The URL can be used to link to this page

Home My WebLink About201-100MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, May 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 16-05A PRUDHOE BAY UNIT 16-05A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/14/2025 16-05A 50-029-20574-01-00 201-010-0 W SPT 8560 2010100 2140 1756 1760 1757 1764 50 282 278 278 4YRTST P Guy Cook 4/13/2025 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT 16-05A Inspection Date: Tubing OA Packer Depth 322 2620 2580 2571IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250412191332 BBL Pumped:2 BBL Returned:2 Wednesday, May 14, 2025 Page 1 of 1 9 9 9 9 9 99 9 9 99 999 9 9 James B. Regg Digitally signed by James B. Regg Date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y Samantha Carlisle at 2:42 pm, Jun 21, 2021 RBDMS HEW 6/24/2021 Abandonment Date 5/31/2021 HEW xGSFD 6/24/2021 DSR-6/24/21MGR28JUN2021 )RUP5HYLVHG6XEPLWZLWKLQGD\VRI&RPSOHWLRQ6XVSHQVLRQRU$EDQGRQPHQW 6XPPDU\RI'DLO\5HSRUWV:HOOSKRWRV:HOOERUH6FKHPDWLF/LVWRI$WWDFKPHQWV ,QIRUPDWLRQWREHDWWDFKHGLQFOXGHVEXWLVQRWOLPLWHGWRVXPPDU\RIGDLO\RSHUDWLRQVZHOOERUHVFKHPDWLFGLUHFWLRQDORULQFOLQDWLRQVXUYH\FRUHDQDO\VLV SDOHRQWRORJLFDOUHSRUWSURGXFWLRQRUZHOOWHVWUHVXOWVSHU$$& Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well S-108 (PTD 201-100)Sundry #:321-015Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCCby the rig workover (RWO) “first call” engineer.AOGCC written approval of the change is required before implementing the change. SecPageDateProcedure ChangeNew 403 Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC Written Approval Received (Person and Date)Procedure, step 215/27/2021No cement top found after sucking gravel out of20” conductor by 7-5/8” surface casing annulusto 10’ below the cut.Authorization to proceed given by AOGCC to conduct cement top job without finding preexisting top of cement.NOSMel Rixie, 5/27/2021Approval:Asset Team Operations Manager DatePrepared: Oliver Sternicki 5/27/2021First Call Operations Engineer DateDigitally signed by Stan Golis(880)DN: cn=Stan Golis (880),ou=UsersDate: 2021.06.21 14:06:15 -08'00'Stan Golis(880) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg roc ;� 1 j0;(1,tc -z� DATE: 5/31/2021 P. I. Supervisor FROM: Bob Noble Inspector SUBJECT: Surface Abandonment PBU S-108 Hilcorp Alaska, PTD 2011000; Sundry 321-015 5/28/2021: 1 traveled to Hilcorp Alaska PBU S-108 and met with Hilcorp representative Rob Bryan. They had the well excavated and cut off. Rob informed me that the OA was found to be full of gravel at that point. Rob included an email chain between him and Mel Rixse of the AOGCC about the gravel. Rob super sucked the gravel down 9 feet and he said they were unable to go any farther. I allowed Rob to fill the OA full of cement as instructed in the email. The well is cut off 4 feet below tundra grade. y 5/30/2021: 1 returned to Hilcorp's PBU S-108 and met with Rob Bryan. I inspected the quality of the cement and it was hard. The marker plate has the correct markings on it, 3/8 -inch thick, and fit the outer most string of pipe. I told Rob they could proceed with welding the plate on the well and bury it. Attachments: Photos (4) 2021-0530 Surface—Abandon—PBU—S- I 08bn.docx Page 1 of 3 C) z M C Q - U) E 0 0 (D CN 0 0 < Lo 0-0-0 0 0 CO N U-) —. PT, - ay s;i ij �. *A :�� Al I oc O •71, MEMORANDUM TO: Jim Regg P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission 7/;q zz f z, DATE: FROM: Lou Laubenstein SUBJECT: Petroleum Inspector May 22, 2021 Surface Abandonment PBU S-108 Hilcorp North Slope LLC - PTD 2011000; Sundry 321-015 5/22/2201: 1 traveled out to PBU S-108 for top -of -cement inspection after the wellhead had been cutoff. Robert Bryan was the Hilcorp rep on location for this inspection. I was handed all the proper paperwork upon my arrival. At first glance there appeared to be -- solid cement to surface, after hitting the top of the cement in the conductor that was not the case. I dug down about an inch and found the conductor to be completely full of gravel. It almost appeared that someone had covered the gravel up with some slurry after the well head was cutoff. I stayed on location and had then dig down as far as they could — about 35 inches and it was still solid gravel. It was decided that they would re- o' submit after all the gravel was removed. Attachments: Photo 2021-0522_Surface_Abandon_PBU_S-108_11. docx Page 1 of 2 Surface Abandon — PBU S-108 (PTD 2011000) Photo by AOGCC Inspector L. Laubenstein 5/22/2021 2021-0522—Surface—Abandon PBU S-108 ll.docx Page 2 of 2 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:201-100 6.API Number:50-029-23021-00-00 PRUDHOE BAY, AURORA OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028257 Property Designation (Lease Number):10. n/a 8. PBU S-108 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon 5 Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG 5 Abandoned Oil WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 7850 Effective Depth MD: L80 11. 2/15/2021 Commission Representative: 15. Suspended Contact Name: Oliver Sternicki Contact Email: oliver.sternicki@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 7029 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool No Packer No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 2857 35 - 2855 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 116 Structural Proposal Summary 13. Well Class after proposed work: No Packer None 3-1/2" 9.3#30 - 1884, 2569 - 5509 Production 30 30 30 7669 36 - 116 470 7-5/8" Contact Phone:(907)564-4891 Date: 80 149020"Conductor 4790 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2823 6890 Intermediate 5271 5-1/2" x 3-1/2" 2565 - 7836 2563 - 7015 7000 / 10160 4990 / 10530 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 0 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:47 am, Jan 12, 2021 321-015 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2021.01.12 08:56:52 - 09'00' Stan Golis SFD 1/13/2021 10-407 MGR12JAN21 DSR-1/12/21 Photo document as described. Yes Required? Comm. 1/28/21 dts 1/28/2021 JLC 1/28/2021 RBDMS HEW 1/29/2021 Plug and Abandon Well: S-108 PTD: 201100 API: 50-029-23021-00 S-108 Plug and Abandon Well Integrity Engineer: Oliver Sternicki, (907)350-0759 Operations Engineer: Brian Glasheen, (907)545-1144 Expected Start Date: 02/15/2021 History Aurora well S-108 (PTD# 201100) was originally drilled and completed in June 2001. S-108 was suspended on 9/11/2015 under sundry #314-411 after a failed RWO attempt to remove collapsed 3.5” tubing and 5.5” casing. All strings were cemented to surface and the wellhead was cut and capped approximately 2 feet below pad grade. Objective Excavate and cut off all casings 3’ below original tundra, permanently install well name cap, and backfill excavation. Procedure 1. Excavate and Cut off all casings 3’ below original tundra level. 2. AOGCC witness of cut-off casings before any top job commences. 3. AOGCC witness cement tops in all annuli. Top off with cement as needed. 4. Bead weld marker cap on outermost casing string. Photodocument all steps and AOGCC witness of installed cap. Marker cap to read as follows: Hilcorp North Slope LLC S-108 API No. 50-029-23021-00 PTD No. 201100 24 hour notice to AOGCC. 2 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:201-100 6.50-029-23021-00-00 PRUDHOE BAY, AURORA OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 7850 30 30 30 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 36 - 116 36 - 116 1490 470 Surface 2824 7-5/8" 35 - 2857 35 - 2855 6890 4790 Intermediate Production 5-1/2" x 3-1/2" 2565 - 7836 2563 - 7015 7000 4990 Perforation Depth: Measured depth: None feet True vertical depth: None feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# L-80 30 - 1882, 2567 - 4933 Packers and SSSV (type, measured and true vertical depth) None Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Suspended Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Andy Ogg PBFieldWellIntegrity@hilcorp.co Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)659-5102 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP 5 SPLUG 16. Well Status after work:Oil Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured7029 Sundry Number or N/A if C.O. Exempt: No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Inspect Suspended Well Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028257 PBU S-108 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 30 - 1884, 2569 - 5509 m 5271 By Samantha Carlisle at 1:03 pm, Aug 24, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.08.24 12:36:20 - 08'00' Stan Golis RBDMS HEW 8/26/2020 DSR-8/24/2020 SFD 8/31/2020MGR04SEP2020 ACTIVITY DATE SUMMARY 8/2/2020 Well cut off below pad grade. Suspended well inspection by AOGCC rep Matt Herrera. Daily Report of Well Operations PBU S-108 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name:S-108 Field/Pool: Prudhoe Bay / Kuparuk Oil Permit # (PTD):2011000 API Number: Operator:Hilcorp North Slope LLV Date Suspended: 9/11/2015 Surface Location:Section: 25 Twsp: 12N Range: 12E Nearest active pad or road:S Pad Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good. Pad or location surface: Good. Location cleanup needed: No. Pits condition: N/A. Surrounding area condition: Good. Water/fluids on pad: No. Discoloration, Sheens on pad, pits or water: No. Samples taken: None. Access road condition: Access road and pad in good condition. Photographs taken (# and description): No. Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Well cut off below pad grade. Cellar description, condition, fluids: N/A. Rat Hole: N/A. Wellhouse or protective barriers: N/A. Well identification sign: N/A. Tubing Pressure (or casing if no tubing): N/A. Annulus pressures: N/A. Wellhead Photos taken (# and description): Yes, (1) S-108 surface location. Work Required: None. Operator Rep (name and signature):Eric Dickerman AOGCC Inspector: Matt Herrera Other Observers: Inspection Date: 8/2/2020 AOGCC Notice Date: 7/31/2020 Time of arrival: 11:15am Time of Departure: 11:30am Site access method: Truck/Walk. 5002923021 Re-Inspection Suspended Well—Inspection Review Dep ort In�pec(No: susMFH200803065206 | Date Inspected: 8/2/2020 �| Inspector: Matt Herrera / Type of Inspection VVeUName: PRUDHOEBAY UNAUR0S-l0D Permit Number: 2011000 ' Suspension Approval: Sundry # 315-K90 ' Suspension Date.: 9/11/2015 ' Location Verified? W !fVerified, Huw? GPS - Offshore? 11 Subsequent Date AOG[INotified: 7/31/2020 Operator: Hi|corpNorth Slope, LLC Operator Rep: EhcDickennan Wellbore Diagram Avail? W Photos Taken? W1 l Well Pressures (psi): Tubing: Fluid in Cellar? EJ - - BPV|nstaUed? [] OA: YKP|ug(s)installed? F� VVeUhead[ondition Well casing cutoff and buried approx 1 foot below pad level; surface equipment removed. - Condition of Cellar NA 5unoundin�5urface[ondidon � Gravel covering area where well casing buried showed no sign of leakage or stains and no subsidence - Comments 5upewisor[omments Photo(l)attached. Well does not qualify asP&A due nocut-off depth and temporary marker plate. - Thursday, August 2l2O2O TT, W N O 00 O O N O N STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N 4 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other:Initial Susp Inspect Rpt 171 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 201-100 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-23021-00-00 7. Property Designation(Lease Number): ADL 0028257 8. Well Name and Number: AURA S-108 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,AURORA OIL 11.Present Well Condition Summary: RECEIVED' Total Depth: measured 7850 feet Plugs measured 30 feet !.yy true vertical 7029 feet Junk measured 7669 feet JUL.` U0 2016 Effective Depth: measured 30 feet Packer measured feet E, 4.e1 true vertical 30 feet Packer true vertical feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 1. 9 5#H-40 36 116 36 116 1490 470 Surface 2823 7-5/8"29.7#L-80 35-2859 35-2857 6890 4790 Intermediate Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner Perforation Depth: Measured depth: 7536 7566 feet feet 7620-7632 feet True vertical depth: 6715-6745 feet feet 6799-6811 feet JAN 2 52Wi! Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 -386 0 1035 326 Subsequent to operation: Suspended Well 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Gd Exploratory 0 Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP IZI SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-490 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,/ Garry R(Wipro) Title PDC Principal Engineer Signature r► ��,✓//�� Phone +1 907 564 4424 Date 6/30/16 Form 10-404 Revised 5/2015tr'�� 1/71.- 9 /Z / I RBDMS 0-iJUL0 6 2016 Submit Original Only �� //6 e .O O co co co LC I- O O LU In LI) ~ O O O O O P P U o 0 0 0 0 rnrnCD "`" v CO O O O O mPCOI,- co N- CO N V LO N CO CO = 000) 000 a) N V cr H N- CO CO Ln CO N O a) CO CO Lf) 0) CO LO N V N I a) CO a) Oa) COLO Ln C7) co 00 O P 00 00 co LO N LO I— P LC) O 0 ++ 4-a O r a0 0) N CO LC) CO O O a) a) ^ CO CO in ".:1- M LO V/ N Lf) N Ids p c0 c0 CO 0 0 0 Cr) J J 0) N L CO MCO •� Ln N a) a) a) U - CV N N \ \ P P P h LO M M M t +'' co P a) L(") co O (N P co L() P C00 co O) co co a) d N N N P N J Z Z ,0 0 0 c F- w H H O Ou_ O O Z Z Z f 0 0 0000 0DIf2CD : 0U) 0_ d F- F • • c 0 N a) O d Q 0 O 0 -0 O 2 5 0 E 0 < 0- w Co 0 a) 0 E a a) D 5 LL 0 z w I- Q o � o N F- N Q i CO U • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: S-108 Field/Pool: Prudhoe Bay!Prudhoe Oil Permit#(PTD): 2011000 API Number: 50-029-23021 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 9/22/2015 Surface Location: Section 25 — Twsp: 12N Range: 12E Nearest active pad or road: S Pad Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges,fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean gravel. No standing fluid, no sheen or discoloration. Pad or location surface: Clean gravel pad Location cleanup needed: None Pits condition: None Surrounding area condition: Good Water/fluids on pad. Minimal (puddles) Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good gravel road Photographs taken (#and description): 3 showing gravel pad and reserve pit with adjacent well houses for reference Condition of Wellhead AOGCC requires. 1)a description of the condition of the wellhead, 2)well pressure readings,where practicable, 3)photographs showing the wellhead condition Wellhead/tree/valve description, condition: None: wellhead removed Well has been plugged and abandoned 4 ft below pad level, not below tundra Cellar description, condition, fluids: None, filled w/gravel Rat Hole: None Wellhouse or protective barriers: None Well identification sign: None\ Tubing Pressure (or casing if no tubing): N/A Annulus pressures: N/A Wellhead Photos taken (#and description) None Work Required: None Operator Rep (name and signature) Josh Murphy _ y''✓�� AOGCC Inspector: Jeff Jones Other O servers:1141 U Inspection Date: 6/6/2016 AOGCC Notice Date. 6/4/2016 Time of arrival. 10:00 AM Time of Departure: 10:30 AM Site access method: P/U truck S is ..... _._ V E L C, ^ G CD ~ CU o .co dLn l J — - Jj a o TO Q M OVi Lf1 ir 1�l1 O cnp O a o th N o C W O N CO QQ rn 45 O " CJ O co Ci.. th r, N `o 0 c 0 C1 C _ d y ch d T 7 0 t '3 0 M 2 d m h n c o O na .,L,g M - a n Ch N c O m m o m m c c _ m`o a] o y Eac g m o O `c_a a .9.o Q d U cO J E m g L c U H Q co O N •CD C 4 CO ry a m o 4 �m a 7 -J to m Y n L C 2 p �N �11J 0)a 3 %' _ a ci C d N 5 co (% �e O Q u) c th o IT': 0 n x W a m M W r`o - N { In a Tr N _ m 0 a S -� C rn to u i a m , , - - ,.„.,_,-:,---,, , _#40-. : ',,-,,.,.,'. * t lit! . .4.''' ,4101104' t 4. ,..,, t_ 1 'ir ,41, ,� t#. 41110 Aolii"i4 . j '[ c t a I • ' � s� Y . mo. 4410r,. __..: .- . , :_,,-, .„_ -I €rte r �q}i ° a ' .. tAli . . , .., . ,or 1,,.!, ,,,,,,,,, - - , ,. . - . , , . ,.. . ,,,.. . ,. . ., ,. . .. . . ., . ......,.. . . .. , la plir . , .........,,, ... ,, ... .. . . , .. . , . .• , ......... ..,. IN will- P PlIFIF 11 . a ......... IMi ,... . I . -....,.. III 11 ,. .,,,,,., ,, ,.._ - . . • . . . -..- .,,,, - III- ' .,.. . ,., , ....,: .,.. ....„ ,..............„,„,....„_„._ ,„, ! IV! ' PFAIII , A , .- A I /4111P t , - •. 4 ,.. 1 ArA .,„,..,. .,.. . „..,,,... . , ,; al irI .. li if i 1.1� µ NIIIiihi, 1116.. 'iK i f '� fi ie .... Lk:- .d 9 ' 111111 I .11, ip. J!N �'" a M,YIF -.- 11-xi4 TREE= - 31t8 pwt VELI e1'BELOW -1S 0 8 ( I fig_ RAC VYaLI SADS TY NOTES: ACTUATOR= 3_1/8. REMOVAL(09/10/15) PAD LVL 1 rIIi II r 0' - 1890' —ICENENTTOSURFACE,STAGE 3(10/1114) OKB.ELEV= 70.25 �I1I1I�I1I Vile"►i♦ BE. ILEV= 41.2' ilii.%♦%% - 993' —{TAM FORT COLLAR D=6.875" KOP= 3150' 3-1/2"KLL STRING, 1 1884' Pit!,L III�r XiiiIIIIIII+ . .NAN.1,,,NApl+41 yip Max Angle= 48"©5502' 9.3#,L-80 NSCT, - % oioio 1890' --I TOP OF STAGE 2-CMT(10!07/14) Datum MD= 7591' .0087 bpf,ID=2.992" A. * i' a01*.: 2559' 7-5/8"CREW RETAINER(10/06/14) Datum TVD= 6700'SS 5-1/2"CSG STUB(10/02/14) H 2565' �10; _ 3-1/2"TBG STUB(Rig 10/04/14) 1I 2569' 2601' 5-1/2'CSG&3 1!2"TBG COLLAPSE) 7-518"CSG,29.7#,L-80 BIC,D=6.875' — 2857' �I1;1f�,' VOA 2575' H TOP OF STAGE 1-CMT(10/05/14) 10101.1 4f/I4 GAS LIFT MANDRELS ..4' ST MD ND DEV TYPE VLV LATCH FORT DATE Torzir.e► ESTIMATED TOC !CAI + � 3 3005� 3003 6 KBG2-9 DMY INT 0 09/06/01 (06/21/01) -- -3180 I. ,//�� 2 3669 3628 31 KBG2-9 SO INT 22 10/20/08 1 5385 4848 47 KBG2-9 'DMY INT 0 09/25/03 �IiiI�► ty `STA#1=HAS EXTH+DED PACKING STACKS DMV 16,1,1♦% ►. ►111 + ALL GLV'S CEMENTED ►6,16,16,1' • 11%6,16,%' ,II*6,1 i P. ►Illi r: ps 04 III: r k11i ••III. r ►. 44F4 i 144 ►I1I1It �I*6,16,+1►' P c ►1I�I 5443' —13-1/2"HES X NP,D=2.813" Ag ►616,%41 Cl etI.I4: rid ►IiIiI� , or �►6,771 - 549T 13-1/2"NO SUB,D=3.00" '1 0I1I1ji k• 441 5-1/2"CSG,15.5#,L-80 BTG,D=4.95" 0 �I1IiII 5497' %,%%i 550y --15-1/2'X 3-1/2"XO,D=2.968' �..a�►.�i ayC°► 0>,p: �1/2"TBG,9.3#,L-80 NSCT,.0087 bpf, D=2.9� .5497' 1.%%• 5509' 3-1/2"SEAL ASSY w!MULE SHOE,D=3.00" II. , ►iii TOP FO SCHRADER BLEAT — 6688 and ►IiI1I� III. . viii)• I1I1I*, Pili! • 6164' —31/2'FES XNP,ID=2.813' PERFORATION S(.*J4ARY ,IIT IQ REF LOG: Ii►�X ANGLE AT TOP PERE: 0' 7536' ►1f tl li 6206' —13-1/2"RA TAG MARKER IN COLLAR Note:Refer to Ftoduction OB for historical perf data SIZE SPF NTERVAL Opn/Sgz SNOT SQZ kl c, 7385' —{3-1/2"RA MARKER N COLLAR AAA: 2-1/8'P 4 7536-7566 S 09/07/01 10/05/14 �i61�� 2" 6 7620-7632 S 04/17/02 10/05/14 ►1►I1j r� 7490` �-�3-112"HES X NP,D=2.813' ll�1l`ill - *I I11� -, I 7669' slm —FISH-1.75'X 9'BALER TOP Kuparuk — 7633'Ind li r1 A w/GAUGE:'- 1-3/8'FN(09/07/01) 'ittlol7722' H LATCH-IN BY PASS RBCEPT,I)=2.250' PBTD —1 7768' 3-1/2"CSG,9.3#,L-80 NSCT,.0087 bpf, D=2.992" 1 7836' DATE REV BY COMMBVTS DATE FEV BY COMMENTS AURORA UI+fT 06/23/01 D-14 I INTIAL COMPLETION WELL S-108 10/11/14 D-16 P&A PERMIT Na "2011000 10/14/14 PJC DREG HO CORRECTIONS AR Ib 50-029-23021 10/14/14 Slut/PJC FINAL ODE APPROVAL SEC 25,T12N,R12E,4511'ESL&4497'FEL 02/29/16 KSBfTLH WELLHEAD REMOVAL(09/10/15) _ BP Exploration(Alaska) • • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 06/06/16 Inspector: Jeff Jones Operator: BPXA Well Name: PBU S-108 Oper.Rep: J.Murphy PTD No.: 2011000 Oper.Phone: 659-5766 Location Verified? Yes - Oper.Email: If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 09/11/15 Date AOGCC Notified: 06/04/16 • Sundry No.: 315-490 Type of Inspection: Initial Wellbore Diagram Avail.? Yes • Well Pressures(psi): Tubing N/A Photos Taken? Yes IA N/A OA N/A Condition of Wellhead: Wellhead removed and cellar backfilled to pad level. Mr.Murphy indicated the well was previously plugged 4'below pad level(not below tundra)with a removable cap on top. ✓ Condition of Surrounding Surface Location: Clean gravel pad.No standing water or evidence of hydrocarbons. Follow Up Actions Needed: None Comments: Well location determined by pad map and location of adjacent wells. Attachments: Operator will submit photos w/report r REVIEWED BY: Insp.Supry 0—be- 6/i ,/,la Comm PLB 12/2015 DEC I #2016 2016-0606_Suspend_PBU_S-108jj.xlsx RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM! N SEP 2 2 2015 WELL OMPLETION OR RECOMPLETION RFPO T AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned L 'Suspended • lb.Well Clik0GCC 20AAC 25.105 ,OAAC 25.110 ' Development p Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Zero • Service ❑ Stratigraphic Test El 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 9/11/2015 201-100 ' 314-411/315-490 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 6/11/2001 50-029-23021-00-00 - 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 6/18/2001 PBU S-108 Surface: -4512'FSL,4498'FEL,Sec.35,T12N,R12E,UM 17. Field/Pool(s): 9. KB(ft above MSL): 70.25 Top of Productive Interval: 1416'FSL,3863'FEL,Sec.26,T12N,R12E,UM GL(ft above MSL): 36.3 PRUDHOE BAY,AURORA OIL' Total Depth: 1415'FSL,3865'FEL,Sec.26,T12N,R12E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: Surface ADL 028257 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 618930 y- 5980715 Zone - ASP 4 c 7850'/7029' - TPI: x- 619526 y- 5982909 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 619525 y- 5982908 Zone - ASP 4 None 1900'(Approx.) 5. Directional Survey: Yes ❑ (attached) No RI 13. Water Depth.if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) N/A 22 Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD,GYRO,PWD,LWD,CMR,Sonic/Caliper 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H40 34' 114' 34' 114' 30" 260 sx Arctic Set(Approx.) 7-5/8" 29.7# L-80 34' 2857' 34' 2855' 9-7/8" 298 sx Arctic Set Lite 3,136 sx Class'G' 5-1/2"x 15.5#/ L-80 2565' 5509' 2563' 4933' 6-3/4" 204 sx LiteCrete,302 sx Class'G' 2534' 3-1/2" 9.3# 24. Open to production or injection? Yes ❑ No O 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 3-1/2"9.3#L-80 1884' None '�� N 3-1/2",9.3#,L-80 2569'-5509' }}�� NOV5 1 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. %MOO NOT 0 '!2O 1 Was hydraulic fracturing used during completion? Per 20 AAC 25.283(i)(2)attach electronic and printed Yes El No Q information ----- ••* , DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period --OP. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate Non► Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only UTL /°/9//S * IV/II/AY f' A,o-2:_-zrs' RBDMV -)SEP 2 5 2015 I.& 28. CORE DATA • Conventional Core(s) Yes ❑ No 17I • Sidewall Cores Yes 0 No Iv! If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes ❑ No WI Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Ugnu 3611' 3578' AAC 25.071. Schrader Bluff M 5272' 4772' Schrader Bluff N 5590' 4989' Schrader Bluff 0 5750' 5102' Base of Schrader Bluff/Top of 6167' 5410' Colville Mudstone CM1 7272' 6451' HRZ 7401' 6580' Kalubik 7526' 6705' Kuparuk C 7534' 6713' LCU/Kuparuk B 7588' 6767' Kuparuk A 7613' 6792' Base of Kuparuk/Top of 7671' 6850' Miluveach Formation at total depth: 31. List of Attachments: Summary of Daily Reports,Summary of Post Rig Work,Well Schematic Diagram,Photos of Cement to Surface and Marker Plate Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sayers,Jessica Email: Jessica.Sayers@bp.com Printed Name: Joe Lastuf a I Title: Drilling Technologist Signature: • one: +1 907 564 4091 Date: I h..21( INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1 a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each segregated pool is a completion. Item 1 b.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only • WELL NAME: S-108 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 2569' Cut and Pull Tubing 2565' Cut and Pull 5-1/2" Casing 2596' 60 Bbls Class 'G' 2559' Set EZSV 1890' 35 Bbls Class 'G' Surface 103 Bbls Class 'G', 49 gallons Arctic Set I • • g North America-ALASKA-BP Page 1 of 32 Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay I Site:PB S Pad 1 Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM 1 Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 9/14/2014 20:00 - 21:30 1.50 MOB P PRE 'PJSM,R/D RIG FLOOR,PREP TO MOVE OFF OF WELL C-19C -PREP TO LAY DERRICK DOWN 21:30 - 00:00 2.50 MOB P PRE PJSM,COVER CONTROL OF WORK DURING RIG MOVE,WSL TOUR PUSHER AND CREW -RAISE RIG,PULL SHIMS AND RIG MATS, PULL OFF OF WELLAND POSITION ON PAD 9/15/2014 00:00 - 01:00 1.00 MOB P PRE PJSM,POSITION RIG ON PAD -REMOVE BOP FROM CELLAR AREA,INSTALL ON TRAVEL SKID AND SECURE 01:00 - 02:30 1.50 MOB P PRE INSTALL REAR BOOSTERS AND FUNCTION 'TEST 02:30 - 06:00 3.50 MOB P PRE PERFORM DERRICK AND TOP DRIVE .INSPECTION BEFORE E LAYING DERRICK OVER INSPECTION REVEALED THAT THE ODS BRIDLE LINE HAD.BEEN DAMAGED,UNABLE TO LAY DERRICK OVER -NOTIFICATIONS WERE MADE TO BP RWO SUPERINTENDENT AND DOYON DRILLING SUPERINTENDENT -STAND BY FOR DECISION ON RIG MOVE 06:00 - 12:00 6.00 MOB N RREP PRE RIG MOVE WILL NOT BEGIN UNTIL BRIDLE LINE IS REPLACED COMPLETE RIG MP2 WORK ORDERS AND RIG MAINTENANCE 1-CONTINUE WITH BP GLOBAL AUDIT -PERFORM WELDING PROJECTS 12:00 - 18:00 6.00 MOB N RREP PRE PJSM,PERFORM HAZARD RECOGNITION SURVEY FOR REMOVAL OF BRIDLE LINE -PREP BRIDLE LINE FOR REMOVAL/ REPLACE,LOCATE EQUIPMENT NEEDED -SCHEDULE CRANE AND OPERATOR PER DDI SUPERINTENDENT 18:00 - 00:00 6.00 MOB N RREP PRE COMPLETE RIG MP2 WORK ORDERS AND RIG MAINTENANCE -CONTINUE WITH BP GLOBAL AUDIT -PAINT PROJECTS, REMOVE RIG TONGS FROM RIG FLOOR,SERVICED PIPE SHED I DOOR SHEAVES 9/16/2014 00:00 - 06:00 6.00 MOB N RREP PRE 1 PJSM,RIG MOVE WAITING ON BRIDLE LINE REPLACEMENT -PERFORM EQUIPMENT AND SPCC CHECKS -RIG MAINTENANCE, MONTHLY MP2 FOR KOOMEY BOTTLES -TIGHTEN CABLE ON PIPE SKATE,PAINT PIPE SHED FLOOR 06:00 - 12:00 6.00 MOB N RREP PRE CONT BP GLOBAL AUDIT INSPECTIONS -RIG MAINTENANCE,GREASE CELLAR DOOR SHEAVES -GREASE/SERVICE MOVING SYSTEM JACK AND STEERING COMPONENTS 12:00 - 18:00 6.00 MOB N RREP PRE j CONT BP GLOBAL AUDIT INSPECTIONS -RIG MAINTENANCE,PAINT RIG,PIPE SHED FLOORS,AND SHAKER ROOM Printed 9/17/2015 4:32 49PM North America ALASKA-BP ` Page 2 of 32 Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E.EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. I UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 00:00 6.00 MOB N RREP PRE RIG MAINTENANCE,PAINTING PROJECTS, CLEAN/CLEAR RIG ROOF ODS !-REMOVE DAMAGED BRIDLE LINE FROM ODS ROOF 9/17/2014 00:00 - 06:00 6.00 MOB N RREPPRE PJSM,RIG MOVE WAITING ON BRIDLE LINE REPLACEMENT CONT.PAINT PROJECTS IN PIPE SHED AND HOPPER ROOM 1—ORGANIZE/CLEAN WELL WELL HARDLINE 1EQUIPMENT 06:00 - 12:00 6.00 MOB N RREP PRE PJSM,REMOVE ELECTRICAL JUNCTION BOX ON TOP DRIVE,RE-WIRE TO OEM SPEC I-FUNCTION TEST TOP DRIVE ROTATION WELDER BUFLDING STEAM LOOP FOR PITS 3&4 12:00 - 00:00 12.00 MOB N WAIT PRE PJSM,PAINT SKATE CONSOLES,SHAKER ROOM FLOOR,AND STAIRS AT DRIVING CAB -CONT.HOUSEKEEPING AND MP 2 WORK ORDERS j-REPAIR WEATHER STRIPING AROUND CELLAR DOORS -HANG"LOW CLEARANCE"SIGNS ON FRONT OF RIG RECOVER CERTIFICATION#'S ON SAFETY CABLES -PREP WELDS ON RIG FLOOR MUD MANIFOLD FOR MPI -CREATE AS-BUILT DRAWING FOR RIG FLOOR MUD MANIFOLD 9/18/2014 00:00 - 12:00 12.00 MOB N - WAIT PRE PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -PAINT PROJECTS,CLEAN CATTLE CHUTE, MP-2 WORK ORDERS,MENTORING MOTORMAN POSITION -PAINT LANDING BY BRAKE TANK,FUNCTION TEST MOVING SYSTEM 12:00 - 00:00 12.00 MOB N WAIT PRE PJSM,RIG MAINTENANCE,CONT.PAINT PROJECTS I-CLEAN OUT SECONDARY CONTAINMENTS THROUGHOUT RIG,CLEAN UNDER STEAM TABLES '-REPLACE DAMAGED AND UN-LEDGEABLE SIGNAGE THROUGHOUT RIG -PAINT STEAM LINES IN HOPPER ROOM, CLEAN AND PAINT AIR SLIPS 9/19/2014 00:00 - 12:00 12.00 MOB N WAIT PRE PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -RIG MAINTENANCE,CONT PAINT PROJECTS -LOCKOUT AND CLEAN UNDER PIPE SKATE 12:00 - 20:00 8.00 MOB N WAIT PRE PJSM,PERFORM SPCC AND EQUIPMENT CHECKS _RIG MAINTENANCE,CONT PAINT PROJECTS 20:00 - 00:00 j 4.00 MOB N WAIT PRE BRIDLE LINE ON LOCATION AT 20:00, INSPECT AND CONFIRM IT IS CORRECT -HIGH WINDS 28-36 MPH,UNABLE TO OPERATE CRANE TO ASSIST LINE INSTALL 9/20/2014 00:00 - 09:00 9.00 MOB N WAIT PRE PJSM,PERFORM SPCC AND EQUIPMENT CHECKS WAITING ON WEATHER AND CRANE OPS TO INSTALL BRIDLE LINE -RIG MAINTENANCE,CONT PAINT PROJECTS Printed 9/17/2015 4.32:49PM North America ALASKA BP „ Page 3 of 32 Operation SunmaryiReport Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) I Project:Prudhoe Bay I Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task 1 Code I NPT I NPT Depth j Phase Description of Operations (hr) (usft) 09:00 - 12:00 3.00 MOB N RREP PRE PJSM,PERFORM HAZARD ASSESSMENT j CHECK LIST WITH WSL,TOOLPUSHER, CRANE OPS AND CREW -INSTALL NEW ODS BRIDLE LINE -R/D CRANE OPERATIONS 12:00 - 13:30 1.50 1 MOB P PRE PJSM FOR BRIDLE UP AND LAY DERRICK IOVER PERFORM SPCC AND EQUIPMENT CHECKS FINAL R/D FLOOR PREP 13:30 - 14:30 1.00 MOB P : PRE LAY DERRICK OVER AND SECURE TO DERRICK STAND 14:30 - 15:00 0.50 MOB P PRE PJSM WITH CREW AND CRANE OPERATOR ' '-USE CRANE TO PICK UP BELLY BOARD AND SET ON RIG FLOOR 15:00 - 16:00 1.00 MOB P PRE RAISE STAIRS,SPOT CHECK AROUND RIG, j PREP FOR RIG MOVE OFF OF LOCATION -FUNCTION TEST MOVING SYSTEM AND EMERGENCY STOPS -RAISE RIG AND MOVE TOWARD PAD IENTRANCE 16:00 - 19:30 3.50 MOB N WAITPRE I FIELD WIDE EMERGENCY SHUT DOWN PER BP SECURITY I-STAND BY,WAIT ON SECURITY 19:30 - 00:00 4.50 MOB j P I PRE PJSM,BEGIN MOVE FROM PBU C-PAD TO i J-PAD PULL ONTO SPINE ROAD AT 21:00 HRS -POSITION OFF SPINE ROAD ONTO J-PAD 9/21/2014 00:00 - 15:00 15.00 MOB N WAIT PRE PJSM,PERFORM SPCC AND EQUIPMENT - CHECKS -POSITION RIG ON PBU J-PAD ENTRANCE -STAND BY TO LAY RIG MATS -RIG MAINTENANCE AND PAINT PROJECTS -WELDING PROJECTS ON DRAIN GRATES IN 'HOPPER ROOM 15:00 - 16:00 1.00 MOB N WAIT PRE PJSM,RIG READY TO MOVE WAIT ON SECURITY 16:00 - 18:00 2.00 MOB P PRE MOVE RIG FROM PBU J-PAD ENTRANCE TO M-PAD ACCESS ROAD I 1-POSITION RIG TO ALLOW TRAFFIC AND I MATS TO PASS 18:00 - 00:00 6.00 MOB N WAIT PRE STAND BY TO LAY RIG MATS 1 ,-RIG MAINTENANCE AND PAINT PROJECTS 9/22/2014 00:00 - 12:00 12.00 MOB N WAIT I PRE PJSM,PERFORM SPCC AND EQUIPMENT I CHECKS I -STAND BY TO LAY RIG MATS -RIG MAINTENANCE AND PAINT PROJECTS WELDER INSTALL CAGE AROUND ACCESS LADDER PAINT HI-TEMP PAINT ON STEAM LINES IN I HOPPER ROOM I-PAINT ACCESS LADDER CAGE,PAINT I- BRIDLE LINE TUGGERS 12:00 00:00 12.00 MOB N I WAIT I PRE PJSM,PERFORM SPCC AND EQUIPMENT I CHECKS -STAND BY TO LAY RIG MATS I -RIG MAINTENANCE AND PAINT PROJECTS -PAINT TEST PUMP AND RIG FLOOR HYD 4 RESERVOIR TANK Printed 9/17/2015 4:32.49PM North£ iS9e4of32 Operation Summary Reportlf' Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001 V6-E.EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 9/23/2014 00:00 - 12:00 12.00 MOB N WAIT PRE PJSM.PERFORM SPCC AND EQUIPMENT !CHECKS. -STAND BY TO LAY RIG MATS AT M-PAD ACCESS ROAD. -RIG MAINTENANCE AND PAINT PROJECTS. 12:00 - 18:30 6.50 MOB N WAIT PRE PJSM.PERFORM SPCC AND EQUIPMENT CHECKS. -STAND BY TO LAY RIG MATS AT M-PAD ACCESS ROAD. 18:30 - 20:30 2.00 MOB P PRE MOVE RIG FROM M-PAD ACCESS ROAD TO S-PAD ENTRANCE. 20:30 - 00:00 3.50 MOB P PRE STAGE AT S-PAD ENTRANCE AND LAY RIG MATS. REMOVE REAR BOOSTERS. 9/24/2014 00:00 - 03:00 3.00 MOB N WAIT PRE PJSM.PERFORM SPCC AND EQUIPMENT CHECKS. STAND BY TO LAY RIG MATS AT S-PAD ENTRANCE. 03:00 - 06:00 3.00 MOB P PRE MOVE RIG FROM S-PAD ENTRANCE ONTO S-PAD. 06.00 - 09:30 3.50 MOB -P PRE - READY'RIG FLOOR,LAY MATS. II -SECURE BRIDLE LINE. MAKE UP 11"X 13-5/8"ADAPTER FLANGE TO BOTTOM OF STACK. 09:30 - 12:00 2.50 MOB P PRE PJSM.MOVE OVER WELL. -SLOW GOING AS IT IS VERY TIGHT. -RIG ACCEPTED AT 12:00 HRS/09/24/2014. 12:00 - 17:30 5.50 RIGIJ P PRE •PJSM.RIG UP LINES IN CELLAR. -RIG UP KILL MANIFOLD,SPOT MUD PUMP #2. -SPOT FLOW BACK TANK AND R/U HARD LINES. -TAKE ON 8.5 PPG SEAWATER. -IA=460 PSI,OA=500 PSI. 17:30 - 18:00 0.50 RIGU P PRE RIG EVACUATION TABLE TOP DRILL WITH !CREW. AAR WITH CREW TO DISCUSS MUSTER AREAS AND H2S PAD REQUIREMENTS. 18:00 - 18:30 0.50 RIGU P PRE TEST LINES AND MANIFOLD TO 250 PSI LOW, 3,500 PSI HIGH FOR 5 MINUTES.GOOD TEST. 18:30 - 21:30 3.00 RIGU P PRE PJSM.PULL BPV. P/U DSM LUBRICATOR. -PRESSURE TEST LUBRICATOR TO 250 PSI LOW,3,500 PSI HIGH FOR 5 MINUTES.GOOD TEST. -PULL BPV. -L/D LUBRICATOR. -TBG=500 PSI. Printed 9/17/2015 4:32:49PM North America-ALASKA B Page 5 of 32 Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:OO:OOAM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21.30 - 00:00 2.50 KILLW P DECOMP PJSM.WELL KILL OPERATION. -TBG=100 PSI,IA=140 PSI,OA=220 PSI. CIRCULATE: 1-ICP AT 3 BPM=220 PSI,FCP AT 4 BPM=240 PSI.TOTAL 60 BBLS UNTIL 8.5 PPG SEAWATER RETURNS AT SURFACE. BULLHEAD: ICP AT 3 BPM=630 PSI,FCP AT 3 BPM=930 PSI.TOTAL 65 BBLS BULLHEAD. MONITOR WELL FOR 15 MINUTES: I INITIAL:TBG=100 PSI,IA=100 PSI,OA= 1150 PSI. FINAL:TBG=100 PSI,IA=100 PSI,OA=150 PSI. 24 HR FLUID LOSS=70 BBLS 8.5 PPG SEAWATER. 9/25/2014 00:00 - 07:00 7.00 KILLW P DECOMP PJSM.PERFORM SPCC AND EQUIPMENT . CHECKS II PJSM.WELL KILL OPERATION. -BLEED OFF OA PRESSURE FROM 150 PSI II TO O PSI IN 5 MINUTES.ALL GAS,NO FLUID. MONITOR WELL FOR 30 MINUTES: INITIAL:TBG=25 PSI,IA=25 PSI,OA=70 PSI. FINAL:TBG=25 PSI,IA=25 PSI,OA=65 PSI. NO GAS NOTED AT SURFACE IN IA OR TUBING. CALL ODE AND SUPERINTENDENT. DECISION MADE TO CIRCULATE DOWN IA UP OA. i CIRCULATE: PUMP AT 6 BPM=700 PSI.PUMP 95 BBLS UNTIL 8.5 PPG SEAWATER NOTED IN RETURNS. -MONITOR WELL FOR 30 MINUTES: INITIAL:TBG=25 PSI,IA=25 PSI,OA=70 PSI. FINAL:TBG=25 PSI,IA=25 PSI,OA=55 PSI. -CALL ODE DECISION MADE TO BLEED OA TO 0 PSI,SHUT IN TO ALLOW PRESSURE TO BUILD,REPEAT. BLEED OA TO 0 PSI,SHUT IN 15 MINUTES: TBG=15 PSI,IA=15 PSI,OA=15 PSI. BLEED OA TO 0 PSI,SHUT IN 15 MINUTES: TBG=20 PSI,IA=20 PSI,OA=20 PSI. BLEED OA TO 0 PSI,SHUT IN 15 MINUTES: TBG=25 PSI,IA=25 PSI,OA=25 PSI. ' KEEP SHUT IN 60 MINUTES:TBG=100 PSI, IA=100 PSI,OA=60 PSI.GAS PRESENT IN TBG,IAAND OA. Printed 9/17/2015 4:32.49PM • North AmericaP�;3e s of 32SKA Operation Summary Report Common Well Name:5-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT I NPT Depth Phase I Description of Operations (hr) (usft) 07:00 - 08:00 I 1.00 KILLW P DECOMP 'CONSULT ODE,AGREE TO RE KILL. PJSM.LINE UP TO BULLHEAD DOWN 3-1/2" TUBING. BULLHEAD 65 BBLS 1%KCL DOWN TUBING j AT 3.5 BPM/1000 PSI. -IA=975 PSI WHILE BULLHEADING,OA=900 PSI. CIRCULATE 40 BBLS DOWN TUBING,TAKING I RETURNS THRU CHOKE UP IA TO FLOW BACK TANK. -SMALL AMOUNT OF GAS OBSERVED UP I/A TURNING QUICKLY TO BRINE. -CIRCULATE AT 4 BPM=400 PSI. -CIRCULATE DOWN IA TAKING RETURNS UP OA,50 BBLS. -SMALL AMOUNT OF GAS BACK INITIALLY TURNING QUICKLY TO CLEAN BRINE. CIRCULATE 50 BBLS AT 5 BPM=500 PSI. SHUT DOWN,SHUT IN WELL AND MONITOR 'PRESSURES: ' 08 00 - 09:00 1.00 KILLW P DECOMP MONITOR WELL BORE PRESSURES. -OA,IAAND TUBING SHUT IN PRESSURES INITIALLY 150 PSI EACH. -AFTER(1)HOUR,TUBING=90 PSI,IA=90 PSI,OA=80 PSI. 09:00 - 09:30 0.50 KILLW P DECOMP PJSM.LINE UP AND PUMP DOWN TUBING TAKING RETURNS UP IA. !-PUMP 40 BBLS AT 3.5 BPM=400 PSI. -PUMP 50 BBLS DOWN IA TAKING RETURNS UP OAAT 3.5 BPM=350 PSI. I-NO GAS OBSERVED IN RETURNS DURING EITHER CIRCULATION. I-SHUT IN AND MONITOR WELL BORE PRESSURES. 09:30 - 12:00 2.50 KILLW P DECOMP I MONITOR WELL WHILE WAITING ON DIRTY j VAC TRUCK TO EMPTY FLOW BACK TANK -AT 12:00 HRS,SHUT IN TUBING,IAAND OA PRESSURES DOWN TO 70 PSI EACH. -SLOW PUMP RATES,PUMP#1:2 BPM=150 PSI,3 BPM=220 PSI AT 2552'MD WITH 8.5 I PPG BRINE. 12:00 - 13.00 1.00 KILLW P DECOMP PJSM.VAC TRUCK EMPTYING FLOW BACK TANK. -CONTINUE TO MONITOR WELL. -TUBING,IAAND O/AALLAT 60 PSI SHUT IN PRESSURES. 13:00 - 13:30 0.50 KILLW P DECOMP ,PJSM.LINE UP AND PUMP 40 BBLS 8.5 PPG I BRINE DOWN TUBING,TAKING RETURNS UP IA TO FLOW BACK TANK. -NO GAS OBSERVED IN RETURNS. LINE UP AND PUMP 50 BBLS DOWN IA TAKING RETURNS UP OA,NO GAS IN RETURNS. -BLEED OFF ALL PRESSURE,SHUT IN AND MONITOR. 13:30 - 15:00 1.50 KILLW P DECOMP I MONITOR WELL.OBSERVE PRESSURE BUILD. -AFTER 90 MINUTES,TUBING 90 PSI,IA=80 PSI AND OA=65 PSI. -CONSULT ODE. Printed 9/17/2015 4:32:49PM North America ALAS BP ale 7 of 32 Operation Summary Report`" ' Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ' NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 15:30 0.50 KILLW P DECOMP PJSM.LINE UP TO BULLHEAD 8.5 PPG BRINE I DOWN TUBING. -BULLHEAD 135 BBLS DOWN TUBING,8 BPM, FCP=2450 PSI. -BLEED BACK 20 BBLS,TUBING=0 PSI,IA=0 PSI AND OA=20 PSI. -SHUT IN AND OBSERVE PRESSURES. INITIALLY PRESSURES CAME RIGHT UP TO 190 PSI ON EACH. i-REPORT TO ODE AND ORDER OUT 9.8 PPG BRINE. -CONTINUE TO MONITOR SHUT IN 1PRESSURES. PERFORM DERRICK INSPECTION. 15.30 - 00:00 8.50 KILLW N FLUD DECOMP WAIT ON 9.8 PPG BRINE. 24 HOUR FLUID LOSS=115 BBLS 9.8 PPG BRINE. OA=92 PSI. 9/26/2014 00:00 - 01:30 1.50 KILLW N FLUD DECOMP PJSM.PERFORM SPCC AND EQUIPMENT CHECKS. 01:30 - 03:30 2.00 KILLW P DECOMP PJSM.PERFORM WELL KILL OPERATIONS. -LOAD 400 BBLS 9.8 PPG BRINE IN PITS. SPR#1:2 BPM=150 PSI,3 BPM=220 PSI WITH 9.8 PPG BRINE AT 2,552'MD. BULLHEAD 65 BBLS DOWN TUBING. -PUMP AT 6 BPM.TBG=980 PSI,IA=1000 PSI,OA=980 PSI. CIRCULATE 40 BBLS DOWN TUBING TAKING RETURNS UP IA. -PUMP AT 6 BPM.TBG=500 PSI,IA=140 PSI, SOA=50PSI. -CIRCULATE 130 BBLS DOWN IA TAKING RETURNS UP OA.9.8 PPG BRINE IN RETURNS. -PUMP AT 6 BPM.TBG=200 PSI,IA=325 PSI, OA=65 PSI. PUMPS OFF AT 03:00 HRS,WELL ON A ',VACUUM. LOSS RATE=35 BPH 9.8 PPG BRINE. 03:30 - 09:00 5.50 KILLW P DECOMP !MONITOR WELL. -CONTINUOUS HOLE FILL AT 35-40 BPH. -DISCUSS OPTIONS WITH TOWN.GIVEN THE OK TO SET TWC AND N/D TREE. Printed 9/17/2015 4 32 49P ALASKA BP 41) North America-ALA Page 6 of s2 spc 1 Operation Summary Report Common Well Name S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date 10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM !Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 15:00 6.00 ! WHSUR N WSEQ DECOMP PJSM.SET TWC. -PU DSM LUBRICATOR. -TEST LUBRICATOR TO 250 PSI LOW,3,500 I PSI HIGH.GOOD TEST. -SET TWO WAY CHECK VALVE. -PERFORM ROLLING TEST AT 500 PSI,3 BPM FOR 5 MINUTES. PUMPED AWAY(20)BBLS OF 9.8 PPG BRINE WHILE PERFORMING ROLLING TEST. -ATTEMPT TO GETA HIGH PRESSURE TEST TO 3,500 PSI ON TWO WAY CHECK. I-CHECK TORQUE ON LOCK DOWN SCREWS AND ISOLATE ALL VALVES. -SLOW BLEED OFF,UNSATISFACTORY FOR BOPE TEST.PJSM.PULL TWC. -MAKE UP PULLING TOOL. '-MAKE UP LUBRICATOR AND TEST TO 250 PSI LOW,3,500 PSI HIGH.GOOD TEST. -PULL TWO WAY CHECK VALVE AND INSPECT,SIGNIFICANT GROOVE IN 0-RING AND THREAD DAMAGE. SPR#1:2 BPM=110 PSI,3 BPM=210 PSI -WITH 9.8 PPG BRINE AT 2,552'MD. 15:00 - 17:00 2.00 WHSUR P DECOMP '-MAKE UP LUBRICATOR AND TEST TO 250 PSI LOW,3,500 PSI HIGH.GOOD TEST PICK UP NEW TWO WAY CHECK VALVE AND SET. -PERFORM ROLLING TEST AT 500 PSI,3 BPM FOR 5 MINUTES. -PRESSURE TEST FROM ABOVE TO 3,500 PSI FOR 5 MINUTES.GOOD TEST. 17:00 - 18:00 1.00 WHSUR P DECOMP L/D LUBRICATOR. -BLOW DOWN LINES. '-R/D KILL MANIFOLD. -R/U SECONDARY KILL AND CLEAR CELLAR. 18:00 - 19:30 1.50 WHSUR P DECOMP FMC REPRESENTATIVE BLEED VOID. -N/D TREE AND ADAPTER FLANGE. -CHECK 3-1/2"NSCT HANGER THREADS,9 TURNS. 19:30 - 00:00 4.50 BOPSUR P DECOMP N/U FOUR PREVENTER BOPE. -CHANGE UPPER RAMS FROM 2-7/8"X 5" IVBRTO3-1/2"X6"VBR. 24 HOUR FLUID LOSS=694 BBLS 9.8 PPG BRINE. OA=0 PSI. 9/27/2014 00 00 - 02:30 2.50 BOPSUR P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. j-PERFORM BODY TEST ON 13-5/8"BOPE AND RELATED EQUIPMENT. -CHANGE OUT KILL LINE OTECO SEAL AND CLAMP. Printed 9/17/2015 4:32:49PM • NorthAmerica-ALASKA-BP Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001 V6 E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM I Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table l70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 11:00 8.50 j BOPSUR P DECOMP PJSM.TEST FOUR PREVENTER 13-5/8"BOPE I AND RELATED EQUIPMENT. I-TEST BOPE ACCORDING TO AOGCC REGULATIONS,DOYON AND BP PROCEDURES. '-TEST ANNULAR WITH 2-7/8'TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST UPPER 3-1/2"X 6"VARIABLE RAMS WITH 3-1/2"AND 5-1/2"TEST JOINT TO 250 PSI,3,500 PSI HIGH FOR 5 CHARTED MINUTES. TEST LOWER 2-7/8"X 5"VARIABLE RAMS WITH 2-7/8"AND 4"TEST JOINT TO 250 PSI, 3,500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3,500 PSI HIGH FOR 5 CHARTED MINUTES. -PERFORM ACCUMULATOR DRAW DOWN TEST WITH WSL PRESENT. '-NO FAILURES,JOHN HILL/BOB NOBLE WAIVED WITNESSING. 11:00 - 12:00 1.00 BOPSUR P DECOMP PJSM.RIG DOWN TEST EQUIPMENT. BLOW DOWN ALL ASSOCIATED LINES. 12 HOUR FLUID LOSS=227 BBLS 9.8 PPG BRINE. OA=0 PSI. 12.00 - 14:30 2.50 WHSUR P DECOMP PJSM.RIG UP DUTCH RISER. -RIG UP LUBRICATOR,TEST AT 250/3500 'PSI,5 MIN EACH,CHARTED. -PULL TWO WAY CHECK,TUBING ON A VACUUM. -RIG DOWN LUBRICATOR AND DUTCH RISER. 14:30 - 15:30 1.00 PULL P DECOMP I PJSM. MAKE UP LANDING JT&MAKE UP TO TOP DRIVE. -BOLDS.PULL HANGER TO FLOOR. -HANGER PULLED FREE AT 61K AND 61K UP WT. 15.30 - 16:30 1 00 PULL P DECOMP PJSM.CLOSE ANNULAR PREVENTOR. -CIRCULATE DOWN TUBING W/9.8 PPG BRINE. -ACQUIRE SLOW PUMP RATES. -PUMP#1=1 BPM/60 PSI,2 BPM/60 PSI,3 BPM/100 PSI. -PUMP#2=1 BPM/60 PSI.2 BPM/60 PSI,3 BPM/100 PSI. -SLOW PUMP RATES W/9.8 PPG BRINE AT l 2,530'MD IN 3 1/2"TUBING. -CIRCULATE BRINE DOWN TUBING&THRU CHOKE TO MUD GAS SEPARATOR. I CIRCULATE AT 5 BPM/340 PSI,CIRCULATE 55 BBLS,NO GAS IN RETURNS. -MONITOR WELL,FLUID LOSS RATE=26 BPH.OPEN ANNULAR PREVENTOR. Printed 9/17/2015 4:32:49PM • North America ALASKA •BP• • Page 10 of 32 • Operation Summary Report '< Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date.9/14/2014 End Date 10/11/2014 Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay I Site:PB S Pad Rig Name/No.:DOYON 16 I Spud Date/Time:6/11/2001 12.00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table 170.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 21:00 4.50 I PULL P DECOMP PJSM.POOH WITH 3-1/2"9.3#L-80 NSCT TUBING. -L/D HANGER AND LANDING JOINT. -POOH FROM 2,552 MD TO SURFACE. -RECOVERED:HANGER,3 PUP JOINTS,78 JOINTS,1 X-NIPPLE AND 4.8'CUT JOINT. -TUBING STUB AT 2,542'MD FROM RIG t FLOO R. 21:00 - 23:30 2.50 PULL P DECOMP ,CLEAR AND CLEAN RIG FLOOR. M/U RUNNING TOOL AND SET 6-15/16"WEAR RING. P/U BHA#1 TO FLOOR. -LOAD 2-7/8"DRILL COLLARS AND WASH PIPE IN SHED.STRAP AND TALLY. 23:30 - 00:00 0.50 PULL P DECOMP PJSM.M/U WASH PIPE AND SHOE BHA#1. 24 HOUR FLUID LOSS=449 BBLS 9.8 PPG BRINE. OA=0 PSI. 9/28/2014 00:00 - 00:30 0.50 CLEAN P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. 00:30 - 02:00 1.50 CLEAN P DECOMP PJSM.M/U WASH PIPE AND SHOE BHA#1. I-P/U 3-1/4"DRILL COLLARS FROM SHED. -RIH TO 405'MD. 02:00 - 05:30 3.50 CLEAN P DECOMP P/U AND RIH WITH 2-7/8"HTPAC PIPE FROM SHED. -RIH FROM 405'MD TO 2,386'MD. 05:30 - 07:00 1.50 CLEAN P DECOMP PJSM.SLIP AND CUT DRILLING LINE. -SLIP AND CUT 61'OF DRILLING LINE. 07:00 - 09:00 2.00 CLEAN P DECOMP PJSM.TAG UPAT2,540'MD. -RIG UP CONNECTION JOINT WITH CROSS OVERS. -PICK UP LONG BALES AND ESTABLISH PLAN FORWARD. 09:00 - 10:00 1.00 CLEAN P DECOMP ACQUIRE SLOW PUMP RATES. -MUD PUMP#1:30 SPM=580 PSI,40 SPM= 960 PSI. -MUD PUMP#2:30 SPM=800 PSI,40 SPM= 1300 PSI. -SLOW PUMP RATES WITH 9.8 PPG BRINE AT 2,540'MD. -UP WT=67K,DOWN WT=67K,ROTATING WT=67K,ALL WT CHECKS INCLUDE 40K TOP DRIVE. -ROTATE/WASH DOWN OVER FLARED END OF TUBING STUB. -SLIDE ON DOWN WITHOUT PUMPS OR ROTATING TO 1ST COLLAR AT 2,568'MD. Printed 9/17/2015 4:32.49PM North America ALAS KA BP Pc f,Mage 11 of 32 Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 IZ3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay _ — Site:PB S Pad Rig Name/No.:DOYON 16 i Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 12:00 2.00 CLEAN P t DECOMP I ESTABLISH PARAMETERS,PUMPING 2 BPM= 500 PSI. -FREESPIN TORQUE OFF BOTTOM=500- 1000 FT-LBS. -MILL ON COLLAR WITH 1K WOB AND 1500- 2000 FT-LBS OF TORQUE. -TORQUE LIMITER SET AT 2,500 FT-LBS.40- 45 RPM WHILE MILLING. -TRICKLING IN SAFE LUBE TO SUCTION PIT 'WHILE MILLING. 12 HOUR FLUID LOSS=260 BBLS 9.8 PPG BRINE. OA=0 PSI. 12:00 - 16:00 4.00 CLEAN P DECOMP CONTINUE TO MILL ON COLLAR FROM 2,568' MD TO 2,568.8'MD. -COLLAR LENGTH=A.75'.OBSERVE THROUGH COLLAR AND FREE TRAVEL FOR -1' -TAG UP AGAIN AT 2,569.6'MD AND MILL TO 2.569.8'MD OR-2". -CONFER WITH TOWN ENGINEER AND AGREE TO POOH AND LOOK AT SHOE. -MONITOR WELL FOR 10 MINUTES.WELL STABLE. -TOTAL TIME MILLING ON SHOE=5-1/2 HRS. 16:00 - 18:30 2.50 CLEAN P DECOMP POOH WITH WASH PIPE AND SHOE BHA#1. -L/D 3 JOINTS,BLOW DOWN TOP DRIVE AND CHANGE OUT BAILS. -POOH FROM 2,569'MD TO 405'MD. -MONITOR WELL.WELL STABLE. 18:30 - 20:00 1.50 CLEAN P DECOMP UD DRILL COLLARS. -BREAK AND UD BHA#1. -SHOE HAS NO OUTER WEAR,MINIMAL WEAR ON FACE AND INTERIOR. 20:00 - 21:30 1.50 CLEAN P DECOMP !PJSM.P/U NEW SHOE AND WASH PIPE BHA #2. -P/U DRILL COLLARS FROM CELLAR. -RIH TO 405'MD. 21:30 - 00:00 2.50 CLEAN P DECOMP RIH WITH WASH PIPE AND SHOE BHA#2. -RIH WITH 2-7/8"HTPAC FROM 405'MD TO 12,539'MD. UP WT=66K,DOWN WT=67K. -CHANGE OUT BAILS. 24 HOUR FLUID LOSS=448 BBLS 9.8 PPG BRINE. OA=0 PSI. _ 9/29/2014 00:00 - 00:30 0.50 CLEAN P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT I CHECKS. CHECK CROWN-O-MATIC.OK. Printed 9/17/2015 4:32:49PM • i North America ALASKA BP Operation Summary Report Common Well Name S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date: 10/11/2014 Z3-001V6-E.EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00.30 - 03:00 2.50 CLEAN P DECOMP PJSM.TAG UP AT 2,540'MD. 1-ACQUIRE SLOW PUMP RATES. -MUD PUMP#1:1 BPM=80 PSI,2 BPM=320 PSI. -MUD PUMP#2:1 BPM=100 PSI,2 BPM=410 PSI. -SLOW PUMP RATES WITH 9.8 PPG BRINE AT 2,540'MD. -UP WT=67K,DOWN WT=67K,ROTATING WT=67K,ALL WT CHECKS INCLUDE 40K TOP DRIVE. -ROTATE/WASH DOWN OVER TOP TUBING STUB. -WASH DOWN WITH PUMPS AT 2 BPM=410 PSI FROM 2,541'MD TO 2,570'MD. -MILL FROM 2,570'MD TO 2,572'MD AT 40 RPM,2-3 K TQ,WOB=1.5-2K.PUMP AT 2 BPM 500 PSI -WASH DOWN WITH PUMPS AT 2 BPM=500 I PSI FROM 2,572'MD TO 2,601'MD. -MILL FROM 2,601'TO2,601MDAT40RPM, 1.5-2K TQ,WOB=1-3K PUMP AT 2 BPM=500 'PSI. UNABLE TO MILL PAST 2,601'MD.BAKER SUGGEST POOH AND INSPECT SHOE. -MONITOR WELL FOR 10 MINUTES.WELL STABLE. -TOTAL TIME MILLING ON SHOE=2-1/2 HRS. 03:00 - 07:00 4.00 CLEAN P DECOMP POOH WITH WASH PIPE AND SHOE BHA#2. UD 3 JOINTS,BLOW DOWN TOP DRIVE AND CHANGE OUT BAILS. I-POOH FROM 2,601'MD TO 405'MD. -LAY DOWN WASH PIPE,JUNK SUBS AND BURN SHOE. -SHOE LOOKED GOOD,A FEW CHIPS ON THE FACE. -SOME METAL SHAVINGS IN THE JUNK SUBS AND A BIT OF PARAFIN/TAR. 07:00 - 09:00 2.00 FISH P DECOMP PJSM.DECISION MADE TO PICK UP SPEAR ASSEMBLY. -MAKE UP FISHING,(SPEAR),BHA#3. -PICK UP 3-1/8"DRILL COLLARS FROM PIPE SHED. 09:00 - 11:30 2.50 FISH P DECOMP ,RIH WITH 2-7/8"PAC HT AND FISHING BHA#3. PICK UP SINGLES FROM PIPE SHED,RIH TO 2,536'. -67K UP WT,67K DOWN WT,ALL WT CHECKS INCLUDE 40K TOP DRIVE. -CHANGE OUT TO LONG BAILS FOR FISHING OPERATION. -r 11.30 - 12:00 0.50 FISH P DECOMP (PJSM.MAKE UP TO TOP DRIVE. I-ACQUIRE SLOW PUMP RATES. -#1 MUD PUMP=1 BPM=320 PSI,2 BPM= 1000 PSI. -#2 MUD PUMP=1 BPM=280 PSI,2 BPM= 1100 PSI. 12 HOUR FLUID LOSS=200 BBLS 9.8 PPG BRINE. OA=52 PSI. Printed 9/17/2015 4:32:49PM North America ALASKA-BP Page 13 of 32 • , Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 [Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr)12:00 - 13:30 1.50 (usft) FISH P DECOMP PJSM.TAG TOP OF 3-1/2"TUBING STUB AT 2,540'MD. -ENGAGE FISH,NO GO 10'IN TO 2,550'MD. -CONDUCT PRE JARRING DERRICK INPSECTION. CIRCULATE DOWN TUBING AT 2 BPM 1600 PSI,PUMPED 15 BBLS. OBSERVED SOME RETURNS WHILE PUMPING AND AFTER SHUTTING DOWN PUMP OBSERVED STATIC FLUID LEVEL IN I BELL NIPPLE. I-PULL TO 100K,NO MOVEMENT.JAR LIGHTLY,(20K OVER)AND PULL TO 115K SEVERAL TIMES. JAR AT 100K,(33K OVER UP WT), AND PULL I TO 125K,FISH CAME FREE. 13:30 - 14:00 0.50 FISH P DECOMP PJSM.CIRCULATE(50)BBLS 9.8 BRINE DOWN TUBING. -CIRCULATE AT2 BPM=1330 PSI.MONITOR WELL,LOSS RATE=18 BPH. 14 00 - 16 30 2.50 FISH P DECOMP POOH WITH SPEAR BHA#3. LID 2 JOINTS,BLOW DOWN TOP DRIVE AND CHANGE OUT BAILS. --POOH FROM 2,550'MD TO 303'MD. -MONITOR WELL,WELL STABLE. UD DRILL COLLARS AND SPEAR BHA#3. RECOVERED=28.10'FISH. -CLEAR AND CLEAN RIG FLOOR. 16:30 - 19:00 2.50 FISI-t P DECOMP PJSM.M/U WASH PIPE AND SHOE BHA#4. -RIH TO 407'MD. 19:00 - 21:00 2.00 FISH P DECOMP RIH WITH WASH PIPE AND SHOE BHA#4. -RIH WITH 2-7/8"HTPAC FROM 407'MD TO 2,568'MD AND TAG STUMP. -WORK OVER STUMP AND CONTINUE RIH TO 2,574'MD. -UP WT=66K,DOWN WT=67K. -CHANGE OUT BAILS,M/U TO TOP DRIVE. 21 00 - 00:00 3.00 FISH P DECOMP PJSM.MILL ON 3-1/2"TUBING. -ROTATE AND WASH DOWN FROM 2,574'MD TO 2,599'MD. -ACQUIRE SLOW PUMP RATES. -MUD PUMP#1:1 BPM=60 PSI,2 BPM=380 PSI. 1-MUD PUMP#1:1 BPM=90 PSI,2 BPM=360 PSI. —SLOW PUMP RATES WITH 9.8 PPG BRINE AT 2,599'MD. -UP WT=66K,DOWN WT=67K,ROTATING I WT=67K,ALL WT CHECKS INCLUDE 40K TOP DRIVE. -MILL FROM 2,599'MD TO 2,600'MD AT 50 RPM,1-3 K TQ,WOB=2-4K.PUMP AT 2 BPM= l 1500 PSI -TOTAL TIME MILLING ON SHOE=2 HRS. 24 HOUR FLUID LOSS=378 BBLS 9.8 PPG :BRINE. OA=210 PSI,WITH PUMPS ON. Printed 9/17/2015 4:32:49PM 111/ North America-ALASKA 7 BP , age 14 of 32 Operation Summary Report' Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date.10/11/2014 Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UW:500292302100 Active datum:Kelly Bushing/Rotary Table t70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 9/30/2014 00:00 - 04:00 4.00 FISH P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. PTSM.MILL ON 3-1/2"TUBING. -MILL FROM 2,600'MD TO 2,601.5'MD AT 50 RPM,1-3 K TQ,WOB=2-4K.PUMP AT 2 BPM= 500 PSI. -UNABLE TO MILL PAST 2,601.5'MD,TORQUE 1 LOSS WITH ADEQUATE WOB. -MONITOR WELL FOR 10 MINUTES.WELL STABLE. -TOTAL TIME MILLING ON SHOE=3-1/2 HRS. 04 00 - 06:30 2.50 FISH P DECOMP TPOOH WITH WASH PIPE AND SHOE BHA#4. L/D 3 JOINTS,BLOW DOWN TOP DRIVE AND CHANGE OUT BAILS. -POOH FROM 2,577'MD TO 438'MD. -MONITOR WELL,LOSS RATE AT 12-15 BPH. 06:30 - 08:30 2.00 FISH P DECOMP PJSM.LAY DOWN AND INSPECT BHA#4. LAY DOWN DRILL COLLARS,JUNK SUBS AND STAND BACK WASH PIPE. -INSPECT BURN SHOE,MINIMAL WEAR.OD= 6-11/16". 08:30 - 09:00 0.50 FISH P DECOMP PJSM.MAKE UP SPEAR FISHING ASSEMBLY BHA#5. -PICK UP DRILL COLLARS FROM PIPESHED. 09:00 - 11:00 2.00 FISH P DECOMP PJSM.RIH WITH SPEAR FISHING BHA#5. RIH ON 2-7/8"HTPAC DRILL PIPE. -RIH TO 2,565'MD.UP WT=67K,DOWN WT= 67K. -CHANGE OUT BAILS AND PICK UP KELLY JOINT. 11 00 - 12:00 1.00 FISH P DECOMP PJSM.ACQUIRE SLOW PUMP RATES. -MUD PUMP#1=12 SPM=340 PSI,24 SPM= 1150 PSI. -MUD PUMP#2=10 SPM=300 PSI,20 SPM= 1100 PSI. -SLOW PUMP RATES DONE WITH 9.8 PPG BRINE AT 2,565'MD INSIDE 3-1/2"TUBING. 12 HOUR FLUID LOSS=155 BBLS 9.8 PPG BRINE. OA=50 PSI. 12:00 - 12:30 0.50 FISH P DECOMP PERFORM PRE-JARRING DERRICK INSPECTION,NOANOMOLIES FOUND. -SERVICE AND INSPECT RIG. -PUMP DOWN TUBING AT 2-1/2 BPM=1800 PSI,NO RETURNS UP I/A,20 BBLS PUMPED i I AWAY. 12 30 - 15:00 2.50 FISH P DECOMP PJSM.WORK PIPE AND JAR AT 110K,(43K OVER UP WT). - LL EVERY ON WEIGHT INDICATOR !AFTER ( STRETCH CALCULATION INDICATES STUCK POINT AT OR AROUND-2,500'. -AFTER(44)JAR HITS,JARS NEED TO COOL OFF. -CONDUCT DERRICK INSPECTION AND RESUME JARRING,JARS WORN OUT. Printed 9/17/2015 4:32:49PM North America /ALASKA BP Page 15 of 32 Operation Summary Report f Common Well Name S-108 AFE No Event Type:WORKOVER(WO) Start Date.9/14/2014 i End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site.PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM I Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 16:00 1.00 FISH P DECOMP PJSM.RELEASE SPEAR FROM FISH. -RELEASE BY ADJUSTING TORQUE LIMIT TO 2,000 FT-LBS AND TURNING TO THE RIGHT AT 10 RPM. -PICK UP SLOWLY,OBSERVING NO OVER PULL,SPEAR RELEASED OK. CIRCULATE 40 BBLS DOWN DRILL PIPE AT 2 _ BPM=1130 PSI. 16:00 - 17:30 1.50 FISH P DECOMP PJSM.POOH WITH SPEAR FISHING BHA#5. MONITOR WELL BEFORE POOH.WELL STABLE. I-BLOW DOWN TOP DRIVE,CHANGE OUT BAILS. POOH FROM 2,568'MD TO 303'MD. -MONITOR WELL.WELL STABLE. 17:30 - 18:00 0.50 FISH P DECOMP BREAK DOWN AND L/D SPEAR FISHING BHA #5. -L/D DRILL COLLARS. -CHANGE OUT JARS AND BUMPER SUB. ' -CLEAR AND CLEAN RIG FLOOR. 18:00 - 20:30 2.50 FISH P DECOMP PJSM.M/U AND RIH WITH DRESS OFF BHA#6. -P/U DRILL COLLARS. 1-RIH TO 220'MD. 20:30 - 22:00 1.50._._. FISK P DECOMP RIH WITH DRESS OFF BHA#6. '-RIH FROM 220'MD TO 2,544'MD. -CHANGE OUT BAILS. -P/U KELLY JOINT AND M/U TO TOP DRIVE. 22 00 - 23:30 1.50 FISH P DECOMP DRESS OFF 3-1/2"TUBING STUB. -UP WT=66K,DOWN WT=67K,ROTATING WT=67K,ALL WT CHECKS INCLUDE 40K TOP DRIVE. -ACQUIRE SLOW PUMP RATES. -MUD PUMP#1=12 SPM=120 PSI,36 SPM= 660 PSI. -ROTATE AND DRESS TOP OF STUB FROM 2,568'MD TO 2,572'MD.NO GO AT 2,572'MD. -WOB=1-2K AT 50 RPM,FREE TORQUE= 1,500 FT-LB. 23:30 - 00:00 0.50 FISH P DECOMP I POOH WITH DRESS OFF BHA#6. -L/D KELLY JOINT,BLOW DOWN TOP DRIVE AND CHANGE OUT BAILS. 24 HOUR FLUID LOSS=325 BBLS 9.8 PPG BRINE. OA=30 PSI. 10/1/2014 00:00 - 02:30 2.50 FISH P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. PJSM.POOH WITH DRESS OFF BHA#6. -MONITOR WELL BEFORE POOH.WELL (STABLE. 1-POOH FROM 2,547'MD TO 283'MD. MONITOR WELL.WELL STABLE. 02:30 - 03:00 0.50 FISH P DECOMP 'I BREAK DOWN AND L/D DRESS OFF BHA#6. L/D DRILL COLLARS. CLEAR AND CLEAN RIG FLOOR. 03:00 - 03:30 0.50 FISH P DECOMP PJSM.MAKE UP SHORT CATCH OVERSHOT BHA#7. -PICK UP DRILL COLLARS FROM PIPESHED. j-RIH TO 184'MD. Printed 9/17/2015 4:32:49PM • North America ALASKA BP Page 16 of 32 Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay T Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 06:00 2.50 FISH P DECOMP PJSM.RIH WITH SHORT CATCH OVERSHOT BHA#7. -RIH ON 2-7/8"HTPAC DRILL PIPE. -RIH FROM 184'MD TO 2,543'MD. -CHANGE OUT BAILS AND PICK UP KELLY JOINT. 06 00 - 06 30 0.50 FISH P DECOMP PJSM.PREPARE TO BACK OFF 3-1/2"TUBING. UP WT AND DOWN WI'=67K.WEIGHT CHECKS INCLUDE 40K TOP DRIVE. -ACQUIRE SLOW PUMP RATES. -MUD PUMP 1=12 SPM=50 PSI AND 24 SPM =260 PSI. -MUD PUMP 2=10 SPM=30 PSI AND 20 SPM 1=250 PSI. -TAG TOP OF STUB=2,468'AND ENGAGE OVERSHOT,(1')SWALLOW. i-VERIFY LATCHED ON W/70K OVER PULL AND SLACK OFF TO 71K. -SET TORQUE LIMITER TO 2,500 FT-LBS AND APPLY 2-1/2 LEFT HAND TURNS TO PIPE. � � I -HEAR AUDIBLE POP AND OBSERVE PIPE JUMP.OPINION IS WE BACKED OFF THE DRILL PIPE. -APPLY 4-1/2 RT HAND TURNS,CONTINUE TO ROTATE TO THE RIGHT AND RELEASE OVERSHOT. -LAY DOWN KELLY JT. 06:30 - 07:30 1.00 FISH P DECOMP PJSM.POOH WITH SHORT CATCH OVERSHOT BHA#7. I-MONITOR WELL BEFORE POOH.WELL ASTABLE. 1-POOH AND L/D 2 JOINTS. -POOH FROM 2,543'MD TO 2,480'MD. -P/U KELLY JOINT,P/U AND M/U 10'DRILL PIPE PUP FOR SLIP AND CUT. 07:30 - 09:00 1.50 FISH P DECOMP 1 PJSM.SLIP AND CUT 68'OF DRILLING LINE. 09:00 - 12:00 3.00 FISH P DECOMP PJSM.POOH WITH SHORT CATCH OVERSHOT BHA#7. L/D 10'DRILL PIPE PUP AND KELLY JOINT. -CHANGE OUT BAILS. -POOH FROM 2,480'MD 184'MD. -CHECK TORQUE ON EVERY CONNECTION. 12 HOUR FLUID LOSS=133 BBLS 9.8 PPG BRINE. OA=30 PSI. 12:00 - 12:30 0.50 FISH P DECOMP L/D DRILL COLLARS FROM 184'MD TO SURFACE. j 1-BREAK AND L/D SHORT CATCH OVERSHOT BHA#7_ 12:30 - 14:00 1.50 FISH P DECOMP RIH WITH WASH PIPE TO 191'MD. -POOH AND L/D 1 X 1 TO SHED. I-CLEAR AND CLEAN RIG FLOOR. 14:00 - 19:00 5.00 EVAL N WAIT DECOMP 'WAIT ON HALLIBURTON WIRE LINE. -CLEAN AROUND RIG. Printed 9/17/2015 4.32.49PM • North America-ALASKA BP .Page 17 of 3,2 Operation Summary Report Common Well Name S-108 AFE No Event Type WORKOVER(WO) Start Date:9/14/2014 , End Date:10/11/2014 Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table tt70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (usft) 19:00 - 00:00 5.00 t EVAL P DECOMP PJSM.R/U HALLIBURTON WIRE LINE. -RIH WITH 4.81"GAUGE RING WITH JUNK BASKET TO 2,567'MD. -POOH WITH 4.81"GAUGE RING WITH JUNK BASKET. 24 HOUR FLUID LOSS=286 BBLS 9.8 PPG 'BRINE. QA=20 PSI. 10/2/2014 00:00 - 05:00 5.00 EVAL P DECOMP 'PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. PJSM.M/U CEMENT BOND LOG TOOLS. -TEST TOOLS,TROUBLE SHOOT 1 ELECTRONIC TOOL. CHANGE OUT ELECTRONIC TOOL. -ATTEMPT TO RIH,CENTRALIZERS TOO STIFF. -CHANGE OUT CENTRALIZERS. RIH WITH LOGGING TOOL FROM SURFACE TO 2,568'MD. -LOG FROM 2,568'MD TO SURFACE. 05:00 - 13:00 8.00 EVAL P DECOMP PJSM.M/U 40 ARM CALIPER LOGGING TOOLS. ASSIST HALLIBURTON IN CHANGING OUT TOOLS. -MAKE UP 40 ARM CALIPER LOGGING TOOL AND TEST. -RIH WITH CALIPER LOGGING TOOLS FROM SURFACE TO 2,568'MD. -POOH WITH LOGGING TOOL. -RIG DOWN HALLIBURTON WIRE LINE. -RIG UP OA TO FLOW BACK TANK,OPEN AND MONITOR,NO FLOW. 12 HOUR FLUID LOSS=158 BBLS 9.8 PPG 1 BRINE. OA=30 PSI. 13:00 - 14:30 1.50 CLEAN P DECOMP PJSM.BACK OUT LOCK DOWN SCREWS ON 5-1/2"CASING HANGER. -MAKE UP MULTI STRING CUTTER BHA#8. CHANGE OUT BAILS AND MAKE UP KELLY 'JOINT. -PICK UP CUTTER AND FUNCTION TEST KNIVES,OK. -L/D KELLY JOINT. -P/U DRILL COLLARS AND RIH TO 188'MD. 14:30 - 18:00 3.50 CLEAN P DECOMP ,RIH WITH MULTI STRING CUTTER BHA#8. RIH FROM 188'MD TO 2,544'MD. CHANGE OUT BAILS AND P/U KELLY JOINT AND M/U TO TOP DRIVE. Printed 9/17/2015 4 32:49PM • 1111 North America -BP Pae 18 of 32 a Operation Summary Report Common Well Name S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 21:30 3.50 CLEAN P DECOMP PJSM.PERFORM CUT ON 5-1/2"CASING. -PUMP AT 1 BPM=110 PSI,LOCATE COLLAR AT 2,561'MD. -RIH AND TAG TOP OF STUB AT 2,568'MD, P/U 3'TO 2,565'MD. -SPR#1:13 SPM=240 PSI,15 SPM=340 PSI, 21 SPM=770 PSI.AT 2,565'MD WITH 9.8 PPG BRINE. -ROT WT=66K,PUW=65K,SOW=66K. -PERFORM CUT ON 5-1/2"CASING AT 2,565' MD. -ROTATE AT 80 RPM UP TO 100 RPM,FREE TQ=1500 FT-LBS. PUMP AT 1 BPM=110 PSI,FINAL PUMP AT 1 BPM=190 PSI. 21 30 - 23:30 2.00 CLEAN P DECOMP POOH WITH MULTI STRING CUTTER BHA#8. -POOH FROM 2,565'MD TO 2,544'MD. -L/D KELLY JOINT,BLOW DOWN TOP DRIVE AND CHANGE OUT BAILS. -POOH FROM 2,544'MD TO 282'MD. -MONITOR WELL.WELL STABLE,LOSS RATE =13 BPH 9.8 PPG BRINE. 23 30 - 00:00 0.50 CLEAN P DECOMP L/D DRILL COLLARS. -L/D MULTI STRING CUTTER BHA#8. 24 HOUR FLUID LOSS=307 BBLS 9.8 PPG BRINE. OA=0 PSI. 10/3/2014 00:00 - 00:30 0.50 CLEAN P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. CONTINUE L/D MULTI STRING CUTTER BHA #8. 00:30 - 03:30 3.00 CLEAN N SEAL DECOMP PJSM.CHANGE OUT UPPER IBOP. -TEST IBOP TO 250 PSI LOW,3,500 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. -CLEAR AND CLEAN RIG FLOOR. i-CHANGE OUT BAILS,PULL WEAR BUSHING. 03:30 - 05:30 2.00 CLEAN ! P DECOMP PJSM.CLEAR/CLEAN RIG FLOOR. -CHANGE OUT BAILS,PULL WEAR BUSHING. 05:30 - 07:30 2.00 CLEAN P DECOMP PJSM.M/U SPEAR ASSEMBLY BHA#9. -MAKE UP 4.9"NOMINAL GRAPPLE/SPEAR. -TAKE RKB MEASUREMENTS AND RIH,TAG HIGH. -LOOKS LIKE WE ARE TAGGING UP IN THE TOP OF THE HANGER. -ATTEMPT TO RELEASE SPEAR,UNABLE TO RELEASE. -DOUBLE CHECK MEASUREMENTS AND FIGURE THE BOTTOM OF THE GRAPPLE IS 9" INTO THE HANGER MANDREL. -CALL SUPERINTENDANT,GET PERMISSION TO PULL,TAKING PRECAUTIONS. -PULL 5-1/2"HANGER TO RIG FLOOR, (SLOWLY WITH NO HANGUPS). !-HANGER CAME FREE AT 55KAND MAX PULL WAS 100K. -ALL WT CHECKS INCLUDE 40K TOP DRIVE. Printed 9/17/2015 4:32:49PM 1. .;.. North America ALASKA BP Page 19 of 32 Operation Summary Report Common Well Name S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. I UWI:500292302100 Active datum:Kelly Bushing/Rotary Table t70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 09:00 1.50 PULL P DECOMP PJSM.CIRCULATE 100 BBLS DOWN THE IA AND UP THE OA TO THE FLOW BACK TANK -CIRCULATE AT 3 BPM=300 PSI.CIRCULATE I 50 BBLS,(BOTTOMS UP),3 BPM=300 PSI. I-SMALL AMOUNT OF CRUDE OIL INITIALLY IN FIRST 100 BBLS CIRCULATED,(MAYBE 1 BBL). 09:00 - 10:30 1.50 PULL P DECOMP MONITOR WELL,WELL STATIC,NO LOSSES. 1 -BREAK DOWN SPEAR AND LAY DOWN I I HANGER ASSEMBLY. , I -BREAK OUT TOP DRIVE AND BLOW DOWN 1 LIMES 10:30 - 11:00 1 0.50 PULL P DECOMP 'PJSM.GATES HOSE COMPANY INSPECTS KELLY HOSE,BOTH ENDS ALSO. 11:00 - 16:00 5.00 PULL P DECOMP PJSM.POOH WITH 5-1/2"15.5#BTC CASING. -POOH AND UD TO SHED FROM 2,565'MD TO SURFACE. -RECOVERED:61 JOtNTS AND 8.34'CUT JOINT. 16:00 - 19:00 3.00 PULL P DECOMP 'R/D CASING EQUIPMENT. CLEAR AND CLEAN RIG FLOOR. 1 -R/U TO TEST FOUR PREVENTER 13-5/8" BOPE AND RELATED EQUIPMENT. 19:00 - 00.00 5.00 BOPSUR P DECOMP ',PJSM.TEST FOUR PREVENTER 13-5/8"BOPE AND RELATED EQUIPMENT. -TEST BOPE ACCORDING TO AOGCC REGULATIONS,DOYON AND BP ,PROCEDURES. , -TEST ANNULAR WITH 2-7/8"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST UPPER 3-1/2"X 6"VARIABLE RAMS WITH 4"TEST JOINT TO 250 PSI,3,500 PSI HIGH FOR 5 CHARTED MINUTES. I-TEST LOWER 2-7/8"X 5"VARIABLE RAMS 1 WITH 2-7/8"AND 4"TEST JOINT TO 250 PSI, 3,500 PSI HIGH FOR 5 CHARTED MINUTES. i I-TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3,500 PSI HIGH FOR 5 CHARTED MINUTES. 1-PERFORM ACCUMULATOR DRAW DOWN I TEST WITH WSL PRESENT. NO FAILURES. 1 1 JOHN CRISP OF AOGCC WITNESS TEST. 24 HOUR FLUID LOSS=199 BBLS 9.8 PPG BRINE. —_.____ OA=O PSI. 10/4/2014 00:00 - 01:30 1.50 BOPSUR P ABAN I PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. I 1 BLOW DOWN KILL AND CHOKE LINES. 1 I-BLOW DOWN CHOKE MANIFOLD. -R/D TEST EQUIPMENT,BLOW DOWN AND RIG DOWN FLOOR VALVES. -DRAIN OUT STACK. -PULL TEST PLUG. 01 30 02:00 0.50 i BOPSUR P ABAN PJSM.PERFORM WEEKLY DERRICK AND TOP ' DRIVE INSPECTION. -SERVICE TOP DRIVE. Printed 9/17/2015 4.32'49PM 4111) North America-ALASKA-BP Page 20 of 32 Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date 10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 0.50 CEMT P (hr) (usft) - 02:00 - 02:30 ; ABAN PJSM.M/U SPEAR AND PACK-OFF BHA#10. -M/U SAFETY JOINT. -RIH TO 199'MD. 02:30 - 07:00 4.50 CEMT P ABAN RIH WITH SPEAR AND PACK-OFF BHA#10. P/U 4"DRILL PIPE 1 X 1 FROM SHED. RIH FROM 199'MD TO 2,506'MD. 07:00 - 09:00 2.00 CEMT N RREP ABAN RIG REPAIR. -TROUBLE SHOOT AND REPAIR LO DRUM CLUTCH. -REPLACE HI/LO DRUM CLUTCH CONTROL. 09:00 - 09:30 0.50 CEMT P ABAN PJSM.ESTABLISH PARAMETERS. -ACQUIRE SLOW PUMP RATES AT 2,506'MD WITH 9.8 PPG BRINE. #1 MUD PUMP=12 SPM=220 PSI,17 SPM= 550 PSI,24 SPM=920 PSI. -#2 MUD PUMP=10 SPM=230 PSI,15 SPM= 590 PSI,20 SPM=880 PSI. BREAK CIRCULATION,CEMENTERS CALLED AND WILL NOT BE OUT UNTIL NOON. 09:30 - 13 00 3.50 CEMT P ABAN PJSM.RIH WITH SPEAR AND PACK-OFF BHA #.I0 RIH AND TAG AT 2,560'MD. *I1PWT=80K,DOWNWT=82K. -WASH DOWN AT 2 BPM=940 PSI TO 2,571' MD.PACK-OFF AT TOP OF TUBING STUB. -WORK PIPE,PUMP ON/PUMP OFF,SET DOWN 10K,UNABLE TO GET PACK OFF TO ENTER 3-1/2"TUBING STUB. -MAKE CALL TO ODE AND PERMISSION GIVEN TO CONTINUE TO TRY AND POOH AFTER. 1-SET DOWN MORE WEIGHT,17K AND OBSERVE PACK OFF ENTER TUBING STUB. -RIH TO 2,577'MD,BRING PUMP RATE UP TO 3-1/2 BPM=2980 PSI,FULL RETURNS,NO LOSSES. _- 13:00 - 15:30 2.50 CEMT P ABAN POOH WITH SPEAR AND PACK-OFF BHA#10. POOH FROM 2,577'MD TO 199'MD,STAND BACK 4"OP IN DERRICK. -STAND BACK4-3/4"DRILL COLLARS IN DERRICK. 15:30 - 16:30 1.00 CEMT t P j ABAN UD SPEAR AND PACK-OFF BHA#10. INSPECT DAMAGED PACK-OFF ASSEMBLY. -DISCUSS OPTIONS WITH ODE,PLAN TO PICK UP PACKER MILLAND MILL TOP OF 3-1/2"TUBING STUB. 16:30 - 18:00 1.50 CLEAN P ABAN WAIT ON BAKER TOOLS. CLEAR AND CLEAN RIG FLOOR. SERVICE RIG EQUIPMENT. 18:00 - 19:00 1.00 CLEAN P ABAN PJSM.M/U AND RIH WITH DRESS OFF BHA #11. RIHTO215'MD. Printed 9/17/2015 4:32:49PM • • North America-ALASKA-BP A� n z J �� a � Operation Summary Report Common Well Name S-108 AFE No Event Type WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT r NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 21:00 2.00 CLEAN P ABAN RIH WITH DRESS OFF BHA#11. -RIH FROM 215'MD TO 2,565'MD. PUW=80K,SOW=81K,ROT=82K AT 60 RPM,FREE TORQUE=15 FT-KLBS. 1-ACQUIRE SLOW PUMP RATES AT 2,565'MD WITH 9.8 PPG BRINE. -#1 MUD PUMP=2 BPM=90 PSI,3 BPM=170 PSI. #2 MUD PUMP=2 BPM=80 PSI,3 BPM=160 PSI. _ 21.00 - 21.30 0.50 CLEAN P ABAN RIH AND TAG TOP OF STUB AT 2,568'MD. -MILL FROM 2,568'MD TO 2,569'MD. -PUMP AT 3 BPM=170 PSI,60 RPM=15-25 FT-KLB,WOB=1-2K. 21:30 - 22:00 0.50 CLEAN P ABAN CIRCULATE BOTTOMS UP AT 10 BPM=1,400 PSI. -MONITOR WELL.WELL STATIC. 22:00 - 23:30 1.50 CLEAN P ABAN PJSM.POOH WITH DRESS OFF BHA#11. -POOH FROM 2,569'MD TO 215'MD,STAND BACK 4"DP IN DERRICK. -MONITOR WELL.WELL STATIC. 23:30 - 00:00 0.50 CLEAN P ABAN UD DRESS OFF BHA#11. CLEAN 3-1/2"GROOVE ON MILL. 24 HOUR FLUID LOSS=6 BBLS 9.8 PPG BRINE. OA=0 PSI. 10/5/2014 00:00 - 00:30 0.50 CLEAN— P ABAN PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. 00:30 - 01:30 1.00 CLEAN IP __ ABAN PJSM.M/U 2-1/16"CS TUBING CLEAN OUT BHA#12. RIH TO294'MD. 01-30 04:00 2.50 CLEAN P ABAN RIH WITH 2-1/16"CS TUBING CLEAN OUT BHA #12. -RIH FROM 294'MD TO 2,560'MD. -WASH DOWN AT 7 BPM=830 PSI FROM 2,560'MD TO 2,663'MD. -MONITOR WELL.WELL STATIC. -CONTACT ODE AND DECISION MADE TO POOH AND PICK UP 2 MORE JOINTS 2-1/16" 1 CS HYDRIL. 04:00 - 05:30 1.50 CLEAN P ABAN POOH WITH 2-1/16"CS TUBING CLEAN OUT BHA#12. 1-POOH FROM 2,663'MD TO 294'MD. MONITOR WELL.WELL STATIC. -STAND BACK COLLARS 05:30 - 07:30 2.00 CLEAN P ABAN 1 PJSM.ADD(2)JTS OF 2-1/16"CS HYDRIL TO MULE SHOE BHA. -RIH ON(6)4 3/4"DCS AND 4"DRILL PIPE. -RIH TO 2627'.80K UP WT,80K DOWN WT. -ACQUIRE SLOW PUMP RATES. -MUD PUMP#1=24 SPM=40 PSI,36 SPM= 140 PSI. -MUD PUMP#2=20 SPM=40 PSI,30 PSM= 140 PSI. SLOW PUMP RATES ACQUIRED WITH 9.8 'PPG BRINE AT 2,627'MD. Printed 9/17/2015 4 32:49PM 410 North America ALASKA BP • f Page 22 of 32 Operation Summary Report Common Well Name S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task 1 Code 1 NPT NPT Depth Phase , Description of Operations (hr) (usft) 07:30 - 09:30 + 2.00 CLEAN P ABAN PJSM.RIH,TAG AT 2,658'MD,BRING ON PUMP AT 7 BPM=980 PSI. -WASH DOWN TO 2,674'MD,SET DOWN 5K- 7K,UNABLE TO GET DOWN FURTHER. -PUMP SWEEP WHILE WASHING DOWN AND ANOTHER WHILE ON BOTTOM. -20 BBLS HI VIS SWEEPS EACH.FLUID LOSS IRATE WHILE PUMPING=40-50 BPH. -SHUT DOWN AND TAG W/O PUMPING,2,674'. _ STATIC LOSS RATE=10 BPH. 09:30 - 10:30 1.00 CLEAN P ABAN PJSM.POOH WITH 2-1/16"CS TUBING CLEAN OUT BHA#1 3. -POOH FROM 2,631'MD TO 419'MD. -MONITOR WELL,STATIC LOSS RATE=18 - BPH.STAND BACK DRILL COLLARS. 10:30 - 12:00 1.50 CLEAN P I ABAN L/D 2-1/16"CS TUBING CLEAN OUT BHA#13 -MULE SHOE SEVERELY CRIMPED ON THE END INDICATING COLLAPSED 3-1/2"TUBING I IAT 2,674'MD. -CLEAR AND CLEAN RIG FLOOR. 12 HOUR FLUID LOSS=130 BBLS 9.8 PPG BRINE. -OA=0 PSI. 12:00 - 12:30 0.50 CEMT P ABAN PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. 12:30 - 13:30 1.00 CEMT F ABAN PJSM.M/U SPEAR AND PACK-OFF BHA#14. -RIH TO 199'MD. 13:30 - 16:00 2.50 CEMT P ABAN RIH WITH SPEAR AND PACK-OFF BHA#14. -RIH FROM 199'MD TO 2,500'MD. _., -PUW=81K,SOW=80K. -ACQUIRE SLOW PUMP RATES. -MUD PUMP#1=24 SPM=700 PSI,36 SPM= 1400 PSI. -MUD PUMP#2=20 SPM=760 PSI,30 PSM= 1600 PSI. -SLOW PUMP RATES ACQUIRED WITH 9.8 PPG BRINE AT 2,500'MD. -RIH AND STING INTO 3-1/2"TUBING AT 2,569' MD. -ESTABLISH INJECTION RATE:2.5 BPM= 1,470 PSI. -BULLHEAD 50 BBLS AT 2.5 BPM=1,700 PSI. -SHUT DOWN PUMPS,BLEED BACK 6 BBLS. 16:00 - 17:00 1.00 CEMT P ABAN R/U TIW HEAD PIN WITH CEMENT LINES. -PJSM FOR CEMENT JOB WITH CREWAND SCHLUMBERGER. Printed 9/17/2015 4:32:49PM • North America ALASKA BP a/9 23 of 32_ Operation Summary Report • Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) ! Start Date:9/14/2014 End Date:10/11/2014 Z3-001 V6-E.EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. I UWI:500292302100 Active datum:Kelly Bushing/Rotary Table Q70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr)17:00 - 17:30 0.50 (usft) CEMT P ABAN PJSM.PRESSURE TEST SCHLUMBERGER LINES. -FILL LINES AND PRESSURE TEST TO 250 PSI,5,000 PSI HIGH.WSL VERIFY TRIP SETTING AT 3,000 PSI. -MECHANICAL POP OFF ON CEMENT PUMP SET @ 5000 PSI. -MECHANICAL POP OFF ON RIG MUD PUMPS SET @ 4200 PSI. WEAKEST POINT IN SYSTEM=5000 PSI. -PRE JOB HELD WITH CEMENTERS, PRESSURE CROSS CHECK LIST REVIEWED. EMPHASIS ON VALVE ALIGNMENT AND COMMUNICATION. VALVE ALIGNMENT CHECKED DOUBLE CHECKED AND AGAIN BY WSL. 17:30 - 19:00 1.50 CEMT P ABAN PUMP CEMENT PLUG#1. -PUMP 60 BBLS 15.8 PPG CLASS G CEMENT WITH GASBLOK ADDITIVE. -PUMP AT 2.5 BPM=1,100 PSI. -WASH UP WITH 5 BBLS WATER. '-SWITCH TO RIG TO DISPLACE. -DISPLACE WITH 27 BBLS 9.8 PPG BRINE AT 2.5 BPM=1,150 PSI. -CEMENT IN PLACE AT 18:30 HRS. 19:00 - 20.00 1.00 CEMT P ABAN UNSTING FROM 3-1/2"TUBING. DROP(2)4"DRILL PIPE WIPER BALLS. -PUMP AT 2.5 BPM=745 PSI,AFTER 25 BBLS AWAY PRESSURE INCREASE TO 3,900 PSI. -UNABLE TO PUMP BALLS THROUGH BHA. -DROP BALL AND ROD TO ATTEMPT TO OPEN CIRC SUB,UNABLE TO OPEN CIRC SUB. -BLOW DOWN TOP DRIVE. -MONITOR WELL FOR 10 MINUTES.WELL STABLE. 20:00 - 22:00 2.00 CEMT P ABAN POOH WITH SPEAR AND PACK-OFF BHA#14. -POOH FROM 2,469'MD TO 199'MD. 22:00 - 22:30 0.50 CEMT P ABAN UD SPEAR AND PACK-OFF BHA#14. -RECOVER(2)4"WIPER BALLS AT TOP OF SPEAR TOOL. 22:30 - 23:00 0.50 CEMT P ABAN CLEAR AND CLEAN RIG FLOOR. M/U FLOOR VALVE FOR 2-7/8"HT PAC PIPE. 23:00 - 00:00 1.00 CEMT P ABAN RIH WITH 2-7/8"HT PAC PIPE. -RIH FROM SURFACE TO 2,358'MD. 24 HOUR FLUID LOSS=249 BBLS 9.8 PPG BRINE. OA=0 PSI. 10/6/2014 00:00 - 00:30 0.50 CLEAN P ABAN PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. 00:30 - 03:00 2.50 CLEAN P ABAN PJSM.UD 2-7/8"HT PAC TO SHED 1 X 1. -POOH FROM 2,358'MD TO SURFACE. 03:00 - 03:30 0.50 CLEAN P ABAN H2S RIG EVACUATION DRILL. -ALL PERSONNEL AND THIRD PARTY ACCOUNTED FOR. !-MUSTERED IN THE PRIMARY MUSTER AREA. -AAR HELD IN DOG HOUSE,REVIEWED ALARMS AND LEVELS AT WHICH ALARMS SOUND. Printed 9/17/2015 4:32.49PM • IF/VMP.Ptittlfiftd$1,/ ., North Amenca ALASKA BP Pace 24 of 32 operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay I Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date I From-To Hrs 1 Task I Code NPT I NPT Depth Phase I Description of Operations (hr) 1 (usft) 1 03:30 - 04:00 0.50 CLEAN P ABAN R/D 2-7/8"HANDLING EQUIPMENT. -R/U TO RUN 4"DRILL PIPE AND NEW BHA. 04:00 - 05:30 1.50 CLEAN P ABAN PJSM.M/U SCRAPER BHA#15. -RIH TO 222'MD. 05:30 - 07:30 2.00 CLEAN P ABAN RIH WITH SCRAPER BHA#15. -RIH FROM 222'MD TO 2,497'MD. -PUW=80K,SOW=81K. -CONTINUE RIH FROM 2,497 MD TO 2,562' MD. I-CIRCULATE 20 BBLS HI VIS SWEEP AT 5 BPM =330 PSI. 07 30 - 08 00 0.50 CLEAN PABAN PJSM.POOH WITH SCRAPER BHA#15. -MONITOR WELL.WELL STATIC. -POOH FROM 2,562"MD TO 2,497'MD. 08:00 - 09:30 1.50 CLEAN P ABAN PJSM.SLIP AND CUT 68'DRILL LINE. 09:30 - 10:30 1.00 CLEAN P ABAN ;PJSM.POOH WITH SCRAPER BHA#15. -POOH FROM 2,497'MD TO 222'MD. -MONITOR WELL.WELL STATIC. 10:30 - 11:30 1.00 CLEAN P i ABAN L/D SCRAPER BHA#15. -R/B DRILL COLLARS. -L/D BHA#15. -CLEAN BOOT BASKETS.RECOVERED 0.5 LBS OLD CEMENT. 11:30 - 12:00 0.50 CLEAN P ABAN CLEAR AND CLEAN RIG FLOOR. -MOBILIZE BHA#16 TO RIG FLOOR. 12 HOUR FLUID LOSS=0 BBLS 9.8 PPG BRINE. OA=0 PSI. 12:00 - 12:30 0.50 CLEAN P ABAN PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. 12:30 - 13:00 0.50 CLEAN P ABAN PJSM.M/U SPEAR AND PACK-OFF BHA#16. -RIH TO 199'MD. 13:00 - 14:30 1.50 CLEAN P ABAN RIH WITH SPEAR AND PACK-OFF BHA#16. -RIH FROM 199'MD TO 2,500 MD. 1-PUW=80K,SOW=81K. �i I RIH AND ENGAGE 3-1/2"TUBING STUB AT 2,569'MD. -SET DOWN 15K. Printed 9/17/2015 4:32:49PM North America-ALASKA BP Page 25 of 32 ly Operation Summary Report VaAg Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date.9/14/2014 End Date:10/11/2014 Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (usft) 14:30 - 17:00 2.50 CLEAN P ABAN PJSM.R/U CIRCULATING LINES. PRESSURE TEST CEMENT PLUG IN 3 1/2" TUBING TO FORMATION. -PRESSURE UP ON DRILL PIPE WITH BAKER PACKOFF STABBED INTO TUBING @ 2569'. -PRESSURE UP TO 250 PSI W/9.8 PPG BRINE AND HOLD FOR(5)CHARTED MINUTES, GOOD TEST. -ATTEMPT SEVERAL TIMES TO TEST©1000 PSI,BLEEDING OFF AND OBSERVED RETURNS INDICATING PACKOFF LEAKING. -CONSULTED ODE AND DECISION MADE TO ITEST ENTIRE WELL BORE TO 1000 PSI. -PJSM.FLUID PACK LINES AND CLOSE PIPE RAMS.PRESSURE UP I/AX O/AAND DRILL PIPE SIMULTANEOUSLY. -TEST @ 250 PSI FOR(5)CHARTED I MINUTES,GOOD TEST AND TEST TO 1000 PSI FOR(30)CHARTED MINUTES. -PRESSURE UP TO 1060 PSI. APPROXIMATELY 1 BBL TO PRESSURE UP, (CALCULATED.6 BBLS). -BLED OFF 60 PSI IN 1ST 15 MINUTES AND 0 PSI IN SECOND 15 MINUTES.FINAL TEST PRESSURE=1000 PSI. -CONTACT ODE WITH RESULTS.GOOD TEST. 17.00 - 18:30 1.50 CLEAN P ABAN PJSM.POOH WITH SPEAR AND PACK-OFF BHA#16. UNSTING FROM 3-1/2"TUBING STUB. -POOH FROM 2,569'MD TO 199'MD. 18:30 - 19.00 0.50 CLEAN P ABAN UD SPEAR AND PACK-OFF BHA#16. -RACK BACK DRILL COLLARS. -L/D BHA#16. 19.00 - 20:00 1.00 CLEAN P ABAN CLEAR AND CLEAN RIG FLOOR. -MOBILIZE HES TOOLS TO RIG FLOOR. 20:00 - 21:00 1.00 CLEAN P ABAN PJSM.RUN HES EZSV. -M/U HES EZSV AND PERFORM DUMMY RUN THROUGH STACK. -RIH TO 31'MD. 21.00 - 00:00 3.00 CLEAN P ABAN RIH AND SET HES EZSV. -RIH FROM 31'MD TO 2,559'MD. PUW=81K,SOW=82K 1-SET EZSV AT 2,559'MD AS PER HES REPRESENTATIVE. -PERFORM 35 TURNS TO THE RIGHT,P/U 10K INTERVALS TO 39K OVER TO SHEAR OUT OF EZSV. I-ROTATE 22 TURNS TO THE RIGHT. 24 HOUR FLUID LOSS=0 BBLS 9.8 PPG BRINE. OA=O PSI. Printed 9/17/2015 4.32:49PM , • No America ALASKA B m ,� sz � Operation Summary Report"`: Common Well Name:S-108 AFE No Event Type.WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10/7/2014 00:00 - 00:30 0.50 PXA P ABAN 1PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. PJSM.STING BACK INTO EZSV AND SET DOWN 20K. -ATTEMPT TO ESTABLISH INJECTION RATE. -PUMP AT 0.5 BPM UNTIL PRESSURE REACH 2,500 PSI,$HUT DOWN PUMPS. PUMPED 1.6 BBL,BLED PRESSURE OFF AND RETURNED 1.6 BBL.INJECTION NOT POSSIBLE. CALL ODE WITH INJECTION RATE INFORMATION. UNSTING FROM EZSV. 00:30 - 01:30 1.00 PXA P ABAN L/D SINGLE JOINT AND 10'PUP. -M/U TIWAND HEAD PIN AND SPACE OUT TO 2,555'MD IN PREPARATION FOR CEMENT PLUG#2. 01:30 - 03.00 1.50 PXA P ABAN R/U LRS TO HEAT PITS. SPOT IN SCHLUMBERGER CEMENT TRUCKS. 03:00 - 07:30 4.50 PXA P ABAN CIRCULATE WELL BORE UNTIL 90°F RETURNS. 07:30 - 10:00 2.50 PXA P ABAN PJSM WITH ALL PARTIES INVOLVED. 1-EMPHASIS ON PRESSURE CONTROLAND 'GOOD COMMUNICATION. -VERIFY PRV SETTINGS AND PUMP TRIP SETTINGS. PUMP 5 BBLS FRESH WATER AHEAD AND PRESSURE TEST LINES AT 250/4000 PSI,OK. PUMPED APPROXIMATELY 35 BBLS 15.8 PPG NEAT CEMENT,CEMENT UP TO WT AT 08:45 HRS. 1-AVERAGE PUMP RATE WHILE PUMPING CEMENT,5 BPM=180 PSI. -PUMPED 5 BBLS FRESH WATER BEHIND AND DISPLACED WITH 10 BBLS 9.8 PPG BRINE. -LAID DOWN(1)JT DP AND PULLED 10 STANDS,(DRY),CEMENT IN PLACE AT 09:45 HRS. -PUMPED FOAM BALLAND CIRCULATED SURFACE TO SURFACE AT 7 BPM=400 PSI. -NO LOSSES DURING PUMPING. 10:00 - 12:00 2.00 PXA P . ABAN POOH WITH EZSV RUNNING TOOL. -POOH FROM 1,495'MD TO 580'MD AND L/D 1 X 1 TO SHED. j -BLOW DOWN TOP DRIVE. POOH FROM 580'MD TO SURFACE. L/D EZSV RUNNING TOOL. 12 HOUR FLUID LOSS=0 BBLS 9.8 PPG BRINE. OA=0 PSI. 12:00 - 12:30 0.50 PXA P ABAN PTSM.PERFORM SPCC AND EQUIPMENT ;CHECKS. CHECK CROWN-O-MATIC.OK. 12:30 - 14:30 2.00 PXA P ABAN RIH WITH 10 STANDS 4"DRILL PIPE FROM DERRICK. i-POOH AND L/D 1 X 1 TO SHED. Printed 9/17/2015 4:32.49PM » North America-ALASKA-BP ,,,-,Aigooulonsmer; - Page 27 of 32 7 Operation Summary Report Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site.PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table(c270.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14 30 - 17:00 2.50 PXA P ABAN I LOAD AND STRAP 3-1/2"9.3#L-80 NSCT TUBING IN PIPE SHED. 17:00 - 20:30 3.50 PXA P ABAN PJSM.RIH WITH 3-1/2"9.3#L-80 NSCT TUBING. RIH FROM SURFACE TO 1,500'MD. -PUW=55K,SOW=55K. -ACQUIRE SLOW PUMP RATES: PUMP#1:2 BPM=50 PSI,3 BPM=80 PSI. -PUMP#2:2 BPM=50 PSI,3 BPM=90 PSI. 20.30 - 00:00 3.50 PXA P ABAN WAIT ON CEMENT. -GENERAL HOUSEKEEPING,PAINTING PUMP #2 ROOM. -CHANGE OUT JERK AND SNUB LINES ON EZ I TORQUE. 24 HOUR FLUID LOSS=0 BBLS 9.8 PPG I BRINE. OA=0 PSI. 10/8/2014 00:00 - 12.00 12.00 PXA P ABAN PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. r CHECK CROWN-O-MATIC.OK. WAIT ON CEMENT PLUG#2. GENERAL HOUSEKEEPING,PAINTING PUMP #2 ROOM. 12 HOUR FLUID LOSS=0 BBLS 9.8 PPG BRINE. OA=0 PSI. 12:00 - 12.30 0.50 PXA P ABAN PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. _ 12:30 - 16:30 4.00 PXA P ABAN PJSM.RIH WITH 3-1/2"9.3#L-80 NSCT TUBING. RIH FROM SURFACE TO 1,768'MD. -WASH DOWN CEMENT STRINGSER FROM 1,768'MD TO TOP OF CEMENT AT 1,816'MD. -PUW=55K,SOW=55K. 16:30 - 20:30 4.00 PXA P ABAN j PRESSURE TEST CEMENT PLUG#2. WITNESSED BY LOU GRIMALDI -SET DOWN 15K,PUMP AT 1 BPM PRESSURE INCREASE TO 1,100 PSI. -ATTEMPT TO PRESSURE TEST CEMENT PLUG#2 TO 250 PSI LOW,2,000 PSI HIGH FOR 30 MINUTES.DID NOT MEET BP CRITERIA. 1-BLEED OFF PRESSURE. -ATTEMPT TO PRESSURE TEST CEMENT PLUG#2 TO 250 PSI LOW,1,700 PSI HIGH FOR 30 MINUTES.DID NOT MEET BP j CRITERIA. -BLEED OFF PRESSURE. -CONTACT ODE WITH INFORMATION,GIVEN PERMISSION TO TEST TO 1,000 PSI. -PRESSURE TEST CEMENT PLUG#2 TO 250 PSI LOW,1,100 PSI HIGH FOR 30 MINUTES. PROCEEDURE REQUIRED 1,500 PSI. 20 30 - 21 30 1.00 PXA P ABAN R/D TEST EQUIPMENT. 1-BLOW DOWN SURFACE LINES. -L/D(2)JOINTS 4"DRILL PIPE TO SHED. Printed 9/17/2015 4-32 49PM • 0 North America-ALASKA-BP Page .� 28 of 32 Operation Summary Reportf Common Well Name:S-108 1 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 1Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. it UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT j NPT Depth Phase Description of Operations (hr) (usft) 21 30 - 22:00 0.50 PXA P ABAN PJSM.M/U 3-1/2"TUBING HANGER. -RIH WITH(1)STAND OF 3-1/2"TUBING FROM DERRICK TO 1,782'MD. 122:00 22:30 0.50 LAND TUBING HANGER,FMC RILDS. - PXA P ABAN FLUSH MUD PUMPS,CHOKE AND TOP DRIVE. -FLUSH ALL SURFACE LINES WITH FRESH II WATER. i-BLOWDOWN SURFACE EQUIPMENT. 22:30 - 00:00 1.50 PXA P ABAN PJSM.PRESSURE TEST CEMENT PLUG#2. R/U TO IA WITH BLIND RAMS CLOSED. -ATTEMPT TO PRESSURE TEST CEMENT i PLUG#2 TO 250 PSI LOW,1,500 PSI HIGH FOR 30 MINUTES.DID NOT MEET BP CRITERIA. -BLEED OFF PRESSURE. -CONTACT ODE AND WTL WITH INFORMATION,DECISION MADE TO RUN RTTS AND SET AT-1,700'MD AND TEST BELOW RTTS. 24 HOUR FLUID LOSS=0 BBLS 9.8 PPG BRINE. OA=0 PSI. 10/9/2014 00:00 - 00:30 0.50 PXA P ABAN PTSM.PERFORM SPCC AND EQUIPMENT I CHECKS. j I CHECK CROWN-O-MATIC.OK. BLOW DOWN CEMENT LINES. -DRAIN BOPE STACK 00:30 - 01.00 0.50 PXA P ABAN PJSM.M/U SAFETY VALVE. i -M/U LANDING JOINT TO HANGER. -FMC,BOLDS. 01:00 01:30 0.50 -- _ PXA P ABAN PULL HANGER TO RIG FLOOR. -PUW=55K -L/D LANDING JOINT AND HANGER. 01:30 - 03:00 1.50 PXA P ABAN PJSM.POOH WITH 3-1/2"9.3#L-80 NSCT TUBING. -STAND BACK TUBING IN DERRICK POOH FROM 1,754'MD TO SURFACE. 03:00 - 05:00 2.00 PXA ' P ABAN PJSM.M/U HES 7-5/8"RTTS. -RIH FROM SURFACE TO 507'MD ON 4"DP I FROM SHED. -PUW=48K,SOW=50K. SET RTTS AT 507'MD AND SET DOWN 15K TO VERIFY. 05.00 - 05 30 0.50 PXA P ABAN R/U TEST EQUIPMENT. -ATTEMPT TO PRESSURE TEST CEMENT PLUG#2 TO 250 PSI LOW,1,700 PSI HIGH FOR 30 MINUTES.DID NOT MEET BP , CRITERIA. I I BLEED OFF PRESSURE AND RELEASE RTTS. 05 30 07 00 1.50 PXA P I ABAN CONTINUE TO RIH WITH HES 7-5/8"RTTS. -RIH FROM 507'MD TO 1,011'MD. 1 1 I I -BREAK CIRCULATION AT 6 BPM=120 PSI. -PUW=55K,SOW=58K -SET RTTS AT 1,011'MD AND SET DOWN 15K TO VERIFY. Printed 9/17/2015 4:32.49PM • • North Amenca ALASKA BP Page 29 of 32 i' Operation Summary Report' Common Well Name S-108 AFE No Event Type WORKOVER(WO) Start Date:9/14/2014 End Date 10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON'16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) i (usft) 07:00 - 09:00 2.00 PXA P ABAN PRESSURE TEST PLUG#2 AT 1,011'MD. -ATTEMPT TO PRESSURE TEST CEMENT PLUG#2 TO 250 PSI LOW,1,700 PSI HIGH FOR 30 MINUTES.DID NOT MEET BP CRITERIA. BLEED OFF PRESSURE. -PRESSURE TEST ABOVE RTTS TO 250 PSI -LOW,1,700 PSI HIGH FOR 30 MINUTES. BLEED OFF PRESSURE AND RELEASE RTTS. 09:00 - 10:30 1.50 PXA P ABAN CONTINUE TO RIH WITH HES 7-5/8"RTTS. RIH FROM 1,011'MD 1,675'MD. -BREAK CIRCULATION AT 6 BPM=160 PSI. -PUW=65K,SOW=67K. SET RTTS AT 1,675'MD AND SET DOWN 15K TO VERIFY. 10:30 - 13.00 2.50 PXA P ABAN PRESSURE TEST PLUG#2 AT 1,675'MD. -ATTEMPT TO PRESSURE TEST CEMENT PLUG#2 TO250 PSI LOW,1,700 PSI HIGH FOR 30 MINUTES.DID NOT MEET BP CRITERIA. -BLEED OFF PRESSURE. PRESSURE TEST ABOVE RTTS TO 250 PSI LOW,1,700 PSI HIGH FOR 30 MINUTES. 12 HOUR FLUID LOSS=0 BBLS 9.8 PPG BRINE. OA=O PSI. 13:00 - 14:00 1.00 PXA P ABAN DISCUSS OPTIONS WITH WTL. 14:00 - 15:00 1.00 PXA P H ABAN POOH WITH HES 7-5/8"RTTS. -RELEASE RTTS. -ACQUIRE SLOW PUMP RATES. PUW=67K,SOW=67K. -POOH FROM 1,675'MD TO SURFACE. -UD HES RTTS TO SHED. 15:00 - 17:00 2.00 PXA P ABAN P/U(9)4-3/4"DRILL COLLARS AND STAND BACK IN DERRICK. -WAIT ON BOT STRING MILL BHA. 17:00 - 18:00 1.00 PXA P ABAN PJSM.P/U STRING MILL BHA#17 -RIH WITH STRING MILL BHA TO 289'MD. 18:00 - 20:30 2.50 CLEAN P ABAN RIH WITH STRING MILL BHA#17. RIH FROM 289'MD TO 1,768'MD. PUW=73K,SOW=74K. -M/U TOP DRIVE. 20:30 - 21:30 1.00 CLEAN P ABAN PJSM.DRILL CEMENT PLUG#2 FROM 1,816' MD TO 1,890'MD. -PUMP AT 8 BPM=720 PSI. -DRILL AT 10-20 RPM,WOB=3-5K,TORQUE= 3-5K. 21:30 - 22:30 1.00 I CLEAN P ABAN P/U 10'AND CIRCULATE UNTIL RETURNS CLEAR UP. 1-PUMP AT 9 BPM=650 PSI. 1-MONITOR WELL FOR 10 MINUTES.STATIC. Printed 9/17/2015 4:32:49PM North America-ALASKA-BP "r Page 30 of 32 Operation Summary Report , Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 1Z3 001 V6 E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM 1 Rig Release:10/11/2014 Rig Contractor DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) i-- (usft) 22:30 - 00:00 1.50 CLEAN P ( ABAN PJSM.POOH WITH STRING MILL BHA#17. -PUW=73K,SOW=74K. -POOH FROM 1,880'MD TO 289'MD. -MONITOR WELL.WELL STATIC. -L/D DRILL COLLARS TO SHED. 24 HOUR FLUID LOSS=0 BBLS 9.8 PPG BRINE. OA=O PSI. 10/10/2014 00:00 - 01:00 1.00 CLEAN P ABAN PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. CHECK CROWN-O-MATIC.OK. UD STRING MILL BHA#17. 01:00 - 03:00 2.00 CLEAN P ABAN PJSM.M/U HES 7-5/8"RTTS. -PRESSURE TEST CASING TO 250 PSI LOW, 1,500 PS4 HIGH FOR 30 MINUTES FROM SURFACE BEFORE RIH WITH RTTS.DID NOT MEET BP CRITERIA. !-RIH FROM SURFACE TO 1,871'MD. PUW=68K,SOW=68K. ACQUIRE SLOW PUMP RATES. WASH DOWN FROM 1,871'MD TO 1,890'MD, TAG TOP OF CEMENT AT 1,890'MD. -P/U AND SET RTTS AT 1,884'MD,SET DOWN 15K TO VERIFY. 03 00 - 04:30 1.50 CLEAN P ABAN R/U TEST EQUIPMENT. -ATTEMPT TO PRESSURE TEST CEMENT PLUG#2 TO 250 PSI LOW,1,500 PSI HIGH 1 FOR 30 MINUTES.DID NOT MEET BP CRITERIA. -BLEED OFF PRESSURE. -CALL ODE WITH INFORMATION.DECISION 1 MADE TO POOH TO 1,600'MD AND PRESSURE TEST ABOVE RTTS. -RELEASE RTTS. 04.30 - 06:00 1.50 CLEAN P ABAN POOH WITH HES 7-5/8"RTTS. -POOH FROM 1,884'MD TO 1,613'MD. I-PUW=65K,SOW=65K. -SET RTTS AT 1,613'MD. PRESSURE TEST ABOVE RTTS TO 250 PSI LOW,1,500 PSI HIGH FOR 30 MINUTES.GOOD i TEST. 06:00 - 07:00 1.00 CLEAN P ABAN POOH WITH HES 7-5/8"RTTS. -POOH FROM 1,613'MD TO SURFACE. 07:00 - 09:30 2.50 CLEAN P ABAN DISCUSS OPTIONS IN TOWN. CLEAN RIG FLOOR. 09:30 - 13:00 3.50 CLEAN P ABAN 1 RIH WITH WITH 4"DRILL PIPE FROM DERRICK,POOH AND UD TO SHED 1 X 1. 13:00 - 13:30 0.50 PXA P ABAN PTSM.PERFORM SPCC AND EQUIPMENT (CHECKS. CHECK CROWN-O-MATIC.OK. I i j j I FLUSH BOPE,TOP DRIVE AND MUD MANIFOLD WITH FRESH WATER. 13:30 - 15:00 1.50 PXA P ABAN PJSM.RIH WITH 3-1/2"KILL STRING TUBING. RIH FROM SURFACE TO 1,877'MD. PUW=58K,SOW=58K. ACQUIRE SLOW PUMP RATES. Printed 9/17/2015 4 3249PM • • Nh America ALASKA BP ./,...,Page 31 of 32 Operation Summary Report'' Common Well Name S-108 AFE No Event Type:WORKOVER(WO) Start Date 9/14/2014 End Date 10/11/2014 Z3-001 V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM Rig Release:10/11/2014 Rig Contractor:DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table©70.25usft(above Mean Sea Level) Date From-To NPT I NPT Depth Phase ; Description of Operations (h) Task Code (usft) 15:00 - 17:30 2.50 PXA P ABAN M/U HANGER AND LANDING JOINT. -LAND HANGER,FMC RILDS. -INSTALL TWC. -PRESSURE TEST TWC FROM BELOW TO 250 I PSI LOW,1,000 PSI HIGH FOR 5 MINUTES. GOOD TEST. -PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOW,2,000 PSI HIGH FOR 5 MINUTES. GOOD TEST. 17:30 - 18:30 1.00 PXA P ABAN PJSM.N/D 13-5/8"BOPE. -FLUSH OUT SURFACE LINES AND EQUIPMENT. DRAIN BOPE STACK. -N/D MOUSE HOLE,TURNBUCKLES,RISER AND HYDRAULIC ACCUMULATOR LINES. 18:30 - 20:30 2.00 PXA P ABAN PJSM.N/U ADAPTER FLANGE AND TREE. -FMC CLEAN AND INSPECT HANGER THREADS. N/U OLD ADAPTER FLANGE AND TREE. -PRESSURE TEST ADAPTER TO 250 PSI LOW, 2,000 PSI HIGH FOR 5 MINUTES.GOOD TEST. 20:30 - 21:00 0.50 PXA P ABAN PJSM.R/U DSM LUBRICATOR. PRESSURE TEST TREE AND LUBRICATOR TO 250 PSI LOW,2,000 PSI HIGH FOR 5 MINUTES.GOOD TEST. 21:00 - 23:00 2.00 PXA W N SEAL ABAN PULL TWC. -ATTEMPT TO PULL TWC,RETRIEVING TOOL PARTED WHEN ATTEMPTING TO PULL TWC. -CLOSE MASTER AND SWAB VALVES,R/D DSM LUBRICATOR. 23:00 - 00:00 1.00 PXA N SFAL ABAN CALL DAY WSL AND ODE.DECISION MADE TO RE-PRESSURE TREE,N/D TREE AND REMOVE PARTED TOOL FROM TWC. -PRESSURE TEST TWC FROM ABOVE TO 250 PSI LOW,2,000 PSI HIGH FOR 5 MINUTES. GOOD TEST. 124 HOUR FLUID LOSS=0 BBLS 9.8 PPG BRINE. OA=0 PSI. 10/11/2014 00:00 - 00:30 0.50 PXA P ABAN PTSM.PERFORM SPCC AND EQUIPMENT 'CHECKS. CHECK CROWN-O-MATIC.OK. 00:30 - 01:00 0.50 PXA N SFAL ABAN j PJSM.N/D TREE. RETRIEVE DSM TOOL IN TWC. -N/U TREE. 01:00 - 02:30 1.50 PXA P ABAN R/U DSM LUBRICATOR. PRESSURE TEST TREE AND LUBRICATOR I TO 250 PSI LOW,2,000 PSI HIGH FOR 5 MINUTES.GOOD TEST. 02:30 04:30 2.00 PXA P ABAN PJSM.R/U SCHLUMBERGER CEMENTERS. 1-PRESSURE TEST LINES TO 250 PSI LOW, 13,000 PSI HIGH.GOOD TEST.WSL VERIFY TRIP SETTING ON PUMP UNIT. Printed 9/17/2015 4:32 49PM NorthAmencaALASKA BP Page of Operation Summary Report`' Common Well Name:S-108 AFE No Event Type:WORKOVER(WO) Start Date:9/14/2014 End Date:10/11/2014 Z3-001V6-E:EXCAV(2,310,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:6/11/2001 12:00:00AM I Rig Release:10/11/2014 Rig Contractor DOYON DRILLING INC. UWI:500292302100 Active datum:Kelly Bushing/Rotary Table @70.25usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 06:00 1.50 PXA P ABAN PJSM.PUMP CEMENT PLUG#3. -PRE-JOB WITH ALL PARTIES INVOLVED, REVIEWED PRESSURE CROSS-CHECK LIST. -LINE UP TO PUMP DOWN TUBING TAKING I RETURNS UP OA TO SLOP TANK. -PUMP AT 5 BPM=550 PSI. -PUMP UNTIL GOOD CEMENT SEEN AT SLOP TANK. -SHUT DOWN PUMPS. -SHUT IN OAAND PRESSURE UP TO 200 PSI ON WELLHEAD,SHUT IN TREE AND ALL WELLHEAD VALVES. -BLEED PRESSURE OFF SURFACE LINES. -WSL VERIFY.GOOD CEMENT TO SURFACE AND IN ALL ANNULI VALVES. -PUMP 103 BBLS TOTAL OF 15.8 PPG GLASS G CEMENT. WASH-UP WITH 20 BBLS CITRIC PILL TO CLEAR LINES AND CEMENTERS. 06:00 - 10:00 4.00 PXA P ABAN SECURE TREE AND CELLAR. -CHECK MOVING SYSTEM. -CLEAN OUT CUTTINGS BOX. -RDMO TO S-101. RIG RELEASED AT 10:00 HRS ON 10/11/2014 TO S-101. Printed 9/17/2015 4:32.49PM • • S-108, Well History (Post Rig Suspension) T/I/O=TWC/0/O. Pulled 3"CIW TWO#321 through tree for Doyon 16 Completion. Final WHP's 10/11/2014 0/0/0. ***Job Complete***See log. T/I/O=0/0/0. Removed Piggy back annulus valves(temp valve#74 and#75), and installed tapped 10/25/2014 blind flanges.Torqued and Pt'd. (See log.) RDMO. ***Job complete*** T/I/O= SI/0/0. Temp= SI. Monitor(Eval conductor size P&A). No flowline or AL attached. MV and crown valve only. Well has 20"conductor with a tree brace installed. —3'from grating to cellar floor. 11/22/2014 MV=C. IA&OA=OTG. NOVP. 1440. T/I/O=0/0/0. Temp= SI. MIT-T FAILED, MIT-IA, Strap Cement in TBG& IA& Install Lifting eye. (Post P&A). TBG, IA&OA Cemented to surface. See LOg for Details. MIT-T 4 tests, Last test TP lost 92 psi in the first 15 minutes. Bled TP to 0 psi&performed 5 minute BUR, TP increased 1 psi, re-bled TP to 0 psi. Rig down as per WSL. Final WHP's=0/0/0. Job Incomplete. 12/5/2014 SV= C. MV= O. IA&OA= OTG. NOVP. 16:45 T/I/O=9/4/1. Temp =SI. Strap TBG& IA Cement, Install Lifting eye, prep for cut off. (Post P&A). See Log for Details. Measurement from outside of SC to inside of cellar box(culvert)is 38"to 44". Center of circ ports to WH floor is 43"&cellar is—44"deep at the lowest point. Cellar gravel sample taken for flash point, Lifting eye installed on Tree cap. Final WHP's=0/0/0. 12/6/2014 SV&my = C. IA&OA=OTG. NOVP. 15:45. T/I/O=0/0/0. Temp= SI. (Spray bolts on conductor extension). Sprayed bolts on conductor extension using Aero-Kroil. 12/14/2014 SV, MV= C. IA, OA=OTG. 21:40. 12/18/2014 T/I/O=Cemented. Cut cellar box and remove conductor clamp. Heater installed in cellar. 12/19/2014 T/I/O=Cemented. Super suck gravel out of cellar. 12/20/2014 T/I/O=Cemented. Finish cutting cellar box(culvert) Rigged saw up on tree. Cut tree off. Strapped tubing @ 3'9"from top of cut to solid bottom with small amount of fluid on 12/21/2014 top. Strapped conductor from cut to top of fluid 19"and 3'of blue goo below that for a total of 55". Cement conductor to surface for P&A. Removed—30 gallons Blue Goo from conductor. Strapped conductor @ 45"and 3.5"kill string @ 45".. Used 48 gallons of 15.7 ppg Arctic Set 1 to fill 12/22/2014 conductor and kill sting to surface. Mud scale used to weigh cement. Cement top job. Cemented the conductor to surface with — 1 gallon of AS-1 cement. Installed cattle guard around cellar. Re-installed planks and plywood covering over cellar, cleaned up job 12/24/2014 site. Eval P&A. Shoveled snow from cellar boards to inspect cellar. Unable to see conductor due to cellar being full of snow, installed heater in cellar. 1/6/2015 21:55. Eval P&A. Cellar is completely thawed and free of snow or water. Conductor top appears clean with no signs of any material movement. Heater installed in cellar. Cattle guard around cellar. 1/8/2015 Plywood cover in good condition. 12:50. 9/11/2015 AOGCC wittnessed by Lou Grimaldi. Installed ID cap on conductor. Mi v ,, ,z ,. f 1', • r t fes.. t fir" "n�... '' t • t., ..., - ...„,,,,,,, ,, * a ,,,,, , , , „. A . 4 , ,,,,Iiii., , S yv st44, _ e , , ,.... * ie rr' I . ,5v.. a7ai'Tra ,,.,-; w.,, r y x l''. Nt . *,r 4 N. ' 1111 4 ,''.' its''''"sifr44411 z c, a0 t v .r • ovo, .se it W yen 44 e 144 a' is aPl �* y € 4' � ^ 1 i { i ° b x x I 1 "x 777222 14 . : it i a 1 l >v � tt i 1 A. kle':‘ \''k , it �� ‘41, �$j { r w • >4, , , .� r 4 ,i 4*k ' ‘,,,„...,i!it*: , 1 41 ‘$!7‘ - S • ri • t • r. _ • t r . _, .16 66. a :� D 's 'L i ‘d p s ..' r. TREE= 3-1/8"CNV S-1 0 8 AL-5 NOTES: WELLHEAD= FMC ACTUATOR= 3-1/8" ( �w'74• ;rlr7►i►AA 0'-1890' -10EMENT TO SURFACE,STAGE 3(10/1114) OKB BEV= 70.25' .}'i —. BF.ELEV= 41.254 993' —TAM PORT COLLAR,D=6.875" v_ KOP= 3150' 3-1/2"KLL STRING, H 1884' Max Angle= 48°@ 5502' 9.3#,L-80 NSCT, ted,,I� , 1890' HTOP OF STAGE 2-CMT(10/07/14) Datum MD= 7591' .0087 bpf,ID=2.992" ----- Llatum TVD= 6700'SS 2559' H 7`518"CEMENT RETAINER(10/06/14) 5-1/2"CSG STUB(10/02/14) — 2565' 3-1/2"TBG STUB(Rig 10/04/14) 2569' P1114,1‘440.34'::4 I x 2601' 5-1/2"CSG&3-1/7 TBG COLLAPSED 1 7-5/8"CSG,29.7#,L-80 BTC,ID=6.875" — 2857' ;t.'+`;iy 2575' —,TOP OF STAGE 1-CMT(10/05/14) 74' 4., _ GAS LIFT MANURES ST MD NO DEV TYPE VLV LATCH PORT DATE 3 3005 3003 6 KBG2-9 DMY INT 0 09/06/01 / 41 ESTIMA TED TOC(06/21/01) — —3180 4 2 3669 3628 31 KBG2-9 SO INT 22 10/20/08 ti III 1 5385 4848 47 KBG2-9 "DMY INT 0 09/25/03 �; (rOF T��• �7j,�sv THE STATE Alaska Oil and Gas �� n lsKA. aska OiConservation Commission wit.-,,:_-_-,,,, 333 West Seventh Avenue 'ma GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: OA"ALASE Fax• 907.276 7542 StItIE' M+ www.aogcc.alaska goy Jessica Sayers Well Integrity Engineer _ /00 BP Exploration (Alaska), Inc. a© I P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Aurora Oil Pool, PBU S-108 Sundry Number: 315-490 Dear Ms. Sayers: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /04,,,,.--k--...__ Cathy P. oerster Chair DATED this 2 day of August, 2015 Encl. RBDMS *..1 SEP 0 4 2015 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM IN APPLICATION FOR SUNDRY APPRO' .,S 20 AAC 25.280 1 Type of Request Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend Ii/P�.17 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program El • Plug for Rednll 0 �S Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 0 2. Operator Name BP Exploration(Alaska),Inc 4 Current Well Class 5. Permit to DnII Number 201-100 • 3. Address P.O.Box 196612 Anchorage,AK Exploratory 0 Development RI. 99519-6612Stratigraphic 0 Service ❑ 6 API Number 50-029-23021-00-00. 7. If perforating 8. Well Name and Num " What Regulation or Conservation Order governs well spacing in this pool? RECEIVED M Will planned perforations require a spacing exception? Yes 0 No RI PBU S-108 • AUG 1 i 2015 9 Property Designation(Lease Number) 10. Field/Pools c Y 2 r S ADL 028257 • PRUDHOE BAY,AURORA OIL • AOGC 11 PRESENT WELL CONDITION SUMMARY v Total Depth MD(ft) Total Depth TVD(ft) Effective Depth MD(ft) Effective Depth ND(ft) Plugs(measured) Junk(measured) 7850' 7029' Surface Surface Surface -7669' Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 34'-114' 34'-114' 1490 470 Surface 2823' 7-5/8" 34'-2857' 34'-2855' 6890 4790 Intermediate Production 5720' 5-1/2"x 3-1/2" 2565'-7835' 2563'-7014' 7000 4990 Liner Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) None None 3-1/2"9 3# L-80 29'-1884'/2569'-5509' Packers and SSSV Type None Packers and SSSV MD(ft)and TVD(ft) None No SSSV Installed No SSSV Installed 12.Attachments Descnption Summary of Proposal 0 13.Well Class after proposed work. BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development a • Service 0 14.Estimated Date for Commencing Operations. August 25,2015 15. Well Status after proposed work _ _. Oil 0 Gas 0 WDSPL 0 Suspended m • 16.Verbal Approval Date WINJ 0 GINJ 0 WAG 0 Abandoned 0 Commission Representative Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sayers,Jessica Email Jessica Sayers©bp com Pnnted Name Sayers,Jessica Title Well lntegnty Engineer Signature l / AAArne +1 907 564 4281 Date gIll I's V�/ COMMISSION USE ONLY Conditions of approval ify Commission so that a repre tive may witness Sundry Number Plug Integnty p BOP Test 0 Mechanical Integrity Test 0 Location Clearance V Other Ai(9ti fy 41th f6 l'✓t$pr.e /-&v Gc #-d p is fio d0 Cv+vtfnf 1-4-)t fol/aw1140 '. I, kV l7"r1fSS t'fl`li/r(c/ f0 Co .-, ri'.- -, C'fvlt✓� is C 2. R j1-t1fC 55 1-1-0 Fr nrr`0i- 1-0 't K_Gfvf -/-z,-/-z, Sv ' 1'.-I P``'1- e- 3 ,7latt 3 - S I 4--f G r✓Z In rGl,,j L G(1,p, ti a l Spacing Exception Required? Yes 0 No Lf Subsequent Form Required /0 — (j APPROVED BYTHE Approved by aL(47/4514-- COMMISSIONER COMMISSION Date 8-2S-/J ORIGINAL RBDMS SEP04 2015 Submit Form and Attachments in Duplicate To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 08-10-15 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281, cell: 602-8715) Subject: S-108 Well Suspension Summary S-108 was scoped for no further utility and planned for end of well life plug and abandonment. The RWO operation performed the downhole scope of work in October 2014. Below is a summary of the job execution. Rig up and circulate the well to seawater. Pressure remained on the well after multiple circulations with 1°/0 KCI. Ultimately 9.8 ppg brine was used to kill the well. The tree was removed and BOPE nippled up and tested. 3-1/2" tubing was recovered to the pre-rig jet cut at 2,552'. Washover, mill, and fish additional 3-1/2" tubing to 2,568'. Unable to washover 3-1/2" collar and wear on the outside of the shoe indicated casing damage. Rig up e-line and perform CBL and caliper. Cut and recover 5-1/2" casing from 2,565'. Run spear and packoff to stab into 3-1/2" tubing and confirm no injectivity. Mill top of 3-1/2" tubing stub to 2,569'. Run 3-1/2" cleanout BHA and establish loos rate of 40-50 bph while circulating. Find collapsed tubing at 2,674'. Run spear and packoff and establish injectivity of 2.5 bpm at 1,470 psi. Pump 60 bbl 15.8 ppg cement plug to isolate the reservoir. The cement plug failed to test with a test packer indicating a casing leak. 80 feet of cement was milled and another test packer was run in the hole and again the test failed. Set 5-1/2" cement retainer at 2,559' and confirm no injection possible below the retainer. Pump 36 bbls of 15.8 ppg cement on top of the retainer leaving TOC at 1890'. Test of cement plug failed due to casing leaks. Run 3-1/2" kill string to 1884'. Pump 103 bbls of 15.8 ppg cement surface to surface. Observe good cement at surface and in all annuli valves. RDMO. After the rig operation in December 2014, blue goo was removed and replaced with cement to surface, in addition to the wellhead being removed. The plan for this well is for the status to remain suspended with the wellhead removed about one foot below tundra, with a mechanically fastened marker plate a top the tubing/casing/cement. Well Detail Current Status: Not Operable — PAL Integrity Issues: Well fully abandoned downhole, three cement plugs to surface Relevant History: > 10/11/14: Well Cemented to surface > 12/05/14: MIT-T Fail w/ N2 to 500 psi > 12/06/14: Strap TBG and IA cement > 12/21/14: Cut off tree > 12/22/14: Remove blue goo, cement conductor to surface Well Program: 1 SPr Ensure wellhead is removed approximately 1' below pad grade 2 SPr Mechanically fasten marker plate to conductor, with well specific information • Notify the AOGCC for inspection and provide photo documentation of the following: o Cement to surface o Cutoff prior to attaching marker plate o Marker plate attached o Site clearance 2 of 3 PTO 20! —/ 0c7 • • Loepp, Victoria T (DOA) From: Sayers, Jessica <Jessica.Sayers@bp.com> Sent: Thursday, August 20, 2015 11:35 AM To: Loepp, Victoria T (DOA) Cc: Lastufka,Joseph N Subject: RE: PBU Y-38(PTD 195-046); S-108(PTD 201-100); 15-24(PTD 191-128) Suspend Sundries Follow Up Flag: Follow up Flag Status: Flagged 5 20%LIAR Thanks, Victoria. solve 20 AAC 25.120 specifies requirements for an abandoned well and we are only suspending the wells with a surface plug to surface, one foot below pad level. The wells will not be abandoned three feet below tundra until a later date, in which we have full intentions of welding the marker plate as specified in 20 AAC 25.120. Thanks! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent: Thursday, August 20, 2015 11:09 AM To: Sayers, Jessica Cc: Lastufka, Joseph N Subject: RE: PBU Y-38(PTD 195-046); S-108(PTD 201-100); 15-24(PTD 191-128) Suspend Sundries Why aren't you welding the marker plate on flush with the outermost casing string consistent with 20 AAC 25.120? Why this new design?Will require a waiver. Thanx, Victoria From: Sayers, Jessica [mailto:Jessica.Savers(abp.com] Sent: Thursday, August 20, 2015 9:10 AM To: Loepp, Victoria T(DOA) Cc: Lastufka, Joseph N Subject: RE: PBU Y-38(PTD 195-046); S-108(PTD 201-100); 15-24(PTD 191-128) Suspend Sundries Hi Victoria, please see below for comment responses in blue. Thanks! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loeppPalaska.gov] Sent: Tuesday, August 18, 2015 10:27 AM To: Sayers, Jessica Subject: PBU Y-38(PTD 195-046); S-108(PTD 201-100); 15-24(PTD 191-128) Suspend Sundries Jessica, Please provide the following for each suspension: 1. Information to be provided on the marker plate 1 Loepp, Victoria T (DOA) From: Sayers,Jessica <Jessica.Sayers@bp.com> Sent: Thursday, August 20, 2015 9:10 AM To: Loepp,Victoria T (DOA) Cc: Lastufka,Joseph N Subject: RE: PBU Y-38(PTD 195-046); -108(PTD 201-100), 15-24(PTD 191-128) Suspend Sundries Attachments: IMG_3253jpg;IMG_3254jpg; 15-24 Sundry Plan Forward.doc; S-108 Sundry Plan Forward.doc;Y-38 Sundry Plan Forward.doc Hi Victoria, please see below for comment responses in blue. Thanks! Jess Sayers From: Loepp, Victoria T(DOA) [mailto:victoria.loepp©alaska.gov] Sent: Tuesday, August 18, 2015 10:27 AM To: Sayers, Jessica Subject: PBU Y-38(PTD 195-046); S-108(PTD 201-100); 15-24(PTD 191-128) Suspend Sundries Jessica, Please provide the following for each suspension: 1. Information to be provided on the marker plate The following information will be welded/stenciled onto the top of the marker plates: BP Exploration Alaska, Inc Y-38. PTD#195-046 API No. 50-029-2255 =00 BP Exploration Alaska,Inc 5-108 PTD#201-100 API No. 50-029-23021 BP Exploration Alaska,Inc 15-24 PTD#191-128 API No. 50-029-22223 2. Modify the procedures to include the following: a. AOGCC inspection and photo documentation of the following: i. Cement to surface ii. Cutoff prior to attaching marker plate iii. Marker plate attached iv. Site clearance 1 Please see attached, revised procedures. 3. How will the marker plate be attached?Schematic would be helpful. I attached two pictures of the marker plates. The lip will have 4-5 spaced out, '/<" to 1"threads machined for set screws into the conductor. 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.Loeppl alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 2 044, To: Ken Bulloch / Scott Bundy; AK, D&C Special Projects Tyler Norene / Len Seymour; AK, D&C Well Services Team Lead Date: 08-10-15 From: Jessica Sayers, Well Integrity/Intervention Engineer (office: 564-4281 , cell: 602-8715) Subject: S-108 Well Suspension Summary S-108 was scoped for no further utility and planned for end of well life plug and abandonment. The RWO operation performed the downhole scope of work in October 2014. Below is a summary of the job execution. Rig up and circulate the well to seawater. Pressure remained on the well after multiple circulations with 1% KCI. Ultimately 9.8 ppg brine was used to kill the well. The tree was removed and BOPE nippled up and tested. 3-1/2" tubing was recovered to the pre-rig jet cut at 2,552'. Washover, mill, and fish additional 3-1/2" tubing to 2,568'. Unable to washover 3-1/2" collar and wear on the outside of the shoe indicated casing damage. Rig up e-line and perform CBL and caliper. Cut and recover 5-1/2" casing from 2,565'. Run spear and packoff to stab into 3-1/2" tubing and confirm no injectivity. Mill top of 3-1/2" tubing stub to 2,569'. Run 3-1/2" cleanout BHA and establish loos rate of 40-50 bph while circulating. Find collapsed tubing at 2,674'. Run spear and packoff and establish injectivity of 2.5 bpm at 1,470 psi. Pump 60 bbl 15.8 ppg cement plug to isolate the reservoir. The cement plug failed to test with a test packer indicating a casing leak. 80 feet of cement was milled and another test packer was run in the hole and again the test failed. Set 5-1/2" cement retainer at 2,559' and confirm no injection possible below the retainer. Pump 36 bbls of 15.8 ppg cement on top of the retainer leaving TOC at 1890'. Test of cement plug failed due to casing leaks. Run 3-1/2" kill string to 1884'. Pump 103 bbls of 15.8 ppg cement surface to surface. Observe good cement at surface and in all annuli valves. RDMO. After the rig operation in December 2014, blue goo was removed and replaced with cement to surface, in addition to the wellhead being removed. The plan for this well is for the status to remain suspended with the wellhead removed about one foot below tundra, with a mechanically fastened marker plate a top the tubing/casing/cement. Well Detail Current Status: Not Operable — PAL Integrity Issues: Well fully abandoned downhole, three cement plugs to surface Relevant History: > 10/11/14: Well Cemented to surface > 12/05/14: MIT-T Fail w/ N2 to 500 psi > 12/06/14: Strap TBG and IA cement > 12/21/14: Cut off tree > 12/22/14: Remove blue goo, cement conductor to surface Well Program: 1 S Ensure wellhead is removed approximately 1' below pad grade 2 S Mechanically fasten marker plate to conductor, with well specific information SUPERSEDED 2 of 3 TREE= 3-1/8"CNV S-108 W LHEAD= FMCFL QTY NOTES: ACTUATOR= 3-1/8" IV III /IA 0'-1890' —CENENT TO SURFACE,STAGE 3(10/1114) OKB.ELEV= 70.25' ►� y/y/� ►��v♦le III PC/4 993' —TAM FORT COLLAR D=6.875' BF.ELEV= 412 ��i ♦1� III//`•••' KOP= 3150' 3-1/T KLL SIRING, H 1884' .i ii•I•I•Selae•III •IrI_I,I•I_I_I_ItI1• Max Angle= 48°@ 5502 9.3#,L-80 NSCT, iI�"I*I�I"I'I.01,-/ 1890' —TOP OF STAGE 2-CMT(10/07/14) Datum MD= 7591' .0087 bpf,D=2.992" •��+•44.414.46f.1_1� 2559' —7-5/8"C9 fT RETANER(10/06/14) Datum TVD= 6700'SS 5-1/2"CSG STUB(10/02/14) — 2565' ' i I ‘4 P. •,'4 3.1/T TBG STUB(Rig 10/04/14) — 2569' *VI 2601' — 5-1/T CSG&3-1/T TBG COLLAPSED•ii • 7-5/8"CSG,29.7#,L-80 BTC,D=6.875" — 2857' 1I I� ,I`I I 2575' HTOP OF STAGE 1-CMT(10/05/14) 0I.,I GAS LFT MANDRELS ,I,I+� ST MD TVD DEV TYPE VLV LATCH PORT DATE a••I3 3005 3003 6 KBG2-9 DMY NT 0 09/06/01 III'. ESTIMATED TOC(06/21/01) —3180 a I`I`I ,' 2 3669 3628 31 KBG2-9 SO NT 22 10/20/08 x I_I_�. 1 5385 4848 47 KBG2-9 *MY NT 0 09/25/03 P. ►I•I•I "i ‘,.••• k.,„' I 'STA#1=HAS EXTENDED PACKING STACKS CMY' Nig krvv III r ALL GLV'S CEMENTED P.P. •/•/r/• tI Pi t‘ 1.' !* �I*ISI I, liag /II �/I1/I1I c0 ,III;;II ,ItII i� tj‘I'‘j4' 5443' —H3-1/2'HESX NP,D=2.813" ►` ,/tI`I ►I kVP. ,, , 549T H 3-112"NO SIB,D=3.00" P. III. I 5-1/2"CSG,15.5#,L-80 BTC,13=4.95' —{ 549T01,. ,.... � ' 5509' —15-1/T X 3-1/2"XO,13=2.968" i I: / 3-1/2"TBG,9.3#,L-80 NSCT,.0087 bpf, D=2.992' 5497' �ItI,I5509' —i3 1/2'SEAL ASSY w!MULESHOE.,HOE,D=3.00' I III.'. TOP FO SCHRADER BLUFF — 6688'and c. vim-111V ►I III. '4 III 6164' 3-1/2'HES X WAD=2.813" PERFORATION SUMMARY �i I�I�I. 4I/I. REF LOG: i►Ilb • ►ll:ev 6206' H3-1/2"RA TAG MARKER N COLLAR ANGLE AT TOP PERF: Cr @ 7536' i.e.A� Note:Refer to Production DB for historical perf data j‘I4e,, 7386' —13-1/2"RA MARKER N COLLAR ►•••• SIZE SPF INTERVAL Opn/Sqz SHOT SOZ �4 4I‘/�Il 2-1/8" 4 7536-7566 S 09/07/01 10/05/14 ;4 ±;j;��-. 7490' 3-1/2'HES X NP,D=2.813' 2" 6 7620-7632 S 04/17/02 10/05/14 4 ♦II '. klrl `t, ,4,I`4 III II a1.le i 411 `III 7669'slm1w/GAUG -1-3/8'FN(09/07/01) RSH-1.75"X 9'BALER • TOP Kuparuk — 7633'md : 44,Iy1 t r �.r, • 7722' —ILATCI+NBYPASS RECE'T,13=2.250' R31D H 7768' 74,7.474. 3-1/2"CSG,9.3#,L-80 NSCT,.0087 bpf, ID=2.992" — 7835' * + ' DATE REV BY CONCENTS DATE REV BY COMMENTS AURORA UNT 06/23/01 D-14 INTIAL COMPLETION WH L: S-108 10/11/14 D•16 P&A PERIAT Na:P`2011000 10/14/14 PJC DRLG HO CORRECTIONS AR No: 50-029-23021 10/14/14 SMc/PJC FNAL ODE APPROVAL SEC 25,T12N,R12E,4511'FSL&4497'FEL BP Exploration(Alaska) t ,: • e f • J j y , ` 1T,4-,.-1...:.,.0','..., ,IDdy 1a 5,.m 9 .4.:- 0,--4.P, „4., X! 0 1 a '47,44,. ,” wfi a •.+ i . q # ' 0 , fat 6 :4'4:;' � ..f .� .)4tAk is k. Rp • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected 12/27/14 Inspector John Crisp Operator BPX Well Name PBU S-108 Oper Rep Dan Scarpella PTD No 2011000 Oper Phone 659-5580 Location Verified? Yes Oper Email scardm@l_p corn If Verified,How? Other(specify in comments) Onshore/Offshore. Onshore Suspension Date. 10/11/14 Date AOGCC Notified. 12/25/14 Sundry No 314-411 _ Type of Inspection. Initial Wellbore Diagram Avail ? Yes Well Pressures(psi): Tubing N/A Photos Taken? Yes IA N/A OA N/A Condition of Wellhead All casing strings cut off 2'below surface of PBU S-pad Condition of Surrounding Surface Location. Between active wells on PBU S Pad Snow covering location make it impractical to check surrounding area for debris,evidence of spills,etc - Follow Up Actions Needed This well will have to be cut off at least 3'below tundra level to be permanent P&A Temporary marker plate to be installed before burial at future date Comments This seems to be BPX policy in all Fields to cut off 2'below Pad level and suspend Attachments Photos(6) SCAN ,1 l -(-•' REVIEWED BY: �J Insp Supry 31(9(15" Comm PLB 12/2014 2014-1227_Suspend_PBU_S-108Jc xlsx , , p .,6, ,,. ,, .,,,,,,::0)4., ,,4044,..,3"7, 1,,„73,. .q .: 1Y -. Z. V /� "hzyi _�'ry 0.b '� d 00 O ,,ar. R v cn Ip p 4,yOgq o O N CI.oU � t:141N tO ,� U C`1 -0 au 0 V O N y O ; a 1 4 CA « y N 4 1 1 iii 1 1... ,I I I \ z . i_x d l,S i $ 1'. i F 1 • 4 X U ii, 6 00 1M 0 N �I tll 0 CV) N cd Q.a S :£. •1 1 - , N N • #3, x © • 3 • 4 .♦ 4 • , 1 S 404> * cl N M r o N • s , • o o O o N 9o j if,p., o o .. ' Q. Or•°, wWz o 1-4 r • II u, \\ `1 iG Q 1 t Allr*.k "" .., ' "10 4 oc O o ,,,, ' '' .. . VA PO l o pIM Q bA N aS F,',.'". N h o r-' f' 'r , ,,, , , ,, . , ,,,,, , , N , , ,f • rylr' r::,t Y fI dA 7 r Irr!:,'.ae Project Well History File Cove, Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c~ O J-- / ~~ Well History File Identifier RESCAN DIGITAL DATA ~/" Color items: ~"' Diskettes, No. ~ [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY; BEVERLY ROBIN VINCENT SHERYI~~VINDY , OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation _(-,~ x30 =~+ BY: BEVERLY ROBIN VINCENT SHERYL~~WINDY ' ! Production Scanning Stage I PAGE COUNT FROM SCANNED FLEE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES Stage 2 IF NO IN STAGE 1~ PAGE(S) DISCREPANCIES WERE FOUND: YES BY: BEVERL~ VINCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) NO NO I RESCANNED BT; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is/ General Notes or Comments about this file: Quality Checked 12110102Rev3NOTScanned.wpd OF 7,4 y*v*,,I�j,'s THE STATE Alaska Oil and Gas N� "—yrs ALASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFALASY'PAnchorage, Alaska 99501-3572 Main: 907.279.1433 to 6 2V4 Fax: 907.276.7542 David Bjork v U Engineer Team Leader BP Exploration (Alaska), Inc. / /� D P.O. Box 196612 pt7 ,�0 Anchorage, AK 99519-6612 Re: Prudhoe Bay Oil Field, Aurora Pool, PBU S-108 Sundry Number: 313-619 Dear Mr. Bjork: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ae,47Cathy Foerster Chair DATED this Ay of December, 2013. Encl. ev LA$ RECEIVED STATE OF ALASKA o ' ALASKA OIL AND GAS CONSERVATION COMMISSION �'�'ti ` APPLICATION FOR SUNDRY APPROVAL ®?S 1z( ti NOV 2 5 201f3 20 AAC 25.280 AOGCC 1. Type of Request: �+ ❑Abandon 0 Plug for Redrill 0 Perforate New Pool ®Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate ®Pull Tubing 0 Time Extension I ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate !Ti Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. 0 Exploratory ❑Stratigraphic 201-100 3. Address: ® Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-23021-00-00 ' 11 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU S-108 , Will planned perforations require a Spacing Exception? 0 Yes No 9. Property Designatior 10. Field/Pool(s): ADL 028257 - Prudhoe Bay/Aurora . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7850' • 7029' . 7768' 6947' None —7669', 7722' Casing Length Size MD TVD Burst Collapse Structural Conductor 107' 20" 107' 107' 1490 470 Surface 2823' 7-5/8" 34'-2857' 34'-2855' 6890 4790 Intermediate Production 7804' 5-1/2"x 3-1/2" 31'-7835' 31 -7014' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7536'-7632' 6715'-6811' 3-1/2",9.3# L-80 5509' Packers and SSSV Type: None Packers and SSSV None MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: 1 ®Description Summary of Proposal ®BOP Sketch - 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation January 1,2014 . _I Oil ❑WINJ ❑WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: ❑WAG 0 SPLUG 0 Suspended '17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Sean McLaughlin,564-4387 Printed Name: David Bjork Title: Engineering Team Leader Email: Sean.McLaughlin@bp.com Signature:` Phone: 564-5683 Date: 1//3//c Commission Use Only Conditions of approval: Notify Commission so that a representative may witness ,�` Sundry Number: ?J`% ,cc `q ❑Plug Integrity I_7 BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: B op fie S f iz, 35-e 6 p S ; RBDM MAY 0 9 2014 Spacing Exception Required? 0 Yes [ No Subsequent Form Required: /a — 4..0 4- APPROVED BY / Approved By: COMMISSIONER THE COMMISSION Date: /2 -2.9 66 - 11 Form 10-403 Revised 1 /2012 / ApproGRrtINALRTG n' ir 12 months from the date of approval Submit In Duplicate I' tilit rl.it; 3 f I/ bp Sundry Request for casing repair Well: S-1080 Date: 11/13/2013 Engineer: Sean McLaughlin MASP: 830 psi Well Type: Producer Estimated Start date: January 2014 History: S-108 was drilled as a vertical producer in the Kuparuk reservoir in 2001 and is currently classified as not operable for TxIA communication. S-112 is the only injection support for S-108 producer. - The well has failed pressure testing in the past but with a patch over a leaking GLM the well was reclassified as operable. The use of a seal assembly may have put enough pressure on the tubing string and eventually caused the collapse in the tubing. The primary objective of this RWO is to bring well back to operability and have the ability for CTD to sidetrack the well for future development. During the pre-rig integrity testing S-108 exhibited T/I/O communication. As a result the RWO scope was increased to include a 5-1/2" casing repair. Scope of Work: Pull collapsed 3-1/2"completion, Cut and pull 5-1/2" surface casing and run tie-back, Run 3-1/2" chrome completion. Pre Rig Prep Work: W 1 Check the tubing and casing hanger lock down screws for free movement. Completely back out _ and check each lock down screw for breakage(check one at a time). PPPOT-T& IC. F 2 Bullhead 290 bbls into well with 120 degree S/W to kill well and thaw IA. Diesel F/P. ✓ 3 Prep annular valves per WSL, Set a BPV in the tubing hanger. O 4 Remove the well house &flow line. Level the pad as needed for the rig. Proposed RWO Procedure: 1. MIRU. Pull BPV. Circulate KWF. Install TWC. Nipple down tree and adapter flange. 2. NU 4 preventer BOP consisting of annular, 3-1/2"x 6"VBRs, blind shear rams, flow cross and 2-7/8"x 5"VBRs. Pressure test BOPE to 3,500psi high/250psi low. Test the annular to 3,500 psi. 3. Pull and lay down 3-1/2" 9.2# L-80 tubing to cut. 4. Overshot tubing stub and jar seals free. LD remainder of 3-1/2"tubing. 5. Run 5-1/2" RBP to 5,450' and test to 1000 psi. 6. RU E-line, Run USIT in the 5-1/2"casing to determine TOC in the 5-1/2"x 7-5/8" annulus, Run caliper to 3000'. 7. Set 5-1/2" RBP and 50'of sand —100' below logged TOC. PT RBP to 2,000 psi. 8. Mechanically cut 5-1/2"casing in 1st full joint above the TOC. 9. Pull 5-1/2"casing to surface. 10. Scrape 7-5/8"and dress-off 5-1/2"casing stub 11. Run 5-1/2"tie-back fully cemented to surface with 45 bbls of 15.8 ppg class G cement **no change to wellhead equipment 12. Drill out the 5-1/2" shoetract and test casing to 3,000 psi. 13. Recover the upper and lower RBPs. 14. Run scraper and test packer to test casing to 3000 psi at 5,450'. 15. Run 3-1/2"9.2# 13Cr VamTop tubing. Test packer to 3000 psi../ 16. Set TWC. ND BOPE. NU and test tree. Pull TWC, Freeze Protect, Install BPV. RDMO. Post ri Work ✓ 1 Pull BPV S 2 Pull ball and Rod, Pull RHC seat, Install GLV's SAFETY NOTES: NO PRODUCTION PKR IN WELL; ELLHEAD= FMC 11/13/13 CIUATOR= BAKER S-1F SEAL ASSY ONLY. 3.ELEV= 70' F.ELEV= 412 I DP= 3150' TXIAXOA communication = _1 993' --I TAM PORT COLLAR,D=6.875" ax Angle= 48 @ 5_310' atum MD= 7591' ' - 2188' H3-1/2"HES X NP,D=2.813" 3tum TV D= 6700'SS Jet Cut at 2,552' ) ( 2652' RESTRICTION,D=1/5"(SMALLER THAN) .3 (TAGGED 06/11/11) 1-5/8"CSG,29.7#,L-80 BTC,113=6.875" H 2857' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 1.825" @ 5370' L 3 3005 2933 8 KBG2-9 DMY NT 0 09/25/03 3-1/2" BAKER TBG PATCH 2 3669 3558 30 KBG2-9 SO NT 22 10/20/08 1 5385 4779 47 KBG2-9 **MY NT 0 09/25/03 �"" ti ""ST TION#1 =DMY HAS EXTENDED PACKING CI 2 5370' -5405' H3-1/2"BKR PATCH,D=1.825"(03/13/06) l g c i i I I 5443' H 3-1/2"HES X NP,D=2.813" • 5497' H3-1/2"NO SUB,D=3.00" – Fl 5-1/2"CSG,15.5#,L-80 BTC,D=4.95" H 5497' —I11�� I 5509' H5-1/2"X 3-1/2"XO,D=2.968" -1/2"TBG,9.3#, L-80 NSCT, .0087 bpf,D=2.992" —I 5489' 5509' —13-1/2"SEAL ASSY w/MULE SHOE,ID=3.00" PERFORATION SUMAARY REF LOG: ANGLE AT TOP PERF: .50 @ 7536' I I 6164' H 3-1/2"FES X NP,D=2.813" Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 111 6206' H RA TAG 2-1/8"/". 4 7536-7566 0 09/07/01 2" 6 7620-7632 0 04/17/02 U 7385' —IRA TAG I I 7490' H 3-1/2"FES X NP,D=2.813" ak 0 7669'slim 1.75"X 9'BALER W/GAUGES(1-3/8"FN)(09/07/01 lir 7722' H FISH-LATCH-IN BY PASS RECEPT,ID=2.250" PBTD H 7768' ."; 3-1/2"CSG,9.3#,L-80, NSCT,D=2.992" —I 7835' 4.4.. DATE REV BY COMWENTS DATE REV BY COPW'ITS AURORA UNIT 06123/01 CIi1KAK ORIGINAL COMPLETION 06/14/07 KSB/PJC GLV GO&MSC CORRECTIONS WELL: 5-108 11/13/05 DTR/PJC SET LTTP @ 5398 09/16/07 KSB/PJC GLV GO PERMIT No:'2011000 03/10/06 RLNYPAG RLL LTTPILWR PKR(01/17/06) 11/10/08 DAV/SV GLV GO(10/20/08) API No: 50-029-23021 03/17/06 RRDVTLH PATCH SET(03/13/06) 09/29/09 RMC'/SV TREE GO(07/11/09) SEC 25,T12N,R12E 4511'FSL&4497'FEL 04/14/06 KSB/PJC GLV GO 06/15/11 ALW PJC TBG RESTRICTION(6/11/11) 06/03/07 DAV/PAG GLV GO BP Exploration(Alaska) CIW P WELLHEAD 31/8"FMC S-108 PKR SEAL ASSY ONLY. PKR IN WELL; ACTUATOR= BAKER KB. =6- 41z_ PROPOSED KOP= 3150 — 993' -ITAM PORT COLLAR,ID=6.875" MaxAngle= 48 @ 5310' •ti •1 Datum MD= __7591' rti '� r• 3-1/2" HES X N I P, I D=2.813" © 2200' Datum TVD= 6700'SS •1 1 • i 5-1/2" ES Cementer - 5-1/2" Baker ECP — , ; 5-1/2" Bowen casing Patch 7-5/8"CSG,29.7#,L-80 BTC,D=6.875" H 2857' GAS UFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 2/5" @ X N NIP L C z X79 1 5285 3-1/2" 9.2# 13Cr-80 VamTop 3-1/2" HES X NIP, ID=2.813" 3-1/2" x 5-1/2" BKR SABL Packer R —@5,415' ID=2.78" I I 3-1/2" HES XN NIP, I0=2.635" 3-1/2" half mule shoe @5505' 66498• -IPBR ID=4.0" 5-1/2"CSG,15.5#,L-80 BTC,D=4.95" -{ 5497' I-- 5509" -5-1/2"X 3-1/2"XO,D=2.968" 3-1/2"TBG,9.3#,L-80 NSCT,.0087 bpf,D=2.992" H 5499' —� PERFORATION SUMutARY REF LOG: ANGLE AT TOP PERF: .50 @ 7536' ' IP 6164' -13-1/2"FES X NP,D=2.813" Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I 6206' HRA TAG 2-1/8"r 4 7536-7566 0 09/07/01 2" 6 7620-7632 0 04/17/02 111 7385' -IRA TAG I I 7490' H 3-1/2"FES X NP,D=2.813" 7669'slm H 1-75"X 9'BALER W/GAUGES(1-3/8"FN)(09/07/01) alk 7722' -I FISH-LATCH-IN BYPASS RECEPT,ID=2.250" PBTD 7768' 4' V 3-1/2"CSG,9.3#,L-80,NSCT,D=2-992" 7835' 444 DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 06/23/01 CI-WKAK ORIGINAL COMPLETION 06/14/07 KSB/PJC GLV C/0&MSC CORRECTIONS WELL: S-108 11/13/05 DTR/PJC SET LTTP @ 5398 09/16/07 KSB/PJC GLV GO PERMT No:' 011000 03/10/06 RUNPAG FULL LTTP/LWR PKR(01/17/06) 11/10/08 DAV/SV GLV(70(10/20/08) API No: 50-029-23021 03/17/06 RRDVTLH PATCH SET(03/13/06) 09/29/09 RMC/SV TREE GO(07/11/09) SEC 25,T12N,R12E,4511'FSL&449T FEL 04/14/06 KSB/PJC GLV GO 06/15/11 ALW PJC TBG RESTRICTION(6/11/11) 06/03/07 DAV/PAG GLV G0 BP Exploration(Alaska) - I a • 0 1 t: . •1 0 5 1 8 WZS HHHE 0 "r 1 -r : ; ,- .:' : Z b Zo s g Q Z Z a 11 ppe 0 0 a o w a a O 0. 6• i•x �sl y w a W se CC a g YW a. R = o = O Z N • J $ 111 Q , LACk O I I' 1) Oo vii ami -�-I o on ,, yea -I W aU � M U O 7 _O� 0� �J a -� �I a m _yam l! m �� o -� Z N ..1a- -1 ¢ • -ll z z qa L o .0 8 . N ^Q X U j 6 a �am p L., CO ca ¢ O NO OpP o Jp W 0 10 I S •o IF rh) i . /11 Ed U'ii'I' o III' I'F e a w f ! $\ ill • E •Ate ' o 0 _ 3 rY W _ Vp m m Lj h N Ferguson, Victoria L (DOA) From: McLaughlin, Sean M <Sean.McLaughlin@bp.com> Sent: Wednesday, December 11,2013 10:28 AM To: Ferguson,Victoria L(DOA) Subject RE: PBU S-108(PTD 201-100, Sundry 313-619) Yes,The tubing will be tested just before testing the packer. We will drop a ball n rod and pressure up on the tubing to set the packer. Pressure (3000 psi)will be held on the tubing for a 30 min test. We then bleed to tubing to 1500 psi and test the casing/packer to 3000 psi for 30 minutes. Regards, sean From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent: Wednesday, December 11, 2013 9:36 AM To: McLaughlin, Sean M Subject: PBU S-108(PTD 201-100, Sundry 313-619) Sean, In step 14 a test packer is run to 5450'and the casing is tested to 3000 psi;then is step 15,the tubing is run and the packer is tested to 3000 psi. Do you pressure test the tubing? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferguson(a�alaska.gov 1 • • Page 1 of 1 Regg, James B (DOA) From: Jones, Jeffery B (DOA) Sent: Thursday, December 03, 2009 9:35 AM ~~~ (z(~1~~ To: Regg, James B (DOA) 1\ t Subject: PBU S-108 conductor extension Attachments: S-108 conductor extension 11-12-09 006.jpg Please see attached S-108 well head photo. Jeff 12/3/2009 • • PBU 5-108 Conductor Extension PTD 201100 Photo by AOGCC Inspector Jeff Jones 11 / 12/2009 BPX installed a new steel clam that extends the conductor up and over the surface casing flutes, minimizing the wellhead movement. *, ~ ~ «~¢~:~+~ «.,.o-. r ~ :/ J s v a ... ,..e a x . ~ Page 1 of 3 Regg, James B (DOA) 2~?1~It~O From: Jones, Jeffery B (DOA) ~ ~. Sent: Thursday, December 03, 2009 9:14 AM ` `~~ Ivy 3I ( To: Regg, James B (DOA) Cc: Crisp, John H (DOA); Jones, Jeffery B (DOA); Grimaldi, Louis R (DOA); Noble, Robert C (DOA); Regg, James B (DOA); Scheve, Charles M (DOA) Subject: FW: S-108 (PTD #2011000) conductor extension Jim, I was out at S pad for MIT's last hitch and looked this item over. A new steel clamp was installed that extends the .-- conductor up and over the surface pipe flutes minimizing the well head movement. It appears BPXA has successfully addressed this problem. From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Saturday, November 21, 2009 2:00 PM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay; GPB, Ops Supt; NSU, ADW Well Integrity Engineer Subject: S-108 (PTD #2011000) conductor extension Hi Jim, S-108 (PTD #2011000) conductor extension was installed last week and observed by Inspector Jeff Jones on November 17, 2009. Please let us know if there is any additional information you need. Thank you, Anna ~Du6e, ~.~. (alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, September 18, 2009 9:55 AM To: NSU, ADW Well Integrity Engineer Cc: DOA AOGCC Prudhoe Bay Subject: RE: PBU S-pad Issues Please notify Inspector when installing the S-108 extension so he document what is being done. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] 12/3/2009 • Page 2 of 3 Sent: Thursday, September 17, 2009 4:03 PM To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer Cc: DOA AOGCC Prudhoe Bay Subject: RE: PBU S-pad Issues Mr. Regg, Well S-100 (PTD 2000780) SSV barrel was wiped clean on 9/14. There has not been any other signs of a leak since the barrel was cleaned. However, I would like to monitor the well for another couple more days to ensure it doesn't re-appear. Well S-108 (PTD 2011000) will have an extension added on to the conductor to eliminate wellhead movement. It will take another day to fabricate the extension and fasten it to the conductor. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, September 17, 2009 2:47 PM To: GPB, Ops Supt; NSU, ADW Well Integrity Engineer Cc: DOA AOGCC Prudhoe Bay Subject: RE: PBU S-pad Issues Any progress? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 - From: Regg, James B (DOA) Sent: Thursday, September 10, 2009 5:09 PM To: 'GPB, Ops Supt'; 'NSU, ADW Well Integrity Engineer' Cc: DOA AOGCC Prudhoe Bay Subject: PBU S-pad Issues Copying each of you because I'm guessing issues are in both areas of responsibility. Refer to attached safety valve system (SVS) test report dated 8/25/2009. Please verify exceptions have been addressed as requested by Inspector in discussions with operator rep. Summary of issues: S-100 (PTD 2000780): SSV leaks hydraulic fluid S-108 (PTD 2011000): SVS panel leaks hydraulic fluid; Excessive wellhead movement Jim Regg AOGCC 12/3/2009 Page 3 of 3 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 12/3/2009 • • Page 1 of 1 Regg, James B(DOA) ~ Z t~ l- i0O From: Jones, Jeffery B (DOA) Sent: Tuesday, September 15, 2009 12:04 PM To: Regg, James B (DOA) Subject: PBF S-108 excessive wellhead movement photo Foilow Up Flag: Follow up Flag Status: Red Attachments: PBF S-108 wellhead movement 9-14-09 JJ.zip ~ Hi Jim, I went out to BPXA's PBF S pad yesterday to witness SSV retests on S-117 & J-27 (both passed R/T). Attached is pi re of the wellhead fluted hanger that is not engaged in the conductor. There is alot of movement side to s di e and the lead operator told me "it's in DHD problem weils hands" and that they recently applied the "b ue goo" grease sealant for corrosion prevention. Prior to that there was sand packed around the surface pipe to prevent movement, which was removed for the b-ue goo treatment. The hydraulic fluid leak at the SVS control panel of well S-108 has been repaired. The hydraulic fluid leak on the SSV of well S-100 has not yet been addressed. f" Jeff -~. ~ ..(,,.~~ l~v74.~~it ~, ~ L.U6.?~~ ~, ~1~ 4 `~j'~ r~1K L ~i ( 9/18/2009 • • PBU 5-108 PTD 2011000 Photo by AOGCC Inspector Jeff Jones 9/ 14/2009 Photo shows the PBU 5-108 wellhead fluted hanger not engaged in the Conductor; this well is subject to excessive movement a'~,~~ ~' ,~~,~ ~ +,r ~^ ~ ~ ,r y ~j ~~~~ f~~,~ i ,;. 9 a ~ ~St~' ¢'~F~~~~~¢tir~ y ~ M . ~ T' Y / # , : . , ,';~11 ~1:1 ~~+.s.. . ~: ;Yy ; ~1l~~.t~.asa '~. ' ~ ' ' ' ~-' i° ~- !r ~ :_ ~" ~, a ~ : g , . . , c~'~ ~ 3`T ~ J ~ ~~ t ! ~ ~~ ~ ~~'~-~'j'~'~ r.,~Y,ll.il~ . m , , .i ~~`ei!~0~.~~/~i~,~-~^~~~_ ~~`~'.,,~-• , j ~l~~~/ ~' r 7 ~ ~ . , "~~ ~i;:tJV~/~ /~# / ,'r'~,/1s,Ll~ ~y~r ~y':, ..- „Y `~ ~~~f~~Ii~~fl.~~'~ ,. ~_:~ ~~ °'= i ~~~~/ +! '( f ~/1 h~~f~ J J~ '' '*' f~l'.~`.~~'~l~'IIIII~'i'~,~.. ~ ,. ~ ~'~.C~'JII.~J~Jlll ~T~1:~ . ~ -; ..._-__._W. ~~f~1~ilr.~~~fll~~~~~h s~ ~_ . +~;~, ~ ~~~~yi~~,~~~-~~ _:~~:~ „ ~y . . x~`~'~'~~~I~~-~~~' ~ ~-~ ,~ ~ , . '~/~'~!~'/~/~~.~~~ ~ ~ ~~~~~ ~~~~~~ :~~.~~-~~~ , - ~~ ~ , f / ~ p~ ~ ,,~PJ.~I J;~~~ ~~1 ~~~/ V~~If ~'~~ f '1~'t.•t:-~-r- .~ : --- , ~ r..~ ~.~~"~ ., . r~ ~ ~ ~~'~~~~~ ~~~'Mw ~ _~ i'~"~'~~A~~~~~`~~~tt~~~lr~4 ,., •'1~~1 111`t 1 ~ ;':'1li-~11~~~~ ~f=. ~ ~ ~~1.~.ljili i t `1't11 ~~l~p0.~~ ~~ ~ i~ii ~ ~~~~ ~~,~ \~~ v .~ ~~~~~~1'~~11~'11~:~ ~ ~`~ ° 1~~t 11i-11-1~.'~fi~'I * _ , _ , . t~i,l i i~~~:!1111Z~~ , ~~~~Ll +~~1-~l'~~. ? `~ ~~~~~ : ~ ~~~~~~a~:~«~~ ~s ' ~.~-`..~'s~.~~~P~~~ ~ ~'~ ~~~1 ''~ '~' ~"~' ~r +~~ ~ ~~ "~~y M ,~+ +'~ ~a {~~ • ~ ~ BP Exploration (Alaska) Inc. ~ ~ x~~ ~ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 P ~ ~ Enciosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~_ p ~, +{y[~~~ d;.~'SV d~ Tw~f~S'.3~~a'~ sJ U L. ~ ~`~~ ~r U le ~ Torin Roschinger BPXA, Well Integrity Coordinator U BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operetions (10-404) S-pad ~ n~e 6/25/20(19 Well Name PTD # Initial top of cement Vol. of cement um ed Final top ot cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al S-O18 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 025 NA 1.7 5/25/2009 S-03 1811900 73.25 NA 1325 NA 92.65 5/2W2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 S-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA 0.9 5/26/2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27l2009 S-09 1821040 1.5 NA 1.5 NA 9.4 5/3//2009 S-10A 1917230 0.5 NA 0.5 NA 3.4 5/31/2009 S-118 1990530 0.25 NA 025 NA 1.7 5/27/2009 S-12A 7851930 025 NA 025 NA 1.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 025 NA 025 NA 3 6/2/2009 S-17C 2020070 025 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2I2009 5-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 025 NA 1.3 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 S-23 /901270 025 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/31I2009 S-28B 2030020 0.5 NA 0.5 NA 2.s 5/31/2009 S-29AL1 7960120 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-31A 7982200 0.5 NA 0.5 NA 3.4 5/26/2009 S32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/26I2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31l2009 5-35 1921480 0 NA 0 NA .BSin 5/31/2009 5-36 1921760 0.75 NA 0.75 NA 4z5 5/27/2009 5-37 1920990 125 NA 125 NA 7~.9 5/27I2009 S-38 1921270 0.25 NA 0.25 NA 102 5/27/2009 5-41 1960240 1.5 NA 1.5 NA t7.1 5/30/2009 S-42 1960540 0 NA 0 NA 0.9 5l30/2009 5-43 1970530 0.5 NA 0.5 NA 7.7 5/28/2009 S-44 1970070 025 NA 0.25 NA 1.7 5/28/2009 S-700 2000780 2 NA 2 NA 21.3 5/29/2009 S-t07 2001150 125 NA 725 NA 71.9 5/29/2009 5-102L1 2031560 125 NA 125 NA 11.7 5/31/2009 S-703 2001680 1.5 NA 1.5 NA ~7.9 5/18/2009 S-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-106 2010120 16.25 NA 1625 NA 174.3 6/2/2009 5-107 5-108 5-709 2071130 2011000 2022450 2.25 3.5 2 NA NA NA 225 3.5 2 NA NA NA 28.9 40 21.3 5/18/2009 5/30l2009 5/30/2009 S-71o 2011290 11.75 NA 11.75 NA se.6 5/30/2009 S-17i 2050510 2 NA 2 NA 19.6 5/30/2009 S-7~2 2021350 0 NA 0 NA 0.5 5/30/2009 5-773 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-~14A 2021980 125 NA 125 NA 702 5l30l2009 S-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 &117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 5718 2032000 5 NA 5 NA 76.5 5/28/2009 5-119 2041620 1 NA 1 NA 52 5/30/2009 S-120 2031980 5.5 NA 5.5 NA 67.2 S129/2009 S-121 2060410 4.5 NA 4.5 NA 53.8 5/28/2009 S-1Y2 2050810 3 NA 3 NA 21.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 175 NA 11.9 5l26/2009 5-125 2070830 2.25 NA 2.25 NA 20.4 5/28/2009 5-726 20710970 125 NA 125 NA 15.3 6/1/2009 S-200 1972390 125 NA 125 NA 14.5 SI28/2009 S-201 2001840 0 NA 0 NA 0.85 6/19/2009 5-213A 2042130 2 NA 2 NA 13.6 5/29l2009 S-215 2021540 2 NA 2 NA 19.7 6/7/2009 5-216 2001970 4.75 NA 4.75 NA 51 S129/2009 5-217 2070950 025 NA 025 NA 1.7 6!1/2009 S-400 2070740 2 NA 2 NA 9.4 5l28/2009 S-401 2060780 16 NA 1fi NA 99.5 6/2/2009 5-504 0 NA 0 NA 0.85 5/28/2009 ~ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg '' j~~` c~ ~ 2r~ (~~ DATE: Sept 28, 2008 P. I. Supervisor ~~ FROM: Bob Noble SUBJECT: Tree Growth Petroleum Inspector PBU, WOA, S-108 BPXA PTD 201-100 ~ Seut 28, 2008: I responded to a request from Jim Regg on reported tree growth on PBU, WOA, S-108. Summary: I met with lead operator Rich Vincent. Rich told me that he was not aware that there was a problem with the well. It looked to me, as the fluted hanger was about 18" above the conductor (see attached photo). The top of the flow line was hitting on the back of the wellhouse. The flow line was 3" to 4" above the VSM (see attached photo). The operator told me that the flow lines had been leveled about a month ago. He said that either they missed this one or it has grown that much in a month. Rich Vincent told me that he would report it to the well's group. Attachments: photos (2) ~~~~~~,~~, `~~~ L, .~ ~Cl PBU S-108 Tree Growth • • PBU S-108 Tree Growth Photos by AOGCC Inspector Bob Noble September 28, 2008 Fluted surface casing hanger estimated at 18" above wellhead; surface casing is 7-5/8" Flowline (immediately outside wellhouse) estimated to be 4" above blocks on support used recently to level flowline PBU S-108 Tree Growth ~-ivo iicc ~iuwui ~u~l~uil - Yd~C 1 OI ~ Regg, James B (DOA) -_ .. ~ .~~___a w. ~~ _ _.n~__ . ~r ~ ._ _. __ ~ -.._ _..... ~ .. ~~_.__. _.~ _ ~..~~ _ .~._ __ __ _--~--... From: Regg, James B (DOA) ~<~~~ ~ (z~~~ ~ Sent: Monday, September 29,.2008 1:50 PM To: 'NSU, ADW Well Integrity Engineer; Maunder, Thomas E (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: RE: S-108 Tree growth support Inspector visited S-108 on 9/28/08. He found the fluted casing hanger approximately 18" above the wellhead and annular space filled with dirt/gravel. He also observed the flowline unsupported, approximately 4" above several temporary blocks stacked on the flowline support. The flowline was against the top of the outlet where it exits the wellhouse. Pad Opertor accompanying our inspector stated he thought the flowline was leveled last month, so the current situation indicates to us that the tree growth is an ongoing issue and must be monitored closely. Please provide TIO pressures for past year. PBU S-108 has been on near continuous production since November 2007. Not sure which "routine state testing operations" you are referencing; .From our data, it appears the AOGCC witnessed SVS tests on S-pad as follows: - 2!1212007, 8130/2007, 2/18/2008 {pad tests); only 2/18108 test has a witness of 5-018; -numerous miscellaneous SVS tests (1-2 wells per visit; none involving S-108}. I'm curious why you are addressing this {or at least advising us of this} now as opposed to last year when it was identified as an issue. Please explain. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSU, ADW Well Integrity Engineer [mailto:NSUADWWeIIIntegrityEngineer@BP.com] Sent: Tuesday, September 23, 2008 2:37 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSU, ADW Well Integrity Engineer Subject: S-108 Tree growth support Jim and Tom, Last year during routine state testing operations on S-pad, it was noted by the state's representative that S-108's tree could benefit from additonal support to mitigate instability due to tree growth. This email is to inform you that additional gravel has been added to completely fill the cellar, effecitivly increasing wellhead and tree support. Please let us know if you need additional information or require further inspection. Thank you. On behalf of Anna Dube and Andrea Hughes ,7ason ~. In, a~iCem alternate -Taylor Wellman 9/29/2008 ,~-ivo iicc ~iuw~u ~uj~j~uL~ by Alaska -Well Integrity Engineer office: 907-659-5098 cell: 713-299-2651 pager: 659-5100 x1446 harmony: 758-2418 rake 9/29/2008 Reviewed sy: Safety Valve & Well Pressures Test Report P.I.Saprv-5~- z~z~~~ Comm Pad: PBU_s InspDt: 2/18/2008 Inspected by John Crisp Interval [nspNo svsJCr08022114U934 Related Lisp: Field Name PRUDHOE BAY Operator BP EXPLORATION (ALASKA) INC Operator Rep Rich Vincent Reason 180-Day `~ rc: Ins ector __ -- _ -- _ ~ ,__ - -_ - p _ - _ - - ~. I Well Data ~ Pilots 1 SSV ~ SSSV Shutln Dt FY'ell T e j Well Pressures ~ Gas Lit Waiver Comment . 1 ----_- .. _ -- __- -- I ~ - - -- -- - YP---~--- - -------- f - -_. ---- ____ _~ --- T - - _--- ------ ------~ Well Permit Separ Set UP Test Test Test Date SI Oi1,WAG,GIN1, Inner Outer Tubing Number Number PSI PSI Trip Code Code Code GAS,CYCLE, S[ PSI PSI PSI Yes/No Yes/No - I 5-100 2000780 ~ 153 125 ~ --125 ~ P I P --- --- - ' i ----- -- -~ - -~ - 1-0[L - -- --- ___ ~ - S-103 2001680 - - --- ---~ 5-105 2001520 ~ 125 ' ~ 1~3 - -- - 153 125 ~ 120 l- - - 110 P ~ -- P ~ ~ P --- P ------ ------- --; I 1-OIL -- --..- - I-O1L ~ ~ ~ -- - --- __ ~ - -- -- S-106 i 2010120 S-108 2011000 ---- - i 153 125 ~ 153 x 125 ~ - 40 125 -- 30 P P P - -- - ---- -- ------- 1-OIL ~ l-O1L - . _ _ __--a - ~---- --- I - -- -I- _ --- - S-109 i 2022450 _ 153 125 125 -- P - ---- I P - --- rt - 1-OlL - -- - -- -~ ' -- - --_ __ - ---- - - 1136 ~ 2021430 I 15 I I 1 - I---- --- - ~ - ' ~ --- --- r -- f - - - S-115 -I 2022300 - -- ------- S-117 ~ 2030120 _.-.. -1---------._ 3 125 - -I--- 1 153 I 125 ,-- --- 153 ! 125 ! ... --- 125 ----- 120 ~-- - 135 P - - P t- ...- ( P P P -- P - -- I _ - -- - _- l-O1L- i + 1-OIL ~ -- 1-OIL - -~ - - - ~ --- --- i - ; -- S-121 2060410 ~ -- lS3 125 -- 125 T P^ ---~ P _ - -- _ ----- ----. ._...----- ~ 1-OlL --- r- ----~ I 5-122 ~ 2050810 - - ------- S-IZS I 2070830 i ~ 153 125 r---- Y_ - --- - 153 125 110 Il5 P i --- P P ~ -- P -- ~ ~ { j 1-O[L - - - 1-OIL - _-- - - - ~ -_ _t - -- - S-17C ; 2020070 -18A 2021630 I --- - - - -- -213A 2042130 153 125 I -- - 153 125 ~- -{---- -j U3 ~ 125 l!0 00 25 P P -- ~-P~ P ---- --- - ' - - I-OIL -O1L j - ---- - _ --- -- ~ - j S-44 i 1970060 _____--J_____._ ~ 153 i 125 ~ _ 100 ~~ P_ I P _--_y P ~P -.-_ __ _ I _-_-.-_.i I-OlL ~ 1-0[L _ -_~ _-_._.1 , - __ __ --~--~ S 5 j _ __; i-- -- - _ _ _ _ ___ -r --~- --- ---- _ _. ----{ I ' ---~ - --T --- -_ - -- -- -~ - - r- a -- I j I i --"--_- - -----=- --~------ -___ I Comments Performance ~'-' I Wells Components Failures Failure Rate c9~ ~f iN~ctq-1 ~tl~i.~[~- I/~~4Ji~- ~T2S5L'v~' ~ i 16 - - 32- - ---1- --- 3.12%-- - ~ i ~~~~ ~~I-.ee~,~ ;~~;~ . ------------ ----------- -----------.~ ~(~ MAR ~ ~ 2008 Monday, February 25, 2008 t S-108 (PTD# 2011000) Stabilized Wellhead with Gravel Page 1 of 1 Regg, James B (DOA) From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Thursday, September 20,20073:11 PM To: Regg, James B (DOA); Grimaldi, Louis R (DOA); Lirette, Todd Cc: NSU, ADW Well Integrity Engineer; GPB, Environ Advisor (Services); GPB, Environ Advisor East Subject: S-108 (PTD# 2011000) Stabilized Wellhead with Gravel ~1' 1/~'(DÎ Hello Jim and Lou, Well S-108 wellhead has been stabilized by adding clean gravel in the open conductor by surface casing annulus. With gravel, if there is any additional subsidence of the cellar box and conductor, the gravel is free to move with it. Please let us know if you have any questions. Thank you, ftnna (])u6e, æ f£ Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED SEP 2 B 2007 9/2712007 . STATE OF ALASKA a. ALA Oil AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS o o o 1. Operations Abandon 0 Repair Well [] Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 70.25 KB 8. Property Designation: ADL-028257 11. Present Well Condition Summary: Total Depth measured 7850 true vertical 7028.78 Effective Depth measured 7768 true vertical 6946.78 Casing Conductor Surface Intermediate Production Size 20" 91.5# H-40 7-5/8" 29.7# L-80 5-1/2" 15.5# L-80 3-1/2" 9.3# L-80 Length 80 2820 5473 2338 Perforation depth: Measured depth: 7536 - 7566 True Vertical depth: 6714.79 - 6744.79 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development ~i Stratigraphic c: Stimulate DiÆ:';,;¡iíiHtþf~}O WaiverD Time ExìerÏ¿lo¡il~¡S I;:ii"!,. Re-enter Suspended wel~fIm:f'f7~'~_0:' 5. Permit to Drill Number: n°,; 201-1000 6. API Number: 50-029-23021-00-00 9. Well Name and Number: Exploratory Service S-108 10. Field/Pool(s): PRUDHOE BAY Field/ AURORA OIL Pool feet feet Plugs (measured) Junk (measured) None 7642, 7722 feet feet MD 38 - 118 37 - 2857 36 - 5509 5497 - 7835 TVD Burst Collapse 38 - 118 1490 470 37 - 2855.29 6890 4790 36 - 4932.6 7000 4990 4924.51 - 7013.78 10160 10530 7620 - 7632 6798.79 - 6810.79 3-1/2" 9.3$ 34 - 5499 L-80 3-1/2" Baker Patch 5370 - 5405 RBDMS BFlAPR 2 8 2DD6 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development ~ 16. Well Status after proposed work: Oil ~ Gas c:¡ WAG Tubing pressure o o Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal Printed Name Sharmaine Vestal Signature~~ Title Data Mgmt Engr Phone 564-4424 Date 4/20/2006 Form 10-404 Revised 04/2004 OR1G\r~AL Submit Original Only -<Þ . . S-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/30/2006 PATCH MODIFICATION CHARGE FOR MACHINE WORK 2/27/2006 T/I/O= 540/500/100. Temp= SI. Tubing FL for E-Line (pre-patch). Tubing FL @ 168' (2 bbls). 3/11/2006 T/I/O= 510/510/90. ALP=1700 psi (SI). Temp= SI. Tbg & IA FL's (Pre E- line Patch). TP decreased 30 psi, lAP increased 10 psi and OAP decreased 10 psi since 02-27-06. Tbg FL @ 100' (.9 bbls). IA FL @ 50' (.6 bbls). 3/13/2006 SET BAKER 3.5" TUBING PATCH AT 5370' - 5405'. FLUIDS PUMPED BBLS 1 I ::::L 1 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc a STATE OF ALASKA _ AlA~ Oil AND GAS CONSERVATION COM.SION REPORT OF SUNDRY WELL OPERATIONS o o o " 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 70.25 KB 8. Property Designation: ADL-028257 11. Present Well Condition Summary: Total Depth measured 7850 true vertical 7028.78 Effective Depth measured 7768 true vertical 6946.78 Casing Conductor Surface Production Production Size 20" 91.5# H-40 7-5/8" 29.7# L-80 5-1/2" 15.5# L-80 3-1/2" 9.3# L-80 Length 80 2820 5473 2326 Perforation depth: Measured depth: 7536 - 7566 True Vertical depth: 6714.79 - 6744.79 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x RECEIVED Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P1 Stratigraphic D Stimulate 0 Waiver 0 Re-enter ÇlIþ.Ef!;[¡] ~ Time ExtJñ~~ ~ s n I 5. . 201-1000 Anchorage 6. API Number: 50-029-23021-00-00 9. Well Name and Number: Exploratory Service S-108 10. Field/Pool(s): Prudhoe Bay Field/ Aurora Oil Pool feet feet Plugs (measured) None Junk (measured) 7642, 7722 feet feet MD 38 - 118 37 - 2857 36 - 5509 5509 - 7835 TVD Burst Collapse 38 - 118 1490 470 37 - 2855.29 6890 4790 36 - 4932.6 7000 4990 4932.6 - 7013.78 10160 10530 7620 - 7632 ;.;.,¡r,t.i\ it~), ~,þ If.. i 6798.79 - 6810.~·, I'i.';" "'.....,~. 3-1/2" 9.3# L-80 34 - 5499 RBOMS 8Ft 2 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 000 15. Well Class after proposed work: Exploratory Development P1 16. Well Status after proposed work: Oil P1 Gas WAG Tubing pressure o o Service WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal ~ Printed Name Sharmaine Vestal Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 Date 2/23/2006 ORIGINAL Submit Original Only ~ e e S-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYD~TE I fV;i'" S,YMJVI~~Y ",;>"1 1/17/2006 *** WELL SHUT IN UPON ARRIVAL *** OPull tbg patch pkr & sbhps) RAN 21/2 GS, SAT DOWN @ 5375 SLM, LATCHED AND PULLED L TTP. RAN 2.80 GAUGE RING,SAT DOWN @ 5375 SLM.POOH PULLED LOWER ANCHOR ASSEMBLY @ 5377 SLM. MISSING ONE SEALS RAN 2.25 WIRE GRAB TO TD @ 7587 SLM. RECOVERED 1 SEAL, 1 STILL IN HOLE RUNNING SBHPS-- CO NT ON 1-18-06 WSR 1/18/2006 ***CONTINUED FROM WSR 1-17-06*** (PULL LOWER PACKER AND STATIC) RAN 2.20" CENTRALIZER AND PETRADA T GAUGES PERFORM STATIC PER PROGRAM. GOOD DATA ***WELL SHUT IN ON DEPARTURE. TURNED WELL OVER TO DSO*** 1/30/2006 PATCH MODIFICATION CHARGE FOR MACHINE WORK FLUIDS PUMPED BBLS 1 I ::::L 1 STATE OF ALASKA VED ALASKA 01 L AND GAS CONSERVATION COMM ISSION Jì1f C E' REPORT OF SUNDRY WELL OPERA TIO ;tT 1 5 ?OO4 1. Operations Performed: .., AbandonD RepairWellŒ PluQ PerforationsD Stimulate D 8WPiIßla" Cons. Commission Alter Casing D Pull TubingO Perforate New Pool 0 ~Ia~a I ;) WaiverD T me xtensionlþJ¡chOrage Change Approved Program D Operation Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryD 201-1000 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-23021-00-00 7. KB Elevation (ft): 9. Well Name and Number: 70.25 5-108 8. Property Designation: 10. Field/Pool(s): ADL-o028257 Prudhoe Bay Field I Aurora 011 Pool 11. Present Well Condition Summary: Total Depth measured 7850 feet true vertical 7028.8 feet Plugs (measured) None Effective Depth measured 7768 feet Junk (measured) 7642 true vertical 6946.8 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 38 - 118 38.0 - 118.0 1490 470 Production 5473 5-112" 15.5# L-80 36 - 5509 36.0 - 4932.6 7000 4990 Production 2326 3-112" 9.3# L-80 5509 - 7835 4932.6 - 7013.8 10160 10530 Surface 2820 7-5/8" 29.7# L-80 37 - 2857 37.0 - 2855.3 6890 4790 Perforation depth: Measured depth: 7536 - 7566,7620 - 7632 True vertical depth: 6714.79 - 6744.79,6798.79 - 6810.79 Tubing ( size, grade, and measured depth): 3-112" 9.3# L-80 @ 34 - 5499 2-1/16" 3.25# L-80 @ 5363 - 5398 Packers & SSSV (type & measured depth): 2-1/16" Eclipse Patch Packer @ 5363 2-1/16" Eclipse Patch Packer @ 5394 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl I Gas-Me! I Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: 454 I 6 I 7 350 287 Subsequent to operation: Well Shut-In 350 1115 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Daily Report of Well Operations. ! Oil[!] GasD WAGD GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or NIA if C.O. Exempt: Contact Garry Catron 304-182 Printed Name Garry Catron Title Production Technical Assistant Signature 11........ ('~- Phone 564-4657 Date 10/12/04 \J Form 10-404 Revised 4/2004 0 RIG I f\] þ, L MO115 ~ 5-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/31/04 SET WEATHERFORD 3-1/2" ECLIPSE PATCH OVER INTERVAL 5365' - 5398' (ELEMENT TO ELEMENT). TOP OF PATCH AT 5363'. PATCH OAL= 35.02 FT., MIN ID = 1.75". SET DOWN ON EACH PACKER AFTER SETTING. PULLED UPPER ELEMENT 1000 LBS OVER NORMAL TENSION AFTER STINGING IN TO INSURE SNAP LATCH IS SET. REF SLB - JEWELRY GRI CCL LOG DATED 7-SEP-01. NO PROBLEMS RIH OR POOH. WELL LEFT SHUT IN. PO NOTIFIED. FLUIDS PUMPED BBLS :TOT AL No Fluids Pumped 0 Page 1 TREE = 3-1/8" CrN WELLHEAD = FrY(; ACTU<\TOR- KB. 8..EV = 70' BF. 8..EV = 412' KOP= 3150' Wax Angle - 48 @ 5310' Datum M) = 7591' Datum TVD - 6700' 58 7-5/8" CSG, 29.7#, L-80, ID = 6.875" Minimum ID = 2.250" @ 7722' LATCH-IN BYPASS RECEPTACLE 15-1(2" CSG, 15.5#, L-80, ID =4.95" H I TOP OF PBR, ID =4.00" H 13-1/2"TBG, 9.3#, L-80 NSCT, .0087 bpf, ID = 2.992" H 5-1/2"X 3-1/2" XC, ID=2.968" H 5497' 5498' 5499' 5509' PERFORATION SUWMARY REF LOG: ANGLEATTOPÆRF: .50 @ 7536' !\hte: Refer to Production DB for historical perf data SIZE SPF INTERV A L OpnlSqz C\t\ TE 2-1/8" 4 7536 - 7566 0 09ÆJ7/01 2" 6 7620 - 7632 0 04/17/02 7768' 7835' 8-108 SAFETY NOTES: NO PRODUCll0N PKR IN W B.L; PKR & SEALASSYONLY. HTAMPORTCOLLAR, ID =6.875" I H 993' 2188' 3-/12" I-ES X NP, ID = 2.813" ST M) TVD DBI 3 3005 2933 8 2 3669 3558 30 1 5385 4779 47 GAS LIFT MANDRELS TYPE VLV LATCH PORT KBG2-9 [}',,1Y INT 0 KBG2-9 [}',,1Y INT 0 KBG2-9 **DMY INT 0 DATE 09/25/03 09/25/03 09/25/03 "STATION#1 = IJ\4Y HASEXTEIÐEDPACKING 5363' TOP OF B::LlPSEPATŒi, ID = 1.75" SET 08/31/04 3-1/2" ECLIPSE PATCH (33') ELEM:NTTO ELEM:NT, OAL = 35.02 5443' 3-1/2" HEB X NIP, ID = 2.813" BTM OF SEAL ASSY, ID = 3.00" 6164' 3-1/2" HEB X NIP, ID= 2.813" 6206' 7385' 7490' 3-1/2" HEB X NIP, ID = 2.813" 7669' 81m 7722' 1.75" X 9' BAILER W/GAUGES (1-3/8" FN)(09/07/01) LATŒi-IN BYPASS RECEPTACLE, ID = 2.250" DATE REV BY COMM:NTS DATE REV BY COt\itv1ENTS 06123101 CH/KAK ORIGINAL COMPLETION 04/09/03 DRSlTP lV D'MD CORRECllONS 09/10101 ONSltlh ADD ÆRF 06/10/03 MH'TLH GLV C/O 09/07/01 TMNiKK FISH 07/01/03 CAOIKK GLV C/O 04117/02 O\OIKK ADD ÆRF 09/25/03 JL..VTLH GLV C/O 03112/03 DRSlTP TVD CORREcrlON 08/31/04 M)C'TLP B::LPSEPATCH 04105103 JJ/KAK GLV C/O ALRORA UNT W8..L: S-108 ÆRMT!\h: 2011000 API !\h: 50-029-23021 SEC 25, T12N, R12E, 4511' FSL & 4497' Fe. 8P Exploration (Alaska) ..--... -"'I-~:T ()d 5//4-7 'f- STATE OF ALASKA . EI\ - ALASKA Oil AND GAS CONSERVATION COMMISSION REG IVED APPLICATION FOR SUNDRY APPROVAL MAY 1 3 2004 20 AAC 25.280 StratigraphicD Service D 9. Well Name and Number: $-108 / 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool PRESENT WELL CONDITION SUMMARY IEffective Depth MD (ft): IEffeCtiVe Depth TVD (ft): 7768 6876.5 S~ MD WD r""\ ... 1. Type of Request: Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: Suspend D RepairWell 001 Pull Tubing 0 BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 70.25 KB 8. Property Designation: ADL-028257 11. Total Depth MD (ft): 7850 Casing ITotal Depth TVD (ft): 7028.8 Length ,.-...." Ala~ka nil R, r,a~ r.nn~ r.nmmi!:!:iol1. PerforateD waiver~nCR~FW DisposalD StimulateD Time ExtensionO OtherD Re-enter Suspended Well 0 5. Permit to Drill N;!.!Jlber: 201-1000 Operation Shutdown D Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: /' Development ŒJ Exploratory D 6. API Number / 50-029-23021-00-00 Plugs (md): None Burst Junk (md): 7642 Collapse top bottom top bottom Conductor 107 20" 91.5# H-40 34 - 141 34.0 141.0 1490 470 Production 5477 5-1/2" 15.5# L-80 32 - 5509 32.0 4932.6 7000 4990 Production 2326 3-1/2" 9.3# L.80 5509 - 7835 4932.6 7013.8 10160 10530 Surface 2824 7-5/8" 29.7# L-80 33 2857 33.0 2855.3 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7536 - 7566 6714.8 6744.8 3.5" 9.3 # L-80 32 5499 7620 - 7632 6798.8 6810.8 Packers and SSSV Type: 12. Attachments: Description Summary of Proposal D Detailed Operations Program ŒJ BOP Sketch D M&2004 14. Estimated Date for Commencing Operation: 16. Verbal Approval: Commission Representative: Packers and SSSV MD (ft): 13. Well Class after proposed work: Exploratory 0 Development ŒJ ServiceD 15. Well Status after proposed work: Oil ŒJ / GasO PluggedO AbandonedO WAG 0 GINJD WINJD WDSPLn Prepared by Sharmaine~opeland 564-4424. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature t\ Young L rb. {O', Contact Jim Young Title Phone Petroleum Engineer 564-5754 5/13/04 Commission Use Only I Sundry Number: / Jd./.. /9' d- Conditions of approval: Notify Commission so that a representative may witness Mechanciallntegrity Test ~ Other: Subsequen Form 10-403 Revised 12/2003 Location Clearance 0 BY ORDER OF THE COMMISSION Date: ~þtf - , 1\\~ ORIGINAL R8OM5 Bfl SUBMIT IN DUPLICATE bp ~ ,-.., To: Doug Cismoski/John Smart, GPB Well Ops TL Date: May 3, 2004 From: Neil Decker, Production Engineer Subject: 8-108 Diaanostics & Tubina Patch AFE: AUSPDWL08-N Est. Cost: $60 M lOR: 300 BOPD Please run the 3-1/2" D&D Holefinder to isolate lower and upper most leaks prior to running a 3- .,,/' 1/2" tubing patch. This procedure includes the following steps: Steps 1 2 3 Type S E(P) O(P) Current Status: Last Test: Max Deviation: Min.ID: Last TD tag: Last Downhole Ops: Latest H2S level: Tie in Log: Procedure Pull TTP, D&D Holefinder, Drift Patch Dummy (Pre-patch) Run -33', 3-1/2" Eclipse Tbg Patch. MIT-T. ,/ SI, TxlA Communication, FTS, secured with TTP on 7/1/03 460 BOPD, 13,047 GOR, 1% WC on 6/11/03 48 degrees @ 5310' 2.25" @ 7722' Latch-in Bypass Receptacle Drift and Tag @ 7578' w/ 2.5 x 10' dummy gun on 3/21/02 Set DGL V with extended packing in station #1 on 9/25/03 Not in Database Schlumberger GR/CCL on 9/7/01 / S-108 is a FTS well with TxlA communication, SI since 5/18/03. On 9/25/03 a DGL V with extended packing was set in station #1 and an MIT - T failed as the IA tracked the tubing up 350 psi over starting pressure. A new DGLV was set and a re-MIT-T failed. The well originally failed a TIFL on 4/2/03. A re-TIFL failed on 7/22/03, the IA fluid level rose 775'. After two failed NFT-IA's (6/20/03 & 6/21/03) all gas lift valves were dummied.efHind a TTP was set on 7/1/03. An MIT-IA failed on 7/22/03 and an LLR of 1.5 bpm @ 2700 psi was .-/ established. A LDL was run on 9/8/03, indicating a leak at GLM #1 @ 5385' DD. A caliper was not run in the well due to the new condition of the tubing (completed in 6/2001). Based upon the LDL and the two subsequent failed MIT-T's it appears the source of TxlA communication is / most likely a washed out mandrel in station #1. The objective of this procedure is to run the D&D Holefinder and make sure there are no additional leaks prior to setting a tubing patch across gas lift mandrel station #1. If no other leaks are identified a tubing patch will be run to restore tubing integrity. A CMIT-TxIA to 3000 psi passed on 7/22/03. If you have any questions or comments regarding this procedure, please call Kristin Carpenter at (W)564-5850, (C)229-2772. Well File J. Young K. Carpenter cc: w/a: w/o: S Rossberg ,,-.... . Slickline & Pump. Set D & D Holefinder Plu~ and Pressure Test 1. Shoot fluid levels on IA and Tubing and order fluids to load IA and tubing for pressure test. 2. RU SL, Pump, and fluids. Load IA and tubing (this step can be done earlier) 3. Pull TTP set on 7/1/03. 4. MU D&D plug, RIH and tie in to 3.5" HES X nipple plug (ID = 2.813") at 5437' or tubing end at 5499'. Correct depth to drillers depth. If not able to tie in, zero out at tubing hanger. Tie in is critical for all tool setting depths. 5. Pull up hole and set D&D plug at 5350' DD, this is the middle of the 1 SI full joint above suspect station #1 GLM. This setting depth will identify any additional leaks above the station #1 GLM. MIT tubing to 1000 psi. Bleed off pressure on IA & Tubing. If MIT Tubing passes it confirms the upper most leak is isolated. Proceed to step #6. If MIT tubing fails at setting depth, pull up hole 50' to 5300' and repeat step #5. If MIT tubing fails again, POOH and check plug condition (i.e. elements are not damaged). If elements appear to be damaged, redress tool and repeat step #5. If elements are in good condition, contact WOE prior to proceeding to step #6. Further Diagnostics will be considered (i.e. LDL) to identify additional leaks above the station #1 GLM. 6. Drift Patch dummy to -5500'. 7. Finalize patch setting depths with WDE based on diagnostic results and proceed with patch procedure attached below. Patch Specs 3-1/2" Eclipse patch, 2 run system Length= 33', ID= 1.745", OD= 2.80", Pressure rating burst & collapse= 6000 psi Reference Loa All depths are referenced to Schlumberger GR/CCL 9n101. Schlumberger GR/CCL 9/7/01 ties in to station # 1 GLM @ 5385' DD. .., . ~ ,~ Patch Depth Patch Setting Depths are 5365' - 5398' Patch Length: 33' from element to element. The Patch will straddle the entire station #1 GLM joint, including two collars, with the lower element set at 3' below the collar in the 1 sl full joint below station #1 GLM and the upper element will be set at 3' above the collar in the 1 st full joint above the station #1 GLM. leak is at -5385' DD. Depths from Schlumberger GRlCCL 9nlOl. Item Top Bottom Joint 5337' 5368' Pup joint 5369' 5379' GLM station #1 5380' 5385' Pup joint 5386' 5394' Joint 5395' 5426' Patch 5365' 5398' Pre-Patch Slickline 1. Run dummy patch to -5500'. (will be completed after D&D holefinder, Check AWGRS) /' E-line Set Patch 2. RU EL. RIH with CCL and begin logging a continuous pass from -2400' to 5500', tying in to station #1 GLM at 5385' DD (reference Schlumberger GR/CCL 9/7/01). 3. Set patch across leak at -5385' with center of elements at 5365' and 5398'. The patch will straddle the entire station #1 GLM, both pup joints, and a portion of the 1 sl full joints above and below the GLM station, including two collars. The lower element will be set at 5398' (3' below the collar in the 1st full joint below the station #1 GLM) and the upper element will be set at 5365' (3' above the collar in the 1st full joint above the station #1 GLM). Post Patch Fullbore 1. MIT-T to 3000 psi. ~ 3 l' r-- .. TREE = 3-1/8" CrN W8.LHEAO = FMC ACTUATOR = KB. 8.EV = 70' BF. 8.EV = 41.2' KOP= 3150' Max Angle = 48 @ 5310: Datum MD = 7591' DatumTVD= 6700' SS 17-5/8" CSG, 29.7#, L-80, ID = 6.875" H Minimum ID = 2.250" @ 7722' LATCH-IN BYPASS RECEPTACLE 15-1/2" CSG, 15.5#, L-80, 10 = 4.95" 1-1 TOPOFPBR,ID=4,OO" H 13-1/2" lBG, 9.3#, L-80 NSCT, .0087 bpf, 10 = 2.992" I-i 15-1/2" X 3-1/2" XO, 10 = 2.968" H 2857' ~ 5497' 5498' 5499' 5509' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: .50 @ 7536' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 7536 - 7566 0 09/07/01 2" 6 7620 - 7632 0 04/17102 13-1/2" CSG, 9.3#, L-80, NSCT, 10 = 2.992" H DATE 06/23/01 09/10/01 09/07/01 04/17102 03/12/03 04/05/03 REV BY COMMENTS CHIKAK ORIGINAL COMPLETION CWS/tlh ADD PERF TMNlKK FISH CAO/KK ADD PERF DRSfTP TV 0 CORRECTION JJ/KAK GLV C/O 7835' 8-1 08 / =-1 I ~ r".. SAFETY NOTES: NO PRODUCTION PKR IN W8..L; PKR & SEAL ASSY ONL Y. 993' HTAM PORT COLLAR, 10 = 6.875" I 2188' H3-/12" HES X NIP, 10= 2.813" I GAS LIFT MANDRElS TYÆ VLV LATCH PORT KBG2-9 DMY INT 0 KBG2-9 DMY INT 0 KBG2-9 **DMY INT 0 L - ST MD TVD OEV 3 3005 2933 8 2 3669 3558 30 1 5385 4779 47 DATE 09/25/03 09/25/03 09/25/03 **STATION #1 = DMY HAS EXTENDED PACKING ý h 5443. !-t3-1/2" HES X NIP, 10= 2.813" 1 5509' 1-1 BTM OF SEAL ASSY, 10 = 3.00" 1 6164' 1-;3-1/2" HES X NIP, 10 = 2.813" 1 6206' HRA TAG 7385' 7490' HRA TAG! 1-;3-1/2" HES X NIP, 10 = 2.813" 1 ~ Wfl 7669' slm 1-;1.75" X 9' BAILERW/GAUGES (1-3/8" FN)(09/07/01) I I 7722' -ILATCH-INBYPASSRECEPTACLE,ID=2.250" 1 I 7768' I~ DATE 04/09/03 06/10/03 07/01/03 09/25/03 REV BY COMMENTS DRSfTP TV D/MO CORRECTIONS MHlTLH GLV C/O CAO/KK GLV C/O JLJITLH GLV C/O AURORA UNIT W8.L: S-108 ÆRMrr No: 2011000 API No: 50-029-23021 SEC 25, T12N, R12E, 4511' FSL & 4497' F8. BP Exploration (Alaska) Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2986 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10/8/2003 Field: Aurora Midnight Sun Well Job # Log Description Date BL Color CD IE-102 ¢.~(,.~ ~ ,_ \ ~,~ (~2 STATIC TEMP/PRESSURE 04102/03 1 S-103 ~--~, {~' PEP PRODUCTION PROFILE 09/08/03 1 S-106 _~(~) ~ '~ ~ GAS LIFT SURVEY 08121103 1 S-108 ~___~.(~_ [. -- ~ ~_~_ LEAK DETECTION LOG 09108103 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1:..~=.,~,.~., .;., % ~ ~.~. ,~'.,=, ~ ,~ 900 E Benson Blvd. :_~ ...~ ........... ........... Anchorage AK 99508-4254 Date Delivered: Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Beth Permit to Drill 2011000 DATA SUBMITTAL COMPLIANCE REPORT 10~3~2003 Well Name/No. PRUDHOE BAY UN AURO S-108 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23021-00-00 MD 7850 TVD 7029 Completion Date 9/7/2001 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey N__~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Name Scale Media No Start Stop CH Received .... -'""-""'-~"'""-" Directional Survey FINAL Open 7/10/2001 Comments Dierctional Survey, Paper !Rpt ~I'0~393 /-~r0359 !::'!!:.ii:~!':~-'::!!:.!?i!!::!:~.:! !::::.!i.i:?!!::i:::'-?.!:'i" !?!i?!:?i::?i?! ¢.~D Gr/Reisitivity 2/5 FINAL 112 7850 Open 10/10/2001 ...... ................ ~ ..... :.: :.....:::..::: :-::.:...-::.........:....:..:... ~S~'~!!;:::-i:::::'i.:.-~; ..................................... 1 2670 7838 Open 12/7/2001 .... !ii!?.i..i:?i:.!::~.:::~::~..~:.~*~:.*~*~...~.:*~:~:~*.~.~ii~.: Directional Survey FINAL Case 7/10/2001 ........................ IIFR Survey Gamma Ray ~GR / Porosity / Density 2/5 _.MI~GR / Resistivity./ROP 2/5 ;~P/Pres Log 5 MWD Survey (~D DGPJ Porosity / Density 2/5 LIS Verification ~ment bond log 5 FINAL 7385 7644 Case 10/3/2001 FINAL Case 7/10/2001 FINAL 5200 7700 Case 7/13/2001 FINAL 62 7801 Open 10/4/2001 FINAL 112 7850 Open 10/10/2001 FINAL 112 7850 Open 10/10/2001 FINAL ~385 7644 Case 10/3/2001 FINAL Open 7/10/2001 1 2670 7838 Open 12/7/2001 FINAL 2780 7754 Open 10/10/2001 FINAL 112 7850 Open 10/10/2001 FINAL Open 10/4/2001 FINAL 5400 7600 Case 10/26/2001 Copy 112-7850 BL, Sepia Directional Survey, Paper Copy 7385-7644 Digital Data IIFR Survey 5200-7700 BL 62-7801 Digital Data 112-7850 BL, Sepia 112-7850 BL, Sepia 7385-7644 BL, Sepia MWD Survey 2780-7754 Digital Data 112-7850 BL, Sepia LIS Verification Paper copy 5400-7600 Color Print Well Cores/Samples Information: Name Start Interval Stop Sent Sample Set Received Number Comments Permit to Drill 2011000 MD 7850 ~'- TVD ADDITIONAL INFORMATION Well Cored? Y / ~"~ Chips Received? Analysis Received? DATA SUBMITTAL COMPLIANCE REPORT 10/3/2003 Well Name/No. PRUDHOE BAY UN AURO S-108 Operator BP EXPLORATION (ALASKA) INC 7029 -~- Completion Date 9/7/2001" Completion Status 1-OIL Current Status 1-OIL Daily History Received? (~/N Formation Tops ~/N APl No. 50-029-23021-00-00 UIC N Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ SCHMOO-BE-GONE Pu, tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 768' FNL, 4497' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 3864' FNL, 3863' FEL, Sec. 26, T12N, R12E, UM At effective depth 3863' FNL, 3863' FEL, Sec. 26, T12N, R12E, UM At total depth 3864' FNL, 3864' FEL, Sec. 26, T12N, R12E, UM 5. Type of Well: Development _X Explorato~._. Stratigraphic_ Service__ (asp's 618930, 5980 71~)X~ (asp's 619526, 5982908) (asp's 619526, 5982909) (asp's 619525, 5982908) 6. Datum elevation (DF or KB feet) RKB 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-108 9. Permit number / approval number XJ 201-100 10. APl number 50-029-23021-00 11. Field / Pool Prudhoe Bay Field / Aurora Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 7850 feet Plugs (measured) 7029 feet 7643 feet Junk (measured) 6822 feet FCO to 7653' (04/17/2002). Casing Length Conductor 107' Surface 2823' Production 7804' Size Cemented 20" 260 sx AS (Approx) 298 sx Arcticset Lite 3, 7-5/8" 136 sx 'G' 204 sx LiteCrete, 302 sx 5-1/2" x 3-1/2" Class 'G' Measured Depth 141' 2857' 7835' True Vertical Depth 141' 2855' 7014' Perforation depth: measured Open Perfs 7536'- 7566', 7620'- 7632' true vertical Open Perfs 6715' - 6745', 6799' - 6811' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 NSCT @ 5499'. Top of PBR @ 5498', BTM of Seal ASSY @ 5509'. 3-1/2" HES 'X' Nipple @ 2188'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 03/03/2003 Subsequent to operation 03/27/2003 Representative Daily Average Production orlnjection Data OiI-Bbl Gas-Mcf WateFBbl 410 5996 22 359 3946 15 Casing Pressure Tubing Pressure 266 304 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations _ 16. Status of well classification as: Oil_X Gas_ Suspended_ Service 17. I hereby certify that the foregoing~s truce and correct to the best of my knowledge. DeWayne R. Schnorr 9.6/15/88 Form 10-404 Re{j [~ ORI$1NAL Date March 28, 2003 Prepared by DeWayne R. $chnorr 564-5174 SUBMIT IN DUPLICATE S-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/07/2003 HOT OIL TBG WASH' BRUSH / BROACH; HOT OIL TREATMENT; PARAFFIN / ASPHALTENE REMOVAL 03/07/2003 HOT OIL TBG WASH' BRUSH / BROACH 03/24/2003 ANN-COMM (AC-EVAL AND REPAIR)' AC-BLEED; AC-FLUID LEVEL 03/25/2003 HOT OIL TBG WASH: HOT OIL TREATMENT 03/26/2003 HOT OIL TBG WASH: SCMOO-B-GONE EVENT SUMMARY 03/07/03 <<< WELL FLOWING ON ARRIVAL >>> RUN 3 1/2 BLB W/2.31 GR BRUSH & FLUSH W/HOT DIESEL. HBR PUMPED TOTAL OF 21 BBLS WELL STARTING TO PRESSURE UP. NOTIFY PAD OP POP 03/07/03 SLICK-LINE ASSIST - BRUSH AND FLUSH. INT.-900/900/0 PUMPED 18 BBLS. HOT DSL. DOWN TBG. TBG. LOCKED UP. S-LINE PUT WELL BACK ON PROD. FI NALS- 1500/910/0. 03/24/03 T/I/O=100/1520/50 BLEED IA (FOR FREEZE PROTECT); INITIAL IA FL @ 5230' (59 BBLS). BLED IA FROM 1520 PSI TO 800 PSI IN 1.5 HOURS. SI AND THE lAP INCREASED FROM 800 PSI TO 1150 PSI IN 5 MINUTES. FINAL WHP's =100/1480/50. 03/25/03 PUMPED CRUDE DOWN IA @ 180 DEGREES TO FREE UP PARAFFIN PLUG IN TUBING. LEAD IN WITH 5 BBLS NEAT METHANOL, 225 BBLS OF CRUDE @ 180 DEGREES. SWAPPED TO TUBING, PUMPED 9 BBLS NEAT METHANOL, 41 BBLS OF CRUDE @ 180 DEGREES. SWAPPED BACK TO IA, PUMPED 10 BBLS OF NEAT METHANOL, 130 BBLS OF CRUDE @ 180 DEGREES - WHILE GAS LIFT WAS ON. FREEZE PROTECT FLOWLINE WITH 10 BBLS NEAT METHANOL. LEAVE WELL SHUT-IN. 03/26/03 PUMPED SBG TREATMENT. 5 BBLS NEAT METHANOL SPEAR, 50 BBLS SBG/FRESH WATER (MIXED @ 16%), 5 BBLS NEAT METHANOL TO FREEZE PROTECT. FLUIDS PUMPED BBLS 0 PRESSURE TEST LUBRICATOR W/2 BBL OF DIESEL, (0'TEST) 34 NEAT METHANOL 18 DIESEL 396 CRUDE 42 FRESH WATER 8 SCHMOO-BE-GONE 498 TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: FCO ! ADD PERFS Operation shutdown_ Stimulate _ Pull tubing _ Alter casing _ 2. Name of Operator 5. Type of Well: Plu ' . ,',,~ ,, ,-,. 4~erforate _X ..... Repair well ,~ ~'~u .O~ X FCO - ~,: ~C:; ;~Jr~-~ 6. Datum elevation (DF orKB feet) BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface 768' FNL, 4497' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 3864' FNL, 3863' FEL, Sec. 26, T12N, R12E, UM At effective depth 3863' FNL, 3863' FEL, Sec. 26, T12N, R12E, UM At total depth 3864' FNL, 3864' FEL, Sec. 26, T12N, R12E, UM Development __X Exploratow__ Stratigraphic_ Service.__ (asp's 618930, 5980715) (asp°s 619526, 5982908) (asp's 619526, 5982909) (asp's 619525, 5982908) RKB 70 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-108 9. Permit number / approval number 201-100 / 302-086 10. APl number 50-029-23021-00 11. Field / Pool Prudhoe Bay Field/Aurora Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 107' 2823' 7804' Production 7850 feet Plugs (measured) 7029 feet 7643 feet Junk (measured) 6822 feet Size Cemented 20" 260 sx AS (Approx) 298 sx Arcticset Lite 3, 7-5/8" 136 sx 'G' 204 sx LiteCrete, 302 sx 5-1/2" x 3-1/2" Class 'G' FCO to 7653' (04/17/2002). Measured Depth 141' 2857' 7835' True Vertical Depth 141' 2855' 7014' Perforation depth: measured Open Perfs 7536'- 7566', 7620'- 7632' true vertical Open Perfs 6715' - 6745', 6799' - 6811' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 NSCT @ 5499'. Top of PBR @ 5498', BTM of Seal ASSY @ 5509'. 3-1/2" HES 'X' Nipple @ 2188'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 04/02/2002 Subsequent to operation 04/21/2002 OiI-Bbl 449 Representative Daily Averaqe Production or Injection Data Gas-Mcf Water-Bbl 3371 0 627 7517 6 Casing Pressure Tubing Pressure 796 341 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil _X Gas _ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,,~~~~J~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date April 26, 2002 Prepared by DeWayne R. Schnorr 564-51 SUBMIT IN DUPLICATE'~.~ 03/21/2002 03/29/2002 04/16/2002 04/17/2002 03/21/02 03/29/02 04/16/02 04/17/O2 S-108 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERFORATING: DRIFT/TAG PERFORATING: HOT OIL TREATMENT PERFORATING: FILL CLEAN OUT; JEWELRY LOG--DEPTH CONTROL; PERFORATING PERFORATING: FILL CLEAN OUT; ]EWELRY LOG--DEPTH CONTROL; PERFORATING EVENT SUMMARY DRIFT AND TAG W/2.50" X 10' DUMMY GUN @ 7578' SLM, SAMPLE OF FRAC SAND. RDMO. <<<NOTIFY DSO TO POP>>> HOT OIL TBG WITH 60 BBLS DIESEL. FCO/ADPERF- MIRU DOCT #5. RIH W/2.25" JSN TO DRY TAG. TAG FILL @ 7597' CTMD. FCC TO 7653' CTMD. POOH, RU SWS MEM GR/CCL. RIH, LOG INTERVAL 6900' - 7653', TIE INTO SWS GR/CCL, 09/07/2001. MU SWS TCP 2" PJ2006 - HMX - 6 SPF - 60 DEG PHASING. RIH TO TAG AT 7645' CORRECTED CTD, PUH TO SHOOT 7620' - 7632', POOH. WELL FP TO 2500' WITH 60/40 METHANOL, FLOWLINE FP WITH 60/40 METHANOL. <<<PAD OPERATOR TO POP>>> FLUIDS PUMPED BBLS 1 PRESSURE TEST LUBRICATOR W/2 BBL OF DIESEL, (1 TEST) 41 60/40 METHANOL WAER 60 DIESEL 234 2% KCL SLICK WATER 36 1.5# BIO 372 TOTAL ADD PERFS 04/17/2OO2 THE FOLLOWING INTERVAL WAS PERFORATED WITH THE 2" PJ 2006, 6 SPF, 60 DEGREE PHASED GUN, RANDOM ORIENTATION. 7620'-7632' Page I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Alter casing _ Add Perfs Suspend_ Operational shutdown _ Re-enter suspended well _ Repair well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Vadance _ Perforate _X Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 4. Location of well at surface ~' v/' v/ 768' FNL, 4497' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 3864' FNL, 3863' FEL, SEC 26, T12N, R12E, UM At effective depth 3863' FNL, 3863' FEL, Sec. 26, T12N, R12E, UM At total depth 3864' FNL, 3864' FEL, Sec 26 T12N, R12E, UM 5. Type of Well: Development Exploratory __ Stratigraphic _ Service__ (asp's 618930, 5980715) (asp's 619526, 5982908) (asp's 619526, 5982909) (asp's 619525, 5982908) 6. Datum elevation (DF or KB feet) RKB 70.0 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-108 9. Permit numbe~r/~pproval number 201-100~ 10. APl number 50-029-23021-00 11. Field / Pool Prudhoe Bay Field / Aurora Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 107' Surface 2823' Production 7804' 7805 feet Plugs (measured) 7029 feet 7643 feet Junk (measured) 6822 feet Size Cemented 20" 260 sx AS (approx) 298 sx Arctic Lite 3, 136 7-5/8" sx 'G' 204 sx LiteCrete, 302 sx 5-1/2" x 3-1/2" Class 'G' Measured Depth 141' 2857' 7835' True vertical Depth 141' 2855' 7014' Perforation depth: measured Open Perf 7536'- 7566' true vertical Open Perf 6715' - 6745' rubing (size, grade, and measured depth 3-1/2" 9.3#, L-80 NSCT @ 5499'. RECEIVED Alaska0il&GasCo~.~ A~ Packers & SSSV (type & measured depth) Top of PBR @ 5498', BTM of Seal ASSY @ 5509'. 3-1/2" HES 'X' Nipple @ 2188'. 13. Attachments Description summary of proposal __X Detailed operations program _ BOP sketch__ 15. Status of well classification as: 14. Estimated date for commencing operation 11 03/11/2002 16. If proposal was verbally approved Name of approver Date approved Oil _X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~"~ ~~~ Title: Aurora Surveillance Engineer Jim Young FOR COMMISSION USE ONLY Questions? Call Jim Young @ 564-5754. Date March 04, 2002 Prepared by DeWayne R. Schnorr 564-5174 Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test _ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~.~k~t Original Signed By Approved by order of the Commission ~m_m.,v .ri. _~.h.$!~ commissioner Form 10-403 Rev 06/15/88 · J Approval n~,~,~)~...~_ ~)~.~,~ Date SUBMIT IN TRIPLICATE bp f BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 04, 2002 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for S-108 to Add Perfs (Kuparuk A5 Sand) BP Exploration Alaska, Inc. proposes overbalanced perforating the Kuparuk A5 Sand in Aurora development well S-108. Over balanced should be maintained due to open fraced peris from 7540' - 7570'. The procedure includes the following major steps: Category IOR Step Description C 300 1 E 250 2 Jet hydrates/drift 2.2" to PBTD, attempt to fish gauge, pre-APERFS Perforate A-Sand (deep penetrators) Last Production: FBHP: Max. Deviation: Perfs: Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: Reference Log: Tie in Log: BHP: 01-27-02,530 BOPD, 0% WC, 2MMscfd ALG 300 psi 48° @ 5310' md Deviation at perfs: 0.30° Present Perfs 7536'- 7566' MD Three .... 2.813" at X nipples, see schematic 7360' MD (10/19/2001) Drift/Tag, 10/19/2001 < 10 ppm Sperry MWD GR Schlumberger GR/CCL (09/07/2001). 3400 psia @ 7600' MD @ 6779' TVDSS 1. Obtain Well test no less than 2-days prior to, and ASAP after perforating. 2. Shut-in well before perforating A5 sand. E-Line , Perforate well, Zone A5 from 7620'- 7632' MD, (6799'-6811' TVD). Perforate using Schlumberger 2-1/2" HSD P J, 2506 UP, 4SPF, 180 degree phasing, random orientation. Tie-into SWS GR/CCL (18/Jun/2001). 4. POOH to safety and gas lift to 2.0MMcfd, for post-perf test. 5. Obtain Well....st ASAP after perforating. Please call (Jim Young 564-5754, hm: 248-0133, cell: 440-8007) if there are any questions. Sincerely, Jim Young Greater Prudhoe Bay Aurora Development Engineer ROW PERFORATING PROCEDURE CC or AFC: F58AUR Detail Code: Var 4.0 06/04/01 Well: S-108 APl #: 50-029-23021-00 Date: ....................... ~./..0.,2 ........................ Prod Engr,,.J.!.,m,,,,.Y,,.o.,,u.,n.,,g,, .................... Office Ph: ........................... .,5,,.6,..4.,-.,.5.,7_,5,,.4' ........................... II H2S Level: Home Ph: , 2. . .4, . .8.-. .0. ~, .3, .3._ ____ ..................................................... . Cell/Pager: ........................... ..4,.,4..0.-..8...0..0...7' ........................... 9335-070-770 < lOppm Description: ...D...R..L...G..../....C....O...M...P...L...E..T..!..O...N../....P..E..R..[ ................................................................................................................................................................................................................................................................. WBL Entries IOR Type Work Desciption 300 C I Jet hydrates/drift 2.2" to PBTD, attempt to fish gauge, pre-APERF. 250 E Perforate A-sand (deep penetrators) Well Obiectives and Loq(iin.(I Notes..; CAUTION: Restriction in liner at ~7350'. Make ONE attempt to fish BHP gauge w/CT prior to RDMO. LEAVE FILTERED 2%KCL ACROSS PERFS POST FCO Flow well & test no more than 2-days prior to and post-perforating. Attachment: Reference Log Tie in Log Log: MWD GR GR/CCL Date: 6/18/2001 9/7/2001 Company: ,,,S,p,,,e,,r,,,ry, ...................... ,,S,,.,C,,,,H,,,L,,: ........ Depths (from-to) Depths (from-to) ......... ,.7,,,,.,6,,,2,,0,'' ........ - ~,:~3,~', ....... .............. ,~,:6,,,2,,0,,', ....... - 7,632' . . . . - . Reference log with proposed perfs annotated, 5"/100' scale Add 0 to the tie-in log to be on depth with the reference log. Feet SPF Orient. 12 4 Requested Gun Size: na No At what Depth? ........... .2.,:..5.11 ............ Charge: ............. .p,j..2...5...O...6., ............ Desired Penetration: >20" Is Drawdown Necessary/Desired/Unnecessary During Perforating Describe below how to achieve drawdown (check w~ Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardllne) Tie in to Jewelry @ 7385 MD Tie in using: Minimum ID: 2.813 in Min ID Type: Tail Depth: .......... ,5...5..0,..9. .......... ff MD Casing Size: Est Res. Pres. @ Last Tag: ........ ..N,,~..N,..E' ........ ff MD on ................................ feet Well: S-108 Date: General Comments: Phasing Zone Ad/Re/Iperf N/A Entry Hole Diem: 0.3 RA TAG MULTIPLE X-NIPPLES @ 'MD 3.5 in ....... ,,7,:,,6,,,0,,.0,, ...... MD is ................ ,,3,,4,,,0.,,0.. psi Perforation Summary ISummary Diet IF°w": APl #: 50-029-23021-00 Prod Engr: IIAnch Prod Engr ........................................................................................................................................ IIP.D. Center PBTD Depths Zone Aperf/Reperf Balance O/B/U O/B/U Referenced to BHCS Gun Dia. Orient. SPF Phasing O/B/U O/B/U O/B/U ,,, TREE = 3-1/8" ClVV WELLHEAD= FMC S 108 SAFETY NOTES: NO PRODUCTION PKR IN WELL; PKR & ACTUATOR= ~ SEAL ASSY ONLY. KB. B_EV = 70' BF. ELEV 41.2' KOP = 3150' Max Angle = 48 @ 5310' ' ' ' Datum MD = I , 2188' 3-/lZ' t-ES X ~P, D = 2.813" Datum TVD = 8800' SS 17-5/8" CSG, 29.7#, L-80, ID = 6.875" H 2857' GAS LIFT MANDRB_S ST MD TVD DEV TYPE VLV LATCH SIZE DATE 3 3005 2933 8 KBG2-9 RP BTM 06/23/01 ~,'~ 7722' II 2 3669 3558 30 KBG2-9 DV BTM 06/23/01 Minimum ID 2~.50" 1 5385 4779 47 KBG2-9 DV BTM 06/23/01 LATCH-IN BYPASS RECEPTACLE I -' ITOPO~R,'D=4.00"H 54.8' ~ ~_ [/~,~ ~**' 1--13-1/2"*~G, 9.3#,L-80NSCr,.00~7~p,,,D=2.992" 15-1~"X3-112"XO,'D=2.968"I--I 550.' I~ i55°*' I-'t~mO~SEALASSY''D=3'00" I PERFORATION SUMM~ FlY REF LOG: ANGLEATTOP PERF: I i I 6164' I~ 3-1/2" HES X NIP, ID = 2.813" I I Note: Refer to R'oduc~on DB for historical perf data I SIZE SFF INTERVAL Opn/Sqz DATE · i i I , 6206' TAG i 2-1/8" 4 7536-7566' O 09/07/01 ' I : _- I I I I ?~o' I-t~-~".~x~,..,~=~.~"l i 7722' HLATCH-INBYPASS RECEPTACLE, ID=2.250" , 13'112"CSG, 9.3#,L-aO, NSCT, ID=2.992"I~ 7885' ~ DATE REV BY COMMENTS DATE REV BY COIVIVIENTS PRUDHOEBAY UNIT 06/23/01 CH/KAK ORIGINAL COIVPLETION WELL: S-108 09/10/01 CWS/th ADDPERF PERIVIT No: 201-100 09/07/01 TMN/KK FISH APl No: 50-029-23021 4511' FSL & 4497' FEL, Sec. 25, T12N, R12E BP Exploration (Alaska) SIZE SFF INTERVAL Opn/Sqz DATE 2-1/8" 4 7536- 7566' O 09/07/01 12/6/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie NO. 1667 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job # Log Description Date Color Sepia BL CD S-108 21394 CMPJBHC/GR 06/19/01 1 S-108 21394 CMR 06/19/01 1 1 S-108 21394 MD BHC 06/19/01 1 1 S-108 21394 TVD BHC 06/19/01 1 1 S-108 21394 BOREHOLE PROFILE 06/19/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Bivd, Anchorage AK 99508-4254 RECEIVED Date Delivered: DEC 0 ,,' 2001 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 AI-rN: Sherrie Received ~ LJ~G~ 10/16/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1535 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Well Job # Log Description Date Color Sepia BL CD S-108 ~O/-/L)~ 21405 SCMT ¢/' 09108101 2 L-117 ,~'~O)- l/r~'? 21407 CMR v/'' 09/2S/01 2 L-144 21374 BHC,CMR v/' 08/13/01 L-114 ~,O)-i,~(.z2 21374 BHC ¢' 08113/01 1 1 L-114 21374 CMR .~/" 08/13/01 1 1 L-107 24420 PP,D/N, IMPULSE (PDC) v" 08/27/01 L-407 C~ OJ- / ~ / 21420 MD VISION RES ¢' 08/27/01 1 t L-107 21420 TVDVISION RES v/' 08/27/01 1 1 L-107 21420 MD VISION D/N-QUAD v" 08/27/01 L-107 21420 TVD VISION D/N-QUAD .. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED OCT 2 2001 AI~ 0i! ~ C_-,_-,_-,_-,_-,_-,~__ C_-C~!..~. Anchorage Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Receive~ ~ WELL LOG TRANSMITTAL To: State of Alaska October 4, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs' S-108 AURORA, AK-MM-11098 S-108 AURORA: Digital Log Images: 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED OCT 10 2001 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs · S- 108 AURORA, S-108 AURORA: 2"x 5" MD Resistivity & Gamma Ray Logs · 50-029-23021-00 2"x 5" TVD Resistivity & Gamma Ray Logs · 50-029-23021-00 2" x 5" MD Neutron & Density Logs: 50-029-23021-00 2"x 5" TVD Neutron & Density Logs: 50-029-23021-00 October 4, 2001 AK-MM- 11098 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled SePia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 R E]'VED OCT 10 2.001 Signe ' ' Anchorage i"' STATE OF ALASKA {~' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service [] TSUSP 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-100 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-23021-00 4. Location of well at surface 9. Unit or Lease Name 4511' NSL, 4497' WEL, SEC. 35, T12N, R12E, UM .- - : ~ Prudhoe Bay Unit At top of productive interval 1415' NSL, 3863' WEL, SEC. 26, T12N, R12E, UM I~..'"~. ~/'~,..~ At total depth .f~ ~ 10. Well Number ....... S-108 1406' NSL, 3864' WEL, SEC. 26, T12N, R12E, UM S1~n_~ati0 i 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease, De n nd Serial No. 11. Field and Pool Prudhoe Bay Field / Aurora Pool KBE = 70.25' ADL 028257 (Undefined) 12. Date Spudded6/11/2001 113' Date T'D' Reached 114' Date c°mp'' susp'' °r Aband'6/18,2001 9,7,2001 115' Water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+'I'VD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 7850 7029 FTI 7643 6822 FTI [] Yes [] NoI (Nipple) 2183' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GYRO, PWD, LWD, CMR, Sonic/Caliper 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 107' 30" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 34' 2857' 9-7/8" 298 sx Arcticset Lite 3~ 136 sx 'G' 5-1/2,, x 3-1/2" 15.5# / 9.2# L-S0 31' 7835' 6'3/4" 204 SX LiteCrete~ 302 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/8" Gun Diameter, 4 spf 3-1/2", 9.3#, L-80 5504' N/A MD TVD MD TVD , 7536' - 7566' 6715'- 6745' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7536' - 7566' Fractured with 122861#'s of 16/20 Carbolite Placed 9971 l#'s of Carbolite behind pipe. Freeze Protected with 80 bbls Diesel and 20 bbls of MECH. , 27. PRODUCTION TEST , Date First Production Method of Operation (Flowing, gas lift, etc.) September 26, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 9/25/2001 22 TEST PERIOD 1873 704 398 176I 376.26 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED OCT 0 4 2001 ~. ~, , ~-~. ~ ~ ~ ~ ~ Alaska 0il & Gas Cons. Commission', Form 10-407 Rev. 07-01-80 Anch°rag~ubmit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top of Ugnu 3611' 3578' Schrader Bluff M 5272' 4772' Schrader Bluff N 5590' 4989' Schrader Bluff O 5750' 5102' Base of Schrader Bluff/Top of 6167' 5410' Colville Mudstone CMl 7272' 6451' THRZ 7401' 6580' TKLB 7526' 6705' Top of Kuparuk C 7534' 6713' LCU / Top of Kuparuk B 7588' 6767' Top of Kuparuk A 7613' 6792' Base of Kuparuk/Top of 7671' 6850' RECEIVED Miluveach OCT 0 4 2001 Alaska Oi~ & Gas Cons. Commissio~ Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Post Rig Summary and Leak off Test Summary. -- , , , , , , ,, 32. I hereby certifY that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble~~_~ ~ Title TechnicalAssistant Date S- 108 201 - 100 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 '":'." :'!:i'i::""'".' ": '.. ... : "'...'".:...'. ~".' ." " ': -'.: · .' .'. :. · . ..... .., :... . .,,. ...... ::::: :::: ~:: ..... "'"" ....... ' Off Test.. summary. Legal Name: S-108 Common Name: S-108 Test Date .:". ::.'Test:'TyPe:. TeSt Depth (TMD)' Test Depth (TVD) AMW :: :SU~CePressure Leak Off Pressure (BHP) EMW 6/15/2001 LOT 2,857.0 (ft) 2,855.0 (fi) 9.60 (ppg) 950 (psi) 2,374 (psi) 16.01 (ppg) Printed: 6/26/2001 3:12:46 PM BP EXPLORATION Page I of 4 Operations Summary Report Legal Well Name: S-108 Common Well Name: S-108 Spud Date: 6/10/2001 Event Name: DRILL+COMPLETE Start: 6/10/2001 End: 6/23/2001 Contractor Name: DOYON Rig Release: 6/23/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/10/2001 07:00 - 11:00 4.00 RIGU P PRE PJSM. Cantilever derrick into transport position. Move off of S - 106. Finish prep work around S - 108. 11:00 - 13:00 2.00 RIGU P PRE Spot rig mats. Hold Pre spud & weekly safety meeting w/both crews & rig team. Focus on Objectives met / Objectives Expected. 13:00 - 17:00 4.00 RIGU P PRE Move in rig & spot same on S - 108. Shim rig, cantilever derrick into position and connect lines. Spot cuttings tank. ACCEPT rig at 1700 hrs June 10, 2001 17:00 - 00:00 7.00 RIGU P PRE Offload & condition spud mud /water. Rig in support equipment. Load pipe shed w/HWDP & BHA components. NU diverter, riser & flow line. MU & stand back HWDP & DC's 6/11/2001 00:00 - 02:00 2.00 RIGU P PRE Change out saver sub & bell guide. Condition spud mud. 02:00 - 04:30 2.50 DRILL P SURF PU BHA, orient MM. 04:30 - 06:00 1.50 DRILL P SURF Load MWD, MU Bit. 06:00 - 09:00 3.00 DRILL P SURF Break circulation, check for leaks. Surface test MM / MWD. Clean out to 107 ft. Circulate & condition mud. Mobilize slickline unit for Gyro. 09:00 - 21:00 12.00 DRILL P SURF Directional drill 9 7~8" surface hole 107 to 792 ft. Utilize Gyro for kick off @ 158 ft and 249 ft. 21:00 - 22:00 1.00 DRILL P SURF Circ Btms up. POH 1 std. Change out saver sub to 4" HT 38. RIH 1 std. 22:00 - 00:00 2.00 DRILL P SURF Directional drill 9 7/8" surface hole 792 to 888 ft. 6/12/2001 00:00 - 22:30 22.50 DRILL P SURF Drilling from 888 to 2875. Drilling parameters: GPM= 400 to 550, WOB= 15-20, Torque on bottom= 5,000, RPM-60 to 80. ART= 17.25 AST=1.91 22:30 - 23:00 0.50 DRILL P SURF Circulate bottoms up. Observe well. 23:00 - 00:00 1.00 DRILL P SURF POH slowly to 2300. Minimal overpulls of 10-15k. No swabbing. 6/13/2001 00:00 - 04:30 4.50 DRILL P SURF POH working intermittent tight hole from 2,300 to 530. Back ream from 530 to 350, continue trip out to Jars. 104:30 - 10:00 5.50 DRILL P SURF RIH washing and reaming as needed. Ream intervals = 520 to 1,075, @ 1,833 to 2,036. 10:00 - 12:00 2.00 DRILL P SURF Circulate sweep surface to surface until shakers are clean. Pea gravel, sand and large pieces of wood coming over shakers. 12:00 - 17:30 5.50 DRILL P SURF Drop 2" rabbit and POH. Back ream from 2052 to 1475 and 996 to 800. 17:30 - 18:00 0.50 DRILL P SURF Clean, gauge and grade bit. No problems with BHA. 18:00 - 20:30 2.50 DRILL P SURF RIH working intermittent tight hole, reaming as needed. Wash and ream last stand to bottom as precautionary measures. No fill on bottom. 20:30 - 21:30 1.00 DRILL P SURF Circulate sweep surface to surface x2. Pea gravel, sand and drift wood coming across shakers.( No large amount) 21:30 - 00:00 2.50 DRILL P SURF Observe well. P.O.H. to run casing. No adverse hole conditions on trip out of hole. Hole took proper fill. 6/14/2001 00:00 - 02:30 2.50 DRILL P SURF Lay down remainder of HWDP and BHA. Break and grade bit. Down load MWD. 02:30 - 05:30 3.00 CASE P SURF Change bales to longer set for running casing. Swap saver subs and R/U "Franks Fillup tool". Make dummy run with casing hanger to landing shoulder. R/U casing equipment and rig floor. 05:30 - 06:30 1.00 CASE P SURF P/U shoe track and check floats. 06:30 - 10:00 3.50 CASE P SURF RIH with 68 Jts. of 7 5/8 L-80 29.7 # casing to a setting depth of 2,857. Set hanger on landing ring. 10:00 - 11:00 1.00 CASE P SURF Circulate and condition mud for cement job. Printed: 6/26/2001 3:12:56 PM BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: S-108 Common Well Name: S-108 Spud Date: 6/10/2001 Event Name: DRILL+COMPLETE Start: 6/10/2001 End: 6/23/2001 Contractor Name: DOYON Rig Release: 6/23/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/14/2001 11:00 - 13:30 2.50 CEMT P SURF Cement 7 5/8 casing as follows: Pump 10 bbls. CW 100, and test lines to 3500. Pump remaining 30 bbls. CW 100, 75 bbls. spacer and drop top plug. Pump 239 bbls. of lead @ 10.7 ppg., 29 bbls. tail @ 15.8. and drop bottom plug. Displace cement with rig pumps and bump at calculated displacement. Hold pressure for 5 minutes and bleed off. Check floats. Dye and leading edge of cement seen at surface. 13:30 - 16:30 3.00 CEMT P SURF Flush drilling nipple and hydril of cement. PJD cement head and lay down landing Joint. Clear floor of all vendors excess equipment and ready floor for next operation. 16:30 - 18:30 2.00 CEMT P SURF Nipple down 20" bag and diverter system. Install split speed head and test metal to metal seal. 18:30 - 00:00 5.50 BOPSUF P SURF Nipple up BOP stack. Install drilling nipple and mouse hole. Change upper well control valve and saver sub on top drive. 6/15/2001 00:00 - 04:30 4.50 BOPSUF.P SURF Test BOP per BP policy, 250 Iow .... 3,500 high. Witness of test waived by AOGCC rep. "John Spalding" 04:30 - 05:00 0.50 BOPSUF.P SURF Pull test plug and install wear bushing. 05:00 - 08:30 3.50 DRILL P INT1 P/U 6 3/4 PDC bit with 1.22 degree 6 stage motor, MWD and PWD. Orient and install source. 08:30 - 11:30 3.00 DRILL P INT1 P/U d.p. 1x1 to 867. Shallow test BHA. 11:30 - 12:00 0.50 DRILL P INT1 RIH to 2,686 washing last stand to bottom. 12:00 - 13:00 1.00 DRILL P INT1 Cut drilling line. Circulate bottoms up while rig work is completed. i 13:00 - 14:00 1.00 DRILL P INT1 Test casing to 3500 for 30 minutes on chart. Graph results for future leak-off test. 14:00 - 16:00 2.00 DRILL P INT1 Drill shoe track and clean out to old TD. Drill 20 feet of new hold for leak-off test. i 16:00 - 16:30 0.50 DRILL P INT1 Perform leak-off test to 950 psi @ 16ppg. 116:30 - 17:30 1.00 DRILL P INT1 Displace mud system over to new 10.6 LSND system. Perform slow pump rate after completion of mud swap. Get baseline E.C.D. information. = 17:30 - 00:00 6.50 DRILL P INT1 Drill 6 3/4 hole from 2,897 to 3,404. Pump weighted sweeps to assist in cuttings removal. 6/16/2001 00:00 - 13:30 13.50 DRILL P INT1 Drilling 6 3/4 hole from 3,396 to 4,508. Pump weighted, barafibre sweeps every 500 ft. or as hole dictates. Drilling parameters: GPM=295 @ 2800 RPM=60 WOB=4 to 6. 13:30 - 15:30 2.00 DRILL P INT1 Short trip to shoe @ 2,857. Intermittant 20k overpulls. No fill on bottom. 15:30 - 00:00 8.50 DRILL P INT1 Drilling 6 3/4 hole form 4,508 to 5,181. Hole in good shape. No problems or over pull on connections. 6/17/2001 00:00 - 09:30 9.50 DRILL P INT1 Drilling 6 3/4 hole from 5,181 to 5,946. Pump weighted barafibre sweeps for cuttings removal. No overpull or fill on connections. 09:30 - 11:30 2.00 DRILL P INT1 Short trip to 4,490 with 20K overpull from 5,465 to 5,390. Wipe clean. No adverse hole conditions on trip back in hole. 11:30 - 12:00 0.50 DRILL P INT1 Circulate and reduce ECD's prior to drilling. 12:00 - 00:00 12.00 DRILL P INT1 Drill from 5,947 to 6,805. Drilling parameters: RPM=60 WOB=5-8 GPM=295 @ 2,900 ART= 10.5 AST= 5. 6/18/2001 00:00 - 16:00 16.00 DRILL P INT1 Drill from 6,805 to 7,850. Drilling parameters: RPM=60 WOB=5-8 GPM=287 @ 3,100 Printed: 6/26/2001 3:12:56 PM BP EXPLORATION Page 3 of 4 Operations Summa Report Legal Well Name: 8-108 Common Well Name: S-108 Spud Date: 6/10/2001 Event Name: DRILL+COMPLETE Start: 6/10/2001 End: 6/23/2001 Contractor Name: DOYON Rig Release: 6/23/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/18/2001 16:00 - 18:30 2.50 DRILL P INT1 Short trip to 5,860 with not adverse hole conditions or fill. 18:30 - 20:00 1.50 DRILL P INT1 Circulate sweep until shakers are clean. Minimal cutting seen at shakers. Pump dry job. Observe well. 20:00 - 22:30 2.50 DRILL P INT1 POH to run logs. Hole in very good shape. No overpull or swabbing conditions. Pull to 2,390. 22:30 - 23:00 0.50 DRILL P INT1 H2S drill. Perform head count. Sniff for H2S with scott air pack donned. Return to work stations. 23:00 - 00:00 1.00 DRILL P INT1 POH for logging run. At app. 850 at report time. 6/19/2001 00:00 - 01:00 1.00 DRILL P INT1 POH to BHA with no adverse hole conditions. 01:00 - 03:30 2.50 DRILL P INT1 PJSM Lay down BHA, including source. Adjust motor and break stabilizer. 03:30 - 04:30 1.00 DRILL P INT1 PJSM PJU logging tools 04:30 - 08:30 4.00 DRILL P INT1 RIH w/logging tools. Unable to go below 4380. POH & RD Schlumberger to run wiper trip. 08:30 - 09:00 0.50 DRILL P INT1 MU wiper BHA 09:00 - 10:30 1.50 DRILL P INT1 RIH to 2770. Break circ. 10:30 - 11:30 1.00 DRILL P INT1 ~Cut drilling line while CBU. 11:30 - 14:30 3.00 DRILL P INT1 i RIH to 7850. No indication of tight hole. 14:30 - 17:30 3.00 DRILL P INT1 iCirc. & cond. hole. Pump sweep. 17:30 - 21:00 3.50 DRILL P INT1 Flow check. POOH. 21:00 - 21:30 0.50 DRILL P INT1 Stand back BHA 21:30 - 22:30 1.00 DRILL P INT1 I PJSM. RU Wireline for elogs 22:30 - 00:00 1.50 DRILL P INT1 I RIH w/logging tools. Work past tight spot at 4990'. i6/20/2001 00:00 - 09:30 9.50 DRILL P INT1 , Logging from 7842' (WLM) to csg shoe @ 2857'. Ran CMR :from TD across Kuparuk and Schrader Bluff. Ran BHC Sonic/Caliper from TD to csg shoe at 2857' 09:30 - 13:30 4.00 DRILL P INT1 RIH to TD. Break circ. @ 2770' and 4850'. 13:30 - 16:30 3.00 DRILL P INT1 Circ. and cond. mud. Pump weighted barofibre sweep. CBU. Spot casing running pill in open hole. Rotate and reciprocate while circ. 16:30 - 22:30 6.00 DRILL P INT1 Flow check. POH and LDDP. 22:30 - 23:30 1.00 DRILL P INT1 Lay down BHA. 23:30 - 00:00 0.50 DRILL P INT1 Pull wear bushing. 6/21/2001 00:00 - 00:30 0.50 DRILL P INT1 Pull wear bushing. RU 5 1/2" mandrel hanger and make dummy run. 00:30 - 01:00 0.50 DRILL P INT1 Rig up to run 3 1/2" X 5 1/2" tapered production casing string. 01:00 - 01:30 0.50 DRILL P INT1 PJSM. Pick up and run 3 1/2" shoe joint, 2 joints, and float collar. Bakerlok per plan. 01:30 - 02:00 0.50 DRILL P INT1 Run 3 1/2" 9.3 #, NSCT, L-80 casing. 02:00 - 03:00 1.00 DRILL N RREP INT1 Change out leaking air boot on drilling nipple riser. 03:00 - 07:30 4.50 DRILL P INT1 Run total of 71 jts. 3 1/2" 9.3 #, NSCT, L-80 casing. Fill every 10 joints. 07:30 - 09:30 2.00 DRILL P INT1 PJSM. Rig down 3 1/2" casing tools. Rig up 5 1/2" casing tools. 09:30 - 10:30 1.00 DRILL P INT1 Run 5 1/2", 15.5#, NSCT, L-80 casing to 2843'. 10:30 - 11:30 1.00 DRILL P INT1 Break circulation and circ. pipe vol. 11:30 - 17:30 6.00 DRILL P INT1 Run 5 1/2" casing to 7834'. Hole taking fluid while running into open hole. Slow slack-off speed to reduce surge pressures. (71 centralizer run on 3 1/2) 17:30 - 18:00 0.50 DRILL P INT1 Land casing and rig up cementing head 18:00 - 21:00 3.00 DRILL P INT1 Reciprocate pipe while circ. and cond. hole and mud for cementing. PU 137,000#; SO 94,000#. Final circ rate up to 5 BPM at 1000 psi. Printed: 6/26/2001 3:12:56 PM BP EXPLORATION Page 4 of 4 Operations Summa Report Legal Well Name: 8-108 Common Well Name: S-108 Spud Date: 6/10/2001 Event Name: DRILL+COMPLETE Start: 6/10/2001 End: 6/23/2001 Contractor Name: DOYEN Rig Release: 6/23/2001 Rig Name: DOYEN 14 Rig Number: Date From - To HoUrs Activity Code NPT Phase Description of Operations 6/21/2001 21:00 - 23:00 2.00 DRILL P INT1 Prop 5 bbl CW100. SD and test lines to 4000 psi, OK. Pmp 25 bbls CW100 followed by 40 bbls of Mudpush XL. Drop bottom plug. Mix and pmp 87 bbls 12 ppg LiteCRETE lead slurry and 57 bbls 15.8 ppg GasBLOK tail slurry. Drop top plug and displace with 150.8 bbls filtered seawater. Displaced at 6 bpm for 130 bbls then slowed rate to 1 bpm to bump plug. Bumped plug and pressured to 2700 psi (500 psi over final circ pressure. CIP at 2245 hrs. Check floats-OK. 23:00 - 00:00 1.00 DRILL P INT1 Rig down cementing and casing tools. 6/22/2001 00:00 - 01:00 1.00 DRILL P INT1 RD casing and cementing tools. 01:00 - 02:30 1.50 DRILL P INT1 Run casing packoff and test to 5000 psi for 10 minutes. RILDS. 02:30 - 03:30 1.00 DRILL P INT1 Establish annular inj. rate with 10 bbl mud at 3 bpm at 1500 psi. RU Hot Oil Serv and pump 35 bbls dead crude at 2 bpm at 2000 psi to freeze protect annulus. 03:30-04:00 0.50 DRILL P INT1 PJSM. RU 3 1/2" tubing tools. 04:00 - 11:00 7.00 DRILL P INT1 Run 3 1/2" 9.3 #, NSCT, L-80 tubing to 5467' 11:00 - 12:00 1.00 DRILL P INT1 RU and test 3 1/2 X 5 1/2 tapered casing string to 3500 psi for 30 min. ;12:00 - 13:30 1.50 DRILL P INT1 RIH with 3 1/2" tubing tagging PBR at 5509' while pumping slowly to verify seals entering PBR. P/U and calculate space out. No pups needed. Total of 167 its plus GLM and X nipple accessories. 13:30 - 14:00 0.50 DRILL P INT1 Prop 28 bbl saltwater with corrosion inhibitor and displace w/36 bbl plain saltwater to spot inhibited fluid in annulus between GLM 1 at 5391' and GLM 3 at 3012'. 14:00 - 15:00 1.00 DRILL P INT1 Sting back into PBR. Land tubing. RILDS. 15:00 - 17:00 2.00 DRILL P INT1 Press. test 3 1/2" tubing & annulus per well plan. Test tubing to 3500 psi for 30 min. Bled to 1500 psi then press, test annulus to 3500 psi for 30 min. Bled tubing off shearing RP in GLM 3. 17:00 - 17:30 0.50 DRILL P INT1 Set TWC and press, test to 2800 psi for 5 min. 17:30 - 19:30 2.00 DRILL P INT1 ND BOPE 19:30 - 22:00 2.50 DRILL P INT1 NU Tree. Test adapter flange seals to 5000 psi for 10 min. Press. test tree to 5000 psi for 10 min. 122:00 - 00:00 2.00 DRILL P INT1 Prep to pull TWC. Wait on adapter for 3" tree cap. 6/23/2001 00:00 - 01:00 1.00 DRILL P INT1 PSJM. Pull TWC. :01:00 - 02:00 1.00 DRILL P INT1 Freeze protect tubing and annulus by pumping 62 bbls diesel down annulus w/rtns up tubing. Circ through GLM w/RP at 3011'. 02:00 - 03:00 1.00 DRILL P INT1 Set BPV. Secure tree. Rig Released at 0300, 6/23/2001. Printed: 6/26/2001 3:12:56 PM Well: S-108 Rig Accept: 06/10/01 Field: Prudhoe Bay Field / Aurora Pool Rig Spud: 06/11/01 APl: 50-029-23021-00 Rig Release: 06/23/01 Permit: 201-100 Drillin~l Rig: Doyon 14 POST - RIG WORK 09/06/01 & 09/07/01 Drift Tubing with 2.5" tag TD at 7612' SLM, Set DGLV in STA Cf 3 and MITIA to 3500 PSI. Perforated Interval 7536' - 7566' with 2-1/8" ENERJET, Big hole charges. Run Cement Bond log SCMT and Jewelry Log GR / CCL. Gun stuck after firing, 48' Fish left in hole. Pulled Catcher Sub, set Tandem Petredat SPMG inside 1.75" bailer with 1-3/8" F.N. (9' 3" total length) at 7669' SLM (PBTD). Completed SCMT, Perforated 30' interval (7536' - 7566') with 2-1/8" BH EJ HMX Gun. Unable to pull up after shot; worked toolstring down to 7575' but unable to move it up hole; had to pull off. Did not complete static. 09108/01 - 09/10101 Fished 48' E-Line T.S. and Strip Gun. Attempting to fish Petredat gauges from PBTD. Bailed .-.3 QTS of Gun junk, run pump/drive down/Hydro bailers in attempt to clean up fill above gauges set at 7669' SLM. (Bailed to 7625' WLM and stopped making progress. 09113101 Drifted with 2.50" CENT to TD at 7626' SLM. Ran a PDS Memory Pressure / Temp Gauges and pumped Methanol down tubing for injectivity test. 09114/01 & 09/15/01 Ran TEMP / PRESS survey sat down at 7521' SLM. (105' higher than pre-data FRAC) Ran 2.30 CENT. And sample bailer sat down at 7539' SLM. (Recovered sample of FRAC Sand) Start bailing with 10', 2.25 pumps Bailer. Pumped two YF-100 EX Data FRACS. Experienced temporary tubing pluggage at beginning of second Data FRAC, worked pumps to clear and regain injectivity. Pumped second Data FRAC attempted to Memory log perforated interval for warm back and found obstruction at 7544' ELM. Attempted to clear obstruction with Centralizer and SX Bailer, recovered 1 pint of 20 / 40 Carbolite. RDFN FRAC unit, continued to bail on obstruction to regain all perforations. Bail FRAC Sand from 7534' (SLM) to 7537' (SLM). Assist Wire Line; arrive on location Spot Unit Safety meeting with Wire Line Crew R/U to tree caps P.T Line to tubing pump Methanol down tubing to help free up Hydrates. Pumped 12 bbls NEET and 44 bbls 50 / 50 mix. 09/16/01 MIRU CTU Cf 3 clean out sand / drilling solids from 7530' to 7620' (.--50 of Rat hole) with Biozan and slick 2% KCL in 3-1/2" liner. Chase any solids OOH at 50%. Returns 1:1. Freeze protect Well to 2000' with 50 / 50 Methanol. 09/18/01 Fractured Perforations 7536' - 7566' with 122861Cf's of 16 / 20 Carbolite using WF-100 GW system. Screened out with 10.3 PPGA on Perforations. Placed 9971 l Cf's of C-LITE behind pipe, left 23150#'s in casing (38.6 bbls). Max treat = 12400 PSI, EST TOS = 3131' MD with bridges above. Well not freeze protected, lost half of Treesaver seal cup (1.5" x 4" x ~,4"). Load to recover = 1195 bbls watch for yielded pipe during Post FRAC FCO and slickline. S-108, Post Rig Summary Page 2 09/19/01 Fished one complete tree saver element from tree (.25" x 1.25" x 2.92"). 09120/01 MIRU CTU #5. RIH with JS Nozzle tag sand at 61', pump 1 BPM. Stack out at 450'. Increase rate to 1.3 BPM. Hard sand until 1000'; into Carbolite and gel at 4100' to 4400', cleanout to 7642' CTMD. POOH circulating BU. RIH with Hydraulic JDC overshot. Tag up at 7643' CTMD. Wash top of FISH, POOH. Did not recover FISH. Freeze protect Well to 2500' with Methanol. 09123/01 & 09/24101 Attempt to Fish Bailer and Gauges from TD. Found FRAC sand and metal junk at 7428' SLM (Gauges left at 7669' SLM). Set 3-1/2" X-Lock catcher at 5414'. Attempt to pull STA #1 DGLV. Pull INT- DBLV's from STA # 1 and 2. Run INT OGLV, STA # 1 at 5362' SLM. Run INT LGLV, STA # @ at 3643' SLM. Pull catcher. 03-Jul-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-108 MWD Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 7,850.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) North Slope Alaska Alaska Drilling 8, Wells PBU_WOA S Pad, Slot 14 S-108 MWD Job No. AKMMl1098, Surveyed: 18 June, 2001 S UR VEY REPORT July, 200~ Your Ref: API5002923021 O0 Surface Coordinates: 5980715.27 N, 6~8929.89 E (70° 21' 21.4758" N, 149° 02' 02.8846" W) Kelly Bushing: 70.25ft above Mean Sea Level BRILLING SERVICES · Survey Ref: svy10868 A Halliburton Company Sperry-Sun Drilling Services Survey Report for S-108 Your Ref: API500292302100 Job No. AKMMlI098, Surveyed: ~8 June, 200~ North Slope Alaska Measured Depth Incl. (ft) : : S-108 Gyros -~. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -70,25 0.00 71.00 0.250 342.000 0.75 71.00 160.00 1.650 98.000 89.74 159.99 S-~08 MWD , · 277.00 4.988 104.872 206.53 276.78 277.41 5.000 104.880 206.93 277.18 371.49 5.180 106.410 300.64 370.89 '461.63 4.220 79.460 390.49 460.74 550.40 4.110 66.070 479.03 549.28 639.07 2.410 56.310 567.55 637.80 730.08 1.920 42.810 658.50 728.75 830.04 2.280 43.710 758.39 828.64 925.16 1.010 130.700 853.48 923.73 1022.62 1.960 159.500 950.97 1021.16 1118.07 1.800 157.820 1046.30 1116.55 1214.70 1.110 157.010 1142.90 1213.15 1311.00 1.330 175.520 1239.18 1309.43 1406.65 0.830 148.920 1334.81 1405.06 1503.03 0.880 138.230 1431.18 1501.43 1598.94 0.800 111.130 1527.08 1597.33 1695.77 0.860 107.110 1623.90 1694.15 1792.00 0.880 97.970 1720.12 1790.37 1888.44 1.050 90.650 1816.55 1886.80 1984.06 1.170 93.340 1912.15 1982.40 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5980715.27 N 618929.89 E 0.15 N 0.05W 5980715.42 N 618929.84 E 0.15 N 1.16 E 5980715.44N 618931.05 E 1.39 S 7.75 E 5980714.01N 618937.66 E 1.40 S 7.78 E 5980714.00 N 618937.69 E 3.65 S 15.82 E 5980711.87 N 618945.76 E 4.19 S 22.98 E 5980711.44 N 618952.94 E 2.30 S 29.10 E 5980713.43 N 618959.02 E 0.02 N 33.56 E 5980715.82 N 618963.44E 2.20 N 36.19 E 5980718.04 N 618966.04 E 4.87 N 38.70 E 5980720.75 N 618968.51 E 5.69 N 40.64 E 5980721.60 N 618970.44E 3.56 N 41.88 E 5980719.50 N 618971.70 E 0.65 N 43.01E 5980716.60 N 618972.89 E 1.62 S 43.95 E 5980714.35 N 618973.86 E 3.59 S 44.40 E 5980712.38 N 618974.35 E 5.29 S 44.85 E 5980710.69 N 618974.82 E 6.44 S 45.70 E 5980709.55 N 618975.69 E 7.23 S 46.82 E 5980708.78 N 618976.82 E 7.69 S 48.14 E 5980708.35 N 618978.15 E 8.00 S 49.56 E 5980708.05 N 618979.57 E 8.12 S 51.18 E 5980707.97 N 618981.19 E 8.18 S 53.03 E 5980707.93 N 618983.04 E Dogleg Rate (°/lOOft) 0.'352 1.993 2.868 2.868 0.240 2.639 1.100 2.010 0.774 0.362 2.570 1.211 0.177 0.714 0.466 0.727 0.173 0.418 0.086 0.146 0.217 0.137 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 0.00 0.13 0.48 Tolerable Gyro 0.88 0.89 1.02 2.55 6.11 9.61 12.45 15.72 17.06 15.38 12.91 11.01 9.24 7.74 6.88 6.44 6.38 6.49 6.84 7.31 Tie On to S-108 Gyros MWD Magnetic July, 2001 - 12:22 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-~08 Your Ref: AP!500292302~00 Job No. AKMM11098, Surveyed: 18 June, 2001 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (m Vertical Depth (ft) 2078.89 0.500 101.950 2006.97 2077.22 2173.92 0.690 92.280 2102.00 2172.25 2269.82 0.780 87.880 2197.89 2268.14 2364.31 0.680 82.410 2292.37 2362.62 2456.52 0.620 98.220 2~84.57 2454.82 2556.23 0.530 100.010, 2484.28 2554.53 2652.38 0.390 95.33Q* 2580.43 2650.68 2748.33 0.500 100.780 2676.37 2746.62 2817.51 0.700 102.560~ 2745.55 2815.80 2873.76 0.990 86.220 2801.79 2872.04 2911.39 1.360 72.240 2839.42 2909.67 3007.25 5.630 20.080 2935.09 3005.34 3105.49 8.480 18.600 3032.58 3102.83 3201.56 12.260 12.230 3127.06 3197.31 3298.45 16.040 11.390 3221.00 3291.25 3394.83 20.860 3490.70 24.870 3583.21 28.690 3679.29 31.720 3775.92 34.450 14.890 16.770 14.910 14.490 16.170 13.870 14.060 12.940 14.490 13.410 13.960 13.230 14.120 13.270 13.570 3869.31 38.170 3965.67 43.470 4002.10 43.990 4061.54 45.310 4158.69 46.350 3312.40 3400.72 3483.29 3566.32 3647.27 3722.52 3795.42 3821.74 3864.O3 3931.72 3997.06 4O64.09 4132.67 4198.59 4264.56 4252.84 45.750 4348.74 45.570 4446.97 45.880 4542.06 46.340 4638.22 47.030 3382.65 3470.97 3553.54 3636.57 3717.52 3792.77 3865.67 3891.99 3934.28 4001.97 4067.31 4134.34 4202.92 4268.84 4334.81 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 8.33 S 54.40 E 5980707.81 N 618984.42 E 8.44S 55.38 E 5980707.72 N 618985.40 E 8.43 S 56.61 E 5980707.74 N 618986.63 E 8.34 S 57.81 E 5980707.85 N 618987.82 E 8.34 S 58.84 E 5980707.87 N 618988.86 E 8.49 S 59.83 E 5980707.73 N 618989.85 E 8.60 S 60.60 E 5980707.63 N 618990.62 E 8.71 S 61.33 E 5980707.54 N 618991.35 E 8.86 S 62.04 E 5980707.40 N 618992.06 E 8.90 S 62.86 E 5980707.37 N 618992.89 E 8.74 S 63.61E 5980707.54 N 618993.63 E 3.98 S 66.31E 5980712.35 N 618996.26 E 7.42 N 70.28 E 5980723.80 N 619000.04 E 24.11 N .. 74.70 E 5980740.56 N 619004.20 E 47.29 N 79.52 E 5980763.82 N 619008.65 E 76.95 N 86.57 E 5980793.58 N 619015.22 E 112.76 N 96.77 E 5980829.55 N 619024.86 E 152.86 N 108.10 E 5980869.82 N 619035.55 E 199.61 N 120.36 E 5980916.77 N 619047.07 E 250.46 N 134.33 E 5980967.84 N 619060.23 E 303.87 N 148.61 E 5981021.46 N 619073.66 E 364.98 N 163.81E 5981082.80 N 619087.89 E 389.46 N 169.69 E 5981107.38 N 619093.37 E 430.04 N 179.60 E 5981148.11 N 619102.64 E 497.67 N 196.39 E 5981215.99 N 619118.36 E 563.52 N 212.43 E 5981282.10 N 619133.34 E 630.19 N 228.55 E 5981349.01 N 619148.40 E 698.53 N 245.18 E 5981417.60 N 619163.95 E 765.11N 261.40 E 5981484.43 N 619179.11E 833.16 N 277.64 E 5981552.73 N 619194.27 E Dogleg Rate (°/lOOft) 0.717 0.225 0.111 0.129 0.204 0.092 0.151 0.123 0.290 0.665 1.237 5.126 2.907 4.106 3.907 5.129 4.251 4.227 3.161 2.980 4.241 5.502 2.560 2.879 1.335 0.764 0.576 0.721 0.806 0.753 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 7.56 7.74 8.09 8.53 8.82 8.95 9.07 9.18 9.24 9.43 9.80 15.13 27.19 44.44 68.04 98.47 135.71 177.37 225.68 278.40 333.66 396.56 421.71 463.43 533.03 600.73 669.22 739.46 807.90 877.75 1 July, 2001 - ~2:22 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-lO8 Your Ref: AP!500292302'100 Job No. AKIVIM? 1098, Surveyed: ~8 June, 200'1 North Slope Alaska Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 4734.59 45.480 12.790 4331.19 4401.44 4830.65 46.040 12.610 4398.21 4468.46 4925.20 46.040 15.510 4463.85 4534.10 5023.09 46.480 15.400 4531.53 4601.78 5119.36 47.020 14.530 4~97.49 4667.74 14.570, 15.40~j 14.730 15.o5o~ 17.330 17.100 16.510 16.760 16.560 14.680 5214.90 47.120 5310.02 47.780 5406.17 46.450 5502.49 47.630 5598.75 44.710 4662.56 4726.89 4792.32 4857.96 4924.62 4992.94 5059.54 5126.33 5192.07 5264.54 5695.24 45.130 5790.04 45.610 5885.81 45.960 5977.88 42.900 6073.53 38.540 4732.81 4797.14 4862.57 4928.21 4994.87 5063.19 5129.79 5196.58 5262.32 5334.79 6169.38 34.760 12.720 5341.43 5411.68 6264.71 31.620 13.110 5421.20 5491.45 6359.88 28.660 11.310 5503.50 5573.75 6453.35 25.650 12.640 5586.66 5656.91 6549.74 22.250 15.550 5674.74 5744.99 6645.79 19.190 13.550 5764.56 5834.81 6742.47 15.860 12.940 5856.74 5926.99 6838.36 12.380 18.020 5949.73 6019.98 6933.06 9.220 17.680 6042.74 6112.99 7028.11 5.660 15.720 6136.97 6207.22 7122.18 2.240 1.240 6230.81 6301.06 7218.15 1.330 337.050 6326.73 6396.98 7312.73 1.180 338.260 6421.29 6491.54 7407.59 0.880 339.540 6516.13 6586.38 7502.81 0.360 315.480 6611.35 6681.60 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 900.94 N 293.52 E 5981620.76 N 619209.07 E 968.08 N 308.65 E 5981688.12 N 619223.13 E 1034.08 N 325.18 E 5981754.39 N 619238.61 E 1102.25 N 344.02 E 5981822.84 N 619256.37 E 1169.99 N 362.13 E 5981890.86 N 619273.40 E 1237.70 N 379.70 E 5981958.84 N 619289.89 E 1305.39 N 397.82 E 5982026.81N 619306.94 E 1373.42 N 416.14 E 5982095.12 N 619324.17 E 1441.54 N 434.25 E 5982163.52 N 619341.20 E 1508.22 N 453.58 E 5982230.50 N 619359.47 E 1573.30 N 473.74 E 5982295.89 N 619378.59 E 1637.88 N 493.25 E 5982360.78 N 619397.07 E 1703.65 N 512.90 E 5982426.85 N 619415.67 E 1765.39 N 531.37 E 5982488:87 N 619433.17 E 1825.45 N 548.21E 5982549.19 N 619449.05 E 1881.01 N 561.80 E 5982604.96 N 619461.76 E 1931.87 N 573.46 E 5982656.00 N 619472.61E 1978.56 N 583.59 E 5982702.85 N 619482.00 E 2020.29 N 592.42 E 5982744.71 N 619490.16 E 2058.24 N 601.88 E 5982782.81 N 619499.02 E 2091.11 N 610.46 E 5982815.81 N 619507.07 E 2119.44 N 617.14 E 5982844.24 N 619513.30 E 2142.00 N 623.25 E 5982866.89 N 619519.06 E 2158.88 N 628.70 E 5982883.86 N 619524.24 E 2170.65 N 632.28 E 5982895.69 N 619527.63 E 2176.96 N '633.58 E 5982902.01 N 619528.83 E 2179.86 N 633.19 E 5982904.91N 619528.39 E 2181.78 N 632.40 E 5982906.81 N 619527.57 E 2183.36 N 631.78 E 5982908.39 N 619526.93 E 2184.26 N 631.32 E 5982909.28 N 619526.45 E Dogleg Rate (°/~00ft) 1.711 0.598 2.208 0.457 0.865 0.109 0.946 1.474 1.249 3.481 0.467 0.673 0.411 3.327 4.735 4.128 3.301 3.252 3.285 3.733 3.269 3.450 3.849 3.338 3.754 3.759 1.211 0.161 0.317 0.599 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 947.25 1015.91 1083.89 1154.59 1224.68 1294.59 1364.64 1435.06 1505.52 1574.94 1643.07 1710.53 1779.18 1843.62 1905.99 1963.12 2015.19 2062.83 2105.34 2144.41 2178.36 2207.42 2230.78 2248.52 2260.82 2267.24 2269.90 2271.51 2272.86 2273.59 July, 200~1 - '12:22 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-108 Your Ref: AP!500292302100 Job No. AKMMl~098, Surveyed: ~8 June, 200~ North Slope Alaska Measured :~ Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. -~ Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 7598.64 0.250 293.870 6707.17 6777.42 2184.56 N 630.91 E 5982909.57 N 619526.04 E 7694.40 0.450 238.210 6802.93 6873.18 2184.45 N 630.40 E 5982909.45 N 619525.53 E 7788.89 0.510 211.820 6897.42 6967.67 2183.90 N 629.87 E 5982908.89 N 619525.01 E 7850.00 0.510 211.600 6958.53 7028.78 2183.43 N 629.58 E 5982908.42 N 619524.73 E Ali data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Exp Slot 6. Northings and Eastings are relative to Exp Slot 6. Magnetic Declination at Surfaci9 is 26.491 ° (08-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Exp Slot 6 and calculated along an Azimuth of 16.600° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7850.00ft., The Bottom Hole Displacement is 2272.39ft., in the Direction of 16.085° (True). Dogleg Rate (°t'~OOft) 0.164 0.388 0.240 0. O03 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 2273.76 2273.51 2272.82 2272.30 Projected Survey Comments Measured Station Coordinates Depth 'I'VD Northings Eastings (ft) (ft) (ft) (ft) 277.00 276.78 1.39 S 7.75 E 7850.00 7028.78 2183.43 N 629.58 E Comment Tie On to S-108 Gyros Projected Survey July, 200~ - ~2:22 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-lO8 Your Ref: API500292302~00 Job No. AKMM. I ~098, Surveyed: ~8 June, 200~ North Slope Alaska Survey tool program for S-~8 MWD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 277.41 277.18 277.41' 7~50.00 .I , Vertical Depth (ft) 277.18 7028.78 Survey Tool Description Tolerable Gyro (S-108 Gyros) MWD Magnetic (S-108 MWD) Alaska Drilling & Wells PBU WOA S Pad July, 200t - '12:22 Page 6 of 6 DrillQuest 2.00.08.005 DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad, Slot 14 S-108 Job No. AKZZl1098, Surveyed: 18 June, 200~ S UR VEY REPORT 3 July, 2001 Your Ref: API500292302~ O0 Surface Coordinates: 5980715.27 N, 618929.89 E (70° 21' 2~.4758" N, 149° 02' 02.8846" Vt/) Kelly Bushing: 70.25ft above Mean Sea Level DRILL. iNI3 ~ERViE. E~, A Halliburton Company Survey Ref: svy10866 Sperry-Sun Drilling Services Survey Report for S-lO8 Your Ref: APi500292302~ O0 Job No. AKZZ~I098, Surveyed: ~8 June, 200~ North Slope Alaska Measured Depth (ft) Incl. . '~ S-~08 Gyros 0.00 71.00 160.00 S-108 277.41 0.000 0.250 1.650 5.000 0.000 342.000 98.000 105.040 Sub-Sea Depth (ft) -70.25 ' 0.75 89.74 206.93 Vertical Depth (ft) 0.00 71.00 159.99 277.18 371.49 5.180 106.410 300.64 370.89 '461.63 4.220 79.490 390.49 460.74 550.40 4.110 66.090 479.03 . 549.28 639.07 2.410 56.280 567.55 637.80 730.08 1.920 42.820 658.50 728.75 830.04 2.280 43.670 758.39 828.64 925.16 1.010 130.690 853.48 923.73 1022.62 1.960 159.470 950.91 1021.16 1118.07 1.800 157.880 1046.30 1116.55 1214.70 1.110 157.100 1142.90 1213.15 1311.00 1.330 175.680 1239.18 1309.43 1406.65 0.830 149.320 1334.81 1405.06 1503.03 0.880 138.230 1431.18 1501.43 1598.94 0.800 111.230 1527.08 1597.33 ' 1695.77 0.860 107.290 1623.90 1694.15 1792.00 0.880 97.990 1720.12 1790.37 1888.44 1.050 90.850 1816.55 1886.80 1984.06 1.170 93.570 1912.15 1982.40 2078.89 0.500 102.120 2006.97 2077.22 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5980715.27 N 618929.89 E 0.15 N 0.05W 5980715.42 N 618929.84 E 0.15 N 1.16 E 5980715.44 N 618931.05 E 1.41S 7.78 E 5980713.98 N 618937.69 E 3.67 S 15.81E 5980711.85 N 618945.76 E 4.22 S 22.98 E 5980711.42 N 618952.93 E 2.33 S 29.10 E 5980713.40 N 618959.02 E 0.01S 33.55 E 5980715.79 N 618963.44 E 2.17 N 36.18 E 5980718.01 N 618966.03 E 4.84 N 38.69 E 5980720.72 N 618968.50 E 5.66 N 40.63 E 5980721.57 N 618970.43 E 3.54 N 41.87 E 5980719.47 N 618971.70 E 0.62 N 43.01 E 5980716.57 N 618972.88 E 1.65 S 43.94 E 5980714.32 N 618973.85 E 3.62 S 44.39 E 5980712.35 N 618974.33 E 5.32 S 44.83 E 5980710.66 N 618974.80 E 6.48 S 45.68 E 5980709.52 N 618975.66 E 7.27 S 46.79 E 5980708.75 N 618976.79 E 7.73 S 48.11E 5980708.31N 618978.12 E 8.05 S 49.54 E 5980708.01 N 618979.55 E 8.16 S 51.15 E 5980707.92 N 618981.17 E 8.24 S 53.00 E 5980707.88 N 618983.02 E 8.38 S 54.37 E 5980707.75 N 618984.39 E Dogleg Rate (°/lOOft) 0.352 1.993 2.869 0.231 2.637 1.101 2.011 O.772 0.361 2.571 1.210 0.176 0.714 0.467 0.724 0.179 0.417 0.085 0.148 0.216 0.137 0.717 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 0.00 0.13 0.48 Tolerable Gyro 0.87 1.00 2.52 6.08 9.58 12.42 15.69 17.03 15.35 12.88 10.98 9.21 7.70 6.84 6.40 6.34 6.44 6.79 7.25 7,.50 Tie On to Surface Gyros AK-6 BP IFR-AK 3 July, 2001 - 7:~0 Page 2 of 6 DrillQuest 2.00,08.005 Sperry-Sun Drilling Services Survey Report for S-~08 Your Ref: AP!500292302~ O0 Job No. AKZZI~098, Surveyed: ~8 June, 200~ North Slope Alaska Measured Depth Incl. Azim.*~ Sub-Sea Depth (ft) Vertical Local Coordinates Global Coordinates Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) 2173.92 0.690 92.170 2102.00 2172.25 2269.82 0.780 87.850 2197.89 2268.14 2364.31 0.680 82.470 2292.37 2362.62 2456.52 0.620 98.280 2384.57 2454.82 2556.23 0.530 99.980 2484.28 2554.53 2652.38 0.390 95.610, 2580.43 2650.68 2748.33 0.500 100.600'~ 2676.37 2746.62 2817.51 0.700 101.710 2745.55 2815.80 2873.76 0.990 86.140~ 2801.79 2872.04 2911.39 1.360 72.240 2839.42 2909.67 3007.25 5.630 20.060 2935.09 3005.34 -3105.49 8.480 18.730 3032.58 3102.83 3201.56 12.260 12.570 3127.06 3197.31 3298.45 16.040 11.390 3221.00 3291.25 3394.83 20.860 15.050 3312.40 3382.65 3490.70 24.870 16.930 3400.72 3470.97 3583.21 28.690 14.810 3483.29 3553.54 3679.29 31.720 14.520 3566.32 3636.57 3775.92 34.450 16.360 3647.27 3717.52 3869.31 38.170 14.190 3722.52 3792.77 3965.67 43.470 14.380 3795.42 3865.67 4002.10 43.990 13.310 3821.74 3891.99 4061.54 45.310 14.740 3864.03 3934.28 4158.69 46.350 13.530 3931.72 4001.97 4252.84 45.750 14.050 3997.06 4067.31 4348.74 45.570 13.410 4064.09 4134.34 4446.97 45.880 14.080 4132.67 4202.92 4542.06 46.340 13.050 4198.59 4268.84 4638.22 47.030 13.450 4264.56 4334.81 4734.59 45.480 12.600 4331.19 4401.44 8.49 S 55.35 E 5980707.66 N 618985.37 E 8.49 S 56.58 E 5980707.68 N 618986.60 E 8.39 S 57.78 E 5980707.80 N 618987.79 E 8.39 S 58.81 E 5980707.81 N 618988.83 E 8.55 S 59.80 E 5980707.67 N 618989.82 E 8.66 S 60.57 E 5980707.57 N 618990.59 E 8.77 S 61.30 E 5980707.48 N 618991.32 E 8.91S 62.01 E 5980707.35 N 618992.04 E 8.95 S 62.83 E 5980707.32 N 618992.86 E 8.79 S 63.58 E 5980707.49 N 618993.61E 4.02 S 66.28 E 5980712.30 N 618996.23 E 7.37 N 70.26 E 5980723.75 N 619000.03 E 24.04 N 74.76 E 5980740.49 N 619004.26 E 47.21 N 79.64 E 5980763.74 N 619008.77 E 76.85 N 86.73 E 5980793.49 N 619015.39 E 112.64 N 97.04 E 5980829.43 N 619025.13 E 152.73 N 108.38 E 5980869.70 N 619035.84 E 199.49 N 120.62 E 5980916.65 N 619047.32 E 250.32 N 134.69 E 5980967.69 N 619060.58 E 303.66 N 149.21E 5981021.26 N 619074.26 E 364.68 N 164.75 E 5981082.52 N 619088.83 E 389.13 N 170.77 E 5981107.06 N 619094.46 E 429.65 N 180.90 E 5981147.74 N 619103.95 E 497.22 N 197.91 E 5981215.57 N 619119.88 E 563.05 N 214.07 E 5981281.65 N 619134.99 E 629.68 N 230.35 E 5981348.53 N 619150.21E 698.00 N 247.06 E 5981417.10 N 619165.84 E 764.61N 263.13 E 5981483.96 N 619180.85 E 832.71N 279.17 E 5981552.31N 619195.80 E 900.54 N 294.86 E 5981620.38 N 619210.42 E Dogleg Rate (°/100ft) 0.227 0.110 0.128 0.204 0,092 0.150 0.121 O.290 0.653 1.234 5.127 2.906 4.095 3.912 5.141 4.251 4.256 3.157 3.010 4.214 5.502 2.482 2.791 1.394 0.751 0.513 0.581 0.918 0.779 1.730 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 7.68 8.03 8.47 8.76 8.89 9.01 9.11 9.18 9.38 9.74 15.08 27.13 44.39 68.00 98.43 135.67 177.33 225.63 278.36 333.63 396.55 421.70 463.43 533.04 600.74 669.24 739.49 807.92 877.76 947.24 3 July, 2001- 7:10 Page 3 of 6 DfillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-108 Your Reft API5002923021 O0 Job No. AKZZl1098, Surveyed: 18 June, 2001 North Slope Alaska Measured Depth (ft) 4830.65 4925.20 5023.09 5119.36 5214.90 5310.02 5406.17 5502.49 5598.75 5695.24 5790.04 5885.81 5977.88 6073.53 6169.38 6264.71 6359.88 6453.35 6549.74 6645.79 6742.47 6838.36 6933.06 7028.11 7122.18 7218.15 7312.73 7407.59 7502.81 7598.64 Incl. 46.040 46.040 46.48O 47.020 47.120 47.78O 46.450 47.630 44.710 45.130 45.610 45.960 42.9O0 38.540 34.760 31.620 28.660 25.650 22.250 19.190 15.860 12.380 9.220 5.660 2.240 1.330 1.180 0.880 0.360 0.250 Azim. ~ 12.490 15.520 15.460 14.630 14.540 15.140, 14.560" 14.800 17.530~ 17.190 16.930 16.760 16.470 14.600 12.610 13.180 11.320 12.550 15.050 13.080 12.440 17.260 16.840 15.480 1.270 337.490 338.800 339.82O 315.490 293.970 Sub-Sea Depth (ft) 4398.21 4463.85 4531.53 4597.49 4662.56 4726.89 4792.32 4857.96 4924.62 4992.94 5059.54 5126.33 5192.07 5264.55 5341.44 5421.20 5503.50 5586.66 5674.74 5764.57 5856.75 5949.73 6042.74 6136.97 6230.81 6326.73 6421.29 6516.13 6611.35 6707.18 Vertical Depth (ft) 4468.46 4534.10 4601.78 4667.74 4732.81 4797.14 4862.57 4928.21 4994.87 5063.19 5129.79 5196.58 5262.32 5334.80 5411.69 5491.45 5573.75 5656.91 5744.99 5834.82 5927.00 6019.98 6112.99 6207.22 6301.06 6396.98 6491.54 6586.38 6681.60 6777.43 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) fit) (ft) 967.71N 309.81E 5981687.78 N 619224.30 E 1033.74 N 326.28 E 5981754.05 N 619239.71 E 1101.89 N 345.16 E 5981822.50 N 619257.52 E 1169.61 N 363.36 E 5981890.50 N 619274.64 E 1237.30 N 380.98 E 5981958.47 N 619291.18 E 1305.04 N 398.93 E 5982026.48 N 619308.05 E 1373.13 N 416.99 E 5982094.85 N 619325.02 E 1441.32 N 434.85 E 5982163.31N 619341.80 E 1508.01 N 454.14 E 5982230.30 N 619360.03 E 1573.04 N 474.47 E 5982295.64 N 619379.33 E 1637.54 N 494.26 E 5982360.45 N 619398.09 E 1703.23 N 514.15 E 5982426.45 N 619416.94 E 1764.98 N 532.58 E 5982488.49 N 619434.38 E 1825.07 N 549.33 E 5982548.83 N 619450.18 E 1880.65 N 562.83 E 5982604.62 N 619462.79 E i931.52 N 574.46 E 5982655.67 N 619473.62 E 1978.20 N 584.63 E 5982702.50 N 619483.04 E 2019.94 N 593.43 E 5982744.37 N 619491.18 E 2057.93 N 602.71E 5982782.51N 619499.85 E 2090.88 N 611.00 E 5982815.59 N 619507.62 E 2119.27 N 617.45 E 5982844.07 N 619513.61 E 2141.88 N 623.32 E 5982866.78 N 619519.13 E 2158.84 N 628.53 E 5982883.82 N 619524.07 E 2170.65 N 631.99 E 5982895.68 N 619527.34 E 2176.96 N 633.27 E 5982902.01 N 619528.52 E 2179.87 N 632.88 E 5982904.91N 619528.09 E 2181.79 N 632.11 E 5982906.82 N 619527.28 E 2183.38 N 631.51E 5982908.41N 619526.66 E 2184.28 N 631.05 E 5982909.30 N 619526.18 E '2184.58 N 630.64 E 5982909.59 N 619525.77 E Dogleg Rate (°/lOOft) 0.589 2.307 0.452 0.842 0~125 0.835 1.452 1.239 3.658 0.501 0.543 0.387 3.331 4.733 4.133 3.310 3.261 3.276 3.680 3.267 3.450 3.828 3.338 3.750 3.754 1.203 0.161 0.317 0.600 0.164 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 1015.89 1083.87 1154.58 1224.67 1294.58 1364.62 1435.03 1505.48 1574.90 1643.03 1710.49 1779.13 1843.58 1905.94 1963.07 2015.14 2062.78 2105.29 2144.35 2178.29 2207.34 2230.69 2248.43 2260.74 2267.15 2269.82 2271.45 2272.80 2273.53 2273.70 3 July, 2001 - 7:11 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-lO8 Your Reft API500292302~ 00 Job No. AKZZl?O98, Surveyed: ~8 June, 200~ North Slope Alaska Measured Depth Incl. Azim. ~ Sub-Sea Vertical ., Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 7694.40 0.450 237.860 6802.93 6873.18 2184.47 N 630.13 E 5982909.47 N 619525.26 E 7788.89 0.510 211.600 6897.42 6967.67 2183.91 N 629.60 E 5982908.90 N 619524.74 E 7850.00 0.510 211.600 6958.53 7028.78 2183.45 N 629.32 E 5982908.44 N 619524.46 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Exp Slot 6. Northings and Eastings are relative to Exp Slot 6. Magnetic Declination at Surfa(~e is 26.491° (08-Jun-01) . The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Exp Slot 6 and calculated along an Azimuth of 16.600° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7850.00ft., The Bottom Hole Displacement is 2272.33ft., in the Direction of 16.078° (True). Dogleg Rate (°/'~OOft) 0.390 0.239 0.000 Alaska Drilling & Wells PBU WOA S Pad Vertical Section Comment 2273.45 2272.76 2272.24 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 277.41 277.18 1.41S 7.78 E 7850.00 7028.78 2183.45 N 629.32 E Comment Tie On to Surface Gyros Projected Survey 3 July, 2001 - 7:1'! Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling ServiceS Survey Report for S-108 Your Ref: API500292302100 Job No. AKZZl~O98, Surveyed: ~8 June, 200~ North Slope Alaska Alaska Drilling & Wells PBU WOA S Pad Survey tool program for S-'1(~8 From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 277.41 277.18 277.41' 7~50.00 .I . Vertical Depth (fi) 277.18 7028.78 Survey Tool Description Tolerable Gyro (S-108 Gyros) AK-6 BP_IFR-AK (S-108) 3 July, 2001.7:11 Page 6 of 6 DrillQuest 2.00.08.005 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs S- 108, AK-MM- 11098 1 LDWG formatted Disc with verification listing. API#: 50-029-23021-00 September 28, 2001 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANS~TAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED OCT 0 4 2001 Alaska Oil '&Gas Cons. Commi~on Anchorage IA}eLL LO ; ,,. Ti:TA $ I AL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE · Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning signed a of copy this transmittal letter to the attention of' Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM COLOR Open Hole I I 1 o/-Ioo S-1 08 9/1 3/01 Res. Eval. CH I I 1 , Mech. CH 1 Caliper Survey :ii Signed · ,i, ~i! Print Name: , Date · RECEIVED 0CT03 2001 Alaska Oil & Gas Cons. Commission Anchorage ProActive DiagnosTic Services, Inc., 310 K Street SuiTE 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907)245-8952 E-mail: pdsanchorage~memorylog.com Website: _.w__w_.w....._m._..e._.m.__o_r. yJ_.o.g,_c..o_m_ 07/11/01 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. t282 Company: Alaska Oil & Gas Cons Comm At'm: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Polaris Well Job # Log Description Date Color Sepia BL CD S-108 -'~Ol~/~ 21315 CMR 06/19/01 2 S-t05 ~)~ I~- 21317 ,RST 06116101 W-201 Z~,~,.,' O~ ~ 21293 USIT 0610310t 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED 'JUL 1 3 2001 AJaska Oil & Gas Cons. P.,onanis~ Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie Receiv~"~. AI,ASKA OIL AND GAS CONSERYA~ION CO~SSION Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 TONY KNOWLES, GOVERNOR 333 W. '~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit S-108 BP Exploration (Alaska) Inc. Permit No: 201-100 Sur Loc: 4511'NSL, 4497'WEL, Sec. 35, T12N, R12E, UM Btmhole Loc. 1406'NSL, 3845'WEL, Sec. 26, T12N, R12E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not eXempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. According to the rules provided in our letter of November 30, 2000, your request for an exception to the Diverter requirements of 20 AAC 235.035(c) is granted. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit S-108. Blowout prevention equipment (BOPE) must be tested in aCcordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this ~ 7~ day of June, 2001 j jo/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil [] Drill [] Reddll lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone la. Type of work [] Re-Entry [] Deepen 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE - 70' Prudhoe Bay Field / Aurora 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028257 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4511' NSL, 4497' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1406' NSL, 3845' WEL, SEC. 26, T12N, R12E, UM S-108 Number 2S100302630-277 At total depth 9. Approximate spud date 1406' NSL, 3845' WEL, SEC. 26, T12N, R12E, UM 06/06/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028258, 1433' MDI No Close Approach 2560 7840' MD / 7011' TVD 16. To be completed for deviated wells 17. Anticipated pres. s~ure~see 20~ AAC 25.035 (e) (2)} Kick Off Depth 2900' MD Maximum Hole Angle 46.3 ° Maximum surfa(~ 281'4 ps!g?At total depth (TVD) 6651' / 3479 psig 18. Casing Program Specifications Setting Depth"- ......... Size To 3 Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' Surface Surface' 133' 133' 260 sx Arctic Set (Approx.) 9-7/8" 7-5/8" 29.7# L-80 BTC 2816' Surface Surface 2850' 2850' 283 sx Arcticset Lite 3, 122 sx 'G' 6-3/4" 5-1/2. x 3-1/2" 15.5#/9.2# t-80 BTC-M/IBT-M 7806' Surface Surface 7840' 7011' ;~23 sx titeCrete, 257 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate Production lc, 200t Perforation depth: measured ,?~lasi~a 0if & Gas Cons. true vertical ,.anchorage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AA(:; 25.050 Requirements Oontact Engineer Name/Number: Phil Smith, 564-4897 Oave Wesley, 564-5??$ Prepared By Name/Number: Terrie Hubble, 564o46£~ 21. I hereby certify that the foregoing is true and o...a[rect to the best of my knowledge Signed Dan Stone ~ .... -~,~-.~ , ~~ Title Senior Drilling Engineer Date ~'/~t ii..~' .::.: ..': .. '.~. ~. ..i :. . .:.:'. :.' : '::'..::' ::,.,::.?.!.: ::'".'.:.,.'.' .'..~..:.??,..'... :.;..:.~::.;i~`!:..:~..!:....C.~...:..?i..~..:.:..`:::c~m~i.s~i~:~i~..~i~:`...?:.~.~...~:~::......:~.:.:...:.i..~.:!~...~:.:`~..../.~..~..· ..i:'...':,,'.,':':~,:..'"::i ~..~...', .:.,:'...: ..... :.',.'."...,..' .::.2':.,.:. · ~..O/-~/Oo 150-O.~..~- ~ :~O~_./ I (,o-O~-O ~ I for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes I~ No Hydrogen Sulfide Measures [] Yes 1~ No Directional Survey Required ~3 Yes [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ,1~3.5K psi Othe~RIGINAL SIGNED BY byorderof/f,~ /(~'/d / ~Approved By D Ta¥10~Se.a_._m~)u_n.! , Commissioner the commission Date Form 10-401 Rev. 12-01-85 n Triplicate To: Commissioner, AOGCC Date: May 16, 2001 From: Phil Smith Subject: Dispensation for 20 AAC 25.035 (c) on Aurora S-108 BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale of the request. To date, none of the 40-plus Ivishak wells at S-pad, nor the recent ten Aurora/Polaris wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first ten surface holes for the Aurora/Polaris development were drilled no deeper than the shale underlying the SV-1 sands; S-108 is planned to TD in the shallower SV-3 shale, as did the most recent wells (apart from S-106 where a diverter was installed). The shale underlying the SV1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is +500' TVD above the Ugnu horizon. The shallowest and most recent RFT points recorded in the area are from S-201, recording a pore pressure of 1,423psi at 3,175' TVDss (8.6 ppg EMW) and not exceeding 8.7 ppg EMW above 3700' TVDss. S-108 is planned to reach 9.6 ppg mud weight before TD at 2,850' TVDss. This planned mud weight, and the aforementioned RFT data, is plotted on the attached chart. Supporting surface hole gas detection information is on file with the AOGCC from recently drilled S-105. Your consideration of the waiver is appreciated. Sincerely, Phil G. Smith ADW Engineer 564-4897 5OO 1000 1500 2000 2500 Aurora/Polaris Surface Hole Mud Weight Mw (ppg) 9 10 ~ Pore Pressure ~S-100 ~ ~$~101 ~ ~S-102 ~ . IS~105 -e- S-103 ~ S~201 3000 , '~-®~'~ $-216 ~ S-213 - - S-104 -~- S-108 Plan 3500 4000 PGS 5/16/2001 S-108 Drilling Permit I Well Name: I S-108 Drill and Complete Plan Summary i Type of Well (service / producer / injector): I Producer Surface Location: As-Staked Target Location: Kuparuk "C" sands Bottom Hole Location: X = 618,929.89' Y = 5,980,715.27' 4511' FSL (768' FNL), 4497' FEL (782' FWL), Sec. 35, T12N, R12E Umiat X = 619,544.0' Y = 5,982,900.0' 1406' FSL (3873' FNL), 3845' FEL (1433' FWL), Sec. 26, T12N, R12E Um X = 619,544.0' Y = 5,982,900.0' 1406' FSL (3873' FNL), 3845' FEL (1433' FWL), Sec. 26, T12N, R12E Um I AFENumber: 15M0021 I I Rig: I Doyon14 I Estimated Start Date: 1 6/6/2001 I I Operating days to complete: 1 14.0 iMD:17840' I I TVD:I70~' I I BF/MS: 136.3' I IRKS: 170.0' I Well Design (conventional, slimhole, etc.): I Microbore (Iongstring) I Objective: I Kuparuk Formation (Target zones C sands) Mud Program: 9-7/8" Surface Hole (0-2850' ~: Fresh Water Surface Hole Mud Density Viscosity Yield Point APl FL PH (ppg) (seconds) (Ib/100ft~) (mls/30min) Initial 8.5 - 8.6 300 50 - 70 15 - 20 8.5 - 9.5 below -2000' MD 9.3 - 9.5 100 - 200 30 - 45 < 10 8.5 - 9.5 interval TD 9.6 max 100 25 - 35 < 10 8.5 - 9.5 6 aA" Intermediate / Production Hole (2850'- 7840'): Fresh Water LSND (seconds) Filtrate Filtrate Surface 9.8 ~,10.3' 40-60 20-29 8-15 8.5-9.5 6cc to 4 <10 by shoe to~ HRZ HRZ S-lO8 Permit to Drill Page I Directional: Ver. Sperry WP-03 KOP: 2900' Maximum Hole Angle: 46.3° at 4056' MD Close Approach Wells: All wells pass major risk criteria. A surface gyro will be required to a maximum of 1000'. No IFR required. Logging Program: Surface Intermediate/Production Hole Drilling: MWD / GR Open Hole: Gyro (1000' max) Cased Hole: None Drilling: MWD / GR / Res / Neu-Den Open Hole: CMR/4-Arm Caliper / Cuttings samples Cased Hole: USIT cement evaluation Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, PPG SV6 1555 Base Permafrost 1926 1880 SV5 2196 2130 SV4 2396 2320 SV3 2751 2670 ~__ .,~,,;.,,.~-~,,..~ SV2 2906 2840 SVl 3249 3190 8.7 ppg '?~ UG4 3615 3525 UG4A 3673 3575 UG3 4079 3880 UG1 4839 4380 Top Schrader (Ma) 5280 4715 8.7 WS2 Schrader Na 5598 4930 8.6 WSl Schrader OA 5757 5035 8.5 Base Obf 6149 5330 8.2 Colville mudstone 7211 6357 to,'~ HRZ 7416 6510 ~'/'ppg mud weight (in prep for target sand) Kalubik 7535 6636 '~' Kuparuk Top (C) 7547 6651 Target Sand 10.35 ppg EMW .. LCU (KUP B) 7606 6707 Kuparuk A 7632 6733 Miluveach 7696 6796 TD 7840 TD Criteria 150' below Miluveach top S-108 Permit to Drill Page 2 Casinq/Tubinq Proc ram: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 133/133 9-7/8" 7 5/8" 29.7# L-80 BTC 2816' GL 2850'/2850' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 5096' GL 5130'/4675' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 2710' 5130'/4675 7840'/7011' Tubing 3-1/2" 9.2# L-80 IBT-mod 5096' GL 5130'/4675' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casin(. Basis: Size 17-5/8" Surface I Lead: Based on 1920' of annulus in the permafrost @ 175% excess and 430' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2350' MD (2350' TVDbkb). Lead 1 224 bbl / 1258 ft~ / 283 sks of Dowell ARTICSET Lite 3 at 1 10.7 ppg and 4.44 cf/sk. Tail 25 bbl / 140 ft~ / 122 sks of Dowell Premium 'G' at 15.8 ppg and 1.15 cf/sk. Casing Size~15-1/2''x3-1/2''Longstring Production I Basis: Lead: Based on TOC 500' above top of Ugnu 4A formation & 30% excess above Tail Lead TOC: 3180' MD, 3180' TVDbkb Tail: Based on TOC 1000' TVD above top of Kuparuk C4B target and 30% excess + 80' shoe volume Tail TOC: 6500' MD, 5688' TVDbkb ITotal Cement Volume: I Lead 95 bbls / 533 ft~/223 sks of Dowell LiteCrete at 12.0 I ppg and 2.39 cf/sk. Tail 155 bbls / 309 ftc/257 sks of Dowell Premium 'G' at 15.8 I ppg and 1.20 cf/sk. S-108 Permit to Drill Page 3 Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- , Maximum anticipated BHP: · Maximum surface pressure: 3479 psi @ 6651' TVDss - Kuparuk C -Sands 2814 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 3500 psi · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal'. · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. S-108 Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. Operations: MIRU Doyon 14. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2850' MD / 2850' TVD. The actual surface hole TD will be +/-100' TVD below the top of the SV3 sands. 4. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar or stage tool will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 3500 psi. 6. MU 6-3/4" drilling assembly with MWD/GR/Res/Neu/Den and RIH to float collar. Test the 9-5/8" casing to 3000 psi for 30 minutes. 7. Drill out shoe joints and displace well to 6% KCI LSND GEM drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill ahead to -150' of rat hole below the Kuparuk. Condition hole for logging and POOH. 9. RU Schlumberger E-line unit. Make a single run with CMR/Caliper. POOH and RD Schlumberger. 10. If logging time is excessive, RIH with 6-3/4" cleanout assembly and condition hole for running the 5 ~" x 3 Y2" casing. POOH laying down the 4" DP. 11. Run and cement the tapered production casing as required to cover all significant hydrocarbon intervals. Displace the casing with seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. 12. Test the casing to 3500 psi for 30 min. 13. Run the 3-1/2", 9.3#, L-80 gas lift completion assembly. Sting seal assembly into tieback receptacle and test to 3500 psi for 30 minutes both the tubing and annulus. 14. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 15. Freeze protect the well to -2200' and secure the well. 16. Rig down and move off. Estimated Spud Date: 6-6-2001 Phil Smith Alaska Drilling & Wells 564-4897 S-108 Permit to Drill Page 5 S-108 Hazards and Contingencies Job 1: MIRU Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad in the last 12 months was on S-40 @ 70 ppm, (January 2001). The closest wells to S-108 are S-102, and S-103. Both measured 8 ppm at their last tests. S-100 and S-101 are the closest BHLs to S-10, with readings of 8 ppm. The closest surface locations are S-102 and S-103, each at 60' from well S-108. No surface shut- in's will be required. Materials have been staged on S-Pad as contingency for bridge outage. Job 2: Drillinc~ Surface Hole No faults are expected to be penetrated by S-1,!.9-71 in the surface interval. There are no close approach issues in the surface hole. All wells pass major risk criteria. The closest well apart from those on close centers immediately after spud is S-213 at roughly 170' center-center at approximately 1600' MD. The SV4 sand may contain gas hydrates, though little or none have been encountered thus far in the recent S-pad development. Hydrate will be treated at surface with appropriate mud products. Job 3: Install surface Casinq It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at _+1000'MD to allow a secondary circulation as required. Job 7: Drillinq Intermediate / Production Hole S-108 will not cross any faults. The only fault mapped in the area is well outside the driller's polygon, tipping out in the colville shales east of the well trajectory. The vertical well profile then diverges from the fault dip to TD. The surface casing point is chosen just below the SV3 sands, leaving the SV1 exposed for the 8- 3/4" hole. Differential sticking across the SV-1 sands has not been identified as a major issue in the Aurora development, though the potential exists with the higher mud weight required on this well. KICK TOLERANCE: In the worst case scenario of 10.35 ppg pore pressure at the Kuparuk target depth, a fracture gradient of 13.5 ppg at the surface casing shoe, and 10.7 ppg mud in the hole, kick tolerance is 19 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 13.5 ppg. Job 8: Loq Production Hole The CMR is a magnetic log which is highly influenced by metal debris. Make every effort to keep the hole free of metal shavings. Ensure the hole is in very good condition to avoid a stuck tool string or log impass. S-108 Permit to Drill Page 6 Job 9: Case & Cement Production Hole The Ugnu 4A is expected to be oil bearing. For this reason the 5-1/2" casing will be cemented to 500' above the Ugnu 4A sand (the uppermost significant hydrocarbon). The top of the hydrocarbon interval should be verified with LWD resistivity Icg. After freeze protecting the 5 ¥2"x 7-5/8" casing annulus with 35 bbls of dead crude, the hydrostatic pressure alone will be less than the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Expect trapped annulus pressure after pumping the dead crude. This is the first microbore completion on Doyon 14 or on S-pad. Most of the differences between this well design and other more conventional designs (apart from hole size) is in the tapered Iongstring and tubing/seal-bore items. Thorough pre-job planning meetings will help ensure Success. Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Job 13: ND/NU/Release Ric~ Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. S-108 Permit to Drill Page 7 S-108 Ri.qsite Summary of Drilling Hazards POST THIS NOTICE IN THE DOGHOUSE Monitor closely for signs of gas in the surface hole and perform regular evacuation drills. No gas has been encountered so far in the Aurora development and none is expected, however without the diverter on this well the consequence of encountering shallow makes reaction time more critical for personnel safety. The Ugnu interval can be expected to contain hydrocarbons. Kick tolerance is very Iow: 19 bbls. Hold a pre-reservoir meeting and conduct kick drills every tour. Do not hesitate to shut in the well if flow is suspected after observing even minor pit gains. High formation pressures are present both in and sometimes above the Kuparuk reservoir zone. Expected formation pressure below the permafrost is 9.0 ppg EMW. Previous Aurora S-Pad surface holes were drilled with 9.6- 9.7 pgg mud weight without problem. Hydrates have occasionally been encountered at S pad. No other shallow gas has been reported. S-100i and S-101 did not encounter any shallow gas problems. S-102 encountered hydrate shows at 2700' and 2850' TVDbkb, however there were no associated complications. Lost circulation while drilling has not been a problem so far in the Aurora development, despite several fault crossings. There are no faults in the area, but the closest is +500' away from the well plan. Pipe sticking tendency can be mitigated through short trips in the Ugnu / West Sak area. Backream connections with caution. Ream down with reduced pump rates. pad is not a designated H2'S pad. CONSULT THE S PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Aurora S-108 Hazards and Contingencies Page ! of 1 COMPANY DETAILS BP Amoco Calculation Methed: Minimum C~n~tere En~r System: 1SCWSA Scan Melhod: High Side- Az/mul:h Erwr Surface: Ell/p6cal + Casing Wami~ Mea~xt Ru~s rased REFERENCE IlqFORMATION Co-ordinate (N'E) Refere~.-e: Well Cenli-e: Plan S-lo8. True North Verfcal (TVD) Reference: N-9ES 64.5 Section (¥S) Reference: Sk>t - (0.00,0.001 Measured Del>th Reference: N-9ES 64.5 Calculalion Method: Minimum Curvature SURVI~Y PROGRAM DepthFm DepthTo Sureey,Plan 6430 500.00 Planned: S-108 ~p03 VI 500.O8 7795.57 Planned: S-lo8 v, p03 VI 1ool CB-GYRO-SS /~pArD Plan: S-108 wp03 (Plan S-IllS/Plan S-1081 Created By: Ken Alien 1)ale: 4/3/211111 Checked: Date: Reviewed: l)a~e: ANNOTATIONS No. TVD MD Annotation I 300.00 300.00 Start Dir 1°/100': 300' MD, 300'TVD 2 1298.73 1300.00EndDir : 1300'MD, 1298.73'TVD 3 2898.73 2900.00Start Dh- 4°/100': 2900' MD, 2898.73'TVD 4 3933.44 4056.25End Dir: 4056.25' MD, 3933.44' TVD 5 5248.65 5958.18Start Dir 4°/100': 5958.18' MD, 5248.65'TVD 6 6283.36 7114.43EndDir : 7114.43' MD, 6283.36'TVD 7 6964.49 7795.56Total Depth: 7795.57' MD, 6964.5' TVD Dir 1°/100': 300' MD, 300'TVD End Dir : 1300' MD, 1298.73' TVD FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1924.50 1925.77Base Permafrost 2 2194.50 2195.77SV5 3 2394.50 2395.77SV4 4 2749.50 2750.77SV3 5 2904.50 2905.77SV2 6 3244.50 3249.22SV1 7 3584.50 3615.11UG4 8 3634.50 3672.70UG4A 9 3949.50 4079.47UG3 10 4474.50 4838.68UG1 11 4779.50 5279.74Ma (Top Shrader Bluff) 12 4999.50 5597.88WS2 (lq sands) 13 5109.50 5756.95WS1 (Osands) 14 5389.50 6149.15Obf base 15 5389.50 6149.15T. Colville / base Shrader 16 6379.50 7210.57CMl (Colville ShalesK-10) 17 6584.50 7415.57THRZ 18 6703.50 7534.57BHRZ CKalubik) 19 6703.50 7534.57Kuparuk D 20 6715.50 7546.57Kupamk C 21 6774.50 7605.57LCU 22 6800.50 7631.57KupamkA 23 6864.50 7695.57TMLV CAS hNG DETAILS No. TVD MD Name Size I 2849.50 2850.77 7 5/8" 7.62 2 6964.49 7795.56 5 1/2" x 3 1/2" 5.50 WELl, DE TAILS Name ~N-S ~EI'-W Ncslhm,8 Easlin8 Latirm~., l.oogimde Slot Plan S-108155.44 1007.84 5980715.00 618930.00 70°21'21.473N 149 O2'02.Sg2W TARGET DETAILS Name ]WD ~N'-S-F.~-WN,n~hin8Easang Shape S-10g SB OA 511430 1614.40 492.42 5982336.87 619396.69 Polygon S-10g II 6715_q0 217525648.37 5982900.08 619M3.71 Polygon SECTION DETAILS Sec MD Inc Azi TVD N/S E/W DLeg TFace VSec Target 1 64.50 0.00 0.00 64.50 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 800.00 5.00 90.00 799.37 0.00 21.80 1.00 90.00 6.23 4 1300.00 0.00 15.54 1298.73 0.00 43.61 1.00 180.00 12.46 5 2900.00 0.00 15.54 2898.73 0.00 43.61 0.00 0.00 12.46 6 4056.25 46.25 15.54 3933.44 425.73 161.96 4.00 15.54 454,26 7 5764.18 46.25 15.54 5114.50 1614.40 492.42 0.00 0.00 1687.79 S-108 SB OA 8 5958.18 46.25 15.54 5248.65 1749.41 529.96 0.00 0.00 1827.90 9 7114.43 0.00 0.00 6283.36 2175.14 648.32 4.00 180.00 2269.70 10 7546.57 0.00 0.00 6715.50 2175.14 648.32 0.00 0.00 2269.70 S-108 TI 11 7695.57 0.00 0.00 6864.50 2175.14 648.32 0.00 0.00 2269.70 12 7795.57 0.00 0.00 6964.50 2175.14 648.32 0.00 0.00 2269.70 ti 7 5/8" start Dir 4°/100' . _ 2900'MD, 2898.73'TVD MD, 3933.44' TVD All TVD depths are ssTVD plus 64.5' for RKBE. ~000 ~tart Dh- 4°/100': 5958.18' MD, 5248.65'TVD ~ 1/'l~f~"~e3pt}/2:'~795.57' MD, 6964.5' TVD 500 3000 4500 6000 7500 9000 10500 12000 13500 Vertical Section at 16.60° [ 1500~in] COMPAaNY DETAILS BP Amoco Calculation I'defl~clc Minmann Cuv, aun'e Eh'or S)~em: ISCWS^ Scan Me~l~k High Side. ~ A~math Error Surface: EIIJI~ical ~ Casing Wamin~ Method: Rules Based REFERENCE INFORMATION Cc-oxrlmat¢ i2'~E) Reference: Well Cemte: plan S-10g. Tree North Vertical (IVD) Refexence: N-9ES 643 Sec6on (VS) Reference: Slot - (0.00,0.00J Meas~l Depth Refe~nce: N-9ES 64.5 Calculalion Melhod: Minimum Curvalure WELL DETAILS Name -N~-S ~E/-W Northing Easing Latitude Longitude Slot Plan S-10gl55.44 1~07.g4 5980715.00 618930.00 70~21'21.473N 149~02'02~82W TARGET DETAILS Name TVD *N~-S ~E/-W No~hing Easling Shape S-108 SB OA 5114.50 1614.40 492.42 5982336.87 619396.69 Polygon S-108 TI 671530 2175.23 648.37 5982900.08 619543.71 Polygon SECTION DETAILS Sec MD Inc Azi TVD N/S E/W DLeg TFace VSe¢ Target 1 64.50 0.00 0.00 ~4.50 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 -:::1.00 0.00 0.00 0.00 0.00 fl.00 3 800.00 5.00 90.00 --}.37 0.00 21.80 1.00 90.00 i.23 4 1300.00 0.00 15.54 ' -~.73 0.00 43.61 1.00 180.00 ' ~.46 5 2900.00 0.00 15.54 .'~ ,4.73 0.00 43.61 0.00 0.00 '..46 6 4056.25 46.25 15.54 .... 1.44 425.73 161.96 4.00 15.54 ' ~.26 7 5764.18 46.25 15.54 -. t.50 1614.40 492.42 0.00 0.00 ~ '.79 S-108 SB OA 8 5958.18 46.25 15.54 - ' :'~.65 1749.41 529.96 0.00 0.00 ~ - ~.91 9 7114.43 0.00 0.00 ' TM 1.36 2175.14 648.32 4.00 180.00 - ~.70 10 7546.57 0.00 0.00 ,- '/.50 2175.14 648.32 0.00 0.00 - ' L70 S-108 TI 11 7695.57 0.00 0.00 .~- L50 2175.14 648.32 0.00 0.00 }.70 12 7795.57 0.00 0.00 - t.50 2175.14 648.32 0.00 0.00 '- L70 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1924.50 1925.77 Base Permafrost 2 2194.50 2195.77 SV5 3 2394.50 2395.77 SV4 4 2749.50 2750.77 SV3 5 2904.50 2905.77 SV2 6 3244.50 3249.22 SV1 7 3584.50 3615.11 UG4 8 3634.50 3672.70 UG4A 9 3949.50 4079.47 UG3 10 4474.50 4838.68 UGI 1 4779.50 5279.74 Ma (Top Shrader Bluff) 12 4999.50 5597.88 WS2 (lq sands) 13 5109.50 5756.95 WS1 (O sands) 14 5389.50 6149.15 Obfbase 15 5389.50 6149.15 T. Colville/base Skrader 16 6379.50 7210.57 CMl (Colville Shales K-10) 17 6584.50 7415.57 THRZ 18 6703.50 7534.57 BHRZ (Kalubik) 19 6703.50 7534.57 Kupamk D 20 6715.50 7546.57 Kupamk C 21 6774.50 7605.57 LCU 22 6800.50 7631.57 KuparukA 23 6864.50 7695.57 TMLV CASING DETAILS No. TVD MD Name Size I 2849.50 2850.77 7 5/8" 7.62 2 6964.49 7795.56 5 I/2" x 3 1/2" 5.50 ANNOTATIONS No. TVD MD Annotation 1 300.00 300.00 Start Dir 1°/100': 300' MD, 300'TVD 2 1298.73 1300.00 EndDir : 1300'MD, 1298.73'TVD 3 2898.73 2900.00 Start Dir 4°/100': 2900' MD, 2898.73'TVD 4 3933.44 4056.25 End Dir : 4056.25'MD, 3933.44' TVD 5 5248.65 5958.18 Start Dh'4°/100': 5958.18' MD, 5248.65'TVD 6 6283.36 7114.43 End Dir : 7114.43' MD, 6283.36' TVD 7 6964.49 7795.56 Total Depth: 7795.57' MD, 6964.5' TVD SUR¥~Y PROGRAM Depth Fm Depth To Survey~plan Tool 6450 500.00 PI. anneck S-log ~p03 VI CB~3YRO-SS 500.00 779537 Planned: S-10g gpO3 VI MWD Plan: S-I08 v. p03 (PI~ S-lOg/Pla, S-10g) Created By: Ken Allen ])ale: 4/3Q001 Checked: I)atc: Reviewed: Date: · ~pproveo: i~azc: 2400- 2000 1600 1200 _ 800 400-- 0 -400 5 1/2" x 3 I/2" t 6500 ~ Total Depth 7795.57' MD 6964.5' TVD .... _. . _,l [ / l-'~i End Dir : 7114.4Y MD. 6283.36' TVD ...... ..... / / ~ SlartDir4°/100':5958.18'MD,5248.65'TVD / / / / /-//__ / All TVD depths are ssTVD plus 64.5' for R E. ............... 7 5/8":~~ 29~~73'IVD "{~" End Dir : 1300' MD, 1298.73' TVD St~ ~r 1°/100': 300' MD, 300'TVD .... I .... I .... I .... I .... 0 400 800 1200 1600 West(-)/East(+} [400fl/in] BP Amoco Planning Report - Geographic Company: BP Amoco Date: 4/3/2001 Time: 08:30:21 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan S-108, True North Site: PBS Pad Vertical (TVD) Reference: N-9ES 64.5 Well: Plan S-108 Section (VS) Reference: Well (0.00E,0.00N,16.60Azi) Wellpath: Plan S-108 Plan: S-108 wp03 ...................... ~- _ ~ .... -__~_ ............... ~--_ ............. .__: ......... ._+_.__ ........... .~_:~_-_ ...... ~ ....__ ..... __ .......................... ~- ............................. Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: PBS pad TR-12-12 UNITED STATES · North Slope Site Position: Northing: 5980854.54 ft Latitude: 70 21 23.002 N From: Map Easting: 617919.92 ft Longitude: 149 2 32.343 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.90 dec Well: Plan S-108 Slot Name: Surface Position: +N/-S -155.44 ft Northing: 5980715.00 ft Latitude: 70 21 21.473 N +E/-W 1007.84 ft Easting: 618930.00 ft Longitude: 149 2 2.882 W Position Uncertainty: 0.00 ft Reference Point: +N/-S -155.44 ft Northing: 5980715.00 ft Latitude: 70 21 21.473 N +E/-W 1007.84 ft Easting: 618930.00 ft Longitude: 149 2 2.882 W Measured Depth: 64.50 ft Inclination: 0.00 de9 Vertical Depth: 64.50 ft Azimuth: 0.00 de9 Wellpath: Plan $-108 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: N-9ES Height 64.50 ft Above System Datum: Mean Sea Level Magnetic Data: 3/22/2001 Declination: 26.56 de9 Field Strength: 57463 nT Mag Dip Angle: 80.78 dec Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 16.60 Plan: S-108 wp03 Date Composed: 4/2/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information 64.50 0.00 0.00 64.50 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 800.00 5.00 90.00 799.37 0.00 21.80 1.00 1.00 0.00 90.00 1300.00 0.00 15.54 1298.73 0.00 43.61 1.00 -1.00 -18.00 180.00 2900.00 0.00 15.54 2898.73 0.00 43.61 0.00 0.00 0.00 0.00 4056.25 46.25 15.54 3933.44 425.73 161.96 4.00 4.00 0.00 15.54 5764.18 46.25 15.54 5114.50 1614.40 492.42 0.00 0.00 0.00 0.00 5958.18 46.25 15.54 5248.65 1749.41 529.96 0.00 0.00 0.00 0.00 7114.43 0.00 0.00 6283.36 2175.14 648.32 4.00 -4.00 -1.34 180.00 7546.57 0.00 0.00 6715.50 2175.14 648.32 0.00 0.00 0.00 0.00 7695.57 0.00 0.00 6864.50 2175.14 648.32 0.00 0.00 0.00 0.00 7795.57 0.00 0.00 6964.50 2175.14 648.32 0.00 0.00 0.00 0.00 S-108 SB OA S-108 T1 Section 1 : Start ,' inCl:; : Azim TVD:, ::,:+NIls:, i,i:+ :.'VS: . ' deC ' deC' :: ':':~ ' ,ft:.i :. '::".c 64.50 0.00 0.00 64.50 0.00 0.00 0.00 100.00 0.00 0.00 100.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 deg/lOOft :deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 4/3/2001 Time: 08:30:21 Page: 2 Field: Pmdhoe Bay Co-ordinate(NE) Reference: Well: Plan S-108, True North Site: PBS Pad Vertical (TVD) Reference: N-gES 64.5 Well: Plan S-108 Section (VS) Reference: Well (0.00E,0.00N,16.60Azi) Wellpath: Plan S-108 Plan: S-108 wp03 Section 2: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/lOOft deg/lOOft deg 400.00 1.00 90.00 399.99 0.00 0.87 0.25 1.00 1.00 0.00 0.00 500.00 2.00 90.00 499.96 0.00 3.49 1.00 1.00 1.00 0.00 0.00 600.00 3.00 90.00 599.86 0.00 7.85 2.24 1.00 1.00 0.00 0.00 700.00 4.00 90.00 699.68 0.00 13.96 3.99 1.00 1.00 0.00 0.00 800.00 5.00 90.00 799.37 0.00 21.80 6.23 1.00 1.00 0.00 0.00 : Section 3: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft deg/100ft deg 900.00 4.00 90.00 899.06 0.00 29.65 8.47 1.00 -1.00 0.00 180.00 1000.00 3.00 90.00 998.87 0.00 35.75 10.21 1.00 -1.00 0.00 180.00 1100.00 2.00 90.00 1098.78 0.00 40.11 11.46 1.00 -1.00 0.00 180.00 1200.00 1.00 90.00 1198.74 0.00 42.73 12.21 1.00 -1.00 0.00 180.00 1300.00 0.00 15.54 1298.73 0.00 43.61 12.46 1.00 -1.00 0.00 -180.00 Section 4: Start ft dog d°g ft , ff ft ft deg/lOOff deg/looft deg/ioOft deg 1400.00 0.00 15.54 1398.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 1500.00 0.00 15.54 1498.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 1600.00 0.00 15.54 1598.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 1700.00 0.00 15.54 1698.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 1800.00 0.00 15.54 1798.73 0.00 43.61 12.46 0.00 0.00 0.00 15,54 1900.00 0.00 15.54 1898.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2000.00 0.00 15.54 1998.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2100.00 0.00 15.54 2098.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2200.00 0.00 15.54 2198.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2300.00 0.00 15.54 2298.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2400.00 0.00 15.54 2398.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2500.00 0,00 15.54 2498.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2600.00 0.00 15.54 2598.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2700.00 0.00 15.54 2698.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2800.00 0.00 15.54 2798.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 2900.00 0.00 15.54 2898.73 0.00 43.61 12.46 0.00 0.00 0.00 15.54 Section 5: Start 3000.00 4.00 15.54 2998.65 3.36 44.54 15.95 4.00 4.00 0.00 0.00 3100.00 8.00 15.54 3098.08 13.43 47.34 26.40 4.00 4.00 0.00 0.00 3200.00 12.00 15.54 3196.54 30.16 52.00 43.76 4.00 4.00 0.00 0.00 3300.00 16.00 15.54 3293.55 53.46 58.48 67.94 4.00 4.00 0.00 0,00 3400.00 20.00 15.54 3388.64 83.23 66.75 98.83 4.00 4.00 0.00 0.00 3500.00 24.00 15.54 3481.34 119.31 76.79 136.28 4.00 4.00 0.00 0.00 3600.00 28.00 15.54 3571.20 161.54 88.53 180.10 4.00 4.00 0.00 0.00 3700.00 32.00 15.54 3657.78 209.70 101.92 230.08 4.00 4.00 0.00 0.00 3800.00 36.00 15.54 3740.67 263.56 116.90 285.98 4.00 4.00 0.00 0.00 3900.00 40.00 15.54 3819.46 322.87 133.39 347.52 4.00 4.00 0.00 0,00 4000.00 44.00 15.54 3893.75 387.32 151.31 414.41 4,00 4.00 0.00 0.00 4056.25 46.25 15.54 3933.44 425.73 161.96 454.26 4.00 4.00 0.00 0.00 Section 6: Start 4100.00 46.25 15.54 3963.69 456.18 170.43 485.86 0.00 0.00 0.00 0.00 4200.00 46.25 15.54 4032.85 525.77 189.78 558.08 0.00 0.00 0.00 0.00 4300.00 46.25 15.54 4102.00 595.37 209.13 630.30 0.00 0.00 0.00 0.00 4400.00 46.25 15.54 4171.15 664.97 228.49 702.53 0.00 0.00 0.00 0.00 4500.00 46.25 15.54 4240.30 734.56 247.84 774.75 0.00 0.00 0.00 0.00 4600.00 46.25 15.54 4309.45 804.16 267.19 846.98 0.00 0.00 0.00 0.00 BP Amoco ,ii' Planning Report - Geographic Company: BP Amoco Date: 4/3/2001 Time: 08:30:21 Page: 3 : Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan S-108, True North Site: PBS Pad Vertical (TVD) Reference: N-9ES 64.5 Well: Plan S-108 Section (VS) Reference: Well (0.00E,0.00N,16.60Azi) Wellpath: Plan S-108 Plan: S-108 wp03 Section 6: Start , MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft degllOOft deg/lOOft deg/lOOft deg 4700.00 46.25 15.54 4378.60 873.75 286.54 919.20 0.00 0.00 0.00 0.00 4800.00 46.25 15.54 4447.75 943.35 305.90 991.42 0.00 0.00 0.00 0.00 4900.00 46.25 15.54 4516.90 1012.94 325.25 1063.65 0.00 0.00 0.00 0.00 5000.00 46.25 15.54 4586.06 1082.54 344.60 1135.87 0.00 0.00 0.00 0.00 5100.00 46.25 15.54 4655.21 1152.14 363.96 1208.10 0.00 0.00 0.00 0.00 5200.00 46.25 15.54 4724.36 1221.73 383.31 1280.32 0.00 0.00 0.00 0.00 5300.00 46.25 15.54 4793.51 1291.33 402.66 1352.54 0.00 0.00 0.00 0.00 5400.00 46.25 15.54 4862.66 1360.92 422.01 1424.77 0.00 0.00 0.00 0.00 5500.00 46.25 15.54 4931.81 1430.52 441.37 1496.99 0.00 0.00 0.00 0.00 5600.00 46.25 15.54 5000.96 1500.11 460.72 1569.22 0.00 0.00 0.00 0.00 5700.00 46.25 15.54 5070.11 1569.71 480.07 1641.44 0.00 0.00 0.00 0.00 5764.18 46.25 15.54 5114.50 1614.40 492.42 1687.79 0.00 0.00 0.00 0.00 Section 7: Start ft deg deg ft ft ft' ft degllOOft deg/100ft deg/lOOft deg 5800.00 46.25 15.54 5139.27 1639.33 499.35 1713.67 0.00 0.00 0.00 0.00 5900.00 46.25 15.54 5208.42 1708.92 518.71 1785.89 0.00 0.00 0.00 0.00 5958.18 46.25 15.54 5248.65 1749.41 529.96 1827.90 0.00 0.00 0.00 0.00 Section 8: Start .... : ......... hi~ ............ :-:'i;;;;i'-'i ...... :":~i~ ...................... :;~i~i'"-! ......... 7','~'~i~'~:'"-:::"i"-'~E)~ ........... i":"-'"'~'' ............ :':ii"i~L~ ............. ~'iid"i" ......... ~r-~": ............. 6000.00 44.58 15.54 5278.01 1778.10 537.94 1857.68 4.00 -4.00 0.00 180.00 6100.00 40.58 15.54 5351.63 1843.28 556.06 1925.31 4.00 -4.00 0.00 180.00 6200.00 36.58 15.54 5429.79 1903.34 572.76 1987.65 4.00 -4.00 0.00 180.00 6300.00 32.58 15.54 5512.11 1958.01 587.97 2044.38 4.00 -4.00 0.00 180.00 6400.00 28.58 15.54 5598.19 2007.01 601.59 2095.23 4.00 -4.00 0.00 180.00 6500.00 24.58 15.54 5687.60 2050.10 613.58 2139.95 4.00 -4.00 0.00 180.00 6600.00 20.58 15.54 5779.92 2087.08 623.86 2178.33 4.00 -4.00 0.00 180.00 6700.00 16.58 15.54 5874.69 2117.77 632.39 2210.18 4.00 -4.00 0.00 180.00 6800.00 12.58 15.54 5971.45 2142.02 639.13 2235.34 4.00 -4.00 0.00 180.00 6900.00 8.58 15.54 6069.73 2159.70 644.05 2253.68 4.00 -4.00 0.00 180.00 7000.00 4.58 15.54 6169.05 2170.73 647.12 2265.13 4.00 -4.00 0.00 180.00 7100.00 0.58 15.54 6268.93 2175.06 648.32 2269.63 4.00 -4.00 0.00 180.00 7114.43 0.00 0.00 6283.36 2175.14 648.32 2269.70 4.00 -4.00 0.00 -180.00 Section 9: Start :' ::,: deg:;i : deg : i,:: ,::ft:: ~: :, :i i::: '?,ft : ::,:!:: fi:: ::: 7300.00 0.00 0.00 6468.93 2175.14 648.32 2269.70 0.00 0.00 0.00 0.00 7400.00 0.00 0.00 6568.93 2175.14 648.32 2269.70 0.00 0.00 0.00 0.00 / 7500.00 0.00 0.00 6668.93 2175.14 648.32 2269.70 0.00 0.00 0.00 0.00 / 7546 57 0 O0 0 O0 6715 50 2175.14 648 32 2269 70 0 O0 0 O0 0 O0 0 O0 / / ............. : .................. '_' ....................... " :_' ....................... ........................ : .................... " ........... : ..................... t : : L Section 10: Start ":'T~:'"'i":~-i~:ii":'i'"- i'~ InelAzim +Ni-s irt: :i:aeg ~eg ft : ft 7695 57 0 O0 0 O0 6864 50 2175 14 648 32 2269 70 0 O0 0 O0 0 O0 0 O0 I ......... : t ......................... : _'_ : ........................... : ...................... : : .................. ' .......... ' _ ' Section 11 : Start '~ ......... : :h-~':~ '~'""~ iii;::'"~:9-/; ~--::: :¢~):~ :'""i:-'~i':~:7 i~-'-: !":~'-':':~ :~ ~'--,- "!'-::?bi;~: ': :-::"'/i ii'ii~'!':-:":"-¥-~; ii";' ":"'""~-~--6"::","::-':~-'' :? '::"-'~" ':" ..... ; 'ft : deg , deg : : ff : , :ft , :'ft:: :,: :ft :' deg/lO0 .: ........... ::, ......... ....... :_.:.. --. ........ i_...-:~:--:~.L.::.._.-._,,:.L ..... :..._ = __.::.--._-£2 ........ i .:._~.L ....... ~.--__:._..L:.~.,:.2:____=L:_.: ._::L_.:__ .L .............. ........... __~__..=._:..: ....... 7700.00 0.00 0.00 6868.93 2175.14 648.32 2269.70 0.00 0.00 0.00 0.00 7795.57 0.00 0.00 6964.50 2175.14 648.32 2269.70 0.00 0.00 0.00 0.00 BP Amoco Planning Report- Geographic Company: BP Amoco Date: 4/3/2001 Time: 08:30:21 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan S-108, True North Site: PBS Pad Vertical (TVD) Reference: N-9ES 64.5 Well: Plan S-108 Section (¥S) Reference: Well (0.00E,0.00N,16.60Azi) Wellpath: Plan S-108 Plan: S-108wp03 Survey Map Map <-- Latitude ---> <m Longitude ---> MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec fl deg deg ff ff ff ff ff 64.50 0.00 0.00 64.50 0.00 0.00 5980715.00 618930.00 70 21 21.473 N 149 2 2.882 W 100.00 0.00 0.00 100.00 0.00 0.00 5980715.00 618930.00 70 21 21.473 N 149 2 2.882 W 200.00 0.00 0.00 200.00 0.00 0.00 5980715.00 618930.00 70 21 21.473 N 149 2 2.882 W 300.00 0.00 0.00 300.00 0.00 0.00 5980715.00 618930.00 70 21 21.473 N 149 2 2.882 W 400.00 1.00 90.00 399.99 0.00 0.87 5980715.01 618930.87 70 21 21.473 N 149 2 2.856 W 500.00 2.00 90.00 499.96 0.00 3.49 5980715.06 618933.49 70 21 21.473 N 149 2 2.779 W 600.00 3.00 90.00 599.86 0.00 7.85 5980715.12 618937.85 70 21 21.473 N 149 2 2.652 W 700.00 4.00 90.00 699.68 0.00 13.96 5980715.22 618943.95 70 21 21.473 N 149 2 2.474 W 800.00 5.00 90.00 799.37 0.00 21.80 5980715.35 618951.80 70 21 21.473 N 149 2 2.244 W 900.00 4.00 90.00 899.06 0.00 29.65 5980715.47 618959.64 70 21 21.473 N 149 2 2.015 W 1000.00 3.00 90.00 998.87 0.00 35.75 5980715.57 618965.74 70 21 21.473 N 149 2 1.836W 1100.00 2.00 90.00 1098.78 0.00 40.11 5980715.64 618970.10 70 21 21.473 N 149 2 1.709W 1200.00 1.00 90.00 1198.74 0.00 42.73 5980715.68 618972.72 70 21 21.473 N 149 2 1.632W 1300.00 0.00 15.54 1298.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 1400.00 0.00 15.54 1398.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 1500.00 0.00 15.54 1498.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 1600.00 0.00 15.54 1598.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 1700.00 0.00 15.54 1698.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 1800.00 0.00 15.54 1798.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 1900.00 0.00 15.54 1898.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2000.00 0.00 15.54 1998.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2100.00 0.00 15.54 2098.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2200.00 0.00 15.54 2198.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2300.00 0.00 15.54 2298.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2400.00 0.00 15.54 2398.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2500.00 0.00 15.54 2498.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2600.00 0.00 15.54 2598.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2700.00 0.00 15.54 2698.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2800.00 0.00 15.54 2798.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 2900.00 0.00 15.54 2898.73 0.00 43.61 5980715.69 618973.60 70 21 21.473 N 149 2 1.607W 3000.00 4.00 15.54 2998.65 3.36 44.54 5980719.07 618974.48 70 21 21.506 N 149 2 1.579W 3100.00 8.00 15.54 3098.08 13.43 47.34 5980729.18 618977.12 70 21 21.605 N 149 2 1.497W 3200.00 12.00 15.54 3196.54 30.16 52.00 5980745.98 618981.51 70 21 21.770 N 149 2 1.362W 3300.00 16.00 15.54 3293.55 53.46 58.48 5980769.38 618987.62 70 21 21.999 N 149 2 1.172W 3400.00 20.00 15.54 3388.64 83.23 66.75 5980799.27 618995.42 70 21 22.292 N 149 2 0.930W 3500.00 24.00 15.54 3481.34 119.31 76.79 5980835.50 619004.88 70 21 22.647 N 149 2 0.637W 3600.00 28.00 15.54 3571.20 161.54 88.53 5980877.91 619015.95 70 21 23.062 N 149 2 0.294W 3700.00 32.00 15.54 3657.78 209.70 101.92 5980926.27 619028.57 70 21 23.535 N 149 1 59.902W 3800.00 36.00 15.54 3740.67 263.56 116.90 5980980.36 619042.69 70 21 24.065 N 149 I 59.464W 3900.00 40.00 15.54 3819.46 322.87 133.39 5981039.92 619058.24 70 21 24.648 N 149 1 58.982W 4000.00 44.00 15.54 3893.75 387.32 151.31 5981104.64 619075.13 70 21 25.282 N 149 1 58.458W 4056.25 46.25 15.54 3933.44 425.73 161.96 5981143.21 619085.17 70 21 25.660 N 149 I 58.147W 4100.00 46.25 15.54 3963.69 456.18 170.43 5981173.79 619093.15 70 21 25.960 N 149 I 57.899W 4200.00 46.25 15.54 4032.85 525.77 189.78 5981243.68 619111.39 70 21 26.644 N 149 1 57.333W 4300.00 46.25 15.54 4102.00 595.37 209.13 5981313.56 619129.64 70 21 27.328 N 149 1 56.768W 4400.00 46.25 15.54 4171.15 664.97 228.49 5981383.45 619147.88 70 21 28.013 N 149 1 56.202W 4500.00 46.25 15.54 4240.30 734.56 247.84 5981453.34 619166.13 70 21 28.697 N 149 1 55.636W 4600.00 46.25 15.54 4309.45 804.16 267.19 5981523.23 619184.37 70 21 29.382 N 149 1 55.070W 4700.00 46.25 15.54 4378.60 873.75 286.54 5981593.12 619202.61 70 21 30.066 N 149 1 54.504W 4800.00 46.25 15.54 4447.75 943.35 305.90 5981663.01 619220.86 70 21 30.751 N 149 1 53.938W 4900.00 46.25 15.54 4516.90 1012.94 325.25 5981732.89 619239.10 70 21 31.435 N 149 1 53.372W 5000.00 46.25 15.54 4586.06 1082.54 344.60 5981802.78 619257.35 70 21 32.120 N 149 1 52.806W 5100.00 46.25 15.54 4655.21 1152.14 363.96 5981872.67 619275.59 70 21 32.804 N 149 1 52.240W i' BP Amoco Planning Report- Geographic Company: BP Amoco Date: 4/3/2001 Time: 08:30:21 Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: Plan S-108, True North Site: PBS Pad Vertical (TVD) Reference: N-9ES 64.5 Well: Plan S-108 Section (VS) Reference: Well (0.00E,0.00N,16.60Azi) Wellpath: Plan S-108 Plan: S-108 wp03 Survey Map Map <--- Latitude --> <-- Longitude ---> MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ff deg deg ff ff ff ff 5200.00 46.25 15.54 4724.36 1221.73 383.31 5981942.56 619293.83 70 21 33.489 N 149 1 51.675-w 5300.00 46.25 15.54 4793.51 1291.33 402.66 5982012.45 619312.08 70 21 34.173 N 149 1 51.109 W 5400.00 46.25 15.54 4862.66 1360.92 422.01 5982082.34 619330.32 70 21 34.858 N 149 1 50.543 W 5500.00 46.25 15.54 4931.81 1430.52 441.37 5982152.22 619348.57 70 21 35.542 N 149 1 49.977 W 5600.00 46.25 15.54 5000.96 1500.11 460.72 5982222.11 619366.81 70 21 36.226 N 149 1 49.411 W 5700.00 46.25 15.54 5070.11 1569.71 480.07 5982292.00 619385.05 70 21 36.911 N 149 1 48.845 W 5764.18 46.25 15.54 5114.50 1614.40 492.42 5982336.88 619396.69 70 21 37.350 N 149 1 48.484 W 5800.00 46.25 15.54 5139.27 1639.33 499.35 5982361.91 619403.22 70 21 37.596 N 149 1 48.281 W 5900.00 46.25 15.54 5208.42 1708.92 518.71 5982431.80 619421.47 70 21 38.280 N 149 1 47.715 W 5958.18 46.25 15.54 5248.65 1749.41 529.96 5982472.46 619432.08 70 21 38.678 N 149 I 47.386 W 6000.00 44.58 15.54 5278.01 1778.10 537.94 5982501.27 619439.60 70 21 38.960 N 149 1 47.152 W 6100.00 40.58 15.54 5351.63 1843.28 556.06 5982566.72 619456.68 70 21 39.601 N 149 1 46.622 W 6200.00 36.58 15.54 5429.79 1903.34 572.76 5982627.03 619472.43 70 21 40.192 N 149 1 46.134 W 6300.00 32.58 15.54 5512.11 1958.01 587.97 5982681.93 619486.76 70 21 40.730 N 149 1 45.689 W 6400.00 28.58 15.54 5598.19 2007.01 601.59 5982731.14 619499.60 70 21 41.212 N 149 1 45.291 W 6500.00 24.58 15.54 5687.60 2050.10 613.58 5982774.41 619510.90 70 21 41.635 N 149 1 44.940 W 6600.00 20.58 15.54 5779.92 2087.08 623.86 5982811.55 619520.60 70 21 41.999 N 149 1 44.639 W 6700.00 16.58 15.54 5874.69 2117.77 632.39 5982842.37 619528.64 70 21 42.301 N 149 1 44.390W 6800.00 12.58 15.54 5971.45 2142.02 639.13 5982866.71 619535.00 70 21 42.539 N 149 1 44.193W 6900.00 8.58 15.54 6069.73 2159.70 644.05 5982884.47 619539.63 70 21 42.713 N 149 1 44.049W 7000.00 4.58 15.54 6169.05 2170.73 647.12 5982895.55 619542.52 70 21 42.822 N 149 1 43.959W 7100.00 0.58 15.54 6268.93 2175.06 648.32 5982899.90 619543.66 70 21 42.864 N 149 1 43.924W 7114.43 0.00 0.00 6283.36 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 I 43.924W 7200.00 0.00 0.00 6368.93 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 1 43.924W 7300.00 0.00 0.00 6468.93 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 1 43.924W 7400.00 0.00 0.00 6568.93 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 1 43.924W 7500.00 0.00 0.00 6668.93 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 1 43.924W 7546.57 0.00 0.00 6715.50 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 1 43.924W 7600.00 0.00 0.00 6768.93 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 1 43.924W 7695.57 0.00 0.00 6864.50 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 1 43.924W 7700.00 0.00 0.00 6868.93 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 I 43.924W 7795.57 0.00 0.00 6964.50 2175.14 648.32 5982899.98 619543.65 70 21 42.865 N 149 1 43.924W TREE: 3-1/8" - 5M ClW L-80 WELLHEAD: 11" - 5M FMC G5 S-108 Proposed Completion Cellar Elevation = 36.3' RKB = 7O' 7-5/8", 29.7 #/ft, L-80, BTC I 2850' 3-1/2" 9.3# IBT-Mod L-80 5-1/2", 15.5 #/ft, L-80, BTC- Mod (reduced clearance cplg) 3-1/2" 'X' Landing Nipple with 2.813" seal bore. I 2200' I 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. TVD Size Valve Type 3000 1" RP shear 4500 1" DV 1 jt above 1" DV seal assy 3-1/2" 'x' Landing Nipple with 2.813" seal bore 5080' 3-1/2" Seal Asembly, 12' 3-1/2" PBR 5-1/2"x3-1/2" XO placed at +/-150' above the Schrader Ma Sand 5118' 5130' 3-1/2" 'X' Landing Nipple with 2.813" seal bore (@ base OBf) Marker joint w/RA tag (1 jt below base OBf) 6155' 6195' Marker joint w/RA tag (150' above top Kuparuk) 3-1/2" 'X' Landing Nipple with 2.813" seal bore (50' above top Kup) I I 7400' 7500' Plug Back Depth 7755' 3-1/2",9.3 #~t,L-80,1BT-Mod 7840' Date Rev By Comments 5/17/01 PGS Proposed Seal Bore Completion Microbore with 5-1/2"x3-1/2" tapered Iongstring Polaris WELL: Producer APl NO: 50-029-????? BP Alaska Drilling & Wells Subject: Date: Tue, 5 Jun 2001 14:50:54 -0500 From: "Wesley, Dave E" <WesleyDE@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Smith, Phil G (FAIR)" <SmithPGl@BP.com> Mr. Maunder In response to the issues outlined regarding the application for Permit for the S-108, I talked with the geologists to confirm estimated pore pressure. The 10.3 ppg is the correct value. The 10.7 was a typo error. In talking with Chris Avant at Dowell, he said the 1.2 cf/sk is correct based upon the slurry being a GasBLOK system. I corrected the typo error in the hazards section referring to S-107i, rather than S-108. I've included an attachment of the document. Please advise of any further actions we need to take, <<S-108 Revised Permit to Drill 4.ZIP>> Thanks, Dave Wesley, Jr. Operations Drilling Engineer Alaska Drilling & We. lis 907 564. 57'73 Office 907 440 8631 Cell 907 564 4040 Fax wesleyde@bp.com [~-~S-108 Revised Permit to Drill 4.ZIP Name: S-108 Revised Permit to Drill 4.ZIP Type: Zip Compressed Data (application/x-zip-compressed) Encoding: base64 I of 1 6/6/01 9:49 AM DATE I CHECK NO. H 189908 VENDOR ALASKADILA O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 051401 CK051401A 1OO. OO 100. OO PYMT COMMENTS: Pern~it to Drill Fee HANDLIN~ INST: S/H - Terrie Hobble X46~8 3- o6 HE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DE$CRIBED ABOVE. ~ll[e]l~!II ] 100. O0 ~-00o O0 BP EXPLORATION, (ALASKA)INC. RO. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56~389 412 No. H 189908 CONSOLIDATED COMMERCIAL ACCOUNT 00189908 PAY To Th e :ORDER '0~ ALASKA OIL AND OAS :CONSERVATION COMM,ISS.I:ON 333 WEST 7TH AVENUE SUITE 100: .... ." !..,:.,,.'DATE'::',:: .AMOUNT I 05/1 '6'/0 i ::':; :::'?~',::1 ,i NOOn'VALID ANCHORAGE Al4 995;01 ," &SqqOS," m'_Om~ & E)Oq,O, qSm'- o0,qm~m., WELL PERMIT CHECKLIST COMPANY .Z~,,/e) WELL NAME FIELD & POOL ~' ~"/'C3 ~ 2.. CD INIT CLASS i~p__.,Z~,/ /-~ ~') ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... GEOLOGY ABPR DATE 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to *.-~"~--;~,,) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. ANNULAR DISPOSAL35. With proper cementing records, this plan PROGRAM: exp dev ~ redrll __ serv __ wellbore seg __ann. disposal para req __ GEOL AREA ~' ? ¢3 UNIT# ./~/C,~'_,~ ON/OFF SHORE APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N 31. Data presented on potential overpressure zones ....... Y//N. 32. Seismic analysis of shallow gas zones ............. , 33. Seabed condition survey (if off-shore) N,/,Y N 34. Contact name/phone for weekly progress reports [exploratory o N (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: M/,~~~ '"""'"~J M H Commentsllnstructions: Z -I- c:\msoffice\wordian\diana\checklist (rev. 11/01//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPE .NDIXi .. NO special'effort has been made to chronologically organize this category of information. ,o s-108.tapx Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mort Sep 24 15:26:17 2001 Reel Header Service name ............. LISTPE Date ..................... 01/09/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/09/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD S-108 500292302100 BP Exploration (Alaska) Inc. Sperry Sun 24-SEP-01 MWD RUN 1 MWD RUN 2 AK-MM-Ii098 AK-MM-ii098 S. HUIBAN S. HUIBAN L. VAUGHAN L. VAUGHAN 35 12N 12E 4511 4497 .00 70.25 36.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 20.000 112.0 2ND STRING 6.750 7.625 2857.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING Page 1 s-108.tapx GEIGER-MUELLER TUBE DETECTORS. 3. MWD RUN 2 IS DIRECTIONAL WITH DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), STABILIZED LITHO-DENSITY (SLD), AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). 4. DEPTH SHIFTING IS WAIVED PER THE E-MAIL OF 9/12/2001 FROM D. SCHNOOR OF BP EXPLORATION (ALASKA) INC. LOG AND HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 5. MWD RUNS 1-2 REPRESENT THE MWD DATA FOR WELL S-108 WITH API# 50-029-23021-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7850' MD, 7029' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE PARAMETERS USED IN NEUTRON / POROSITY LOG CALCULATIONS: HOLE SIZE: 6.75" MUD WEIGHT: 10.4 - 10.6 PPG MUD FILTRATE SALINITY: 600 - 1200 PPM CHLORIDE FORMATION WATER SALINITY: 50,000 PPM CHLORIDE FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH ROP .0 GR 62.0 NCNT 2780.5 STOP DEPTH 785O.5 7801.5 7754.5 Page 2 NPHI 2780.5 7754.0 FCNT 2780.5 7754.5 PEF 2795.0 7769.0 DRHO 2796.5 7769.0 RHOB 2796.5 7769.0 FET 2833.5 7808.5 RPD 2833.5 7808.5 RPM 2833.5 7808.5 RPS 2833.5 7808.5 RPX 2833.5 7808.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) s-108.tapx EQUIVALENT UNSHIFTED DEPTH MERGE BASE 2874.5 7850.5 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 .0 MWD 2 2785.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 RHOB MWD G/CC 4 1 68 32 9 DRHO MWD G/CC 4 1 68 36 10 PEF MWD B/E 4 1 68 40 11 NPHI MWD PU 4 1 68 44 12 NCNT MWD CP30 4 1 68 48 13 FCNT MWD CP30 4 1 68 52 14 Name Service Unit Min Max Mean Nsam DEPT FT 0 7850.5 3925.25 15702 ROP MWD FT/H 0 2378.1 132.099 15559 GR MWD API 5.81 458.28 74.3549 15480 RPX MWD OHMM 0.23 650.68 9.67403 9951 RPS MWD OHMM 0.29 1533.37 9.60746 9951 RPM MWD OHMM 0.33 2000 11.0926 9951 RPD MWD OHMM 0.29 2000 13.7029 9951 FET MWD HOUR 0.1675 67.9458 1.20596 9951 RHOB MWD G/CC -0.02 3.234 2.26799 9930 DRHO MWD G/CC -2.202 0.763 0.0786731 9930 PEF MWD B/E 1.18 16.93 5.21464 9949 NPHI MWD PU 12.03 163.46 33.6179 9948 NCNT MWD CP30 11977.5 33317.7 20444.6 9949 FCNT MWD CP30 51.3 784.5 273.179 9949 Page 3 First Reading 0 0 62 2833.5 2833.5 2833.5 2833.5 2833.5 2796.5 2796.5 2795 2780.5 2780.5 2780.5 Last Reading 7850 5 7850 5 7801 5 7808 5 7808 5 7808 5 7808 5 7808 5 7769 7769 7769 7754 7754.5 7754.5 First Reading For Entire File .......... 0 Last Reading For Entire File ........... 7850.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 s-108.tapx Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP .0 2874.5 GR 62.0 2831.0 $ LOG HEADER DATA DATE LOGGED: 12-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 2875.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .3 MAXIMUM ANGLE: 5.2 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02051HGV6 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 2857.0 # BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G): 9.20 MUD VISCOSITY S): 245.0 MUD PH: 9.3 MUD CHLORIDES PPM): 600 FLUID LOSS (C3 : 9.5 RESISTIVITY (OHMM} AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 .000 .0 Page 4 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 s-108.tapx .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 0 2874.5 1437.25 5750 ROP MWD010 FT/H 0 494.56 137.654 5607 GR MWD010 API 13.26 115.73 50.7294 5539 First Reading For Entire File .......... 0 Last Reading For Entire File ........... 2874.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 0 0 62 Last Reading 2874.5 2874.5 2831 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/24 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # Page 5 FILE SUMPLARY VENDOR TOOL CODE NCNT NPHI FCNT PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 2780 5 2780 5 2780 5 2795 0 2796 5 2796 5 2831.5 2833.5 2833.5 2833.5 2833.5 2833.5 2875.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: s-108.tapx STOP DEPTH 7754 5 7754 0 7754 5 7769 0 7769 0 7769 0 7801 5 7808 5 7808 5 7808 5 7808 5 7808 5 7850 5 18-JUN-01 Insite 66.16 Memory 7850.O .3 47.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER CTN COMP THERMAL NEUTRON PB01993HAGR4 SLD STABILIZED LITHO DEN PB01993HAGR4 DGR DUAL GAMMA RAY PB01993HAGR4 EWR4 ELECTROMAG. RESIS. 4 PB01993HAGR4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin 6.750 LSND 10.50 45.0 9.0 7OO 3.5 2.600 78.0 1.680 124.3 2.400 68.0 3.500 68.0 Sandstone 2.65 Page 6 s-lOS.tapx Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name DEPT ROP GR RPX RPS RPM RPD FET RHOB DRHO PEF NPHI NCNT FCNT Service Order Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 MWD020 FT/H 4 1 68 4 2 MWD020 API 4 1 68 8 3 MWD020 OHMM 4 1 68 12 4 MWD020 OHMM 4 1 68 16 5 MWD020 OHMM 4 1 68 20 6 MWD020 OHMM 4 1 68 24 7 MWD020 HOUR 4 1 68 28 8 MWD020 G/CC 4 1 68 32 9 MWD020 G/CC 4 1 68 36 10 MWD020 B/E 4 1 68 40 11 MWD020 PU 4 1 68 44 12 MWD020 CP30 4 1 68 48 13 MWD020 CP30 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET RHOB DRHO PEF NPHI NCNT FCNT Service Unit Min Max Mean Nsam FT 2780.5 7850.5 5315.5 10141 MWD020 FT/H 2.25 2378.1 128.969 9952 MWD020 API 5.81 458.28 87.5187 9941 MWD020 OHMM 0.23 650.68 9.67403 9951 MWD020 OHMM 0.29 1533.37 9.60746 9951 MWD020 OHMM 0.33 2000 11.0926 9951 MWD020 OHMM 0.29 2000 13.7029 9951 MWD020 HOUR 0.1675 67.9458 1.20596 9951 MWD020 G/CC -0.02 3.234 2.26799 9930 MWD020 G/CC -2.202 0.763 0.0786731 9930 MWD020 B/E 1.18 16.93 5.21464 9949 MWD020 PU 12.03 163.46 33.6179 9948 MWD020 CP30 11977.5 33317.7 20444.6 9949 MWD020 CP30 51.3 784.5 273.179 9949 First Reading For Entire File .......... 2780.5 Last Reading For Entire File ........... 7850.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/09/24 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 First Reading 2780.5 2875 2831.5 2833 5 2833 5 2833 5 2833 5 2833 5 2796 5 2796 5 2795 2780.5 2780.5 2780.5 Last Reading 785O 5 7850 5 7801 5 7808 5 7808 5 7808 5 7808 5 7808 5 7769 7769 7769 7754 7754.5 7754.5 Physical EOF Tape Trailer Service name .... , ......... LISTPE Date ..................... 01/09/24 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/09/24 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Page 7 s-108.tapx Comments ................. ST$ LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 8