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Home My WebLink About184-0711 Carlisle, Samantha J (CED) From:Bo York <byork@hilcorp.com> Sent:Tuesday, November 23, 2021 10:13 AM To:Price, Jeremy M (OGC) Cc:Carlisle, Samantha J (OGC); Regg, James B (OGC) Subject:RE: [EXTERNAL] RE: NOV OTH-21-055 Attachments:ASR - MP F73A BOPE test report - 18 Nov 2021.pdf; Diverter Hilcorp Innovation 11-1-21.pdf; Diverter Hilcorp 147 11-21-21.pdf; 404 - MRF_K-12RD2_Daily_Report_18 Nov 2021.pdf; 404 - MRF_K-12RD2 _Daily_Report_19 Nov 2021.pdf CommissionerPriceͲ AnactionnotedinHilcorp’sresponsetotheNOVOTHͲ21Ͳ055wasforHilcorptoconductclosuretestsonallourAlaska operatedrigs.Hilcorphascompletedtheclosuretestsandtheclosuretimeresultsaresummarizedinthetable below.Eachrig’stestisincludedintheattacheddocuments. Pleaseletmeknowifyouhaveadditionalquestionsorwouldliketodiscussfurther. Bestregards. BoYork HilcorpAlaskaLLC PBEOperationsManager byork@Hilcorp.com 907.777.8345Anchorageoffice 907.659.5149PBOCoffice 907.727.9247cell From:BoYork Sent:Sunday,November14,202111:48AM To:Price,JeremyM(CED)<jeremy.price@alaska.gov> Cc:Carlisle,SamanthaJ(CED)<samantha.carlisle@alaska.gov>;Regg,JamesB(CED)<jim.regg@alaska.gov> Subject:RE:[EXTERNAL]RE:NOVOTHͲ21Ͳ055 CommissionerPriceͲ AttachedisHilcorp’sresponsetotheNoticeofViolationOTHͲ21Ͳ055. 2 Ahardcopywillbeplacedinthemailtomorrowifyourrecordsrequireahardcopysubmittal.Ibelieveeverythingisstill electronicsubmittalsforyou.However,IdidreceiveahardcopyoftheNOVvianormalmailandnotanelectronic versionsowantedtobesureIamsubmittingcorrectly. Bestregards. BoYork HilcorpAlaskaLLC PBEOperationsManager byork@Hilcorp.com 907.777.8345Anchorageoffice 907.659.5149PBOCoffice 907.727.9247cell From:Regg,JamesB(CED)<jim.regg@alaska.gov> Sent:Thursday,November4,20219:58AM To:BoYork<byork@hilcorp.com> Cc:Carlisle,SamanthaJ(CED)<samantha.carlisle@alaska.gov> Subject:[EXTERNAL]RE:NOVOTHͲ21Ͳ055 ResponsebyMonday11/15isok JimRegg Supervisor,Inspections AOGCC 333W.7thAve,Suite100 Anchorage,AK99501 907Ͳ793Ͳ1236 From:BoYork<byork@hilcorp.com> Sent:Wednesday,November3,20214:36PM To:Regg,JamesB(CED)<jim.regg@alaska.gov> Subject:NOVOTHͲ21Ͳ055 JimͲ ReceivedtheNOVre:BOPtesttimestoday.Itisdated1Nov.Wehave14daystorespond.ThatwouldbeSunday,14 Nov.IsrespondingonMonday,15NovokordoIneedtosubmitbyFriday12Nov? Thankyou. BoYork HilcorpAlaskaLLC PBEOperationsManager byork@Hilcorp.com 907.777.8345Anchorageoffice 907.659.5149PBOCoffice 907.727.9247cell 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 Date: 11/1/2021 Development: X Exploratory: Drlg Contractor:Rig No. Innovation AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.:2210860 Rig Phone: Rig Email: MMISCEL L A NEOUS:DDIVERTER SYSTEM: Location Gen.:P Well Sign: P Designed to Avoid Freeze-up? P Housekeeping:P Drlg. Rig. P Remote Operated Diverter? P Warning Sign P Misc: NA No Threaded Connections? P 24 hr Notice:P Vent line Below Diverter? P A CC UMULATOR SYSTEM:Diverter Size: 13 5/8 in. Systems Pressure:2900 psig P Hole Size: 12 1/4 in. Pressure After Closure:1900 psig P Vent Line(s) Size: 16 in. P 200 psi Recharge Time:20 Seconds P Vent Line(s) Length: 211 ft. P Full Recharge Time:56 Seconds P Closest Ignition Source: 79 ft. P Nitrogen Bottles (Number of):6 Outlet from Rig Substructure: 199 ft. P Avg. Pressure: 2304 psig P Accumulator Misc:NA Vent Line(s) Anchored: P MUD SYSTEM:Visual Alarm Turns Targeted / Long Radius:NA Trip Tank:P P Divert Valve(s) Full Opening: P Mud Pits:P P Valve(s) Auto & Simultaneous: Flow Monitor:P P Annular Closed Time: 8 sec P Mud System Misc:0 NA Knife Valve Open Time: 5 sec P Diverter Misc:NA G AS DETECTORS:Visual Alarm Methane:PP Hydrogen Sulfide:PP Gas Detectors Misc:0NA Total Test Time: 1 hrs Non-Compliance Items: 0 Remarks: Submit to: jlott@hilcorp.com TEST D ATA Joel Sture phoebe.brooks@alaska.gov Hilcorp Tested with 5" DP 0 James lott 0 907-670-3094 TEST D ETA IL S jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov PBU L-240 STATE OF ALASKA AL ASK A OIL AND GAS CONSERVATION COMMISSION Di v er t er Syst em s In s p ec t io n Rep or t GENERA L IN FORMATION WaivedHilcorp *All Di verter r ep o rt s ar e d u e to th e agenc y w i th i n 5 d ay s o f t es ti n g * Form 10-425 (Revised 05/2021)Diverter Hilcorp Innovation 11-1-21.xlsx Date: 11/21/2021 Development: X Exploratory: Drlg Contractor:Rig No. 147 AOGCC Rep: Operator:Oper. Rep: Field/Unit/Well No.:Rig Rep: PTD No.:2210760 Rig Phone: Rig Email: MMISCEL L A NEOUS:DDIVERTER SYSTEM: Location Gen.:P Well Sign:P Designed to Avoid Freeze-up? P Housekeeping:P Drlg. Rig. P Remote Operated Diverter? P Warning Sign P Misc: NA No Threaded Connections? P 24 hr Notice:P Vent line Below Diverter? P A CC UMULATOR SYSTEM:Diverter Size: 21 1/4 in. Systems Pressure:2900 psig P Hole Size: 13 1/2 in. Pressure After Closure:1450 psig P Vent Line(s) Size: 16 in. P 200 psi Recharge Time:19 Seconds P Vent Line(s) Length: 115 ft. P Full Recharge Time:91 Seconds P Closest Ignition Source: 77 ft. P Nitrogen Bottles (Number of):4 Outlet from Rig Substructure: 100 ft. P Avg. Pressure: 2625 psig P Accumulator Misc:NA Vent Line(s) Anchored: P MUD SYSTEM:Visual Alarm Turns Targeted / Long Radius:NA Trip Tank:P P Divert Valve(s) Full Opening: P Mud Pits:P P Valve(s) Auto & Simultaneous: Flow Monitor:P P Annular Closed Time: 29 sec P Mud System Misc:0 NA Knife Valve Open Time: 16 sec P Diverter Misc: NA G AS DETECTORS:Visual Alarm Methane:PP Hydrogen Sulfide:PP Gas Detectors Misc:0NA Total Test Time: 1 hrs Non-Compliance Items: 0 Remarks: Submit to: STATE OF ALASKA AL ASK A OIL AND GAS CONSERVATION COMMISSION Di v er t er Syst em s In s p ec t io n Rep or t GENERA L IN FORMATION WaivedHilcorp *All Di verter r ep o rt s ar e d u e to th e agenc y w i th i n 5 d ay s o f t es ti n g * dyessak@hilcorp.com TEST D ATA B. Davis / P. Lynch phoebe.brooks@alaska.gov Hilcorp Alaska LLC Function tested annular and knife valve with joint 4 1/2" DP in hole. Verified annular holding by slacking off blocks. Performed accumulator draw down test. uadco Rep tested audio and visual gas alarms. Measured vent line and outlet from sub base. Function tested PVT and flow show audio and visual alarm. We have 2 well on diverter signs posted. One at pad entrance one near vent line. 0 D. Yessak / J. Riley 0 907-776-6776 TEST D ETA IL S jim.regg@alaska.gov AOGCC.Inspectors@alaska.gov Ivan River Field Ivan River Unit Well IRU 241-01 Form 10-425 (Revised 05/2021)Diverter Hilcorp 147 11-21-21.xlsx 11 DATE: JOB: LEASE:MRF K-12RD2 215-03268 FIELD:COUNTY / PARISH / API#:/507332015602 AK AFE Budget: FUNC DUE: 8.4 DAILY LOSS:69 1762 SIZE:WT:DEPTH: ID:SIZE/WT/THD://GRADE ID: SIZE:WT:DEPTH: ID:// SIZE:WT:DEPTH: ID:// SIZE:WT:DEPTH: ID:// SIZE/DEPTH: DEPTH:ID:SCSSV: DEPTH:ID: DEPTH:ID: DEPTH:ID: DEPTH:ID: PROD TREE: SMALLEST ID:DEPTH: PBTD:ELEVATION: WD: Packer Fluid: FROM 6:00 11:30 15:00 16:00 17:00 0:00 PREVIOUS DAILY PREVIOUS CUM LAST BOP TEST:11/13/2021 NEXT BOP TEST:11/20/2021 REPORTED BY:Harold Soule CONTRACTOR REP: PHONE FLUID:TYPE:FIW WEIGHT:CUM LOSS: EXP - Supervision/Consultant Code - Description AFE-Company Labor EXP - Contract Labor EXP - Rig EXP - Equipment Rental EXP - Materials & Supplies EXP - Overhead EXP - Transportation – Marine EXP - Transportation – Land EXP - Meals EXP - Casinghead/Wellhead Job Type Exp WO EXP - Workover Insurance EXP - Transportation – Air CUM ACCIDENTS?None Code - Description Job Type Exp WO DAILY INTANGIBLE COSTS 16:00 P/U 4" c/o assy,= 3" BIT, xo, 2 7/8" mud motor, Float sub, xo = 15.61 17:00 R/u surface test motor, 2 BPM,- 430 psi, 3 BPM- 800 psi, r/d circulating line, blow down surface lines. 0:00 RIH p/u 2 3/8" PH6 wk string t/1,116.34' p/u PZL tube and extended ball catcher, RIH w/ 4 3/4" DCs from derrick, surface test motor @ 1,323', 2 BPM = 650 psi, 3 bpm = 1,300 psi. Blow down surface lines. BHA #3 = 3 1/8" bit, XO, Mud motor, Float sub, XO, oil jar, 4 each 4 3/4" DC, Ball catcher, PZL tube, XO = 1,263.25' TO ACTIVITY SUMMARY (Chronological order for the last 24 hrs.) 11:30 M/U 2 3/8" TJ, prep 4" cleanout BHA, l/O & tally 2 3/8" wk string, install test joint, fill surface eq. had leak on test plug, pull test plug, repair deficiency, re-install same, re-fill stack, test upper pipe rams dressed with 2 3/8" rams, 250/2500 good, test annular 250/2500 good, capture closing time on annular 27sec. 15:00 Blow down lines, pull 2 3/8" test joint, r/d test Eq., C/O handling eq to accommodate 2 3/8" tools & wk string., repair backups on 500 Gills PRESENT PERFS:0 to 0 NIPPLES: NIPPLES: NIPPLES: NIPPLES: TBG HD/FLANGE: CASING DATA PRODUCTION TUBING EQUIPMENT DATA / Packer: (907) 776-6754 CONTRACTOR / RIG #:/0 McArthur River Field STATE: PRESENT OPERATION AT REPORT TIME:RIH with BHA #3 @ 7,537’ DAILY COST: CUM. JOB COST: HILCORP ENERGY COMPANY DAILY OPERATIONS REPORT REPORT NO. 11/19/2021 WELL: AFE/PROJ NO: 215-03268 KS K-12RD2 W/O - Replace ESP C/O TANGIBLE COSTS 6:00 RIH with BHA #3 on 3 1/2" PH6 work string out of derrick to 7,537', Filling pipe every 2,000' 10 DATE: JOB: LEASE:MRF K-12RD2 215-03268 FIELD:COUNTY / PARISH / API#:/507332015602 AK AFE Budget: FUNC DUE: 8.4 DAILY LOSS:109 1693 SIZE:WT:DEPTH: ID:SIZE/WT/THD://GRADE ID: SIZE:WT:DEPTH: ID:// SIZE:WT:DEPTH: ID:// SIZE:WT:DEPTH: ID:// SIZE/DEPTH: DEPTH:ID:SCSSV: DEPTH:ID: DEPTH:ID: DEPTH:ID: DEPTH:ID: PROD TREE: SMALLEST ID:DEPTH: PBTD:ELEVATION: WD: Packer Fluid: FROM 6:00 6:30 8:30 12:00 17:00 19:00 20:30 0:00 4:30 PREVIOUS DAILY PREVIOUS CUM 6:00 Make up XOs on 2 3/8" test joint prep to test 2 3/8" rams. 20:30 Cut and slip drilling service rig adjust brakes, rig maintenance. 0:00 Performing maintenance and housekeeping while drilling tools in transit from onshore. 4:30 Continue house keeping and rig maintenance while drilling tools in transit from onshore. TANGIBLE COSTS CUM. JOB COST: HILCORP ENERGY COMPANY DAILY OPERATIONS REPORT REPORT NO. 11/18/2021 WELL: AFE/PROJ NO: 215-03268 KS K-12RD2 W/O - Replace ESP C/O (907) 776-6754 CONTRACTOR / RIG #:/0 McArthur River Field STATE: PRESENT OPERATION AT REPORT TIME:Make up 2 3/8” test joint DAILY COST: CASING DATA PRODUCTION TUBING EQUIPMENT DATA / Packer: NIPPLES: NIPPLES: NIPPLES: NIPPLES: TBG HD/FLANGE: PRESENT PERFS:0 to 0 TO ACTIVITY SUMMARY (Chronological order for the last 24 hrs.) 6:30 Cont.Reverse circ at 9,985' 3.4 bpm @ 340 psi. getting back some scale & couple pieces "P" size gravel, 8:30 R/D swivel, Pull circulating head, C/O handling tools 12:00 POOH standing back 3 1/2" wk string. t/5977', up wt 56k, dn wt 45k 17:00 Cont. POOH standing back 3 1/2" wk string. F/5977', t/ BHA, preformed Annular closing test on last joint of 3 1/2" wk string, closing time= 25 sec. 19:00 Break and lay down BHA #2 CUM ACCIDENTS?None Code - Description Job Type Exp WO DAILY INTANGIBLE COSTS EXP - Casinghead/Wellhead Job Type Exp WO EXP - Workover Insurance EXP - Transportation – Air EXP - Transportation – Marine EXP - Transportation – Land EXP - Meals EXP - Supervision/Consultant Code - Description AFE-Company Labor EXP - Contract Labor EXP - Rig EXP - Equipment Rental EXP - Materials & Supplies EXP - Overhead FLUID:TYPE:FIW WEIGHT:CUM LOSS: LAST BOP TEST:11/13/2021 NEXT BOP TEST:11/20/2021 REPORTED BY:Harold Soule CONTRACTOR REP: PHONE Hilcorp North Slope, LLC 8 November 2021 Commissioner Jeremy Price Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: OTH-21-055, Notice of Violation, Thunderbird Rig 1, PBU S-15 (PTD 1840710) Dear Commissioner Price: Hilcorp received the above referenced Notice of Violation (NOV) on 4 November 2021. The NOV references a Hilcorp submitted blowout prevention equipment (BOPE) system test report from 25 October 2021(attachment 1). The test was performed on PBU Well S-15 with the Thunderbird Rig 1. On the submitted BOPE test report, Hilcorp tested and recorded all required parameters as “P” and one as “FP”. In addition to the normal test paraments listed on the BOPE test report, AOGCC requested Hilcorp record the closure times for this specific test. Since there is not a specific section on the BOPE test form for closure times, the times were simply added to the remarks section. As is the normal practice, after submitting the BOPE test report with all test results marked as “P” and one “FP”, Hilcorp continued operations in good faith. On that same day, after reviewing the submitted BOPE test report, AOGCC notified Hilcorp the annular closing time failed to meet API RP 53 standards, the test was considered a “fail”, and directed Hilcorp retest “when next at surface”. Hilcorp’s company Wellsite Supervisor overseeing the Thunderbird Rig 1 acknowledged receipt of the AOGCC notification and responded: “Understood. Will retest immediately as we have a good opportunity soon and report the results. Will also send 24 hr notice for witness opportunity.” Hilcorp understands that the BOPE test submitted was not a passing test due to the noted annular closure time and Hilcorp will take the below steps to prevent recurrence. In the NOV, AOGCC states that “Hilcorp provided neither evidence of repairs to the annular preventer or well control equipment control systems nor the results of a passing retest prior to the start of the workover operations on PBU S-15. Continued operation with an unresolved failure of safety critical equipment is a violation of AOGCC regulations.” Hilcorp disagrees with this statement and believes Hilcorp did provide “evidence” of BOPE system repairs and modifications in written form to AOGCC via email communications. In addition, although Thunderbird Rig 1 did struggle with closure times, Hilcorp successfully conducted witnessed and/or approved passing closure timed tests and associated pressure tests prior to restarting any operations. 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Bo York Operations Manager byork@Hilcorp.com Phone: 907/777-8345 Fax: 907/777-8560 By Samantha Carlisle at 7:45 am, Nov 15, 2021 Re: OTH-21-055, Notice of Violation, Thunderbird Rig 1, PBU S-15 (PTD 1840710) Page 2 of 4 AOGCC requested in the NOV: 1. Details about performance issues on Thunderbird Rig 1 annular preventer and the BOPE control system 2. What has or will be done in the future to prevent recurrence at Hilcorp operated rigs in Alaska In addition to the AOGCC requested information, Hilcorp will provide details in this response that demonstrate our operations did not continue operation with an unresolved failure of safety critical equipment and were in frequent communication with AOGCC while troubleshooting the issue. Details on Thunderbird Rig 1’s BOPE System Closing Time Issues – Root Causes Identified As noted above, the annular closing time for the Thunderbird’s BOPE system did not close within the API RP 53 allowable time of 30 seconds during the 25 October 2021 BOPE system test. An investigation of the BOPE system identified a number of potential root causes: 1. One accumulator bottle (1 out of 16 x 11 gallon bottles in the system) was found to not be holding a full 1,100 psi pre-charge. 2. Choke points/flow restrictions were present in the system that would contribute to back pressure. 3. One of three air pumps was not functioning correctly. However, this would not affect closure times, only system re-pressurization times after closure. 4. Contaminated hydraulic fluid. 5. System pressures not optimized per manufacturer recommendations. What has or will be done to prevent recurrence on the Thunderbird Rig 1 – this information has been supplied to AOGCC previously, but is consolidated here for reference: 1. Replaced the one accumulator bottle not holding a full charge. 2. Verified all 16 bottles in the accumulator system have 1,100 psi pre-charge. As discussed below, subsequently bumped the pre-charged to ~1,5370 psi. 3. Where possible, removed potential sources of flow restrictions (e.g., connections, elbows, etc). 4. In consultation with the original equipment manufacturer, Control Technology Inc (CTI), increased the accumulator regulator pressure from 1,200 psi to 1,500 psi (nominal pressure). This is the pressure per API that indicates the annular is closed. Note CTI is an API Certified BOPE and accumulator manufacturer with API License 16D-0032, API Certification of Registration for a quality management system Q1-0326 (since 2006), and has an APIQR ISO 9001 Certificate (Cert No. 0596, since 2013). 5. In consultation with CTI, increased the accumulator bottle pre-charge pressure to ~1,537 psi. Calculations provided to AOGCC demonstrate the 16 bottle system maintains 86 gallons of useable fluid at ~1,600 pounds which is more than 150% for total system closure. Re: OTH-21-055, Notice of Violation, Thunderbird Rig 1, PBU S-15 (PTD 1840710) Page 3 of 4 6. CTI Factory Technician flew to slope to perform thorough walk down of system to ensure all components are in proper working order per API specifications. 7. Swapped out 1” system connection fire-rated hose to 1.25” fire-rated hose to remove the potential choke point. Current hard piping on the accumulator system is 1.25”; however, the connection hose was 1”. 8. Replaced the one faulty air pump. 9. Replaced annular preventor regulator gauge. 10. Initially replaced hydraulic system strainers and filtered hydraulic fluids then performed an entire drain and flush of the system. Fluid lab results indicated the hydraulic system was not significantly contaminated. What has or will be done to prevent recurrence on the other rigs in Alaska: 1. Hilcorp will conduct timed closure tests per API 16D on all BOPE systems on other rigs to confirm the systems are closing within allowable times. Initial tests will be performed in November 2021 unless unusual circumstances do not allow the testing. If that is the case, timed closure tests will be performed in December after additional communication with AOGCC. 2. BOPE system failures will be addressed on a case by case basis as individual BOPE systems vary across Hilcorp’s operation Sequence of Events: How this occurred/Root Cause 25 Oct 2021 x 2300 hrs (24 Oct) to 0830 hrs (9.5 hr test), Thunderbird conducted BOPE test on S-15. Witness waived by Bob Noble, AOGCC Inspector. x Morning hours, Arvell Bass (Hilcorp Wellsite Supervisor) called Mr. Noble to discuss the test. Mr. Noble asked that Mr. Bass time and record closure times. Mr. Bass complied. Since there is nowhere on the BOPE test report to log the closure times as it is not a common practice to do so, Mr. Bass included the times in the comments section. x 1326 hrs email from Mr. Bass to AOGCC with a BOPE test report with all “passing” categories attached. Report indicated annular closure time of 42 seconds in the remarks section. At this time, Mr. Bass was unaware that this was not a passing closure time. x 1345 hrs, Having submitted a “passing” BOPE test report, Thunderbird Rig 1 starts to circulate out freeze protect fluids x 1540 hrs email from Mr. Regg responding to Mr. Bass’s BOPE test report submittal notes the 42 second closure time is a failure and “It must be retested when next at surface. Notify for opportunity to witness” x 1643 hrs email from Mr. Bass to Mr. Regg, as noted in the NOV, “Understood. Will retest immediately as we have a good opportunity soon and report the results. Will also send 24 hr notice for witness opportunity.” 26 Oct 2021 Re: OTH-21-055, Notice of Violation, Thunderbird Rig 1, PBU S-15 (PTD 1840710) Page 4 of 4 x 1401 hrs email from Mr. Bass to AOGCC providing notification of retest “in a few hours when we get out of the hole”. In addition, Mr. Bass submitted notice to witness the test via the online system. Continued to work and troubleshoot the accumulator system and closure times in conjunction with requested pressures tests until 28 Oct. Thunderbird Rig 1 operations did not re-commence until AOGCC granted approval on 28 Oct as noted below. 28 Oct 2021 x 1052 hrs email from Jay Murphy (Hilcorp Wellsite Supervisor) to Jim Regg requesting Thunderbird Rig #1 to return to work on S-15 after passing closure time tests and closure pressure tests. x 1457 hrs email from Mr. Regg to Mr. Murphy with approval to return to work with a request for additional information on what work Hilcorp had performed to achieve the passing test. 29 Oct 2021 x 1142 hrs email from David Bjork, Hilcorp Operations Engineer, to Mr. Regg summarizing work done to date plus additional planned actions Based on the above sequence of events, Hilcorp did not continue operations with a known failure of a safety system. Hilcorp submitted a presumed passing BOPE test report and commenced sundried operations. Hilcorp was in communication with AOGCC personnel throughout the BOPE tests and complied with all requests and directives. Hilcorp respectfully requests AOGCC to consider this provided information when considering potential additional action. If you have questions regarding this response please contact me at 907.777.8345 or byork@hilcorp.com. Sincerely, Hilcorp Alaska, LLC Bo York Operations Manager Attachment 1: 25 October 2021 BOPE Test Report Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.11.14 11:43:08 -09'00' Bo York STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Contractor:Rig No.:Thunderbird 1 DATE: 10/25/21 Rig Rep.: Rig Phone: 307-321-6563 Operator: Op. Phone: 907-444-7218 Rep.:E-Mail Well Name: PTD #1840710 Sundry # 321-388 Operation: Drilling: Workover: X Explor.: Test: Initial: X Weekly: Bi-Weekly: Rams: 250/5000 Annular: 250/3000 Valves: 250/3000 MASP: 2470 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.P Well Sign P Upper Kelly 0NA Housekeeping P Rig P Lower Kelly 0NA PTD On Location P Hazard Sec.P Ball Type 1P Standing Order Posted P Misc.NA Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" x 5M P Pit Level Indicators PP #1 Rams 1 2 7/8" x 5" VBR FP Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 0NAH2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NA Quantity Test Result Choke Ln. Valves 1 3 1/8"P Inside Reel valves 0NA HCR Valves 1 3 1/8"P Kill Line Valves 3 3 1/8"P Check Valve 0NAACCUMULATOR SYSTEM: BOP Misc 0NA Time/Pressure Test Result System Pressure (psi)2950 P CHOKE MANIFOLD:Pressure After Closure (psi)1500 P Quantity Test Result 200 psi Attained (sec)22 P No. Valves 11 P Full Pressure Attained (sec)108 P Manual Chokes 1P Blind Switch Covers: All stations Yes Hydraulic Chokes 1P Nitgn. Bottles # & psi (Avg.): 6 @ 2150 P CH Misc 0NA ACC Misc 0NA Test Results Number of Failures:1 Test Time:9.5 Hours Repair or replacement of equipment will be made within days. Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 10/22/21 00:39 Waived By Test Start Date/Time: 10/24/2021 23:00 (date) (time)Witness Test Finish Date/Time: 10/25/2021 8:30 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Bob Noble Hilcorp Test #2 - leak on ram door seal, tightened door and obtained a good test. Test #1 - Re-tested to obtain a better line on chart. Closing times: Annular- 42 Seconds, Pipe Rams- 12 Seconds, Blind Rams- 15 seconds, HCR- 4 Seconds. Initial test on new dual ram to 5000 psi Will Ragsdale/Matt Rivera Hilcorp Arvell Bass/Daniel Scarpella PBU S-15 Test Pressure (psi): pbrwowss@hilcorp.com Form 10-424 (Revised 05/2021) Hilcorp Thunderbird 1 10-25-2021 Attachment 1: 25 October 2021 BOPE Test Report 1 Carlisle, Samantha J (CED) From:Regg, James B (CED) Sent:Thursday, November 4, 2021 9:58 AM To:Bo York Cc:Carlisle, Samantha J (CED) Subject:RE: NOV OTH-21-055 ResponsebyMonday11/15isok JimRegg Supervisor,Inspections AOGCC 333W.7thAve,Suite100 Anchorage,AK99501 907Ͳ793Ͳ1236 From:BoYork<byork@hilcorp.com> Sent:Wednesday,November3,20214:36PM To:Regg,JamesB(CED)<jim.regg@alaska.gov> Subject:NOVOTHͲ21Ͳ055 JimͲ ReceivedtheNOVre:BOPtesttimestoday.Itisdated1Nov.Wehave14daystorespond.ThatwouldbeSunday,14 Nov.IsrespondingonMonday,15NovokordoIneedtosubmitbyFriday12Nov? Thankyou. BoYork HilcorpAlaskaLLC PBEOperationsManager byork@Hilcorp.com 907.777.8345Anchorageoffice 907.659.5149PBOCoffice 907.727.9247cell 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. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov November 1, 2021 CERTIFIED MAIL – RETURN RECEIPT REQUESTED 7018 0680 0002 2052 9457 Mr. Bo York Hilcorp North Slope LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Docket Number: OTH-21-055 Notice of Violation Thunderbird Rig 1 Prudhoe Bay Unit S-15 (PTD 1840710) Dear Mr. York: On October 25, 2021, the Alaska Oil and Gas Conservation Commission (AOGCC) received a report for a 13 5/8-inch blowout prevention equipment (BOPE) system test completed early that same day. The test was performed on Hilcorp Thunderbird Rig 1 while preparing for a tubing workover of Prudhoe Bay Unit S-15. Hilcorp reported the annular close time was 42 seconds, calling the test result a pass. By email dated October 25, 2021 AOGCC notified Hilcorp North Slope LLC (Hilcorp) that the annular closing time exceeds the allowed closing time, the test report should be changedto “F” (Fail), and that the annular preventer must be retested when the workover string is next at surface. Hilcorp’s Thunderbird rig representative responded: “Understood. Will retest immediately as we have a good opportunity soon and report the results. Will also send 24 hr notice for witness opportunity.” Secondary well control for tubing workover operations (blowout preventer requirements) are addressed in 20 AAC 25.285. Paragraph (a) notes that workover operations performed with the tree removed are also subject to the requirements of 20 AAC 25.527 which incorporates by reference API RP 53, “Recommended Practices for Blowout Prevention Equipment Systems for Drilling Wells”.1 Closing time for an annular preventer that is less than 18 ¾ inches (close on pipe and affect a pressure seal) is within 30 seconds. 1 API RP 53 has been superseded by API Standard 53, “Well Control Equipment Systems for Drilling Wells”, 5th Edition, December 2018. The annular close response times and description of what constitutes “closed” are unchanged. Docket Number: OTH-21-055 November 1, 2021 Page 2 of 2 For a passing annular preventer performance test, Hilcorp needed to demonstrate a closure response time for the well control packing element which was within 30 seconds, and the ability to hold the required test pressure for at least 5 minutes. Hilcorp provided neither evidence of repairs to the annular preventer or well control equipment control systems nor the results of a passing retest prior to the start of workover operations on PBU S-15. Continued operation with an unresolved failure of safety critical equipment is a violation of AOGCC regulations. Within 14 days of receipt of this letter, you are requested to provide the AOGCC with a written description of how this occurred (root cause), details about performance issues on Thunderbird Rig 1 annular preventer and the BOPE control system, and what has or will be done in the future to prevent recurrence at Hilcorp-operated rigs in Alaska. Information requested in this notice is in accordance 20 AAC 25.300; failure to comply with this request will be an additional violation. The AOGCC reserves the right to pursue additional enforcement action in connection with this Notice of Violation. Questions regarding this letter should be directed to Jim Regg at (907) 793- 1236 (email: jim.regg@alaska.gov). Sincerely, Jeremy M. Price Commissioner, Chair cc: AOGCC Inspectors Phoebe Brooks, AOGCC Jeremy Price Digitally signed by Jeremy Price Date: 2021.11.01 11:06:10 -08'00' 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: 5/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250523 Well API #PTD #Log Date Report Type AOGCC E-Set# PBU S-10APB1 50029207657000 191123 10/20/1991 Directional Survey PBU S-10APB2 50029207657100 191123 10/29/1991 Directional Survey PBU S-15PB1 50029211137000 184071 07/04/1984 Directional Survey PBU S-16PB1 50029211237000 184082 08/16/1984 Directional Survey Please include current contact information if different from above. 184-084 T40442 T40443 T40444 T40445 PBU S-15PB1 50029211137000 184071 07/04/1984 Directional Survey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.27 08:30:54 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240116 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 09A 50133204450100 224113 10/26/2024 YELLOWJACKET SCBL BCU 12A 50133205300100 214070 8/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 233-23T 50283202000000 224088 12/28/2024 AK E-LINE PPROF BRU 233-27 50283100260000 163002 12/31/2024 AK E-LINE PPROF BRU 243-34 50283201240000 208079 12/27/2024 AK E-LINE PPROF GP 03-87 50733204370000 166052 12/25/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/16/2024 AK E-LINE CBL GP AN-17A 50733203110100 213049 12/21/2024 AK E-LINE Perf GP BR-03-87 50733204370000 166052 1/3/2025 AK E-LINE CBL IRU 44-36 50283200890000 193022 1/3/2024 AK E-LINE Depth Determination/Plug IRU 44-36 50283200890000 193022 12/26/2024 AK E-LINE DepthDetermination KU 31-07X 50133204950000 200148 12/3/2024 AK E-LINE Perf MPU B-21 50029215350000 186023 1/4/2025 AK E-LINE PlugSettingRecord MPU H-08B 50029228080200 201047 12/28/2024 AK E-LINE Welltech MRU G-01RD 50733200370100 191139 12/12/2024 AK E-LINE IPROF MRU G-01RD 50733200370100 191139 12/18/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/3/2024 AK E-LINE Perf MRU M-25 50733203910000 187086 12/19/2024 AK E-LINE Perf PBU 01-37 50029236330000 219073 11/23/2024 HALLIBURTON PPROF PBU 06-05 50029202980000 178020 12/21/2024 HALLIBURTON RBT PBU 06-19B 50029207910200 224095 12/11/2024 HALLIBURTON RBT PBU 11-38A 50029227230100 198216 11/27/2024 HALLIBURTON TEMP PBU 14-31A 50029209890100 224090 11/11/2024 HALLIBURTON RBT PBU L-103 50029231010000 202139 11/25/2024 HALLIBURTON IPROF PBU M-207 50029238070000 224141 12/25/2024 HALLIBURTON RBT PBU P2-55 50029222830000 192082 12/5/2024 HALLIBURTON PPROF PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT TBU M-25 50733203910000 187086 12/13/2024 AK E-LINE Perf T39958 T39959 T39960 T39961 T39962 T39963 T39964 T39964 T39965 T39966 T39966 T39967 T39968 T39969 T39970 T39970 T39971 T39971 T39972 T39973 T39974 T39975 T39976 T39977 T39978 T39979 T39980 T39981 PBU S-15 50029211130000 184071 11/18/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.16 13:56:40 -09'00' Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 07/31/2023 InspectNo:susKPS230621131235 Well Pressures (psi): Date Inspected:6/21/2023 Inspector:Kam StJohn If Verified, How?Other (specify in comments) Suspension Date:12/26/2022 #322-688 Tubing:310 IA:318 OA:0 Operator:Hilcorp North Slope, LLC Operator Rep:Ryan Holt Date AOGCC Notified:6/21/2023 Type of Inspection:Initial Well Name:PRUDHOE BAY UNIT S-15 Permit Number:1840710 Wellhead Condition The was clean and all valves had gauges. No sign of leaks everything looked in good condition Surrounding Surface Condition No sheen anywhere and condition of wellhouse and surounding area clean Condition of Cellar Had some ice, well below valves. Comments location verified by pad map Supervisor Comments Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, July 31, 2023             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 S-15 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 184-071 50-029-21113-00-00 11960 Conductor Surface Intermediate Production Liner 9208 75 2480 11281 1379 4854 20" 13-3/8" 9-5/8" 7" 4601 28 - 103 28 - 2508 26 - 11307 10581 - 11960 28 - 103 28 - 2508 26 - 8770 8278 - 9208 None 2670 4760 5410 4854, 11317 4930 6870 7240 11384 - 11715 4-1/2" 12.6# L80 24 - 2555, 7002 - 10631 8823 - 9046 Structural 4-1/2" Brown Packer 10524, 8241 10524 8241 Torin Roschinger Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 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 0028257 24 - 2555, 6034 - 8310 N/A N/A Well Not Online Well Not Online 250 300 0 0 N/A 13b. Pools active after work:Prudhoe Oil Pool 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 8:25 am, Jun 29, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.28 16:37:41 -08'00' Torin Roschinger (4662) DSR-6/29/23WCB 1-10-2024 RBDMS JSB 120723 ACTIVITY DATE SUMMARY 6/20/2023 T/I/O = SSV/300/0. Temp = SI. Pre-Suspended well inspection. Well is disconnected from the system, no flowline or scaffold. Area around well is clean of debris. SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 11:00 6/21/2023 T/I/O = 310/318/0. Temp = SI. AOGCC Witness Kam StJohn SU well inspection. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:15 Daily Report of Well Operations PBU S-15 AOGCC W itness Kam StJohn SU well inspection WELL COMPLETION OR RECOMPLETION REPORT AND LOG 2494 cu ft Class G w 8% Gel, 230 cu ft Class G, 279 cu ft Permafrost C F F F F F F Suspended 12/26/2022 JSB RBDMS JSB 030123 Received 1/25/2023 xGDSR-3/3/23MGR28JULY2023 28. CORE DATA Conventional Cores(s): Yes No Sidewall Cores(s): Yes No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and persence of oil, gas or water (submit separate pages with this form if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)30. FORMATION TESTS Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this for, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. MD TVDNAME Permafrost - Top Permafrost - Base Top of Productive Interval Formation Name at TD: 31. List of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071 Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Stan Golis Sr. Area Operations Manager Oliver Sternicki Oliver.Sternicki@hilcorp.com 907.564.4891 8748'11379' Well Service Reports, Wellbore schematic Sag River Shublik Ivishak 11379' 11434' 11582' 8748' 8786' 8887' Ivishak 11582' 8887' Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.01.24 18:54:00 -09'00' Stan Golis (880) ACTIVITY DATE SUMMARY 12/25/2022 ***HES UNIT 759 WEATHER HOLD**** **********CONT, ON 12/26/2022********** 12/26/2022 ** ASSIST SL** State witnessed combo by Sully Sullivan CMIT T x IA (PASSED ) to 2382/2390/4 Pumped 4.9 bbls diesel in for test and bled 4.6 bbls back FWHP's 2/13/0 SL on well at time of departure. 12/26/2022 ***CONT WSR FROM 12/25/2022*** LRS PERFORMED PASSING AOGCC STATE WITNESSED CMITxIA TO 2300# TAG CEMENT @ 4,854' SLM W/ 2.5" BAILER - WITNESSED BY SULLY SULLIVAN ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** Daily Report of Well Operations PBU S-15 CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Abbie Barker To:Brooks, James S (OGC) Subject:RE: [EXTERNAL] FW: PBU S-15 (PTD #184-071) 10-407 Report Submittal Date:Friday, February 24, 2023 1:41:29 PM Attachments:image002.pngimage003.png James, The corrected TPI for Sag River is 11379’ MD. The coordinates for this depth are X – 621086 and Y – 5984800. These coordinates place TPI at 1998’ FNL, 2271’ FEL, Sec. 26, T12N, R12E, UM ,AK. According to the screen shot you provided (see below), the error is that the 2271’ should be FEL, not FWL. Please let me know if you have any questions. Thanks, Thanks, 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 From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Friday, February 24, 2023 9:20 AM To: Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: [EXTERNAL] FW: PBU S-15 (PTD #184-071) 10-407 Report Submittal Hi, I am following up on this issue as the tpi X value is still off. Can you look into this ? I am using Sag River 11379/8748 as tpi value thanx From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Thursday, February 9, 2023 2:40 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: [EXTERNAL] FW: PBU S-15 (PTD #184-071) 10-407 Report Submittal Hi James, See attached corrected 10-407 form. My error was using an incorrect formation top (Shublik instead of Sag River) as the TPI. Please let me know if you need additional information. Abbie From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Wednesday, February 8, 2023 8:17 AM To: Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: [EXTERNAL] FW: PBU S-15 (PTD #184-071) 10-407 Report Submittal Hi, I am a bit confused by your response. I do not have any coordinates other than the ones provided on the 407 which are off. Can you resubmit a new 407 with the right coordinate and I can enter them in our database. thanx From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Tuesday, February 7, 2023 3:57 PM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: RE: [EXTERNAL] FW: PBU S-15 (PTD #184-071) 10-407 Report Submittal Hello James, Apologies in the delay getting back to you. I reviewed the submittal and the issue is that I used the incorrect interval for X&Y coordinates. Yours are correct for the Sag River. Thank you for your assistance, 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 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From: Brooks, James S (OGC) <james.brooks@alaska.gov> Sent: Friday, February 3, 2023 8:16 AM To: Abbie Barker <Abbie.Barker@hilcorp.com> Subject: [EXTERNAL] FW: PBU S-15 (PTD #184-071) 10-407 Report Submittal Hi, Can you check coordinates on this one as it is a little off: thanx From: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Sent: Wednesday, January 25, 2023 8:58 AM To: Brooks, James S (OGC) <james.brooks@alaska.gov> Subject: FW: PBU S-15 (PTD #184-071) 10-407 Report Submittal From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Wednesday, January 25, 2023 8:41 AM To: AOGCC Permitting (CED sponsored) <aogcc.permitting@alaska.gov> Cc: Claire Mayfield <Claire.Mayfield@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; David Douglas <David.Douglas@hilcorp.com>; Joseph Lastufka <Joseph.Lastufka@hilcorp.com> Subject: PBU S-15 (PTD #184-071) 10-407 Report Submittal Hello, Please see the attached 10-407 Report of PBU S-15 Well Suspension. If you have any questions or need additional information, please let me know. Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp North Slope Email: Abbie.Barker@hilcorp.com 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. 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 regardand the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 35 Township: 12N Range: 12E Meridian: Umiat Drilling Rig: n/a Rig Elevation: n/a Total Depth: 11960 ft MD Lease No.: ADL 028257 Operator Rep: Suspend: X P&A: Conductor: 20" O.D. Shoe@ 103 Feet Csg Cut@ Feet Surface: 13 3/8" O.D. Shoe@ 2508 Feet Csg Cut@ Feet Intermediate: 9 5/8" O.D. Shoe@ 11307 Feet Csg Cut@ Feet Production: O.D. Shoe@ Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 9208 Feet Csg Cut@ Feet Tubing: 4.5" O.D. Tail@ 10631 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Retainer 6000 ft 4854 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 2540 2434 2382 IA 2545 2440 2390 OA 3 3 4 Remarks: Attachments: Brad Elias Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Verification of isolation plug above Schrader Bluff formation for well suspension. PBU S-15 changed to water injector 11/25/2022; failed attempt at remedial cement squeeze led to decision to suspend well to evaluate for future redrill. Initial plug tag (prior to CMIT TxIA) found at 4852 ft MD; tag after test at 4284 ft MD. December 26, 2022 Sully Sullivan Well Bore Plug & Abandonment PBU S-15 Hilcorp North Slope LLC PTD 1840710; Sundry 322-688 none Test Data: P Casing Removal: rev. 3-24-2022 2022-1226_Plug_Verification_PBU_S-15_ss 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 Conductor Surface Intermediate Production Liner 2670 4760 5410 Structural Date: Current Pools:Proposed Pools: 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 December 3, 2022 State to witness slickline tag and cement plug CMIT-TxIA pressure test to 2300 psi. AOGCC witnessed well site inspection within 12 months of initial well inspection. Suspension approved for 5 years. MGR07DEC22 DSR-12/5/22 10-404 after within 30 days of initial well inspection. SFD 12/5/2022GCW 12/08/22 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.12.08 11:14:22 -09'00' RBDMS JSB 020223 Well Suspension WELL: S-15 PTD:184-071 Well Name:S-15 API Number:50-029-21113-00-00 Current Status:Shut-In Rig:SL Estimated Start Date:12/19/2022 Permit to Drill Number:184-071 First Call Engineer:Wyatt Rivard 907-777-8547 (O) 509-670-8001 M Second Call Engineer:Brodie Wages 907-564-4763 (O) 907-440-7692 M Max. Anticipated BHP for Schrader:2314psi @ 5000’ TVD 8.9 PPGE (Est. from S-15 and W-212 RWO) Max. Anticipated Surface Pressure:2,470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:0 psi (Taken on 11/30/22) Min ID:3.725” ID XN Nipple @ 10,566’ MD Max Angle:60 Deg @ 9,400’ Well Summary and Status: S-15 is an Ivishak Not Operable produced water injector that has been SI since 2010 and secured since June 2015. The well’s Ivishak (Prudhoe Oil Pool) perforations were abandoned with a 25’ cement plug and an AOGCC witnessed MIT-T to 2500 psi on 9/11/21. A passing CMIT-TxIA was obtained to 2500 psi on 9/14/21 and a workover was attempted to recomplete the well as a Schrader Bluff (Polaris Oil Pool) Injector. As part of the RWO, well was circulated and left with 9.0 ppg KWF above the Ivishak abandonment plug. After pulling tubing, a CBL of the 9-5/8” casing showed insufficient cement for isolation of injection fluids. A CIBP was set at 6000’MD and a cement squeeze was attempted on rig but failed due to cement retainer failure with cement returned inside the 9-5/8” casing. A follow-up cement squeeze was attempted with coil tubing in Nov 2022 however heavy losses resulted in only half the planned cement volume circulating behind 9-5/8” casing. Subsequent CBL was indeterminate with poor logging response on CBL amplitude, but VDLshowed no relative change or formation returns across the zone that was squeezed when compared to un-squeezed intervals. A subsequent MIT failed at .9BPM at ~1500 psi indicating squeeze was ultimately unsuccessful. Prior to rigdown, CTU laid in a cement plug up from existing CIBP/retainer cement (6000’ MD) up to ~5000’ to complete isolation of the Schrader Bluff. The Schrader Bluff formation is confined between shale zones between 5240’ MD (upper confining layer) and 5970’ MD (lower confining layer). The Ivishak has been abandoned and Schrader bluff isolated. The Kuparuk formation (Aurora Oil Pool) was never opened in this well and remains isolated behind cemented 9-5/8” casing and bounded by the Schrader Bluff and Ivishak isolation plugs within the wellbore. The well will not damage freshwater or producing formations or allow migration of fluids to surface. An unwitnessed CMIT-TxIA passed to 2000 psi on 11/30/22 against cement plug at ~5000’MD. As part of this suspension, an AOGCC witnessed tag and pressure test of the plug will be obtained. The well is on an active, well-maintained pad. Production and surface casing have good integrity and well has future utility as a sidetrack candidate. The strata through which the well was drilled is neither abnormally geo- pressured or depleted. Variance A variance to the provisions of 20 AAC 25.110 (c)(2) is requested under 20 AAC 25.112(i) to allow the well to remain suspended in its current condition with optionality for future sidetrack. Hydrocarbon intervals are isolated and there are no underground sources of freshwater in this area. Notes Regarding Wellbore Condition: An SC leak at 21’ was sealed off with a cement conductor top job in 2021. Ivishak perfs were abandoned with high expansion plug and 25’ cement set at ~11351’ MD with passing pressure test to 2500psi. squeeze was ultimately unsuccessful. Well Suspension WELL: S-15 PTD:184-071 CMIT-TxIA passed to 2000 psi 11/30/22 confirming production casing integrity above the cement plug (TOC @ ~5000’ MD). Objective: Pressure test and tag cement plug isolation above Schrader Bluff formation to complete suspension of the well. Sundry Procedure (Approval required to proceed): Slickline & Hot Oil 1. Notify AOGCC at least 24hrs prior to tagging and pressure test for opportunity to witness. 2. MIRU SL and PT. 3. MU SL drift & bailer. 4. RIH and tag TOC (estimated at ~5000’ MD). 5. CMIT-TxIA to 2300 psi a. Chart test b. 9-5/8” casing shoe at 8770’ TVD c. Min test pressure = 2192 psi. 6. RDMO DHD 1. Perform suspended well inspection within 12 months of initial suspension a. Notify AOGCC at least 10 daysprior to suspended well inspection for opportunity to witness. Attachments: 1. Wellbore Schematic 2. Sundry Change Form Well Suspension WELL: S-15 PTD:184-071 S-15 Wellbore Schematic Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry Procedure Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 12/02/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20221202 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-34 50283201860000 222039 11/22/2022 AK E-Line Perf BRU 233-23 50283201360100 222050 11/3/2022 AK E-Line GPT BRU 244-27 50283201850000 222038 11/23/2022 AK E-Line Perf GPT CLU 05RD2 50133204740200 222092 11/17/2022 AK E-Line Perf MPU K-34 50029227120000 196169 11/10/2022 AK E-Line Punch CLU 13 50133206460000 214171 11/12/2022 Halliburton SBHP END 3-25B 50029221250200 203021 11/24/2022 Halliburton PPROF PBU S-15 50029211130000 184071 11/24/2022 Halliburton RBT PBU Z-221 50029237040000 221095 11/17/2022 Halliburton IPROF PBU Z-221 50029237040000 221095 11/19/2022 Halliburton IPROF Please include current contact information if different from above. T37345 T37346 T37347 T37348 T37349 T37350 T37351 T37352 T37353 T37353 By Meredith Guhl at 12:25 pm, Dec 02, 2022 PBU S-15 50029211130000 184071 11/24/2022 Halliburton RBT Meredith Guhl Digitally signed by Meredith Guhl Date: 2022.12.02 12:24:17 -09'00' 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: Attempted Remedial Cement Squ Conductor Surface Intermediate Production Liner 2670 4760 5410 Structural 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: 13b. Pools active after work: 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 RBDMS JSB 120822 WCB 11-29-2024 DSR-12/1/22 The CBL is a COA of Sundry 322-558. The CBL was emailed to the AOGCC on 11-25-2022. 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Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2022.09.23 13:20:03 -08'00' RBDMS JSB 092922 dh^ƋƵĞĞǌĞWƌŽĐĞĚƵƌĞ t>>͗^Ͳϭϱ Wd͗ϭϴϰͲϬϳϭ tĞůůEĂŵĞ͗^ͲϭϱW/EƵŵďĞƌ͗ϱϬͲϬϮϵͲϮϭϭϭϯͲϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ŚƵƚͲ/ŶZŝŐ͗dh͕> ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϭϬͬϲͬϮϬϮϮWĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϴϰͲϬϳϭ &ŝƌƐƚĂůůŶŐŝŶĞĞƌ͗tǇĂƚƚZŝǀĂƌĚ ϵϬϳͲϳϳϳͲϴϱϰϳ;KͿ ϱϬϵͲϲϳϬͲϴϬϬϭD ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ƌĂƐtŽƌƚŚŝŶŐƚŽŶ ϵϬϳͲϱϲϰͲϰϳϲϯ;KͿ ϵϬϳͲϰϰϬͲϳϲϵϮD DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ,WĨŽƌ^ĐŚƌĂĚĞƌ͗ϮϯϭϰƉƐŝΛϱϬϬϬ͛dsϴ͘ϵWW';ƐƚŝŵĂƚĞĚĨƌŽŵtͲϮϭϮZtKͿ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗Ϯ͕ϰϳϬƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ^/t,W͗ϬƉƐŝ ;dĂŬĞŶŽŶϭϭͬϭϱͬϮϭͿ DŝŶ/͗ϯ͘ϳϮϱ͟/yEEŝƉƉůĞΛϭϬ͕ϱϲϲ͛D DĂǆŶŐůĞ͗ϲϬĞŐΛϵ͕ϰϬϬ͛ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ ^ͲϭϱŝƐĂŶ/ǀŝƐŚĂŬEŽƚKƉĞƌĂďůĞWƌŽĚƵĐĞĚtĂƚĞƌ/ŶũĞĐƚŽƌ ƚŚĂƚǁĂƐƌĞĐĞŶƚůǇ ƌĞƐĞƌǀŽŝƌĂďĂŶĚŽŶĞĚĂŶĚ ĚĞĐŽŵƉůĞƚĞĚĂƐƉĂƌƚŽĨĂZtKƚŽĐŽŶǀĞƌƚǁĞůůƚŽŝŶũĞĐƚŝŽŶŝŶƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨĨŽƌŵĂƚŝŽŶŝŶEŽǀϮϬϮϭ͘ĨƚĞƌ ĚĞĐŽŵƉůĞƚŝŽŶ͕ĂďŽŶĚůŽŐǁĂƐƌƵŶĂĐƌŽƐƐƚŚĞϵͲϱͬϴ͟ĐĂƐŝŶŐƐŚŽǁŝŶŐdKďĞůŽǁ ^ĐŚƌĂĚĞƌůƵĨĨ͘ ŶĂƚƚĞŵƉƚƚŽƌĞŵĞĚŝĂůƐƋƵĞĞǌĞƚŚĞϵͲϱͬϴ͟ĐĂƐŝŶŐǁĂƐƉĞƌĨŽƌŵĞĚŽŶƌŝŐǁŝƚŚĐĂƐŝŶŐŚŽůĞƐƉƵŶĐŚĞĚĂďŽǀĞĂŶĚ ďĞůŽǁƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨ͘ ŝƌĐƵůĂƚŝŽŶǁĂƐĞƐƚĂďůŝƐŚĞĚďĞŚŝŶĚƉŝƉ 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ƐŚĞĂƚŚŚĂĚŝƐŽůĂƚĞĚϱϮϯϬ͛ͲϱϮϰϬ͛DĐĂƐŝŶŐƉƵŶĐŚŚŽůĞƐ͘ x /ǀŝƐŚĂŬƉĞƌĨƐǁĞƌĞĂďĂŶĚŽŶĞĚǁŝƚŚ ŚŝŐŚĞǆƉĂŶƐŝŽŶƉůƵŐĂŶĚϮϱ͛ĐĞŵĞŶƚƐĞƚĂƚΕϭϭϯϱϭ͛DǁŝƚŚƉĂƐƐŝŶŐ ƉƌĞƐƐƵƌĞƚĞƐƚƚŽϮϱϬϬƉƐŝ͘ x ŶD/dͲ/ƉĂƐƐĞĚƚŽϮϱϬϬƉƐŝŽŶ ϵͬϭϰͬϮϬϮϭ ǀĞƌŝĨǇŝŶŐWŝŶƚĞŐƌŝƚǇƉƌŝŽƌƚŽĐĂƐŝŶŐƉƵŶĐŚĞƐ͘ x tĞůůǁĂƐůĞĨƚǁŝƚŚϵ͘ϬWW'ďƌŝŶĞĂŶĚĨƌĞĞǌĞƉƌŽƚĞĐƚĞĚǁŝƚŚϭϳϬďďůƐŽĨĚŝĞƐĞů KďũĞĐƚŝǀĞ͗ WĞƌĨŽƌŵĂƌĞŵĞĚŝĂůĐĞŵĞŶƚƐƋƵĞĞǌĞŽĨϵͲϱͬϴ͟ĐĂƐŝŶŐƚŽĞƐƚĂďůŝƐŚŝƐŽůĂƚŝŽŶĂĐƌŽƐƐƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨĂŶĚ ƉƌĞƉĂƌĞǁĞůůĨŽƌĨƵƚƵƌĞƌĞĐŽŵƉůĞƚŝŽŶĂƐ^ĐŚƌĂĚĞƌůƵĨĨŝŶũĞĐƚŽƌ͘ ^ƵŶĚƌǇ WƌŽĐĞĚƵƌĞ;ƉƉƌŽǀĂůƌĞƋƵŝƌĞĚƚŽƉƌŽĐĞĞĚͿ͗ Ͳ>ŝŶĞ ϭ͘ D/Zh > ĂŶĚWd Ϯ͘ Dh ϭϬ͛,^ŐƵŶǁŝƚŚ ďŝŐŚŽůĞĐŚĂƌŐĞƐ͘ '/% '/% WĞƌĨŽƌŵĂƌĞŵĞĚŝĂůĐĞŵĞŶƚƐƋƵĞĞǌĞŽĨϵͲϱͬϴ͟ĐĂƐŝŶŐƚŽĞƐƚĂďůŝƐŚŝƐŽůĂƚŝŽŶĂĐƌŽƐƐƚŚĞ^ĐŚƌĂĚĞƌůƵĨĨĂŶĚ ƉƌĞƉĂƌĞǁĞůůĨŽƌĨƵƚƵƌĞƌĞĐŽŵƉůĞƚŝŽŶĂƐ^ĐŚƌĂĚĞƌůƵĨĨŝŶũĞĐƚŽƌ͘ dh^ƋƵĞĞǌĞWƌŽĐĞĚƵƌĞ t>>͗^Ͳϭϱ Wd͗ϭϴϰͲϬϳϭ ϯ͘ Z/,ĂŶĚ ŽƌƌĞůĂƚĞƚŽ,^>ĚĂƚĞĚϭϬͲEKsͲϮϭ͘ŽŶƚĂĐƚ K tǇĂƚƚZŝǀĂƌĚϭ;ϱϬϵͿϲϳϬͲϴϬϬϭŽƌƌĂƐ tŽƌƚŚŝŶŐƚŽŶ ϵϬϳͲϰϰϬͲϳϲϵϮ ĨŽƌĨŝŶĂůĂƉƉƌŽǀĂůŽĨƚŝĞͲŝŶ͘ ϰ͘ WĞƌĨŽƌĂƚĞ ΕϱϵϬϬͲϱϵϭϬ͛D͘ ϱ͘ ŽŶĨŝƌŵŝŶũĞĐƚŝǀŝƚǇƚŚƌŽƵŐŚĐĂƐŝŶŐƉƵŶĐŚĞƐĂƚůĞĂƐƚϮWD͘ŽŶŽƚĞǆĐĞĞĚϭϱϬϬƉƐŝŝŶũĞĐƚŝŽŶƉƌĞƐƐƵƌĞ͘ Ă͘KŶƉƌĞǀŝŽƵƐƐƋƵĞĞǌĞĂƚƚĞŵƉƚ͕ŝŶũĞĐƚŝŽŶĞƐƚĂďůŝƐŚĞĚĂƚϭWDĂƚϴϬϬƉƐŝĂŶĚϮWDĂƚϵϱϬƉƐŝ͘ ď͘Z/,ĂŶĚƐŚŽŽƚĂĚĚŝƚŝŽŶĂůϭϬ͛,^ŐƵŶĨƌŽŵΕϱϴϵϬ͛ͲϱϵϬϬ͛DŝĨŶĞĞĚĞĚƚŽĞƐƚĂďůŝƐŚŝŶũĞĐƚŝŽŶĂƚ ϮWDфϭϱϬϬƉƐŝ͘ ϲ͘ Dh ƐĞĐŽŶĚ ϭϬ͛,^ŐƵŶǁŝƚŚŝŐŚŽůĞĐŚĂƌŐĞƐ͘ ϳ͘ Z/,ĂŶĚŽƌƌĞůĂƚĞƚŽ,^>ĚĂƚĞĚϭϬͲEKsͲϮϭ͘ŽŶƚĂĐƚ K tǇĂƚƚZŝǀĂƌĚϭ;ϱϬϵͿϲϳϬͲϴϬϬϭŽƌƌĂƐ tŽƌƚŚŝŶŐƚŽŶ ϵϬϳͲϰϰϬͲϳϲϵϮ ĨŽƌĨŝŶĂůĂƉƉƌŽǀĂůŽĨƚŝĞͲŝŶ͘ ϴ͘ WĞƌĨŽƌĂƚĞΕϱϮϰϬͲϱϮϱϬ͛D͘ ϵ͘ Dh ϮϬ͛ƐƚƌŝŶŐƐŚŽƚ͘ ϭϬ͘ Z/,ĂŶĚĨŝƌĞƐƚƌŝŶŐƐŚŽƚƚŽ ĐůĞĂƌ ĂŶǇ ůŽŽƐĞ ĐĞŵĞŶƚ ƐŚĞĂƚŚĨƌŽŵϱϴϳϱ͛Ͳϱϴϵϱ͛ƉƌŝŽƌƚŽ dh ĐĞŵĞŶƚ ƌĞƚĂŝŶĞƌ ƐĞƚ͘ ϭϭ͘ ZDK dh ϭϮ͘ D/Zh dhĂŶĚWd ϭϯ͘ Dh'Zͬ>ĚƌŝĨƚ͘ ϭϰ͘ Z/,ĂŶĚůŽŐ ĨƌŽŵdƚŽϱϭϱϬ͛D͘ ϭϱ͘ &ůĂŐƚŚĞůŝŶĞ Ăƚ ĐĞŵĞŶƚ ƌĞƚĂŝŶĞƌƐĞƚĚĞƉƚŚŽĨ Εϱϴϴϱ͛D͘ ϭϲ͘ ŝƌĐƵůĂƚĞǁĞůůŽǀĞƌƚŽϴ͘ϰWW'ϭй <>͕ůĞĂǀŝŶŐ ǁĞůůƐůŝŐŚƚůǇƵŶĚĞƌďĂůĂŶĐĞĚĂŚĞĂĚ ŽĨ ƐƋƵĞĞǌĞ͘ Ă͘ tĞůůďŽƌĞǀŽůƵŵĞсϰϳϬďďůƐ ϭϳ͘ WKK,ĂŶĚĐŽŶĨŝƌŵŐŽŽĚĚĂƚĂ͘ŽƌƌĞĐƚĨůĂŐƚŽ ,^>ĚĂƚĞĚϭϬͲEKsͲϮϭ͘ ϭϴ͘ WhϯͲϯͬϴ͟ǆ ϵͲϱͬϴ͟ /ŶĨůĂƚĂďůĞ ĞŵĞŶƚZĞƚĂŝŶĞƌ ĂŶĚZ/,ƚŽƐĞƚĚĞƉƚŚŽĨ Εϱϴϴϱ͛D ϭϵ͘ ƐƚĂďůŝƐŚ ŝŶŝƚŝĂů ŝƌĐƵůĂƚŝŶŐ WƌĞƐƐƵƌĞ ;WͿ ĂƚΕϮWD ƉƵŵƉƌĂƚĞ ǁŝƚŚϭй<> ĨŽƌ ƵƐĞĚƵƌŝŶŐƐƋƵĞĞǌĞ͘ ϮϬ͘ ^Ğƚ ŝŶĨůĂƚĂďůĞ ƌĞƚĂŝŶĞƌ ĂŶĚƐƚĂĐŬƐƵĨĨŝĐŝĞŶƚǁĞŝŐŚƚƚŽĐŽŶĨŝƌŵ ŝŶĨůĂƚĂďůĞ ƌĞƚĂŝŶĞƌ ĞŶŐĂŐĞĚŝŶĐĂƐŝŶŐ͘ Ϯϭ͘ ŽŶĚŝƚŝŽŶƚŚĞ ϵͲϱͬϴ͟ǆK,ĂŶŶƵůƵƐ ƚŚĞŶƉƵŵƉĐĞŵĞŶƚĂƐĨŽůůŽǁƐ͗ ͘ WƵŵƉ ΕϰϬďďůƐ ϭй<> ƚŚƌŽƵŐŚƌĞƚĂŝŶĞƌƚĂŬŝŶŐƌĞƚƵƌŶƐĨƌŽŵƚŚĞ / x WƵŵƉĂƚΕϮWD͕ĚŽŶŽƚĞǆĐĞĞĚϭϱϬϬƉƐŝŽǀĞƌ W ƚŽĂǀŽŝĚĨƌĂĐƚƵƌŝŶŐĨŽƌŵĂƚŝŽŶ x ϯͲϯͬϴ͟ŝŶĨůĂƚĂďůĞƉĂĐŬĞƌŝƐƌĂƚĞĚĨŽƌΕϮϯϬϬƉƐŝĚŝĨĨĞƌĞŶƚŝĂůĞǆƉĂŶĚĞĚŝŶ ϵͲϱͬϴ͟ĐĂƐŝŶŐ ͘ WƵŵƉΕϰϬ ďďůƐ ϭϱ͘ϴ ƉƉŐůĂƐƐ'ĞŵĞŶƚ;ŝŶĐƌĞĂƐĞ ǀŽůƵŵĞƉƌŽƉŽƌƚŝŽŶĂůůǇŝĨĐŝƌĐƵůĂƚŝŶŐƌĞƚƵƌŶƐ ĂƌĞŶŽƚϭͬϭͿ x WƵŵƉĂƚΕϮWDĂƚŝŶŝƚŝĂůŵĂǆƉƌĞƐƐƵƌĞŽĨϭϱϬϬƉƐŝŽǀĞƌ W ĚƌŽƉƉŝŶŐƚŽϮϬϬƉƐŝŽǀĞƌ W ĂƐĂ ĨƵůůŚǇĚƌŽƐƚĂƚŝĐĐŽůƵŵŶŽĨĐĞŵĞŶƚŝƐĞƐƚĂďůŝƐŚĞĚ ƚŚĞŶŝŶĐƌĞĂƐŝŶŐďĂĐŬƚŽϭϱϬϬƉƐŝŽǀĞƌWĂƐ ĐĞŵĞŶƚŝƐĨƵůůǇĚŝƐƉůĂĐĞĚĨƌŽŵĐŽŝů͘ x ŝƐƉůĂĐĞĐĞŵĞŶƚǁŝƚŚϭй<>͕ƵƐĞĨƌĞƐŚǁĂƚĞƌƐƉĂĐĞƌƐĂƌŽƵŶĚĐĞŵĞŶƚ x ϵͲϱͬϴ͟ǆϭϮͲϭͬϰ͟ K,ǀŽůƵŵĞŽĨΕϲϱϬĨƚĂŶŶƵůƵƐсϯϲďďůƐ ͘ hŶƐƚŝŶŐĨƌŽŵƌĞƚĂŝŶĞƌĂŶĚ ĐŽŶƚĂŵŝŶĂƚĞ ƌĞƐŝĚƵĂůĐĞŵĞŶƚĨƌŽŵǁĞůůďŽƌĞ͘ DŝŶŝŵŝǌĞĐŝƌĐƵůĂƚŝŽŶƚŽ ĂǀŽŝĚ ĚŝƐƉůĂĐŝŶŐ<>ƚŚƌŽƵŐŚϱϮϰϬ͛ͲϱϮϱϬ͛DŚŽůĞƐ ϮϮ͘ KŶĐĞĐĞŵĞŶƚŚĂƐƌĞĂĐŚĞĚ ϱϬϬƉƐŝĐŽŵƉƌĞƐƐŝǀĞŵĂŬĞƵƉ ϮͲϳͬϴ͟ŵŽƚŽƌĂŶĚΕϯ͘ϳͲϯ͘ϴ͟ŵŝůů͘ Z/, dŽdK͘ Ă͘ /ĨdKĞŶĐŽƵŶƚĞƌĞĚŶĞĂƌƵƉƉĞƌϱϮϰϬ͛DͲϱϮϱϬ͛DŚŽůĞƐ 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'DWH'LJLWDOO\VLJQHGE\$UDV:RUWKLQJWRQ'1FQ $UDV:RUWKLQJWRQRX 8VHUV'DWH $UDV:RUWKLQJWRQ Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 11/10/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU S-15 (PTD 184-071) CAST-M Record 10/26/2021 Please include current contact information if different from above. Received By: 11/12/2021 37' (6HW By Abby Bell at 9:27 am, Nov 12, 2021 STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Suprv--),7--"7 -194 BOPE Test Report for: PRUDHOE BAY UNIT S-15 ✓ Comm Contractor/Rig No.: Hilcorp Thunderbird I -/ PTD#: 1840710 ' DATE: 11/8/2021 - Inspector Lou Laubenstein Insp Source Operator: Hilcorp North Slope, LLC Operator Rep: Jay Murphy Rig Rep: Will Ragsdale Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopLOL211109103016 Rams: Annular: Valves: MASP: Type Test: WKLY 321-388 - -' - - - -- - - Related Ins No: 2500 /3000 250/2500' 250/3000 0 � 24-70-, p TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Quantity P/F Quantity Size Visual Alarm Quantity Time/Pressure Upper Kelly P/F Location Gen.: P Trip Tank NA NA, System Pressure 3000 - P Housekeeping: _P_" Pit Level Indicators P - P - Pressure After Closure 1900 - P " PTD On Location P Flow Indicator NA NA 200 PSI Attained 12 P " Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 50 P ' Well Sign P H2S Gas Detector P - P Blind Switch Covers: _yes- -_- P ' Drl. Rig P MS Mise NA NA Nitgn. Bottles (avg): 6 (a-), 2250 P ' Hazard Sec. P _ -_-- _ _ 0 NA INSIDE REEL VALVES: ACC Mise0 NA - Misc NA 0 NA (Valid for Coil Rigs Only) FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity PIF Upper Kelly --_ 1- - P- Stripper 0 NA _ No. Valves 11 - P - Lower Kelly 0 NA- Annular Preventer 1- 13 5/8" - P - Manual Chokes 1 - P, Ball Ball Type 1 P-- #1 Rams -_ 1 " 2-7/8" x 5"vb - P -' Hydraulic Chokes 1 _ ' P-_' Inside BOP I P- #2 Rams 1 " Blind P CH Mise 0 NA FSV Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams _ -_-- _ _ 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 3-1/8 P - Quantity P/F HCR Valves 1 -3-1/8 P - Inside Reel Valves 0 NA Kill Line Valves 3 " 3-1/8 P - Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 ✓ y Test Results V/ Test Time 4 Remarks: Test completed with 2-7/8 and 4-1/2 test joints. Annular close time 28 sec, Ram close time 12.63 sec Blind close time 14.35' sec, HCR close time 5.65 sec. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re gg E� (�� IZ��3� 7-z��i DATE: 10/28/2021 P. I. Supervisor FROM: Guy Cook SUBJECT: BOPE Annular Preventer Retest Petroleum Inspector Thunderbird Rig 1 - PBU S-15 PTD 1840710 Hilcorp Alaska LLC 10/28/2021: 1 arrived at PBU S-15 to witness the annular preventer retest on Hilcorp's Thunderbird 1. 1 met with the Hilcorp company man Mr. Jay Murphy, the tool pusher Mr. Will Ragsdale, and the driller Mr. Brandon Stiffler. We talked briefly about the testing procedure and what had been done to resolve the issues with the accumulator system since the failures on 10/26/2021. To fix the issues with the accumulator system L, Hilcorp: 1. Powered up and put the second electric pump into service. 2. Filtered the accumulator hydraulic oil for debris and water. 3. Flushed the accumulator hydraulic lines. 4. Wrapped and heated the accumulator hoses from the accumulator shack to the BOP cellar/hooch (photo attached). 5. Cleaned/replaced the accumulator hydraulic filters. 6. Changed out the annular pressure gauge as they felt debris in the system may have affected its performance. - The third air actuated diaphragm pump was rebuilt, but still did not work properly so it was not put into service at this time. Hilcorp plans to rebuild or replace the pump after - completing work on PBU S-15 so they will have all three diaphragm pumps working for the next well. They will also replace hydraulic oil in the accumulator system. We spoke about the pre -charge bottles with the accumulator system and I questioned them about all three bottles that were under suspicion of having issues for the last three weeks (workover at PBU P2-34 and current well PBU S-15). 1 was told by the 3 Hilcorp representatives the 3 charge bottles in question were #4, #9, and #12. - Charge bottle #4 had an issue with bleeding off the pre -charge pressure. The bottle would bleed the pre -charge nitrogen from 1000 psi to 800 psi. They would charge the bottle back up and finally took it out of service by isolating it from the accumulator system. They asked Yellow Jacket to inspect this bottle and I was told Yellow Jacket found nothing wrong with it. 2021-1028_BOP_Thunderbird l _ Annular _retest_PBU_S-15_gc.docx Page 1 of 4 Charge bottle #9 had issues holding pre -charge pressure on the last well, bleeding from 1000 psi to 900 psi. They told me it had also been taken out of service. Charge bottle #12 was also isolated from the accumulator system on the last well but wasn't replaced until the 10/26/21. Yellow Jacket was asked to inspect charge bottle #12 as well and I was told they found nothing wrong with it. Both charge bottles #4 and #9 are still in service and have not been replaced. I was told by the company representative Arvell Bass on 10/27/2021 that they have not had any issues with charge bottles #4 and #9 in a week. After our discussion we headed out to the accumulator shack and I noticed that charge bottle #12 still did not have a pressure gauge on it. I instructed the Mr. Murphy to have the gauge and protective cage installed on the bottle before the day was done. He is to send me pictures of the gauge and protective cage installed before the end of the day. I also asked for a picture of all the bottles with the gauges and protective cages on them in one picture. In addition, the annular gauge on the accumulator that that had been replaced did not have a calibration sticker on it. Hilcorp could not confirm its calibration was current. I asked that the documentation for this gauge and the accumulator gauge be sent to me to confirm they were currently calibrated. We started testing the annular preventer closure time (recovery time to nominal pressure after actuation; must not exceed 30 seconds). The annular was tested six -- times. Out of six tests the annular the first 2 failed and last 4 passed. I believe the first two test failures were due to thermal expansion — heaters in the accumulator shack keep the accumulator system very warm, increasing manifold pressure from 1550 to 1600 psi. The test times for each test were as follows (hydraulic pressures are on the accumulator system; air pressure is supplied to diaphragm pumps): Test Manifold (psi) Accumulator (psi) Annular (psi) Supplied Air (psi) Recovery Time seconds Test Result 1 1400 3000 1600 100 45 Fail 2 1500 3000 1600 100 43 Fail 3 1500 3000 1550 100 28.5 Pass 4 1500 3000 1550 100 30 Pass 5 1500 3000 1550 100 29 Pass 6 1500 3000 1550 100 28.7 Pass Annular pressure consistently fell to 500 psi before returning to nominal pressure. I felt satisfied the annular was meeting the closing time requirements (recovery time to nominal pressure not to exceed 30 seconds) so they proceeded with the pressure test of the annular preventer, documented on a test chart (attached). On the way to the BOP stack I was shown the wrapped and heated hydraulic lines from the accumulator shack. 2021-1028_BOP_Thunderbird 1 _Annular_retest_PBU_S-15_gc. docx Page 2 of 4 A test plug was installed in the tubing hanger spool and a 4.5 -inch test joint was used. The test fluid was fresh water unlike on 10/262021 when brine was used to pressure test as there was no fresh water available at the time. I reminded Mr. Murphy that using brine to test last time was a one-time exception because AOGCC needed to see results on the annular preventer immediately due the previous test being deemed a failure exceeding the closing time requirement). The first pressure test of the annular resulted in a fail. The low of approximately 290 psi -' held for five minutes and passed, but the 2700 psi high pressure test failed due to a slow, steady pressure bleed off even after bumping up the pressure twice to compress any possible air in the system. After the second bump in pressure I physically tapped the chart recorder resulting in the chart rolling backwards. They bled the pressure off and came back up to a high of 2800 psi. The results were the same as before with a slow, steady pressure bleed off. At this time, I recommended they bleed off the pressure and purge the system of any possible trapped air and cycle the annular before starting the next test. The system was still fluid packed, so no purge was done. The annular was opened and then closed for the second attempt to pressure. The second pressure test results: - Low Pressure: 300 psi; 5 minutes; PASS - High Pressure: 2850 psi; pressure bled slowly to 2800 psi then held solid for 5 minutes; PASS After testing was completed, I called Inspection Supervisor Jim Regg to inform him of the results. We spoke and I was instructed to inform the company representative to send an email requesting approval allowing well workover operations to restart with Thunderbird 1 and include the test results in the email request. I passed those instructions on to Mr. Jay Murphy and Mr. Will Ragsdale. Before leaving location, I spoke again to Mr. Murphy and Mr. Ragsdale about the charge bottles (#4, #9, and #12), reminding them about the pictures I requested and to have the gauge on charge bottle #12 with the protective cage by the end of the day. I also mentioned needing documentation regarding the calibration of the pressure gauges on the accumulator. Attachments: Photos (2) - 2021-1028_BOP_Thunderbird 1 _ Annular _retest_PBU_S-15_gc. docx Page 3 of 4 Annular Preventer Retest — Hilcorp Thunderbird 1 PBU S-15 (PTD 1840710) 10/28/2021 2021-1028_BOP_Thunderbird 1—Annular — Annular_ retest_PBU_5-15_gc.docx Page 4 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �E� ,� IZ-�z71 z DATE: 10/27/2021 P. I. Supervisor FROM: Guy Cook SUBJECT: BOPE Annular Preventer Test Petroleum Inspector Thunderbird Rig 1 PBU S-15 PTD 1840710 Hilcorp Alaska LLC 10/26/2021: 1 arrived at PBU S-15 to witness the annular preventer test on Hilcorp's Thunderbird Rig 1. 1 met with the Hilcorp company men Mr. Arvell Bass and Mr. Daniel Scarpella and we briefly spoke about the test and how they had previously conducted the annular test. I informed them what API 53 states regarding when the annular may be considered closed and sealed. Mr. Bass told me they believed the annular was closed and sealed when the pressure on the accumulator started to rise again after the annular had been actuated and the pressure had dropped in the accumulator system to fill the annular. He then told me that is how they wanted to test because this is the way they had performed the test in the past and they had achieved passing times with this method. I was informed by the Hilcorp representatives they had replaced charge bottle #12 on the accumulator system as it was bad and not performing well. I was also told they had past issues with two other charge bottles, but they seemed to be working fine now. Hilcorp was aware of this issue for approximately 3 weeks. Before I arrived at location, I p was informed about them needing to change out a charge bottle but not about any issues with the other two bottles. They did the function test as they had done during their last BOP test when the annular failed to close and seal at 30 seconds or under. At 24 seconds the annular was at the pressure they considered closed and sealed — as they had done previously when the close time was recorded as 42 seconds (fail). At 35 seconds the annular was at nominal pressure of 1400 psi After some conversation about whether this was a pass or a fail — depending on their interpretation of API 53 — I told them I would get confirmation from Inspection Supervisor Jim Regg and get back to them. I left location and soon after spoke with Mr. Regg who instructed me that we needed more than a function test of the annular and that I needed to return to the rig and witness a full function pressure test of the annular preventer. I arrived back at Thunderbird 1 and witnessed the function -pressure test of the annular — again performed in the same way as the first test, except they did not continue - pressuring up to nominal pressure. Mr. Bass had left location and was off duty — Mr. 2021-1026130P Hilcorp_ Annular —Thunderbird l_PBU_S-15_gc.docx Page 1 of 3 Scarpella oversaw the test. The pumps were turned off when they believed the annular closed and sealed. Brine was used for the test fluid this time as there was no fresh water available. At 26 seconds Mr. Scarpella considered the bag to be closed and sealed. They pressure tested the annular to a low of 260 psi. The annular held pressure at 260 psi for 5 minutes and then raised to 2500 psi minimum. The annular f began leaking and they could not achieve the high of 2500 psi. When the test pump was shut down, pressure on the accumulator measured between the blinds and the annular dropped from 2200 psi to 1000 psi in 1 minute. The annular preventer was confirmed to be leaking, by observing swirling fluid on top of the annular and by fluid observed in the line returning to the pit. The Inner Annulus was also checked and produced zero fluid during this test. The well was fluid packed according to Daniel Scarpella. Hilcorp tested the annular preventer two more times to see if they could achieve and hold nominal pressure within 30 seconds. On the first attempt reached nominal pressure of 1300 psi (annular preventer closure) at 53.94 seconds — no pressure test was performed as it failed to meet the time requirement. The accumulator manifold pressure was raised from 1300 psi to 1500 psi and the test was performed again. This time the annular reached nominal pressure at 81.70 seconds failing to meet the annular 4 preventer closure time requirement. - I informed the Mr. Daniel Scarpella to secure the well and not to move forward with any well work until the annular preventer closure time deficiency was resolved and they achieved an AOGCC-witnessed passing test. I also pointed out to Mr. Scarpella that they had only one of their two electric pumps powered up and running and only two of three air -actuated diaphragm pumps were working, as one was defeated due to it needing rebuilt. When I left location the plan forward according to Mr. Scarpella was to get the second electric pump working and to troubleshoot their accumulator system for any other issues that may be hindering its performance. The third diaphragm pump was likely not to be put into service due to lack of parts and hadn't been in service since the rig started working, according to Mr. Scarpella. Attachments: Annular Preventer Test Chart BOP Stack Configuration and Capacities 2021-1026_BOP_ Hilcorp_ Annular_Thunderbird 1 _PBU_S-15_gc.docx Page 2 of 3 Annular Preventer Test — Hilcorp Thunderbird 1 PBU S-15 (PTD 1840710) 10/26/2021 2021-1026 BOP_ Hilcorp_ Annular —Thunderbird l_PBU_S-15_gc.docx Page 3 of 3 Regg, James B (OGQ From: Cook, Guy D (CED) <� Sent: Wednesday, October 27, 2021 2:39 PM To: Regg, James B (CED) [ Subject: Thunderbird 1 BOP Stack PBU S-15 and Capacities Attachments: TB1 Yellow Jacket BOP PBU S-15 10-27-21.pdf Jim, Here is the stack configuration I was given by the company rep on TB 1. It has capacities on it for their stack. I also included the Cameron fluid requirements for the rams page that covers several different sizes as an extra that may be useful in the future. Thank you, Guy Cook Petroleum Inspector AOGCC 907-227-2614 guy.cook@alasl<a.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 Guy Cook at 947-227-2614 or guy.cook@alaska.gov. 13-5/8" SM BOP STACK SIDE OUTLET W1 3-1/8" VALVES SIDE VIEW 4-1/16"5M X 3-1/8" SM DSA Jr 3.1/8" 5M MGV YELLOW CKET OILFIELD SERVICES 13-5/8- 5M ANNULAR, INTEGRATED ISA TYPE HEIGHT- 45.28 WEIGHT 12,906 1-85. 13-5/8" SM DOUBLE ROP, INTEGRATED LWS TYPE TOP RAMS: 2-7/8 TO 5-1/2" MULTI RAMS BOTTOM RAMS; BLIND HEIGHT: 36" WEIGHT 10,250 LBS. 4-1/16" 5M X 3-1/8" SM DSA GATE VALVE ASSEMBLY WEIGHT I t KILL AND LBS CHOKE Wl DSMS @,Xll- 1700 Z SM MGV 3-118" SM HCR 13-5/8" SM SPACER SPOOL HEIGHT: 24" WEIGHT: 1500 LBS. 13-5/8" SM SINGLE BOP, INTEGRATED LWS TYPE RAMS: TBD HEIGHT: 1950" WEIGHT: 5000 UBS. OPEN AND CLOSE DATA OPEN CLOSE 13-518" SM ANNULAR 17.41 23.58 13-518" SM RAMS (PER CAVITY) 5.50 5,80 34/8" 510 HCR 0.61 0.52 Up dated 10/23/2021 with Cameron U Rams 5il Bore Size and Gals to Open Gals to Close locking Closing Opening Working Pipe dams Pipe Rams Screw Turns Ratio Ratio Pressure (1 Set) (1 Set) (Each End) 11 " Lxcept 15,000 psi 11" 15,000 psi 1 13-5/8" Except 15,000 psi 13-5/8" 15,000 psi Model 8 i# Modelt i • f t M i 16-3114" 5000 psi Model B t-3/4" 10,0100 psi . .: 18-3/4- 10,000 psi 20-3/4" 3000 psi 21-1/4" 5000 psi 0.0 21-1i4" 10,000 psi r " i ��.. 26-3/4" 3000 psi � f�� I ( e-7( IIVZ,t Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/30/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU S-15 (PTD 184-071) Cement Evaluation (Cast-M) 11/10/2021 Please include current contact information if different from above. Received By: 01/03/2022 37' (6HW By Abby Bell at 9:42 am, Jan 03, 2022 STATE OF ALASKA< Reviewed By: OIL AND GAS CONSERVATION COMMISSION P. 1. Supry BOPE Test Report for: PRUDHOE BAY UNIT S-15 , Comm Contractor/Rig No.: Hilcorp Thunderbird 1 - PTD#: 1840710 DATE: 11/1/2021 Inspector Brian Bixby Insp Source Operator: Hilcorp North Slope, LLC Operator Rep: J. Murphy/ D. Scarpella Rig Rep: W. Ragsdale / M. River Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopBDB211101151904 Type Test: WKLY 321-388 Rams: Annular: Valves: MASP: 250/3000 250/3000 250/3000 2470 , Related Insp No: MISC. INSPECTIONS: TEST DATA MUD SYSTEM: Visual Alarm Trip Tank - P P , Pit Level Indicators P --_ P Flow Indicator NA NA Meth Gas Detector P_ P H2S Gas Detector P P " MS Misc 0 _NA ACCUMULATOR SYSTEM: P/F Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted 13 Well Sign _ P " Drl. Rig P Hazard Sec. P_ Misc NA FLOOR SAFTY VALVES: Quantity P/F Upper Kelly --- 0__--- NA_ - Lower Kelly 1 -1 P _ Ball Type _ _ P " Inside BOP _ 1 ' P FSV Misc 0 NA TEST DATA MUD SYSTEM: Visual Alarm Trip Tank - P P , Pit Level Indicators P --_ P Flow Indicator NA NA Meth Gas Detector P_ P H2S Gas Detector P P " MS Misc 0 _NA ACCUMULATOR SYSTEM: Time/Pressure P/F System Pressure _ 3000 P Pressure After Closure 1925_. P _ 200 PSI Attained 11 _" P " Full Pressure Attained -_67 P . Blind Switch Covers: YES P , Nitgn. Bottles (avg): 6 a�2150 P' - ACC Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper - 0 - NA- No. Valves 11 P " Annular Preventer 1 - 13518 P Manual Chokes 1 P #1 Rams 1 '27/8x5 P Hydraulic Chokes 1 P" #2 Rams 1 Blinds FP CH Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 " 31/8 P - Quantity P/F HCR Valves 1 -3 1/8 13 Inside Reel Valves -0 - NA Kill Line Valves 3 " 31/8 P Check Valve -0 - - - __ - _ NA BOP Misc 0 NA Number of Failures: 1 ✓ Test Results Test Time 6 Remarks: Full Acumulator test, Checked pre -charge pressure f all bottles, All Closer times, Annular = 28.4 sec., Rams 1 = 11 sec., Rams 2 to simulate blinds = 12 sec , HCR = 3.7sec. Tested with 4 1/2 and 2 7/8 test joints. Blinds had to be cycled and passed retest. Witnessed all gas alarms and PVT's. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regge��°I icl IZcZ� P.I. Supervisor FROM: Bob Noble Petroleum Inspector Section: 35 - Township: Drilling Rig: N/A Rig Elevation: 11960 ft MD Operator Rep: 11313 ft MD Brad Elias OA P&A: Casing/Tubing Data (depths are MD): Conductor: 20" 0. D. Shoe@ Surface: 13 3/8" - 0. D. Shoe@ Intermediate: 9 5/8" 0. D. Shoe@ Production: Feet 0. D. Shoe@ Liner: 7" 0. D. Shoe@ Tubing: 4.5" 0. D. Tail@ Plugging Data: Test Data DATE: September 11, 2021 SUBJECT: Plug Verification PBU S-15 Hilcorp Alaska PTD 1840710; Sundry 321-388 12N Range: 12E Meridian: Umiat N/A Total Depth: 11960 ft MD Lease No.: ADL0028257 11313 ft MD Suspend: OA P&A: 0 0 Casing Removal: 103 Feet Csg Cut@ Feet 2508 Feet Csg Cut@ Feet 11307 Feet Csg Cut@ Feet Feet Csg Cut@ Feet 11960 Feet Csg Cut@ Feet 10631 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Veritied Tubing Bridge plug 11351 ft MD 11313 ft MD Wireline tag OA 0 0 0 Initial 15 min 30 min 45 min Result Tubing 2755 2573 2500 IA 0 0 0 P OA 0 0 0 Tubing IA OA Initial 15 min 30 min 45 min Result Remarks: _ Plug back to reperf as Shrader Bluff injector. Top of cement was located by sick line tag with a bailer. Sample in bailer looked like semi -hard chunks of cement covered with crude oil. Brad Elias told me the the cement was bailed in and the well bore was full of crude oil. Pressure test on tubing passed. Attachments: none rev. 11-28-18 2021-0911 _Plug_Verification_PBU_S-15_bn -5000 500292111300 1840710 BP PBU S-15 TWP: 12 N - Range: 12 E - Sec. 35 f�z 3n %I Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:184-071 6.API Number:50-029-21113-00-00 Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028257 Property Designation (Lease Number):10. 8. PBU S-15 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations 5 Fracture Stimulate Repair Well 5 Operations shutdown Op Shutdown GAS GSTOR 55 WAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 55Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11960 Effective Depth MD: L80 11. Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9208 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate 5Perforate New Pool 10524, 8241 No SSSV Installed Date: Liner 1379 7" 10581 - 11960 8278 - 9208 7240 5410 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 28 - 2508 28 - 2508 14. Estimated Date for Commencing Operations: BOP Sketch 28 - 103 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Brown Packer 11382 - 11735 8821 - 9060 4-1/2" 12.6#24 - 10631 Production 11887 9160 None None 28 - 103 13-3/8" 9-5/8" Contact Phone:907.564.4763 Date: 4760 75 20"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2480 4930 Intermediate 11281 26 - 11307 26 - 8770 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Prudhoe Bay, Prudhoe Oil / Polaris Oil 484 9/1/2021 By Meredith Guhl at 10:15 am, Aug 06, 2021 321-388 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.06 09:28:16 -08'00' Stan Golis (880) * BOPE test to 3000 psi. Annular to 2500 psi. *AOGCC to witness MIT-IA to 2500 psi. 10-404 1. Six months post initial injection, a pulsed neutron water flow and temperature log will be conducted on offset wells S-10 PTD191-123, S-20 PTD201-045, S-24 PTD203-163. 2. One year after S-15 is POI and all subsequent years, a pulsed neutron water flow and temperature log will be conducted on offset wells S-10, S-20, S-24. Results to AOGCC. 3. CBL to be run from tubing cut ~7000' MD to TOC on 9-5/8" casing. Results to AOGCC. X DSR-8/6/21DLB 08/06/2021 2470 MGR06AUG21 Variance to 20 AAC 25.402. Enhanced recovery operations (b) is approved with the following conditions: dts 8/9/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.09 10:11:37 -08'00' RBDMS HEW 8/11/2021 RWO Procedure WELL: S-15 PTD:184-071 Well Name:S-15 API Number:50-029-21113-00 Current Status:Shut-In Rig:Thunderbird #1 Estimated Start Date:09/01/2021 Permit to Drill Number:184-071 First Call Engineer:Aras Worthington 907-564-4763 (O)907-440-7692 M Second Call Engineer:Brian Glasheen 907-564-5277 (O)907-545-1144 M Current Bottom Hole Pressure:3,350 psi @ 8,800’ TVD 7.4 PPGE | No recent SBHPS; Ivishak Average Max. Anticipated BHP for Schrader:2300 psi @ 5140’ TVD (Estimated from offset wells) Max. Anticipated Surface Pressure:2,470psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:1,900 psi (Taken on 5/10/17) Min ID:3.725” ID XN Nipple @ 10,566’ MD Max Angle:60 Deg @ 9,400’ Brief Well Summary: S-15 is an Ivishak Not Operable Produced Water Injector with a Surface Casing Leak @ ~21’ MD that has been SI since 2010 and secured since June of 2015. The SC leak was sealed off with a Conductor top job in 2021. A passing OA Integrity test with gas was performed to 50 psi on 5/23/2021. An MIT-T passed to 2500 psi on 6/12/2015 verifying tubing/plug integrity An MIT-IA passed to 2500 psi on 6/12/2015 verifying PC, tubing, and packer integrity. Notes Regarding Wellbore Condition: x The SC leak was sealed off with a cement conductor top job in 2021. x Ivishak perfs will remain hydraulically isolated throughout RWO by a cement abandonment plug. Objective: P&A the Ivishak perforations with a mechanical plug and cement. Pull the existing 4 ½” L80 tubing out of the well. Perforate the Schrader. Run an injection completion with L-80 tubulars, packers, and Water-Flow- Regulating-Mandrels (WFRMs). Verify completion Integrity with a passing MIT-IA & MIT-T. Area of Review – PBU S-15 (PTD # 184-071) Prior to the conversion of well S-15 from Ivishak Injector to Schrader Injector, an Area of Review (AOR) was conducted. This AOR found 21 wells within ¼ mile of S-15’s entry point into the Schrader Formation. See attached table Area of Review S-15 for annulus integrity and zonal isolation of all wells within the AOR. Three wells within the ¼-mile radius do not have cement across the Schrader interval when calculated volumetrically. These wells are S-10, S-20, and S-24 (see table below). Hilcorp requests a variance from 20 AAC 25.402 (b) due to not having adequate cementing data across the confining zone for wells within the ¼ mile radius of an injection well under 20 AAC25.402(h). RWO Procedure WELL: S-15 PTD:184-071 The assurance that the injection zone is isolated is based on the following: 1. Hilcorp provides monthly TIO plots of the three wells. If out of zone injection occurs alongside the un-cemented portion of the casings on these wells, it may show up in the OA pressure- plots as an anomaly. 2. Hilcorp performs temperature logs in the three wells across the Schrader interval before injection occurs, 6 months after injection commences, and quadrennially thereafter. 3. Alternatively, Hilcorp performs a CBL of the Production Casing on any of these three wells and submit to AOGCC for review. If sufficient cement isolation exists across the Schrader for any of the three wells then that well would not be subject to the requirements above. & Water-flow (pulsed neutron) RWO Procedure WELL: S-15 PTD:184-071 Pre-Sundry Work: DHD 1. MITIA to 2500-psi, run E-line LDL if failing. 2. Cycle LDS 3. PPPOT-T 4. PPPOT-IC RWO Procedure WELL: S-15 PTD:184-071 Sundry Procedure (Approval required to proceed): E-Line 1. Set Through-Tubing-Bridge-Plug (T-TBP) @ ~11,350’ MD (within 50’ of perforations per 20 AAC 25.112 (c) (1) (E). 2. Dump-bail 25’ of cement on top of T-TBP. Fullbore 1. MITT to 2500 psi. Slickline 1. Tag TOC. Eline 1. Cut tubing @ ~ 7000’ MD 2. Circulate well to 8.4 ppg 1% KCL or equivalent w/ diesel FP on T & IA Valve Shop/Ops 3. Bleed WHPs to 0 psi 4. Set and test TWC 5. Nipple Down Tree and tubing head adapter. Inspect lift threads. 6. NU BOPE configured top down, Annular, 2-7/8” x 5-1/2” VBRs, Blinds and integral flow cross. RWO 7. MIRU Thunderbird #1 Rig. 8. 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 2-7/8” x 5-1/2” VBR’s with 4-½” and 2-7/8” test joints. Test the Annular preventer with a 2-7/8” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 9. Pull TWC. 10. MU landing joint or spear, BOLDS and pull Tubing Hanger to the floor. PU weights are expected to be ~90K 11. Circulate bottoms up. 12. LD 4-1/2” Tubing. 13. RU EL and run CBL to identify 9-5/8” Annular TOC and verify zonal isolation. 14. If zonal isolation is sufficient, perforate Schrader per below table. Annotated log attached for reference. Reference log is DI-SFL dated 6/11/84 – 6/29/84. Eline perforating utilizing PCE. Assure well is dead post perforating. RWO Procedure WELL: S-15 PTD:184-071 15. Run 4 ½” L-80 tubing completion as detailed on proposed schematic. 16. Land Hanger and reverse in corrosion inhibited 8.4 ppg 1% KCL or equivalent. 17. Drop ball and rod and set packer with 3,500psi pump pressure. 18. Perform MIT-T to 2500 psi and MIT-IA to 2500 psi for 30 charted minutes. Give the AOGCC 24hrs notice to witness MIT-IA. Document and submit on State of Alaska form 10- 426.) 19. Shear-out valve in mandrel @ ~5300’ MD and freeze-protect tubing and IA with diesel to ~2000’ MD. 20. Set TWC. 21. Rig down Thunderbird #1. Valve Shop/Ops 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. Slickline/Fullbore 1. Pull Ball and Rod and RHC profile. 2. Set Plug in X-nipple @ ~5970’ MD. 3. MITT to 2500 psi. 4. Set WFRV’s per Operations Engineer. 5. RDMO & POI. Fullbore 1. Perform MITIA to 2500 psi once injection has stabilized. Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Schematic 4. Proposed Perforation Log AOGCC to witness. RWO Procedure WELL: S-15 PTD:184-071 RWO Procedure WELL: S-15 PTD:184-071 Proposed Wellbore Schematic Packers 9-5/8" x 4-1/2" Schrader Perforations X-Nipples 3.813" WFRMs MMG 2200' 5350' 5430' 5455' 5480' 5520' 5560' 5570' 5575' 5595' 5615' 5620' 5635' 5638' - 5658' 5655' 5675' 5680' 5690' 5705' - 5735' 5720' 5755' 5760' 5800' 5794' 5870' 5910' 5940' 5970' WLEG 6040' 5533' - 5563' 5587' - 5614' 5781' - 5801' T-TBP @ ~11,350’ MD w/25’ of Cement Dump-Bailed on top RWO Procedure WELL: S-15 PTD:184-071 RWO BOPs RWO Procedure WELL: S-15 PTD:184-071 RWO Procedure WELL: S-15 PTD:184-071 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate:Subject: Changes to Approved Sundry Procedure for WellSundry #: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 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:184-071 6.50-029-21113-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 11960 11887 9160 10524 None None 8241 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 75 20" 28 - 103 28 - 103 Surface 2480 13-3/8" 28 - 2508 28 - 2508 4930 2670 Intermediate 11281 9-5/8" 26 - 11307 26 - 8770 6870 4760 Production Perforation Depth: Measured depth: 11382 - 11735 feet True vertical depth:8821 - 9060 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L80 24 - 10631 24 - 8310 10524 8241Packers and SSSV (type, measured and true vertical depth) 4-1/2" Brown Packer Liner 1379 7" 10581 - 11960 8278 - 9208 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Cemented Conductor x SC Annulus with 10 gals of 15.6-ppg Permafrost cement Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 400Not on Injection Not on Injection 260 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Aras Worthington Aras.Worthington@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.4763 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9208 Sundry Number or N/A if C.O. Exempt: 321-198 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Conductor x OA Cement Operations shutdown Change Approved Program 5 OA x Conductor Annulus from 21' to Surface Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028257 PBU S-15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 10:22 am, Jun 08, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.07 19:45:15 -08'00' Stan Golis (880) MGR26JUL2021 RBDMS HEW 6/8/2021DSR-6/8/21 SFD 6/18/2021 ACTIVITY DATE SUMMARY 4/30/2021 T/I/O = SSV/0/0. Temp = SI. Circ OA (Pre RWO). Secondary containment in cellar. Flute at the 6 o'clock postion is open. All other flutes are bridged off with old cement. Underneath the open flute is a cavity (27" to the bottom of the flutes, 37" to the conductor top). Dug old cement from conductor down to ~6" (top of flutes). Pumped 1 bbl of neat meth down the OA till returns were observed in the conductor cavity (40 - 50 psi pump pressure, milky retrns, ~ 15 minutes, .35 gpm). Continued to pump another .33 bbls till returns cleaned up. Used ALP to depress the OA liquid level back down to the leak point (observed bubbling in the conductor & high LEL's @ 30 psi). Removed remaining fluid from conductor (vac truck). Bled the OAP from 8 psi to 0 psi in 20 seconds (All gas). FWP's = SSV/0/0. SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:10 5/11/2021 T/I/O = SSV/0/0. Temp = SI. Cemented Conductor x SC Annulus with 10 gals of 15.6 ppg Permafrost cement. Conductor fully topped off and stable. Will return tomorrow to check for any cement slump and re-top as needed. 5/16/2021 **WELL S/I ON ARRIVAL** RAN 2.5" SB & 3.55" BELLGUIDE TO 10577'SLM *UNABLE TO LATCH PRONG* **WSR CONT ON 5/17/21** 5/17/2021 **WSR CONT'D FROM 5/16/21** BAILED PLASTIC TBG FROM AROUND RMX PRONG @ 10590'MD. PULLED RMX PRONG @ SAME BAILED PLASTIC TBG FROM PLUG BODY @ 10599'MD RAN 4 1/2" GS & SD IN SSV,FELL THROUGH & HUNG UP BELOW SSV, HANDSPANGED FREE. RAN 3.79" GAUGE RING & SD IN SSV **VALVE CREW DETERMINED SSV TO BE OVERSTROKING BY 1/4"** DRIFT FREELY THROUGH TREE w/ 3.79" GAUGE RING **LEFT SSV 1/4" FROM FULL STROKE WHEN PASSING THROUGH** PULLED RMX PLUG BODY @ 10599' MD **TURNED WELL OVER TO DSO** 5/22/2021 T/I/O = SSV/0/0. Temp = SI. Assist Ops w/ POI (Post conductor top job). OA FL @ near surface. Removed water from cellar. Job postponed for instrument work. SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:45 5/23/2021 T/I/O = SSV/0/0. Temp = SI. OA integrity test -Passed- (Pre Injection). OA FL @ near surface. Cellar has ~1' of water in it. Conductor top is ~1' above fluid. Used ALP to incrementally increase the OAP to 50 psi. The OA lost 4 psi in 15 minutes and 3 psi in the second 15 minutes. No LEL's or bubbling seen on new cement top or anywhere else in the cellar. Bled the OAP to 0 psi (all gas). Tag hung. FWPs = SSV/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 5/25/2021 ***WELL S/I ON ARRIVAL*** (cement squeeze) RIGGED UP POLLARD UNIT #58 ***WSR CONTINUED ON 5/26/21*** Daily Report of Well Operations PBU S-15 Daily Report of Well Operations PBU S-15 5/26/2021 ***WSR CONTINUED FROM 5/25/21*** (cement squeeze) TAGGED FILL @ 11,348' SLM w/ 2.80" CENT, 1-3/4" S-BLR. (perfs appear covered) PULLED RA-DGLV FROM ST# 5 @ 3,570' MD. LRS CIRC'D IN FREEZE PROTECT FOR TUBING & IA. RAN 3.75" GAUGE RING TO XN-NIP @ 10,599' MD. SET RM-DGLV IN ST# 5 @ 3,570' MD. LRS PERFORMED PASSING 2,500 psi MIT-T. (against fill) BAILED HARD PACKED SCHMOO FROM 11,350' SLM TO 11,355' SLM. LRS PRESSURED UP TUBING TO 2,500 PSI w/ SAME RESULTS. DRIFTED w/ 30' x 3.0" BAILER TO 11,353' SLM. ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** 5/26/2021 T/I/O= 155/10/0 Circ well to DSL (CIRC OUT) Pumped 10 BBLS 60/40 followed by 270 BBLS 120* diesel down IA taking returns up TBG to S-16 FL. SL set DGLV. Pressured up TBG to 2510 psi, monitored TBG pressure for 30 min. TBG lost 140 psi in 1st 15 min and 42 psi in 2nd 15 min.Slickline made bail runs. Pumped 1.2 bbls diesel down TBG.TBG pressured up. Slickline in control of well upon departure. CVs OTG FWHP's=670/100/0 Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, May 21, 2021 2:23 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Aras Worthington; Oliver Sternicki Subject: OPERABLE: Injector S-15 (PTD #1840710) Eval SC repair Mr. Wallace, Injector S-15 (PTD #1840710) surface casing leak has been repaired with a cement top job on the conductor. The well is now classified as OPERABLE and can be brought online. The well will have dedicated manning to monitor for leakage when put on injection until stabilized and AOGCC MIT -IA once thermally stable. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P:(907)659-5102 M:(907)232-1005 From: AK, D&C Well Integrity Coordinator Sent: Thursday, September 9, 2010 10:48 AM To: 'Maunder, Thomas E (DOA)' <tom.maunder@alaska.gov>;'Regg, James B (DOA)' <jim.regg@alaska.gov>; 'Schwartz, Guy (DOA) <guy.schwartz@alaska.gov>' <guy.schwartz@alaska.gov>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2WellpadLead@bp.com>; Engel, Harry R <Harry.Engel@bp.com>; AK, RES GPB East Production Optimization Engineer<AKRESGPBEastProductionOptimizationEngineer@bp.com>; AK, RES GPB West Production Optimization Engineer<AKRESG PBWestProductionOptimization Engineer@ bp.com>; Cismoski, Doug A <CismosDA@BP.com>; AK, D&C Well Services Operations Team Lead <AKDCWel[ServicesOperationsTeamLead@BP.com>; AK, D&C Wireline Operations Team Lead <AKDCWireIineOperationsTeamLead@BP.com>; AK, OPS Prod Controllers <AKOPSProdControllers@bp.com>; AK, OPS GC2 Ops Lead <AKOPSGC20psLead@bp.com> Cc: Sayed, Mohamed <Mohamed.Sayed@sel.bp.com>; AK, D&C Well Integrity Coordinator <AKDCW elllntegrityCoordinator@bp.com> Subject: NOT OPERABLE: Injector S-15 (PTD #1840710) Confirmed SC leak FAQ Injector S-15 (PTD #1840710) has been confirmed to have a surface casing leak. On 09/09/10, an attempt to increase the OA pressure for UIC compliance was unsuccessful when RG -2401 was seen bubbling in the conductor. The well has been reclassified as Not Operable and needs to be shut-in as soon as it's freeze protected. The plan forward is to evaluate a leak depth for future remediation. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:184-071 6.API Number:50-029-21113-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0028257 Property Designation (Lease Number):10. 341H 8. PBU S-15 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS 5 GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development Stratigraphic 5Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11960 Effective Depth MD: L80 11. 4/30/2021 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9208 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10524, 8241 No SSSV Installed Date: Liner 1379 7" 10581 - 11960 8278 - 9208 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 28 - 2508 28 - 2508 14. Estimated Date for Commencing Operations: BOP Sketch 28 - 103 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Brown Packer 11382 - 11735 8821 - 9060 4-1/2" 12.6#24 - 10631 Production 10599 8289 10599 None 28 - 103 13-3/8" 9-5/8" Contact Phone:907.564.4763 Date: 4760 75 20"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2480 4930 Intermediate 11281 26 - 11307 26 - 8770 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2470 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Conductor Top Job, OA Squeeze By Meredith Guhl at 2:09 pm, Apr 16, 2021 321-198 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.04.16 14:02:15 -08'00' Stan Golis (880) DSR-4/16/21MGR22APR21 X DLB 04/16/2021 10-404Yeson Required? Comm 4/23/21 dts 4/22/2021 RBDMS HEW 4/26/2021 Well: S-15 PTD: 184-071 Date: 04/15/2021 Well Name:S-15 API Number:50-029-21113-00-00 Current Status:Not Operable; Secured; SC Leak Rig:FB/SL Estimated Start Date:May 2021 Estimated Duration:2 weeks Reg.Approval Req’std?Yes Date Reg. Approval Rec’vd: First Call Engineer:Aras Worthington 907-440-7692 Second Call Engineer:Brian Glasheen 907-564-5277 Current Bottom Hole Pressure:Est. 3350 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2470 psi Max Inc:See Schematic Integrity Issues:SC Leak est. ~21’ MD Brief Well Summary S-15 is an Ivishak Not Operable Produced Water Injector with a Surface Casing Leak @ ~21’ MD that has been SI since 2010 and secured since June of 2015. An OA pressure-test in 2010 to 300 psi resulted in a discharge of RG-2401 to the wellhouse/cellar. Subsequent diagnostics (depressing fluid level in OA with nitrogen while taking fluid returns from the Conductor and then getting a fluid strap in the OA) indicated the SC leak @ ~21’ MD. An MIT-T passed to 2500 psi on 6/12/2015 verifying tubing/plug integrity An MIT-IA passed to 2500 psi on 6/12/2015 verifying PC, tubing, and packer integrity. Objective Pump sealant/cement down the OA to the SC leak to squeeze the leak off. Pending a successful squeeze Hilcorp plans to P&A the Ivishak and re-complete the well as a Schrader Injector under a separate Sundry. Procedural Steps DHD/Special projects 1. Top job the Conductor x SC with cement as deemed necessary. 2. Pump sealant (squeezecrete, Well Lock, or similar product) into the OA. 3. Squeeze sealant into the SC leak. 4. Put well on Injection and perform AOGCC witnessed MITIA. 5. Re-treat OA with sealant/cement as required. Schrader Injector under a separate Sundry. Well: S-15 PTD: 184-071 Date: 04/15/2021 • • ~~ BP Exploration (Alaska) inc. ~ Attn: Weil Integriry Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ Encfosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ,,.p: ~+'~s.;F#' ;! `~ '. ,~,. ~~~t~yC{ Y,~'x~;~`~ at,. ti!~„iav 4. 4_. Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Seatant Top-off Report of Sundry Operetions (10-404) S-pad Date W ell Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top otf date Conosion inhibitor Corrosion inhibitod sealant date ft bbls ft na al S-018 1952020 025 NA 025 NA 2.6 5/30/2009 S-02A 1941090 025 NA 0.25 NA 1.7 5/25/2009 5-03 7817900 13.25 NA 1325 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 S-OSA 1951890 0 NA 0 NA 0.9 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-o7A 1920980 0 NA 0 NA 0.9 5/26/2009 S-OBB 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/37/2009 S-1oA 1911230 0.5 NA 0.5 NA 3.a 5/31/2009 5-118 1990530 025 NA 025 NA 1.7 5/27/2009 S-12A 1851930 025 NA 025 NA 1.7 6/1I2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 S.xS 1 025 NA 025 NA 3 6/2/2009 S-17C 020070 0.25 NA 0.25 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA ~ 0.25 NA 1.3 5/19/2009 5-21 7900470 ~ 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 S-248 2037630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 S-288 2030020 0.5 NA 0.5 NA 2.s 5/31/2009 S-29A11 1960720 0 NA 0 NA 0.85 5/27/2009 S30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S-37A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 5-32 1901490 0.5 NA 0.5 NA 3.4 5/31I2009 5-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 5-34 1927360 0.5 NA 0.5 NA 3.4 5/31/2009 S35 1921480 0 NA 0 NA .BSin 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 4.25 5/27/2009 5-37 7920990 125 NA 125 NA 11.9 5/27/2009 5-38 1921270 025 NA 025 NA 702 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 S-a2 1960540 0 NA 0 NA 0.9 5/30/2009 5-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 5-44 1970070 025 NA ~~ 025 NA 17 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 S-101 2001150 125 NA 125 NA i7.9 5/29/2009 5-102L1 2031560 1.25 NA 125 NA 11.1 5/31/2009 S-103 2001680 1.5 NA 1.5 NA 11.9 5/18/2009 S-104 2001960 175 NA 175 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 S-106 2010120 16.25 NA 16.25 NA 774.3 6/2l2009 5-107 2011130 2.25 NA 225 NA 28.9 5/18/2009 S-i08 2011000 3.5 NA 3.5 NA 40 5/30/2009 S-109 2022450 2 NA 2 NA 21.3 5/30/2009 S-t70 2011290 17.75 NA 11.75 NA 98.6 5/30/2009 S-11 t 2050510 2 NA 2 NA 19.6 5/30/2009 S-112 2021350 0 NA 0 NA 0.5 5/30f2009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-7taA 2021980 1.25 NA 125 NA 702 5/30/2009 5-115 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 5-116 2031810 1.5 NA 1.5 NA 13.6 5/28/2009 S-117 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-118 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 52 5/30/2009 S-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 5-127 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-122 2050810 3 NA 3 NA 2t.3 5/29/2009 5-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1.75 NA 11.9 5/26/2009 5-725 2070830 2.25 NA 225 NA 20.4 5/28/2009 5-126 20710970 125 NA 125 NA t5.3 6/1/2009 S-200 1972390 125 NA 125 NA 14.5 5l26/2009 S-20t 2001840 0 NA 0 NA 0.85 6/19/2009 S-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 025 NA 1.7 6/1/2009 S-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA 99.5 6/2/2009 S-SOa 0 NA 0 NA 0.85 5/28/2009 6/25/2009 ~- t$~-c`~°`~ ~ S~~S ~• MGM®~N~UM Toy Jim Re ! P.I. Supggisor tl Ql/(~ l7l ~ ~lC~~ FROM: Chuck Scheve Petroleum Inspector • State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 09, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 5-15 PRUDHOE BAY UNIT S-15 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT S-15 API Well Number: 50-029-211 13-00-00 Inspector Name• Chuck Scheve Insp Num: mitCS080609080629 Permit Number: t84-o~1-o Inspection Date• 6ni2oo8 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. T s I s T-T Well I Type Inj. i w ~ TVD ~ az4~IA ~ - I3o 23IO ~ 2aoo ~ zsoo ~ zsoo p•T• Isao~IO iT eTest I SPT ~ Test s~ -~~- ~ - - -- ~p _ 2060 25 / OA 40 40 40 ~ 40 40 i I - -- i -_ --- I_- 4YRTST P Interval p/y' _-___ TUhln __ __ g; Ia3o I3oo Izso o i 3zo Notes' The injection had been down until just prior to this test. The IA was fluid packed with 35 degree fluid (12+ bUl) then test pressure applied. ~ ~~Nl~~ JUL ~~ ~ 200$ Monday, .tune 09, 2008 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: --., t<Rfl hI ~/C4 DATE: Tuesday, June 15,2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-15 PRUDHOE BAY UNIT S-15 Jim Regg P.I. Supervisor FROM: John Crisp Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv \.1~ Comm Well Name: PRUDHOE BAY UNIT 5-15 Insp Num: mitJCr040612202419 ReI Insp Num: API Well Number: 50-029-21113-00-00 Permit Number: 184-071-0 Inspector Name: John Crisp Inspection Date: 6/6/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-15 Type Inj. F TVD 9205 IA 160 2480 2440 2430 P.T. 1840710 TypeTest SPT Test psi 2060 OA 0 0 0 0 Interval OTHER P/F P Tubing 1000 1000 1000 1000 Notes: MlTIA prep. For Pit dewatering start up. Tuesday, June 15, 2004 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair DATE: July 20, 2002 THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests bpx S-Pad 15, 34 PBU Prudhoe Bay Field Packer Depth Pretest Initial 15 Min. 30 Min. we,,Is-15 I Type,nj.I S i oo i oo I oo]Interval] 4 P.T.D.I 1840710 ITypetest} P ITestpsil 2060 ICasingI 22O I 22901 2230 I 2210 } P/F } P Notes: Annulus not fluid packed; injection temp. 117F WellI S-34 I Typelnj.'l S I T.V.D. 18505 I Tubingl 250 J 290 J 290 1290 J lntervalI 4 P.T.D.I 1921360 TypetestI P ITestpsil 2126 ICasingI 250 I 23061 2250 .I 2240 I P/F } P Notes: Annulus not fluid packed; injection temp. 11 OF Well . P.T.D.J Notes: Well P.T.D.J Notes: P.T.D. Notes: IType Inj. Type test IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Slight bleed down possibly caused by pumping cold fluids and not having the annulus fluid packed prior to commencing the MIT. M.I.T.'s performed: 2 Number of Failures: 0_ Attachments: none Total Time during tests: 1,5 hrs cc: none MIT report form 5/12/00 L.G. MIT PBU S-PAD 7-20-02 JSJ.xls 7/24/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging.__ Pull tubing__ Alter casing __ Repair well __ Perforate X Other__ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X 4. Location of well at surface 1984' SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM (top of Sag R) At effective depth 1851'SNL, 2082'WEL, SEC. 26, T12N, R12E, UPM ORIGINAL At total depth 1732' SNL, 1935' WEL, SEC. 26, T12N, R12E, UPM 6. Datum elevation (DF or KB) KBE = 68. 74 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-15 (32-26-12-12) PBU 9. Permit number/approval number 84-71 / 10. APl number 50- 029-21113 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured 11960 feet , true vertical BKB 9205 feet Effective depth: measured 11707 feet true vertical BKB 9041 feet Casing Length Size Structural -- Conductor 110 20x30 Surface 2480 13 3/8 Intermediate 11279 9 5/8 Production -- Liner 1378 7 Perforation depth: measured 11584'- 11640' Plugs (measured) Junk (measured) Cemented 8 c.y. 3470 c.f. 3003 c.f. 391 c.f. true vertical subsea 8889'-8927' fill at 11707' MD (07/90) Measured depth True vertical depth BKB 138 138 25O8 25O8 11307 8767 10582-11960 82 76-9205 Sqzd: 11382'- 11430' (Sag R) 11640-35,11700-05,11730-35 (Ivishak) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10524' with 4 1/2" tailpipe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BO~'packer at 10524'; 4 1/2' SSSV at 1942' 13. Stimulation or cement squeeze summary 7/6/94 Converted well to a water injector Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure 93O 2043 Tubing Pressure 5971 6O04 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operation2s? Oil Gas Suspended Service Water & Gasln/ection 17' I he~c~ha~7 fore/~/~is true an,~Trec~! to the best of mY knowledge'"' ..,~.,/,Z~ "~ 7/~ ~/~.,~ Signed /'/ ~ ./c-/"/"/4/, ,Z /// //"~ ~_.¢/~.,¢~'_.~'.,-..-z,-?,.,, Title Supervisor Waterflood and Miscible Flood Date Form 10-404 Rev 06/1 ~5/1~1~ "'" - SUBMIT IN DUPLICATE WELL S-15(32-26-12-12) 8/18/95 Reperf The following interval were reperforated using 2 1/2"guns, 4 SPF, random orientation and 180° phasing. 11640' - 11715' MD LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRI%FE ANCHORAGE AK, 99501. Date: 22 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL { .O[ N-13 (42-07-11- 3) B-29 (32-31-11-14) DESCRIPTION CCL FINAL BL+RF PLS FINAL BL + RF PDK FINAL BL + RF CN/GR FINAL BL+RF PLS/STP FINAL BL+RF GR/CCL FINAL BL+RF PFC/PERF FINAL BL+RF PFC/PERF FINAL BL+RF ECC No. Run # 1 1390.09 Run ~ 1 2189.04 Run # 1 3576.05 Run # 1 5784.07 Run # 1 5818.07 Run # 1 Run ~ 1 5897.03 Run # 1 6236.04 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street ~~~uite 201 -~/ ~ Or F~to (907) 563-7803 Received by__Date: STATE OF ALASKA ALM"--"-OIL AND GAS CONSERVATION COMMISSI¢--" REPORT OF SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other 3( 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service X 4. Location of well at surface 1984'SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM (top of Sag R) 0 ~ ~' ~ i ~ ~ ~' At effective depth 1 .... i ~: 'i ~' I 1851' SNL, 2082' WEE, SEC. 26, T12N, R12E, UPM , I At total depth 1732'SNL, 1935' WEL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical 11960 feet Plugs (measured) BKB 9205 feet 6. Datum elevation (DF or KB) KBE= 68.74 AMSL 7. Unit or Property name Prudhoe Bay Unit feet 8. Well number S-15 (32-26-12-12) PBU 9. Permit number/approval number 84-71 / 10. APl number 5O- 029-21113 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 11707 feet true vertical BKB 9041 feet Junk (measured) fill at 11707'MD (07/90) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20x30 8 c.y. 138 Surface 2480 13 3/8 3470 c.f. 2508 Intermediate 11279 9 5/8 3003 c.f. 11307 Production -- Liner 1378 7 391 c.f. Perforation depth: measured 11584'- 11640' true vertical subsea 8889'-8927' True vertical depth BKB 138 2508 8767 10582-11960 8276-9205 Sqzd: 11382'- 11430' (Sag R) 11640-85,11700-05,11730-35 (Ivishak) Tubing (size, grade, and measured depth) 4 1/2"L-80 to 10524' with 4 1/2" tai~oipe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at10524';4 1/2" SSSVat194R E E EIV D 13. Stimulation or cement squeeze summary 7/6/94 Converted well to a water injector Intervals treated (measured) Treatment description including volumes used and final pressure N0V - $1994 0il & Gas Cons, C0mmissl0n Anch0raje 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ] 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations Oil Gas ~ Suspended Service Water Iniector 17. I hereby ce_.~-.~ o._ that the~oregoingj~ is true and correct to the best of my knowledge. ///[ Signed -~' ~~,,-~ Title Supervisor Waterflood and Miscible Flood Date Form 10-404 Rev 06/15/88 /// SUBMIT IN DU~LI~:AT~ y STATE OF ALASKA ALAS~'~--"')IL AND GAS CONSERVATION COMMISSIO"--' REPORT SUNDRY WELL OPEhATIONS 1. Operation's performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development X Exploratory Stratigmphic Service 4. Location of well at surface 1984' SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM (top of Sag R) At effective depth 1851' SNL, 2082' WEL, SEC. 26, T12N, R12E, UPM At total depth 1732' SNL, 1935' WEL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: measured 11960 feet true vertical BKB 9205 feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 68. 74 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-15 (32-26-12-12) PBU 9. Permit number/approval number 84-71 / 10. APl number 50- 029-21113 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 11707 feet true vertical BKB 9041 feet Junk (measured) fill at 11707' MD (07/90) Casing Length Size Cemented Structural -- Conductor 110 20x30 8 c.y. Surface 2480 13 3/8 3470 c.f. Intermediate 11279 9 5/8 3003 c.f. Production -- Liner 1378 7 391 c.f. Perforation depth: measured 11584'- 11640' true vertical subsea 8889'-8927' Measured depth True ve~icaldepth BKB 138 138 2508 2508 11307 8767 10582-11960 8276-9205 Sqzd: 11382'- 11430' (Sag R) 11640-85,11700-05,11730-35 (Ivishak) Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10524' with 4 1/2" tai~ipe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10524'; 4 1/2" SSSVat 1942' 13. Stimulation or cement squeeze summary see attachment RECEIVED 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data JUN 2 3 1994 At~.ska Oil & Gas Cor~s. Commissi Ancnora_se Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl Casing Pressure 820 1344 1143 1508 600'~'' 1028 //t 573 1474 Tubing Pressure 274 317 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~( Gas Suspended Service 17. I hereby c, ertify that the fore~.0ing is true and correct to the best of my knowledge. Signed ~'--"~/[~.., L~/~x.~ ~ ~:b.-t,-u~ Title Senior Technical Assistant I Form 10-404~ Rev 06/15/88 Date SUBMIT IN DUlSLIO,4,TE 2/21/93 WELL S-15(32-26-12-12) REPERF The following interval were reperforated using 3 3/8" guns, 4 SPF, 45° orientation and 90° phasing. 11384' - 11406' MD 11406' - 11430' MD 3 SPF fjh 6/20/94 RECEIVED JtJN 25 'i994 !,,is:_~ha Oi~ & Oas Cons. Commission Anchorage STATE OF ALASKA ~-,..--,oKA OIL AND GAS CONSERVATION COMMISb,~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service Other 6. Datum elevation (DF or KB) ~, KBE = 68. 74 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 1984' SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM (top of Sag R) At effective depth 1851' SNL, 2082' WEL, SEC. 26, T12N, R12E, UPM At total depth 1732'SNL, 1935' WEL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: measu red 11960feet true vertical BKB 9205feet 8. Well number S-15 (32-26-12-12) PBU 9. Permit number/approval number 84-71/90-085,90-379 10. APl number 50- 029-21113 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 11707feet Junk (measured) true vertical BKB 9041feet fill at 11707' MD (07/90) Casing Length Size Cemented Structural -- Conductor 110 20x30 8 c.y. Surface 2480 13 3/8 3470 c.f. Intermediate 11279 9 5/8 3003 c.f. Production -- Liner 1378 7 391 c.f. Perforation depth: measured 11584'- 11640' Measured depth True verticaldepth BKB 138 138 2508 2508 11307 8767 10582-11960 8276-9205 Sqzd: 11382'- 11430' (Sag R) 11640-85,11700-05,11730-35 (lvishak) true vertical subsea 8889'-8927' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10524'with 4 1/2" tailpipe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10524'; 4 1/2" SSSV at 1942' 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure Alaska, Oil &. ,.'5as Cons, Oom~iss~or Anchorage 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation S.L S.L S.L S.L 3191 2454 631 0 S.L 235 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoin__g is true and correct to the best of my knowledge. Signed ~ Title Senior Technical Assistant I Form 1 o-404-Rev 06/15/88 Date SUBMIT IN DUPLICATE 3/01/90 7/12/90 fjh 2/10/93 WELL S-15(32-26-12-12) Non-RigWorkOver/Frac Approval#90-379,90-085 A NRWO CTUWO WSO was performed using the following fluids: SQZ 415 bbls Prod H20 to Load Well(215 bbls behind pipe) 28 bbls 12% HCL/20% Xylene Acid 78 bbls PW to maintain whp 10 bbls EFF H20(Spacer) 22 bbls Cement 10 bbls Eft H20 30 bbls dual polymer SQZ No Prod WTR for loading(well already dead) 10 bbls EFF H20 22 bbls Cement 15 bbls EFF H20 30 bbls Dual Polymer SQZ #3 No Prod WTR for loading(well already dead) 10 bbls EFF H20 20 bbls Cement 15 bbls EFF H20 28 bbls Dual Polymer Well Cleaned out to 11749 ft. Gas Cap to 4470 ft. Leave well with 2500 psi s/i pressure. Class G Cement: FL28 .88%, CD31 .1%, R11 .02%, FP6L 1 GAL/SK, EFF H20:Chlorides<100 MG/L Performed a Hydraulic Fracturing using the following fluids: Data Frac: 118 bbls 15 HCL as per program 205 bbls 10g Gel Displacement 103 bbls 10g Step Rate (Rate wouldn't stabilize) 200 bbls 10g First 150 bbls w/1500# scale inhib. 400 bbls 40# Gel at 45 bpm 200 bbls 10g gel displacement Frac' 1200 bbls 40# Gel Pad 97 bbls (Clean) 40# Gel Pad W/1 PPG 16/20 CL 61 bbls (Clean) 40~ Gel Pad W/1 PPG 16/20 CL 36 bbls (Clean)40# Gel Pad W/1 PPG 16/20 CL 19 bbls (Clean) 4~ Gel Pad W/1 PPG 16/20 CL 49 bbls (Clean) 40g Gel Pad W/1 PPG 16/20 CL ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 14 April 1994 Transmittal of Data Sent by: ANCHORAGE XPRES Dear Sir/Madam, Enclosed, please find the data as described below: WELL W-l= ( 4-28-11-12) DESCRIPTION 1 PLS STATIC FINAL BL 3~B~STATIC RF SEPIA 1 PLS INJ. FINAL BL ~"PLS INJ. RF SEPIA ~-0~ A-08 (23-36-11-13) 1 PLS INJ. FINAL BL ~'PLS INJ. RF SEPIA A-39 (31-35-11-13) 1 PLS PROF. FINAL BL ~PLS PROF. RF SEPIA f::b-ll s-30 1 PL STATIC FINAL BL ~ STATIC RF SEPIA ~-5OS H-24 c/;k-o.9 S-TA 1 PLS STATIC FINAL BL --~ PLS STATIC RF SEPIA 1 PLS STATIC FINAL BL -'l PLS STATIC RF SEPIA 1 PLS STATIC FINAL BL -Tp~ STATIC RF SEPIA 1 PL STATIC FINAL BL -~ P~ STATIC RF SEPIA 1 PLS STATIC FINAL BL ~'PA~ STATIC RF SEPIA ~_j~ Z-04 (41-24-11-11) ~-LO~ u-13 1 PLS STATIC FINAL BL ~ PI~S STATIC RF SEPIA 1 PLS STATIC FINAL BL _~ PLS STATIC RF SEPIA ECC No. Run # 1 5642.01 Run ~ 1 Run # 1 3038.01 Run # 1 Run # 1 6163.00 Run # 1 Run # 1 5999.02 Run # 1 Run # 1 3583.02 Run # 1 Run ~ 1 4735.01 Run Run ~ 1 5670.01 Run ~ 1 Run # 1 Run ~ I 6157.00 Run # 1 6160.00 Run # 1 Run # 1 6159.00 Run # 1 Run # 1 4129.02 Run # 1 Run # 1 5815.01 Run cont/ 1 PL STATIC FINAL BL -/r~ STATIC RF SEPIA 1 PLS STATIC FINAL BL /f~S STATIC RF SEPIA Run ~ 1 Run ~ i Run # 1 Run ~ 1 5010.01 5897.02 Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 . o Attn. Rodney D. Paulson Received by: Date: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 BP/PBU ~OGS DATE: 04/21/93 T# 84491 Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-04~~'0~ PFC 04/07/93 #1 -'~A-2~%,~O~ PDK-100 04/06/93 #1 %'F a-2 PFC 04/04/93 #1 ~,~B-07 ,\~ PFC 04/17/93 #1 B-15~~ - PRODUCTION LOG 04/16/93 #1 B-34~'gD~ PFC 04/15/93 91 ~C-26 w%~ PFC 04/11/93 #1 ~ D-i~ '' PFC 04/12/93 91 ,~E-10 , PRODUCTION LOG 04/17/93 91 ~\~" E-11~'~ PRODUCTION LOG 04/14/93 #1 F-i~'~~' CCL/PERF 04/06/93 #1 k~H-17 ,~ PFC 04/13/93 91 %~ H-2~b PFC 04/06/93 #1 %,~'~J-15_,~. LEAK DET 04/15/93 #i S-i~~ PRODUCTION LOG 04/04/93 #1 ~\~-35q~ PFC 04/08/93 91 ~ X-02 PRODUCTION LOG 04/16/93 #1 Y-15~~ PRODUCTION LOG 04/10/93 #1 Y-1 PRODUCTION LOG 04/10/93 91 10500.00-10893.00 ATLAS 5 " 11050.00-11495.00 ATLAS 5 " 10754.00-11037.00 ATLAS 5 " 11550.00-11800.00 ATLAS 5 " 9180.00- 9450.00 ATLAS 5 " 11600.00-11950.00 ATLAS 5 " 11371.00-1].795.00 ATLAS 5 " 8700.00- 9200.00 ATLAS 5 " 11450.00-11694.00 ATLAS 5 " 10350.00-10705.00 ATLAS 5 " 9985.00-10240.00 ATLAS 5 " 10280.00-10670.00 ATLAS 5 " 9604.00- 9920.00 ATLAS 5 " 11000.00-11500.00 ATLAS 5 " 3000.00-11610.00 ATLAS 5 " 9600.00- 9900.00 ATLAS 5 " 9500.00- 9920.00 ATLAS 5 " 9930.00-10320.00 ATLAS 5 " 2200.00-10280.00 ATLAS 5 " Information Control~ O~k Well Records ~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 02-25-93 T# 84388 BP CH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-24 ~[~70 CH 02/22/93 REF#124672 S-15 ~-~1 CH 02/21/93 REF#124671 PFC GAMMA RAY PERFORATI ATLAS PFC GAMMA RAY PERFORATI ATLAS Information Services Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 04/10/90 Transmittal: 81060 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy questions, please contact A-16 RST F-16 COMP J-15 TDT-P S-15 COMP N-23 NTL CC-02A CBT CC-02A CET -. of" the material listed below. If BP Well.Records at (907) 564-4445. 2: you have any 03/03/90 #1 0-10612 Sch 5" 03/03/90 #1 9175-9550 Sch 5" 04/01/90 #1 10590-11333 Sch 5" 03/31/90 ~1 10440-11729 Sch 5" 04/01/90 #1 40-10160 Sch 5" 04/02/90 #1 2390-3521 Sch 5" 04/02/90 #1 2390-3543 Sch 5" Distribution: · ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR s~_~~~~ ARCHIVES RECEIVED APR ! 7 ]990 Alaska 011 & Gram Conm, Oommimel0n Anchorage REC£!v, n BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 03/05/g0 Transmittal: 80955 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. E-II Perf 02/27/90 #1 10200-10532 Sch 5" F-05 Completion 02/25/990 #1 10520-11370 Sch 5" S-15 Completion 02/24/90 #1 11406-11828 Sch 5" W-Ii TDT-P 02/25/90 #9 13000-13545 Sch 5" W-25 TDT-P 02/26/90 #1 10050-10575 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR ,~STATE OF ALASKA~ STATE OF ALASKA ~"-~-' . ..~,SKA OIL AND GAS CONSERVATION COIVt, SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend.. Operation Shutdown__ Re-enter suspended well__ Alter casing , Repair well__ Plugging Time extension__ Stimulate X Change approved program __ Pull tubing __ Variance __ Perforate__ O~er __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 '4. Location of well at surface 1984' SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM (top of Sag R) At effective depth 1784'SNL, 2001° WEL, SEC. 26, T12N, R12E, UPM At total depth 1732' SNL, 1935' WEL, SEC. 26, T12N, R 12E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11960 feet BKB 9205 feet 11848 feet BKB 9131 feet 5. Type of Well: Development X Exploratory ~ Stratigraphic ~ Service 6. Datum elevation (DF or KB) KBE=68.74 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-15 (32-26-12-12) PBU 9. Permit number 84-71 10. APl number 50- 029-21113 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) fill at 11848'MD (01/90) Casing Length Size Cemented Measured depth Structural -- Conductor 110 20x30 8 c.y. 138 Surface 2480 13 3/8 3470 c.f. 2508 Intermediate 11279 9 5/8 3003 c.f. 11307 Production -- Liner 1378 7 391 c.f. 10582-11960 Perforation depth: measured 11584'-11640 'BKB true vertical subsea 8889.4'-8927' Tubing (size, grade, and measured depth) 4 1/2"L-80 to 10524' with 4 1/2" tailpipe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10524'; 4 1/2" SSSV at 1942' True vertical depth BKB 138 2508 8767 8276-9205 RECEIV[ Gas Cons. CommiSSi¢ 13. Attachments Description summary of proposal × Detailed operations program BOP sketch 14. Estimated date for commencing operation MA Y/JUNE 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'.~ , ~ ~ .~ /~ ,~;[:-, ~0~)~COMMiSSIoNTitle Supervisor Waterf/ood/MiscibleFIOOdusE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity. BOP Test~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- ~- c~ ~. Date ,,..'~//~,.5"'~?(J I Approval ,o. ~ ~ ~.~:~ ?~ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE O. OM!TII Commissioner Approved Copy ,~J~,~e~O, SUBMIT IN TRIPLICATE WELL S-15 (32-26-12-12) HYDRAULIC FRACTURE PROGRAM 1 A hydraulic fractture of the Ivishak interval 11584'-11640' will be performed as follows Rig up fracturing equipment and pressure test. Perform a calibration frac. 3. Fracture as follows: PROPPANT STAGE VOLUME PPG TYPE LBS BPM PAD 50.0 0 0 45 1 4.0 1.0 16/20 CL 4000 45 2 2.5 3.0 16/20 CL 7500 45 3 1.5 5.0 16/20 CL 7500 45 4 0.5 7.0 16/20 CL 3500 45 5 0,2 8.0 16/20 CL 1600 45 6 4.5 10.0 16/20 CL 45000 45 FLUSH 8.4 0 0 45 TOTAL 71.6 69,1 3. Leave well shut in overnight. 4. Clean-out any frac sand left in the wellbore, and return well to production BOWEN P, CKOFF FLOW TUBES & PACKOFF HAND GREASE SEAL FLOWTUBE PUMP FLOWLINE FLOWLINE VALVE GREASE LINE RISER GREASE yMANIFOLD PUMP ~- GREASE RESERVOIR BOP BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 7, 1990 Alaska Oil & Gas Conservation Commi~:sion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-15 (32-26-12-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perform remedial/capacity sustainment work on the well. Yours //~~ very B. J. Po2ficky ~/ Supervisor Waterflood/Miscible Flood BJP:JAM Enclosures (9) cc: L. Burke (MB12-1) Well File RECEIVED A~chor~e 1. Type of Request: ~ STATE OF ALASKA ^ APPLICATION FOR SUNDRY APPROVALS Abandon ~ Suspend. Alter casing ~ Repair well Change approved program ~ 2. Name of Operator BP Exp!oration (Alaska)/nc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. LocatiOn of well at surface 1984' SNL, 716' EWI., SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM (top of Sag R) At effective depth 1784' SNL, 2001' WEL, SEC. 26, T12N, R12E, UPM At total depth 1732' SNL, 1935' WEL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: measured 11960 feet true vertical BKB 9205 feet operation Shutdown ~ Plugging Time extension Pull tubing ~ Variance _ Perforate~ 5. Type of Well: 6. Development x Exploratory Stratigraphlc ~ 7. Service, Re-enter suspended well~ SlJmulate Other X Datum elevation (DF or KB) KBE . 68.74 AMSL feet Unit or Property name Prudhoe Bay Unit 8. Well number S-15 (32-26-12-12) PBU 9. Permit number 84-71 10, APl number 50- 029-21113 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 11848 feet true vertical BKB 9131 feet Junk (measured) fill at 11848'MD (01/90) Casing Length Size Structural -- Conductor 110 20x30 Surface 2480 13 3/8 Intermediate 11279 9 5/8 Production -- Liner 1378 7 Perforation depth: measured 11382'- 11430' (Sag R) 11584'- 11685' (Ivishak) true vertical subsea 8752'- 8785', 8889'- 8957' Cemented Measured depth True vertical depth BKB 8 c.y. 138 138 3470 c.f. 2508 2508 3003 c.f. 11307 8767 391 c.f. 10582-11960 8276-9205 Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10524' with 4 1/2" tailp~pe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BO T packer at 10524'; 4 1/2"$SSVat 1942' 13. Attachments Description summary of proposal × Detailed operations program BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: February 1990 16. If proposal was verbally approved Oil X Gas~ Suspended Name of approver Date approved Service 17. I hereby certify that the.f, oreg, o~g i~ true/~nd correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- '~-c~ 0hlGh,:~L $16i,!ED ~¥ Approved by order of the Commission Commissioner I Approval "o<:~ _ 0~'~ Form 10-403 Rev 06/15/88 LONNIF r,., _~?~IT'~. Approved Copy Retu, rned SUBMIT IN TRIPLICATE STATE SUNDRY NOTICE Well S-15 Well S-15 needs a WSO cement squeeze with coiled tubing. The program involves squeezing all perforations followed by phased reperforation. A summary of the planned procedure is as follows: 1. MIRU coiled tubing unit. 2. Acid wash the perforations. 3. Liquid pack the well and cool the reservoir. 5. Cement squeeze all perforations up to 3000 psi differential. 6. Reverse out cement after holding squeeze for 30 to 40 minutes. 7. Reverse in nitrogen to underbalance well for perforating and inflow test. 8. Leave well with sufficient WHP to maintain 1000 psi positive differential at perforations for WOC period. 9. Inflow test well. 10. Resqueeze well if it fails inflow. 11. If no inflow is observed then reperforate as follows: (P,¢£, 6/29/84 BHCS) 11382'-11430' 11584'- 11640' 11640'- 11650' 11650'-11675' 11675'-11685' Phase II Reperf Phase I Reperf Suspend Phase II Reperf Suspend 12. Put well on production. PLH,2/7/90 Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Off Blind Rams Cutter Rams 2" Chicksan (Kill Line) Slips Pipe Rams Pump-In Sub (C irc ula te/R e turn s ) W ell Head Swab Valve BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard EO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: ARCO CHEVRON EX~0N TEXACO HOBIL PHILLIPS ARCHIVES DATE: 01/25/90 T#: 80813 BP FINAL DATA - PRESSURE SURVEY DATA Enclosed is your copy of ~he material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. R-19 BEP Pressure Report 01/01/90 Static Gradient Camco S-15 BHP Pressure Report 01/02/90 Static Gradient Camco REEl ED J~~]990 ~~ Oil '&; Gas Cons. CommissiO_.i3 Anchorage Information Control Well Records LR 2-1 J. Dietz/S. McCurry BP EXPLORATION BP Exl31orat~on (Alaska) Inc. 900 Eas! Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 01/22/90 Transmittal: 80808 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If questions, please contact BP Well Records at (907) 564-4445. C-02 TEMP~' 01/03/90 #1 9800-10194 C-05 TEMP~ r 01/03/90 ~1 11500-11843 F-22 ~J~0D-F~ 01/05/90 #1 9550-9840 G-17 PROD:/ 01/04/90 ~1 11000-11299 M-11 .~'.' 01/04/90 #1 8100-9203 Q-05 TE~4P~--- 01/08/90 ..- #I .. 10100-10421 a-02 INJ ~_ 01/01/90 #1 9250-9913 S-15 CCLJ - 01/02/90 #1 10250-11650 W-Il S~I~ER( 01/04/90 #1 12500-13562 Z-02 PRODJ 01/05/90 #1 g60D-9800 you have Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco 5" 5" 5" 5" 5" 5" 5" 5" 5" any Distribution: .ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (9O7) 561-5111 To: Distribution Date: 12/05/89 Transmittal: 80645 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. S-15 PITS 11/20/89 #1 10400-11850 Camco 5" DEC 1. 1989 Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RES ERVO_O_IR~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 Eas! Benson Boulevard PO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO HOUSTON ARCO CHEVRON EXXON , MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES Date: 06/09/89 T~: 80118 BP CASED HOLE FINAL LOGS The following material is being submitted herewith, Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-18 Collar 06/05/89 %1 9235-10235 Atlas A-22 Completion 06/02/89 #1 11300-11783 Sch A-35 Completion 06/02/89 #1 9550-9775 Sch C-26 Completion 06/03/89 %1 11223-11754 Sch F-07 GR 06/03/89 #1 9157-11590 Sch J-02 Collar 06/04/89 #1 9100-101184 Atlas N-11A Gas Lift Temp Sur 05/17/89 #1 2500-10603 Camco N-19 Gas lift Temp Sur 05/17/89 #1 2500-10010 Camco S-15 Temp-Spin 05/20/89 %1 2500-11458 Camco Q-04 Completion 06/04/89 #1 9365-9600 Sch J-06 GR 05/16/89 ~1 10000-11452 Camco W-37. Pits 05/19/89 ~1 9650-10214 Camco GC-lC Collar 06/03/89 ~1 5-3585 Sch GC-lC Straddle Ass Setting Record 06/03/89 #1 3368-3595 w 5" 5" 5" 5" 5" 1"/5" 1"/5" 1"/5" 5' 5" 5" 5" Sch 5' Received: Date: f 14 1989 Well Records LR2-1 J, Dietz/S. McCurry Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION ~tOUSTON ARCO CEEVRON E3:XON TEXACO 'TO: MOBIL STA~E Ok' AR~S I NOEXED BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anct~orage. Alaska 99519-6612 (907) 561-5111 Date: 05-05-89 80036 REFERENCE:: BP F~NAL DATA - PRESSURE SL~Y DATA The following meterlat Is being submitted herewith. Please acknowledge receipt by signing a copy of this.le~-fer and returning It to this office: A-33 BHP--S tatic Gradient 04-27-89 Camco C-04 BHP--S tatic Gradient 04-30-89 Camco K-O1 B~P--S tatic Gradient 04-26-89 Camco M-05 BHP--S tatic Gradient 04-26-89 Camco N-09 BH~--Static Gradient 04-27-89 Camco S-07 BHP--S tatic Gradient 04-30-89 Camco S-15 BHP--S tatic Gradient 04-25-89 Camco U-06 BHP--S tatic Gradient 04-25-89 Camco W-22 · BHP--Static Gradient 04-26-89 Camco X-09 BHP--Static Gradient 04-29-89 Camco X-15 BHP--Static Gradient 04-27-89 Camco W-20 BHP--S tatic Gradient 04-28-89 Camco Gas Cons. Commission Anchorage Received Date Shirley R. McCurry ~ NFORMAT ~ ON CONTROL Wel I Records LR2-1 BP EXPLORATION May 8, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-15 (32-26-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of performing a stimulation of the well. Yours very truly, ~~naA~eBrr;grogduction Englneerinv V g JAM: JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File STATE OF ALASKA AI_~KA OIL AND GAS CONSERVATION COMMIS~,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Stimulate X Plugging Alter casing Repair well 5. Type of Well: Development X Exploratory S~'atigraphic Service Perforate Other 6. Datum elevation (DF or KB) KBE = 68. 74 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 1984' SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM (top of Sag R) At effective depth 1972' SNL, 2244' WEL, SEC. 26, T12N, R12E, UPM At total depth 1732' SNL, 1935'WEL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: Effective depth: 8. Well number S- 15 (32-26-12-12) PBU 9. Permit number/approval number 84-71 / 9-148 10. APl number 50- 029-21113 11. Field/Pool Prudhoe Oil Pool measured 11960 feet true vertical BKB 9205feet measured 11435 feet true vertical BKB 8855feet Plugs (measured) Junk (measured) fill at 11435' MD (04/89) covering Ivishak peris Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20x30 8 c.y. 138 138 Surface 2480 13 3/8 3470 c.f. 2508 2508 Intermediate 11279 9 5/8 3003 c.f. 11307 8767 Production -- Liner 1378 7 391 c.f. 10582-11960 8276-9205 Perforation depth: measured 11382'- 11430' (Sag R) 11584'- 11685' (ivishak) true vertical subsea 8752'- 8785', 8889'- 8957' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10524' with 4 1/2" tailpipe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BO T packer at 10524? 41/2"SSSVat 1942' R ~ C 13. Stimulation or cement squeeze summary see attachment MAY i 0 Intewals treat~ (measure) Alasl~a Oil & ~ {'.~,~:~ ~".~,:, ........ Treatment de~ription including volumes used and final procure A[lch~t 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 720 1096 672 1001 199 720 1163 24 1645 228 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing i~ true and correct to the best of my knowledge. Form ~'-~4 Rev 06/15J88 SUBMIT IN DUPLICATE A 15% FICI perforation wash was performed April 11, 1989, on the following Sag R. interval in Well S-15. 11382' - 11430' MD BKB acid wash consisted of pumping 27 bbls. of diesel followed by 60 bbls. 15% HCI/10% reciprocating across the perfs. The well Thc xylen~ down coiled tubing at maximum rate while was returned to production immediately following the acid treatment. jm 4/26/89 RECEIVEr':) MAY 1 0 Alasl',a Oil & G~.s Anche~a§e BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 February 21, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-15 (32-26-12-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, Manager Production Engineering JAB:JAM Enclosures (9) cc: L. Burke (MB12-1) Well File · _ Gas Cons, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend Operation Shutdown Re-enter suspended well Alter casing __ Repair well Plugging ~ Time extension ~ Stimulate X Change approved program Pull tubing Variance __ Perforate __ Other __ 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1984' SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC,. 26, T12N, R12E, UPM At effective depth 1947' SNL, 2212' WEL, SEC. 26, T12N, R12E, UPM At total depth 1732' SNL, 1935' WEL, SEC. 26, T12N, R12E, UPM 5. Type of Well: Development x Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE,68.74 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-15 (32-26-12-12) PBU 9. Permit number 84-71 10. APl number 50- 029-21113 11. Field/Pool Prudhoe Oil Pool 12. Present well condition summary Total depth: measured 11960 feet Plugs (measured) true vertical BKB 9205 feet 11490ffs( Effective depth: measured 11490 feet Junk (measured) fill at 10/88) covering true vertical BKB 8892 feet Ivishak pe Casing Length Size Cemented Measured depth Structural -- Conductor 110 20x30 8 c.y. 138 Surface 2480 13 3/8 3470 c.f. 2508 Intermediate 11279 9 5/8 3003 c.f. 11307 Production -- Liner 1378 7 391 c.f. 10582-11960 Perforation depth: measured 11382'- 11430' (Sag R). 11584'- 11685' (Ivishak) true vertical subsea 8752'- 8785', 8889'- 8957' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10524' with 4 1/2" tailp~oe to 10631' Packers and SSSV (type and measured depth) 95/8"BOTpackerat 10524'; 4 1/2"SSSVat 1942' True vertical depth BKB 138 2508 8767 8276-9205 13. Attachments Description summary of proposal x Detailed operations program BOP sketch _Z__ 14. Estimated date for commencing operation February 1989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY I Condigns of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test Location clearance ~ Subsequent form required 10- ~ c/~ Mechanical Integrity Test~ Approved by order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LO.?!!5 C. _~.~!TH Commissioner ~,pproved Copy Returned Date~O I Approval No. ~..-/'-~ Date ~-~Y 7f ~ SUBMIT IN TRIPLICATE WELL ~-15 (32-26-12-12~ PBU STIMULATION PROPOS,a_L A 15% HC1 perforation wash followed by a contingent scale inhibition treatment is proposed for the following perforated intervals in Well S-15. 11382'- l1430'MDBKB 11584'- l1685'MDB~ The acid wash will consist of pumping 25 bbls. of diesel followed by 2500 gal. 15% HCI/ xylene down coiled tubing at maximum rate while reciprocating across the Ivishak perfs. If TD is above the perfs, the CT will be positioned 10' off bottom and the treatment pumped. The well will be returned to production immediately following the acid treatment. Depending on the results of the HC1 wash, the following scale inhibition treatment will be pumped: 15 bbls. diesel preflush 15 bbls. methanol 36 bbls. EDTA w/OSR 125-150 bbls. scale inhibitor w/OSR 15 bbls. seawater followed by diesel The treatment fluids will be displaced to the perforations with remaining seawater. well will be left shut in for 24 hours, then returned to production and tested. The jm 2/9/89 Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Of~ ! ~ '~ I . Cutter Rams j~~I-/'-~2'~Chlcksan (Kill Line) m Pipe Rams ump In Sub (Clrcula te/R e turns) W ell Head Swab Valve -~-L..-' TO: HOUSTON ARCO CHEVRON E~YON TEXACO MOBIL PHILLIPS STATE OF ALASKA ARCHIVES INDEXED .-------_... ION Date: 10-28-88 ri: 79476 REFERENCE: SAPC FINAL'DATA - PRESSURE SURVEY DATA The following mater/a/ is being submiYted herewith. Please acknowledge receipt by signing a copy of this ie~-fer and returning it to this office: Pressure Buildup Static Gradient Static Gradient Static Gradient Static Gradient Static' Gradient Static Gradient Static Gradient Static Gradient Static Gradient S ratio Gradient Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient Static Gradient W-38 ~ A-21 ~ B-07 ~ B-23 ~E-15 ~E-28 ~J-26 K-Il M-03 M-i0 M-11 S-15 S-19 W-35 Y-14 Y-24 24 10-09-88 Gearhart 10-17-88 Camco i 0-15-88 Camco 10-12-88 Camco 10-i4-88 Camco 10-14-88 Camco 10-12-88 Camco I0-17-88 Camc~ I0-16-88 Camc~ 10-15-88 Camco 10-i8-88 Camco 10-18-88 Camco 10-I8-88 Camco 10-19-88 Camco 10-19-88 Camco 10-20-88 Camco i0-14-88 Camco 10-17-88 Camco S ratio Gradient 10-20-88 Camco' s~lon 0a to Anchorage fOu,~ded ,,.,, ('le,elo~*d. C~.o. ,n 18,70 Shirley R. McCurry INFORHAT !ON CONTROL WeJ I Records LR2-1 Standard Alaska Production Company 900 East Benson Boulevc~d P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION October 20, 1988 Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-15 (32-26-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM~ EncloSures (4) cc: L. Burke (FfB12-1) Well Records (LR2-1) w/10 S-15 Well File RECEIVED OCT 2 6 ] 88 A~chora~e A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSi,.,N REPORT OF SUNDRY WELL OPERATIONS 1. Oper~ntions performed: Operation shutdown Stimulate × Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1984' SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM At effective depth 1947' SNL, 2212' WEL, SEC. 26, T12N, R12E, UPM At total depth 1732' SNL, 1935' WEL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical BKB Effective depth: measured true vertical BKB 5. Type of Well: Development X Exploratory StraUgraphic Service 6. Datum elevation (DF or KB) KBE = 68. 74 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-15 (32-26-12-12) PBU 9. Permit number/approval number 84-71 / 8-588 10. APl number 50- 029-21113 11. Field/Pool Prudhoe Oil Pool 11960feet 9205feet 11490feet 8892feet Plugs (measured) Junk (measured) fill at 11490' (09/88) covering Ivishak perfs Casing Length Structural -- Conductor 110 Surface 2480 Intermediate 11279 Production -- Liner 1378 Perforation depth: measured Size Cemented Measured depth True vertical depth BKB 20x30 8 c.y. 138 138 13 3/8 3470 c.f. 2508 2508 9 5/8 3003 c.f. 11307 8767 7 11382'- 11430' (Sag R) 11584'- 11685' (Ivishak) 391 c.f. 10582-11960 8276-9205 true vertical subsea 8752'- 8785', 8889'- 8957' Tubing (size, grade, and measured depth) 4 1/2" L-80 to 10524' with 4 1/2" tailpipe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BOTpackerat 10524~ 4 1/2" SSSV at 1942' R E C E ] V E D 13. Stimulation or cement squeeze summary see attachment O~,L~ 2 6 1988 Intervals treated (measured) Treatment description including volumes used and final pressure · ,~,. ,:?. Oil & Gas Cons. Anchoi'ail~; 14. Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 1010 1271 346 1046 220 1010 1144 589 973 222 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas . Suspended 17. I. hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10~'4 Rev 06/15/88 Title Manager Production Engineering Date//,,)' SUBMIT IN DUPLICATE WELL S-15 (32-26-12-12) PBU STIMI. ILATIQN PROPOSAL An EDTA treatment was performed August 21, 1988 on the following perforated interval in Well S-15. 11584' - 11654' MD BKB (Ivishak) The bottom 31' (11654'-11685'MD) was not stimulated due to fill covering the bottom of the hole. An inflatable packer was set at 11525' to isolate the treated interval from the upper Sag interval. The treatment consisted of pumping the following down coiled tubing: 40 bbls. EDTA for sump cleanout 48 bbls. treated seawater to set packer 10 bbls. diesel preflush w/mutual solvent 20 bbls. EDTA 6 bbls. diverter 20 bbls. EDTA 6 bbls. diverter 20 bbls. EDTA 6 bbls. diverter 20 bbls. EDTA 6 bbls. diverter 30 bbls. EDTA 12 bbls. diverter 30 bbls. diesel overflush The scale inhibition portion of the treatment was aborted due to hole conditions. The inflatable packer was released but was left in the hole while POH. Fishing operations were as follows: 8/23/88 Performed an HC1 cleanout to 10750' (fill is OSR resin). 8/24-9/1 1/88 Attempted to fish packer. 9/12/88 Performed an fill cleanout with 23 bbls. HC1. Found top of CTU packer at 11403' CTD. 9/13-26/88 Recovered fish. Fill covering Ivishak pcrfs at 11490'. Returned well to production and tested. RECEIVED jm o/ 4/ss OCT 2 6 1988 Oil & (~as Cons. Cornrnis~:: _ Anchorage Standard Ala$i,a Production Company ~0 l:O$1 Ban%on Boulevard Anchorage. Alaska ~519-66 (~7) 564-51 I I HOUSTON INDEXED ARCO CHEVRON EXXON TEXACO STANDARD ALASKA PRODUCTION 07/29/88 Date: TO: MOBIL TI: 79145 PHILLIPS STATE OF ALASKA GEOSCIENCES RES ERVO IR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter end returning it to this office: ! M-19 R-22 S~15 Z-01 Z-O1 Z-O1 Production 07/21/88 #2 11120-11600 Sch 5" Completion Record 07/23/88 #2 9820-10490 Sch 5" Production 07/23/88 ~2 10470-10478 Sch 5" Production 07/20/88 ~1 10300-10692 Sch 5" Production 07/19/88 #2 ~11200-11500 Sch 5" CBT 07/21/88 #1 9886-10784 Sch 5" CET 07/21/88 #1 9886-10802 Sch 5" Perf Record 07/22/88 #1 10468-10752 Sch 5" Rece I ved Da te A un,! al ~h~ I:~,.,,,J-H ,n (-I~'.*-I¢],,d Commission Jennifer Dietz I NFORHAT I ON CONTROL Wel I Records LR2-1 Standard Alaska Production Company 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION July 27, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-15 (32-26-12.-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM Enclosures (9) cc: J. L. Haas (MB12-1) S-15 Well File anager [ roduction Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon [] Suspend I"! Operation Shutdown I-I Re-enter suspended well [] Alter casing I"1 Time extension [] Change approved program D Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Standard Alaska Production Company Address P. O. Box 196612, Alaska 99519-6612 1984' SNL, 716' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, SEC. 26, T12N, R12E, UPM At effective depth 1917' SNL, 2170'WEL, SEC. 26, T12N, R12E, UPM At total depth 1732' SNL, 1935' WEL, SEC. 26, T12N, R12E, UPM Present well condition summary Total depth: measured 11960 feet true vertical BKB 9205 feet Effective depth: measured 11562 feet true vertical BKB 8941 feet Casing Length Size Structural -- Co nd ucto r 110 20x30 S u rface 2480 13 3/8 I nterm ed late 11279 9 5/8 Production Liner Perforation depth: 5. Datum elevation (DF or KB) KBE = 68.74 AMSL feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number S-15 (32-26-12-12) PBU 8. Permit number 84-71 9. APl number 5 0 - 029-21113 0. Pool Prudhoe Oil Pool Plug; (measured) Junk (measured) fill at i1562' WLM (07/88) Cemented Measured depth True Vertical depth BKB 8 c.y. 138 138 3470 c.f. 2508 2508 3003 c.f. 11307 8767 ._ 1378 7 391 c.f. measured 11382°- 11430' (Sag R) 11584'- 11685' (ivishak) true vertical subsea 8752'- 8785', 8889' - 8957' Tubing (size, grade and measured depth) 4 1/2"L-80to 10524'with 4 1/2"tailpipe to 10631' Packers and SSSV (type and measured depth) I0582-11960 8276-9205 9 5/'8" BOTpacker at 10524'; 4 1/2" SSS V at 1942' 12. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 3. Estimated date for commencing operation 1988 Su~seqt:e~_ ~Vor~ 4. If proposal was verbally approved Form No./6)- Name of approver Lonnie Smith Date approved 7/18/88 J15. I he~by~ certify that t,h~e, oforegoing is true and correct to the best of my knowledge Signed ~ ~,~~ Title Manager Production Engineering I ~/ /"/'¢ Commission Use Only J Condmons of approval Notify commission so representative may witness IApproval No. [] Plug integrity E] BOP Test E] Location clearance I ~/~,~,~~ ~,pproved.l~etu r n.e,~ Copy omm~i~OrdOr 0f Approved by _ . C commission Form 10-403 Rev 12-1-85' // / Date 7' ~ 2' ~(~ S,~bm'it in triplicate WELL S-15 (32-26-12-12~ PBU STIMULATION PROPOSAL A combination EDTA/scale inhibition treatment is proposed for the following perforated intervals in Well S-15. 11382' - 11430' MD BKB (Sag R) 11584' - 11685' MD BKB (Ivishak) The Sag interval may or may not be stimulated, depending on the results of a pre- stimulation spinner. If there is some indication of Sag production, the Sag will not be stimulated and an inflatable packer will be set between 11430' and 11584' to isolate the Sag interval from the Ivishak inter~al. The treatment will consist of the following pumped via coiled tubing: 25 bbls. treated seawater 10 bbls. diesel preflush w/mutual solvent 10 bbls. EDTA 8 bbls. diverter 20 bbls. EDTA 8 bbls. diverter 30 bbls. EDTA 8 bbls. diverter 40 bbls. EDTA 108-130 bbls. scale inhibitor Seawater overflush The well will be left shut in for 24 hours, then returned to production and tested. jm 7/19/88 Coiled Tubing Blow-Out-Preventers Coiled Tubing · Pack-Off ') Blind Rams Cutter Rams 2" Chicksan (Kill Line) Slips Pipe Rams Pump-In Sub (Circula te/R e turns ) W ell Head Swab Valve Standard Alaska P~oduction Company ~ Eo$! aenson Boulev P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 564-5! ! ! INDEXED DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD ALASKA PRODUCTION Date: 01/07/87 TO: TI: 77646 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: C-32 Perf. Record 08/14/86 #1 9220-10398 Sch O-1 " " 07/21/86 #1 9010-9778 Sch D-24 Per.f-. Record 07/28/86 #1 9690-11060 Sch D-25 Perf. Record 07/26/86 #1 9990-10876 Sch F-5 Tubing Puncher 08/16/86 #1 Sch F-5 EPL ~: 08/17/86 #1 0-9650 Sch F-5 Tubing Puncher 08/21/86 9300-9663 Sch F-9 Collar 07/28/86 #1 8500-8810 Sch F-18 Perf. Record 07/i9/86 #1 11210-12220 Sch F-23 CCL-tie-in 12/31/86 #1 9500-10480 Camco H-21 Temp. 12/27/86 #1 2858-9827 Camco J-2 GR 12/31/86 al 9000-10333 camco M-4 Production Profile 01/01/87 al 11150-11630 camco M-23 -Production Profile 12/30/86 #1 9350-9850 Camco M-28 Injection Profile 01/02/87 #1 8580-9160 Camco S-15 EPL 07/07/86 'al 11200-11750 Sch s-19 ELowmeter 12/29/86 #2 9500-10050 Camco U-13 Perf. Record 07/25/86 #1 10195-11473 Sch X-14 Perf. Record 08/07/86 al 10650-11510 Sch 5II 5" 5" 5" 5" 5" 5'm 5t~ 5" 5" 5" 5" 5" Received ·. 7 . ~aska Oil & .Gas. Com. Commisslon Date ancnorafle A unil of the oflg;nol Standard Oil Company Founded in Cle,elond. Victoria Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 I',oduct~n Compo~ 900 Eos~ Be~c~ Bou~ P-O ~o, JgOl) f~$4-.~ I I I I NDE:XED TO: DALLAS A~co STANDARD cimwo. ALASKA PRODUCTION EXXON Date: 07/29/86 TEXACO TI: 77227 MOBIL PHILLIPS GEOSCIENCES REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following m~terlal is being submitted here~ith. Please acknowledge receipt by signing a copy of this let-far and returning It to this office: ---A-22 ?A-30 ~A-30 C-1 lJ G_i~- _ G-16 jrt-6 --H-6 H-24-- -- H-25 ~- M-4- ~N-9 -R-1 --S-2 - S-2 --S-10 -- S-13 -S-15 ~-X-25 Received Date Static 07/01/86 GO BH Pressure data 06/19/86 GO PBU 06/18/86 GO Static 06/20/86 Camco Static 07/03/86 GO Static 07/05/86 Camco Static 06/21/86 Camco Static 06/24/86 Camco Static 07/01/86 Camco Static 07/01/86 Camco Static 06/07/86 Camco Static 06/16/86 Camco Static : 06/20/86 Camco Static 07/0~/86 Camco Static 07/06/86 Camco Static 07/03/86 Camco Static 07/07/86 Camco BHPD & PBU 07/05/86 GO BHPD & PBU 06/23/86 GO BHPD & Flow test & PBU 06/15/86 GO Victoria Aldridge LR2-1 INFORMATION CONTROL Wel I Records LR2-1 A ,.,mt c.! me o*,<~,.,,,I 5,und,,,,t 0,1 [ound~.ll ,n Cie,e. lu,,~,l CI~, ,,. SOHIO ALASKA PETROLEUM COMPANY DALLAS ARCO CHEVRON EXXON TO: DAL/UNIT/STATE: TE]OkCO (-Marathon) MOBIL PHILLIPS 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: T#: 04/18/86 77006 STATE OF AK BPAE GEOSCIENCES REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- DAL/UNIT/STATE/GEOS: A-28 CNL 01/03/86 #1 11500-11955 Sch 5" Q-3 packer Depth - 01/i7/86 #2 4100-4362 Sch 5" S-15 Temp. 04/08/86 #1 20-2500 Camco 5" S-18 Temp. 04/08/86 #1 40-2500 Camco 5" A R 2 1 l OSG RECEIVED Victoria Aldridge LR2-1 INFORMATION CONTROL WELL RECORDS LR2-1 19 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 July 17, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTN: Mrl C,V. Chatterton Wells S-15, S-16 AND S-17 PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells These contain our proposals to perforate these wells JAB h 7178~: 0505N Yours very truly, VSAPC Petroleum Engineer Enclosures cc: T.N. Tyler Well Records (LR2-1) Drilling Well File #17 RECEIVED Alaska 0il & Gas Cor~g. STATE OF ALASKA ALASKA u~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator Sohio Alaska Petroleum Company '~ Anchorage~ AK 99502 3. Address PO Box 6612, , COMPLETED WELL OTHER [] 4. Location of Well At Surface: 1984' SNL, 716' EWL, Sec. 35, T12N, .R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 7. Permit No. 84-71 8. APl Number 50-- 029-21113 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-15 (32-26-12-12) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool I 6. Lease Designation and Serial No. KBE = 68.74' AMSL ADL 28257 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any 12. proposed work, for Abandonment see 20 AAC 25.105-170). The following interval will be perforated in August 1985 using Schlumberger 2-7/8" Hyperdomes at 4 spf. A lubricator will be installed and tested to 3500 psi for all well work. 11584' - 11685" BKB (Ref. BHCA/GR, 6/29/84) A SSSV will be set and tested in the b-all valve nipple at 1942', 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Condit~ of Approval, if any: ~pproved Co~y Date Approved by By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate Standard Alaska Production Compan 900 East Benson Boul~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION June 6, 1986 Alaska 0il & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Well S-15 (32-26-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, SLB:JAM~ Enclosures (4) cc: J. L. Haas, MB12-1 Well Records, LR2-1 S-15 Well File S. L. Bryant, Supervisor Reservoir/Production Surveillance Unit II A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. ~- STATE OF ALASKA ALASKA (. AND GAS CONSERVATION COMMIS[ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed' Operation shutdown ~ Stimulate ~ Plugging ~ Perforate ,~ Pull tubing Alter Casing ~ Other ~ 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 68.74 Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. 11. Present well condition summary Total depth: measured true vertical Location of well at surface 1984' SNL, 716' EWL, Sec. 35, Ti2N, R12E, UPM At top of productive interval 1997' SNL, 2276' WEL, Sec. 26, T12N, R12E, UPM At effective depth 1766' SNL, 1978' WEL, Sec. 26, T12N, R12E, UPM At total depth 1732' SNL, 1935' WEL, Sec. 26~ .T12N, R12E, UPM 11960 feet Plugs (measured) 9205 feet BKB 7. Well number S-15 (32-26-12-12) PBU 8. Approval number N/A 9. APl number 50-- 029-21113 10. Pool Prudhoe Oil Pool Effective depth: measured 11887 feet Junk (measured) true vertical 9157 feet BKB 12. Casing Length Size Cemented Structural -- Conductor 69' 20"x30" 8 cu.yds o Surface 2467' 13 3/8" 3470 c,f, Intermediate 11266' 9 5/8" 3003 C.f. Production Measured depth 110' 2508' 11307' True Vertical depth BKB 110' 2508' 8767' Liner 1378' 7" Perforation depth: measured 11382" - 11430' (Sag) 11584' - 11685' (Ivishak) true vertical (subsea) 8752' - 8785' 8889' - 8957' Tubing (size, grade and measured depth) 391 c.f. 10582'-11960' 4 1/2" L-80 to 10524' with 4 1/2" tailpipe to 10631' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 10524"; 4 1/2" SSSV at 1942' Stimulation or cement squeeze summary Intervals treated (measured) 8276'-9205' Treatment description including volumes used and final pressure ii ,,,. ',: :_:; 13. Representative Daily Average ProduCtion or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 2560 1907 20 14. Attachments 1372 218 Daily Report of Well Operations Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowle~~ll~~i~_ ~ _,,~~ Signed ./~~~ ~'~ ~ TitleSupvr. Res./Prod. Surveillance II Date¢/_~/~ Form 10-404 Rev. 12-1-85 Submit id Duplicate' PERFORATING DATA - Well S-15 (32-26-12-12) PBU 5/9/86 5/17/86 5/27/86 5/29/86 5/30/86 Installed and tested lubricator to 3500 psi for all well work. Rigged up Gearhart and perforated the following intervals for initial production using 3 1/8" hollow-steel carrier guns at 4 spf: 11584' - 11604' MD (8889' - 8903' TVDss) Put on production and tested. Installed and tested lubricator to 3500 psi for all well work. Rigged up Gearhart and perforated the following additional intervals using 3 1/8" hollow- steel carrier guns at 4 spf: 11382' - 11430' MD (8752' - 8785' TVDss) 11604' - 11685' MD (8903' - 8957' TVDss) Note: All depths are referenced to BHCS/GR, 6/29/84. Put well on production and tested. Shut in well to prepare for static pressure survey. Ran static presSure/temperature survey at 8800' TVDss. Set and tested SSSV in ball valve nipple at 1942'. Well on'prodUction jm 6/4/86 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502~612 March 12, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 kttn: Mr. C. V. Chatterton Well S-15 (32-26-12-12) PBU Gentlemen: Enclosed in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to perforate the well. Very truly yours, S. L~~. Br~ya~3nt ~ ~ Supervisor, Reservoir/ Production Surveillance Unit II SLB: JAM ~ Enclosures (3) cc: Drilling Well Files (MB 12-1) Well Records (LR 2-1) S-15 Well File 4052m RECEIVED 1 4 1986 Alaska ~)il & ~.~:~s g~)P.s. Commission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. STANDARD ALASKA PRODUCTION COMPANY 84-71 3. Address 8. APINumber P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50- 029-21113 4. Location of Well At surface: 1984' SNL, 716' EWL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 68.74' AMSL 12. I 6 . Lease Designation and Serial No. ADL 28257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-15 (32-26-12-12) PBU 11. FieldandPool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [-] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following Sag River interval will be perforated in March/April, 1986 at 4 spf: 11382' - 11430' BKB (Ref. BHCS/GR, 6/29/84) A lubricator will be installed and tested to 3500 psi for all well work. An SSSV will be set and tested in the'ball valve nipple at 1942'. RECEIVED MAR 1 4 191{6 Alaska 0il & Gas Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. '~~dac~ '~"~ T,tle SUpV3f. Re s ervoir/Prodl/ction p ow or uommission use S. L. Bryant Surveillance Unit II Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 4/82) SOHIO ALASKA PETROLEUM COMPANY TO: SFO ARCO CHEVRON EXXON SFO/UNIT/ TEXACO STATE: ~t~dlATHON MOBIL PHILLIPS *STATE OF AK BPAE (Transmittal Only) CENTRAL FILES (CC#'s-Transmittal Only) REFERENCE: 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE 1907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 12/26/84 CC#: 75936 *Date to State Via Drilling: SOH~ OPEN HOLE FINAL LOGS /~he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- SFO/UNIT/STATE: S-15 Gamma Ray 5/28/84 9700-11320 GO 5" & 2" SFO/ARCo/EXXON/MOBIL/PHILLIPS ONLY: S-15 Gamma Ray-TVD 5/28/84 7700-8760 GO 5" STATE ONLY: DIRECTIONAL SURVEYS Magnetic Single Shot Directional Survey Date: Jobt!: Gyroscopic Directional Survey RECEIVED DAT[ Date: Jobtt: ,~\,:~...~/J.~l ,~..~,~ Victoria Aldridge TPi-1 Gas Cons, O0mmissi0~ Anchorage SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON ' 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 GETTY TO: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS .?~TATE :'OF-' AK BPAE -(Transmittal Only) .. CENTRAL FILES (CC#' s-Transmittal 'Only) Date: 8-30-84 CC#: 75680 REFERENCE: 0_._HI..__~O CASE~_D HOLE__ FINAL LOGS The foflowing materia~ is being submitted herewith. P~ease acknowledge receipt by signing copy of this letter amd returning it to this office:-- c_12/ S-15 ~/~L J-11 J-12 ~' .~- J_13~' M- 16 ~.~ R-Il R-12 ~' R-22/ S-15f R-13 CNL TDT-M TDT-M TDT-M TDT-M TDT-M Compl. Rec. Compl. Rec. Compl. Rec. GCT Gyro Well GCT Gyro Well Perf. Record 7-18-84 #2 7-4-84 #1 6-26-84 ~1 7-12-84 %1 7-14-84 #1 7-13-84 ~2 7-7-84 #2 7-9-84 ~0 7-18-84 %1 7-19-84 #1 7-5-84 #1 7-4-84 #1 6-26-84 #1 7-22-84 #1 11000-11896 Sch 5" 11250-11872 Sch 5" 8850-9265 ...... Sch " 10100-10970 Sch 5" 9150-10172 Sch 5" 10800-11717 Sch 5" 10750-11630 Sch 5" 9590 Sch 5" 10822-10851 SCh 5" 5" 5" -- : l1022rllQ6Q ....... Sc_b__ 9950-10879 Sch - - -11846 Sch - - -9294 Sch 8700-10108 Sch (4/82) RECEIVED DATE Carolyn Bishop Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 August 3, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: WELL S-15 (32-26-12-12) PBU Enclosed, in duplicate, is Form 10-407, Well Completion Report, for the above-named well together with the Well History and Directional Surveys. Partial open hole logs were obtained in the 8 1/2" hole. A compensated neutron log was run in cased hole. This well has been completed as a non-perforated oil well. Yours very truly, MQ4:ckg 8184 Enclosure cc: Well File #17 Geology RECEIVED o Alaska Oil & Gas Cons, Commission Anchorage -- STATE OF ALASKA wELL ALASKA .-LAND GAS CONSERVATION C(~ MISSION COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum ~mpany R4-71 3. Address 8. APl Number Pouch 6-612, Ar~hora~e. Alaska 99502 50- n~q-?l ] ] ~ 4. Location of well at surface 9. Unit or Lease Name 1984' SNL, 716' EWL, Sec. 35, T12N, R12E, UPM pr~h~ .~v 1'l'n'~- At Top Producing Interval ~t:)p of Sag. R. Sst. 10. Well Number'~ 1997' SNL, 2276' W-EL, Sec. 26, T12N, R12E, UPM S-15 (32-26-12-12) PBU At Total Depth 11. Field and Pool 1732' SNL, 1935' ~EL, Sec. 26, T12N, R12E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. t:~%t~hoe Oil KBE = 68.74' AMSLI ADL 29257 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 5/22/84 6/29/84 7/5/84 feet MSL One 17. Total Depth (MD+TVD) 18.Plug Back DePth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11960'MD-9205'TVD 11887'MD-9157'TVD YES ~ NO []I 1943feet MDI 1860' 22~ Type Electric or Other Logs Run DIL/SFL/GR, DIL/SP/GR/BHCS, CBL/CNL/VDL/GR, GC~ Survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 x 30 Insulat~ ConductdrSurface 110 36 ~ ~_ 13 3/8 72# L-80 Surface 2508 17½ 3470 cu. f~-_. Arc~-_~'c .~- TTT 9 5/8 47# L-80 Surface 11307 12% 2494 c~]. f~. Cla.~.~ C~ w/R~ c~] · - 230 cu. ft. Class G: 279 cu.f~. Perma 7 26# L-80 10581- 11960 8½ 391 CLz.ft. Class G ~i/18% 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4½" 10524 ' 10524 ' None w/4~"tailDi~ 10633 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 11315'-~11109' ;120 cu.f~z. C.]~ss G 10736'-10950' 175 c~].f~-_. C]~.q.q G w/15% .~and 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED.~, OIL-BBL GAS-MCF WATER-BBL 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. None RECEIVED Alaska Oil & ~as Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - : . . ."'._ i :GEoLOGiC MARK'E'Rs .... ~-: i: i'i :~. :~ ~,~ "~.:iI '.' ':"' .,: .... '~":" ;' '-'~ .' . FoRMATioN TEsTs . .. ' · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . _ BKB Shabsea Sag. R. Sst. 11379' 8748' Shublik 11434 ' 8786 ' Ivishak 11582 ' 8887 ' 31. LIST OF ATTACHMENTS Well History.. and Directional Surveys and Well L0. gs 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Date tr. H. tielJ_ey INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached Supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "nOne''. WELL S-15 (32-26-12-12) PBU WELL HISTORY Spudded well at 1800 hours, May 22, 1984. Vertically drilled 17 1/2" hole to 2520' Ran 64 jts. 13 3/8" 72# L-80 Buttress casing to 2508'. Cemented with 300~ cu. ft. Arcticset III cement followed by 465 cu. ft. Arcticset II cement . Installed and tested BOPE. Cleaned out to 2465'; tested casing to 3000 psi, okay. Drilled out to 2540'; ran leak-off test to 0.77 psi/ft. gradient. Directionally drilled 12 1/4" hole to 11320'. Ran open hole logs (DIL/SFL/GR) from 2509' to 8880' MD. Could not get logs below 8880' MD. Ran 278 jts. 9 5/8" 475 L-80 Buttress casing 11307'. Cemented with lead slurry of 2494 cu. ft. Class G cement with 8% Gel followed by tail slurry of 230 cu. ft. Class G neat. Tested casing to 3000 psi, okay. Installed and tested packoff to 5000 psi, okay. Pumped 175 bbls. 9.3 ppg. NaCl down 9 5/8" x 13 3/8" annulus. Tested BOPs. Cleaned out float equipment and directionally drilled 8 1/2" hole to 11519'. Stuck Pipe' - unable to recover~, fish. Plugged back to abandon 8 1/2" hole by laying a 120 cu. ft. Class~G cemeht plug with 18% salt from 11315' MD to 11109' MD. A window Was cut in the 9 5/8" casing from 10830' ~D to 10890' MD. Laid kick-off.plug 'across 9 5/8" window consisting of 175 cu. ft. Class G cement with 15% sand from 10736' MD to 10950' MD. Cleaned out cement to 10835', kicked off and directionally drilled 8 1/2" hole to 11960'. Attempted to obtain open hole logs. Ran DIL/SP/GR/BHCS from 10831' - 11918' MD. Stuck logging tools - RIH;recovered fish. No further attempt to log was made. Ran 34 jts. 7" 26# IJ4S liner to 11960'. Pumped 35 bbls. Sepiolite followed by 391 cu. ft. Class G cement with 18% salt to cement liner. Down-squeezed the 9 5/8" x 13 3/8" annulus with 279 cu. ft. Permafrost C cement followed by Arctic Pack. Cleaned out to 11887' , tested liner to 3000 psi, okay. Changed well over to NaCl. Ran GCT, and CBL/CNL/VDL/GR. Ran 326 jts. 4 1/2" 12.65 A/B Mod Buttress IPC tubing with 4 1/2" tailpipe assembly to 10633'. Landed tubing with ball valve at 1943'. Installed and tested tree. Displaced tubing to diesel, set packer at 10524'. Tested tubing to 3500 psi, okay. Released rig at 1400 hours July 5, 1984. RECEIVED AUG 0 3 1904 Alaska Oil & Gas Cons. Commission Anchorage ~CW DIR~O~ONAL CU&?OMkR I~ISTII~G FOR SOHIO AbASKA PETROLEUM CO, S'15 (32'26'12'12) PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 4 dULY ~984 METHODS OF CO~PU?:ATION ; TOO[~ LOCATION: TANGENTIAL- averaged deviation and azimuth INTERPOLATION.: i~LINEAR VERTICAL SECTION: HORI~ZONTAL DISTANCE PROJECTED ONTO AN AZIMUTH COMPUTATION OAI'E: 30 JULY 1984 PAGE SOHIO A!.,AShA PE~RObEU $-15 (32-20-12-12) PRUDHOE B~Y NORTH SLOPE, ~bA~KA DATE OF SURVEY1 4 JULY 1984 KELLY BUSHING ELEYATXONI ENGINEER: RATHERT iNTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASI]RED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG ~IN DEG VERTICAL DOGLEG RECTANGULAA COORD/NATES HORIZ. SECTION SEVERITY NORTH/SOUT~ EAST/WEST D~ST. FEET DEG/IO0 FEET FEET FEET 0.0'0 0.00 -68,70 0 0 N 0 0 E 100 oO 100,00 31,30 0 0 $ 15 0 W 200:00 200,00 131.30 0 0 S 9 18 W 300 O0 300 O0 231.30 0 34 S 16 16 ~ 400:00 400:00 331 30 0 34 S 20 20 E 500,00 500.00 431:30 0 34 S !.5 57 E 600.00 600.00 53~'30 0 34 S 8 49 E 700 O0 699,99 63J,29 0 34 S 20 18 E 800:00 799.99 731..29 0 34 S 42 46 E 900~00 899,98 ~31,28 0 34 S 49 57 E 0.00 0.00 0,00 N 0.00 '0.29 0,46 0,29 $ 0,24 '0.66 0.12 0'06 S 0.16 -1.13 0.23 1,13 $ 0.02 '1.70 0.28 1 70 S 0,09 o.,o 2,91 O. 2 91 S 0.26 3.60 0.15 3,60 S 0,3~ '4.29 0.22 4,29 S 0,82 -4.92 0,29 4,92 S 1,b5 1000 O0 1100 120~ 1400 1500 1600 1700 1~00 1900 999.98 93].28 O0 1099,97 1031.~7 O0 1199.99 O0 1299.98 O0 1399.97 O0 1499 97 O0 1599 97 O0 1699 97 O0 1799 97 O0 1899 97 0 34 S 47 6 E -5,43 0 0 N 44 43 E -5.62 1131,28 0 0 N 53 35 E -5.46 1231,28 0 0 N 49 12 E -5,20 1331,27 0 34 N 41 49 E '4.82 1431~27 0 0 N 31 18 E -4,44 1531,27 0 0 N 65 16 ~ -4.1b 1631~27 0 34 N 8347 ~ -4.04 1731,~7 0 34 S 80 34 E -4,05 i831.27 0 34 S 75 48 E -4.26 0.31 0.25 0.14 0.09 0 10 0 85 0 1 o 5,43 5.62 5,46 5.20 4 82 S 4 44 S 4 ~6 S 4 04 S 4 05 4 26 20OO O0 2~00 2 O0 2300 2400 2500 260O 2700 2~00 2900 E 1999.96 $ O0 2099,96 S ~94 O0 ~99'96 S 31 1'2 W -5.78 O0 2299,96 S 31 2 W -6,31 O0 2399196 S' 43 45 W -6,64 O0 2499 95 2431. 25 0 0 S 50 18 w -6 94 00 2599 95 2531 00 2699 95 25 0 ~ N 44 56 W -7 25 00 2799 86 6 4,6 43 O0 2899 4~ 2830.7! b 18 N 5 4] ~ 5 81. 0.28 1 22 0 44 0 5O 0 16 48 0 8~ 4 58 4 94 5 78 .31 .64 9 4 17 I25 43S 5.81 3000 31.00 320~ ::: 33'0 3400 :3500 360O 370O 3800 3900 O0 2998 O0 3097 oo 3~9~ o0 32oi O0 348 0 3574 ~0 ~666 O0 37§? O0 ]~7 O0 44: : I: 8O 2 1 09 77 36 37 52 40 36 58 18: 35 56 110 4' I :2 177 299 68,7.0 FT DiPARTURE A INUTH 0,00 N 0 0 g 0,37 $ ~0 16- E 0,68 S 13 25 g 1,14 S 0 5~ E 1,70 2,27 $ 2 25 E 2,92 S 5 2 E 3'62 S 6 4 g 4.37 5,19 2.23 2,44 2.64 2,98 3,35 3.70 3,98 4.45 , 5 ~ 55,16 5,87 S 22 18 g 6,13 S 23 28 g 6,07 $ 25 44 E 5.99 ~ 29 50 E 5,~7 ~ 34 46 E 5,78 S 39 50 E 5,76 S 43 46 E ~.01 S ~7 47 E b,55 5 51 49 ~ 7.24 S 54 I E 6 59 E § 5 5 7 N: 10'49 E 36: ,,il 28 16:;;39 E 82 O0 N 21,14 E 112 O1 N i 52 44 N ,54 E 145 08:10 56 E, 5 27 Nil 13 E 67 N 44 20 N 36 E 1 N 54 263~ O~ N 12 0 33 N 65 4~ :E 306~ 41 N :12 20 E CONPbTATION DATE: 30 JdLY 1984 SnHlO ALASKA PETROLEUM CU, PRUDHOE BAY NORT~ SLOPE, ALASKA PAGE 2 DATE OF SURVEY: 4 JUL~ 19B4 K~LbY BUSHING ELEVATION~ ENGINEER~ RAT~ERT INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAl... VERTICAL DEVIaTiON AZL~UTH DEDT~ DEPTH DE. ~H DEG MIN DEG MIN 68.70 FT 4000,00 3935,87 3867.17 29 2 4100.00 4021.80 3953.19 32 0 4~00.00 4105.40 4036.70 3458 4300 O0 4185,94 4~7,24 37 48 4400 O0 426400 4~95.]0 3943 4500 O0 4339~52 4270'82 42 6 4600 O0 4413:50 4344.80 4223 4700 O0 4487 39 4418.69 42 23 4800 O0 4560.93 449~.~3 4225 4900 O0 4634.0~ 4565,32 4332 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVeRiTY NORTH/SOUTH EAST/WEST DIST, FEET DES/lO0 FEET FEET FEET DES N ~551E 344.38 ~ 17 11 E 393.22 N 18 20 E 445.61 N 18 54 E 50~.75 N 19 28 E 560.75 N ~928 E 62~ 48 N 1928 E 685:92 N ~928 E 749,52 N lg 28 E 813.45 N 1928 E 877.84 5000 00 4700 31 4637,61 44 21. N 18 54 E 943,09 5100 O0 477'7 35 4708.65 45 15 N 1854 E 1009.69 5200 00 484b77 4778.07 4b 24 N 18 27 E 1077.88 5300 O0 491.5 53 4846'83 4657 N 1820 E 1146.77 5500,00 505005 4981.35 4842 N 1745 E 1287,65 5600,00 511,543 5046.73 49 ~6 ~ 17 I! E 13~,86 5700,00 5150.7! 51I~,0~ 496& 5800,00 524~'~,605176,g0 4.946 ~ ~636 E ~505,24 5900,00 5310'46 524:1'7:61:49: 16: 383 2:54 2.05 1,84 2.69 1.47 0.76 0.74 0 54 0:23 344 38 N 44~ 22 N 501 560 622 749 813 877 77 70 E 353.04 N 1242 E 9227 g 403,90 a 1312 E 61N 108 75 N 127 48 N 92 N 192 52 N 215 45 N 237 U4 N 260 99 £ 458.75 N 1344 E 98 g 51 82 N 14 l~ E~: 57 E 58 09 N '4 50 E 98 E 712~55 N 15 42 E 6 E 779.82 N 16 1F 2 E 847.48 ~ 16 11 t 34 ~ 9~5.b3 N ~6 3 I 46 I 89 0 55 0 98 0 53 2 19 0 62 0'61 0 9 94 9 100~ 0 N 1077 1146 1,21.6 1287 1359 1432 1505 1578 283,05 g 984,65 N 16 42 E 69 N 305,76 E 1054,98 h 16 50 E 88 N 328.84 E 1126,93 N 16 57 E 77 N 351,75 E 1199,50 N 17 3 E 6572 NN 397~09374'46 E 1347'48 N .~7 8 E ~ 1273;04 N 17 6 E 86 N 419,~9~ .14~3,15 N 17 9 E N 485,09 ~ 165I:~I0 N 1~ 5 g 61.0000 5440,1.9 5371..49 4950 N i62 E !724,49 1,23 !'724,49 N 527.26 E 1.80329 N 17 0 El 6200 ,00 5505~:2,4 ii797,63 0;51 17:9:7:;63 N: N 16:59 E 6300 O0 5570~33 5501 .63 4.9 16 N' 1453 E 1870,85 0,85 1.870,85 hl 567,79 E 1955. 11 h 1652 ~ 6:46500,0000 O05935 5701;77 5633,07:4::9::]:]154842 N 145]::2: B: : 19 E ~016,67 0,63 2016,67194 NN 5606,00 E 2105..758 I6N 164348 E 6600,0057675:699; 53:0629~:5 :N 76 N 37 E 6700.00 5833,9~ 5765,22 4842 N !~ 10 E 216~,48 0,81 2~.62,48 N 641 .67 E 225568 N ~6 ~1 ~' 6800,00 5900:' ::36 0~4 9235 N 6 ,44 N 4:( 6900,00 5966~58 5897.88 4.8 7 N 12 I E 2308,49 0,62 2308,49 N 674 .57 E 2405'04 N ~6 17 ~ 7000,00 6033, 7 100 006099. 7200 7300 4 0 0 5OO 7600 ::::7700 7800 7900 O0 6302:~: N O0 ,00 644 ~006:5I,: .00 6591 91 .006664 ~3~6 2 E 8279' 2527 :'39 ~{ 2:6 O, 4 ::N :~ 9 N 147 78 t:65 i:6::3:: ::::E 87 34 2' 3 E 3( 99 15 g COMPUTATif)N OATE: 30. JOl,¥ 1984 PAGE 3 SOHIO AI~ASKA PETROLEU~ CO, S-15 (32-26-12-12) PRUDHOE ~l¥ NORTH St, OPE, AbASKA DAT~ OF SURVEY~ 4 JULY 1984 KEbbY BUSHING EbEVATION~ ENGINEER~ RATHERT 68.7-0 FT IMTERPOLATED VAt, UES FOR EVEN 100 FEET OF MEASUREO DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG SIN DEG SIN VERTICAL DOGbEG NECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/100 FEET FEET FEET PEG ~IN 8000 00 6736.55 6667.85 44 7 8100 00 6808.34 6739.64 44 5 8~00 O0 688~ 21 681~,51 42 58 8300 00 6953 70 ~885,00 44 18 8400 O0 70~3 49 6954,79 47 1 8500.00 7089 94 702! 24 49 44 8600.00 7152 7~ 7084:02 52 26 8700 O0 7212 27 7143 52 53 5] 8900,0.0 7331 11 7262,41 53 51 N 15 13 E 3070.03 N 16 4 E 3137 15 N 19 28 E 3202 20 N 18 54 E 3267 27 N 18 54 E 3334 99 N 1.9 28 ~ 3405 52 N 20 37 £ 3478.64 N 24 34 E 3553,30 N 32 40 E 3623,15 N 33 48 ~ 3690.37 0.88 3,87 0,33 2,80 2.40 2,57 2,79 7,94 2.87 0,98 3070 03 N 860.26 E 3188.28 3137~15 N 878,75 E 3257.90 3202,20 N 900,13 E 3326,31 3267.27 N 922.72 E 3395,06 3334 99 N 945,95 E 3466,55 3405 52 N 970 ~5 E 3541,14 3478 64 N 997128 ~ 3~18,77 3553 30 N 1026!99 K 3698,74 3623 15 N 106~ 20 E 3776.77 3690 37 N 1110 73 E 3853,90 9000,00 7389 03 '1320,33 55 0 9100.00 7445147 7376,77 56 22 9200,00 7499,78 7431,08 57 52 9300,00 7551,80 7483,1'0 59 35 9400,00 7601.82 9 9500 O0 7651 '71 35 9600 O0 7702 ~4 0 9700 00 7755 08 9800 9900 N 33 48 E 3757,96 N 34 22 E 3826,33 ~,~ 33 48 E 3895,83 N 33 48 E 3966,64 7533,1~ 60 N 33 48 E 4038,38 7583,00 59 N 34 22 E 4110,05 '1633,94 59 N 34 22 E 4181.05 7686.38 57 52 N 34 57 E 4250,921 00 63 8'7 0,89 1,89 2,77 3895 0,67 3966 0,76 4038 0,64 411.0 1,35 418~ ,33 425 4387 83 N 1249,~8 E 4091 64 N 1297,41E 417 38 N 1345,90 E 4256 05 N 139.4,63 E 4340 0 5 N ~.~43,27 E 4~23, :92 N 1491;93 E :4505. 64 N 1540,62 E 4586 87 N 3757 96 N 1156,30 g 3931 83 N 17 6 g 3826 33 N 1202.55 E 4010 86 bi 17 26 E 36 N 17 47 E 43 S18 ~ g 76 N 18 25 E 2 N 844 E 10000 00 7920. 10300 ::10400 1,0500 1:0600 10700 10900 00 7977. 81 7909; 5 ~ 34 57 E 452~,40 1 1,12 4522 .40 N 1683 .52 N 24 g O0 8036, 31,4 ,22 4:5 :, 43 17291 ;60 N 0 39 g O0 809'1 47 8 8 N 3457 ~ 465 1 1,05 4653,,61 N 177532 E 4980,75 N 2052 g O0 815974:4 1547 ,83 N 02 E: E: O0 8223,35 81 50 ~5 N 34 57 E 478 11 0,62 4781 ,ll N 1864 15 ~ 5131~67 N 21 18 g O0 8287 :~0:9 4844 ,122 29 E oo a352 a9 8~ 48 42 34 57 E 490 38 2~48 4906 38 ~ 1950 90 E 5280 02 N 21 4! E 0000 848690 8418,20 4556 N 3953 E ~:5026,,434: 4,13 5026,43;::67 :NN 2038:::04!3 E 542393:: N ~221542 ~' :: : : : : ::: 11000 O0 8 5 N 4 8 E 50 ' 1 3 5079 89 ~ :11100 I 513i 11200 00 86! 46 58 N 46 46 E 3 I 518 N 2 11300 O0 11500 O0 889~ 1~00 O0 9099, 63 51 1~900 O0 9~65, 23 N ~593 2 g 5 19 E 35 E 2 53 E ,2 E 3 g '7 N 24 34 E ~5 N 24 54 E 22 E 6084 51 N 25 13 E COMPUTATiOI~i DA'I'Ej 30 JUI,¥ lg84 PAGE 4 SOt~IO ALASKA PETRObEU~q CO. S-15 (32-26-12-12) NORTH S~.OPE, ALASKA DATE OF SURVEY: 4 JULY 19~4 ENGINEER: RATHERT 68.70 FT INTERPOI.ATED VALUE6 FOR EVEN 100 FEET DF MEASlJRED DEPTH TRUE SUB-SEA COURSE ME~SI~RED VERTICAT, VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG NIh VWRTICAL DO~LEG RECTANGUbAR COORDINATES HORIZ, DEPARTURE 6ECTION S~VERITY NORTH/SOUTH EAST/WEST DiST, AZIMUTM FEET DEG/~O0 FEET FEET FEET DEG M~N 11960.00 9205.42 9136.72 48 42 ~'] 51 33 E 5532,25 0,00 5532.25 N 2~28.53 E 6124.94 N 25 24 ~ COMPUTATION DATE: 30 JULY 1984 PAGE 5 SOHIO ALASK~ PETRObEU~ $-15 (32-26-12-12) PRUDHOE NORTH St. OPE, ALASKA DATE OF SURVEY: 4 JULY 1984 KELLY BUSHING ~bEVATION: ENGINEER: RATHERT 68,7.0 FT iNTERPOLATED VALUES FOR EVEN 1000 FEET OF mEASURED DEPI TRUE SUB-SEA COURSE MEAGURFD VFRTICAI. VERTTCAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGbEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOOTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0,00 0,00 -68,70 0 0 1000.00 999,98 931.P8 0 34 2000 O0 1999,96 193~,~6 0 34 3000 O0 ~998,~1 2929,gl 8 13 4000 O0 3935,87 3~67,17 ~9 2 5000 O0 4706,31 4637,61 44 21 6000 O0 5375,39 5306,69 49 16 7000 O0 6033.19 5964 49 48 7 8000 O0 673~.55 6667~85 44 7 9000 O0 7389,03 7320'33 55 0 N 0 0 E 0.00 S 47 6 E -5,a3 S 58 49 E -4,58 N 0 18 E 18,26 N 15 51 E 344.38 N 18 54 E 943,09 N 16 2 E 1651,~8 N 12 1E 238],43 N ~5 13 E 3070,03 N 33 48 E 3757,96 0.00 0,3~ 0,28 4,09 3,83 1,46 0,32 0,72 0,88 0,89 0,00 N 0,00 E 0,00 5,43 S 2,23 g 5,~7 4,58 S 6,59 E 8,03 $ 55 13 E 18,26 g N 24 50 E 8 45 E 20,12 344 38 N 77:70 g ~53,04 N 12 42 g 943 09 N 283,05 ~ 984,65 1651 28 N 506,27 E 1727,14 N 2381 43 N 690,14 E ~479,4! a 16 9 E 3070 03 N 860.26 E 3188.28 N 15 39 3757,96 N 1156,30 E 3931,83 1.0000,00 7920,10 7R51..40 55 0 11000.00 R55b.b6 8487.96 45 55 11960.00 g205.42 9136,72 48 42 N 34 57 E ~455,56 N 42 58 E 5079.89 N 51 33 E 5532,25 1,05 1,43 0.00 4455,56 N 163b,42 E 474b,56 N 20 10 E 5079,89 N 2085,82 E 5491,45 N 22 19 E 5532,25 N 2628,53 E 6124,94 N 25 24 E COMPUTATION D~: 30 JULY 198,4 SOHIO ALASKA PgTROLEU~ $-15 (32-26-12-12) PRUOHOE NORTH SLOPE, ALASKA DAT~ OF SURVE~I 4 dULY 1984 KELLY BUSHING ~EVATZONI ENGINEER; RATHERT INTERPOLATED VALUMS FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE ~EASUREO VFRTICAL VERI?CAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MTN DEG MIR 0,00 0.00 'bS.?O 0 0 N 0 0 E 68 70 68,70 0,00 0 0 S 23 12 E 168~?0 168,70 100,00 0 0 S ? 35 W 26~,70 268,'70 200,00 0 ~ S ].8 5 W 368.71 368,70 300.00 0 34 S 14 4 W 468.70 468,70 400,00 0 34 S 18 25 E 568,71 568.70 500.00 0 34 S 11 54 E 668,71 668.70 600,00 0 34 S ~2 35 E 768,71 768,70 700.00 0 34 $ 36 14 E 868,72 868.70 ~00,00 0 34 S 56 39 E 968 72 968 70 900,00 load:vD looo.oo 116 72 1168.'70 1100.00 1268 73 ~268,70 1~00 O0 1368 72 1368,70 1300:00 1468 73 1468.70 1400'00 156~ 73 1568,70 1500 O0 1668 73 1668,70 1600 O0 1768 73 1768,70 170~ O0 ~868 74 1868.70 1800 O0 0 34 $ 47 48 E 0 0 S 71 43 E 0 0 N 39 12 E 0 0 N 52 7 E 0 34 N 42 10 E 0 34 N 4412 E 0 0 ~57 57 E 7 E 0 34 S 84 53 E 0 34 S 70 58 E 1.968 2068 68 21 2468 2568 69 '0 73 1968 I 1900~,00 0 34 74 2068 226~. 2468 2568 26 68 2768 2 2B68 $ 62 13 ~ 70 2000 70 2100, lo 2 oo 70 2400 70 2SO0 '10 2600 70 7oo 70 2800 O0 0 0 $ 40 16 E O0 0 34 S 21 1.9 W O0 0 0 S 18 46 w ~ 9 O0 0 0 $ 42 2: W 00 0 0 S 47 34 w .00 0 0 $ 0 1:0 E o S 79 37 W 5 : N 7:26:~ 43 {~] 6 45 E 2969, 30711 3 76, 3593 ' 2 370.~ 3~1~ 3923 79 2968, 09 3068, 4.4 3368 18 34168 31 3568 36 3668 54 3768 82 3868 70 70 2OO 70 3300 70 3400 70 3500 70 38 68,70 FT VERTICAb DOGbEG RECTANGUbAR COORDINATES HORXZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 F~,~I FEET FEET DEG MIN 0,00 0,00 0,00 N 0,00 '0,21 0,57 O 21 S 0,24 -0.53 0,08 0~53 S 0.17 '0,98 0,13 0,98 S 0,06 '1,54 0,33 1.54 S 0,09 -2.08 0,07 2,08 $ 0,04 -2,70 0,08 2.70 $ 0.22 '3,39 0,26 3,39 S 0,32 '4,08 0 32 4,08 S 0,64 '4,72 0~!3 4,72 S 1,38 '5,31 '5,63 '5,53 '5.29 -4 94 '4 54 '4 22 '4 06 -4 02 '4 18 0,00 N 0 0 E U,31 S 48 43 E 0,56 $ 17 45 E 0,98 $ 3 48 E 1,54 $ 3 26 ~ 2,08 5 1 6 E 2.71 S 4 36 E 3,40 $ 5 18 F ~. 2 $ 16 15 -4 46 -4 83 -5 51 -6 16 -6 54 '6 85 '7,08 27 0,20 5,31 S 2,08 0,70 5,63 S 2,42 0,17 5,53 S 2,56 0.06 5 29 S 2,86 0,08 4:94 S 3,2a 0.21 4.54 S 3,60 0,10 4,22 S 3,88 0,15 4,06 S 4,27 0,18 4,02 S 4,91. 0,11 4,18 S 5~64 E 14 E 30 E 5O E 75 00 1'1 45 N E 104 ~00 ~0~ 3' 1:1:4:7 ~: I37 00 22 20 ~ 12 36 E 175 241~ 217. 0 25 1 N ].4 19 E 262. 309 0 ,21 0 5 0 10 ~ 46 S 4 83 S 5515 6 16 S a 54 s *'i, 85 S ,08 S 2, g SN 6 39 E 6 94 E 6 81 E 6~42 E ~ 63 E .49 E 6 7,79 5 55 5 g 8,45 S 55 8 E 8,76 S 51 2 g 8,90 5 46 8 E ,99 $ 43 18 E i,01 S 40 27 E ,10 N $0 [ ,13 ,08 6 32 74 6,3 04 67 24 14, 104. 1371 175, 217 262 309 ' 1 ' ' " T CC, MPUTA¥ION DA g-' 30 JULY 1984 PAGE 7 SOHIO ALASK~ PETRO[,E!JN CO, PRUDHOE NORTH SLOPE, ~LASKA DATE OF SURVEY: 4 JULY 1984 KBLLY BUSHING ELEVATION) ENGINEER: RATHERT INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZiMUT~ DEPTH D~PTH DEPTH DEG MIN DEG ~IN 4037.86 3965.70 3900.00 3022 4155,60 4068,70 4000.00 3339 4~78.28 4~68.70 4100.00 ~717 440612 4268,70 4200.00 3954 453935 4368.70 4300.00 42 7 467471 4468.70 4400,00 4223 481056 4568.70 4500.00 4243 494773 466870 4600.00 4.332 508769 4768:70 4700.00 4515 523~:84 486~.701 4800,00 4624 68.70 FT VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WES%~ D1ST, AZIMUTH FEET DE~/IO0 FEET FEET FEET DEG MiN 5378 P7 4968 70 490~,00 47 33 5528:43 5068:70 500~,00 4912 568156 5168,70 5~00.00 4916 583559 5268'70 5200,00 4916 598969 536~.70 5300,00 4916 6~4384 5468.70 5400.00 4916 629751 556~.70 5500,00 4916 644996 5668.70 5600,00 4842 ~60~ 35 5768,70 5700,00 4842 675~ 51 586~,70 5800.00 4842 N 1636 E 362.47 N 17 45 E 421,84 ~ lB 54 E 489225 N 1928 E 564,44 N ~928 E 647.35 N 19 28 E 733.44 N 19 28 E 820.20 N 1.9 28 E 908.78 6903, 7053, 7202. 7493 7630 7768 7905 8044 8182 N 1854 E 1001.41 N 1820 E 1099,77 N ~.7 45 E 1201 40 N 17 45 E 1308 11 N ~b 36 ~ I418 94 N 16 36 E 1531 20 N 15 2 E 1643 74 N 1528 E 1756.54 N 14 53 E 1~69.03 N 14 19 E 1980,28 N 1345 E 2090,51 N ~3 6 E 2~00,81 23, 98 6168 70 610~00 48 7 N 10 53 M 25.29 82 6268 70 6~00,00 46 53 ~ ~0 58 E 2637 02 6368:70 6300,004332 N ).6 0 :E 2734 68 6468 70 6400 O0 43 32 N 16 2 E 2825 97 666~ O0 43 32 N 1,5 28 E 3007 68 6768 00::144 7 N 1:4:53 E 3099 91 6868 71 6800 01 42 58 N 19 18 E 3191 53 ;168.70 7100 57 268'70 '720]0 59 7368,70 7300 39 7468'707400 2 7568, 0 5 0 ~7 7668. 2,59 3.53 2.58 2,86 0 89 0,55 0,97 1,46 2.17 0.78 879.. 8gb~~ 914 .333 53'3 972~ 990 1,22 0,60 1 O3 0~49 0.40 0.54 0,7R 0.75 0,~9 O. 6 82 0 30 0 5:7 o 87 3 62 0 47 0 02 0 30 0 99 ~, 362 47 N 421 489 564 647 733 820 908 1001 1099 83.01E 371 ~6 N 1253 E 84 N 101,26 E 433:83 N 1329 E 25 N 123.69 E 504'65, N ~411E 44 N 149,88 E 584,00 N ~452 E 35 N 179.43 E 671,75 N 1529 E 44 N 20961E 762.80 h 1556 E ~0 N 24010 E 85462 N 16 ~8 t 8 N 27115 E 948:37 N 1636 E 41N 30295 E X046,23 N ~649 ? 77 g 336 !8 ~ ~150,0! N 1659 ( ,0!~ 4~ 0 ~ lS ~4 f 3281.34 2 0 ,0:057 t3 :~ 3 K 3t 0 00 60 0 ~ 3. E 3! 2 1 193 ,, 80 1201 40 N 369 53 El 1256 94 N 17 5 E 153~ 20 N 471 23 E 1602 , 96 7 E 2O68 1980 28 N 2090,51N 624,41E 2181 95 N 17 8 g 91 N 17 8 E 07 N 17 6 E I09 ~ 17 2 E N 16 ~8 E E 1 N 16 77 N 95 ~ 1662~7 E8 m 55 35 6'3 16 92 S2 62 64 2310 2420 ,529 25 2916 3007 19 ~7 N 720, ~ , 1~ 53 E .. ,86 N I 40 E 62 , 764;29 E 2839 41 N 15 36 E .79o,vo . ss z 30 M 642,91 E 3123.19 N ~5 39 E 20 N 896.29 E 3314.68 t~ I 41 ,67 45 95 48 81 25 .3281 3 382 498 3619 3733 44133 268 4393 ,34 N 927 ,2:1 N 1962 45 N 1004 51 N 80 N 1,593, 54 E 3609 40:iE 35~6 73 E 36~9 86E3772 07 E 3904 5:0 :~: 4044 56 E 4201 97E 4368, 35 E 4525~ 0':8 E4673 L'~ ~ lmllil ,I:41! [~1 C[]MPUTA?ION DATE: 30 JULY 198.4. PRUDHO~ ~¥ NORTH SI.OPE, ALASKA DAT~ OF SURVEY: 4 JUI.l 19B4 ~LLY BUSHING ELEVATION: ENGINEER: RATH~RT INTF. RPObATED VALUES FOR EVEN ~00 FEET OF SUB-SEA DEPTH 68.70 TRUE SUB-SEA COURSE MEASURED ¥~RTICAL VERTICAL DEVIATION AZIMUTH DEPT~ DEPTH DEPTH DEG SIN DEG SIN 10084,38 7968.70 7900.00 54 25 10252,71 8068.70 800o,00 52 42 10414.13 8168,70 8100.00 50 25 10570,62 826~,70 U200.O0 49 50 10724.01 ~368,70 8300,00 48 42 10873.62 8468.70 b400,OO 46 3~ '11017,37 8568.70 8500.00 4b 24 11163,{7 ~668.70 8600.00 46 24 11309.04 8768,70 8700,00 46 24 11455.33 856~,70 8800.00 47 31] VERTICAL DOGLEG RECTANGULAR COORDINATES 80RIg, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/100 FEET FEET FEET DEG ~IN N 34 57 E 4512,00 N 34 57 E 4622.~6 N 34 57 E 4726.78 N 34 22 E ~825.61 N 34 57 E 4921,19 N 3~ 6 E 5011.59 N 43 0 g 5089 08 N 46 14 ~ 5164~49 N 50 17 E 5~35.43 N 52 A E 5301.41 1,32 0,57 0.85 0,42 0.94 ~,51 2,01 1,74 2,44 1,42 3,22 0,00 o;oo 4512,00 N 1676,06 E 4813,24 ~ 20 22 E 4622 86 N 1753,8! E 4944 36 N 20 46 E 4726 78 N 1826.27 E 5067 4825 61N 1895,00 E 5184 4921 19 N 1961,26 E 5297 501.1 59 N 2026.12 E 5405 5089 08 N 2094,33 E 5503 18 N 22 22 £ 5164,49 N 2168,96 ~ 5601 5235'43 N 2247 95 E 5697 5301,41 N 2331189 E 5'791 32 N 21 7 g 35 1~ 21 26 E 61 N 21 43 E 66 lq 29- 0 E 46 N 22 46 f: 63 N 23 14 bO N 23 44 ~ 5368,10 N 2418,56 E 5887.77 a 24 15 E 5435,93 N 2506,b2 E 5986,02 N 24 45 g 5506,26 N' 2595,79 E 6087,45 N 25 14 E 5532,25 N 2628,53 E 6124,94 N 25 24 g 1160~.52 8968,70 ~900.00 47 33 1175104 9068,70 9000,00 48 7 11904 36 9~68,70 9100.00 48 42 11960 O0 9205.42 9136,72 48 42 N 52 42' E 5368 10 N 52 8 E 5435193 N 51 33 E .5506,26 N 51 33 E 5532.25 GREAT LAND DIRECTIONAL DRILLING INC. REPO. RT OF SUB-SURFACE DIRECTIONAL SURVEY SOHIO COMPANY S-15 WELL NAME PRUDHOE BAY~ ALASKA LOCATION AL584D9 SINGLE SHOT 6-12-84 JOB NUMBER TYPE SURVEY_ /I DON MASON ENGINEE.R ~_ NAME TITLE .--.-- .~ DATE ~GNAI'URE 11320 DEPTH INTERNAL FROM TO 5-23-84 6-9-84 DATES SURVEY TAKEN FROM CONFIDENTIA[ THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our files for your convenience; however, should you so desire, all copies of the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confi- dence. Additional copies of your survey report can be made from the original by any blueprint company. RECEIVED AUG 0 ~ 1984 Alaska Oil & Gas Cons. Commission Anchorage GREATLAND DIRECTIONAL DRILLING' COMPLETION REPORT :OMPU'FED ON 6-12-84 USING RADIUS OF CURVATURE TECHNIQUE :ROM SURVEY DATA TAKEN :INAL CLOSURE DIRECTION N 27.50 E ;1NGL. E SHOT SURVEY RECORD OF SURVEY IWELL ASSUMED VERTICAL TO 2508. SOH I 0 SOHIO S-15 lEAS DRIF:'F 'rRUVERT SUBSEA SECTION DIRECT]ON }EP'rlI DG MN DEPI'H DEPTH DIST ANGLE REt.AI'IVE COORDINATES FROM WELI..-FIEAD 0 0 0 0.00 -68.74 0.00 0.00 0.00 0 0 2508.00 2439.26 0.00 0.00 0.00 1 0 7:.:%'70 99 c. 602 . .c_o 1.36 N 10.83 E 1.40 N 3 12 2733.9'5 2665.2:1. 3. U3 N 4.7'7 E 3. (58 N 4 42 2795.80 2!727.06 7.55 N :1.0.50 L: 7.91 N 45 0 2856.53 2787.79 12.92 N (5.00 E 13.54 N 7 30 29'50,87 2882, :1:1.3 23,28 N 5,25 E 24,65 N P 42 30#0.84 29'72.10 35.99' N 8.00 E 38.17 N .12 0 313:1..19' 3062.45 52.33 N 8.25 E 55.3:1. N 13 45 3222.82 3154.08 72.25 N .1.0.75 E ?5.9'? N 16 13 3314.59 3245.85 9'5.82 N 11.68 E :1.00.04 N 1? 25 3#32.42 33/;3.88 132.47 N 13.42 E 137.08 N 23 0 3578.9'7 3510,23 187.71 N 14.75 E 192.14 N 25 0 3?48.88 3680.14 261.80 N 17.00 E 264.9'2 N 2? #5 3887.73 3818.9'9 329.43 N 18.25 E 330.54 N 33 23 4047.82 3979.08 423.04 N 18.95 E #20.15 N 38 26 41~4.80 4128.06 S29'.9'8 N 21.00 E S21.54 N 40 30 42?8.43 #209.89' 597.01 N 22.42 E 584. ].3 N 42 35 4#59.00 4390.24 754.0:]. N 21.00 E 732.60 N #3 22 #5~3.42 4524.88 880.d2 N 20.93 E 8#~.73 N 45 30 4774.41 #?07.4? 1058.47 N 21.00 E 1017.07 N 48 3 4988.02 #919'. 28 1282.00 N 17.50 E 1228.29 N 49 23 5220.9'2 5152.18 1544.10 N 17.83 E 1479'. 59' N 4~ 40 5524.05 5455.31 1895.56 N 20.51 E 1815.10 N 48 44 582~.85 5761.J,J, 2245.14 N 16.00 E 2151.44 N 48 41 6039.04 5970.30 2477.89 N 14.50 E 2381.24 N 48 13 4197.56 4128.82 2651,55 N 12.80 E 2555.05 N #3 11 6397.24 6328.50 2852.17 N 19.86 E 2751.29 N 2L;08 247 :t 2734 2'796 2857 2952 3043 3135 3229 3324 3#48 3oO5 3791 3946 4132 4422 466~J 4847 5103 5412 8232 6700 7017 7256 75~2 0.00 0.00 0.27 E 0.58 E 1.15 E ~.. 9'6 E 3.06 E 4.63 E 7.08 E 10.53 E 15.31. E 23.55 E 37.37 E 58.06 E 78.91 E 109'. 07 E 145.92 E :1.70.84 E 229.9'5 E 274.83 E 338.9'5 E 416.87 E 501.76 E 618.40 E 729.35 E 792, O0 E 834.20 E 891.70 E CLOSURE D1S'FANCE DG MN S 0.00 0 0 0 0.00 1,42 3.73 8.00 13.68 24.84 38.45 55.76 76.49' 101.22 139.09 195.76 271.21 339.83 434,08 541.56 608.60 767.84 893.07 1072.07 1297.11 1562.35 19'17.56 2271.72 2509.50 2687.78 2892.18 0 0 0 N 10 49 48 E N 8 57 20 E N 815 2E N 815 1E N 7 4 34 E N 6 54 47 E N 7 17 22 E N 7 53 34 E N 841SSE N 9 44 S3E N 11 0 18E N 12 2~]. 43 E N 13 25 36 E N 14 33 8 E N 1S 37 51E N 16 18 9 E N 17 25 35 E N t? 55 23 E N 18 25 53 E N 18 44 49 E N 18 43 59 E N 18 48 SO E N 18 43 36 E N 18 23 49 E N 18 4 53 E N 17 57 28 E DOG LEG deg/4?O_ 0.000 0.000 0.6~.3 3. 492 2.420 2. 133 1. 579 2.419 2.500 1. 868 2. 598 2. 585 2. 288 1. 097 3;031 2. 778 2.030 0.906 O. 426 O. 833 O. 868 O. 466 O. 339 O. 580 0.247 0.441 2. 106 t-I10 S- 15 6-~2-84 ., RECORD OF SURVEY EAS DRIFT EPTI'I DG MN 7~7 43 30 8353 46 0 8446 48 224 8542 51 12 8635 53 !54 882 ~ 53 42 9008 ~5 ~8 9190 t5'7 0 9464 60 0 9702 t','r 42 9918 ~6 ]2 0297 ~2 18 06~6 49 ~4 0960 46 42 .~212 43 6 1320 ~1 3~ TP, UVERT SUBSEA SECTION DIRECTION RELATIVE COORDINATES DEPTH DEPTH D1SI ANGLE FROM WELL-HEAD 66.9.l.79 8623.05 3.1.27.28 N 18.70 E 3013.87 N 983.#8 E 6980.10 6911.36 3410.5G 'N ;-!1.10 E .?_1282.39 N 1080.'76 E 7043.28 69'/'~.54 3478.28 N 20.00 E 3346.28 N 11.04.71 E 7.1.05.2'.4 7036.50 3551.0.1. N 20.50 E 3~t.1.5.06 N 1130.08 E 71.61.79 7093.05 362#.36 N 21.50 E 3483.98 N 1.1.56.54 E 727.1.64 7202.90 3774.:1.6 N 33.90 E 3616.62 N 1226.17 E ,-, ..,:192~:; . . . 7380.,:.,3 7311,49 ......... 48 N 321 70 L7 ::J743 12 N 1310 845 E 7481.60 '74.1.2.86 4075.~6 N 35.50 E 3887.53 N 13,96.69 E 7624.7,% 7556.0.l 4306.89 N 35. :tO E #058.17 N 153J.67 E ?74?,85 7679.1.1. 4508.2.'9 N 3?.00 E ~222.84 N 1851.52 E 7865.6,ri; 7796.9.1. 4686.85 N 3?. O0 E 4367.42 N 1760.48 E 8087.0~+ 8018.30 4990.3# N 36.60 E 4613.67 N 19'44.69 E 8299.90 823J.18 5251.00 N 36.10 E #826.1# N 2101.08 E 8515.41 8446.87 5489.5,9 N 3?.80 E 5019'.43 N 2248.45 E 8693.88 8625.14 5664.52 N 38.00 E 5.1,59.77 N 2355.70 E 8?73.69 8704.95 5?36.04 N 38.10 E 52.1.7.06 N 2400.54 E CLOSURE DISTANCE DG f4N S 3170.08 N 18 4 25 E 3455.74 N 18 13 29 E 3523.91 N ~8 16 11 E 3597.~8 N 18 18 345 E 3670.921 N 18 21 51 E 3818.822 N 1,8 43 43 3966.02! N 19' 18 2 E 41712.00 N 19 51 2..2 E 4337.60 N 20 40 ~,~. E 4534.30 N 21 2J. 37 E 4708.89 N 21 57 15 E 5006.7'7 N 22 51 21 F 5263.66 N P3 3:1. 321 5499.21 N 24 6 39 E 5672.09 N 24 32 21 E 5742..85 N 2~ 42 3:1. E DOG LEG deg/J 0 0 O. 157 0. 688 22. 664 4.3B~ O. 859 1. 165 I. J. O0 1.1.22 O. 65,'4 1.03J, 0.7J3 1. 026 1. 429 1. 389 ~HIO S- 15 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPI'H 6-12-8# lEAS. ~EP'Ftl 0 100 20O 300 qO0 UO0 800 7O0 80O .90O 1000 1100 1200 1300 1400 1500 ldO0 1700 1800 2O0O 2100 2200 23OO 2400 2500 2600 2700 2800 2901 3002 3103 3206 3309 341# TRU VERT DEPTH 0 100 2O0 3O0 l~O0 5OO 60O 7O0 800 9O0 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 31~00 SUB SEA MD-TVD DEPTH O 1 FF. VERT ] CAL CORRECT RELAT]VE COORDINATES FROM WELL-HEAD -69 0 0 O. O0 O, O0 31 0 0 0,00 0.00 13:1, 0 0 0.00 0.00 231 0 0 O. O0 O. O0 331 0 0 O. O0 O. O0 43:1. 0 0 O. O0 O. O0 531 0 0 O. O0 O. O0 631 0 0 O. O0 O. O0 73.1 0 0 O. O0 O. O0 83:1. 0 0 O. O0 O. O0 9'31 0 0 O. O0 O. O0 '1.033. 0 0 0.00 0.00 113:1. 0 0 O. O0 O. O0 123:1, 0 0 O. O0 O. O0 1331 0 0 O. O0 O. O0 1#31 0 0 O. O0 O. O0 1531 0 0 O. O0 O. O0 1631 0 0 O. O0 O. O0 1731 0 0 O. O0 O. O0 183~. 0 0 O. O0 O. O0 _1.93 ~. 0 0 O. O0 O. O0 2031 0 0 0.00 0.00 2133. 0 0 O. O0 O. O0 223J. 0 0 O. O0 O. O0 2331 0 0 O. O0 O. O0 2431 0 0 O. O0 O. O0 2531 0 0 0.#5 N 0.05 W 2631 0 0 2.15 N 0.39 E 2731 0 0 8.26 N 1.21 E 2831 1 1 18.35 N 2.45 E 2931 2 1 31.63 N 3.61 E 3031 3 1 48.99 N 6.13 E 313_1. 6 3 70.65 N 9.04 E 3231 9 3 96.03 N 14.20 E 3332. 14 5 126,35 N 20.44 E HIO S- 15 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 6-12-84 EAS. TRU VERT SUB SEA MD-'FVD VERTICAL. EP'r FI DEP'F H DE P'F [.I 01 FF. CORRECT 3520 3628 3737 3848 3960 4076 4196 4320 4451 4584 4719 4856 4996 5137 5283 543o 55822 5733 588'7 6o41 6195 6348 6501 6654 6806 6958 7109 7259 7403 7546 7683 7821 7959 8099 8240 3500 3431 20 6 3600 3531 28 8 3700 363J. 37 3800 3731 48 '3900 3831 60 12 4000 3931 76 16 4JO0 403~ 96 20 4200 413J. ~2!0 24 4300 4231 151 3~. 4400 4331 184 33 4500 443J 219 35 4600 4531 256 37 4700 463J. 296 40 4800 4731 337 41 4900 4831 383 46 5000 493J. 430 47 5100 5031 482 52 5200 513J. 533 5300 5231 587 54 5400 S331 641 54 5500 5431 695 54 5600 5531 748 53 5700 5631 801 53 5800 5731 854 53 5900 5831 906 52 6000 5931 958 52 6100 6031 1009 6200 6131 1059 50 6300 6231 1103 44 6400 6331 1146 43 6500 6431 1183 37 6600 6531 1221 38 6700 6631 1259 38 6800 6731 1299 40 6900 6831 1340 4J. RELATIVE COORDINATES FROM WELL-HEAD 161.44 N 29.22 E 200.91N 39.65 E 243.87 N 50.21E 288.45 N 65.15 E 336.89 N 81.00 E 39'2.04 N 98.90 E 454.54 N 120.63 E 523.94 N :1,46.84 E 601.33 N J77.90 E 6821.21N 210.75 E 768.09 N 243.57 E 855.46 N 277.02 U 946.38 N 3J. 1.76 E 1040.08 N 347.74 E 1J39.12 N 384.73 E 12#1.03 N 421.38 E 13#8.17 N 458.38 E 1456.71N 494.37 E 1567.85 N 529.56 E 1680.06 N 563.20 E 1792.94 N 595.16 E 1898.24 N 648.58 E 2008.14 N 685.68 E 2118.46 N 719.76 E 2228.35 N 751.03 E 2338.25 N 780.77 E 2448.08 N 808.88 E 2557.59 N 834.78 U 2660.23 N 854.63 E 2753.73 N 892.58 E 2842.44 N 724.26 E 2931.54 N 955.39 E 3021.21N 986.03 E 3114.14 N 1016.61E 3208.95 N 104&.31E H10 S-15 DATA ]NTERPOLATED F'OR EVEN 100 FEET OF SUBSEA DEPTH 6-12-8# lEAS. TRU VERT SUB SEA MD-TVD VERTICAL 'EP'[' H DEP T H DEP T H D 1 F F. CORRECT 8382 7000 8931 1382 8534 7100 7031 :[434 8700 7200 7133. 1500 8870 7300 7231 1570 9044 7400 7331 1644 9225 7500 7433. 1725 9417 7600 753~ 1817 9609 7700 763J. 1909 9798 7800 7733. 1998 9977 7900 7831 2077 10148 8000 7933. 2148 10318 8100 8033. 22!3.8 10477 8200 8131 2277 10636 8300 8231 2336 10786 8400 8331 2386 ~0937 8500 8431 2437 11079 8600 853:[ 2479 11220 8700 8631 2520 42 52 66 70 74 P2 P2 8~ 79 70 50 42 41 RELATIVE COORDINATES FROM WELL-HEAD 3302.3.9 N 3409.33 N 3533.28 N 3649.38 N 3767.50 N 3891.63 N 4024.71N 4161.24 N 4287.15 N 4406.33 N 4518.~5 N 4626.7? N 4727.15 N 4826.23 N 493.8.59 N 5009.73 N 5087.]9 N 5164.23 N 1088.33 E 1127.37 E 1173.85 E 1248.17 E 1327.01E 1413.86 E 1508.3.2 E 1602.56 E 1699.99 E 1789.76 E 1873.56 U 1954.42 E 2028.56 E 2103.. 3.2 E 2167.50 E 2231.3.0 E 2298.92 E 2359.18 E HIO S- 15 DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH 6-::1.2-84 MEAS. TRU VERT SUB SEA DEPTI.-I DEPTH DEPTt. I 100 20O 300 #00 50O 60O 700 800 .900 1000 1100 0 1000 933. 0 2000 1931 0 23998 29229 0 3935 3866 0 470# #635 0 5374 5305 0 6028 5959 0 6730 6661 0 7376 7307 0 79:1.2 7841.3 0 85#3 8474 RELATIVE COORD] NATES [:ROM WELL-HEAD 0.00 0.00 0.00 0.00 31.38 N 3.59 E 355.08 N 86.95 E 9#9.02 N 31.2.76 E .1.650.22 N 554-.4# E 2!368.88 N 788.79 E 30#8.36 N 995.1.2.. E 3737.65 N 1307.21 E 4421.60 N 1.80:)..2!4 E 5042.3,?.4 N 2264.20 E Notcs: All values in feet. Depths shown ar~ TVD. Closgp¢: 5743 ft ~t a 24 d~g 4~ mi;~ E Bottom ho]e: TVD 8774 TMD ~13E0 HORIZONTAL VIEW SOHIO SOHIO S-15 RADIUS OF CURVATURE SINGLE SHOT SURVEY. SCALE' 1 inch = 1000 feet DRAWN ' i ~ i i I I I ,'t iII j 1 Ift x iooo } VERTICAL SECTION 0.75 i.50 2.25 3.00 3.75 4.50 6.00 6.75 7.50 9.00 9.75 i0.50 ii.25 i2.00 t2.75 i3.50 ., SOHIO SOHIO S-15 RADIUS OF CURVATURE SINGLE SHOT SURVEY , , . SCALE: ! inch = 1500 feet DRAWN: 6-12-B4 , · , .. " IVD gl!14 TMD ~ ~1~20 = · . _ .. · . -0.75 0 0.75 i.50 2.25 3.00 3.75 4.50 5.25 6.00 6.75 7.50 B.25 S UB-S URFA CE DIRECTIONAL SURVEY r-~ UIDANCE ~-~ONTINUOUS r-~ OOL Company Well Name Field/Location SOHIO ALASKA PETROLEUM COHPANY S-15 (32-26-12-12) PRUDHOE BAY - NORTH 5LOPE. ALASKA Job Reference No. 69336 Logged By: RATHERT RECEIVED AUG 0 Alaska 0il & Gas Cons. Commission Anchorage Date JULY 4, 1984 Computed By: RI CK KRUWELL SCHLUMBERGER SOHIO RLRSKR PETROLEUM COMPRNY S-I,~ (:92-2~6-12-12) PRUDHOE BRY NORTH SLOPE. RLRSKR JULY 4, 1984 TVW PLOT FROM OCT DRTR JOB REFERENCE 693@S WELL: S-15 (32-26-12-.2) SURFACE LOCATION' 1984 SNL & 716 EWL VERTICAL PROJECTION ~OUTH PROdECTION ON VERTICAL PLANE OF AZIMUTH 0 SCi:LED IN VERTICi:L DEPTHS HORIZ SCALE : 1/1000 IN/FT 6000 ' NORTH ......................................... .... ' ' : [ ! i ! ! ! !- - i ! ] ! [ ! i [ ! ] ~ ! 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I I I I ! i i.L! :! ! i i.: l. liii iiii iii! iili iltl Iltt .'_: -.'~,' ::'-: ....... .... i iJl ::*...i :T":...-".."-FFI... :I '"'~'."*'"~.---~..--m~..-,-~-?-v-: .... :-.*-?-.? ,, :.l.. ;: ': : ': ::: ~' :: -J-J."-44-.: ::i==i: : :m--'r-~.. t : ..:: .: =:::..*-~ :. .... [ i j i : : : [ ! -'.' -'.' :--.i-~--4-.4-4-., ..-.~4..4-....-~...~.-,-, ;..4...:..., ........ .i--,- .... +.-+.-+ ...... -4 : -'. ! ! : ] ] [ ~ : ."- :' : -' : '-' ' ' ' ' ..... ~':T ?T'T~'--T-:-t: ......F~-? : I : : .... : : : : ~ : : : [ i [ i i i i i [ i i [ [ i [ i [ i i i i i i ! i il i : i i i i i4 i: .-b.-b~--4--4-~-~ ~ i'-.-'T"-¢'i-?-l-: ' H-4.-i;-i-i-~--H ! : : : : : ! ! :: i i : ! -'. : ! :: -:~-t :j i t:i---L4-4 ! k-t. i i i :~ff~--t:4-t.'?'--t-.. f"fft-~-j-~'::- ~- .-: !.:- ~:J J: J ~ ~ ~ :~-4.:-.--'-:-~-b-.~-:-b-..~-,-.:.+---r.. +..:.-,.... +,.-:..-.. .... .,-.:.-.,-., i i i ! i ! : ! : :: ! I i i i; : ! ! ! ! } j i {: { :..' ~ j j...~-..4.-4.'.4..4' i..4..4--4 ..4-4...i..4-4-~.~- -zooo ,,::,:::: ::.:~ :::.: :,:: :::: ,,:, ,::: r-'H~'i-- -sooo -4ooo -~ooo -~mo - :mo o i ooo 2ooo NEST EA$? Suggested form to be inserted in each "Active" well folder to d'.eck for timely ccmpliance with our regulations. uperato~., Well Name and Numker Reports and Materials to be received by: ~ .-~ LTL Date Required Date Received _Remarks Ccmpletion Report .Yes _~- ,, ,. Core mscrip~on Inclina~n S~ey ,, P . . . Drill St~ Test Re. ms ~~~_ , ., , , ~~0n T~t Re~rts ~ ~~ ~s R~ · ~ ~ ~;:~ :' ~? ~~f~ ;Y es :/~'~~~' "'-''~' ~'::""'~ ~ ~/~ Digitiz~ ~ta '' Y ~ - , , INDEXED SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TO: SFO/UNIT/ GETTY STATE: MARATHON MOB IL PHILLIPS * STATE OF AK BPAE (Transmittal Only) REFERENc~:ENT]~kL FILES (CC#' s-Transmittal Only) 31 I 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 7/11/84 CC#: 75511 * Date to State Via Drilling: 8/02/84 SOHIO OPEN HOLE FINAL LOG___~S ollowing material is being submitted herewith. Please acknowledge receipt by signing a of this letter and returning it to this office:-- SFO/UNIT/STATE: S-15 S-15 DIL/SFL 6-11-84 #1 2509-8880 Sch 5" & 2" 6-29-84 #2 8650-11950 Sch 5" & 2" ~HCS/GR 6-29r84 #2 10831-11918 Sch 5" & 2" STATE ONLY: DIRECTIONAL SURVEYS: Magnetic Single Shot Directional Survey Gyroscopic Directional Survey Date: 6/12/84 Date: 7/04/84 Job#: AL584D9 Job#: 69336 RECEIVED DATE ~ ~,- ~' !% I I'1~ Carolyn Bishop .~ . ~ ~ ~ ~V ~~Development Geology /I / ~/~ /Y'. ~ / ~ ~ __ _ ._ ~ / //I/ · ~/~ ~ ~ %/~eil ~ecor~s Al~ka Oil & Gas ~ns. Commission Anchorage ~ SOHIO ALASKA PETROLEUM COMPANY SFO ARCO EXXON TO~ PHILLIPS :~- STATE 0 ~.AK:: CENTRAL FILES (CC#' s-Transmittal Only 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 7-20-84 Da t e: CC#: 75544 REFERENCE: ~..~he following material is being submitted herewith, acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: *H-14 C.H. TDT-Edit w/ Listing 5-11-84 *S-15 C.H. CNL w/ Listing 7-4-84 *U-6 C.H. CNL w/ Listing 6-29-84 Sch#69283 Sch#69345 Sch#69340 03059 03057 03058 *SFO & EXXON: An Asterisk~(*) next to a listing abo~e means you should have received the Tape(s) and Li~ting(s) ~eq~_~y. from the respective service company. Please confirm this. ~ !' "~[-'- RECEIVED .j [j['~ ~mv t~_Development Geology ' ~,,.~r.¢~ W~il. Records ~9 DATE ..... :~;3SXa Oil & Gas Corls. C0rrlrllls$i0rl Anchorage SOHIO ALASKA PETROLEUM COMPANY SFO ARCO EXXON IO~ PHILLIPS STATE OF AK CENTRAL FILES(CC#'s-Transmittal Only 3111 "C" STRE['I AN(' HOF-'.AC-.{ aL A!,k A TELEPHONE (907~ 265 MAIL: POUCH 6.612 ANCHORAGE. ALASKA 99,502 7-10-84 Date: 75510 CC#: REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- OPEN HOLE TAPES *S-15 - O.H. DiL/~,~C w/ Listing 6-29-84 #1,2 ' *X-27~ ~ O.H. DIL/BHC w/ Listing ' 7-9-84 X_,,tTzI O- I- I CASED' HOLE TAPES :'X-27 C.H./CNS w/ Listing 7-9-84 Tape Pos # ach ~69341 03050 Go JTN#,28Z~ 0304S GO JTN~281797 03049 (4/82) *SFO & EXXON: An Asterisk (*) next to a listing abo~e means you should have n~g(s¥,d.ir~c_tl¥ from the res s '~ ~[l~''' ..received the Tape(s) and Listi FD pective ervice company. Please confirm this.x~ _ ~-~ , RECEIVED tL~/~v~/~~~ m V//~_~ Carolyn Bishop JUL 1 Development Geology DAT~ ~9 ...... Well Records Alaska 0JJ & Gas Cons. O0mmiss]o. Anchorage SOHIO ALASKA PETROLEUM COMPANY June 20, 1984 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: ~. C. V. Chatterton Gentlemen: Well S-15 (32-26-12-12) PBU Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This report contains our subsequent report of plugging back the 8 1/2" hole on Well S-15. This report also confirms our intent to mill a section in the 9 5/8" casing and sidetract to the original BHL. Yours very truly, District Drilling Engineer RHR:TOS: ckg 61984 Enclosure cc: Well File 917 RECEIVED JUN 2 2 1984 Alaska 0il & Gas Cons. Commission Anchorage .... STATE OF ALASKA ~-.. ALASKA~ _ AND GAS CONSERVATION CC MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 COMPLETED WELL [] OTHER [] 4. Location of Well 1984' SNL, 716' EWL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 60 6. Lease Designation and Serial No. ADL 28257 7. Permit No. 84-71 8. APl Number 50- 029-2113 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-15 (32-26-12-12) PBU 12. 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or )ther Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ]~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The 8 1/2" hole of S-15 was plugged back by laying a 100 sk Class G cement plug from 11,315' M.D. to 11,109' M.D. The 9 5/8" casing was pressure tested to 3000 psi. A section will be milled in the 9 5/8" casing at 10,800" M.D. in order to sidetrack to the original BI~L. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~. The space below for Commission use ' lay below for Commission use 1/ 1~.. l~e~/ Conditions of Approval, if any: Approved by RECEIVED JUN 2 2 Alaska 011 & Gas Cons, Commission Anchorage Title District Drillinq Enqineer Date Approved 'Coot. Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 June 19, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: Well S-15 (32-26-12-12) PBU Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. As discussed in telephone conversation this day between Blair Wondzell and Ted Stagg, this report contains our proposal to plug back and abandon the 8 1/2" hole, mill a window in the 9 5/8" casing, and sidetrack to the original BHL. Yours very truly, RHR:TOS:ckg 61984 Enclosure cc: Well File #17 RECEIVED JUN 1 91984 Alaska Oil & Gas Co~. c~mmlsslon Ancb~ra~ ALASKA O~U.II. AND GAS CONSERVATION COM. MISSION SUNDRY IL _JTICES AND REPORT .)N WELLS 1. DRILLING WELL I~ COMPLETED WELL [] OTHER [] 2. Name of Operator Alaska Petroleum 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of Well 1984' SNL, 716', EWL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) 12. 6. Lease Designation and Serial No. ADL 28257 7. Permit No. 84-71 8. APl Number 50-029-21113 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S--15 (32--26--12--12) PBU 11. Field and Pool ~Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The 8 1/2" bole was drilled to 11519 MD (8925" TVD) after setting 9 5/8" casing at 11307' MD. A fish consisting of an 8 1/2'" bit, a roller r~, and one square drill collar is in the hole. The 8 1/2" hole will be aSandoned by laying a 100 sk cement plug from the top2of ffill at approximately 11330" MD to 100'- inside the 9 5/8" casing. The c6~aent plug will be tagged and the casing pressure tested. A section will be milled in the 9 5/8" casing at approximately 10600t MD and 8 1/2" hole directionally drilled to the original target. RECEIVED J U N 1 9 1984 Alaska O. '. 14. I here,~,~ertify th~at the~ing istrul~d correct to the best of my knowledge. (\ ( Signed _~. %~_._~.~ ~ The space 5elow for ~mmis~ u~ Conditions of ADprovab if any: Approwed Co~ ~' By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~o ~ 20 s-15 : (_Propos_ed) (P¢oposed) · l ...... 217 .......... 2'6 / ' o~1 / LAT. = 70°21'09.52' ....................... t / --LONe-' i4~o02'04.77". I I/ X: 618,885 Y=5~979,499 I ~ . S-17(ProP. osed) L:.J - ~ SCALE: 1"=I/2MILE _SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT ! AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A LOCATION SURVEY OF THE WELLPAD SHOWN AND THE WELLS THEREON. THIS SURVEY WAS MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. BOTTOM HOLE LOCATIONS ARE FURNISHED BY OTHERS. DATE ~A~' Il;ID~,' REGISTRATION NO. REGISTERED LAND Sb'~VEYOR ~ - PAD DETAIL SCALE:I :500 -- PLANT ADDED LOCATION DIMENSIONS FOR WELL S-15 RECEIVED JUN ! 4 t984 A/aska Oil & Gas Cons. Commiss Anchorage k~ 6/~ ~/$4 PAD "S" EXTENSION Located In PROTRACTED SECT. ~.0 NS 26!ZTt34,351Z. 8, .3~..T! ZN~TI I N,R 12E, UM Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by OCEAN TECHNOLOGY LTD. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights,Boulevard Anchoroge, Aloeko M EMORAN OUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Chai~ ~ ~?- Co~ss~o~e~ DATE: June 12, 1984 FILE NO: D. 4I. 24 TELEPHONE NO: FROM: Doug Amos ~ Petroleum Inspector SUBJECT: Witness the BOP Test on Sohio's S-15 Well, Sec. 35, T12N,R12E,UPM Permit No. 84-71 at Nabors Rig 1SE. Fr'iday, l~ay 25, 1984: I traveled this date from Parker Rig No. 141 to S~hio S S'15 w~ to witness the BOP test. The test co__m~_~enced at 12:00 am and was concluded at 3:00 am, May 26, 1984. There were no failures and I filled out an AOGCC BOP test report which is attached. In summary, I witnessed the successful BOP test at Sohio's S-15 well. Attachment -O&G 4/80 STATE oF ALASKA.'OIL' &:, GAs::CONsERVATION iCOMMIS SION - . - -B.O.. P.. E..jih'SPe. ct'ion Report ..................................... -- _.; .... : ...~.~--~.~-:¢ :. _- -.. .- .--.. . . ,- . ) . . ' j' ,'-:--': ;-:- ' ::-:-, '- :--<. <: --: F':.:.:. "'<~:?.~:-:..: ..... ~ · Inspector Drilling-~on'~a~to' ~cation, ~ner~ -- Well Si~ ':'.' ':/"--'.-'-~:""'--',/ ""-'%-' '":?'~:'-~ ':'~'-'"'":""'"': ............ " " F~'i ~'arg~:'~p~eSmre.:.'~ ~ a :~-.'.. ............ ', -." . .... .... ....:: /:'(----'¥-'-.":-. -:,: . · ~ . Gener~ Ho~ekeeping'' '.' ';- "~' :--' "'---,}~" ....... :-'~"<"- Pr'e:s~re'};:Af~ :cie-stire'' [ ~ D _ . _ :-._. -. . :-,.-~ ~-_ ---....:,~ Ci":~ ._..-i?."...~':%: . :...::~-..: . ._ - . . . - ',"' - R~Ote' .~ Blinds switch BOPE Stack. 'Test".Pres~re . .-Kelly r~ ~nular Preventer 'Pipe R~s .Blind Rms : ' ::-"' " ' "Bali TYPe" "( l:: [---''~est Pressure Choke Line v~ves~¢,m~ [~-~est Pres~re Kill Line Valves Check Valve Test Pressure 'H~dra~].Cal ly.i?OPe rated choke Test Results: Failures "- -' .... ~-:~ \-~:~' '"' ~ .... -:' Test'LT!~e::.:":' -.-~., . hrs... .- . ':,'~?~, :--~:: < ~ . . ......_. ::.:;:..... Repair or Replac~ent of-failed ~ipmen, t tO ~ ~de..-Within','.',_ , ~ .. . - Inspector/Commission office notified ' ~ _ Remarks: Distribution ....... orig-~ .... AO&GCC' - ..... cc - O~erator - cc - SUPervisor d~ys and May 15, 1984 Mr. R. H. Rei!ey District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Re: Prudhoe Bay Unit S-15 Sohio Alaska Petroleum Compamy Permit No. 84-7! Sur. Loc. 1984'SN~L, 716'EWL, Sec. 35, T12N, R12E, UPM. Btmho!e Loc. 1873'S~, !757'WEL, See. 26, T12N, R12E, UPM. Dear Mr. Rei!ey: Enclosed is the approved application for permit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the re..gulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Mr. R. H. Reiley Prudhoe Bay Unit S- 15 -2- May 15, 1984 equipment so that a representative of the Co._mmission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation ~o that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, C, V. Chatterton SY oRD=~R OF THE Chairman of Alaska Oil and Gas Conse~ation Co~ission be EnclosUre cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. SOHIO ALASKA PETROLEUM COMPANY 3111 "O" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 May 11, 1984 Alaska Oil & Gas Conservation Conmission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton WET,I,: S-15 '(32'26--12-12) PBU , Enclosed are the following documents, in triplicate, along with our check for $100 to cover the permit filing fee. 1. Application for Penuit to Drill; 2. Proposed drilling program outline; 3. Proposed Blc~out Prevention Diagram; 4. Surveyor's plat showing well location; 5. Directional map. If you have any questions, please call Ted Stagg at 564-5173. Yours very truly, R. H. Reiley District Drilling Engineer encs cc: Well File $17 RECEIVED MAY 1 11984 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA U,L AND GAS CONSERVATION CO,,,~vllSSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN 1 b. Type of well EXPLORATORY [] DEVELOPMENT OIL :~ DEVELOPMENT GAS [] 2. Name of operator Sohio Alaska Petroleum ~y 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 1984 ' SNL, 716 ' EWL, Sec. 35, T12N, R12E, UPM At top of proposed producing interval (Target) 2050' SNL, 1850' WEL, Sec. 26, T12N, R12E, UPM At total depth 1873' SNL, 1757' WRT,, Sec. 26, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF etc.) Est. KBE = 60' AMSL I 6 . Lease designation and serial no. ADL 28257 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. 2975387 13. Distance and direction from nearest town 14. Distance to nearest property or lease line NW of Deadhorse - 10 miles South of ADL 47448 - 2050 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 11783' MD - 9200' TVD feet 2560 - 19. If deviated (see 20AAC25.050) 47¢ 57 ! 120' Anticipated pressures KICK OFF POINT 2700 feet. MAXIMUM HOLE ANGLE I (see 20 AAC 25'035 (c) (2) 21 Proposed Casing, Liner and Cementing Program I Weight t36 Insula~ 17% 72# 12¼ 475 7 265 22. Describe proposed program: S,~E Hole , Casing 20×30 13 3/8 9 5/8 CASING AND LINER Grade J Couplingt Length :ed Conductor I 80 L-80 I BUttI 2440 L-80 IButt I ll000 SETTING DEPTH MD TOP TVD Surface Su.~ace Surfiace 10808I 8547 See attached proposed drilling and completion program. SERVICE [] STRATIGRAPHIC SINGLE MULTIPLE ZONE 9. Unit or lease name Prudhoe Bay Unit 10. Well number S-15 (32-26-12-12) PBU 11. Field and pool Prudhoe Bay Prudhoe Oil Pool Amount $200,000.00 15. Distance to nearest drilling or completed wellN, KuDa~ State 18. Approximate sp"ud date -- .2300 fi May 17, 1984 3330 psig@_____ Surface 4390 psig@ R~00 ft. T~J~(TVD) D BOTTOM TVD 110 110 2500 2500 110601 8715 QUANTITY OFCEMENT (includestagedata) 8 cu.yds.concrete 3470 cu.ft.Arcticset et :I & 2730 cu.ft.Class G; III I 285 cu.ft.Arcticset ~ 11783 9200 288 cu.ft.Class G wi~h As shown on the attached 18% sjlt9 directional plat, we are aware of the potential 'intersection problems which can result from the drilling of this well. If during actual drilling operations, one of these intersections is approached within hazardous proximity, the well to be intersected will be shut-in. RECEIVED MAY t 11984 23. I here, by certify that theforegoing is true and correct to the best of my knowledge Alaska 0il & Gas Cons. ~* ~/" ~ V.4~~,~ / Dis~ict Drill~g Engin~r Anchorage SIGNED . f~~ TITLE DATE The space below for Commission use R. H. Reiley CONDITIONS OF APPROVAL I Samples required []YES ~,NO Permit number APPROVED BY Form 10-401 Mud Icg required []YES Approval date Directional Survey required ~-Y ES I--]NO APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE May ]5, ]984 by order of the Commission Submit in triplicate PROPOSED DRILLING AND COMPLETION PROGRAM WELL S-15 (32-26-12-12) PBU Install and cement 80' of 20' x 30' insulated conductor to surface. Drill 17 1/2" hole to 2700' TVD and cement 13 3/8# 72~ L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and-.an oil column to 8B00' TVDss. Directionally drill 12 1/4' hole to +100' TVD above the Sag River Sandstone. Run 9 5/8" 47# L-80 Buttress casing to within 5' of 12 1/4" TD and cement in two stages: First stage using C/ass G cement around the 9. 5/8" shoe, The second stage to be downsqueezed in the 13 3/8' x 9 5/8' annulus followed by Arctic Pack. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement with 18% salt, Clean out to 7" float equipment, Change Dyer to 9.6 PI~- NaCl completion fluid. Test casing and lap to 3000 psi, Run CBL. Run 9. 5/8" production packer on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer +50' above top of liner. A sub- surface safety valve with ~ual control lines will be placed +50' below base of permafrost. Install and test Xmas tree, Displace tubing to ~iesel. Set and test packer. Suspend well for perforating subsequent to rig release, Tubing Size: 4 1/2" 12.60 L-80 AB-mod. Butt. RECEIVED MAY i i 1984 Alaska Oil & Gas Co~s. Commissfon Anchoraoe B.O.P._,~S TA C K ,.CO N f I G U R. A_T 10N 15 5/8" TRIPLE RAM STACK i i i · ii SO00 PSI WP i DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS 2' KILL LINE DRILLING SPOOL CHECK GATE GATE GATE PIPE RAMS 4" CHOKE LINE H Y DR. ASST. GATE RECEIVED MAY ! 119~4 0ii & Gas Cons. Commission Anchorage O2 05 . _ - 04 ' ] ....... '~;i~-{Proposed) ............. 1 ~PLoP md } .....I ..... : ,' OI [ /-- S- Iff : . I . /: LAT. = 70°~1'09.52 [ · I S* 18 ( Propo.~e d) OF T. I1N. & T. 12N., R. 12 E.~ U.M. PORTION SCALE: 1"=I/2MILE SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A LOCATION SURVEY OF THE WELLPAD SHOWN AND THE WELLS THEREON. THIS SURVEY WAS MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. BOTTOM HOLE LOCATIONS ARE FURNISHED BY OTHERS. DATE ~A,vII~I3~,4 REGISTRATION NO. REGISTERED LAND SIo~RVEYOR WELLS PAD DETAIL SCALE :1": 500' -- PLANT RECEIVED MAY 1 1198~ Alaska Oil & Gas Cons. commission Anchorage II _ I I I PAD "S" EXTENSION Located In PROTRACTED SECTIONS 26tZ7t;~4,3§12 ~, 3lTl Z.N~TI I.N,RIZE? UM Surveyed for SOHIO ALASKA PETROLEUM CO. u I I III Surveyed by OCEAN TECHNOLOGY LTD. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Llghtm.Boulevard Anchorage, Alaska ! I I II I I I II ! '--- CLOSEST APPROACH AHAt. Y,qIS --- VER,~ZON 5,5 FOR PROPO~KD ~£1.1. S-1S COIIR.qE L]HF.. I:~LI:III. f~T.~rlH FI'IR gEI.L. $-15 LOCflTION = g-E S-N TUD(S~S) TOP 61SgR~.O0 5979499.00 -60.00 BOTTON 6~157~.96 59R4~79.80 90S4,60 NOTE - ALt. DEPTHS ~H FEET BELOW KEt. LY ~II~H~HI~ CLOSEST ~PPRO~CH WELl. 1DENT /PROPOSED\ /N£ARBY\ TUD DEPART TUD DFPART ~TSTANC£ A03200 7470.4 4159.~ 74~?,~ 0,0 S-3 92,9 0.0 lO0.O ,2 43&.4 A72900 S-~2 92,9 0.0 ~00,0 1,3 S-~! 4205,1 ~&4,2 39~9,7 90.S 10~4.R A76500 S-10 47g3.7 11~0.3 4643,4 5~,4 950,3 A77100 S-9 3979.1 390,8 4012oR 376,H 629.6 AT?BO0 S-g 4043.~ 435.5 403~.5 2~O,g A7170! .,,~'! 3403.4 110,9 ~36~.2 118,0 A80400 S-14 2713.5 .3 ~700,0 0.0 1504.7 A69900 S-2 3595,g 102.7 35~],0 227.3 153,0 A82900 S-7 0.0 0.0 5.~ .0 77R,2 S-13 2392.3 0.0 2~99,9 11.9 ~4~9.4 Ag3900 S-6 4064,0 4~0,7 4040,6 I08,] 430,7 A86900 ~-~ 4107,7 483,7 4099.7 24,0 2g],O SUHNARY THE .Et.L .HlC. COHES CLOSEST TO T.£ PROPOSE, .ELL A95900 CLOSEST APPROACH DXSTA.CE - 149.4 F~£T .0 PR~.TE~ REPORT CLOSE,T APPROACH FOR , ~EORE£ I. EAR .~LL ENTER A REPORT T]TLE ? UERT~ChI.. ~HT£RS£CTION TUD ~FP~RT TVD DEPART 4097,~ 4?5.3 ~ORO,3 DX;TANCE -~Ogg.7 RECEIVED MAY ! ! 19t]4 Alaska Oil & Gas Cons. Commission Anchorage 377?.,3 2&&,7 .%494,4 269,6 1~?09,0 ~.. VERSION FOR PROPOSED #ELL 8-15 --- CLOSEST flPPRIIAI:H hNflI. Y~IS --- 7 DEGREE LEAD I:~I. CUI. hTI()H FOR M£1. L S-15 ' LOCATION - g-E S-N TVD(SDS) TOP 618885,00 5979499,00 -60.00 DOTTO# 620900,6~ 5985167.46 9084.60 NOTE - ALL DEPTHS iN FEET DELOU KELLY CL.OSEG[ APPROACH gELL ZDENT /PROPOSED\ /HEARBY\ CLOSEST TVD DEPART- TVD DEPART DISTANCE A03200 7630,5 4337,1 7617,3 0.0 940,¥ A69500 S-3 92,9 0,0 IO0,O ,2 436.4 A72900 S-12 92,9 0,0 100,0 A72800 S-11 4054,9 444,! 3841.9 64,V A76500 S-lO 4495,2 960,~ 4255,2 44],~ 10~,2 A77100 S-9 3937.2 362.~ 3999.5 368.3 67~,4 A77800 S-B 3994,2 400,9 4004.~ 208.4 61~.4 A71701 ~/ 342fl.g 2J9,5 3383,1 124,¥ 248.3 A80400 S-14 27J0,2 ,2 2700,0 0.0 1~04.7 A69800 S-2 3574,J 173,3 3563,0 219,2 173,6 A82900 S-7 0.0 O.O 5.8 .0 77~.2 A81000 S-Z3 2392,3 0,0 2399,? Jl.9 1409.4 A83900 S-& 3883,5 329,8 3797,R 50.0 482.4 A86900 _%"~.~' 4064,5 45~,1 4061.6 21,9 A95900 '~*ZJ 4080.0 462.4 4095.5 14,9 207.2 I~7 SUNHARY THE gELL gHICH CDHEG CLOSEST TO THE PROPO!;ED gELI. IS A69800 CLOSEST APPROACH DISTANCE ~ 173,6 FEET NO PRINTED REPORT ~)ERI' x CAL JNTERfiECT[ON /PROPOSED\ /NEARBY\ TVD DEPART TYD DF. PAR'[ 4135.4 50~,9 27,6.%. 0 14H,0 gAG THE CLOSEST APPROACH OK I EC£1vED Chorage Commission YFKT%CAL D%STANCE .-[777.5 1901,8 ~oo_ ~~ ~- ~_~oo __ N~ 1] ('1 ('1 / ~nn / \ \ J-~ ,o MAY L ]. AlaSKa 3il & Ga; Cons. ommissi ~n Amhorage ] 2~ 30 4~ ]0 6~ ]0 8~30 1 300 1 ;~00 ql I~ FA SF 2J~ RI~F S-~TI ~IN:R!~.RNI =lqlR4' JFI CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee (2) Loc thru 8) ( (3) Admin 69' thru 11) (10 and 11) (4) (12 thru 20)' YES NO 1. Is the permit fee attached .......................................... ~z/~z~-- .... 2. Is well to be,located in a defined pool ............................. ~C~__ 3. Is well located proper distance from property line ................. i/,~(~__., 4. Is well located proper distance from other wells ................... ~ 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is well bore plat included ............... ,~ ...... 7. Is operator the only affected party ................................. 8. Can. permit be approved before ten-day wait .......................... 9. Does operator have a bond in force .................................. 10. Is a conservation order needed ...................................... 11 Is administrative approval needed · eeeeeeeeeeee~eeeee.eeeeeeeeeeeeeee~ 12. 13. 14. 15. 16. 17. 18. 19. 20. REMARKS Is conductor string provided ........................................ ~. Is enough cement used to circulate on conductor and surface ........ Will cement tie in surface and intermediate or production strings ..i Will cement cover all known productive horizons .................... ._,~". Will surface casing protect fresh water zones ...................... Will all casing give adequate safety in collapse, tension and burst. __ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandOnment procedure included on 10-403 ............ Is adequate well bore separation proposed ............................ (5) BOPE ,,fT/,,'~,kf d--/~/-~/ (21 thru 24) ! (6) Add: ~-~ b-'!~"~4 21. 22. 23. 24. 25. Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~z~ .. Does BOPE have sufficient pressure rating - Test to ..o~-~-Z) psig .. /~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. /V~7- Additional requirements ............................................. Additional Remarks: ~F-S~- /~fO/~z~l~t~ /-~ ./~/ f! T~:) _~-~/ C~ /~ ~ZZD sz-?& i o ~ 0 ~,-] Geology: Engineering: /-~ rcs WVA~ JKT ~.HJH ~-~ JAL MTM ~,,-. rev: 12/08/83 6.CKLT INITIAL'' GEO. UNIT oN/oFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry 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 APPENDIXi No special'effort has been made to chronologically organize this category of information. YP Ulo,H02 VERi["ICA'FIOI'.~ b.I]STING PAGE 1 ERVICE ~IA.~)E :)::bit ATE :~,t07/ ~ RIGIN : ONIIaUATIOI,~ ~ * TAi~E }.~EAOEK ER//ICg NAME ATE :~.t0'tt RIGI~'~ :0~00 RE'V I0~.~5 TAPE * FILE HPZADER 'ILE N A t',l E :EDIT .o01 ER VIC}!, NAP, E ; ATE : AX~MOi~ LENGTH : 1024 IL~ TYPE REVIUUS WILE ; 'N : 'N : PRUUHOE BAY ',AN'G: 'OWN: 12~.~ ~OUN: N ,TAT: ,ALASKA ~TRY: U N I "ii' T 'Y P ~ C/4 'f E 81 Z lC C 0 D E 000 000 030 065 OOu 000 004 065 000 0 o 0 012 065 u o 0 0 0 0 0 0 zi 0 6 5 0 ¢) 0 0 o 0 o (; 4 065 ooo 000 002 065 000 0o0 00~ 065 000 000 0()o 065 O 00 000 004 065 VP OiO.H02 V~ll{i~'..i. CATiO~ UI~'I.ING PAGE 2 OB NU*..~i~ER AT AC(,,'.: 49341 UN ~'2, ;)ATE i.~L]GGE!'): 29 Jt)~,~ 84 OP: T .it.AL, 5'IEAL) ASING ~NSITf H bUiD -' 9,~2b" ~l 10831" - blt ,:~£Z~.;'-' = 8.'30" TO 11956' = 9,6 b!.~lG ~'~ : 2.~0 [a ~0,(; DF = b4,0 ~ R~';F = 1,110 fa 66,0 DF = 12,0 RMC : 1,940 {~ bS,0 D~' = 3.0 C3 R~ AT ~HT : 1.I0~ (a :tSO,O DF ~rp 010.h02 V£RIf:ICATiUi'; I,,,!.STING PAGE :iN #.1., DATE i,,O(.,(4gl.;; 11 dt~ra 84 DP: T HAb$I"b~AD ~PE FLu!O EN$ITY ISCOSJ' T¥ 13,375" ~:,a2509' - i.3I'C SI7.,E = 12.25" "!:'O 11320' 9.9L~/G R~ = 2.690 ~9 bB.0 DF 3U.O S RMF = 2.820 ~ 58,0 DF 10.5 ~{~C = 2.670 La b~,O DF * DATA F£]RMAi Al<CORD *~ NTRY ~hOCK$ TYPE SIZE; REPR COPE ENrR~ ~ i 66 6 4 73 60 9 4 65 0 !. 66 ATUM ~>P,,,.,~ I'F ICAT'i uN NE~ ~ERV.ICE L~E~VI~ C~,'" UNI.[' APl ID ~'iRDER ~ LOG TYPE CLASS ,¥~[}D t'~{.,;, LEVEL CODE DATA gPT P 11988, OuOO -999.2500 -999,2:) 0 ILD 24,, 5(~(')~) [. 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H02 VERIF'IC.A',i.'J. ON b.[6TING PAGE 5 010 O -999 EPT 10000,0000 5Fl.d p -999,2500 Ga ~P'I' 9900.000e 5~, l,d P -999.2b00 Ga EPT 9800. 000o SFLu p -999,2500 GR EPT 9700. 000u p -999,2500 MPT 9600.0000 SFLO p -999.2500 G~ EPT 9500,000u p -999.250u EPT 9400,00oo 8Ff, U p -999.2500 GH g P T 9 .~ 00.00 () 0 S F l.. u p -999,2500 GR EPT 9200. oOOu SF!~ P -999.25~;u GR EPT 9100.00o0 SFI'.,U p -999.25i)0 G~ EPT 9o0o. 00oo P -ggq. 25oo EPT 890o. OoO0 SFLt~ p -9Y9,25o0 G~ gPT 8800.0000 SFLu p -999.2500 G~ £PT 8700.00Oo SFI,iJ EPT 8bO0,0000 p ' 20 4375 EPT 8500.00o0 SFI,O ~]PT ~400. (.)00 o SFL~ p -6. 2031 GR -999. 2500 -999.2500 ILD 44.7188 -999.2500 41.1562 -999.2b00 1LO -999.250U 58.0000 -999.2500 fbi) 54.5313 O~ -099. 2500 ILl.) -999. 2500 ILO 5 L,. ~ 750 D T -999. 2500 o5. !~7b bT -999 2500 I.bD 5517813 DT -99q 25o0 I'i.,D 5 4, · 0 e, 2 5 D T -999,2500 64.0625 DT -999. 2500 IbD 56.1 250 DT -999. ~,500 52.2g~.t3 '!, 89l~4 I. 49.7 .[ 8 u D f 2.6973 lk, D ~o DT 2.6 u ii 5 11, D ,I 03. 2500 DT 1o8o9o ,iud I00.~250 OT -999.2500 Ih~ -999.2500 GR -999.2500 -999.2500 -999.250o -999.2500 · -999,250u IbM -999.2500 GR -999.2500 -999.25(~0 GR -999. 2500 -999.2500 Gl{ -999,2500 -999.2500 (JR -999.2500 IbM -99q.2500 GR -g99.2500 IbM -999.2500 -9~9,250U -999.2500 G'R -999.250{) -999.2500 -999.2500 IbM -999.2500 GR -999.25Ou -999.2~00 GE -999.2~00 -99Q.2500 GR 9,5000 IbM -999,2500 Ga 2.50'7~ -999.2500 GR 2.8906 -999.2500 2.1445 -999.2500 GR -999.2500 52.3~38 -999,2500 44.7188 -999,2500 41.1562 -999,2500 41.4688 -999,2500 58.0000 -999.2500 54,5313 -999,2500 5~.0000 -999,2500 50.8750 -999.2500 bb.1875 55.781,3 -999.2500 5~,u~25 -999,2500 54,0625 -~99.2500 50,1250 '99~,2500 52.281.3 lO.bOlb -!!9 ~391 25O0 2.8301 -999.2500 -999 5O0 VP OlO,H02 V'ER[FiCA'r.IDh bI,b']71~{~ PAGE EPT 8300.900o P -7.91su EPT 8200,0000 P -18.390o GR blO0.OOOu EPT 80~0, Ouoo P -30.1094 GR EPT 7900. O00u SFI.,h P -b..12bi EPT 7800.00~0 S~' t.,,U P -22.343~ EPI 7700,0U00 P -lb.632~ G~ EPT 76~0,00D~ ~FL, u EPT 7500. OOO0 P -i1..343a~ GR P 16:g219 GR EPT '1300.ouoo SF'L,o P -4.0898 E P T '12 o 0, () o u u P -10'2969 EPT 7100. OOO0 SFLU P -25.ov94 E b T '10 O 0,0 O 0 u S f" b u P -~6.3281 GR EPT 6900. OOO0 SFIdU P -o. 3~ EPT 6800. oo{,,0 EPT o7oo. oooo SFLu P -23.93"15 EPT o600, OuOu P -.15.9 7 a b G 2 92 2 lo0 60 9 69 3 1 'I 8 I.'/2 3 107 152 111 3 1 O5 3 84 1 O0 9'/ 2 90 2 91. .7383 .8 '; 5 0 .7500 .9760 .156k .9219 .5000 .9395 .5OOu .25O0 .2617 .0o25 . 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B 88 't -999. 2500 2,9902 -999,2500 3,1094 -999.2500 10. 4063 -999,2500 11.~969 -999.2500 ., 3.9082 -99~.2b00 -999.2500 2,354~ -~9~, 250(; 2,2773 -999,2600 2,8828 -999,2500 3.84~57 -999.2500 3. 498'0 3. ,~531 -999.2500 99~:0742 - 250O 3.5527 -~99,2500 3,8945 -999.~500 3,3150 -99~J, 3500 ~, 5"11. 9 -999. 2500 VP OlO,H02 Vr2Ri?'IC^TiO~'~ blSTiNG PAGE; 7 bSU.9, OUOg P -&l ,69b~ gPT b300. OOO0 P -14.007~ EPT 0200, Ou{~O S~' LO P -14,9~44 EPT ~lO0,Ouuu SFLU P -3,0000 G~ EPT bO00,0000 P 2,4902 EPT 59o0. 0000 SFL,~J P '7,B12b GR 5PT 58U0,0000 8FL~ P -52,2~15 EPT 5700,0000 SFLO P -29,0469 GR ~PT 5600,00{30 SFLb P -4~ ,0313 GR EPT 5500. 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