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201-105
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: 5/08/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250508 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 241-26 50283201970000 224068 4/15/2025 AK E-LINE Perf BRU 244-27 50283201850000 222038 4/19/2025 AK E-LINE Perf IRU 11-06 50283201300000 208184 4/14/2025 AK E-LINE CIBP PBU S-22B 50029221190200 197051 4/15/2025 AK E-LINE IPROF SRU 231-33 50133101630100 223008 4/13/2025 AK E-LINE CIBP PBU 14-33B 50029210020200 223067 1/22/2025 BAKER MRPM END 1-65A 50029226270100 203312 4/15/2025 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON LDL END 2-72 50029237810000 224016 4/11/2025 HALLIBURTON MFC40 MPU R-105 50029238150000 225017 4/20/2025 HALLIBURTON CAST-CBL NS-19 50029231220000 202207 4/12/2025 HALLIBURTON RBT PBU 06-12B 50029204560200 211115 3/22/2025 HALLIBURTON RBT PBU 07-22A 50029209250200 212085 3/31/2025 HALLIBURTON RBT PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG PBU H-17A 50029208620100 197152 4/10/2025 HALLIBURTON RBT-COILFLAG PBU H-29B 50029218130200 225005 5/1/2025 HALLIBURTON RBT PBU J-10B 50029204440200 215112 4/15/2025 HALLIBURTON RBT PBU M-207 50029238070000 224141 4/21/2025 HALLIBURTON IPROF PBU Z-25 50029219020000 188159 4/23/2025 HALLIBURTON IPROF PBU Z-31 50029218710000 188112 4/25/2025 HALLIBURTON IPROF Please include current contact information if different from above. T40372 T40373 T40374 T40375 T40376 T40377 T40378 T40379 T40379 T40380 T40381 T40382 T40383 T40384 T40385 T40386 T40387 T40388 T40389 T40390 PBU B-30B 50029215420100 201105 4/9/2025 HALLIBURTON RBT-COILFLAG Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.08 12:42:44 -08'00' 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: 4/02/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250402 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BCU 19RD 50133205790100 219188 3/20/2025 YELLOWJACKET GPT-PERF BCU 19RD 50133205790100 219188 3/16/2025 YELLOWJACKET PLUG BRU 212-26 50283201820000 220058 3/21/2025 AK E-LINE Perf BRU 212-26 50283201820000 220058 3/15/2025 AK E-LINE Perf CLU 7 50133205310000 203191 1/22/2025 YELLOWJACKET PLUG IRU 11-06 50283201300000 208184 3/20/2025 AK E-LINE Perf KALOTSA 10 50133207320000 224147 3/1/2025 YELLOWJACKET GPT-PLUG-PERF KBU 22-06Y 50133206500000 215044 1/25/2025 YELLOWJACKET GPT-PLUG-PERF KU 13-06A 50133207160000 223112 3/18/2025 AK E-LINE CIBP MPE-20A 50029225610100 204054 3/13/2025 READ CaliperSurvey MPI 1-39A 50029218270100 206187 3/4/2025 YELLOWJACKET PERF MPU C-01 50029206630000 181143 1/30/2025 YELLOWJACKET PERF MPU K-17 50029226470000 196028 2/7/2025 AK E-LINE Caliper MPU S-53 50029238110000 224159 3/7/2025 YELLOWJACKET SCBL MRU A-15RD2 50733201050200 202019 3/10/2025 AK E-LINE TubingCut PBU 18-27E 50029223210500 212131 3/15/2025 YELLOWJACKET RCT PBU B-30A 50029215420100 201105 3/7/2025 READ CaliperSurvey PBU S-10A 50029207650100 191123 11/18/2024 YELLOWJACKET CBL-TEMP PBU W-220A 50029234320100 224161 2/22/2025 YELLOWJACKET SCBL Revision explanation: Fixed API# on log and .las files Please include current contact information if different from above. T40256 T40256 T40257 T40257 T40258 T40259 T40260 T40261 T40262 T40263 T40264 T40265 T40266 T40267 T40268 T40269 T40270 T40271 T40272 PBU B-30A 50029215420100 201105 3/7/2025 READ CaliperSurvey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.02 12:55:27 -08'00' 9810, 11870, 12200 By Grace Christianson at 3:34 pm, Jan 30, 2025 325-050 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.30 14:19:15 - 09'00' Sean McLaughlin (4311) A.Dewhurst 20FEB25JJL 2/24/25 10-407 *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 and 25’ feet of cement on top of the RBP at 9810' in B-30A *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. DSR-1/31/25*&: 2/24/2025Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.24 15:21:43 -09'00' RBDMS JSB 022625 To: Alaska Oil & Gas Conservation Commission From:Ryan Ciolkosz Drilling Engineer Date: January 30, 2025 Re:B-30 Sundry Request Sundry approval is requested to set a whipstock and mill a window in the B-30 wellbore as part of the drilling and completion of the proposed B-30B CTD lateral. Proposed plan: Slickline will run a whipstock drift. E-line will set a 4-1/2" whipstock. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. A coil tubing drilling sidetrack will be drilled with the Nabors CDR2/CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2" whipstock. A dual string 3.80" window + 10' of formation will be milled. The well will kick off drilling Ivishak Zone 4. The lateral will continue in Zone 4, 3 and 2 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 completely isolate and abandon the parent Ivishak perfs. This Sundry covers plugging the existing perforations via the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). 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 in March 1st, 2025) x Reference B-30 Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift, set DMGLV's, & caliper liner across whipstock target depth(Send caliper data to ODE and Whipstock Vendor) 2. E-Line : Set 4-1/2" Baker Whipstock TOWS at 9615' @ 180 deg ROHS 3. Valve Shop : Pre-CTD Tree Work 4. Operations : Remove wellhouse and level pad. Rig Work: (Estimated to start in March 18, 2025) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,451 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” - 4-1/2"x7" Dual String Window. 3. Drill build section: 4.25" OH, ~712' (26 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~2252' (12 deg DLS planned). Swap to KWF for liner. 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 36 bbls, 14.8 ppg Class G (1.33 ft3/sk yeild), 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. * Approved alternate plug placement per 20 AAC 25.112(i) *dump 25’ feet of cement on top of the RBP at 9810' Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : Liner Lap test, Post rig RPM (rush process), CBL, Perforate ~40' of 2" guns 3. Slickline : Contingent LTP set (dependent on Liner lap test) & set GLV's Ryan Ciolkosz CC: Well File Drilling Engineer Joe Lastufka 907-244-4357 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 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 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Ryan Ciolkosz To:Lau, Jack J (OGC) Cc:Joseph Lastufka Subject:RE: [EXTERNAL] PBU B-30A (201-105) Date:Monday, February 24, 2025 1:27:24 PM Attachments:image001.png Sounds good, thanks. Ryan Ciolkosz Drilling Engineer | C: 907.244.4357 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, February 24, 2025 11:10 AM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] PBU B-30A (201-105) I can write it into the sundry. Probably the simplest way forward. Jack From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Sent: Monday, February 24, 2025 11:03 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] PBU B-30A (201-105) Thanks Jack, Is there anything we need to on our end to update the permit/sundry or can you just write that in on your end? Ryan Ciolkosz Drilling Engineer | C: 907.244.4357 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, February 24, 2025 10:32 AM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] PBU B-30A (201-105) Sounds like a good plan From: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> Sent: Monday, February 24, 2025 10:31 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: RE: [EXTERNAL] PBU B-30A (201-105) Jack, Following up on our discussion last week regarding B-30A, we would prefer to maintain a low liner lap for future CTD sidetracks. Additionally, to further support the variance to 112 for the abandonment of the parent bore, we propose dumping 25’ feet of cement on top of the RBP at 9810, in conjunction with the short, cemented liner lap and the multiple bridge plugs already installed. Let me know what you think. Thanks, Ryan Ciolkosz Drilling Engineer | C: 907.244.4357 3800 Centerpoint Dr. Suite 1400 | Anchorage, Alaska 99503 44.4357 | O: 907.564.4413 H From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Monday, February 10, 2025 4:26 PM To: Ryan Ciolkosz <Ryan.Ciolkosz@hilcorp.com> CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Subject: [EXTERNAL] PBU B-30A (201-105) Good afternoon Ryan – Reviewing the sundry for B-30A pre-CTD. The variance as per 20 AAC 25.112(i) is contingent on a good liner cement job with a minimum of 100’ of liner lap (typically to TOL). 1. Proposed TOL is at 9615’ only 25’ above the window. This should be 100’ per 20 AAC 25.030(d)(6). 2. Proposed whipstock is non-sealing. Wouldn't a non-sealing whipstock create a risk of cement loss below the whipstock, potentially compromising the integrity of the liner cement job? Note that if B-30A is cemented then both 1) and 2) above are acceptable. Jack Lau Senior Petroleum Engineer Alaska Oil and Gas Conservation Commission (907) 793-1244 Office (907) 227-2760 Cell The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT B-30A JBR 08/28/2024 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:3 2 3/8", 3.5", and 5.5" combo test joint used for testing. During test #2 Romeo #2 valve failed. The valve was serviced and retested for a fail due to the test pump failing to get over 5000 psi. At the very end of the high the test was bled off and it was discovered that the pressure had barely dropped below 5000 psi and couldn't be seen as the pin on the chart made it difficult to see. We went back up to the high and got a pass after adjusting the test pump to pressure up higher that 5000 psi. Test #7 the 3.5"x6" VBRs failed on the high. Cycled rams and retested for a fail. Pulled and checked the test joint and reinstalled after finding no issues. Possible leaking 4way valve issue. Test #8 the annular failed and again they are thinking it is a 4way valve issue. When I left the rig mechanic was troubleshooting to find the issue with both failures to see if they are accumulator problems or the annular seals leaking. Tested the flow paddle/sensor in addition to the micro motion flow sensor. The component passed. Left the rig to get ready to catch the plane home. I instructed the company reps that they are to contact me and let me know what the issue was with the rams and annular and not to proceed with well work until the problem is fixed and passes the tests UPDATE: I was contacted by the company rep and informed that the 4way valves the annular and VBRs Test Results TEST DATA Rig Rep:G. Coyne/R. FletcherOperator:Hilcorp North Slope, LLC Operator Rep:J. Perl/D. Johnson Rig Owner/Rig No.:Nabors CDR2AC PTD#:2011050 DATE:7/15/2024 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/5000 Rams: 250/5000 Test Pressures:Inspection No:bopGDC240713153220 Inspector Guy Cook Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9.5 MASP: 2520 Sundry No: 324-284 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 1 NT Lower Kelly 1 NT Ball Type 2 P Inside BOP 1 P FSV Misc 0 NA 12 PNo. Valves 1 PManual Chokes 1 PHydraulic Chokes 0 NACH Misc Stripper 1 2 3/8"P Annular Preventer 1 13 5/8" 5000 NT #1 Rams 1 2 3/8" Solids P #2 Rams 1 2 3/8" Solids P #3 Rams 1 3.5"x6" VBR NT #4 Rams 1 Blind/Shear P #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 2 1/16" 5000 P HCR Valves 2 2 1/16" 5000 P Kill Line Valves 2 2 1/16" 5000 FP Check Valve 0 NA BOP Misc 0 NA System Pressure NT Pressure After Closure NT 200 PSI Attained NT Full Pressure Attained NT Blind Switch Covers:NT Bottle precharge NT Nitgn Btls# &psi (avg)NT ACC Misc F2 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 NT #1 Rams NT #2 Rams NT #3 Rams NT #4 Rams NT #5 Rams NA0 #6 Rams NA0 HCR Choke NT HCR Kill NT 9 9 9 9 9999 9 9 9 9 )XOO5HPDUNVDWWDFKHG MEU FP 2 F Romeo #2 valve failed.serviced and retested for a fail 3.5"x6" VBRs failed on the high Cycled rams and retested for a fail When I left the rig mechanic was troubleshooting to find the issue with both failures BOPE Test Remarks Nabors CDR2AC PBU B-30A (PTD 2011050) AOGCC Inspect # bopGDC240713153220 2 3/8", 3.5", and 5.5" combo test joint used for testing. During test #2 Romeo #2 valve failed. The valve was serviced and retested for a fail due to the test pump failing to get over 5000 psi. At the verƅ end of the high the test was bled oƯ and it was discovered that the pressure had barely dropped below 5000 psi and couldn't be seen as the pin on the chart made it diƯicult to see. They went back up to the high and got a pass after adjusting the test pump to pressure up higher that 5000 psi. Test #7 the 3.5"x6" VBRs failed on the high. Cycled rams and retested for a fail. Pulled and checked the test joint and reinstalled after Ʊnding no issues. Possible leaking 4way valve issue. Test #8 the annular failed and again they are thinking it is a 4way valve issue. When I left the rig mechanic was troubleshooting to Ʊnd the issue with both failures to see if they are accumulator problems or the annular seals leaking. Tested the Ʋow paddle/sensor in addition to the micro motion Ʋow sensor. The component passed. Left the rig to get ready to catch the plane home. I instructed the company reps that they are to contact me and let me know what the issue was with the rams and annular and not to proceed with well work until the problem is Ʊxed and passes the tests. UPDATE: I was contacted by the company rep and informed that the 4way valves the annular and VBRs were bad and replaced to Ʊx the issue. The failures are captured in the ACC misc box of the Accumulator System section. 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 B-30A Tubing Swap RWO Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-105 50-029-21542-01-00 12859 Surface Intermediate Liner Liner Liner 9037 2636 9512 1510 1890 2457 9810 13-3/8" 9-5/8" 7" 5-1/2" x 4-1/2" 3-1/2" x 3-3/16" x 2-7/8" 8920 40 - 2676 36 - 9548 9308 - 10818 8955 - 10845 10412 - 12859 40 - 2676 36 - 8563 8418 - 9007 8210 - 9010 8910 - 9037 10400, 10855 2670 4760 7020 6120 10530 9810, 11870, 12200 5380 6870 8160 7740 10160 9618 - 12670 4-1/2" 12.6# L80 34 - 8960 8603 - 9033 Conductor 83 20" x 30" 42 - 125 42 - 125 4-1/2" HES TNT Packer 8838 8105 Torin Roschinger Operations Manager Michael Hibbert michael.hibbert@hilcorp.com 907-903-5990 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 0028310 34 - 8215 N/A N/A 714 798 58247 57056 14 173 2000 1300 1780 1300 324-284 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8838, 8105 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 9:12 am, Aug 13, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.08.12 19:54:25 - 08'00' Torin Roschinger (4662) DSR-8/14/24 RBDMS JSB 082024 ACTIVITY DATE SUMMARY 6/10/2024 ***WELL S/I ON ARRIVAL*** (rwo capital) MADE ATTEMPT TO PULL 5-1/2" KEYLESS X-CATCHER AT 9,099' MD RAN 10' x 3" PUMP BAILER TO CATCHER AT 9,099' MD (recovered ~1.5 gal plastic coating) ***CONTINUE ON 6/11/24 WSR*** 6/10/2024 T/I/O=250/0/0 (Assist slickline W/ load and test) Travel to location. Rig up and pressure test. Standby for slickline *Job continues to 6-11-24* 6/11/2024 ***CONTINUED FROM 6/10/24 WSR*** (rwo capital) BAILED PLASTIC COATING FROM CATCHER AT 9,099' MD (recovered ~1.5 gal plastic coating & hard plastic piece ~2"x2"x.75") PULLED 5-1/2" KEYLESS X-CATCHER AT 9,099' MD ATTEMPTED TO EQUALIZE XX-PLUG IN NIPPLE REDUCER AT 9,099' MD (no pressure change) BAILED ~2 GAL OF SANDY PLASTIC COATING FROM XX-PLUG AT 9,099' MD (also recovered rubber chunks & heavy duty coil/ springs) ***CONTINUE ON 6/12/24 WSR*** 6/11/2024 *Job continues from 6-10-24* (Assist Slickline) Standby for slickline *Job continues to 6-12-24* 6/12/2024 ***CONTINUED FROM 6/11/24 WSR*** (rwo capital) RAN 2.50" PUMP BAILER W/ SNORKEL BOTTOM TO XX-PLUG AT 9,099' MD (recovered rubber chunks) PULLED 2.75" XX PLUG f/ NIP REDUCER AT 9099' MD (recovered slip fish from 10/19/23) PULLED 4.56" x 2.75" NIP REDUCER AT 9099' MD T-BIRD LOADED TBG w/ 300 BBLS 1%KCL FOLLOWED BY 58 BBLS DIESEL FP SET 3.81" PX PLUG AT 9222' MD T-BIRD ATTEMPTED CMIT-TxIA TO 2500 psi (pressure rapidly falls off) SET 4-1/2" D&D HOLE FINDER ON PX PLUG AT 9,222' MD & AT 9,184' SLM (not holding) ***CONTINUE ON 6/13/24 WSR*** 6/12/2024 *Job continues from 6-11-24* (Assist Slickline) Pumped 294 bbls of 1% KCL down the TBG to load for slickline followed load with 58 bbls of DSL to freeze protect on top. Pumped 38 bbls of DSL down the TBG to attempt and pressure up against plug downhole. Unable to reach pressure, established LLR @ (.8 BPM). Pumped an additional 47 bbls of DSL down the TBG while slickline ran a D&D holefinder, again unable to maintain holding pressure. *Job continues to 6-13-24* 6/13/2024 ***CONTINUED FROM 6/12/24 WSR*** (rwo capital) 2 x RAN 5-1/2" D&D HOLE FINDER FROM 9,173' MD (failed tests - eq o-rings in hole finder cut each time) RAN 5-1/2" D&D HOLE FINDER (unable to get past SSD - failed test) PULLED 4-1/2" PX PLUG AT 9,222' MD SET 4-1/2" PX PLUG AT 9,222' MD (oversize pkg sandwich) T-BIRD PERFORMED FAILING CMIT-TxIA TO 2500 (see log - established llr ~.5 bpm at 2500 psi ) ***CONTINUED ON 6/14/24 WSR*** Daily Report of Well Operations PBU B-30A Daily Report of Well Operations PBU B-30A 6/13/2024 T/I/O 100/0/0 (TFS unit 1 assist SL with DND holefinder) Pumped a total of 99 bbls of DSL to assist SL in performing DND holefinder and establishing a LLR. Attempted to pressure the Tubing and IA to 2750 PSI for a CMIT. After being unable to Reach and Maintain Test Pressure. Rolled into a LLR. Established the Liquid Leak Rate of 0.45 BPM while assisting Slickline. Slick Line in control of well upon departure. FWHP = 500/0/0 6/13/2024 *Job continues from 6-12-24* (Assist Slickline) Pumped 20 bbls of DSL down the TBG to attempt to pressure up and hold pressure while slickline set a D&D hole finder in various spots. Unable to hold pressure. RDMO for unit swap with unit 1 Well left in control of slickline upon departure 6/14/2024 ***CONTINUED FROM 6/13/24 WSR*** (rwo capital) POLLARD #60 RIG DOWN ***WELL S/I ON DEPARTURE*** 6/17/2024 T/I/O= 400/0/0 Assist SL Pumped 19 bbls Crude Per Slick Line WSL down TBG to Help set plug *** Job continues to 6-18-2024*** 6/17/2024 ***WELL S/I ON ARRIVAL*** PULL & RESET PRONG IN PLUG BODY @ 9222' MD SET WHIDDON ON TOP OF PRONG AS JUNK CATCHER SET 4.56" PX PLUG BODY @ 9099' MD ON 3RD ATTEMPT. RAN CHECK SET TO PX PLUG BODY @ 9099' MD (SHEARED). ***WSR CONTINUED ON 6-18-24*** 6/18/2024 ***Continued from 6-17-2024*** Pumped 22 bbls Crude to help set plug and attempt to pressure up CMIT-TxIA ***PASSED*** to 2370/2395 psi. pumped 8.5 bbls crude to Reach Max Applied psi of 2500 with a target pressure of 2250 psi. 1st 15 min TxIA lost 75/80 psi. 2nd 15 min TxIA lost 19/20 psi. Total loss of 94/100 psi. Pumped A total of 37 bbls crude to Assist SL with CMIT-TxIA ***Job Continues to 6- 19-2024*** 6/18/2024 ***WSR CONTINUED FROM 6-17-24*** SET PRONG IN PX PLUG BODY @ 9099' MD. T-BIRD TO CMIT 2500 PSI (FAILED 5 TESTS). PULLED PRONG AND PX PLUG BODY FROM 9099' MD. RAN 3.80" CENT, 3' x 1.875" STEM, 4.50" CENT, 4.54" G RING THROUGH X NIPPLE @ 9099' MD W/ T-BIRD FLUSHING. SET NEW 4.56" PX PLUG BODY @ 9099' MD. SET PRONG IN PLUG BODY. T-BIRD TO CMIT 2500 PSI (PASSED). PULLED PRONG & PX PLUG BODY FROM 9099' MD. PULLED WHIDDON CATCHER FROM 9184' SLM. ***WSR CONTINUED ON 6-19-24*** 6/19/2024 ***Continued from 6-18-2024*** Assist SL, Pumped 30 bbls of crude down TBG to assist SL in setting plug. Tags hung on WV and IAC. SL in control of well upon departure. FWP= 100/100/0 6/19/2024 ***WSR CONTINUED FROM 6-18-24*** SET 4 1/2" EVO-TRIEVE PLUG @ 9185' SLM. T-BIRD ATTEMPTED CMIT; ESTABLISHED LLR OF .5 BBLS/MIN @ 2250 PSI. PULL EVO SET WHIDDON AS JUNK CATCHER ON TOP OF P PRONG @ 9222' MD TOP OF WHIDDON ~9208' MD. *** WELL LEFT S/I ON DEPARTURE. JOB COMPLETE *** Daily Report of Well Operations PBU B-30A 6/20/2024 *** WELL SI ON ARRIVAL*** PT 250 LOW AND 2500 PSI HIGH. LOG CORRELATED TO SLB CBL LOG DATED 6-16-15 CCL TO CUT: 19.6' CCL STOP DEPTH: 8935.4'' TUBING CUT DEPTH: 8955' CUTTER OD REACHED: 5.613" ***JOB COMPLETED*** 7/1/2024 T/I/O = 170/0/0. Pre CDR2. Set 6" J BPV #423, RD upper tree, RU dry hole tree, Torqued to spec, Tested against MV 250/350 low 5000 high (PASS). Pulled 6" J BPV #423. RDMO 7/11/2024 Set J plug (TWC) w/ T-bar & Worley boom truck 7/11/2024 T/I/O= 175/116/2 (RWO CAPITAL) Pumped 51 bbls of Deep Clean and 1086 bbls of 1% KCL down TBG, taking returns up the IA, and out to B-19 FL. Pad Op notified of LRS departure. Valve Positions: SV = Closed, SSV/MV = Open, IA/OA = OTG, isolated from choke skid Final WHPs = vac/vac/8 7/12/2024 T/I/O = TWC/VAC/10. Bleed WHPs to 0 psi (pre-rig). Dry hole tree & TWC installed. BLP/CLP = 0 psi. OA FL near surface. Bled OAP to BT to 0 psi in < 1 min (gas). Monitored for 30 min. OAP unchanged. Final WHPs = TWC/VAC/0. SV, MV = C. IA, OA = OTG. 09:00 7/13/2024 Remove tree, clean void, plug (2) 1/8" NPT ports in hanger neck, function tubing hanger lock down screws one at a time, measure from flange OD to end of lock downs when fully clear of bowl ID (4"), re-torque to 550 ft/lbs, make up 7" IJ4S sub to hanger lift threads 6 RH to make sure theyre good, remove sub, measure top of tubing head flange to top of hanger neck (9-1/2"), measure top of TWC to top of hanger neck (5"), measure from rig floor to tubing hanger lock down screws (25.80'), RDMO. 7/13/2024 Nabors CDR 2 - RWO, B-30A Job Scope: Tubing Swap, Tree Replacement ***Rig Accepted at Midnight*** Confirm Zero PSI on Well, No Flow Check. Remove Old tree. 16k #'s over Top Drive Weight to Pull Tree off. Cycle LDS's to ensure good movement. Run Hanger XO down 6 turns to full bottom out. Good Threads. NU Coil stack to top of Annular. Bring CB74 Risers and Connections to Rig floor up to QTS. All Koomey hoses hooked up to BOP Stack. ***WSR Continued on 7/14/2024*** Daily Report of Well Operations PBU B-30A 7/14/2024 Nabors CDR 2 - RWO, B-30A Job Scope: Tubing Swap, Tree Replacement Build Test Joint. Confirm all Koomey Hoses hooked up properly. Visually inspect rams/bag open/close. PT Test joint 5000 psi. (Sundry test requires 5000 psi initial test on 13 5/8" BOP) Start BOPE Test w/ State Witness Guy Cook. Function test Gas/H2S Alarms. Fail/Pass R2 (cycle,grease). Continue Testing. ***Job Continued to 7/15/2024*** 7/15/2024 Nabors CDR 2 - RWO Job Scope: Tubing Swap, Tree Swap Continued from 7/14/2024 Continue BOPE Test with State Witness Guy Cook. Cannot build pressure while testing 13 5/8" Annular and 13 5/8" VBR. State Rep left location for days off. Remaining Tests Waived by State at this time. Troubleshoot Koomey Unit 4 - way valves. Find Annular 4 - way valve leaking. Replace. Test Annular again, PASS. Rebuild Test Joint due to connection leaks. Test VBR with 3.5" joint, FAIL // PASS. Could not get VBR to test with 5.5" test joint. Plan to use 5.5" Donut Joint. RD 2 3/8" Double Gate BOP, flow cross and flange XO. ***Job Continued to 7/16/2024*** 7/16/2024 Nabors CDR 2 - RWO Job Scope: Tubing Swap, Tree Swap Continued from 7/15/2024 Finish RD 2 3/8" Double Gate BOP, flow cross and flange XO. Install Bell Nipple on Annular. Get Dimensions for Flow Box piping. Torque 4.5" IF to 20K lb-ft. Rig Max. Complete test on 5.5" VBR and Upper and Lower IBOP (hydraulic/manual). 250 low/ 5000 high. BOP Testing Complete. Pull TWC, no pressure. Thread in Landing Jt. to hanger 5.5 - 6 turns. Stab on Top Drive. BOLDS 4 inches. ***Job Continued to 7/17/2024*** 7/16/2024 Run in hole w/ T-bar & J plug running & retrieving tool, make up 4 RH, offset poppet, 0 psi, rotate 3 more RH, pull J plug w/ tugger, make up landing joint 6 RH, back out lock down screws, all 4"+, (2) were tight, but came to full out measurement, pull hanger to floor, stand by for tubing swap. Daily Report of Well Operations PBU B-30A 7/17/2024 Nabors CDR 2 - RWO Job Scope: Tubing Swap, Tree Swap Continued from 7/16/2024 Thread into Hanger, 6 turns. Pull on Hanger with Top Drive. 220k #'s, pull free. Tubing moves freely at 164k#'s. LD first joint, Close Annular. Circulate Surface to Surface, 77 bbls to fill hole. Circulate 655 bbls around, 8.39 ppg IN, 8.39 ppg OUT. Flow check well, ~12 bbl/hour losses. Maintain continous hole fill down flow riser. Spool on Control lines. Conduct Kick while tripping drill with both day/night crews. Pull and LD 5.5" production tubing with 2150' of control lines. Cut is on the Rig Floor @ 23:50 PM - Clean Cut Losses still Consistent @ 12 bbl/hour Maintain Continous Hole Fill - Clean and Clear Rig Floor ***Job Continued to 7/18/2024*** 7/18/2024 Nabors CDR 2 - RWO, Tubing Swap, Tree Swap Continued from 7/17/2024 Total Tubing L/D = 220 jts. 8 GLM. 1 SSSV Nip. 4 metal bands and 24 control line clamps recovered. Continous Hole Fill, 8 bbl/hour losses. Clean/Clear Rig Floor/Pipe Shed. Drift and Tally 4.5" Completion. ***Job Continued to 7/19/2024*** 7/19/2024 Nabors CDR 2 - RWO, Tubing Swap, Tree Swap Continued from 7/18/2024 Continous Hole Fill, 8 bbl/hour losses. Clean/Clear Rig Floor/Pipe Shed. Drift and Tally 4.5" Completion. Break out TIW off De-Completion Landing Joint. Get XO's for TIW valve staged on rig floor. Fit test Hanger with Landing joint. Completion and Tubing Summary approved by OE. Begin PU and Running 4.5", 12.6#, 13Cr80, JFE Bear, Gas-Lifted Completion. Conduct Trip/Standing Order Drills with day/night crew. Losses consistent at 8 bbl/hour during trip in hole. ***Job Continued to 7/20/2024*** 7/20/2024 Make up hanger to string, run in hole, land on RKB, verify landed looking through IA valve, run in lock down screws, the lock down screw @ 9:00 (as you enter the well house from the pad) wouldn't run in all the way, stopped ~3/4" short of where it should be. left it in the out position),set 4" CIW H CTS BPV, stand by for BOP nipple down. Daily Report of Well Operations PBU B-30A 7/20/2024 Nabors CDR 2 - RWO Tubing Swap, Tree Swap Continued from 7/19/2024 Continue PU and RI with 4.5", 12.6#, 13Cr80, Gas-Lifted Completion. Space out accordingly at surface. 1 full 40' joint below hanger XO. Land Hanger in Wellhead, RILDS. Circulate 480 bbls of CI 1% KCL into IA. Drop Ball and Rod. Set Packer @ 8838'. MIT-T 3150 psi. Pass. MIT-IA 3200 psi. Pass. Bled WHP to Shear out Valve at Upper GLM ~2500 psi. Circulate 10 bbls KCL across Valve in both directions to confirm clear. Set CTS BPV in Stack. Begin Swap out VBR rams on 13 5/8" BOP stack to 2-7/8" x 5". ***Job Continued to 7/21/2024*** 7/21/2024 Nabors CDR 2 - RWO Tubing Swap, Tree Swap Continued from 7/20/2024 Begin Swap out VBR rams on 13 5/8" BOP stack to 2-7/8" x 5". Install New Tree. Test Void on Packoff to 5000 psi for 30 minutes. FP well to 2500' with Diesel. Allow diesel to U-tube, complete RDMO checklists. Release Rig @ 1900. Begin Move to 06-18A. ***Job Complete*** 7/21/2024 Set CTS plug in BPV, clean void & ring groove, install new BX-160, install DX seal in hanger, function the lock down screw that wouldn't run in completely, discover the nose is broken, it doesn't move when the LDS is functioned. Tried to remove broken LDS tip that is protruding into ID of bowl, leave the LDS out, it's @ the 9:00 position from the pad, it's the only LDS that's more than 3-1/2" out, grease hanger neck OD, inspect THA ID, make up THA to tubing spool, rig crew nipple it up, test hanger void 600 psi/5 min, 0 psi loss, test 5000/30 min, lost 175 psi first 15 min., lost 0 psi second 15 min., bleed off test psi, stand by for rig crew to test tree, pull CTS plug & BPV, RDMO 7/21/2024 LRS Unit 76 (RWO CAPITAL) Pumped 175 bbls of 60*f diesel down IA, taking returns up TBG to tiger tank. RDMO 7/22/2024 T/I/O = SI/0/0. Post CDR2 RWO, RD Temp Valve #17, Install New 4" CIW Upper Tree with SH-3000 actuator. PT upper tree against MV to 350/5000 psi.Passed. Installed production piping and set wellhouse. Final WHP's SI/0/0. ***Job Complete*** 7/22/2024 ****WELL S/I ON ARRIVAL**** (Rwo capital) PULLED BALL & ROD FROM RHC @ 8,912' MD PULLED DGLV FROM ST #3 @ 5,869' MD PULLED SOV FROM ST #4 @ 3,602' MD SET RK-LGLV IN ST #4 @ 3,602' MD ***CONTINUED ON 7/23/24 WSR*** (Rwo capital) 7/23/2024 ***CONTINUED FROM 7/22/24 WSR*** (Rwo capital) SET RK-OGLV IN ST #3 5,869' MD PULLED RHC FROM 8,912' MD PULLED WHIDDON FROM 9,222' MD PULLED PRONG & PX PLUG BODY FROM 9,222' MD. ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** v 7 co -, stir_ `8 i F 3 Q `° z . 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Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other StimulateAlter Casing 0 Change Approved Program [H' Plug for Redrill 0 Perforate New Pool 0 Repair Well Re-enter Susp Well 0 Other PackerSq_u zA, 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 2011-105 3. Address: P.O.Box 196612 Anchorage, Development (J Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21542-01-00 7. Property Designation(Lease Number): ADL 0028310 8. Well Name and Number: PBU B-30A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: hfhI V E I Total Depth: measured 12859 feet Plugs measured See Attachment feet true vertical 9037 feet Junk measured 10855 feet J U L 0 7 2015 Effective Depth: measured 11870 feet Packer measured See Attachment feet true vertical 9040 feet Packer true vertical See Attachment feet A G C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11330-11390 feet 11500-11560 feet 11904-11979 feet 12023-12098 feet 12340-12445 feet 12560-12640 feet 12650-12670 feet 12445-12470 9039-9039 feet 9040-9037 feet 9034-9030 feet 9025-9029 feet True vertical depth: 9030-9036 feet 9035-9034 feet 9033-9033 feet 9029-9030 See Attachment See Attachment See Attachment Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: y$�g®y tc') NOV 1 2 2015 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 429 23148 58 0 878 Subsequent to operation: 570 16332 257 0 243 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations IZ Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Summerhays,Nita M IPRO Technologies Email Nita.Summerhays@bp.com Printed Name Summerhay Nit./ (WIPRO Technolor es) Title Petrotechnical Data Manager ---Amor/ / Sig .It < %, 41.41e/dee-OW / Phone +1 907-564-4035 Date 07/07/2015 Form 10-404 Revised 5/2015 (/'TL 'I /17/ 7(y /��. Submit nginal Only RBDMS� JUL - 8 2015 • • Daily Report of Well Operations PBU B-30A ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL SWCP 4521***(cement squeeze) RAN QC, KJ, 3.60" BELL GUIDE, 2" EXT, 2-1/2"JDC,S/D @ 9104' SLM ,PULLED P-PRONG MADE 3 RUNS W/2.5 P-BAILER TO 9195'SLM.REC 1 1/2 GALS OF PLASTIC COATING. RAN 4 1/2 GR, SAT DOWN @ 9198'SLM. LATCHED AND PULLED PLUG BODY, RDMO. 5/4/2015 ***** LEFT WELL SHUT IN, TURNED WELL OVER TO PAD OPER. ***** ***WELL SHUT IN ON ARRIVAL*** (SLB E-LINE SET PLUG - PRE PKR SQUEEZE) INITIAL T/I/O =450/150/0 RIH W/ELINE LOGGING TOOLS & 4.5" HALLIBURTON COMPOSITE BRIDGE PLUG SET PLUG @ 9186' MID ELEMENT (TOP OF PLUG @ 9185') (PLUG SPECS = 2.4' OAL/3.66" MAX OD) TIED INTO SLB LDL DATED 1/28/15. PUMP TOTE OF DIESEL DOWN TBG TO TEST PLUG. T/IA= 1200/400 PSI. CONT TO PUMP 5 BBLS METH DOWN TBG TO TEST PLUG T/IA= 1800/1000 PSI. MONITOR PRESSURES TO SEE IF THE EQUALIZE AND THEN HOLD FOR MIT. T/IA= 1425/1070, BOTH HOLDING STEADY. HELD FOR 10 MINUTES. WSL SATISFIED THAT PLUG IS HOLDING -- LRS TO COME OUT AT LATER DATE TO PERFORM FULL MIT AND GET LLR WELL LEFT SHUT IN UPON DEPARTURE- NOTIFIED PAD OP OF WELL STATUS FINIAL T/I/O = 1425/1070/0 5/7/2015 ***JOB COMPLETE*** T/I/0=380/1000/10 Temp=S/I LLR TBG.(Cement Squeeze) Bled IAP from 1000 psi to 225 psi. (All gas) Pumped 10 bbls neat meth down TBG taking returns up IA to Tiger tank to establish LLR of 5/9/2015 .40 bpm to .60 bpm @ 2500 psi. Rates never stabilized. ***Continued on 05-10-15 WSR*** ***Continued from 05-09-15 WSR*** MIT-IA to 2500 psi (PASSED) Pumped 5.6 bbls of meth down IA to reach test pressure. 1st 15 min IA lost 72 psi. 2nd 15 min IA lost 22 psi for a total loss of 94 psi in 30 min. Bled back— 5 bbls. Tags hung on WV/IA. AFE sign hung on master. SV WV SSV= 5/10/2015 closed MV IA OA= open. FWHPS= 400/200/14 T/I/O = 370/190/10. Temp = SI. TBG & IA FL (Coil Request). No AL. T& IA FLs @ surface, OA FL near surface. 5/19/2015 SV, WV= C. SSV, MV= 0. IA, OA= OTG. NOVP. 1915. CTU#6 1.75" CT Job Scope: Packer Squeeze MIRU. MU cementing BHA w/a 2.49" BDJSN. Pressure IA to 1950psi and confirm no communication to the tubing. Line up down the tubing and establish a LLR —.7bpm TxIA. RIH and tag plug at 9184'. PUH and get wt back at 9181'. PUH 2'and flag pipe yellow/orange at 9179', correct elec depth to 9183'. SLB pumpers completed field testing. Pump 9bbls squeeze crete cement and lay in tubing. PUH to safety. Start displacing cement into IA. Continued on 6/5/15. 6/4/2015 ***Job in Progress*** CTU#6 1.75" CT Job Scope: Packer Sqz Continued from 6/4/15. Displace 7.5bbls cement into IA, est TOC —9002'. RIH and contaminate cement left in tubing (1.5bbls) with 25bbls gel, laying in from CBP up to 8620'. Chase gel out of well. Freeze protect well with 46bbls 50/50 methanol. Wash BOPs. RDMO. 6/5/2015 ***Job Complete*** T/I/O= 10/115/13 Temp= S/I MIT-IA to 2500 psi ***PASSED*** MIT-T to 2500 psi ***PASSED*** (CEMENT SQUEEZE) MIT-IA= Pumped 8.4 bbls meth down IA to reach test pressure of 2500 psi, IA lost 51 psi in 1st 15 min and 20 psi in 2nd 15 min for a total loss of 71 psi in 30 min test, Bleed IAP, Bleed back—6 bbls meth, MIT-T= Pumped 2.3 bbls meth down TBG to reach test pressure of 2500 psi, TBG lost 20 psi in 1st 15min and 7 psi in 2nd 15 min for a total loss of 27 psi in 30 min test, Bleed TBG pressure, Bleed back—2 bbls meth, FWHP= 11/195/13 AFE sign & tags hung on IA,WV,MV SV, WV, SSV= Closed MV= Open IA&OA= OTG Pad-op notified upon 6/8/2015 departure • • Daily Report of Well Operations PBU B-30A CTU#6 1.75" CT Job Scope: Mill/Retrieve CBP MIRU. MU & RIH w/ Baker motor, Venturi, and 3.80" burn shoe w/opticut. Tag contaminated cement at 9180'. Mill easily down to top of CBP at 9182'. Mill up CBP with 2 stalls. Push dry down to x-nipple at 9218' (9222' MD). POH, pumping at 1.5 bpm to attempt to keep CBP in BHA. Did not recover CBP. Clean up Venturi and burn shoe and RIH w/same BHA to attempt to recover CBP. 6/14/2015 ***Continued on 6/15/15*** CTU#6 1.75" CT Job Scope: Mill/Retrieve CBP RIH w/2nd run of Baker motor, Venturi, and 3.80" burn shoe w/opticut. Sat down on LTP at 10389' (10400' MD). PU and come online down coil at 2.3 bpm. RIH and stack 2k on LTP and see 150 psi motor work for about 30 seconds, attempting to burn over/push CBP into burn shoe. POH while continuing to pump at 2.3 bpm. Recovered about a pint of chunks of rubber and composite material from CBP, and cement chunks, in Venturi. FP well with 58 bbl of 50/50 methanol. RDMO. 6/15/2015 ***Job Complete*** ***WELL S/I ON ARRIVAL*** (cement squeeze) DRIFT 20'x 2" DUMMY PERF GUNS, 1.75" S-BLR,AND TAG KB PKR @ 10,400' MD. 6/15/2015 ***WSR CONTINUED ON 6/16/15*** ***WSR CONTINUED FROM 6/15/15*** (Cement Squeeze) TAGGED PKR @ 9,173' MD w/4.50" G-RING. LRS PUMPS 70 BBLS KCL&61 BBLS DIESEL DOWN TBG. MAKE 2 PASSES FROM 9,400'- 8,900' SLM w/SCMT MEMORY TOOL. (Good Data) 6/16/2015 ***WSR CONTINUED ON 6/17/15*** T/I/O=0/145/10 SI Assist SL as directed (CEMENT SQUEEZE) End Ticket and AWGRS due to 6/16/2015 end of the day. ****Job continued from 6/16/15 ****Assist SL as directed, 6/17/2015 FWHP = 0/300/12 SV/WV/SSV/MV-SLICK LINE IA/OA/OPEN TO GAGE. ***WSR CONTINUED FROM 6/16/15*** (Cement Squeeze) SET 5-1/2" DREAM CATCHER @ 9,099' MD. SET 5-1/2"WHIDDON @ 9,099' MD. PULLED RM-DGLV FROM ST#8 @ 4,824' MD. PULLED RM-DGLV FROM ST#9 @ 3,087' MD. SET RM-LGLV IN ST#9 @ 3,087' MD. SET RM-OGLV IN ST#8 @ 4,824' MD. PULLED WHIDDON @ 9,099' MD. 6/17/2015 ***WELL S/I ON DEPARTURE DSO NOTIFIED*** Fluids Summary Bbls Type 86 DIESEL 41.6 METH 637 50/50 METH 319 SLICK 1% KCL 37 FRESHWATER 9 SQUEEZECRETE 26 POWERVIS 131 SLICK 1% KCL W/SAFELUBE 70 1% KCL 1356.6 Total • • m co) O O O O 0 0 m N- N O co O 00 O C N N- �O CO I� 0 0 0 i oo (DCo O ,n � O rnacoA- oM Ca Nt CO CO ocO ti coo O O CO I- O co M x c O ti N O O O N CO CI CO O Co O O Cr O CO CS) N CO CA CA C)) CO 0) CO CO a I It H N- CO M I` CO O O co N co O co N V rt V O) O O O M coCo00coa) 00 4-1 CD O N O � v- C) M 6) O caO N (0 N N cc) O C1) N O L O C70 O V' CO CO N O 0 0 N 0 A- U a Q CN V LCO O M ) O O N c=4. N O O M VO M O O O O O CA = r r CO Oo Ocoo OO coco CO co J O o0 O o? J J = d N *k J CO NO r# co* •(1) X f— �$ N O am- N (A _ CO _ O U N OO CV N N Oo N N Ch M V C'7 N .4 " CO N O N O O �O C co CO C() O N O J N C) O (A W cs)O I 0 _ W ' U W U O u_O Z_ Z Z c W W W W O] O D F- Z Z Z Z Z D D 0 u) Z J J J J J H s • Packers and SSV's Attachment PBU B-30A SW Name Type MD TVD Depscription B-30A PACKER 9177.37 8334.22 4-1/2" BAKER FHL PACKER B-30A PACKER 10400.48 8906.61 3-1/2" BAKER KB TOP PA B-30A PACKER 10703.52 8987.8 4-1/2"TIW TOP PACKER • • B-30A 205-081-0 Plugs Attachement SW Name Date MD Description B-30A 04/30/2013 11870 Set 2-7/8" Baker CIBP B-30A 06/11/2004 12200 CIBP 114±= 6-CW • B—DOA S.'NOTES:***WELL ANGLE>70° , VEL TEAD= McEVOY Q,0000• •, ` ACTUATOR= BAKER C PLASTIC COATED TSG"” OKE.ED/= 82.3' I I BF.ELEV= 46.3' 1-760 7=-------3200; 2138• —5-1/2"OTIS HR©SSSVN,D=4.562" I Max Angle= 91'@ 11700' • Datum RD= 10328' ._....._......__._.______. ._... ._.. GAS LFT MANDRELS Datum ND= 8800'SS ST EVD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8'CSG,72#,L-80,D=12.347'I--- 2676• 9 3108 3107 8 LED DOME Fa 4 16 06/17/15 8 4824 4666 29 LED SO RM 20 06117/15 7 5716 5449 28 LED DMV RM 0 03/06/86 6 6290 5954 30 LED OM' MA 0 03/06/86 Minimum ID =2.37" @ 10927' 5 6869 6444 32 LED DMY RM 0 03/18/04 3-3/16" X 2-7/8" LNR XO . 4 7448 6945 30 LED DMY RA 0 03/06186 3 8026 7453 28 LED DMY RA 0 03/06186 2 8609 7938 40 LED DMY RA 0 03/06/86 FKR CMT SQZ(06/04/15) — —9002 i,- F 1 9031 8238 48 LED DMY RM 0 09/15/05 I bac: I I ' 9099• --5-112'OTE XA SLD SLV,0=4.562- eV 5-1/2"TBG-FC,17#,L-80, 0232 bpf,0=4.892' H 9159' A .. 1 9169' 1—BAKER PBR,D=4.75' I 45i zo = ..N9173' —9-5/8'BKR FHL PKR,D=4.00' 9222' I—4-1/2"OTIS X NP,D=3.813' TOP OF 7'LNR H 9308• 9-5/8'CSG,47#,L-80,D=8.681" — 9648• I-'--4 10400' H3.70'BKR KB PKR D=2.56" 1 10412' 1---3.75'BKR DEPLOY SLV,D=3.00' 10412' — BKR SEAL ASSY,D=2.39' I 10421' I—3-1/2"X 3-3/18'X0,D=2.88'i I4-1/2"TBG, 12.64,L-80,.0152 bpf,D=3.958" -- 10681' 10681' —TM'0/5 SEAL ASSY,D=? 1068T -TM/POLISHED FaSE R,D=? BEHIND CT LNR E ►: 10699' —7"X 4-1/2"T )/RKR D=? 4 17'LNR 29#,L-80,.0371 bpf,D=6.184"— 10818' 4-1/2"MLLOUT WIt€OW 10845'- 10855' 4-1/2'BKR WHPSTOCK w!RA TAG 0 10855' 10845' FISH CENTRALIZER ARM(10/23/14) — ? 1092T H3-3/16"X 2-7/8'LNR XO,0=2.37" 4-1/2'LNR L-80 FL4S,.0152 bpf, D=3.920" H 12496' 144441 ` 11870' J—2-7/8'BKR CEP PERFORATION SUMMARY 4S (05/17/13) REF LOG: AMC GR/RESISTIVITY ON 06/25/01 12200' I—2-7/8'BKR CEP ANGLE ATTOP PERF: 86'011330' � ` ( 4) Note:Refer to Production DB for historical pert data ` Pr SIZE SPF INTERVAL Opn/Sqz SHOT S(t7 2" 6 '11330-11390 0 04/24/14 2' 6 11500-11560 0 04/29/13 /�`- 2' 6 11904-11979 C 06/09/04 MID — 12794' 2" 6 12023-12098 C 11/04/04 2" 4 12340-12470 C 07/23/02 2-7/8'LNR,6.16#,L-80 STL,.0058 bpf,D=2.37" I— 12869' 2' 4 12560-12640 C 06/26/01 2' 4 12650-12670 C 07/23/02 DATE REV BY C MENTS DATE REV BY COPMENTS PFaD OE BAY LNT 03/07/86 INITIAL COMPLETION 06/25/15 JTGIJAID GLV G0(06/17/15) VVE3L B-30A 06/27/01 CTD SIDETRACK(B-30A) FERMI No:'2011050 10/29/14 GJB/JM)GLV GO(10/19/14) AR No: 50-029-21542-01 10/29/14 SWGJMC SET PX FEUG&FISH(10/23/14) SEC 31,T11N,R14E,619'SI4_&1894'V1IEL 05/04/15 RJK/PJC PULL PX PLUG .06/25/15 TTRJM)+R(R CMT SQZ(06/05/15) _ BP Exploration(Alaska) In11) 1 Ta, a, _0 w LL >.ON L OL L~ T 111arY Y 6 CO OCA vfs U• +,�+ eij EcO Q li o c -0 o_ ° .o• cu � a0 V C. CO O v E •Er CO -C 0L J J Y N Oen., In Q N L C C Z O / c c c c c c c c C ca 0) O- N z y ,a ,a fa la fa ,a ns R U• 'O ° > Q LL 7 7 7 7 7 7 7 7 O N O U +-+ 1W- f,!) O 0 00 ,!) 00 N e! M 5 . c6 Q M N N NNN Y V co C ra N U L 6 'Z7, a E -o a � a, ;n C ""> 000000 COO v CO` ° p U ,.- W J J J J J J J J J a) L N N yj W W W W W W W W W Utz Vi {- LL LL LL LL LL LL LL LL LL 71.3 .0 C 0 Q J J J J J J J J J +-, a) > ''' �'.,. 0. Z Z Z Z Z Z Z Z Z E Q v O O LL LL LL LL LL LL LL LL LL C 0 L C -° lJ m ,- C C co O _ Q a) L OU > U it G Z U y O_ Z } '? „� aro F..cL O W F Q) co al Wre Ill,.X w O cca Lis 2 z z t " - -'4ri H i , " 1 u R n~010 a J O O -.I J O O O O E 2 2 3 2 2 2 2 3 W W W W w w !LIall 2 2 2 2 2 n ([''�� v 0 Ln , o N CV t� ao T /� dL `�R _ X n � v } } } } } } } } } 0 V m ® _ >-m m m m m m m m m �_ l0 LU Q W W W W W W W W W .4 ILI W < Z000000 000 ,32 2 2 2 2 2 = I 2 EN Cr .. w O O O O O O O O O C N W R cc2 LY 2 cea' LY a' ro C O O. a a a a a a a a m U S C) N CO ,O vl N ,...-.. O) N N ,n O V T1 ct \ iU O 0 1 0J 0 0 0 0 0 0 0 0 0 C W 0 0 0 9 0 0 O O O '7 OE NN xi 0 2 LY O O O 1 ••- U O m M M LY LL N N } C eM U O O D U O D U U aJ . ... L M^ 3 a) i� ,LyC�� ^ C O L_ ca V a+ S t0 N O co O cc ` c 1 EIC , CO CO MOM NMNN fa E 7 7 ,n Lp n N c 14 m z L)1 L1 N 4-, 0.1 cEo a Fe s N w Z 0.1 CO _ I n c c m ,n AP 8 y E 3 dr F= n`. a Q STATE OF ALASKA "l 7C, '! r Al A OIL AND GAS CONSERVATION COMM )N ,,,I L 2 1 Rill REPURT OF SUNDRY WELL OPERATIONS ,(wy; 1.Operations Abandon H Repair Well H Plug Perforations H Perforate H Other LI �"-- Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver IS Time Extensions Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WOO 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ % 201-105-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 f 50-029-21542-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028310 • h PBU B-30A 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: Total Depth measured NI 12859 feet Plugs measured See Attachment feet true vertical 9036.63 feet Junk measured None feet Effective Depth measured 11870 feet Packer measured See Attachment feet true vertical 9039.56 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 36-116 36-116 0 0 Surface 2636 13-3/8"72#L-80 40-2676 40-2675.99 4930 2670 Intermediate 9512 9-5/8"47#L-80 36-9548 36-8563.48 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11330-11390 feet 11500-11560 feet 11904-11979 feet 12023-12098 feet 12340-12445 feet 12445-12470 feet 12560-12640 feet 12650-12670 feet True Vertical depth 9030.07-9035.5 feet 9038.8-9038.65 feet 9039.91-9036.99 feet 9034.22-9030.01 feet 9024.8-9028.76 feet 9028.76-9030.06 feet 9034.66-9033.68 feet 9033.48-9033.28 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment 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): SCANNED FRAY 2 7 2014 RBDMS .MAY 21 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 215 14153 23 0 924 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Ur • Service IS Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil , Gas (J WDSPLIJ GSTOR ❑ WINJ IS 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.O.Exempt: N/A Contact Garry Catron Email Garry.Catronc BP.Com Printed Name Garry Catron Title PDC PE Signature A C Phone 564-4424 Date 5/20/2014 S-,2 I-/y Form 10-404 Revised 10/2012 ,AiAl'mog Submit Original Only B-30A 201-105-0 Plugs Attachement SW Name Date MD Description B-30A 4/30/2013 11870 Set 2-7/8" Baker CIBP B-30A 6/11/2004 12200 CIBP Packers and SSV's Attachment ADL0028310 SW Name _ Type MD TVD Depscription B-30A PACKER 9173 8331.39 4-1/2" Baker FHL Packer B-30A PACKER 9173 8331.39 4-1/2" BAKER FHL PACKER B-30A PACKER 10400 8906.45 3-1/2" BAKER KB TOP PACKER B-30A PACKER 10699 8986.88 4-1/2"TIW TOP PACKER U N- 4.0 0 0 0 0 0 0 0 0 co • co � 0 NI- m CO 00 CO N- CO CO CO CO N CO M C) - CO tl N- C r— (0 O) co co • CO CO M N- O CO O CO OD O r r r M N- CO co O O 0) O O O CO O) 0) 00 C) co co O CA N oo co 0) NN N N CO CO co MN. 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Q N `� +'� Q Q � � Q c vi 2 , Q � � m7 ° .o o 2a0 Q (0 W E N J J H O C U) .� C +� -a L.d 0_ O CD > C- (n W W p L O 0- N (>3 i J F O Q 0. 1- Cr 0 V WQZQ a) 73 c -aa QU .( ;� M � .- 0C u) � � CD ZEN •- _) a_ Oaa) aa� D � •' aiUas � O V) 0 Iz W' 0 = (D W N F- •(n & 0 ~- O O Q- (tea H O)'J w < (n a •0 o •�o (nom 0� �� co 60 Q Jdn0 .E U C -a aS o F- CD LL 11 O � O II mZZQ W � F- bw ' O0O a a J d o E Q < < co � Q 0XQm � �O oo ^0 _c-0 > t 0 a (9O LO a) , Ou) D .Q _c1E- o C Lo Q odD -.5 ' 0_ � M v) Q2QcoQ �O0 LI- COpig C E 0 3c) E -cm a) a) ° 11 -_ a) - * _U Z Q M L O m O L Q Q L ' * LI_ F- Q a- co O 2 O M ° N O 7 W II .(n o O z + J u) W M — L C •- co C '-' a) Q- ° Q II II V) ( �' II �' II Iz 0 0 L ,, E o2 o ) > P m -6 > > J � > ; > -0i>3 m aQ > - co 0 (nw ▪RS I- O a) Q (iS w to c (Lo a)N F- c i o w (13 o F- 0 E (n + F- N � � � X � QpUN 3 o � vU(\ o � � � w +O CA O . ' O U O CL) > Q 0_ Q N - O Q L C - V O D - (n ELJ 6 c a O II N Z - U X ° a c O ° N U) (4 O O M > co_ ° - O W s s? Q b ° ° .° a O > 0 6 w , c O V w r D r 9 p C O U > F -a 00 0) co %.-• E ;-. u) v � J � 0ri _ Q � C •• -av � (ate U) H O co a) L) O ° J Q > J M —• 3 C co D r - C 11 0 u) > II 0 > 11 N M C w J O F- w 4 (6 D o o *k C � * C 0 m 0 a o 0 , » 0u) a� 0 _1 0 1- D r z m c IDD C c c ai ° O Cs_ L - 0 > . > u) ,, Q W CC * I- -i 0 0 0 F- O a D ca N * I H ddm1- U) u) F- 0 oQ : 0 0 020 .EU o CD 0 1 v v v dr dr 0 0 0 0 0 0 N N N N N N LO N CO U7 0 O M CV N N N dr V V 4 rt -4- dr TREE= 6"CNV WCITES:= Mc B-3 0 AWELL ANGLE>70°@ 10000' "' SLASTIC COATED TBG• ACTUATOR= BAKB2 C IN'TIAL KB,ELE 82.3' BF.ELEV= 46.3' KOP= 3200' O 2138' H5-1/2"OTIS HRo SSSV N,D=4.562' Max Angle= 91°@ 11700' [ tum MD= 10328' GAS LFT MANDRELS Datum TVD= 8800'SS ST PA) TVD DEV TYPE VLV LATCH PORT DATE 9 3108 3107 8 LBD M1' RM 0 12/14/13 113-3/8'CSG,72#,L-80,D=12.3471- 2676' —, 8 4824 4666 29 LBD DMY RM 0 12/14/13 7 5716 5449 28 LBD DMY RA 0 06/17/04 6 6290 5954 30 LBD [MY RA 0 03/06/86 Minimum ID =2.37" @ 10927' L 5 6869 6444 32 LBD DMY RM 0 03/18/04 3-3/16" X 2-7/8" LNR XO 4 7448 6945 30 LBD DMY RA 0 03/06/86 3 8026 7453 28 LBD DMY RA 0 03/06/86 2 8609 7938 40 LBD DMY RA 0 03/06/86 1 9031 8238 48 LBD DMY RM 0 09/15/05 7 I 9099' -15-1/2"OTIS XA SLD PLV,D=4.562' 5-1/2"PC-TBG,17#,L-80,.0232 bpf,D=4.892' H 9159' 9159' ---1BAKER PBR D=4.75" 21 9173' -19-5/8"BAKER FF-L R(R D=4.00' L 9222' H4-112'OTIS X NP,D=3.813" TOP OF 7-LNR 9308' 9-5/8"CSG,47#,L-80,D=8.681' - 954$• , 1 10400'-1-1 3.70'BKR KB PKR,D=2.56" S I- 1041Y-1-13.75"BKR 10412' H BKR SEAL ASSY,D 2. 9' 3.00"1 1 _ 10421' -13-1/2-X 3-3/16"XO,D=2.88' 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 10681' i " 10681' -. TW O/S SEAL ASSY,D=? - 1 10687' -1TIW POLISHERD H)RIS , =? BEHIND — CT LNR $-------I 10699' 1-7"X 4-1/2"TIW PKR D=? 1 7'LNR,29#,L-80..0371 bpf.D=6.184'-1 10818' 1-4 , 4-1/2"MLLOUTVVNDOW 10845'-10855' 4-1/2"BKR W-iPSTOCK w/RA TAG 610855' H 10845' I 10927' -13-3/16"X 2-7/8'LNR XO,D=2.37" 4-1/2"LNR,L-80 FL4S,D=3.920" -I 12495' 144441 ` 11870' -2-7/8-BKR CEP PERFORATION SUARY k (05/17/13) MM FIEF LOG: MWD GR/RESISTIVITY ON 06/25/01 12200' 2-7/8"BKR CEP ANGLE AT TOP PERF: 86°@ 11330' 4( ` 1(06/09/04) Note:Refer to Production DB for historical pert data `` SIZE SPF INTERVAL Opn/Sqz SI-OT SOZ p� ft. 2" 6 11330-11390 0 04/24/14 & ``V 2" 6 11500-11560 0 04/29/13 2" 6 11904-11979 C 06/09/04 1 POTD H 12794' 2" 6 12023-12098 C 11/04/04 2" 4 12340-12470 C 07/23/02 2-7/8'LNR 6.16#,L-80 STL,.0058 bpf,D=2.37" -1 12859' 2" 4 12560-12640 C 06/26/01 2" 4 12650-12670 C 07/23/02 DATE REV BY COMMENTS DATE FEV BY COMvDITS PRUDHOE BAY UNIT 03/07/86 INITIAL COMPLETION '12/20/13 STF/JM.) GLV C/O(12/14/13) WELL 8-30A 06/27/01 CTD SIDETRACK(B-30A) 03/07/14 TBD/JM) SET 4-1/2"PX PLUG(02/26/14) PERMIT No: 2011050 05/03/13 TTR/PJC CPB/ADF RFS(04/29 8 5/17/13) 04/21/14 CM PJC PULL FX PLUG(04/20/14) AR No: 50-029-21542-01 05/25/13 Dl)PJC TREE C/O 04/28/14 ALMJM)ADPERFS(04/24/14) SEC 31,T11 N,R14E,619'SNL&1894'WEL 05/25/13 VVKPPKC GLV C/O(05/27/13) 06/04/13 JMD MNOR®ITS/TVD CORRECTIONS BP Exploration(Alaska) • rrikiviCI vGV STATE OF ALASKA MAY 2 9 ?013 AKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations [✓j • Perforate U . Other Li Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc • Development0 • Exploratory ❑ 201-105-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21542-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028310 PBU B-30A • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12859 feet, Plugs measured 11870,12200 feet true vertical 9036.63 feet Junk measured None feet Effective Depth measured 11870 feet Packer measured See Attachment feet true vertical 9039.56 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 37-117 37-117 1490 470 Surface 2640 13-3/8"72#L-80 36-2676 36-2675.99 4930 2670 Intermediate None None None None None None Production 9513 9-5/8"47#L-80 35-9548 35-8563.48 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11500-11560 feet 11904-11979 feet 12023-12098 feet 12340-12445 feet 12445-12470 feet 12560-12640 feet 12650-12670 feet True Vertical depth 9038.8-9038.65 feet 9039.91-9036.99 feet 9034.22-9030.01 feet 9024.8-9028.76 feet 9028.76-9030.06 feet 9034.66-9033.68 feet 9033.48-9033.28 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment 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): SCANNED NOV Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 418 28802 25 0 928 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorL] Development 0 Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil © • Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC-❑ (17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt:N/A Contact Nita Summerhays Email Nita.Summerhays(caBP.com Printed Name Nita Summerhays Title Petrotechncial Data Technician j ` Phone 564-4035 Date 5/22/2013 4.---------- t r-- //1� Apl9P3Pjpftmha f / ;:: RBDMS MAY 2 9 201 0 / `b / `3 Submit Original Only Form 10-404 Revised 10/2012 #0441/., • • Daily Report of Well Operations ADL0028310 CTU #3 1.75" Coil (CTV=32.8bbls) Job Scope: Set CIBP,Addperfs MIRU. Complete monthly BOP swap/test. MU & RIH w/ PDS GR/CCL logging tools& 2.3" DJN to 12000'. Log up at 40 fpm. Flag coil at 11820'. Log up to 9000'. POH. Check bairiers. Lay out tools. Good PDS data. PT MHA. M/U Baker 2-7/8" CIBP BHA. PT Lube. RIH. 4/28/2013 ***Continued on WSR of 04/29/13 *** ***Continued from WSR of 04/28/13 *** CTU#3 1.75" Coil (CTV=32.8bbls) Job Scope: Set CIBP,Addperfs Continue RIH W/BTT CIBP to the flag, correct the flag depth to 11843.7 ft, Set the plug @ 11870 ft. POOH. MU 30'x2"2006 PowerJet, HMX pert gun & RIH. Gun#1: Perforate from 11530-11560'. Gun#2: Perforate from 11500-11530'. POOH. FP well w/40bbls of 60/40 methanol. Lay out fired guns. N/D BOPE. N/U tree cap and PT. Secure well and RDMO CTU. 4/29/2013 «< Job Complete >>> FLUIDS PUMPED BBLS 252 1% KCL 214 60/40 METH 466 TOTAL Casing / Tubing Attachment ADL0028310 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 37 - 117 37 - 117 1490 470 LINER 1510 7"29# L-80 9308 - 10818 8417.92 - 9006.78 8160 7020 LINER 21 3-1/2" 9.3# L-80 10400 - 10421 8906.45 - 8913.26 10160 10530 LINER 536 3-3/16" 6.2# L-80 10421 - 10957 8913.26 - 9019.64 LINER 158 4-1/2" 12.6# L-80 10687 - 10845 8984.38 - 9010.08 8430 7500 LINER 1902 2-7/8"6.16# L-80 10957 - 12859 9019.64 - 9036.63 13450 13890 PRODUCTION 9513 9-5/8"47# L-80 35 - 9548 35 - 8563.48 6870 4760 • SURFACE 2640 13-3/8" 72# L-80 36 - 2676 36 - 2675.99 4930 2670 TUBING 9125 5-1/2" 17#L-80 34 - 9159 34 - 8322.29 7740 6280 TUBING 1540 4-1/2" 12.6# L-80 9159 - 10699 8322.29 - 8986.88 8430 7500 • • . Packers and SSV's Attachment ADL0028310 SW Name Type MD _ TVD Depscription B-30A PACKER 9173 8249.09 4-1/2" BAKER FHL PACKER B-30A PACKER 10400 8824.15 3-1/2" BAKER KB TOP PA B-30A PACKER 10699 8904.58 4-1/2"TIW TOP PACKER 1 TREE= 6"McEVOY sAFT ©TES:WELL EXCEEDS 70° 10000'AND WELLHEAD' McEVOY B-30A GOES HORIZONTAL @ 11000'. ACTUATOR=__.. 011S KB.ELEV 82 3' __ BF REV= 46.3' KOP- 3200' 2138' 5-1/7 O113FA113 SSSVN,13=4.562" Max Angle= 91 Z 11700' Datum Datum WO_ 10328' GAS LFT MkNDRELS DatumTVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE ' 9 3107 3024 8 LBD DMY RM 0 07/30/07 113-3/8"CSG,72#,L-80,D=12.347'H 2676' 8 4823 4533 29 LBD MY RM 0 07/30/07 7 5715 5366 28 LBD DWI RA 0 06/17/04 6 6290 5872 30 LBD MAY RA 0 03/06/86 Minimum ID =2.37"i 10927' 5 6868 6361 32 LBD MY RM 0 03/18/04 3-3/16" X 2-7/8" LNR XO 4 7447 6862 30 LBD (WY RA 0 03/06/86 3 8026 7371 27 LBD DMA' RA 0 03/06/86 2 8608 7855 39 LBD DMY RA 0 03/06/86 1 _ 9030 8155 48 LBD DMY MI 0 _09/15/05 I I 9099' H5-1/2"OTIS XA SLD SLV,D=4.562" I I5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892' H 9159' I I 9169' H BAKER PBR,D=4.75" c Z „ 9173' H 9-5/8"BAKER FFL PKR,13=4.00" I I 9222' H 4-1/2"OTIS X NP,D=3.813' ITOP OF 7"LNR H 9308' I I9-5/8'CSG,47#,1-80,D=8.681" H 9648' • S 10400' H3.70"BKR KB PKR,D=2.56' I 10412'�I—H 3.75"BKR DEPLOY SLV,D=3.00" I 10412' H BKRSEALASSY,D=2.39" I 10421' H3-1/2"X3-3/16"XO,D=2.88" I I4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 10681' 1 f I 10681' 1--1110/0/S SEAL ASSY,D=? BEHIND --I 1068T HT1W POLE RISER,D=? I CT LNR $ $------1 106W HT X 4-1/2"TIW PKR,D=? I 17"LNR,29#,L-80,.0371 bpf,0=6.184"H 10818' • • 4-1/7 MLLOUT YVIhDOW 10845'-10855' IBAKERWHPSTOCK H 10846' I RA TAG 10855' 1092T H 3-3/16"X 2-7/8"LNR XO,D=2.37" •�•�•�•�•• '—`/� v — I4-1R'LNR,L-80 FL4S,D=3.920"H 12496' I Not [ 11870' I 2-7/W BKR CEP 'K (05/17/13) j PERFORAT1ON S(J J#RY ■ 12200' I—2-7/8"BKR CEP REF LOG: MM)GR/FESFS1NITY ON 06/25/01 A44t (06/09/04) ANGLE ATTOPFERF: 90° -, 11904'Note:Refer to Production DB for historical perf data--SIB PIIl 1/AL---,-9pn/S9i SHOT St =`. l 2" 6 1500-11560 O 04/29/13 / `2 6 11. -11979 C 06/09/04 PC1TD H 12794' . 2" 6 12023-12098 C 11/04/04 2" 4 12560-12640 C 006/26/01 I2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,D=2.3T H 12869' I 2" 4 12650-12670 C 07/23/02 DATE REV BY COMMENTS DATE REV BY COMMENTS I PRLDHOE BAY UNIT 03/07/86 INITIAL COMPLETION 05/03/13 PJG TTR CM/ADPEl2FS(04/29&5/17/13 WELL: B-30A 06/27101 CTD SIDETRACK(B-30A) PERMIT No: 2011050 10/09/06 SKB/TLH WANERSFTY NOTE DELETED All Mx 50-029-21542-01 10/20/06 JRP/PAG GLV GO(10/17/06) SEC 31,T11N,R14E,619'SNL 81894'WEL 10/27/06 DTWPAG GLV C/O 07/30/07 CJNSV GLV C/O BP Bcploration(Alaska) • BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Pad B Dear Mr. Maunder, • ~-~~~~~~ DEC 1 ~ ?Cllr ~iasls~ Cil Czs Cons. Cammisso~x~ gn~l~nr~~e ~o~- !as ~-3a Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) n~re• ~~/~1/na Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al B-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA B-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-OSB 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-06 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 50029203210100 Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 8-12 1970090 50029203320100 NA 0.6 NA 3.40 8/22/2009 B-13 1990570 50029203410100 NA 0.4 NA 1.70 8/20/2009 B-14 2090590 50029203490000 NA 0.4 NA 1.70 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLS 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 8-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA B-30A (PTD #2011050) , EVALUATION for sustained casinWessure - TxIA c... Page 1 of 1 Maunder, Thomas E (DOA) NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Friday, July 27,20077:59 AM Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADWWell Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers NSU, ADW Well Integrity Engineer; Roschinger, Torin T.; Subekti, Herry ß.3OA (P"ft)#2011050) UNDER EVALUATION for sustained casing pressure - TxlA communication Attachments: B-30A.pdf From: Sent: To: Cc: Subject: All, Well B-30A (PTD #2001105) has been found to have sustained casing pressure on the IA. The wellhead pressures were 2320/2350Nac on 07/25/07. A subsequent TIFL failed on 07/26/07. The well has been classified as Under Evaluation and may be produced under a 28-day clock. Due to the high shut-in pressure (2350 psi) on this well, it will be put back on-line to restrict the lAP to the FTP around 900 psi. The plan forward is: 1. D: TIFL - FAILED 2. S: Set DGLVs in STA# 8 & 9 3. F: MIT-IA to 3000 psi, LLR if fails 4. EP: LDL pending MIT-IA & LLR results SCANNED JUL 3 1 2007 A wellbore schematic has been included for reference. «B-30A. pdt» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 7/30/2007 B-30A (PTD #2011050) Internal Waiver Cancellation - Trouble Well . A/ I \Ò\ lùtOlo ~&vl All, An internal waiver was issued for TxlA communication on well B-30A (PTD #2011050) on OS/27/04. The well no longer passes a NFT for waiver compliance and may not be produced. Therefore the waiver for continued operation with TxlA communication is cancelled. Please confirm that the well is shut-in and freeze protected. Plans are being evaluated to secure the well with a downhole plug. The well is reclassified as a Trouble well. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, }lnna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ')T' ~~\N~C i" ~J ,¡.....;".~ 1 of 1 1 0/1 0/2006 1 :52 PM . 10' FWL6 272' FSL sec. 11, T2S. R13W, 8M RJ·THF: 11.88' RT"GL: 16.8' 1bg 11ft lnadl . :nil" 1ST " TI1I8C1n .~" Bowen men , ",9.2 PPf. LoBO, IIST-Mod-wII\' see 10 9áeei OðrnoliItM - Oh8mØil infac1iCn lldepoclœt mandrel., 1953' (7) . , . BaIcet 7040 SC01 packer at 8097' . aa.r CMU ~ ......,. at 8161 (Opln) 2.813" X-proIIIe , - X-n!JIpIe at 8181' ID. U13" - Baker 7040 80-1 packer at 9406' _. ~ III1dIng IIHY8 at 94æ (oland) 2.813" x.,rctIe . ' , XX.plug Inatded 3I11W4, C8pped wi 20' of SafaCarb eoo , - saur 85-40 1=-1 pack&r at 9B86' - X-nlpple,at 9678' 1D . 2.813" - WlnIIIAI i't-entty gUlcie at me' :J~ Data· , wrtIaaI hole , NNA-1 8Chemlllfc 8·26-2004 . Well Name~NNA #1 Field: D"p Creek Unit State: Alaska r 1~", 81 ~. K-85 \0 I BurfaCII c..tnð: 9%', 47 Pøf. L-80, 8TO \I') 21«J', Cnmt wltl\ 146 bbI at 12.8 PØGlead and 48 Þbl of 15.8 ppg _ "G" 'ð 6182' . Ø222' (12 spf, 11801O2} -7 6473' . e4às' (81pt, 4I2SW4) ·12 6782' . em (8., .4128104) ~. .9170' -11183' (II spf, 4f.Z111iD4) -100 9208' ·11234' (81pf, 4f20.004) T·108 _ - Ø278' 81pf, 4f20.004) 114æ' -11628' (IIcHIId. pllfd, 1~) gear . 91147'. (1IIOIa_ pert'd .wI02) -.....""CMlnq¡ r, 29ppf, L~, 8 to 9928' . ; Cmnt with 172 Þbl of 11.0 PAl u.crete IIIed ~ BS ~ er 16..8 PPII "0" .... ':m", . ppI, L-SQ, 5T-L liner frOII'I 11801' - 10678' Saker ZXP peoker, ~MO fIner'ltanger .. tllbai:k lIIew atØ801' ' C8ll'lll'ltfld wIII'I S5 ÞbI of 15.8 PPIiI "Q" Drawn by. JOE June 26, ~ e e WELL LOG TRANSMITTAL 1', ' ;JD /-- /ûtJ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 RE: MWD Fonnation Evaluation Logs B-30A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 B-30A: LAS Data & Digital Log Images: 50-029-21542-01 1 CD Rom I, ,.~/-¡ t'1~Lh ' JlgØ/D~ e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc ) STATE OF ALASKA ) ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATlO,NS 1. Operations Performed: Abandon D Alter Casing D Change Approved Program D 2004 "',e"' Stimulate D OtherD WaiverD Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 201-1050 6. API Number 50-029-21542-01-00 RepairWellD PluQ PerforationsD Pull Tubing 0 Perforate New Pool 0 Operation Shutdown 0 Perforate [KJ 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 82.30 8. Property Designation: ADL-0028310 11. Present Well Condition Summary: Total Depth measured 12859 feet Effective Depth true vertical 9036.6 feet measured 12200 feet true vertical 9030.2 feet Casing Conductor Liner Liner Liner Liner Liner Production Surface Length 80 1510 21 536 158 1902 9513 2640 Perforation depth: Size 20" 91.5# H-40 7" 29# L-80 3-1/2" 9.3# L-80 3-3/16" 6.2# L-80 4-1/2" 12.6# L-80 2-7/8" 6.16# L-80 9-5/8" 47# L-80 13-3/8" 72# L-80 Meas u red depth: 11904 - 11979, 12023 - 12098 Tubing ( size, grade, and measured depth): True vertical depth: 9039.91 - 9036.99, 9034.22 - 9030.01 5-1/2" 17# L-80 4-1/2" 12.6# L-80 4. Current Well Class: Development 00 Stratigraphic 0 9. Well Name and Number: B-30A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD Service D Plugs (measured) 12200 Junk (measured) None MD TVD Burst Collapse 37 117 37.0 - 117.0 1490 470 9308 - 10818 8417.9 - 9006.8 8160 7020 10400 - 10421 8906.5 - 8913.3 10160 10530 10421 - 10957 8913.3 - 9019.6 10687 - 10845 8984.4 - 9010.1 8430 7500 10957 - 12859 9019.6 - 9036.6 13450 13890 35 - 9548 35.0 - 8563.5 6870 4760 36 - 2676 36.0 - 2676.0 4930 2670 @ 34 @ 9159 9159 10699 RBDMS BFL NOV 8 0 2004 Packers & SSSV (type & measured depth): 3-1/2" Baker KB Liner Top Packer 4-1/2" Baker FHL Packer 4-1/2" TIW Liner Top Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Averaqe Production or Injection Data Gas-Met Water-Bbl Casing Pressure 22.6 123 25 2.9 547 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron }j~ ~~, 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run - Daily Report of Well Operations. ! Signature Form 10-404 Revised 4/2004 Oil-Bbl 861 116 @ 10400 @ 9173 @ 10699 SCANNED DEC 0 2 2004 Tubing Pressure 857 179 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD DevelopmentŒ) Service D WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A Title Production Technical Assistant Pho~e .564-4657 OR\G\NAL; Date 11/29/04 ) ) B-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/03/04 CTU #5, ADD PERF; MIRU OS CTU #5. PERFORM WEEKLY BOP TEST. MU/RIH W/ PDS GR/CCL FOR COIL FLAG. TAG TO @ 12,1951 MD (CORRECTED TO TIE-IN LOG). LOG FROM 12,195' TO 118001 CTMD AND PAINT FLAG @ 119751 CTMD. TIE LOG IN TO SLB MCNL 6/25/01. MU/RIH W/ 251 OF SLB 2" 6 SPF PJ HMX GUN (GUN #1). PERFORATE INTERVAL 120781 TO 12103'. POOH. MU/RIH W/ 251 OF SLB 2" 6 SPF PJ HMX GUN (GUN #2). CONT ON WSR 11/4/04 ... 11/04/04 CTU #5, ADD PERF; CONT FROM WSR 11/3/04... RIH WITH GUN #2 ( 251 OF SLB 2" 6 SPF PJ HMX). PERFORATE INTERVAL 120531 TO 120781. POOH. MU/RIH W/251 OF SLB 2" 6 SPF PJ HMX GUN (GUN #3). PERFORATE INTERVAL 120281 TO 120531. PERF DEPTHS ARE CORRECLATED TO SLB CNL 6/25/01. THE ENTIRE ADD-PERF INTERVAL CORRECTED TO THE REFERENCE LOG SPEERY SUN MWD 6/24/01 WAS 120231 - 120981 MD. POOH WHILE FREEZE PROTECTING TUBING. ALL SHOTS FIRED. FLUIDS PUMPED BBLS 195 195 60/40 Methanal TOTAL Page 1 T~.= 6" McEVOY WELLHEAD = McEVOY ........................""..--.,..." ...' ,. c. .M',«"................. ACTUA TOR = OTIS KB. ELEV = 82.3" 'S'F'. tiEV ;..u..........~..... n. 46"3ï' "KÕp~.;;.^w~~_m"" ~wmmm"32^Õ'Ö' .......... .......". '.. ........... ...' ............ .......... Max Angle = 91 @ 11700' Datum MD = 10350' t5ãiÙnï"i\lb .;...... ", 8S'ÓÓï'''S'S' ) 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2676' r----4 Minimum ID = 2.37" @ 10927' 3-3/16" X 2-7/8" LNR XO 15-1/2" TBG, 17#, L-80, .0232 bpf, 10 = 4.892" 1-1 9159' I TOP OF 7" LNR 1-1 9308' 1 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 9548' 1 4-1/2"TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" 1-1 10681' 1 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184"1-1 I TOP OF BAKER WHIPSTOCK 1-1 I RA TAG 1-1 14-1/2" LNR, L-80 FL4S, ID = 3.920"1-i 10818' 1 1 1 1 1 0845' 1 0855' 12495' PERFORA TION SUMMARY REF LOG: MWD GRI RESISTIVITY ON 06/25/01 ANGLE AT TOP PERF: 90 @ 11904' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 11904 - 11979 0 06/09/04 2" 6 12023 - 12098 0 11/04/04 2" 4 12340 - 12470 C 07/23/02 2" 4 12560 - 12640 C 06/26/01 2" 4 12650 - 12670 C 07/23/02 B-30A 8 ~ I I ~ þ. ... r 1 8 .4 SAFE)OTES: WELL EXCEEDS 70° @ 10000' AND GOES HORIZONTAL @ 11000'. *** T X IA COMM. OPERATING LIMITS: MAX lAP = 2500 PSI; MAX OAP = 1000 PSI (05/27/04 W AIVER)*** I 2138' 1-1 5-1/2" OTIS HRQ SSSVN, ID = 4.562" 1 GAS LIFT MANDRELS TVD DEV TYÆ VLV LATCH 3024 8 LBD DOME RM 4533 29 LBD SO RM 5366 28 LBD OMY RA 5872 30 LBD DMY RA 6361 32 LBD DMY RM 6862 30 LBD DMY RA 7371 27 LBD OMY RA 7855 39 LBD DMY RA 8155 48 LBD DMY RM ST MD .. 9 3107 8 4823 7 5715 6 6290 5 6868 4 7447 3 8026 2 8608 1 9030 PORT DATE 16 06/17104 20 06/17104 0 06/17/04 0 03/06/86 0 03/18/04 0 03/06/86 0 03/06/86 0 03/06/86 0 03/18/04 1 9099' 1-15-1/2" OTIS XA SLIDING SLEEVE, ID = 4.562" 1 I 9159' 1-1 BAKERPBR, ID = 4.75" 1 I 9173' 1-1 9-5/8" BAKER FHL PKR, ID = 4.00" 1 I 9222' 1-1 4-1/2" OTIS X NIP, ID = 3.813" 1 ~ r 10400' 1-1 I 10412' 1-1 ~ 10412' 1-1 I 10421' 1-1 1 10681' 1-1 1 10687' I., I 10699' 1-1 3.70" BKR KB PKR, ID = 2.56" 1 3.75" BKR DEPLOYMENT SLV, ID = 3.00" I BTM OF BKR SEAL ASSY, 10 = 2.39" 1 3-1/2" X 3-3/16" XO, ID = 2.88" 1 TOP OF TIW O/S SEAL ASSY 1 TOP OF TIW POLISHED RISER 1 7" X 4-1/2" TIW PKR 1 8 ~ 4-1/2" MILLOUT WINDOW 10845' - 10855' I 10927' 1-13-3/16" X 2-7/8" LNRXO, ID = 2.37" 1 1 12200' 1-12-7/8" BKR CIBP (06/09/04) 1 PBTD 1-1 12794' 1 I 12859' 1-12-718" LNR, 6.16#, L-80 STL, .0058 bpf, ID = 2.37" 1 DA TE REV BY COMMENTS 06/09/04 SRB/KAK ADPERFS & SET CIBP 06/17104 FWE/KAK GLV C/O 07/28/04 ELHlTLP REF LOG CHANGE (6/25/01) 11/04/04 BMcLITLP ADD PERF PRUDHOE BA Y UNrT WELL: B-30A PERMrT No: 2011050 API No: 50-029-21542-01 SEC 31, T11N, R14E, 619' SNL & 1894' WEL OA TE REV BY COMMENTS 03/07/86 ORIGINAL COM PLETION 06/27/01 CTD SIDETRACK (B-30A) 07/23/02 fTLH ADD PERFS 12/04/02 JOW/TLH PERF CORRECTION (2001) 10/13/03 JLAITLP GLV C/O ON 07/02/01 3/25-5/14/04 JLJ/TLH GLV C/O OS/27/04 JLA/KAK WAIVER SAFETY NOTE BP Exploration (Alas ka) ) ) t5<ol-IO:) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 9950 I October 26, 2004 RE: MWD Formation Evaluation Logs: B-30A, AK-MW-11105 .B-30A: Digital Log Images: 50-029-21542-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:!¥- r¡é ~'Ir' 1L.J..r,~r~~~r ,:'un:¡ ~~" ~e..-.~~'. ~. ~:j ZDOt; /"""' ~ BP Exploration (Alaska), Inc. STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~ECE'VED Stimulate 0 Othe~ G 2 7 2004 WaiverD TimeAiämimJi. Gas Cons. Commissit n Re-enter Suspended Well 0 Anchorage 5. Permit to Drill Number: 201·1050 6. API Number 50-029-21542-01-00 Repair Well 0 Pull TubingD Operation Shutdown 0 PluQ Perforations[K] Perforate New Pool D Perforate IKJ 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D 2. Operator Name: 3. Address: 4. Current Well Class: Development ŒJ ExploratoryD P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 82.30 8. Property Designation: ADL-0028310 11. Present Well Condition Summary: Total Depth measured 12859 feet true vertical 9036.6 feet Effective Depth measured 12200 feet true vertical 9030.2 feet Stratigraphic D 9. Well Name and Number: B-30A 10. FieldlPool(s): Prudhoe Bay Field / Prudhoe Oil Pool ServiceD Plugs (measured) Junk (measured) 12200 None Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 37 117 37.0 - 117.0 1490 470 Liner 1510 7" 29# L-80 9308 - 10818 8417.9 - 9006.8 8160 7020 Liner 21 3-1/2" 9.3# L-80 10400 - 10421 8906.5 - 8913.3 10160 10530 Liner 536 3-3/16" 6.2# L-80 10421 - 10957 8913.3 - 9019.6 Liner 158 4-1/2" 12.6# L-80 10687 - 10845 8984.4 - 9010.1 8430 7500 Liner 1902 2-7/8" 6.16# L-80 10957 - 12859 9019.6 - 9036.6 13450 13890 Production 9513 9-5/8" 47# L-80 35 - 9548 35.0 - 8563.5 6870 4760 Surface 2640 13-3/8" 72# L-80 36 - 2676 36.0 - 2676.0 4930 2670 Perforation depth: Measured depth: 11904 -11979 True vertical depth: 9039.91 - 9036.99 Tubing ( size, grade, and measured depth): Packers & SSSV (type & measured depth): 5-1/2" 17# L-80 @ 4-1/2" 12.6# L-80 @ 3-1/2" Baker KB Liner Top Packer 4-1/2" Baker FHL Packer 4-1/2" TIW Liner Top Packer 34 9159 @ @ @ 9159 10699 10400 9173 10699 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: Oil-Bbl 660 601 Representative Dailv Averaae Production or Iniection Data Gas-Mcf Water-Bbl Casing Pressure 11.8 13 1340 32.6 38 1410 Tubing Pressure 1027 236 13 14. Attachments: ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD Development Œ] ServiceD Copies of Logs and Surveys run _ Daily Report of Well Operations_ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron )1~ Cæh-~ Title Production Technical Assistant Signature Form 10-404 Revised 4/2004 Phone ORIGINAL 564-4657 Date 8/19/04 JØll&BFL ø 3U 20M /""". .---..., B-30A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/08/04 CTU#5: GR/CCL LOG, CIBP, PERFORATING; MIRU DES CTU #5. WELL SHUT-IN UPON ARRIVAL. LOAD WELL WITH 140 BBLS KCL TO REDUCE WHP. RIH WI PDS GR/CCL IN 2.2" CARRIER AND 2.75" NOZZLE. TAG UP IN PERFS @ 12369' CTMD. LOG INTERVAL 12360' TO 11200' CTMD. FLAG PIPE AT 11925' CTMD. POOH WI LOGGING TOOLS. RIH WITH BAKER 2 7/8" CIBP. 06/09/04 SET CIBP @ 12200' 06/10104 CTU #5, ADPERF; CO NT' FROM WSR 6/09/04... POOH WI GUN #3. FP WELL TO 1750' WITH 50/50 METHANOL WHILE POOH. AT SURFACE, ALL SHOTS FIRED. RD OS CTU #5. STAND-BY FOR HIGH WINDS (>45 MPH). FLUIDS PUMPED BBlS 114 50/50 Methenal 305 1 % KCl 419 TOTAL Page 1 /'""" ...--..., lREE= 6" McEVOY WELLHfAD = McEVOY ACTIJATOR = OTIS KB. ELEV - 82.3' BF. ELEV = 46.3' KOP= 3200' Wax Angle = 91 @ 11700' 03tum MD - 10350' 03tum lVD= 8800' SS 13-318" CSG, 72#, L-80, D = 12.347" Minimum ID = 2.37" @ 10927' 3-3/16" X 2-718" LNR XO 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 9159' TOP OF 7" LNR 9308' 9-5/8" CSG,47#, L-80, ID =8.681" 9548' 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10681' 10818' 10845' 10855' 12495' ÆRFORA TON SUMMARY REF LOG: MWDGR/RESISTIVITY 0006/25/01 ANGLE AT TOP PERF: 90 @119O4' Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DA TE 2" 6 11904 - 11979 0 06109/04 2" 4 12340-12470 C 07/23102 2" 4 12560 - 12640 C 06126/01 2" 4 12650 - 12670 C 07/23102 B-30A SAFElY NOTES: WELL EXCŒCS 700@ 10000' AND GOES HORIZONTAL@ 11000'. ***T X IACOMM. OPERATING LIMITS: MAX lAP =2500 PSI; MAXOAP = 1000 PSI (05/27/04 WAlVER)-* . 2138' 5-1/2" OTIS HRQ SSSVN, ID = 4.562" GAS LIFT MANDRELS ST MD lVD DEV lYPE VLV LATCH PORT DATE 9 3107 3024 8 LBD DOME RM 16 06117/04 8 4823 4533 29 LBD SO RM 20 06117/04 7 5715 5366 28 LBD DMY RA 0 06117/04 6 6290 5872 30 LBD DMY RA 0 03106186 5 6868 6361 32 LBD DMY RM 0 03118/04 4 7447 6862 30 LBD DMY RA 0 03106186 3 8026 7371 27 LBD DMY RA 0 03106186 2 8608 7855 39 LBD DMY RA 0 03106186 1 9030 8155 48 LBD DMY RM 0 03118/04 I I 9099' 5-1/2" OTIS XA SLIDING SLEEV E. ID = 4.562" BAKERPBR, ID =4.75" 9159' 9173' 9222' 9-5/8" BAKER FHL A<R, ID = 4.00" 4-1/2" OTIS X NIP, ID = 3.813" 3.70" BKRKB PKR, D = 2.56" 7"X 4-1/2" TIN A<R I 4-112" MLLOUTWNDOW10845'-10855' 2- 7/8" LNR, 6.16#, L-80 STL, .0058 bpf, 10= 2.37" DATE REVBY COMMENTS DATE REV BY COMMENTS 03107/86 ORIGINAL COMPLETION 05/14/04 KSBlKAK GLV C/O 06127101 CTD SIDETRACK (B-30A\ OS/27/04 .LA/KAK WA W ER SAFErY NOTE 07/23102 /TLH ADD ÆRFS 06109/04 SRBlKAK ADÆRFS & SEr OBP 12/04102 JDWrrLH PERF CORRa:;TON (200 1) 06117/04 FWC'KAK GL V C/O 10/13103 JLAITLP GLV C/O ON OU)2J1J1 07/28/04 EL I-VTLP REF LOG CHANGE(6125/01) 03125/04 .LJITLH GLV C/O 03131/04 GJB/KAK GLV C/O PRUDHOE BAY UNIT W8...L: B-3OA ÆRMT!\b: 2011050 API!\b: 50-029-21542-01 Sa:; 31, T11 N, R14E, 619' SNL & 1894' W8... BP Exploration (Alaska) Permit to Drill 2011050 MD 12859 J TVD DATA SUBMITTAL COMPLIANCE REPORT 71812003 Well Name/No. PRUDHOE BAY UNIT B-30A Operator BP EXPLORATION (ALASKA) INC 9037 ,~- Completion Dat 6/27/2001 J Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-21542-01-00 UIC N REQUIRED INFORMATION Mud Log No Sample No Directional Survey ~ ~ ~..~,.. DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Medina Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments D D C [~D Ver LIS Verification Rpt Ver LIS Verification Directional Survey FINAL MWD Survey Compensated NEU/GR 2 10221 10309 12793 Case CH FINAL OH FINAL 10309 12793 OH FINAL 10309 12793 CH 1 10828 12812 Open 1 10828 12812 Open 8/3/2001 ~e221 7/10/2001 7/10/2001 8/3/2001 8/3/2001 ~0221 7/17/2002 ~3962~ 7/17/2002 10309-12793 Directional Survey, Paper Copy MWD Survey, Digital Data 10309-12793 BL, Sepia 10309-12793, Digital Data Well Cores/Samples Information: Name Start Interval Stop Dataset Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y/~:~ Chips Receiv~.d'~ y / ..u_.., Analysis "~ Y / N Daily History Received? ~ N Formation Tops ~)/N Comments: Compliance Reviewed Date: Permit to Drill MD 12859 2011050 '['VD DATA SUBMITTAL COMPLIANCE REPORT 718/2003 Well Name/No. PRUDHOE BAY UNIT B-30A Operator BP EXPLORATION (ALASKA) INC 9037 Completion Dat 6/27/2001 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-21542-01-00 UIC N WELL LOG TRANSMITTAL To: State of Alaska July 12, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs B-30A, AK-MW- 11105 1 LDWG formatted Disc with verification listing. API#: 50-029-21542-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING. AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: RECEIVED J J£ 7 2007. ~ask8 Oil l Gas Cons. Commisdon 08~01/01 Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1345 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job if Log Description Date Blueline Sepia Prints CD D.S. 18-28 ] ~ ~- o7/--/ PSP-LDL 07122/01 !B-30A 2.O I-- i ~)5 21329 MCNL 06125101 E-35A ~_O ! - ~t ? 21333 MCNL 07/03/01 K-10A -~i-- 05 ~ 21331 MCNL 06/27/01 D.S. 18-32A Zcrl-/07 21328 MCNL 06/21/01 Y-15A ~-O J '-O~/ 21334 MCNL 07/05/01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie RECEIVED ,AUG 0 5 ?.001 Received by: AJaeka 0il & Gas Cons. C0mmisei0n Anchorage STATE OF ALASKA (' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL El GAS r-'l SUSPENDED E~ ABANDONED E~ SERVICE 2. Name of Operator ~ 7. Permit Number BP Exploration (Alaska), Inc.~~ 201-105 3. Address 8. APl Number P. O. Box 196612 Anchorage, AK 99519-6612 -. , ..... ~, 50-029-21542-01 4. Location of well at sudace 9. Unit or Lease Name 619'FNL, 1894' FEL, Sec. 31 T11N, R14E, UM (asp's663737,5950025)¢ -¢':'~'-' -"'~t-' '~z"-:~"~ At Top Producing Interval~~' ~.TE ./ t 10. Well Number 1659' FNL, 3064' FEL, Sec. 30, T11N, R14E, UM (asp's 662458, 5954238) ~ /VF_~iE¢ ~ B-30A At Total Depth .~~._ .~, 11. Field and Pool 5054' FNL, 2523' FEL, SEC 19, T11N, R14E, UM (asp's 662951,5956133)~. '-'~-,~,~Di Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 82.3 feetI ADL 28305 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions June 19, 2001 June 24, 2001 June 27, 2001I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 12859' MD /9037' TVD 12794' MD /9034' TVD YES [~] No F~I 2138' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD EWR DGR & Mem GR/CCL/CNL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" X 30" sulated Condu( 0 Surface 110' 36" 8 cubic yards concrete 13-3/8" 72# L-80 Surface 2676' 17-1/2" 3255 cubic ft PFE & 465 cubic ft PF 9-5/8" 47# L-80 Surface 9548' 12-1/4" 575 cubic ft Class G 7" 26# L-80 9308' 10818' 8-1/2" 500 cubic ft Class G 4-1/2" 13.5# L-80 10699' 1084S' 6" (Orig Slotted Liner uncemented) - during P&A pumped 102 bbls Class G 3-3/16"X 2-7/8" 6.2#/6.16# L-80 10400' 12859' 3-3/4" 24 bbls Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) ;PACKER SET (MD) (2" CTC PJ carriers, 4 SPF, & Zone 2A) 5-1/2" 9158' 10699' 12560' - 12640' MD; 9035' - 9034' TVD 4-1/2" 10687' 9173' 10400' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' FP'd w/20 bbls Diesel, 28 bbl Methanol cap (See Sidetrack Summary for details) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 2, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/3/2001 2.0 Test Period >I 15219 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -194 psi 24-Hour Rate > 403 6130 34 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED * This 10-407 is submitted as directed per the 10-401 form approved June 6, 2001 (Permit #201-105) AUG 0 2,' 2001 Alaska 0il & Gas Cons, .. ,~ Arlnhnm, ,~^ Form10-407 Subr~ duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGII ) L GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR, and time of each phase. Top of Sag River Sand 9399' 8475' Top of Shublik 9446' 8503' Top of Sadlerochit 9583' 8583' Top of Zone 2C 10267' 8861' Top of Zone 2B 10358' 8892' Top of Zone 2A 10785' 9002' 31. LIST OF ATTACHMENTS Summary of B-30A CT Sidetrack Drilling Operations + End of Well Survey + Updated Schematic. 32. I hereby certify that the following is true and correct to the best of my knowledge. ~' ~" Tod Stagg Prepared by Paul Rauf 564-5799. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECE ~VE D Item 28: If no cores taken, indicate "none". Form 10-407 Alaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION Page 1 of 1 Final Well I Event Summary Legal Well Name: B-30 Common Well Name: B-30A Event Name: REENTER+COMPLETE Start Date: 6/14/2001 End Date: DATE TMD 24 HOUR SUMMARY 6/14/2001 12,500.0 (ft) Move from X to B pad 6/15/2001 12,500.0 (ft) Test BOPE. Attempt to set WS. Pull it back OOH 6/16/2001 11,392.0 (ft) Set WS. Pump LCM and cement 6/17/2001 11,392.0 (ft) Mill cement in liner 6/18/2001 11,392.0 (ft) Mill cement in slotted liner-found ID restriction 6/19/2001 10,845.0 (ft) CO liner. Set anchor, then WS. Mill starter hole 6/20/2001 10,900.0 (ft) Mill and dress window. MU drilling assy, RIH 6/21/2001 11,415.0 (ft) Drill lateral and stayed in 4-1/2" x 8-1/2" OH annulus. Sidetrack 6/22/2001 11,900.0 (ft) Test BOPE. Drill lateral 6/23/2001 12,352.0 (ft) Trip from 11966' (at CT Iockup). Swap mud. Drill lateral 6/24/2001 12,859.0 (ft) Drill to TD. MU liner 6/25/2001 12,859.0 (ft) Run and cement liner. CO liner. RIH w/CNL 6/26/2001 12,859.0 (ft) Log memory CNL/GR. Press test liner lap-failed PT. Perforate. Run PKR. 6/27/2001 12,859.0 (ft) Printed: 7/31/2001 2:53:39 PM TREE= 6" McEVOY WELLHEAD= McEVOY SAFETY NOTES: WELL EXCEEDS 70 DEG ACTUATOR= OTISB 30A @ 10OO0' A ND GOES HORIZONTAL @ KB. ELEV = 82.3' ~ 11000'. BF. ELEV = 46.3' KOP = 3200', Max Angle = 91 @ 11,700' Datum TVD = 8800' SS 113-3/8" CSG, 72~, L-80, ID= 12.347"H 2676' ~-~ k GAS LIFT MA NDRELS ST MD 'TVD DEV TYPE VLV LATCH SIZE DATE 9 3107 3024 8 LBD DV RA 1.5" 03/06/86 8 4823 4533 29 LBD DV RA 1.5" 03/06/86 7 5715 5366 28 LBD DV RA 1.5" 03/06/86 ~ 10927' I_ 6 6290 5872 30 LaD DV RA 1.5" '03/06/86 Minimum ID 2.37" 5 6868 6361 32 LBD DV RA 1.5" 03/06/86 3-3/1 6" X 2-7/8" LNR XO 4 7447 6862 30 LBD DV RA 1.5" 03/06/86 3 8026 7371 27 LBD DV RA 1.5" 03/06/86 2 8608 7855 39 LBD DV RA 1.5" 03/06/86 1 9030 8155 48 LBD DV RA 1.5" 03/06/86 ~ ~ 9099' OTIS SLIDING SLEEVE, : 4.562" 15'1/2" TBG'17#' L-80"0232bpf' ID = 4'892" H 9159' i I i i=~:= 9159' I I BAKERPBR' ID= 4'75" I ~' 2 i 9173'I---I9'5/8" BAKER FHL PKR' ID = 4'00" I 19-5/8" CSG, 47#, L-80, ID = 8.681" H 9548' I .~ · PERFORATION SUMMA RY Note: Refer to Production DB for historical perf data -'"~ 10412' ]~ BTMOF BKR SEAL ASSY, D =2.39" I S, E s.: INTERVA, Opn/Sqz DATEI 10421' I---I I 3-1/2" X 3-3/16" XO, ID =2.88" 2-7/8" 6 10800' - 10810' S 06/16/01 ~,-- I 2-7/8" 6 10842' - 10852' S 06/16/01 i/ i 10687' I~ TOP OF TIW POLISHED PJSER I 17"LNR, 29~,L-80,.0371bpf, ID=6.184"H 10818' ~_jI · I 4-1/2" ~LLOUTWHDOW10845'-10855' P~TD ~ 12791'I I DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 03/07/86 ORIGINAL COMFLETION 07/01/01 CH/KAK CORRECTIONS WELL: B-30A 12/20/00 SIS-MD CONVERTED TO CANVAS PERMIT No: 201-105 01/03/01 SIS-MD 2ND REVISION APl No: 50-029-21542-01 03/20/01 CH/TP CORRECTIONS i 619' SNL & 1894' WEL, Sec.31, T11 N, R14E 06/27/01 CTD SIDETRACK i BP Exploration (Alas ka) SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10800' - 10810' S 06/16/01 2-7/8" 6 10842'- 10852' S 06/16/01 2" 4 12560'- 12640' O 6/26/2001 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/07/86 ORIGINAL COMFLETION 07/01/01 CH/KAK CORRECTIONS 12/20/00 SIS-MD CONVERTED TO CANVAS 01/03/01 SIS-MD 2ND REVISION 03/20/01 CH/TP CORRECTIONS 06/27/01 CTD SIDETRACK BP EXPLORATION Page 1 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 6/14/2001 03:30 - 16:00 12.50 MOB PRE RD on X Pad. Move from X-15 to B-30. 16:00 - 20:30 4.50 RIGU PRE RU on B Pad. Lay herculite 20:30 - 21:30 1.00 RIGU PRE ND tree cap. Move over tree and set down 21:30 - 22:30 1.00 RIGU PRE NU BOPE 22:30 - 23:30 1.00 RIGU PRE Pull injector out of box. RU gooseneck 23:30 - 00:00 0.50 RIGU PRE Accept rig at 2330 hrs 6/14/01. Stab CT 6/15/2001 00:00 - 00:30 0.50 PERF DECOMP Spot misc equipment 00:30 - 07:00 6.50 BOPSUF DECOMP Test BOPE. Witness waived by J. Spaulding. No failures. 07:00 - 11:00 4.00 RIGU DECOMP RU flow back tanks. RU Howco encoder for CCL log depth control. 11:00 - 12:00 1.00 RIGU DECOMP Open and check well. No WHP. Bleed fow line to check lateral valve to twinned well. Wing and lateral both held. 12:00 - 12:30 0.50 STWHIP WEXlT Hold PJSM/tool box mtg with all hands. 12:30 - 13:30 1.00 STWHIP WEXlT MU TIW LX whipstock assy in pipe shed. Add Sperry ESS and Howco CCL tool, along with Baker J setting tool and Weatherford MHA. 13:30 - 15:45 2.25 STWHIP WEXlT RIH with WS assembly. Test tool at 7000'. OK. Continue RIH. 15:45 - 16:15 0.50 STWHIP WEXlT Stop at 10600' to fill coil with 2% kcl. Log from 10700 to 10813'. Print log. Add 3' correction. Total BHA: 60.55'. CCL Iocator 53' above tool btm. TOW 14' above tool btm. 16:15 - 17:30 1.25 STWHIP WEXlT RIH to 11404' (TOW at 11390'). 41k# up wt. Drop 7/16" ceramic ball. 1.1 bpm @ 2500 psi. Ball on seat at 58 bbls. Pressure up to 1800 psi to "pre" set. Hold for 5 minutes to let Sperry tool stabilize. Pressure to 4400 psi. Indication of set, but no shear. Set dn. No packer set. 17:30 - 19:30 2.00 STWHIP WEXlT POOH to check BHA. Flag EOP at 11,000' (yellow). Continue POOH. Fill down back side. 19:30 - 19:40 0.17 STWHIP WEXlT Safety mtg 're: trapped press 19:40 - 20:30 0.83. STWHIP WEXlT LD WS assy. Continue to fill hole w/charge pump at 80 bbls/hr w/no returns. Found Halco ball seat had shifted down and ball was on seat-had a little debris in ports. TIW WS okay. 20:30 - 21:45 1.25 STWHIP WEXlT Send Baker J Hyd tool to shop for inspection. Found seat had shifted up (shear pins set for 1000 psi) due to hydrostatic press when weep hole plugged. WO Sperry to change O-rings on ESS tool 21:45 - 22:30 0.75 STWHIP WEXlT MU BHA w/o Halco Depth Pro and with Baker inflation valve assy 22:30 - 00:00 1.50 STWHIP WEXlT RIH w/BHA #2 6/16/2001 00:00 - 00:30 0.50 STWHIP WEXlT RIH and set down at 10993'. Work several times and get thru it, 36.5K 00:30 - 01:00 0.50 STWHIP 3 WEXlT Corr to flag -14.2' at 11000'. RIH to set depth 01:00 - 01:55 0.92 STWHIP 3 WEXlT Launch 1/2" alum ball and circ to seat w/53 bbls KCI water. Pressure up to 1950 psi and hold for Sperry SS to shoot a few 3ics. Press up to 2180 and set WS. Wait for a few more pics. Stack 5K to verify set. Top of WS is at 11390' 01:55 - 03:30 1.58 STWHIP 3 WEXlT POOH filling from BS-still no returns, losing 60-80 bbls/hr KCI water. Found FL @ 3200' 03:30 - 04:00 0.50 STWHIP 3 WEXlT LD WS assy. SS data shows WS face at 120L 04:00 - 06:30 2.50 STWHIP ~ WEXlT MU cement nozzle assy and RIH. Mix 30 bbl LCM pill in pill pit. Tqg WS @ 11396'. Corr to pinch pt at 11392' 06:30 - 07:15 0.75 STWHIP 3 WEXlT Start LCM pill, SI @ choke. Bull head LCM at 1.5 bpm. Some ~ncrease in CT pressure but no rtns. Printed: 7/2/2001 11:28:38 AM BP EXPLORATION Page2 of lO Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity: Code N PT Phase Description of Operations 6/16/2001 07:15 - 08:00 0.75 STWHIP P WEXlT POOH to 10800'. 08:00 - 10:00 2.00 STWHIP P WEXlT Mix 100 bbls 55 ppb Icm at MI plant. 10:00 - 11:30 1.50 STWHIP P WEXlT Pump 100 bbls Icm @ 2.8 bpm. Began to get partial returns after 40 bbls out of pipe. Close choke and bullhead +~-20 bbls. No increase in WHP. 11:30 - 12:15 0.75 STWHIP P WEXlT POOH and lay in remaining 60 bbls Icm at 1:1. POOH to 8000'. 12:15 - 14:00 1.75 STWHIP P WEXlT Circulate across top while waiting for dirty va¢ truck 14:00 - 15:00 1.00 STWHIP P WEXIT RU DS cementers. Spot KCL & dirty vac trucks. 15:00 - 15:45 0.75 STWHIP P WEXIT Batch.mix 50 bls Class G, 15.8 ppg cement. 15:45 - 16:00 0.25 S'I'WHIP P WEXIT Hold PJSM before pumping cement. 16:00 - 17:45 1.75 STWHIP P WEXlT Test lines to 5000 psi to clear coil. Pump 10 bbls water, 10 neat, 30bbls 20ppb aggreg, 12 bbls neat. RIH with CT to 10800'. Establish 50% rtns while displacing cmt to nozzle. Close choke and squeeze cmt at 2.0 bpm @ 100-150 psi WHP. Slow rate to 1.0 bpm. Max WHP 100 psi. POOH to safety at 9700'. Circ at min rate. No returns. CIP at 1730. 17:45 - 18:15 0.50 STWHIP P WEXIT Hold safety mtg with night crew/cmtr's. Mix batch #2 18:15 - 19:35 1.33 STWHIP' P WEXIT Swap to pump #2 dn CT, pump #1 dn BS. RIH 30'/min from 9700' 1.0/1.0 bpm's w/choke closed 470 psi WHP 19:35- 19:55 0.33 STWHIPP WEXIT Tag at 10786'. PUH. Swapto CT only and jet 2.0 bpm. Jet thru 10786' easy and set down at 10804'. Jet to 10806' 2.5/400 psi WHP and no further progress 37k, 20k 19:55 - 20:15 0.33' STWHIP P WEXIT DS cementers load CT w/50 bbls 15.8 ppg G cmt as in job #1. Cmt TT is 5+ hrs. Displace cmt w/KCI wter and jet at 10806' 3.0/550 psi whp and get to 10817' just prior to cmt arrival 20:15 - 20:50 0.58 STWHIP P WEXIT Cmt @ noz at 10800'. PUH 3'/rain 48k. Displace first 19 bbls at 2.1/650 whp psi unitl catching fluid. Displace next 17 bbls at 1.9/1100 psi whp. Displace next 6 bbls at 1.0/1100 psi whp. Bleed whp to zero and lay in last 8 bbls from 10740'-10200'. Had nearly 1/1 returns 20:50 - 22:15 1.42 STWHIP;P WEXIT POOH and let cement settle. Will need to clean out below top perfs at 10800' to see if we've done any good 22:15 - 22:30 0.25 STWHIP P WEXIT LD cementing BHA 22:30 - 23:15 0.75 STWHIP P WEXIT MU milling BHA. Hole staying full 23:15 - 00:00 0.75 STWHIP P WEXIT RIH w/BHA #4 (3.74" junk/cmt mill) 6/17/2001 00:00 - 01:00 1.00 STWHIP P WEXIT RIH w/milling assy (Weatherford tool string) 01:00 - 01:30 0.50 STWHIP P WEXIT Precautionary ream 40'/min from 9300' 2.5/2000 full returns 01:30 - 02:00 0.50 STWHIP P WEXlT Precautionary ream 20'/min from 10200' 2.4/1960 full returns 02:00-02:30 0.50 S'I'VVHIP P WEXIT A few minor stringers to10750', no stalls. PUH slow and circ hi vis Fie Vis pill to mill while WOC 2.3/1920. Losing about 0.1 bpm 02:30 - 03:50 1.33 S'I'WHIP P WEXIT Backream while chase pill OOH from 10750-9100' at 2.7/2400 psi. Recovered less than a bbl of cement fines. RIH 03:50 - 04:35 0.75 STWHIP 3 WEXIT Cement UC^ @ 1240 psi. Ream liner looking for cement from 10750' 2.7/2.6 @ 1870. First stall at 10772' and mill firm cement from here at 100'/hr to 10788'. Numerous weak stalls at 10788' and no further progress. Losing 0.2 bpm at rate 04:35 - 06:20 1.75 STWHIP 3 WEXIT POOH for motor. DS mechanics work on injector (1/2) 06:20 - 07:00 0.67 S'I'WHIP 3 WEXIT LD Weatherford motor & MHA. MU Baker motor and DS MHA 07:00 - 08:45 1.75 STWHIP ~ WEXIT RIH with clean out assy BH^ #4 08:45 - 10:30 1.75 STWHIP 3 WEXIT Tag cement at 10787'. 39k# up, 22k# dn wt. 1800 psi@2.6 bpm. Losing 0.2 bpm. Stall twice. Milling ahead at 60 fph. Printed: 7/2/2001 11:28:38 AM BP EXPLORATION Page 3 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity COde NPT Phase Description of Operations 6/17/2001 08:45 - 10:30 1.75 STWHIP P WEXlT 200-300 dpsi. Mill to 10835'. Stalling very often, avg 10 fph. 10:30 - 12:45 2.25 STWHIP P WEXlT POOH for milI/BHA. 12:45 - 13:15 0.50 STWHIP P WEXlT MU 3.74" used 5 bladed pdc bit. Cement mill showed a lot of scarring on extended gauge surfaces. 13:15 - 14:00 0.75 STWHIP P WEXlT RIH. Stop at 600'. Wait for mechanics to inspect injector chain alignment. 14:00 - 14:45 0.75 STWHIP P WEXIT POOH. Adjust injector skates. Check same. 14:45 - 15:15 0.50 STWHIP P WEXlT Change out 3.75" pdc bit for 3.70" bit. 15:15-17:00 1.75 STWHIP P WEXlT RIHw/BHA#5. Tag TDat 10,835'. 39k#up, 19k#dnwt. 2000 psi@ 2.7 bpm. 17:00 - 18:15 1.25 STWHIP P WEXlT Mill to 10906'. Several stalls. 18:15 - 19:00 0.75 STWHIP! P WEXlT Get to 10908' With lots of stalls and miserablly slow penetration rate 19:00 - 20:40 1.67 STWHIP'P WEXlT POOH for mill. Losing 0.1-0.2 bpm at rate 20:40 - 21:00 0.33 STWHIP P WEXIT Change mill to Weatherford 3.70" "Chump" (short insert nearly flat bottom mill). Bit had one chipped cutter on taper 21:00 - 22:45 1.75 STWHIP P WEXlT RIH w/BHA #6 22:45 - 23:00 0.25 STWHIP P WEXlT Precautionary ream 10750-908' 23:00 - 00:00 1.00 STWHIP P WEXlT Mill cement from 10908' 2.6/2.5 @ 2170 6/18/2001 00:00 - 00:30 0.50 STWHIP P WEXlT Mill cement to 10915' and going no where fast 00:30 - 02:10 1.67 STWHIP P WEXlT POOH for mill 02:10 - 02:50 0.67 STWHIP P WEXlT . Change out the Chump for a 3.70" DS49 bit. Change packoff. I Chump had no wear except that steel body gauge just above cutters appeared pinched to 3.65" for 1/8" 02:50 - 04:45 1.92 STWHIP N DPRB WEXlT RIH w/BHA #7 04:45 - 05:00 0.25 STWHIP N DPRB WEXlT Precautionary ream from 10750-915' 05:00 - 05:30 0.50 STWHIP N DPRB WEXlT Attempt to mill from 10915' and too grabby. This cmt is hard! No progress 05:30 - 07:00 1.50 STWHIP N DPRB WEXlT POOH for dia mill 07:00 - 07:45 0.75 STWHIP N DPRB WEXlT At surface. Change motor & bit. DS49 had several broken cutters. MU 3.72" HC DSM window mill. 07:45 - 09:30 1.75 STWHIP N DPRB WEXlT RIH with mill assy (BHA #8). Tag TD & correct to 10915'. 09:30-11:45 2.25 STWHIP N DPRB WEXlT Millcement. 39k#up, 19k#dnwt. 2000psi@2.5bpm. Millto 10923'. Begin stalling. Unable to make any progress. 11:45-13:15 1.50 STWHIP N DPRB WEXlT Pull out of hole to check BHA & MHA. 13:15 - 14:30 1.25 STWHIP N DPRB WEXlT LD BHA. DSM had substantial wear on radius from gauge to nose bevel. Re-runable, but a lot of wear for "cmt". Test MHA & connector. Ok. Replace same. 14:30 - 16:30 2.00 STWHIP N DPRB WEXlT RIH with cement mill assy (BHA #9) (weatherford 3.72" cmt mm mill with cut down gauge pads) 16:30 - 17:30 1.00 STWHIP N DPRB WEXlT Tag up at 10923'. Mill on cement. 2000 psi @ 2.7 bpm. Several stalls 17:30 - 18:00 0.50 STWHIP N DPRB WEXlT Pump 2 ppb bio sweep with 5% lubtex. No change/no progress. 18:00 - 19:50 1.83 STWHIP N DPRB WEXlT POOH. Discuss. Will dress 4-1/2" 12.6# solid liner (3.958" ID) m preparation to set a Baker Torque Master WS 19:50-20:20 0.50 STWHIP N DPRB WEXlT LD junk mill. MU 3.80" dia mill. Junk mill had wear at gauge to 3.65". Abnormal metal shavings over shaker 20:20-21:55 1.58 STWHIP N DPRB WEXlT RIHw/BHA#10 21:55 - 23:20 1.42 STWHIP N DPRB WEXlT Precautionary ream 2.4/1900 30'/min from 9300', 20'/rain from 9750' 2.7/2350. No motor work 23:20 - 00:00 0.67 STWHIP N DPRB WEXlT Tag and stall at 10871' CTD which is XO from solid to slotted liner (ID change). Ream 10800-871' several times slow. Flag Printed: 7/2/2001 11:28:38 AM BP EXPLORATION page. 4 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description Of Operations 6/18/2001 23:20 - 00:00 0.67 STWHIP N DPRB WEXlT CT @ 10700' EOP 6/19/2001 00:00 - 02:00 2.00 STWHIP N DPRB WEXlT POOH for WS assy. Backream 10871-9300' 40'/min. Still losing 10-15 bbl/hr 02:00 - 02:20 0.33 STWHIP N DPRB WEXlT LD milling assy. Mill had no wear 02:20 - 03:10 0.83 STWHIP N DPRB WEXIT MU WS assy (Baker 4-1/2" Torque Master Packer w/Sperry ESS, 102.65' OA) 03:10 - 05:30 2.33 STWHIP N DPRB WEXIT RIH w/BHA #11. Set down thrice at 10687' CTD and twice at 10700'. TIW SBR and Packer area. Corr -2.0' at flag. RIH to set depth, 36.5k, 20.5k 05:30 - 06:25 0.92 STVVHIP N DPRB WEXIT Park at set depth of 10865' at bottom of anchor. Load 5/8" phenolic ball. Circ to seat with KCI water at 51.6 bbls. Pressure up to 2000 psi and hold for 5 min while Bud takes a few pics. Pull off of anchor at 37K 06:25 - 08:30 2.08 STWHIP N DPRB WEXIT POOH for whipstock 08:30 - 09:30 1.00 STWHIP N DPRB WEXIT Lay down ESS & J setting tool. Down load ESS data. Setting lug oriented to 214L of HS. MU Baker window master on running tool. 09:30 - 12:30 3.00 STVVHIP N DPRB WEXIT RIH with tray assy. 12:30 - 13:15 0.75 STVVHIP N DPRB WEXIT COrrect to 10800' EOP flag (-5' correction). 38k# up, 19k# dn wt. Work pipe to relax swivel. Tag & latch at 10865'. Pull to 49K# to shear free. TOW at 10845'. RA tag at 10855'.' 13:15- 14:30 1.25 STVVHIP N DPRB WEXlT POOH for starter mill. ~ 14:30 - 15:00 0.50 STWHIP P WEXlT Hold safety stand down to discuss importance of awarness working high energy systems and driving. 15:00 - 15:30 0.50 STWHIP P WEXlT Cut 400' pipe before starting window. 15:30 - 16:15 0.75 STWHIP P WEXlT MU Baker 3.8" starter mill on straight motor BHA. 16:15 - 18:15 2.00 STWHIP P WEXlT RIH with BHA #13 18:15 - 18:35 0.33 STWHIP P WEXlT Tag whipstock. Subtract 8' correction to 10845'. 2.5 bpm@1950. 39k# up, 19k# dn wt. 18:35 - 20:25 1.83 STWHIP P WEXlT Mill notch 10845-10846.5'. Still losing 10-15 bbl/hr 20:25 - 22:00 1.58 STWHIP P WEXlT POOH for window mill 22:00 - 22:25 0.42 STWHIP P WEXlT LD starter mill. MU used 3.80" dia window mill and 3.80" SR 22:25 - 00:00 1.58 STWHIP P WEXlT RIH w/BHA #14 6/20/2001 00:00 - 00:30 0.50 STWHIP P WEXlT Continue RIH w/BHA #14. Tag dry at 10846.5' CTD, wet at 10845.5'. No corr 00:30 - 02:00 1.50 s'rVVHIP P WEXlT Mill window from 10845.5' 2.8~2.6 @ 2340. Swap to new FIo Pro mud 02:00 - 03:00 1.00 STWHIP P WEXlT Milling at 10847.5' 2.7/2.4 2320, 10848.5' 2.6/2.1 @ 2470 with hole completly displaced 03:00 - 04:00 1.00 STWHIP P WEXlT 10850.0' 2.6/2.1 @ 2450 04:00 - 04:50 0.83 STWHIP P WEXlT 10851.0' 2.6/2.3 @ 2500 04:50 - 05:20 0.50 STWHIP P WEXlT 10855.0' 2.7/2.5 @ 2550 Drilling formation at 10855'. At 10858' losses increased to 2.2/1.4 @ 2250 05:20 - 05:40 0.33 STWHIP P WEXlT Several stalls at 10860.5' 2.3/2.0 @ 2070 05:40 - 05:55 0.25 STWHIP P WEXlT Mill to 10863' and call it good. Begin reaming passes and can't get back down to top of WS. Losses increased to 2.0 bpm for 'a while, but healed slowly? 05:55 - 07:15 1.33 STWHIP P WEXlT ,Wiper to 5-1/2" to check 4-1/2" liner for debris-more mud onl location. Back to losing 0.2 bpm at rate 07:15 - 10:15 3.00 STWHIP P WEXlT Resume dress window. Continue to see bobbles at 10848 & 10854'. Unable to drift dry. 10:15- 12:00 1.75 STWHIP P WEXlT POOH for dressing assy. 12:00 - 12:45 0.75 STWHIP P WEXlT LD window mill & short string reamer (mill gauged at 3.79, Printed: 7/2/2001 11:28:38 AM BP EXPLORATION Page5 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations , , 6/20/2001 12:00 - 12:45 0.75 STWHIP P WEXlT reamer 3.8"). MU 3.8" crayola with long string mill (3.8). 12:45 - 15:00 2.25 STVVHIP P WEXlT RIH with dressing mill assy. 15:00 - 17:15 2.25 STWHIP P WEXlT Ream/dress window. Had good motor work at 10851', (Middle of whipstock), continue to ream down and backream as needed. Losing 0.2 bpm. 17:15 - 18:00 0.75 STWHIP P WEXlT Drift dry 2 x. Able to get through the window, but some driag at 10843'. Continue to work window. 18:00 - 19:35 1.58= STWHIP P WEXlT Window appears to be in good shape, POOH to check mill for gauge, and pick up drilling BHA. 19:35 - 19:55 0.33: STWHIP' P WEXIT Kick drill. LD milling BHA 19:55 - 20:30 0.58 STWHIP P WEXIT MU drilling BHA w/res 20:30 - 21:20 0.83 STWHIP P WEXIT Upload res 21:20 - 23:15 1.92 STVVHIP P WEXIT RIH w/BHA #16 23:15 - 23:40 0.42 STVVHIP P WEXIT Check TF at 125L at 10800' 2.6/2.5 @ 2850. Orient high side. RIH thru window with a few bobbles and tag TD at 10870' CTD at 5R-no corr. Orient to right. 36K, 20K 23:40 - 00:00 0.33 STWHIP P WEXIT Drilling 60-120'/hr 2.6/2850/65R with full returns! Muse, muse 6/21/2001 00:00 - 01:00 1.00 DRILL P PROD1 Drilling 120'/hr. Sperry having trouble w/GR (counts are wrapped 3 times on 0-150 scale) so can't log to see where we ~ are (were). Drill to 10979' and Gee blinked. Resistivity shows btm of window at 10855' CTD 01:00 - 03:00 2.00 DRILL !N DPRB PROD1 Wiper to window. Log tie-in in 4-1/2" liner from 10790' logging up and determine GR tool is working correctly, but there are no markers to correlate with. RIH thru window at 100R and minor bobbles thru window. Log down from 10880' to see if GR counts repeat, yup, still off scale. RIH to TD 03:00 - 04:40 1.67 DRILL P PROD1 Drilliing 80-140'/hr 10979-11100' 2.6/2850/90R when pump #2 went down 04:40 - 05:00 0.331 DRILL P PROD1 Wiper to window 05:00 - 06:30 1.50 DRILL P PROD1 Drilling 60-90'/hr 11100-11196' 06:30 - 07:00 0.50 DRILL P PROD1 Update at 06:30 hrs. 11198', drilling ahead. 2.6 bpm, 3050 psi, 1 for 1 returns. Appear to be tracking original open hole (81/2"). 07:00 - 07:50 0.83 DRILL P PROD1 Appear to be tracking old open hole. Also, GR not reading correctly. May be an artifact of old open hole. PUH to top of Sadlerochit for a tie in pass. 07:50 - 09:40 1.83 DRILL P PROD1 9600', log tie in pass down. Make a +8' correction. RIH to 10700', log GR spike for future tie in passes. Make a +5' correction based on spike at 10700'. Flag pipe at 10690.5', EOP flag at 10600'. 09:40- 11:15 1.58 DRILL P PROD1 POOH. 11:15 - 11:45 0.50 DRILL P PROD1 Tag up at surface, CO DS-49 with M-09. DS-49 all cutters at leading edge of gauge section chipped badly. Adjust motor to 2 degrees. 11:45 - 12:15 0.50 DRILL P PROD1 Fire drill, and post drill safety discussion. 12:15 - 14:00 1.75 DRILL P PROD1 RIH with BHA #17. 14:00 - 14:35 0.58 DRILL P PROD1 Stop at flag. Make +5 correction. Continue to RIH. Thru window ok. Tag at 11262.5' 14:35 - 14:55 0.33 DRILL P PROD1 Tool face 90R, Drill ahead at 2.5 bpm, 2850 psi free spin, 1 for 1 returns, Drill ahead 10' to ensure clean cement top/ramp at 160 f/hr and 2950 psi on motor work. Very little motor work to drill. 14:55 - 17:30 2.58 DRILL P PROD1 Never found good hard cement, but did get to the point we had Printed: 7/2/2001 11:28:38 AM BP EXPLORATION Page6 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity COde NPT Phase Description of OPerations · 6/21/2001 14:55 - 17:30 2.58 DRILL P PROD1 400 lbs motor work and some reactive torque. Flag pipe at 11290'. Begin troughing from 11290'-11270'. 17:30 - 19:30 2.00 DRILL P PROD1 11290', begin time milling, 6/hr, 90R 19:30 - 20:00 0.50 DRILL P PROD1 11300', start pushing and see incl change at 11270'. Res confirmed departure later 20:00 - 23:10 3.17 DRILL P PROD1 Drill ahead and get az readings. Then get a believable GR. Life is good again. Drill a few feet at a time (wi TF 70-100R and survey to pick POOH point based on projections. Drill to 11415' 2.5/2920/90R 23:10 - 23:30 0.33 DRILL P PROD1 Wiper to window 23:30 - 00:00 0.50 DRILL P PROD1 POOH for lateral motor 6/22/2001 00:00 - 01:15 1.25 DRILL P PROD1 Finish POOH 01:15 - 02:15 1.00 DRILL P PROD1 LD drilling BHA and download res data 02:15 - 07:00 4.75 DRILL P PROD1 Weekly BOPE test. Witness waived by AOGCC 07:00 - 07:15 0.25 DRILL P PROD1 BOP test completed ok, hold safety meeting prior to picking up . BHA. 07:15 - 08:45 1.50 DRILL 'P PROD1 !Make up BHA #18. 1.0 deg motor, 3.75" Hycolog DS49 bit. 08:45 - 10:45 2.00 DRILL P PROD1 RIH with BHA #18. Took 3 bbls to fill up well after BOP test. Well is apparantly taking fluid at about 1/2 bbl/hr. Shallow hole test of MWD ok. 10:45 - 11:05 0.33 DRILL P PROD1 Log tie in pass down from 10700'. Make +4' correction. 11:05 - 11:45 0.67 DRILL P PROD1 Orient around to 45R, RIH through window with pumps at minimum. No problems seen. Bring pumps on and continue RIH. Make it through sidetrack at 11390' ok. Orient to 90R, Tag at 11417', tool face fell around to 170L.Pickup to orient. 11:45 - 12:20 0.58 DRILL P PROD1 Orient around to 90 deg. 12:20 - 12:40 0.33 DRILL P PROD1 On bottom drilling. 2.5 bpm, 3000 psi free spin, 3200 psi drilling, 90R TF, 110 fpm. Start drilling at 11417'. 12:40- 12:50 0.17 DRILL P PROD1 Orienting. 12:50- 14:30 1.67 DRILL P PROD1 11475', resume drilling. 14:30 - 15:20 0.83 DRILL P PROD1 11600', wiper trip to window. Orient TF to high side so as to inet damage bit in annular near old wellbore. Orient to 90R lwhen running through OH sidetrack interval. (11370'). 15:20 - 15:35 0.25 DRILL P PROD1 ~Orient 90L 15:35 - 16:30 0.92 DRILL P PROD1 11600', resume drilling. 2.5 bpm, 2850 psi free spin, Drilling at 2950 psi, TF90L, I for 1 returns, 72 fph ReP, Pit vol=319 bbls. 16:30 - 17:30 1.00 DRILL P PROD1 11665', Update at 16:30. Continue drilling, 2.5 b/m, lost 4 bbls mud in past 1 hour. Pit vol 315 bbls. 17:30 - 18:30 1.00 DRILL P PROD1 11699', Update at 17:30. Continue drilling, 2.6 bpm, lost 3 bbls mud in past 1 hour. Pit vol 312 bbls. Drill to 11750' 18:30 - 19:30 1.00 DRILL i p PROD1 Wiper to window, clean. RIH. Orient to 78R thru sidetrack area. RIH, clean 19:30 - 19:45 0.25 DRILL P PROD1 Orient around from 80L 19:45 - 22:00 2.25 DRILL P PROD1 Drilling 2.8/3000/94L 11750-900' 22:00 - 22:30 0.50 DRILL P PROD1 Wiper to window 22:30 - 23:15 0.75 DRILL P PROD1 Log tie-in from 10730-689' 2.4/2660/21L 23:15 - 00:00 0.75 DRILL P PROD1 Add 14', RIH. Tag at 10870' at 27L. Orient to 30R. RIH to TD @ 11912' 6/23/2001 00:00 - 00:15 0.25 DRILL P PROD1 Orient around to begin building angle to find some oil. Now in water at 8957' TVD 00:15 - 02:45 2.50 DRILL P PROD1 Drilling 2.6/2940/40R 11912-966'. Had trouble making hole from 11950' due to length and OD of tool string, 180 deg TF change. Ream and backream to 11850' and had no more Printed: 7/2/2001 11:28:38 AM BP EXPLORATION Page7 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: i Date From - To Hours Activity Code NPT Phase Description of OPerations 6/23/2001 00:15 - 02:45 2.50 DRILL P PROD1 progress at 11966'. Stack max and had no motor work 02:45 - 03:10 0.42 DRILL P PROD1 Wiper to window 03:10 - 03:45 0.58 DRILL P PROD1 Tie-in, add 3.0'. Flag at 10200' EOP 03:45 - 05:30 1.75 DRILL P PROD1 POOH to check BHA 05:30 - 06:05 0.58 DRILL P PROD1 Change out bit and motor 06:05 - 08:00 1.92 DRILL P PROD1 RIH w/BHA #19 08:00 - 08:40 0.67 DRILL P PROD1 Stop at EOP flag at 10200', add +9'. Continue RIH. 08:40 - 09:00 0.33 DRILL P PROD1 Tag up at 11964', resume drilling. 2.6 bpm, 3050 free spin, Drilling at 3200 psi, TF 901:{, 100% returns. Drilling at 90 fph. 09:00 - 09:30 0.50 DRILL P PROD1 11973', Having trouble getting weight to bit. Having to drilling with 8klbs string wt. Shot trip up. Getting real draggy pickup. Kept dragging as we came up hole, possibly like something was beside the BHA. 09:30 - 10:45 1.25 DRILL P PROD1 Back on bottom. Getting 12klbs string weight now. Resume drilling. Make a few ft, then getting more drag, and poor weight transfer. Send directional data to DS, ask for coil cade. Ask mud man to bring lubtex from deadhorse for lub/sweep. Call for mud swap, new mud to have 6% lubetex. 10:45- 11:00 0.25 DRILL P PROD1 Backream. 11:00 - 11:25 0.42 DRILL P PROD1 No progress, looks as if we are at coil lock up. 11:25 - 15:10 3.75 DRILL P PROD1 PUH to window to wait on pill and new mud. 15:10 - 15:20 0.17 DRILL P PROD1 New mud on location. Orient to 45R, start pumping pill with 10% lubtex, followed by new mud. 15:20 - 16:00 0.67 DRILL P PROD1 RIH. Didn't see any weight at window. 16:00 - 17:50 1.83 DRILL P PROD1 Back on bottom. New mud to bit, resume drilling. 12010', 2.5 bpm, 3200 psi drilling, 1 for 1 returns. 17:50 - 19:35 1.75 DRILL P PROD1 12167', Short trip to window. 19:35 - 20:15 0.67 DRILL P PROD1 Drilling 90'/hr 2.6/3000/90R 12167-210' 20:15 20:40 0.42 DRILL P PROD1 Work to get thru something hard at 12210' (fault?). Flopped TF 180 deg. Orient around 20:40 - 22:50 2.17 DRILL P PROD1 Drilling 90'/hr 2.5/2980/90R 12210-352' 22:50 - 23:30 0.67 DRILL P PROD1 Wiper to window 23:30 - 23:55 0.42 DRILL P PROD1 Tie-in 23:55- 00:00 0.08 DRILL P PROD1 Add 10.0', RIH 6/24/2001 00:00 - 00:55 0.92 DRILL P PROD1 Fin RIH and tag at 12361' (8943' TVD). Orient to hold 88 deg to TD 00:55- 02:45 1.83 DRILL !P PROD1 Drilling 150'/hr 2.7/3100/140L 12361-12510' 02:45- 04:45 2.00 DRILL !P PROD1 Wiper to window, clean 04:45 - 05:50 1.08 DRILL ~ P PROD1 Drilling 90'/hr 2.6/3070/70L 12510-622' 05:50 - 06:15 0.42 DRILL P PROD1 Orient around 06:15- 06:25 0.17 DRILL :P PROD1 Drilling 90'/hr 2.7/3100/105L 12622-650' 06:25 - 08:40 2.25 DRILL P PROD1 Wiper to window 08:40 - 10:30 1.83 DRILL P PROD1 Back on bottom, resume drilling. 2.6 bpm, 3400 psi, 1 for 1 returns. 10:30 - 12:00 1.50 DRILL P PROD1 12810', Short trip. 12:00 - 13:00 1.00 DRILL P PROD1 Resume drilling. 13:00 ~ 14:30 1.50 DRILL P PROD1 TD well at 12850' CTM uncorrected. Short trip to shoe to condition for liner. No overpull or drag seen on way up. 14:30 - 14:55 0.42 DRILL P PROD1 Log tie in pass down at 10700'. Make +14' correction. 14:55 - 16:00 1.08 DRILL P PROD1 RIH to tag and start MAD pass. No loss of weight or drag seen on way in. 16:00 - 17:45 1.75 DRILL P PROD1 Tag TD at 12859' (8954' TVD) corrected to ELM. Start MAD pass up at 20 fpm. No overpulls seen on MAD pass Printed: 7/2/2001 11:28:38 AM BP EXPLORATION Page'8 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From To Hours Activity Code NPT Phase Description of Operations 6/24/2001 16:00 - 17:45 1.75 DRILL P PROD1 If you're interested in trivia-TD is 9036' TVD nearly directly below the BOC! 17:30 - 19:00 1.50 DRILL P PROD1 POOH to run liner. 19:00 - 19:45 0.75 DRILL P PROD1 LD drilling BHA 19:45 - 21:00 1.25 DRILL P PROD1 Download res data and LD tools 21:00 - 21:45 0.75 CASE P COMP RU to run liner 21:45 - 22:00 0.25 CASE P COMP Safety mtg re: liner 22:00 - 00:00 2.00 CASE P COMP MU 60 jts 2-7~8" 6.16# L-80 STL and 16 jt 3-3/16" 6.2# L-80 TC11 tubing w/float equip and pup 6/25/2001 00:00 - 01:15 1.25 CASE P COMP Fin MU liner. Kick drill using 2-3/8" safety jt on 3-3/16" pipe went well 01:15 - 02:10 0.92 CASE P COMP MU Baker CTLRT. Install Baker CTC. PT @ 35K, 3500 psi 02:10 - 03:40 1.50 CASE P COMP RIH w/liner 03:40 - 04:15 0.58 CASE P COMP 38.4K, 20K @ 10800' 04:15 - 04:45 0.50 CASE P COMP RIH to TD @ 12848' CTD w/nary a bobble. Recip 40' 42.5k, 13.8K clean. Load 5/8" steel ball. Circ ball to seat at 47.9 bbls and sheared at 3800 psi. Released from liner at 32K 04:45 - 06:00 1.25 CASE P COMP Displace mud w/2% KCl water 3.013030 06:00 - 06:45 0.75 CASE P COMP RU DS cementers. Mix cement 06:45 - 07:05 0.33 CASE P COMP Hold PJSM with cementers, DS CT crew, rig crew, et al. 07:05 - 07:20 0.25 CASE P COMP Continue to circulate, waiting on cementers to mix. 07:20 - 08:20 1.00 CASE P COMP Pump 2 bbls water, PT hardlines to 4000 psi, ok. Online with cement. Pump 23.9 bbls of cement mixed as per proceedure. Drop dart, pump 2 bbls water, swap to rig pumps, resume pumping chasing dart. Pump 2 more bbls with rig pumps, SD check dart away ok. Resume pumping. Latched into liner wiper plug ok, sheared, Continue displacing cement. Pumping 1.5 bpm/getting back 1.2 bpm. Landed wiper plug into latch collar at 14.0 bbls away (Calculated 14.7 bbls). Pressure up to 1000 psi over. Confirm good latch. Bleed down pressure, floats holding ok. Lost 3 bbls cement to formation while displacing liner wiper dart. 08:20 - 10:15 1.92 CASE P COMP Kick on pumps, stab out of liner ok PUH washing contaminated cement ahead of us. Wash liner top prior to POOH. 10:15 - 10:55 0.67 CASE P COMP Tab up at surface. Lay down CTLRT. Recovered all, ok. Rig up mill and motor to clean out 2-7/8" liner. 10:55 - 11:15 0.33 CASE P COMP Safety meeting prior to picking up CSH work string. 11:15 - 13:45 2.50 CASE P COMP Make up Mill and motor, stab in hole, make up CS hydrill work string. 13:45 - 14:00 0.25 CASE P COMP Make up DS MHA, make up injector. 14:00 - 16:10 2.17 CASE P COMP RIH with BHA #20 16:10 - 16:40 0.50 CASE P COMP Tag top of cement at 12690' CTM. Mill cement at 3 fpm. Mill to 12776' CTM, got drilling break, hard drilling, and a stall. Picked up 3 times and repeated. Probably latch collar. Discontinue further milling. 16:40- 17:10 0.50 CASE P COMP POOH 17:10 - 17:40 0.50 CASE N UFAL COMP Dowell power pack making unusual noises. Call for mechanics, shut down power pack. Drop 5~8" ball to open circ sub so that we don't damage tubing while sitting here. 17:40 - 19:00 1.33 CASE P COMP Resume POOH. Mechanic will need to do further repairs at surface. 19:00 - 21:00 2,00 CASE P COMP Standback CSH workstring Printed: 7/2/2001 11:28:38 AM BP EXPLORATION Page 9 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours ,Activity Code NPT Phase Description of Operations 6/25/2001 21:00 - 21:15 0.25 CASE P COMP Safety mtg re: source 21:15 - 22:00 0.75 CASE P COMP RU SWS GPJCNL tool 22:00 - 23:15 1.25 CASE P COMP 'MU CSH 23:15 - 00:00 0.75 CASE P COMP RIH w/CT 6/26/2001 00:00 - 01:00 1.00 CASE P COMP RIH w/CNL 01:00 - 02:30 1.50 CASE P COMP I Log down from 10300' @ 30'/min 02:30 - 04:00 1.50 CASE P COMP Tag PBD at 12775' CTD. PUH logging @ 30'/min leaving 150K FIo Vis pill in liner 04:00 - 05:30 1.50 CASE P COMP POOH 05:30 - 06:15 0.75 CASE P COMP Crew changeout. Safety meeting prior to standing back CSH. 06:15 - 07:15 1.00 CASE P COMP Standback CS hydrill. 07:15 - 07:30 0.25 CASE P COMP Safety meeting prior to rigging down CNL tool. 07:30 - 08:00 0.50 CASE P COMP Lay down CNL tool. 08:00 - 08:45 0.75 CASE P COMP UCA indicates cement compressive strength is 2450 psi. PT liner lap to 2000 psi. Have leak downhole. Possibly at liner top. Check IA, OA pressures and flowline pressure. IA holds steady at 120 psi. OA steady at 0 psi. Flowline steady at 0 psi. Pressure up WHP to 2100 psi. Bleeds off at 200 psi/min. Pressure back up 3 times bleeds of each time. Shut in HCR and kill line valves. Surface lines hold like a rock and WHP continues to bleed off. Looks like downhole, possibly liner lap. 08:45 - 09:05 0.33 CASE P COMP Safety meeting prior to picking up perf guns. 09:05 - 09:30 0.42 CASE P COMP Make up perf guns as per revised perf proceedure of 6-25-01. 09:30 - 10:45 1.25 CASE P COMP Make up CS hydrill. 10:45 - 11:15 0.50 CASE P COMP Make up injector. 11:15 - 13:15 2.00 CASE P COMP RIH with perf guns. 13:15 - 14:05 0.83 CASE P COMP Tag bottom (downweight) at 12773', tagged on memory log run at 12775'. PU at 12767'. Set depth to 12796', ELM tag based on memory log ELM tag. Correlates well with latch collar from liner tally at a calculated depth of 12794'. Pull up into ball drop position. Drop 5/8" ball to fire guns. Confirm ball rolling. Chase ball with 5 bbls flopro. Position guide nose at 12741'. Perf zone 12560'-12640'. Chase flopro with KCL. 14:05 - 16:00 1.92 CASE P COMP Got indication of fire. Only took 2000 psi to fire. (Lower than usual). Brought pumps up and pressured up to 4500 psi 2 x. No other indications. Pull OOH. 16:00- 16:30 0.50 CASE P coMp Rig down injector and MHA. 16:30 - 18:00 1.50 CASE P COMP 'Standback CS hydrill. 18:00 - 18:30 0.50 CASE P COMP Standby for changeout, safety meeting prior to laying down guns. 18:30 - 19:00 0.50 CASE P COMP Lay down perf guns. All guns fired, all shots fired OK. Perforated Interval: 12,560 - 12,640 ft BKB. 80 ft total. 4 SPF. 19:00 - 19:15 0.25 CASE P COMP Pick up Baker liner top packer equip, from PU. 19:15 - 19:45 0.50 CASE P COMP Safety meeting prior to making up Baker KB packer. 19:45 - 20:30 0.75 CASE P COMP Make up BHA for setting KB liner top packer. 20:30 - 22:30 2.00 CASE P COMP RIH with KB packer and seal assy. 22:30-22:45 0.25 CASE P COMP Upwtat 10300ft.=36.5K. dwnwt=21K. RIHatl0fpm, pumping 0.5 bpm at 130 psi. Sting into Liner deployment sleeve at 10, 406 ft. Stack 1 OK at 10413.6 ft. Flag CT. 22:45 - 23:15 0.50 CASE P COMP Press test 2 3/8" CT x 5 1/2" tubing against seal assy in deployment sleeve. PT with 2000 psi. Lost 700 psi in 2 min. Press up twice to 2000 psi, loose 350 psi / min. lAP steady at 115 psi. CT Printed: 7/2/2001 11:28:38 AM BP EXPLORATION Page 10 of 10 Operations Summa Report Legal Well Name: B-30 Common Well Name: B-30A Spud Date: 1/29/1986 Event Name: REENTER+COMPLETE Start: 6/14/2001 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To Hours ActivityCode NPT Phase Description of Operations I '6/26/2001 122:45 - 23:15 0.50 CASE P COMP press, slowly inc. from 130-300 psi [thermal]. 5 1/2" tubing, 4 1/2" liner or 3 3/16" liner lap leaking. 23:15 - 00:00 0.75 CASE P COMP Pick up wt at 10408 ft. RIH stack 10 K at same depth, 10,413.6 ft. Pick up. Pump 5/8" AL ball. Incl at 10,400 ft = 71 deg. Pump 1.4 bpm at 510 psi. Pump 40 bbls by midnight. 6/27/2001 00:00 - 00:40 0.67 CASE P COMP Pump ball on seat at 0.5 bpm, 110 psi. Ball on seat at 48.7 bbls. 320 psi. RIH with packer, stack 10 K at 10413.6 ft. Pick up Wt. at 10,408 ft. Set packer at 10,406 ft CTD. In¢ press to 2500 psi to set packer. Pull to 39K, slips are set. Slack offto 14K at 10,410 ft CTD. Seal assy still inside sleeve. 00:40 - 01:15 0.58 CASE P COMP Press test 2 3/8" x 5 1/2" against set packer with 2080 psi. 30 min. test. Final press = 2050 psi. Good Liner Lap pressure test. Charted. 01:15 - 01:30 0.25 CASE P COMP Inc. Press to 3350 psi and disconnect from packer. 01:30 - 02:50 1.33 CASE ;P COMP POOH with Baker running tools. 02:50 - 03:15 0.42 CASE i P COMP Lay out Baker tools. 03:15 - 03:30 0.25 CASE P COMP Safety Meeting. Review hazards, procedures to run / pull CSH 03:30 - 0.00 CASE P COMP RIH with 40 stds CSH workstring. Printed: 7/2/2001 11:28:38 AM 29-Jun-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well B-30A Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,818.00' MD Window / Kickoff Survey: 10,845.00' MD Projected Survey: 12,859.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED "JUL 1 0 2001, Al~Oii&GasCons. Comm~ Anchem~e DEFINITIVE North Slope Alaska Alaska Drilling & Wells PBU_WOA B Pad, Slot B-30 B-30A Job No. AKMW~f05, Surveyed: 24 June, 200~ $ UR VEY REPORT 29 June, 2001 Your Reft API500292154201 Surface Coordinates: 5950025.00 N, 663737.00 E (70° t6' 11.3758" N, Kelly Bushing: 82.30ft above Mean Sea Level 148° 40' 32.7775" I/V) DRILLINEi 51ERVIr_E5 Survey Reft svy10864 A Halliburton Company Sperry-Sun Drilling Services Survey Report for B-30A Your Ref: API500292'i54201 Job No. AKMWff'I05, Surveyed: 24 June, 200'1 North Slope Alaska Measured Depth (ft) 10818.00 10845.00 10869.74 10908.74 10940.74 Incl. 82.600 83.400 84.140 85.37O 86.260 87.52O 88.550 89.430 89.070 88.810 10975.94 11005.34 11040.34 11068.14 11099.34 352.810 352.700 352.700 351.410 351.300 351.20Q'~ 351.100 353.000} 353.000 353.100 Sub-Sea Depth (ft) 8924.48 8927.77 8930.46 ~934.02 8936.36 8938.27 8939.28 8939.89 8940.26 8940.84 Vertical Depth (ft) 9O06.78 9010.07 9012.76 9016.32 9018.66 9020.57 9021.58 9022.19 9022.56 9023.14 11149.34 88.720 353.000 8941.91 9024.21 11192.34 88.810 352.800 8942.84 9025.14 11254.94 88.630 352.500 8944.24 9026.54 11303.34 86.870 4.100 8946.15 9028.45 11339.94 85.880 12.840 8948.46 9030.76 11369.74 83.170 18.710 8951.31 9033.61 11394.54 86.780 22.240 8953.48 9035.78 11432.39 88.630 31.050 8955.00 9037.30 11462.59 88.190 36.160 8955.84 9038.14 11499.79 89.780 38.800 8956.50 9038.80 11550.19 90.400 47.960 8956.42 9038.72 11580.99 90.480 39.680 8956.18 9038.48 11611.39 88.460 31.930 8956.46 9038.76 11647.19 89.340 29.460 8957.15 9039.45 11678.99 89.430 26.290 8957.49 9039:79 11714.39 90.400 24.350 8957.54 9039.84 11748.79 89.520 19.420 8957.57 9039.87 11782.79 89.870 16.420 8957.75 9040.05 11812.79 90.750 10.430 8957.59 9039.89 11841.39 90.660 6.030 . 8957.24 9039.54 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4272.14 N 1190.01W 5954270.24 N 662454.34E 4298.72 N 1193.38W 5954296.75 N 662450.38 E 4323.12 N 1196.51W 5954321.07 N 662446.73 E 4361.58 N 1201.88W 5954359.40 N 662440.52 E 4393.13 N 1206.68W 5954390.84 N 662435.04 E 4427.87 N 1212.02W 5954425.46 N 662428.94 E 4456.90 N 1216.54W 5954454.38 N 662423.79 E 4491.56 N 1221.38W 5954488.93 N 662418.20 E 4519.15 N 1224.77W 5954516.44 N 662414.21E 4550.12 N 1228.54W 5954547.31 N 662409.76 E 4599.74 N 1234.59W 5954596.79 N 662402.64E 4642.40 N 1239.91W 5954639.33 N 662396.40 E 4704.47 N 1247.91W 5954701.21N 662387.04 E 4752.72 N 1249.35W 5954749.42 N 662384.56 E 4788.82 N 1243.98W 5954785.62 N 662389.14 E 4817.35 N 1235.92W 5954814.32 N 662396.58 E 4840.48 N 1227.28W 5954837.64 N 662404.71E 4874.25 N 1210.33W 5954871.77 N 662420.92 E 4899.39 N 1193.63W 5954897.26 N 662437.07 E 4928.90 N 1171.00W 5954927.26 N 662459.05 E 4965.49 N 1136.42W 5954964.59 N 662492.83 E 4987.69 N 1115.11W 5954987.26 N 662513.65 E 5012.33 N 1097.34W 5955012.27 N 662530.88 E 5043.10 N 1079.08W 5955043.44 N 662548.47 E 5071.21N 1064.21W 5955071.86 N 662562.72 E 5103.21 N 1049.07W 5955104.18 N 662577.16 E 5135.12 N 1036.25W 5955136.36 N 662589.28 E 5167.46 N 1025.79W 5955168.92 N 662599.04 E 5196.63 N 1018.83W 5955198.24 N 662605.36 E 5224.93 N 1014.74W 5955226.61N 662608.84 E Dogleg Rate (°/100ft) 2.990 2.991 4..56O 2.802 3.591 3.520 5.982 1.295 0.893 0.269 0.510 0.559 24.222 23.985 21.613 20.319 23.764 16.977 8.283 18.216 26.884 26.343 7.323 9.972 6.127 14.558 8.883 20.181 15.387 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 4374.28 4401.07 4425.66 4464.47 4496.36 4531.47 4560.81 4595.79 4623.58 4654.77 47O4.76 4747.74 4810.31 4858.45 4893.76 4921.28 4943.37 4975.15 4998.37 5025.31 5058.03 5077.85 5100.46 5129.12 5155.49 5185.70 5216.07 5247.13 5275.39 5303.09 Tie-On To B-30 MWD Magnetic Window Point 29 June, 2001 - 10:47 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-30A Your Ref: API50029215420'1 Job No. AKMWl f'i05, Surveyed: 24 June, 200'! North Slope Alaska Measured Depth (ft) Sub-Sea Depth (ft) Vertical Depth (ft) 11875.39 88.990 357.570 8957.34 9039.64 11905.19 89.960 357.390 8957.61 9039.91 11936.19 93.040 1.800 8956.80 9039.10 11950.79 93.130 3.210 8956.01 9038.31 11974.49 92.330 5.500 8954.89 9037.19 12025.69 94.800 14.310, 8951.70 9034.00 12062.89 94.180 16.95Q" 8948.78 9031.08 12089.89 90.310 20.040 8947.73 9030.03 12118.29 88.720 21.360~ 8947.97 9030.27 12155.69 89.160 25.060 8948.66 9030.96 12188.49 92.070 30.170 8948.31 9030.61 12224.89 92.950 35.100 8946.71 9029.01 12256.29 92.690 40.740 8945.16 9027.46 12287.09 90.930 44.970 8944.19 9026.49 12320.29 92.420 47.080 8943.22 9025.52 12356.49 91.190 52.370 8942.08 9024.38 12390.29 86.960 50.430 8942.63 9024.93 12428.29 85.200 46.030 8945.22 9027.52 12460.89 87.400 40.560 8947.33 9029.63 12494.09 86.430 37.040 8949.12 9031.42 12523.49 86.610 33.160 8950.90 9033.20 12563.09 88.990 28.930 8952.42 9034.72 12606.09 91.540 23.290 8952.22 9034.52 12642.29 91.280 18.890 8951.33 9033.63 12680.49 89.780 9.200 8950.98 9033.28 12715.69 91.630 9.900 8950.55 9032.85 12756.69 89.070 6.030 8950.29 9032.59 12793.29 87.400 354.570 8951.43 9033.73 12829.29 87.490 354.040 8953.03 9035.33 12859.00 87.490 354.040 8954.33 9036.63 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5258.88 N 1013.67W 5955260.58 N 662609.17 E 5288.65 N 1014.98W 5955290.31 N 662607.21 E 5319.62 N 1015.20W 5955321.28 N 662606.32 E 5334.19 N 1014.56W 5955335.85 N 662606.64 E 5357.79 N 1012.77W 5955359.49 N 662607.92 E 5408.08 N 1003.99W 5955409.96 N 662615.60 E 5443.79 N 994.00W 5955445.88 N 662624.81E 5469.37 N 985.44W 5955471.63 N 662632.81E 5495.93 N 975.41W 5955498.41 N 662642.27 E 5530.29 N 960.67W 5955533.08 N 662656.25 E 5559.34 N 945.48W 5955562.46 N 662670.81 E 5589.95 N 925.87W 5955593.49 N 662689.74E 5614.68 N 906.60W 5955618.63 N 662708.47 E 5637.25 N 885.67W 5955641.65 N 662728.91E 5660.29 N 861.79W 5955665.20 N 662752.28 E 5683.67 N 834.20W 5955689.18 N 662779.36 E 5704.75 N 807.79W 5955710.82 N 662805.30 E 5729.99 N 779.52W 5955736.68 N 662833.01E 5753.66 N 757.23W 5955760.83 N 662854.79 E 5779.49 N 736.46W 5955787.10 N 662874.99 E 5803.50 N 719.59W 5955811.47 N 662891.34 E 5837.39 N 699.19W 5955845.80 N 662910.99 E 5875.98 N 680.27W 5955884.79 N 662929.06 E 5909.74 N 667.25W 5955918.83 N 662941.35 E 5946.75 N 657.99W 5955956.03 N 662949.80 E 5981.46 N 652.15W 5955990.86 N 662954.88 E 6022.05 N 646.47W 5956031.56 N 662959.67 E 6058.57 N 646.28W 5956068.08 N 662959.07 E 6094.36 N 649.85W 5956103.78 N 662954.73 E 6123.88 N 652.93W 5956133.23 N 662951.00 E Dogleg Rate (°/100fi) 25.362 3.311 17.346 9.663 10.225 17.837 7.269 18.335 7.276 9.961 17.926 13.745 17.959 14.868 7.778 14.996 !3.767 12.445 18.052 10.983 13.187 12.249 14.393 12.172 25.667 5.619 11:317 31.626 1.492 0.000 Alaska Drilling & Wells PBU WOA B Pad Vertical Section Comment 5336.74 5366.48 5397.31 5411.72 5435.00 5484.07 5518.52 5543.05 5568.39 5601.00 5628.27 5656.63 5679.18 5699.39 5719.77 5740.09 5758.25 5780.35 5801.52 5825.01 5847.09 5878.62 5914.99 5947.18 5983.00 6016.89 6056.65 6092.94 6128.91 6158.59 Projected Survey ~29 June, 2001 - 10:47 Page 3 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for B-30A Your Ref: API500292154201 Job No. AKMWlff05, Surveyed: 24 June, 200~ North Slope Alaska All data is in Feet (US) unless ~)therwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.631° (18-Jun-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Refere,nce and calculated along an Azimuth of 353.910° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12859.00ft., The Bottom Hole Displacemerlt is 6158.59ft., in the Direction of 353.914° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 10818.00 9006.78 4272.14 N 1190.01W 10845.00 9010.07 4298.72 N 1193.38W 12859.00 9036.63 6123.88 N 652.93W Comment Tie-On To B-30 Window Point Projected Survey Survey tool program for B-30A From To · Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 10818.00 9006.78 10818.00 9006.78 12859.00 9036.63 Survey Tool Description AK-2 BP_CG - BP Conventional Gyro (B-30) MWD Magnetic (B-30A) Alaska Drilling & Wells PBU WOA B Pad ~9 June, 2001 - 10:47 Page 4 of 4 DrillQuest 2.00.08.005 ~ILA OIL AND GAS CONSERVA~ION COMPl~SSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 R.e.' Prudhoe bay Unit B-30A BP Exploration (Alaska) Inc. Permit No: 201-105 Sur Loc: 619' SNL, 1894' WEL, SEC. 31, TllN, R14, UM Btmhole Loc. 183' NSL, 2559' WEL, SEC. 19, TllN, R14, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permitS required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. . Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit B-30A Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice maY be given by contacting the Commission Petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Chair BY ORDER OF THE COMMISSION DATED this/.~x day of June, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA .... ' ALASKA L,,_ AND GAS CONSERVATION CoMML,51ON PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory ~tratigraphic Test [] Development Oil la. Type of work [][] Re-EntryDdll [][] DeepenReddll lb. Type of well [] Service [] Development Gas F'~S~ ?le Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KE[) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 82.30' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation~z~/~ :~ z... Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL.Q2,828~ o~ ~ 4. Location of well at surface ~q. 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 619' SNL, 1894' WEL, SEC. 31, T11N, R~rE, UM Prudhoe Bay Unit At top of productive interval /,J 8. Well Number 2508' NSL, 2939' WEL, SEC. 30, T11N,R,,I~E, UM B-30A Number 2S100302630-277 At total depth /~ ~ : 9. Approximate spud date 183' NSL, 2559' WEL, SEC. 19, T11N, RI~,'UM 06/18/01 Amount $200,000.00 12. Distance to near~..s,t property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 02828.~,~D,.~:)I No Close Approach 2560 12860' MD / 8966' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11385' MD Maximum Hole Angle 93 ° Maximum sudace 2244 psig, At total depth (TVD) 8800'/3300 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Couplin.q Length MD TVD MD TVD (include stage data) 3-3/4" 3-3/16. x2-7/s.. 6.2#/6.16# L-80 ST-L 2460' 10400' 8906' 12860' 8966' 90 cu ft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12500 feet Plugs (measured) true vertical 9029 feet Effective depth: measured 12495 feet Junk (measured) true vertical 9029 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds Concrete 110' 110' Surface 2636' 13-3/8" 3255 cu ft Permafrost 'E', 465 cu ft PF 2676' 2676' Intermediate 9512' 9-5/8" 575 cu ft Class 'G' 9548' 8563' Production Liner 1510' 7" 500 cu ft Class 'G' 9308' - 10818' 8418' - 9007' Liner 1796' 4-1/2" Uncemented Slotted Liner 10699' - 12495' 8987' - 9029' Perforation depth: measured 10800'- 10810', 10842'- 10852' Slotted Liner: 10873'- 12456' ~._ ~..~;i~.,j true vertical 9004' - 9006', 9010' - 9011' Slotted Liner: 9013'-9028' '~:'.i~.~.',~I~t 0~I t~ ~::.',~': 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drillin'g'Pr'(Y§hail~ [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: 'Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is truff and correct to the best of my knowledge .... Signed Ted Stagg/~(][/~ /f~, .,~,~~1r-~ I~T~ Ti,,tLe CT Drilling Engineer Date ~ / //(~ / Permit Number ~.,~d APl Number I ~,/_ppr(~al~ate I See cover letter ~..~/-"/~.) 50-029-21542-01 ~/~e/q for other requirements Conditions of Approval: Samples Required [] Yes ,1~1~1o Mud L uired [] Y_es Hydrogen Sulfide Measures ~'~'es [] No Directional Survey Required ~es [] No Required Working Pressure for BOPE ' [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~ ;,,~3.5K psi for CTU Other: 0ri§ills, Si~]llelJ By by order of ~///~ /~/ Approved By Cammy 0echsli ......... Commissioner the commission Date Form 10-401 Rev. 12-0~,-85 0 ~ I G j J~IA L ,Triplicate BP B-30a Sidetrack Summary of Operations: B-30 is a horizontal Zone 2 producer, drilled in 1986, that is being sidetracked due to high GOR. B-30a will exit the existing 4 Y2" slotted liner and drill approx. 1,475' into the 21P and 22P sands. The sidetrack will be completed with a fully cemented 3 3/16" x 2 7/8" liner. Phase 1: Clean out liner, set whipstock and squeeze perfs. Planned for June 11,2001 · The IA will be liquid packed and an MIT test performed. · Service coil will clean out the liner and set a whipstock at approx. 11,385' (8948ss). · Service coil will use approx. 50 bbls 13.8 ppg cement to squeeze the slotted liner. Phase 2: Mill window, Drill and Complete sidetrack: Planned for June 18, 2001. Drilling coil will be used to clean out cement above the whipstock, mill the window and drill the directional hole per attached plan. The sidetrack will be completed with a cemented liner. Mud Program: · Phase 1: Seawater · Phase 2: FIo-Pro (8.6- 8.7 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · A combination 3 3/16" x 2 7/8" liner will be fully cemented with a minimum of 16 bbls cement. The top of the 3 3/16" liner will be inside the existing 4 W' tailpipe at approx. 10,400'MD (8824ss). Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan. Max. hole angle is 92 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray/Resistivity log will be run over all of the open hole section. A Memory CNL will be run inside the liner. Hazards r(/~'"'~' sli · The highest H2S recorded to date o.~_S 02 i ppm on 8/12/00. · Two small faults will be crossed but 10st circ ri~.s~ is Iow. Reservoir Pressure Res. press, is estimated to be 3300 psi at 8800ss. Max. surface pressure with gas (0.12 psi/ft) to surface is 2,244 psi. TREE =' 6" McEVOY WELLHEAD= McEVOY ~'8~'T6i~ 'i~'i'"~'"'~ ...................................................... 82.3' .................................BF. ELEV "~"~"~'~i~;' ........................................................ Datum MD = 10350' 113-3/8'' CSG, 72#:, L-80, ID= 12.347" Id B-30A PROPOSED CTD SIDETRACK 2676' IMinimum ID = 3.813" @ 9222' 4 1/2" OTIS "X" NIPPLE 15 1/2" TBG, 17#, L-80, 0232 bpf, ID=4.892"I--[ 9099' 2138' ITOP Of 4 1/2" TA IL PIPE, 12.6#, L-80, ID = 3.958" INOTE: HOLE IS J:L.QJ~J~.D_~L~L IN SLOTTED I I LINER INTERVAL 10873'- 12270'. I J--~5-1/2" HRQ OTIS SSSV LANDING I I NIPPLE, ID = 4.562" I GAS LIFT MANDRELS STA I MD I TVD I DEV I MAN 9 I 3107l 3024l 8I LBD 8 I 4823l 4533I 29 I LBD 7 I 57151 5366J 28 I LBD ~ 6 I 629°1 58721 30 I LBD ~ 16~6~1636~I 32 I L~D I ~ I 7~71 ~S621 3O I LBD I ~ 18O261 ~37~1 27 I L~D I 2 I 8~0Sl ~8SSl ~9 I LBD I 1 I 90301 S1551 48 I LBO 9099' 9158' J 9173' J 9222' J LATCH I I5 1/2" OTIS "XA" SLIDING SLEEVE, ID =4.562" I BAKER PBR, ID = 4.75" I I 9 5/8" BAKER FHL PKR, ID = 4.000" I I TOP OF 7" LNR I-I 9308' 19-5/8'' CSG, 47#, L-SO, ID = 8.681" I---[ 9548' IBTM OF 4-1/2" TBG, 12.6#, L-S0, ID= 3.958" I ~op of Proposed 3-3/16" Liner I-I 10400' 17'', 29# LNR, L-80, .0371 bpf, ID = 6.184"I---~ 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" TOPOF 4 1/2" SLT LNR 10818' I 4 1/2" OTIS "X" NIPPLE, ID = 3.813" J ~o6.., 1 I 7" TIW PACKER I I4-1/2" BOTTOM OF SLOTTED LNR, 13.5#, L-80, .014 bpf, ID = 3.845" r~---~ 12495, I--t 12270' PERFORATION SUMMARY REF LOG: CCL/GR on 3/28/1986 ANGLE AT TOP PERF: 83 @ 10800' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10800' -10810' O 10/02/00 2-7/8" 6 10842' -10852' O 04/17/99 \ \ Mill Window off Mechanical Whipstock 4-1/2" Slotted Liner P&A'd w/13.8 ppg Cement · . 11445' to 2-7/8" XO J I 3-3/4" Open Hole 2-7/8", 4.6#, L-80 LINER- Cemented & Perforated Id 12860' DATE REV BY COMMENTS 3/7/1986 !ORIGINAL COMPLETION 12/20/00 SIS-MD iCONVERTEDTO CANVAS 01/03/01 SIS-MD :2ND REVISION 03/20/01 CH/TP CORRECTIONS 04/02/01 pcr ~CTD ST Proposal PRUDHOE BAY UNIT WELL: B-30A (Proposed) PERMIT No: 86-031 APl No: 50-029-21542-00 Sec. 31, TN11N, RGE 14E BP Exploration (Alas ka) BP Amoco ~t ~% --~.,c~3., /~-'t.-: ~q-.~ E~-3o (1~-3o) .l~ ~ Magnetic NoAh: 26.69° Created By, B~ Pob'~s Date: 4r3rz(x)1 O 4~!] ";]i]~ Plard/4 B-3OA Magnetic Fieldl Comact h~f ...... ti '!i."~-;:.-i.~ [ Strength: 57475nT I .. , Dip Angle: 80.76° ! Oir~.~.-I (007) 26';~6613 Plan#1 B-3OA I]N~'~["'~Q' / Date: 4/3/2001 ~ E Model: BGGM2000 ~ I:~a.':.er Hughes ..:NTE©: / Parent Wellpath: B-30 Tm on MD: 11385.00 R~g: · : ': '. ;'.....' i...:.':'.:!.:'.:-'::.' :', ;:- ' ;...:. i. '' i: ! ::! ; Ref. Datum: 41: 30 112911986 00:00 82.30ft ?"~ ;"?'.'"":"i":'"":'-'~"~'~'"":'-"';'~',". ' · · ' · '-~-~--:-"---'~' .......... i--i ....... :"{": '"""'""i':":'"-'" ! ............ i ............. ~ ............ ~ ......... ~":' ~ ' ~ :!..:-}.::.:.:.--.:.?.-i'-:-.i-i'--:'.-i:+:.:.:. ' ......... ~ ..................... :'-~'---'-.---:-~---~ .......... · .... ~ ........... ~ ........... ~"~ .......... ~ ............ ~+---..-..~ ........... ~ ........ , ........... ~ ....... i ........ . ...?.: ....... : · . . ~ :.: ~ .... : .~ : ; ~: ~ -.-.'...:..:.'.'~:':.:;. :.:; '.' :~.' .: ~: · ; ~,~,.~ ............. ~......~..-:.~...?...~ - ' ~ ~ ' ~~] ................. ~ .......... ? '"~" ~"~"~-" ~': ....... ~ ..... ,, ...... ~ t Co-ordinate (N/E) Reference: Well Centre: B-30, True North .' ..... ..... ;...~, . ~ ~.:' ....:..! .... , ~ . : :,- : ! ; . . ........ i" ~ : -:~:..]-.....-.:. .... ~' ~ .i .,, :. .~ i ~ . Vertical (TVD) Reference: System: Mean Sea Level ': :.i' :.:"i::. i..!'i::'::"::!':'~:: · Se~ion0~s~ ~e,e~e~ce: S,ot-~o {O.00N,0.®~ ~i--4--i--i-.-i::~!!:!i;i!ii:!i...:-....:!~¢:.-.~--i--:---i--i.-i.-i i .... i-~--~.-~-~-~iF~.~.:i:¢ .......... i.:--~-~-~i .............. i ......... Measured Depth Re[erence: 4'1: 30 '1/2~/'1~86 00:00 82.30 . . ~ i i i ' I. / ...... .......... .......... ...... ......... .... ~. ::.;.~:" ~..:'~:.":::':".:'.i:.;..: ' · i' .i ' i ~ '; ~ . ......... ;...........~ . :.....: . . . . · : . :: · ........ I~;t ~ ~'-~ ~ I:~ ] ':: .... : .................. /: / /: .i...:. ............ ii .......... ........... i.: ........... ill .... .... : ............. : ................................ · : .~ .... :~'"'-'~ ' ':' ~ i ' ' ·~ ~ ..... ~.......: ~ ~ ...... :. :-. ~ - .~ . . ~. ~ ,. ; ~ ~ : : .:..:.-:; .~, · i."-.'.:-i ...... . ~ . '~ '~. i . i .......... ':'i""-'"~ ......... T'"'"-?-:'" ......... ~ ..... ? ---'--'-"i- ............. r'·--'' ':-'--~ .............. ~---'-","·'~ ............ ~ ............ ~ ............ ~ ......... :~':."¢'::.'..'.'.':....'t-.'-.i';i'-"ii'" ·~ - ~:. ' i · :-i ..... : · · .::..'.:.'.'::'.i'.'....'.¥'.;'..i..;.::-!.:.~..!:i.i.-::.:..i..i-..i.; ....... 'i----'-~--:-~-.i.~.~,---i-~-----.---ii .......... ! ........... ! .............. ! ........ ~ .......... i ....... .~.!..:.!..:..;:::i':~'t' '..~-:--;-:: ~,...~ ; .... i · i · I: .. 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'i ! · · ~ .: ·· ~ ...~. !..:..: · ~; : . : :: · . ....... ~ ....................... ~ ........... ~..: .;...: ........... ~ .......... ?- ........... ?:~.- ?--.~-.~-- --~.-.-~-~, .......... ~ .......... ~. ............ r ........... ~ ........... : ........ ~ :'~. ... -2200-2.100-2000-~900-1800-'1700-'1cc00-'1500-'1400-'1300-'1200-'1'100-1000-~00-800-700-600-,500-400-300-200-'100 0 '10~ 200 300 400 We~t{-}/Ea~t{+} [IOOf/in] "~87 · : .......... :-~-*.-~--+-o-~ ............. ; ............ i ............ { ......... ~ ....... ~..} ........ ,~ ........ :..~' · --~.,~,_ 8800_.:i.'d . . · . .. .: -:..-:..{.--..-:...-..i .............. ~ .............. ; ........... } ............ i ........... :..i ~. ~ ~.. >., '. i i. '; :: · · . .... ~.r-~.-.-..-..-.--T---~--? ..................... r- --:-.-~ ........... I ~':'-- t' - -- ~ : :- : ..... · ' ·: : .............. ~ !"' '"~ 'r': ....... ~ ...... "? ............. ~' .............. [] · ~ · ' . . '~i- : ! ! i . ~ .............................. . .................... . ,-- . · · .. ~ .......... ~ ~- .~ ..?~-?- ...... ~ ....... ;,~:. ...... T~.7.....~.i .......... ...- .......... ] ........ :.. ~ : . : . . . -' " ' :" · · · · : ~ ...... ~ :: I i i ~ .q ~OSO-::t ....... · ...... · ...................... ! ............ ~ ............ ~ ............. ~ ........................ ~ ........... ; ........... ~" .... . . . : ~.. ~ : : ~ . . . . .~ :..:~ : :. "~ ....... .1- ' ' ' .... :'~: ['~ ' ~" f : ! :r r r'r'r'[. ...... ,~ '~'mT~· ~rrrr'rrrr.~ , rr?rYr'~?'"'rrm'rrr'~'m?'rrrrrrr'rrr~'?~ ~ ~ ~ ~ ~ ~ r?"rT.;"'r'"'~?Trrrq'""'"':-'"'r?'~'~'i'rr? "r' F'rrrF~?" n "~"" ?~'~w'ri~r~r*~~'[ ~ ~ ~ I .... I~'' ~ 1 ~ ~ "I'" ~ I 45~ 4t~ 4~50 47m 4750 4800 4850 4~Jo0 4850 ~ 5050 Sl00 5'150 ,5200 5250 $300 §350 [>400 5450 Sr~XI §silo 5~.)0 5~fiO 5700 s750 5800 5850 §9~0 5850 co0(10 co050 6'100 6'1,50 §200 62,50 6300 ~350 6400 6450 6500 Vertical Section at 353.54' [50ftlin] 8943.78 1125&00 TIP 8g.47.26 11385.00 KOP 8946.89 11435.00 1 8946.76 11735.00 2 8954.57 12110.00 3 8966.11 12860.00 TD 4/3/2001 3:14 PM ObP BP Amoco Baker Hughes INTEQ Planning Report i~qi!'~./~ ...................... Company: BP Amoco Date: 4/3/2001 Time: 10:53:55 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: B-30, True North Site: PB B Pad Vertical (TVD) Reference: System: Mean Sea Level Well: B-30 Section (VS) Reference: Well (0.00N,0.00E,353.54Azi) Wellpath: Plan#1 B-30A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: PB B Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5946440.22 ft Latitude: 70 15 36.475 N 662094.05 ft Longitude: 148 41 22.843 W North Reference: True Grid Convergence: 1.23 deg Well: B-30 Slot Name: 30 B-30 Well Position: +N/-S 3548.84 ft Northing: 5950025.01 ft Latitude: 70 16 11.376 N +E/-W 1719.85 ft Easting: 663737.00 ff Longitude: 148 40 32.777 W Position Uncertainty: 0.00 ft Wellpath: Plan#1 B-30A Drilled From: B-30 500292154201 Tie-on Depth: 11385.00 ft Current Datum: 41 · 30 1/29/1986 00:00 Height 82.30 ft Above System Datum: Mean Sea Level Magnetic Data: 4/3/2001 Declination: 26.69 deg Field Strength: 57475 nT Mag Dip Angle: 80.76 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0,00 0.00 0,00 353.54 :::::_-_-: ...... :: .......... :..-7--:::: ........... :_. :-.-::--: ::.: :::: :_:: ::: :: ::::_-.:: :.:. :: :::--':::: .: :_: _---:7__.. _,_:::-:::...--: :__.~_.-:: :--: :: '"::: _---_ _-:--::: :: :: :::~ ::----:::..-::.: ::: :-:.-: :: ::_' :: ._---.-. ::: :.':: :::.:: ::: ::: .... Plan: Plan #1 Date Composed: 4/3/2001 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets .... :.'.: :'..":..: "'.::.:..." ·: · '. · : ..:. '.:. :....::: .. ': Map....: ~;i;~.::.~:~:~:~.~:::~.i::i~ii;~i~;~::~...~.:~i:;;.~i~::~i~;-:::;~.~ : Name. · :' Description ' TVD : +N/~S' ' · +E/-W "N°rthing: Easting · Deg'Min Sec ' Deg Min 'Sec .: : '" ::: ":':" :" """ "ff ' : :.'.:'.'fi: ' '.ff ..... 'ft' · ...' ft::..:.' .... .....:'. · B-30APolygonl.1 0.00 5176.66 -1212.95 5955173:70 662411.82 70 17 2.287 N 148 41 8.111 W -Polygon 1 0.00 5176.66 -1212.95 5955173.70 662411.82 70 17 2.287 N 148 41 8.111 W -Polygon 2 0.00 5418.27 -726.60 5955425.81 662892.76 70 17 4.664 N 148 40 53.944 W -Polygon 3 0.00 6076.22 -529.38 5956087.85 663075.61 70 17 11.135 N 148 40 48.200 W -Polygon 4 0.00 6087.70 -830.23 5956092.79 662774.60 70 17 11.248 N 148 40 56.965 W -Polygon 5 0.00 5641.92 -939.85 5955644.76 662674.71 70 17 6.863 N 148 41 0.157 W B-30ATI.1 8955.00 5367.41 -919.76 5955370.77 662700.77 70 17 4.164 N 148 40 59.571 W B-30A T1.2 8965.00 6130.08 -754.29 5956136.80 662849.59 70 17 11.665 N 148 40 54.753W Annotation ................. '" ................................... - ................. "-'~ .......................... :-"'---' ...................... ' ................ - ...... '-~-~----.' .......... -.' ...................... : .......................................... '..-,.: .................................................. ~---: ................. ' .............................. · ........... ' ........... · .............................................. :_..- ................ !_:. 11258.00 8943.78 TIP 11385.00 8947.26 KOP 11435.00 8946.88 1 11735.00 8946.75 2 12110.00 8954.56 3 12860.00 8966.13 TD BP Amoco Baker Hughes INTEQ Planning Report i~"'i!"i~'~ .................... Company: BP Amoco Date: 413/2001 Time: 10:53:55 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: B-30, True North Site: PB B Pad Vertical (TVD) Reference: System: Mean Sea Level Well: B-30 Section (VS) Reference: Well (0.00N,0.00E,353.54Azi) Wellpath: Plan#1 B-30A Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD lncl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 11258.00 88.70 352.50 8943.78 4707.20 -1249.74 0.00 0.00 0.00 0.00 11385.00 88.16 352.50 8947.26 4833.07 -1266.31 0.43 -0.43 0.00 180.00 11435.00 92.69 354.61 8946.88 4882.74 -1271.92 10.00 9.06 4.23 25.00 11735.00 87.36 24.15 8946.75 5175.36 -1223.58 10.00 -1.78 9.84 100.00 12110.00 90.34 61.54 8954.56 5445.33 -973.12 10.00 0.79 9.97 86.00 12860.00 88.16 346.56 8966.13 6082.22 -688.75 10.00 -0.29 -10.00 268.00 Survey MD lncl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 11258.~)0 88.70 35215'(~ ......8943'178 '4~07.20 -12~9.74 59~4703.58' ' 662385.25' 0.00 4817.'9:~' (~i00'" TIP 11275.00 88.63 352.50 8944.18 4724.05 -1251.96 5954720.38 662382.66 0.43 4834.92 180.00 MWD 11300.00 88.52 352.50 8944.80 4748.83 -1255.22 5954745.08 662378.86 0.43 4859.91 180.00 MVVD 11325.00 88.41 352.50 8945.47 4773.61 -1258.48 5954769.78 662375.06 0.42 4884.90 180.00 MWD 11350.00 88.31 352,50 8946.18 4798.38 -1261.74 5954794.47 662371.26 0.42 4909.88 180.00 MWD 11375.00 88.20 352.50 8946.94 4823.16 -1265.01 5954819.17 662367.47 0.42 4934.87 180.00 MWD 11385.00 88.16 352.50 8947.26 4833.07 -1266.31 5954829.05 662365.95 0.42 4944.86 180.00 KOP 11400.00 89.52 353.13 8947.56 4847.95 -1268.19 5954843.89 662363.75 10.00 4959.86 25.00 MWD 11425.00 91.78 354.19 8947.28 4872.79 -1270.95 5954868.66 662360.45 9.99 4984.85 24.95 MWD 11435.00 92.69 354.61 8946.88 4882.74 -1271.92 5954878.59 662359.26 9.99 4994.85 24.96 1 11450.00 92.43 356.09 8946.21 4897.68 -1273.13 5954893,49 662357.72 10.00 5009.83 100.00 MWD 11475.00 91.99 358.55 8945.25 4922.63 -1274.30 5954918.41 662356.01 10.00 5034.75 100.07 MWD 11500.00 91.55 1.01 8944.47 4947.61 -1274.40 5954943.39 662355.37 10.00 5059.59 100.16 MWD 11525.00 91.10 3.47 8943.90 4972.59 -1273.42 5954968.37 662355.80 10.00 5084.29 100.24 MWD 11550.00 90.65 5.93 8943.51 4997.50 -1271.37 5954993.32 662357.31 10.00 5108.81 100.29 MWD 11575.00 90.20 8.39 8943.33 5022.30 -1268.25 5955018.18 662359.89 10.00 5133.11 100.33 MWD 11600.00 89.76 10.85 8943.34 5046.94 -1264.07 5955042.91 662363.53 10.00 5157.13 100.35 MWD 11625.00 89.31 13.31 8943.54 5071.39 -1258.84 5955067.46 662368.23 10.00 5180.83 100.35 MWD 11650.00 88.86 15.77 8943.94 5095.58 -1252.57 5955091.78 662373.98 10.00 5204.16 100.33 MWD 11675.00 88.41 18.23 8944.53 5119.48 -1245.26 5955115.83 662380.76 10.00 5227.09 100.29 MWD 11700.00 87.97 20.69 8945.32 5143.04 -1236.93 5955139.57 662388.57 10.00 5249.56 100.23 MWD 11725.00 87.53 23.16 8946.30 5166.21 -1227.60 5955162.93 662397.39 10.02 5271.53 100.11 MWD 11735.00 87.36 24.15 8946.75 5175.36 -1223.58 5955172.17 662401.22 10.02 5280.17 100.02 2 11750.00 87.47 25.65 8947.43 5188.95 -1217.27 5955185.89 662407.23 10.00 5292.97 86.00 MWD 11775.00 87.65 28.14 8948.49 5211.23 -1205.97 5955208.41 662418.04 10.00 5313.83 85.93 MWD 11800.00 87.83 30.64 8949.48 5232.99 -1193.71 5955230.43 662429.82 10.00 5334.07 85,83 MWD 11825.00 88.02 33.13 8950.39 5254.20 -1180.52 5955251.92 662442.55 10.00 5353.67 85.73 MWD 11850.00 88.21 35.63 8951.21 5274.82 -1166.41 5955272.84 662456.21 10.00 5372.57 85.64 MWD 11875.00 88.40 38.12 8951.95 5294.81 -1151.42 5955293.15 662470.76 10.00 5390.74 85.55 MWD 11900.00 88.60 40.61 8952.60 5314.13 -1135.57 5955312.81 662486.19 10.00 5408.15 85.48 MWD 11925.00 88.80 43.11 8953.17 5332.74 -1118.89 5955331.78 662502.45 10.00 5424.77 85.42 MWD 11950.00 89.01 45.60 8953.64 5350.61 -1101.42 5955350.02 662519.53 10.00 5440.57 85.36 MWD 11975.00 89.21 48.09 8954.03 5367.71 -1083.18 5955367.51 662537.39 10.00 5455.50 85.31 MWD 12000.00 89.42 50.58 8954.33 5384.00 -1064.22 5955384.21 662555.99 10.00 5469.55 85.27 MWD 12025.00 89.63 53.07 8954.54 5399.45 -1044.57 5955400.08 662575.30 10.00 5482.69 85.24 MWD 12050.00 89'184 55.56 8954.66 5414.03 -1024.27 5955415.10 662595.28 10.00 5494.90 85.22 MWD 12075.00 90.04 58.06 8954.68 5427.71 -1003.35 5955429.23 662615.89 10.00 5506.14 85.21 MWD 12100.00 90.25 60.55 8954.62 5440.47 -981.85 5955442.46 662637.11 10.00 5516.40 85.21 MWD 12110.00 90.34 61.54 8954.56 5445.33 -973.12 5955447.50 662645.73 9.97 5520.24 85.01 3 12125.00 90.29 60.04 8954.48 5452.65 -960.03 5955455.11 662658.66 10.00 5526.04 268.00 MWD 12150.00 90.20 57.54 8954.37 5465.60 -938.65 5955468.52 662679.75 10.00 5536.51 267.99 MWD 12175.00 90.11 55.04 8954.30 5479.47 -917.85 5955482.84 662700.24 10.00 5547.95 267.98 MWD 12200.00 90.02 52.55 8954.27 5494.24 -897.68 5955498.04 662720.08 10.00 5560.36 267.97 MWD 12225.00 89.93 50.05 8954.28 5509.87 -878.17 5955514.09 662739.24 10.00 5573.69 267.97 MWD BP Amoco Baker Hughes INTEQ Planning Report i~:Y~ ...................... Company: BP Amoco Date: 4/3/2001 Time: 10:53:55 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: B-30, True North Site: PB B Pad Vertical (TVD) Reference: System: Mean Sea Level Well: B-30 Section (VS) Reference: Well (0.00N,0.00E.353.54Azi) Wellpath: Plan#1 B-30A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft fi: fi: fi: ft deg/100ft ft deg 12250.00 89.85 47.55 8954.33 5526.34 -859.36 5955530.96 662757.69 10.00 5587.94 267.97 MWD 12275.00 89.76 45.05 8954.42 5543.61 -841.29 5955548.62 662775.38 10.00 5603.07 267.98 MWD 12300.00 89.67 42.55 8954.54 5561.65 -823.99 5955567.03 662792.28 10.00 5619.05 267.99 MWD 12325.00 89.58 40.05 8954.71 5580.43 -807.49 5955586.17 662808.37 10.00 5635.85 268.00 MWD 12350.00 89.50 37.55 8954.91 5599.91 -791.83 5955605.98 662823.60 10.00 5653.44 268.01 MWD 12375.00 89.41 35.06 8955.14 5620.05 -777.03 5955626.44 662837.96 10.00 5671.80 268.03 MWD 12400.00 89.33 32.56 8955.42 5640.82 -763.12 5955647.51 662851.41 10.00 5690.87 268.06 MWD 12425.00 89.25 30.06 8955.73 5662.18 -750.13 5955669.14 662863.93 10.00 5710.63 268.09 MWD 12450.00 89.16 27.56 8956.08 5684.08 -738.08 5955691.30 662875.50 10.00 5731.04 268.12 MWD 12475.00 89.08 25.06 8956.46 5706.49 -727.01 5955713.94 662886.09 10.00 5752.05 268.15 MWD 12500.00 89.01 22.56 8956.88 5729.36 -716.91 5955737.02 662895.68 10.00 5773.64 268.19 MWD 12525.00 88.93 20.06 8957.33 5752.64 -707.83 5955760.49 662904.25 10.00 5795.75 268.23 MWD 12550.00 88.86 17.56 8957.81 5776.30 -699.77 5955784.32 662911.79 10.00 5818.35 268.28 MWD 12575.00 88.78 15.06 8958.33 5800.29 -692.75 5955808.45 662918.29 10.00 5841.40 268.32 MWD 12600.00 88.71 12.56 8958.87 5824.55 -686.78 5955832.84 662923.73 10.00 5864.84 268.38 MWD 12625.00 88.65 10.06 8959.45 5849.06 -681.88 5955857.45 662928.09 10.00 5888.64 268.43 MWD 12650.00 88.58 7.56 8960.05 5873.76 -678.05 5955882.22 662931.39 10.00 5912.75 268.49 MWD 12675.00 88.52 5.06 8960.68 5898.59 -675.30 5955907.11 662933.59 10.00 5937.12 268.55 MWD 12700.00 88.46 2.56 8961.34 5923.53 -673.64 5955932.07 662934.71 10.00 5961.71 268.61 MWD 12725.00 88.40 0.06 8962.03 5948.51 -673.07 5955957.06 662934.74 10.00 5986.47 268.68 MWD 12750.00 88.35 357.56 8962.73 5973.49 -673.59 5955982.02 662933.68 10.00 6011.35 268.75 MWD 12775.00 88.30 355.06 8963.46 5998.43 -675.19 5956006.91 662931.53 10.00 6036.31 268.82 MWD 12800.00 88.25 352.56 8964.22 6023.27 -677.89 5956031.69 662928.30 10.00 6061.29 268.89 MWD 12825.00 88.21 350.06 8964.99 6047.97 -681.66 5956056.30 662923.99 10.00 6086.26 268.97 MWD 12850.00 88.17 347.56 8965.78 6072.48 -686.51 5956080.70 662918.61 10.00 6111.16 269.04 MWD 12860.00 88.16 346.56 8966.13 6082.22 -688.75 5956090.38 662916.16 10.00 6121.09 269.34 TD 2 3/8" CT I I I 10,000 psi Pack-Off Lubricat°r4 l Nordic 1 B-30a CT Drilling & Completion BOP 7 1/16" Annular 7 1/16" 5000 psi I 7 1116" I ,, -- ~ I Pipe/Slips I ~ ~ 2 318 .... -' '-~ "' 'l BIBIIlil~ Pipe/Slips Pipe7 1116" I ~ iBBiIBBii ~ ~ VaR 2 718" ' 2 318" to 3.5" SWAB OR MASTER VALVE I I__ . .DA.TE._ . I CHECK:NO. L89911 io~., ~:o~ ] ~ iooisg.¢i I VENDOR /~LI~I&AU 1L~ O0 ., 'E INVOICE / OREDIT MEMO DESCRIPTION GROSS DISOOUNT NET $0~ CKO5~40~D ~00. O0 ~00. O0 I~L]N~ ZNST: S/H - Te~-&e Hub~Ze X4~28 .,, t CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~[e]~]~l ~ z oo. OD z OO. OD XPLORATION, (ALASKA)INC. )X 196612 )RAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND. OHIO No. H 189911 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 O0189911 ONE HUNDRED & 00/i00~~~~~~~.~~~ US DOLLAR ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 DATE' 0:5/16/01 ], NOT'VALID AFTER 120 DAYS AMOUNT $100.,00 WELL PERMIT CHECKLIST COMPANY ~ ~"~ WELL NAME ~4~--/~ PROGRAM: exp dev~ FIELD & POOL _/~'~ ~Z'~/,~ INIT CLASS~E-V/ /~'~¢'/__. GEOL AREA DATE ADMINISTRATION 1. 2. 3.. 4. 5. 6. 7. 8. 9. 10. 11. ' g)//13. 15. '17. ~8. 10. 20. 2'1. 22. 23. 24. 25. 26. 27. 28. 20. G EOL.____O. G_~.Y 30. 31. 32. AP, ER DATE 33. &.,Of. p134. / redrll v" serv wellbore seg Permit fee attached: ............... / ......... Lease number appropriate.'~. ~.~..~~/./~.' Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from ddlling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in ddlling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs. CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. ann. disposal para req ~ ON/OFF SHORE If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation .......... ~ ..... BOPE press rating appropriate; test to ~C~ ~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... i~/~L._ Is presence of H2S gas probable, y ~'~,~3c~%~,~3~. C~ ,~ ~-~¥,~ %% ................ Permit can be issued w/o hydrogen sulfide measures ..... , Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. Seabed condition survey (if off-shore) .... ~ ...... ~" Y N Contact name/phone for weekly progress reports [expl.~a3ory only] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well'used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N G EO LO~/~)Y~: ENGINEERING: UI/~nnular COMMISSION: MSH l Commentsllnstructions: O Z O c:\msoffice\wordian\diana\checklist (rev. 11/01//00) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Perrnitting 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 APPEN. DIXi ,. No 'special'effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Ut±lity SRevision: 3 $ LisLib SRevision: 4 $ Fri Jul 12 09:41:27 2002 Reel Header Service name ............. LISTPE Date ..................... 02/07/12 Origin ................... STS Reel Name ................ UNKNOWN Centinuatien Number ...... 01 Previeus Reel Name ....... UNKNOWN Cemments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/07/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writi~lg Library. Scientific Technical Services Scientific Technical Services O96a Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: B-30A 5002921.54201. BP Exploration (Alaska), Inc. Sperry-Sun Drilling Services 12-JUL-02 MWD RUN 1 MWD RUN 2 MWD RUN 3 AK-MW-ii105 AK-MW-ii105 AK-MW-Ii105 S. LATZ S. LATZ S. LATZ SEVCIK/SARBE SEVCIK/SARBE SEVCIK/SARBE ,lOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (F'r FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 MAD RUN 4 AK-MW-ii105 AK-MW-ii105 S. LATZ S. LATZ SEVCIK/SARBE SEVCIK/SARBE 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 31 llN 14E 619 1894 82.30 46.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 2676.0 8.500 9.625 9548.0 6.].25 7.000 10818.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH-SUBSEA (TVDSS). 3. ~D RUNS 1 - 4 COMPRISED DIRECTIONAL, WITH DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUN 1 PARALLELED THE SLOTTED LINER IN THE ORIGINAL WELLBORE. THE HIGH GAMMA VALUES OBSERVED IN THIS HOLE SECTION WERE PROBABLY DUE TO SCALE AND/OR OTHER PRODUCED FLUID RESIDUES. 4. DIGITAL AND LOG DATA ONLY ARE SHIFTED TO THE SCHLUMBERGER CASED-HOLE WIRELINE GAMMA RAY LOG RUN ON 25 JUNE 2001. HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. ALL LOG 5. MWD RUNS 1 - 4 REPRESENT WELL B-30A WITH API#:50-029-21542-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12859'MD / 8954'TVDSS (UNSHIFTED). SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE := SMOOTHED FORMATION EXPOSURE TIME. "M" SUFFIX ON CURVE MNEMONIC DENOTES MAD PASS DATA. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generatior~ ........ 02/07/12 Maximum Physical. Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL, CODE START DEPTH STOP DEPTH GR 10828 0 12812.0 RPS 10838 0 12823.0 RPX 10838 0 12823.0 RPM 10838 0 12823.0 RPD 10838 0 12823.0 FET 10858 5 12823.0 ROP 10871 0 12857.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH 10828.0 10832.5 10866.5 10876 0 10883 0 10903 0 10931 0 10944 5 11050 5 11056 0 11061 0 11080. 0 11119.5 11137.5 11174 .5 _l. 1235.5 11245.5 11267.0 11288.5 11297.5 11316.0 11344.0 11378.5 11388.5 11486.5 11494.0 11504.5 11525.0 11536.5 11558.0 11583.5 11585.0 11588 5 11597 0 11603 0 11612 5 11630 5 11644 5 11671 5 11690 0 11707 0 11721 0 11753 0 11779 5 11786 0 11804 0 11812 0 1,1831 0 11892 5 11904 0 11913 5 11917 0 11,944 0 11964 5 11994 0 12007 5 12011 5 12020 0 12026.5 12029.5 12040.5 12058.5 12080.5 12116.5 1.2119.0 12127.0 12164 .5 12182.5 12189.0 12193.5 12196.5 12210.0 12215.0 12248.0 GR 10821 0 10825 5 10859 5 10869 0 10876 0 10896 0 10924 5 10938 0 11043.5 11049.5 11054 . 0 11071.0 11112.5 11129.0 11166.5 11234.5 11244.0 11265.0 11286.5 11295.5 11314.5 11341.5 11376.0 11386.0 11487 0 11494 0 11504 5 11526 0 11,536 5 11559 5 11586 5 11588 5 11590 5 11598 5 11604 0 11614 5 11631 5 11647 5 11675 5 11696 0 11713 0 11728 0 11759.0 11785.5 11791.0 11809.5 11817.5 11838.5 11899.5 11911.0 11920.0 11924.0 11946.0 11965.5 11995.0 12003.0 12008.0 12016.5 12023.0 12025.5 12037.0 12057.5 2079.0 2115.5 2119.0 2126.5 2166.5 2186.5 12192.0 12197.0 12200.5 12213.0 12219.0 12251.0 ]2272 5 12278 5 12301 0 12303 0 12306 5 12314 5 12323 5 12332 0 12337 0 12345 0 12371 0 12396 0 12407 5 12420.5 12434.5 12449.0 12477.0 12480.0 12491.5 12494.0 12497.5 12508.5 12521.5 12552.0 12569.0 12573 5 12606 5 12659 5 12666 0 12677 0 12682 5 1,2686 5 12689 0 12693 5 12708.0 12734.5 12772.5 12857.5 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REHARKS: 12273.0 12278.0 12302.5 12305.0 12308.0 12315.0 12323.5 12332.0 12338.0 12346.0 12373.0 12398.5 12410.0 12424.0 12437.0 12451.(/ 12478.0 12481.0 12494.0 12497.0 12500.0 12510.5 12523.5 12555 0 12569 5 12576 5 12610 5 12658 5 12665 0 12676 5 12681 5 12686 0 12688 5 1,2692 5 12708.5 12735.5 12774.0 12859.0 BIT RUN NO MERGE TOP MERGE BASE 1 10821..0 11254.0 2 1,.1.254.0 11415.0 3 1.11.415.0 11964.0 4 11964.0 12859.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specificati. on Bl. ock sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 10828 12857.5 ROP MWD FT/H 1.37 1437.7 GR MWD API 17.61 524. 97 RPX MWD OHMM 0.25 2000 RPS MWD OHMM 0.16 2000 RPM MWD OHMM 0.39 2000 RPD MWD OHMM 0.12 2000 FET MWD HOUR 0.2293 13.3046 First Reading For Entire File .......... 10828 Last Reading For Entire File ........... 12857.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Mean 11842.8 112.55 112.99U 8.43826 16.3658 14.812 18.5394 1.51263 Nsam 4060 3974 3841 3956 3956 3956 3956 3915 First Reading 10828 10871 10828 10838 10838 10838 10838 10858.5 Last Reading 12857.5 12857.5 12812 12823 12823 12823 12823 12823 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RAT 1.1203.0 12857.5 RPS 11204 0 12826 0 FET 11204 0 12826 0 RPM 1,1204 0 12826 0 RPX 11204 0 12826 0 RPD 11204 0 12826 0 GR ]..].234 0 12815 0 MERGED DATA SOURCE PBU TOOL CODE MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE MTND 4 1 11198.5 12859.0 $ REMARKS: MERGED MA[) PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 ~Dept h Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OMMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMH 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 Name Service Unit Mir Max Mean Nsam DEPT FT 11.203 12857.5 12030.3 3310 RAT MAD FT/H 549.4 1010.67 720.07 3310 GR MAD API 11.22 495.52 42.2218 3123 RPX MAD OHMM 1.03 58.33 5.76267 3245 RPS MAD OHMM 1.3 18.33 6.36752 3245 RPM MAD OHMM 1.56 18.6 6.83805 3245 RPD MAD OHMM 2.08 46.77 7.68477 3245 FET MAD HOUR 3.3633 82.8306 33.8969 3245 First Reading For Entire File .......... 11203 Last Reading For Entire File ........... 12857.5 File Trailer Service name ............. STSLIB.O02 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 11203 11203 11234 11204 11204 11204 11204 11204 Last Reading 12857.5 12857.5 12815 12826 12826 12826 12826 12826 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOl, CODE START DEPTH STOP DEPTH GR 1082]... 0 ].1168.5 RPS ].0831 0 11220.0 RPX 10831 0 11220.0 RPM 10831 0 11220.0 RPD 10831 0 11220.0 FET 10851. 5 11220.0 ROP 10864 0 11254.0 $ LOG HEADER DATA DATE LOGGED: 21-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 'POP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BlT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF {IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-'type...0 Memory 11254.0 10820.0 11254.0 83.4 89.4 TOOL NUMBER 2049RF3 2049RF3 3.750 Flo Pro 8.50 65.0 9.0 23000 12.4 .195 .000 .200 .270 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD010 FT/H 4 i 68 GR MWD010 AP[[ 4 1 68 RPX MWD010 OHMM 4 i 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 74.0 156.0 74.0 74.0 Name Service Unit Min Max DEPT FT 10821 1.].254 ROP MWD010 FT/H 14.96 1437.7 GR MWD010 API 110.83 524.97 RPX MWD010 OHMM 0.25 2000 RPS MWD010 OHMM 0.16 2000 RPM MWD010 OHMM 0.39 2000 Mean 11037.5 131.661 414.052 15.1026 53.5135 44.0444 Nsam 867 781 668 779 779 779 First Reading 10821 ,10864 10821 10831 10831 10831 Last Reading 11254 11254 11168.5 11220 11220 11220 RPD HWD010 OHMM 0.12 2000 FET MWD010 HOUR 0.3067 10.0523 Firs~ Reading For Entire File .......... 10821 Last Reading For Entire File ........... 11254 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 61.3277 0.703845 779 738 10831 10851.5 11220 11220 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11225.0 11369 . 5 RPD 11229.0 11380.5 FET 11229,0 11380,5 RPS 11229.0 11380.5 RPM 11229.0 11380.5 RPX 1,1..229.0 11380.5 ROP 1,.1.254.5 ]..1,41.5.0 $ LOG HEADER DATA DATE LOGGED: 21-JUN-01 S O FTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT'): 11415.0 TOP LOG INTERVAL (FT): 11254.0 BOTTOH LOG INTERVAL (FT): 11415.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.0 MAXIMUM ANGLE: 88.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 2049RF3 EWR4 ELECTROMAG. RESIS. 4 2049RF3 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.67 MUD VISCOSITY (S): 65.0 MUD PH: 10.5 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 9.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .195 MUD AT MAX CIRCULATING TERMPERATURE: .100 MUD FILTRATE AT MT: .200 MUD CAKE AT MT: .270 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DE PT FT 4 1 68 ROP MWD020 FT/H 4 1 68 GR MWD020 API 4 1 68 RPX MWD020 OHMM 4 1 68 RPS MWD020 OHMM 4 1 68 R PM MWD 020 OHMM 4 1 68 RPD MWD020 OHMM 4 1 68 FET MWD020 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 74.0 150.0 74.0 74.0 Name Service Unit Min Max DEPT FT 1,1225 11415 ROP MWD020 FT/H 1.5 214.3 GR MWD020 API 18.5 51.6.75 RPX MWD020 OHMM 2 6.76 RPS MWD020 OHMM 2.02 6.85 RPM MWD020 OHMM 2.32 7.2 RPD MWD020 OHMM 3.83 10.15 FET MWD020 HOUR 0.3251 9.4725 First Reading For Entire File .......... 11225 Last Reading For Entire File ........... 11415 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Mean 1.1.320 90.9157 1,84.89]. 3.93227 4.40151 4.86296 5.7796 3.40541. Nsam 381, 322 290 304 304 304 304 304 First Reading 11225 ].1254.5 11225 1].229 11229 1,1229 11229 11229 Last Reading 11415 11415 11369.5 11380.5 11380.5 ].1380.5 11380.5 11380.5 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 DaYe of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11370.0 11926 0 RPS 11381.0 11937 0 RPX 11381.0 11937 0 RPM 11381.0 11937 0 RPD 11381.0 11937 0 FET 11381.0 11937 0 ROP 11415.5 11964 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWR, RE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAl., GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY' (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MLJD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ 23-JUN-01 Insite 4.3 Memory 11971.0 11415.0 11971.0 88.2 93.1 TOOL NUMBER 2049RF3 2049RF3 3.750 Flo Pro 8.70 65.0 9.5 23000 6.6 .195 74.0 .090 162.0 .200 74.0 .270 74.0 Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... , Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 0 1 4 2 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT FT 1,1370 ]_1964 ROP MWD030 FT/H 4.27 190.05 GR MWD030 API 17.8 66.92 RPX MWD030 OHMM 1.9'7 6.49 RPS MWD030 OHMM 2.08 6.83 RPM MWD030 OHMM 2.2 7.43 RPD MWD030 OHMM 2.44 8 FET MWD030 HOUR 0.2712 13.3046 First Reading For Entire File .......... 11370 Last Reading For Entire File ........... 11964 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... 'Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Mean 1.1667 94.4763 28.7637 3.47833 3.75627 4.03989 4.26301. 1.64958 Nsam 1,].,89 1098 11.13 1113 ].1.13 1113 11,13 111,3 First Reading ].1370 ].1415.5 11370 1].381 11381 11,381 1,,1,38]. 11,381 Last Reading 11964 11964 11926 11937 11937 11937 11937 11937 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit. run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11926.5 12813.5 RPM 11937.5 12824.5 FET 11937.5 RPX 11937.5 RPD 11937.5 RPS 11937.5 ROP 11964.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUH ANGLE: 1°°'~4 5 128 '24.5 12824.5 12824.5 12859.0 24-JUN-O1 tnsite 4.3 Memory 12859.0 11971.0 12859.0 85.2 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAl., GAMMA RAY 2049RF3 EWR4 ELECTROMAG. RESIS. 4 2049RF3 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 BOREHOLE CONDITIONS MUD TYPE: Fie Pro MUD DENSITY (LB/G): 8.62 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 23000 FLUID LOSS (C3): 8.2 RESISTIVITY (OHMM) AT TEMPERATURE {DEGF) MUD AT MEASURED TEMPERATURE (MT): .150 MUD AT MAX CIRCUI.,ATING TERMPERATURE: .070 MUD FILTRATE AT' MT: .120 MUD CAKE AT MT: .110 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DE PT FT 4 1 68 ROP MWD040 FT/H 4 1 68 GR MWD040 API 4 1 68 RPX MWD040 OHMM 4 1 68 RPS MWD040 OHMM 4 i 68 RPM MWD040 OHMM 4 i 68 RPD MWD040 OHMM 4 1. 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 70.0 165.0 70.0 70.0 FET MWD040 HOUR 4 1 68 28 8 Name Service Unit Min Max DEFT FT 11926.5 12859 ROP MWD040 FT/H 1.37 380.82 GR MWD040 API 17.61 117.33 RPX MWD040 OHMM 1.13 39.33 RPS MWD040 OHMM 1.43 19.7 RPM MWD040 OHMM 1.83 19.68 RPD MWD040 OHMM 3.81 19.63 FET MWD040 HOUR 0.2293 8.8913 Mean 12392.8 120.467 40.0724 9.26424 9.82322 10.2662 10.7285 1.38003 First Reading For Entire File .......... 11926.5 Last Reading For Entire File ........... 12859 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Nsam 1866 1790 1775 1775 1775 1775 1775 1775 First Reading 11926.5 11964.5 11926.5 11937.5 11937.5 11937.5 11937.5 11937.5 LasE Reading 12859 12859 12813 5 12824 5 12824 5 12824 5 12824 5 12824 5 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Gen, eration ....... 02/07/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record. FILE HEADER FILE NUMBER: 7 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL, CODE START DEPTH STOP DEPTH RAT 11198.5 12859.0 FET 11.199.5 12827.5 RPD 11199.5 12827.5 RPM 11,199.5 12827.5 RPS 11199.5 1,2827 . 5 RPX 11199.5 12827 . 5 GR 1].233.0 12816.5 $ LOG HEADER DATA DATE LOGGED: 24-JUN-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12859.0 TOP LOG INTERVAL, (FT): 11200.0 BOTTOM LOG INTERVAL (FT): 12859.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 94.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEM?ERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical lo9 depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER 3.750 Flo Pro 8.62 65.0 9.0 23000 8.2 .].5O 7O.O .070 165.0 .120 70.0 .110 70.0 Name Service Order [,]nits Size Nsam Rep DEPT FT 4 1 68 RAT MAD041 FT/H 4 I 68 GR MAD041 API 4 1. 68 RPX MAD041 OHMM 4 1 68 RPS MAD041 OHMM 4 i 68 RPM MAD041 OHMM 4 1 68 RPD MAD041 OHMM 4 1 68 FET MAD041 HOUR 4 I 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 2O 6 24 7 28 8 Name Service Unit Min Max DEPT F'r 11198.5 12859 RAT MAD041 FT/H 549.4 1010.67 GR MAD041 API 11.22 4:95.52 RPX MAD041 OHMM 1.03 58.33 RPS MAD041 OHMM 1.3 18.33 RPM MAD041 OHMM 1.56 18.6 RPD MAD041 OHMM 2.08 46.77 FET MAD041 HOUR 3.3633 82.8306 Mean 12028.8 720.07 41,. 9313 5.7092 6.3107 (5.78208 7.63921 34. 0156 First Readin9 For Entire File .......... 11198.5 Last Reading For Entire File ........... 12859 Nsam 3322 3322 3129 3257 3257 3257 3257 3257 First Reading 11198.5 111.98.5 11233 11199.5 11199.5 11199.5 11199.5 ].].199.5 Last Reading 12859 12859 1280.6.5 12827.5 12827.5 12827.5 12827.5 12827.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/07/12 Ma?~imum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/07/12 Origir~ ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Mame ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/07/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
