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(Rica _ Well History File Identifier
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7/8/2014 Well History File Cover Page_20140708.doc
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McMains, Stephen E (DOA)
From: Lastufka, Joseph N [Joseph.Lastufka@bp.com]
Sent: Tuesday, November 06, 2012 2:59 PM
To: McMains, Stephen E (DOA); Davies, Stephen F (DOA); Schwartz, Guy L (DOA)
Cc: Ross, Matthew
Subject: FW: P-17I1 directional.
Attahments: P-17L1Plan 13 MDINCAZGRID.txt PTP ,zl
a w
Hello, I I
This Permit to Drill will be delivered today.
Please withdraw sundry 312-381 and permit to drill 212-151 as this will be the plan going forward on this well.
Thanks!!
Joe
yoF Tk •
hw\��\���, s,, THE STATE Alaska Oil and Gas
o � °fALAS�
; _ =_-1-_-.4& Conservation Commission
i GOVERNOR SEAN PARNELL 333 West Seventh Avenue
Anchorage, Alaska 99501-3572
ALAS1 Main: 907.279.1433
Fax: 907.276.7542
John McMullen
Engineering Team Leader
BP Exploration (Alaska), Inc.
P.O. Box 196612
Anchorage, AK 99519-6612
Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU P-17A
BP Exploration (Alaska), Inc.
Permit No: 212-151
Surface Location: 2378' FSL, 2095' FWL, SEC. 31, T11N, R13E, UM
Bottomhole Location: 3073' FSL, 1850' FWL, SEC. 31, T11N, R13E, UM
Dear Mr. McMullen:
Enclosed is the approved application for permit to re-drill the above referenced
development 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 Commission reserves the right to
withdraw the permit in the event it was erroneously issued.
Operations must be conducted in accordance with AS 31.05 and Title 20,
Chapter 25 of the Alaska Administrative Code unless the Commission
specifically authorizes a variance. Failure to comply with an applicable
provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code,
or a Commission order, or the terms and conditions of this permit may result
in the revocation or suspension of the permit.
Sincerely,
(,,,r;_l_"(e }
4fr_e_ s_Z,
C;t1111137 Foerster
Chair
DATED this l D d y of October, 2012.
cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail)
Department of Environmental Conservation w/o encl. (via e-mail)
STATE OF ALASKA RECEIVED
4
ALAS )IL AND GAS CONSERVATION COMMI )N OCT 0 4 2012
• PERMIT TO DRILL
20 AAC 25.005
1 a.Type of work: lb.Proposed Well Class ®Development Oil• 0 Service-Winj 0 Single Zone . 1 c. S P I ssoposed for.
❑Drill ®Redrill . 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates
❑Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas
2. Operator Name: 5. Bond: ®Blanket 0 Single Well 11. Well Name and Number:
BP Exploration(Alaska) Inc. Bond No. 6194193 • PBU P-17A •
3. Address: 6. Proposed Depth: 12 Field/Pool(s).
P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 11951' • ND 8835'ss • Prudhoe Bay/Prudhoe Bay
4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number):
Surface. ADL 028288
2378' FSL, 2095'FWL,Sec.31,T11N, R13E, UM •
Top of Productive Horizon: 8 Land Use Permit: 13. Approximate Spud Date:
2126' FSL, 711'FWL, Sec.31,T11N, R13E, UM November 15,2012
Total Depth: 9.Acres in Property: 14.Distance to Nearest Property:
3073'FSL, 1850'FWL, Sec. 31,T11N, R13E, UM 2560 13500'
4b. Location of Well(State Base Plane Coordinates-NAD 27): •10.KB Elevation above MSL: 91.85' • feet 15.Distance to Nearest Well Open
Surface. x- 631380 • y-5947108 • Zone- ASP4 GL Elevation above MSL: 37.75' feet to Same Pool: 700'
16.Deviated Wells. Kickoff Depth: 9055' • feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035)
Maximum Hole Angle: 104 degrees Downhole: 3213 • Surface: 2333 •
18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks
Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data)
4-1/4" 3-1/2 x-114"x2-7/6^ 9 3#/6 6#/6 5# 13Cr60/L-80 sTL/TC-II 3191' 8760' 8466'ss 11951' 8835'ss 174 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): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured):
9525' 9308' 9168' 9401' 9186' None
Casing Length Size Ciment Volume ! MD TVD
Conductor/Structural 110' 20" 260 sx Actic Set(Approx.) 110' 110'
Surface 2703' 10-3/4" 2191 cu ft Permafrost 2703' 2703'
Intermediate 9036' 7-5/8" 1260 cu ft Class'G' 9036' 8827'
Production
Liner 726' 5-1/2" 168 cu ft Class'G' 8799'-9525' 8596'-9308'
Perforation Depth MD(ft): 9146'-9274' Perforation Depth ND(ft): 8935'-9060'
20.Attachments: 0 Property Plat ®BOP Sketch ®Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis
0 Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements
21. Verbal Approval: Commission Representative: Date:
22. I hereby certify that the foregoing is true and correct. Contact Matt Ross,564-5782
Printed Name John McMullen Title Engineering Team Leader
µA,q-/�SS L r Prepared By Name/Number
Signature pt(,�/ �T�-to�(�r� Phone 564-4711 Date (0(4-��li Joe Lastufka,564-4091
Commission Use Only .
Permit To Drill API Number: Permit Appr val a See cover letter for
Number 2./2- i 57 50-029-22105-01-00 (I I i 2 other requirements
Conditions of Approval. If box is checked,well may not be usedseto explore for,test,or produce coa ed methane,gas hydrates,or gas contained shales: El
Other: - 3 506 /°s`- 30/ S7 Samples Req'd: Dyes ['No Mud Log Req'd: ❑yes Q No
H2S Measures: Yes ❑ No Directional Survey Req'd: gYes 0 No
ORIGINAL
, p - , PROVED BY THE COMMISSION
Date /0 - (0 (Zof ,COMMISSIONER
Form 10-4(R0p [U g/29r 1 1 T itpermit is valid for 24 months from the date appro al(20 AAC 25.005(9)) Submit In Duplicate v
i',1 -?lJl i 74 j6-i?-12- /9/1k
— ~\o
To: Alaska Oil & Gas Conservation Commission bp
From: Matthew Ross
CTD Engineer
Date: October 4, 2012
Re: P-17A Permit to Drill Request
Approval is requested for a permit to drill a CTD sidetrack from well P-17. •
CTD Drill and Complete P-17A program: Rig Start Date: November 15th, 2012
Pre-Rig Work: (scheduled to begin October 15th, 2012)
1. S Dummy off tubing.
2. F MIT IA.
3. S Drift for whipstock to 9,168' MD.
4. E Mill XN profile at 8,756' MD.
5. F Load, kill & freeze protect well.
6. E Set Posi-set plug at 9,140' MD & dump bail cement. 27k1
,
7. E Set 4-1/2" by 5-1/2" whipstock at 9,055' MD.
8. V PT MV, SV, WV.
9. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange.
10. 0 Remove wellhouse, level pad.
A
Rig Work: (scheduled to begin November 15th, 2012)
1. MIRU and test BOPE to 250 psi low and 3,500 psi high.
2. Mill 3.80" window at 9,055' and 10' of rathole. Swap the well to PowerVis.
3. Drill Build: 4.25" OH, 645' (25°/100 planned) with resistivity.
4. Drill lateral: 4.25" OH, 2,251' (12°/100 planned) with resistivity.
5. Run 3-1/2" 13Cr x 3-1/4" L-80 x 2-7/8" 13Cr liner leaving TOL at 8,760' MD.
6. Pump primary cement leaving TOC at 8,760' MD, 36 bbls of 15.8 ppg liner cmt planned.
7. Perform liner cleanout with mill, motor and MCNL/GR/CCL log. /
8. Test liner lap to 2,400 psi.
9. Perforate liner per asset instructions (1000').
10. Freeze protect well to 2500' TVD
11. Set BPV, RDMO.
Post-Rig Work:
1. Re-install wellhouse, flowline and pull BPV. -
2. Set liner top packer if needed with slickline & test to 2,400psi.
3. Test separator.
Mud Program:
• Well kill: 8.4 ppg brine. '
• Milling/drilling: 8.6 ppg PowerVis for milling window and drilling (722 psi over-balance). -
Disposal:
• All Class I & II non-hazardous and RCRA-exempt drilling and completion fluids will go to GNI -
atDS4orPad 3atDS6.
• Fluids >1% 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" From 9,055' MD to 11,951' MD
Liner Program:
• 3-1/2", 9.3 lb/ft, 13Cr, STL liner 8,760' MD — 9,010' MD.
• 3-1/4", 6.6 lb/ft, L-80, TC-II Solid liner 9,010' MD — 11,000' MD.
• 2-7/8", 6.5 lb/ft, 13Cr, STL Solid liner 11,000' MD — 11,951' MD.
• A minimum of 36 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 8,760' 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.
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 104.1°, inclination at kick off
point is 11.9°.
• Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run.
• Distance to nearest property— 13,500'.
• Distance to nearest well within pool — 700'.
Logging
• MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. •
• Open hole Resistivity/Neutron/Density log will be run should hole conditions warrant from -
9,055' MD to 11,951' MD.
• Cased hole GR/CCL/MCNL logs will be run.
Perforating:
• SWS 2", 6 spf, perf guns, 1-W CSH work string, & 2-3/8" PH6
• 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.
Anti-Collision Failures
• None
Hazards
• P-Pad is considered an H2S pad. '
• Most recent H2S level on P-17 is 14 ppm recorded on 1/30/2012.
• The lost circulation n:,.. in the P-17 is considered to be m�..,um and 2 fault crossing are
planned.
Reservoir Pressure
• The reservoir pressure on P-17A is expected to be 3,213 psi at 8,800' TVDSS. (7.1 ppg
equivalent).
• Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,333 psi. •
• An EMW of 8.4 ppg for this well will provide 630 psi over-balance to the reservoir.
Matthew Ross CC: Well File
CTD Engineer Sondra Stewman/Joe Lastufka
TREE CM/
WELLHEAD= FMC SAF NOTES: ***4-1/2 CHROME TBG&5-1/2"
ACTUATOR= OTIS p-1 7 CHROME LNR***
KB.ELEV= 91.85'
BF.ELEV= 55.19' 1 i
KOP= 4400'
Max Angle= 20°@ 5700' 1 I 1985' —14-1/2"HES X NIP,ID=3.813"
Datum MD= 9102'
Datum TVD= 8800'SS GAS LIFT MANDRELS
ST MD TVD DEV TYPE VLV LATCH PORT DATE
10-3/4"CSG,45.5#,L-80,ID=9.953" 2703' 5 3182 3182 0 KBMG DOME BK 16 09/08/10
1.7
4 4800 4784 18 KBMG DOME BK 16 09/08/10
3 6257 6156 19 KBMG DOME BK 16 09/08/10
2 7629 7470 16 KBMG DOME BK 16 09/08/10
1 8455 8263 14 KBMG SO BK 0 09/08/10
Minimum ID = 3.725" @ 8756'
4-1/2" HES XN NIPPLE I I 8543' —4-1/2"HES X NIP,ID=3.813"
8565' --17-5/8"X 4-1/2"BKR S-3 PKR,ID=3.87"
1 8599' —14-1/2"HES X NIP,ID=3.813"
' ' 8756' I—4-1/2"HES XN NIP,ID=3.725"
TOP OF 5-1/2"TIW LNR — 8799'
4-1/2"TBG,12.6#,13CR-80 VAM TOP, — 8808' I / ` 8808' —4-1/2"WLEG, ID=3.958"
.0152 bpf,ID=3.958" 8823' H ELMD TT LOGGED 08/22/10
7-5/8"CSG,29.7#, NT-95HS,ID=6.875" — 9036' 141
IL
PERFORATION SUMMARY
REF LOG: HLS BHCS 12/06/90 9089' HMARKER JOINT
ANGLE AT TOP PERF: 12°@ 9146'
Note: Refer to Production DB for historical perf data
SIZE SPF INTERVAL Opn/Sqz DATE
1.
3-1/8" 4 9146-9166 0 04/12/91 I 9168' I—TOP OF SAND(TAGGED 08/30/10) I
3-3/8" 6 9146-9166 0 08/22/10
3-3/8" 4 9166-9186 C 03/25/91
3-3/8" 4 9194-9198 C 03/25/91
3-3/8" 4 9208-9252 C 03/25/91
3-3/8" 4 9260-9274 C 03/25/91 ,�,
PBTD _ 9401' /'e1W1v1'1
11111111111111
5-1/2"LNR, 17#,13-CR, .0232 bpf,ID=4.892" — 9525' '......1:
DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT
12/11/90 DGH ORIGINAL COMPLETION ' 07/29/11 CJN/PJC WLEG DEPTH CORRECTION WELL: P-17
03/30/09 N4ES RWO PERMIT No: 1901550
09/13/10 PJC/KJB REPERF(08/22/10) API No: 50-029-22105-00
09/13/10 JD/PJC TAG TOP OF SAND(08/30/10) Sec.31,T11N,R13E,2378 FSL&2095 FWL
09/24/10 GTW/PJC GLV C/O(09/08/10)
02/27/11 ?/PJC ELMD TT LOG(08/22/10) BP Exploration(Alaska)
I HEE= CNV
I WaLHEAD= RC P 17A SAY NOTES: ***4-1/2 CHROME TBG&5-112"
ACTUATOR=_ OTIS CHROME LNR***
KB.B_Ej_ 91.85 Planned CTD Sidetrack
BE BEV=----- 55.19' I
KOP= 4400' I I 1985' H 4-1/2"HES X NP,D=3.813"
Max Angle= 20'@_5700'
Datum MD= 9102'
DatumTVD= 8800 SS GAS LFT MANDRELS
ST MD ND DEV TYPE VLV LATCH PORT DATE
10-3/4"CSG,45.5#,L-80,D=9.953" — 2703' 1 "1 5 3182 3182 0 KBMG DOME BK 16 09/08/10
4 4800 4784 18 KBMG DOME BK 16 09/08/10
3 6257 6156 19 KBMG Mt' BK 0 08/18/12
2 7629 7470 16 KBMG DOME BK 16 09/08/10
1 8455 8263 14 KBMG SO BK 22 08/18/12
Minimum ID = 3.725" @ 8756'
4-1/2" HES XN NIPPLE
PERFORATION SUMMARY ' , 8543' —14-1/2"t X NP,D=3-813"
REF LOG: ILS BHCS 12/06/90
ANGLE AT TOP PERF: 12"@ 9146' g x 8565' —I7-5/8"X 4-1/2"BKR S-3 PKR,ID=3.87"
Note:Refer to Production DB for historical perf data
SIZE SPF NTERVAL Opn/Sqz DATE
3-1/8" 4 9146-9166 0 04/12/91
3-3/8" 6 9146-9166 0 08/22/10 I I 8599' —14-1/2"1-ES X NIP,D=3.813"
3-3/8" 4 9166-9186 C 03/25/91
3-3/8" 4 9194-9198 C 03/25/91
3-3/8" 4 9208-9252 C 03/25/91 8756' H4-1/2"F6 XN NP,ID=3.725"
3-3/8" 4 9260-9274 C 03/25/91
Mi111D3 .80"
TOL -8,760'M D -` ,
TOP OF 5-1/2"TNV LNR H 8799'
op
4-1/2"TBG,12.6#,13CR-80 VAMTOP, H 8808' z !1‘ 8808' —I4-1/2"WLEG,ID=3-958"
-0152 bpf,ID=3-958" 8823' —I ELM)TT LOGGED 08/22/10
7-5/8"CSG,29-7#,NT-95HS,ID=6.875" —I 9036' INA
L 2-7/8"13C rLiier
TD 11,950' •
TOWS 4-1/2"x 5 12"Gen II
9055' MD 0° RO H S .--------
` 7
f_ -.. .J3 1/4"x 2-7/8"X0 @ -11,000'
Pose-setplig w/Cem ent------
-9,140'M D • 9089' --{MARKER JOINT
9168' —I TOP OF SAND(TAGGED 08/30/10)
I
FBTD H 9401' 1••••••1
5-1/2"LNR, 17#,13-CR,.0232 bpf,ID=4-892" —{ 9525' •/•/•/•/•/A A A
DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT
12111/90 DGH ORIGINAL COMPLETION 07/29/11 CAW PJC VVLEG DEPTH CORRECTION WELL: P-17
03/30/09 N48S RWO 08/22/12 BSE/JMD GLV C/C(08/18/12) PERMIT No:"1901550
09/13/10 PJC/KJB REFERF(08/22/10) API No: 50-029-22105-00
09/13/10 JD/PJC TAG TOP OF SAND(08/30/10) Sec-31,T11N,R13E 2378 FSL&2095 FWL
09/24/10 GTW/PJC GLV CIO(09/08/10)
02/27/11 ?/PJC ELM)TT LOG(08/22/10) BP Exploration(Alaska)
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HUGHES Travelling Cylinder Report 0 bp
INTEQ
Company: North America-ALASKA-BP Local Co-ordinate Reference: Well P-17
Project: Prudhoe Bay TVD Reference: Mean Sea Level
Reference Site: PB P Pad MD Reference: ORIG KELLY BUSHING @ 91.85ft(NABORS 4ES)
Site Error: 0.00ft North Reference: True
Reference Well: P-17 Survey Calculation Method: Minimum Curvature
Well Error: 0.00ft Output errors are at 1.00 sigma
Reference Wellbore P-17A Database: EDM.16-ANC Prod-WH24P
Reference Design: Plan 13 Offset TVD Reference: Offset Datum
Summary
Reference Offset Centre to No-Go Allowable
Measured Measured Centre Distance Deviation Warning
Site Name Depth Depth Distance (ft) from Plan
Offset Well-Wellbore-Design (ft) (ft) (ft) (ft)
PB P Pad
P-06-P-06A-P-06A Out of range
P-06-P-06B-P-06B Out of range
P-07-P-07-P-07 Out of range
P-07-P-07A-P-07A Out of range
P-08-P-08-P-08 Out of range
P-08-P-08A-P-08A Out of range
P-08-P-08APB1 -P-08APB1 Out of range
P-09-P-09-P-09 Out of range
P-09-P-09L1 -P-09L1 Out of range
P-10-P-10-P-10 Out of range
P-11 -P-11 -P-11 10,750.00 9,175.00 737.71 126.37 619.69 Pass-Major Risk
P-16-P-16-P-16 Out of range
P-16-Plan P-16A-Plan#4 P-16A Out of range
P-17-P-17-P-17 9,074.99 9,075.00 0.28 1.45 -1.17 FAIL-Major Risk
P-19-P-19L1 -P-19L1 Out of range
P-20-P-20-P-20 Out of range
P-20-P-20A-P-20A Out of range
P-20-P-20APB1 -P-20APB1 Out of range
P-20-P-20B-P-20B Out of range
P-21 -P-21 -P-21 Out of range
P-21 -P-21A-P-21A Out of range
P-21 -P-21 B-P-21B Out of range
P-24-P-24-P-24 Out of range
P-24-P-24PB1 -P-24PB1 Out of range
P-27-P-27-P-27 Out of range
P-29-P-29-Plan#11 P-29 Out of range
PBU MP 22-31-11-13 2
PBU MP 22-31-11-13 2-PBU MP 22-31-11-13 2- 11,225.00 10,625.00 496.55 419.66 98.41 Pass-Major Risk
CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation
10/3/2012 11:26:56AM Page 3 of 9 COMPASS 2003 16 Build 73
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TRANSMITTAL LETTER/ CHECKLIST
WELL NAME �✓(. 7,42/ 7/1
PTD#
,/ Development Service Exploratory Stratigraphic Test
Non-cgnventional Well
POOL: Airaks. I /.
Check Box for Appropria aetter I Paragraphs to be Included in Transmittal Letter
CHECK ADD-ONS
WHAT (OPTIONS) TEXT FOR APPROVAL LETTER
APPLIES
MULTI LATERAL The permit is for a new wellbore segment of existing
well
(If last two digits in Permit No. , API No. 50- - -
API number are
between 60-69) Production should continue to be reported as a function of the
original API number stated above.
PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs
acquired for the pilot hole must be clearly differentiated in both
well name ( PH) and API number
(50- - - ) from records, data and logs
acquired for well
SPACING The permit is approved subject to full compliance with 20 AAC
EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of
a conservation order approving a spacing exception.
assumes the liability of
any protest to the spacing exception that may occur.
DRY DITCH All dry ditch sample sets submitted to the Commission must be in
SAMPLE no greater than 30' sample intervals from below the permafrost or
from where samples are first caught and 10' sample intervals
through target zones.
Non-Conventional Please note the following special condition of this permit:
Well production or production testing of coal bed methane is not allowed
for (name of well) until after (Company Name) has designed and
implemented a water well testing program to provide baseline data
on water quality and quantity. (Company Name) must contact the
Commission to obtain advance approval of such water well testing
program.
Rev:9/09/2011
❑❑
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