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Home My WebLink About204-070STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT 18-33A JBR 08/22/2025 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Choke HCR Initially failed, greased, exercised,retested and passed, Choke manifold valve 15 Initially failed, greased, exercised,retested and passed. No other failures. Test Results TEST DATA Rig Rep:G. CoyneOperator:Hilcorp North Slope, LLC Operator Rep:John Pearl Rig Owner/Rig No.:Nabors CDR2AC PTD#:2040700 DATE:6/17/2025 Type Operation:WRKOV Annular: 250/3500Type Test:INIT Valves: 250/3500 Rams: 250/3500 Test Pressures:Inspection No:bopSTS250820160546 Inspector Sully Sullivan Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 6 MASP: 2460 Sundry No: 325-189 Control System Response Time (sec) Time P/F Housekeeping:P PTD On Location P Standing Order Posted P Well Sign P Hazard Sec.P Test Fluid W Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 2 P Inside BOP 0 NA FSV Misc 0 NA 12 FPNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2 3/8"P Annular Preventer 1 7 1/16"P #1 Rams 1 blind/shears P #2 Rams 1 2-3/8"P #3 Rams 1 3"P #4 Rams 1 2 3/8"P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16"P HCR Valves 2 2 1/16"FP Kill Line Valves 2 2 1?16 P Check Valve 0 NA BOP Misc 0 NA System Pressure P3025 Pressure After Closure P2200 200 PSI Attained P15 Full Pressure Attained P57 Blind Switch Covers:Pall stations Bottle precharge P Nitgn Btls# &psi (avg)P10@2010 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 1 P Annular Preventer P4 #1 Rams P3 #2 Rams P2 #3 Rams P2 #4 Rams P2 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill P1        By Grace Christianson at 11:25 am, Apr 01, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.03.31 11:55:27 - 08'00' Sean McLaughlin (4311) 325-189 SFD 4/4/2025 DSR-4/2/29 *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. JJL 4/9/25 10-407 *&: 4/10/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.04.10 08:23:20 -08'00' RBDMS JSB 041025 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: March 31, 2025 Re:18-33A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the 18-33A wellbore as part of the drilling and completion of the proposed 18-33B CTD lateral. Proposed plan: Prior to drilling activities, screening will be conducted to drift for whipstock and MIT. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See 18-33B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to pre-rig, the rig will set the 4-1/2" packer whipstock and mill a single string 3.80" window + 10' of formation. The well will kick off drilling in the Ivishak Zone 2 and lands in Zone 1. The lateral will continue in Zone 1 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will not completely isolate and abandon the parent Prudhoe Pool perfs (Sag perfs will remain open). 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the liner cement job, packer whipstock and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start April 2025) x Reference 18-33A Permit submitted in concert with this request for full details. 1. Slickline : Dummy WS drift 2. E-Line : Set 4-1/2" Packer Whipstock at 11,250’ MD at 330 degrees ROHS* 3. Fullbore : MIT-IA and/or MIT-T to 2,500 psi 4. Coil : Mill Window (if window not possible, mill with rig). – see procedure in PTD 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. Rig Work: 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,460 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~278' (28 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2,696' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr solid liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 40.5 bbls, 15.3 ppg Class G, 1.24 (ft3/sk), TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * Alternate plug placement variance request per 20 AAC 25.112(i) ,p yppg( completion will not completely isolate and abandon the parentpgpg) Prudhoe Pool perfs (Sag perfs will remain open). Post Rig Work: 1. Valve Shop : Valve & tree work 2. Slickline : set LTP*. Set live GLVs. 3. Service Coil : perforate (~1250’) 4. Testing : Portable test separator flowback. Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 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 18-33A Pulled Straddle Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-070 50-029-22598-01-00 13445 Conductor Surface Intermediate Production Liner 8698 80 4104 10926 955 1754 13410 20" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 8698 37 - 117 37 - 4141 35 - 10961 10805 - 11760 11691 -13445 37 - 117 37 - 3586 35 - 8251 8145 - 8679 8668 - 8698 11602 470 3090 5410 7500 10530 none 1490 5750 7240 8430 10160 10903 - 13400 4-1/2" 12.6# L-80 10702 - 10807 8212 - 8698 Structural 4-1/2" HES TNT Perm , 10597 , 7991 No SSSV 10597 , 10749 7991 , 8104 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4545 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 0028321 & 0028307 8069 - 8146 228 0 9625 0 7774 0 0 0 491 0 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S , 10749 , 8104 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 8:04 am, Sep 13, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.09.12 13:31:16 - 08'00' Bo York (1248) WCB 10-3-2024 RBDMS JSB 091924 DSR-9/13/24 ACTIVITYDATE SUMMARY 7/2/2024 ***WELL FLOWING ON ARRIVAL*** (profile modification) MADE MULTIPLE ATTEMPTS TO PULL 2-3/8'' INSITU INSERT SET IN PATCH @ 10891' MD (see log) DRIFTED CLEANLY w/ KJ, 2' x 1-7/8'' STEM, 3.80'' G-RING TO TOP OF PATCH @ 10886' MD RAN KJ, 4-1/2'' GS (cont on next day) ***WSR CONT ON 7-3-24*** 7/3/2024 ***WSR CONT FROM 7-2-24*** (profile modification) PULLED 4-1/2'' NS 450-368 MONO-PAK UPPER PATCH w/ 2.-3/8'' INSITU FROM 10886' MD (elements & o-rings all intact) ***WELL LEFT S/I*** 7/8/2024 ***WELL S/I ON ARRIVAL*** (profile modification) POLLARD #60 RIGGED UP ***CONTINUE ON 7/9/24 WSR*** 7/8/2024 (TFS unit 1 assist SL with Load and Test) Got called off job. 7/9/2024 T/I/O 2537/125/0 Temp S/I (TFS unit 1 assist SL with Load and Test) Pumped 190 bbls of Crude down the TBG for a TBG load. ******WSR Continued on 7-10- 2024******** 7/9/2024 ***CONTINUED FROM 7/8/24 WSR*** (Profile modification) RAN 3.80" GAUGE RING TO TOP OF NS PATCH AT 10,880' SLM RAN 2-7/8" BRUSH & 2.25" G. RING TO 10,950' SLM (brushed 2.31" x-nip in lower patch section) T-BIRD LOADED TBG W/ 190 BBLS CRUDE SET 2-7/8" XX-PLUG IN LOWER PATCH SECTION AT 10,928' SLM ***CONTINUE ON 7/10/24 WSR*** 7/10/2024 *******WSR Continued from 7-9-2024********* Pumped 2 bbls of Crude down the TBG to pressure test patch. TBG lost 33 psi in 5 min. Bled TBG down to 421 psi bleeding back 2 bbls. Well left in SL control. Final WHPS 421/200/0 7/10/2024 ***CONTINUED FROM 7/9/24 WSR*** (Profile modification) SET 4-1/2" UPPER NS MONO-PAK PATCH W/ NERLA 2 SSD (opens up) AT 10,882' SLM T-BIRD PERFORMED PASSING PT TO 2,000 psi PULLED 2-7/8" XX-PLUG AT 10,928' SLM OPENED NS NERA 2 SSD AT 10,873' SLM (42BO pin intact) SET 2-7/8" ORIFICE INSERT IN SSD AT 10,873' SLM (confirmed w/ check set) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** 7/11/2024 T/I/O = 2592/0/0 LRS 70 - Assist Slickline (PROFILE MODIFICATION) Pumped 202 bbls of Crude into TBG for load and test ***Job Continued to 7-12-2024*** 7/11/2024 ***WELL S/I ON ARRIVAL*** PULLED 2-7/8" ORIFICE INSERT FROM 10,853' SLM (all looks good). TAGGED BOTH NIPPLES W/ INSERT; 52' DIFFERENCE. DECISION MADE TO INVESTIGATE. CLOSED SSD @ 10,854' SLM. LOADED TBG W/ 200 BBLS CRUDE. RAN TEST TOOL TO PACKER @ 10,844' SLM. ***WSR CONTINUED ON 7-12-24*** Daily Report of Well Operations PBU 18-33A () RAN 3.80" GAUGE RING TO TOP OF NS PATCH AT 10,880' SLM () PULLED 4-1/2'' NS 450-368 MONO-PAK UPPER PATCH w/ 2.-3/8'' INSITU FROM 10886' MD (elements & o-rings all intact) () MADE MULTIPLE ATTEMPTS TO PULL 2-3/8'' INSITU INSERT SET IN PATCH @ 10891' MD Daily Report of Well Operations PBU 18-33A 7/12/2024 ***Continue Job from 7-11-2024*** LRS Unit 70, Assist Sickline (PROFILE MODIFICATION) Pumped 3 bbls Crude into TBG to assist SL w/ pressure test. SL in control of well and DSO notified upon LRS departure. 7/12/2024 ***WSR CONTINUED FROM 7-11-24*** LRS TO MITT 2000 PSI AGAINST TEST TOOL IN PACKER @ 10,844' SLM (PASSED). PULLED TEST TOOL. SET 2.31" XX PLUG IN X NIPPLE @ 10,906' SLM. MITT 2000 PSI (PASSED). RAN 4 1/2" GS TO 10,845' SLM. PULL TEST UPPER PATCH SECTION 1800#; NO MOVEMENT. OPEN SSD @ 10,854' SLM (decision made to close ssd, pull plug & pop w/ ssd closed) CLOSE SSD @ 10,854' SLM (pt'd tbg w/ gas to 1500 psi to confirmed closed) EQUALIZED & PULLED 2.31" XX PLUG FROM 10,906' SLM ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 7/15/2024 T/I/O=2542/198/0 Temp=S/I (Assist SL with load) Pumped 210 bbls of Crude down the TBG to perform Load and Kill. Ending psi on TBG was 421 psi. Well left in SL control. Final WHPS 421/203/0 7/15/2024 ***WELL SHUT IN ON ARRIVAL*** (Profile modification)' RAN 3.80" G. RING TO PATCH AT 10,860' SLM JARRED ON UPPER PATCH SECTION FOR 1 HR T-BIRD LOADED TBG W/ 210 BBLS CRUDE JARRED FOR TWO HOURS ON UPPER SECTION OF STRADDLE PATCH AT 10,860' SLM. CONTINUED ON 7/16/24 WSR 7/16/2024 ***CONTINUED FROM 7/15/24 WSR*** (Profile modification) PULLED COMPLETE 3 TRIP NS STRADDLE PATCH AT 10,886' ME (all sections in good condition) RAN 10' x 3" BAILER TO DEVIATION AT 11,638' SLM (empty) ***CONTINUE ON 7/17/24 WSR*** 7/16/2024 T/I/O= 730/193/0 LRS 72 Asist Slickline (PROFILE MODIFICATION). Pumped 205 bbls crude into the TBG. FWHP= 512/198/1 7/17/2024 ***CONTINUED FROM 7/16/24 WSR*** (Profile modification) RAN READ 40 ARM CALIPER FROM 11,635' SLM TO SURFACE (good data) ***WELL S/I ON DEPARTURE*** 8/13/2024 *** WELL SI ON ARRIVAL *** MIRU HALLIBURTON TOOLSTRING OAL: 39.11' MAX OD: 1.69" PT TO 300PSI LOW AND 3500PSI HIGH LOG INTO 4.5" X NIPPLE AT 10631' DEVIATED OUT AT 11575' LOGGED INTERVAL 11575' - 10520' RIGGED DOWN *** WELL LEFT S/I ON DEPARTURE. PAD OP NOTIFIED AND STATUS *** JOB COMPLETE JARRED ON UPPER PATCH SECTION FOR 1 HR JARRED FOR TWO HOURS ON UPPER SECTION OF STRADDLE PATCH AT 10,860' SLM. () PULLED COMPLETE 3 TRIP NS STRADDLE PATCH AT 10,886' ME (all sections in good condition) PULL TEST UPPER PATCH SECTION 1800#; NO MOVEMENT. Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/27/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240827 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BCU 23 50133206350000 214093 7/18/2024 AK E-LINE PPROF BRU 222-24 50283201800000 220043 8/8/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 8/6/2024 AK E-LINE Perf BRU 222-26 50283201950000 224035 7/16/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 8/12/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 8/2/2024 AK E-LINE Perf BRU 241-34S 50283201980000 224077 7/28/2024 HALLIBURTON CAST-CBL IRU 44-36 50283200890000 193022 8/10/2024 AK E-LINE PlugPerf PBU 18-13D 50029217560400 224039 8/2/2024 HALLIBURTON RBT PBU 18-33A 50029225980100 204070 8/13/2024 HALLIBURTON RBT PBU Z-228 50029237180000 222055 7/28/2024 HALLIBURTON PPROF PBU Z-234 50029237620000 223065 7/29/2024 HALLIBURTON IPROF PCU 2 50283200229000 179009 7/9/2024 AK E-LINE TubingCut TBU M-02 50733203890000 187061 8/6/2024 AK E-LINE CBL TBU M-02 50733203890000 187061 8/12/2024 AK E-LINE Perf Please include current contact information if different from above. T39491 T39492 T39493 T39493 T39494 T39495 T39495 T39496 T39497 T39498 T39499 T39500 T39501 T39502 T39502 PBU 18-33A 50029225980100 204070 8/13/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.27 11:27:22 -08'00' 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 18-33A Reset Straddle Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-070 50-029-22598-01-00 13445 Conductor Surface Intermediate Production Liner 8698 80 4104 10926 13410 20" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 8698 37 - 117 37 - 4141 35 - 10961 10805 - 11760 11691 -13445 37 - 117 37 - 3586 35 - 8251 8145 - 8679 8668 - 8698 11602 470 3090 5410 7500 10530 none 1490 5750 7240 8430 10160 10903 - 13400 4-1/2" 12.6# L-80 10702 - 10807 8212 - 8698 Structural 4-1/2" HES TNT Perm , 10597 , 7991 No SSSV 10597 , 10749 7991 , 8104 Bo York Operations Manager Dave Bjork David.Bjork@hilcorp.com 907.564.4545 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 0028321 & 0028307 8069 - 8146 0 378 0 9333 0 3107 0 0 0 417 N/A 13b. Pools active after work:PRUDHOE OIL 4-1/2" Baker S , 10749 , 8104 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 1:20 pm, Aug 22, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.08.22 10:02:51 -08'00' DSR-8/23/23WCB 3-11-2024 RBDMS JSB 082923 ACTIVITYDATE SUMMARY 5/17/2023 ***WELL SHUT IN ON ARRIVAL*** PULL 2-7/8" ISO SLEEVE @ 10,849' SLM (10,884' MD) FROM INSIDE PATCH CLOSE 2-7/8" CMD @ 10,849' SLM (10,884' MD) INSIDE PATCH RAN 11' x 2.125", 10' x 2.25" BLR, UNABLE TO PASS OBSTRUCTION @ 10,880' SLM (~15' into blast joint, 2.441" min id) ***WELL LEFT SHUT IN ON DEPARTURE*** 5/23/2023 ***WELL S/I ON ARRIVAL*** RAN 3.70" BARBELL w/ 3.70" LIB TO TOP OF PATCH @ 10,878' MD (clean impression of f/n) PULLED UPPER SECTION OF PATCH FROM 10,878' MD (all elements recovered) (slip housing & slips?) PULLED MIDDLE SECTION OF PATCH FROM 10,898' MD PULLED LOWER ANCHOR @ 10,948' MD (recovered all elements & slips) ***CONTINUE 5/24/23*** 5/24/2023 ***CONTINUE FROM 5/23/23*** DRIFT W/ 10' X 3.0" BAILER, S/D @ 11,622' SLM RUN REED CALIPER, LOG FROM 11,600' SLM TO 10,460' SLM DRIFT w/ 20' x 3.70 DUMMY WHIPSTOCK TO 11,100' SLM ***WELL S/I ON DEPARTURE*** 7/16/2023 ***WELL SHUT IN ON ARRIVAL*** (PATCH SET) MIRU HES E-LINE PT PCE 300 PSI LOW, 3000 PSI HIGH CORRELATE TO SLB PERF AND PATCH RECORD DATED 12-MAY-15 SET NORTHERN SOLUTIONS 4.5" LOWER ANCHOR WITH ME AT 10935' CCL TO ME = 23.5', CCL STOP AT 10911.5' RDMO E-LINE ***WELL SHUT IN ON DEPARTURE*** READY FOR SLICKLINE 7/24/2023 ***WELL S/I ON ARRIVAL*** (pprof) SET MIDDLE ASSEMBLY W/ HEAVY BLAST JOINTS AND 2.31" X-NIPPLE @ 10904' MD (26.15' OAL) SET UPPER NS PATCH ASSEMBLY & MONOPAK PKR MID-ELEM @ 10886' MD (17.05' OAL) 2.31 " ORIFACE INSERT INSTALLED IN OPEN BAKER SLCMD @ SURFACE (2x .188" ports, 45" OAL) ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED*** Daily Report of Well Operations PBU 18-33A SET NORTHERN SOLUTIONS 4.5" LOWER ANCHOR WITH ME AT 10935' () SET UPPER NS PATCH ASSEMBLY & MONOPAK PKR MID-ELEM @ 10886' MD 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): 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 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 18-33A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 204-070 50-029-22598-01-00 13445 Conductor Surface Intermediate Liner Liner 8698 80 4104 10926 955 1759 13410 20" 9-5/8" 7" 4-1/2" 3-1/2" x 3-3/16" x 2 37 - 117 37 - 4141 35 - 10961 10805 - 11760 11686 - 13445 37 - 117 37 - 3586 35 - 8251 8145 - 8679 8667 - 8698 11602 470 3090 5410 7500 10530 / 11160 None 1490 5750 7240 8430 10160 / 10570 10903 - 13400 4-1/2" 12.6# 13Cr85 / L-80 33 - 10807 8212 - 8698 Structural 10597 , 10749 10597 , 10749 7991 , 8104 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 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 13.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 028307 & 028321 No SSSV 10530 / 11160 7991 , 8104 N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: Reset Straddle Patch 42896 4 0 1211 8698 4-1/2" HES TNT Perm / 4-1/2" Baker S 79 By Meredith Guhl at 8:38 am, Apr 08, 2022 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2022.04.07 16:02:15 -08'00' Bo York (1248) ACTIVITYDATE SUMMARY 9/24/2021 ***WELL SHUT IN ON ARRIVAL*** PULL 2 7/8" XX PLUG @ 10,933' MD PULL TOP PORTION OF 45 KB PATCH @ 10,885' MD (11' OF 45 KB PATCH RECOVERED) ***CONTINUE 9/25/21*** 9/25/2021 ***CONTINUE FROM 9/24/21*** 9/26/2021 ***CONTINUE FOM 9/25/21*** RECOVER MISSING PACKING AND BOTTOM PIECE OF QCLL LATCH ASSEMBLY THUNDERBIRD PUMPED 201 BBLS CRUDE SET 2.313" XX PLUG @ 10933' MD ***LAY DOWN CONTINUE 9/27/21 9/26/2021 Assist HES with loading well pump 201 bbls crude to load well 9/27/2021 ***CONTINUE 9/26/21*** ATTEMPT TO TEST BOTTOM HALF OF 45KB STRADDLE PACKER QCLL TEST SUB 2' SPACER, 4 1/2" PACK-OFF @ 10883' SLM, NO PSI INCREASE QCLL TEST SUB 14' SPACER, 4 1/2" PACK-OFF @ 10883' SLM, NO PSI INCREASE LEFT QCLL TEST SUB 12' SPACER 4 1/2" PACK-OFF IN HOLE (16' 8" OVERALL LENGTH) ***CONTINUE 9/28/21 9/28/2021 T/I/O = 1900/183/45. Assist Slickline. Pumped 25bbls diesel down tubing. FWHP's = 1550/180/40 9/28/2021 ***CONTINUE FROM 9/27/21*** RUN CAT STANDING VALVE TO TOP OF PACK-OFF TEST W/ LRS (GOOD TEST) ATTEMPT TO TEST PACKOFF ASSEMBLY, PUMPED 20 BBLS UNABLE TO PRESSURE UP PULL 2 7/8" XX PLUG @ 10,933' MD 10,922' SLM, HUNG UP @ 10,912' SLM 2 7/8" XX PLUG LEFT IN HOLE @ 10,912' SLM ***CONTINUE 9/29/21*** 9/29/2021 ***CONTINUE FROM 9/28/21*** ATTEMPT TO PULL 2 7/8" PLUG @ 10,912' SLM 2 7/8" PLUG LEFT IN HOLE @ 10,912' SLM ***CONTINUE 9/30/21 9/30/2021 ***CONTINUED FROM9/29/21*** PULL 4 1/2" PACK-OFF SPACER JOINT QCLL TEST ASSEMBLY @ 10,867' SLM PULL 27' OF BLAST JOINT @ 10883' SLM ***LAY DOWN CONTINUE 10/1/21*** 10/1/2021 ***CONTINUE FROM9/30/21*** ATTEMPT TO PULL 45 KB LOWER STRADDLE PACKER @ 10926' MD 45 KB LOWER STRADDLE PACKER LEFT @ 11,440' SLM ***CONTINUE 10/2/21*** Daily Report of Well Operations PBU 18-33A Daily Report of Well Operations PBU 18-33A 10/2/2021 ***CONTINUE FROM10/1/21*** PULLED 45 KB LOWER STRADDLE PACKER @ 10,940' MD (MISSING 2 ELEMENTS) 2 7/8" PLUG RECOVERED WITH STRADDLE PACKER RUN 3.70" WIRE GRAB AND 4 1/2" BLB TO 11,545' SLM (RECOVERED SMALL PIECES OF ELEMENT) ***WELL LEFT SI*** 10/5/2021 ***WELL SI ON ARRIVAL*** DRIFT TO 11,642' SLM, WITH 3.80" CENT. 10' X 3" BAILER ***CONTINUE 10/6/21*** 10/6/2021 ***CONT. FROM 10/5/21*** CALIPER TUBING FROM 11550' SLM TO 10500' SLM. (good data) ***WELL LEFT S/I UPON DEPRTURE, PAD OP NOTIFIED OF WELL STATUS*** 2/20/2022 YELLOW JACKET E-LINE JOB SCOPE: SET PART 1 OF 3 BAKER PATCH MIRU. MU AND RIH W/ 9/32 LINE, GR AND BAKER 10 SETTINGTOOL, BAKER SETTING ADAPTER, AND 19.6' LOWER PATCH ASSY W/ 4.5" FLOGARD PACKER.MAX OD 3.70" LOG UP AND CORRELATED TO SCHLUMBERGERPERFORATION AND PATCH SETTING RECORD GR/CCL/HSD/BAKER PATCH X2 12-MAY-2015 SET FLOGARD PACKER MOE AT 10929 FT. CCL TO CENTER OF ELEMENTS IS 18.8 FT. CCL STOP DEPTH 10910.2 FT TOP OF ASSY @ 10923'. ***JOB COMPLETE NOTIFIED DSO WELL TO BE LEFT SI*** 3/14/2022 ***WELL S/I ON ARRIVAL*** (profile mod) SET MIDDLE BLAST JOINT w/ QCLL (Min ID: 2.375", OAL: 27') @ 10,896' elmd) SET UPPER 45KB -SSD w/QCLL, (Min ID = 2.313"OAL 18.03') Top of packer @ 10,878' elmd) T-BIRD LOADED TBG w/ 220 bbls CRUDE SET 2-7/8" XX-PLUG IN BTM OF KB ASSEMBLY @ 10,859'SLM T-BIRD PERFORMS PASSING MIT-T (see t-bird log) SHIFT 2-7/8" CMD OPEN IN PACKER ASSEMBLY @ 10,859' SLM(see psi change) PULLED 2-7/8" XX-PLUG FROM 10,859' SLM. SET 2-7/8" ORIFICE SLEEVE IN CMD @ 10,859' SLM. (check set)(.188 inserts x2) ***WSR CONTINUED ON 3/15/22*** 3/15/2022 ***WSR CONTINUED FROM 3/15/22*** (profile mod) RIGGED DOWN POLLARD UNIT #59 ***JOB COMPLETE, WELL LEFT S/I*** Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:204-070 6.50-029-22598-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13445 13410 8698 10597, 10749 11602 None 7991, 8104 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 37 - 117 37 - 117 1490 470 Surface 4104 9-5/8" 37 - 4141 37 - 3586 5750 3090 Intermediate 10926 7" 35 - 10961 35 - 8251 7240 5410 Liner 955 4-1/2" 10805 - 11760 8145 - 8679 8430 7500 Perforation Depth: Measured depth: 10903 - 13400 feet True vertical depth:8212 - 8698 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr85 / L-80 33 - 10807 33 - 8146 10597 7991Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Perm Packer Liner 1759 3-1/2" x 3-3/16" x 211686 - 13445 8667 - 8698 10160 / 10570 10530 / 11160 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 12210824542 275 37229 Shut-In 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Oestgaard, Finn Finn.Oestgaard@bp.com Authorized Name:Oestgaard, Finn Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 5026 Treatment descriptions including volumes used and final pressure: 13. Production Engineer Challenger Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8698 Sundry Number or N/A if C.O. Exempt: N/A 4-1/2" Baker S Packer 10749 8104 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Set Straddle Patch Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028307 & 028321 PBU 18-33A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Finn Oestgaard Digitally signed by Finn Oestgaard Date: 2020.03.31 12:46:35 -08'00' By Samantha Carlisle at 10:52 am, Apr 02, 2020 RBDMS HEW 4/6/2020 MGR08APR20 DSR-4/2/2020 SFD 4/2/2020 ACTIVITYDATE SUMMARY 12/4/2019 ***WELL FLOWING ON ARRIVAL*** (profile mod) 12 HOUR NIGHT UNIT. SPOT-UP UNIT IN FRONT OF WELL UNTIL TOMORROW. ***WSR CONT ON 12/05/19*** 12/5/2019 ***WSR CONT FROM 12/04/19*** (profile mod) DRIFT TBG W/ 3.805" GAUGE RING TO DREAM CATCHER @ 10,611' SLM/10,631' MD PULL 4-1/2" DREAM CATCHER FROM 10,611' SLM. DRIFT TO 11,000' SLM W/ 12'x3-3/8" DMY GUNS (3.70" od) ***WELL FLOWING ON DEPARTURE*** 12/8/2019 ***WELL S/I ON ARRIVAL*** (IOR) SET 4-1/2" XX-LOCK W/ DREAM CATCHER @ 10,631' MD. RAN CHECK SET TO CONFIRM GOOD SET (sheared). ***WELL LEFT S/I ON DEPARTURE*** 1/12/2020 ***WELL FLOWING ON ARRIVAL***(patch) PULLED 4-1/2" X-LOCK W/ DREAM CATCHER FROM 10,631' MD ****CONT WSR ON 1-13-20**** 1/13/2020 ****CONT WSR FROM 1-12-20****(profile mod) DRIFT W/ 10' X 3.70" DUMMY WHIPSTOCK, 2-1/2" S-BAILER TO DEV @ 11,374' SLM (79 deg) ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** 2/20/2020 ***WELL SHUT IN ON ARRIVAL*** SPOT IN EQUIPMENT AND RU E-LINE. ***JOB CONTINUES ON 21-FEB-20** 2/21/2020 ***JOB CONTINUES FROM 20-FEB-20*** SET LOWER 45 KB STRADDLE PACKER ME @ 10926', TOP OF PACKER @ 10923', OAL = 11.67', MIN ID = 1.781" R-nipple. LOG CORRELATED TO SLB PATCH SETTING RECORD DATED 12-MAY-2015 ***WELL S/I ON DEPARTURE. DSO NOTIFIED*** 2/23/2020 ***WELL S/I ON ARRIVAL***(profile mod) SWCP 4517 RIG UP ***CONTINUE JOB ON 02/24/2020*** 2/24/2020 ***CONTINUE JOB FROM 02/23/2020***(profile mod) DRIFTED W/ 20' x 3.70" DUMMY WHIPSTOCK TO LOWER ANCHOR @ 10,923' MD SET NSAK BLAST JOINT SECTION TO LOWER ANCHOR @ 10,923' MD SET 45 KB UPPER STRADDLE W/ 2 7/8" CMD SLEEVE ON BLAST JOINT SECTION SET 4 1/2" DREAM CATCHER @ 10601' SLM. ***CONTINUE JOB ON 02/25/2020*** 2/25/2020 ***CONTINUE JOB FROM 02/24/2020*** (profile mod) SET 4 1/2" DREAM CATCHER IN X NIPPLE @ 10,631' MD RAN 4 1/2" CHECK SET TO DREAM CATCHER @ 10,631' MD (sheared) ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** Daily Report of Well Operations PBU 18-33A Wallace, Chris D (DOA) From: AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com> Sent: Friday,July 22, 2016 12:59 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Field OIL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AKOpsProdEOCTL;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;AK, OPS Prod Controllers;AK, OPS FS1 DS18 Operator;Wallace, Chris D (DOA); Stone, Christopher Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep;AK, GWO SUPT Well Integrity; Regg,James B (DOA); Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington, Aras J Subject: NOT OPERABLE: 18-33A(PTD#2040700)Tubing x IA Communication All, Producer 18-33A(PTD#2040700)was confirmed to have tubing x inner annulus communication.The well is reclassified as Not Operable, and has been secured with a downhole plug. Work Completed: 1. Slickline:Set tubing tail plug—DONE 07/19/16 2. Fullbore: MIT-T, CMIT-TxIA—DONE 07/19/16.CMIT passed. MIT-T failed with a liquid leak rate of 1.5 bpm. 3. Downhole Diagnostics: MIT-OA—DOEN 7/22/16. Failed, no response to surface Please call with any questions or concerns. Ryan Holt self i Et' GBP Alaska-Well IntegritGlobal W@I15 �lNOV 1 B 40 t5 W Organization Office: 907.659.5102 From: AK, GWO SUPT Well Integrity "-Seat:Jhursday, June 30, 2016 12:30 PM To: AK, S1 OSM; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, GWO SUPT Special Projects; , WO SUPT Slickline; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engl..; sProdEOCTL; AK, OPS PCC Ops Lead; AK, OPS EOC Specialists; AK, OPS Prod Controllers; AK, OPS FS1 DS18 Operator; 'c allace@alaska.gov'; Stone, Christopher Cc: AK, GWO SUPT Well Integrity; AK,'MVO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; 'Regg, James A) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION 18-33A (PTD #2040 Sustained Casing Pressure Inner Annulus Over MOASP All, Producer 18-33A(PTD#2040700)was reported to have inner annulus pressure over`MOASP on June 28th 2016. Wellhead pressures were confirmed to be Tbg/IA/OA= 2400/2240/20 psi and subseque?rt. iFL failed on June 29th 2016 indicating a lack of two competent well barrier envelopes.Additionally during the TIFL, liquid' a&,noted in the conductor x surface casing annulus.The well is now reclassified as Under Evaluation for tubing x inner annulus tammunication and possible surface casing leak.The well is now on a 28 day clock to be repaired or secured. 1 • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday,June 30, 2016 12:30 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Facility OTL;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC EOC IL;AK, OPS PCC Ops Lead;AK, OPS EOC Specialists;AK, OPS Prod Controllers;AK, OPS FS1 DS18 Operator;Wallace, Chris D (DOA); Stone, Christopher Cc: AK, GWO SUPT Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg,James B (DOA) Subject: UNDER EVALUATION 18-33A(PTD#2040700) Sustained Casing Pressure Inner Annulus Over MOASP All, Producer 18-33A(PTD#2040700)was reported to have inner annulus pressure over MOASP on June 28th 2016. Wellhead pressures were confirmed to be Tbg/IA/OA=2400/2240/20 psi and subsequent TIFL failed on June 29th 2016 indicating a lack of two competent well barrier envelopes.Additionally during the TIFL, liquid was noted in the conductor x surface casing annulus.The well is now reclassified as Under Evaluation for tubing x inner annulus communication and possible surface casing leak.The well is now on a 28 day clock to be repaired or secured. Plan Forward: 1. Slickline:Set tubing tail plug 2. Fullbore: MIT-T,CMIT-TxIA 3. Downhole Diagnostics: MIT-OA 4. Well Integrity: Further diagnostics as required Please call with questions or concerns. Ryan Holt (Alter nate: Lee Grey) BP as Well GIO�raGW i Wells 162Ui6 Organization Office: 907.659.5102 1 • STATE OF ALASKA n_ .SKA OIL AND GAS CONSERVATION COMh.._SION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon E Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubmh Operations shutdown ❑ Performed Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casmm Change Approvedrogram Plug for Rednll ❑>erforate New Pool ❑ Repair Well Q Re-enter Susp Well n Other /d 5tracJgC r'! 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development ❑✓ Exploratory ❑ 204-070-0 3 Address P 0 Box 196612 Stratigraphic ❑ Service ❑ 6 API Number Anchorage,AK 99519-6612 50-029-22598-01-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028321 PBU 18-33A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary RECEIVED Total Depth measured 13445 feet Plugs measured None feet JUN 1. 5 2015 true vertical 8898 37 feet Junk measured None feet Effective Depth measured 13410 feet Packer measured See Attachment feet 4OtCC true vertical 8698 2 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"101 1#H-40 38 35-118 35 38 35-118 35 1650 650 Surface 4106 88 9-5/8"40#L-80 35 77-4142 65 35 77-3587 12 5750 3090 Intermediate 10926 48 7"26#L-80 36 45-10962 93 36 45-8252 64 7240 5410 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10903-10918 feet 12220-12470 feet 12850-13400 feet True Vertical depth 8212 07-8222 21 feet 8695 36-8695 1 feet 8689 04-8697 72 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#L-80 32 9-10808 64 32 9-8146 92 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) Treatment descnptions including volumes used and final pressure 13 Representative Daily Average Production-or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1791 4349 0 0 470 Subsequent to operation 1819 6657 32 0 430 14 Attachments(required per 20 AAC 25 070 25 071,&25 283) 15 Well Class after work Daily Report of Well Operations Q Exploratory❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16 Well Status after work Oil 2 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17 I 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 Contact Nita Summerhays Email Nita.Summerhays[Q�bp.com Printed Name Nita Summerhays / Title Data Manager Signatur: Phone 564-4035 Date 6/15/2015 iii• vn- 71q/r5' RBDMS— JUN 2 5 2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028321 ACTIVITY TE I SUMMARY ****WELL S/I UPON ARRIVAL****(Patch Tubing/Liner) R/U SLICKLINE UNIT SWCP#4517 W/RISER VALVE CREW INSTALLED ASV(ssv will not pass LTI test) 5/1/2015 ****CONT. JOB ON 5/2/15**** ****CONT.JOB FROM 5/1/15****(Patch Tubing/Liner) DRIFTED W/30'45KB DUMMY PATCH DRIFT, S/D FROM 230' SLM- 532' SLM (Recovered parafin) DRIFTED W/3.0"GAUGE RING TO 3000' SLM (No restrictions, parafin on g-ring) DRIFTED W/3.50"GAUGE RING TO 4500' SLM (Tools fall slowly, parafin on g-ring) BRUSH & FLUSH W/4-1/2" BRUSH, 3.75"G-RING TO 11,486' SLM (heavy cutting from 200'-1900' SLM) LRS PUMPED—5 BBLS METH &—85 BBLS HOT(180*F) DIESEL DOWN TBG (see Irs log) 5/2/2015 ****CONT. JOB ON 5/3/15**** T/I/0=1500/779/vac Temp=S/I Assist SLB w/B&F (Economic evaluation) Pumped 5 bbls ambient 5/2/2015 neat followed by 85 bbls of 180* DSL down Tbg for B&F. ***Job Cont to 05-03-15 WSR*** ***Job Cont from 05-2-15 WSR*** Standby for SLine to run drift. RD. SLine in control of well per 5/3/2015 LRS departure. FWHP's=1000/780/vac IA,OA=OTG ****CONT. JOB FROM 5/2/15****(Patch Tubing/Liner) DRIFTED W/30'45KB DUMMY PATCH DRIFT TO 11,050'SLM (no restrictions) SET 4-1/2"SLIP STOP CATCHER @ 8102' SLM PULLED INT-OGLV FROM STA#2 @ 7995' SLM/8027' MD SET INT-LGLV IN STA#2 @ 7995'SLM/8027' MD PULLED 4-1/2"SLIP-STOP CATCHER FROM 8102' SLM (empty) 5/3/2015 ****WELL LEFT S/I&DSO NOTIFIED OF STATUS UPON DEPARTURE**** 5/12/2015 (Assist E-line) LRS portion of job was cancelled. E-line in control of well upon LRS departure. ***WELL SHUT IN ON ARRIVAL*** (ELINE: PERF/PATCHES) INITIAL T/I/O= 900/1300/0. (ASV INSTALLED ON WELL) RUN# 1 -- RIH W/ELINE TOOLS& 15'X 2-7/8" PJ OMEGA GUN-PERFORATED INTERVAL @ 10903'- 10918' RUN#2 -- RIH W/4-1/2"BAKER STRADDLE W/CMD SLIDING SLEEVE IN THE OPEN POSITION AND SET @ 10897'- 10922' MID ELEMENT TO ELEMENT(TOP @ 10896') (STRADDLE SPECS=31.86' OAL/3.70"MAX OD/2.313"MIN ID)(SET STRADDLE ACROSS NEW PERFS SHOT ON PREVIOUS RUN) RUN#3 -- RIH W/4-1/2"BAKER FLOGAURD PATCH AND SET @ 5645'-5675' MID ELEMENT TO ELEMENT(TOP© 5644') (FLOGAURD PATCH SPECS= 36.60' OAL/3.70" MAX OD/2.45" MIN ID) FINAL T/I/O=2200/1300/0. WELL SI ON DEPARTURE. 5/12/2015 ***JOB COMPLETED ON 12-MAY-2015*** T/I/O=2521/1309/4 Temp=S/I Assist SSL with Load&test (Patch) Job in Progress ***Job 5/13/2015 cont. to 5-15-15 WSR*** ***WELL S/I ON ARRIVAL***(patch tubing/liner) R/U SWCP 4519 5/13/2015 ***WSR CONT ON 5/14/15*** ***WSR CONT FROM 5/13/15***(patch tubing/liner) SET 2-7/8"XX PLUG IN CMD SLIDING SLEEVE @ 10,899' SLM/10,912' MD LRS PERFORM PASSING MIT-T TO 2500 psi (see Irs AWGRS) 5/14/2015 ***CONTINUE ON 5/15/2015*** ***Job cont from 5-13-15 WSR*** T/I/O=2521/1309/4 Temp=S/I Assist SSL with Load&test (Patch) Pumped 2 bbls neat follwed by 235 bbls of 60*crude down TBG to load. Pumped 1 bbls crude down TBG to pressure up on SLine plug for PT. Pumped a total of 68 bbls of crude down IA during lube and bleed to load. (MIT-T) Pumped a total of 1 bbls down TBG to reach test pressure of 2500 psi 1st 15min=TBG lost=55 psi // IA gain=4 psi 2nd 15min=TBG lost= 20 psi // IA lost= 1 psi Total test TBG lost 75 psi // IA lost= 3 psi ***Job cont. to 5-15- 5/14/2015 15 WSR*** Daily Report of Well Operations ADL0028321 - ***CONTINUE FROM 5/14/2015*** LRS PERFORM PASSING C-MITT x IA(see Irs AWGRS) R/D SWCP 4519 5/15/2015 ***JOB COMPLETE, PAD OP NOTIFIED*** ***Job cont.from 5-14-15 WSR*** CMIT TxIA 2500 psi Pumped a total of 2 bbls crude to obtain test pressure 1st 15 min=TBG lost= 8 psi II IA lost= 11 psi 2nd 15min =TBG lost= 6 psi // IA lost= 6 psi Total test= TBG lost= 14 psi II IA lost= 17 psi Sline in control of well per LRS departure. DSO notified of well. There was a FLUID PACKED ANNULUS on the SSV panel conversation had with DSO ok to leave it there. Caution Tags hung on MV& IA CV. CV's= 5/15/2015 OTG FWHP's=850/850/9 ****WELL S/I UPON ARRIVAL****(Patch tubing/liner) PULLED 2-7/8"XX PLUG FROM CMD SSD @ 10876' SLM/ 10910' MD RAN 2-7/8" B-SHIFTING TOOL THROUGH CMD SSD @ 10876' SLM/ 10910' MD (Open) SET 2-7/8"ORIFICE INSERT W/2 x 3/16" PORTS IN CMD SSD @ 10876' SLM/ 10910' MD RAN CHECK SET TO ORIFICE INSERT(Sheared) 5/30/2015 ***WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** FLUIDS PUMPED BBLS 7 METH 89 DIESEL 307 CRUDE 403 TOTAL • C) w O o o• vLn o oLO O LC) r- � U O o O N o O O o L LU d CO O Ln M CO N v - «) ti d CO N CO CO N N CO d' N N CO 06 a7 N d' r CO O co r` O in O) N- ti O) O) 00 d' N CO CO CO CO (O LC) CO CO CO CO CO CO CO CO p „ „ , „ „ H r- CO N CO L() LO LO LC) N N N- O M d O N • - 00 CO d' (fl r-- LO,-) 00 .- (O CO O CO CO CO CO CO CO CO MO) N CO CO N M CA C) 00 (fl 00 N CO d- O O) N T d' CO N- O CO N N CO O 2 QN LO N CO CO M co (0 O O) N M (p OO M M COCD N-(0 N- N- N M co N = 0 i � J H O O O o roc o 0 Q d• co co co 0o co J J J �CI) co , C () It J (0 M Nin O (fl U F N N N O r r i M N 40; 01 ,4) (.1014 L N CO 00 O CN O a) M O N K d O J W 01 O O W W O Q U O CC CC 1Y CC CC CC W Z Z W W W W W W m Q H Z Z Z Z Z O O U Z J J _J J J U) F- Packers and SSV's Attachment ADL0028321 SW Name Type MD TVD Depscription 18-33A PACKER 10750.93 8105.43 4-1/2" BAKER SABL-3 PACKER 18-33A PACKER 10805.22 8144.51 4-1/2" TOP PACKER 18-33A PACKER 11685.87 8666.5 3-1/2" BAKER KB TOP PACKER f TREE= 4-1/8"CIW FLSWELL _ ACTUATOR 18-3 3A SAFE THAN NORMAL. CHECK ITH WES HAVE ER PSI RATE ACTUATOR= BAKER C OKB.ELEV= 54.0' BF.EI.EV= 33.87' KOP= 1053' Max Angle= 100'©12479'' 2199' -I4-1/2"F5 ERG)SVLN SSS/NP,D=3.812" Datum MD 7869' I] Datum ND= 8800'SS 9-5/8"CSG,40#,L-80 BTC,D=8.835" -{ 4141' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE I 1 4283 3679 49 KBG2-LS-M DOME NT 16 04/05/15 L 2 8027 6223 46 KBG2-LS-M DOME NT 16 05/03/15 4-1/2"BKR FLOGUARD PATCH, -I 5644'-5681' —ay 3 10683 8055 42 KBG2-LS-M TO DMY NT 0 10/29/95 D=2.45(05/12/15) awl NOTE REQUIRES MOG'Fi VALVES *STA#3=EQUALIZING DMY Minimum ID = 2.313" @ 10910' 2-7/8" X NIPPLE INSIDE SLD SLV j x X" 10749' - 7"X4-1/2"BKR SPKR,D=3.937" ' in—I., 10783' H4-1/2"HES XN NP,MSL®D=3.80"(06113/04) TOP OF 4-12"LNR -{ 10806' 4-1/2'TBG.12.6#,L-80 BTC-MOD, -{ 10807' ] 10806' --Ir X 4-1/2"BKR LTP&LNR I-GR,ID=? .0152 bpf,ID=3.958' 10807' -{4-12"WLEG,D=3.958' -{ELMD TT NOT LOGGED 10896'-10929' -{4-112"BKR 1a-SIT-U GL STRADDLE, D=2.45`(05/12/15) L.` .z _ 10902' H 3-1/2"XO T02.7/8"PIN,D=2.441" ' ` 7'CSG,26#,L-80 BUTT MOD, H 10961' 10910' -{2-7/8"BKR SLCMD SLD SLB,D=2.31"(05/13/15) .0383 bpf,D=6.276' 10912' -{2-31"X-ORFICE PiSERT w/2ea 3/16"FORTS(05/30/15) :. _. 11686' -{3.7'BKR KB LTP,D=2.372" TOP OF LM/CEMENTED -{ 11691' N 1 ► 11691' --I3.r BKR DEPLOY SLV,D=3.0' 4 • ' 11711' -{3-1/2"HOWCO X NP,D=2.812" • • • ► 3-12'LM,9.3#,L-80 STL,_0087 bpf,D=2.99T H 11722' 4 ! 11722' H3-1/2"X 3-3/16'XO,0=2.786" •4 PERFORATION SUMMARY •• MLLOUT WrDOW(18-33A) 11760'-11776' REF LOG: BFO CR/ROP/PRESS ON 06/18/04 ♦1%, ANGLE AT TOP PERF: 84' C 12220' Note:Refer to Production DB for historical perf data SIZE SPF NERVAL Opn/Sqz SHOT SQZ 12166' --{3-3116 X 2-7/8"XO,D=2.387" 2-7/8' 6 10913-10918 0 05/12/13 2 6 12220-12470 0 06/22/04 2" 6 12850-13400 0 06/22/04 .v v.y.y.v atati 4-12"LNR,12.6#,L-80,.0152 bpf,D=3.958" -{ 13289' `......'A A 13410' H PBTD 3-3/16"LN 2,6.2#,L-80 TCN,.0076 bpf,ID=2.80' H 12166' `. vir 2-718"LPR 6.5#,L-80 STL,.0058 bpf,D=2.441" -{ 13446' DALE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/29/95 D-9 INITIAL COMPLETION 05/08/15 RCT/JMD GLV C/0(05/03/15) WELL: 18-33A 06/23/04 KAK CTD SIDETRACK(18-33A) 05/12/15 JCP/PJS ADPERF/SET PATCFES PERMIT No: 2040700 04/14/14 AO/PJC SET VAR'(04/12/14) 05/14/15 STF/PJC SET XX PLUG N SLD SLV API No: 50-029-22598-01 02/26/15 RJK/PJC PULL WRP 05/26/15 RCB/PJC TREE C/O SEC 24,TI 1N,R14E,1590'FNL&56'FEL 02127/15 PJC GLV/LEGEND CORRECTIONS -05/30/15 RCT/PJC RLL XX PLUG/SET ORFCE INSERT 04/05/15 JMG/PJCdGLV CJO-VALVE TY FE UPDATE BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, May 31, 2015 11:16 AM To: AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Field OTL; AK, OPS FS1 Facility OTL; AK, OPS FS1 OSM; AK, OPS PCC EOC TL;AK, OPS Prod Controllers; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A; AK, OPS FS1 DS18 Operator; Morrison, Spencer;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Regg, James B (DOA) Subject: OPERABLE: Producer 18-33A (PTD# 2040700) Passing CMIT T x IA Post Patch set Attachments: image001.png; image002.png; 18-33A.pdf; Producer 18-33A (PTD#2040700) TIO Plot 05-31-15.docx All, Producer 18-33A (PTD#2040700) passed an MIT-Ton 05/14/2015 and a CMIT T x IA on 05/15/15 after setting a tubing patch to repair tubing x inner annulus communication. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please use caution while placing the well on production due to fluid packed annuli. • Well status is Operable • Annuli are fluid packed A copy of the wellbore schematic and TIO plot are included for reference. Thank you, Kevin Parks (Alternate: Whitney Pettus) JUN U 9 2-M5 BP Alaska-Well Integrity Coordinator scow JUN GVVGlobal Wells �/�/ Organization Office: 907.659.5102 WIC Email:AKDCWeIIIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, May 14, 2015 8:47 PM —� To: AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead;-AK, OPS FS1 Field OTL; AK, OPS FS1 Facility OTL; AK, OPS FS1 OSM; AK, OPS PCC EOC TL; AK, OPS Prod Controllers; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A; AK, OPS FS1 DS18 Operator; Morrison, Spencer; Wallace, Chris D (DOA); 'Regg, James B (DOA) (IIm.regg(a alaska_gov)' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Inegrity Engineer; 1 Producer 18-33A(PTD#2040700)TIO Plot 05-31-15 OM MOM 05515 059511 OM% 041515 �„ aa„ ot,K„ MO 11 01.15 • TREE= ' CNV D 1 8-33A LOWER THAN NORMAL. CHECK WITH W ACTUATOR PSI RATE ACTUATT OR= BAKER OKB.ELEV= 54.0' BF.ELEV= 33.87' KOP= 1053' Max Angle= 100°@ 12479' Datum MD 7869' I 2199' J4-1/2"HES HRQ SV LN SSSV NP,D=3.812' O Datum TVD= 8800'SS 9-5/8"CSG,40#,L-80 BTC,ID=8.835" —( 4141' GAS LIT MANF� DS ST NO TVD DEV TY PE _ VLV LATCH PORT DATE 1 4283 3679 49 KBG2-LS-M DOME NT 16 04/05/15 2 8027 6223 46 KBG2-LS-M DOME NT 16 05/03/15 4-1/2"BKR FLOGUARD PATCH, H 5644' -5681' 2 • 3 10683 8055 42 KBG2-LS-M 'EO DMY NT 0 10/29/95 D=2.45(05/12/15) 'd NOTE REQUIRES MODIR®VALVES STA X 3=EQUALIZING DMY Minimum ID = 2.313" @ 10910' 2-7/8" X NIPPLE INSIDE SLD SLV g 10749' —17"X 4-1/2'BKRS PKR,D=3.937" 10783' —4-1/2"HES XN NP,MILLED D=3.80'(06/13/04) TOP OF 4-1/2"LNR H 10806' f 10805' 7"X 41/2"BKR LTP&LNR HGR,ID=? 4-1/2-TBG, 12.6#,L-80 BTC-MOD, J 10807' j ' P_ _ .0152 bpf,D=3.958' I 10807' —14-1/2"WLEG,D=3.958' H ELM)TT NOT LOGGED 10896' - 10929' J4-1/2'BKR IN-SIT-U GL STRADDLE, MI 0174 ' D=2.45"(05/12/15) 10902' H3-112"XO TO2.7/8"FIN,ID=2.441" 7"CSG,26#,L-80 BUTT MOD, J 10961" 1--Al 10910' J2-718'BKR SLCMD SLD SLB,D=2.31'(05/13/15) l .0383 bpi,ID=6.276' 10912' H2-7/8"HES NP,D=2.313"(05/14/15) I E:41 :I I 11686' —13.7"BKR KB LTP,D=2.372" TOP OF LNR/CEMENTED H 11691' 11691' H3.7"BKR DEPLOY SLV,D=3.0" • 11711' -13-1/2"HOWCO X NIP,D=2.812" X. 4 4 / 3-1/2"LNR,9.3#,L-80 STL,.0087 bpf,D=2.992" H 11722' 4 __ , i 0, 11722' —{3-112"X 3-3/16"XO,D=2.786" •41 • 4 MLLOIJT WINDOW(18-33A) 11760'-11776' PERFORATION SUMMARY REF LOG: BH GR/ROP/PRESS ON 06/18/04 •Os%., ANGLE AT TOP PERE: 84°@ 12220' �` Note:Refer to Roduction DB for historical peri data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 12165'J-13-3/16 X 2-7/8"X0,113=2.387' 2-7/8" 6 10913- 10918 0 05/12/13 2" 6 12220- 12470 0 06/22/04 2" 6 12850- 13400 0 06/22/04 •V.... 4-1/2"LNR, 12.6#,L-80,.0152 bpi,ID=3.958" J 13289' `1.1.1.1•'•'• 13410' H PBTD 3-3/16"LNR,62#,L-80 TCA,.0076 bpf,D=2.80" H 12165' i A;;, 2-7/8'LNR 6.5#,L-80 STL, .0058 bpf,D=2.441" H 13445' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY (J14T 10/29/95 D-9 IMTIAL COMPLETION 05/08/15 RCT/JMD GLV CIO(05/03/15) WELL: 18-33A 06/23/04 KAK CTD SIDETRACK(18-33A) 05/12/15 JCMf PJS ADPERF/SET PATCHES PERMIT No:"2040700 04/14/14 AO/PJC SET WRP(04/12/14) 05/14/15 STF/PJC SET XX RUG N SLD SLV AR No: 50-029-22598-01 02/26/15 RJK/PJC PULL WRP SEC 24,T11N,R14E, 1590'FNL&56'1H 02/27/15 PJC GLV/LEGEND CORRECTIONS 04/05/15 JMG/PJC GLV C/O-VALVE TY PE UPDATE BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, May 14, 2015 8:47 PM To: AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Field OTL; AK, OPS FS1 Facility OTL; AK, OPS FS1 OSM; AK, OPS PCC EOC TL;AK, OPS Prod Controllers;AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A; AK, OPS FS1 DS18 Operator; Morrison, Spencer;Wallace, Chris D (DOA); Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney Subject: NOT OPERABLE: Producer 18-33A (PTD# 2040700) Well Test for Economic Evaluation Complete Attachments: image001.png All, Producer 18-33A (PTD#2040700) recently underwent well tests for economic evaluation. The well tests have been completed and a tubing patch was set on May 12, 2015 to repair known tubing by inner annulus communication. However, pressure testing to confirm two competent barriers to formation will not be complete before the 28 day evaluation period granted by the AOGCC expires. This well has been reclassified as Not Operable until integrity can be verified or restored. Plan forward: 1. Fullbore: MIT-IA to confirm well barriers 2. Well Integrity Coordinator: Reclassify well as operable pending a passing MIT-IA Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED MAY 2 12015 (iillrrnule: k&'i'in l'ctrlo) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D&C_WelI Integrity Coordinator Sent: Tuesday, April21, 2015 8:45 PM To: AK, OPS EOC Specllists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Field OTL; AK, OPS FS1 Facility OTL; AK, OPS FS1 OSM; AK, OPS PCC EOC TL; AK, OPS Prod-Controllers; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A; AK, OPS FS1 DS18 Operator; Morrison, Spencer; Wallace, Chris D (DOA); 'Regg, James B (DOA) (jim.regg@alaska.gov)' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects-lllell Integrity Engineer; 1 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Tuesday, April 21, 2015 7:48 AM To: 'AK, D&C Well Integrity Coordinator' Cc: Regg,James B (DOA) Subject: RE: UPDATE April 20, 2015: UNDER EVALUATION: Producer 18-33A (PTD#2040700) Economic Evaluation Attachments: image001.png Whitney, Plan forward approved with the requested 28 days. Thanks and Regards, ;gys Chris Wallace s�.ANNE�) .p R 2 3 2015 Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542(fax) chris.wallace@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 Chris Wallace at 907-793-1250 or chris.wallace©alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Monday, April 20, 2015 9:38 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: UPDATE April 20, 2015: UNDER EVALUATION: Producer 18-33A(PTD# 2040700) Economic Evaluation Chris, As per our conversation, Producer 18-33A(PTD#2040700) has been online since April 17th and has thermally stabilized. The current well pressures are T/I/0= 570/1620/130 psi with 1930 psi of gas lift utilized to assist with well kick off. We have seen no significant pressure changes. BP requests the Under Evaluation period be extended to 28 days instead of the originally requested 14 days in order to obtain more accurate Well Test data.The well is currently being considered for a tubing patch.The additional data is to confirm the current Well Test data is not anomalous or due to the long shut- in period. Please call with any questions or concerns. As requested, an updated TIO plot is attached. Thank you, Whitney Pettus 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday,April 21, 2015 8:45 PM To: AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Field OTL; AK, OPS FS1 Facility OTL;AK, OPS FS1 OSM; AK, OPS PCC EOC TL;AK, OPS Prod Controllers;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A;AK, OPS FS1 DS18 Operator; Morrison, Spencer;Wallace, Chris D (DOA); Regg,James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney Subject: UPDATE April 21, 2015: UNDER EVALUATION: Producer 18-33A (PTD#2040700) Economic Evaluation Attachments: image001.png All, Producer 18-33A(PTD#2040700) has been online since April 17th and has thermally stabilized. BP has been given permission by the AOGCC to extend the Under Evaluation period to 28 days instead of the originally requested 14 days. The extension will be used to obtain more accurate Well Test data in consideration of setting a tubing patch. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED APR 2 3 2015 (4lie rnatc'. Kevin Parks) BP Alaska-Well Integrity Coordinator G1NO :al�'�ciis WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com From: • D&C Well Integrity Coordinator Sent: Thurs.• April 16, 2015 9:12 AM To: AK, OPS EOC •- ists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Field OTL; AK, OPS FS1 Facility OTL; AK, OPS FS1 OSM; AK, OPS PCC EOC TL; • •PS Prod Controllers; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, D&C Wireline Operations -• Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A; AK, OPS FS1 DS18 Operator; Morris.- pencer Cc: AK, D&C DHD Well Integrity Engineer; AK, D& - I Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, s tney; 'Wallace, Chris D (DOA)'; 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION: Producer 18-33A(PTD# 2040700) Econo ' valuation All, 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday,April 20, 2015 9:38 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; Regg,James B (DOA) Subject: UPDATE April 20, 2015: UNDER EVALUATION: Producer 18-33A(PTD#2040700) Economic Evaluation Attachments: Producer 18-33A(PTD#2040700)TIO Plot.docx Chris, As per our conversation, Producer 18-33A(PTD#2040700) has been online since April 17th and has thermally stabilized. The current well pressures are T/I/0=570/1620/130 psi with 1930 psi of gas lift utilized to assist with well kick off.We have seen no significant pressure changes. BP requests the Under Evaluation period be extended to 28 days instead of the originally requested 14 days in order to obtain more accurate Well Test data.The well is currently being considered for a tubing patch.The additional data is to confirm the current Well Test data is not anomalous or due to the long shut- in period. Please call with any questions or concerns. As requested, an updated TIO plot is attached. Thank you, Whitney Pettus (.lhcrnolc hcrrvr !'orbs) BP Alaska-Well Integrity Coordinator Gyv . SCANNED APP 2 3 2015 WIC Office: 907.659.5102 WIC Email: AKDCWelllntexrityCoordinator@BP.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, April 16, 2015 9:12 AM To: AK, OPS EOC Specialists; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Field OIL; AK, OPS FS1 Facility OR; AK, OPS FS1 OSM; AK, OPS PCC EOC TL; AK, OPS Prod Controllers; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A; AK, OPS FS1 DS18 Operator; Morrison, Spencer Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Wallace, Chris D (DOA); 'Regg, James B (DOA) (jim.regg@alaska.gov)' Subject: UNDER EVALUATION: Producer 18-33A(PTD# 2040700) Economic Evaluation All, Producer 18-33A(PTD#2040700) is a long term shut in natural flow producer with known tubing x inner annulus x outer annulus communication.The well passed a CMIT-TxIA to 3,500 psi performed on April 12,2014 as well as passed PPPOT- T/IC testing performed Feb 17, 2014. BP has been given permission by the AOGCC to flow the well for economic evaluation. The well will be placed online for a maximum of 14 days to facilitate this evaluation. The well will be monitored during this time at a minimum of twice daily until thermally stable. Once the well is stable,the annuli 1 pressure will not be actively managed. If any abnormal pressure responses are observed or an annulus breaks MOASP, immediately report the problem to the Well Integrity Engineer. At this time the well has been reclassified as Under Evaluation. Please use caution when bringing the well online as the annuli are fluid packed. Plan forward: 1. Operations: Place well on production 2. DHD: Monitor until thermally stable Please call with any questions or concerns. Thank you, Whitney Pettus 1110'laic kcvi,i Parks) BP Alaska-Well Integrity Coordinator GW WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator@BP.com 2 Producer 18-33A(PTD#2040700)TIO Plot 4/200is- LD / W«1.1633 3 3X +n, t a 5a ON 00A 000A —a Dx 3230Ur 15 010695 011315 03015 033315 04,115 50 10.15 003"15 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, April 16, 2015 9:12 AM To: AK, OPS EOC Specialists;AK, OPS FS1 DS Ops Lead;AK, OPS FS1 Field OTL;AK, OPS FS]. Facility OTL;AK, OPS FS1 OSM;AK, OPS PCC EOC TL;AK, OPS Prod Controllers;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead; Daniel, Ryan; Cismoski, Doug A;AK, OPS FS1 DS18 Operator; Morrison, Spencer Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney;Wallace, Chris D (DOA); Regg, James B (DOA) Subject: UNDER EVALUATION: Producer 18-33A (PTD#2040700) Economic Evaluation Attachments: image001.png All, Producer 18-33A(PTD#2040700) is a long term shut in natural flow producer with known tubing x inner annulus x outer annulus communication.The well passed a CMIT-TxIA to 3,500 psi performed on April 12, 2014 as well as passed PPPOT- T/IC testing performed Feb 17, 2014. BP has been given permission by the AOGCC to flow the well for economic evaluation. The well will be placed online for a maximum of 14 days to facilitate this evaluation. The well will be monitored during this time at a minimum of twice daily until thermally stable. Once the well is stable,the annuli pressure will not be actively managed. If any abnormal pressure responses are observed or an annulus breaks MOASP, immediately report the problem to the Well Integrity Engineer. At this time the well has been reclassified as Under Evaluation. Please use caution when bringing the well online as the annuli are fluid packed. Plan forward: 1. Operations: Place well on production 2. DHD: Monitor until thermally stable Please call with any questions or concerns. SCANNED APR 2 3 2015 Thank you, Whitney Pettus (Alternate: Kevin Parks) BP Alaska-Well Integrity Coordinator GJ,j Gsobal Weis X71/1! Orgawat,on WIC Office: 907.659.5102 WIC Email: AKDCWelIIntegntyCoordinator(a)BP.com 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday,January 29, 2015 8:21 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Permission to flow 18-33A(PTD#2040700)for economic evaluation Attachments: 18-33A Wellbore Schematic.pdf; image001jpg Chris, Per our conversation early I would like to request permission to bring online Producer 18-33A(PTD#2040700)which is a natural flow well that has been a LTSI due to TxIA and IAxOA communication for economic evaluation.The well has a passing CMIT-TxIA to 3,500 psi performed on April 12, 2014 as well as passing PPPOT-T/IC performed Feb 17, 2014. Plan forward: 1. Operations: Bring well online 2. DHD: Constant monitoring of well while online 3. Operations: Perform necessary well tests The current thought is that 14 days will be sufficient for evaluating the economics involved with the necessary wellwork to bring this well back to operability status. Please let me know if you have any questions. I have included a copy of the wellbore schematic for reference. Thank you, Laurie Climer (Alternate:Jack Disbrow) BP Alaska-Well Integrity Coordinator GVVGVVGlottal Wens Orgarnzat.on WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 TWE CNV ' WELLHEAD= FMC 1 8-33A STHANTY NOTES: GLMS HAVE NORMAL. CHECKWITH W EER PSI RATE ACTUATOR= BAKER C KB.BEV= 54.0' BF.B_EV= 33.87' I] I KOP= 1053' Max Angle= 100°@ 12479' Datum _ 9 2199' H4-1/2"HES HRO SVLN SSSV NP,D=3.812" 1751 Datum TV D= 8800.-B-6- 9-5/8" 800'SS9-5/8"CSG,4011,L-80 BTC,ID=8.835" - 4141' GAS LIFT MANDRELS ST MD 'VD DEV TYPE VLV LATCH FORT DATE 1 4283 3679 49 KBMG-2 DMY NT 0 01/27/05 Minimum ID =2.372" 11686 L 2 8027 6223 46 KBMG-2 DMY NT 0 01/27/05 3 10683 8055 42 KBMG-2 DMY INT 0 06/29/04 3.70" BKR KB LNR TOP PKR NOTE PROBLEM MANDRELS;REQUIRE SPECIAL VALVES z 10749' —{7"X 4-1/2"BKR S PKR,D=3.937" ' , 10783' —14-1/2"HES XN NP,MLLED ID=3.80"(06/13/04) TOP OF 4-1/2"LNR — 10806' 4-1/2"TBG, 12.6#,L-80 BTC-MOD, — 10807' r 10805' —{7"X 4-1/2"BKR LTP&LNR HGR,ID= .0152 bpf,D=3.958" 10807' H4-112"WLEG,D=3.958" HELM)TT NOT LOGGED 10888' —{4-1/2"WFDWRP(04/12/14) 7"CSG,26#,L-80 BUTT MOD, —{ 10961' , .0383 bpf,ID=6.276" ►_. ►_ 11686' —13.7"BKR KB LTP,ID=2.372" TOP OF CEuENT — 11691' 4 11691' 3.7"BKR DEPLOYMENT SLV,ID=3.0" t • 11711' —13-1/2"HOWCOXNP,ID=2.812" I 4 3-1/2"LNR,9.3#,L-80 STL,.0087 bpf,D=2.992" —{ 11722' 3 , 11722' H3-1/2"X 3-3/16"XO,D=2.786' ♦ i ♦ i • PERFORATION SUMARY •.4\ MLLOUT iM'DOW(18-33A) 11760'-11776' REF LOG: BH GR/ROP/PRESS ON 06/18/04 ��%�� ANGLE AT TOP PERF: 84'@ 12220' �` Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ 12165' —13-3/16 X 2-7/8"XO,D=2.387" 2" ' 6 12220- 12470 0 06/22/04 2" 6 12850- 13400 0 06/22/04 v11a11 4-1/2"LNR, 12.6#,L-80, .0152 bpf,D=3.958" H 13289' `vv'v'vy' 13410' —I PBTD 3-3/16"LNR,6.2#,L-80 TCI,.0076 bpi,D=2.80" --I 12165' .� `\, 2-7/8"LNR,6.5#,L-80 STL,.0058 bpf,D=2.441" H 13445' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/29/95 D-9 IMTIAL COMPLETION 01/14/14 PJC DRAWING CORRECTIONS WELL: 18-33A 06/22/04 KAK CTD SIDETRACK(18-33A) 01/26/14 PJC XN NP MILLED(06/13/04) PERMIT No: 2040700 08/26/06 GJF/PAG PULL&RESET WFD WRP 04/09/14 JAM PJC PULL WRP AR No: 50-029-22598-01 12/14/07 CJN/PJC M 'CORRECTION 04/14/14 AO/PJC SET WRP(04/12/14) SEC 24,T11N,R14E,3616.87'FEL&2210.43'Hs/ 03/26/11 BSE/PJC RILL&RESET WRP(03/14/11) 01/10/14 JCM PJC RIURESET WRP BP Exploration(Alaska) e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 '=f- - 0 70 Well History File Identifier Organizing (done) D Two-sided "' 11111111 ""1111 D Rescan Needed III 111/1111" 1/111I RESCAN ~Ior Items: D Greyscale Items: DIGITAL DATA ~skettes, No. t D Other, NofType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: Date 7/!;.JO t> D Other:: NOTES: BY: r MariD 151 V11P Project Proofing BY: C Maria~ 1111111111111111111 Date 7/J.lf/Ob I x30=~+ Date: b 151 ~f 51 f Scanning Preparation = TOTAL PAGES (Count does not include cover sheet) 151 BY: 111111111111111111I Production Scanning Stage 1 Page Count from Scanned File: (5 ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~YES BY ~ Date7!:J-.If/Ofp Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 1M ~f NO BY: Maria Date: 151 11111111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: 151 Comments about this file: Quality Checked III /11111111111111I 10/6/2005 Well History File Cover Page.doc • . ~.,- MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_Inserts\Microfilm_Marker.doc Sc~lIn~e,... RECEIVED NO. 3907 r C! ..... Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth AUG 1 0 2006 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 !\Jaska Oil & Gas Cons. Commission Anchorage ;J01.../- 07-0 Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD 02-16B 11209601 MEM 04125/06 1 16-21 11221558 II:MP 04/03/06 1 16-01 1105228 INJECTION PROFILE 07/21/05 1 16-01 10980601 INJECTION PROFILE 08/15/05 1 D.S 11-08 11223100 INJECTION PROFILE 02/27/06 1 D.S. 02-26C 11223117 LDL 05/16/06 1 09-09 11211484 PROD PROFILE W/DEFT 04/28/06 1 18-33A 11258719 LDL 06/08/06 1 X-07A 11217272 USIT 08/05/06 1 D-03A 11243918 SCMT 06/02/06 1 D-03A 11217271 USIT 08/04/06 1 Z-19 11217273 US IT 08/06/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 08/08/06 . . ?-. ~ J~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/5/2006 Permit to Drill 2040700 Well Name/No. PRUDHOE BAY UNIT 18-33A Operator BP EXPLORATION (ALASKA) INC S(1wá- IJ J_~..., API No. 50-029-22598-01-00 MD 13445./ TVD 8698 /' Completion Date 6/23/2004 / Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Su DATA INFORMATION Types Electric or Other Logs Run: GR / ROP / PRESS, Memory GR / CNL / eeL (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 11760 13445 Open 9/3/2004 MWD ~ Directional Survey 11760 13445 Open 9/3/2004 MWD .§9- C Lis 12841 Neutron 10615 13330 Case COMPENSATED NEUTRON LOG/MEMORY GRlCCUCNL J.og Neutron 2 Blu 10615 13330 Case COMPENSATED NEUTRON LOG/MEMORY GR/CCLlCNUDSN 12841 J!t5'9 Induction/Resistivity 25 Blu 11776 12903 Open 2/3/2005 multiple propagation resistivity/gr/pb 1 )tOg Induction/Resistivity 25 Blu 11776 12903 Open 2/3/2005 multiple propagation resistivity/gr/pb 1 . ¡.og Gamma Ray 25 Blu 11776 12903 Open 2/3/2005 GR PB 1 pt 13052 LIS Verification 11776 12903 Open 2/3/2005 multiple propagation resistivity/gr/ C Lis 13052 Induction/Resistivity 11776 13445 Open 2/3/2005 multiple propagation ~ resistivity/gr Induction/Resistivity 25 Blu 11776 13445 Open 2/3/2005 multiple propagation resistivity/gr ~Og Induction/Resistivity 25 Blu 11776 13445 Open 2/3/2005 multiple propagation resistivity/gr -c,g Gamma Ray 25 Blu 11776 13445 Open 2/3/2005 /gr I I DATA SUBMITTAL COMPLIANCE REPORT 7/5/2006 Permit to Drill 2040700 Operator BP EXPLORATION (ALASKA) INC Well Name/No. PRUDHOE BAY UNIT 18-33A MD 13445 Completion Date 6/23/2004 Current Status 1-01L TVD 8698 Completion Status 1-01L Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? ~ Daily History Received? ~/N lJ/N Chips Received? ¥ I "-I, Formation Tops Analysis Received? ~ API No. 50-029-22598-01-00 UIC N Comments: ~ Date: ç-J\r' ~.~ 1 Compliance Reviewed By: . . ,¡ . STATE OF ALASKA a ALA..... Oil AND GAS CONSERVATION COM~ION KI::t; I:. I v I::U JAN 2 6 2006 REPORT OF SUNDRY WELL OPERATI0ti§ska Oil & Gas Cons. Commission 1. Operations Abandon D Repair Well D Plug Perforations [2] Stimulate D Othe'AhQhorage Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver 0 Time Extension 0 Change Approved Program D Opera!. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development M Exploratory 0 204-0700 3. Address: P.O. Box 196612 Stratigraphic 0 Service 0 6. API Number: Anchorage, AK 99519-6612 50-029-22598-01-00 7. KB Elevation (ft): 9. Well Name and Number: 54 KB 18-33A 8. Property Designation: 10. Field/Pool(s): ADL-028321 Prudhoe Bay Field/ Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 13445 feet Plugs (measured) 10764 true vertical 8698.37 feet Junk (measured) None Effective Depth measured 13411 feet true vertical 8698.23 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 101.1# H-40 35 - 115 35 - 115 1650 650 Surface 4107 9-5/8" 40# L-80 34 - 4141 34 - 3586.05 5750 3090 Production 10928 7" 26# L-80 33 - 10961 33 - 8251.33 7240 5410 Liner 881 4-1/2" 12.6# L-80 10805 - 11686 8144.36 - 8666.52 8440 7500 Liner 36 3-1/2" 8.81# L-80 11686 - 11722 8666.52 - 8672.91 10160 10530 Liner 443 3-3/16" 6.2# L-80 11722 - 12165 8672.91 - 8690.13 Liner 1280 2-7/8" 6.5# L-80 12165 - 13445 8690.13 - 8698.37 10570 11160 Perforation depth: Measured depth: 12220 - 12470 12850 - 13400 Closed True Vertical depth: 8695.36 - 8695.1 8689.04 - 8697.72 Closed Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 31 - 10807 Packers and SSSV (type and measured depth) 4-1/2" Baker SABL-3 Packer 10749 4-1/2" Top Packer 10805 3-1/2" Baker KB Top Packer 11686 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft .IAN :3 JOn/ì Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure I Tubing pressure Prior to well operation: 611 33875 16 0 I 1712 Subsequent to operation: SHUT-IN 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory Development M Service 0 Daily Report of Well Operations X 16. Well Status after proposed work: Oil M Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: N/A Contact Sharmaine Vestal p"ted Name Sha:a',e vesta'. .. ~..J!l Title Data Mgmt Engr Slgnat~~........~ ~ Phone 564-4424 Date 1/24/2006 Form 10-404 Revised 04/2004 o \G\\\!AL Submit Original Only -. '. . 18-33A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYÐATE I ··$\IIIOi~"y 12/28/2005 ***WELL FLOWING ON ARRIVAL*** PULL SSSV SER. # QOS-13 FR. 2165' SLM DRIFTED W- 3.65 CENT. 3' 1 7/8 STEM. AND 3.80 GAUGE RING TO XN NIP. @ 10748'SLM. **** WELL LEFT SHUT IN AND TURNED OVER TO DSO *** 12/29/2005 T/I/0=2450/2260/0 Load & freeze protect TBG & IA for Pre E-Line job. Pumped 10 bbls methanol, 290 bbls 1 % KCL, 38 bbls crude down tubing while bleeding gas off IA to flowline. Continued to 12-30-05 12/30/2005 Continued from 12-29-05 T/1/0=2450/2260/0 Load & freeze protect well for pre E-Line job. Finish bleeding gas off IA down flowline. Pumped down IA 5 bbls methanol, 100 bbls crude, Rigged up to tbg to freeze protect flowline/Hot oil treatment on F/L, Pumped 5 bbls methanol spear, 100 bbls crude @ 180* as directed by DSO. FWHP's=0/140/120 12/31/2005 T/I/0=10NACNAC, Temp=SI. TBG FL (pre-WRP). TBG FL @ 642' (10 bbls). 12/31/2005 SET WFD WRP PLUG MID ELEMENT 10764', TOP 10761'. WELL SHUT IN FLUIDS PUMPED BBLS 1 I ::::L 1 . dò1-o7o . Transmittal Form r'__ BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Robin Deason Reference: 18-33A & 18-33APBl Contains the following for each well: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - GR/Directional Measured Depth Log 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log LAC Job#: 701576 Date: Jan 31, 2005 Date: ¥ Received B : au- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ¡=;~~;';;~~j, .[~,:,,[~~; '~~; ,_.~ ., ~-.: -! ~~~-,,-,~~..~~::--:--._~;.-! ..",;"""",~ : =.::----=..----~---~-- -~ ~ ...-..... -_...,;. -- :;;..--. ' :..,... ,:... '.;-;;-::-=:1 ~._~ ":;;.-;...,;~.;~1 :::-::. ~~ t'~ ~ ....;:.: .". ._.__nn,_,__n.._.__n..__U_+n.n ~}r-"-"- lL:,';:j ,~-~----~----- ~j~..- V;ì;;,;:~ . ¡.-_:"':_~~ +,,___ u___ . L....-~_-..'.--.~ 18-33A (PTD #2040700) Classified as Problem Well . . All, Well 18-33A (PTO #2040700) has been found to have sustained casing pressure on the inner annulus and has been classified as a Problem well. TIO pressures were 1700/1970/170 psi on 12/23/05 when the well failed a NFT-IA. The plan forward for this well is as follows: 1. SL: Secure with WRP (or equivalent plug) A wellbore schematic has been included for reference. Please call if you have any questions. «18-33A.pdf» Rob Mielke Well Integrity Engineer, BP Exploration, (Alaska) Inc. Office: 1-907-659-5102 Pager: 1-907-659-5100 #1154 robert.mielke@bp.com Content-Description: 18-33A.pdf Content-Type: application/octet-stream Content-Encoding: base64 SA 71{ Lßo 26 ¢- I JJtR{ P ~ 7 zt1opS: " Scp== /Cj'7D pC:; -> '17. z % of J.J:f<1 f ~ F 0041 '2- K~1 \ZIZ7/0S- ) 1 of I 12/27/20059:31 AM 18-33A (PTD# 2040700) Classified as Problem Well All, Well 18-33A (PTD # 2040700) has sustained pressure on the lA and has been classified as a Problem Well. The well failed a TlFL on 01/18/04 with the TlO's 1750/2030/320. Currently the well is flowing to keep the lAP from increasing to SlTP of 2470 psi. Current plans are to: 1. SL: C/O OGLV in sta#2 2. DHD: Re-TlFL Attached is the wellbore schematic. Please call if you have any questions. «18-33A.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer (0) 907-659-5525 (p) 907-659-5100 #1923 Content-Description: 18-33A.pdf Content- Type: application/octet-stream Content-Encoding: base64 i>re$SIJ,,~ M3yf 4~ J.£fy? N ò4-é' s - 'T(;tb¡ ~1 115Vrs~ ~ - 2I(1Dpc>: I XA- 'Z û30fs; 72J¡OpeJ' 3"2;;:6{5: Ô~ OA- 3'20 f>S; 5750 ~"JBß f;J: ûV- . 1 of 1 1/24/2005 9:54 AM TREE = WELLHEAD= FIIIC 18-33A SAFETY NOTES: GLMS HAVE LOWER PSI RATE ACTUA. TOR = BA KER C THAN NORMAL CHECKWITHWIE. KB. ELEV = 54.0' BF. ELEV = KOP= 1053' fv1ax Angle = 100 @ 12479' D3tum M) = 7869' . 2199' 4-1/2" HES HRQ SVLN SSSV NIP, ID - 3.812" D3tum1VD - 8800'SS I 9-5/8" CSG, 40#, L-80,ID = 8.835" 4141' ~ .. GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LA TCH PORT DATE Minimum ID = 2.372" @ 11686' I L 1 4283 3679 49 KBMG-2-LS-WOD DOrÆ INT 16 06/29/04 BKR KB LNR TOP PKR 2 8027 6223 46 KBMG-2-LS-WOD SO INT 20 06/29/04 3 10683 8055 42 KBMG-2-LS-WOD DMY INT 0 06129/04 NOTE: PROBlBIII MAN:>RELS; REQUIRE SPECIAL VALVES ~ ¡.c 10749' 7" x 4-1/2" ßA.KER S PKR, ID = 3.937" J . 10783' 1-1 4-1/2"HESXNNIP,D=3.725" 1 . 1 TOP OF 4-112" LNR 1 10805' II!!! 4-112" TBG. 12.6#, L-80, .0152 bpf. ID = 3.958" 10807 r 7 10807' H 4-1/2" TUBING TA IL WLEG, ID = 3.958" 1 1 H ELMD TT NOT LOGGED 1 I 7" CSG, 26#, L-80, ID = 6.276" I 10961' µ It.. 1 TOP OF CEM~T I l5< I 11686' 3.7' BKR KB LNR TOP A<R, ID = 2.372" I 11691 ' -, 11692' 3.7" BKRDEPLOYrÆNT SLV,ID =3.0" I I 11711' H 3-1/2" HES X NIP, ID = 2.812" I I 13-1/2" LNR, 8.81#, L-80, .0087 bpf, D =2.990" I 11722' I 11722' 3-112" x 3-3/16" XO, ID = 2.786" I I I I I PERFORA 110 N SLMMlI. RY MLLOUTWINDOW 11760'- 11776' RB= LOG: BHI GR / ROP / ffiESS ON 06/18/04 h~ ANGLEATTOPPERF: 91 @ 12220' Note: ReIer to A"oduction DB lor historical perl data I 12165' H 3-3/16X 2-7/8" XO I SIZE SA" NTERVAL Opn/Sqz DATE 2" 6 12220 - 12470 0 06/22/04 2" 6 12850 - 13400 0 06/22/04 I 13411' H PBTD I 4-112" LNR,12.6#, L-80, .0152 bpf, ID- 3.958" 13289' 13-3/16" LNR, 6.2#, L-80, .0076 bpI, ID= 2.80" I 12165' I 12-7/8" LNR, 6.5#, L-80, .0058 bpI. ID=2.441" I 13445' ()6. TE REV BY COMrÆNTS DATE REV BY COMrÆNTS PRUDI-OE BAY UNIT 10/29/95 ORIGINAL COMPLETION WELL: 18-33A 06122/04 KAK CTD SlDETRACK(18-33A) PERMIT No: 2040700 06129/04 PWElKA ~ GLV ao API No: 50-029-22598-01 SEC24, T11 N. R14E, 3616.87' FEL & 2210.43' FNL BP Exploration (Alaska) 10/21/04 Schlumbergel' NO. 3238 ~BLf- D7 Ó Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay e Color ffl- 1 c¡/.... ~ f67-- I !J1 ZI:ß-- IfA Well Job# Log Description Date Blueline Prints CD [¿ DS 15-13A 10913854 SCMT 10/04/08 1 't¡1 E-20 10866600 USIT 10/01/04 1 1t8·33A 10861918 MCNL 06/21/04 1 1 ..( 'PSI-05 10830793 RST-SIGMA 04125104 1 1 < L2-32 10687661 RST-SIGMA 01102104 1 1 L2-32 10672377 RST-SIGMA 04/28/04 1 1 L2-32 10912982 RST-SIGMA 09/06/04 1 1 L2-32 10687650 RST-SIGMA 09/22/03 1 1 '\ W-400 40009731 OH EDIT MWD DATA 10/21-26/03 2 1 W-400 10621738 OH EDIT AIT/BHC/PEX/6 ARM CALIPER 10/28/03 6 1 JIV-400 10621779 US IT 05/05/04 1 . .- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /pdz;b-¡ I Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 ^:;''':,"~c! / r Receive : . ~ · STATE OF ALASKA . ALASKA-e'lL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: IBI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 IBI Development o Exploratory OGINJ OWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/23/2004 204-070 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 6/13/2004 50- 029-22598-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 6/18/2004 PBU 18-33A 3690' NSL, 56' WEL, SEC. 24, T11 N, R14E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 3155' NSL, 4852' EWL, SEC. 18, T11N, R15E, UM 54' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 2772' NSL, 4043' EWL, SEC. 18, T11N, R15E, UM 13410 + 8698 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 691721 y- 5960277 Zone- ASP4 13445 + 8698 Ft ADL 028321 TPI: x- 696505 y- 5965147 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 695707 y- 5964743 Zone- ASP4 (Nipple) 2199' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost IBI Yes ONo N/A MSL 1900' (Approx.) 21. Logs Run: GR / ROP / PRESS, Memory GR / CNL / CCL 22. CASING, LINER AND CEMENTING RECORD ·rg~i~$ ....... '>i SETTING OEI'fI'MMD SETTNG.pe~H'MJ -~~f:" » . .i'i~è6.. WT. .Pr;RF'T. GRAbE Top BOTr"OM Top I BOTr"OM ii .>¡ 20" 91.5# H-40 Surface 110' Surface 110' 30" 260 sx Arctic Set lADDroxT 9-5/8" 40# L-80 34' 4141' 34' 3586' 12-1/4" 1023 sx Permafrost 'E', 588 sx 'G' 7" 26# L-80 35' 10961' 35' 8251' 8-1/2" 180 sx Class 'G' 4-1/2" 12.6# L-80 10805' 11760' 8144' 8679' 6" 270 sx Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 8.81# /6.2# /6.5# L-80 11686' 13445' 8667' 8698' 3-314" x 4-118" 92 sx Class 'G' 23. Perforations oRen to Production (MD + TVD of Top and 24, > ,.i TUBING .··i,.¡,,'" >i >, Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter 6 spf 4-1/2", 12.6#, L-80 10807' 10749' MD TVD MD TVD 12220' - 12470' 8695' - 8695' 125. ~p'I:)' r-l:<ðq:[IJ~I:, I,.;E~r;t-J r:T...."> 12850' - 13400' 8689' - 8698' '.J~: DEPTHINTERVAllMD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protected with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): July 3, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-MCF WATER-Bsl CHOKE SIZE .\ GAS-Oil RATIO 6/8/2004 12.1 TEST PERIOD .. 482 19,974 -0- 60.53 41 ,433 Flow Tubing Casing Pressure CALCULATED .. Oll-Bsl GAs-McF WATER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 956 39,617 -0- 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ; .'~'~.~,;::~~ None ¡ "JiÚLtTlON k:i ~T~~ OR\G\NAL .~3 . RBDMS Bfl JJl22 ,nOt j --4'~ ~ ~,,")" ..-.-- -- Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE Gti/ 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Zone 1 (From Parent Well 18-33) 11526' 8611' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble PBU 18-33A Well Number Title Technical Assistant Date Ot¡~;Z {-o 204-070 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Dan Kara, 564-5667 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-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. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 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). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-33 18-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/9/2004 6/23/2004 N2 Spud Date: 10/4/1995 End: 6/23/2004 6/12/2004 06:00 - 07:00 1.00 MOB P PRE Rig released from L2-14b at 0600 hrs Crew change/final preps to move. PJSM 07:00 - 07:50 0.83 MOB P PRE Move from L2 Pad to DS 18 while set Nordic rig mats 07:50 - 09: 10 1.33 MOB P PRE PJSM. Line up rig and move onto mats close to tree. Determine middle stair landing on ODS won't clear top of well house (18-34). Back rig off mats and set down 09:10- 10:50 1.67 MOB N HMAN PRE Arrange for VECO tractor to move trailer w/ GBR mats from L2-14 to DS 18. Set mats 10:50 - 13:00 2.17 MOB N PRE PJSM. Move rig onto 2nd set of mats and move close to tree. Stair below ODS middle landing won't clear well house when rig is set down. Remove lower stairs and chain off middle landing exit. Welder added kick plate and railing later. Shim DS rear to get clearance above 18-31 well house. Set rig down 13:00 - 15:45 2.75 BOPSU PRE Accept rig at 1300 hrs 6/12/2004 ND tree cap. NU BOPE 15:45 - 16:00 0.25 BOPSU PRE Safety mtg re: BOPE test 16:00 - 22:00 6.00 BOPSU PRE Initial BOPE test. Witness waived by AOGCC. Same time PU injector. Pressure and Meg test BHi connector. 22:00 - 22:15 0.25 STWHIP P WEXIT Check well for pressure. On vacuum. 22: 15 - 23:20 1.08 STWHIP P WEXIT P/U BHA #1 Weatherford WS-R-BB packer and BHi e-line tools. (63.22') Open EDC and confirm. 23:20 - 00:00 0.67 STWHIP P WEXIT RIH 6/13/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT RIH to 11100'. 01 :30 - 01 :50 0.33 STWHIP P WEXIT Log Gr tie-in -6' correction. 01 :50 - 02:05 0.25 STWHIP P WEXIT RIH logging CCL pick-up collars at 11702,11743,11784'. 02:05 - 02:25 0.33 STWHIP P WEXIT PUH to 11700'. (45.3k) RIH to 11776'. Orient packer lug to 42R. Close EDC bring on pump, ramp pressure up to 4200 psi observe sheer. Setdown 10k confirm set. TOH 02:25 - 04:10 1.75 STWHIP P WEXIT TOH paint flag at 11400' EOP 04:10 - 05:30 1.33 STWHIP P WEXIT UD Fury setting tool. Install 3 pip tags in WE whipstock. P/U whipstock BHA. Whipstock set for 45R highside exit. 05:30 - 07:25 1.92 STWHIP P WEXIT RIH with WE whipstock 07:25 - 07:40 0.25 STWHIP P WEXIT Corr -12.6' to flag. RIH. 11700' 45.3k, 38k, 18.2k 0.5/230 PVT 288 07:40 - 08:10 0.50 STWHIP P WEXIT SD pump. Start losing wt at 11767' and stack 17k. PUH 53k to verify latched. RBIH and stack 17k. PUH 52k 40' and free-seems too easy. RBIH and stack 5k at 11767'. PUH wI 52k and must not be latched up. RIH faster at 30'/min and stack 17k. PUH w/5k over and RBIH and stack 10k. PUH 60k and looks better this time. Let jars go off and back to 39k neutral. RBIH and set 10k. PUH to 60k and lost wt quickly. PUH 100' at 46k. RBIH and stack 20k. PUH to 56k and wo jars and wt back to 36k. PUH and still have 5k extra. Stack 17k, get string wt back and cycle this way 3 times. PUH 59k and wo jars, okay and still had 52k, good. RBIH and cock jars. PUH 55k and wo jars and had 52k, real good. Cock jars. PUH 61 k and wo jars and wt fell back to 38k (assumed we left it this time), but PUH 5k over. Retag and stack 5k. PUH 60k and wt fell off quick to 48k, PUH w/ 5k over. Chk wt 11700' 48k at 0.5/230 08:10 - 10:30 2.33 STWHIP P WEXIT POH to see if WS was left in hole 10:30 - 11 :15 0.75 STWHIP P WEXIT WS was gone, no marks on running tool and swivel moves freely. MU motor and mill assy Printed: 6/29/2004 10: 17:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-33 1 8-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/9/2004 6/23/2004 N2 Spud Date: 10/4/1995 End: 6/23/2004 6/13/2004 11: 15 - 13: 1 0 1.92 STWHIP P WEXIT RIH w/ BHA #3 (3.80" window mill, 3.80" SR) 13:10 - 13:25 0.25 STWHIP P WEXIT 11750' 42k, 15k 0.3/230 Tag XN at 10790' CTD-did not carr. Start motor 2.65/2080. Tag at 10788.9' 13:25 - 14:10 0.75 STWHIP P WEXIT Mill XN 2.7/2.7/2050 w/ two stalls 14:10 - 15:00 0.83 STWHIP P WEXIT RIH to flag 1.0/600 and corr -18.9'. RIH 0.4/240 to tag at 11747'. Muse, muse. Start motor and ease in hole 2.7/2140 and first motor work at 11745.5', go to 11745.7' and got 50 psi ditto Paint flag here and corr to 11760' Total corr is -4.6' which is close to GR tie-in earlier of -6' 15:00 - 17:30 2.50 STWHIP P WEXIT Mill window 2.7/2140 from 11760' w/ 0-100 psi ditt, starting w/ 16.3k hanging wt ECD 9.0 17:30 - 20:20 2.83 STWHIP P WEXIT 11762.0' 2.7/2150 w/200 psi ditt, 2.2k wob 20:20 - 20:45 0.42 STWHIP P WEXIT 11764.0' 2.7/2.7 2130fs 2-300psi mw 2-3k wob Mill to 11764.5' start to drill formation. Start swap to Flo-Pro mud. 20:45 - 22:20 1.58 STWHIP P WEXIT Drill formation f/11764.5' to 11776'. 22:20 - 23:10 0.83 STWHIP P WEXIT Dress window area. Pass thru window wo pump, looks good. Samples: sand 23: 10 - 00:00 0.83 STWHIP P WEXIT TOH 6/14/2004 00:00 - 00:50 0.83 STWHIP P WEXIT Continue TOH with window milling BHA. 00:50 - 01 :30 0.67 STWHIP P WEXIT UD mill BHA. Both window mill and string reamer 3.80" go 3.79" no-go. P/U drilling build BHA. 01 :30 - 03:30 2.00 DRILL P PROD1 RIHt011120'. 03:30 - 03:40 0.17 DRILL P PROD1 Log Gr tie-in. -4' correction 03:40 - 03:52 0.20 DRILL P PROD1 RIH thru window no problem tag bottom at 11776' 03:52 - 06:00 2.13 DRILL P PROD1 Wash to bottom f/ 11770' 2.6/2.6 3640psi free-spin. Drill ahead f/11776' 100-200psi mw 2-3k wob 25'/hr 06:00 - 07:30 1.50 DRILL P PROD1 Drill from 11834' 2.6/3440/1 OOR w/ 200-400 psi diff, 2-4k wob at 87 deg and putting most into turn, ECD 10.4, PVT 256 07:30 - 07:45 0.25 DRILL P PROD1 Stacking. Wiper to window 07:45 - 10:25 2.67 DRILL P PROD1 Drill from 11891' 2.6/3450 Showing good sand on GR, but stacking bad. Make slow hole with frequent pickups and 50' wipers while wo fresh mud 10:25 - 10:45 0.33 DRILL P PROD1 Wiper to window 10:45-12:15 1.50 DRILL P PROD1 Drill from 12000' 2.6/3450/135R maintaining 87 deg and continuing turn at <40'/hr 12:15 - 12:25 0.17 DRILL P PROD1 100' wiper w/ new mud at bit 2.6/3200 12:25 - 13:40 1.25 DRILL P PROD1 Drill from 12054' 2.6/3200/11 OR w/ 400 psi ditt, 4k wob at 80'/hr and better sliding. By the time new mud was back to surface were at 1 OO'/hr and smooth sliding and few pickups 2.6/3000 13:40-14:10 0.50 DRILL P PROD1 Wiper to window 14:10 - 14:30 0.33 DRILL P PROD1 Drill from 12150' 2.6/3000/11 OR w/ 400 psi ditt, 4k wob at 87 deg and finished build/turn at 12182' 14:30 - 14:50 0.33 DRILL P PROD1 Wiper to window 14:50 - 16:25 1.58 DRILL P PROD1 POOH for lateral assy 16:25 - 17:50 1.42 DRILL P PROD1 Change bit (1-1-1), add resistivity, adj motor 17:50 - 19:45 1.92 DRILL P PROD1 RIH w/ BHA #5 (DS49, 1.5 deg) to 11685' 19:45 - 22:00 2.25 DRILL P PROD1 Log tie-in from 11685' - 11776' then MAD pass to TD. -6' correction. 22:00 - 23:00 1.00 DRILL P PROD1 Directionally drill ahead f/12182' to 12323'. 2.6/2.6 3100psi FS 4-500psi MW 2-3k WOB 23:00 - 23:35 0.58 DRILL P PROD1 Wiper trip to window area. 23:35 - 00:00 0.42 DRILL P PROD1 Directionally drill ahead f/ 12323' to 12370' 2.6/2.6 10.17ppg ECD 3150psi FS 4-500psi MW 2-3k WOB Printed: 6/29/2004 10: 17:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-33 18-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/9/2004 Rig Release: 6/23/2004 Rig Number: N2 Spud Date: 10/4/1995 End: 6/23/2004 6/15/2004 00:00 - 00:50 0.83 DRILL P PROD1 Continue directionally drilling ahead f/12370' to 12490' 2.6/2.68.67/8.72 3125psi free-spin 3-500psi motorwork 00:50 - 01 :30 0.67 DRILL P PROD1 Wiper trip to window. 01 :30 - 02:35 1.08 DRILL P PROD1 Directionally drilling ahead f/12490' to 12614' 2.6/2.6 8.67/8.72 3050psi free-spin 3-500psi motorwork 2-4k wob 02:35 - 03:20 0.75 DRILL P PROD1 Wiper trip to 11780' 03:20 - 06:25 3.08 DRILL P PROD1 Directionally drilling ahead f/12614' 2.6/2.68.67/8.72 3120psi free-spin 3-500psi motorwork 2-4k wob. Starting to have some stacking problems at 12650' (shale). Frequent small wipers. Work thru and drilling good by 12665'. Pump 25bbl high-vis pill seen slight increase in cuttings. Looks like we're cleaning the hole fairly good. Drill to 12766' 06:25 - 06:55 0.50 DRILL P PROD1 Wiper to window 06:55 - 07:05 0.17 DRILL P PROD1 Log tie-in to RA marker, add 6.0' 07:05 - 07:35 0.50 DRILL P PROD1 Wiper to TD 2.5/3200 ECD 10.3 Had MW and set down at 12687', but reamed thru clean after PU 07:35 - 08:15 0.67 DRILL P PROD1 Drill from 12766' 2.53/3200/90R wI 100-400 psi ditt, 2-4k wob, ECD 10.35. Drill to 12801' and project we have gained 7' TVD at bit and still digging like shale-may have cut an unmapped fault 08:15 - 08:30 0.25 DRILL P PROD1 150' wiper to test the waters 2.5/3100. Clean PUH at 41.3k, MWat 12698' on RIH 08:30 - 10:20 1.83 DRILL P PROD1 Drill from 12801' 2.5/3100/1 OR with stacking, but clean pick ups while drilling up and out of shale. ROP improved by 12840', but had diff sticking overpulls then while drilling w/ neg wt. Drill to 12903' wI 98 deg at bit and stall 10:20 - 10:55 0.58 DRILL P PROD1 Wiper to window while discuss-will weight up 0.5 ppg. 5k overpulls at 12740' and 12674', but otherwise clean 10:55 - 11 :30 0.58 DRILL P PROD1 Wiper to TD and was clean to 12880' and had MW. Tag at 12890' (13' high) and overpull10-15k with no forward progress 4 times 11 :30 - 12:30 1.00 DRILL N DPRB PROD1 Wiper while discuss. Tie-in to pip tags. +3' correction. PUH thru window with reduced pump rate pulled tight and became stuck trapping 2000psi below bit. Quickly RIH and bacame free. RIH and opened EDC. 12:30-15:15 2.75 DRILL N DPRB PROD1 TOH pumping 3.3bpm thru open EDC to 600' RI H to 1100' pumping at 3.3bpm, large amounts of pea gravel size shale coming over shaker. TOH to 500' RIH close EDC TOH at 3bpm 15:15 - 15:35 0.33 DRILL N DPRB PROD1 UD BHA #5. 15:35 - 17:20 1.75 DRILL C PROD1 Wait on Weatherford OHWS 17:20 - 17:45 0.42 DRILL C PROD1 PIU We OHWS. 17:45 - 17:35 23.83 DRILL C PROD1 RIH with BHA #6. WF OH AL billet whipstock and setting tool on BHI coiltrack BHA. 17:35 - 21 :25 3.83 DRILL X HMAN PROD1 WF has the incorrect BHA in the hole. There is a diverter sub in the BHA that needs to be activated with a ball. This is the correct BHA for conventional coil, but not for E-coil. The WF hands changed out in the middle of the job, and problem was caught by new hand. Need to POOH to remove the diverter sub from the BHA. 21 :25 - 22:00 0.58 DRILL X HMAN PROD1 Tag up at surface, stand back injector. Remove diverter sub from BHA. Make up BHA #7. 22:00 - 23:30 1.50 DRILL C PROD1 RIH with BHA #7. AL OH whipstock. 23:30 - 23:45 0.25 DRILL C PROD1 Continue RIH to set whipstock. Printed: 6/29/2004 10: 17:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-33 18-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/9/2004 Rig Release: 6/23/2004 Rig Number: N2 Spud Date: 10/4/1995 End: 6/23/2004 6/15/2004 23:45 - 00:00 0.25 DRILL C PROD1 Log tie in pass over RA tag. Make -10' correction. 6/16/2004 00:00 - 00:20 0.33 DRILL C PROD1 Continue RIH. IAP=465 psi, OAP=10 psi. 00:20 - 00:30 0.17 DRILL C PROD1 Check up weight at 12400'=42klbs. Position whipstock anchor at 12415', top at 12400'. Close EDC, and pressure up 4000 psi to set WS. Good indication of set. Stack 10 klbs on WS, confirmed set. 00:30 - 02:30 2.00 DRILL C PROD1 Initial PU 44 klbs, then cleaned up to 39 klbs. Open EDC, POOH circulating to clean hole. 02:30 - 02:50 0.33 DRILL C PROD1 Tag up at surface, lay down OH WS setting BHA. Confirmed WS left in hole. Setting tool functioned properly. 02:50 - 03: 10 0.33 DRILL C PROD1 Safety meeting prior to jacking rig to add timbers to adjust rig for settling, and to provide clearance to adjacent wellhouses. 03: 10 - 03:40 0.50 DRILL P PROD1 Jack rig up 3", and install timbers under rear foot. Readjust BOP stack alignment at rig floor. 03:40 - 04:05 0.42 DRILL C PROD1 PU BHA #8 to sidetrack off of whipstock. MU 2.0 deg motor, and HTX R335C bit. 04:05 - 06:00 1.92 DRILL C PROD1 RIH with BHA #8 to sidetrack off of whipstock. 06:00 - 06:10 0.17 DRILL C PROD1 Log tie-in at pip tag -10' correction. 06:10 - 06:50 0.67 DRILL C PROD1 RIH to top of OHWS 06:50 - 09:20 2.50 DRILL C PROD1 Drill off aluminum billtet OHWS 45rTF f 12400' to 12410' slowly apply wob. Continue drilling ahead following new directional plan. Drilled to 12483' lost MW stacked out. PU pulled tight and appears we are differentually stuck. 09:20 - 10:05 0.75 DRILL X STUC PROD1 Continue pumping at 2.6bpm to clear cuttings from hole. Call for crude oil tanker. Try orienting from 80r to HS and back again no help with 3k over pull. After 20 min shutdown pump relax coil wt. Wait 20 min pull to 77k and came free. PUH into casing. Start swap to new mud. 10:05 - 11 :10 1.08 DRILL C PROD1 PUH to 11600' open EDC swapping mud to surface. (planned event) 11 : 1 0 - 11 :50 0.67 DRILL C PROD1 RIH bottom.to 11 :50 - 12:45 0.92 DRILL C PROD1 Continue drilling sidetrack f/12483' 2.5/2.5 2850 fs 2-300psi mw 10.04ppg ECD 2-3k wob 100'/hr. Drill to 12593'. 12:45 - 14:05 1.33 DRILL C PROD1 Wiper trip 14:05 - 15:20 1.25 DRILL C PROD1 Continue drilling sidetrack f/12593' to 12704' 2.5/2.5 2900psi fs 3-500psi mw 3-4kwob started drilling shale at 12620' and may have landed (90 deg) in it at 12650'. 15:20 - 17:15 1.92 DRILL C PROD1 Wiper trip. Town eng's making decision on plan forward. Tie-in +12' correction. RIH 17:15 - 18:30 1.25 DRILL C PROD1 Orient down and gradually drop to 8640' tvd. 2.5/2.5 2900 fs 3500psi mw 2-4k wob. 18:30 - 20:30 2.00 DRILL C PROD1 Sidetrack is landed as per geo. POOH to adjust motor for lateral section, and change bits. Pit vol=350 bbls. IAP=580 psi, OAP=13 psi. Clean PU off bottom and thru OH whipstock. Pump at full rate OOH. The micro motion plugged off at 2800' while POOH. It was full of shale cuttings. Still getting lots of shale debris back. 20:30 - 22:00 1.50 DRILL C PROD1 Tag up at surface with sidetracking BHA. Yo-Yo pipe to clean hole. Hold PJSM to discuss BHA swap. Stand back injector and lay down sidetrack BHA. PU DS49 bit, 1.2 deg lateral motor, RES tool, remainder of Coiltrack BHA. Printed: 6/29/2004 10: 17:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-33 1 8-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/9/2004 6/23/2004 N2 Spud Date: 10/4/1995 End: 6/23/2004 6/16/2004 22:00 - 00:00 2.00 DRILL C PROD1 RIH with BHA #9 to continue drilling lateral section of hole. 6/17/2004 00:00 - 00:15 0.25 DRILL C PROD1 Log tie in pass down over RA tag. Make -8' correction. 00:15 - 00:35 0.33 DRILL C PROD1 Continue RIH to resume drilling. 00:35 - 00:40 0.08 DRILL C PROD1 Set down several times at 12480'. Make 1 slow backreaming pass to wipe out any possible ledges. Most likely shoving debris or mud ball ahead of us. 00:40 - 01 :00 0.33 DRILL C PROD1 Continue RIH easily until 12769'. 01 :00 - 01 :05 0.08 DRILL C PROD1 Motor work the last 100' to bottom. Looked like we were shoving something ahead of us. 01 :05 - 01 :30 0.42 DRILL C PROD1 Free spin 2930 psi at 2.6 bpm. Pit vol=342 bbls. Drilling ahead at 2.55/2.57/3370 psi. ROP=150 fph. IAP=515 psi, OAP=6 psi. 01 :30 - 01 :35 0.08 DRILL P PROD1 Continue drilling ahead. 01 :35 - 01 :50 0.25 DRILL N STUC PROD1 Motor work dropping off while we stacked weight. Looks like differential sticking. Try to PU, and are stuck. Pull 70 klbs, with no luck. Circulate for 15 minutes to lift cuttings up hole. Pumping 2.5/2.5/2850 psi. Pull to 80 klbs 2 times, and it popped free. 01 :50 - 02:00 0.17 DRILL P PROD1 Make 200' wiper prior to resuming drilling. 02:00 - 02:45 0.75 DRILL P PROD1 Drill ahead. 02:45 - 03:50 1.08 DRILL P PROD1 Wiper trip to shoe. Ratty up to 12800'. Smooth above here, and back to TD. 03:50 - 05:25 1.58 DRILL P PROD1 Resume drilling. IAP=570, OAP=12 psi. Drilling at 2.6/2.6/3250 psi. Pit vol=340 bbls. 05:25 - 06:20 0.92 DRILL N STUC PROD1 Making short wiper trip, pulling up at 30 fpm, got differentially stuck at 13010'. Pull 2x to 70 klbs, and can't move. Position at neutral weight, and pump for 20 minutes to clean up hole. Try pulling again - nope. SD pump for 20min pull and came free. 06:20 - 09:35 3.25 DRILL N PROD1 Wiper trip into 4.5" (make-up 40bbls hi-vis pill, take on water from cellar) open EDC pump 2 sweeps between 100 bbls mud 5/20bbl water/mud. Seen some pea gravel shale and postage stamp size pipe scale. RIH to bottom got to 12290' and lost comms to BHi tools. Tools drawing high current meaning they are shorting out. Need to POH from here. 09:35 - 12:30 2.92 DRILL N PROD1 TOH to 400' RIH to 1000' unload some shale and scale not as much as before. 12:30 - 14:30 2.00 DRILL N PROD1 LID BHA #9. P/U BHA #10 with the Agitator 14:30 - 16:30 2.00 DRILL N PROD1 RIHwithBHA#10 (91.74')to11800'. RIHwithEDCopen. 16:30 - 16:50 0.33 DRILL N PROD1 Log tie-in -1' 16:50 - 17:00 0.17 DRILL N PROD1 RIH, Close EDC. Kick on pumps. Free spin 2.2 BPM at 4700 psi, and fluctuating. This is too high of a pressure! On previous runs, the free spin w/o the Agitator was 2950 psi @ 2.6 bpm. Previous experiance on Nordic 1 shows a 600-800 psi pressure gain with the Agitator in the BHA, with constant pressures. These pressures are fluctuating, and much higher than expected. The Agitator may not be working properly, or there may be some plugging off somewhere in the BHA. 17:00 - 17:50 0.83 DRILL N PROD1 RIH and attempt to drill with a suspect BHA. 17:50 - 18:05 0.25 DRILL N PROD1 Begin drilling. Free spin fluctuating from 3950 to 4450 psi at 2.0 bpm. Something is not working properly. Tag bottom. Begin drilling. Drill 6', and the BHI tool failed. There is a dead short in the coiltrack BHA. 18:05 - 20:15 2.17 DRILL N DFAL PROD1 PU off bottom. Discuss situation. There may be 2 problems. 1 Printed: 6/29/2004 10:17:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-33 1 8-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/9/2004 6/23/2004 N2 Spud Date: 10/4/1995 End: 6/23/2004 6/17/2004 18:05 - 20:15 2.17 DRILL N DFAL PROD1 - Plugging in BHA, and 2 - an electrical problem with BHI eq. POOH to sort out problems. 20:15 - 21:00 0.75 DRILL N DFAL PROD1 New mud around. Getting some dark brown, old mud, polimer balls (1/8" dia) back. May be leftover from old mud and high vis sweeps pumped earlier in the day. 21 :00 - 21 :15 0.25 DRILL N DFAL PROD1 Shallow hole check at 1000'. Pumping 2.1 bpm, 3780 psi. There was good indication of the Agitator working. Good vibration on the pipe. Pump pressures are still higher than expected. Continue POOH. 21:15 - 23:40 2.42 DRILL N DFAL PROD1 Tag up at surface. Stand back injector. Lay down BHA #10. Trouble shoot BHA. Found electrical short in lower quick connect. Check out remainder of BHA. Tests ok. Consult with town and discuss the plan forward. Layout Agitator tool. Make up new components to replace damaged ones. Check bit. Looks good. Check motor, nice and tight. MU BHA. Stab on injector. 23:40 - 00:00 0.33 DRILL N DFAL PROD1 RIH with BHA #11; DS49 bit, 1.2 deg motor, RES, BHI Coiltrack BHA. Stop at 500', and shallow hole test BHA with EDC closed. Free spin pressures are 3070 psi at 2.1 bpm, and 3820 psi at 2.6 bpm. This is considerably higher than our free spin pressure of 2950 psi at 2.6 bpm yesterday. Check pressure with EDC open. Found it to be 3260 psi at 2.6 bpm. POOH to examine BHA. Something is partially plugged. Suspect check valves. 6/18/2004 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 Tag up at surface. Break quick connect, examine check valves. Found 1 broken and 1 damaged check valve. The flapper axle is broken and the flapper from the check valve was laying down in the bottom of the valve body obstructing the flow path. This was in most likelyhood the source of our abnormal and fluctuating pressures. Replace the damaged check valves. MU to BHA. MU injector. 01:00 - 03:10 2.17 DRILL N DFAL PROD1 RIH. Shallow hole test with EDC closed. Free spin pressure is 2900 psi at 2.6 bpm. This is identical to what was observed yesterday during normal drilling operations. Continue RIH. 03: 10 - 03:20 0.17 DRILL N DFAL PROD1 Log tie in pass over RA tag. Make -10' correction. 03:20 - 04:15 0.92 DRILL N DFAL PROD1 Continue RIH to begin drilling. Current mud has 4% lubtex. Adding 1.5% flolube as we RIH. 04:15 - 06:20 2.08 DRILL P PROD1 Resume drilling. Free spin=3060 psi at 2.6 bpm. Drilling at 2.55/2.55/3300 psi. ROP=100 fph. String weight=8700 Ibs. Good weight transfer with new mud and lubricants. Pit vol=359 bbls. IAP=533 psi, OAP=6 psi. Drilled to 13219'. 06:20 - 07:50 1.50 DRILL P PROD1 Wiper trip tight spot at 13080'. MW going in at 12500 thru 12900'. 07:50 - 09:30 1.67 DRILL P PROD1 Continue drilling ahead f/13219'. Fight getting to bottom and start drilling. Frequent stacking. 2.5/2.5 3060psi free-spin 3-400psi mw. Drill to 13305'. 09:30 - 10:35 1.08 DRILL P PROD1 Wiper trip 10:35 - 11 :00 0.42 DRILL P PROD1 Drill f/13305' to 13359' then stack out. 11:00 -11:10 0.17 DRILL P PROD1 200' wiper trip 11:10 -11:20 0.17 DRILL P PROD1 Drill f/13359' to 13367' again stacking out. Clean pu's. 11 :20 - 11 :30 0.17 DRILL P PROD1 Wiper trip 300'. 11 :30 - 11 :40 0.17 DRILL P PROD1 Drill f/13367' to 13881 '. 11 :40 - 12:50 1.17 DRILL P PROD1 Wiper trip back to 10500' Opened EDC above window and Printed: 6/29/2004 10: 17:05 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-33 1 8-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/9/2004 6/23/2004 N2 Spud Date: 10/4/1995 End: 6/23/2004 6/18/2004 11 :40 - 12:50 1.17 DRILL P PROD1 pumped 4.1 bpm 12:50 - 13:00 0.17 DRILL P PROD1 Log tie-in at pip tags + 11' correction. 13:00 - 13:30 0.50 DRILL P PROD1 RIH back to bottom clean. 13:30 - 14:00 0.50 DRILL P PROD1 Drill ahead f/13381' back into good sands. 2.5/2.5 3100psi FS 3-400psi MW 2-3k wob 150'/hr. Drilled to 13444' P/U 51 k try couple times to get back drilling. Differentually stuck 110' off bottom 14:00-18:15 4.25 DRILL N STUC PROD1 Circulate 20 min call for crude tanker. Shutdown wait 20m in pick-up still stuck, wait another 20min..nope. Circulate/relax coil. Retry pulling to 90k. Wait for 45 min and try again to 90k. Circulate and wait for crude. 18:15 - 19:05 0.83 DRILL N STUC PROD1 Check vapor pressure of crude=1.0 psi. Less than 1.5 psi maximum. OK to pump crude. On line with crude. Pump 20 bbls of crude. (Annular open hole volume=20.2 bbls) Chase crude with mud. Pump crude out the bit with weight stacked. Pumping 2.9/2.9/4200 psi. Pump 10 bbls crude. Coil life at this point is 12%. PU to 90 klbs, rotate orienter. Still stuck. PU again to 90 klbs and hold. Still stuck. Stack weight, standby for 10 minutes. Work pipe again to 90 klbs, and it popped free. 19:05 - 20:00 0.92 DRILL P PROD1 Wiper trip to shoe. Discuss plan forward with slope geo and town engineer. Plan forward is to call TD where we are. To condition hole and run liner. 20:00 - 20:15 0.25 DRILL P PROD1 Log tie in pass over RA tag. Make +8' correction. 20:15 - 21 :25 1.17 DRILL P PROD1 Run back to bottom for final depth tag. Tag official TD at 13445'. 21 :25 - 21 :30 0.08 DRILL P PROD1 Circulate new mud pill to TD. 21 :30 - 00:00 2.50 DRILL P PROD1 POOH, laying new flopro in open hole. Open EDC and pump at full rate while POOH. 6/19/2004 00:00 - 00:15 0.25 DRILL P PROD1 Continue POOH with the BHA. Tag up, RIH, Tag up again, pumping the entire time. Hold PJSM for changing BHA while POH. 00:15 - 00:35 0.33 DRILL P PROD1 Tag up at surface, stand back injector. Lay down BHA #11. Bit recovered at 1,2. 00:35 - 00:50 0.25 CASE P RUNPRD Shut master valve. Remove BHI checks, and make up nozzle. Stab injector onto well. 00:50 - 01 :05 0.25 CASE P RUNPRD Hold safety meeting prior to pumping N2. 01 :05 - 02:30 1.42 CASE P RUNPRD PT N2 lines to 4500 psi. Pump 30 bbls water. Swap to N2 pumper. Pump N2 at 1500 scfm to purge coil. Finish pumping, bleed off N2 from coil. 02:30 - 02:50 0.33 CASE P RUNPRD Rig up to unstab coil from injector and spool back on reel. 02:50 - 03:05 0.25 CASE P RUNPRD PJSM Re: unstabbing pipe and securing it to shipping reel. 03:05 - 04:45 1.67 CASE P RUNPRD Unstab pipe. Secure it to reel. Stand back injector on legs. 04:45 - 05:05 0.33 CASE P RUNPRD PJSM prior to running liner. 05:05 - 08:30 3.42 CASE P RUNPRD Pick-up 2-7/8" x 3-3/16" solid liner and CTLRT. SIMOPS make-up hardline in reel. Prep end of coil, thread wirerope thru injector back to coil, attached internal connector and wirerope. 08:30 - 11 :50 3.33 CASE P RUNPRD Stab coil to injector. MU CTC pull test to 38 MU dart catcher. Load and pump coil dart 54.7 bbl vol. Pump another 30 bbls to clear coil. Stab on injector to liner. 11 :50 - 13:50 2.00 CASE P RUNPRD RIH with liner to window RIH wt at window 15.6k Wt check up 43k. RIH slow thru window ok. RIH speed 100'/min Printed: 6/29/2004 10: 17:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-33 18-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/9/2004 6/23/2004 N2 Spud Date: 10/4/1995 End: 6/23/2004 6/19/2004 11 :50 - 13:50 2.00 CASE P RUNPRD 12000' : 14.8k 12250' : 14.3k slowdown for OHWS no problem increase RIH speed 120'/min 12500' 13.6k overthe hump at 12600' : 12k 12750': 11.5k 13000': 10k 13250' :7k 130'/min 13300' : 6k 13400' : 2k Hit bottom 13445' with 5001b. 13:50 - 14:35 0.75 CASE P RUNPRD P/U wt off bottom 60k. Load and launch .625" steel ball. Ball on seat 47.4bbls pressure up to 4050psi for liner release. Pu wt 40k liner released. 14:35 - 16:35 2.00 CASE P RUNPRD Swap to 2% KCL and displace hole/annulus. Sent mud to MI. SIMOPS r/u cementers RD BHi and load out tools. 16:35 - 16:50 0.25 CEMT P RUNPRD PJSM review cement procedures. 16:50 - 18:25 1.58 CEMT P RUNPRD Batch mix cement 15.8ppg at 171 Ohrs. Pump 2 bbls water ahead, PT lines to 4000psi. OK bleed off. Pump 5 bbls water ahead then 19 bbls of 15.8ppg cement. Load and launch coil wiper dart. Displace coil with 37 bls Bio/KCL. LWP hit at 55 bbls (Expected vol=54.7 bbls) Displace cement. Plug landed at 65.6 bbls (Calculated 65.4 bbls) Pump plug with 500 psi over. Got 17.7 bbls of returns. Had 90% returns thru out job. Total of 17.7 bbls of returns during job. Annular volume with 40% excess in open hole was 14.9 bbls. 2.8 bbls of cement over top of liner. 18:25 - 21 :00 2.58 CEMT P RUNPRD PU at 39 klbs. Using new standard cementing proceedure, POH replacing pipe voidage with biozan. 21 :00 - 21 :30 0.50 CEMT P RUNPRD Lay down Baker CTLRT. All recovered as expected. 21 :30 - 22:45 1.25 EVAL P RUNPRD PJSM Re: logging and cleanout run. Pickup mill, motor, 2 jts of CS hydril, SWS logging tool. 22:45 - 23:45 1.00 EVAL P RUNPRD Run 29 stands, 58 joints of CS hydril work string. 23:45 - 00:00 0.25 EVAL P RUNPRD MU SWS BHA and stab on injector. 6/20/2004 00:00 - 00:30 0.50 EVAL P RUNPRD Continue to stab on injector. MU Schlumberger memory logger depth encoder. 00:30 - 02:20 1.83 EVAL P RUNPRD RIH with memory logging-c/o BHA. Cement at 700 psi compressive strength at 01 :00. 02:20 - 02:40 0.33 EV AL P RUNPRD Log down at 60 fpm, pumping 1.5 bpm. Motor work at 11580'. Stall at 11610'. PU and work down thru it slow. Free spin=2050 psi at 1.45 bpm. 02:40 - 03:35 0.92 CEMT P RUNPRD Begin drilling cement in 4-1/2" tubing. Free spin=2050 psi at 1.45 bpm. 1 for 1 returns. Getting harder and harder as we get into it. 11650'=35 fph. Looks like pretty hard cement. Note - Cement is hard enough we are leaving a cement sheath with a 2.3" hole thru it. Setting a liner top packer will not be possible wlo a full bore cleanout with a mill. Running perf guns thru it may not be wise either. 03:35 - 06:00 2.42 CEMT N DPRB RUNPRD Made PU just before entering liner and had overpulls and motor work. We have the wrong BHA in the hole for this situation. POOH to pick up a big mill and motor. Drop 5/8" ball to open circ sub. Never seen ball hit. Checked returns while POH, and are gettting cement cuttings over shaker. 06:00 - 08:45 2.75 CEMT N DPRB RUNPRD Setback injector. Standback CSH (wet) UD SLB mem tools. motor/mill. No 5.8" ball found. 08:45 - 09:05 0.33 CEMT N DPRB RUNPRD P/U injector. MU dart catcher. Pump at 3bpm 5/8" ball hit catcher after 26 bbls away. 09:05 - 10:00 0.92 CEMT N DPRB RUNPRD Change out CTC pull test to 35k. PU 3" MHA 3.78" D331 mill Printed: 6/29/2004 10: 17:05 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 18-33 1 8-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/9/2004 6/23/2004 N2 Spud Date: 10/4/1995 End: 6/23/2004 6/20/2004 09:05 - 10:00 0.92 CEMT N DPRB RUNPRD and BTT 3" straight motor. 10:00 - 11 :50 1.83 CEMT N DPRB RUNPRD RIHw/ BHA#13t011540'. 11 :50 - 13:00 1.17 CEMT N DPRB RUNPRD Milling cement f/11540' 2.8 bpm 1650psi fs drilling good cement at 11681' 26'/r 150 psi mw mill down to top of liner at 11690'. 13:00 - 15:20 2.33 CEMT N DPRB RUNPRD TOH backreaming slowly to 11500'. 15:20 - 15:50 0.50 CEMT N DPRB RUNPRD UD BHA #13. PIU 1 -11/16" motor and 2.30" D331 diamond mill and 1 stand of hydril. 15:50 - 16:35 0.75 EVAL N WAIT RUNPRD Gas leak at drill site #2. All traffic held up. SLB Memory Tools in the hold up. 16:35-17:10 0.58 EVAL P RUNPRD Program Memory tools. 17:10 - 17:20 0.17 EVAL P RUNPRD PJSM review handling precautions of SLB logging tools. 17:20 - 17:50 0.50 EVAL P RUNPRD P/U SLB Memory logging tools. 17:50 - 19:30 1.67 EVAL P RUNPRD Trip in hole with 29 stands of 1-1/4" CS hydril work string. 19:30 - 21 :30 2.00 EVAL P RUNPRD Stab on injector, RIH with coil. 21 :30 - 21 :55 0.42 EVAL P RUNPRD Log down from 10700'. 21 :55 - 23:30 1.58 EVAL P RUNPRD Tag up at 11693'. Begin milling cement. Free spin is 1750 psi at 1.54 bpm. Mill cement inside deployment sleeve down to 11703'. Broke thru bottom of cement at 11703'. Clean below this depth to 13335'. Milled cement from 13335' down to 13412'. Hit hard drilling here, this is probably the liner wiper plug. 23:30 - 00:00 0.50 EVAL P RUNPRD Log up at 30 fpm laying in perf pill at 0.2 bpm. 6/21/2004 00:00 - 01 :00 1.00 EVAL P RUNPRD Continue logging pass up to 10700'. 01 :00 - 01 :35 0.58 EVAL P RUNPRD Finish logging. Drop 518" ball to open circ sub. Chase with a foam pig. Chase pig with 15 bbl flopro mud pill. Chase pill with new 2% KCL with 1 ppb biozan. RIH to top of 11650. 01 :35 - 04:00 2.42 EVAL P RUNPRD POOH circulating at 1.5 bpm, 1990 psi. 04:00 - 05:00 1.00 EVAL P RUNPRD Stand back Injector, stab into bunghole. Pump 1 coil volume + 5 bbls at 3.5 bbls/min. Recover ball. Drop it down the CS hydril. Pump on seat to open the circ sub. Stand back the Injector. 05:00 - 05:15 0.25 EVAL P RUNPRD Hold PJSM prior to tripping CSH OOH. 05:15 - 07:00 1.75 EVAL P RUNPRD POOH standing back 10 stands, coming out sideways with the remainder. SIMOPS bump IA up to 1000psi useing Little Red pumper. 07:00 - 07:15 0.25 EVAL P RUNPRD PJSM review logging tools handling procedures. 07:15 - 08:00 0.75 EVAL P RUNPRD UD logging tools. Corrected logs showing TOL at 11686' PBTD 13411' (RA tags and top of window at 11760') 08:00 - 10:50 2.83 CASE N RUNPRD Double block all surface valves and prep for Liner Lap test. 1st test to 2000psi seeing 300psi pressure drop in 10 min. Check all surface equipment and valves. Retest with same results. IA stable. Close master/swab valves test surface valves etc...leaker somewhere. Close HCR's and inner manual valves on choke/killlines. Rig up test pump to lubricator cap. Pump up to 2000psi. Continued to see bleed off down to 1360psi after 15min. Close master/swab valves, surface pressure remains constant, reopen m/s valves after 3 min see 25psi pressure drop. No surface leaks on stack. fA remains constant. 10:50 -11:15 0.42 CASE P RUNPRD 2 jts PH-6 to cleanup deployment sleeve polish bore and to circulate 4.5" tbg clean at high pump rates. 11:15-13:20 2.08 CASE N DPRB RUNPRD Wait for BTT polish bore mill assembly. 13:20 - 14:00 0.67 CASE N DPRB RUNPRD PIU BHA #15 (90.23') Printed: 6/29/2004 10: 17:05 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-33 1 8-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: Spud Date: 10/4/1995 End: 6/23/2004 6/9/2004 6/23/2004 N2 DPRB RUNPRD RIH tag TOL at 11693' (coil depth). DPRB RUNPRD Mill/ polish from 11693' to 11699' 2.88 bpm 1550fs 100psi mw. P/U above TOL and make repeated passes. Load and lanuch 3/4" ball to open circ sub. Slow to 1 bpm after 40 bbls pumped. Ball on seat after 42.8 bbls pump open circ sub with 2825psi. Ramp up pump rate to 5.5bpm +/- 500fpm A V DPRB RUNPRD TOH circulating well clean at 5.5bpm. Seeing some cement cuttings coming over shaker but no shale after bottoms up. Pump at full rate to tag up, RIH and pull back to surface. No surge of debris observed. Wellbore is clean. Lay down milling BHA. All recovered ok. Safety meeting re: Perf guns and CS Hydril. Make up safety joint. Deploy 3 guns. Hold trip drill. Several good lessons learned from drill. Stand down and discuss drill with rig crew. Run Perf guns in hole. RIH with 10 stands of CS hydril work string. Check every connection with little jerks. Stab on injector. RIH with perf guns and CS hydril on coil tubing. Weight check at 11600' = 49 klbs. RIH tag bottom, PU at 54 klbs. Set depth to last ELM tag of 13411 '. Make +8.5' correction. PU into ball drop depth. Pump 10 bbls of flopro perf pill. Drop 5/8" ball to fire guns. RIH to PBTD, confirm tag at 13411'. PU stop at 13404', (3' below firing depth). Circulate ball on seat. Ball landed at 48.5 bbls (Coil vol=54.7 bbls). PU, fire guns on the run with the gun nose at 13400.7'. Good indication of fire at 3100 psi. PU weight after firing=60 klbs. Pulled heavy for 20' prior to cleaning up to 54 klbs up weight. Intervals perforated; 12200'-12470' 6 spf 12850'-13400', 6 spf POOH. Lay in remainder of flopro mud until coil voided, then swap to filling accross the top holding backpressure with the choke to keep from swabbing in the well. Crew changeout. PJSM with oncoming crews review I/d precautions and procedures of the perf guns. Lay down 20 joints of CS hydril. Again go over procedures for "wet" guns and possible trapped gas. Also wearing proper PPE. UD 56 perf guns. All blanks had trapped gas. All shots fired. Roll out guns on pipe shed racks with absorb pads under them. LOWER1 Load out guns. Clean-up floor. DPRB RUNPRD Safety meeting Re: Liner top packer. RUNPRD Make up BHA #17, for setting liner top packer. RUNPRD RIH with liner top packer. RUNPRD Weight check up at 11500'=45klbs up. Kick on pumps to 0.5 bpm. RIH sting into deployment sleeve, observe CTP and confirmed in deployment sleeve. SI pumps, run down 6' and stack out. Pull up until pickup, then PU 2', and paint flag at 11686'. Repeat to confirm depths. Got same setting depth on second attempt. PU free of deployment sleeve. Drop 5/8" ball 6/21/2004 14:00 - 15:45 15:45 - 16:35 1.75 CASE N 0.83 CASE N 16:35 - 18:40 2.08 CASE N 18:40 - 19:30 0.83 CASE N DPRB RUNPRD 19:30 - 20:10 0.67 PERFO P LOWER1 20:10 - 20:40 0.50 PERFO P LOWER1 20:40 - 23:25 2.75 PERFO P LOWER1 23:25 - 00:00 0.58 PERFO P LOWER1 6/22/2004 00:00 - 02:45 2.75 PERFO P LOWER1 02:45 - 03:20 0.58 PERFO P LOWER1 03:20 - 06:00 2.67 PERFO P LOWER1 06:00 - 06:30 0.50 PERFO LOWER1 06:30 - 11 :30 5.00 PERFO LOWER1 11 :30 - 12:45 12:45 - 13:05 13:05 - 13:50 13:50 - 16:20 16:20 - 17:55 1.25 PERFO 0.33 CASE 0.75 CASE 2.50 CASE 1.58 CASE Printed: 6/29/2004 10: 17:05 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 8-33 1 8-33 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: Rig Release: Rig Number: 6/9/2004 6/23/2004 N2 Spud Date: 10/4/1995 End: 6/23/2004 6/22/2004 16:20 - 17:55 1.58 CASE P RUNPRD circulate on seat. Ball landed at 46.5 bbls (Coil vol=54.7 bbls). Open Baker choke. RIH and stack weight. PU to flag depth. Pressure up to 2500 psi to start setting packer. SI pumps, PU 5klbs over. Confirm partial set. Set 10 klbs down. Line up down the backside. Pump WHP to 2000 psi. 17:55 - 19:45 1.83 CASE P RUNPRD Initial pressure=2084 at 18:05. Pressure bled off to 2040 in 35 minutes. Test good. Bleed off coil annulus. Pressure down coil to 3650 psi to shear off packer running tool. 19:45 - 20:30 0.75 CASE P RUNPRD POOH to 2500'. Circulate 60/40 MEOH to freeze protect well to surface. Continue to pull out of hole. 20:30 - 21 :15 0.75 CASE P RUNPRD Circulate to surface. Get off well. Unstab coil. 21:15-21:45 0.50 CASE P RUNPRD LD packer running tools. 21 :45 - 00:00 2.25 RIGD P POST Blow down reel with N2 to lighten rig for move on soft access road. Clean pits. ND BOPS. NU & test tree cap. 6/23/2004 00:00 - 03:30 3.50 RIGD P POST ND BOPs. Set back injector. Unstab coil and spool onto reel. Continue to clean pits. Vac truck availability very limited. Warm up rig drive system hydraulics. Release rig at 0330 hrs. 03:30 - 04:00 0.50 DEMOB P POST Back rig off well, remove coil BOP's from cellar. Further telex entries carried on L2-21 morning report. Printed: 6/29/2004 10: 17:05 AM e e -.I: INTRQ Obp BP-GDB Baker Hughes INTEQ Survey Report Fietd: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Modet: Alaska. Zone 4 Well Centre bggm2003 Site: PB DS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959213.15 ft 691583.44 ft Latitude: 70 17 Longitude: 148 26 North Reference: Grid Convergence: 35.252 N 55.555 W True 1.46 deg Well: 18-33 Slot Name: 33 18-33 Well Position: +N/-S 1060.28 ft Northing: 5960277.20 ft Latitude: 70 17 45.680 N +E/-W 163.86 ft Easting : 691720.22 ft Longitude: 148 26 50.778 W Position Uncertainty: 0.00 ft Wellpath: 18-33APB1 500292259870 Current Datum: 60: 335/31/199609:48 Magnetic Data: 7/16/2004 Field Strength: 57608 nT Vertical Section: Depth From (TVD) ft 38.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 18-33 11760.00 ft Mean Sea Level 25.31 deg 80.89 deg Direction deg 48.08 Height 54.00 ft Survey Program for Definitive Wellpath Date: 6/16/2004 Validated: Yes Version: 3 Actual From To Survey Toolcode ft ft 250.69 11752.83 1 : MWD - Standard (250.69-13289.00) (0) MWD 11760.00 12903.00 MWD (11760.00-12903.00) MWD Tool Name MWD - Standard MWD - Standard Annotation Survey: MWD Start Date: 6/15/2004 CoilTrak Company: Baker Hughes INTEa Engineer: Tool: MWD;MWD - Standard Tied-to: From: Definitive Path Survey 11752.83 81.10 90.30 8677.76 8623.76 4749.38 5122.79 5965155.43 696719.90 6984.79 0.00 11760.00 82.00 90.32 8678.81 8624.81 4749.34 5129.88 5965155.57 696726.99 6990.04 12.56 11790.58 87.10 95.00 8681.72 8627.72 4747.92 5160.27 5965154.93 696757.40 7011.70 22.59 11820.53 91.31 103.91 8682.13 8628.13 4743.01 5189.78 5965150.77 696787.02 7030.37 32.89 11854.52 88.76 115.14 8682.11 8628.11 4731.67 5221.76 5965140.25 696819.28 7046.59 33.88 11887.76 90.35 125.24 8682.37 8628.37 4714.97 5250.45 5965124.29 696848.38 7056.78 30.76 11924.18 88.34 136.22 8682.79 8628.79 4691.25 5278.00 5965101.28 696876.53 7061.43 30.65 11959.94 87.99 148.72 8683.94 8629.94 4662.96 5299.73 5965073.56 696898.98 7058.70 34.95 12000.46 90.63 159.98 8684.43 8630.43 4626.50 5317.24 5965037.56 696917.41 7047.36 28.54 12034.05 86.92 170.66 8685.15 8631.15 4594.07 5325.74 5965005.35 696926.73 7032.02 33.65 12062.65 87.80 179.87 8686.47 8632.47 4565.63 5328.10 5964976.98 696929.81 7014.77 32.32 e e ..I: IN'l'EQ Obp BP-GDB Baker Hughes INTEQ Survey Report 12099.89 88.88 191.33 8687.55 8633.55 4528.64 5324.47 5964939.92 696927.13 6987.36 30.90 12133.94 88.27 201.85 8688.40 8634.40 4496.07 5314.76 5964907.11 696918.26 6958.37 30.94 12167.66 85.13 214.54 8690.35 8636.35 4466.46 5298.90 5964877.11 696903.15 6926.78 38.70 12199.96 84.30 221.49 8693.33 8639.33 4441.13 5279.10 5964851.29 696884.01 6895.14 21.58 12233.64 83.86 228.45 8696.80 8642.80 4417.45 5255.44 5964827.01 696860.96 6861.71 20.60 12277.68 86.18 238.54 8700.64 8646.64 4391.39 5220.22 5964800.06 696826.42 6818.09 23.42 12322.46 88.76 244.73 8702.61 8648.61 4370.15 5180.88 5964777.83 696787.63 6774.62 14.96 12361.13 90.69 242.58 8702.80 8648.80 4352.99 5146.23 5964759.79 696753.44 6737.38 7.47 12392.52 91.33 237.92 8702.25 8648.25 4337.42 5118.99 5964743.53 696726.60 6706.71 14.98 12437.43 91.30 232.67 8701.22 8647.22 4311.87 5082.09 5964717.05 696690.37 6662.18 11.69 12466.48 90.48 235.17 8700.76 8646.76 4294.76 5058.62 5964699.35 696667.34 6633.29 9.06 12494.45 90.23 232.52 8700.59 8646.59 4278.26 5036.03 5964682.28 696645.19 6605.46 9.52 12525.12 87.86 233.55 8701.10 8647.10 4259.82 5011.53 5964663.22 696621.17 6574.92 8.43 12555.49 88.88 239.44 8701.97 8647.97 4243.07 4986.23 5964645.83 696596.31 6544.90 19.67 12591.00 88.85 244.59 8702.67 8648.67 4226.42 4954.89 5964628.39 696565.40 6510.45 14.50 12630.55 88.39 250.25 8703.62 8649.62 4211.24 4918.40 5964612.29 696529.31 6473.16 14.35 12666.17 87.99 250.43 8704.75 8650.75 4199.27 4884.87 5964599.46 696496.10 6440.21 1.23 12701.92 92.47 252.75 8704.61 8650.61 4187.98 4850.96 5964587.31 696462.49 6407.44 14.11 12739.92 94.80 259.55 8702.19 ·8648.19 4178.91 4814.17 5964577.30 696425.94 6374.00 18.88 12771.07 94.69 266.03 8699.61 8645.61 4175.01 4783.39 5964572.62 696395.27 6348.50 20.73 12800.35 94.90 268.41 8697.17 8643.17 4173.60 4754.24 5964570.47 696366.18 6325.87 8.13 12830.25 99.01 269.58 8693.55 8639.55 4173.07 4724.58 5964569.19 696336.54 6303.45 14.28 12863.66 99.54 275.82 8688.16 8634.16 4174.63 4691.66 5964569.90 696303.59 6279.99 18.50 12903.00 99.54 275.82 8681.64 8627.64 4178.56 4653.06 5964572.85 696264.91 6253.91 0.00 - Survey: MWd (18-33/18-33A) Created By: Digita! Business Client UserDate: 1/1612004 4200 4300 4400 4500 4700 4800 4900 West(-)/East(+) [1 DDft/in) BP 18-33APBI 12400.00 Rig: lIIon:lìc2 Ref. Datum: 60: 33 5131/1996 00:48 54.00ft rlgin Origin Slartl N/-S +EI-W From 253.00' 0.00 0.00 38.00 rtr 54.00 TVD MD 8624.81 8$48,25 864a.07 864<t56 ....,¡!251 C i8301 o 1:!?ß351 .s::: 1.840( G> aB45( i !J8500 i G>8550- )I CÞ 860t} i! ... 8851 Obp e e ... ..... INTEQ BP-GDB Baker Hughes INTEQ Survey Report Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB DS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959213.15 ft 691583.44 ft Latitude: 70 17 Longitude: 148 26 North Reference: Grid Convergence: 35.252 N 55.555 W True 1.46 deg Well: 18-33 Slot Name: 33 18-33 Well Position: +N/-S 1060.28 ft Northing: 5960277.20 ft Latitude: 70 17 45.680 N +E/-W 163.86 ft Easting : 691720.22 ft Longitude: 148 26 50.778 W Position Uncertainty: 0.00 ft Wellpath: 18-33A 500292259801 Current Datum: 60: 33 5/31/1996 09:48 Magnetic Data: 6/10/2004 Field Strength: 57605 nT Vertical Section: Depth From (fVD) ft 38.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 18-33APB 1 12400.00 ft Mean Sea Level 25.36 deg 80.89 deg Direction deg 253.00 Height 54.00 ft Survey Program for Definitive Wellpath Date: 7/16/2004 Validated: Yes Version: 2 Actual From To Survey Toolcode ft ft 250.69 11752.83 1 : MWD - Standard (250.69-13289.00) (0) MWD 11760.00 12392.52 MWD (11760.00-12903.00) (2) MWD 12400.00 13445.00 MWd (12400.00-13445.00) MWD Tool Name MWD - Standard MWD - Standard MWD - Standard Annotation 11760.00 12392.52 12400.00 13445.00 8678.81 8702.25 8702.07 8698.58 Window TIP KOP TO Survey: MWd CoilTrak Company: Baker Hughes INTEQ Tool: MWD;MWD - Standard Start Date: 6/18/2004 Engineer: Tied-to: From: Definitive Path e BP-GDB Baker Hughes INTEQ Survey Report e -- ..... INTßO 11760.00 82.00 90.32 8678.81 8624.81 4749.34 5129.88 5965155.57 696726.99 -6294.30 0.00 12392.52 91.33 237.92 8702.25 8648.25 4337.42 5118.99 5964743.53 696726.60 -6163.45 23.25 12400.00 91.33 237.05 8702.07 8648.07 4333.40 5112.68 5964739.35 696720.40 -6156.25 11.63 12433.70 95.93 241.75 8699.94 8645.94 4316.29 5083.75 5964721.51 696691.92 -6123.57 19.49 12478.66 100.21 247.99 8693.62 8639.62 4297.39 5043.48 5964701.59 696652.15 -6079.54 16.71 12507.03 99.87 256.85 8688.67 8634.67 4288.96 5016.88 5964692.48 696625.77 -6051.64 30.77 12546.82 96.23 264.51 8683.09 8629.09 4282.60 4978.04 5964685.13 696587.11 -6012.63 21.14 12583.43 94.29 270.90 8679.73 8625.73 4281.14 4941.63 5964682.75 696550.75 -5977.39 18.17 12620.83 95.63 282.08 8676.48 8622.48 4285.34 4904.67 5964686.00 696513.70 -5943.27 29.99 12654.35 89.74 289.24 8674.91 8620.91 4294.37 4872.47 5964694.21 696481.28 -5915.12 27.63 12694.65 90.14 297.89 8674.96 8620.96 4310.47 4835.56 5964709.36 696443.97 -5884.53 21.49 12725.86 89.00 298.39 8675.19 8621.19 4325.19 4808.04 5964723.37 696416.09 -5862.52 3.99 12765.10 81.04 295.10 8678.59 8624.59 4342.77 4773.17 5964740.06 696380.78 -5834.31 21.94 12803.92 82.43 286.90 8684.18 8630.18 4356.52 4737.34 5964752.89 696344.61 -5804.06 21.21 12847.25 85.35 273.14 8688.82 8634.82 4363.98 4695.02 5964759.27 696302.12 -5765.77 32.28 12890.35 86.43 270.15 8691.91 8637.91 4365.22 4652.05 5964759.41 696259.13 -5725.04 7.36 12917.49 87.24 267.66 8693.41 8639.41 4364.70 4624.96 5964758.20 696232.07 -5698.98 9.63 12947.88 90.54 264.13 8693.99 8639.99 4362.52 4594.66 5964755.25 696201.84 -5669.37 15.90 12974.32 89.46 257.90 8693.99 8639.99 4358.40 4568.56 5964750.46 696175.85 -5643.21 23.91 13006.17 88.39 258.01 8694.59 8640.59 4351.75 4537.42 5964743.02 696144.89 -5611.48 3.38 13041.13 90.11 260.50 8695.05 8641.05 4345.23 4503.08 5964735.63 696110.73 -5576.74 8.66 13093.58 90.41 269.01 8694.81 8640.81 4340.44 4450.89 5964729.51 696058.69 -5525.43 16.23 13126.60 90.41 271.96 8694.57 8640.57 4340.72 4417.88 5964728.95 696025.68 -5493.94 8.93 13176.25 91.03 279.49 8693.95 8639.95 4345.67 4368.52 5964732.64 695976.21 -5448.19 15.22 13208.28 92.47 280.32 8692.97 8638.97 4351.18 4336.98 5964737.34 695944.54 -5419.64 5.19 13237.47 88.97 278.03 8692.60 8638.60 4355.83 4308.17 5964741.25 695915.63 -5393.45 14.33 13265.61 87.34 276.19 8693.51 8639.51 4359.31 4280.27 5964744.02 695887.64 -5367.78 8.73 13295.17 88.11 273.29 8694.68 8640.68 4361.75 4250.83 5964745.71 695858.16 -5340.34 10.14 13328.90 88.60 269.91 8695.65 8641.65 4362.69 4217.13 5964745.79 695824.45 -5308.39 10.12 13366.44 88.88 267.74 8696.48 8642.48 4361.92 4179.61 5964744.06 695786.96 -5272.29 5.83 13401.02 86.82 270.94 8697.78 8643.78 4361.53 4145.07 5964742.78 695752.44 -5239.13 11.00 13430.00 90.00 270.00 8698.58 8644.58 4361.76 4116.10 5964742.28 695723.48 -5211.51 11.44 13445.00 90.00 270.00 8698.58 8644.58 4361.76 4101.10 5964741.90 695708.49 -5197.16 0.00 LEGEND 0.00 54.00ft 38,00 BP Amoco WELLPATH DETAILS 18-33A 500292259001 Nordîc .2 60: 33 513111900 09:48 0,00 Ref. \f.Seclion Angle 253.00° TREE = WELLHEA D = FfIIC 18-33A SAFETY NOTES: GLMS HAVE LOWER PSI RATE ACTUA. TOR- BAKERC THAN NORMAL CHECK WITH WE. KB. B...EV = 54.0' BF. B...EV = KOP= 1053' MIx Angle - 100 @ 12479' Datum rvÐ = 7869' . 2199' 4-1/2" HEB I-RQ SVLN SSSV NIP, ID = 3.812" I Datum TVD - 8800' SS I 9-5/8" CSG, 40#, L-80, ID = 8.835" 4141' -¡---.4 .. GAS LIFT MANDRELS ST MD ND DEV TYÆ VLV LATCH PORT DATE Minimum ID = 2.372" @ 11686' L 1 4283 3679 49 KBMG-2-LS-MOD DO rv1E INT 16 06/29/04 BKR KB LNR TOP PKR 2 8027 6223 46 KBMG-2-LS-MOD SO INT 20 06/29/04 3 10683 8055 42 KBMG-2-LS-MOD DMY INT 0 06/29/04 NOT~ PROBL8\/I MAI'ÐRElS; REQURESPECIAL VALVES 8: 10749' 7" x 4-1/2" BAKER S PKR, ID = 3.937" I "-' . . 10783' H 4-1/2" HEB XN NIP, D - 3.725" I I TOP OF 4-112" LNR 10805' . 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10807 -- / 10807' 4-1/2" TLBING TAIL WLEG, ID = 3.958" 1 I H ELMD TT NOT LOGGED I I 7" CSG, 26#, L-80, ID = 6.276" 10961' µ .. I TOP OF CEMENT I 15<. . 11686' 3.7" BKR KB LNR TOP A<R, ID = 2.372" I 11691' I .- -. 11692' 3.7" BKR DEPLOYrvENT SLV, ID - 3.0" I . 11711' 3-1/2"f-ESXNIP,ID=2.812" ì 3-1/2" LNR, 8.81#, L-80, .0087 bpf, D = 2.990" 11722' 11722' 3-1/2" X 3-3/16" XO, ID - 2.786" I ~ I PERFORA 1l0N SlXv1M4. RY Uh~ I fv1ILLOUTWINDOW 11760'- 11776' I RB= LOG: BH GR / ROP/ ffiESS ON 06/18/04 ANGLE AT TOP PERF: 91 @ 12220' Note: Refer to A'oduction œ for historical perf data II 12165' 3-3I16X 2-7/8" XO I SIZE SFF NTERV A L Opn/Sqz DATE 2" 6 12220 - 12470 0 06/22/04 2" 6 12850 - 13400 0 06/22/04 I I 13411' PBTD 1 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" 13289' 13-3116" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" 12165' 1 12-7/8" LNR, 6.5#, L-80, .0058 bpf, ID = 2.441" 13445' r DATE REV BY COMrvENTS DATE REV BY co MrvENTS PRUDI-OEBAY LNIT 10/29/95 ORIGINAL COMPLErION WELL: 18-33A 06122/04 KAK CTD SIDErRACK(18-33A) PERfv1IT I'b: 2040700 06/29/04 PWEfKA~ GLV ao APII\b: 50-029-22598-01 SEC 24, T11 N, R14E, 3616.87' ÆL & 2210.43' Ff\l. BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR AItASIiA. ORAND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe 18-33A BP Exploration (Alaska) Inc. Permit No: 204-070 Surface Location: 3690' NSL, 56' WEL, SEC. 24, TIIN, RI4E, UM Bottomhole Location: 2634' NSL, 3754' EWL, SEe. 18, TIIN, RI5E, UM Dear Mr. Kara: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ITom obtaining additional permits or approvals required by law fÌ"om 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 North Slope petroleum field inspector -3607 (pager). BY ORDER 9X THE COMMISSION DATED tbisU day of April, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. W (¡ A;- 4/ ,¿4, I zo04 I STATE OF ALASKA · ALAS OIL AND GAS CONSERVATION ~MMISSION PERMIT TO DRILL 20 AAC 25.005 o Drill III Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3690' NSL, 56' WEL, SEC. 24, T11 N, R14E, UM Top of Productive Horizon: 3082' NSL, 4460' EWL, SEC. 18, T11N, R15E, UM Total Depth: 2634' NSL, 3754' EWL, SEC. 18, T11N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 691721 y- 5960277 Zone- ASP4 16. Deviated Wells: Kickoff Depth 18. Casing PtOgr~nrl Size Casina Weiaht 3-3/4" x 4-1/8" 3-3/16" x 2-7/8" 6.4# / 6.5# 1b. Current Well Class 0 Exploratory III Development Oil 0 Multiple Zone I 0 Stratigraphic Test 0 Service 0 Development Gas 0 Single Zone 5. Bond: 0 Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 PBU 18-33A 6. Proposed Depth: 12. Field / Pool(s): MD 13800 rvD 8706 Prudhoe Bay Field I Prudhoe Bay 7. Property Designation: Pool ADL 028321 8. Land Use Permit: 13. Approximate Spud Date: 06/01/04 14. Distance to Nearest Property: 26000 9. Acres in Property: 2560 11760 ft 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): 54' feet 806' away from L2-20 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle 900 Downhole: 3373 psig Surface: 2488 psig ('" To~AttinCJDént~ot dl"l'l_iii Grade CouDlinc Lenath MD rvD MD rvD (includina staae data) L-80 TCII/ STL 2100' 11700' 8702' 13800' 8706' 84 sx Class 'G' f" Hole 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redri" AND Re-entry Operations) Total Depth MD (ft): Total Depth rvD (ft): 13289 8681 ......~" 'M ' , ..nnth ~ Plugs (measured): I Effective Depth MD (ft): IEffective Depth rvD (ft):1 Junk (measured): None 13202 I 8681 I None Size " ,!\An rvD r.nnnlJr:tnr 110' 20" 260 sx Arctic Set (Approx.) 110' 110' 4107' 9-5/8" 1023 sx PF 'E', 588 sx Class 'G' 4141' 3586' 10926 7" 180 sx Class 'G' 10961 ' 8251' prnrl' ,rotinn I inAr 2484' 4-1/2" 270 sx Class 'G' 10805' - 13289' 8144' - 8681' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth rvD (ft): 8683' - 8680' 181 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements Perforation Depth MD (ft): 11800' -13190' 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Kara, 564-5667 Printed Name --Dan Kara ¡(~ Title CT Drilling Engineer , . \"; J) \ I --¡r-:"/ Prepared By Name/Number: Signature /\ Y1\.~-L-- - Phone 564-5667 Date 'fDð/r,'j Sondra Stewman, 564-4750 '...... ',. ...', ", ",..(.%;..'iii" ....Øîjî..i iT ..t, ",i,/i....;:,;{ .: Permit To Drill I API Number: Permit ApproYéllll"\,A 'hi see cover.letter for Number:?o9' - C> /r>150-029-22598-01-00 Date: 11 ¡!1\' I (lV other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Requir/ d I I t:) ....,~fi'~}iQ. Hydrogen Sulfide Measures ~Yes 0 No Directional Survey RequiM~ liVtf!!: D Other:TeSf-"ßOPE~~ÇOO pç,j j ¡).ey- C.O, Sit,;.OOO . APR 232004 iZ ~ aH ~"'R 2' 8 ìOM~ ORDER ~~.ka Oil & ;::h~::~ C~~';'n , ADDroved Bv: -l~" ~ _ _ . _ I &. I A I THE COMMISSION Date If/t 1/ elf Form 10-401 Revised 1 ~3 UK! lJ I I\! Ii L Submft In DÚplicate . . BP Prudhoe Bay 18-33A CTD Sidetrack Summary of Operations Well 18-33 is scheduled for a through tubing sidetrack with coiled tubing drilling rig Nordic 2. The sidetrack, 18-33A, will kick off from a window milled off a mechanical whipstock set above the existing perforations, the use of a perforatable whipstock allowing the possibility of reinstating production from the original 18-33 wellbore at a later date. Zone 1A will be the target for this sidetrack. /' Pre Rig Prep Work i) Complete mechanical integrity test of inner and outer annulus. ii) Pressure test wellhead and tubing packoffs. iii) Run whipstock through 4-1/2" tubing into the 4-112" liner and set at 11760' MD. Nordic 2 CTD - Mill window, drill and complete sidetrack: iv) Mill 3.8" window at 11760' MD, through the 4-1/2" liner. /" v) Directional1y drill 2040' of 3-3/4" to 4-118" hole to a planned TD of 13800' /' MD, 8706' TVD. LJ vi) Run 3-3/16" x 2-7/8" liner from TD up to 11700' MD, pump~bl cement / from TD to 11700" MD. vii) Run cased hole CNL log and shoot at least 800' of perforations. viii) Rig down Nordic 2. Mud Program 8.7 ppg Flo-Pro /' Disposal All drilling and completion fluids and all other Class II wastes will go to grind and inject or to Pad 3. All Class I wastes will go to Pad 3 for disposal. Casing Program , 550' of 3-3/16" TCIl 6.4# L-80 from 12250' MD up into the 4-Yí" liner to 11700' MD. /' 1550' of 2-7/8" STL 6.5# L-80 from TD up to 12250' MD. Cement from TD to top ofliner at 11700' MD with 17.2 bbl,15.8 ppg cement slurry. Well Control 7-1/16" BOP diagrams are attached. . . Directional See attached directional plan. New hole consists of a build section of length 482' and a horizontal section of length 1558'. Max planned hole angle is -90.1 degrees. Magnetic and inclination surveys will be taken every 30 ft. Logging MWD gamma ray and possibly resistivity will be run over the open hole section for geosteering purposes. MCNL log will be run to determine the GOC location. Hazards Two faults are progn~ to be crossed by the well path. Lost circulation is not expected. Drill Site 18 is not an H2S drillsite, the most recent H2S reading was 5 ppm taken at 18- 16B on Jan 1st 2004. The greatest H2S reading was 16 ppm taken at 18-09B on July 23rd 1999. Reservoir Pressure A pore pressure of 3373 psi at 8854' TVD was measured at well 18-33 in Sept 03 (7.4 ppg equivalent mud weight). , Maximum surface pressure with gas (0.1 psi/ft) to surface is 2488 psi. /' TREE - . . WELLHEAD = FMC 18-33 SAFETY NOTES: GLMS HAVE LOWER PSI ACTUATOR - BAKERC RATE THAN NORMAL. CHECK WITH WIE. KB. ELEV = 54.0' BF. ELEV = KOP= 1053' Max Angle = 96@ 12552' 2199' -f I Datum MD - N/A 4-1/2" HES HRQ SVLN SSSV NIP, ID = 3.812" Datum lVD = 8800'S5 . I 9-5/8" CSG, 40#, L-80, ID = 8.835" I 4141' ~ ~ GAS LIFT MANDRELS ST MD lVD DEV VLV TYPE LATCH PORT DATE Minimum ID = 3.725" @ 10783' U 1 4283 3679 49 KBMG-2-LS-MOD INTEGRAL 4-1/2" HES XN NIPPLE 2 8027 6223 46 KBMG-2-LS-MOD INTEGRAL 3 10683 8055 42 KBMG-2-LS-MOD INTEGRAL 8: - 10749' -f 7" X 4-1/2" BAKER S PKR, ID = 3.937" I ~ I I 10783' 1-1 4-1/2" HES XN NIP, ID = 3.725" I I TOP OF 4-1/2" LNR I 10805' I ~ 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I 10807' , I" 10807' H 4-1/2" TUBING TAIL WLEG, JD = 3.958" I I H ELMD TT NOT LOGGED I I 7" CSG, 26#, L-80, ID = 6.276" I 10961' µ ~ PERFORATION SUMMARY 0 REF LOG: BHCA ON 10/23/95 ANGLE AT TOP PERF: 87 @ 11800' 0 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE [] 4 11800 - 12075 0 10/28/95 4 12160 - 12415 0 10/28/95 4 12510 - 12740 0 10/28/95 [] 4 12840 - 13190 0 10/28/95 I PBTD I 13202' 14-1/2" LNR. 12.6#, L-80, .0152 bpf, ID = 3.958" I 13289' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 10/29/95 ORIGINAL COM PLETION WELL: 18-33 05/19/01 RNIKAK CORRECTIONS PERMrrNo: 1951430 06/15/03 CMOITLP KB ELEVATION CORRECTION API No: 50-029-22598-00 09/13/03 CMOITLP DATUM MD & PERF ANGLE SEe 24, T11N, R14E, 3616.87' FEL & 2210.43' FNL 02/27/04 A TDITLP WELLHEAD CORRECTION BP Exploration (Alaska) PERFORA TION REF LOG: SHCA ANGLE AT Note: Refer to SPF 4 4 4 4 ObP . . BP-GDB Baker Hughes INTEQ Planning Report Company: Field: Site: Well: Wellpath: BP Amoco Prudhoe Bay PB DS 18 18-33 Plan#318-33A Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB DS 18 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5959213.15 ft 691583.44 ft ... BAKU: IIUGIIIS I Nl"EQ Date: 3/31/2004 Time: 11 :27:23 Page: Co-ordinate(NE) Reference: Well: 18-33, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,O.00E,253.00Azi) Survey Calc~lationMethod: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Latitude: 70 17 Longitude: 148 26 North Reference: Grid Convergence: Alaska, Zone 4 Well Centre bggm2003 35.252 N 55.555 W True 1.46 deg Well: 18-33 Slot Name: 33 18-33 Well Position: +N/-S 1060.28 ft Northing: 5960277.20 ft Latitude: 70 17 45.680 N +E/-W 163.86 ft Easting : 691720.22 ft Longitude: 148 26 50.778 W Position Uncertainty: 0.00 ft Wellpath: Plan#318-33A 500292259801 Current Datum: 60: 335/31/199609:48 Magnetic Data: 3/31/2004 Field Strength: 57600 nT Vertical Section: Depth From (TVD) ft 38.00 Targets Name Description TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip. 18-33A Polygon3.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 -Polygon 9 -Polygon 10 -Polygon 11 -Polygon 12 -Polygon 13 18-33A Fault 1 -Polygon 1 -Polygon 2 18-33A T3.1 Dir. 0.00 0.00 0.00 8648.00 8652.00 8652.00 18-33A T3.2 18-33A T3.3 Height 54.00 ft +N/-S ft 0.00 +N/-S 4565.38 4565.38 4559.67 4016.68 4069.72 4058.88 4108.22 4107.68 4117.04 4113.83 4489.15 4426.24 4416.85 4426.04 4420.93 4420.93 4505.15 4253.18 4200.33 4225.24 +E/-W 5299.27 5299.27 5523.21 5514.35 5121.56 4919.20 4436.28 4026.10 3659.20 3393.02 3503.63 4087.25 4651.23 5114.64 3432.87 3432.87 5973.99 5067.21 4119.50 3810.02 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Map Map Northing Easting ft ft 5964976.00 696901.00 5964976.00 696901.00 5964976.00 697125.00 5964433.00 697130.00 5964476.00 696736.00 5964460.00 696534.00 5964497.00 696050.00 5964486.00 695640.00 5964486.00 695273.00 5964476.00 695007.00 5964854.00 695108.00 5964806.00 695693.00 5964811.00 696257.00 5964832.00 696720.00 5964784.00 695039.00 5964784.00 695039.00 5964933.00 697577.00 5964658.00 696677.00 5964581.00 695731.00 5964598.00 695421.00 18-33 11752.83 ft Mean Sea Level 25.44 deg 80.89 deg Direction deg 253.00 <-- Latitude --> Deg Min Sec 70 18 30.562 N 70 18 30.562 N 70 18 30.504 N 70 1825.164 N 70 18 25.688 N 70 18 25.583 N 70 18 26.071 N 70 18 26.068 N 70 18 26.162 N 70 18 26.132 N 70 18 29.823 N 70 18 29.201 N 70 18 29.105 N 70 18 29.193 N 70 1829.152 N 70 18 29.152 N 70 18 29.965 N 70 18 27.493 N 70 18 26.979 N 70 18 27.226 N <- Longitude.--> Deg Min See 148 24 16.225 W 148 24 16.225 W 148 24 9.694 W 148 24 9.964 W 148 24 21.418 W 148 24 27.319 W 148 2441.402 W 148 24 53.364 W 148 25 4.064 W 148 2511.827 W 148 25 8.596 W 148 24 51.576 W 148 2435.128 W 148 24 21.613 W 148 25 10.661 W 148 25 10.661 W 148 23 56.548 W 148 24 22.999 W 148 24 50.639 W 148 24 59.664 W ObP . BP-GDB . IG.. BAIICD IIUGIIIS Baker Hughes INTEQ Planning Report IN'I'EQ Company: BP Amoco Date: 3/31/2004 Time: 11 :27:23 Page: 2 Field: Prudhoe Bay Co-ordlnate(NE) Reference: Well: 18.33, True North Site: PB DS 18 Vertical (TVD) Reference: System: Mean Sea Level Well: 18·33 Section (VS) Reference: Well (0.00N,0.00E,253.00Azi) Wellpath: Plan#3 18-33A Survey Calculation Method: Minimum Curvature Db: Oracle Annotation MD TVD ft ft 11752.83 8623.76 TIP 11760.00 8624.81 KOP 11780.00 8627.37 3 11830.00 8631.61 4 12242.05 8648.25 5 12729.05 8648.25 6 12979.05 8649.37 7 13259.05 8651.68 8 13484.05 8652.34 9 13800.00 8652.27 TO Plan: Plan #3 Date Composed: 3/31/2004 Identical to Lamar's Plan #3 Version: 6 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD loci Azim TVD +N/-S +E/-W DLS ßuild Turn 1'FO Target ft deg deg deg/100ft deg/10OO deg/10OO deg ~..- --'.' - -. ~ ~ 11752.83 81.10 90.30 8623.76 4749.38 5122.79 0.00 0.00 0.00 0.00 11760.00 82.00 90.32 8624.81 4749.34 5129.88 12.56 12.55 0.28 1.26 11780.00 83.27 91.60 8627.37 4749.01 5149.71 9.00 6.37 6.41 45.00 11830.00 87.05 105.13 8631.61 4741.76 5198.88 28.00 7.55 27.06 75.00 12242.05 90.00 220.54 8648.25 4411.56 5300.47 28.00 0.72 28.01 91.40 12729.05 90.00 278.98 8648.25 4250.31 4863.09 12.00 0.00 12.00 90.00 12979.05 89.50 248.99 8649.37 4224.41 4617.30 12.00 -0.20 -12.00 269.00 13259.05 89.58 282.59 8651.68 4204.13 4342.05 12.00 0.03 12.00 90.00 13484.05 90.08 255.59 8652.34 4200.59 4119.15 12.00 0.22 -12.00 271.00 13800.00 89.94 293.51 8652.27 4225.20 3809.91 12.00 -0.04 12.00 90.20 Survey MD Incl Azlm Sys 1'VD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 11752.83 81.10 90.30 8623.76 4749.38 5122.79 5965155.43 696719.90 -6287.53 0.00 0.00 TIP 11760.00 82.00 90.32 8624.81 4749.34 5129.88 5965155.57 696726.99 -6294.30 12.56 1.26 KOP 11775.00 82.96 91.28 8626.77 4749.13 5144.75 5965155.74 696741.85 -6308.46 9.00 45.00 MWD 11780.00 83.27 91.60 8627.37 4749.01 5149.71 5965155.74 696746.82 -6313.17 9.00 44.87 3 11800.00 84.75 97.03 8629.46 4747.51 5169.54 5965154.75 696766.68 -6331.69 28.00 75.00 MWD 11825.00 86.66 103.79 8631.33 4743.01 5194.04 5965150.88 696791.28 -6353.81 28.00 74.43 MWD 11830.00 87.05 105.13 8631.61 4741.76 5198.88 5965149.75 696796.15 -6358.07 28.00 73.93 4 11850.00 86.93 110.74 8632.66 4735.61 5217.87 5965144.09 696815.29 -6374.43 28.00 91.40 MWD 11875.00 86.82 117.75 8634.03 4725.37 5240.62 5965134.43 696838.29 -6393.19 28.00 91.11 MWD 11900.00 86.75 124.76 8635.43 4712.42 5261.94 5965122.04 696859.94 -6409.80 28.00 90.72 MWD 11925.00 86.74 131.77 8636.85 4696.98 5281.53 5965107.10 696879.91 -6424.01 28.00 90.33 MWD 11950.00 86.77 138.78 8638.27 4679.25 5299.08 5965089.83 696897.91 -6435.62 28.00 89.93 MWD 11975.00 86.85 145.79 8639.66 4659.52 5314.34 5965070.49 696913.66 -6444.44 28.00 89.53 MWD 12000.00 86.98 152.80 8641.01 4638.07 5327.08 5965049.37 696926.94 -6450.35 28.00 89.14 MWD 12025.00 87.15 159.81 8642.29 4615.22 5337.10 5965026.79 696937.55 -6453.26 28.00 88.76 MWD 12050.00 87.37 166.81 8643.49 4591.31 5344.27 5965003.07 696945.32 -6453.12 28.00 88.40 MWD 12075.00 87.62 173.82 8644.58 4566.71 5348.47 5964978.59 696950.15 -6449.94 28.00 88.07 MWD 12100.00 87.91 180.82 8645.56 4541.77 5349.64 5964953.69 696951.95 -6443.77 28.00 87.76 MWD 12125.00 88.23 187.81 8646.40 4516.87 5347.76 5964928.75 696950.71 -6434.69 28.00 87.49 MWD 12150.00 88.58 194.81 8647.09 4492.38 5342.86 5964904.14 696946.44 -6422.85 28.00 87.25 MWD 12175.00 88.95 201.80 8647.63 4468.67 5335.02 5964880.24 696939.20 -6408.42 28.00 87.06 MWD 12200.00 89.33 208.79 8648.01 4446.08 5324.35 5964857.39 696929.11 -6391.61 28.00 86.91 MWD 12225.00 89.73 215.78 8648.21 4424.96 5311.00 5964835.93 696916.31 -6372.67 28.00 86.80 MWD 12242.05 90.00 220.54 8648.25 4411.56 5300.47 5964822.27 696906.13 -6358.68 28.00 86.75 5 12250.00 90.00 221.50 8648.25 4405.56 5295.25 5964816.14 696901.06 -6351.94 12.00 90.00 MWD ObP . BP-GDB . IGíì. BAICD. IIIUGHIS Baker Hughes INTEQ Planning Report ,- I,NIltQ Company: BP Amoco Date: 3/31/2004 Time: 11 :27:23 Page: 3 )<'ield: Prudhoe Bay Co-ordinate(NE) Reference: Well: 18-33, True North Site: PB DS 18 Vertical (TVD) Reference: System: Mean Sea Level Well: 18-33 Section (VS) Reference: Well (0.00N,0.00E,253.00Azi) Wellpath: Plan#3 18-33A Survey Calculation Method: Minimum Curvature Dh: Oracle ~~ ,______'m."._ Survey --~- "---'-~--~--~-------'--- MD IDcI Azim Sys TVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 12275.00 90.00 224.50 8648.25 4387.28 5278.21 5964797.43 696884.49 -6330.29 12.00 90.00 MWD 12300.00 90.00 227.50 8648.25 4369.91 5260.22 5964779.61 696866.96 -6308.02 12.00 90.00 MWD 12325.00 90.00 230.50 8648.25 4353.51 5241.36 5964762.74 696848.52 -6285.18 12.00 90.00 MWD 12350.00 90.00 233.50 8648.25 4338.12 5221.66 5964746.85 696829.22 -6261.84 12.00 90.00 MWD 12375.00 90.00 236.50 8648.25 4323.78 5201.19 5964731.99 696809.12 -6238.07 12.00 90.00 MWD 12400.00 90.00 239.50 8648.25 4310.53 5179.99 5964 718.21 696788.27 -6213.93 12.00 90.00 MWD 12425.00 90.00 242.50 8648.25 4298.41 5158.13 5964705.54 696766.72 -6189.48 12.00 90.00 MWD 12450.00 90.00 245.50 8648.25 4287.45 5135.66 5964694.01 696744.54 -6164.79 12.00 90.00 MWD 12475.00 90.00 248.50 8648.25 4277.69 5112.65 5964683.66 696721.79 -6139.93 12.00 90.00 MWD 12500.00 90.00 251.50 8648.25 4269.13 5089.16 5964674.51 696698.53 -6114.96 12.00 90.00 MWD 12525.00 90.00 254.50 8648.25 4261.83 5065.26 5964666.59 696674.82 -6089.97 12.00 90.00 MWD 12550.00 90.00 257.50 8648.25 4255.78 5041.00 5964659.93 696650.73 -6065.00 12.00 90.00 MWD 12575.00 90.00 260.50 8648.25 4251.01 5016.46 5964654.53 696626.32 -6040.14 12.00 90.00 MWD 12600.00 90.00 263.50 8648.25 4247.53 4991.71 5964650.42 696601.67 -6015.45 12.00 90.00 MWD 12625.00 90.00 266.50 8648.25 4245.35 4966.81 5964647.61 696576.83 -5991.00 12.00 90.00 MWD 12650.00 90.00 269.50 8648.25 4244.47 4941.83 5964646.10 696551.88 -5966.86 12.00 90.00 MWD 12675.00 90.00 272.50 8648.25 4244.91 4916.83 5964645.90 696526.89 -5943.08 12.00 90.00 MWD 12700.00 90.00 275.50 8648.25 4246.65 4891.90 5964647.00 696501.92 -5919.75 12.00 90.00 MWD 12725.00 90.00 278.50 8648.25 4249.69 4867.09 5964649.41 696477.04 -5896.91 12.00 90.00 MWD 12729.05 90.00 278.98 8648.25 4250.31 4863.09 5964649.93 696473.02 -5893.26 12.00 90.00 6 12750.00 89.96 276.47 8648.26 4253.13 4842.33 5964652.21 696452.20 -5874.23 12.00 269.00 MWD 12775.00 89.90 273.47 8648.29 4255.29 4817.42 5964653.74 696427.25 -5851.05 12.00 269.00 MWD 12800.00 89.85 270.47 8648.34 4256.15 4792.44 5964653.96 696402.25 -5827.41 12.00 269.00 MWD 12825.00 89.80 267.47 8648.42 4255.70 4767.45 5964652.88 696377.28 -5803.38 12.00 269.01 MWD 12850.00 89.75 264.47 8648.52 4253.94 4742.51 5964650.48 696352.40 -5779.02 12.00 269.02 MWD 12875.00 89.70 261.47 8648.64 4250.89 4717.70 5964646.79 696327.68 -5754.40 12.00 269.03 MWD 12900.00 89.65 258.47 8648.78 4246.53 4693.09 5964641.81 696303.18 -5729.59 12.00 269.05 MWD 12925.00 89.60 255.47 8648.94 4240.90 4668.73 5964635.56 696278.98 -5704.65 12.00 269.06 MWD 12950.00 89.55 252.47 8649.13 4233.99 4644.71 5964628.05 696255.15 -5679.66 12.00 269.08 MWD 12975.00 89.51 249.47 8649.33 4225.85 4621.08 5964619.30 696231.73 -5654.68 12.00 269.11 MWD 12979.05 89.50 248.99 8649.37 4224.41 4617.30 5964617.77 696227.99 -5650.64 12.00 269.13 7 13000.00 89.50 251.50 8649.55 4217.33 4597.58 5964610.19 696208.46 -5629.71 12.00 90.00 MWD 13025.00 89.50 254.50 8649.77 4210.02 4573.67 5964602.27 696184.75 -5604.72 12.00 89.98 MWD 13050.00 89.51 257.50 8649.99 4203.97 4549.42 5964595.61 696160.66 -5579.76 12.00 89.95 MWD 13075.00 89.51 260.50 8650.20 4199.21 4524.88 5964590.21 696136.25 -5554.90 12.00 89.93 MWD 13100.00 89.52 263.50 8650.41 4195.73 4500.13 5964586.11 696111.60 -5530.21 12.00 89.90 MWD 13125.00 89.52 266.50 8650.62 4193.55 4475.23 5964583.29 696086.76 -5505.76 12.00 89.87 MWD 13150.00 89.53 269.50 8650.83 4192.68 4450.25 5964581.79 696061.81 -5481.61 12.00 89.85 MWD 13175.00 89.54 272.50 8651.03 4193.11 4425.26 5964581.58 696036.82 -5457.84 12.00 89.82 MWD 13200.00 89.55 275.50 8651.23 4194.86 4400.32 5964582.69 696011.85 -5434.51 12.00 89.80 MWD 13225.00 89.56 278.50 8651.42 4197.91 4375.51 5964585.11 695986.97 -5411.67 12.00 89.78 MWD 13250.00 89.58 281.50 8651.61 4202.25 4350.89 5964588.82 695962.25 -5389.40 12.00 89.75 MWD 13259.05 89.58 282.59 8651.68 4204.13 4342.05 5964590.48 695953.36 -5381.49 12.00 89.73 8 13275.00 89.62 280.67 8651.79 4207.35 4326.42 5964593.29 695937.66 -5367.49 12.00 271.00 MWD 13300.00 89.67 277 .67 8651.94 4211.34 4301.74 5964596.65 695912.89 -5345.05 12.00 271.01 MWD 13325.00 89.73 274.67 8652.07 4214.02 4276.89 5964598.70 695887.98 -5322.07 12.00 271.03 MWD 13350.00 89.78 271.67 8652.18 4215.41 4251.93 5964599.45 695862.99 -5298.61 12.00 271.05 MWD 13375.00 89.84 268.68 8652.27 4215.48 4226.94 5964598.89 695838.01 -5274.73 12.00 271.06 MWD 13400.00 89.89 265.68 8652.32 4214.25 4201.97 5964597.02 695813.08 -5250.49 12.00 271.07 MWD 13425.00 89.95 262.68 8652.36 4211.72 4177.10 5964593.85 695788.29 -5225.97 12.00 271.08 MWD 13450.00 90.01 259.68 8652.37 4207.88 4152.40 5964589.39 695763.69 -5201.23 12.00 271.08 MWD 13475.00 90.06 256.68 8652.35 4202.76 4127.93 5964583.64 695739.36 -5176.33 12.00 271.08 MWD 13484.05 90.08 255.59 8652.34 4200.59 4119.15 5964581.25 695730.64 -5167.30 12.00 271.08 9 ObP . BP-GDB . Bíi. BAKDt. ...... Baker Hughes INTEQ Planning Report IN'r EQ Company: BP Amoco Date: 3/31/2004 TÎlne: 11 :27;23 Page: 4 Field: Prudhoe Bay Co-ordlnate(NE) Reference: Well; 18-33, True North Site: PB DS 18 Yertical(fVD)Reference: System: Mean Sea level Well: 18-33 Section (YS) Reference: Well (0.ooN,0.00E,253.00Azi) Wellpath: Plan#3 18-33A Survey Caleutation Method: Minimum Curvature Db: Oracle Survey MD Inel Azlm Sys TVD EIW MapN MapE YS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/10OO deg 13500.00 90.08 257.51 8652.32 4196.88 4103.64 5964577.15 695715.23 -5151.38 12.00 90.20 MWD 13525.00 90.07 260.51 8652.29 4192.11 4079.10 5964571.76 695690.82 -5126.52 12.00 90.20 MWD 13550.00 90.05 263.51 8652.26 4188.64 4054.34 5964567.65 695666.16 -5101.83 12.00 90.21 MWD 13575.00 90.04 266.51 8652.24 4186.46 4029.44 5964564.84 695641.33 -5077.38 12.00 90.21 MWD 13600.00 90.03 269.51 8652.23 4185.59 4004.46 5964563.33 695616.38 -5053.23 12.00 90.21 MWD 13625.00 90.02 272.51 8652.21 4186.03 3979.47 5964563.13 695591.38 -5029.46 12.00 90.21 MWO 13650.00 90.01 275.51 8652.21 4187.78 3954.53 5964564.24 695566.41 -5006.12 12.00 90.22 MWO 13675.00 90.00 278.51 8652.20 4190.83 3929.72 5964566.66 695541.53 -4983.29 12.00 90.22 MWD 13700.00 89.99 281.51 8652.21 4195.17 3905.10 5964570.37 695516.81 -4961.02 12.00 90.22 MWO 13725.00 89.98 284.51 8652.22 4200.80 3880.75 5964575.37 695492.32 -4939.37 12.00 90.22 MWD 13750.00 89.96 287.51 8652.23 4207.69 3856.72 5964581.65 695468.13 -4918.41 12.00 90.22 MWO 13775.00 89.95 290.51 8652.25 4215.83 3833.08 5964589.19 695444.29 -4898.19 12.00 90.21 MWD 13800.00 89.94 293.51 8652.27 4225.20 3809.91 5964597.96 695420.89 -4878.76 12.00 90.21 TO p 055267 DATE INVOICE I CREDIT MEMO DESCRIPTION PERMIT TO DRILL PPLlCATIONS GROSS Ii; DATE 3/2/2004 CHECK NO. 055267 VENDOR DISCOUNT NET 3/2/2004 PR0226041 POUCH TO TERRI UBBLE MB7-5 75LL í5"~3A P.ECE.\ E.O '2 ~ 'L\)\\~ þ.?R CO\1\O\\SS\O{\ . &. Gas C "s. þ.\as¥.3 IJ\\ þ.\\C" ta\\e TOTAL ... THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 PAY: TO THE ORDER OF: B.···.·..·. ....p>.... r;~ "II'" ..1111) ,.11\', " ',' or.· ..... ..'~ .:J..i ,. ttu..r (tUttI STATE OFALASKA AOGCC 333 WEST7THAVENUE SUITE 100 ANCHORAGE AK 99501 NATIONAL CITY BANK Ashland, Ohio 1110 5 5 2 ¡; ? III !: 0 ~ ¡. 2 0 j 8 q 5 I: 0 ¡. 2 ? 8 q ¡; liD ~ 412 No. P 055267 CONSOLIDATED COMMERCIAL ACCOUNT DATE AMOUNT 3/2/2004 I.. ....1 **1'***$100.00***1 NqTV~fTE.R 1~O D~Y~ .' . '. , " ~I':"':':'\:'~ .'.'~:.: :~·"~;~~~~?::::.:::·:iSf··" ../-}:.~;~~:::; ,t· ,: '. \;' :.,] , '. .e._,_ ,{" . ...._.. .........~~H..j...'··H.. .""'''j ill~;;;~. '''{f:¡f'~{;.;;:i'·>:~Ij·j H . . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME Pßo¡ . /t- :5 3A PTD# 2.0 t.¡ -¿;? /1"""") x Exploration Stratigraphic Development Service CHECK WHAT ADD-ONS "CLUE". APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well . Permit No, API No. . (If API number Production should continue to be reported as last two (2) digits a function' of the original API number. stated are hetween 60-69) above. Pfi,OT HOLE In accordance with 20 AAC 25.005(1), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) .' and API Dum ber (SO - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.05S~ Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. DRY DITCH All dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' sample intervals from below tbe permafrost or from wbere samples are first caught and ] 0' sample intervals tbrougb target zones. Geologic Commissioner: Date: ~(v Engineering Commissioner: Date 35 36 37 38 39 Conta~ct l1am~elphoneJor we~kly prpgre!1sreport$ No~ ~NA NA NA NA Appr RPC Date 4/23/2004 ~S~abed ~cpnditi.oo $urvey ~(if Off-!;h~ore) ~S~tsmlcanalysjs~ of sbaJlow gaszooes P~rmit ~D~atapreseoted on pote~ntial oveJPres~sure ~ZOnes Geology Appr WGA Date 4/26/2004 8 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 cao be iS$l!ed wlo hydrogen s~ulfide measures J!1 pre!;eoce~ of MecbanicaLcoodJt[oo of well$ within .l\OR yerified (Forservjce W~IJ onJy) H2S gas probable p!¡ig CMkeruanifold compJies w/API RF'-53 (May 84) Work will Occur withoyLoperation ~sbutdown ~BOPEs,dothey meet reguJatioo BOPE~press raiiog appropriate; ~test to ~(put in ~comment!;) Jtdjv~rter required, does it me~t reguJations~ Drilliog fluid~ program $chematic~& equip Ji$Ladequale Adequate well bore !;eparatJo~n propo!¡ed Adequate tan~kage~ OJ Rue-drill. bas~a~ to-4~03 fOJ abandonme~nt be!:m apPJQved re~serye pit ~C~a$iog deslgo!¡ ad~eçya-'e for CMT vol ad~Qu~ate~ to tie-inJQngstriog to~surf Ç!;g~ ~CMT will COyer ~all KnOwn ~pro~ductiye borizon~s known USQW!¡ ~CMT vol ad~Ql!ate~ to çirculateo~n ~cond~uctor ~C90du~ctor string SUrfac~ca!;ing prQtect!; all & $uJfcsg NA NA NA NA Y~$ Y~$ Y~$ Ye$ ~Y~$ NA ~Y~$ Y~$ Y~$ Y~$ Y~$ No~ NA Test lo ~3500~ psLMSF' 2488 psi. Sidetraçk. Max MW~8~ I RP9· CTQU. * CJ, B ~&~ perruafr~o$t Engineering . Appr RPC Date 4/23/2004 ~Unique wellnam~~aod oumb~er locat~d Administration 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 PJovid~d ~AII.w~lJs~withtn.1l4~ruile~area~of reyi~w id~ot[fi~d (For !;efVjc~ew.e[l Only) Pre-produçed ioj~ctor; duratioRof pr~-production I~$!; tban~ 3 montbs~ (For~s~rvtce well only) ACMP~ F'indjngof CQl1sisteocy~ h~as bee~n J!;sued~ for tbis proieçt P~rmit cao be iS$ued witbout admini!¡tratÏ\le~approvaJ Can permit be approved before 15-day wait WelUocated within area and~strata ~autborized byJojectioo Ord~r # (puUO# in~commeots) (For js weJlbore platincluded Operator only: affected party ~ ~ ~ ~Oper~ator bas~appropriate_bo!1d tnJQr~ P~rmit c_ao be issued witbQut co_nserva_tion order _S_utficient Jfdeviated, acr~a9-e_ayailable from Qtber w~lJs in~drilliog unjt Well Well Well IQcated proper distaoce~ locat~d proper ~dista!1ce_ from driJli!1g unilboundafY_ P~rmit fee attache_d Leas~ ~number _apprOPJiat~ Field & Pool in_a defined pool PRUDHOE BAY, PRUDHOE OIL - 640150 NC nitial ClasslType Y~s Y~s Y~$ _Y~$ Ye$ Y~$ Y~$ Y~$ Y~$ Y~$ Y~$ Y~$ Yes NA _NA NA NA Well Name: PRUDHOE BAY ~NII 11-01L GeoArea 890 t8-33A Unit ll650 Program On/Off Shore On Well bore seg 0 Annular Disposal 0 e e 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. e e **** REEL HEADER **** MWD 04/12/30 # BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/06/18 701576 01 3.125" CTK *** LIS COMMENT RECORD *** Remark File Version 1.000 Extract File: 1dwg.1as !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 11743.5000: STOP.FT 13445.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NYUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 18 TOWN.N 11N RANG. 15E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 54 DMF KB EKB .F 54 EDF .F N/A EGL .F N/A CASE.F N/A OSl . DIRECTIONAL -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data (GRAX) presented is real time data. (4) Baker Hughes INTEQ utilized CoilTrak downhole tools and ADVANTAGE surface system. 1. 20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska), Inc. 18-33A Prudhoe Bay 70deg 17'45.680" N, 148deg 26'50.778" W North Slope Alaska Baker Hughes INTEQ 3.125" CoilTrak - Gamma Ray 18-June-04 500292259801 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 /)0 f-o 70 c:::::"< ( po \ -¡.. e e (5) Tools run in the string included Casing Coil Locator, Electric Disconnect and Circulating sub, a Drilling Performance Sub, (inner and outer downhole pressure, and downhole weight on bit), Ultra Slim Resistivity Sub, a Gamma and Directional Sub, and Hydraulic Orienting Sub with near bit inclination sensor. (6) Data presented here is final and was depth shifted to a PDC (Primary Depth Control) logged by SWS on June 21, 2004. (7) The sidetrack was drilled from milled window in 4 1/2" liner. Top of window: 11760' MD (8624.8' SSTVD). Bottom of window: 11768.4' MD (8625.7' SSTVD). (8) Open hole sidetrack from 18-33PBl at 12400' MD (8648' SSTVD). (9) The interval from 13415' MD (8644' SSTVD) to 13445' MD (8644' SSTVD) was not logged due to bit to sensor offset. (10) Tied in to 18-33 at 11673'MD (8610' SSTVD). MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROP -> Rate of Penetration, feet/hour RACLX -> Compensated Attenuation Resistivity Borehole Corrected (LS) [MWD] (400kHz), ohm-m RACHX -> Compensated Attenuation Resistivity Borehole Corrected (LS) [MWD] (2MHz), ohm-m RPCLX -> Compensated Phase Difference Resistivity Borehole Corrected (LS) [MWD] (400kHz), ohm-m RPCHX -> Compensated Phase Difference Resistivity Borehole Corrected (LS) [MWD] (2MHz), ohm-m TVD -> Subsea True Vertical Depth, feet CURVE SHIFT DATA BASELINE, MEASURED, 11759.2, 11760.4, 11760.4, 11760.8, 11764.6, 11766, 11951.8, 11953.7, 12201.5,12204.2, 12331.9, 12332.7, 12435.6, 12440.6, 12451.8, 12455.2, 12455.6, 12460.2, 12465.3, 12470.5, 12469.2, 12474.6, 12471.7, 12477.1, 12487.1, 12491, 12492.3, 12498.1, 12497.6, 12501.6, 12500.3, 12504.5, 12507.1, 12510.2, 12520.8, 12525.2, 12545.4, 12547.1, 12559.8, 12561.4, 12581.3, 12583.1, 12587.5, 12587.3, 12635.6, 12635.8, 12636.7, 12637.9, 12645.4, 12643.9, 12653.9, 12652.4, 12662.6, 12661.8, 12709.6, 12709.2, 12730.2, 12729.1, 12735.2, 12734.1, 12749.1,12749.1, 12758.2,12759.5, 12765.5, 12762.6, 12812.7, 12809.4, 12820.2,12820, 12827, 12826, 12893.7, 12893.3, 12906.2, 12909.1, 12914.5, 12916.8, 13318.3, 13317.7, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 DISPLACEMENT 1.24707 0.416016 1. 45508 1.87012 2.70117 0.831055 4.9873 3.3252 4.57227 5.19531 5.40332 5.40332 3.94824 5.81836 3.94824 4.15625 3.11719 4.36328 1.66211 1.66211 1.87012 -0.208008 0.208008 1.24707 -1.45508 -1.4541 -0.831055 -0.415039 -1.03906 -1.03906 o 1. 24609 -2.91016 -3.3252 -0.208008 -1.03906 -0.415039 2.90918 2.28613 -0.623047 112 records... e e Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT 18-33a 5.xtf 150 BP Exploration (Alaska) Inc. 18-33A Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 21-June-04 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM OOEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 RAD RAO RACLX 0.0 RAS RAS RACHX 0.0 RPD RPO RPCLX 0.0 RPS RPS RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 e e 5 6 RPD RPS MWD MWD 68 68 1 1 OHMM OHMM 4 4 4 4 ------- 24 Total Data Records: 95 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11743.500000 13444.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 108 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 18-33a.xtf 150 BP Exploration (Alaska) 18-33A Prudhoe Bay North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 ROPS ROPS ROPA 0.0 RACL RACL RACLX 0.0 RACH RACH RACHX 0.0 RPCL RPCL RPCLX 0.0 RPCH RPCH RPCHX 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) e e Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 AAPI 4 4 2 ROPS MWD 68 1 F/HR 4 4 3 RACL MWD 68 1 OHMM 4 4 4 RACH MWD 68 1 OHMM 4 4 5 RPCL MWD 68 1 OHMM 4 4 6 RPCH MWD 68 1 OHMM 4 4 ------- 24 Total Data Records: 190 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 11742.250000 13443.750000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 203 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/06/18 701576 01 **** REEL TRAILER **** MWD 04/12/30 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes e e rape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 11743.5000 48.5557 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11744.0000 48.0990 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11800.0000 56.8356 41. 6207 2213.0000 6200.2695 112.6900 102.4590 11900.0000 60.3459 58.9177 2213.0000 6200.2695 192.3863 187.5300 12000.0000 56.5126 44.8592 2213.0000 6200.2695 212.6300 226.3400 12100.0000 58.2075 92.6569 2213.0000 6200.2695 176.2013 177.1800 12200.0000 61.6687 178.5811 417.0914 6200.2695 187.6278 204.6649 12300.0000 64.6262 169.1566 41. 6048 152.6081 108.2600 167.8200 12400.0000 64.5265 204.1603 194.9391 6200.2695 205.9485 225.5653 12500.0000 68.7350 90.3303 2213.0000 6200.2695 288.8500 200.7729 12600.0000 39.2369 93.9025 2213.0000 6200.2695 318.4700 225.9402 12700.0000 62.7821 146.4257 2213.0000 6200.2695 459.3506 258.2704 12800.0000 79.3896 131.0057 2213.0000 6200.2695 232.6839 189.8930 12900.0000 61.6996 158.9324 2213.0000 6200.2695 243.0300 196.3143 13000.0000 59.4761 138.2206 2213.0000 6200.2695 195.6200 165.8400 13100.0000 61.4259 173.7527 2213.0000 6200.2695 209.3200 165.8400 13200.0000 70.6320 117.5054 2213.0000 6200.2695 238.5469 174.9900 13300.0000 60.6008 180.9790 2213.0000 6200.2695 217.3724 165.9699 13400.0000 65.8548 133.9722 2213.0000 6200.2695 195.6200 150.4147 13444.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 11743.500000 Tape File End Depth 13444.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet .. e e Tape Subfile 3 is type: LIS DEPTH GRAX ROPS RACL RACH RPCL RPCH 11742.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11742.5000 48.5557 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11800.0000 58.9505 43.0700 2213.0000 6200.2695 112.6900 100.0500 11900.0000 57.0210 49.3100 2213.0000 6200.2695 188.5660 187.5300 12000.0000 55.8353 44.3100 2213.0000 6200.2695 223.3967 237.2466 12100.0000 59.6847 93.0400 2213.0000 6200.2695 183.8700 177.1800 12200.0000 56.3987 183.4100 257.4400 6200.2695 186.0800 211.8900 12300.0000 63.6719 172.5500 42.7667 166.6433 108.2600 167.8200 12400.0000 63.8608 191.7720 80.0200 6200.2695 200.6600 201.0400 12500.0000 78.7215 83.9700 2213.0000 6200.2695 276.4600 202.5900 12600.0000 37.7889 97.9200 2213.0000 6200.2695 318.4700 238.8000 12700.0000 62.6848 128.1800 2213.0000 6200.2695 532.8099 301.8400 12800.0000 82.5670 138.9800 2213.0000 6200.2695 224.9800 196.3300 12900.0000 64.7239 162.1900 2213.0000 6200.2695 243.0300 185.1000 13000.0000 59.1236 152.5900 2213.0000 6200.2695 195.6200 165.8400 13100.0000 60.1335 149.5600 2213.0000 6200.2695 209.3200 165.8400 13200.0000 70.7108 117.5200 2213.0000 6200.2695 238.5175 174.9900 13300.0000 63.0959 181.0800 2213.0000 6200.2695 217.1500 170.4150 13400.0000 64.1917 133.2000 2213.0000 6200.2695 195.6200 151.8100 13443.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth 11742.250000 Tape File End Depth 13443.750000 Tape File Level Spacing 0.250000 Tape File Depth Units feet