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Home My WebLink About184-084David Douglas Hilcorp North Slope, LLC Sr. Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Hilcorp North Slope, LLC Date: 5/23/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250523 Well API #PTD #Log Date Report Type AOGCC E-Set# PBU S-10APB1 50029207657000 191123 10/20/1991 Directional Survey PBU S-10APB2 50029207657100 191123 10/29/1991 Directional Survey PBU S-15PB1 50029211137000 184071 07/04/1984 Directional Survey PBU S-16PB1 50029211237000 184082 08/16/1984 Directional Survey Please include current contact information if different from above. 184-084 T40442 T40443 T40444 T40445PBU S-16PB1 50029211237000 184082 08/16/1984 Directional Survey Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.05.27 08:30:54 -08'00' 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU S-16 Dump Bail Cement Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 184-084 50-029-21123-00-00 11300 Conductor Surface Intermediate Production Liner 9248 80 2643 10665 864 10513 20" x 30" 13-3/8" 9-5/8" 7" 8660 31 - 111 30 - 2673 28 - 10693 10436 - 11300 31 - 111 30 - 2673 28 - 8794 8603 - 9248 10965 2670 4760 5410 10513, 10670 5380 6870 7240 10704 - 10964 4-1/2" 12.6# 13Cr85 / 13cr80 26 - 10459 8802 - 8998 Structural 4-1/2" HES TNT Packer 10354, 8543 10192, 10354 8428, 8543 Torin Roschinger Operations Manager Marshall Brown henry.brown@hilcorp.com 601-613-0173 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028257 26 - 8620 10513 - 10670'MD in Tubing Dump Bail 54-gallons of 17-ppg Neo Cement and 30-gallons 15.8-ppg Class G Cement on top of IBP at 10670'. 1250 Well Not Online 669 1158 1600 750 320 0 323-042, 323-213 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker SB-3 Packer 10192, 8428 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:50 am, Sep 15, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.09.14 19:50:05 -08'00' Torin Roschinger (4662) ACTIVITY DATE SUMMARY 1/29/2023 T/I/O=SHUT IN/900/0 Stung into tubing hanger void with HPBT, had 880 psi., bled off, took ~7-8 min., shut in 10 min., stung back in, went to 880 psi. within 15 min. of stinging in with HPBT, bled off again, went back to 880 psi. within 15 min., RDMO 2/3/2023 T/I/O=SHUT IN/900/0. PPPOT-T (PASS). Pre RWO Tubing hanger void had 880 psi on it, bled off, shut in 10 min., 880 psi again, bled off, shut in 30 min., 880 psi again, torque upper lock down screws to 500 ft/lbs., bled off, shut in 10 min., 0 psi, test void 500 psi/5 min., 0 psi loss, test 5,000 psi/30 min., lost 200 psi first 15 min., lost 50 psi second 15 min., pass, bled off, RDMO (No intermediate casing on this well). 2/24/2023 ***WELL S/I ON ARRIVAL*** STAND BY FOR HIGH WINDS AND PHASE CONDITIONS B&F w/ 3.70" GAUGE RING, 4-1/2" BRUSH OUT TBG TAIL @ 10,459' MD T-BIRD PUMPED 150 bbls CRUDE @ 2 bpm DRIFTED CLEANLY W/ 20' x 3 3/8" DUMMY GUNS TO TAG @ 10,948' SLM. BEGAN LOGGING HES 40 ARM CALIPER FROM 10,460' SLM. ***WSR CONTINUED ON 2-25-23*** 2/24/2023 T/I/O= 2200/900 TFS unit 4 Assist SL (B&F) Pumped 150 bbls of Crude down TBG while SL Brushed. SL in Control of well upon departure. Final WHPS= 650/950 2/25/2023 ***WSR CONTINUED FROM 2-24-23*** CONT LOG OOH w/ CALIPER (Good Data) SET 4-1/2" PXN w/ BAIT SUB IN X-NIPPLE @ 10,228' MD PULLED RK-OGLV FROM ST#1 @ PULLED RK-LGLV FROM ST#2 @ 8,139' MD PULLED RK-LGLV FROM ST#4 @ 6,445' MD PULLED RK-LGLV FROM ST#5 @ 3,713' MD SET RK-DGLV IN ST#5 @ 3,713' MD SET RK-DGLV IN ST#4 @ 6,445' MD. SET RK-DGLV IN ST#2 @ 8,139' MD. T-BIRD TO BEGIN LOADING WELL W/ KCL. ***CONTINUED ON 2-26-23*** 2/25/2023 T/I= 341/930 Temp=S/I (TFS Unit 4 Assist SL with Circulate out) Pumped 2 bbls of 60/40 Followed by 350 bbls of 2% KCL Down TBG, taking returns down FL of S-135. *********WSR continued on 2-26-23*********** 2/26/2023 ***WSR CONTINUED FROM 8-25-23*** T-BIRD TO FINISH LOADING WELL W/ 578 BBLS KCL AND 171 BBL CRUDE F/P (U-TUBE F/P). STAND BY FOR HIGH WINDS. SET RK-DGLV IN STA# 1 (9253' MD). ***WSR CONTINUED ON 2-27-23*** 2/26/2023 TFS unit 4 Standby for weather Daily Report of Well Operations PBU S-16 Daily Report of Well Operations PBU S-16 2/26/2023 ************WSR continued from 2-25-23**********(TFS 4 assist SL with circ out) Pumped 224 bbls of 2% KCL followed by 2 bbls of 60/40 for a spacer, Further pumped 172 bbls of crude for freeze protect, followed by 2 bbls of 60/40 down the TBG. Isolated hardline and pumped 2 bbls of 60/40 for freeze protect taking returns down S-135 FL. Performed U-TUBE TBG/IA. Tags hung on IAC and WV. SL in Control of well upon Departure. FWHP= 0/0 2/26/2023 Rig up to IA, No fluids pumped 2/27/2023 ***WSR CONTINUED FROM 2-26-23*** LRS TO MITIA 3500 PSI (PASSED). LRS TO MITT 3500 PSI (PASSED). PULLED BAITED JD, EQ PRONG, AND PX PLUG BODY FROM 10,228' MD ***WELL S/I ON DEPARTURE*** 2/27/2023 T/I= 940/0 Assist S-Line (RWO) MIT IA PASSED to 3651 psi (3500 Target, 3750 Max) Pump into IA w/ 9.4 bbls Crude to reach test pressure Loss of 53 psi 1st 15 min, Loss of 23 psi 2nd 15 min for a total loss of 76 psi during 30 min test. MIT-T PASSED to 3658 psi (3500 target, 3750 Max) Pumped 1.5 bbbls crude down Tbg. to reach test pressure Loss of 55 psi 1st 15 min, Loss of 22 psi 2nd 15 min for a total loss of 77 psi during 30 min test. Bled back 1.5 bbls FWHP=300/1000 S-line on location upon departure 2/27/2023 TFS Unit 4 Standby for weather 3/13/2023 T/I/O = SSV/900. Temp = SI. Function LDS (RWO). AL SI @ CV = 1960 psi. Stung into TBG hanger test port (0+ psi), bled to 0 psi. Mono bore, no Intermediate hanger. Functioned LDS, all functioned normally, torqued to 500 lb/ft. SV, WV, SSV = C. MV = O. OA = OTG. 14:00. 3/27/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP W/ T-BIRD PUMP 160 BBLS CRUDE TO FLUID PACK WB RIH W/ 1-7/16" CHD (1" FN), 1-11/16" BAKER RUNNING TOOL, 3-3/8" IBP (26.5' OAL) PLUG DID NOT SET POOH FOR BAKER TO INSPECT TOOLS JOB CONTINUED 3/28/2023 ***WELL LEFT S/I*** 3/27/2023 T/I/O=1200/900/ Temp=SI (Assist ELine w/ Load and test) TFS U3. Pumped 160 bbls to load TBG for Eline to set a plug. Well left in control of Eline upon departure 3/28/2023 Assit Eline, pressure test plug to 1000PSI , pumped 7 BBLS crude, unable to achieve test PSI, E-line in control of well upon departure 3/28/2023 ***WELL S/I UPON ARRIVAL*** (rwo capital) R/U HES 759 SLICKLINE UNIT ***CONT WSR ON 3/29/23*** Daily Report of Well Operations PBU S-16 3/28/2023 JOB CONTINUED FROM 3/27/2023 ***WELL S/I ON ARRIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1-7/16" CHD (1" FN), 1-11/16" CCL, 2-1/8" BAKER RUNNING TOOL, 3-3/8" BAKER IBP (23.5' OAL) CORRELAT LOG TO SLB CBL DATED 8/04/1984 ME SET DEPTH=10,694.2' CCL OFFSET=21.9' CCL STOP DEPTH=10,672.3' IBP FAILED PT, PRESSURED UP TO 650 PSI THEN DROPPED OFF TO 250 PSI RIH W/ 1-7/16" CHD (1" FN), 2 X 1-11/16" WB, 2" WB, 3-1/8" CCL (18' OAL) DRIFT TO PLUG @ 10,719' TURN WELL OVER TO SL ***WELL LEFT S/I*** 3/29/2023 ***CONT WSR FROM 3/28/23*** (rwo capital) PULLED BAKER 2-1/8" RUNNING TOOL W/ 3-3/8" BAKER IBP FROM 10,719' MD.(missing 2 elements & stiffner ring) MADE 4 RUNS W/ 4 1/2" BRUSH, 3.50" WIRE GRAB TO 10,966' SLM (recovered 1.5 elements & stiffner ring) ***CONT WSR ON 3/30/23*** 3/30/2023 ***CONT WSR FROM 3/29/23*** (rwo capital) RAN 4 1/2" BRUSH, 3.50" WIRE GRAB TO 10,966' SLM (no recovery) DRIFTED TUBING W/ 22' x 3 3/8" DUMMY GUNS (3.66" max od) TO 10,900' SLM (no issues) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 3/31/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP SET 3-3/8" BAKER IBP AT 10670' MD, CCL TO ME=23.7', CCL STOP DEPTH=10646.3' MD LOG CORRELATED TO SLB CBL DATED: 8/4/84 ***CONTINUED ON 4/1/2023 WSR*** 3/31/2023 T/I/O= 330/884/NA Temp=S/I (TFS Unit 4 Load and Kill Pre E-Line) Pumped 2 bbls 0f 60/40 followed by 290 bbls of 1%KCL down TBG. Further Pumped 38 bbls of 60/40 down TBG for Freeze Protect Pre E-Line. Final WHPS= 0/761/NA Well Secured upon Departure. Tag hung and DSO notified 4/1/2023 ***CONTINUED FROM 3-31-2023*** PT PCE 250LP-3000HP DRIFTED WITH 3" X 30' DUMP BAILER AND TAGGED TOP OF IBP AT 10666' MD. DUMPED 140# OF 100 MESH SAND AROUND TOP OF IBP, RE-TAGGED IBP AT 10666' MD WITH 3" X 30' BAILER DUMPED 136# OF 100 MESH SAND ON TOP OF IBP, TAGGED SAND AT 10660.5' MD WITH 3" X 30' BAILER. RE-TAGGED SAND TOP AT 10660.5' MD AND DUMP 9 GALLONS OF 17 PPG NEO SUPER SLURRY. ESTIMATED TOC CURRENTLY AT 10654.9' MD ***CONTINUED ON 4-2-2023 WSR*** DRIFTED WITH 3" X 30' DUMP BAILER AND TAGGED TOP OF IBP AT 10666' MD. DUMPED 140# OF 100 MESH SAND AROUND TOP OF IBP, RE-TAGGED IBP AT 10666' MD WITH 3" X 30' BAILER DUMPED 136# OF 100 MESH SAND ON TOP OF IBP, TAGGED SAND AT 10660.5' MD WITH 3" X 30' BAILER. RE-TAGGED SAND TOP AT 10660.5' MD AND DUMP 9 GALLONS OF 17 PPG NEO SUPER SLURRY. SET 3-3/8" BAKER IBP AT 10670' MD, CCL TO ME=23.7', CCL STOP ESTIMATED TOC CURRENTLY AT 10654.9' MD Daily Report of Well Operations PBU S-16 4/2/2023 ***CONTINUED FROM 4-1-2023 WSR*** PT PCE 250LP-3000HP TAG STICKY BOTTOM AT 10656' MD WITH 3" BAILER AND DUMP 9 GALLONS OF NEO CEMENT. DUMP ANOTHER 9 GALLONS OF NEO CEMENT ON SAND TOP AT 10660.5' MD. ESTIMATED TOC=10643.7' MD. ***CONTINUED ON 4-3-2023 WSR*** 4/3/2023 ***CONTINUED FROM 4-2-2023*** PT PCE 250LP-3000HP TAG STICKY CEMENT TOP AT 10642.5' MD WITH 3" X 30' BAILER, DUMP 9 GALLONS OF 17 PPG CEMENT. DUMP 9 GALLONS OF 17 PPG NEO CEMENT. ESTIMATED TOC=10631.3' MD. CEMENT READY FOR TAG 4-6-2023. XN-NIPPLE AT 10447' ELMD TIED INTO CBL DATED 8-4-84. ***WELL LEFT S/I, PAD OP NOTIFIED*** 4/6/2023 T/I=115/820 AOGCC MIT T ****Job Cancelled***** 4/6/2023 ***WELL S/I ON ARRIVAL*** RAN 2.50'' SAMPLE BAILER TAG CEMENT @ 10647'SLM/10648'MD (recovered sample of wet cement) RAN 3.79'' G-RING TO XN-NIP @ 10446'SLM/10447'MD (+1' correction) RAN 4-1/2'' TEL & 2.50'' SAMPLE BAILER, LOCATE TT @ 10456'SLM/10459'MD (+3' correction) TAG CEMENT @ 10647'SLM/10650'MD (3' correction) ***WELL LEFT S/I ON DEPARTURE*** 4/7/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP TIE INTO XN NIPPLE AT 10447' MD & TAG STICKY BOTTOM WITH 3" X 30' BAILER AND 3-1/8" GR/CCL AT 10646.6' MD DUMP 9 GALLONS OF CASING CLEANER AT 10646.6' MD. DUMP 9 GALLONS OF 17 PPG CEMENT WITH 3" X 30' BAILER AT 10646.6' MD. DUMP ANOTHER 9 GALLONS OF 17 PPG CEMENT WITH 3" X 30' BAILER AT 10640.8' MD. ESTIMATED TOC=10635.4' MD. ***CONTINUED ON 4-8-2023 WSR*** 4/8/2023 ***CONTINUED FROM 4-7-2023 WSR*** PT PCE 250LP-3000HP TAG TOC AT 10636.5' MD WITH 3" X 30' BAILER, DUMP 9 GALLONS OF 17 PPG CEMENT. ESTIMATED TOC=10631.4' MD. READY FOR TAG 5/1/2023. ***WELL LEFT S/I, PAD OP NOTIFIED*** 4/12/2023 ***WELL S/I ON ARRIVAL*** R/U POLLARD #58 RAN 3' x 1-3/4" STEM, 3.50" G-RING, DRIFT FREELY TO 10570' SLM, WORK TOOL TO S/D @ 10650' SLM (possible cement stringers) ***WSR CONT ON 4-13-23*** DUMP 9 GALLONS OF 17 PPG NEO CEMENT. ESTIMATED TOC=10631.3' MD. CEMENT READY FOR TAG 4-6-2023. XN-NIPPLE AT 10447' ELMD TIED INTO DUMP ANOTHER 9 GALLONS OF NEO CEMENT ON SAND TOP AT 10660.5' MD. ESTIMATED TOC=10643.7' MD. Daily Report of Well Operations PBU S-16 4/13/2023 ***WSR CONT FROM 4-12-23*** RAN 3' x 1-3/4" STEM, 3.70" G-RING, DRIFT FREELY TO S/D @ 10652' SLM RAN3' x 1-3/4" STEM, 3.68" CENT, 4-1/2" TEL, 2.5" S. BAILER (msfb) LOC TT @ 10461' SLM / 10461' ELMD, TAG CEMENT @ 10652' SLM / 10652' MD (sample of cement) ***JOB COMPLETE, WELL LEFT S/I*** 4/14/2023 ***WELL S/I ON ARRIVAL*** JOB SCOPE: (DRIFT AND TAG TOC ,AND DUMP BAIL CEMENT) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RUN #1 CH/ 2.75'' CCL/ 3.5'' X 30' EMPTY BAILER TO DRIFT AND TAG @ 10535.4' AND POOH TO CHANGE BAILER SIZE TO 2.5'' OD RUN#2 CH/2.75'' CCL/ 2.5'' x30' EMPTY BAILER TO COMFIRM TAG DEPTH @10542.5' MD LAID DOWN FOR TONIGHT AND FIX HIGH STRAND ***JOB CONTINUE ON 4/15/2023*** 4/15/2023 ***CONTINUED FROM 4/14/2023 WSR*** JOB SCOPE: (DUMP 30 GALLONS OF CEMENT) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RUN #1 RIH 2 3/4' CCL, SWIVEL, 3.5" BAILER X 30' W/ 10 GALLONS CEMENT TAG BTM @ 10545' PULL INTO POSITION AND DUMP 10 GALLONS OF 15.8 PPG CEMENT SLURRY RUN #2 RIH 2 3/4' CCL, SWIVEL, 3.5" BAILER X 30' W/ 10 GALLONS OF CEMENT 15.8 PPG SLURRY. DUMP CEMENT ON TOP PREVIOUS RUN RUN #3 RIH 2 3/4' CCL, SWIVEL, 3.5" BAILER X 30' W/ 10 GALLONS OF CEMENT 15.8 PPG SLURRY. DUMP CEMENT ON TOP PREVIOUS RUN POOH AND RIG DOWN JOB COMPLETE ***WELL S/I ON DEPARTURE*** 4/18/2023 T/I/O= 142/830/NA (Assist SL with MIT) TFS U-3, MIT-T ***FAIL*** Pumped 8.1 BBLS DSL to reach Max PSI of 2749, 1st 15 min TBG lost 113 PSI, 2nd 15 min TBG lost 77 PSI, Total loss of 190 PSI ***FAIL***, Astablished a LLR of .42 GPM @ 2700 PSI. FWHP=142/830/NA 4/18/2023 ***WELL S/I ON ARRIVAL*** RAN 2 1/2" CENTRALIZER & SAMPLE BAILER, TAG CEMENT @ 10,508' SLM T-BIRD PERFORMED AN INCONCLUSIVE AOGCC WITNESSED MIT-T TO 2,500PSI AOGCC WITNESSED CEMENT TAG @ 10,513' MD (corrected depth +9' to md w/ tubing end locator) DRIFTED W/ 3.65" CENTRALIZER TO 10,480' SLM FOR TUBING CUTTER ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** AOGCC WITNESSED CEMENT TAG @ 10,513' MD (corrected depth +9' to md w/ Daily Report of Well Operations PBU S-16 4/19/2023 T/I/O = 120/845. Temp = SI. MIT-T (FAIL) (MIT-T to 2500 psi target, Pre-RWO). Drilling scafold on well, no s-riser or flow lines. No AL. T & IA FL @ surface. Max applied 2750 psi, Target = 2500 psi. Pressured TBG w/ DSL to 2707 psi (2.6 bbls), lost 114 psi in 15 min, lost 79 psi in second 15 min. Re-pressured TBG to 2746 psi for second attempt, lost 94 psi in 15 min, lost 64 psi in second 15 min. Third attempt, pressured TBG to 2746 psi, lost 67 psi in first 15 min, lost 59 in second 15 min (FAIL) Bled TBG back to 90 psi. FWHP's = 90/840. SV, WV, SSV = C. MV = O. IA = OTG. 13:30. 4/23/2023 T/I/O= 0/800/NA TFS U-3 (Assist ELine as directed). pumped 5.1 bbls of crude to pressure up TBG to 2500 psi for eline to run LOG. Pumped additional .2 bbls of crude to maintain 2500 psi. LLR established at .28 GLM @ 2500 psi. Bleed back TBG to 0 psi took back 2.1 bbls. Standby for Eline to finish job to attempt MIT-T isolated from eline lubricator. * Job Continues to 4-24-23* 4/23/2023 ***WELL SHUT IN ON ARRIVAL*** (LDL) MIRU E-LINE PT PCE 300 PSI LOW, 3000 PSI HIGH. RIH WITH 1.75'' SAMPLE BAILER AND TAG CEMENT AT 10485', BAILER FULL LOG READ ACOUSTIC LDL FROM 10480' TO 10100' PER PROGRAM, NO LEAK FOUND RDMO E-LINE ***WELL SHUT IN ON DEPARTURE*** 4/24/2023 ** Job continues from 4-23-23*** (MIT-T to 2500 psi MAP) TFS U-3. MIT-T ***FAIL*** Pumped 2.4 bbls of crude down the TBG to MIT-T to 2501 psi, 2250 target. First 15 minutes lost 111 psi, Second 15 minutes lost 83 psi. Total loss= 194 psi ***FAIL***. Bleed back TBG to starting pressure, Took back 2.3 bbls. FWHPS=0/850 SV, WV, SSV=C. MV=O. IA=OTG LOG READ ACOUSTIC LDL FROM 10480' TO 10100' PER PROGRAM, NO LEAK FOUND RDMO E-LINE T/I/O = 120/845. Temp = SI. MIT-T (FAIL) (MIT-T to 2500 psi target, Pre-RWO). T/I/O = 120/845. Temp = SI. MIT-T (FAIL) (MIT-T to 2500 psi target, Pre-RWO). Drilling scafold on well, no s-riser or flow lines. No AL. T & IA FL @ surface. Max Drilling scafold on well, no s-riser or flow lines. No AL. T & IA FL @ surface. Max applied 2750 psi, Target = 2500 psi. Pressured TBG w/ DSL to 2707 psi (2.6 bbls), applied 2750 psi, Target = 2500 psi. Pressured TBG w/ DSL to 2707 psi (2.6 bbls), lost 114 psi in 15 min, lost 79 psi in second 15 min. Re-pressured TBG to 2746 psi for second attempt, lost 94 psi in 15 min, lost 64 psi in second 15 min. Third attempt, pressured TBG to 2746 psi, lost 67 psi in first 15 min, lost 59 in second 15 min (FAIL) ** Job continues from 4-23-23*** (MIT-T to 2500 psi MAP) TFS U-3. MIT-T ** Job continues from 4-23-23*** (MIT-T to 2500 psi MAP) TFS U-3. MIT-T ***FAIL*** Pumped 2.4 bbls of crude down the TBG to MIT-T to 2501 psi, 2250 target. First 15 minutes lost 111 psi, Second 15 minutes lost 83 psi. Total loss= 194 target. First 15 minutes lost 111 psi, Second 15 minutes lost 83 psi. Total loss= 194 psi ***FAIL***. Bleed back TBG to star MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:35 Township:12N Range:12E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:11300 ft MD Lease No.:ADL0028257 Operator Rep:Suspend:X P&A: Conductor:20" X 30"O.D. Shoe@ 111 Feet Csg Cut@ Feet Surface:13-3/8"O.D. Shoe@ 2673 Feet Csg Cut@ Feet Intermediate:9-5/8"O.D. Shoe@ 10693 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 11300 Feet Csg Cut@ Feet Tubing:4-1/2 O.D. Tail@ 10459 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Tubing Bridge plug 10690 ft 10513 ft 7.2 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing 2753 2761 2603 IA 917 915 913 OA Initial 15 min 30 min 45 min Result Tubing 2753 2632 2561 2498 IA 920 17 915 913 OA Remarks: Attachments: Steve Soroka F Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): Top of cement was tagged at 10513 ft W/L measurement (with +9 ft correction). Had really good cement in bailer. MIT was attempted twice while I was on location with both failing due to no stabilization trend. This is also a Monobore well - no O/A. April 18, 2023 Kam StJohn Well Bore Plug & Abandonment PBU S-16 Hilcorp North Slope LLC PTD 1840840; Sundry 323-042 Photo - Cement sample Test Data: F Casing Removal: rev. 11-28-18 2023-0418_Plug_Verification_PBU_S-16_ksj              7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-16 Recomplete Well Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 184-084 50-029-21123-00-00 341J / 457B ADL 0028257 11300 Conductor Surface Intermediate Production Liner 9248 80 2643 10665 864 ~10631 20" x 30" 13-3/8" 9-5/8" 7" ~8747 31 - 111 30 - 2673 28 - 10693 10436 - 11300 2461 31 - 111 30 - 2673 28 - 8794 8603 - 9248 10965 2670 4760 5410 ~10631, 10670 5380 6870 7240 10704 - 10964 4-1/2" 12.6# 13Cr85 / 13cr80 26 - 104598802 - 8998 Structural 4-1/2" HES TNT Packer 4-1/2" Baker SB-3 Packer 10192, 8428 10354, 8543 Date: Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY 4/15/2023 Current Pools: PRUDHOE OIL Proposed Pools: Aurora / Schrader Bluff, Polaris STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 323-213 By Kayla Junke at 10:38 am, Apr 07, 2023 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.04.07 06:31:57 -08'00' Stan Golis (880) Convert Producer to a Polaris injector or as an Aurora producer. SFD 4/18/2023 10-404 DSR-4/13/23 2461 Perforate New Pool BOP test to 3000 psi, annular test to 2500 psi. Prudhoe Oil: CO 341J; Aurora Oil: CO 457B; Polaris Oil: CO 484A SFD 4/10/2023 See attached list of additional conditions of approval. Service X Aurora / Schrader Bluff, Polaris *State to witness Eline tag (~10,655' MD minimum a) and pressure test to 2500 psi of reservoir abandonment plug. Email complete CBL to melvin.rixse@alaska.gov. *For Polaris SB WINJ completion, AOGCC to witness MIT-IA to 3500 psi. * For Polaris WINJ completion, AOGCC to witness MIT-IA to 3500 psi within 5 days of stabilized injection. * Variance to 20 AAC 25.223 (c)(1)(E) approved for setting bridge plug > 50' above top perforation. Bridge plug to be placed above TSAD and within the PB oil pool confining zones. * All 16 offset wells within 1/4 mile that do not have a CBL across the Aurora and SB-Polaris to demonstrate isolation will have PNL and temperature logs as described in the program. CDW 04/26/2023 MGR26APR23 SFD 4/26/2023JLC 4/26/2023 4/26/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.04.26 17:20:54 -08'00' RBDMS JSB 042723 RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 WellName:SͲ16APINumber:50Ͳ029Ͳ21123Ͳ00 CurrentStatus:NotOperableduetoSCleaktoonlyhotgasliftgas EstimatedStartDate:3/21/23Rig:Nordic3 Sundry#?XXXͲXXXDateReg.ApprovalRec’vd:XXͲXXͲXXXX RegulatoryContact:AbbieBarkerPermittoDrillNumber:184Ͳ084 FirstCallEngineer:BrodieWages(907)564Ͳ5006(O)(713)380Ͳ9836(M) SecondCallEngineer:ClaireMayfield(970)443Ͳ3631(M) CurrentBottomHolePressure:3341psi@8799’TVD7.3PPG|(1/25/2014static) 7.6PPGwith2500’freezeprotect Max.AnticipatedSurfacePressure:2461psi(Basedon0.1psi/ft.gasgradient) LastSIWHP:110psi (Takenon12/25/2022) MinID:3.725”XNat10,447’MD MaxAngle:53.2Deg@5,600’MD 70deg:N/A FormationTops: Shrader:5251’MD,4943’TVD Kuparuk:7778’MD,6664’TVD Sag:10,700’MD,8799’TVD Sadlerochit:10,877’MD,8933’TVD MITs: CMITͲTxIA:2428psion8/3/2019 Objective: TheIvishakreservoirnolongerremainseconomicallyviableandboththeShraderandtheKuparukintervalfor SͲ16motherboreisinaperfectlocationtoreͲcompletethewelltoupholeproduction/injection.ARWOis plannedtodeterminecementtopviaCBLandtorecompletetoShraderinjectionifthecementishighenough orKuparukproductionifthecementisbelowthetopofShrader. WellSummary: SͲ16: ThewellwasdrilledasanexploratorywellinNWFBtargetingZ4Ivishakin1984.Aftersettingandcementing thesurfacecasing,atopjobonthesurfacecasingwasperformedthenthecasingwastestedto3000psiforan initialfail.Acementretainerwassetjustabovetheshoe@2620’and300cuftofPermafrostCcementwas squeezedbelowforagoodtest.Afterdrillingouttheshoe,theywereunabletodrillpast“junk”justbelow shoesoakickͲoffplugconsistingof186cuftarcticsetIIwaspumped. Theproductionholesectionwasdrilledandcoredwitha12Ͳ1/4”bitfairlyuneventfully,9Ͳ5/8”casingwasrun andcementedat10,693’with2260cuftclassGwithsomeadditivesfollowedby230cuftclassGneat. Theproductionlinerwasrunafteranuneventful8Ͳ1.2”holesectionwasdrilled.The7”linerwascementedin placewith312cuftClassGwithsomeadditives.Finally,the9Ͳ5/8”x13Ͳ3/8”annuluswasdownsqueezedwith 279cuftArcticSetIIcementfollowedbyarcticpack. InApril1992,aworkoverwasperformedtoupsizethetubingto4Ͳ1/2”13Crfrom3Ͳ1/2”tubingandaddressa leakinthe3Ͳ1/2”tubing. RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 In2002,bubblingwasidentifiedinthecellarandawaiverforIAxOAcommunicationwasgranted.Thewellwas thenproducedonandoffuntilthewaiverexpiredin2004,whenthewellwasshutin.On9/11/2011,anMITͲT failedindicatingTxIAcommunication. 2015RWOforIAxOArepair:pulledtubing,ranUSITfrom~2800’tosurface,foundlittlecementbelow2225’, goodcementfrom2225’–1610’andnocementabove1610’.SetRBP@1593’,PTto1000psi,cutcasingat 1520’,spearedandPOHwith9Ͳ5/8”casingfine.“Casingwasingoodcondition,nomajorcorrosionnoted.” Aftercuttingoffthe13Ͳ3/8”startinghead,alandingringwithaslipbowlwasinstalledandthe9Ͳ5/8”overshot, ECPandcementingvalvewasrunandcementedinplacewith115bblsof15.8ppgclassG.Cementedperplan withgoodindicationthecementingvalveclosed.A9Ͳ5/8”sliplockstartingheadwasinstalledthenthecement aroundthecementingvalvewasdrilledoutandpressuretestedto3500psiforapassingtest.4Ͳ1/2”tubing wasruntoachievecurrentwellcondition.ThetubingandIAwaspressuretestedto3500forpassingtests.The IApassed3700psiwith0psilost. ShortlyaftertheRWO,thebubblingwasagainobservedinthecellar.AnMITͲTandMITͲIAwasperformed, bothofwhichpassed.GLVswerereͲinstalledandthewellwasstackedoutcoldwithALon3/16/16.Overthe nexttwomonths,thewellwasleftstackedoutandnobubblingwasobserved.However,whenthewellwas popped,2dayslaterLELsweobserved.AftershuttingintheIA,theLELreadingswenttozero. In2017,awellocktopjobwasperformed,howeverLELsandbubblingwasstilldetected,thewellwasmade operableasthereadingsweremuchlowerandwithinBP’ssafethresholds. In2019,thebubblingbecameworsewithLELsover10%andthewellwasmadenotoperable. IvishakAbandonmentPlug: TheproposedIvishakabandonmentplugwillbesetabovethetopofSag@10,690’.Thisiswithin50’MD abovethetopexistingperforationbutabovetheproductioncasingshoeandingoodcementofthe4Ͳ1/2”liner confirmedbyCBL.Aftersettingtheinflatableplug,wewilldumpbailsandtoprotectitforfutureretrievalprior todumping25’ofcementontopofthesand.Theplannedtopofcementisat10,655’insidetheproduction liner/casing.Wehavegoodcementinthe4Ͳ1/2”linerandexpectgoodcementqualityattheproductioncasing shoe.Withacementtopat10,655’,wewillhavegoodcircumferentialcoveragefrom10,680’–10,655’. AreaofReview–PBUSͲ16(PTD#184Ͳ084) PriortotheconversionofwellSͲ16fromIvishakInjectortoSchraderInjector,anAreaofReview(AOR)was conducted.ThisAORfound20wellswithin¼mileofSͲ16’sentrypointintotheSchraderFormation.See attachedtableAreaofReviewSͲ16forannulusintegrityandzonalisolationofallwellswithintheAOR. Twowellswithinthe1/4mileradiusdonothavecementacrosstheSchraderintervalwhencalculated volumetrically.ThesewellsareSͲ23,andSͲ36(seetablebelow). Hilcorprequestsavariancefrom20AAC25.402(b)duetonothavingadequatecementingdataacrossthe confiningzoneforwellswithinthe¼mileradiusofaninjectionwellunder20AAC25.402(h). Theassurancethattheinjectionzoneisisolatedisbasedonthefollowing: 1. HilcorpprovidesmonthlyTIOplotsofthetwowells.IfoutofzoneinjectionoccursalongsidetheunͲ cementedportionofthecasingsonthesewells,itmayshowupintheOApressureͲplotsasan anomaly. 2. HilcorpperformsPNL&TemperatureWaterͲFlowlogsinthethreewellsacrosstheSchraderinterval within6monthsafterinjectioncommences,andannuallythereafter. 16 wells withing 1/4 mile with volumetric cement calculation only and without CBLs to demonstrate isolation across SB will require assurance as describe in requirements 1 and 2 below for variance to 20 AAC 25.402 (b) - mgr RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 3. Alternatively,ifHilcorpperformsaCBLoftheProductionCasingonanyofthesetwowellsandsubmit toAOGCCforreview.IfsufficientcementisolationexistsacrosstheSchraderforanyofthetwowells thenthatwellwouldnotbesubjecttotherequirementsabove. SundryProcedure(ApprovalRequiredtoProceed) PreͲRig 1. ObtainupdatedpressuretestsonWHseals Slicklinewithfullboreassist 1. Drift 2. B&Ftubing 3. Pullcaliperfromtubingtailtosurface a. LookingtoevaluatetubingreͲusability b. Tubingis2015install,shouldbegoodtoreͲrun,saveifpossible 4. SetpluginXnipple@10,228’ 5. DummyGLVs 6. PullSt1GLVforcirc’inginKWF 7. Loadholewith2%KCl+Freezeprotect a. TotalT+IAvolumetoSt#1:635bbls b. Freezeprotectvolumeto2500’:171bbls 8. Obtain3500psiMITͲIA 9. MITͲTto3500psi 10. PullpluginX Eline 1. SpotEͲLineunittowell,RUandPT. 2. MU,RIHandsetIBPin@10,690’ a. Thisisabovethe9Ͳ5/8”shoebutweshouldbeingoodcementintheproductionlinerand goodcementattheproductioncasingshoe 3. Dumpbail10’ofsandonIBP a. 230#neededfor10’offillin7”26#liner 4. Dumpbail25’ofcementonIBP 5. Afterdumpbailingcement,statewitnessthetagofTOC. 6. Pressuretestcementplugto2500psi,statewitnesscementplugpressuretest 7. MUtubingcutterandRIHandcorrelate. 8. Pickupandcuttubingat10,180’ a. ~4’intopupontopofpacker b. CorrelatetoTubingTallydated2/13/2015. 9. RDMOEline. PreͲRWO*Note:Dependingontimingofrigmove,wellkillandBOPinstallationstepsmaybeperformedonrig ratherthanpreͲrig. Mostrecentstaticwasobtainedin2014.Thisvalueshouldbeaccurateand~2%KClmaybeusedasKWF. 1. Checkwellpressures,reͲkillwellasneeded 2. RDwellhouseandflowlines.Clearandlevelareaaroundwell. Completed 4-3-23 mgr25' minimum cement above top of sand. Completed 3/31/23 Completed 4/1/23 Completed 2/27/23 RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 3. SetBPVw/insert(TWC)andtest.NDTreeandTHA. 4. NUBOPEconfiguredtopdown:Annular,2Ͳ7/8”x5”VBRs,Blindsandintegralflowcross. RWOProcedure: 1. MIRUNordic3workoverrigandancillaryequipment 2. BleedTBG/IApressuresto~0psi.Killwellw/2%KClasneeded. 3. TestBOPEto250psiLow/3,000psiHigh,annularto250psiLow/2,500psiHigh(holdeachram/valve andtestfor5Ͳmin).RecordaccumulatorpreͲchargepressuresandcharttests. a. NotifyAOGCC24hoursinadvanceofBOPtest. b. PerformTestper“Nordic#3TestProcedure” c. ConfirmtestpressurespertheSundryConditionsofapproval. d. TestVBRramandAnnularon4Ͳ1/2”andon3Ͳ1/2”testjoint. e. SubmittoAOGCCcompleted10Ͳ424formwithin5daysofBOPEtest. 4. PullTWCinsertandBPV. a. UtilizelubricatorforBPVremovalifpotentialfortrappedpressureexists. 5. MUlandingjointorspear,BOLDSandPUonthetubinghanger. a. ~10,180’of4Ͳ1/2”12.6#tubingweighs~112klbs(buoyedby8.4ppgfluid) b. Ifpulledupto230Klbs(80%of4Ͳ1/2”yieldstrength)withnohangermovement,RUeline andperform2ndtubingcut,discusswithOE. 6. POOHandlaydownthe4Ͳ1/2”tubing. a. Savetubingifpossible,preͲrigcaliperwillinformjointstobediscarded b. Ifanygaulingatconnectionsisseen,discardthesejointsaswell 7. RUEline 8. PullCBLfromlinerhangertiebacksleeve@10,180’tosurfacetoverifycementqualityover Shrader/Kuparukinterval a. SendcopyoflogtoDavid.wages@hilcorp.com b. SendcopyoflogwithvendorTOCinterpretationtoAOGCC c. MustreceiveapprovalfromstatepriortoperforatingShraderinterval i. Ifwedonothavecementcoverage,wewillcompletethewellasaKuparukproducer andperforatepostrig. Must receive approval from AOGCC prior to running Kuparuk completion. - mgr email: melvin.rixse@alaska.gov RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 BelowRWOandpostrigstepsareforinstallingtheShraderInjectorCompletion,musthavestateapproval: 9. IfCBLshowsgoodShraderintervalisolation,usingCBLastieinlog,perforatethefollowingintervals: a. OAsand:~5437’–5475’MD(38’perfs) i. 26’betweenbottom/topperf b. OBasand:~5501’–5521’MD(20’perfs) i. 36’betweenbottom/topperf c. OBbsand:~5557’–5577’MD(20’perfs) i. 49’betweenbottom/topperf d. OBcsand:~5626’–5652’MD(26’perfs) i. 57’betweenbottom/topperf e. OBdsand:~5709’–5745’MD(36’perfs) f. Guns:2.875”MaxForce,175MaxForceHMXorsimilar i. 38.6penetration,0.37”EHD 10. AfterCBLconfirmationofcementoverShraderintervalandwithAOGCCapproval,PUnew/used 13Cr804Ͳ1/2”completionandrunperSͲ16ProposedShraderCompletionRunningOrder. a. LoadIAwithinhibitedKWFbrine b. Landtubingwithmuleshoe/WLEG@~5720’ c. EnsureRHCplugbodypreͲinstalledinlowermostXprofile 11. LandthetubinghangerandRILDS.Laydownlandingjoint.NotePickͲupandslackͲoffweightsontally. 12. Dropballandrodandhydraulicallysetthepackerspermanufacturer’ssettingprocedure a. ConductMITͲTto3500psiandMITͲIAto3,500psifor30mins(charted,statewitnessed) 13. ShearcircvalveinGLMandcircfreezeprotect. 14. Bleedtubingpressurebackto~0psi.SetBPVwithTWCinsert. 15. RDMONordicRigandancillaryequipment.Movetonextwelllocation. 16. RUcrane.NDBOPE. 17. NUthetubingheadadapterandtree.Testtubinghangervoidandtreeto500psilow/5,000psihigh. 18. PullBPVwithTWCinsert. 19. Replacewellhouseandgauge(s)ifremoved. Slickline 1. SpotSlicklineunit,RUandPT. 2. RIHandpullRHCplugfromXprofileat±5715’MD 3. DummyGLVabovetoppacker 4. IfShraderCompletion:InstallWFRVsperbelow: WFM#ApproxDepth,MDInjectionZoneWFRVValvedRate,bwpd 95437OA500 85475OA0 75501Oba500 65521Oba0 55557OBbGuttedw/checkvalve RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 45577OBbGuttedw/checkvalve 35626OBcGuttedw/checkvalve 25652OBcGuttedw/checkvalve 15709OBdGuttedw/checkvalve XͲnippleTubingtailOBdGuttedw/checkvalve 5. RDMO Operations 6. ObtainAOGCCwitnessedSVStestwithin5daysofputtingwellonline. BelowRWOandpostrigstepsareforinstallingtheKuparukProducerCompletion,musthavestateapproval: 20. AfterCBLconfirmationofcementoverKuparukintervalandwithAOGCCapproval,PUnew/used 13Cr804Ͳ1/2”completionandrunperSͲ16ProposedKuparukCompletionRunningOrder. d. LoadIAwithinhibitedKWFbrine e. Landtubingwithmuleshoe/WLEG@~7650’ f. EnsureRHCplugbodypreͲinstalledinlowermostXprofile 21. LandthetubinghangerandRILDS.Laydownlandingjoint.NotePickͲupandslackͲoffweightsontally. 22. Dropballandrodandhydraulicallysetthepackerspermanufacturer’ssettingprocedure b. ConductMITͲTto3500psiandMITͲIAto3,500psifor30mins(charted,statewitnessed) 23. ShearcircvalveinshallowGLMandcircfreezeprotect. 24. Bleedtubingpressurebackto~0psi.SetBPVwithTWCinsert. 25. RDMONordicRigandancillaryequipment.Movetonextwelllocation. 26. RUcrane.NDBOPE. 27. NUthetubingheadadapterandtree.Testtubinghangervoidandtreeto500psilow/5,000psihigh. 28. PullBPVwithTWCinsert. 29. Replacewellhouseandgauge(s)ifremoved. Slickline 7. SpotSlicklineunit,RUandPT. 8. RIHandpullRHCplugfromXprofileintubingtail 9. InstallLGLVsperGLengineer 10. RDMO Eline–IfKuparukCompletion 11. Perforatepergeologist~50’ofshots,CBLmidworkoverwillbetieinlog a. Chargeswillbe2Ͳ7/8”MaxForceorsimilar b. 6SPF c. 60degPhasing Testers 12. POPwell a. Startwellatminimumchokeand1mmscfduntilwellIAclearedandwellisflowing RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 b. Afterwellisonlineandstable,Openchoke~10stepsperhour,checkingsolidseverychoke adjustmentandbottomsup c. IncreaseGLasneededtokeepflowstable d. Obtain8hourpiggybackwelltestwithpadseparatorpriortoRDMO Operations 13. ObtainAOGCCwitnessedSVStestwithin5daysofputtingwellonline. NOTE:ifcompletedasaKuparukproducer,wewillneedtoaddressthesurfacecasingreͲpressurization,this programwillbesubmittedimmediatelyaftertherigmovesoffthewell.Also,wewilllikelywanttofracthe Kuparuk,aseparatefracsundryandprogramwillbesubmitted.ThisprogramonlycoverstheRWO. IfcompletedasaShraderinjector,thewellworkiscomplete. RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 CurrentWBD: RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 ProposedShraderInjectorWBD: RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 ProposedContingentKuparukProducerWBD: RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 NordicRig3BOPSchematic RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 LinertopareaCBLandIBPsetdepthtiein: RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 10,700’ 10,600’ 10,500’ 9Ͳ5/8” Production CasingShoe: 10,693’ IBPSet@10,690’ 10’ofsand,Top @10,680’ 25’ofcement,top @10,655’ RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 TubingTally: RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 AORMap RecompletetoShrader(KuparukContingent) Well:SͲ16 CurrentPTD:184Ͳ084 AORTable: Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Well Name:S-16 API Number:50-029-21123-00 Current Status:Not Operable due to SC leak to only hot gas lift gas Estimated Start Date:4/15/23 Rig:Thunderbird 1 Sundry #?323-042, TBD Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:184-084 First Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Second Call Engineer:Claire Mayfield (970) 443-3631 (M) Current Bottom Hole Pressure:3341 psi @ 8799’ TVD 7.3 PPG | (1/25/2014 static) 7.6 PPG with 2500’ freeze protect Max. Anticipated Surface Pressure:2461 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:110 psi (Taken on 12/25/2022) Min ID:3.725” XN at 10,447’ MD Max Angle:53.2 Deg @ 5,600’ MD 70 deg: N/A Formation Tops: Shrader: 5251’ MD, 4943’ TVD Kuparuk: 7778’ MD, 6664’ TVD Sag: 10,700’ MD, 8799’ TVD Sadlerochit: 10,877’ MD, 8933’ TVD MITs: CMIT-TxIA: 2428 psi on 8/3/2019 Objective: The Ivishak reservoir no longer remains economically viable and both the Schrader and the Kuparuk interval for S-16 motherbore is in a perfect location to re-complete the well to uphole production/injection. A RWO is planned to determine cement top via CBL and to recomplete to Schrader injection if the cement is high enough or Kuparuk production if the cement is below the top of Shrader. Well Summary: The well was drilled as an exploratory well in NWFB targeting Z4 Ivishak in 1984. After setting and cementing the surface casing, a top job on the surface casing was performed then the casing was tested to 3000 psi for an initial fail. A cement retainer was set just above the shoe @ 2620’ and 300 cu ft of Permafrost C cement was squeezed below for a good test. After drilling out the shoe, they were unable to drill past “junk” just below shoe so a kick-off plug consisting of 186 cu ft Arctic Set II was pumped. The production hole section was drilled and cored with a 12-1/4” bit fairly uneventfully, 9-5/8” casing was run and cemented at 10,693’ with 2260 cuft class G with some additives followed by 230 cuft class G neat. The production liner was run after an uneventful 8-1.2” hole section was drilled. The 7” liner was cemented in place with 312 cuft Class G with some additives. Finally, the 9-5/8” x 13-3/8” annulus was downsqueezed with 279 cuft Arctic Set II cement followed by arctic pack. In April 1992, a workover was performed to upsize the tubing to 4-1/2” 13Cr from 3-1/2” tubing and address a leak in the 3-1/2” tubing. In 2002, bubbling was identified in the cellar and a waiver for IAxOA communication was granted. The well was then produced on and off until the waiver expired in 2004, when the well was shut in. On 9/11/2011, an MIT-T failed indicating TxIA communication. o determine cement top via CBL a bubbling w Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 2015 RWO for IAxOA repair: pulled tubing, ran USIT from ~2800’ to surface, found little cement below 2225’, good cement from 2225’ – 1610’ and no cement above 1610’. Set RBP @ 1593’, PT to 1000 psi, cut casing at 1520’, speared and POH with 9-5/8” casing fine. “Casing was in good condition, no major corrosion noted.” After cutting off the 13-3/8” starting head, a landing ring with a slip bowl was installed and the 9-5/8” overshot, ECP and cementing valve was run and cemented in place with 115 bbls of 15.8 ppg class G. Cemented per plan with good indication the cementing valve closed. A 9-5/8” sliplock startinghead was installed then the cement around the cementing valve was drilled out and pressure tested to 3500 psi for a passing test. 4-1/2” tubing was run to achieve current well condition. The tubing and IA was pressure tested to 3500 for passing tests. The IA passed 3700 psi with 0 psi lost. Shortly after the RWO, the bubbling was again observed in the cellar.An MIT-T and MIT-IA was performed, both of which passed. GLVs were re-installed and the well was stacked out cold with AL on 3/16/16. Over the next two months, the well was left stacked out and no bubbling was observed. However, when the well was popped, 2 days later LELs we observed. After shutting in the IA, the LEL readings went to zero. In 2017, a wellock top job was performed, however LELs and bubbling was still detected, the well was made operable as the readings were much lower and within BP’s safe thresholds. In 2019, the bubbling became worse with LELs over 10% and the well was made not operable. Ivishak Abandonment Plug: The proposed Ivishak abandonment plug will be set above the top of Sag @ 10,690’. This is within 50’ MD above the top existing perforation but above the production casing shoe and in good cement of the 4-1/2” liner confirmed by CBL. After setting the inflatable plug, we will dump bail sand to protect it for future retrieval prior to dumping 25’ of cement on top of the sand. The planned top of cement is at 10,655’ inside the production liner/casing. We have good cement in the 4-1/2” liner and expect good cement quality at the production casing shoe. With a cement top at 10,655’, we will have good circumferential coverage from 10,680’ – 10,655’. Area of Review – PBU S-16 (PTD # 184-084) Prior to the conversion of well S-16 from Ivishak Injector to Schrader Injector, an Area of Review (AOR) was conducted. This AOR found 20 wells within ¼ mile of S-16’s entry point into the Schrader Formation. See attached table Area of Review S-16 for annulus integrity and zonal isolation of all wells within the AOR. Two wells within the 1/4 mile radius do not have cement across the Schrader interval when calculated volumetrically. These wells are S-20, and S-24 (see table below). Hilcorp requests a variance from 20 AAC 25.402 (b) due to not having adequate cementing data across the confining zone for wells within the ¼ mile radius of an injection well under 20 AAC25.402(h). The assurance that the injection zone is isolated is based on the following: 1. Hilcorp provides monthly TIO plots of the two wells. If out of zone injection occurs alongside the un- cemented portion of the casings on these wells, it may show up in the OA pressure-plots as an anomaly. 2. Hilcorp performs PNL & Temperature Water-Flow logs in the three wells across the Schrader interval within 6 months after injection commences, and annually thereafter. 3. Alternatively, if Hilcorp performs a CBL of the Production Casing on any of these two wells and submit to AOGCC for review. If sufficient cement isolation exists across the Schrader for any of the two wells then that well would not be subject to the requirements above. Hilcorp requests a variance from 20 AAC 25.402 (b) d In 2019, the bubbling became worse with LELs over 10% and the well was made not operable. e bubbling was again observed Two wells within the 1/4 mile radius do not have cement across the Schrader interval w Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Sundry Procedure (Approval Required to Proceed) Pre-Rig 1. Obtain updated pressure tests on WH seals Slickline with fullbore assist Complete 2/27/23 1. Drift 2. B&F tubing 3. Pull caliper from tubing tail to surface a. Looking to evaluate tubing re-usability b. Tubing is 2015 install, should be good to re-run, save if possible 4. Set plug in X nipple @ 10,228’ 5. Dummy GLVs 6. Pull St1 GLV for circ’ing in KWF 7. Load hole with 2% KCl + Freeze protect a. Total T+IA volume to St#1: 635 bbls b. Freeze protect volume to 2500’: 171 bbls 8. Obtain 3500 psi MIT-IA 9. MIT-T to 3500 psi 10. Pull plug in X Eline 1. Spot E-Line unit to well, RU and PT. 2. MU, RIH and set IBP in @ 10,690’Complete 3/31/23 a. This is above the 9-5/8” shoe but we should be in good cement in the production liner and good cement at the production casing shoe 3. Dump bail 10’ of sand on IBP Complete 4/1/23 a. 230# needed for 10’ of fill in 7” 26# liner 4. Dump bail 25’ of cement on IBP Complete 4/3/23 5. After dump bailing cement,state witness the tag of TOC. 6. Pressure test cement plug to 2500 psi,state witness cement plug pressure test 7. MU tubing cutter and RIH and correlate. 8. Pick up and cut tubing at 10,180’ a. ~4’ into pup on top of packer b. Correlate to Tubing Tally dated 2/13/2015. 9. RDMO Eline. Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. Most recent static was obtained in 2014. This value should be accurate and ~2% KCl may be used as KWF. 1. Check well pressures, re-kill well as needed 2. RD well house and flowlines. Clear and level area around well. 3. Set BPV w/insert (TWC) and test. ND Tree and THA. mgr25' minimum cement above top of sand. Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 4. NU BOPE configured top down: Annular, 2-7/8” x 5” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Thunderbird 1 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/2% KCl as needed. 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Thunderbird 1 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 4-1/2”and on 3-1/2”test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. ~10,180’ of 4-1/2” 12.6# tubing weighs ~ 112klbs (buoyed by 8.4 ppg fluid) b. If pulled up to 230 Klbs (80% of 4-1/2” yield strength) with no hanger movement, RU eline and perform 2 nd tubing cut, discuss with OE. 6. POOH and lay down the 4-1/2” tubing. a. Save tubing if possible, pre-rig caliper will inform joints to be discarded b. If any galling at connections is seen, discard these joints as well 7. RU Eline 8. Pull CBL from liner hanger tieback sleeve @ 10,180’ to surface to verify cement quality over Schrader/Kuparuk interval a. Send copy of log to David.wages@hilcorp.com b. Send copy of log with vendor TOC interpretation to AOGCC c.Must receive approval from state prior to perforating Schrader interval i.If we do not have cement coverage, we will complete the well as a Kuparuk producer and perforate post rig. Below RWO and post rig steps are for installing the Schrader Injector Completion, must have state approval: 9. If CBL shows good Schrader interval isolation, using CBL as tie in log, perforate the following intervals: a. OA sand: ~5437’ – 5475’ MD (38’ perfs) b. OBa sand: ~5501’ – 5521’ MD (20’ perfs) c. OBb sand: ~5557’ – 5577’ MD (20’ perfs) d. OBc sand: ~5626’ – 5652’ MD (26’ perfs) e. OBd sand: ~5709’ – 5745’ MD (36’ perfs) f. Guns: 2.875” MaxForce, 175 MaxForce HMX or similar i. 38.6 penetration, 0.37” EHD 10. After CBL confirmation of cement over Schrader interval and with AOGCC approval, PU new/used 13Cr80 4-1/2” completion and run per S-16 Proposed Schrader Completion Running Order. Must recieve approval from state prior to running Kuparuk completion. -bjm Must receive approval from state prior to perforating Schrader interval email: melvin.rixse@alaska.gov Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 a. Load IA with inhibited KWF brine b. Land tubing with mule shoe/WLEG @ ~5720’ c. Ensure RHC plug body pre-installed in lowermost X profile 11. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 12. Drop ball and rod and hydraulically set the packers per manufacturer’s setting procedure a. Conduct MIT-T to 3500 psi and MIT-IA to 3,500 psi for 30 mins (charted, state witnessed) 13. Shear circ valve in GLM and circ freeze protect. 14. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 15. RDMO Thunderbird 1 Rig and ancillary equipment. Move to next well location. 16. RU crane. ND BOPE. 17. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 18. Pull BPV with TWC insert. 19. Replace wellhouse and gauge(s) if removed. Slickline 1. Spot Slickline unit, RU and PT. 2. RIH and pull RHC plug from X profile at ±5715’ MD 3. Dummy GLV above top packer 4. If Schrader Completion: Install WFRVs per below: WFM #Approx Depth, MD Injection Zone WFRV Valved Rate, bwpd 9 5437 OA 500 8 5475 OA 0 7 5501 Oba 500 6 5521 Oba 0 5 5557 OBb Gutted w/ check valve 4 5577 OBb Gutted w/ check valve 3 5626 OBc Gutted w/ check valve 2 5652 OBc Gutted w/ check valve 1 5709 OBd Gutted w/ check valve X-nipple Tubing tail OBd Gutted w/ check valve 5. RDMO Operations 6. Obtain AOGCC witnessed SVS test within 5 days of putting well online. Below RWO and post rig steps are for installing the Kuparuk Producer Completion, must have state approval: 20. After CBL confirmation of cement over Kuparuk interval and with AOGCC approval, PU new/used 13Cr80 4-1/2” completion and run per S-16 Proposed Kuparuk Completion Running Order. d. Load IA with inhibited KWF brine e. Land tubing with mule shoe/WLEG @ ~7650’ f. Ensure RHC plug body pre-installed in lowermost X profile Dummy GLV above top packer Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 21. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 22. Drop ball and rod and hydraulically set the packers per manufacturer’s setting procedure b. Conduct MIT-T to 3500 psi and MIT-IA to 3,500 psi for 30 mins (charted, state witnessed) 23. Shear circ valve in shallow GLM and circ freeze protect. 24. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 25. RDMO Nordic Rig and ancillary equipment. Move to next well location. 26. RU crane. ND BOPE. 27. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 28. Pull BPV with TWC insert. 29. Replace wellhouse and gauge(s) if removed. Slickline 7. Spot Slickline unit, RU and PT. 8. RIH and pull RHC plug from X profile in tubing tail 9. Install LGLVs per GL engineer 10. RDMO Eline – If Kuparuk Completion 11. Perforate per geologist ~ 50’ of shots, CBL mid workover will be tie in log a. Charges will be 2-7/8” MaxForce or similar b. 6 SPF c. 60 deg Phasing Testers 12. POP well a. Start well at minimum choke and 1 mmscfd until well IA cleared and well is flowing b. After well is online and stable, Open choke ~10 steps per hour, checking solids every choke adjustment and bottoms up c. Increase GL as needed to keep flow stable d. Obtain 8 hour piggyback well test with pad separator prior to RDMO Operations 13. Obtain AOGCC witnessed SVS test within 5 days of putting well online. NOTE: if completed as a Kuparuk producer, we will need to address the surface casing re-pressurization, this program will be submitted immediately after the rig moves off the well. Also, we will likely want to frac the Kuparuk, a separate frac sundry and program will be submitted. This program only covers the RWO. If completed as a Schrader injector, the wellwork is complete. Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Current WBD: Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Proposed Schrader Injector WBD: Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Proposed Contingent Kuparuk Producer WBD: Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Thunderbird 1 BOP Schematic Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Liner top area CBL and IBP set depth tie in: Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Tubing Tally: 10,700’ 10,600’ 10,500’ 9-5/8” Production Casing Shoe: 10,693’ IBP Set @ 10,690’ 10’ of sand, Top @ 10,680’ 25’ of cement, top @ 10,655’ Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 AOR Map Superseded Recomplete to Schrader (Kuparuk Contingent) Well: S-16 AOR Table: (OA) No Cem ent for SB ? Che ck No Cem ent for SB ? TOC ~ 5,110' MD Superseded Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: April 6, 2023Subject: Changes to Approved Sundry Procedure for Well S-16ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 1 Davies, Stephen F (OGC) From:Brodie Wages <David.Wages@hilcorp.com> Sent:Monday, April 10, 2023 3:54 PM To:Davies, Stephen F (OGC) Cc:McLellan, Bryan J (OGC) Subject:RE: [EXTERNAL] PBU S-16 (PTD 184-084; Sundry 323-213) - Question HelloSteve, LastupdateI’veheardisthattheworkoverrigshouldbecomingbackfromBadamiaround4/22,sowehavealittle time. Backoftheenvelop,Igeta25%increaseinthevolumegivesustheTOCreportedintheAORforSͲ04.We’veusedthis listofAORwellsforseveraloftherecompleteswehavedoneintheareasoI’veaskedtheoriginalauthortohelpmeout withhiscalculationsforSͲ23asthatsame25%excessdidn’tfindthesameTOCforme. Wewillhaveananswerforyouverysoon. David“Brodie”Wages OpsEngineer C:713.380.9836 From:Davies,StephenF(OGC)<steve.davies@alaska.gov> Sent:Monday,April10,20232:16PM To:BrodieWages<David.Wages@hilcorp.com> Cc:McLellan,BryanJ(OGC)<bryan.mclellan@alaska.gov> Subject:[EXTERNAL]PBUSͲ16(PTD184Ͳ084;Sundry323Ͳ213)ͲQuestion Brodie, I’mreviewingHilcorp’sSundryApplicationtoconvertPBUSͲ16toaninjectorinthePolarisOilPool.I’mconfirming cementisolationfortheSchraderBluffinterval,andIwanttomakesurethatmycalculationmethodagreeswith Hilcorp’s.Couldyoupleaseprovideacopyofyourvolumetriccalculationsthatshowhowyouestimatethetopof cementforacoupleofexamplewellsforme?Let’srandomlychoosetwowells:PBUSͲ04(PTD183Ͳ079–firstwellon thelist)andPBUSͲ23(190Ͳ127—fromthemiddleofthelist). CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION:Externalsender.DONOTopenlinksorattachmentsfromUNKNOWNsenders. 2 ThisrequesthasasomewhattightturnaroundtimeastheestimatedoperationsstartdateisApril15th.Isthatdatestill accurate? Thanksandstaysafe, SteveDavies AOGCC CONFIDENTIALITYNOTICE:ThiseͲmailmessage,includinganyattachments,containsinformationfromtheAlaskaOilandGasConservationCommission (AOGCC),StateofAlaskaandisforthesoleuseoftheintendedrecipient(s).Itmaycontainconfidentialand/orprivilegedinformation.Theunauthorizedreview,use ordisclosureofsuchinformationmayviolatestateorfederallaw.IfyouareanunintendedrecipientofthiseͲmail,pleasedeleteit,withoutfirstsavingorforwarding it,and,sothattheAOGCCisawareofthemistakeinsendingittoyou,contactSteveDaviesat907Ͳ793Ͳ1224orsteve.davies@alaska.gov. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1Davies, Stephen F (OGC)From:Brodie Wages <David.Wages@hilcorp.com>Sent:Friday, April 14, 2023 4:34 AMTo:Davies, Stephen F (OGC); McLellan, Bryan J (OGC)Subject:RE: [EXTERNAL] PBU S-16 (PTD 184-084; Sundry 323-213) - QuestionAttachments:AOR for S-16 (4-14-2023).xlsx; PBU S-16 Recomplete to Kuparuk RWO program VER2 4-13-23.docxHelloSteve,Bryan,IttookmeabitasIhadtorecalculateeveryTOCafterthefindingsdescribedinmyoriginalnote.Tosummarize,theoriginalAORhad2wellsincludedinthe“watchlist”thatwesaidtheydidn’thaveenoughannularcementcoverage,SͲ20andSͲ24(highlightedinyellowbelow):CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 3Itwasmymistake,butIdidnotrecalculatetheTOCforthewellsabovethatareshadedred.TheywerepartofthepreviouslyapprovedSͲ15AORsoImadetheassumptionthatthoseTOCsweregoodtogo.Afteryourinitialemail,IwasstrugglingtogetTOCtomatchonSͲ23soIreͲcalculatedtheentiretable: 4 5Thevolumetriccalculationsthistimesaidthatourpreviouswellsofconcern(SͲ20andSͲ24)wefinebutrevealedthatSͲ23andSͲ36hadcementcoverageissues.TheoldandnewAORtablesareattachedintheexcelfileintheemail,thecalculationsforallthecementtopsareinthetablejusttotheright.IfwehaveaCBL/USITintheproductioncasing,I’veincludedthecementtopandthenusedtheloggedcementtopoverthecalculatedone.Thereareacouplethingstonote:x IntheoldAOR,Iadjustedthewashout%togetthevolumetriccalculationtomatchwhatwasoriginallyreported,youcanseethatthe%washoutnumberitselfchangesquiteabitx InthenewAOR,Ileftallthe%washoutnumbersas25%ifwedidn’thavealogoverthewell’sproductioncasingx In3outof4oftheloggedTOCs,thewashout%is0%x InSͲ26wherethereportedTOCisquiteabitlowerthanitneedstobe,thelogshowsmanystringersofcementaboveandbelowshraderthatadduptoover5000’MDofcementbetweenDPZs,ThegoodnewsforusisthatIfeelconfidentinsayingthatthevolumetriccalculationsareconservativeasevidencedbythe0%washoutneededtobeappliedtothevolumetriccalculationstocorrecttotheloggedTOCs.WeknowhistoricallyinEWEthatwe’vehadquiteafewwellswithshalesloughinginwhilewearedrillingthemwhichmayaccountforthechannelingseenattimeswhichwouldleadtohigherthanexpectedcementtops.Alsogoodforusisthatthetwonewwellsofconcernbothhaveacementtopthatisvolumetricallycalculatedwhichmeansthetopshouldbehigherthandisplayedifweweretoassumea0%washout.Next,IwillspreadthisAORtablewiththecalculationswithmyteamtoensurethecalculationsareperformedinthesamewayandfuturesundriespresentthesamedatawiththesameassumptions.Finally,pleaseseeattachedupdatedprogramwhichupdatesthetwomonitorwellsweneedtowatch.David“Brodie”WagesOpsEngineerC:713.380.9836The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:McLellan, Bryan J (OGC) To:Brodie Wages Cc:Rixse, Melvin G (OGC) Subject:RE: S-16 (PTD: 184-084) Ivishak P&A Plug Date:Friday, March 31, 2023 11:50:00 AM Attachments:image001.png image002.png Brodie, Hilcorp has approval to move the cement plug up 20’ shallower than written in the Sundry 323-042 as requested in your email below. Bryan McLellan Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, AK 99501 Bryan.mclellan@alaska.gov +1 (907) 250-9193 From: Brodie Wages <David.Wages@hilcorp.com> Sent: Friday, March 31, 2023 10:09 AM To: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Subject: RE: S-16 (PTD: 323-042) Ivishak P&A Plug Sundry attached this time. David “Brodie” Wages Ops Engineer C: 713.380.9836 From: Brodie Wages Sent: Friday, March 31, 2023 10:00 AM To: bryan.mclellan@alaska.gov Subject: S-16 (PTD: 323-042) Ivishak P&A Plug Hello Bryan, We are seeking approval to move the Ivishak P&A IBP plug and subsequent dump bailed cement from the approved set depth of 10,690’ up to 10,670’. Please see attached approved sundry for the work, the below screenshot shows the physical log of the cement on the 7” liner. Moving the IBP up 20’ keeps the dump bailed cement within good quality cement of the 7” liner and remains very near the 9-5/8” production casing shoe. Please let me know if additional information is needed. David “Brodie” Wages Ops Engineer C: 713.380.9836 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU S-16 Recomplete Well Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 184-084 50-029-21123-00-00 341J / 457B ADL 0028257 11300 Conductor Surface Intermediate Production Liner 9248 80 2643 10665 864 11189 20" x 30" 13-3/8" 9-5/8" 7" 9166 31 - 111 30 - 2673 28 - 10693 10436 - 11300 2461 31 - 111 30 - 2673 28 - 8794 8603 - 9248 10965 2670 4760 5410 None 5380 6870 7240 10704 - 10964 4-1/2" 12.6# 13Cr85 / 13cr80 26 - 104598802 - 8998 Structural 4-1/2" HES TNT Packer 4-1/2" Baker SB-3 Packer 10192, 8428 10354, 8543 Date: Stan Golis Sr. Area Operations Manager Brodie Wages David.Wages@hilcorp.com 907.564.5006 PRUDHOE BAY 2/15/2023 Current Pools: PRUDHOE OIL Proposed Pools: Aurora / Schrader Bluff, Polaris STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov No SSSV Installed By Samantha Carlisle at 7:07 am, Jan 26, 2023 323-042 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2023.01.25 15:44:39 -09'00' Stan Golis (880) MGR03FEB23 10-404 * BOPE test to 3000 psi. Annular 2500 psi. * State to witness Eline tag (~10,655' MD minimum) and pressure test to 2500 psi of reservoir abandonment plug. * Email complete CBL to melvin.rixse@alaska.gov * For Polaris SB WINJ completion, AOGCC to witness MIT-IA to 3500 psi. * For Polaris SB WINJ completion AOGCC to witness MIT-IA to 3500 psi within 5 days of stabilized injection. * Variance to X DLB 02/01/2023 DSR-1/26/23GCW 02/09/23 20 AAC 25.112 (c)(1)(E) approved for setting bridge plug >50' above top perforation. Bridge plug to be placed above TSAD and within the PB oil pool confining zones. JLC 2/9/2023 2/10/23Brett W. Huber, Sr.Digitally signed by Brett W. Huber, Sr. Date: 2023.02.10 12:00:28 -09'00' RBDMS JSB 021023 Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Well Name:S-16 API Number:50-029-21123-00 Current Status:Not Operable due to SC leak to only hot gas lift gas Estimated Start Date:3/21/23 Rig:Nordic 3 Sundry #?Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:184-084 First Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Second Call Engineer:Claire Mayfield (970) 443-3631 (M) Current Bottom Hole Pressure:3341 psi @ 8799’ TVD 7.3 PPG | (1/25/2014 static) 7.6 PPG with 2500’ freeze protect Max. Anticipated Surface Pressure:2461 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:110 psi (Taken on 12/25/2022) Min ID:3.725” XN at 10,447’ MD Max Angle:53.2 Deg @ 5,600’ MD 70 deg: N/A Formation Tops: Shrader: 5251’ MD, 4943’ TVD Kuparuk: 7778’ MD, 6664’ TVD Sag: 10,700’ MD, 8799’ TVD Sadlerochit: 10,877’ MD, 8933’ TVD MITs: CMIT-TxIA: 2428 psi on 8/3/2019 Objective: The Ivishak reservoir no longer remains economically viable and both the Schrader and the Kuparuk interval for S-16 motherbore is in a perfect location to re-complete the well to uphole production/injection. A RWO is planned to determine cement top via CBL and to recomplete to Schrader injection if the cement is high enough or Kuparuk production if the cement is below the top of Shrader. Well Summary: The well was drilled as an exploratory well in NWFB targeting Z4 Ivishak in 1984. After setting and cementing the surface casing, a top job on the surface casing was performed then the casing was tested to 3000 psi for an initial fail. A cement retainer was set just above the shoe @ 2620’ and 300 cu ft of Permafrost C cement was squeezed below for a good test. After drilling out the shoe, they were unable to drill past “junk” just below shoe so a kick-off plug consisting of 186 cu ft Arctic Set II was pumped. The production hole section was drilled and cored with a 12-1/4” bit fairly uneventfully, 9-5/8” casing was run and cemented at 10,693’ with 2260 cuft class G with some additives followed by 230 cuft class G neat. The production liner was run after an uneventful 8-1.2” hole section was drilled. The 7” liner was cemented in place with 312 cuft Class G with some additives. Finally, the 9-5/8” x 13-3/8” annulus was downsqueezed with 279 cuft Arctic Set II cement followed by arctic pack. In April 1992, a workover was performed to upsize the tubing to 4-1/2” 13Cr from 3-1/2” tubing and address a leak in the 3-1/2” tubing. In 2002, bubbling was identified in the cellar and a waiver for IAxOA communication was granted. The well was then produced on and off until the waiver expired in 2004, when the well was shut in. On 9/11/2011, an MIT-T failed indicating TxIA communication. -00 DLB Recomplete to Schrader (Kuparuk Contingent) Well: S-16 2015 RWO for IAxOA repair: pulled tubing, ran USIT from ~2800’ to surface, found little cement below 2225’, good cement from 2225’ – 1610’ and no cement above 1610’. Set RBP @ 1593’, PT to 1000 psi, cut casing at 1520’, speared and POH with 9-5/8” casing fine. “Casing was in good condition, no major corrosion noted.” After cutting off the 13-3/8” starting head, a landing ring with a slip bowl was installed and the 9-5/8” overshot, ECP and cementing valve was run and cemented in place with 115 bbls of 15.8 ppg class G. Cemented per plan with good indication the cementing valve closed. A 9-5/8” sliplock startinghead was installed then the cement around the cementing valve was drilled out and pressure tested to 3500 psi for a passing test. 4-1/2” tubing was run to achieve current well condition. The tubing and IA was pressure tested to 3500 for passing tests. The IA passed 3700 psi with 0 psi lost. Shortly after the RWO, the bubbling was again observed in the cellar.An MIT-T and MIT-IA was performed, both of which passed. GLVs were re-installed and the well was stacked out cold with AL on 3/16/16. Over the next two months, the well was left stacked out and no bubbling was observed. However, when the well was popped, 2 days later LELs we observed. After shutting in the IA, the LEL readings went to zero. In 2017, a wellock top job was performed, however LELs and bubbling was still detected, the well was made operable as the readings were much lower and within BP’s safe thresholds. In 2019, the bubbling became worse with LELs over 10% and the well was made not operable. Ivishak Abandonment Plug: The proposed Ivishak abandonment plug will be set above the top of Sag @ 10,690’. This is within 50’ MD above the top existing perforation but above the production casing shoe and in good cement of the 4-1/2” liner confirmed by CBL. After setting the inflatable plug, we will dump bail sand to protect it for future retrieval prior to dumping 25’ of cement on top of the sand. The planned top of cement is at 10,655’ inside the production liner/casing. We have good cement in the 4-1/2” liner and expect good cement quality at the production casing shoe. With a cement top at 10,655’, we will have good circumferential coverage from 10,680’ – 10,655’. Area of Review – PBU S-16 (PTD # 184-084) Prior to the conversion of well S-16 from Ivishak Injector to Schrader Injector, an Area of Review (AOR) was conducted. This AOR found 20 wells within ¼ mile of S-16’s entry point into the Schrader Formation. See attached table Area of Review S-16 for annulus integrity and zonal isolation of all wells within the AOR. Two wells within the 1/4 mile radius do not have cement across the Schrader interval when calculated volumetrically. These wells are S-20, and S-24 (see table below). Hilcorp requests a variance from 20 AAC 25.402 (b) due to not having adequate cementing data across the confining zone for wells within the ¼ mile radius of an injection well under 20 AAC25.402(h). The assurance that the injection zone is isolated is based on the following: 1. Hilcorp provides monthly TIO plots of the two wells. If out of zone injection occurs alongside the un- cemented portion of the casings on these wells, it may show up in the OA pressure-plots as an anomaly. 2. Hilcorp performs PNL & Temperature Water-Flow logs in the three wells across the Schrader interval within 6 months after injection commences, and annually thereafter. 3. Alternatively, if Hilcorp performs a CBL of the Production Casing on any of these two wells and submit to AOGCC for review. If sufficient cement isolation exists across the Schrader for any of the two wells then that well would not be subject to the requirements above. Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Sundry Procedure (Approval Required to Proceed) Pre-Rig 1. Obtain updated pressure tests on WH seals Slickline with fullbore assist 1. Drift 2. B&F tubing 3. Pull caliper from tubing tail to surface a. Looking to evaluate tubing re-usability b. Tubing is 2015 install, should be good to re-run, save if possible 4. Set plug in X nipple @ 10,228’ 5. Dummy GLVs 6. Pull St1 GLV for circ’ing in KWF 7. Load hole with 2% KCl + Freeze protect a. Total T+IA volume to St#1: 635 bbls b. Freeze protect volume to 2500’: 171 bbls 8. Obtain 3500 psi MIT-IA 9. MIT-T to 3500 psi 10. Pull plug in X Eline 1. Spot E-Line unit to well, RU and PT. 2. MU, RIH and set IBP in @ 10,690’ a. This is above the 9-5/8” shoe but we should be in good cement in the production liner and good cement at the production casing shoe 3. Dump bail 10’ of sand on IBP a. 230# needed for 10’ of fill in 7” 26# liner 4. Dump bail 25’ of cement on IBP 5. After dump bailing cement,state witness the tag of TOC. 6. Pressure test cement plug to 2500 psi,state witness cement plug pressure test 7. MU tubing cutter and RIH and correlate. 8. Pick up and cut tubing at 10,180’ a. ~4’ into pup on top of packer b. Correlate to Tubing Tally dated 2/13/2015. 9. RDMO Eline. Pre-RWO*Note: Depending on timing of rig move, well kill and BOP installation steps may be performed on rig rather than pre-rig. Most recent static was obtained in 2014. This value should be accurate and ~2% KCl may be used as KWF. 1. Check well pressures, re-kill well as needed 2. RD well house and flowlines. Clear and level area around well. 3. Set BPV w/insert (TWC) and test. ND Tree and THA. Recomplete to Schrader (Kuparuk Contingent) Well: S-16 4. NU BOPE configured top down: Annular, 2-7/8” x 5” VBRs, Blinds and integral flow cross. RWO Procedure: 1. MIRU Nordic 3 workover rig and ancillary equipment 2. Bleed TBG/IA pressures to ~0psi. Kill well w/2% KCl as needed. 3. Test BOPE to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per “Nordic #3 Test Procedure” c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR ram and Annular on 4-1/2”and on 3-1/2”test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 4. Pull TWC insert and BPV. a. Utilize lubricator for BPV removal if potential for trapped pressure exists. 5. MU landing joint or spear, BOLDS and PU on the tubing hanger. a. ~10,180’ of 4-1/2” 12.6# tubing weighs ~ 112klbs (buoyed by 8.4 ppg fluid) b. If pulled up to 230 Klbs (80% of 4-1/2” yield strength) with no hanger movement, RU eline and perform 2nd tubing cut, discuss with OE. 6. POOH and lay down the 4-1/2” tubing. a. Save tubing if possible, pre-rig caliper will inform joints to be discarded b. If any galling at connections is seen, discard these joints as well 7. RU Eline 8. Pull CBL from liner hanger tieback sleeve @ 10,180’ to surface to verify cement quality over Schrader/Kuparuk interval a. Send copy of log to David.wages@hilcorp.com b. Send copy of log with vendor TOC interpretation to AOGCC c.Must receive approval from state prior to perforating Schrader interval i.If we do not have cement coverage, we will complete the well as a Kuparuk producer and perforate post rig. Below RWO and post rig steps are for installing the Schrader Injector Completion, must have state approval: 9. If CBL shows good Schrader interval isolation, using CBL as tie in log, perforate the following intervals: a. OA sand: ~5437’ – 5475’ MD (38’ perfs) b. OBa sand: ~5501’ – 5521’ MD (20’ perfs) c. OBb sand: ~5557’ – 5577’ MD (20’ perfs) d. OBc sand: ~5626’ – 5652’ MD (26’ perfs) e. OBd sand: ~5709’ – 5745’ MD (36’ perfs) f. Guns: 2.875” MaxForce, 175 MaxForce HMX or similar i. 38.6 penetration, 0.37” EHD 10. After CBL confirmation of cement over Schrader interval and with AOGCC approval, PU new/used 13Cr80 4-1/2” completion and run per S-16 Proposed Schrader Completion Running Order. Recomplete to Schrader (Kuparuk Contingent) Well: S-16 a. Load IA with inhibited KWF brine b. Land tubing with mule shoe/WLEG @ ~5720’ c. Ensure RHC plug body pre-installed in lowermost X profile 11. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 12. Drop ball and rod and hydraulically set the packers per manufacturer’s setting procedure a. Conduct MIT-T to 3500 psi and MIT-IA to 3,500 psi for 30 mins (charted, state witnessed) 13. Shear circ valve in GLM and circ freeze protect. 14. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 15. RDMO Nordic Rig and ancillary equipment. Move to next well location. 16. RU crane. ND BOPE. 17. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 18. Pull BPV with TWC insert. 19. Replace wellhouse and gauge(s) if removed. Slickline 1. Spot Slickline unit, RU and PT. 2. RIH and pull RHC plug from X profile at ±5715’ MD 3. Dummy GLV above top packer 4. If Schrader Completion: Install WFRVs per below: WFM #Approx Depth, MD Injection Zone WFRV Valved Rate, bwpd 9 5437 OA 500 8 5475 OA 0 7 5501 Oba 500 6 5521 Oba 0 5 5557 OBb Gutted w/ check valve 4 5577 OBb Gutted w/ check valve 3 5626 OBc Gutted w/ check valve 2 5652 OBc Gutted w/ check valve 1 5709 OBd Gutted w/ check valve X-nipple Tubing tail OBd Gutted w/ check valve 5. RDMO Operations 6. Obtain AOGCC witnessed SVS test within 5 days of putting well online. Below RWO and post rig steps are for installing the Kuparuk Producer Completion, must have state approval: 20. After CBL confirmation of cement over Kuparuk interval and with AOGCC approval, PU new/used 13Cr80 4-1/2” completion and run per S-16 Proposed Kuparuk Completion Running Order. d. Load IA with inhibited KWF brine e. Land tubing with mule shoe/WLEG @ ~7650’ f. Ensure RHC plug body pre-installed in lowermost X profile Recomplete to Schrader (Kuparuk Contingent) Well: S-16 21. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. 22. Drop ball and rod and hydraulically set the packers per manufacturer’s setting procedure b. Conduct MIT-T to 3500 psi and MIT-IA to 3,500 psi for 30 mins (charted, state witnessed) 23. Shear circ valve in shallow GLM and circ freeze protect. 24. Bleed tubing pressure back to ~0 psi. Set BPV with TWC insert. 25. RDMO Nordic Rig and ancillary equipment. Move to next well location. 26. RU crane. ND BOPE. 27. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 28. Pull BPV with TWC insert. 29. Replace wellhouse and gauge(s) if removed. Slickline 7. Spot Slickline unit, RU and PT. 8. RIH and pull RHC plug from X profile in tubing tail 9. Install LGLVs per GL engineer 10. RDMO Eline – If Kuparuk Completion 11. Perforate per geologist ~ 50’ of shots, CBL mid workover will be tie in log a. Charges will be 2-7/8” MaxForce or similar b. 6 SPF c. 60 deg Phasing Testers 12. POP well a. Start well at minimum choke and 1 mmscfd until well IA cleared and well is flowing b. After well is online and stable, Open choke ~10 steps per hour, checking solids every choke adjustment and bottoms up c. Increase GL as needed to keep flow stable d. Obtain 8 hour piggyback well test with pad separator prior to RDMO Operations 13. Obtain AOGCC witnessed SVS test within 5 days of putting well online. NOTE: if completed as a Kuparuk producer, we will need to address the surface casing re-pressurization, this program will be submitted immediately after the rig moves off the well. Also, we will likely want to frac the Kuparuk, a separate frac sundry and program will be submitted. This program only covers the RWO. If completed as a Schrader injector, the wellwork is complete. Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Current WBD: Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Proposed Schrader Injector WBD: Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Proposed Contingent Kuparuk Producer WBD: Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Nordic Rig 3 BOP Schematic Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Liner top area CBL and IBP set depth tie in: Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Tubing Tally: 10,700’ 10,600’ 10,500’ 9-5/8” Production Casing Shoe: 10,693’ IBP Set @ 10,690’ 10’ of sand, Top @ 10,680’ 25’ of cement, top @ 10,655’ Recomplete to Schrader (Kuparuk Contingent) Well: S-16 Recomplete to Schrader (Kuparuk Contingent) Well: S-16 AOR Map Recomplete to Schrader (Kuparuk Contingent) Well: S-16 AOR Table: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: January 25, 2023Subject: Changes to Approved Sundry Procedure for Well S-16ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. 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DERYHFRQGXFWRUDQGFHOODU0RQLWRUHGIRUWHPSSUHVVXUHVDQG /(/V/(/VWKURXJKRXWPRQLWRU5HOHDVHGE\SDGRSHUDWRU)LQDO:+3V 7HPS 69 &:966909 2,$2$ 27* 7, 7HPS 0RQLWRUFHOODUIRU/(/VXQGHUHYDO$/3 SVL RQOLQH/(/VDQG DERYHFRQGXFWRU:HOO/RFNDQGDURXQGFHOODU 69 &:966909 2,$ 27* 7, 7HPS 6QLII&RQGXFWRU(YDOJDVHPLVVLRQV$/RSHQ# FDVLQJYDOYH&HPHQWLQFRQGXFWRUVKURXGLVFOHDQDQGGU\ZLWKQRHYLGHQFHRI OHDNDJH1R/(/ VGHWHFWHGDERYHFHPHQWWRSLQFRQGXFWRUVKURXGRUDQ\ZKHUH HOVHLQZHOOKRXVH 69 &:966909 2,$ 27* Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:184-084 6.API Number:50-029-21123-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028257 Property Designation (Lease Number):10. 8. PBU S-16 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Conductor & OA Top J Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 11300 Effective Depth MD: 13Cr80 / 13Cr85 11. 7/25/2020 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email: aras.worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" Baker SB-3 Packer Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9248 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10192 / 8427 10354 / 8543 Date: Liner 864 7" 10436 - 11300 8603 - 9248 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 30 - 2673 30 - 2673 14. Estimated Date for Commencing Operations: BOP Sketch 31 - 111 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" HES TNT Packer 10704 - 10964 8802 - 8998 4-1/2" 12.6#26 - 10358 Production 10228 8453 10228 10965 31 - 111 13-3/8" 9-5/8" Contact Phone:907-564-4763 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2643 5380 Intermediate 9145 28 - 10693 28 - 8794 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:22 am, Jul 16, 2020 320-301 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.07.16 06:38:28 - 08'00' Stan Golis 10-404 MGR16JUL20 SFD 7/16/2020 DSR-7/24/2020 Yes on Required? Comm 7/24/2020 dts 7/24/2020 RBDMS HEW 7/24/2020 S-16 Conductor & OA Top Job Integrity Engineer: Aras Worthington (907) 564-4763 Ops Engineer: Brian Glasheen (907) 545-1144 Ops Manager: Stan Golis (907) 777-8356 Expected Start Date: July 25, 2020 History S-16 is a gas-lifted producer that went Not Operable in 2016 due to gas in the cellar with LEL readings over 10%. In December of 2016 a LockCem Conductor top job was performed and restored operability even though some gas in the cellar was still present but at much lower readings and within the Operator’s safe thresholds. In 2019 the gas readings became worse and readings over 10% LELs were recorded by a wireless gas meter installed in the wellhouse so the well was made Not Operable again. Current Status The well is Not Operable well due to gas readings in the cellar and is secured with a Tubing Tail Plug and a passing CMIT TxIA to 2428 psi on 8/3/2019. Objective Circulate microfine cement/sealant/or Well Lock into the OA and to top off the conductor. POP and monitor cellar for LEL. Procedural steps Special Projects/DHD 1. C/O the OA to top of good cement. Circulate cement/sealant or Well Lock into the OA. Squeeze to 500 psi. 2. C/O the Condutor x 13-3/8” Annulus and top off with cement/sealant or Well Lock. SL 1. Pull Tubing Tail Plug and install GLVs. DHD 1. After cure period, POP well and monitor cellar for LEL. Re-treat/sqeeze OA and Conductor if necessary. 2 2 From: Abbie Barker <Abbie.Barker@hilcorp.com> Sent: Wednesday, July 15, 2020 10:56 AM To: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: Cancel Sundry #320‐058 Good Morning Mel, This serves as notice of the cancellation of Sundry #320‐058 for Surface Casing repair on Well S‐16 (PTD #184‐084). We will be submitting a new sundry to cover future work on the well shortly. Would you like me to send this information to the permitting email address as well? Thank you, Abbie Abbie Barker Regulatory Tech, Prudhoe Bay West Team Hilcorp Alaska Email: Abbie.Barker@hilcorp.com Cell: (907)351‐2459 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. RBDMS HEW 7/15/2020 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Aras Worthington Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU S-16 Permit to Drill Number: 184-084 Sundry Number: 320-058 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.clasko.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, er V.. Price DATED this day of February, 2020. ABDMS FEB a 4 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 �I" ° E!"D 9� ...9' ^IC d M Org 213110 JAN ; 0 2020 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ A Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susie Well ❑ Alter Casing 0 Other Surface Casing Repair 0 2. Operator Name: SP Exploration (Alaska), Inc 4, Current Well Class: . Exploratory ❑ Development 0 5. Permit to Dnll Number 184-084 - 3. Address: P.O. Box 196812 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6 API Number: 50-029-21123-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU S-16 - 9. Property Designation (Lease Number). 10. Field/Pools: ADL 028257 PRUDHOE BAY. PRUDHOE OIL ' it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MO): Junk (MD): 11300 • 9248 10228 8453 10228 10965 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 30" 31 - 111 31 - 111 Surface 2643 13-3/8" 30-2673 30-2673 5380 2670 Intermediate 9145 9-5/8" 28-10693 1 28-8794 6870 4760 Production Liner 864 7" 1 10436 .11300 18603-9248 1 7240 1 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 1 10704 - 10964 8802 - 8998 4-1/2" 12.6# 13Cr80 / 13Cr85 26-10358 Packers and SSSV Type: 4-1/2" HES TNT Packer Packers and SSSV MD (ft) and TVD (ft): 10192 / 8427 4-1/2" Baker SB -3 Packer 10354 / 8543 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 15, 2020 15. Well Status after proposed work: Oil 0 - WINJ ❑ WOSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Area J be deviated from without prior written approval. Contact Email: Anas.Worthingt000bp.com Authorized Name: Worthington, Area J Contact Phone: +1907 564 4102 Authorized Title: Interventio & Integrity Engineer Authorized Signature: Date: 3o COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: 3BOMS -R�0 FEB 0 b 2020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exce tion Required? Yes No G` Subsequent Form Required: APP/ROVED BYTHE Approved by: COMMISSIONER COMMISSION Date. WX ��q312,0 Form 10-403 Revised 04/2017 ORIGINAL �/T ' lxx Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate by 4A*00. ktj 5-16 Surface Casing Excavation & Repair Well Intervention Engineer: Aras Worthington (907) 564-4102 Pad Engineer: Samuel Infanti (907) 564-5676 Expected Start Date: 2/15/2020 History The well was originally drilled in 1984 and perfed in 1986. The well went Not Operable in 2016 due to bubbling in the cellar and conductor cement with LEL readings over 10%. In December of 2016 a LockCem Conductor top job was performed and restored operability even though some bubbling in the cellar was still present but at much lower readings and within BP's safe thresholds. In 2019 the bubbling became worse and readings over 10% LELs were recorded so the well was made Not Operable again. Current Status The well is Not Operable well due to cellar bubbling and is secured with a Tubing Tail Plug and a passing CMIT TxIA to 2428 psi on 8/3/2019. f Objective Excavate, cut away and remove existing conductor. Install a CMP (Corrugated Metal Pipe) Conductor shroud around SC. Cement CMP x SC annulus to surface and backfill excavation. After cure period, POP well and monitor cellar for LEL. Procedural steps Valve Shop 1. Install TWC Special Projects 1. Excavate and install shoring to 8' below OA valve. 2. Cut conductor away. 3. Install CMP Conductor. 4. Cement or LockCem CMP x SC annulus to surface. 5. Backfill and remove shoring. Valve Shop 1. Pull TWC. SL 1. Pull Tubing Tail Plug and install GLVs. DHD 1. After cure period, POP well and monitor cellar for LEL. THEE= 4-1r16"CNV Vd3-LHFAD= CIW aCTIYITbR=-en c OIB. ELEV = 67.1' BF. 9tV n 4010' KJOP= 3300' 20' COPD -110 UCTOR Ma. Angle = 54' Q 5700' aMD= Dahm 1079' 0' O01m TVD= 8800'SS D_ &&W CSG. 470, L-80 VAM TCP, D=8.681' 1521' 0591" BOWFN CSG PA TCn n 9 776-4621' - 15; Minimum ID = 3.725" @ 10447' 44/1" SWN NIPPLE 4-12" TBG. 12.6x- 13CR-86 VAM TOP, 0152 bpf, D = 3.958' 4-172' TBG, 1260, 13CR-80 TDS. 0152 bpf, 0 = 3.958" P6WORATON SLJYMARY FEF LOG: SV75 &HCS ON 07!31184-SM5 CBL ON 08704184 ANGLE AT TOP PEF F 41'@ 10704' Nota. Pater to RodmWn OB for hislv"l cert data 2.714' 6 10704 - 107'" [) 21178' 4 10708 - 10750 S 21178' 4 10882 - 10887 O VIM' 4 10882 - 10907 O 21178' 4 10887 - 10907 O 27118' 4 10914 - 10918 O 2!118' 4 10914 - 10918 O 21178' 4 109M - 10964 O VIM' 4 10926 - 10964 O 1 WssI R3TD 11257' T LW 26M, L-80 WS, .0383 W. D • 6.276' 11300' S-16 SAFETYNOTES: CHROME TWO 1501' —9-5W GPZCNE ECP, u = 8.720' 2199' 40.117IR5XNRn=3813' rr/.ya y�>sn.lnsn-y ST MD TVD DEV TME VW LATCH PORT. DATE 5 3713 3697, 16 MMD OMY RK 0 060419 4 8445 MMG OMY RK 0 08A419 3 2 1 7147 6139 9253 U776546 M6Y., MMG MW OMY DMY DMY RK 0 RK 0 RK 0 02+13115 O&Wl'19 08!0119 10192' M9-5M-X4-112"RESTNTRCR,11>=3.9D3- 10228' 4-1:2' IES X tW, D • 3.813' 10228' ?X PLUG108N3r19) i 10311V -19 STS" X 4 12- UNCLE OV uisHOT 10353'-JUKRT13GANpgR(ED4122).n=3.875 10354' 9-518' X 4-112" OKR SR -3 WR D 4.750' 10356' r MLLOUT ENTE�6DN. D = 6.00' X 4X 4-1/2 1044T 4-12' PARKER SNTI NP, D = 3.725' 10459' — 4 112" W'LEG. D = 3.958' 10461' I f1 MD TT LOGGED D471h'92 DATE REV BY COMMENTS DATE REV BY COM6IENTS 8&O61114 H-186 INITIAL COMPLETION 06/23717 CJWJMD GLV C/O(0820117) 04107182 0-16 RM 092317 CJWJMD,CORRECTED MND 0213116 0-16 RM 0&0719 CJWJMVSETPK PLUG QW 19) 1VOWS CJNIJMD PULED PXN PLUG (10125115) 4&07/9 JPKIJMO GLV CAO 804119 11N315 CJWJMO GLVCAD 1025115 072116 GJBMMD SET PXN PLUG 7119116 MARKER JON! PRUDHOE BAYUNIT WELL: S-16 PERMR No: 194OS40 APINo 50-029.211234)0 T12N, T12E, 2094' FNL & 715 BP EXPfaradon (Aknka) • STATE OF ALASKA • t ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well II Re-enter Susp Well 0 Other:Cement OA tO 5v/{:et m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 184-084 3. Address: P.O.Box 196612 Anchorage, Development Q1 Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-21123-00-00 7. Property Designation(Lease Number): ADL 0028257 8. Well Name and Number: PRUDHOE BAY UNIT S-16 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11300 feet Plugs measured 11047 feet true vertical 9248 feet Junk measured 10965 feet MAY 0 2 2017 Effective Depth: measured 11047 feet Packer measured See Attachment feet true vertical 9060 feet Packer true vertical See Attachment feet AOG/1.0 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 31 -111 31-111 Surface 2644 13-3/8"72#L-80 30-2674 30-2674 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 864 7"26#L-80 10436-11300 8603-9248 7240 5410 Perforation Depth: Measured depth: 10704-10708 feet 10708-10744 feet 10744-10750 feet 10882-10887 feet 10887-10902 feet 10902-10907 feet 10914-10918 feet 10926-10964 feet True vertical depth: 8802-8805 feet feet 8805-8833 feet 8833-8837 feet 8936-8940 feet 8940-8951 feet 8951-8955 feet 8960-8963 feet 8969-8998 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Surface MAI 2.0 17. CAINE0 MAI V Treatment descriptions including volumes used and final pressure: 3 Gallons Soapy Water w/Surfactant,4 Gallons LockCem,Atmospheric Pressure. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 4 0 20 823 159 Subsequent to operation: 195 258 2362 1249 224 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I1 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: 316-445 Authorized Name: Worthington,Aras J Contact Name: Worthington,Aras J Authorized Title: Interventions&Integrity Engineer Contact Email: Aras.Worthington@bp.com Authorized Signature: ele ,.. .,0''''''., •-•' Date: ,5/:` �"bi�2 Contact Phone: +1 907 564 4102 RBDMS D M S 1,v MAY - 3 2017 Form 10-404 Revised 04/2017 /'((0(7 v 77- 5/Jo r/�` • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 25, 2017 To Whom it May Concern: (rIA K14 sud c-e"- Attached please find the Report of Sundry Well Operations for S-16 Cement OA Repair to close out Sundry Application # 316-445. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 . • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary April 25, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for S-16 Cement OA Repair to close out Sundry Application # 316-445. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 0 i Packers and SSV's Attachment PRUDHOE BAY UNIT S-16 SW Name Type MD TVD Depscription S-16 TBG PACKER 10194.21 8429.39 4-1/2" HES TNT Perm Packer S-16 _ TBG PACKER 10352.56 8542.3 4-1/2" Baker SB3 Packer • S m —Qc0D0r- 0000 m co — v0Ln N- o N "Sr Cr LO CO N U N 0 0 0000 I,- C) N C7 7 CA CO CO N O v' CO CO CO N- CA 00 Cfl d' CO N- CA N ' CO 0 f" N CD O N A- CO CA CO 00 144 ▪ CA') CO O CO N O 1- 0 01 0 7 N CD CO N CD s- CO CO CD CDCCh CO - r- r CO 01 O r tD CO CND CD CO Cr) V N 0 0 0 V i i I I I QNI. COO LU O CON N- 0 CO C7 N 1.0O N C Q ▪ CO W I- 0 Cn 0 ` = p 0 (0 CO OJO CO CO CU M CY) J J 00 C 0OMN # J *k .y N X rd �# CO CO U (NI ChCO00• _ N p O r r O .1- O O O) M C CO Co CON Lf) J (NI Q) CO O W W im C - - U U W W V 0 L CC I Z Z Z c W W W 00 m OD ;- c- z » Uv) zZ � I_ I_ • • ii ca co - a) a o s Oa) Zra ° y o W -6 w 47-- LL _ ° _ .o C o m Z .. ot3O = cuoc�o � � a � � o a) Q __• L `� a)ci) YO 0 -0 cot a)a) ca Q C as o cn o. 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S-1 6 SAFETY NOTES: CHROME TBG ACTUA TOR= BAKER C OKB ELEV= 67 1' I T BF.ELEV= 40.10 } 1478' --I 9-5/8"HES ES CEMENTERKOP= 3300' 20"CONDUCTOR 110 �S 1501' —19-5/8"ISO-ZONE ECP,D=8.720" Max Angle= 54°@ 5700' Datum MD= 10790' `—#, , ' II2199' 4-1/2"HIES X NP,D=3.813" Datum TVD= 8800'SS D 9-5/8"CSG,47#,L-80 VAM TOP,D=8.681" 1521' , GAS LFT MANDRELS ST M) IVO DEV TYPE VLV LATCH PORT DATE 9-5/8"BOWEN CSG PATCH,D=9.720" — 1521'-1522' 5 3713 3697 16 IMG DOME FE v 16 10/25/15 13-3/8'CSG,72#,L-80 BUTT,D=12.347" —I 2673' LI 4 6445 5693 47 MMC SO FE ' 20 10/25/15 3 7147 6191 43 MFG OW Fac • 0 02/13/15 2 8139 6940 40 MAG DMI' FE r 0 10/25/15 Minimum ID = 3.813" QC? 2199' 1 9253 7765 46 MM3 DMY FE r 0 10/25/15 4-1/2" HES X NIPPLE / 10161' —14-1/2"HiesxNIP,D=3.813" 1 ..M/ 10192' 9- 5/8"X 4-112"FES TNT PKR D=3.903'1 I �— 10228' H4-1/2"HES X NP,0=3.813' 1 4-1/2"TBG, 12 6#,13CR-85 VAM TOP, H 10299' .0152 bpf,D=3.958' ---.1„,...... 10314' I— 95/8"X 4-1/2'UNIQUE OVERSHOT 10353' — BKR TBG ANCHOR(63H-22).ID=3.875' 4-1/2'TBG STUB(01/31/14) H 10306' �� 10354' -f9-5/8"X 4-1/2'BKR SB-3 PKR,0=4.750' 10358' H7'FALLOUT EXTBJSDN,D=6.00" \ 1 10365' --17'X 4-1/2"XO,D=4.00' 10389` H4-1/2'PARKER SWS NP,D=3.813' TOP OF r LNR 10436' --, 4-1/2'TBG, 12.6#,13CR-80 TDS, H 10459' L. 10447' 1-14-1/2"PARKER SWT!NP, 0=3.725" .0152 bpf,D=3.958" 9-5/8'CSG,47#,L-80 BUTT,0=8.681' H 10693' '\. 10459' H4-1/2'VWLEG,D=3.958" FB ORATION SIJMtIufAFZY 10461' H B_MD TT LOGGED 04/12/92 REF LOG:SWS BRCS ON 07/31/84-SVS CBL ON 08/04/84 , ANGLE AT TOP PERF:41°@ 10704' Note:Refer to Production DB for historical perf data SIZE SFE INTERVAL Opn/Sgz DATE SQZ Q 2-7/8" 6 10704-10744 0 12/20/96 ' 2/1/8" 4 10708-10750 S 05/14186 11/29/91 2/1/8" 4 10882- 10887 0 07/15/86 0 1084V —r 7"MARKER JONT 2/1/8" 4 10882- 10907 0 08/11/90 2/1/8" 4 10887-10907 0 07/04/86 2/1/8" 4 10914-10918 0 07/15/86 2/1/8" 4 10914-10918 0 08/11/90 2/1/8" 4 10926-10964 0 07/15/86 2/1/8" 4 10926- 10964 0 08/11/90 10965' CTMD --IFISH=MLLED CBP(04/25/15) J -- 11047' H TOP OF SAND 7"LNR,26#,L-80 U4S XO TO L-80 BUTT —I 11189' I---Y * PTD -- 11257' + 7'LNR,2611,L-80 1145, .0383 bpf,D=6.276" — 11300' DATE REV BY COMETS DATE REV BY COME/NITS PRUDHOE BAY UNFT 08/05/84 N-18E INTIAL COMPLETION 09/01/15 BF/JMD SET PXN PLUG(08/29/15) WELL: S-16 04/07/92 DW -16 I O 11/03/15 CJN'JMD RA.LED PXN PLUG(10/25/15) PERMIT No: 1840840 02/15/15 0-16 Fa/VO 11/03/15 CJNJMD GLV GO(10/25/15) API No: 50-029-21123-00 04/20/15 MGS/JMD GLV CIO(04/10/15) 07/21/16 GJB/JMD SET PXN PLUG(07/19/16) SEC 35,T12N,T12E,2094'FNL&715'PAL 105/01/15 DBMVJMD MLLH)CBR'RJSHED 01-1(04/25/15) 02/15/17 GJB/JMD PULLED PXN FLOG(01/21/17) 08/14/15 NXW/JME GLV GO(07/29/15) BP Exploration(Alaska) I ' • • tiOFTy //7:_ , THE STATE Alaska Oil and Gas Of TAsKA Conservation Commission 333 West Seventh Avenue C GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O�ALASY'Q' Fax: 907.276.7542 www.aogcc.alaska.gov Aras Worthington Interventions and Integrity Engineer r , BP Exploration (Alaska), Inc. sC NED JAN 1201, P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S-16 Permit to Drill Number: 184-084 Sundry Number: 316-445 Dear Mr. Worthington: 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, Cath P. Foerster Chair Sf' DATED this / day of September, 2016. RBDMS /t- SEP - 1 2016 • STATE OF ALASKA • ',ALASKA OIL AND GAS CONSERVATION COMM N APPLICATION FOR SUNDRY APPROV�S 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other OA Cement 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 184-084 ' Exploratory 0 Development 0 3, Address: P.O.Box 196612 Anchorage,AK 6. API Number: 50-029-21123-00-00 • 99519-6612 Stratigraphic 0 Service ❑ 7, If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? w Will planned perforations require a spacing exception? Yes 0 No 0 PBU S-16 9. Property ADL028257 D Designation(Lease Number): 10. PRUDHOEField/Pools.BAY,PRUDHOE OIL ��2 �0 16 a /.b 11. PRESENT WELL CONDITION SUMMARY ACC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk 11300 • 9248 - 10447 • 8611 .. 10447.11047 10965 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 29-109 28-108 Surface 2645 13-3/8" 28-2673 28-2673 4930 2670 Intermediate 10666 9-5/8" 27-10693 27-8794 6870 4760 Production Liner 864 7" 10436-11300 8603-9248 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10704-10964 ` 8802-8998 4-1/2"12.6# 13Cr85/13Cr80 25-10459 Packers and SSSV Type: 4-1/2"HES TNT Packer Packers and SSSV MD(ft)and TVD(ft): • 10192/8428 4-1/2"Baker SB-3 Packer - 10354/8543 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 i Service 0 14.Estimated Date for Commencing Operations: September 16,2016 15. Well Status after proposed work: . Oil 0 - WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Worthington,Aras J be deviated from without prior written approval. Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Interventions&Integrity Engineer Signature 3f'Phone +1 907 564 4102 Date /4/ ) p/ ,,,,•'..-,,,,•'..- COMMISSION USE ONLY ��✓✓✓ Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 31(k -1{1-{6 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: O Post Initial Injection MIT Req'd? Yes 0 No I f ?kik, , Spacing Exception Required? Yes 0 No Subsequent Form Required: /a — 4 o 4 7/' APPROVED BYTHE Approved by: /COMMISSIONER COMMISSION Date:4 11136 ��i' S/3�/i V`TL g/31/l( ORIGINAL RBDMS L L-SEP - 1 2016 Submit Form and Attachments in Duplicate Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. • • • bp • S-16 OA & Conductor Cement Top Jobs Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Matt Bergene (907) 564-4849 Expected Start Date: September 16th 2016 History The well was originally drilled in 1984 and perfed in 1986. In 1991 the well was SI after a leak in the tubing was discovered. The first RWO was performed in 1992, replacing the corroded 3-1/2" tubing with 4-1/2" 13CR-80. The well produced consistently until 2002 when bubbling in the cellar was first observed.____ The well was produced periodically until 2004 when the waiver for IAxOA was cancelled and required the well to be SI. It was not until 2015 that a RWO was performed and the well was restored to production. While on the well, the rig cut and pulled —1500 ft of 9-5/8" csg, cementedi9 surface new 9-5/8" csg, landed new tubing, and installed a sliplock well head. On August 2 rapid bubbling was again observed in the cellar. A MIT-T and CMIT-TxIA with fluid were performed to 3000 psi, both passed. A generic GLD was reinstalled on 10/25/15. The well was stacked out cold with AL on 3/16/16 to 1650 psi. Over the course of 2 months, the well was left stacked out, and no bubbling was observed. The well was POPd UE on 7/2/16 with a 24/7 man watch. LELs were first observed at surface on 7/4/16, but were not recorded again until 7/8/16, when the LELs were measured at 50% 1' above the conductor. The IA was bled on 7/10/16, on 7/15/16 (the next monitor) the LEL readings were all negative. On 7/18/16, the well was flow restricted with a plug set at 10,423'. Currently the well is deemed inoperable by BP. Objective This proposal is to perform a cement top job on the OA as well as clean out the conductor and /op off the cement in the conductor with an aim to seal-off the gas bubbling from the cellar/conductor. Procedural steps DHD/Special projects 1. Strap TOC in OA. 2. Circulate microfine cement into OA until clean cement returns are observed. Note that a squeeze cannot be performed on this OA due to the sliplock wellhead on the new 9-5/8" casing. 3. Hot water/surfactant wash the Conductor x Surface Casing Annulus to top of good cement. 4. Circulate cement into the conductor from the top of existing cement to surface until clean cement returns are observed. 5. Wait on cement to cure. DHD/WeII Integrity Superintendent 1. POP well Under-Evaluation and monitor conductor/cellar for any bubbling/gas. r • • TREE= 4-1/16"CAN WELLH AD= CNV s-1 6 SAFETY NOTES: CHROME TBG ACTUATOR= BAKER C BF EEVV= 40 10'V= 67.1' ( ( 1478' H9-5/8"I-ES ES CEMENTER KOP= 3300' 1501' —{9-5/8"ISO-ZONE ECP,D=8.720" Max Angle= 54"@ 5700' 20'CONDUCTOR, 110 Datum MD= 10790' —#' r 2199' }—4-1/2"HES X fes,D=3.813' Datum TVD= 8800'SS D= GAS LIFT MANDRELS 9-518"CSG,47#,L-80 VAM TOP,D=8.681" — 1521' ST MD TVD DEV TYPE VLV LATCH PORT DATE 9-5/8"BOWEN CSG PATCH,D=9.720" H 1521'-1522' 5 3713 3697 16 MAG DONE RK r 16 10/25/15 LI 4 6445 5693 47 MAG SO RK ' 20 10/25/15 13-3/8'CSG,72#,L-80 BUTT,D=12.347" — 2673' 3 7147 6191 43 MUG LM( RK ' 0 02113/15 2 8139 6940 40 MUG CMY FM ' 0 10/25/15 Minimum ID = 3.813"@ 2199' 1 9253 7765 46 MGOMY lac ' 0 10125/15 4-1/2" HES X NIPPLE IT" 10161' I-4-112"FES x NIP,D=3.813' M, ›:<- 10192' H9-5/8"X 4-1/2'HES TNT PKR,D=3.903' ' 10228' H4-1/2"F S X NP,D=3.813" 4-1/2'TBG,12.6#,13CR-85 VAM TOP, —{ 10299' Ni,,,,,,,,,I 10314' H9-5/8"X 4-112"UNOLE OVERSHOT .0152 bpf,D=3.958" 10353' H BKR TBG ANCHOR(EBI-22),D=3.875' 4-1/2'TBG STT, (01(31/14) H 10306' -. 10354' —9-5/8'X 4-1/2"BKR SB-3 PKR,D=4.750" 10358' —7'MLLOUT EXTENSION,D=6.00' 10365' --Ir x 4-12"xo,D=4.00" 10389' H4-1/2"PARKER SWS NP,D=3.813" TOP OF 7'LM — 10436' 1 47,, ( 4-1/2'TBG,12.6#,13CR 80 TDS, — 10459' 1044T H4-1/2'PARKER SWN NP,D=3.725" .0152 bpf,D=3.958" 10447' —14-1/2"F'XN PLUG(07/19/16) 9-5/8"CSG,474,L-80 BUTT,D=8.681" — 10693' 10459' —14-1/2"W/LEG,D=3.958" PERFORA11ON SUMMARY10461' H ELM]TT LOGGED 04/12/92 REF LOG:MA66 BHCS ON 07/31/84-SWS CSL.ON 08/04/84 ' ANGLE AT TOP PEFF:41'@ 10704' Note:Refer to Production DB for historical perf data I SIZE SPF NITBtVAL Opn/Sqz DATE SQZ 2-7/8" 6 10704-10744 0 12/20/96 2/1/8" 4 10708-10750 S 05/14/86 11/29/91 2/1/8" 4 10882-10887 0 07/15/86 10846' —{rMARKHZJOINT 2/1/8" 4 10882-10907 0 08/11/90 2/1/8" 4 10887-10907 0 07/04/86 2/1/8" 4 10914-10918 0 07/15/86 I 2/1/8' 4 10914-10918 0 08/11/90 2/1/8" 4 10926-10964 0 07/1586 , 2/1/8" 4 10926-10964 0 08/11/90 10965'CTMD —FGH ALLEDCBP(0425l15) I 11047' --I TOP OF SAND 7"LHR,26#,L-80 U4S XO TO L-80 BUTT — 11189' H PBTD 1125r 7'LMR 26#,L-80 U4S,.0383 bpf,D=6.276' — 11300' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY TNT 08/05/84 N-18E INITIAL COMPLETION 09/01/15 BF/JMD SET PXN PLUG(0829/15) WELL: S-16 04/07/92 D-16 MO 11/03/15 CJN'J M)PILLED PXN FLOG(1025/15) PERMIT No: 1840840 02/15/15 D-16 MO 11/03/15 CHAD GLV C/O(10/25/15) API No: 50-029-21123-00 04/20/15 MGS/JMD GLV 00(04/10/15) 07/21/16 GIB/JMD SET PXN PLUG(07/19/16) SEC 35,T12N,T12E,2094'FNL&715'FWL 05/01/15 DBMJM)PALLED CBP/RJSHH)DH(04/25/15) 08/14/15 M(W/JMC GLV CIO(07/29/15) BP Expioration(Alaska) 2 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION C(. ....JIISSION REPORT OF SUNDRY WELL OPERATIONS MAY 19 nib 1. Operations Performed: IAOGCC 0 Abandon ® Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well 0 Alter Casing 0 Pull Tubing 0 Stimulate-Frac 0 Waiver 0 Other 0 Change Approved Program 0 Operation Shutdown 0 Stimulate-Other 0 Time Extension 2 Operator Name: 4. Well Class Before Work. 5. Permit To Drill Number BP Exploration (Alaska) Inc. 0 Exploratory 0 Stratigraphic 184-084 3 Address. 0 Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-21123-00-00 7 Property Designation(Lease Number): 8. Well Name and Number: ADL 028257 PBU S-16 9. Logs(list logs and submit electronic and printed data per 20AAC25.071). 10. Field/Pool(s): USIT Prudhoe Bay/Prudhoe Bay 11. Present well condition summary: Total depth: measured 11300' feet Plugs:(measured) 11047'(Top of Sand) feet true vertical 9248' feet Junk:(measured) 10965' feet Effective depth measured 11047' feet Packer. (measured) 10192', 10354' feet true vertical 9060' feet Packer: (true vertical) 8411',8543' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20"x 30" 29'- 109' 29'- 109' Surface 2645' 13-3/8" 28'-2673' 28'-2673' 4930 2670 Intermediate 10668' 9-5/8" 25'- 10693' 25'-8794' 6870 4760 Production Liner 864' 7" 10436'- 11300' 8603'-9248' 7240 5410 SCANNED _ 0 '2,0!' Perforation Depth Measured Depth: 10704'- 10964' feet True Vertical Depth. 8802'-8998' feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# 13Cr85/13Cr80 10459' 8620' Packers and SSSV(type,measured and true vertical depth): 9-5/8"x 4-1/2" HES TNT Packer; 10192'; 8428'; 9-5/8"x 4-1/2"Baker SB-3 Packer 10354' 8543' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: Cut&Pull 4-1/2", 12.6#, L-80 Tubing from 10306'. Cut&Pull 9-5/8",47#, L-80 Casing from 1520', Run 9-5/8",47#, L-80 Tie-back to 1522',Cement 9-5/8"Tie-back w/115 Bbls,Yield 1.17(552 sx)Class'G', Run 4-1/2", 12.6#, 13Cr85 Tubing to 10314'. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 0 0 0 0 0 Subsequent to operation: 245 926 1262 1560 240 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work. 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0 Daily Report of Well Operations 16. Well Status after work. ®Oil 0 Gas 0 WDSPL 0 Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O. Exempt: Contact: J.E.B.Bolen,564-5110 J.E.B.Bolen@bp.com 314-675 Printed Name: Joe Lastu a A. i Title: Drilling Technologist Signature: Phone: 564-4091 Date: Sh 1/15 Form 10-404 Revised 10/2012 I q-//I,1 ``� Subfnit Original Only S-16, Well History (Pre-Rig Workover) Date Summary 01/25/14 PULL 4 1/2" PLUG BODY FROM 10417' SLM (10447' MD). RUN SBHPS PER PROGRAM W/TEL, LOC TT @ 10,431'SLM (10,461' ELM) +30'CORRECTION. RAN 3.80" G-RING,TAG XN NIP @ 10,420' SLM (10,447' MD). SET 4 1/2"COMPOSITE BRIDGE PLUG @ 10,291' SLM (10320' MD). 01/28/14 T/I/O= 143/174/5 Temp=Sl CMIT-TxIA to 3000psi. ***FAILED***3rd attempt(RWO EXPENSE) Pumped 24 bbls DSL down IA for 3000 psi test. Tbg/IA Lost 18/17 psi in 1st 15 min, Tbg/IA lost 21/22 psi in 2nd 15 min for total loss of 39/39 psi in 30 min test. Bled back—13 bbls. FWHP=200/200/5. 01/29/14 T/I/O=292/254Nac.Temp=Sl. CMIT TxIA to 3000 psi PASSED (Pre RWO). AL SI & blinded @ casing valve. T& IA FL @ surface. Increased TP& IAP to 3000 psi w/12 BBL diesel. Lost 32/31 psi in first 15 min& 18/17 psi in second 15 min for a total of 50/48 psi in 30 min. Bled T& IA to 245/225 with 12 bbl returned. Final WHPs=245/225/4. SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1410. 01/31/14 INITIAL T/I/O= 150/280/0 PSI. RIH W/HEAD/HALIBURTION 2.9375" RADIAL CUTTING TORCH (RCT- 2937.200) &CUT TBG @ 10306' MD. GOOD INDICATION OF CUT FROM PRESSURE CHANGE ON TBG & IA- POOH &CONFIRMED CUTTER CUT. WELL SHUT IN ON DEPARTURE- DSO NOTIFIED OF WELL STATUS. FINAL T/I/O = 150/280/0 PSI. 02/02/14 T/I/0=223/219/0 Temp=SI. Obj: RWO Prep. CMIT TxIA to 1000 PSI ***PASSED***Pumped 4.08 bbls crude to reach test pressure. (See log and data tab for details). MIT-OA to 2000 PSI ***FAILED***. (See log and data tab for details)While able to reach test pressure, OA would not hold pressure, Unable to establish positive LLR. FWHP 241/234/0. SwV, WV, SSV=Closed. MV=Open, IA/OA=OTG. 02/02/14 T/I/O=223/219/vac. Temp=SI.Assist Fullbore with cellar watch (SC Leak). AL blinded (0 psi). OA FL near surface. See log for details. Monitored cellar during LRS pumping operations. No activity in conductor. Job complete. Final WHPs=241/234/0. LRS in control of valves. 02/03/14 T/I/O=270/213/0 Temp=SI (RWO EXPENSE) Circ out. Pumped 10 bbl methanol spear, followed by 1375 bbls of Sea water, Taking returns down the F/L on S-17, then 171 bbls of diesel to Freeze protect. Freeze protected F/L on S-17 with 30 bbls crude, 10 bbls methanol. U-tube diesel in IA to tbg. FWHP=260/260/0. Swab, SSV, &wing shut. Master, IA, &OA open. 02/04/14 Assist hardline crew with thawing out hard line(Rig down) Pump 3 bbls meth down hardline to tank to thaw. 02/06/14 T/I/O= SSV/20NAC.Temp= SI. Obtain gravel sample(cellar evac).AL blinded. Unable to obtain gravel sample due to snow in cellar. Called for heater. SV, WV, SSV=C. MV=0. IA, OA=OTG. 2200. 02/08/14 T/I/O= SSV/20Nac.Temp= SI. Gravel sample(Evac cellar). AL SI @ casing valve. Cellar is 48"from grating to top of ice. Installed heater in cellar to thaw cellar for gravel sample. Snow removal needed in front of wellhouse. Residual fluid (crude/hydraulic)on tree, scaffolding&drips in cellar. No active leaks observed & no source identified. Unable to verify SV status(only 10 turns of 23&crunching). Pad Operator notified of residual fluids& SV status. SV=?. WV&SSV=C. MV=O. IA&OA=OTG. NOVP. 2359 hrs. 02/10/14 T/I/O= SSV/20Nac.Temp=SI.AL SI @ casing valve. Cellar&SV(23.5 turns)thawed. Cellar gravel sample taken. SV, WV& SSV=C. MV=O. IA&OA=OTG. NOVP. 0200 hrs. Page 1 of 3 S-16, Well History (Pre-Rig Workover) Date Summary 06/16/14 T/I/O=SSV/0+/0+,Temp=SI. PPPOT-T(PASS), PPPOT-IC(FAIL). Pre RWO. PPPOT-T: Stung into test port(0+ psi), bled to 0 psi. Functioned LDS, all moved freely(2.5"). 1 blank installed, LDS was drilled out 1-3-14. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port(0+psi), bled to 0 psi. Functioned LDS, all moved freely(2.5"). 1 LDS blank installed, LDS was drilled out, 1 LDS was left backed out 1-4-14. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 600 psi in 15 min, bled void to 0 psi.Torqued LDS to 600 lb/ft. Pressured void to 3500 psi, lost 600 psi in 15 min (FAIL). Bled void to 0 psi. 06/27/14 T/I/O = SSV/15/vac. Temp=SI. WHPs(Re-energize secondary seals). AL blinded @ casing valve.ALP =0 psi. IA FL @ surface. SV, WV, SSV=C. MV=O. IA, OA= OTG. 22:00. 06/28/14 T/I/O = SSV/20NAC, Temp:SI, PPPOT-IC (PASS) Re-energize secondary seal. PPPOT-IC: Stung into test void, (400 psi) bled void to 0 psi. DHD bled IAP&OAP to 0 psi. DHD held open bleed on IA&OA. Opened SBS on test void to verify 0 psi. Opened SBS on packing port to verify 0 psi in void. Removed 1" pipe plug and RU packing gun. Pumped through void, good returns. Closed SBS and re-energized secondary seal to 3,500 psi. Pressured test void to 3,500 psi for 30 minute test. Lost 150 psi in 15 minutes, lost 0 psi in second 15 minutes. LDS already at max torque of 600 ft/lbs. (AWGRS 6-16-2014) (PASS) Bled void to 0 psi. 06/28/14 T/I/O = SSV/20/vac. Temp=SI.Assist Cameron (Open bleed IA&OA).AL SI @ CV.ALP=0+psi. Bled IAP from 20 to 0 psi in 1 min. (gas/fluid). Held an open bleed on the IA&OA while Cameron re=energized the Y-Seal. FWHP's=SSV/0/0. SV,WV, SSV= C. MV= O. IA, OA=OTG. NOVP. 1630. 07/24/14 T/I/O=SSV/ONAC. Temp=SI. Eval cellar for spray in liner.AL SI @ casing valve,ALP=0. No spray in liner, Cellar Depth=50". WV= LOTO. SV,WV,SSV= C. MV= O. IA, OA=OTG 13:45 hrs. 12/09/14 T/I/O = SSV/0/0,Temp: SI, PPPOT-T(PASS), PPPOT-IC (PASS) Pre RWO. PPPOT-T: Stung into test void, (0+ psi) bled void to 0 psi. Functioned LDS, all moved freely, 1 blank installed.Torqued LDS to 500 ft/lbs. Pumped through void, good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) bled void to 0 psi. PPPOT-IC: Stung into test void, (0+ psi) bled void to 0 psi. Functioned LDS, 1 blank installed, 1 backed out and flagged (appears to be broke), and the rest moved freely. Torqued LDS to 600 ft/lbs. Pumped through void, good returns. Pressured test void to 3,500 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 50 psi in second 15 minutes. (PASS) Bled void to 0 psi. 01/05/15 T/I/O=VacNac/3.Temp= SI. CMIT TxIA 3000 psi (RWO).AL shut in at casing valve.ALP=0 psi.TBG& IA FL @ near surface. Pumped total of 26 bbls of diesel down the IA. Diesel sorce to be dilvered after shift change. Final WHPs=Vac/14/2. SV,WV, SSV= C. MV= O. IA, OA=OTG. NOVP. 1645 hrs. 01/06/15 T/I/O=6/22/4.Temp=Sl. CMIT TxIA to 3000 psi. PASS (Pre-rig).AL is connected, SI @ casing valve. ALP=0 psi.TBG FL 200', 3 bbls. IA FL @ 210', 12 bbls. Pumped 21 bbls to reach test pressure of 3006/3006 psi. Loss of 20/21 in 1st 15 min& 10/11 psi in 2nd 15 min for a total 30 min loss of 30/32. Bled T and IA to 0 psi in 1 hr. Monitor during rig down. TP& IAP unchanged. Final WHPs=0/0/0.Tags hung. SV, WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 1020. 01/09/15 T/I/O=0/0/0. Pumped through IA and pressured tubing and IA to 250Psi. Set 4"TWC#295 . @125" Through tree had good set and LTT(PASSED). RDMO. Final WHP's TWC/230/0. 01/18/15 T/I/O=TWC/0/0 Removed upper tree and installed Temp. SV valve#83 onto MV(dry hole tree). FWP= TWC/0/0. Page 2 of 3 S-16, Well History (Pre-Rig Workover) Date Summary 01/18/15 T/I/O=TWC/0/0. Pt'd dry hole tree(temp valve#83)and TWC. Installed piggy back IA(temp valve#59) and OA(Integral with 90 and plug valve). Torqued and Pt'd. RDMO. Page 3 of 3 North America-ALASKA-BP Page 1 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/1/2015 06:00 - 09:00 3.00 RIGD P PRE PJSM. RIG DOWN AND PREPARE TO MOVE OFF WELL D-24. -CLEAN AND CLEAR CELLAR. -R/D,CLEAN AND CLEAR RIG FLOOR. -PREPARE RIG FLOOR TO L/D DERRICK. *SIMOPS: -R/D AND STAGE MUD PUMP#2,CUTTINGS BOX AND CREW TRAILER OUT RIGS MOVE PATH. -R/U SCAFFOLDING ON RIG FLOOR. -REPLACE TOP DRIVE SERVICE LOOP. -INSTALL PLATE FOR PULL BACK LINE ON RIG FLOOR. -MOBILIZE ALL RIG SUPPORT EQUIPMENT 'FROM D-24 TO S-16. OBTAIN WELL WORK TRANSFER PERMIT FOR WELL S-16 ON 1/31/15. *PAD OPERATOR AGREED THAT PLACEMENT OF THE WSL OFFICE IS WELL OUT OF THE 300'RED ZONE OF THE RIG AS WELL AS THE MANIFOLD BUILDING. 09:00 - 12:00 3.00 RIGD P PRE PJSM AND REVIEW DDI SOP FOR LAYING DOWN DERRICK. LAY DOWN DERRICK FOR RIG MOVE. -PERFORM SPCC AND EQUIPMENT CHECKS. -BRIDLE-UP,AS PER DDI SOP. -PULL DERRICK PINS. -LOWER AND SECURE DERRICK FOR RIG MOVE. 12:00 - 13:30 1.50 MOB P PRE PJSM. MOVE RIG OFF OF WELL D-24. -CONTACT PAD OPERATOR TO WITNESS RIG MOVING OFF WELL. *PAD OPERATOR WAIVED WITNESS. -RAISE CELLAR DOORS,STAIRS AND LANDINGS. -POSITION RIG CREW MEMBERS AND VERIFY RADIO COMMUNICATION. -FUNCTION TEST ESD ON MOVING SYSTEM BEFORE MOVING RIG.TEST PASS. -MOB RIG OFF WELL D-24 AND STAGE IN MIDDLE OF D-PAD. 13:30 - 15:00 1.50 MOB P PRE PJSM. REMOVE BOP STACK AND INSTALL REAR BOOSTERS. -SECURE BOP STACK IN CRADLE AND REMOVE FROM CELLAR. -INSTALL REAR BOOSTERS. 15:00 - 17:00 2.00 MOB P PRE PJSM.MOBILIZE RIG TO D-PAD ACCESS ROAD. -MOB RIG FROM MIDDLE OF D-PAD AND STAGE RIG AT D-PAD ENTRANCE. 17:00 - 18:30 1.50 MOB N WAIT PRE WAIT ON SECURITY AND RIG MOVE SUPPORT. -WORK ON DDI MP2's,WHILE WAITING ON SECURITY AND RIG MOVE SUPPORT. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 2 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date!Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:3-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 00:00 5.50 MOB P PRE PJSM WITH RIG CREW,SECURITY AND SUPPORT CREW. MOBILIZE RIG FROM D-PAD TO S-PAD,WELL S-16. -CONDUCT RADIO COMMUNICATIONS CHECKS. -MOB RIG DOWN D-PAD ACCESS RD TO LEFT ON SPINE RD. -MOB RIG DOWN SPINE RD TO J-PAD ACCESS RD AND POSITION RIG TO THE SIDE, ALLOWING TRAFFIC BY. INSPECT MOVING SYSTEM. -MOB RIG DOWN SPINE RD FROM J-PAD ACCESS RD TO M-PAD ACCESS RD AND POSITION RIG TO THE SIDE FOR RIG CREW CHANGE OUT. 2/2/2015 00:00 - 05:00 5.00 MOB P PRE PJSM WITH RIG CREW,SECURITY AND SUPPORT CREW. MOBILIZE RIG FROM D-PAD TO S-PAD,WELL S-16. CONDUCT RADIO COMMUNICATIONS CHECKS. -MOB RIG DOWN SPINE RD FROM M-PAD ACCESS RD TO RIGHT ON S-PAD ACCESS RD. -MOB RIG DOWN S-PAD ACCESS RD AND STAGE IN MIDDLE OF S-PAD. 05:00 - 06:30 1.50 MOB P PRE PJSM. REMOVE REAR BOOSTERS AND SECURE BOP STACK IN CELLAR. -R/D AND REMOVE REAR BOOSTERS. -MOB BOP STACK TO CELLAR. -REMOVE BOP STACK FROM CRADLE AND SECURE BOP STACK ON STUMP IN CELLAR. 06:30 - 09:00 2.50 RIGU P PRE PJSM. RAISE DERRICK. -PREPARE,RAISE DERRICK,INSTALL PINS AND SECURE DERRICK. -BRIDLE DOWN. -R/U RIG FLOOR EQUIPMENT. *SIMOPS: -LAY AND POSITION RIG MATS AROUND WELL S-16,FOR RIG FOOTPRINT. '24 HR INITIAL BOPE NOTICE SUBMITTED ON 2/2/15 AT 07:00 HRS WITH INTENT TO PRESSURE TEST BOPE ON 2/3/15 AT 07:00 HRS. 09:00 - 12:00 3.00 RIGU P PRE PJSM. PREPARE TO MOVE IN AND POSITION RIG OVER WELL S-16. -LAY AND POSITION RIG MATS AROUND WELL S-16,FOR RIG FOOTPRINT. -PLACE NEW CAMERON 9-5/8"x 11"5M SLIP-LOCK WELLHEAD,NEW DRY HOLE TREE AND ALL EQUIPMENT FOR RWO BEHIND WELL S-16,PRIOR TO POSITIONING RIG OVER THE WELL. *SIMOPS:COMPLETE RIG MODIFICATIONS APPROVED THROUGH CI PROCESS. -RIG WELDER,COMPLETE INSTALLATION OF DAVIT PLATE FOR PULL-BACK TUGGER. -RIG WELDER,REMOVED AUXILIARY PIT MODULE 12"EQUALIZING ELBOW,THAT IS NO LONER USED,FROM REAR WHEEL WELL DOOR WAY. -RIG ELECTRICIAN,COMMISSION NEW TOP DRIVE SERVICE LOOP. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 3 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16©67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 16:30 4.50 RIGU P PRE PJSM. POSITION RIG OVER WELL S-16. -CONTACT PAD OPERATOR TO WITNESS RIG MOVING OVER WELL S-16. *PAD OPERATOR WAIVED WITNESS. -CONDUCT RADIO COMMUNICATIONS CHECKS. -CHECKED PRESSURES ON WELL BEFORE 'MOVING OVER WELL S-16. *TUBING PRESSURE=0 PSI,IA PRESSURE= 0 PSI,OA PRESSURE=0 PSI. -FUNCTION TEST ESD ON MOVING SYSTEM 'BEFORE MOVING RIG OVER WELL.-TEST PASS. -POSITION AND CENTER RIG OVER WELL S-16. -LEVEL AND SHIM RIG. -INSTALL LANDINGS AROUND RIG. 16:30 - 18:00 1.50 RIGU P PRE RIG EVACUATION DRILL. -CONDUCT RIG EVACUATION DRILL DUE TO SIMULATED I-12S RELEASE,FOLLOWED BY AAR. *RIG ESD WAS FUNCTION AND ALL RIG CREW MEMBERS REPORTED TO SAFE BRIEFING AREA. *IA AND OA PRESSURE AT 18:00 HRS=0 PSI 18:00 - 21:30 3.50 RIGU P PRE PJSM WITH RIG AND HARDLINE CREW. POSITION AND RIG UP SUPPORT EQUIPMENT. -POSITION,SPOT AND R/U CUTTINGS BOX, CREW TRAILER AND BULK FUEL TANK. -HARDLINE CREW,R/U AND TEST HARDLINE FROM RIG TO FLOWBACK TANK TO 250/ 4,200 PSI FOR 5 CHARTED MINS EACH. -PREPARE PITS AND TAKE ON 8.5 PPG SEAWATER. -R/U LINES AND TEST EQUIPMENT. -TEST TWC FROM ABOVE TO 250/3,500 PSI FOR 5 CHARTED MINS EACH.-TEST PASS. 'RIG ACCEPTED AT 18:00 HRS. *OA OPEN TO FLOWBACK TANK AT 21:30 HRS. 21:30 - 00:00 2.50 WHSUR P DECOMP PJSM WITH RIG CREW AND CAMERON REPS. NIPPLE DOWN 4-1/16"x 11"5M ADAPTER AND 4-1/16"DRY HOLE TREE. -CAMERON REPS,BLED ALL PRESSURE FROM ADAPTER VOID AND CONTROL LINES. -N/D ADAPTER AND DRY HOLE TREE. *BARRIERS IN PLACE=TWC,CBP,PACKER, CSG VALVES AND TBG HANGER. 2/3/2015 00:00 - 00:30 0.50 WHSUR P DECOMP SERVICE RIG. -LUBRICATE TOP DRIVE,ST-80 AND BLOCKS. -INSPECT AND SERVICE PIPE SKATE RIG FLOOR EQUIPMENT. -CROWN-O-MATIC AND SPCC CHECKS- GOOD. 'OA OPEN TO FLOWBACK TANK AT 21:30 HRS ON 2/2/15 AND CONTINUOUSLY MONITOR,IN PREPARATION OF WELLHEAD WORK. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 4 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:30 - 01:30 1.00 P WHDTRE PJSM WITH RIG CREW AND CAMERON REPS. NIPPLE DOWN 4-1/16"x 11"5M ADAPTER AND 4-1/16"DRY HOLE TREE. -N/D ADAPTER AND DRY HOLE TREE. BARRIERS IN PLACE=TWC,CBP,PACKER, CSG VALVES AND TBG HANGER. -REMOVE ADAPTER AND DRY HOLE TREE FROM CELLAR. -CAMERON REPS,CLEAN,INSPECT AND VERIFY TBG HANGER THREADS. *TBG HANGER THREAD 4-1/2"TDS PROFILE IS IN GOOD CONDITION. -CLEAN HANGER AND INSPECT LOCK DOWN SCREWS. '"OBSERVED 1-LDS BLANK USED TO REPLACE DAMAGED LDS,WHICH WAS TAPPED OUT PRE-RIG. DISCOVERED HEAD OF DAMAGED LDS PARTIALLY ENGAGED. DISCUSSED PLAN FORWARD WITH ODE. -M/U 4-1/2"TDS X-OVER WITH CLOSED FOSV TO TOP OF HANGER. 9-1/2 TURNS TO M/U. 01:30 - 03:00 1.50 WHSUR P WHDTRE RIG EVACUATION DRILL. '-CONDUCT RIG EVACUATION DRILL DUE TO SIMULATED H2S RELEASE,FOLLOWED BY AAR. ALL RIG CREW MEMBERS AND 3RD PARTY REPORTED TO SAFE BRIEFING AREA HELD PRE-SPUD SAFETY MEETING WITH CREW. 03:00 - 05:00 2.00 BOPSUR P DECOMP PJSM. NIPPLE UP 13-5/8"5M BOPE. -N/U 13-5/8"5M SPACER SPOOL. -N/U 13-5/8"BOPE DRESSED WITH 9-5/8" SOLID BODY RAMS IN UPPER PIPE RAMS AND 3-1/2"x 6"VBR IN LOWER PIPE RAMS. -R/U HYDRAULIC CONTROL LINES,CHOKE AND KILL LINES TO BOPE. -R/U TURN BUCKLES,BELL NIPPLE,FLOW LINE,HOLE FILL LINE,BLEEDER LINES AND MOUSE HOLE. 05:00 - 06:00 1.00 BOPSUR P DECOMP PJSM. INSTALL NEW KELLY HOSE. -INSTALL NEW KELLY HOSE. -R/U TEST EQUIPMENT. -PRESSURE TEST NEW KELLY HOSE TO 250/ 5,000 PSI FOR 5 CHARTED MINS EACH.- TEST PASS. 06:00 - 08:00 2.00 BOPSUR P DECOMP PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. SHELL TEST 13-5/8"5M BOPE. -R/U FLOOR VALVES,CROSSOVERS BOPE TEST ASSEMBLY AND EQUIPMENT. -ESTABLISH EXCLUSION ZONES AND NOTIFY ALL ON WELL SITE OF PRESSURE TESTING OPERATIONS IN PROGRESS. -FUNCTION TEST RAMS TO ENSURE PROPER OPERATION.-TEST PASS. -FILL STACK AND CHOKE MANIFOLD TO MGS. 9 BBLS TO FILL GAS BUSTER. -SHELL TEST BOPE WITH ANNULAR PREVENTER CLOSE ON 4"TEST JT,TO 250/ 3,500 PSI.-TEST PASS. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 5 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 15:00 7.00 BOPSUR P DECOMP PRESSURE TEST 13-5/8"5M BOPE DDI SOP, AOGCC AND BP REQUIREMENTS. -TEST BOPE WITH 4",4-1/2"AND 9-5/8"TEST JTS TO 250/3,500 PSI FOR 5 CHARTED MINS EACH.-TEST PASS. -TEST ANNULAR PREVENTER WITH 4"TEST JT TO 250/3,500 PSI FOR 5 CHARTED MINS EACH. -TEST PASS. -PERFORM ACCUMULATOR DRAW DOWN TEST. TEST PASS. *TEST UPPER PIPE RAMS W/9 5/8"TEST JT AND LOWER 3-1/2"x 6"VBR's WITH 4"&4 1/2" TEST JTS. 'TEST DART VALVE,(2)SAFETY VALVES,ALL CHOKE VALVES AND VALVES ON MUD CROSS. 'TEST IBOP AND UPPER AND LOWER KELLY VALVES. *TEST GAS ALARMS. *NO FAILURES. 15:00 - 18:30 3.50 BOPSUR P DECOMP PJSM. RIG DOWN BOPE TEST EQUIPMENT. BLOW DOWN CHOKE MANIFOLD AND LINES. -R/D BOPE TEST ASSEMBLY AND EQUIPMENT. 18:30 - 21:00 2.50 DHB P DECOMP PJSM WITH RIG AND DSM CREW. RETRIEVE TWC. -R/U DUTCH RISER,RILDS ON DUTCH RISER AND CLOSE ANNULAR PREVENTER. -R/U AND TEST DSM LUBRICATOR WITH QTS, TO 250/3,500 PSI FOR 5 MINS EACH. -RETRIEVE TWC WITH TESTED LUBRICATOR. -R/D DSM LUBRICATOR AND DUTCH RISER. '0 PSI UNDER TWC. 21:00 - 21:30 0.50 CONDHL P DECOMP PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. RIG UP TO DISPLACE FREEZE PROTECT. -R/U LINES TO DISPLACE FREEZE PROTECT. -PRESSURE TEST LINES FROM MUD PUMPS TO SKID MANIFOLD,IA AND RIG FLOOR TO 250/3,500 PSI. 21:30 - 23:00 1.50 CONDHL P DECOMP PJSM WITH PRESSURE CROSSCHECK DISCUSSION AND CONFIRMED CHALLENGE QUESTIONS WITH CORRECT RESPONSES. DISPLACE OUT FREEZE PROTECT. -PUMP 51 BBLS 8.5 PPG SEAWATER DOWN IA TAKING RETURNS UP TUBING. -PUMP AT 5 BPM WITH 530 PSI. -LINE UP AND PUMP DOWN TUBING. -PUMP 180 BBLS DOWN TUBING WITH 8.5 PPG SEAWATER. -PUMP AT 6 BPM WITH 490 PSI. -PUMP UNTIL RETURNS CLEAN UP. -APPROXIMATELY 180 BBLS DIESEL RECOVERED. -ACQUIRE SLOW CIRCULATING RATES. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 6 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UVN:500292112300 Active datum:S-16 c@67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 23:00 - 00:00 1.00 CONDHL P DECOMP I MONITOR WELL FOR(10)MINUTES.WELL STATIC. I-BLOW DOWN ALL SURFACE LINES TO FLOW BACK TANK. -R/D CELLAR LINES. -R/U SLB SPOOL AND DOUBLE STACK TONGS ON RIG FLOOR. 2/4/2015 00:00 - 02:00 2.00 CONDHL P DECOMP PTSM.R/D SURFACE LINES AND CHOKE SKID. -CROWN-O-MATIC AND SPCC CHECKS- GOOD. 02:00 - 07:00 5.00 BOPSUR P DECOMP PJSM.PULL TUBING HANGER TO RIG FLOOR. -WELL OUT OF BALANCE,BEFORE PULLING HANGER FREE CIRCULATE 157 BBLS DOWN TUBING TAKING RETURNS UP IA. -MONITOR WELL FOR(10)MINUTES.DIESEL STILL MIGRATING UP IA. -CIRCULATE 710 BBLS DOWN TUBING TAKING RETURNS UP THE IA. -MONITOR WELL FOR(15)MINUTES.WELL ASTABLE. M/U LANDING JOINT. -CAMERON BOLDS. PULL HANGER TO RIG FLOOR.PUW=146 KLBS. 07:00 - 09:00 2.00 CONDHL P DECOMP PJSM.CIRCULATE WELL BORE. -CLOSE ANNULAR PREVENTER. -CIRCULATE BOTTOMS UP THROUGH CHOKE MANIFOLD. -PUMP AT 6 BPM=350 PSI. -MONITOR WELL FOR(15)MINUTES.WELL STATIC. -PUMP 20 BBL DRY JOB. 09:00 10:00 1.00 BOPSUR P DECOMP R/D AND PREPARE TO POOH WITH 4-1/2" • 13CR80 TUBING. -L/D LANDING JOINT. -TERMINATE CONTROL LINES. -L/D HANGER. BLOW DOWN TOP DRIVE,CHOKE,AND MUD •GAS SEPARATOR. -R/U 4-1/2"EQUIPMENT. 10:00 - 12:00 2.00 PULL P DECOMP PJSM.POOH WITH 4-1/2"13CR80 TUBING. -POOH FROM 10,306'MD TO 9,233'MD. -SLB SPOOLING DUAL CONTROL LINE. -ACQUIRE SLOW CIRCULATING RATES. LOSSES TO WELL PAST(12)HOURS=0 BBLS 8.5 PPG SEAWATER. 12:00 - 12:30 ' 0.50 PULL P DECOMP PTMS.SERVICE RIG. -INSPECT AND SERVICE PIPE SKATE RIG FLOOR EQUIPMENT. -CROWN-O-MATIC AND SPCC CHECKS- GOOD. 12:30 - 19:00 6.50 PULL P DECOMP PJSM.POOH WITH 4-1/2"13CR80 TUBING. -POOH FROM 9,233'MD TO 2,912'MD. -SLB SPOOLING DUAL CONTROL LINE TO SSSV.RECOVERED 27 DUAL LINE CLAMPS. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 7 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UW:500292112300 Active datum:S-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 00:00 5.00 PULL N HMAN DECOMP SAFETY SHUT DOWN FOR PINCHED FINGER INCIDENT. -PROPER NOTIFICATION MADE. -WELL SECURED AND ALL OPERATIONS STOPPED. -INCIDENT INVESTIGATION WITH DDI SAFETY,DRILLING SUPERINTENDENT,BP HSE,DRILLING SUPERINTENDENT AND WSLS. 2/5/2015 00:00 - 09:00 9.00 PULL N HMAN DECOMP SAFETY SHUT DOWN FOR PINCHED FINGER INCIDENT. -SAFETY VALVE INSTALLED,HOLE FILL IS ON AND WELL IS BEING MONITORED.LOSS RATE =0 BPH. 09:00 - 12:00 3.00 PULL N HMAN DECOMP SAFETY SHUT DOWN FOR PINCHED FINGER INCIDENT. -REVIEWED PAST INCIDENTS WITH THE CREW,HAD CREWS WRITE UP COMMITMENT TO SAFETY STATEMENTS TO GO BACK TO WORK. 12:00 - 19:00 7.00 PULL N HMAN DECOMP SAFETY SHUT DOWN FOR PINCHED FINGER INCIDENT. -SAFETY VALVE INSTALLED,HOLE FILL IS ON AND WELL IS BEING MONITORED.LOSS RATE =0 BPH. 19:00 - 23:00 4.00 PULL P DECOMP PJSM.POOH WITH 4-1/2"13CR80 TUBING. -POOH FROM 2,912'MD TO SURFACE. -RECOVERED:(261)JOINTS,(5)GLM,(1)XN, (1)PUP JOINT,(1)CUT JOINT 3.71'WITH 4.56" FLARE. 23:00 - 00:00 1.00 PULL P DECOMP PJSM.R/D 4-1/2"TUBING EQUIPMENT. -MOVE DOUBLE STACK TONGS OFF RIG FLOOR. -CLEAR AND CLEAN RIG FLOOR. LOSSES TO WELL PAST(24)HOURS=0 BBLS 8.5 PPG SEAWATER. NO PUMP OPERATIONS WITH SLOW CIRCULATING RATES. 2/6/2015 00:00 - 01:00 1.00 PULL P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. HAD CREW MEMBERS WRITE UP THEIR COMMITMENT TO SAFETY STATEMENTS. -WSLAND TOOLPUSHER PRESENT FOR DISCUSSION WITH CREW AROUND THEIR SAFETY COMMITMENTS. 01:00 - 01:30 0.50 BOPSUR P DECOMP INSTALL WEAR RING,ID=12-1/8". 01:30 - 02:30 1.00 EVAL P DECOMP PJSM.R/U AND RUN LOGGING TOOLS WITH E-LINE. -LOAD AND R/U SLB E-LINE EQUIPMENT ON RIG FLOOR. 02:30 - 04:00 1.50 EVAL P DECOMP RIH WITH 9-5/8"CASING CALIPER. -LOG FROM 2,000'MD TO SURFACE. 04:00 - 05:00 1.00 EVAL P DECOMP PJSM.CHANGE OUT CALIPER TOOLS TO USIT TOOLS. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 8 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:OOAM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16 Q67.12usft(above Mean Sea Level) Date 1 From-To 1 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) '105:00 - 10:30 5.50 EVAL P DECOMP 1RIH WITH 9-5/8"USIT LOGGING TOOLS. • -LOG FROM 2,800'MD TO SURFACE,REPEAT RUN TO CONFIRM DATA. 10:30 - 11:30 1.00 EVAL P DECOMP PJSM.R/D SLB EQUIPMENT. -DRAIN STACK. 11:30 - 12:30 1.00 DHB P DECOMP PJSM.M/U 9-5/8"HES RBP. -M/U 9-5/8"RUNNING TOOL AND RBP. 12:30 - 15:00 2.50 DHB P DECOMP PJSM.RIH WITH 9-5/8"HES RBP. • -RIH ON 4"DP FROM SHED. -RIH FROM SURFACE TO 1,593'MD. -SET RBP AT 1,593'MD. 15:00 - 16:00 1.00 DHB P DECOMP PJSM.PRESSURE TEST RBP. -R/U TEST EQUIPMENT. 1-PRESSURE TEST RBP TO 250 PSI LOW, 1,000 PSI HIGH FOR 5 CHARTED MINUTES. SUCCESSFUL TEST. 16:00 - 16:30 0.50 DHB P DECOMP POOH AND UD 3 JOINTS TO SHED. -POOH FROM 1,593'MD TO 1,507'MD. -ACQUIRE SLOW CIRCULATING RATES USING 8.5 PPG SEAWATER. 16:30 - 20:30 4.00 DHB P DECOMP SAFETY STAND DOWN WITH NEW CREW. -MEETING WITH BP WSL,SUPERINTENDENT [AND DDI SUPERINTENDENT. i-DISCUSS HOW TO IMPROVE SAFETY AND COMMITMENT TO SAFETY STATEMENT FROM — -- CREW. 20:30 - 00:00 3.50 DHB P DECOMP PJSM.DUMP 47 SACKS OF 20/45 RIVER SAND ON TOP OF RBP. 2/7/2015 00:00 - 01:30 1.50 DHB P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. 1-CROWN-O-MATIC AND SPCC CHECKS GOOD. j I CONTINUE TO DUMP 47 SACKS OF 20/45 RIVER SAND ON TOP OF RBP. 01:30 - 02:00 0.50 DHB P DECOMP P/U(1)STAND AND PUMP DRILL PIPE VOLUME. 02:00 - 03:00 1.00 DHB P DECOMP •PJSM.RIH AND TAG TOP OF SAND AT 1,533' •MD. • 1-ACQUIRE SLOW CIRCULATING RATES USING 8.5 PPG SEAWATER. 03:00 - 04:00 1.00 I DHB P DECOMP PJSM.POOH WITH 9-5/8"HES RBP RUNNING 'TOOL. -STAND BACK4"DRILL PIPE IN DERRICK. POOH FROM 1,533'MD TO 1,263'MD. -ADJUST NEW KELLY HOSE,IN THE WAY OF STANDING BACK DRILL PIPE. '-CONTINUE POOH FROM 1,263'MD TO SURFACE. -UD 9-5/8"HES RBP RUNNING TOOL. 04:00 - 04:30 0.50 CASING P DECOMP PJSM.PRESSURE TEST CASING. -R/U TESTING EQUIPMENT. -PRESSURE TEST 9-5/8"CASING TO 250 PSI LOW,3,000 PSI HIGH FOR 5 CHARTED MINUTES.GOOD TEST. -BLOW DOWN LINES,R/D TEST EQUIPMENT. 04 30 - 05:30 1.00 CASING P DECOMP PJSM.M/U BAKER 8-1/4"CUTTER BHA#1. -RIH WITH CUTTER BHA#1 FROM SURFCAE TO 13'MD. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 9 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:OOAM Rig Release:2/15/2015 Rig Contractor.DOYON DRILLING INC. UWI:500292112300 Active datum:5-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 07:30 2.00 CASING I P DECOMP RIH WITH BAKER 8-1/4"CUTTER BHA#1. -RIH FROM 13'MD TO 1,520'MD. -ACQUIRE SLOW CIRCULATING RATES USING 8.5 PPG SEAWATER. 07:30 - 08:30 • 1.00 CUT P DECOMP CUT 9-5/8"CASING AS PER BAKER REPRESENTATIVE. -CUT CASING AT 1,520'MD. -ROTATE AT 80 RPM,FREE TORQUE=2-3K FT-LBS,ROTATE WEIGHT=65 KLBS,TORQUE =3-10K FT-LBS. OPEN CIRCULATING SUB AND PUMP 5 BBLS. 08:30 - 10:30 2.00 CONDHL P DECOMP 'PJSM.R/U LRS TO PUMP DIESEL. PRESSURE TEST LRS LINES TO 250 PSI LOW,2,500 PSI HIGH.REVIEWED PRESSURE CROSS CHECK LIST IN PJSM. -PUMP 15 BBLS DIESEL TO FILL TUBING. -CLOSE ANNULAR AND PUMP 15 BBLS DIESEL THROUGH CUT TAKING RETURNS TO FLOW BACK TANK. -DISPLACE DRILL PIPE VOLUME WITH 16 BBLS 9.8 PPG BRINE AT 2 BPM=350 PSI. -ALLOW DIESEL TO SOAK FOR(1)HOUR IN OA.MONITOR OA THROUGHOUT SOAK 10.30 - 14:00 3.50 CONDHL P DECOMP 'PUMP 130 BBLS 9.8 PPG AT 2 BPM=350 PSI. • -PUMP 40 BBLS DEEP CLEAN PILL AT 2 BPM= 350 PSI. -CHASE WITH 8.5 PPG SEAWATER AT ICR 2 BPM=380 PSI,FCR 5 BPM=240 PSI. -BEGIN TAKING RETURNS TO TRIP TANK ONCE RETURNS ARE CLEAN 8.5 PPG SEAWATER. -SHUT DOWN AND MONITOR WELL FOR(10) MINUTES.WELL STATIC. 14:00 - 15:00 1.00 CONDHL P DECOMP PJSM.POOH WITH BAKER 8-1/4"CUTTER BHA #1. -BLOW DOWN TOP DRIVE. -POOH FROM 1,520'MD TO 41'MD.MONITOR WELL PRIOR TO BHA#1 ENTERING STACK. WELL STATIC. 15:00 - 16:00 1.00 CONDHL P DECOMP PJSM.L/D BAKER 8-1/4"CUTTER BHA#1. -L/D BAKER TOOLS,CLEAR AND CLEAN RIG FLOOR. 16:00 - 16:30 0.50 WHSUR P DECOMP P/U RUNNING TOOL AND PULL WEAR RING. -L/D RUNNING TOOL AND WEAR RING. 16:30 - 17:30 1.00 CONDHL P DECOMP PJSM.M/U BAKER 9-5/8"SPEAR BHA#2. -RIH AND SPEAR INTO 9-5/8"CASING HANGER. -R/U 9-5/8"CASING EQUIPMENT. 17:30 - 19:30 2.00 WHSUR P I DECOMP CAMERON FLUSH GLAND NUT PACKINGS AND BOLDS. 19:30 - 20:00 0.50 CASING P DECOMP PJSM.PULL 9-5/8"HANGER TO RIG FLOOR. -FREE AT 110 KBS,PUW=102 KLBS. -PULL TO RIG FLOOR. 20:00 - 20:30 0.50 CASING P DECOMP i CIRCULATE AND RECIPROCATE 9-5/8" CASING. -ACQUIRE SLOW CIRCULATING RATES. -MONITOR WELL FOR(10)MINUTES.WELL STATIC. 20:30 - 21:00 0.50 CASING I P DECOMP PJSM.L/D BAKER 9-5/8"SPEAR BHA#2. -L/D SPEAR AND HANGER. Printed 2/23/2015 12.18:45PM North America-ALASKA-BP Page 10 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:OOAM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UW:500292112300 Active datum:S-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 CASING P DECOMP PJSM.POOH WITH 9-5/8"CASING. -POOH FROM 1,520'MD TO 861'MD. FLUID LOSS PAST(24)HOURS=0 BBLS 8.5 PPG BRINE. 2/8/2015 00:00 - 03:00 3.00 CASING P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. PJSM.POOH WITH 9-5/8"CASING. -POOH FROM TO 861'MD TO SURFACE. CASING WAS IN GOOD CONDITION,NO MAJOR CORROSION NOTED. -AVERAGE BREAKOUT TORQUE=40,000 FT-LBS. -RECOVERED:(36)JOINTS,(1)PUP JOINT,(1) CUT JOINT=14.83'WITH 10"FLAIR,(9) TURBO CLAMPS. 03:00 - 04:00 1.00 CASING P DECOMP R/D 9-5/8"CASING EQUIPMENT. CLEAR AND CLEAN RIG FLOOR. 04:00 - 06:30 2.50 CUT P DECOMP PJSM.M/U BAKER 9-5/8"DRESS OFF BHA#3. -P/U(6)6-1/4"DRILL COLLARS. RIH FROM SURFACE TO 220'MD. 06:30 - 07:00 0.50 CUT P DECOMP PJSM.RIH WITH BAKER 9-5/8"DRESS OFF BHA#3. -RIH FROM 220'MD TO 1,451'MD. ACQUIRE SLOW CIRCULATING RATES. -RIH AND TAG TOP OF STUMP AT 1,519.5'MD. 07:00 - 10:00 3.00 CUT P DECOMP M/U DRILL PIPE TO TOP DRIVE. -PUW=75 KLBS,SOW=76 KLBS,ROTATE WEIGHT=75 KLBS,FREE TORQUE=3 K FT-LBS. -RIH AND BEGIN MILLING. -ROTATE AT 40-60 RPM,WOB=2-8 KLBS. -DRESS OFF 9-5/8"CASING TO 1,521'MD. 10:00 - 11:00 1.00 CUT P DECOMP PUMP 40 BBL DEEP CLEAN PILL AT 12 BPM= 500 PSI. -BLOW DOWN TOP DRIVE. -MONITOR WELL FOR(10)MINUTES. 11:00 - 12:00 1.00 CUT P DECOMP PJSM.POOH WITH BAKER 9-5/8"DRESS OFF BHA#3. -POOH FROM 1,521'MD TO 315'MD. 12:00 - 12:30 0.50 CUT P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. 12:30 - 13:00 0.50 CUT P DECOMP PJSM.POOH WITH BAKER 9-5/8"DRESS OFF BHA#3. -POOH FROM 315'MD TO 220'MD. -MONITOR WELL BEFORE ENTERING BOPE STACK.WELL STATIC. 13:00 - 14:30 1.50 CUT P DECOMP PJSM.UD BAKER 9-5/8"DRESS OFF BHA#3. -CLEAR AND CLEAN RIG FLOOR. 14:30 - 16:30 2.00 CUT P DECOMP DRAIN OUT BOPE STACK. -RECOVERED(3)GALLONS OF METAL SHAVINGS. FLUSH OUT STACK. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 11 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor.DOYON DRILLING INC. UWI:500292112300 Active datum:S-16©67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 18:30 2.00 BOPSUR P DECOMP P/U RUNNING TOOL. SET TEST PLUG,UD RUNNING TOOL. -CAMERON RILDS. - - --- — ---- — ---- ---- 18:30 - 00:00 5.50 BOPSUR P DECOMP PJSM.TEST FOUR PREVENTER 13-5/8"BOPE AND RELATED EQUIPMENT. -TEST BOPE ACCORDING TO AOGCC REGULATIONS,DOYON AND BP PROCEDURES. -TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES. FLUID LOSS PAST(24)HOURS=0 BBLS 8.5 PPG BRINE. 2/9/2015 00:00 - 09:00 9.00 BOPSUR P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. PJSM.TEST FOUR PREVENTER 13-5/8"BOPE AND RELATED EQUIPMENT. -TEST UPPER 9-5/8"FIXED RAMS WITH 9-5/8" j TEST JOINT TO 250 PSI,3,500 PSI HIGH FOR 5 (CHARTED MINUTES. I-TEST LOWER 3-1/2"X 6"VARIABLE RAMS WITH 4-1/2"AND 4"TEST JOINT TO 250 PSI, 3,500 PSI HIGH FOR 5 CHARTED MINUTES. -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3,500 PSI HIGH FOR 5 CHARTED MINUTES. -PERFORM ACCUMULATOR DRAW DOWN TEST WITH WSL PRESENT. -MPL TEST ALL RAMS. -(1)FOSV FAILURE,REPLACED WITH NEW FOSV AND RETEST.GOOD TEST. '-(1)BLIND RAM FAILURE,CHANGE OUT BLIND RAMS AND RETEST.GOOD TEST. 1-JEFF JONES WITNESSED TEST. 09:00 - 10:00 1.00 BOPSUR P DECOMP R/D TEST EQUIPMENT. !-DRAIN BOPE STACK. -CAMERON BOLDS. P/U RUNNING TOOL AND PULL TEST PLUG, UD RUNNING TOOL. 10:00 - 11:00 1.00 BOPSUR P DECOMP i PJSM.N/D 13-5/8"FOUR PREVENTER BOPE STACK. -N/D BOPE STACK AND SET ON STUMP. 11:00 - 14:00 3.00 WHSUR P DECOMP PJSM.N/D TUBING SPOOL AND REMOVE •FROM CELLAR. -R/U BRIDGE CRANES ON WELL HEAD AND SECURE. 1400 - 15:30 1.50 WHSUR P' DECOMP PJSM.M/U BAKER 11-3/4"CUTTER BHA#4. 15:30 - 17:00 1.50 CUT P DECOMP RIH AND POSITION CUTTER BELOW WELLHEAD. ROTATE AT 40 RPM USING TEST PUMP TO 150 PSI. -FINAL ROTATE 60 RPM WITH TEST PUMP TO 890 PSI. -CUT WELL HEAD. 17.00 - 18:30 1.50 CUT P DECOMP UD BAKER 11-3/4"CUTTER BHA#4. CLEAN AND CLEAR RIG FLOOR. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 12 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X400XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud DateTme:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:5-16 t 67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (usft) 18:30 - 19:30 1.00 CUT P DECOMP REMOVE WELLHEAD FROM CELLAR. -INSTALL FMC 13-3/8"LANDING RING AND SLIP BOWL ASSEMBLY ON THE 13-3/8"STUB. i-REINSTALL BRIDGE CRANES ON STACK CLEAR CELLAR. 19:30 - 20:30 1.00 CUT P DECOMP R/D 9-5/8"POWER TONGS FROM RIG FLOOR. 20:30 - 22:00 1.50 CASING P DECOMP PJSM.R/U VOLANT TOOL AND RELATED EQUIPMENT FOR RUNNING 9-5/8"CASING. 22:00 - 00:00 2.00 CASING P DECOMP 'PJSM.RIH WITH 9-5/8"47#L-80 VAMTOP CASING TIE-BACK. -P/U AND M/U PAYZONE ECP AND HES ES CEMENTER. -RIH FROM SURFACE TO 267'MD. FLUID LOSS PAST(24)HOURS=0 BBLS 8.5 PPG BRINE. NO PUMP OPERATIONS WITH SLOW CIRCULATING RATES. 2/10/2015 00:00 - 05:00 5.00 CASING P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. PJSM.RIH WITH 9-5/8"47#L-80 VAMTOP CASING TIE-BACK. -RIH FROM 267'MD D TO 1,521'MD. 05:00 - 08:30 3.50 CASING P DECOMP SPACE OUT AND ENGAGE CASING PATCH OVER STUMP AS PER BAKER REPRESENTATIVE. -OVER PULL TO 100 KLBS. 08:30 - 10:00 1.50 CASING P DECOMP PJSM.R/D VOLANT TOOL. -R/U AND M/U CEMENT HEAD. PRESSURE TEST LINES TO 250 PSI LOW, 3.500 PSI HIGH. -FILL CASING. 10:00 - 10:30 0.50 CASING P DECOMP PJSM.INFLATE ECP AS PER BAKER REPRESENTATIVE. -INCREASE PRESSURE IN 200 PSI INCREMENTS UP TO 1,700 PSI.PRESSURE DROP TO INDICATE ECP INFLATED. I-PRESSURE UP TO 2,000 PSI TO CLOSE ECP INFLATE VALVE FOR(10)MINUTES. -BLEED OFF PRESSURE TO 0 PSI. -PRESSURE UP TO 2,000 PSI FOR(10) CHARTED MINUTES. 10:30 - 11:30 1.00 CASING P DECOMP PJSM.SHEAR OPEN HES ES CEMENTER. -PRESSURE UP TO 2,800 PSI TO SHEAR. -CIRCULATE 110 BBLS AT 5 BPM=160 PSI TAKING RETURNS TO CELLAR BOX. 11:30 - 12:00 0.50 WHSUR P DECOMP PJSM.FMC REPRESENTATIVE SET MANUAL i SLIPS WITH 100 KLBS TENSION. R/U SCHLUMBERGER CEMENTERS. 12:00 - 13:00 1.00 CASING P DECOMP PJSM FOR CEMENT JOB WITH WSL, TOOLPUSHER,ALL CREW MEMBERS INVOLVED AND SCHLUMBERGER. REVIEW PRESSURE CROSS CHECK LIST AND ANSWER ALL CHALLENGE QUESTIONS. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 13 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3.7731000.00) Project:Prudhoe Bay i Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16(g67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 15:30 2.50 CASING P DECOMP CEMENT 9-5/8"47#L-80 TIE BACK -BLOW DOWN HARDLINE FROM RIG FLOOR TO CEMENT UNIT. -PUMP 10 BBLS OF FRESHWATER TO PRIME LINES. -PRESSURE TEST TO 250 PSI LOW FOR 5 MINUTES.GOOD TEST MEETING BP LOW I PRESSURE TEST CRITERIA. 1-PUMP 5 BBLS OF FRESHWATER. -PRESSURE TEST TO 4,500 PSI HIGH FOR 5 MINUTES.GOOD TEST MEETING BP HIGH PRESSURE TEST CRITERIA. -BLOW DOWN HARDLINE FROM RIG FLOOR TO CEMENT UNIT. 1 1-MIX,(ON THE FLY),AND PUMP 115 BBLS OF 115.8 PPG CLASS G CEMENT. -SHUT DOWN AND DROP HES CLOSING PLUG.WSL VERIFY PLUG RELEASE FROM CEMENT HEAD VIA TATTLETALE. 1-DISPLACE WITH SCHLUMBERGER 1 CEMENTERS WITH 110.9 BBLS OF 8.5 PPG. -NOTED CEMENT RETURNS IN CELLAR 'AFTER 79 BBLS PUMPED AWAY.FINAL PUMP PRESSURE=625 PSI PRIOR TO CLOSING ES CEMENTER. -BUMP PLUG AND PRESSURE UP TO 1,850 PSI TO CLOSE ES CEMENTER.GOOD INDICATION AT SURFACE THAT ES CEMENTER WAS CLOSED. -CEMENT WET AT 13:55 HRS ON 02/10/2015. -CEMENT IN PLACE AT 15:28 HRS ON 02/10/2015. 15:30 - 17:00 1.50 CASING P DECOMP BLOW DOWN LINES. -R/D SCHLUMBERGER CEMENTERS. -R/D CEMENT HEAD AND CLEAR RIG FLOOR. 17:00 - 19:30 2.50 CUT P DECOMP PJSM.WACHS CUT 9-5/8"CASING. -P/U 2,000 KLBS ON TOP DRIVE. -CAMERON R/U WACHS CUTTER AND CUT 9-5/8"CASING. -UD CUT JOINT AND DRESS STUMP. 19:30 - 00:00 4.50 WHSUR P ! DECOMP PJSM.INSTALL CAMERON 9-5/8"SLIPLOCK WELLHEAD. FLUID LOSS PAST(24)HOURS=0 BBLS 8.5 PPG BRINE. 2/11/2015 00:00 - 02:00 2.00 WHSUR P DECOMP 1PTSM.SPCC AND EQUIPMENT CHECKS 'AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. PJSM.INSTALL CAMERON 9-5/8"SLIPLOCK WELLHEAD. -PRESSURE TEST SEALS TO 250 PSI LOW FOR(5)MINUTES AND 3,500 PSI HIGH FOR (30) INSTALL DOUBLE I/A VALVES,SET TEST PLUG AND RUN IN LOCK DOWN SCREWS.(5 1/4"WHEN LOCK DOWNS ARE IN,6"WHEN OUT). 02 00 03:30 1.50 BOPSUR P DECOMP PJSM.N/U 11"X 13-5/8"ADAPTER FLANGE. -N/U 13-5/8"X 5M FOUR PREVENTER BOPE. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 14 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-0OXL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT ! NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 04:30 1.00 BOPSUR P DECOMP PJSM.FILL AND BODY TEST BOPE. -TEST BREAKS AND BODY TEST BOP TO 250 PSI LOW,3,500 PSI HIGH FOR(5)MINUTES, CHARTED.GOOD TEST. -BLEED ALL PRESSURE AND RIG DOWN TEST EQUIPMENT. 04:30 - 06:00 1.50 WHSUR P DECOMP PJSM.CAMERON REP BACK OUT LOCK DOWN SCREWS ON TEST PLUG,(6"OUT). -PULL TEST PLUG,INSTALL WEAR BUSHING, (9"ID). LAY DOWN RUNNING TOOL. 06:00 - 07:30 1.50 CLEAN P DECOMP PJSM.P/U AND M/U 8-1/2"BAKER DRILL OUT BHA#5. -RIH FROM SURFACE TO 219'MD. 07:30 - 08:30 1.00 CLEAN P DECOMP RIH WITH 8-1/2"BAKER DRILL OUT BHA#5. -RIH FROM 219'MD TO 1,449'MD. -ACQUIRE SLOW CIRCULATING RATES. -ESTABLISH PARAMETERS:PUW=71 KLBS, SOW=75 KLBS,ROTATE WEIGHTS=74 KLBS,FREE TORQUE=5 K FT-LBS,RPM= 100,PUMP AT 3 BPM=60 PSI. -RIH AND TAG TOP OF CEMENT PLUG AT 1,475'MD. 08:30 - 15:00 6.50 CLEAN P DECOMP PJSM.DRILL OUT CEMENT SHOE TRACT. --DRILL PLUG AND ES CEMENTER FROM 1,475'MD TO 1,480'MD AT 100 RPM,WOB= 2-4 KLBS,TORQUE=2-5 K FT-LBS. 1-DRILL CEMENT FROM 1,480'MD TO 1,531' MD AT 80 RPM,WOB=5 KLBS,TORQUE=2-3 K FT-LBS. -P/U AND PUMP 20 BBLS HI-VIS SWEEP AT ICR 5 BPM=140 PSI,FCR 8 BPM=320 PSI. -DRY DRILL FOR(15)MINUTES ON TOP OF SAND AT 40 RPM,WOB=3 KLBS. -P/U AND WASH DOWN FROM 1,531'MD TO 1,544'MD. -PUMP 20 BBLS HI-VIS SWEEP AT 8 BPM= 320 PSI. MONITOR WELL FOR(10)MINUTES.WELL STATIC. 15:00 - 15:30 0.50 CLEAN P DECOMP PICK UP FROM 1,544'MD TO 1,530'MD. -PERFORM TOP DRIVE INSPECTION. -BLOW DOWN TOP DRIVE. 15:30 - 16:30 1.00 CLEAN P DECOMP PJSM.POOH WITH 8-1/2"BAKER DRILL OUT BHA#5. -POOH FROM 1,530'MD TO 313'MD. -MONITOR WELL FOR(10)MINUTES PRIOR TO BHA ENTERING STACK 16:30 - 18:30 2.00 CLEAN P DECOMP PJSM.L/D 8-1/2"BAKER DRILL OUT BHA#5. -STAND BACK DRILL COLLARS. CLEAN OUT BOOT BASKETS AND RECOVERED:3.5 GALLONS SAND,1 GALLON METAL,1 GALLON CEMENT. 18:30 - 20:30 2.00 CASING P DECOMP PJSM.PRESSURE TEST 9-5/8"CASING. -R/U TESTING EQUIPMENT. -PRESSURE TEST 9-5/8"CASING TO 250 PSI LOW FOR(5)MINUTES,3,500 PSI FOR(45) j 1 MINUTES.PASSES BP TESTING CRITERIA. WTL RICH BURNETT APPROVAL TO PROCEED. 1-R/D TEST EQUIPMENT. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 15 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16©67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:30 - 22:00 1.50 CLEAN P DECOMP PJSM.M/U 8-1/2"BAKER RCJB BHA#6. RIH FROM SURFACE TO 229'MD. 22:00 - 23:30 1.50 CLEAN P DECOMP RIH WITH 8-1/2"BAKER RCJB BHA#6. -RIH FROM 229'MD TO 1,542'MD. -ACQUIRE SLOW CIRCULATING RATES. -ROTATE AT 40 RPM,PUMP AT 5 BPM=1,640 PSI. -WASH FROM 1,542'MD TO 1,587'MD. -TAG TOP OF RBP AT 1,587'MD,SET DOWN 4 KLBS TO VERIFY. 23:30 - 00:00 0.50 CLEAN P DECOMP PICK UP TO 1,584'MD AND PUMP 20 BBL HI-VIS SWEEP AT 5 BPM=1,650 PSI. FLUID LOSS PAST(24)HOURS=0 BBLS 8.5 PPG BRINE. 2/12/2015 00:00 - 01:00 1.00 CLEAN P DECOMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. CONTINUE CIRCULATING AT 7 BPM=2,740 PSI UNTIL RETURNS ARE CLEAN 8.5 PPG SEAWATER. -BLOW DOWN TOP DRIVE. -MONITOR WELL FOR(10)MINUTES.WELL STATIC. 01:00 - 02:00 1.00 CLEAN P DECOMP PJSM.POOH WITH 8-1/2"BAKER RCJB BHA #6. -POOH FROM 1,584'MD TO 229'MD. -MONITOR WELL FOR(10)MINUTES.WELL STATIC. 02:00 - 04:00 2.00 CLEAN P DECOMP PJSM.UD 8-1/2"BAKER RCJB BHA#6. -L/D DRILL COLLARS TO PIPE SHED. -RECOVERED:5 GALLONS OF METAL FROM MAGNET,2 LARGE PIECES OF ES CEMENTER SLEEVE,ALUMINUM AND SMALL BITS OF RUBBER. CLEAR AND CLEAN RIG FLOOR. 04:00 - 05:00 1.00 CLEAN P DECOMP PJSM.M/U 9-5/8"HES RBP RETRIEVAL TOOL. 05:00 - 06:00 1.00 CLEAN P DECOMP RIH WITH 9-5/8"HES RBP RETRIEVAL TOOL. 06:00 - 08:00 2.00 CLEAN P DECOMP PJSM.SLIP AND CUT DRILLING LINE. -CUT AND SLIP 60'OF DRILLING LINE, INSPECT DRAWWORKS. -INSPECT AND ADJUST BRAKES,INSTALL NEW DEADMAN BOLTS. 08:00 - 09:00 1.00 CLEAN P DECOMP CONTINUE TO RIH W/RBP RETRIEVING TOOL. -RIH TO 1585',UP WT=60K,DOWN WT=65K. -ALL WT CHECKS INCLUDE 40K TOP DRIVE WT. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 16 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16©67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:00 - 10:30 1.50 CLEAN P DECOMP PJSM.RIG UP TO REVERSE CIRCULATE THROUGH TOP DRIVE. -ACQUIRE SLOW CIRCULATING RATES. -REVERSE CIRCULATE 20 BBLS HI VIS SWEEP FOLLOWED BY 8.5 PPG SEAWATER. PUMP AT 7 BPM=450 PSI,OBSERVE SWEEP BACK WITH SOME SMALL RUBBER AND METAL PARTICULATE. -OBSERVE CLEAN SEAWATER RETURNS, PUMPED TOTAL OF 150 BBLS 8.5 PPG SEAWATER BEHIND SWEEP. 10:30 - 12:00 1.50 CLEAN P DECOMP PJSM.ENGAGE HALLIBURTON RBP AT 1,587' MD AND RELEASE. -BLOW DOWN KILL LINE AND TOP DRIVE, MONITOR WELL FOR(10)MINUTES.WELL STATIC. -PULL(1)JT DRILL PIPE AND LAY DOWN SAME.NOTICE OVER PULL ON 2ND JT.(25K OVER). FLUID LOSSES TO WELL PAST(12)HRS=0 BBLS 8.5 PPG SEAWATER. 12:00 - 12:30 0.50 CLEAN P DECOMP SERVICE RIG AND INSPECT ALL EQUIPMENT. PRE JOB MEETING ON POOH AND HALLIBURTON BRIDGE PLUG HANGING UP. 12.30 - 13:00 0.50 CLEAN P DECOMP ESTABLISH PARAMETERS AND CIRCULATE DOWN DRILL PIPE AT 8 BPM=330 PSI. -PICK UP AND OBSERVE 15K OVERPULL TO 75K AND BRIDGE PLUG FREE. POOH TO 1,555'MD. 13:00 - 15:30 2.50 CLEAN P DECOMP PJSM.BLOW DOWN TOP DRIVE. -CONTINUE TO POOH SLOWLY FROM 1,555' MD TO 80'MD,LAYING DOWN DRILL PIPE. -MONITOR WELL FOR(10)MINUTES.WELL STATIC. -INSPECT RBP,SIGNIFICANT AMOUNT OF METAL SHAVINGS IN PACKER ABOVE UPPERMOST ELEMENT. -PICTURES SENT TO TOWN ENGINEERS AND DISCUSSION WITH HALLIBURTON REPS. 15:30 - 17:00 1.50 BOPSUR P DECOMP PULL AND L/D WEAR RING. -CLEAR AND CLEAN RIG FLOOR. 17:00 - 18:30 1.50 RUNCOM P RUNCMP R/U EQUIPMENT ON RIG FLOOR FOR RUNNING 4-1/2"12.6#13CR-85 VAMTOP COMPLETION. 18:30 - 00:00 5.50 RUNCOM P RUNCMP PJSM.RUN 4-1/2"12.6#13CR-85 VAMTOP COMPLETION. -RIH FROM SURFACE TO 1,532'MD.(PACKER AT 1,410'MD). -REVERSE CIRCULATE 25 BBLS 8.5 PPG SEAWATER,PUMP AT 3 BPM=140 PSI. NOTHING NOTED OVER SHAKERS. -RIH FROM 1,532'MD TO 1,615'MD.(PACKER AT 1,492'MD). -REVERSE CIRCULATE 25 BBLS 8.5 PPG SEAWATER,PUMP AT 3 BPM=140 PSI. NOTHING NOTED OVER SHAKERS. -ACQUIRE SLOW CIRCULATING RATES. -BLOW DOWN CHOKE AND KILL LINES. FLUID LOSSES TO WELL PAST(24)HRS=0 BBLS 8.5 PPG SEAWATER. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 17 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:OOAM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16©67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/13/2015 00:00 - 00:30 0.50 RUNCOM P RUNCMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. 00:30 - 12:00 11.50 RUNCOM P RUNCMP PJSM.RUN 4-1/2"12.6#13CR-85 VAMTOP COMPLETION. -ALL TUBING DRIFTED WITH 3.833"OD DRIFT. -USE TORQUE TURN SERVICES TO 4,440 FT-LBS. USE JET LUBE SEAL GUARD THREAD COMPOUND. ALL CONNECTIONS BELOW PACKER BAKER-LOCED. -RIH FROM 1,532'MD TO 5,168'MD.(PACKER AT 5,046'MD). -REVERSE CIRCULATE 80 BBLS 8.5 PPG SEAWATER,PUMP AT 3 BPM=150 PSI. NOTHING NOTED OVER SHAKERS. -RIH FROM 5,168'MD TO 8,668'MD. -ACQUIRE SLOW CIRCULATING RATES. -LOSSES TO THE WELL=0 BBLS. 12:00 - 14:30 2.50 RUNCOM P RUNCMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. PJSM.RUN 4-1/2"12.6#13CR-85 VAMTOP COMPLETION. -ALL TUBING DRIFTED WITH 3.833"OD DRIFT. -USE TORQUE TURN SERVICES TO 4,440 FT-LBS. -USE JET LUBE SEAL GUARD THREAD COMPOUND. -ALL CONNECTIONS BELOW PACKER BAKER-LOCED. -RIH FROM 8,668'MD TO 10,245'MD. -REVERSE CIRCULATE 160 BBLS 8.5 PPG SEAWATER,PUMP AT 3 BPM=170 PSI. NOTHING NOTED OVER SHAKERS. -ACQUIRE SLOW CIRCULATING RATES._ 14:30 - 16:30 2.00 RUNCOM P RUNCMP PJSM.SHEAR OVERSHOT PINS AND PERFORM SPACE OUT. -RIH FROM 10,245'MD TO 10,310'MD,SHEAR OUT LOWER PINS WITH 10 KLBS DOWN. -RIH FROM 10,310'MD TO 10,318'MD,SHEAR OUT UPPER PINS WITH 10 KLBS DOWN. -RIH FROM 10,318'MD TO 10,320'MD,NO-GO 31'IN ON JOINT 240 WITH 5 KLBS DOWN. -NO SPACE OUT PUPS REQUIRED,SPACE OUT 4.60'ABOVE NO-GO. 16:30 - 18:30 2.00 RUNCOM P RUNCMP PJSM.LAND CAMERON TUBING HANGER. -P/U LANDING JOINT AND M/U IN HANGER, PUW=141 KLBS,SOW=129 KLBS. -LAND HANGER,CAMERON RILDS. -L/D LANDING JOINT. • Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 18 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) I Start Date:2/1/2015 1 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) I Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16©67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:30 - 19:30 1.00 RUNCOM P • RUNCMP R/U TO REVERSE CIRCULATE 8.5 PPG SEAWATER VNTH MI KI-3869. -R/U LINES AND PRESSURE TEST TO 250 PSI LOW,3,500 PSI HIGH FOR(5)CHARTED MINUTES.GOOD TEST. 19:30 - 22:00 2.50 RUNCOM P RUNCMP PJSM.REVERSE CIRCULATE 8.5 PPG SEAWATER WITH MI KI-3869. REVIEWED PRESSURE CROSS CHECK LIST, ALL CHALLENGE QUESTIONS ANSWERED CORRECTLY. -REVERSE CIRCULATE AT 4 BPM,PUMP 53 BBLS AND NOTED MI KI-3869 IN RETURNS. -SHUT DOWN PUMPS AND TROUBLE SHOOT, DISCOVERED WASHED OUT HALLIBURTON ;1 VALVE ON SQUEEZE MANIFOLD IN CELLAR. 2200 - 00:00 2.00 RUNCOM N SFAL RUNCMP i PJSM.CHANGE SCOPE OF WORK ON 'PRE-JOB TO REFLECT CHANGING OUT I HALLIBURTON VALVE. -BLOWDOWNALLLINES. -CHANGE OUT HALLIBURTON VALVE. PRESSURE TEST LINES TO 250 PSI LOW, 3,500 PSI HIGH FOR(5)CHARTED MINUTES. GOOD TEST. r FLUID LOSSES TO WELL PAST(24)HRS=0 BBLS 8.5 PPG SEAWATER. 2/14/2015 00:00 - 00:30 0.50 RUNCOM P RUNCMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. CROWN-O-MATIC AND SPCC CHECKS GOOD. 00:30 - 03:30 3.00 RUNCOM P RUNCMP PJSM.REVERSE CIRCULATE 8.5 PPG SEAWATER WITH MI KI-3869. -REVIEWED PRESSURE CROSS CHECK LIST, 'ALL CHALLENGE QUESTIONS ANSWERED CORRECTLY. -REVERSE CIRCULATE AT 3.5 BPM=600 PSI, PUMP TOTAL OF 546 BBLS DOWN IA. Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 19 of 20 Operation Summary Report Common Well Name:S-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:00AM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16©67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 06:30 3.00 RUNCOM P RUNCMP PJSM.SET PACKER AND TEST 4-1/2"TUBING AND 9-5/8"CASING. -M/U LANDING JOINT. -DROP 2"BALL AND ROD. -L/D LANDING JOINT. -PRESSURE TEST TUBING TO 250 PSI LOW, 3,500 PSI HIGH FOR(30)CHARTED MINUTES. -TUBING BLED OFF FROM 3,725 PSI TO 3,660 PSI IN FIRST(15)MINUTES AND TO 3,630 PSI IN 2ND(15)MINUTES,PASSING TEST. -IA MONITORED THROUGH OUT TEST,NO FLOW FROM IA. BLEED TUBING PRESSURE DOWN TO 2,000 PSI AND HOLD PRESSURE. -PRESSURE TEST 9-5/8"X 4-1/2"TUBING TO 250 PSI LOW,3,500 PSI HIGH FOR(30) CHARTED MINUTES. -PRESSURE HELD AT 3,700 PSI FOR(30) MINUTES,NO PRESSURE LOST,PASSING TEST. -RECEIVED PERMISSION FROM WTL JAMES WILLINGHAM TO PROCEED AHEAD. -BLEED OFF TUBING PRESSURE AND OBSERVE DCR VALVE SHEAR. '-PUMPED BOTH WAYS THROUGH DCR VALVE AT 3 BPM=300 PSI TO CONFIRM SHEAR. 06.30 12:00 5.50 RUNCOM P RUNCMP PJSM.SPOT UP LITTLE RED HOT OIL SERVICES. -RIG UP LINES AND PRESSURE TEST TO 250 PSI LOW,3,500 PSI HIGH FOR(5)CHARTED MINUTES. -CIRCULATE 60 DEGREE DIESEL DOWN IA, THROUGH DCR VALVE AND UP TUBING. -TAKING SEAWATER RETURNS TO SLOP TANK. -PUMP AT ICR 1.5 BPM=20 PSI,FCR 1.5 BPM =300 PSI. -PUMP A TOTAL OF 172 BBLS OF DIESEL. -ALIGN VALVES AND ALLOW DIESEL TO U-TUBE FROM IA TO TUBING. FLUID LOSSES TO WELL PAST(12)HRS=0 BBLS 8.5 PPG SEAWATER. 12:00 - 15:00 3.00 RUNCOM P RUNCMP PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. -CROWN-O-MATIC AND SPCC CHECKS GOOD. PJSM.SET TWC WITH DRY ROD. -LRS PRESSURE TEST TWC FROM BELOW AND ON TOP TO 250 PSI LOW,3,500 PSI HIGH FOR(5)CHARTED MINUTES.GOOD TESTS. 15:00 - 17:30 2.50 RIGD P RUNCMP BLOW DOWN LINES AND DRAIN STACK -R/D MANIFOLD. -M/U STACK FLUSHER AND FLUSH OUT STACK. -FUNCTION RAMS AND BAG,DRAIN STACK. -CLEAR CASING EQUIPMENT FROM RIG FLOOR. • Printed 2/23/2015 12:18:45PM North America-ALASKA-BP Page 20 of 20 Operation Summary Report Common Well Name:5-16 AFE No Event Type:WORKOVER(WO) Start Date:2/1/2015 End Date:2/15/2015 X4-00XL7-E:(3,773,000.00) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:DOYON 16 Spud Date/Time:7/6/1984 12:00:OOAM Rig Release:2/15/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292112300 Active datum:S-16 @67.12usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 21:00 3.50 BOPSUR P RUNCMP OPEN RAM DOORS AND CLEAN RAM BODY. -REMOVE UPPER AND LOWER RAMS,CLEAN AND INSPECT. -GREASE DOORS. 21:00 - 00:00 3.00 BOPSUR P RUNCMP PJSM.N/D 13-5/8"FOUR PREVENTOR BOPE STACK. -SET ON STUMP IN CELLAR. FLUID LOSSES TO WELL PAST(24)HRS=0 BBLS 8.5 PPG SEAWATER. 2/15/2015 00:00 - 00:30 0.50 WHSUR P WHDTRE PTSM.SPCC AND EQUIPMENT CHECKS AROUND THE RIG. CROWN-O-MATIC AND SPCC CHECKS GOOD. 00:30 - 03:30 3.00 WHSUR P WHDTRE PJSM WITH RIG CREWAND CAMERON REPS. NIPPLE UP 11"5M x 4-1/16"ADAPTER FLANGE AND TEST TUBING HANGER VOID AND SEALS. -PREP 9-5/8"x 11"5M SLIP LOCK WELLHEAD. -N/U ADAPTER FLANGE. -R/U TEST EQUIPMENT. -CAMERON REPS,PRESSURE TEST TBG HANGER VOID AND SEALS TO 250 PSI FOR 5 CHARTED MINS AND 5,000 PSI FOR 30 CHARTED MINS.-TEST PASS. 03:30 - 06:00 2.50 WHSUR P WHDTRE PJSM WITH RIG CREW AND CAMERON REPS. NIPPLE UP AND TEST 4-1/16"5M DRY HOLE TREE. -N/U DRY HOLE TREE. -R/U TEST EQUIPMENT. -FILL DRY HOLE TREE WITH DIESEL TREATED WITH 2-CANS OF DIESEL 911 FREEZE PROTECT. -PRESSURE TEST DRY HOLE TREE TO 250/ 5,000 PSI FOR 5 CHARTED MINS EACH.- LEAK TIGHT TEST. -FUNCTION ALL VALVES ON DRY HOLE TREE AND LEAVE IN CLOSED POSITION. -SECURE TREE AND CELLAR. -RDMO. RIG RELEASED AT 06:00 HRS. *TBG AND IA PRESSURE=0 PSI Printed 2/23/2015 12:18:45PM S-16, Well History (Post-Rig Workover) Ill = TWCNac. ND Dryhole Tree Temp#21 . NU 4" Upper Tree. Torqued and PT'd to API specs. (PASSED). Pulled TWC#427 @125" Through tree. PT'd tree cap (PASSED). ND IA PB#95 . Installed blind flange Torqued and PT'd API specs. (PASSED). Installed AFE Signs on Well. Annulus 3/3/2015 is fluid packed. RDMO. Final WHP's VacNac. PULLED B&R FROM RHC-M @ 10206' SLM. PULLED STA#4 RK-DGLV FROM 6428' SLM/ 6445' MD. PULLED STA#5 RKP-DCR SHEAR FROM 3696' SLM /3713' MD. SET STA#5 RK- LGLV & STA#4 RK-OGLV. PULLED 4-1/2" RHC-M PLUG BODY FROM 10,207' SLM / 10,228' 4/10/2015 MD. CTU#9 length=18920 volume=40.4. Job Scope: Mill composite plug and push to bottom. MIRU 4/24/2015 CTU. MU up CTC 1.9" and 3.66 JSN. Weekly BOP test. CTU#9 length=18920 volume=40.4. Job Scope: Mill composite plug and push to bottom. MIRU CTU. MU up CTC 1.9" and 3.66 JSN. Weekly BOP test. MU/RIH w/jars, 3.68" venturi. Displace 4/24/2015 meth from coil. CTU#9 length=18920 volume=40.4. Job Scope: Mill composite plug and push to bottom. MIRU CTU. MU up CTC 1.9" and 3.66 JSN. Weekly BOP test. MU/RIH w/jars, 3.68"venturi. Displace 4/24/2015 meth from coil. CTU#9 length=18920 volume=40.4. Job Scope: Mill composite plug and push to bottom. RIH w/ jars, 3.68" venturi to 10310' (ctm up). Recip on tag 5 times @ 1.5-2.1 bpm. POOH. Recover minor 4/25/2015 cuttings and seal ring in venturi. MU/RIH w/3.72" burn shoe. CTU#9 length=18920 volume=40.4. Job Scope: Mill composite plug and push to bottom. RIH w/ jars, 3.68" venturi to 10310' (ctm up). Recip on tag 5 times @ 1.5-2.1 bpm. POOH. Recover minor cuttings and seal ring in venturi. MU/RIH w/3.72" burn shoe. Tagged CBP 10,315' CTM, Milled and 4/25/2015 pushed to bottom and tagged 10,965' CTM. POH. Nothing recovered in Burn Shoe. RDMO. 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Cl C C O O) UO R T a) ❑ O O- ) 'L), c .Ta) a) 'C 0_ Z H N • N > O r L o CO ` O o > o - E E a) is .0a a - Y a`) 1 N v co o m a O d W O W O O O K a) m L ' a) 0 O ❑ a O LL (n a > co O 2 0 ) o n � � \ _ \ / 2 j { 4 ) / 4aa _ 0a) 0 ) D — z 1.12 / _ / � — / _ CO 0 ) 12 I- in 2 ` / Z - \ — ) z 1 a 0 z g 0.k ƒ / $ f co ) = \ / 0 £ in .E ZD- E - z Z &t £ 3 � ` I _ � & - ® - �co 0. ) } \ 0_ re { \ \ - ti CO ° � � \ o > :1 ai•F— C \ ) , = j .c oe R � _ / § § a a 3 * . 2 0 IL £ •e q k , ) / . = - o 2 E. \ } \ 6 / ) . } \ ) \ o ; _ - » § ( » $ \ 7 $ < § 5 § § \ q ) } 0 y Q x ® 0 f R a = X 7 } ; , _ \ / e E ( 73 a • ) cE 2 0 in (HH \ w � ) ( = a E co § ( Om ) ° I- # z & f .. _ % /30 \ , = e �] » Li (2 U) . 17 \ ) \ E a 3 = \ { 77 34f 0 2I CO . CC / u C ! 2 ( H\ 21 ) 1E ° ƒ/) \ � z 1 n — Co E — - o $ 2 ] z z zca % _ \ \ ? H \ { \ Z ± a z E 27 Lo ) > 0 m U 2 ) ) \ 0 CL \ \ \ \ \ k - > . \ ° 6 Fri \ ) k ~ § -1 U) \ .. - cp. ra \ \ \ / — j 0 Et § » \ : — k | u ` = K ( 0 0 3 0 = \ ~ H \ \ 0 co 5 ] \ 3 a ± TREE ygLl{- CAN S-16 VAD_ SE :NOTES: CHROME TBG ACTUATOR= BAKER C OKB fEV= 67.1' I 7.47 Y. w 1478' -I 9-5/8"FES ES CEMENTER BF.ELEV= 40.10' 1 -1--OP= 3300' 20'CONDUCTOR, ,i 0 1501' H 9-518"ISO ZONE ECP,D=8.720" Max Angle= 54"@ 5700' Datum MD= 10790' —#' I I 2199' —4-1/2"FES X NP,D=3.813" Datum TVD= 8800'SS D= " GAS UFT MANDRELS 9-5/8"CSG,47#,L-80 VAM TOP,ID=8.681" H 1521' ST MD TVI) DEV TYPE VLV LATCH FORT GATE 9-5/8'BOWEN CSG PATCH,D=9.720" 1521'-1522' 5 3713 3697 16 MAG DOME RK 16 04/10/15 13-3/8'CSG,72#,L-80 BUTT,D=12.347' H 2673' 4 6445 5693 47 MvG SO RK " 20 04/10/15 3 7147 6191 43 Mu1G LVW RK r 0 02/13/15 2 8139 6940 40 MMC DMY RK ' 0 02/13/15 Minimum ID = 3.813" @ 2199' 1 9253 7765 46 MdG DMY Fac I r 0 02/13/15 4-1/2" HES X NIPPLE I I 10161' --14-112"t X NP,D=3.813" S 10192' —19-5/8"X 4-1/2"FES TNT PKR,D=3.903" I I 10228' H 4-1/2"FES X NP,D=3.813" 4-1/2'TBG, 126#,13CR-85 VAM TOP, — 10299' 10314' —{9 5/8"X 4-112"UNIQUE OVERSHOT 0152 bpf,D=3.958" -1,,,,,,,,, 10353' --{BKR TBG A NCHOR(�H-22),D=3.875' 4-1/2"TBG STUB(01/31/14) — 10306' Et: 10354' —H9-5/8"X 4-1/2"BKR SB-3 PKR,D=4.750" 10358' —17'MELOUT EXTENSION,D=6.00" -..'"H 10365' —17"X 4-1/2"XO,ID=4.00" I 10389' —14-1/2"PARKER SWS NP,D=3.813" TOP OF 7"LNR— 10436' 4-1/2"TBG, 12.6#,13C R-80 TDS, —1 10459' I - 1044T —{4-1/2'PARKER SIMV NP,D=3.725' .0152 bpf,D=3.958" 9-5/8"CSG,47#,L-80 BUTT,D=8.681" — 10693' \\\ Ni 10459' —I4-112"W/LEG,D=3.958' SUMMARY H ELMO TT LOGGED 04/12/92 RERFORATIONRET LOG:SWS BHCS ON 07/31/84-SWS CBL ON 08/04/84 ' ANGLE AT TOP PERF:41'@ 10704' Note:Refer to Production DB for histoncal pert data Q SIZE SPF INTERVAL Opn/Sgz GATE SQZ 2-7/8" 6 10704-10744 0 12/20/96 , 2/1/8" 4 10708-10750 S 05/14/86 11/29/91 211/8" 4 10882-10887 0 07/15/86 • 10846' --17"MARKER JOWT 2/1/8" 4 10882-10907 0 08/11/90 2/1/8" 4 10887-10907 0 07/04/86 2/1/8" 4 10914-10918 0 07/15/86 2/1/8" 4 10914-10918 0 08/11/90 2/1/8" 4 10926-10964 0 07/15/86 2/1/8" 4 10926-10964 0 08/11/90 10965'CTMD FISH:MLL®GBP(04/25/15) 11047' --I TOP OF SAND 7"LNR,26#,L-80 114S XO TO L-80 BUTT H 11189' }—'5 xC MID — 11257' R4,F , . 7'LNR,26#,L-80 U4S,.0383 bpf,D=6.276" — 11300' •ar' r} DATE REV BY COMMENTS DATE REV BY COMAENTS PRUDHOE BAY UNIT 08/05/84 N-18E INITIAL COMPLETION 03/10/15 JUPJC SQZ PERF CORRECTION WEI L: S-16 04/07/92 0-16 F&4O 03/10/15 JUPJC PILL PX 1 SET CIBP(1/25/14) PERMIT No: 1840840 02/15/15 D-16 MVO 04/20/15 MGS/JMJ GLV C/O(04/10/15) API No: 50-029-21123-00 02/24/15 JMD DRLG HO CORRECTIONS 05/01/15 DBMJMJ MLLE!?C8P/PUSI-ED DH(04/25/15) SEC 35,T12N,T12E,2094'FNL&715'FWL 02/25/15 JB/A3 TBG DEPTH ADJUSTMENTS 02/25/15 JB/JMD MAL ODE APPROVAL BP Exploration(Alaska) a "- N C O U) HiQ ( , f- w Low " °1 `° v N s — V 01 0NZ O Q Q" a, N N Om O s s C \ • + F- T Q_r rowYco o 2 cocc @ Y > o r c O d O oC �° ° < ❑ u a @ o a E m U Y • a.: J Q C CQ) O a+ c N ❑ E 0 L il 0 in 10 in 1A 1A IA IA 1A IA V- O_ C N O_ O C C C C C C C C OU -13 EO T a'QM VI M0 00 ul 00NN NNN 7v v @ 4) CJ 7 0) E -O vi cu OCcQ C:7 cu V V YZ � ❑ ❑ ❑ ❑ CI CI ❑ ❑ ❑ u cocup U ) _ J J J J J J J J N -C UN a U.I Lil K F- LL LL U. LL LL LL U.. U. LL ro Q) r O • _ Q J J J J J J J J J .1..) a) > ''' i f•• Q Q Q Q Q Q Q Q Q 'J C • 0 ❑ ZZZZZZ ZZZ E v "- U Ga LL LL LL LL LL LL LL LL LL L O -0 CQ v U) _ > > C Z O _ < N L OU > Li ? k� Xs N _l y .- y 0 Z >- 00 -. O +M r N U cd p t ailj U J < WO. J 4 O1/4"2y • ❑ 1- gZNW _1 ❑ O N J W U rt' cci $ as vW a ^� z Zi LU W ❑ a Z oct R ocv cG CG CG CG a JOO -� JO OOO E 0 L1.1 w w w w W ILU N Uua'• 2 1 min T di x ) a x li O 4- ` A:.:' .. Q Q Q Q Q Q Q Q Q co O VLu 1 m O wm m m m CO CO m m CO •� LIDN LU Q W W W W W W W W W a p S S 2 2 S S S S 2 v CC -10000 ❑ 0000 'O N t+J n > > > D > > > > Cco R x LL a' w a' re a' a' S a' C Q1 a a a a a a a a a a CO G N N co O �t 'et •7 a \ N kJ ce 0 0 00 0 0 0 0 P 00 E 7 W c) o o 0 0 0 O O O _ cn O N ❑ O S ez IX ❑ ❑ ❑ a0'D C 1.-,- IA O '2 !n '- .- p CO M M a' LL � �co � L. N 01 .....' U ❑ ❑ U U U U U O N 'i v � � :__ 8 c C.C. z) C)in , 2 v > i pp c d1 a� O Q m Q ti o rn o o v 3 •Q. t •• I^. Z' ,- M O M N M Nco N 70 �' w r) In oo z d d N v) « y �! H e r` w O — `° ` n O. Q •- 3i E Z N RI tp n C C CO• w 1n JP ea r -1U OF Tk� • • ,w\�\��/�y�sv THE STATE Alaska Oil and Gas ALl 1 Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue pF gyp. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 'j,11‘3 Fax: 907.276.7542 SOH David Bjork Engineering Team Leader oqk BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S-16 Sundry Number: 313-620 Dear Mr. Bjork: 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, Daniel T. Seamount, Jr. Commissioner DATED this/Z - day of December, 2013. Encl. • STATE OF ALASKA • %xv RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION ,�y APPLICATION FOR SUNDRY APPROVAL NOV 2 6 2013 20 AAC 25.280 (� 1. Type of Request: AOGCC ❑Abandon ❑Plug for Redrill ❑Perforate New Pool ®Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate ®Pull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ®Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑Exploratory ❑Stratigraphic 184-084• 3. Address: 6. API Numbe ®Development ❑Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-21123-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU S-16 • Will planned perforations require a Spacing Exception? ❑Yes ®No 9. Property Designatior 10.Field/Pool(s): ADL 028257 ' Prudhoe Bay/Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10447',11047(Top of Sand) 11300' • 9248' • 11257' 9216' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20"x 30" 110' 110' Surface 2673' 13-3/8" 2673' 2673' 4930 2670 Intermediate 10693' 9-5/8" 10693' 8794' 6870 4760 Production Liner 865' 7" 10435'-11300' 8602'-9248' 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10704'- 10964' 8802'-8998' 4-1/2", 12.6# 13Cr80 10459' Packers and SSSV Type: 9-5/8"Baker SB-3 Permanent Packer Packers and SSSV 10354'/8543' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: ■■ Description Summary of Proposal ®BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic IN Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: January 18,2014 , ` ®Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ❑Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.E.B.Bolen,564-5110 Printed Name: David Bjork Title: Engineering Team Leader Email: J.E.B.Bolen©bp.com Signature: � �� Phone: 564-5683 Date: (I'as/13 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �n L v Sundry Number: _ ❑Plug Integrity BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: aUP /-c$t — °, S / Spacing Exception Required? ❑Yes I/No Subsequent Form Required: //9 4 04_ 111 / APPROVED BY Approved By: COMMISSIONER THE COMMISSI N Date: 1 -( j 24 ( 1 41 Form 10-403 Revised 10/2012 Approv r n v f 1 mont f ate rov Submit In Duplicate 1' hill rLr �z�1)113 �� ' I Ltt�. 3 vim/ 07//, ,ti.1 • p • Sundry Request for casing repair Well: S-16 Date: 11/22/2013 Engineer: J.E.B. Bolen MASP: 2596 psi Well Type: Producer Estimated Start date: January 18, 2014 History: S-16 was originally drilled as a NWFB exploratory well in August 1984 to Ivishak Z4 with TD at 11,300' MD. The well was completed with 9-5/8"casing to 10,693' MD, a 7" liner from 10435' MD- 11,300'MD, and 3-1/2"tubing with 6 GLM's to 10,490'MD. S-16 was first perforated in May 1986 with over 42' MD in the Sag (10708'-10750' MD). In July 1986, 67' MD of lvhishak perforations were added from • 10882'-10907', 10914'-10918', and 10926'-10964' MD. Cement bond logs indicated poor cement across the Sag and Ivishak intervals. S-16 was stimulated multiple times before a tubing leak was identified in 1991. The current tubing string was then run during workover in 1992. Following that it was stimulated and provided with injector support multiple times. In 2002, bubbling was identified in the cellar and a waiver for IAxOA communication was granted The we Wa-§Thien produceron and off until the waiver expired in 2004, . when the wen-was shut-in. On 09/11/11, an MIT-T failed indicating S-16 also has TxIA communication. The tubing hanger, seals, IC pack-offs, and tree will bpIaced during the RWO. Scope of Work: The primary objective of this RWO is to restore well integrity and return the well to . operable status. Pre Rig Prep Work: S 1 Pull PX plug from 10,447', Run SBHPS, Set 4-1/2"composite plug at 10,320' W 2 Check all LDS for movement; PPPOT-T to 5,000 psi and PPPOT-IC to 3,500 psi. F 3 CMIT-TxIA to 3000 psi, MIT-OA to 2000 psi E 4 Power jet cut the 4-1/2" tubing at- 10,306' (between the nipple and packer; 3' from top of first full joint above the packer, leaving a 37' stub). (Reference tubing summary 04/05/1992) F 5 Post jet cut CMIT-TxIA to 1000 psi. Circulate well with seawater and Diesel F/P. ✓ 6 Prep annular valves, Set a BPV. O 7 Remove the well house&flow line. Level the pad as needed for the rig. W 8 Excavate the cellar as needed to get top of spray-in liner below the 13-3/8" starting head. Line the cellar around the wellhead with impermeable, Rhino-lined Herculite. Proposed RWO Procedure: • MIRU Doyon 14. Pull BPV. Circulate KWF. Set TWC. Load OA with KWF. • ND tree. NU and test BOPE with four preventers configured top down (annular, 9-5/8"fixed, blind shears, mud cross and 3-1/2"x 6"VBR's). Test the fixed, blind and VBR's to 3,500 psi and the annular to 3,500-psi. Pull TWC. • Pull 4-W 13-CR tubing from jet cut-10,354' MD. • RU E-line, Run USIT in the 95/8"casing to determine TOC in the 9-5/8"x 13-3/8" annulus. . • Run RTTS to test lower barrier(if CMIT-TxIA fails during the prerig testing). • Set 95/8" RBP-100' below logged TOC. PT RBP to 3,000 psi. • Dump 50' of sand on top of RBP • Mechanically cut 95/8"casing in 1st full joint above the TOC. • Pull 9-5/8"casing to surface. • Scrape 133/8" and dress-off 95/8"casing stub • Split the BOP stack and cut off 133/8" starting head ', • Run 95/8" tie-back fully cemented to surface with bbls of 15.8 ppg latex class G cement . • • • Install 9-5/8"x 133/8" hanger and 9-5/8" sliplock wellhead. Nipple up and test BOP equipment. • • Drill out the 95/8" shoe track and test casing to 3,000 psi. • Recover the RBP. • Run a scraper, dress stub and drill out composite bridge plug. • Run new 4.5" 12.6# 13Cr completion with 95/8"x 4-%" HES"TNT" packer. MIT-T& MIT-IA to 3000 psi. • Set a BPV and RDMO. Post rig Work ✓ 1 Pull BPV S 2 Pull ball and Rod, Pull RHC seat, Install dummy GLV's TREE 4"CM/ WELLHEAD 13 3/8"McEVOY • S OTES:CHROME TBG***IA X OA COMM. S-1 6 *** ACTUATOR= BAKER KB. ELEV= 67.12' BF. ELEV= 40.10' KOP= 3300' 2087' H4-1/2"OTIS HXO SSSV NIP,ID=3.813" Max Angle= 54 @ 5700' Q Datum MD= 10790' Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3082 8020 5 CAMCO RK 13-3/8"CSG,72#, L-80,ID=12.347" H 2673' I 4 5313 4917 50 CAMCO RK . 4 3 8212 6928 40 CAMCO RK N' 1i( k0 G 2 10088 8290 45 CAMCO RK f" Jh /SCj 1 10235 8393 44 CAMCO RK • Minimum ID = 3.725" @ 10447' I _ 10292' H4-1/2"PARKER SWS NIP, ID=3.813" I 4-1/2" PARKER SWN NIPPLE 0, �� 10353' H BAKER TBG ANCHOR(EBH-22) I ►m 6 10354' H 9-5/8"BAKER SB-3 PKR, ID=4.750" PV1 N \ I 10389' 1-14-1/2"PARKER SWS NIP, ID=3.813" I 18 10447' H4-1/2"PARKER SWN NIP,ID=3.725" I 10447' 1-14-1/2"PXN PLUG(07/14/06) I 14-1/2"TBG, 12.6#,13-CR, .0152 bpf, ID=3.958" I—I 10459' I / 10459' H4-1/2"W/LEG I 10461' -1 ELMD TT LOGGED 04/12/92 I TOP OF 7"LNR-I 10435' 9-5/8"CSG,47#,L-80, ID=8.681" H 10693' I ' PERFORATION SUMMARY 10847' I-1MARKERJOINT I REF LOG:SWS BHCS ON 07/31/84-SWS CBL ON 08/04/84 ANGLE AT TOP PERF:41 @ 10704' I Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE ' 2-7/8" 6 10704- 10744 C 12/20/96 j 2/1/8" 4 10744- 10750 S 10/29/91 ' 2/1/8" 4 10882- 10907 C 08/10/90 2/1/8" 4 10914- 10918 C 08/10/90 11047' I-1TOPOF SAND I 2/1/8" 4 10926- 10964 C 08/10/90 ' PBTD --I 11257' I ,,,A,A,A,A,Avv 7"LNR,26#,L-80 IJ4S, .0383 bpf, ID=6.276" IH 11300' WAWA.. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/05/84 ORIGINAL COMPLETION WELL: S-16 04/07/92 HF LAST WORK OVER PERMIT No:'1840840 12/20/04 RDJ/PAG WAIVER SAFETY NOTE REV API No: 50-029-21123-00 07/14/06 TEL/PJC SET PXN PLUG SEC 35,T12N,T12E,2094'SNL&714'EWL BP Exploration(Alaska) TREE= , 4"cfW • WELLHEAD= 3-3/8"McEVOY SA NOTES:CHROME TBG***IA X OA COMM. ACTUATOR= BAKER S-16 *** KB.ELEV= 67.12' BF.ELEV= 40.10' KOP= 3300' Max Angle= 54 @ 5700' 2087' �4 1/2"OTIS HXO SSSV NP,D=3.813" Datum MD= 10790' Datum ND= 8800'SS GAS MANDRELS ST MD TVD DEV TYPE LIFT MAVLV LATCH FORT DATE 5 3082 8020 5 CAMCO RK 4 5313 4917 50 CAMCO RK 13-3/8"CSG,72#,L-80,ID=12.347" H 2673' 3 8212 6928 40 CAMCO RK 2 10088 8290 45 CAMCO RK 1 10235 8393 44 CAMCO RK Minimum ID = 3.725" @ 10447' 4-1/2" PARKER SWN NIPPLE 10292' —14-1/2"PARKER SWS NIP,D=3.813° 10353' H BAKER TBG ANCHOR(EBH-22) Jet cut at 10,306' OM 6 10354' —{9-5/8"BAKER SB-3 PKR,ID=4.750" 1 10389' H4-1/2"PARKER SWS NIP,ID=3.813" 4-1/2" Composite plug 10447' —14-1/2"PARKER SWN NP,ID=3.725" 4-1/2"TBG,12.6#,13-CR,.0152 bpf,D=3.958" —I 10459' 10459' �4-1/2"W/LEG 1 i I TOP OF 7"LNR—i 10435' 10461' H ELMD TT LOGGED 04/12/92 IIII 9-5/8"CSG,47#,L-80,ID=8.681" —1 10693' ' PERFORATION SUMMARY REF LOG:SWS BHCS ON 07/31/84-SWS CBL ON 08/04/84 10847' —I MARKER JOINT ANGLE AT TOP PERF:41 @ 10704' ' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10704-10744 12/20/96 ' 2/1/8" 4 10744-10750 S 10/29/91 2/1/8" 4 10882-10907 C 08/10/90 ' 2/1/8" 4 10914-10918 C 08/10/90 2/1/8" 4 10926-10964 C 08/10/90 11047' H TOP OF SAND I PBTD —I 11257' •vvvvvv •,■ 7"LNR,26#,L-80 U4S, .0383 bpf,ID=6.276" —I 11300' 1.1.W.I.M'1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/05/84 ORIGINAL COMPLETION WELL: S-16 04/07/92 HF LAST WORK OVER PERMIT No:'1840840 12/20/04 RDJ/PAG WAIVER SAFETY NOTE REV API No: 50-029-21123-00 07/14/06 TEL/PJC SET PXN PLUG SEC 35,T12N,T12E,2094'SNL&714'EWL BP Exploration(Alaska) TREE= 4"CIW • WLHEAD= 3-3/8"McEVOY s-I 6� SA NOTES:CHROME TBG***IA X OA COMM. ACTUATOR= BAKER *** KB.ELEV= 67.12' New 9-5/8" Slip Proposed RWO BF.ELEV= 40.10' Lock Wellhead , KOP= 3300' Max Angle= 54 @ 5700' 9-5/8" 47# L-80 H563 I 2100' H4-1/2"X NIP,ID=3.81-:' Datum MD= 10790' Datum TVD= 8800'SS Cemented to surface GAS LIFT MANDRELS =I ST MD ND DEV TYPE VLV LATCH PORT DATE TOC - ???? 5 4 13-3/8"CSG,72#,L-80,D=12.347" H 2673' I 3 2 1 I H4-1/2"X NIP,ID=3.813" 9-5/8" x 4-1/2" HES TNT Chrome Packer 4-1/2", 12.6# 13CR-85, VAMTop - I 14-1/2"X NIP,ID=3.813" r/ 10353' —I BAKER TBG ANCHOR(EBH-22) 6 Unique Overshot / 10354' H9-5/8"BAKER SB-3 PKR,D=4.750" I I 10389' H4-1/2"PARKER SWS NIP,ID=3.813" Minimum ID = 3.725" @ 10447' 4-1/2" PARKER SWN NIPPLE I I 10447' H4-1/2"PARKER SWNNIP,ID=3.725" 4-1/2"TBG,12.6#,13-CR,.0152 bpf,D=3.958" —I 10459' / l 10459' —I4-1/2"W/LEG TOP OF 7"LNR 10435' 10461' --I E LIvD TT LOGGED 04/12/92 III 9-5/8"CSG,47#,L-80,ID=8.681" H 10693' ' PERFORATION SUMMA RY REF LOG:SWS BHCS ON 07/31/84-SWS CBL ON 08/04/84 10847' H MARKER JOINT ANGLE AT TOP PERF:41 @ 10704' ' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 10704-10744 12/20/96 ' 2/1/8" 4 10744-10750 S 10/29/91 2/1/8" 4 10882-10907 08/10/90 ' 2/1/8" 4 10914-10918 08/10/90 2/1/8" 4 10926-10964 08/10/90 11047' —I TOP OF SAND I PBTD H 11257' ATAT•vAve 7"LNR,26#,L-80 U4S,.0383 bpf,ID=6.276" H 11300' LOAAAAAA. DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/05/84 ORIGINAL COMPLETION WE-L: S-16 04/07/92 HF LAST WORK OVER PERMIT No:•1840840 12/20/04 RDJ/PAG WAIVER SAFETY NOTE REV API No: 50-029-21123-00 07/14/06 TBJPJC SET PXN PLUG SEC 35,T12N,T12E,2094'SNL&714'EWL BP Exploration(Alaska) .. . • • CAMERON v 1 [a 4-1/8 API 5000 Tree Assembly With Actuated Valve in Upper Master Position ': \ - - ma- Q � �� 7 11 =1! / /r� t a? ' _fir 7J �m Tubing Hanger Type SA-SRL 11" Bowl,4-1/2" 12.6 lb. TC-II Tubing Head Adapter ' /,, Top &�Btm. 4" Type "H" BPV. 11" 5K Bottom x 4-1/16" API 5K Top, Two Two /< NPT CCL Preps. and CCL preps. PN 2247222-05-01 011 W etal Seal Neck -M PN 2031940-15-01 Slip Lock Casing Head Type S-3. 9-5/8 Slip Lock BTM x 11" API 5K FLG To �' ° i c �� - !c �\G With (2) 2-1/16 API 5K Manual ; i g�?19 � ��, ( d00 ,) I' Gate Valves, Companion Flanges and L _ ° H'' /'/ . % K-- 0 ; ,� Bull Plugs Min Bore 8.88 V , _ �l�;;' PN 2263050-10-21 1, 1 -_i 9-5/8 Casing 4-1/2 Tubing s . • • 4 g o' ; x N ¢ O N - Z ma Sp w pig p�rc. O R¢1 w Q J O � Z d Z Q 6G Q m Y U m m Q > N rn N 0 h g o a i cc .. �� w.1 �•� a g i 11111 0 O33333 it MD- 0 �x� 1111 ft _, N N i E 4* CI - O N�Z N [7 In J 1� 1 I I -O \ O © Z N 7 =N d ` J \ Y Ce el: O ¢m d /k G� y ■= gad 6-_ W c/ = d - U—1x Z Q H Q u 1 1 it $ e $ $ 6 _ s8 III 1 i 'A 1 I 1 z 1 — Ill II� I Z Q .. iI 0 Y 0 - r0 MI o illi III / 4IlI1®1111111 S P e! 8 ° a ! = i m w * * •Ir___ w • m cn w R. S �ii II OHIO-- i K t::. \..., t:.1 V t: u . STATE OF ALASKA . SEP 2 7 2006 ALASKA OIL AND GAS CONSERVATION CO~~~U>~Gas Cons. Commission REPORT OF SUNDRY WELL OPERATI.GNr&e 1. Operations Perfonned: Stimulate 0 OtherOOSecure Wen AbandonD Repair Well 0 Plu: PerforationsO Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD 184-0840 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-21123-00-00 7. KB Elevation (ft): 9. Well Name and Number: 67.12 5-16 8. Property Designation: 10. Field/Pool(s): ADL-028257 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11300 feet true vertical 9248.0 feet Plugs (measured) Secured Wen -- 4-1/2" TIP @ 8193' (07/14/2006) Effective Depth measured 11047 feet Junk (measured) true vertical 9060.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 30 - 110 30.0 - 110.0 1490 470 SURFACE 2644 13-3/8" 72# L-80 29 - 2673 29.0 - 2673.0 4930 2670 PRODUCTION 10665 9-5/8" 47# L-80 28 - 10693 28.0 - 8794.0 6870 4760 LINER 731 7" 26# L-80 10435 - 11300 8602.0 - 9248.0 7240 5410 Perforation depth: Measured depth: 10704-10744,10882-10907,10914-10918,10926-10964 , 'J ...:(; !!iM .)~133) \ True vertical depth: 8802-8833, 8936-8955, 8960-8963, 8969-8998 ç~' ~'-.;;.t \.'l. '\0< ' ...~ Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 27 - 10459 Packers & SSSV (type & measured depth): 9-5/8" Baker SB-3 Packer @ 10354 4-1/2" Otis HXO SSSV Nipple @ 2087 ...~ ... ,~u 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RBDMS 8Ft 0 C1 () 3 2006 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casin: Pressure Tubina Pressure Prior to well operation: SI 0 0 -- --- Subsequent to operation: SI 0 0 --- --- 14. Attachments: 15. Well Class after proposed work: ExploratoryD Development[! ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ! OilŒ] GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature Phone 564-5174 Date 9/26/06 Form 10-404 Revised 4/2004 AL OR\G\N . . 5-16 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/18/2006 TIIIO = 350/475/0+. SI. Bleed WHPs < 500 psi (for Secure). Replaced bad 3000 # gauge on IA gate valve. AL line blinded. 08/08/2006 TIII0=300/46010+. Temp=SI. WHPs (post bleed to secure). TBGP decreased 80 psi, lAP decreased 10 psi over night. No change in OAP. Note: AL line is connected and has blind installed. Cellar Liner has a 2' tear in it at the 12 o'clock position. 08/01/2006 T/I/0=380/47010+. Temp=SI. WHP's post bleed. (for Secure). TP decreased 10 psi overnight. lAP increased 10 psi overnight. No change in OAP overnight. AL line pressure @ 710 psi. 07/31/2006 TIIIO = 390/46010+. Temp = SI. WHPs (post bleed for secure). Tubing pressure increased 100 psi overnight. No change in lAP or OAP. 07/30/2006 T/I/0=980/1300/10. Temp=SI. Bleed WHP's < 500 psi, assist CAM. (For Secure). IA FL @ 5313' sta#4 (285 bbl). Bled TP from 980 psi to 370 psi to Prod in 1 hour 20 minutes. lAP decreased 180 psi to 1120 psi during TP bleed. Bled lAP from 1120 psi to 460 psi in 1 hour 20 minutes. IA FL dropped 1058' during lAP bleed to 6371' between sta#4 & sta#3 (341 bbl). TP decreased 80 psi to 290 psi during lAP bleed. OAP decreased 10 psi to 0+ during Bleeds. Final WHP's=290/46010+ 07/30/2006 TIIAlOA = 980/1300/10 (Evalleak on Tubing Head Adapter) PPPOT-T = PASSED Bled void to +0 psi.Torqued Lockdowns to 550 ftllbs. Upper packing port bled to 0 psi. By Energizing lower packing port elastomer neck seals with (3 1/2) sticks of packing, able to bleed tubing hanger void to 0 psi. Packing stopped communication from control line. Rigged up test equipment, pressured up void to 5,000 psi. for 30 mins. - Passed No external leaks on ring gasket flanges or lockdownlgland assemblies. 07/14/2006 ** WELL SHUT IN UPON ARRIVAL** {secure well} DRIFTED TBG WI 3.70" CENT,T.E.L, PETRADAT GAUGES TAGGED BTM @ 10970' CORRECTED. PERFORMED SBHP AS PER PROCEDURE. MADE STOPS @ 8600', 8700' & 8800' TVD SS. PRESSURE AT 8800' TVD SS 110790 MD = 3479 PSI 1221 DEG F. BRUSHED TBG TO 10438' SLM. SET 41/2" PXN PLUG BODY @ 10438' SLM. SET PRONG (1 3/4"-FN, 1.75"- BODY 00,96"- OAL) @ 10435' SLM, TIIIO 1700/1825/0- WHEN SET. BLED TO T/I/O- 675/145010, WATCH FOR 15 MIN, GOOD TEST. ** TURNED WELL OVER TO PAD OP, LEFT SHUT IN** 06/06/2006 TIO = 15901161010. Temp = SI. MITOA-FAILED to 500 psi wI N2 (monitor leak off). OA FL @ 66'. Stacked OAP to 40 psi wI N2. OAP decreased 20 psi in 10 mins, three times. Stacked OAP to 40 psi. Monitored 30 mins. After 15 mins OAP decreased 30 psi. After 27 mins OAP decreased to 0 psi. FWHP's = 1590/161010. FLUIDS PUMPED BBLS I 1 PT Surface Equipment 1 TOTAL Page 1 , TREE = 4" CrN WELLHEAD = 13-3/8" McEVOY 5-16 5 OTES: CHROME TBG ***IA X OA COMM. . *** ACTUATOR = BAKER KB. ELEV = 67.12' BF. ELEV = 40.10' KOP= 3300' 2087' 1-14-1/2" OTIS HXO SSSV NIP, ID = 3.813" I Max Angle = 54 @ 5700' . Datum MD = 10790' Datum ìVD = 8800' SS GAS LIFT MANDRELS ST MD ìVD DEV TYÆ VLV LATCH PORT DATE 1~ 5 3082 8020 5 CAMCO RK 113-3/8" CSG, 72#, L-80, 10 = 12.347" H 2673' ~ 4 5313 4917 50 CAMCO RK L 3 8212 6928 40 CAMCO RK 2 10088 8290 45 CAMCO RK 1 10235 8393 44 CAMCO RK Minimum ID = 3.725" @ 10447' . . I 10292' H4-1/2" PARKER SWS NP, ID - 3.813" I 4-1/2" PARKER SWN NIPPLE ~ 10353' -1 BAKER TBG ANCHOR (EBH-22) I :8: ~ 10354' -19-5/8" BAKER SB-3 A<R, ID = 4.750" I 1"'--0' I I I 10389' -14-1/2" PARKERSWS NP, ID= 3.813" I .181· I 10447' 1-14-1/2" PARKER SWN NP, 10 - 3.725" I -.. r- r--r 10447' 1-14-1/2" PXN A..UG (07/14/06) I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpt, 10 = 3.958" I 10459' I 10459' -14-1/2" W/lEG I ITOPOF 7" LNRI I I 10461' H ELMD TT lOGGED 04/12/92 I 10435' ~ . 19-5/8" CSG, 47#, l-80, ID = 8.681" I 10693' ~ )~ II ÆRFORA TION SUMMARY I 10847' 1-1 MARKER JOINT 1 REF lOG: SWS BHCS ON 07/31/84-SWS CBl ON 08/04/84 ] ANGLE AT TOP ÆRF:41 @ 10704' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERV Al Opn/Sqz DATE 1 2-7/8" 6 10704 - 10744 C 12/20/96 2/1/8" 4 10744 - 10750 S 10/29/91 ] 2/1/8" 4 10882 - 10907 C 08/10/90 2/1/8" 4 10914 - 10918 C 08/10/90 11047' -I TOP OF SAND I 2/1/8" 4 10926 - 10964 C 08/10/90 I PBTD H 11257' 1-- 17" lNR, 26#, l-80 U4S, .0383 bpf, ID = 6.276" I 11300' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 08/05/84 ORIGINAL COM PLETION WELL: S-16 04/07/92 HF LAST WORK OVER ÆRMrr No: "1840840 12/20/04 RDJ/PAG WAr-/ER SAFETY NOTE REV API No: 50-029-21123-00 07/14/06 TELlPJC SET PXN A..UG SEC 35, T12N, T12E, 2094' SNl & 714' EWL BP Exploration (Alaska) LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 3 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~..r ..... '"7 F-21 (12-35-12-13) , ~ DESCRIPTION 1 PLS/STP FINAL EL+RF Run ~ 1 1 PLS/STP FINAL BL+RF Run # 1 1 PDK FINAL BL+RF Run # 1 1 PFC/PERF FINAL BL+RF Run # 1 1 PFC/PERF FINAL BL+RF Run # I ECC No. 522.08 2011.01 5646.01 5718.08 5811.06 Please sign and return to: Attn. R0dn~ Su~ Received Suite 201 Anchorage, AK 99518 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 3 August 1995 RE: Transmittal of Data ECC #: 5646.01 Sent by: ANCH.EXPRESS Data: PDK Dear Sir/Madam, Reference: BP S-16 PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: LDWG TAPE + LIS Run # 1 Tapes/Diskettes: 1 Please sign and return to: Attn.~odney D. paulson ~uite 201 ~ Anchorage, AK 9~ or to (907 6 Received by: _j~.~ /~.-/-~.~ ~aDate: ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 November 1, 1994 Jerry Bixby/Steve Farris Wireline/Completion Supervisors BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification, seven wells BPX PBU -- five on $ Pad & two on U Pad Dear Mr. Bixby/Farris: Our inspector Lou Grimaldi witnessed no-flow tests on and recommended no-flow status for the seven BPX PBU wells listed below. The wells were open t© an atmospheric tank to determine fluid production (there was none), and monitored through a gas meter to determine gas production rates. The inspector recommended "no-flow" status for the wells listed below. Well No. PTD No. Test Date Fld Rate Gas Rate '$-13 82-135 0/26/94 dead 135 scf/h ~ 10/26/94 dead 0 scf/h ~-20 86-I~7 10/26/94 dead 240 scf/h U-6 84-078 10/26/94 dead 360 scf/hr U-8 84-102 10/26/94 dead 300 scf/hr The above wells meet the criteria of a "no-flow" performance test, and as such are considered incapable of flow to the surface. Under the authority of Conservation Order 145, Rule 5 (amended by CO 333), these wells are not required to have a fail safe automatic SSSV. However, the surface safety valve and pilot must be maintained in good working condition, and if for any reason the wells again become capable of unassisted flow of hydrocarbons, the subsurface safety valves must be reinstalled and maintained in good working condition. Sincerely, Blair E. Wondzel~' PI Supervisor c: Lou Grimaldi bew/n 17 bpws MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: David Johns~/ DATE: Chairma~.~.,>~ Blair Wondzell, ~ FILE NO: P. I. Supervisor ~ Lou Grimaldi~ SUBJECT: Petroleum In§pector October 27, 1994 919JJZBD.DOC No flows BPX wells S pad Prudhoe Bay Field Wednesday. October 26, 1994: I verified the No flow status of 5 wells on BPX S pad in the Prudhoe Bay Field with the following results; Well Name ~-13~ S-16 S-2__._~0 S-26 S-28 Permit # 82-135 84-84 86-147 90-58 0.il produced NONE NONE NONE NONE NONE Gas.produced 135 SCF NONE 240 SCF 120 SCF NONE These wells were observed in this state for 4 hours each, the wells SSSV's were removed for these tests. I recommend No flow status be granted these wells. SUMMARY: I verified the No flow status of 5 wells on BPX S pad in the Prudhoe Bay Field. Attachments: None ' · ' . STATE OF ALASKA AL._ LA OIL AND GAS CONSERVATION COMMIS, ? ~. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate. Plugging e~e~orate ~_~~' Pull tubing .. Alter casing Repair well . Oth 5. Type of Well: 6. Datum elevation (DF or KB)~/~ KBE = 67.12 AMSL ~feet 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2094' SNL, 714' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, SEC. 26, T12N, R12E, UPM At effective depth 2380' SNL, 1441' EWL, SEC. 26, T12N, R12E, UPM At total depth 2212'SNL, 1480' EWL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: measured 11300 feet true vertical BKB 9248 feet Development 3( Exploratory Stratigraphic 7. Unit or Property name Servk:e Prudhoe Bay Unit 8. Well number S-16 (12-26-12-12) PBU 9. Permit number/approval number 84-84 / 10. APl number 50- 029-21123 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 11041' feet true vertical BKB 9056 feet Junk (measured) fill at 11041'MD (07/90) Casing Length Structural -- Conductor 110 Surface 2646 Intermediate 10666 Production -- Liner 864 Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth BKB 137 137 2673 2673 10693 8794 20x30 8 c.y. 13 3/8 3812 c.f. 9 5/8 2769 c.f. 7 312 c.f. 10436-11300 10708'- 10750' (Sag R.) 10882'-10907', 10914'-10918', 10926'-10964' (Ivishak) subsea 8738'- 8770' (Sag R.) 8868'-8930' (three Ivishak intervals) 3 1/2" L-80 EUE to 10381' with 2 7/8"tailpipe to 10489' 8602-9248 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10381'; 3 1/2" SSSV at 1975' K L IV. H S E P 1 7 1993 Alaska OJJ & Gas Cons. Representative Daily Average Production or Injection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation S/I S/I S/I S/I S/I Subsequent to operation 670 1667 4019 2120 278 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations Oil X.. Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed - . r:l~.'~,3 Title Senior TechnicalAssistant I Form 10-404 ~ev 06/15/88 7 Service Date SUBMIT IN DO'f:::~LI~;ATE 4/19/92 WELL S-16(12-26-12-12) FRAC Performed a FRAC (IVISHAK) Treatment using the following fluids: FLUIDS PUMPED DOWNHOLE FRAC: 10 BBLS 50# GEL PREPAD TO ESTABLISH RATE 127 BBLS 50# X-LINK GEL PAD W/9% ESL(520 GAL) 41 Dirty 1 PPG 8 2 PPG 13 3 PPG 18 4 PPG 21 5 PPG 25 6 PPG 28 7 PPG 30 8 PPG 32 9 PPG 283 10 PPG 167 20# LINEAR GEL FLUSH fjh 6/26/93 Alaska Oil & Gas rjons.,,.,,,,. ,.,. ~,",'~ ,:.l.,,s,,,,-' ~' '~ Anchorage A~. ~,{A OIL AND GAS CONSERVATION COMMIL REPORT OF SUNDRY WELL OPERATI stimulate X Plugging Alter casing Repair well 5. Type of Well: Development Exploratory Stratlgraphic Service 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2094' SNL, 714' EWL, SEC, 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, SEC. 26, T12N, R12E, UPM At effective depth 2380'SNL, 1441' EWL, SEC. 26, T12N, R12E, UPM At total depth 2212' SNL, 1480' EWL, SEC. 26, T12N, R12E, UPM 12. Present well cOndition summary Total depth: measured 11300feet true vertical BKB 9248feet Perforate ' ' /-~ / Other 6. Datum elevation (DF or KB) KBE - 67.12 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-16 (12-26-12-12) PBU 9. Permit number/approval number 84-84/ 10.APl number 50- 029-21123 11.Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 11041'feet true vertical BKB 9056feet Junk (measured) fill at 11041'MD (07/90) Casing Length Structural -- Conductor 110 Surface 2646 Intermediate 10666 Production -- Liner 864 Perforation depth: measured true vertical Size Cemented Measured depth 137 2673 10693 20x30 8 c.y. 13 3/8 3812 c.f. 9 5/8 2769 c.f. 7 312 c.f. 10436-11300 10708'- 10750' (Sag R.) 10882;10907', 10914;10918', 10926;10964'(Ivishak) subsea 8738'- 8770' (Sag R.) 8868'-8930' (three Ivishak intervals) Tubing (size, grade, and measured depth) 3 1/2' L-80 EUE to 10381' with 2 7/8" tailpipe to 10489' True vertical depth BKB 137 2673 8794 8602-9248 Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 95/~"BOTpackerat ,0381'; 31/2" $SSVat 1975' R E ([ E IV £ D DEC 1 4 1992 Alaska Oil & Gas Cons. comm[ssiOr~ Anchorage 14. Represente, tiye Daily Average Production or In!ection Data Prior to well operation Subsequent to operation S/I S/I 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 17. I hereby c~rtify that the foregoi.0g is true and Correct to the best of my knowledge. Si~lnod (~./'[~~.~ ~-/ ~/~ TitloSeniorTechnicalAssistan, l Form 10-404 Rev 06/15/88 OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Note: Well wao Shut In S/I S/i S/I S/I S/I S/I S/! S/I 16. Status of well classification as: Oil X Gas Suspended Service Date SUBMIT IN DU~LIC'ATE WELL S-16¢12-26-12-12~ Ngn-Ri~WorkOver 10/30/9 1 A NRWO was performed using the following fluids below: 295 bbls PW to Load Well 9 bbls MEOH 5 bbls PW 13 bbls ACID 150 bbls PW 5 bbls EW(Preflush) 8 bbls Cement 24 bbls EW(Spacer) 12 bbls Duo Polymer(Contaminant) 34 bbls PW(Displacement) 362 bbls PW(Reverse Out) 89 bbls PW(Jet Pass) 80 bbls PW(Final Reverse Out) 77 bbls PW(Displacement) 33 bbls MEOH(Freeze Protection CT) 24 bbls MEOH(Freeze Protection Well) Well Cleaned Out to 10748' 173 bbls load fluid behind pipe 8 bbls Cement Recovered(Does not include cement not pumped) ACID: 15% EDTA, .4% NE-41, .4% CI-25, .7% S-500, 25 PPB CI-25 CEMENT:15.8 ppg class g cement containing, .78% FL-32, .1% CD-31, .2% R-Il, 1.0GAL PER SK FP-6L SQZ #1 10/07/92 fjh Al~k~ Oil & I~ Oons. I~om~°r~ Anohorage ORI /~'"~ STATE OF ALASKA AL....~A OIL AND GAS CONSERVATION COMMIS,~ REPORT OF SUNDRY WELL OPERATIONS §INAL¥ 1. Operations performed: Operation shutdown Stimulate 34 Plugging Pull tubing Alter casing Repair well Perforate Other .. 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2094' SNL, 714' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, SEC. 26, T12N, R12E, UPM At effective depth 2380' SNL, 1441' EWL, SEC. 26, T12N, R12E, UPM At total depth 2212' SNL, 1480' EWL, SEC. 26, T12N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11300feet BKB 9248feet 11041'feet BKB 9056feet 5. Type of Well: Development Exploratory SEat]graphic Service 6. Datum elevation (DF or KB) KBE = 67.12 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-16 (12-26-12-12) PBU 9. Permit number/approval number 84.84/90-487 10. APl number 50- 029-21123 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Junk (measured) fill at 11041'MD (07/90) Casing Length Size Cemented Measured depth True vertical depth Structural -- BKB Conductor 110 20x30 8 c.y, 137 137 Surface 2646 13 3/8 3812 c,f. 2673 2673 Intermediate 10666 9 5/8 2769 c.f. 10693 8794 __ Production -- Liner 864 7 312 c.f. 10436-11300 8602-9248 Perforation depth: measured 10708'- 10750' (Sag R,) 10882'-10907; 10914'-10918; 10926'-10964'(Ivishak) true vertical subsea Tubing (size, grade, and measured depth) 8868'-8930' (three Ivishak intervals) 3 1/2" L-80 EUE to 10381'with 2 7/8"tailpipe to 10489' Packers and SSSV (type and measured depth) 9 5/8" BOTPacker at 10381~ 3 1/2" SSSV at 1975' - 13. Stimulation or cement squeeze summary see attachment 14. Intervals treated (measured) Treatment description including volumes used and final pressure JUN 1 1992 Alaska 0il & Gas Cons. C0mmissio~, Prior to well operation Subsequent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 22O 385 5O 977 2500// 628 2600 1338 Tubing Pressure 236 28O 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~ Title Supervisor WaterfloodlMiscible Flood Form 10-404 Rev 06/15/88 {~ Date ( lrl z SUBMIT IN DUPLICATE WELL S-16 ¢12-26-12-12} PBU REPERF/IVISHAK FRAC OPERATIONS 8/4/9O 8/1 1/90 8/12/90 11/11/90 Performed pre-frac tubing wash with 24 bbls. 15% HCI. Rigged up Schlumberger and reperforated the following intervals using 2 1/8" carrier guns at 4 spf. 10882'- 10907' MD BKB 10914'- 10918' MD BKB 10926'- 10964' MD BKB Returned well to production and tested. Performed hydraulic fracture of the Ivishak interval. Cleaned out well and returned well to production and tested. Performed post-frac scale inhibition treatment. Returned well to production and tested. fjh .5/13/92 RECEIVED JUN 1 5 199?- Alaska 0il & Gas Cons. commisSiOn' Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 05/11/92 T# 83499 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. · s-16 ~¢-~¢ COL x-23~-~ / [NJ -23 GAS ·LIFT SURVEY 04/05/92 Y-28 ~/-~ LEAK DET 04/26/92 5 " 04/14/92 #1 04/23/92 #1 04/12/92 #1 04/15/92 #1 04/24/92 #1 04/05/92 #2 Information Control Well Records Adrian J. Martin 9600.00- 9950.00 CAMCO 5 " 10050.00-10678.00 CAMCO 5 " 10180.00-11085.00 CAMCO 5 " 0.00-14410.00 CAMCO 2/5" 11300.00-11660.00 CAMCO 5 " 10900.00-11170.00 CAMCO 5 " 17.00-10090.00 CAMCO 2 " 2900.00- 8950.00 CAMCO 2/5" 04/19/92 #1 9400.00- 9807.00 CAMCO E£EIVED MAY 1 8 1997. Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/22/92 T# 83436 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. 04/18/92 #1 04/19/92 #1 04/18/92 #1 04/19/92 #1 04/19/92 #1 11490.00-11708.00 ATLAS 5 " 9700.00-10552.00 ATLAS 5 " 11695.00-12295.00 SCH 5 " 10650.00-10922.00 SCH " 10385.00-11212.00 SCH 5 " InfOrmation Control Well Records Adrian J. Martin . RECEIVED MAY 1 4 199,?. Alaska 011 & Gas Cons. Commission Anchorage ~= STATE OF ALASKA D ALAbr,,A OIL AND GAS CONSERVATION COMMISSluN U [~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging . Pull tubing ~[ Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2094' SNL, 714' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, SEC. 26, T12N, R12E. UPM At effective depth 2340' SNL, 1448' EWL, SEC. 26, T12N, R12E, UPM At total depth 2212' SNL, 1480' EWL, SEC. 26, T12N, R12E, UPM 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 67.12 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-16 (12-26-12-12) 9. Permit number/approval number 84-84/Conservation order 258 10. APl number 50- 029-21123 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11300 feet BKB 9248 feet 11102 feet BKB 9101 feet Plugs (measured) Junk (measured) Fill tagged @ 11102'MD (4/4/92) Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Size Cemented Measured depth True vertical depth 4-1/2" 12.6#, 13CR TDS tubing to 10459'MD RECEIVED MAY 1 1 1992 Alaska 0il & Gas Cons. ~mmisS%0~ Ar~horage Packers and SSSV (type and measured depth) 9-5/8" Baker 'SB-3' Permanent Packer @ 10354'MD, 4-1/2" Otis 'HXO" SSS V @ 2087'MD 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Re.Dresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations x Oil x Gas Suspended 17. I hereby~certify that the foregoing is true and correct to the best of my knowledge. Sicjned//u//[/r~'~~_~_~' ~ ~ Title WorkoverEn~ineer Supervisor Form 10-404 Rev 06/15/88 Service Date SUBMIT IN DUPLICATE ACTIVITY SUMMARY for WELL FROJECT 145110 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : S-16 Page: 1 DRLG RIG : NONE WO/COMP RIG: DOYON 16 (COMP) KILL: 2.0 04/01/92 (1) TD:ll300 PB:11257 SUPV:NJS NU ND: 5.5 OTHER: 11.0 PL TBG: 5.5 POH W/ 3-1/2" TBG MW: 8.5 Seawater MOVE RIG TO S PAD, PULL BPV, ND TREE, NU BOPE, TEST SAME, PULL TBG FREE, PULL TBG HGR TO FLOOR, CBU, POH W/ 3-1/2" TBG & LAY DOWN. (145110) DAILY: $ 64,528 CUM: $ 64,528 EFC: $ 782,000 (COMP) PL TBG: 24.0 04/02/92 (2) TD:ll300 PB:11257 SUPV:NJS RIH W/ OVERSHOT. POOH, LD/ TBG. RIH W/ OVERSHOT. (145110) DAILY: $ 64,978 CUM: $ MW: 8.5 Seawater 129,506 EFC: $ 782,000 04/03/92 TD:ll300 PB:11257 SUPV:NJS (COMP) PL PKR: 18.0 PL TBG: 6.0 ( 3) LD PKR & TAILPIPE MW: 8.5 Seawater SPILL DRILL & SAFETY MEETING, RIH W/ OVERSHOT, P/U 3-1/2" DRILLPIPE, WASH DOWN OVER FISH @ 10332', POH, LD FISH RECOVERED PBR SEAL ASSEMB., RIH W/ PKR MILL TAG FISH @ 10374', CBU, WELL STABLE, POH, LD PKR & TAILPIPE, BRK DOWN FISHING TOOLS, LD DRILL COLLARS. (145110) DAILY: $ 32,664 CUM: $ 162,170 EFC: $ 782,000 04/04/92 (-- 4) TD:ll300 PB:11257 SUPV:NJS (COMP) CLN OUT: 22.0 PL PKR: 2.0 POH ~/ 6" BIT CLEANOUT MW: 8.5 Seawater LD DRILL COLLARS, RIH TO 10768', TAG FILL IN HOLE, WASH & REAM TO 11256' PBTD, REVS CIRC, DRILL STRING PLUGGED CANNOT CIRC, POH TO LINER TOP-TIGHT, WORK PIPE FREE, REVS CIRC, RIH TO 10677', REVS CIRC, RIH TO 11006', TAG FILL, WASH & REAM TO 11254', REVS CIRC, DRILL PIPE PLUGGED OFF, WILL NOT CIRC, POH TO LINER TOP, TIGHT, WORK PIPE FREE, REVS CIRC, RIH, TAG UP @ 10996', WASH & REAM THRU TIGHT SPOT, RIH TO 11102', REVS CIRC, POH W/ 6" BIT. (145110) DAILY: $ 46,178 CUM: $ 208,348 EFC: $ 782,000 (COMP) CLN OUT: 13.0 OLD PROB: 4.0 04/05/92 (-- 5) TD:ll300 PB:11257 SUPV:NJS TEST CSG: 7.0 POH LD DRILL PIPE MW: 8.5 Seawater POH W/ 6" BIT, RIH W/ BAKER TEST PK R TO 10469', SET PKR, TEST CSG, RELEASE PKR, POH W/ TEST PKR & LD, MU SCRAPER, RIH CANNOT GO THRU WEAR RING, TOP OF WEAR RING DAMAGED, POH WORK WEAR RING THRU STACK, INSTALL NEW WEAR RING, RIH W 8-1/2" BIT, REVS CIRC, CHANGE WELL OVER TO SEAWATER, POH, LD 3-1/2" DP (145110) DAILY: $ 32,588 CUM: $ 240,936 EFC: $ 782,000 (COMP) CLN OUT: 10.5 OLD PROB: 1.5 RUN COMP: 12.0 04/06/92 (-- 6) RIH W7 4-1/2" COMP -- MW: 8.5 Seawater TD:ll300 POH, LD DP, RIG UP OTIS, RIH W/ GR/JB TO 10433' POH JB FULL PB:11257 OF METAL & RUBBER RERUN JB, JB CLEAN, RIG DOWN OTIS, PULL SUPV:NJS WEAR RING, RIG UP TORQUE TURN, RIH 4-1/2" CHROME COMP., REPAIR PIPE SKATE, RIH W/ COMP (145110) DAILY: $ 47,652 CUM: $ 288,588 EFC: $ 782,000 ACTIVITY SUMMARY for WEL~ pRoJECT 145110 COMPANY: BP/AAI SHARED SERVICE, NORTH SLOPE, AK FIELD : PRUDHOE BAY WELL : S-16 Page: 2 DRLG RIG : NONE WO/COMP RIG: DOYON 16 (COMP) NU ND: 7.0 RUN COMP: 11.0 04/07/92 ( 7) RIG RELEASE 24:00 4/6/92 MW: 8.5 Seawater TD:ll300 RIH W/ 4-1/2" CHROME COMP., LAND TBG, SET PKR PRESSURE UP PB:11257 TBG ANNULUS, ND BOPE NU TREE, SECURE WELL, RIG RELEASE SUPV:NJS 24:00 4/6/92 (145110) DAILY: $ 446,283 CUM: $ 734,871 EFC: $ 734,871 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 04/01/92 T9 83353 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. D-07 7~-2~ CCL 03/23/92 91 W-38~~'~ CCL 02/25/92 91 F-303~~//° PRODUCTION LOG 03/24/92 91 N-18~-/~ PERF 03/25/92 cc . 10000.00-10170.00 ATLAS 5 " 13700.00-13943.00 ATLAS 5 " 12000.00-12450.00 SCH 5 " 9100.00-10014.00 SCH 5 " 10200.00-10380.00 ATLAS 5 " Information Control Well Records Adrian J. Martin RECEIVED APR 1,5 199;; AJaska 0il & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 01/16/92 T# 83187 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. ~~~ 168~'~Y~' LEAK DET 12/26/91 #1 12/28/91 #1 ~___.~ PROD-F -~05~Z-~ GAS LIFT SURVEY 12/26/91 #1 ~ ~/~-25 ~"'1~,) TEMP 12/26/91 #1 '~-17A~I'I;%GAS LIFT SURVEY 12/25/91 #1 · ~_~ ~1-~~TEMP 12/29/91 #1 ~~ JEWELRY 12 / 30 / 91 # 1 5 " -24 JEWELRY 12/28/91 #1 9800.00-11774.00 CAMCO 5 " 7580.00-10455.00 CAMCO 2 " 8500.00- 9462.00 CAMCO 5 " 2000.00-10229.00 CAMCO 2 " 350.00- 9467.00 CAMCO 2 " 8500.00-10200.00 CAMCO 2/5" 8500.00- 9462.00 CAMCO 5 " 2000.00- 9984.00 CAMCO 2 " 8700.00- 9740.00 CAMCO 5 " 8500.00-10200.00 CAMCO 8500.00- 9462.00 CAMCO Information Control Well Records Adrian J. Martin RECEIVED JAN 199Z Alaska 011 & Gas Cone. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :08/16/90 T#:81497 FROM' SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. S-16 Peal 08/10/90 10400-10980 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR RECEIVED Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :07/19/90 T#:81406 FROM' SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the matedai listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. F-03 TEMP 07/07/90 #1 10850-11155 CAMCO 5" F- 15 PROD-F 07/03/90 # 1 9300-9742 CAMCO 5" F-32 TEM P/G R 07/06/90 #1 10300-10802 CAMCO 5" G-13 PROD-F 07/09/90 #1 9100-9420 CAMCO 5" N-14 PITS 07/04/90 #1 9500-10124 CAMCO 5" S-16 PITS' 07/05/90 #1 10500-11019 CAMCO 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RES~~ ARCHIVES 1. Type of Request:. Abandon ~ Suspend Alter casing ~ Repair well Change approved program ~ , ' % STATE OF ALASKA ' ~ ~' n D APPLICATION FOR SUNDRY APPROVALS Operation Shutdown Re-enter suspended well Plugging ~ Time extension ~ Stimulate X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2094' SNL, 714' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, SEC. 26, T12N, R12E, UPM At effective depth 2254' SNL, 1475'EWL, SEC. 26, T12N, R12E, UMI At total depth 2212'SNL, 1480' EWL, SEC. 26, T12N, R12E, UPM 11300 feet BKB 9248 feet 11235 feet BKB 9133 feet 12. Present well condition summary Total depth: measured · true vertical Effective depth: measured true vertical Pull tubing ,,, Variance 5. Type of Well: Development X Exploratory Stratigraphic ~ Service O~e~ 6. Datum elevation (DF or KB) Plugs (measured) Junk (measured) Perforate KBE = 67.12 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-16 (12-26-12-12) PBU 9. Permit number 84-84 10. APl number 50- 029-21123 11. Field/Pool Prudhoe Oil Pool Casing Length Size Cemented Measured depth Structural -- Conductor 110 20x30 8 c. y. 137 Surface 2646 13 3/8 3812 c. fo 2673 Intermediate 10666 9 5/8 2769 c.f. 10693 Production -- Liner 864 7 312 c.f. 10436-11300 Perforation depth: measured 10708'- 10750' (Sag R.) 10882'-10887', 10887'-10907', 10914'-10918', 10926'-10964'(Ivishak) true vertical subsea 8738'- 8770'(Sag R.) 8869'8931' (four Ivishak intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 EUE to 10381' with 2 7/8" tailpipe to 10489' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10381~ 3 1/2" SSSV at 1975' Description summary of proposal X Detailed operations program __ 13. Attachments True vertical depth BKB 137 2673 8794 8602-9248 ._, .,/ , .Oil .6. Gas Cons. BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: June 1990 16. If proposal was verbally approved Oil X Gas ~ Suspended Conditions of approval: Notify CommiSsion so representative may witness I Approve, ,o. ¢0 Plug integrity__ BOP Test Location clearance __ Mochanieal Integri~ Test~ Su---'~sequent form r~luired 10- ~9/-'/- Approved by order of the Commission Date ~ Form 10-403 Rev 06/15/88 ORIGINAL SIGNED .BY LONNIE C.' 'SMITH Commissioner Approved Copy SUBMIT IN TRIPLICATE Returned , STATE SUNDRY NOTICE WELL S-16 Well S-16 requires a hydraulic fracture of the ivishak to increase productivity, as follows: I . Rig up fracturing equipment and pressure test. Perform a calibration frac. 3. Fracture as follows: pROPPANT STAGE ,VOLUME ppg ~ LBS Pad 63.0 0 1 2.2 1 16/20 CL 2200 2 2.1 3 16/20 CL 6300 3 2.0 5 16/20 CL 10000 4 1.9 7 16/20 CL 13300 5 0.5 9 16/20 CL 4500 6 4.2 10 16/20 CL 42000 FLUSH 4.4 0 35 35 35 35 35 35 35 35 Leave well shut in overnight. Clean-out any frac sand in wellbore, return well to production FLOW TUBES & PACKOFF FLOWLINE FLOWLINE VALVE -- BOWEN PA,....~OFF J-*-' HAND PUMP GREASE SEAL FLOWTUBE GREASE LINE RISER GREASE / MANIFOLD ~GREASE ~ PUMP ,, BOP ,,~ GREASE RESERVOIR BP EXPLORATION March 20, 1989 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-16 (12-26-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, J. A. Brag~ /qanager Production ~ngineering JAB:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File STATE OF ALASKA AI.a,~KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Stimulate X Alter casing !. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc, 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2094' SNL, 714' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, SEC. 26, T12N, R12E, UPM At effective depth 2240' SNI., 1473' EWL, SEC. 26, T12N, R12E, UPM At total depth 2212' SNL, 1480' EWL, SEC. 26, T12N, R12E, UPM Plugging Repair well 5. Type of Well: Development X Exploratory Sffatigraphic Servi~e 12. Present well condition summary Total depth: measured true vertical 11300 feet BKB 9248 feet Plugs (measured) Perforate Other 6. Datum elevation (DF or KB) KBE. 67.12 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number $-16 (12-26-12-12) PBU 9. Permit number/approval number 84-84 / 9-140 10. APl number 5O- 029-21123 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 11257feet Junk (measured) true vertical BKB 92!6feet Casing Length Size Cemented Structural -- Conductor 110 20x30 8 c.y. Surface 2646 13 3/8 3812 c.f. Intermediate 10666 9 5/8 2769 c.f. Production -- Liner 864 7 312 c.f. Perforation depth: measured 10708'- 10750'(Sag R.) 10882'-10907', 10914'-10918', 10926'-10964' (Ivishak) true vertical subsea 8738" 8770' (Sag R.) 8868'8930' (three ivishak intervals) Measured depth 137 2673 10693 10436-11300 Tubing (size, grade, and measured depth) 3 1/2" L-80 EUE to 10381' with 2 7/8" tailpipe to 10489' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10381'; 3 1/2" SSSV at 1975 True vertical depth BKB 137 2673 8794 8602-9248 13. Stimulation or cement squeeze summary see attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. R~.oresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1010 802 116 1393 205 Subsequent to operation 1010 711 106 1408 213 15. Attachments I 16. Status of well classification as: Copies of Logs and Surveys run I Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby ~is. true and correct to the beStTitleOf my knowledge.Production ~/~//~ ned ,,:~/ ~/~ Manager Engineering . Date Form 06/15/88 ~J' -- / ~SUBMIT IN DUPLICATE WELL S-16 (12.26.12.12~ PBU STIMULATION OPERATIONS A 15% HCI perforation wash followed by a scale inhibition treatment was performed on the following perforated intervals in Well S-16. 10882' - 10907' MD BKB 10914' - 10918' MD BKB 10926' - 10964' MD BKB The acid wash consisting of 27 bbls. of diesel followed by 55 bbls. 15% HCI/ xylene was performed February 16, 1989. The well was returned to production immediately following the acid treatment. The following scale-inhibition treatment was performed March 5, 1989 via coiled tubing: 16 bbls. diesel preflush 24 bbls. methanol 98 bbls. EDTA w/OSR 84 bbls. scale inhibitor w/OSR 323 bbls. seawater followed by 100 bbls. diesel The well was left shut. in for 24 hours, then returned to production and tested. jm 3/17/89 Standard Alaska .~"~ Production Company 900 East Benson Boulevc P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 STANDARD ALASKA PRODUCTION January 31, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-16 (12-26-12-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB:JAM Enclosures (9) cc: L. Burke (MB12-1) Well File /A. Bragg &/Manager Production Engineering RECEIVED FEB 2 "¢ ~'~' Alas~ gil & Gas ~ons. Commissio~ A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA AL.-~KA OIL AND GAS CONSERVATION COMMISo~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon , Suspend Alter casing Repair well Change approved program 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2094' SNL, 714' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, SEC. 26, T12N, R12E, UPM At effective depth 2240' SNL, 1473' EWL, SEC. 26, T12N, R12E, UPM At total depth 2212' SNL, 1480' EWL, SEC. 26, T12N, RI2E, UPM 12. Present Well COndition Summary Total depth: measured true vertical BKB Effective depth: measured true vertical BKB Operation Shutdown Plugging Time extension ~ Pull tubing Variance ~ Perforate ~ 5. Type of Well: 6. Development X Exploratory Stratigraphlc 7. Service Re-enter suspended well Stimulate X Othe~ Datum elevation (DF or KB) KBE = 67.12 AMSL feet Unit or Property name Prudhoe Bay Unit 8. Well number S-16 (12.26-12-12) PBU 9. Permit number 84-84 10. APl number 50- 029-21123 11. Field/Pool Prudhoe Oil Pool 11300 feet Plugs (measured) 9248 feet 11257 feet Junk (measured) 9216 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth .. BKB 110 20x30 8 c.y. 137 137 2646 13 3/8 3812 c.f. 2673 2673 10666 9 5/8 2769 c.f. 10693 8794 measured .. 864 7 312 c.f. 10436-11300 10708'- 10750' (Sag R.) 10882'-10907', 10914'-10918', 10926'-10964' (Ivishak) true vertical subsea 8738'- 8770'(Sag R.) 8868'-8930' (three Ivishak intervals) Tubing (size, grade, and measured depth) 3 1/2" L-80 EUE to 10381' with 2 7/8" tailpipe to 10489' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 10381'; 3 I/2" SSSV at 1975' .13. Attachments Description summary of proposal × Detailed operations program ~ ; ECEIVED ~,las~.Oil .& Gas Cons. , ,. N~ch0rage'? BOP sketch x 4. Estimated date for commencing operation' I February 1989 6, If proposal was verbally approved Oil X Name of approver Date approved Service 7. I hereby Certify that the foregoing is true and correct to the best of my knowledge. 15. Status of well classification as: Gas Suspended~ FOR COMMISSION USE ONLY Condit~ns of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- .~z~ Approved Copy ORIGINAL SIGNED BY Returned Approved by order of the CommissionLONNIE C. SMITH ~ -- ~-~' Form 10-403 Rev 06/15/88 Commissioner _ SUBMIT IN TRIPLICATE WELL 8-16 (12-26-12-12) I~BU STIMULATION PROPOSAL A 15% HCI perforation wash followed by a contingent scale inhibition treatment is proposed for the following perforated intervals in Well S-16. 10882' - 10907' MD BKB 10914' - 10918' MD BKB 10926' - 10964' MD BKB The acid wash will consist of pumping 25 bbls. of diesel followed by 2000 gal. 15% HCI/ xylene down coiled tubing at maximum rate while reciprocating across the Ivishak perfs. The well will be returned to production immediately following the acid treatment. Depending on the results of the HC1 wash, the following scale inhibition treatment will be performed via coiled tubing: 15 bbls. diesel preflush 15 bbls. methanol 24 bbls. EDTA w/OSR 84-100 bbls. scale inhibitor w/OSR 15 bbls. seawater followed by diesel. The treatment fluids will be displaced to the perforations with remaining seawater. well will be left shut in for 24 hours, then returned to production and tested. The jm 2/3/89 Coiled Tubin~ Blow-Out-Preventers Coiled Tubing Pack-Of~ Cutter Rams I fl Slips ump-ln Sub (Circu~ t~R e turns) W ell Head Swab Valve Standard Alaska Production Company ~ 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 r STANDARD ALASKA PRODUCTION July 20,.1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-16 (12-26-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB:JAM Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 S-16 Well File /Manager Production Engineering A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation performed: Operation shutdown [] Stimulate I~ Plugging [] Perforate [] Pull tubing [] Alter casing [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2094' SNL, 714' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, SEC. 26, T12N, R12E, UPM At effective depth 2240' SNL, 1473' EWL, SEC. 26, T12N, R12E, UPM At total depth 2212' SNL, 1480' EWL, SEC. 26, T12N, R12E, UPM 1. Present well conditio'n summary Datum elevation (DF or KB) KBE = 67.12 AMSL feet Unit or Property name IPrudhoe Bay Unit 7. Well number S-16 (12-26-12-12) PBU 8. Approval number 7-857 9. APl number 5 0- 029-21123 10. Pool Prudhoe Oil Pool Total depth: measured 11300 feet true vertical BKB 9248 feet Plugs (measured) Effective depth: measured 11257 feet true vertical BKB 9216 feet Junk (measured) Casing Length Size Cemented Measured depth Structural -- Co nd ucto r 110 20x30 8 c.y. 137 Surface 2646 13 3/8 3812 c.f. 2673 I ntermed late 10666 9 5/8 2769 c.f. 10693 Production -- L i n e r 864 7 312 c.f. 10436-11300 Perforation depth: measured 10708'- 10750' (Sag R.) 10882'-10907', 10914'-10918', 10926'-10964'(Ivishak) true vertical subsea 8738'- 8770' (Sag R.) ~ 8868'-8930' (three Ivishak intervals) Tubing (size, grade and measured depth) 3 1/2"L-8~ EUE to 10381'with 2 7/8"tailpipe to 10489' True Vertical depth BKB 137 2673 8794 8602-9248 Packers and SSSV (type and measured depth) 9 5/8"BOTpackerat 10381'; 3 1/2"SSSVat 1975' 2. Stimulation or cement squeeze summary Intervals treated (measured) see attachment Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Averac~e Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 310 200 0 1170 1280 800 110' 1587 Tubing Pressure 220 220 4. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 5. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ,,~~ ' Form 1,0-404 Rev. 12-1-85 ~ Title Manager Production Engineering Date STul~m~it~i~D u~plicate WELL S-16 ¢12-26-12-12} PBU ~TIMI. It~ATION OPERATIONS A bullheaded HC1/xylene perforation wash in four stages was performed July 5, 1988 on the following perforated intervals in Well S-16. 10708'- 10750'MDBKB 10882'- 10907'MDBKB 1091~ - 10918'MDBKB 10926'- 10964'MDBKB One day prior to the perforation wash, the tubing was pickled with 20 bbls. 7.5% HCI w/20# dispersed xylene. The four-stage perforation wash was as follows: 500 gal. HC1/xylene 30 bbls. foam 1000 gal. HC1/xylene 50 bbls. foam 2000 gal. HC1/xylene 50 bbls. foam 2500 gal. HC1/xylene 19 bbls. diesel w/10% mutual solvent The treatment fluids were displaced to the perforations with 90 bbls. dead crude. The well was returned to production immediately following the treatment; then tested. jm 7/12/88 i NOEXED DALL~,S ~co STANDARD CHEVRON ALASKA PRODLJC TIC)N EYO(ON Date: 02/24/88 TEXACO 78597 TO: T#: MOBIL PHILLIPS REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this let-~er and returning It to this office: 02/02/88 Camco Static Gradient 02/08/88 Camco " " 02/08/88 Camco " " 02/12/88 Camco " " 02/12/88 Camco " " 02/03/88 Camco " " 01/27/88 Otis " " 02/02/88 Camco " " 02/04/88 GO " 02/04/88 GO " 02/10/88 Camco " " 02/13/88 Camco " " 01/28/88 Otis " " 01/24/88 Otis " " 01/23/88 Otis " " 02/03/88 Camco " " 01/25/88 Otis " " 01/26/88 Otis " " 02/15/88 Camco " " 02/10/88 Camco " " ~~~~ '~ Vic t°r ia $cAoi!~i~g e Date un.I OI the. O~.,g,~Ot Slo~s~o~'d C~l C Standard Alaska ~-~x, Production Compan~ 900 East Benson Bou~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) ,564-5111 STANDARD ALASKA PRODUCTION October 27, 1987 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-16 (12-26-12-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM ~ Enclosures (9) cc: J. L. Haas (MB12-1) S-16 Well File j.-A. Bragg -- Supervisor Production Operations A unit of the original Standard O~1 Company Founded in Cleveland, Ohio, in 1870. ~-~-~' STATE OF ALASKA ALA~...~-, OIL AND GAS CONSERVATION CON ..... ,.,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 I~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 67.12 feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 2094' SNL, 714' EWL, Sec. 35, T12N, R12E, %7PM At top of productive interval 2602' SNL, 1383' EWL, Sec. 26, T12N, R12E, UPM At effective depth 2240' SNL, 1473' EWL, Sec. 26, T12N, R12E, UPM At total depth 2212' SNL, 1480' EWL, Sec. 26, T12N, R12E, UPM 7. Well number S-16 (12-26-12-12) PBU 8. Permit number 84-84 9. APl number 50-- 029-21123 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 11300 feet Plugs (measured) 9248 feet BKB Effective depth: measured true vertical 11257 feet Junk (measured) 9216 feet BK Casing Length Structural -- Conductor 110' Surface 2646 ' Intermediate 10666 ' Production -- Liner 864' Size Cemented Measured depth True Vertical depth BKB 20"x30" 8 cu.yds.' 137' 137' 13 3/8" 3812 c.f. 2673' 2673' 9 5/8" 2769 c.f. 10693' 8794' 1! (Sag R.) (3 Ivishak intervals) 312 c.f. 10436'-11300' Perforation depth: measured 10708' - 10750' 10882' - 10964' true vertical (ss) 8738' - 8770' 8868' - 8930' lubing (size, grade and measured depth) 3 1/2" L-80 EUE to 10381' with 2 7/8" tailpipe to 10489' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 10381'; 3 1/2" SSSV at 1975' 8602 ' -9248' RECEIVED ,- ,-,'? ,~ (~ 'i u, ii ~ Al.aSk3 Oil & Gas Cons. Commission Anchorage 12.Attachments Description summary of proPosal I~ Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation November 1987 14. If proposal was verbally approved Name of approver Subsequent Work Reported on Form No. ~' Dated ',_Zd~.~_ '~ /~ Date approved 15..I hereby certify that the foregoing is true and correct to the best of my knowledge Si~d ~ Title Supervisor Production Operations Date ~ J. A. Bragg Commission Use Only Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] L.gcation clo_arance gY [tg~![ C. SllTI ~ ............... Y by order of Commissioner the commission Date/'o- Submit in triplicate Form 10-403 Rev 12-1-85 Well S-16 (12-26-12-12) PBU STIMULATION PROposAL A bullheaded HCl/xylene perforation wash in four stages is proposed for the following perforated intervals in Well S-16. 10708' - 10750' MD BKB 10882' - 10907' MD BKB 10914' - 10918' MD BKB 10926' - 10964' MD BKB One day prior to the perforation wash the tubing will be pickled with 20 bbls. 7.5% HC1 w/20% dispersed xylene. The four-stage perforation wash is as follows: 500 gal. HC1/xytene 30 bbls. foam 1000 gal. HC1/xylene 50 bbls. foam 2000 gal. HC1/xylene 50 bbls. foam 2500 gal. HCl/xylene 20 bbls. diesel w/10% mutual Solvent The treatment fluids will be displaced to the perforations with dead crude. The well will be returned immediately to production and tested. jm 10/27/87 Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Off' I I I Blind Rams Cutter Rams Chicksan (Kill Line) I Slips Pipe Rams Pump-In Sub (Circulate/Returns) --~ W ell Head Swab Valve Standard AIo$1~o P~oduction Company 900 Eo~! P O. Bo Ancho~oge. Alu~ko {9071 564-51 I I DALLAS ARCO CHEVRON EXXON TEXACO Date: TO: MOBIL TI: PH ILL IPS STATE OF ALASKA GEOSCIENCES INDEXED' STANDARD ALASKA PRODUCTION O3/19/87 77777 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-15 B-7 C-32 D-25 D-28 G-32 !l-26 N-21 WOPITS 03/02/87 al 10650-11200 camco 5" GR 02/10/87 al 10197-12067 GO Production Profile 02/27/87 al 10175-10430 Camco 5" Cont. Flow 02/26/87 al 10530-10832 G0 Dynamic Spinner 02/27/87 #- 10850-11050 Otis Production Profile 02/28/87 al 9190-9500 camco 5" Production Profile 02/26/87 al 9600-9850 camco 5" cont. Flow 02/26/87 al 10900-11220 Go 5" $-]2A Cont. Flow . .02J25/87 ttl 9620-1 01 50 GO _ _ 5" ~..16" Pr~du~-ti~n-P;ofile- 02/~7/87 'Iii ' i0~50-11246 C~o ~ , o .~c.~v.d ( ~ ~/~, .!~I~7 ~ _ ' ' -/w I-~'/ii~ ~ ~ ..... Victoria Aldridge ~ / ~t~ssiO~ INF~HAT I~ CONTR~ Dote .. / ~ ..... ,~ ,.: t;ui~S. ~il~ ," ~el I Records LR2-I Fou-ded ,. Cle-~,o. ,n I~0 Stondowd Alaska Pwocluc tion Corn pan¥/.~-'~ 900 Eost Ben~,on BOV[~ ' P.O Bo, 19661;) Ancho~oge. AIo~l~o 99.519-6612 19071 564-.511 I TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS rSTATE OF' ALASKA GEOSCIENCES INDEXED STANDARD ALASKA PRODUCTION Date: 03/19/87 T#: 77777 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of this letter and returning it fo this office: "-.5 A_15 ~ B-7 -'"~ C-32 ',~ D-25 '--.a D_28 ~ G-32 ~ H-26 -"- N-21 ~ S-12A WOPITS 03/02/87 #1 GR 02/10/87 #1 Production Pro£ile 02/27/87 #1 Cont. Flow 02/26/87 #1 Dynamic Spinner 02/27/87 #- Production Profile 02/28/87 #1 Production Profile 02/26/87 #1 Cont' Flow 02/26/87 #1 Cont. Flow 02/25/87 #1 ProduCTion Pr---ofile 02/27/87 #1 10650-11200 Camco 5" 10197-12067 GO 5" 10175-10430 Camco 5" 10530-10832 GO 5" 10850-11050 Otis 5" 9190-9500 Camco 5" 9600-9850 Camco 5" 10900-11220 GO 5" .,9620-10150 GO 5" 10550-11246 Camco ~ Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 standard Alaska ~ p~oduclion Company / 900 EOSI Ben,on Boutevo, P.O. Box 1966l? Anthoroge, Alosko 99219-66 (907! 564-3! I ! TO: DALLAS ARCO. CHEVRON EXXON_ TgXACO_ MOBIL_ PHILLIPS_ STA~E OF ALASKA_ GEOSC~NCES_ INDEXED____ STANDARD ALASKA PRODUCTION 12/O3/86 Date: -- TI: 77563 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. : signing a copy of this letter and returning It to this office: ---'"--B-6 Perf Record 07/08/86 11.1 · 04/25/86 t1.]. ~ D-19 EPL 04/28/86 t1.2 -'---M-14 EPL 04/11/86 #2 ~---- M-14 EPL 11.1 '~N-2 Multi-finger Caliper 07/02/86 07/06186 t1.1 ~ N-7 Perf. Record 04/22/86 #1 "~'-'R- 6 EPL 11.1 4--~S_I6 Perf. Depth Control 07/04/86 S-16 Perf. Record 07/15/86 #1 ~ - 04/11/86 1t. 2 ---- X-14 EPL Please acknowledge receipt by 8446'9335 'Sch 9000-9400 Sch 5" 10200-10727 Sch 10100-10900 Sch 5" 9266-10461 Sch 5" 9440'10554 Sch 5" 9700_10400 Sch 5" 10674-11228 Sch 5" 10300-11235 Sch 5" 11490-11567 Sch 5" ~ Naska 011 & Gas Cons. Commission Anchorage Rece i ved , ,, -- :. Date founded m Cle,,elond. 0h'm "'~ 1870 Victoria Aldridge INFORMATION CONTROL Well Records LR2-1 TO: DALLAS ARCO CHEVRON EXXON TEXACO bIOBIL PHILLIPS k,LSTATE OF :ALASKA? GEOSC IENCES INDEXED STANDARD AL ASIC~ PRODUCTION Date: 09/24/86 TI: 77362 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by slgnlng a copy of thls letter and returning It to this office: -'"~-A-33 Perf. Record 04/04/86 #3 10950-11350 Sch 5" ~'"B-4 Packer Depth Record 04/10/86 #1 9550-9810 Sch 5" ''""E-1 ~ Packer setting 04/05/86 #1 8200-9450 Sch 5" '"k'-~-3i CBL 07/i8/86 #1 7000-9250 GO 5" ~'-K-5 Perf. Record 04/12/86 #2 8920-9785 Sch 5" ~'~K-5 Perf. Record 05/24/86 #3 9240-9766 Sch 5" ""--M-2 EPL 03/06/86 #1 9600-10120 Sch 5" ~M-2 EPL 03/13/86 #1 9700-10030 Sch 5" ~'~M-28 GR CCL (RA CEMENT) 04/30/86 #1 2100-3500 Sch 5" ~N-1 CNL 03/21/86 #2 8450-8975 Sch 5" -~-3 TDT-MA 04/01/86 #2 11100-11737 Sch 5" ~-Q-1 Perf. Record 04/23/86 #1 9300-9660 Sch 5" NR-9 Perf. Record 05/15/86 #1 9100-9500 Sch 5" "~S-2 Perf. Record 04/15/86 #2 10700-11287 Sch 5" ~S-5 Perf. Record 05/16/86 #1 10100-10500 Sch 5" ~S-16 Perf. Record 05/14/86 #1 10300-11221 Sch 5" X-9 Perf. Record 04/02/86 #2 12000-12268 Sch 5" ~"-Y-21 GR/CCL 04/18/86 #1 8750-10525 Sch '5" ~-Y-21 GR/CCL 04/18/86- #1 8750-10525 Sch 2" '~---Y-21 GR Tie-in 04/25/86 #1 9725-10750 Sch 5" Date ~ Vwl!! ~'~e ! ]rO~dAs 1C d(dod~R2d(~'lg Standard Alaska Production Company 900 East Benson Boule~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION July 21, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Well S-16 (12-26-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well 0perations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, SLB:jAM'~~ Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 S-16 Well File S. L. Bryant, Supervisor Reservoir/Production Surveillance Unit II RECEIVED Alaska Oil 8, Gas Cons. Commission An,,h~,. age A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. .---'-,, STATE OF ALASKA ..-~,,,, ALASKA ~ AND GAS CONSERVATION COMMI )N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown []' Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 67.12 Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 2094' SNL, 714' EWL, Sec. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, Sec. 26, T12N, R12E, UPM At effective depth 2240' SNL, 1473' EWL, Sec. 26, T12N, R12E, UPM At total depth 2212' SNL, 1480' EWL, Sec. 26, T12N, R12E, UPM 7. Well number S-16 (12-26-12-12) PBU 8. Approval number N/A 9. APl number 50-- 029-21123 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 11300 feet Plugs (measured) 9248 feet BKB Effective depth: measured 11257 feet Junk (measured) true vertical 9216 feet BKB 12. Casing Length Size Cemented Structural -- Conductor -70' 20"x30"' 8 cu.yds. Surface 2633" 13 3/8" 3812 c.f. Intermediate 10653' 9 5/8" 2769 c.f. Production __ Measured depth 110' 2673' 10693' True Vertical depth BKB 110' 2673' 8794' 864' 7" Liner Perforation depth: measured 10708' - 10750' (one Sag R. interval) 10882' - 10964' (three'Ivishak intervals) true vertical(subsea) 8738' - 8770' 8868' - 8930' ~bing(size, grade and measured depth) 312 c.f. 10436'-11300' 3 1/2" L-80 EUE to 1038'1' with 2 7/8" tailpipe to 10489' Packers and SSSV(type and measured depth) 9 5/8" BOT packer at 10381'; 3 1/2" Camco SSSV at 1975' Stimulation orcementsqueeze summary Intervals treated (measured) 8602'-9248' Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas,Mcf Water-Bbl Casing Pressure 750 2194 1 1239 680 2501 0 1529 Tubing Pressure 205 212 14. Attachments Daily Report of Well Operations 5[ Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Form 10-404 Rev. 12-1-85 Title Supvr. Res./Prod. Surveillance II Date Submit in Duplicate pERFORATING DATA - Well S-16 (12-26-12-12) PBU The following additional intervals were perforated July 15, 1986 using Schlumberger 2 1/8" Hyperdome guns at 4 spf: 10882' - 10887' MD (8868' - 8872' TVDss) 10914' - 10918' MD (8892' - 8896' TVDss) 10926' - 10964' MD (8902'- 8930' TVDss) Note: All depths are referenced to BHCS/GR, 7/31/84. A lubricator was installed and tested to 3500 psi for all well work. The well was put back on production and tested following perforating operations. jR 7/18/86 Standard Alaska Production Company 900 East Benson Boule~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION -.-?~,,.~ July 10, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Well S-16 (12-26-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, SLB:JAM Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 S-16 Well File Supervisor Reservoir/Production Surveillance Unit II RECEIVED JUL 1 1 ~g86 Alaska Oil & Bas Cor~s. Commission Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. ,,'---,, STATE OF ALASKA ALASK;, _ AND GAS CONSERVATION COMM .~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 67.12 Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 2094' SNL, 714' EWL, Sec. 35, T12N, R12E, UPM At top of productive interval 2602' SNL, 1383' EWL, Sec. 26, T12N, R12E, UPM At effective depth 2240' SNL, 1473' EWL, Sec. 26, T12N, R12E, UPM At total depth 2212, SNL, 1480' EWL, Sec. 26, T12N, R12E, UPM 11. Present well condition summary Total depth: measured true vertical 7. Well number S-16 (12-26-12-12) PBU 8. Approval number N/A 9. APl number 50-- 029-21123 10. Pool Prudhoe Oil Pool 11300 feet Plugs (measured) 9248 feet BKB Effective depth: measured 11257 feet Junk (measured) true vertical 9216 feet B:Fd~ Casing Length Size Cemented Structural -- Conductor 70' 20"x30" 8 cu.yds. Surface 2633' 13 3/8" 3812 c.f. Intermediate 10653' 9 5/8" 2769 c.f. Production -- Liner 864' 7" 312 c.f. Measured depth 110' 2673' 10693' 10436'-11300' Perforation depth: measured 10708' - 10750' (Sag R.) 10887' - 10907' (Ivishak) true vertical (subsea) 8738' - 8770' 8872' - 8888, ~bing(size, grade and measured depth) 3 1/2"' L-80 EUE to 10381' with 2 7/8" tailpipe to 10489' Packers and SSSV(type and measured depth) 9 5/8" BOT packer at 10381'~ 3 1/2" Camco SSSV at 1975' 12. Stimulation orcementsqueeze summary Intervals treated (measured) Treatment description including volumes used and final pressure True Vertical depth BKB 110' 2673' 8794 ' 8602'-9248' RECEIVED J u L 1 11986 13. Alaska Oil & Gas Cons. Commission Anchorage Representative Daily Average Production or In'ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 940 2662 0 1537 206 14. Attachments ~ ?~'-"/7-"~ Form 10-404 Rev. 12-1-85 Daily Report of Well Operations [] Copies of Logs and Surveys.Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~'~~//.~ J ~ Title S upvr. Res./Prod. Surveillance II Date Submit in Duplicate slsOls6 at~. to 3000 pS~._ ~acJ Riffle ,, tic ~- - ~:ollOWir~9 lub e ~ - BYPer te~' 0' T~ss) 1070S' - 10750' ~P ?ut well on pzodUCtf°n and tested' Set and tested SSSV in ba~l ~al~e nipple at ~975' · _ f ~gged _~ l~b~ica~ ' he {°~L°w - ~0s$7' - ~0907' put wel~ baC~ on prodUctiOn an& tested' A%1 depths are referenced %o BBcs/G~' Note: RECEIVED JUL 1 1 1986 Alaska Oil & Gas Cons. Anchorage 7/9/86 INDEXED DALLAS 'A~c0 ~E~ON E~ON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD ALASKA PRODUC'[ION Date: 06/25/86 TI: 77147 Page 1 of 2!.t REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material is being subml~ed herewith. Please ecknowled~e receipt by signing a copy of thls le~'fer and returning It to this office: A-26 '~ BHP Survey A-29 ~" " A-31 "'-BHPD A-31 ~.BH Pres. Survey A-33 ~'~BHPD &"~BU A-33 ~Static Gradient A-34A '~'PBU A-34A ~BHPD F-17 _~"~tatic Gradient F-24 ~'Static Gradient J-3 ~tatic Gradient K-8 .~"BHPD ~-PBU M-10 ~tatic Gradient M-16 -~w " " M-19 '~" " M-21 ~" " M-24 ~' '" N-7 "~survey N-15 ~" Gradient N-18 ~" " N-19 ~--" " R-13 ~'~" " R-16 ~, . R-19 ', 05/28/86 Otis 05/29/86 Otis 05/11/86 Dres 05/09-11/86 Dres 06/03/86 GO 06/11/86 Camco 05/19-20/86 Camco 05/20/86 Camco 06/04/86 Camco 06/06/86 Camco 06/13/86 Camco 04/26/86 Otis 04/19/86 Otis 06/06/86 camco 06/02/86 Camco 06/03/86 Camco 06/08/86 06/08/86 Camco 05/24/86 GO 05/31/86 Camco 06/05/86 Camco 06/05/86 Camco 06/10/86 Camco 06/11/86 Camco 06/07/86 Camco 05/21/86 GO Static Gradient It I NFORHAT I ON CONTROL Wel I Records LR2-1 .= Dare: 06/25/86 T#: 77147 ~'""~-1 R/D~BHPD & Flowin- ~ S-16 ~Static Gradien~ Gradient U-2 ~ " ,, 05/27/86 06/01/86 U-10 ~BHPD ~"Flowing Gradient U-12 ~"Static Gradient 05/27-28/86 --~ 22-i1-12 Static Gradient 03/16/86 P_~e 2 of 2!! 05/13/86 Camco Camco 06/01/86 Camco Camco C~co Camco l& Gas Cons. Commissi~:' Anchorage Victoria Aldridge Well Records LR2-1 LR2-1 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 March 12, 1986 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 kttn: Mr. C. V. Chatterton Well'S-16 (12-26-12-12) PBU Gentlemen: Enclosed in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to perforate the well. Very truly yours, Supervisor, Reservoir/ Production Surveillance Unit II · SLB: Jk~4 '~ Enclosures (3) cc: Drilling Well Files (MB 12-1) Well Records (LR 2-1) S-16 Well File 4052m RECEIVED MAR ,1. 4 ]986 k~aska 0il & GaS Corl$. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator 7. Permit No. STANDARD ALASKA PRODUCTION COMPANY 84-84 3. Address 8. APl Number P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 50- 029-21123 OTHER [] 4. Location of Well At surface: 2094' SNL, 714' EWL, Sec. 35, T12N, R12E, UPM 5, Elevation in feet {indicate KB, DF, etc,) KBE = 67 12' AMSL 12. I6. Lease Designation and Serial No. ADL 28257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-16 (12-26-12 -12) PBU 11. FieldandPool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate ~] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state' all pertinent details and give per.tinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following Sag River interval wilI be perforated in March/April, 1986 at 4 spf: 10708' - 10750' BKB (Ref. BHCS/GR, 7/31/84) A lubricator will be installed and tested to 3500 psi for all well work. An SSSV will be set and tested in the ball valve nipple at 1975'. RECEIVED MAR 1 4 lg86 Alaska 0il & G:~s C0~]s. Commission Ar~ch'~ra;je 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ed Title Supvr. Reservoir/Production tThespacebel~w ~o~ C0;nmission use S. ~. B~yan Surveillance Unit II Conditions of Approval, if any: ~proYed CoF' By Order of the Commission Date~_ ~ X ~~' Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5f 11 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 July 17, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 ATTN: Mr, C,Vl Chatterton Wells S-15, S-16 AND S-17 PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wellsl These contain our proposals to perforate these wells, JAB /sh 7178~: 0505N Enclosures cc = T.N. Tyler Well Records (LR2-1) Drilling Well File #17 ' Yours very truly, /~.A. ,ragg ~SAPC Petroleum W. ngtneer RECEIVED J U L 1 91955 Alaska 0il & Gas Cons. commisslorl Anchorage STATE OF ALASKA ~ ALASKA (./,L AND GAS CONSERVATION CO,v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska PetrOleum Company 84-84 3. Address 8. APl Number PO Box 6612, A~chorage, AK 99502 50- 029-21123 4, Location of Well At Surface: 2094' SNL, 714' EWL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 67.12 ' AIRSL 6, Lease Designation and Serial No. ADL 28257 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-16 (12-26-12-12) PBU 11, Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [--] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated in August, 1985 using Schlumberger 2-1/8" Hyperdome guns at 4 spf. A lubricator will be installed and tested to 3500 .psi for all well work. 10882' - 10907' BKB (Ref. BHCA/GR, 7/31/84) 10914' - 10918' BKB " 10926' - 10964' BKB " 'A SSSV will be set and tested in the ball valve nipple at 1975'. RECEIVED J U L ! ~ ]985 ed Title SAPC Petroleum Engineer n use V ~~ ne sp.. Date l~pProve d C,o:=, BY k[ll~lE C. SMITil By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Date __2/~_~ Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. / ARCO ExplOr~,,,on - Alaska Operations Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 277 5637 HAND CARRIED SAMPLE TRANSMITTAL SHIPPED TO: ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501 ATTN' MIKE MINDER OPERATOR: S0}tI0/~q~ SAMPLE TYPE: CORE CHIPS SAMPLES DATE:HARCH 1931985 NAME ~ S- 16 NUMBER OF BOXES: REQUESTED TO BE SENT BY MASTANEH MADANI ATO .1018 10 DRY DITCH BOXi PLEASE SEE ATTACHED LIST UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO: ARCO ALASKA, INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99510 ATTN R. L. BROOKS RECEIVED BY: ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. ~ Internal Correapon~ Date: ~ARCH 1,1985 Subject: -16 CORE CHIPS FOR THE STATE From/Location: To/LOcation: EVA ANN ENDICOTT, PALEO MASTANEH MADANI ATO1018 LAB ABV 100 ~EPTHS 7763 7764 7765 : 7766 7767 7768 7769 7770 7771 7772 7773 7774 7775 7776 7777 7778 7779 7780 7781 7782 7783 7784 7785 7786 7787 7788 7789 7790 7791 7792 7793 7794 7795 7796 7797 7798 7799 7801 7802 7803 7804 7805 7806 7807 7808 7809 7810 7856 791~__ 7811 7857 ~]~'i9 7'812 7858 7920 7813 57859 7921 7814 7~-7~(r0''~ 7922 7815 ~7861 7925 7816 7862 7924 7817 7865 7925 7818 7864 7926 7819 7865 7927 7820 7866 7928 7821 7867 7930 7822 7868 7931 7823 7869 7932 7824 7870 7933 7825 7871 7934 7826 7872 7935 7827 7875 7936 7828 7874 7937 7829 7875 ' 7938 7830. 7876 7939 7831 7877 7940 7832 7879 7941 7833 7880 7942 7834 7881 7943 7835 7882 7944 7856 7885 7945 7837 7884 7946 7838 7885 7947 7839 7886 7948 7840 7887 7949 7841 7888 7950 7842 7889 7951 7843 7890 7952 7844 7891 7955 7845 7892 7954 7846 7893 7955 7847 7956 7848 7957 7849 7958 7850 7959 7851 7960 7852 7961 7853 7962 7854 7963 7855 7964 7965 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany 7966 cO~ENTS/CORRE CTIONS: ARCO PICKED UP THE COST FOR CORING THIS LIST EXCEPT AS' NOTED IN CO~EMTS AND CORRECTIONS, REPRESENTS A COMPLETE LIST OF SAI~LES DUE THE STATE OF ALASI~, · PLEASE SIGN AND RETURN THIS FORM TO'- "E.A.. ENDICOTT, ABV-100 NAME DATE SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON to. SFO/UNIT/STATE: TE]Q%CO (-.~a r a thon) MOBIL PHILLIPS CENTRAL FILES (CC//' s-Transmit tal Only) 31 I 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 12/5/84 CC#: 75911 REFERENCE: . /~ CASED HOLE FINAL LOGS ~Y~h: ~°~il°wing material is being submitted herew'th' Please ackn°wledge receipt by signing a copy of this letter and returning it to this office:- SFO/UNIT/State: M-87~ TDT-M 8/8/84 H2 10450-11659 Sch 5" S-9~, EPL 9/3/84 H1 3000-3250 Sch 5" Y-18~ EPL 9/1/84 H1 10975-11200 Sch 5" U/West End Test Well Temp. 7/30/84 Hi 9050-9695 Sch 5" S-i~6/GR in Casing 7/31/84 H2 9550-9900 Sch 2"/5" [l/84) REC[IV[O DAli Victoria Aldridge TPI-5 0il & ~ Cons. {.]0mmiSs[0~evel°Pment Geology Ai]chorage SOHIO ALASKA PETROLEUM COMPANY ARCO CHEVRON EXXON 3111 "C" S~RE[T ANCHORAGI AL A%k.;~ TELEPHONF (907~ 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 To SFO/UNIT/ GETTY Date: 8-28-84 STATE: MARATHON MOBIL CC#: 75668 PHILLIPS ,_ * Date to State ~~.~__~~(Transmlttal Only), , Via Drilling: R[F£REN~ENTRAL FILES (CCI!' s-Transmit tal Only) .SOHIO oPEN HOLE [IN...AL LOGS ~//'~,,.~__,)_ . . . ~ T~wing m~t~i~is being submi~ herewith. P~c ~ {t~..~CODV OJ~~_andireturni ' SFO/UNiT/sTAT~: ~.- S-!6. DIL/SFL 7-28-84 #1 2680-10672 Sch S- 16 BHCS S- 16 CNL/FDL S- 16 FDL 7-31-84 #2 10691-11293 Sch 7-28-84 #1 2680-10642 Sch 7-31-84 #2 10691-11262 Sch 7-28-84 #1 2680-8100 Sch 8-1-84 #2 10691-11295 Sch 7-28-84 , #1 2680-8100 Sch 8-1-84 #2 10691-11295 Sch 7-28-84 #1 2550-8100 Sch 7-28-84 #1 2680-8100 Sch 5" & 2" 5" & 2" 5" & 2" 5" & 2" 5" & 2" 5" & 2" 5" & 2" 5" & 2" 5" 5" 8-1-84 #2 10691-11265 Sch 5" S-16 CPL-Cyberlook S-16 Sidewall Core Shot Summary S-t6 CPL-CYBERLOOK Magnetic Single Shot Directional Survey Gyroscopic Directional Survey RECEIVED DATE Date: Job#: Date: Job#: RECEIVED ~ Carolyn Bishop .... / 0C~ ~--/--!~-'- Development Geology ....... / ....~ ,9 ....... Well Records ............... ' ...... ~. ~gk~-0ii-'&--(l~is' Cons. Commission Anchorage SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 October 9, 1984 Alaska Oil & Gas Conservation Conmission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton WRT,T, S-16 ~ (12-26'12-12) Permit No.' 84-84 Reference is made. to your inquiry dated October 4, 1984 requesting further information on the' above-named well. Please refer to our letter to you dated September 14, 1984 (copy attached) ooncerning whole core desCription. As noted, the actual cores' are in the possesSion i of Arco Alaska Inc. and core chips must be Obtained frc~ them'. Also attached herewith is a copy of the transmittal letter which accompanied the Blueline Logs and sepia which were acknc~ledged by your William Van Alen as having been received by AO~OC on September 5, 1984. Very truly yours, cc: Mr. Thomas L. Fithian ARCO Alaska' Inc. Well File #17 RECEIVED OCT! Alaska Oil & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 September 14, 19 84 Alaska Oil & Gas Conservation Ccemission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: Well S-16 (12-26-12-12) PBU Enclosed, in duplicate, is a whole core description of cores obtained in the above-~ well, S-16. The actual cores are in the possession of Arco Alaska, Inc. Very truly yours, District Drilling Engineer Well File ~17 RECEIVED OCT1 Alaska Oil & Gas Cons. Commission Anchorage SOHIO ALASKA PETROLEUM COMPANY Whole Core Description 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561.5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 %~ell: Sohio PBU S-16 (12-26-12-12) Geologic ~[orizon: Kuparuk Core No. 1 7764 - 7799' MD 7764 - 7788' 7788 - 7792.5' 7792.5 - 7795' 7795 - 7799' Shale: dark gray Intbd shale and silt SS: gray-gm, f-mg SS: it bm, vfg Core No. 2 7799 - 7859' MD 7799 - 7859' SS: lt-m bm, vf-fg Core No. 3 7859 - 7918' MD 7859 - 7866' 7866 - 7872' 7872 - 7894' 7894 - 7918' SS: It bm, vfg SS: it bm-gm, fg Intbd ss, shale and silt No recovery Core No. 4 7918 - 7968' MD 7918 - 7919' SS: m bt, vfg 7919 - 7968' Intbd ss, shale and silt HCH:dec 9/13/84 2661S RECEIVED 0CT! I Alaska 0il & Gas Cons. Commission /~nchor~ge -1509u6 SOHIO ALASKA PETROLEUM COIV~A~X ;)~/U SFO AaCO CH£V~ON EXXON 3111 "C" STREET ANCHORAG[. Al. ASKA TELEPHONE 19071 265-O000 MAll.: POUCH 6-612 ANCHORAGE. ALASKA 99502 SFO/UNIT/ GETTY Date: 8-28-84 STATE: HARATHON MOBIL Cc#: 75668 PHILLIPS . Date to State , , Via Drilling: 8-29-84 BPAE (Transmittal Only) , ~EFERE.Ci~:ENTRAL FILES(CC~'s-Transmittal 0nly) --=__ C'~NTRA L~. SUSJECT~.,.~ com~FILE soaIo oP~ HOL~ ~,.~ LOtS .... The following material is being submitted herewith. Please acknowledge receipt by signing a · copy of this letter and returning it to this office:-- S FO / UNIT / STATE: S-16 DIL/SFL S-16 BHCS S-16 CNL/FDL S-16 FDL S-16 Sidewall Core Shot Summary 7-28-84 #1 2680-10672 Sch 5" & 2" 7-31-84 - #2 10691-11293 Sch 5" & 2" 7-28-84 ~1 2680-10642 Sch 5" & 2" 7-31-84 ~2 10691-11262 Sch 5" & 2" 7-28-84 ~1 2680-8100 Sch 5" & 2" 8-1-84 --. #2 10691-11295 Sch 5" & 2" 7-28-84 ~1 2680-8100 Sch 5" & 2" 8-1-84 #2. 10691-11295 Sch 5" & 2" 7-28-84 ~ 1 2680-8100 Sch 5" STATE ONLY- RECEIVED OCT t I DIRECTIONAL SURf'S: Alaska Oil & Gas Cons. Commission Anchorage Magnetic Single Shot Directional Survey Date: 7-8,27-84 Job//: AL84Dll Gyroscopic Directional Surve '' ma--,'~),n BL.'.:':" ..... Development: .._ ,~ '?'. . _ ........... -_ OIL MID Bill Sheffield, Governor 3001 PORC'UPINE DRIVE ANCHORAGE,ALASKA ggs01.1-3ig2 TELEPHONE (907) 27g,-1433 .. S / We wish to bring to your attention that the Co~ission has yet receiVed the following required items on the subject well which our records indicated was completed. Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. C. V. Chatterffon/ Chairman lc:C.024 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 September 14, 19 84 Alaska Oil & Gas Conservation Coam~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: Well S-16 (12-26-12-12) PBU Enclosed, in duplicate, is a whole core description of cores obtained in the above-named well, S-16. The actual cores are in the possession of Arco Alaska, Inc. Very truly yours, District Drilling Engineer \ cc: Well File #17 SOHIO ALASKA PETROLEUM COMPANY Whole Core Description 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCH ORAG E, ALASKA 99502-0612 Well: Sohio PBU S-16 (12-26-12--12) Geologic Horizon: Kuparuk Core No. 1 7764 - 7799' MD 7764 - 7788' 7788 - 7792.5' 7792.5 - 7795' 7795 - 7799' Shale: dark gray Intbd shale and silt SS: gray-gm, f-mg SS: it brn, vfg Core No. 2 7799 - 7859' MD 7799 - 7859' SS: lt-m brn, vf-fg Core No. 3 7859 - 7918' MD 7859 - 7866' 7866 - 7872' 7872 - 7894' 7894 - 7918' SS: it bm, vfg SS: it brn-grn, fg Intbd ss, shale and silt No recovery Core No. 4 7918 - 7968' MD 7918 - 7919' 7919 - 7968' SS: m br, vfg Intbd ss, shale and silt HCH:dec 9/13/84 2661S RECEIVED SEP 1 Oil & Gas Cons. Commission SOHIO ALASKA PETROLEUM COMPANY Whole Core Description 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 Well: Sohio PBU S-16 (12-26-12-12) Geologic Horizon: Kuparuk Core No. 1 7764 - 7799' MD 7764 - 7788' 7788 - 7792.5' 7792.5 - 7795' 7795 - 7799' Shale: dark gray Intbd shale and silt SS: gray-gm, f-rog SS: it brn, vfg Core No. 2 7799 - 7859' MD 7799 - 7859' SS: lt-m bm, vf-fg Core No. 3 7859 - 7918' MD 7859 - 7866' 7866 - 7872' 7872 - 7894' 7894 - 7918' SS: It bm, vfg SS: it brn-grn, fg Intbd ss, shale and silt No recovery Core No. 4 7918 - 7968' MD 7918 - 7919' SS: m br, vfg 7919 - 7968' Intbd ss, shale and silt HCH:dec 9/13/84 2661S RECEIVED SEP 1 8 Alaska Oil & Gas Cons, commission Anchorage INDEXED SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE {907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 ~o: SFO/UNIT/ GETTY STATE: MARATHON MOBIL PHILLIPS BPAE (Transmittal Only) ,,, REFEREN&:~TR~L FILES(CC#'s-Transmittal Only) Date: 8-28-84 CC#: 75668 * Date to State Via Drilling 8-29-84 SOHIO OPEN HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by $ignimg a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: S-16 S-16 DIL/SFL BHCS CNL/FDL - FDL S-16 S-16 S-16V Sidewall Core Shot Summary 7-28-84 #1 2680-10672 sch 5" & 2" 7-31-84 #2 10691-11293 Sch .... 5" & 2" 7-28-84 #1 2680-10642 Sch 5" & 2" 7-31-84 #2 10691-11262 Sch 5" & 2" 7-28-84 #1 2680-8100 Sch 5" & 2" 8-1-84 #2 10691-11295 Sch 5" & 2" 7-28-84 #1 2680-8100 Sch 5" & 2" 8-1-84 #2 10691-11295 Sch 5" & 2" 7-28-84 #1 2680-8100 Sch 5" STATE ONLY: DIRECTIONAL SURVEYS: Magnetic Single Shot Directional Survey Date: 7-8,27-84Jobt/: AL84Dll Gyroscopic Directionalu~ -A/~~~~Survey_~ .~' t- ~ ~ Date: 8-16-84 Job#: AK-BO-400( RECEIVED Carolyn Bishop ~[sS~%ve lopment Geology ........ --AmS~ 0[I & G~$ C,0?. ~0~ Well Records o^~E ....... /kh~t~or~.oue ......... ' SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 September 4, 1984 Alaska Oil & Gas Conservation Coamtission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: '~ 'S-16 ' (12-26-12-12) PBU Enclosed, in duplicate, is Fonm 10-40 7, Well Completion Report, for the' above-named well together with the Well History, Well Logs and Directional Surveys. This well has been completed as a non-perforated oil well. Very truly yours, District Drilling Engineer cc: Well File #17 RECEIVED SEPO AlasKa Oil & Gas Cons. Commission Anchorage ;-~-~ STATE Of AlaSka "'"" ALAS~: .L AND GAS CONSERVATION ~,,. '!MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well . OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum O3mpany 84-84 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-21123 4. Location of well at surface 9. Unit or Lease Name 2094' SNL, 714' E~L, Sec. 35, T12N, R12E, UPM Prudhoe Bay Unit At Top Producing Interval (Top of Sag- R. Sst.) 10. Well Number 2602' ~L, 1383' EWL, Sec. 26, T12N, R12E, UPM S-16 (12-26-12-12) PBU At Total Depth 11. Field and Pool 2212' SNL, 1480' E~., Sec. 26, T12N, R12E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 67.12' AMSL ADL 28257 12. Date Spudded 13. Date I.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 07/06/84 07/31/84 08/05/84 feet MSLI One 17. TotaIDepth(MD+TVD) 18. Plug Back Depth (MD+TVS)19. DirectionalSurvey I 20. Depth where SSSV set I 21.Thickness of Permafrost l1300'MD-9248'TVD l1257'MD-9216'TVD YES~ NO[] 1975 feetMD 1860' 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR, LDT/CNL/CAL/GR, CBL/VDL/CCL/GR, Gyroscopic survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20 x 30 Ins,~late~ Conduct()r Surfac.~ 1]0 36 8 cu. y~s. concrete 13 3/8 72# L-80 Surface 2673'17%. 3812 cu.ft.Arctic~et III, II & I 9 5/8 47# L-80 Surface 10693 12~ 2260 cu.ft.Class G w/'8% Gel follc~ed b 230 cu. ft.Class G; 27c~ cu. ft. AS II 7 269 L-80 i 10436 11300 8% 312 cu.ft. Class G wi.th 18% salt 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) 3½" EUE 8rd 10381' 10381' w/2 7/8" taiLpipe 10491' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 2620 ' EZ Drill ~.~tainer - 300 cu.ft. PermafroSt C Squee 2819 ' - 2673 ' Kick-off Plu~ - ~ 186 cu. ft. ~rcticset II 27. PRODUCTION TEST Date;First Production " I Method of Operation (Flowing, gas lift, etc.) t Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERI.OD ,1~ Flow Tubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None (Core data will be submitted under separate cover) RECEIVED Alaska 0il & Gas Cons. Commission ze Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. .,.. MARKERs. .i,"::~ .::: :"i".~i.. 'i' "'.'.> · "~ ~ ' ::' · ,'": ' ~. FORMATION TEstS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag. R. Sst. 10694' 8727' Shublik 10751 ' 8770 ' Ivishak 10 879 ' 8866 ' I 31. LIST OF ATTACHMENTS Well History, Well Logs and Directional Survey 32. I hereby certify that the foregoing is true and'correct to the best of my knowledge .~$ Signed ~J ~ ~ ~ '-'~"~-~"~-~-~ Title ' Date R. H. Reile.v INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases~in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental .records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Qther-explain. Item 28: If no cores taken, indicate "none". Fnrm 1 WELL S-16 (12-26-12-12) PBU Spudded well at 0800 hours July 6, 1984. Vertically drilled 17 1/2" hole to 2700'. Ran 67 jts. 13 3/8" 724 L-80 Buttress casing to 2673'. Cemented with 3255 cu. ft. Arcticset II cement followed by 465 cu. ft. Arcticset III cement. Performed 92 cu. ft. Arcticset I top job. Installed and tested BOPE. Cleaned out to 2630', tested casing to 3000 psi, leaked off. Drilled out shoe and cleaned out to 2683'. Picked up EZ Drill retainer and set at 2620'. Tested casing to 3000 psi, okay. .Squeezed 13 3/8" shoe with 300 cu. ft. Permafrost C cement. Tested casing to 3000 psi, okay. Drilled out to 2720', ran leak-off test to 0.66 psi/ft, gradient. Unable to drill past junk at 2819'. RIH with open-ended drill pipe and spotted kick-off plug consisting of 186 cu. ft. Arcticset II cement. Dressed plug off to 2783 ', picked up Dynadrill and directionally drilled 12 1/4" hole to 3555'. Laid down Dynadrill, picked up BHA, directionally drilled 12 1/4" hole to 7764 '. RIH with 8 1/2" core barrel, drilled and .cored from 7764' to 7968'; obtained four cores, recovered 184'. Opened 8 1/2" hole to 12 1/4", drilled and surveyed to 10700'. Ran open hole logs. Shot 50 sidewall cores from 3664' to 7919', recovered 49 cores. Ran 260 jts. 9 5/8" 474 L-80 Buttress casing to 10693' Cemented with lead slurry of 2260 cu. ft. Class G cement with 8% ~el followed by tail slurry of 230 cu. ft. Class G neat. Tested casing to 3000 psi, okay. Installed and tested packoff to 5000 psi, okay. Pumped 175 bbls. 9.3 ppg. NaCl down 9 5/8" x 13 3/8" annulus. Tested BOPs. Cleaned out float equipment and directionally drilled 8 1/2" hole to 11300'. Ran open hole logs. Ran 21 jts. 7" 26~ L-80 IJ4S liner to 11300' Pumped 35 bbls. Spacer 3000 followed by 312 cu. ft. Class G with 1'8% salt ~to cement liner. Down-squeezed the 9 5/8" x 13 3/8" annulus with 279 cu. ft. Arcticset II cement followed by Arctic Pack. Cleaned out to 11257', tested liner to 3000 psi, okay. Changed over to NaCl. Ran CBL. Ran 318 jts. 3 1/2" EUE 8rd 9.3~ Mod Buttress IPC tubing with 2 7/8" tailpipe assembly to 10491'. Landed tubing with ball valve at 1975'. Installed and tested tree. Displaced tubing to diesel, set packer at 10381'. Tested tubing to 3500 psi, okay. Released rig at 0600 hours August 5, 1984. Ran gyroscopic survey~ tested and secured well August 15, 1984. RECEIVED SEPO 5 ]984 Alaska Oil & Gas Cons, Commission .~nchorane GREAT LAND DIRECTIONAL DRILLING INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY SOHIO COMPANY S- 16 WELL NAME PRUDHOE BAY, ALASKA LOCATION AL784D11 SINGLE SHOT 7-30-84 JOB NUMBER DON MASON NAME TYPE SURVEY DATE TITLE -- SIGNATURE 0 10648 DEPTH INTERNAL FROM TO 7-8-84 7-27-84 DATES SURVEY TAKEN FROM TO CONFID NTI$ THIS IS A RECORD OF A SUB-SURFACE SURVEY OF YOUR WELL We have retained a copy of your survey report in our ,ile/~r. your convenience; however, should you so desire, all copies the survey report will be forwarded to you on written request. All surveys are kept in a locked file and are held in strictest confi- dence. Additional copies of your survey report can be made from the original by any blueprint company. 1VIJ. CII:INO) GREATLAND DIRECTIONAl._ DRII_LING COMPLET]ON REPORT ]OMPUTED ON 7-30-84 USING RADIUS OF CURVATURE TECHNIQUE :ROM SURVEY DATA TAKEN :INAL CI_OSURE DIRECTION N 6.22 E 3INGL. E SHOT SURVEY RECORD OF SURVEY IWEL. L ASSUMED VERTICAl_ TO 2673.01 ~EAS DRIFT TRUVERT SUBSEA SECTION DIRECTION DEPTH DG MN DEPTH DEPTH DIST ANGI_E RELATIVE COORDINATES FROM WEt_L-HEAD CLOSURE DISTANCE DG MN S 0 0 0 0.00 -68.74 0.00 0.00 0.00 0.00 0.00 0 0 0 2673 2797 2920 3045 3199 3293 3512 3739 3934 4086 4210 4336 4456 4551 4643 4736 4799 4923 S056 S209 5366 5477 5634 5727 5819 5974 6199 0 0 2673.00 2604.26 0.00 0.00 0.00 0 54 2796.99 2728.25 0.96 N 2.00 W 0.97 N 2 54 2919.92 2851.18 5.03 N 8.00 E 5.04 N S 36 3044.57 2975.83 14.27 N 1.2.60 E 14.15 N 8 0 3197.47 3128.73 32.46 N 6.20 E 32.13 N 9 54 3290.32 3221.58 47.08 N 4.20 E 46.69 N 13 S4 3504.57 3435.83 92.1.9 N 3.50 E 91.74 N 17 24 3723.12 3654.38 153.34 N 3.20 E 152.86 N 20 0 3907.81 3839.07 215.78 N 3.70 E 215.26 N 23 30 4048.97 3980.23 272.08 N 6.00 E 271.37 N 26 18 4161.43 4092.69 324.28 N 6.60 E 323.26 N 29 42 4272.67 4203.93 383.42 N 7.70 E 381.94 N 32 36 4375.35 4306.61 445.45 N 8.40 E 443.40 N 35 42 4453.96 4385.22 498.73 N 8.70 E 496.1.3 N 38 24 4527.38 4458.64 554.14 N 5.80 E 551.1,1 N 42 36 4598.09 4529.35 614.50 N 9.60 E 610.94 N 44 J8 4643.82 4575.08 657.76 N 9.00 E 653.69 N 46 42 4730.73 4661.99 746.09 N 9.00 E 741.04 N 48 48 4820.15 4751.41 844.38 N 9.90 E 838.15 N SO 0 4919.71 4850.97 960.36 N 9.00 E 952.73 N 51 12 5019.36 4950.62 1081.53 N 9.00 E 1072.56 N 52 0 5088.31 5019.57 11.68.45 N 8.00 E 1158.59 N 53 12 5183.67 5114.93 1293.12 N 7.90 E 1282.11 N 53 24 5239.25 5170.51. 1367.62 N 9.00 E 1355.87 N 52 54 5294.42 5225.68 1441.15 N 9.20 E 1428.56 N 51 12 5389.74 5321.00 1563.22 N 8.90 E J. 549.26 N 49 36 5533.15 5464.41 1736.41 N 8.60 E 1720.60 N 0.00 0.03 W 0.18 E 1.83 E 4.81 E 6.14 E 9.17 E 12.75 E 16.51 E 21.27 E 27.00 E 34.36 E 43.05 E S0.98 E 57.97 E 66.06 E 73.06 E 86.9O E 103.06 E 122.13 E 141.11 E 153.97 E 171.22 E 182.18 E 193.82 E 213.04 E 239.42 E 0.00 0.97 5.04 1.4.27 32.49 47.09 92.20 153.39 215.89 272.20 324.39 383.49 445.48 498.74 554.15 614.S0 657.76 746.I2 844.46 960.53 1081.80 1168.78 1293.49 1368.05 1441.65 1563.84 1737.18 0 0 0 N 2 0 0 W N 2 2 9 E N 7 23 16 E N 8 30 59E N 7 29 14E N S 42 25 E N 4 45 SgE N 423 7 E N 4 28 53 E N 4 46 26 E N S 825E N 5 32 44 E N S 51 60 E N 6 0 18E N 6 10 17E N 6 22 39 E N 641 17 E N 7 0 36E N 7 18 18 E N 7 2':2 42 E N 734 12E N 7 36 23 E N 739 9E N 7 43 3SE N 7 49 47 E N 7 55 18 E SOHIO S-J. 6 DOG -i~G deg/].60 0.000 0.000 0. 726 1. 626 2. 160 1. 561. 2. 022 1. 827 1. 542 1. 334 2.315 2. 260 2 ~3 3. 265 3. 177 4. 889 2. 738 1. 935 I. 625 O. 857 O. 764 0.912 O. 765 O. 792 0. 561 1..103 0.7_15 -.16 RECORD OF SURVEY , 7-30-84 4EAS DRIFT TRUVERT SUBSEA SECTION )EPTH DG MN DEPTH DEPTH DIST DIRECTION RELATIVE COORDINATES ANGI._E FROM WELL-HEAD 6507 46 36 5738.82 5670.08 1965.42 N 8.80 E 1947.18 N 6728 44 42 5893.30 5824.56 2123.38 N 6.50 E 2]03.79 N 6848 44 24 5978.82 59~0.08 2207.56 N 7.60 E 2187.34 N 7064 43 24 6].34.46 6065.72 2357.32 N 5.60 E 2336.1]. N 7285 42 36 6296.08 6227.34 2508.03 N 5.30 E 2486.15 N 7499 41 30 6454.99 6386.25 2651.33 N 5.10 E 2628.89 N 7721 40 12 6622.91 6554.17 2796.53 N 6.80 E 2773.31 N 7939 40 24 6789.17 6720.#3 2937.49 N 8.30 E 29].3.08 N 8095 40 6 6908.24 6839.50 3038.24 N 7.40 E 30].2.93 N 8282 39 18 7052.12 6983.38 3157.6]. N 9.20 E 3].31.12 N 8439 38 24 7174.38 7105.64 3255.95 N 9.30 E 3228.32 N 8508 38 48 7228.31 7:1.59.57 3298.97 N ?.50 E 3270.91 N 8572 40 :1.8 7277.66 7208.92 3339.70 N 8.00 E 3311.29 N 8634 42 24 7324.20 7255.46 3380.63 N 9.00 E 3351.80 N 8666 43 :1.2 7347.67 7278.93 3402.36 N 7.50 E 3373.31 N 8725 43 48 7390.47 7321.73 3442.95 N 8.70 E 3413.52 N 8820 43 42 7459.10 7390.36 3508.56 N 9.50 E 3478.38 N 89.1.3 43 36 7526.39 7457.65 3572.66 N 9.00 E 3541.74 N 9039 43 30 7617.7]. 7548.97 3659.27 N 1]..]0 E 3627.22 N 9:146 45 42 7693.89 7625.15 3734.33 .N 4.20 E 3701.63 N 925# 45 36 7769.39 7700.65 3811.39 N 1.00 E 3778.77 N 9505 45 6 7945.78 7877.04 3989.53 N 3.60 E 3957.18 N 9725 45 0 8101.21 8032.47 4145.06 N 3.60 E 4112.57 N 9887 45 6 8215.66 8146.92 4259.57 N 3.10 E 4227.02 N 10~.63 45 6 8410.48 834]..74 4454.83 N 3.70 E 4422.18 N 10478 43 6 8636.68 8567.94 4673.93 N 5.30 E 4640.70 N 10648 41 6 8762.81 8694.07 4787.80 N 10.60 E 4753.53 N 274.09 E 295.:1.2 E 305.46 E 322.67 E 336.98 E 349.97 E 365.03 E 383.55 E 397.32 E 414.56 E 430.39 E 436.68 E 442.17 E 448.23 E 451.35 E 457.07 E 467.46 E 477.78 E 492.93 E 502.92 E 506.42 E 513.59 E 523.37 E 530.07 E 541.66 E 558.86 E 574.62 E CLOSURE DISTANCE DG MN S 1966.38 N 8 0 45 E 2124.39 N 7 59 8 E 2208.56 N 7 56 59 E 2358.29 N 7 S1 5] E 2508.88 N 7 43 9 E 2652.08 N 7 34 59 E 2797.23 N 7 29 54 E 2938.22 N 7 30 3 E 3039.01 N 7 30 44 E 3158.45 N 7 32 32 E 3256.89 N 7 35 37 E 3299.93 N 7 36 15 E 3340.68 N 7 36 22 E 3381.63 N 7 37 I E 3403.37 N 7 37 .1.5E 3443.98 N 7 37 36 E 3509.66 N 7 39 15 E 3573.82 N 7 40 58 E 3660.56 N 7 44 20 E 3735.64 N 7 44 14 E 3812.55 N 7 37 60 E 3990.36 N 7 23 42 E 4145.74 N 7 15 9 E 4260.13 N 7 8 51 E 4455.23 N 6 58 60 E 4674.23 N 6 52' I E 4788.13 N 6 53 33 E DOG LEG deg/JO0 0. 975 1.002 O. 7 0.516 O. 667 0.303 0.307 O. 576 O. 574 :l. :177 2. 366 3. 466 3. 328 1.408 0.416 0. 277 0. 794 O. 557 O. 0~5 O..167 O. 109 O. 678 I. 789 16 DATA INTERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH EAS. EPTH 0 100 200 3O0 400 500 6O0 70O 8OO 90O IOO0 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3103. 3202 3303 3405 TRU VERT DEP'fH 0 100 200 300 400 500 600 700 800 900 JO00 11.00 1200 1.300 1400 1500 3.600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 SUB SEA MD-T\/D VERTICAL DEPTH DIFF. CORRECT -69 0 0 31 0 0 1,31 0 0 23I 0 0 331 0 0 431 0 0 531 0 0 631. 0 0 731 0 0 831 0 0 933. 0 0 1,031 0 0 1131 0 0 1.231 0 0 1331 0 0 1431 0 0 1531 0 0 1631 0 0 1731 0 0 183J. 0 0 1931 0 0 2031 0 0 2131 0 0 2231 0 0 2331 0 0 2431 0 0 2531 0 0 2631 0 0 273J 0 0 2831 0 0 2931 0 0 3031 J. J 3131 2 J. 323J 3 J 3333 G 2 REI_ATIVE COORDINATES FROM WELL-HEAD 0.00 0.00 0.00 O.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 O.OU N 0.00 W J..02 N 0.04 W 4.08 N 0.37 W 3.0.28 N 0.78 E ]9.90 N 3.00 E 32.49 N 4.85 E 48.40 N 6.26 E 67.88 N 7.63 E .16 DATA IN'fERPOLATED FOR EVEN 100 FEET OF SUBSEA DEPTH 7-30-84 ~EAS. TRU VERT SUB SEA MD-TVD VERTICAL )EPTH DEPTH DEPTH DIFF. CORRECT 3507 3611 3?]5 382O 3926 4033 4142 4254 4368 448E 4609 4739 4879 S026 5179 5335 5496 5661 5828 5990 6147 6299 6449 6595 6737 6877 7016 7154 7290 7425 7559 7691 7822 7953 8084 3500 3431 7 2 3600 3531 ~.1 4 3700 3631 15 4 3800 3731. 20 5 3900 3831 26 6 4000 393~. 33 7 4100 4031. 42 9 4200 4131 54 12 4300 4231 68 14 4400 4331 86 18 4500 4431 J, 09 23 4600 4531 ~39 30 4700 4631 179 40 4800 473] 226 47 4900 4831 279 53 5000 4931 335 5~ 5100 5031 396 61 5200 5131 4~ 65 5300 523] 528 67 5400 5331 590 62 5500 5431 647 57 5600 5531 699 52 5700 5631 749 50 5800 5731 795 46 5900 5831 837 42 6000 5931 877 40 6100 6031 916 39 6200 6131 954 38 6300 6231 990 36 6400 633J ~025 35 6500 6431 1059 34 6600 6531 1091 32 6700 6631 1122 3~ 6800 6731 1153 31 6900 683~ ~.]84 3~ RELATIVE COORDINATES FROM WELL-HEAD 90.62 N 9.10 E 116.79 N 10.67 E ]45.76 N 12.35 E 177.83 N 14.10 E 212.48 N 15.83 E 251.02 N 18.35 E 294.26 N 23.62 E 342.89 N 29.20 E 397.81N 36.48 E 459.49 N 45.41E 530.16 N 55.63 E 612.70 N 66.36 E 709.75 N 81.94 E 816.15 N 98.33 E 929.86 N 118.47 E ..... 1049.11N 137.40 E 1173.62 N 156.08 E 1303.81N 174.]7 E 1435.70 N ~94.97 E J561.64 N 214.98 E 1681.33 N 233.45 E 1795.43 N 250.69 E 1905.32 N 267.09 E 2009.71N 283.26 E 2110.36 N 295.87 E 2207.71N 308.12 E 2303.36 N 319.33 E 2397.22 N 328.60 E 2489.70 N 337.31E 2579.83 N 345.57 E 2668.04 N 353.31E 2754.14 N 359.54 E 2838.20 N 372.36 E 2922.18 N 384.8? E 3006.03 N 3~6.#2 E -16 DATA INTERPOI_ATFD FOR EVEN J O0 FEET OF 4EAS. TRU VERT SUB SEA MDLTVD VERTICAl.. )EPTH DEPTH DEPTH DIFF: CORRECT 8214 7000 6931 1214 8343 7100 7031 1243 8472 7200 7131 1272 8602 7300 7231 1302 8738 7400 7331 1338 8877 7500 7431 1377 90J. 5 7600 7531 1415 9155 7700 7631 1455 9298 7800 7731. 1#98 9440 7900 7831 1540 9582 8000 7931 1582 9723 8100 8031 1623 9865 8200 8J, 31 :1665 10006 8300 8231 J706 10148 8400 8331 1748 10288 8500 8431 1788 10427 8600 8531 1827 10563 8700' 8~31 J863 3O 29 29 3O 36 39 38 40 43 42 42 41 4J. 42 #0 39 36 SUBSEA DEPTH 7-30-84 RELATIVE COORDINATES FROM WELL-tlEAD 3088.80 N 406.#0 E 3169.42 N 420.75 E 3248.48 N 433.5# E 3330.56 N 444.80 E 3422.54 N 458.44 E 3516,90 N 473,80 E 3611,02 N 487.70 E 3707,87 N 503.37 E 3809,87 N 506,85 E 3911,13 N 506.51 E 401J,41 N 517,00 E 4111,36 N 523.29 E 42JJ.34 N ~2~.2J E 43JJ.54 N 534.45 E 4411.78 N 539.15 E 4509.72 N 546.84 E 4606.11 N 55J.40 E 4598.32 N 562.86 E DATA INTERPOLATED FOR EVEN 1000 FEET OF MEASURED DEPTH 7-30-84 MEAS. TRU VERT SUB SEA DEPTH DEPTH DEPTH REI_AT IVE COORDINATES FROM WELI_-~IEAD 1000 1000 93]. O. O0 O. O0 2000 200-0 1931 O. O0 O. O0 3000 3000 2931. ~,0.25 N 0.78 4000 3970 3901. 238.62 N 17.81 5000 4783 47:1.4 796.98 N 95.50 6000 5406 5337 :1569.;::2_5N 216.17 7000 6088 601P 2292.25 N 318.14 8000 6836 6767 2952.17 N 389.13 9000 7589 7520 3601.08 N #86.41 10000 8295 8226 4306.96 N 53Z~ · 22 8763 !8637 2673 _79~ 76~8 . 7t74 573g 5533 ~ s~o ~ ' 4731 45~7 ................................................ : ................. ~273 ............................................... 3908 August 24, 1984 Mr. 3ames A. Bragg Sohio Alaska Petroleum Company Pouch &-&12 Anchorage, Alaska ~502 CONFIDENTIAL STATE OF AIAS COPt Re: Our BOSS Gyroscopic Survey Job No. AK-BO-4OO&8 Well: S-I& (SEC55 T12N R12E) Prudhoe Bay North Slope, Alaska Survey Date: August 16, 1~84 Operator: samec/McGuire Mr. Bragg: Please find enclosed the "Original" and sixteen (16) copies of our BOSS Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Kirk Afflerbach Di strict Supervi sot Eno1 osures REC .'iYED $~P 0 $198¢ Alaska 0il & fias C~qs 0 .... ,- :E;PERR¥-~LII',J_WELI_ ;r.,_IRUIE'_¥ZN,G C:OMF"AKI¥ rqNF:HORAGE ALAE;KA SOHIO ALASKA PETROLEUM COMPAIqY ~i~__i.~EC 35 T12N_B. '.~ ='RUDHOE BAY ALASKA COMF'.LITA T Z FiN _.O.g~]'LE.. ~ ~ AUGU'7;T' 17, 1984 CERTICAU SECTION CALC:ULATED ALONG CLOSLIRE DATE OF SURVEY ALIGUST 16,:, :1.9E;4 :L__::: / 4._LELL~i:d.! ]' 0 R JG2~LO ...... ,_lOB NLIMBER AI<-LB-'l. 006, E: KELLY BUSHING ELEV. = ,"_-,7.12 FT. _.. J~'.E~~_B~:tMEC/JdCG U I F~ ............ TRUE .:, _IF..: -.=,E A ~EA.;.,URED VERT I CAL VERT I _.AL. DEPTH DEPTH DEF'TH COLIR.'F_;E I NCL I NAT I ON DEG -MIN F: 0 U R :::; E _,[) 0 G.- L E G D I FREC]" i F-d',l :.-.-.;EVER I TY D E G R E E S FI E ~"'~ / 100 'TOTAL___ RECTAI',JG UL At:;; c:00RD INA ]"ES I',[ (] R ]' H / S El 1_i T I"t E A S T / W E.:, ] VERT I r'::A L / · :,E ,..] I 0 0.00 -6.7. 12 100 100 00 .:?-z, ::, 2(.')(.') 2(7)(_] (')0 1'-"-' ':":' C) C) cz) ..:, =. 0 25 N O. C) E ('.).0C) N 59.89 E 0.42 hi 4'.-:;'. 8C) E C). 0'7 0.00 C). 00 c). (')C) 0 1:5: Iq 0 :'::2 E (') '-"-' 0 .... ,"-,C.)iq 0 91 F..-. ( ...... ). / ..:,' 300 299.99 232,87 400 399.99 332,87 500 499.99 __4~2_.87 600 599.99 532.87 700 699.98 632.86 800 799.98 732.86 0 0 0 0 C) 1.07 N 1.02 E C).93 N 0.81 E ~..;~J.&_.l..q. ........ :_ .......... '_.L , O'_,E .E_ ........ ("), C.)2 .S 1 · 04 E 0,:::/2.,...,':' 1, ~..,:, E 0.8:3 S 1..7:3 E_ 1.2(]) 1.04 ......... _CJ... DJ:L! ........... 0. ~ 4 - C). 2C) -C). 56 90(7.) 1000 1100 1200 1300 1400 899,98 832.86 999,,' 98 932.86 109'.-"], 97 . 1032.85 1199.97 11 :--:2.85 1299.97 1232.85 139'?. 96 133'_2, 84 1500 1499.96 I432.84 1600 1599.95 1532.83 1700 1699.95 1632.83 1800 1799.95 1732.83 1900 1899.95 1832.83 0 1 'P. · N .:,'-'. 60. E 0.68 C) 19 N i i. 60 E 0, 0=''.::, -_ .-,~....,_.~-..'.:,_i_ E . . O, 61 C) .-,r= 0 ':2,:4 '.~; ::;:_:-;__.,~.),. W_ O, ;I, 4 0 30' '-' , · =,15.60 W 0 19 O' 19 S :2:.6,0 W 0·i9 19 . S 4. :2:9 E .. 0. o' ._.=i, · -.._., '._:; 1 · :'::':~ E 0. '::.,.:5 ::-.; E;. 5(') E 0, C.)5 :~0 ',S 61.60 E ' 0,4-;2 .¢.._, 1"4 ,::...- .'-"-' :z:C) E 0,69 0 1C) S 45, 19 · 0. 15 .q '-"-' nO , , , -.,. ',.¢;,,,=,.~ . 0 40 N 2'9. :--;9 0 30 N 18 · 80 C) 34 N 12~69 N 'i 0,.60 .E- N 14,'60 E N'.: 11,60" E 2100 2200 2300 2099.94 2032.82 2199.94 2132.82 '~'~--C 94 '--"-"-"--'1~"--' 2399.93 2332.81 2499 93 '-''~'-' .. ~4.~.E:i 2599.92 2532.80 2400 '2500 26C) C) 2799.90 2899.82 0.79 :.:; 0. '7., "7., 0,,1.:~ ~; ., C).45 F-; 2.44 E 1. 00 ._.'::' 1 . /:..'~ E · ,:,..., :~;; :t,, 01 F - ":' 69 '::' 0.6i E 3·-40 S 0.4.8 E 3.97 '.--; .-) o /I-.63 S 0.5I E . ..:,._, S 0. :5::: E 5,'?:;;:: % ~ ;L,O1 IE 5 · 79 '.:::; 1,54 E S i.57 E S____ 1.57 E S 1.97 E W O' 58' 5.56 E 0,, :26 ~. r-..': ,:,.=, . , 'J- ~t, E 0. F-;::: 5.5-~ E E ('). 20 4.. 62 ::-:; 2.40 E C) 1 (:) "" 7 J, S 7,/-,!=i P' # '"~ w ..... , ~.'- S '-' "W: ~ ,~... .~. '-- '" E ,~ :. ,i11] . d,..,=,4. 1.02 S 3.26 E · 1...=_';0 "-"~/;,7 Iq 4 09 E .-- ,.~ , . ~,, · 2, 02 E - 0.49 - 2. O':T,' E 0,09 _ '-.2.~_&Z_E 0.24 -C). 0 -(:). ~":i- -;L, ':-ii:..: .. -2.57 -3.29 - :_::. ::: 6 -4.5() -.-5.21 -5.7 !, -5.50 -5.27 -5.56 _ -.J. 19 ~ .=" 'F .~i 'L], _ -'~' 27 ':3.24' _ _ SOHIO ALASKA PETROLEUM COMPANY S,!6 (~FC 35 T!2N R!2E) PRUDHOE BAY ALASKA SF'F_~RY-:::UN WELL SURVEYING CC, MPANY '" I ....... ' ] · ~I',I,I-IL~KAL E ALASKA IlIA T E OF' SUR V E Y A UIDUS "1' 1 A, CO!']PIJTATIni'q DATE ' 1 :]:/4. Li:'EVEF? RO'i'C':F~ G'¥'PO AUGIJ'ST :t 7. 1984 dOB NI_IMBER .: A'K-.L.B-40068 VERTICAL SECTION C:ALCULATED ALONG CLOSURE KELLY BUSH IIqG ELEV = 67.1'-:' FT 0 P E P,A ]_" 0 R-L=; A M [; C / M C A I. I ! P F: TRLIE __ :F:I IB=S;FA .... COUR.t=;E ~.:~' MEASURED VERT I CAL VERT I CAL I NCL I'NAT ION D I REC:T I'ON DEPTH DEPTH DEPTH DEG :. MIiq DEUREE~, ~] 0 G- L E G 'SEVER I TY DEG/100 VERT I CAL SEC T I F'll . ) 3000 2999.57 2932.45 5 0 N 12.50 E 3100 3099.0~ 3031.97 6 4 Iq 10.50 E 3200 3198.27 3131~_L5 ........... ~: ..... ~.~3 ........ ~J_~,,6C!.E_ 3300 3296.93 3229.81 10 i9 N 3.50 E 3400 3394.96 3327.84 12 19 N 3.60 E ~L~¢! 0 2492. 3800 3589,00 352~.88 15 34 tq 3.60 E 3700 3685.23 3618.11 16 0 Iq 2.60 E 3800 3780.8~ ~:713.77 ~7 49 .... lq__.~A~__. 3~00 3875,64 3808,52 19 25 Iq :3.60 E 4000 3969-48 3902.36 21 0 N 4,60 E 2.08 1.10 _2,54 1.92 47.67 Iq 9.o3 E 2.00 67.2'2' N 10.84 E Z_._&,.:?L .......... ~;.'.{):~.Q.i_J'4 ................. 12 ·_0~_ E_ .......... 1.60 li5.'.=;0 N 13.46, E C).50 142.67 Iq 14.92 E 1.85 1Z_.t. 7 i_ }J ................. 1A,_D i 15.9 20 '-' 59 - · ._-,. N 1 a:.._':';... ':' E 1.62 238.04 N 21.00 E 116.22 .1. 4:2:. :2:1 ;LTJ. E:. :28 ..... 204.1, 0 .~...9,2.~.._ 4200 4152.52 4085.40 26 10 iq 6..'_'-,0 F-' 4300 4241.01 4173.89 29 19 lq ::::. 50 E 4400 4327.27 4260. I5 31 25 N 8. A9 E 4500 4411.0:;: 4.:,4,:,. 96 34 40 Iq :3. F:;'-} E 4600 4491.54 4424.42 39,,:.- 10 N 9. . 0 E 4700 R ,-, .~.o - 4._ 6 o.~, ~ 4501 . -~' F) 41 3 ('). N, 9.. E;. 0 E 4E:00 464i.59 4574,47 44 1.5 N 11.:39 E 4-'P00 4.711,9:::. _ 4644. ,:,'-',_-,' 4/-,_ 15 iq 10.. 69 E 5000 '4779.91 4712.79 48 10 N 10.60 E. :31 '7 o,::'. 364. 1('~ Iq ;1.14.08 N 24.72 E 2 ,-}..._F, 4 E :31 ::::. 8 ._, ~= :::5 70 E '-' ':q ._. · .:,/_- .... ":: 9 4:F:L,_2 &, ~'] .....415.9 470.4.7 '='-'"'] 8:":: · J .,:Z :' . ~'-]":' ~., f'~' 1 ,-, I:.':' 7:32.78 806. i 0 46,7.96 Iq .="; 1. d, 1 E 526-,. 6,:") N 60. :2:4 E · _,,:, ;,.N 71 :2:...2 E A56. '~':' c...:, N :3:::. :::6 E / .'c,.:2:4 N 97.46 E 7'--~.. :::_. 45 N 111 . 02 r-_ 'q 1F~O 4:::45 ..... --,4 4778.71 49 1 '-;' 5200 4910 ·,-65 4843. 44 50 0 ?]'-' ' ' '- '- 4907.21 F, ' ._.:,oo 4.':)74 · ..:-~,:: ,_ o 4._=; N 9.80 E N 9.69 E N '.?.5C) E tq ?. 1 '.:) E N 9.60 E . N 2,39 E N 9.69 E N 8.50 ]E · 5400 5037.04 4969.92 51 34 5~C)0 ='"'--~'-' 52 .... ,,.,; ,:,. E, 1 F,C)':: 1 48 '-'= 5600 5159, 07 50':.'~1,95 _ 5:3 10 5700 5218.55, 5151.43 53 49 5800 5278.27 5211.15 52 49~ ~ O. 0.77 O. 6:6, 0.90 O. 77 O. 70 1,3'F/ E:72. "!.4 N 124.33 E ::~:---: 1.24. 947.5'7 lq 137,24 E 957·45 C)2:3.51 Iq I50.0E: E 1034.,46, _ _ I Cx"~. :2,'7 N :l 6,2.7:_:: E 1112. :2,4 17:--:. 1 1 lq i7._-q. 6,1 E 1 i91.13 256. ~,-'.~, !~_______i. S:i.::..-z':.'-'; F' .s,-'n 7L-, ~ 3:35 '~'":' N '-,c '-, .: .~ .'. 0':,-/ E i ':' ~ 1 i :2: ,. ~..i · 1415. 13 N 214 . -;'::' E. _, 1431 . '-'""._',~; 1510..~.5.7__ ,) SOHIO ALASKA PETROLEUM COMPANY S.~6 (SEC ~5 Y12N PRUDHOE BAY ALASKA Y-dlLDL~ELL_~IJ~ COMPA~Y _ . ANCHORAGE ALASKA [ R ] E 0 F .::, _ R V E ~' A U F:il_ _1'.=:_ T ......... ~ME~.t]'_(CEIL-IN .~'l'L 1 3/Z..LLEVER F:OTC:F.' GYRO AUGUS]' 17 ~ i 9R4. _ .:.iCIB NI...tMBER HK-L..~5-4" ..... (JOoo-' VERTICAL SECTION CALCULATED ALONG CLOSURE PALE ._,, 1 KELLY BUSHING ELEV. = 67.12 FT. ........... u ~E~.I:!J[z~-.~.~MEL:z. L~~.BE_ ............. MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH I NCL INA]' I ON D I REL.] I ON DEG M I N DEGREES DC.3-I_EG ~ .... .:.EVER I TY RECTANGLfLAR C:OORD INA TES VERT I C:AL I'" "[ " ~" I--.' ~--' --*' DEG/100 NOIRTH/.z,L LI FH E~4.:, F/WES]' .:,EL. FION 6000 5401 29 =""-' . ._,oo4.16 6100 5464.45 ~oy7F,""- '. b:Z-' - 6200 ='="-"-' "' =' · _,._, ..' ,=,..';._, 5461. ,:,.:,'-"-' 51 19 N '7.89 E · .0 19. N ,_,. 0 E 49 i'P N 8. 10 E . ,:,.,: 1571 i:=: N ...""'".:,7 ' "" . c,,:, E i ':"-"- ,, ..1 ,=, ;/ 1,00 1647 .91. 1'4 24F-: .40 E 1666 , ._,-~':' 1,00 172:3, [5'7 N "25'.:.~, i 0 E 1742, ':'-,/:}.", 6300 5594.78 5527.66 4-8 19 6400 5661 . 96 5594.84 47 15 6500 __~..__7_ 30, 27 .... 5~t~...._ ;!,_~ ............... __4/__=, 34 6600 579'P. 42 57532. :30 45 55 6700 5556~. 45 5802.33 45 10 6800 5940.41 5873.29 44 25 AgOF) 6011 · :.~9 ,., .~44.87 7000 6084,07 ' ..:: ]601'6, 95 7100 61565 71 ' ":'.':'"~08'.9.59 7200 6229. --'F . ~.) 6,162 68 7300 6303...:,'-"-',:, 6236 .26 · 7400 6377.45 6310..'_--:2 7500 64~,~.10 A384_ . eA.. _, 7600 6527.57 6460.45 7700 6604.''~ =~' 6~,~6, 7800 6680.63 6613.51 7..-,OL 6756 86 66c.;,. 74 800C) 6833.1:9 6'766.07 4. 4 10 4;:-: :34 4.3 15 42 42 42 41 40 39 25 34 40 4(') 40 4() 19 19 10 7.80 E 0,, '""' 1..~ ,:, , ,:,, 10 rE 0.7L=: :::.46 E 0.79 8.10 7./:,0 7,19' 6. 7.10 6.60 6, 80 8.50 10.10 N N Iq N 10. :_::0 N 1 1.89 N 1 1. :::'F.~ E 0 '-'F, E ~ 0,68 E _ 0;, 4.:: E 0.50 E ~ 0.46 E ~ (') ?,4 E ~ .0.60. E ~ 1" 4 ~~ E ]12~ 1 ""-' ..... ,,, E r'-,,,,- 0.67 E 1,04 E 0.1 ,":., 2015.54 N 298.39 E 2086.2:3 N 308.26 E 2155, ?/.';, . :N .............. .:-'_3_._t_ ,'.:!.._..'-jr 51 ..... E 2225. o6 Iq .328.47 E · 22'73.72 N 337.';73 E 2361 ,_E:Z_ Iq :_=:;~!.-7'.'? ~,~ :;2429. 652' N '-'' '-' 84 · .'4 .';o. N '-"--; ':' 54 N ,,' .._i i'"~ ._, # 262.':?. 62 N 2694.64 N '2758.23 N "355· 1 i E 5365=:. :=50 E 371., 31 E 379.07 E 387.80 E :=:'P 8. ']20 E '?'"]'.-' i 4'? N 2884. 'F"=.-~ N 2948. :22 N 407.59 E 4.22.05 E 4.:-_.:37 E 2 053'7.51 .... 108.89 217'P. :34 2656.78 2722.37 27L=56.80 '---":' ?] 1 05 ~ m_m ._ · 2'P15.69 2980.1 '.-} 8100 6909.70 6842.57 8200 6.986.58 6.919.46 8300 7064.06 69.96..94 8400 7142.19 7C 7._,. 07 ::5500 ......7220 1:5: 71 .S'-'._-,. O1 8600 ~'-":~/- .,..' :: o · 16 7229.04 40 0 · .... ..=, (.) 38 55 N 1i.19 E ':.'0.'48 N i1·30 E 0,50 N 10.60 E 0.77: N 10.80 E 0.60 N 11.6'? E 1.08 N 12.60 E 2.57 3:_=: I 'P 39 15 41 4.5 ;2:011.30 N 3074.02- N 31 :_--:6.08 N 44:3.26 E 460.74 E 472. ' .~] 7~ E :3 044.4::: :31 F)P,. '"'= . _ ..=, 53171.50 3197 ' '-' .4~. N · --, ---, r'.'.'.'.'.'.'.'.~ ,'% ,-~ ~ · :..,::,.J o. ,:,.J N :=::322 ,. :3:3 N 484. :_::4 E 4-'P/_.",. :56, E 510. Z-:4 E :3253 :=:. :;:555 32"P6.44 [211 [:: ~I 1. :24 8700 7369,4~ ,,-._., '""-' 0"'"..,::;, ,...15"4 8800 7441.52':. 7374, 4.0 8~700 751 ''~ o, 71 7446,,-'F,~?.. 44 O: 43 5 '" 43 49 N 1 '_T.' · .,. ~.'~. E .~.,'-' 2A 12.30 .E 0'.48.' ;L.2,30.:.E . . : :'0.08 ._,~.._,, 26 E 540. 5353 E SOHIO ALASKA PETROLEUM COMPANY S-16 (SEC 35 T12N R12E) PRUBHOE BAY ALASKA ~E_~.~.~_~],~,I. N WRLI__l_ EiLIRVFV T NG F':I]MPANY ANCHORAGE ALASKA ('iCIblPIJT~i~ CiN DATE AUGIJST ~7, ~984 .. VERTICAL SECTION CALCULATED ALONG uLU.=,LIRE PAG~ 4 .... BATE OF SURVEY ALIGUST 16., 1984 I :7~/4 I F:_~)FP RCTi'iR t':.~YPCI dOB NUMBER AK-LB-40068 KELLY BUSHING ELEV, = /.-,7.12 FT. OPERATOR-SAMEC /MCGL! I RF MEASURED VERT I C:AL DEPTH DEPTH ~-_.'-~E A .... JCLO U R S E ....... CO U R $2E ........... I:ff] O--. I-.EG . · :,EVER I t Y VERTICAL INCLINATION DIREF:TION " ......' "' DEPTH BEG M l N DEGREES DEG/100 __]:B.]."~I, RECTANGLII_AR F:OORD I NATES NORTFi/SOLITH EAt., ] ~ WE.:,T VERTICAL x, SE C T I F'It .. ) 9000 7585.7:-? 7518.67 43 55 N 13 · 0 E O. 4':} 3591..56 N 570 · 3(] E 36:36. :'-':7 .9100 7657.21 7590.09 44 55 N 10.:::0 E 1.84 :'::660.03 N 584.72 E ::-:706.21 ..'9200 77~7.70 76,60,. 58 45 30 N _4. :'::':} E 4.58 37~:,,_:..:;;[. N ............ ~'4, 07 E _:. _37_77_.__10 9300 7797.75 7730.62 45 34 Iq 2.8C:, E 1,14 3801.54 Iq 598.5'.5 E 3848.22 9400 7867.79 7800.67 45 30 N 2. :-qO E O. 37 :3872. :34 N 6,01.73 E 3919.2I · =" ] ......................... 60_.4... ~_£ ':' ':> ::: '~' ':~ 1 ................ .......... ~OO_ ...... _Z_..~3:~ ....... _7._870,..~6 .............. _.,$5 ..... 1~. ........ tx] .... 2 .... 10 E_. O'x'":6 .'.:,,:)z~ :, ,:~ ~u .... · ,;Z~,....]' t.,,.~ .,,_ .,'...,- -. ~'~ .................... .~Z ,~ '...~.. ,'. .96,00 8008.74 794 i. 62 44 55 N 1. :s;9 E O. 2;:} 4014.6,3 Iq 606, 9:3 E 4060.2:3 9700 807.9.50 _~800 8150.47 9900 8221.49 10000 8292,10 _ 10100 8362.45 lo~.)u 84:=:~ 00 10300 8504.07 iq 1.80 E _BI ....... .~Z.~ E °154. :-':7 44 ~"'= o,., N 2 'mi E i~i · _~ ") '-, ..'! ~----- '~"~ ' '- - 0 ' ,;,-..~-~. ~,_~ 45 1. 5 N ..:~. A'..T~ E ~--~.--~ ~.'"! ~ .--,--, . · ~ ......... ,=,..' .~ ;.z,,_.-',,:, 4.~, i9 N. :q,~O_E_ .... ,-,.-, / .-r5 ,:, c, ~ ~ - - ,:,.:,= .......... 44 ._-., N 2. ~:~':~. E ,'_-q4:E:6. 95 .44 30 Iq :3, 10 E 0 ~' ' ,--,, 1 '-' .,_,' .~_~, V_ ~,_,..c,_ _. 42. ~ bC. _4.,. 6'?_ ._F 10500 864.9 -,'"' ,-,.~o--, . & ,:, o._ ~.,..'. 51 42 40 N 8. 0 E 27 "~ .~ 62 40 '-' ~= 10600 8723 · 75 ,:,6._ 6. 41 N 11.50 E ,~ ..... , ,~ .-, ~_ 10700 87.98.87 ,,7._-,1.75 4.0 ,.._, . N .14.'::'.~.. E 2.06 · _ . ._ 10800 8874.15 8 :--: 07.0:3 41 '.F' 5 N 14 ::~'~ E 0. ~ ' 1. 0900 8949. '-'" . · . ..'d P, 882 16 4::1_ 10 N 14.19 E 0·28 1 .~0 L'L__ 9024.41 . . ..E: 957~L__ 41 '"'. ' 5 N 13. :::'P. E 0. :--: 2 __ 11100 .9099.16 ~032.04 4.1' 49 N 1. 3.6':} E 0,. 4':-'._, 11150 '~136.37. 9069...-._,'-'= 42' 0 N 1:3.60 E 0.3,'"-, 11E:OC~ 'P247.84 ':} 1 :::0.72 42 0 N 1 :E:. 60 E 0.00 0,11 4085.26 N 609.21 E O, ~ ..415.~i.., 64 ' B._ ..... A_CL2._i_/~_ F 0,60 4225.96 Iq -615,4i E 1,05 429,'.-,. ,'..,8 N 619.12 E 0.16_ ~.'~6, O_.l.xj ........... _.&,'2:~;.,_58.__E ......... ..:,/,. , ,. 0.5':} 44:::::: ......N 627.54 E O. 4.4 4508,61 Iq ,'2,31.22 E · ,-,, ,=.-,.-., ,.-.,.:.., , · .-,~ ,--/ . ..l_,,.~:~ ...... &,=.z_z. .... ,_.-..__.[:,l .......... ~a ......1._.F 4645. 13 Iq 643.42 E 4711.27 hi 654.76 E 477D_.~?,.LN____ /- ~ ,-'., ..._~.,0 ;L~,: ~.. ,E 4 8:3':}. :32 N ' '-' :~ 'P c,,:,._, i E 490:3.27 N 702.21 E ¢'P6~TL_ _N _ 718.23 E 50:31.E;0 N 734.,07 E 5064.26 N 74~.95 E %OE~ ,78 _N ............ ~4.E< 516,1.8~ N 765.56 E 4130, 4 :::: ,~.cj_,~L ..... 4270.5'.--. ' 4341.02 _,.:L4_i.:!..,_8.3 ....... 44,:,'-' .--"". 40 4552, 4:3 · ~, .-~. .-.r' , ':1:~~ ,~t ..... 4 :,,:, :.' 27 4756. :_::5 4:--:22. ! '.-" _ 4887.5 4953.24 501 ::':~. 9 :L 50:'::5.05 5118.31 .... 5.151.. 63 '--i':.' 1 F:: '-' l- ' ':' T'i~I"~ .")/- ~.,ITIxl. EA'.E;T ¢ ,,"'r; = j._l'::('~C:, ~.-.,.l,:, 27 FEET AT NJRTH .... -,, ~__.,.,.~u_~3..TL_[d ...................... HORIZCINTAL DISF'LACEMENT = ~.. ..... ,-, THE CALCULATION pROCEDLIRES .ARE BASED ON-':.THE'LISE OF THREE DIMEiqSIONAL RADILIS OF uLRVATURE METHOD. : . __~RY=SUN WELL sURVEYING COMpANy. SOHIO ALASKA PETROLEUM COMF'ANY .DATE OF SURVEY AUGU:--:T S-16 (SEC 35 T12N R12E) COMPLITATION PRUDHOE BAY . AUGUST 17, 1S;84 ,_lOB NUMBER AK-LB-40068 ALASKA F'AGE 16 ~ 1 'P 84 KELLY BUSHING ELEV. = 67.1:.2 FT. _ c~ F__. '.E R A ]]3 R-S~"I E.___'C / I't;.-; ~ INTERFLLATED VALLIES F'OF( EVEN 10C)(:~ FEET OF MEASLIRED DEF'TFt ]'RUE. SUB-SEA MEASURED VERTICAL VERT I CAL DEPTH DEPTH DEF TH · . TOTAL _ RECiTANGI. ILAR L..L-' ]UKD' -" I N~4TE.=,' "" . .,. MD='TVD NORTH/SOUTH EAST. WE.=,T E 1FFERENCE VERT i CAL _. U R R E _. T I 0 N 0.00 0.0c~ 0.00 0 · 2'.} f:; 2.0':7/ E 0.02 O. 02 2000 3000 4000 5000 6000 7000 8000 ::2000 10.000 11000 11300 1999.94 1932.82 5.92 2999.57 2932.45 9.42 3969, 48~ 3902..3_/4= ......... 238, 04 4779'.91 4.712.79 798.45 5401.29 5334.16 1571.13 608.4_.07 ~2~L1.../-:,_.~. .... 22?3, 72 6833.19 6766.07 2948.22 7585.7.~P 7518.67 3591.56 8272. i0 8224. '.~;'8 _ 4296, 68 9024.41 8'.~57.29 4967.29' 9247.84 '.~ 180.72 5161.8 t S 1.01 E 0.06 0.03 lq 5.54 E 0.43 0.3 1,4 ........... ;ZI__.j)_O ~ ~(_;."!.,~2 ..... ~ .................. ~_~Z._.Q'ii;'_ ........................................................... N 111.02 E 220. ¢~9' 18'.:.'/. 57 N 237.68 E 59:--:. 71 378.62 N :.7-.;37.9:}'.: L .... 915. '~:._.:: ............. _:.-".L:!.. 7.2.1. N 4'-'= ;':: 7' - · -',._,. _ E 1' 166. b: :1. 250 ' 8'il) I',1 57c~. 30 E 14.14.21 247. N 4~.!,_?_~_12 E 17'07'. 90 2'F.,'.'3. lq 71 :=:. 23 E 1975.59 267'. N "7'o._~' = .._,6 ~' E ""(' ='-' . ..... ]'HE CALCULATION PROL, EDJREo ARE BA.:,ED ON ]'HE USE r'iF THREE D IMENSIOI~AL RADIUS OF CURVATURE METHOD . SOHIO ALASKA PETROLELIM r'~ _.uMF ANY S-16 (._,E_. 35 T12N R12E) ...... PRUDHOE'~BAY~ · ALAoKA · · ANCHr~RAGE ALASKA CAMP[FI'ATION DATE -' t'-'"" '.'.; 84 AUOL.,=,I 17~, I- D A T E 0 F' F;IJ !:? V E Y A U G I_1S T l/',, 1 '."? L:: 4. AI-...-LB-40 .)¢,c:, ,JOB NLiMBER .... "'c '""' "i : : KELLYoF, E__RA]..bR~tgAi,,if:?::/MC:i:flJiRE;" ' .BUt, HI' "' 'lqr'J ELEV' .... '. = 67, 12 FT. INTERFLLATED VALLE:5 FOI::~ EVEN 100 FEET 13F .:.LB-.:.E~4 DEF'TH TRLIE SUB=SEA :' TOTAL .' .]: :':.:::. :.:' .:.' MEASURED VERTICAL . VERT'' IP.,AL.:,:.:. RECTANL~IJLAR: '~;" ' C:Cu3RDI DEPTH DEPTH · . 0 167 :_--:67 467 567 /-,67 767 867 ~67 .. 1067 467.12 567.12 667.12 767.12 O. 00 -67. 12 .67.12 0. O0 ..... 167.12 100. O0 267.1~'--' 200 C~O. 400. O0 867. ~ 2 "" )'. ,=,L 0 00 · 96.7: 12 ~O0. OO 106 7.1 ':.' 10 O0. O0 1167 1167.12 1100.00 ...... 1267_____~ ...... £2Q0, Oo .... 1367 1367.12 1300.00 1467 1467.12 ......... 15&7 15&7.!2 1667 1667.12 1767 1767.12 (). 00 0. O0 (). 0('~ (),06 .~ ().11 IE 0.00 0 45 N c~ 7':' E ' 0~0¢"~ 0. '-':'.:, ~.':' N 1 1,..,':' E "'.: .' · '0" 01 1 .... ZT_:-bt.. ...... ' '="-' :~ o, ,_~,~i.._E.::' ::' ..._0'. 0 _1 0.4.9 N 0.89 IS ().01' O.OC:~ N 1..~:, E 0 O1 · 0 · '-'"' ........... z._-, 'S .... 0.8:3 E . 0 02 0 6/-, '."4 1.5A E () ' ":" · . . , 0. ()C~ O. 0C~ O. O0 O. OQ O. O0 O. 0(") O. O0 E E l-': E O. O0 O_..£~f.L .............................................. 0.00 0. O0 0.00 "1----- 0 · 01 O.Oi ...... !. O0 O. O0 0.00 SOHIO ALASKA PETROLEUM COMPANY PRLIDHOE BAY ALASKA ~'ERBY-~N_ w F:I t . SU. FZN'E~_CO !"Ii:' AN Y ANCHORAGE ALARK'A ~P__U_]].A]]i.I F'_iN I]ATE A U 13 U ~:;_ T :t. 7 ' 1 '-':-' c,'-' Z.l, PAGE 7 i3A]"E OF SLIRVEY. AUGUE;]" 1x,.:,-, 1 ,_lOB NUMBER AK-LB-40()68 KEL. LY BIJL:;HING ELEV. = 67 1 . .,:. FT. ............. OL? Ei~A~_OE'.~-'_ SAME C Z H C GL!I I FI~E INTERF'OLATEB VALUEE: FOR EVEN l()C). FEE'I' OF .:,L'-' I"'~.{-.:,E.A' ....... Li '-'"'E.I... [ H ] R ..IE SUB-::;EA 'I'~]]"AL "~ "'",, -, -" ~'l~ '' ," .... MEASLIRED VERT I I'":AL VERTICAL REIL, TAI',iL~LILNF, C:OClR'J[I .[ NA 1Eo. ' .: MD-TVD VERT I CAL DEF_'_'!'.H I ' ' '" ,' ' ' F T i -F Ii -,1111 IH -" '"" ....'"' 1867 1867. 12 1R(')O. 00 5, 12 S 0. !54 E." O. 05 ............ _:1,_'~6_7. ....... .]:~67._'J:.~ ............ _:1..'-"C___~_(L.__Q_O ........... 5, 7'.-:,' S (). 76 E: 0.0,"_-. 20 67 2067, 1 '2 2¢')(")N. 00 6, 02 S I, 45 E ' 0, 06 .,: 167 '-" 167 1'-' .,:- ..... ::,-~ E 0.06 2267 2267. I · _. 7.::, '.'3 .L..:,.J E t~, (.~/", ...................................................... 2367 :2:'::67, 12: 2 :--:00, 00 5, 87 F:; 1,78 E 0, 06 2467 2G67. 12 240C).0C) 4.E:'i? S 2.:31 E 0.07 · -,:/. ~ .,-,~ ~ ~.-, ::, / .,::._ :..-,/, ]. 2 9 Fi(')("~ (")(') 4 ("~4 :::; "::' F:;::: F' (") C)'7 2667 '"/ ' -' · ." :,6/, 12 2600.00 ._,":', (')5. S 2. :30 E 2767 2767, 12 2700.00 1 . ::!: 1 S ..:,'-', C,:.') ~' E · --i ,'"l ,"~t i--i ,-J .-, i-~ .... · '" -',=,67 ."-o67., _12.2_' .... __~_"~-..:L-!_~2,~_U~.~. 1 ............ OZLN_ ....... ~.:,'" -'"- E 29' 67 2 .';.'~ 67.1 .-"-' 2.9 (] 0.00 6 ....... 65 N 4- '-~' ":' F 3067 3067 :L '-';' :3(') 0 N. N 0 ~ '"-' Pq":' · _,. N 6:3:}': E · .i.. . _ ._ .~l 316:.-3.' :3167. 1 '--.-' :3100. (:)0 26. :-'::0 N__ 8..54 I£ 3'269 3267. 12 :320 C). (') 0 42.24 N '.::). 2 '? E 3371 :]:367 1'--' :3:3F)0. C)0 61 20 N 10 46 E 3474 3467, 12 :340C) . C)C)_ ,_-,._",'-"-'. 7:_--: N 11 . 7:-3, E 2:577 2:567. i '2 :'2:5('~(:). 00 1N'F/. 41 N 1:2:. 07 E 3 6::: 1 :2:667.12 2:600.00 1:37.48 N 14.69 E 0.08 cZ). 3'1 N. 7'2 4.38 6. '? ~ 10. i 6 14.04 0.00 0.00 ..... ~)...00... 0.00 0.01 0.00 0.01 0 ' (")1 0.05 O. 17 O. 41 (:). 66 . ,-,,-: SOHIO ALASKA PETROLELIM COMF'ANY '._:;-~/:-, ('._:;EC :--:?] T!.2N RI2F) PRUDHOE BAY ALASKA .-.-,PEE~F{Y_=BL;itN_ WFi I :=;UF:N~_~G COtiPANV AhlL. HLIR~L~E ALASKA .LAJ~.%~] _ L]iq DA TF A U G U'..3 T 17, 1 '- '"'' ............. J~GE' DATE OF." SURVEY AUGU:F.;T 16, 1984 ,_lOB IWUMBER AK--L,B-40068 KELLY BLtSHING ELEV. = OF:' E R A]ZELR - F_:;'A~ft ? C / MF':G[ I I RE 67 Ic' Fl' I NTERF'OLATED VF~LLE.=. FOR EVEN 1(~,(') FEET AF SLIB-SEA DEF'TH 4. :';~'7 .......... ~.:::: A.. 51 8.22 .... _10, 62 13. ,':',4 17. i6. '-":'5 4667 1'--" 4600 O0 681. t o ,:, ,,.,... . ")'"" · ~'--?'-'¢~ 47A7 12 47C)n. (')(') Z:=:_4,,~1 ........ 'n:.2_~ ~ - . ................................................... !:'q i '- ''~' .- -':-'" 48/-',7· 12 480C~ . AO :--:'P /_.., . ,..,'='~;._ ._F, .._'.-.' ,_,o ,_,'=' 49 &, 7 .12 4900 · 00 _1014 . L:: :l r~' ~"~ · .., 44.,;, .... :~n~Z ,.1 '":' 5QO0 _o0 11~_,_':21 5613 5 Z ~7. Z .,:.'-' 5 ! O0 , ,O,c) Z 267 · 2'7 ._ 7,=. 1 5267.12 ._ ..' ~.)~J,. O0 1400. ~'" · _,~ N 212 60 E 514 4:3 68 12 ~C~ ~'-, '-, ~'-, .... ~",,-, - "~ '-,'-, ...... , ~ ,-, (" ,') 6104 ._ 467.1 ~ 54(30. . O0 1651 . 11 N 24E:. ,_,._':":~ E 6:37.07 6';'~8~ _ 5567.1 ~';' ~5(')A ..... 00 17E, 7. ~':: 1 N 2'c, '=._, . 29' E 691.27 ._~4 .20_ :SAHIO ALASKA PETF, tOLEUM COMF'ANY S-16 (SEF: :35 T12N R12E) ,=,FERB..]_'_-::, Jll MELL _~UtREEN. iJgu_ COMFgd.~f.. ANCHORAGE' ALA:::;KA A LIG U:-_-;T J. 7, ]. ,:i;. $::4 PRUDHOE BAY ,,*. ~...o ~L~._-,F,G DATIE FiF :::,Jh:VEY AULqi_IST F'AGE 16, 1 '5'84 ,_lOB NLtMBER Ai<-LB-40068 KELLY BUSHING EL. EV. = ,:!:,'7. :1.2 F'T. " I '- .... I" :!. 01-- S I..t B-S E A D E F' 1" I---I INTERF'EILATED V~-.~LLE..-:, FLF.~ EVEN 00 FEET MEASURED DEPTH TRLIE SUB-SEA VERT I CAL VERT I F:AL DEPTH DEF'TH TOTAL . REC:TAi'4GLILAF;,: COF'It:;:D i' hh..,~ I E.::, MD-TVD N 0 R T 1--I / S 0 U T FI E J:':.:! ;.~J]'?'. Id E. :;ii_'. ..... D I F' F' E R E N C E V E R T I C: A L C (] R R E E: T I (] N 6407 65,.,,:, 6696 /_-,837 6976 7114 7 '250 7.:',,=,6 7520 76,.,,-" 7782 F, ' F,/-,A 0 00 · _ z-,67 1 '-' 5767.1 '2 5700.00 · _,,_-,67, i '-' 5.967.12 5900.00 6067. 12 60 C:,0.00 791'-',:. 8044 8174 1 ,=, 77.08 Iq z 79. '? 6 E '74 o. 4.8 1 "'-"-' 29 3 ,, ',E: ~7 E'" .... '"" ,, ..-,'c:,.a. Z l. 4 Iq /,::,o 41 64 6 7.12 64 C:, 0.0'2, 6567, :1.2 =C ' 6,_, J 0.00 6667, 1'2 6600.00 2083.91 Iq 307, ';):3 E 829.57 2181.84 N ::.::22.26 E 870.2'7 2277.7:3 N 237I..=59 N :348. ()1 E 94.7.17 2463.91 N :35'P.21 E · '.,F, Szi '-," = ~ ._ -,. o 0 N :3',70. :24. E 2642, 78 N 380.64 E 2Z28, 00 .N :B'.-.-¢2. ::::'F' E 281,0.21' N 4.07.54 E 6767, 12 6700.00 68 67, 12 680 C). 00 6967 · 12 /:--,'P 00. ("} 0 '.':. ':_:: 93.51 N 'i. 2:3.84 E 25)76.24 N 441.2d- E · ":,Ap';o. 2':2. N 4":"7..., 59' E ._1.._ 1_1 . n 1018.9 1052.91 1084 ':"'"' ,, ,'-, ,-_, 1115..i6 8303 8431 8561 :_--:6'.P6 8:;::35 7067.1 ='° 7000 .00 7167.1 ':.' 7100.00 7267. 1°~ 7700~... 00 ......... ,1 N ,+/:3.:2C) E :2:216, 78 N 488.0:3 1:7. '-., 'U,, C~ , · .,~..7.46 N 5O4 76 E 3386.._,::i Iq .~-i24_. 76 E .::, 4._,. ,'"-. 0 E · :, 4,:, O. 2'7 N "= ' '= 72:67. I'.-'.' 7:_::00.00 7467.1 ,':' 7400 .0 C) J.'2':'/', :31 , '_ ._H_. u 1264,66 12'.;'4.25 1 ':'":":/ 6,"-, .-~ d'-- .. it 1 ':'/- ':' :2:2 ._1 __ll__l · ............................................................... ;~R.W=SUbl..]4ELL_-':;~;.'W.~N~3 COh'it:'ANY ANCHORAGE ALASKA .-3OHIO AL~SK~ F'ETROLELIM COMF'ANY %-_j,, 6 ( SEC: ':'.'-'; T 12N R ~ '=.'E ) :*RUDHOE BAY ~LASK~ , C C:! M F' LIT A T I O!q :0 A TIE AUGUST .1.7, 1984 DATE F~F:' ::3L.IRVEY ALiGLIF:;T 16.., ,JOB NUMBER AK-.'.L,B.-40C~/:.S KELL. Y bd.:,H-l:NG ELEV. = OP EF-~_~ TOR-5:;A hie C / M C GLt l' RE I NTERF'OLATED VALLIES F:OI:;; EVEN :l.C::O F:EE"F OF '.-3UB-SEA DEF:'TH 8,7.1 '') FT I'RUE MEA~i. RED VERT I [:AL ' 'T .DEPTH .:, JB-.=,E~ '1'0't¥4 L VERT I C:AL RECTANGULAR CO(]RD I NATES MD-TVD VERT I CAE i , ' [t I i'= F E -- F;; E ' N (~ ' .... r': ~_ n. tR R E:' __ t-: T LObl_ o Y74 '.~114 7567.1..'--' 7 ._, (.) o .00 :=: 5 '74. . o 4 hi !:'; ..... ¢':.,,,,'., . ...:'",...., ':= E 76/_-, 7, 1~2 ...... Z 600.00 :366'.-'.,' ~_..Z 7' J_~ ........ D ::J/'._.., ,~ 4 L-, .E- . ';,...~':.'._F, ,_./., 7767 .12 77 (')_ C)_. (") 0 3770. :2::3 N 9399 7:--:/:,7.12 7800.00 :::872..1. 6 1'4 · =,,:~- .=, (-),:) ..... ..... ~.;L ......... 7'~5_7_.,._12 ............ 7.'}:..,iC)_C). 00 ............. ~ ..... Z~ ........ itl y 6 o ..' ::: ..... 0/-, 7, 12 :E: F)0 (') F) 0 ~'~ c'., -'/..-'-'. ,:,'-' ,:,'-' Iq 7 o ..' .:, ::: 167. 1 '-' ::: 100.00 4172.02 N ,~ .-, .-., _ :-'.,"..-?/_-, 4 ,_ z. 67, 1.. ::~,'2QC~ QD ........J27_CL,.5 4._ l.~J.__ 10106 ,:, o 67. I ._':' 8:5:00 .00 4:372 .~.~.'=: '''~ N "=.,c/ 10248 8467.1:2 8400.00 4472.~.. N 5':~> 6. '..T,"i? E 60.1.. 70 E E, 0-5.....5:3 /:., ¢") ::: ,--,--, 61:-]:.02 E _ .,'J~. Z 7_._ ~.:'-Z. E c'-,2:':3.87 E :,,- y. 2:7 ....... 10523 8667.12 10657 8767.12 .....10790 . ~7.12 10923 8967.12 11057 ~067.12 11191 11:300 A/:,00.00 4661.09 8700.00 8800.00 8900.00 9C~00. O0 9167.12. 9 ~ 00~_00 9247.84 9180.72 N ..... 5:35.21 . -E_ ............ 1.,'-32D_...33 .... Iq .... "- ,'", 4 .::,. 66 E :1.,:, '"''._,=''e, · 66 474:_-':. :=:8 N ,'_'--,,';,2.72 E 1 :=:'::?0. ::4. 482::2: ':".--" N /-':'4.. ':'7 E .__.~.."'~._~ 4918.40 N 706.0:3 E 1'256.58 5003..95 lq 727.28 E 1 ':.:'8'F'. 88 ........... ~!2 ,,_ SD ..................................................... :_::6 · 34 ::-:4. 18 ......... ~L._6Z_ ......... .J. __ 3:3.07 :3:3.30 ....... T_.H_E__E_:.¢%..r__LULAT_ION PBOCED~J__~_'~L_.USE A L_]j~EAR. _L.I)J_TE:RF_'_QL~]~.DhI_D_E.~E~: ........................................ THE NEAREST 20 FI-lOT MIl (F'ROM RADIUS ElF C:LIRVATLIRE) POINT:E: TRUE NORTH 000.00 .00 ~o 5218.27' N 8° 26' Sohio Alaska Petroleum Company Our BOSS Gyroscopic Survey Job No. AK-LB-40068 'Well: S-16 (SEC 35 T12N R12E) Prudhoe Bay Field North Slope, Alaska Survey Date: August 16, 1984 Operator: Samec/McGuire Scale: 1" = 1000' ).00 00. O0 -! 0~)0. O0 I Surface Location 2094 SNL 714 EWL ! 000. O0 HORIZONTAL PROJECTION ' Suggested form to be inserted in each "Active" well folder to d]eck for tin~ly cc~liance with our' rc<julations. Operator, Well 'Name and Numker Reports and Materials to be received by: Required Date Received Remarks , · Cc~pletion Report Yes · Well History Yes Mud Log 4x ---pt -- Core ~scrip:on . Registered S~ey Plat y.~ . ..Inclina:°n S~ey ~& ...... _, ~ ..Drill St~ Test Re~s .~~~_ '""~ ~14 ~~0n T~t Re. rte r~~ SOHIO ALASKA PETROLEUM COMPANY MOBIL SFO ARCO EXXON T0: PHILLIPS ~ ' i! ~TATE OF AK CENTRAL FILES(CC#'s-Transmittal Only 3111"C"STREET ANCHORAGE, ALASKA TELEPHONE(907) 265-O000 MAIL:POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 8-15-84 CC#: 75635 REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS following material is being submitted herewith..Please acknowledge receipt by signing copy of this letter and returning it to this 'offiCe:- _~ S~!6~_ OH (DIL,C~NL,BHC._LDT) w/ LAsting 7-31-84 #1,2 Sch#69433 03091 . (4/82) *SFO & EXXON: An~stertsk(*) next to a listing abo~e means you should have received the Tape(s) and Listing(s) directly from the respective service company. Please confirm this.. RECEIVED Carolyn Bishop Development Geology DATE 19 Well Records ....... 'MEMORANDUM · State of Alaska A2LASKA OIL ~ GAS cONSERVATION COMMISSION DATE: FILE NO: TELEPHONE NO: SUBJECT: July 16, 1984 D.41.31 Witness BOP Test at Sohio's S-16 Well, Sec. 35, T12N,R12E,UM, Permit No. 84-84 at Nabor's Rig 1SE. Sunday, July 8, 1984: I traveled this date from Anchorage to P-~h~-e~-B~aY'~'~b ~i~m~ss the BOP test at Sohio's S-16 Wail. The BOP test commenced at 5:30 pm and was concluded at 10:30 pm. There was one failure during this test the lower kelly cock. This kelly cock was replaced with the floor safety valve and a new floor valve was ordered. I filled out an AOGCC BOP test report which is attached. In summarY, I witnessed the BOP test at Sohio's S-16 Well. Attachment: The 13 3/8 casing shoe failed to test. The casing was pressured to 2700 psi'when~he pressure started dropping. Returns were noticed in the cellar~ro~d the outside of the conductor pipe, because of this failure a 320 sack squeeze job was performed around the 13 3/8 casing shoe and drilling was resumed. A leak off test was performed'after drilling 10 feet of formation, pressure at surface was 550 psi with 8.8 ppg mud. EMU = 12.7 ppg. Attached please find copies of the pressure charts used during the casing test and squeeze job. t~9.~¢11 A/Rev lf~/7.q~ O&G #4 4/80 STATE OF ~LASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P. E. Inspe~t~ion Report .Inspector Date Wel 1 Operator ~/';~d) Well .~ -- / .d~ Location: Sec DD TIZ~ R /~ ~ ~;,~, . ~ Drilling Contractor .A_/O~)/~5 Rig # Representative.. ~,'// ~/y.~ ~ /~ Permit # ~- ~ ,/ /~Casing Set @ .~7~ ft. /~epresentative /~, ~' ~/ '~ ~ ~ Location; General .~ Well Sign d)/< General Housekeeping ~ Reserve pit ~ Rig ~/~ BOPE stack Annular Preventer Pipe Rams ~ < L- Blind Rams ~J~ Choke Line Valves H.C.R. Valve PC/ Kill Line Valves ~)~~ Check Valve ITest Pres sure ::-. ,; ~ :'.':: ,.. , Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure ~..d)~ psig Pressure After Closure /~) psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: N2 ~,. ~-~9~; ~.~d~,. ~Z~_~ . psig Controls: Master ~ .... Remote ~ Blinds switch cover ~.~ Kelly and Floor Safety Valves Upper Kelly / ~st Pressure Lower Kelly /~Test Pressure Ball Type ~ ~-~Test Pressure Inside BOP ./~'~est Pressure ' Choke Manifold ./ ~est Pressure No. Valves Z~ . No. flanges Adjustable Chokes Hydrauically operated choke / Test Time ~ hrs. miL ~ sec. miL ~ sec. o~ Repair or Replacement of failed equipment to be made within .. Inspector/Commission office notified. Remarks /,~ t~' ~/~ ~'~ '~ ~'/~--"'~-- ;'("~, ~/~ _~ ... ..... , days and Distribution orig. - LO&GCC' cc - Operator · cc - Supervisor Inspector -:~! ~ 10 /,Sl'd ,~e , .D 3.5,( /~ /~~ SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 June 12, 19 84 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: ~T,. .(12-26-12-12) PBU Pursuant to our telephone ~n~rsation, enclosed are three copies of a revised surveyor's plat for S Pad shc~ing surface hole distances frcm section lines for Well S-!5. Please substitute these drawings for those formerly sent you with our application for Permit to Drill for Well S-16. Very truly yours, District Drilling Engineer encs cc: Well File 917 RECEIVED JUN 1 4 0ii & C~3s Cons. commissio~t Anchorage 500, CALI~ 'OOS 0 I0 20 ~0 · 40 ! J I 2.0 5 40 ........... ........ :~;16(Proposed) 2-7 1 ...... 2'6 I0 04 Ot r-- S-lB I I ~1 / LAT. I ' I] X= 618,885 Y=5,979,499 I _ _ S- 17 ( Pro posed ] ' ~ . O~ TI2N TIIN PORTION OF T. II N. & T. 12N.~ R. 12 E., U.M. SCALE' I"= I/2MILE SURVEYQ, R'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A LOCATION SURVEY OF THE WELLPAD SHOWN AND THE WELLS THEREON. THIS SURVEY WAS MADE BY ME OR UNDER MY DIRECT SUPERVISION, · AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. BOTTOM HOLE LOCATIONS ARE FURNISHED BY OTHERS. DATE ~/[l~V 11.1~,4 REGISTRATION NO. ! REGISTERED LA Y L$51~1 ADDED LOCATION DIMENSIONS FOR WELL S-15 RECEIVED JUN ! ~ ~ Alaska 0il & Gas Cons. Commi~ Anchorage (J~'- 6/11 / a4 PAD DETAIL SCALE: I": 500' PLANT .............. IIIII I III - PAD "S" EXTENSION Located In I:~OTRACTED SECTIONS 26, Z7~:~4,:~5, 2.8, $~1'! ZNtTIIN,R!2E, UM_ Surveyed for SOHIO ALASKA PETROLEUM CO. I II lilt I II III H III I II _ . -- Surveyed bY OCEAN TECHNOLOGY LTD. LAND & HYDROGRAPHIC SURVEYOR8 2502 West Northern Lights.Boulevard Anchorage, Alaska I II I I I III I II I I Jme 11, 1984 Mr.. R, H. Reiley District Drilling Engineer Sohio Alaska Petroleum Ccnnp~y Pouch 6-612 ~chorage, Alaska 99502 Prudhoe Bay Unit S-16 Sohio Alaska Petroleum Company Pemit No. 84-84 Sur. Loc. 2094'SNL, 714'EWL, Sec. 35, T12N, R12E, UPM. Btmhole Loc. 2269'SNL, 1269'EWL, Sec. 26, T12N, R12E, UPM. Dear Mr. Reiley: Enclosed is the approved application for permit to drill the above referenced ~¢~11.. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.05.0(b) (5). If available, a tape co~taining the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter Surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game-. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 ~nd the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal WAter Pollution Control Act, as amended. Prior to commencing operations you ma. y be contacted by a representative of the Department of Environmental Conservation. To aid.us in scheduling field work, please notify this office 24 hours prior tO commencing installation of the blowout prevention P~r. R. H. Reiley -2- Prudhoe Bay Unit S-16 June 11, 1984 equipment so that a representative sE the Commission may be present to vitness testin'g of the equipnent beEore the surface casini~ shoe is drilled, ~'here a divercer system is required, pl~s~ also not~fy th~s of~ce 24 hours prior to co~enc~ng equip~t installation $o-tha~ the Co~ission ~7 witness testing before drillint beloV ~he shoe of the conductor pipe, In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a viCness present. Very truly yours, Chai~n of ~. ORDER OF THE Alaska Oil and Gas Conservation Commission be Enclosure cc~ Department of Fish & Game, Habitat Section w/o eno1. Department of Environmental Conservation w/o encl. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 June 5, 19 84 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: WELL S-16 (12-26-12-12) PBU Enclosed are the following documents, in triplicate, along with our check for $100 to cover the permit filing fee. 1. Application for Permit to Drill; 2. Proposed drilling program outline; 3. Proposed Blowout Prevention Diagram; 4. Surveyor's plat showing well location; 5. Directional map. If you have any questions, please call Ted Stagg at 564-5173. Yours very truly, MCM: ckg 6584 Enclosure cc: Well File #17 RECEIVED JUN 0 6 1984 Alaska Oi~ & Gas Cons. Commission Anchorage .~---,. STATE OF ALASKA ?% ALASKA~...'' AND GAS CONSERVATION CO,.,,vllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL ~;] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL r~ SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 9. Unit or lease name 2094' SNL, 714' EWL, Sec. 35, T12N, R12E, UPM PrudLh~e Bav Unit At top of proposed producing interval (target) 10. Well number- 2450' SNL, 1250' EWL, Sec. 26, T12N, R12E, UPM S-16 (12-26-12-12) PBU At total depth 11. Field and pool 2269' SNL, 1269' ~L, Sec. 26, T12N, R12E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. Prudhoe Oil Pool Est. KBE = 60' AMSLI ADL 28257 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. 2975387 Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest dril'ling or completed NW ..Of De~db~rse - 10 miles East of 'ADL 28258 - 1250 feet well N. Kuparuk State .~.~y 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 111391 MD - 9199 ITVD feet 2560 June 15, 1984 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3330 psig@ . Surface KICK OFF POINT 2800 feet. MAXIMUM HOLE ANGLE 43-1°I (see 20 AAC 25.035 (c) (2) 4390 psig@RR00 ft.~'~(TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT , Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 36 20x3:0 Insulat-=d COnd~lctor 80 SurEace 110~I 110 8 cu.yds, concrete 17½ 13 3/8 72~ L-80 Butt 2650 Surface '26801 2680 3720 cu. ft. Arctic Set 12¼ 9 5/8 47~ L-80 Butt 10407 SurCace 104371 8686 2236 cu.ft,~ .Class G: ~ I 280 cu. ft. Arctic Set 8½ 7 26# L-80 Ij4S 952 10187 ~. 8504 11139 II 9199 283 cu. ft. Class G wi 22. Describe proposed program: 18960 salt See attached proposed drilling and completion, program.. As shown on the attached directional plat, we are aware of the potential intersection problems which can result from the drilling of this well. If during actual drilling operations, one of these intersections is approached within hazardous proximity-, the well to will be shut-in. ~,,~ '~,~ Alasl(a 0ii & Gas Cons. c0mmissi0tl Anchorage 23. I hereby certify that the foregoing is tr~,"'~d correct tj;~the best of my knowledge ~ ~ / - ( ~ District Drilling SIGNED 0 ~ ~ ~ TITLE Engineer DATE&.6~- The space below for Commission use R. H. Reiley CONDIIIDNS OF APPROVAL Samples required Mud Icg required Directional Survey required APl number I-lYES [~.NO []YES ~[.N O ~YES [-]NO 50- Permit number Approval date ~"~-(~.4/"'"~ ... 0~F/]~1/8/-4 I SEE COVER LETTER FOR OTHER REQUIREMENTS I APPROVED B F/ ~~~ ,COMMISSl ONER DATE %_~ ,_ ~ by order of the Commission 500' ~S II & III I Form 10-401 ' / ;::,% - Submit in triplicate Rev. 7-1-80 .... t~ PROPOSED DRILLING AND COMPLETION PROGRAM WELL S-16 (12-26-12-12) PBU Install and cement 80' of 20" x 30" insulated conductor to surface. Drill 17 1/2" hole to 2700' TVD and cement 13 3/8" 72# L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to +_100' TVD above the Sag River Sandstone. Run 9 5/8" 47# L-80 Buttress casing to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9~ 5/8" shoe, The second stage to be downsqueezed in the 13 3/8" x 9 5/8" annulus followed by Arctic Pack. Directionally drill 8 1/2" hole to TD, Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement with 18% salt. Clean out to 7" float equipment, Change over to 9.6 ppg. NaC1 completion fluid, Test casing and lap to 3000 psi, Run CBL, Run 9 5/8" production packer on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer +50' above top of liner. A sub- surface safety valve with dual control line~ will be placed--+50' below base of permafrost. Install and test Xmas tree, Displace tubing to diesel. Set and test packer. Suspend well for perforating subsequent to rig release. Tubing Size: 4%" 12,6# L-80 A/B Mod. Butt., w/.GI/~s RECEIVED J UIV 0 619 4 ~laska &A~?s. Cons. Cornmiseion /~Chorage B.O,P. ,,STACK. CONFIGUR -,TION I:~ 5/8" TRIPLE RAM STACK ii i i ] i i i i i i 5000 PSI WP iii . DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS CHECK 2" KILL LINE GATE DRILLING SPOOL GATE GATE CHOKE LINE HYDR. ASST. GATE PIPE RAMS RECEIVED JUNO 6, 19t~ Alaska 011 & Gas Cons. Commissloit Anchorage 1 I PORTION OF T. II N. E~ T. 12N.~ Iq. i2E~=,.U.M. SCALE: 1":I/2MILE =~URVEYOR'$ CERTIFICATE I HEREBY CERTIFY THAT i AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A LOCATION SURVEY OF THE WELLPAD SHOWN AND THE WELLS THEREON. THIS SURVEY WAS MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT. BOTTOM HOLE LOCATIONS ARE FURNISHED BY OTHERS. DATE /~l~V |1.1~>'~' REGISTRATION NO. REGISTER~:D LAND SklRVEYOR (32-26-12- t2) S - 15 (/~.-Z6-/2-/2) $ -16 ($$-$'I-12-/2~ - H (15- 0~-/I- 12)$ - 18 WELLS PAD DETAIL SCALE: I": 500' -- PLANT RECEIVED JUN 0 6 1984 Alaska Oil & Gas Cons. Commission Anchorage PAD "S" EXTENSION Located In PROTRACTED SECTIONS Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by OCEAN TECHNOLOGY LTD. LAND & HYDROGRAPHIC SURVEYOI~S 2502 We~t Northern Llght~.Boulevard Anchorage, Alaska COURSE LINE --- CLOSEST APPR~..CM ANALYSIS --- VERSION 5,5 FOR PROPOSED WELL =16 ( COURSE LINE CALC. FOR 5-16 LOCATION = W=E S-N TVD(S~S) TOP 618885,00 5979389,00 -60,00 BOTTOM 619357,13 5984475,14 9110,89 NOTE - ALL DEPTHS IN FEET BELOW KELLY ~USHING (OKd) ,, .... CLOSEST APPROACM WELL IDENT /PROPOSED- /NEARdY- CLOSEST TVD DEPART TVD DEPART DISTANCE A03200 8567.9 4544,b 8554.7 0,0 147,4 A69500 S-3 ' 92,9 ' 0.0 100.0 .2 A72900 S-12 92,9 0,0 100,0 1,3 1327,5 A72800 S-l{ 3892,1 277,5 3722,7 50,2 11~1,7 A76500 S-lO 2692,4 0,0 2700,0 5,2 1118,4 A77100 S-9 3987,4 332,2 4102,6 438,7 A77800 S-8 4051,1 372,1 4104,4 248,5 678,5 A71701 3702,6 185,7 3607,4 216,9 335,0 A80400 S-14 92,2 0,0 100,0 0,0 1534,5 A69800 S-2 3705,7 187,1 3698,7 283,8 226.6 A82900 S-7 0,0 0o0 5,5 ,0 834,3 A81000 S-13 292,4 0,0 300.0 ,7 A83900 S-6 4057,8 376,6 4040.6 108,1 569.i A86900 .... ' 4130,2 425,9 4101,2 24,1 441,5 A95900 4236,8 507,0 4254,1 15,~ 302,5 SUMMARY THE WELL WfllC~ COMES CLOSEST TO THE PROPOSED WELL iS A03200 CLOSEST APPROACH DISTANCE = 1~7,4 FEET VERTICAL INTERSECTION /PROPOSED- /NEARBY- VERTICAL TVD DEPART TVD DEPART DISTANCE 4159,4 447,3 1604,'! 20,9 -2361,1 4131,0 ~26,5 2~2~.2 40,7 -13U9,1 3930.2 898,~ 574~,0 37~,b 1791,~ I..LJ 0 W~W~I Wl'I w ~1 W t'l w i~l W lVl w IVl ~lVI W i-t ~ i11 WI'I ~ IVl W l-i w ~-i W I'l ~ i-i w i~ W i'1 w IVI w i-i ~ irt W I'l W i-i ~ t-i ~ i,i ~ i-i ~ i-i W i'l w I~I w l-i ~ I-I ~ Cl w i-t w i~ ~ i-i w i'l w t-i W lVl ~ i-i w i,i w ~1 W PI ~ I'1 ~ i-i w i'1 W ivi w i-! ~ ~ W ~1 ~ ill ff ivl w i11 w iVl w I,i w i-i W FI N 7 DEGREE LEAD LINE --- CLOSEST APPRb..CH ANALYSIS --- VERSION 5,5 7 DEGREE LEAD LINE FOR S-lb FOR PROPOSED WELL -16 ( LOCATION : W-E $-N TVD(SBS) TOP 618885,00 5979389,00 -60,00 BOTTOM 618734,18 5984494,77 9110,89 NOTE - ALL DEPTHS IN FEET BELOW KELLY BUSHING CLOSEST APPROACH WELL IDENT /PROPOSED- /NEARBY- CLOSEST TVD DEPART TVU DEPAN'[ DISTANCE A03200 ' B512.5 4492,8 0499.3 0.0 699.8 A69500 S-3 92,9 .... 0,0 ' 100.0 .2 529.7 A72900 'S-12 92.9 0,0 100.0 1,3 1327.5 A72800 S-Il 2920,8 3,5 28g~,4 51,2 1198.7 A76500 S-lO 2692.~ 0,0 2700.0 5.2 lll~.~ A77100 S-9 '3946,7- 307,5 4094,6 433,1 7~1,/ A77800 S-8 4001,8 341,0 4077,2 237,6 721,b A71701 3754,9 208.7 3658,3 240.6 319,8 S-l~ 92.2 0.0 100.0 O.O 153~.5 A69800 .5-2 3685,8 178,3 3684,5 276,6 AB2900 S-7 0,0 0,0 5.5 ,0 834,3 ABIO00 5-13 292.4 0.0 300.0 .7 1429.5 A83900 5-6 ~024,8 354,9 40~0,6 10~,! 613,7 ABbgO0 4095,0 401,4 4091,1 23.5 491.9 A95900 4188.1 468.4 4~06.3 15.5 SUMMARY THE WELL WHICH COMES CLOSEST TO THE PROPOSED WELL IS A6gBO0 5-2 VERTICAL INTERSECTION /PROPOSED- /NEARBY- [VD OEPART TVO DEPAR'[ VERTICAL DISTANCE 452~,2 766,3 3043,9 408,8 -1~e7,4 4135.~ ~E9,8 3146,5 58,6 -995,3 3891.~ 277.1 5839.~ 415.0 193~,0 CLOSEST APPROACH DISTANCE = 248,~ FEET .. RECEIVED JUN 0 6.1984 - 4taska Oil & ~as Cons. Commission' Anchorage 2BO'I RAI- IUS C',ET ( IRC_ 4BNN TI['N RI?F~ . _,_PIN PA,,c,I',)I =?z,qN' NFl =4n.-ar · ......... - ~ , 4?NN ,,. '' .... I..... ~ .... . Ai-~NN .~4NN .... R[CEI~/ED ~ 'II-ICI ~ Ala~ka,.,Oi,I & Gas Co is. Comn ~nn t.. .... ............. ~oo 7° LEAD_ ! ~ , ,, 24n0 __ ......... ? ~nn ,. , , , ....... , ; , ,, 1~00, ,. ~ .... 1~NN I ~ ...... ]4ON 1 ~' ' t' 17N~ ,,, ,,, 1 ~-= 7' _E~D ........ ~nn ~ , ....... ....... 4NN - ,, ,, /r Anch~)rage CHECK LIST FOR NEW WELL PERMITS Company ,/~ ~ Lease & Well No. IT EM APPROVE DATE (2) Loc (~?thru 8) (3) Admin v~,_ ~' 7-fY thru 11) (10 and 11) (12 thru 20) (21 thru 24) (6) Add: lo YES NO Is the permit fee attached .......................................... :~ 2. Is well to be-located in a defined pool ............................ ..~__~_ 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ........... 6. Is well to be deviated.and is well bore plat included ............... 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. REMARKS 21. 22. 23. 24. 25. Does operator have a bond in force .................................. ~t_- Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ...... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ......... Will all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~. Does BOPE have sufficient pressure rating - Test to O?/~Z) psig · Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. IV, H'b PA q u S 7'ATW o .Geology: Engineering HWK LCS BEW WVA JK ' HJH rev: 12/08/83 6. CKLT INITIAL GEO. UNIT ON/OFF FOOL CLASS STATUS AREA NO. SHORE ,,, Well Histo.ry File APPENDIX Information of detailed nature that is not Particularly germane to the Well Permitting Process but is part of the history file, To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ No special'effort has been made to chronologically organize this category of information. S-16 ~ 3~ PRUDHOE BAY ~o~TY~ I Run 1' 30 - July- 1995 PDK-1001GR 11021 Logging Services Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD S - 16 500292112300 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 03-AUG-95 5646.01 J. DAHL Jo SHARP 35 12N 12E 2093 715 67.12 66.12 40.12 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 10693.0 3RD STRING 7.000 11300.0 PRODUCTION STRING 4.500 10459.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BHCS GR 2 1 06-JUL-84 SWS 47.00 26.00 12.60 BASELINE DEPTH 10711.0 10746.5 10759.0 10764.0 10777.5 10780.0 10797.0 10798.5 10799.5 10826.0 10827.0 10836.5 10837.0 GRCH 10709.5 10747.0 10759.5 10765.0 10778.5 10781.0 10797.5 10799.0 10799.5 10826.0 10826.5 10836.0 10837.0 EQUIVALENT UNSHIFTED DEPTH ......... 10839.0 10853.0 10872.0 10874.0 10874.5 10882.0 10885.5 10886.0 10887.5 10904.5 10905.0 10906.0 10911.0 10914.5 10919.0 10922.5 10926.0 10931.5 10963.5 10964.5 10968.0 10973.0 10974.0 10978.0 10980.0 10986.0 10989.0 10990.0 11000.5 $ REMARKS: 10839.5 10853.5 10872.0 10874.0 10875.0 10882.5 10884.5 10885.0 10885.5 10904.5 10905.0 10905.5 10910.0 10914.0 10919.0 10922.0 10926.0 10931.0 10963.0 10963.5 10967.0 10974.0 10975.0 10979.5 10981.5 10986.5 10989.5 10990.0 11000.5 PDK-100/GR. LOG TIED INTO: BHCS (31-JUL-84/SWS). WELL TEST SUMMARY TEST DATE ELAPSED TIME GROSS FLUID RATE NET OIL RATE NET WATERRATE FORMATION GAS RATE LIFT GAS RATE CASING PRESSURE TGOR TGLR CHOKE OPENING MANIFOLD PRESSURE 05-JUL-95 HOURS MPBD MBOPD MBWPD MMSCFD SCF/STB MMSCFD PSIG SCF/STB SCF/BBL PSIG MANIFOLD TEMPERATURE DEGF WATER CUT (CALC) PCNT 4.0 2.06 0.41 1.65 0.01 33 2.43 1771 6621 1318 93.7 213 159 80.0 WELL FLOWING DURING ALL 3 LOGGING PASSES. A DIFFUSION CORRECTED SGMA CURVE IS INCLUDED FOR ALL THREE PASSES. THE CURVE IS CALLED SGNT AND WAS CORRECTED WITH THE FOLLOWING PARAMETERS: BOREHOLE SIZE = 8.0" CASING SIZE = 7.0" SALINITY = 25,000 PPM. A PDK POROSITY CURVE (PHI) WAS ALSO CREATED FOR ALL THREE PASSES. SHIFT PROCEDURE AS FOLLOWS: 1) FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2) FIRST PASS SGMA (PDK) DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 3) ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4) ALL SUBSEQUENT PDK PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS PDK. / ? ?MATCH1A. OUT $ FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10690.0 11009.0 PDK 10692.0 11021.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 EQUIVALENT UNSHIFTED DEPTH ......... BASELINE DEPTH SGMA 10746.5 10747.0 10753.0 10753.0 10759.0 10759.5 10764.5 10765.0 10777.5 10778.5 10780.0 10781.0 10783.0 10783.0 10790.0 10791.0 10797.0 10797.5 10798.5 10799.0 10799.5 10799.5 10826.0 10826.0 10827.0 10826.5 10836.5 10836.0 10837.0 10837.0 10839.0 10839.5 10847.5 10847.5 10853.0 10853.5 10867.5 10867.5 10870.0 10870.5 10872.0 10872.0 10874.0 10874.0 10874.5 10875.0 10878.0 10878.0 10882.0 10882.5 10904.5 10904.5 10905.0 10905.0 10906.0 10905.5 10911.0 10910.0 10914.5 10914.0 10919.0 10919.0 10922.5 10922.0 10926.0 10926.0 10931.5 10931.0 10963.5 10963.0 10964.5 10963.5 10968.0 10967.0 10973.0 10974.0 10974.0 10975.0 10978.0 10980.0 10986.0 10989.0 10990.0 11000.5 11018.5 REHARKS: 10979.5 10981.5 10986.5 10989.5 10990.0 11000.5 11017.5 PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. GRCH WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. / ? ?MATCH1B. OUT $ CN : BP EXPLORATION WN : S - 16 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 SS PDK 68 1 CPS 4 8 MSD PDK 68 1 CU 4 9 RATO PDK 68 1 4 10 RBOR PDK 68 1 4 11 RICSPDK 68 1 4 12 RIN PDK 68 1 4 13 SGMA PDK 68 1 CU 4 14 SGMB PDK 68 1 CU 4 15 SGNT PDK 68 1 CU 4 16 PHI PDK 68 1 PU-S 4 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 99 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 52 Tape File Start Depth = 11045.000000 Tape File End Depth = 10685.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12258 datums Tape Subfile: 2 266 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 10690.0 11009.0 PDK 10691.0 11021.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH 10694.0 10696.0 10697.0 10702.0 10713.0 10722.5 10745.5 10746.5 10757.5 10758.0 10759.5 10771.0 10771.5 10782.0 10783.0 10786.5 10789.0 10792.5 10794.0 10796.5 10803.5 10813.5 10814.0 10823.0 10825.5 10828.5 10829.5 10830.5 10831.5 10834.5 10835.0 10836.5 10837.0 10839.0 10840.5 10841.0 10847.0 ~mmmmmmmm GRCH 10692.5 10696.0 10700.5 10745.5 10759.5 10787.0 10797.0 10804.0 10815.5 10824.5 10826.5 10831.5 10832.0 10835.0 10836.0 10842.0 10848.0 in separate files. EQUIVALENT UNSHIFTED DEPTH ......... SGMA 10695.5 10697.5 10713.5 10722.5 10746.0 10757.0 10758.0 10771.0 10772.0 10782.5 10783.0 10790.0 10793.5 10794.5 10814.0 10815.0 10829.5 10830.0 10837.0 10838.0 10840.0 10842.0 10850.0 10852.5 10853.0 10855.0 10855.5 10858.5 10860.0 10861.5 10869.5 10870.5 10871.5 10872.5 10873.0 10882.0 10882.5 10883.5 10888.0 10889.0 10891.0 10904.0 10905.0 10907.0 10915.0 10915.5 10928.0 10931.5 10932.5 10933.0 10936.5 10940.5 10945.0 10948.0 10953.5 10962.5 10963.0 10967.5 10970.5 10974.5 10976.0 10981.0 10982.0 10984.0 10986.5 10987.5 10989.5 10990.0 10996.0 11003.0 11015.0 11019.0 $ REMARKS: 10851.0 10853.5 10854.5 10855.5 10856.5 10859.5 10860.5 10862.0 10869.5 10871.0 10871.5 10872.5 10873.5 10882.0 10883.0 10883.0 10883.5 10888.5 10889.0 10889.0 10904.0 10904.0 10904.5 10906.0 10914.0 10915.0 10927.5 10931.0 10931.5 10932.0 10935.5 10939.5 10944.0 10947.5 10953.0 10962.0 10962.0 10967.0 10969.5 10975.5 10977.0 10982.0 10982.0 10982.5 10982.5 10984.5 10987.0 10986.5 10987.5 10989.5 10990.5 10996.5 11003.5 11015.0 11019.0 PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH2A. OUT / ??MATCH2B. OUT $ CN : BP EXPLORATION WN : S - 16 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name T°ol Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 5 CSLS PDK 68 6 LS PDK 68 7 SS PDK 68 8 MSD PDK 68 9 RATO PDK 68 10 RBOR PDK 68 11 RICS PDK 68 12 RIN PDK 68 13 SGMA PDK 68 14 SGMB PDK 68 15 SGNT PDK 68 16 PHI PDK 68 1 GAPI 4 1 4 1 CPS 4 1 CPS 4 1 CU 4 1 CPS 4 1 CPS 4 1 CU 4 1 4 1 4 1 4 1 4 1 CU 4 1 CU 4 1 CU 4 1 PU-S 4 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 4 51 995 99 1 64 * DATA RECORD (TYPE# 0) 958 BYTES * Total Data Records: 52 Tape File Start Depth = 11045.000000 Tape File End Depth = 10685.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12258 datums Tape Subfile: 3 173 records... Minimum record length: 62 bytes Maximum record length: 958 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 START DEPTH 10690.0 10693.0 STOP DEPTH 11009.0 11021.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 10693.5 10692.0 10696.0 10694.5 10697.0 10698.5 10698.5 10697.0 10700.5 10701.5 10707.5 10708.5 10708.5 10709.0 10710.5 10709.0 10712.5 10713.0 10727.5 10727.5 10742.5 10742.0 10744.0 10743.5 10745.5 10746.0 10746.0 10746.5 10746.0 10747.0 10747.0 10757.0 10757.0 10757.5 10758.0 10758.0 10758.0 10758.5 10759.0 10766.5 10767.0 10771.0 10771.5 10771.5 10772.5 10776.5 10777.5 10777.5 10778.0 10778.0 10779.0 10787.0 10787.5 10788.5 10789.5 10793.0 10794.0 10794.5 10795.0 10797.5 10798.0 10803.0 10804.0 10804.0 10805.5 10813.0 10813.5 10813.5 10814.5 10815.0 10816.0 10815.5 10817.0 10819.5 10821.0 EQUIVALENT UNSHIFTED DEPTH ......... SGMA 10695.0 10825.0 10829.0 10830.0 10830.5 10836.0 10836.5 10837.5 10839.0 10839.5 10840.0 10849.0 10853.0 10856.0 10859.0 10861.0 10871.0 10883.0 10884.5 10886.5 10889.5 10890.5 10892.0 10894.5 10895.5 10901.5 10904.0 10904.5 10905.0 10905.5 10906.0 10914.5 10915.0 10924.5 10925.5 10929.0 10931.5 10948.0 10948.5 10956.5 10963.0 10967.5 10970.5 10974.0 10976.5 10980.0 10981.0 10983.5 10984.0 10986.0 10986.5 11001.0 11005.5 11006.0 11009.0 11010.0 11013.0 11014.0 REMARKS: PASS 3. 10826.0 10830.5 10837.5 10838.5 10841.5 10842.5 10858.5 10873.0 10885.0 10886.0 10891.5 10904.5 10905.0 10905.5 10914.0 10915.0 10924.5 10925.0 10967.0 10978.0 10981.5 10982.0 10985.0 10987.0 10830.0 10830.5 10831.5 10838.5 10841.0 10851.0 10855.5 10861.5 10863.0 10886.5 10891.5 10892.0 10896.0 10896.5 10902.5 10904.5 10905.0 10905.5 10929.0 10931.0 10947.5 10948.5 10956.5 10962.5 10970.0 10975.5 10982.5 10984.5 10986.5 11001.5 11005.5 11006.5 11009.5 11010.0 11013.0 11013.5 ALL PDK CURVES WERE SHIFTED WITH SGMA. / ? ?MATCH3A. OUT / ? ?MATCH3 B . OUT $ CN : BP EXPLORATION WN : S - 16 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 SS PDK 68 1 CPS 8 MSD PDK 68 1 CU 9 RATO PDK 68 1 10 RBOR PDK 68 1 11 RICS PDK 68 1 12 RIN PDK 68 1 13 SGMA PDK 68 1 CU 14 SGMB PDK 68 1 CU 15 SGNT PDK 68 1 CU 16 PHI PDK 68 1 PU-S * DATA RECORD (TYPE# 0) Total Data Records: 52 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 64 958 BYTES * Tape File Start Depth = 11045.000000 Tape File End Depth = 10685.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24516 datums Tape Subfile: 4 Minimum record length: Maximum record length: 180 records... 62 bytes 958 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: .5000 PASSES INCLUDED IN AVERAGE PBU TOOL CODE PASS NUMBERS GRCH PDK $ REMARKS: 1 1, 2, 3 AVERAGED PASS. PASSES 1, 2, & 3 WERE AVERAGED. $ CN : BP EXPLORATION WN : S - 16 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKL PNAV 68 1 CPS 4 3 BKS PNAV. 68 1 CPS 4 4 BIF PNAV 68 1 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 SS PNAV 68 1 CPS 4 8 MSD PNAV 68 1 CU 4 9 RATO PNAV 68 1 4 10 RBOR PNAV 68 1 4 11 RICS PNAV 68 1 4 12 RIN PNAV 68 1 4 13 SGMA PNAV 68 1 CU 4 14 SGMB PNAV 68 1 CU 4 15 SGNT PNAV 68 1 CU 4 16 PHI PNAV 68 1 PU-S 4 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 1 4 53 995 99 4 53 995 99 4 53 995 99 1 4 53 995 99 1 64 * DATA RECORD (TYPES 0) 958 BYTES * Total Data Records: 52 Tape File Start Depth = 11045.000000 Tape File End Depth = 10685.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24516 datums Tape Subfile: 5 74 records... Minimum record length: Maximum record length: 62 bytes 958 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10686.0 PDK 10686.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 11031.0 11043.0 30-JUL-95 FSYS REV. J001 VER. 1.1 1050 30-JUL-95 11257.0 11029.0 10690.0 11021.0 60O.O YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 11300.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 250 FAR COUNT RATE HIGH SCALE (CPS): 5250 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 1. NEAR COUNT RATE HIGH SCALE (CPS) = 100,000 $ CN : BP EXPLORATION WN : S - 16 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK. 68 1 GAPI 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 BIF PDK 68 1 4 5 CCL PDK 68 1 4 6 CSLS PDK 68 1 CU 4 7 CSS PDK 68 1 CPS 4 8 ISS PDK 68 1 CPS 4 9 G1 PDK 68 1 CPS 4 10 G2 PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 SS PDK 68 1 CPS 4 13 MON PDK 68 1 CPS 4 14 MSD PDK 68 1 CU 4 15 RATO PDK 68 1 4 16 RBOR PDK 68 1 4 17 RICS PDK 68 1 4 18 RIN PDK 68 1 4 19 SGMA PDK 68 1 CU 4 20 SGMB PDK 68 1 CU 4 21 SGNT PDK 68 1 CU 4 22 PHI PDK 68 1 PU-S 4 23 SPD PDK 68 1 F/MN 4 24 TEN PDK 68 1 LB 4 4 51 310 01 4 51 391 51 4 51 390 51 4 51 995 99 4 51 150 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 995 01 4 51 995 02 4 51 391 99 4 51 390 99 4 51 430 01 4 51 995 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 420 99 4 51 400 01 4 51 995 99 4 51 995 99 4 51 995 99 4 51 636 99 4 51 635 99 96 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 * DATA RECORD (TYPE# 0) 1006 BYTES * TotaI Data Records: 145 Tape File Start Depth = 11046.000000 Tape File End Depth = 10686.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 60542 datums Tape Subfile: 6 221 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10685.0 PDK 10685.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ STOP DEPTH 11030.0 11042.0 30-JUL-95 FSYS REV. J001 VER. 1.1 1140 30-JUL-95 11257.0 11029.0 10690.0 11021.0 600.0 YES TOOL NUMBER 3913NA 2725XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): .000 11300.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED FLUIDS .00 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 250 FAR COUNT RATE HIGH SCALE (CPS): 5250 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2. NEAR COUNT RATE HIGH SCALE (CPS) = 100,000 $ CN : BP EXPLORATION WN : S - 16 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units 1 GR PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 ISS PDK 68 1 CPS 9 G1 PDK 68 1 CPS 10 G2 PDK 68 1 CPS 11 LS PDK 68 1 CPS 12 SS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 1 18 RIN PDK 68 1 19 SGMA PDK 68 1 CU 20 SGMB PDK 68 1 CU 21 SGNT PDK 68 1 CU 22 PHI PDK 68 1 PU-S 23 SPD PDK 68 1 F/MN 24 TEN PDK 68 1 LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 51 310 01 1 4 4 51 391 51 1 4 4 51 390 51 1 4 4 51 995 99 1 4 4 51 150 01 1 4 4 51 995 99 1 4 4 51 995 99 4 4 51 995 99 1 4 4 51 995 01 1 4 4 51 995 02 1 4 4 51 391 99 1 4 4 51 390 99 1 4 4 51 430 01 1 4 4 51 995 99 1 4 4 51 420 99 1 4 4 51 420 99 1 4 4 51 420 99 4 4 51 420 99 1 4 4 51 400 01 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 636 99 1 4 4 51 635 99 mmmmmmm 96 * DATA RECORD (TYPES 0) 1006 BYTES * Total Data Records: 145 Tape File Start Depth = 11045.000000 Tape File End Depth = 10685.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 60542 datums Tape Subfile: 7 221 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10688.0 PDK 10688.0 $ LOG H~ADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIV SWIVEL SUB SBAR SINKER BAR PDK PDK-100 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 11030.0 11042.0 30-JUL-95 FSYS REV. J001 VER. 1.1 1229 30-JUL-95 11257.0 11029.0 10690.0 11021.0 600.0 YES TOOL NUMBER 3913NA 2725XA .000 11300.0 .0 PRODUCED FLUIDS .00 .0 .0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): .0 BASE NORMALIZING WINDOW (FT): .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 250 FAR COUNT RATE HIGH SCALE (CPS): 5250 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR .COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 3. NEAR COUNT RATE HIGH SCALE (CPS) = 100,000 $ CN : BP EXPLORATION WN : S - 16 FN : PRUDHOE BAY COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 24 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR PDK 68 1 GAPI 2 BKL PDK 68 1 CPS 3 BKS PDK 68 1 CPS 4 BIF PDK 68 1 5 CCL PDK 68 1 6 CSLS PDK 68 1 CU 7 CSS PDK 68 1 CPS 8 ISS PDK 68 1 CPS 9 G1 PDK 68 1 CPS 10 G2 PDK 68 1 CPS 11 LS PDK 68 1 CPS 12 SS PDK 68 1 CPS 13 MON PDK 68 1 CPS 14 MSD PDK 68 1 CU 15 RATO PDK 68 1 16 RBOR PDK 68 1 17 RICS PDK 68 1 18 RIN PDK 68 1 19 SGMA PDK 68 1 CU 20 SGMB PDK 68 1 CU 21 SGNT PDK 68 1 CU 22 PHI PDK 68 1 PU-S 23 SPD PDK 68 1 F/MN 24 TEN PDK 68 1 LB 4 4 51 310 01 1 4 4 51 391 51 1 4 4 51 390 51 1 4 4 51 995 99 1 4 4 51 150 01 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 01 1 4 4 51 995 02 1 4 4 51 391 99 1 4 4 51 390 99 4 4 51 430 01 1 4 4 51 995 99 1 4 4 51 420 99 1 4 4 51 420 99 4 4 51 420 99 1 4 4 51 420 99 1 4 4 51 400 01 1 4 4 51 995 99 1 4 4 51 995 99 1 4 4 51 995 99 4 4 51 636 99 4 4 51 635 99 1 96 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 145 Tape File Start Depth = 11045.000000 Tape File End Depth = 10685.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 96568 datums Tape Subfile: 8 221 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 9 is type: LIS 95/ 8/03 01 **** REEL TRAILER **** 95/ 81 3 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 3 AUG 95 ll:06a Elapsed execution time = 10.71 seconds. SYSTEM RETURN CODE = 0 [:4 ~ ,0 01 102a. PANG: TLJW 1,~: 12 SECT: 35 COON: N. STAT: CTRY: TYPE OOO 000 000 000 000 000 00o o00 000 OOo 000 000 000 OOo 000 000 000 000 030 004 012 O05 007 012 006 004 CODE 0o5 065 065 O65 O65 065 O65 065 I~,'l'",{ I'1 I! I iil iI:~ ,[! [:t I DgNSITY V ISC OS I 'I'Y F~UI.L L. OSb AI..AbI:iY FOCUSED:[,OG' {Dlb) T,,*PE. CODE eJ ~'IRi 5 .lin DA'!"l,.ib~ SPECIFICATiOM BLOCKS ORDER LOG' TYPK CbA.'SS ~OO NO' CODE : ' ('OCOmA:L) , t~U 000 ,00 O O: 4 1 6~ 0 O: 220 0 i 0 0 ~ i 6~ GAOl gU 3i0 oi GADI O0 310 Ol I :'~ 00 28 0 O 1 G/C3 00 350 02 G/C3 gu 3b~ Ol 0O ~.2n 01 O0 00o gu Pij O0 P, 90 OO 35~ gl CP~ o0 33o 3i 00000000000000 OOOO000000000O O00000OO000000 00000000000000 00OO0000000000 00000000000000 O00000UO000000 O00OOOO0000000 O000OOOOOO0000 O000OO00000000 G k P ~ 3 -999. 2500 'ILD 99,,. -999,2500 · ,:9 ~ 9:' -, , , , 0000 -999:-'~ 500 -999.25'00 2i; 3594 -999,25'0 5OOO 2O; 6055 1.9092 ~";3672 RHOB 1559;0:000 -999,2500 ~,0723 27'73 2500 1110 G.N 21 PEF 2 GR -999 -99 .2500 PT 2172:5O0 -999 ~UO0 7~.37'50 ,42'3 '0430 -999.2500 DEF'J' 1. i SP - t, PEF GR -99 15.3'125 ILD 25,b313 GR 25.3'750 CALl 2,304'1 412n. o0o0 FCNL, -9~9. 250U 12.3438 Ib~ 16'/1.0QUO -999,2500 11,3438 ~4,3125 2,3105 ~2~,5352 -:~99'2500 20. 109~ ILO 24.9375 Gx 22,6503 CALl 2.3 34 0 !:~ r4 !-,' a 364E., 0009 FCNL, -999. 2500 GR -99g.250o DT 8,39~4 N~Ob 2.459o NPH~ 1483.0000 GR 1.~,8984 82,7500 2~3828 24:,0234 '999,2500 SP -11.1.562 GA 39,3125 ]i.,D 97.bH75 G~ 1'll.5025 CAI,Z 20,984i ILM 9,1172 RHlJb 22.5000 78,~75 2.5000 L"I~¢] ri 1 ! 1 iii iI~ iii [q iii _ .... :'4. ,~ ,~ii~! U.l 5o ~,{::A'i : ' 3574 R~iRA 6367 N~EI 23;3887 25 ~') O G i,: 999.2 $ O 0 G R - 999,2500 O u (') 0 5 F L ,., 1.828 'i I I., D 1, ,! t ~ 0 iL ~ I. 47'85 116;50~)0 (.;R -999'~500 CALl '999,2'500 RHO[~ - 99,250'0 2500 NCf,~L -999. 2500 FCNI, -999. 2500 GR -99g,2500 D E P T !. 0400.0 O <) 0 5 ?' I, ii3 2. SP i ~. "1 ?t:,O GR ~ '8125 G9 - 99; ORHu '999 ....... ~'~ ..... ,:2590 ,'.~ ~t A i ' 999, PEF -g99. 25500 SC3iL '9'99, Ga -999.2bU0 G~ DEPT 103~O,OgUU ,. FbU SP -25,5000 Gt:t 1 C" , - 999 DKHO -999,25~1o :,~ k/~ T -999' PEF -999.250u ~sk'. M b -9~9, G[~ -999. 2500 ('~ -999 OEP'I I OloO.o(~ou 8Fbu 2. SP -38.0UNO (;:~ 75, GN 84.1875 (;M -999, DRHO -999.2500 r~RAT 999. PEF -999.2 b':) g NCNb -999, GR -999.2bOu GR -999. DEPT ;I. 0000. nOl}O SFI,o 2500 2L~O0 CALl -~9:9 2500 R~OB ~ . , ~, ~ ' , ~ ,, . .., 2500 GR 999,2500 2 00'5'9 7969 lbo 2500 GR 2500 CAbI -99,9 2500 ~ ~<~ R. - 999 2500 FCab -999,2500 2500 GR -999'2500 2500 2500 2500 8'750 GR ~9.8750 UT 2500 CAI,I -999,2b00 RHOB 2500 ~i, RA -999.2500 NPMi 2500 FCt.}b 99 2oC0 Ga 2bOu G~ -999,2500 2.9141 87~0~2§ -999,2500 -999,2500 -999,2500 943~ lbD 2,8320 ibm 8750 GR -999.2500 DT 2500 CALI -999,2m00 RitO~ 2500 R~:R~ -999.2500 NPHI 2500 FCNu -999.250u gk 2500 (;R -999.2500 2,9141 88.8750 -99~,2500 -999,2500 -999,2500 3.2U5i Ib{) 3.1406 ibm 3,2617 SP DRHO PEF D~PT S P D~6PJ? SP Da GR -~,7.50'00 d~ 75. 937 5 G~ ' '9:99 j~ b02!3 (~,~ .gqc'. ~:"[~ :' ~ ~' '~'~"c .9 5000: ...... , , 2..~ U C~l,z 9~ 99,2500 , : 2 b,~'j ~A: '99~, 250:0 .'~:~ 2500 -q99,2500 ~':C~'~] '999 2'5o0 FCb~L '999,2500 GR -999'.2500 -999. 2500 GF ":999 ;2.500 G~,, -,~,.,e~, 2500 -q: 99 8[,;' GR D B F! u SP ORHU PEF GR D t; P T SP ,,, 1250 G R - ;.~ 99,2500 D T 8., 625 0 CALl :~:9, :. 250J R~lOb: -999, '~'5:00 ,2500 R{.4RA '099' 2500 NPF~I -999' 2500 ,25du ~ C~ ~9,2500 r ' ~: .!87~ ,~ 56.' c~,,.-7~ 5 .0723 ],[,D 2.5625 IL/~ 2 5[{:59 ~.. ,! .,, , : . , , , f ~ ~ ' :2500:2500 GN . :-9~969:6250 .250c. 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