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213-072
Gil Meredith D (DOA) From: Guhl, Meredith D (DOA) Sent: Wednesday, March 01, 2017 1:15 PM To: Lastufka, Joseph N Cc: Davies, Stephen F (DOA) Subject: PBU 18-09C, PTD 213-072, Issued 17 May 2013 Hello Joe, Permit to Drill 213-072, for PBU 18-09C, issued 17 May 2013, has expired under the Regulation 20 AAC 25.005 (g). This PTD 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 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 Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. THE STATE , Laska Oil and, Gas �f L-oocamma E GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 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 l 8-09C BP Exploration (Alaska), Inc. Permit No: 213-072 Surface Location: 486' FNL, 342' FEL, SEC. 24, T11N, R14E, UM Bottomhole Location: 3209' FNL, 4761' FEL, SEC. 14, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name PBU 18-09C plus PH and API number 50-029-21566-70 from records, data and logs acquired for well PBU 18-09C. 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, al� Cathy P oerster Chair DATED this 7 day of May, 2013. STATE OF ALASKA ALASKh OIL AND GAS CONSERVATION COMMI: _.ON PERMIT TO DRILL 20 AAC 25.005 RECEIVED MAY 16 2013 GCC 1 a. Type of work: 1 b.Proposed Well Class: ® Development Oil ❑ Service - Wini ® Single Zone 1 c. Specify if well is proposed for: ❑ Drill . ❑ Lateral ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ® Redrill ❑ Reentry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ Geothermal ❑ Shale Gas 2. Operator Name: 5. Bond • ® Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No 6194193 • PBU 18-09C 3. Address 6. Proposed Depth: 12. Field / Pool(s) P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 15000' • TVD 8660'ss Prudhoe Bay / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): Surface: ADL 028307 486' FNL, 342' FEL, Sec. 24, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 4208' FNL, 1967' FEL, Sec. 14, T11N, R14E, UM June 20, 2013 9. Acres in Property: 14.Distance to Nearest Property: Total Depth 3209' FNL, 4761' FEL, Sec. 14, T11 N, R14E, UM 2560 22800' - 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10.KB Elevation above MSL: 48' , feet 15.Distance to Nearest Well Open Surface: x 691406 • y- 5961373 • Zone- ASP4 GL Elevation above MSL: feet to Same Pool: 1270' 16. Deviated Wells: Kickoff Depth: 11531' feet 117. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 degrees Downhole: 3257 - Surface: 2377 18. Casing Program Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3-1/4" 2-3/8" 4.7# L-80 STL 4400' 10600' 7930'ss 15000'. 8660'ss 77 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 TVD (ft): Junk (measured). 1 13636' 8694' None 13607' 8693' None Casing Length Size Cement Volume MD TVD Conductor / Structural 110, 16" 1635# Poleset 110, 110, Surface 4651' 10-3/4" 2400 sx CS III 400 sx CS II 4651' 4011' Intermediate 9560' 7-5/8" 450 sx Class'G' 200 sx CS 1 9560' 7305' Production Liner 2550' 5-1/2" 365 cu ft Class'G' 9417' - 11967' 7198' - 8666' Liner 1 3041' 1 2-3/8" 115 Bbls LARC Cement 1 10593' - 13634' 1 7975' - 8694' Perforation Depth MD (ft): 12030' - 13589' Perforation Depth TVD (ft): 8678' - 8693' 20.Attachments: ❑ Property Plat ® BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ® Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program ® 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date 22. 1 hereby certify that the foregoing is true and correct: Contact David Johnston, 564-5985 Printed Name Title Engineering Team Leader Email David. Johnston2@bp.com Johi c rfeR g g Signature Phone 564-4711 Date Commission Use Only Permit To DrP I 2-- 7 API Number: PermitApproval See cover letter for I Number: 50-029-21566-03-00 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 0 Other: 1 contained shales: Samples Req'd �No Y1 ❑ Yes Mud Log Req'd: ❑ Yes No 1 fps / to 35-UU �jS � / H2S Measures: ® Yes ❑ No Directional Survey Req'd: Mi Yes ❑ No Spacing exception req'd: ❑ Yes © No inclination -only svy Req'd: ❑ Yes 0'No APPROVED BY APPROVED (� +'�`-� BY �T " - COMMISSIONER Date-'-' ( l L '////����.... THE COMMISSION - Form 10 401 Revised i%r5117W �e ) R I;r[4rjnAs Irom the date of approval (20 AAC 25.005(g)) Submit Form and Attachments in Duplicate � To: Alaska Oil & Gas Conservation Commission From: David E Johnston bp CTD Engineer Date: May 15, 2013 Re: 18-09C Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well 18-09B with the SLB/Nordic 2 Coiled Tubing Drilling rig, targeting Zone 1A. Required Permit? Rig Work (scheduled to begin June 20, 2013) 10-403 PTD 1 MIRU and test BOPE 250 psi low and 3,500 psi high. No Yes 2 Pull cut 2-3/8" liner out of well. No No 3 Set 3-1/2" X 5-1/2" through tubing whipstock at 11,527' MD No No 4 Mill 2.74" window at 11,531' and 10' of rathole. No Yes 5 Drill P131: 3.25" OH, 1603' (12 deg DLS planned) No Yes 6 Set billet at 12,400' MD. No Yes 7 Drill lateral: 3.25" OH, 2600' (12 deg DLS planned). No Yes 8 Run 2-3/8" liner leaving TOL at 10,600' MD No Yes 9 Pump primary cement job: 16 bbls, 15.8 ppg, TOC at 11,600' MD No Yes 10. Perform liner cleanout and GR/CCL log No Yes 11 Perforate liner based on log interpretation (-800') No Yes 12 Set 3-1/2" liner top packer with sized orifice at 10,950' MD No Yes 13 Freeze protect well to 2500' MD No Yes 14 Set BPV; RDMO No Yes Post -Rig Work: 1. Re -install wellhouse, flowline and pull BPV. 2. ASRC flowback/well test Mud Program: • Milling/drilling: 8.5 ppg PowerVis for milling window and drilling (588 psi over -balance). Disposal: • All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3 at DS 6. • 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: • 3.25" From 11,531' MD to 15,000' MD Liner Program: • 2-3/8", 4.7 Ib/ft, L-80, STL Solid liner 10,600' MD - 15,000' MD. • 16 bbls of 15.8 ppg cement will be used for liner cementing leaving TOC outside the window at-11,600' 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 plans. • Maximum planned hole angle is 91.490, inclination at kick off point is 55°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 22,800' to the North. • Distance to nearest well within pool 15-09B - 1,270'. 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. Perforating: • 1.56" , 6 spf, perf guns, 1" CSH work string, & 2-1/16" CSH • 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 • 18-09B Parent well at KOP • 15-07 center to center distance • 15-07B center to center distance • 15-07C center to center distance • 15-07CL1 center to center distance will be isolated with CIBP 1157.81' status - plugged back 879.11' status - plugged back 881.29' Producer -will be SI 881.29'. Producer - will be SI Hazards • DS18 is not considered a H2S pad. • Most recent H2S level on 18-09B is 20 ppm recorded on 2/22/2013. • The lost circulation risk in the 18-09C is considered to be medium Reservoir Pressure • The reservoir pressure on 18-09C is expected to be 3,257 psi at 8,700' TVDSS. (7.2 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2,377 psi. ' • An EMW of 8.4 ppg for this well will provide 543 psi over -balance to the reservoir. David Johnston CC: Well File CTD Engineer Joe Lastufka 907-564-5985 TF;um= 3-1/8" FMC WELLHEAD= FMC ACTUATOR= AXELSON INITIAL KB. ELE 48, BF. ELEV = - KOP = 1900' Max Angle = _ 94" @ 12753' Datum MD = WA DatumTVD= 88W SS PROPOSED 10-3/4" CSG, 45.5#, L-80/J-55, D = 9.953" I 465V EST TOC FROM IA SOZ OF 12/11/99 5700' Minimum ID = " @ 10600' TOP OF 2-3/8" 4.7# LINER TOP OF BKR TACK SLV , D = 5.75" '- 941 T 7-5/8" X 5-1/2- BKR LNR HGR, ID = 4.875" 942g' SAFE X)TES: TMl HBBP PKRS REDUCED TEST �0 PRESS. LIMITS IN SOME CASES. CONTACT WIE (X5102) PRIOR TO ANY PT WORK CMT SQZ HOLE IN 5-112" LNR @ 10623'. WELL ANGLE > 70° @ '. 5-1 /2" CHROME LNR O 2179' 3-1l2" CA TRDP 2A TRSV f�, O = 2.812" LOCK® OUT (9/29/98) J l ST MD I �," D DEV - TYPE VLV LATCH PORT DATE 1 2 3 4 3940 6817 9119 9274 3522 5460 6977 7091 48 50 45 42 OT-ME OT-ME OT-ME OT-ME DMY DMY DMY EMPTY T2 T2 RA - 0 0 0 CMT 10/08/10 09/23/99 09/15/92 12/11/99 7-5/8" CSG, 29-7#, L-80, D = 6-875" 95W — 3-1/2" LTP w /FLOW THRU ORIFK lD = i0598' 2-70" BKR DEPLOYMENT SLV, ID = 1-969" 10600' 3-1/2" TBG PC, 9.2#, L-80, -0087 bpf, D= 2.992" 1-1 10679' 5-1/2" LNR, 17#, 13-CR-80, ID=4-892" 1 1152T 5-1/2" WHIPSTOCK (XX-XX-XX)-11527' PERFORATION SUMMARY REF LOG: ON XX/XX/XX ANGLE AT TOP PERF= _'@ Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ PBTD 2-3/8" LNNR, 4.7#, L-80 TH511, .0039 bpf, D = 1-995" ^-15000' — 929V-13-1/2- PARKER SWS NP, ® = 2.813" 9349' 7-5/8" X 3-1 /2" TPN HBBP PKR, ID = 3-00" 937Z 3-1/2- PARKER SWS NIP, ID = 2.813- 942E 1—i7-5/8- X 5-1/2" BAKER H PKR, D = 4.875- 17-5/8" CSG SDTRK WINDOW (18-09A) 956U- 9629 (SECTION TILL) 10651'-{5-1/2" X 3-1/2" BAKER SABL-3 PKR [ID = 2, 780" (BEHIND LNR) 10668' 3-1/2 PARKER SWN W, D = 2.635" MILLED TO 2.780" (BEHIND LNR) 10680' 3-1/2" WLE G (BB 1ND LNR) E_MD T7 (BEi/� LNR) 5-1/2" MLLOUT WINDOW (18-09C) 11527- - -11600' 1-ITOC DATE REV BY COMMENTS DATE REV BY COMMENTS 04105/86 ORIGINAL COMPLETION 09/15/92 FIG SIDETRACK (18-09A) 07/27/98 CTD SIDETRACK (18-09B) 05/16113 JM) BUILT PROPOSED PRUDHOE BAY UNLIT WELL: 18-09C PE RMT No: AR No: 50-029-21566-03 SEC 24, T11 R R14E� 486 FNL & 342' FEL BP Exploration (Alaska) TREE = ' 3-1 /8" FMC 'WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 48, BF. ELEV = KOP = 1900, Max Angle = 94 @ 12753' Datum MD = N/A Datum TVD = 8800' SS 10-3/4" CSG, 45.5#, L-80/J-55, ID = 9.953" EST TOC FROM IA SOZ OF 12/11 /99 4651' 5700' Minimum ID = 1.941" @ 10598' TOP OF 2-3/8" 4.43# LINER TOP OF BKR TIEBACK SLV, ID = 5.75" 9417' 9429' 7-5/8" X 5-1/2" BKR LNR HGR, ID = 4.875" 9560' 7-5/8" CSG, 29.7#, L-80, ID = 6.875" 10593' 2.70" BKR DEPLOYMENT SLV, ID = 1.969" TOP OF 2-3/8" LNR, 4.43#, ID = 1.941" 10598' 1 3-1/2" TBG PC, 9.2#, L-80, .0087 bpf, ID = 2.992" 1-1 10679' PERFORATION SUMMARY REF LOG: CNL ON 09/12/92 ANGLE AT TOP PERF: 83 @ 12030' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-9/16" 6 12030 - 12095 O 04/08/02 1-9/16" 6 12130 - 12205 O 04/08/02 1-11/16" 4 12240 - 12305 O 07/27/98 1-11/16" 4 12595 - 12705 O 07/27/98 1-11/16" 4 12745 - 12855 O 07/27/98 1-11/16" 4 12915 - 13589 O 07/27/98 5-1 /2" LNR, 17#, 13-CR-80, ID = 4.892" • SAFE TOTES: TIW HBBP PKRS REDUCED TEST PRESb. LIMITS IN SOME CASES. CONTACT WIE (X5102) PRIOR TO ANY PT WORK. CMT SQZ HOLE IN 5-1/2" LNR@ 10623'. WELL ANGLE> 700 @ 11965' & > 900 @ 12262'. 5-1/2" CHROME LNR 2179' 3-1 /2" CA TRDP-2A TRSV NIP, ID = 2.812" LOCKED OUT (9/29/98) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3940 3522 47 OT-ME DMY T2 0 10/08/10 2 6817 5460 50 OT-ME DMY T2 0 09/23/99 3 9119 6977 43 OT-ME DMY RA 0 09/15/92 4 9274 7091 42 OT-ME EMPTY — CMT 12/11/99 9296' 3-1/2" PARKER SWS NIP, ID = 2.813" 9349' 7-5/8" X 3-1/2" TW HBBP PKR, ID = 3.00" 9372' 3-1/2" PARKER SWS NIP, ID = 2.813" 9425' 7-5/8" X 5-1/2" BAKER H PKR, ID = 4.875" 7-5/8" CSG SDTRK WINDOW (18-09A) 9560'- 9620' (SECTION MILL) 10651' �5-1/2" X 3-1/2" BAKER SABL-3 PKR, ID = 2.780" (BEHIND LNR) 10668' 3-1/2 PARKER SWN NIP, ID = 2.635" MILLED TO 2.780" (BEHIND LNR) 10680' —13-1/2" WLEG (BEHIND LNR) ELMD TT (BEHIND LNR) 5-1/2" LNR SDTRK WINDOW (18-09B) 1196T- 11971' (OFF CMT RAMP) PBTD 1--1 13607' 2-3/8" LNR, 4.43#, FL4S, .0039 bpf, ID = 1.941" 1--1 13634' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 04/05/86 ORIGINAL COMPLETION 03/03/06 TEL/PJC GLV C/O 09/15/92 RIG SIDETRACK (18-09A) 03/07/06 RCT/PJC TRDP LOCKED OUT (9/29/98) 07/27/98 CTD SIDETRACK (18-09B) 10/23/10 RCT/AGR GLV C/O (10/08/10) 04/08/02 JAF/tIh ADD PERFS 09/13/03 CMO/TLPj DATUM MD/TVD & PERF ANGL 08/27/04 CAO/TLP GLV C/O ON 05/25/02 PRUDHOE BAY UNIT WELL: 18-09B PERMIT No: F1980790 API No: 50-029-21566-02 SEC 24, T11 N, R14E, 486' FNL & 342' FEL BP Exploration (Alaska) iA NOaW; = m a 1m a (n L a J a 1 O CL � V �L o Oo°'a) m c �(D(D m O a N C a E O V a M N � m Q Q J Q t9 U T 9 E m �° co ao a om r2 z a a m r° a � a `�V T i a a y m F� o Q- m m d Z U a m 3 3❑ Q W O = C � O K a m cn m U Z a x O O ul U m � z m O U m Z a a � C N N N U) N m Q m z ¢ m E e d a O a a` ic7� r N O m r O � N � N o W m y a J a U J J I7 Gi > > 'O C �rn U J J I:i � V O ri co o � N V O D1cc O N c O > i N C Ol q W L C If m O O A Z L C L W fn i w z° w 3 O N tO N i ❑ n CL E n O] V O y y in 0 0 0 a V7 O O O Z m a a aD d a m m a n rr^^ -! 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C V M V O m n m W r toW GO n m n N tr0 N 4] n N L O O a M M M M M M M M M M ` m m m m m m m 111 ` C N U O N o C y i N r O � M N m r M r (6 O m O O) N ❑ O w V O V' N r O m m N N N U v V T R mm m m o O O O O O O O O O m N m N m M m M m M m M m M m M m M m M m M m o >❑> ❑ o rn m rn m e m rn rn rn rn a C G n Z fn ❑ O N Z N N N N N m m m N N N N C y N � � C U � Q O m O O m t0 N O m r o m n N M t0 o) M O N N _ rr M m O N CJ N O) O N O M O) m O) m m m r M N � N N M V: v � N m m m n W r ll r n n P7 ll� ll� ll r m 9 W Z O U V n N�2 O O N r m N N W O m O) m N M N O N CO') r O) n m m N O c O) m M m m n m m m m ro m ro rn a _ Z � E r � n co n co r ao rr (q r (R n (q n 1p n m •- m r` m N m m Z O N <o m O m m O m m O m m O cc m O m O co m O m m m N m m M m m r m m O r m � N m m o M N ^ a v M .- N M t0 N M ci o M ci o rn N m r rn N q o m N aq m n N m of r N m of n N m of n N m of n N m of n N a� M N a m _ o a y � m u) J O O O O O O O O O O O O O O O O O U� O O O N O In O O j m rn rn rn rn rn rn rn m n n m N oT O m E m mco C m L UV m m Q N rn C C ❑ .fir zo in N Z D a.m ro a 0 0 0 0 0 0 0 0 0 0 0 0 0 N o N O O Cl! 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(O (O (O Iq 7 - �E L (O M 1- M M M M M O O U C O) 0I O V O O O O O N O o? g VL mIrl m m E; (Cl m c m m 0 0 0 0 0 0 0 0 0 0 0 0 0 D N O O O O O O N N N N N N i M () M N N 0 0 0 mYV] (Vo (n (n (n (q m 0) N M (n (° n rn 6 co m m N U M 0 m W 3 T mas b q v 0.,. aamsm 1 o ao � o � O eo O� W v y M � =' 3 M ' 9969 009� 9700 — g600 i m I kil.m- e le Mao Z .4 m a �0 62 m "z m �v'bc m a E m u Z c Q m� cps IL �noroN v�nm�nam u�nNammmm�n m�IGNg O. .tNG NV A . z V O ���MONhtI N2 m mmmmmmAnrnnn o00000000 �ov00000000000 LLO�mmY1 N �+)Omm�Om Om H NfVmmr 3ci cl!cy! w�mnrnvmi�Nmu`�io�aN +mmmmmo�� ro ��m�nrrrnn�n� Nryv mNtnA�mOmV�CION a �eomrnmao� Z �c of ao viv mvvmni�mai ��nla'�mmmmmm p uNi ao��monArnn.-m m mmmmmmmmmmmn m m N mm T cl LQ Lq mm^"'^ m m m m m aov�+i oiv vai ai�rmmm t0'l �[O'INNN���NNNN Iq lg000000 N NhtmO lnOnm OOI��TmN p0000000000000 N O O O O O O N N N N N N N f7NNN6 N000u4 l4 4 u� in u2 m m m�NnNmrm N N? Y m n m T O N In z 0 m o a w m m9949999m9$9 mom m � n262222 # 1 1 1 1 f 4 i i 1#+ O i 1 1+# I f## 4# i 1 1+ f 4* i+ l I ■e:Flr BAKER HUGHES INTE Q North America - ALASKA - BP Prudhoe Bay PB IDS 18 18-09 18-09CPB1 Plan 2 Travelling Cylinder Report 13 May, 2013 ri.I BAKER MUGMS INTEQ Company: North America - ALASKA - BP Project: Prudhoe Bay Reference Site: PB DS 18 Site Error: 0.00 usft Reference Well: 18-09 Well Error: 0.00 usft Reference Wellbore 18-09CPB1 Reference Design: Plan 2 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 18-09 - Slot 09 Mean Sea Level 18 : 09 6/12/1998 15:04 @ 48.00usft (generic drilling rig) Tru e Minimum Curvature 1.00 sigma EDM R5K - Alaska PROD - ANCP1 Offset Datum Reference Plan 2 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval 25.00usft Error Model: ISCWSA Depth Range: 11,525.20 to 12,954.20usft Scan Method: Tray. Cylinder North Results Limited by: Maximum center -center distance of 1,492.22 usft Error Surface: Elliptical Conic Survey Tool Program Date 5/13/2013 From To (usft) (usft) Survey (Wellbore) 100.00 9,500.00 1 : Schlumberger GCT multishot (18-09) 9,560.00 11,525.20 Survey #1 CB Gyro MS (18-09A) 11,525.20 12,954.20 Plan 2 (18-09CPB1) Casing Points Measured Vertical Depth Depth (usft) (usft) 12,954.20 8,700.89 2-3/8" Summary Site Name Offset Well - Wellbore - Design PB DS 15 15-34 - 15-34 - 15-34 15-34 - 15-34A - 15-34A PB DS 18 18-07 - 18-07 - 18-07 18-07 - 18-07A - 18-07A 18-07 - 18-07AP81 - 18-07APB1 18-07 - 18-07APB2 - 18-07APB2 18-09 - 18-09 - 18-09 18-09 - 18-09A - 18-09A 18-09 - 18-09B - 18-09B 18-09 - 18-09C - Plan 2 18-10 - 18-10 - 18-10 18-10 - 18-10A - 18-10A 18-10- 18-10APB1 - 18-t0APB1 18-10 - 18-10APB2 - 18-10APB2 18-10 - 18-10B - 18-10B 18-10 - 18-10C - 18-10C 18-10 - 18-10CPB1 - 18-10CPB1 18-27- 18-27A- 18-27A 18-27 - 18-27B - 18-27B 18-27 - Plan 18-27E DO NOT USE - Plan 18-27E Tool Name Description GCT-MS Schlumberger GCT multishot CB -GYRO -MS Camera based gyro multishot MWD MWD - Standard Casing Hole Diameter Diameter Name (in) (in) 2.375 4.125 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 11,530.08 11,625.00 693.14 146.71 550.60 Pass - Major Risk 11,550.09 11,550.10 0.35 42.89 -31.49 FAIL - Major Risk 11,550.09 11,550.10 0.35 42.89 -31.49 FAIL - Major Risk 12,400.01 12,400.00 0.03 0.27 -0.24 FAIL - Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range 11,536.11 13,225.00 1,004.91 509.85 524.44 Pass - Major Risk 11,531.00 13,225.00 1,016.29 507.95 538.69 Pass - Major Risk 11,531.00 13,225.00 1,004.79 509.77 524.72 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor.. 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Z ��oo.-o,uioOr�mcyl�l�ro��„ty Q o m m r v ZarNe o�vminm ornvrn Nm �m mm v N . .rYoo.mim N� oa v oVmi p r'im mr'7 nE r'tm ��� r4��nrn o.'n �2 (ui/-Usn OL) gldaQ luoilloA onil j f� b- y � W - 3 S969 O09w 9704 --� �- -I ----- -_ - -_- (mjUsn 06) (+)uuoS/(-)glnOS 2 � m 9F- o � o �o w y 3 �$ F Ftlrw pap za g:�85 g�g Z7S yo G U T 9 m m U m N m Q y O _m - 9 aau 0c 0 eN3 3a IL n a UJom�ON<mNmIV �D vi<�NON�m I�1�1`I�t�mmmmmmmm.mmmm m O o 0 0 0 o N m r ommrv.mmmmmWmmrn'.�mmmm O 00 p O N N N N N N N N N N N N N N N N N N 3 000nmarv�mvminm.mmNNon Q � U�,� 'rimain m �oav �.mnmmmo�rvnumim 0O mom N moo�m�oo my woo aE#mm Z <mO�1�NOm r mNnnm O T= N N N N N N N N y Z m N W m emo�vmi wmie nnanmmon�anm if a: �. c o0000 H ONOO ....... m m m m mm mmmm to ui oo mo(qnu'i. n n n n N N N n N N N N n M N N N N n O o 0 0 0 0 O O N O O "ry''NtO LommN wmnwmammm......... o.� 0 �00000000000000eoea000 �o6.6 4 4 4 4 aavo 3 8 WO }i}61/ilrri a/4ai+i ii #i6Oid <i #i#dii/di/ Oii1 i O z E O FeAFka BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PBDS18 18-09 18-09C Plan 2 Travelling Cylinder Report 13 May, 2013 TRANSMITTAL LETTER CHECKLISST WELL NAME t � ("� IOG^ n / n PTD9 z r n 7Z' ` Development Service Exploratory Stratigraphic Test Non -Conventional Well /� FIELD:- POOL: ��k" Check Box for Appropriate Letter / 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 j acquired for the pilot hole must be clearly differentiated in both well name (� /� ^ GCS PH) and API number (50- (j 21- 'Z f S - 7©) from records, data and logs acquired for well 4f / 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 tar et 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: 9/09/201 I WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - PTD#:2130720 Company BP EXPLORATION (ALASKA) INC Initial Class/Type Administration 1 Permit fee attached NA 2 Lease number 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 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 5/16/2013 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 Engineering Appr Date VLF 5/17/2013 Geology Appr Date SFD 5/16/2013 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 Conductor string provided Surface casing protects all known USDWs CMT vol adequate to circulate on conductor & surf csg CMT vol adequate to tie-in long string to surf csg CMT will cover all known productive horizons Casing designs adequate for C, T, B & permafrost Adequate tankage or reserve pit If a re -drill, has a 10-403 for abandonment been approved Adequate wellbore separation proposed If diverter required, does it meet regulations Drilling fluid program schematic & equip list adequate BOPEs, do they meet regulation BOPE press rating appropriate; test to (put psig in comments) Choke manifold complies w/API RP-53 (May 84) Work will occur without operation shutdown Is presence of H2S gas probable Mechanical condition of wells within AOR verified (For service well only) Permit can be issued w/o hydrogen sulfide measures Datapresentedon potential overpressure zones Seismic analysis of shallow gas zones Seabed condition survey (if off -shore) Contact name/phone for weekly progress reports [exploratory only] Well Name: PRUDHOE BAY UNIT 18-09C DEV / PEND GeoArea 890 Unit 11650 NA NA NA NA Yes Yes Yes Yes Yes NA Yes Yes Yes Yes NA Yes NA --- --- -- - --- --- - - No - Yes NA ---- NA- - NA Geologic Engineering Wr Commissioner: Date: Co missione : Date Date Entire well in ADL 028307. Program DEV Well bore seg _I On/Off Shore On Annular Disposal PRUDHOE BAY, PRUDHOE OIL POOL - 64015, governed by CO 341 D CO 341 D, Rule 2: There shall be no restrictions as to well spacing except that no pay shall be opened in a well closer than 500 feet to the boundary of the affected area. Conductor set in PBU 18-09 Surface casing set in PBU 18-09 Surface casing set and fully cemented liner will be cemented and perforated Rig has steel tanks; all waste to approved disposal wells. PTD 198-079, Sundry 313-247 Proximity analysis performed. 18-096-isolated w/ CIPB, 15-07, 15-076-plugged back, 15-07C, 15-07CL1 -SI Max formation pressure is 3257 psi(8700'TVD)EMW 7.2. Will drill w/ 8.4 ppg. MPSP is 2377 psi. BOPs will be tested to 3500 psi. H2S measures required. IDS 18 wells are H2S-bearing. H2S measures are required. Expected reservoir pressure is 7.2-ppg EMW. Wellbore will be drilled using 8.4 - 8.5 ppg mud and coiled tubing. -
