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178-013
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): 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 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: Authorized Title: Authorized Signature with date: Contact Name: Contact Email: Contact Phone: PBU 07-05 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 178-013 50-029-20293-00-00 10750 Conductor Surface Intermediate Production Liner 9172 80 2677 10701 709 10225 20" 13-3/8" 9-5/8" 2-7/8" 8718 37 - 117 37 - 2714 35 - 10736 9801 - 10510 37 - 117 37 - 2714 35 - 9160 8361 - 8964 none 520 2670 5080 / 4760 11165 10225 1530 4930 8150 / 6870 10566 9876 - 10578 8423 - 9023 Structural 4-1/2" Baker SB-3A HYD PERM PKR Bo York Operations Manager Ryan Thompson Ryan.Thompson@hilcorp.com (907) 564-5280 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 13.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 0028309 289 263 32805 15273 11 1 0 0 929 250 n/a STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Senior Pet. Engineer: Senior Res. Engineer: Form 10-404 Revised 3/2020 Submit Within 30 days or Operations 4-1/2" 12.6#13Cr85 / L-80 33 - 8258 / 8267 - 8408 9526 8138 33 - 9674 / 9685 - 9851 No SSSV 9526 8138 By Samantha Carlisle at 10:08 am, Oct 12, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.10.11 20:36:31 -08'00' Bo York MGR15OCT2021 SFD 10/12/2021DSR-10/12/21 RBDMS HEW 10/12/2021 ACTIVITYDATE SUMMARY 9/2/2021 ***WELL SI ON ARRIVAL*** DRIFT FOR CIBP 2.2" CENT' TAG @ 10573' SLM (SAND IN SAMPLE BAILER DRIFT WITH 33' OF 2.18" DUMMY GUN TO 10573' SLM ***WELL LEFT SI*** 9/18/2021 ***WELL SHUT IN ON ARRIVAL*** LRS LOADED TBG W/ CRUDE TO ENSURE SHOOTING GUNS IN FLUID. RIG UP AK ELINE. RUN 1: SET 2-7/8" (2.1" OD) LEGACY OIL TOOLS CIBP AT 10225', CCL TO ME = 13', CCL STOP DEPTH = 10212' RUN 2: PERFORATED INTERVAL 9876' TO 9907' WITH 31' X 2" GEO CONNEX PERF GUN, CCL TO TS = 7.5', CCL STOP DEPTH = 9868.5'. RIG DOWN ELINE UNIT. ***JOB COMPLETE / TURN OVER TO DSO TO POP*** 9/18/2021 T/I/O=2300/915/370 LRS Unit #72 Assist E-Line (PERFORATING) Pumped 280 BBL's of 110* crude down the tubing to load pre-E-line. FWHPs=0/985/420 Daily Report of Well Operations PBU 07-05 07-05 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:178-013 6.50-029-20293-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10750 10693 9123 9526 none none 8138 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 37 - 117 37 - 117 1530 520 Surface 2677 13-3/8" 37 - 2714 37 - 2714 4930 2670 Intermediate Production 10701 9-5/8" 35 - 10736 35 - 9160 8150 / 6870 5080 / 4760 Perforation Depth: Measured depth: 10386 - 10578 feet True vertical depth:8857 - 9023 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13CR-85 x L-80 28 - 9851 28 - 8402 9526 8138Packers and SSSV (type, measured and true vertical depth) 4-1/2" HES TNT Liner 709 2 -7/8" 9801 - 10510 8361 - 8964 10566 11165 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 799035419 7534559 0 27744 433 981 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-5280 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9172 Sundry Number or N/A if C.O. Exempt: 321-215 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Tubing Swap Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028309 PBU 07-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:36 pm, Aug 05, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.08.05 09:22:26 -08'00' Bo York DSR-8/6/21MGR05AUG2021 RBDMS HEW 8/9/2021 ACTIVITYDATE SUMMARY 2/22/2021 T/I/O = 130/130/210. Temp = SI. CMIT-TxIA PASSED to 2457/2455 psi (Pre- RWO). No AL. TBG & IA FL @ surface. OA FL @ near surface. Used 8.9 bbls amb Diesel to pressure T/IA to 2507/2504 psi. T/IA decreased 33/32 psi in the 1st 15 min, and 17/17 psi in the 2nd 15 min for a total of 50/49 psi in 30 min. Bled T/IA to 100/100 psi (8.9 bbls). Hung tags. OA integrity test to 1200 psi PASSED (Pre-RWO). Used 2.4 bbls amb Diesel to pressure OA to 1200 psi. No visible leaks. Monitored for 5 min. OAP decreased 230 psi to 970 psi. No visible leaks detected on the surface kit or anywhere else. Bled OAP to 100 psi (0.5 bbls). Hung tags. Final WHPs = 130/130/100. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 2/23/2021 T/I/O = 130/130/180. Temp = SI. PPPOT-T (PASS), PPPOT-IC (PASS) (pre RWO). PPPOT-T: Stung into test port (500 psi), bled void to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Torqued to 550 lb/ft. Single port, unable to pump through void. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (0+ psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. One gland nut in the 10 oclock position sheared the starting threads when running back in. RU bleed hose to IA & OA and bled to BT to 0 psi, maintained open bleed. Pulled LDS and bad gland nut. Ran tapered tap through gland nut profile, inspection showed that ther threads on the head were good. Installed new LDS assembley and gland nut. Torqued all to 550 lb/ft. Pressured test void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. FWHP's = 130/0/0. SV, WV, SSV = C. MV = O. IA & OA = OTG. 19:30 3/11/2021 ***WELL S/I ON ARRIVAL***(rwo expense) PULLED UPPER BKR 45KB PATCH @ 5002' MD.(intact) ***CONT'D ON 3/12/21 WSR*** 3/12/2021 Assist Slickline: TBG/IA load (RWO Expense) Road unit to location/ released from job no fluids pumped. HSL in control of well upon LRS departure 3/12/2021 (TFS Unit 1 Assist Slick-Line with load and Test) Arrived on location, stoodby for Slickline *****WSR Contunied on 3/13/2021***** 3/12/2021 ***CONT'D FROM 3/11/21 WSR***(rwo expense) PULLED LOWER BKR 45KB PATCH @ 9502' MD.(intact) RAN 10' x 2.25" PUMP BAILER TO XX-PLUG @ 9789' MD.(recovered 1 gallon of pct) EQUALIZED & PULLED 2-7/8" XX-PLUG @ 9789' MD. PULLED 45KB/NIPPLE REDUCER ASSY @ 9778' MD.(missing 1 element) ***CONT'D ON 3/13/21 WSR*** Daily Report of Well Operations PBU 07-05 Daily Report of Well Operations PBU 07-05 3/13/2021 ***CONT'D FROM 3/12/21 WSR***(rwo expense) BRUSHED TBG W/ 4-1/2" BRUSH & 3-PRONG GRAB TO LTP @ 9778' MD. SET 4-1/2" EVO-TRIEVE PLUG W/ P-SUB @ 9773' MD. SET EVO-TRIEVE PRONG AND JUNK CATCHER @ 9,772' SLM. ***PULL W/ 4" GS*** THUNDERBIRD PERFROMED PASSING CMIT-TxIA 2750 PSI. ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 3/13/2021 *****WSR Continued from 3/12/2021****(TFS Unit 1 Assist SL with Load and Test) T/I/O=450/200/100 Temp=S/I CMIT-TxIA Passed to 2940 psi. Max applied pressure=3000 psi. Target pressure=2750 psi. Pumped 10.7 bbls of crude down the tbg to reach test pressure. 1st 15 min T/IA lost 50/5 psi. 2nd 15 min T/IA lost 10/5 psi. Total loss of 60/10 psi in 30 min test. *PASS*. Established LLR of less than 0.1 BPM from tbg to IA. FWHP=300/300/100 Slickline still on well upon departure. 3/30/2021 ***COST PLACEHOLDER*** PURCHASE 3 - 1 7/8", 1 - 1 5/16" STEEL BALLS 6/3/2021 ***WELL SI ON ARRIVAL*** PULLED RK-DGLV IN ST# 7 @ 9394' MD ***JOB COMPLETE, WELL LEFT S/I, DSO NOTIFIED OF STATUS*** 6/6/2021 T/I/O=135/30/130 Circ-Out (RWO) Pump 670 bbls 1% kcl down tbg returns up IA to open top tanks. Pump 170 bbls diesel down tbg U-tube Tbg x IA for 1 hr. Freeze protect hardline w/5 bbls diesel FWHPs=470/470/55 6/7/2021 Pollard E-line: Chem. Cut Tbg. RUN 1: PERFORM STRING SHOT OVER INTERVAL 9676' - 9686' 15 min CMIT-TxIA passed to 460 psi RUN 2: CUT TUBING AT 9685', CCL TO CUT 14.3', CCLSTOP DEPTH = 9670.7' 5 min CMIT-TxIA passed to 500 psi BLEED TXIA TO 0 PSI Job Complete 6/11/2021 T/I/O = Vac/Vac/130. Temp = SI. Bleed CL/BL to 0 psi (pre-rig). No FL or well house, drilling scaffold on well. Bled CL/BL to 0 psi. Stung into TBG hanger test void (0+ psi), bled to 0 psi. Removed BL housing and installed blank flange. SV, WV, SSV = C. MV = O. IA & OA = OTG. 13:45 7/1/2021 T/I/O = VAC/VAC/240. Temp = SI. Bleed WHPs (pre RWO). OA FL @ near surface. Bled OAP to BT to 0 psi in 5 hrs (gas/fluid mix, 0.2 bbl). Held open bleed for 1 hr. Monitored for 30 min. OAP increased 11 psi. Final WHPs = VAC/VAC/11. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:30 7/2/2021 T/I/O = 0-/0/0. Pre-RWO ND Tree / NU BOP Valve shop used lubricator to set 5" K plug. #615. Sting into tubing hanger test void. 0 psi on test void. Assist Worley to ND tree. Clean void and ring groove, install new BX-160. Test fit 5.875 MCA landing sub. Unable to get more than 1 turn due to sub ID impinging on K plug OD. Visually inspect MCA lift threads and they look good. Installed K plug test dart for BOP test. Function tubing hanger LDS to clear bowl at 3-3/4" OUT measurement. All LDS functioned smoothly, Re-torque all LDS and gland nuts to 600 ft/lbs. Assist Worley with setting BOPs. Orient BOPs per Thunderbird tool pusher's marks. Worley crew continued with torquing 13-5/8" 5M connection. RDMO Daily Report of Well Operations PBU 07-05 7/3/2021 TBird-1: New WSR for Well 07-05 started at 00:01 on 7/3/2021. Job Scope TBG Swap with Tubing Spool Replacement. Continue clearing location on 18-26 and prepping equipment to be moved to 07-05. Move Rig to Thunderbird Yard in Deadhorse to replace Packing elements on both telescoping rams.Trucks move all trailers to DS 07. 7/4/2021 TBird-1 Job Scope: Tubing Swap Walk down of location with crew. Review Daily Plan Forward w/ crew. Procedure for spotting equipment and rigging up Dragon rig. RU Dragon rig and supporting equipment. Preform function test of BOPE. Shell test BOP and calibrate gas sensors. AOGCC witness; Austin McLeod, 250 psi Low / 3000 psi High Annular 250 psi Low / 2500 psi High. 10 min each. Accumulator draw down. Passing test. 10-424 emailed to AOGCC. Pull dart and liberate K-Plug from hanger. Closed blind rams and rocked out diesel from TBG & IA. MU landing joint and installed into hanger 16 1/2 turns. Pulled hanger free at 112k and continued 5' up and stopped ~40k over for a few minutes then back down to just above hanger bowl. PU to ~50k over and completion came free. Hanging Wt 112k. pulled hanger to rig floor and terminated both 1/4" SSSV control lines and 3/8" chemical injection line. ...Continue WSR on 7/5/2021... 7/5/2021 TBird-1 Job Scope: TBG Swap. ...Continue WSR from 7/4/2021... Pull 4 1/2" TBG with two 1/4" control lines (2200') and one chemical injection line (9620') Pulled TBG to SSSV and one joint past and attempted to rotate completion with no luck. Well directional showing most of completion hanging at 40-45 deg. W ith centralizers every joint this is contributing to the issue of rotation. Circ 120 bbls of 1% KCL down TBG then continue pulling. ...Continue WSR from 7/5/2021... 7/6/2021 Pull 4 1/2" TBG with chemical injection line. Pulled 143 joints then attached 9 5/8" Storm PKR at joint 144. RIH and set PKR @ 68' (42K) then pressure tested top side to 500 psi (Good) Pulled BOP, TBG head and upper IC-packoff. Removed lower IC- packoff and installed new lower IC-packoff. Installed new TBG head. Tested void to 3500 psi. Installed test plug in TBG spool. NU and test BOP break 250 psi Low / 3000 psi High. While pulling test plug crew found broken guide tab from VBR insert on top. Made call to Yellow Jacket and had service tech come out and check it out. Calls/conversations led to decision to swap out BOP stack. Send notification to AOGCC for witnessing BOPE test. AOGCC responded within two hours and waived witnessing the test. Rigged back floor and prepped area for crane activities. WS arrived on location with crane and replacement stack just after midnight. ...Continue WSR on 7/7/2021... 7/7/2021 ***RIG ON WELL UPON ARRIVAL***(rwo) GATHER TOOLS AND STANDBY FOR RIG ASSIST ***WSR CONTINUED ON 7/8/21*** 7/7/2021 T/I/O=0/0/0. Pulled 5" K BPV through stack with 8' of extention with gray lubracator. Job Complete. Daily Report of Well Operations PBU 07-05 7/7/2021 TBird-1 Job Scope: TBG Swap: ...Continue WSR from 7/6/2021... Swap BOP stack. Hook up hoses and function test. Preform BOPE test. Witness waived; Austin McLeod, during BOPE testing. Test BOP and valves 250 psi Low / 3000 psi High Annular 250 psi / 2500 psi Test PVT's preform draw down on Koony system. Test PVT and gas sensor alarms. All Passing tests. Send 10-424 form to AOGCC. RIH w. 2 7/8" work string and recover Storm PKR set @ 68' latch and check for pressure. Recovered PKR start pulling 4 1/2" completion. Old completion pulled just before midnight. Chemical cut looks clean; picture taken and sent to OE, cut joint fit tested in overshot. ...Continue WSR on 7/8/2021,,, 7/8/2021 ***WSR CONTINUED FROM 7/7/21*** (rwo) MADE (2) 8.29" JUNK BASKET RUNS TO TOP OF TBG STUB @ 9685' ELMD. (recovered 1 band, 3/4 gallon control line coating, 2 rubber pieces) RAN 9-5/8" BRUSH, WIRE SCRATCHER, 4 PRONG 5.54" WIRE GRAB TO 9,685' ELMD. (recovered 1 band) RAN 4.89" TAPERED LIB TO TBG STUB @ 9,685' ELMD. (clean impression of stub) ***THUNDERBIRD RIG ON WELL UPON DEPARTURE*** 7/8/2021 TBird-1 Job Scope: TBG Swap: ...Continue WSR from 7/7/2021...4 1/2" completion pulled. All clamps accounted for, missing several stainless steal bands. RU Slickline to drift CSG and fish bands. BHA #1 RIH w/ 8.29" junk basket to ~6100' saw sinificant weight loss. Worked area and POOH. OOH w/ rubber from encapsolated line and rubber packing elements missing from TBG hanger. BHA #2 Make second run with 8.29" Junk Basket... Drift to 9651 SLM Top of TBG stub. OOH w/ a few pieces of Hanger packing and more plastic/rubber from control line. BHA #3 RIH w/Braden line brush and wire grab tag top of tubing stub @ 9651' SLM Recovered stainless steel band (Total of 2 recovered with slickline). BHA #4 RIH w/ 4.89" tapered LIB to tubing stub @ 9651' SLM OOH w/clean impression of TBG stub. Rig down Slickline and start running 4-1/2" VamTop L-80 Completion with GBR Torque-N-Turn Services Call Kick while tripping drill while running new completion. ...Continue WSR on 7/9/2021... Daily Report of Well Operations PBU 07-05 7/9/2021 TBird-1 Job Scope: TBG Swap. ...Continue WSR from 7/8/2021... At midnight last night 225 joints of the new completion had been ran. The tripping process in hole was then slowed knowing we were close to the old tubing stub. We made the connection on joint #226 then slowly crept in the hole looking for the signs of the overshot going over the stub. It appeared that we started over the stub and confirmed it by seeing the first set of shear pins go. We continued moving down slowly looking for the next set of pins and had to add joint #227. We crept deeper another 5¿ 7¿ and stacked out. We put 20k down then pulled back up to get our weight back (118k) continued up to 20k over and stopped for a few minutes. Continued up and pulled free @ 135k. Decision to pull joint #227 and RU to reverse circulate. Came on line at min rate and established returns. Continue to increase pump rate slowly making sure not to pack off. Once at rate started to recipicate slowly up/down until all free of any obstructions. Pick up Pup Joint and Tag No-Go. POOH and M/U Space out subs and hanger and land 4-1/2" 12.6# Completion, RILDS and reverse circulate 100 BBLs 1% KCL, 300 BBLs of Corrosion Inhibited 1% KCL and 220 BBLs of 1% KCL. Drop Ball and Rod and Set Packer and conduct MIT Tbg by Pressuring up to 3180psi. 15 minute pressure was 3100psi and 30 minute pressure was 3090psi. Bled Tbg pressure to 2000psi and pressured up on IA for MIT, Initial pressure was 3120psi, 15 minute pressure was 3120psi and 30 minute pressure was 3110psi. Bleed Tbg pressure to Shear GLM and Freeze protect well with 175 BBLs of Diesel. Install TWC and test from underneath. Good Test. Blow Down all lines and RDMO. 7/10/2021 T/I/O = TWC/VAC/200. Post Rig. ND BOP'S. NU THA torque to API specs. Wellhead Tech PT. Install 4" CIW Tree with SH3000 Booster. Torque to API specs. PT to 350/5000psi (PASS) Pull TWC #432 at 125". RDMO ***Job Complete*** Final T/I/O = VAC/VAC/200. 7/10/2021 ***WELL S/I ON ARRIVAL*** (post rig) PULLED BALL & ROD FROM 9601' SLM. ATTEMPTED TO PULL RK-DGLV FROM STA# 3 (5870' MD); SHEARED JD. IA PRESSURE RESPONSE OBSERVED. ATTEMPTED TO PULL RK-DGLV FROM STA# 3 (5870' MD). UNABLE TO LATCH. MARK ON JD SKIRT CONSISTANT W/ EMPTY POCKET. ***WSR CONTINUED ON 7-11-21*** 7/11/2021 ***WSR CONTINUED FROM 7-10-21*** RAN 3.60" BELL GUIDE W/ GUTTED 2.5" JD. AGGRESSIVELY SWEEP GLM's. RECOVER STA# 3 RK-DGLV FROM RHC @ 9612' MD. PULLED RKP-DCR FROM STA# 4 (3377' MD). SET RK-LGLV IN STA# 4 (3377' MD). SET RK-OGLV IN STA# 3 (5870' MD). PULLED 3.81" RHCM PLUG BODY FROM 9612' MD. RAN 3" PUMP BAILER TO 9,762' SLM (recovered 3 cups solids) MADE 6 RUNS W/ 2.5" BAILER W/ FINGER BASKET FROM 9,756' SLM TO 9,773 SLM (recovered ~7 gallons of solids) PULLED JUNK CATCHER & EQ PRONG FROM 9764' SLM. PULLED 4 1/2" EVO-TRIEVE PLUG BODY FROM 9773' SLM (ALL COMPONENTS ACCOUNTED FOR). ***WELL S/I ON DEPARTURE. COMPLETE*** 07-05 STATE OF ALASKA J&111Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Supry �I�Ll BOPE Test Report for: PRUDHOE BAY UNIT 07-05 Comm Contractor/Rig No.: Hilcorp Thunderbird I PTD#: 1780130 - DATE: 7/4/2021 Inspector Austin McLeod Insp Source Operator: Hilcorp North Slope, LLC Operator Rep: Jay Murphy Rig Rep: John Hoskins Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopSAM210704182807 Rams: Annular: Valves: MASP: Type Test: INIT 321.215 250/3000 � 250/2500 250/3000 2376 Related Insp No: TEST DATA MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: CHOKE MANIFOLD: P/F P/F Visual Alarm Time/Pressure P/F Quantity Location Gen.: P Trip Tank P - P System Pressure -- 3000 P Housekeeping: _P Pit Level Indicators P P ' Pressure After Closure 1550 P PTD On Location P Flow Indicator P P 200 PSI Attained 22 P Standing Order Posted P-' Meth Gas Detector --P P -' Full Pressure Attained 108 P Well Sign P H2S Gas Detector P P_ Blind Switch Covers: All stations P Drl. Rig P, MS Misc _NA_ NA Nitgn. Bottles (avg): 6(x,2262 P ' Hazard Sec. P #4 Rams 0 NA ACC Misc 0 NA Misc NA #5 Rams 0 NA INSIDE REEL VALVES: FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 0 NA' Stripper - INA No. Valves 11 P Lower Kelly 0 NA' Annular Preventer _0 1 13-5/8 P - Manual Chokes 2 P Ball Type 1- P- #1 Rams I ' 2-7/8x5-1/2 P- Hydraulic Chokes 0 NA Inside BOP _1 P - #2 Rams _ 1 Blinds P CH Misc 0 NA FSV Misc 0 NA #3 Rams 0 NA #4 Rams 0 NA #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 -3-1/8 P - Quantity P/F HCR Valves I -3-1/8 - P - Inside Reel Valves - -0 -NA Kill Line Valves 3 ' 3-1/8 P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 Test Results Remarks: 4-1/2" joint. Good test Test Time 3.5 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:178-013 6.API Number:50-029-20293-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028309 Property Designation (Lease Number):10. 8. PBU 07-05 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 5 Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10750 Effective Depth MD: L-80 11. 6/1/2021 Commission Representative: 15. Suspended Contact Name: Ryan Thompson Contact Email: Ryan.Thompson@hilcorp.com Authorized Name: Bo York 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: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9172 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9738, 8309 No SSSV Installed Date: Liner 709 2-7/8"9801 - 10510 8361 - 8964 10566 11165 Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 37 - 2714 37 - 2714 14. Estimated Date for Commencing Operations: BOP Sketch 37 - 117 Structural Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker SB-3A HYD PERM PKR 10386 - 10578 8857 - 9023 4-1/2" 12.6# L-80 35 - 9858 Production 9773 8338 9773 none 37 - 117 520 13-3/8" Contact Phone:(907)564-5280 Date: 80 153020"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 2677 4930 Intermediate 10701 9-5/8" 35 - 10736 35 - 9160 8150 / 6870 5080 / 4760 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 2376 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. 4-26-21 By Samantha Carlisle at 11:24 am, Apr 26, 2021 321-215 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.04.26 11:09:59 -08'00' Bo York DSR-4/26/214/26/2021 10-404 MGR13MAY21 BOPE test to 3000 psi. Annular to 2500 psi. dts 5/13/2021 JLC 5/13/2021 5/14/2021Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.14 10:13:41 -08'00' RBDMS HEW 5/14/2021 RWO 07-05 Well Name:07-05 API Number:500292029300 Current Status:Shut-In Rig:Thunderbird Estimated Start Date:6/1/2021 Estimated Duration:5 days Regulatory Contact:Carrie Janowski Permit to Drill Number:178-013 First Call Engineer:Ryan Thompson 907-564-5280 907-301-1240 Second Call Engineer:Dave Bjork 907-564-4672 907-440-0331 AFE Number:215-00611.16.11 IOR 110 Current Bottom Hole Pressure:3256 psi @ 8,800’ TVD 7.2 PPGE | Offset well 07-33C 9/16/16 Max. Anticipated Surface Pressure:2376 (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2450 (Taken on 8/20/17) Min ID:2.25” Max Angle:47° @ 6100’ MD Brief Well Summary: 07-05 was initially drilled in 1978, had a RWO in 1989 and a CTD liner installed in 1994. The well went not operable in August of 2017 for a tubing leak. A patch was set in April 2018 but the well would not pass an MIT- T. An LDL was ran in March 2020 identifying a second leak in the well. In August 2020 the patch was pulled & two new patches were set. The well passed a CMIT but still failed an MIT-T, therefore a RWO is being pursued to change out the tubing. Objective: Pull the existing 4 ½” L80 tubing out of the well and replace with new L80 tubing. Achieve a passing MIT-IA & MIT-T. Pre RWO work already complete (current schematic reflects completed SL work below). DHD – MIT OA – 1200 psi Cycle LDS’s PPPOT-T PPPOT-IC SL – 1. Pull 1 trip patch 2. Pull widepack packer 3. Drift for Eline cutter 4. Set Evotrieve w/ prong & junk catcher. 5. CMIT-TxIA to 3000 6. LLR Tubing to IA Pre RWO work still to be completed: EL – Cut tubing @ ~ 9685’ Circulate well to 8.5 ppg 1% KCL w/ diesel FP on T & IA 00 Completed s completed SL work below) RWO 07-05 DHD - Bleed WHP’s to 0 Valve Shop – 1. Set and test TWC 2. Nipple down tree & Tubing Head Adapter (THA). Inspect lift threads. 3. Nipple up BOPE to THA flange. Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3000psi High, annular to 250psi Low/2500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2 7/8” x 5 ½” VBR’s with a 4 ½” test joint. Test the Annular preventer with a 4 ½” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. 4. Rock out diesel freeze protect from T & IA. 5. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~110K 6. Pull tubing hanger to the floor and circulate bottoms up. 7. Pull 4 1/2” tubing to below the SSSV. 8. Set Storm packer and test to 1000 psi 9. Nipple down BOP’s 10. Remove tubing head. 11. Remove and install new IC packoffs. 12. Install new tubing head. Test IC void to 3500 psi. 13. Install test plug. 14. Nipple up BOPE and test break in stack to 250 psi low / 3000 psi high. 15. Pull test plug. 16. Pull storm packer. 17. Pull remainder of 4 ½” completion. 18. Run 4 ½” tubing with stacker packer completion as detailed on proposed schematic. 19. Land Hanger and reverse in corrosion inhibited 8.5 ppg 1 % KCL. 20. Drop ball and rod and set packer with 3,500 psi pump pressure. 21. Perform MIT-T to 3000 psi and MIT-IA to 3000 psi for 30 charted minutes. 22. Shear valve and circulate FP fluid. 23. Set TWC. 24. Rig down Thunderbird #1. Post rig Valve Shop Work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC RWO 07-05 Post rig Slickline Work 1. Pull Ball and rod 2. Pull RHC profile 3. Pull Downhole plug 4. Set GLV’s per GL Engineer 5. RDMO & pop well Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing RWO 07-05 Wellbore Schematic RWO 07-05 Proposed Wellbore Schematic RWO 07-05 RWO BOPs RWO 07-05 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:178-013 6.50-029-20293-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10750 9789 8351 9738 none 9789 8309 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 37 - 117 37 - 117 1530 520 Surface 2677 13-3/8" 37 - 2714 37 - 2714 4930 2670 Intermediate Production 10701 9-5/8" 35 - 10736 35 - 9160 8150 / 6870 5080 / 4760 Perforation Depth: Measured depth: 10386 - 10578 feet True vertical depth:8857 - 9023 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 35 - 9858 35 - 8408 9738 8309Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker SB-3A HYD PERM PKR Liner 709 2-7/8" 9801 - 10510 8361 - 8964 10566 11165 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 799035419 00 0 27744 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Ryan Thompson Ryan.Thompson@hilcorp.com Authorized Name:Torin Roschinger Authorized Title: Authorized Signature with Date:Contact Phone:(907) 564-5280 Treatment descriptions including volumes used and final pressure: 13. Sr.Operations Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9172 Sundry Number or N/A if C.O. Exempt: Junk Packer Printed and Electronic Fracture Stimulation Data 5 set patches, failed Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028309 PBU 07-05 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:48 pm, Sep 16, 2020 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2020.09.16 12:42:35 -08'00'Torin Roschinger (4662) DSR-9/18/2020 RBDMS HEW 9/17/2020MGR18SEP2020 ACTIVITYDATE SUMMARY 8/16/2020 ***WELL S/I ON ARRIVAL*** TAGGED 45 KB PKR PATCH W/ 3.80" GAUGE RING @ 4,998' MD. ATTEMPTED TO PULL 45 KB PKR PATCH @ 4,998' MD. PATCH HUNG UP @ 3,171' SLM, UNABLE TO PASS. ***JOB CONTINUED ON 8/17/2020 WSR*** 8/17/2020 ***JOB CONTINUED FROM 8/16/2020 WSR*** PULLED 45 KB PKR PATCH FROM 4998' MD. RAN 4-1/2" BRUSH, 3.77" GAUGE RING TO RESTRICTION @ 5,784' SLM. RAN 4-1/2" BRUSH, 3.71" GAUGE RING TO 9,600' SLM. RAN 20' x 3.70" DMY WHIPSTOCK TO 9,650' SLM (no issue). ***WELL LEFT S/I ON DEPARTURE*** 8/21/2020 T/I/O=0/0/170 SI (PATCH TUBING / LINER) CMIT TxIA ***PASSED*** to 2154/2194 psi MIT T ***FAILED*** to 2106 psi Max Appiled pressure=2300 psi Target Pressure=2075 psi Pumped 8.57 bbls crude down TxIA to pressure up to 2300 psi. 15 min loss of 21/11 psi, 30 min loss of 15/9 psi, for total loss of 36/20 psi in 30 mins. Bleed IAP down to 1000 psi for MIT T, bled back ~3.1 bbls. Pumped .3 bbls crude down TBG to pressure up to 2280 psi. 15 min loss of 67 psi, 30 min loss of 56 psi, for total loss of 123 psi in 30 mins. Bleed TxIA to 0 psi, bled back total ~8 bbls. DSO notified Tags hung on WV/IA FWHP=0/0/100 8/21/2020 ***WELL S/I ON ARRIVAL*** (HES E-Line Patch Set) SET 4-1/2" BAKER 45KB PATCH 9502' - 9532' ELEMENT TO ELEMENT. (OAL LIH ~ 36.67', top of patch ~ 9500', min. i.d. = 2.45") SET 4-1/2" BAKER 45KB PATCH 5002' - 5032' ELEMENT TO ELEMENT. ( OAL LIH ~ 36.67', top of patch ~ 5000', min. i.d. = 2.45") UPPER PATCH LOG CORRELATED TO PDS LDL DATED 23-AUG-2017. LOWER PATCH LOG CORRELATED TO PDS LDL DATED 22-MAR-2020. ***JOB COMPLETE ON 21-AUG-2020*** 8/24/2020 T/I/O = 155/78/146. Temp = SI. MIT-T to 2300 psi **FAILED**, LLR = 7 GPM @ 2296 psi (post patch). T & IA FL @ surface. Pressured up using 4 bbls of diesel to 100 psi on IA & 2300 psi on TBG, TP lost 55 psi in 1st 15 min, TP lost 39 psi in 2nd 15 min for a 30 min total of 94 psi on the 3rd attempt. TLLR = 7 GPM @ 2296 psi. Bled 1.9 bbls back from TBG & 3 bbls from IA. Tag hung. Final WHPs = 230/70/160. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30 Daily Report of Well Operations PBU 07-05 07-05 c RECEIVED STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMION WIREPORT OF SUNDRY WELL OPERATIS JUL 10 2nm 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operati dew��`, ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ ChangA p ed'Ptoar>r' ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well H Re-enter Susp Well ❑ Other: Set Patch, failed H 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development H Stratigraphic ❑ Exploratory ❑ Service ❑ 5. Permit to Drill Number: 178-013 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 6. API Number: 50-029-20293-00-00 7. Property Designation (Lease Number): ADL 028309 8. Well Name and Number: PBU 07-05 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: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SWNEO JUL 2 Total Depth: measured 10750 feet Plugs measured None feet Subsequent to operation. No test available true vertical 9172 feet Junk measured None feet Service ❑ Stratigraphic ❑ Effective Depth: measured 10693 feet Packer measured 9738 feet 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. true vertical 9123 feet Packer true vertical 8309 feet Contact Email: Prachi.Vohra(cDbp.com i Authorized Signature: Date: �J! j C� t Contact Phone: +1 907 564 4677 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 37-117 37-117 1530 520 Surface 2677 13-3/8" 37-2714 37-2714 4930 2670 Intermediate Production 10701 9-5/8" 35-10736 35-9160 8150/6870 5080/4760 Liner 709 2-7/8" 9801-10510 8361 -8964 10566 11165 Perforation Depth: Measured depth: 10386 - 10578 feet True vertical depth: 8857-9023 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 35-9858 35-8408 Packers and SSSV (type, measured and 4-1/2" Baker SB -3A HYD PERM PKR 9738 8309 true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: SWNEO JUL 2 4 M6 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 419 27744 35 0 799 Subsequent to operation. No test available 20 0 14. Attachments: (required per 20 AAc 25.070.25.071, &25,283) 15. Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development H Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil H Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: WA Authorized Name: Prachi Vohra Contact Name: Prachi Vohra Authorized Title: Production Engineer Contact Email: Prachi.Vohra(cDbp.com i Authorized Signature: Date: �J! j C� t Contact Phone: +1 907 564 4677 Form 10-404 Revised 04/2017 v rz- RMDM&� JUL 112018 111"11 (X Submit Original Ony Daily Report of Well Operations PBU 07-05 ACTIVITYDATE SUMMARY ***WELL S/I UPON ARRIVAL*** (patch tubing liner) DRIFT FREELY TO 9780' SLM W/ 30'x 3.70" DRIFT 11/30/2017 ***CONT. ON 12/1/2017 WSR*** T/I/O = SSV/0/275 TEMP = SI, PPPOT-IC Leaky LDS (PASS) PPPOT-IC: Stung into test void 0 psi on void. Monitored for 10 min, no change in pressure. Torque all LDS to 500 ft/lbs. Pump through void, good returns of fluid out test port. Pressure void to 3,500 11/30/2017 psi for 30 min test. Lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. ***CONT. FROM 11/30/2017 WSR*** (patch tubing liner) SET 4-1/2" WHIDDON C -SUB @ 9775' SLM *****TIGHT SPOT @ 5773' SLM***** TROUBLESHOOT TG-DGLV @ 6114' MD 12/1/2017 ***CONT. ON 12/2/2017 WSR*** ***CONT. FROM 12/1/2017 WSR*** (patch tubing liner) ATTEMPT TO PULL STA# 4 @ 6114' MD WITHOUT SUCCESS. 12/2/2017 ***START WEATHER TICKET*** ***CONT. FROM 12/2/2017 WSR*** (patch tubing liner) ATTEMPT TO PULL STA # 4 @ 6114' MD WITHOUT SUCCESS 12/4/2017 ***CONT. ON 12/5/2017 WSR*** ***CONT. FROM 12/4/2017 WSR*** (patch tubing liner) TROUBLE SHOOT BENT DGLV IN STA#4 @ 6114' MD (decided to leave in pocket) PULL WHIDDON C -SUB @ 9769' SLM, PULL 4-1/2" EVO-TRIEVE PLUG @ 9797' MD (intact) 12/5/2017 ***CONT. ON 12/6/2017 WSR*** T/I/O = 0/230/220. Temp = SI. T & IA FL (SL req). No AL. T FL @ surface. IA FL @ 1300'(70 bbls). 12/6/2017 SL in control of well upon departure. 11:30 ***CONT. FROM 11/5/2017 WSR*** (patch tubing liner) SET BAKER 4-1/2" 45 KB REDUCING NIPPLE (OAL=159") TOP IS @ 9765' SLM (9778' MD) w/ 2.31" XX -PLUG INSTALLED (OAL=23.5") 2.31"X -NIPPLE & PLUG @9789' MD 12/6/2017 ***JOB COMPLETE, WELL LEFT S/I*** WHP: 200/220/290/ Temp = S/I Pumped a total of 2bbls of 60/40 down TBG and 232 bbls of DSL down the TBG for S.Line FWHP:200/30/200 RDMO: 12/6/2017 VALVES= S.Line T/1/0=400/340/300 Temp=Sl (LRS Unit 72 - CMIT-TxIA) CMIT-TxIA to 2500 psi **FAILED*** Max applied Pressure = 2600 psi. Pumped 12.8 bbls crude down IA for CMIT-TxIA. IA came up to 2487 psi and Tbg to 1946 psi when Tbg started falling off. Rigged jumper from IA to TBG. Establish LLR 0.4 bpm at 2558 psi on the IA and 2340 psi on the TBG with 33 bbls (19 diesel and 14 crude). Bled back 2 bbls with jumper open. DSO notified of well status upon departure. SV,SSV,WV closed. MV open. IA/OA OTG. 2/23/2018 FWHP= 209/237/295 (pressures are slowly falling) T/l/O = 280/250/260. Temp = SI. TBG FL (SL Request). No AL. TBG & IA FL = @ Surface. 3/27/2018 SV, SSV, WV = C. MV = O. IA, OA = OTG. 18:30. T/1/0=277/257/288 Temp=S/I (LRS Unit 70 -Assist Slickline:CMIT-T/PatchTubing/Liner) CMIT TxIA to 2500 psi PASSED max applied 2600 psi. Pressured TxIA to 2600 psi with 9.9 bbls 70* crude. TxIA lost 38/25 in 1st 15 min and 15/16 psi in 2nd 15 min. for a total loss of 53/41 psi in 30 min test. 3/31/2018 bled back —10 bbls. Final WHP's 314/321/319 SL on well at departure Daily Report of Well Operations PBU 07-05 ***WELL S/I ON ARRIVAL SWCP 4518***(patch tbg/liner) RAN 4-1/2" LTTP & SET IN KB PACKER @ 9776' SLM (9778' MD). LRS PERFORM PASSING CMIT-T x IA. PULLED 4-1/2" LTTP FROM KB PACKER @ 9776' SLM (9778' MD). 3/31/2018 ***CONTINUE WSR TO 4/01/18*** T/1/0=277/257/288 Temp=S/I (LRS Unit 70 -Assist Slickline:CMIT-T/PatchTubing/Liner) CMIT TxIA to 2500 psi PASSED max applied 2600 psi. Pressured TxIA to 2600 psi with 9.9 bbls 70* crude. TxIA lost 38/25 in 1st 15 min and 15/16 psi in 2nd 15 min. for a total loss of 53/41 psi in 30 min test. 3/31/2018 bled back —10 bbls. Final WHP's 314/321/319 SL on well at departure T/1/0=55/100/253. Assist Slickline (PATCH TUBING / LINER) CMIT-TxIA PASSED @ 2538/2553 psi, Max Applied Pressure= 2600 psi, Target Pressure= 2500 psi, Pumped 12 bbl crude down TxIA to reach test pressure, TxIA lost 18/15 psi in 1 st 15 min and 14/10 psi in 2nd 15 min for a total loss of 32/25 psi in 30 min test, Bled back — 10 bbls, AFE & tags hung on well, SSL in control of 4/2/2018 well at departure, FWHP= 85/100/272 ***WELL S/I ON ARRIVAL***(patch tbg/liner) EQ 2-7/8" XX -PLUG @ 9788' SLM (9789' MD). PULL 2-7/8" XX -PLUG FROM 9788' SLM (9789' MD). SET 2-7/8" XX -PLUG @ 9788' SLM (9789' MD). CMIT TO 2500psi PASSED. 4/2/2018 ***WELL LEFT S/I ON DEPARTURE*** ***WELL S/I ON ARRIVAL*** (SLB E -LINE PATCH) INITIAL T/I/0 = 200/0/300. MIRU, PT TO 3250 PSI. RIH W/ 4-1/2" X 30' BAKER 45 KB PATCH AND SET AT 5000'- 5030' ELEMENT TO ELEMENT. GOOD INDICATION OF SET, TAG PATCH, POOH. TOP OF PATCH = 4998', OAL LIH = 38', MIN I. D. = 2.45". ALL LOGS CORRELATED TO PDS LEAKPOINT SURVEY DATED 23 -AUG -2017. WELL LEFT S/I ON DEPARTURE. FINAL T/I/0 = 50/0/300 PSI. 4/20/2018 ***JOB COMPLETE 20 -APRIL -2018*** T/1/0=30/45/300 Temp=S/I (LRS Unit 42 - MIT -T Post Patch) MIT -T **FAILED** to 2382 psi, Target 2500 psi, max applied 2600 psi. Pumped a total of 3.6 bbls diesel down TBG to reach test pressure for MIT -T. First 15 min TBG lost 131 psi. 2nd 15 min TBG lost 102 psi for total loss of 233 psi in 30 min. Bled TBGR Bled back 2.8 bbls DSL. Valve positions SSV, SV, WV closed MV open CV's OTG 4/21/2018 FWHP 30/29/196 T/I/O=SSV/0/350, Temp=Sl. PPPOT-T (PASS), eval TxIA com. PPPOT-T: Stung into test port (800 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Single port, unable to pump through void. Pressured void to 5000 psi for 30 min test, lost 100 psi in 4/28/2018 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. Fluids Summary Bbls Type 258 diesel 2 60/40 methanol 49 crude TRF = rV7 9=Ur 19( d WIB.LHEAD= GRAY ACTUATOR BAKER C 6KB. ELEV - 64' SHOT SQZ NOTES: SCASING CD10184' MD (GEL 07-05 7-05 IWRR CASING/05/93) TIGHT SPOT N TBG @ 5778' < 3.8^ 5.112" TBG, 17#, 33'33' S 112" X 4-112' XO, = 3.958" KOP= 2900' L-80, _0232 bpf, Max Angie = 46° 5800' 1) = 4.892" Datum.A�__ 10354' Datum TV D = 8800' SS 20" CONDUCTOR 94#, H-40, ID= 19.124^ 102' 9-518" CSG, 47#, S0095 BTC XO TO L-80 BTC 2309' / 13-3/8" CSG, 72#, N-80 BTG, ®= 12.347" 2714' Minimum ID = 2.25" @ 9797" DBD PACK OFF IN UP 4112" KB BKR PATCH, D = 2.45" (04/20/18) 4998' --503 9-5/8- 503 9-5/8" CSG, 47#, L-80 BTC XO TO 50095 BTC H 9311' 2-718" LNR 1-1 9801' 4-1/2' TBG -PC, 12.6#, L-80 BTC -M, 9851' .0152 bpf, D = 3.958" \ PERFORATION SL" ARY REF LOG: BHCS ON 10/05/78 ANGLE AT TOP PERF: 30° Q 10534' Note: Refer to Production DB for historical pert data SIZE SPF NTERVAL Opn/Sgz SHOT SQZ DATE 4 10386-10410 S 12/22/78 09/05/93 DMY 4 10426-10473 S 12/22!78 09/05/93 3-318" 4 10497-10508 S 12122/78 09/05/93 3-31W 4 10522-10540 S 12/08/86 09/17/92 3-31W 4 10534-10550 O 10/06/93 TE-TGPD 3-318" 4 10540-10550 S 10/06193 09/17/92 2" 6 10544-10.578 O 12125/99 6 3-3/8" 4 10550-10554 O 10/06/93 TG 0 2-7/8" CT LNR, 6.4#, L-80 FL4S, I—E 10510' .0058 bpf, ID= 2,441' L PBTD -t_10693' 9-5/8" CSG, 47#, S0095 BTC, .0733 bpf, D= 8.681" 10736' 0 11 2196'��4-1t2" QTIS HRO SSSV Nom, �= 3.813" 2329' H 9-5/8" FO CEM3 TER 244$' --L9-5/8" FQ t�2 GAS LIFT MANDRE[ S ST MD TVD DEV TYPE VLV LATCH PURI DATE 1 2600 2600 0 TE-TGPD DMY TG 0 07/13/89 2 3287 3270 19 TE-TGPD DMY RK 0 07130!08 3 4573 4384 41 TE-TaGPD DMY RK 0 07!30108 4 6114 5502 45 TE-TGPD DMY TG 0 07/13/89 5 7389 6437 39 TETGPD DMY TG 0 07/13/89 6 8431 7272 29 TE-TGPD DMY TG 0 07/13/89 7 9394 8063 35 TE-TGPD DMY RK 0 08/21/17 $ 9506 8154 36 1 TE-TGPD 1WI31RKP 1 0 07/13/89 10610' I-12-7/8" BAKER SHOE 10691' I—� TOP OF CBAENT (TAGGED 12123/99) SPNN6Z SHIELD (LOST 06/23/92) DATE REV BY COMMENTS DATE REV BY COMuBJTS - 04!23118 MAC SET PATCH (04/20118) 07/16189 AUDI RWO tX trJ1L^L Mpi 08/23/13 PJC DRAWING CORRECTIDNS b 12/12/17 BSF1J RJLL PLUG, SET PKR w WW RED 8 PLUG 04/03/18 BSE/JLq RESET XX PLUG (04/02/18) 11 c ST MD TVD DEV TYPE VLV LATCH PORT DATE 9 9620 8248 35 MMG DV RK 0 0911519; 9729' BKR LOCATOR SEAL ASSY w / GBH , D = 3.875^ 9731' 9-5/8" X 4-1/2" BKR SB 3A PKR D = 3.875" 9746' 7" M1Aq..LOUT E7CTBVSiON, D = 6.00" 9778' 4-f/2"PKRw/REDUCNGN�PPLE(12/06117} a ME 97$9' 2.31" X NP(12/06117} 9789' 2-7/8" XX PLUG {04/02118) 9797' D8D LTP, D = 2.25" {08!22!14) 9801' 4-112' G LANDNG SUB, D = 2.992" 9802' 3-112" X 2-718" XO, D = 2.387^ 9839' 4-1/2" OTOS XN NP, D = 3.725^ 9860'_— 4-112" KRSI EARQUT Sty BEHIND 9861' CT LNR 9813' B.MD TT LOGGED 07/1 s/89 996$' - 10619' TOP oFceAENT (04!22,94) 10610' I-12-7/8" BAKER SHOE 10691' I—� TOP OF CBAENT (TAGGED 12123/99) SPNN6Z SHIELD (LOST 06/23/92) DATE REV BY COMMENTS DATE REV BY COMuBJTS 10/13178 RDW 35 INITIAL COMPLETION 04!23118 MAC SET PATCH (04/20118) 07/16189 AUDI RWO 04/21194 ACEWPJC 2-718" CTU LNR 08/23/13 PJC DRAWING CORRECTIDNS 12/12/17 BSF1J RJLL PLUG, SET PKR w WW RED 8 PLUG 04/03/18 BSE/JLq RESET XX PLUG (04/02/18) 11 PROD IDE BAY UMT WELL 07-05 PEFUT ND: '1780130 API No: 50-029-20293-00 SEC 33, TI 1N, RUE, 1567 FNL & 91' FE - BP Exploration (Alaska) . • 2.15CoSO WELL LOG 0. TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. i lia To: AOGCC * �. Makana Bender 333 W. 7th Ave OCT 06 201 Suite 100 Anchorage, Alaska 99501 (907) 793-1225 180N ,c RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Merion Kendall LR2-1 900 Benson Blvd. Anchorage, AK 99508 AKGDMINTERNALabp.com and ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907)245-8952 1) LeakPointTM Survey 23-Aug-17 07-05 BL /CD 50-029-20293-00 2) Signed : MALtSzo-d417) .- Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFil es\Templates\Distribution\Transmittal Sheets\BP_Transmit.docx • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday,August 21, 2017 6:43 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL;G GPB FS3 Drillsites;Vandergon, Mark A;Vohra, Prachi; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington,Aras J;Wallace, Chris D (DOA) Subject: NOT OPERABLE: Producer 07-05 (PTD# 1780130)Well Secured with Downhole Plug All; Producer 07-05 (PTD#1780130)was reported to have sustained inner annulus casing pressure above NOL. A review of caliper surveys confirmed an increase in corrosive damage in the tubing during the time between logs. An Evo-Trieve plug was set at 9773'on 08/20/2017 and a CMIT TxIA to 2620psi was performed on 08/21/17. The tubing tail plug will remain in place to secure the well while a solution is identified. The well is reclassified as Not Operable. Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 Harmony 4530 SCANNED AUG 2 3 2011. • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, August 2, 2017 1:39 PM To: AK, OPS EOC Specialists;AK, OPS FS3 DS Ops Lead;AK, OPS FS3 Facility OTL;AK, OPS FS3 Field OTL;AK, OPS FS3 OSM;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; G GPB FS3 Drillsites;Vandergon, Mark A;Vohra, Prachi; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer 07-05 (PTD# 1780130) Sustained inner annulus casing pressure above NOL All, Producer 07-05(PTD#1780130)was reported to have sustained inner annulus casing pressure above NOL on 7/31/17. The pressures were reported to be T/I/O=2250/2250/250psi . The well failed a subsequent TIFL on 8/2/17 indicating a potential failure of one or more well barriers. The well is now reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repairs. Please respond with any questions, Joshua Stephens Well Integrity Engineer % , P ,g Office: 907-659-8110 "' Cell: 907-341-9068 WO *ad weft wM..a. 1 Gyrodata Incorporated • • •23000 Northwest Lake Dr.k ,WrOe Dr. ,Wr Houston,Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281) 213-6301 1'0k3 vEE SEP 01 tui AOGCC !!_.)N 0 6 2.0\s SURVEY REPORT BP Exploration Drill Site 07 #07-05 Wellhead Prudhoe Bay, North Slope Borough, AK AK0115GCM107 27 Jan 2015 RIGHT PLACE FIRST TIME SEit, www.gyrodata.com Pyrodata Incorporated • •23000 Northwest Lake Dr. gyro/data Houston, Texas 77095 Precision Wellbore Placement T: (281) 213-6300 • F: (281)213-6301 August 27, 2015 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill Site 07, Well #07-05 Prudhoe Bay, Alaska Enclosed, please find one (1) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Kelly Landram Senior Operations Assistant RIGHT PLACE FIRST TIME i www.gyrodata.com €5) i , 0 • / U \ \ \ / @ / , -tEl \ 2 � ,- \ 2 3 5 \ a 2 \ ® \,0u ® , , a \ \ U / \ \ / / o y . § g ; r% \ \ / \ \ . / U \ � \ \ \ \ \ 2 a / u <s.a N fal \2 o \ / \ \ / $ \ \ 0.4 \ 0 / ® w / \ \ ^ ed / \ � \ & o / = \ \ \ » t \ \ / / $ * \ \� N a ,71- 4 a 4 • § > . / t "C ° / \ /d % \ © 2 \ \ 2 /. 2 \ kr) \ [ / \ \ 2 - 2N 2 e \ g M .. Q 0 ./ / \ U § f ; U /. \ N \ C •� k •; ,-C' \ \ \ \ w w = o \ 0./o \ \ \ \ 2 • 0 w 33ww wwwww wwwww wwwww C/1 O CCD D VD CD 00N [SMO, TrGoGoTr N 0\ en 00 N41V000CT ON V) OM Vn VD00NM EWA O 6000 COOCO .� rr .rNN NNN NN z .tl o 40 N 2 O Z ZZr1DC c4cAc4cA0 (1) 0ZZZ ZZZZo N D1 N N N M -. V0 VO M M N M 1n 01-4 ,—, O O O O •--- ,-. 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N CO O 0 'L .. • C • Cly O v IJ N c , _O a p Ln O Cr) p in O CO J M N N ,-i ,1 Ci o A I2 A3S o3-9oa Survey QC - RGS-specification Sheet gyro/data SURVEY QUALITY CONTROL-SPECIFICATION DATA PRE-)OB CALIBRATION VERIFICATION CHECK(ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 64 269.88 173.51 0.00004298 -0.84 63 269.88 175.57 0.00004349 -1.24 62 226.10 360.82 0.00009016 -4.17 61 226.10 360.07 0.00008998 -4.47 60 44.83 401.31 0.00010033 3.62 59 44.83 401.35 0.00010034 2.78 58 0.70 44.73 0.00001129 -1.29 57 0.70 55.21 0.00001394 -0.38 56 330.80 -215.33 -0.00005411 -1.08 55 330.80 -215.21 -0.00005408 -1.11 54 299.92 -150.18 -0.00003737 -1.13 53 299.92 -150.62 -0.00003749 -1.09 52 271.12 173.55 0.00004299 -0.32 51 271.12 181.86 0.00004505 -0.78 50 240.67 380.60 0.00009469 -1.39 49 240.67 387.92 0.00009651 -1.02 48 211.74 327.21 0.00008214 -1.22 47 211.74 330.57 0.00008299 -1.94 46 180.83 78.11 0.00001972 -0.23 45 180.83 82.69 0.00002087 -1.21 44 150.95 -146.71 -0.00003687 0.59 43 150.95 -139.02 -0.00003494 0.81 42 119.41 -44.21 -0.00001100 3.02 41 119.41 -40.40 -0.00001006 3.25 40 89.65 295.41 0.00007319 5.33 39 89.66 299.63 0.00007424 4.53 38 59.91 471.53 0.00011735 4.49 37 59.91 474.17 0.00011801 3.93 36 29.97 335.96 0.00008439 2.17 35 29.97 337.91 0.00008488 1.43 34 357.13 -0.17 -0.00000004 -1.39 33 357.13 4.32 0.00000109 -2.71 32 270.59 221.59 0.00005489 -3.17 31 270.59 225.45 0.00005585 -3.26 30 226.56 384.61 0.00009610 -6.47 29 226.56 384.41 0.00009605 -8.28 28 46.40 426.76 0.00010664 -0.02 27 46.40 433.95 0.00010844 0.55 26 359.75 25.58 0.00000646 -1.48 25 359.74 29.43 0.00000743 -2.00 24 330.22 -218.50 -0.00005490 -0.63 23 330.22 -219.77 -0.00005522 -2.81 22 300.55 -125.01 -0.00003112 -1.61 21 300.55 -122.67 -0.00003054 -2.90 20 268.91 257.50 0.00006379 -1.00 19 268.91 257.08 0.00006369 -1.19 18 239.82 442.10 0.00011002 -1.07 17 239.82 444.85 0.00011071 -1.38 16 209.26 323.15 0.00008119 0.28 15 209.26 326.16 0.00008194 0.20 14 181.08 68.65 0.00001733 0.61 13 181.08 71.43 0.00001803 0.03 12 150.99 -144.52 -0.00003632 3.51 11 151.00 -138.57 -0.00003483 2.26 10 120.02 -6.95 -0.00000173 6.12 9 120.02 -1.84 -0.00000046 3.69 8 90.47 366.99 0.00009094 3.39 7 90.47 376.02 0.00009318 3.03 6 60.53 533.99 0.00013289 3.00 5 60.53 544.96 0.00013562 3.56 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 1 of 6 AK0115GCM107 r s Survey QC - RGS-specification Sheet • to 4 30.67 341.47 0.00008575 0.73 3 30.67 358.19 0.00008996 0.19 2 359.38 -11.39 -0.00000287 0.25 1 359.38 -15.71 -0.00000396 -0.31 MBO = 0.06 Gravity Error= 169.87 Scale Factor Uncertainty = 0.00004234 Rate Error = 0.01 POST-JOB CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 13878 270.45 280.08 0.00006939 3.46 13877 270.45 291.95 0.00007234 0.59 13876 222.54 460.82 0.00011531 -4.96 13875 222.54 463.82 0.00011606 -5.81 13874 46.50 519.97 0.00012996 2.80 13873 46.50 526.95 0.00013170 3.35 13872 0.81 153.99 0.00003888 1.73 13871 0.81 170.52 0.00004305 3.76 13870 329.61 -118.20 -0.00002970 3.29 13869 329.60 -107.41 -0.00002699 5.15 13868 301.25 -57.63 -0.00001435 7.84 13867 301.25 -53.91 -0.00001343 8.79 13866 270.41 290.95 0.00007209 5.70 13865 270.41 299.68 0.00007425 7.04 13864 238.10 506.22 0.00012606 2.00 13863 238.10 509.84 0.00012696 1.83 13862 210.63 436.96 0.00010976 -0.58 13861 210.63 435.11 0.00010929 0.89 13860 180.35 188.41 0.00004757 4.75 13859 180.35 192.98 0.00004872 6.06 13858 150.11 -26.59 -0.00000668 9.47 13857 150.11 -14.60 -0.00000367 7.66 13856 119.36 67.55 0.00001682 8.41 13855 119.36 72.82 0.00001813 7.88 13854 92.13 388.36 0.00009625 6.49 13853 92.13 392.36 0.00009724 5.58 13852 60.59 598.96 0.00014908 3.59 13851 60.59 611.35 0.00015216 1.24 13850 31.40 474.87 0.00011926 -0.23 13849 31.40 477.44 0.00011990 0.78 13848 0.39 163.69 0.00004133 0.37 13847 0.39 163.85 0.00004136 -1.33 13846 268.91 325.48 0.00008065 -6.34 13845 268.90 343.42 0.00008509 -7.10 13844 222.84 461.77 0.00011553 -9.25 13843 222.84 472.39 0.00011820 -10.33 13842 45.12 516.02 0.00012902 -2.48 13841 45.12 520.42 0.00013013 -1.98 13840 359.99 132.95 0.00003356 -4.31 13839 359.99 141.46 0.00003571 -5.39 13838 332.59 -101.30 -0.00002547 -4.60 13837 332.59 -88.02 -0.00002213 -5.42 13836 301.67 -46.88 -0.00001168 -2.36 13835 301.67 -44.10 -0.00001098 -2.79 13834 270.38 324.01 0.00008028 -4.16 13833 270.38 328.03 0.00008128 -3.27 13832 240.67 531.67 0.00013231 -3.93 13831 240.67 534.40 0.00013299 -4.52 13830 207.99 419.36 0.00010542 -2.10 13829 207.99 425.64 0.00010700 -2.27 13828 177.88 151.75 0.00003831 -1.21 13827 177.88 156.84 0.00003960 -1.73 13826 150.17 -34.67 -0.00000871 1.18 SURV-Q167(OPS SUR-MA-003) 19'"Nov 03/Rev 15 Page 2 of 6 AK0115GCM107 Survey QC - RGS-CQpecification Sheet gyro/datar 13825 150.17 -28.75 -0.00000723 0.15 13824 119.18 107.54 0.00002677 1.07 13823 119.18 109.61 0.00002729 -0.44 13822 92.20 454.86 0.00011274 -0.46 13821 92.20 474.73 0.00011767 -3.15 13820 60.77 640.09 0.00015932 0.70 13819 60.77 664.08 0.00016530 1.59 13818 30.69 467.35 0.00011739 -1.75 13817 30.69 475.41 0.00011942 -0.38 13816 359.78 109.16 0.00002756 -0.69 13815 359.78 108.43 0.00002737 0.65 MBO = 0.18 Gravity Error= 278.35 Scale Factor Uncertainty = 0.00006950 Rate Error= 0.32 INITIALISATION Gyro Compass Reading /Station Raw Inclination Raw Azimuth Abs(ERMeas-ERTheo) 107 10.96 67.57 0.0527 108 10.96 67.62 0.0547 109 10.96 67.66 0.0582 110 10.96 67.60 0.0590 111 10.96 67.63 0.0472 112 10.96 67.47 0.0481 Average 10.96 67.59 0.0533 Tolerance on Average* nlf:MlaU ,W0.0818 Standard Deviation 0.00 0.07 0.0049 Tolerance on St. Dev.** 0.1° 0.2° 0.0372 Advanced Initialisation Azimuth Advanced Initialisation Standard Deviation Tolerance =TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Coll)*J[(CosA*SinI*0.1)2+0.0821 °/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cosi)*J[(CosA*SinI*0.1)2+(0.082/(n-1))] °/hr DRIFT TUNES Drift Tune Ending Ending Ending Ending Residual Gx Bias Residual Gy Bias Number Time Depth Inclination Azimuth Start End Start End 1 743.04 3500.11 19.99 70.22 -0.009 0.009 0.001 -0.002 2 1450.64 5300.38 42.58 82.07 0.003 -0.003 -0.002 0.003 3 1433.62 7350.10 42.11 85.29 -0.001 0.001 -0.001 0.002 4 798.55 7950.31 38.66 84.93 -0.003 0.003 0.001 -0.001 5 998.28 8500.09 36.89 85.70 0.001 -0.001 -0.003 0.003 6 1222.85 9425.17 36.28 90.62 -0.003 0.003 -0.001 0.001 7 1053.65 9784.97 35.42 102.72 0.003 -0.003 -0.002 0.001 8 814.17 9450.05 36.17 90.50 0.001 -0.001 0.003 -0.003 9 430.50 9349.53 35.17 90.54 0.001 -0.001 0.001 -0.001 10 1034.95 8399.15 37.66 85.86 0.003 -0.003 0.002 -0.002 11 1312.71 7349.98 42.31 85.15 -0.002 0.002 0.005 -0.005 12 1451.15 6075.05 46.84 84.36 -0.003 0.003 0.000 -0.001 13 1663.62 4550.06 39.47 80.03 0.002 -0.001 0.002 -0.002 14 838.55 3899.98 26.53 75.74 0.005 -0.004 0.000 -0.000 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 3 of 6 AK0115GCM107 ► . Y Survey QC - RGS-specification Sheet • gyro/data 15 1094.76 2999.48 11.06 67.03 -0.003 0.003 0.001 -0.001 Average -0.000 0.000 0.000 -0.000 Standard Deviation 0.004 0.004 0.002 0.002 Tolerance for both the Average and the Standard Deviation 0.033°/hr 0.033°/hr 0.033°/hr 0.033°/hr INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * I Outrun * I Difference Inrun * I Outrun * Difference 100.00 0.01 0.01 -0.00 356.41 359.74 -3.33 200.00 0.02 0.12 -0.09 352.81 58.82 -66.00 300.00 0.04 0.10 -0.06 73.69 134.12 -60.43 400.00 0.06 0.04 0.02 153.68 64.60 89.08 500.00 0.10 0.14 -0.04 125.14 99.73 25.42 600.00 0.14 0.09 0.05 95.00 133.45 -38.45 700.00 0.14 0.03 0.11 89.22 97.41 -8.19 800.00 0.15 0.03 0.11 83.23 91.17 -7.95 900.00 0.08 0.04 0.04 75.73 110.28 -34.55 1000.00 0.02 0.08 -0.06 68.47 93.81 -25.34 1100.00 0.15 0.35 -0.21 57.25 46.93 10.32 1200.00 0.28 0.37 -0.09 46.03 38.39 7.64 1300.00 0.20 0.26 -0.06 57.17 54.54 2.63 1400.00 0.13 0.18 -0.05 68.71 72.87 -4.16 1500.00 0.17 0.12 0.06 107.74 55.39 52.35 1600.00 0.22 0.18 0.05 147.08 160.06 -12.98 1700.00 0.28 0.16 0.12 177.06 162.92 14.14 1800.00 0.34 0.35 -0.01 206.69 216.24 -9.55 1900.00 0.38 0.29 0.08 226.78 240.92 -14.14 2000.00 0.42 0.39 0.03 246.98 247.59 -0.61 2100.00 0.42 0.49 -0.07 252.79 267.10 -14.31 2200.00 0.42 0.46 -0.03 258.18 272.31 -14.12 2300.00 0.45 0.46 -0.01 279.69 280.41 -0.72 2400.00 0.47 0.54 -0.07 301.45 290.02 11.42 2500.00 0.55 0.58 -0.03 317.74 315.58 2.16 2600.00 0.64 0.90 -0.26 334.09 324.42 9.67 2700.00 0.68 0.60 0.08 0.39 350.52 9.87 2800.00 0.72 0.76 -0.04 26.81 30.09 -3.28 2900.00 5.84 5.59 0.25 46.93 63.39 -16.46 3000.00 10.97 10.84 0.13 67.04 66.96 0.09 3100.00 15.57 15.64 -0.07 65.01 64.92 0.09 3200.00 17.33 17.34 -0.02 65.05 65.14 -0.09 3300.00 18.38 18.17 0.22 66.49 66.91 -0.41 3400.00 19.29 19.29 0.00 68.47 68.49 -0.01 3500.00 20.15 20.11 0.04 70.26 70.17 0.09 3600.00 21.46 21.51 -0.05 71.69 71.68 0.01 3700.00 22.79 22.85 -0.06 72.85 72.91 -0.07 SURV-Q167(OPS SUR-MA-003) 19th Nov 03/Rev 15 Page 4 of 6 AK0115GCM107 Survey QC - RGS-specification Sheet • gy to 3800.00 24.42 24.46 -0.04 74.21 74.30 -0.10 3900.00 26.39 26.37 0.02 75.66 75.72 -0.06 4000.00 28.17 28.17 0.00 76.74 76.59 0.16 4100.00 30.32 30.31 0.00 77.09 77.01 0.07 4200.00 32.50 32.55 -0.04 77.57 77.54 0.04 4300.00 34.63 34.63 0.00 78.30 78.29 0.01 4400.00 37.04 37.04 0.00 79.14 79.17 -0.02 4500.00 38.72 38.77 -0.05 79.61 79.64 -0.03 4600.00 40.07 40.09 -0.02 80.08 80.12 -0.04 4700.00 40.39 40.42 -0.03 80.42 80.41 0.01 4800.00 40.49 40.49 -0.01 80.74 80.72 0.01 4900.00 40.86 40.89 -0.03 80.91 80.89 0.02 5000.00 41.17 41.20 -0.02 80.96 80.94 0.03 5100.00 41.46 41.49 -0.03 81.18 81.15 0.03 5200.00 42.26 42.30 -0.04 81.49 81.46 0.03 5300.00 42.49 42.53 -0.03 82.60 82.01 0.60 5400.00 42.93 42.97 -0.03 82.30 82.24 0.06 5500.00 43.62 43.63 -0.01 82.55 82.53 0.02 5600.00 44.36 44.36 -0.00 82.89 82.84 0.05 5700.00 45.34 45.34 0.00 83.16 83.13 0.03 5800.00 46.98 46.95 0.04 84.19 84.13 0.06 5900.00 46.45 46.42 0.04 84.13 84.06 0.07 6000.00 46.66 46.61 0.04 84.23 84.17 0.06 6100.00 47.16 47.10 0.06 84.39 84.32 0.08 6200.00 46.25 46.37 -0.12 84.56 84.44 0.12 6300.00 45.53 45.64 -0.11 84.53 84.38 0.15 6400.00 45.41 45.53 -0.11 84.70 84.57 0.12 6500.00 45.06 45.20 -0.14 84.79 84.60 0.19 6600.00 43.91 44.06 -0.14 84.52 84.34 0.18 6700.00 43.93 44.05 -0.12 84.73 84.53 0.20 6800.00 43.96 44.06 -0.10 84.92 84.78 0.13 6900.00 43.72 43.82 -0.09 84.89 84.70 0.19 7000.00 43.60 43.67 -0.07 84.86 84.64 0.22 7100.00 43.10 43.16 -0.06 85.07 84.86 0.21 7200.00 43.22 43.25 -0.03 85.00 84.77 0.22 7300.00 42.23 42.24 -0.01 85.22 85.04 0.18 7400.00 41.68 41.72 -0.04 85.07 84.92 0.15 7500.00 41.23 41.23 -0.00 85.32 85.24 0.09 7600.00 40.82 40.83 -0.00 84.74 84.60 0.14 7700.00 40.20 40.25 -0.05 84.74 84.59 0.15 7800.00 39.43 39.44 -0.01 86.01 85.94 0.07 7900.00 39.08 39.03 0.06 86.08 86.09 -0.01 8000.00 38.56 38.55 0.01 85.85 85.75 0.10 8100.00 38.27 38.24 0.02 85.21 85.02 0.19 SURV-Q167(OPS SUR-MA-003) 19`h Nov 03/Rev 15 Page 5 of 6 AK0115GCM107 a, i Survey QC - RGS-1,pecification Sheet • gyro/data 8200.00 37.99 38.01 -0.02 84.62 84.51 0.11 8300.00 37.41 37.39 0.02 85.06 84.95 0.10 8400.00 37.65 37.64 0.02 85.90 85.81 0.09 8500.00 36.92 36.92 -0.00 84.79 85.57 -0.78 8600.00 36.48 36.47 0.01 84.27 84.06 0.21 8700.00 36.21 36.16 0.05 85.77 85.63 0.14 8800.00 35.38 34.96 0.42 85.28 85.31 -0.03 8900.00 35.39 35.35 0.03 85.37 85.30 0.07 9000.00 35.11 35.03 0.08 85.26 85.14 0.12 9100.00 34.33 34.22 0.10 86.83 86.74 0.10 9200.00 34.82 34.74 0.08 88.97 88.90 0.07 9300.00 34.95 34.92 0.03 89.93 89.85 0.08 9400.00 35.41 35.39 0.02 89.74 89.74 0.01 9500.00 36.16 36.17 -0.01 92.09 91.99 0.11 9600.00 36.43 36.45 -0.01 95.99 95.91 0.07 9700.00 36.10 36.06 0.04 99.67 99.69 -0.02 Average -0.0041 0.0631 Standard Deviation 0.0867 r , 0.1577 Tolerance for both the Average and the Standard Casing 0.30 4 ,> k c,� Casing 0.5° Deviation Drillpipe 0.3° '" ,.,,..°' ° ,1„ ",--';'''1''. Drillpipe 0.75° * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167(OPS SUR-MA-003) 190"Nov 03/Rev 15 Page 6 of 6 AK0115GCM107 4 MOW Survey QC - RGS-Analysis Sheet • gyrcclata SURVEY QUALITY CONTROL- DATA ANALYSIS REFERENCE SYSTEMS Grid System f I Grid Correction I 0.00 Azimuth reference: Grid/True North TRUE NORTH Vertical reference: RKB/MSL/Other RKB If other give details TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 TVD 0.00 Northings 0.00 Eastings 0.00 Latitude 70.2672 Az. Ref: Grid/True True Grid Corrected Y/N? N Description CALIBRATION Tool Number 1 F0052 Calibration Date 17 May 2014 OPERATING TEMPERATURE Calibration range From 50.48 To 120.02 Gyro operating range From 62.85 To 82.46 Spec'-Within calibration range FIELD ROLL TEST (Only valid on fixed structures. When not possible input roll test data performed after return to base) Cal value Pre job offset Post job offset Abs dif.cal.post Abs dif.pre.post Spec' Accel Scale 0.000056 0.000042 0.000069 0.000069 0.000027 Cal/Post-0.00015 Mass Unbalance 0.50 0.06 0.18 0.18 0.13 Pre/Post-0.4°/hr INITIALISATION Depth (Approx) 3000.03 No of stns 6 Spec'- Min No. - 6 Azimuth Mean 67.59 Std deviation 0.07 Spec'-Azi SD 0.2° Inclination Mean 10.96 Std deviation 0.00 Spec'-Inc SD 0.1° Earth Horizontal Rate Mean (Abs(meas-theor)) 10.05 Std deviation 0.00 Spec'-See Q167 DRIFT TUNE Residual x gyro bias Mean 0.000 Std dev' 0.004 Spec's- Mean and SD - 0.333°/hr Residual y gyro bias Mean -0.000 Std dev' 0.002 Spec's- Mean and SD- 0.333°/hr TOOLFACE RATE Maximum toolface rate 55.56 Spec'-400°/sec IN/OUT COMPARISON (AZI' N/A IF INC' <15° Inclination Difference Mean -0.00 Std dev' 0.09 Spec's- Casing 0.3°/Drill pipe 0.3° Azimuth Difference Mean 0.06 Std dev' 0.16 Spec's-Casing 0.5°/Drill pipe 0.75° Lateral Divergence/1000 0.43 Spec-5.0/1000 _ Vertical Divergence/1000 0.06 Spec'- 2.0/1000 DEPTH CONTROL Wireline Company Schlumberger I Line type 7/32 Encoder SF Schlumberger Max Depth (TD) 9784 CCL Corrected No Zero Depth (Rig up) RKB@ 64 ft MSL Rezero Depth 4 Given pup joint depth NA Measured PJ NA Strech cor. At TD divided by TD/1000 .5231 Spec'- 1.5/1000 Dif. Between rigup and rezero depths divided by TD/1000 .4124 Spec'- 2.0/1000 Dif. Between given and meas depth divided by meas/1000 NA Spec'- 2.0/1000 SURV-Q165(OPS SUR-MA-010)22nd Jan 2004/Revision 20 Page 1 of 1 AK0115GCM107 4 1111, a ISurvey QC - RGS-CT Acceptance Sheet FIELD AND SURVEY INFORMATION Operator BP Exploration (Alaska)Inc. Field/ Platform Well Head. Well Number Drillsite 07 07-05 Survey section From 0.00 ft. to 9784.00 ft. Date 25 Jan 2015 Gyrodata Job No AK0115GCM 107 Gyrodata Surveyors Lukes Koerner Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey'Hot'section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurvey with backup tool Continuous initialisation within Take new initialisation,after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurvey with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurvey with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166(OPS SUR-MA-003)13th Nov 03/Revision 12 Page 1 of 1 AK0115GCM107 . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon I I Repair Well L \� Plug Perforations L Perforate ''L Other SET LTP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ,❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well❑ 2. Operator 4 Well Class Before Work: 5 Permit to Drill Number: Name. BP Exploration (Alaska), Inc Developmerti i-, ,jl Stratigraphid❑ Exploratory u Service ❑ 178-013-0 3. Address: P.O. Box 196612 6 API Number: Anchorage, AK 99519-6612 50-029-20293-00-00 7. Property Designation (Lease Number): 8. Well Name and Number ADL0028309 PBU 07-05 9 Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary (/�- " g^� E ML Total Depth measured 10750 feet Plugs measured None feet `E v true vertical 9207.13 feet Junk measured None feet SEP 17 201 Effective Depth measured 10693 feet Packer measured See Attachment feet true vertical 9157.76 feet true vertical See Attachment feet AOGCC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 74 20" 94# H-40 28-102 28-102 1530 520 Surface 2687 13-3/8" 72# N-80 27-2714 27-2713,99 4930 2670 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth 10386 - 10410 feet 10426 - 10473 feet 10497 - 10502 feet 10502 - 10508 feet 10522 - 10534 feet 10534 - 10540 feet 10540 - 10544 feet 10544 - 10550 feet 10550 - 10554 feet 10554 - 10578 feet True Vertical depth 8891.89 - 8912.67 feet 8926 53 - 8967.24 feet 8988.02 - 8992.35 feet 8992.35 - 8997 55 feet 9009.67 - 9020.06 feet 9020.06 - 9025.26 feet 9025.26 - 9028.73 feet 9028.73 - 9033.92 feet 9033.92 - 9037.39 feet 9037.39 - 9058.17 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None one None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): "NED Treatment descriptions including volumes used and final pressure. 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation. 518 25607 52 0 743 Subsequent to operation 466 23658 41 0 844 14 Attachments: 15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development Service Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work: Oil ' Gas L WDSP GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC❑ 17 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C O Exempt: N/A Contact Nita Summerhays Email Nita.Summerhaysp_bp.com Printed Name Nita Summerhays Title Petrotechnical Data Engineer Signatu Phone 564-4035 Date 9/15/2014 rt- q/ir/I"�F RRCMS SEP 1 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028309 ACTIVITYDATE SUMMARY ""*COST PLACEHOLQER**" labor & material to build seal stinger for LTP. labor & meterial to build XO from seal 8/13/2014 assy to D&D packoff assy. ***WELL S/I ON DEPARTURE' (Profile Mod) RAN PDS 24 ARM CALIPER FROM 10217' SLM TO SURFACE (see pds log) SET D&D PACK OFF (max od--3.72", oal--58", min id 2.25"), IN LANDING SUB @9787' SLM (9801'MD) SET D&D TUBING STOP @ 9785' SLM 8/22/2014 ***CONT ON WSR 8/23/14*** ***CONT FROM WSR 8/22/14***(Profile Mod) SWCP 4517 RIG DOWN 8/23/2014 ***WELL S/I ON DEPARTURE*** FLUIDS PUMPED BELS 1 DIESEL 1 TOTAL Casing / Tubing Attachment ADL0028309 Casing Length Size MD TVD Burst Collapse CONDUCTOR 74 20" 94# H-40 28 - 102 28 - 102 1530 520 PRODUCTION 2283 9-5/8" 47# SOO-95 26 - 2309 26 - 2309 8150 5080 PRODUCTION 7002 9-5/8" 47# L-80 2309 - 9311 2309 - 7995.76 6870 4760 PRODUCTION 1425 9-5/8" 47# SOO-95 9311 - 10736 7995.76 - 9195 8150 5080 SURFACE 2687 13-3/8" 72# N-80 27 - 2714 27 - 2713.99 4930 2670 TUBING 5 5-1/2" 17# L-80 28 - 33 28 - 33 7740 6280 TUBING 9818 4-1/2" 12.6# L-80 33 - 9851 33 - 8436.88 8430 7500 Packers and SSV's Attachment ADL0028309 SW Name Type MD TVD Depscription 07-05 PACKER 9731 8338.12 4-1/2" Baker SB -3A HYD PERM PKR 07-05 PACKER 9797 8392.29 4-1/2" Top Packer TREE = 5X7 FMC 1201 WELLHEA = GRAY ACTUATOR = BAKER C OKB. ELEV = 64' BF. ELEV = ? KOP = 2900' Max Angle = 46° @ 5800' Datum MD = 10354' Datum TV D = 8800' SS 5-1/2" TBG, 17#, L-80, .0232 bpf, D = 4.892" l`F CONOUCTOR, 94#, H-40, ID = 19.124" 102' 9-5/8" CSG, 47#, S0095 BTC XO TO L-80 BTC 2309- F1 3-3/8- 309'13-3/8" CSG, 72#, N-80 BTC, D = 12.347"-27714' —� 9-5/8" CSG, 47#, L-80 BTC XO TO 50095 BTC (--{ 9311' Minimum ID = 2.25" @ 9802' DSD PACK OFF IN LTP I TOP OF 2-7/8" LNR I 9801' 4-112" TBG -PC, 12.6#, L-80 BTC -M, 9851' .0152 bpf, D = 3.958' PERFORATION SLJM"AARY REF LOG: BHCS ON 10/05178 ANGLE AT TCW PERF: 300 @ 10534' We Refer to Production DB for historical pert data SIZE SPF NTI RVAL Opn/Sqz SHOT SQZ TE-TGPD 4 10386-10410 S 12/22/78 09/05/93 TETGPD 4 10426-10473 S 12/22/78 09/05/93 3-3/8" 4 10497-10508 S 12/22/78 09/05/93 TETGPD DMY TG 0 07/13/89 5 7389 6437 39 3-3/8" 4 10522-105401 S 12/08/86 09/17/92 3-3/8" 4 10534-10550 O 10/06/93 7 9394 8063 35 3-31W 4 10540-10550 S 10/06/93 09/17/92 2" 6 10544-10578 O 12/25/99 3-3/8" 4 10550-10554 O 10/06/93 2-7/8" CT LNR 6.4#, L-80 FL4S, .0058 bpf, D = 2.441" PBTD 10693' 9-5/8' CSG, 47#, S0095 BTG, .0733 bpf, O = 8.681" 1 10736' I U I-1 10 50! SAFETY NOTES: SPLIT N CAS14G @10184' MD (GEL 07-05 7 -0 5 SOZ 09/05/93) TIGHT SPOT N TBG @ 5778'< 3.8" / ) 33' 5-112" X 4-1/2" XO, D= 3.958" 2196 -14-1/2" OTIS HRQ SSSV NP, ID = 3.813" 2329' �2g48'9-5/8" FO C�E32 ST MD TVD DEV TY FE VLV LATCH PORT DATE 1 2600 2600 0 TE-TGPD DMY TG 0 07/13/89 2 3287 3270 19 TETGPD DMY RK 0 07/30/08 3 4573 4384 41 TE-TGPD OMY RK 0 07/30/08 4 6114 5502 45 TETGPD DMY TG 0 07/13/89 5 7389 6437 39 TE-TGPD DMY TG 0 07/13/89 6 8431 7272 29 TI: TGPD DMY TG 0 07/13/89 7 9394 8063 35 TE- TGPD DMY RWK 0 08✓08/13 8 9506 8154 36 TE-TGFD RKP 0 07/13/89 9729' -IBKR LOCATOR SEAL ASSY w / GBH , 1D= 3.875" 9731' 10/13178 ROW 35 INITIAL COMPLETION 9-518" X 4-1/2- BKR SB -3A PKR, 67--3-8-757- =3875"9745' 974V 7" AM. LOUT ED(TEVSION, D = 6.00" 9751' — 7' X4-1/2" XO, D = 3.958- 9797 D8D LTP, D = 2.25" (08/22/14) 9801' 4 1/2' G LANDNG SUB, D = 2.992" 9$ IT 3-1/2" X 2-7/8" XO, D = 2.387" 9$39' 4-1/2' OTIS XN NP, D= 3.725" 9$Sp� 4 1/2" BKR SHEAROLlT SUB BEHIND 9851' 4-1l2' WLEG, ID - 3.958' CT LNR 9813' —�E3H� TT LOGGH3 07119189 9958' - 10519'TOP OF CHNBT (04/22/94) 10510' 1—{2-7/8" BAKER SHOE 10591' 1—{TOP OF CB4E WT (TAGGED 12/23/99) 10558' hi SPNNBR SHIELD (LOST 06/23/92) DATE I REV BY COMMENTS DATE REV BY COWENTS 10/13178 ROW 35 INITIAL COMPLETION 08/20/13 DJS/ PJC SET DGLV (08/08/13) 07/16/89 AUDI 4 RWO 08/23/13 PJC DRAWING CORRECTIONS 04/21/94 ACEVPJC 2-7/8" CTU LNR 09/10/13 RB/JMD TREE 00 (08/19/13) 02/02/94 SY /PJC CMT SQZ 08/25/14 MGSIPJC SET LTP (08/22(14) 07/27108 AK/PJC PERFORATION CORRECTIONS 08/05/081 BSFIPJC GLV C/O (07130/08 PRUDHOE BAY LUT WELL 07-05 PERMIT No: '1780130 AR No: 50-029-20293-00 SEC 33, T11 N, R14E, 1567' FTL 8 91' FE - BP Exploration (Alaska) FW: Producer 07 -05 (PTD #1780130 bing Integrity Restored Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] �� c (Z Z) j( Sent: Tuesday, February 15, 2011 3:41 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS EOC Specialists; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany; Holt, Ryan P (ASRC) Subject: FW: Producer 07 -05 (PTD #1780130) Tubing Integrity Restored All, Producer 07 -05 (PTD #1780130) passed a MITIA to 3000 psi on 2/13/2011. The passing MITIA confirms the presence of two competent barriers in the wellbore. The well has been reclassified as Operable. The well may be returnedlo production as operations convenience. Please be aware of the potential for annular fluid expansion when returning the well to production. Please call if you have any questions. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 Pb b From: AK, D &C Well Integrity Coordinator Sent: Thursday, February 10, 2011 4:43 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS EOC Specialists; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany; Holt, Ryan P (ASRC) Subject: Producer 07 -05 (PTD #1780130) Sustained IA Casing Pressure Above MOASP All, Producer 07 -05 (PTD #1780130) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to 898/2025/500 psi on 02/08/11. The well has been reclassified as Under Evaluation and may be produced under a 28 -day clock. The plan forward is as follows: 1. Pumping: MIT -IA to 3000 psi, LLR if fails A TIO plot and wellbore schematic have been included for your reference. Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/22/2011 Producer 07 - 05 (PTD #1780130) Sullied IA Casing Pressure Above MOASP Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] ¢ 1111 it Sent: Thursday, February 10, 2011 4:43 PM `C To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS EOC Specialists; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Lee, Timothy Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany; Holt, Ryan P (ASRC) Subject: Producer 07 -05 (PTD #1780130) Sustained IA Casing Pressure Above MOASP Attachments: 07 -05 (PTD #1780130) TIO Plot.doc; 07 -05 (PTD #1780130) welibore schematic.pdf All, Producer 07 -05 (PTD #1780130) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to 898/2025/500 psi on 02/08/11. The well has been reclassified as Under Evaluation and may be producender a 28 -day clock. The plan forward is as follows: 1. Pumping: MIT -IA to 3000 psi, LLR if fails A TIO plot and wellbore schematic have been included for your reference. «07 -05 (PTD #1780130) TIO Plot.doc» «07 -05 (PTD #1780130) welibore schematic.pdf» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752-0755 (907) 659 -5100 Ext. 1154 4101 FE - 2/11/2011 PBU 07 -05 PTD #1780130 2/10/2011 TIO Pressures Plot Well: 07 -05 4,000 • 3.000 - - Tbg -F IA 2,000 -AL-- OA 00A -�- 000A On 1,000 - • In 12/11/10 12/18/10 12/25/10 01/61/11 01/08/11 01/15/11 01/22/11 01/29/11 02/05/11 TREE= MCEVOY WELLHEAD = GRAY • 07-05 SAFETY : SPLIT IN CASING @10184' MD (GEL SQZ 09/0 ) TIGHT SPOT IN TBG @ 5778' < 3.8" ACTUATOR = AXELSON KB. ELEV = 64' BF. E-EV = ? 5 -1/2" TBG, 17 #, --` 33' 3 I ' J I f 33' I 15-1/2" X 4 -1/2" XO, ID = 3.958" KOP 2900' L -80, .0232 bpf, Max Angle = 46° @ 5800' ■ I 2329' H 9 -5/8" FO CEMENTER _; Datum N i _. TV �. D = 8800' ' SS ._... 4. ID = 4.892' Datum = 10 SS • .1. 1 2448' H 9 -5/8" FO CEMENTER I I 2196' - {4-112" OTIS HRQ SSSV NIP, ID = 3.813" I 120" CONDUCTOR, 94 #, H-40, ID = 19.124" I 102' x 1 9 -5/8" CSG, 47 #, SOO95 BTC XO TO L -80 BTC I I-I 2309` L GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, N-80 BTC, ID = 12.347" 1 2714' ST MD ND DEV TYPE VLV LATCH PORT DATE 1 2600 2600 0 TE-TGPD DMY TG 0 07/13/89 Minimum ID = 2.387" 9802' 2 3287 3270 19 TE-TGPD DMY TG 0 07/30/08 3 4573 4384 40 TE -TGPD DMY TG 0 07/30/08 3 -1/2" X 2 -7/8" X0 PIN 4 6114 5502 45 TE -TGPD DMY TG 0 07/13/89 5 7389 6437 39 TE -TGPD DMY TG 0 07/13/89 6 8431 7272 27 TE -TGPD DMY TG 0 07/13/89 1 9 -5/8" CSG, 47 #, L -80 BTC XO TO SOO95 BTC I-1 9311' (— < 7 9394 8063 35 TE -TGPD DMY TG 0 07/26/10 8 9506 8154 36 TE -TGPD DMY RKP 0 07/13/89 CHEMICAL MANDRELS c ST MD ND DEV TYPE VLV LATCH PORT DATE 9 9620 8248 35 MMG DV RK 0 09/15/92 9729' _I-1 BKR LOCATOR SEAL ASSY w I GBH , ID = 3.875" I �� . 9731' H 9 -518" X 4 -1/2" BKR S &3A PKR, ID = 3.875" I J 9745' 1-17" MILLOUT EXTENSION, ID = 6.00" I TOP OF 2 -7/8" LNR H 9801' 9751' 1-17" X 4 -112" XO, ID = 3.958" I 4 -1/2" TBG -PC, 12.6 #, L -80 BTC-M, -1 9851' .0152 bpf, ID = 3.958" H 1 9801' 1--1 -1/2" G LANDING SUB, ID = 2.992" 1 9802' H 3 -1 /2" X 2 -7/8" XO, ID = 2.387" 1 PERFORATION SUMMARY REF LOG: BHCS ON 10/05/78 I 9839' I- -1 4 -1/2" OTIS XN NIP, ID = 3.725" ANGLE AT TOP PERF: 30° @ 10534' \ I 9850' I- 14 -1/2" BKR SHEAROUT SUB I BEHIND Note: Refer to Production DB for historical pert data CT LNR SIZE SPF INTERVAL Opn /Sqz DATE 9851' 1-1 -1/2" WLEG, ID = 3.958" 4 10386 -10410 S 02/02/94 1 9813' 1-I ELMD TT LOGGED 07/19/89 4 10426 -10473 S 02/02/94 3 -3/8" 4 10497 -10508 S 02/02/94 3 -3/8" 4 10522 -10540 S 12/08/86 3 -3/8" 4 10534 -10550 0 10/06/93 3 -3/8" 4 10540 -10550 S 02/02/94 2" 6 1 0544 -10578 0 12/25/99 3 -3/8" 4 10550 -10554 0 10/06/93 10510' 1--{ 2-7/8" BAKER SHOE I 2 -7/8" CT LNR, 6.4 #, L -80 FL4S, -I 10510' I .0058 bpf, ID = 2.441" 1 PBTDI —I 10693' .otvy V♦Il■ 10591' I- -1TOP OFCEMENT (TAGGED 12 /23/99) I 1 1 9 -5/8" CSG, 47 #, SOO95 BTC, .0733 bpf, ID = 8.681" I 10736' - 1 l 1 ! e 1.. 111Mf.'�1-1`1�1� 10558' I-I SPINNER SHIELD (LOST 06/23/92) I 1 1 TD H 10750' AtivA..., DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE E 10/13/78 ROW 35 ORIGINAL COMPLETION 11/18/08 AK/PJC DRAWING CORRECTIONS WELL: 07 07/16/89 AUDI 4 LAST WORKOVER 07/24/10 JLJ /AGR GLV C/O (07/21/10) PERMIT No: r 17 04/21/94 ACB/PJC 2 -7/8" CTU LNR API No: 5C 02/02/94 SY /PJC CMT SQZ SEC 33, T11 N, R14E, ' 07/27/08 AK/PJC PERFORATION CORRECTIONS OPERABLE: Producer 07-OS (PTD #0130) Confirmed tubing integrity • Regg, James B (DOA) Page 1 of 1 From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] Sent: Thursday, July 22, 2010 5:30 AM To: AK, D&C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; AK, RES GPB West Production Optimization Engineer; AK, OPS FS3 DS Operators; AK, OPS FS3 OSM Cc: Janowski, Carrie; Lee, Timothy Subject: OPERABLE: Producer 07-05 (PTD #1780130) Confirmed tubing integrity All, Producer 07-05 (PTD #17801 0) passed an MITIA on 07/21/10 after the as lift valves were dummied off. The passing test verifies tubing integrity. The well has been reclassified as Operable and may e placed on production when convenient for operations. Please be careful when placing on production as the IA is fluid packed. Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: AK, D&C Well Integrity Coordinator Sent: Tuesday, July 20, 2010 9:01 PM a t-. s. '~ ~~~ ~A~J ~` ~ 2C To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, RES GPB East Production Optimization Engineer; AK, OPS EOC Specialists; AK, RES GPB West Production Optimization Engineer; AK, OPS FS3 DS Operators; AK, OPS FS3 OSM Cc: Janowski, Carrie; AK, D&C Well Integrity Coordinator; Lee, Timothy Subject: UNDER EVALUATION: Producer 07-OS (PTD #1780130) for Sustained Casing Pressure due to TxIA Comm All, Producer 07-05 (PTD #1780130) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to 2197/2300/50 psl on 10. The well has been reclassified as Under Evaluation and may be produced under a 28-day clock. The plan forward is as follows: 1. Pumping: MIT-IA to 3000 psi, LLR if fails 2. Slickline: Caliper tubing A TIO plot and wellbore schematic have been included for your reference. « File: 07-05 TIO Plot 07-20-10.doc » « File: 07-05.pdf » Thank you, Toxin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 --i-r~- - _~- ~~~~ ~ `~qs ~ 4ZPPF ~-~, ~cP = z ~. z`~ 1tD~c~ tib~ ~T CL7 '~Z- 7/23/2010 PBU 07-OS PTD 1780130 7/20/2010 TIO Pressures Plot 4.000 Well: U7-05 ~.~100 2,010 1,000 04124110 0510Qi10 05/22110 06105110 OE~19i10 07103110 07,'17110 ~~ Tbg -f- IA -~ OA OOA OOOA On •I TREE= MCEVOY WELLHEAD = GRAY ACTUATOR= AXEL50N KB. ELEV = 64` BF. ELEV = ~ KOP - 2900' Mix AnrylP = uatum iviD = i.idiwn I v G = 46° ~ 5800' 10354' - oou0' SS 5-112" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 20" CONDUCTOR, 94#, H-40, ID = 19.124" 9-518" CSC, 47#, S0095 BTC XO TO L-80 BTC 13-318" CSC, 72#, N-80 BTC, ID = 12.347" n Minimum ID =2.387" @ 9802' 3-1 /2" X 2-7i8" X® PIN 9-5/8" CSC, 47#, L-80 BTC XO TO S0095 BTC o~-os 0 c SAFETES: SPLff IN CASING @10184' MD {GEL 5QZ 09/ 3) TIGHT SPOT IN TBG @ 5778' < 3.8" 33' I-~ 5-1(2" X 4-112" XO, ID = 3.958" 232g' 9-5i8" FO CEMENTER 2448' 9-5/8" FO CEMENTER 2196' 4-112" OTIS HRO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2600 2600 0 TE TGPD DMY TG 0 07/13/89 2 3287 3270 19 TE TGPD DMY TG 0 07/30/08 3 4573 4384 40 TE TGPD DMY TG 0 07/30/08 4 6114 5502 45 TE TGPD DMY TG 0 07113!89 5 7389 6437 39 TE-TGPD DMY TG 0 07/13/89 6 8431 7272 27 TE-TG~ DMY TG 0 07/13(89 7 9394 8063 35 TETGPD DMY TG 0 07/30/08 8 9506 8158 36 TETGPD DMY RKP 0 07!13/89 S BKR LOCATOR SEAL ASSY w / GBH , ID = 3.875" ~ TOP OF 2-7/8" LNR 4-1(2" TBG-PC, 12.6#, L-80 BTGM, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: BHCS ON 10105/7$ ANGLE AT TOP PERF: 30° @ 10534' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 10386-10410 5 02/02!94 4 10426-10473 S 02!02194 3-318" 4 10497-10508 S 02!02/94 3-3/8" 4 10522-10540 S 12/08/86 3-3/8" 4 10534-10550 O 10106!93 3-3/8" 4 10540-10550 S 02102!94 2" 6 10544-10578 O 12125!99 3-3/8" 4 10550-10554 0 10/06/93 2-7(8" CT LNR, 6.4#, L-80 FL4S, 0058 bpf, ID = 2.441'" I PBTD I 9-518" CSC, 47#, 50095 BTC, .0733 bpf, ID = 8.681" TI D -I i SPINNER SHIELD {LOST 06!23/92) DATE REV BY COMMENTS DATE REV BY COMMENTS 10!13/78 ROW 35 ORIGINAL COMPLETION 11/18!08 AK/PJC DRAWING CORRECTIONS 07!16!89 AUD14 LAST WORKOVER 04/21/94 ACB/PJC 2-718" CTU LNR 02102/94 SY/PJC CMT SOZ 07/27/08 AK/PJC PERFORATION CORRECTIONS 08(05108 BSE/PJC GLV C/O {07!30/08 PRUDHOE BAY UNIT WELL: 07-05 PERMIT No: 1780130 API No: 50-029-20293-00 SEC 33, T11 N, R14E, 1567' FNL & 91' FEL BP Exploration (Alaska) 9731' -~9-5/8" X 4-1/2" BKR SB-3A I~CR, ID = 3.875" 9745' 7" MILLOUT EXTENSION, ID = 6.00" 9751' 7" X 4-112" XO, ID = 3.958" 9801' - -j4-1/2" G LANDING SUB, ID = 2.992" 9802' 3-112" X 2-7i8" XO, ID = 2.387" g$3g' 4-1(2" OTIS XN NIP, ID = 3.725" g850' 4-112" BKR SHEAROUT 5UB BEHIND 9851' 4-1/2" WLEG, iD=3.958" CT LNR g813' ELMD TT LOGGED 07/19/89 C:1IGVIIC:HL IVW IVUKtLJ J TYPE VLV LATC MMG DV RK 2-7/8" BAKER SHOE 10591" ~-~ TOP OF CEMENT (TAGGED 12123/99) AIASRd vll a uas cons i.omm Anchorage, AK 99503 2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date BL Color CD MPI -13 AWJI -00055 3 J •ZV' 10/18/09 1 1 MPC -07 AXBD-00057 MEM PROD PROFILE 1 0/ 2 4 09 1 i 04 -11A AWL8 -00040 INJECTION PROFILE V -220 AYS4 -00100 INJECTION PROFILE I" .J4117011%11 10/04/09 1 1 L -220 B1JJ -00035 MEM INJ PROFILE (REVISED) z. J... -a' AI 07/30/09 1 1 V -221 AXBD -00037 MEM INJ PROFILE (REVISED) C)T.0 ac -t(3 /61 „G 07/28/09 1 1 L -214A AP3Q -00064 INJ PROFILE/RST (jr( 0( 10/06/09 1 1 S -22B AYTU -00052 INJECTION PROFILE a ii 10/27/09 1 1 14 -07 B581-00016 PROD PROFILE �Aillill 10/27/09 1 1 07 -05 AYS4 -00105 SCMT -Q 10/28/09 1 1 R -28 AWL8 -00041 USIT -I. 10/26/09 1 1 2- 08/K -16 AZCM-00046 PRODUCTION PROFILE 01 fs9 n 10/30/09 1 1 PSI -05 B14B -00080 TEMP WARMBACK SURVEY oZC a0 /'I's9° ,i 11/03/09 1 1 C -12B B2WY -00030 MCNL IP 09/19/09 1 1 U-05A 09AKA0074 OH MWD1LWD EDIT T -p tail 08/19/09 2 1 01 -18A 09AKA0151 OHMWD/LWD EDIT �I =F,' 08/27!09 4 1 H -09 ANHY -00110 RST ''t /'b 7 Mi .1i 09/20/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. ry Anchorage, AK 99503 -2838 w ',H' OEPRABLE: 07-OS (PTD #1780130) Tubing integrity restored Page 1 of 2 • Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~ llllo` Sent: Wednesday, July 30, 2008 2:52 PM ' To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Roschinger, Torin T.; Kaminski, Alice; GPB, Gas Lift Engr; NSU, ADW Well Integrity Engineer Subject: OEPRABLE: 07-05 (PTD #1780130) Tubing integrity restored Follow Up Flag: Follow up Flag Status: Yellow Hi all, Well 07-05 (PTD #1780130) passed aMIT-IA on 07/30/08 after dummying off the gas lift valves proving integrity has been restored. The well has been reclassified as Operable and may be brought on line w en convenient for operations. Please be prepared for the IA pressure to increase due to thermal expansion as the IA is liquid packed. ~_~ From: NSU, ADW Well Integrity Engineer Sent: Wednesday, July 23, 2008 5:33 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCi/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; Kaminski, Alice; GPB, Gas Lift Engr Subject: UNDER EVALUATION: 07-05 (PTD #1780130) for Sustained casing pressure due to TxIA Comm Hi all, Well 07-05 (PTD #1780130) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSSV/2060/50 psi on 07/13/08. A subsequent TIFL failed on 07/20/08. The well has been reclassified as Under Evaluation and may be produced under a 28-day clock. The plan forward for this well is as follows: D: TIFL -FAILED 2 S: Caliper tubing, set DGLVs 3. F: MITIA to 3000 psi, LLR if fails A TIO plot and wellbore schematic have been included for reference. / 11/10/2008 OEPRABLE: 07-OS (PTD #1780130) Tubing integrity restored Page 2 of 2 • Please call with any questions. Thank you, Anna ~Du6e, ~'. E. Weii Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907} 659-5100 x1154 11/10/2008 U 1 rJ ti G -1 M J N (~ ~1 l T f r- c -~. ctJ r~ ~~ rp `r ~yi C~ r-- a~ ~. r~ c~J w} c~ r tJ rjj ~r 1~ O 't,. `-7' -k C6 L G I`~- O tip Q l k, (" a _~ LCt t~] Q 'si' t -d u~ co h-- u-, 0 oa G C~ _r LL"? Q ~~ O t-,z Q -~.. LEi G~ L1 !L1 tV ~' Q O ~ O iQ O O O C~ Q O O O ~t M N r TREE= GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 64' B F. ELEV = KOP = Max Angle = ? 2900' 46 @5800' Datum MD= 10354' Datum ND = 8800' SS 5-1/2" TBG, 17#, L-80, 0.0232 bpf, ID= 4.892" H 33' TOP OF 4.1/2" TBG 33' 13-3/8" CSC, 72#, N-80, ID= 12.347" 2714' Minimu m ID = 2.441 " @ 9802' Crossover 3-1/2" X 2-7/8" 07-05 SAFEN NOTES: SRff IN CASING @ 10184' MD (GEi SQZ 09A75/93) TIGHT SFa)T IN TBG @ 5778' < 3.8" 5-1/2" X 4-1l2" XO 2196' 41 /2" OTIS HRO SSSV NP, ID = 3.813" GAS LIFT MANDRH S ST M D N D DEV N PE VLV LATCH PORT DATE 1 2600 2600 0 TETGPD TG 2 3287 3270 19 TETGPD TG 3 4573 4384 40 TETGPD TG 4 6114 5502 45 TETGPD TG 5 7389 6437 39 TETGPD TG 6 8431 7272 27 TETGPD TG 7 9394 8063 35 TETGPD TG 8 9506 8154 36 TETGPD RKP CHEMICAL MANDRELS ST MD ND DEV TYFE VLV LATCH PORT DATE 9731' 4-12" BAKERSEAL ASSY ~ 9742' 9-58" X 4-1 /2"BAKER SB-3A ITtR, ID = 3.875" TOPOF2-7/8"LNR - CT 9801' 9801' 4-1/2" G LANDING SUB (TOP OF LNR) 9802' 3-12" X 2-7/8" XO 9839• 4-12" OTISXNNIP(BEHNDCT), ID= 3.725" 9850' 4-12" BAKERSHEAROUf SUB (BEHIND CT) 4-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID= 3.958" 9851' 9851' 4-12" TUBING TAIL (BEFNNDCT) PERFORATION SUMMARY 9813' ELMD TT LOGGED 07/19/89 R~ LOG: BHCS ON 10/05/78 A NGLE AT TOP PERF: 30 @ 10386' Note: Refer to Production DB for histor'ral nerf data SIZE SPF INTERVAL O n/S DATE 4 10386-10410 S 12/22/78 4 10426-10473 S 12/22/78 3-3/8" 4 10497-10508 S 12/08/86 3-3/8" 4 10522-10540 S 12/08/86 3-3/8" 4 10534-10550 O 10/06h03 3-3/8" 4 10540-10550 S 12/08/86 2" 6 10544-10578 O 12/25/99 3-3/8" 4 10550-10554 O 10/06/93 2-7/8"LNR CT, 6.5#, L-80, .00579 bpf, ID= 2.441" 10510' STD 10693' 9-5/8" CSC; 47#, N-80, ID= 8.681" 10736' TD 10750' - 10510' H 2-7/8".BAKER SHOE 10514' TOP OF CEMENT 10558' SPINNER SHIELD (LOST 06/23/92) DATE REV BY COMMENTS DATE REV BY COMMENTS 10/13/78 ORIGINALCOMFLETION 09/21/01 RNYTP CORRECTIONS 07/16/89 LAST WORKOVER 04/21/94 RAN 2-7/8" LNR 12/05/00 SIS-MD CONVERTED TO CANVAS 02/08/01 SIS-LG REV ISION PRUDHOE BAY UNff WELL: 07-05 FERMff No: 78-0130 API No: 50-029-20293-00 SEC 33, Tt 1N, R14E 853.51 FEL 1180.11 FNL BP rycploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Per/orate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 64 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1564, FNL, 92' FEL, Sec. 33, T11 N, R14E, UM (asp's 676119, 5949356) 07-05 At top of productive interval 9. Permit number / approval number 1172' FNL, 915' FEL, Sec. 34, T1 1 N, R14E, UM (asp's 680565, 5949857) 178-013 At effective depth 10. APl number 50-029-20293 At total depth 11. Field / Pool 1180' FNL, 854' FEL, Sec. 34, T11 N, R14E, UM (asp's 680625, 5949847) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 10750 feet Plugs (measured) Tagged PBTD @ 10587' MD (12/25/99) true vertical 9207 feet Effective depth: measured 10587 feet Junk (measured) true vertical 9066 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 102' 20" 229 Sx AS 102' 102' Surface 2650' 13-3/8" 4800 Sx AS ~ 2714' 2714' Production 10672' 9-5/8" 12oo Sx Class G & 300 Sx AS I 10736' 9195' Scab Liner 709' 2-7/8" 12 bbls LARC 10510' 8999' Perforation depth: measured10534'-10578'. 0~IF'~ii~'~IALu '~ true vertical 9020' - 9058'. Tubing (size, grade, and measured depth) 5-1/2", 26#, L-80 Tbg @ 33' MD; 4-1/2"12.6#, L-80 PCT @ 9851' MD. Packers & SSSV (type & measured depth) 9-5/8" x 4-1/2" BAKER SB-3A PACKER @ 9742' MD. 4-1/2" OTIS HRQ SSSV @ 2196' MD. 13. Stimulation or cement squeeze summary ~.I~S~(.3 Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 792 11391 0 274 Subsequent to operation 845 12050 0 278 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .... ~:~?...,.y~ ~q ~ Title ARCO Engineering Supervisor Date Erin Oba ' Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 o SUBMIT IN DUPLICATE 07-05 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 12/23/1999: 12/25/1999: RIH &tagged PBTD @ 10591' SLM. MIRU ELU. PT'd equip to 3000 psi. RIH w/perf guns & tagged PBTD @ 10587' MD. Shot 24' of add perforations @: 10554' - 10578' MD (Zone 2) Reference Log: BHCS 10/05/1978. Used 2" carriers and all shots @ 6 SPF, 60° orientation, & balanced pressure. POOH w/ guns. ASF. Returned well to production & obtained valid welltest data. RECEIVED AlaS~ 0il & Gas Cons. comm't~ion Anchorage ._. STATE OF ALASKA __. ALASKA _AND GAS CONSERVATION CO ,tlSSION REPORT OF SUNDRY WELL OPERATIONS 1. OperatiOns performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1567' S & 92' W of NE cr., Sec. 33, T11 N, R14E, UM At top of productive interval 1172' S & 915' W of NE cr., Sec. 34, T11N, R14E, UM At effective depth At total depth 1180' S & 857' W of NE cr., Sec. 34, T11N, R14E, UM 5. Type of Well Development X Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-5 9. Permit number/approval number 78-13 10. APl number 50 - 029-20293 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10750' feet 9207' feet Plugs(measured) Fill @ 10610' MD (4/28/94) Effective depth: measured 10610 feet true vertical 9086 feet Casing Length Size Conductor 102' 20" Surface 2650' 13-3/8" Production 10672' 9-5/8" CT Liner 709' 2-7/8" Junk(measured) Cemented Measured depth True vertical depth 229 SX AS 102' 102' 4800 sx AS II 2714' 2714' 1200 sx Cl G & 300 sx AS I 10736' 9194' Perforation depth: measured 10534-10554' true vertical 9019-9036' Tubing (size, grade, and measured depth) 5-1/2", 26#, L-80, Tbg @ 33' MD; 4-1/2", 12.6#, L-80, PCT @ 9851' MD Packers and SSSV (type and measured depth) 4-1/2" Otis HRQ SSSV @ 2196' MD; Baker SAB Packer @ 9742' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 1748 26663 0 1225 1524 0 Tubing Pressure 298 195 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. Form 10-404 Rev 06/15/88' 1122/_q ~R.C; ~.' .IFF3 .IWP Title Engineering Supervisor Date ~' Z 7-~ ~/ SUBMIT IN DUPLICATE 7-05 DESCRIPTION OF WORK COMPLETED CTU CONVEYED SCAB LINER INSTALLATION 1/8/94: RIH & tagged PBTD at 10598' MD. 1/27/94: RIH w/CT & pumped gelled sand slurry containing 4000 lbs of 20~40 & 40~60 mesh sand, to place a sand plug to 10525' MD, to isolate the open perforations located at: 10534 - 10554' MD (Z2) Ref Log: BHCS 10/5/78. POOH w/CT. Rigged down. 1/28/94: RIH & tagged the top of the sand plug at 10519' MD. 1/30/94 - 1/31/94: MIRU CTU & PT equipment. Made up & RIH with a CT conveyed Scab Liner assembly, consisting of 23 joints of 3.5" OD, 9.3#, L-80 FL4S Liner (692'), a 3.5" OD Pup joint (9') w/3.5" Float Shoe w/check valves. Landed the liner assembly at 9829' MD, w/shoe at 10505' MD. Disconnected CT from assembly top & POOH. Rigged down. 2/2/94: MIRU CTU & PT equipment. Fluid packed the wellbore w/Seawater, then RIH w/CT & stung into GS fish neck on liner assembly at 9824' MD. Pumped 47 bbls of Latex Acid Resistive cement, down the CT & through the dual check valves, to cement the Scab Liner in position from 9829' - 10505' MD, while simultaneously squeezing the 9-5/8" casing hole located at 10184' MD. Attained 1150 psi maximum squeeze pressure & placed an estimated 8 bbls of cement behind pipe, held for 1 hour. Flushed away cement from CT w/25 bbls of Biozan gel, then PU CT to disconnect from liner assembly. Could not release from liner & POOH w/CT dragging up the top of the liner from above a split at 10184' MD. Rigged down. 2/3/94 - 2/4/94: MIRU Crane & Thongs. Circulated Hot Seawater & Meth Water, then RIH & fished out all the remaining 3.5" liner from the well. Rigged down. 2/6/94: RIH & tagged top of cement at 9958' MD. 4/5/94: MIRU CTU & PT equipment. RIH w/CT mounted 3.625" PDC bit & milled through cement from 9980' to 10485' MD. Circulated wellbore clean w/Seawater & Biozan Gel, then POOH w/milling assembly. PT squeeze to 1000 psi after drillout; leaked off to 250 psi in 10 minutes. Rigged down. 4/7/94: MIRU CTU & PT equipment. 10485' MD, into the sand plug to 10525' MD. POOH w/milling assembly. Rigged down. RIH w/CT mounted 3.625" PDC bit & milled through cement from Circulated wellbore clean w/Seawater & Biozan Gel. 4/8/94: RIH & tagged PBTD at 10514' MD. RECEIVED ;.,. ,~.~.~ ;~: & Gas Cons, 6ommission Anch0ra~e 7-05 DESCRIPTION OF WORK COMPLETED CTU CONVEYED SCAB LINER INSTALLATION 4/21/94: MIRU CTU & PT equipment. Made up & RIH with a CT conveyed Scab Liner assembly, consisting of 23 joints of 2-7/8" OD, 6.4#, L-80 CT Liner (696'), a 2-7/8" OD Pup joint (9') w/2-7/8" Float Shoe w/check valves. Landed the liner on the ' XN' Nipple at 9839' MD, w/shoe at 10510' MD. Disconnected CT from liner top & POOH. Rigged down. 4/22/94: MIRU CTU & PT equipment. Fluid packed the wellbore w/1% KCI FW, then RIH w/CT & stung into GS fish neck on liner assembly at 9819' MD. Pumped 12 bbls of Latex Acid Resistive cement, down the CT & through the dual check valves, to cement the Scab Liner in position from 9801' - 10510' MD, while simultaneously squeezing the 9-5/8" casing hole located at 10184' MD. Attained 1000 psi maximum squeeze pressure & placed an estimated 11.2 bbls of cement behind pipe. Estimated TOC in annulus at 9827' MD. Flushed away cement from CT w/40 bbls of Biozan gel, then disconnected CT from liner assembly. POOH w/CT. Rigged down. 4/23/94: RIH & tagged top of cement in liner at 10158' MD. 4/24/94 - 4/25/94: MIRU CTU & PT equipment to 4000 psi. Made runs w/CT mounted 2.385" carbide & metal muncher mills, to drill through cement from 10150' to 10523' MD. Circulated wellbore clean w/Biozan Gel, then POOH w/milling assembly. Rigged down. 4/28/94: RIH & jetted a sand fill cleanout down to 10610' MD, to uncover the open perforations (listed above). 5/7/94: RIH & tagged bottom fill at 10576' MD. Placed the well on production & obtained a valid welltest. Note: Oil rate decreased by 523 BOPD, but the decrease in the gas rate provided an Incremental Rate Benefit of 2095 BOPD, resulting in a Net Oil Benefit of 1572 BOPD. ~( ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 10-22-93 REFERENCE: ARCO ~FINALS 1-19 "10-1-93 1-22 ~2- 1-74 "10-1-93 1-29 / 10-8-93 2-16A c~-l~ ~'9-29-93 3-9 ~10-6-93 3-29 ~c{ /10-6-93 3-31 ~10-5-93 3-32 ~0~ ~0-5-93 3-33 ~0-10-93 4-4 ~-~ ~0-9-93 4-12 ~ 10-2-93 4-24 ~%- ~o{ ~'10-10-93 ,o~6-4~' 9-30-93 -7%~2~6 4 ~ - 10-1-93 6-12A ~- ~ ~9-29-93 6-13 10-1-93 7-5 7'~-~ 10-6-93 -28 10-9-93 -2S 10-9-93 9-11~t;~ ~ /10-4-93 9-13 /10-3-93 9-20 '77-t{ ~' "10-7-93 ** "-~11-16ST ~10-1-93 12-22 ~t~-~O "9-28-93 /13-20 ~10-2-93 ~, 13-20 /10-10-93 14-3 ~ ~-28-93 ~~ 14-32 ~10-2-93 15-22 ~~ ~9-30-93 1LO 16-17 ~ 10-8-93 16-22e~ -~0-~0-93 %~mOo 17-~5 ~ ~0-8-0~ 17-16 e~-~ 40-3-93 17-21~ ~5~10-4-93 Perf Record Run P_crf_Record Run Prod Profile t~ ~l ~t~''~ Run USlT~,~¢~ ~ ~olor Run Perf Record u t ~ - ~ ~ ~7 R~ Perf Record ~ ~ - ~ ~ R~ Completion R~ Pe~ Record R~ Inj ~o~e j~[~e~/~t~ R~ Perf Record Perf Depth Control/Coa,/cc~ Run Completion Run Leak Detect / %0~ l-r~m~l ~~ Run WProd Proflle/~n l'rer~/~.~ ~ Run /Completion Run ~Prod Profile/~mt~~ef-~ Run ~Dual Burst TDTP Run Leak Detect/~al-~[?~-~T£1i~a Run Leak Detect[Shal7~W-~/~a Run Inj Profile iS~[~el~e~/e~_ Run Dual Burst TDTP Run Data Frac./~'~?~$9~ Run Patch Setting 1~5 ~-50~% Run InJ Profile ]~N~}~ ~1 ~ Run CNTG/GR/CCL Run HLDT ~ ~ ~. l cc t- Run Prod Proffie/Se~alw=-~?a~%i~a Run Completion l~V~ -~u~ Run Completion Run Prod Profilel~a~l 7e~ ~~ Run Inj ProfilePem~ ~%)e~ Run Production ~-~m I-~m~ ~e~/~~ Run Please sign and return th~ attached copy,as r~ceipt of data. RECEIVED BY ~~ Have A Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON #BIX # STATE OF ALASKA The correct APl# for 1-22 is 50-o2g-20848-00. The correct API# for 11-16ST is 50-029-21581-00. The correct API# for 17-16 is 50-029-22286-00. APPROVED_ Z,~_~C~__ _ Trans# 93123"- - # LILLIAN TIULANA # EXXON '" # MOBIL .___ STATE OF ALASKA ALASKA . AND GAS CONSERVATION CC IISSION REPORT OF SUNDRY WELL OPF_.HATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing' Repair well ~ Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1567' S & 92'W of NE cr., Sec. 33, T11N, R14E, UM At top of productive interval 1172' S & 915' W of NE cr., Sec. 34, T11N, R14E, UM At effective depth At total depth 1180' S & 857' W of NE cr., Sec. 34, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 64 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-5 9. Permit number/approval number 78-13 10. APl number .. 50 - 029-20293 11 Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10750' feet 9207' feet Effective depth: measured 10620' feet true vertical 9093' feet Plugs(measured) Fill @ 10620' MD (10/5/93) Junk(measured) Casing Length Size Conductor 102' 20" Su dace 2650' 13-3/8" Production 10672' 9-5/8" Cemented Measured depth True vertical depth 229 sx AS 102' 102' 4800 sx AS II 2714' 2714' 1200 sx CIG & 300 sx AS I 10736' 9194' Perforation depth: measured 10534-10554' true vertical 9019-9036' OCT 5, ? 1993 giaska 0il & Gas Cons. c0mmiSsto~"~ Anchorage Tubing (size, grade, and measured depth) 5-1/2", 26~, L-80, Tbg @ 33' MD; 4-1/2", 12.6#, L-80, PCT @ 9851' MD Packers and SSSV (type and measured depth) 4-1/2" Otis HRQ SSSV @ 2196' MD; Baker SAB Packer @ 9742' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Shut in 1299 023 Tubing Pressure 222 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. S~gned ~-~ F~rm 10-404 ev~06/15/88 ~'~ Title Engineering Supervisor SUBMIT IN DUPLICATE 7-5 DESCRIPTION OF WORK COMPLETED CTU MARASEAL GEL SQUEEZE OF CASING LEAK FOR GAS SHUTOFF 9/2/93: RIH & tagged bottom fill at 10616' MD. 9/5/93: A Fullbore Maraseal Gel Squeeze was performed to seal split casing for Gas Shutoff as follows: MIRU & PT equipment to 4100 psi. Pumped 125 bbls 80° F Seawater down the tubing, followed by 25 bbls 9.5#/gal Xanvis, followed by 145 bbls 80° F Seawater. Shutdown I hour to let Xanvis settle into rathole, then resumed pumping 150 bbls 139° F Seawater Preflush @ 6 bpm, followed by 244 bbls of 8.3#/gal 62° F Maraseal Gel @ 6 bpm, followed by 155 bbls Crude @ 2 bpm, to squeeze the large casing split at 10184' MD, and to resqueeze possible leaking squeezed perforations at: 10386 - 10410' MD (Z2: Sqz'd) 10426 - 10473' MD (Z2: Sqz'd) 10497 - 10508' MD (Z2: Sqz'd) 10522 - 10550' MD (Z2: Sqz'd) Ref Log: BHCS 10/5/78. Placed a total of 235 bbls Gel behind pipe, and briefly attained 1875 psi maximum squeeze pressure. Took two large pressure drops during the squeeze, & hesitated twice before achieving 1100 psi final squeeze pressure, held for 20 minutes. Rigged down. 9/20/93: MIRU CTU & PT equipment to 4000 psi. RIH w/CT & jetted Slick Seawater down to 10620' MD, to cleanout excess Gel from wellbore. POOH w/CT leaving wellbore fluid packed, then PT squeeze to 1300 psi, and had leakoff to 600 psi. Tested injection rate at 0.25 bpm/950 psi, on the squeeze. Pre squeeze injection rate (10/5/92) was 6.0 bpm/950 psi. Loaded well w/75 bbls Meth Water. Rigged down. 9/21/93: RIH & tagged hard bottom fill at 10540' MD. 10/1/93: RIH w/CT & jetted a fill cleanout to 10628' MD. 10/5/93: Reperforated: 10534 - 10550' MD (Z2) Ref Log: BHCS 10/5/78. Added Perforations: 10550 - 10554' MD (Z2) Ref Log: BHCS 10/5/78. Returned well to production w/gaslift & attained a valid welltest. OCT 2 ? t99 A.~aska 0it & Gas Conso Commissit,~: Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 11-3-92 REFERENCE: ~.- ARCO CASED HOLE FINALS 10-3-92 Prod Profile Run 1. l~' Camco 9-28-92 Leak Detect (Flexstak) Run 1. [~' Camco 9-14-92 InJ Profile Run 1, [~' Camco 9-29-92 Inj Profile Run 1, ~' Camco 10-2-92 Prod-InJ (Flexstak) Run 1. I~' Camco 9-19-92 Leak Detect Run 1. ~' Camco 9-26-92 GR/Collar Run 1, I~' Camco 9-27-92 GR/Collar Run 1, ~' Camco 9-25-92 Prod Profile Run 1, [~' Camco 9-14-92 Prod Profile Run 1. ~' Camco 10-2-92 InJ Profile Run 1, [~' Camco 9-4-92 Prod Profile Run 1, g~' Camco 10-4-92 InJ Profile Run 1, ~' Camco 9-26-92 Prod Profile Run 1, ~' Camco 9-26-92 GR/Collar Run 1, [~' Camco 10-5-92 InJ Profile/PITS Run 1, I~' Camco 9-27-92 InJ Profile Run 1. [~' Camco 9-19-92 Leak Detect Run 1, [~' Camco 9-27-92 Prod Profile Run 1, ~' Camco 10-4-92 InJ/6hut-In Temp Run 1, ~' Camco 10-2-92 InJ Profile Run 1, [~' Camco 10-2-92 InJ Profile (Flexstak) Run I, [~' Camco 10-1-92 . InJ Profile Run 1. [~' Camco 9-15-92 InJ Profile Run 1, [~' Camco 9-17-92 Prod Profile (Flexstak) Run 1, ~' Camco 10-1-92 Prod Profile Run 1, iP' Camco 9-28-92 GR/Collar Run 1. ~' Camco 9-28-92 Prod Profile Run 1. [~' Camco 9-15-92 Prod Profile Run 1. ~' Camco 10-1-92 Prod Profile Run 1. [~' Camco Please sign and return t~e attac~e~d copy as receipt of ~,~ E ] V E D _ /.z/' / /~ ~' Alaska Oil & Gas Cons. Commission Have A Nice Dg~! / Anchorage) Sonya Wallace APPROVED ~~(~/_ ATO- 1529 Trans# i}224~-'~ ..... # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL F~F~ # BPX # STATE OF ALAS~ STATE OF ALASKA ALASKA . AND GAS CONSERVATION CC-' 41SSION REPORT SUNDRY WELL OPF..,-IATIONS 1. Operations performed: oparation shutdown Stimulate,.._. Plugging__ Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BOX 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1567' S & 92' W of NE cr, Sec. 33, T11N, R14E, UM At top of productive interval 1172' S & 915' W of NE cr, Sec. 34, T11N, R14E, UM At effective depth At total depth 1180' S & 857' W of NE cr, Sec. 34, T11N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 64' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 7-5 9. Permit number/approval number 78-13 10. APl number 50 - 029-20293 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10750 feet 9207 feet Plugs(measured) PBTD @ 10618' MD (10/2/92) Effective depth: measured true vertical Casing Length Conductor 102° Sudace 2650' Production 10672' 10618 feet 9092 feet Junk(measured) Size Cemented 20" 229 SX AS 13-3/8" 4800 sx AS II 9-5/8" 1200 sx Cl G & 300 sx AS I Measured depth 102' 2714' 10736' True vertical depth 102' 2714' 9194' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, Tbg @ 33' MD; 4-1/2", 12.6#, L-80, IPCT @ 9851' MD Packers and SSSV (type and measured depth) Baker SB-3A Packer @ 9742' MD; 4-1/2", Otis HRQ SSSV @ 2196' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaoe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation Shut-in Subsequent to operation Shut-in Tubing Pressure 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 Engineering Supervisor Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 7-5 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR GAS SHUTOFF 9/14/92: RIH & tagged bottom fill at 10542' MD. 9/17/92: A Fill Cleanout & CTU Cement Squeeze for Gas Shutoff were performed as follows: MIRU CTU & PT equipment to 4000 psi. RIH w/CT & fluid packed the wellbore w/Seawater. Reversed a CT fill cleanout to 10560' MD, then pumped 34 bbls of Latex Acid Resistive Cement to squeeze the perforations at: 10497 - 10508' MD (Z2) 10522 - 10550' MD (Z2) Ref Log: BHCS 10/5/78. Hesitated squeeze pressure to 2950 psi, & took a breakback to 2500 psi after placing 7.5 bbls of cement behind pipe. Hesitated squeeze pressure back up to 3500 psi. After 12 minutes at 3500 psi, squeeze pressure broke back to 0 psi within 2 minutes. Could not rebuild squeeze pressure. Contaminated cement w/biozan & jetted cement from wellbore down to 10625' MD. POOH w/CT. Rigged down. 10/2/92: Performed an Injection Profile indicating a casing leak was present at 10184' MD. I 0/5/92: Ran a video log & saw a large casing split at 10184' MD. POOH. Rigged down. A Sidetrack is currently being planned for 1993. ARCO ,~laska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-10-92 REFERENCE: ARCO CASED HOLE FINALS 2-32 ?/-//? 6-21-92 Prod Profile Run 1, 5" 3-10 77--~/ 6-20-92 Inj Profile Run 1, 5" 3-26~3~?~-/ 6-28-92 Prod Profile Run 1, 5" 4-14 ?~' 3~ 6-28-92 Temperature Run 1, 5" 5-5 7.~-~/? 6-22-92 Prod Profile Run 1, 5" 7-5 6-23-92 Prod Profile Run 1, i~" 9-38 6-30-92 Inj Profile Run 1, 5" 9-39 6-30-92 Inj Profile Run 1, 5" 12-17 ~$~/ 6-29-92 Leak Detect Run 1, 5' 13-158.l-/~'7 6-27-92 Inj Profile Run 1, 5" 13-29~3--~/3 6-19-92 Prod Profile Run 1, 5" 13-32~°.,~'~1..'~$ 6-27-92 Inj Profile Run 1, 5" 14-14~/-/~- 6-26-92 Inj Profile Run 1, 5" 14-36~°3-./~3 6-26-92 Inj Profile Run 1, 5" 16-7 ~f°.>~ 6-19-92 Prod Profile Run 1, 5" Please sign and return the attached copy as receipt of data. APPROVED_~___ Trans# 92150 Have A Nice Day! Sonya W~11~ce AT0-1529 Canlco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO F:'., 0 _. BOX i ,3,,'.:)360 A N C H 0 R A iL; E: A t_ A ~,' K F;,'EFERENCE' ARCO f:'RES'5'URE DATA i--tA ii-23-89 BHF'--£TATiC Gi:;.:ADiENT 2-8 i i-S0-89 Bt--tF: ........ STATIC 3; .... ',:' i 2 4 cd'::' B H F: .... ;.i:'i" ¢', T :i: c; ;-- :,,,, ..--, T '- -- ,. .. ,.,., ~,-, t; ,. [:' N'T' 'S .... i' ':."'.'i i - 2 "5- S g' ":: H F .... :_'i: T A T I f'-: f2- F:: .,q D iiE N 'i' 4--"~ i.,..i i-- 24-:-')c;', BHF ....... S';-A T T r', ., ,, G F;,'A D I E~,l T. 7 .-% ~ 27 - S 9 B H F ....... 3' '!- A 'F ! i.'.'. C-F;.'. A D I E N T i S - 5: i i - 24 - :ii: 9 B H F ...... :"';:' 3" A T :1: C (.;- R ,,':'~ D 1: E N "f' iS-9 i2-i6-89 BHF ....STATIC GF;.:ADiEN'F i3-22 i2-i6-:-39 BHF ....STAT:t:C GRADIENT ! 4--i 3 t 2-6-89 BHF ....:;.:"FATiC GF;:.ADtEN'F i4-2'7 i2-'i7-89 BHF ....STATIC GRADIENT i ;x, g i i '-''- '" - '= :" . '" ,.- ~ 4 ,_,.? BHF'~--Z.";'-AT.[C i ,:I.-56 i 2--i 6-89 BHF ....STAT3:C GF;,'AD]:ENT C A h C F C ~':'.'~ h C 0 C A i'i C 0 C A t'i C 0 C A M C 0 C A H C 0 C A f'i C 0 C A M C 0 C A ~'~ C 0 C ~:'~ rd C 0 C A M C 0 C: A id C'O F'L. EASE 3,'IGN AND F:ETURN TI-tIE A'f"F~CHED COF'Y A;£ !4.'ECEIF"F OF Rii:-.CE]:VED E:y HAVE A NICE DAY! £At_LY HOFFFCKER ATO-i 529 FEB 1. !990 A~aska Oil & Gas Cons. Go~ Anchorage ~'1' "2TR 1' BU'I' ]: QN AF'F'ROVED .~. .... I'RAN3'~ 9¢'~o9~;'3 DATA CENTRAL FILES CHEVRON D & M EXTENSION EXF'LOF,'ATi ON EXXON .. MARATHON' · MOBIL F'I-tILL tF'$ F'B WELL F:']:LES' ¢ R & D ,,. ¢ S'FATE OF' ALASI<A :~ TIE X A C 0 ARCO ALASKA, INC. P~O. BOX i00360 ANCHORAGE, ALASKA 995 i O DATE' t2-20-89 REFERENCE' ARCO CASED HOLE FINALS 3-t ¢ t t / ~-..._,/o9 TEH ~'URVEY (PRE-FRAC) RUN t 4-2t t t-24-89 PITS RUN I'-' 7-5 t i -">7-89 PRODUCTION I::'ROF ILF RUN it-4 tt-25-89 PRODUCTION PROFILE RUN i, t t -i ~' t i --'>5.-89 'I"EMF' RUN i ~,_ · i i-t 7 t t.-26-89 F'RODUC't"ION I'"F;.:OFILE RUN 1 , t i-23 t t-"~":'-89 PITS RLIN i i3-6 ti-24'-89 LEAK DETECTION RtJN t4-38 tt-23-89 LEAK i)ETECTION RUN PLEASE ~IGN SALLY HOF:F'ECKER DEe, 281989 ATO- t 529 O. m Gas COn cho ge. AND RETURN THE A'¥TAC!fED COPY AS RECEIPT OF DA'Y'A, DISTRIBUTION ~ CENTRAL FILES ~. F'HII_LIF'S -.-~"' CHEVRON F'B WELL FILES D & M R & D -.- E"XTENSI ON EXPLORATION '~- BF:'X ~~ EXXON .$ ~ ~TAI'E OF ALASKA HARAI'HON ~ TEXACO ~ MOBIL CAMCO C A H C CAMCO CAMCO C A i"i L; (] CAM(;(] C:: A H C 0 C A i',i C 0 CAMCO ARC(] ALASKA, INC. P.O~ BOX 'i00S6¢ ANCHORAGE, ALASKA 99510 DATE:' 8-29-89 REFERENCE' ARCO PRESSURE DATA 5--t5 7-'27-89 BHP--~'TATIC GRADIENT CAMCO S-SS 7-t4-89 BHF'--STATIC GRADIENT CAMCO 4-2 7--8.-89 BHF'--~'TATIC GRADIENT (W/ATTACH.) CAMCO 7-5 7-t9-89 BHP--£TATIC GRADIENT CAMCO 7-7A 7-St -89 BHF ....PBU HR~' 7-8 '?-29-89 BHP--~'TA'I' I C GRADIENT CAMCO 7-t0 8--5'-89 BHF ....£'TATIC GRADIENT CAMCO 7-t 4 '?-29-89 Bi-IF .... PBU HR$ 7-27 7-23-89 BHP--$TATIC GRADIENT CAMCO '?-SS 7-2~-89 BHF ....STATIC GRADIENT CAMCO 9-:24 7/t4-t5/89 BHF'--S'TATIC GRADIENT CAMCO 9-~8 8- t';Z-89 BHF'--~TATIC GRADIENT CAMCO t t .-2 7-7-89 BHP--~'TA'FIC GRADIENT HR~' tt-7 7-9-89 BHP--~TATIC GRADIENT HR$ t t -t 6 7-t 0-89 BI-'tF'--~'TATIC GRADIEN'T' HR,S' ~t-t7 8-tl-89 BHP--FI_OWING GRADIENT CAMCO t 2-:30 7-2S-89 BHP--$TATIC GRADIENT CAMCO t4..-t9 8-t 0-89 BHP--$TATIC GRADIENT CAMCO t4-22 8-t 7-89 BHP--$TATIC GRADIENT CAMCO ~4-S6 7-29-89 BHP--FLOWING GRADIENT CAMCO t4-~9 8-tS-89 BHF'--S'TATIC GRADIENT CAMCO t5-t5 7-2t-89 BHF'--$TATIC GRADIENT CAMCO t 6'-t 2,, 7-26-89 BHF'--;S'I'ATIC GRADIENT CAMCO t 6.-2¢ 7--i ~-89 BHP--$TATIC GRADIENT CAMCO t 8-25 7--i S-89 BHF'--~'TATIC GRADIENT CAMCO PLEASE ~IG N AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. DI£TRIBUTION CENTRAL FILES CHEVRON ~ D & M E'XTEN$ION EXPLORAI'ION ~ EXXON MARATHON /2.. - ,$ MOBIL ~ PHILLIF'~' PB WELL F'ILE~' R & D BPX STATE OF ALASKA TEXACO ARCO ALASKA, INC. F'.O. BOX i4)G360 ANCHORAGE, ALASKA 995i G DATE: REFERENCE: 8-t t-89 ARCO CASED HOLE FINALS 2-t4 4-22 4-26 7-5 7-7A ?-t4 7 tt-t8 t 1-24 t t-25 i4-t5 44-t6 t4-20 ~ 4-24 7-t4-89 PITS 7-t6-89 RIT$ 8-4-89 COLLAR/PERF 7-42-89 TEMP 7-t9-89 GR/CCL 7-J4)-89 SPINNER/TEMP 7-28-8? SPINNER/TEMP 7-23-89 COLLAR 5-t8-89 I'MD 5-t7-89 TMD 7-t2-87 TEMP 7-2J-89 COLLAR 7-2~-87 PITS 7-47-89 PITS ?-2t-8~ PITS 7-22-89 PITS RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN RUN PLEASE SIGN AND R RECEIVED BY · HAv~ ~ ~ZC~ ~A¥ ~ SALLY HOFFECKER AT0-1529 ETURN THE ATTACHED COPY AS RECEIPT OF DATA .. . . · V 7&~slm oil & Gas cons. ~omm~l~N s, e ~ 3 4 ~ Anchorage 2"&5" 2"&5" 5" 2"&5" 5" 5' 5" 5" 5" 5" 2"&5" 5" 5" 5' 5" 5" CAMCO CAMCO ATLA~ CAMCO CAMCO OTIS OTIS CAMCO HLS HL$ CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES ~ ~ PHILLIPS CHEVRON F'B WELL FILES D & M R & D EXTENSION EXPLORATION ~ BPX EXXON ~ ~ STATE OF ALASKA M~RATHON ~ TEXACO MOBIL * THE CORRECTED AF'I~ FOR ~i4-~6 IS 50-4)29-20688. " STATE OF ALASKA ~~ ~ ALASKA ulL AND GAS CONSERVATION CC,,,,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS .r i SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO A1 aska, I nc. 78-1 3 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20293 4. Location of well at surface 1567' FNL, 92' FEL, 5ec.33, TllN, R14E, UN At Top Producing Interval 1172' FNL, 915' FEL, Sec.34, TllN, R14E, UR At Total Depth 1180' FNL, 857' FEL, Sec.34, T11N, R14E, UR 9. Unit or Lease Name Prudhoe Bay Unit. 10. Well Number 7-5 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 64' I ADL 28309 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 09/19/78 10/05/78 10/13/78* 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 10750'MD/9207'TVD 10693'MD/9158'TVD YES [] ~O [] I 2196' feet MD 22. Type Electric or Other Logs Run FDC/CNL/Ca]/GR, DIL/SP, BHCS/Ca]/GR~ CBL~CCL~ Gyro 23. CASING, LINER AND CEMENTING RECORD 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 15. Water Depth, if offshore 16. No, of Completions N/A feet MSL 1 21. Thickness of Permafrost 1900' (approx.) SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94.0# H-40 13-3/8" 9-5/8" 72.0# 47.0# N-80 N-80/RS/$0( ,-95 Surf Surf Surf 24. Perforations open to Production (MD+TVD of Top and interval, size and number) 102' . 2714' 107~R' ~),, 17-1/?" '~ ~-!/4" 229 s× AS cmt ~800 ~x AS II !200 sx C!ass G & 399 ~ottom and 25. TUBING RECORD ~v A~ I SIZE DEPTH SET (MD) PACKER SET (MD) 4½" 9851 ' 9731 ' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 10386 ' -10410 'MD/8890 ' -8911 'TVD 10426 ' -10473 ' MD/8926 ' -8966 ' TVD 10497 '-10508 ' MD/8987 ' -8996 ' TVD 27N/A PRODUCTION TEST Date First Production Date of Test Hours Tested IMethod of Operation (Flowing, gas lift, etc.) GAS-MCF PRODUCTION FOR IOIL-BBL TEST PERIOD $ 1 IOIL-BBL Flow Tubing Casing Pressure CALCULATED GAS-MCF Press. 24-HOUR RATE I~ 28. CORE DATA WATER-BBL WATER-BBL ICHOKE SIZE JGAS-OILRATIO OIL GRAVITY-APl (corr) Brief description of l ithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. None *Note: Perforated well 12/22/78. Workover performed 7/15/89. (Dani) WC6/053 RECEJVED ALiC 0 2 t989 ~laska Oil & 8as Cons. Comm/ssl0i Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. ~,, 30, , GEOLOGIC MARKERS FORMATION TESTS : · , , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. OEPTH GOR, and time of each phase. Top Sadl erochi t 10000 ' 8562 ' N/A Base Sadlerochit 10632' 9105' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Signed ~/~ ~ ~Z~O~ J Title Drilling Analyst Date 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 (D.F, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10~407 ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager July 22, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 7-5 Approval No. 6-550 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations formed on the above-referenced well. Very truly yours, D. F. Scheve DFS/CMH/jp Attachment cc: Standard Alaska Production Company J. Gruber, AT0-1478 P!(DS 7-5)Wl-3 detailing work per- WELLS3/05 AR3B-6132-C --- STATE OF ALASKA AL ~A OIL AND GAS CONSERVATION COMM. ,3N REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate __ Pull tubing __ Alter casing __ Repair well ~ Pull tubing ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1567' FNL, 92' FEL, 5ec.33, T11N, R14E, UN At top of productive interval 1172' FNL, 915' FEL, 5ec.34, T11N, R14E, UN At effective depth 1176' FNL, 885' FEL, 5ec.34, T11N, R14E, UN At total depth 1180' FNL, 857' FEL, $ec.34, T11N, R14E, UN 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 64 ' 7. Unit or Propedy name Prudhoe Bay Unit 8. Well number 7-5 9. Permitnumbedapprovalnumber 78-13/9-315 10. APInumber 50-- 029-20293 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10750 ' MD feet 9207 ' TVD feet 10693 ' MD feet 9158 'TVD feet Plugs (measured) Junk (measured) None. None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented 80' 2684' 20" 229 sx AS 13-3/8" 4800 sx AS II 10708' 9-5/8" 1200 sx Class G & 300 sx AS I 10386-10410 ', 10426-10473, 10497-10508 ' Measured depth 102 ' MD 2714'MD 10736'MD True vertical depth 102 ' TVD 2714 ' TVD 9194 ' TVD true vertical 8890-8911 ', 8926'-8966', 8987 ' -8996' Tubing (size, grade, and measured depth) 4-1/2", L-80, tbg w/tail (~ 9851' Packers and SSSV (type and measured depth) 01;is 'HRO' SSSV ~. 2196' & Baker 'SB-3A' pkr (~ 9731' 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments ' ~ i6. Status of well classification as: Copies of Logs and Surveys run __ ! Daily Report of Well Operations ./ Oil ~ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Form 10-404Rev06/15/88u * Workover Wel 1 History (DAM) SW04/046 SUBMIT IN DUPLICATE ARCO Oil and Gas Company O Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. · I County, parisl~ or borough ARCO ALASKA INC. ~ ~?..~T.n=~ I Lease or Unit - -- PRUDHOE [ Auth. or W.O, no. Title ~,.DL: ~R~lt3o~ A83005 I WOt~KOV~R District Field State JWe, no. Opera[or ARCO Spudded or W.O, begun ACCEPT Date and depth as of 8:00 a.m. 07/07/89 ( TDt10693 PB:10693 SUPV:ZR 07/08/89 ( TD=10736 PB=10693 SUPV=ZR 07/09/89 ( TD=10736 PB:10693 SUPV:ZR 07/10/89 ( TD:10736 PB:10693 SUPV:ZR 07/11/89 ( TD=10736 PB:10693 SUPV:ZR 07/12/89 ( TD:10736 PB:10693 SUPV:ZR The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pallas 86 and 87. APl -- Bo-oge-~n~9? JARCO W.~. I JDate [Ho.r 07/06/89 Complete record for each day reported AUDI 4 POOH & LD 5-1/2 TBG. MW: 8.5 FSW MIRU. ACCEPT RIG 0600 7/6/89~ KILLED WELL. ND TREE. NU BOPE. TEST BOP. REMOVED 2 7/8" PIPE RAMS. INSTALLED 3 1/2" PIPE RAMS. TESTED 13 3/8" PACKOFF TO 2000 PSI. OK. PULLED AND L/D TBG HGR WITH PUP JT. CONT TO POOH AND L/D 5 1/2" TUBING. DAILY:S70,000 CUM:S70,000 ETD:S70,000 EFC:$806,000 POOR W/ FTA #1 MW: 8.5 FSW SERVICE RIG. CONT POOH W/ 5-1/2 TBG. SLIP DRILL LINE. PULL TBG. COLLAR ON 9214 CRUSHED. CHANGE TO 3-1/2" RAMS. INSTALL W-RING. STRAP & MU FTA 91. TAG FISH ~ 9033'. WASH & ROTATE ONTO FISH. PU W/ 15-20K OVER STRING WT. WORK PIPE. POOH W/ FTA 91 DAILY:S27,100 CUM:$97,100 ETD:S97,100 EFC:$806,000 POOH W/ FTA #3 MW: 8.5 FSW SERV RIG. CONT POOH W/ FTA [1. NO RECOVERY. MU FTA 92. RIH W/ 3-1/2" DP. CUT & SLIP D-LINE. ROT OVER FISH W/ WASH PIPE F/ 9033' TO 9041'. POOH. NO RECOVERY. MU FTA 93. TAG FISH ~ 9037'. LATCH FISH. PU WT INC BY 6K TO 141K POOH SLOWLY W/ FTA #3. DAILY:S33,196 CUM:$130,296 ETD:S130,296 EFC:$806,000 POOH W/ FTA #5 MW: 8.5 FSW SERV RIG. POOH W/ FTA #3. RECOVERED JT #215. JT COMPLETELY CRUSHED. COLLAR STILL IN HOLE. MU FTA ~4 W/& OVERSHOT. TAG FISH @ 9075'. ROTATE OVER & PU W/ 5K OVER STRING WT. POOH W/ FTA ~4. LD GUIDE WHICH WAS SPLIT. MU FTA ~5 W/ 6" INSIDE MILL & OVERSHOT. RIH. SLIP D-LINE. CONT RIH. TAG FISH 8 9073'. ROT OVER. LATCH ON. PULL 65-80K OVER STRING. JAR UP. ROT 14 TIMES TO RIGHT. RELEASE K-ANCHOR. POOH W/ 9K OVER STRING WT. DAILY:S27,100 CUM:$157,396 ETD:S157,396 EFC:$806,000 RIH TO FULLY ENGAGE FISH MW: 8.5 FSW SERV RIG. CONT POOH W/ FTA #5. LD FISH- 10 JTS TBG, TBG PUPS, SLIDING SLEEVE, NIPPLE,SBR & K-ANCHOR. MU FTA #6. RIH & TAG PKR @ 9579'. MILL F/ 9579' TO 9583' CBU TO REMOVE TRAPPED GAS. 10 BBL GAIN. POOH W/ PKR. 20-30K DRAG. NO DRAG AFTER 10 STDS. RIH TO ENSURE PKR LATCHED. DAILY:S27,000 CUM:$184,396 ETD:S184,396 EFC:$806,000 POOH W/ RTTS MW: 8~? aIa TO RET LOST FISH (PKR). LATCH W/ PRT ~ ~925 FTA #6. NO RECOV. MU FTA %7 (SPEAR). RIH. CUT & :~LIP~.i D-LINE. TAG FISH @ 10531'. PU W/ 50- 80K pRA~. ~iRC ~ MIX DRY JOB. POOH W/ FTA & FISH. MU & RIH W/ 9-5/8.~_~ ~. SET RTTS ~ 251~'. JTitle ' - AR3B-459-1 -D JNumber all da y well history forms consecutively as they are prepared for each well. Page no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO ALASKA INC. ICounty or Parish IState NORTH SLOPE AK Lease or Unit DS 7-5 IWetl no. Date and deptll as of 8:00 a.m. 07/13/89 TD:10736 PB:10693 SUPV:ZR 07/14/89 TD:10736 PB:10693 SUPV:ZR 07/15/89 TD:10736 PB:10693 SUPV:ZR Complete record for each day while drilling or workover in progress AUDI 4 3000 PSI F/ 15 MIN NO BLEED OFF. POOH W/ RTTS. DAILY:S59,707 CUM:$244,103 ETD:S244,103 EFC:$806,000 7) MU BHA FOR CLEAN OUT MW: 8.5 FSW SERV RIG. CONT TOH W/ RTTS. PU & RIH W/ RET BP. SET @ 9778'. TEST 9-5/8 CSG TO 3000 PSI F/ 30 MIN. GODD. TOH 2 STDS. MU RTTS. RIH HANG OFF DP. ND BOP & TBG HEAD. NU REPLACEMENT HEAD & INSTALL NEW PACKOFFS. TEST ALL TO 5000 PSI. NU BOPS & TEST SAME. RECOVER RTTS & STORM VALVE. RIH & RECOVER RET BP. POOH & LD BRIDGE PLUG. MU BHA FOR CLEAN OUT RUN. DAILY:S27,100 CUM:$271,203 ETD:S271,203 EFC:$806,000 8) RUN 4-1/2" COMPLETION MW: 8.5 FSW SERV'RIG. CUNT RIH W/ 8-1/2" BIT. SLIP 42' D-LINE. TAG FILL @ 10554' (AUDI4 RKB). CO FILL F/ 10554' TO 10672'. CIRC & PUMP HEC SWEEP. CHASE W/ S-WATER. PUMP 2ND 50 BBL HEC SWEEP. CIRC @ 5 BPM. POOH & LDDP. LD BHA. PULL WEAR RING. CHANGE RAMS TO 4-1/2". TEST SAME. RU FLOOR TO RUN COMP. PU TAIL PIPE , 9-5/8" SB-3A PKR. RIH W/ 4-1/2" TBG. (OTIS 'HRQ' SSSV @ 2196', BAKER 'SB-3A' PKR @ 9731', & TT @ 9851' . ) DAILY:S47,932 CUM:$319,135 ETD:S319,135 EFC:$806,000 9) BLEED ANNULUS MW: 8.5 FSW CUNT ANN TEST. BLEED OFF. LD LNDG JT. DAILY:S32,464 CUM:$351,599 ETD:S351,599 EFC:$806,000 The above is correct For form ~reparation and distribution see Procedures Manual Section t0, Drilling, Pages 86 and 87 ~ AR3B-459-2-B INumber all daily well history forms as lhey are prepared for each well. consecutively IPage no ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Flaal Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and~epresentatlve test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if s0ace is available. IAccounting cost center code .Slate AK DS 7-5 IWell no. lCounty or Parish .~..DistrtctA~CO ~ASY,~ INC. I NORTH SLOPE ILease or Unit Field PRUDHOE I ADL: 28309 I Auth. or W.O. noAs3005 J Title WORKOVER API: 50-029-20293 Operator AR, CO } A.R.Co. W.~.0,0000 Spudded or W.OA~i~T IDate 07/06/89 I Iotal number of wells (active or inactive) on this, ost center prior to plugging and bandonrnent of this well our 0600 IPrlor status if a W.O. I Date and depth as of 8:00 a.m. 07/16/89 ( TD:10736 PB:10693 SUPV:ZR Complet ..... ~[~)r.l.ea~h day reported RIG RELEASED MW: 8.5 FSW ND BOP. NU TREE. TEST 5-1/2" GRAY GEN II TREE TO 5K PSI. PULL TEST PLUG. PRESS ANN TO 1K PSI. PRESS TBG SLOWLY TO 3800 PSI. SUB SHEARED. BLEED ANN. SET BPV. RELEASE RIG @"1100 HRS, 7/15/89. DAILY:S287,511 CUM:$639,110 ETD:S639,110 EFC:$806,000 Old TD Released rig Classifications (oil, gas, etc.) New TD I PB Deplh Date IKind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. . Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signatu~,~ Dat ITitle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. OlvlNon of AttsntlcRIchfleldCompany l/i RECEIVED ~' '~ Dee ...- ,Ill ~~&~~s.~m~o~:_: ......... n ,~.~,.~,~,~_ ...': ....... ~/._~ _.. ...... ~_ . ,,'..~~~ .... ~... ~-. .... . , ~. ~, :. , , .',. , .... . -~ _ - . _,_, .,,; .,.., ..... ., i ii ..... ,. . , ,. ...... i _ . ., . ._ _~ ~:~:~ ~'~"~':'"' ' ~l~Ible Choke. de)*o ind :Enspea~or/ · ;' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown __ Re-enter suspended well ~ Plugging __ Time extension ~ Stimulate ~ Pull tubing ...¢_ Variance ~ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface 1567' S & 92'W of NE cr,. Sec.33, T11N, R14E, UM At top of productive interval 1172'S, & 915'W of NE cr, Sec.34, T11N, R14E, UM At effective depth 1Att69(~lsd%'pth857'W of NE cr, Sec.34, TllN, R14E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 64 ' 7. Unit or Properly name Prudhoe Bay Unit 8. Well number 7-,5 9. Permit number 78-13 10. APl number 50-- 029~20293 11. Field/Pool Prudhoe Bay 0il Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 102 ' Surface 2714 ' Intermediate Production 10736 ' Liner Perforation depth: 10750'MD 9207'TVD 10693'MD 9158'TVD Size feet Plugs (measured) feet feet Junk (measured) feet Cemented 20" 229 1 3-3/8" 4800 None None Measured depth True vertical depth 102' 102' 2714' 2714' 9-5/8" 1 200 1 0736' 9194' measured 10386-10410', 10426-10473', 10497'-10508' true vertical 8890-8911', 8926'-8966', 8987'-8996' Tubing (size, grade, and measured depth) 5-1/2" to 9715'MD RECEIVED Packers and SSSV (type and measured depth) CAMCO Bal-0 SSSV (~ 2249'MD; Baker SAB Packer ~ 9597'MD &iaska Oil & Gas Cons. Anchorage 13. Attachments Description summary of proposal ..¢- Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 115. Status of well classification as: August 1~ 1989 16. If proposal was verbally approved Oil Name of approver Date approved Service 17. I hereby certify that_the fp[egoing is true and correct to the best of my knowledge. Signed "~-'./ ~ Title Regional Drilling Engineer ,(// FOR COMMISSION USE ONLY 074/SA4 Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- ~pproved COPY ORIGINAL SIGNED BY Returned- Approved by order of the CommissioLn0NNIE C. SMITH Commissioner Gas __ Suspended __ Date J Approval N o. ~'~_~/,,~-- Date ~ ~'~, J-~-¢9¢, Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PBU DS 7-5 PRELIMINARY WORKOVER PROCEDURE OBJECTIVE: Pull the 5-1/2" tubing, mill up the packer, test the 9-5/8" casing and clean out to PBTD. Run 4-1/2" IPC tubing with GLMs and 9-5/8" permanent packer. 1. MIRU Audi 4. 2. Kill well with seawater and/or HEC pill. unmanageable, a Temblok pill may be required. If fluid loss is 3. Set BPV. ND tree. NU BOPs and test same. Retrieve BPV. 4. Pull 5-1/2" NPC completion string. 5. Fish remaining 5-1/2" tubing and Baker SBR/pup joint/K-anchor assembly. 6. Mill and recover Baker 9-5/8" SAB packer and tailpipe. 7. TIH with 8-1/2" bit and 9-5/8" scraper. Clean out 9-5/8" to top of hard fill or PBTD. 8. TIH with 9-5/8" squeeze tool. Pressure test 9-5/8" casing to 3000 psi for 30 min. POOH. LD DP. 9. Run 4-1/2" IPC tubing with GLM's and 9-5/8" packer assembly. Tubing will be hung below a 5-1/2" Gray Gen II retrofit tubing hanger. 10. Displace well with inhibited seawater and freeze protect top 2200' of the well with diesel. Drop ball and set packer. 11. Test tubing to 3000 psi for 30 min and annulus to 3000 psi for 30 min. 12. Set BPV. ND BOPs. NU 5-1/2" 5000 psi WP tree and test. RECEIVED Oil & Gas Cons, C~mrnissi°~'~ Anchorage 13. Release rig. Pull BPV. BHP: 3594 psi @ 8864'MD (7.80 ppg EMW) Workover fluid: 8.5 ppg seawater O03/PW08 STATE OF ALASKA ALASK*-, OIL AND GAS CONSERVATION COMM,oSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging ' Perforate -- Pull tubing Alter Casing ~ Other ~ 2. Narne of Operator ARCO Alm.~l¢2: Tnt'. 3. Address P. O. Box 100360~ Anchorage~ AK 99510 4. Location of well at surface 1567' S & 92' W of NE cr., Sec. 33, TllN, R14E, UM At top of productive interval 1172' S & 915' W of NE er., Sec. 34, TllN, R14E, UM At effective depth At total depth 1180' S & 857' W of NE cr.~ Sec. 34, TllN, R14E, UM 11. Present well condition summary Total depth: measured true vertical 10750 feet 9207 feet Effective depth: measured 10693 feet true vertical 9158 feet Casing Length Size Plugs (measured) Junk (measured) Cemented 5. Datum elevation (DF or KB) &/, ' RWB 6. Unit or Property name Prudhoe Bay Unit 7. Well number 7-5 8. Approval number 6-550 9. APl number 50-- 02q-2029~ 10. Pool Prudhoe Bay Oil Pool Feet Measured depth True Vertical depth Conductor 102' 20" 229 sx Surface 2650' 13-3/8" 4800 sx Production 10672' 9-5/8" 1200 sx 102' 102' 2714' 2714' 10736' 9194' Perforation depth: measured 10497-10508'; 10522-10550' true vertical 8987-8996'; 9009-9034' Tubing (size, grade and measured depth) 5~"2 , 17#, L-80, NPC @ 9604' MD Packers and SSSV (type and measured dePth) Camco Bal-0 SSSV ~ 2243' MD; Baker SAB packer @ 9~92' MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Attached 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 1800 13,102 0 -- 3300 2,416 0 Tubing Pressure 2020 330 14. Attachments 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 .,~ Form 10-404 Rev. 12-1-85 WELLS3/05 C. M. Hi~htower, 263-4713 Date ~Z///¢f'' Submit in Duplicate/~ DS 7-5 CTU SQUEEZE AND REPERFORATION WORK SUMMARY 11-10-86: SHOT SQUEEZE PERFORATIONS AT 10540' - 10550' BHCS. SHOT AT 4 SPF, 180 DEGREE PHASING, WITH 3.125" GUN. 11-12-86: DID PRESQUEEZE ACID WASH OF PERFORATIONS AT: 10386' - 10550' BHCS (OVERALL), USING 35 BBLS 15% HCL ACID AND 50 BBLS 6~ - 1.5~ HCL/HF MUD ACID. 11-13-86: SQUEEZE CEMENTED PERFORATIONS AT: 10386' - 10550' BHCS (OVERALL), WITH 40 BBLS CEMENT (15.8 PPG). CONTAMINATED CEMENT IN WELLBORE. WOC. 11-14-86: JETTED WELLBORE CLEAN TO 10644' MD. 12-04-86: MADE GAUGE RUN TO 10689' WLM. 12-07-86: LIFTED WELL DOWN TO 3000' WITH NITROGEN. 12-08-86: REPERFORATED WELL IN THE INTERVALS: 10497' - 10508' MD, BHCS 10-5-78 10522' - 10550' MD RETURNED WELL TO PRODUCTION. ARCO ALASKA, P.O. BOX tOOS60 ANCttORAGE , ALA,.~K DATE: 2-t0-88 I~EFI~[RENCE· ARC][] MAGNETIC TAPE,.~ W/I...I,.~TIN[; ~ 3-9 ~ 2-4-87 S-2S t 2-4-87 ~4-~ 6. ~ 2-2-B7 ~ 4-32 i 2-3-87 "'" 7;~5";;- t 2-'~-87 ~ ~5-5 ~-4-88 MAGl'APESECC-S228 CN/M,? MAGTAF'ESECC-S227 CN/M,~ MAGTAF'ESECC-S225 CN/M~? MAGTAF'ESECC-S226 CN/M,.~ MAGTAF'E,$ECC-S2,.%0 CN/M,.~ MAGTAPE~.ECC-S24(') CN/M,.~ RI.IN RI.IN RI.IN RI,IN RI. IN RI,IN F'LEA~tE ~IGN AND RETURN THE ATTACHED COPY A,.~ RECEIPT OF HAVE A NICE PEG.t,Y BENNETI' _. ,~.9F __% DT2TRIBL.ITION TRAN~ $88~96 APPROVED DATA. ATt..AS ATI. A2 ATL. A2 Al'LA2 ATt. A2 ATI...A,.~ (2)CENTRAl... FIL..E~ ~ PHILI..IF'I' CHEVRON PB WEI. L FII.E2 I) & M R & D (t)F',MCF'HEETER~ ~ SAF'C EXXON ~ STATE OF ALASKA MARATHON TEXACO MOBIL. ARCO ALASKA, INC. ANCHORAGE, ALASKA 99510 REFERENCE' ARCO CA~ED HOI_E FINAl_ ~ S-9 t 2-4-87 --- 3-23 t 2-4-8'7 ~- 4-t6 t 2-2-87 ~ 4-32 t 2-;~- .R7 '"'"--~, ~-5 t 2-6-87 ~,, t t-3 t 2-2-87 CN/MI.II_.TI~PACE/DR CN/MIIL..TI~F'ACE/6R CN/M!JLTI~PACE/6R CN/MI..ILTISPACE/~R CN/MtJLTZ~PACE/GR CN/MI. ILTZ~F'ACE/GR PI.EA,.~IF ,S'IGN AND RET!JRN T__HI~,,,~'~T~ED~C, OF'Y A,~ F,'ECEIF'T ! N3.S~ O~, 8, Gas Cons. Co~'tsS'tO~t HAVE A NICE DAY~s.k~&~Of,gO ATO-t 529 TRAN~ $88036 ~ APPROVED ..... DI~TRIBI..ITTON RUN t, 5 · RI. IN 1, 5 · RI.IN ~, 5" RLIN i , 5" RUN t, 5 · RtllN t, 5 · OF DATA, WAI WAT WAI WAI CENTRAl... FII_E~ CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIl_ ARCO ALaskm, Inc. Anchormgm, A La.ska DATE' 9-30-87 REFERENCE' 9-.5 ,~ ~ ~-4 9-84 CH 7-5 ~' ~-2t&3t-85 CH ~ 5-~ ~ 5-~ 6-87 CH 3-9/ 5-~5-85 CH CN/M~, ~ 4-35/5-~ ~-85 CH ARCO Magne}ic Tapes w/Lis¢iog ECC208S ECC2~ ECC2~78 ECC2t79 ECC2~66 Run 2 Run 6 Run 2 Ru.n ~ AC I.a.$ AC I.m.s A+, Las F'~ea$e sign and re¢~-I~~~eceJpt Iff AVE A NICE - TE~NS App~-oved D of da}a. ~ (2)Ceotra[ Fi Les ~ Phi [Lips Chevron PB Wel.[ Fi res D & M R & D · ~"~( i ) F' , Mc F'h ee t' er .s .~ ~AF'C ~ Exxon ~ E~a+e of Alask Mm r a t h on ~... :~ .", ,': o Hob i [ ARCO AI.a~.~'i<a, Inc. i::'~0. Box ~(.)-0360 Anc:hc~r'age, ALaska 995i0 DATE: May'ch '27, i987 R E F' F.:: R E N C E: A R C 0 :3-t 4 S-.i 6-87 4-4 ;5-i S--.-87 4-6 ZS--t 6--87 4 .- i :3 S-. i S -' 8 '7 4-10 :~ .... i .5--~l"? · ?- t 7-2 7-5 S"-8-.87 7-9 7 .... i 0 :~- 8-87 7'-i 7 S--i i-8'? 7 .... i 8 :3 '-'- 9 --8'7 i S-2i S-i '2-8'7 i 4-4 i 8- S S- i 4- 8'7 C a .s' ecl I..I o i. e I= i n a L F'ro. duct.'ion Pv'o. fi Le Run i, ':".'_, [;R/CCI.. Run i , ."5" I iq .j , F:'~" o 'f" i I. e R t.t'lq i , % ' In.j, I:'r'o'f:i I.e Run t, 5" F:'u. mpIn 'T'emp, I...o5! Run t, 5" S'pinner'/Fl. uid Den.s'it.'y Run t, '.5" S p i n n e ~" / I:: L u icl D e n .~ i !; y F:,' u. n i , ":..j" S'pinner Run t, 5" S'pinnev'/'l'emp. Run t, 5" ..c.,.pinner/Fl. uid Den.-.-;ity Rtin t, 5" ~:p i n n e 'r'/'t" e m p, R u n t , .5" Pr'c, duc't'ion Pr'o fi I.e Run t, .5" S'p inner/F I. u id i)ens' i ty Ru.n t , ':S' In.j,,- F:'ro'f:i Le Run t, 5" 'T'emp/FLowme'l;er/FLuid i)en~i'ty Run t, l..eai< De't'ect:,/Dii':f,Temp/FLow, Rtin t, 5" I::'l. ea~e .t~ign and fei'urn 'the at~'i:.ac:l"~ecl~y as'~"ec:eip't of clat:a, .................... ' I"1A V E: A iq I C I:i: D A Y~i~ .~' ,. ~ Alaska. Oil & Gas Cons. Gommioslo~ R o.s' a n n e F:'e e k Anohore,~o ATO-i '"~: ::~ 9 D I S'¥' R I B U T I 0 N :~1: C e n 't' ~- a L F:' i L e s' :,',': i::' h i I. L i p "~...C'. h e v r' o n P B W e I. I. F' i !. e....,s' D ,t, M R ° -. Cx .. '"' 0 :,'1:I:.Ex't'en:~;ion Exp i. or'a't' ion ..,~ ..... Sol'ii fLA' '"' '"'. :;-,s' · ,,.E ::< ::-.'. o n ... 't':,.~ i: e.: ' ft a r' a t' h o n :',':'1" e x a c o !1, .,,. Pi o b i I. "2' o o,::.' t / ,.' ..! . DATli!:' Decembe¥' t 8, l°°~'- F:: E F:' Iii: R Iii: N C iii:: A R C 0 C a s' e d I..I o !. e F:' i n a I. "? ..-. 5: t~-.. ''~ '"-8 ....,.,° 6 fi; N L.. '7 --. 5 t 2 ...-8 -8 6 P e 'r- f o ¥' a t' i o n R e c o r' d D I Y'i" R. I BUT I ON · 'il:C e n .I: 'r' a t. F: i I. e ~: :',': P h i L L i 1:.) ...... · II: C h e v'r' o n t::'B W e L I. I=' i L e s D & J"i R & D :',': [il x -I: e n.~: i o'n I"_-': x p t. o'r' a -I: i o ni: ~' o h i o · 'JJ:E x x c.', n :~: ~.' !' a t' e o 'f' A L a ~.' I< a J"i.:~ 'r' a t: h o n ~ Te x a c: o :,~: M c,l::, i L ARCO At.a:~:ka, Inc. P..O~ Bo× ~O(~S6G Anchor'age, Alaska REFERIENCE: ARCO Mag'ne±it' Tape:..: w/t. is't' "~----':~' ~'~-.-8-68 Maq~' p~-~ ~" ~ ..... C ,' ..... a ~-~.~ ~ ~ H CNI_ R u 'n 'i ~: c h F'Lea:,.'e .s'ign and Y'e't'u:n 'the a't't:ached copy I-lAVE A N'[CE DAY'Received B':~' .................................................................. ~~'~ l:;,'o_s'annc~ F:'eek .--- ,,,~ ~ ~------~-- ATO-t '~":'~F / / :, f~____~)~--~ 'T' I:;~ A f...j. ~.,- f,: ,_,° c..,' ,_,° :_'5 9) T) ;[ iT,' T F;.'. ]; B U T ]; 0 N ARCO Alaska, Inc. Prudhoe Bay ~..,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager October 31, 1986 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 7-5 Permit No. 78-13 Dear Mr. Chatterton: Attached is the "Intention" Sundry Notice detailing work proposed on the above mentioned well. Very truly yours, D. F. Scheve DFS/C~/jp Attachment cc: Standard Alaska Production Company Pi(DS 7-5)W1-3 CMH2/15 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 1. Type'of Request: ~- STATE OF ALASKA -- ALASK 3IL AND GAS CONSERVATION COMk 31ON APPLICATION FOR SUNDRY APPROVALS Abandon [ i Suspend ~ Operation Shutdown [ i Re-enter suspended well [ , Alter casing Time extension [: Change approved program ', Plugging { I Stimulate [ ~ Pull tubing ' i Amend order I i Perforate [ ~ Other 2. Name of Operator. 5. Dstum elevation (DF or KB) ARCO AlasKa, Inc. b4' RKB 3. Address 6. Unit or Property name PO BOX 100360, Anchorage, AK 99510 Prudhoe Bay Unit 4. Location of well at surface 7. 1567'S & 92'W of NE ct. Sec. 33, TllN, R14E, UN At top of productive interval 8, 1172'S & 915'W of NE cr. Sec. 34, TllN, R14E, UN At effective depth At total depth ll80'S & 857'W of NE cr. Sec. 34, TllN, R14E, UM Well number 7-.5 , , Permit number 78-13 9. APl number 50-- 029-20293 10. Pool Prudhoe Bay Oil Pool feet 11. Present well condition summary Total depth: measured true vertical 10750 feet Plugs (measured) 9207 feet Effective depth: measured 10693 feet Junk (measured) true vertical 9158 feet Casing Length Size Cemented Structural Measured depth True Vertical depth Conductor 102 ' 20" 229 Surface 2714' 13 3/8" 4800 102'MD 102'TVD 2714'MD 2714'TVD Intermediate Production 10736 ' 9 5/8" 1200 Liner 10736'MD 9194'TVD Perforation depth: measured 10386-10410'; 10426-10473'; 10497-10508' true vertical 8890-8911'; 8926-8966'; 8987-8996' ~bing(size, grade and measured depth) 5½" to 9715'MD Packers and SSSV(type and measured depth) CAMCO Bal-O SSSV @ 2249'MD; Baker SAB Packer @ 9597'MD RECEIVI I) ¥ uV 0 5 1986 Nask~ Oit & Gas Cons. 6ommisslon Anchorage 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 14. If proposal was verbally approved Name of approver Subsequent Work Reported. on ,/.-" Form No./d ,yd~ qDated "~" -,,. ~ Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~ ~,t ~, d f~'--~ _.,_.-- Title Operations Enaineerina Manaaer -- - _ Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test [] Loc_aJi,el¥cJearancel . yC/~. Z C~ by order of App oved b ~ the commission Dat Commissionerr Form 10-403 Rev 12-1-85 [ / brflit in triplicate 3~ . e DS 7-5 Prudhoe /lay Field CTU Cement~ Squeeze !n~ended Procedure APP, No. 69 7818 RU ~1. U and make gauge r~g to PBTD 0 10693,~. Perforate the ~nterva] and C/ean well. 10540-50, BHCS for Precautionary ~ ~zorst~ons ;n~. Oleg UD~t ~o0-J0550' (CTu) and Perform HC1/mud Squeeze Cement e I0540-550' B~pe P. rforst~ono .... o wit~ ~. ..o 10386-410,, 10426-4 Cement In Well5o~_ ". 31 bbJ C/Sss ~ and WOC. "G" 73 Squeeze. Flow acid wash of ' 10497-508, Cement using CTU. and Jet Wellbore Clear to 10693'MD. Contaminate POH & rig CTU down. Perforate the following intervals: 10463-87, BHCS 10-5-78 10497-508, BHCS 10-5-78 10522-50, BHCS 10-5-78 Bring Well in and test. Return Well to Production. RECElVEI) NOV 0 5 1986 Alaska Oil & Gas Cons. Commission Anchorage CMI-I/15 6 5 4 2 ¶. 50D0 PSI ?" W£LLH~I~) CONNECTOR 2. 5DO0 PSI 4 1/16" PIP[ RAMS 3. 5DDO PSI 4 1/6" HYDRAUL~ SLIPS 4. SC)DO PSI 4 1/6" SHEAR RAMS 5. 5C)C)0 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX NOV o 5 1986 Alaska 0i~ & Gas Co~s. commission A~chora~Je COILED TUBING IN]'[ BOP EOU.]PHENT 3 2 1. 5000 PSi 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSi WlRELINE RAMS (VARIABLE SIZE) ,3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSi 4 1/6" FLOW TUBE PACK-OFF ! I RECEIVED NOV 0 5 19BG Alaska 0ii & Gas Cons. Commission Anchorage, I,I I REL I NE BOP EOU I PMENT ARCO Alaska, In( Post Office Box 100360 Anchorage. Alaska 99510 Telephone 907 276 1215 Date' February 22, 1985 Reference: ARCO CH Finals 5-4 Epilog ~ Spinner /5-8 Fluid Density /.7- CNL /GR Epilog ~13-1 CNL Run 1 5" 11-14-84 DA GO GO · 1 5" 1-28-85 1 5" 1-28-85 1 5" 1-21-85 1 5" 11-19-84 4 5" 8-31-84 DA DA .~ Sch ~lease sign and return the attached copy as receipt of data. Received by Pam Lambert ATO 1429C Trans#~X-h_~L/ Chevron D& M Expl. Services Ext. Exploration Exxon Marathon Mobi 1 Mobil E & P Phillips PB Well Files R & D Sohio State of Alaska Texaco ARCO Oil and Gas ~c--~mpany North Alask~ .strict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer August 18, 1981 Reference: ARCO Cased Hole Final D.S.7-5 11/1/80 Spinner Log 5" ~ P~~lease sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #523 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA ARCO Oil ano Gas Company is a Division of AtlanticRichfieldCompany EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARco Oil and Gas~Company North Aia,. District Post Office aox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer January 29, 1981 Reference: ARCO PRESSURE SURVEY ~--~ease make this correction in your files. Thank You, Mary Kellis North Engineering DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG; MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany I E£EI VEo F£9 '- 2 1981 Oil & Gas Coils. Commission Anchorage ARCO Oil and GaLCompany Nor~.h Ala, District Post Office ~ox 350 Anchorage, Alaska 99510 Telephone 907 ?.77 5637 Jerry A. Rochon District Operations Engineer December 19, 1980 Reference: ARCO Pressure Data ~ D S 7-5 " 11-03/04-80 \ - D.S. 7-5 11-01/03-80 D.S. 5-13 10-28/29.~80 Pressure survey Pressure survey Pressure survey ~/~Please sign and return the attached-~:hopy as receipt of data. Mary F. Kellis North Engineering Transmittal #911 DISTRIBUTION NORTH GEOLOGY EXXON R & D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D & M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AtlanlicRichfietdCompany Norlh Alaska Dislrict Post Offi,'"-'qox 360 AnchoraGe. Alaska 99510 Telephone 907 277 5637 ':Jerry A. Rochon District Operations Engineer December ll, 1980 Reference' ARCO Cased Hole Finals D.S. 14-9 11/3/80 D.S. 14-9 11/4/80 D.S. 17-5 1~/3/80 / ..... ~-.S. 7-5 ~ 9/28/80 D.S. 7-4 8/25/80 D.S. 7-12 10/26/80 4-Arm caliper Run l CBL Run I CBL Run 1 CML Run 2 Spinner Spinner 11 11 11 11 se sign and return the attached copy as receipt of data. Mary F. Kellis North Engineering Transmittal #891 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY PHILLIPS SOHIO MARATHON CHEVRON ARCO Oil and Gas Company is a Division of AllanlicRichlieldCompany ARCO Oil and G~G~as Company North / :a District Post Ofl,,..e Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 24, 1980 Reference' ARCO Pressure Data D.S. 6-9 11/10/80 Pressure Survey 9/3/80 Pressure --Gradient:Survey se sign and return the attached copy as receipt of data,. Mary Kellis North Engineering Transmittal #843 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division ol AtlanticRichf~eldCompany ARCO Oil and Ga.s.~Company North Ala District Post Office ~ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer November 24, 1980 Reference: ARCO Magnetic Tapes 1-17 11/2/8o p.s. 7-5.. o/3o/8o Tape #CNL/MSN 8900-9830 Tape #CN/MS 9500-10680 ~lease sign and return the attached copy as receipt of;data. Mary F. Kellis North Engineering Transmittal #845 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON RECEIVED. NOV26]~O ~ Alaska Oil & Gas Cons. Commission Anchorage ARCO O~1 and Gas Company is a Division ol AtlanlicRichl,eldCompany ARCO Oil and Gas Company North AlasF~3istrict Post Office tx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon .District Operations Engineer November 13, 1980 Reference: ARCO Cased Hole Finals 9/4/80 Spinner 5" D.S. 3-6 8/17/80 Lifetime log ~Run 1' 5" D.S. 3-10 9/26/80 Neutron log Run 3 5" D.S. 7-12 10/24/80 Collar log 5" sign and return the attached copy as receipt of data. Mary Ke!lis ~_~or ~a E~lgineering Transmittal #804 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON -'7 - i' ..... ~OV 1 8 1~80 Alas~ 0il & Gas Cons. Commission ~ch0rage ARCO Oil and Gas Company is a Division of AtlanticRichfieldCompany ARCO Oil and Gas Company North Alas!'--"-rJist rict Post Offic~ Jx 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 21, 1980 Reference: ARCO Cased Hole Finals D.S. 6-16 '8/23/80 Collar Log Gyro Run 1 D,S. 6-16 8/23/80 CNL Multi-Spaced Run 1 5" D.S. 7-2 '9/1/80 Collar Log Gyro ./D~:S. 7-5' i~i 9/8/80 Diff Temp {D.S. 7-5 /[ 9/8/80 Fluid Dens. ~~ 9/7/80 Spinner D.S. 14-4 8/12/80 4-Arm Caliper Run 1 2" & 5" (same log) Run 1 Run 1 Run 1 5" Run 1 D.S. 14-4 8/12/80 Spinner Run 1 5" D S 77 3 8/26/80 ^°B/VDT. · P~lease sign and return the attached copy as receipt of data. Mary Kellis North Engineering TRASNMITTAL #730 DISTRIBUTION NORTH GEOLOGY EXXON R&D MOBIL DRILLING GETTY ENG. MANAGER PHILLIPS D&M SOHIO GEOLOGY MARATHON STATE OF ALASKA CHEVRON ARCO Oil and Gas Company is a Division of AllanticRtchlieldCompany _ ARCO Oil and Gas Company North Atas'~ }strict Post Office ,_,ox 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Jerry A. Rochon District Operations Engineer October 7, 1980 Reference: ARCO Pressure Surveys (~[-~7-'7-~ 9/8/80'''~ Pressure Survey D.S. 7-6 9/16/80 Pressure Survey lease sign and return the attached co~y as receipt of data. Mary F. Kellis North Engineerinx TRANSMITTAL #675 DISTRIBUTION NORTH GEOLOGY R&D DRILLING ENG. MANAGER D&M GEOLOGY STATE OF ALASKA EXXON MOBIL GETTY SOHIO MARATHON./?. ARCO Oil and Gas Company ;s a Division of At,anticRichfieldCompany North A!askn District -. Post O~iic x 330 Ancho-- 2" qqS i0 Telephone 907 277 5637 September 25, 1979 F~cto~r} are Pressure reports for the ~ollow:[ng kt~0'" weils- D.S. 7-4 6/27-28/79 24 ttr HP Analysis Cem~co D.S. 7-5 ~ 6/24-26/79 ,, ,, D.S. 7-7 ~" 7/1-2/79 ,, ,, D.S. 7-8 / 6/29-30/79 ,, ,, D.S. 7-9 v/ 7/14-]5/79 ,, ,, D.S. 7-10/ 7/16-17/79 ,: ,, D.S. 9~12~" 5/11/79 Pressure Data Otis D.S. 4-9~' 9/6/79 " Oearhart-(¥:en D.S. 13-4~/ 8/16/79 Pressure Buildup Dresser At]as ? ~~ease sign and return the attached copy as rc~eipt ~/ of data. Very t~dly )'ours, K. J. Sahlstrom North Engineering 363 rqor{h American Producing Division No,th Pos~' O~fic~. .3G0 Anchorage, Alaska 99510 Telephone 907 277 5837 September 24, 1979 Reference- Enclosed are Cased Hole Logs for the following ARCO wells- D.S. 7-6 D.S. 7-8 D.S. 7-9 D.S. 7-10 D.S. 14-1 6/28/79 Spinner Log 5" 6/26/79 " " 5" 8/30/79 " " 5" 6/29/79 " " 5" 7/14/79 " " 5" 7/16/79 " " S" 7/28-29/79 Spinner Log 5" Please sigp~return the attached copy as receipt of data. c~ Very truly yours, K. J. Sahlstrom North Engineering TRANSMITTAL # 359 DISTRIB[H'ION ~ (7 r North G~oloo) Drilling Eng. Manager R&D Geology State of Alaska ]~XXOt[ ~,!obil (;etty Sohio Marathon Phillips Chevron ARCO Oil and Gas.¢-4)mpany Alaska Rog i~:ost Office ..... ~;× 3(.;0 Ancl-,omge, Alaska 99510 ~eep-one .... 277 5637 June 12, 1979 Mr. Hoyle Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject' DS 7-1 Permit No. 77-61 DS 7-2 Permit No. 78-10 DS 7-3 Permit No. 78-11 Permit No. 78-12 Permit No 78-13 -DS 14-1 Permit No 78-50 DS 14-2 Permit No. 78-51 DS 14-3 Permit No. 78-52 Dear Sir' Enclosed please find a Completion Report reporting production information for the above-mentioned wells. Very truly yours, // /! District Drilling Engineer PAV'cs Attachments j' , Oil and Gas Company is a Oivi,.io. of Atl~nlicP,~chlieldComp~rff Form P- 7 SUBMIT IN DU'~ L.CATE* STATE OF ALASKA (Seeot~r m- st ructions on OIL AND GAS CONSERVATION COMMITTEE ~,.,~..~,~ ~m,,~ . _ i WELk ~OMpLETIO~ OR RECOMPCETIO~ REPORI A~D kOG* 5. API N~CAL CODE 50-029-~0293 6. LEASE DESIGNATION AND SERIAL NO. ADL 28309 la. TYPE OF WELL': OIL ~AS~ w ELL Iv ELL DR ¥ Other b. TYPE OF COMPLETION: NEw []]ovzaW°nK [] exo¢¢e' n-~nac~enes ~ ~,,¢.nzsva.~ Other Perforated WELL ,, ,, 2. NAME OF OPERATOR Atlantic Richfield Company · 3. ADDRESS OF ~PERATOR P.O. Box 360 Anchorage, Alaska 99510 LOCATION OF IVELL (Report location clearly and in accordance with any State requirements)* At surface 1567'S & 92'W of NE cr Sec. 33, TI1N, R14E, UM At top prod. interval reported below 1172'S & 915'W of NE cr Sec. 34, TllN, R14E, UM At total depth l180'S & 857'W of NE cr Sec 34, TllN, R14E, UM 7. IF INDiA~T, AJ~OTTEE OR TRIBE NAAVIE 8. UNIT,FAIL1VI OR LEASE NAME Prudhoe BaS Unit 9. WEa_,L NO. DS 7-5 (41-34-11-14) 10. FLEI_,D AND POOL, OR WILDCAT Prudhoe Ba Fie]d- P~urlhne fli{ Pnnl 11. SEC., T., R., M., (BOTTOM HC>LAil OEMECTIVE) Sec. 34, TllN, R14E, UM 12. PERA4IT NO. 78-1 3 9/19/78 10/5/78 llO/13/78(perf'd 12/22~78) 64' RKB 18. TOTAL DEPTH, MD a TVD~9. PLUG, B~CK MD & TVD[~. IF 1VL'ULTI~PLE CONLPL., { 21. lO,750'MD 9207 ' TVql O, 693 ' MD 9158ITVD I ~°~in~g~ ' ROTA~YI~OOLS 22. PRODUCING INTERVAL(S), OF THIS C(~MPLETIO/N'--TOP, BOTTOM, NAME (MD AND Top Sadlerochit: 10,000'MD 8562'TVD Base Sadlerochit 10,632'MD 9105'TVD 24. TYPE ELECTRIC AND OTHER LOGS.RUN I RT, GR, ETC)*I17. EI.~V. CASINGHEAD INTERVALS DRILLED BY CABI,E T001..[4 23. WAS DIRECTIONAL S UI~VEY MADE i ,, Yes FDC/CNL/CAL/GR, ,DIL/_SP,,; BHCS/CAL/GR, CBL, CCL _ 25. : CASENG RECORD (Report all strings set in well) 20" [94# Welded /H-40 I 10'2' 30" 1229 sx Arcticset emt _ 13-3./8" /72# BUtt i IN-80 ! 271~' 17-1/2" 14800 sx Arcticset II cmt i 9-5/8" [47# Butt I N-aOal o.73 ' l~-l/a" I12o0 .~x Cla_~ a cmt ! _ I I RS&SOCl-95 1 26. LINER I:LECOD i 27. TUBING RECO'PJZ) 28. PERFORATIONS OPF/N TO pRODu (interval, size and number) 29. ACID, Si!el7, F.%A~CTURE, CF..%iE:NT SQUF-EZ~, ETC. ~5 ] 0,4 97-- ] 0,508' D~t ~'~V~ ~M~) ] I ' ~ ] 0,426-] 0,473' :~ ~10,386-10,410' w/4 shOts/ft. [ }~ ~30. ' PRODU~ION ' f''"' ] :~ ' ' '" DATE(~/V9.__.>F~ P~O~ON[[ ~ODUCTION~] 0W~ n ~ME1HO~ (Flowh~g,_ gas lif~, pump~g--size and type of pump) ia.' [~[%ELLs:z~'~n)~'FATUSpc0duc ~ ng(Pr°d~ing or DAT~ ~.~T~ ...... [HOURS TE$~ ' [~{OXE~iZE [PROD'N FOR OI~BEL. "~.&~MCF. W/JI'E~BBL. {GAS-OIL R.%TIO [ .... ° FLOW, TUBING lcls~a P~SSURE ICAL~~ OI~BBL. GA~. WA~BBL. [OIL GRAVITy-~I (CO~.) 942 I -- 'l ' ; [ 7001 I 4793 I 0 I 27 - i 3f. D'lSPOSlTION O~ GaS (~old, ~ed ~or ]NeI, ~t~d, ~tc.) Rei nj.~cted I 32. LIST 0F ATTACHMENTS I 33.'I hereb} certify, that the"fore~goindand attached information is complete and correct as determined from all-available records SIGNED ~~~~/~42 T i?LE Di strict Dri 11 ing Engineer DATE ___6/12/ ill : *(See Instructions and Spaces [or AdditiOnal Data on Reverse Side) INSTRUCTIONS General: Th,s form is des,gned for subm,tttng a complete aad correct well cor'qplet,on report and log on all types of lanJs and leases in Alaska. item: 16: Indicate whict~ elevation is usec~ as reference (where not otherwise showr~) for depth measure- merits given ~n ether spaces on this forr~ and in amy attazk~r~emts Items 20, and 22:: If this well is completed for separate f)rc'duction from more than one ~nterval zone (multiple completion), so state ,n ~tem 20. ,and in ite,~; 22 show thc prcJuc,r'~9 interval, or ,ntervals, top(s), bottom(s) and name (s) (if any) for only the interval] ret,orted ir~ iter~ 30. Submit a separate report (page) on this form, ade<tuately identiflc<J, for each add~t,or~al ~r~te~val to be seperately prod~ce:t, show- ing the ackJitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). '' ' 34. SUMMAi{"~ (IF' P()iIMATI()N 'I'E.~TS IN('I,UI)IN(; IN'I'~:liVAL TF.S'rF:D, I'HE~SUI1E DATA ~'RECOVERIF.~ ()V ()II, GAS 35 (; ~G IC MARK~q WAT~[ AND MUD NAME None ~ ~,~.s o~ ~u~ V~v. ~, .... Top Sadl er0chit 1 0,0001 8562' Base Sadl erochit 10,632' 9105' i i ii i i~' lUll/i ~ i i I i i ' i i" I" ~ CoI[E DATA. A'I'I'A('ll AND IIN'I'~('I'EI~ MIIOWS O~' Oil.. GAS O1~ WAI'~I None ~ ........ DS 7-5 PERFORATING HISTORY API 50-029-20293, ADL 28309, Permit No. 78-13 Began perf operations @ 1000 hrs. 12-19-78. Tstd tree, csg & wireline BOP's. Pulled dummy valve. Perf'd intervals 10,497- 10,508', 10,426-10,473' & 10,386-10,410' w/4 shots/ft~ All perf'd depths references to BHCS dated 10-5-78. Ran Amerada pres bombs. Flowed well. Ran & set ball valve. Tstd balance & control lines to 5000 psi, OK. Tstd ball valve, OK. Installed & tstd tree cap to 5000 psi, OK. Released well to Production Dept. @ 0600 hrs. 12-22-78. ,'-!orlh ::t.,,'~eric~.n Produ~:','~O Di¥i3ion bJor~.h Alaska ~?' 'rict Post Ot~ice k~ ..60 Ancl~ora~e, Alaska ggSqO Telephone 907 277 5637 February 16, 1979 Reference: Enclosed are the following Pressure Surveys: DS'1-18 DS 4-12 DS 4-13 DS 6-3 DS 6-4 DS 6-5 DS 6-7 DS 6-8 DS 7-2 DS 7-4 DS 7-5 DS-9Z20 Static-Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Transient Survey 12/26/78 12/1/78 12/3/78 11/23/78 11/23/78 12/6/78 12/10/78 12/11/78 12/16/78 12/19/78 12/21/78 ]2/4/78 Please sign and return the copY as receipt of data. Sincerely, V.G. Reimers North Engineering TRANS~'IITTAL # 73 DISTRIBUTION North Geology Drilling Eng. Manager R & D Geology State of Alaska D &M 'Exxon Sohio Mobil Marathon Phillips Chevron Getty AtlanticRi<:hfieidq; :~mpany North American Producing Division North Alas, -~-~ District Post Olfic(. × 3~0 Anchorage, Alaska 99510 Telephone 907 27"1 563T December 27, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS 7-1 Permit No. 77-61 DS 7-2 Permit No. 78-10 DS 7-3 Permit No. 78-11 DS 7-4_ Permit No. 78-12 (~Permit No 78-13 I.,[I - Dear Si r: Enclosed please find a Completion Report along with the Perforating History for the above-mentioned wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/cs Attachments Form P---7 SUBMIT IN DUo~. CATE* STATE OF ALASKA : (Seeothertn- st ructions on reverse side OIL AND GAS CONSERVATION COMMITTEE i WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* 5. API NUIVLF_,RICAL CODE 50-029-20293 6. LEASE DESIGNATION AND SERIAL NO. ADL 28309 "7 · IF INDIAN, A-LLOTTEE OR TRIBE NA/VLE Other '"la, TYPE OF WELL: ou, [] GAS ~-~ WELL WELL DRY b. TYPE OF COMPLETION: Perforated WELL OVER EN BACK nESVg. Other 2. NAME OF OPERATOR At]antic R]chf]eld Company 3, ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 J~. LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 1567'S a 92'W of NE cr Sec. 33, TllN, R14E, UM At top prod· interval reported below 1172'S & 915'W of NE cr Sec. 34, TllN, R14E, UM At total depth ll80'S & 857'W of NE cc Sec. 34, TllN, R14E, UM 8. UNIT,FAIt/VI OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 7-5 10. FIELD AND POOL, OR WILDCAT D~,, ,~ h,-,~, Dnnl O~E~IVE) Sec. 34, TllN, R14E, UM 12. PE1LIVIIT NO. 78-1 3 13. DA-TE SPUDDED [14. DAT~ T;D. RF, A,GHED [15. DATE COMP SUSP OR ABAN'D. t16. ELEVATIONS (DF, RKB, RT, 9/19/78 10/5/78 : lO/13/78(perf'd 12/2 /78) 64'RKB 18. TOTAL DEPTH, 1VLD & TVD[19. PLUG, BA~CK MD & TVDr. L~ 1V[ULT1PLE CO1V"~L.,21. lO,750'MD 9207'TVDIlO,a93'MD 9158'TVDi a°wS~qh~J~e 22. PRODUCING INTEttVAL(S), OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND TVD)' Top Sadlerochit lO,O00'Ma 8562'TVD Base Sadlerochit 10,632'MD 9105'TVD ! GR, ETC)* ]17. ELEV. CASINGHEAD INTERVALS DRILLED BY CABI,E T00 I..8 23. WAS DIRECTIONAL SURVEY MADE Yes i 24. TYPE ELECTRIC AND OTHER LOGS RUN FDC/CNL/CAL/GR, DIL/SP, BHCS/CAL/GR, CBL, CCL 25. CASING RECORD (Report all strings set in well) CA, SLNG SIZE [ w,E.,,IGHT, LB/FT. ~ GP,~DE . t DEPTH SET (MD) [ HOLE SIZE] C -~\iLN TING RECOI-kD i AMOUNT PULLED 20' 94# Welded[ H-40 [ lO?! 30" 229 sx Arctic Set cmt --13-3/8" [72# Butt [ N-80 [ 27141 ] 17-1/2"]4800 sx Arctic Set II cmI _ 9-5/8" 47# Butt J N-80&i 10.736 12-1/4" 12130 sx £1a~ a cmt _ , IRS&SOOt. 95 I ' I !=. 26. LINER I:LECOl:SD TUBING RECOP~D 28. PERFORATIONS OPW--2N TO PR~.U~plg ~ , (inter~val, ~iz~ and number) ~ ~ i!--~ '~-~ i .... ~ ~ ~ ..... ~.~' 10,497-10,508' 10,426-10,473' ~::~ ~",, 10,386-10,410' w/4 -~Shots/ft. ~ODucTION ~. : 29. ACID, SiiOT, Fi~.A. CIURE, CEa~iVNT SQUE'V'7.*, ETC. DI~'-~T~/i INTERVA~L (MD) AMOUNI' £~ND I'i!ND O.r'' MA'IE?~IAL USED N/A DATE Or T]~ST, [HOURS TEST~ '[CIItOXE SiZE [PROD'N FOR W, G ]CAShNG PRESSURE [CALCULATEI) OIL--BBL. 21'. D'~SPOS~T~ON O~ ~AS (~old, u,ed )'or $uel, vented, etc.) DATE FIRST PI%©DUCTION [ PI~ODUCTION MEi:HOD (Flowh~g, gas 1i£~, pumping--size and type of pump) [V¢ELL STATUS (Producing or N/A [ ] OI~BBL. G.~CF. WYJI'E~BBL. [ GAS-OiL g.tTIO I I i GA~C~. W~BBL. ] OIL GRAVITY-~I (CO~.) TES'r WITNESSED BY 32. LIST 0F ATTACHMENTS Perforating ~]story 33. I hereby certify t~at the .foregoing and attached information Is complete and correct as determined from all-available records SIGNrD f~ ~7~ TITLE DistriCt Drill ing Engineer *(See Instructions and S~ces [or AdditiOnal Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report end log on all types of lanJs and leases in Alaska. Item: 16: Indicate which eJevation is used as reference (where not otherwise show~) for depth measure- ments given in ather spaces on this form ancJ in any att,~chmer'~Is Items 20, and 22:: If this well is completed for separate production fror'n, more than one ~nterval zone (multiple completior~), so state .n ~ten~ 20, and in ~te,~ ?2 show thc p~cJ~)c~;~.,,l interval, or ,,~te~v~ls, top(s), bottom(s) and name (s) (if any) for only the interv,~l ret)orted ir~ iter~ 30 SL~hr'nit a sep~'~rate report (page) on this form, adequately identified, for each additior~l ir~te, val to be seperately producert, show- ing the acktitional data pertinent to such interval. Item26: "Sacks Cernent": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cemer~ting and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each inierval to be separately produced. (See instruction for items 20 and 22 above). 34. SUMMAItY ()F b'(){~.M'ATf()N '1'I:'.._"~'1','~ INt'I,UI)IN¢; INTI-:IIVAL, 'I'F~T'EI) I'HE;~SUI~E DATA A~ REC'()VF~IHF~N (~F ()II, (;A~ 35 G~GIC MARK~ WAT~I AND MUD HAME MEAs. O~t ~U~ V~T. ~! i i , imm, , , i i i, AND I}E~E~'~I~I) NIIO~'S-0~ Olb. G~S 011 WA~I. ........ · qttanticF;icnlieid Compa~'i~, North Alaska District Post Oificc'~ 'x 350 Anchorage, ,.~iaska 99510 Telephone 907 277 5637 January 2, 1979 Reference: Enclosed are the folloWing S!ngleshot Surveys: ~ 12/20/78 v'D-S 7-6 12/20,~78 · .,-"'DS 7-7 12/20/78 ,~/'DS 13-1 11/27/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL # 0 01 DISTRIBUTION North Geology- Drilling Eng. Manager...,' R&D Geo lo gy State~. o f ~ 'Alaska · D&M · Exxon 'Sohio' Mobil. Mara Ebon Pt~illips Chevron Getty Nor'th/'-,!aska Post Office,_. ~ Anchorage, , ~ ¢o ..... 907 277 5S37 November 16, 1978 Reference: Enclosed are the following logs: D.S. #5-9 Fluid Density 9/20/78 D.S. #4-2 Diff. Temp. 10/5/78 ~' CNL 10/10/78 D.S. #4-2 ' Flow Meter 10/5/78 D.S. ¢7-2 CBL/VDL/GR' 10/2/78 D.S. ¢4-2 Fluid Density 10/5/78 D.S. #5-1 Neutron 10/12/78 D.S. #7-5 CBL/VDL/GR 10/9/78 D.S. #9-19 Fluid Density 10/24/78 D.S. #5-1 Flow Meter 10/12/78 D.S. #7-4 CBL/VDL/GR 9/15/78 D.S. #9-17 Dual Spaced Neutron 10/26/78 D.S. #7-4 Noise Log 9/30/78 D.S. #9-9 Neutron 10/28/78 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #566 November 16, 1978 Reference: Enclosed are the following open hole logs: D.S. #6-7 8/21/78 :.10/5/78 CNFD 5" DIL BHCS 5" FDC 5" · ,. D.S. #7-5 DIL DIL BHCS BHCS FDC CNFD Please sign and return Sincerely, V.G. Reimers North Engineering 1! 2" 2'~ 5~ 5~ 5~ the copy as receipt of data.~ TRANSMITTAL #569 AtlanticRict~fieldCompany North Arnefi~-~n Producing Division North Alasr Astrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 13, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' D~-5~ermit No. 78-13 DS'~-2, Permit No. 78-51 Dear Sir: Enclosed please find a Completion Report along with the Drilling History and Gyroscopic Survey for the above-mentioned wells. Very truly yours, ...... ~ ,--~/ t~. P. A. V~nDusen D~s[r~ct Drilling [ng~neer PAV.jh Enclosures Form 'SUBMIT IN DU STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE i i i ',ATE* (Sec, other In- st ructions on reverse side; WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: oH, .._~. ~AS [~] [] WELL WELL DRY Other b. TYPE OF COMPLETION: VVELL OVER EN BACK nssvR. Other NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 ~. LOCaTION OF WELL- (Report location clearly and in accordance with any State requirements)* 5. API NUM. EI~CAL CODE 50-029.-20293 6. LEASE DESIGNATION A_ND SERIAL NO. ADL 28309 7. IF INDIA-N, ALLO'FTEE OR TRIBE NA1V/.E 8. UNIT,FAiIAVI OR LEASE NAME Prudhoe Bay Unit 9. WELL NO,: ......... _ I ~ru~noe-l~v I PruOhoe Ul~ voo~ At surface Ill. SEC., T., R., M., (BOTTOM HOLE 1567'S & 92'W of NE cr Sec. 33, TllN, R14E, UM It top prod. interval reported below 1172'S & 915'W of NE cr Sec 34, T11N, R14E, UM At,otal depth ' Sec. 34, TllN, R14E, UM ~1180'S & 857'W of NE cr Sec. 34, TllN, R14E, UM 12.~~o. 78-13 13. DATE SPUDDED ~14. DATE T.D RE~CHED~[i5. I>.~E CO,IVI. P SUSP CkR ABAN'D. [16. I~EVATIO2q'S (DF I{KB RT, GR, ETC)*]17. ELEV. CASINGHEAD 9/19/78 10/5/78 10/13/78 ~ RKB 'i'~./TOTAL DEPTH, 1ViD & TVD~lg. PLUG, ]B~CK MD'& TVD~]0, IF 1VUJLT~PLE COM~L.. ~2I.~ INTERVAI,S '~R[LLED BY_ CABI,E TOOLS [ ! I'{ow 1VI. ANY* ] ROTARY TOOLS ./lO,750'MD 9207'TVD[ 10,693'MD 9158'TVD~ Single [ - All 22..Pl~ODUCING INTE}IVAL(S), OF THIS COMPLETIO2q~TOP, BOTTOM, NAME (NIT) AND 'IV-D)* 123. 1,VAS DIRECTIONAL I S [J [~.VE¥ MADE Top Sadlerochit IO.,O00'MD 8562'TVD ! Yes Base Sadlerochit 10,632'MD 9105'TVD 24. TYPE ELECTRIC AND OTHEI{ LOGS RUN FDC/CNL/CAL/GR, D, IL/S,P, BHCS/CAL/GR, CBL, CCL CASING S~ZE 2'0" _13-3/8" . 9-5/8" 26. SIZ~ CASIZN'G RECORD (Report all strings set in well) 94# Welded[ H-401 102" ' ' 30" 1229 sx Arctic Set cmt. j 72# Buti:! N-80I 2714" 17-1/2"14800 sx Arctic Set II cm~. 47# Butt /N-80&! 10,736" 12-1/4"| 1200 sx Class G cmt. ] ' : ' 1 ! o L, IN~,I'{ I::I,ECOI:I.D ~ .?, TUBING R~COI'~I) 5-1/2" 9592' o.~ .o pao~uc'no~'" (~t~l, size ~d number) . , D~i INT~V.~ (MD)[ AMOUN ~ /~D KIND OF MA'I'E2~AL US~ [ [[ ],-,--,--,. --. ~,,~jl~t,*~' uuo, i i~ m~l [~ldl[, ,. N/A m i 30. PRODUCTION DATE FIRST PI%ODUCTIOAI I PI~ODUCTION ME'iI-[O'D (Flowhog, gas lift, pumping--size and type of pump) [\'FELL STATUS (Producing or N/At I .... DATE OF TEST. 1~OUlqs TESTED ' ICZISOZ<E SiZE IPROD'N FO.l{ OIL--BBL. GAS--1VLCF. W£JI'EI{-~BBL. [ GAS-OIL I -° i §1. D'mPOSXTIO~ Or S*S (~Ol), u~e4 )or yueZ, vented, etc.) 32. LIST OF AT~kCHMENTS Drilling History, Gyroscopic Survey WATER--BBL. [OIL GRAVITY-APl I TEST WITNESSED 33. I hereby certify~_~?~,thatthe/~ ,.nthe oregoing and attached information is complete and correct as determined from all-ai;atlable records SIGNED~-~//~/ ~'~ TITLE District Drilling Engineer i *(See Instructions and Spaces [or AdditiOnal Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete ar'~d correct well completion report end log on all types of lanJs and teases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise showr~) for depth measure- ments given in cther spaces on this for~ and ir'~ ar~y -. Items 20, and 22:: If this well is completed for separate: ~)rc:d'~c:tior~ frort~, more than one i~terval zone (multiple completion), so state ~n item 20, ,3nd in ite,'~ ?2 show the prcJuc~;'~.'.l interval, or ~nter'v~'~ls, top(s), bottom(s) and name (s) (if any) for only the interv,~I reported ir~ item 30. Submit a separate report (page) on this forml adequately identified, for each ac:lditior~c~l ir~te~val to be seperately prodt~cert, show- ing the ackJitional data pertinent to such interval. Ite, m26: "Sacks Cer'nent": Attached supplemental records for this well shoulcJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each ir~terval to be separately produced. (See instruction for items 20 and 22 above). ,, , ......... 34. SUMMARY ()p 'pO{HX,~AT'i(.)N 'FE:S'I'.'-; 1Ni'I.I. II)IN¢; INTF. IiV^L TFlX'FEI) I']IE~SURE DATA ~ ~ECOV~iIHY~$ ()F OII. GAS. 35 G~G IC MARK~ WAT~ AND MUD , NAME , ~ , 36. CORE DATA. A'I'I'ACII BRIEF. D~RiPI~ONS OF LITIIOLOGY, POCOSIn. FIIA~HF~; APP~N~ DI~ DS 7-5 Drilling Hi story API 50-029-20293, ADL 28309, Permit No. 78-13 Spudded well @ 0100 hrs 9/19/78. Drld 17-1/2" hole to 2740'. Ran 13-3/8" csg to 2714'. Cmtd w/4800 sx Arctic Set II cmt. Did 50 sx top job. Tstd pkoff & csg. Drld FC & cmt. Drld 10' new form & tstd. Drld 12-1/4" hole to 10,750'. Ran FDC/CNL/CAL/GR, DIL/SP, BHCS/CAL/GR. Ran 9-5/8" csg set @ 10,736'. Cmtd w/1200 sx Class G cmt. Did second stage cmt job thru lower FO. Did Arctic Pack job thru upper FO. Displ mud w/wtr & wtr w/CaCl2. Ran CBL, GR/CNL/CCL. Ran junk bskt & gauge ring. Ran 5-1/2" compl assy w/shear sub set @ 9715', pkr set @ 9592'. Displ CaC12 w/diesel. Installed & tstd Xmas tree. Pulled dummy valve. Ran CCL/dummy gun log. Reran dummy valve. Press tbg for long term tbg tst. Released rig @ 0600 hrs 10/13/78. :OY~PLETI01 REPORT OCT. 24, 1978 '-~TLANT!C RICHFIELD COi',~PAi',;Y DS 7-5 JOB 073 ~ADIUS OF CURVATURE METHOD OF CO?iPL.~TATIONS ~ K.B. ELEV, 6~ FEET ~YROSCOPIC SURVEY ~' DE'CLINATIOh 31 DEGREES ECAST 20MPLtTED FOR SDC BY F.?,i,LINDSEY AND ASSOCIATES ~-,.ECORD OF oUR, VbY ALL A - ' C,,LCUL,,,T~Od5 PERFORMED BY [ B hl ELECTRONIC COiqPUTER TRUE ..lEAS, DRIFT VERTICAL SUB Di'qIFT TOTAL COORDIhiATES C L 0 S )EPTH ANGLE DEPTH SEA DIREE DISTANCE D !','1 DEG, 0 0 0 0.00 -64,,00 N 1,OOE 0.00 S 0,00 W 25,,)o o o 2600.00 Z 6.00 i.UoE 400 . S O.O0 2.700 1 0 2699,99 2635,99 N 1.OOE u~7 N O,O1 E 2{~00 4 45 2799,85 2735,85 N60,OOE 5~0 N 2,~ E 2900 10 0 2898,98 2834,98 N63,00E ll 3000 15 0 2996,58 2932,58 N66,00E 20,~:~;..f.; 3200 18 0 3187,95 3123,95 N66,OOE 3300 19 30 3282,64 3218,64 N66,OOE 57,12 N 115,64 E 34n ~ 0 76 3312,76 N65.OOE 71.13 ;" ,,0 2'J 3378, .. 146,3g E 3500 22 15 3470,03 3406,03 N66,OOE d6.08 N 179,18 E 360.0 23 0 3562,33 3498,33 N68,00E 101,11 N 214,59 E 370~ 25 30 2653,50 3589,50 F~71,0OE 115.49 ~ 253.06 E 3800 28 O 3742,79 3678,79 r~71,OOE 130,14 ~ 295,61 E 3900 29 15 3830,57 3766,57 N74.00E 144.55 N 341,30 E 40DC 30 0 3917,50 3853,50 ix~74,O(JE 15~,17 ."~ 3~.51 4100 32 0 4003,21 3939,21 ;'.~77.C. 0E 171,07 N 438,67 E 4200 32 3G 40~7,7~ 4023,7b NT~,5,'SE 1~2,39 4300 35 0 4170.92 4106,92 N60.OOE 192,75 N 5a5,39 E 4400 38 15 ~.251,17 4187.17 ."NSO.OOE 203.11 ~ 604.13 E 4.5C)0 40 C. ~528,74 4264,74 NSI.O~E 213.52 N 656.36 E 4600 41 1~. 4404,64 ~''=3~C,, 64 t..82.00E 223.1~ "~. 7~0~ .76 E 4700 41 15 4~79.82 ~15,82 Nd2.COE 232.32 74 79~.05 E 4800 41 0 4555,15 ~91.15 r.;83,0OE 2~0.91 N 861.26 E ~900 42 0 4630,04 ~566,04 ~'~87. OOE ORES ANG L E D M 195,79 N 64 20 24 E 237,22 ,N 64 46 16 E 278,17 N 65 28 6 E 322,99 N 66 14 17 E 370,64 N 07 2 44 E 419,76 N 67 51 45 E 470,8:+ N 68 41 4-4- E 523,61 i".~ 69 36 52 E 57~.45 N 70 32 7 E 637,36 N 71 2~ ~ E 699.74 K 72 13 58 E 764,07 i'473 1 8 E 829,26 i~ 73 43 49 E 894.32 ¢~ 74 22 21 E 959,21 ,k 75 6 8 E DOG LEG SEVERITY DEG/iOOFT 0 · 0 00 C · 000 t .000 3.772 5.251 5 2.250 0, '750 1,500 0,51~- 2,255 C.~lO 2,561 2 · 5C0 1.441 0,750 2,170 0,661 2.54U 3.250 1,79~ 1.323 0.000 0,/498 2.051 DISTAh~CE O,O0 0 · 0 () 0.08 2,86 14,62 34,87 il,12 89,73 120.10 151.94 185.d9 222./-+5 262. 352.40 400.91 451,68 504.60 559.87 619.28 082.18 7~+7.16 812.99 ~'15, 70 944,94 ~,RCO DS 7-5 GYR()$COPIC SURVEY OCT 24., 1978 ALL RECORD OF SURVEY CALCULATIONS PERFORHFjD BY ! B M EL~zCT~.r)t,~IC CO;'fiPUTER tEAS, DRIFT )EPTH ANGLE D M 5000 41 0 5100 42 0 5200 42 0 5300 42 15 5400 44 C 5500 45 0 5600 45 45 5700 45 15 5800 46 0 5900 z+6 0 6000 46 0 6100 45 0 6200 45 0 6300 45 0 64D~ 44 15 6500 44 15 6600 44 0 6700 44 6300 41 0 6900 42 30 7003 40 30 7100 42 0 7200 42 0 7300 40 0 7400 39 0 7500 39 0 76.00 3S 15 7'700 38 0 7800 38 0 TRUE VERTICAL SUB DRIFT DEPTH SEA DIREC DEG, 4704,94 4640,94 N87, 4779,83 4715,83 N86, 4854,15 4790,15 N87, 4928,32 4864,32 N87, 5001,30 4937,30 N88, 5072,62 5008,62 N88, 5142.87 5078.87 NBB, 5212.96 5148.96 N88. 5282,89 5218,89 NO8. 5352,36 5288,36 N89. 5421,83 5357,83 N89, 5491,92 5427.92 N88, 5562.63 5498.63 N89. 5633.34 5569,34 N88. 5704,51 5540,51 5776,14 57i2,14 h~38, 5847,92 5783,92 5~b7. 5919.85 5855,85 ii85. 5993,57 5929,57 6068.18 6004.18 5143.07 6079.07 N83, 5218,25 6154,25 NS2, 5292,57 6228,57 N82, 6368,03 6304,03 6445.19 6381.19 ~81. 6522,91 6458.91 6~01.03 6537.03 5!81. 6679,70 6615.70 !~81, 6758.50 6694.50 N81. OOE OOE 0OE OOE OOE O~E 00E 5OE 5OE OOE 00E OOE OOE 00E O~,E OOE O~E OOE 00E ~_ ,0~ OOE 00E COE OOE OOE OOE TOTAL COORDINATES CLOSURES DI STANCE ANGLE D M 250,15 254,19 258,28 26i.79 264,77 267 2 269 0 272 9 274 7 27~ 276, 278, 280,2 282,14 284.59 287,02 290,06 29~,91 300,79 308.33 316.98 325.5~ 334.90 344,59 354.54 364,93 375.23 3~4.59 394.52 993,42 E 1024,43 N 75 51 58 E 1059,56 E 1089,63 N 76 30 33 E 1126,35 E 1155,58 N 77 5 5 E 1193.33 g 1221,71N 77 37 39 E 1261,62 E 1289,11 N 78 8 51 E 1331,67 E 1358.21N 78 39 12 E 1~02,80 E 1428.49 N 79 7 1 E 1~74.08 E 1499.00 N 79 32 16 E 1545.52 E 1569,~9 N 79 55 59 E 16Z~0,76 N 80 19 44 E 6 E 1711.86 N 80 42 8 E 7 17 2.55 81 o E 1902,04 E 1922,85 N 81 33 *4 E 1972.24 E 1992.67 N 81 47 20 E 2041,98 E 2062,06 N 81 59 55 E 2111.54 E 2131.37 N 82 10 41E 2180,83 E 2200.68 N 62 17 55 E 2243,12 E 226~.16 N 82 22 44 E 2314,27 E 2~34.72 N 82 24 39 E 2379,97 E 2400,98 N 82 24 48 E 2445.33 E 2466,91 Iq 82 24 57 E 25'11,59 E 2533,82 N 82 24 17 E 2576,48 E 2599,42 N 82 22 55 E 282~,30 E 2663,01N 82 20 56 E 2701.57 E 2725,91 N 82 18 22 E 276Z,93 [ 2788,30 N 82 15 57 E 2823,91 E 2850,02 N 82 14 18 E 2884,72 f 2911,57 Iq 82 12 44 E DOG LEG SEVERITY DEG/iOOFT 1,000 1.096 0,669 0,250 1,815 1.000 0,750 0.500 0,793 0.719 0,360 1,118 0.707 0.707 0.750 O.O00 0,543 3.000 2.031 2.044 1.565 0,000 2,042 1.000 0,629 0.250 0.000 SEC T I ON DISTANCE 1011,17 1077, ) 1144,~0 1211,34 1279.63 1349,63 1420,71 1491,95 1563,32 1635,08 i706,83 1778.03 1548.61 1919.20 1989.35 2059'04 2128.60 2195.'' 2265.~.~' 2~32.16 2398.35 24~4,21 2531.03 2596.50 2659,95 2722,67 27~4.89 2846,47 2907,88 ARCO DS '7-5 GYROSCOPIC SURVEY OCT 24', 1978 RECORD OF ,SURVEY ALL CALCULATIONS PERFO~ '" r~I','~ED BY I B M ELECTRONIC COF4PUTER TRUE F',!EAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D SUB DRIFT SEA DIREC DEG. 7900 37 15 6837,70 6773'70 NS1,50E 8000 36 O 6917,96 6853.96 N8B,OOE 8100 36 15 6998,73 6934,73 N81.50E 8200 36 15 7079,37 7015,37 N83,00E 8300 37 0 7159,63 7095.63 N81.OOE 8400 26 45 7244,44 7180.44 NB3.00E 6500 ~5 0 7~0,19 7266.19 8600 3~ 0 7412,11 7248,11 8700 34 0 7494,52 7430,52 N88.00~ 8800 34 0 7977,42 7~13.42 N87,00E 8900 34 15 7660,20 7596,20 N86,00E 9000 34 15 7742.86 7678,86 N86.50E 9100 36 0 7824,65 7760.65 N87,005 9200 36 0 7905,55 7841,55 N88,50E 9~00 35 30 7986.7! 7922,71 N89,50E 9400 35 15 8068,25 5004,25 588.005 9500 36 0 8149,53 8085.53 S85.00E 9600 35 15 8230.81 8166,81 S83.00E 9700 35 0 8312.60 8248.60 S82.COE 9800 36 45 8~9q.64 8330.64 SSI.OOE 9900 33 0 8477,67 8413.67 681,50E lOOOO 33 0 8561,53 8497,53 S81,50~ 10100 32 0 8645,87 6581,87 582,505 10200 31 0 87B1.13 8667,13 S85.00E 10300 30 0 8817,30 8753,30 S85,50E 10400 30 © 8903,90 8'839,90 S85,50E 10500 ~0 0 8990,50 8925,50 582,00E 10750 30 0 9207,01 9143,C1 S82,0GE TOTAL COORDINATES CLOSURES DISTANCE ANGLE O M $ 403,81 N 2945,06 E 411,85 N 3004,17 E 419,80 iN 3062,58 E 427,78 N ~121,17 E 436.08 N 3180,24 E z~43.42 N 3232,46 E ~49 2 N 3283,41 E 45~ N 3~40,50 E 2972,61 N 82 11 33 E 3032.27 N 82 11 37 E 3091,22 N 82 11 41 E 3150,35 N 82 11 44 E 3210,00 N 82 11 31E 3262,7~ N 82 11 20 E 3314.0'0 N 82 12 33 E ~371,31 N 82 14 5~ E 458 8 N 3397,03 cd 3427,79 N 82 19 6 E 4aO 3483,48 N 82 24 5 E 467, 3595,60 FI 82 31 32 E 470,981 .N N 82 35 31 E 473,29 N 3681,22 E 474,31N 3739,63 E 473,55 N 3797,52 E 470.00 N 3855,65 E 463,91N 3913.58 E 456.40 N 3970,62 447,95 N 4027,17 439.47 N 4082,26 E 431.42 N 4136.12 E 423,94 N 4189.~3 E 418,25 N 4241.26 E 414.05 g~ 42~1.84 410,13 N 4341,69 E 404.69 N 4391.38 E 387,29 N 4515,16 E 3711,52 N 82 40 25 E 3769.59 N 82 46 17 E 3826.93 N 82 53 30 E 38~4.19 N 83 2 59 E 3940,98 N 83 14 22 E 3996.76 N 83 26 34 E '4052,01N 83 39 10 E 4105,84 N 83 51 19 E 4158.56 N 84 2 42 E 4210,72 N 84 13 17 ~ 4261,84 N 8~ 22 4 E 4~11,77 N 84 29 21 ~ 4361.01N 84 36 13 E 4409.99 N 84 44 5 E ~531.74 N 85 5 50 E DOG LEG SEVERITY DEG/iOOFT 0.772 1.353 0,581 0,887 1.043 10,258 8,257 0.574 1.371 0,559 0.404 0,281 1,759 0,882 0,603 0.869 1.279 1.003 0.~13 0,4i0 1,756 O.OOO 1,039 1.200 1,OOa O,oOO 1.750 SECTION DISTANCE 2968.79 3028, } ~087,46 3146.31 3205.88 3258.54 3309.79 3367.14 3423,76 3479.63 3535,71 3591,98 3649,49 3708.20 3766,49 3824,10 3~81,71 3938, } ~99be~d 4050,72 4104.8S 4157.86 4210,23 4261,49 4311.52 4360.85 4409,90 4531.74 5GTTO!,.! HOLE CLOSURE 4531,74 FEET AT N 85 5 50 k ~,RCO DS 7-5 GYROSCOP]:C SURV[-:.!Y INTERPOLATED TRUE VERTICAL D~PTHS, ~v~,~D~F.~ATE5 AND CLOSURES ru~ GIVEN DEPTHS TRUE 'ODE ¥,EASURED VERT I CAL ~A;,IE DEPTH DEPTH TOTAL COORD[ NATES CLOSURE D ! S TAN CE A/',~G L E D H 5 OCT SUB SEA 'OP SAD 10000 8561.53 ~ASE SAD 10632 9104.82 'P 10750 9207,01 4~1.42 N 4136,12 E 4158.56, N 8/+ 2 42 E 8497.53 387,29 N~~''~ 4515,16 E :'.,. 4531,74 N 85 5 50 E 9143.01 ARCO DS '7-5 GYROSCOPIC SURVEY !4EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF ,SUB SEA DEPTH, OCT 24-, 1978 TRUE MEASURE[} VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 164 164. 100 0 264 264, 200 0 364 364, 300 0 464 464, 400 0 564 564, 500 0 664 664. 600 0 764 764, 700 0 864 864, 800 0 964 964, 900 0 1064 1064, 1000 C 1164 1164. 1100 0 1264 1264, 1200 0 1364 1364, 1300 0 1464 1464. 1400 0 1564 1564. 1500 0 1664 1664, 1500 0 1764 1764, 1700 0 1864 1884. 1800 0 1964 1964, 1900 0 2064 2064. 2000 0 2164 2164, 2100 O 2264 2264, 2200 0 2364 2364. 2300 0 2464 2464, 2400 0 2564 2564. 2500 0 2564 2664. 2600 0 2764 2764. 2700 C 2865 2864, 2800 0 2966 2964, 2900 2 3070 3064, 3000 6 3175 3164, 3100 10 3280 3264, 3200 16 33S6 3364, 3300 22 3493 3464, 3400 29 3602 3564, 3500 37. 0 0 0 0 0 0 0 0 0 0 0 0 2 4 4 6 7 0,00 0.00 0,00 0,00 0.00 0,00 0.00 0,00 0,00 O.OO 0.00 0,00 ~' ,:~,, L', ~,~'~?, ¢ 0,00 0,00 0,00 0,00 0.00 0.00 0,00 0,00 0.00 O.O0 0.35 3.14 8.52 16.97 40.90 5q.43 69.12 85.00 101.37 0,00 W 0,00 W 0,00 W 0,00 W 0.00 W 0,00 W 0,00 W 0,00 W 0,00 W 0,00 W 0.00 W 0,00 W 0.00 W 0.00 W 0,00 W 0,00 W 0,00 W 0,00 W 0.00 W 0,00 W 0.00 ~,'~ 0,00 W 0.00 W 0~00 W 0,00 W 0,00 E 0,83 E ~,78 E 25,71 E 50,6.~ E 79,21 E 109.59 E 142.06 E 176,78 E 215,25 E kRCO DS 7-5 E,tXSURC:D DEPTH OTHER DATA GYF, OSCOPIC SURVEY EVERY EVE~''.~ i00 Fc'.::~T OF' SUB SEA OCT 2/+, 1976 HEASURED DEPTH TRUE VERTICAL D E P T H SUB SEA MD-TVD D I FFERENCE VERT I CAL C 0 R !R E C T ! 0 ~N TOTAL COO)RD INATES 371 382 393 405 417 429 441 454 467 481 494 507 521 534 548 577 591 606 620 648 662 676 6,89 702 716 729 742 755 780 793 805 3664 3764 3864 3964 .4'054 4164 4264 4354 4464 4564 4664 4?64 4864 4964 5064 5164 5264 5~64 5464 5564 5664 5764 5864 5964 6064 6164 6264. 63.54 6464 6564 3664 6764 6864 6964 7064 3600 47 10 3700 60 13 3800 74 14 3900 89 15 4000 107 18 4100 127 20 4200 152 25 4300 182 30 4400 215 33 4500 247 32 4600 281,', 34 4700 314 33 ~ 49.!!, 4,~00 4900 5000 423 5100 466 5200 508 42 5300 553 5400 ~96 43 5500 638 42 5600 679 41 5700 719 40 5800 758 39 5900 796 6000 83C,, 34 6100 ~53 33 6200 897 34 6300 9~1 34 6400 960 29 6~00 9~9 29 6600 1316 27 6800 lOU9 ." 26 69C0 16)92' 23 700O 1117 25 117,13 133,76 149,69 165,36 179,44 192.0~ 204,82 218,05 230.39 241,81 24~,25 253.23 0,45 274.00 275.8~ 277,54 280.31 283.20 286.61 290.92 29~.51 307.78 319.17 356.94 370.52 ~'~ 96 395 . 19 406 . 80 416.27 426 · 62 257,82 E 306,34 E 359.22 E 415,29 E 475,99 E 540,29 E 613,92 E 695.76 E 782,~1 868,91 E 957,19 E 1045,39 E 1135,04 E 1225,83 E 1323,07 E 1424,24 E 1526,03 E 1629.49 E 1732.30 E 1~32,72 E 1932.34 E 2030.13 E 2126.79 E 2221.97 E 2310.27 E 2397.44 E 2485.75 E 2573,12 E 2654.21 E 2733,93 2811.74 E 2d88,95 E 2964.67 E 3037.41 E 3109.95 E ARCO DS 7-5 ~.'!EASURED D[i'PTH.A'"'~D~'~ 0 T H ~ R DATA FOR GYROSCOPIC SURVEY ZV[ZRY EVEN 100 FEET OF SEA DEPTH. OCT 24, F'iEASLJRED D E P T H TRUE VERTICAL DEPTH S U SEA hi D- T V D D IFFE:RENCE VERT I CAL C 0 ,:~ f~ F C T I 0 N TOTAL COORDINATES 83 84 87 90 91 92 93 97 98 O0 O1 02 03 04 05 O7 05 22 41 63 04 26 72 18 63 03 21 69 85 O0 7164 7264 7364 7464 7564 7664 7764 7864 7964 8064 8164 8264 8364 8464 8564 8664 8764 8864 8964 9064 9164 710 720 730 74O 75.0 760 770 78O 790 8O0 810 820 830 840 850 86O 870 690 90O 910 1141 1158 1177 1199 1220 1240 1261 1285 1308 1331 1354 1376 1399 1420 1439 1457 1474 1490 1505 1521 1536 24 17 22 21 20 21 24 23 17 16 16 436,54 N 444,64 N 45i,60 N 457,26 N 46 0 · 16 t'~ 464.20 N 468,70 N 4.72,36 N 474.50 ;"~ 473,91 iN 469,05 N 461.02 N 416.56 N 411,70 N 406,50 N 398,7~ N 390.77 N 3183.20 E 3242,61 E 3306.80 E 3376,31 E 3443,85 E 3511.13 E 3579.53 E 3651.04 E 3725.34 E 3794.51 E 3~66.09 E 3936.45 E 4006,12 E 4073,40 E 4137,70 E 4200,32 E 4260,65 E 4318.70 E 4975,99 E 4433.40 E 4490.41 i ~,RCO [)$ 7-.,5 %TERPOLATED VALUES FOR EVEN TRUE MEASURED VERT ! (';AL DEP TH DEPTH 1000 1000. 2 000 2000, 3 000 2996, A. O00 3917. 5000 ~704. 6000 5421. 7000 6143, 8000 6917. ~000 77~+2. 10000 8561, GYROSCOPIC SURVEY 1000 FEET OF I'4EASURED DEPTH, SUB SEA TOTAL C©ORD INATES 936. 0,00 S 1936, 0,00 S 2932, 20,44 N 3853, 158,17 N 3 ~640. 250.15 N ?'" 9 5357. 276.88 Nv' 6079. 316,98 lq ~ 23 6853, ~. 412.11N W 30 7678, 467.97 N 8497, .!5. 430,95 0,00 W 0,00 W 33,2.5 E 88,81 E 93,4.2 E:" 89,37 E. 79,97 E 04.13 65.03 E 36e05 E OET 1978 HORIZONTAL. Vl EW .... ATLANTIC RICHFIELD COMPANY . ........ SCALE I" = I000' D. RILL SiTE 7-5 ....... ........... RADIUS OF CURVATURE ._ .............. GYROSCOPIC SURVEY IALL- DEPTHS- SHOWN ....... ................. ~. a o_ .~ ., ~-~ .~ : .~ _ ~~ _ ~ ~'- TVD= 9207 ~ ~ O O ~ ~. - ' ~ ..... ......... ~ ~ 'O ..... I I I , ~' ' ' . ~n-~m~m~ ........ ~ . . i ! / ill~- i~1/~~ .... ........................................................................................... : ....................................................................................................... , ......... ......................................... L__ ......................... 2L. ........ i ........................................ i_,_VER.TICAI__.. S.ECTION .................................................. . ATLANTIC RICHFIELD .COMPANY ........ SCALE I"= I000' 4oo ....... ..... ii ....i ................ ~' ................................... _~.__~L_ ................DRILL. SITE ....... RADIUS- OF' CURVATURE GYROSCOPIC SURVEY 1200 _ . 2800 ............................................................................................... TMD: 10,750' DON BAKER INC. DIRECTIONAL & DRILLING CONSULTANTS REPORT AND PLAN OF SUB-SURFACE SURVEY FOR: ARCO PRUDHOE BAY, ALASKA DRILL SITE 7 - 5 ~E__T_ION REPORT DEC 2,3 ~ 1978 ATLANTIC RICHFIELD COHPANY DS 7-5 RADIUS OF CURVATURE METHOD OF COHPUTATIONS K,~3, ELEV, 64 FEET ,qAGNETIC SINGLESHOT SURVEY DECLIi,~ATIOhl 31 DEGR[:.:ES EAST COMPUTED FOR DON BAKER INC [3Y F '/vi LINDSEY AND ASSOCIATES RECORD OF SURVEY ALL CALCULATIONS PERFORMED 5Y I b Fi ELECTRC?,4IC COF!PUTER TRUE DOG LEG HEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDIt',!ATES C L O S U R E S SEVERITY CECT! L._i DEPTH ANGLE DEPTH SEA DIREC DISTANCE ANGLE DEG/iOOFT DISTANCE' D H DEG, D I'4 S , 0 0 0 0.00' -64,00 N31,OOE 0.00 S 0,00 W O.O0 S 3 0 0 W 0.000 O.OO 1396:0 15 1395.99 1331,99 NBL,OOE 2.61 N 1.56'E 3,04 N 30 59 59 E 0,018 1,76 1878 0 15 1877,99 1813,99 N66.00W 4,38 hi 1,00 E z~,50 N 12 57 36 E 0,078 1.38 2740 1 0 2739,93 2675,93 N26.00W !0,78 N 5.61 w 12,16 N 27 3C 49 W 0,087 -4,67 2793 1 0 2792.92 2728,92 N61,OOE 11,58 N 5.36 W 12.76 N 24 51 3 W 2,597 -4,35 /2855 ' 4 0 2854.85 2790,85 N64,00E 12.83 N 2.96 W 13,17 N 13 1 8 W 4,839 -1,85 2949 8 45 2948.25 28B4,25 N66,0OE 17,24 N 6,48 E 1b,42 N 20 37 17 E 5.053 7,93 3042 13 15 3039.51 2975,51 NSB,OOE ~4,17 ~'1 2.2,81 E 33.24 N 43 20 47 E 4,840 24,80 3256 17 ~5 3245.68 3181,68 N65.00E 46,97 N 75,24 E E~,70 N 58 1 33 E 2.107 78,9~ 3525 20 30 3499,81 3435,~1 N70,OOE 80,68 ~.~ 155,63 a' 176,19 N 62 44 4fl E 1,047 162,9~ 3777 25 0 3732,1z+ 36~8.1~ N74.00E 110,78 N. 24.9,27 E 272,78 IX~ 66 2 18 E 1,dO8 257,83 4026 29 0 3953,96 3889.96 N76.OOE 140,03 N 35~.q3 E 384..$2 N 68 39 37 E 1.617 369.09 430S 35 0 z~193,00 4129.00 N78.00E 173.63 ~. 503.97 E 533.04 N 70 59 22 E 2,140 516.°' 4497 39 30 4343.z~0 z~279.40 N79,0(;E 196,z+3 h~ ~,15.04 E 6z+6.~,0 N 72 15 51 E 2,391 z~96g 41 30 4701.54 46~7,54 NgO.OOE 252.17 ;t 916,79 E 950.84 N 74 37 13 E 0,435 934,99 5527 44 0 5111.99 5047,99 N83,00E 308,25 N 1292.00 E 1328.26 N 76 34 51 E 0,517 1313.62 5715 45 45 5245.~1_ 5181,o1,, ~,~82, .COE 325.56 ,,," 1'423,=0., E 14~,0.26 N 77 7 ~ E 0.970 1~46.12 64~9 ~5 0 57~9.91 5724-.91 F~83,00E 397.4~. N 1¢(~.&5 E 2009,3b N 78 35 2b E 0,116 1996,41 6927 43 30 6031,h2 5967.02 ~'<86 OCE z~20 ' N ' ,' ' · . .0o 22~z~.38 E z24t+.05 N 79 12 39 E 0.611 7765 39 15 6734.73 f, b70.73 N84.COE Z~Tq. Og i,~ 2u21.d5 E 24~61.40 [~ 80 27 46 E 0.~61 2U52.05 BSq~ 37 0 7389.98 'I325.98 N~5.COE 573,37 ~: 37Z3.72 [: '~:~7~..56 H 81 4 39 E 0,274 3366,26 9033 34 15 7743.53 7679,53 1'.:~7.¢0E 541.C4 ~. 35~C.,45 ~' ;~627.03 N 81 25 lfi E O,oZ, 9 3519,57 9884 35 0 B4z~3,f~l g379,Sl 575.L.~E 490,71 :..~ ,..C65.~.5 f 4,.)gz~.P. 7 i'~g3 7 2 E 0.701 4092~43 1067~ 30 15 qln~,13 n044 13 576 nor 3~.~ 23 F: 4~77 07 E ~497. q3 ?.Jb" 5 40 E 0,603 4q93,55 "'~ -" AT [~(')TT~,,, htOLE CLO~ ARCO DS 7-5 MAGNETIC SINGLESHOT SURVEY DEC 20, 1978 , MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SU~.~ SEA DEPTH, TRUE MEASURED VERT]CAL SUB t.1D--.T VD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 164 164, 100 0 0 0,03 N 0,02 E 264 264, 200 0 0 ~ N 0,05' E 364 364, 300 0 0 0;-1'7 N 0.10 E 464 464, 400 0 0 0.28 N 0.17 E 564 564. 500 0 0 0.42 N 0.25 E ., 664 664, 600 0 0 0.59 N 0.35 E 764 764. 700 0 0 0,78 N 0,47 E 864 864, 800 0 0 1.00 N 0.60 E 964 964, ' 900 0 0 1.24 N 0,74 E 1064 1064. 1000 0 0 1,51N 0,91 E 1164 1164, 1100 0 0 1.81N 1.09 E 1264 1264, 1200 0 0 2,1'4 N 1.28 E 1364 1364. 1300 0 0 r ~.49 N 1464 1464, 1-/~O0 0 0 2-;-8-4 N ~.--7~ .... 1564 1564. 1500 0 0 3'.09 N 2.10 E 1664' 1664, 1600 O 0 3.~0 M 2.52 1764 1764. 1700 0 0 3.17 N 2~95 E 1864 1864. 1800 0 0 2.98 N 3.34 E 1964 1964, 1900 0 0 4,57 N 0,62 E 2064 2064. 2000 0 0 4.89 N 0.06 E 2164 2164, 2100 0 0 5.33 N 0,59 W 2264 2264, 2200 0 0 5,91 N 1,34 W ~ 2364 2364, 2300 0 0 6.63 N 2,16 W 2464 2464. 2400 0 0 7.50 N 3.04 w 2564 2564. 2500 0 0 ~.54 N 3,96 W 2664 2664, 2600 0 0 9.75 N 4,90 W 2764 ~76'4,' 2700 0 0 11,'1'9 N 5,6~ W 2864 2864, 2800 0 0 13.12 N 2.36 W 2965 2954, 2900 0 0 15.26 N 8.81 E 3067 3064, 3000 3 3 26,38 N 28,22 E 3171 3164. 3100 6 ' 3 36.83 N 52,7~ E 3275 3264, 3200 11 5 49,41N 80,53 E 3381 336'4, ' 330'0 .... 16 5 62."90 N '" lll,31'"E 3487 3464. 3400 22 6 76.06 N 144,28 E 3594 3564, 3500 29 7 " 8~i.96 ?t 18(3,07 E ARCO DS 7-5 NAGNETIC SINGLE~%HOT .~IJRVFY DEC 20~ !97R . MEASURED .DEPTH AND OTHER DATA FOR EVERY EVEN !00 FEET OF SUB SE.A D[~PTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 3702 3664, 3600 38 9 101.91N 219.78 3812 3764, 3700 48 lO 114..86 i'! 263~65 3924 3864, 3800 60 12 12a,O0 ~ 311,78 E ~ 4037 · 3964. 3900 72 13 141,32 N 363,63 E ~154 4064. 4000 90 17 155.13 N 421.14 E : ~273 4164, 4100 108 18 lt~,43 N 484,56 E ~--i 4396 4264, 4200 132 24 1~4,17 ~ 554,57 E .... 4524 4364. 4300 159 27 199.70 N 632,92 E 46~54 4464. 4400 190 31 215.34 N 714.85 4785 4564, 4500 221 31 230,91 N 798,66 4918 4664. 4600 253 32 246.39 ~'4 884,24 5052 4764. 4700 288 3.5 261,61 N 971,61 5187 4864~ 4800 323 35 276.07 ?4 1061,06 5323 4964. 4900 359 36 2~.~9.69 N 1152.61 E 5461 5064, 5000 396 3~7 302.50 i,l 1246,64 E 5~00 5164, 5100 435 39 314.64 N 1342,62 E 5742 5264, 5200 478 4.3 328,24,N 1442,59 E 5885 5364, 5300 521 43 342.25 N 1543,94 E 6028 5464, 5'~00 '564 4~ 355,87 N 1644.84 E 6170 5564, 5500 606 42 ~ 36V,11N 1745.30 6312 5664, 5600 648 42 3~1.95 N 1845.32 6454 5764. 5700 690 42 394..41N 1944.90 6595 5864, 5800 731 41 405.94 N 2043.63 6734 5964, 5900 770 39 415,16 N 2140,51 6872 6064, 6000 805 38 422.26 N 2235,49 7009 6164, 6100 845 37 429.15 N 2328,46 7144 6264. 6200 880 35 436.35 N 2419.42 7278 6364~ 6300 914 3a 443.85 N 2508.42 7~11 6464, 6400 9~7 33 4~].64 N 2595.5b--~ 7543 6564, 6500 979 32 459.70 ~'1 26g0.68 E 7673 6664, 6600 iOOW 30 46!~.03 N 2764.00 E 7803 6764. 6700 1039 30 476.57 Fi 2845,59 E 7931 6864. 6800 1067 28 494.86 N 2925.08 E 8059 6964, 6900 1095 2S 492.83 /'1 3005,59 E 8187 7064. 7000 1123 28 500.49 N 3094.16 E ARCO DS 7-5 .~4AGf'~.ETIC SINGLESHOT SURVEY DEC 20, 1978 ~'4EASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TP, UE P!.EA~UR ED VERTICAL SUB F4D-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 8314 7164. 7100 1150 27 507.85 N 3161,77 E 8440 7264. 7200 1176 26 514,90 N 3238,44 E 8565 7364. 7300 1201 25 521,66 N 3314.I8 E 8690 7464, 7400 1226 25 8814 7564. 7500 1250 24 527.98 N 3388.72 E 533.43 N 3461.25 E 8936 7664, 7600 1272 22 538,00 N 3531,77 E 9058 7764. 7700 1293 21 541.71N 3600,37 E 9179 7864. 7800 1314 21 543.13 .iq 3668.72 E 9300 7964. 7900 1336 22 541.48 N 373'1.11 E 9422 8064. 8000 1357 21 536.75 N 3806.11 E 9543 8164, 8100 1379 22 528.95 N 3874.45 E 9665 8264. 8200 1400 21 518.05 N 3943.12 E 9787 8364. 8300 1422 22 504.06 N 4011.42 E 9909 ~464. 8400 1445 23 4£7,06 N 4079,98 E. 10030 8564, 8500 1466 21 469.40 N 4145.38 E 10150 8664, 8600 1486 20 452.39.N 4210,06 E 10270 8764, 8700 1506 20 436,00 N 4273.03 E 10388 8864. 8800 1524 18 420.23 N 4334.32 E 10505 8964, 8900 1541 17 405.06 N 4393,96 E 10622 9064, 9000 1558 17 390.48 N 4451.97 E ARC~ BS 7~ M A G~SLF_T_I_f._S_I N 6 L E S H 0 T SURVEY DF.C. 2-0-,--t-9-'/. 8 NTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTtt. ~ TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDINATES 1000 999, 935, 1.33 N 0,80 2000 1999, 1935. 4.67 N 0.43 3000 ' 2998, 2934. 20.76 N 14.59 E 4000 B931, 3867. 136,97 N 346.29 5000 4725, 4661. 255.83 N 937.?1 6000 5444, 5380. 353.25 N 1625,28 7000 6157. 6093, 4~8.69 N 2322.29 E 8000 69i7, 6853. 489.16 N 2968.76 E 9000 7716. 7652. 540.05 ,N 3567,85 E 10000 8539, 8475. 473.72 N 4129.09 E EIO RIZONTALL LVI EW ..... · .......... ATLANTIC- RICHFIELD ·COMPANY'i ...... .. ~-'."'. DRILL SITE 7-5 .................... SCALE' '!"= 1000 RAOIUS-0.F'-cURVATURE .................. : ..................................... MAGNETIC. SINGLE*- SHOT ............... ' ......................... ..................................................... '~- ........ '~E P,_'"E I CA IZ-LS EC l". IQ N ................ · i : ---.-_~ATL'AN T lC-- RI CH F i E L D - C 0 MPANY .~' -,, - DRILL SITE 7- 5 ........................ --,--~ i SCALE- !': ' I000 .................................. ' i -- ._RAD I US- 0 F 'C URVATU RE MAGNETIC SINGLE-SHOT ......................... i ........ L .... '.--.-~- .~ ........................................................... ---~----- t ~ ._.;,. ......... L. ........................ ,,- ...................... ?~ti~;'~ticRichfi etdCompan:¢ North Ame;ican Produci¢~g Division North Aia-~'-a -~dstrict Post Offi~ ,~ux 380 Anchorage, Alaska 99510 Telephone 907 277 5637 October 31, 1978 Reference: Enclosed isa Gyroscopic Survey for D.S. #7-5. ,~~Plea ' se sign .and return the copy as receipt of data. SinCerely, V.G. Reimers North Engineering TRANSMITTAL #544 North American Producing Division Alaska Re ~ Post Office ~,o× 360 Anchorage, A~aska 99510 Telephone 907 277 5637 October 4, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject- DS 7-5 Dear Si r- Enclosed please find a Monthly Report of Drilling Operations for the above-mentioned well. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'jh Enclosure Form No..10404 REV. 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL 1567'S & 92'W of NE cr Sec. 33, T11N, R14E, UM 5. APl NUMERICAL CODE 50-029-20293 6. LEASE DESIGNATION AND SERIAL NO. ADL 28309 7. IF INDIAN'ALOTTEE OR TRIBE NAME 8. UNIT FARM OR LEASE NAME Prudhoe Bay Unit 9. WELL NO. DS 7-5 10. FIELD AND POOL, OR WILDCAT ~rudhoe Bay Field-Prudhoe 0il 11, SEC. T. R. M. (BOTTOM HOLE OBJECTIVE) Sec. 34, T11N, R14E, UM 12. PERMIT NO. 78-13 Pool 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for the Month of September, 1978 Spudded well @ 0100 hrs 9/19/78. Drld 17-1/2" hole to 2740'. RU & ran 13-3/8" csg to 2714' Cmtd w/4800 sx Arctic Set II cmt. Did 50 sx top job. Drld float & cmt & 10' new ~ole. Tstd form. Drld 12-1/4" hole to 9386' as of September 30, 1978. 14. I hereby ~hat ~~~d~rrect SIGNED. /~' ~- T,TLEDistrict Drilling EngineerDATE.. NOTE-Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and gas conservation committee by the 15th of the succeeding month,unless otherwise directed. DEPA~I~4ENT OF NATURAL RESOURCE~q Divisic~ of Oil and Gas Conservation Direct_or r~ Harold R. ~s ~=p~ 29, 1978 Witness BOP Test, Arco Drill Site 7-5 Sec. 34, TllN, R14E, L~4. Permit No. 78-13 ~~y, ~ 20.,..1978_ - I left Anchorage by Wien Air at 11:15 AM, ~i~ at ~ at 12: 45' ~4. Purpose of trip was to witness BOP test for Arco on Drill Site 7-5 well. When I arrived at 7-5 they were onning out of the hole with drill pipe, gett/ng ready to run 13 3/8 casing. Time 1:30 PM. Thursday, ..~_~. _te~ 21, 1978 - Top job on ce~anting was dc~e a~ nippling ~'"~' cc~pleted ~ 'BoP'%s ~ te~ started at 7:00 PM. George Bean was the supemxmlsor for Arco. The annular preventer was tested first to 3000 psi. Test was done wi~% water, using a wellhead type test plug. Next the ~ pipe rams, outside choke (HCR valve) and outside kill were tested to 5000 psi. Before ~ pipe rams would hold test, door seal had to be installed. Next ~ was i~ide kill valve and inside choke valve to 5000 psi. Check valve had been disabled, was Fat back togeth~_r and te~ to 5000 psi. Before check valve would test ring seal had to be put Ln check valve. The manifold had 6 valves and 22 flanges and one Swaco sup~_rchoke that were tested to 5000 psi, separately. The m~l choke on manifold operated freely. The upper kelly failed test ~ was replaced and tested to 5000 psi. The lower kelly tested to 5000 psi. There was a ~ valve and ball valve on floor that operated freely. The location was clean and free of debris. The mud pit was open but w~ll ~. The well sign was up and all data OK. The acctmu]~tor master gauge had 3000 psi, 1500 psi on manifold. The ni~ bac~ bottles had 2250, 2150, 1900, 2000 each. The drill spool had 3" outlets. I also found broken hose on nitrogen backup system,, which was replaced with new hose. B ~l/nd rams were tested last to 5000 psi. Remote and master controls operated satisfactorily. In ~mmrary: I witnessed BOP test c~ Drill Site 7-5 for Arco. ~en tests were completed, BOP's and all ~rking cc~pon~nts and inspections w~re satisfactory. Commi . ~ "".AIOa 0il and,Gas Conservation ' Fie-ld inspection Report Drig. Permit No,~._/_~ Well/Platfm Operator_,~r, ./?.Z~. ~ Represented by~/~/~ ~A~ Name & Number Satisfactory Type Inspection Yes No Item (~) Location,General () (X) ( ) ~) () () () () () () () () (). () () () () 1. Well Sign 2. General Housekeeping 2. Reserve Pit-(~Oopen( )filled 4. Rig ( ) Safety Valve Tests 5. Surface-No. Wells 6. Subsurface-No. Wells ( ) Well Test Data 7. Well Nos. , , , 8. Hrs. obser , , , 9. BS&W , , , 10. Gr. Bbls. ( ) Final Abandonment Satisfactory Type Inspection Yes No Item ~,BOPE Tests ( ) .1 . /~asi'nq set ~/zT~/~ ( ) 1~. les~rfluia-O~'wt~]mud ()oil ( ) .17. Master Hyd. Control Sys.-~?_~z'___~_psig () (~) () (X) () (~ () (x) () (X) () (x) () (~) () (x) () (x) () 18. N2 btls~_4~,~, ~d~ _~/.~sig 19. Remote Controls 20. Drilling spool-'~' "outlets 21. Kill Line-(X) Check valve 22. Choke Flowline ~(~) HCR valve 23. Choke Manifold No. va,lvs~__flgs~ 24 Chokes-(~Remote()~P. os. Od)Adj. - 25 Test Plug-( )Wellhd(;Xk)cs.a( )none 26. Annular Preventer,_]l~.psiQ 27. Blind Rams~-~mpsio ( ) ( ) 11. P&A Marker (~K) ( ) 28. Pipe Rams~~psiq ( ) ( ) ' 1Z. Water well-( )capped( )plugged (X) ( ) 29. Kelly & Kelly-cock.~ psig ( ) ( ) 13. Clean-up '' (~[) ( ) 30. Lower Kelly valve.~f_~sio ( ) (). 14. Pad leveled - · .t ~ ~ ( ) 31. Safety Floor valve~~BV '~Dart Total inspection observation time~~/days Total number leaks and/or equip, failures Remarks Notify in days or when ready Inspected by~//~ ~/~/~' ...Da Fe~ 3, 1978 ~ ~ Unit DS 7-5 (xx-34-11-14) AtL~n~c RickfieI~ Sta~e Pennit I~. 78-I3 Atlantic Richfield ~y P. O. ~ ~0 Anchora~, ~ ~510 Enclosed is the app~ application for ~t to drill the above ref~ ~1 ~ a location ~ Section 34, Township llN, Range 14E, UM. ~11 samples, ~ chips ~ a mua log ~ not required. ~y is re~{~. A ~onal F~ny ri~_~s in Alaska ~ ~ drainage s~ ha~ been classified as i~porta~t ~ ~ sp~ning or migraticn of ar~3drc~ fish. Operations ~ ~ ~ are sub,ct to AS 16.50.870 and the regulatic~s prc~ulgated e_hereunder (Ti~ 5, ~ ~strati~ Code). Prior to ~g operaticr~s ~ i~ay be contacted ~f ~ Habitat Cocrd/nator's office, D~part~mt of Fi~ ~ ~. poltutic~ of. ~y waters of ~ State is prohibited by AS 46, Chapter 03, ~icle 7 and ~ re~~ prc~mlgated thc_rear (Title 18, Alaska Ad~strati~ ~, ~ 70) ~ by the Fedaral Water Pollution Cc~I ~, as ~. Prior ~ ccmm~n~ing operations you may be contacted by a repre~e~ti'~e of ~ ~De~t of Envirc~m~al Ccn~ation. Pur~m~nt to AS 38.40, ~ ~ ~ State I~, ~ Alas¥~ De~t of ~ is being no~f~ of t~ is~mzK~ of bhis permit to drill. ~ aid us in ~~ field ~ork, ~ would appreciate your notifying this office within 48 hours ~ ~ well is spudded. ~ would ~lso like to ~e notifie~ so that a rep~. sentati~ of ~ Divisi~% may be present to witness tes 'ting of blc~t p~ter, e~/ip~nt before surface casing shoe L~ drilled. F. M. Brown 2- P.Bo Unit DS 7-5 Feb_~ 3, 1978 Ln tP~ event of ~icn or ~t please give this office ad~foate ~ notification so bhat %~ my have a witness present. O. K. Gi!breth~ Jr. Alaska Oil and Gas Ccm~~ Omnnitt~e Enclosure De~t of Fish and Gang, Habitat Sectic~ w/o encl. Deparb~t of Envimmmmntal Om~mrvation w/o encl. De~t of Italy, ~sorv Labor Law Czx~lianoe Di%~is~ w/o er~l~ Ati~ n~jcR]chfie]dCo,~pany North Americ~, Producing North Alaska ~tdct Post Office Bo× 360 Telephone 907 ~77 5637 January 5, 1978 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: D.S. 7-5 (xx-34-11-14) Dear Sir: Enclosed herewith is our Application for Permit to Drill D.S. 7-5, a $100.00 filing fee, and the required survey plat. Very truly yours, Frank M. BrOwn District Drilling Engineer /am Enclosures Form 10-401' REV. 1-1-71 la. TYPE OF WORK SUBMIT IN TR. .ATE (Other instructions on $. OIL AND GAS CONSERVATION COMMITTEE JAN 1 3 1978 PERMIT TO DRILL OR DEEPEN ,. ~s~sm~o~s~s~[so. 'D.visio~ ot 0il ~,d Ga~ Ca,,-,-~, ADL 28309 DRILL ~ DEEPEN ~ Anohorage 7. IFINDIAN, ALLO~EEORTmBENAME b. TYPE OF WELL - OIL GAS SINGLE MULTIPLE WELL ~ OTHER WELL ~] ZONE [] ZONE Atlantic Richfield Company 3. ADDRESS OF OPERATOR P.O. Box 360; Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 1567'S & 92'W of NE er Sec. 33, TllN,-'R14E, UM · At proposed prod. zone 1320'S & 1320'W of NE cr Sec. 34~ TllN~ R14E, UM 13. DISTANCE IN blILES AND D!REcTION FROM NEAREST TOW~'N OR POST OFFICE* 5 miles N~of Deadhorse, Alaska 8. UNIT FARM OR LEASE NAME Prudhoe Bay Un±t 9. WELL NO. DS 7-5 (xx-34-11-14) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay Field-Prudhoe Oi, 11. SEC., T., R., M., (BOTTOM Pool tlOLE OBJECTIVE) Sec. 34, TllN, R14E, UM 12. 14. BOND INFORMATION: TYPE Statewidesuretyana/orNo. Federal Insurance Co. #8011-38-40 Amount" $100', 000 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE. ,FT. (Also to nearest drig, unit, if any) 1320' 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 2640' 21. ELEVATIONS (Show whether DF, RTl CR, etc.) Pad Level - 30' RKB - 54' 16. No. OF ACRES 1N LEASE 2650 19. PROPOSED DEPTH 10538'MD 17. NO.ACRES ASSIGNED TO TillS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START November 1978 23. PROPOSED CASING AND CEMENTING PROGRAM sIZEoFItoLE ~IzEOFcAsING wE1GHTPERFObT GRADE SET]'INGbE~H Qua,,tityofcement 32"' .......... 20" 94 lb. H-40 80' 250 sx Permafrost II. t° surf 17-1/2" 13-3/8." 72 lb. ~N-80 2700'MD Circ to surf - approx 5500 sx ~12~1'/4''' 9'5/8" '47 lb. B0 & 95 10538'MD 2600'& cmt Column on 1st stg ..... approx 1500 sx) plus 300'+ colum on 2nd s.tg (approx 300 sx) Atlantic Richfield Company proposes to directionally drill this well to 10538'MD, 9142'TVD to produce the Sadlerochit zone. Logs will be run across selected intervals. A' 13-5/8" 5000 psi RSRRA BOP stack will be used. It will be pressure tested each week and opera- tionally tested each trip. A string of 5-1/2" 17# N-80 tubing, packer, and necessary provisions for subsurface safety equipment will be run. The packer will be set above the Sadlerochit. A non-freezing liquid will be left in all uncemented annuli within the permafrost interval. Selected intervals within the Sadlerochit interval will be perforated, and reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. Well will be flowed to production facilities durinz Derforatinz and testing. The downhole safety valve will be installed IN ~OVE SPACE DESC~BE'?ROPOSED PROG~M:~ propo~l is to deepen ~ve data on present productive zone and pro~sed new productive zone. If propel ~ to d~ or deepen ~fion~y, ~ve ~rtinent data on sub~ce locations and measured and true / ~ . verti~ depth~ Give blowout preventer pro~am~ ~UQ~E'~ '-- Revers e Sid, DATE /~ ;/~ "~2 TiTLEDiSt. Drlg. Eng. (This space for State office use) [ SAMPLES AND CORE CI'HPS REQUIRED ~ YES, ~ .~o , DIRECTIONAL SURVEY REQUIRED X~ YES [] NO MUD LOG [] YES ~ so CONDITIONS OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE 50-029-20293 PERMIT NO. 78-13 APPROVAL DATE .... - ~ee; Instruction On R;verse Side SECTION 28 PR OTRACTEO SECTION SECTION LINE 27 DRILL SITE No.7 T IIN,R 14E. U.M. - REcEiVED ~ 7 j, -- ~'~2~ SECTION 3~ SECTION 33 ~_-. NOT~ ; JANUARY Il, t978 -- CORRECTED PAD CONFIGURATION CERTIFICATE OF SURVEYOR ,,, I HEREBY CERTIFY THAT ! AM PROPERLY REGISTERED :AND LICENSED TO PRACTICE LAND SURVEYING iN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME. OR UNDER MY SUPERVISION, AND ALL DIMEN- SIONS AND OTHER DETAILS ARE CORRECT. DATE SURVEYOR L/~," OF CO0/~D//VATES WELL S ~/ - #/4 AS -BULL T W£/_L NO. I - LAT. 7~ /5' 57 4z/" LO~V6. ~48° 34: zg. 965" WELL NO. Z - - LAT. 70° 15' 58 580" LelY'6.148° 34-' 30. 668" WELL /VO. 3 ~ LAT. 70* /5' ..~. 757" LO/Vd. 14~ ~4: .~/. 4Z4" WELL 4/0. 4 ~ LAT 70 ° /b' OO. 891 ,, LO, V(,. /48 ° ..34' .32.14(:, WELL A/O. 5 -- lA-Ir 7o~ 16' oz. 045" Lo,v'6.148 34' a z. 8 78" WELL NO. 6 .... LA~. 70' 16' 03. 201" l~. 148 ° 34 ' 3'3. 598" WELL /VO. 7 - LA~. 70 ' 16' 04.354" Zo~/6. /4.0 '34' 34.327" WELL A/O. 8 tAT 70°/~,' 05. ~O&" ION6. 1480 34'.~5.048" WELL #o. 9 LAT. 70' 16'06. 664" to, q6. 148 °34' 35.799" WELL NO 10 LAT 70' /6' 07.8i(=" lo, v~. 148 '34' 3b. ~2(," WELL lv'o. I! LAT. 70 ° le,' oB 9&~" lo,vG 148 ° 34' 37.2~9" WELL NO. 12 ZJ;rr. 70.° lb' /o. 125" L6,/O. 148' 34' 37. 957" WEt L A/O. 15 '~ LAT. 70' lb' II. 279" Lo~6. 14B 034'38 699" EAT. 70 ' i2 434'; Lo#5. 148 ° 34' 39.412" Y 5 ')48 887.99 X 676 229 · 68 Y 5 949 o05...23 X ;(,76 202 . o3 7' 5 949 /ZZ. 19 X 67& 174. O0 ; , · Y 5 949 Z~8. 97 X ' 676 146.44 Y .5 949 355. 70 · X 676 118. 57 Y' 5' 94-9 472. 56 X ~7(::, 09l . 08 · .. y ~ 949 ~89 16 X 676 o63.,] 31 Y 5' 94.9 7o5". 67 X 676 o.35... B2 .. Y 5' 949 8Z2'-. 8Z X 67& 0o7, i'. 25 ! Y 5 949 939~. 3/ X 675 979. 55' )" 5 950 055 . 80 x 675 95Z': . 53 y' ~ 9~0 17Z 87 X (,7~ 9Z4-i. 93 Y 5 950 289 .SZ ,~' 675 89(= .71 Y ..5' 95,0 40(= . 37 X 675 669 . 48 SURVEY DATE : JANUARY 5, 1978 ARCO No. AFE HVL No. ATLANTIC RICHFIELD CO. AS - DUI LT DRILL SITE No.7 WELLS : I THRU 14 LOCATEO IN PROTRACTED SECTION 33,T I IN , R Ia, E,U.M.' PREPARED BY HEWlTT V. LOUNSBURY 8,, ASSOC. 723W. 6TH. AVE., ANCHORAGE, ALASKA DATE JAN 6, 1978 'SCALE I'"= :300; , . CHKD. BY G D. ; . CHECK LIST FOR NEW WELL PERMITS Company ~//~_~ Yes No Rema fks Ill 1 Is the permit fee attached " ~,;" 2 Is well to be located in a defined pool 3. Is a registered survey plat attached ................ ~:,~,,:>" 4. Is well located proper distance from property line ......... ~=~m;~:. 5. Is well located proper distance from other wells 6. Is sufficient' undedicated acreage available in this pool ...... 7. Is well to be deviated ....................... 8. Is operator the only affected party ..... - :~::~.~,::' 9. Can permit be approved before ten-day wait ........... ' . ~<i:~j::!' 10. Does operator have a bond in force .... . ............. · l l. Is a conservation order needed ........ 12. Is administrative approval needed . . . ............ 13. Is Conductor string provided ....... lq. Is enough cement used to circulate on conductor and surface .... 15 Will cement tie in surface and intermediate or production strinqs 16. Will cement cover all known productive horizons ' 17. Will surface casing protect fresh water zones 18. Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient pressure rating - Test to ~=/~l psig 20. Has DMEM approved Plan of Operation ............. Additional ReQuirements' Approval Recommended' Geology' Engineer i rig' TRM~-yl/1 JAL HHH ..~:~--~ -dCM ~ HWK ~, .~-.;:: LCS'./C!C'~ RAD _Revised 11/17/76 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 APPEN. DIx. No special'effort has been made to chronologically organize this category of information. C~mpan? LIBRA_~Y TC~FE ARCO .~l~ska. ina. Well Field 7-5 ~ Bay ECC~ 3230 County, $ca~. N~r-_h ._=~ooe. , Alaska "-. Daue 12/6/87 " DELIVERY DATE 2/8/88 (Ahhrev.) l ! CCL i LSN l ,[ Ca~ing Collar Loca:or Logs Used i I Cmmpe.~.$a~.ed Neu~rcu -. $cz!e i CN - Mulzis=ace t 60 - 0 5O - 55O 0- 2OO 0 - !00, 100 - 200 ., ** REEL HEADER REEL NAME : CATE : ORIGIN : ~SYS SERVICE NAME: REEL CONTINU~TI~ NUMBER: O1 PREVIOUS REEL ~A~E : COMMENTS: ORESSE~, ~TLAS LIS CUSTOMER TAPE --- CRE.~T~ ~Y SDS PROGRAM R 2.C LENGTH: 132 5~T E S ** TAPE PEADER ** TAPE NAME : CATE : ORIGIN : FS'YS SERVICE NAM:: ~SS 1 T~PE CONTZNUATZO~ NUMBER: mREVIOUS T~PE ~E : COMMENTS: LENGTH: 132 B~TES ** FiL$ HEADER ~ I ** =ILE N~ME: PASS 1.001 SERVICE NAME: VERSION # : 1 CATE: $5/11/2G ~AX~. RECORD LE N~TP: 1~2~. ByT:q~_ FiLE TYPE: LC PREVIOUS FILE N~FE: · ** INFORMATICN RECORDS ** ** FCRM~aT ** UNITS ENTRY E L~,CKS TYPE ENTRY C:~SCRIPTiON 9 11 0 I C[,PTHS OECRE&SE 6C.O F- ~&,v. E SPACING .lIN F~$~E SP~CZNG UNITS. 19 M~XINUM FR~MES/~ECCRD T_~R~'INATOR -0, 500 L~VEL SP~CING '- C4TUM SPECIFICATION BLOCKS . CURVE REPR NAME CODE SIZE SAMPLE UNITS iiIi ,i, ! ,i,i LSN 68 4 I CPS SSN 68 & I CPS GR 68 4 I API CCL1 68 ~ 1 TEN 68 4 I LBF CN 68 & 1 % ** FCRMAT .7 CURVE REPR NAME CC3E SIZE mmmm mm--m CLSN 68 4 CSSN 66 C CCL 68 4 TTEN 68 4 SPD 68 4 CNC ~8 4 S~MPLE 1 1 1 1 1 1 UNITS CPS CPS SIM L~F F/MN % ENTRY BLOCKS TYPE ENTRY ~ESC~iPTION /+ I CEPTHS D~_CREAS~ 8 6C.C FRAME SPACING 9 .lIN FRA~5 SPACING UNITS 11 19 ~$XIMUM ~RAMES/RECORD 0 TERMINATOR -O ~0~ .~ ~ L~VEL SP~CZNG D~TUM S~ECI~!CATICN ~LOCKS CURVE REPR N~ME CODE SIZE SAMmLE LNITS i I -- -- LSN 6,~ 4 I CPS SSN 68 4 1 CPS SR 6.8 4 I ~PI CCLI 6~ ~ 1 TEN 68 4 1 LSF C N 6 ~ 4 1 DATA ** DEPTH 10500.CC0 FT 323C.,..~FcC M LSN 29.2!3 CLSN GR 33.539 CCL TEN -t7.438 SPO 6.823 C.CCO 26.997 DEPTH lO500.CCe FT 3200.~05C M LSN 64.G76 CLSN SR 35.274 CCL TEN -30.869 SmD 13.645 8.COO 27.694 DEPTH 10400.CCC FT 3169.927C'M LSN 50.934 CLSN GR 39.540 CCL TEN 25.847 S$C 11.197 O.COO 27.871 CEPT~, 103CO.CGC FT 3139.4400 M SSN CCL1 CN SSN CCL1 SSN SCL1 CN SSN CCL1 CN 15C.9a5 C.OCC 15.0C0 130.31C C.0CC 2.17.867 C .0CC ~_1.3z, 6 19C .093 O.OCC 39.686 CSSN CNC CSSN TTEN C~ CSSN TTEN CNC CSSN TTEN CNC UNITS CmS CPS mlM L~: FInN 1~'~ ~02.710 19,000 129.892 1137.05m 195.~55 106;.409 35 ~46 18~.3~4 1122.6~1 ¢3.656 LSN 83.914 CLSN 21.619 SSN 239.3'45 CSSN 238.288 GR 23.$42 CCL O.CgO T=N -39.805 SRO 27.997 CCL1 CN OEPTH IO~O0.CCC FT 3108.9660 M LSN 95.773 CLSN 32.924 GR 24.506 CCL 0.000 TEN 18.657 SPO 28.227 SSN CCL1 CN DEPTH 10100.000 FT'. 3078.4560 M LSN 105.899 CLSN 23.717 GR 35.8~7 CCL 0.000 TEN -16.6g4 SRO 2~.568 SSN CCL1 CN DEPTH lOGOg.rcg F~ 3v4~ ~ 60 LSN 108.6~8 CLSN 29.510 GR ~3.032 CCL O.0CO T~N 14.25C S~D 28.99 SSN ~CL1 CN BERTH 9900.CCC FT 3017.5260 LSN ~4.685 CLSN GR 65.778 CCL TEN -~3.6~£ SPC 12.~e~ ~.~. CCr,,., 29.~. CCL1 CN DEPTH 9307,500 FT LSN 25.C97 CLSN GR 89.~07 CCL TEN -3..C5~ M 6.?~9 0.CCC, 29.097 SSN CCL1 C N STARTING OEmTP =10655.000 FT ENDING DEPTH = 9807.500 FT 3~7.6510 ~ 2~89.3320 ** FILE TRAILER ** FILE NAME: ~SS 1.001 SERVICE NAME: VERSION ~ : 1 DATE: 85/11t MAXI~M LENGTH: 1024 FILE TYPE: LC NEXT FILE NAPE: ** FILE HEADER FILE NAME: P$SS Z'.GO2 SERVICE N~E: VERSION # : ! gATE: ~5/11/2C M~X RECORD LENGTH: 1~2~ FILE TYPE: LO ~REVICUS FILE *~ INFOR~TICN ~ECOR~S ** MNEM CONTENTS UNITS APIN : 500202~'2~3 CN : ARCC &L$$Ka, INC. WN : ~.S. 7-5 FN : P~UOHO~ B~Y COUN: NORTH SLOPE C ,OCC 21.402 251 .21C C.0CC 15.3C1 256.5'~C C .OCt 1,5.735 25 = .~55 C.OCC 15.136 101.711 C.OCC 33.925 1.55. Q:~ '- C .CCC TTEN CNC CSSN TTEN CNC CSSN TTEN CNC CSSN TTEN CNC CSSN TTEN CPC CSSN TTEN CNC 1043.C49 .25.402 297.519. 1092.042 lC.~1 241.813 1025.249 22.73~ 264.371 1,344.~15 19.136 ~ ~2= 15~.98'~ 9e5.102 85.155 sTAT LCC : aLAsKA : 150.~0 ENTRY TYPE ~NTRY IIIi liIii 4 1 8 6C.O 9 .I~N~ 1t 19 0 -0.500 D&TdM SPECIFIC BLOC.~S CESCRIPT!ON OEmTHS DECREASE FRAFE SPACING CRAFE. SPACING UN~TS~ MAXIMUM FRAMES/RECORD TERmiNATOR LEVEL SR4CING ATTM ~N ~LOCKS CURVE REmR NAM~ CC3E SIZE SAMPLE bNiTS mmmm lllI LSN 68 4 I CPS SSN 68 ~ 1 C~S GR 68 ¢ 1 CCL1 58 ~ 1 TEN 6:5 ~ 1 L~ CN 68 4 1 ** FORMAT ** CURVE N~ME CLSN CSSN CCL TTEN CNC ~CD~ 65 SIZE 4 SAMPLE 1 1 1 1 1 1 UNITS CPS CPS DIM F / !"~N /¢ ENTRY BLOCKS CATUM S~ECIFIC~TION BLOCKS CURVE REPR NAME COOE SIZE SAMPLE UNITS .Iii i I I! LSN 6~ 4 I CPS SSN 68 '4 I CPS GR 6~ CCLt ~8 4 1 TEN 68 CN 68 ** D~TA ** DEmTH 10657.COC FT 3248,260C M LSN 34.996 CLSN ~.749 GR L0.960 CCL C,~CO TEN 189,C$1 SeC 0,C-C3 DEPTH I06C0,C£0 F~ 3230,~86C M iiiiIliliIIiiiiiIlililliIliill LSN 28.873 CLSN 6.5~6 CURVE NaME SLSN CSSN CCL TTEN SmD rNC SSN CCL1 CN SSN mEPR CCCE 6~ C 15.3C'C 12;.192 S$MPLE 1 1 1 1 1 1 CSSN TT EN CNC CSSN UNITS CPS C=S C I?,' LBF F/MN 70~.523 I~,COO 13C.2~1 GR 29.?92 CCL 0.000 TEN 5.643 SmO 26.294 CCLI CN DEPTH 10500.000 FT 3200.4060 M LSN 61 .317 CLSN 13.810 GR 34.951 CCL C.CCO TEN -46.559 SPD 26.92C SSN CCL1 CN OEPTH 10400.CC0 FT .3169.927£ M LSN 48.320 CLSN 11.8c5 GR 32.485 CCL 0.000 T=N -31.967 SPO 26.997 SSN CCL1 CN £EPTH IO~'""O.CCO FT 3139.4450 LSN 80.293 CLSN -- ,,~.R 2 ' · 362 CCL TEN -22.C44 SPD 21.072 0 ~C 26.635 SSN CCL1 CN ,2.,EPTH 102C0.CC0 F-'T 3108.9,56C LSN 80,12'3 CLSN ,$R 25.193 CCL TEN 3.1'07 SPC M 32.~m7 0.000 26.797 SSN CCL1 CN DEPTH 10100.000 FT LSN 1~6.229 CLSN GR 28.642 CCL TEN -31.~58 SPO 2c.313 ~.CCO £6.&71 $SN CCL1 CN OEPT~ 1OOCC.CC lllIIIIIlIIlI LSN 105.400 G~ 31 .114 TEN -35.625 0 FT 304~.00~C M CLSN CCL 29.336 0.000 26.c27 SSN CCL1 CN DEPTH 9900.000 FT 3 iIliiilIIIIIIIIIlIIII LSN 57.~31 CL GR 45.260 CC TEN -!8.325 SP 017.5260 M SN 12.~69 L ~. C '3 D 26.997 SSN CCL1 CN DEPTH 9825.500 FT 29 IIIiiIIIIIIIIIIIIIiIII LSN 34.996 CLS GR ~ C~5 C~L TEN ~2.69~ SPC 94.~18C M II~IIIII N 7.277 O .~C0 SSN ~CLI~ ST~DTING DEPTH =10657.000 FT 324~.2600 M ENDING DEPTH : 9825.500 FT 2994.8180 M ** FILE TRAILER ** FiLE NAME: P~SS 2.002 SERVICE NAME: VERSZON ~ : I E~TE: ~5/11/ MAXIMUM LENGTH: 1024 FIL¢ TYPE: LO NEXT FILE N&ME: ** FILE HEADER # 3 ** C.0CC 55.1~5 2C3.17E C.OCC 32.310 187.247 C.OGC C.0CC 22.315 243 .=41 C,OCC 15.27C 257.z, 31 C .CCC 19 .OC8 251.5Cl 15.134 193.215 O.CCC 34.095 157.9£~ C.CCC a5.062 TTEN CNC CSSN TTEN CNC CSSN TTEN CNC CSSN TTEN CNC CSSN TTEN CNC CSSN TTEN CNC CSSN TT~N CNC CSSN TTEN CNC CSSN TTEN CNC 1200.156 59.185 201.640 1089.150 36.310 187.263 1093.0~3 40.399 232.597 26.315 297.242 1C7,:,. c- PC lC.27C 103~.453 23.008 262.652 1000.o06 19.134 194.441 1007.935 35.C~5 15A.o52 1~' c .~. ~:62 FILE N~ME: PASS 3°003 SERVICE NANE: VERSION ~ : 1 DATE: 85/11/2C MAX RECORD LENGTh: · 1024 FILE TYPE: LC PREVIOUS FILE NAME: ** INFORMATICN RECOROS ** BYTES MNEM CONTENTS ~ I I I APIN : 5002920_~93 CN : ARCO ALASKA, INC. WN : O.S. 7-~ FN : FRUCHCE COUN : ,NORTH S~.OPr- STAT : LCC : I 50.C0 ** F-CRN!&T ** UNITS ENTRY ~LOC~S TYPE ENTRY £ ES£RI.PTZON 4 I C EP~,S r.,EC~:E ~ S E 8 6C:.0 F R ~ E SP~CZNS 9 .lIN FR~r- SPACINS UNITS 11 19 ~XIMUM FR~M~S/R;CO~O 0 TErmiNATOR -0.500 L~V'~L ~mAC=NG~ ~ATUM SPeCIFICATiON ~-LOCKS CURVE REPR N~ME CODE SIZE SAt.!~Lz :LNITS ilmI i--I-- Ii--IIi. LSN 68 ~ 1 CPS SSN 6~ ~ 1 ~PS GR 68 CCL1 68 ~ 1 TEN 68 CN 68 4 I ** FORMAT ** CURVE NAME CLSN CSSN CCL TTEN SPC CNC R~m~ CO£E 68 ~8 SiZE S~MPLE 1 1 1 1 t 1 UNITS i i i ! i C~S CPS L~F m / MN % ENTRY ~LOC~,S TYPE ENTRY CES~RIPTION ~ I ~E~THS ~ECREASE 8 6C.0 FRA~ SPACING 9 .lIN FR~E SPACING UNITS 11 19 MAXIMUM FRAMES/RECOR~ 0 TER~'ZN&TOR -0.5C0 L:VEL .SPACING CATUM SPmCIFIC a~'ICN SLOCKS CURVE REPR NAME COD;. q[ZE SAMPLE LN'TS IImI CURVE N~NE REPR CCCE SIZE, S~PLE UN~'TS~. LSN 68 ¢ 1 CPS SSN 68 4 i CPS GR 68 4 1 CCLJ 68 ~ 1 TEN 68 & i LBF CN 68 4 I DEPTH 10656. CCn~- FT . ~z247. 955C- · M LSN 35.9C6 CLSN GR 43.~69~ CCt. O. uu TEN 253.125 SPC 1.OCO gEPTH 106GO.CCC FT 3230.8~6C H LSN 33.236 CLSN GR 34.G40 CCL TEN 22.4S4 SPD 7.525 2~.997 CEPTH. 10500.CC0 FT ~.~00.406C ,, ~ LSN 56.444, CLSN GR _~/+. ~g CCL TEN -25.397 SPC 15.317 O.COO 27.?9t CEPTH IOCOO.CCC FT 31~9.927C M LSN 49.413 CLSN GR 30.271 CCL TEN -13.12~ SPg 13.355 0.CCO 27.!01 OEPTH 10300.00 LSN 83.944 CLSN SR 20.C6~ CCL TEN -17.36S SmD C FT 3139.~46C M 21.518 O.CC0 ~ 7~7 CEPTH 10100.000 FT ~078.4566 M LSN 111.66~ CLSN 26.~29 OR 28.S~2 CCL TEN -23.101 S=g 28.£71 CEPT~ IO000.CCC 'T 3048.006C mmmmlmlmmmmlmlmlllllimmmlllmli LSN ~2.737 CL.SN Z$.159 GR 24.8~6 CCL TEN -0.339 SPD ~7,997 DEPTH 9900.CCC FT 301-7.526C M LSN ~1.857 CLSN 14,130 GR 38.407 CCL TSN 9.79~ SPD 27.997 DEPTH ,9824.560 ~T 2994.514G M mmmmmmmmmmm--.m----mmm--mm LSN 20.995 CLSN 7.975 CLSN CSSN CCL. TTEN SPD CNC SSN CCL1 CN SSN CCL1 CN SSN C"L1 CN SSN CCL1 CN SSN C"L1 CN $SN CCL1 CN SSN CCL1 C N SSN CCL1 CN SSN CCL1 CN SSN 68 68 6~ 147.'985 C.OCC 1= OCC C.3CC ~.5C~ 1=; ~7 C.0CC 32.1a3 234.185 c .occ 22.26E 2~4.a45 C .CCC 16.O~g 27C.78t C.OCC 17.53C 2~ 6~2 C.OCC 16.126 196.462 C.OCC 31.434 153.915 4 .4 4 4 4 CSSN TTEN CNC CSSN "'T:N, CNC CSSN TT.=N CNC CSSN TTEN CNC CSSN TTEN CNC CSSN TT;N CNC CSSN TTEN CNC CSSN TTEN CNC CSSN TT=N CNC C SSN CPS CPS ElM LSF F/MN 147.985 82~.517 19.000 133.661 1152.0e~ 4a.503 113C.94q 33.191 1~1.:32 1093.70o 36.183 24&.285 108e.653 2~.268 28~.207 1CS2.&6~ 2C.099 26! .261 1C~_C.292 7_1 · 262.352 1C50.750 2C.126 201.203 1055.265 3~.43c 151 .255 GR 86'230 CCL TEN 9.149 SPD STARTING DEPTH =~0656.000 PT ENDING DEPTH = 9824.500 PT 0.C00 COL1 Z8.997 CN 3247.9550 M 2994.5140 M C.OCC 52,223 TTEN CNC 1122.288 56.223 ** FILE TRAILER ** :!LE NAME: PASS 3.003 SERVICE NAME: VERSION # : 1 gATE: ~5/11/ MAXIMUM LENGTH: 1024 FILE TYPE: LC NEXT FILE NAN: *~ TAPE T~AILER TAPE NAME: SERVICE NAME: PASS 3 ~ATE: ...... ORIGIN O: OAT~: FSYS TAPE CONTINUATION NEXT TAPE NAME: COMMENTS: ** REEL TR~ZL~R REEL NAME: SERVZC: NA~E: ~ITLiS DATE : ORIGIN OF DAT~: ~SYS REEL CONTINUATION NEXT REEL NAME: COMMENTS: DqESSE~ ATLAS LIS CUSTOMER TAPE --- CREATE£ BY SDS PROGRA~ ~ 2.C RE;L HEACER - 1 TAPE HEACER - 1 ;iLE HEAC,:R - 3 INFORMATION - 3 FORMAT - 6 DATA - 266 TABLE DUMP - 3 FILE T~AILEP - 3 TAPE TRAILER - 1 RE~L TRAILER - 1 TOTAL RECORDS: 288 LIBRARY TAPE CURVE SPECIFICATIONS Company ARCO Alaska, !nc. Well D.S. 7-5 ~. Field Prudhoe Bay County, Scare North Slooe, A!~ska Curve ~ame (Abbrev.) S~andard Curve Name Logs Used Scale Casing Collar Locator CCL -~- CN : I Compensated Neutron t " 60 - 0 SSN Short Soace " ' - 50 - 550 ss~ I~ $o~ S~ce I " o - 200 , File 4 .I 1 REEL NAME : gATE : S~RViC~ NAME" ~iTL!~ REEL CONTiNUSTZON NUMBER: 01 PREVzOUS' . RmEL~ NAv;~ CONMENTS: DRESSER ATLAS LIS CUSTOWER NG,H 1=p :YTES TAPE NAME : ORIGIN : :SYS SERVICE NAM-~: PASS1 T~ CONTiNUaTION NUH~2R: COMMENTS: L~NSTH: 1=2 ~YT:S T SY SDS 1 ** F1 FiLE SERVI VERSt BATE: ~AX R =iL PRE LE HE,DE NAME: P~ CE NA~E: ON ~ : ! 35/11 12 TYPE: LC V]OUS FILE R # t ** SS1 .001 NGT~: 1024 NANE: *..,. INFOPf'cATTCN,,, , _RF~EOR'""'~,... ,..... ** EYTES MN:EM CONTENTS APiN ' 5002920293 CN :; ARCC AL~SKA~ WN : C.S. 7-5 FN : P~UOHOE SAY COUN : NORTH SLOPE STAT · ALASKA LCC : !Su.u0 ** ~ORMAT I NC. UNITS ENTRY aLOCKS TYPF~ :N~'py C¢-S CRIDTiON 3~,TUM SPECI~iC'~TiON 8LOCK. S ENTRY ~LOCKS TYPE ENTRY. C:ESrRiPT='m:''~~ ~'~,,, 4. t CEPTHS DECRE4S: ~ ~ q~ ING ~ ,,!IN FRAME SP.6CZNG UNITS 11 ~1 ,~'AX=MUM~ =~-~M~S/~=C~$~,~ '~ 0 TERMINATOR -0,, 500 LEVEL SP~C~NG '~'uATUM SP'~CIF!C~TiC~',. ,~ ~LOCKS CURVE ~EmR N~ME CODE SiZE S,~MPLE UNITS LSN 8.8 4 ! CPS SSN 68 4 1 C~S G~ 68 4 1 CCL 6f$ 4 1 T~N ~$ 4 1 S~D ~ 4 1 m/~N CN 6,~ 4 I DATA DEPTH 1066,~ ~(3 ~ uu FT 3551.613C M TEN -378~ .162, SPD, 1.con.,, ~ OEmTH 1<)~0~ COO ='T =?3O.;E:6C M LSN 22.878 SSN 116.15~ TEN 16~'. OEPTH 1A4OC.CG,.O FT 3!6g.927C ~ T~N ...... -<~9900.C!,O,'*~.. . ...~ n~PTM 103C0,Ci3r~ =T 31.5~.~,45C ~ C N 42.53e !7.67t CCL COL COL COL z 4. "' C C - ,3.4 f~ 5 7C,':, · SJO 2 TEN PO_ · 12t SP~ 31.697 C N ~..,5'~T,~ 1 01" '""' n ~ v , ., uO.uuO FT ~u7 .4b,Af' LSN 243.799 SSN 4¢4.1 40 'TEN -JO_ .136 ,.qP'"u 28.41.. i G P C N ..... ~ M C'EPTH. 1 C)',.. ~: 0 · C 0',,.:, FT3 o 4 i!!,. O04u,~ ,..~., LSN 24~..,. 6~5~ SSN 452 .4;59 TEN -10.010 S~'D 2;5.67S END.lNG C) r-P SERViC- NAME: ~ATE: ~5/1!/ P'AXZF, UM LENGT~: 1024 =ZLE TyO=: LC NEXT FILE NA~E: * l* FILE hEADER FILE NAME' P~SS2 SERVICE N&ME: VERSION :~ : 1 OATE: BS/11/~C MAX RECOR~ L~NGT~: tOP4 =~L; TYPE: L¢ PREVIOUS FiLE ** ZNFORYATZON R~CC. RDS ** ~'yTEc ¢,4N:~t C~<~ .~, u,~*ENT~. ~PiN : 50:,9~:920~3 wN : D,S. 7-5 CN : PRUSHOE :BAY COUN : NORTH ,SLOPE STAT : ~L~SK~ LCC : INC. UNITS TYP= 9 11 ENTRY ~LOCKS ENTRY t .!IN OESCRIPTZON uEP'T~ ~ECRE~CE Sm&CiNG SP&CZNG UNITS 14.,279 2~ CCL CCL 5 1 · 0 '3:2 ~,~ TUM SPECiF iCATTON E, LOCKS CURVE R[PR NAME CODE SIZE SAMPLE ~ i i-I, ,m, m,e m T E N 6 ~ 4 1 SPD 68 ~ 1 C N 68 4 1 GR ~8 4 1 LSN 68 4 1 SSN 68 4 I *'* F 0 R !,,' A T UNITS F/MN SNTRY A L'"~' K S TYPE ENTRY DESCRIPTION 4 I E:EPT~S ~ECREASE 8 6C.0 ~R~E SPACING 9 ,,lin FRAME SPACING UNITS 11 31 MSXZMUM FRAMES/RECORE: 0 TERmiNATOR .... vO LEVEL SPAC~N,¢ ION 5LOCKS ** 3 E t:::' T H, 1 ["i 5 ~ ~;.,,..-~. CC0 FT, 3 24 !i). ~":' 5 O.. M CF"· ~,L 31 F~C:O TEN 57. 543 :JR ~3 56'~ ~ SN ~,i CCL 27.C00 T=N 58.127 25.$;67 CCL 208.C30 T~N GR 31.525 LSN t04C, n ccn ~T ,~ I ,~ ,,,.,', -10.972 3159,927C p4 CCL 79.300 TEN ,SR ~6..3~4 LSN -t 06. I '3C~ 6! .t&7 S mD S SN SSk S SN S SN 11t .7C1 7'21 CN C N C N 3 ! . 8 41 34. ,5 C' 1 DEPTH ? 3 .x, 43 LSN t84,417 SeN CCL ~7 o¢,n T~N uR ,-. 7.8 ~1 LSN '-~1 -46 v 273.475 S S N ~n C~ ' ~n78 4,¢,~C r -116,707 S PO SSN ~0 ~ '.J ...... Ce r'~ b ~ ' ,~L · T~N GR ~Z, .6t 1 LSN S P D SSN nEPTH ¢~9~n ~nO =T ;029,261C M ~CL u. CCO TEN ~ 1-~0,.~ 51 LqN ~ C8 ** ~IL= TR~!LER ** =ILE NAME: P/~SS2 SERVICE NAME: VERSION = : ! D~TE: 85tt!I M AXit,!bM LENGTH: 1024 miLE TYP~: LC NEXT FILE ** ~ILE HEADER # 3 ** FiLE NAME: P~Sq3.. SERVICE N~ME: VERSION # : t D~TE: S5II1/20 MAX RECORD LENGT~: 1 024 ~ILE TYPE: LO PREVIOUS FILE ** INFORMaTiON RECORDS ** EYTES MNEM CONTENTS aPiN ' c9 20~93 ~ ~C ,~N F N : m ~ iJ ~ H n ~ COUN : NORTH SLC~ STAT - aLASKA L C C : I S 9. l N C. UNITS E~N~TRY BLOCK.S 415.974 2g.12C 488.61~ r oct ~0! C.OCC ~.~.61q CN CN C N 13.555 ~ .771 5 TYmE: .-_NT~-Y, ,, ~ ~rESCRIPTiON 9 tl ~TUM 6C,0 ~RA~E S~ACZNG ,,lin ~R~aM~ SP.ACZNG UNITS ~1 ~XZ~UM ~RAM~StRECCR© TERNiNATOR -9,500 LEVEL SP~CING SP:CIFtC~T]ON~ aLOrKS,~ CURV~ REPR NAME COOE SIZ~ SAMPLE bN!TS LSN ,58 4 ! CPS SqN :5a / 1 CPq S R 6 ,~ a I A ~i ~ L, ,_ ,68 a. ! ~ ~ M TEN 68 4 I L6F SPD ~;8 4 I F/MN ~ N ~8 4 I ~'~ ENTRY BLOCKS TYPE ENTRY CE:SCRIPTION 4 I n~PTHS :~ -6C,0 FRAME SP~CZNG 9 lin FP~N:E S~ACING UNITS 11 ~! ~$XIMUM ~q T:R~IN~T~R -O.~O0 LEVEL .SP~CiNG ~,~TUM SP~'~I~Ir~TiON ~LOCK. S ~,URV~ N~ME CODE SiZE SAMPLE bNiTS L S N 6 ~ 4 t C e ~ S S N 6 8 4 I C ~ S G~ 68 4 ! C C L 6 ~ 4 I O ~ M TEN 68 4 1 LBF SnD ~8 4 t f/MN C N 6 8 4 1 ** DATA ** Of.o~H 1()661.C00 ~T '~"' . ~' , .,/,,+9 479C M LSN ~6.9g7 SSN TEN 45.795 SP~;;., I . C c! O FT 3230. 895C L SN -'~7. 079 SSN TEN 162,4~4 S:~9 O~PTW 1 95r ~n LSN 68.659 SSN T ~k~ 6 O, ~: OFi S mn 2 ! 9.3 ~ 7 P S , '< 'X ::~ G R C N OR 1 C]. [~121 44t OC ] CCL CCL CCL TEN -?S ~13 Sm3 '2, 419 S~ S R FN BERTH I~.~~ ~ ...... 60 ~'~ uuuu. CCO ,=T, 4:~x..uu i I ! I LSN 403.167 SSN 599.463 T~N 39.117 SPO 29.297 DEPTH 9~!.5~: FT 3~0,t7¢r *' LSN 375.8~1 SSN 592.C51 T~N 7.~3! SmO .~T:ARTING ~ DEPTH. =106~3.!.©n0,~, .:T ~'i,.~O~NG' . u,~';~H.~ ~ = 9941.500 , 3247.4790 M 3030.17Sn~ ,. M ** =ILe TRAiLeR FiLE N.~n~E: PfiSS3 SERVICE NAME: VERsiON 3ATE: 85t11/ MAXIMUM LENGTh: FILE TYPE: LO NEXT FILE 10Z4 ** FILE H~ADER # '~ ** FILE NAME: SErViCE N .... ~: V~RSION # · I .~AT~: :~5/11t~ MAX R:~CORO ~ EN~T~-_ ,.~ .... 102~ FZLE T~PE1 LC pReViOUS FILE NAME: ** INfORMAtiON RECORDS ** 5YTES M N E,.,4 rON~,NTS ~. , :, ,,~ .: ~ ,m ~ ,i, ~ .~ ~ ~ .&~'ZN = 5nn~9~O29~ CN : ~CC ~L~SKA, ZNC. WN : O. S. 7-5 FN · P~',UB~.S~. ~.~Y uOgN : NORTH SLOPE STAT : ALASKA L~C~ : I FO. 03 ItNTT.S i ! I I I ** FORMAT 12.824 26.74= 1 1. S3c ~4 10.6C8 1',3. I 51 37.342 '-CL CCL CCL CCL CCu 1 ,?, .'" · S :3 ,q BLOCKS 8 ENTRY TYPE ENTRY 9 .1 IN 11 31 50,3 DATUM SPECIF D~PTHS DECR FRAME SPAC! FRAME SP~CI ~XiFiUM FR~,, T,ER~ IN,TOP: LEVEL S$~CZ NG NG UNITS ~ES/RECSR~ ICATION ~LOC~,S UNITS ~PS CPS Lm:F- F / H N ENTRY 8LOCKS TYPE ENTRY CE.SCRiPTION 4 ! E;EPTMS ~CR ~ 6C.0 FR.&NE SDACI 9 ,,lin F R,&F ~ S~Ar=- : ~ ~ '~' ' EVEL ~P$CZ NG NG UkiTS NG DATUM SPECEFIC.'~TION ~LC:CK, S ** gAT& ** LSN ~7.997 SSN t54.989 G~ C CCL C N ~.b _. FT S16:* 02 ~ ~' i TEN -~7.2'38 S~D GR DEPT~ tc'=Cn " ~' FT ~1~ 446C N,: LSN 56.967 SSN 17.023 CN nEPTH~ IOPOO_ .u:"CO FT 310~.:.. ~'660, M LSN ~'~ ~' ..... ~)1 SSN T2N -35.245 SPD 16.998 GR CN g~PTM_ ...... ,, 1010~.,.CO0 =T~ ~07~.4~',6~,. ~ M LSN '~9.96! SSN 54! .2C~ 17.204 GR C N 53.0.45~. 17 47~ GR DEPTH 9~30 5C~'' FT ~'26 ~23C N~ LSN 133.850 SSN TEN -39.'~ ,~5 SPO i 7.52 ~ STARTING DEPTH =1066~.000 =T r---NDiNC,,. S.~p,, , ,~ = 99'~v,., . 500 ='"', 3251,0£:30 ~0:''~ :~: Z 30 ** mILE FiLE NAME: SERVICE VERSION # : D~TE: ~5/ M~XIMUM LENGTh- FILE TYPE: LC NEXT $1LE NA~E: iLER P~SS4 ,00* E: 1 11/ I02~ ** FILE HEAOE FILE NAME" PA V~RSICN # : ! DATE: ~5/11/2 MAX ~S02D LE ~!LE TYP~: LC PREVIOUS FILE R ~ 5** SS5 1024 BYTSS ** iNFOR~ATiCN RECORDS MN~M CONT[~ TS APiN C N ~N : ARCC : O.S. 7-5 : P~U0~0~ i N C. UNITS 1CC .GCC :25 · 83 ~ r~ lrC.OC~. 1CC.OCC Z6.172 7g · ~ C '.:,. 7 ..,.17u 47.4r .: ~CL CC~ CCL CCL CCL 2 .'~ 1 . C 0 59 $7.~OO .9 LCC : 150,00 ENTRY ELOCKS TYPE ENTRY unESCRIPTiON ~ I CEPTHS DECREASE 9 ,,!i*~ 'RAME SPACING UNI~ ~ ! 1 ~1 ~.~X~MUM.. ~ FR~M~S/~ ..... ECOR3 O T ERF~iNATOR -O.. =CO LEV~ ~pAC~N~ ~.ATUM SP:CTF-ICaT~ON ~L~rKs CUmVE N'~ME CCDE SiZE £.&MPL E UNITS L.SN ,58 4 1 CPS CCL 68 4 I 5IF Tc~ 6~ 4 1 L;F SPO 68 4 I F/MN C N 6 8 4 " I ** =CRMAT ** ENTRY BLOCKS OATU"m S;):CI:"CATiC, N, ,~.. , ;. =,LOCKS. CURVE ~EPR ,,~. ,' ,-,n F- ~iZE SAMPL~ UNiTq LSN 6~ .~ 1 CPS SSN 68 4 1 CPS rCL 6g 4 i T E N ~ $ 4 1 L ~ F C N 6 8 4 ! O~PTM 1057& Cuu ~=T 325~.~,~.2C: M t ¢-N 2~ 9c7 S~N TEN 207,57~ SPr. I r N ,~, 322 I=1 CCL z ,,. r, ,] in 10 TEN t9.751 DEPTH SPD FT 3200.4060 M LSN AO t~9 TEN -13.5~9 DF-~T~ 104n0.r'mO SSN SPD FT 3169.927C M 5-~ .47t TEN CEPTH L S N a .2. ~ 11 T~N, -3~_,, · 64t r, EPTM 1 u 2,., O. C:G,.~ SSN 194.71 7 t7.721 FT 31 39.446~ M S SN FT 3108.~6a0 M LSN 183.275 TEN -~,1 I =3 ~=PTH 1~,1u0 Cuu SSN 401 . 86! 17.458 ST 307~ 4~60 M S R C N · ., .N GR C N 3 R C N LSN 90.447 SSN TEN -35.1~3 SP9 17.822 GR CN DEPTH 10C, 00.C00 FT 30~B.0060 M LSN g'~.965 SSN TEN -~,"'t8 SmD 539.248 17.519 OEPT~ 9¢2~.500 FT 3024.3840 M LSN 0 COn SSN T~N O.C00 SPD STARTING O~PTH :10574.000 FT 3253.4,420 M E ND T NG,.,. ,.,,,"'" 5 P T H, = Q~22.:r;., .., L..', .... h T ,.,q '" ") ,&u ,... . ~ r.,, '4. 0¢ ~: ,M, ** FILE TRAILER ¢'ZLE NAME: ,~ASS5 .095 SERVICE NAME: VERSION # : ! DATE: 95/!1/ M~XiMUM LENGTH: 10~4 FILE TYPE: LO NTXT FILE NANE: ~ZL= N~Nt~ r.:' a,S S 6 S~PVICE N~ME: V~RSZON ~ ' DATE: ~11!t~C '~AX RECORD LENGTH: 1024 FILE Tym~: LC FR~VIOUS ~ILE ** =NmORM*~ -¢¢. ,~ION Rt~vRDS ~ . 50.1&7 31 .'~rT,. 31.771 23.~CI ~,5.1C4 '25 17.7~ 34 ..5~4 ..-, CCL CCL CCL "CL CCL ,CC L 3 ¢. C; O ,3 i 71 . .) "" © ,,. L., C.C'OC II WN FN COUN STAT LCC FORMAT T NC 12 TY~E m mm m 0 tATUM ENTRY F.:: L 0 CK S ENTRY OESCRiPTiON t DEPTHS DECREASE , .0 FRA~'= qP&CZNG ,.lIN ~.m...a. NE SP,~CING UNITS ~1 ...... ~:&XIMUM ~RAME~/RE~vRn TERPZN&TOR -0.¢~00 LEV~- .SoACiNc, ,~ SPECT~CATION.~. ~ . ~LOCKS~ CURVE REPR NAME CODE SZZE SAMPLE bNITS LSN ~8 ~ 1 C~S qSN ~ 4 I C~ ~,~R 6g 4 1 ,SCL 68 4 1 T E N 6 ~ 4 I L ~ F S PO 68 ** ~ORMAT ** ENTRY ~LOCK..$ TYPE ENTRY DESCRIPTION llml fi, ilI llllltllmltlillllml 4 I ~=~TH~ B:CREASE ~ ~C,O ~RAME SP~CING Q .I!N P~2ME SP~CING UNITS 1! $1 MAXIMUM FR~MES/RECORO 0 TERMiNaTOR u.)Ou LEVEL SPACZNG ~AiUM SD=CTFIC~TiCN BLOCKS CURVE N ,& ,~.~ ~. ton' SIZ~ SAi'4PL F- LSN 68 4 I CPS SSN 68 4 I Cmc :SR 68 4 1 ~Pl ~CL ~ 4 1 OlM TEN 6~ 4 I L:F CN 6 .,,a DEPTH 10'~7 r";PTH 10('_0"',7m~' · , ........ ,,.., FT ~?~'0. ~6~ LSN ~3 7n7 SSN I "" ~ I'EN 72. gO."f 'S:O ~ -, t,,} 6 F,...,; .. ::5 S N 1 ,s 9. ~ .:' o SEPTH lO&cC rCr~ FT 316~ 97.7C ~,'~ L S ~",,; 59 · I .5, 5 S S !,4 1,97 · t 67 TEN -44,.152 SPD 17. g 5..,5 C=pT~ 10=0C C:'3~ FT x1:39 44~,c M L S."4 ~1 · 746 S SN ? 35 · 662: TEP',~,. -~_ ·7",9 SP3 !7.~*~.,, 3EP''r~,,, 13~Cn:.. ,.,·CuC. ,=':": 5tno.966C., ,M~ 413.1fis 1 L S N '3 · C C ;3 S S N C N GR C N C N GR :5 R CN C N ** F--iLE TR&!LE~: FiLE ,;=RVT,'"E I',~&;~E: ~ _ ,. ~. VE~S2CN C:~TE: ;~5/11/ ~' ~ X T ~ J ;4 L E N 'o: X: I 32 4 F~LE TYP~: NEXT ~IL~ N,&~E: ** T~F=- TR~ILF-'P. ** $~2ViCE N~ME: PASS6 3~TE: C.:2ZGit,J CF 9'A"r¢,: FSYS TAP::: CGNTIIx]UC, TI:3N = : ,? 1 4~ '45.171 ]! .7z, 2 42.8t~ :1 87~ 25.051 ,,': 4.. 7117 0.0CC O.OCC ,SCL CCL CCL CCL CCL CCL CCL '~CL '~7 OOS 4 C, 39. 1 22.000 x 7. C :39 C, 00 !3 ** PE~L SE~VZC DATE EEEL N~XT FILE i N F 0 3AT~ T~SL~ FiLE ~E2L E N~ME: ~!TLIS Q$ mATA: :SYS ONTINu~T~ON ~ EEL NA~E: TS: ~:R:SSE~ E~ER - ~ , f~ & T [ C N - T - TRAILER TR~!LE~ T~&;LER : Cl LIS CU STCMER CRE~TEO 5¥ 14 TOTAL LIBRARY TAPE CURVE SPECIFICATIONS Company Arco Oil & Gas Co. Well DS 7-5 Field Prudhoe Bay County,S~tate North Slope, Alaska Date 10-30-80 Curve Name (Abbreviated) Standard Curve Name Logs Used Scale GR1 Gamma Ray Pass 1 ,. CN/MS 0-100 SS1 Short Space Pass 1 CN/MS 0-2000 LS~ iLong Space Pass 1 CN/MS 0-2000 NEU1 Neutron CN/MS 60-0 · , GR2 Gamma Ray Pass2 CN/MS ,,0-100 SSI Short Space Pass 2 CN/MS 0-2000 LS1 Long Space Pass 2 CN/MS 0-2000 NEU2 !Neutron Pass 2 CN/MS 60-0 ,, ,. , , , , PR~OF~OF BAY ..... ~,IORT!4 SLOmE,ALi~RKA dL~C G~,.55 ~~ ATI..A~JTIC R~CH;'IFL9 C9.- .... O,S. 7-5 PF~I~r~M~F' BAY ..... h~ORTW SLOaLE,AL&S,(/~ ~L&C 3~,.TA ~uFRY I SA~PLES qSOf~.SO 52.~2 ~50.93 /002.9~ 34.01 60.79 93~.fi6 1.004.15 ~3.10 "'"""": ................. '5"~:"~':'??"::~"~' .......... :"':::: ""';~=~':""'c'T' '"": '- "~'~;">::-=':7::'F":':";'::'""im:;5'"?':F;:~;",::':~" :'"':'"'":":~"~;::'A~::}:'-"~;"~'~':' ............ "'~"~- ................. ~ ........................... q ~ 7 ....... ~ ..... ~'~ ............................ 9501.50 ~.~ 941.1~ 100~.93 3~.23 R~.~9 9~3.~fl 998. 0~ 3~.0B ........ L.......:...~. 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LIS TAPE VERIFICATION LISTING VP 010.~02 VER!FICATIO~ [iSTiN~ P~$E 1 -,- R'-~L HEADER '~'"' ERVICE NAME :EDIT ,ATE ~86t12/14 R!GIN : EEL NAME :72111 ONTINUATION ~ :01 REVIOUS REEL : OMMENTS :LIS TAPE, ARCO PRUDHOE BAY [,.S. 7-5, APl 50-029-20293 * TAPE H~AD=R '-'- ERVZCE NAHE :EDIT ATE :86/12/14 RIGiN :FS1A APE NAME : .ONTINUATION ~ :01 'REVIOUS TAPE OMMENTS :LIS TAPE, ARCO PRUOMOE BAY DoS. 7-5, API 50-029-20293 :'"-,. FILE HEADER .... ~--.' :ILE NAME :EDIT .001 ;ERVICE NAME : ~ERSZON ~ : )ATE : IAXIMUM LENGTH : 1024 :ILE TYPE : 'REViOUS FILE : ,-,- INFORMATION RECORDS "'"' ~NEM CONTENTS :N : ARCO ALASKA, INC CN : O.S. 7-5 :N : PRUDHOE BAY ~ANG: 14E FOWN: llN ~ECT: 33 :OUN: NORTH SLOPE ~TAT: ALASKA :TRY: USA 4NEM CONTENTS ORES: E COMMENTS -' .... UNIT TYPE CATE SIZE CODE 000 000 016 065 000 000 008 065 000 000 012 065 000 OOO 004 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 003 065 UNIT TYPE CATE SIZE CODE 000 000 001 065 VP 010.M02 VERIFICATION LISTING PAGE : SCHLUMBERG ER ::: : ALASKA COMPUTING CENTER '~: OMPANY = ARCO ~LASKA INC. 'ELL = D.S. 7-5 :IELD = PRUDHO5 SAY OUNTY = NORTH SLOPE BOROUGH 'TATE = ALASK~ lOB NUMBER AT ACC: 72111 'UN ml, DATE LOGGED: 08-DEC-85 .DP: RICK KRUWELL 'ASING 'YPE ~LU!O = 9.625" ~ 10736' = SEAWATER }OTE: CHANNELS WITH THE EXTENSION PS1 ARE FROM LOG PASS CHANNELS WITH THE EXTENSION PSi ARE FROM LOG PASS VP OlO.HO2 VERIFICATION LISTING P4GE 3 SCHLUMBERGER LOGS INCLUDED WITH THIS MAGN£TIC TAPE: ~',-' COMPENSATED NEUTRON LOG- CASED HOLE (CNL 2 P4SSES) ".~ GAMMA RAY LOG (GR) :~.. .,- --~ DATA FORMAT RECORD ~-;~ :NTRY BLOCKS TYPE SiZE R"PR CODE ENTRY 2 .l 66 0 ~ 1 66 i 8 4 73 60 9 4 65 .liN 16 1 66 1 0 1 66 0 ]ATUM SPECIFIC~TigN BLOCKS qNEM SERVICE SERVICE UNIT API API API API ~iLE SiZE SPL REPR PRO~CESS VO OlO.H02 VERIFICATION LISTING P~AGE 4 ~D EPT R PS1 PHI RAT NRA PS1 CNL PS1 CNL PS1 ENS PS1 R PHI PS2 RAT PS2 NRA PS2 CNL PSZ 'CNL PS2 ENS PS2 gRDER ~ LOG TYPE CLASS NO FT O0 000 O0 0 G~APi O0 310 01 0 FU O0 890 O0 0 O0 420 O0 000 O0 0 CPS O0 330 31 O CPS O0 330 30 0 L~ O0 635 21 0 GAPI O0 310 Ol 0 PU O0 890 O0 O O0 420 O1 0 O0 000 O0 0 CPS O0 330 31 0 CPS O0 330 30 0 LB O0 635 21 0 .,NO. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 CCOE (3CTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 O0000000000OO0 68 00000000000000 68 00000000000000 68 O0000000OO0000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 58 00000000000000 68 00000000000000 68 00000000000000 ~EPT :NRA ;R ICNL 10700.0000 3.9473 -999.2500 -999.2500 )EPT ~NRA ;R ICNL 10600.0000 3.6074 24.8125 1471.0000 )EPT ;R ICNL 10500.0000 2.9238 21.5313 1795.0000 )EPT :NRA ;R tCNL 10400.0000 2.9336 20.9531 1733.0000 )EPT [NRA ;R ~CNL 10300.0000 2.6992 11.5000 2248.0000 )EPT ~NRA ;R ~CNL 10200.0000 2.3359 16.1562 2404.0000 )EPT ~NRA ;R ICNL 10100.0000 2.0215 17.6875 2186.0000 GR NCNL NPHi FCNL GR NCNL NPHI FCNL GR NCNL NPHI FCNL GR NCNL NPHI FCNL GR NCNL NPHI FCNL GR NCNL NPHI FCNL GR NCNL NPHI FCNL 61.8437 1507.0000 -999.2500 -999.2500 25.3750 1449.0000 36.7676 373.7500 19.2969 1'711.0000 24.8047 560.5000 20.9844 1790.0000 28.9062 560-5000 11.7344 2192.0000 18.0664 855.0000 14.1875 2544.0000 16.2598 1073.0000 16.10'94 2144.0000 14.7949 931.0000 NPHI FCNL NRAT TENS NP'HI FCNL NRAT 'TENS NPHI FCNL NRAT TENS NPHI FCNL NRAT TENS NPHI FCNL NRAT TENS NPHI F:CNL NRAT TENS NPHi FCNL NRAT TENS 41.3574 381.7500 -999.2500 -999.2500 34.3750 391.7500 3.4219 3270.0000 25.8789 530.0000 2.7637 3290.0000 28.6621 513.5000 2.9883 3290.0000 18.6035 835.5000 2.3574 3244.0000 15.1855 1119.0000 2.2285 3164.0000 11.47:46 1057.0000 2.1250 3090.0000 NRAT 3.6699 TENS 1825.0000 RNRt -999.2500 NRAT 3.2871 TENS 3254.0000 RNRA 3.4785 NRAT 2. 8242 TENS 3250.0000 RNRA 3.0762 NR~T 2.9'766 TENS 3240.0000 RNR.& 3.0859 NRAT Z.3906 TENS 3214.0000 RNRA 2.6055 NRAT 2.1543 TENS 31150.0000 RNRA 2.2441 NRAT 1.8750 TENS 3180.0000 RNRA 2.1016 VP OlO.HO2 VERIFICATION LISTING P~GE 5 EmT lO000.O000 GR NRA 2.4551 NCNL R 19.9844 NPHI CNL 2270,0000 ~CNL EPT 9900.0000 GR NRA -999.2500 NCNL R 26.2187 NPHI CNL 1691.0000 FCNL ,EPT 9800.0000 GR NRA -999.2500 NCNL ,R 63.8125 NPHZ ICNL -999,2500 FCNL IEPT 9700.0000 GR 'NRA -999.2500 NCNL ;R 57.1250 NPHi iCNL -999.2500 FCNL )EPT 9800.0000 GR :NRA -999.2500 NCNL ;R 53.3125 NPHI tCNL -999.2500 FCNL )EDT 9599.3000 GR ~NRA -999.2500 NCNL ;R 46.5313 NPH! ~CNL -999.2500 FCNL 17.2813 2280.0000 13.2813 1054.0000 -999.2300 -999.2500 29.2969 5~0.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 NPHi FCNL NRAT TENS NPHI FCNL NRAT TENS NPHI FCNL NRAT TENS NPHI FCNL NRAT TENS NPHI FCNL NRAT TENS NPHI FCNL NRAT T~NS 14.4531 1068.0000 2.0137 3080.0000 -999.2300 -999.2500 3.0078 3104.0000 -999.2500 -999.2500 -999.2500 2974.0000 -999.2500 -999.2500 -999.2500 3100.0000 -999.2500 -999.2500 -999.2500 2904.0000 -999.2500 -999.2500 -999.2500 2920.0000 NRAT TENS RNR~q NRAT TENS RNRA NRAT TENS RNRA NRAT TEN S RNRA NR~T TENS RNRA NR~T TENS RNR A 2.0996 3064.0000 2.1621 -999.2500 -999.2500 3.3027 -999.2500 -999.2500 -999.2S00 -999.2500 -999.25 O0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 :~',~ FILE TRAILER :ILE NAME :EDIT .001 ~ERVICE NAME : fERSION # : )ATE : ~AX!MUM LENGTH : IOZ4 :!LE TYPE : ~EXT FiLE NAME : ..... 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IEPT 10700,4160 CCL tEPT 10600,2500 CCL )EPT 10500.2500 CCL IEPT 10400,Z500 CCL )EPT i0300.Z500 CCL tEPT 10200.2500 CCL ~EPT 10100.Z500 CCL )EPT 10000.2500 CCL tEPT 9900.2500 CCL )EPT 9800,2500 CCL )EPT 9700,2500 CCL )EPT 9600,2500 CCL )EPT 9599.,5000 CCL 0,0093 CCL -0,0552 CCL -0,0972 CCL 0,0327 CCL -0,0498 CCL -0,0186 CCL -0,6960 CCL 0 , O 283 C C :L -999,2500 CCL -999,2500 CCL -999.2500 CCL -999,2500 CCL -999,2500 CCL ,-,- FILE 'TRAILER ~'"' :ILE NAME :EDIT ,002 ;ERVICE NAME : fERSION ~ : )AT:~. : ~AXIMUM LENGTH : 10Z4 :ILE TYPE : ~EXT FILE N:A~E : ~NT~Y 0 1 10 ,lin I 0 SiZE SPL 4 1 -999,2500 0.0386 0,0166 -0,1299 -0,0713 -0,1445 -0,1382 0.0239 0.0166 0,0205 0.0596 -0.0132 0.0176 ~,, , CO~ ~ uE 68 68 68 PROCESS (OCTAL) 00000000000000 00000000000000 00000000000000 Va OlO.H02 VERIFICATION LISTING PAGE 7 ~ TaPE TRAILER ~: ERVICE NAME :EDIT ATE :86112/14 RIGIN :FSIA APE NAME : ONT!NUATION ~ :01 EXT TAPE NAME : OMMENTS :LIS TAPE~ ARCO PRUDHOE BAY D.S. 7-5~ Aml 50-029-20293 :~'- REEL TRAZL,=R '"~' ;ERVICE NAME :EDIT )ATE :56/12/14 ]RIGIN : IEEL NAME :72111 'ONTINUATZON ~ :01 ~EXT REEL NAME : ~OMHENTS :LIS TAPE~ ARCO PRUDHOE BAY D.S. 7-5:~ APl 50-029-20293
