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HomeMy WebLinkAbout215-124Guhl, Meredith D (DOA)
From: Guhl, Meredith D (DOA)
Sent: Monday, September 11, 2017 12:02 PM
To: 'Lastufka, Joseph N'
Cc: Davies, Stephen F (DOA); Loepp, Victoria T (DOA)
Subject: Expired PTDs: PBU S-04A PTD 215-111 and PBU U-06131_1-01 PTD 215-124
Joe,
Permit to Drill 215-111, for PBU S-04A, issued 14 July 2015, has expired under the Regulation 20 AAC 25.005 (g).
Also, Permit to Drill 215-124, for PBU U-06131-1-01, issued 27 July 2015, has expired.
The two PTDs will be marked expired and updated in our database. Please update BP Exploration (Alaska) databases
also.
If you have any questions, please contact me.
Thank you,
Meredith
Meredith Guhl
Petroleum Geology Assistant
Alaska Oil and Gas Conservation Commission
333 W. 7th Ave, Anchorage, AK 99501
meredith.guhl@alaska.gov
Direct: (907) 793-1235
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 fort he 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 Meredith Guhl at
907-793-1235 or meredith.guhl@alaska.gov.
a 16 tay'6
Carlisle, Samantha J (DOA)
From: Loepp, Victoria T (DOA)
Sent: Wednesday, September 09, 2015 10:11 AM
To: Davies, Stephen F (DOA); Carlisle, Samantha J (DOA)
Subject: FW: PBU U06-BL2(PTD 215-124)
Steve, Sam
Please handle this name change.
Thanx,
Victoria
From: Lastufka, Joseph N [mailto:Joseph.Lastufka@bp.com]
Sent: Tuesday, September 08, 2015 11:05 AM
To: Loepp, Victoria T (DOA)
Subject: RE: PBU U06-BL2(PTD 215-124)
Victoria,
We submitted a Permit to Drill (U-06131-2 PTD #215-124) which we labeled incorrectly. The wellname should have been
U-06131-1-01 as it is a lateral from L1.
Please let me know if you have any additional questions.
Thanks,
Joe
From: Loepp, Victoria T (DOA)[mailto:victoria.loepp@alaska.gov]
Sent: Tuesday, September 08, 2015 10:45 AM
To: Lastufka, Joseph N
Subject: PBU U06-BL2(PTD 215-124)
Joe,
Please send email outlining the name change you are requesting-
Thanx,
Victoria
Victoria Loepp
Senior Petroleum Engineer
State of Alaska
Oil & Gas Conservation Commission
333 W. 7th Ave, Ste 100
Anchorage; AK 99501
Work: (907)793-1247
Victoria. Loepp(o)alaska.gov
THE STATE
of
ALASKA
GOVERNOR BILL WALKER
John McMullen
Engineering Team Leader
BP Exploration (Alaska), Inc.
P.O. Box 196612
Anchorage, AK 99519-6612
Alaska Oil and Gas
Conservation Commission
333 West Seventh Avenue
Anchorage, Alaska 99501-3572
Main: 907.279.1433
Fax: 907.276.7542
www.aogcc.alaska.gov
Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU U-06BL2
BP Exploration (Alaska), Inc.
Permit No: 215-124
Surface Location: 103' FSL, 1663' FEL, SEC. 18, T11N, R13E, UM
Bottomhole Location: 3888' FNL, 4172' FEL, SEC. 24, T11N, R12E, UM
Dear Mr. McMullen:
Enclosed is the approved application for permit to re -drill the above referenced development
well.
The permit is for a new wellbore segment of existing well Permit No. 205-064, API No. 50-029-
21117-02-00. Production should continue to be reported as a function of the original API
number stated above.
This permit to drill does not exempt you from obtaining additional permits or an approval
required by law from other governmental agencies and does not authorize conducting drilling
operations until all other required permits and approvals have been issued. In addition, the
AOGCC reserves the right to withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the
Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to
comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska
Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit.
Sincerely,
Cathy . Foerster
Chair
DATED this 2.-? day of July, 2015.
STATE OF
ALASKA OIL AND GAS CONSERVAT ON COMMI JUL 2 0 2015
PERMIT TO DRILL
20 AAC 25.005
1 a. Type of Work:
1 b. Proposed Well Class: Development -Oil 0 Service - Winj ❑ Single Zone ,0
1c. Specify if well is proposed for:
Drill ❑ Lateral ' [a
Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Colabed Gas ❑ Gas Hydrates ❑
Redrill ❑ Reentry ❑
Exploratory ❑ Service - WAG ❑ Service - Disp ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond ' Blanket 0 Single Well ❑
11 Well Name and Number:
BP Exploration (Alaska), Inc
Bond No. 6194193
PBU U-06BL2
3 Address:
6. Proposed Depth:
12. Field/Pool(s):
P.O. Box 196612 Anchorage, AK 99519-6612
MD: 14500' TVD: 8936'ss
PRUDHOE BAY, PRUDHOE
OIL
4a. Location of Well Governmental Section):
( )
7. Property Designation (lease Number):
ADL 028283 & 047451
Surface: 103' FSL, 1663' FEL, Sec. 18, T11N, R13E, UM
8. Land Use Permit:
13. Approximate spud date:
Top of Productive Horizon: 2766' FNL, 2088' FEL, Sec. 24, T11 N, R12E, UM
September 20, 2015
9. Acres in Property: 2480 & 2560
14. Distance to Nearest Property:
Total Depth: 3888' FNL, 4172' FEL. Sec. 24, T11 N, R12E, UM
22000'
4b. Location of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL: 76.63' feet •
15. Distance to Nearest Well Open
to Same Pool:
Surface: x- 632339 ' y- 5960690 Zone - ASP4
GL Elevation above MSL: 47.5' feet.
1150'
16. Deviated wells: Kickoff Depth: 11955' feet
17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 95 degrees
Downhole: 3384 Surface: 2490
18. Casing Program:
Specifications
Top - Setting Depth - Bottom
Cement Quantity, c.f. or sacks
Hole
Casing
Weiqht
Grade
Coupling
Length
MD
TVD
MD
TVD
(including staqe data)
3-1/4"
2-3/8"
4.6#
13Cr80
Hvdril 511
3159'
11341'
8666'ss
14500'
8936'ss
172 sx Class'G'
19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
Total Depth TVD (ft):
Plugs (measured):
Effect. Depth MD (ft):
Effect. Depth TVD (ft):
Junk (measured):
1
15229'
9020'
None
14316'
8956'
None
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
80,
20" x 30"
8 cu vdds Concrete
31' - 11 V
31' - 111'
Surface
2646'
13-3/8"
3746 cu ft Permafrost'E' and II
31' - 2677'
31' - 2677'
Intermediate
2930'
9-5/8"
1740 cu ft Class'G', 279 cu ft PF
28' - 2958'
28' - 2958'
Liner
8749'
7"
1420 cu ft Class'G'. 196 cu ft Class'G'
2786' - 11535'
2766' - 8866'
Liner
3044'
4-1/2"
730 cu ft Class'G'
11361' - 14405'
8756' - 8961'
Perforation Depth MD (ft):
See attachment Herroration Depth I VU (ft): See attachment
20. Attachments Property Plat ❑ BOP Sketch 0 Drilling Program Q Time v. Depth Plot ❑ Shallow Hazard Analysis ❑
Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program 0 20 AAC 25.050 requirements 0
21 Verbal Approval: Commission Representative:
Date
22. 1 hereby certify that the foregoi is true and correct. Contact Ciolkosz, Rvan R
Email Ryan. Ciolkosz(a)bp.com
Printed Name Jo Title Engineering Team Leader
Signature Phone +1 907 564 4711 Date ZO /"
7
Commission Use Only
Permit to Drill
Number: 1 l G,
API Number:
50-029-21117-61-00
Permit Approval
Date:
See cover letter for other
/
requirements:
Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Q__�
Other:.30p f« r f O 3 j Oil fj5 / Samples req'd: Yes ❑,/ No QtMud log req'd: Yes ❑ No B-1
��1i' / -Sf Z�H23 measures Yes No El Directional
Directional svy req'd: Yes B' No El
Spacing exception req'd: Yes ❑ No CK Inclination -only svy req'd: Yes ❑ No IS'
APPROVED BY
Approved by: COMMISSIONER THE COMMISSION Date:7.2-7_IS
ORIGINAL"" 7-1,74 / '5-
Form 10-401 Revised 10/2012 This permit is valid for 24 months from the date of approval (20 AAC 25.005(g)) Submit For, and
Attachments in Duplicate
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To: Alaska Oil & Gas Conservation Commission
From: Ryan Ciolkosz Rig: Nordic 1 bp
CTD Engineer Target Reservoir: Ivishak Zone 4
Date: July 15, 2015
Re: U-06BL1&L2 Permit to Drill Request
History and current status: U-06B was completed in 2005. It has produced over 1.5MMBO and is currently
producing 100-150 BOPD at 96% WC. There are two separate prospects that are recommended to be added
as laterals to improve ultimate oil recovery of this wellbore yet allow remaining reserves from the current
wellbore to continue producing.
Proposed plan: Dual lateral completion in Ivishak Zone 4 while preserving parent bore production. Set
whipstock in current U-06B perforations. Sidetrack out of the 4-1/2" liner and drill U-06BL1. Set 2-3/8"
slotted liner with liner top Billet. Open hole sidetrack of liner top billet and drill U-06L2. Run 2-3/8" solid liner
and cement in place below sidetrack point. Perforate U-06L2 and produce U-061_1 through U-06B annulus.
CTD Drill and Complete U-06BL1&L2 program: Rig Start Date: Sept 20'h, 2015
Pre Rig Work
1.
S
Dummy GLV's, MIT -IA. Drift to deviation with 2.60" Centralizer
2.
F
A/SL: Load IA. MIT -IA
3.
C
Mill out XN Nipple to 3.74" ID with LH motor/mill assembly and drift assembly to
11,900' MD. Drift to 11,900' MD with whipstock drift.
4.
V
Pre CTD Tree Work. Set TWC
Rig Work:
1. MIRU and test BOPE to 250 psi low and 3,500 psi high. Maximum expected surface pressure with gas (0.10
psi/ft) to surface is 2,490 psi.
2. RIH and set 3-1/2"x4-1/2" whipstock Top at -V11,825' MD
3. Mill 2.74" window plus 10' of rathole. Swap the well to 8.5-9.5 ppg PowerPro.
L� 4. PU drilling BHA with GR/Resistivity
5. Drill 3.25" hole to U-06BL1 TD. POOH.
--� 6. Run 2-3/8" 13Cr-80 Slotted liner with liner top billet leaving TOL at—11,955 MD.
7- 7. PU BHA with GR/Resistivity and Kick off billet
8. Drill 3.25" hole to U-06BL2 TD. POOH
9. Run 2-3/8" 13Cr-80 Liner leaving TOL at 11,341' MD
10. Pump primary cement bringing TOC to—12,450, 35.5 bbls of 15.3 ppg liner cmt planned
11. Cleanout liner and run GR/CCL log if cement job does not go as planned.
12. Perforate liner per asset instructions (-500')
13. Freeze protect well, set TWC, RDMO
Post Rig:
1. V: Pull TWC, tree work as necessary.
2. S: KO GLV's
3. T: ASRC flowback
4. F: Scale Inhibition treatment
Mud Program:
• Well kill: 8.4-8.6 ppg brine.
• Milling/drilling: 8.4-9.5 ppg Power Pro for milling window and drilling (>520 psi
over -balance ).
Disposal:
• All drilling and completion fluids and all other Class II wastes will go to Grind & Inject.
• All Class I wastes will go to Pad 3 for disposal.
Hole size: 3.25"
Liner Program L1:
• 2-3/8", 4.6# 13Cr-80, Hydril 511 Slotted Liner 11,955' MD — 13,750' MD
• The primary barrier for this operation: a minimum EMW of 8.4 ppg.
• A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
Liner Program L2:
• 2-3/8", 4.6# 13Cr-80, Hydril 511 11,341' MD — 14,500' MD
• A minimum of 35.5 bbls of 15.3 ppg G Cement will be pumped to isolate L2 from L1
• The primary barrier for this operation: a minimum EMW of 8.4 ppg.
• A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
Well Control:
• BOP diagram is attached.
• Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.
• The annular preventer will be tested to 250 psi and 3,500 psi.
Directional
• See attached directional plan.
• Magnetic and inclination surveys will be taken every 30 ft.
• Distance to nearest property — 22,000'
• Distance to nearest well within pool U-06BL1 — 2200' (P-08A)
• Distance to nearest well within pool U-06BL2 — 1150' (P-28)
Logging
• MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section.
• Cased hole GR/CCL logs will be run if cleanout run is run.
Perforating:
• SWS 1.56", 6 spf, pert guns
• The primary barrier for this operation: a minimum EMW of 8.4 ppg. An EMW of 8.4 ppg for this well will
provide 606 psi over -balance to the reservoir.
• A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole.
Anti -Collision Failures
• U-061-1 &L2 fails Major risk with K241112
• At its closest point is within 197' Center to Center. K241112 was completely abandoned to surface in
1980. Collision would result in plug back and open hole side track to continue drilling
Hazards //
• U-pad is an H2S pad
• High Risk of lost circulation with two planned fault crossings
• The planned U-06B L2 will cross Fault #1, a long, E-W trending 60 ft D to S fault. Fault #2 has been
crossed in the reservoir section by the H-09A without losses. Based on this history, the risk of loss
circulation in crossing Fault #1 is considered moderate. The planned L2 will also cross Fault #2, a short,
30 ft, D to W fault. The U-06B parent had loss rates as high as 100 bbl/hr after crossing a N-S trending
40-50 ft D to W fault, and TD was called early as a result of these losses. Based on this nearby history,
the risk of lost circulation in crossing Fault #2 is considered high.
Reservoir Pressure
• The reservoir pressure on U-06BL1&L2 is expected to be 3,384 psi at 8940' TVDss. (7.28 ppg
equivalent).
• Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,490 psi.
• An EMW of 8.4 ppg for this well will provide 520 psi over -balance to the reservoir.
Ryan Ciolkosz CC: Well File
CTD Engineer Joseph Lastufka
TREE= 4-1/16"CIW
VVELLHEAD-
MCEVOY
ACTUATOR:
BAKER
_ - -.._—__..._
OKB. IiEV =
__._._.�_
84.30'
BF. ELEV =
48.80'
KOP =
7700'
Max Angle = 97° @ 13609'
Datum MD =
8967
Datum ND=
88WSS
PROPOSAL
CONDUCTOR, —L ?
ID
13-3/8" CSG, 72#, L-80 BUTT, ID = 12.347' 2685'
9-5/8" WHIPSTOCK (04/30/05)
5/8" CSG, 47#, L-80 BUTT, ID= 8.6-2958
Minimum ID = 2
3-1/2" TBG, 9.2#, 13CR-80 VAM ACE,
0087 bpi, ID = 2.992"
17" LNR, 26#, L-80 BTC, .0383 bpf, ID = 6.276" 1
U_O 6 B 3- 1/ ETY NOTES: CHROME TBG L MAX DOGLEG: 1 @9""
L1 & L2
27' 4-1/2" X 3 1/2" XO,
2192' 3-1/2- HES X NIP, D = 2.813"
1 11366' 1
1 11535' 1
4-1/2" BKR FLOW-THRU WF#PSTOCK (XX/X)(/15) �-j-11825
PERFORATION SUMMARY
REF LOG: MENL RESISTIVITY LOG ON 08/01/99??
ANGLE AT TOP PERF: NA
Note: Refer to Production DB for historical pert data
SIZE J SPF I INTERVAL I Opn/Sqz I SHOT I SQZ
SEEPAGE 2 FOR PERFORATION DETAILS
75" INC.
4-112" LNR, 12.6#, L-80 IBT-M, .0152 bpf, D = 3.958" F-1 14406'
2786' 9-5/8' X 7" ZXP LTP &
FLEX LOCK HGR, ID = 6.31"
MLLOUT WINDOW (U-06B) 2958' - 2974'
GAS LIFT MANDRELS
ST
MD
ND
DEV
TYPE
VLV
LATCH
PORT
GATE
6
3000
3000
3
MMG
DMY
RK
0
02/05/09
5
3848
3810
26
MMG
DOME
RK
16
02/20/13
4
7111
6012
50
MMG
DOME
RK
16
02/20/13
3
9122
7301
51
MMG
DOME
RK
16
03/12/15
2
10376
8108
48
MMG
SO
RK
24
03/07/15
1
111223,8665,
49
1 MMG
I DMY
I RK
1 0
02/20/13
11,341' 2.70' BKR DEPLOY SLV, D = 2.00"
11283' 3-1/2" HES X NP, D = 2.813"
11304' H
3-1/2" X 4-1/2" XO, D= 2.94"
11306'
7" X 4-1/2- BKR S-3 PKR, D = 3.875"
11310'H
4-1/2" X 3-1/2"
1133V
3-1/2- HES X NIP, D= 2.813"
11357 H 3-1/2" HES XN NIP - Milled ID= 2.80"
11361' I7" X 5" BKR ZXP LTPw /TEBACK SLV, D = 4.42"
11366' 3-1/2" WLEG & 3-1/2" X 4-1/2- XO, D= 2.992"
11378' 7" X 5" BKR HMC HGR, D = 4.43"
11385' 5" X 4-1/2" XO, D= 3.96"
MLLOUT WINDOW (U-06B L1)-11825' - '
11,965, 2.60" Liner Top Billet
A
\ —-u=vst3•L� —
2-3/8" LNR, _#, 13Cr STL, -13750
-06 2 .0039 bpf, 1) = "
06 -12450 EsnMAT> 0 TOC
PBTD ��
2-3/8" LNR, #, :1:3:CrSTL,
.0039 bpf, ID =
DATE
06/28/84
08/04/99
05/11/05
06/08/05
xxnwlo
06/09/15
PRUDHOE BAY LUT
WELL: Ll-06B L1 & L2
PERMIT Na: '2050640,
ARNo: 50-029-21117-02(60),(61)
SEC 18, T11N, R13E, 103' FSL & 1663' FEL
REV BY
COMMENTS
DATE
REV BY
CONWENTS
AUDI 2
ORIGINAL COMPLETION
N9ES
CID SIDETRACK (U-06A)
WES
ATTEMPTED SDTRCK (U-06B)
N2ES
SIDETRACK(U-06B)
i CTD M L ST (U-06B L4 & L2)
BP Exploration (Alaska)
ZB/ PJC
I BUILD PROPOSAL.
TREE= 4-1/16" CIW
VMLLHEAD=
MCEVOY
ACTUATOR:
BAKER'',
OKB. ELEV =
84.30'
BF. ELEV =
48.80'
KOP =
7700'
Nhx Angie = 97" @ IWW - CONDUCTOR
Datum MD =
Datum
13-3/8" CSG, 72#, L-80 BUTT, D = 12.347"
9-5/8" VIMPSTOCK (04/30/M)-
9-5/8" CSG, 47#, L-80 BUTT, D = 8.681"
Minimum ID = 2.635" a@ 11352'
3-1/2" HES XN NIPPLE
3-1/2" TBG, 9.2#, 13CR-80 VAM ACE,
0087 bpf, D = 2.992'
U —0 :TY NOTES: WELL ANGLE> 70° @ 11789'
3-112" CHROME TBG
27' 4-1/2" X 3-1/2' XO, D = 2.992'
2192' 3-1 /2" HES X NP, D = 2.813"
2685'
2786' 9-5/8' X 7" ZXP LTP 8
t
FLEX LOCK FMR, D = 6.3158
MLLOUr WINDOW (UO6B) 2956 - 2974'
GAS LET MANDRELS
I 11366' 1
PERFORATION SUMWRY
REF LOG: MEAA. RLDSTNITY LOG ON 08/01/99??
ANGLE AT TOP PEW: 52° @ 11538
Nate: Refer to Production DB for historical perf data
SIZE
SPF
NTERVAL
Opn/Sgz
SHOT
SOZ
2"
6
11538 - 11568
O
11/07/11
2-1/2"
6
11750 - 12000
O
06/06/05
2-1/2"
6
12020 - 12050
O
06J06/05
2-1/2'
6
12080- 12100
O
06/06/05
2-1/2"
6
12130 - 12160
O
06/06/05
2-1/2"
6
12180 - 12200
O
06/06/05
2-1/2'
6
12300 - 12620
O
06/06/05
2-1/2"
6
12635 - 12685
O
06/06/05
2-7/8'
6
12715 - 12885
O
06/06/05
2-71W
6
12900 - 13030
O
06/06/05
2-7/8"
6
13040 - 13235
O
06/06/05
2-7/8"
6
13290 - 13335
O
06/06/05
2-7/8"
6
13345 - 13625
O
06/06/05
2-7/8"
6
13660 - 13720
O
06/06/05
2-7/8"
6
13735 - 13920
O
06/06/05
2-7/8'
6
13975 - 14170
O
06/06/05
1 7" LNR, 26#, L-80 BTC, .0383 bpf, D = 6.276" I--j 11535'
PBS 14316'
112" LNR, 12.6#, L-80 BT, .0152 bpf, D = 3.958" 14405'
ST
MD
ND
I DEV
TYPEJ
VLV
LATCH
PORT
DATE
6
3000
3000
3
MWG
DMK
RK
0
02/05/09
5
3848
3810
26
MNG
DOME
RK
16
02120/13
4
7111
6012
50
MNG
DOME
RK
16
02/20/13
3
9122
7301
51
MMG
DOME
RK
16
03112/15
2
10376
8108
48
M1AG
SO
RK
24
03107/15
1
11223
8665
49 1
MuIG I
DMY I
RK
1 0
02/20/13
11283' H 3-1/2" HES X NP, D = 2,813'
113" H3-1/2-X4-1/2-XO,1D=2A4"
11306' 7" X 4-1/2" BKR S-3 PKR, D = 3.875"
1131W 4-1/2" X 3-1/2" XO, D = 2.96"
11331' 3-1 /2" HES X NP, D = 2.813"
11352' H 3-1 /2" FEES XN NP, D = 2.635"
11361' H 7" X 5" BKR ZXP LTP w fnEBACK SLV , D = 4.42"
11366' 3-1/2" WLEG 8 3-1/2" X
4-1/2" XO, D = 2,992"
11378' 7" X 5' BKR HMC HGR, D = 4.43"
11385' 5" X 4-1/2" XO, D = 3.96"
DATE
REV BY
COMu1113�ITS
DATE
REV BY
COMABSfTS
06/28/84
AM2
ORIGINAL COMPLETION
03/06/15
R!K/ PJC
SET PXN & CATCHER SUB
08104/99
N9ES
CTD SIDETRACK (ll06A)
03/07/15
RJK/ PJC
GLV GO
05/11/05
WES
ATTEPAPTED SDTRCK (U-06B)
03/12/15
DLWP.0
PULL PXWCATCHER SUB/ GLV C!O
06/08/05
WES
SIDETRACK(U-06B)
06/01/00
PJC
LNWCSGCORRECTIONS
01/12/11
jJCW PA
ADFERFS(11107/11)
03101/131
BSE1
GLV C/O (OD20113)
PRUDHOE BAY UPfT
WELL: U-06B
PERMT No: 2050640
API No: 50-029-21117-02
SEC 18, T11 K R13E, 103' FSL 8 1663' FEL
BP Exploration (Alaska)
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North America - ALASKA - BP
Prudhoe Bay
PB U Pad
U-06
500292111700
U-06BL2
U-06BL2 WP05
Travelling Cylinder Report
14 July, 2015
Company:
North America - ALASKA- BP
Project
Prudhoe Bay
Reference Site:
PB U Pad
Site Error:
0,00 usft
Reference Well:
U-06
Well Error.
0.00 usft
Reference Wellbore
U-06BL2
Reference Design:
U-06BL2 WP05
BP
Travelling Cylinder Report
Local Co-ordinate Reference:
TVD Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset TVD Reference:
Well U-06
Mean Sea Level
U-06B(N-2ES) @ 76 63usft (Nabors 2ES)
True
Minimum Curvature
1.00 sigma
EDM R5K- Alaska PROD - ANCP1
Offset Datum
Reference U-06BL2 WP05
Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA
Depth Range: 11,900.00 to 14,500.00usft Scan Method: Tray. Cylinder North
Results Limited by: Maximum center -center distance of 1,647.22 usft Error Surface: Elliptical Conic
Survey Tool Program
Date 7/14/2015
From
To
(usft)
(usft) Survey (Wellbore)
Tool Name
92.33
2,893.63 U-06 Srvy 1 GCT-MS (U-06)
GCT-MS
2,953.13
3,102.23 Survey GYD GC SS (U-06B)
GYD-GC-SS
3,219.65
11,469.06 Survey SLB MWD+IFR+MS (U-06B)
MWD+IFR+MS-WOCA
11,492.65
11,709.31 U-06B (N-2es-Sperry IIFR) (U-06B)
MWD+IFR+MS-WOCA
11,709.31
11,900.00 U-06BL1 WP06 (U-06BL1)
MWD
11,900.00
14,500.00 U-06BL2 WP05 (U-06BL2)
MWD
Casing Points
Description
Schlumberger GCT multishot
Gyrodata gyro single shots
MWD + IFR + Multi Station W/O Crustal
MWD + IFR + Multi Station W/O Crustal
MWD - Standard
MWD - Standard
Measured
Vertical
Casing
Hole
Depth
Depth
Diameter
Diameter
(usft)
(usft) Name
(in)
(in)
2,677.33
2,600.57 13 3/8"
13.375
17.500
11,534.27
8,788.80 DRILLING LINER 1
7.000
8.500
14,500.00
8,935.81 2-3/8"
2.375
3.250
Summary
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation
Warning
Site Name
Depth
Depth
Distance
(usft)
from Plan
Offset Well - Wellbore - Design
(usft)
(usft)
(usft)
(usft)
PB Kup State
K241112 - K241112 - K241112
11,983.53
13,400.00
140.91
11.25
140.49
Pass - NOERRORS
PB P Pad
P-23 - Plan P-23A - Plan #2 P-23A
14,150.00
17,375.00
892.28
513.56
379.07
Pass - Major Risk
P-28 - P-28 - P-28
14,075.00
15,075.00
1,116.31
279.80
836.52
Pass - Major Risk
PB U Pad
U-05 - U-05A - U-05A
Out of range
U-06 - U-06B - U-06B
11,900.00
11,900.00
5.89
0.87
5.56
Pass - NOERRORS
U-06 - U-06BL1 - U-06BL1 WP06
11,900.00
11,900.00
0.00
0.23
-0.23
FAIL- NOERRORS
U-16 - U-16 - Plan #18 U-16 Approved
Out of range
U-16 - U-16 - U-16
Out of range
Offset Design
PB Kup State - K241112 - K241112 - K241112
offset site Error. 0,00 usft
Survey Program: 100-C&GYRO-MS
Rule Assigned: NOERRORS
Offset well Error: 0-00 usft
Reference
onset
Semi Major Axis
Measured Vertical
Measured
Vertical
Reference Offset
Toolface +
Offset Wellhore Centre
Casing -
Centre to
No Go
Allowable Warning
Depth Depth
Depth
Depth
Azimuth
+W-5
+E/-W
Hole Sae
Centre
Distance
Deviation
(usft) (usft)
Nstt)
(usft)
(usft) (usft)
('y
(usft)
(usft)
(in)
(usft)
(usft)
(usft)
11,976.78 8,940.08
13,575.00
8,927.81
33.74 701.59
129,14
-3,165.55
-5,371,69
5.125
233,27
11.15
232.84 Pass - NOERRORS
11,976.82 8,940.08
13,600.00
8,941.54
33.74 703,29
125.79
-3,178.33
-5,355.17
5.125
253,83
11,15
253.41 Pass - NOERRORS
11,977.00 8,940.07
13,625.00
8, 955,18
33,75 705.00
122,97
-3,191,26
-5,338.68
5.125
275.18
11.15
27475 Pass-NOERRORS
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TRANSMITTAL LETTER CHECKLIST
WELL NAME: ffL—U ,Z.
PTD: V
Development _ Service _ Exploratory _ Stratigraphic Test — Non -Conventional
FIELD: POOL:
Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter
CHECK
OPTIONS
TEXT FOR APPROVAL LETTER
MULTI
The permit is for a new wellbore segment of existing well Permit
LATERAL
(If last two digits
No. s 7 , API No. 50- L%' - '�/%/1-7
Production should continue to be reported as a function of the original
in API number are
API number stated above.
between 60-69)
In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both well
Pilot Hole
name ( PH) and API number (50- -
- -� from records, data and logs acquired for well
(name on permit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a conservation
Spacing Exception
order approving a spacing exception. (Company Name) Operator
assumes the liability of any protest to the spacing exception that may
occur.
All dry ditch sample sets submitted to the AOGCC must be in no greater
Dry Ditch Sample
than 30' sample intervals from below the permafrost or from where
samples are first caught and 10' sample intervals through target zones.
Please note the following special condition of this permit:
production or production testing of coal bed methane is not allowed for
Non -Conventional
(name of well) until after (Company Name) has designed and
Well
implemented a water well testing program to provide baseline data on
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing program.
Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of
well logs to be run. In addition to the well logging program proposed by
(Company Name) in the attached application, the following well logs are
also required for this well:
Well Logging
Requirements
Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071,
composite curves for well logs run must be submitted to the AOGCC
within 90 days after completion, suspension or abandonment of this well.
Revised 2/2015
WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150
PTD#:2151240 Company BP EXPLORATION (ALASKA) INC Initial Class/Type
Well Name: PRUDHOE BAY UNIT U-06BL2 Program DEV Well bore seg ❑�/
DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ❑
Administration 1
Permit fee attached
NA
2
Lease number appropriate
Yes
Surface location in ADL0028283; top prod interval & TD in ADL0047451
3
Unique well name and number
Yes
PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341 D
4
Well located in a defined pool
Yes
CO 341 D, Rule 2: There shall be no restrictions as to well spacing except that no pay shall be
5
Well located proper distance from drilling unit boundary
Yes
opened in a well closer than 500 feet to the boundary of the affected area. Planned well
6
Well located proper distance from other wells
Yes
conforms to CO 341 D, Rule 2.
7
Sufficient acreage available in drilling unit
Yes
8
If deviated, is wellbore plat included
Yes
9
Operator only affected party
Yes
10
Operator has appropriate bond in force
Yes
11
Permit can be issued without conservation order
Yes
Appr Date 12
Permit can be issued without administrative approval
Yes
13
Can permit be approved before 15-day wait
Yes
SFD 7/21/2015
14
Well located within area and strata authorized by Injection Order # (put 10# in comments) (For
NA
15
All wells within 1/4 mile area of review identified (For service well only)
NA
16
Pre -produced injector: duration of pre -production less than 3 months (For service well only)
NA
17
Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D)
NA
18
Conductor string provided
NA
Engineering
19
Surface casing protects all known USDWs
NA
20
CMT vol adequate to circulate on conductor & surf csg
NA
21
CMT vol adequate to tie-in long string to surf csg
NA
22
CMT will cover all known productive horizons
No
23
Casing designs adequate for C, T, B & permafrost
Yes
24
Adequate tankage or reserve pit
Yes
25
If a re -drill, has a 10-403 for abandonment been approved
NA
26
Adequate wellbore separation proposed
Yes
27
If diverter required, does it meet regulations
NA
Appr Date
28
Drilling fluid program schematic & equip list adequate
Yes
VTL 7/23/2015
29
BOPEs, do they meet regulation
Yes
30
BOPE press rating appropriate; test to (put psig in comments)
Yes
31
Choke manifold complies w/API RP-53 (May 84)
Yes
32
Work will occur without operation shutdown
Yes
33
Is presence of H2S gas probable
Yes
34
Mechanical condition of wells within AOR verified (For service well only)
NA
35
Permit can be issued w/o hydrogen sulfide measures
No
Geology
36
Data presented on potential overpressure zones
Yes
Appr Date
37
Seismic analysis of shallow gas zones
NA
SFD 7/21/2015
38
Seabed condition survey (if off -shore)
NA
39
Contact name/phone for weekly progress reports [exploratory only]
NA
Geologic Engineering Public
Commissioner: Date: Commissioner Date Commissioner Date
hTS -7/ ?__� I ►S , 7 -Z? _s,
Conductor set in PBU U-06
Surface casing set in PBU U-06
Surface casing set and fully cemented
Productive interval will be completed with uncemented slotted liner
Rig has steel tanks; all waste to approved disposal wells
Anti -collision analysis complete;major risk failure w/ K241112:abandoned to surface
Max formation pres is 3384 psi(7.3 ppg EMW); will drill w/ 8.4 ppg EMW
MPSP is 2490 psi; will test BOPS to 3500 psi
H2S measures required
U-Pad wells are H2S-bearing. H2S measures are required.
Planned drilling mud program (8.4 ppg) appears adequate to control operator's forecast
pore pressure gradient of 7.3 ppg.
