T ~/~/~4-27-93
-~13-25 C2-~/ 12-26-93
~6-27 ~. ~i ~2-27-92
~7-~S ~'~2~ 4-~S-~3
Please sign and
ARCO CASED HOLE FINALS
GR/CCL/Jewelry/Temp Run 1,
Tubing Cutter Run 1,
[IBT/GR/CCL Run 1,
Perf Record Run 1.
Jewelry/GR/CCL Tie-In Run 1,
CNL/GR Color Run 1,
U[IlT/GR Color Run 1, [~'
Leak Detect Run 1,
[itatic Press/Temp Run 1,
Leak Detect Run 1. :~'&5"
Prod Profile Run 1,
Production Log Run 1,
Pressure Build-Up Run 1,.
Press/Temp Run 1,
Perf Record Run 1.
Produotion Log Run 1, l"&5"
Dual Burst TDTP (Borax) Run 1.
Perf Record Run 1,
PFC/GR (Packer Set) Run 1,
lnJ Profile Run 1,
Leak Detect Run 1.
Leak Detect Run 1.
Leak Detect Run 1.
InJ Profile Run 1,
Prod Profile Run 1,
Prod Profile Run 1,
Leak Detect Run 1, 2~'&5''
[IBT/GR/CCL Run 1, 2'&5"
RECEIVED B'
Have A Nice
SonFa Wallace
~ ATO-1529
Camco
Atlas
Atlas
[ich
[ich
[ich
[ich
Camco
[ich
[ich
Camco
Sch
[ich
[ich
[ich
[ich
[ich
Atlas
Camco
Camco
[ich
[ich
Camco
Camco
Camco
$ch
Atlas
# CENTRAL FILES
# CHEVRON
# CLINT CHAPMAN
# EXXON
# MOBIL
as rect4J)~ of data.
# 93056/
#
PB WELL FH, ES.
# BPX
# STATE OF ALAS~
The Correct well n~_me for this log is 1-24A.
The correct APl# for 3-20A is 50-029,20980~1.
The correct l~I# for 12-14ST is 50~2c~206594)0.
ARCO Alaska, Inc.
P.O.Box 100360
Anchorage, Alaska 99510
RECEIVED
DATE: AP~ ] ~ ]$~
m~_,.-~ .REFERENCE: ARCO CASED HOLE FINALS '.,Alaska Oil & Gas Cons, Cot~lllsalOl~
~ ~' ~,~~(fl- 11 1-24-93 Perf Record A~r~, HIS
__ kl-11 2-7-93 Peri Record Run 1, I~' HIS
77,.~~=~1-13 2-7-93 Peri Record Run 1. ~' HIS
~~-1-24A 2-20-93 Peri Record Run 1.5" HIS
~'-L--~/o~1-30 1-24-93 Peri Record Run 1. I~' HLS
~[~-- 2-14 7-27-91 TMD Run 1.5" HIS
-/c]~ 37~'- 3-9 12-19-92 Peri Record Run 1, I~' HIS
~ ~-.~7j_~.3-24 1-25-93 Peri Record Run 1, 5" HIS
~?q_ '3-32 4-25-92 PGST Computed Results Run 1, I~' HIS
~3-32 4-25-92 PSGT Run 1.5" HIS
. 3-32 2-19-93 Peri Record Run 1. HIS
--~:~'--3-34A 2-19-93 Peri Record Run 1. ~' HIS
c]l~ ~_ ~ .4-35 8-16-92 TMD Run 1. ~' HLS
8-18-92 TMD Boron Injection Run 1. I~' HLS
-4A 2-22-93 Peri Record Run 1.5" HLS
3-2-93 Peri Record Run 1, ~' HIS
-27 .: 3-1-92 PSGT Computed Results Run 1, ~' HLS
3-1-92 5 Run 1.
"'-'"-- ~9-27 3-1-92 PSGT 10 Ft/Mln Run 1, li~' HIS
e]_Z~ _/9-51 2-6-93 Peri Record Run 1. ~' HIS
--'~-51 2-8-93 Peri Record Run 1.5" HIS
mp
1-1 4-21-92 PSGT Run 1.5" HLS
1-13A 3-8-93 Peri Record Run 1. ~' HIS
~_~~1-18 4-14-92 PSGT Coml~uted Results Run 1.5" HLS
1-18 4-14-92 PSGT Run 1. ~' HLS
~/~ I~\T~~] ---12-4A 2-11-93 Peri Record Run 1, 5" HIS
~\ct%---~12-19 2-11-93 Peri Record Run 1, 1~' HIS
St~.- ~9--~ 12-29 12-22-92 Peri Record Run 1. ~' HIS
~ .~ |~ ..~12-32 12-26-92 Peri Record Run 1. ~' HIS
~,/14-5A 2-20-93 Peri Record Run 1.5" HLS
c~.~w., ~-14-12 4-24-92 PSGT Computed Results Run 1.5" HLS
~4-12 4-24-92 PSGT Run 1. ~' HLS
_ 4-37 4-13-92 PSGT Computed Results Run 1. I~' HLS
4-37 4-13-92 PSGT Run 1, 5' HIS
6-21 7-23-92 PSGT Run 1. ~' HLS
_~16-27 8-23-92 Peri Record Run 1. ~' HIS
_c/~7(o ~16-30 2-12-93 Peri Record Run 1, 5" HIS
~[~~17-21 12-20-92 Peri Record Run 1, ~' HLS
_,.~..
Please sign and return the attached copy as receipt of data.
RECEIYED BI' ....... . . .
APPROVED
Sonya Wallace
AT0-1529 Trans# 930
# CENTRAL FILES
# CHEVRON
# LUCILLE JOHNSTON
# EXXON
PHILLIPS
MOBIL
BPX
STATE OF ALASKA
* The correct api# for 3-32 is 50-029-21141-00.
~.--,., STATE OF ALASKA
ALASKA ,..AND GAS CONSERVATION CC VllSSION
REPORT OF SUNDRY WELL OPERATIONS
1. Operations performed:
Operation shutdown Stimulate Plugging Perforate X
Pull tubing Alter casing Repair well Other
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P.O. Box 100360, Anchorage, AK 99510-0360
4. Location of well at surface
1685' SNL,68' WEL, SEC. 33, T11N, R14E, UM
At top of productive interval
1171' SNL, 1322' WEL, SEC. 33, T11N, R14E, UM
At effective depth
At total depth
756' SNL, 1727' WEL, SEC.33, T11N, R14E, UM
5. Type of Well
Development
Exploratory
Stratigraphic
Service
MAR 0
^taska 0il & Sas Cons.
Anchorage
6. Datum of elevation(DF or KB)
64 RKB feet
7. Unit or Property
Prudhoe Bay Unit
8. Well number
7-4A
9. Permit number/approval number
92-67
~10. APl number
50 - 029-20292-01
11. Field/Pool
Prudhoe Bay Oil Pool
12. Present well condition summary
Total depth: measured
true vertical
9900 feet
9214 feet
Plugs(measured)
Effective depth: measured 9848 feet
true vertical 9174 feet Junk(measured)
Casing Length Size Cemented Measured depth
Conductor 110' 20" 450 cuft Poleset 110'
Surface 2660' 13 3/8 6050 cu ft Arcticset 11 2724
Production 7731' 9 5/8" 1450 sx CL "G" & 300 sx AS1 7795'
Liner 2300' 7" 449 cuft Class "G" 9900'
True verticaldepth
110'
2723'
764O'
9214'
Perforation depth: measured 9548-9550, 9589-9594, 9594-9604, 9604-9610, 9630-9644
true vertical 8949-8950, 8979-8983, 8983-8991,8991-8995, 9010-9021
Tubing (size, grade, and measured depth) 4 1/2", 13CR80, 12.6#, to 8709' MD
Packers and SSSV (type and measured depth) Otis MHR Packer @ 8651, Otis HRQ SSSV Nipple @ 2195' MD
13. stimulation or cement squeeze summary
Intervals treated(measured)
Treatment description including volumes used and final pressure
14.
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Injection Data
Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure
186 242 434 1482
2371/- 1752 "- 798 1646
Tubing Pressure
229
240
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 fore,~g is true and correct to the best of my knowledge.
Signed ~ (~.L ~,,,~'~~ ~ Title Senior Engineer
Form 10-404 Rev 06/15/88 /J
c.c' R Wallace/DS Enr~r/J. W. Peirce
Date
SUBMIT IN DUPLICATE
DS 7-4A
SADLEROCHIT ADPERFORATION PROCEDURE
REPORT OF WELL OPERATIONS
PROCEDURE:
WORK PERFORMED:
·
,
.
03-02-93
RIG UP E/L AND TEST LUBRICATOR.
RIH WITH PERFORATING GUNS AND TIE IN TO REFERENCE LOGS (BHCS 8/5/92).
ADPERFORATE SADLEROCHIT INTERVAL 9548-9550 MD AT 2 SPF AND 9589-
9594 TO ATTAIN 4 SPF WITH RUNS AS REQUIRED(REF LOG BHCS 8/5/92).
POOH.
4. RD AND RELEASE E/L.
5. RETURN WELL TO PRODUCTION STATUS.
Alaska 0ii & G~s Cons.
'Ar~chorage
ARC() Al a~k a~ Inc. is a Subsidis~ of AtlanticRichfleklCompany
ARCO p.l.~tr., Inc.
P.O.Bax 100360
Anchorage, Alaska 99~10
DATE: 3-22-93
REFERENCE: ARCO CASED HOLE FINALS
.._~~--A-30
.-11
-11
· o. is
-32
-14A
-6
2-10&
~--~ J4-22
' ' ' 4-22A
q~4-43
~6-28
- · ~** ~ 6-29A
~6-30
1-31-93 Perf Record
1-4-93 Pert Record
1-10-93 Peri Record
1-11-93 Peri Record
11-12-92 Peri Record
11-8-92 Perf Record
11-28-92 Peri Record
1-29-93 Perf Record
11-15-92 Peri Record
11-19-92 Peri Record
11-6-92 Perf Record
11-27-92 Perf Record
11-18-92 Peri Record
1-2-93 Peri Record
1-1-93 Peri Record
2-1-93 Peri Record
1-9-93 Peri Record
11-18-92 Peri Record
11-15-92 Peri Record
1-3-93 DSN
1-8-93 Peri Record
11-2-92 Collar (Inflatable Packer]
11-16-92 Collar [To spot Jet cutter]
1-8-93 Peri Record
11-14-92 Perf Record
12-2-92 Peri Record
11-20-92 Peri Record
12-31-02 Peri Record
11-20-02 Peri Record
1-5-03 Perf Record
11-17-92 Peri Record
Please sign and return the attached copy as receipt of data.
Have A Nice Dayf
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Sonya Wallace
ATO-1529
HIS
HIS
HIS
HIS
HIS
HIS
HIS
HIS
HIS
HIS
HIS
HIS
HIS
HL8
HIS
HL8
HIS
HL8
HIS
HL8
HIS
HIS
HIS
HL8
HIS
HIS
HLS
HIS
HIS
HIS
HIS
,ECEIVED
# PH]LUPS
I~B ~ FRES
#BPX
# STATE OF ~
These logs were mn in 1993 not 1992.
The correct API# for 4-14A is 504Y29-20310-00.
The correct APl# for 1~29A is 504Y29-22272-01.
Oil & Gas Cons. Commission
Anctmrago
ARCO Alaslu~ Inc.
P.O.Box 100360
Anchorage, Alaska 99510
DATE: 7-7-93
REFERENCE: ARCO CASED HOLE FINAL~
~~ 10-12-92 Perf Record R~m 1, 5"
7 ~- ~J3-25 8-15-92 Perf Record R~m 1, 5"
8-15-92 Perf Record R~_m 1, 5"
9-19-92 Perf Record R!m 1, 5"
5-2-92 GR/Temp Log Ru~ 1, 5"
~ 10-17-92 Perf Record Run 1, 5"
~ -J~7~T~- 8-21-92 Perf Record Run 1, 5"
~I~/~_~_~T 8-22-92 Perf Record Run 1, 5"
~ 14-~_19ST 6-23-92 GR/Perf Record R~m 1, 5"
¥~15 10-19-92 Perf Record Run 1, 5"
8-11-92 Perf Record R~m 1, 5"
10-16-92 Perf Record Run 1, 5"
Please sign and retu~~attache~l Fopy as receipt of data.
RECEIVED
Sonya Wallace ~[~ ~Ii) APPROVED
ATO- 1529 ~ ~
~:~ 0 ~ ~ Trans# 93005
# CHEVRON PB WELL FILES
D&M R&D
# EXTENSION EXPLORATION # BPX
# EXXON # STATE OF ALAS~
MARATHON TEXACO
# MOBIL
* The correct API# for 3-34A is 50-029-21132-01.
** The correct API# for 7-4A is 50-029-20292-01.
~ STATE Of ALASKA , ,~ ~
ALASKA ~. AND GAS CONSERVATION C(--~ '/IISSION ~G '~'~
REPORT OF SUNDRY WELL OPE. ATIONS
Operations performed:
operation shutdown .... Stimulate Plugging Perforate X
Pull tubing Alter casing Repair well Other
,,
2. Name of Operator
ARCO Alaska, Inc.
3. Address
P.O. Box 100360, Anchorage, AK 99510-0360
,~. Location of well at surface
1685' SNL,68' WEL, SEC. 33, T11 N, R14E, UM
At top of productive interval
1171' SNL, 1322' WEL, SEC. 33, T11N, R14E, UM
At effective depth
At total depth
756' SNL, 1727' WEL, SEC.33, T11N, R14E, UM
5. Type of Well
Development
Exploratory
Stratigraphic
Service
6. Datum of elevation(DF or KB)
64 RKB
7. Unit or Property
Prudhoe Bay Unit
8. Well number
7-4A
9. Permit number/approval number
92-67
10. APl number
50 - 029-20292-01
11. Field/Pool
Prudhoe Bay Oil Pool
feet
12. Present well condition summary
Total depth: measured
true vertical
9900 feet Plugs(measured)
9214 feet
Effective depth: measured 9848 feet
true vertical 9174 feet Junk(measured)
Casing Length Size Cemented
Conductor 110° 20" 450 cu ft Poleset
Surface 2660' 13 3/8 6050 cu ft Arcticset 11
Production 7731' 9 5/8" 1450 sx CL "G" & 300 sx AS1
Liner 2300' 7" 449 cu ft Class "G"
Perforation depth: measured 9594-9604, 9604-9610, 9630-9644
true vertical 8986-8994,8994-8998, 9010-9023
Tubing (size, grade, and measured depth) 4 1/2", 13CR80, 12.64t, to 8709' MD
Measured depth
110'
2724
7795'
9900'
True vertical depth
110'
2723'
7640'
9214'
RECEIVED
DEC - ~J ~o,~
AJaska Oil & Gas Coils, Cor.m.fdssio~
Anchorage
Packers and SSSV (type and measured depth) Otis MHR Packer @ 8651, Otis HRQ SSSV Nipple @ 2195' MD
13. Stimulation or cement squeeze summary
Intervals treated(measured)
Treatment description including volumes used and final pressure
14.
Prior to well operation
Subsequent to operation
Representative Daily Average Production or Injection Data
OiI-Bbl Gas-Md Water-Bbl Casing Pressure
28 3218 922 1350
186 2570 434 1482
Tubing Pressure
215
229
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.
Signed ~ ~. ~Title Senior Engineer
Form 10-404 Rev 06/15/88 /~
cc: S. Wallace/DS Enar/J. W. Peirce
Date /.,?-/"/*/~ Z-.-
SUBMIT IN DUPLICATE
DS 7-4A
SADLEROCHIT REPERFORATION PROCEDURE
REPORT OF WELL OPERATIONS
pROCEDURE:
WORK PERFORMED:
I ,
.
.
.
.
1 0/1 8/92
RIG UP E/L AND TEST LUBRICATOR.
RIH WITH PERFORATING GUNS AND TIE IN TO REFERENCE LOGS (BHCS 8/5/92).
ADPERFORATE SADLEROCHIT INTERVAL 9604'-9610 MD (BHCS 8/5/92) TO
ATTAIN 4 SPF WITH RUNS AS REQUIRED. POOH.
RD AND RELEASE E/L.
RETURN WELL TO PRODUCTION STATUS.
WORK PERFORMED:
.
.
.
.
.
1 1/1 5/92
RIG UP E/L AND TEST LUBRICATOR.
RIH WITH PERFORATING GUNS AND TIE IN TO REFERENCE LOGS (BHCS 8/5/92).
ADPERFORATE SADLEROCHIT INTERVAL 9594'-9604 MD (BHCS 8/5/92) TO
ATTAIN 4 SPF WITH RUNS AS REQUIRED. POOH.
RD AND RELEASE E/L.
RETURN WELL TO PRODUCTION STATUS.
Oil & Gas Cons.
,. nuhoraqe
ARCO Ahsk~ Inc.
P. O2~ox 100360
Anchorage, Alaska 99510
DATE: 10-16-92
REFERENCE: ARCO MAGNETIC TAPE(S] WITH LISTINGS
~/~ '7-4A f_~'"~, 10-8-92 ~ {_~BCS/~/D~ Run I Job/~2484
~' ~/~'~ 16-30 ~- ? ~ ~ ~ ~ BCS/DTE l~m 1 J~3
Please sign and return tl~e attached copy as receipt of dat~
Have A Nice Dayi
Sonya Wallace APPROVED_~_.
ATO-1529 Trans# 9223~~'- .....
CENTR~L FILES (CH)
CHEVRON
D&M
# BOB OCANAS (OH/GC)
# EXXON
MARATHON
MOBIL
# PHILLiI~
PB WELL FILES
R&D
# BPX
# STATE OF ALASKA
TEXACO
RECEIVED
NOV 2 3 1992
Alaska 0ii & Gas Cons. Commission
Anchorage
ARCO .~I,skA; Inc.
P.O.Box 100360
Anchorage, Alaslm 99510
DATE: 10-9-92
REFERENCE: ARCO DIRECTIONAL DATA
11-78T ~, 8-4-2
15-30 ~'~'?~' 9-2-02
15-31 fZ-~ 9-37-92
16-31 ~-7~ 8-11-02
17-16 ~2"~/ 9-30-92
Magnetic Multi-Shot Survey Job#AK-EI-20056
MWD Directional Survey Job#NA
Mwd Directional Survey Job#AKMM920821
MWD Directional Survey Job#AK-MW-20075
MWD Directional Survey Job#lll7
MWD Directional Survey Job#NA
Finder Survey Job#45FG0992027
Please sign and return the attached copy as receipt of data.
RECEIVED BY~_~..L-
Have A Nice Dayi
Sonya Wallace
ATO-1529
APPROVED -~J~___
Trans# 92230
8perry
8ch
8perry
8perry
Teleco
Teleco
8DII
CENTRAL FILES
CHEVRON
D&M
# EXTENSION EXPLORATION
# EXXON
M~THON
MOBIL
# PB WELL FLS ' : "' ~:
R&D
# BI~X
# ST. OF ~.K__ (2 cOPIES)
RECEIVED
NOV ,1 ? 1992.
Alaska 0il a ~as Cons. Commission
;\ncbora~e
ARCO Alaska, Inc.
P.O.Box 100360
Anchorage, Alaska 99510
DATE: 10-16-92
REFERENCE:
ARCO OPEN HOLE FINALS
14-41 10-1092
14-41 10-10-92
14-41 10-1092
t 17-16 9-30-92
17-1617-16 9-30-92 9-30-92
17-16 9-30-92
/,19-1~
DLLfMSFL/GR '/ Corrected' Run 1, 2"&5" Sch
SSTVD ~ Rrm 1, l"&2' Atlas
4-Arm Calipe/r/GR -~(~.re,'t./,:/~/- ..,,,... 1, [~' Atlas
FMT/GR ./ Run 1, 2~'&i~' Atlas
SSTVD -/ Color Run 1, 1"&2' Sch
PISFL Color.~ Run 1, 2"&i~' Sch
Litho-Density / Color / Rrm 1, :~'&i~' Sch
Array Sonio Full Waveforms'Color Run 1, :~'&i~' Sch
LWD: CDN ~/ Runs 1-5, 2"&t~' Sch
LWD: CDN Density/GR j l~ns 1-5, ~'&t~' Sch
LWD: CDN Neutron/GR ~/ Runs 1-5, 2"&[~' Sch
LWD: CDN Near-F~r Overlay~RmlS 1-5, l~'&~' Sch
LWD~ CDN TVD ,/Runs 1-5, 2"&~' Sch
LWD~Density/GR TVD ,/Runs 1-5, 2"&i~' Sch
LWI~Neautron/GR TVD -/Runs 1-5, :~'Sd~' Sch
Please sign and return the attached c,opy as receipt of data.
EC IVEI
Have A Nice Day! ___ / ~~~_
Sonya Wallace APPROVED
ATO-1529 Trans# 9223~~'' ......
# CENTRAL FILES
# CHEVRON
#D&M
# EXTENSION EXPLORATION
# EXXON
MARATHON
# MOBIL
# PtHLLIPS
# PB WELL FH, ES :'
R&D
# BPX
# STATE OF ALASKA
# TEXACO
RECEIVED
NOV 09 1992
Alaska Oil & Gas Cons. Commission
Anchorage
STATE OF ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
WELL COMPLETION OR RECOMP LETION REPORT AND LOG
1. S~tatus of Well Classification of Service Well
OIL ~ GAS I-I ~ [] ABANDONED [] SERVICE []
2. Name of Operator 7. Permit Number
ARCO Alaska, Inc. 92-67
3. Address B. APl Number
P. O. Box 196612, Anchorage, Alaska 99519-6612 $0- 029-20292-01
4. Location of well at surface 9. Unit or Lease Name
1685'SNL, 68' WEL, SEC. 33, T11N, R14E, UM ~ .... . L ..~^ TtONS J Prudhoe Bay Unit
~ :":=': :: :' ............. '~ V'E~.~.E~ I 10. Well Number
At Top Producing Interval ~ bOt~'?~:'LETiOi~ I ~
1171'SNL, 1322' WEL, SEC. 33, T11N, R14E, UM ~ ~:~'~:: ~ i., r DS 7-4A
At Total Depth~ ~/J~,'Fm~) ~ Prudhoe Bay Field/Prudhoo Bay Pool
756' SNL, 1727' WEL, SEC. 33, T11N, R14E, uM ~ ~.-~, ~-- ~
!5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No.
KBE = 64' i ADL 28309
12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. J15. Water Depth, if offshore J16. No. of Completions
7/31/92 8/6/92 8/17/92I N/A feet MSL J One
17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD] 19. Directional Survey ~20. Depth where SSSV set ~21. Thickness of Permafrost
9900'MD/9214' TVD 9848'MD/9174' TVD YES [] NO []! 2195'feet MD J' 1900'(Approx.)
22. Type Electric or Other Logs Run
MHFL/DLL/GR/BHCS/CNL
23. CASING, LINER AND CEMENTING RECORD
SETTI~IG DEPTH MD
CASING SIZE WT'. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED
20" Cond. H-40 Surface 110' 30" 450 cufl Poleset
13-3/8" 72# N-80 Surface 2724' 16" 6050 cufl AS II
9-5/8" 47# N-80 Surface 7800' 12-1/4" 1450 sx "G" & 300 sx AS I
7" 26# 13CR80 7600' 9900' 8-1/2" 449 cufl Class "G"
24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD
interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI
Gun Diameter3-3/8" 4 spf 4-1/2", 13CR80 8709' 8652'
MD TVD
9630'-9644' 9010'-9023' 26. ACID, FRACTURE, CEMENT SQUEF_ZF_~ ETC.
DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED
27. PRODUC'rlON TEST
Date First Production JMethod of Operation (Flowing, gas lift, etc.)
8/19/92 I Gas Lift
Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE ]GAS-OIL RATIO
TEST PERIOD I~
I
Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr)
Press. 24-HOUR RATE I~
28. CORE DATA
Brief description of lithology, porosity, tractures, apparent dips, and presence of oil, gas or water. Submit core chips.
RECEIVED
N OV -
AJ~ska 0il & Gas Cons. 6or~['~jssJop
~r~ohora~jo
,,
Form 10-407
Rev. 7-1-80
CONTINUED ON REVERSE SIDE
Submil in duplicate
29. 30.
GEOLOGIC MARKERS FORMATION TESTS
NAME Include inlerval tested, pressure data, all fluids recovered and gravity,
MEAS. DEP']3-1 TRUE VERT. DEPTH GOR, and time of each phase.
Sag River 8903' 8471'
Shublik 8945' 8501'
Top Sadlerochit 9027' 8562'
Base Sadlerochit 9810' 9145'
31. LIST OF ATTACHMENTS
32. I hereby certify that the foregoing is true and correct to the best of my knowledge
Signed Title Drilling Engineer Suoervisor 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. ~ E ~ E IV ~ D
Item 28: If no cores taken, indicate "none".
Form 10-407
NOV - 5
Alaska Oil & Gas Cons. Commission
Anchorage
BP/AAI SHARED SERVICE
DAILY OPERATIONS
PAGE: 1
WELL: 7-4A
BOROUGH: NORTH SLOPE
UNIT: PRUDHOE BAY
FIELD: PRUDHOE BAY
LEASE:
API: 50-029-20292
PERMIT:
APPROVAL:
ACCEPT: 07/24/92 12:07
SPUD:
RELEASE: 08/09/92 01:08
OPERATION:
DRLG RIG: DOYON 16
WO/C RIG: DOYON 16
07/24/92 ( 1)
TD:12013
PB: 9463
MOVING RIG TO DS 7 MW: 8.5 Seawater
MOVE RIG OFF DS 12, INSTALL NEW WHEEL ADDITION, MOVING DOWN
OXBOW ROAD TO DS 7 @ REPORT TIME
07/25/92 (2)
TD:12013
PB: 9463
07/26/92 (3)
TD:12013
PB: 9463
07/27/92 ( 4)
TD:12013
PB: 9463
07/28/92 (5)
TD:12013
PB: 9463
POH W/3-1/2" TBG MW: 8.5 Seawater
MOVE RIG F/ DS12 TO DS 7, SPOT OVER WELL 7-4, RIG UP ON
TREE TO CIRC UNTIL WELL STABLE, N/D TREE & ADAPTOR FLANGE,
N/U BOPE, INSTALL PIPE RAMS, TEST BOPE, PULL TBG FREE, POH
L/D TBG, WELL TAKING FLUID @ 120 BPH
P/U 5" DP, RIH W/ PRT MW: 8.5 Seawater
SAFETY MEETING ON PLG TBG, PULL & L/D 3-1/2" TBG, FOUND
COLLAPSED GLM @ STATION 2, CHG RAMS TO 3-1/2" TO 4-1/2",
TEST BOPE, PULL TEST PLUG, M/U BAKER PRT, RIH W/ PRT.
POH TO PU 4" SPEAR MW: 8.5 Seawater
RIH W/PRT, LATCH INTO TOP OF PBR W/PRT @ 8784', SHEARED PRT
WILL NOT LATCH BACK INTO TOP OF PBR, CBU, CONFIRM TBG PATCH
IN 9-5/8" HB PKR, POH, L/D PRT, R/U W/L, RIH W/GS TOOL,
LATCH INTO PKR @ 8774', JAR PKR FREE, POH, L/D PKR, R/D
CAMCO R/U ATLAS, RIH W/JET CUTTER, LOCATE CUTTER TO FIRE @
9076', CUTTER DID NOT FIRE, POH TOP OF CUTTER MALFUNCTIONED,
M/U NEW CUTTER, RIH, FIRE CUTTER @ 9076', POH R/D ATLAS,
M/U NEW BAKER PRT, RIH TO TOP OF PBR, @ 8782', LATCH INTO
PBR 2 8784', ATTEMPT TO RELEASE PKR, TOOL SHEARED @ 290K,
WILL NOT LATCH BACK INTO PBR, CBU, POH TO PU 4" TRI-STATE
SPEAR
CIRC., WOC MW: 8.5 Seawater
SAFETY MEETING, POH, L/D BAKER PRT, RIH W/TRI-STATE SPEAR,
SPEAR INTO PKR @ 8784', CBU, WELL STABLE, POH RECOVERED
FISH, L/D PKR, M/U MULE SHOE, RIH W/5" DP TO 9094', CIRC,
TEST LINES TO 3000 PSI, MIX & PUMP 45 BBLS CMT', POH 12
STDS, APPLY SQZ PRESSURE TO 2500 PSI, LOST 500 PSI, SQZ 6
BBLS AWAY TO OPEN PERFS @ HOLE IN CSG @ 8855', CIRC, WOC
NOV- 5 9,92
Anchorage
WELL : 7-4A
OPERATION:
RIG : DOYON 16
PAGE: 2
07/29/92 ( 6)
TD:12013
PB: 9463
07/30/92 (7)
TD:12013
PB: 9463
07/31/92 (8)
TD:12013
PB: 8030
08/01/92 (9)
TD: 8303'( 0)
08/02/92 (10)
TD: 8895' ( 592)
08/03/92 (11)
TD: 9009' ( 114)
08/04/92 (12)
TD: 9460' ( 451)
08/05/92 (13)
TD: 9897' ( 437)
MAKING CUTOUT/9-5/8" @ 7795' MW: 8.5 Seawater
WOC, HOLD SAFETY MEETING, RIH TO 8528', WASH F/8528'-8810',
BUMP CMT ABNDMNT PULG @ 8810', TEST AGAINST PLUG TO 1500
PSI, OK, POH, LD MULESHOE, PU EZ DRILL, SET SAME @ 8030',
DISPLACE WELL TO MILLING FLUID, POH & LD MILLING TOOL,
SAFETY MEETING, PU SMITH MILLMASTER SECTION MILL, RIH TO
8030', PUMP & SPOT 17PPG PILL (15BBL) POH TO 7795', BEGIN
CUT SECTION @ 7795'
CIRC/COND TO SPOT KO PLUG MW: 8.5 Seawater
MILL SECTION F/7795'-7855', SWEEP HOLE, POH, LD SECTION
MILL, PU MULESHOE & RIH, BREAK CIRC EVERY ROW ON WAY IN
HOLE, REV CIRC, MIX & PUMP 20 BBL CAUSTIC WATER
ATTEMPT TO KICKOFF. MW: 9.6 KC1
PUMP 20 BBLS CAUSTIC WATER. PUMP 15 BBLS ARCO SPACER, 36
BBLS 'G' CMT W/ 1% CFR-2, .25% LAP-I, .01 GPS 434-B, .05
GPS D-AIR. DISP W/ MUD. POOH 12 STDS. REV CIRC. SQZ CMT
W/ 1800 PSI. POOH. L/D BHA. TEST BOPE. RIH W/ BHA #5.
WASH & REAM F/ 7500'-7726'. DRLG CMT TO 7800' BEGIN
KICKOFF TO 7815'.
PU KELLY AFTER SHORT TRIP MW: 9.4 VIS: 55
DYNA DRILG F/7815'-8303'MD, CIRC LOW VISC/HIGH BISC SWEEP
AROUND, SHORT TRIP TO 9-5/8" CSG, RIH, HOLE CLEAN, PU KELLY
POH W/DYNADRILL MW: 9.4 VIS: 54
DYNA-DRLG F/8303'-8895', CIRC LOW VISC/HIGH VISC SWEEP
AROUND, MU SS SURVEY, DROP SURVEY, POH INTO 9-5/8" CSG,
PUMP SLUG, CONT POH W/BHA #5(DYNADRILL)
DRLG @ 9009'MD MW:10.0 VIS: 51
FINISH POH W/DYNADRILL, TEST BOPE, WITNESSED BY LOU
GRIMALDI W/AOGCC, MU BHA #6 (PACKER ROTARY ASSEMB.) RIH TO
7785', BREAK CIRC, CONT. TO 8410', HOLE TIGHT, PU KELLY,
REAM F/8410'-8895', RAISE MUD WT TO 10PPG, GAS BREAK OUT AT
BOTTOMS UP, CIRC OUT, ROTARY DRLG F/8895'-9009'
DRLG W/ROTARY ASSEMB @ 9460' MW:10.0 VIS: 52
ROTARY DRLG F/9009' TO 9411', CIRC LOW/HIGH VISC SWEEP
AROUND, SHORT TRIP TO 9-05/8" SHOE, PULLED HARD
F/8530'-8340', NOT REALLY TIGHT HOLE, RATTY HOLE, RUN BACK
TO BOTTOM, TIGHT @ 8637', WORK THRU, CONTINUE IN HOLE, PU
KELLY, ROTARY DRLG F/9411' TO 9460'
DRILL 8-1/2" HOLE W/RT ASSEMB MW:10.0 VIS: 49
ROTARY DRILL 8-1/2" HOLE F/9460' TO 9897, HELD SAFETY
MEETING FOR NEW HANDS ON RIG. EST TD @ 9900'
WELL : 7-4A
OPERATION:
RIG : DOYON 16
PAGE: 3
08/06/92 (14)
TD: 9900'( 3)
08/07/92 (15)
TD: 9900
PB: 0
08/08/92 (16)
TD: 9900
PB: 0
08/09/92 (17)
TD: 9900
PB: 0
08/10/92 (18)
TD: 9900
PB: 9848
08/11/92 (19)
TD: 9900
PB: 9848
POH TO RUN LINER MW:10.0 VIS: 47
DRILL 8-1/2" HOLE TO TD @ 9900', CIRC, WORK PIPE, SHORT
TRIP TO SECTION @ 7795', CBU, DROP MULTI-SHOT, POH, L/D BHA,
R/U SCHLUMBERGR, RIH W/OPEN HOLE LOGS, MHFL/DLL/GR/BHCS/CNL,
TAG BTM @ 9899', TIGHT COMING OFF BTM.,WORK TOOL FREE, LOG
OPEN HOLE -NO PROBLEM, RIH FOR WIPER TRIP, RIH, WORK TIGHT
SPOTS F/8950'-9650', TAG BTM @ 9900', CBU, SMALL AMT SAND
RETNS, SET KELLY BACK, POH TO RUN LINER
RIH W/ BIT TO TOL. MW:10.0 WBM
POOH. LD/ DP, BHA. R/U TORQ TURN. RIH W/ 7" 13 CR LNR ON
DP. CIRC. PUMP 25 BBLS ARCO PREFLUSH, 80 BBLS CMT. NO
BUMP PLUG. ROTATE F/ HGR. POOH 10 STDS. REV CIRC. POOH.
L/D BAKER RUN TOOL. RIH W/ BIT.
NOTE: 7" LNR F/ 7617'-9900'.
CIRC SEAWATER, ADD INHIBITOR MW:10.0 WBM
TIH W/8-1/2" BIT TO 7400', WASH DOWN F/7400'-7599', LINER
TOP, CBU, NO CMT PRESENT, POH LD DC'S, PU BIT & SCRAPER,
RIH, TAG PLUG @ 9848' PBTD, ATTEMPT TO PRESSURE TEST LINER,
LINER LAP BROKE DOWN ~ 2000 PSI, CIRC, DUMP & CLEAN PITS
FOR SEAWATER DISP, DISPLACE HOLE, POH, MU BAKER TEST SEAL
ASSEMB. RIH TO LINER TOP, STING INTO LINER TIE-BACK SLEEVE
@ 7600', PRESSURE UP TO 4000 PSI TO SET LINER TOP PKR &
LINER HGR, UNSTING, PRESSURE TEST ANNULUS TO 3500 PSI, REV
CIRC SEAWATER, ADD INHIBITOR
SET TREE TESTER VALVE, ND MW:10.0 WBM
REVS CIRC SEAWATER, ADD INHIBITOR, POH, LD 5" DP, LD TEST
TOOL, PULL WEAR RING, R/U TORQUE TURN, MU 4-1/2" CR
TAILPIPE ASSEMB., & 7" OTIS PKR ASSEMB, RIH W/TBG & GLM'S,
TEST TO 5000 PSI, OK, SET 7" PKR, BACK OUT LANDING JT, SET
TREE TESTER VALVE, N/D BOPE
RELEASE RIG 1300 8/9 MW:10.0 WBM
N/D BOPE, N/U TREE, TEST TO 5000 PSI, OK, DISPLACE WELL TO
142 BBLS DIESEL, U-TUBE DIESEL, SET BPV, SECURE WELL,
RELEASE RIG @ 13:00 8/9/92
MW:10.0 WBM
SIGNATURE:
(drilling superintendent)
DATE:
,r1.1aska Oil & Gas Cons. 6ommissio~'~
PRUDHOE BAY DRZLLZNG
PBU/7-4A
500292029201
NORTH SLOPE
COMPUTATZON DATE: 8/10
SPERRY-SUN DRZLLING SERV]:CES
~,. ANCHORAGE ALASKA --- 0 16 A [
DATE OF SURVEY' 08~)~-~/
MAGNETTC MULTI-SHOT SURVEY
dOB NUMBER: AK-EI-20056
KELLY BUSHING ELEV. = 64.00
/92 OPERATOR: ARCO ALASKA
PAGE
FT.
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
COURS COURSE D
INCLN DIRECTION
DG MN DEGREES DG/
LS TOTAL
RECTANGULAR COORDINATES
100 NORTH/SOUTH EAST/WEST
VERT.
SECT.
7800 7640,00 7576,00 26 0 N 75,50
7939 7761,02 7697,02 32 58 N 70,13
8031 7837,02 7773,02 36 34 N 67,88
8125 7911,67 7847,67 38 28 N 63,23
8219 7984.58 7920,58 39 34 N 55,46
.00 30.OON 629.00W 565.25
5.36 50.53N 694.22W 632.26
4,13 69,48N 743,47W 684.54
3.62 93.23N 795,59W 741.66
5,34 123.33N 846,28W 800.58
8313 8055,38 7991,38 42 4 N 49,46 W
8416 8130,63 8066,63 44 46 N 46,42 W
8500 8189.86 8125,86 45 55 N 44,26 W
8595 8253,82 8189,82 48 28 N 45,45 W
8688 8317,41 8253,41 45 32 N 46,53 W
4,97 160,60N 894,65W
3,30 208,.33N 947.48W
2,27 250,48N 990.12W
2,87 299.43N 1038,84W
3,26 346,83N 1087.89W
860.94
930,25
987.94
1054,25
1120,09
8779 8381,69 8317,69 45 14 N 44,44
8874 8449,33 8385,33 43 23 N 44,41
8967 8517,51 8453,51 42 39 N 44,56
9060 8586,14 8522,14 42 17 N 44,35
9152 8654,16 8590,16 42 17 N 43,47
9246 8723,63 8659,63 42 9 N 44,69
9340 8793,48 8729,48 41 57 N 44,98
9434 8863,03 8799,03 41 46 N 44,64
9524 8930,76 8866,76 41 42 N 44,66
9618 9001,10 8937,10 41 30 N 44,32
1,66 392.51N 1134.35W
1.96 439.67N 1180.58W
.79 485.07N 1225.17W
,42 529.93N 1269,18W
.64 574.51N 1312,09W
.88 619.80N 1355.95W
.30 664.50N 1400.39W
.32 708.71N 1444.32W
.08 751,69N 1486.78W
,32 796,24N 1530.54W
1182,83
1246,09
1307.07
1367,27
1426,38
1486.65
1547,16
1606,98
1664,92
1724,76
9712 9071,69 9007,69 41 22 N 44,23 W ,15 840
9805 9141,52 9077,52 40 47 N 44,10 W ,62 884
9838 9166,59 9102,59 40 17 N 43,96 W 1,57 899
,86N 1574,04W 1784,39
,53N 1616,46W 1842,63
.95N 1631.37W 1863,13
THE CALCULATION PROCEDURES ARE BASED ON THE USE OF
THREE-DZMENSZON MINIMUM CURVATURE METHOD.
HORIZONTAL DISPLACEMENT = 1863,13 FEET
AT NORTH 61 DEG, 6 MIN, WEST AT MD = 9838
VERTICAL SECTION RELATIVE TO WELL HEAD
VERTICAL SECTION COMPUTED ALONG 298.88 DEG.
/
RECEIVED
NOV 1 7 1992
Alaska Oil & Cas Oons. Commission
Anchorage
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAG
PRUDHOE BAY DRILLING
PBU/7-4A
500292029201
NORTH SLOPE
COHPUTATION DATE: 8/10/92
DATE OF SURVEY' 080592
JOB NUMBER' AK-EI-20056
KELLY BUSHING ELEV. = 64.00
OPERATOR' ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH
TRUE SUB-SEA
MEASD VERTICAL VERTICAL
DEPTH DEPTH DEPTH
TOTAL
RECTANGULAR COORDINATES
NORTH/SOUTH EAST/WEST
MD-TVD VERTICAL
DIFFERENCE CORRECTION
7800 7640,00 7576,00 30.00 N 629.00 W
8800 8395.85 8331,85 402.70 N 1144.34 W
9800 9137,25 9073,25 881,89 N 1613.90 W
9838 9166.59 9102.59 899,95 N 1631.37 W
160.00
404.15 244.15
662,75 258.59
672.04 9.29
THE CALCULATION PROCEDURES ARE BASED ON THE.USE OF
THREE-DIMENSION MINIMUM CURVATURE METHOD,
FT.
SPERRY-SUN DRILLING SERVICES
ANCHORAGE ALASKA
PAGE
PRUDHOE BAY DRILLING
PBU/7-4A
500292029201
NORTH SLOPE
COMPUTATION DATE: 8/10/92
DATE OF SURVEY' 080592
JOB NUMBER' AK-EI-20056
KELLY BUSHING ELEV, = 64,00
OPERATOR' ARCO ALASKA INC
INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH
TRUE SUB-SEA TOTAL
MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-
DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERE
TVD VERTICAL
NCE CORRECTION
7800 7640,00 7576,00 30,00 N 629,00 W 160
7826 7664,00 7600,00 33,17 N 640,67 W 162
7942 7764,00 7700,00 51,20 N 696,05 W 178
8065 7864,00 7800,00 77,42 N 762,12 W 201
,00
.88 2,88
.66 15.78
,39 22,73
8192 7964,00 7900,00 114,05 N 832.17 W 228
8324 8064,00 8000,00 165,73 N 900,59 W 260
8463 8164,00 8100,00 231,35 N 971,48 W 299
8610 8264,00 8200,00 307,38 N 1046,95 W 346
8754 8364,00 8300,00 379,77 N 1121,86 W 390
,92 27,53
,72 31.80
.78 39.O7
,35 46,57
,77 44,42
8894 8464,00 8400,00 449,58 N 1190,28 W 430
9030 8564,00 8500,00 515,52 N 1255,10 W 466
9166 8664,00 8600,00 581,01 N 1318,25 W 502
9300 8764,00 8700,00 645,74 N 1381.65 W 536
9435 8864,00 8800,00 - 709,33 N 1444,92 W 571
.63 39,86
,83 36,20
,02 35,19
,97 34,95
,31 34,33
9569 8964,00 8900,00 772,76 N 1507,57
9702 9064,00 9000,00 836,01 N 1569,31
9838 9166,59 9102,59 899,95 N 1631,37
605,28
638,74
672,04
33,97
33,47
33,29
THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN
THE NEAREST 20 FOOT MD (FROM.MINIMUM CURVATURE) POINTS
FT.
COl~ PRUI)HO£ BAY I)RILLING
WELL NA~ I)S-7-04A
LOCATION I PRUI)HO£ BAY
LOCATI~ 2 NSB, ALASICA
KqGNETIC I)ELINATION 30.10
02-AUG-f2
WI~LL HF. AJ) LOCATION: LAT(I,V-$) 0.00
AZIMUTH FROI ROTARY ?ABIZ TO l'~EI IS
TIE IN POINT(TIP)
I~ ))BVI'H
INCLINATION
AZIMUTH
LATITUI)E(I,I/-S)
I)~ARII.{(I!(F./-W)
7000.00
7640.00
26.00
284.50
30.00
-629.00
DEP(F../'W)
312.80
PAG£ i,10, 2 ~-7-04~
MEASLREO INTERVAL VERTICAL
DEPTH DEPTH
ft ft ft
78O0.00 0,0 7~0,~
8084,77 284,8 7882,33
8115.87 31.1 7906.96
8147,54 31,7 7931,78
8178,34 30,8 7955,78
8209.81
8237.20
8272.79
8301.94
8333.38
~4.~
8395,75
8427,(Y5
8458,61
8489,94
8521.39
8552,58
8584.01
8~15,71
8~t7.08
8677,56
8709.09
8740.51
8769.72
8829.07
31.5 7980.13
27,4 8001,16
35.6 8O28,39
29,2 8050.43
31.4 8073.67
30,9 80%,14
31.5 8118,73
31.3 8140,82
31,6 8162,80
31.3 8184,41
31.5 8206,20
31,2 8227.92
31,4 8249,87
31,7 8272.06
31.4 8294,05
30,5 8315.42
31.5 8337.40
31,4 8359,23
29,2 837%64
59,4 8421,64
9URUEYg41Zt~TIOI~
::::r.: MINII'U'I CtIRVA~ {'l~O ~
TAR'CET STATION AZII'ILrFH LATITUDE
SEL'YrlON INCLN,
ft decj decj
481,90 26.00 284.50 30,00
618,57 37,17 293,52 80,14
636,53 38,10 294,16 87,82
655,37 38,72 Lx;'8,04 96,48
674,11 38,89 299,94 105,83
693,66 39,73 303.20 116,27
711,01 40,02 304,56 126,06
733,74 40,15 306,71 139,41
752,74 41,62 307,93 150,98
~,~ 43,05 311.21 164.47
795.02 43,51 310,19 178,2Y
816,96 44,90 314.07 192,99
839,13 45,33 314.17 208,43
861.78 46,40 314.59 224,28
884,43 46,34 315.83 240,37
907.07 45.99 316.73 256,76
929,43 45.76 314.85 272,81
951,91 45,63 315.25 288,73
974,53 45.51 312,47 304,41
996,91 45,50 311,89 319,44
1018.64 45,45 312.15 333,98
1041.24 46.14 313.63 349,36
1063,84 45,84 312.39 364,78
1084,72 45,~ 315,69 ~9,30
1126,59 ~,40 316,78 40%59
DEPARqL~ DI~LACB'I~f at
E/-W
ft ft
-6~,® 6~,72
-7~,84 773,00
-7~,21 791,10
-803,86 8O9,63
-820,75 87.7.54
AZIWJTH
deq
272.73
2..75,95
276,37
~6,~
277.35
DLS
lOOft
0,00
4,25
3.22
7.86
3.91
-837.73 845,76 277,90 7,07
-852.31 861,58 278,41 3,35
-870.93 882.01 279.09 3.91
-866,10 898,~ 2.79,67 5,74
-902,41 917,27 280,33 8,37
-918.45 935.59 280,98 2,69
-934,72 954,44 281,67 9,65
-950,64 973,23 282,37 1.40
-966,83 992,50 283,06 3,52
-982,80 1011.77 283,74 2.87
-998,48 1030,97 284.42
-I014.10 1050.15 285.06
-102%99 1069,69 285,6~
-1046,30 1089,&8 286.22
-1062,89 1109,85 286,73
-1079,03 112%53 287,20
-I095,59 114%74 287.69
-1112,11 1170,41 288,16
-1127,13 1189,24 288,60
-I156,14 1226,5"5 289,51
2.35
4.39
1.00
6.26
1.33
0.63
4,02
2,99
8.15
2,29
ANADRILL
2401 NABAR LOOP
ANCHuRAGE, ALASKA 99507
(907) 349-6575
Prudhoe Bay Unit
P O ox 19661
· .~B 2
Anchorage, AK 99519-6612
Attention' Terry Jordan
August 03, 1992
Dear Terry,
I have compiled a summary of Anadrill's performance on DS 07-04A.
SERVICES PROVIDED
Directional Survey Service with DWOB and DTOR (DSW) was picked up on 28-JUL-92 to
facilitate the casing milling operation from 7795' to 7855'. DSW was also used for the kick off run
on 30-JUL-92 to 02-AUG-92 from 7800' to 8895'.
.IOB PERFORMANCE
Downhole weight on bit and torque (DWOB & DTOR) were used in the milling operation as on the
previous wells. The milling went very smoothly and was completed in 13 hours. There was a 4 to
6 KLBS difference in surface weight on bit vs downhole weight on bit. Milling typically requires
low weights on bit (4-10 KLBS) to efficiently cut the casing without damaging the cutting structure
of the blades. Poor weight transfer results in inefficient penetration rates whereas excessive milling
rates have recently proven to be disastrous due to cuttings build up in the annulus. The use of
DWOB has allowed Prudhoe Bay Drilling to optimize ROP while minimizing the potential hazards.
DSW service was continued throughout the kickoff. DWOB has again proven to make the kickoff
smoother and less time consuming. Standard practices would dictate time-drilling at perhaps 10 to
15 min/ft, resulting in 15 hours to clear a 60' section. DWOB permits a constant weight of 2-3
KLBS to be maintained while feathering the plug. The section on this well was cleared in 8 hours.
SPIN was used to monitor the hole conditions which were good throughout the well. No hole
condition Problems were encountered. MEL was used to monitor the bit condition for wear, gauge,
and locking cones. This is very useful on a long bit run such as this because a locked cone can be
detected immediately thus avoiding costly fishing time.
A total of 24 surveys were taken of which 10 were used for calculation of the well path. The first
survey to be clear of magnetic interference was taken 284' into the kickoff at a measured depth of
8084'. Anadrill is currently pursuing research of methods to factor out interference vectors from
casing proximity to permit accurate directional steering sooner for the sidetrack/redrill projects.
For your convenience, I have included an ASCII file of the surveys along with a hardcopy of the
surveys. I have also included a copy of the sticking pipe indicator (SPIN) log. Anadrill appreciates
the opportunity to supply services on your well and we look forward to continuing a healthy
business relationship.
Manager- AlaSka
MICROFILME )
ORIGINAL
COI"F'~ PRUI)t~£ I~Y I)RILLI]~
LIr,~TION 1 ~£ l~¥
LOCqTI~ 2 ~B,
i~TE: 29-3UL-92
I~Qih'TIC I)~LII~?I~ 30.10
RECEIVED
SEP 2 5 1992
Alaska Oil & Gas Cons. Commission
Anchorage
PAG£ NO, 2 DS-7-O4A
MD TUD INC C~ Ct.~INC_CH~ I_RATE ~M_[]~ Ct~_C~ ~ RATE CLOSt~ TOOL_FACE DLS DLSRT
7 ,0 7 0,00 0.00 0,00 0,00" 0'.00' 40s,3 0,00 0.00 0,00
8084.8 7882.33 11.17 11,17 3.92
8115.9 7906.96 0.92 12.10 2.96
8147.5 7931.78 0,62 12.72 1.97
8178.3 795'5.78 0.17 12.89 0.56
9,02 9,02 3,17
0,64 9.66 2.06
3.88 13,54 12.25
1.90 15.44 6.17
463,57 0,00 4,25 1.49
469,74 0.00 3.22 3.32
475.3']' 0,00 7.86 14.67
0.00 0,00 3.91 12.64
820'7.8 7980.13 0.84 13.73 2,66
8237,2 8001.16 0.29 14,02 1.05
8272.8 8028,39 0.13 14,15 0,37
8301.9 6050,43 1.47 15.62 5.03
8333,4 8073,67 1.44 17.06 4,58
3.26 18,70 10.35
1.36 20.06 4.97
2.15 22.21 6.04
1.23 23.43 4,21
3.27 26,71 10.41
483.88 0.00 7.07 10.07
466.60 0,00 3.35 13.58
489,46 0,00 3.91 1,56
491,28 0,00 5.74 6.26
480.00 0,00 8.37 8,38
8364,3 8096.14 0.45 17.51 1.46 -1.02 25.69 -3.3:0
83-75,7 8118.73 1,39 18.90 4.42 3.88 29,57 12.31
8427.0 8140.82 0.43 I9.33 1,38 0.10 29,67 0.32
8458.6 8162.80 1.07 20.40 3.:39 0,42 30,09 1.34
8489,9 8184.41 -0.06 20.34 -0.18 1.24 31.33 3,95
493.24 0.00 2.69 18.40
493,48 0,00 9.65 22.10
492,97 0,00 1.40 26.37
492.35 0,00 3.52 6,73
492.46 0,00 2.67 2.09
8521,4 8206.20 -0.35 19.99 -1,12 0.90 32,23 2.86
85'52,6 8227.92 -0.22 19.76 -0.72 -1,88 30.35 -6.04
8584,0 8249.87 -0.14 19.63 -0.43 0,40 30,75 1.26
8615,7 8272,06 -0.12 19,51 -0.38 -2.77 27.97 -8.75
8647.1 8294.05 -0.01 19.50 -0.03 -0,59 27,3'7 -1,87
490.02 0,00 2.35 1,64
488.85 0.00 4.39 6.56
487.96 0,00 1.00 10.79
487.55 0.00 6.26 16.59
491.39 0,00 1.33 15,70
8677.6 8315.42 -0.05 19,45 -0.17 0,26 27.65 0.85
8709,1 8337.40 0.69 20,14 2.20 1.48 29,13 4.69
8740.5 835?.23 -0.30 19.84 -0.97 -1.24 27.89 -3.94
8769,7 8379,64 -0.32 19.52 -1.10 3.30 31,19 11.28
8829,I 8421,64 -1.11 18.40 -1.88 1,10 32.28 1.85
488.08 0.00 0.63 2.31
468,05 0,00 4.02 10,76
487.97 0,00 2.99 3.28
487,52 0,00 8.15 17.65
487.79 0,00 2.29 9.88
ARCO ~l_~sk~; Inc.
P.O.Box 100360
Anchorage, Alaska 99510
DATE: 9-18-92
REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS
7-4A 8-5-92 BCS/CITI'H/DLL R~m I Job# 92484
Please sign and return the attached copy as receipt of data.
RE C E IVE D BY___2~~_~-~~
Have A Nice Day!
Sonya Wallace
ATO-1529
APPROVED_ff~_
Trans# 922L~~'' .....
Sch
CENTRAL FILES (CH)
CHEVRON
D&M
# (OH/C, CT)
# EXXON
MARATHON
MOBIL
# PHILLIPS
PB W"~ F-'~
R&D
# BPX
# STATE OF ALASKA
TEXACO
RECEIVED
OCT 15 1992
Alaska Oil & Gas Cons. Commission
Anchorage
ARCO Alaska, Inc.
P.O.Box 100360
Anchorage, Alaska 99510
DATE: 10-2-92
REFERENCE: ARCO CASED HO!JE FINALS
14-3 6-28-92
Perf l~m L
Perf Run 1, ~' HLS
Perf Run L
Perf Run 1, I~' HLS
Collar l~m 1, ~' HLS
Perf Run 1, ~' HLS
Perf thru 1, ~' HIS
Per/ Run 1, 5" HLS
Perf l~m L 5"
Perf Run L ~' HLS
Perf l~m L N' HLS
Peri' Run 1, l~' HI~
Perf l~m 1, ~' HI~
Collar Run L ~" HI~
Perf Run L ~" HI~
Collar Run L ~' BI~
Perf Rm~ 1, ~' HLS
Perf Run L
Perf Run L i~' HL~
Pelf Run L
Please sign and return_~t~/~_copy as receipt of data.
RECEIVED
IVEDE
Sonya Wallace OCT 0 5 ]99~ APPROVED__ff~__
AT0-1529 Tr~ns# 9221~~''-''----
Alaska Oil & Gas Cons. Commiss/.o.r~
# CEN'I'I~kL FILl~horage
# C]~VRON
# EXTENSION EXI:%OI:L~k'rI01~
# EZXON
# MOBIl,
#
PB WEI~ FH.F~
# BPX
# STATE OF ALASKA
The correct ~ell .nm~ ia 1-LB.
The correct API# f~ 1-LB is 504Y29-21007-01.
The correct well nnme is
The correct API# for 7-4A is 50-029-202924)1.
The correct AP1 # fur 14-1 is 504)29-20317-00.
The correct AP1 # for 14-5A is 50-02~20327-01.
The correct AP1 # for 16-31 is 504Y29-22280-00.
/?
ARCO Alask~ Inc.
P.O.Box 100360
Anchorage, Alaska 99510
DATE: 10-2-92
REFERENCE: ARCO CASED HOr.~'- FINALS
~~/ ~ s-30-92 Prod Profile
~2_~-3 ~x3 9-x-92 Prod Proffie ~_m L
-~?~i~L~_~/I~ 9-6-92 Leak Detect (Flex:s'~k) Run 1,
~z? S-Z~ . 9-6-92 ~ Detect ~exstak) ~-~'L
~o5-- 3/5- ~-i~ 8-21-92 Prod Profile Ih_m
-~_~.~j- 5-1Cl 8-30-92 GR/Collar Ibm 1,
~ 7-4A ?Z~t? 9-8-92 T_~mp Run1,
7-
9-7-92 PITS Run
9-1-92 Prof Profile R,m 1,
~. 8-24-92 Peri Breakdown
Please sign and return th~ attac~I copy as receipt of dat~
Sonya Wallace OCT 0 5 Ii)i)/ AppRovED_
ATO-1529 Alaska 0ii & aas Cons. C0mmi~'s# 9221~
Anchorage
# CENTRAL FILES
# CHEVRON
D&M
# EXTENSION EXPLORATION
# EXXON
# MOBIL
# pm~.r~rps
PB WELL FILES
R&D
# BPX
# STATE OF ALASKA
* This is not a field print for 1-11.
ARCO ,~ln$~, Inc.
P.O.Box 100360
Anchorage, ,~!~slra 99510
DATE: 9-18-92
REFERENCE: ARCO CASED HOLE FINALS
8-18-92
8-18-92
8-8-92
8-9-92
8-13-92
8-14-92
8-15-92
8-17-92
8-14-92
8-10-92
8-17-92
Prod Profile R~_m 1, 5"
Prod Profile R-n 1, 5"
Prod Profile (Flexstak) R~_n 1, 5"
Prod Profile R.n 1, 5"
GR/CCL/Jewelry Run 1, 5"
GR/CCL R~_n 1.5'
Prod Profile R~_m 1, 5"
Leak Detect R~m 1, 5"
Temp R~_n 1, 5"
GR/Collar Run 1, 5"
Prod Profile R~m 1.5"
Please sign and return ~'attagl}e~ copy as receipt of data~
Sonya W-!l_~_ce o C~O~ 199Z D_~~_
ATO- 1529 ~1.~}~. 0ii & 6as ~0as. ~0mmi~ig.n AP P R OV E
C~mco
C~mco
C~_mco
Camco
CAmco
CAmco
Camco
C~mco
Camco
Camco
Camco
# CENTRAL ~
# CI~VRON
D&M
# EXTENSION EXPLORATION
# EXXON
MARATHON
# MOBIL
# PHILLIPS
R&D
# BPX
# STATE OF ALASKA
TEXACO
ARCO ,~!~-~ka, Inc.
P.O.Box 100360
Anchorage, Alaska 99510
DATE: 8-14-92
REFERENCE:
~"~ I6' 12A ~/ 7-14-92
×
?~q-d~_ 7-4A ~) 8-2-92
~/-/22 ~-~4ST ~ 6-30-9~
' (15-18 ~ 7-30-92
ARCO DIRECTIONAL DATA
RECEIVED
Have A Nice Day!
Sonya W~11~ce
ATO-1529
MWD Directional Survey Aha
Magnetic Multi-Shot Survey Job#AK-EI-20050 Sperry
MWD Directional Survey Aha
MWD Directional Survey Ana
MWD Directional Survey Job#AK-MM-920719 Sperry
MWD Directional Survey Job#AK-MW-20054 Sperry
MWD Directional Survey Job#1107 Teleco
Please sign and return the attached copy as receipt of data.
CENTRAL FILES
CHEVRON
D&M
# EXTENSION EXPLORATION
# EXXON
MARATHON
MOBIL
PHILLIPS
# PB WELL FLS (2 COPIES)
R&D
# BPX
# ST. OF AK. (2 COPIES)
TEXACO
RECEIVED
S£P 2 5 1992
Alaska Oil & Gas Cons. Commission
Anchorage
ALASKA OIL AND GAS
CONSERVATION COMMISSION
WALTER J. HICKEL, GOVERNOR
-.
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
TELECOPY: (907) 276-7542
SEPTEMBER 24, 1992
MARION SLOAN
BP EXPLORATION ALASKA INC.
P O BOX 196612
ANCHORAGE, ALASKA 99518-6612
RE:
92-0053 PRUDHOE BAY UNIT N-24 COMPLETION REPORT '
92-0066 PRUDHOE BAY UNIT DS16-29A COMPLETION REPORT
92-0056 PRUDHOE BAY UNIT DS16-29 P&A PAPER WORK
92-0075 PRUDHOE BAY UNIT DS16-31 COMPLETION REPORT
92-0067 PRUDHOE BAY UNIT DS7-4A COMPLETION REPORT
78-0012 PRUDHOE BAY UNIT DS7-4 P&A PAPER WORK
92-0060 PRUDHOE BAY UNIT DSl5-18 COMPLETION REPORT
91-0054 PRUDHOE BAY UNIT. DS4-34 P&A PAPER WORK
DEAR MARION SLOAN,
OUR FILES INDICATE THAT ARCO ALASKA AND BP EXPLORATION
ALASKA INC. IS THE OPERATOR OF THE REFERENCED WELLS. THESE
WELLS HAVE REPORTED PRODUCTION TO US AND WE HAVE NOT
RECEIVED THE APPROPRIATE COMPLETION REPORTS (407 FORMS) TO
DATE.
AUGUST MONTHLY PRODUCTION PREPORTS INDICATE THAT THESE WELLS
ARE OIL PRODUCER FOR THE YEAR 1992. WE HAVE NO PAPER WORK
SHOWING THE COMPLETIONS FOR THE WELLS OR PLUGGING AND
ABANDONMENT OF THE ORIGINAL WELL.
I AM FORWARDING THIS LETTER AS A RECORD FOR YOU AND ME, NOT
AS A FAILURE TO COMPLY. THANKS FOR YOUR QUICK RESPONSE ON.
THESE REPORTS.
SINCERELY,
STEVE MC MAINS
ARCO Alaska; Inc.
P.O.Box 100360
Anchorage, Alaska 99510
DATE: 8-18-92
REFERENCE:
ARCO OPEN HOLE FINALS
8-5-92 SSTVD Color Run 1, l"&2'
8-5-92 DLL/MSFL/GR Color Run 10 :~'&~'
8-5-92 BHCS/GR Color Run 1, ~'&5~'
8-5-92 CNL/GR Color Run 1, ~'&5~'
8-6-92 SSTVD Run 1, r'&2"
8-6-92 DLL/GR Run 1.
8-6-92 BHCA/GR Run 1, 2~'&.~'
8-6-92 CNL/GR Run 1, ~'&[~'
8-9-92 SSTVD Run 1, l"&2'
8-9-92 PISFL Run 1, :~'&~'
8-9-92 BHCS Run 1, :~'&.~'
Please sign and return tile attached copy as receipt of data.
RECEIVED I~Y___
Have i Nice Day!~/~__~
Sonya W~llace APPROVED .~
ATO- 1529 Trans# 9218~-}r
Sch
Sch
Sch
Sch
Atlas
Atlas
Atlas
Atlas
Sch
Sch
Sch
# CENTRAL FILES
# CHEVRON
#D&M
# EXTENSION EXPLORATION
# EXXON
MARATHON
# MOBIL
# PHILLIPS
# PB WELL FILES
R&D
# BPX
# STATE OF ALASKA
# TEXACO
RECEIVED
SEP 05 1992
Alaska 0il & Gas Cons. Commission
Anchorage
PEIlMIT ~
GEOLOGiC,AL M`ATERi`ALS iNVENTORY LiST
COMPLeTiON DaTF k'- ! / 7 ~ ,9'Z--CO. coN'racT ~
check off or list data as it is received.*li:
drillinQ history*
cored intervals core analysis
received date for 407. if not required Iisi as Nil
survey tests core dcscri.
ditch intervals diQital data
i .i i
~' , , r- SCALE
i L,~,= ~,r,~ RUN ,.-~n,,~,o
i1~1 I Lg~SLd
NO. {to the nearest footI [inchl100:1
, , ,,
~1 i '
'121 I '
, , , ~ , ,
i i ~
~q I I
1
~q .......... 1 ....
TO:
THRU:
FROM:
MEMORANuUM State of Alaska
ALASKA OIL AND GAS CONSERVATION COMMISSION
David W Johns~
Commissioner
DATE:
FILE NO:
August 4, 1992
lg8492-6.doc
'1Blair Wondzell ~/£
p. I. Supervisor
Grimaldi
r InSpector
TELEPHONE NO:
SUBJECT:
BOP Test
Doyon Rig #16
(659-4610)
ARCO #DS 7-46
Permit No. 92-67
Prudhoe Bay Unit
sunday. A~ust..2,. 1.992 I witnessed a BOP test on Doyon Rig
#16 which is presently redrilling ARCO's well #DS 7-4 in the
Prudhoe Bay Unit.
I received no advance notice for this BOP test even though on
the preceding week I had notified ARCO company rep Nick Scales
that this test was to be state witnessed. James Robertson
(alternate company rep) was unaware that he was required to
give 24 hours notice and assured me that in the future proper
notice would be given.
The BOP test went well although the floor hands seemed
unfamiliar with the drill. Constant instruction by the
driller kept the test going smoothly.
All BOP compone~{s were tested and two failures were observed.
'These being the upper kelly cock which appeared to be washed
out and the #2 valve on the alternate flare line which
although tested "ok" would not reopen and the valve stem was
stripped. Both failures were repaired before the rig
continued with the redrill program.
In. sum~ar¥, the BOP test I witnessed on Doyon Rig #16 revealed
two failures, the upper kelly valve and a choke manifold
valve. Both were repaired before the rig proceeded with the
redrill of ARCO's ~DS 7-4.
Attachment
02-00lA (Rev. 6/89)
20/11/MEMOl.PM3
STATE OF. ALASKA
ALASKA OIL AND GAS CONSERVATION COMMISSION
BOP Test Report
OPERATION: Drlg ~ Wkvr
TEST: Initial~ Weekly 'X[j Other
/
csg set. ~ ft ACCUMULATOR SYSTEM:
Location (general) ~0~ Well sign ~ Full charge pressure
Housekeeping (general)~O~ Rig~O~> Press after closure,~
Rsrve pit ~__~.
MUD SYSTEMS:
Trip tank
Pi t gauge
.¢
F1 on monitor
Gas detectors
psig
psig
Pump incr clos press 200 psig ..... min ~..J~sec
Full charge press attained ~.~ min __sec
Visual Audio~
! N2 psig.
Controls: ~aster
~ KELLY AND FLOOR SAFETY VALVES:
Upper Kelly ~ Test pressure
Lo.er Kelly ~ Test pressure
T.~st Pressure
BOPE STACK:
Annul ar preventer
Pi pe rams
B1 ind rams
Choke' 1 i ne vel ves
HCR Valve
Kill llne valves
Check vel ve
Ball type ~ Test pressure
Inside BOP /~ Test pressure
Choke manifold ~~Test pressure '~~
Number val yes
~mO~ N~ber flanges
/~l~ "~~ ~.~
.... ~ 0,~.~ <~ Adjustable chokes
TEST RESULTS: Failures ~ ...... Test time hrs
Repair or replacement-of failed equipment to be made within ~ days. Notify the
; Inspector, and follow with written/FAXed [276-7542] verification to Commission office.
.... '"' ~ ~ ~ ~,~';:~ ~
Distribution:
orig - AOGCC
c - Operator
c - Supervisor
STATE WITNESS REQUIRED? I
ye$~l no I
24-HR NOTICE GIVEN? I
yes ..... no~ I
C.004 (rev 03/92)
' ' STATE OF ALASKA
AL~._,,A OIL AND GAS CONSERVATION COMMIS~,-,,JN
APPLICATION FOR SUNDRY APPROVALS
1. Type of Request:
Abandon x Suspend ~ Operation Shutdown ~ Re-enter suspended well ....
Alter casing ~ Repair well Plugging x Time extension ~ Stimul~'ie '
Change approved program ~ Pull tubing ~ Vadance ~ Perforate ,. OuSer x
Plugback for Reddll
2. Name of Operator
ARCO Alaska,/nc.
3, Address
P. O. Box 196612, Anchorage, Alaska 99519-6612 '
5. Type of Well:
Development
Exploratory
Stratigraphic
Service
6. Datum elevation (DF or KB)
KBE = 64 feet
7. Unit or Property name
Prudhoe Bay Unit
4. Location of well at surface 8.
1685'SNL, 68' WEL, SEC. 33, T11N, R14E
At top of productive interval 9.
1412' SNL, 988' WEL, SEC. 33, T11N, R14E
. At effective depth 10.
At total depth
1155'SNL, 1198' WEL, SEC. 33, T11N, R14E
Well number
DS 7-4
Permit number
78-12
APl number
50- O29-2O292
11. Field/Pool
Prudhoe Bay Field/Oil Pool
12. Present well condition summary
Total depth: measured 9535 feet
true vertical BKB 9219 feet
Effective depth: measured 9463 feet
true vertical BKB 9164 feet
Plugs (measured)
Junk (measured)
Casing Length Size
Structural
Conductor 80' 20"
Surface 2724' 13-3/8"
Intermediate
Production 7800' 9-5/8"
Liner
Perforation depth: measured 9248'-9279', 9298'-9318'
Cemented Measured depth True vertical depth
450 cu ft Poleset 110' 110'
6050 cuft AS II 2724' 2724'
1450 sx Class "G" +
300 sx AS I
7800'
RECEIVED
7640'
true vertical 9091;9105: 9113;9122' ,JUL_ - 1 1992
Tubing (size, grade, and measured depth) 5-1/2"x 3-1/2" U80 tubing to 9248'MD Alaska 0il & Gas 0ohs. Commissio~
Anchorage
Packers and SSSV (type and measured depth) BOT 'HB' Packer @ 8781'MD, 3-1/2" Camco SSS V @ 2223'MD
13. Attachments
Description summary of proposal _z__.. Detailed operations program
BOP sketch
14. Estimated date for commencing operation
7/5/92
16. if proposal was verbally approved Oil x
Name of approver Date approved Service
17. I hereby certify that the foregoing is true and correct to the best of my knowledge.
15. Status of well classification as:
Gas
Title Drilling Engineer Supervisor
FOR COMMISSION USE ONLY
Suspended
Conditions of approval: Notify Commission so representative may witness
Plug integrity ~ BOP Test~ Location clearance
Mechanical Integrity Test~ Subsequent form required 10-
Approved by order of the Commission
/
Commissioner Date '~'" 1"" F~'~
Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE
I00'
+' ~"ioO'nD '
G,7~l '
·
· .
9 Z3'7 'nn
~rlD.
d UL - 1
· .
Alaska Oil & 6as Cons. Commission
Anctiorag~
;'.~ ..
..,; ~.~¢~,~......,
/z, ! .... ' :
/ ·
A~vs,
///
, ~'~DS7-4A PLUGBAC:K
PROC[ IRE
Procedure Outline: (Refer to attached weilbore schematic)
1. Notify an AOGCC representative prior to commencing operations.
2. RIH w/slickline unit and fish Teledyne Meda tubing patch @ 8761'md ELM. RIH and tag
PBTD estimated at 9365'md (6-20-90).
Note: There will no need to install a plug in the 3-1/2" XN nipple @ 9246' md ELM due to a.
cement retainer being installed at 8030' md.
3. RIH w/perforating sonde and perforate 3-1/2" tubing ( in straddle) @ 8855' md - adjacent to
9-5/8" intermediate casing leak.
4. RIH w/coiled tubing to PBTD ( top of fill ) @ 9365' md and circulate.well to filtered seawater.
Lay in a cement plug of sufficient volume to cover 100' md above casing leak @ 8855'md.
5. RU slick line unit and RIH and tag cement top to ensure a minimum of 100' md above 3-1/2"
tubing perforations/casing leak at 8855'md.
..
Note: Cement top tag to be witnessed by AOGCC representative.
6. RU E-line and RIH to make tubing cut @ +/- 8700' md.
7. Circulate well over to filtered seawater and freeze protect the upper 2000' md of the well.
8. Bleed tubing, inner annulus, and outer annulus to 0 psi.
9. Set 5-1/2" BPV. Remove the well house and flowlines. Level the pad and dig out the cellar if
required. Prepare pad for RWO.
RECEIVED
fl U L - 1 7992
Alaslca Oil & Gas Cons. Commission
Anchorage
ALASKA OIL AND GAS
CONSERVATION COMMISSION
WALTER J. HICKEL, GOVERNOR
·
3001 PORCUPINE DRIVE
ANCHORAGE, ALASKA 99501-3192
PHONE: (907) 279-1433
TELECOPY: (907) 276.7542
July 15, 1992
Michael Zanghi
Drilling Engineer Supervisor
ARCO Alaska, Inc.
P O Box 196612
Anchorage,' AK 99519-6612
Re:
Prudhoe Bay Unit DS 7-4A Redrill
ARCO Alaska, Inc.
Permit No. 92-67
Sur. Loc. 1685'SNL, 68'WEL, Sec. 33, TllN, R14E, UM
Btmnhole Loc. 806'SNL, 3117'WEL, Sec. 33, TllN, R14E, UM .
Dear Mr. Zanghi:
Enclosed is the approved application for permit to redrill the above
referenced well.
The permit to redrill does not exempt you from obtaining additional
permits required by law from other governmental agencies, and does not
authorize conducting drilling operations until all other required
permitting determinations are made.
Blowout prevention equipment (BOPE) must be tested in accordance with
20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given
to allow a representative of the Commission to witness a test of BOPE
installed prior to drilling new hole. Notice may be given by contacting
the Commission petroleum field inspector on the North Slope pager at
659-3607.
Sincerely,
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
20 AAC 25.005
la. Type of work Drill [] Redrilll;'lllb. Type of well. Exploratory[] Stratigraphic Test[] Development OilE]
Re-Entry [] Deepen[]l Service [] Development Gas [] Single Zone [] Multiple Zone El
2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool
ARCO Alaska, Inc. KBE = 67feet Prudhoe Bay Field/Prudhoe
3. Address 6. Property Designation Bay Pool
P. 0. Box 196612. Anchoraae. Alaska 99519-6612 ADL 28309
4. Location of well at surf-ace 7. Unit or property Name 11. Type Bond(see 2o ^^c 25.025)
1685' SNL, 68' TEL, SEC. 33, T11N, R14E, UM Prudhoe Bay Unit
At top of productive interval 8. Well number Number
1018' SNL, 1477'TEL, SEC. 33, T11N, R14E, UM DS 7-4A U-630610
At total depth 9. Approximate spud date Amount
806' SNL, 3117' TEL, SEC. 33, T11N, R14E, UM 8/20/92 $200,000.00
12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandmVD)
property line
ADL 28310/2162 feet No near well proximity feet 2560 9872'MD/9186'TVD~eet
16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2))
Kickoff depth ~'8oofeet Maximum hole anvils44.2?° Maximum surface 3330psig At total depth (TVD) ~O0'/4390Pslg
!18. Casing program Setting Depth
s~ze Specifications Top Bottom Quantity of cement
Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data)
8-1/2" 7" 26# 4130/L8~' NSCC 743' 7620' 7478' 8363' 8104'
8-1/2" 7" 26# cr13/LSO Fox 1509' 8363' 8104' 9872' 9186' 460 cu fl Class "G"
19. To be completed for Redrill, Re-entry, and Deepen Operations. [~ ~ [~ I V [-..
Present well condition summary
Total depth: measured 9535feet Plugs (measured)JUi l 0 1992
true vertical BKB 9219 feet
Effective depth: measured 9463feet Junk (measured) Alaska 0il & Gas Cons. Commission
true vertical BKB9164 feet Anchorage
Casing Length Size Cemented Measured depth True Vertical depth
Structural
Conductor 80' 20" 450 cu ft Poleset 110' 110'
Surface 2724' 13-3/8" 6050 cu fl AS II 2724' 2724'
Intermediate
P rod uction 7800' 9-5/8" 1450 sx "G" 7800' 7640'
Liner + 300 sx AS I
Perforation depth: measured
true vertical
20. Attachments Filing fee 171 Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[]
Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed report[] 20 AAC 25.050 requirements[]
21.1 hereby certify jthat the forflgoing is true and correct to the best of my knowledge
Signed/~ .,~/~¢:{//~' "- Title Drilling Engineer Supervisor Date___,,3
' (,.,/' / Commission Use Only
Permit Number IAPI number IApproval date ... ISee cover letter
Conditions of approval Samples requ. ired [] Yes ,E~NO Mud Icg required [] Yes ,I~'NO
Hydrogen sulfide measures [] Yes ~ No Directional survey requ~reo ~ Yes [] No
Required working pressure for BOPE []2M; 1-13M; ,J~5M; []10M; []15M;
Other:
Approved by Original Signed BY by order of
.... ~,~ v,/ johnston Commissioner ~ne commission Date
Form 10-401 Rev. ¥~-'1'-~5 Submit in triplicate
PROPOSED REDRILL PROG .... ,M
WELL 7-4A
OBJECTIVE:
The pdmary objective the the DS 7-4A Redrill is to return the well to production by drilling
a new production hole to a location approximately 440' NW of the current BHL. DS 7-4 is
currently shut-in due to a 9-5/8" casing leak and a leaking straddle. A redrill is
preferable to RWO options based upon the high cost associated with the RWO and the
attendant benefits to be gained by drilling to the new BHL. The DS 7-4A BHL will provide
an effective offtake location for both lower Romeo and upper/lower Tango oil lense
reserves. In addition, open hole compensated neutron logging will provide additional
resolution to a complex gas contact picture in the DS 7 area that will be benefical to
future profile modification work.
The DS 7-4A redrili scope of work will include: Perforate 3-1/2" tubing adjacent to casing
leak at 8855'md. Rig up coiled tubing unit. Position cement plug from PBTD @ 9365' md
to 8700' md. Squeeze cement into leaking squeeze perfs and casing leak. Tag cement
plug - ensure that top of cement is a minimum of 100'md above 9-5/8" casing leak at
8855'md. Cut tubing at 8700' md. Pull 5-1/2" x 3-1/2" tubing.
Position cement retainer at 8030'md - spot 100' md of 17 ppg high viscosity mud on top
of cement retainer. SectiOn mill 60' md window in intermediate 9-5/8" Casing from 7770'
md to 7830' md. Run in hole and spot cement from cement retainer @ 8030' md to 200'
md above top of section window @ 7570' md. Run in hole with kickoff assemby and
directional drill 8-1/2" production hole to new BHL (440'.- NW azimuth). Run open hole
formation evaluation logs. Run 7" 13CR 26# Fox/7" 4130 26# IJ4S liner- test liner and
intermediate casing. Replace wellhead intermediate 9-5/8" packoff as needed. Complete
DS 7-4A with 4-1/2" 13CR tubing. Upper/lower Tango and Romeo perforations to be
performed after rig has moved off location.
CURRENT STATUS:
DS 7-4 has a 9 5/8" casing leak at 8855' MD which is located just above the original
GOC. The casing leak is straddled, but the well is currently shut-in with an uncompetitive
GOR (50,000+) due to a tubing leak in the straddle at ~8786' MD just below the top
packer. A specially designed seal bore tubing patch has been set over the the straddle
leak, but does not appear to have isolated the gas.
DS 7-4 was spudded 8-27-78. The well was TD'd @ 9535' md w/12-1/4" hole size. The
production casing consists of a 9-5/8" Iongstring casing program. Surface(13-5/8")
casing is set at 2724' md.
PERMITTING:
The attached sundry notice covers the plugback of the original well and the drilling permit
covers the proposed drilling program.
I '[¢EIVED
JUN 0 1992
Alaska Oil & Gas Cons. Cornrnissio~
Anchorage
'~-'"PROPOSED REDRILL PROG--'M
WELl,. 7-4A
SUMMARY PROCEDURE:
lo
e
e
4.
5.
6.
7.
10.
11.
12.
~13.
14.
15.
16.
17.
18.
19.
20.
21.
Plug-back existing straddle/non straddle perforations and casing leak @ 8550'md
with cement, cut tubing @ 8700' md just above the isolation packer @ 8787'md
prior to arrival of the workover dg.. MIRU workover rig.
Pull 5-1/2" BPV. Circulate freeze protection fluid from well and recover for future
use.
Set two-way check valve. Remove the tree.
Install and test BOP's. Pull two-way check valve.
Pull the 5-1/2"x 3-1/2" 17# L-80 PC tubing completion.
Test 9-5/8" packoff in the Gray wellhead to 3000 psi. Replace it and tubing head if
necessary.
RIH and position cement retainer @ 8030'md (200' md below estimated milled
section). POOH.
RIH w/section mill and spot 100' md of 17 ppg high vis. pill on top of cement
retainer. POOH to 7730' md and section mill 60' md of 9-5/8" intermediate casing
to a depth of 7830' md.
Set a cement kick-off plug from 100' below base of section to 200' above top of the
section.
Run in the hole with a steerable, directional drilling assembly and dress off the
plug to 5' below top of section.
Kickoff through the milled section and directionally drill to TD of 9186' TVD
approximately 440' departure northwest from the current BHL.
Run wireline conveyed open hole (GR/DIL/CNI_/BHCS) logs.
Install and cement 7" L-80 / 13CR liner from TD to 250' above top of the section.
Clean out liner to PBTD, displace well to inhibited, filtered seawater (if unable to
displace cement with seawater) and test to 3000 psi.
RIH with 4-1/2" 13CR completion assembly. Space out and land tubing hanger.
Drop packer setting ball and pressure tubing to. set 7" 13CR production packer.
Test tubing to 3000 psi. Test tubing x casing annulus to 2500 psi. Pressure
annulus to shear RP reverse circulating valve.
Set two-way check valve. Remove BOP's.
Replace tree and test to 5000 psi with diesel. Pull two-way check valve.
Displace dielsel/or other freeze protection fluid) down annulus and U-tube into
tubing to freeze.protect to a depth of 2000' MD.
Set BPV. Release rig.
Well will be perforated using wirline conveyed guns through tubing after rig has
moved off of location.
Anticipated BHP: 7.8 ppg equiv. Drilling Fluid: 9.5 ppg Workover Fluid' 8.5 ppg.
PRELIMINARY WELL PLAN
WELL' DS 7-4A Redrill
PBU
APl No.: 50-029-20292-00 (on the original 7-4 well)
LOCATION: Surface: 1685' FNL, 68' FEL, Sec. 33, T11N, R14E
Target: 1018' FNL, 1477' FEL, Sec. 33, T11N, R14E @ 8759' ssTVD
BHL: 806' FNL, 3117' FEL, Sec. 33, T11N, R14E @ 9118' ssTVD
ESTIMATED START: 20 August, 1992
OPR. DAYS TQ COMPLETE: 14 (4 days prep & mill, 5 days drill, 5 days complete)
CONTRACTOR: Doyon Rig #16
DIRECTIONAL: Kickoff at 7800' MD. (18.27 degree angle build and 28.30 degree
north turn.)
WELLBORE:
Item TVD(BKB) MD{BKB) Mud Wt.
20" CONDUCTOR 110' 110' N/A
13-3/8" SHOE 2724' 2724' N/A
KOP 7640' 7800' 9.3
TOP SAG RIVER SANDSTONE 8463' 8863' 9.5
TOP SADLEROCHIT 8564' 9004' 9.5
TOTAL DEPTH 91 86' 9872' 9.5
LOGGING PROGRAM:
8-1/2" Hole: DIL / GR / BHCS / CNL
,MUD PROGRAM'
The milling/drilling fluid program will consist of a 9.3 - 9.5 ppg XCD polymer / KCI water
based mud in the 8-1/2" hole.
DEPTH
CrVD)
7800'
to
9185'
DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD
(PPG) fCP) (#/FT~GEL GEL cc/30min f%1 f%1 TYPE
9.3 10 10 5 7 8 0 5 Water
to to to to to to to to Base
9.5 16 18 10 15 5
JUN ,~ 0 1992,
Alaska 0il & Gas Cons. 6ommissiO~
Anchorage
MUD WEIGHT CALCULATIONS / WELL CONTROL:
Mud Wt. (8-1/2" Hole): 9.5 ppg.
Est. Pore Press. Sag River:
Est. Pore Press. Sadlerochit:
4075 psi/8628' ss TVD.
3545 psi/8800' ss TVD.
Overbalance Sag River:
Overbalance Top Sadlerochit:
224 psi.
800 psi.
Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular
preventer will be installed and will be capable of handling "worst case" situations as
follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based
upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based
upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss.
Fluids incidental to the drilling of a well will be removed by truck and disposed down
CC-2A.
LINER DETAILS:
CASING DEPTH
7" 26# 13CR-80 FOX
7" 26# L-80 IJ4S
9872'-8563' MD
(9185'-8241' TVD)
8563'-7620' MD
(8241' -7478' TVD)
CEMENT CALCULATIONS;
7" LINER:
Measured Depth:
Basis:'
Bt,JRST COLLAPSE TENSILE
7240 psi 5410 psi 604 klbs
7240 psi 5410 psi 567 klbs
7620'MD (Hanger)- 9872'MD (Shoe)
Total Cement Vol:
35% open hole excess, 80' shoe joints, 150' liner lap and 200'
excess above liner with DP.
452 cu ft or 390 sxs of Class G blend @ 1.16 Cu ft/Sk
TUBING DETAILS: 4-1/2" 12.6# 13CR-80 Fox (0'- 8900' MD)
DOYON RIG NO. 1t~
MUD SOLIDS CONTROL EQUIPMENT
1 - Continental Emsco Fl000 Mud Pumps
1 - Brandt Shale Shaker
1 - Mud Cleaner
1 - DRECOGas Buster
1 - Pioneer Sidewinder Mud Hopper
1 - 5 H P Flash Mixer Agitator
3 - Abcor 10 HP Agitators
1 - 50 bbl. Trip Tank
1 - Recording frilling fluid pit level indicator with both visual
and audio warning devices at driller's console.
1 - Drilling fluid flow sensor with readout at driller's console
RECEIVED
JUN
Alaska Oil & Gas Cons. t;ornr~issiO~'
Anchorage
GA £ LAND DIRECTIONAL DRILLING,
Corporate Office
1111 East 80th Avenue
Anchorage, AK 99518
(907) 349-4511 Fax 349-2487
DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING
Well ......... : DS 7-4A (DOG LEG 4)
Field ........ : PRUDHOE BAY DRILL SITE 7
Computation..: MINIMUM CURVATURE
LOCATIONS
FROM WELL HEAD
Surface ...... : 1685 FNL 68 FEL S33 TllN R14E UM
Tie-in ....... : 1656 FNL 697 FEL S33 TllN R14E UM
Target ....... : 1018 FNL 1477 FEL S33 TllN R14E UM
TD ........... : 806 FNL 3117 FEL S33 TllN R14E UM
676146.0
675516.0
674720.0
673075.2
PROPOSED WELL PROFILE
Prepared ..... : 06/24/92
Section at...: N,47.47,W
KB elevation.: 67.00
5949239.0
5949254.0
5949873.0
5950047.2
STATION MEAS INCLN
IDENTIFICATION DEPTH ANGLE
VERT-DEPTHS SECT
BKB SUB-S DIST
TIE-IN 7800 26.00 7640 7573
7900 28.51 7729 7662
8000 31.31 7815 7748
BASE HRZ 8023 32.01 7835 7768
8100 34.32 7899 7832
END OF CURVE
JURRASIC B
SAG RIVER
SHUBLICK
SADDLEROCHIT ZONE 4
SADDLEROCHIT ZONE 3
SADDLEROCHIT ZONE 2
TARGET
GOC
TOP HOT
SADDLEROCHIT ZONE 1
OWC
KAVIK
TD
DIRECTION REL-COORDINATES
BEARING FROM-WELLHEAD
DL/
100
484 N 75.50 W 30 N 629 W <TIE
525 N 68.69 W 44 N 673 W 4.0
573 N 62.95 W 64 N 718 W 4.0
584 N 61.83 W 70 N 729 W 3.9
625 N 58.09 W 91 N 765 W 4.0
8200 37.50 7980 7913
8300 40.81 8058 7991
8400 44.20 8132 8065
8402 44.27 8133 8066
8599 44.27 8274 8207
683 N 53.95 W
746 N 50.37 W
814 N 47.25 W
815 N 47.20 W
953 N 47.20 W
124 N
162 N
207 N
208 N
301 N
814 W 4.0
864 W 4.0
914 W 4.0
915 W 4.0
1016 W 0.0
8863 44.27 8463 8396
8903 44.27 8492 8425
9004 44.27 ' 8564 8497
9264 44.27 8750 8683
9370 44.27 8826 8759
1137 N 47.20 W
1165 N 47.20 W
1235 N 47.20 W
1417 N 47.20 W
1491 N 47.20 W
427 N
446 N
493 N
617 N
667 N
1151 W 0.0
1172 W 0.0
1224 W 0.0
1357 W 0.0
1411 W 0.0
9370 44.27 8826 8759
9381 44.27 8834 8767
9667 44.27 9039 8972
9671 44.27 9042 8975
9722 44.27 9078 9011
1491 N 47.20 W
1498 N 47.20 W
1698 N 47.20 W
1701 N 47.20 W
1736 N 47.20 W
667 N
672 N
808 N
810 N
834 N
1411 W 0.0
1417 W 0.0
1563 W 0.0
1565 W 0.0
1591 W 0.0
9798 44.27 9133 9066
9872 44.27 9186 9119
1790 N 47..20 W
1841 N 47.20 W
870 N
905 N
1631 W 0.0
1668 W 0.0
(GLDD (c)92 DS74A4 B1.33 7:33 AM 2)
P~JDHOE BAY DRTL~_ING
DS 7-4A (DOG LEG 4)
VERTICAL SECTION VlEN
Section at: N 47.47 W
TVD Scale.: ! inch = 300 feet
Dep Scale.: ! inch = 300' feet
Drawn ..... : 06/24/92
Breat Land DJrectJona]
~arker Identification HO 8KB SECTN INCLN
Al TIE-IN 7800 7640 484 26.00
BI END OF CURVE 8402 8t33 815 44.27
C) TARGET 9370 8826 t49t 44.27
DJ TD 9872 gtB6 184! 44.27
~ . 'r ~ ~ t ' · . , ' i :' ' r . · . ~ ' , . .............. i ........
..'i-:!: ~::::J..i.:.i:.':::..i_ '.~-.: t_::!~,!~_tc:.'.'! X'.:' I':'i.~-:j :~::i:':~.;'. J ;i't z.:i::.l:~ .: ~' .! :i'....~.: .i:-!:~::.J:-i:'L t.'.: :.'/-_!..-. i 't:L:. l'~:~.' 2!':i'.' zz:.':'L 27'..i :.!::i..
' ; ~ ' L~ ' ' ~ ' ' ' :" ..... -1- : ' ; t ' ' .... ~ i ..... / ; ~ : ....
'~:~---.~',~,,-- 7..: .-[?..-.: .-':~:: ,-'? ~.-.-..-._-':7 F....,...-~ -': -"~"q.': -.-., l -- -~--.---..'. ;' .'" ':: :' --FY-." .':..7 _q.'.;-'..:_.;.-./ .... : ..... ;.--t i.-;.--;-. I .... : ...... i--:-'~ :-':-'
-:--~ .... :-4---.-+-! .... :---i.-; .... :,---: ........ !-~ F:.~---:-i .... :.. :..t-m .... :" I-- ;-i-c-.!-..'. ...... ;-"/- '-~'-;--':--i-"-, ........ !' "'-'I: ':''''::
.-r----:-. T,-t-:-:- . , .---~--', '~ . , j , : , ~---- --~7~--~ . ----.-~---. ~-,--~-
-,.-. :~-.~ .... :--~--~-~..~.,,- ..... :-i :. ::: i--!- f-t:::'i.~": AVERAG:E':-ANGLE":' ,~4:-::27: den.:..:..:_:.:,
-',:...i._ :.:.i..i~..!:.?~i...~:~T~.¢~...:`.!:.:..~i~i~.~``:`¢:..~!~.!.~!...~!!?Ti.:-~..~...! :--. :--: i~--..:~ .:.-!. ~..:::._..: t..:-'.:.--"':':. !. :'-':'--:-.':~ :'-:-~:. !'
~m~r~z~-~-: .... l'---';-i-~,.i,,.-.-'X,-,--.--I--.-.-'.-l---.:'-7-.-.-.7 --i .......: .... 1 ........ :"!" ': .....
: .' ' ; : ! ."~ '-~ ....., ...... ~, .... T' 'i ........... ' ' ; ' ' - . ............
:~... ! .-T' i .,,,~, .... ,: .......... ~:: ~ ...... t--....,i ........
.:!..~.:i' '.i..';" i.:'i /!.'.!i!.' i '"': . "-' i i i-F .i.i
~-~'~ -' '-'~-'--'- '-"-' ' i'-'"-' '-"'-:': -'-':" '- -~ -"- h- '- %-"'-'"'"--~ :'" I ' '-'"-- ' '--"'--:"-'- '-' -"- q~---" '-' '----'-~
"~"- -~-~ :- .... i ........... t- - - - ~~- -- --. - -.- F - - ' -. "q .... l - -. -.--- t' ..... I- :.- - -': ....
~r~--~r~-.---- ----.--------- -~--h--'- ....... '-'' .... '--: ......... .- ............. ''' ~
c-i- .. i' ' ' i
- ~ .......... ~ .................... :.-' ...... :--::----. '. i:~-'..::'-.~'::.-:'.:-: ¢.':-'--'--::-~-.: :'~.:::.'i-':-'.: ': :' t': :" :; ": .... -:'~.:-:i .... : ......
· -t~-[ ...... ; ................. t ................... ? .................. ; .............. i .................... f .........................
,o,oo. - ......... :-'i-:--: .... , "':"'I .... :: ........ I ........ :...'.'::--"'I ..... : .......... : .... I':-': ....... ! ........... I ............. :': .... I ...........
400 550 701 850 tO00 iiSO t300 i450 i600 i750 i900 2050 2200 2~50 2500
Section Departure
P,,JDHOE BAY DRIL IN8
B) ~ ~ C~VE 840a ~08 ~ gt5 ~
C) TARGET 9370 667N t4tt~ PLAN VIE~
D) TD 9872 905 N t668
CLOSURE · t898 ft
DECL[NAT[ON· 30.00 E
SCALE · t ~nch = 300 fee[
DR~N ' 0~/2~/~
~reat Land DJrec~JonaJ
.~,., . . , , , , ,, , ,
RE' IVED
JUN ~ 0 199~
Alaska Oil & Gas Cons. Oomm[Ssm~
Anchorage
.
.
~.-:. ~.. .~ ......~ ~ ......~ ~ .....~ ~ ........ ; ...............
~::::':.:::~:: ~:~ .... ~.-~.... :~. :~ ..... . .~-:.
~ - -~200
..... : ..... · ~ ~ ,
~ ,[ ~ .... ~ . . . , ........
~ .....
.........
................................................. . ! ...................................... : ...... t050
1
.............. ' ........... : ........... ~ ...... ' ............................. ~ ............................. ~50
~ . . : .... 7. XXX ~ [ ~. . ~ ~.'... '...'~. '~ ~".
· ~ - . i ' /-- ;-~ ". I .-., ~~,
,, , ' I ..... .. ,,.i,-,. :,'. I "'I" i..
t950 t800 t650 t500 t350 t~00 1050 900 750 800 450 300 150 0 150
<- NEST · EAST ->
...... ,
' "~0 Alaska Ir'~. - Prudhoe Boy Field
,.
W~ 7'4 ,' '~¢: ,50-(Z2~202<;'2-03 W ype: Producer
Spud Date: 8-27-78 ,n~etlof3 Date: 9-18-88 New r-I Workover []
Oflglnal RKBE: 64' Har~e~ Type: Gray Hanger: 28'
'-. Top of Sadlerochlt: . 8789" ' Max Hole Angle:3C~ @ 6988'MD Angle ~ Top Sad. :24"
.Ann Fluid:Diesel/8.4 ¢5'W Reference Log: BHCS 9-10-78 Angle @ TD: 26°
·
All De re RKB Drilllng MD to Top of Equipment except where notecl.
Casing and Tubing
3 Size_ Weight Grade Z.9..E Bottom DescrlDtlon
'- 1 13 3/8' 72,~ N-80 0 2724' But1 Csg
2 9 5/8' 47¢ N-80 0 8206' Butt Csg
4 9 5/8' 47# S-95 8336' 9519' Bull Csg
5 1/2' 17~ L-80 0 44' IPC Tbg
3-1/2' 9.3# L-80 44' 9248' IPC:
,4 H Jewelry
3 44' Crossover 5-1/2 X 3-1/2
4 2223' 3-I/2' Camco TRDP-1A-SSA SSSV Nipple ID .-2.812'
5 8761' ELM TE-Meda Tubing Patch - Top Element @ 8764'
6 8~)2',,, Baker PBR Assembly
7 §78t'~' BaT 'HB' Packer
11 8 8855' Bast Joints Length=39' ID=2.992'
9 9083' I~ost Joints Length=98' ID=2.992'
10 9 ] 91' Dost Joints Length=39' ID=2.992'
5
4~'" 6,7 1] Gas Llft Information (Valve Change Date: 8-12-89 )
, Depth
'8 MD. TVD ~ Vlv Type
2771' (2771') i CA-MMG CA DUM EK
;. 9 4641' (4640') 2 MC1FMHO MC DUM BK-2
6048' (6046') 3 MC lFMHO MCDUM BK-2
· 694(7 (6883') 4 MC1FMHO MC DUM BK-2
12,13 78]0' (7649') 5 MC1FMHO N4CDUM BK-2
10 8333' (8127') 6 MC:IFM~ MC DUM BK-2
8641' (8413') 7 CA-MMG CA EKED EKP
14 12
15,16
Production Mandrel Info (VALVE CHANGE DATE: 3-30-91)
Depth
MD TVD ~,tn. Mandrel VlvZ,Y..E..~ Latch Port Sz. TRC) Date
9182' (8905') 8 CA-MMG TE ED-15R R K 03-30-91
17
14
15
"16
17
18
Perforation Data (ELM Depths)
Inte~al Zone FT SPF
8855 Hole in csg.
9105-9125 2 23 0
9156-9182 2 25 0
9203-9~1 2 31 8
Date Comments
9-17-88 Discovered
9-7-84 CTU Sqz
9-7-8.4 CTU Sqz
10-21-84 RPERF
Jewelry
9237'
9246'
9247'
9248'
9246'
Baker "DB" Packer
Offs 'XN' Nipple ~ ID=2.750"
Bake¢ Shear Out Sub
Tubing Tall
ELM Tubing Tall (4-23-90)
Minimum ID: Otis 'XN' Nipple NoGo ID=2.750"
Perforation Data (ELM Depths)
Interval Zone FI' SPF
9248-9272 2 24 4-1/2
9272-9279 2 7 6
9298-9318 18 23 6
Date Comments
9-17-88 RPERF
9-17-88 Aperf
9-17-88 Aperf
PBTD = 9463'
TD - 9535'
DcTtum
8700' SS = 9024' MD
8800' SS = 9136' MD
Revision Date: 9-25-91 by RJR
Reason: Teledyne Merla Tbg Patch Installation
Previous Revision:8-2-91
ALASKA OIL AND GAS CONSERVATION COMMISSION
Russell A Douglass
Commissioner
June 13, 1992
Michael T Minder
Sr Petr Eng
· .
CASING ANO TUBIHG OESIGN
CASI~ SIZE
7.'i
/!
'7
HYO cP. z 6,~/9f pst/rt.
HUD WT. Ii
0.50 PSI/FT GRADIENT ON OUTSIDE, VOID ON INSIDE FOR COLLAPSE
0.$0 PSI/FI GRADIElqT ON INSIDE, VOID ON OUTSIDE FOR BURST
INTERVAL DESCRIPTION
Bottom Too LENGTH Wt. Grade Thread
~ e's'~,~ ~o~ '2_.L~st' l~C..~-~ _ Fox_
/
7¥7B
~/q. HYO. GR. II psi/ft.
WEIGHT
W/ BF
W/O 8F Tr
lbs
TENSION MINIMUM coLLAPSE
-top of STRENGTH 1,25'" PRESS. Q
section TENSION bottom
lbs 1000 Ihs ,TDF, _psi
CCI. LAPSE INTERN~I.
RESIST. BURST MINIMUM
) ,oo
tension ~') ~ PRESSURE YIELD
psi CDF psi psi BOF
ITEM
(1) Fee
....
(2) Loc
, ,
** CHECK LIST FOR NEW WELL PERMITS **
APPROVE DATE
[ 2 -thru
[9 thru 13]
[10 & 13]
(4) Casg ~..~,,~.~4/,, 7- l- ~ Z.~
[14 thru 22]
(s) B0 E -¢m
[23 thru 28]
Company,
YES NO
1. ~ ,,,
3.
4,
6. Is well to be deviated & is wellbore plat included
7 Is operator the only affected party ................
8 Can permit be approved before 15-day wait.
e
10.
11
12.
13.
14.
15.
Lease & Well
16.
17.
18.
19.
20.
21.
22.
23.
24.
25
26
27.
28.
Is permit fee attached ...............................................
Is well to be located in a defined pool ..............................
Is well located proper distance from property line ...................
Is well located proper distance from other wells .....................
Does operator have a bond in force ...................................
Is a conservation order needed ....................................... . ....
Is administrative approval needed .
Is lease nLmber appropriate .......................................... L ..
Does well have a unique name & n~nber ................................
Is conductor string provided ......................................... ~ .....
Will surface casing protect all zones reasonably expected
to serve as an underground source of drinking water ..................
Is enough cement used to circulate on conductor & surface ............
Will cement tie in surface $ intermediate or production strings ......
Will cement cover all known productive horizons .....................
Will all casing give adequate safety in collapse, tension, and burst. ~ .....
Is well to be kicked off from an existing wellbore ...................
Is old wellbore abandonment procedure included on 10-403 .............
Is adequate wellbore separation proposed .............................
Is a diverter system required ........................................
Is drilling fluid program schematic & list of equipment adequate .....
Are necessary diagrams & descriptions of ~~ BOPE attached. ~ ,.,
Does BOPE have sufficient pressure rating -- test to ~o psig..
Does choke manifold comply w/API RP-53 (May 84) ......................
Is presence of H2S gas probable ......................................
REMARKS
, ,
Other /~/~/'~ thr~~~
-['29
E32 ]
Ad d 1 ,,~.~."~.
29.
30.
31.
32.
33.
FOR EXPLORATORY & STRATIGRAPHIC WELLS'
Are data presented on potential overpressure zones ...................
Are seismic analysis data presented on shallow gas zones .............
If offshore loc, are survey results of seabed conditions presented...
Name and phone nt~er of contact to supply weekly progress data ......
Additional requirements .............................................
0
-rZ
geology'
DWJ
R PCA~£rC
rev 04/92
jo/6.011
eng i neet i hq:
M TM.,/~.g LCS_____
BEW ~-~,
INITIAL GEOL UNIT ON/OFF
POOL CLASS STATUS AREA ~ SHORE
,,
Add i t i ona 1
remarks:
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.
T° 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.
chlU~berger ,AlasKa Comput~nn Center
20:4t
DS
500292029201
ARCt) ALASKA, I~C,
SCHLUNBERGER ~Ebb 8k',~'VIC~S
25-d~Jb-9~
i 1. ~',~
!4~
1~84
~7
~4 . UA
3t~, UO
PAGE: 1
RECEIVEI)
JAN 0 5 1995
Alaska Oil & Gas Cons, Oommission
Anchorage
IS w~ve ~er!fi..cat~on Li. sti. n<~
9620,
956 ~4.0
9~55,C~
95~5.~
95O !, O
95O0.5
946 ~:, 0
94 ~ 7.5
946 '{, O
9430 ~
9~57.5
92~14,0
9~3Q.5
915~.~
9151,0
91~a,5
.9!46.0
9!25,0
908~,n
907 ¢ .
90t~.0
100,0
!
ALE NT
9626,0
956.~.~
955~,5
95~5.5
9499o~
9499,0
9466,5
94.66,5
9463,0
94~1,~ 94.6~,5
9430,5
9~30. ~
9375.5
9357.~
932g.5
9276.0 9~76.0
925~,g 925~,5
9~3~,0
9~59,5
9157.0
9140,5
9t46.5
9146,5
9!26.0 9126,~
908~o0
9n6~.n
9047.O
9024.5
26-0CT-1994 20:.{i
26-0CT-1996 2~14I
~e~th shifte~! and c!.i.P~::ed curves for each oass in separate files,
t
0,5OO0
FTL? SU~iAR¥ Lu G
aRCH
965¢2,0
STOP DDPTH
9000.0
C!~a'Vg S~I~"T O,aT~~ - ~A~S Tn r, igS(~-'~Yl,ASUttEn DEPTH) PASfi:!,!.~g CURV~.] FOk, SHIFTS
,, ~. ~'~ %
Pg~-~APgS: T~IF FiLE CC~4TATNS ~ASS ~i OF~ THE CN'.fO. NO PASS TO PASS
5~iF:!:f ~,F~i~.: APpr,IF'i~ TO Thlb DIT~.
"[~i~. T VAI Ij DE?'I
C~ ~PC~ ~.b~SKA, ~.~C. Comoa~V Name
F~,: PRUphOE B~Y Field ~:ame
w~; 9S 7-4A ~ell hame
A~I~ 5n-a2q-~O~9~-Oi APl Serial
IS ~'ave yerlficat...ton Listino
~ield [ tlon
~ . ~OCa
Sect~ion
Township
RaDqe
County
State ~r prov~nce
Nation
~itness Name
Service Order Number
Per~anent ~atu~
Elev~tion o[ Permanent Datu~
Lo~ ~easure~ From
Above Permanent Datum
Elev~t.l..o~ oi Kelly Oushinq
Elevat~.o~ of Derrick Floor
Elevation ni Ground Leve!
Total Depth - Driller
Total Demth
Bottom b°o I~terval
ToD Loo I~terval
Drilling Fluid ~ype
Time Loqoer at Bottom
DVp'n ~e~th
NPHT Com[::ensate~ ~.~eutro~ ~orosit. y, S8 ~':~.atri~, cal~. & dead. time corr.
;~A~ ~.~eut;,ro~ ?ation ~on-bead time Corrected
C~AT ~eutron P~)tl.o, I3eaa ~ime Corrected
~c~w ~aw ~:~ear O~t~ctor Count ~ate, ~,eao T!me Corrected
FC~T P~,? ~a~' ~>etector Count rate, Dead Ti~e Corrected
CVIC Corrected War r, etector Count ~ate
C~".?C Corrected '-~ear Detector Count ~ate
CCL CC! Av':nlt
~P~-Corrocte~ Cam~-,a
Tape Yerlficat!o. T~ist.in~
c~lumberger A!esKo C.o~p~.~tin~ (~enter
20:41
2 66 0
3 73
4 66
6
6~ 0,5
1,3 66 0
16 66
¢ 66
F? 485~.,
AN * *
' .... X ..... '''''''''''''''''''''''''''''''''''''''"'' .... '''
AOl PT APl. APl PI!.~E NUMB t~iB SlZ~ .,EPR P~OCESS
00 o !. I ! 4 0 0o00000
000 00 C; 1 ! 1 4 68 0000000000
OOn O0 0 !, 1 I 4 68 o000000000
OOn 00 u 1 1 ! 4 68 0000000000
00o O~ 6 !. 1 ~ 4 68 0000000000
00~ O0 0 ! 1 ~ 4 68 00~0000000
oon O0 0 I 1 1 4 6~ n(}O0000000
oOn O~ (, I ~ ! 4 68 (?0000000~0
(~00 O0 O ! ! 1 4 6~ 0000000000
aon oo o i 1 !. 4 68 ooo0ooo0oo
aon t)n 0 I ! 1 4. 68 O000000000
oCo On t, ! ! ~ 4 66 oO00noo000
/',i C ~'~' C
GPCU. Ci~rl~
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PAGE:
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Tape Ver!~iicatJon l:,isti..ncz
cbll.~mberqer .41asKa Co~pt.lt!nG Center
26-0CT-!994 20:4I
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2~-QCT-~9~4 ~0:41
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Total DePth - Loo~er
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T~E~,E '!'Yg'~i : CbPV
Con'.r, onsated ~,'eutro. Oorosity, SG ~!atrix, cal!& dead time corr.
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~.;e~trom Patio, Dead ~ime Corrected
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Corr~cte.'~ var Detector Count Rate
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Elevat~.~on oi :Kelly B~1shimQ
Elevation o~ ~errick Floor
Elevatlom o~ Ground Level
Total DePth -Drlller
Total DePth - LoQ~er
Bottom Lo~ IDterva!.
TOD 5oQ Interval
Dr~l!inq F]u~d Type
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NPH~ Co~,l.?er~sated ~e~.lt:ron PorositV, s~ ~<~atri~, cali g dead time corr.
t~PAT ~e:.]tro~ Patlon ~:on-i::ead time corrected (~,/F)
CPAw t,~e~ rom Patio,
~;ci,:T ~aw ,~ear Detector Couht ~ate, Dead Ti~e Corrected
C~'TC rerr,cted ~ar Detector Count ~ate
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CCi, a~nl
I=,~ ~aoe,. Veri. f~catlo~
cblumberger Alaska Co~'~)ut,ir~O center
26-~CT-1994 20;4:!
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FI, l~Ta' ~'t~b & 67' FFL Flel~ I~ocation
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26-0CT-! 9~4 20:al
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STA'r ALASKA
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fi~AT ~;eutron Pation Non-Dead time Corrected (N/F)
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aC[,i~ Paw ~.!ear Detect. or Count Pate, Demo Tii~e Corrected
FCa~' ~a~, ~'ar T~etector Count; rate, Dead ~ime Corrected
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C~'.rC Corrected ~ear !)erector Count ~ate
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765.280
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{ch!u~ber~er Alaska Co~,putino Center
S-OCT-1992 !3:24
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12
S;~vlCE : ~blC
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t,~i~,X REC SIZE : ~024
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