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Alaska Oil and Gas Conservation Commission
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HomeMy WebLinkAbout220-0261
Winston, Hugh E (CED)
From:Joseph Lastufka <Joseph.Lastufka@hilcorp.com>
Sent:Wednesday, November 17, 2021 9:22 AM
To:AOGCC Permitting (CED sponsored)
Cc:Davies, Stephen F (CED); Boyer, David L (CED); Winston, Hugh E (CED); Trevor Hyatt
Subject:Please cancel approved Permit to Drills for PBU L1-13L1 (PTD# 220-014) and PBU L1-01 (PTD #
220-026)
Follow Up Flag:Follow up
Flag Status:Flagged
Hello,
Please cancel 2 2020 approved PTD’s:
PBU L1‐01L1 PTD #220‐026
PBU L1‐13L1 PTD #220‐014
We will be drilling the wells in 2022, however, they will fall outside the 2 year window and they have been re‐submitted.
Please let me know if you have any questions. Thanks!
Thanks,
Joe Lastufka
Sr. Drilling Technologist
Hilcorp North Slope, LLC
Office: (907)777-8400, Cell:(907)227-8496
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THE STATE
°fALASKA
GOVERNOR MIKE DUNLEAVY
Kenneth Allen
Engineering Team Lead
BP Exploration (Alaska), Inc.
PO 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
w .aogcc.alasko.gov
Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU Ll-01L1
BP Exploration (Alaska), Inc.
Permit to Drill Number: 220-026
Surface Location: 2183' FSL, 2448' FWL, SEC. 01, TI IN, R14E, UM
Bottomhole Location: 4883' FSL, 1190' FWL, SEC. 13, T11N, R14E, UM
Dear Mr. Allen:
Enclosed is the approved application for the permit to redrill the above referenced development well.
The permit is for a new wellbore segment of existing well Permit No. 185-055, API No. 50-029-21317-
00-00. Production should continue to be reported as a function of the original API number stated
above.
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.
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,
J sie L. Chmielowski
Commissioner
DATED this j fday of March, 2020.
STATE OF ALASKA
LASKA OIL AND GAS CONSERVATION COMMIS( 1
PERMIT TO DRILL
20 AAC 25.005
RECEIVED
ta. Type of Work:
d Well Class: Exploratory - Gas ❑ Service - WAG ❑ Service - Disp❑
1 c. Specify if well is proposed for
Drill ❑ Lateral 0
Test ❑ Development - Oil 0 Service - Wnj ❑ Single Zone 0
FExpiomtory
Coalbed Gas ❑ Gas Hydrates ❑
Reddil ❑ Reentry ❑
Oil ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑
Geothermal ❑ Shale Gas ❑
2. Operator Name:
5. Bond Blanket 0 Single Well ❑
11. Well Name and Number:
BP Exploration (Alaska), Inc
Bond No. 29S105380
PBU L1-01L'1 '
3_ Address
6. Proposed Depth NDss: 8787'
12. Field/Pcol(s):
t
e, P.O. Box 196612 Anchors AK 99519-6612
9
MD: IL% ND: 8841'
PRUDHOE BAY, LISBURNE
OIL
'
4a. Location of Well (Governmental Section):
7. Property Designation (Lease Number):
ADL 028302 5 028307
8. DNR Approval Number.
13, Approximate spud date:
Surface: 2183' FSL, 2448' FWL, Sec. 01, T11 N, R14E, UM
1174' FSL, 1224' FWL, Sec. 12, T11N, R14E, UM
Top of Productive Horizon:
84-62
May 1, 2020
9. Acres in Property: 2560
14. Distance to Nearest Property:
Total Depth: 4883' FSL, 1190' FWL, Sec. 13, T11 N, R14E, UM
21000
41bLocation of Well (State Base Plane Coordinates - NAD 27):
10. KB Elevation above MSL: 54.00 feet
15. Distance to Nearest Well Open
Same Pool:
Surface: x- 688579 y- 5974535 Zone - ASP 4
GL Elevation above MSL: , 15.50 feet
0
16. Deviated wells: Kickoff Depth: 11932 feet
17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035)
Maximum Hole Angle: 110 degrees
Downhole: 3378 Surface: 2488
18, Casing Program:
Specifications
Top - Setting Depth - Bottom Cement Quantity, c.f or sacks
Hole
Casino
Weight
Grade
Courilma
Len th
MD
ND
MD
ND
findudino stane
4-1/4^
3-1/4" x2-7/8"
6.8#/i
L-80
STL / TCII
1853'
11700'
8712'
13553'
8841"
Uncemented Solid I Slotted Liner
19. PRESENT WELL CONDITION SUMMARY To be completed for Redrill and Re -Entry Operations)
Total Depth MD (ft):
Total Deppth ND (ft):
Plugs (measured).
Effect. Depth MD (ft): Effect. De in ND (ft):
Junk (measured):
12856
9573
None
12150 9034
12040,12169,12170
Casing
Length
Size
Cement Volume
MD
TVD
Conductor/Structural
80
2T
200011 Poleset (Approx.)
39 - 119
10110_
Surface
4050
133r8"
2600 s PF'E', 400 sx Class'G'
39 -
Intermediate
11860
850 sx Class'G' 300 sx CS 1840 sx Class'G'
37 - 11897
37-8851
Production
Liner
1110
7-5/8"
200 sx Class'G'
11690 - 12800
8705 - 9529
Perforation Depth MD (ft): 11900 - 12166 Perforation Depth ND (it): 8853 - 9009
Hydraulic Fracture planned? Yes ❑ No 0
20. Attachments Property Plat ❑ BOP Sketch 0 Drilling Program 0 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 foregoing is true and the procedure approved herein will not be deviated Contact Name Hvatt, Trevor
from without prior written approval.
Authorized Name Allen, Kenneth W Contact Email Treyor.HyattCQbp.com
Authorized Title Engineering Team Lead Contact Phone +l 907 564 4627
Authorized Signature �7 - _,�^,�_. Date:—j
Commission Lisle, Onlvl
Permit to Drill
Number:
API: 50-029-21317-60-00 ,�p�
Permit ApproI
Da
Date:
See cover letter for other
0 � O
YP�
1
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:
Other: U. P�-� y� 7� Samples req'd: Yes ❑ No Mud log mq'd: Yes ❑ No ISK
1' y
H2S measures Yes 9' No ❑ Directional svy req'd: Yes CW' No ❑
Spacing exception req'd: Yes ❑ No W Inclination -only svy req'd: Yes ❑ No V
Post initial injection MIT req'd: Yes ❑ No ❑
APPROVED BY J
Approved by: COMMISSIONER THE COMMISSION Date: 3 ,
r
p �� G4 NA1� l (911 htb{t IZIkiiQ2o
Form 10.a0t Revi t7 This permit is valid for s r m a oval 20 AAC 25.005 Submit Form and
Att merits in Duplicate
To: Alaska Oil & Gas Conservation Commission
� bFrom: Trevor Hyatt 1 ♦ j'1
CTD Engineer Ak IL r.,,J
Date: March 3, 2020
Re: Ll-01L1 Permit to Drill Request
Approval is requested for a permit to drill a CTD sidetrack lateral from well Ll-01 with the Nabors CDR2
Coiled Tubing Drilling rig.
Proposed plan:
The sidetrack 1-1-011-1 will be a -1200' horizontal CST that will kick -out from the Ll-01 parent in the Lisburne. The
planned sidetrack will increase rate and recovery within the identified target block in an area of high productivity and
reservoir quality in the Lisburne. Pre rig will set a 4-1/2" whipstock, at a kickoff depth of-11,932' MD, and mill a 3.80"
window. The rig will move in, test BOPE and kill the well. The well will invert to land in the upper section of the Lisburne.
The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" L-80 solid/slotted liner
�i
Pre -Rig Work (scheduled to begin March 2020)
1.
SL
Dummy GLMs. Drift for Whipstock
2.
EL
Set Whipstock.
3.
C
Mill Window
4.
F
MIT -IA
5.
Pre-CTD Tree work.
'g Work (scheduled to begin May 2020)
1.
MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2488 psi).
3.
Drill build section: 4.25" OH, -243' (21 deg DLS planned).
4.
Drill lateral section: 4.25" OH, -1378' (12 deg DLS planned).
5.
Run 3-1/4" x 2-7/8" L-80 slotted liner to TD.
6.
Freeze protect well to a min 2,500' TVDss.
7.
Close in tree, RDMO.
Post -Rig Work:
V: Tree Work as needed
S: Set LGLVs, Drift to Dev. Set LTP to isolate mainbore
CT: Acidize Lateral by reciprocating acid as deep as possible.
SL: Pull TLP if set
5t.w 1"�tt q
3zo-! Zj)
z zo-ez(�
Operation Details:
Mud Program:
• Drilling/Completion: a min EMW of 8.4 ppg KCL with Geovis for drilling (509 psi over -balance).
Disposal:
• All Class I & If non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6.
• Fluids >S% hydrocarbons or flammables must go to Pad 3.
• Fluids >15% solids by volume must go to GNI.
• Fluids with solids that will not pass through 1/4" screen must go to GNI.
• Fluids with PH >11 must go to GNI.
Hole Size:
4.25" for entirety of the production hole section.
Liner Program:
• 2-7/8", 6.5#, STL, L-80 solid/slotted liner: 12,100 MD-13,553' MD
• 3-1/4", 6.6#, TCII, L-80 solid liner: 11,700 MD—12,100' MD
• The primary barrier for this operation: a minimum EMW of 8.4 ppg (509 psi over -balance).
• 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. Maximum planned hole angle is 110% inclination at kick off point is 42'.
• Magnetic and inclination surveys will betaken every 30 ft. No gyro will be run.
• Distance to nearest property— 21,000'
• Distance to nearest well within pool — none (0')
Logging:
• MWD directional, Gamma Ray, and Resistivity will be run through the entire open hole section.
Anti -Collision Failures:
• None. All offset wells pass BP anti -collision scan criteria.
Hazards: `/
• L1-Pad is NOT an H2S pad. Max recorded H2S reading on L1-01: 40 ppm on 4/2/2019.
o Max H2S recorded on the pad: 70 ppm on LS-23 on 1/6/2018.
• Two planned fault crossings.
• Lost circulation risk is considered High.
Reservoir Pressure:
• The reservoir pressure is expected to be 3378 psi at 8900' TVDSS (7.3 ppg equivalent).
• Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2488 psi. sec vi(GTd
• ,� A min EMW of 8.4�p pifor this well will provide 509 psi over -balance to the reservoir. 7.-T-
Trevor Hyatt CC: Well File
CTD Engineer Joseph Lastufka
564-4627
TREE= 4-1/16' CNV
VW9IHEAD= FMC
ACTUATOR= BAKER
INFML KB. ELE 54'
BF. ELEV = 14'
KOP= 3200'
Max Angle = 62° @ 9200'
Datum M)
wtum N
= 11903'
D= 8900'SS D=19.124'
CSG, 47#, L-80 VAM TOP, D = 8.861
1 —110 f
TOP 2 JTS = 68#, K-65, ID=12A'15-
Minimum ID = 3.813" @ 2232'
4-1/2" HES X NIPPLE
242V
4-112" TBG, 12.6#, 13CT685 VAM TOP, h 115C
.0152 bpf, D = 3.958'
4-12" TUBNG STOB (05/29/14) 1151
I TOP OF 7-5/8" LNR I
12.6#, L-80, .0152 bpf, D =
/R' CRG 4711 1 -R0 RTC n =
PERFORATION SUMMARY
1 —110 f
TOP 2 JTS = 68#, K-65, ID=12A'15-
Minimum ID = 3.813" @ 2232'
4-1/2" HES X NIPPLE
242V
4-112" TBG, 12.6#, 13CT685 VAM TOP, h 115C
.0152 bpf, D = 3.958'
4-12" TUBNG STOB (05/29/14) 1151
I TOP OF 7-5/8" LNR I
12.6#, L-80, .0152 bpf, D =
/R' CRG 4711 1 -R0 RTC n =
PERFORATION SUMMARY
REF LOG: LDT/CM. ON 05/14/85
ANGLEAT TOP FEE- 43" Q 11900'
We: Refer to Production DB for historical pert data
SIZE
SIF
INTERVAL
Opn/Sgz
I SHOT
I SOZ
5"
4
"12076 - 12154
O
01/16/89
5'
4
11900 - 11970
O
01/26/86
5"
12
11900-12000
O
01/15M
5-
4
11988 - 12000
O
0126/86
2-78"
6
12088 - 12100
O
01108/O6
2-78'
6
12108-12116
O
01/0aM6
5"
4
12200 - 12310
S
0126/86
01/1689
' SaECTNE SHOTS
7-5/8- LNR 29.04#, L-80 M SMLS,
.0459 bpf, D = 6.875'
L 1-01
SAF. i NOTES: CHROMETOG
8" FE5 EXT CSG PKR
GAS LIFT MANDRELS
STI
MD
I ND
DEV
TYPE
I VLV
I LATCH
POT04/25117
3
3048
7
M4NG
DOM£
FaC
12
�37
5
5185
51
M4NC'
DOME
W
11
7682
6347
56
MAG
so
RK
2
19-5/8" X 4-1/2" HES TNT WJR D = 3.903' 1
14-112' HES X W,, D = 3.813" 1
1 11575- —j9-5/8" X 4-1/2" BKR S-3 FKR D=
N 599' 41/2"FESX NP, 9)=3.813'
11690' --j9-5/8" X 7-5/8" TEBK SLV, ID=?
11747' 14-l/2- VVLEG (9CR), D= 3.855"
11732 MBAORY TT LOG ON 1 D/16/OS
12OW -jRSH-3 BKR PKR ELEMENTS
1215W EST TOC(MLLED TO 6.75"
FISHS-2
DATE
REV BY
O0M"SJTS
DATE
REV BY
COMbSdTS
06123MS
ORGIWLLCOMPLETION
07/10/14
JMuYPJC
RILL JCJ EVO TREVE(07/06114)
0111989
RWO
07/10/14
JMMPJC
GLV UO (07/101/14), MN DADIDED
12131104
KCFtTLH
RWO
07/10/14
PJC
TRB/ACIJTATOR UPDATE
06120114
0-14
RWO
07/16/14
JMD/CK
FINAL ODEAPP ROVAL
0623/14
JWJM D
R37F CDRRECTIDNS
04/27/17
JPK/JMD
GLV CYO (04125/17)
0626/14
JMD
DRLG HO OORFECII(NdS
L1SBIUR E UJT
WELL L1-01
PUW No:'1850550
AR No: 50-029-21317-00
SEC,'I, T11N, R14E 2187 FSL & 2447' FWL
BP Exploration (Alaska)
TREE =
WELLHEAD =
FMC
ACTUATOR=
NffAL KB. EUP
54'
BF. ELEV =
14'
KOP =
3200'
MaxAngle=
Dasxn MD =
Datum TVD=
89007SS
PROPO° 3
20" CONDUCTOR, —110
91# H-40
D = 19.124"
5/8- CSG, 47#, L-80 VAM TOP, D = 8.861" 2426'
9-5/8- BOWEN CSG PATCH, D = 9.05" 2426' - 2430"
13-3/8" CSG, 720, L-80, D = 12.347" 4089'
TOP 2 JITS = 68#, K-65, ID=12.415"
Minimum ID = 3.813" @ 2232'
4-1/2" HES X NIPPLE
1-12" TBG, 12.6#, 13CR-85 VAM TOP, —L 11502'
.0152 bpf, D = 3.959"
4-12" TUBNG STUB (05(29/14) 115V
I TOP OF 7-5/8" LNR I
4-1/2" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 11747'
9a/8" CSG, 47#, Lao BTC, ID = 8.681" 11897'
7-5/8" X 442- BKR DELTA WHIPSTOCK L/ / ) 11932"
PERFORATION SUMMARY
REF LOG: LDT/CNL ON 05/14/85
ANGLE AT TOP PERF: 43' @ 11900'
Note: Refer to Production DS for hslorical pert data
SIZE
I SPF
I INTERVAL I Opn/Sclz I SHOT I SOZ
LI-01
5"
4
*12076 -12154
O
01/16/89
5"
4
11900 -11970
O
0126/86
5"
12
11900 -12000
O
01/15/89
5"
4
11988 -12000
O
0126/86
2-7/8"
6
12088 -12100
O
01/08/06
2-718"
6
121 D8 -12116
O
01 /08106
5"
4
12200 -12310
S
0126/86
01/16/89
LI-01 LI
SLTO
SLTD / /
r-Sl8" LNIR, 29.04#, L-80 R3 SfrLS. I 12800'
.0459 bpf, D = 6.875"
L 1 -0 1 L 1 SAI !NOTES: CHROMETBG
LI-01
2232' -�4-1/2" HES X NIP, D= 3.813"
2383' 9-5/8" HES ES CEA84TEf2
2405' 9-5/8" HES EXT CSG PKR
GAS LIFT MANDRELS
>T
I MD
I ND
I DEV TYPE
I VLV
I LATCH
I PORT
DATE
3
3049
3048
7 MMG
DOME
RK
16
11Po2/19
2
5742
5185
51 MMG
DOME
RK
16
11/02/19
1
7682
6347
56 MMG
SO
RK
24
11/02/19.
7760'
4-1/2" HES X NP, D = 3.813"
7788'
9-5/8' X 4-12" HES TNT PKR, D = 3.903"
11431'
4-1IT FIBS X NP, D = 3.813"
11517'
6" X 4-12" UNDUE OV ERSHOT
11575'
9-5/8" X 412" BKR S3 PKR, D = 3.875"
11599' 4-12" HES X NP, D = 3.813'
3.70" DEPLOY SLV, ID = 3.00'
3-1/2" X NP, D = 2.813"
11707' H9-5/8" X 7-5/W BOT HYD LNR HGR, D =?
11732 MEMIORY TT LOG ON 10/16/05
L1-01 L1
2-7/8" SLTD LNR, 6Z#, Lao STL, 13553'
.0058 bpf, ID = 2.441"
12M' I—IFLSH1-3 BKR PKR ELEMENTS(OM2M)
1215W EST TOC (MLLED T06.75" OD-1229/04)
DATE
REV BY
COMMENTS
DATE
REV BY
COMMENTS
05123/85
ORGINAL COMPLETION
0IM9189
RWO
12131/04
KCF/TLH
RWO
0520/14
D44
RWO
I I
CTD ML
11/19/19
JMD
BULTPROPOSED
LISBURNE UNIT
WELL: L1-01 L1
PERMIT No: 1850550,
API No: 50-029-21317-00(60)
BP Exploration (Alaska)
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North America - ALASKA - BP
Lisburne
L1
L1-01
PLAN L1-01L1
L1-01L1 WP03
Anticollision Summary Report
03 March, 2020
Baker 8
Hughes
?N
)bp
00+
Company:
North America - ALASKA - BP
Project:
Lisburne
Reference Site:
L1
Site Error:
O.00usft
Reference Well:
L7-01
Well Error:
0 00usft
Reference Wellbore
PLAN L1-01L1
Reference Design:
L7-OiLi WP03
f
BP Baker Eil
Anticollision Report Hughes
Local Co-ordinate Reference:
Well L7-01
TVD Reference:
Mean Sea Level
MD Reference:
ORIG KELLV BUSHING @ 54.00usft (NORDIC 2)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
1.00 sigma
Database:
EDM RSK - Alaska PROD - ANCP7
Offset TVD Reference:
Offset Datum
teference
11-0111 WP03
'ilter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
iterpolation Method:
MD Interval 25.00usft Error Model:
ISCWSA
lepth Range:
11,925.39 to 13,553.07usft Scan Method:
Tray. Cylinder North
tesults Limited by:
Maximum centre distance of 1552 Error Surface:
Pedal Curve
Survey Tool Program Date 3/3/2020
From To
(usft) (usft) Survey (Wellbore) Tool Name Description
43.20 11,925.39 1 : Schlumberger GCT multishot (Li-Ot) GCT-MS Schlumtxirger GCT multishot
11.925,39 13,553.07 11-0111 WP03(PLAN LI-01 1-1) MWD MWD-Standard
Site Name
Offset Well - Wellbore - Design
18
18-10 - 18-1 OC - 18-10C
18-10 - 18-10CPB1 - 18-10CPB1
18-11 - 18-11 B - 18-11 B
18-11 - 18-11 BPB2 - 18-11 BPB2
18-11 - 18-11 BPB3 - 18-11 BPB3
18-11 - PLAN 18-11 C CTD Concept Lateral - 18-1
L1
Li-01 - L7-01 - L7-01
Li-09 - L7-09 - L7-09
L7-13 - L7-13 - L7-13
Li-13 - PLAN L1-13LI - L7-13L1 WPO6
L2
1-2-07 - 1-2-07 - 1-2-07
1-2-07 - 1-2-07A- 12-07A
1.2-07 - L2-07APB1 - 1-2-07APB1
1-2-07 - 1-2-07B - L2-07B
1-2-07 - L2-07BPB1 - L2-07BPB1
PBST
PBST01 - PBST01 - PBST01
PBST01 - PBST01PB1 - PBST01-OH
Reference
Offset
Centre to
No -Go
Allowable
Measured
Measured
Centre
Distance
Deviation Warning
Depth
Depth
Distance
(usft)
from Plan
(usft)
(usft)
(usft)
(usft)
Out of range
Out of range
Out of range
Out of range
Out of range
Out of range
12,238.19
12,350.00
210.36
11.12
210,36
Pan -NOERRORS
Out of range
Out of range
Out of range
12,400.00
11,57200
515&69
347.91
232.53
Pass - Major Risk
12,907.86
12,200.00
180.48
33.02
152.44
Pass - Minor 1/200
12,966.11
11,700.00
635,60
342,37
315.53
Pass - Major Risk
12,425.00
11.100.00
1,009.78
341.43
693.23
Pass - Major Risk
12,425.00
11,100.00
1,009.78
341.60
693.06
Pass - Major Risk
Out of range
Out of range
Y312020 1:2670AM Page 2 of 3 COMPASS 5000. 15 Build 90
ek*% BP
t1= p Anticollision Report Baker
10*41 k Hughes
Company:
North Amenca- ALASKA - BP
Project:
Lisburne
Reference Site:
L1
Site Error:
0.00usft
Reference Well:
L1-01
Well Error:
O.00usft
Reference Wellbore
PLAN 11-0111
Reference Design:
1-1-011-1 WP03
Local CO -Ordinate Reference:
ND Reference:
MD Reference:
North Reference:
Survey Calculation Method:
Output errors are at
Database:
Offset ND Reference:
Well L1-01
Mean Sea Level
ORIG KELLY BUSHING @ 54.00usft (NORDIC 2)
True
Minimum Curvature
1.00 sigma
EDM R5K-Alaska PROD -ANCPI
Offset Datum
Reference Depths are relative to ORIG KELLY BUSHING @ 54.00usft Coordinates are relative to Lt-01
Offset Depths are relative to Offset Datum Coordinate System is Alaska NAD27 State Plane Zones, NAD27' OGP-Usa AK
Central Meridian is 150' 0' 0.000 W ° Grid Convergence at Surface is 1.44`
1600-
To
M
d % 800-
C
d
0
LD
cw 400-
U
Ladder Plot
i
2500 5000 7500 10000
Mea$U&LaT0p0W500 usftln)
12500 15000
-F L1-02,L1-02,L1-02V1
-0- L2-07,L2-07APB1,L2-07APB1 11
—&— 1-1-02,PLANLI-024,1-1-02AWe 07V0
$ L2-07,L2-078,L2-07BVO
$ L1-0B,L1-09,L1-09W
—j— L2-07,L2-07BPB1,L2-07BPB7
-Z- L1-10,L1-10,L1-10V1
-if NGI-04,19GI-04,N31-04V2
$ Li-13,L1-13,L1-13V0
$ NGI-05,14GI-05,14GI-05V1
ra1,18-11CCTDCono?ptl-aterel V0 L1-13,L1-13PB1,L1-13P61V0
$ NGI-07,NGL07A,NGI-07AV6
$ L1-13,PLANLI-13L1,L1-13L1 WP06V0
NG413,NGL13,NGI-13V8
-F L1-15,L1-15,L1-15V1
♦— NGI-13,NG413A,NGF13AV1
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3132020 1 2620AM Page 3 of 3 COMPASS 5000.15 Build 90
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North America - ALASKA - BP
Lisburne
L1
L1-01
PLAN 1-1-011-1
L1-01L1 WP03 Plus 500ft MD
AOGCC Offset Well Report
03 March, 2020
Baker S
Hughes
by"Ote
Company:
North America- ALASKA - BP
Project:
Lisburne
Reference Site:
L1
Site Error:
0.0Ousft
Reference Well:
L1-01
Well Error:
0 00usft
Reference Wellbore
PLAN 1-1-011-1
Reference Design:
1 1-01L1 WP03 Plus 500ft MD
i
BP
Anticollision Report Hughes
Local Local Co-ordinate Reference:
Well Ll-01
TVD Reference:
Mean Sea Level
MO Reference:
ORIG KELLY BUSHING @ 54.00usft (NORDIC 2)
North Reference:
True
Survey Calculation Method:
Minimum Curvature
Output errors are at
1.00 sigma
Database:
EDM R5K - Alaska PROD - ANCP7
Offset TVD Reference:
Offset Datum
Reference
1-1-01 L1 WP03 Plus 500ft MD
Fitter type:
GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference
Interpolation Method:
MD Interval 25.00usft Error Model:
ISCWSA
Depth Range:
Unlimited Scan Method:
Tray. Cylinder North
Results Limited by:
Maximum centre distance of 200 Error Surface:
Pedal Curve
Survey Tool Program Date 3/3/2020
From To
(usft) (usft) Survey (Wellbore) Tool Name Description
43.20 11,925.39 1 : Schlumberger GCT multishol (L1-01) GCT-MS Schlumberger GCT multishot
11,925.39 14,053.07 11-0111 WP03 Plus 500ft MD (PLAN 111-0 MWD MWD- Standard
Summary
Site Name
Offset Well - Wellbore - Design
18
L1
L1-02 - L1-02 - L1-02
L1-02 - PLAN L1-02A - L1-02A WP07
L2
12-07 - 12-07A - 12-07A
NGI
PBST
Reference Offset Centre to
Measured Measured Centre
Depth Depth Distance
(usft) Well) (usft)
1,450.64 1,450.00 18283
1, 443.38 1,450.00 182-73
12, 900.00 12, 275.00 199.58
3/3/2020 3 59: 37AM Page 2 of 2 COMPASS 5000. 15 Build 90
Well Bighole
CDR2-AC 4 Ram BOP Schematic Date 21-NOV-17
Quick Test Sub to Otis
Top of 7"Otis
O.Oft
— — — — — — --- — --- — —
CDR2 Rig Drip Pan
Distances from top of riser
Excluding quick -test sub
7-1116" Sk Flange x 7" Otis Box
Top of Annular
6.0 ft
dril 7 1116
Top of Annular Element
6.7ft
Annular
Bottom Annular
8.0 ft
CL Blind/Shears
9.3 ft
CL 2-3/8" Pipe/Slips
10.1 ft
Bi B2 B]
84
Kill Line
CL 2-3/8" x 3-1/2" VBRS 12.6 ft
CL 2-3/8" Pipe/Slips 13.4k
CL of Top Swab 16.0 ft
CL of Flow Cross 17.4 ft
CL of Master 18.8 k
LDS O
LDS
Ground Level
�-J
aF— Swab
T1 ar, Trg :M ,2
��pR
p�
alp
Master
IA
CA
Test Pump Hose
Boyer, David L (CED)
From: Swanson, Mark <Mark.Swanson@bp.com>
Sent: Thursday, February 13, 2020 2:35 PM
To: Bredar, William L; Boyer, David L (CED)
Subject: RE: Conservation Order 207C.001
Dave,
FYI. The L2-0713 is an Ivishak only well.
Best Regards;
Mark H. Swanson
Geophysicist
GPMA Team
BP Alaska
(907) 564-5931
Cube: 876D
Email: Mark.SWanson@bp.com
From: Bredar, William L<William.Bredar@bp.com>
Sent: Thursday, February 13, 20201:18 PM
To: Swanson, Mark <Mark.Swanson@bp.com>
Subject: FW: Conservation Order 207C.001
Mark,
FYI. Let's talk as necessary.
From: Boyer, David L (CED) <david.boyer2@alaska.gov>
Sent: Thursday, February 13, 2020 9:45 AM
To: Bredar, William L <William.Bredar@bp.com>
Cc: Davies, Stephen F (CED) <steve.daviest?a alaska.¢ov>
Subject: FW: Conservation Order 207C.001
M1
I researched the status of the Lisburne approved PTD's and Spacing Exceptions issued so far:
1. K-333 PTD was sent out and no spacing exception was needed. K-322 will need one since it was drilled after K-
333.
2. 1-3-26 PTD and Spacing Exception went out.
3. L5-07 Spacing Exception (enclosed) went out on 01/22/20. No PTO app. has been received for this well.
4. 1.1-131.1 PTD went out. A Spacing Exception was waived since it is an extension o44and is still reported as
one well. LI -13
5. K-322 Spacing Exception has not been written yet. No PTD package has been received to date.
6. L1-011-1 Spacing Exception may be waived like L1-13L1 since it is a lateral of the same well and still reported as
1-1-01. 1 need to see how close the actual well path is to L2-078(aacctiiv-e well. L2-07 & L2-07A are P & A'd. No PTD
package has been received for this well yet. See %� arh S-'dh50h)S is,09
Hope this helps.
Dave B.
AOGCC
From: Carlisle, Samantha J (CED) <samantha.carlisle alaska.gov>
Sent: Wednesday, January 22, 2020 10:54 AM
To: AOGCC-Public-Notices <AOGCC Public Notices @list.state.ak.us>
Subject: [AOGCC-Public-Notices] Conservation Order 207C.001
Docket Number: CO-19-024
Request for a spacing exception by Administrative Approval under Conservation Order 207C to allow drilling,
completion, and production of the Prudhoe Bay Unit L5-07 development oil well within the same
governmental quarter sections as wells that are, or may be capable of, producing from the same pool.
Prudhoe Bay Unit L5-07 (PTD 219-102)
Prudhoe Bay Field
Lisburne Oil Pool
Samantha Carlisle
Executive Secretary III
Alaska Oil and Gas Conservation Commission
333 West 7u' Avenue
Anchorage, AK 99501
(907) 793-1223
CONFIDENTIALI'N N017CI: This snail nlC.SsagW, indudmg ant' attachments, contains information from the Alaska Oil and Gas Clmsenefion
Co,nunission (ACGCC), State of Alaska and is for tho sole use of the int exled cucipront(a). It may contain confidential andi oi prmlcgod information.
The unauthori .od review, use or disdosurc of such information may Violate State oI federal law. If FOu are an unintended recipient of this a -maul, please
delete it, without first saving or forwarding it, and, so that the OCICC is aware of Ilic mistake in sending it to you, contact Samantha Carlisle at (967)
791-1223 or S.nnanlh.tCarlislc nl.,=rskpgov.
List Name: AOGCC Public Notices@Iist.state.ak.us
You subscribed as: david.bover2@alaska.eov
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TRANSMITTAL LETTER CHECKLIST
WELL NAME: PB u L 1— 01 1- 1-
PTD: Z�. C) — Q -,;L, o
Development _ Service _ Exploratory _ Stmtigraphic Test _ Non-Conventional
IConventional
FIELD: Py d te- f3c—y POOL: LiSAtl r P Q I
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
No. 1 RS — 055 API No. 50-_023- 21313L
(If last two digits
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(i), 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 ermit).
The permit is approved subject to full compliance with 20 AAC 25.055.
Approval to produce/inject is contingent upon issuance of a
Spacing
conservation order approving a spacing exception. (Company Name)
Exception
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' sam le 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-
(name of well) until after (Company Name) has designed and
Conventional
implemented a water well testing program to provide baseline data on
Well
water quality and quantity. (Company Name) must contact the AOGCC
to obtain advance approval of such water well testing ro
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
J
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
J
within 90 days after completion, suspension or abandonment of this
well.
Revised 2/2015
WELL PERMIT CHECKLIST Field &Pool PRUDHOE BAY, LISBURNE OIL - 640144
Well Name: PRUDHOE BAY UN LIS 11-011-1 - ____Program _OEV Well bore seg d❑
PTD#: 2200260 Company BP Exploration "Alaka) Inc. _ Initial Class/Type
_DEV / PEND GeoArea $90 Unit 11650 On/Off Shore On Annular Disposal ❑
Administration
1
Permit fee attached- ---------------------- ----------------- ---NA..-----.
....---....----------.....---.....------------------....-------
2
Leasenumber appropriate. _. ___
Yes__..-----_-...-.-_-__-_....___----......._.---...__--...-------------..
3
Unique well name and number _ _ - - . _ - _
Yes
-...
4
Well located in.a defined -pool _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ........... -Yes.....-----..
5
Well located proper distance from drilling unit boundary. . .................. . .
Yes-
6
Well located proper distance from other wells- ... _ ..... . . . . .. . . . . . ..
Yes
7
Sufficient acreage available indrillingunit-- - - - - - - --- - - - - - - - -- - - - - - - - _
Yes,
8
If deviated, is wellbore plat. included - - _ _ - .. - - - - - ..
Yes
_ - Directional -plan view & wellbore profile included..
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
DLB 3/10/2020
13
Can permit be approved before 15-day wait . ..... . . . . . . .... .
Yes
_ ... _ _ _ _ _ _ _
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
116
Pre -produced injector; duration of pre production less than 3 months (For service well only) ...NA
- _ .. _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
17
Nonconven. gas conforms to AS31,05,030Q.1.A),1j.2.A-D) __ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _
NA-
18
Conductor stringprovided....... . . . . . . . . . . .....
-NA.
_ - - _ - . This is a CTD sidetrack In the reservoir. Slotted liner,. comingled Liskurne. produces_
Engineering
19
Surface casing -protects all known USDWs - ..... . . . . . .. . - _
NA
_ .........
_ _ - .. This is a CTD sidetrack in the reservoir. Slotted liner,. comingled Lisburne producer.- _ - .
20
CMT.vol adequate to circulate.on conductor. & surf csg _ .... _ _ _ _ _ _ - _ .....
NA
- ... - _ - This is a CTD sidetrack in.the reservoir, Slotted tiner,_comingled Lisburne -producer.... - - _ _ - - - - - -
21
CMT vol adequate to tie-in long string to surf csg. . . . .. . . . . . ... . . . .. -
NA..
_ - _ - _ - This is a CTD sidetrack in the reservoir. Slotted liner,. comingled Lisburne producer. _ _
22
CMT. will cover all known productive horizons. .. _ _ _ - - - ..... _ _ ..
Yes
- _ ... This is a CTD sidetrack in the reservoir.- Slotted liner, comingled Lisburne producer.
23
Casing designs adequate for C, T, B &. permafrost_ - _ - .. _ .
Yes
_ . - - - - - This is a CTD sidetrack in the reservoir.. Slotted liner, comingled Liskurne. producer.-
24
Adequate tankage or reserve pit . . ....... . . . . . . . . . . ..... -
Yes
. _ _ _ _ _ - CDR2 has good truck support and adequate tankage....
25
If a re -drill has.a 10-403 for abandonment been approved _ _ _ _ .. _ _ _ .... - .. -
.NA_
_ - . This will be an additional lateral to the existing_ producing latera. _ ...... - . _
26
Adequate wellbore separation proposed- ... _ _ _ - _ _ _ _ _ _ - _ _ _ ....
Yes
_ _ - All offset wells meet SP separtion criteria, 1-2-07A closeapproachwill be -in the reservoir.
27
If diverter required, does it meet regulations- - - - - - - - - -- - - - - - - - - - - -
NA..
_ - - _ - This is a CTD sidetrack In the reservoir, Slotted liner,. comingled Lisburne. producer._
Appr Date
28
Drilling fluid. program schematic& equip list adequate_ _ _ - .....
Yes
- _ - - - All fluids are.overbalanced to the reservoir...
MGR 3/12/2020
29
BOPEs,_do they meet regulation - . - - - - - - - --- - - - - - - -
Yes
_ - .. 1 packoff, 1 annular, 3-ram CTD stack.-
30
BOPE press rating appropriate; test to.(put psig in comments) _ _ _ _ .... - _
Yes
_ _ _ _ _ 5000 psi stack, pressure tested to 3500 psi..
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-- - - - - - - - - --- - - - - - - - _ _ _ ... _ _ ..
NO
_ _ .. 70 ppm-H2S maximum on LJ-pad..-
34
Mechanical condition of wells within AOR verified (For service well only) .. . . . . .... . ...NA_
-
- _ _ _ _ - This is a development well. _ . _ ... -
35
Permit can be issued w/o hydrogen sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _
No
..... - L1-Pad wells are H2S-bearing.t{2S measures, are required...
Geology
36
Data presented on. potential overpressure zones - .. ... _ _ - - . - - ... _ _
Yes ..
_ _ - - Max H2S, reported in-Lt-01:-40_ppm on 412119. Max 112S on Li- Pad: 70ppm on 1)J/06/18.
Appr Date 137
Seismic analysis of shallow gas,zones.
NA
_ (per regulation 20AAC 2¢ 065: H2S. readings >20
_ - _ _ - g ppm require H2S measures) -
DLB 3/10/2020
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
ors 3J12j 0 �o 31l?-(2�
