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HomeMy WebLinkAbout187-085Nolan 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: 10/04/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20241004 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 214-13 50283201870000 222117 9/26/2024 AK E-LINE Perf END 2-72 50029237810000 224016 8/26/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON COILFLAG END 2-72 50029237810000 224016 8/29/2024 HALLIBURTON RBT MPI 2-16 50029218850000 188134 9/9/2024 AK E-LINE Perf MPI 2-16 50029218850000 188134 9/20/2024 AK E-LINE Perf MPU B-16 50029213840000 185149 9/28/2024 READ CaliperSurvey MPU B-24 50029226420000 196009 8/20/2024 HALLIBURTON PERF MPU B-28 50029235660000 216027 9/28/2024 HALLIBURTON TUBINGCUT MPU I-01 50029220650000 190090 8/17/2024 HALLIBURTON PERF MPU R-103 50029237990000 224114 9/20/2024 AK E-LINE Hoist MRU M-02 50733203890000 187061 9/23/2024 AK E-LINE Perf PBU 02-21B 50029207810200 211033 9/30/2024 HALLIBURTON RBT PBU L2-10 50029217460000 187085 8/23/2024 HALLIBURTON RBT PBU L-212 50029232520000 205030 9/24/2024 HALLIBURTON IPROF PBU L-254 50029237520000 223030 9/20/2024 HALLIBURTON IPROF PBU P1-17 50029223580000 193051 9/7/2024 HALLIBURTON RBT PBU S-09A 50029207710100 214097 8/21/2024 HALLIBURTON RBT PBU Z-235 50029237600000 223055 9/19/2024 HALLIBURTON IPROF Please include current contact information if different from above. T39619 T39620 T39620 T39620 T39621 T39621 T39622 T39623 T39624 T39625 T39626 T39627 T39628 T39629 T39630 T39631 T39632 T39633 T39634 PBU L2-10 50029217460000 187085 8/23/2024 HALLIBURTON RBT Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.10.04 15:10:24 -08'00' 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 this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L2-10 Mill plugs & cmt (post 2018 Pkr sqz) Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 187-085 50-029-21746-00-00 ADL 0028321 10404 Conductor Surface Intermediate Production Liner 9270 80 4065 9827 787 9530 20" 13-3/8" 9-5/8" 7" 8543 35 - 115 34 - 4099 30 - 9858 9613 - 10400 2075 35 - 115 34-4028 30 - 8813 8611 - 9267 9710 , 9980 470 1950 4760 7020 ~9530 , 9710', 9849, 1490 3450 6870 8160 9924 - 10184 2-7/8" 6.5# L-80 L-80 31 - 99808869 - 9117 Structural 7" Brown 1-B Perm , 2-7/8" AVA No SSSV (TRDP locked out) 9569 , 9962 8575 , 8902 Date: Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com (907) 564-5258 PRUDHOE BAY 5-3-2024 Current Pools: LISBURNE OIL Proposed Pools: LISBURNE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:46 pm, Apr 19, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.04.19 11:56:50 - 08'00' Eric Dickerman (4002)  DSR-4/23/24MGR19APR24SFD 4/22/2024 * State to witness MIT-T and MIT-IA to 2500 psi. * CBL to AOGCC upon completion. 2075 10-404 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.04.26 08:25:23 -08'00'04/26/24 RBDMS JSB 042624 L2-10 : RTP PTD: 187085 Page 1 of 11 Well Name:L2-10 API Number:50-029-21746-00 Current Status:Not Operable, Offline Permit to Drill Number:187085 Estimated Start Date:May 2024 Rig:Coil/Eline Regulatory Contact:Carrie Janowski Estimated Duration:6 days First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Dave Bjork Cell Number:907-440-0331 Brief Well Summary: L2-10 is a Lisburne producer completed with perforations in Wahoo Zones 7, 6, and 5. In November 2016 a gas leak was found at the wellhead, and the well was secured with a tubing plug. However it was later diagnosed that the 9-5/8” x 2-7/8” production packer at 9,569’ had failed and was allowing communication from Z7 to surface. Well integrity was eventually established after four cement jobs. These cement jobs have been pumped in to Z7. Objective: Mill retainers, cement, and bridge plugs to regain access to the reservoir. Re-perf Wahoo Zone 7. Return well to production. After the operation is complete, the well will fall under CO 736 regulations.After the operation is complete, the well will fall under CO 736 regulations. Re-perf Wahoo Zone 7 L2-10 : RTP PTD: 187085 Page 2 of 11 Current Bottom Hole Pressure:2,965 psi at 8,900’ TVDss (SBHPS 9/30/2008) Max. Anticipated Surface Pressure:2,075 psi (0.1 psi/ft gas gradient to surface) Last Shut-in WHP:1,050 psi (7/11/23 WSR) Min. ID:2.197” BNG Nipple (see schematic note) Max. Deviation:36.62 deg at 6,600’ md H2S Concentration:70 PPM (4/3/2015) Well Integrity Information: Tbg: MIT-T passed 2,370 psi – 7/11/23 IA: CMIT-TxIA passed 2,340 psi – 7/11/23 OA: N/A PPPOT-T: PPPOT-T passed 5,000 psi – 7/7/23 PPPOT-IC: LPE-IC determine primary holding, secondary failed. Well Completion Information: Wellhead: FMC Gen IV, 13-5/8” x 11”, 5M Tree: FMC, 2-9/16”, 5M SVLN: 2-7/8” Camco TRDP1A-SSA, Locked out GLM: 4x McMurry FMHO, 1” pocket 1x McMurry FMHO, 1-1/2” pocket (bottom mandrel) Production Pkr: AVA RHS-XL, 9-5/8” x 2-7/8” (cemented) Straddle Pkr: Brown 1-B, 7” x 2-7/8”, permanent Existing Casing/Tubing Program: String Pipe #/ft Grade Connection Top Bottom Surface csg.13-3/8 68#, 72# K-55, L-80 BTC Surface 4,099’ Int. csg.9-5/8 47 L-80 NSCC Surface 9,857’ Prod. Lnr.7 29 L-80 BTC 9,613’10,400’ Tbg.2-7/8 IPC 6.5 L-80 EUE 8rd Surface 9,977’ L2-10 : RTP PTD: 187085 Page 3 of 11 Recent Well History: 11/10/2016 DSO found wellhead leak. 11/12/2016 Slickline set WRP in tbg tail and got passing MIT-T. 11/14/2016 CMIT-TxIA failed. 11/15/2016 Eline LDL showed packer leak at 9,569’. 11/17/2016 Slickline pulled WRP. 11/20/2016 Slickline set CBP at 9,849’ and cement retainer at 9,785’. 11/23/2016 Cement job #1 – retainer squeeze pumped through AVA ported nipple at 9,832’ with coil against CBP at 9,849’ and retainer at 9,785’. 117bbl of Class G, no squeeze. Left ~7ft of cement on top of retainer. After cement job, LLR 4.75bpm at 800 psi pumping down IA taking returns to Z7 perforations. 12/23/2016 Slickline tagged retainer at 9,780’slm. Pulled STA 7 DGLV and left open pocket. 12/27/2016 Cement job #2 – Pumped 50 bbl Class G, fullbore through STA 7 open pocket. Bottom was cement retainer at 9,785’. Wiped tubing with foam ball. No squeeze. After cement job, LLR 1.7 bpm at 800 psi pumping down IA in to Z7 perforations. 01/06/2017 Slickline tagged cement at 9,698’slm (this leaves approximately 80’ of cement on top of retainer at 9,785’). 01/31/2017 Eline punched 9,667 – 9,669’. 02/04/2017 Cement job #3 - pumped 1500# Crystal Seal and 50 bbl Class G fullbore through tubing punches. Returns initially taken to Z7 perforations, then circulated into IA. After cement job. LLR still 1.1 bpm at 800 psi pumping down IA in to Z7 perforations. 02/16/2017 Slickline tagged wiper ball at 9,651’ slm (this leaves approximately 134’ of cement on top of retainer at 9,785’ assuming all cement). 09/01/2017 Eline punched tubing from 9,550’ – 9,555’ and set a cement retainer at 9,540’ (failed). 10/17/2017 Coil milled the failed retainer from 9,545’ and pushed to 9,710’. 12/01/2017 Eline set new retainer at 9,530’. 12/04/2017 Cement job #4 - coil pumped 30 bbl of 8.6ppg light cement through retainer and left 10’ of cement on top of retainer. 12/10/2017 CMIT-TxIA passed. 12/22/2017 MIT-T failed, CMIT-TxIA passed. L2-10 : RTP PTD: 187085 Page 4 of 11 Recent Well History continued: 06/24/2023 LPE on IC packoff. Secondary IC packoff failed, Primary IC packoff intact (test void communicates with IA but not OA). 07/07/2023 PPPOT-T passed. 07/11/2023 Slickline dummied all gas lift valves. MIT-T and CMIT-TxIA passed. L2-10 : RTP PTD: 187085 Page 5 of 11 Wellwork Procedure: Coil: 1. Mill retainers at 9,530’, 9,710’, and 9,785’. Mill composite bridge plug at 9,849’ and push to TD. a. Expecting 10’ of cement on top of retainer at 9,530’. b. Potential for cement between retainer at 9,530’ and 9,710’ from cement job on 12/4/17. c. Expecting cement from 9,710’ to retainer at 9,785’. d. Potential for cement below retainer at 9,785’ to composite bridge plug at 9,849’. e. The retainers look to be the cast iron FH model. Eline: 2. Locate top of cement in the 9-5/8” x 2-7/8” annulus by logging CBL from 9,970’ up to TOC (expected around 9,500’). Tie in to tbg tally. 3. Set bridge plug at ~9,600’ (below 9-5/8” x 2-7/8” production packer at 9,569’). Tie in to tbg tally. 4. MIT-T to 2,500 psi target to test bridge plug. Integrity: 5. AOGCC witnessed MIT-T and CMIT-T to 2,500 psi target. Provide 24hr notice to witness. 6. Update well file and database to perform biennial MIT-T and CMIT-TxIA to 2,500 psi target as required by CO 736. Slickline: 7. Pull bridge plug from 9,600’. 8. Dummy gun drift for eline. Max swell of 2” Maxforce is 2.165”. 9. Set gas lift design per gas lift engineer. 10. Hand well over to DSO to POP. Eline: 11. Drift with gummy guns as necessary. 12. Perforate Wahoo Zone 7 from 9,924’ – 9,952’ with 2” MaxForce guns. a. Tie in to SLB Perforation Record 27-October-2014. CBL to AOGCC for review. - mgr Perforate Wahoo Zone 7 from 9,924’ – 9,952’ L2-10 : RTP PTD: 187085 Page 6 of 11 b. Be ready to PUH immediately to prevent any possible cement sheath or debris packing off around guns. L2-10 : RTP PTD: 187085 Page 7 of 11 Current Wellbore Schematic: L2-10 : RTP PTD: 187085 Page 8 of 11 Proposed Wellbore Schematic: L2-10 : RTP PTD: 187085 Page 9 of 11 Tie in log: L2-10 : RTP PTD: 187085 Page 10 of 11 L2-10 : RTP PTD: 187085 Page 11 of 11 Perf Modeling through blast joints: STATE OF ALASKA •LASKA OIL AND GAS CONSERVATION COMMIS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change ApprovePioq� r 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well El Re-enter Susp Well 0 Other Cemen tweeze I I 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 87-085 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21746-00-00 7. Property Designation(Lease Number): ADL 028321 8. Well Name and Number PBU L2-10 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: Total Depth: measured 10404 feet Plugs measured 9530,9785,9849 feet true vertical 9270 feet Junk measured 9980,9710 feet Effective Depth: measured 9530 feet Packer measured 9569,9962 feet true vertical 8543 feet Packer true vertical 8575.8902 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 35-115 35-115 1490 470 Surface 4065 13-3/8" 34-4099 34-4028 3450/4930 1950/2670 Intermediate 9827 9-5/8" 30-9858 30-8813 6870 4760 Production Liner 787 7" 9613-10400 8611-9267 8160 R E`(�'/ \r/Et2 `E D Perforation Depth: Measured depth: 9924-10184 feet True vertical depth: 8869-9089 feet JAN 0 4 2018 Tubing(size,grade,measured and true vertical depth) 2-7/8"6.5#L-80 31-9980 3 G C C Packers and SSSV(type,measured and 2-7/8"AVA HydroSet Ret Packer 9569 8575 true vertical depth) 2-7/8"Brown 1-B Perm Packer 9962 8902 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: ,CANNED JAN 1 g 2J3 S G 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 119 1606 369 1604 525 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 Anc 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development RI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil a Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-300 Authorized Name: Lastufka,Joseph N Contact Name: Hibbert,Michael Authorized Title: Information a to Controller Contact Email: Michael.HibbertaBP.com Authorized Signature: k .......„------ Date: 1/4/16 Contact Phone: +1 907 564 4351 Form 10-404 Revised 04/2017 VR-I [- 0/8 itiicAt E0 f7273 li'/ ° '^ 1 Submit Original Only • • Daily Report of Well Operations L2-10 ACTIVITYDATE SUMMARY ***WELL SHUT IN ON ARRIVAL*** (secure) DRIFT W/2.275" CENT. & 1-1/2" S. BAILER &TAG @ 9654' SLM (sample of wiper ball) 8/30/2017 ***WELL LEFT SHUT IN, DSO NOTIFIED*** ***WELL SHUT IN ON ARRIVAL*** (SLB ELINE TBG PUNCH/SET WFD CMT RETAINER) RIH w/5'x1.56" MEDIUM TBG PUNCH, 4 SPF, 0° PHASING CCL STOP DEPTH = 9542.8', CCL TO TOP SHOT= 7.3' PUNCHED TBG FROM 9550' -9555' RIH w/2-7/8" WFD WP PACKER CMT RETAINER SET CMT RETAINER MID ELEMENT AT 9540', GOOD INDICATION ALL LOGS TIED INTO 2-7/8 TBG TALLY DATED 29-SEPT-1987. AT SURFACE, FOUND TENSION ROD NOT SHEARED AT CORRECT POINT ***R/D COMPLETE AT 0030 ON 2-SEPT-2017. WELL LEFT SHUT IN UPON DEPARTURE*** 9/1/2017 T/I/O =VacNacNac. Temp = SI. TBG & IA FLs (E-line request). ALP = 0 psi, SI @ CV. TBG FL @ 90' (0.5 bbls). IA FL @ 2935' (191.4 bbls). 9/1/2017 E-line in control of well. 15:30 T/I/O = VacNacNac. Temp = SI. TBG & IA FL's. (E-line request). ALP = 0 psi & SI @ IA casing valve. Gas available across pad @ L2-11. TBG FL @ 2806', ( sta#2, dmy vlv, 14 bbl). IA FL @ 2914', (108' below sta#2 dmy vlv, 190 bbl). 9/2/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. ***WELL S/I ON ARRIVAL*** (Secure well) FISH E-LINE TENSION ROD FROM CEMENT RETAINER AT 9,528' SLM/9,540' MD. 9/24/2017 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** T/I/O = SSVNacNac. Temp = SI. IA FL (Special Projects Request). ALP = 0 psi &SI @ IA casing valve. IA FL @ 2900', 94' below sta#2 dglv, 189 bbl). 9/24/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. T/I/O = 0/vac/vac. Temp = SI. Job Scope: Compress IA fluid level —100'. Open SSV 2.5", swab valve 15.5 turns and downhole TRSV to monitor pressures. Shot IA FL = 2571'. Compressed IA with lift gas till 100psi, wait 30 min and shoot FL post compression to evaluate if fluid moved downhole? Shoot post compression FL = 2631'. Called APE and discussed out come of process. Secure well by closing both AL laterals behind wellhouse. Tree valves, swab closed, SSV closed, master open. Wellhead csg valves open to gauges 9/25/2017 and AL csg and inline valves closed. ***Job Complete*** CTU 9 1.75" CT Job Objective: Pump 25bbl of 8.6ppg cement into IA. MIRU. MU WFD cement stinger, RIH. Verify MM in/out are good. Never caught fluid while RIH. Cement retainer is potentially leaking by. RIH all the way to packer, never caught pressure (WHP nor coil). Pumped 24bbls 60/40 down coil,into well in attempt to catch pressure, never caught pressure. (backside volume at cmt retainer is 27bb1) Sting into retainer, pump 5bbl 60/40 down CTBS, never caught pressure, IA pressure only came up —7psi. Able to get LLR of 1 bpm-1.25bpm (300-550psi)with weight stacked down as well as 10' up off retainer. Plan forward is to mill retainer and push to bottom then RDMO while town comes up with new plan. MU 2.22" 3 bladed junk mill. 10/16/2017 ***Job in Progress*** • • Daily Report of Well Operations L2-10 CTU 9 1.75" CT Job Objective: Pump 25bb1 of 8.6ppg cement into IA. MIRU. MU WFD cement stinger, RIH. Verify MM in/out are good. Never caught fluid while RIH. Cement retainer is potentially leaking by. RIH all the way to packer, never caught pressure (WHP nor coil). Pumped 24bbls 60/40 down coil,into well in attempt to catch pressure, never caught pressure. (backside volume at cmt retainer is 27bb1) Sting into retainer, pump 5bbl 60/40 down CTBS, never caught pressure, IA pressure only came up —7psi. Able to get LLR of 1 bpm-1.25bpm (300-550psi)with weight stacked down as well as 10' up off retainer. Plan forward is to mill retainer and push to bottom then RDMO while town comes up with new plan. MU 2.22" 3 bladed junk mill. 10/16/2017 ***Job in Progress*** CTU 9 1.75" CT Job Objective: Pump 25bb1 of 8.6ppg cement into IA. MIRU. 10/16/2017 ***Job in Progress*** CTU 9 1.75" CT 0.156 WT CV=44.6bbl Job Objective: Mill/push failed cement retainer to TOC —9651' MU/RIH w/2.22" 3 blade junk mill. Tagged down at 9545 and milled through retainer. Had obvious communication with the IA throughout. Milled and pushed the retainer to 9710CTMD. POOH. Well freeze protected with 23bb1 of 60/40. DSOnotified of well status upon departure. RDMO. 10/17/2017 ***Job Incomplete*** CTU 9 1.75" CT 0.156 WT CV=44.6bbl Job Objective: Mill/push failed cement retainer to TOC —9651' 10/17/2017 MU/RIH w/2.22" 3 blade junk mill. T/I/O = SSV/100NAC. Temp = SI. WHPs (Eval L&K). ALP = 30 psi & SI @ IA casing valve. No signs of WH Leaks. SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:32 11/2/2017 T/I/O = VAC/100/VAC. Temp = SI. WHPs (Eval L&K). ALP = 40 psi. AL SI @ casing valve. 11/15/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 15:30 T/I/O = Vac/100Nac. Temp = SI. WHPs (Eval L&K). ALP = 160 psi, SI @ IA CV. No signs of WH Leaks. 11/30/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 22:00 ***WELL S/I ON ARRIVAL*** (SLB ELINE SETTING CEMENT RETAINER) INITIAL T/I/O = 0/150/0 PSI. MIRU, LPT/HPT= PASS. RIH W/ PEH-EF (1.20" FN)/WEIGHT X2/CCL/FIRING HEAD/MSST/WFT 2-7/8" CEMENT RETAINER. OAL = 25.5', OAW = 225 LBS, MAX OD = 2.19". TIE INTO TUBING TALLY DATED 9/29/87. SET CEMENT RETAINER SETTING AT 9530' MID-ELEMENT, CCL TO MID ELEMENT = 10.4', CCL STOP DEPTH = 9519.6'. POOH, RDMO. WELL S/I ON DEPARTURE. FINAL T/I/O = 0/150/0 PSI. 12/1/2017 ***JOB COMPLETE 01-DECEMBER-17*** T/l/O = 0/100NAC. Temp = SI. IA FL (CT request). AL IS @ CV. IA FL @ 2730' (4630' above sta#4 SO, 178 bbls). 12/3/2017 CT in control of valves upon departure. 20:00 CTU#8 1.75" CT. Job Scope: Cement Annulus MIRU CTU. MU WFT cement retainer stinger and RIH. 12/3/2017 ***Continued on 12/04/17** • • Daily Report of Well Operations L2-10 TWO =VAC/230/VAC. Temp = SI. IA FL (Assist CT). ALP = 160 psi, SI @ CV. Assiste CT w/ IA FL's for secure. 12/4/2017 CT in control of valves upon departure. 06:00 CTU#8 1.75" CT. Job Scope: Cement Annulus Rih with WFT stinger. Stopped short of cement retainer and attempted to circulate 60/40 meoh btms up. Able to get a positive pressure response as rate was increased to 2.5 bpm but would go on a vac once the pump came offline. The IA pressure increased from 68 psi to 190 psi. Shot a fluid level and the level had risen from 2730' to 1300' (84 bbls). Stung in to cement retainer and pumped following: 5 bbl fresh water spacer, 29.6 bbls of 8.6 ppg of light weight cement, 5 bbls FW spacer, 10 bbls of PowerVis, 5 bbls 1% slk kcl, and 10 bbls of 60/40 meoh. Once 5 bbls of cement exited the the retainer the IA was cracked and bled to 0 psi while continuing to pump cement. Unstung from retainer and laid in 2 bbls of cement. Contaminated cement 10' above retainer and pooh pumping pipe dispacement. Shot fluid levels through out job and level had risen to 730'. 12/4/2017 **In progress** T/I/O =Vac/20/Vac. Temp = SI. IA FL (Assist CT). ALP = 160 psi, SI @ CV. IA FL © 690' (45 bbls). 12/4/2017 SL in control of valves upon departure. 08:30 CTU#8 1.75" CT. Job Scope: Cement Annulus Rih with WFT stinger. Stopped short of cement retainer and attempted to circulate 60/40 meoh btms up. Able to get a positive pressure response as rate was increased to 2.5 bpm but would go on a vac once the pump came offline. The IA pressure increased from 68 psi to 190 psi. Shot a fluid level and the level had risen from 2730' to 1300' (84 bbls). Stung in to cement retainer and pumped following: 5 bbl fresh water spacer, 29.6 bbls of 8.6 ppg of light weight cement, 5 bbls FW spacer, 10 bbls of PowerVis, 5 bbls 1% slk kcl, and 10 bbls of 60/40 meoh. Once 5 bbls of cement exited the the retainer the IA was cracked and bled to 0 psi while continuing to pump cement. Pushed 27 bbls of cemnet behind pipe. Unstung from retainer and laid in 2 bbls of cement. Contaminated cement 10' above retainer and pooh pumping pipe dispacement. Shot fluid levels through out job and level had risen to 690'. Well is Freeze Protected w/ 15 bbls 60/40 Methanol.Rig Down 12/4/2017 CTU. T/I/O = SSV/10/VAC. Temp= SI. IA FL (CT request). ALP = 160 psi, SI @ CV. IA FL @ 690' (45 bbls). 12/10/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 04:00 T/I/O= 3/vac/vac. Temp = S/I (LRS Unit 42 - MIT-IA Post Cement) MIT-IA unable to complete-tbg tracked with IA, so rolled into CMIT-TxIA***PASSED***to 2501 psi (3rd Attempt) per Greg Lewis. test. Pumped 5 bbls 60/40 and 57 bbls diesel to load IA. 1st 15 min T/IA lost 14/14 psi, 2nd 15 min. T/IA lost 13/12 psi for total losses of 27/26 psi in a 30 min. Bled back 6.8 bbls. Bleed down IAP, Tubing tracking. Tags hung on tree, 12/10/2017 FWHP= 289/404/0 T/I/O = 20/150/Vac. Temp = SI. TBG FL. (Pre-MIT). ALP = 150 psi & SI @ IA casing valve. TBG FL= Near surface. 12/18/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 00:50 s • Daily Report of Well Operations L2-10 T/I/O = 5/133Nac. Temp = SI. MIT-T to 2500 psi FAILED. Tbg FL near surface. IA FL @ surface. MIT-T failed Used 13.5 bbls to establish an averaged LLR of 12.4 GPM @ 33 psi while taking return up the IA with an average of 11.6 GPM. CMIT-TxIA to PASSED to 2466/2450 psi, Max Preassure = 2500 psi, Target Pressure = 2250 psi. On the 2nd attempt used 7.3 bbls to pressure up Tbg/IAP from 25/61 psi to 2505/2450 psi. TP/IAP lost 27/27 psi in the 1st 15 mins and 12/12 psi in the 2nd 15 mins for a total loss of 39/39 psi in 30 mins. Bled IAP from 2450 psi to 30 psi and TP tracked (7.1 bbls). Hung Tags. Final WHPs = 10/30Nac. 12/22/2017 SV, WV= C. SSV, MV= O. IA, OA= OTG. 16:45 Fluids Summary Bbls Type 59 Bbls Diesel 236 Bbls 60/40 Methanol 29.6 Bbls 8.6ppg Cement 5 Bbls 1% slk KCL 10 Bbls Power Vis 12 Bbls Fresh Water TREE= 2-9/16"CNV FLS WELLHEAD=OR= FMC NEW STD�SL1 L2-1 0 SAF NO t t.5: ACTUA _....._.__. 13-3/8" , 99' OKB.ELEV= 45' 68#,K-55 BTC I REF RBI= 45' D=12-415" E-11 2200' —2-7/8"CAMCO TRDP1 A-SSA,D=2.312" BF.ELEV= 14.68' LOCKED OUT(01/20/16) KOP= 3200' 20'OOP), —115' a-BeICAL MANDRELS MS9x Angie= ____ 37*37"©66001 91 .5#,H-40 ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum Aro= 10,013' --- ID=19.124' c 1 2284-2284 1 CA KBG DArfl' BK 0 09/30/87 Datum TVD= 800'9SS GAS LFT MAPDRELS Uhi. ST M? TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTC,D=12.347" H 4099' L 2 2806 2806 3 Mc FM-i0 DBK 0 09/30/87 3 5336 5062 32 McFMIO DOME BK 16 08/25/15 Minimum ID = 1.875" @ 9832' 4 7360 6732 33 McFMi0 SO BK 24 05/15/16 2 7/8" AVA BPL NIP W/BPC 5 8755 7902 33 McFMiD DM'( BK 0 09/30/87 6 9466 8491 36 McFM-I0 DMY BK 0 06/24/95 EST TOC(12/04/17) —9501' 4I°d'. '1'1'' 9630' H2-7/8"VVFD CMT RETAINER(12/01/17) 2-7/8"TBG PUNCH,4 SPF(09/01/17) H 9660'-9666' ,'►`'�►',�r.— Ve 9669' —19-5/8"X 2-7/8"AVA RHS-XL PKR,0=3.375" TOP OF 7"LhER H 9613' PRODUCTION MANDRELS ST ND TVD DEV TYPE VLV LATCH PORT DATE L 2-7/8"TBG PUNCH(01/31/17) 9667'-9669' 7 9700 8681 35 AAcFMiO EMPTY BK 12/23/16 416. 9710'CTM —I FISH:2-7/8'VVFD CMT RET PUSHED(10/17/17) TBG TOC H—9710'CTM t 9786' l—2-718"VVFD CMT RETAINER(11/20/16)_...1 9832' —12-7/8"AVA BPL NP,D=2.259' ►, 9849' j--12-7/8"VVFD CBP(11/20/16)] 9-5/8"CSG,47#,L-80 NS(XJBTC,D=8.681" —1 985T 1--41 , I I 9898'-9957' H2-7/8"CAMCO BLASTJONTS,60' FISH:2 AND 1/2 WRP E3_BVIENTS LEFT DH(11/17/16). H 9980' _ 9962' H7"X 2-7/8"BROWN 1-B ECR,D=3.25" ABLE TO DRIFT PASS w/220". UNABLE TO DRIFT PASS w/2.245"CETT. 9976' —2-7/8"AVA BNG NP,D=2.197"BNG NIP PROFILE 2-7/8"FC TBG,6.5#,L-80 RE, H 9980' LIKELY CORRODED-ABLE TO DRIFT THRU NIP .0058 bpf,D=2A41" w12.245"CETT.(11/17/16) PERFORATION SUNTARY N/ 1 I 9980' H2-7/8"WLEG w LAVA SI-EAR OUT SW,D=2.441" REF LOG:CBL ON 09/22/87 ANGLE AT TOP PERF:32°( 10006 ' 9977' —1 ELMD TT LOGGED ON 10/22/87 Note:Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 1-2/3" S 9924-9952 0 09/28/87 ' 1-2/3" 6 10006-10028 0 10/28/14 1-2/3" S 10020-10094 0 10/22/87 ' 1-2/3" 6 10028-10050 0 10/28114 1-2/3" 6 10064-10080 0 10/27/14 I 1-2/3" 6 10080-10100 0 10127/14 1-2/3" 6 10122-10143 0 10/27/14 I 1-2/3" S 10124-10218 0 10/22/87 1-2/3" S 10143-10164 0 10/27/14 I 1-2/3" S 10164-10184 0 10126/14 I PBTD H 10354' 11111111 7"LMR,29#,L-80 BTC,.0371 bpf,D=6.184" --I 10400' 1.11111111111.111 DATE REV BY COMMENTS DATE REV BY COME NTS LISBURPE LW 10/01/87 ORIGINAL COMPLEITON 09/27/17 BSEIJMD RECOVEREDTENSION ROD FROM RE WELL: L2-10 08/11/01 RWTP CORRECTIONS 10/18/17 JTC/JM]MLLED RET DH(10/17/17) PIRISIT No: '1870850 03/29/17 M-1/ D REMOVED IA CMT 12/06/17 MAD SET VVFD CMI'RETAINER(12/01/17) AR No: 50-029-21746-00 03/29/17 JNUJND ADDED REF&BF ELEV 12/18/17 MSS/JMJ CMF(12104/17) Sec.18,T11 N,R15E,1439'FSL&1295'FWL 03/29/17 M-VJM) SL TAGGED TBG TOC(02/17/17) - 09/06/17 NND(W/JNC SET CMT RETAINER&TBG RJNCHES BP Exploration(Alaska) • • ":‘.\ OF Tj \ //7:�� � �e THE STATE Alaska Oil and Gas At 4 ofALConservation Commission As KA. 14 - 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0l1l�Q' Main: 907.279.1433 Fax: 907.276.7542 ALAS www.aogcc.alaska.gov Michael Hibbert Well Interventions Engineer SCANNED . UL2 0 2017, BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L2-10 Permit to Drill Number: 187-085 Sundry Number: 317-300 Dear Mr. Hibbert: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, daCCC\-- Hollis S. French Chair DATED this day of July,2017. RBDMS Vi'"' 1 7 2017 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM•N APPLICATION FOR SUNDRY APPROVALS ' 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 i• Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other Cement Squeeze II• 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 187-085 • • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development H 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21746-00-00• 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No m PBU L2-10 RECEI VED 9. Property Designation(Lease Number): '10. Field/Pools: ! f p` 9 n 17 ADL 028321 • PRUDHOE BAY,LISBURNE OIL J U l\ 2 201 11. PRESENT WELL CONDITION SUMMARY �' Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): J Q�CC 10404• 9270 . 9651 8641 9651.9785,9849 9980 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 35-115 35-115 1490 470 Surface 4065 13-3/8" 34-4099 34-4028 3450/4930 1950/2670 Intermediate 9827 9-5/8" 30-9858 30-8813 6870 4760 Production Liner 787 7" 9613-10400 8611-9267 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9924-10184 8869-9089 2-7/8"6.5# L-80 31-9980 Packers and SSSV Type: 2-7/8"AVA HydroSet Ret Packer Packers and SSSV MD(ft)and TVD(ft): 9569/8578 2-7/8"Brown 1-B Perm Packer 9962/8902 12.Attachments: Proposal Summary 0 Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development ® • Service 0 14.Estimated Date for Commencing Operations: August 1,2017 / 15. Well Status after proposed work: Oil ® • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hibbert,Michael be deviated from without prior written approval. Contact Email: Michael.Hibbert@BP.corn Authorized Name: Hibbert,Michael Contact Phone: +1 907 564 4351 Authorized Title: Well Interventions En 'neer Authorized Signature: *N44 ._, Date: _ j-p/13....COMMISSION USE OLto L/Y L Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31'7- c,v Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other. Post Initial Injection MIT Req'd? Yes 0 No ❑—/ Spacing Exception Required? Yes❑ No LN Subsequent Form Required: lb - 404. APPROVED BYTHE 1 •-� Approved by: T........-CQ.C.2.< COMMISSIONER COMMISSION Date: k t •q, *<"," ,\ V7 7-/i /1 nV,\`�,•'O R I I N AL RBDMS V L!L. 1 7 2017 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. AttachMn Duplicate • 40 IS • • gose Well: L2- 10 L2-10 Cement Squeeze Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Mark Sauve (907) 564-4660 Objective The primary objective of this procedure is to re-establish integrity barriers. An active flange leak was discovered on the well and subsequent diagnostics revealed that thepacker at 9569 had failed. The flange leak has been mitigated by re-torqueing the flange and appears to be holding, but with the presence of the failed packer a pressure test has not been able to be performed. This work will setup the well to isolate Zone 7 and place cement between the packers at 9569' and 9962'. Well History L2-10 had valve swap performed in May 2016. The TIFL done post job was declared a pass by the Well Integrity team on May 16th. On Nov 10th, a gas leak was found between the production casing spool and the surface casing spool, requiring Slickline to set a downhole plug to allow for surface repair. A passing MIT-T to 2,250 psi on Nov 12th demonstrated competent tubing/plug downhole, however, there was determined through two different attempts at performing a OMIT- TxIA that there was a well barrier issue in the inner annulus. During these two attempts, over 1,000 bbls of crude have been pumped down the backside at a rate of 5 bpm. A LDL found that the upper packer has failed at 9569'. Sundry number 316-591 was approved on 11/22/16 to complete this same objective. Three attempts were made to cement the failed packer and all failed. The sundry was closed in March of 2017. This attempt will utilize light weight cement and fluid column manipulation to place cement and return the integrity to this well. Step Type Procedure 1 S D&T w/ 2.25" drift 2 E Tubing punch 9550'-9555', set cement retainer @ 9540' 3 F Depress IA fluid level w/ Nitrogen 3 C Pump 25 bbls of 8.6 ppg cement 4 F MIT-IA to 2500 psi. LLR if fails. • Slickline • 1. D&T with 2.25" drift down to 9569'. Eline 2. Tubing punch from 9550'-9555' 3. Set cement retainer @ 9540' Fullbore 4. Depress IA fluid level 200-300 feet with nitrogen. Coil 5. MU retainer stinger and RIH and sting into retainer. 6. Pump the following down CT with IA and CTBS closed. a. 3 bbl FW spacer b. 27 bbls of 8.6 ppg light weight cement c. 3 bbls FW spacer d. 15 bbls of 1.25 powervis e. KCL displacement 7. When 5 bbls are pumped into retainer then crack IA valve and bleed pressure down to zero while continue to pump cement @ 1 bpm. Unsting from cement retainer with 1 bbl of cement in coiled tubing. Pump gel on top of retainer and POOH circulating @ 80%. Freeze protect well on the way out of hole. 8. RDMO. Fullbore 9. WOC 3 days - MIT-IA to 2500 psi. Establish LLR if fails. 2 ' • • Pre Job Schematic !HEE= 2-9/16"C1W ELS - WEL LI-EA D- ENICPC-W STD SLIM-L L2-1 SAFETY NOTES. AC niA TOR= BAKER c 13-3/8'CSG, --[ OKB REV- 45, 68#,K-55 Bit REF RB/= 47 ID=12-415" I 22001 2-718"CA MCO TREP1A-SSA,D. 2 312' BF FLEV= 14 68 0 LOCKED OUT(01/20/16) KOP= 3200 far COW, -Ili 6; CI-EMCAL IAANDRELS Max Angle= 37°@ 6600' ,91 sg 1440 - ST 11•13 NO DEV -NEE VLV LATCH FORT DATE Datum MD= 10,013' D-19.124 1 2284 2284 1 CA-KBG (MY BK I 0 09/30/87] " Datum 1 IVO= 8900'SS - GAS L FT MANDRELS 1. ST kV ND'4 DEV TY FE VLV LATCH PORT DATE L13'118'CSG,771,,I 80 BTC ID 12 34r I—I, 40981 _.1--A I] 2 2806 2806 3 ktFM-10 i OW BK 0 09/30/87 3 5336 5062 32 ktRAHO 1 DOKE BK 16 08/25/15 [Minimum ID = 1.875" @ 9832' 4 7360 1 67321 33 MFM-IO SO BK 24 05115/16 5 8755 79021 33 kt FM-10 DMY BK 0 09/30187 2 7/8" AVA BPL NIP VW 8PC 6 9466 8491 36 ktEM-10 DMY BK 0 06/24195 9669 }-l9-5/8'X 2-718"AVA R1S-XL PKR.ID-3.375' i TOP OF 7"LNR H 9613' PRODUCTION MANDRELS SL TAGGED TBG TOC(02117;17) -9651'5 LM Mee0. ST MO 11,10 DEV TY PE V LV LATCH PORT BATE I 7 9700 8681 35 Mc FM/40 EMPTY' BK - 12/23/16 2-7/B•TUG PuNCI1(0i au ir) i 9667--9669' ....„..0411 ---1 9 7as• .1-12-7/8'WED CMT RETAMR(11/20/16) I : p92' 1-2-7/8*AVA BR_NF I)=2259' 9849 1--2-7r8-AFD CRP(11/20016) I 9-5/8'CSG,474,L-80 NSCCIBTC,D=TIFEIW' 1-1 9se7 1-41 1. 9898'-9957 -12-7/Er CAMCO SAST J01,1175,60' F1Sut 2 AND 1/2 WM"ELEMENTS LEFT CH(11/17/16). 991110' 7 9962' -17'X 2-7/8'BROWN 1 8 PKR,D sr 125' . ",.4 01,7,11 ABLE TO DRIFT PASS w1220". UNABLE TO DRIFT PASS vt/2.246"CENT. 1 9976' .1-2-7/8'AVA BNG NF',ID=-2 19r BPIG MP PROFILE 2-7/8'FC MG.6.5e,1-80 RE. H 9981T LI103_Y CORRODED-ABLE TO DRIFT TIM MP 0058 bpf,D=2A41" w/2.246-CENT.(11/17)1s) 1 FERFORATION SULIARY I 9990' I-I 2-11r mho w/AV A SHEAR OUT 5113,0=2 441" REF LOG.C13L ON 09.22/8/ I I 9977' -akID TI LOGGED ON 10722/87 ANGLE AT TOP EU :32-@ 10006' No Refer b Production OB for historical perf data I SIZE SPF INTERVAL Opn/Sqz SHOT I SQZ 1-213" S 9924-9952 0 09/26/87! I 1 2/3' 6 100(16 10028 0 10/28/14i 1-2/3" S 10020-10094 0 10/22/87 I 1-213" 6 10028-10050 0 10/28/14 1 2/3'' 6 10064 10080 0 10/27/14, I 1 2/3" 0 10000-10100 0 10/27/14 1-2)3' 6 10122-10143 0 10/27/14 1 I 1-2/3' S 10124-10218 0 10022187 1-2/3" S 10143-10164 0 10/27/14 I 1-217 S 10164-10184 0 10/26/14 I li Pr -1i-TT)-1- 10354' 1 _ 440904041 7*LNR,294,L-80 BTC,.0371 bpf,D=6154- I - 10400' ---------- _ r1 2/01116 MGS/J&C SET 2-7/8'CMT FT&CBP(11/20/ 03/29)17 ivt4JND SL TAGGED TBG TOC(02/17/17)DATE 'REV BY C014,ENTS DA M ilEv BY COMENTS LJSBURPE MIT , 70/01/87 06 * 3GINAL COMPLETION 03/29/17 MRA)'REMOVED LA OAT —4 WELL: L2-10 C18/11/01- FWP OORRECTUNS 03/29)17 ..1NLAMD'ALICIE0 REEF&BF REV FERMT No: '1870850 iE -1AFI No 50-029-21746-00 -2/28/16 MDLIMD GLV C10(12/23/16) Sec 18, 111N,R15E,1439'FSL&1295'RAIL 02115/17 BTNIJMD 2 7/8'TOG PUNCH(01/31/17) 02/15/17 ACB/J1A)IA&TBG CUT(02/04/17) BP Exploration(Alaska) _ 3 • • Post Job Schematic 2-9/16"CMI FLS , AELLHEAD= FM EW STD SLM-L - L2-1 SAFETY NOTES: ACTLA TOR= BAKER C 13-3/8'1.: 4:3: — 99' OKB.HEV= 45'1 6 ,K-55 BTC 4510=12-415' ____111 REF RP) .1_11 2200' —27/8'CA MCO TRDP1A-SSA,13=231? = '' BF ELEV= 14.681 0 LOCKED OUT(01/20/16) KOP= 3200'I 21r COND. --I 11 CI-EMCAL MANDRTIS Mix Anglo= 37',i",&EGO'? i 91 54,1-4-40 ST MD IVO'DEV: TY PE VLV LATCH PORT DATE Datum16.0. 10,013':„ _ CAKBG O 1 2284 22841 1 ' - :, W BK 0 09/30/87 , 0-19.124' II Datum TVD',' 8900ssi GAS Li-i-mancrins ST MD TVOIDEV; TYPE '., VLV LATCH PORT DATE 1 . [ 13-3/8"C-SG,7214,I-80 8TC,ID=17347' I— 4099' I A I] c 2 2806 2806; 3 Mc RHO ' OW BK 0 09/30/87 3 5336 5062' 32 LERIHO ''DOi.lE BK 16 08/25/15 -, : Minimum ID = 1.875" @ 9832' 4 7360 6732 33 McF144-10 : SO BK 24 05/15/16 5 8755 7902:: 33 . MFM-1O , OW BK 0 09/30187 2 7/8"AVA BPL NIP W/BPC , ; 6 9466 8491: 36 , MFM-IO i OW BK 0 06/24/95 133(/vi to 9689' 19-5/6"X 2-7/6"AVA Fti TS-XL PKR,13-3 375' ' 144''- TOP OF 7'LNR j--I 9613' II ,- - PRODUCTION MANDRELS : m SL TAGGED IBC TOG(02i 17/17) —9651'S LA ' MD TV 0 DEV TY PE VLV LATCH PORT DA TE: P Of, ST .. I 7 *9700 8681 35 McFkitiO EMPTY BK — 112/23/16, 2-7I8'SSG PUNC:444(0"1131117) I 1[2:51:00 4P 4 k&•1 I I 4,141 •e-419- 9786' -12-7/8-WED CMT RETANER(11/20/16) I -...- I II o n• J-H2-7/8"AVA BR NP,LI=2 259' k, 9849' —2-7,6'VVFD COP(11/20e16) -....- r9-5/13;OSOr.'47-ti:L-80 Nkeiiiii-,-6.&sal. Ji---9887-;-71—A 116 Mr-9967' 2-7/8-CAMCO BLAST JONTS,60' RISK 2 AND 1/2 N 'ELEMINTS LEFT LII(11/17/16) —I 9980' 9962 —(7'X 2-7/8'BROWN 1-B PKR,I)=125' ABLE TO DRIFT PASS w/2_20"_ UNABLE TO DRIFT PASS w11245"CENT. I 9976' 1—2-7/8'AVA BNG NP,ID=2 197'ENG MP PROFILE I FC TBG,6 54,L-80 RE H 9980' 1N LIKELY CORRODED-ABLE TO DRIFT TI4LU NIP .0058 bpf,13=2.44 1' w/2.245 CENT.(11117116) i PERFORATION SUKIMARY N\\N./ I I 9980' H 2 1/8'MEG w fAV A SHEAR OUT SLB,ID=2441' FIEF LOG:CSL ON 09.22/87 9977' —ELM)[1 LOGGED ON 10/22/87 ANGLE AT TOP 8-32"cie 10006 NO Refer b Production DB for historical perf data I SIZE SPF I NIERVAL Opn/Sqz SI-UT SQZ 1-2/3' S 9924-9952 - 0 09/28/87 I 1-2/3" 6 10006-10028 0 10/28/14: 1-2/3' S 10020-10094 0 10122/87 I 1-2/T 6 10028-10050 0 10/28/14 1 2/3" 6 10064-10080 0 10/27/14;1 1-2/3', G 10000-10100 0 10/27/14!" 1-2/3' 6 10122-10143 0 10127/14i 1-2/3' S 10124-10218 0 10022/871 1-2/1- S 10143-10164 0 10027/14, I 1-2/3' S 10164-10184 0 10/26/14 I , I , I i , [ RIM 1-1-10354' 1 AilitAttik 1 7'LNR 231,L-80 BTC,.0371 bpf,ID=8.164' I 10400' -------------- DATE REV BY COMMBITS DATE 'REV BY 0016.13kI1S LISBURNE MIT 10/01/87 ORIGINAL COMPLETION 03/29/17 NI-VJMO'REMOVED IA CMT WELI: L2-10 08/11101 RN'TP CORRECTIONS 03/29/17 JNIJA.43 AIMED REF&BF EI_EV PERITT No. '1870850 12/01116 MGS/AIO SET 2-7/8'GAT RFT&CBP(11/20/ 03/29/17 M-PJM) SL TAGGED TSG TOC(02/17 f 17) API No. 50-029-21746-00 12/26/16.1BEJM)GLV 00(12/23/16) 1 __, Sec 18, T11N.R-15E 1431 FS,.&1295 FWL - . ! 02/15/17 EiTNIA13 2-7/8"TBG RICH(01/31/17) ------4 02/15/17 ACEV..11.1D IA&MG CUT(02/04/17) 13P Exploration(Alaska) , 4 • • 'om ",x :1 •e4s' .',',o..'-':.„ 1/4,1A0,0' » i v 41 + { ' s — 1 ''''''''',',' .1:':', . ., if y,A e , ,...... ...,.. , ... . ,. .., ,. .....,..... . . , f (000:,, ,i,,,, ,t,„ -.- '?"'— ,,„,-.,,,,.4 .,,,. 4 "ar N . , S.rN eMR H+e a F .a*..,., �P„ a dM. . i 5 • • Loepp, Victoria T (DOA) From: Hibbert, Michael <Michael.Hibbert@BP.com> Sent: Monday,July 10, 2017 7:42 AM To: Loepp,Victoria T(DOA) Subject: RE: PBU L2-10(PTD 187-085, Sundry 317-300) Packer Cement Squeeze Good morning Victoria, The job is designed to place the cement top at 9,536' MD. Let me know if you need any other information. Thanks, Michael Hibbert BP Alaska—Intervention&Integrity Engineer Email: Michael.Hibbert@bp.com From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Friday,July 07, 2017 1:18 PM To: Hibbert, Michael Subject: PBU L2-10(PTD 187-085, Sundry 317-300) Packer Cement Squeeze Where will the TOC be in the IA post squeeze? Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(a.alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov 1 STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMI� REPORT OF SUNDRY WELL OPERATI�RS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved/� Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well IBJ Re-enter Susp Well 0 Other:Cele' t S/queezze(fail) m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 187-085 3. Address: P.O.Box 196612 Anchorage, Development D Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21746-00-00 7. Property Designation(Lease Number): ADL 028321 8. Well Name and Number: PBU L2-10 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10404 feet Plugs measured 9651,9785,9849 feet MAR 2 true vertical 9270 feet Junk measured 9980 feet MAR 9 2017 Effective Depth: measured 9651 feet Packer measured 9569,9962 feet true vertical 8641 feet Packer true vertical 8575.8902 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 35-115 35-115 1490 470 Surface 4065 13-3/8" 34-4099 34-4028 3450/4930 1950/2670 Intermediate 9827 9-5/8" 30-9858 30-8813 6870 4760 Production Liner 787 7" 9613-10400 8611-9267 8160 7020 Perforation Depth: Measured depth: 9924-10184 feet True vertical depth: 8869-9089 feet Tubing(size,grade,measured and true vertical depth) 2-7/8"6.5#L-80 31-9980 31-8917 Packers and SSSV(type,measured and 2-7/8"AVA HydroSet Ret Packer 9569 8575 true vertical depth) 7"Brown 1-B Perm Packer 9962 8902 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JUN 1 5 20I?. Treatment descriptions including volumes used and final pressure: See Attached 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 119 1606 369 1604 525 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I! Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-591 Contact Hibbert,Michael Email Michael.Hibbert@BP.com Printed Name Joe Last ffkka i. Title Drilling Technologist SignaturerA\8 Phone +1 907 564 4091 Date 5/10 1 7 Form 10-404 Revised 5/2015 l t`' 5T 0/`7_RBDMs APR - 3 2017 Submit Original Only /7 vIA/ • • Lastufka, Joseph N From: Hibbert, Michael Sent: Wednesday, March 29, 2017 8:59 AM To: Lastufka,Joseph N Subject: L2-10 Cement Jobs Hi Joe, Here is that write-up for L2-10. Let me know if you need any further detail or clarification: BPXA requested sundry approval for a packer repair cement job on Well L2-10.The sundry was approved on 11/22/16. The repair was attempted 3 times.The first attempt was made on 11/23/16 with a Coiled Tubing cement job.A squeeze was not achieved and the packer was not repaired.The well was made ready for a second attempt,which was pumped fullbore down the tubing on 12/27/17.This job did appear to achieve some squeeze pressure but did not end up hold a cement column and the packer remained impaired.The well was then prepared for another fullbore job by punching the tubing.A third and final attempt was made on 2/24/17.This job appeared to go well, but when the well was MIT-IA'd on 2/8/17 it failed with a liquid leak rate of 1.1 bpm @ 800 psi.This well will continue to be monitored and further work will be progressed as it is risk ranked against other wells with similar failures. Thanks, Michael Hibbert BP Alaska—Intervention&Integrity Engineer nlmweIs Email: Michael.Hibbert@bp.com 1 • • Daily Report of Well Operations PBU L2-10 ACTIVITYDATE SUMMARY T/I/O = 0/VAC/VAC. Temp = SI. IA FL (eval well head leak). AL SI @ casing valve, ALP = 730 psi. IA fluid level near surface. IA has hard line to skid and OT tank. UR tank on location. SL on location at time of job. 11/17/2016 SV, WV, SSV, and MV= SLC. IA and OA= OTG. 1630. T/I/O = SSVNac/0. Temp = SI. Bleed AL line (eval wellhead leak). ALP = 2500 psi, SI @ casing & lateral valve. IA FL near surface. No visible or audible leaking from wellhead at this time. Bled AL line from 2340 psi to 300 psi in -1 min. Monitor during RD. ALP increased 60 psi, called grease crew to service AL lateral valve. 11/17/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 04:45 ***WELL S/I ON ARRIVAL***(secure well) PULLED 2-7/8"WFD WRP FROM 9788' MD.(missing 1.5 elements) PULLED BPC FROM 9832' MD.(only missing 1 0-Ring of 4 ) 11/17/2016 ***CONT ON 11-18-16 WSR*** ***CONT FROM 11-17-16 WSR*** RAN 2.20" CENT AND PASSED THRU THE 2.197" NIPPLE @ 9976' MD, STOPPED AT 9980' SLM (9998' MD) RAN 2.245" CENT, SD AT 9963' SLM, UNABLE TO GET DEEPER. RAN 2.20" CENT AND TEL, LOCATED TTL AT 9963' SLM 11/18/2016 **WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** T/I/O =Vac/Vac/0. Temp = SI. WHP's & IA FL. (Eval WH Leak). ALP = 520 psi & SI @ IA casing valve. Unable to get IA FL due to hard vac. No change in WHP's overnight. ALP increased 160 psi overnight. 11/18/2016 Slick line in control of WH Valves. 04:15 ***WELL S/I ON ARRIVAL SWCP 4518***(cement squeeze) DRIFT W/2.30" &TAG AVA BPL NIP @ 9815' SLM FOR A 17' CORRECTION (9832' MD). 11/19/2016 ***CONTINUE WSR TO 11/20/16*** T/I/O =Vac/40/0. Temp = SI. Monitor WHP's (Eval WH Leak). IAP increased 30 psi since 05;25 this morning. ALP = 220 psi & SI @ IA casing valve. IA FL @ 2555' (167 bbl). Slickline on location to rig up. WV, SV, SSV= C. MV= O. IA, OA= OTG. 18:00. 11/19/2016 11/19/2016 Road to Location. Coninue on 11/20/16 T/I/0 = SSV/10/0. Temp = SI. IA FL. (Eval WH Leak). ALP = 220 psi & SI @ IA casing valve. IA FL @ 2611', (171 bbl). 11/19/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 05:25 T/I/O = SSV/60/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 40 psi, AL SI @ casing & lateral valve. IA FL @ 2611' (171 Bbls). Monitor well head flange for leak. 11/20/2016 **WSR continued on 11-21-2016. ***CONTINUE WSR FROM 11/19/16 SWCP 4518***(cement squeeze) SET COMPOSITE BRIGE PLUG(od =2.13")...STOP @ 9832' SLM(9849' MD) RAN 2.30" G-RING, TAGGED AVA BPL NIP @ 9815' SLM (9832' MD) (+17' correction) SET WFD CEMENT RETAINER (2.19" od) @ 9768' SLM (9785' MD) LRS PERFORM PASSING PRESSURE TEST TO 1000psi 11/20/2016 ***WELL LEFT S/I DSO NOTIFIED ON DEPARTURE*** • • Daily Report of Well Operations PBU L2-10 T/I/O = 100/60/0. Temp = SI. IA FL. (Eval WH Leak). ALP = 50 psi & SI @ IA casing valve. IA FL @ 2611', (171 bbl). Hard line rigged up from TBG and IA to OT tank. UR tanks on location. Gass for shooting FL is available on #06, #14. 11/20/2016 S/L in control of well upon departure. IA, OA= OTG. 1630. ***Job continued from 11-19-16 WSR*** T/I/O=0/55/6 SI Pumped 3 bbls Meth down TBG, followed by 90 bbls of DSL to load for SL. Pumped 11.66 bbls for pressure test on cement retainer. PT'd to 1029 psi, see log for details. Tag hung on MV SLB SL on well upon 11/20/2016 departure CVs OTG FWHP=100/60/5 T/I/O = SSV/60/0. Temp = SI. IA FL. (Eval WH Leak). ALP = 85 psi & SI @ IA casing valve. IA FL @ 2611', (171 bbl). S/L in control of well upon departure. 05:10 11/20/2016 **WSR continued from 11-20-2016. T/I/O = SSV/60/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP =40 psi, AL SI @ casing & lateral valve. IA FL @ 2611' (171 Bbls). Monitor well head flange for leak. 11/21/2016 ***WSR Continued on 11/22/16.*** **WSR continued from 11-21-2016. T/I/O = SSV/60/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 40 psi, AL SI @ casing & lateral valve. IA FL @ 2611' (171 bbls). Monitored well head flange for leak until coil arrived on location. SV, WV, SSV= C. MV= O. IA, OA= OTG. 23:00 11/22/2016 CTU # 14 - 1.75" Coil Job Objective: Packer/IA Cement Squeeze MIRU CTU. 11/22/2016 ...Continued on WSR 11-23-16... CTU #14 - 1.75" Coil ***Cont.from WSR 11-22-16*** Job Objective: Packer and IA Cement Squeeze MIRU CTU. 11/23/2016 ...Job in Progress... CTU #14 - 1.75" Coil ***Cont.from WSR 11-22-16*** Job Objective: Packer and IA Cement Squeeze MIRU CTU. Make Up WFT Cement Stinger assembly and RIH. PT tubing to 1000 psi, OK. RIH and load IA with 465 bbls of diesel at 4.8 bpm. Pump 117 bbls of 15.8 ppg Class G Cement(115 bbl behind pipe) no response to IA pressure. Fluid level dropped and never reached surface during cement job. DHD shot level after 50 bbls put behind pipe and level was @ 1450' (94.5 bbls). 11/23/2016 ...Job Complete CTU #14 - 1.75" Coil ***Cont.from WSR 11-22-16*** Job Objective: Packer and IA Cement Squeeze MIRU CTU. Make Up WFT Cement Stinger assembly and RIH. PT tubing to 1000 psi, OK. RIH and load IA with diesel at 4.8 bpm. 11/23/2016 ...Job in Progress T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI @ CV. Monitored well head flange for leaks. 11/23/2016 ***WSR Continued on 11/24/16. • • Daily Report of Well Operations PBU L2-10 III ***WSR Continued from 11/23/16.*** T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP 11/24/2016 SI @ CV. Monitored well head flange for leaks. Continued on WSR 11-25-16. ***WSR Continued from 11/24/16.*** T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI @ CV. TBG FL = near surface. IA FL = 1600' (104 bbls). Monitored well head flange for leaks. 11/25/2016 ***Continued on WSR 11-26-16.*** T/I/O=0/0/0 Temp= SI (MIT-IA post Cement Squeeze) Pump 3 bbls Meth Spear down IA, 11/25/2016 followed by 30 bbls crude. ***Job continues 11-26-16*** ***WSR Continued from 11/25/16.*** T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI @ CV. TBG FL = near surface. IA FL = 1600' (104 bbls). Monitored well head flange for 11/26/2016 leaks. Continued on WSR 11-27-16. ***Job continued from 11-25-16*** (Post Cement Squeeze) MIT IA to 2500 psi. ***FAIL*** Pump 220 bbls crude (250 total) down IA. Crude was chosen (over diesel) because coil prefers a fluid packed IA for a cement squeeze, but the IA would not support a column of diesel. Never reached test pressure, Established a LLR of-4.75 bpm @ 800 psi. (see log for 11/26/2016 details). Hang caution tags, Notify DSO, SV,WV,SSV,AL=closed MV=open, IA/OA=OTG. ***WSR Continued from 11/26/16.*** T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI @ CV. TBG FL = near surface. IA FL = 1600' (104 bbls). Monitored well head flange for leaks. 11/27/2016 ***WSR Continued on 11/28/16.*** ***WSR Continued from 11/27/16.*** T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI @ CV. TBG FL = near surface. IA FL = 1600' (104 bbls). Monitored well head flange for 11/28/2016 leaks. ***WSR Continued from 11/27/16.*** T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI © CV. TBG FL = near surface. IA FL = 1600' (104 bbls). Monitored well head flange for leaks. 11/28/2016 ***WSR Continued on 11/29/16.*** ***WSR Continued from 11/28/16.*** T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI @ CV. TBG FL = near surface. IA FL = 1600' (104 bbls). Monitored well head flange for leaks. 11/29/2016 Cont on WSR 11/30/16 Cont from WSR 11/29/16. T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI @ CV. TBG FL = near surface. IA FL = 1600' (104 bbls). Monitored well head flange for leaks. 11/30/2016 Cont on WSR 12/1/16. ***WSR Continued from 11-30-16.*** T/I/O = SSVNac/0. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 30 psi, ALP SI @ CV. TBG FL = near surface. IA FL = 1600' (104 bbls). Monitored well head flange for leaks, no LEL%. 12/1/2016 ***WSR Continued on 12/2/16 • • Daily Report of Well Operations PBU L2-10 ***WSR Continued from 12-01-16.*** T/I/O = SSV/Vac/Vac. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 0 psi, AL SI @ CV. Monitored well head flange for leaks & LEL readings. No signs of leaks on well head. 0% LELs detected through out wellhouse. 12/2/2016 ***WSR Continued on 12/3/16.*** ***WSR Continued from 12-02-16.*** T/I/O = SSV/VacNac. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 0 psi, AL SI @ CV. Monitored well head flange for leaks & LEL readings. No signs of leaks on well head. 0% LELs detected through out wellhouse. 12/3/2016 Cont on WSR 12/4/16. Cont from WSR 12/3/16. T/I/O = SSV/VacNac. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 0 psi, AL SI @ CV. Monitored well head flange for leaks& LEL readings. No signs of leaks on well head. 0% LELs detected through out wellhouse. 12/4/2016 Cont on WSR 12/5/16. Cont from WSR 12/4/16. T/I/O = SSVNacNac. Temp = SI. Monitor well (eval wellhead flange leak). ALP = 0 psi, AL SI @ CV. Monitored well head flange for leaks & LEL readings. No signs of leaks on well head. 0% LELs detected through out wellhouse. Continuous monitoring no longer needed. Final WHPs = SSVNacNac. SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:30. 12/5/2016 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (eval flange leak). ALP = 20 psi, SI @ CV. No signs of leaks on well head. 0% LELs detected throughout well house. 12/6/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 03:00 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on well head. All atmospheric readings are normal on wellhead and throughout well house. 12/6/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 03:30 T/I/O = SSV/Vac/Vac. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ casing valve. No sign of leaks on well head. 0% LELs. 12/6/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 21:00 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on well head. All atmospheric readings are normal on wellhead and throughout well house. 12/7/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 03:40 T/I/O = SSVNac/Vac. Temp = SI. WHPs & LEL's (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on well head. 0% LELs detected throughout well house. 12/7/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 03:40 T/I/O = SSVNACNAC. Temp = SI. WHPs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. 0% LEL detected throughout wellhouse. 12/7/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 21:00 T/I/O = SSVNacNac. Temp = SI. WHPs & LEL's (Eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on well head. 0% LELs detected throughout well house. 12/7/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 11:20. T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI © CV. No signs of leaks on wellhead. 0% LEL detected throughout wellhouse. 12/8/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 03:00 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. 0% LEL detected throughout wellhouse. 12/8/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 21:00 • • Daily Report of Well Operations PBU L2-10 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on well head. All atmospheric readings are normal on wellhead and throughout well house. 12/8/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:00. T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on well head. All atmospheric readings are normal on wellhead and throughout well house. 12/8/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 09":50. T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. 0% LEL detected throughout wellhouse. SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:00. 12/9/2016 T/I/O = SSVNac/Vac. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on well head. All atmospheric readings are normal on well head and throughout well house. 12/9/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 03:30 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. 0% LEL detected throughout wellhouse. 12/9/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 09:30. T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No sign of leaks on wellhead. 0% LEL throughout wellhouse. 12/10/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 03:30 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No sign of leaks on wellhead. 0% LEL throughout wellhouse. SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:00. 12/10/2016 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. 0% LEL detected throughout wellhouse. SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:55.. 12/11/2016 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No sign of leaking on wellhead. 0% LEL throughout wellhouse. 12/11/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 04:30 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaking on wellhead. 0% LEL on wellhead and throughout wellhouse. 12/12/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 10:30. T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, AL SI @ casing valve. No signs of leaking on well head. 0% LEL on well head and throughout well house @ this time. 12/13/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 22:00 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No sign of leaking on wellhead. 0% LEL throughout wellhouse. SV, WV, SSV= C. MV= O. IA, OA= OTG. 17:15. 12/14/2016 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No sign of leaking on wellhead. 0% LEL throughout wellhouse. 12/15/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG 05:00 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, SI @ CV No sign of leaks on wellhead. No LEL throughout wellhouse. 12/15/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 14:00 • Daily Report of Well Operations PBU L2-10 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, AL SI @ casing valve. No signs of leaking on well head. 0% LEL on well head and throughout well house @ this time. 12/15/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 23:15 T/I/0 = SSVNacNac. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, SI @ CV. No sign of leaks on wellhead. No LEL throughout wellhouse. SV, WV, SSV= C. MV= O. IA, OA= OTG. 15:00 12/16/2016 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, SI @ casing valve. No sign of leaks on wellhead. No LELs throughout wellhouse. 12/19/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 05:15 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, AL SI @ casing valve. No sign of leaks on wellhead. No LELs throughout wellhouse. SV, WV, SSV= C. MV= O. IA, OA= OTG. 22:00 12/20/2016 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout. 12/20/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 14:00 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, AL SI @ casing valve. No sign of leaks on wellhead. No LELs throughout wellhouse. 12/20/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 05:05 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs. (eval flange leak). ALP = 0 psi, SI @ IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout. 12/21/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 20:00 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs. (eval flange leak). ALP = 0 psi, SI @ IA Casing valve. No change in WHP's. No signs of leaks on wellhead. No LELs detected throughout. 12/22/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 19:30 ***WELL SHUT-IN ON ARRIVAL***(secure) RIG UP HES UNIT 214 12/22/2016 ***CONT. WSR ON 12/23/16*** T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs. (eval flange leak). ALP = 0 psi, SI @ IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout. 12/23/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 15:45 ***CONT. WSR FROM 12/22/16*** (secure) DRIFT TBG W/ BARBELLED 1.80" LIB TO CEMENT RETAINER AT 9,780' SLM (9,785' MD) PULLED STA. #7 BK-DGLV FROM 9,695' SLM (9,700' MD) 12/23/2016 ***WELL LEFT SHUT-IN ON DEPARTURE, DSO NOTIFIED*** T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs. (eval flange leak). ALP = 0 psi, SI @ IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout. 12/24/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 17:00 T/I/O = SSVNACNAC. Temp = SI. WHPs & LELs (eval flange leak). ALP = 0 psi, SI @ IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout. 12/25/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 09:00 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs. (Eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout. 12/26/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 10:15 12/26/2016 LRS Unit 42 - Heat 130 bbls diesel on CH2 Vac Truck#86095 from 40*to 90* • • Daily Report of Well Operations PBU L2-10 HES Cementing: Job Scope: Cement Squeeze for Secure: MIRU HES cement van and bulk trucks. Initial IA fluid level at 1925'. Pump 10 bbls 60/40 McOH spear, 92 bbls 1% KCL, 10 bbls fresh water, 50 bbls neat Class"G" cement, 5 Bbls fresh water to launch 2 -6"foam wiper balls, 5 bbls 60/40 spear, and 44 bbls 90 degree diesel for displacement. Observe pressure bump to 440 psi after displacing 40 bbls of cement, but it was not squeezing off. Shut down pumps, treating pressure dropped to 0 psi. Final IA fluid level at 400'. RDMO. 12/27/2016 Initial and Final T/I/O = 0/0/0 psi ***Job Complete*** T/I/O = 0/Vac/Vac. Temp = SI. Cement job (assist SP). ALP = 0 psi, SI @ CV. IA FL @ 1926' (126 bbls). Monitored WHPs & IA FL during cement pumping OPS. Monitored for 1 hr. IA FL @ 990' (64.5 bbls). Final WHPs= ONacNac. 12/27/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 14:30 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, SI @ IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout. 12/30/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 15:30 TWO = SSVNacNac. Temp = SI. IA FL (FB Request). ALP = 0 psi, SI @ IA Casing valve. IA FL @ 1280' (83.5 bbls). 12/31/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 16:40 T/1/0=0/0/0 Temp=S/I (LRS Unit 76 - MIT-IA Post Cement) Drove to location, standby on snow removal. 12/31/2016 ***Job Continued on 01-01-17*** T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, SI @ IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout. 12/31/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 15:45 ***Job Continued from 12-31-16*** (LRS Unit 76 - MIT-IA Post Cement) MIT-IA***Failed***to 2600 psi. (Secure Well) Target pressure = 2500 psi. Max applied pressure=2650 psi. Pumped 95 bbls of 120*crude down IA to load. Caught pressure on IA and TBG started tracking. IA lost 2600 psi in 6 min. LLR of 2.75 bpm @ 2600 psi. by pumping an additional 35 bbls of 120*crude down IA. LLR of 1.7 bpm @ 800 psi by pumping an additional 20 bbls of 120*crude down IA. T/IA on vac. Tags hung DSO notified. 1/1/2017 Final T/I/O=vac/vac/9 psi. T/I/O = SSVNac/10. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout. 1/1/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 08:00 T/I/O = SSVNac/10. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout. 1/1/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 08:00 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 100 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout. Halliburton SL in control of well on departure. 14:50. 1/4/2017 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 100 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout well house. SV, WV, SSV= C. MV= 0. IA, OA= OTG. 15:15 1/6/2017 ***WELL S/I ON ARRIVAL***(secure well) RAN 3' x 1.5" STEM, 1 3/4;; SAMPLE BAILER TO 9698' SLM; SAMPLE OF ORANGE SPONGE AND SMALL AMOUNT OF CEMENT RAN 5'x 1 3/4" DD-BAILER TO 9698' SLM; NO SAMPLE RAN 5' x 1.5" DD- BAILER TO 9698' SLM; ORANGE SPONGE, NO CEMENT 1/6/2017 ***CONTINUED TO 1/7/17 WSR*** • • Daily Report of Well Operations PBU L2-10 ***CONTINUED FROM 1/6/17 WSR***(secure well) RIG DOWN HALLIBURTON SLICKLINE UNIT 214, ( WINDS OVER 35 MPH ) 1/7/2017 ***WELL LEFT S/I ON DEPARTURE*** T/I/O = SSVNacNac. Temp = SI. WHPs & LELs (Eval flange leak). ALP = 100 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout well house. 1/8/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 13:30. T/I/O = SSVNacNac. Temp= SI. WHPs & LELs (Eval flange leak). ALP = 100 psi, SI © CV. No signs of leaks on wellhead. No LELs detected throughout well house. 1/10/2017 SV, WV, SSV= C. MV= O. IA, OA = OTG. 03:40 T/I/O = SSVNacNac. Temp = SI. WHPs & LELs. (Eval flange leak). ALP = 100 psi, SI © IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout well house. 1/10/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG 19:45 T/I/O = SSVNacNac. Temp = SI. WHPs (Eval flange leak). AL SI @ casing valve (0 psi). No change in the LELs or WHPs since 1-10-16. 1/12/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 1120 hrs. T/I/O = SSVNacNac. Temp = SI. WHPs (Eval flange leak). AL SI @ casing valve (0 psi). No change in the LELs or WHPs since 1-12-17. SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 09:30. 1/13/2017 T/I/O = SSVNACNAC Temp=SI. WHPs and LELs (Eval flange leak). AL SI @ casing valve ( 0 psi). No signs of leaks on wellhead. No LELs detected throughout wellhouse. 1/14/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 0930hrs. T/I/O = SSVNACNAC Temp=SI. WHPs and LELs (Eval flange leak). AL SI @ casing valve ( 0 psi). No signs of leaks on wellhead. No LELs detected throughout wellhouse. WHP's unchanged since 1/14/17. SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 13:30. 1/15/2017 T/I/O = SSVNacNac. Temp=Sl. WHPs and LELs (Eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout wellhouse. WHP's unchanged overnight. SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 16:20 1/16/2017 T/I/O = SSVNacNac. Temp=SI. WHPs and LELs (Eval flange leak). ALP = 0 psi & SI @ IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout wellhouse. WHP's unchanged overnight. 1/19/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 04:40 T/I/O = SSVNacNac. Temp=SI. WHPs and LELs (Eval flange leak). ALP = 0 psi & SI @ IA Casing valve. No signs of leaks on wellhead. No LELs detected throughout wellhouse. WHP's unchanged overnight. 1/19/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 21:20 T/I/O = SSVNacNac. Temp = SI. WHPs & LEL's (eval flange leak). ALP = 0 psi & SI @ IA casing valve. No signs of leaks on wellhead. No LEL's detected throughout wellhouse. WHP's unchanged overnight. 1/20/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 19:50 T/I/O = SSVNac/Vac. Temp = SI. WHPs & LEL's (eval flange leak). ALP = 0 psi & SI © IA casing valve. No signs of leaks on wellhead. No LEL's detected throughout wellhouse. WHP's unchanged overnight. 1/21/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 20:00 • • Daily Report of Well Operations PBU L2-10 T/I/O = SSVNacNac. Temp = SI. WHPs (Eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LEL's detected throughout wellhouse. WHP's unchanged overnight. SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 11:20 1/22/2017 T/I/O = SSVNACNAC. Temp = SI. WHPs (Eval flange leak). ALP = 0 psi, AL SI @ casing valve. No signs of leaks on wellhead @ this time. No LEL's detected throughout wellhouse. WHPs unchanged overnight. 1/24/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 01:50 T/I/O = SSVNACNAC. Temp = SI. WHPs (Eval flange leak). ALP = 0 psi, AL SI @ casing valve. No signs of leaks on wellhead @ this time. No LEL's detected throughout wellhouse. WHPs unchanged overnight. SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 15:45 1/24/2017 T/I/O = SSVNacNac. Temp = SI. WHPs (Eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LEL's detected throughout wellhouse. WHP's unchanged since 1/24/17. SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 16:00 1/26/2017 T/I/O = SSVNacNac. Temp = SI. WHPs (eval flange leak). ALP = 0 psi, SI @ casing valve. No signs of leaks on wellhead. No LEL's detected throughout wellhouse. WHPs unchanged since 01-26-2017. 1/28/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 01:30 T/I/O = SSVNacNac. Temp = SI. WHPs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout wellhouse. WHPs unchanged since 01- 28-2017. 1/29/2017 SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 16:20 ***STARTED 31-JAN-2017***(SLB ELINE UNIT 2362 -TUBING PUNCH) WELL SI ON ARRIVAL. PAD OP NOTIFIED. RU. TAGGED AT 9704'; FIRST COLLAR ABOVE CEMENT SEEN AT 9668'. RIH W/ HEAD/ERS/SWIVEL/WEIGHT(x2)/GR/CCL/MPD/1.56"x 2' TUBING PUNCHER LOADED 4 SPF WITH SMALL CHARGES/BOW SPRING DECENTRALIZER. OAW= 233LBS; MAX OD = 1.69"; OAL= 31'. SHOT TUBING PUNCHER FROM 9667' - 9669'. ; CCL TO TS = 8.6'; CCL STOP DEPTH = 9658.4'. CORRELATED TO 2-7/8"TUBING TALLY DATED 29-SEP-1987. 1/31/2017 ***JOB CONTINUED 1-FEB-2017*** T/I/O = SSVNACNAC. Temp = SI. WHPs (eval flange leak). ALP = 0 psi, SI © CV. No signs of leaking from WH. 0% LEL deected @ WH and throughout wellhouse. WHPs unchanged from 1/29/17. 1/31/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 01:30 1/31/2017 Assist E-Line. Test circulation threw tbg punch. **WSR continued on 2-1-17** **WSR continued from 1-31-17**T/I/O=0/0/2 Temp=Sl Assist E-Line. Test injectivity thru tbg punch. Pumped 1 bbls of methanol and 71 bbls of crude down the tbg to test injectivity thru 2/1/2017 tbg punch. FWHP=0/0/6 E-Line still on well upon departure. T/I/O = SSVNACNAC. Temp = SI. WHPs (eval flange leak). ALP = 0 psi, AL SI @ casing valve. No signs of leak @ this time. 2/1/2017 SV, WV, SSV= C. MV= O. IA, OA = OTG. 21:15 I • • Daily Report of Well Operations PBU L2-10 ***JOB CONTINUED FROM 31-JAN-2017**(SLB ELINE UNIT 2362 -TUBING PUNCH) TUBING PUNCH CONFIRMED SHOT AT SURFACE LRS PERFORMED INJECTIVITY TEST TO VERIFY FLOW PATH. SEE LRS PUMPING REPORT FOR DETAILS. LRS CONFIRMED COMMUNICATION. RD LRS RD ELINE. WELL SI ON DEPARTURE. PAD OP NOTIFIED. FINAL T/I/O =VAC/0/0. 2/1/2017 ***JOB COMPLETE 1-FEB-2017*** T/I/O = SSVNACNAC. Temp = SI. WHPs (eval flange leak). ALP = 0 psi, AL SI @ casing valve. P sub, choke tlr and return tank R/U for cement job. No signs of leak @ this time. WHPs un changed since 2/1/17 2/2/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 11:30 LRS Unit 70 -Assist Special Projects: Heat Diesel Pre Cement Squeeze 2/3/2017 Heat 100 bbls diesel on CH2 Vac truck#86057 to 90* T/I/O = SSVNACNAC. Temp = SI. Assist SP w/Packer squeeze. Assisted Halliburton w/Packer squeeze. 2/4/2017 Halliburton in control of well. HES Cementing: Job Scope-Cement squeeze for secure. MIRU HES. Confirm wing valve jug tight, WC Drill, Starting FL in IA 2670'. Intenionally leave void in IA to minimize hydrostatic overbalance. Pump down tbg - 10b 60/40, 27b 3% KCL, 160b 3% KCI w/ .25 ppg CrystalSeal (1500 lbs), 10b FW spacer, 50b 15.8 cement w/o fluid loss additives, 3b FW Spacer, launch two 6" balls, 8b FW spacer, and 46b diesel. Est TOC in Tbg 9355' (311' above tbg punch holes @ 9667') Est TOC in IA 9276'. 11 b cement in formation. 2300 psi rolling squeeze. placed -25b below tbg punch holes into annulus and —25b above. Request tree valves serviced tonight and FL shot after 24 hrs. IA pressure increased from 0 to 2500 psi @ 90b CrystalSeal in formation -take returns/partial returns to keep IA below max press of 2500 psi. Gaseous crude returns to surface. Able to close chk completely 41 bbls before cement @ perfs (27b before cement to tbg punch holes) Unable to shoot final fluid levels. Appx 30b crude returns in OT. Note CrystalSeal returns taken up IA- possible that as much as 44 bbbls in IA followed 25b cement CrystalSeal could be as high as 8600' in IA(150' above GLM#5) Will recommend that we circulate CrystalSeal out of IA before returning to production. 2/4/2017 ***Job Complete*** T/I/O = SSVNACNAC. Temp = SI. WHPs (eval flange leak). ALP = 0 psi, AL SI @ casing valve. P&A rigged up from tree cap & IA to choke trailer& return tank R/U for cement job. No signs of leak @ this time. WHPs unchanged since 02-02-2017. SV, WV, SSV= C. MV= 0. IA, OA= OTG. 05:15 2/4/2017 T/1/0= vac/vac/vac Temp= S/I. (LRS Unit 70 - MIT-IA Post Cement Squeeze) Load diesel, pick up procedure, travel to location, RU/PT 2/7/2017 ***Job Continued on 02-08-17*** ***WSR continued from 02-07-17*** (LRS Unit 70 - MIT-IA Post Cement Squeeze) MIT-IA FAILED to 2500 psi, Max Applied Pressure = 2750 psi, Target Pressure = 2500 psi. Pressured TBG to 2750 psi with 150 bbls diesel. IA lost 2750 psi in 1st 15 minutes and 0 psi in 2nd 15 minutes, for a total loss of 2750 psi during 30 minute test. LLR of 1.10 bpm @ 800 psi. Valve postions: WV, SV, SSV= closed; MV= open. Casing valves= OTG's. All hardline valves= closed. 2/8/2017 FWHP's-20/-23/-14 • • Daily Report of Well Operations PBU L2-10 T/I/O = SSVNacNac. Temp = SI. WHPs (eval flange leak). ALP = 0 psi, SI @ CV. No signs of leaks on wellhead. No LELs detected throughout wellhouse. SV, SSV= C. WV= LOTO. MV= O. IA, OA= OTG. 16:45. 2/9/2017 T/I/O = SSVNACNAC. Temp = SI. IA FL (Special Projects Request). IA FL @ 2430' (159 bbls). 2/9/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 17:00. T/I/O = SSVNacNac. Temp = SI°. WHPs (eval flange leak). ALP = 0 psi, SI @ casing valve. IAP & OAP unchanged from 02/09/2017. No visible or audible leaks on the wellhead. Atmospheric conditions are normal around well head flanges and inside of wellhouse. 2/11/2017 SV, WV, SSV= C. MV= O. IA, OA = OTG. 15:30. ***WELL SHUT IN ON ARRIVAL*** (Secure Well) DRIFT W/2.27" CENT & 1.5" SMPL BLR, TAG @ 9651' SLM (recovered peice of wiper ball). 2/16/2017 ***WELL TURNED OVER TO DSO*** TWO = SSVNacNac. Temp = SI°. WHPs (eval flange leak). ALP = 0 psi, SI ©casing valve. IAP & OAP unchanged from 02/11/2017. No visible or audible leaks on the wellhead. Atmospheric conditions are normal around well head flanges and inside of wellhouse. 2/17/2017 SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:10. T/I/O = SSVNacNac. Temp= SI. WHPs (eval flange leak). ALP = 0 psi, SI @ casing valve. IAP & OAP unchanged from 02/17/2017. No visible or audible leaks on the wellhead. Atmospheric readings are normal around well head flanges and all areas inside wellhouse. 2/24/2017 SV, WV, SSV= C. MV= O. IA, OA = OTG. 13:40. T/I/O = SSVNacNac. Temp = SI. WHP's. (Eval Flange leak). ALP = 0 psi & SI @ IA Casing valve. No Change in WHP's since 2-24-17. No signs of leaks on WH. 0% LEL throughout entire wellhouse. 3/7/2017 SV, WV, SSV= C. MV= O. IA, OA = OTG. 04:25 T/I/O = SSVNacNac. Temp = SI. WHP's. (Eval Flange leak). ALP = 0 psi, SI @ CV. No Change in WHP's since 3-7-17. No signs of leaks on WH. Atmospheric readings are normal at flanges &throughout wellhouse. 3/13/2017 SV, WV, SSV= C. MV= O. IA, OA = OTG. 08:00. T/I/O = SSVNacNac. Temp = SI. WHPs (Eval flange leak). ALP SI @ CV, ALP = 0 psi. No change in WHPs since 3/13/17. No signs of leaks on WH. Atmospheric readings are normal at flanges &throughout wellhouse. 3/19/2017 SV, WV, SSV= C. MV= O. IA, OA = OTG. 10:20 TREE= 2-9/16"CNV FLS L2- � � o WELLHEAD= FMC NEW STD SLIM_ - NOTES: ACTUATOR= BAKER C 13- G —I 99' OKB.ELEV— 45' 68#,K-55 BTC _ —� 4g D=12-415" 2200' J—2-7/8"CAMCO TRDP1A-SSA,U=2312" LOCKED OUT(01/20/16) .&-.-11-.E.\77-;--- 14.68' 0 KOP= 3200' 20"cow, —115' CHEMICAL AL MASS Max Angle= _ 37°@ 6600' 915#,H.40 I ST MD f DEV TY FE VLV LATCH PORT DATE I Datum MD= 10,013' ID=19.124"+ C 1 2284 2284 1 CA-KBG DMY BK 0 09/30/871 roatum TVD= -69-667-§§- D GAS LET MANDRELS ST DEV TYFE VLV LATCH PORT DATE LI. 2 2806 2806 3 McFM 10 DMK BK 0 09!30187 13-3/8"CSG,72#,L-80 BTC,D=12.347" —( 4099' 3 5336 5062 32 McFM-IO DOME BK 16 08/25/15 Minimum ID = 1.875" @ 9832' 4 7360 6732 33 McFMHO SO BK 24 05/15/16 2 7/8°° AVA BPL NIP W/BPC 5 8755 7902 33 McFM1O DMY BK 0 09/30/87 6 9466 8491 36 Kt FM-10 DMY BK 0 06/24/95 X 9669' H9-5/8"X 2-7/8"AVA RHS-XL FCR,ID=3.375" TOP OF 7"LNR —I 9613' PRODUCTION MANDRELS SL TAGGED TBG TOC(02/17/17) — 9651'SLM ST MD 83><'�, DEV TYPE VLV LATCH PORT DATE 7 9700 8681 35 McFMHO EMPTY BK — 12/23/16 2-7/8"TBC PUNCH(01/31/17) I— 9687'-9669' tit' ;le 9786' —I2-7/8"WFDCMT RETANER(11/20/16) i ' 9832' H2-7/8"AVA BPL NP,D=2.259" .' 9849' H2-7/8"WFD CBP(11/20/16) 9-5/8"CSG,47#,L-80 NSCC/BTC,D=8.681" H 9867' J---4 I I 9898'-9957" H2-7/8"CAMCON BLASTJOTS,60' FISH:2 AND 1/2 WRP ELEMENTS LEFT DH(11/17/16). — 9980' R 9962' H 7"X 2-7/8"BROWN 1-B PKR,D=3.25" ABLE TO DRIFT PASS w/2.20". UNABLE TO DRIFT PASS w/2.245"CENT. ' , 9976' —2-7/8"AVA BNG NP,D=2.197"BNG NIP PRORLE 2-7/8"PC TBG,6.5#,L-80 EUE, H 9980' LIKELY CORRODED-ABLE TO DRIFT THRU NIP .0058 bpf,ID=2.441" w/2.245"CENT.(11117116) NPERFORATION SUMMARY / 1 I 9980' —{2-7/8"WLEG w/AVA SHEAR OUT SUB,D=2.441" REF LOG:CBL ON 09/22/87 ANGLE AT TOP PBS:32°@ 10006' I 9977' ELMD TT LOGGED ON 10/22/87 Note:Refer to Production DB for historical perf data I SIZE SFF INTERVAL Opn/Sqz SHOT SQZ 1-2/3" S 9924-9952 0 09/28/87 I 1-2/3' 6 10006-10028 0 10/28/14 1-2/3" S 10020-10094 0 10/22/87 I 1-2/3" 6 10028-10050 0 10/28/14 1-2/3" 6 10064-10080 0 10/27/14 I 1-2/3" 6 10080-10100 0 10/27/14 1-2/3" 6 10122-10143 0 10/27/14 I 1-2/3" S 10124-10218 0 10/22/87 1-2/3" S 10143-10164 0 10/27/14 I 1-2/3" S 10164-10184 0 10/26/14 I PBTD --I 10354' 111111111111111 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" — 10400' 6.1.4•41•44A DATE REV BY COMvENTS DATE REV BY C O ?vE NTS LISBURNE MIT 10/01/87 ORIGINAL COMPLETION 03/29/17 M-YJMD REMOVED IA CMI WELL: L2-10 08/11/01 RNITP CORRECTIONS 03/29/17 JUAN)ADDED REF&BF ELEV FERMI No: '1870850 12/01/16 MGS/JMJ SET 2-7/8"CMT RET&GBP(11/20/ 03/29/17 M-YJMD SL TAGGED TBG TOC(02/17/17) API No: 50-029-21746-00 12/28/16 TBLYJMtD GLV C/O(12/23/16) Sec. 18,T11N,R15E,1439'FSL&1295 FWL 02/15/17 BTWJM)2-7/8"TBG PUNCH(01/31/17) 02/15/17 ACB/JMJ IA&TBG CMT(02/04/17) BP Exploration(Alaska) LP � ti i (W 7 r p •- •- x •CU (139 CD_oz O E N CI �O �// N L 'a O 4, ANYCC VI (0 -0 r0 f9 H QJ z N U 0 E > P 111 0 cc `° C C + a, O v a a c C — (� �.,, ro L y_., -p ¢ a 0 s Ou N Q j Q Q tO ., v E o Q m L7 7 J C a) U ¢ >c, 0 L1 E +, L 'p O I O z d a @ lA ,,, D 4- C v) a o U O U a tx v >1) v o C ;.H a3, u +� CO 0 G 0 0 C ^ U w J J 0 a1 0 '". y W W_ W v vl L v o F I LL LL O ¢ a >5 a) Z Co I- < J J Q ¢ N vi C w 't O m ¢ 2 z z u ro a) O C pdCDp > a) 44v ra O E c u J � w{i izi v, a Cli v . , `° 0 C o ou ;.o _ O 4 u ci. C~ O C co 0.m Q as aa 0 rts � > No a L O , JW N a a ,CN O E = E, 0 112 U i H LU U b m a) o co a y N 1 x ! w °' ' �Q iv j a' £ J J , 7 M S m � � � � � ramLIJ Ui Z w Q 2 all ZZ \% ¢. w W z 0 > > 0 �o m m w � � � . Ci w J J +- H a. ..ro O Q WU W .1rNt tto xoo N ( ' 0 0 .- 0 m rn °' �. coo E co cm 0 V N CO5 rd al Q LU CO o W CJ 0 0 C co V a W d CO u 0 oo C o O Q h CO r ln +cc. _ S" > ts4 N N N C m 6 rA rT LA C p C O 01 O O O c 4 C an N UUi O. 'Yco O w Cv w M ~ZI �j � u C E O ti .122 Z 0cu 1 ,,,¢ v C 04 Y aJ C -0 N _ 0 NCC N 14 . N N ro u J los O. Q N _r 3 J _1 C Z a) 'O U fig L `u C y+ O 0 y a` Re I ca - ai c CO u n Fy a a m m vof TSF • 14 I//7.(s• THE STATE Alaska Oil and Gas -s em p f A LA S KA Conservation Commission 333 West Seventh Avenue x'— GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Michael Hibbert Well Interventions EngineerFEB 2 i! `.v 1`, BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L2-10 Permit to Drill Number: 187-085 Sundry Number: 316-591 Dear Mr. Hibbert: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair Kot- DATED this�day of November,2016. RIBDMMIS (, NOV 2 8 2013 STATE OF ALASKA *ALASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROVIk 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well RI • Operations shutdown❑ Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing ❑ Other Cement Squeeze 0 • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 187-085 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0• 6. API Number: 50-029-21746-00-00 • 99519-6612 Stratigraphic ❑ Service 0 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU L2-10 9. Property Designation(Lease Number): 10. Field/Pools: A V ED ADL 028321 • PRUDHOE BAY,LISBURNE OIL • 11. PRESENT WELL CONDITION SUMMARY N UV 1 7 2016 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 10404 • 9270 • 9788 8754 9786 N ,.,;:" Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 35-115 35-115 1490 470 Surface 4065 13-3/8" 34-4099 34-4028 3450/4930 1950/2670 Intermediate 9827 9-5/8" 30 9858 30-8813 6870 4760 Production Liner 787 7" 9613-10400 8611-9267 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9924-10184 8869-9089 2-7/8"6.5# L-80 31-9980 Packers and SSSV Type: 2-71'AVA HydroSet Ret Packer Packers and SSSV MD(ft)and ND(ft): 9569/8575 7"Brown 1-B Penn Packer 9962/8902 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory ❑ Stratigraphic 0 Development 0 • Service 0 14.Estimated Date for Commencing Operations: November 17,2016 .,% 15. Well Status after proposed work: . Oil 0 • WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: 11/16/2016 GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: Michael Quick GINJ 0 Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Hibbert,Michael be deviated from without prior written approval. "" Email Michael.Hibbert@BP.com Printed Name Hibbert,Michael Title Well Interventions Engineer Signature .."-".... .....\.0........... ... ...� Phone +1 907 564 4351 Date ‘,i 1 !/t 2 COMMISSION USE ONLY ` Conditions of approval:Notify Commission so that a representative may witness Sundry Number: �j Plug Integrity ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: 1.-1< F it ii---1- t b Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No1 Subsequent Form Required: 1 O—404- / APPROVED BYTHE Approved by: ,J COMMISSIONER COMMISSION Date:II.22.—`co ORIGINAL RBDMS NOV 2 8 28 18 MA—U. ‘41111 Ib Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate tr ) • • 0.•,00 • Well: L2- 10 L2-10 Cement Squeeze Intervention Engineer Michael Hibbert (907) 564-4351 Production Engineer Mark Sauve (907) 564-4660 Objective The primary objective of this procedure is to re-establish integrity barriers. An active flange leak was discovered on the well and subsequent diagnostics revealed that the packer at 9569 had failed. This work will setup the well to isolate Zone 7 and place cement between the packers at 9569' and 9962'. This is a risk reduction job and requires prompt turn-around. Well History L2-10 had valve swap performed in May 2016. The TIFL done post this work was declared a pass by WI on May 16th. On Nov 10th, a gas leak was found between the production casing spool and r the surface casing spool, requiring Slickline to set a downhole to allow for surface repair. A passing MIT-T to 2,250 psi on Nov 12th demonstrated competent tubing/plug downhole, however, was determined through two different attempts at performing a CMIT-TxIA that there was a well barrier issue in the inner annulus. During these two attempts, over 1,000 bbls of crude have been pumped down the backside at a rate of 5 bpm. A LDL found that the upper packer has failed at 9569'. Step Type Procedure 1 S Pull WRP from 9,788'. Pull 2-7/8" BPC AVA sleeve from 9,832'. Drift for CBP and retainer (2.20" OD). Set CBP below AVA nipple -9850'. Load tbg and IA with 693 bbls of 2 E diesel. Set WFD cement retainer above AVA nipple @ 9815'. Verify good retainer set by pressuring up tbg. F Assist EL with load and verifying retainer set. 3 C Squeeze Zone 7. 4 F MIT-IA to 2500 psi. LLR if fails. 5 E Contingent LDL if MIT-IA fails Slickline 1. Pull WRP from 9,788'. 2. Pull 2-7/8" BPC AVA sleeve from 9,832'. 3. Drift for CBP and retainer (2.20" OD). 4. RDMO. • • EL and Fullbore 1. Set Baker Quickdrill CBP below AVA nipple -9850'. 2. Load tbg and IA with 693 bbls of diesel. Bullhead a tubing volume down tubing and then pump remaining volume down IA taking no returns. 3. Set WFD cement retainer above AVA nipple @ 9815'. 4. Verify good retainer set by pressuring up tbg. 5. RDMO. Coil 1. MU retainer stinger and RIH and sting into retainer. 2. Pump the following down CT with IA and CTBS closed. a. 5 bbl FW spacer b. 100 bbls of Class G cement- see SOR for cement specs c. 5 bbls FW spacer d. 25 bbls of 1.25 powervis 3. Attempt to attain a squeeze pressure of 500-1000 psi. Monitor IA pressure to determine if a squeeze is building. Hesitate if necessary. If squeeze pressure is obtained then cut cement at surface and open IA at surface and circulate 15 bbls of cement up the IA. Unsting from retainer and layin remaining cement above retainer. Run back in hole with Powervis to contaminate down to retainer. POOH. 4. If no squeeze is obtained and IA has positive pressure then attempt to open IA and determine if returns can be achieved and circulate in up to 15 bbls if possible. Unsting from retainer with -2 bbls in the coil and lay in cement on top of retainer. Contaminate down to retainer. POOH. 5. PU JSN and RIH to WCTOC. Jet with Powervis down to retainer and POOH @ 80% jetting more slowly across all jewelry. 6. RDMO. Fullbore 1. MIT-IA to 2500 psi. Establish LLR if fails. 2 • lit , � i I I ii t,, t f x '` 5 .44.,.. (jI A • , a - ID ..,,...„ .. ... ,. .'141.; . n . « y. x Z 010 . * s ....• rod� •.Y '� , .. *a4 A� } X e6'F e { y b 5 . III • .Pre Job Schematic TREE 2-9/16"CM RS WELLHEAD- FMC NEW STD SLMIDLEI L2-1 SAFETY NOTES: ACTIIATOR= BAKER C 091111IV. 45' BE ELB/= 20'coma, H.116--1,/, jI 1 _i 2200 1-2-7/8"CAVACO TROPIA-SSA,V=2.312 KOP= 3200. 91.56,H-40 0 LOCKED OUT(C1120/16) Mu Angle= 37'41)6600' 13=19.124- CH3ACAL MAICRELS Daum MD= 10,013' ST MD TVD DEV TY FE VLV LATCH PORT DATE Datum TVD- 8900'SS El1 2284 2204 1 CA-KSG DMP 8K-2 0 08/30/137 13-318'CSG,681,K-55 BTC,D=12.415' 99' GAS LET PAMEREIS ST I M) TVD DEV TY FE VLV LATCH PORT DATE 13-3/8'CSG,721t.1-80 BTC.13=12 34r H 4099' I__Al L.I.I i 2 2806 2806 3 AkRAHO DIM 13K-2 0 0930/87 3 5336 5062 32 AtF11-10 DOLE BK 16 0825/15 4 7360 6732 33 Mc RAID SO BK 24 05/15/16 Minimum ID z 1.875" © 9832' 5 8755 7902 33 WRFC OW BK-2 0 05/30/87 2 7/13"AVA BPL NIP W/BPC 6 9466 8491 36 McF14-10 DAY TGE 0 0624/95 op.- 9867 —9-5/8"x 2-7/T AVA nus-m.RCR,D=3.375' i TOP OF 7"LAIR I-1 9613 • PRODUCTION MANDRELS ST MO IVO DEV TYPE VLV LATCH]PORT DATE 7 9700 8681 35 Mc FICO DW BK-2 0 10/01/87 fi/iite, cit." . . I 9832* H - ' AVA -.."-JL 4'„--113772: 9832' H2-718"BPC,ID=1 875'(02/12/90) 9-518'CSG„471,L-30 NSCOBTC,13=83581" — 9857' SSW-1/4MT H2-7/13"CAMCO BLAST JOINTS,601 9967 7'8 2-7/11-BROWN 1-6 PKR,D=3.25' .7.14 CA 111 9979' H2-7.-AVA BNG MP,13=2.197' 2 718 TBG 6 5* L-80 0058 bpi,D-2 411 j_r 9980* 99811 —2-715-WLEG w/AVA SI-EAR OUT SOB,0=2 441' 1 REFFORATION SULIARY , 1 9•77' HEIJAD IT LOGGED ON 10122167 j Po+LOG 111 UN Isi/./7.11/ ANGLE AT TOP REF-32 6 wow Pb :Refer to Production OS for!intones(per/data I SIZE SW PRERVAL gm/5w SHIT SQZ 1-213' S 9924-9952 0 09'28/87 I , 1-2/3 6 10006-10028 0 1026/14 1-2/3 S 10020-10094 0 1022/87 I 1-2/3- 6 10028-10050 0 1028/14 1-2/3" 6 10064-10080 0 1027/14 I 1-2/3" 6 10080-10100 0 1027/14 1-2/3' 0 10122,10140 0 1027/14 I 1-280' S 10124-10218 0 10/22/87 1-2.17 S 10143-10164 0 10/27/14 I 1-2/3" S 10164-10164 0 1026/14 I _ PBTO — 10384' I 14.10.04 MAMMA I 7'IM(,7911,I no um, 0311 bp!,o,,,8.184- 1—I 10400' ••••••DA lb WV BY LULGABIllS DA I E RB/BY CO614391S LJSBURPE UPIT '001/87 'ORIGINAL coloPLEFION 05/18/16 EISE/JIA3GLV(20(05/15/16) WEIL: L2-10 98/11101 RCP CORFECTIONS 09/28116 AO 7'LMT DEPTH CORRECTION FMK 14): •1870850 - '1/03/14 JCL4.111)ADFERFS(10/26-2&14) AR No: 50-029-21746-00 68/27/15 TJHIJAD CORFECDON TO AVA MP(2112/90) 18/27115 TJHL11143 GLV GU(0825/15) 01/25/16 JTG/JIMD LOCKED OtIT TRDP1A01/20/16 ( ) i - Sec..18.T1114 R15E,1439'FSL&1295'PMOP Exploration(Alaska) 3 • • ,Post Job Schematic 2916"CAM I-1 V411. 'EAR RCIPNSTDSLMx.E. L2-1 0 SAFE-1Y NOTES: ACTUATOR= BAKR1 C CUB iv 45' 20'CONO, - _ _ 2200° j CAMCO TH-13PIA-SSA,ID=2312" KOP-= 3200 915$,13-40 LOCKED OUT(61/20116) Max Angle= 3r 6600' U=19.124' GLMDS Datum hAD- 10,313" ST P83 TVD WV TYPE VLV LATCH FORT DATE Datum IVO- 6900'SS 1 2264 2284 1 CA-KBO OW DKr 2 0 09/30/87 13-318"OSG,65$,K-55 BTC,0=12415' H 99' GAS LFT MANDRELS ST1 MD TVD DEV 'r/Ft VLV LATCH FORT DATE 13-3/8'CSG,724.L-80 BTC,93=12 347' H 4099' I--a 2 2806 2806 3 NERCO OW 51(2 0 09/30187 3 5336 5062 32 ktFluIFIO DOVE BK 16 08/25/15 4 7360 6732 33 MFM-1C) SO BK 24 05/15/16 Minimum ID 5 8755 7902 33 At FIA-10 OW 8K2 0 09/30187 = .875"( 9832' 2 718AVA BPL NIP Wi BPC 6 946618491 36 I/c RIA10 DW 'TGE 0 06124/95 " • 9559' 9-518'X 2-718'AVA RHS-XL PKR 13=3.375' TOP OF T 1NR H 9613' PRODUCTION MANDRELS I ST MD TVD my TYPE VLV LATCH,PORT DATE 7 9700 8681 35 *MHO DMY 8K-2 ; 0 10/01/87 • 99132' --12-7/8"AVA BEL NFL 13-2259'I 9837 H2-7/8"MD ID=1875'(02/12/90) 9-543"CSG,474,1-80 NSCCIBTC. 8181" 1-1 9867 HA [9896'-9967'H2-7119-CAMIDO BLAST JOINTS,030e' 9962 H7"X 2-7/11-MOWN 1-8 PICK 3.25" MI ICI 9979' H2-ra.AVA BNG 9JP, ••=2.197" r2r7iiTTTG: e7C80,7005taisrli2.:14114-4"911-1 99817 —2-7/8"VILEG w/AVA SMEAR OUT SUB. =1441- PERFORATEN SUMMARY 9972 HELMDTT LOGGED ON 10/22/87 FItt LUT3'UiL t44 .'1/H( ANGLEAT TOP FERE.32'@ 10006' fbie:Refer to Production DB for tislorical perf data SEE SPF tflUIVAL On/3qz SI-DT SCE 1-2/3' S 9924-9952 0 09128/87 1-2/3" 6 10006-10028 0 10/28114 1-2/3' $ 10020-10094 0 10/22187 1-243' 6 10028-10050 0 10128/14 1-2/3' 6 10064-10080 0 10/27/14 1-2/3" 6 10080-10100 0 10/27/14 1 213' 0 10122 10143 0 10,27/14 1-217 S 10124-10218 0 102297 1-2/3' S 10143-10164 0 10/27/14 1-2/3" S 10164-10184 0 10126114 Few 10354' I M**•*44AMMA414 PINK 294,1 80/ITC. 0371 bpi.0%6 184' 1---[ 10400' •••••••=‘==."v-` DA IE IV BY LUIVIart S LTA IE 185/5y COMMENTS LISBURNE MIT 0101187 ORIGINAL COM PLE110f4 05/18(16 BSRIMD GLV (05/15116) AUL: 1.2-10 198/11/01 wry ooRREcrous 09/28/16 JA) 7-1.148 DEPTH COFFECTION PERMIT I4:): '1870850 11/03/14 JCMUNDACPERFS(10/26-28114) API No: 50-029-21746-00 /8/27115 T.84.941)CORRIKTION TO AVA NP(2/12190) See.18,71186 105E,14394 FSL&1295'PAIL 08/27/15 TJIIJAID GLV(20(08/25/15) 11/26/16..ITGMAID LOCKED 0151791:P1A(01/20/16) BP Exploration(Alaska) 4 I • • Quick, Michael J (DOA) From: Quick, Michael J (DOA) Sent: Wednesday, November 16, 2016 3:25 PM To: 'Daniel, Ryan'; Lastufka,Joseph N Cc: Regg,James B (DOA); Hibbert, Michael; Schwartz, Guy L (DOA) Subject: RE: PLEASE APPROVE: L2-10 Sundry for zonal secure... Verbal approval to proceed as per your submitted plan. SCANNED JUN 2 8 2017, Please submit the sundry with wellhead and tree diagram indicating where the leak is. Thanks _---� Michael Quick �' v Sr. Petroleum Engineer 0 lS Alaska Oil and Gas Conservation Commission V 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) (907)276-7542(fax) mike.quick@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mike Quick at 907-793-1231 or mike.quick@alaska.gov. From: Daniel, Ryan [mailto:Ryan.Daniel@bp.com] Sent:Wednesday, November 16, 2016 2:36 PM To:Quick, Michael J (DOA)<michael.quick@alaska.gov>; Lastufka,Joseph N<Joseph.Lastufka@bp.com> Cc: Regg,James B (DOA)<jim.regg@alaska.gov>; Hibbert, Michael<Michael.Hibbert@BP.com> Subject: PLEASE APPROVE: L2-10 Sundry for zonal secure... Importance: High Good Afternoon Michael, Following up on the message I left on your phone this afternoon, BP request verbal approval to proceed and secure the intermediate zone between the two packers on well L2-10 immediately. Recent diagnostics following a small surface flange leak have identified the upper packer as leaking. Michael Hibbert (907 903 5990) has drafted the procedure (attached) and can be contacted for any additional information.The well is currently on a vac with Tubing, IA and OA pressures 0,0,0. Your prompt review and turn a round of approval (email or verbal)on this well risk is much appreciated.Joe Lastufka will follow-up with the written Sundry tomorrow. thanks Ryan 1 • • From: Hibbert, Michael Sent: Wednesday, November 16, 2016 2:21 PM To: Daniel, Ryan Subject: L2-10 Sundry Hi Ryan, Here is the Sundry/program for L2-10. Let me know if you need anything else. -Michael 2 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate IL Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: a C/CI f-i`.vf 121/ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 187-085 3. Address: P.O.Box 196612 Anchorage, Development RI Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21746-00-00 7. Property Designation(Lease Number): ADL 0028321 8. Well Name and Number: LISB L2-10 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 10404 feet Plugs measured feet true vertical 9270 feet Junk measured feet APR 2 5 2016 Effective Depth: measured 10354 feet Packer measured See Attachment feet true vertical 9229 feet Packer true vertical See Attachment feet AOG CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 35-115 35-115 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate 9827 9-5/8"47#L-80 30-9858 30-8813 6870 4760 Production Liner 787 7"29#L-80 9613-10400 8611-9267 8160 7020 Perforation Depth: Measured depth: See Attachment feet 2 True vertical depth: See Attachment feet SCANNED JUN 1 201b Tubing(size,grade,measured and true vertical depth) 2-7/8"6.5#L-80 31 -9980 31 -8917 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 2.875 Camco TRDP-1A SSSV 2198 2198 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9923'-10218' Treatment descriptions including volumes used and final pressure: 120 Bbls 2%KCL,40 Bbls 2%KCL w/Musol,165 Bbls 28%SXE Main Acid,20 Bbls 20%VDA Self-Diverting Acid,55 Bbls 20%MaxCO3 Acid/Fiber Diverting(150 ppt),3400 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1 740 135 1945 589 Subsequent to operation: Shut-In 400 0 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations RI Exploratory 0 Development RI Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 1 ett/4 Phone +1 907 564 4424 Date 4/25/16 Form 10-404 Revised 5/2015 lin- 5-1q//4' RBDMS t;.- APR '2 6 2016 Submit Original Only • • Packers and SSV's Attachment LISB L2-10 SW Name Type MD TVD Depscription L2-10 SSSV 2198.3 2198.3 2.875 Camco TRDP-1A SSSV L2-10 TBG PACKER 9566.93 8572.95 2-7/8"AVA HydroSet Ret Packer L2-10 TBG PACKER 9962.32 8901.91 7" Brown 1-B Perm Packer • • a) Qo 0 0 0 c to r N- O N rncoN- o 0 N v I- U 0 0 0 0 0 0 y i 6) Ln CO N- O LoLo V 0) CO N— CO m N M cY CO CO O 00 M I� N- 1.0 N N- CO O O CO N O O O • 1 1 1 1 e 1 H Ln O O CO CO O M C) CO CO a) O 00 00 O O Ln 00 O) O co O c O ✓ a ▪ o % I ' Ln CD O 7M LoN M M CA CO COCY) rn ▪ rn 12 kw MCO 1_▪ J L 0 0LO CO a) ' J J O • d *k co N N_ •N N Lo co M fn - oo00 N 01,0 c i co Co 6) � r N t N- 0) O Cf) O N - C CO CO O CO °°,_ O) a) V W O) J w c S Uwww (7) D < < C.9 U � u_ u_ Z Z W w m O > > ,H Z D 0 ci— • 10 N m CX) O CO N- CX) V �t Ln CO C) 6) Ln N- r N CX) Ln 6) 00 N CO aO N Ln r N CO �Y N- N L CO N C''S) r Ln r Ln M N r N- M N M CX) 0) N- Ln M O OO ‘T N O N CO NrCO d- M Q, O N N- Niti O M L0 = N-: CX) (0 O M V CO CO = N O O M M CX) 00 O N M N CO f- M d CO N O N- CX) CX) 6) 0) O Ln Ln Ln m CO N N- N Cn 6) CA CA O r r r M M Nr v- LU Ln Ln LU CO 0 O CX) m O CX) CX) O O O 6) 6) O) O C� O O 6) CA CA CA O O O O O O O O O O O O O O 0 CO CX) CO O CJO O O CO 00 O CO O O Oo C1O OO O O 6) 6) CA CA 6) CA 6) 6) CA 6) 6) CA 6) 0. 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Cl-EMCAL MANDRELS Datum MD= 10,013' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum ND= 8900'SS 1 2284 2284 1 CA-KBG DMY BK-2 0 09/30/87 13-3/8"CSG,68#,K-55 BTC,D=12.415" H 99' GAS LET MANDRELS ■ ST MD TVD DEV .TY PE VLV LATCH FORT DATE — 2 2806 2806 3 McFMHO DMY BK-2 0 09/30/87 13-318"CSG,72#,L-80 BTC,D=12.347" —( 4099' 3 5336 5062 32 Mc FM1HO DOME BK 16 08/25/15 4 7360 6732 33 McFMHO SO BK 24 08/25/15 Minimum ID = 1.875" @ 9832' 5 8755 7902 33 McFMHO DMY BK-2 0 09/30/87 2 7/8" AVA B P L NIP W/BPC 6 9466 8491 36 McFM-IO DMY TGE 0 06/24/95 =111 OM 8589' --�9-5/8"X 2-7/8'AVA RHS-XL PKR,D=3.375" TOP OF r LM H 9613' PRODUCTION MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7 9700 8681 35 Mc FMHO DMY BK-2 0 10/01/87 9832' H2-7/8"AVA BR NP,D=2.259" 9832' -12-7/8"BPC,D=1.875"(02/12/90) 9-5/8"CSG,47#,L-80 NSCC/BTC,D=8.681" H 9857' 1 • ' 9898"-9957' H2-7/8"CAMCO BLAST JOINTS,60' 9862' H7"X 2-7/$"BROWN 1-B PKR,D=3.25" 9976' H2-7/8"AVA BNG NIP,D=2.197" 2-7/8"TBG,6.5#,L-80,.0058 bpf,ID=2.441" H 9980' 9980' H2-7/8"VVLEG w/AVA SHEAR OUT SUB,D=2.441" PERFORATION SUMMARY ' 9977' H ELM)TT LOGGED ON 10/22/87 REF LOG:CBL ON 09122/87 ANGLE AT TOP FERE:32°@ 10006' Note:Refer to Production DB for historical pert data ' SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 1-2/3" S 9924-9952 0 09/28/87 1-2/3" 6 10006-10028 0 10/28/14 1-2/3" S 10020-10094 0 10/22/87 1-2/3" 6 10028-10050 0 10/28/14 1-2/3" 6 10064-10080 0 10/27/14 1-2/3" 6 10080-10100 0 10127/14 1-2/3" 6 10122-10143 0 10/27/14 ' 1-2/3" S 10124-10218 0 10/22/87 1-2/3" S 10143-10164 0 10/27/14 ' 1-2/3" S 10164-10184 0 10/26/14 PST() -1 10354' 11111111 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" —i 10404' DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 10/01/87 ORIGINAL COMPLETION 11/03/14 JCMJM)ADPERES(10/26-28/14) WELL: L2-10 08/11/01 RN/TP CORRECTIONS 08/27/15 TJH/JM)CORRECTION TO AVA M3(2/12/90) FI RMT No: '1870850 11/26/13 RCT/JM)REMOVED SAFt1Y NOTE 08/27/15 TJWJMD GLV C/O(08/25/15) API No: 50-029-21746-00 11/26/13 RB/JMD TREEGO(11/16/13) 01/26/16 JTG/JM)LOCKED OUT TROPIA(01/20/16) Sec. 18,T11N,R15E,1439'FSL&1295'FWL 02/02/14 GJF/PJC SSSV CORRECTION 06/03/14 MGS/JM)GLV C/O(05/29/14) BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. aj , Attn: Well Integrity Coordinator, PRB -20 Ec e,� !9 Post Office Box 196612 . � W Anchorage, Alaska 99519 -6612 /,�G 3 SIOi August 22, 2011 NO"- Mr. Tom Maunder \(0r ®$ 10 Alaska Oil and Gas Conservation Commission V^ 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA L2 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L2 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Lisburne 02 Date: 7/7/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal L2 -03A 1980620 500292146501 Top Plate NA NA NA NA NA L2 -06 1830470 500292093000 2" NA 2" NA 0.90 7/7/2011 L2 -07A 2040530 500292291001 14" NA 14" NA 8.50 6/30/2011 L2 -08A 1981400 500292176101 Top Plate NA NA NA NA NA r > L2 -10 1870850 500292174600 Top Plate NA NA NA NA NA L2 -11 1980960 500292288500 14" NA 14" NA 6.80 6/30/2011 NA L2 -13A 1980780 500292144001 Top Plate NA NA NA NA L2-14B 2040950 500292175802 Top Plate NA NA NA NA NA L2 -16 1870970 500292175400 Top Plate NA NA NA NA NA L2 -18A 1981060 500292176601 Top Plate NA NA NA NA NA L2 -20 1851340 500292137600 Top Plate NA NA NA NA NA L2 -21A 2041040 500292148501 Top Plate NA NA NA NA NA L2 -24 1850900 500292134600 Top Plate NA NA NA NA NA L2 -25 1860060 500292152500 Top Plate NA NA NA NA NA L2 -26 1851040 500292135900 Top Plate NA NA NA NA NA L2 -28 1850350 500292129800 62" NA 62" NA 35.70 7/5/2011 L2 -29 1852970 500292150500 Top Plate NA NA NA NA NA L2 -30 1850090 500292127200 Top Plate NA NA NA NA NA L2 -32 1871370 500292177800 Top Plate NA NA NA NA NA L2 -33 1860220 500292153400 Top Plate NA NA NA NA NA ~ ~ (¡;' I ::; 0,;', fì\ ::'~~;:.í rr' I \'V ': ! r\ I, II I' ,,', !: ; 1\ \ :. ! :'~ '-\ïJ'-J\lll' l1J) L fIl,l ¡J ~.J .. --", ..-¡ (fì 'j ! r lJj lI~ ..,. '." I_' ,-""> I,"~." {"", ',':: , fe,)' It .J' ! r. \ I ¡ ! Î\ i ,\ '-' ! ¡! .i I, ' "'. I ,..' " ,. I' fl'i\ Ii [[1,\ '<' ',\ 1.'\; U~~ L~ U::u æJ U~ Lf\j FRANK H. MURKOW5KI, GOVERNOR / ! / AT/ASIiA OIL AND GAS CONSERVATI ON COMMISSION , 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12,2004 Mr, Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. 0, Box 196612 Anchorage, AK 99519-6612 t~7-0~~ Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location PBU L1 PBU L2 PBU L3 Date of SVS Test Apri123,2004 April 26, 2004 April 27, 2004 Failure Rate 30.0% 16,7% 50,0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to \-\I't th SVS test. Sincerely, ÇJ~;Ý J . Norman, Chair C~missioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) ,------- ~ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Submitted By: Ron Marquez Date: 04/26/2004 Operator Rep: Rob Endebrod Unit/Field/Pad: Greater Pt McIntyre/Lisburne/L2 AOGCC Rep: None Separator psi: LPS HPS 448 8Ji8l11JJJ- _m6- 1IJ8. 1'1- IJI{fJl~lllJl}JiI -- Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI L2-06 1830470 448 350 280 P P P OIL L2-10 1870850 11/9/1996 SI L2-14A 2032140 448 350 250 P 4 P 4/27/2004 OIL L2-16 1870970 5/16/1995 SI L2-20 1851340 6/29/1995 SI L2-21 1852750 448 350 320 P P P OIL L2-24 1850900 3/28/1995 SI L2-25 1860060 3/23/1996 SI L2-26 1851040 1118/1996 SI L2-28 1850350 8/4/2000 SI L2-29 1852970 2/24/1994 SI L2-30 1850090 8/4/2000 SI L2-32 1871370 6/9/2003 SI L2-33 1860220 3/28/1995 SI Wells: 3 Components: 6 Failures: 1 Failure Rate: Remarks: Page 1 of 1 SVS PBU LIS L2 04-26-04,xls STATE ANNULUS TES]TNG DATABASE FOR PR~~LISBURNE IN.tECTION WELLS 1988 AHNULAFI TESTS TUltlI~G PACKER TEST LAST TEST .. ..WE. ,.U' _ ,ANNU....U,IS .FI~..Um. _ _ ,~,,IZE ~, IAD'/TVD' CASING _ PRE~,, ,~, DATE __ __ 4..~6 /, , _'~D_h~_...d.i~_~+ !O,_4 ~ . .5.-!I2." 10487/7..834. ..... 9-5~.", 47#,~ MN-80. · . .......... 1.5.00 ~ ~ i i iiii i iii i i : £ ..... . ..... - .......... , , -- ,,, , I_LII I 1, 2-2 ~ .... ~ '7' 11675/8464 9.-5/8'. 4?#, L.-BO 3064 2/28/'8 8 .............................. , .... - '12-' t05'L~Di"~,~i+a.5.NaC1 5-1/2' ~: 8900!8394 ._9...-5/!l:', 47#, L-80 2505 1/1/88' · i iii iiii i IL I I II ,/ 8705-84.82 .~',. 4.7_#, L-BO NSCC lo 221XT', N-80 lo 70i~' 2493 3f30168 e-'& 8 s'~ ~ d~:..,, e.5 ,Na.Ct .... : ° ..... . ........................... . ......... . . . ......... - 7-":--.--.=_ ,,,,,, ~.-,~ .., _ ; ...... --9-19"'"' 98.E.., ;~I + 8.5 N,.aC~. 5-112"'. .... 11051t8668 9,-5dP8', 47#, $CN~-95 f,o 2:320', #--n ~. ,,,,..,pL", 25,65 i i i 16.1. 6'/., 76 ~'-A diese~,,.,, , .,, ,,i. 8.6,,. . .,..NaCI, .5.-.1/2' .9826.,,re4.3_8 ....... 9-5.,'8:, 47'~,_ .L'BO ........ 24,,23 ,, 3_/8/'88', · , 1..2-1 0 '~ Diesel, 2-718' 9569f857~ 9-5,/8' 47# L-BO 3t 0~4 3/618~B 2508 3/6188 L2-24 ~ Cl'ud~ 2-?18........_..,~.' ~ 9-.5t~' 47# L-80 28'I~5 3129tS~ "/ 7' NGI.--6 51 ~ diesel+ 9.4 Na, Ct ~ 8066t742~ 9-518' 47:t MN,-.80 1950 ' 21816~' F C [', · _ "?"' lO 41.53', 5-1/2' below Page 8 Revised 4,tl MICROFILMED 9/218/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 July 30, 1993 Ms. Joan Miller AOGCC 3001 Porcupine Drive Anchorage, AK 99501 RE: Delinquent Subsequent Sundry Notices Dear Madam: Enclosed are delinquent subsequent sundry notices for the Lisburne Oil Pool. Please refer to the list below. Form 10-404 W~Jl permit Approval Date Description Comment L1-15 89-132 90-314 5/8/90 Stimulate Completed L1-30 90-18 90-798 11/1/90 Pe rf/Stimu late L2-06 83-47 9-928 10/20/89 Install Kinley Buttons " L2-10 87-85 90-850 12/3/90 Stimulate " L2-16 87-97 90-865 12/13/90 Stimulate Job Canceled L2-18 87-118 90-851 12/13/93 Pe d/Sti mu late Completed L2-30 85-9 9-955 11/1/89 Install GLVs " L3-01 86-161 90-779 10/16/90 Acid Wash " L3-28 89-66 90-807 11/9/90 Pad/Stimulate " L4-03 88-67 91-248 8/27/91 Perf/Stimulate " L4-15 83-71 91-308 10/16/91 Stimulate " L4-30 88-101 90-800 10/24/90 Stimulate " L5-12 87-10 90-781 10/16/90 Stimulate " L5-21 87-57 90-609 8/9/90 Stimulate " ~ /~ z.:,M, ~]," ,', l......:: - ,'" ~ 7-, -'.,-: .' :~',~> ' ,'," i'./'? / ~ 5"~' - Y,' ~ ~'~" ~+" ....... ;~" ' Sincerely, George K. Phillips Engineering Supervisor Lisburne/Point Mclntyre Engineering GKP:LSL:jb R [C[IX,/E D Enclosures cc: R.G.M. Oba, ARCO Alaska, Inc. (Without Enclosures) Alaska 0il & Ca::; Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company 1. Type of Request: STATE OF ALASKA /"'~ ALASKA OIL AND GAS CONSERVATION COMMI~:~k~iON , .... REPORT OF SUNDRY WELL OPERATIONS. Opera'tion Shutdown Stimulate X~ ' Plugging ... Perfo'r~'te ~/,~./~ Pull tubing Alter casing .. Repair well Pull tubing O t h e r .~'.,,~/,'~,~ 5. Type of Well: ¢. Datum elevation (DF or KB) 2. Name of Operator ARC. O Ala.~ka, Inc. 3. Address P. O. Box 100360 Anchorage AK 99510 4. Location of well at surface 1438' FSL, 1296' FWL, Sec.18, T11N,R15E,UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 19, T11N,R15E,UM At effective depth 1523' FSL, 1554' FWL, Sec.19, T11N,R15E,UM At total depth 1545' FSL, 1539' FWL, Sec.19, T11N,R15E,UM Development Exploratory Stratigraphic Service x RKB 7. Unit or Property name Prudhoe/Lisburne Unit 8. Well number L2-10 9. Permit number/approval number 87-85/90-850 10. APl number 50-029-21746-00 11. Field/Pool LISBURNE OIL POOL feet 12. Present well condition summary Total Depth: measured 1 0404' feet true vertical 9279' feet Plugs (measured) NONE Effective depth: measured 1 0354' feet true vertical 9237' feet Junk (measured) ~E Casing Length Structural Conductor 80' 20" Surface 4 0 6 5' 1 33/8" Intermediate Production 9 8 2 7' 9 $/8" Liner 787' 7" Perforation depth: measured 9924-9952', true vertical 8869-8893', Tubing (size, grade, and measured depth) Size Cemented Measured depth 1850 lb. Poleset 2400 sx AS III & 600 sx Class G 900 sx Class G 280 sx Class G & 175 sx AS1 110' 4099' 9857' 9613'-10400' 10020-10069', 10124-10193' 8951-9013', 9039~9117' 27/8" L-80, tbg w/tail @ 9,980' WLM and SSSV (type and measured depth) 95/8" RHS-XL pkr @ 9569", 7" 1-B @ 9962' WLM & TRDP-1A-SSSV @ 2200' True vertical depth 110' 4027' 8821' 8620'-9275' 13. Stimulation or cement squeeze summary Intervals treated (measured) Wahoo Zones 6 & 5. Treatment description including volumes used and final pressure Please refer to the attached. 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 244 1578 86 5O 3960 1850 139 50 Tubing Pressure 43O 431 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations ~X 16. Status of well classification as: Water Injector ~ Oil ,x,. Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned George, K. Phi!lips Title Engineering Supervisor-Lisb/Pt Mc Form 10-404 Rev 05/17/89 f Date SUBMIT IN DUPLICATE Lisburne Well L2-10 Stimulation Procedure 8/28/91 Shut in for stimulation. Rigged up service company to pump CFA stimulation. Acidized Wahoo 6 and 5 with the following stimulation fluids: · 47 BBL 15% Gelled HC1 · 145 BBL Diesel w/5gpt MS10 · 11 BBL 1% KC1 w/10% S-220 (Well control was provided by surface chokes and production valves). Released service company. 08/30/91 Opened well to flow. STATE OF ALASKA t .,-~..,, OIL AND GAS CONSERVATION COMM~,.,.,IC.. APPLICATION FOR SUNDRY APPROVALS '~. ~ype ct Hequest: Abandon Suspend Alter casing~ Repair well Change approved program 2. Name of Operator ARCO ALASKA INC. 3. Address P.O. BOX 100360 ANCH. AK 99510 4. Location of well at surface Operation shutdown Re-enter suspended well Plugging .. Time extension Stimulate_z~._ Pull tubing Variance Perforate_.___ Other 5. Type of Well: . Development~ Exploratory Stratigraphic Service 1438' FSL, 1296' FWL, Sec. 18, T11 N, R15E,UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 19, T11N, R15E, UM At effective depth 1523' FSL, 1554' FWL, Sec. 19, T11N, R15E, UM At total depth 1545' FSL, 1539' FWL, Sec. 19, T11 N, R15E, UM 6. Datum elevation (DF or KB) RKB 45 7. Unit or Property name Pru~h0(t/Lisburne Unit 8. Well number L2-10 feet 9. Permit number 9-1011 10. APl number 50-029-21746-00 11. Field/Pool LISBURNE OIL POOL 12. Present well condition summa,ry Total depth: measureo 10404' feet true vertical 9279' feet Plugs (measured) NONE Effective depth: measured 10354' feet true vertical 9237' feet Junk (measured) Casing Length Size Structural Conductor 80' 20" Surface 4065' 13-3/8" Intermediate Production 9827' 9-5/8" Liner 787' 7" Perforation depth: 22 Selective Perforations: Tubing (size, grade, and measured depth) 2-7/8" L-80, tbg w/tail @ 9,980' WLM Packers and SSSV (type and measured depth) Cemented 1850 lb. Poleset 2400 sx AS III & 600 sx Class G 900 sx Class G 280 sx Class G 175 sx AS1 Measured Depth 9924-9952' True Vertical Depth 8869-8893' 9-5/8" RHS-XL pkr @ 9569', 7" 1-B @ 9962' WLM & TRDP-1A-SSSV @ 2200' NOV ?-9 1990 NONE Alaska 0ii & Gas Cons. C0mm'tss Anchorage Measured depth True vertical depth 110' 110' 4099' 4027' 9857' 8821' 9613'-10400' 8620'-9275' 10020-10069' 10124-10193' 8951-9013' 9039-9117' 13. Attachments Description summary of proposal x Detailed operations program__ BOP sketch_ 14. Estimated date for commencing operation December 5, 1990 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oilx_ Gas Suspended Service 17. I hereby ce~ify~at_.t_~true and correct to the best of my knowledge. Signed~--~~~ Kirk M. Bartko Title: Sr. Operation Engr. /' ~ - FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative my witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10-/l ..,,,~t=_0 ~{ Approved Copy ~ 5~:'~'~' Retur ed 0~'~\~1~ 0 ~B ~ Commissioner Approved by order of the Commission ~.0~\tC ' Form 10-403 Rev 06/15/88 Date Approval No.~ .- ! SUBMIT IN TRIPLICAT~ Proposed CFA Stimulation- L2-10 1. Shut in well. RU E-Line. . Closed Fracture Acidize Wahoo 6, and 5 with the following stimulation fluids: 1,400 BB1 40 pptg gelled water. 1,400 BB1 emulsified acid 30:70 crude/10% HC1. 1,200 BB1 crude overflush. 50 BB1 diesel. . Maximum treating pressure: 6,500 psi. Release service company and open well to flow. RE( EIVED NOV ~ 9 199~ Alaska Oil & Gas Cons. commission Anchorage A~. :t OIL AND ~..~' ~(~I~"R~,~,:I'iON COMr 3N REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X. 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 1438' FSL, 1296' FWL, Sec. 18, T11N, R15E, UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 19, T11N, R15E, UM At effective depth 1523' FSL, 1554' FWL, Sec. 19, T11N, R15E, UM At total depth 1545' FSL~ 1539' FWLr Sec. 19r T11N, R15E, UM 12. Present well condition summary Total Depth: measured 1 0 4 0 4' feet true vertical 9 2 7 9' feet 6. Datum elevation (DF or KB) RKB 45' feet 7. Unit or Property name Prudhoe Bay/Lisburne Unit 8, Well number 12-10 9. Permit number/approval number 9-1011 10. APl number 50-029-21746-00 11. Field/Pool Lisburne Oil Pool Plugs (measured) Effective depth: measured 1 0354' feet true vertical 9237' feet Junk (measured) NCt~ Casing Length Structural Conductor 4 0 6 5' Surface Intermediate 9 8 2 7' Production 7 8 8' Liner Perforation depth: Size Cemented 13-3/8" 2400 sx AS Il & 600 sx Class G' 9 - 5 / 8" 900 sx Class G 7" 280 sx Class G 175 sx AS I Measured depth 4099' 9857' 9613-10400' 10020'-10069', 10124'-10193' measured 9924'-9952', true vertical 8868'-8892', 8950'-8992', Tubing (size, grade, and measured depth) 2-7/8", L-80, 9980' Packers and SSSV (type and measured depth) PKR: 9-5/8" RHS-XL @ 9569', 7" 1-B @ 9962' SSSV: Camco TRDP=IA @,2200' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) N/A 9038'-9095' True vertical depth 4027' 8821' 8620'-9275' APE o 197r',, c~ Gas Cons. Commission Treatment description including volumes used and final pressure N/A AnchoraF~ 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure N/A Well on Water Injection 501 1 61 499 16. Status of well classification as: January 7,1990 Oil X Gas Suspended Service Tubing Pressure 416 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ (_O._L_~_~ ~ Title Engineering Aide Form 10-404 Rev ~)6/15/88 Date April 27, 1990 SUBMIT IN DUPLICATE Report of Well Operations for L2-10 Well L2-10 was converted from a water injection well to a producing well due to poor reservoir respone from the field waterflood. To perform the conversion, a header line was attached to transmit flow and gas lift valves were installed downhole to assist hydrocarbon production. APPLIcaTION FOR SUNDRY AP . ovAL 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program_ Pull tubing _ Variance _ Perforate _ Other .~_ 2. Name of Operator ~ 5. Type of Well: 6. Datum elevation (DF or KB) I Development ~ ARCO Alaska. Inc. Exploratory 3. Address ~ Stratigraphic P. O. Box 100360, Anchorage, AK 99510I Service 4. Location of well at surface 1438' FSL, 1296' FWL, Sec. 18, T11N, R15E, UM At top of productive interval 1320' FSL, 1320' FWL, Sec. 19, T11N, R15E, UM At effective depth 1523' FSL, 1554' FWL, Sec. 19, T11N, R15E, UM At total depth 1545' FSL~ 1539' FWL, Sec. 19~ T11Nr R15E~ UM 12. Present well condition summary Total Depth: measured 10404' feet Plugs (measured) true vertical 9279' feet none RKB 45' feet 7. Unit or Property name Prudhoe Bay UniFLisburne 8. Well number L2-10 9. Permit number 8-03 10. APl number F:)-029-21 746-00 11, Field/Pool Lisburne Oil Pool Effective depth: measured 1 0354' feet Junk (measured) true vertical 9 2 3 7' feet none Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 4065' 1 3-3/8" 2400 sx AS II & 4099' 4027' Surface 600 SX Class G' Intermediate 9 8 2 7' 9 - 5 / 8" 900 sx Class G 9 8 5 7' 8 8 21' Production 788' 7" 280 sx Class G 961 3-1 0400' 8620'-9275' Uner 175 sx AS I Perforation depth: measured 9924'-9952', 10020'-10069', 10124'-10193' true vertical 8868'-8892', 8950'-8992', Tubing (size, grade, and measured depth 2-7/8", L-80, 9980' Packers and SSSV (type and measured depth) PKR: 9-5/8" RHS-XL @ 9569', 7" 1-B @ 9962' SSSV: Camco TRDP=IA ~ 2200' . 13. Attachments Description summary of proposal _ Convert well from water injector to producer. (Wellbore 14. Estimated date for commencing operation November- December. 1989 16. If proposal was verbally approved Name of approver Date approved 9038'-9095' Detailed operation program ~X schematic attachod). 15. Status of well classification as: Oil Gas Service _Water In!ector BOP sketch_ Suspended _ to Producer 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form require Approved by the order of the Commission ORIGINAL SIGNED BY LO.NN!E ".. SMITH Title Engineering Aide Date FOR COMMISSK~ USE ONLY IApproval No..dy~ WELL L2- 10 $CHEMATI APl ~ 50-029-21746 L' 7 9 12 13 18 16 17 19 Well Status: Seawater Injector Surface Locatlon: 1438FSL, 1296FWL,Sec. 18,T 11N,R 15E,UM Top Lisburne Loc: 1423FNL, 1469FEL,Sec. 19,T I 1N,R 15E,UM RKB To Tubing Hanger: 30 Feet Top of Wahoo: 9923 MD/8824 SS Datum: I O013 MD/8900 SS Reference Log :Z-DENSITY(PORO), DA, 9-10-87 Annulus Fluids: Dlesel Spud Date: 8-23-87 Completior~ 10-1-87 Minimum ID: !.875" (~ 9832' MD . . , I. 30 MD -- 2-7/8" TBG HANGER, 2-7/8" X 6.5~ L-80, I PC 2. 2200 MD -- CAMCO SSSV TRDP- I A, 2.312"ID 3. 2284 MD -- CHEM. INJ. MANDREL CAMCO KBMG 1 'DUMMY BK2 4099 MD -- 13-3/8" X 72~ X L-80 CSG. SET GAS LIFT MANDRELS DEPTH MANDREL TYPE VALVE LATCH TRO SS DEPTH 2805 MD MCMURRY I"FMHO DUMMY BK2 (2760 SS) 5335 MD MCMURRY I"FMHO DUMMY BK2 (5017 SS) 7360 MD McMURRY I'FMHO DUMMY BK2 (6686 SS) 8755 MD MCMURRY I"FMHO DUMMY BK2 (7857 5S) 9466 MD MCMURRY 1-1/2"FMHO E.DUMMY RKED (8446 SS) 9569 MD - AVA 9-5/8" RHS-XL PACKER, 3.375"1D 9613 MD - TOP OF 7"X29~ L-80 LINER EQUAL IZ! NG MANDREL 9700 MD - MCMURRY I" FMHO EQ DMY EKED 9857 MD - 9-5/8"X47~L-80 CASING 10.9832 MD - AVA BPL NIPPLE 2.259"1D, W/PORTED 'BPI' SLV, 1.875' ID 11.9898 MD - CAMCO BLAST JOINTS, 60 FEET 12. WAHOO 7 PERFORATIONS GUN 9924,27,30,33 2" SLIMKONE 9941,45,48,52 13. 9962 ELMD - BROWN ' 1 -B" PACKER 3.25'1D 14. 9976 ELMD - AVA 'BNG' NIPPLE, 2.197"1D NO GO 15. 9980 ELMD - TUBING TAIL , AVA SHEAR OUT SUB 16. WAHOO 6 PERFORATIONS 10020,28,62,69 10037,47,78,94 17. WAHOO 5 PERFORATIONS 10124,29,40,46 10154,59,65,68 10172,80,86,93 10201,18 18. 10354 MD - PBTD 19. 10404MD-TD (8824-8848' SS) GUN (8906-8968' SS) I-II/16"HYPDOME 1-1 I/16" SILV JET GUN (8994-9072' SS) 1-11/16" HYP DOME 1-I 1/16" SILV JET MAXIMUM WELL DEVIATION-- 36 DEGREES ~ 6600 MD HOLE ANGLE THRU WAHOO: 32 DEGREES MAX. H2S LEVEL MEASURED: 5PPM Revision Date: 9-25-89 Waterflood Injection Well Conversion With limited potential for future conventional waterflood implementation, coupled with our current understanding of the recovery mechanism, justification for continued DS-L2 waterflood is tenuous. Therefore, we have decided to shutdown the waterflood pilot. Shutdown will include the conversion of the five existing waterflood injection wells to producers within the next 6 weeks. Actual conversion timing will depend on both LPC water handling capacity and gas lift installation timing. DATE: 8-10-88 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH final for L2-10 Injection Profile Log 7-31-88 run I 5" Sch RECEIVED BY: PLEASE SIGN AND' TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D & M STANDARD EXXON STATE TRANSMITTIAL # 546 DATE: 5-3-88 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LiSBURNE: Magnetic Tape for L2-10 MWD Tape 12-2-87 Run I NL Baroid RECEIVED BY: PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC, 700 G STREET ATO 477 ANCHORAGE, AK. 99510 TRANSMITTIAL # CENTRAL FILES PLANO D&M EXXON 417 STANDARD STATE OF ALASKA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 12. 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 1438' FSL, 1296' FWL, Sec. 18, T11N, R15E, UM At top of productive interval 1320' FNL, 1320' FEL, Sec. 19, T11N, R15E, UM At effective depth 1523' FNL, 1554' FEL, Sec. 19, T11N, R15E, UM At total depth 1545' FNL, 1539' FEL, Sec. 19, T11N, R15E~ UM Present well condition summary Total Depth: measured true vertical 10404' feet 9279' feet Effective depth: measured 10354' feet true vertical 9237' feet Casing Length Size Structural Conductor 4065' 13-3/8" Surface Intermediate 9827' 9 - 5 / 8" Production 787' 7" Liner Perforation depth: measured SEE ATTACHED true vertical Cemented 6. Datum elevation (DF or KB) RKB 45' 7. Unit or Property name Prudhoe Bay/Lisburne 8. Well number 9. Permit number/approval number 8-03/ 9-251 10. APl number 50-029-21746 11. Field/Pool Lisburne Oil Pool feet Plugs(measured) RECEIVED APR 2 Junk (measured) Nam Alask~,0il & Gas Cons, Cc, mmissi0n Measured dep~h~''''' ~Ll~;u~e01'av~.~ical depth 2400 sx AS III & 4099' 4027' 600 sx Class G 900 sx Class (3 9 8 5 7' 8821' 280 sx Class (3 9613'-10400' 8620'-9275' Tubing (size, grade, and measured depth) 2-7/8", L-80, 9980'' Packers and SSSV (type and measured depth) PKR: 9-5/8" RHS-XL @ 9569', 7" 1-B @ 9962' SSSV:: Camco TRDP=IA @ 2200' 13. Stimulation or cement squeeze summary Stimulated with 25 bbls of 15% HCL. Flushed with 10 bbls of diesel and 80 bbls of source water. Intervals treated (measured) Treated all the perforated intervals. Treatment description including volumes used and final pressure Final treatincg pressure of 1320 psi. 14. N/A Prior to well operation Subsequent to operation Re0resentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Water Injectionm 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~[~ ~/~rT('-'~('~.,~ ~, Title En~ineerin~ Aide Form 10-404 Rev '(~)/15/88 Date SUBMIT IN DUPLICATE Zone LISBURNE WILL Depth MD 9924, 27, 30, 33 9941, 45, 48, 52 10020, 28, 62, 69 10037, 47, 78, 94 10124, 29, 40, 46 10154, 59, 65, 68 10172, 80, 86, 93 10201, 18 L2-10 Holes 14 RECEIVED AP~ 2 ~': ~'~'~'~ i~laska ~Oil & Gas Cons. Cc'~mJs,sj~)r~ ' "'~;. ~nchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program ~ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension ~ StimulateX--x Pull tubing ~ Variance __ Perforate ~ Other 2. Name of Operator ARCO Alaska Inc. 3. Address P.O.Box 100360 Anchorage, AK 99510 4. Location of well at surface 1438' FSL, 1296' At top of productive interval 1320' FNL, 1320' At effective depth 1523' FNL, 1554' At total depth 1545' FNL~ 1539' FEL~ Sec 12. Present well condition summary Total depth: measured 10404 ' true vertical 9279 ' Effective depth: measured 10354 ' true vertical .9237 ' FWL, Sec. 18, FEL, Sec. 19, FEL, Sec · 19, . 19, 5. Type of Well: Development x Exploratory __ Stratigraphic __ Service __ TllN, R15E, UM TllN, R15E, UM TllN, R15E, UM TllN, R15E, UM 6. Datum elevation (DF or KB) RKB 45' Z UnitorPropertyname Prudhoe Ba¥/Lisburne 8. Weltnumber L2-10 9. Permit number 8-03 10. APl number 50-- 029-21746 11. Field/Pool Lisburne Oil Pool feet feet Plugs (measured) none feet feet Junk(measured) none feet Casing Length Size Structural Conductor 4065 ' 13-3/8" Sudace Intermediate 9827' 9-5/8" Production 7 8 7 ' 7" Cemented Measured depth True vertical depth 2400 sx AS III & 4099' 4027' 600 sx Class G 900 sx Class G 9857' 8821' 280 sx Class G 9613'-10400' 8620'-9275' Liner Perforation depth: measured 9924'-9952', 10020'-10069 , 10124-:10193 true vertical 8868 ' -8892 ' ,(size. grade, and measured8950 '-8992 ' ,depth) 9038 ' - 9095 ' ' ::~" ~ ':'~:-: ~' ;'~ ~ :"~ " Tubing Cons. Co~ 2-7/8", L-80, 9980' Packers and SSSV (type and measured depth) PKR: 9-5/8'~ RHS.XL ~ 9569', 7" 1-B ~ 9962' SSSV: Camco TRDP=iA ~ 2200' 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch x__ 14. Estimated date for commencing operation April 7, 1989 16. If proposal was verbally approved Lonnie C. Smith 4/5/89 Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service Water Injection 17. I hereby c/e:,rtify that the foregoing is true and correct to the best of my knowledge. Signed /~~;~,_.~,/~~~__~ Title Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH App;'ow)~ Copy RetUme,~,~ ..~ ,/ J Approval NO. Date '~-~b r-¢ ~ P Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ATTACHMENT 1 WELL L 2-1[o . e . SHUTIN WELL RIG UP SERVICE COMPANY TO PUMP STIMULATION. (WELL CONTROL PROVIDED BY SURFACE CHOKES AND PRODUCTION VALVES). ACIDIZE WAHOO ~ 6_7 WITH 2~ BBLS 15% HCL ACID USING BALL SI~/{LERS FOR DIVERSION. FLUSH WITH 60 BBLS SLICK DIESEL. (MAX. TREATING PRESSURE 5000 PSI) RELEASE SERVICE COMPANY. OPEN WELL TO FLOW. * STATIC BHP 33oo ps± WIRELINE BOP EQUIPMENT 2 ' ii i, I 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2, 5000 PSI WIRELINE RAMS 3, 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK OFF DATE: 3-?R-RR FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Finals "~ L2-10 Collar Log 9-29-87 Run I 5" WAI ~ L2,10 Collar Log 12-11-87 Run I 5" WAI ~" L2~10 Injection Profile 3-16-88 Run 1 5" Sch ~ L2~-,~ Collar Log 11-23-87 Run 1 5" WAI ~ L2-21 Collar Log 10-9-87 Run 1 5" DA ~ L3~12 ProdUction Profile 3-2-88 run 2 5" Camco ~ L5-12 Collar Log 10-15-87 Run 1 5" DA ~ L5-29 Collar Log 10-2-87 Run 1 5" WAI PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D &M. STANDARD EXXON STATE OF ALASKA TRANSMITTIAL # ~ STATE OF ALASKA ALASr... OIL AND GAS CONSERVATION COM. _~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate EJ Pull tubing iii-] Alter Casing [] Other x~ water injection 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska ]]nc. RKB 45' Feet 3. Address Po0. Box 100360 Anchorage, Alaska 99510 6. Unit or Property name Prudhoe Ba,v/Ei sburne 4. Location of well at surface 1438' FSL, 1296' FW1 Sec. 18, T11N R15E UM At top of productive interval ' ' ' 1320' FNL, 1320' FEL, Sec 19, T11N, R15E, UN At effective depth 1523' FNL, 1554' FEL, Sec. 19, T11N, R15E, UH At total depth 1545' FNL. 1539' FEL: Sec. 19: T11N; R15E; UM 11. Present well condition summary Total depth: measured 10404' feet Plugs (measured) true vertical 9279' feet 7. Well number L2-10 8. Approval number 8-03 9. APl number 50--029-21746 10. Pool I i_~hl~rne fli 1 none Pnnl Effective depth: measured 10354 ' feet true vertical feet 9237' Casing Length Size Cemented Structural Conductor 4065' 13-3/8" Surface 9827' 9-5/8" Intermediate 787' 7" Production Liner Perforation depth: measured Junk (measured) none Measured depth 2400 sx AS III & 4099' 600 sx Class G 900 sx Class G 9857' 280 sx Class G 9613'-10400' 9924'-9952' 10020'-10069' 10124'-10193' true vertical 8868'-8892', 8950'-8992', 9038'-9095' Tubing (size, grade and measured depth) 2-7/8", L-80, 9980' Packers and SSSV (type and measured depth)pK R: SSSV: 12. Stimulation or cement squeeze summary True Vertical depth 4027' 8821' 8620'-9275' I ECEIVED 9-fi/8" RHS-XL ~ 9569', 7" Z-B ~ 996~' Camco TRDP=!A ~ 2200' Intervals treated (measured) ~/ahoo 5 & 6 Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run Ill 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Technical Aide Form 10-404 Rev. 12-1-85 Date 2-29-88 / Submit in Duplicate/ ATTACHMENT 1 ARCO ALASKA INC. HAS CONVERTED LISBURNE WELL L2-10 TO A WATER INJECTOR FOR THE LISBURNE PILOT WATER- FLOOD. THE DATE OF CONVERSION WAS FEBRUARY 24, 1988. ARCO Alaska, In¢/~'''' ?o~i O?iice ~× 100360 ,?~,~'~cho~-a[~a~ A!aska 9951 T'?iephoae 907 278 12t5 December 30, 1987 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: L2-10 Dear Mr. Chatterton: Enclosed is a copy of the L2-10 Addendum to include with the Well Completion Report, dated 11/20/87. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG:pk GRU1/90 Enclosure ADDENDUM WELL: L2-10 9/22/87 R~DA, rn CBL/VDL/GR/CCL f/10,347'-9500' in 2 passes @ 0 psi & 1000 psi. Rn gyro f/10,300'-surf. 'Drilling Supervisor · - \ Da%e STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION COMi~,,,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] OtherX3 Water Anchoracle~ Alaska 99510 FWL, Sec. 18, T11N, R15E, UM 2. Name of Operator ARCO Alask~ In(;. 3. Address P.O. Box 100360 4. Location of well at surface 1438' FSL, 1296' At top of productive interval 5. Datum elevation (DF or KB) RF, R 45' 6. Unit or Property name Prudhoe Bay/Li sburne 7. Well number L2-10 feet 8. Permit number 87-85 9. APl number 50--029_21746 10. Pool Li s'burne 0i 1 Pool 1320' FNL, 1320' FEL, Sec. 19, T11N, R15E, UM At effective depth 1523' FNL, 1554' FEL, Sec. 19, T11N, R15E, UM At totaldfg~, FNL, 1539' FEL, Sec. 19, T11N, R15E, UM 11. Present well condition summary Total depth: measured true vertical measured true vertical 10404' feet Plugs (measured) NONE 9279' feet 10354' feet Junk (measured) NONE 9237' feet Effective depth: Cemented Measured depth 2400 sx AS III & 4099I §00 sx Class G 900 sx Class G 9857' 280 sx Class G 9613'-10400' Casing Length Size Structural Conductor 4065' 13-3/8" Surface Intermediate 9827' 9-5/8" Production 787 ' 7" Liner True Vertical depth 4027' 8821' 8620'-9275' ,¢, ,, ,,-~ ,,i J A r'-] 0 4 ,:,.; .!, · '::s!<a 0il & Gas Cons. C0mmissi01t Anchorage Perforation depth: measured 9924'-9952' 10020'-10069' 10124'-10193' true vertical 8868'-8892' 8950'-8992' 9038'-9095' Tubing (size, grade and measured depth) 2-7/8" L-80 9980' Packers and SSSV (type and measured depth)i:~,R' 9-5/8" RHS-XL 3.375"TD @ 9569', 7" 1-B 3.25"TD A 9962' SSSV' Camco TRDP-1A 2.312" @ 2200' Description summary of proposal YEI Detailed operations program [] BOP sketch 12.Attachments 13. Estimated date for commencing operation February 1.. 1988 14. If proposal was verbally approved Date approved Name of approver Date 12-30-87 15. I here~,y.~ertify that the foregoing is true and correct to the best of my knowledge Signed '~/C~ L']~/~"~~ Title Technical Aide Conditions of approval Approved by Form 10-403 Rev 12-1-85 LUNNIE C. SMITH Commission Use Only Notify commission so representative may witness J Approval No. ~) ~,) -~ [] Plug integrity [] BOP Test [] Location clearance! ~) - ~" ~/ Apprmiqd CoPy ~~~~~~~ Returned ~ ORIGINAL. SIGNED BY / ~ ~-~ by order of Gomm,sSionor tho commission ~ato/~ ~ ~ ~ ~4 Submit in triplicate ~ Inj. ATTACHMENT 1 ARCO ALASKA INC. PROPOSES TO CONVERT LISBURNE WELL L2-10 TO WATER INJECTION FOR THE LISBURNE PILOT WATER- FLOOD. EXPECTED DATE OF CONVERSION IS FEBRUARY 1,1988. Gas Cons. Commission Anchorage STATE OF ALASKA ~': i~ ALASK~ OIL AND GAS CONSERVATION ~,,.~,vlMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] ... 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-85 ,.. 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21746 4. Location of well at surface 9. Unit or Lease Name 1438' FSL, 1296' FWL, Sec.18, T11N, R15E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 1425' FNL, 3499' FWL, Sec.19, T11N, R15E, UM L2-10 At Total Depth 11. Field and Pool 1652' FNL, 3635' FWL, Sec,19, T11N, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Li sburne Oi 1 Pool RKB 45'} ADL 28321 ALK 2319 , 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. ] 15. Water Depth, if offshore 116. No. of Completions 08/23/87 09/10/87 09/30/87*I N/A feet MSLI 1 ,, 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10404'MD, 9269'TVD 10354'MD, 9228'TVDi YES [~ NO [] 2200' feet MDI 1900' (approx) 22. Type Electric or Other Logs Run DLL/Spectra l og/MLL/SP, Z Den/CN/Cal/GR, CBL/VDL/GR/CCL, CHT/Temp/GR/RMFD, GR/CBL/VDL/CCL, CBL/VDL/GR/CCL, Gyro 2~. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED ..... 20" 91.5# H-40 Surf 110' 30" 1850# Pol eset 13-3/8" 68.0/72.0# K-55/L-80 Surf 4099' 17-1/2" 2400 sx AS Ill & 600 sx Class G Performed top .~ob w/150 sx AS I 9-5/8" 47.0# L-80 Surf 9857' 12-1/4" 900 sx Class G 7" 29.0# L-80 9613, 10400' 8-1/2,. 280 sx Class G " 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See attached sheet 2-7/8" 9977' 9569' & 9962' '26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Well Work lo9~ dated 10/24/87~ for fracture data. 27. N/A PRODUCTION TEST . __ Date First Production I Method of Operation (Flowing, gas lift, etc.) t Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (cor'r) Press. 24-HOUR RATE ~! 2'8. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. *Note: Drilled RR 9/15/87. Perforated well & ran tubing 9/30/87. Fractured well 10/24/87. ,,, Form 10-407 WC4/6: Dani Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE -'; .... STATE OF ALASKA "' .... /'V . ALASK~ OIL AND GAS CONSERVATION t,,JMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 87-85 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510-0360 50- 029-21746 4. Location of well at surface 9. Unit or Lease Name 1438' FSL, 1296' FWL, Sec.18, T11N, R15E, UM Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number 1425' FNL, 3499' FWL, Sec.19, T11N, R15E, UM L2-10 At Total Depth 11. Field and Pool 1652' FNL, 3635' FWL, Sec.19, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Li sburne 0i 1 Pool RKB 45'I ADL 28321 ALK 2319 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. or Aband. I 15. Water Depth, if offshore 116' No. of Complet,ons 08/23/87 09/10/87 09/30/87*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth whereSSSV set 21. Thickness of Permafrost 10404'MD, 9269'TVD 10354'MD, 9228'TVD YES [~ NO [] 2200' feet MD 1900' (approx) 22. Type Etectric or Other Logs Run DLL/Spectra l og/MLL/SP, Z Den/CN/Cal/GR, CBL/VDL/GR/CCL, CHT/Temp/GR/RMFD, GR/CBL/VDL/CCL, CBL/VDL/GR/CCL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91 .5# H-40 Surf 110' 30" 1850# Poleset 13-3/8" 68.0/72.0~ K-55/L-80 Surf 4099' 17-1/2" 2400 sx AS Ill & 600 st Class G Performed top job w/15C sx AS I 9-5/8" 47.0# L-80 Surf 9857' 12-1/4" 900 sx Class G 7" 29.0# L-80 9613' 10400' 8-1/2" 280 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See attached sheet 2-7/8" 9977' 9569' & 9962' , .. 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See attached Well Work lo9~ dated 10/24/87_, for- fracturie data. 27. N/A, PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO ~TEST PERIOD I~ 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 , ,, WNote: Drilled RR 9/15/87. Perforated well & ran tubing 9/30/87. Fractured well 10/24/87. Form 10-407 Rev. 7-1-80 WC4/6:Dani CONTINUED ON REVERSE SIDE Submit in duplicate ADDENDUM WELL' 12/27/87 L2-10 Arctic pack w/300 sx AS I & 127 bbls Arctic pack. D~illing Supervisor WELL COMPLETION OR RECOMPLETION L2-10 (cont'd) REPORT AND LOG Item 24. Perforations: Perforated w/1 spf, 0© phasing MD TVD 9924 9927 9930 9933 9941 9945 9948 9952 10020 10028 10062 10069 10124 10129 10140 10146 10154 10159 10165 10168 10172 10180 10186 10193 8868 8871 8874 8876 8883 8886 8889 8892 8950 8957 8986 8992 9038 9042 9051 9056 9063 9067 9072 9074 9078 9084 9089 9095 WC4/6a 11/20/87 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 September 29, 1987 At~CI-10~GE I:iLE COPY A~O ALASKa. INC. Re: Our Boss Gyroscopic Survey Job No. AK-BO-70075 Well: L2-10 Field: Lisburne Survey Date: September 22, ~87 Operator-. T. McGuire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Enclosure Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager NL Sperry. SunlNL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 Ei;F'ERRV-E;LiN blEL L, L I SE{URNE EIEFq"F:i 7oo 1!300 1499,, 99 14E;4~ 99 ~. ~:;©o ~ t::;'igs,. ':?'? ~, ::5!~;4:~ 9-11:, ?7!7OO 0 11 S SPEF~F;~Y-'SLd*4 WEI_L ME I:.EF 1 { IN3LI ,IA'" ]' D EG M ~ N 12 42. 1 ~ 32 )i I RE ST I r3~ NE 3REES ElM ¥--,.lI.t WELL D E P T I l 6600 6 i 04 ,,,,::,* ,,~:" 6700 '. I :;:4 ,, 64 C,i?O0 (, z(:,, 79 7100 6512.57 7200 6!7;9,5. !~.SB EE, F] H IJEG N:[N Dli (:~REEL:; 4~:, 46'7.57 L, I ,_,E'tU RNE ~Lgr,kA LEI-Itl ;:;F :' .,:7' '~d-i,: ' i F,~ VERT1 CAL RF":TANF:~ I A i::;, C()C~RDiNA]'E:if.; MD '-'TVD ?l~ P'T'H I. ~ I ,' WE ~ I DtFFEF:E'NCE' ~5000 7000 'THE CALCLII.A]i~]N .=,-'ERRY-:,UN kIEL[, I.,.Z.:: B JRNE A L A S K A h'l E A'.E; t.. IF: [~' D~' E J::: 'I ] C:A i DEF:']"I~ :: ! , CORRECT I 3N 445 : -'t '::,:it;::;,. C(i '?Oi), O0 ::,. 07 ::3 i4zl5 {z145~00 l~tO:':.OCi 4. 12 S .... F E. RF, Y- .:,UN WELL. L I c, BL RNE htEra.:JJR E:.D V ,7.1 <15 214 ~:;, t3C ? J O0 ,, C)('~ 3. '9'P :: i. 30 w 0.02 0, O0 ..... F ERR~ ,.,UN NELL.. L I ._ BLIRNE ALAoKA ~ Ri ~E SUB-SEA I~EAS[IRFE ~]R FtCAI VERTICAl DEP]-I-.t ~il- !:'Ti I FIFT:'TH TOTAL R'EZTAN- I1 Al I'.:CORE 'rNATEE "" 4:345.00 .,-. = .... at ,s/: ',-.. ;. ]¢~ 4500., OO -.:- .. 47 .... (3. c, /t ;~: al 5 _ 0 0 4 o ......)0 51'~: 4945, 0~. 4'F'O0. O0 "7o,...~' = . 74 ._. '5 Z ':'- ._~":, / L .... :,4._.. O0 5300 ~79. 215. 2:B E 254 ~ 78 E 2':P5.86 E 4/!:,0. :3 J E 500.77 E 540.44 E MEI-TVB l) I FFERENCE VERTICAL C:ORRECT I ON 74. ':' ...... 17.77 'r/= ')4 214.7:3 . :..:.:4 .... t E. RRY ~.,UN WELL 6774. ,S:245 O0 '74.':75 7 (i", ~; :1 '? J. fi ':5, <;,.; 7100, ()( I :¢24. :7;:3 .: 72z!5. O0 7200~ O0 I972.'27 S N 'Z _ L AF T" :: P T H N C R T J-.t / '~: J?ll c, J. :~..J ,, !')(' ~::,,, ] O0., O0 8245. O0 8200 ~ O0 I. r.',:~-; F/WEST ]E'l I FFERENCE .... tRRE' Z T ,t' 3f',t 'z,-, :2 7 J, ,/,, ,. OU [- THE )"i E J:-:' '1' Iq ] 0 ] :I ] 0 :::() 0 '.?! ]: I'!Cf~i VIERT~ 3Al. RE:C:T ;~I",K:;I.E.#~F~ _~.. _ *.L IhlA1 E .... :,,~ ~-, ...... , '- *' ': ;";'P~'fi 12 E TF~F' W~l"]OO ZONE ........... : ....... E TOP Mt:~HOO ZONE '' ":~ ' ?::::':~ :~; ~:-:,-,::,. 7o E ::IIRVEY DEPTH SPERRY -SUN 5CRLE :- 1 INCH TO 1000.00 / 1000.0 LISBURNE L2-10 AK-BO-70.075 T~UE NORTH -10~0..00 HORIZONT,qL RRCO RLRSKR SEPTEHBER 2! i oo~. oo 2oob. oo --tO00. O0 --2000.00 --~000. O0 L._4000. O0 PROJECT~ON 10404 SCALE :- 1 SPERRY -S INCH TO 2000,00 / 2000. O. O0 LISBURNE L2-10 AK-BO-70075 2000.00 4000.00 6000.00 9268. 92 10000.00[ VERTICAL I 2000, O0 PROJECTION RflCO SEPTI k~-10404 40~0.00 98"/ ARCO Alaska, Inc. Well Work Lo, ~.T..=. ~~-'-" ~ ' ~ ' '":'~ ' ~~ ' , ~~ ~( S: .~~ 6: 1:~4~ 2: ~~ ~': ,~~ '~: m '.Z. ~,: ,, ~,: ,, ':.... I ..... T ........ ~n~ /CC.u~ ..' ' t i I I i i II I i I · ;., .. ~.:' .I ~ V ~ ! - ~' ~':'. . - , ~1 ~ ......... , i i i i i Ul*~'1 _ : .~ i ~ i ,, , ~ ~;..~?, u i i i i i ii i ii I :~f ~ I i i i i ii ii i i i II I I I I ~ I I I I I I II I I II I II . , , , ,,-- I ill I I I I I ALASKA OIL AND GAS CONSERVATION COMMISSION November 24, 1987 ~ 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 TELEPHONE (907) 27g-1433 Telecopy No. (907) 276-7542 ADMINISTRATIVE APPROVAL NO. 207.9 Re: Lisburne Southern Pilot Waterflood Project C H Robinson Sr Operations Engineer Lisburne ARCO Alaska, Inc P O Box 100360 Anchorage, AK 99510-0360 Dear Mr Robinson: By correspondence dated November 19, 1987 ARCO Alaska, InC requested approval to expand a pilot waterflood project in the Lisburne Oil Pool of the Prudhoe Bay Field approved April 17, 1987. The proposed pilot will evaluate injectivity, benefits of pressure maintenance, implementation strategies, and feasibility of waterflood operations in the Lisburne Oil Pool. The pilot will include an additional three injection wells (L2-6, L2-10, L2-16) and one producing well (L2-14) enclosing a pattern of approximately 320 acres drilled from the L2 drilling pad. Fluid injection into the Lisburne Oil Pool is governed by Area Injection Order No. 4 issued to ARCO Alaska, Inc on July 11, 1986. The Commission has determined the proposed pilot project to be a necessary step for the purpose of developing a prudent enhanced recovery method for the pool. The pilot project will not create waste, and is approved as proposed. In addition to the reports required by Title 20, Chapter 25 of the Alaska Administrative Code, a report summarizing the facts and progress of the project will be submitted every six months by the 20th day of the month following the reporting period. Sin~cerely, · .:., "'" Lonnie Commissioner BY ORDER OF THE CO}~ISSION jo/3.AA207 A[RCO ALA IKA ]NC, DATE: 11-5-87 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Finals L2-10 ~ L2-10 Leak Detection Flowmeter 10-3-87 run i 5" Perforation Record 10-22-87 Run i 5" Sch C amc o RECEIVED BY: PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES D&~ EXXON~ PLANO, STANDARD, STATE OF ALASKA , TRANSMITTIAL # 338 ,'~'"-~' STATE OF ALASKA , AL/.. ... OIL AND GAS CONSERVATION CO~ -,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging 1~. Perforate ,~ Pull tubing [] Alter Casing [] Other ~ COMPLETE 2. Name of Operator ARCO Alaska: Inc, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1438' FSL, 1296' FWL, Sec.18, T11N, R15E, UN At top of productive interval 1425' FNL, 3499' FWL, Sec.19, T11N, R15E, UM Datum elevation (DF or KB) RKD 45' Feet 6. Unit or Property name Prudhoe Bay Unit/Lisburne 7. Well number L2-10 . Approval number 7-,i6c) ;~ 7-A~R At effective depth 1628' FNL, 3621' FWL, Sec.19, T11N, R15E, UM At total depth 1652' FNL~ 3635' FWL~ $ec,19~ T11N~ R15E~ UN 11. Present well condition summary Total depth: measured 10404 'MD true vertical 9269 ' TVD Effective depth: measured 10354 'ND true vertical 9228 'TVD 9. APl number 50-- ri?e-?17/~R 10. Pool Lisburne 0il Pool feet Plugs (measured) None feet feet Junk (measured) None feet Casing Length Size Cemented Measured depth · Conductor 80' 20" Conductor Report not available 110'ND Surface 4065' 13-3/8" 2400 sx AS III & 4099'ND 600 sx Class G Top job w/150 sx AS I Production 9827' 9-5/8" 900 sx C1 ass G 9857 'MD Liner 787' 7" 280 sx Class G 9613'-10400'MD True Vertical depth 110 'TVD 4027 ' TVD 8812 'TVD 8610 ' -9266' TVD Perforation depth: measured 9924'MD, 9927'MD, 9930'MD, 9933'MD, 9941'MD, 9945'MD, 9948'MD, 9952'MD true vertical 8868'TVD, 8871'TVD, 8874'TVD, 8876'TVD, 8883'TVD, 8886'TVD, 8889'TVD, 8892'TVD Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail ~ 9977' Packers and SSSV (type and measured depth) RHS-XL pkr ~ 9569', lB pkr @ 9962' & TRDP-1A-SSA SSSV ~ 2200' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (Completion Well Histoury) Daily Report of Well Operations ~ Copies of Logs and Surveys Run ~ Gyro ,.-.. _ ., - ~',--J, 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~-/~ .... ~ (-. 0'/ I I Title Associate Engineer Date 10'27-~7 i Form 10-404 Rev. 12-1-85 (Dani) SW02/94 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Inelructionl: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District IC°unty or Parish Alaska I North Slope Borough Field ~Lease or Unit -.. -~.. ?rudhoe Bay I ADL 28321 Auth, or W'.O. no. ~Title AF~. AL0435 I Completion WWS #l API #50-029-21746 Operator ~ A.R. Co. W.I. ARCO Alaska, Inc. I 50% I Dato 9/28/87 Spudded or W.O. begun Complete Accounting cost center code State Alaska IWell no. L2-10 Date and depth as Of 8:00 a.m. 9/29/87 9/30/87 10/01/87 Complete record for each day reported I otal number of wells (active or inactive) on this @st center prior to plugging and bandonment of this well I our ~Prior status if e W.O. 1100 Hrs. I 7" @ 10,400' 10,354' PBTD, POOH, RD DA 9.0 ppg NaC1 Accept rig @ 1100 hrs, 9/28/87. ND tree, NU & tst BOPE. RU DA, perf 9952', 9948', 9945', 9941', 9933', 9930', 9927' & 9924' @ 1SPF, 0° phasing. Make GR/JB rn to 9626' & 10,300' WLM. RIH, set lB perm pkr @ 9962' WLM. POH, RD DA. 7" @ 10,400' 10,354' PBTD, NU tree 9.0 ppg NaC1 Rn 308 jts, 2-7/8", 6.5# L-80 EUE 8RD tbg w/SSSV @ 2200' & 1-B perm pkr @ 9962', RHS-XL Retrv Pkr @ 9569'. Tst tbg to 2500 Old TD psi & ann to 1500 psi. ND BOPE. NU tree. 7" @ 10,400' 10,354' PBTD, RR 7.0 ppg Diesel NU & tst tree to 5000 psi. hrs, 9/30/87. Displ well w/diesel. INew TD PB Depth Date 9/30/8 IKind of r g 7 Rotary Released rig 1330 Hfs, Classifications (oil, gas, etc.) Oil Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Lisburne Potential test data Well no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct IDate 10/19/87 ITM Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. ~-'~'"" STATE OF ALASKA ----' AL .... , OIL AND GAS CONSERVATION CC .. .3SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program ~ Plugging [] Stimulate ~ Pull tubing ~ Amend order ~ Perforate ~ Other 2. Name of Operator ARCO Alaska~ Inc 3. Address P. O. Box 100360 Anchorage, AK 4. Location of well at surface 99510-0360 1438' FSL, 1296' FWL, Sec.18, T11N, R15E, UN At top of productive interval 1320' FNL, 1320' FEL, Sec.19, T11N, R15E, UN (approx) At effective depth 1523' FNL, 1554' FEL, Sec.19, T11N, R15E, UN (approx) At total depth 1545' FNL,. 1539' FEL,. 5ec.19, TllN, R15E~ UN (approx) 11. Present well condition summary Total depth: measured 1 0404 'MD feet Plugs (measured) true vertical 9279 ' TVD feet 5. Datum elevation (DF or KB) ~KB 45 ' feet 6. Unit or Property name Prudhoe Bay Unit/Lisburne 7. Well number L2-10 8. Permit number 87-~ 9. APl number 50-- 029-21746 10. Pool Lisburne Oil Pool None -Effective depth: measured 10354'ND feet true vertical feet 9237'TVD Casing Length Size Conductor 80' Surface 4065' Producti on 9827 ' Li ncr 787 ' Perforation depth: measured Junk (measured) None Cemented Measured depth 20" Conductor Report not available 13-3/8" 2400 sx AS III & 600 sx Class G Top job w/150 sx AS I 9-5/8" 900 sx Class G 9857'MD 7" 280 sx Class G True Vertical depth 1 10 'ND 1 10 'TVD 4099'MD 4027'TVD 8821'TVD 9613'-10400'MD 8620'-9275'TVE None true vertical None ~bing(size, grade and measured depth) None Packers and SSSV(type and measured depth) None 12.Attachments WELL HISTORY Description summary of proposal ~ Detailed operations program .~ BOP sketch 13. Estimated date for commencing operation October, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~J~__,4~ Title Associate Enqi n~r Commission Use Only (Dan/) 5A2/95 Conditions of approval Notify commission so representative may witness © Plug integrity ~ BOP Test ~ Location clearance Approved by Commissioner Date by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO 011 and Gas Company Well History - Initial Report - Dally lnltllictkllll: Prepare and submit the "lnilill Illllert" on the first Wednesday alta, a well is spudded or wori<over operations are started. Daily work prior tO spudding should be summarized on the form giving inclusive dates only. District ICounty, parish or borough Alaska I Field Lease or Unit Prudhoe Bay Auth. or W.O. no. ITitle AL0435 North Slope Borough State Alaska Nabors 28-E Operator A~CO A.l. aska, Inc. ADL 28321 Drill AP1 50-029-21477 8/23/87 I ARCO W.I. [Hour 2400 Hrs. IPr'°r sl'tu' if a w'O' Well no. L2-IO Spudded or W.O. begun Spud 50% Date and depth as of 8:00 a.m. 8/24/87 8/25/87 8/26/87 8/27/87 8/28/87 8~29/87 thru 8/31/87 The above is correct . For form preparation and distribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. Complete record for each day reported 20" @ 110' 315', (205'), Drlg Wt. 8.8, PV 31, YP 43, PH 9.8, WL --, Sol 3.5 Accept rig @ 1800 hfs, 8/23/87. NU diverter sys. Spud well @ 2400 hfs, 8/23/87. Drl to 315'. 20" @ 110' 1175', (860'), Drlg Wt. 9.2, PV 15, YP 60, PH 8.9, WL 16, Sol 6.5 Drl Co 1175'. 20" @ 110' 2591', (1416'), Drlg We. 9.2, PV 9, YP 31, PH 9.0, WL 22.5, Sol 6.5 Drl to 2591'. 20" @ 110' 3900', (1309'), Drlg Wt. 9.2, PV 7, YP 23, PH 8.9, WL 21.2, Sol 6.5 Drl to 3900'. 3239', 12.8°, S42.5E, 3235 TVD, 60.18 VS, 44.8S, 40.2E 20" @ 110' 4132', (232'), Cmt 13-3/8" Wt. 9.3, PV 5, YP 24, PH 8.6, WL 19.3, Sol 7 Drl to 4132', 30 std short trip, C&C, POOH. RU & rn 100 Jts, 13-3/8", 72#, L-80 BTC csg & 2 jts, 68#, K-55 BTC csg to 4099'. Prep to cmt. 13-3/8" @ 4099' 5255', (1123'), TIH w/bit Wt. 9.1, PV 4, YP 12, PH 11.6, WL 25, Sol 6 Cmt 13-3/8" csg w/2400 sx AS III & 600 sx Cl "G" w/l% CaC12 & 2% D-46. Displ using rig pmp, bump plug. ND diverter sys. Pmp 150 sx AS I top job. NU & tst BOPE TIH, tag FC @ 4011', tst 13-3/8" csg to 2500 psi. DO flt equip & 10' cmt. Conduct formation tst to 14 ppg EMW. Drl to 5255'. 4316', 33.5°, S40.4E, 4210.18 TVD, 498.76 VS, 364.92S, 340.83E 4825', 32.9°, S39.7E, 4635.35 TVD, 778.58 VS, 578.09S, 522.11E 5205', 32.3°, S38.3E, 4955.84 TVD, 982.71VS, 736.15S, 651.32E Date I Title 10/19/87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim Inatn~¢tiolte: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. I County or Parish Alaska North Slope Borough Lease or Unit Prudhoe Bay ADL 28321 Complete record for each day while drilling or workover in progress 9/01/87 9/02/87 9/03/87 9/04/87 9/05/87 thru 9/08/87 9/09/87 State Alaska Well no, L2-10 13-3/8" @ 4099' 6755', (1500'), Drlg Wt. 9.1, PV 6, YP 7, PH 10.6, WL 21.2, Sol 6 RIH, PU 14 its DP, tag btm @ 5255'; no fill. Drl to 6755'. 5385', 31.7°, S38.6E, 5108.48 TVD, 1078.04 VS, 810.85S, 710.64E 6127', 35.3°, S38.0E, 5729.66 TVD, 1483.41VS, 1128.93S, 962.30E 6581', 36.1°, S41.8E, 6097.76 TVD, 1749.11VS, 1331.07S, 1134.76E 13-3/8" @ 4099' 7374', (619'), Drlg Wt. 9.6, PV 8, YP 8, PH 11.5, WL 10.4, Sol 9 Drl to 7374'. 6854', 35.0°, S42.5E, 6319.87 TVD, 1907.75 VS, 1448.74S, 1241.28E 7054', 33.3°, S42.8E, 6485.38 TVD, 2019.93 VS, 1531.31S, 1317.34E 13-3/8" @ 4099' 8277', (903'), POOH Wt. 9.7, PV 11, YP 9, PH 11.5, WL 5.8, Sol lO Drl to 8277'. 7434', 32.7°, S42.1E, 6802.40 TVD, 2225.65 VS, 1683.22S, 1456.29E 8154', 32.5°, S41.8E, 7410.66 TVD, 2610.74 VS, 1970.08S, 1713.42E 13-3/8" @ 4099' 8960', (683'), Drlg Wt. 9.8, PV 14, YP 9, PH 11.5, WL 5.4, Sol 10.5 POH, chg BHA. TIH, rm f/8180'-8277'. Drl to 8960'. 8500', 34.2°, S36.5E, 7701.35, 2801.94 VS, 21t8.39S, 1834.16E 9-5/8" @ 9857' 9870', (910'), C&C Wt. 9.8, PV 11, YP 8, PH 11.7, WL 4.8, Sol 10.5 Drl & surv to 9870', short trip, CBU, POOH. RU & rn 132 its, 9-5/8" BTC & 113 jts, 9-5/8", NSCC + 2 XO jCs w/FS @ 9857'..C&C & prep to cmt. 8877', 33.0°, S35.4E, 8015.35 TVD, 3009.96 VS, 2287.27S, 1936.64E 9064', 33.6°, S35.1E, 8189.47 TVD, 3115.53 VS, 2373.52S, 2018.16E 9580', 35.4°, S34.7E, 8592.87 TVD, 3409.14 VS, 2615.31S, 2187.00E 9815', 33.1°, $34.7E, 8785.79 TVD, 3542.66 VS, 2725.61S, 2263.38E 9-5/8" @ 9857' 9880', (10'), Rn LOT Wt. 8.9, PV 4, YP 8, PH 10.0, WL 21.2, Sol 5 Batch mx 60 bbls chemical wsh & 150 sx 50/50 Pozz w/4% D-20, .5% D-65, .2% D-46 & .5% D-112. Tail w/750 sx C1 "G" w/.5 gal/sx D-lO0, .06% gal/sx D-135, .3% D-65, .05 gal/sx D-47 & .2% D-13. Displ w/rig pmp, bump plug. NU & tst BOPE. TIH w/BHA, tag cmt @ 9759', tst csg to 3000 psi. Displ well w/8.9 ppg mud. DO flt equip. Conduct LOT to 12.5 ppg EMW. 9870', 32.0°, S34.7E, 8832 TVD, 3572 VS, 2750S, 2280E The above is correct ~,, For form prel3~rati-~n a~d distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 ~o/19/8 Drilling Supervisor ARCO Oil and Gas Company ~, Daily Well History--Interim Inatr-ctiona: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "lltlerim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District [County or Parish [State Alaska North Slope Borough Field ILease or Unit Prudhoe Bay I ADL 28321 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 9/10/87 9/11/87 9-5/8" @ 9857' 10,404', (524'), Drlg Wt. 9.0, PV 5, YP 4, PH 11.2, WL 13.1, Sol 5.5 Drl to 10,404'. 9-5/8" @ 9857' 10,404', (0'), Re-rn logs Wt. 9.0, PV 4, YP 5, PH 11.7, WL 10.8, Sol 3.5 Short trip to 9857', C&C, POH f/logs. RU DA, rn log #1 DLL/Spectra Log/MLL/SP, rn log #2, Z Density/CN/CAL/GR, rn log #3, CBL/VDL/GR/CCL; tl failure. Re-rn tl #3 logs. Alaska no. L2-10 The above is correct For form preparation and ~'stribdti~'n . see Procedures Manual Section 10, Drilling, Pages 86 and 87 IOate l0 8tTM IZ91 Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned, or Sold. "Final Report" should be submitted also when operations are susoended for an indefinite or appreciable length of time On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish Alaska Field ~Lease or Unit Prudhoe Bay [ Auth. or W.O. no. J Title AL0435 I Nabors 28-E AR.Co. W.I. Operator ARCO Alaska, Inc. Spudded or W.O. begun Date Spud 8/23/87 Date and depth Complete record for each day reported as of 8:00 a.m. 9/12/87 thru 9/15/87 North Slope Borough ADL 28321 9/16/87 IAccounting cost center code State Alaska IWell no. L2-10 Drill AP1 50-029-21477 I otal number of wells (active or inactive) on this pst center prior to plugging and bandonment of this well I our IPrlor etatua if a W.O. 2400 Hrs. ! 7" @ 10,400' 10,404' TD, 10,354 PBTD, Freeze protect well 9.0 ppg, NaCl Brine Re-run CHT/TM~/GR/RMFD, Rn GR/CBL/VDL/CCL, RD DA. Rm open hole f/9857'-9920': fill @ 9960'. C&C, POOH. RU & rn 17 its 7", 29#, L-80 BTC w/LC @ 10,225', TOL @ 9613', FC @ 10,354', FS @ 10,400'. Cmt w/280 sx 35/65 C1 G w/2% D-20, 1% D-112, .5% D-65, .75% S1 & .2% D-46. Displ cmt w/rig pmp, bump plug, POH. TIH, tag cmt @ 9438', DO cmt to 9613' CBU, POH. RIH w/6" bit & 7" csg scrpr to 9613', drl cmt to 10,224'. Tst csg to 3,000 psi. Drl cmt, LC to 10,354', circ. Displ well to 9.0 ppg brine, tS~..~ lap to 3,000 psi, POH, LD DP. Pmp 400' diesel cap. ND~BOPE, tst pack off, NU tbg spool adapter & master vlv & tst to 3,000 psi. Freeze protect well. 7" @ 10,400' 10,404' TD, 10,354', RR 9.0 ppg diesel Freeze protect 9-5/8" x 13-3/8" ann w/100 bbls crude. hfs, 9/15/87. RR 0800 Old TD New TD P8 Depth 10,404' 10,354' Released rig Date Kind of rig 0800 Hrs. 9/15/87 Rotary Classifications (oil, gas, etc.) / Type comOletion (stogie. dual. etc ) Oil t Single Producing method Official reservoir r, ame(s) Flowing Lisburne Potential test data Well no. Date Reservoir Producing Interval Pi! or gas ITest time Production Oil on test Gas per day Pump size, SPM X length Choke size ' T P C.P Water % GOR Gravqy Allowable Effective date corrected The above is correct Signature ~,x~. ,,~>~- For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date Title 10/19/87 I Drilling Supervisor LI]S UI NE ENGIINEEIRIIN DATE: 10-14-8'7 FROM' ~AM I~MBERT'~ ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: OH Finals for L2-10 Borehole Profile 9-10-87 Run 1 5" DA DLL/GR 9-10-87 Run 1 2"&5" DA Compensated Neutron/GR 9-10-87 Run 1 5" DA DLL/MLL/GR 9-10-87 Run 1 2"&5" DA Spectralog 9-10-87 Run i 2"&5" DA Z-Densilog/Gr (Raw) Run I 2"&5" DA Z-Densilog/GR (Poro) Run I 2"&5" DA FMT 9-11-87 Run i 5" DA RECEIVED BY~~.;~ ,~ ~ ~.~ Cons. commiss|otl PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES . pLANO D & M STANDARD EXXON STATE OF ALASKA TRANSMITTIAL # 322 DATE: 10-14-87 FROM' PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Fina].s L2-10 Acoustic CE,[. 9-11-87 Run 1 5" ~L2-10 Acoustic CBL 9-22-87 Run ] 5" ~ L5-5 Acoustic CBL 9-2-87 Run 1 5" RECEIVED BY: .~ : :~ A1~,s,ka Oil & G~s Cons. C~mm~ss~ PLEASE SIGN AND RETURN TO: P~C~ERT ARCO ALASKA INC. 700 G STREET ATO 47~ ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D&M EXXON STANDARD · S~ATE OF ALASKA TRANSMITTIAL # 3 21 ARCO ALASKA iNC. LISBURNE ENGINEERING Date: 9-10-87 From: Pam Lambert Enclosed are the following: ~Magnetic Tape for L5-5~~~-'~-- ~~H~ LIS Shifted Run 1 8-18-87 ~ ~ ~~ /Magnetic Tape for L5-28~~~ I 30 -~ /Magnetic Tape for L2-10 ~O ( ~H LIS Shifted Run 1. 9-10-87 10 EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL DATE: 9-30-87 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Final for L2-33 Temperature Log 8-30-87 Run 1 5" OH Finals L2-10 Mudlog L5-5 Mudlog Camco 9-6-87 Run 1 Westlog 8-12-87 Run 1Westlog 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANO D&M EXXON STANDARD STATE OF ALASKA TRANSM ITTIAL # 31 R '~'~'-"'" STATE OF ALASKA -'-"' ALA~,,,-, OIL AND GAS CONSERVATION CON ..... .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon D Suspend [] Operation Shutdown [] Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program.. [] Plugging [] Stimulate7 Pull tubing [] Amend order ~ Perforate ~' Other~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 45' 3. Address 6. P. O. Box 100360 Anchorage, AK 99510-0360 p 4. Location of well at surface 7. 1438' FSL, 1296' FWL, Sec.18, T11N, R15E, UM L2-10 At top of productive interval 8. Permit number 1320' FNL, 1320' FEL, Sec.19, TllN, R15E, UM (approx) 87-85 At effective depth 9. APl number 1523' FNL, 1554' FEL, Seco19, TllN, R15E, UM (approx) 50m 029-21746 At total depth 10. Pool 1545' FNL, 1539' FEL, Sec.19, T11N, ELSE, UH (approx) Lisburne 0il Pool 11. Present well condition summary Total depth: measured 1 0404 ' MD feet Plugs (measured) None true vertical 9279 ' TVD feet feet Unit or Property name rudhoe Bay Unit/Lisburne Well number Effective depth: measured 10354 ' MD feet Junk (measured) true vertical 9237 ' TVD feet None I Production 9827' 9857'MD 8821'TVD Liner 787' 9613'-10400'MD 8620'-9275'TV Casing Length Size Cemented Measured depth True Vertical depth Conductor 80' 20" Conductor Report not available 1lO'MD 110'TVD Surface 4065' 13-3/8" 2400 sx AS II I & 4099'MD 4027'TVD 600 sx Class G Top job w/150 sx AS 9-5/8" 900 sx Class G 7" 280 sx Class G Perforation depth: measured true vertical None ~bing(size, grade and measured depth) None None l aockers and SSSV (type and measured depth) ne RECEIVED 2 Alaska Oil & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation September 30, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~. Title Associate Enqin~r Commission Use Only ( J G ) SA2/99 Date Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance · .~ ~ ::J~, i~ Approved by ~;:~ii.~. ....... ~.):';'~. ' .... ~:'~' ' Commissioner Approval No. _~ ... ~ ~ ~ by order of the commission Form 10-403 Rev 12-1-85 Submit in triplicate 'COMPLETION (DRILLING L2-10 PROCEDURE SUMMARY PERMIT ADDITION) 1) MIRU completion rig. 2) Perforate. 3) Run production tubing assembly. 4) Release production rig. 5) Stimulate. LWP5/13m 9/24/87 DATE: 9-21- ~..~<~_,,~' FROM: PAM LAMI~ ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: OH Finals for L2-10 Electromagnetic Wave ResiStivity GR 9-10-87 NL Compensated Neutron Porosity GR 9-10-87 2"&5" NL RECEIVED BY: PLEASE SIGN AND RETURN TO: P, ,M LAMBERT lCO ALASKA INC. I,.G STREET ATO 477 C'FIORAGE, AK. 99510 CENTRAL FILES PLANO D & M STANDARD EXXON STATE OFALASKA' ~ TRANSMITTIAL # 310 A~CQ ALASKA lINC. LIIS[~UR[NE E[NG~II[N[F. EF{II[NG DATE: 9-21-87~ FROM: PAM LAMBE']A~ ~N~/-- ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: Magnetic Tape for L2-10 LIS Data Tape/MWD 9-13-87 NL Baroid ~ 0,~ ~ 6,3 - 0 - o.x.-..x eJ .- 9',~ -/~ ~S~~ Oit & Gas Co~S. PL~SE RN TO~~MBERT ' ( ~ ARCO A~SKA INC. _~~.--' 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES D&M EXXON- PLANO STANDARD ST~~ OF'ALASKA TRANSMITTIAL # 309 DATE' 9-18-87 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: Magnetic Tape for L2-10 OH LIS Unshifted 9-10-87 Run 1 DA RECEIVED BY' i ~ 8,. ?~ Cot~s. ~uomtlt'tSS10It PLEASE SIGN AJ'q9 RETURN~O: PAM LAMBERT {' / '~ ARCO ALASKA INC. - / / ) 700 G STREET ATO 477 · ~ / ANCHORAGE, AK. 99510 CENTRAL FILES: D&M EXXON PLANO STANDARI!I TRANSMITTIAL # 308 MEMORANDoM State uf Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: C.V. Chatterton ~ ..<: oATa: September 16, 1987 Chairman F,LE NO: D.ADA. 34 THRU: Lonnie C. Smith C ommi s s loner TELEPHONE NO: SUBJECT: BOP Test ARCO PBU L2-10 Permit No. 87-85 Lisburne Oil Pool FROM: Doug Amos Petroleum Inspector Thursday, August 28, 1987: I traveled this date from SAPC PBU K-9 Well to ARCO PBU L2-]0 ~1i to witness the BOP test. Friday, August 29, 1987: The testing commenced at 3:00 p.m. and was 60ncluded at 4:45 p.m. There were no failures. I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the successful BOP test atARCO PBU L2-i0 well. Attachment I~_ O0 tA fRev · ~&G 5184 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.0.P.E. Inspection Report Inspector ~perator ~L~P Well £~'~'1~ Location: Sec / ~ T,///~ R /:~-M ~/,fA~, Drilling Contractor Representative. ~/~ VA. '~/~Z/'/~ Permit tt ~ 7 " ..~._~ Rig fl~ Representative V, ~F~ -~'w' Location. General ~/~ Well Sign General Housekeeping ~ Rig. ~ Reserve Pit 0/%" .... Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors Annular Preventer ..~,.~ /O~ 0 Blind RamS ~ / ~.,: Choke Line Valves~'' H.C.R. Valve Kill Line Valve~ Check Valve Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure Pressure After Closure Pump incr. clos. pres. 200 psig Full Charge ~ressure Attained: N Controls: Master Remote D~ psig, psig, L.--''~' min ~ ~ sec. ! min ~Osec. psig Blinds switch cover ~117 and Floor Safety Valves Upper Kelly Lower Kelly Ball Type / ~.~est Pressure / u~'Test Pressure / ~ Test Pressure Inside BOP, /..~.,Test Pressure I/ Choke Manifold / .... .Test Pressure No. Valves /~ / No. flanges ~ ~ ~ Adjustable Chokes , Hydrau. ically operated choke Test Time / hrs. Repair or Replacement of failed equipment'to be made within Commission office notified. days and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor ARCO Alaska, In( '?c,t~:t Office ~ 100360 August 26, 1987 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' L2-10 Dear Mr. Chatterton- Enclosed is a Sundry Notice for the subject well. We propose changing the casing program as noted on the attached Sundry Application. This is the follow up to the verbal approval received from M. Minder on August 23, 1987. Sincerely, 1'o Po Regional Drilling [ng~neer TPO:DRN:pk GRU1/81 Enclosure cc: J. Gruber L2-10 Well File Al~$k~ 0~ & G~s ~$, Oommissio~. ~' STATE OF ALASKA ~"~ ALI,-..,,,~ OIL AND GAS CONSERVATION CO ....... ,~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend © Operation Shutdown [] Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program ~ Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other ,~_~ 2. Name of Operator ARCO Alaska~ Inc 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1438' FSL, 1296' FWL, Sec.18, T11N, R15E, UN At top of productive interval At effective depth At total depth 5. Datum elevation (DF or KB) RKB 45' pAD 32' 6. Unit or Property name Prudhoe Ba.y/Lisburne 7. Well number L2-10 feet 8. Permit number 9. APl number 50~2~-21 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Length Size Cemented ARCO Alaska, Inc. Surface 68#, K-55 70', BTC 13-3/8" Surface 72#, L-80 3980', BTC 13-3/8" PROT 47#, L-80 9854', NSCC/BTC 9-5/8" PROD 29#, L-80 719' BTC 7" Measured depth True Vertical depth proposes to make the following changes to approved casing program 2375 sx AS II I & 600 sx Class G 725 sx Class G & 200 sx AS I Cover liner 200 ft3 w/14,0 ppg Perforation depth: measured true vertical RECEIVED Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) Alaska 0ii & Gas 0OHS. Commissl0rt Anchorage 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation August 23, 1987 14. If proposal was verbally approved Name of approver Mike Hinder Date approved 8/21/87 15. I hereby certify,t, hat t,p~ e fOregoing is true-and correct to the best of my knowledge Signed /, Title Regional Drilling Engineer Commission Use Only ( DRN ) 5A2/'90 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test Approved by ~ Form 10-403 Rev 12-1-85 I Approval No. [] Location clearance '~ -~:~2 ~' by order of Commissioner ~,commission Date '~~ Sub~'it in triplicate~ August 12, 1987 Mr. T. P. Oostermeyer Regional Drilling Engineer ~A~RCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy.' (907) 276-7542 Re: Prudhoe Bay Unit L2-10 ARCO Alaska, Inc. Permit No. 87-85 Sur. Loc. 1438'FSL, 1296'FWL, Sec. 18, TllN, R15E, UM. Btmhole Loc. 1522'FNL, l148'FEL, Sec. 19, TllN, R15E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. I~ere a diverter system is required, please also notify this office 24 hours priOr to commencing equipment installation so that the Co'mmission may witness testing before drilling below the shoe of the conductor pipe. V~,t ru I~fY~TS, ~ ~ Chairman of Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ¢-,,.. STATE OF ALASKA ALASKA O. AND GAS CONSERVATION CON..,,ISSION PERMIT TO DRILL ! 20 AAC 25.005 l la. Type of work Drill ~ Redrill ~]1 lb. Type of well. Exploratory [] Stratigraphic Test Fi Development Oil Re-Entry [] Deepen[]1 Service [] Devet~pement Gas [] Single Zone ~ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc RKB 45' PAD 32' · ' feet Prudhoe Bay Fi el d 3. Address 6. Property Designation iLisburne 0il Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 28321 /~j_j~ 2,,~t~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 1438'FSL, 1296'FWL, Sec.18, TllN, R15E, UM Prudhoe Ba.y/Lisburne Statewide At top of productive interval 8£_We_lL210 number Number _ , #8088_26~27 1320'FNL, 1320'FEL, Sec.19, T11N, R15E, UN At total depth 9. Approximate spud date Amount 1522'FNL, 1148'FEL, Sec.19, TllN, R15E, UM 08/20/87 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line L2-6 1296' @ Surface feet 53' @ 3517'TVD feet 2482 10404'MD/9279'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2700' feet Maximum hole angle33°° Maximum surface 3438 psig At total depth (TVD) 4490 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 32' 32' 112 112' 2000# Poleset 13-1/2" 10-3/4" 45.5# J-55 BTC 70' 32' 32' 102 102' 1275sx AS Ill & 13-1/2" 10-3/4" 45.5# L-80 VAM 398C' 102' 102' 4082 4000' 325sx C1.G 9-7/8" 7-5/8"33/29# L-80 NSCC/FL!~S 9854' 31' 31' 9885 8845' 425sx C1.G + 200sx ASI 6-1/2" 5-1/2"16.87# L-80 FL4S 719' 9685' 8708' 10404 9279' 200sx 14.0 ppg slurry 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet EffeCtive depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface RECEIYEI) Intermediate Production AUG 0 7 1987 Liner Perforation depth: measured .AJaska 0ii & Gas 6ens. Commission Anchorage true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch ~, Drilling program ~ Drilling fluid program [] Timevs depth plot [] Refraction analysis [] Seabed report [] 20AAC25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~ .,,.~,~.~. Title Regional Drilling Engineer D ate~,,~. . Commission Use Only (FPG) PD2/41 Permit Number <;.,.~_ I APl number I Approval date I See cover letter ~_.. ¢ .... , . ,¢,- ..... ,¢-, ,' , (~ 08/12/87 for other requirements Conditions of approval Samples required [] Yes j~.,No Mud log required L--J Yes ~No Hydrogen sulfide measures [] Yes [] No DirectiOnal survey required ,'J~..Yes [] No Required work~r~~5M;. [] 10M; [] 15M Other: ' by order of Approved by iN. ~.. "/" ~ ~, f'~~,~~'~t Commissioner the commission Bat Form 10-401 Rev. 12-1-85 SuCh :ate NOTE: a) In accordance with Area Injection Order No. 4, excess non-hazardous fluids developed from well operations and as necessary to control the fluid level in the reserve pit, will be disposed of down the 7-5/8" x 10-3/4" annulus. The annulus will be left with a non- freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 200 sx of cement followed by Arctic pack upon the completion of the fluid disposal process. b) The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. c) Maximum surface pressure is based upon BHP of 4490 psi @ 8960'TVD, less an oil column to 8660', less a gas column to the surface. d) Wells within 200' of L2-10 are: L2-6 53' from L2-10 @ 3517'TVD L2-13 187' from L2-10 @ 2797'TVD PD2/41a 8/5/87 L2-10 DRILLING PROCEDURE 1) MIRU Nabors 28E. 2) Drill 13-1/2" hole to 2700'MD. Kickoff and build angle at 2.5°/100'MD to 33°23'/S40°19'E. Maintain angle and direction to 10-3/4" casing point at 4082'MD/4000'TVD. 3) Run 10-3/4" casing and cement to surface. 4) Drill 9-7/8" hole to 9885'MD/8845'TVD maintaining angle and direction. 5) Run and cement 7-5/8" casing. 6) Drill 6-1/2" hole to TD 10404'MD/9279'TVD. Maintaining angle and direction. 7) Run open hole logs. 8) Run and cement 5-1/2" liner. 9) Cleanout liner and change over to brine with a diesel cap. 10) Install tubing hanger and production tree. Release drilling rig. 11) Run cased hole logs. 12) MIRU completion rig. 13) Run 2-7/8" tubing single selective completion. 14) Release completion rig. PD2/41a 8/5/87 L2-10 MUD PROGRAM Depth (TVD) Density #/gal Plas Yield Vi sc. Point Initial 10M FL (CP) #/100 ft2 Gel Gel CC/30M Surf 8.8 Funnel to to 100- 10-3/4" 9.7 300 Csg Point 10-3/4" Csg Shoe to K-lO 40-60 20+ 40+ 20+ 8.3 Minimum 6 2 5 25 to Possible to to to to 9.4 20 10 30 10 % % pH and Oil Solids Type of Mud 0 8-10 Spud Mud 0 3 Low Solids to to Non-dispersed 2 7 K-lO to 7-5/8" Csg Poi nt 9.2 10 4 4 8 8 to to to to to to 10.2 20 10 8 20 4 2 4 pH 10-12 to to Low Sol ids 5 15 7-5/8" Csg Point to TD 9.0 4 6 2 8 10 to to to to to to 9.8 10 10 8 20 4 2 4 pH 10-11 to to Low Solids 8 8 NOTE: Exact mud properties will be selected by ARCO representative based on hole conditions. EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Mud cleaners , Pit level indicator (with both visual and audio warning devices) Drilling fluid flow sensor (with read out convenient to the driller's console) 5. Trip tank 6. Agitators 7. Desander 8. Centrifuge PD2/O7a MUD SYSTEM NABORS 28E MUD CLEANER MUD CLEANER II SAND TRAP 4 BBLS ' TRIP TANK PIT I 171 BBLS 130 BBLS I PIT 2 PIT 3 81 BBLS 137 BBLS PIT 5 117 BBLS PIT 4 179 BBLS i PILL PIT 20 BBLS I i i i ii PIT 6 135 BBLS CAVIEM SB-7 MUD CLEANERS (2 @ 750 GPM EACH) DESANDER 3 X 12" DIAMETER CONES DRILCO DEGASSER BRANDT CENTRIFUGE MUD PUMPS: 2 CONTINENTAL EMSCO FB-1600 DACRO GAS BUSTER JG 8/6/87 L2-10 1000 2000 3000 ~000 5000 6000 7000 BO00 SAG RIVER SHUBLIK ~AD LEROCHI'I' 0 )000 2000 3000 4000 5000 6000 KA! 7000 0 1000 ...............' ' ' ~0' CONDUCTI,~ ,.,~,.~_L, ~ ~,rVD ~- ' , , , I I I , , ................... ARC 3 ALA,SKA, INC. .~CALE lIN =1880 FI. SURFACE: 14313' FSL, 1296' FWL SEC. 18, 3'11N, R15E, U <OP TVD = ~71 ~0 TARGET: 132(1' FNL, 1320' FEL 2.5 7.5 ~E~. 19 1'11N. R1RF II  12.5 17.~ 22.:~ 2~ .5 ' 2.5 Eqc_TYP = 3981 MD = ~038 DEP = 378  lU-~/~- ~u~A~ ~vu =4000 ~D--~u~z u~I4O~ 8 40 Bile le MINE Self F~'lto TARGET) AVERAeE ANaLE Sa DEe la MIN K-10 TV~ --7020 MD K-5 TVD = 7~20 M 3 = 8298 DEP = 2724 .~D=8150 MD =9052 DEP~ .139 ~ LC UT VD--8 25 MD'902~, Dx~P~j~.,~123 PrD--8190 MD-9100 DEP =3185 T ~D -- 8250 MD -- 9172 DEP -- 3205 k~ 'IK TVD = 870{) MD = 8711 DI[P = ~E02 7-6/8'C8G P~ TVD -- 8845 MD ="886 DI~P = 3597 " q SG P TVD e27w MD 1040,t DEP 3882 , , , , , , , , ~ , , , , , ~ , , , , , , , , , , , , ~ , ~ , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , , TD/5-1/2' loooo 11ooo 0 1000 2000 3000 4000 5000 6000 VF. RTI CRL SF, O? I ON 2000 3000 4000 500O 6000 7OO0 8OOO 10000 iiooo 7000 E - N COOROINFI"rES W f.~ r'~ 0 Z -2000 -1000 0 1000 2000 3000 tO00 SO00 t ~ t I I I I I I I I I I I I I I I I I I I I I I I t ~ t ~ ' t ' ' ' ' ~ I I I I I ' ' ' ' ' ' ' ' ' t I I I I ' ' ~ ' ' °t C~, , i i i i I i i ! i i i i i i i i i i i i i I i i i i i i i i i i i ~ i i i i i i i i i ! i i i i i ! i i i i i i i ! i i i -2000 -1000 0 1000 2000 3000 4000 5000 E - 1,4 OOOROINFt"I'ES -2000 0 0 o 0 w Z Fi. - W COOROINRT£S - 1000 0 1000 2000 3000 4000 SO00 -2000 -1000 0 1000 2000 3000 4000 5000 E - N COORDINATES E - N COOROINFtTES -300 -200 -100 0 lO0 200 300 o I I I t I I I I I I I ~ ~ ~ J ~ ' ~ ' ~ ' ' ~ ~ ' I I , , ~ , i i ~ i ~ ' ' ' ' ' I I I I t , , , , I I I I I I ~ J ~ I i ~ t / ioo - ',09~ 0 ~/3~76 X ~2-10 ~ - ...................................................... ......... ! o tO Zo L2-1 Z o 123 I o (23 I 0 o I I -300 -200 -100 0 100 200 300 400 E - IA COORDINFtTES NABORS 28E DIVERTER SYSTEM SCHEMATIC ARCO ALASKA, INC. FILL-UP LINE I I RISER II I I 2000 PSI DIVERTER IFLOWLINE 10" BALL VALVE 10" BALL VALVE' I CONDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 RESERVE PIT 10" VENT LINE WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. JG 8/6/87 13-5/8" 5000 PSI BOP STACK DIAGRAM ACCUMULATOR CAPACIT'¢TEST IA#NULAR PREYENTER1 . CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPEI~ LEVEL WITH HYDRAULIC FLUID ASSURE THAT ACCUMULATOR PRESSURE IS $000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ONIADC REPORT. THE ACCEPTABLE LOWER LIMITI5 45 SECONDS CLOSING TIME AND 1 200 PSI REMAINING PRESSURE I PI PE RAHS I 9LINDRA"$ ,1 CJ , I,:~] DRILLING SPOOL IPIPE RAHs) .' ~ HEAD ALL 80P EQUIPMENT 5000 PSI RATED 1 3. 4 5. 6 7 8 9 10. 11 12. ~3 14. 15 16 17 18 13-5/8" BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. CHECK THAT ALL HOLI~ DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILLPlPE AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. FUNCTIONALLY TEST CHOKES. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 2SO PSI LOW PRESSURE TEST FOR A MINIMUM OF 3 MINUTES, THEN TEST AT THE HIGH PRESSURE. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR A MINIMUM OF :5 MINUTES. BLEED PRESSURE TO ZERO. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. ~"~ CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO SOOO PSI AND HOLD FOR AT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. OPEN TOP SET OF PIPE I~AM$ THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST 3 MINUTES TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. ( BACK OFF RUNNING JOINT AND PULL OUT OF HOLE CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST $ MINUTES BLEED PRESSURE OFF ALL EQUIPMENT OPEN BLIND RAMS MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERATION OF DEGASSER. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLINGSUPERV1SOR PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JG 8- 26-85 II II III I I I I III II I II I III~I I Il LOCATED WITHIN ~ hD / NOTES// /,r..'/,.. PROTRACTED SEC. 18, \~ .LEGE,. , · , - cop Tw. ~ N.,.~E. ~5 E., // ~ CONDUCTOR AS- BUJLT ~ 0 FUTURE WELLS ~' ) .. ' ~ EXIST. WELL ~4/ L-I AND L-2 PER FR. BELL B ..... .. - .? ALL COORDINATES SHOWN ARE ~.~g , ~-' ~ o33 o ~ , ~20 ~ BASIS ~ ELEVATION IS [ 031 ' ~ [B.M. L-2-D PER F.R. BELL ~ ASSOC. , o~ zso VICINITY MAP .o SCALE 0~5 260 ~ . ~ 021 ' ~ 017 ' ~ 16t ~ OI5 I~ O1~ ~ ! 120 j 011 ; - i 09 IOe [~ LZ. 2. Y=5~965~104.82 LAT~7~I8'I3.1477"' 13~' EWe. ; 8~ ' X= 693,~8.03 ~.=14~26'~.970" 1~3' ES.L. 07 6e ~ CELLAR BOX ELEV.: 14.2 --Ira. L2.8 Y= 5,9 63~ ~0.11 LA[=7~ I ~ 14.881 6"5. I ~ ~ EW'L' i 05 40 ~ i 05 m' X = 693~7.67 ~NG.=I48°~'II.OI 13~' F.S.L. [ 2l ~ CELLAR ~X ELEV. = 13.8 el , ~ ,~ L2-10 Y=5~96~ ~8.44 LAT.=70°I8'IS.4584" 1296' EW.L. i ' ~' X= 692~994.12 L~G~I~OZ6'II.366" ~438' ES.L. ' ; CELLAR BOX ELEV.=I~.8 ~ [~ ~' ~' ~' L2-16 Y=5,963~513.97 LAT.=7~IS'I7.1~5" 1260' EW.L. ' ~ X= 692~95~.76 ~.= 148°26'12.411" 1614' F.S.L CELLAR' ~X ELEV.= 13.8 L2-18 Y=~96~572.45 LA[=7~18'17.7730" 1248' EW.L. ~,_,~, ~ ~ ~ X= 69~,940.19 ~G~14~6'1~63" 1673'ES.L. CELLA~ ~X ELEV.~ 1~.7 /~i,,. ,..,u~,. ~u ,~ ~ ~:*~.>, . _~~'Z ~- · ...... .~ ............... . .., ...... I HEREBY CE~I~ THAT I AM ' ..' ...... PROPERLY REGISTERED AND LICENSED TO PRACTICE ~ND SURV~ING IN THE STATE OF . THAT THIS P~T f¢?G/'...~'~W...'..~ A~S~ AND REPRESENTS AN A~BUILT SURV~ ~'~" ...... "-~ MADE BY M~ AND THAT ALL ~ DIMENSIONS AND OTHER D~AI~ u '~' " ARE ~RRECT, AS OF:FEB. 5,1985. ..... " '" SHEET { ARco ka . , , as , nc. DATE ~-6-85 Subsidiary of Atlantic Richfield Company j~B NO.716 ~ .NORTH SLOPE DRILLING-PR~HOE BAY _ ,., i i i ii II II I I III I II II (2 'rnm.~ 8) (4) Cas~ /~,~ F-~-f ? (14 r.~ 22) (6) OTHER (Z91 i1~1 31 ) YES 1. Is r_ha pezmiu fee at-~r_had .......................................... ~-- 2. Is w~ll to be located in a dafined pool ............................. .3. Is w~!l located proper disr~nce fr~n prone_~-y Lima .................. 4. Is ~ located p .rcper distance fm~n odn4r w~!ls ................... 5. Is suffi~t u~dedicated acreage ~le in r_his pool ............ 6. Is ~ to be deviated and is weilhore plat inal~ ................ 7. Is operator the only affected parry .......................... 8. :1 ..... 1.. 1..: . 1.. :.. i i 9. Does operator have a bond in force .................................. 10. Is a conservation or'or needed ...................................... 11 Is administrative approval-needed 12. Is the lease rn~her appropriate ....................... 14 Is conduator string providad ' 1~. Will sum-~ace casir~ pro~ec~ ~resh wa~ar zones ....................... 16. Is eno~ csmsn~ use~ ~o cir~~e on conductor an~ surface ......... 17. Will csmsn~ tie in surface an~ intermediate or production strirgs ... 18. Will c~m~ cover all known productive horizons ..................... 1~. Will all casir~ ~ive adequate sa~e~y in collspse, ~snsion sn~ bu~s~. 20. Is ~ ~ ~o be kick~ o~ ~ an ~m~.~ir~ ~!!bora ............ 21. Is o1~ ~_!lbora ahando~mn~ proce~a inctu~a~ on lO-40B ............ 22 Is adequate w~!lbore separation proposed 23 Is a div~rcer system requested . 26. Does BOPE have sufficien~ pressu=a rating - Tes~ ~o J~oo~ psig .. 27. Does tha choke ~*o1~ ccmpl7 w~API RP-SB ~ 8~) .................. 28 IS the presence o£ H2S gas probable .... · t I I I I I t I I t I e I t I I i t t I I I e I I I I t I t I i i ii For exploratory an~ Stratigraphic wells: 2~. Are data presented on potential overpressura zones? ................. ~1. If an offshore loc., ara survey zesults o~ seabe~ condi~ presented Lease & Well No. P ~ ~d' (.. ~-~' 0 NO REMARKS MIMF~ RAD ~- 01/28/87 011 POOL CLASS STATUS AREA NO. S~_ORE ,