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Home My WebLink About204-139Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 12/12/2025 InspectNo:susJDH251026124340 Well Pressures (psi): Date Inspected:10/26/2025 Inspector:Josh Hunt If Verified, How?Other (specify in comments) Suspension Date:5/2/2008 #307-370 Tubing:390 IA:380 OA:31 Operator:Hilcorp North Slope, LLC Operator Rep:Ryan Holt Date AOGCC Notified:10/24/2025 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT E-18B Permit Number:2041390 Wellhead Condition Light surface rust on the wellhead and valves. The SSV was closed upon arrival, opened to get tubing pressure. No leaks or drips visable. All valves and gauges were in good condition and functioning. Surrounding Surface Condition Inside the well house was clean. Snow preventing a surrounding gravel pad inspection. Approved Sundry (325-525) for P&A - work delayed; reason for the late inspection. Condition of Cellar Dry gravel, no trash or debris. Comments Location was verified with location map and wellhouse sign. Supervisor Comments Photos (10) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, December 12, 2025           2025-1026_Suspend_PBU_E-18B_photos_jh Page 1 of 5 Suspended Well Inspection – PBU E-18B PTD 2041390 AOGCC Inspection # susJDH251026124340 Photos by AOGCC Inspector J. Hunt 10/26/2025 2025-1026_Suspend_PBU_E-18B_photos_jh Page 2 of 5 2025-1026_Suspend_PBU_E-18B_photos_jh Page 3 of 5 2025-1026_Suspend_PBU_E-18B_photos_jh Page 4 of 5 Tree Cap Pressure Gauge 2025-1026_Suspend_PBU_E-18B_photos_jh Page 5 of 5 IA Pressure Gauges OA Pressure Gauges 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU E-18B Pull WRP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-139 50-029-20654-02-00 10375 Conductor Surface Intermediate Liner Liner 8327 80 2655 10187 360 448 10100 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" 8084 32 - 112 31 - 2686 29 - 10216 9856 - 10216 9926 - 10374 32 - 112 31 - 2681 29 - 8180 7888 - 8180 7943 - 8326 None 2670 4760 5410 10530 10100 5380 6870 7240 10160 None 5-1/2" 17# x 4-1/2" 12.6# L80 27 - 9965 Structural 4-1/2" Baker SAB Packer 9825 7863 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) 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: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028304 27 - 7974 N/A N/A Well Not Online 0 550 0 0 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 9825, 7863 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:27 pm, Aug 28, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.28 13:21:08 - 08'00' Torin Roschinger (4662) DSR-9/11/25J.Lau 11/4/25 RBDMS JSB 090425 ACTIVITY DATE SUMMARY 7/6/2025 ***WELL S/I ON ARRIVAL*** RAN 8' x 2-1/2" PUMP BAILER (msfb), DRIFT FREELY TO WRP @ 9834' MD(recovered ~2 tbs of plastic, good metal marks on bailer bottom) RAN 3.69'' WRP PULLING SLEEVE(colletless) TO WRP @ 9847' SLM (No psi change, some metal marks) RAN 3'' x 10' P. BAILER w/3.68'' TRASH COLLECTOR BTM TO WRP @ 9847' SLM (Bailer empty,3 ttls sheared) RAN 4-1/2" GR, 3.69" WRP PULLING TOOL (Removed Collet). TO WRP @ 9847' SLM (No psi change) ***WSR CONT. ON 07-07-2025*** 7/7/2025 TFS 4 Assist S/Line with Injectivity Test ***Job Canceled*** 7/7/2025 ***WSR CONT. FROM 07-06-2025*** RAN 4-1/2" GR, WRP PULLING SLEEVE w/COLLET. LATCH 3.69" WRP @ 9847' SLM/9834' MD (Shear GR after 20 mins of jarring) RAN 4-1/2" GS, PULL WRP UP TO 9676' SLM, (After ~30 mins of jarring, hit 1850# OJ lick & appear to part wire, pull out recover all wire) RAN 3.62" CENT, 2' x 1-7/8" STEM, 3.70" CENT, 3.63" LIB, TAGGED ROPE SOCKET @ 9661' SLM (Impression of clean rope socket) RAN KJ, 3.60" BELLGUIDE, 3" EXT, 2-1/2" JU.. LATCHED TOOLSTRING @ 9768' SLM, PUH INTO PATCH @ 9649' SLM (1 light oj lick shear JU) RAN KJ, 3.60" BELLGUIDE, 3" EXT, 2-1/2" JD. LATCHED TOOLSTRING @ 9649' SLM, JAR 1 HOUR, NO MOVMENT RAN KJ, 3.60" BELLGUIDE, 3" EXT, 2-1/2" JU. LATCHED TOOLSTRING @ 9649' SLM (jar down 10 mins shear GS & Recover Toolstring) RAN 4-1/2'' GS TO WRP @ 9680' SLM, JAR 1 HOUR, NO MOVEMENT ***WSR CONT. ON 07-08-2025*** 7/8/2025 ***CONT. FROM 07, 07, 2025*** RAN 4-1/2'' GS TO WRP @ 9680' SLM (Jar a total of 3 hours) RAN 4-1/2" GR TO WRP @ 9680' SLM, BEAT WRP OUT OF PATCH(unable to shear GR below patch, pull into patch & shear off, leave wrp @ 9680' slm) GET CALL TO RIG DOWN & MOVE TO HIGHER PRIORITY JOB ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 8/3/2025 ***WELL S/I ON ARRIVAL*** JARRED UP FOR 3 HOURS, AND DOWN FOR 1.5 HOURS TOTAL ON .125, W/ NO MOVEMENT. SWAPPED TO .160 ***CONTINUED ON 8-4-25*** 8/4/2025 T/ I / O = 400/ 50/ 350 Temp = S/I ( TFS U4, Assist S-Line with load and MIT-T ) Pumped 11 BBLS of Crude down TBG to pressure up against plug. confirmed .2 gal per minute LLR @ 2000 psi, SL went in to pull plug and reset, ***WSR continues on 8/5/25*** Daily Report of Well Operations PBU E-18B Daily Report of Well Operations PBU E-18B 8/4/2025 ***CONTINUED FROM 8-3-25*** JARRED ON WRP @ 9,963' SLM FOR 2 HOURS PULLED WRP FROM 9,963' SLM. MISSING 1-3/4 ELEMENTS MADE 1 ATTEMPT TO FISH ELEMENTS. COULDN'T GET PAST TOP OF PATCH @ 9,652' MD DRIFTED W/ 2.74" CENTRALIZER & 1.75" SAMPLE BAILER TO CIBP @ 10,100' MD THUNDERBIRD PRESSURED TUBING UP TO 2,000 PSI. ESTABLISHED A LLR OF .21 GPM/.005 BPM. ATTEMPTED TO SET 3 1/2" DDIC PLUG BODY @ 10,085' SLM. UNABLE TO SHEAR GS W/ 1.5 HRS OF JARRING. SAND IN PLUG BODY. RAN 10' x 2.5" PUMP BAILER; UNABLE TO WORK INTO LINER STUB @ 9913' SLM. ***CONTINUED ON 8-5-25*** 8/5/2025 ***CONTINUED FROM 8-4-25*** ATTEMPTED TO SET 3 1/2" AD2 STOP. UNABLE TO WORK INTO LINER STUB @ 9926' MD. MADE MULTIPLE 2.25" PUMP BAILER RUNS FROM 10,085' TO 10,087' SLM, METAL MARKS ON LAST RUN RAN 3-1/2" DDIC PLUG BODY. SAT DOWN 100' HIGH @ 9,981' SLM. UNABLE TO PASS. SET PLUG BODY RECOVERED PLUG BODY FROM 9,981' SLM (missing element) THUNDERBIRD PERFORMED A GOOD PT ON TUBING TO 2,000 PSI THUNDERBIRD PERFORMED A PASSING IA TEST TO 2,500 PSI ***WELL LEFT S/I ON DEPARTURE*** 8/5/2025 ***WSR cont from 8-4-25*** TFS U4, (Assist S-line W/MIT-T) Initial WHP T/IA/OA= 400/50/350, MIT-T PASSED to 1985 psi, Max applied pressure 2000 psi, Target pressure 1750 psi, Pressured TBG to 2017 psi with 2 BBLS of Crude. MIT-T lost 21 psi in 1st 15 min and 11 psi in 2nd 15 min. For a total of 32 psi during 30 min test, Bled TBG bled down to 500 psi. MIT-IA PASSED to 2375 psi. Max applied pressure 2500 psi. Target pressure 2250 psi. Pressured IA 2506 psi with 8 BBLS of Crude. MIT-IA lost 21 psi in 1st 15 min and 13 psi in 2nd 15 min test. Bled IA down 50 psi. Well left in control of Pollard S-Line. FWHP's = 400/ 50/ 350 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU E-18B Reservoir Abandonment Compliance Plug Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-139 50-029-20654-02-00 341J ADL 0028304 10375 Conductor Surface Intermediate Liner Liner 8327 80 2655 10187 360 448 10100 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" 8084 32 - 112 31 - 2686 29 - 10216 9856 - 10216 9926 - 10374 2370 32 - 112 31 - 2681 29 - 8180 7888 - 8180 7943 - 8326 None 2670 4760 5410 10530 10100 5380 6870 7240 10160 None 5-1/2" 17# x 4-1/2" 12.6# L80 27 - 9965 Structural 4-1/2" Baker SAB Packer No SSSV Installed 9825, 7863 Date: Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY 9/11/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:52 pm, Aug 28, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.08.28 13:24:14 - 08'00' Torin Roschinger (4662) 325-525 DSR-9/9/25 X *AOGCC witnessed tag TOC and CMIT-TxIA to 2500 psi. *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement with lateral plug placed in confining zone per program. A.Dewhurst 03SEP25 X June 1, 2026 10-407 JJL 9/4/25 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.09.10 08:49:30 -08'00'09/10/25 RBDMS JSB 091125 Res AB Sundry Well: E-18B PTD: 204-139 API: 50-029-20654-02 Well Name:E-18B Permit to Drill Number:204-139 Well Type SU API Number:50-029-20654-02 Job Scope:Res Abandon Reg.Approval Req’d?Yes Current Status:Not Operable, Offline Date Reg. Approval Rec’vd:TBD Estimated Start Date:9/11/2025 Estimated Duration:4days Regulatory Contact:Abbie Barker 907-564-4915 First Call Engineer:Finn Oestgaard 907-564-5026 Second Call Engineer:Oliver Sternicki 907-564-4891 Current Bottom Hole Pressure:3250 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2370 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:300 psi – 8/5/25 after SL pulled off the well Min ID:2.992” Top of 3-1/2” Liner @ 9,926’ Max Angle:54 deg @ 7,000’ MD Top of Sag:10,381’ MD Suspension Extension: Due to coil tubing staffing constraints we are unable to complete work to get required reservoir plugs in place in E- 18B, Y-25A, S-14A and W-09A prior to the required suspension renewal submission date of 8/28/25. Due to this we are requesting a temporary extension of the existing suspensions on the condition that we can show we are progressing this work by the suspension renewal submission due date of 8/28/25. To comply with this requirement, we are planning to have Sundries for this work submitted prior to 8/28/25. Well History: E-18B is suspended well to be reservoir abandoned with future utility to be rotary sidetracked. The well was suspended in 2008 after the 2nd attempt to sidetrack failed. The initial attempt was halted when the 3-1/2" liner was discovered to be collapsed just outside the window in the Kingak after the cement job. A 2nd CTD attempt was considered, however after 3 chemical cuts a cut and pull resulted in only 10’ of liner attached to the deployment sleeve being recovered pushing the KO point to the upper Kingak which is inaccessible to CTD and all operations on the well were shutdown. Most recent PTs: MIT-T to 1985 psi 8/5/25 MIT-IA to 2375 psi 8/5/25 Notes on 3-1/2” liner between the stub and CIBP: - 9,926’ – 8/9/05 – Chem Cut (current liner stub) - 9,990’ - 8/8/05 – Chem Cut - 9,991’ - 8/5/25 – SL noted some sort of restriction, unable to get past with plug - 9,998’ - 10,000’ - 7/15/05 Tubing Punch - 10,060’ – 8/7/05 – Chem Cut - 10,086’ – 12/24/04 SCMT TOC - 10,097 – 8/5/25 2.25 pump bailer recovered 3 cups of sand/scale/cement/metal shavings, metal marks on inside of muleshoe. Confining Zone: The confining zone is the Kingak, starting @ TSAG @ 10,381’ to TKNG @ 9,645’ Annular Cement: 9-5/8” Casing – Estimated TOC @ 6,816’ – based off volumetrics assuming 30% washout 1450 ft 3 Class G. No indications of issues from drilling reports. 7” Liner – Estimated to be fully cemented from 11,265 to TOL @ 9,856’ – Rig cemented with 432 ft 3 Class G w/ 18% salt – Volume pumped ~ 95% excess assuming 30% washout for open hole section. Res AB Sundry Well: E-18B PTD: 204-139 API: 50-029-20654-02 3-1/2” Liner – CTD pumped total of 11 bbls 15.9 ppg cement, 8.4 bbls behind pipe. 12/24/04 SCMT @ 10,086’ MD. Target TOC in the 5-1/2 tubing & annulus = 9,645’ MD (top of the Kingak) Current Status: E-18B is currently not operable and offline. Objectives: The intent of this program is to place a cement plug from 9,645’ – 9,926’, resulting in a 104’ (9,822’ – 9,926’) cement plug additional to a 155’ (9,645’ – 9,800’) across all lateral strings of pipe in the confining zone. Variance Request: A variance is requested to the plugging requirements under 20 AAC 25.112(c). A lateral plug will be placed from 9,645’ – 9,926’MD, across the confining interval and will provide isolation of the reservoir and prevent vertical movement of fluid within the wellbore. Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. Slickline: 1. Drift for Tubing Punches Eline: 1. Tubing Punch 4-1/2” right below packer 9,822’ - 9,827’ Tie into SCMT 12\24\2004 2. Tubing Punch 5-1/2” right above packer 9,775’ – 9,780’ Tie into Caliper 9/20/2004 Fullbore: 1. Displace IA with 350 bbls of 1% KCL through tubing punch above packer taking returns up the tubing. This will allow slight overflushing of IA interval to be cemented (332 bbls - tubing punch @ 9,780’ to 2,200’) 2. Follow displacement with diesel FP (97 bbls - 2,200’ to surface) Slickline 1. Pull DMY GLV @ 9,176’ GLM #3 Coil Cementing: 1. RIH with nozzle & tag liner stub, PUH ~ 5’ 2. Pump per following pump schedule a. 230 bbls 1% KCl (tubing displacement to surface) Pumping @ base of cement interval ensures tubing tail is flushed effectively. b. 5 bbl FW spacer c. ~16 bbls cement d. 5 bbl FW spacer e. Displace with diesel f. 51 bbl diesel FP Once cement is at the nozzle lay in cement while PUH at rate required to fill the 7” liner & tubing taking returns 1:1 from the coil backside, once at 9,856’ (top of 7” liner) adjust rates to accommodate to 9-5/8” casing & continue to POH while laying in cement w/ 1:1 returns. Target TOC = 9,645’ Once 5 bbl FW spacer has been pumped POOH while pumping diesel for coil volume. Once nozzle is @ 2,200’ pump remaining diesel required minus coil displacement to leave well with 51 bbls of diesel total in the tubing and continue to POOH while displacing remaining diesel required. Once out of hole equalize T& IA with a jumper to keep T & IA equalized. – Objective is to have diesel from surface to 2,200’ & KCL from 2,200’ to TOC in both IA & T. Res AB Sundry Well: E-18B PTD: 204-139 API: 50-029-20654-02 Cement Volumes: x 4.5” tubing from 9,805’ – 9,926’ MD: 121’ x 0.0152 bpf = 1.9 bbls x 4.5”x 7” annulus from 9,856’ – 9,926’ MD: 70’ x 0.0186 bpf = 1.3 bbls x 4.5”x 9.625” annulus from 9,825’ – 9,856’ MD: 31’ x 0.0536 bpf = 1.7 bbls x 5.5” tubing from 9,645 – 9,805’: 160’ x 0.0232 = 3.7 bbls x 5.5” x 9.625” annulus from 9,645’ - 9,805’: 160’ x 0.0438 = 7.0 bbls Total cement: 15.6 bbls Cement Type/weight:Class G 15.8 ppg or similar Bottom hole static temp:192°F Thickening Time:6 hours (WSL discretion to adjust) Slickline 1. WOC 5 days, Drift and tag TOC –AOGCC Witnessed Fullbore 1. WOC 5 days, CMIT-TxI to 2750 psi max applied pressure, 2500 psi target pressure –AOGCC Witnessed Attachments: x Caliper & SCMT Logs x Current Wellbore Schematic x Proposed Wellbore Schematic x Sundry Change Form Res AB Sundry Well: E-18B PTD: 204-139 API: 50-029-20654-02 Tubing Stub & 4-1/2” Tubing tail overlap ~ 17’ Res AB Sundry Well: E-18B PTD: 204-139 API: 50-029-20654-02 Current Schematic Res AB Sundry Well: E-18B PTD: 204-139 API: 50-029-20654-02 Proposed Schematic Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: August 28, 2025Subject: Changes to Approved Sundry Procedure for Well E-18BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y- 25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) Date:Wednesday, August 20, 2025 2:28:33 PM From: Lau, Jack J (OGC) Sent: Wednesday, August 20, 2025 11:05 AM To: Torin Roschinger <torin.roschinger@hilcorp.com>; dave.roby@alska.gov; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y-25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) Good day Torin, Hilcorp’s request to extend the completion of the reservoir abandonments for the suspended wells listed below until June 1, 2026, is approved. The AOGCC appreciates Hilcorp’s effort to progress this activity before the June 1, 2025 date. E-18B (PTD#204139) Y-25A (PTD#208140) S-14A (PTD#204071) W-09A (PTD#204102) Jack From: Torin Roschinger <torin.roschinger@hilcorp.com> Sent: Wednesday, August 20, 2025 6:04 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; dave.roby@alska.gov; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Cc: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Finn Oestgaard - (C) <Finn.Oestgaard@hilcorp.com>; Hunter Gates <Hunter.Gates@hilcorp.com>; Tyson Shriver <Tyson.Shriver@hilcorp.com>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: Extension Request for Suspended Well Reservoir Abandonments, June 1, 2026 - E-18B (PTD#204139), Y-25A (PTD#208140), S-14A (PTD#204071), W-09A (PTD#204102) is safe. Good morning Jack, Earlier this summer Hilcorp requested permission from the AOGCC to move the following suspended well’s reservoir abandonments out to Q1/Q2 2026 due to the high rig activity and the inability to add well trained and competent crews to keep up with the work. The AOGCC granted permission, but we didn’t land on a specific date. I would like to propose that these wells all be completed by June 1, 2026 to allow time in Q2 should Q1 have similar inclement weather as it was 2 years ago and very little work was able to get executed January-March. Please note that while Hilcorp is requesting permission to extend these reservoir abandonments until June 1, 2026, it is our full intention to continue working with our service vendors this Fall to obtain crews/equipment to execute this work well before the requested extension date of June 1st. Please let me know if you approve this request. Suspended Wells under this request for Reservoir Abandonment extension: E-18B (PTD#204139) Y-25A (PTD#208140) S-14A (PTD#204071) W-09A (PTD#204102) Please let me know if you have any question. Thank you, Torin Roschinger Hilcorp Energy Alaska Prudhoe Bay West - Operations Manager c. 406 570 9630 Torin.roschinger@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU E-18B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-139 50-029-20654-02-00 10375 Conductor Surface Intermediate Liner Liner 8327 80 2655 10187 360 448 9834 20" x 30" 13-3/8" 9-5/8" 7" 3-1/2" 7870 32 - 112 31 - 2686 29 - 10216 9856 - 10216 9926 - 10374 32 - 112 31 - 2681 29 - 8180 7888 - 8180 7943 - 8326 None 2670 4760 5410 10530 9834, 10100 5380 6870 7240 10160 None 5-1/2" 17# x 4-1/2" 12.6# L80 27 - 9965 Structural 4-1/2" Baker SAB Perm Packer 9825 7863 Torin Roschinger Operations Manager Andrew Ogg andrew.ogg@hilcorp.com 907.659.5102 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) 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: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028304 27 - 7974 N/A N/A Suspended N/A 13b. Pools active after work:PRUDHOE OIL 9825, 7863 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:55 pm, Aug 20, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.20 09:55:31 - 08'00' Torin Roschinger (4662) WCB 10-2-2024 DSR-8/21/24 RBDMS JSB 082824 ACTIVITY DATE SUMMARY 7/22/2024 T/I/O = 0/75/300. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Austin McLeod. Pictures taken. SV, WV, SSV = C. MV = O. IA & OA = OTG. 10:00. Daily Report of Well Operations PBU E-18B Reviewed By: P.I. Suprv Comm ________ :ZϬϴͬϯϬͬϮϬϮϰ /ŶƐƉĞĐƚEŽ͗ƐƵƐ^DϮϰϬϳϮϮϭϴϯϳϰϰ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϳͬϮϮͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗ƵƐƚŝŶDĐ>ĞŽĚ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨǇŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϱͬϮͬϮϬϬϴ η ϯϬϳͲϯϳϬ dƵďŝŶŐ͗Ϭ /͗ϳϱ K͗ϯϬϬ KƉĞƌĂƚŽƌ͗,ŝůĐŽƌƉEŽƌƚŚ^ůŽƉĞ͕>> KƉĞƌĂƚŽƌZĞƉ͗ŶĚƌĞǁKŐŐ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϳͬϭϲͬϮϬϮϰ dǇƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗^ƵďƐĞƋƵĞŶƚ tĞůůEĂŵĞ͗WZh,KzhE/dͲϭϴ WĞƌŵŝƚEƵŵďĞƌ͗ϮϬϰϭϯϵϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ Η&ƵůůΗƚƌĞĞ͘^^sǁĂƐĐůŽƐĞĚ͘KƉĞŶĞĚƚŽŐĞƚƉƌĞƐƐƵƌĞ͘&ůĂŶŐĞŽĨĨƚƌĞĞŝŶƐƚƌƵŵĞŶƚĨůĂŶŐĞĚǁͬŶĞĞĚůĞǀĂůǀĞ͘ůůǀĂůǀĞƐ ŽƉĞƌĂďůĞ͘'ŽŽĚĐŽŶĚŝƚŝŽŶ͘ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ ůĞĂŶƉĂĚŐƌĂǀĞů͘&ůŽǁůŝŶĞƌĞŵŽǀĞĚ͘ ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ ůĞĂŶͬĚĂŵƉŐƌĂǀĞůͲŶŽƐŚĞĞŶƐ͘ ŽŵŵĞŶƚƐ WĂĚŵĂƉƵƐĞĚ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ EŽŝƐƐƵĞƐ͖WŚŽƚŽƐ;ϭϬͿĂƚƚĂĐŚĞĚ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗^ƵŶĚƌǇ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ &ƌŝĚĂǇ͕ƵŐƵƐƚϯϬ͕ϮϬϮϰ 9 9 9 9 9 9 9 9 9 9 2024-0722_Suspend_PBU_E-18B_photos_am Page 1 of 5 Suspended Well Inspection – PBU E-18B PTD 2041390 AOGCC Inspection # susSAM240722183744 Photos by AOGCC Inspector A. McLeod 7/22/2024 2024-0722_Suspend_PBU_E-18B_photos_am Page 2 of 5 2024-0722_Suspend_PBU_E-18B_photos_am Page 3 of 5 2024-0722_Suspend_PBU_E-18B_photos_am Page 4 of 5 Tubing pressure IA and OA pressures 2024-0722_Suspend_PBU_E-18B_photos_am Page 5 of 5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Cr7 1, r 1. Operations Performed I Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations w .,- ❑ 6 kr Qa'.'d4 Suspend ❑ Perforate 11 OtherStimulate ❑ Alter Casing 11ChangeA Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number: 204-739 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 1 6, API Number: 50-029-20654-02-00 7. Property Designation (Lease Number). ADL 028304 8: Well Name and Number: PBU E -18B 9. Logs (List logs and submit electronic and panted data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11, Present Well Condition Summary: Total Depth: measured 10375 feet Plugs measured 9834, 10100 feet true vertical 8327 feet Junk measured None feet Effective Depth: measured 9834 feet Packer measured 9825 feet true vertical 7870 feet Packer true vertical 7863 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" x 30" 32-112 32-112 Surface 2655 13-3/8" 31 -2686 31 -2681 5380 2670 Intermediate 10187 9-5/8" 29-10216 29-8180 6870 4760 Liner 360 7' 9856-10216 7888-8180 7240 5410 Liner 448 3-1/2" 9926-10374 7943-8326 Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) 5-1/2" 17# x 4-1/2' 12.6# L-80 27-9965 27-7974 Packers and SSSV (type, measured and 4-1/2" Baker SAB Perm Packer 9825 7863 true vertical depth) 12. Stimulation orcement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mct Water -Bbl Casing Pressure Tubing Pressure Prior to well Operation: Suspended Subsequent to operation: 14. Attachments (required per 20 MC 25.070,26 071. a 25.285) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C, 0. Exempt: N/A Authorized Name: Lastufka, Joseph N Contact Name: MontgomeryTravis J Authorized Title: IM Speci js Contact Email: Travis.MontgomervObp.com Authorized Signature: Date: - 4 'Q Contact Phone: +1 907 564 4127 Form 10-404 Revised 04/2017�� /�� per/ BBDMS � SEP > > 7n10 Submit Original Only TWO = SSV/250/230. Temp = SI. Pre SU well inspections. No flowline or AL. Wellhouse sign installed. 8/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. T/I/O = LOTO/245/245. Temp = SI. WHPs (AOGCC Suspended well inspection). State witnessed by Brian Bixby. Wellhouse clear of any trash and debris. Took pics. 8/17/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG = 09:50 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: E -18B Field/Pool: Prudhoe Bay/ Prudhoe Oil Permit # (PTD): 2041390 API Number: 50-029-20654-01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 5/2/2008 Surface Location: Section: 6 Twsp: 11N Range: 14E Nearest active pad or road: E Pad Access road Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation 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: ( _Ipn Pad or location surface: Location cleanup needed: �S Pits condition: Surrounding area condition: Water/fluids on pad: Discoloration, Sheens on pad, pits or Samples taken: None Access road condition: Photographs taken (# and 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: C --km^ Cellar description, condtio Rat Hole: Wellhouse or protective ba Well identification sign: Tubing Pressure (or casino Annulus pressures: Wellhead Photos taken (# Work Required: None Operator Rep (name AOGCC Inspector: _ Inspection Date: _ Time of arrival: Site access method fluids: re): Other O sserverr.— None AOGCC Notice Date 8/16/2019 Time of Departure: 09a�S' E -19A 4' E -27A - E-058 - I h'04AeDl .E-35 i 11 -2-0.. K-04APE3. rF-23A li E-AAPE1 1A jE-35U _. h-1PA E -We E-167E-'15AP61 fy�, C.E-75D ,.�. - E-25 EASCPBi _ E_15 K-1'9AL't,K 1d�t E -158P E'1FB >= 15AFEi E„35.,75PE1. _0FC E -029C K_i� _ X-04 F-23. E-35784 1 F-236 E-1� E-179,! - M13 E-38 � E -D54. F- 47A E-20 E-1)5F�17C k-72APE1 i E -13A [ E-1 E -33A _- E-0 E-D2S �� _ E -20B K-USEPE1 C k-12 + r- U01A C K -95B K-ODC. K 1 CPEI C G-01 ! E-33 E-218. C -0tA E29�-,, K-Sa.. -E-i,K ^2uPaz C}91BPBi ^, E-25 2 C. E-38F,p A k.-99AP61 +' G97BP62I LL E-2'1 N -0S'0` I C K -18A CE-37'4iG-018 E_02 _ E -2D K-05CF K-15AL2. E-37APB7 i- C E-9 C E -38A _ -1G32 E-37PB1--�—__ F - 02A;E-42A.P 1 �i E-14:, _ M,OF .T J E- PBI E-25 C E 29C G E-97 E -25A &12A . , GA2E 3 -248. E-23CPE2 C E-14 ( K -20P61 F_-034 4 E-37.itY1 I E-24AP 1 E-156 E-23CPB1 G-31APBA, G31,1�--G-13I E-24 _ _ AC -14C g _ �- K-13 h -0_,8P8.1 _ N;24 fSCRE7Gt�- FIST` CT -2`4- 2 E 117 K -05B K Zvi, 1 E -21A' G-25APB2 E-24AR82 328 11 v Ca -39 E-23AF81 -' '_-• cr398 G-02 Cr3D.A + - E-24AE - E-18 S G1$B ,) t= 15.21A C..amMFB1 G- - _,� C -186P61 _. G<5EP81 . E238- E_fE E -23A E u1 K-1 G-30CPB1 =,G-23A b E-32APB1-_ 5-18 E-32PE1 - L E-iSA r I8 [��---{{{M1 V S + G-02 E 32A Cs -ow C-D8C c- 14B C G -19c Gr' G-23 E32 C-17 F'-1 .= i _ .. .- G-2?.C- A L_ DSCPE7Y �- Ct C-88CPH2 �v17APe2 C -13A G -27B0 G -07A G -28B C -17A C-33PB.1' G -z4 '3 c-D8A-c-Dj8P81 _ ( . 3lyj E -07A E-08 M- � E 044 1 v EA7B E -04A. ^E K -08B ! - E-07APS! -i TAPB2 E-1 4PBi E117 ( E91A '.f_-07E 'E-0tAP81 E-11 y 12 E,L4A KO, Ry �Ay E'S.A ! AD l•'E-01H - -K — - E-34 E -34L1 ` E28 CKE-1�E 1 LEA4 _ !, L: E-01 K1DA F.Dt'CPBI E-1EC �E-3gPS1 k-19 d,VL .ICY-iDAPB�3 �-e K-1(1 PEi. K IOA,PE2 -S88PS2 - - 0 E 12A E-U3APB1 E -19A 4' E -27A - E-058 - I h'04AeDl .E-35 i 11 -2-0.. K-04APE3. rF-23A li E-AAPE1 1A jE-35U _. h-1PA E -We E-167E-'15AP61 fy�, C.E-75D ,.�. - E-25 EASCPBi _ E_15 K-1'9AL't,K 1d�t E -158P E'1FB >= 15AFEi E„35.,75PE1. _0FC E -029C K_i� _ X-04 F-23. E-35784 1 F-236 E-1� E-179,! - M13 E-38 � E -D54. F- 47A E-20 E-1)5F�17C k-72APE1 i E -13A [ E-1 E -33A _- E-0 E-D2S �� _ E -20B K-USEPE1 C k-12 + r- U01A C K -95B K-ODC. K 1 CPEI C G-01 ! E-33 E-218. C -0tA E29�-,, K-Sa.. -E-i,K ^2uPaz C}91BPBi ^, E-25 2 C. E-38F,p A k.-99AP61 +' G97BP62I LL E-2'1 N -0S'0` I C K -18A CE-37'4iG-018 E_02 _ E -2D K-05CF K-15AL2. E-37APB7 i- C E-9 C E -38A _ -1G32 E-37PB1--�—__ F - 02A;E-42A.P 1 �i E-14:, _ M,OF .T J E- PBI E-25 C E 29C G E-97 E -25A &12A . , GA2E 3 -248. E-23CPE2 C E-14 ( K -20P61 F_-034 4 E-37.itY1 I E-24AP 1 E-156 E-23CPB1 G-31APBA, G31,1�--G-13I E-24 _ _ AC -14C g _ �- K-13 h -0_,8P8.1 _ N;24 fSCRE7Gt�- FIST` CT -2`4- 2 E 117 K -05B K Zvi, 1 E -21A' G-25APB2 E-24AR82 328 11 v Ca -39 E-23AF81 -' '_-• cr398 G-02 Cr3D.A + - E-24AE - E-18 S G1$B ,) t= 15.21A C..amMFB1 G- - _,� C -186P61 _. G<5EP81 . E238- E_fE E -23A E u1 K-1 G-30CPB1 =,G-23A b E-32APB1-_ 5-18 E-32PE1 - L E-iSA r I8 [��---{{{M1 V S + G-02 E 32A Cs -ow C-D8C c- 14B C G -19c Gr' G-23 E32 C-17 F'-1 .= i _ .. .- G-2?.C- A L_ DSCPE7Y �- Ct C-88CPH2 �v17APe2 C -13A G -27B0 G -07A G -28B C -17A C-33PB.1' G -z4 '3 c-D8A-c-Dj8P81 _ ( . Lft V. I TREE= CMV63/8" WELLHEAD = FMC ACTUATOR_= _ _ OKB. ELEV = REF ELEV _ _OTS 60_.45' B_F. ELEV= 30.62' KOP = 2600' Max Argle = 54" CW 7000' Datum MD = 7ahm TVD = _ _ 10931' NRnn- RS E-1 / 8 ^ SAFETY NOTES: MAX DLS: 15.4° @ 10244' SUSPENDED VX �Y( 19-5/8" OV WR –I 2581' — 13-3/8' CSG, 72#, L-80 BTRS, D =12.347' 2686' Minimum ID =2.992" @ 9926' TOP 3 -Mu' LNR 21' MERLA TBG PATCH D = 3.75' 9652' - 9673' - 5-1/2' TBG, 17#, L-80 UA S PC, 9805 .0232 bpf, D = 4.892' 4-1/2' WRP(3.69 OD)(OS/02/08) gg34' SPECIAL CLEARANCED I TOP OF 7" LNR I 3-12' LNR STUB (08/09/05)�–{ 9926' 4-1/2" TB, 12.6#, L-80, .0152 bpf, D = 3.958' TOP OF CEMENT (12/24/04 CMT BOND LOG) j0086' .EN 1 MECHANICAL WHIPSTOCK (11/02/(A) 10214' RA TAG 10222' - 2-7/8" LNR STUB (09/17/04) 10254' CSG, 47#, L-80 BTRS, D= 8.681" V, L-80 U4S, .0383 bpf, D = 6.276" PERFORATIONSUMMARY REF LOG: ANGLEATTOPPHff: @' Note: Refer to Production DB for historical cert data -12- SSSV OTIS ROM NP, D = GAS LFT MW NDRR S ST IOD WD DEV TYPE VLV LATCH TORT DATE `"12 2891 2882 13 M IGW DMY RK 0 12WJ03 –11 5119 4594 49 MVIGW CMY W 0 12/22/03 10 6890 5718 53 M IGW DW RK 0 10/14/81 9 6996 5781 54 kTAGW OMY RK 0 10/14/81 8 7871 6355 42 MMIGW DMY RK 0 10/14/81 7 7975 6432 42 MMGW DMTY RK 0 10/14/81 6 8549 6869 38 MMGW OM1' RK 0 10/14/81 5 8656 6953 38 MMGW — RK 0 10/14/81 4 9072 7280 39 MvIGW DMY RK 0 10/14/81 3 9176 7361 39 MMGW DMY RK 0 10/14/81 2 9551 7651 40 Mu1GW DIY RK 0 10/14/81 '1 9656 7731 39 MVAGW DMY W 0 10/14/81 -- VLIVIffI WVt1QL t1Y N11bA TBG PATCH ' GLMS # 11 & # 12 = DCf34DI3D PACKING 9723' 571/2' BKR L SLIDING SLV, ID = 4.562' 9805' TUBING SFA LASSY, D=7 9825' 9-5/8' X 4-1/2' BKR SAB RCI, D= 3.8 9856' 9-5/8'X 7" BKR HYDRO HGR 05/05/08 KJB/PJC w / TRACK, D = 6.25' 9887 4-1/2' OTIS X NP, D = 3.813" 14-1/2" OTS XN NP, D = 3725' 9965' �–�4-i/2"BAKER WLEG,D=3.9: 9940' ELMD TT LOGG®05/03/89 MLLOLT WINDOW (E -18B) 10216-1102211' 10225' CTMD3-1/2' PARI -H)/ DAMAGED LNR �� 10234'MXX3./GR DEPTH LNR, 8.81#, L-80 STL, I 10374' D )pf, = 2.992° DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14!81 ORIGINAL COMPLETION 11!26/07 JSR/PJC DRLG DRAFTCORRECTONS 05/0757 RW CTD SIDETRACK -A" 05/05/08 KJB/PJC SET VVRP 105102/OB) 1U09/04 NORDIC I CTDSOTRCK"B"SUSPENDE 03/10/16 JMD MINOR EDITS 08818/07 G1B/PJC CHEMCUT@9990' 0910/19 JNUJMD ADDED REF, BF ELEV&SUSPB 08/10/07 KSB/PJC PULL DEPLOYSLV 0 9914- 10/25/07 JSR/PJC DRLGDRAFTCORRECTONS PRUDHOE BAY UNIT WELL E -18A PERMIT No: 1970690 API No: 50-029-20654-01 T11 N, R14E, 1853' SNL & 501' WEL BP Explombon (Alaska) Suspended Well Inspection Review Report InspectNo: susBDB190817160435 Date Inspected: 8/17/2019 Inspector: Brian Bixby Type of Inspection: Subsequent Well Name: PRUDHOE BAY UNIT E -18B Date AOGCC Notified: 8/16/2019 Permit Number: 2041390 Operator: BP Exploration (Alaska) Inc. Suspension Approval: Sundry tt 307-370 " Operator Rep: Josh Prowant Suspension Date: 5/2/2008 Wellbore Diagram Avail? ❑� Location Verified? Photos Taken? If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: 245 - BPV Installed? ❑ OA: 245 VR Plug(s) Installed? ❑ Wellhead Condition Good, Flowlines are disconnected. Condition of Cellar Good, No fluids and clean Surrounding Surface Condition Good Comments Wellhead is Locked Out so we didn't get a tubing pressure. Location was verified by pad As -Built Map. Supervisor Comments Photos(3)attached Gl (L INty Monday, September 9, 2019 Suspended Well Inspection — PBU E -18B PTD 2041390 Photos by AOGCC Inspector B. Bixby 8/17/2019 2019-0817_Suspend_PBU_E-18B_photos_bb.docx Pagel of 2 "A L STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM•N • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Sus Well Inspection Rpt Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 204-139 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20654-02-00 7. Property Designation(Lease Number): ADL 0028304 8. Well Name and Number: PBU E-18B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10375 feet Plugs measured 9834/10100 feet N O V 14 2016 true vertical 8327 feet Junk measured feet Effective Depth: measured 9834 feet Packer measured 9804 feetAO G true vertical 7870 feet Packer true vertical 7847 feet C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2658 13-3/8"72#L-80 31 -2689 31-2684 4930 2670 Intermediate 10187 9-5/8"47#L-80 29-10216 29-8180 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: feet True vertical depth: feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"Baker SAB Perm Packer 9804 7847 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: scANNED MAR 3 I20012. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: suspended While D Subsequent to operation: 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development Q 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 ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP Q 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: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ddefaAA, A Phone +1 907 564 4424 Date 11/14/16 Form 10-404 Revised 5/2015 1/77- Z l i(o / /7- RBDMS L ' NOV 1 6 2016 Submit Original Only ,l *2' > 7' • • Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Drill Pad E No 18B Field/Pool: Prudhoe Bay Field/Prudhoe Bay Pool Permit#(PTD): 2041390 API Number: 50029206540200 Operator: BP EXPLORATION (ALASKA) INC Date Suspended 5/2/2008 Surface Location: Section: 6 Twsp: 11N Range: 14E Nearest active pad or road: G 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 Active gravel pad Pad or location surface: Flat Gravel Location cleanup needed Misc. trash behind wellhouse (insulation, wood ect.) Pits condition: Frozen Water, misc. trash, overall good Surrounding area condition: good condition Water/fluids on pad. None Discoloration, Sheens on pad, pits or water: Frozen puddles Samples taken: None Access road condition Good gravel road Photographs taken (#and description): 1-Photo wellhouse 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. Good Condition, Clean, Production Tree. No Flowline outlet blinded Slight Leak on SSV barrel Cellar description, condition, fluids: Gravel Cellar, Small spot of blue goo in cellar, otherwise clean Rat Hole: N/A Wellhouse or protective barriers. Well house in good condition Well identification sign: Yes Tubing Pressure(or casing if no tubing): SSV Closed no panel Annulus pressures: OA=200psi, IA=200psi Wellhead Photos taken (#and description) 2-photos of tree and annuli gauges. 1-photo of SSV barrel Work Required: Clean up misc. trash near reserve pit, Operator Rep (name and signature): Joshua Stephens AOGCC Inspector: Jeff Jones Other Observers: Inspection Date: 10/10/2016 AOGCC Notice Date: 1 /9/2016 Time of arrival: 11:15 AM Time of Departure: 11:35 AM Site access method Pickup Truck • • m a O O O O o co -O „72:m00N if) C N V Cn CO N- U U) O O O O o i co I— V V co c C)) 00 N I� • V O CO N V O O CO N- CO a0 (b a0 N V N- CO c- C7 CO CA N CO (b 00 ▪ I I I I I I CO CO N- (NIN- CT) CO NI- co I� V co N CO C)) N CO N- N- N- CD O CO O V cv CV CO 0 0 0 0) N o o W Q CO (0 r. N C)) LO N ti O CO Cr) N CO CT N CO C)) C)) CA 1- a o OO o 00 o0 O J J CO J J J • d co N N X *k J *k •N V O V N ch N N co I r � O co LO V co p CC) CO O CO CCK) CO ' (O V N- a) N O Cr) V LU CC I- 01 • W 0 U lDu_ Ctr W Z Z_ Z W W W m m Q D H Z Z_ J D U (n z J J • • c 0 CD c a 0 v7 0 0 • (-13- '-E ?� O c 0 0 a) N 0_ C 2 '- N O >- U 0° L E 0 CD 2 < u) Q Q D L = r w Q D a) J � -O m 0 N Q co aJ 0 LL W �p c Q Q W 0 II m . 0 < 0 0 Q. II .� G) 0_ a) E y o H U it CI o0 > oOU a) CO a n Q ccv Q> > v) U) L CO a) CO a o - a IIc..) 7 0 0 U- c>n w Q CD a a >- N • CO m I O 0 4111 • 0 by .�, 0.2 0.1 0 0.2 Miles E-36 '0e-10A `K-0B 5 E-12 h5-10e ✓I(- -K-06D E-38176 13,38 K-IOAP6AK-IOAPB2 X5-0613 c 5-03E ,1E-381782 :(E-09A (E-OSB ••e-09APB1 (E-09 )3-oaAa 1 E-t6APBE-16 t -(K319A ';:E-09CPB1 ;E-092 E-36$ ` 251761 w-04 <E-0� K.'OC,r( Legend E-35 =-358 `-' ;(5-19 "K-19AL1 £-05C E 6A Eo5APB 'K -A Pipelines(General) i.E-AA <E-17A \1303 tt(11(51111.1 :K-048 E-;6N lluIIC-ll >.E-O6 d K-12C /K-12AP61 E-6.333 =- =K-72 Pipelines(Detailed) '5-0981781 l:fG I W PB i _.,_ -5-390 - "K-12CPB2 (El E-21B E-06A K-05DP6: 1,1.E-20A7t-05D K_gA \I .(E-25P62 '<E-39 .:1302 :(E-20 `(E-02A a.E-39A n 12:1,I '£-OO PBI -:1G-1EA-- ---1 linty (G-02A ),E 25 a E-23C .K-05 t'ohm,is ii �<Ir:rail P11511 n5, `(G-02B ...E-248 XE-23CPB2 E-24APB 1 34=24 :E-196 ':K-20178 1 'E 23CP81 %tK-05C K-t 3 3(A-058561 ::G-02 -E-!813 ::5-05A ;:K-29 -ii:3 :'G-25A ?.1<-058 { -75--54 - X(3-25APB2 X6-24APB2' �} } -35.18 (E-23AP61 '/j�t ,,,i', e 5-326 f M 4(� G-25APB1 ¶0-168 1114 i 30A ;'E-'4A 7:13-19 _- 4 (G-25 ,(E-31 >;C-188PB1 Author: :E-18A 335-23 XE-23A ;Irk.; U-30CE-31A 0-230 33-30C PEI ,G-25BPB I 14 November,2016 BP1\catrgl ©BP Exporaeon(Alaska)Inc.Au rights reserved.This map is informational In nature and Is presented without representations or Product of BPXA Atlas Enterprise GIS. alaska- is.b web.b .com warranties as to accuracy,completeness,or use for any purpose P 9 P P TREE= C IW 6 3/8" WE_L.HEAD= FMC • NOTES: MAX OLS:15.4°@ 10244' ACTUATOR= OTIS E-1 8 B OKB_ELEV= 60.45' BF.aEV= 31.72' KOP= 2600' _.. 1996' 1—5-1/2"SSSV OTIS ROM NP,D=4.562" , Max Angle= 54"@ 7000' Datum MD= 10931' GAS LIFT MANS Datum TVD= 8800'SS ST MD TVD DEV TY FE VLV LATCH FORT DATE 9-5/8"DV FKR H 2581' "'12 2891 2882 13 MMIGW DMY RK 0 12/22/03 � � "11 5119 4594 49 MMIGW DMY RIC 0 12/22/03 13-3/8"CSG,72#,L-80 BTRS, D=12.347" H ,___4 2686' 10 6890 5718 53 MMIGW DMY RK 0 10/14/81 L 9 6996 5781 54 MMIGW DMY RK 0 10/14/81 8 7871 6355 42 MIVIGW DMY RK 0 10/14/81 Minimum ID =2.992" @ 9926' I 7 7975 6432 42 MM11GW DMY RK 0 10/14/81 TOP 3-1/2" LNR 6 8549 6869 38 MMGW DMY RK 0 10/14/81 5 8656 6953 38 MMIGW OMY RK 0 10/14/81 4 9072 7280 39 MIRGW OMY RK 0 10/14181 21'MERLA TBG PATO D=3.75" ( 9652'-9673' 3 9176 7361 39 MMIGW DMY RK 0 10/14/81 PATCH U 2 9551 7651 40 MMIGW DMY RK 0 10/14/81 '1 9656 7731 39 MMIGW OMY RK 0 10/14/81 "GLM#1 C OV E�BY ME2LA TBG PATCH 'GLMS#11&#12=EXTE DE)PACK JG I 9723' H 5-112"BKR L SLDNdG SLV,D=4.562" 5-112"TBG,17#,L-80 IJ4S PC, H 9805' 1-- 9805' -TUBS SEAL ASSY,D=? III .0232 bpf,ID=4.892" — 0 R9825' H9-518' X 4-112"BKR SAB PKR,D=3,813- 4-1/2"WF2P(3.69 OD)(05/02/08) —{ 9834' SPECIAL CLEARANCED 9856' —9-5/8"X 7"BKR HYDRO HGR w/TEBACK,D=6.25" TOP OF 7"LNR —{ 9856' 9882' H4-1/2"OTIS X NP,D=3.813" 3-1/2"LNR STUB(08/09/05) —I 9926' 9920' -14-1/2"OTIS XN NP,ID=3.725" 4-1/2"TB,12.6#,L-80,.0152 bpf,D=3.958" —1 9965' 9965' H4-1/2"BAKER VVLEG,D=3.958" TOP OF CBVIBIT(12!24/04 CMT BOND LOG) H 10086' r• 9940' HELM)TT LOGGED 05/03/89 •♦•' ►•4 ►•4 A! GEN 1 MECHANICAL HPSTOCK(11/02/04) —j 10214' ►•�•. �� 10100' 1-13-112"CBP(07/15/05) W RA TAG - 10222' ,'i"p„ Mt L(WT WINDOW(E-18B) 10216'-10221' 2-7/8'LNR STUB(09/17/04) 10254' „•4,.4.4......4 ••4�'li� 10225'CTMD -3-1/2”PARTED/ N 4*: DAMAGED LNR •�4 ►•4 9-5/8"CSG,47#,L-80 BTRS,D=8.681" —1 10377' " , ,* ►�• 10234'MCCLJGR DEPTH ♦4 ♦4 • ►♦ ♦4• ♦4 7'LNR,26#,L-80 U4S,.0383 bpf,D=6.276' 11265' �• i•• iir� �0i ►' PBTD — 10370' iersiii. PERFORATION SUMMARY irsiiii.,!A4 •i111iirii WWI/ REF LOG: 'F". 3-1/2"LNR,8.81#,L 80 STL, H 10374' ANGLE AT TOP PERE: @' illb .0087 bpf,D=2.992" Note:Refer to Ftoduction OB for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 11110 DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 10/14/81 ORIGINAL COMPLETION 08/08/07 GJB/PJC CSA CUT @ 9990" WELL: E-18A 05/07197 RW CTD SIDETRACK"A" 08/10/07 KSB/PJC PULL DEPLOY SLV @ 9914' FERMI-No:'1970690 11/09/04 NORDIC 1 CTD SDTRCK"B"SUSPENDED 10/25/07 JSR/PJC DRUG DRAFT CORRECTIONS AFI No: 50-029-20654-01 07/15/05 RACITLH SET CEP 11/26/07 JSR/PJC DRLG DRAFT CORRECTIONS SEC 6,T11 N,R14E,1853'SNL&501'WE- 07/19/05 WJW TLH CHEW CUT @ 10073' 05/05/08 KJBIPJC SET WRP(05/02/08) 08/07/05 JGMPJC CHEM CUT @ 10060' 03/10/16 JM13 MNJOR EDITS BP Exploration(Alaska) s N • P, k 411P t4 t , t B ► {. 111 , t , t j t , a __ 31 W 3. a. '- I. 0 r-I [ , ,,,,, : .„; .* 1 , , , ..,, 1 ,,, , r. , ::'''''':*.ai' . [- 1 i k . , ,P++ r, p. • 3 wW t•4 • v K: • a 4 • . ,..; ,,,41y / �,. , \ • • ,... , ,,,, . , ., 4 . , ,, , a ,ter C ,. J , � , #4. -f . "+, Ativr1► "1P4SP.^M " le.,,,,P., ,, 4.,0.00,04:. I'lli'7":P4j;P'4sp'T41S,IlrIP:ip;ipll:41:'**'?'IA";Alk':' ''''''/11-''';'4.0,''''''' " , ,; a i''''''''''''''f'ilf411111-'4":„,''/114. 4111'4 :* , i '.- A 1 I p 4,00 a Vie 1 4, . -.1 h a irk , , -,i ! _03 't.'1. - 1 '4 - 1 ` 1 11\ a &� i. 1 6 A • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 10/10/16 Inspector: Jeff Jones Operator: BPXA Well Name: PBU E-18B Oper.Rep: J.Stephens PTD No.: 2041390 Oper.Phone: 659-5766 Location Verified? Yes Oper.Email: ioshua.stephens(rDbp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 05/02/08 Date AOGCC Notified: 10/09/16 - Sundry No.: 307-370 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing N/A ' Photos Taken? Yes IA 200 OA 200 Condition of Wellhead: Good condition.Outlet is blinded,SSV closed,no hydraulics or flowline attached.Slight hydraulic leak @ SSV barrel seal. Condition of Surrounding Surface Location: Frozen level gravel pad with road access.No visible hydrocarbon residue.Small amount of blue grease in cellar. Follow Up Actions Needed: Repair Hydraulic fluid leak @ SSV.Clean up grease in cellar&misc.trash behind wellhouse&near reserve pit. Comments: Well identified by permanent well identification sign on wellhouse.Mr.Stephens took pictures at my direction and they are attached to his report. Attachments: none SCANNED clj jtty 0 8 2Ui REVIEWED BY:n� Oki/to SCANNED 1 Comm JJff PLB 12/2015 2016-1010_Suspend_PBU_E-18B_jj.xlsx OF Ty • • %/�� THE STATE Alaska Oil andGas of Conservation Commission LASKA #t #, x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®FALAS"- Fax: 907.276.7542 SCANNE ; OV 1 4j 2015 www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity& Compliance Team Leader BP Exploration(Alaska), Inc. P.O. Box 196612 to L- " Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-18B Sundry Number: 315-583 Dear Mr. Daniel: 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. Approval is granted contingent on development of a P&A plan for suspended wells with no future utility which brings these wells closer to abandonment prior to pad decommissioning. This plan must be developed and approved through the Commission by 12-31-2016. Failure to comply with this requirement will invalidate this sundry. 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, Cathy . Foerster Chair DATED this Zity of October,2015 Encl. RBD MS NflV 022015 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ON • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend p Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Itr Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other 5-G'3,Of14 5/774V/Z d'1-CI("1-/4 / • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 204-139• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development [VJ 99519-6612Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20654-02-00. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes 0 No D Will planned perforations require a spacing exception? PBU E-18B • RECEIVED Property Desig 9. Field/Pools: ADP 0028304•nation(Lease Number): 10 PRUDHOE BAY,PRUDHOE OIL • S L f 2 1 2015 11. PRESENT WELL CONDITION SUMMARY 0.15606U Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Ju 10375 • 8327 • 9834 7870 9834/10100 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 32-112 31 -111 0 0 Surface 2658 13-3/8"72#L-80 31 -2689 31-2684 4930 2670 Intermediate 10187 9-5/8"47#L-80 29-10216 29-8180 6870 4760 Production Liner 448 3-1/2"8.81#L-80 9926-10374 7943-8326 Liner 360 7"26#L-80 9856-10216 7888-8180 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5-1/2"17#/4-1/2"12.6# L-80/L-80 27-9964 Packers and SSSV Type: 4-1/2"Baker SAB Perm Packer Packers and SSSV MD(ft)and TVD(ft): 9804, 7846.45 No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development E Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended RI - 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 Daniel,Ryan Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan i Title Alaska Wells Integrity&Compliance Team Leader Signature AA i , - Phone +1 907 564 5430 Date Pio /St 2a i COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 16-6`e3 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other:nppr-o✓4 / l� r a.v1V-tCI e o t-r.,� rh f o v -dt l/C/o pl-t-,rpt e F a. P .5 pla�-. Fo r- 5 5 c,5p-r-1.--2 dr-d Well Wi'f h N v Ev f v v-r /v t/ I 011 Ui kjL— b v- ('-i2 j t -t z 5 t -c115 0ld5tr to a b.(hc/o,-t -i-r1-tt pri'or- fo pad do Ca,,,�,.,., i's 51 v et 1"1PR.. play. fa /2 z dz-1/t-1a ped a h0/ appro ✓ea/ th+rav, h tCo h-..-,,, /�5-)efv by i zj3tll 4 . Spacing Exception Required? Yes 0 No Q" Subsequent Form Required: 1/L r�1 et V� !t�l a fi L 7�1 t' ‘),A&f FA /vre cvw,h1 wrth �!-rr rrt f_v 1,-e*rvrr.1 `�' APPROVED BYTHE Approved by: y` COMMISSIONER COMMISSION Date: ._/5-1 alehr to/zWlS ORIGINAL RBDMS�Ply o 2 2015 ,0-(qr26 � Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate jcs.2.4, 1i TREE= CNV 6 318" • SerY NOTES: MERLA TBG PATCH 9652'-9673' yVELLHEAD FMC ACTUUATTORR= OTIS E-1 8 B MD,OVERGLM 1,ID=3.75" KB. ELEV= 60.45' BF. ELEV = 31.72' KOP= 2600' 1996' —I SSSV OTIS RQM NIP. ID=4.562" Max Angle= 95© 11553' GAS LIFT MANDRELS Datum MD= 11119' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD= 8800'SS 12 2891 2821 12 MMIGW DMY RK 0 12/22/03 9-5/8"DV PKR --1 2580' I 11 5119 4533 49 MMIGW DMY RK 0 12/22/03 13-318"CSG,72#,L-80 BTRS, ID= 12.347" — 2686' 10 6890 5657 49 MMIGW DMY RK 0 10/14/81 ' 9 6996 5720 50 MMIGW DMY RK 0 10/14/81 L 8 7871 6295 51 MMIGW DMY RK 0 10/14/81 Minimum ID = 2.370" @ 9862' 7 7974 6371 52 MMIGW DMY RK 0 10114/81 6 8549 6808 53 MMIGW DMY RK 0 10/14/81 TOP 2-7/8" LNR 5 8656 6893 53 MMIGW DMY RK 0 10/14/81 4 9071 7219 54 MMIGW DMY RK 0 10/14/81 3 9177 7301 53 MMIGW DMY RK 0 10/14/81 21'MERLA TBG PATCH ID=3.75" — 9652' -9673' u 2 9551 7590 45 MMIGW DMY Rh 0 10/14/81 "1 9655 7670 43 MMIGW DMY RK 0 10/14/81 ! '"GLM#1 COVERED BY MERLA TBG PATCH GLM'S#11 &#12=EXTENDED PACKING I I 9723' 15-1/2 BKR L SLIDING SLV, ID=4.562" 5-1/2"TBG, 174.L-80 U4S IPC, — 9805' _I-- 9805' —TUBING SEAL ASSY, ID=? .0232 bpf, ID=4,892" 4-1/2"WRP(3.69 00)(05/02/08) —I 9834' 11 9825' —9-5/8" X 4-1/2"BKR SAB PKR, ID=3.813„ rl SPECIAL CLEARANCED 9856' —9-5/8"X 7"BKR HYDRO HGR w I TIEBACK,ID=6.25" TOP OF 7"LNR —I 9856' 9882' —14-1/2"OTIS X NIP, ID=3.813" 3-1/2"LNR STUB(08/09/05) 9926' 9920' —14-1/2"OTIS XN NIP, ID=3.725" 4-112"TB. 12.64. L-80, .0152 bpf. ID=3.958" — 9965' 9965' —14-112"BAKER WLEG, ID=3.958" TOP OF CEMENT(12/24/04 CMT BOND LOG) — 10086' I4.• .� 9940' —I ELMD TT LOGGED 05/03/89 ••�• .•-• GEN II MECHANICAL WHIPSTOCK(11/02/04) — 10214' .'+: ..7.. 10100' —13-1;2"CIBP(07%15/05) RA TAG — 10222' - r .„ MILLOUT WINDOW(E-18B) 10216'- 10221' 2-7/8”LNR STUB(09/17!04) — 10254' 0•••••••1 62,r`- .V 10225' CTMD -3-1/2"PARTED/ �i ••• / DAMAGED LNR 9-5/8"CSG.47#, L-80 BTRS, 10=8.681" —I 10377' 1-4 N ►: 10234' —MCCL/GR DEPTH • •4 4•• 7"LNR,264 L-80 IJ4S. .0383 bpf, ID=6.276" — 11263' jQ .•• . V e PBTD 10370' P PERFORATION SUMMARY 'VI/I/14, �� . REF LOG: vow ANGLE AT TOP PERF: @' 3-1/2"LNR,9.3#,L-80 STL, 10374' Note: Refer to Production DB for historical perf data 0 .0087 bpf, ID=2.992" SIZE SPF INTERVAL Opn/Sqz DATE + ii DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/14/81 ORIGINAL COMPLETION 08/08/07 GJB/PJC CHEM CUT©9990" WELL. E-18A 05/07/97 RW CTD SIDETRACK"A" 08/10/07 KSB/PJC PULL DEPLOY SLV @ 9914' PERMIT No: 1970690 11/09/04 NORDIC 1 CTD SDTRCK"B"SUSPENDED 10/25/07 JSR/PJC DRLG DRAFT CORRECTIONS API No: 50-029-20654-01 07/15/05 RAC/TLH SET CIBP 11/26/07 JSR/PJC DRLG DRAFT CORRECTIONS SEC 6,T11 N, R14E, 1853'SNL&501'WEL 07/19/05 WJH/TLH CHEM CUT @ 10073' 05/05/08 KJB/PJC SET WRP(05/02/08) 08/07105 JGM/PJC CHEM CUT© 10060' BP Exploration (Alaska) • • BP Exploration (Alaska) Inc. Douglas A. Cismoski, P.E., BPXA Wells . Intervention Manager Post Office Box 196612 Anchorage,Alaska 99519-6612 August 28, 2015 Ms. Cathy P. Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well E-18B (PTD # 2041390) Application for Renewal of Existing Suspension (10-403) Dear Ms. Foerster, BP Exploration (Alaska) Inc. completed an AOGCC witnessed suspended well inspection of Prudhoe Bay Unit well E-18B on 05/30/2014 (20 AAC 25.110 (h). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: • Wellbore diagram illustrating the current configuration of the well • Suspended Well Site Inspection form documenting the pressures and site condition Prudhoe Bay Unit well E-18B was suspended on 05/02/2008. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is secured with a bridge plug set in the cemented liner and another in the tubing tail. The well is mechanically sound as proven by a pressure test after the lower plug was placed. Based on these conditions and the inspection on 05/30/2014 Prudhoe Bay Unit well E-18B meets the provisions required in 20 AAC 25.110 (a)(1). Based on this information, BPXA requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h) and (i)). In summary, BPXA believes Prudhoe Bay well E-18B is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 564-4303 or Whitney Pettus/ Kevin Parks at 659-5102. Sincerely, • S Dougla A. Cismoski, P.E. BPXA Wells Intervention Manager Attachments Technical Justification 2014 Suspended Well Site Inspection form Wellbore Schematic Cc: Doug Cismoski Pettus/ Parks Ryan Daniel • r Prudhoe Bay Well E-18B (PTD 2041390) Technical Justification for Renewal of Suspended Status August 28, 2015 Well History and Status Prudhoe Bay Unit well E-18B (PTD 2041390) was suspended on 5/02/2008 after a failed sidetrack attempt. The well is secured with bridge plugs set at 10100' MD in the cemented liner and at 9834' MD in the tubing tail. A MIT-IA passed to 3000 psi on 4/6/2008 prior to setting the upper plug. In the current state the well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, is secure, safe and not a threat to public health The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of Wellhead and Surface Location Prudhoe Bay Unit well E-18B is located on an active, well maintained pad with clean gravel. The surrounding area is in good condition and there is no discoloration and no sheen on the pad, pits or in nearby water. The well pressure readings are T/I/O= NA/150/100 psi recorded on 5/30/2014 and are stable. Request BPXA requests approval for renewal of the existing suspension status for E-18B. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness 10 Year Well Name Dnllpad E NO 1BB Field/Poor: Prudhoe Bay Bald/Prudhoe Bay pool Permit (PTD). 2041390 API Number 50029206540200 Operator: BP EXPLORATION(ALASKA)INC Date Suspenc 5/2/2008 Surface Location: Section 6 Twsp: /1N Range 14E Nearest active pad or road: G 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,clear but active pad Pad or location surface. level gravel pad Location cleanup needed none Pits condition: NIA Surrounding area condition. clean Water/fluids on pad snow melt Discoloration, Sheens on pad,pits or water none Samples taken none Access road condition good Photographs taken(#and description): Yes.wellhouse, surrounding.and behind house 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: FMC wellhead,OW tree, SSV closed.all clean Cellar description,condition, fluids. ice Rat Hole. N/A Wellhousa or protective barriers. Yes, house Well identificabon sign: Yes Tubing Pressure(or casing if no tubing): NIA SSVclosed Annulus pressures IA-150 psi OA-100 psi Wellhead Photos taken($and description) Yes, cellar,WH,tree,annuli valves Work Required none ocicA_ Operator Rep(name and signature): Laurie Climer AOGCC Inspector John Crisp Other Ob eers Ryan Hayes Inspector Date: 5/30/2014 AOGCC Notice Date: 5/29r2014 Time of arrival 2 45 PM Time of Departure. 3.00 PM Site access method: truck r . • ID TREE= OW 6 18' SAFETY NOTES: MERLA TBG PATCH 9652-9673' WELL FEAD= FPC A CTLATOR= 0115 E-1 8B MD.OVER GLM 1.ID=3.75" KB REV= 60.45 BF ELEV= 3 1 71 NOP= MOO' I 1996' h sssv CMS ROM riP.El=4567 It Ange= 95,j 11553CI GAS LIFT MANDRELS Datum MD= 1 11 19' ST NI3 TVD DR TY FE VLV LATCH PORT DATE Ltum TV D= 5 800'SS 12 2801 2821 12 PailIGW WY RK 0 12/22/03 9-503'DV FIR 2580' 11 5 119 45 33 49 MMIGW (JAY FI K 0 12/22/(13 10 6890 56 57 49 MMIGIN DPAY FR 0 10/14/81 11 3-316 CSG,72#,L-80 BTRS, ID=12.34r H 2686' 1 Illr 9 6996 5720 50 NMIGW [MV FE 0 10114t81 8 787 1 6295 51 N1.1IG1N [NY F4( 0 10/14181 Mm km m ID =2.370"@ 9862' i 7 7974 6371 52 NMIGVi [NV FR 0 10/14181 6 8549 6808 53 UNION CMY FE 0 10/14/81 TOP 2-718"LNR = 9657- ' -X 5 8656 6893 53 MAHON OW lit 0 10/14031 4 9071 7219 54 MOON [MY 1114 0 10/1.081 3 9177 7301 53 1.1.113W (JAY RK 0 10/14/81 21'hERLA TBG PATCH ID 3 75' H 9673 2 9551 7590 45 MOON [NY II( 0 10114/81 '1 9855 ism 43 NIMIGW CRAY FIC. 0 10114/81 7,GL:4,1, 11 8,v EKED EZCFMERIACIETFTPATCH 3_ s 11_11 972 3' H5-1!2'81021 SLUNG SW,D=4.967 5-112-TBG,1714,L-80 U4S IPC, —I 9805' ,.. . 1" 990 5' HTUBING S,EA L ASSY,ID- MS 11 g-5rw X4-1.Z I3KR SA B PK R,ID=3.81 3" I - .023 2 bpi,ID=4 897 -, I 4-1,2"WRP 13.69 04405032108) —I 9834' SPECIAL CLEARAIsCED . . 9856' 9-58"X 7'BKR HYDRO HGR • wi 71/33ACK IC TOP OF 7"LNR %%' 9887 I—I4-1,2'"715 f'‘1, D=1813' 13-1.12"LtiR STUB 1080905) H 99 26' I 992(f H4- .71""i,Y:,,! ',JP,10=3.725' I 14-1/2'TB,12.50.[-8),.1152 tip f, 0=3.955' H9965. I I 9965 H 4_1..2 I3AKER ALM,ID=1958" I I 1-0 P OF CEAENT(1124/04 C76111 B(JA)LOG( 10086' • 0 °3: 9940' HELIX:77 Loocar 0503+89 I I GEN II MECH.%N:ICA L WiiIPSTOCK 01/02034:I 1 021 4' I A,••,,----.•,T.- 1 0 1 00' F 1 2-1:2'CPI17/1505 1 1111 ..• RA TAG 11111(7 m:11" .. %ALDO"'4,eircoos 1E-18B) 10216-10221 *Nye* 12-7:6 LNR STUB 0917341 H 1 02 54. Iv6% p _dw le .—7...z.:- 1 0 2 2 5'CTM I) 3-1/7 PA RTED '• -/ I• • 0AMAGE3 LNP •to, 1 CSG,474,L-80 EfTRS•ID=8.68 1' ik Pa 4 ' // I 10234' HhfCGL/GET DTH 1 4 0 ta ll• IT LNR,25#,L-80 U4S,.0383 Opt.0=6.276' Illikall'. '11 I,4 •• C. •• • k 0 •• •d6i. 4 ,•• FB1D 10371T FERFOFtATK3N SLIJIMARY tr:2ffl.;, I • magssw' REF LOG: ar44r., A NGL E A T TOP PE '1" RE: tit" --..-- 3.1 ar LAR.9.3t,1_430 STL. H 10374' rwie.Ref e r to Paducton 1313 far firstorical per!dales I _OW bpi,D=1997 -...-- SIZE SW INTERVAL OpnrSox DATE --..-- I 0:40:411 DATE FEV BY COMEN-S DA 7E RB/ BY cormarrs PRUDHOE BAY UNIT 10/14/81 OFIGNAL C OM P LET ION 3538/0 7 GJ3/P-IC arar CUT @ 3990' WELL E-18A 05/07/97 RW CD)SIDETRACK"A" 05 113 7 KSBSPJC RLL OEFLOY SLV @ 93 14" PERMT No:rig 70690 11/09/04,NOROC I CTD SOT FICK"Er SLISPEN)ED 100517 JSRRIC OR1_G DRAFT CORRECTIONS API Na: M-0 29-20654-0 1 07115/35 RA DTLFI SET COP 1 1:26417 JSR1PJC ORLG DRAFT CORRECTIONS SEGE.T11 N,R14 E 1853'SM.&501 W B_ 37.119105 WJR,TL(-1 CHEM CLT'T. 1 00 73 05/a518 KU/PJC SET WRP(05102,09) 38107/05 ..IGM'PJC Cl-EM CUT @ 1M60" BP Exploration(Alas ka) • • Loepp, Victoria T (DOA) From: Daniel, Ryan <Ryan.Daniel@bp.com> Sent: Thursday, October 22, 2015 9:01 AM To: Loepp,Victoria T (DOA) Cc: Sternicki, Oliver R Subject: FW: PBU Suspension Renewal Wells Good Morning Victoria, Thanks for the conversation this morning. BPXA currently have 59 suspended status wells,of which many would not have *future utility today. My view for the business and from a risk perspective is to leave these wells "as is" until pad level decommissioning.The SU wells on pads with trees are monitored daily and pose minimum risk to our operations. Any wells,that are determined to have a higher risk associated with communication, re-pressurization etc will certainly be given priority for intervention and mitigation. *Additionally,as the business starts to realign from oil to gas over the next 10-15 years we would want to preserve various options (wells and surface locations)for the future. Let me know if you have any other questions Rgds Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loeppCalalaska.gov] Sent: Wednesday, October 21, 2015 3:56 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells Oliver, At what point will these wells with no future utility be brought closer to abandonment?Approximately how many suspended wells are in this category? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.LoeppCa�alaska.Qov 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.Loem@alaska.gov 1 i ! Loepp, Victoria T (DOA) Subject: From: Daniel, Ryan [ ;Abp.com] Sent: Tuesday, October 20, 2015 4:25 PM To: Loepp, Victoria T(DOA); Sternicki, Oliver R Cc: Regg, James B (DOA); Julian, Jennifer Y; Bill, Michael L(ASRC) Subject: RE: PBU Suspension Renewal Wells Hello Victoria, Negative. BP and its working Interest owners are developing some longer term options for"decommissioning" work scope which includes some wells and surface kit.These are screening opportunities only(potential future activities)and still in the very early scoping stage. They are not funded or approved yet, and as such it would be premature for BPXA to comment any further. The Observation well P&A program which I discussed recently with Jim,and the Suspended well renewal applications submitted by Oliver are also separate(discrete and unrelated) activity plans for well stock management and as such have different timelines and rational. We are happy to discuss the Suspended wells further id necessary. If you could use Oliver as the single point of contact for this work that would be much appreciated. Thanks Ryan From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, October 20, 2015 2:16 PM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, Do you have any information to share with us on the sustained P&A program and where these suspension renewal wells fit in the program? Thanx, Victoria 1 • • From: Sternicki, Oliver R [maiito:Oliv_ Jternicki©bp.com] Sent: Thursday, October 08, 2015 4:03 PM To: Loepp, Victoria T(DOA) Cc: Daniel, Ryan Subject: PBU Suspension Renewal Wells Victoria, This is the response from Base Management for the 9 suspended wells renewals and if the fall under A or B of 20AAC 25.110(a)(2). 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. WGI-01: no current sidetrack plans 02-30B: no current sidetrack plans G-13A: no current sidetrack plans, but may use surface equipment for another well V-201: no current sidetrack plans S-14A: no current sidetrack plans W-09A: no current sidetrack plans E-18B: evaluating several sidetrack options NK-14A: evaluating a sidetrack option Y-25A: no current sidetrack plans Let me know if you have any other questions. Regards, Oliver Sternicki WO 'global was criorwasakos Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternicki c(Dbp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Monday, September 28, 2015 3:10 PM To: Sternicki, Oliver R Subject: RE: PBU Suspension Renewal Wells So no well listed below,with the exception of 1-100 has future utility as an exploratory, development,or service well and no well listed below is a viable candidate for redrilling? I understand the wells are all located on active pads. Victoria Victoria Loepp Senior Petroleum Engineer 2 • • State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a)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.Loeop@alaska.gov From: Sternicki, Oliver R [ micki©bp.com] Sent: Monday, September 28, 2015 2:41 PM To: Loepp, Victoria T(DOA) Cc: AK, D&C Well Integrity Coordinator; Daniel, Ryan Subject: RE: PBU Suspension Renewal Wells Victoria, The below wells that you have listed fall under the category; (C) is located on a pad or platform with active producing or service wells. 1-100 which you did not list is the only well that BPXA sent for renewal of suspended status that falls under the category. (A) has future utility as an exploratory, development,or service well; no wells meet the(B)criteria. Regards, Oliver Sternicki O glob**waft piano stion Well Integrity Engineer BP Exploration Alaska Office: 1 (907) 564 4301 Cell: 1 (907) 350 0759 oliver.sternickibp.com From: Daniel, Ryan Sent: Monday, September 28, 2015 9:26 AM To: Sternicki, Oliver R Cc: AK, D&C Well Integrity Coordinator Subject: FW: PBU Suspension Renewal Wells Oliver, Can you please reply to Victoria on this question, Copy me, or come and discuss if we have an issue. Thanks Ryan 3 • • From: toepp, Victoria T(DOA) [mailto:victoria.loeppCa alaska.gov] Sent: Monday, September 28, 2015 9:25 AM To: Daniel, Ryan Subject: PBU Suspension Renewal Wells Ryan, PBU 02-30B 200-126 PBU V-201 201-222 PBU E-18B 204-139 PBU G-13A 200-163 PBU S-14A 204-071 PBU W-09A 204-102 PBU WGI-01 179-031 PBU Y-25A 208-140 PBU NK-14A 206-031 20 AAC 25.110(a)(2):the well (A) has future utility as an exploratory, development,or service well; (B) is a viable candidate for redrilling; or (C) is located on a pad or platform with active producing or service wells. Which wells meet the criteria of(A) and/or(B)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeop(a�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 Victori, oepp@alaska.gov 4 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/11/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU E-18B - Oper. Rep: Jack Winslow PTD No.: 2041390 Oper. Phone: 659-5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 05/02/08 - Date AOGCC Notified: , . Sundry No.: 307-370 Type of Inspection: Initial Wel !bore Diagram Avail.? Yes Well Pressures (psi): Tubing SSV closed Photos Taken? Yes IA 520 • by Operator OA 120 Condition of Wellhead: Well house in place, full tree with closed SSV, flow line removed and blinded. Condition of - Surrounding Surface OK Location: .. Follow Up Actions none Needed: Attachments: None REVIEWED BY: Insp. Supry . (.....> Comm j- PLB 08/2010 2010-0911_Suspend_PBU_E-18B_cs.xls STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other Q Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ WELL 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Dri ll Number: Name: Development Q Exploratory F 204 -1390 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20654 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number ADLO- 028304 , PBU E -18B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10375 feet Plugs (measured) 9834'10100' feet true vertical 8326.66 feet Junk (measured) None feet Effective Depth measured 983 feet Packer (measured) 9825 true vertical 7870.3 feet (true vertical) 7863 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2686 13 -3/8" 72# L -80 SURFACE - 2686 SURFACE - 2681 4930 2670 Intermediate 10216 9 -5/8" 47# L -80 SURFACE - 10216 SURFACE - 8180 6870 4760 Production 360 7" 26# L -80 9856 - 10216 7888 - 8180 7240 5410 Liner 448 3 -1/2" 8.81# L -80 9926 - 10374 7943 - 8326 Liner Perforation depth: Measured depth: NONE - —` L True Vertical depth: _ _�= d� Tubing: (size, grade, measured and true vertical depth) 5 -1/2' 17# L -80 SURFACE - 9805 SURFACE - 7848 4-1/2" 12.6# L -80 L -80 9805-9965 7848-7974 Packers and SSSV (type, measured and true vertical depth) 9- 5/8 "X4 -1/2" BKR SAB PKR 9825 7863 y . 12. Stimulation or cement squeeze summary: Intervals treated (measured): ^ . fr . Treatment descriptions including volumes used and final pressure: � 4 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: L Copies of Logs and Surveys Run Exploratory[ \ geelopment Service ❑ Daily Report of Well Operations X 16. Well Status after we kooSUSPENDED Oil Gas WDSPL I GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564 -4944 Date Ri Prudhoe Bay Unit Well E -1813, PTD 2041390 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of PBU E-1 8B on 9/11/10. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Chuck Scheve witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one - quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • PBU E-1 8B was suspended on 5/02/08 after a failed sidetrack attempt. • PBU E-1 8B is located on a pad with active producing wells and /or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with bridge plugs set at 10100' MD in the cemented liner and at 9834' in the tubing tail. • The well is mechanically sound as proven by a pressure test after the plug was set. MLB 09/14/10 • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT E -18B Field /Pool: PRUDHOE BAY / PRUDHOE OIL Permit # (PTD): 2041390 API Number: 50029206540100 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 5/2/2008 Surface Location: Section: 6 Twsp: 11N Range: 14E Nearest active pad or road: PRUDHOE BAY E -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: Gravel pad Location cleanup needed: No Pits condition: Good Surrounding area condition: Good Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: Good Photographs taken (# and description): (2) wellhouse and sign 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: FMC wellhead; ClW tree - good condition Cellar description, condition, fluids: Gravel, dry Rat Hole: None Wellhouse or protective barriers: Wellhouse Well identification sign: Yes Tubing Pressure (or casing if no tubing): 10 psi Q Annulus pressures: IA = 520 psi, OA = 120 psi f 1A bj Wellhead Photos taken (# and description): (2) wellhead and tree Work Required: None Operator Rep (name and signature): Torin Roschinger c ,, t ,. AOGCC Inspector: Chuck Scheve Other Observers: Jack Winslo Inspection Date: 9/11/2010 AOGCC Notice Date: 9/8/2010 Time of arrival: 9:20 AM Time of Departure: 9:30 AM Site access method: Truck TREE = CM/ 6 3/8" ffA E S: MERLA TBG PATCH 9652' -9673' WELLHEAD = FMC , OVER GLM 1, ID = 3.75" ACTUATOR = OTIS E=1 8B KB. ELEV = 60.45' BF. R EV - 31.72' KOP = 2600' 1996' SSSV OTIS ROM NIP, ID = 4.562" Max Angle = 95 @ 11553' GAS LIFT MANDRELS Datum MD = 11119' ST MD I TVD DEV TYPE I VLV LATCH PORTI DATE Datum TVD = 8800' SS 12 2891 2821 12 MMIGW DMY RK 0 12/22103 9 -5/8" DV PKR 2580 11 5119 4533 49 MMIGW DMY RK 0 12/22/03 13 -318" CSG, 72 #, L -80 BTRS, ID 7 - 12 - 34 – F 2686' 10 6890 5657 49 MMIGW DMY RK 0 10/14/81 9 6996 5720 50 MMIGW DMY RK 0 10/14/81 8 7871 6295 51 MMIGW DMY RK 0 10/14/81 Minimum ID = 2.370" Cl 98621 7 7974 6371 52 MMIGW DMY RK 0 10/14/81 6 8549 6808 53 MMIGW DMY RK 0 10/14/81 TOP 2 -7/8" LNR 5 8656 6893 53 MMIGW DMY RK 0 10/14/81 4 9071 7219 54 MMIGW DMY RK 0 10/14/81 3 9177 7301 53 MMIGW DMY RK 0 10/14/81 21' MERLA TBG PATCH ID = 3.75" 9652' - 9673' 2 9551 7590 45 MMIGW DMY RK 0 10/14/81 *1 1 9655 7670 43 MMIGW I DMY I RK 1 0 10/14/81 ** GLM #1 COVERED BY MERLA TBG PATCH * GLM'S # 11 & # 12 = EXTENDED PACKING I ' 9723' 5 -1/2" BKR L SLIDING SLV, ID = 4.562" 1 5 -1/2" TBG, 17 #, L -80 U4S PC, 9805 9805' TUBING SEAL ASSY, ID = ? .0232 bpf, ID = 4.892" _ —F - 98 - 25' -- 1 4 - 9-5 — /8' — X 74 - 7 112- BKR SAB PKR, ID = 3.813" 4 -1/2" WRP (3.69 OD)(05/02/08) 9834' SPECIAL CLEARANCED 9856' 19-5/8 w /TIEBACK ID = 6.25" TOP OF 7" LNR 9882' 4 -1 /2" OTIS X NIP, ID = 3.813" 3 -1/2" LNR STUB (08/09/05) 9926' 9920' 4 -1/2" OTIS XN NIP 1D = 3.725" 4 -1/2" TB, 12.6#, L -80, .0152 bpf, ID = 3.958" 9965' 9965' 4 -1/2" BAKER WLEG, ID = 3.958" TOP OF CEMENT (12/24/04 CMT BOND LOG) 10086' 9940' ELMD TT LOGGED 05/03/89 GEN II MECHANICAL WHIPSTOCK (11/02/04) 10214' 10100' 43 -1/2" CIBP (07 115/05) RA TAG 10222' MILLOUT WINDOW (E-18B) 10216'-1022V ' 2 -7/8" LNR STUB (09/17/04) 10254' 10225' CTMD 3 -1/2" PARTED/ DAMAGED LNR 9 -5/8" CSG, 47 #, L -80 BTRS, ID = 8.681" 10377 10234' MCCL/GR D EPTH 7" LNR, 26#, L -80 IJ4S, .0383 bpf, ID = 6.276" 11263' PBTD 10370' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: @ ' 3-1/2" LNR, 9.3 #, L -80 STL, 10374' Note: Refer to Production DB for historical perf data 1 .0087 bpf, ID = 2.992" SIZE SPF INTERVAL Opn /Sqz DATE DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/14/81 ORIGINAL COMPLETION 08/08/07 GJB /PJC CHEM CUT @ 9990" WELL: E -18A 05/07/97 RW CTD SIDETRACK "A" 08/10/07 KSB /PJC PULL DEPLOY SLV @ 9914' PERMIT No: 1970690 11/09/04 NORDIC 1 CTD SDTRCK "B" SUSPENDED 10/25/07 JSR/PJC DRLG DRAFT CORRECTIONS API No: 50- 029 - 20654 -01 07/15/05 RAC/TLH i SET CIBP 111/26/07 JSR/PJC DRLG DRAFT CORRECTIONS SEC 6, T11 N, R14E, 1853' SNL & 501' WEL 07/19/05 1 WJH/ TLI CHEM CUT @ 10073' 05/05/08 KJB /PJC SET WRP (05/02/08) 08/07/05 JGM/PJC CHEM CUT @ 10060' BP Exploration (Alaska) � = 501' O - a 38 Z -a 7 34 9 c 100 102 10 Enter /Exit 104 j 1 � o ■ 11 12 \� nn � 31 1� 1 a l 15 �� J — CV �\ N 4 �) - ■ 35 �1 5 101 6 � e 26 2 00 33 ■ 103 /PW 21 16 29 36 25 53; 20 -- -a 17 2 8 c 24 27 23 19 •18 37 39 52 Metering Skid 90 54 Lo C13 56 55 Enter /Exit Enter /Exit _ WELL PRODUCER ■ or WELL INJECTOR A DATE : 01/06/2009 SCALE: 1" = 300' MAP DATE: 2007 PBU - E PAD WELL SLOT W /CONDUCTOR fogy bs14495.dgn E Pad July 25, 2010 Approximate Scale: 1" =300' 2010- 19c -5 -27 A UIO-MITRIC Pr w i - r ' r4 , s �. r. , , u Af Al I P A-4 I' - l r r r "� '- �„{,' .. may.. _ -� ^"'- "- ._..._._- . - �•��`.�.��.� 1 1 w E -18B k, ti t - A v WELL NAME E•18B OWNER Prudhoe Bay Unit OPERATOR BP Exploration (Alaska) Inc. API NUMBER 50- 029- 20654 -02 -00 SUR. LOCATION NE 1i4, Sec. 06, T11N, R14E DRILLING PERMIT 204 -139 « .\ �� \. ©� � .a\ � . � . . | . � . . � \\ \, � ° }: . : � a y . . .. � \ ? :« ». « 12.<. ; a . : >� . . . . �:� w °?. ` : «�< �� \ � � � � y. � �/ \ \ ° w �� yvy«» <yy � l� »\ \ � <\� \ w § } . .�� ? \� ~ / »� � < : » v� . \. . \ \ : � °° 2 < » t� ^ y� \ » y \ � � :. , . . : y � > � yy \ \. ^�~ � � : »� »<y < «: § . . . . � � > \� . » % � � � � � � \\ /� \< \ ,\ \ - ... __. .. w . � � � }\ \� \� � \\ � . .ar� :� . /� /� ;= \� »« .« »< «lt .. � . 's »� .. .mom w > � .w:x< ©�. � � \ \ \ \� \ \\ � \ .. �� | \ � « « < . � . : v = . .. � y « «« d :. . ¥ . v » » < < ?: 2. / /� \� � . ~^ 2 2 ::2�< + ?? :� . \ \ :.y� \+ \ � /� \ � . �� /� / \� . \ \\~ y , \, \ . ` <� � /: . � \ � � \ \� � ��(� \ \� < y \ \�\. ,� � - .�,� . r��. 3 `s 0 0 E -18B (PTD #2041390) TIO Plot Well 4,000 3,000 e - Tbg —IF IA 2000 —A— OA OOA «- OOOA On 1,A 1,000 07;03/10 07/17/10 07/31110 0811411p 1 /10 09/25/10 ~ ~~ a..es ro DATA SUBMITTAL COMPLIANCE REPORT 6/3/2010 Permit to Drill 2041390 Well Name/No. PRUDHOE BAY UNIT E-186 Operator BP EXPLORATION (ALASFC/~ INC API No. 50-029-20654-02-00 MD 10375 TVD 8327 Completion Date 5/2/2008 Completion Status SUSP Current Status SUSP UIC N REQUIRED INFORMATION Mud Log No DATAINFORMATgN Types Electric or Other Logs Run: MWD GR Well Log Information: Log/ Electr Data Digital Dataset Samples No Directional Survey (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / 1 Y~7 n~cwr~~~~a .r.....vc. IY21111r vvu... ........u Irv .~w~a .~wN i~ca.c.rcu D D Asc Directional Survey 10200 10375 Open 12/21/2004 IIFR pt, Directional Survey 10200 10375 Open 12/21/2004 IIFR Cog Cement Evaluation 5 Col 1 9783 10212 Case 4/25/2006 Slim Cement Mapping Tool Log SCMT/GR/CCL 24- ' 6 03 7 O 1/31/2006 Dec-2004 GR/ROP PB1 D D Lis 13418 Gamma Ray 983 1 4 pen pt 13418 LI S Verification 9836 10347 Open 1/31/2006 GR/ROP P61 v D C Lis 13895 "Gamma Ray _ _- 9836 -- 10347 Open - 5/70/2006 PB 1 Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / f / Daily History Received? / Chips Received? -~F-,CAI--- Formation Tops ~ N Analysis _X.E#'"" Received? • Comments: DATA SUBMITTAL COMPLIANCE REPORT 6/3/2010 Permit to Drill 2041390 Well Name/No. PRUDHOE BAY UNIT E-18B Operator BP EXPLORATION (ALASKA INC API No. 50-029-20654-02-00 MD 10375 ND 8327 Completion Date 5/2/2008 Completion Status SUSP Current Status SUSP UIC N -- --- - ---- ~ u.,.r_ ~.t9 t C7. Compliance Reviewed By: _____ __ Date: STATE OF ALASKA '~~~%j v~ ALAS~IL AND GAS CONSERVATION COSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ®Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions Zero 1 b. Well Class:AO I i ®Developmen~ ~ploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 5/2/2008 12. Permit to Drill Number 204-139 307-370 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11 /02!2004 ~ 13. API Number 50-029-20654-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/02/2004 14. Well Name and Number: PBU E-186 FNL, 501 1853 FEL, SEC. 06, T11 N, R14E, UM Top of Productive Horizon: N/A 8. KB (ft above MSL): 60.5' Ground (ft MSL): 30.25' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1646' FNL, 586' FEL, SEC. 07, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 9834' 7870' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 664487 y- 5975211 Zone- ASP4 10. Total Depth (MD+TVD) 10375' 8327' 16. Property Designation: ADL 028304 TPI: x- y- Zone- Total Depth: x- 664531 y- 5970139 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed in .r~m~ation per AAC 25.071): MWD GR L//NDD.G~~ /O, e`~/'~ %~'Id / / ~~~?YD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING:DEPTH MD" SETTING DEPTH.TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE' CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surfac 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2686' Surface 2681' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-80 Surface 1 21 Surface 8180' 12-1/4" 1450 cu ft Class'G' 130 cu ft AS I 7" 26# L-80 9856' 1 7888' 8180' 8-1/2" 432 cu ft Class'G' 3-1/2" 8.81# L-80 2 ' 10374' 7943' 8326' 3-3/4" 62 cu ft Class'G' 23. Open to production or inject ion? ^Yes ®No 24. TUBING RECORD If Yes, IISt each I (MD+TVD of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD 5-1/2", 17#, L-80 x 9805' MD TVD MD TVD 4-1/2", 12,6#, L-80 9805' - 9965' 9825' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ( DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 10100' Set CIBP (07/15/05) 9834' Set WRP (05/02/08) 26. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HOUR RATE.., OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No 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 250.071. None ~ ~~Oi`J i'LE'~I+,J:`~ -0 '~ ~i~ .!UN 7 2 200$ Al~s~ ~ 4 'on Form 10-407 Revised 02/2007 ~ M1 ~ ~ ~ CONTINUED ON REVERSE SIDE S ~~~ J~L ~ ~ 2Q~0 ~ ~ ~,., . ~ ~ ~. ~ ~~ (V; .. ~~I 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS A ' ' RKERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Test ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sag River -10375' 8327' None Formation at Total Depth (Name): Sag River -10375' 8327' 30. List of Attachments: Summary of Daily Drilling Reports and Well Work, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoi g is true and correct to the best of my knowledge. ~ Signed Terrie Hubble Title Drilling Technologist Date O ~ PBU E-18B 204-139 307-370 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Dulling Engineer: Jacki Randall, 564-4590 INSTRUCTIONS GeNew-~: 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. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Boz 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-!n, or Other (explain). IreM 27: 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. IreM 29: 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. Form 10-407 Revised 02/2007 Submit Original Only • • BP EXPLORATION Page 1 of 7 Operations Summary Report Legal Well Name: E-18 Common W Event Name Contractor Rig Name: Date ell Name: E : R Name: N N From - To -18 EENTE ORDIC ORDIC Hours R+COM CALIST 1 Task , PLET A Code E NPT Start Rig R Rig N Phase II Spud Date: 9/26/1981 : 10/21/2004 End: 11/8/2004 elease: 11/8/2004 umber: N1 Description of Operations 10/31/2004 17:00 - 19:00 2.00 MOB P PRE RD off E-17a PT tree cap to 3500 psi 19:00 - 00:00 5.00 MOB N WAIT PRE Rig on standby waiting on Pad Prep. Held weekly Safety Meeting with Crew Tool Ser started to level Pad at 2030 hrs. Rig off standby at 2300 hrs 00:00 - 01:00 1.00 MOB P PRE Move off E-17a and move to E-18b Rig Accept at 00:00 hrs 11-1-2004 11/1/2004 00:00 - 02:00 2.00 RIGU P PRE Cut studs off and remove tree cap, and NU BOP's 02:00 - 08:30 6.50 RIGU P PRE PT BOP. John Crisp, AOGCC inspector, wavered wittnessing BOP test. - 250/3500 psi. Install IA/OA gauges = 297/255 psi - Taking on 290 bbl 10.5ppg FloPro using 8" * 8" tire bumpers 08:30 - 11:15 2.75 RIGU P PRE Service injector. Test inner reel valve to 3500 psi. 11:15 - 12:00 0.75 RIGU P PRE RU dart catcher. Pump dart. Hit at 56.7 bbls. Rig down dart catcher. Nordic crew arrived for going home change out. 12:00 - 12:30 0.50 RIGU P PRE Pre Spud 12:30 - 13:00 0.50 STWHIP P WEXIT PU window milling BHA. - 3.72 no-go / 3.73 goon string mill and pilot mill. 13:00 - 14:45 1.75 STWHIP P WEXIT RIH with window milling BHA, pumps off, at 100 fpm. 14:45 - 15:00 0.25 STWHIP P WEXIT Stop at 9600' for weight check. - 32.5k PU w/o pumps. 15:00 - 18:15 3.25 STWHIP P WEXIT Tag pinch point and paint flag at 10,214' (Correct -30'). Mill window as per RP. - Time drill the window 0.1ft/6min. - Pump at 2.65 / 2.75 bpm. - 10.7 ppg in the hole. - Free Spin at 2550 psi. - Keeping motor work to < 400 psi. 18:15 - 20:45 2.50 STWHIP P WEXIT Milling window 0= 2.60 / 271 CTP = 2550 / 2850 psi Den = 10.69/10.44 ppg Out MM needs caliperated Milling at 6 min / 0.1 ft. 20:45 - 00:00 3.25 STWHIP P WEXIT Milling window 0= 2.60 / 271 CTP = 2550 / 2889 psi Den = 10.69/10.46 ppg Vp = 295 bbl PU at 10219.7 ft clean, check PUW = 28k, Off btm = 2554 psi Restart at 2.7/2.8 bpm, Off btm CTP =2700 psi. Milling Op = 2.8/2.92 bpm CTP = 2700/3098 psi Acts like formation at 10,219 ft Still time drilling 11/2/2004 00:00 - 00:40 0.67 STWHIP P WEXIT Milling window. Some motor work at 10220.6 ft wo/ WOB, -' outside Op= 2.8/2.90 bpm CTP = 2700/3250 psi Density = 10.7/10.7 ppg Vp = 294 bbl 00:40 - 00:55 0.25 STWHIP P WEXIT PU to check window PUW = 32k Off btm P = 2600 psi RIH and ream window. Gained 150 psi once mill on tray and fell of at 10,220 ft. Tagged at 10,222.1 ft 00:55 - 01:30 0.58 STWHIP P WEXIT Drilling Kingak formation. Shaker sample 90% metal shavings, some shale Qp = 2.78/2.8 bpm, CTP= 2600/3146 psi ROP= 14 fph Window from 10,214 ft to 10,219.7 ft 01:30 - 03:40 2.17 STWHIP P WEXIT Back ream rathole and window rnncea: on uzw° iv:~°.ou r~rvi • • BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: E-18 Common Well Name: E-18 Spud Date: 9/26/1981 Event Name: REENTER+COMPLETE Start: 10/21/2004 End: 11/8/2004 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2004 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT I,, Phase Description of Operations 11/2/2004 01:30 - 03:40 2.17 STWHIP P WEXIT 1st Pass - 60 to 180 psi motor work from 10,214.3 ft to 10,219.3 ft (5 ft Window) Tagged at 10230 ft, PUH and ream window again At 10214.3 ft 150 psi motor work on pass up # 2 Reamed down 10,212 ft to 10222 ft 2 time, no motor work, clean. Tagged bottom again at 10230 ft. PUH, RIH and dry tagged at 10230 ft. 03:40 - 05:05 1.42 STWHIP P WEXIT POOH, Painted flag at 10,000 ft EOP 05:05 - 06:00 0.92 STWHIP P WEXIT LD Window milling BHA. Mill had core point with marks on internal gauge. Mill OD 3.72" with String mill at 3.72" NoGo. 06:00 - 08:00 2.00 DRILL P LNRi PU lateral driliing BHA. - 1.04 deg motor 08:00 - 10:15 2.25 DRILL P LNR1 RIH with drilling BHA at 100 fpm. - Tie in at 10,000' EOP flag, -30' correction. - PU 36k; SO 16k - Orient 180E prior to entering window. - RIH through window, pumps off, clean - Tag at 10,230' MD. 10:15 - 13:45 3.50 DRILL P LNR1 Drill ahead in Kingak to 10,280' MD - 10.6+ ppg flo pro on "in density". -2.6/2.7bpm. - 3500 psi - 3300 psi free spin. - 30 -40 fph. - Occasional stalls, clean off bottom. 13:45 - 13:55 0.17 DRILL P LNR1 Wiper trip to window, clean. 13:55 - 16:40 2.75 DRILL P LNR1 Drill ahead in Kingak to 10,330' MD. - 10.6+ ppg flo pro on "in density". -2.6/2.7bpm. - 3500, psi - 3300 psi free spin. - 30 -40 fph. - Occasional stalls, clean off bottom. 16:40 - 18:15 1.58 DRILL P LNR1 Wiper trip to tubing tail. - Log pip tag and GR at -9900 for tie in. Plus 6 ft correction 18:15 - 18:50 0.58 DRILL P LNR1 RIH to retie-in the RA marker Set down at 10,225 ft, pulled heavy up to 10,205 ft. PUH and oriented TF from 160E to 160R RIH to 10,255 ft. 18:50 - 19:00 0.17 DRILL P LNRi Tie-in coming up Correct to RA TOWS at 10,212 ft TOW at 10,216 ft BOW at 10,221ft RA Marker at 10,222 ft 19:00 - 19:15 0.25 DRILL P LNR1 RIH and tagged bottom at 10,334 ft 19:15 - 21:35 2.33 DRILL P LNR1 Drilling at 156R TF Op = 2.62/2.70 bpm; CTP = 3300/3552 psi Vp = 299 bbl ROP = 28 to 36 fph with stalls Resultant TVD 8265 ft Projected to 10373.5 ft MD Let bit drill off 21:35 - 22:45 1.17 DRILL P LNR1 Work CT and circulate bottom up for Geo. 22:45 - 22:50 0.08 DRILL P LNRi Sample up, PUH to confirm with Tie-in. rrinteo: onuzuuu iu:~aa~r+m ~ • BP EXPLORATION Operations Summary Report Page 3 of 7 ~ Legal Well Name: E-18 Common Well Name: E-18 Spud Date: 9/26/1981 Event Name: REENTER+COMPLETE Start: 10/21/2004 End: 11/8/2004 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2004 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 11/2/2004 22:50 - 23:00 0.17 DRILL P LNR1 PUH logging tie-in. No correction. Siltstone and glauconite in samples 23:00 - 23:15 0.25 DRILL P LNR1 RIH and confirm TD 10,374 ft 23:15 - 00:00 0.75 DRILL P LNR1 PUH, circulate bottoms up and wait on shale stability CBU from above WS to Casing Patch at 9673 ft 11/3/2004 00:00 - 00:55 0.92 DRILL P LNR1 CBU and pulling to Casing Patch 00:55 - 03:50 2.92 DRILL P LNR1 Working CT at 0.5 bpm and waiting for 3 hours. 03:50 - 03:55 0.08 DRILL P LNR1 RIH past WS and inc Qp to 2 bpm, RIH and check hole integrity. Tagged TD at 10374 ft. Clean hole. 03:55 - 04:30 0.58 DRILL P LNR1 PUH, worked CT and pumped 12 bbl Flo-Pro/Asphosol w/ 5% Lubetex liner pill down CT. 04:30 - 06:00 1.50 DRILL P LNR1 POOH laying in 12 bbl liner pill. Painted EOP flag at 9700 ft, POOH. 06:00 - 07:30 1.50 DRILL P LNR1 Lay down BHA. 07:30 - 08:00 0.50 CASE P LNR1 MU CTC. Pull test to 3500 Ibs, pressure test to 3500 psi. MU dart catcher. Pump dart. Hit at 56.5 bbls. RD dart catcher. 08:00 - 10:45 2.75 CASE P LNR1 PJSM. RIH with 3-1/2" liner and CTLRT. - Baker-lok FE, o-ring sub, and last 5 jts of liner. 10:45 - 13:15 2.50 CASE P LNR1 PJSM. Run innerstring. - Rig up to run inner string. - Run 13 jts CSH. - Spaceout (use 11.83' and 1.91' pup). - Test O-ring seal to 500 psi. - PU CTLRT. - Make up Injector head. NOTE: 3 pip tags installed in Deployment sleeve. 13:15 - 15:00 1.75 CASE P LNRi RIH to flag at 9700' EOP (10,169.5' MD). - Correct at flag (-25') 10,169.5' MD. - 38.7k PU wt; 15.Ok SO wt. - 0.25 bpm at 750 psi 15:00 - 16:00 1.00 CASE P LNR1 RIH with liner into open hole. - Liner on bottom. - Tough time getting liner to bottom. - Difficutlies tracked dog leg severity. - Finally got liner to bottom at 10,376' MD, confirmed 3 times. 16:00 - 17:00 1.00 CEMT P LNR1 Establish circulation with full returns at 0.5 bpm (1000 psi) Drop 5/8" steel ball. Establish circulation with full returns at 0.5 bpm (1000 psi) Increase circulation to 1 bpm, lost full returns at 2800 psi, lost full returns. Total losses of 42 bbls. - Listening for ball in reel, no indication of ball going over the gooseneck. PU pipe, RBIH to bottom, still losing full returns. 17:00 - 18:30 1.50 CEMT P LNR1 Wellbore healed on its own. Re-established circulation at 0.5 bpm (1000 psi) Total bbls pumped as of 17:30 = 64 bbls. Suspect ball still in reel. - PLAN FORWARD -- DO NOT MOVE PIPE OFF BOTTOM Staging up pumps at 0.1 bpm increments establishing constant pressure. Printed: 6/12/2008 10:08:50 AM C.J • BP EXPLORATION Operations Summary Report Legal Well Name: E-18 Page 4 of 7 Common Well Name: E-18 Spud Date: 9/26/1981 Event Name: REENTER+COMPLETE Start: 10/21/2004 End: 11/8/2004 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2004 Rig Name: NORDIC 1 Rig Number: N1 Hours Task Code NPT ~ Phase Description of Operations Date From - To - - __ 11/3/2004 17:00 - 18:30 I 1.50 CEMT P LNR1 18:30 - 19:15 ~ 0.751 CEMT I P 19:15 - 19:45 0.50 CEMT P 19:45 - 20:20 0.58 CEMT P 20:20 - 21:30 I 1.171 CEMT I P 21:30 - 23:35 2.08 CEMT P 23:35 - 00:00 0.42 CEMT P 11/4/2004 00:00 - 00:30 0.50 CEMT P 00:30 - 02:30 2.00 DEMOB P 02:30 - 03:30 1.00 DEMOB P 03:30 - 06:00 2.50 DEMOB P 06:00 - 09:00 3.001 DEMOB ~ P 09:00 - 17:00 I 8.001 DEMOB I P 0.5 bpm - 1000 psi 0.6 bpm - 1100 psi 0.7 bpm - 1500 psi 0.8 bpm - 1700 psi 0.9 bpm - 2000 psi 1.0 bpm - 2100 psi, pressure ranging from 1700 to 2100 psi 1.1 bpm, started seeing some losses as pressure reached 2700 psi. creeping back on rate to lower pressure. Established 1.1 bpm at 2400 psi. LNR1 Switched pumps and inc Op to 1.65 bpm ball rolling in reel. O = 1.65/ 0.34 to 0.44 bpm Vp1 = 238 bbl Vp2 = 209 bbl Red Op to 0.48 bpm and out MM reads 0.53 bpm. Ratio 1:1 Dart landed at 47 bbl and shear at 4700 psi. PU and released at 34k string wt. LNR1 Cir at Op = 0.49/0.55 bpm and held PJSM LNR1 Batch mix cement and 11.6 ppg mud push. Cement at Density at 2010 hrs. Cir at 0.5 / 0.59 bpm CTP is 1900 psi with moderate pressure swings LNR1 Pumped 2 bbl 11.7 ppg Mud push, PT to 4500 psi Pumped 6 bbl 11.7 ppg Mud Push Pumped 11 bbl 15.9ppg cement at 1.5 / 0.7 bpm SD, dropped dart and launched. Pumped 28 bbl 10.5 brine / biozan At 47.1 bbl cement at shoe, red Op to 1.00/0.0.73 bpm Pumped to 57 bbl, SD, Dart didn't hit, 0.5 bbl left in CSH Cir 8.4 bbl cement up annulus Calculate annular volume = 9.7 bbl Unstung from O-ring sub. PUW = 34k up, cir at 1:1 ratio PUH laying in 0.5 bbl cement. Pulled tight--60K at 10345 ft and 10311 ft; 50k at 10284 ft and 45k at10254 ft. Mechanical sticking. LNR1 POOH contaminating cement LNRi LD CTLRT and ball catcher sub, recovered ball and dart LNR1 Stood CSH in derrick and LD stinger. No marks on tool joint or tube on inner string. Closed SV LNR1 Stab CT on well and flushed CT with fresh water and 5 bbl MEOH PJSM on blowing CT down with N2 LNR1 Blow down CT LNR1 Cleaning pits Pull CT back to reel house LNR1 PJSM, pre-pick checklist. Pick reel from reelhouse. OFF CRITICAL PATH: - Replace piping in pits. - Maintenace on generator 1. LNR1 Change drive plates on reel. OFF CRITICAL PATH: - Replace piping in pits. rnmea: wiuzuuo iv:uo:ovr+m • • BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: E-18 Common Well Name: E-18 Spud Date: 9/26/1981 Event Name: REENTER+COMPLETE Start: 10/21/2004 End: 11/8/2004 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2004 Rig Name: NORDIC 1 Rig Number: N1 Date From - To '. Hours Task ', Code NPT ~~ Phase Description of Operations - - - 11/4/2004 - - 09:00 - 17:00 - 8.00 DEMOB P LNR1 - -Maintenance on generator 1. -Rebuild pump #1 -Change rams in BOP. - Change injector grippper blocks. 17:00 - 18:00 1.00 DEMOB P LNR1 PJSM, pre-pick checklist. Pick and install 2" coil in reel house. 18:00 - 00:00 6.00 DEMOB P LNR1 Replacing gripper blocks to 2" (144 ) Installed hardline in reel house RU to pull CT arcoss pipe shed roof. Loading pit with 290bb1 new mud 11/5/2004 00:00 - 03:10 3.17 DEMOB P LNR1 Finished gripper block, inspected, OK, Housekeeping Stab injector on pack-off, PU and repair Otis threads 03:10 - 06:00 2.83 DEMOB P LNR1 Pulling CT across and stab in injector, clamped guide arch rollers Function tested BOP's from all remotes. Weld on CTC w/ GBR. 06:00 - 09:00 3.00 BOPSU P LNR1 Pressure test BOP rams, 250 psi low / 3500 psi high. Test inner reel valve. Witness waived by John Spaulding 09:00 - 11:00 2.00 CEMT P LNR1 MU dart catcher. Pump KCI in reel. Load and pump dart (40.1 bbls). RD dart catcher. 11:00 - 11:45 0.75 CEMT P LNR1 Pressure test liner lap with 10.7 ppg mud to 200 psi. Time Pressure Delta 0 223 ---- 5 216 7 10 205 11 15 201 4 20 201 0 25 201 0 30 201 0 11:45 - 12:45 1.00 CEMT P LNR1 PU milling BHA - 2.8" mill - 2-3/8" MM. 12:45 - 15:00 2.25 CEMT P LNR1 RIH at 100 fpm, circulating minimum rate with KCI at 300 psi. - Bring up rate to 1.6 bpm prior to entering liner, 2300 psi. - No problems entering liner. - Followed KCI with flo-pro for fluid swap. - PU 26.5k; SO 9k - 2300 free spin at 1.6 bpm. 15:00 - 16:45 1.75 CEMT P LNR1 Tag cement at 10,240' MD. Attempt to mill cement. -1.6/1.7 bpm - Free spin decreased to 1900 psi with 8.7 flo pro. - Repeated stalls. 16:45 - 17:15 0.50 CEMT P LNR1 From 10,239.9 - 10, 240.3' MD drilled hard. 17:15 - 18:00 0.75 CEMT P LNR1 Completed drilling hard spot, found cement? -1.6/1.7 bpm - 2300 psi (1900 free spin) -1-15fph Printed: 6/12/2008 10:08:50 AM • • BP EXPLORATION Operations Summary Report Page6of7~ Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: E ell Name: E e: Name: N N From - To ' -18 -18 REENTE ORDIC ORDIC Hours R+COM CALIST 1 Task PLET A Code E NPT Start Rig Rig N Phase Spud Date: 9/26/1981 : 10/21/2004 End: 11/8/2004 Release: 11/8/2004 umber: N1 Description of Operations 11/5/2004 18:00 - 20:30 2.50 CEMT P LNR1 Milling on same spot @ 10241.4 ft Time drilling, some wt but no motor work with light WOB Lost 300 psi motor work at 10241.4 ft Milled to 10242.2 Something isn't right 20:30 - 22:00 1.50 CEMT P LNR1 POOH to look at the mill and motor 22:00 - 00:00 2.00 CEMT C LNR1 OOH, pulled BHA and looked at Mill (no marks on frontal or gauge sections of 2.8 DSM. Conversed with town and the decision was to PU Sperry Drilling BHA with 0.8 deg motor and 2.75" STR 324 PDC Bit MU Sperry's BHA 11/6/2004 00:00 - 00:30 0.50 CEMT N DFAL LNRi MU Sperry's BHA 00:30 - 02:15 1.75 CEMT N DFAL LNR1 RIH with drilling BHA, SHiT at 2300 ft 02:15 - 02:50 0.58 CEMT N DFAL LNR1 Tie-in RA Marker in BOT Deployment Sleeve Found RA at 9913 ft (-3 ft) 02:50 - 03:00 0.17 CASE N DFAL LNR1 RIH to 10,200 ft and orient TF to 160R. PUW = 28.3k. Orient TF to 160 R 03:00 - 03:40 0.67 REMCM N DFAL LNR1 RIH and tagged at 10,225 ft, PUH, clean. Work down and had several stalls trying to get started. Stalling at 10,225 ft. Clean pickups after stalls Op = 1.75 bpm CTP = 2725 psi; TF at 177 R 03:40 - 04:15 0.58 REMCM N DFAL LNR1 Oriented TF to HS for a test TF at 14L RIH and 50 psi motor work at 10,223.7 ft Unable to get past 10,225 ft at 14L TF Orient TF to 98 R and try it there. 04:15 - 05:45 1.50 REMCM N DFAL LNR1 POOH to plan way forward 05:45 - 06:30 0.75 REMCM N DFAL LNRi OOH, LD Sperry BHA 06:30 - 08:00 1.50 REMCM N DFAL LNRi PU 1.875 mill, motor assembly, 4 jts 1" CSH, MHA. Stab on injector. 08:00 - 09:45 1.75 REMCM N DFAL LNR1 RIH with milling BHA at 100 fpm, pumping minimum rate. 09:45 - 10:30 0.75 REMCM N DFAL LNR1 Tie in to flag at 10,000' -- Correct depth to 10,137.6' MD. RIH. Tag at 10,219.9' MD, no-go. - Bring pumps up to 1 bpm, 1650 psi free spin. - 28.5k PU, 11.3 k SO. - Mill at restriction. Slowly drilling off to 10,220.4' MD. 10:30 - 12:00 1.50 REMCM N DFAL LNR1 PU. SO. Tag at 10,220.4' MD. Mill to 10, 222.7 MD - Pumps at 1 bpm, 1650 psi free spin. - 27.4k PU, 11.4 k SO. - Milling metal/cement. - Decision to POOH for slickline LIB. 12:00 - 13:30 1.50 REMCM N DFAL LNR1 POOH for slickline LIB/Drift run(s). 13:30 - 14:30 1.00 REMCM N DFAL LNRi LD BHA. 14:30 - 17:00 2.50 REMCM N DFAL LNRi PJSM. Spot and rig up slickline. MU Spang jars, knuckle joint, oil jars, and 2" tapered LIB. 17:00 - 20:00 3.00 REMCM N DFAL LNR1 RIH with LIB on slickline. RIH w/ 2" LIB and tagged at 10231 ft. Took impression. POOH 2" LIB showed parted liner, Ref tp photos 20:00 - 00:00 4.00 REMCM N DFAL LNR1 Wait on drivedowh 1.25" bail from Halliburton. RIH w/ 1.2" bailer, WB and 2.25" No/Go. Tagged at 9666 ft WLMD (Patch), unable to pass, POOH and shorten the stinger to 10 ft, RIH tagged 96666 ft ,POOH, RIH w/ 1.25" Bull plug. 11/7/2004 00:00 - 01:00 1.00 REMCM N DFAL LNR1 RIH and passed patch area after 6 attempts, RIH and tagged at 10231 ft. Worked 1.25" bull plug through parted liner area. got Printed: ti/1'L/'LUUtl IU:Utl:SU HM • • BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: E-18 Common Well Name: E-18 Spud Date: 9/26/1981 Event Name: REENTER+COMPLETE Start: 10/21/2004 End: 11/8/2004 Contractor Name: NORDIC CALISTA Rig Release: 11/8/2004 Rig Name: NORDIC 1 Rig Number: N1 Date -From - To Hours Task Code NPT Phase Description of Operations 11/7/2004 00:00 - 01:00 1.00 REMCM N DFAL LNR1 2 ft at best. Pulled tight once. POOH and RD WL 01:00 - 01:35 0.58 REMCM N DFAL LNR1 Move WL truck and loaded milling tools into pipe shed PU 2.79" Tapered mill, MM, CS, HDC, 2 WB, DCV, CTC 01:35 - 03:30 1.92 REMCM N DFAL LNRi RIH, (Corrected -20 ft at flag), RIH and tagged at 10217 ft 03:30 - 11:00 7.50 REMCM N DFAL LNR1 Milling on liner 11:00 - 13:00 2.00 13:00.- 21:30 8.50 21:30 - 21:55 0.42 21:55 - 23:45 1.83 23:45 - 00:00 0.25 11 /8/2004 100:00 - 04:00 I 4.00 04:00 - 06:30 2.50 REMC 06:00 - 08:00 2.00 REMC 08:00 - 10:00 2.00 REMC 10:00 - 11:00 1.00 REMC 11:00 - 11:30 0.50 REMC 11:30 - 13:15 1.75 REMC 13:15 - 13:30 0.25 REMC 13:30 - 14:15 0.75 REMCM N 14:15 - 16:15 2.00 REMCM N 16:15 - 17:00 0.75 REMCM N 17:00 - 18:30 1.50 RIGD P 18:30 - 20:00 1.50 RIGD P Op = 1.73/1.83 bpm CTP 2373 psi Time drill from 10217.2 ft to 10217.7 Slow starting Made no headway. DFAL LNR1 POOH, look at mill. DFAL LNR1 Waiting on Mill. DFAL LNR1 PU 2.5" Tapered mill DFAL LNRi RIH Corrected to EOP flag - 28 ft DFAL LNR1 Working mill down. Stall # 1 at 1016.6 ft Started milling at 1021.6.4 ft Op = 1.84/1.90 bpm CTP 2347 psi. Vp = 298 bbl lost 35 bbl since last night. DFAL LNR1 Milling without much success. Made no progress in 4-1/4 hrs Op = 1.84/1.90 bpm CTP 2347 psi. Unable to make any head way with mill DFAL LNR1 POOH. LD BHA. DFAL LNR1 Wait on orders. DFAL LNR1 Wait on SLB for GR/CCL log DFAL LNR1 PU and program tools. DFAL LNR1 PJSM. MU GR/CCL logging tools, MHA and 2.5" nozzle. DFAL LNR1 RIH at 100 fpm. - Circulate in KCI. DFAL LNR1 Tag restriction at 10247.8' CTMD - POOH logging at 60 fpm - Log to 9500 ft. - Pumping at 1.5 bpm. DFAL LNR1 Drop 5/8" steel ball for circ sub. Circulate down. Shear ball seat 38.1 bbls.. DFAL LNR1 POOH at 100 fpm swapping well to KCI. - Pump in 60/40 MEOH from 2200' MD. DFAL LNR1 LD Memory Tools POST Cleaning pit and hauling out fishing tools Closed Tree 34 turns POST ND BOP's, PT Tree Cap to 3500 psi. Rig Released at 20:00 hrs 11-8-2004 Printed: 6/12/2008 10:08:50 AM E-18B Well History -Suspended Well Date Summary 12/21/2004 T/I/O=SSV/180/40. Temp=Sl. TBG & IA FL's, (for EL). Cannot access swab valve for TBG FL due to no scaffold on well head. IA FL C~3 1302' (69 bbls). 12/22/2004 T/I/O=SSV/240/60. Temp=S1. TBG FL, (for EL). Cannot get TBG FL due to lock out on master valve. IAP increased 60 psi and OAP increased 20 psi overnight. 12/23/2004 T/I/O =VAC/240/90. Temp = SI. TBG FL (For EL). TBG FL near surface. OAP increased 30 psi. overnight. 5/31/2005 T/I/0= 0/500/0. Pumped 62.6 bbls crude to reach 3000 psi.for MITxI.A.(PASSED) on 2nd test. Loss of 120 psi.1 st 15 min. loss of 60 psi. 2nd 15 min. FWHP= 0/500/0. 5/31/2005 TIO=SSV/540/40, SI. IA FL C~ surface. OA FL C«3 36' (2 bbls). Pre MITIA / MITOA CTD Screen. 6/19/2005 T/I/0=210/600/50. Temp=S1. IA & OA FL. (Pre MIT). IA FL C«3 220' (12 bbls), OA FL near surface. 6/26/2005 .WELL S/I ON ARRIVAL. RU DATA CRANE. RIH WITH 3.70 X 20' DMY WHIPSTOCK. 6/27/2005 BRUSHED PATCH W/ BLB & 3.50" G-RING, TAG C~ 9895' SLM. DRIFTED W/ 20' x 3.65" DMY WHIPSTOCK TO 9895' SLM. DRIFTED W/ 2.80" SWAGE TO 10,170' SLM. WELL LEFT S/I, PAD-OP NOTIFIED. 7/14/2005 T/I/O = 890/500/0 Pressured packoff to 3000 psi. Pressure was 3000 psi at 15 min and 3000 psi at 30 min. Test passed. Lockscrews were functioned and torqued to 450 ft lbs. Tested tubing hanger to 5000 psi. Pressure was 4900 psi at 15 min. and 4900 psi at 30 min. Test passed. Several lockscrews were frozen. 7/15/2005 SET BAKER 035 CAST IRON BRIDGE PLUG IN 3 1/2" 9.3# TUBING AT 10100'. DETONATED TUBING PUNCH AT 9998'-10000'. NOTIFY DSO OF WELL STATUS. 7/15/2005 T/I/0=100/510/50. Assist E-line [pressure test plug] MIT TBG C~ 1000 psi [FAILED] Pumped 8.5 bbls to pressure. First test failed. Lost 150 psi in 15 min. 2nd test failed. Pumped .3 bbls diesel to pressure. Lost 150 psi in 15 min. Bled pressure down. Final WHP's=0/520/50. 7/19/2005 SHOT STRINGSHOT AT 10063'-10076'. CHEMICAL CUTTER MISRUN. FIRED CHEMICAL CUTTER AT 10073'. JOB COMPLETED AND NOTIFIED DSO. 8/4/2005 T/I/O = BOP's/600/30 Temp = SI. TBG & IA FI's (for CT). BOP's on tree. Only 1 IA casing valve. (Hard line rigged up on IA valve with diesel present from PT.) Was able to get WHP's on IA & OA. 8/6/2005 Conduct BOPE test as per BP and AOGCC procedures -Good Test. MU 4" GS BOT fishing BHA. RIH, park coil at 9825' and condition hole w/200 bbls 1 %, 25 bbls Flo Pro. Set Down, latch liner and make 30 jar licks with last 15 at 25k over. Pump off and POOH. MU 2" JSN and RIH. Tag CIBP at 10105' ctm. Pump 20 bbls 1 % KCL and then start chasing OOH at 80%. 8/7/2005 RIH with string shot from 10050' to 10063'. RIH with chemical cutter and cut pipe at 10060'. RD/ Stand back SLB a-line. 8/8/2005 SHOT A 2.38" CHEMICAL CUTTER AT 10060'. SEVERING HEAD INDICATES GOOD CUT. SHOT A ONE STRAND STRING SHOT FROM 9980'-9992' PRIOR TO RUNNING CHC. STAND BACK AND WAIT FOR COIL TO FISH LINER. 8/8/2005 MU / BOT fishing BHA #2 RIH and engage fish at 9902' up CTM. Attempt to free liner with total 50 jar licks with increasing and decreasing weights from 10 k to 25 k overpull. Fish did not pull free. Release from fish and POH. Prep to chemical cut liner at 9995'. Cap well to 1100' with 25 bbls of 50/50 meth down backside while POOH. Lay mast down for a-line. RIH and chemical cut pipe at 9990' (there was a collar at 9995'). Raise mast, cut 150' pipe MU / BOT / BHA # 3. Page 1 of 2 • E-18B Well History -Suspended Well Date Summary 8/9/2005 RIH with BHA # 3 -conduct no flow test prior to engaging fish. Attempt to pull liner with 50 jar licks, alternating weights up /down by increasing and decreasing weights in 5 k increaments to max over pull. Liner did not come free. Pump off and POH. FP well to 2500. LD tools and mast. Prep for 4th chemical cut. Job scope change. Slickline will pull deployment sleeve. RDMO, JOB NOT COMPLETE - COULD NOT PULL LINER. NOTE: Deployment sleeve has 3 PIP (RA) tags installed. 8/9/2005 RAN 1 STRAND 12' LONG STRING SHOT FROM 9916' - 9928'. SHOT 2.38" CHC AT 9926'. SEVERING HEAD INDICATES GOOD CUT. THIRD CHC AS PART OF PRERIG WORK. UNIT RELEASED AFTER 4 DAYS AND 3 TOTAL CUTS. 8/10/2005 PULLED DEPLOYMENT SLEEVE W/ 10' OF LINER, SWS TOOK DEPLOYMENT SLEEVE TO REMOVE RA TAG. WELL LEFT SHUT-IN NOTIFY PAD OPERATOR. 4/3/2008 T/I/0= 0+/470/0+. Temp= SI. IA & OA FL (RST screening). IA FL C~ 174' (10 bbls). OA FL C~ 42' (3 bbls). Well house still covering well, but flowline has been removed. 4/6/2008 SVC MASTER , I/A & O/A ,RESET DRIFT ON I/A 3 1/8 mod 75 fmc. / for hot oil . / T-250 I/A-410 / O/A-0 4/6/2008 T/I/0=0/500/0 MIT IA PASSED to 3000 psi, MITOA PASSED to 200~si. (RST Screening) Pumped 15 bbls crude down IA to reach test pressure. IA lost 140 psi in 1st 15 min and 60 psi in 2nd 15 min for a total loss of 200 psi in 30 min. Bled IA back to 500 psi . T/I/0=20/300/40 Pumped 3.3 bbls of crude down OA to reach 2000 psi. OA lost 0 psi in 30 min. Bled OA back to 0 psi, 2 bbls returned. Final WHP= 20/340/0. Casing valves open to gauges and tagged. 4/10/2008 T/IA/OA= 0/400/0 Temp= warm PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RST). Torque LDS "Standard style" (1) bent pin will move, (1) stuck pin, and one in the out position, all others were in good condition. PPPOT-IC RU 1 HP bleed tools onto IC test void 50 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3400/ 15 minutes, 3400/ 30 minutes. Bleed IC void to 0 psi, RD test equipment. Cycle and torque LDS "Standard style" all moved with no problems. 5/1/2008 RIH W/3.72" x 80" DUMMY DRIFT, SAT DOWN ON PATCH C«~ 9652' MD. RAN 4-1/2" BRUSH 3.50" GAUGE RING TO LNR TOP C~ 9926' MD.:ATTEMPT TO RUN 3 ~~" Y Rn~~ rn innnnv nHiFT. uNa~~t i c~ PASS THROUGH PATCH ~ 9652' MD. RAN 3.705" CENT, 3.72"SWAGE BARBELL SETUP, UNABLE TO PASS 9652' MD. 5/2/2008 RAN 3.705"CENT, 3.25"CENT BARBELL SETUP (SETS DOWN BUT FALLS THROUGH PATCH AT 9652' MD). RAN 3.25"CENT, 3.70" BROACH (TOOLS S/D AT PATCH BUT ABLE TO WORK THROUGH). RAN 3.25" CENT, 3.75" STIFF BRUSH, MAKE SEVERAL PASSES THRU PATCH C~ 9652' MD. RAN 3.72" x 88" DUMMY DRIFT, SAT DOWN IN PATCH Q 9652' MD. RAN 3.70" CENT., 1-7/8" x 5' WB, 3.70" CENT., DRIFT THRU PATCH C~? 9652' MD, NO PROBLEMS. RAN 1-7/8" x 2' WB, 4.00" GAUGE RING, TAG TOP OF PATCH C~3 9648' SLM -FLAG LINE SET 4.5" WRP (3.69" O.D x 3.90' OAL1 C~ 9834' MD. GOOD SET., RAN 3.60" BELL GUIDE, 2" SS TO FISH DROPPED SHEAR SUB C~3 9829 SLM (RECOVERED). LEFT WELL SI AND TURNED OVER TO PAD OP. Page 2 of 2 Halliburton Sperry-Sun North Slope Alaska BPXA E-186 Job No. AKMW3369841, Surveyed: 2 November, 2004 Survey Report 75 November, 2004 Your Ref: API 500292065402 Surface Coordinates: 5975211.00 N, 664487.00E (70° 20' 18.8755" N, 211 ° 20' 05.1322" E) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 60.50ft above Mean Sea Level A Haliiburton Company DEFI~lITfVE Survey Ref: svy4441 • Halliburton Sperry-Sun Survey Report for E-186 Your Ref: AP1500292065402 Job No. AKMW3369841, Surveyed: 2 November, 2004 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 10200.00 33.300 190.190 8106.08 8166.58 5004.98 S 56.22 W 5970205.99 N 664540.59 E 10212.00 33.090 190.320 8116.12 8176.62 5011.45 S 57.39 W 5970199.50 N 664539.56 E 10243.71 28.280 188.800 8143.38 8203.88 5027.40 S 60.09 W 5970183.49 N 664537.21 E 10278.79 23.380 186.290 8174.95 8235.45 5042.54 S 62.12 W 5970168.31 N 664535.51 E 10308.62 19.820 189.450 8202.68 8263.18 5053.41 S 63.60 W 5970157.41 N 664534.27 E 10339.14 16.120 189.980 8231.71 8292.21 5062.69 S 65.19 W 5970148.09 N 664532.89 E 10375.00 16.120 189.980 8266.16 8326.66 5072.50 S 66.91 W 5970138.25 N 664531.38 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True N orth. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 85.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10375.OOft., The Bottom Hole Displacement is 5072.94ft., in the Direction of 180.756° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 10200.00 8166.58 5004.98 S 56.22 W 10212.00 8176.62 5011.45 S 57.39 W 10375.00 8326.66 5072.50 S 66.91 W Comment Tie On Point Window Point Projected Survey Dogleg Vertical Rate Section Comment (°/100ft) -492.22 Tie On Point MWD Magnetic 1.847 -493.95 Window Point 15.364 -498.03 14.309 -501.37 12.551 -503.80 12.135 -506.18 0.000 -508.76 Projected Survey BPXA :~ • 15 November, 2004 - 17:18 Page 2 of 3 Dril/Quest 3.03.06,006 North Slope Alaska Survey tool program for E-18B From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 10200.00 8166.58 10200.00 8166.58 10375.00 8326.66 Halliburton Sperry-Sun Survey Report for E-186 Your Ref: API 500292065402 Job No. AKMW3369841, Surveyed: 2 November, 2004 BPXA Survey Tool Description BP High Accuracy Gyro -Boss-Gyro (E-18) MWD Magnetic (E-186) • 15 November, 2004 - 17;18 Page 3 of 3 DrillQuest 3.03.06.006 TREE = CNV 6 3/8" WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 60.45' BF. ELEV = 31.72' KOP = 2600' Max Angle = 95 @ 11553' Datum MD = 11119' Datum TV D = 8800' SS 9-518" DV PKR 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" Minimum ID = 2.370" @ 9862' TOP 2-718" LNR 21' MERLA TBG PATCH ID = 3.75" 5-1/2" TBG, 17#, L-80 IJ4S IPC, .0232 bpf, ID = 4.892" 4-1/2" WRP (3.69 OD)(05/02108) SPECIAL CLEARANCED TOP OF 7" LNR ~3-1/2" LNR STUB (08/09105) 4-1/2" TB, 12.6#, L-80, .0152 bpf, ID = 3.958" TOP OF CEMENT (12/24/04 CMT BOND LOG) GEN II MECHANK:AL WHIPSTOCK (11/02/04) RA TAG 2-7/8" LNR STUB (09117104) I9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" 7" LNR, 26#, L-80 U4S, .0383 bpf, ID = 6.276" 9834' I 10086' I PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Oon/Sqz DATE E-18B S OTES: MERLA TBG PATCH 9652'-9673' MD, OVER GLM 1, ID = 3.75" SSSV OTIS ROM NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2891 2821 12 MMIGW DMY RK 0 12/22/03 11 5119 4533 49 MMIGW DMY RK 0 12/22/03 10 6890 5657 49 MMIGW DMY RK 0 10/14/81 9 6996 5720 50 MMIGW DMY RK 0 10/14/81 8 7871 6295 51 MMIGW DMY RK 0 10/14/81 7 7974 6371 52 MMIGW DMY RK 0 10/14/81 6 8549 6808 53 MMIGW DMY RK 0 10/14/81 5 8656 6893 53 MMIGW DMY RK 0 10/14/81 4 9071 7219 54 MMIGW DMY RK 0 10/14/81 3 9177 7301 53 MMIGW DMY RK 0 10/14/81 2 9551 7590 45 MMIGW DMY RK 0 10/14/81 *1 9655 7670 43 MMIGW DMY RK 0 10/14/81 "` CiLM #1 C:UV tKtl.) tiY MtKLH I tSli F'H I l;ti * GEM'S # 11 & # 12 =EXTENDED PACKING 9723' 5-1/2" BKR L SLIDING SLV, ID = 4.562" -805' TUBING SEAL ASSY, ID = ? 9825' 9-5/8" X 4-1/2" BKR SAB PKR, ID = 3.813" 9856' 9-5/8" X 7" BKR HYDRO HGR w /TIEBACK, ID = 6.25" 9$$2' 4-112" OTIS X NIP, ID = 3.813" 9920' I~ 4-112" OTIS XN NIP, ID = 3.725" 9965' --{ 4-1/2" BAKER WLEG, ID = 3.958" 9940' -{FEND TT LOGGED 05!03(89 10100' 3-1/2" CIBP(07/15/05 I MILLOUT WINDOW (E 18B) 10216' - 10221' I 10225' CTMD 3-1/2" PARTED/ DAMAGED LNR ~~ 10234' MCCL/GR DEPTH PBTD 3-1/2" LNR, 9.3#, L-80 STL, .0087 bpf, ~ = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14/81 ORIGINAL COMPLETION 08/08/07 GJB/PJC CH9v1 CUT @ 9990" 05/07/97 RW CTD SIDETRACK "A" 08/10/07 KSB/PJC PULL DEPLOY SLV @ 9914' 11/09/04 NORDIC 1 CTD SDTRCK "B" SUSPBJD® 10/25/07 JSR/PJC DREG DRAFT CORRECTIONS 07/15/05 RAC/TLH SET CIBP 11/26/07 JSR/PJC DREG DRAFT CORRECTIONS 07/19/05 WJW TL CHEM CUT @ 10073' 05/05/08 KJB/PJC SET WRP (05/02/08) 08/07/05 JGMIPJC CHEM CUT @ 10060' PRUDHOE BAY UNIT WELL: E18A PERMR No: 1970690 API No: 50-029-20654-01 SEC 6, T11N, R14E, 1853' SNL & 501' WEL BP Exploration (Alaska) • C01~5ER~TIO C hIIII SIpH Jacki Randall E Pad Engineer BP Exploration Alaska Tnc. PO Box 196612 Anchorage, Alaska 99519-6612 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU E-1 SB Sundry Number: 307-370 a~~~ ~ ~~ Dear Ms. Randall: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of January, 2008 Encl. ~' j 9/~ ~ _~j STATE OF ALASKA '~ RE~~I1~/~ ALASIL AND GAS CONSERVATION COMM~N APPLICATION FOR SUNDRY APPROVA +~~~ EC 1 2 ~Op~ 20 AAC 25.280 dlaska (lil fL rac f'nnc P^nr.~~~~~,,., 1. Type of Request: ^ Abandon ~ ®Suspend ^ Operation Shutdown ^ Perforate ^ Time Ext~4#IghOfBgL ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-139 / 305-144 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20654-02-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU E-18B . Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ~ ADL 028304 ~ 60.5' ~ Prudhoe Ba Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10374 8265 10234 8196 10100 10234 I ~~ ' 7 7' 1 4 'n r 7 ' 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None s-,rz~~, ~~n X a-~rz~~,,z.sa L-80 9965' Packers and SSSV Type: 9-5/8" Baker'SAB' packer; Packers and SSSV MD (ft): 9825' Otis 'RQM' SSSV Nipple 1996' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: Upon Approval To Proceed ^ Oil ^ Gas ®Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Jacki Randall, 56a-4590 Printed Name Jacki Randall Title E Pad Engineer ,^ Prepared By Name/Number: Signature ~' " ~,~ " Phone 564-4590 Date 12 ~ `~- Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: ~- Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: Subsequent Form Required: ~~~ APPROVED BY /~ Y ~ C~ A roved B : MMISSIONER THE COMMISSION Date l/ Form 10-403 Revised 06/2006 v ~ ~~ Submit In Duplicate ~~~~ ~~~„ ~a~ ~~ ~oo~ O R I G I NA L • by To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Jacki Randall E-Pad Engineer Re: Change E-18B status from Operations Shut down to Suspended Sundry Approval is requested to change the status of E-186 from operations shut down to suspended. Operations were suspended on 11/16/04 with plans to resume on 8/5/05. The following describes the work planned to place the well in suspended status. r Well Status ~~o~sw~.•~~i c~ iO~ l40 The well is shut in due to parted/collapsed 3-1/2" STL LNR at 10234'. The liner parted/collapsed due to a high dogleg window and lower strength during the first E-186 sidetrack attempt. In an attempt to resume the sidetrack in 6/05 a CIBP was set at 10100'. The subsequent pressure testing of the tubing to 1000 psi failed. E-line attempted three chemical cuts on the 3-1/2" STL LNR at 10073', 10060', and 9926' above the top of LNR cmt top at 10075'. Service coil latched on after the first two cuts and was unable to move the LNR. After the third cut slickline fished out the deployment sleeve and 10' of LNR. This moved the kick out point into the upper Kingak inaccessible to coil tubing drilling and operations were shut down. Plan Forward This well is slated for rig sidetrack in the future. To place the well in suspended status the well needs to be secured. Plan to secure the well is as follows: 1) slickline -Drift tbg to 9900' with 3.72° dummy & Set 4-1/2" WRP (turned down to 3.688" ID) at 9850' Jacki Randall E-Pad Engineer 564-4590 CC: Well File Terrie Hubble • Wireline Work Request Alaska Wells Group ril 2006 / J~16 2007 (TLH E-18B Well: E-~ 8B AFE: PBEPDWL18-M H2S: Date: 11/16/07 Engineer: Ja_c__ki Randall_ 10-403? IOR 0 WB~ Cat. _ _ REG COMPL 10-404? AWGRS Job Scope: PACKERS/BRIDGE PLUGS (INTEGRITY; 5 ppm (6/4/01) Y Y Problem Description E-18B is a LTSI well SI during drilling operations due to a split/collapsed LNR. The objective_of this program is tos_e_c_u_re the well to change the status from ops_shut down to suspended. Initial Problem Review > 07/27/04: PPPOT-T Passed, PPPOT-IC Passed, LDS cycled OK --._. _ > 07/29/04: MIT-IA to 2500 psi -Passed _ _____ ___ _ _ > 08/02/04: Tree Valves passed PT _____ ___ ___ ___ _ > 08/06/04: MITOA Passed to 2000 psi __ _ __ > 08/15/04: Set CIBP @ 10280' MD _____ _ __ > 08/24/04: MITIA Passed to 2500 psi _____ > 05/31/05: MITIA to 3000 psi Passed _ __ > 06/22/05: MITOA Passed to 2000 psi _> 07/1.4/05: PPPOT-T Passed to 5000 psi, IC Passed to 3000 psi,_several LDS on Tbg hanger stuck > 07/15/05: CIBP set a~ 10100'; MIT-T Failed to 1000 psi ___ _ _ _ > 07/19/05: Chem cut tubing @ 10073'_ ____ ___ _____ ___ _ > 08/07/05: Chem cut tubing @ 10060' _ ____ __ ____ _ __ > 08/10/05: Fished deployment sleeve and liner top Remedial Plan - WIRELINE ACTION Obj. Set WRP 1. S: Drift tba to 9900' w/ 3.72" dummy & Set 4-1/2" WRP (turned down to 3.688" ID) at 9850' TREE _ _ CNV 6 3/8" WELLHEAD = ~ FMC ACTUATOR= OTIS KB. ELEV = 60.45' BF. ELEV = 31.72' KOP = 2600' Max Angle = 95 @ 11553' Datum MD = 11119' Datum TV D = 8800' SS S NOTES: MERLA TBG PATCH 9652'-9673' PJ E,~~ $B M RGLM1,ID=3.75" DRAFT 1996' SSSV OTIS ROM NIP, ID = 4.562" hAR I IFf MANDRELS 9-5/8" DV PKR I-~ Z5SC '8" CSG, 72#, L-80 BTRS, ID = 12.347" ~ 26$f Minimum ID = 2.370" @ 9862' TOP 2-7/8" LN R 21' MERLA TBG PATCH ID = 3.75" 9652' - 5-1/2" TBG, 17#, L-80 IJ4S IPC, .0232 bpf, ID = 4.892" ~3-1/2" LNR STUB (08/09/05) ~• 4-1/2" TB, 12.6#, L-80, .0152 bpf, ID = 3.958" TOP OF CEMENT (12/24/04 CMT BOND LOG) GEN II MECHANICAL WHIPSTOCK (11/02/04) 12-7/8" LNR STUB (09!17/04) 9-518" CSG, 47#, L-80 BTRS, ID = 8.681" ~- 7" LNR 26#, L-80 IJ4S, .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ST MD TV D DEV TYPE V LV LATCH PORT DATE 12 2891 2821 12 MMIGW DMY RK 0 12/22/03 11 5119 4533 49 MMIGW DMY RK 0 12/22/03 10 6890 5657 49 MMIGW DMY RK 0 10/14/81 9 6996 5720 50 MMIGW DMY RK 0 10/14/81 8 7871 6295 51 MMIGW DMY RK 0 10/14/81 7 7974 6371 52 MMIGW DMY RK 0 10/14/81 6 8549 6808 53 MMIGW DMY RK 0 10/14!81 5 8656 6893 53 MMIGW DMY RK 0 10/14/81 4 9071 7219 54 MMIGW DMY RK 0 10/14/81 3 9177 7301 53 MMIGW DMY RK 0 10/14/81 2 9551 7590 45 MMIGW DMY RK 0 10/14/81 *1 9655 7670 43 MMIGW DMY RK 0 10/14/81 ** GLM #1 GC.)V t-J•tkL.) kiY MtKLH I tSCi rH ~ lrYi * GLMS # 11 & # 12 =EXTENDED PACKING I I 9723' S-1/2" BKR L SLIDING SLV, ID = 4.562" 9$05' TUBING SEAL ASSY, ID = ? 9$25' 9-5/8" X 4-1/2" BKR SAB PKR ID = 3.813" 9$56' 9-5/8" X 7" BKR HYDRO HGR w /TIEBACK, ID = 6.25" g$$2' 4-1/2" OTIS X NIP, ID = 3.813" 9920' ~ 4-1 /2" OTIS XN NIP, ID = 3.725" 9965' 4-1/2" BAKER WLEG, ID = 3.958" 9940' ELMD TT LOGGED 05/03/89 10100' - 3-1/2" CIBP (07/15/05) MILLOUT WINDOW (E-188) 10216' - 10221' I 10225' CTMD 3-1/2" PARTED/ DAMAGED LNR PBTO 3-1/2" LNR, 9.3#, L-80 STL, .0087 bpf, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14/81 ORIGINAL COMPLETION 08/08/07 GJB/PJC CHEM CUT @ 9990" 05/07/97 RW CTD SIDETRACK "A" 08/10/07 KSB/PJC PULL DEPLOY SLV @ 9914' 11/09/04 NORDIC 1 CTD SDTRCK "B" SUSPENDED 10/25/07 JSR/PJC DRLG DRAFT CORRECTIONS 07/15/05 RAC/TLH SET CIBP 07/19/05 WJHI TL CHEM CUT @ 10073' 08/07/05 JGIWPJC CHEM CUT @ 10060' PRUDHOE BAY UNIT WELL: ~18A PERMff No: 1970690 API No: 50-029-20654-01 SEC 6, T11 N, R14E, 1853' SNL & 501' WEL BP Exploration (Alaska) V1A3LHEAD = FMC ACTUATOR= OTC KB. ELEV = 60.45' BF. ELEV = 31.77 KOP = 2600' Mt~x Angle = 35 ®11553' Datum MD = 11119' Datum TVD = 8800' SS 8" CSG, 72X, L-80 BTRS, ID = 12.347" H 2! Minimum ID = 2.370" ~ 9862' TOP 2-718" LNR E-18B Proposal 5-18" TBG, 17X, L-80 U4S IPC, 9805 .0232 bpf, ID = 4.892" 4-112" WRP 9860' TOP OF 7" LNR 9856' I3-112" LNR STUB (08!09/05) ~- 4-1 /2" TB, 12.8X, L-80, .0152 bpf, ID = 3.958" TOP OF C8IAENT (1284/04 CMiT BOND LOG) ~2-7/8" LNR STUB (09!17104) ~ 9-5/8" CSG, 47X, L-80 BTRS, ID = 8.881" 7" LNR, 26X, L-80 U4S, .0383 bpi, ID = 8.278' FB2FORATION SUMMARY REE LOG: ANGLEATTOPFERF: ~' Note: Refer to Roduction DB for historical pert data S OTES: MERLA TRIO PATCH 985Z'-9873' MD, OVER GLM 1. ID = 3.T5" 1 ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2891 2821 12 AAVKIN DMK RK 0 1282103 11 5119 4533 49 Al11AGW DMY RK 0 12!22!03 10 6890 5657 49 MMGW DRAY RK 0 1x14/81 9 6996 5720 50 MAAGW DMTY RK 0 1x14/81 8 7871 6295 51 AAVIGIN DRAY RK 0 10/14/81 7 7974 6371 52 MMK11V DRAY RK 0 1x14/81 6 8546 6808 53 MIMIGWI DMtY RK 0 1x14/81 5 8666 6893 53 MMIGW DNfY RK 0 1x14181 4 9071 7219 54 M91AGV11 DMY RK 0 10/14/81 3 9177 7301 53 MMGW DMY RK 0 1 x1 x/81 2 9551 7590 45 M1MGW DMtt RK 0 10/14/81 •1 9655 7670 43 MMGW DMY RK 0 1x14/81 " GLM X1 COVl3iED BY MHiLA ~BG NA f GFi ' GLMS X 11 b 812 =EXTENDED PACKING 9723' 5-1/2" BKR L SLIDING SLV, ID = 4.582" 980b' TUBgVG SEAL ASSY, ID = ? 982b' 9-5/8" X 41/2" BKR SA B PKR, ID = 3.813" 9-5/8"X7" BKR HYDRO HGR w /TIEBACK ID = 6.25" d-1 @" OTLS X NIP_ ID = 3.813" 9920' H418" OTIS XN NIP, ID = 3.725" 9966' 41/2" BA KER WLEG, ID = 3.958" 9940' ELMD TT LOGGED 05/03!89 10100' 3-18" CIBP (07/15!05) M~LOUT WNNDOW (E-1i8) 10216' - 10221' I 10225' CT M D 3-1 /2" PARTED/ DAMAGED LNR \ ~~ 10234' MCCL/GR DEPTH ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10M4181 ORGINAL COMPLETION 08!08107 GJBIPJC CHEM CUT ~ 9990" WE1L: E18A OS107187 RIN CTDSIDETRACK"A" OSI10/07 KSB/PJC PULL DEPLOY SLV X9914' PERMtTNo:'1970690 11/09101 NORDIC 1 CTD SQTRCK "8" SLt3P9VD® 1x25/07 JSR/PJC DRLG DRAFT CORRECTIONS API No: 50-029-20Ei54-01 07/15/05 RACfTLH SET CIBP 11/26/07 JSRIPJC DRLG DRAFT CORRECTIONS SEC 6, T11 N, R14E, 1853' SNL b 501' WEL 07/19/05 WJ W TL CHEM CUT ~ 10073' 08!07/05 JGMVPJC CHEM CUT ~ 10060' BP 6cploratlon (Alsska) r ~ Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, December 18, 2007 8:24 AM To: Maunder, Thomas E (DOA) Subject: RE: PBU E-186 (204-139) Attachments: E-18B Non-Rig Work.pdf Hi Tom, Page 1 of 2 There have been no rig operations since November 2004. Here are the non-rig work operations that have occurred since then. Do you need anything else? Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, December 17, 2007 4:16 PM To: Hubble, Terrie L Subject: RE: PBU E-186 (204-139) Hi Terri, We have discussed this well previously. I have shortened the original message we exchanged removing references to 05-28B. 1 am reviewing the sundry to change the well from OSD to Suspended. Are there any operational reports for activities since the well was OSD in November 2004? I suspect that you are planning to submit such reports with the 407 after the new plug is set in the well. Is it possible to send the reports that currently exist? That would help in the review. Thanks in advance, Tom Maunder, PE AOGCC From: Hubble, Terrie L [mailto:Terr're.Hubble@bp.com] Sent: Friday, September 07, 2007 2:27 PM To: Maunder, Thomas E (DOA) Subjects FW: PBU E-186 (204-139) Hi Tom, Per your questions below... PBU E-18B (PTD 204-139), which is currently in Ops Shutdown status. I have learned that there is isolation from the reservoir. The 3-1/2" liner was cemented in place and a CIBP was set in the tubing after the rig moved off. The Pad Engineer will ensure that everything is pressure tested and I expect to be submitting a Sundry shortly to change the status from Ops Shutdown to Suspended. Thanks, Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] 1/'7/2008 Page 2 of 2 Sent: Friday, August 03, 2007 9:09 AM To: Hubble, Terrie L Cc: Fleckenstein, Robert 7 (DOA) Subject: PBU E-186 (204-139} and PBU 05-28B (206-089) Terrie, Bob and I have some questions on these wells. E-18B -- This welt was granted operational SD via sundry 304-402 dated November 16, 2004 due to an obstruction in the newly cemented 3-1J2" liner. Sundry 305-144 was issued June 13, 2005 to re-start operations. We have 2 transmittal letters in the fi~ labeled E-186 PB. One is LWD data and the other survey data received in late 2005. There is no other information in the file. If operations were completed around late November 2005 the completion report should have been submitted some time ago. Would you please advise us of the well condition and submit the appropriate reports? Any report should also include the operations information from the activities conducted around November 2004. Also, see comment below. Thanks in advance, Tom Maunder, PE AOGCC 1 /7/2008 Well Hist©ry Weq babe Surnrnary E-18B 12/21!2004 T/VO=SSV/180/40. 7errp~l. TBG $ b FL's, (far H.}. Cannot access sw ab vakre for TBG FL due to no scaffold art we/ lA FL ~ (302' {fig bole}. E-188 12222004 T/VO=SSV240/60. Terre-SL TBG FL, (far ~}. Cannot g~'I't~ FL d~ to Irk aut an master valve. tAP itcreased 60 psi arxi OAPetcreased 20 psi overnight. E18B 1223/2004 T/VO = VAC240/90. Terre = St TBG FL (For ~}. TBG FL near surface. OAP increased 30 psi. overnght E18B 12242004 CBVBNT BOND LOG N3-12 " LN62 FB.D PICK TOG AT 10086 FT LOGt~ TO TOP OF 7w f_[+@i D~ SIT NSUE 4-12" TtJBNG tX1~AT® TO SWS fu84K)RY Gt~L DAT® $-IV01/-2004 E-186 5!'312005 T/YES 0<500r10'*CF~.LAR IS FI~..L OF WAT~t"' tab scaffokiirtg for tree, vaMe handle is gate for w ~g valve. Rrrrped 62.6 obis crude to reach 3000 psifor MttxlA.(HRSSB}j on 2nd best. Loss of 120 psi.lst 15 rrin. bss of 60 psi. 2nd 15 rrtrt. FV1A-~ 0/500 E t 8B 3/312005 T10=SS~J/540/40, SE W FL ~ surface. 0~4 FL ~ 36' {2 t~lsj. Pte MFFiA I MFTOVI CTD Screen. E 18B 6!6/2005 OA valve stil underwater, Unable to MT QA E~18B 6/19200.5 T/YCr`210/600/50. Tempel W 8~ QA FL. (PI'e MR}. IA FL ~ 220' (12 (tole), O~F1 FL near surface. E 186 61212005 MT OrA ---Travel and ~9 Up-- Cartintre on Next AWGRS E-186 6222005 TtO=SY580/40 MIT QA PASSE ~ 20(10 ~i {Shut h}{CTC3 Serest) O~Ai Pressured up w / 3 bbL~ ~sel Purnpeet.1st Test OA bet 40 psi b t5 min. w/ total bss of 80 psi b 3ti rrtrt. 2rd Test OA bet 20 psi in 15 rrin. w/ total of 30 psi b 30 mmRrr. Fnal WttPs= SY390/0 E-186 6262005 *"V1l~L Sfl ON ARRNAL"'" (drat for w ttipstock) Rl1 DATA CRAPE RH Wtl'H 3.70X20' DMY WHP5T10CIC "*".IOB OONT ON 6-27-05'"* E-18B 627/2005 "'.)OB OOtrf FROAA6-2605""' PIATCH tAY BLB 8 3.50' G-RNG, TAG ~ 9895' SLM DRFT® VW 20 x 3.65" DRAY VNiPSTOpC TO 9895' SLM. DRtF7H? WI 2.80" SWAGE TO 10,170' SLM """WB_L LBT S/( PAD-OP NOTFI®"" E-186 7/142005 T/YO = 890/50p10 Ptessun~ paclaoff to 3000 psi. i~essure was 3000 psi at 15 min ~ 3000 psi at 30 rrtrt. Test passed. Lockscrews were fur~tiorted ~ torqued to 450 ft bs. Tested tubng harder to 5000 psi Ptessure w as 4900 psi at 15 raft. and 49W psi st 30 mn. Test posed. Severs[ bckserew s w ere frozen. More ~rfo in padarff sectiar E 186 7/152005 SET BAI~t 035 CAST FiOM BR(DGE PLUG N 3 12" 9.3# TUBNG AT 10100 (PRE C1U} DEFONAT® TUBNG PI~JCFf AT 9998'-10000 **" P10TFY DSO OF W~L STATUS"" E 186 7/1502005 T/f~t 00/510V50 Assist El'ine [pressure test plug] M1T TBG ~ 1000 psi [FALH3~ Pumped 8.5 t~rls to pressure. First best faced. Lost 150 psi b 13 rm. 2nd test faced. Ptrrrpect .3 trots diesel to pressure. Lost 1511 psi b 13 men. t3fed pressure dow n. ~ Wkf's~1/520J50 E 18B 7/19/2005 SHOT Sl'RIY(~'iF10T AT 10063'-10076' (RiE CTD} CI.84ACAL CUTfB2 MSRIN FN® CFBNCAL CUiT82 AT 1(X173' ""`.~B COMPLETB3 APD NOTF® DSO'"' E18B 7232005 SET BPN / ~ RIG E 18B 8/412005 T/YO = BOPst600.30 Terre = SL TBG itE Mt FRs {far Ct). BOPs on tree. Only 1 IA casing vstve. (hard 6rte rigged up art Mt valve w~ diesel present from PF }. Was able to get WFf's ar Y4 & OA. E1t3B 8/52005 C1U 9 - 1314" Coi - Mtgl,! to WWP-Rep to test ROPE "" Cartinued on 8/fil05 WSR """ E-18A 8/62005 CTU 9 -13!4" coi "" Continued from 8~5 W5R "'"' Conduct ROPE test as pet BP and AOGCC procedures -Good Test- NU Baker fishing BFY4- IZM-i Print Date: 12/182047 Page 1 oft • Well Date Summary E18A 8/6/2005 CTU 9 -13!4" cot "'"" Corairued from 8/5!05 WSR """" Conduct BOPEtest as per BP and AOGCC procedures -Goad Test- NU 4" GS BOT fishng BFW- RH. Park cot at 9825' and cond'Rian hole w1200 bbls 1 %, 25 E>b~ Fla Ra. SD. Latch firer and males 30 jar hcfcs w ith last 15 at 25k aver. Punp off and POOH. MU 2" JSN and RN Tag Ct~ at 10105' etm. Purrp 20 bola 1% KCL and then start chasing OOH at 80°~........ '*' .JOB N PROGRESS """ E-18A 8/612005 C1U 9 -13/4 Cot '"*"` Continued from 8/6!05 WSR ""' Wal an scarce E-18B 816!2005 C1U 9 -1314" cot """' Co~irued from 8/5105 WSR """" Conduct BODE test as per F?i' and AOGCC procedures -Good Test- tiitJ 4" GS BOT fisting BHit- tilt. Park. cot at 9825' and condiion hole w/200 bb(s 1 °~, 25 obis Flo Ro. ~ Latch freer and make 30 jar ticks w ltr last 15 at 25k over. Pump off and POOH. AIU 2" JSN and Rli. Tag C13P at 10105' ctrn. Rrrrp 20 obis 1°~ KCL and then start chaslrg OOH at 80°~. Crane deWered to location had strand cable on w hip €xte. Order arx! w aR on cram'. "'"" Contnued an 8!7!05 WSR """` E 186 81612005 CTiJ 9 -1314" cot'"" Cordnued f coin 8/5/05 WSR """ Conduct BOPE best as per BP and ACX''CC procedures -Good Test N11 Bataer fishlrg BHA- Wi E-18A 8/7/2005 CtU 9 -1314 Cot """` Ccx~irued from 8Ati/05 WSR'"""" Wet on crane and ~. See separate E~tne WSR """ .106 N PROGt~S - PB~DIJO ~Ll~E '"" E18B 8/7!2005 SS NT132VAL 10049 - 10061 Ff CHC AT 10060' E-18B 817!2005 CTU 9 -13/4 cot """' Continued from8l61tJ5 WSR'"'" Wad an cram and Etrre. See separate E-~e WSR Rll-1 w ith sting snot from 10tl50' to 100&3` - Rl-1 w qtr c~emlcal cutter and cart pipe at 10060'. ROV Starxi back SLB e-~ *`"" CArrtltued on 8!8/05 WSR "°"" E 18A 8/8/2005 "*` Continued from VU6R 8/7105 "`"" MJ / BOT fishing BFY4 #2 RH and engage fish at 9902` up CiM Attempt to free tner w ltr tota150 jar 1ck5 w Rh increasing and decreas'rrg w eigt~ from i 0 k to 25 k overput. Fish did not put free. release fromfish and POFi Rep to cherricai cut firer at 9995'. E~18B 8/8/2005 SHOT A 2.38" (~-841('AL tXll-!Bt AT 10060`. SEi/B21VG H6+1D NDICATES GOOd CCIT. SHOT A OPE S'tf?APD STRNG SHOT t~01N 9980'-9992' PRIOR TO F CHC. STAFD BACK AND WAR FOR COL TO FRSti Lf~}Z E-186 8!8/2005 CiU #9 w 11.75" CT. ""'" Continued from W5R 8!7105 "'" NI1 / BOPT fisni~ BHA #2 tali arxi engage f fish at 9902' up CTAIt Atberrpt to free finer w lh tots 50 jar ldc4 w ~t iricreasir~ and decreases w eights from 10 k to 25 k overpul. Fah did not put free. release from feh and POFi Rep to cherricai cut finer at 9995'. Cap w e1 to 1100' w llr 25 obis of 50/50 metre dew n backside w hie PC70Fi Lay mast dow n for e- lse. RH and ctterriical cut pipe at 9990' (there w as a solar at9995q Raise nest, cut 1501 pipe MJ / BOT / i#if1 # 3 ""'Cont~ue on 8/9105 WSR """ E-186 8/82005 CTU #9 w /1.75" CT. """"Continued from WSR $(7105 "" fdU / BOT fishing Btu ~2 Rii and engage fish at 990'1' up CiM Atberrpt kt free freer w Rh tots 50 jar leks w iEtr ixreasirg and decreaslg w eghts from 10 k to 25 k onrerpW. Fsh did ~ pu1 free. release from fish and POFt Rep to ctrerrical cut freer at 9995'. Cap w et to i 10EP w ih 25 bola of 5015f! meth dow n backside w hie F00F1 Lay rn~t dow n for e- ~re. "`"` JOB N PROGRE55 - PB~DHIG ~LNE "" E~186 8/912005 "*" WB1 SHIJf-1N"" (fish finer tap } "'" JOB N P OOFtf ON WSR 8-t0-05"" f=18B 8/92005 CTiJ iE9 w ti .75" Cf : '""' C~nued from 8JSIt}5 W5R'"'" Rl~t w iM ~- ~ 3 - cardud ra fbw best poor to ergagirg fish. Atberrpt to put trer w ih 50 jar 1dcS, atemating w eigtrts up / dow n by ercreas'srg and decreasing w eights n 5 k ircreaner~ to nex over ~. Li>~ did rat c:orne free. Pump off and POFi. FP w el to 2500. LD tools and mast. Rep for 4th cherricai cut. Job scope change. S'lcidrre w ~ puN depbymerrt sleeve. RDM(} '"` JOB NOT CONPLE"tE -COULD NOT PULL LF~2 "" NOT<= Depbyrrent sleeve has 3 PP {RA} tags instated. ~18B 8!912005 OOIJfI~J® FROtiA t'REVfOUS t]AY. RAN 1 STRAND 12' L(7NG S1RNC SHCTT FrOM 9916' -9928'. SHOT 2.38" (~iC A7 9926'. Stl/t3~ lf1lD !~tJICAiES GOOD (~.lF. TffiD CHC AS P14RT OF PR67Jf' WORK tai' RH..t~St~ AFt132 4 D4YS AND 3 TOTAL Ct1TS. E18B 8/102008 *" OOFJR~Jt~ FrCXN4 WSR 8-09-05 "` (Re CTD} PULL1~ DEPLOYAIB~tT SLEi?1/E W/ 1U OF Ll~Bt, SWS TOOK DB'LOYI~B~iT SL~1/E TO RButON/E RA TAG **` Wf3L Ll~l' SHUT N NOTFY F14D OP67ATOR "'" X186 8/142005 Cost placehotder for welding lEbndiee tool har~rg ec~rgmerrt ~ 186 8/162005 SET BP1! FOR rIG TO t11O1/E OFF Print Date: 12/182007 Page 2 oft ~ ~ AAaunder, Thomas E (DOA) To: Hubble, Terrie L Cc: Fleckenstein, Robert J (DOA) Subject: P~`1`E~-'f86 (204-fi3'~and PBU 05-28B (206-089} Terrie, Bob and I have some questions on these wells. Page 1 of 1 E-18B -This well was granted operational SD via sundry 304-402 dated November 16, 2004 due to an obstruction in the newly cemented 3-1/2" finer. Sundry 305-144 was issued June 13, 2005 to re-start operations. We have 2 transmittal letters in the file labeled E-18B PB. One is LWD data and the other survey data. There is no other information in the frle. If operations were completed around late November 2005 the completion report should have been submitted some time ago. Would you please advise us of the weft condition and submit the appropriate reports? Any report should also include the operations information from the activities conducted around November 2004. Also, see comment below. 05-28B -This welt was granted operational SD via sundry 306-277 dated August 22, 2006. The sundry is the most recent information in the fife. Would you please advise us of the weft condition? See comment below. There seems to be some confusion about ftltng reports when an operational SD is granted for a well A report is required by 20 AAC 25.072 (b) which states, "The operator shall file with the commission, within 30 days after operation shutdow, a complete well record on ... [Form 10-404] ..." The regulation further states that "If well operations are not resumed within 12 months, the operator shall .., proceed to abandon or suspend the well. Upon application ... the commission will extend the 12-month period, if the operator shows that operational circumstances beyond the operator's control prevent resumpion ..." Thanks in advance, Tam Maunder, PE AOGCC 8/3!2007 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7°i Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs E-18131)[31, The technical data listed below is being submitted herewith concerns to the attention of: 13 `69 5 April 27, 2006 Please address any problems or Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 E -18B PB1: LAS Data & Digital Log images: 50-029-20654-70 SC NEV MAY 18 2000 133 sl�sl�(' LJj-- 1 CD Rom ~ ~ WELL LOG TRANSMITTAL To: State of Alaska November 21, 2005 Alaska Oil and Gas Conservation Comm. Attn.: Ceresa Tolley 333 West 7°i Avenue, Suite 100 Anchorage, Alaska 99501 I ,~ I~ ~~ RE: MWD Formation Evaluation Logs: E-18B PB 1, ~ ~ / `~~ AK-MW-3369841 1 LDWG formatted Disc with verification listing. API#: 50-029-20654-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petro-Technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: I 07 D~ Signed: ~~c~av~~ nEC 0 '7 2005 Alaska Oii & Gas Cons. Commission Anchorage • • 03-Nov-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Revised well name to E-186 PB1 Re: Distribution of Survey Data for Well E-18B PB1 Dear Dear Sir/Madam: Enclosed is one disk with the `.PTT and *.PDF files. Tie-on Survey: 10,200.00' MD Window /Kickoff Survey: 10,212.00' MD (if applicable) Projected Survey: 10,375.00' MD s~~ ~,q .Mnv. o ~ PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ~ /1Q ~~ Si ned t g Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~ -13y 1~-ru.+~ d~~ vr~ J~uM r `r ~t ~ ~ oyV ~~ 1 '~ ~ ~~ ~ ~ ~ ~ ~ ~ m ~ 'v ~ 1 ~' FRANK H. MURKOWSKI, GOVERNOR ~~~ ~ ~ ~r ~ ~+ ~+ ~~ O~ ~ ~ ~ 333 W. 7T" AVENUE, SUITE 100 C~~-7~R~AZiDis CQ~QII5SI0~ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay E-18B Sundry Number: 305-144 Dear Mr. Johnson: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such. further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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 liday or weekend. A person may not appeal a Commission decision to Superio o unless rehearing has been requested. /~'1 ~ DATED this ~~day of June, 2005 Encl. STATE OF ALASKA ~ ~~~~--5 ALASKA O~AND GAS CONSERVATION COMSION ~ ~ ; "°;:~"~ _ ~ a . APPLICATION FOR SUNDRY APPROVA~,,~~ ~~ ~~ -~ 20 AAC 25.280 ~~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ®Other % Fie-~ti3tt`~ '~'~tions `- ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspendtd~Vllell ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-139 / 304-402 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O.Box196612,Anchorage,Alaska 99519-6612 50-029-20654-02-00 ~ 7. KB Elevation (ft): 60 5' 9• Well Name and Number: . PBU E-18B ~ 8. Property Designation: 10. Field /Pool(s): ADL 028304 Prudhoe Bay Field / Prudhoe Bay Pool 11. PRESENT WELL CO NDITION'BUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10374 8265 10234 8196 None 10234 Casin Len th Size MD TVD Burst Colla se tr I 110' 20" x 30" 110' 110' rf a 2686' 13-3/8" 2686' 2681' 5380 2670 10377' 9-5/8" 10377' 8317' 6870 4760 P Lin r 927' 7" 9856' - 10216' 7888' - 8180' 7240 5410 Liner 460 3-1/2" 9914' - 10374' 7934' - 8265' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None si/z"•"u x a-,/z°,,zs# L-80 9965' Packers and SSSV Type: 9-5/8" Baker'SAB' packer; Packers and SSSV MD (ft): 9825' Otis 'RQM' SSSV Nipple 1996' 12. Attachments: ~ 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 5, 2005 ®Oil ^ Gas ^ Plugged ^ Abandoned 16. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Johnson, 564-5666 Printed Name Mark Johnson Title CT Drilling Engineer ~'l Prepared By Name/Number: / ~-~ ~~^-y~"'- Phone 564-5666 Date ~D ~ O.S Terrie Hubble, 564-4628 Si nature Commission Use Only t/ Sundry Number: 30~_ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ~ Other. ~ ~ ~ ~ (~ n" ~ >/ Yl.(.L rti ec. r Subsequent For a ire - ~ ~.'~~~,- f.4.t~,~( L'~tir~,~),~'~tc-~- APPROVED BY THE COMMISSION ~ ~~ ~^-' Date Approved By: COMMISSIONER Form 10-403 Rid 1 04 ~- ~„" ~ q ~ ~ bmit Yfi Duplicate ~~ ~~ 3 ~ ~ ~+ a~~ ~ ~ ~~Q~ • • ~~„~ bn To: Winton Aubert Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Mark O. Johnson CTD Engineer Date: June 9, 2005 Re: Resume sidetrack operations on PBU E-18B sidetrack Sundry approval is requested to resume si ack perations on PBU E-18BrOperations were suspended on E- 18B under approved sundry 304-402 on 1/16 BP plans to resume sidetrack operations on 815105. The following describes work planned to res the sidetrack and is submitted as an attachment to Form 10-403. / The existing 3 %" CTD liner is collapsed at 10234' md. This liner will be abandoned by placing a 3 /2" CIBP at 10100' md. After removal of the remaining 3 '/z" liner above a chemical cut at 10075', the sidetrack E-18B, will / exit-ex~a€the existing 7" liner from a mechanical whipstock and target Zone 1 reserves. A schematic diagram of the proposed sidetrack is attached for reference. l Note: Permit to redrill #204-139 was issued by AOGCC on 7/29/04. The well is scheduled for resumption of sidetrack operations on 818/05 under the same permit. Well Status and Reason for Sidetrack The well is shut in due to parted/collapsed 3 '/2" STL liner at 10234'md. The liner partedlcollapsed due to a high dogleg window and lower strength flush joint connection during th st E-18B sidetrack attempt. The well must be sidetracked above the collapsed section before it can be ton production. Before the attempted E-18B sidetrack, the E-18A wellbore produced at a low oil rate (300 - 00 bopd) at above marginal GOR (47000 ~ scf/stb). There was little to no indication that the well was healing after being shut-in, even for long periods of time (6+ months). All wellwork options had been exhausted. The current zone 1 bottomhole location has value and needs to be moved to a new offtake point outside of its current gas cone. In addition, with the parted/collapsed 3 %i" liner the well has no value in its current condition. The proposed sidetrack will allow access to new zone 1 reserves and return this wellbore to production status. The nre CTD work is slated to begin on June 20, 2004. 1) Slickline -Drift tubing. Pressure test IA to 2500 psi. Drift 3 1/2" liner for CIBP. 2) E-line -Set 3 U2" CIBP at 10100' md. Pressure test wellbore to 1000 psi. P&A is complete. ~ Regardless of pressure test results continue with planned operations. The old wellbore will be isolated by 2 additional cement jobs during the liner completion phases. 3) E-line -Chemical cut 3 1/2" STL liner above top of liner cement at 10075' md. ~ 4) Service coil -Latch onto deployment sleeve at 9915' and and pull check 3 %2" liner to confirm free. Set back down. • • CTD Sidetrack Summary ` l) MIRU CTD rig. 2) Pull 3 U2" liner from chemical cut. ,i 3) Underream 7" liner from 9940-10075' md. 4) Log PDS caliper survey of 7" liner to confirm all cement is gone. 5) Set 4 %2" x 7" whipstock in 7" liner at 10050'md. 6) Mi113.8" OD window at 10050' md. 7) Drill Kingak shale to 10400' and to TSAG. 8) Run and cement 3 3l16" protective casing string. ~ 9} Dri112.7" x 3" bicenter hole from 10400' to TD at 12525' and with MWD/GR. 10) Run and cement 2 3/8" solid liner. % 11) Perforate and freeze protect well. 12) RDMO. Post Rig Work 1 } Reinstall wellhouse and production lines 2) Run GLVs 3) Flowback well t~ Mark O. Johnson CTD Drilling Engineer 564-5666, 240-8034 CC: Well File Sondra Stewmanfferrie Hubble CNV 6 3/8" WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 60.45' BF. 1EV = 31.72' KOP = 2600' Max Angle = 95 @ 11553' Datum MD = 11119' Datum TV D = 8800' SS • E ~ ~ S B ~ SAFETY NOTES: M82LA TBG PATCH Proposed CTD Sidetrack 9652'-9673' MD, OVBt GLM 1, ID = 3.75" C V Y'Y e/~ Gu e ~ sfi~t~s I 13-3/8" (SG, 72#, L-80 BTRS, D = 12.347" ( TOP PATCH OV ER GLM 61 I BOTTOM OF M[32LA PATCH D = 3.75' 5-1/2" TBG, 176, L-80 IJ4S IPC, .0232 bpf, D = 4.892' TOP OF 4-112' TBG 9652' 9673' I TOP OF 7" LNR H 9856' 7' BAKER LNR HANGER W/TEBACK, D = 6.25" 14-1/2" TB, 12.6#, L-80, .0152 bpf, D = 3.958" I-i 9965' Calculated top of cement 10035' md~ top of whipstock 10214` and Cut and FuU 2-7/8" Liner 10250' 9-5/8" CSG, 476, L-80 BTRS, D = 8.681" 1037T CBP 10280' 7 'AfIU_LOt3T VNNDCl~M -10783 -10789' 7" LNR, 26#, L-80 U4S 11263' PB3FORAT[ON SUMMARY REF LOG: SS MWD/GR ON 05/04/97 ANGLE AT TOP PERF: 66 @ 11228' Jote: Refer to Production DB for historical pert data SIZE SPF gJTFJ2VAL OpnlSgz DATE 2" 6 11228 - 11288 isolated proposed 2" 6 11312 - 11327 isolated proposed 1-11/16" 4 11500 - 11700 isolated proposed 1-11/16" 4 11760- 11900 isolated proposed 1-11/16" 4 11960 - 12240 isolated proposed 1996' -i SSSV OTIS ROM N~, D = 4.562" • GAS LIFT MANDRI3S ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2891 2821 12 CAM/MMIGW DMY RK 0 12/22!( 11 5119 4533 49 G>M/WMAIGW DMY RK 0 12/22/( IMMIGW DMY RK 0 10 6890 5657 49 CAM 9 6996 5720 50 CAM/MMIGW DMY RK 0 8 7871 6295 51 CAMIMMIGW DMY RK 0 7 7974 6371 52 CAMIMMIGW DMY RK 0 6 8549 6808 53 CAMIMMIGW DMY RK 0 5 8656 6893 53 G~M/MMIGW DMY RK 0 4 9071 7219 54 CAMIMMIGW DMY RK 0 3 9177 7301 53 CAMA16u0GW DMY RK 0 2 9551 7590 45 CAMAhMIGW DMY RK 0 "1 9655 7670 43 G4MfMU1GW G LM 1 C OV ER ED W/ TBG PATCH ' ' 9723' BKR L SLDNrG SLV, D = 4.562" 980$' TUBNG SEAL ASSBuIBLY 9825' 9-518" BKR SAB PKR, D = 3.813" 9$$2' 4-112" OTIS X NP, D = 3.813" 9914' Top of 31/2" der 9920' 4-1/2" OTIS XN NP, D = 3.725" (BEH. LNR) 4-1/2' BAKER TUBNIG TAL (BiJi. ' ~ 9940' H E1MD TT LOGGED OS/03/89 I 10225' PartedlDamaged 3-1/2" L'mer ~ 10234' MCCUGR Depth 3-1/2" Liner l . 10374' Bottom of 3-112" Liner 11720' H BKR CAP 11816' 11 BKR CIBP FAILED I 11920' 2-7/8" HES MOD M CAP 12270' PBTD 12303' 2 7!8" 6.16# STL L-80, D = 2.37" DATE REV BY COMMENTS DATE REV BY COIuW6JT'S 10114/81 ORIGINAL COMPLETION 08/05/04 MOJ E186 proposed 05/07/97 RW CTD SIDETRACK 11/08/04 DLH Suspensed Ops 11-8-2004 04/07/01 CH/KAK CORRECTIONS 11/01!01 WB/'TP SURF LOC CORRECTION 09/il/03 CMOIRP P62FANGLECORRECTION 12/28/03 JLJ/PAG GLV GO PRUDFIOE BAY UNfr WELL: E18A PERMtT No: 1970690 API No: 50-029-20654-01 SEC 6, T11 N, R14~ 1853' SNL & 501' WEL 8P 6rploration (Alaska) ,TREE = CMJ 6 3/8" WELLHEAD = ACTUATOR ___ FMC OTIS KB. ELEV = - 60.45' BF. EL'EV = KOP = 31.72' 2600' Max Angle = 95 @ 11553' Datum MD = Datum TVD = 11119' 8800' SS • E-18B Proposed CTD Sidetrack 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" ~-~ 2686' TOP PATCH OVER GLM #1 ~ 9652' BOTTOM OF MERLA PATCH ID = 3.75" ~3' 5-1/2" TBG, 17#, L-80 U4S IPC, 9805' .0232 bpf, ID = 4.892" TOP OF 4-1/2" TBG 9825' TOP OF 7" LNR I-I 9856' ~ 7" BAKER LNR HANGER W/TIEBACK, ID = 6.25" I4-1/2" TB, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 9965' Mechanical whipstock 10050' Cut and Pull 3-1/2" Liner " 10075' CIBP 10100' Mechanical ~w hipstock 10050' Cut and Pull 2-7/8" Liner 10250' CIBP 10280' 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" 10377' 7 "MILLOUT WINDOW - 10783' -10789' 7" LNR, 26#, L-80 U4S 11263' PERFORATION SUMMARY REF LOG: SS MWD/GR ON 05/04/97 A NGLE AT TOP PERF: 66 @ 11228' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11228 - 11288 isolated proposed 2" 6 11312 - 11327 isolated proposed 1-11/16" 4 11500 - 11700 isolated proposed 1-11/16" 4 11760 - 11900 isolated proposed 1-11!16" 4 11960 - 12240 isolated proposed SAFETY NOTES: MERLA TBG PATCH 9652'-9673' MD, OVER GLM 1, ID = 3.75" I 1996' SSSV OTIS ROM NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2891 2821 12 CAM/MMIGW DMY RK 0 12/22(03 11 5119 4533 49 CAMIMMIGW DMY RK 0 12/22/03 10 6890 5657 49 CAMIMMIGW DMY RK 0 9 6996 5720 50 CANVMMIGW DMY RK 0 8 7871 6295 51 CAMIMMIGW DMY RK 0 7 7974 6371 52 CAM/MMIGW DMY RK 0 6 8549 6808 53 CAM/MMIGW DMY RK 0 5 8656 6893 53 CAM/MMIGW DMY RK 0 4 9071 7219 54 CAM/MMIGW DMY RK 0 3 9177 7301 53 CAM/MMIGW DMY RK 0 2 9551 7590 45 CAM/MMIGW DMY RK 0 *1 9655 7670 43 CAM/MMIGW * G LM 1 C OVER ED W/ TBG PATCH 9723' BKR L SLIDING SLV, ID = 4.562" 9$05' TUBING SEAL ASSEMBLY 9825' 9-5/8" BKR SAB PKR, ID = 3.813" 9860' Top of 2-3/8" liner & Cement 9882' 4-1/2" OTIS X NIP, ID = 3.813" 9900' Top of 3 3/16" liner & Cement 9920' 4-1/2" OTIS XN NIP, ID = 3.725" (BEH. LNR) 9965' 4-1/2" BAKER TUBING TAIL (BEH. LNR) 9940' ELMD TT LOGGED 05/03/89 -10400 ~-~ Bottom of 3 3/16" TCII Liner 2-3/8" cemented and perfed liner ~ 12525' 10234 Collapsed 3-1/2" liner 11720' -j BKR CIBP 11816' BKR CIBP FAILED 11920' 2-7/8" HES MOD M CIBP 12270' PBTD 12303' 2 7/8" 6.16# STL L-80, ID = 2.37" DATE REV BY COMMENTS DATE REV BY COMMENTS 10!14(81 ORIGINAL COMPLETION 08!05/04 MOJ E-186 proposed 05/07/97 RW CTD SIDETRACK 04/07/01 CH/KAK CORRECTIONS 11/01/01 WB/TP SURF LOC CORRECTION 09!17/03 CMO/TLP PERF ANGLE CORRECTION 12/28/03 JLJ/PAG GLV C/O _~ ~ I ~~ __._ PRUDHOE BAY UNfT' WELL: E-18A PERMfi' No: 1970690 API No: 50-029-20654-01 SEC 6, T11 N, R14E, 1853' SNL 8 501' WEL BP Exploration (Alaska) • • 29-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well E-18B ~,y ~,~ 84 ~ A ~ Dear Dear Sir/Madam: ~ Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,200.00' MD Window /Kickoff Survey: 10,212.00' MD (if applicable) Projected Survey: 10,375.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ,~ ~ -~ Date Signed C~-w Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~o~- ~3 ~ FRANK H. MURKOWSKI, GOVERNOR oiI[~-7~ OIL ~ ~ 333 W. 7TM AVENUE, SUITE 100 COI1TSFiRQA'1'IO1~T CO1~II-'IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay E-18B Sundry Number: 304-402 Dear Mr. Johnson: 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 Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OFT COMMISSION DATED this /iay of November, 2004 Encl. STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO~SION wi ~~ u ~ I~~i.~e4 ~ ~ j 1~~ ~ ~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 r a 1. Type of Request: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ®Operation Shutdown ^ Perforate ^ Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-139 ~ 3. Address: ^ Stratigraphic ^ Service 6. API Number: P.O.Box196612,Anchorage,Alaska 99519-6612 50-029-20654-02-00 7. KB Elevation (ft): 60.5' 9. Well Name and Number: PBU E-18B 8. Property Designation: 10. Field /Pool(s): ADL 028304 Prudhoe Bay Field / Prudhoe Bay Pool ~~. PRESENT WELL CO NDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10374 8265 10234 8196 None 10234 Casin Len th Size MD TVD Burst Colla se tr trl n t r 110' 20" x 30" 110' 110' rf 2686' 13-3/8" 2686' 2681' 5380 2670 Int rm iat 10377' 9-5/8" 10377' 8317' 6870 4760 Pr ti n Lin r 927' 7" 9856' - 10216' 7888' - 8180' 7240 5410 Liner 460 3-1/2" 9914' - 10374' 7934' - 8265' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None s-'/2", "# X 4-'/2"•'z.s~ L-80 9965' Packers and SSSV Type: 9-5/8" Baker'SAB' packer; Packers and SSSV MD (ft): 9825' Otis 'RQM' SSSV Nipple 1996' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Novem r 8 004 ®Oil ^ Gas ^ Plugged ^ Abandoned 16. Verbal Approval: Date. ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Re resentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Johnson, 564-5666 Printed Name Mark Johnson Title CT Drilling Engineer _,,.•~4 _ Prepared By Name/Number: ~ ~ Phone 564-5666 Date 11 15 U Terrie Hubble, 564-4628 Si nature ;'~ ~ Commission Use Only Sundry Number: ~ ~, _ ~~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: " .:,;` ,'hS BFL i~OV 17 2004 Subsequent Form R ~ / ~ ~ ~ ~~ 3 ~" t%trl roc' d `~' Yom' S ~~ +~~ y~~. t'vA`''l S APPROVED BY Approved B . COMMISSIONER THE COMMISSION Date / /~ Q Form 10-403 R is 06/2QO.q/ ~-~ S~Ibmit Ir(Duplicate • • Temporary shutdown of drilling operations - PBU E-18B CTD sidetrack operations were stopped on PBU E-18B on 11/8/04 due to an obstruction ~,- in the newly installed 3 '/z" liner. The Nordic 1 rig was released from location at 20:00 on 11/8/04. Description of problem/obstruction After milling a 3.72" OD dual string window in E-18A at 10214', the Kingak was drilled down to casing point at top of Sag River (TSGR) at 10374'md. A 3 '/z" liner was ran and cemented in place on 11/3/04. The 3 '/z" liner passed a pressure test to 200 psi on 11/5/04. With 10.7 ppg mud in the hole this provided a 1800 psi pressure test across the shoe track. A 2.80" mill and -motor cleanout assembly was not able to pass an obstruction at 10225' md. Four additional runs with mills from 2.79" to as small as 1.87" OD were unable to make forward progress. A lead impression block indicates that the 3 '/z" liner may be parted or collapsed at 10234'. Wellbore fluids were swapped to 2% KCL water with methanol freeze protection. Nordic 1 operations were shut dawn and the rig was released on 1118104. Plan Forward Diagnostic work is planned to evaluate the extent of the 3 '/z" liner obstruction. This may include another lead impression block run, video camera, and cement bond log. A future CTD sidetrack may be attempted if the 3 '/z" liner can be cut and pulled above calculated top of cement in the annulus at 10035' md. Mark O. Johnson 564-5666 office 240-8034 cell r;~,1 iwr • .-~ ~-. n ~ `:~- N r~~•~,,~ ENGINEERING DATA • SHEET NO. OF SUBJECT BASED ON BUDGET/AFE NO. 7/~Z~~ aF ~ ~~ ~~ ~P k I: G'~°~~ ~~~ '/ p ,~J of /I h t~^ =~yd~l / 2 z J 6Hk~a = /63?y-b~v= E4o(y./xs_3_s - G,7yy/.y= /.off 111 ~u~,.q ~~ ~8 . y - I ~-- _. 2 ~ ~ ___---- ~' / +r o, ouY blot ~~``"'~.. ! 0 3) S - Zia ~OO 3S ~:, `~ .. ~ 163 i 5 2~~$ .~ ~;~ ~ a .- ~ °°` ,~~~ C_ AK 2337 (11/00) TREE ~ CMJ 6 3/8" WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 60.45' BF. ELEV = 31.72' KOP = 2600' Max Angle = 95 @ 11553' Datum MD = 11119' Datum TVD = 8800' SS ~ E-18B , Proposed CTD Sidetrack 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" ~~ 2686' TOP PATCH OV ER GLM 41 ~ 9652' BOTT0~9 OF MERLA PATCH D = 3.75" 5-1/2' TBG, 17#, L-80 U4S IPC, 9$05' .0232 bpf, ID = 4.892" TOP OF 4-1 /2" TBG 9825' L TOP OF 7" LNR ~~ 9$56' 7" BAKER LNR HANGER W/TIEBACK, D = 6.25" 1/2" TB, 12.8#, L-80, .0152 bpf, D= 3.958" ~--i 9965' Calculated top of cement 10035` md~ top of whipstock 10214` and Cut and Pull 2-718" Liner 10250' 9-5/8" CSG, 47att, L-80 BTRS, ID = 8.681 • 10377' cIBP 10280' 7 "TJ~ILLOUT 1Mt`1DOW - 10783' -10789' 7" LNR, 26#, L-80 U4S 11263' PERFORATION SUMMARY REF LOG: SS MWD/GR ON 05/04/97 ANGLE AT TOP PERF: 66 @ 11228' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11228 - 11288 isolated proposed 2" 6 11312 - 11327 isolated proposed 1-11/16" 4 11500 - 11700 isolated proposed 1-11/16" 4 11760 - 11900 isolated proposed 1-11/16" 4 11960 - 12240 isolated proposed 1996' ~ SSSV OTIS RQM NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2891 2821 12 CAM/MMIGW DMY RK 0 12/22/03 11 5119 4533 49 CAM/MMIGW DMY RK 0 12/22/03 10 6890 5657 49 CAMIMMIGW DMY RK 0 9 6996 5720 50 CAM/MMIGW DMY RK 0 8 7871 6295 51 CAMIMMIGW DMY RK 0 7 7974 6371 52 CAMIMMIGW DMY RK 0 6 8549 6808 53 CAM/MMIGW DMY RK 0 5 8656 6893 53 CAM/MMIGW DMY RK 0 4 9071 7219 54 CAMIMMIGW DMY RK 0 3 9177 7301 53 CAM/MMIGW DMY RK 0 2 9551 7590 45 CAM/NMAIGW DMY RK 0 `1 9655 7670 43 CAM/MMIGW ' G LM 1 C OVER ED W/ TBG PATCH 9723' BKR L SLIDING SLV, D = 4.562" 9805' TUBING SEAL ASSEMBLY 9$25' 9-5/8" BKR SAB PKR, ID= 3.813" 98$2' ~4-112" OTIS X NIP, ID= 3.813" 9914' Top of 3 112" liner 9920' 4-1/2" OTIS XN NIP, ID = 3.725" (BEH. LNR) I 9965' ~4-1/2" BAKER TUBING TAIL (BEH. LNR) 9940' H ELMD TT LOGGED 05/03189 10225' Parted/Darnaged 3-1/2" Liner 10234' MCCL/GR Depth 3-1/2" Liner 10374' Bottom of 3-1/2' Liner 11720' ~ BKR CIBP ~ 11816' BKR CIBP FAILED 11920' 2-7/8" HES MOD M CIBP 12270' PBTD 12303' 2 7/8" 6.16# STL L-80, ID = 2.37" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14/81 ORIGINAL COMPLETION 08/05/04 MOJ E-18B proposed 05/07/97 RW CTDSIDETRACK 11/08/04 DLH SuspensedOps 11-8-2004 04/07/01 CWKAK CORRECTIONS 11/01/01 WB/TP SURF LOC CORRECTION 09/17/03 CMO/TLP PERF ANGLE CORRECTION ..~;r~ _~=.... _~ _ i i _.. ._.__~~_. PRUDHOE BAY UNrf WELL: E-18A PERMfr No: 1970690 API No: 50-029-20654-01 SEC 6, T11 N, R14E, 1853' SNL & 501' WEL BP Exploration (Alaska) -~.~ ~ r 6 ~~ .~~ ~,4 t Lam' ~LA581A OIL ~1~TD G~-5 COI~TSERQA'TI011T COM1~II551O1Q Mark Johnson CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ~~ FRANK H. MURKOWSKI, GOVERNOR i /r i° 333 W. 7'" AVENUE, SUITE 100 / ANCHORAGE, ALASKA 99501-3539 / PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay E-18B BP Exploration (Alaska) Inc. Permit No: 204-139 Surface Location: 1853' SNL, 501' WEL, SEC. 06; T11N, R14E, UM Bottomhole Location: 1644' SNL, 696' EWL, SEC. 08, T11N, R14E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field insp BY ORDER THE COMMISSION DATED thi day of July, 2004 cc: Department of Fish & Game, Habitat Section w/o.encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA IL AND GAS CONSERVATION COM ISSION PERMIT TO DRILL 20 AAC 25.005 v~Gh z/ u~l~c'c=~ 13 pry. 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Welt Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number:/ PBU E-186 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12525 TVD 8863'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1853' SNL 501' WEL R14E SEC 06 T11N UM 7. Property Designation: ADL 028304 Pool , , . , , , Top of Productive Horizon: 2146' SNL, 762' WEL, SEC. 07, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 5, 2004 Total Depth: 1644' SNL, 696' EWL, SEC. 08, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 15585' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664487 y- 5975211 Zone- ASP4 10. KB Elevation (Height above GL): 60.5' feet 15. Distance to Nearest well within Pool E-236 is 405' away at 12498' MD 16. Deviated Wells: Kickoff Depth: 10250 feet Maximum Hole Angle: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.03 j Downhole: 3222 Surface: 2342 asing Program: Size Specifications Setting Depth T Bottom Quantity o Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data a-,/s• x s-a/a• 3-3/16" 6.2# L-80 TCII 500' 9900' 7862' 10400' 8284' 2 cu ft Class 'G' 3" 2-3/8" 4.7# L-80 STL 2675' 9850' 7883' 12525' 8863' 5 cu ft Class 'G' 1g: `PRESENT WELL CONDITION SUMM ARY(To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 12303 Total Depth TVD (ft): 8923 Plugs (measured): 11720 Effective Depth MD (ft): 11720 Effective Depth TVD (ft): 8936 Junk (measured): None Casing Length Size Cement Volume MD TVD ndu for 110' 20" x 30" 8 cu s Concrete 110' 110' 2686' 13-318" 3720 cu ft Arcticset I I 2686' 2681' Int rm ' t 10377' 9-5/8" 1450 cu ft Class 'G', 130 cu ft Arcticset I 10377' 8317' Produ i n i 927' 7" 32 cu ft Class 'G' 9856' - 10783' 7888' - 8660' Liner 2448' 2-7/8" 143 cu ft Class 'G' 9855' - 12303' 7887' - 8923' Perforation Depth MD (ft): Above Plugs: 11228' - 11700' Perforation Depth TVD (ft): 8914' - 8937' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mark Johnson, 564-5666 Printed Name Mark Johnson Title CT Drilling Engineer DT Prepared By Name/Number: °~--~^ '~~tn. Phone 564-5666 Date Terrie Hubble, 564-4628 Si re s Commission Use Only Permit To Drill Number: ~ O API Number: 50- 029-20654-02-00 Permit Ap~ro al Date: J o2 See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes ,~No Mud Log Required ^ Yes ,~No Hydrogen Sulfide Measures Yes ^ No Directional Survey Required 'Yes ^ No Other: T~' c ~ ~ ~SGp ~ s i~ ~UP~ P~ ~ ~LZ~'`~ e S I)t~r ~ , ~• S j ~, GGG ~' f- ~~~'-r'~~ircytS ~~~1"lilPCl ~t~.~~'-,.- (U^ APPROVED BY ~i D A roved B THE COMMISSION Date 7 Form 10-401 Rased 06/~ ~~~ G i N A L JsudmJc m uupucate • • BP E-18B Sidetrack Summary of Operations: Well E-18A is scheduled for a through tubing sidetrack with the SLB/Nordic 2 CTD rig. The sidetrack, E- 18B, will exit~t.e~the existing 7" liner from a mechanical whipstock and target Zone 1 reserves. The following describes the planned sidetrack. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (Phase 1} ' 1} Slickline -Drift tubing. Dummy gas lift valves. Pressure test IA to 2500 psi. Drift 2 7/8" liner for CIBP. 2) E-line -Set 2 7/8" CIBP at 10280' md. Pressure test wellbore to 1000 psi. P&A is complete. Regardless of pressure test results continue with planned operations. The old wellbore will be isolated by 2 additional cement jobs during the liner completion phases. 3) E-line -Chemical cut 2 7/8" liner above top of liner cement at 10270' md. 4} Service coil -Latch onto deployment sleeve at 9855' and and pull check liner to confirm free. Set back down. CTD Sidetrack Summary (Phase 2A and 2B) 1) Phase 2A start - MIRU CTD rig. 2) Pu112 7/8" liner from chemical cut. 3) Underream 7" liner from 10200-10270' md. 4) SL -Log PDS caliper survey of 7" liner to confirm all cement is gone. 5) Set 4 %" x 7" whipstock in 7" liner at 10250'md. -~-~ ~ ~ O _ ,t ~ ~ ~,~,y)~~(~., , 6) Mi113.8" OD window at 10250' md. `t f 7) Drill Kingak shale to 10400' to TSAG. 8) Run and cement 3 3116" protective casing string. End phase 2A. 9) Phase 2B start -Drill 2.7" x 3" bicenter hole from 10400' to TD at 12525' and with MWD/GR. 10) Run 2 3/8" solid and slotted liner completion and cement solid portion in the build section (bonzaii completion). 11) Cleanout bonzai equipment to TD 12) RDMO. Mud Program: • Phase 1: 8.4 ppg seaw r • Phase 2A (Kingak): -1 pg NaBr Flo Pro or biozan for milling, and drilling Kingak shale. • Phase 2A (Sadleroclu .6 ppg used Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will ga to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Casing Program: • Phase 2A - 3-3/16" solid cemented line co pletion across Kingak 9900' to 10400' (protective string). The liner cement volume is planned to be 11 bls of 15.8 ppg class G. • Phase 2B - 2 3/8" solid cemented lin 850-11200') and pre drilled liner (11200-12525') in formation. The liner cement volume is planned to b~bls of 15.8 Ppg class G. • • Parent Well Casin s Burst si Colla se si 13 3/8" 72# L-80 5380 2670 95/8" 47#, L-80 6870 4760 7" 26#, L-80 7240 5410 Sidetrack Casin s 3-3116" 6.2#, L-80, TCII -Prod LNR 8520 7660 2 3J8" 4.7#, L-80, STL -Prod LNR 11200 i 1780 Well Control: • BOP diagram is attached.? • Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /~ • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 90 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • E-18B will be approx 405'md center to center away from well E-23B at 12498'md • E-18B will be approx 15,585' from the unit boundary, (Prudhoe Bay Unit) Logging • MWD Gamma. Ray log will be run over all of the open hole section. Hazards • E pad is not H2S pad. H2S is typically <10 ppg on the pad. No H2S measurements have been taken for well E-18B. The nearest bottom hole ration, E-23B had a lOppm sample on 3/20!04. All H2S monitoring equipment will be operational. • No crossings are predicted. Lost circulation risk is considered "medium" so LCM material will be on location as a contingency. Reservoir Pressure • Res. press. is estimated to be 3222 psi at 8800'ss (7.1 ppg EMVt~. Max. surface pressure with gas (0.10 psi/ft) to surface is 2342 psi. MOJ 7J21/04 a a Z W Z W LL O Z w w x N 0 Z LL Q H W O m 9~0 Apo f;~- ~ ~ ,~.~ ~ ~ ~ r` f \ ! ,l j ~~~ ~ ~ ~~'1s'A ~ =3 ~ ~ ~ ~ ~~ \ ~ ~ ~ ~ 'r , ~ ~ ~ ~ t' // Z~ l"~~r ~' Sral~ ~ 8 ~Cw~lptfGf. ' - ~rG ~v~O~e ~ -ZSzS ~ ~; c, e., e e e ~ is b R C~ • Q 'M~~~~~: ~~~ '~~~ ri~~;~w- Z U ~ °~° a (~ m ~~ S ~/~ -- ~ ~~ ~ ~ pL 3~6X ~f'~ ~t~yov ...~Q?~'o ~/,/ S, ~ l kr! 5~ = (I y ~~ /o L~ -. _ ~ 3~~ ~ 7 99`S - /0250 6.29' L- 3.rS~ g~ l~ 3 ~6 o Y~ s N Q TREE= CNV 63/8" WELLHEAD = FMC ACTUATOR= OTIS K8. ELEV = 60.45' BF. 8_EV = 31.72' KOP = 2600' Max Angle = 95 @ 11553' Datum MD= 11119' Datum ND = 8800' SS • E-18A SAFETY NOTES: MERLATBGPATCH 9652'-9673' MD, OVH2GLM 1, ID= 3.75" 1996' SSSV OTIS ROM NP, D = 4.562" C~GC 1 Fi' MA MRFI S 13-318" CSG, 72#, L-80 BTRS, ID =12.347" H 2686' Minimum ID = 2.370" @ 9862' TOP 2-7/8" LNR ' TOPPATCHOVERGLM#1 f-j 9652' BOTTOM OF MERLA PATCH ID = 3.75' 9673' 5-1/2" TBG, 17#, L-80 U4S IPG 9805' .0232 bpf, ID = 4.892" TOPOF4-1/2"TBG 9825' TOP OF 2-7/8" LNR 9855' TOP OF 7" LNR 9856' 7" BA KER LNR HA NGER W/TIEBA p<, D = 6.25" X41/2" TB, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9965' 9.5/8" CSG, 47#, L-80 BTRS, ID = 8.681" H 10377' PERFORATION SUMMA RY REF LOG: SS MWLYGRON05l04/97 ANGLE AT TOP PERF: 66 @ 11228' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL O n/S DATE 2" 6 11228 - 11288 O 01/20101 2" 6 11312 - 11327 O 01/19101 1-11116" 4 11500 - 11700 O 05107/97 1-11/16" 4 11760 - 11900 C 09/14100 1-11/16" 4 11960 - 12240 C 03/19/98 7"LNR 26#, L-8o u4S f--~ 11263' ST MD ND DEV TYPE VLV LATCH PORT DATE 12 2891 2821 12 CAM/MMIGW DMY RK 0 12/22N3 11 5119 4533 49 CAM/MMIGW DMY RK 0 12J22r03 10 6890 5657 49 CAM/MMIGW DMY RK 0 9 6996 5720 50 CAM/MMIGW DMY RK 0 8 7871 6295 51 CAM/MMIGW DMY RK 0 7 7974 6371 52 CAM/MMK'W DMY RK 0 6 8549 6808 53 CAM/MMIGW DMY RK 0 5 8656 6893 53 CAM/MMIGW DMY RK 0 4 9071 7219 54 CAM/MMIGW DMY RK 0 3 9177 7301 53 CAM/MMIGW DMY RK 0 2 9551 7590 45 CAM/MMIGW DMY RK 0 '1 9655 7670 43 CAM/MMIGW ' G LM 1 O OVER ED W/ TBG PATCH 1 9723' SKR L SLDING SLV, ID = 4.562" 9805' TIEING SEAL ASSBu16LY 9825' 9-5/8" BKR SAB PKR ID = 3.813" 9$55' II BKR GS DEPLOYMENT SLV, ID= 3.00" 9882' 4-1 /2" OTIS X NP, ID = 3.813" (BEH. WR) 9920' 4-1 /2" OTIS XN NIP, ID = 3.725' (BEH. LNI~ 9965' 4-1/2" BAKB2 TUBING TAIL (BEH. LNR) 9940' ELMDTTLOGGED05/03/89 10780' TOP OF WHPSTOCK 7 "MILLOUT W INDOW - 10783' -10789' 11720' SKR CIBP 11816' BKRCIBPFAILED 11920' H2-7/8" HES MOD M CIBP PBTD 12270' 2 7B" 6.16# STL L-80, IO= 2.37" I DATE REV BY COMMENTS DATE REV BY COMMENTS 10/14/81 ORIGINAL COMPLETION 05/07/97 RW CTDSIDEfRACK 04/07!01 CH/KAK CORRECTIONS 11/01!01 WB/TP SURF LOC CORRECTION 09/17/03 CMO/TLP PERFANGLECORRECTION 12/28/03 JLJ/Fl4G GLV C/0 PRUDHOE BAY UNfT WIiL: E-18A PERMT No: 1970690 API No: 50-029-2065401 SEC 6, T11 N, R14E,1853' SNL 8 501' WEL BP 6cpbration (Alaska) TREE = CM/ 6 3/8" WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 60.45' BF. l3EV = 31.72' KOP = 2600' _ _ Max Angle = ._~ __ 95 ~ 11553' _... ~.- Datum MD = 11119' Datum TV D = 8800' SS 13-3/s" CSG. 72#. L-8o BTRS. ID = 12.3x7" H 2686' TOP PATCH OVER GLM #1 ~~ 9652• BOTTOM OF MERLA PATCH ~ = 3.75" 9673' E ~ ~ S B • SAFETY NOTES: MERLA TBG PATCH Proposed CTD Sidetrack 9652'-9673' MD, OV82 GLM 1, ID = 3.75" 1996' SSSV OTC RQM NIP D = 4 562" , . • GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2891 2821 12 CAMMNMGW DMY RK 0 12/22/0 11 5119 4533 49 G~1M/MMIGW DMY RK 0 12/22/0 7 MrMnmcw G DMY 1o s6so 565 a9 > RK o 9 6996 5720 50 CAM/MMIGW OMY RK 0 8 7871 6295 51 G>M/MMlcw DMY Rlt 0 7 7974 6371 52 CAM/MMIGW DMY RK 0 6 8549 6808 53 CAM/MMIGW DMY RK 0 5 8656 6893 53 CANVMMIGW DMY RK 0 4 9071 7219 54 CAM/MMIGW DMY RK 0 3 9177 7301 53 CAMIMMIGW DMY RK 0 ' 2 9551 7590 45 CAM/MMIGW DMY RK 0 '1 9655 7670 43 CAMIMMIGW ~ ~ 9723' BKR L SL~NVG SLV, ~ = 4.562' 5-1/2" TBG, 17#, L-80 U4S ~C, 9805' .0232 bpf, D = 4.892" 9805' TUBING SEAL ASSEMBLY TOP OF 4-1l2" TBG 9825' 9825' 9-518" BKR SAB PKR ~ = 3.813" J$50' Top of 2-3/8" Gner 8~ Cement 9882' 4-1/2" OTIS X NIP, ID = 3.813' TOP OF 7" LNR 9856' 9900' Top of 3-3/16" liner & Cement 7" BAKER LNR HANGER W/TEBACK, ~ = 6.25" 9920' 4-1/2" OT1S XN N~, ID = 3.725" (BEH. LNR) TB, 12.6#, L-80, .0152 bpf, ~ = 3.958" 9965' 9965' 4-1/2" BAKER TUBWG TAB (BEH. LNR) ' 9940' ELMD TT LOGGED 05/03/89 Mechanical whipstock 10250 Cut and Pud 2-7/8" Liner ~- j 10270. CSG, 47#, L-80 ~TRS, D = 8.681" 10377 '~ cIBP 10280' 7 "MILLO~JT WINDOW - 10783' -10789' 7" LNR 26#~ L-8o uas 11263' Bottom of 3-3/16" Liner I II ?.©o' PERFORA'''ION SUMMARY REF LOG: SS A~IWDIGR ON 05/04197 A NGLE AT TOFF PERF: 66 @ 11228' Note: Refer to Productbn I~B for historical perf data SQE SPF ~1TEI2VAL Opn/Sqz DATE 2" 6 11228 ~ 11288 isolated proposed 2" 6 11312 ~ 11327 isolated proposed 1-11/16" 4 11500 - 11700 isolated proposed 1-11/16" 4 11760 - 11900 isolated proposed 1-11/16" 4 11960 - 12240 isolated proposed 2-3/8" eonzai completion 12525' ~ 11720' BKR CAP 11816' H BKR CAP FA ILED 11920' gals" HES MOD M CAP 12270' PBTD 12303' 2 7/8" 6.16# STL L-80, ~ = 2.37" OWTE REV BY COMMENTS DATE REV BY COMMENTS 10/14/81 ORIGINAL COMPLETION 05/07/97 RW CTD SIDETRACK 04/07/01 CWKAK CORRECTIONS 11ro1ro1 wBrrP suRF LOC coRREC:rION 09/17/03 gN0/TLP PERF ANGLE CORRECTION 12/28/03 JLJ/PAG GLV GO PRUDHOE BAY UNfT WELL: ~18A PERMfT No: 1970690 API No: 50-029-20654-01 SEC 6, 711 N, R14E, 1853' SNL & 501' WEL BP Exploration (Alaska) ao ~ T m rue m S Ve 'i rtic al Depth [50ft/in] ~ N a° ~ ~' w m N N ~ ~ - ~~.~i~'~~ d ~:~~ ~ ' °"~{""".°3~i$F»»++°$gF°$";»g.Q i EYYY~Ei~$8a a=a ~ r - II I. 1 1 III III ~ 1111 III III 4 IIII 1.111 I.1 IIII IIII I.I IIII 1111 ~ ~ I ~ . w i rg~rrr t: ~rrrr _ ;E ~Y~~~33~~~1~~ y ~~~~~YYSYf s:, apY:^kCki-.~S~a 3[ ~ ~ y~ 8 - - ~ : . . - -~ ~ ~ ~ ! 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BP-GDB ~''~``~ ~~ Baker Hughes INTEQ Planning Report ~ra~ i S «~r+~ Company.: BP AmOCO Date: 7/1/2004 Time: 11:45:02 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: E-18, True North Site: PB E Pad Vertical (TVD) Reference: System: Meah Sea lev el Well: E-18 Section(VS) Reference: Well (O.OON,O.OOE,85.OOAzi) Wellpath:- Plan#8 E-186 Survey Calculation Method: Mi nimum Curvature Db: Oracle 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: bggm2003 Site: PB E Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973160. 88 ft Latitude: 70 19 59.134 N From: Map Easting: 662538. 97 ft Longitude: 148 40 53.054 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Weil: E-18 Slot Name: 18 E-18 Weil Position: +N/-S 2007.57 ft Northing: 5975211. 00 ft Latitude: 70 20 18.875 N +E/-W 1992.14 ft Essting : 664487. 00 ft Longitude: 148 39 54.868 W Position Uncertainty: 0.00 ft Welipath: Pian#8 E-186 Drilled From: E-18 500292065402 Tie-on Depth: 10250.00 ft Current Datum: 31:18 9!26/1981 00 :00 Height 60. 50 ft Above System Datum: Mean Sea Level Magnetic Data: 7/1/2004 Declination: 25.23 deg Field Strength: 57598 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.50 0.00 0.00 85.00 Targets Map Map <- Latitude --a <- Longitude -> Name Description .TVD +N/-S +El-~V Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft E-186 Polygon8.1 0.00 -4965.30 -786.16 5970230.00 663810.00 70 19 30.042 N 148 40 17.815 W -Polygon 1 0.00 -4965.30 -786.16 5970230.00 663810.00 70 19 30.042 N 148 40 17.815 W -Polygon 2 0.00 -4989.78 -126.49 5970220.00 664470.00 70 19 29.802 N 148 39 58.560 W -Polygon 3 0.00 -4909.87 790.54 5970320.00 665385.00 70 19 30.587 N 148 39 31.793 W -Polygon 4 0.00 -4899.19 1215.91 5970340.00 665810.00 70 19 30.691 N 148 39 19.377 W -Polygon 5 0.00 -5094.38 1221.63 5970145.00 665820.00 70 19 28.772 N 148 39 19.211 W -Polygon 6 0.00 -5102.86 696.28 5970125.00 665295.00 70 19 28.689 N 148 39 34.545 W -Polygon 7 0.00 -5470.93 603.18 5969755.00 665210.00 70 19 25.069 N 148 39 37.263 W -Polygon 8 0.00 -5547.58 221.38 5969670.00 664830.00 70 19 24.316 N 148 39 48.406 W -Polygon 9 0.00 -5335.05 -119.06 5969875.00 664485.00 70 19 26.406 N 148 39 58.343 W -Polygon 10 0.00 -5301.45 -738.52 5969895.00 663865.00 70 19 26.736 N 148 40 16.423 W E-186 Fault 1 0.00 -4872.05 -248.95 5970335.00 664345.00 70 19 30.959 N 148 40 2.134 W -Polygon 1 0.00 -4872.05 -248.95 5970335.00 664345.00 70 19 30.959 N 148 40 2.134 W -Polygon 2 0.00 -4623.18 261.67 5970595.00 664850.00 70 19 33.407 N 148 39 47.230 W E-188 Fault 2 0.00 -4801.26 627.88 5970425.00 665220.00 70 19 31.655 N 148 39 36.540 W -Polygon 1 0.00 -4801.26 627.88 5970425.00 665220.00 70 19 31.655 N 148 39 36.540 W -Polygon 2 0.00 -4835.80 1062.25 5970400.00 665655.00 70 19 31.315 N 148 39 23.861 W E-186 Fault 3 0.00 -4851.51 1321.99 5970390.00 665915.00 70 19 31.160 N 148 39 16.280 W -Polygon 1 0.00 -4851.51 1321.99 5970390.00 665915.00 70 19 31.160 N 148 39 16.280 W -Polygon 2 0.00 -4991.70 1328.92 5970250.00 665925.00 70 19 29.781 N 148 39 16.079 W E-188 Fault 5 0.00 -5444.04 -166.47 5969765.00 664440.00 70 19 25.334 N 148 39 59.726 W -Polygon 1 0.00 -5444.04 -166.47 5969765.00 664440.00 70 19 25.334 N 148 39 59.726 W -Polygon 2 0.00 -5883.40 254.02 5969335.00 664870.00 70 19 21.013 N 148 39 47.454 W E-186 Fault 4 0.00 -5194.82 784.29 5970035.00 665385.00 70 19 27.785 N 148 39 31.976 W -Potygon 1 0.00 -5194.82 784.29 5970035.00 665385.00 70 19 27.785 N 148 39 31.976 W -Polygon 2 0.00 -5464.66 773.37 5969765.00 665380.00 70 19 25.131 N 148 39 32.296 W -Polygon 3 0.00 -5745.27 797.22 5969485.00 665410.00 70 19 22.371 N 148 39 31.600 W C • . ~~ ! BP-GDB Baker Hughes INTEQ Planning Report i~E~ Company: _- BP Amoco Date: 7/112004 Time: 11:45:02 ' Page: 2 Field: > Prudhoe Bay Co-ordinate(NE) Reference: Well: E-18, True North Site: PB E Pad ' Vertical (TVD) Reference: System:' Mean Sea Leven. Well: E-18 Section (VS),Reference: Well, (O.OON,O.OOE,85.OOAzi) Welipath: Plan#8 E-i 8B Survey Calculation Method: .M inimum Curvature Db: Qracle Targets Map Map <-- Latitude -.> 4-- Longitude --a Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec ..Deg Min Sec Dip. Dir. ft ft ft ft ft -Polygon 4 0.00 -5464.66 773.37 5969765.00 665380.00 70 19 25.131 N 148 39 32.296 W E-186 T8.1 8857.00 -5289.19 -66.04 5969922.00 664537.00 70 19 26.857 N 148 39 56.795 W -Plan out by 5.1 2 at 8857.00 -5291.46 -61.44 5969919.84 664541.65 70 19 26.835 N 148 39 56.661 W E-18B T8.2 8863.00 -5071.23 1215.14 5970168.00 665813.00 70 19 28.999 N 148 39 19.400 W Annotation MD TVD ft ft 10200.00 8106.08 TIP 10250.00 8148.08 KOP 10270.00 8165.13 3 10320.00 8209.71 4 10390.00 8274.79 5 10470.00 8349.78 6 10554.00 8428.40 7 10629.00 8498.48 8 10704.00 8568.59 9 10779.00 8638.28 10 10894.00 8742.53 11 11122.36 8857.91 12 11772.36 8861.74 13 12462.36 8862.55 14 12525.00 8862.56 TD Plan: Plan #8 Date Composed: 7/1/2004 Identical to Lamar's Plan #8 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD ft Incl deg Azim deg TVD fi +N/-S ft +E/-W ft DLS Build Turn TFO Target deg/100ft deg/100ft deg/100ft deg 10200.00 33.30 190.19 8106.08 -5004.98 -56.19 0.00 0.00 0.00 0.00 10250.00 32.41 190.73 8148.08 -5031.66 -61.12 1.87 -1.78 1.08 162.01 10270.00 30.61 190.73 8165.13 -5041.93 -63.06 9.00 -9.00 0.00 180.00 10320.00 23.11 190.73 8209.71 -5064.11 -67.27 15.00 -15.00 0.00 180.00 10390.00 20.84 218.39 8274.79 -5087.43 -77.59 15.00 -3.24 39.52 115.00 10470.00 21.04 252.40 8349.78 -5102.98 -100.20 15.00 0.26 42.51 105.00 10554.00 21.39 287.68 8428.40 -5102.89 -129.29 15.00 0.42 42.01 105.00 10629.00 21.31 256.45 8498.48 -5101.93 -155.65 15.00 -0.11 -41.64 255.00 10704.00 21.24 225.10 8568.59 -5114.75 -178.60 15.00 -0.09 -41.79 255.00 10779.00 23.03 195.31 8638.28 -5138.56 -192.14 15.00 2.38 -39.72 265.00 10894.00 28.49 156.87 8742.53 -5185.83 -187.27 15.00 4.75 -33.43 270.00 11122.36 89.53 115.72 8857.91 -5299.33 -45.74 30.00 26.73 -18.02 315.00 11772.36 89.90 37.72 8861.74 -5161.32 539.15 12.00 0.06 -12.00 270.00 12462.36 89.99 120.52 8862.55 -5042.16 1159.31 12.00 0.01 12.00 90.00 12525.00 89.99 113.01 8862.56 -5070.35 1215.20 12.00 0.00 -12.00 270.00 • ~~ ~~ BP-GDB Baker Hughes INTEQ Planning Report ~~ ItYTLQr Company: BP Amoco Date: 7/1/2004 Time: 11:45:02. Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: E-18, True North Site: PB E Pad Verti cal (TVD) Reference: System: Mean Sea Level Well: E-1 8 Section (VS) Reference: Well (O.OON,O. OOE,85.OOAzi) Wellpath: Pla n#8 E-188 Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S E/W MapN MapE VS DLS TFO -- Tool ft deg deg ft ft ft ft ft ft deg/100ft deg' 10200.00 33.30 190.19 8106.08 -5004.98 -56.19 5970206.34 664540.61 -492.19 0.00 0.00 TIP 10225.00 32.85 190.46 8127.03 -5018.41 -58.64 5970192.86 664538.46 -495.80 1.87 162.01 MWD 10250.00 32.41 190.73 8148.08 -5031.66 -61.12 5970179.56 664536.27 -499.42 1.87 161.78 KOP 10270.00 30.61 190.73 8165.13 -5041.93 -63.06 5970169.25 664534.55 -502.26 9.00 180.00 3 10275.00 29.86 190.73 8169.45 -5044.40 -63.53 5970166.77 664534.14 -502.94 15.00 180.00 MWD 10300.00 26.11 190.73 8191.53 -5055.93 -65.72 5970155.20 664532.21 -506.12 15.00 180.00 MWD 10320.00 23.11 190.73 8209.71 -5064.11 -67.27 5970146.99 664530.84 -508.38 15.00 180.00 4 10325.00 22.80 192.48 8214.31 -5066.02 -67.66 5970145.07 664530.49 -508.93 15.00 115.00 MWD 10350.00 21.58 201.88 8237.47 -5075.02 -70.42 5970136.01 664527.92 -512.47 15.00 113.38 MWD 10375.00 20.93 212.08 8260.77 -5083.07 -74.51 5970127.87 664524.02 -517.24 15.00 104.68 MWD 10390.00 20.84 218.39 8274.79 -5087.43 -77.59 5970123.45 664521.03 -520.69 15.00 95.17 5 10400.00 20.50 222.53 8284.15 -5090.11 -79.87 5970120.71 664518.80 -523.20 15.00 105.00 MWD 10425.00 20.10 233.29 8307.60 -5095.91 -86.28 5970114.78 664512.53 -530.09 15.00 101.13 MWD 10450.00 20.37 244.12 8331.07 -5100.38 -93.64 5970110.15 664505.26 -537.81 15.00 91.03 MWD 10470.00 21.04 252.40 8349.78 -5102.98 -100.20 5970107.40 664498.77 -544.57 15.00 80.86 6 10475.00 20.86 254.43 8354.45 -5103.49 -101.91 5970106.85 664497.07 -546.32 15.00 105.00 MWD 10500.00 20.33 265.00 8377.86 -5105.07 -110.53 5970105.09 664488.49 -555.04 15.00 103.10 MWD 10525.00 20.45 275.77 8401.30 -5105.01 -119.20 5970104.96 664479.81 -563.68 15.00 93.21 MWD 10550.00 21.21 286.11 8424.68 -5103.31 -127.90 5970106.46 664471.09 -572.19 15.00 83.11 MWD 10554.00 21.39 287.68 8428.40 -5102.89 -129.29 5970106.86 664469.69 -573.54 15.00 73.44 7 10575.00 20.79 279.08 8448.00 -5101.14 -136.62 5970108.45 664462.32 -580.69 15.00 255.00 MWD 10600.00 20.66 268.48 8471.39 -5100.55 -145.41 5970108.84 664453.52 -589.40 15.00 263.03 MWD 10625.00 21.17 258.06 8494.75 -5101.61 -154.24 5970107.59 664444.71 -598.29 15.00 272.95 MWD 10629.00 21.31 256.45 8498.48 -5101.93 -155.65 5970107.24 664443.31 -599.72 15.00 282.68 8 10650.00 20.71 247.82 8518.09 -5104.22 -162.80 5970104.79 664436.21 -607.05 15.00 255.00 MWD 10675.00 20.58 237.17 8541.49 -5108.28 -170.59 5970100.57 664428.51 -615.16 15.00 263.06 MWD 10700.00 21.10 226.72 8564.86 -5113.74 -177.56 5970094.95 664421.66 -622.58 15.00 273.02 MWD 10704.00 21.24 225.10 8568.59 -5114.75 -178.60 5970093.92 664420.65 -623.70 15.00 282.80 9 10725.00 21.19 216.39 8588.18 -5120.49 -183.55 5970088.07 664415.83 -629.13 15.00 265.00 MWD 10750.00 21.70 206.22 8611.45 -5128.28 -188.27 5970080.18 664411.28 -634.51 15.00 273.12 MWD 10775.00 22.80 196.74 8634.60 -5137.06 -191.71 5970071.32 664408.03 -638.71 15.00 282.59 MWD 10779.00 23.03 195.31 8638.28 -5138.56 -192.14 5970069.82 664407.63 -639.26 15.00 291.37 10 10800.00 23.23 187.30 8657.60 -5146.63 -193.75 5970061.71 664406.20 -641.57 15.00 270.00 MWD 10825.00 23.98 178.12 8680.52 -5156.60 -194.21 5970051.73 664405.96 -642.90 15.00 277.37 MWD 10850.00 25.25 169.64 8703.25 -5166.93 -193.09 5970041.44 664407.31 -642.68 15.00 285.78 MWD 10875.00 26.95 162.03 8725.71 -5177.57 -190.38 5970030.86 664410.25 -640.91 15.00 293.50 MWD 10894.00 28.49 156.87 8742.53 -5185.83 -187.27 5970022.67 664413.54 -638.53 15.00 300.33 11 10900.00 29.78 154.31 8747.77 -5188.49 -186.06 5970020.04 664414.81 -637.56 30.00 315.00 MWD 10925.00 35.62 145.55 8768.81 -5200.11 -179.24 5970008.57 664421.88 -631.78 30.00 317.24 MWD 10950.00 41.93 139.06 8788.30 -5212.44 -169.64 5969996.46 664431.75 -623.28 30.00 324.62 MWD 10975.00 48.53 134.02 8805.90 -5225.27 -157.41 5969983.89 664444.26 -612.22 30.00 329.69 MWD 11000.00 55.30 129.92 8821.32 -5238.40 -142.77 5969971.10 664459.18 -598.78 30.00 333.25 MWD 11025.00 62.19 126.45 8834.28 -5251.58 -125.97 5969958.29 664476.26 -583.20 30.00 335.78 MWD 11050.00 69.16 123.40 8844.58 -5264.59 -107.30 5969945.68 664495.21 -565.73 30.00 337.59 MWD 11075.00 76.17 120.61 8852.02 -5277.22 -87.07 5969933.50 664515.71 -546.68 30.00 338.85 MWD 11100.00 83.22 118.00 8856.49 -5289.25 -65.63 5969921.95 664537.41 -526.37 30.00 339.68 MWD 11122.36 89.53 115.72 8857.91 -5299.33 -45.74 5969912.31 664557.52 -507.43 30.00 340.15 12 11125.00 89.53 115.41 8857.93 -5300.46 -43.36 5969911.23 664559.92 -505.16 12.00 270.00 MWD 11150.00 89.53 112.41 8858.13 -5310.59 -20.50 5969901.60 664582.99 -483.28 12.00 270.00 M W D 11175.00 89.53 109.41 8858.34 -5319.51 2.85 5969893.20 664606.53 -460.79 12.00 270.03 MWD 11200.00 89.54 106.41 8858.54 -5327.20 26.63 5969886.04 664630.48 -437.77 12.00 270.05 MWD 11225.00 89.54 103.41 8858.74 -5333.63 50.79 5969880.14 664654.76 -414.26 12.00 270.08 MWD 11250.00 89.55 100.41 8858.94 -5338.79 75.24 5969875.52 664679.33 -390.35 12.00 270.10 MWD • • ~,~ BP-GDB Baker Hughes INTEQ Planning Report ~EQ _ Company:. BP AmocA - Date: 71112004. Tlme: 11`.45:02 Page: 4 . Field: Prudhoe Bay Co-ordinate(NE) Reference; Well: E-18, True North Site; PB E Pad ' Verti cal (TVD) Reference: ~r_System'. Mea n Sea Level Well: E-1 8 Section (VS) Refere nce: W ell (O.OON,O.OOE,85.OOAzi) Wellpath: Plan#8 E-18B Survey Calculation Method: Mi nimum Curvature Db: Oracle Survey MD Incl ' Azim SSTVD N/S E/W b1apN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 11275.00 89.55 97.41 8859.14 -5342.66 99.94 5969872.19 664704.10 -366.08 12.00 270.12 MWD 11300.00 89.56 94.41 8859.33 -5345.23 124.80 5969870.16 664729.01 -341.54 12.00 270.15 MWD 11325.00 89.57 91.41 8859.52 -5346.50 149.77 5969869.44 664754.00 -316.78 12.00 270.17 MWD 11350.00 89.58 88.41 8859.70 -5346.46 174.76 5969870.03 664778.99 -291.88 12.00 270.19 MWD 11375.00 89.59 85.41 8859.88 -5345.11 199.72 5969871.93 664803.91 -266.89 12.00 270.22 MWD 11400.00 89.61 82.41 8860.06 -5342.46 224.58 5969875.13 664828.70 -241.90 12.00 270.24 MWD 11425.00 89.62 79.41 8860.23 -5338.50 249.26 5969879.62 664853.29 -216.97 12.00 270.26 MWD 11450.00 89.64 76.41 8860.39 -5333.27 273.70 5969885.39 664877.60 -192.16 12.00 270.28 MWD 11475.00 89.65 73.41 8860.54 -5326.76 297.84 5969892.43 664901.59 -167.55 12.00 270.30 MWD 11500.00 89.67 70.41 8860.69 -5319.00 321.60 5969900.71 664925.17 -143.21 12.00 270.32 MWD 11525.00 89.69 67.41 8860.83 -5310.00 344.92 5969910.21 664948.29 -119.19 12.00 270.33 MWD 11550.00 89.71 64.41 8860.96 -5299.80 367.74 5969920.91 664970.88 -95.57 12.00 270.35 MWD 11575.00 89.73 61.41 8861.09 -5288.41 389.99 5969932.78 664992.87 -72.41 12.00 270.37 MWD 11600.00 89.75 58.41 8861.20 -5275.88 411.62 5969945.79 665014.22 -49.77 12.00 270.38 MWD 11625.00 89.77 55.41 8861.31 -5262.23 432.56 5969959.89 665034.86 -27.72 12.00 270.40 MWD 11650.00 89.79 52.41 8861.41 -5247.50 452.76 5969975.06 665054.73 -6.31 12.00 270.41 MWD 11675.00 89.81 49.41 8861.49 -5231.74 472.16 5969991.24 665073.78 14.39 12.00 270.42 MWD 11700.00 89.83 46.41 8861.57 -5214.98 490.71 5970008.40 665091.95 34.33 12.00 270.43 MWD 11725.00 89.86 43.41 8861.64 -5197.28 508.36 5970026.48 665109.20 53.45 12.00 270.44 MWD 11750.00 89.88 40.41 8861.70 -5178.68 525.06 5970045.45 665125.49 71.71 12.00 270.45 MWD 11772.36 89.90 37.72 8861.74 -5161.32 539.15 5970063.11 665139.19 87.26 12.00 270.45 13 11775.00 89.90 38.04 8861.74 -5159.23 540.77 5970065.23 665140.77 89.05 12.00 90.00 MWD 11800.00 89.90 41.04 8861.78 -5139.96 556.68 5970084.85 665156.25 .106.58 12.00 90.00 MWD 11825.00 89.90 44.04 8861.83 -5121.54 573.58 5970103.63 665172.74 125.03 12.00 89.99 MWD 11850.00 89.90 47.04 8861.87 -5104.03 591.42 5970121.53 665190.20 144.33 12.00 89.99 MWD 11875.00 89.90 50.04 8861.91 -5087.48 610.16 5970138.48 665208.56 164.43 12.00 89.98 MWD 11900.00 89.91 53.04 8861.95 -5071.93 629.73 5970154.45 665227.79 185.29 12.00 89.98 MWD 11925.00 89.91 56.04 8861.99 -5057.43 650.09 5970169.40 665247.82 206.83 12.00 89.97 MWD 11950.00 89.91 59.04 8862.03 -5044.02 671.18 5970183.27 665268.62 229.01 12.00 89.97 MWD 11975.00 89.91 62.04 8862.07 -5031.72 692.95 5970196.04 665290.10 251.77 12.00 89.96 MWD 12000.00 89.91 65.04 8862.11 -5020.58 715.33 5970207.66 665312.23 275.03 12.00 89.96 MWD 12025.00 89.92 68.04 8862.15 -5010.63 738.26 5970218.11 665334.94 298.74 12.00 89.96 MWD 12050.00 89.92 71.04 8862.19 -5001.89 761.68 5970227.36 665358.16 322.84 12.00 89.95 MWD 12075.00 89.92 74.04 8862.22 -4994.39 785.52 5970235.38 665381.83 347.24 12.00 89.95 MWD 12100.00 89.92 77.04 8862.25 -4988.15 809.73 5970242.15 665405.89 371.90 12.00 89.94 MWD 12125.00 89.93 80.04 8862.29 -4983.19 834.23 5970247.66 665430.28 396.74 12.00 89.94 MWD 12150.00 89.93 83.04 8862.32 -4979.51 858.95 5970251.88 665454.91 421.69 12.00 89.93 MWD 12175.00 89.94 86.04 8862.35 -4977.13 883.84 5970254.80 665479.74 446.69 12.00 89.93 MWD 12200.00 89.94 89.04 8862.37 -4976.06 908.81 5970256.42 665504.68 471.66 12.00 89.93 MWD 12225.00 89.94 92.04 8862.40 -4976.29 933.81 5970256.73 665529.67 496.54 12.00 89.92 MWD 12250.00 89.95 95.04 8862.42 -4977.84 958.76 5970255.74 665554.65 521.26 12.00 89.92 MWD 12275.00 89.95 98.04 8862.45 -4980.69 983.59 5970253.43 665579.54 545.75 12.00 89.92 MWD 12300.00 89.96 101.04 8862.47 -4984.83 1008.24 5970249.83 665604.27 569.95 12.00 89.92 MWD 12325.00 89.96 104.04 8862.48 -4990.26 1032.64 5970244.94 665628.78 593.78 12.00 89.91 MWD 12350.00 89.97 107.04 8862.50 -4996.95 1056.73 5970238.77 665653.01 617.19 12.00 89.91 MWD 12375.00 89.97 110.04 8862.51 -5004.90 1080.43 5970231.35 665676.87 640.11 12.00 89.91 MWD 12400.00 89.98 113.04 8862.53 -5014.08 1103.68 5970222.68 665700.32 662.47 12.00 89.91 MWD 12425.00 89.98 116.04 8862.54 -5024.46 1126.42 5970212.80 665723.28 684.22 12.00 89.91 MWD 12450.00 89.99 119.04 8862.54 -5036.02 1148.58 5970201.73 665745.69 705.29 12.00 89.90 MWD 12462.36 89.99 120.52 8862.55 -5042.16 1159.31 5970195.83 665756.55 715.44 12.00 89.90 14 12475.00 89.99 119.01 8862.55 -5048.43 1170.28 5970189.80 665767.65 725.83 12.00 270.00 MWD 12500.00 89.99 116.01 8862.55 -5059.98 1192.45 5970178.75 665790.07 746.91 12.00 270.00 MWD • i ~~ ~,~, BP-GDB Baker Hughes INTEQ Planning Report ~~ s tCY°TL+Q- Company: BP Amoco Date: 7/1/2004 Time: 11:45:02 'Page: 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: E-18, True North Site: PB E Pad Vertical (TVD) Reference: System: Mean Sea Level Well: E-18 Section (VS) Reference: Well (O.OON,O.OOE,85.OOAzi)-' Wellpath: Plan#8 E-186 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S ' ' E/W MapN MapE VS DLS TFO' Tool ft deg deg ft ft ft ft ft ft' deg/100ft deg 12525.00 89.99 113.01 8862.56 -5070.35 1215.20 5970168.88 665813.04 768.66 12.00 270.00 TD ~~ BP-GDB Anticollision Report • ~~~ INTLQ~ Company: BP Amoco Date: 7/1/2004 Time: 11:14:33 Page: 1 Field: Prudhoe Bay .Reference S ite: PB E Pad Co-ordinate(NE) Reference: Well: E-1 8, True North Reference Well: E-18 Vertical (T VD) Reference: 31:18 9/26/1981 00 :00 60.5 Re[erence Wellpath: Plan#8 E-186 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Plan: Plan #8 8 NOT PLANNED PROG Interpolation Method: MD + Stations Interval: 1 0.00 ft Error Model: ISCWSA Ellipse Depth Range: 10250.00 to 12525.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1449.45 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Ho le Size Name ft ft in in 2686.00 2680.78 13.375 17.500 13 3/8" 10250.00 8208.58 9.625 12.250 9 5/8" 12525.00 8923.06 2.875 3.750 2 7/8" Plan: Plan #8 Date Composed: 7/1/2004 Identical to Lamar's Plan #8 Version: 1 Principal: Yes Tied-to: From: Definitive Path Summary < Offset Wellpath --> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB E Pad E-18 E-18 V1 10250.00 10250.00 0.00 0.00 0.00 FAIL: NOERRORS/ PB E Pad E-18 E-18A V1 10250.00 10250.00 0.00 0.00 0.00 FAIL: NOERRORS PB E Pad E-19 E-19 V2 Out of range PB E Pad E-19 E-19A VO Out of range PB E Pad E-23 E-23 V2 11615.22 11260.00 1278.72 930.43 348.28 Pass: Major Risk PB E Pad E-23 E-23A V3 12498.51 10480.00 405.05 0.00 405.05 Pass: Minor 1/10 PB E Pad E-23 E-23APB1 V2 12498.51 10480.00 405.05 136.91 268.13 Pass: Major Risk PB E Pad E-23 E-236 V5 12498.51 10480.00 405.05 0.00 405.05 Pass: Minor 1/10 PB E Pad E-24 E-24 V1 10825.00 10730.00 1285.66 827.98 457.68 Pass: Major Risk PB E Pad E-24 E-24A V1 10894.90 11480.00 870.43 0.00 870.43 Pass: Minor 1110 PB E Pad E-24 E-24APB1 V1 10794.16 10630.00 1173.26 754.74 418.52 Pass: Major Risk PB E Pad E-24 E-24AP62 V1 10875.00 11460.00 986.51 963.79 22.72 Pass: Major Risk PB E Pad E-24 E-246 V1 11900.00 11910.00 735.41 647.76 87.65 Pass: Major Risk PB E Pad E-32 E-32 V2 10252.80 10020.00 1120.49 728.08 392.41 Pass: Major Risk PB E Pad E-32 E-32A V4 10252.80 10020.00 1120.49 728.08 392.41 Pass: Major Risk PB E Pad E-32 E-32AP61 V1 10252.80 10020.00 1120.49 728.06 392.43 Pass: Major Risk PB E Pad E-32 E-32PB1 V1 10252.80 10020.00 1120.49 728.08 392.41 Pass: Major Risk PB K Pad K-13 K-13 V1 Out of range Site: PB E Pad Well: E-18 Rule Assigned: NOERRORS Wellpath: E-18 V1 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD A1D `' 'TVD Ref Offset-° TFO+AZLTFO-H S Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft, deg deg in ft ft ft 10250.00 8208.58 10250.00 8208.58 277.40 278.15 190.73 0.00 9.625 0.00 0.00 0.00 FAIL 10260.00 8217.07 10260.00 8217.03 277.45 278.51 190.73 0.00 9.625 0.06 0.00 0.06 Pass 10270.00 8225.63 10270.00 8225.50 277.50 278.86 195.08 4.35 9.625 0.25 0.00 0.25 Pass 10279.98 8234.29 10280.00 8233.98 277.58 279.25 194.85 4.12 9.625 0.62 0.00 0.62 Pass 10289.94 8243.05 10290.00 8242.48 277.65 279.64 194.51 3.78 9.625 1.22 0.00 1.22 Pass 10299.86 8251.90 10300.00 8251.00 277.73 280.02 194.27 3.54 9.625 2.04 0.00 2.04 Pass 10309.74 8260.82 10310.00 8259.53 277.80 280.38 194.04 3.31 7.000 3.11 0.00 3.10 Pass 10319.56 8269.80 10320.00 8268.06 277.87 280.75 193.81 3.08 7.000 4.41 0.00 4.41 Pass 10329.39 8278.86 10330.00 8276.61 277.40 280.63 192.88 358.82 7.000 5.88 0.00 5.88 Pass 10339.19 8287.93 10340.00 8285.16 276.80 280.36 190.68 352.98 7.000 7.45 0.00 7.45 Pass 10348.95 8296.99 10350.00 8293.71 276.20 279.97 187.96 346.50 7.000 9.13 0.00 9.13 Pass 10358.64 8306.01 10360.00 8302.28 275.32 279.45 185.06 339.72 7.000 10.94 0.00 10.94 Pass 10368.25 8314.98 10370.00 8310.85 274.42 278.82 182.15 332.88 7.000 12.91 0.00 12.91 Pass 10377.79 8323.88 10380.00 8319.43 273.46 278.08 179.35 326.10 7.000 15.03 0.00 15.03 Pass 10387.23 8332.70 10390.00 8328.02 272.34 277.23 176.70 319.48 7.000 17.34 0.00 17.33 Pass 10396.52 8341.39 10400.00 8336.61 271.33 276.49 174.26 313.19 7.000 19.83 0.00 19.83 Pass 10405.66 8349.95 10410.00 8345.21 270.32 275.77 172.12 307.19 7.000 22.56 0.00 22.55 Pass TERRIE L RUBBLE BP EXPLORATION AK INC "Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 ~ ,~ ,. r . ~ ; .~ :~ ~d d PAY TO THE ORDER OF 89-6/1252 ~ 28 ~_ DATE ~t--~ { ~ ,.z 6,,,1 . $ ~ ~~~J ~ .~~' DO First National~Bank Alaska ~+ Anchorage, AK 99501 ~ ~ ,; ~t~-- MEMO ~ " ~~~~ ~:L25200060~:99L4~~~6227~~~L55611' OL28 • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ,~~~j ~ /~'~_ PTD# .2~ ~- ~~~ ~ .Development Exploration. Service Stratigraphic CHECK WAAT ADD-OHS `CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well ~ , Permit No, ~ API No. (lf API number Production. shou]d continue to be reported as last two (2) digits a function of the original. API number, staied are between 60-69) above. PILOT IIOLE In accordance with 20 AAC 25.0050, all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated ~in both name (name on permit plus PIS and API number (50 - 70/80) from records, data and .logs acquired for well (name on permit). SPACING The permit is approved subject ~to full EXCEPTION comp]iance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. lCompany Hamel assumes the liability of any protest to the spacing .exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission musi be in no greater than. 30' sample intervals from below the permafrost or from where samples are first .caught and ] 0' sample intervals through target zones. WELL PERMIT CHECKL ST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT E-186 Program DEV Well bore seg ^ PTD#:2041390 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV / 1-OIL GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 Permitfee at#ached- - - - - Yes - - - - - - - - 2 Lease number appropriate__---__ Yes- ------------------------------- -- - - 3 Uniquewell_nameandnumber______________________________________ Yes_ ___--__--__--________- 4 Well located in a_de_finedpool_-_____------------ ---------- Yes- ----.---,---------------------- ----. -- - - 5 Well located proper dis#ance f[om drilling unitboundary- _ - - - .. Yes _ _ ... - .. - - - - -- - -- - - 6 Well located proper distance from other wells______-__---_---------------- Yes_ ____ ___._-------------____.-_--__--_-------_-_-__--__--___-_--_- 7 Sufficient acreage_ayailablein_drillingunit-_-__-________ -_------------- Yes_ --_-.--___________ ------------------------------------------------------- 8 If deviated,is_wellboreplatincluded--------------- ------------ ------ Yes_ ______-________ ---------------------------------------------------------- 9 Operator only affected party - - - - - Yes - ------------------------------------- - - - - - 10 Operato[hasappropriate.bondinfarce---------- -- -- ----- -- -- Yes- ---- -- -- -- -- -- ------- ------- ------------ - -------.....-.. 11 Pe[mit_canbeissuedwithout~nseryatignorder--------------------------- N°-- ---------------------.-------------------------------------------------- Appr Date 12 Permit. can be issuedwjthoutadminist[ative_approval_________________________ Yes_ ____-_-__________________-_------.--_--_-___-__--_...-.._.._____-__--__-_ RPC 7126!2004 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized bylnjection9rde[#(put_1O#in_comments).(For- NA__ ______________-----.-......--.__--__--_----..-._--__ -__--_____-__--__-_ 15 All wells within114_mileareaofreyiewjdentified(Fo[servicewellonly)_______________ NA-_ ____-___--__-_________----.----_-..--..----_-.....-_-_----..----_--_-.---- 16 Pre-produced injector; duration-of pre Production less than 3 months(FOr service well on-ly) - - _N_A_ - - - - - - - - - - - - - - - - - - -------------------------- 17 ACMP_FindingofConsistency_hasbeenissued-for-thisproject_---.---__--__ __-- NA-_ _-__-.-_____________-__--____---------------_-__--__-___-_-_ Engineering 18 Conduckorstring-provided - - - - - - - - NA - - - - - - - - - 19 Surface casingprgtec_ts aII known USDWS - - - NA - - - - - - - - - - 20 CMT-voladequate_tocirculate-onconductor-&surf-csg________________________ NA_- _-__-.-_-.-_-_-_______________--_---.-.- - -- - 21 CMT_vol_ adeguate_to tie-in long s#ring to surf csg_ _ - - - _ - - NA_ _ _ - - _ --------------------------------------------------------------------- 22 CMT.willcoverallknown.productivehorizons_____________ __--_---__--_-- Yes_ _-_-----.---_----_--_--_____-_-_---.-.--.--____-__---------._..---------- 23 Casing designs adequate for G,T,B&-pemiafcost--------------------- ---- Yes- ----- ---.----------------------------.----------------------------------- 24 Adequate tankage-or [eserve pit - - - - - - Yes - - - - . CTDU. - - - - - 25 If_a_re-drill,has_a_10~03forabandonmen#beenapproved_____ ________________ Yes- _____"________---__--__---..____-____-_-------.----__--__--____-___--_-- 26 Adequatewellboreseparation-proposed- ---------- -------------- ---- Yes- -- -- --- -- ---------- ------ ----------------- ..... -------------- -- 27 Ifdiverterrequired,doesitmee#regulations___--__-______________________ NA__ __-__Sidetrack.-.__-__----_____.___-----..-..--______--_-------_-.-----..-.. Appr Date 28 Drillingfluid_programsehematic&equiplistadequate------------------------- Yes_ ___-_-Max MW_12ppg.--_-__________--_------_____-_-.---.._-------. WGA 712612004 29 _B_OPEs,-do They meet-regulation - - Yes - - - - - - - - - - - 30 BOPE-press[atingappropriate;testto-(putpsigincomments)___---------------- Yes_ _-----Test to3500-psi._MSP2342psi._________-_-_-__--__________-----.-_-------..-.. 31 Choke_manrfoldcomplieswlAPI_RP-53 (May 84)------------------------ Yes- ----------------------------------------------------------.---------...-- 32 Work willoccurwi#houtoperationshutdo_wn_______________________________ Yes_ -_____-----_--___-_-----_--______-_---.-...-----___-__------_-------..-.- 33 Is presence-of H2S gas_probable- - - - - - - - - - - N0 Not an H?S pad• - - - - - - - - - - - 34 Mechanical condition of wells withinAORVerifiedGFOr_servicewellonly)____-__ _ NA__ --__---_-____________--_---__-------------_-.--..- ----------------- Geology 35 Permiteanbeissuedwlohydrogen-sulfide measures_________________________ No_- ____-_____- ____-__-------_-___--__---_--__--..-_--_ __--__--_____--_-_ 36 t)ata-presented on potential overpressure zones_--_---------------------- -N_A__ __-___--.__--__-__--__--________-_----...-----_-__--__-----------..-..--.. Appr Date 37 Seismic analysis of shallow gas-zones_ _ - - - - - _ - - - ... - - . - NA- _ - ---------------------------------------------------------------------- RPC 7/26!2004 38 Seabed condition survey-(ifoffshore)_-_-.-_---_._--_--------- ----- NA__ ____ 39 Contact namelphone for weekly progress-reports [exploratory only] - - - - NA_ _ _ _ _ - . - Ge logic ss'on Engineering Public Date: ~,+ ,I Commissioner: Date Commissioner Date 0 ~•2~~ / ~~ • • • 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 APPENDIX. No special effort has been made to chronologically organize this category of information. • Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 18 10:28:53 2005 Reel Header Service name .............LISTPE Date .....................05/11/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/11/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library 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 MWD RUN 1 MW0003369841 S. LATZ HOLT/HILDRET /3~l 8 0~0~ - 1.3~ Scientific Technical Services Scientific Technical Services E-18B PB1 500292065470 BP Exploration (Alaska) Inc. Sperry Drilling Services 18-NOV-05 SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 6 11N 14E 1853 501 60.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 9965.0 • • REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 10212' MD AND THE BOTTOM WAS AT 10220' MD. 4. MWD RUN 1 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS. UPHOLE TIE-IN DATA WERE MERGED WITH RUN 1 DATA. 5. E-18B PB1 WAS ABANDONED AFTER THE RUN 2 TOOLSTRING FAILED TO EXIT THE WINDOW AT 10220'MD/8123'TVDSS. THIS WELL WAS DRILLED AND PERMITTED AS E-18B, BUT THE NAME AND API NUMBER WERE CHANGED AFTER ABANDONMENT TO E-18B PB1. 6. DEPTH SHIFTING WAS WAIVED PER E-MAIL FROM D.DORTCH (SAIC/BP) DATED OCTOBER 17, 2005. THIS WAIVER WAS AUTHORIZED BY DOUG STONER, BP GEOSCIENTIST. MWD DATA ARE CONSIDERED PDC FOR THIS WELL. 7. MWD RUN 1 REPRESENTS WELL E-18B PB1 WITH API#: 50-029-20654-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10375'MD/8266'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/18 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 STOP DEPTH GR 9836.0 10347.0 ROP 10235.0 10375.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE • • PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 9836.0 10375.0 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9836 10375 10105.5 1079 9836 10375 ROP MWD FT/H 0.72 45.57 19.37 281 10235 10375 GR MWD API 23.27 1028.38 108.344 502 9836 10347 First Reading For Entire File..........9836 Last Reading For Entire File...........10375 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/18 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 t • • VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9836.0 10347.0 ROP 10235.0 10375.0 LOG HEADER DATA DATE LOGGED: 02-NOV-04 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10375.0 TOP LOG INTERVAL (FT) 9836.0 BOTTOM LOG INTERVAL (FT) 10375.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 16.1 MAXIMUM ANGLE: 28.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 78012 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 4.125 DRILLER'S CASING DEPTH (FT) 9965.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G) 10.60 MUD VISCOSITY (S) 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 175000 FLUID LOSS (C3) 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 120.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 \~ • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9836 10375 10105.5 1079 9836 10375 ROP MWDO10 FT/H 0.72 45.57 19.37 281 10235 10375 GR MWDO10 API 23.27 1028.38 108.344 502 9836 10347 First Reading For Entire File..........9836 Last Reading For Entire File...........10375 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/11/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................05/11/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File