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Home My WebLink About198-090Nolan 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: 11/07/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20251107 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-26 50283201820000 220058 9/20/2025 AK E-LINE Perf BRU 212-35 50283100270000 162018 10/12/2025 AK E-LINE TubingPuncher BRU 234-27 50283202070000 225065 7/17/1905 AK E-LINE CBL-02-October BRU 234-27 50283202070000 225065 10/6/2025 AK E-LINE CIBP/Perf GP 42-23RD 50733201140100 195145 10/26/2025 AK E-LINE TubingPunch GP ST 42-23RD 50733201140100 195145 10/9/2025 AK E-LINE JetCut MPL-54 50029236070000 218066 10/16/2025 READ CaliperSurvey MPL-57 50029236090000 218072 10/27/2025 READ CaliperSurvey MPU B-21 50029215350000 186023 10/25/2025 AK E-LINE RBP NCIU A-07 50883200270000 169058 10/10/2025 AK E-LINE JetCut NCIU A-17A 50883201880100 225089 10/10/2025 AK E-LINE Perf NCIU A-17A 50883201880100 225089 10/14/2025 AK E-LINE Perf PBU 01-10A 50029201690200 225055 8/29/2025 HALLIBURTON RBT PBU 05-11A 50029202520100 196097 10/11/2025 BAKER RPM PBU 05-31B 50029221590200 210085 10/14/2025 BAKER SPN PBU F-06B 50029200970200 225054 9/27/2025 BAKER MRPM PBU F-42A 50029221080100 207093 10/27/2025 BAKER RPM PBU H-07B 50029202420200 225064 9/29/2025 BAKER MRPM PBU L5-27 50029236270000 219046 10/7/2025 BAKER SPN PBU Q-06A 50029203460100 198090 8/22/2025 YELLOWJACKET SCBL SD-06 50133205820000 208160 7/23/2025 YELLOWJACKET GPT-PERF SRU 222-33 50133207150000 223100 7/15/2025 YELLOWJACKET PERF Please include current contact information if different from above. T41066 T41067 T41068 T41068 T41069 T41069 T41070 T41071 T41072 T41073 T41074 T41074 T41075 T41076 T41077 T41078 T41079 T41080 T41081 T41082 T41083 T41084 PBU Q-06A 50029203460100 198090 8/22/2025 YELLOWJACKET SCBL Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.11.07 15:03:51 -09'00' 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: 09/19/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250919 Well API #PTD #Log Date Log Company Log Type AOGCC E-Set# BRU 212-35T 50283200970000 198161 8/10/2025 AK E-LINE PPROF T40899 BRU 223-34T 50283202060000 225059 8/17/2025 AK E-LINE CBL T40900 BRU 234-27 50283202070000 225065 9/12/2025 AK E-LINE CBL T40901 BRU 242-04 50283201640000 212041 6/9/2025 AK E-LINE Perf T40902 KBU 11-08Z 50133206290000 214044 9/8/2025 AK E-LINE Perf T40903 MPU H-03 50029220630000 190088 9/9/2025 AK E-LINE SetPacker T40904 MPU H-11 50029228020000 197163 2/9/2025 AK E-LINE Caliper T40905 MPU M-62 50029237440000 223006 8/31/2025 AK E-LINE LDL T40906 NCIU A-06 50883200260000 169050 8/25/2025 AK E-LINE TubingCut T40907 NCIU A-21A 50883201990100 225075 8/26/2025 AK E-LINE Perf T40908 ODSK-33 50703205620000 207183 9/10/2025 READ Caliper Survey T40909 ODSN-01a 50703206480100 216008 9/8/2025 READ Caliper Survey T40910 ODSN-06 50703207150000 215098 9/9/2025 READ Jewelry Log T40911 PBU C-34C 50029217850300 225068 8/25/2025 BAKER MRPM T40912 PBU Q-06A 50029203460100 198090 8/21/2025 BAKER SPN T40913 TBU M-25 50733203910000 187086 8/31/2025 AK E-LINE Drift T40914 Please include current contact information if different from above. PBU Q-06A 50029203460100 198090 8/21/2025 BAKER SPN Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.09.22 13:22:50 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU Q-06A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-090 50-029-20346-01-00 12521 Conductor Surface Intermediate Production Liner 9016 80 2656 10486 1087 2622 11750 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 9021 31 - 111 30 - 2686 29 - 10515 10004 - 11091 9835- 12518 31 - 111 30 - 2674 29 - 8365 8001 - 8815 7924 - 9016 12421 2670 4760 7020 7500 11750 5380 6870 8160 8430 11655 - 12240 4-1/2" 12.6#, 7" 26# L-80 27 - 9795, 9835 - 10019 9020 - 9030 Structural 4-1/2" HES TNT Packer 9745 7816 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 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 0028281, 0028284 27 - 7851, 7879 - 8012 N/A N/A 488 Well Test Not Available 53365 60 300 950 1060 660 N/A 13b. Pools active after work:Prudhoe Oil No SSSV Installed 9745, 7816 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:38 pm, Sep 18, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.18 13:20:16 - 08'00' Torin Roschinger (4662) RBDMS JSB 092525 J.Lau 11/6/25 ACTIVITY DATE SUMMARY 9/7/2025 ***WELL S/I ON ARRIVAL*** (SET PLUG IN ZONE) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH, FUNCITON WLVS SET PLUG @ 11750'/ PUMP DOWN ASSIST. CCL TO TOP SHOT= 15.8' CCL STOP DEPTH= 11734.2' CONFIRM PLUG SET . RDMO YJ ELINE *** WELL S/I ON DEPARTURE*** JOB COMPLETE 9/7/2025 Initial WHP T/IA/OA = 150/ 292/ 17 TFS U4, (Assist E-line) W/ (load & secure well/pump down plug) Pumped 1 BBL of 60/40 followed by 180 BBLS of Crude down TBG to Load. Pumped 58 BBLS of Crude down TBG to assist E-Line with setting plug. FWHP's = 45/ 288/ 40 Daily Report of Well Operations PBU Q-06A STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report for: Reviewed By: P.I. Suprv Comm ________PRUDHOE BAY UNIT Q-06A JBR 07/24/2023 MISC. INSPECTIONS: FLOOR SAFTY VALVES:CHOKE MANIFOLD:BOP STACK: ACCUMULATOR SYSTEM:MUD SYSTEM: P/F P/F P/FP/FP/F Visual Alarm QuantityQuantity Time/Pressure SizeQuantity Number of Failures:2 Test with 7" TJ, Had lots of trouble getting started due to test JT leaking at a XO that they could not get torqued up correctly initial shell test that I was told was good was not when I arrived and we started over and figured out it was the test joint. Also plug valves down stream of choke manifold won’t hold high pressure so did a work around. C3 failed serviced and cycled passed, C4 failed cycled and passed. Fluid used was a 60/40 methanol mix also with the cold weather and poorly tented cellar and bop stack we had some thermal issues while testing early on. 16 bottles @ 954 psi precharge avg Test Results TEST DATA Rig Rep:Branndon Stiffler/Apti Operator:Hilcorp North Slope, LLC Operator Rep:Dan Scarpella/Eli Wilson Rig Owner/Rig No.:Hilcorp Thunderbird 1 PTD#:1980900 DATE:5/9/2023 Type Operation:WRKOV Annular: 250/3000Type Test:INIT Valves: 250/3000 Rams: 250/3000 Test Pressures:Inspection No:bopKPS230509222526 Inspector Kam StJohn Inspector Insp Source Related Insp No: INSIDE REEL VALVES: Quantity P/F (Valid for Coil Rigs Only) Remarks: Test Time 9.5 MASP: 2299 Sundry No: 322-490 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 O Misc NA Upper Kelly 0 NA Lower Kelly 0 NA Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA 8 FPNo. Valves 2 PManual Chokes 0 NAHydraulic Chokes 0 NACH Misc Stripper 0 NA Annular Preventer 1 13-5/8"P #1 Rams 1 4-1/2" x 7"P #2 Rams 1 Blinds P #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA #6 Rams 0 NA Choke Ln. Valves 1 3-1/8"P HCR Valves 1 3-1/8"P Kill Line Valves 3 3-1/8"P Check Valve 0 NA BOP Misc 0 NA System Pressure P3000 Pressure After Closure P1600 200 PSI Attained P23 Full Pressure Attained P111 Blind Switch Covers:PAll Stations Bottle precharge P Nitgn Btls# &psi (avg)P3@2233 ACC Misc NA0 P PTrip Tank P PPit Level Indicators P PFlow Indicator P PMeth Gas Detector P PH2S Gas Detector NA NAMS Misc Inside Reel Valves 0 NA Annular Preventer P20 #1 Rams P8 #2 Rams P8 #3 Rams NA0 #4 Rams NA0 #5 Rams NA0 #6 Rams NA0 HCR Choke P1 HCR Kill NA0 9 9 9 9 9999 9 9 9 5(9,6(' C3 failed serviced C4 failed cycled and passed.60/40 methanol mix poorly tented cellar and bop stack Hilcorp Thunderbird 1 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. From:AOGCC Permitting (CED sponsored) To:Brooks, James S (OGC) Subject:FW: CANCEL Request: PBU Q-06A (PTD #198-090) 10-403 Change to Approved Program Sundry #323-072 Date:Tuesday, April 4, 2023 1:15:47 PM Hi James, This is a cancelation for a 10-403 that has already been processed. It was approved on February 7th 2023. Kayla Junke Natural Resources Tech II AOGCC (907) 793-1225 From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Tuesday, April 4, 2023 12:40 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Stan Golis <sgolis@hilcorp.com>; Josh Stephens <Josh.Stephens@hilcorp.com>; Aras Worthington <Aras.Worthington@hilcorp.com> Subject: CANCEL Request: PBU Q-06A (PTD #198-090) 10-403 Change to Approved Program Sundry #323-072 All, Please cancel 10-403 Sundry Request #323-072 for the Change to Approved Program for the Q-06A RWO. This RWO will be executed by Thunderbird 1 rig as originally planned and approved in Sundry #322-490 and, as such, the Change sundry is not required. Please let me know if you have any questions or need additional information. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby 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 Q-06A Casing Patch, Mill CIBPs Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-090 50-029-20346-01-00 12521 Conductor Surface Intermediate Production Liner 9016 80 2656 10486 1087 2622 12437 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 9020 31 - 111 30 - 2686 29 - 10515 10004 - 11091 9835- 12518 31 - 111 30 - 2674 29 - 8365 8001 - 8815 7924 - 9016 12421 2670 4760 7020 7500 None 5380 6870 8160 8430 11655 - 12240 4-1/2" 12.6#, 7" 26# L-80 27 - 9795, 9835 - 10019 9020 - 9030 Structural 4-1/2" HES TNT Packer 9745, 7816 9745 7816 Torin Roschinger Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 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 0028281, 0028284 27 - 7851, 7879 - 8012 N/A N/A 575 1509 130 13030 153 361 100 1450 701 675 322-490 13b. Pools active after work:Prudhoe Oil No SSSV Installed 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 11:44 am, Jun 13, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.13 06:12:21 -08'00' Torin Roschinger (4662) WCB 2-1-204 RBDMS JSB 071423 DSR-6/13/23 ACTIVITY DATE SUMMARY 8/5/2022 T/I/O = LOTO/140/10. Temp = SI. PPOT--T(PASS) & PPOT- IC (PASS) (pre rig). Dry hole tree. PPOT-T: Sting into test void 0 psi. Monitor for 10 min, no change. Increase void to 5000 psi for 30 min test. Lost 150 psi in 1st 15 min, lost 50 psi in the 2nd 15 min for a PASS. Bled void to 0 psi. PPPOT- IC: Sting into test void 20 psi, bled to 0 psi. Monitor for 10 min, no change. Increase voild to 3500 psi for 30 min. Lost 150 psi in 1st 15 min, lost 0 in the 2nd 15 min for a PASS. Bled void to 0 psi. SV = C. MV = O. IA, OA = OTG. 17:45 3/13/2023 T/I/O = 0/0/0. Temp = SI. Function LDS on TBG hanger (RWO). No AL, well house, well scaffold, flow line or S-riser. Dry-hole tree installed. Stung into TBG hanger test void (0 psi). Functioned all LDS on TBG hanger, all functioned normally. SV = C. MV = O. IA & OA = OTG. 17:00. 5/4/2023 T/I/O=120/135/6 CIRC-OUT ( Pre RWO) Pump 2 bbls 60/40 through hardline to prove flowpath and TxIA communication. Pump 100 bbls freshwater/deepclean, 710 bbls 1% KCL / Safelube, and 141 bbls diesel down IA taking returns up TBG to Q-05 flowline. U-tube TxIA to freeze protect. Bleed pressures TxIA to 0 psi ****** Freeze protect Q-05 with 275 bbls crude.***** Pressure up on TxIA with 6.5 bbls diesel to verify integrity. TxIA lost 5/10 psi in 10 mins. Bled 6.5 bbls back to 0 psi. *** Freeze protect Q-06 disconnected flowline ( Per Pad Op ) through 1/2" swedge with 275 bbls crude and pressured up FL to 1500 psi *** Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 5/4/2023 T/I/O = Vac/0/0. Set 6" J TWC #421 through DH tree. RD DH and THA, Installed 13" BOP w/ birdbath and Shooting flange. Torqued to API Spec. PT'd with lift gas from Q- 07 480 PSI (Pass). 5/5/2023 T/I/O = VAC/VAC/VAC. Temp = SI. Bleed WHPs and C&B lines to 0 psi (pre rig). No AL, well house, well scaffold, flow line or S-riser. Bled C&B lines to 0 psi. SV = C. MV = O. IA & OA = OTG. 03:00. 5/5/2023 Check void for pressure. N/D tree, Inspect void, TBG HGR neck and lift threads. TBG HGR threads are bad. will need to spear. LDS out = 4 1/4". Plug (2) 1/8" CCL ports on TBG HGR neck. N/U BOP. Daily Report of Well Operations PBU Q-06A Daily Report of Well Operations PBU Q-06A 5/8/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap MIRU Thunderbird-1. Spot rig, pits, pump house, koomey, choke house. Raise mast. Load of KCL in outside WS on location to rig up iron to return tank and line to IA. Hook up Koomey hoses to BOP stack. Grease choke and kill manifold. Load of KCL in inside URs. Install 3-1/8" integral flanges on IA and OA . Build Scaffold & Hootch around stack. Spot pipe wrangler. M/U 7" Test Joint w/BTC crossover. Scaffold crew completed, install 7" test joint, place in stack. Shell test 250 psi low / 3000 psi high......test joint leaking at BTC connection. ......Job in progress 5/9/2023 T/I/O=TWC/0/0. TB #01 Decompletion. Pulled 6" TWC #421 through stack with dryrod. ***Job Complete*** Final WHP's 0/0/0. 5/9/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap Completed BOPE test with 7" test joint, AOGCC witnessed (Kam St John). Pulled J- plug from hanger. Rock out diesel freeze protect from Tbg & IA. R/U Parker 7" handling equipment. M/U & set YJ 5.75" ITCO spear w/stop sub in hanger pup. BOLDS. Pulled Hanger to floor, 225k to release, break out hanger and lay down. Disconnect control lines and run through sheave. Begin pulling 7" 26# IJ4S tubing and dual control lines. Lay down 49 joints, disconnect control lines, lay down SSSV. Recovered 25 clamps and 2 SS bands. Continue pulling 7" 26# IJ4S tubing. ......Job in progress 5/9/2023 RIH w/ spear. Spear into TBG HGR. BOLDS. Pull TBG HGR to rig floor. Terminate (2) 1/4" CCL's. Laydown TBG HGR. 5/10/2023 M/U test plug and land at verified RKB. RILDS. S/B for BOP test. B/O LDS, Pull test plug 5/10/2023 ***ASSIST THUNDERBIRD RIG*** STAND BY FOR RIG BOP TEST. R/U SLICKLINE. ***WSR CONTINUED ON 5-11-23. 5/10/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap Continue pulling 7" 26# IJ4S tubing. Pulled 241 full joints and 6.25" cut joint. R/D Parker TTS. Set test plug. C/O VBRs to 2-7/8" x 5". BOPE test VBRs w/4-1/2" and 2- 7/8" test joints 250 psi low / 3000 psi high. Test annular w/2-7/8" test joint to 250 psi low / 2500 psi high as per sundry. AOGCC waived witness (Kam St John). BOLDS. Pulled test plug. MIRU Pollard Slickline. RIH w/8.45" junk basket, tagged 7" tubing stub @ 9,850' slm. POOH. ......Job in progress 5/11/2023 ***WSR CONTINUED FROM 5-10-23*** MADE 4 JUNK BASKET RUNS FROM 9,850' SLM TO 9,855' SLM (recovered ~6-8 gallons of rubber pieces & slurry) TAGGED TUBING STUB @ 9,850' SLM W/ 6" LIB SET SCOOP GUIDE ON TUBING STUB DRIFTED THROUGH SCOOP GUIDE W/ 3.80" GAUGE RING & 4 1/2" BRUSH, PUSHED SOMETHING DOWNHOLE FROM 9,927' SLM TO 10,000' DRIFTED TO 10,000' W/ 20' x 3.70" DUMMY WHIPSTOCK, CLEAR ***THUNDERBIRD IN CONTROL ON DEPARTURE*** Daily Report of Well Operations PBU Q-06A 5/11/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap Continue Slickline operations, made 4 runs w/8.45" junk catcher to top of 7" Tubing Stub @ 9,850' slm. Recovered 12 gallons of rubber chunks and encapsulation. Ran 6.0" LIB to 7" tubing stub @ 9,855' slm, impression of stub. Set 8.20" x 8.30' Scoop Guide (3.958" ID) on top of stub @ 9,842' ORKB. Drifted w/brush & 3.80" gauge ring to 9,927' slm, pushed debris to 10,000' slm. Drifted w/3.70" x 20' Dmy WS to 10,000' slm w/no issues. RDMO Pollard Slickline. TB-1 pipe wrangler not functioning, repair broken chain on skate, replace proximity sensor, and remove kick out diverter valve. Lay out drill pipe, tailpipe assy w/RHCM, PBR assy. ......In Progress, Continued on 5/12/23 WSR 5/12/2023 STANDBY FOR PATCH CORRELATION 5/12/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap PJSM. M/U & TIH on WS w/7" x 5" PBR, HES 9-5/8" x 4-1/2" TNT PKR, and X-nipple - RHCM assembly. P/U joint 315 and set 26' in. WLEG depth = 9,795' ORKB, 40' above scoop guide. Circulate 15 bbls of KCI down DP & up 9-5/8" casing to flush ball seat in RHCM plug. Drop Ball & Rod. Pressure up on DP to 3500 psi, good indication of packer set @ 2000 psi. HES TNT PKR set depth = 9,744' ORKB. Bleed DPP to 500 psi. Pressure up 9-5/8" casing to 2000 psi. ......In Progress, Continued on 5/13/23 WSR 5/13/2023 RIH W/ 1-7/16'' CHD (1" FN), 5' X 1-11/16" WB, 5' X 1-11/16" WB, 1-11/16" CCL CORRELATE CEMENTER AT 2,038' TO TALLY DATED 1/29/1979 ADD 11.5' WLEG AT END OF WORK STRING DEPTH=1,919' 5/13/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap Pressure up 9-5/8" casing to 2000 psi. Good test. Bleed DPP & 9-5/8" casing to zero. PUW 67k, SOW 56k. Sheared PBR, TOH w/2-7/8" 7.9# work string LDSW. Rack back 32 stands. L/D seal assy. M/U BHA # 3 = PH6 x VT XO and WLEG. TIH w/2- 7/8" WS stands to 1,922' ORKB. Flag pipe at slips. MIRU AK Wireline services. Correlate CCL to 9-5/8" casing tally 29-Jan-1979. Logged correlation pass from 2,200' to 1,800'. FOC = 2,038' - 2,042' ORKB. WLEG = 1,919' ORKB. TOH w/2-7/8" 7.9# WS racking back stands. B/D & lay down XO/WLEG. M/U Owens Patch BHA. ......In Progress, Continued on 5/14/23 WSR 5/14/2023 (RWO EXPENCE) Assist Thunder Bird setting packer @ 5000 psi. 5/14/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap M/U Owens Patch BHA = 66.21' OAL. TIH w/BHA # 4 on 2-7/8" 7.9# WS stands. At flag, bottom patch element = 1,982.16' ORKB. 9-5/8" FOC = 2,038' - 2,042' ORKB. RIH 67' to set depth straddling FOC, confirmed by Owens rep. Top patch element = 2,028' ORKB. Bottom patch element = 2,049' ORKB. Drop 5/8" ball and set Owens 8.5" X-Span Patch. Setting tool collet not releasing 30k over PUW. Pressure up on setting tool to 5000 psi, no release. Cycle pressure. Rotate DP 100 turns, no release. Pulled 30k over and set pipe in slips, pressure up to 1500 psi and setting tool released. TOH w/2-7/8" 7.9# WS LDSW. Recovered all Owens setting tool components, no definitive marks on setting tool. R/U to run 4-1/2" VamTop completion w/TBird TTS. TBird troubleshooting TTS. Mobilize GBR for torque turn services. ......In Progress, Continued on 5/15/23 WSR gg M/U Owens Patch BHA = 66.21' OAL. TIH w/BHA # 4 on 2-7/8" 7.9# WS stands. At flag, bottom patch element = 1,982.16' ORKB. 9-5/8" FOC = 2,038' - 2,042' ORKB.g RIH 67' to set depth straddling FOC, confirmed by Owens rep. Top patch element =g y 2,028' ORKB. Bottom patch element = 2,049' ORKB. Drop 5/8" ball and set Owens 8.5" X-Span Patch Daily Report of Well Operations PBU Q-06A 5/15/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap Mobilize GBR for torque turn services. R/U GBR dump valve & computer to McCoy tongs, calibrate. RIH w/4-1/2" 12.6# L-80 VamTop completion as per run tally. At joint #293 seal assembly just above PBR, R/U to circulate packer fluid. ......In Progress, Continued on 5/15/23 WSR 5/16/2023 T/I/O= 0/85/0 Temp=S/I (TFS Unit 4 assist rig with freeze protect) Pumped 3 bbls of 60/40 followed by 170 bbls of DSL for freeze protect. Final WHPS 0/123/0 5/16/2023 S/B for RIH & space out. M/U TBG HGR to string, Land TBG HGR at verified RKB. RILDS. S/B for CSG/TBG test. Set 4" H TWC after U-tube diesel. 5/16/2023 TBird RWO Job Scope: Csg Patch & Tubing Swap. Continue WSR from 5/15/2023 Circulate 200 bbls of 1% KCI w/CI corrosion inhibitor down tubing & up the IA 3.5 bpm 300 psi. Chase packer fluid w/148 bbls of 1% KCI. Space out.....P/U joint 295 and no-go 26' in. 26' - 14.38' (rkb) - 3.5' (hgr & pup) - 4' off no go = 4.12' space out pups. P/U 3.97' space out pup. M/U hanger & land completion. RILDS. MIT-T Targeting 2750 psi. Tested at 2950 psi. No loss during 30 mins Bleed TBG to 1500 psi. MIT-IA Targeting 2750 psi. Tested at 2970 psi. 35 psi loss / 15 psi loss. Both passed Bleed Tbg down and shear DCK in top GLM. Pump 170 bbls of diesel down IA then UTube with Tbg for one hour. Set TWC and Rig Down. ***RWO Program Completed*** 5/16/2023 T/I/O=BPV/0/0. Post TB #01. Evcuated fluids from BOP, RD 13 5/8" Cameron BOP and installed 13" McEvoy Two step THA. Torqued flange to API spec, Wellhead tech perform PPPOT-T. Passed. Made changeout with Day shift. (Chvilicek) NU 4" CIW production tree and torque flanges to spec. Pressure test tree against TWC to 500/5000 psi. Passed. Wellhead tehc pull 4" H" TWC with dryrod. Install prodcution S-riser and floor kit for slickline access. ***Job in Progress*** Final WHP's 0/0/0. 5/17/2023 Clean void & ring groove, notice small piece of hanger OD seal sticking up above lock down screw profile. Took picture & sent to Clint Miller to see if he thought it should be changed out. He suggested putting on THA & see if it holds pressure test. Install new BX-160, pick up THA & inspect ID seal areas, grease ID & land on tubing head, well support torqued up studs & nuts. Test void 500 psi./5 min., 0 psi loss, test 5,000 psi./30 min, lost 200 psi. first 15 min., lost 0 psi. last 15 min., bleed off test psi., rig down test equipment, stand by for well support to N/U & test tree. Pull 4" H TWC w/ T bar, RDMO. 5/18/2023 ***WELL S/I ON ARRIVAL*** SET BAITED JU ON B&R @ 9,779' MD MAKE SEVERAL ATTEMPTS PULLING STA. # 3 @ 6,568' MD RAN KJ, 4 1/2" OM-K W/ 1 1/4" LIB S/D IN STA.# 3 @ 6,568' MD (LIB inconclusive) PULL STA. # 4 BEK-DCK @ 3,559' MD RAN 2.80" CENT. 4 1/2" BLB, KJ, KJ, JD RATTLE MANDRELS, S/D @ 9,779' MD (NO RECOVERY) TROUBLE SHOOT STA. # 3 @ 6,568' MD ***CONTINUE 5/19/23*** MIT-T Targeting 2750 psi. Tested at 2950 psi. No loss during 30 mins Bleed TBG to 1500ggg psi. MIT-IA Targeting 2750 psi. Tested at 2970 psi. 35 psi loss / 15 psi loss. Both passed )(g) g M/U hanger & land completion. RILDS. g Daily Report of Well Operations PBU Q-06A 5/19/2023 ***CONTINUE FROM 5/18/23*** TROUBLE SHOOT STA.# 3 (NO LUCK) SET STA. # 4 BK-LGLV (16/64", TRO 1500 psi) PRESSURE TUBING UP TO 500 psi, IA - 0 psi (to ensure sta.# 3 BK-DGLV is still holding) PULL STA.# 2 BK-DGLV SET BK-OGLV IN ST#2 @ 8,378' MD PRESSURE UP TBG, IA TRACKS TAP ON BK-OGLV IN ST#2 PRSSURE UP TBG, IA NO LONGER TRACKING PULLED BAITSUB w/ BELLGUIDE, JU FROM B&R w/o B&R PULLED B&R FROM RHC @ 9,779' MD PULL RHC @ 9,779' MD (Large metal piece inside RHC) RAN 4 1/2" BLB, 3 PRONG GRAB S/D @ 11,167' SLM (small rubber chunk & metal shavings) ***CONTINUE 5/20/23*** Note: possible debris on top of latch in st# 3 5/20/2023 CTU#9 1.75" CT. Job Scope: Mill CIBP's (Post RWO) Depart Slb Yard to Q-06. ***In Progress*** 5/20/2023 ***CONTINUE FROM 5/19/23*** MADE 5 RUNS w/ 3.78" JUNK BASKET FROM 11,168' SLM TO 11,183' SLM (recovered ~3 gallons rubber pieces) RAN 10' x 3.5" PUMP BAILER, SD IN DOGLEGS @ 11,138' SLM MADE 2 RUNS w/ 2.5" PUMP BAILER FROM 11,183' SLM TO 11,191' SLM (recovered ~1/2 gallon of black goo) LAST BAILER RUN COULD NOT PASS TOP OF SCOOP GUIDE @ 9,835' MD CALL MADE TO RIG DOWN & HAND OVER TO COIL ***WELL LEFT S/I*** 5/21/2023 CTU#9 1.75" CT. Job Scope: Mill CIBPs (Post RWO) Rig up CTU. Pumped 1.188" Drift Ball. Perform Weekly BOP Test. Recovered 1.188" Ball. MU & RIH w/ YJ 3-1/8" Venturi w/ 3.70" Mule Shoe. Take pipe disp returns while RIH. Tag at 11183'. Work Venturi down to 11,185'. No issues getting into scoop guide. Work Venturi. Pooh. While pulling ooh the Level Wind quit working. Slb able to Fix Level Wind enough to pull ooh. The Level Wind Lead Screw needs to be replaced. Unclear on path forward with Slb fixing level wind. Freeze Protect Coil & Tbg from 2500' TVD w/ Diesel. Recover ~ 2 gallons of Sludge and ~ 1 cup of Rubber. Slb on downtime replacing reel lead screw. ***In Progress*** PULLED B&R FROM RHC @ 9,779' MD PULL RHC @ 9,779' MD Daily Report of Well Operations PBU Q-06A 5/22/2023 CTU#9 1.75" CT. Job Scope: Mill CIBPs (Post RWO) Slb replace lead screw on level wind. RIH w/ 2-7/8" Milling BHA w/ 3.78" Junk Mill. Take pipe disp returns while Rih. Dry Tag Scoop Guide at 9840'. Roll thru with no issues. Dry Tag top of Fill at 11205'. Cleanout down to CIBP at 11234'. Appear to be on the CIBP. Pump 10 bbl Gel sweep & circulate btms up. Mill CIBP at 11234'. Lost returns and stalled. Bit stuck after stall. Work jars ~2 hrs and come free. POOH and swap tools. RIH w/ 2-3/8" Milling BHA w/ 3.78" Venturi Burnshoe. Push top plug to top of lower plug. Worked for a while, POOH to inspect. Recovered a few slips, some metal pieces and small rocks. RIH w/ 2-3/8" Milling BHA w/ 3.78" Venturi Burnshoe. ***Job Continued on 5/23/23*** 5/23/2023 CTU#9 1.75" CT. Job Scope: Mill CIBPs (Post RWO) ***Job continued from 5/22/23*** Continue RIH w/ 2-3/8" Milling BHA w/ 3.78" Venturi Burnshoe. Set down 11,803 ctmd. Begin burning over. Not seeing any progress, POOH. Recover plug parts (slips/metal) and rubber pieces in venturi. RIH w/ Motor Venturi/Mule Shoe. RIH to 11807' and work Venturi over top of plug and POOH while circulating. Recover ~0.5gal fines/metal and plug core. Changeout packoff and swap to milling BHA with 3.63" reverse clutch mill. Tag CIBP #2 11,806' ctmd. Begin milling, got the plug moving down to 11862 ctmd. ***Job continued on 3/24/23*** 5/24/2023 CTU#9 1.75" CT. Job Scope: Mill CIBPs (Post RWO) ***Job continued from 5/23/23*** Continue to work plug #2 down to 11,868 ctmd. POOH to pick up venturi. RIH w/ Venturi Burn Shoe. Mill CIBP to below perfs and push to bottom @ 12421'. POOH circulating to the tubing tail. FP coil and tubing w/ 38bbls diesel. Retrieved CIBP debris in venturi. RDMO ***Job Complete*** g Mill CIBP to below perfs and push to bottom @ 12421'. POOH circulating to the tubing tail. gg g Tag CIBP #2 11,806' ctmd. Begin milling, got the plugg moving down to 11862 ctmd. Mill CIBP at 11234'. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU Q-06A Casing Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-090 50-029-20346-01-00 N/A ADL 0028281, 0028284 12521 Conductor Surface Intermediate Liner Liner 9016 80 2656 10486 1087 2622 11236 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8912 31 - 111 30 - 2686 29 - 10515 10004 - 11091 9896 - 12518 2299 31 - 111 30 - 2674 29 - 8365 8001 - 8815 7924 - 9016 None 2670 4760 7020 7500 11236, 11800 5380 6870 8160 8430 11655 - 12240 7" 26# L-80 27 - 100199020 - 9030 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Stan Golis Sr. Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 970.779.1200 PRUDHOE BAY 2/17/23 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov procedure approved her February 3, 2023 By Meredith Guhl at 3:29 pm, Feb 03, 2023 323-072 * Initial IC leak rate at test pressure to AOGCC. 2299 DSR-2/3/23MGR06FEB23 * BOPE test to 3000 psi. Annular to 2500 psi. DLB 02/06/2023 10-404X GCW 02/07/23 JLC 2/7/2023 2/7/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.07 14:53:42 -09'00' RBDMS JSB 020823 Rev # 2 1/25/22 RWO Q-06A PTD:198-090 Well Name: Q-06A API Number: 50-029-20346-01 Current Status: Shut-In Rig: Nordic 3 Estimated Start Date: 2/17/23 Estimated Duration: 6 Days Reg.Approval Req’std? 10-403, 404 Date Reg. Approval Rec’vd: N/A Regulatory Contact: Abbie Barker Permit to Drill Number: 198-090 First Call Engineer: Josh Stephens (970)779-1200 Second Call Engineer: Brodie Wages 713-380-9836 Current Bottom Hole Pressure: 3179 psi @ 8800’ TVD 7.3 PPGE (+0.3 SF)| SBHP 2/27/12 Max. Anticipated Surface Pressure: 2299 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP: 0 psi (Taken on 3/23/20 Well Secured TTP) Min ID: 3.813” ID @ 9,896’ MD Max Angle: 94 Deg @ 12,311’ MD’ Brief Well Summary: Q-06A was drilled in 1998. It produced full time until 2003 when it started cycling against MGOR. In 2006, the well was SI due to the transit line leak and did not return to production until 2008. The GOR had healed over that shut-in period so the well again produced near full time until 2011, when it began cycling. The original perforations were open until 2015, when a bridge plug was set and perfs were added uphole in Z2A. Those perfs became marginal in 2016 and the well was screened for sidetrack in late 2017. A CIBP was set to isolate the Ivishak for screening, the tubing patches were pulled, and the tubing was cut in preparation for a RWO + coil sidetrack. In 2018, the BP rig economics changed and the Q-06B sidetrack was dropped off the schedule and the well has been SI with compromised tubing ever since. Also, in 2018, a CMIT-TXIA passed to 2593 psi indicating production casing integrity. There is future potential for Zone 4 and Sag rich gas add perfs that will not be pursued at this time. *Update 8/1/22: Additional review of integrity history confirmed slight IAxOA communication through leaking 9-5/8” cementer at ~2038’ MD as logged on acoustic LDL on 5/30/13 (.1gpm leak rate). While IAxOA communication rates improved following sealtite treatment on PC on 9/24/13 and reenergizing PC wellhead seals in 2014, some IAxOA communication still exists based on T/I/O trends. Additionally, well has not seen gas lift since 2013/2014. For these reasons, a casing patch will be set across the leaking cementer while tubing is out of the well to prevent worsening of the IAxOA comms over time or if well requires gas lift in future. Notes Regarding Wellbore Condition x 10/1/21: Passing CMIT-TxIA to against CIBP set at 11236’ MD to 2500 psi x 9/4/21: OA Integrity test to 1200 psi (No leaks observed) x 8/12/21: Passing PPOT-T and PPOT-IC x 6/7/18: Passing CMIT-TxIA to against CIBP set at 11236’ MD to 2500 psi. MIT-OA failed to 1000 psi. Objective: Pull the existing 7’’ L80 tubing out of the well. Patch leaking 9-5/8” cementer. Replace tubing with 4.5’’ tubing, GLM’s and Stacker packer completion. Achieve a passing MIT-IA & MIT-T. Pre RWO work: DHD * Completed 10/1/21 1. Energize IC seals 2. OA Integrity test 3. Cycle LDS’s 4. Purge and bleed both control lines 5. CMIT-TXIA to 2750 psi Test pressure and leak rate to AOGCC. email: melvin.rixse@alaska.gov -00 DLB Rev # 2 1/25/22 RWO Q-06A PTD:198-090 FB * Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. 6. Circulate out well 1 -3 days prior to rig arrival with 755 (1.2 *Total volume) a. Tubing Volume to Cut is .0383 bbls/ft*9842’=377 bbls b. Annular volume to Cut is .0256 bbls/ft* 9842’=252 bbls c. Total volume to Cut is 629 bbls d. Rig up to neighboring producer FL or take returns to tanks. 7. Pump the following down the IA while taking returns up the TBG at max rate but not to exceed 2000 psi. e. 55 bbls hot (mixed in 160F) FW w/ 2% Baraklean f. 700 bbls of 8.4 ppg 1 percent KCL or equivalent with safe lube. (This is to help the rig pull tubing as we are close to having to swap from 6 to 8 wires) 8. If needed Freeze Protect well. Pump 141 bbls of diesel down the IA while taking returns up the TBG. 9. Rig up jumper from IA to tubing to allow freeze protect to swap. Wellhead/DHD 1. Bleed WHP’s to 0 2. Set and test TWC 3. Nipple Down Tree and tubing head adapter. Inspect lift threads. 4. NU BOPE configured top down, Annular, 7’’ Fixed rams, Blinds and integral flow cross. Workover Procedure: 1) MIRU Nordic 3 workover rig and ancillary equipment. 2) Bleed TBG/IA pressures to ~0 psi. Kill well w/ 8.4 ppg 1% KCL or equivalent as needed. 3) Verify ~0 psi on the annulus and tubing pressure. 4) Test BOPE to 250psi Low/ 3000psi High, annular to 250psi Low/ 2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per Nordic 3 BOP Test Procedure. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test pipe rams on 7’’ test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 5) Pull TWC OR CTS. a. Utilize lubricator for BPV removal if potential for trapped pressure exists. 6) Rig up spooler for 2 control lines 7) MU 7” landing joint or spear and BOLDS. 8) Attempt to pull tubing a. 9842’ of 7’’ 26# tubing = 255.9 klbs (dry) / 222.6 klbs(buoyed by average of 8.4 ppg fluid) b. Do not exceed 80 percent of 7” tubing tensile rating 409 klbs (Yield at 100% 511 klbs) c. Tubing will be scrapped no thread protectors needed. 9) LD Tubing hanger. 10) RU and continue to pull 7” tubing from cut. a. 7” displacement is ~.009bbl/ft b. Tubing will have 2 control lines down to 2026’ MD. c. Count every control line band and inspect. Note any missing pieces. d. Ensure necessary tools are on hand for control line clamps: Rev # 2 1/25/22 RWO Q-06A PTD:198-090 11) With all 7’’ tubing OOH. Swap to 2-7/8” X 5-1/2” VBRs and test with 4” and 4.5” test joint. 12) Perform casing cleanout/fishing runs with 4” workstring or slickline as needed ifcontrol lines and clamps not recovered. 13) Inspect tubing cut of 7’’ Tubing and ensure clean cut that should not sever wire line wire. If not RIH and dress off tubing stub. 14) Rig up SL RIH and drift and run Wire Line scoop guide on top pf cut at 9842’MD. 15) SL Drift deep as possible with 4.5” DMY whipstock to ensure we can enter new scoop guide without issues. 16) If SL drifts clean move to next step. If not pull scoop guide and RIH with full gauge flat bottom mill or concave mill and perform clean out run. 17) MU 9-5/8” Casing packer with polish bore and tubing tail assembly on 4” workstring. a. Baker-Loc all connections below the packer 18) RIH and set 9-5/8” casing packer at ~9722’ with tubing tail at ~9780’ MD. 19) Pressure up on backside against packer to 2000 psi and confirm holding 20) POOH with workstring 21) RU Eline, RIH and log CCL/GR log across 9-5/8” FOC at 2038’ a. Depth shift to casing tally dated 1-29-79. This will be GR tie-in log for 9-5/8” casing patch run. 22) PU 9-5/8” casing patch and RIH to straddle FO cementer at 2038-2042’ MD a. Carefully strap patch, patch running tools and all workstring jts. b. Install short joint ~30’ above patch running tools for GR/CCL tie in. c. Correlate depth to original Nabors 18E KB of 28.6’ above GL 23) RIH with EL GR/CCL, log up from running tools across short joint a. Obtain corrected depth of short joint and patch with respect to previous GR-Tie-In log. b. Adjust casing patch depth based on logging results to ensure FOC cementer straddled. 24) Set 9-5/8” casing patch per MFG procedure. 25) Run the 4-½”, 12.6#/ft, L-80 tubing per schematic and proposed completion running order. a. 9842’ of 4-½”12.6# tubing = 124 klbs (dry) / 108 klbs(buoyed by average of 8.4 ppg fluid) 26) Pump ~220 bbls of seawater or KCL with Corrosion inhibitor down the IA while taking returns up the TBG. 27) Pump an additional 300 bbls of 1% KCL to displace inhibitor between GLM#3 and the packer while taking returns up the TBG. 28) Sting into seal assembly at ~9722’ MD a. RILDS. Lay down landing joint. b. Note PU (Pick Up) and SO (Slack Off) weights on tally. 29) Pressure up and test the tubing to 2750psi for MIT-T with 1000 psi on the IA. Bleed off the tubing to 1000psi. Test the IA to 2750psi for MIT-IA. Bleed off the tubing and observe DCK shear. Confirm circulation in both directions thru the sheared valve. Record and notate all pressure tests (30 minutes) on chart. 30) Freeze Protect well with diesel. Pump ~150 bbls down the IA while taking returns up the TBG. 31) Rig up jumper from IA to tubing to allow freeze protect to swap. Rev # 2 1/25/22 RWO Q-06A PTD:198-090 32) Set TWC. 33) RD Nordic 3 Rig 34) ND BOPE 35) NU tree and tubing head adapter. 36) Test both tree and tubing hanger void to 500psi low/5,000psi high. 37) Pull TWC. Post rig Slickline 38) MIRU SL unit and PT 39) Pull Shear Valve 40) Set gas lift design per gas lift engineer 41) RDMO. Coil 42) MIRU CTU and PT 43) MU burn shoe, venturi and motor a. Venturi burn shoe will allow for potential recovery of upper CIBP plug/pieces 44) RIH and mill CIBP at 11236’ MD a. Pending amount of plug recovered, at WSL discretion to do additional venturi run(s) to remove futher debris from above lower CIBP. 45) MU junk mill and motor 46) RIH and mill CIBP at 11800’ MD and push to bottom 47) Freeze protect well or POP 48) RDMO and handover to production Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Sundry Change Form Rev # 2 1/25/22 RWO Q-06A PTD:198-090 As-built Schematic Rev # 2 1/25/22 RWO Q-06A PTD:198-090 Proposed Schematic Nordic 3 BOP Schematic Rev # 2 1/25/22 RWO Q-06A PTD:198-090 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: January 31, 2023Subject: Changes to Approved Sundry Procedure for Well Q-06ASundry #: 322-490 & TBDAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Hilcorp North Slope, LLC Date: 08/19/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU Q-06A -PTD 198-090 -API 50-029-20346-01-00 Definitive Directional Survey (Gyro + MWD Composited) Gyrodata Survey 08/23/2016 Sperry MWD Survey 05/12/1998 Main Folder Contents: Please include current contact information if different from above. PTD:198-090 T36908 Kayla Junke Digitally signed by Kayla Junke Date: 2022.08.19 15:31:58 -08'00' By Samantha Carlisle at 12:55 pm, Aug 16, 2022 '65 6)'0*5$8* 6)' %23(WHVWWRSVL$QQXODUWRSVL GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.08.19 08:24:23 -08'00' RBDMS JSB 082522 ZĞǀηϭϴͬϱͬϮϮ ZtK YͲϬϲ Wd͗ϭϵϴͲϬϵϬ tĞůůEĂŵĞ͗YͲϬϲW/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϬϯϰϲͲϬϭ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ŚƵƚͲ/Ŷ ZŝŐ͗dŚƵŶĚĞƌďŝƌĚηϭ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϴͬϮϯͬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϲĂǇƐ ZĞŐ͘ƉƉƌŽǀĂůZĞƋ͛ƐƚĚ͍ϭϬͲϰϬϯ͕ϰϬϰ ĂƚĞZĞŐ͘ƉƉƌŽǀĂůZĞĐ͛ǀĚ͗Eͬ ZĞŐƵůĂƚŽƌǇ ŽŶƚĂĐƚ͗ďďŝĞĂƌŬĞƌ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϴͲϬϵϬ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗tǇĂƚƚZŝǀĂƌĚ ϵϬϳͲϳϳϳͲϴϱϰϳ;ŽͿ ϱϬϵͲϲϳϬͲϴϬϬϭ;ĐͿ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ƌŽĚŝĞtĂŐĞƐ ϳϭϯͲϯϴϬͲϵϴϯϲ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯϭϳϵ ƉƐŝΛϴϴϬϬ͛dsϳ͘ϯ WW';нϬ͘ϯ^&Ϳͮ^,WϮͬϮϳͬϭϮ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗ϮϮϵϵƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ^/t,W͗Ϭ ƉƐŝ ;dĂŬĞŶŽŶϯͬϮϯͬϮϬtĞůů^ĞĐƵƌĞĚddWͿ DŝŶ/͗ϯ͘ϴϭϯ͟/Λϵ͕ϴϵϲ͛D DĂǆŶŐůĞ͗ϵϰĞŐΛϭϮ͕ϯϭϭ͛D͛ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ YͲϬϲǁĂƐĚƌŝůůĞĚŝŶϭϵϵϴ͘/ƚƉƌŽĚƵĐĞĚĨƵůůƚŝŵĞƵŶƚŝůϮϬϬϯǁŚĞŶŝƚƐƚĂƌƚĞĚĐǇĐůŝŶŐĂŐĂŝŶƐƚD'KZ͘/ŶϮϬϬϲ͕ ƚŚĞ 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ůĞĞĚd'ͬ/ƉƌĞƐƐƵƌĞƐƚŽΕϬƉƐŝ͘ <ŝůůǁĞůůǁͬϴ͘ϰƉƉŐϭй<>ŽƌĞƋƵŝǀĂůĞŶƚĂƐŶĞĞĚĞĚ͘ ϯͿ sĞƌŝĨǇΕϬƉƐŝŽŶƚŚĞĂŶŶƵůƵƐĂŶĚƚƵďŝŶŐƉƌĞƐƐƵƌĞ͘ ϰͿ dĞƐƚKWƚŽϮϱϬƉƐŝ>Žǁͬ ϯϬϬϬƉƐŝ,ŝŐŚ͕ĂŶŶƵůĂƌƚŽϮϱϬƉƐŝ>Žǁͬ ϯ͕ϬϬϬƉƐŝ,ŝŐŚ;ŚŽůĚĞĂĐŚƌĂŵͬǀĂůǀĞĂŶĚ ƚĞƐƚĨŽƌϱͲŵŝŶͿ͘ZĞĐŽƌĚĂĐĐƵŵƵůĂƚŽƌƉƌĞͲĐŚĂƌŐĞƉƌĞƐƐƵƌĞƐĂŶĚĐŚĂƌƚƚĞƐƚƐ͘ Ă͘ WĞƌĨŽƌŵdĞƐƚƉĞƌ dŚƵŶĚĞƌŝƌĚ ηϭ KWdĞƐƚWƌŽĐĞĚƵƌĞ͘ ď͘ EŽƚŝĨǇK'ϮϰŚƌƐŝŶĂĚǀĂŶĐĞŽĨKWƚĞƐƚ͘ Đ͘ ŽŶĨŝƌŵƚĞƐƚƉƌĞƐƐƵƌĞƐƉĞƌƚŚĞ^ƵŶĚƌǇŽŶĚŝƚŝŽŶƐŽĨĂƉƉƌŽǀĂů͘ Ě͘ dĞƐƚ ƉŝƉĞ ƌĂŵƐŽŶ ϳ͛͛ ƚĞƐƚũŽŝŶƚ͘ Ğ͘ ^ƵďŵŝƚƚŽK'ĐŽŵƉůĞƚĞĚϭϬͲϰϮϰĨŽƌŵǁŝƚŚŝŶϱĚĂǇƐŽĨKWƚĞƐƚ͘ ϱͿ WƵůů dtKZd^͘ Ă͘ hƚŝůŝǌĞůƵďƌŝĐĂƚŽƌĨŽƌWsƌĞŵŽǀĂůŝĨƉŽƚĞŶƚŝĂůĨŽƌƚƌĂƉƉĞĚƉƌĞƐƐƵƌĞĞǆŝƐƚƐ͘ ϲͿ ZŝŐƵƉ ƐƉŽŽůĞƌĨŽƌϮĐŽŶƚƌŽůůŝŶĞƐ ϳͿ Dh ϳ͟ůĂŶĚŝŶŐũŽŝŶƚ ŽƌƐƉĞĂƌ ĂŶĚK>^͘ ϴͿ ƚƚĞŵƉƚƚŽƉƵůů ƚƵďŝŶŐ Ă͘ ϵϴϰϮ͛ŽĨ ϳ͛͛ ϮϲηƚƵďŝŶŐс Ϯϱϱ͘ϵ ŬůďƐ;ĚƌǇͿͬ ϮϮϮ͘ϲ ŬůďƐ;ďƵŽǇĞĚďǇĂǀĞƌĂŐĞŽĨϴ͘ϰ ƉƉŐĨůƵŝĚͿ ď͘ ŽŶŽƚĞǆĐĞĞĚϴϬƉĞƌĐĞŶƚŽĨ ϳ͟ƚƵďŝŶŐƚĞŶƐŝůĞ ƌĂƚŝŶŐ ϰϬϵ ŬůďƐ ;zŝĞůĚĂƚϭϬϬй ϱϭϭ ŬůďƐͿ Đ͘ dƵďŝŶŐǁŝůůďĞƐĐƌĂƉƉĞĚŶŽƚŚƌĞĂĚƉƌŽƚĞĐƚŽƌƐŶĞĞĚĞĚ͘ ϵͿ >dƵďŝŶŐŚĂŶŐĞƌ͘ ϭϬͿ Zh ĂŶĚ ĐŽŶƚŝŶƵĞƚŽƉƵůů ϳ͟ƚƵďŝŶŐ ĨƌŽŵ ĐƵƚ͘ Ă͘ ϳ͟ĚŝƐƉůĂĐĞŵĞŶƚŝƐΕ͘ϬϬϵďďůͬĨƚ ď͘ dƵďŝŶŐǁŝůůŚĂǀĞϮĐŽŶƚƌŽůůŝŶĞƐĚŽǁŶƚŽϮϬϮϲ͛D͘ ZĞǀηϭϴͬϱͬϮϮ ZtK YͲϬϲ Wd͗ϭϵϴͲϬϵϬ Đ͘ ŽƵŶƚĞǀĞƌǇĐŽŶƚƌŽůůŝŶĞďĂŶĚĂŶĚŝŶƐƉĞĐƚ͘EŽƚĞĂŶǇŵŝƐƐŝŶŐƉŝĞĐĞƐ͘ Ě͘ ŶƐƵƌĞŶĞĐĞƐƐĂƌǇƚŽŽůƐĂƌĞŽŶŚĂŶĚĨŽƌĐŽŶƚƌŽůůŝŶĞĐůĂŵƉƐ͗ ϭϭͿ tŝƚŚĂůůϳ͛͛ƚƵďŝŶŐKK,͘ ^ǁĂƉƚŽϮͲϳͬϴ͟yϱ͟ sZƐĂŶĚƚĞƐƚǁŝƚŚ ϮͲϳͬϴ͟ĂŶĚ ϰ͘ϱ͟ƚĞƐƚũŽŝŶƚ͘ ϭϮͿ WĞƌĨŽƌŵ ĐĂƐŝŶŐĐůĞĂŶŽƵƚͬĨŝƐŚŝŶŐ ƌƵŶƐǁŝƚŚϮͲϳͬϴ͟ǁŽƌŬƐƚƌŝŶŐ ŽƌƐůŝĐŬůŝŶĞ ĂƐŶĞĞĚĞĚŝĨ ĐŽŶƚƌŽůůŝŶĞƐĂŶĚ ĐůĂŵƉƐ ŶŽƚƌĞĐŽǀĞƌĞĚ͘ ϭϯͿ /ŶƐƉĞĐƚƚƵďŝŶŐĐƵƚŽĨ ϳ͛͛ dƵďŝŶŐĂŶĚĞŶƐƵƌĞ ĐůĞĂŶĐƵƚƚŚĂƚƐŚŽƵůĚŶŽƚƐĞǀĞƌǁŝƌĞ ůŝŶĞ ǁŝƌĞ͘/ĨŶŽƚZ/,ĂŶĚ ĚƌĞƐƐŽĨĨƚƵďŝŶŐƐƚƵď͘ ϭϰͿ ZŝŐƵƉ^>Z/,ĂŶĚĚƌŝĨƚ ĂŶĚƌƵŶtŝƌĞ>ŝŶĞƐĐŽŽƉŐƵŝĚĞŽŶƚŽƉƉ ĨĐƵƚĂƚϵϴϰϮ͛D͘ ϭϱͿ ^>ƌŝĨƚĚĞĞƉĂƐƉŽƐƐŝďůĞǁŝƚŚϰ͘ϱ͟DzǁŚŝƉƐƚŽĐŬƚŽĞŶƐƵƌĞǁĞĐĂŶĞŶƚĞƌŶĞǁƐĐŽŽƉŐƵŝĚĞǁŝƚŚŽƵƚ ŝƐƐƵĞƐ͘ ϭϲͿ /Ĩ^>ĚƌŝĨƚƐĐůĞĂŶŵŽǀĞƚŽŶĞǆƚƐƚĞƉ͘/ĨŶŽƚ ƉƵůůƐĐŽŽƉŐƵŝĚĞ ĂŶĚ Z/,ǁŝƚŚĨƵůůŐĂƵŐĞĨůĂƚ ďŽƚƚŽŵŵŝůůŽƌ ĐŽŶĐĂǀĞŵŝůůĂŶĚƉĞƌĨŽƌŵĐůĞĂŶŽƵƚƌƵŶ͘ ϭϳͿ Dh ϵͲϱͬϴ͟ĂƐŝŶŐƉĂĐŬĞƌǁŝƚŚƉŽůŝƐŚďŽƌĞĂŶĚƚƵďŝŶŐƚĂŝůĂƐƐĞŵďůǇŽŶϮͲϳͬϴ͟ǁŽƌŬƐƚƌŝŶŐ͘ Ă͘ ĂŬĞƌͲ>ŽĐĂůůĐŽŶŶĞĐƚŝŽŶƐďĞůŽǁƚŚĞƉĂĐŬĞƌ ϭϴͿ Z/,ĂŶĚƐĞƚ ϵͲϱͬϴ͟ ĐĂƐŝŶŐ ƉĂĐŬĞƌ ĂƚΕϵϳϮϮ͛ ǁŝƚŚƚƵďŝŶŐƚĂŝůĂƚΕϵϳϴϬ͛D͘ ϭϵͿ WƌĞƐƐƵƌĞƵƉŽŶďĂĐŬƐŝĚĞĂŐĂŝŶƐƚƉĂĐŬĞƌƚŽϮϬϬϬƉƐŝĂŶĚĐŽŶĨŝƌŵŚŽůĚŝŶŐ ϮϬͿ WKK,ǁŝƚŚǁŽƌŬƐƚƌŝŶŐ ϮϭͿ ZhůŝŶĞ͕Z/,ĂŶĚůŽŐ>ͬ'ZůŽŐĂĐƌŽƐƐ ϵͲϱͬϴ͟&KĂƚϮϬϯϴ͛ Ă͘ ĞƉƚŚƐŚŝĨƚƚŽĐĂƐŝŶŐƚĂůůǇĚĂƚĞĚϭͲϮϵͲϳϵ͘dŚŝƐǁŝůůďĞ'ZƚŝĞͲŝŶůŽŐĨŽƌϵͲϱͬϴ͟ĐĂƐŝŶŐƉĂƚĐŚƌƵŶ͘ ϮϮͿ WhϵͲϱͬϴ͟ĐĂƐŝŶŐƉĂƚĐŚĂŶĚ Z/,ƚŽƐƚƌĂĚĚůĞ&KĐĞŵĞŶƚĞƌ ĂƚϮϬϯϴͲϮϬϰϮ͛D Ă͘ ĂƌĞĨƵůůǇƐƚƌĂƉƉĂƚĐŚ͕ƉĂƚĐŚƌƵŶŶŝŶŐƚŽŽůƐĂŶĚĂůůǁŽƌŬƐƚƌŝŶŐ ũƚƐ͘ ď͘ /ŶƐƚĂůůƐŚŽƌƚũŽŝŶƚΕϯϬ͛ĂďŽǀĞƉĂƚĐŚƌƵŶŶŝŶŐƚŽŽůƐĨŽƌ'Zͬ>ƚŝĞŝŶ͘ Đ͘ ŽƌƌĞůĂƚĞĚĞƉƚŚƚŽŽƌŝŐŝŶĂů EĂďŽƌƐϭϴ < ŽĨϮϴ͘ϲ͛ĂďŽǀĞ'> ϮϯͿ Z/,ǁŝƚŚ >'Zͬ>͕ůŽŐƵƉĨƌŽŵ ƌƵŶŶŝŶŐƚŽŽůƐĂĐƌŽƐƐƐŚŽƌƚũŽŝŶƚ Ă͘ KďƚĂŝŶĐŽƌƌĞĐƚĞĚĚĞƉƚŚŽĨƐŚŽƌƚũŽŝŶƚ ĂŶĚ ƉĂƚĐŚǁŝƚŚƌĞƐƉĞĐƚƚŽ ƉƌĞǀŝŽƵƐ'ZͲdŝĞͲ/ŶůŽŐ͘ ď͘ ĚũƵƐƚĐĂƐŝŶŐƉĂƚĐŚĚĞƉƚŚďĂƐĞĚŽŶůŽŐŐŝŶŐƌĞƐƵůƚƐƚŽĞŶƐƵƌĞ&KĐĞŵĞŶƚĞƌƐƚƌĂĚĚůĞĚ͘ ϮϰͿ ^ĞƚϵͲϱͬϴ͟ĐĂƐŝŶŐƉĂƚĐŚƉĞƌD&'ƉƌŽĐĞĚƵƌĞ͘ ϮϱͿ ZƵŶƚŚĞ ϰͲЪ͕͟ϭϮ͘ϲηͬĨƚ͕ >ͲϴϬ ƚƵďŝŶŐ ƉĞƌ ƐĐŚĞŵĂƚŝĐĂŶĚƉƌŽƉŽƐĞĚĐŽŵƉůĞƚŝŽŶƌƵŶŶŝŶŐŽƌĚĞƌ͘ Ă͘ ϵϴϰϮ͛ŽĨϰ͘ϱ͛͛ϭϮ͘ϲηƚƵďŝŶŐс ϭϮϰ ŬůďƐ;ĚƌǇͿͬ ϭϬϴ ŬůďƐ;ďƵŽǇĞĚďǇĂǀĞƌĂŐĞŽĨϴ͘ϰ ƉƉŐĨůƵŝĚͿ ϮϲͿ WƵŵƉ ΕϮϮϬ ďďůƐŽĨƐĞĂǁĂƚĞƌŽƌ <>ǁŝƚŚŽƌƌŽƐŝŽŶŝŶŚŝďŝƚŽƌĚŽǁŶƚŚĞ/ ǁŚŝůĞ ƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞ d'͘ ϮϳͿ WƵŵƉ ĂŶĂĚĚŝƚŝŽŶĂů ϯϬϬ ďďůƐŽĨ ϭй <>ƚŽĚŝƐƉůĂĐĞ ŝŶŚŝďŝƚŽƌďĞƚǁĞĞŶ '>Dηϯ ĂŶĚƚŚĞƉĂĐŬĞƌ ǁŚŝůĞ ƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞd'͘ ϮϴͿ ^ƚŝŶŐŝŶƚŽƐĞĂůĂƐƐĞŵďůǇĂƚΕϵϳϮϮ͛D Ă͘ Z/>^͘>ĂǇĚŽǁŶůĂŶĚŝŶŐũŽŝŶƚ͘ ď͘ EŽƚĞWh;WŝĐŬhƉͿĂŶĚ^K;^ůĂĐŬKĨĨͿǁĞŝŐŚƚƐŽŶƚĂůůǇ͘ ϮϵͿ WƌĞƐƐƵƌĞƵƉĂŶĚƚĞƐƚƚŚĞƚƵďŝŶŐƚŽ ϮϳϱϬƉƐŝĨŽƌD/dͲd ǁŝƚŚϭϬϬϬƉƐŝŽŶƚŚĞ/͘ůĞĞĚ ŽĨĨƚŚĞƚƵďŝŶŐƚŽ ϭϬϬϬƉƐŝ͘dĞƐƚƚŚĞ/ƚŽ ϮϳϱϬƉƐŝĨŽƌD/dͲ/͘ůĞĞĚŽĨĨƚŚĞƚƵďŝ ŶŐ ĂŶĚŽďƐĞƌǀĞ<ƐŚĞĂƌ͘ŽŶĨŝƌŵ ZĞǀηϭϴͬϱͬϮϮ ZtK YͲϬϲ Wd͗ϭϵϴͲϬϵϬ ĐŝƌĐƵůĂƚŝŽŶŝŶďŽƚŚĚŝƌĞĐƚŝŽŶƐƚŚƌƵƚŚĞƐŚĞĂƌĞĚǀĂůǀĞ͘ZĞĐŽƌĚĂŶĚŶŽƚĂƚĞĂůůƉƌĞƐƐƵƌĞƚĞƐƚƐ;ϯϬŵŝŶƵƚĞƐͿ ŽŶĐŚĂƌƚ͘ ϯϬͿ &ƌĞĞǌĞWƌŽƚĞĐƚǁĞůů ǁŝƚŚĚŝĞƐĞů͘WƵŵƉ ΕϭϱϬ ďďůƐ ĚŽǁŶƚŚĞ/ǁŚŝůĞƚĂŬŝŶŐƌĞƚƵƌŶƐƵƉƚŚĞd'͘ ϯϭͿ ZŝŐƵƉũƵŵƉĞƌĨƌŽŵ/ƚŽƚƵďŝŶŐƚŽĂůůŽǁĨƌĞĞǌĞƉƌŽƚĞĐƚƚŽƐǁĂƉ͘ ϯϮͿ ^Ğƚ dt͘ ϯϯͿ Z dŚƵŶĚĞƌďŝƌĚ ηϭtKZŝŐ ϯϰͿ EKW ϯϱͿ EhƚƌĞĞĂŶĚƚƵďŝŶŐŚĞĂĚĂĚĂƉƚĞƌ͘ ϯϲͿ dĞƐƚďŽƚŚƚƌĞĞĂŶĚƚƵďŝŶŐŚĂŶŐĞƌǀŽŝĚƚŽϱϬϬƉƐŝůŽǁͬϱ͕ϬϬϬƉƐŝŚŝŐŚ͘ ϯϳͿ WƵůůdt͘ WŽƐƚƌŝŐ ^ůŝĐŬůŝŶĞ ϯϴͿ D/Zh^>ƵŶŝƚĂŶĚWd ϯϵͿ WƵůů^ŚĞĂƌsĂůǀĞ ϰϬͿ ^ĞƚŐĂƐůŝĨƚĚĞƐŝŐŶƉĞƌŐĂƐůŝĨƚĞŶŐŝŶĞĞƌ ϰϭͿ ZDK͘ Žŝů ϰϮͿ D/Zh dhĂŶĚWd ϰϯͿ DhďƵƌŶƐŚŽĞ͕ǀĞŶƚƵƌŝĂŶĚŵŽƚŽƌ Ă͘ sĞŶƚƵƌŝďƵƌŶ ƐŚŽĞǁŝůůĂůůŽǁĨŽƌƉŽƚĞŶƚŝĂůƌĞĐŽǀĞƌǇŽĨƵƉƉĞƌ/WƉůƵŐͬƉŝĞĐĞƐ ϰϰͿ Z/,ĂŶĚŵŝůů /WĂƚϭϭϮϯϲ͛D Ă͘ WĞŶĚŝŶŐĂŵŽƵŶƚŽĨƉůƵŐƌĞĐŽǀĞƌĞĚ͕Ăƚt^>ĚŝƐĐƌĞƚŝŽŶƚŽĚŽĂĚĚŝƚŝŽŶĂůǀĞŶƚƵƌŝƌƵŶ;ƐͿƚŽƌĞŵŽǀĞ ĨƵƚŚĞƌĚĞďƌŝƐĨƌŽŵĂďŽǀĞůŽǁĞƌ/W͘ ϰϱͿ DhũƵŶŬŵŝůůĂŶĚŵŽƚŽƌ ϰϲͿ Z/,ĂŶĚŵŝůů/WĂƚϭϭϴϬϬ͛D ĂŶĚƉƵƐŚƚŽďŽƚƚŽŵ ϰϳͿ &ƌĞĞǌĞƉƌŽƚĞĐƚǁĞůůŽƌWKW ϰϴͿ ZDKĂŶĚŚĂŶĚŽǀĞƌƚŽƉƌŽĚƵĐƚŝŽŶ ƚƚĂĐŚŵĞŶƚƐ͗ ϭ͘ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ Ϯ͘ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ ϯ͘ KW^ĐŚĞŵĂƚŝĐ ϰ͘ ^ƵŶĚƌǇŚĂŶŐĞ&Žƌŵ ZĞǀηϭϴͬϱͬϮϮ ZtK YͲϬϲ Wd͗ϭϵϴͲϬϵϬ ƐͲďƵŝůƚ^ĐŚĞŵĂƚŝĐ ZĞǀηϭϴͬϱͬϮϮ ZtK YͲϬϲ Wd͗ϭϵϴͲϬϵϬ WƌŽƉŽƐĞĚ ^ĐŚĞŵĂƚŝĐ ZĞǀηϭϴͬϱͬϮϮ ZtK YͲϬϲ Wd͗ϭϵϴͲϬϵϬ KW^ĐŚĞŵĂƚŝĐ 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. From:AOGCC Permitting (CED sponsored) To:AOGCC Records (CED sponsored) Subject:FW: Cancellation: PBU Q-06A (PTD #198-090) 10-403 Sundry Request #321-401 Date:Monday, August 8, 2022 11:27:03 AM Attachments:Appr Sundry_321-401_081821 Q-06A RWO.pdf From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Friday, August 5, 2022 4:10 PM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Wyatt Rivard <wrivard@hilcorp.com>; PB Wells Tech Aides <PBWellsTechAides@hilcorp.com> Subject: Cancellation: PBU Q-06A (PTD #198-090) 10-403 Sundry Request #321-401 Hello, Please cancel 10-403 Sundry Request #321-401 (copy attached). This sundry is nearing expiration and no reportable work was performed. Any future work on the well will be the subject of a new 10- 403 Request. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com Office: (907)564-4915 Cell: (907)351-2459 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. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field/Pool(s): Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name: Authorized Title: Authorized Signature: Date: Contact Name: Contact Email: Contact Phone: COMMISSION USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE COMMISSIONCOMMISSIONER Q-06A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-090 50-029-20346-01-00 N/A ADL 0028281, 0028284 12521 Conductor Surface Intermediate Production Liner 9016 80 2656 10486 1087 2622 11236 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8912 31 - 111 30 - 2686 29 - 10515 10004 - 11091 9896 - 12518 2299 31 - 111 30 - 2674 29 - 8365 8001 - 8815 7924 - 9016 None 2670 4760 7020 7500 11236, 11800 5380 6870 8160 8430 11655 - 12240 7"L-80 27 - 100199020 - 9030 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Stan Golis Sr. Area Operations Manager Brian Glasheen Brian.Glasheen@hilcorp.com 907.564.5277 PRUDHOE BAY, PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm.Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:38 am, Aug 16, 2021 321-401 PBU Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.13 15:55:18 -08'00' Stan Golis (880) 16AUG2021 X DSR-8/16/21 10-404 BOPE test to 3000 psi. Annular to 2500 psi. DLB 08/17/2021 dts 8/17/2021 JLC 8/18/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.18 09:03:32 -08'00' RBDMS HEW 8/19/2021 RWO – Q-06A PTD:198-090 Well Name:Q-06A API Number:50-029-20346-01 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:9/23/21 Estimated Duration:6 Days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:N/A Regulatory Contact:Abbie Barker Permit to Drill Number:198-090 First Call Engineer:Brian Glasheen 907-545-1144 Second Call Engineer:Brodie Wages 713-380-9836 AFE Number:215-02516 Current Bottom Hole Pressure:3179 psi @ 8800’ TVD 7.3 PPGE (+0.3 SF)| SBHP 2/27/12 Max. Anticipated Surface Pressure:2299 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:0 psi (Taken on 3/23/20 Well Secured TTP) Min ID:3.813” ID @ 9,896’ MD Max Angle:94 Deg @ 12,311’ MD’ Brief Well Summary: Q-06A was drilled in 1998. It produced full time until 2003 when it started cycling against MGOR. In 2006, the well was SI due to the transit line leak and did not return to production until 2008. The GOR had healed over that shut-in period so the well again produced near full time until 2011 when it began cycling. The original perforations were open until 2015 when a bridge plug was set and perfs were added uphole in Z2A. Those perfs became marginal in 2016 and the well was screened for sidetrack in late 2017. A CIBP was set to isolate the Ivishak for screening, the tubing patches were pulled, and the tubing was cut in preparation for a RWO + coil sidetrack. In 2018, the BP rig economics changed and the Q-06B sidetrack was dropped off the schedule and the well has been SI with compromised tubing ever since. Also, in 2018 a CMIT-TXIA passed to 2593 psi indicating production casing integrity. There is future potential for Zone 4 and Sag rich gas add perfs that will not be pursued at this time. Objective: Pull the existing 7’’ L80 tubing out of the well. Replace tubing with 4.5’’ tubing, GLM’s and Stacker packer completion. Achieve a passing MIT-IA & MIT-T. Variance Request:20AAC25.412(b) Packer will be set greater than 200ft measured depth from open perfs. Tubing packer is at 9762’MD which is 1893’ MD above the uppermost open perforations at 11655’. Estimated top of cement in 9-5/8” X 13-3/8” Annulus is 7139’ MD assuming 30 percent washout. Top of the kingak is 8657’MD. Pre RWO work: DHD 1. OA Integrity test 2. Cycle LDS’s 3. CMIT-TXIA to 2750 psi FB 1. Circulate out well with 755 (1.2 *Total volume) bbls of 8.4 ppg 1 percent KCL or Seawater down the IA while taking returns up the TBG at max rate but not to exceed 2000 psi. a. Tubing Volume to Cut is .0383 bbls/ft*9842’=377 bbls b. Annular volume to Cut is .0256 bbls/ft* 9842’=252 bbls c. Total volume to Cut is 629 bbls Tubing is already cut at 9,842' MD. This well is a 'development' well. This variance request is not required. -00 DLB RWO – Q-06A PTD:198-090 d. Rig up to neighboring producer FL or take returns to tanks. 2. If needed Freeze Protect well. Pump 141 bbls of diesel down the IA while taking returns up the TBG. 3.Rig up jumper from IA to tubing to allow freeze protect to swap. DHD 1. Bleed WHP’s to 0 Valve Shop 2. Set and test TWC 3. Nipple Down Tree and tubing head adapter. Inspect lift threads. 4. NU BOPE configured top down, Annular, 7’’ Fixed rams, Blinds and integral flow cross. Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 7’’ fixed rams with 7’’ test joints. Test the Annular preventer with a 4-1/2” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. 4. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~222.6K 5. Pull 7’’ tubing to floor. 6. POOH with 7’’ tubing and laydown 7. Swap 7’’ fixed rams to 2-7/8’ X 5-1/2’’ VBR and test with 4-1/2’’ test joints. 8. SL set wire line scoop guide with 4.5’’ spacer pipe at ~9842’ MD. 9. Run 4.5’’tubing with stacker packers and gas lift mandrels detailed on proposed schematic 10. Land Hanger and reverse in corrosion inhibited 8.4ppg 1%KCl 11. Drop ball and rod and set packer with 3,500psi pump pressure. 12. Perform MIT-T to 2,750 psi and MIT-IA to 2,750 psi for 30 charted minutes. Give the AOGCC 24hrs notice to witness MIT-IA test. Document on State of Alaska form 10-426 13. Shear valve in GLM. 14. Freeze protect to ~2,000ft with diesel 15. Set TWC 16. Rig down Thunderbird #1. Post rig valve shop work: 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC. Post rig: SL 1. Spot Slickline unit and RU. 2. Pressure test lubricator to 300psi low and 2,800psi high. 3. Pull Ball and rod RWO – Q-06A PTD:198-090 4. Pull RHC profile 5. Pull Shear Valve set DMY GLV. 6. RDMO. Coil 1. MIRU 2. Mill both CIBP at 11236 and 11800’ MD 3. Displace well to diesel to allow well to KO naturally 4. RDMO SL (Pending - if well will not KO naturally) 1. Install generic GLV for KO. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing RWO – Q-06A PTD:198-090 Wellbore Schematic RWO – Q-06A PTD:198-090 Proposed Wellbore Schematic RWO – Q-06A PTD:198-090 RWO BOPs Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: August 13, 2021Subject: Changes to Approved Sundry Procedure for Well Q-06ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date OF r„, • • 5 • THE STATE Alaska Oil and Gas �;,,�� Of LAsKA Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba100) JUN ,9'L i Engineering Team Leader—CTD &RWO '� BP Exploration(Alaska), Inc. ib P.O Box 199612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU Q-06A Permit to Drill Number: 198-090 Sundry Number: 318-212 Dear Mr. Egbejimba: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, tjay: Hollis S. French Chair kL DATED this day of June, 2018. RBDNIS2N JUN 13 20W STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION CO ION APPLICATION FOR SUNDRY APPR LS 20 AAC 25.280 SAY 2 1 2018 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 • otpeytionfsfid5vill Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing Il • Change c1r Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Casing Patch 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 198-090 3_ Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development El 6. API Number 50-029-20346-01-00 • 99519-6612 Stratigraphic 0 Service 0 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No B PBU Q-06A . I 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028284&028281 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 12521 . 9016 • 11236 8912 11236.11800 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 31-111 31-111 Surface 2656 13-3/8" 30-2687 30-2676 5380 2670 Intermediate 10486 9-5/8" 29-10515 29-8365 6870 4760 Liner 1092 7" 9999-11091 7998-8815 8160 7020 Liner 2622 4-1/2" 9896-12518 7924-9016 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11655-12240 9020-9030 7"26# L-80 27-10020 Packers and SSSV Type: 7"BOT Packer Packers and SSSV MD(ft)and TVD(ft): 10024/8016 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 12I Service 0 14.Estimated Date for Commencing Operations: June 4,2018 15. Well Status after proposed work: Oil I! WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Browning,Zachary H be deviated from without prior written approval. Contact Email: Zachary.Browningl bp.com Authorized Name: Egbejimba,John Contact Phone: +1 907 564 5220 Authorized Title: Engineering Team Leader-CTD&RWO /... Authorized Signature: /7 Date: �2 /` w t COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 113 z17.... Plug Integrity 0 BOP Test Mechanical Integrity Test 0 Location Clearance 0 Other: 130 rJ1-c5 -1-- 7Lp 3UUO / 17 Post Initial Injection MIT Req'd? Yes 0 No Spacing Exception Required? Yes 0 No 24 Subsequent Form Required: 1 d — 0 APPROVED BYTHE J�ike,Approved by: --- (,,COMMISSIONER COMMISSION Date: v I( V`%L S/31/JT ,' ,)i RBDMS\JUN 131018 ,`s, ORIGINAL /ef� es--.2.,,,,e Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplica.e • To: Alaska Oil &Gas Conservation Commission From: Zach Browning ID RWO/CTD Engineer p Date: May 21, 2018 Re: Q-06A Sundry Approval Well Type: Producer Current Status: The well is currently shut-in, listed as non-operable (TxIA communication). Request: Sundry approval is requested to restore tubing and casing integrity. History and current status: Q-06A was a Zone 2A sidetrack drilled and completed in 1998. Q-06A produced a total of 3.3 MMBO of SLP from 05/98 to 06/15. Q-06A initially produced at a rate as high as 3,000 bopd (with 1%WC & -3,000 scf/stb GOR). The well was SI from 04/12 thru 01/14, due to IAxOA communication. This was fixed with a Seal-Tite ' annular repair job and the repair involved punching the tubing and then patching it. The well was returned to production and the GOR, during a year, climbed to a non-competitive level. In August 2015 a CIBP was set to isolate the original perforations and 60 ft of "end of life" perforations were added close to the heel of the well. These perforations came on poorly with high gas (GOR 90,000+ scf/bbl) and the well was subsequently released for sidetrack. However, recent analysis has shown some discrepancy in the WC, thus GOR may be slightly lower. The plan post RWO is to produce this well as Sag only prior to sidetracking. The well is currently offline, classified as "Non-Operable" due to TxIA communication (patch is pulled). The IA is loaded with heavy fluids (9.8 ppg brine and 9.3 ppg Flo-Seal) and the tubing is fluid packed with 9.4 ppg brine and crude. A CIBP is set above all perforations. The well passed a combo MIT-TxIA to 2701 psi on 3/5/18. Proposed plan: The All American Oilfield 111 Pulling Unit will replace the tubing to restore tubing integrity. Prior to running the tubing, the Seal-Tite will be cleaned out of the 9-5/8" production casing and the historic leak point will be patched with a Halliburton Metalskin patch. MASP=2378 psi. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of both the current and proposed wellbore is attached for reference. Scope of Work: The primary objective of this RWO is to restore tubing integrity with a completion that allows AL capability and will allow for future CTD sidetrack options. The secondary objective is to patch the historical IA x OA leak at the 9-5/8" FOC, which currently has been remediated with Seal-Tite. Pre-Riq Prep Work(Planned Start 6/4/18): 1. W: PPPOT-T, PPPOT-IC. Function LDS. 2. E: Cut Tubing 3. F: CMIT-TxIA 4. V: PPPOT-T, PPPOT-IC. Set TWC and test. Pre-Pulling Unit prep work. 5. 0: Bleed WHP(s) to zero. Remove the well house and flow line. Install wellhead valves as needed. Install dry hole tree. Level the pad as needed for the pulling unit. Proposed RWO Procedure (Planned Start 6/30/18): 1. MIRU. ND tree. NU and test BOPE. --. 2. Pull Tubing. 3. Cleanout/Scraper run. 4. Set 5-1/2" x 9-5/8" Packer with Ratch Latch Receptacle. 5. Set 9-5/8" Casing Patch- MIT Casing. pN` 6. Run new 4-1/2" 13Cr Completion and sting into Ratch Latch Receptacle. MIT-T. MIT-IA. �' 7. Freeze protect. Set TWC. ND BOPE. NU and test tree. RDMO. Post riq Work: 1. V: Tree work as necessary. Install S-Riser. 2. S: Install LGLVs. 3. E: Sag add perfs. Zach Browning CC: Well File RWO/CTD Engineer Joe Lastufka 564-5220 • • Loepp, Victoria T (DOA) From: Leemhuis,Jacob <Jacob.Leemhuis@bp.com> Sent: Tuesday, June 12, 2018 10:09 AM To: Loepp, Victoria T (DOA) Cc: Browning,Zachary H Subject: RE:AAO#111: BOP Stack Victoria, Apologies for not providing the ram configuration with the Sundry. The All American Oilfield 111 rig will have blind rams. The BOP configuration will be as follows: • One Annular Preventer • One Blind Ram-type preventer • Mud Cross with outlets for choke and kill lines • One ram-type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP Policy of a 7 day BOP test. Testing will be 3500 psi high and 250 psi low test for all components. Thanks, Jacob C. Leemhuis From: Loepp,Victoria T(DOA) <victoria.loepp@alaska.gov> Sent:Tuesday,June 12, 2018 9:06 AM To: Browning, Zachary H <Zachary.Browning@bp.com>; Leemhuis,Jacob<Jacob.Leemhuis@bp.com> Subject:AAO#111: BOP Stack Jacob, Zach, Several Sundries have been submitted using this WO rig. Will there be blind shears or blind rams in the BOP stack to meet BPs internal policy? What will be the ram configuration? Please forward a copy of the BOP test procedure. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppalaska.00v CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or c+ic oe > 1 ' TREE= 6 X 7 CNV WELLHEAD= McEVOY . Q_p 6A IDETY NOTES: WELL ANGLE>700 @ 11288'. ACTUATOR= BAKERC OKB.REV= 69.62 ._._. Fill H_.EV= BF.ELEV= 40.59' 2026'l.--- 2026' H7'OTIS SSSV LANDING Nom,D=5.962" KOP= 2399' Max Angle= 94° 12311' 1 2038' 9-5/8"FOC Datum MD-= 11146' Datum TVD= - 8800'SS 2687' H9-5/8"DV PKR Lt 3-3/8"CSG,72#,L-80,D=12.347" —[ 2686' A , Minimum ID = 3.813" @ 9996' 0 ■ 6713'-6714' —TUBING PUNCH(09/05/13) 4-1/2" HES X NIPPLE 9896' 5"BKR C-2 TI63K SLV w/FMC HGR,0=4.438 TOP OF 4-1/2"LNR —j 9896' �� I 9910' 1--{5'X 4-1/2"XO,D=3.938" ■ I 9996' J.-14-112'11M x MP.D 3_813 I TOP OF 7"LNRJ— 10004' I , 10021' �—�T SEAL ASSEMBLY,D= 7"TBG,26#,L-80,.0383 bpf,IO=6.276" H 10026' • �?� 7"MIL LOUT WINDOW(0-06A)11091-11099' ` 9-5/8"CSG,47#,L-80,D=8.681"j—{_ 10515' , A h. 4-1/2" WHIPSTOCK(XX/XX/XX — 11089' 11236' H4-1/2"BKR CEP(11/04/17) 7'LMR,29#,1-80_0371 bpf,D=6.184' H -"11089 (4-VT BRIDGE PLUG H 11100• _ / 11800' H4-1/2-WFT CEP(08114/15) PERFORATION SUMMARY 1r REF LOG. ? 1 ANGLE AT TOP PERF:89'@ 11655' Nate:Refer to Production DB for historical perf data SIZE SPF INTERVAL OFWSOZ SI-DT SQZ 3-3/8" 6 11655- 11715 C 08/14/15 2-3/4" 4 11820- 11960 C 05/14/98 2-314" 4 12020- 12090 C 05/14/98 2-3/4" 4 12150-12240 C 05/14/98 I, PBTD —1 12437' 11401k N\r [4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.953" I-I 12618' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUGHOE BAY UNIT 06/24/79 N18E IMTIAL COMPLETION 08/28/15 ALIMPID SET CBF/ADFERFS(08/14/15) WELL: Q-06A 05/16/98 D-16 SIDETRACK(Q-06A) 11/13/17 JG/JMD SET CBP(11/04/17) FERMI Na:'1980900 10/31/13 RMUMD SET 7"WFD PKR(10/19/13) — 03/07/18 BSE/JM) FULLED PATCH(03/03/18) API No: 50-029-20346-01 11/11/13 STF/PJC SET UPPER FKR(11/4/13) SEC 16,T11 N,R13E 379'FN_&623'FEL 12/04/13 DGB/JMD PERES CORRECTED TO OPEN 04/11/14 OGB/JMD CORRECTED 9-5/8"CSG DEPTH BP Exploration(Alaska) ' TREE= 6 X 7 CtW WELLHEAD= McEVOY PROPOSED Q-O 6A NOTES: WELL ANGLE>700 @ 11288'. ACTUATOR= BAKE C 70KB.ELEV= 69.62' REf H EV= R E V 2J-1 9-5/8"CSG PATCH J BF.ELEV= 40.59' & KOP= 239g 2038' —19-5/8"FOC Max Angle= 94°@ 12311' g I • H42 . 3813" [ +tum MD= 11146' Datum TVD= 8800'SS ,_ 2687' 95/8'DV PKR GAS LFT MANDRELS L_13-3/8"CSG,72#,L-80,D=12.347" — 2686' I---, ' ST MD TVD DEV TYPE VLV LATCH FORT DATE © 2 Minimum ID = 3.813" @ 9996' 1 4-1/2" HES X NIPPLE I I 1 H4-1/2"X MP,D=3.813" Cr 1 -HATCH LATCH RECEV11U1 >< -19-5/8*X 5-1/2"13-CR SEALBORKR,E PD= " 1 7"TBG STUB(,/_/_) H9800" 1...,,,_.................)111 , ' { H4-112'X NP,D=3.813" 4-1/2'LHR, 12.6#,13-CR VAM TOP, - 0152 bpf,D=3.958' r------*** si 9896' -1Rw MR 5'BKR C-2 TK SLV !HC HGR, =4.438 L TOP OF4-1/2" NR — 9896' ----H 9910' -{5'X 4-1/2"XO,D=3.938" I I L 9996' H4-1/2"FES X MP D=3 813' TOP OF 7"LNRiH__10004'__- 1 L_ 1002V -{7"SEAL ASSEMBLY,D.77j L7"TBG,26#,L-80,.0383 bpf,D=6276" H 19026' 7'MLLOUT WINDOW(Q-06A)11091-11099' L9:6/8-CSG,47#,L-80,D=8.68r -1 10616' a 4-1/2" M-PSTOCK(XX/XX/Xx 11089' 11236" --{4-1/2'BKRCBP(11/04/17) 7"LNR 29#,L-80,.0371 bpf,D=6.184' -{ -11089 milr 11800' I4-1/2"WFT CEP(08/14/15) 14-1/2"BFDGEPLUG -I 11100' ` 1 FERFORATION SUMMARY ,� REF LOG. 7 ` ANGLE AT TOP PERP 89°@ 11655' ` Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL OPNISQZ SHOT SQZ ` 3-3/8" 6 11655- 11715 C 08/14/15 2-3/4" 4 11820- 11960 C 05/14/98 2-3/4" 4 12020- 12090 C 05/14/98 2-3/4" 4 12150- 12240 C 05/14/98 PBTD —L1243T 44...Nikiat .-._-...... N. 4-1/2"LNR, 12.6#,L-80,.0152 bpi,0=3.958' -{ 12618' DATE REV BY COMtiENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/24/79 N18E INITIAL COMPLETION WELL. O-06A 05/16/98 D-16 SIDETRACK(Q-06A) pew Pb.'1980900 / / IVO API No 50-029-20346-01 05/02/18 AMC) BIXT PROPOSED SEC 16,T11 N,R13E,379'RA_&623'FEL 05/02/18 ZB/JMD BUST PROPOSED REV 1 05/02/18 JM) BUILT PROPOSED REV 2 BP Exploration(Alaska) • Q • m 0• 0 J Q O rc Q ? ^ rn . o U Z � , .., o a .. Z o .- W W m W IILu O Nr. min _i u' vi v RIM t OJ> O ,— Q I1111 � > ° w Z (.9 Fill gW co ,--,ZZM in Nvo mh- o o°� oEo � QU 7 � Nm N O ww elk 7 N a 00'.* I—I Ce Z CO° a a_ . . -Iujg ❑ E U W ° a . . OF- Zi220 0 a a F-4 Z a O o Q 0 1 Ce M W u M Q 4 zrc w 3WY rc aNZ o. �1 �( N 0 5 u N W a - =poI=i-oa 0 ► o FFW U Z O LL O S - cp r MOW- -. >O F .O _ W a N U 3 0 a— N- Y _ _ N w Y O Z Y O _ :=C."' ..... O K K$i MainP) Mwwwa wrc i xazw*auW io �() lf) ,-awceoawN _ iN......1* C w € o N a a in 3 as N III m N i yl .. 11•19 lig/ Io _ O OHO O r. ...,...4 o 0 0 t— ___ ;:t. € O.1 aiii E — � o 010 0 — cli — = ___ ° II 1 I # IT �p z R '9 � LLJ Cl_ o Oo � ♦ Z 2 V -N 0 J Q J fl ~ (nJ (nW z QQ on CO Z Q..._ �'�.__- i Z_, t+� w O t 0)i o v W W p LO I e— co Lo x M zcezrea z200O o-U�0 <zwOa ZEt wcwE Ou0awzO z?ocr¢U Q I. — CO 0 0 " RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION CO ION REPORT OF SUNDRY WELL OPE NS MAR 2 9 2018 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations y �N❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change A -� / r V-❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 121 Re-enter Susp Well 0 Other: Pull Tubing Patch 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 198-090 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20346-01-00 7. Property Designation(Lease Number): ADL 028284,028281 8. Well Name and Number: PBU Q-06A 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: Total Depth: measured 12521 feet Plugs measured 11236,11800 feet true vertical 9016 feet Junk measured None feet Effective Depth: measured 11236 feet Packer measured None feet true vertical 8912 feet Packer true vertical feet I Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 31-111 31-111 0 0 Surface 2656 13-3/8" 30-2687 30-2676 5380 2670 Intermediate 10486 9-5/8" 29-10515 29-8365 6870 4760 Liner 1094 7" 9999-11093 7998-8816 8160 7020 Liner 2262 4-1/2" 9898-12520 7925-9016 8430 7500 Perforation Depth: Measured depth: 11655-12240 feet True vertical depth: 9020-9030 feet sti ogie Tubing(size,grade,measured and true vertical depth) 7"26#L-80 27-10020 27-8013 Packers and SSSV(type,measured and No Packer true vertical depth) No SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: pR 0 15* RIP '`*.� 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Watr-Bbl Casing Pressure Tubing Pressure Prior to well operation: 483 43405 229 0 1620 Subsequent to operation: No Test Available 420 0 14.Attachments:(required per 20 AAc 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations fff Exploratory ❑ Development a Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 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 Authorized Name: Duong,Lea Contact Name: Duong,Lea Authorized Title: Senior Petroleum Engineer Contact Email: Lea.Duongtbp.com Authorized Signature: 2!Date: " Q/f g' Contact Phone: +1 907 564 4840 Form 10-404 Revised 04/2017 1/77- 4/2 /1 {j Y/sv//rrr Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary March 28, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Pull Tubing Patch for Well PBU Q-06A, PTD #198-090. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Daily Report of Well Operations PBU Q-06A ACTIVITYDATE SUMMARY ***WELL S/I UPON ARRIVAL*** (drlg screen) R/U SWCP 4516 SLICKLINE UNIT 3/2/2018 ***CONT WSR ON 3/3/18*** ***CONT WSR FROM 3/2/18***(drlg screen) PULLED 7"WFD ER UPPER PATCH FROM 6,671' SLM /6,691' MD PULLED 7"WFD ER LOWER ANCHOR FROM 6,691' SLM/6,713' MD DRIFTED TUBING W/35' DUMMY DRIFT(4.99" max od) TO TOP OF LINER @ 9,883' SLM/ 9,896' MD (no issues) 3/3/2018 ***CONT WSR ON 3/4/18*** ***CONT WSR FROM 3/3/18***(drlg screen-maint) DRIFTED W/20'x 3.70" DUMMY WHIPSTOCK TO 11,121'SLM (20*dog leg) 3/4/2018 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** T/I/O= 540/440/0. CMIT-TxIA(DRLG SCREEN) CMIT-TxIA***PASSED*** 2nd attempt. TBG passed to 2701 psi and IA to 2683 psi. Max applied pressure=2750psi Target pressure=2500psi. Pressured TBG to 2744& IA to 2727 psi with 4.8 bbls 60/40. CMIT-TxIA TBG lost 26 psi in 1st 15min and IA lost 29 psi. 2nd 15 min TBG lost 17 psi and IA lost 16 psi, for a total loss of 43 psi on TBG and 45 psi on IA during 30 min test. bled TBG & IA back to 500 psi recovering —6 bbls. Valve 3/5/2018 positions=WV, SV, SSV= CLOSED. MV=OPEN. IAC, OAC=OTG. FWHP= 500/513/4 Fluids Summary Bbls Type 2 Diesel 4 Crude TREE= ' 6X7CW V4ELLFEAD= tvbEVOY Q_0 6A !FETY NOTES: WELL ANGLE a 700 @ 11288'. ACTUATOR= BAKER 0KB.ELEV= 69.62' REF ELEI/_ _ I-FT F3E1/= 40.59 ( i 2026' 7"OTIS SSSV LANDING NF',D=5.962' � KOP_ 2� tax A*Oie=.. 94"©12311' ^' [_2038' J9-5/8"FOC Odium MD= 11146' w_____-.__-. ___8_8.67.___ nom II Odtum TVD= 8800'SS . 9 268T 9-518'DV FKR I 113-3/8"CSG,72#,L-80,D=12.347" H 2686' , Minimum ID = 3.813" @ 9996' 0 a 16713'-6714'i-TUBING PINCH(09/05/13) 4-1/2" HES X NIPPLE 9896' -5'BKR C-2 TIEBK SLV w/}MC HGR D=4.438 TOP OF 4-1/2"LNR H 9896' • -"-L9910' j---15"X 4-1/2"XO,D=3.938' i I L 9996' 1-4-1/2"I$X Nom,D=3.813' TOP OF 7'LNR -I_ 10004' - I 10021' --'7"SEAL ASSH4iSLY,D=? • 7"TBG,26#,L-80..0383 bpf,D=6.276 --{ 10026' 7'MIL LOUT WIDOW(4-06A)11091-11099' 9-5/8"CSG,47#,L-80,D=8.681' 1- 10616' I A 111, 4-1/2" M-4STOCK(XX/XX/XX H 11089' 11236' -14-1/2'BKR CEP(11/04/17) 7"LNR,29#,L-80,.0371 bpf,D=6.184 -- -11089 4-1/2"BM:GE H 11100' 11800' -14-1/2'WFTCBP(08t1a/t5) PERFORATION SUIMARY 16111,w REFLOG: ? ` ANGLE AT TOP PERF:89`c 11655 \I Nnte:Fifer to Roduction CB for historical perf data SIZE SPF INTERVAL OFNISQZ SI-OT SQZ 3-3/8" 6 11655-11715 C 08/14/15 2-3/4' 4 11820-11960 C 05/14/98 2-3/4" 4 12020-12090 C 05/14/98 2-3/4" 4 12150-12240 C 05/14/98 404 LFBTD H 12437' N%*w, 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.953" H 12618' DATE REV BY CONVENTS DATE REV BY CONVENTS FRUC)HOE BAY LINT I 06/24/79 N18E INITIAL COMPLETION 08/28/15 ALNJM)SET CBRAOPERFS(08/14/15) WELL: Q-06A I 05/16/98 D-16 SIDETRACK(0-08A) 11/13/17 JG/JM) SET CBP(11/04/17) FER IT 'b: 1980900 1 10/31/13 F JN? SET 7"WFD PKR(10/19/13) 03/07/18 BSE/A43 PULLED PATCH(03103/18) An No: 50-029-20346-01 11/11/13 STT/PJC SET UPPER PKR(11/4113) SEC 16,T11N,R13E,379'EN_8 623'FF3. i 12/04/13 OGB/JM) PEFRES CORRECTED TO OFU 1 04/11/14 DGB/JM)CORRECTED9-5/8'CSG DEPTH BP Exploration(Alaska) 7,„, • \ OF s THE STATE Alaska Oil and Gas wiAL LAsKA Conservation Commission Witt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wh" Main: 907.279.1433 ‘117,4„., p, ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna Egbejimba NED DEL 1 8 Z017, Engineering Team Leader BP Exploration(Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Q-06A Permit to Drill Number: 198-090 Sundry Number: 317-557 Dear Mr. Egbejimba: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Commissioner DATED this etray of December, 2017. RIDDIVIS L .-EC 1 1 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill a• Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 198-090 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development IZI. 6. API Number 50-029-20346-01-00 • 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No RI PBU Q-06A • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028284&028281 PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12521 - 9016 • 11236 8912 2362 11236.11800 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 31-111 31-111 Surface 2656 13-3/8" 30-2687 30-2676 4930 2670 Intermediate 10486 9-5/8" 29-10515 29-8365 6870 4760 Liner 1092 7" 9999-11091 7998-8815 8160 7020 Liner 2622 4-1/2" 9898-12520 7925-9016 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11655-12240 9020-9030 7"26# L-80 27-10020 Packers and SSSV Type: 7"BOT Packer Packers and SSSV MD(ft)and ND(ft): 10024/8016 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch I1 Exploratory 0 Stratigraphic 0 Development IZI • Service 0 14.Estimated Date for Commencing Operations: December 1,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended El • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Leemhuis,Jacob be deviated from without prior written approval. Contact Email: Jacob.Leemhuis©bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 4989 Authorized Title: Engineering Team Leader-CTD&RWO Authorized Signature: �, _- % Date: %1/ O/2,0 1 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: v.1 6sn Plug Integrity ❑ 1 BOP Test I� Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED Other: Bap tt$1 /0 3 5--C CS 5', tt✓1 v l c✓ pre' trz'��/ , �5¢ fo ?AUC' 5 c a✓ /16ft-r'-a ff pl vy pl4c z- TH "7(" �y Ur2 ►fieI7 Post Initial Injection MIT Req'd? Yes❑ No / 1�tr ,4e2, ---, //Z( , Spacing Exception Required? Yes 0 No ® Subsequent Form Required: `/5 -1-CTi ® ` APPROVED BYTHE DP-S 12-18"l 1 7 Approved by: COMMISSIONER COMMISSION Date: /2 _Q_( 7 vTG /2"5-//7- v RSDS L.- DEC 1 1 2017 ORIGINAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,00 fr/ ;7 , /i- r 7 To: Alaska Oil & Gas Conservation Commission From: Jacob Leemhuis CTD Engineer bp Date: November 17, 2017 Re: Q-06A Sundry Approval Request Sundry approval is requested to plug the Q-06A perforations as part of the preparation, drilling and completing the proposed Q-06B coiled tubing sidetrack. History of Q-06A: Q-06A was drilled in 1998 to target zone 2B sands. Since drilling and completing in 1998, Q-06A has been intervention free. Q-06A was a full time producer up till early 2003 when it was shut-n for high GOR. After initially being shut-in in early 2003 for HOGR the well was produced as a swing well. In 2006 due to the oil transit line leaks from GC2 to GC1 Q-pad and all of it's wells suffered the fate of being shut-in till 2008 when the new OT21 line was put back in service. In 2008 Q-06A was POP showing a GOR healing, however, of all the Q-pad wells, Q-06A went to high GOR and • was allowed again to produce as a swing/cycle well. The completion on Q-06A is typical of original Q-pad wells, 7" production tubing without any gas lift mandrels. Proposed plan for Q-06B: Drill a through tubing sidetrack with the Nabors CDR-2 Coiled Tubing Drilling rig on or around December 2017. The Q-06B sidetrack will be a dual string exit from the existing 4-1/2" liner x 7" liner. A packer whipstock will be set pre-rig allowing isolation from the Q-06A perforations. Q-06B is a horizontal well kicking off in the Shublik, build, land and drill lateral in Zone 2. The proposed sidetrack is a —3,015' horizontal Zone 2 Ivishak producer to be completed with a 3-1/4" x 2-7/8" L-80 liner, cemented in place and selectively perforated post rig. A 4-1/2" x 3-1/2" tubing patch will be ran up to —2200' MD. This Sundry covers plugging the existing Q-06A perforations via the packer whipstock set pre-rig and 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 the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. The spy;ect - /I '4.'5 16 rec4f,,e L"'/7e7 kr rh Lr GO2 ro over go IvicF44 GAd hof 40 A ,2'%ced fee 4.G•e "/'p /rP er2 ea 5r Sev-erq( ey.cle3, f �� '` S we?" ,ter fe°(r;11 f4O J Q/'0n, / I / f eCC)rn),- ��6nti �1 r5 �Ur l i t7�► tie fC°I Pre-Rig Work(scheduled to begin December 1st, 2017) 1. F A/SL: Circ IA to diesel 2. E Set 4-1/2" Packer Whipstock. 3. F NEL: Load and kill well. MIT-T. 4. V Pre-CTD tree work. Rig Work(scheduled to begin December 2017) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,362 psi). 2. Mill 3.80"window and 10' of rathole. 3. Drill Build: 4.25" OH, -280' (20° DLS planned). 4. Drill Lateral: 4.25" OH, -2,735' (12° DLS planned) 5. Run 3-1/4" x 2-7/8" L-80 liner leaving TOL at-10,690' MD. 6. Pump primary cement job: 33 bbls, 15.3 ppg Class G, TOC at-10,690' MD. 7. Perform liner lap test*. 8. Run 4-1/2"x 3-1/2" tubing patch 9. Freeze protect well to a min 2,500' TVDss. 10. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. Re-install wellhouse, and flowline. 2. Set liner top packer if liner lap test fails.* 3. RPM Log 4. Perforate -200' -300' Jacob Leemhuis CC: Well File CTD Engineer Joe Lastufka 564-4989 TREE= 6 X 7 CNV WELLHEAD—ACTUATOR= McEVBAKEOY Q—O 6A SAFETY NOTES: WELL ANGLE>700 @ 11288'. '0KB.a.EV= 69.62' REF ELEV= BF,R.EV= 40.59' 2026'2026' —7"OTIS SSSV LAN]NG N D=5.962" KOP= 2399' Max Angle= 94"@ 12311' .-- nor 2038' H9-5/8"FOC Datum MD= 11146' Datum TVD= 8800'SS � 1 2687' H9-5/8"DV PKR 13-3/8"CSG,72#,L-80,0=12.347" H 2686' • , S" X 16691'-6718'I-17"WFD ER PKR,0=3.95'(11/04/13) Minimum ID = 3.813" 9996' 0 0 6713'-6714' --ITl18NG PUNCH(09/05/13) I 4-1/2" HES X NIPPLE S S TOP OF 4-1/2"LNR --I 9896' r k9896' -15"BKR GTISMAC 2 K SLV w/ HGR D=4.438 -" --i 9910' H5"X 4-1/7 X0,0=3.938" ' ' 9996' —14-1/7 IES X NP,D=3.813" TOP OF 7"LP82 H 10004' 10021' H 7"SEAL ASSEM3LY,D=? 7"TBG,26#,L-80,.0383 bpf,D=6.276" H 10026' r FLOUT WNDOW(Q-06A)11091-11099' 9-5/8"CSG,47#,L-80,D=8.681" —{ 10515' a 16 4-1/2" W-WSTOCK(XXIXX/XX —I 11089' 11236' H4-1/2"BKR(BP(11/04/17) 17"LNR,29#,L-80,.0371 bpf,D=6.184" —I —11089 / 4-1/7 BRIDGE PLUG — 11100' { '*tif 11800' f--I4-1/2-VVFT OSP(08/14/15) PERFORATION SUMWNRY r REF LOG: ? ` ANGLE AT TOP FERE.89"@ 11655' ` Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL OPWSQZ SHOT SOZ ` 3-3/8" 6 11655-11715 C 08/14/15 2-3/4" 4 11820-11960 C 05/14/98 • 2-3/4" 4 12020-12090 C 05/14/98 2-3/4" 4 12150-12240 C 05/14/98 PBTD -� 1243r +w��w 4-1/2"LN2,12.6#,L-80,.0152 bpf,0=3.953" — 12518' DATE REV BY COMVEtTS DATE REV BY COMuuJTS PRUCHOE BAY INT 06/24179 NI8E INITIAL COMPLETION 08/28/15 ALM'JMD SET CBP/ADFERFS(08/14/15) WELL: Q-06A 05/16/98 D-16 SIDETRACK(Q-06A) 11/13/17 JGMIAD SET CBP(11/04/17) FERMI ND:'1980900 10/31/13 RANJMD SET 7"WFD PKR(10/19/13) AR No: 50-029-20346-01 11/11/13 SW/PJC SET UPPER PKR(11/4/13) SEC 16,T11 N,R13E,379'FNL&623'FEL 12/04/13 DGB/JMD PERFS CORRECTED TO OFEid 04/11/14 DGB/JMD( TID 9-5/8"(:SG DEPTH BP Exploration(Alaska) TRS_ VVELLI-EAD=. McR/OY PROPOSED Q06 SAFETY NOTES: W ELL ANGLE>_° ACTUATOR= @ OKB`ELEV= 69.62 REf ELEi/= O 2026' H7"OTIS SSSV LANDING NIP,D=5.962" BF.ELEV= 40.59 KOP= 2399 — 2038' —19-5/8"FOC Max Angle= —o @ — I 2587' H 9-5/8"DV PKR Datum MD= Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,ID=12.347" H 2686' ❑\ . (, )/()' -TUBING PUNCH(X/XX/XX) I TOP OF 4-1/2"TUBING PATCH H 2200' / 6691' -6718' --17"WFD ER PKR,ID=3.95"(11/04/13) 4-1/2"X 3-1/2"XO H 6650' ❑ ■ 6713'-6714' —ITUBNNG PUNCH(09/05/13) TOP OF 4-1/2"LNR -1 9896' 9896' —15"BKR G2 TIEBK SLV w/HMC HGR ID=4.438 r 9910' H5"X 4-1/2"XO,D=3.938" Minimum ID = 3.813" @ 9996' 4-1/2" HES X NIPPLE ' 9996' H4-1/2"FES XNP,ID=3.813" TOP OF 7"LNR H 10004' I----- 10021' H 7"SEAL ASSEMBLY,D=? 7"TBG,26#,L-80,.0383 bpf,D=6.276" — 10025' MI 9-5/8"CSG,47#,L-80,D=8.681" —{ 10515' I TSGR=10,657' 3-1/2"X 3-1/4"X 2-7/8"TOUTOC —1 10690' I' 10690' —13.70"DEPLOY SLV,D=3.00" ' —13-1/2" X NP,D=2.813" 3-1/2"LNR, #,L-80 STL, —i 10710' I--I--------- 10719 —I3-1/2"X 3-1/4"XO,D=2.786" .0087 bpf,D=2.992" 4-112"WHPSTOCK()01./XX/XX H 10740' 4-1/2"MLLOUT WINDOW(O-06B) - ' 11533' 13-1/4"X 2-7/8"XO, D=2.377" 7"VVI-IPSTOCK(XX/XX/XX —1 11089' 7"LNR,29#,L-80,.0371 bpf,D -=6.184" I —11089 1 PUP JT w/ RA TAG 7"MLLOUT WINDOW(Q-06A)11091-11099' PUPJTw/ �RA TAG PERFORATION SUMMARY REF LOG: ON_/_/_ ANGLE AT TOP PERE:_°@ 3-1/4"LNR,6.6#,L-80 TC11, 11533' Note:Refer to Production DB for historical perf data N .0079 bpf,D=2.85" SIZE SPF INTERVAL OPWSOZ SI-DT SQZ W` %IV* PBTD — 2-7/8"LNR,6.5#,L-80 STL, H 13963' PBTD —I 12437' '4'.'4 .0058 bpf,ID=2.441" 4-1/2"LNR,12.6#,L-80,.0152 bpf,0=3.953" — 12518' A��' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/24/79 N18E INTIIAL COMPLETION VVELL: O-06B 05/16/98 D-16 SIDETRACK(Q-06A) PERMIT No: / r_ CTD(Q-06B) AR No: 50-029-20346-0? 04/22/16 JMD BUILT PROPOSAL SEC 16,T11 N,R13E,379'FM_&623'FEL BP Exploration(Alaska) Well Blank CDR2-AC BOP Schematic Date Quick Test Sub to Otis -1.1 ft Top of7"Otis —._.—._._._ - 4 CDR2 Rig's Drip Pan Distances from top of riser Excluding quick-test sub Top of Annular 0.0 ft r n o� 7-1/16"5k Flange X 7"Otis Box Hydril71/16 Top Annular Element 0.7 ft Annular Bottom Annular 2.0 ft I. , rnrn. Blind/Shear CL Blind/Shears I 3.3 ft I ► 2-3/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft ► 65 B6 "1"1 I"' 67 I B6 Deployment Line ""4 t" }}k-1 S. a -/ 1 ;;• ......M YY YY W_.w1 . Sk Mud f- W' 11k It I III III Choke Line 3"Pipe/Slips Cu 3"Pipe/Slips 6.6 ft i 2-3/8"x 3-1/2"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft ► I 81 I B2 I Choke Line Kill Line rr P-�I -t4 iktlr.4 111114:41:111 :; Ill III Blind/ShearIP Cu Blind/Shears 10.0 ft ► I II 2-3/8"Pipe/Slips IV ��,, Cu 2-3/8"Combi's 10.7 ft -a,4 kI • CL of Top Swab 13.3 ft � � 10----Swab 2 Test Pump Hose iiip /Swab 1 CL of Bottom Swab 14.8 ft lid T1 ii T2 • CL Flow Tee 16.2 ft - � - • = BOP2 CL of SSV 17.5 ft] • = i Master 2 } Fusable ' CL of Master Valve 19.0 ft BOP1 .411 ► W.F Master 1 LDS 20.5 ft ----10.,_ “ ,, .. . �� fes. H ❑ . II 11 if n n II II Gound Level �4 II Il II II II Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist g� / in the upper left corner of Form 10-403 is checked. If the "Abandon"or v "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist 32) work) the initial reviewer will cross out that erroneous entry and initial then/ Jit on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. XN o, o Thousand Cubic Feet of Gas ("MCF") per Month od N co O O n N O 0 , O 0 O o O 0 0 O 0 O 0 O N1 O O 0 O O O 0 .-i 0•1 N ei N N .i O ci i—.„, _.a_— OHO` =1 Ol Z0Pr O_I O r O Co C o W r co II m oc a I O 01 >1 4 ♦ m Q4 4 • r U1 I S v z as , �� ♦----may St 'o �°a o ° PP o UI E o �1 w Q a - ----4 a �a • w _ - 4. a * to d vZ M a 4 p ♦ LU 0 v - l . f 1 _ Orw os O _ Z OC r a 4 ° ly 044.4,-.4"."—"—. .i. I I I I oPr a; a } O m I L9 Q d. Z u w O LiW4a a a` Q OO O J N. ala a 00 O • Q COM V , ♦ 0 O I M m 1 . +h- a .n 00..4 �t VP m o-aOa a" _ CO � Sfi r` 0 04 PO O O O rO r4 O O O O W O O O O O rl O .-I i. uo j Jad aaIeM;o siaaae8 Jo yluow Jad Ho to siaaae8 I 0 • RECEIVED SEP 132016 AOGCC SCMU4 NOV 0 3 2016 BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Prudhoe Bay Unit 1 OF 12 AK0816GCM135 • • gyroftiata A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) INC. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 Run Date: 23 Aug 2016 Surveyor: Adam O'Connor,Joshua Camacho Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.313758 deg. N Longitude: 148.834275 deg.W Azimuth Correction: None Gyro: Bearings are Relative to True North Depth Reference: Rotary Table Air Gap( RKB to MSL): 68.19 ft. Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location 2 OF 12 AK0816GCM135 • • • a . .. • A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.0 0.0 0.00 0- 11,288' RATE GYROSCOPIC CONTINUOUS MULTISHOT SURVEY RUN INSIDE 4.5"TUBING ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO RKB ELEVATION OF 68.19 FT AMSL BF TO MSL: 39.21 FT/ BF TO SWAB: 10.875 FT/SWAB TO GYRO: 7.0 FT/ ZERO GYRO ON SWAB: +11.10 FT 100.00 0.54 222.14 100.00 0.35 S 0.31 W 0.5 222.1 0.54 200.00 0.83 259.55 199.99 0.83 S 1.34 W 1.6 238.4 0.52 300.00 0.71 186.59 299.98 1.58 S 2.12 W 2.6 233.4 0.92 400.00 0.76 180.53 399.98 2.86 S 2.20 W 3.6 217.6 0.09 500.00 0.87 189.00 499.97 4.26 S 2.33 W 4.9 208.6 0.16 600.00 0.82 192.66 599.96 5.71 S 2.60 W 6.3 204.5 0.07 700.00 0.62 178.63 699.95 6.95 S 2.74 W 7.5 201.6 0.27 800.00 0.25 342.56 799.95 7.28 S 2.80 W 7.8 201.0 0.86 900.00 0.51 335.17 899.94 6.67 S 3.05 W 7.3 204.6 0.27 1000.00 0.57 346.09 999.94 5.78 S 3.35 W 6.7 210.1 0.12 1100.00 0.60 344.74 1099.93 4.80 S 3.61 W 6.0 217.0 0.03 1200.00 0.68 322.11 1199.93 3.82 S 4.11 W 5.6 227.1 0.26 1300.00 0.71 333.21 1299.92 2.80 S 4.76 W 5.5 239.5 0.14 • 1400.00 0.75 340.29 1399.91 1.64 S 5.26 W 5.5 252.7 0.10 1500.00 0.74 349.92 1499.90 0.38 S 5.59 W 5.6 266.1 0.13 1600.00 0.66 58.80 1599.90 0.56 N 5.21 W 5.2 276.1 0.80 1700.00 0.74 50.15 1699.89 1.27 N 4.22 W 4.4 286.8 0.13 1800.00 0.75 68.33 1799.88 1.93 N 3.11 W 3.7 301.8 0.24 1900.00 0.21 175.36 1899.88 1.99 N 2.49 W 3.2 308.7 0.84 2000.00 1.03 58.55 1999.87 2.28 N 1.70 W 2.8 323.2 1.14 2100.00 2.75 59.93 2099.82 3.95 N 1.14 E 4.1 16.1 1.72 2200.00 4.60 64.23 2199.61 6.89 N 6.83 E 9.7 44.7 1.87 2300.00 7.27 60.08 2299.06 11.79 N 15.93 E 19.8 53.5 2.70 2400.00 10.12 64.29 2397.90 18.76 N 29.33 E 34.8 57.4 2.92 2425.00 10.72 64.90 2422.49 20.70 N 33.41 E 39.3 58.2 2.44 2450.00 11.42 65.45 2447.03 22.72 N 37.77 E 44.1 59.0 2.83 2475.00 11.85 65.69 2471.51 24.80 N 42.36 E 49.1 59.7 1.73 2500.00 12.35 65.76 2495.96 26.96 N 47.14 E 54.3 60.2 2.00 2525.00 12.86 65.81 2520.35 29.19 N 52.11 E 59.7 60.7 2.04 2550.00 13.66 65.61 2544.69 31.55 N 57.34 E 65.4 61.2 3.21 2575.00 14.27 65.70 2568.95 34.04 N 62.84 E 71.5 61.6 2.44 2600.00 15.22 65.56 2593.12 36.66 N 68.63 E 77.8 61.9 3.80 2625.00 15.92 65.80 2617.21 39.43 N 74.75 E 84.5 62.2 2.81 2650.00 16.32 66.46 2641.22 42.24 N 81.10 E 91.4 62.5 1.76 3 OF 12 AK0816GCM135 0 • gyro I a n A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 2675.00 16.52 67.64 2665.20 44.99 N 87.60 E 98.5 62.8 1.56 2700.00 16.70 69.62 2689.16 47.59 N 94.26 E 105.6 63.2 2.38 2725.00 16.87 70.27 2713.10 50.07 N 101.04 E 112.8 63.6 1.01 2750.00 16.90 70.36 2737.02 52.52 N 107.88 E 120.0 64.0 0.16 2775.00 16.98 70.34 2760.93 54.97 N 114.74 E 127.2 64.4 0.32 2800.00 17.04 70.33 2784.84 57.43 N 121.62 E 134.5 64.7 0.24 2825.00 17.06 70.30 2808.74 59.90 N 128.53 E 141.8 65.0 0.09 2850.00 17.05 70.24 2832.64 62.37 N 135.43 E 149.1 65.3 0.08 2875.00 17.01 70.09 2856.55 64.86 N 142.31 E 156.4 65.5 0.24 2900.00 16.71 68.73 2880.47 67.40 N 149.10 E 163.6 65.7 1.98 2925.00 16.57 67.59 2904.42 70.07 N 155.75 E 170.8 65.8 1.42 2950.00 16.59 66.85 2928.38 72.83 N 162.32 E 177.9 65.8 0.85 2975.00 16.68 66.90 2952.34 75.64 N 168.91 E 185.1 65.9 0.36 3000.00 16.76 66.89 2976.28 78.46 N 175.52 E 192.3 65.9 0.32 3025.00 16.96 67.00 3000.21 81.30 N 182.19 E 199.5 66.0 0.81 3050.00 17.21 67.02 3024.10 84.17 N 188.95 E 206.9 66.0 1.00 3075.00 17.55 67.33 3047.96 87.07 N 195.84 E 214.3 66.0 1.41 3100.00 17.95 67.97 3071.77 89.97 N 202.89 E 221.9 66.1 1.78 3125.00 18.27 68.53 3095.53 92.84 N 210.10 E 229.7 66.2 1.46 3150.00 18.74 69.20 3119.24 95.70 N 217.51 E 237.6 66.2 2.06 3175.00 19.09 69.63 3142.89 98.55 N 225.09 E 245.7 66.4 1.51 3200.00 19.42 70.00 3166.49 101.40 N 232.83 E 254.0 66.5 1.41 3225.00 19.70 70.26 3190.05 104.24 N 240.70 E 262.3 66.6 1.17 3250.00 20.02 70.40 3213.56 107.10 N 248.70 E 270.8 66.7 1.29 3275.00 21.01 70.45 3236.98 110.04 N 256.95 E 279.5 66.8 3.96 3300.00 21.65 70.77 3260.26 113.06 N 265.53 E 288.6 66.9 2.60 3325.00 21.99 70.99 3283.47 116.10 N 274.31 E 297.9 67.1 1.40 3350.00 22.62 71.40 3306.60 119.16 N 283.29 E 307.3 67.2 2.60 3375.00 23.84 71.84 3329.58 122.27 N 292.65 E 317.2 67.3 4.93 3400.00 24.36 72.38 3352.40 125.40 N 302.37 E 327.3 67.5 2.26 3425.00 24.93 72.84 3375.12 128.52 N 312.31 E 337.7 67.6 2.41 3450.00 25.51 73.30 3397.74 131.62 N 322.50 E 348.3 67.8 2.45 3475.00 26.16 73.66 3420.24 134.72 N 332.95 E 359.2 68.0 2.67 3500.00 26.64 73.83 3442.63 137.83 N 343.62 E 370.2 68.1 1.94 3525.00 27.11 74.04 3464.93 140.95 N 354.48 E 381.5 68.3 1.92 3550.00 27.58 74.25 3487.14 144.09 N 365.53 E 392.9 68.5 1.92 3575.00 27.99 74.55 3509.25 147.22 N 376.75 E 404.5 68.7 1.73 3600.00 28.45 74.96 3531.28 150.33 N 388.16 E 416.3 68.8 2.00 3625.00 28.94 75.44 3553.21 153.40 N 399.76 E 428.2 69.0 2.17 3650.00 29.47 76.04 3575.03 156.40 N 411.59 E 440.3 69.2 2.42 4 OF 12 AK0816GCM135 • • gyrodata A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 3675.00 30.06 76.28 3596.74 159.37 N 423.64 E 452.6 69.4 2.41 3700.00 30.46 76.76 3618.33 162.31 N 435.89 E 465.1 69.6 1.87 3725.00 30.75 77.06 3639.85 165.19 N 448.28 E 477.8 69.8 1.31 3750.00 31.21 77.29 3661.28 168.05 N 460.83 E 490.5 70.0 1.90 3775.00 31.76 77.34 3682.60 170.91 N 473.57 E 503.5 70.2 2.20 3800.00 32.55 77.33 3703.76 173.83 N 486.55 E 516.7 70.3 3.16 3825.00 33.50 77.36 3724.73 176.82 N 499.85 E 530.2 70.5 3.80 3850.00 34.08 77.21 3745.50 179.88 N 513.41 E 544.0 70.7 2.34 3875.00 34.99 77.06 3766.10 183.03 N 527.23 E 558.1 70.9 3.66 3900.00 35.67 76.94 3786.49 186.28 N 541.31 E 572.5 71.0 2.73 3925.00 36.43 77.01 3806.70 189.60 N 555.65 E 587.1 71.2 3.04 3950.00 37.13 76.97 3826.73 192.97 N 570.23 E 602.0 71.3 2.80 3975.00 37.66 76.92 3846.59 196.40 N 585.02 E 617.1 71.4 2.12 4000.00 38.45 76.77 3866.27 199.91 N 600.03 E 632.5 71.6 3.18 4025.00 39.16 76.70 3885.76 203.50 N 615.27 E 648.1 71.7 2.85 4050.00 39.72 76.64 3905.06 207.16 N 630.73 E 663.9 71.8 2.25 4075.00 40.42 76.58 3924.20 210.89 N 646.38 E 679.9 71.9 2.80 4100.00 41.06 76.52 3943.14 214.69 N 662.25 E 696.2 72.0 2.56 4125.00 41.74 76.46 3961.89 218.55 N 678.33 E 712.7 72.1 2.72 4150.00 42.42 76.52 3980.45 222.46 N 694.62 E 729.4 72.2 2.72 4175.00 42.86 76.49 3998.84 226.41 N 711.08 E 746.3 72.3 1.76 4200.00 43.21 76.50 4017.11 230.40 N 727.67 E 763.3 72.4 1.40 4225.00 43.62 76.49 4035.27 234.41 N 744.38 E 780.4 72.5 1.64 4250.00 43.75 76.46 4053.35 238.45 N 761.17 E 797.6 72.6 0.53 4275.00 43.64 76.63 4071.42 242.47 N 777.97 E 814.9 72.7 0.64 4300.00 43.66 76.76 4089.51 246.44 N 794.76 E 832.1 72.8 0.37 4325.00 43.70 76.84 4107.59 250.38 N 811.57 E 849.3 72.9 0.27 4350.00 43.90 76.84 4125.64 254.32 N 828.42 E 866.6 72.9 0.80 4375.00 44.09 76.84 4143.62 258.27 N 845.33 E 883.9 73.0 0.76 4400.00 44.18 76.87 4161.56 262.23 N 862.28 E 901.3 73.1 0.37 4425.00 43.98 77.30 4179.52 266.12 N 879.23 E 918.6 73.2 1.44 4450.00 43.76 77.61 4197.55 269.88 N 896.14 E 935.9 73.2 1.23 4475.00 43.80 77.72 4215.60 273.58 N 913.04 E 953.1 73.3 0.34 4500.00 43.86 77.81 4233.63 277.25 N 929.96 E 970.4 73.4 0.35 4525.00 43.51 78.02 4251.71 280.86 N 946.84 E 987.6 73.5 1.52 4550.00 43.45 78.12 4269.85 284.42 N 963.68 E 1004.8 73.6 0.37 4575.00 43.56 78.12 4287.98 287.96 N 980.52 E 1021.9 73.6 0.44 4600.00 43.65 78.08 4306.09 291.52 N 997.39 E 1039.1 73.7 0.38 4625.00 43.84 78.05 4324.15 295.09 N 1014.30 E 1056.4 73.8 0.76 4650.00 44.07 78.05 4342.14 298.69 N 1031.28 E 1073.7 73.8 0.92 5 4F 12 AK0816GCM135 411) • g / • . A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 4675.00 44.42 77.94 4360.05 302.31 N 1048.34 E 1091.1 73.9 1.43 4700.00 44.85 77.80 4377.84 306.00 N 1065.51 E 1108.6 74.0 1.76 4725.00 45.24 77.65 4395.51 309.77 N 1082.80 E 1126.2 74.0 1.62 4750.00 45.51 77.44 4413.07 313.60 N 1100.17 E 1144.0 74.1 1.23 4775.00 45.93 77.38 4430.52 317.50 N 1117.64 E 1161.9 74.1 1.69 4800.00 46.15 77.38 4447.88 321.44 N 1135.20 E 1179.8 74.2 0.88 4825.00 46.24 77.32 4465.18 325.39 N 1152.81 E 1197.8 74.2 0.40 4850.00 46.45 77.28 4482.44 329.36 N 1170.45 E 1215.9 74.3 0.85 4875.00 46.72 77.23 4499.62 333.37 N 1188.16 E 1234.0 74.3 1.09 4900.00 46.93 77.22 4516.73 337.40 N 1205.94 E 1252.3 74.4 0.84 4925.00 47.27 77.27 4533.74 341.44 N 1223.81 E 1270.5 74.4 1.37 4950.00 47.53 77.25 4550.67 345.50 N 1241.76 E 1288.9 74.5 1.04 4975.00 47.79 77.31 4567.50 349.57 N 1259.78 E 1307.4 74.5 1.06 5000.00 47.99 77.33 4584.27 353.64 N 1277.87 E 1325.9 74.5 0.80 5025.00 48.18 77.38 4600.97 357.72 N 1296.03 E 1344.5 74.6 0.77 5050.00 48.28 77.45 4617.62 361.78 N 1314.22 E 1363.1 74.6 0.45 5075.00 48.04 77.45 4634.30 365.83 N 1332.41 E 1381.7 74.6 0.96 5100.00 47.90 77.46 4651.04 369.86 N 1350.53 E 1400.3 74.7 0.56 5125.00 48.02 77.47 4667.78 373.89 N 1368.66 E 1418.8 74.7 0.48 5150.00 48.02 77.44 4684.50 377.93 N 1386.80 E 1437.4 74.8 0.09 5175.00 48.14 77.51 4701.20 381.96 N 1404.96 E 1456.0 74.8 0.52 5200.00 48.30 77.56 4717.86 385.98 N 1423.16 E 1474.6 74.8 0.66 5225.00 48.43 77.52 4734.47 390.01 N 1441.40 E 1493.2 74.9 0.53 5250.00 48.28 77.35 4751.08 394.08 N 1459.64 E 1511.9 74.9 0.79 5275.00 48.40 77.29 4767.70 398.18 N 1477.86 E 1530.6 74.9 0.51 5300.00 48.65 77.32 4784.26 402.29 N 1496.13 E 1549.3 74.9 1.00 5325.00 48.88 77.35 4800.74 406.42 N 1514.48 E 1568.1 75.0 0.92 5350.00 49.08 77.48 4817.14 410.53 N 1532.89 E 1586.9 75.0 0.89 5375.00 49.31 77.53 4833.48 414.62 N 1551.36 E 1605.8 75.0 0.93 5400.00 49.50 77.56 4849.75 418.71 N 1569.90 E 1624.8 75.1 0.77 5425.00 49.80 77.64 4865.93 422.81 N 1588.51 E 1643.8 75.1 1.22 5450.00 50.05 77.61 4882.03 426.91 N 1607.19 E 1662.9 75.1 1.00 5475.00 50.45 77.68 4898.02 431.02 N 1625.97 E 1682.1 75.2 1.61 5500.00 50.82 77.80 4913.87 435.12 N 1644.85 E 1701.4 75.2 1.53 5525.00 51.07 77.81 4929.62 439.22 N 1663.83 E 1720.8 75.2 1.00 5550.00 51.28 77.84 4945.30 443.33 N 1682.87 E 1740.3 75.2 0.85 5575.00 51.48 77.85 4960.90 447.44 N 1701.96 E 1759.8 75.3 0.80 5600.00 51.80 77.89 4976.42 451.56 N 1721.13 E 1779.4 75.3 1.29 5625.00 52.01 77.87 4991.84 455.69 N 1740.36 E 1799.0 75.3 0.84 5650.00 52.04 77.83 5007.22 459.84 N 1759.63 E 1818.7 75.4 0.17 6 OF 12 AK0816GCM135 0 • gymdata . A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 5675.00 51.93 77.81 5022.62 464.00 N 1778.88 E 1838.4 75.4 0.44 5700.00 51.73 77.84 5038.07 468.14 N 1798.09 E 1858.0 75.4 0.81 5725.00 51.71 77.84 5053.56 472.28 N 1817.28 E 1877.6 75.4 0.08 5750.00 51.56 77.78 5069.07 476.42 N 1836.44 E 1897.2 75.5 0.63 5775.00 51.42 77.72 5084.64 480.57 N 1855.56 E 1916.8 75.5 0.59 5800.00 51.34 77.65 5100.24 484.73 N 1874.64 E 1936.3 75.5 0.39 5825.00 51.10 77.51 5115.90 488.92 N 1893.67 E 1955.8 75.5 1.05 5850.00 51.09 77.48 5131.60 493.14 N 1912.67 E 1975.2 75.5 0.10 5875.00 50.92 77.43 5147.33 497.36 N 1931.63 E 1994.6 75.6 0.70 5900.00 50.81 77.43 5163.11 501.58 N 1950.56 E 2014.0 75.6 0.44 5925.00 50.76 77.50 5178.92 505.78 N 1969.47 E 2033.4 75.6 0.30 5950.00 50.70 77.35 5194.74 509.99 N 1988.36 E 2052.7 75.6 0.52 5975.00 50.57 77.36 5210.60 514.23 N 2007.22 E 2072.0 75.6 0.52 6000.00 50.49 77.30 5226.49 518.46 N 2026.04 E 2091.3 75.6 0.37 6025.00 50.40 77.30 5242.41 522.70 N 2044.85 E 2110.6 75.7 0.36 6050.00 50.32 77.34 5258.36 526.92 N 2063.63 E 2129.8 75.7 0.34 6075.00 50.11 77.28 5274.36 531.14 N 2082.37 E 2149.0 75.7 0.86 6100.00 50.01 77.19 5290.41 535.38 N 2101.07 E 2168.2 75.7 0.49 6125.00 49.81 77.14 5306.51 539.63 N 2119.71 E 2187.3 75.7 0.81 6150.00 49.63 77.06 5322.67 543.88 N 2138.31 E 2206.4 75.7 0.76 6175.00 49.57 77.00 5338.87 548.16 N 2156.86 E 2225.4 75.7 0.30 6200.00 49.36 76.97 5355.12 552.44 N 2175.37 E 2244.4 75.8 0.84 6225.00 49.10 76.97 5371.45 556.70 N 2193.82 E 2263.3 75.8 1.04 6250.00 49.11 76.99 5387.81 560.96 N 2212.23 E 2282.2 75.8 0.07 6275.00 49.08 77.01 5404.18 565.21 N 2230.64 E 2301.1 75.8 0.13 6300.00 49.02 77.01 5420.57 569.46 N 2249.04 E 2320.0 75.8 0.24 6325.00 49.01 76.90 5436.97 573.72 N 2267.42 E 2338.9 75.8 0.33 6350.00 49.23 76.61 5453.33 578.05 N 2285.82 E 2357.8 75.8 1.24 6375.00 49.55 75.41 5469.60 582.64 N 2304.24 E 2376.8 75.8 3.86 6400.00 49.35 73.27 5485.85 587.76 N 2322.53 E 2395.7 75.8 6.55 6425.00 49.47 71.99 5502.12 593.43 N 2340.64 E 2414.7 75.8 3.92 6450.00 49.59 70.97 5518.35 599.47 N 2358.68 E 2433.7 75.7 3.14 6475.00 49.93 70.25 5534.50 605.81 N 2376.68 E 2452.7 75.7 2.59 6500.00 50.08 69.99 5550.57 612.32 N 2394.69 E 2471.7 75.7 1.00 6525.00 50.17 69.90 5566.59 618.90 N 2412.71 E 2490.8 75.6 0.45 6550.00 50.28 69.81 5582.59 625.52 N 2430.75 E 2509.9 75.6 0.52 6575.00 50.34 69.73 5598.55 632.17 N 2448.80 E 2529.1 75.5 0.34 6600.00 50.31 69.71 5614.51 638.84 N 2466.85 E 2548.2 75.5 0.13 6625.00 50.29 69.67 5630.48 645.51 N 2484.89 E 2567.4 75.4 0.15 6650.00 50.23 69.67 5646.47 652.19 N 2502.92 E 2586.5 75.4 0.24 7 OF 12 AK0816GCM135 • • gyro data A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 6675.00 50.29 69.61 5662.45 658.88 N 2520.94 E 2605.6 75.4 0.30 6700.00 50.91 69.38 5678.32 665.65 N 2539.03 E 2624.8 75.3 2.58 6725.00 50.16 69.47 5694.21 672.43 N 2557.10 E 2644.0 75.3 3.01 6750.00 50.35 69.45 5710.19 679.18 N 2575.10 E 2663.2 75.2 0.76 6775.00 50.30 69.47 5726.15 685.93 N 2593.12 E 2682.3 75.2 0.21 6800.00 50.44 69.46 5742.10 692.68 N 2611.15 E 2701.5 75.1 0.56 6825.00 50.44 69.37 5758.02 699.46 N 2629.20 E 2720.6 75.1 0.28 6850.00 50.42 69.35 5773.95 706.25 N 2647.23 E 2739.8 75.1 0.10 6875.00 50.49 69.32 5789.86 713.05 N 2665.27 E 2759.0 75.0 0.29 6900.00 50.43 69.35 5805.78 719.86 N 2683.31 E 2778.2 75.0 0.26 6925.00 50.21 69.22 5821.74 726.66 N 2701.30 E 2797.3 74.9 0.97 6950.00 50.32 69.35 5837.72 733.46 N 2719.29 E 2816.5 74.9 0.59 6975.00 50.22 69.24 5853.70 740.26 N 2737.27 E 2835.6 74.9 0.52 7000.00 50.34 69.24 5869.68 747.08 N 2755.25 E 2854.7 74.8 0.48 7025.00 50.42 69.19 5885.62 753.91 N 2773.26 E 2873.9 74.8 0.36 • 7050.00 50.41 69.12 5901.55 760.77 N 2791.26 E 2893.1 74.8 0.22 7075.00 50.31 69.12 5917.50 767.63 N 2809.25 E 2912.2 74.7 0.40 7100.00 50.11 69.03 5933.50 774.49 N 2827.19 E 2931.4 74.7 0.85 7125.00 50.12 68.95 5949.53 781.37 N 2845.10 E 2950.4 74.6 0.25 7150.00 50.18 68.96 5965.55 788.26 N 2863.01 E 2969.5 74.6 0.24 7175.00 49.77 68.90 5981.63 795.14 N 2880.88 E 2988.6 74.6 1.65 7200.00 49.65 68.80 5997.79 802.02 N 2898.66 E 3007.6 74.5 0.57 7225.00 49.75 68.85 6013.96 808.91 N 2916.44 E 3026.5 74.5 0.43 7250.00 49.47 68.79 6030.16 815.79 N 2934.20 E 3045.5 74.5 1.13 7275.00 49.34 68.70 6046.43 822.67 N 2951.89 E 3064.4 74.4 0.59 7300.00 49.36 68.63 6062.72 829.57 N 2969.56 E 3083.3 74.4 0.23 7325.00 49.32 68.58 6079.01 836.49 N 2987.21 E 3102.1 74.4 0.22 7350.00 49.12 68.51 6095.33 843.41 N 3004.83 E 3121.0 74.3 0.83 7375.00 48.91 68.55 6111.73 850.32 N 3022.39 E 3139.7 74.3 0.85 7400.00 48.95 68.45 6128.16 857.23 N 3039.93 E 3158.5 74.3 0.34 7425.00 48.76 68.47 6144.60 864.14 N 3057.44 E 3177.2 74.2 0.76 7450.00 48.73 68.39 6161.09 871.05 N 3074.92 E 3195.9 74.2 0.27 7475.00 48.80 68.36 6177.57 877.98 N 3092.40 E 3214.6 74.1 0.29 7500.00 48.62 68.26 6194.07 884.92 N 3109.85 E 3233.3 74.1 0.78 7525.00 48.55 68.20 6210.60 891.88 N 3127.26 E 3252.0 74.1 0.33 7550.00 48.29 68.16 6227.19 898.83 N 3144.62 E 3270.6 74.0 1.05 7575.00 48.14 68.12 6243.85 905.77 N 3161.93 E 3289.1 74.0 0.61 7600.00 48.18 68.07 6260.53 912.72 N 3179.21 E 3307.6 74.0 0.22 7625.00 48.06 68.04 6277.22 919.67 N 3196.47 E 3326.1 73.9 0.49 7650.00 47.80 67.97 6293.97 926.62 N 3213.68 E 3344.6 73.9 1.06 8 OF 12 AK0816GCM135 • • gyrodata A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 7675.00 47.65 67.92 6310.79 933.57 N 3230.82 E 3363.0 73.9 0.62 7700.00 47.51 67.83 6327.65 940.52 N 3247.92 E 3381.4 73.9 0.62 7725.00 47.50 67.77 6344.54 947.48 N 3264.99 E 3399.7 73.8 0.18 7750.00 47.19 67.72 6361.48 954.45 N 3282.00 E 3418.0 73.8 1.25 7775.00 47.07 67.66 6378.49 961.40 N 3298.95 E 3436.2 73.8 0.51 7800.00 47.02 67.64 6395.52 968.36 N 3315.88 E 3454.4 73.7 0.21 7825.00 46.81 67.58 6412.60 975.32 N 3332.76 E 3472.5 73.7 0.86 7850.00 46.82 67.60 6429.71 982.26 N 3349.61 E 3490.7 73.7 0.07 7875.00 46.68 67.60 6446.84 989.20 N 3366.45 E 3508.8 73.6 0.56 7900.00 46.50 67.59 6464.02 996.13 N 3383.24 E 3526.8 73.6 0.72 7925.00 46.28 67.57 6481.26 1003.03 N 3399.97 E 3544.8 73.6 0.88 7950.00 46.12 67.59 6498.57 1009.91 N 3416.65 E 3562.8 73.5 0.64 7975.00 46.07 67.55 6515.90 1016.78 N 3433.30 E 3580.7 73.5 0.23 8000.00 46.00 67.54 6533.26 1023.66 N 3449.93 E 3598.6 73.5 0.28 8025.00 45.73 67.54 6550.67 1030.51 N 3466.51 E 3616.4 73.4 1.08 8050.00 45.62 67.47 6568.13 1037.35 N 3483.03 E 3634.2 73.4 0.48 8075.00 45.53 67.46 6585.63 1044.20 N 3499.53 E 3652.0 73.4 0.36 8100.00 45.28 67.49 6603.19 1051.02 N 3515.97 E 3669.7 73.4 1.00 . 8125.00 45.11 67.39 6620.80 1057.82 N 3532.35 E 3687.3 73.3 0.74 8150.00 45.08 67.32 6638.45 1064.64 N 3548.69 E 3705.0 73.3 0.23 8175.00 44.89 67.44 6656.13 1071.44 N 3565.01 E 3722.5 73.3 0.83 8200.00 44.62 67.38 6673.89 1078.20 N 3581.26 E 3740.0 73.2 1.09 8225.00 44.59 67.40 6691.69 1084.95 N 3597.46 E 3757.5 73.2 0.13 8250.00 44.58 67.27 6709.49 1091.71 N 3613.66 E 3775.0 73.2 0.37 8275.00 44.47 67.18 6727.32 1098.50 N 3629.82 E 3792.4 73.2 0.51 8300.00 44.29 66.96 6745.18 1105.31 N 3645.92 E 3809.8 73.1 0.95 8325.00 44.08 66.84 6763.11 1112.15 N 3661.95 E 3827.1 73.1 0.90 8350.00 44.02 66.73 6781.08 1119.00 N 3677.93 E 3844.4 73.1 0.39 8375.00 43.80 66.65 6799.09 1125.86 N 3693.85 E 3861.6 73.0 0.91 8400.00 43.70 66.61 6817.15 1132.72 N 3709.72 E 3878.8 73.0 0.42 8425.00 43.26 66.55 6835.29 1139.55 N 3725.50 E 3895.9 73.0 1.77 8450.00 43.16 66.50 6853.51 1146.37 N 3741.20 E 3912.9 73.0 0.42 8475.00 42.83 66.43 6871.80 1153.18 N 3756.83 E 3929.8 72.9 1.33 8500.00 42.60 66.31 6890.16 1159.98 N 3772.37 E 3946.7 72.9 0.98 8525.00 42.42 66.31 6908.59 1166.76 N 3787.84 E 3963.5 72.9 0.72 8550.00 42.16 66.19 6927.09 1173.54 N 3803.24 E 3980.2 72.9 1.09 8575.00 42.09 66.24 6945.63 1180.30 N 3818.58 E 3996.8 72.8 0.31 8600.00 41.85 66.05 6964.22 1187.06 N 3833.87 E 4013.4 72.8 1.09 8625.00 41.71 65.94 6982.86 1193.84 N 3849.09 E 4030.0 72.8 0.63 8650.00 41.73 65.85 7001.52 1200.63 N 3864.28 E 4046.5 72.7 0.25 9 OF 12 AK0816GCM135 • • gymdata A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 8675.00 41.69 65.74 7020.18 1207.45 N 3879.45 E 4063.0 72.7 0.33 8700.00 41.75 65.70 7038.84 1214.30 N 3894.61 E 4079.5 72.7 0.26 8725.00 41.71 65.60 7057.50 1221.16 N 3909.77 E 4096.0 72.7 0.31 8750.00 41.42 65.63 7076.20 1228.00 N 3924.88 E 4112.5 72.6 1.16 8775.00 41.12 65.53 7094.99 1234.82 N 3939.90 E 4128.9 72.6 1.23 8800.00 40.87 65.55 7113.86 1241.61 N 3954.82 E 4145.1 72.6 1.00 8825.00 40.70 65.45 7132.79 1248.38 N 3969.68 E 4161.4 72.5 0.73 8850.00 40.46 65.41 7151.78 1255.15 N 3984.47 E 4177.5 72.5 0.97 8875.00 40.23 65.33 7170.83 1261.89 N 3999.19 E 4193.5 72.5 0.94 8900.00 40.24 65.32 7189.92 1268.63 N 4013.86 E 4209.6 72.5 0.05 8925.00 39.97 65.21 7209.04 1275.37 N 4028.49 E 4225.6 72.4 1.12 8950.00 39.76 65.17 7228.23 1282.10 N 4043.03 E 4241.4 72.4 0.85 8975.00 39.75 65.07 7247.45 1288.82 N 4057.54 E 4257.3 72.4 0.26 9000.00 39.68 64.99 7266.68 1295.56 N 4072.02 E 4273.1 72.4 0.35 9025.00 39.79 65.02 7285.91 1302.32 N 4086.50 E 4289.0 72.3 0.45 9050.00 39.95 64.98 7305.09 1309.09 N 4101.03 E 4304.9 72.3 0.65 9075.00 40.07 65.13 7324.24 1315.87 N 4115.60 E 4320.8 72.3 0.62 9100.00 40.32 65.34 7343.34 1322.63 N 4130.25 E 4336.9 72.2 1.14 9125.00 40.52 65.81 7362.37 1329.33 N 4145.01 E 4353.0 72.2 1.46 9150.00 40.52 66.37 7381.38 1335.91 N 4159.86 E 4369.1 72.2 1.46 9175.00 40.47 66.96 7400.39 1342.34 N 4174.76 E 4385.3 72.2 1.55 9200.00 40.54 67.46 7419.40 1348.63 N 4189.73 E 4401.4 72.2 1.33 9225.00 40.80 67.75 7438.36 1354.84 N 4204.80 E 4417.7 72.1 1.29 9250.00 40.81 68.31 7457.28 1360.95 N 4219.95 E 4434.0 72.1 1.46 9275.00 41.03 68.68 7476.17 1366.96 N 4235.18 E 4450.3 72.1 1.31 9300.00 41.31 69.07 7494.99 1372.89 N 4250.54 E 4466.8 72.1 1.52 9325.00 41.52 69.30 7513.74 1378.76 N 4265.99 E 4483.3 72.1 1.04 9350.00 41.98 69.40 7532.39 1384.63 N 4281.57 E 4499.9 72.1 1.86 9375.00 42.41 69.52 7550.91 1390.53 N 4297.30 E 4516.7 72.1 1.75 9400.00 42.66 69.68 7569.33 1396.42 N 4313.14 E 4533.6 72.1 1.09 9425.00 43.02 69.80 7587.67 1402.30 N 4329.08 E 4550.5 72.1 1.48 9450.00 43.45 69.88 7605.88 1408.21 N 4345.16 E 4567.7 72.0 1.73 9475.00 43.77 69.94 7623.98 1414.13 N 4361.35 E 4584.9 72.0 1.29 9500.00 44.07 69.94 7641.99 1420.08 N 4377.64 E 4602.2 72.0 1.20 9525.00 44.30 69.96 7659.92 1426.05 N 4394.01 E 4619.6 72.0 0.92 9550.00 44.60 70.15 7677.76 1432.02 N 4410.47 E 4637.1 72.0 1.31 9575.00 44.75 70.31 7695.54 1437.97 N 4427.01 E 4654.7 72.0 0.75 9600.00 45.07 70.37 7713.24 1443.91 N 4443.63 E 4672.3 72.0 1.29 9625.00 45.37 70.35 7730.85 1449.87 N 4460.34 E 4690.1 72.0 1.20 9650.00 45.35 70.52 7748.42 1455.83 N 4477.10 E 4707.9 72.0 0.49 10 OF 12 AK0816GCM135 • 41111 A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 9675.00 45.09 70.94 7766.03 1461.68 N 4493.86 E 4725.6 72.0 1.58 9700.00 44.97 71.24 7783.70 1467.42 N 4510.59 E 4743.3 72.0 0.98 9725.00 44.83 71.48 7801.41 1473.06 N 4527.31 E 4760.9 72.0 0.88 9750.00 44.75 71.79 7819.15 1478.60 N 4544.02 E 4778.5 72.0 0.93 9775.00 44.64 72.06 7836.92 1484.06 N 4560.74 E 4796.1 72.0 0.88 9800.00 44.54 72.31 7854.73 1489.43 N 4577.45 E 4813.7 72.0 0.81 9825.00 44.40 72.63 7872.57 1494.70 N 4594.15 E 4831.2 72.0 1.06 9850.00 44.09 72.90 7890.47 1499.87 N 4610.81 E 4848.6 72.0 1.45 9875.00 43.96 73.18 7908.45 1504.94 N 4627.43 E 4866.0 72.0 0.94 9900.00 44.21 73.38 7926.41 1509.95 N 4644.09 E 4883.4 72.0 1.14 9925.00 43.66 73.34 7944.41 1514.91 N 4660.71 E 4900.7 72.0 2.20 9950.00 43.98 73.64 7962.45 1519.83 N 4677.30 E 4918.0 72.0 1.53 9975.00 44.17 73.45 7980.41 1524.76 N 4693.98 E 4935.4 72.0 0.93 10000.00 44.07 73.53 7998.36 1529.70 N 4710.67 E 4952.8 72.0 0.46 10025.00 44.27 73.48 8016.29 1534.65 N 4727.37 E 4970.2 72.0 0.81 10050.00 44.16 73.22 8034.21 1539.64 N 4744.07 E 4987.7 72.0 0.85 10075.00 44.33 73.17 8052.12 1544.69 N 4760.77 E 5005.1 72.0 0.69 10100.00 44.41 72.81 8069.99 1549.80 N 4777.49 E 5022.6 72.0 1.06 10125.00 44.53 72.64 8087.83 1555.00 N 4794.21 E 5040.1 72.0 0.68 10150.00 44.64 72.50 8105.63 1560.26 N 4810.95 E 5057.6 72.0 0.59 10175.00 44.78 72.43 8123.40 1565.56 N 4827.72 E 5075.2 72.0 0.59 10200.00 45.02 72.32 8141.11 1570.90 N 4844.54 E 5092.9 72.0 1.01 10225.00 45.04 72.20 8158.78 1576.29 N 486139 E 5110.6 72.0 0.35 10250.00 44.96 72.29 8176.45 1581.68 N 4878.22 E 5128.2 72.0 0.41 10275.00 44.97 72.40 8194.14 1587.04 N 4895.06 E 5145.9 72.0 0.31 10300.00 44.69 72.45 8211.87 1592.36 N 4911.86 E 5163.5 72.0 1.13 10325.00 44.77 72.50 8229.63 1597.66 N 4928.64 E 5181.1 72.0 0.35 10350.00 44.79 72.63 8247.38 1602.94 N 4945.44 E 5198.7 72.0 0.37 10375.00 44.51 72.76 8265.16 1608.16 N 4962.21 E 5216.3 72.0 1.18 10400.00 44.56 72.79 8282.98 1613.35 N 4978.96 E 5233.8 72.0 0.22 10425.00 44.33 73.03 8300.83 1618.50 N 4995.69 E 5251.3 72.0 1.14 10450.00 44.14 72.96 8318.75 1623.60 N 5012.37 E 5268.8 72.1 0.78 10475.00 44.18 72.96 8336.68 1628.70 N 5029.02 E 5286.2 72.1 0.16 10500.00 43.77 73.67 8354.67 1633.69 N 5045.65 E 5303.5 72.1 2.56 10525.00 43.42 74.70 8372.78 1638.39 N 5062.24 E 5320.8 72.1 3.17 10550.00 43.20 75.93 8390.97 1642.73 N 5078.82 E 5337.9 72.1 3.49 10575.00 42.79 76.73 8409.25 1646.76 N 5095.39 E 5354.9 72.1 2.73 10600.00 41.89 78.01 8427.73 1650.45 N 5111.82 E 5371.7 72.1 4.99 10625.00 40.68 79.48 8446.52 1653.67 N 5127.99 E 5388.0 72.1 6.20 10650.00 40.02 80.39 8465.57 1656.50 N 5143.93 E 5404.1 72.1 3.54 11 OF 12 AK0816GCM135 • 0 gyrodata • A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: Q Pad Well: Q-06A Location: Wellhead, Prudhoe Bay Unit Job Number: AK0816GCM135 MEASURED INCL AZIMUTH VERTICAL HORIZONTAL CLOSURE DOGLEG DEPTH DEPTH COORDINATES DIST. AZIMUTH SEVERITY feet deg. deg. feet feet feet deg. deg./ 100 ft. 10675.00 39.48 81.28 8484.79 1659.04 N 5159.71 E 5419.9 72.2 3.14 10700.00 39.16 81.13 8504.13 1661.47 N 5175.37 E 5435.5 72.2 1.34 10725.00 39.14 80.96 8523.52 1663.92 N 5190.96 E 5451.1 72.2 0.44 10750.00 38.83 81.00 8542.95 1666.39 N 5206.49 E 5466.7 72.3 1.24 10775.00 38.51 81.05 8562.47 1668.83 N 5221.92 E 5482.1 72.3 1.29 10800.00 38.46 81.02 8582.04 1671.25 N 5237.29 E 5497.5 72.3 0.21 10825.00 38.13 81.08 8601.66 1673.66 N 5252.59 E 5512.8 72.3 1.33 10850.00 37.97 81.09 8621.35 1676.05 N 5267.82 E 5528.0 72.4 0.64 10875.00 37.53 81.18 8641.12 1678.41 N 5282.94 E 5543.1 72.4 1.77 10900.00 37.41 81.11 8660.96 1680.75 N 5297.97 E 5558.2 72.4 0.51 10925.00 37.24 80.93 8680.84 1683.11 N 5312.94 E 5573.2 72.4 0.81 10950.00 36.94 81.19 8700.78 1685.46 N 5327.83 E 5588.1 72.4 1.35 10975.00 36.59 81.11 8720.81 1687.76 N 5342.62 E 5602.9 72.5 1.41 11000.00 36.50 81.26 8740.89 1690.04 N 5357.33 E 5617.6 72.5 0.51 11025.00 35.93 81.39 8761.06 1692.27 N 5371.93 E 5632.2 72.5 2.30 11050.00 35.71 81.45 8781.33 1694.45 N 5386.40 E 5646.6 72.5 0.89 11075.00 35.13 81.52 8801.71 1696.60 N 5400.73 E 5660.9 72.6 2.33 11100.00 36.76 79.85 8821.95 1698.98 N 5415.21 E 5675.5 72.6 7.61 11125.00 40.09 77.51 8841.53 1702.04 N 5430.43 E 5690.9 72.6 14.53 11150.00 44.53 74.16 8860.02 1706.17 N 5446.74 E 5707.7 72.6 19.91 11175.00 48.93 71.52 8877.15 1711.56 N 5464.12 E 5725.9 72.6 19.20 11200.00 53.49 68.33 8892.81 1718.26 N 5482.40 E 5745.4 72.6 20.77 11225.00 58.47 66.42 8906.79 1726.23 N 5501.52 E 5766.0 72.6 20.90 11250.00 62.91 64.26 8919.03 1735.33 N 5521.32 E 5787.6 72.6 19.29 11275.00 66.94 60.18 8929.63 1745.90 N 5541.34 E 5809.9 72.5 21.87 11287.00 68.11 57.72 8934.21 1751.61 N 5550.84 E 5820.6 72.5 21.30 Final Station Closure: Distance: 5820.65 ft Az: 72.49 deg. 12 OF 12 AK0816GCM135 • • + ,OF Tfp .,04„. 1// ,--4.,, THE STATE Alaska Oil and Gas ‘4, , ofA LAsKA Conservation Commission ell*}t 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 _. Main: 907.279.1433 ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Wells Engineer BP Exploration(Alaska), Inc. tee FEB O '1 7' P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Q-06A Permit to Drill Number: 198-090 Sundry Number: 316-233, 316-370, 316-372 Dear Mr. Worthington: The AOGCC denies the enclosed applications for sundry approval relating to the above- referenced well. As provided in AS 31.05.080(a), within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal an AOGCC decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Chair DATED this cblay of August, 2016. RBDMS G '-AUG - 4 2016 STATE OF ALASKA nCL;t:IVED ',ALAALASKA OIL AND GAS CONSERVATION COMMI N APR 1 9 2016 SKA APPLICATION FOR SUNDRY APPRO 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate ❑ Repair Well Il - `CGutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Cement IA to Surface ® ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 198-090• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ®. 99519-0612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20346-01-00 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU Q-06A , a Property Designation(Lease Number): 10. Field/Pools: ADL 0028281 ' PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12521 • 9027 - 11800 9032 11800 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x30" 31-111 31-111 Surface 2656 13-3/8"72#L-80 30-2687 30-2676 4930 2670 Intermediate 10486 9-5/8"47#L-80 29-10515 29-8374 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7"26#L-80 L-80 27-10020 Packers and SSSV Type: 7"BOT Packer Packers and SSSV MD(ft)and ND(ft): 10024, 8023.19 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ® Wellbore Schematic El 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 13 ` Service ❑ 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ET • WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthingtgp,Aras J Title Wells Engineer Signature Phone +1 907 564 4102 Date 9��/ ).„4/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 /0/Y�/ _ ^C-�). � Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No 1. Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL RBDMS (,(-v AUG - 4 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate 04 � `7 2`' // • S m a o 0 0 0 0 ea C) O N rC� nov N f— 0 y O O O O O i CO CO C.0 �t CA CO r N m Nt CO CO CO f,- CO N- N O N N N C0 M O 00 O N CO CA CO CO 1 1 1 . 1 F- N L[) ✓ O C)) CO O N- CO C) N O) CD N CO Cf) O co O r LO CNC) O O ✓ O N r 0 r r r r v ❑ 4-0 Q Q 0 r O CA O C) N- • W Q. O O CO COCO0 C70 C10 • d CO N *k („0 J J N x V � OoO � _ NN N M CV i r CA r d' D)O i) N C) O) Ccoco co a C)) J N O N r 0) W Q C� O U W LLJ U O L cccwz O D H Z Z D Uv) ZJJI— • • • d N t0 M 00 0 I� Cfl L 00 O N . y co co co -4- c3 p 0 0 0 0 p O) a) 6) O) > a O F' CO CO L 7 7 O) N N In O 0 M M M M W O O) 6) 0 F w p • p W Z w w 0 W Z cp gg J > Y U m O O wY �[ 2 0 O O O 2 U U w W L r (D O) J J J d (n Z 0' d N _0 _0 _0 J W W J Z Z Z O O p p a 0• 0 0 W 2 Z ~Q Z W W LU a F- F- < J < 0 < 2 2 2 0 cn co co (n co CO CO Q C a 0 c s tn000 p, N N O '7 0 (O 00 O Eci r r 4-0 0 CN v- CO a d 2 2 2 O cn (n cn cn co a) CL 0 0 c .2 LL Q O Q Q • Qmmm a O C) m a m F- co 1.0 LO 0 0 0 > c O O O O W Z O N N N N Z a a < w �v 0 W 'L D W W N a i D a :7 J 0 W Q' ZW D W LL W c oo ao w 0 a0 a0 Q p O ? H J J a O co< < mamcwi) LL C co o re m E ca z < < < < 0 0 CO 0 u a co O u. N u. m a o_ o_ U J 0 0 w a 0000 < < m m a u m cn a • • bp lk-C l 7-v 57 o Q-06 IA Cement Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Ryan Rupert (907) 564-4238 History Q-06A has no remaining value (HGOR) and is bring progressed as a CTD sidetrack. An IA cement squeeze is proposed to both cover a PC leak @ -2000' MD and to buttress the production tubing, which is in poor condition. The proposed plan is to bring the TOC above the previously leaking FOC collar in the 9-5/8" casing at 2000'. This PC leak is currently being sealed with Seal-Tite from 2013. It's unknown how long this fix will hold, so electively bringing cement up past that will offer more certainty/reliability in the future. Objective Cement the IA to cover a PC leak at -2000' MD and buttress the production tubing. Cement will be ' circulated down CT and up the IA. The new cement top in the IA will be close to surface. Procedural steps Slickline 1. Pull tubing patch @ 6691' MD. E-Line kg"' 7 2. Set bridge plug above production packer. c cl I i'^�► , 3. Punch holes in tubing directly above bridge plug. :-- s . 4. Set cement retainer above tubing holes. Coiled Tubing 5. Sting into cement retainer and pump Class G cement into the IA to get the TOC in the IA up to surface. Coiled Tubing 6. Mill out cement retainer, residual cemen , and bridge plug. p rTREE= 6X7OW V%43.1.1-EAD= EVOY Q_o 6A SAFETY NOTES:WELL ANGLE>70° 11288'. ACTUATOR= BAKER C N1IAL KB.BEV 69.62' BF.a&= 40.59' n _ KOP= 2 V riv4 • 2026' H7'OTIS SSSV LANCING MP,D=5.962" Ma Angle= 94'a 12311' 00 dO _ ( L • etum RC= 11146 !"� _" 2038' H9-5/8-FOC L-5.„.:1‘ Datum ND= 8800 SS / 2587' —9-5/8'IN PKR 13-3/8'CSG,720,L-80,D=12.347' — 2688' J • ' ^�, ✓ -( �I pin 6691'-6718'1-.1 T WED 62 Ptaz D=3.95'(11/04/13) 1 Minimum ID= 3.813"@ 9996' ❑ . , 16713'-8714'—TIJBNG PUNO-1(09/05/13) 4-1/2" HES X NIPPLE of TOP OF 4-1/2'LFR H 9696' 1 I 9896' BKR C-2 TEBK SLV w/FMC HGR,D=4.438 I a 9910' H5"X 4-12'XO,D=1938' 1 9996' 1—4-12"FES X FP,C=3.813' I TOP OF r LFR — 10004' 1-- t 10021' —17'SEAL ASSEMBLY.D=? I 7'TBG,260,L-80,.0382 bpi,D=6.276- H 10025' _.. 9-5/8'CSG,470,L-80,D=8.881'1— 10615' } 4-1/2' VMHPSTOCK(xx/XX/XX — 11089' r P&LOUT WPDOW)Q-06A)11091-11099' 7'LFR,290,L-80,0.0371 bpf,D=6.184' —I -11089 11800' H4-12'wFr CHP(0804/1s) 1 14-12•BRDGE PLUG H 11100' R34=OR/ATON SULIVARY 1\1111111'\ 41:41 1 FEF LOG: ? ANGLE AT TOP PEW:89°@ 11655' Note:Refer to Production DB for historical pert data SIZE SPF NTSNAL OPWSOZ SHAT SOZ 3-3/8' 6 11655-11715 0 08/14/15 2-3/4' 4 11820•-11960 C 05/14/98 2-3/4' 4 12020-12090 C 05/14/98 2-314' 4 12150-12240 C 05/14/98 Z5 H 1243T `a. 14-1/2'LFR,12.60,L-80,.0152 bpf,D=3953" H 12518' DATE F4 V BY COMFITS DATE REV BY CONDEMN PRUDH OEBAY UNIT 06/24/79 NIKE IMTIAL CCMPLETION 08/28/15 ALMJMD SET CBRADF S(08/14/15) WELL: 0-06A 05/16198 D-16 SIDETRACK(Q-06A) R3TATT Fb: 1980900 10/31/13 RMJMD SET 7'WED R(R(10/19/13) AR No: 50-029-20346-01 11/11/13 STF/PJC SET UFFER Fl R(11/4/13) SEC 16,T11F1 R13E,379'FAL 8 623'FEL 12/04/13 DGB/J 4)PERES CORRECTED TO OPEN 04/11/14 DGWMJ CORRECTED 9-518-TSG DEPTH 13P Exploration(Alaska) 2 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COM N APPLICATION FOR SUNDRY APPROV LS ' 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Squeeze 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 198-090 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 DevelopmentEj 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20346-01-00 . 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU Q-06A ' RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: J U L 15 2016 ADL 0028281 • PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY AOGCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 12521 • 9027 ' 11800 9032 11800 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 31 -111 31-111 Surface 2656 13-3/8"72#L-80 30-2687 30-2676 4930 2670 Intermediate 10486 9-5/8"47#L-80 29-10515 29-8374 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7"26#L-80 L-80 27-10020 Packers and SSSV Type: 7"BOT Packer Packers and SSSV MD(ft)and TVD(ft): 10024, 8023.19 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer Signature �'' Phone +1 907 564 4102 Date 7A S/ 1.,/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No I Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. /��6 , Attachments in Duplicate ,/.511 7, /87 • i Q. 00000 N- CO O N O r- to O o N U O O O O O L co M CO NI- M Cn CO cf r N CO O CO co I- O t` r- O f-- I- N N N CD M O co O N co O) co CX) H N O O 0) M O N- M M N 0) O N CO AFf _ Cf) O M O r O CO LO O O A- O O N r O N r r r r o co Q O 0) 0) 0) N. • /I CO CO NCO CA N _C CA O) C z 03 Q. co O 0 O O M JO O J co CO • 0 co N *k C(O J J •U) N x N. N• *k *k = _ r 0) CD V O o\0 _ N N N ti r � � a)O COO CX) N Oa) 6M) c co co O O O) .J N N (3) W CC F- c OH W TOU W U o u- c o c z Z c W W W m O D F Z Z J U u) z .I 1— • • a) co co mooco r- CD s OD O CN cr; � � N co co co V D 0 0 0 0 O a) O) 6) C)) F a O co C) t � . CA N m co M LC) rn 0 UJ 0) rn 0 LU H LU ❑• ❑ WZ LU cn ❑ I- I-0 a > g < 0 0 O 0 Y cocr) N J U U a CO 0) cr J J J Q ¢ Cr) LU _ 0- r-- O O N < < < W a a U Z N N U U U J W W co d 2 2 2 Z ❑ 0 0 0 0 0 LI-10e GeZ I__ Z W W LU aH QJ Q Q 2 2 O cn cn cn cn cn CCC .F0 a I or ° t LO c) Q. N N O d CO co O 03 ca a m L d Cn Y 0 O cn J d 2 2 2 0 cn v) to cn cn d a. O U LL (i) U) U) is a. a_ a. a. `m Q m m m a 0 a) a) a m F- m LO LO L LO ? O r r .- r ❑ 0 ❑ O = 0 0 0 0 W J J Z O N N (V N Z 1 1 < W 0IXW N LL• �7 �' ❑ W 1) ❑ .L1 J ❑ W yZ a 0 w nj 0 W W LL W 0 C 0 O CO (b m ❑ ❑ Y W J -J J D m E Ca z < < < < yX O CO O CO 9 0 0 0 li a cn 0J W N UL 0aCC < < m m U_ L a Cr • • Well: Q-06 Q-06 IA Cement Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Ryan Rupert (907) 564-4238 History Q-06A has no remaining value (HGOR) and is bring progressed as a CTD sidetrack. An IA cement squeeze is proposed to both cover a PC leak @ -2000' MD and to buttress the production tubing, which is in poor condition and is already patched. The proposed plan is to bring the TOC above the previously leaking FOC collar in the 9-5/8" casing at -2000'. This PC leak is currently being sealed with Seal-Tite from 2013. It's unknown how long this fix will hold, so electively bringing cement up past that will offer more certainty/reliability in the future. Reserves/Economics There are 495,000 bbls of oil estimated to be recovered as a result of a successful CTD sidetrack. Current economics do not support a full blown rig-workover, therefore this alternative integrity repair is proposed to maintain integrity/operability of the well long term. Estimated IOR delivery for the well 235 BOPD. Objective Cement the IA to cover a PC leak at -2000' MD, and a patch and tubing punches @ 6713' MD. Cement will be circulated down CT and up the IA. The new cement top in the IA will be at -500' MD. Post-Job Evaluation This well is a producer so an AA will not be applied for, however the following BP internal criteria will evaluate the integrity of the non-rig workover: ➢ MITIA and MITT ➢ SCMT to locate Top of Cement (TOC) Long-Term Integrity Monitoring ➢ Daily pressure-monitoring of the cemented Inner annulus SII ➢ 4-year (quadrennial) MITIAs and MITTs Contacts: Aras Worthington Bernhard Stechauner 564-4102 (w) 907-564-4594 (w) 440-7692 (c) 907-360-7485 (c) TREE= 6X7 CV/ e likEVIDY0-06 Current SAFETY ROTE S:WELL MIME>79'I@ 112Cr. ACTUATOR= BARER C DICB_HEV= 69_62' FIEF ELEV= BF-ELE V= 40_59' 2026• H7-oils sssv LAFOFIG Nelt D=5.962' P= 2399' liar Aoglb= 94"fi 12311' ^ 203W HI9•5ir FOC Deice 1D= 11146' DalmITVD= 8600'SS MON =I25197' -�9 Mr DV MR 13-311'CSG.72N.L- .D=1234r - 260W • z Ikea!use a= 31113"@ 9996' `4 6691'-6718-17'wFDu MLD=395"(N104fi3) 4 112 HES X NIPPLEin6713'-6714' - T r '(°s�131 7OPCF4117LFR 9696' 9896' H5'NKR C-2l kSLVwlFICFIGR.D=4.4'.16 • 9918 H5'X4-712700 0=3936' 91106" -14-1121-@SXNJP D=3X13' 1OP OF 7'LMR - 1[)014' i0021' -r SEAL A^saa.Y.D=z 7'Tea.ME E-60__0393 W.D=6_271r - 10925' '1519'CSG.474F L-60.D=&061' -I 10515 4-112 YMF1113611X2C(.10(M ]C K, -I 11009' T{ALCM WINDOW(q-.CA)11081-11099' 7'LIOt 29IF.L-CC 71 blot.D=e_1B4- -J -11089 lisss' [--I4-112 WFTCEP(I 11415) 4-V2BRIDGE H_UG 11100' PERFORATDR SUY/ARY REF lO ? A*3LE AT TOP PERE or at 11655 Nate Referb Pa:docke 00 iorilsTxicelperfdds SIZE SPF IU WAL 01111501 SNOT SW 3-316' 6 11655-11715 0 0814115 2-314 4 11620-11960 C 05114196 2-314 4 1720-12090 C 05114/96 2-3W 4 12150-12240 C 05114196 Fero F 12437" •v1t.• r 4-12'I.Mt 12d1F L-60.D152 blot.D=3.953 -I 1251W DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY IMT 99/24/79 MBE NTIA L CO9'LLEHON 06120115 ALWAID SET CBPLADPERFS(06114115) UYB!_ O-06A 96111.99 0-15 SDETRACIC(496A) PERYTHoc 1990900 10131113 MAID SET T 4YFD Rot(10119113) AR Hoz 50-029-20346-01 11111113 S1F7PJC SETUPPERROt(1114113) SEC 16,1110,R13E,379'fill&623'Fa. 12/04113 =UAW PEWS CORRECTED TD OPEN 04111114 DOWNIE)CORRECTED 9-516'CSG DEPTH 1W Explon 1 2 IIII)TREE= 6X7C1 0 WENDY Q-06 Post IA Cement SAFETY NWES_WELL ANGLE>7.-6112sr_ ACTUATOR= BAKER C 0103.ELEV= 691.62' REF ELEV= Bf-�= 40.59' 300' HroCN� �= 239,9' iia A. e= 94'42 12311' I -I9-511'FOC Dian ND= 11146' Dale>r00'TVD= 66SS •• ... 25 IF -9-51r Dv MR 13-35'CSG.7 .450.D=12.347 -I 200W iireim un a= 3 13" 9996' 4,1.4 ►�� 6691-6718'-17 WFD 1 ER FIQZ o=3.95'(11,04/13) 41l2"HES X NIPPLE '" �'- . -�nEr'G PUNCH(00,05,13) I*W OF 4-1121)1k -I 94996 j9896' HS`DIM C-21®K SLY wI-CD f HNC R. =4_436 • 9910' -5'X 4-11'2 xcx U=a931- i9996' -14-112' "ES"W D="13' MC OF 7 LW --I 10004' W 1 101121' - 7-s6Al.ASSIMILV.D=? 71Bf.D G.261.L-60.-4363 bp =6576' - 16023' J"`! IIS ati 9.515-CSG.476.L-60.D=SAN' -I 10513• 4-1/7 WF*SIOCK(]acDa(Doc H 110119r T 6i.LOUi wHx3w(6161611)11091-11099' 7 Lilt 291.ii-no,_ 371 bpf.D=6-154' -I -11089 11:00' [-1 4-1ft wFr caw(05114/15) L___:_11-----)4 4-112 ERDCEFLUG 11100' Al PERFORATION SININARY REF LO ? ANGLE ATOM PERa9'IQ11655 Nate~Raffia Piadmice OB for llidloricaipal Ads SIE SW MTE VAL 019090Z SNOT SOZ 3-316' 6 11655-11715 0 0614115 2-3W 4 11/20-11960 C 0511496 2-3W 4 12020-12090 C 051/4196 2-3104' 4 12150-12240 C 05/14196 FBio I- 1243? vi. 4-112'1W.12_6l.L-60.2152 bpf.D=3_953" H 12510' DATE REV BY COINIERS DATE REV BY COMMENTS PR DHOE BAY UNIT 54111W/1 NUE MUM_COMPLETION OR/24V15 Al NOM SET CHYACIS(0d/14115) WELL Q-06A MAIM 0-14 SIDETRACK RABA) PERI -Na 1960900 101331173 RI VAI) SET r vivo Il (10119113) AMID: 50-029-20346-01 11111/13 STH PJC SET UPPER PIM(11/4/13) SEC 16y T11N,RUE,379'Flt.&623 F9 12104/13 memo Il S CORRECTED TD OPEN 04/11/14 mem]CORRECTED 9-518'CSc DEPTH Esplare 3 I • • Cement Calculations IA fillup volume to 500' MD 243 bbls Total cement to pump 244 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 7 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time,quality control,PJSM 0 Cement displacement 5 Cement contamination 1 Safety 1 Minimum required thickening time: 7 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 1400 2:00 130 1400 3:00 110 200 4:00 80 200 7:00 60 200 15:00 50 200 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 7"tbg 0 8000 7"26# 6.276" 0.0383 9896 379 9-5/8"47#x 9-5/8"x 7" annulus 0 9990 7"26# 8.681" 0.0256 9990 256 4 Eline wt Fullbore S • Notes: • The objective of the gyro is to obtain a new directional survey for Q-06. This is required for the upcoming `B' sidetrack. • The elevation of the Base flange is 39.21' (based on subsidence study in 2014 and updated As-built). See pictures of reference point below. Use this elevation to correct to RKB. • Survey should be corrected to the Q-06 RKB of 69.62'. • Tubing pressure is expected to be -2500 psi during SI. Fullbore will need to load the well prior to performing the Gyro. Gyro Procedure 1. Load TBG with -485 bbls (1.2x tubing volume) of crude to top perf. Pump at max rate, -7 bpm, not to exceed 2500 psi. 2. Using the elevation of the Base flange (shown below), correct tool zero to reference elevation. 3. Run gyro in PDC mode from surface to deviation at -11,288' MD. Pluq & Perf Procedure 1. Set 4-1/2" CBP @ 9975' MD (middle of first full joint of tubing above the X- nipple). 2. Perforate through 4-1/2" tubing and 7" tubing. 10' of HES 2.5" BH charges 0- deg phased charges from 9950' -9960' MD (across the top collar of the first full joint of tubing above the X-nipple). 3. Using Diesel or Methanol, CMIT TxIA to 3500 psi to verify CBP will hold cement hydrostatic pressures. Note: 7" tubing is derated due to pitting (burst -2600 psi, collapse -1950 psi) thus this step must be performed with the Tubing and IA pressure equalized. 4. Pump down tubing and take returns up IA for 5-10 bbls to verify a clear circulation path (this verifies the perforations through both strings are ample, and that circulation through the seal-tite placed @ -2000' MD is feasible). Max pressure 2500 psi. 5. Set 4-1/2" HES Composite Fasdrill SVB Cement Retainer @ 9935' MD (middle of the second full joint of tubing above the X-nipple). Note: All depths reference attached tubing tally of 02/08/1979. 5 Coifed Tubing • • 1. Rig up a micromotion to IA returns. This will help determine if the PC leak is drinking any cement and track the cement top in the IA. PT CT connector & CT to -4800 psi in anticipation of high circulating pressures towards the end of the cement job. Note: usually pressures do not get higher than 4000 psi during IA cement jobs, but they have in isolated cases so best to be prepared. 2. Have a way to divert the FW spacer (ahead of the cement) upstream of the CT so that nothing but cement or diesel goes into the IA). 3. RIH with HES Fasdrill SVB cement retainer stinger. Displace CT x TBG backside to heated 160F 9.8 ppg brine while RIH. This will help minimize the hydrostatic pressure difference between the Tbg and IA while cement is pumped up the IA. 4. Rig up a pump to bump up the CT x TBG backside pressure while pumping cement. Use the following schedule to keep the collapse (& burst) differential pressure between the tbg and IA to <1300 psi throughout the tubing string and throughout the job: ➢ Lead of cement slurry enters IA: 0 psi on CT x TBG backside ➢ 100 bbls of cement into IA: 0 psi on CT x TBG backside ➢ 150 bbls of cement into IA: 300 psi on CT x TBG backside ➢ 200 bbls of cement into IA: 800 psi on CT x TBG backside ➢ 243 bbls of cement into IA: 800 psi on CT x TBG backside 5. Sting into retainer and establish diesel circulation down CT and up IA to tanks. Verify coil backside is SI. Pump the following fluid schedule. Note: Do not pump any freezable fluids through retainer into the IA as these fluids will remain in the IA @ -500' MD after the cement job. ➢ *260 bbls of heated diesel (160F) ➢ Minimal FW spacer (divert this upstream of the CT so that nothing but diesel or cement goes into the IA) ➢ 244 bbls cement per design ➢ CT volume of FW (unsting from retainer w/ last 1-2 bbls of cement in CT) *Note: There are two reasons for the heating the diesel: 1. The cement in the IA acts as an extended packer. Tubing movement models indicate that heating the entire wellbore to -140F before setting a packer on a rig is the optimum temperature for locking the tubing in place in PBU (prevents buckling when the tubing is heated up via producing or injecting). Heating the entire wellbore for this type of job to 160F will approximate this (wellbore fluids will cool before cement sets). 2. Heating the entire wellbore helps the cement to cure. There have been a couple of IA cement jobs where fluids were not heated prior to cementing and the cement took much longer to cure. In one case it took about 2 weeks before the well would pass an MITIA. VIII 6 of�,cont r ,r 6. This should put the TOC in the IA @ —500' MD. Keep track of returns from the IA to track the TOC in the IA. In order to keep a rate of-1 bpm be prepared for CT pressures to be over 4000 psi towards the end of the cement job (when water is displacing cement out the CT). See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. 7. While maintaining Tubing x CT backside pressure (per above schedule this will be 800 psi), unsting from cement retainer w/<1 bbl of cement still in the CT and lay remainder of cement in 1:1 on top of cement retainer. Monitor CT x TBG pressure closely as the stinger is pulled out to ensure retainer seals. If it does not seal, the backside pressure should jump to—2300 psi. If this happens, leave the 2300 psi on the backside for the remainder of the job to keep cement in the IA in place. 8. With the same pressure (800 psi or more; depending on the retainer sealing) trapped on the CT X TBG backside, POOH pumping only CT displacement down the CTxTBG backside. This can be achieved by POOH and pumping just enough down the backside to maintain whatever pressure the CT X TBG backside equalized at in the first place and verifying that for every 100' of CT pulled—0.3 bbls of fluid are pumped into the well, but if there is any question err on the side of pumping more fluid into the well, not less. Also verify upon reaching surface that—30 bbls of fluid total have been pumped into the well since leaving bottom. 9. Leave the well with 500 psi trapped WHP (Bleed WHP from 800 to 500 psi or if retainer did not seal hold —2300 psi). This will keep the derated 7" tubing from collapsing while the cement cures. Freeze protect CT with MEOH/water as needed with the well SI. CO'fril'-'4"1%41:111f15 `! *r r . rr �, Contingency#1: If at some point cement locks up and cannot be pumped into the IA then hold whatever CT x TBG backside pressure has been already established, cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1 maintaining CT x TBG backside pressure. Reverse the remaining cement out of the tubing. U f lr,r�lr� "", *# /f„#,.444"074,/7'!, /r%?`� �' '„de'�j r ;' %'!/� ,'% s °'�3 r6�/�;: '! `` a �",� 0 3 ��! 37 J vr5 '1. ,s'r� ''� ,� ' r'� �r` N„N,,vv„ �`,�:.!!',-� ff,,.y/, �io:/��y�-� if1.✓/tlrw�r�i��/16;.��,,,� 'C;%� ��,� ,��„f �i 1. Wait on Cement at least 5 days 2. MIT-IA to 2500 psi. 3. MITT to 2500 psi. • Coit 1. MU 3.80" OD junk mill. RIH and tag TOC (expected —4700' MD). 2. Mill through cement, retainer, cement and the CBP. 3. Mill/Push CBP remnants down to —11,800' MD (to the top of CIBP). Note that the CTD sidetrack will kick off at—11,090' MD. St ckline 1. Run SCMT log from tubing tail to surface to find TOC and relative bond. 8 • • SUMMARY `i " PIPE WELT. Q—`cr DATE sil- 6- 19 RIG ams 18 E. K.B. ?.Y L.Q ' ABOVE MAT X.4014 JTS. ON RACK 2-4,$-- JTS. RAN 1.S ..-- JTS. OUT FT. ON RACK FT. RAN PT. OUT LAST CASING STRING: " @ t, CASING S CEMENTING EQUIPMENT DETAIL FROM BOTTOM UP: (T.D. to K.B.) ITEM LENGTH DEPTH JT.NOS. DESCRIPTION i- -1' tSta i►ssn. - A0.55� ' TOP @ i.0attO,Tam' L ..►-... -.• tib- AS. ," A.1• ' TOP @ A.0.41.04 t- ' tom. s4 ' TOP Q D.c.174,ftvt ' PAj tl , CANA/. 4(• " _ r t k .Z S' ' TOP Q 54,30k ' A It x,441 t TOP @ ' 3.'[ r TOP @ i• rtit ' TOP @ ' ' TOP @ ' TOP @ ' ' TOP@ e _ ' TOP @ ' ' TOP @ ' ' TOP @ ' c ' TOP @ ' ' TOP @ ' ' TOP @ ' Total Pipe on Hook t �. Jte. Leas Ft. Up - ',.,.,..__.,.__. (Above KB) Shoe Depth I ?A -13,--OF CENTRALIZERS PLACED AT . til t,vi okIst6t.1 0,4,c, Sal. --� AND NO. OF LACED AT Dri ,v,.©vie_ o' STARTED RUNNING AT 0100 HRS. , ON BOTTOM AT ), HRS. STRING WEIGHT ON BOTTOM 1.Y(S}(re O LBS. COMMENTS: `t 2 k i _4-.;_ -__.._ - r iik ..---—..._. . _---_.__ ___. . 0 l._ ' , 9 STATE OF ALASKA . 4110 ALASKA OIL AND GAS CONSERVATION COM N APPLICATION FOR SUNDRY APPROS 20 AAC 25.280 ' 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other IA Squeeze ® • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 198-090 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 99519-0612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20346-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU Q-06A • RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: JUL I, 2 O C ADL 0028281 • PRUDHOE BAY,PRUDHOE OIL • J U 11. PRESENT WELL CONDITION SUMMARY JA Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Jdnk et ) CC 12521 • 9027 " 11800 9032 11800 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 31-111 31-111 Surface 2656 13-3/8"72#L-80 30-2687 30-2676 4930 2670 Intermediate 10486 9-5/8"47#L-80 29-10515 29-8374 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 7"26#L-80 L-80 27-10020 Packers and SSSV Type: 7"BOT Packer Packers and SSSV MD(ft)and ND(ft): 10024, 8023.19 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic ® 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development IZE • Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil IBJ • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer / i-Signature ��/ Phone +1 907 564 4102 Date �/ //J/J COMMISSION USE ONLY r,/,,2, Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31Ce. - 3'72 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No l I Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • S . . . .O ti3. Ca L N r C N V' U N o 0 0 0 0 CO CO V- 0.) CO V N m V CO CO CO f� COV r- f� O f- f- N N N CO CO O CO O N CO a) CO CO I I I i I 1 H N LU 0a) CO O f- MMNa) ON CO _ O O M O I() 6() O O N O N r O = r r r 0 I I I I I I Q Q Q rO O) a) O) N. co co N co d) N c• � O O • W _~ a_ O O O CD O -' OJ a 00 (NI 4k J 15 X - N *k O o0 - = N N U N M ° N - I M r' CD 4 4' CO CD N V CO DI O LU N a) a) c co CO V C4 O J N N cc a7 W Q C 0 U W W Z W W W O D Z Z D O CO Z J J • • 11111 N of m COLn CO oD O N- N ti y co co M o 0 0 0 0 0) 6) 0) 0) H a O co co N co co L() CA °) °) a) o) 0 LU w a O• 0 W Z ww �- 0oa o a) g Y U O > O O < Y Y g m Ln 0 0 0 - - U U W w L.. CO CY) • J J Q Q C7 W R' d N- 0) O N Q Q < a B O Z O p N U_ U_ _U W W W Z Z Z O 5, 5 J p J Eooa `" a U U 0 W O O = w w LU a H f Q Q Q 2 2 2 O cn cn cn cn cyto Q Oa I- C if) 000 LO N N Lo 0 M a) CO co O ._ . Lid 0 • N O - cn = 1- 1 - a 2 2 2 O cn cn cn cn cn O U c LL U) U) U) is O_ dryf� ry� a7 Q /y�W W W a 0 a) a) a m f- LO Lf) Ln LO n :9 o c 0 0 0 0 W _I Z O N N N N Z 1 1 Q • dr dr .ct OW eC W N LL d • Z 0 -1DU W LU LL W oao000000o m oE0zw J _' D a < < �o d m co LL LL tai UO a a) E co z < < < < 0 0 0 0 U- d co 0J LL N LL CL 0000 < < m m u_ LI co co a rt • • Well: Q-06 Q-06 IA Cement Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Ryan Rupert (907) 564-4238 Reservoir Engineer Eli Chambers (907) 564-4289 History Q-06A has no remaining value (HGOR) and is bring progressed as a CTD sidetrack. An IA cement squeeze is proposed to both cover a PC leak @ -2000' MD and to buttress the production tubing, which is in poor condition and is already patched. The proposed plan is to bring the TOC above the previously leaking FOC collar in the 9-5/8" casing at -2000'. This PC leak is currently being sealed with Seal-Tite from 2013. It's unknown how long this fix will hold, so electively bringing cement up past that will offer more certainty/reliability in the future. Reserves/Economics There are 495,000 bbls of oil estimated to be recovered as a result of a successful CTD sidetrack. Current economics do not support a full blown rig-workover, therefore this alternative integrity repair is proposed to maintain integrity/operability of the well long term. Estimated IOR delivery for the well 235 BOPD. Objective Cement the IA to cover a PC leak at -2000' MD, and a patch and tubing punches @ 6713' MD. - Cement will be circulated down CT and up the IA. The new cement top in the IA will be at -500' MD. Post-Job Evaluation This well is a producer so an AA will not be applied for, however the following BP internal criteria will evaluate the integrity of the non-rig workover: ➢ MITIA and MITT ➢ SCMT to locate Top of Cement (TOC) Long-Term Integrity Monitoring ➢ Record WHPs daily (includes pressure-monitoring of the 500' deep Inner annulus) ➢ 4-year (quadrennial) MITIAs and MITTS / 7 �D�vred �'� 0o MCS( 6Og) S G �Gvt �� `I�I(�ltr �'7 ConC1/r• L' ( P 4 J/'al d0 ab T p C . �i�4U t�r ct reserves �� Pr9°S'� GTS �� -a f�`� f q Gye paw TAe well (Of f�PlraG .� . i �p�. USt1f) COrOfvc6'n� �` over �6 This rlia► 6� e / ' d l•C©ve� roo reO pie l act'o''r �ti�ld a(/ - �o� ;ml�o� 1 r//�,6 • • ,• TRff= 6X7Cw MMFII IEAD= Nc£YO1YQ-06Current SAFETY NOTE S:WELL ANGLE 711.Q 112$r. ACiUATOR= BAKER O1B_ELEY= 6957 REF ELEY= BF_ELEV= 40.59' 21126' H7'OM SSSV IAM 4G Fp D=5-962 KIW= 2399' Mix A. e= 94'6!12311' 21130 —195W FOC DAM ND= 11146' DshomTVD= 111900' 2582" H 9-Ear w PICK 13-313"MO.725.L30.U=12347' — 2898' Nrn9•uM = 9996' �� 6691'-6718'-TWIFCERLD=3.95'(11104113) •� 313"� 4 112 HES X NIPPLE -61 —{nBr4G PUNCH(019105113) 70P OF 4-1/7 LFII ' 9096' —15.0104 C-2 1K SLY wJ 1-9c HGR.D=4.435 8910' —15'X4-112 JQ]_D=3933' ' 9996' —4-1rtHES XIE:D=3313' IOP OF T LFR — 101814' 10021' 7'SEAL ASSET LY.D=? • 7-1W3.261.L-e0.A303 bpl.D=0_270" - 10025' 9-S0'CSO.471#L-e0.0=&M1" H 111515' A 4-ir2- WHI S70CK(7/XDOCDOc —I 11009' T I<LOU7 WFDOW(11-.iA)11091-11099' 7'LFII.290 L-e0._0371 bpl.D=6184' — -11009 11 ser H4-1rt WFTcaw(Dan 4A5) 4-1/2'MIME ILUG 11100' /f PERFORATDN SIlINNARY REF LOG ? ANGLE AT1DP PERF_89'42 11653 Rolm Reierb Wad.dsl.DB for bidookal pen dub SIZE SPF INTERVAL ORIISAZ SNOT SOZ 3.3I8' 6 11655-11715 0 0811415 2-3F4' 4 11120-11960 C 05114(98 2-314' 4 12020-12090 C 05114/98 2-3A4' 4 12150-12240 C 05114198 PB7D 12(3T ��1�1�#�i 4-1f2'LFR 1265.L-30.0152 bpl.D= —I 12518' DATE REV BY CEMENTS DATE REV BY COMBOS PRUDHOE BAY IMT (604(71 NUE MORAL COMPLETION 0228115 AIME)SET C1 IYADPERFS(08114115) WELL- 0-06A 921299 0-i5 SIDETRACK(01-116K) miaow No:1980900 10(31113 l00 ] SET T%WPM(101191137 AIME 50-029-20346-01 17111113 STH PJC SET UPPER PPR(11A1113) SEC 16,711N,R13E 379'FAL&62T FEL 12/04113 DGBIJN T PRIES CORRECTED TD OPEN 04111114 DOWNED CORRECTED 9-5I0CSG DEPTH M Eqoloralion 2 i • TREE= 6x7CW 1NELLHEAD= NNE OY Q-06 Post IA Cement SAFETYNOTES:WELL'AUX 70' 11218. ACTIAATDR= BARER C ONB-ELEV= 69_62' REF MEV= SOU BF HEY= 40_59' —I-roc Nm IU]P= 2399' 0 N ix AsOe= 94' 12311' 203w —9.510'FOC O IO= 11116' D■InieTVD= 8800'SS C ^--^ 2587' '•••19-511r DY PIOt 13-316'CSG.72#.1-34.0=12347- — 24181W • J I i ail = 3J13" 9996' S Z4 ^ 6679935.991981. 91'-6718'—1 7 ww ez r o=395'(1181113] 4-112"HES X NPPLE - • �'� R' (O�O�'� 101'OF 4-V LFR - j 98911 98% H 5.01CR C-21 k SLV wf FNC H6IZ I]=4-435 ■ H 991 �5'x41LtJ�D=3938' i 9996• � -v2'IB xF�u=3013' 1CPOF7'111ft —j 10901' H 1082• —17SEM_ASSEMBLY.o=? 7 TSG.201E L-50.-0303 bpi.o=6276' — 10025• 9-511'CSG,4711.L-80.0=&M" -j 10515' J • 4-112' WI-U 10GKpOCwOCDOc [ I 111111 7 LW LOUT WINDOW(M- A)11081-11089' 7-Ink 2911:L-as. 371 bpi.1)=62184- —I —11080 „:..' I-14-111 WFT CBP(01014f15) 4-1ft IIFIIDGE RUG 11100' J PEIiFORATDN SUMMARY or\ REF LOLL AIME AT TOP PERF_er Ifa 1156.8 Nom Reterti 14odxdom DB for pert dais SRE SPF NTERVAL OHYSOZ SHOT S41Z 3-3111" 6 11855-11715 O 08/14116 2-3W 4 11820-11960 C 05/14195 2-3/4' 4 12020-12090 C 06/14191 2-3F4' 4 12150-12240 C 01/14190 FBlD I— 12437' N41.1.` 4-1121 W.12.61E L-00.0152 bpf.D=3-9521' — 12518' 141E REV BY COINENTS DATE REV BY COMMENTS PRINNIK E BAY UNIT 01/24/71 NESE NMUIALCOMLENION 08128115 ALWJN)SET C ADPERFS(09114115) 1NEIL- 0-06A 46/16135 I1-16 SNIETRACX(Q-01A) PER IT No:1980900 10131/13 RWJND SET T MMFD 19Ut(10/19113) All No: 50-029-20346-01 11111113 STN PJC SET UPPER PIER(11/U13) SEC 160 T1111,R13E,379'FIE&623'FEL 12104113 DGB/JIO PERES CORRECTED TD OPEN 04111/14 OGB/AO CORRECTED 9-516'CSG DERR W Explorr 3 • • • TREE= 6X7CW $IAD= M3'VDY Q-06 Proposed P&A 107E S:WELL ANGLE>71'a1121$'. ACTUATOR= BAKER C ORB REV= 69..62' B- = 40.5B 1' Cement Plug#3 Circulated Down tubing,through a2399' 111® a ' tubing punches @ 500' MD and up IA to surface MaxlAad= 94' 12311' Dal=ND= 11146 DalmolVD= 8800'SS — '41 Cement Plug#2 circulated down tubing,through perforations(a7—1800' MD and up OA to surface. 13-as-CSG.17#IL-811.13=1234r - 2686' 6697-671$'- r WFD ER Hato=3.98'(11/04,13) Pil�u� t= 31113" 9996' 172 ! 4112"HES X NIPPLE °i • 3'- " MMHG R.1110-1(99105113) ' (°9105113) I Cement Plug#1 pumped FB or laid in w/CT mP aF 4-1/2"11111 9896' fF. 9910' -5'x4-uraaD.o=3s3a' 9996' -�4-112"FES MN'.D=3_1113' 10F of r H 10004' - 10021' I-r SEAL nssaar.o=? r MG.calk.L-80..0383 bpf,D=BSlB' H 10025' 1♦ �f � 5519'CSG,47$L-210.D=aABY - 10515' 4-1r2' Wl-U IDcK p0UNKI OC l l 11009' r xa i OUT WFODW(D-aawl11091-11019' r LFII 291k.L-ao./0371 spt.o=0.194' -11009 111$$' [H"-" -v rcaeu(09n4noj 4-117 U X3E R1JG 11100' FERFORATUN SUI■PARY REF LOQ ? AIGLE ATTDP FERE 19'1/11655 Holm Reierb Radado-DB for ilslblral pert dds 111111111111111\ SQE SPF I69RVAL OI1ISQZ SHOT 501 jr 3391' 6 11655-11715 O 0611415 2-3W 4 11620-11960 C 05114196 2-3W 4 12'020-12090 C 051149$ 2314• 4 12150-12240 C 051149$ 4� FRID I- 12437' i� , Nees.► 4-1Ft 1261F L-ao.2152 bpf.o=3_953' H 12515 DATE REV BY 03I11113ITS DATE NEN BY CDI■EN TS PRUDHOE BAY UNIT 1112W71 NIOE IU11ALCO'LEHON 0$21115 AHEM SET CNIYADPERFS(0$114115) 'ALL- 0-06A 860268 0-11 SNIE7RACK(81-$5A) PENINTNo 19$0900 10131113 PINAM SET T WFD ROR(10119113) AR Noy 50-029-20346-01 11111113 SIF!PJC SET UPPER Rot(11/0413) SEC 16,Till,R13E,379'RR.3 623'FEL 12104113 DERVAI]R77PSS CORRECTED TO OP91 04111114 DME)CORRECTED 9-511<'CSG D9■IH BP Exploration(Masks) 4 • S vha Q-06 • K2 -A-IA OA 00A f--OOOA a.rjrlt On i••••••••••••=••••••••••wru .a.-c it6'3'5: 5•'=, 1115 pt 7.n£ ::2,"£ 2.323'£ 252355 x24'5. Cement Calculations IA fillup volume to 500' MD 243 bbls Total cement to pump 244 bbls Key Parameters Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc Compressive Strength: 2000 psi in 48 hrs. Thickening Time: Minimum 7 hours Cement thickening time: Mix on the fly Activity Time(hours) Shearing time,quality control, PJSM 0 Cement displacement 5 Cement contamination 1 Safety 1 Minimum required thickening time: 7 5 • Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 1400 2:00 130 1400 3:00 110 200 4:00 80 200 7:00 60 200 15:00 50 200 Volumes: top volume MD bot MD Size ID bbls/ft. Ft. bbls 7"tbg 0 8000 7"26# 6.276" 0.0383 9896 379 9-5/8"47#x 9-5/8" x 7"annulus 0 9990 7" 26# 8.681" 0.0256 9990 256 6 • Eline w/ Fulibore Notes: • The objective of the gyro is to obtain a new directional survey for Q-06. This is required for the upcoming 'B' sidetrack. • The elevation of the Base flange is 39.21' (based on subsidence study in 2014 and updated As-built). See pictures of reference point below. Use this elevation to correct to RKB. • Survey should be corrected to the Q-06 RKB of 69.62'. • Tubing pressure is expected to be -2500 psi during SI. Fullbore will need to load the well prior to performing the Gyro. Gyro Procedure 1. Load TBG with -485 bbls (1.2x tubing volume) of crude to top pert. Pump at max rate, -7 bpm, not to exceed 2500 psi. 2. Using the elevation of the Base flange (shown below), correct tool zero to reference elevation. 3. Run gyro in PDC mode from surface to deviation at -11,288' MD. Pluq & Perf Procedure 1. Set 4-1/2" CBP @ 9975' MD (middle of first full joint of tubing above the X- nipple). 2. Perforate through 4-1/2" tubing and 7" tubing. 10' of HES 2.5" BH charges 0- deg phased charges from 9950' -9960' MD (across the top collar of the first full joint of tubing above the X-nipple). 3. Using Diesel or Methanol, CMIT TxIA to 3500 psi to verify CBP will hold cement hydrostatic pressures. Note: 7" tubing is derated due to pitting (burst -2600 psi, collapse -1950 psi) thus this step must be performed with the Tubing and IA pressure equalized. 4. Pump down tubing and take returns up IA for 5-10 bbls to verify a clear circulation path (this verifies the perforations through both strings are ample, and that circulation through the seal-tite placed @ -2000' MD is feasible). Max pressure 2500 psi. 5. Set 4-1/2" HES Composite Fasdrill SVB Cement Retainer @ 9935' MD (middle of the second full joint of tubing above the X-nipple). Note: All depths reference attached tubing tally of 02/08/1979. 7 • • • Coiled Tubing 1. Rig up a micromotion to IA returns. This will help determine if the PC leak is drinking any cement and track the cement top in the IA. PT CT connector & CT to -4800 psi in anticipation of high circulating pressures towards the end of the cement job. Note: usually pressures do not get higher than 4000 psi during IA cement jobs, but they have in isolated cases so best to be prepared. 2. Have a way to divert the FW spacer (ahead of the cement) upstream of the CT so that nothing but cement or diesel goes into the IA). 3. RIH with HES Fasdrill SVB cement retainer stinger. Displace CT x TBG backside to heated 160F 9.8 ppg brine while RIH. This will help minimize the hydrostatic pressure difference between the Tbg and IA while cement is pumped up the IA. 4. Rig up a pump to bump up the CT x TBG backside pressure while pumping cement. Use the following schedule to keep the collapse (& burst) differential pressure between the tbg and IA to <1300 psi throughout the tubing string and throughout the job: ➢ Lead of cement slurry enters IA: 0 psi on CT x TBG backside ➢ 100 bbls of cement into IA: 0 psi on CT x TBG backside ➢ 150 bbls of cement into IA: 300 psi on CT x TBG backside ➢ 200 bbls of cement into IA: 800 psi on CT x TBG backside ➢ 243 bbls of cement into IA: 800 psi on CT x TBG backside 5. Sting into retainer and establish diesel circulation down CT and up IA to tanks. Verify coil backside is SI. Pump the following fluid schedule. Note: Do not pump any freezable fluids through retainer into the IA as these fluids will remain in the IA @ -500' MD after the cement job. ➢ *260 bbls of heated diesel (160F) ➢ Minimal FW spacer (divert this upstream of the CT so that nothing but diesel or cement goes into the IA) ➢ 244 bbls cement per design ➢ CT volume of FW (unsting from retainer w/ last 1-2 bbls of cement in CT) *Note: There are two reasons for the heating the diesel: 1. The cement in the IA acts as an extended packer. Tubing movement models indicate that heating the entire wellbore to -140F before setting a packer on a rig is the optimum temperature for locking the tubing in place in PBU (prevents buckling when the tubing is heated up via producing or injecting). Heating the entire wellbore for this type of job to 160F will approximate this (wellbore fluids will cool before cement sets). 2. Heating the entire wellbore helps the cement to cure. There have been a couple of IA cement jobs where fluids were not heated prior to cementing and the cement took much longer to cure. In one case it took about 2 weeks before the well would pass an MITIA. 8 • • Coil(cont'd 6. This should put the TOC in the IA @ —500' MD. Keep track of returns from the IA to track the TOC in the IA. In order to keep a rate of—1 bpm be prepared for CT pressures to be over 4000 psi towards the end of the cement job (when water is displacing cement out the CT). See Coil Contingency Procedure#1 below if cement locks up while pumping into the IA. 7. While maintaining Tubing x CT backside pressure (per above schedule this will be 800 psi), unsting from cement retainer w/<1 bbl of cement still in the CT and lay remainder of cement in 1:1 on top of cement retainer. Monitor CT x TBG pressure closely as the stinger is pulled out to ensure retainer seals. If it does not seal, the backside pressure should jump to—2300 psi. If this happens, leave the 2300 psi on the backside for the remainder of the job to keep cement in the IA in place. 8. With the same pressure (800 psi or more; depending on the retainer sealing) trapped on the CT X TBG backside, POOH pumping only CT displacement down the CTxTBG backside. This can be achieved by POOH and pumping just enough down the backside to maintain whatever pressure the CT X TBG backside equalized at in the first place and verifying that for every 100' of CT pulled —0.3 bbls of fluid are pumped into the well, but if there is any question err on the side of pumping more fluid into the well, not less. Also verify upon reaching surface that—30 bbls of fluid total have been pumped into the well since leaving bottom. 9. Leave the well with 500 psi trapped WHP (Bleed WHP from 800 to 500 psi or if retainer did not seal hold —2300 psi). This will keep the derated 7"tubing from collapsing while the cement cures. Freeze protect CT with MEOH/water as needed with the well SI. Cod Procedure Contingency#1: If at some point cement locks up and cannot be pumped into the IA then hold whatever CT x TBG backside pressure has been already established, cut cement at surface, pull out of the retainer and lay cement in the tubing 1:1 maintaining CT x TBG backside pressure. Reverse the remaining cement out of the tubing. Furore 1. Wait on Cement at least 5 days 2. MIT-IA to 2500 psi. 3. MITT to 2500 psi. 9 • • Coil 1. MU 3.80" OD junk mill. RIH and tag TOC (expected —4700' MD). 2. Mill through cement, retainer, cement and the CBP. 3. Mill/Push CBP remnants down to 11,800' MD (to the top of CIBP). Note that the CTD sidetrack will kick off at—11,090' MD. Slickline 1. Run SCMT log from tubing tail to surface to find TOC and relative bond. Integrity Engineer 1. Add Quadrennial (every four years) MITTs and MITIAs to Anncomm. 10 410 \\ • GA6=1.p SUMMARY "1 " " PIPE WELL CI-( DATE _Di.- la-19 RIG .1%4• Q✓s IA K.B. met LO ' ABOVE MAT . ' 2-40 JTS. ON RACK 9...44, '"- JTS. RAN lS'' JTS. OUT FT. ON RACK FT. RAN FT. OUT LAST CASING STRING: " @ I. CASING & CEMENTING EQUIPMENT DETAIL FROM BOTTOM UP: (T.D. to K.B.) ITEM LENGTH DEPTH JT.NOS. DESCRIPTION 1_ "i" fir. bei ?.O.Sb'." ' TOP @ t0060,,4..' . . .. -. %$4,- i 3. -t" il+ ` • ' TOP @ .ta quo 9. ' Y ' 1» •.._ t . +} ' TOP @ ].c07..t..1* ' 1.�t�1 ' °.. Co,....?.`46,.. • , it it m ,/s-- ' TOP @ 34,301. ' ' t- ckit..l ' TOP @ r 4- 1.L ..„ 3_,"1,;[ ' TOP @ ' -76 t t't+ \ ire ' TOP @ ' ' TOP @ ' ' TOP @ ' ' T O P @ it ' TOP@ ' . . . ' TOP @ ' TOP @ ' , ' TOP @ ' ' TOP @ ' ' TOP @ ' Total Pipe on Hook ' 7.4 --. Jts. Leas Ft. Up - ' (Above KB) Shoe Depth A 4 NO, -OF CENTRALIZERS PLACED AT ..41/t,...1.3 OIL tt 4114, Yi1/, �--�� AND S t NO. OF LACED AT A. d� �.v . Q At. 0t+. ✓t STARTED RUNNING AT 0100 HRS., ON BOTTOM AT ..w'1, HRS. STRING WEIGHT ON BOTTOM Wb)ttv Q LBS. • COMMENTS: $t 11 • • Carlisle, Samantha J (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, August 03, 2016 1:57 PM To: Carlisle, Samantha J (DOA) Subject: FW: BP IA Cement Sundries From: Loepp, Victoria T(DOA) Sent: Tuesday, August 02, 2016 1:44 PM To: Ryan.daniel(abp.com Subject: BP IA Cement Sundries Ryan, The following sundries for IA cementing have been submitted by BP for approval. This work requires waivers from our existing regulations. Specifically,for the production wells 20 AAC 25.200(d) requires that all producing wells be completed with suitable tubing and a packer. And for the injection wells 20AAC25.412(a) requires the well be completed with tubing and a packer and that the packer be placed with 200 ft measured depth above the perforated injection interval unless the AOGCC approves an alternate design or packer setting depth. The AOGCC is viewing your proposed work as making the existing tubing a casing string since almost the entire annulus would now be filled with cement. Therefore,the AOGCC believes the best approach is to establish pool rules that outline the criteria for when and how these types of completions can be used. We will not be approving these sundries. We recommend that BP make a request for modification to the respective Conservation Orders and Area Injection Orders and proceed through this public process. PTD Sundry Sundry Sundry PBU PTM P1-21 193-059 316-375 316-371 316-264 PBU B-31 191-046 316-399 316-368 316-270 PBU M-13A 201-165 316-376 316-369 316-259 PBU Q-06A 198-090 316-372 316-370 316-233 PBU E-07A 201-034 316-380 316-288 Regards, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a)alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loecv@alaska.gov 1 STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIO 1. Operations Performed Abandon ❑ Plug Perforations Lf Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ S Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: S C7 G°1 BP 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number:'198-090 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: • 50-029-20346-01-00 7. Property Designation(Lease Number): ADL 0028281, 8. Well Name and Number: • PBU Q-06A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL • 11.Present Well Condition Summary: RECEIVED Total Depth: measured • 12521 feet Plugs measured 11800 feet I n 9 true vertical • 9027 feet Junk measured feet SEP 0 2015 Effective Depth: measured 11800 feet Packer measured 10024 feet true vertical 9032 feet Packer true vertical 8023 feet O3 C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 30-110 30-110 0 0 Surface 2657 13-3/8"72#L-80 29-2687 29-2676 4930 2670 Intermediate 10487 9-5/8"47#L-80 28-10515 28-8374 6870 4760 Production Liner 2622 4-1/2"12.6#L-80 9898-12520 7932-9027 8430 7500 Liner 1094 7"29#L-80 9999-11093 8005-8827 8160 7020 Perforation Depth: Measured depth: 11655-11715 feet 11820-11960 feet 12020-12090 feet 12150-12240 feet True vertical depth: 9031 -9032 feet 9032-9035 feet 9036-9037 feet 9039-9041 feet Tubing(size,grade,measured and true vertical depth) 7"26#L-80 26-10020 26-8020 Packers and SSSV(type,measured and 7"BOT Packer 10024 8023 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: if CO . '. L�i el 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 458 42995 182 0 1915 Subsequent to operation: Shut-In 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory 0 Development m • 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: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ye e?...-1-41, Phone +1 907 564 4424 Date 9/8/15 Form 10-404 Revised 5/2015 (/ / l— //1 ii 44> RI3DMS�4.) SEP 11 2015 Submit Original Only 0 • \_ c co � aCO ,_ O c�\ � \ g = o / \ ± -o $ < f L.,_ -.a. /\ 13 0 m o 6 g O o 0- Cr) ƒ / �» 15_ a_ b - ' EE ƒ co \ 1-- on a m / % w b $ ® / 4t 13 ct / U / ( c 2 = 2 2It0- sa t277 ti � � \ ■ \ k± oc a) ,=, ± C 3 = O E o = ® H o » / < E m .» < e . x a m q = o m * & E E e co < o I & / o)2 / r 6 =E CL CD 0. 2 Es -60 \.cC co ill R \ ° < ' E £ \ / R / � - \ $ ° o - _ e E O / 6 0 /b C r.0 .-§ a u_ 4- & f / ® % o + -B 0 m # c o _ 2 / / o 2 / / \ c 7 % p - Ti) / - / E U A i / ® 0 k / /\ k0 � ? / E IX H 0R � o o / g . : c >+ ƒ m a E\ / O ± a o U al I / N c _ ® R_ \ _� CD ) 0 D 0 k t Cr)% . oma : / i 0 « \ \ t _ \ \ $ ± G 2 G G - o o . \ b = Rea / _1 » I o » b I A — e w - Ect & 2 0 O &`- » 0 \ & . f a o co 1:n0 , ,-,, _,, ...., 0 , ,, [0 .,,,,•- co U y k g # » R o b I # .g a '- ° ,- _ s / / / / » ƒ k f § U 2 t O a 0 2 - 0 0 - ƒ 0 o 7 0 2 H r co r d \ . cn- >- A m .1- ‘-- $ G \ / \ / < TREE.4. 6x7aw VVE11-EAD= It W EVOY Q-06A SA.NOTES: WELL ANGLE>70°@ 11288'. ACTUATOR= BAKE C iiinAL KB.ap, 69.62' BF.B_EV= 40.59' KOP= 23990 2026 —7'OTE SSSV LANDNG MP,D=5.962" Max Angle= 94°a! 12311', Datum AM= 11146' — ....., 2038' H9-5/8"FOC I:Worn-ND= 8800'SS _ ,..— ,-- 258T —9-5/O°IN F4(1,2 L 13-3/8"CSG,72#,L-80,13=12,347" H 2686' A Minimum ID = 3.813" @ 9996' 2C X *91'-6718' —7"WFD ER FKR ID=3.95"(11/04/13) 0 0 6713--6714* HTUBNG PUNCH(09/05/13) 4-1/2" HES X NIPPLE Z Z TOP OF 4-1/2"LM1R — 9696' ' 9896' —15"BKR G-2 TEBK SLV w/HNC HGR,0=4,438 i 9910' H5-X 4-1/2"X0,D=3.93r 1 II 9996' H4-1/2-HES X NP,ID=3,813" TOP OF 7"LNR — 10004' 1 10021' IHr SEAL ASSEMBLY,ID=? 7"TBG,26#,L-80,.0382 bpi,0=6.276" — 10026' 9-5/8"CSG,47#,L-80,ID=8.681" H 10515' a L 4-1/2" WHPSTOCK(XX/)O/XX —( 11089' r ItALLOUT WINDOW(Q-06A)11091-11099. 7'LN ,29#,L-80,0.0371 bpf,0°6.184" — ^11089 11800' —4-1/2"WFT GBP(08/14/15) N 4-1/2"BRIDGE PLUG H 111W _ Jr PERFORATION SUMWkRY NO REF LOG 7 ANGLE AT TOP FEW:89°@ 11655' Note:Refer to Production DB for historical pert data SIZE SFr NIBRVAL OPNISQZ SHOT SOZ I 12437' 4 3-3/8" 6 11655- 11715 0 08/14/15 2-3/4" 4 11820- 11960 C 05/14/98 2-3/4" 4 12020-12090 C 05/14/98 2-3/4" 4 12150-12240 C 05/14/98 _ _ _ TD 7 P8 \4144 lt, `filmes. 4-1/2"LMR, 12.6#,L-80,.0152 bpi,ID=3.953" —1 1251W DATE , REV BY CO/MEWS DATE REV BY COPMENTS PRUDHOE BAY LHT 06/24/79 N18E INITIAL COMPLETION 08/28/15 A LANJMD SET C1314ADFERFS(08/14/15) WE3_L: O-06A 05/16/98 D-16 SIDETRACK(Q-06A) PERANTI•ky 1980900 . , 10/31/13 RIV/Jkl) SET 7-'NFD PKR(10/19/13) AR No. 50-029-20346-01 11/11/13 S7F/PJC SET UPPER FKR(11/4/13) SEC 16,111N,R13E,379'FM_&623'FEL 12/04/13 DGB/JAND FERFS CORRECTED TO OFEN 04/11/14 CGB/J1013 ODRREC7H)9-5/8"CSG DEPTH BP Exploration(Alaska) 0 cr O til LJ.J � r 0 0 '- a- '- N - - a- a- I- e- onU - G cJ Y O Q ra QS oar j .. a, a, 0 a) _c O O Z (w w 1— >. 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F,,e Number o, We,,H,sto F"e PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA D Diskettes, No. n Other, No/Type OVERSIZED D Logs of various kinds ~ Other COMMENTS: Scanned bY:~ildmd Daretha Nathan Lowell [3 TO RE-SCAN Notes: STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMML_iON DEC 0 6 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Repair Well U . Plug Perforations ❑ Perforate ❑ Other❑ ' eCGCC Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time ExtensionD Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Welt] 2.Operator '4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development 0 Exploratory ❑ 198-090-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20346-01-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028281 • PBU Q-06A • 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 12521 feet Plugs measured None feet true vertical 9026.67 feet Junk measured None feet Effective Depth measured 10172 feet Packer measured None feet true vertical 8129.07 feet true vertical None feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 28-108 28-108 0 0 Surface 2658 13-3/8"72#L-80 27-2685 27-2674.7 4930 2670 Intermediate None None None None None None Production 10487 9-5/8"47#L-80 27-10514 27-8373.78 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11820-11960 feet 12020-12090 feet 12150-12240 feet True Vertical depth 9032.1-9035.05 feet 9035.93-9037.17 feet 9039.23-9041.26 feet Tubing(size,grade,measured and true vertical depth) 7"26#L-80 25-10019 25-8019.53 •rye Packers and SSSV(type,measured and true vertical depth) None None None Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JAN 2 t` 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: 735 32490 348 0 1275 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El ' Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0. Gas U WDSPLI GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-301 Contact Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE _ Signature C 1 �ea: /tL Phone 564-4424 Date 12/5/2013 VL ' RB MS DEC 16 20 Form 10-404 Revised 10/2012 Offer Submit Original Only d - - a 0 0 o 0 0 0 FN O CN-Or- � ) O O c0 s I,- r` LO ' N 1.[) C.) 000000 MCOOr- M � O CO O N m 00 00 t!7 CO r- CO N M 00 r O CO cJNI- M r, N N O) r- v- O co co co O O CA co LO 00 N CO lllll CO 00 p Op O r- IC) N c)'O O N N N CO 4-11 r- co 0 C . c0 Tr 0) co — (A N ' co o N N CU r r r r N M a) N N co 8 N. N N N C Q O � J Q L O O _1 000 U 'I 00 d M CEO - X N J •C N O ' N - 00 N U N �y - lL M - U N. _ O co vr t 0)O N 00 N 10 0)) O d co N 0 N 0 0) ' J � Z O (0 = 0QC� VOCeCeVOriZ O Z Z < c D D U M =I 0- 0- C/) F- CB p _ O a) co Q O ()) ` U) co �l in 0 ° d - V N O _ D �o o c o ° E d O Q o ui p ° a a l Q 0i O c 1-2 -c 02 U o Cl) s? 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E \ _ _ 0 �_ / Hof 5 � . _ # /_ « � / / - \ 2 / 0 o b ee - � ta / 'EAU $ cn / m ± o / • p 5R E ƒ \ / 2 \ ) � © � a / CO CO 0 \ \ c \ CD e k $ 2 co < O 0) k = 'Cr / / \ _ Z 0 / } £ U ƒ .7 - a 0 0 0 _ _ ? CL 2 e 2 ± e e o e I . c 'E ± / z % § _f d o / co \ 2 ƒ \ \ 2 \ E f 2 \ \ / / § \ 1 & / E £ 2 i c g / / 2 ® ^ c c / > / 0 %— Cl) % � I > .--: f « H E m » /_ $ O ¥ ® 0 - A < 0 CO 0 2 \ Z E \ \ / ƒ co / > C 0 in 2 b ± / 0 E • . • I ii 0 k 4- o \ / \ 0 R 5 / \I < g ± ee0 7 / / / % C) - I I O i E \ % O ^ a ® - H > / m < o E i c - 2 W \ \ � / • 0 < . p\ � 05 . Ce 3 a � .7 a 9 7 % - m a E a " \ -",-n-$ 1 I o = 0- 4 �� ' �� L m $ > E/ m o 0 E c\ / ao = TD- (xi % / / @ J 3 % $ % � / o $ E \ F— 1:0 R6mI \ . 0 ® oo / 0 / / -0 0 k $ � / \ � \ k / ) \ 0•� ® Al k E 0 \ \ 0) 0 , \ CI p\ Pi o \ § 2 & o w " / CO g / o / " k$ " u) -c k $ $ / s 2 C e § \ 0 / w O = o -c 00 0 @ 0 w e -, - o > - 0 '- - - _ >. A o 0 0 co < t 6 a W 6 1 2 4 m A R 2 r r n r r \ \ / _/ / ( CD-0 / CD \/ / ,TTY= 6X7CIW WaLFEAD= McEVOY Q_0 6A SAFETY NOTES: WELL ANGLE>70°@ 11288'. ACTUATOR= BAKER M1AL KB.ELEb 69.67 BF.ELEV= 40.59' - - I 2026' —17'OTIS SSSV LANDING NIP,D=5.962" KOP= 2399' O Max Angle= 94°@ 12311' Datum MD= 11146' - 2038' H9-5/8"FOC Datum TVD= 8800'SS ■ AMAIN IN■I 2587' H9-5/8"DV PKR 13-3/8"CSG,72#,L-80,D=12.347" H 2686' I 11, 6691' 6718' -WFD ER PKR 0=3.95"(11/04/13) I Minimum ID = 3.813" @ 9996' ►! 4-1/2" HES X NIPPLE ' 6713'-6714' -ITWNG PUNCH(09/05/13) TOP OF 4-1/2"LM H 9896' 9896' —i5"BKR C-2 TEBK SLV w/I-MC I-1GR ID=4.438] ■ 9910' —I5"X 4-1/2"XO,D=3.938" ' li r 9996' H4-1/2"HES X NP,ID=3.813" TOP OF 7"LNR — 10004' f 10021' —I 7"SEAL ASSEMBLY,D=? l 7"TBG,26#,L-80,.0382 bpf,D=6.276" H 10025' 9-5/8"CSG,47#,L-80,D=8.68r — —11089 4-1/2" WHPSTOCK(XX/XX/XX H 11089' 7"MLLOUT WINDOW(Q-06A)11091-11099' 7"LNR 29#,L-80,0.0371 bpf,ID=6.184" —I —11089 4-1/2"BRIDGE PLUG ] 11100' ` PERFORATION SUMMARY ` REF LOG: 7 ANGLE AT TOP FERF:90°@ 11820' Note: Refer to Production DB for historical perf data SIZE SPF NT RVAL OPWSQZ SHOT SQZ 2-3/4' 4 11820-11960 0 05/14/98 2-3/4' 4 12020-12090 0 05/14/98 2-3/4" 4 12150-12240 O 05/14/98 PSTD H 12437' 411414 4-1/2"LW,12.6#,L-80,.0152 bpf,ID=3.953" H 12518' DATE REV BY COMMENTS DATE REV BY COMMENTS FRLDHOE BAY MIT 06/24/79 N18E INITIAL COMPLETION 09/12/13 JCM/JMD TBG PUNCH(09/05/13) WELL: Q-06A 05/16/98 D-16 SIDETRACK(Q-06A) 10/31/13 MAID SET 7"WFDPKR(10/19/13) PERMf Nu: 1980900 03/14/01 SIS-Isl CONVERTED TO CANVAS 11/11/13 STF/PJC SET UPPER PKR(11/4/13) API No: 50-029-20346-01 03/15/01 SIS-MD FINAL 12/04/13 DGB/JMD PEWS CORRECTED TO OPEN SEC 16,T11 N,R13E,379'FM_&623'EEL 02/11/02 RN/TP CORRECTIONS 04/13/13 SV /JMD PULLED PX/SET WRP(04/03/13) BP Exploration(Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 March 31, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 9' Subject: Corrosion Inhibitor Treatments of GPB Pad Q Dear Mr. Maunder, • by APR (7 7 201(1 ' ®N8 ~ ~'ot~. lmssaa~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad Q 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, F , ; ,~~+, ~~ ~ ~, '~ ~~~ ~~:~v 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) Date: 03!31/10 Well Name PTD # API # Initial top 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 Q-O1A 1971260 50029203010100 0.1 NA 0.1 NA 1.70 3/10/2010 Q-02A 1971470 50029203330100 0.2 NA 0.2 NA 1.70 3/10/2010 Q-03A 1972540 50029203220100 0.1 NA 0.1 NA 1.70 3/10/2010 Q-046 2091010 50029203400200 1 NA 1 NA 3.40 3/10/2010 Q-05B 2071560 50029203440200 0.5 NA 0.5 NA 3.40 3/9/2010 A 1980900 50029203460100 0.2 NA 0.2 NA 1.70 3/9!2010 Q-07B 2031570 50029203520200 0.7 NA 0.7 NA 3.40 3/9/2010 Well Compliance Report File on Left side of folder 198-090-0 PRUDHOE BAY UNIT Q-06A 50- 029-20346-01 BP EXPLORATION MD 12521-~ ~IVD 09027 tion Date: 5/15/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8736 ~' SPERRyGR~EWR~J~i~3)'S'Li~ ................................ 0'H ...................................... i'i')'i"i);8 ...... 1'1i'i'2)98 ......................................................... L DGR/CNP/SLD-MD ~ 11107-12521 OH 11/18/98 11/18/98 L DGR/CNP/SLD-TVD ,-L~4 ' 8830-9027 OH 11/18/98 11/18/98 L DGR/EWR4-MD &_~-~4 11107-12521 OH 11/18/98 11/18/98 L DGR/EWR4-TVD ~ 8839-9027 OH 11/18/98 11/18/98 R SRVY RPT .~~10998.57-12521. OH 7/1/98 7/5/98 Daily Well Ops .)/~?//q~ -- 5'//~}/?~ Are Dry Ditch Samples Required? yes ~ ~And Was the ,veil cored? yes ~. Analysis Description ~ ~; Set # Comments: Monday, May 01, 2000 Page 1 of 1 n I::! I L_I_I N G SE~/I r' ES S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Cr~ Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 November 18, 1998 RE: MWD Formation Evaluation Logs - Q-O6A, AK-MW-80218 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way,/tG, Anchorage, AK 99518 Q-06A: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-20346-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-20346-01 2"x 5" MD Neutron & Density Logs: 50-029-20346-01 2"x 5" TVD Neutron & Density Logs: 50-029-20346-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company ~ I=! I I_,L_, I ~,1 !~ SEFIL/I r' E S WELL LOG TRANSMITT ~AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs Q-06A, November 11, 1998 AK-MW-80218 1 LDWG formatted Disc with verification listing. API#: 50-029-20346-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMITYAL LE'ITER TO THE AITENTION OF: Sperry-Sun Drilling Services Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 · ~ :.. -,:,..~ ~ : .... ~ 7 ':.--"~ ~ ~ BP Exploration (Alaska) Inc. Petro-technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Signed~ ' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company STATE OF ALASKA ALASK~OIL AND GAS CONSERVATION coMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service ~ Oil [~ Gas ~l Suspended [--I Abandoned ~ Service~';(;-."~0.-.'-~r:.~" ~' ' "~' ~'~"~' .... '~: 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 98-90 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20346-01 4. Location of well at surface i L;r.;;,7?LF!';i3;'i ~ 9. Unit or Lease Name 378' SNL' 624' WEL' SEC' 16' T11N' R13E' UM i '~AT~ '~'I !:~ Prudhoe Bay Unit At top of productive interval i ....... . 10. Well Number ~ 1725'¢.~1~,L, 4978' EWL, SEC. 10, T11N, R13E, UM i v~-'ai~ ':' Q-06A At tOtfil ~l~pth ..... '~-~-~--~'i' ~ 11. Field and Pool '~ 2708',.~l~_, 4885' EWL, SEC. 10, T11 N, R13E Prudhoe Bay Field / Prudhoe Bay 5. Elevat~Wffn feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 68.19'I ADL 028281 12. Date Spudded5/7/98 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Abandl 15' Water depth' if °fish°re I 16' N°' °f C°mpleti°ns5/11/98 5/15/98 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+-I-VD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12521 9027 FTI 12434 9032 FTI [~Yes r-lNo1 (Nipple) 2026' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, MIR, NEU, DEN, RES 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 30" x 20" Insulated Conductor Surface 110' 36" 607 cu ft Arcticset 13-3/8" 72# L-80 Surface 2686' 17-1/2" 4418 cu ft Arcticset II 9-5/8" 47# L-80 Surface 10515' 12-1/4" 1514 cu ft Class 'G', 130 cu ft Arcticset 7" 29# L-80 10004' 11091' 8-1/2" 480 cuft Class 'G' 4-1/2" 12.6# L-80 9896' 12518' 5-7/8" 336 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/4" Gun Diameter, 4 spf 7", 26#, L-80 10004' None MD TVD MD TVD 11820' - 11960' 9032' - 9035' 12020' - 12090' 9036' - 9037' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 12150' - 12240' 9039' - 9041' DEPTH INTERVAL (MD) AMOUNT & K~ND OF MATERIAL USED Freeze Protect with 85 Bbls of Diesel 27. PRODUCTION TEST i , J Date First Production I Method of Operation (Flowing, gas lift, etc.) May 28, 1998 I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BEE GAS-MCF WATER-DEL CHOKE SiZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Marke~,;-' 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Zone 2 11530' 9016' 31. List of Attachments Summary of Daily Drilling Reports, Surveys '32. I hereby ce~ that the fo~~e and correct to the best of my knowledge ¢///~ ~/~ Signed t~~ J Title Senior Drilling Engineer Date ~- ~-06A 98-90 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No, / Approval No. ~NSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1.' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5-' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28'- If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Progress Report Facility PB Q Pad Well Q-06A Rig Doyon 16 Page 1 Date 03 June 98 Date/Time 03 May 98 04 May 98 05 May 98 06 May 98 07 May 98 08 May 98 22:30-06:00 06:00-06:30 06:30-08:00 08:00-09:30 09:30-11:00 11:00-12:00 12:00-18:00 18:00-18:30 18:30-19:30 19:30-23:00 23:00-00:30 00:30-01:30 01:30-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-12:00 12:00-13:30 13:30-18:00 18:00-18:30 18:30-21:30 21:30-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-06:00 06:00-07:30 07:30-13:30 13:30-14:00 14:00-14:30 14:30-15:00 15:00-18:00 18:00-18:30 18:30-20:00 20:00-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-10:30 10:30-11:00 11:00-14:00 14:00-14:30 14:30-18:00 18:00-18:30 18:30-20:30 20:30-21:00 21:00-06:00 06:00-15:30 15:30-15:45 15:45-16:00 16:00-17:00 17:00-18:00 18:00-18:30 Duration 7-1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr 6hr 1/2 hr lhr 3-1/2 hr 1-1/2 hr lhr lhr 2hr 1-1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 3hr 1 hr 1/2 hr 1 hr 1/2 hr 5-1/2 hr 1-1/2 hr 6 hr 1/2 hr 1/2hr 1/2 hr 3hr 1/2 hr 1-1/2 hr 8hr 1/2 hr 1-1/2 hr 1/2 hr 3hr lhr 1/2 hr 3hr 1/2 hr 3-1/2 hr 1/2 hr 2 hr 1/2 hr 9hr 9-1/2 hr 1/4 hr 1/4 hr lhr lhr 1/2 hr Activity Rig moved 95.00 % Held safety meeting Rig moved 100.00 % Fill pits with Seawater Removed Xmas tree Installed Seal assembly Rigged up BOP stack Held safety meeting Rigged up Bottom ram Tested BOP stack Installed BOP test plug assembly Tested BOP stack Retrieved BOP test plug assembly Made up BHA no. 1 Singled in drill pipe to 1500.0 ft Held safety meeting Singled in drill pipe to 5065.0 ft Rigged up Kelly Singled in drill pipe to 8445.0 ft Held safety meeting Singled in drill pipe to 10845.0 ft Serviced Block line Singled in drill pipe to 11065.0 ft Functioned downhole tools at 11112.0 ft Circulated at 11091.0 ft Milled Casing at 11091.0 ft Milled Casing at 11102.0 ft Pulled out of hole to 48.0 ft Pulled BHA Made up BHA no. 2 Installed Bore protector R.I.H. to 7500.0 ft Held safety meeting R.I.H. to 11102.0 ft '%" Milled Casing at 11106.0 ft Circulated at 11106.0 ft Pulled out of hole to 8800.0 ft Held safety meeting Pulled out of hole to 45.0 ft Pulled BHA Cleared Bell nipple Made up BHA no. 3 Tested MWD/LWD - Via string R.I.H. to 6500.0 ft Held safety meeting R.I.H. to 11043.0 ft Set tool face Drilled to 11340.0 ft Drilled to 11532.0 ft Pulled out of hole to 11101.0 ft R.I.H. to 11532.0 ft Circulated at 11532.0 ft Pulled out of hole to 9200.0 ft Held safety meeting Facility Date/Time 09 May 98 10 May 98 11 May 98 12 May 98 13 May 98 PB Q Pad 18:30-23:00 23:00-01:00 01:00-03:00 03:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:00 09:00-06:00 06:00-11:00 11:00-12:00 12:00-17:00 17:00-18:00 18:00-18:30 18:30-19:30 19:30-21:00 21:00-02:30 02:30-03:00 03:00-06:00 06:00-09:30 09:30-10:30 10:30-11:00 11:00-13:30 13:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-22:30 22:30-23:00 23:00-02:30 02:30-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-13:30 13:30-14:30 14:30-15:00 15:00-16:30 16:30-17:30 17:30-18:00 18:00-18:30 18:30-19:30 19:30-03:00 03:00-03:30 03:30-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-09:30 09:30-10:30 10:30-11:30 11:30-16:30 16:30-17:00 17:00-17:30 Duration 4-1/2 hr 2hr 2hr 3hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 21hr 5hr 1 hr 5hr lhr 1/2 hr lhr 1-1/2 hr 5-1/2 hr 1/2 hr 3hr 3-1/2 hr lhr 1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr lhr 1/2 hr 2-1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 5hr lhr 1/2 hr 1-1/2 hr lhr 1/2 hr 1/2 hr lhr 7-1/2 hr 1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1 hr lhr lhr 5hr 1/2 hr 1/2 hr Progress Report Well Q-06A Rig Doyon 16 Page Date Activity Pulled out of hole to 90.0 ft Pulled BHA Made up BHA no. 4 R.I.H. to 7200.0 ft Held safety meeting R.I.H. to 11070.0 ft Serviced Block line R.I.H. to 11532.0 ft Drilled to 12140.0 ft Drilled to 12308.0 ft Circulated at 12308.0 ft Pulled out of hole to 95.0 ft Pulled BHA Held safety meeting Pulled BHA Made up BHA no. 5 R.I.H. to 12253.0 ft Washed to 12308.0 ft Drilled to 12361.0 ft Drilled to 12521.0 ft Pulled out of hole to 11130.0 ft R.I.H. to 12521.0 ft Circulated at 12521.0 ft Pulled out of hole to 10500.0 ft Held safety meeting Laid down 905.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 189.0 ft Pulled BHA Rigged up Casing handling equipment Ran Liner to 2602.0 ft (4-1/2in OD) Installed Tubing Installed Tubing Installed Liner hanger Circulated at 2622.0 ft Ran Drillpipe in stands to 11075.0 ft Circulated at 11075.0 ft Ran Drillpipe in stands to 12521.0 ft Circulated at 12521.0 ft Mixed and pumped slurry - 60.000 bbl Displaced slurry - 80.500 bbl Functioned Downhole equipment Circulated at 12424.0 ft Pumped out of hole to 0.0 ft Retrieved B ore protector Tested BOP stack Tested All functions Tested Casing - Via string Installed B ore protector Made up DST tools - TCP guns Ran Tubing to 1700.0 ft (2-7/8in OD) Made up DST tools - Packer assembly Ran Drillpipe in stands to 12429.5 ft Set packer at 9582.0 ft with 0.0 psi Perforated 2 03 June 98 Facility Date/Time 14 May 98 PB Q Pad Progress Report Well Q-06A Rig Doyon 16 Page Date Duration Activity 17:30-19:00 19:00-20:30 20:30-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-11:00 11:00-12:00 12:00-13:00 13:00-14:00 14:00-15:00 15:00-18:00 18:00-18:30 18:30-21:00 21:00-22:00 22:00-23:00 23:00-02:30 1-1/2 hr 1-1/2 hr 8hr 1-1/2 hr 1/2 hr 2hr 2hr 1/2 hr lhr lhr lhr lhr 3hr 1/2 hr 2-1/2 hr lhr lhr 3-1/2 hr Reverse circulated at 9591.0 ft Monitor pressures Laid down 9570.0 ft of 3-1/2in OD drill pipe Laid down 2000.0 ft of Tubing Held safety meeting Laid down 1000.0 ft of Tubing Rigged down sub-surface equipment - TCP Removed DST surface equipment Ran Drillpipe in stands to 1675.0 ft Installed Block line Laid down 1675.0 ft of Drillpipe Removed Bore protector Rigged down All functions Held safety meeting Installed Xmas tree Circulated at 0.0 ft Installed Xmas tree Orientated / landed tree 3 03 June 98 RECEIVED JUN ;~ 5 I998 BPXA PDC Prudhoe Bay Unit Alaska State Plane Zone 4 PBU WOA Q Pad Q. O6A O'Ri'GiNAL SURVEY REPORT 23 June, 1998 Your Reft API-500292034601 Last Survey Date 12-May-98 Job # AKMWSO2f 8 KBE - 68.19' DRILLING SERVICES Survey Ref: svy3502 o. Prudhoe Bay Unit Measured Depth (ft) Incl. 10998.57 11091.00 11128.57 11159.53 11191.74 11223.86 11256.o2 11288.13 11320.28 11352.49 11384.73 11416.89 11449.02 11481.15 11510.38 11542.65 11574.63 11607.14 11639.17 11671.88 11701.22 11733.52 11765.44 11797.68 11829,78 11861.92 11894.22 11926.35 11958.43 11990.56 36.070 34.680 40.560 46.16o 51.990 58.070 64.290 68.260 72.250 76.040 76.020 70.420 71.o40 72.640 75.440 78.960 80.230 84.600 87.790 89.320 89.380 89.690 90.030 89.850 90.490 89.780 87.910 87.690 88.15o 89.200 79.900 80.83O 75.1o0 71.400 68.200 65.480 62.270 55.700 49.320 41.540 36.900 33.870 27.220 19.220 lO.680 5.030 1.670 1.22o 1.270 1.140 359.260 356.550 356.950 356.590 356.770 355.820 354.400 353.480 352.980 352.680 Sub-Sea Depth (ft) 8682.06 8757.43 8787.18 8809.69 8830.78 8849.19 8864.68 8877.61 8888.48 8897.29 8905.08 8914.36 8924.98 8935.00 8943.05 8950.21 8955.99 8960.28 8962.40 8963.23 8963.56 8963.82 8963.90 8963.93 8963.84 8963.76 8964.41 8965.65 8966.81 8967.55 Vertical Depth (ft) 8750.25 8825.62 8855.37 8877.88 8898.97 8917.38 8932.87 8945.8O 8956.67 8965.48 8973.27 8982.55 8993,17 9003.19 9011.24 9018.40 9024.18 9028.47 9030.59 9031.42 9031.75 9032.01 9032.09 9032.12 9032.03 9031.95 9032.60 9O33.84 9035.00 9035.74 Sperry-Sun Drilling Services Survey Report for Q-O6A Your Ref: API-500292034601 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 1847.36 N 5288.07 E 5967648.32 N 649084.71 E 5516.41 1856.32 N 5340.82 E 5967658.29 N 649137.28 E 1.613 5566.82 1861.17 N 5363.20 E 5967663.57 N 649159.57 E 18.197 5588.71 1867.33 N 5383.53 E 5967670.11 N 649179.77 E 19.856 5609.46 1875.75 N 5406.35 E 5967678.97 N 649202.42 E 19.591 5633.48 1886.12 N 5430.52 E 5967689.80 N 649226.39 E 20.158 5659.64 1898.54 N 5455.79 E 5967702.70 N 649251.42 E 21.222 5687.76 1913.69 N 5480.95 E 5967718.33 N 649276.28 E 22.438 5717.11 1932.11 N 5504.93 E 5967737.21 N 649299.90 E 22.420 5747.03 1953.85 N 5526.96 E 5967759.36 N 649321.52 E 26.039 5776.88 1978.08 N 5546.74 E 5967783.97 N 649340.83 E 13.966 5805.97 2003.16 N 5564.57 E 5967809.39 N 649358.17 E 19.609 5833.79 2029.27 N 5579.97 E 5967835.78 N 649373.07 E 19.631 5859.98 2057.30 N 5591.98 E 5967864.04 N 649384.55 E 24.174 5884.16 2084.42 N 5599.21 E 5967891.30 N 649391.26 E 29.674 5903.72 2115.58 N 5603.50 E 5967922.53 N 649394.95 E 20.258 5922.69 2146.97 N 5605.33 E 5967953.95 N 649396.18 E 11.070 5939.63 2179.18 N 5606.15 E 5967986.17 N 649396.37 E 13.512 5956.08 2211.13 N 5606.84E 5968018.12 N 649396.46 E 9.961 5972.30 2243.82 N 5607.53 E 5968050.82 N 649396.52 E 4.694 5988.87 2273.16 N 5607.63 E 5968080.16 N 649396.06 E 6.410 6003.30 2305.43 N 5606.45 E 5968112.40 N 649394.26 E 8.445 6018.04 2337.30 N 5604.64E 5968144.23 N 649391.84 E 1.645 6032.03 2369.49 N 5602.82 E 5968176.38 N 649389.41 E 1.248 6046.18 2401.53 N 5600.97 E 5968208.38 N 649386.93 E 2.071 6060.22 2433.60 N 5598.89 E 5968240.41 N 649384.24 E 3.690 6074.08 2465.78 N 5596.14 E 5968272.52 N 649380.88 E 7.269 6087.40 2497.70 N 5592.75 E 5968304.38 N 649376.87 E 2.942 6100.04 2529.54 N 5588.97 E 5968336.14 N 649372.49 E 2.117 6112.30 2561.41 N 5584.96 E 5968367.92 N 649367.87 E 3.399 6124.38 Comment Tie-on Survey Window Point Alaska State Plane Zone 4 PBU WOA Q Pad Continued... 23 June, 1998,12:16 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for Q-O6A Your Ref: API-500292034601 Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 12022.83 90.180 351.910 8967.73 9035.92 12054.99 88.740 352.040 8968.03 9036.22 12087.40 88.190 351.110 8968.90 9037.09 12119,58 88.000 350.870 8969.97 9038.16 12147.64 87.970 350.920 8970.96 9039.15 12179.77 88.370 349.650 8971.98 9040.17 12212.06 88.770 350.100 8972.79 9040.98 12244.20 90.250 349.150 8973.06 9041.25 12278.90 92.710 351.230 8972.17 9040.36 12311.13 93.900 352.600 8970.31 9038.50 12343.25 93.720 353.680 8968.17 9036.36 12375.36 93.200 353.460 8966.24 9034.43 12407.31 92.530 352.770 8964.64 9032.83 12439.46 92.430 352.700 8963.25 9031.44 12470.62 93.570 352,920 8961.62 9029.81 12521.00 93.570 352.920 8958.48 9026.67 2593.39 N 5580.63 E 5968399.81 N 649362.93 E 3.862 6136.23 2625.23 N 5576.14 E 5968431.56 N 649357.83 E 4.496 6147.88 2657.28 N 5571.40 E 5968463.51 N 649352.47 E 3.333 6159.40 2689.04 N 5566.36 E 5968495.18 N 649346.83 E 0.951 6170.52 2716.73 N 5561.92 E 5968522.78 N 649341.86 E 0.208 6180.18 2748.39 N 5556.50 E 5968554.32 N 649335.84 E 4.142 6190.92 2780.16 N 5550.83 E 5968585.98 N 649329.55 E 1.864 6201.50 2811.77 N 5545.04 E 5968617.48 N 649323.16 E 5.472 6211.90 2845.95 N 5539.13 E 5968651.54 N 649316.60 E 9.282 6223.45 2877.81 N 5534.60 E 5968683.30 N 649311.46 E 5.625 6235.06 2909.63 N 5530.78 E 5968715.04 N 649307.03 E 3.401 6247.27 2941.48 N 5527.19 E 5968746.81 N 649302.83 E 1.758 6259.71 2973.15 N 5523.36 E 5968778,41 N 649298.40 E 3.008 6271.85 3005.02 N 5519.30 E 5968810.19 N 649293.72 E 0.380 6283.88 3035.89 N 5515.41 E 5968840.98 N 649289.24 E 3.726 6295.57 3085.79 N 5509.21 E 5968890.75 N 649282.09 E 0.000 6314.54 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. ",~rtical depths are relative to Well. Northings and Eastings are relative to Well. Tl~e Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 60.746° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12521.00ft., The Bottom Hole Displacement is 6314.54ft., in the Direction of 60.746° (True). Comment Projected Survey Alaska State Plane Zone 4 PBU WOA Q Pad Continued... 23 June, 1998 - 12:16 - 3 - DrillQuest Prudhoe Bay Unit Sperry-Sun Drilling Services Survey Report for Q-O6A Your Ref: API-500292034601 Alaska State Plane Zone 4 PBU WOA Q Pad Comments Measured Depth (ft) 10998.57 11091.00 12521.00 Station Coordinates TVD Nothings Eastings (fi) (fi) 8750.25 1847.36 N 5288.07 E 8825.62 1856.32 N 5340.82 E '9026.67 3085.79 N 5509.21 E Comment Tie-on Survey Window Point Projected Survey 23 June, 1998 - 12:16 - 4 - DrillQuest TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION CO~IISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 30. 1998 James E. Sinith Senior Drilling Enginccr BP Exploration (Alaska), Inc.. POBox196612 Anchorage, AK 99519-6612 Prudhoe Bay Unit Q-06A BP Exploration (Alaska), Inc.. Permit No. 98-90 Sur. Loc. 378'SNL. 624'WEL. Sec. 16. TllN, R13E. UM Btmnholc Loc. 2575'SNL. 379'WEL. Sec. 10. T11N. RI3E. UM Dear Mr. Smith: Enclosed is thc approvcd application for permit to rcdrill thc abovc rcfcrcnccd v,'cll. Thc permit to rcdrill docs not exempt you from obtaining additional pcrmits rcquircd by lax,,, from other governmental agencies, and docs not authorize conducting drilling operations until all other rcquircd permitting dctcrminations arc made. Blov,'out prevention cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25 035. Sufficicnt notice (approximately 24 hours) must be given to allow a rcprcscntativc of the Commission to witness a tcst of BOPE installed prior to drilling ncw hole. Notice ma.',.' be given pcctor on thc North Slope pager at 659-3607. David W. Joh~on xk ~ Chairnmn BY ORDER OF THE COMMISSION dlf/Enclosurcs cc; Department of Fish & Game. Habitat Section w/o cncl. Departmcnt of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA'..;L AND GAS CONSERVATION corw,-r.;ISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [-I Drill C~]Redrill lb. Typeofwell I--IExploratory [] Stratigraphic Test C~ Development Oil [-I Re-Entry [] Deepen []Service I-I Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 66.09' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028281 4. Location of well at surface 7. Unit or Property Name 111. Type Bond (See 20 AAC 25.025) 378' SNL, 624' WEL, SEC. 16, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 3427' SNL, 267' WEL, SEC. 10, T11N, R13E, UM Q-06A At total depth 9. Approximate spud date Amount $200,000.00 2575' SNL, 379' WEL, SEC. 10, T11 N, R13E 05/01/98 12. Distance to nearest property line113. Distan'~e to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028280, 379'I No Close Approach 2560 12537' MD / 9026' TVD 16. To be completed for deviated wells il 7. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11089' MD Maximum Hole Angle 9o.7° Maximum surface 2480 psig, At total depth (TVD) 8800' / 3360 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 5.875" 4.5" 12.6# L-80 IBT-Mod 2637' 9900' 7926' 12537' 9026' 221 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 11580 feet Plugs (measured) ,;;q.,-".;-,. c.'-?' true vertical 9238 BKB feet Effective depth: measured 11396 feet Junk (measured) fill at 11396' (08/89) j;~ask~[ 0il & Gas C0f~s. true vertical 9081 BKB feet Anchorage Casing Length Size Cemented M D TVD Structural BKB Conductor 110' 20" x 30" 607 cu ft Arcticset 140' 140' Surface 2656' 13-3/8" 4418 cu ft Arcticset I 2686' 2686' Intermediate 10485' 9-5/8" 1514 cu ft 'G', 130 cu ft Arctic set 10515' 8374' Production Liner 1569' 7" 480 cu ft Class 'G' 10004'-11573' 8008'-9232' Perforation depth: measured Open' 11265'-11335' Squeezed: 11200'-11237', 11245'-11258' true vertical (subsea) 8901-8961' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diver[er Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: John Powell, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certi~/that the for. e.,.goin/t~is true and correct to the best of my knowledge Signed th ~ ~ ,.,..'"--7~.- Title Senior Drilling Engineer Date Jam E. Smi Commission Use Only Permit N u~.b~,r. I APl Number A pro~val .~ I See cover letter _ ~>~:5> 50-029-20346-01 "~.~..~ for other requirements Conditions of Approval: Samples Required []Yes J~No Mud Log Required I--lYes Hydrogen Sulfide Measures ~iYes'1-] No Directional Survey Required ~Yes I--I No Required Working Pressure for BOPE []2M; ~3M; I-ISM; [-110M; [-115M Other: q. Original ,..,~gned 6y by order of Approved By David W. J0hrlst0rl Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IQ-06A I Sidetrack Plan Summary Type of Redrill (producer or injector): I I Surface Location: Ti iN, R13E, Sec 16; 378' SNL, 624' WEL Target Location: Ti IN, R13E, Sec 10; 3427' FNL, 267' FEL Bottom Hole Location: T1 IN, R13E, Sec 10; 2575' FNL, 379' FEL ]AFE Number: [4P1073 I I EstimatedStartDate: 15/01/98 IUD: I 12,537' ITVD: Well Design (conventional, slimhole, etc.): I Rig: I Doyon 16 I Operating days to complete: 1 24 19026, ~ ~s9'~ I Through Tubing Horizontal sidetrack, Zone 2 ] I Objective: I 1) To increase the productivity of Q-06 by horizontally improving gas standoff. I 2) To place the well in a structurally low area to improve drainage of reserves. Mud Program Whipstock Mud Properties: Solids Free 6 % Quikdriln Density Funnel LSR LSRV API FL ph (PPG) Viscosity YP 8.6-8.9 45-65 10-18 >35,000 NC 8.5-9.0 Production Mud Properties: Solids Free 6 % Quikdriln Density Viscosity LSR LSRV API FL pH (PPG) YP 8.6-8.9 45-65 10-18 >35,000 NC 8.5-9.0 Directional I I~oe: I -875, TVDSS, 11,089' MD I IMaximum Hole Angle: 90.7 degrees I Close Approach Well: None Top of cement @ -11,100', w/Bridge Plug set at -11,100, w/whipstock (turned down to 5.910") set for casing exit at 11,089'. Drill out of whipstock window in 7" csg at 35 deg inclination 80 deg azimuth, building at up to 18 deg/100' to invert the well to 90.7 deg, drilling up through HOT. Nearby Well Status: Q-05A & Q-07 may need to be shut in for MIRU & RDMO. Q-06a Sidetrack Drilimg Permit Page 2/6 Formation Markers Formation Tops MD TVD (SS) Begin Sidetrack N10,090' 8743' Window kick off point at top of Zone 2 TSGR Above KOP TSHUB Above KOP TSAD Above KOP TZ3 Above KOP TZ2 N10,090' 8743' Window kick off point at top of Zone 2/Gas 25N Shale 8805 Oil Lens 22N Shale-Upthrown 8885 Oil 22N Shale-Downthrow 8940 Oil HOT 8960 HOT TZ1 Below TD Fault Detail -11,355 8905 +50' Throw in 22N, Lower Zone 2 Casing/Tubing Program Hole ~ize ~Csg Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVDss MD/TVDss existing 13-3/8" 72# L-80 BTC 2686' 30'/30' 2686/2686 existing 9-5/8" 47# L-80 gTC 10,515 30/30 10,515/8374 existing 7"tbg 26# L-80 IJ4S 10,004 surface/10,004 10,004/8008 existing 7"liner 29# L-80 8RD 1,569 10,004/8,008 11,573/9232 5.875" 4.5"liner 12.6# L-80 IBT Mod 2,637 9,900/7926 12,537/9026 NOTE: As his is a TTRD well, the 7" tubing described above is already in place, and will not be disturbed during the sidetrack. Cement Lead Cement Tail Cement Casing/Liner Sx / Wt / Yield Sx / Wt / Yield Comments 4.5" Liner From 221/15.7/1.19 Class G, 30% excess OH + TOC @ Liner 9,900-12,537 Top Volume assumptions: Gauge hole + designated excess; 80' shoe joints; TOC as listed. Do not bring cement past the top of the 7" liner Logging Program ILogs: 4.5" Hole Cased Hole: G R/Directional/Neu/Den/Res, sample catchers; MADD passes may be required to avoid sidetracking, locating HOT / GOC. N/A Q-06a Sidetrack Drilm~g Permit Page 3/6 DRILLING DISCUSSION WELL OBJECTIVE To increase the productivity of Q-06 by horizontalization to increase standoff from gas. To place the well in a structurally-low area which is an ideal recharge point for influxing GD reserves. This well is targeted for 2500 BOPD with expected reserves of 725,000 BBLs. Well Placement It is critical to exit the casing at the top of Zone 2 during the kickoff, which may necessitate a log to ensure placement of whipstock. The accomodation of a Zone 2 KO does not meet the AOGCC 100' above the shallowest cemented perforation rule. An attachment to this Permit to Drill Application outlines this exception. The depth of the HOT is the main uncertainty in well placement, necessitating a slightly inverted trajectory to drill up across the HOT to optimize well trajectory. Additionally, the well will cross a -50 fault and the target polygon is in a complexly- faulted graben with the possible presence of sub-seismic scale faulting. Well Control Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling maximum potential surface pressures. Estimated BHP @ 8800'TVDSS is 3,360psi - 7.34 ppg EMW. Maximum expected surface pressure at 8800'TVDSS is 2480 psi (assuming gas column of 0.1 psi/ft). Diverter, BOPE and mud fluid system schematics on file with AOGCC. Q-06a Sidetrack Drilffng Permit Page 4/6 Hazards 1) Thin, hard Zone 2 Cherts could inhibit the build rate. 2) Lost circulation is possible/probable when crossing fault in the build section (Zone 2). 3) Target polygon is within a complexly faulted graben, and, although faults aren't mapped, sub-seismic faults/fractures are possible. 4) High build rates -18 degrees/100' may be required at kick off of HAW. Plugbacks may be required if build rates are inadequate to optimize well placement within polygon. Disposal All cuttings should be hauled to the ball mill at CC-2A for disposal. Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. Q-06a Sidetrack Drill~g Permit Page 5/6 Operational Summary Pre-Rig Work: Note: If any problems with the 9-5/8" packoff are observed during pre-rig work, contact the wellhead manufacturer to initiate repairs. Please copy the Operations Drilling Engineer on daily reports, and call with any difficulties. Note: All depths listed in the steps below are referenced to Doyon 16 Kelly Bushing Elevation of 66.09' for this well. 1. R/U wireline and retrieve SSSV. If tubing and annulus have not recently (< 1 month) tested, test 7"x9-5/8" tubing annulus to 3,000 psi, looking for pressure increases on tubing and 13-3/8" casing. A successful test will be considered proof of a successful tubing integrity test and 9-5/8" integrity test. If the tubing/9-5/8" do not test, notify the operations drilling engineer before proceeding. 2. RIH and drift tubing to Baker FB-1 pkr depth at 11129' (elmd) w/dummy drift to ensure whipstock (5.910" OD) will pass through successfully. Check that Otis sliding sleeve is open. If Otis sliding sleeve is closed, RIH with shifting tool and open sliding sleeve. 3. P&A existing perforations at 11,140'-11,145' and 11,265-11,335', attempting to squeeze 5 bbls of cement to the perforations. Minimum TOC for AOGCC regulations is 11,040', but the highest depth which must be cemented to is 11,105'. Do not bring top of cement any higher than 11,105' in order to leave room for a kick off below Zone 3. AoGCC has been notified of this arrangement. Note: If necessary to prevent loss of cement, circulate well to a diesel cushion sufficient to remove hydrostatic overbalance from the cement column. 4. Pick up underreamer sized for 7" 29# casing (ensure fit through SSSV nipple), and underream interval from 10,515' to 11,105' to ensure good casing for bridge plug to set in. Tag TOC if required for AOGCC representative and pressure test the plug to standard test pressure. POOH. 5. R/U electric line. Set Baker bridge plug using GR/CCL correlation to allow a whipstock kick off, exiting the casing at -8,747 TVDSS, 11,089' MD. Note: The objective will be to put the top of the whipstock below the base of the Zone 3 formation which is difficult to drill, using GR/CCL locator. If cement plugback problems are encountered, please contact SSD Ops Drilling Engineer immediately for possible alternative procedures. 6. Circulate kill weight fluid and freeze protect with diesel (estimated BHP at 8800'TVDSS is 3,360psi - 7.3ppg EMW) to depth of + 2,200. 7. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Q-06a Sidetrack Drilling Permit Page 6/6 Rig Work: 1. Prior to rig move, test 9-5/8" packoff to 5,000psi, and function lock down screws (FMC wellhead representative to do this). If any problems with the 9-5/8" packoff are observed, contact the wellhead manufacturer to initiate repairs. If repairs are not possible, the TTRD sidetrack may be halted, and an alternative sidetrack method used. 2. MIRU. Pull BPV and set/test TWCV. ND tree, NU BOP's and test same. Pull TWCV. 3. M/U 5.910" OD milling assembly/whipstock and RIH on DP (circulate out freeze protection). Be extremely slow and careful around the SSSV nipple which has an D of 5.962". RIH limit is 90seconds/stand. Record up and down weights prior to tagging bridge plug with whipstock. Set whipstock on bridge plug with weight (Note: perform whipstock set without pumping). Mill out/dress window to 5.910". Do not mill out more formation than is needed to bury the window dressing mill. 4. RIH with 5.875" bit and drilling assembly and tag TD of milled secion. Displace well to Quikdriln drilling fluid, and drill 5.875" hole section to TD of 12,537' as per directional plan with LWD GRJRes/Neu/Den equipment. MAD passes will be made as required. Note: The depth and trajectory of the horizontal section may change depending on the depth at which the HOT is encountered. Expected depth is 8,960' TVDSS, but if found early, the wellbore will be modified to bring the well out of the HOT as quickly as possible. DPC logging will not be required unless the LWD results are unusable. The AFE contains contingency for a DPC logging run if this becomes necessary. 5. M/U and run 2,637' of 4-1/2" solid L80 IBT-Mod liner (X nipple 2 joints below TOL) to hang off depth in 7" tubing of + 9,900'. Cement liner in place with Baker 2- 7/8" inner string cementing assembly. Circulate out excess cement, and displace well to clean seawater, POOH. 6. RIH with DPC perforating guns and perforate -600' of liner with 2-3/4" guns, using underbalance of 100 psi. 7. RIH with DP and circulate freeze protection to + 2,200'MD. 8. Set and test TWCV, ND BOP, NU tree. Pull TWCV and set/test BPV. RDMO. The Doyon 16 Rig Supervisors can be reached at 659-4610. The Operations Drilling Engineer is John Powell, reached at 564-5480 (off) or: 275-5054 pager (number), 346-1468 (home). J. Powell (4/21/98) I~ · I,,~_.. ~.~: ~.~o~ O 6 current Stat WELLHEAD: McEVOY '" US ORIGINAL KB' ELEV = 60'6~- '~ BF. ELEV = 40.59 ACTUATOR: OTIS 1_-80, BIR$ IKOP: 20°°' I MAX ANGLE: 51 deg 7', 26 #/ft, L-80,1J4S TUBING ~ ~, TUBING ID: 6.276' CAPACITY: .0382 BBL/FT ~o.o~^~. I~°°°~ 0~$15', 47#1~t, [ PFRFOR~TION ~HMM~R¥ ~F: lOG: GRL 2-~ '1-70 SIZE SPF INTERVAL OpEN/SQZ'D [~ ~-~ BAKERFB1 111129 i I I 3-3/8' 4 11140-11145 STRDL 10/92 PKR I "l . 4' 4 11200-11237 SOUEEZED SLEEVE 4' 4 11245-11258 SQUEEZED ;><3~ BAKER FB 1 11147 4' 4 11265-1127C SQUEEZED PKR ~ 3.5" PARKER SWS I 33/8 4 11265-11335 OPEN NIPPLE ID = 2.75" 11154 2.5' 4 11265-11335 Re-Open 9/94 I WLEG I 11160 PBTD ~ ~~~.~_~ -~,~, ~.~ 7', 29 #/ft, L-80,I ~'lt:)/3 ~ ~ ~-.~-~-~'--~.--~--~.- BTRS DATE REV. BY COMMENTS PRUDHOE BAY UNIT INITIAL RIG COMPLETION WELL: Q-6 143-10-11-131 9/2/94 JKA post Gel Sqz Reperfs APl NO: 50-029-20346 SEC 16 :T N 11N · RGE 131: 9-21-94 vi. LINDER UPDATED STRADDLE DEPTHS BP Exploration (Alaska) TREE: 6 ~'8~ MoEVOY Q ...... ig Status ~ WELL, EAD: MoEVOY -06~re-r BOYON ,6 KB. ELEV=6~. ACTUATOR: OTiS BF. ELEV = ~.59 ~ 9-5/8 F,O,C ~ SSSV LANDING NIPPLE 9-5/8 D.V. PACKER ~ ( OTIS )(5.962 "ID) 13-&/8*, 72¢/~, ~ L-80, BTRS Diese~ at 2,200' MD Ir KOP: 2000' MAX ANGLE: 51 deg 7", 26 #fit, L-80,1J4S TUBING TUBING ID: 6.276" CAPACITY: ,0382 BBL/FT 9-5/8"' 47#/ft' l L-80, BTRS 10511 Whipstoc~ set for casing exit at 11,089' Bridge plug set at ~11,100' Cement abandonment of pedorations 11,140~11,145' and 11,265~11,335' TOP OF SEAL ASSY. BOTTOM OF SEAL ASSY, 5.910" window milled at 11,089' Top of cement at -1t,100' MARKER JOINT BAKER FB 1 PKR 4.5" OTIS SLIDING SLEEVE BAKER FB 1 PKR 3,5" PARKER SWS NIPPLE tD = 2.75" WLEG BTRS DATE ~ COMMENTS TIAL R~G CO~PLETION 2-25-98 TTRD Sidetrack TREE: 6 3/8" McEVOY WELLHEAD: McEVOY O-06a Proposed Completion DOYON ~6 KB. ELEV:®.® ACTUATOR: OTiS BF. ELEV = 40.59 9-5/8 F.O,C 9-5/8 D.V. PACKER 13-3/8", 72#/ft, L-80, BTRS IKOP: 2000' · SSSV LANDING NIPPLE ( OTiS )( 5.962 "ID) 6.8ppg Diesel at 2,200' MD 7-, 26 #fit, L-80,IJ4S TUBING TUBING ID: 6.276" CAPACITY: .0382 BBL/FT Cement 4-1/2" X nipple at 9,980' 9-5/8", 47#/ft, [ L-8O, BTRS 10511 Whipstock set for casin9 exit at 11,089' Bridge plug set at -11,100' Top of cement at ~11,100' Cement abandonment of perforations 11,140-11,145' and 11,265~ 11,335' 4-1/2" Baker Tie-back sleeve at 9,900' TOP OF SEAL ASSY. ~ BOTTOM OF SEAL ASSY, 4-1/2", 12.6#, L80, 5.875" Section lET-Mod liner TD @ 12,5: MARKER JOINT PKR 4.5" OTIS SLIDING SLEEVE BAKER FB 1 PKR 3.5" PARKER SWS NIPPLE ~D = 2.75" PBTD BTRS DATE REV. BY ~N~T 9Pz/94 JKA Po 9-21-94 M. LINDER UPD~ 2-2,5-98 C,Brown COMMENTS 'IAL RiG CO~PLETiON Gel S~ 8eperfs STRADDLE DEPTHS TTRD Sidetrack BP Exploration (Alaska) Shared Services Drilling [ DrillQuest" Proposal Data for Q-06A WP3 Vect~'aJ Oflg13:Well -Iot'izootal Odgia; Well Measurement Unils: It North Reference:True Nor~ .................................................................. Do~leg Seve~tty: Degrees per 10Oft Vert~ca! Section Aztmu~: 8.630' Vertical Secttoa D~scrtptlon:Well Vertical Sec~on Origin: 0.00 N,0.00 E Measured IncL Azim. Vertical Northiocjs Ea,:tings VerticalDog-Ieg "- Depth Depth Section Rate 11070.0034.96680.628 8808.00 1554.59 N 5330.18 E2633.40 1 ! 100.00 37.06278,637 8832.27 1857.77 N 5347.52 E2639. ! 5 ~,000 11263.1064.51864.803 8934.68 1899.71 N 5464.9~ E2698.23 18.000 11263.4864.518(>4.803 8934.84 1899.86 N 5465.21 E2698.42 0.000 116T/.1490.666352.402 9036.09 2232.55 N 5630.80 E3052.19 12537,0990,666352.402 9026.09 3084.88 N 5517.11 E3877.81 0.000 28 - Jan - 1998 SURFACE LOCATION REFERENCE PLOT DATE: Horizontal Coordlnatas: 5965700.00 N. 643833.00 E [ Cr~'atL~l By: RKB F_Jev~lon: 25.5o f~ Rig (EST) r 40.59 ff Wel~ (CE~) / (::oo~'dln~te 5'ya-tem: NAD27 Alaska State Pianos, I Proposal Target Summary Target Name: TVDss: TVDrkb: Wellhead Offsets: Global Coordinates: Q-06A TI 8970.009036.09 2232.55 N, 5630.80 E 5968040.00 N, 649420.00 E Q-06A T2 8960.009026.09 3084.88 N, 5517./1 E 5968890.00 N, 649290.00 E 2900 2700 Scale: linch = 2001'1 Eastin§s 5300 5500 57oo I 125;t7 09 MD. I '~'" ' rn 2100 ~8~ J:."-~: ...... :~. ..................................................................................................................................................... ~ 1 ..... ~ ..... ~ ..................... ~ ........................................................................ ; ............................................... .,.,..~ > ~~~ ............. ,, ..................... ~ ...................... ~ ..................... ,~ ..................... ?= ..... 53~ S~le: 1 inch 27~ 2~ 31~ 33~ 35~ 37~ 3~ ~ale; linch = 2~ft Ve~ical Section S~tlon ~lmuth: 8.~0' ~me No~h) I 550O 57OO Reference is True North Eastings Sperry-Sun Drilling Services Proposal Report for Q-O6A - Q-O6A WP3 Shared Services Drilling Prudhoe Bay Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl, Azim. Depth Depth Northings East]rigs Northings Eastings Rate Section Comment (n) (n) (ft) (n) (ft) (ft) (ft) (~/~ OOft) (f~) 11070.00 34.966 80.628 8741.91 8808.00 1854.59 N 5330.18 E 5967656.35 N 649126.67 E 2633.40 I1100.00 37.062 78.637 8766.18 8832.27 1857.77 N 5347.52 E 5967659.86 N 649143.96 E 8.000 2639.15 I1170.85 48.787 71.214 8818.00 8884.09 1870.61 N 5393.88 E 5967673.59 N 649190.05 E 18.000 2658.80 25N tl 181.6750.614 70.325 8825.00 8891.09 1873.33 N 5401.67 E 5967676.46 N 649197.79 E 18.000 2662.66 25P 11200.00 53.721 68.920 8836.24 8902.33 1878.37 N 5415.23 E 5967681.76 N 649211.26 E 18.000 2669.68 11263.10 64.518 64.803 8868.59 8934.68 1899.71 N 5464.90 E 5967704.05 N 649260.50 E 18.000 2698.23 11253,48 64.518 64.803 8868.75 8934,84 1899.86 N 5465.21 E 5967704,20 N 649260.82 E 0.000 2698.42 11300.00 65.649 57.662 8884.15 8950.24 1915.80 N 5494.21 E 5967720.69 N 649289.51 E 18.000 2718.53 11314.32 66.184 54.899 8890.00 8956.09 1923.05 N 5505.09 E 5967728.15 N 649300.24 E 18.000 2727.34 22NVGOC 11321.80 66.482 53.467 8893.00 8959.09 1927.06 N 5510.64 E 5967732.27 N 649305.71 E 18.000 2732.13 22P 11352.70 67.852 47.617 8905.00 8971.09 1945.15 N 5532.61 E 5967750.78 Iq 649327.33 E 18.000 2753.32 Fault 11400.00 70.337 38.898 8921.91 8988.00 1977.31 N 5562.83 E 5967783.51 N 649356.93 E 18.000 2789.65 11485.82 75.831 23.796 8947.00 9013.09 2047.25 N 560525 E 5967854.25 N 649398,00 E 18.000 2865.16 Down 22N 11498.47 76.727 21.642 8950.00 9016.09 2058.58 N 5609.99 E 5967865.67 N 649402.53 E 18.000 2877.07 Down 22P 11500.00 76.837 21.382 8950.35 9016.44 2059.97 N 5610.54 E 5967867.07 N 649403.05 E 18.000 2878.53 11600.00 84.453 4.838 8966.70 9032.79 21 65.69 N 5632.67 E 5967963.19 N 649423.34 E 18.000 2976.48 11677.14 90.666 352.402 8970.00 9036.09 2232.55 N 5630.80 E 5968040.00 N 649420.00 E 18.000 3052.19 Target: Q-06A T1, Geological 11700.00 90.666 352.402 8969.73 9035.82 2255.20 N 5627.78 E 5968062.59 N 649416.54 E 0.000 3074.13 11800.00 90.666 352.402 8968.57 9034.66 2354.32 N 5614.56 E 5968161.44 N 649401.43 E 0.000 3170.14 11900.00 90.666 352.402 8967.41 9033.50 2453.43 N 5601.34 E 5968260.28 N 649386.31 E 0.000 3266.15 12000.00 90.666 352.402 8966.25 9032.34 2552.55 N 5588.11 E 5968359.12 N 649371.19 E 0.000 3362.16 12100.00 90.666 352.402 8965.08 9031.17 2651.66 N 5574,89 E 5968457.97 N 649356.08 E 0.000 3458.17 12200.00 90.666 352.402 8963.92 9030.01 2750.78 N 5561.67 E 5968556.81 N 649340.96 E 0.000 3554.18 12300.00 90.666 352.402 8962.76 9028.85 2849.89 N 5548.45 E 5968655.66 N 649325.84 E 0.000 3650.19 12400.00 90.666 352.402 8961.59 9027.68 2949.01 N 5535.23 E 5968754.50 N 649310.72 E 0.O00 3746.20 12500.00 90.666 352.402 8960.43 9026.52 3048.12 N 5522.01 E 5968853.34 N 649295.61 E 0.000 3842.21 12537.09 90.666 352.402 8960.00 9026.09 3084.88 N 5517,11 E 5968890.00 N 649290.00 E 0.000 3877.81 4 1/2' Liner T~rget: Q-06A T2, Geological Alaska State Plane Zone 4 PBU_WOA Q Pad <:~ 29 January, 1998 - 8:00 - I - DrtllQuest Sperry-Sun Drilling Services Proposal Report for Q-O6A - Q-O6A WP3 Shared Services Drilling Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA Q Pad All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. VerticaI Section is from Well and calculated along an Azimuth of 8.630" (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12537.09ft., The Bottom Hole Displacement is 6320.99ft., in the Direction of 60.788° (True). <z: 29 January, 1998 - 8:00 - 2 - DrlllQuest Sperry-S . . Drilling Services Proposal Report for Q-O6A ~ Q-O6A WP3 Shared Services Drilling Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_WOA Q Pad Measured Vertical Vertical Dogleg Depth Incl. Azlm. Depth Northlngs Eastlngs Section Rate (ft) (ft) (ft) (fi) (ft) (°/100ft) 11070.00 34,966 80.628 8808.00 1654.59 N 5330.18 E 2633.40 11100.00 37.062 78.637 8832.27 1857.77 N 5347.52 E 2639.15 8.000 11253,10 64.518 64.803 8934.68 1899.71 N 5464,90 E 2698.23 18.000 11263.48 64.518 64.803 8934.84 1899.86 N 5465.21 E 2698.42 0.0OO 11677.14 90,6§6 352.402 9036.09 2232.55 N 5630.80 E 3052.19 18.000 12537.09 90.666 352.402 9028,09 3084.88 N 5517.11 E 3877.81 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. NorthJngs and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 8.630° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12537.09ft,, The Bottom Hole Displacement is 6320.99ft., in the Direction of 60.788° (True). Formation Tops Measured Vertical Sub-Sea Depth Depth Depth Northlngs Eastlngs Formation Name If t) If t) (ft) (ft) (ft) 11170.85 8884.09 8818.00 1870.61 N 5393,88 E 25N 11181.67 8891.09 8825.00 1873.33 N 5401,67 E 25P 11314.32 8956.09 8890.00 1923.05 N 5505.09 E 22N./GOC 11321.80 8959.09 8893.00 1927.06 N 5510,64 E 22P 11352.70 8971.09 8905.00 1945.15 N 5532.61 E Fault 11485.82 9013.09 8947.00 2047.25 N 5605.25 E Down 22N 11498.47 9016.09 8950.00 2058.58 N 5609.99 E Down 22P Casing details From Measured Vertical Depth Depth If t) <Surface> <Surface> To Measured Vertical Depth Depth Casing Detail (ft) (ft) 12537.09 9026.09 4 1/'2' Liner Targets associated with this we#path Target Name Q-06A T1 Q-06A T2 Target Entry Coordinates TVD Northings Eastlngs Target (fi) (ft) (ft) Shape 9036.09 2232.55 N 5630.80 E Point 9026.09 3084.88 N 5517.11 E Polnl Target Type Geological Geological 29 January, 1998 - 8:00 -1- DrillQuest --- hared rvices rilling The attached work cannot commence without AOGCC approval! Application (check one) r~ Drilling / Sidetrack Permit "'-] Sundry Application Reason for Sundry (check all that apply) Change to submitted Drilling Permit Change to approved Drilling Permit Abandon Wellbore Workover of Injection Well Reenter Suspended Well Suspend Wellbore Change Well Type (Injector, Producer) Extending Expired Permit Other Brief Summary of Changes (if .any): ~,,iaska Oii & Gas Cons= Comrnissio~ Anchorage Application Submittal Documentation Prepared by: Permit Application Attached: Reviewed by: Submitted to AOGCC: Approval tO Proceed Approved AOGCC Permits Received: Approval to Commence Operations: Op,~,Eations Technical Assistan~ gr. Dri, llin~'Eng-~, ecr T~hnical Assistant Technical Assistant Date Date Date Date Date Sr. Drilling Engineer Date ~ DATE ICHECK NO. H 13 I~ 0 8 0 03/27/98 00136080 VENDOR A ASKAST14 O0 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 032498 CK032498]] I00. O0 i00. O0 HANDLI[N~ INST: S/H TERRI HUBBLE X z~528 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. · WELL PERMIT CHECKLIST COMPANY__~C;'f FIELD & PO()t._ .......... ~ ~7'~__~27~.....~_ ......... It',Ill CLASS ,~~ . . ADMINISTRATION 1 2 3 4 5 6 7 8 9 10 11 ENGINEERING 15 16 17 18 19 2O 21 22 23 24 25 APPR .[_.)~' I [! 26 GEOLOGY WELl_ NAME,~ (~-4:~,~',,~_ PROGRAM: exp [] dev~rredrl[~serv [] wellbore seg l ann disposal .,,,'2"'"z~,~/ GEOL AREA <:~ ' UNIf# ...... ' ..___'" _~Z_~"~.~__~ ON/OFF SIIORE .... f't'~llil let' altach~;d [ ease ~und'~er aplr)ropliale Unique well name and nurnbe~. Well tocaled in a defined pool ......... Well Iocaled ploper dislance from drilling unil boundary. Well located proper distance from other wells . . Sufficient acreage available in drilling unit . . If devialed is wellbore plat included Operalor only affected pady. ()perator has appropnale bond in force f-'ern~il can be issued wilhout conservation order Pe~n]il can be issued wilhoul administrative approval ('.a~ l~C'In~d be approved before 15-day wail Conductol siring provided . . Surface casing prolects all known USDWs. . . CI,.1T vol adequale 1o circulate on conductor & surf csg. CMl vol adequale to tie-in long string Io surf csg .... CM'I will cover all known productive horizons Casing designs adequate for C, 'f. B & permafrost Adeqt~ale tankage or reserve pil ........... I1 a re.drill, has a 10-.403 for abandonrnent been approved. Adeqtlale wellbole separation proposed... If diverler required, does it meel regulations l)rilhng fluid program scl'lematic & eqtlip Iisi adeqLJale N N N N N N N N N N N N REMARKS B¢')PE ~,. do ll~ey meet regulatio~ ~'~ N BOPE p~ess rating appropriate: test to .~__~~._ ..... Psig N Choke manifold complies w/APl RP-53 (May 84) ..... (~ N Work will occur without operation sht]tdown .... N Is p~eserlce of t't:.S gas probable. N 30 t'ernnt can be issued w/o hydrogen sulfide measures 31 Data preser~led on polenlial overpressure zones 32 Se~s~nic analysis of shallow gas zones 33 Seabed condilior~ survey (if off-shore) .,~I::: .~~ [explora,o,~/only] IE 3,1 Cordant ~ar~e/phone tor weeklyprogress reports .-.-. ::. r. ; ,- .. -;...:-.::::..:r.:.,: .:::~.:::.~:,.:;,.1-.: ============================== .......................... // Y N . GEOt OGY ENGINEERING COMMISSION ,IDt t...,~_..___ RNC co ..: , :..:-:~ ..~.,- r;.: -: ................................................................. Comments/Instructions' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun DrJ ~ling Services LIS Sca tility Mon Nov 09 18:58:05 1998 Reel Header Service name ............. LISTPE Date ..................... 98/11/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 98/11/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING MWD RUN 2 AK-MW-80218 G.TOBIAS M.JACKSON OPEN HOLE BIT SIZE (IN) Q-06A 500292034601 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 09-NOV-98 MWD RUN 3 MWD RUN 4 AK-MW-80218 AK-MW-80218 G. TOBIAS G. TOBIAS M. JACKSON M. JACKSON 16 lin 13E 378 624 68.20 66.70 41.40 CASING DRILLERS SIZE (IN) DEPTH (FT) NOV ~ND S~RING 3RD STRING PRODUCTION STRING REMARKS: 7.000 11091.0 5.875 12521.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM D. DOUGLAS FOR G. BERNASKI OF BP EXPLORATION (ALASKA), INC. ON 11/o2/9s. 3. RUN 1 IS DIRECTIONAL ONLY TO SET THE WHIPSTOCK AND IS NOT PRESENTED. 4. RUNS 2-4 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR), UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) , COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO DENSITY (SLD) . 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12521'MD, 9027'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE 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 RESISITVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = MUD MOTOR DRILLING (NO ROTATION). SLD SLIDE = LOCATION OF SLD SENSOR WHILE DRILLING WITH MUD MOTOR. TNPS = COMPENSATED THERMAL NEUTRON SANDSTONE POROSITY. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED (BEST BIN). SC02 = SMOOTHED STANDOFF CORRECTION (BEST BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN). ENVIRONMENTAL PARAMETERS USED IN NUCLEAR PROCESSING: HOLE SIZE: 5.875" MUD WEIGHT: 8.7-8.8 PPG FORMATION WATER SALINITY: 11500 PPM CHLORIDES MUD FILTRATE SALINITY: 28500-29000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NIIMEER: 1 EDITED MERGED MWD Depth shifted and clipped C~rves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 11024 0 ROP 11044 5 FET 11076 5 RPD 11076 5 RPM 11076 5 RPS 11076 5 RPX 11076 FCNT 11091 NCNT 11091 NPHI 11091 PEF 11092 DRHO 11092 RHOB 11092 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: STOP DEPTH 12483.5 12521.0 12490.5 12490.5 12490.5 12490.5 12490.5 12438.0 12438.0 12438.0 12453.5 12453.5 12453.5 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 11107.0 11533.0 3 11533.0 12308.0 4 12308.0 12521.0 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPS MWD OHMM 4 1 68 8 3 RPD MWD OHMM 4 1 68 12 4 ROP MWD FT/H 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 SBD2 MWD G/C3 4 1 68 32 9 SCO2 MWD G/C3 4 1 68 36 10 SNP2 MWD BAP~N 4 1 68 40 11 TNPS MWD' FCNT MWD NCNT MWD P .U. n 1 68 CTS/ 1 68 CTS/ e 1 68 44 48 52 12 13 14 Name DEPT GR RPS RPD ROP RPX RPM FET SBD2 SCO2 SNP2 TNPS FCNT NCNT Min 10981.5 13.9262 0 1321 2 7688 8 0711 0 0861 0 5449 0 3506 2 1003 -0.32 0.4993 16.47 344.15 28439.7 Max Mean Nsam 12521 11751.2 3080 126.259 26.9912 2920 2000 20.5736 2829 2000 32.9381 2829 4721.48 124.148 2954 2000 9.0872 2829 2000 32.7369 2829 20.0207 2.6112 2829 2.7535 2.30179 2724 0.19 0.0470894 2724 13.2283 2.03731 2921 33.46 25.9289 2695 996.61 522.455 2695 43604.1 34973.8 2695 First Reading 10981.5 11024 11076.5 11076.5 11044.5 11076.5 11076.5 11076.5 11092 11092 10981.5 11091 11091 11091 Last Reading 12521 12483.5 12490.5 12490.5 12521 12490.5 12490.5 12490.5 12453.5 12453.5 12453.5 12438 12438 12438 First Reading For Entire File .......... 10981.5 Last Reading For Entire File ........... 12521 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 P~AW 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 PEF 11004.0 GR 11024.0 STOP DEPTH 11462.0 11491.5 · ROP 11044.5 FET 11076.5 RPD 11076.5 RPM 11076.5 RPS 11076.5 RPX 11076 5 FCNT 11091 0 NCNT 11091 0 NPHI 11091 0 DRHO 11092 0 RHOB 11092 0 $ 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: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 11532 5 11499 0 11499 0 11499 0 11499 0 11499 0 11446 0 11446 0 11446 0 11462 0 11462 0 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: 08-MAY-98 ISC 5.07 / ISC 5.07 DEP 2.22A MEMORY 11533.0 11107.0 11533.0 36.1 76.0 TOOL NUMBER P1006SP4 P1006SP4 P0986SNL4 P0986SNL4 5.880 5.9 KCL POLYMER 8.70 50.0 8.9 28500 9.0 .100 .055 .120 .080 60.9 .0 Data Format Specification R rd 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 SBD2 MWD 2 G/C3 4 1 68 SC02 MWD 2 G/C3 4 1 68 SNP2 MWD 2 BARN 4 1 68 TNPS MWD 2 P.U. 4 1 68 FCNT MWD 2 CNTS 4 1 68 NCNT MWD 2 CNTS 4 1 68 Rep Code Offset 0 4 8 12 16 20 24 28 32 36 4O 44 48 52 Channel 1 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 10981.5 11532.5 11257 1103 GR 14.4091 126.259 29.8058 936 RPX 0.0861 2000 10.6067 846 RPS 0.1321 2000 43.549 846 RPM 0.5449 2000 81.7419 846 RPD 2.7688 2000 81.6117 846 ROP 8.0711 4721.48 243.959 977 FET 0.6884 2.4499 1.40778 846 SBD2 2.1003 2.7535 2.31338 741 SC02 -0.32 0.159 0.0494765 741 SNP2 0.4993 13.2283 3.28711 938 TNPS 16.47 31.5 23.5391 711 FCNT 368.9 996.61 601.746 711 NCNT 28439.7 43604.1 36542.4 711 First Reading 10981.5 11024 11076.5 11076.5 11076.5 11076.5 11044.5 11076.5 11092 11092 10981.5 11091 11091 11091 Last Reading 11532.5 11491.5 11499 11499 11499 11499 11532.5 11499 11462 11462 11462 11446 11446 11446 First Reading For Entire File .......... 10981.5 Last Reading For Entire File ........... 11532.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF - File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/09 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI 11446.5 PEF 11462 5 DRHO 11462 5 RHOB 11462 5 GR 11492 0 FET 11499 5 RPD 11499 5 RPM 11499 5 RPS 11499 5 RPX 11499 5 ROP 11533 0 FCNT 14446 5 NCNT 14446.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 12221.0 12236.5 12236.5 12236.5 12266 0 12273 0 12273 0 12273 0 12273 0 12273 0 12307 0 12221 0 12221 0 10-MAY-98 ISC 5.07 / ISC 5.07 DEP 2.22A MEMORY 12308.0 11533.0 12308.0 78.9 90.5 TOOL NUMBER P1006SP4 EWR4 CNP SLD $ ELECTROMAG. RESIS. 4 COMPENSATED NEUTRON STABILIZED LITHO DEN BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): P1006SP4 P09866SNL4 P09866SNL4 5.88O DRILLER'S CASING DEPTH (FT) : 5.9 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 QUIKDRILN 8.80 70.0 9.0 29000 4.5 .120 .057 .160 .160 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 SBD2 MWD 3 G/C3 4 1 68 32 9 SC02 MWD 3 G/C3 4 1 68 36 10 SNP2 MWD 3 BAR/~ 4 1 68 40 11 TNPS MWD 3 P.U. 4 1 68 44 12 FCNT MWD 3 CNTS 4 1 68 48 13 NCNT MWD 3 CNTS 4 1 68 52 14 84.8 First Name Min Max Mean Nsam Reading DEPT 11446.5 12307 11876.8 1722 11446.5 GR 13.9262 80.9826 25.8791 1549 11492 RPX 2.6213 19.3692 8.39907 1548 11499.5 RPS 3.6152 23.7968 10.8714 1548 11499.5 Last Reading 12307 12266 12273 12273 RPM 4.76 25.0455 12.1939 1548 RPD 5.3901 27.695 12.6671 1548 ROP 10.2276 630.469 63.5807 1549 FET 0.6263 20.0207 3.03957 1548 SBD2 2.1625 2.7214 2.29699 1549 SC02 -0.042 0.19 0.0439406 1549 SNP2 0.7112 3.2495 1.48472 1549 TNPS 21.63 33.46 27.1016 1550 FCNT 363.75 674.72 485.482 1550 NCNT 29960.9 39157.7 34311.4 1550 11499.5 11499.5 11533 11499 5 11462 5 11462 5 11462 5 11446 5 11446 5 11446 5 12273 12273 ~-''12307 12273 12236.5 12236.5 12236.5 12221 12221 12221 First Reading For Entire File .......... 11446.5 Last Reading For Entire File ........... 12307 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE FCNT NCNT NPHI PEF DRHO RHOB GR FET RPD RPM RPS RPX ROP $ 4 .5000 START DEPTH 12221.5 12221 5 12221 5 12237 0 12237 0 12237 0 12266 5 12273 5 12273 5 12273 5 12273 5 12273 5 12307 5 STOP DEPTH 12438.0 12438 0 12438 0 12453 5 12453 5 12453 5 12483 5 12490 5 12490 5 12490 5 12490 5 12490 5 12521 0 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: M3~XIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Il-MAY-98 ~- ISC 5.07 / ISC 5.07 DEP 2.22A MEMORY 12521.0 12308.0 12521.0 92.4 93.9 TOOL NUMBER P1006SP4 P1006SP4 P0986SNL4 P0986SNL4 5.880 5.9 QUIKDRILN 8.80 63.0 8.6 28000 4.5 .120 .070 .160 · 160 65.6 .0 Name Service Order Units S Nsam Rep DEPT FT · 1 68 GR MWD 4 API 4 1 68 RPX MWD 4 OHMM 4 1 68 RPS MWD 4 OHMM 4 1 68 RPM MWD 4 OHMM 4 1 68 RPD MWD 4 OHMM 4 1 68 ROP MWD 4 FT/H 4 1 68 FET MWD 4 HOUR 4 1 68 SBD2 MWD 4 G/C3 4 1 68 SC02 MWD 4 G/C3 4 1 68 SNP2 MWD 4 BARN 4 1 68 TNPS MWD 4 P.U. 4 1 68 FCNT MWD 4 CNTS 4 1 68 NCNT MWD 4 CNTS 4 1 68 Code Offset Channel 0 4 8 12 16 20 24 28 32 36 40 44 48 52 2 3 4 5 6 7 8 9 10 11 12 13 14 Name Min Max Mean Nsam DEPT 12221.5 12521 12371.2 600 GR 14.8515 54.5441 24.8949 435 RPX 3.6593 17.0662 8.58085 435 RPS 4.1717 22.1728 10.4169 435 RPM 4.4239 22.7618 10.5349 435 RPD 4.515 22.0753 10.4132 435 ROP 12.5009 328.125 69.8544 428 FET 0.3506 18.0854 3.42728 435 SBD2 2.1925 2.4075 2.29912 434 SC02 0.0041 0.1404 0.0542526 434 SNP2 0.876 1.7518 1.3084 434 TNPS 20.32 32.83 25.6559 434 FCNT 344.15 756.38 524.605 434 NCNT 28980.5 40285.1 34769.7 434 First Reading 12221 5 12266 5 12273 5 12273 5 12273 5 12273 5 12307 5 12273.5 12237 12237 12237 12221.5 12221.5 12221.5 Last Reading 12521 12483.5 12490.5 12490.5 12490.5 12490.5 12521 12490.5 12453.5 12453.5 12453.5 12438 12438 12438 First Reading For Entire File .......... 12221.5 Last Reading For Entire File ........... 12521 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/11/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/11/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............... iSTPE Date ..................... 98/11/09 Origin ................... STS Reel Name ................ UNKI~OWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File