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Home My WebLink About201-0027. 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 and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU C-05A Tubing Swap Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-002 50-029-20126-01-00 12987 Conductor Surface Intermediate Tieback / Liner Liner 8994 80 2660 9879 11667 2089 12926 20" 13-3/8" 9-5/8" 7" 2-3/8" 8999 21 - 101 20 - 2680 19 - 9898 18 - 11685 10896 - 12985 21 - 101 20 - 2680 19 - 7590 18 - 8873 8307 - 8995 Unknown 2670 4760 7020 11780 None 4930 6870 8160 11200 11708 - 12920 4-1/2" 12.6# L80 / N80 17 - 11076 8889 - 8999 Structural 4-1/2" HES TNT Packer 10723, 8186 Stan Golis Sr. Area Operations Manager Wyatt Rivard wrivard@hilcorp.com 907.777.8547 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 0028286, 0028305, 0028310 4-1/2" BOT Packer 17 - 8434 10996, 8377 N/A N/A 478 643 27398 3744 554 2055 1200 1580 850 713 321-128 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2021 Submit Within 30 days or Operations Sr Res Eng: 10723, 10996 8186, 8377 By Samantha Carlisle at 9:49 am, Oct 13, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.10.13 09:25:26 -08'00' Stan Golis (880) RBDMS HEW 10/13/2021 MGR15OCT2021 DSR-10/13/21SFD 10/13/2021 ACTIVITYDATE SUMMARY 3/25/2021 T/I/O = SSV/400/150/0. Temp = SI. PPPOT-T (PASS), PPPOT-IC (PASS) (Pre RWO). PPPOT-T: Stung into test port (600 psi), bled void to 0 psi. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 250 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (300 psi), bled void to 0 psi. Unable to pressure void above 500 psi. Torqued LDS to 600 lb.ft. Still unable to pressure test void above 500 psi. RU PKG gun to Hoke valve on PKG port. Pumped plastic packing to re-energize Y seal. Pressured test void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 4/22/2021 ***Pollard Eline 306*** Job Scope: Tbg Punch / Tbg Cut - Pre Rig RIH w/ 1.56" x 3' Tbg Punch Gun ( 6spf / 18 holes / 0-degree Phase). Correct depth to top of SSSV-Nip. Count Tbg joints while Rih. Count a total of 294 full joints below the SSSV-Nip. Lightly Tag WRP at 10886' corrected. Punch Tbg at 10823' - 10826' ( ~ 3' above Collar in Joint 293' below the SSSV-Nip). Had good indication. Pre Punch T/I/O = 650/650/150. Post Punch T/I/O= 700/500/150. Pooh. All shots fired. RIH with 2.5" OD Radial Cutting Torch (RCT) for 4.5" casing. Tied in the same as the tubing punch run, tagged WRP at the same depth. Fired torch and cut the pipe @ 10843', mid joint, 9.9' CCL Offset, CCL Depth 10833.1'. Good indication on shooting panel that torch went off, no weight change and no pressure changes. T/I/O before 150/300/150, T/I/O after 150/300/150. At surface, tools indicate torch went off. ***Job Complete*** 4/22/2021 T/I/O/OO = 250/350/110/0. Temp = SI. T & IA FL (E-line request). No AL. TBG & IA FL @ surface. E-line in control of well upon departure. 09:30 5/12/2021 T/I/O= 136/172/115 CMIT TX IA (Pre-Rig) MIT T to 2500 ps (Max Applied 2750) ***PASSED*** Pressured TxIA to 2750 w/4.8 bbls DSL. TxIA lost 27/30 psi 1st 15 min., Lost18/19 psi 2nd 15 ,and 16/15 3rd 15 min. for a total loss of 61/64 psi in 45 min test. Bled ~4.6 bbls back. Tags hung on WV, IA SV W V SSV= closed MV open CVs OTG FWHP=129/179/116 Pad Op notified on departure. 5/17/2021 T/I/O/OO= 400/300/125/0. LRS unit 72 Circulate Well (RWO EXPENSE). Pumped 150 bbls of 140* F 1% SKL Water into the IA while taking TBG returns to the Flowline. Pumped 82 bbls of diesel into the IA. U-Tubed TxIA for 1 hour. Freeze protected the Flowline with 6 bbls of 60/40 MeOH and 15 bbls of diesel. Final T/I/O/OO= 0/0/130/0. 9/3/2021 Circ Out (RWO EXPENSE) Pumped 100 bbls 140* 1% KCL down IA taking crude returns from Tbg to open top tank. SV,WV,SSV=C MV=O IA,OA=OTG 9/5/2021 T/I/O= 190/40/112 Circ Out (RWO EXPENSE) Pumped 100 bbls 115*F 1% KCl down IA taking crude returns to open top tank. FWHP's=80/180/150 Pad Op notified of well status upon departure. 9/7/2021 Circ Out (RWO EXPENSE) Pumped XX bbls 100* 1% KCL and 50 bbls 100* DSL down IA taking returns from Tubing to OTT. U-Tubed diesel from IA to Tbg for 1 hour. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG Daily Report of Well Operations PBU C-05A Daily Report of Well Operations PBU C-05A 9/10/2021 T/I/O/OO = 0/0/0/0. 0 psi on CCL and Bal line, 0 psi on tubing hanger void. WS remove adapter & tree, H BPV profile washed out. 4-1/2 Hydril lift threads washed out. Plug ½¿ NPT CCL and Bal line ports on tubing hanger neck. Tubing hanger is 11¿ landed in 13¿ false bowl. LDS out 3-1/4¿ to clear 11¿ tubing hanger, LDS out 4- 1/2¿ to clear false bowl, all functioned freely. Clean ring groove, install BX-160 ring gasket. WS nipple up BOP, rotated clockwise 2 bolt holes off two hole with hydraulic fittings to the back. RDMO 9/10/2021 T/I/O/OO = 0/0/0/0. ND 13-5/8" x 7-1/16'" 5M McEvoy THA & 7-1/16" 5M CIW tree. Install new BX-160 ring gasket. Wellhead tech function LDS's & plug C&B lines. NU 13-5/8" BOP's. RDMO. 9/11/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Move equipment from D-Pad to C-05. Mobilize rig from D pad to C-05. Spot rig and equipment on location. Rig up operations. 24 hr BOP test notification given 9-10-21 5am, AOGCC rep Brian Bixby waived witness. Complete RU operations. Shell test BOPE. Make up 4-1/2" test joint. Conduct 1500 psi Rolling test per the sundry & Variance request. Testing against CIBP at 10,862'. 1 fail pass on choke valve #8, grease valve. RU to reverse circulate wellbore. ...Continue WSR on 9/12/21... 9/12/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Reverse circulate 50bbls of Baraclean followed by 400 bbls of 1% KCL, 3.5bpm/450psi. RU handling & floor equipment. Discuss wellcontrol while pulling hanger. Make up Joint of PH6 to the BOT spear w/ 4" grapple. Verify well pressure. Bleed IA psi to flow back. Spear hanger and pull free at 120K. Verify free from cut. Run back in and re-land in attempt to pull false bowl with hanger. Able to pull hanger and false bowl at the same time. LD two full joints. Control line slipping thru the clamps, causing encapsulation to fall off. Cut and secure control lines at connection. Make up Test plug and RIH to land. Xo below the hanger stacked out in the 7" INT casing. Send XO to machine shop to be turned down. Rig crew testing choke valves and strapping completion. MU Test plug and Land. Run in lockdowns. Replace choke valve #8 - inline rebuild. Grease all valves. Start BOPE Test, 250psi low / 2500psi high per Sundry. BOP test notification given Sep 11, 2021, at 5:40 PM, AOGCC rep Brian Bixby waived witness. Complete BOP test. BOLDS & pull test plug to rig floor. ...Continue WSR on 9/13/21... Daily Report of Well Operations PBU C-05A 9/13/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to pull test plug to rig floor. LD same. RD 2-7/8" elevators & RU 4-1/2" elevators. RU shieve & air spooler for control & balance lines. Pull 4-1/2" N-80 CSH tubing w/ control & balance lines (encapsulated). LD 8 jts of tubing & control lines cease to move. 10k OP, setting down. RU to circulate the long way. Secured end of control lines to elevators and pulled two more joints (10 total) All rubber encapsulation is peeling off below surface. One control line broke. Band both to tbg, circ 3.5 bpm @ 475 psi w/ returns to birdbath. Tiny rubber pieces in returns. Move pipe up and down while circulating. Did not recover any rubber or clamps. Continue POH pulling control lines w/ tugger. Both control lines broke @ 434' . Cont. POH w/o control lines. Circulate periodically to birdbath..On Joint 52 PUW-88K , PU to 130K , ~45k over string weight. Will not move up. Work string back down stack 50K to get string going back down. Work pipe in attempt to work obstruction free. Re-set rig jacks. Continue trying to work free. RU TIW, head pin & kelly hose. Forward circulate 30spm/1034psi & work pipe down - no movement. Reverse circulate 25spm/1300psi. Work pipe down - success. RU & run 4.5" 12.7# CSH tubing back in hole. RU & RCBU 130spm/1034psi pumping 50bbls of 0.25ppb viscosified KCl w/ 1% 776 & 1% safelube. Followed by 1% kcl from upright taking all returns to open top tank. ...Continue WSR on 9/14/21... 9/13/2021 RWO: BO LDS to 4-5/8" Spear hanger and pull free at 120K. False bowl came free with tubing hanger, but hung up it stack & started to come off. MU lift rods to false bowl secure with tugger lines and pull to RF with tubing hanger. Cap two control lines & lay down false bowl and tubing hanger. LD two full joints, cut and cap control lines and band to tubing. MU test plug to tubing string & land 2-1/4" high, crossover stacking out on 7" pack off bushing. Turn down crossover at machine shop, re-land test plug, run in LDS 4" Stand by for BOP test & back out LDS to 4-5/8" pull LD test plug. TS NORM tubing hanger and false bowl, deliver to TSB. RDMO. 9/14/2021 ***TB BIRD RIG JOB*** ( TBG CUT ) RIH W/ 2.5" RCT BHA. CORRELATE TO TBG TALLY 12-30-1977. RCT CUT TBG ABOVE SSSV NIPPLE @ 2094'. CCL STOP DEPTH = 2080.2', CCL TO CUTTER = 13.8'. GOOD INDICATION OF TBG BEING CUT. RIG HANGING WEIGHT DECREASED. ***RELEASED FROM RIG / JOB COMPLETE*** Daily Report of Well Operations PBU C-05A 9/14/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to RCBU. RD kelly hose. Flow check well. MIT casing 1500psi for operational integrity - pass. RU e-line unit. Cut tbg 10' above SSSV nipple @ 2094' MD. One mis-run. POH W/ 70 Jts of 4-1/2" CS Hydril (Up Wt 31K). Pulling 25K over intermittently until 490'. Nothing on end of tbg when pulled through the stack. RCT cut clean - no burrs. Set Test plug and change 4-1/2" fixed rams to 2-7/8 x 5-1/2" VBR's. Test Pipe rams w/ 2-7/8 and 4-1/2" test Jt. Test annular w/ 2-7/8" test Jt. Both to 250psi low / 2500 psi high per Sundry. Witness waived by AOGCC representative Guy Cook. BOP test notification given Sep 13, 2021, at 5:00 PM. Pull test plug. Set 8.75" ID wear ring. MU rope spear BHA & trip in hole with singles, stand back same. Make 7 trips in the hole from 250ft down to 377ft & recovered ~ 600ft of cap string, ~ 600ft of 0.25" braided line, 3 complete clamps, 4 partial clamps & 3 pins. ...Continue WSR on 9/15/21... 9/15/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to make multiple rope spear runs to fish cap string, braided line & clamps. Make 7 trips in the hole from 250ft down to 377ft & recovered ~ 600ft of cap string, ~ 600ft of 0.25" braided line, 3 complete clamps, 4 partial clamps & 3 pins. Complete total of 16 trips with rope spear. Run 14 to ~615' made significant recovery of control line and cable & 1 Partial clamp & pin. Run 15 went all the way to the top of the stump at ~2094' POOH with significant recovery of control line and cable and 1 full clamp. Run 16 to the top of the 4-1/2" stump at 2094' came back clean. Break & LD rope spear. Missing 2 pins & half a clamp. MU RCJB. Trip in hole & tag 15ft in on jt #61, 2072ft. RU power swivel. Pump & spin down to fish at 2072ft. Drop 7/8" ball & begin to reverse circulate junk OOH while rotating. CBU. RD power swivel. ...Continue WSR on 9/16/21... 9/16/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion TOH with RCJB - minimal recovery in basket w/ wear ring on shoe. TIH w/ 4.5" OS. Latch & pull fish free. TOH with fish on. LD 4-1/2" tubing. OOH with jt # 364. Inspect cut joint - split ~40" from end & flared. MU packer mill BHA. Trip in hole with workstring from the derrick & singles. Break circulation every 60jts to keep work string clear of possible rubber debris. ...Continue WSR on 9/17/21... 9/17/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to TIH with 2-7/8' PH6 singles. Break circulation every 60jts to keep work string clear of possible rubber debris. Stop at jt #330. Dry watch rig - No change out due to day crew in quarantine. Night Crew continue to single in & tag, 8ft in on jt #346, 10840ft. LD jt 346. PU power swivel. Mill 5ft of 4-1/2" tubing stub. Pump hi-vis pill. ...Continue WSR on 9/18/21... Daily Report of Well Operations PBU C-05A 9/18/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to circulate bottoms up. LD power swivel. TOH sideways. Dry watch rig from 06:00 to 10:00 & wait on crew due to being in quarantine. Continue to TOH sideways. LD BHA. Mill had good wear of the face that dressed the tubing stub - indicating tubing was dressed off & buttons at base of pilot mill were worn - indicating engagement inside the tubing stub. Boot basket was full. String magnet was full of cuttings. RU slickline. RIH w/ 4.0" junk basket. ...Continue WSR on 9/19/21... 9/18/2021 ***RIG JOB*** RECEIVE RIG CALL OUT. MOBILIZE & RIG UP. ***WSR CONTINUED ON 9-19-21*** 9/19/2021 ***WSR CONTINUED FROM 9-18-21*** (Rig job) MADE MULTIPLE JUNK BASKET RUNS TO TBG STUB @ 10,853' SLM (recovered metal & rubber debris). RAN 5.51" LIB TO TBG STUB @ 10,853' SLM (possible control line & half moon of stub). RAN 3.69" WRP DRIFT AND 2.25" LIB TO 10,919' SLM (LIB shows fill). ***T-BIRD RIG IN CONTROL OF WELL; COMPLETE**** 9/19/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to RIH w/ 4.0" junk basket on slickline. Tag at 10853' slm. POH. Recovered pin from control line clamp. Rerun same 4.0" junk basket to 10854' slm - no metal recovery. MU & RIH w/ 5.5" Flat bottom LIB to 10853' slm. Tap down 4 times & POH. Face of tubing stub is clear. RIH with 3.7" WRP drift with 2.25" LIB on bottom. Tag at 10919' slm. POH. Light picture of sand on LIB. RD slickline unit. Pull wear ring. MIT casing 2500psi for operational integrity - pass. Set test plug. Test VBRs w/ 4-1/2" test Jt. Test annular w/ 4-1/2" test Jt. Both to 250psi low / 2500 psi high per Sundry. Witness waived by AOGCC representative Guy Cook. BOP test notification given Sep 18, 2021, at 8:45 AM. Pull test plug. MU & RIH with approved 4-1/2" completion. 4-1/2" 12.6# L-80 VamTop. ...Continue WSR on 9/20/21... 9/20/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to RIH with approved 4-1/2" completion. 4-1/2" 12.6# L-80 VamTop. Unable to make it past 9132' MD with completion. POOH with completion. ...Continue WSR on 9/21/21... 9/21/2021 ***RIG JOB*** MADE 2 RUNS W/ 5.5" JUNK BASKET & 5.85" GAUGE RING TO TBG STUB @ 10,853' SLM. (Recovered 2 pieces of control line, small metal & rubber debris). ***T-BIRD RIG IN CONTROL OF WELL; COMPLETE*** 9/21/2021 ***THUNDERBIRD RIG ASSIST*** RAN 3.74" SWAGE, DOUBLE X WING MAGNETS, 3.78" MAGNET TO TBG STUB @ 10,853' SLM. (Only fine shavings). RAN 5.5" JUNK BASKET W/ 5.85" GAUGE RING TO TBG STUB @ 10,853' SLM (no solids recovered). ***T-BIRD RIG IN CONTROL OF WELL; COMPLETE*** Daily Report of Well Operations PBU C-05A 9/21/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to POOH with 4-1/2" completion. Packer is missing piece of rubber element & badly gouged on one side. RU slickline & RIH w/ 5.5" junk basket & 5.85" gauge ring - recovered two small pieces of control line. Send packer and GLM's to SLB completion shop & send overshot to Northern Solutions to have all components inspected. Packer is not usable. All other components inspected and returned to location. HES TNT packer arrives. Secure well, BOP's & dry watch rig due to night crew being quarantined. ...Continue WSR on 9/22/21... 9/22/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to dry watch rig due to night crew being quarantined. MU & RIH with approved 4-1/2" completion. 4-1/2" 12.6# L-80 VamTop. Stop running tubing at jt #101. Secure well, BOP's & dry watch rig due to night crew being quarantined. ...Continue WSR on 9/23/21... 9/23/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to dry watch rig due to night crew being quarantined. Continue to MU & RIH with approved 4-1/2" completion. 4-1/2" 12.6# L-80 VamTop. Land overshot on TBG stub and space out. Space out bottom of overshot 5' off of No go. MU TBG hanger & land same. Final PUW-85K, SOW-72K in 8.4 ppg KCL. RILDS. Secure well, BOP's & dry watch rig due to night crew being quarantined. ...Continue WSR on 9/24/21... 9/23/2021 Arrive at rig to land TBG HGR. Verify equipment and stage tools. Get 4' x 4 1/2" IBT pup joint sent to rig to make up to top of landing joint (RKB = 13.6', rig floor was set too high to unlatch elevators w/15' Landing join). Verify all LDS are to out measurement. M/U TBG HGR to string, S/B for rig to drain stack. Land (+/-) 10,484' of 4 1/2" 12.6# L80 TBG. R/I LDS and torque to 550 ft lbs, torque gland nuts to same. S/B for rig to circulate/freeze protect. McEvoy 2-step TBG HGR LIFT THREADS 4 1/2" TC-II w/ 4 1/2" H profile. 9/24/2021 T/I/O= 0/0/0 Assist slickline (RWO expense) Pumped 3 bbls DSL down TBG, confirmed IA returns to open top. Pumped 5 bbls per WSL to FP surface lines. Pumped 1 bbl DSL down TBG to hold 500 psi on DND hole finder. 5 min test pass @ 500 psi. Bleed down TBG. Job continues 9-25-21 9/24/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to dry watch rig due to night crew being quarantined. Pump 70bbls of inhibited 1% KCl brine down hole. Attempt to set packer - pumping past. RU slickline & diagnose leak. ...Continue WSR on 9/25/21... 9/24/2021 ***THUNDERBIRD RIG SUPPORT*** (rwo) PULLED B&R FROM 10,787' MD. (appears in good condition) DEPLOY B&R & CHASE TO 10,787' MD. (still not catching pressure) SET 4-1/2" D&D HOLEFINDER @ 90' SLM. THUNDERBIRD PUMPS TO CONFIRM TREE HOLDING. ***WSR CONTINUED ON 9/25/21*** Daily Report of Well Operations PBU C-05A 9/25/2021 Thunderbird Rig 1 Job Scope: Pull TBG/Run New Completion Continue to use slickline & diagnose leak. Pull & dummy off both GLM's. Pull catcher sub. Pull ball & rod, RHC & set XX plug at 10787'. Pressure up tbg & set packer, see packer set ~2000 psi, MIT-T to 3640 psi. - pass. Pressure up Tubing to 3700psi. IA after 15 minutesTubing pressure at 3640psi. and after 30 minutes Tubing pressure at 3630psi. Bleed TBG to 1200 psi. Test. MIT-IA to 2700 psi - pass. MIT-IA, Bring pressure up to 2700psi for initial pressure, Tubing pressure raised from 1200psi to 1610psi. 15 minute pressure on IA at 2700psi and 30 minute pressure on IA at 2700psi. Pull top GLM valve & leave open pocket. RD slickline. Freeze protect well with 70bbls of diesel. Install TWC. Begin RDMO. ...Job Complete... 9/25/2021 ***WSR CONTINUED FROM 9/24/21*** (rig support) PULLED 4-1/2" D&D HOLEFINDER FROM 90' SLM. PULLED BEK-SHEAR VALVE FROM ST# 2 @ 3,430' MD. (sheared) SET BK-DGLV IN ST# 2 @ 3,430' MD. T-BIRD ATTEMPTED MIT-T ( LLR = 0.5 BPM @ 1,000 psi) PULLED & SET BK-DGLV IN ST#1 @ 6,974' MD T-BIRD ATTEMPTED MIT-T ( LLR = 0.5 BPM @ 1,000 psi) PULLED B&R & RHC FROM X NIPPLE @ 10,787' MD SET 4-1/2" XX PLUG IN X NIPPLE @ 10,787' MD T-BIRD PERFORMED PASSING MIT'S & SET PACKER PULLED BK-DLGV FROM ST#2 @ 3,430' MD ***T-BIRD RIG ON WELL CIRCULATING FREEZE PROTECT ON DEPARTURE*** ***ST#2 IS OPEN POCKET*** 9/25/2021 Set 4" HTWC #438 W/ DRY ROD 9/25/2021 Job continued from 9-24-21. Assist Slickline & rig (RWO Expense). Pumped 5 bbls DSL down TBG to diagnose IA return issue. pump 3 bbls DSL to pressure up tubing/ IA for MIT, pump 70 bbls for freeze protect, rig down for chock skid, well left in rigs control upon departure. 9/26/2021 T/I/O/OO = TWC/0/0/0. ND BOP's. Wellhead tech prepped well head. NU THA. Torque to API specs. Well head tech PT THA. (PASS) Install 6" Cameron production tree with Baker actuator. Torque to API specs. Made C/O with night crew (Mott) Final WHP's VAC/0/0/0. Job In Progress 9/26/2021 Assist w/ NDBOP. Remove TBG HGR neck protector, clean void, inspect TBG HGR neck and lift threads. Install new DX seal, and BX160. N/U THA. Fill void w/ test oil. R/U test equipment and test void to 5M for 30 min. After first 15 min loss of 50 psi, after final 15 min no loss. Good test. R/D test equipment and bleed off pressure. Install new RX46, Assist in tree N/U. 9/27/2021 T/I/O/OO=TWC/0/0/0. Made changeout with day crew (Kelly) Installed tree work platforms, RU CIW Lubricator with 4" H pulling tool. PT 6" Cameron tree through CIW Lubricator to 5000psi. Passed. Pulled 4" H TWC #438 @ 135". RD CIW lubricator. Installed floor kit, production piping to lateral valve. Torqued to ANSI spec. Set house. Job Complete. Final WHP's VAC/0/0/0. Daily Report of Well Operations PBU C-05A 9/27/2021 ***WELL S/I ON ARRIVAL*** (post rig) PULLED BK-DGLV FROM ST#1 (6,974' MD) SET BK-LGLV IN ST#2 (3,431' MD) SET BK-OGLV IN ST#1 (6,974' MD) PULLED 4-1/2" XX PLUG FROM X-NIPPLE (10,787' MD) MAKE SEVERAL ATTEMPTS TO GET PAST OVERSHOT @ 10,860' MD. ATTEMPTED TO EQUALIZE WRP @ 10,862' MD. RAN 10' x 2-1/2" BLR TO WRP. (3/4 gallon of fine sand) ***WSR CONTINUED ON 9/28/21*** 9/28/2021 ***WSR CONTINUED FROM 9/27/21*** (post rig) BAILED ~5.5 GALLONS OF FINE SAND ON TOP OF WRP. ATTEMPTED TO EQUALIZE WRP @ 10,862' MD. RAN 2-1/2" HYDROSTATIC BLR TO TOP OF WRP. (UNABLE TO COME FREE) DROPPED CUTTER BAR, RECOVERED ALL WIRE. ***WSR CONTINUED ON 9/29/21*** 9/29/2021 ***WSR CONTINUED ON 9/29/21*** (post rig) RECOVERED CUTTER BAR FROM 10,880' SLM. JAR ON FISH @ 10,884' SLM FOR ~4 HOURS. PLANTED 4-1/2" RELEASABLE WFD OVERSHOT ON FISH @ 10,884' SLM. JAR ON FISH @ 10,884' SLM FOR ~ 1 HOUR. ***WSR CONTINUED ON 0/30/21*** 9/30/2021 ***WSR CONTINUED FROM 9/29/21*** (post rig) JARRED ON FISH FOR ADD'L HOUR W/O SUCCESS ATTEMP TO PULL OVERSHOT, UNABLE TO RELEASE ***JOB INCOMPLETE, HAND OVER TO OPS TO UNLOAD WELL*** 10/1/2021 ***WSR CONTINUED FROM 9/30/21*** (post rig) BEGIN RIGGING UP 1/4" BRAIDEDLINE ***WSR CONTINUED ON 10/2/21*** 10/2/2021 T/I/O/OO= 100/100/0/0. LRS 72 Assist Slickline (RWO EXPENSE). Freeze protect the F/L with WOA recipe. Pumped 9 bbls of 60/40 MeOH and 15 bbls of crude. Pumped 15 bbls of 60/40 MeOH through the poorboy from C-06 and into the IA. Final T/I/O/OO= 100/100/0/0. 10/2/2021 ***WSR CONTINUED FROM 10/1/21*** (post rig) RECOVERED SLICKLINE TOOLSTRING FROM 10,857' BLM. (hydrostatic bailer full packed full of thick sandy goo) SWAP FROM 1/4" BRAIDEDLINE TO SLICKLINE. ALTERNATED 10' x 2-1/2" P-BLR w/ EQ BTM & WRP CLEANER UNTIL EQUALIZED. PLANTED 4-1/2" WRP PULLING TOOL ON WRP @ 10,911' SLM. PULLING OUT OF HOLE w/ 4-1/2" WRP. ***WSR CONTINUED ON 10/3/21*** 10/3/2021 ***WSR CONTINUED FROM 10/2/21*** (post rig) PULLED 4-1/2" WRP FROM 10,911' SLM. (missing 1/2 slip - 1.625" x 3.0") RAN 3.50" MAGNET w/ 4-1/2" BRUSH TO DEP SLEEVE @ 9,551' MD (recovered small chunks of metal) SET 4-1/2" DREAM CATCHER IN SVLN @ 2,205' MD - 40" = OAL - no spacer pipe ***WELL S/I ON DEPARTURE*** MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ��y�� IIZti'LI DATE: 9/26/2021 P. I. Supervisor II FROM: Lou Laubenstein SUBJECT: Rig Inspection — Thunderbird 1 Petroleum Inspector PBU C -05A Hilcorp North Slope LLC PTD 2010020; Sundry 321-128 9/25/2021: 1 went out to Hilcorp Thunderbird Rig 1 at PBU C -05A for an unannounced visit to check on their night watch. Hilcorp advised AOGCC's Sr. Petroleum Engineer Mel Rixse of a restricted rig crew limiting operations to just 16 hours due to COVID cases affecting the night crew. When I arrived at the Thunderbird rig it looked like they had landed the tubing and closed the blinds. Nobody was at the rig when I arrived. I walked around the rig and well for about 40 minutes, waiting to see if anyone would show up — nobody did. Temperature at location was about 30 degrees F. As you can see from the pictures rig "winterization" consists of blue stripe plastic clamped to a metal frame. The cellar was cold, and the BOP stack was ambient temperature. Looking down the BOP stack from the rig's work floor appeared to show the blinds being closed but I am not 100% sure due to poor lighting. There was no floor safety valve and no tubing stub to install on the tubing for the floor safety valve. During multiple past visits to the Thunderbird rig, I have asked about secondary containment for the upright tank and pits; never got an answer. None of the flow lines running from the manifolds were wrapped or heated and from the looks hadn't been. Open ended pipe had duck ponds or drip plans; there did not appear to be Herculite used for secondary containment at the location. The location wasn't in the best order as you can see from the photos. Attachments: Photos (6) 2021-0925_Rig_Inspect —PBU _C-05 A_11. docx Page 1 of 5 gaar :•. : � , From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: OPERABLE: Producer C-05 (PTD #2010020) MIT"s Passed RWO Complete Date:Wednesday, September 29, 2021 3:27:18 PM Attachments:image001.png Well is PBU C-05A (PTD 2010020) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Wednesday, September 29, 2021 2:35 PM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Wallace, Chris D (CED) <chris.wallace@alaska.gov>; Stan Golis <sgolis@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: OPERABLE: Producer C-05 (PTD #2010020) MIT's Passed RWO Complete Mr. Regg, Producer C-05 (PTD # 2010020) passed MIT-T and MIT-IA on 09/25/21 post RWO. The well is now classified as OPERABLE and can be put on production. Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, August 21, 2019 7:21 AM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad AB <AKOPSWellPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWellPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com>; Igbokwe, Chidiebere <Chidiebere.Igbokwe@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: NOT OPERABLE: Producer C-05 (PTD #2010020) TxIA communication via failed patch All, Producer C-05 (PTD # 2010020) was made Under Evaluation on 07/24/19 after it failed a warm TIFL. On 08/19/19 Slickline replaced the screened orifice with a dummy gas lift valve and the well failed another TIFL. The upper patch assembly was pulled, a plug was set in the lower assembly and Fullbore performed a failing CMIT-TxIA. The failed CMIT-TxIA indicates the lower packer of the patch assembly has failed and the well will now be classified as NOT OPERABLE. Slickline is currently rigged up to the well to set a plug for secure. The APE will evaluate for repair. Please respond with any questions. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, July 24, 2019 4:52 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers1@bp.com>; AK, OPS Well Pad AB <AKOPSWellPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWellPadCX@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com>; Igbokwe, Chidiebere <Chidiebere.Igbokwe@bp.com> Cc: 'chris.wallace@alaska.gov' <chris.wallace@alaska.gov>; AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWellIntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWellIntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com>; AK, GWO Well Integrity Well Information <akgwowellintegritywe@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Janowski, Carrie <Carrie.Janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; Smith, Travis T (CONOCOPHILLIPS) <travis.smith1@bp.com>; Sternicki, Oliver R <Oliver.Sternicki@bp.com>; Tempel, Joshua <Joshua.Tempel@bp.com>; Worthington, Aras J <Aras.Worthington@bp.com> Subject: UNDER EVALUATION: Producer C-05 (PTD #2010020) sustained IA casing pressure above NOL All, Producer C-05 (PTD # 2010020) was reported to have sustained IA casing pressure above NOL on 07/22/19 after the well was shut-in briefly for gas handling issues. On 07/23/19 DHD performed a failing warm TIFL. The failing TIFL indicates a failure in one or more well barriers. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics. Plan forward: 1. Slickline: Replace OGLV 2. DHD: warm TIFL 3. WIE: Additional diagnostics as needed Please respond with any questions. Andrew Ogg Well Integrity EngineerBP Global Wells Organization – AlaskaOffice: 907-659-8110 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:201-002 6.API Number:50-029-20126-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028286 Property Designation (Lease Number):10. 8. PBU C-05A 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 Tubing Swap Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12987 Effective Depth MD: N-80 11. 5/1/2021 Commission Representative: 15. Suspended Contact Name: Wyatt Rivard Contact Email: wrivard@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8994 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10996, 8377 No SSSV Installed Date: Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 21 - 101 19 - 9898 19 - 7590 14. Estimated Date for Commencing Operations: BOP Sketch 20 - 2680 Conductor 7240 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker Packer 11708 - 12920 8889 - 8999 4-1/2" 12.6#17 - 11076 Liner 10862 8283 10862 None 20 - 2680 2670 9-5/8" 7" Contact Phone:907.777.8547 Date: 5710 2642 538013-3/8"Surface 4760 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 80 20"21 - 101 1500 Intermediate 9861 6870 Tieback Liner 11667 18 - 11685 18 - 8873 2009 2-3/8" 10896 - 12985 8307 - 8995 11200 11780 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst 3060 Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2430 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:52 am, Mar 15, 2021 321-128 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.03.15 06:54:35 -08'00' Stan Golis (880) DSR-3/15/21MGR15MAR21 10-404 * Variance to 20 AAC 25.285. Secondary well control for tubing workover operations: - Approved for BOPE stump test followed by rolling test on initial BOPE rig up prior pulling compromised tubing hanger. State witnessed BOPE test after pick up of new hanger per program. *BOPE test to 2500 psi. Annular to 2500 psi. 2430 SFD 3/15/2021 Yeson Required? Comm 3/16/21 dts 3/15/2021 JLC 3/16/2021 RBDMS HEW 3/17/2021 TBG Change-Out Well: C-05A Well Name:C-05A API Number:50-029-20126-01 Current Status:Shut-in Producer Pad:C-Pad Estimated Start Date:May 1st, 2021 Rig: Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:201-002 First Call Engineer:Wyatt Rivard (907) 777-8547 (O)(509)-670-8001 (M) Second Call Engineer:Noel Nocas (907) 564-5278 (O)(907)-229-9532 (M) AFE Number:215-00940 IOR 400 Current Bottom Hole Pressure:3310 psi @ 8,800’ TVD 7.23 PPGE | (Average Ivishak BHP) Maximum Expected BHP:3310 psi @ 8,800’ TVD 7.23 PPGE | (Average Ivishak BHP) Max. Anticipated Surface Pressure:2430psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2400 psi (Taken on 8/20/2019) Min ID:1.91” XO at 10896’ MD Max Angle:97 Deg @ 12411’ Brief Well Summary: C-05A developed TxIA communication in 2017 due to a leak at 4541’ MD. The leak was remedied with a patch. Two years later the well failed a TIFL on 7/23/2019 and 8/19/2019. To verify the integrity of the tubing below the original leaks a WRP was set at 4655’ MD and a CMIT- TxIA performed. The CMIT failed with a LLR of 0.63 bpm. Several stops with D&D Hole Finder also indicated leaking below the patch. Tubing is in poor condition and RWO is needed to restore tubing integrity Notes Regarding Wellbore Condition x The 7” production casing passed CMIT-TxIA to 2,600 psig on 11/7/2019. x Ivishak perfs will remain hydraulically isolated throughout RWO by tested WRP at 10862’ MD. x 2-3/8” liner highly corroded. A 9 ft section of liner top recovered by slickline 9/18/17 after it parted while pulling TTP from deployment sleeve. x Offset Injector Support o B-17: Online, 2500’ away. x Tubing Hanger BPV and Landing Joint threads are washed out as confirmed visually during tree swap on 5/1/2014 Objective: x Pull 4-1/2” tubing string, rerun new tubing and return well to production. Variance Request: 20 AAC 25.285(f)Well’s BPV profile is washed out and previous attempts to set TWC were unsuccessful. BOPE installation will rely on tested WRP and KWF column as barriers. BOPE will be installed and visually checked for leaks while pressuring up against the TTP to 1500 psi. Unless BPV threads can be redressed, TBG hanger will need to be pulled and tubing hung off storm packer/test plug to run a new hanger/plug into tubing hanger profile and then perform a full BOP test. Sundry Procedure (Approval Required to Proceed) Eline – Cut tubing 1. Spot E-Line unit to well, RU and PT. 2. MU tubing cutter and RIH. 3. Cut tubing at ±10,810’ md mid joint. Note any TxIA pressure change in WSR. TBG Change-Out Well: C-05A a. Correlate to Tubing Tally dated 12/30/77 b. Contact OE Wyatt Rivard 1(509) 670-8001 or Noel Nocas at (907)-229-9532 (M) prior to cut for final approval of tie in. 4. RDMO Eline. Pumping – Circulate in KWF 5. Spot Pump Truck, RU and PT. 6. CMIT-TxIA to 2500 psi for updated test of WRP and casing. 7. Circulate in at least 100 bbls of 8.4 ppg 1% KCl or equivalent through tubing punch holes at 4541’ a. Tubing and annular volume = .0152 + .0175 = .0327 BPF b. 100 bbls equates to ~3050 ft fluid column 8. Chase with ~ 50 bbls (~1600 ft) freeze protect, allow tubing and IA to U tube. a. Resulting fluid column above WRP will equate to ~7.3 ppg MW. 9. RDMO pumpers RWO Procedure: 10. MIRU workover rig, ancillary equipment, and lines to returns tank. 11. Bleed TBG/IA pressures to ~0psi. Circulate well w/8.4 1% KCl or equivalent as needed 12. BPV and landing joint threads are washed out. BOPE install and testing will require alternative procedures. a. Stump test (charted) BOP stack in shop to 2500 psi prior to wellsite installation b. Minimize breaking BOPE connection in between stump testing and wellsite installation 13. ND tree and NU 13-5/8” BOP’s. c. Barriers consist of tested WRP at 10862’ MD and KWF. d. Mark tree for proper orientation during reinstall e. Function test BOP prior to arrival of AOGCC inspectors. 14. Pressure up tubing/IA to 1500 psi against WRP. Visually confirm no leaks from BOPE. 15. Bleed TBG and IA pressure off to ~0 psi. 16. MU landing joint or spear, BOLDS and PU on the tubing hanger. f. ~10800’ of 4-1/2” 12.75# tubing weighs ~ 138Klbs(dry) or 120Klbs(buoyed by 8.4 ppg fluid) g. If hanger does not come free at 120Klbs, contact Contact OE Wyatt Rivard 1(509) 670-8001 or Noel Nocas at (907)-229-9532 (M) before proceeding. 17. Laydown old tubing hanger and MU new hanger or test plug h. Connect new hanger/test plug to the completion tubing, alternately, hang off completion from storm packer. i. Re-land hanger (or test plug) in tubing head. 18. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Notify AOGCC 24 hours in advance of BOP test. b. Perform Test per AOGCC approved BOP Test Procedure c. Confirm test pressures per the Sundry Conditions of approval. * 24 hour notice for AOGCC to witness rolling test against deep set plug and leaking profile. 24 hour notice for AOGCC to witness rolling test. TBG Change-Out Well: C-05A d. Test VBR ram on 4-1/2” test joint. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 19. Bleed any pressure off casing to returns tank. Kill well w/8.4 1% KCl or equivalent as needed. 20. POOH and lay down the 4-1/2” tubing while spooling SSSV Control Line. j. Due to heavy corrosion of tubing it will be junked. k. The completion has the following amount of clamps/ cap-string: i. SSSV Control line from surface to OTIS HXO at 2098’ MD ii. 19 control line rubber centralizers (4-1/2”x7”) spaced above Otis HXO to surface. 21. PU new 4-1/2” completion and run per C-05A Proposed Completion Running Order. l. Overshot tubing stub at ~10,810’ with packer set ± 10760’ MD. m. Ensure RHC plug body pre-installed in lowermost X profile at ±10,790’ MD n. Freeze protect tubing/IA as needed prior to packer set or utilize a shearout GLV for post set freeze protect. 22. Land the tubing hanger and RILDS. Lay down landing joint. Note Pick-up and slack-off weights on tally. o. Target landing overshot at ~ 10KIPS compression 23. Drop ball and rod and hydraulically set the packer per manufacturer’s setting procedure p. Conduct MIT-T to 4,000 psi and MIT-IA to 2,500 psi for 30 mins (charted) 24. Bleed tubing pressure back to ~0 psi. Set TWC. 25. RDMO WO Rig. Move to next well location. 26. RU crane. ND BOPE. 27. NU the tubing head adapter and tree. Test tubing hanger void and tree to 500 psi low/5,000 psi high. 28. Pull TWC. 29. RD crane. Move returns tank and rig mats to next well location. 30. Replace gauge(s) if removed. Post-Rig Procedure: Slickline 31. Spot Slickline unit and RU. 32. Pressure test lubricator to 300psi low and 2,500psi high. 33. RIH and pull/set GLV generic kickoff design per gaslift engineer. 34. RIH and pull RHC plug from X profile at ±10790’ MD 35. RIH and pull WFT SC WRP from 10862’ MD. 36. RDMO and turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic 4. Blank RWO MOC Form TBG Change-Out Well: C-05A TBG Change-Out Well: C-05A TBG Change-Out Well: C-05A Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: March 12, 2021Subject: Changes to Approved Sundry Procedure for Well C-05ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, October 2, 2017 4:05 PM To: AK, OPS EOC Specialists;AK, OPS GC1 Field O&M IL;AK, OPS GC3 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad CX;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Glasheen, Brian P; Regg,James B (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects 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;Tempel,Joshua; Worthington,Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer C-05A(PTD#2010020)Well barriers restored with tubing patch All, Producer C-05A(PTD#2010020)was made not operable on 7/3/2016 for having tubing by inner annulus communication. On 1/1/17 E-Line ran an acoustic leak detection log and found a hole in the production tubing at 4,530' MD. On 09/28/17 slickline completed setting a gas lift straddle patch over the leak and performed a passing MIT-T to 2,567psi. The passing pressure test confirms the primary well barrier has been successfully restored. At this time the well is reclassified as Operable. Please mind fluid packed annuli when bringing the well online. Please respond with any questions, Joshua Stephens Well Integrity Engineeret A p1ED F 4< ; ,; , Office: 907-659-8110 Cell: 907-341-9068 WO From: AK, GWO S ell Integrity Sent: Sunday, July 03, 20 • -.49 AM To: AK, OPS GC3 Facility OTL; A , •• GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, GWO SUPT Spe •rojects; AK, GWO SUPT Slickline; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Contr. • AK, OPS Well Pad CX; AK, OPS GC3 Field OTL; Boman, Wade; Glasheen, Brian P; 'Regg, James B (DOA) (jim.regg@alas • ' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity, . OPS FF Well Ops Comp Rep; McVey, Adrienne; 'chris.wallace@alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgome ravis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; Tempel,Troy; Worthington, Aras J; AK, G ' PT Well Integrity Subject: NOT OPERABLE: Producer C-05A (PTD #2010020) Secured with tail plug • 2._o\ o02 TRANSMITTAL 21%5 3 0. WELL LOG PROACTIVE DIACINOSTIC SERVICES, INC. DATA LOGGED R '�C YI V D.� \ /1'4/2011 K BENDER JAN 0 6 2017 To: AOGCC AOGCC Makana Bender 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 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 gancpdcabp.com SCANNED APR 0 7 2017 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 02-Jan-17 C-05A BL /CD 50-029-20126-01 2) Signed : Mc'' 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: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalS heets\BP_Transmit.docx S • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday,July 03, 2016 5:49 AM To: AK, OPS GC3 Facility OIL;AK, OPS GC3 Operators;AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, GWO SUPT Special Projects;AK, GWO SUPT Slickline;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad CX;AK, OPS GC3 Field OTL; Boman, Wade;Glasheen, Brian P; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, OPS FF Well Ops Comp Rep; McVey,Adrienne;Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;AK, GWO SUPT Well Integrity Subject: NOT OPERABLE: Producer C-05A (PTD#2010020) Secured with tail plug All, Producer C-05A(PTD#2010020) has been secured with a tubing tail plug and passing CMIT-tubing x inner annulus confirms two well barrier envelopes.The well is now reclassified as Not Operable until tubing integrity is restored. Thanks, Ryan Holt Well Integrity (Alternate:Lee Grey) 0:(907)659-5102 SCANNED DEC 0 92016 C:(907)943-0296 H:2376 Email: AKDCWellIntegrityCoordinator@BP.com m: AK, D&C Well Integrity Coordinator Sen . esday, June 21, 2016 5:35 AM To: AK, 0 C3 Facility OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, • AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West We t Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS Well Pad CX; AK, OPS GC3 Field OTL; Bo Wade; Glasheen, Brian P; 'Regg, James B(DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, D&C DHD Well Integrity Engine • AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, enne; 'chris.wallace@alaska.gov'; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, u; Pettus, Whitney; Sternicki, Oliver R; Tempel,Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer C-05A(PTD #201 0) Sustained IA Casing Pressure Above MOASP All, Producer C-05A(PTD#2010020)was reported to have sustained IA casing press - above MOASP on 06/20/16. Pressures were confirmed to be TBG/IA/0A/00A= 2510/2510/80/0.The well is recla •fied as Under Evaluation. Plan Forward: 1. Slickline:Set Plug, CMIT-TxIA for Secure 2. Fullbore:Assist Slickline—load tubing and CMIT-TxIA 3. Well Integrity Engineer:Additional diagnostics as needed 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Tuesday, June 21, 2016 5:35 AM To: AK, OPS GC3 Facility OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers;AK, OPS Well Pad CX;AK, OPS GC3 Field OTL; Boman, Wade; Glasheen, Brian P; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; AK, D&C Well Integrity Coordinator; McVey, Adrienne; Wallace, Chris D (DOA); Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel, Troy; Worthington, Aras J Subject: UNDER EVALUATION: Producer C-05A (PTD#2010020) Sustained IA Casing Pressure Above MOASP Attachments: Producer C-05A (PTD #2010020) TIO Plot 2016-06-21.docx All, Producer C-05A(PTD#2010020)was reported to have sustained IA casing pressure above MOASP on 06/20/16. Pressures were confirmed to be TBG/IA/0A/00A= 2510/2510/80/0.The well is reclassified as Under Evaluation. Plan Forward: 1. Slickline: Set Plug, CMIT-TxIA for Secure 2. Fullbore: Assist Slickline—load tubing and CMIT-TxIA 3. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot is attached for reference. Please reply if in conflict with proposed plan. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 JAN 0 42.017 C: (907)943-0296 H: 2376 Email: AKDCWeIllntegrityCoordinatorPBP.com 1 • • Producer C-05A(PTD#2010020) TIO Plot 06/21/2016 Well C{b Tb r.k tO 2O d { +OA 00A +oo0A —o. iOIC • Y 1. • 0321116 w2E15 040416 C41116 04°1&1f 0. 16 C62€ OS:91f 051656 05?316 0.53616 05%16 061316 06,201€ Imai Project Well History File Covei' age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q~O I .... - OOc:~ Well History File Identifier RESCAN D I~,~¢rTA ~ OVERSIZED (Scannable) r"~ Color items: ¢;~ Diskettes, No. ~, r'-., Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner D Poor Quality Originals: OVERSIZED (Non~Scannable) [] Other: NOTES: D Logs of various kinds E] Other Project Proofing B Y: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation I x 30 = _.~1~) BY: BEVERLY ROBIN VINCENT SHERY~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' . ............ YES .Xli._ NO BY: ..... ~ .. S,~ERYL.. M^R,A W,NoY '"'~:::~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPAN~ERE FOUND: t ~ NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Is~ General Notes or Comrnents about this file: Q u a Ii ty C h e c k e d :~:,:: ~.:.::, ~, 12/10/02Rev3NOTScanned.wpd • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 r' r 9 'ZV I 0 r w Anchorage, Alaska 99519 -6612 �;. August 22, 2011 RECEIVED' AUG 1 ?nil Mr. Tom Maunder Alaska Oil and Gas Conservation Commission Alaska & G C. 333 West 7 Avenue Commission Anchorage, Alaska 99501 Ancterage -; Subject: Corrosion Inhibitor Treatments of GPB C -Pad ( t - 0 b Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 7 ) C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 11/20/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C-42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 e e ç~~" MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc " ) STATE OF ALASKA"'à ALA3t<..A OIL AND GAS CONSERVATION COMrvhJSION REPORT OF SUNDRY WELL OPERATIONS o o o Operations Abandon D Repair Well 0 erformed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D · Operator BP Exploration (Alaska), Inc. lame: P.O. Box 196612 Anchorage, AK 99519-6612 · KB Elevation (ft): · Address: 55.4 KB k Property Designation: ADL-028286 11. Present Well Condition Summary: StimulateD " (n~~rD Waiver D Time Extension D Re-enter Suspended Well 0 5. Permit to Drill Number: 201-0020 6. API Number: 50-029-20126-01-00 9. Well Name and Number: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development iI?' Stratigraphic Exploratory Service C-05A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool rotal Depth measured 12986 feet Plugs (measured) true vertical 8994.46 feet ,~ 0 ~rtOO~sUred) Effective Depth measured 12926 feet SCANNEl» NO ~ true vertical 8998.61 feet Casing Length Size MD TVD Conductor 80 20" 133# H-40 39 - 119 39 - 119 Surface 2642 13-3/8" 72# L-80 38 - 2680 38 - 2679.98 Production 9861 9-5/8" 47# L-80 37 - 9898 37 - 7589.62 Liner 2332 7" 29# N-80 9353 - 11685 7213.8 - 8873.12 Liner 2094 2-3/8" 4.6# L-80 10891 - 12985 8303.63 - 8994.53 Perforation depth: Measured depth: 11708 - 11728 11975 - 12050 True Vertical depth: 8889.09 - 8901.3 8989.55 - 8995.83 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 3357 x 11710 - 11730 12110 - 12160 8890.38 - 8902.44 9001.12 - 9005.85 11850 - 11900 12400 - 12450 8957.82 - 8976.56 9004.92 - 8999.26 4-1/2" 12.75# N-80 7" Packer 4-1/2" Packer None None Burst 3060 4930 6870 8160 11200 Collapse 1500 2670 4760 7020 11780 11898 - 11923 12500 - 12920 8975.96 - 8982.47 8996.45 - 8999.01 11906 - 11926 8978.28 - 8983.11 36 - 11076 9373 10996 RBDMS BFl SEP 2 (; 2005 Representative Daily Average Production or Injection Data Gas-Met I Water-Bbl I Casing Pressure Tubing pressure SHUT - IN 4759 I 12 I 1260 400 15. Well Class after proposed work: ExploratoryC Development [;7.. Service C 16. Well Status after proposed work: Oil p'. Gas r WAGe GINJ r WINJ r WDSPL r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal _ / Signat~~~/7J,.A:f-d Form 10-404 Revised 04/2004 Title Data Mgmt Engr Phone 564-4424 ORIGINAL Sundry Number or N/A if C.O. Exempt: N/A Date 9/20/2005 Submit Original Only .~ ) ) C-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 8/13/2005 CTU #5, Add Perf; MIRU. RIH with PDS memory GR/CCL. Have trouble getting past tubing hanger. Pump down back side @ 1 BPM and make it through tubing hanger. Continue RIH. Continued on 8/14/05 WSR '" 8/14/2005 CTU #5, Add Perf; Continued from 8/13/05 WSR... Continue in hole for logging ops. Log up @ 40 fpm from 12000' to 11600', Paint flag @ 11850'. POOH. Depth correction (-31') tied-in to SWS MCNL - 2/17/01. RIH with Gun #1 (25' - SWS 1.56" HSD-PJ1606 @ 6 spf). Correct depth to top shot at flag. Perforate interval 11875' to 11900'. POOH. All shots fired. RIH with Gun #2 (25' - SWS 1.56" HSD-PJ 1606 @ 6 spf). Perforate interval 11850' to 11875'. POOH. All shots fired. RIH with Gun #3 (20' - SWS 1.56" HSD-PJ1606 @ 6 spf). Correct depth to top shot at flag. Continued on 8/15/05 WSR ... 8/15/2005 CTU #5, Add Perfs; Continued from WSR 8/14/05... Pumped 1/2" ball to fire Gun #3. Questionable whether gun fired. At surface, gun had not fired, had malfunction in MHA - flapper check valve pin broke. Changed out MHA. Rerun Gun #3 (20' SWS 1.56" HSD-PJ1606 @ 6 spf). Perforated interval 11710' to 11730'. POOH. All shots fired. RIH with 1 3/4" JSN. Begin lifting well with N2 at 2500' working d0\t\ln to 10000' ctmd, flowing to LP system. FWHT steady climbed. Have GC-3 put well into test on full open choke. Stop pumping N2, PUH to observe well. Confinued on 8/16/05 WSR ... FLUIDS PUMPED BBLS 271 2% KCL 43 50/50 MeOH 4400 Gallons N2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: AbanonE~ Suspendr'-] Operation Shutdown[~ Perforate, Variancer'-~ Annuar Disposal['"~ After Casinq[~] Repair WellD Plu.a PerforationsF'"l Stimulate[~ Time Extension~] Other[~ Change Approved Program ~--~ Pull TubingS] Perforate New Pool [] Re-enter Suspended Well E~] ADD PERFS 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. Developement · Exploratory[~ 201-002 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic r-] Service [] 50-029-20126-01-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 55.00 C-05A 8. Property Designation: .10. Field/Pool(s): 028286 Prudhoe Bay Field ! Prudhoe Bay Oil Pool 11. Present Well Condition Summary: Total Depth measured 12988 feet true vertical 8994 feet Plugs (measured) Effective Depth measured 12926 feet Junk (measured) true vertical 8999 feet Casing Length Size MD TVD Burst Collapse Conductor 119' 20" 139' 139' 40K 520 Surface 2660' 13-3/8" 2680' 2680' 80K 2670 Production 9878' 9-5/8" 9898' 7589' 80K 4760 Liner 2332' 7" 9353'-11685' 7213'-8873' 80K 7020 Sidetracker Liner 2094' 2-3/8" 10892'-12986' 8304'-8994' 80K 11780 Perforation depth: Measured depth: Open Perfs 11708'-11728', 11898'-11926', 11975'-12050', 12110'-12160', Open Perfs (continued) 12400'-12450', 12500'-12920'. True vertical depth: Open Perfs 8887'-8900', 8975'-8983', 8990'-8996', 9001'-9006', Open Perfs (continued) 9005'8999', 8997'-8999'. Tubing: (size, grade, and measured depth) 4-1/2" 12.75# N-80 TBG @ 10958'. 4-1/2" TBG TO 11076'. Packers & SSSV (type & measured depth) 9-5/8" x 7" BOT Packer @ 9373'. 4-1/2" x 2-3/8" Baker Tieback SLV @ 10891'. 7" x 4-1/2" BOT Packer @ 10996', 4-1/2" O1~ ~.~l't~~~@ 2098'. 12. Stimulation or cement squeeze summary: Intervals treated (measured): JUN 1 6 2003 Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Oil-abl Gas-Mcr Water-Bbl Casing Pre~P~~:~ ;'- Tubing Pressure Prior to well operation: shut-in Subsequent to operation: 410 2519 10 199 14. Attachments: 15. Well Class after proposed work: Exploratory["] Development~ Servicer-] Copies of Logs and Surveys run _ 1~. Well Status after proposed work: Oil· Gasr"~ WAGr"'] GINJ[~] WINJE~] WDSPLr' Daily Report of Well Operations _X .... 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISundry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr I N/A Printed Name DeWayne R. Schnorr Title Techical Assistant Signature ,~,~-~.~,,~.~~ ~.~..Phone 90,7/564-5174 Date May23,2003 Form 10-404 Revised 2/2003 C-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/14/2003 PERFORATING: DRIFT/TAG 05/14/2003 PERFORAT]iNG: JEWELRY LOG--DEPTH CONTROL; PERFORATING 05/15/2003 PERFORATTNG: JEWELRY LOG--DEPTH CONTROL; PERFORAT]iNG 05/16/2003 PERFORATING: N2 LIFT 05/17/2003 TESTEVENT --- BOPD: 0, BWPD: 0, MCFPD: 2,964, AL Rate: 0 EVENT SUMMARY 04/14/03 WELL FOUND SHUT IN ON ARRIVAL. SSV CLOSED. RAN 1.75" CENTRALIZER, 3'X 1-1/2" STEM & 1.85" CENTRALIZER. STOPPED FALLING @ 11,728' SLM DUE TO DEVIATION. RIG DOWN. SECURED WELL. NOTIFIED DSO OF WELL STATUS. WELL LEFT SHUT IN. 05/14/O3 MIRU CTU # 9. WEEKLY TEST BOPE 200 / 4000 PSI. RIH WITH SWS MEM/GR/CCL. JOB IN PROGRESS. 05/15/O3 RAN GR/CCL FROM 11650 TO 12000 @ 60 FPM. POH. GOOD DATA. MU AND RIH WITH GUN #1 (25') AND PERFORATED INTERVAL 11898'- 11923'. POH, ALL SHOTS HAD FIRED. MU AND RIH WITH GUN #2 (20'). PERFORATED INTERVAL 11708'-11728'. POH, FILLING GAPS IN REEL. RIH AND N2 LIFT WELL WITH 1.75" JS NOZZLE. JOB IN PROGRESS. 05/16/03 CONTINUE TO LIFT WELL. RECOVERED TOTAL OF 445 BBLS OF FLUID DURING LIFT. POH. LEAVE WELL IN TEST SEPARATOR. RDMO. <<< NOTIFY PAD OPERATOR THAT WELL IS FLOWING TO TEST SEPARATOR >>> 05/17/03 TESTEVENT--- BOPD: 0, BWPD: 0, MCFPD: 2,964, AL Rate: 0 FLUIDS PUMPED BBLS 1 DIESEL USED TO PRESSURE TEST - PRESSURE CONTROL EQUIP 104 METHANOL 31 50/50 METHANOL WATER NITROGEN - 2800 GALLONS 136 TOTAL ADD PERFS 05/15/2OO3 THE FOLLOWING INTERVALS WERE PERFORATED USING THE 1-9/16" HSD POWER JET, 6 SPF, 60 DEGREE PHASING, RANDOM ORIENTATION. 11708'-11728' 11898'-11923' Page 1 Permit to Drill 2010020 MD 12988 -"" TVD ~t,I F~ DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. PRUDHOE BAY UNIT C-05A Operator BP EXPLORATION (ALASKA) INC 8994 '" Completion Dat 2/18/2001 '--- Completion Statu 1-OIL Current Status l-OIL APl No. 50-029-20126-01-00 UIC N REQUIRED INFORMATION Mud Log N~o Sample N_.~o Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval OH I Start Stop CH 11680 13000 Open (data taken from Logs Portion of Master Well Data Maint) Dataset Received Numl~.r~./ Comment~ 5/18/2001 1009~/ 11680-13000 4/29/2002 1078~g ED ~ Cn See Notes ED ~ L R L D R Cn See Notes R ~duction Log 9942 Directional Survey Directional Survey 1.3;~G R 5 *' LIS Verification 10095 10018 ~L/GR/CCL 2 MWD Survey Directional Survey Well Cores/Samples Information: Name Interval Start Stop 1 12315 12550 Case 11414 12270 Case 10700 12924 Case I 11768 12111 Case FINAL 11414 12270 ch FINAL 11414 12270 ch FINAL FINAL FINAL 11685 12988 OH FINAL 11680 13000 CH FINAL 11680 13000 CH FINAL 10700 12924 ch FINAL 10700 12924 ch FINAL OH FINAL OH Sent Received 2/912001 09942 ~1'~414-12270 4/6/2001 10018~1~10700-12924 4/2912002 10781~c0il flag 2/912001 11414-12270 BL, Sepia 2/9/2001 9942 v'~11414-12270 Digital Data 4113/2001 Directional Survey Digital Data 4/1312001 Directional Survey Paper Copy 5/23/2001 11685-12988 BL, Sepia 5/2312001 11680-13000 LIS Verifcation 5/23/2001 1009~"~ 1680-13000 Digital Data 4/6/2001 10018 ~.--11~00-12924 Digital Data 4/6/2001 10700-12924 BL, Sepia 716/2001 MWD Survey, Digital Data 716/2001 Directional Survey, Paper Copy Dataset Number Comments Permit to Drill 2010020 MD 12988 TVD DATA SUBMITTAL COMPLIANCE REPORT 41112003 Well Name/No. PRUDHOE BAY UNIT C-05A Operator BP EXPLORATION (ALASKA) INC 8994 Completion Dat 2118/2001 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-20126-01-00 UlC N ADDITIONAL INFORMATION Well Cored? Y I ~ Chips Received? ~ Analysis ~ Received? Daily History Received? ~1 N Formation Tops (~)/N Comments: Compliance Reviewed By: Date: ProActive Diagnostic Services, Inc. t Wt:'LL LOG TRANSMITTAL To: State of Alaska Aor~c 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Print{s) 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' Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration [Alaska}, Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 995138 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S} OR CD-RE)M FILM COLOR Open Hole I I 1 Res. Eval. CH I I 1 CO5A 4/12/02 Mech. CH 1 Caliper Survey Signed' Print Name: Date ' RECEIVED 2 9 2002 Alasl~Oil &Gas Cons.~i~on And~omge ProActive DiagNostic Services, INC., 310 K Street Suhe 200, ANchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: txlsanchoragc~mcmorylog.com Wcbsitc: )~'._w~_3,'._Ln_c_~3_o_r_vl_og, c__on__! ProActive Diagnostic Services, Inc. TRANSMITTAL To'. State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Print{s) The technical data listed below is being submic~ced herewith. Please acknowledge receipt by returning a signed copy of this transmi~al letter to the aCtention of' Joey Burton / Jeni Thompson I~oActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska]. Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, AK 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE' TYPE on SEPIA PRINT[S] OR CD-ROM FILM COLOR Open Hole 1 1 1 Res. Eval. CH I I 1 C-05A 4/10/02 Mech. CH. 1 Caliper Survey Signed' ~ Print Name: Date ' RECEIVED APR 2 9 2002 AlaskaOil&GasCms. n ProActive Diagnostic Services, Inc., 3 IO K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax: (907) 245-8952 E-mail: pdsanchoragc~mcmorylog, com Wcbsite: www. mcmoryl_o.g, corn STATE OF ALASKA .......... ~, ,,: ..... ALASKA OIL AND GAS CONSERVATION COMMISSION ...... REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X ADD PERES Pull tubing _ Alter casing _ Repair well _ Other _ " 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 1963' FNL, 879' FEL, Sec. 19, T11N, R14E, UM At top of productive interval 763' FNL, 821' EEL, Sec. 25, T11 N, R13E, UM At effective depth 503' FNL, 1727' FEL, Sec. 25, T11N, R13E, UM At total depth 517' FNL, 1801' FEL, Sec. 25, T11N, R13E, UM 5. Type of Well: Development __X Exploratory__ Strati§raphic__ Service_ (asp's 664516, 5959256) (asp's 659704, 5955074) (asp's 658793, 5955315) (asp's 658719, 5955299) 12. Present well condition summary Total depth: measured true vertical 12988 feet Plugs (measured) 8994 feet Effective depth: measured true vertical 12912 feet Junk (measured) 8999 feet Casing Length Conductor 119' Surface 2647' Production 9865' Liner 2332' Sidetrack Liner 2094' 6. Datum eleva~..on'.(DF_, or. KB feet) RKB 55 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number C-05A 9. Permit number / approval number 201-0020 10. APl number 50-029-20126-01 11. Field / Pool Prudhoe Bay Oil Pool TD Tag @ 12912' (05/23/2001) Size Cemented Measured Depth True Vertical Depth 20" 135 sx AS 152' 152' 13-3/8" 3250 sx AS 2680' 2680' 9-5/8" 1819 Howco Lite, 1400 9898' 7590' sx Class 'G', 185 sx PF 7" 1100 sx Class 'G' 9353' - 11685' 7214' - 8873' 2-3/8" 67 cf Class 'G' 10892'-12986' 8304'- 8996' Perforation depth: measured Open Perfs 11906'-11926', 11975'-12050', 12110'-12160', 12400'-12450', 12500'-12920' true vertical Open Perfs 8978'-8983', 8990'-8996', 9001'-9006', 9005'-8999', 8996'-8999' Tubing (size, grade, and measured depth) 4-1/2", 12.75#, N-80 TBG @ 861210958'. 4-1/2" Tubing Tail @ 11076' Packers & SSSV (type & measured depth) 9-5/8" x 7" BOT Packer @ 9373'. 7" x 4-1/2" BOT Packer @ 10996' 4-1/2" Otis SSSV Landing Nipple @ 2098'. 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 Dally Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-In Well Shut-In Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil ~ Gas _ Suspended Service 17. I hereby certify that the foregoing is,true and correct to the best of my knowledge. DeWa}/ne R. Schnorr Form 10-404 Rev 06/15/88 · Date April 25, 2002 Prepared by DeWayne R, Schnorr 56.~:5174 SUBMIT IN DUPLICA~TM ; ( (' 01/16/2002 01/17/2002 01/18/2002 02/14/20O2 04/10/2002 04/11/2002 04/12/2002 01/16/02 01/17/02 01/18/02 02/14/02 04/10/02 04/11/02 04/12/02 04/13/02 C-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PERF(ADD-PERF) PERF(ADD-PERF) PERF(ADD-PERF) PERF(ADD-PERF) PERF(ADD-PERF) PERF(ADD-PERF) PERF(ADD-PERF) : MEM LOG/ADD PERF : ADD-PERF : N2 LIFT :DRIFT/TAG :PERFORATING :PERFORATING :PERFORATING EVENT SUMMARY MIRU DS CTU #1. MU WFD 1-11/16" MHA & SWS MEMORY TOOLS, LOG GR/CCL FROM 11,700' TO 12,150'. FLAG AT 11,900' CT EOP. POOH. MU 25' SWS 1.56"6 SPF GUNS. RIH TO FLAG, CORRECT DEPTH - DROP 1/2" STEEL BALL - SHOOT INTERVAL FROM 12025'-12050'. POOH, CUT OFF 1' OF PIPE, PUT ON NEW CONNECTOR AND 1-11/16" MHA AND 25' SWS 1.56" 6 SPF GUN. RIH MU 25' SWS 1.56" 6 SPF GUNS (2ND GUN RUN). RIH TO FLAG, REPAINT, AND CORRECT DEPTH. DROP 1/2" STEEL BALL AND FIRE GUNS FROM 12000'- 12025', POOH. MU FINAL 25' SWS - 1.56" PJ GUN, RIH TO FLAG AND CORRECT DEPTH (23' CORRECTION). DROP 1/2" STEEL BALL AND FIRE GUNS FROM 11975'-12000', POOH. BREAK OFF GUN #3, MU 1.75" JSN. RIH PUMPING N2 @ 300 SCF/MIN. ***JOB IN PROGRESS*** FINISH PUMPING N2 IN WELL AT 500 SCF/MIN FROM 7000'- PUMP TOTAL OF 6500 GALS OF N2. LEFT WELL FLOWING AT 250 BOPD, 1500 BWPD, 2~5 MMSCFD GAS - FLOWLINE TEMP IS 75 DEGF. RIG DOWN DRIFT W/1.562" DUMMY GUN TO 11650' SLM RDMO(PRE CTU ADD PERF) MIRU DS CTU #3. RIH W/PDS 1-11/16" MEM TOOLS. LOG UP FROM 12,500' AT 40 FPM. PAINT FLAG AT 12,350' CTDM. GOOD MEM LOG DATA. RIH W/1.56" HSD GUN #1, 6 SPF. SHOT GUN #1, 12,425-12,450' MD. POOH. RIH W/1.56" HSD GUN #2, 6 SPF. SHOT GUN #2, 12,400-12,425' MD. POOH. RIH W/1.56" HSD, 6 SPF, GUN #3 - PERF 12,135'-12,160'. POOH. CHAIN INSPECTION, CHANGE BEARINGS. RIH W/PDS MEMORY TOOLS, LOG 11,600 TO 12,150' CTMD - GOOD DATA. RIH W/1.56 HSD, 6 SPF, GUN RUN #4 - PERF 12,110'-12,135'. RIH W/GUN RUN #5 - 1.56" HSD, 6 SPF, PERF 11,906'-11,926'. RU N2 TRUCK. RIH W/1.75" JSN. LIFT W/2300 GAL N2. POOH. WELL IS NOT FLOWING ON ITS OWN. Page 1 C-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 04/14/02 FINISH PUMPING N2 AT 500 SCF/MIN FROM 8500'. PUMPED A TOTAL OF 5000 GAL N2. WELL LEFT FLOWING AT 165 PSI WHP, 90 DEGF TEMP. **PAD OP TO MONITOR WELL FOR NEXT 24 HR.** FLUIDS PUMPED BBLS I DIESEL FOR PRESSURE TESTING SURFACE PRESSURE CONTROL EQUIP 86 DIESEL 306 ~60/40 METHANOL WATER 219 NITROGEN GAS (9200 GALS) 612 TOTAL ADD PERFS 01/16-17/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 1-11/16" POWERJET, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 11975'-12050' 04/11-13/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 1-11/16" POWERJET, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 11906'-11926' 12110'-12160' 12400'-12450' Page 2 STATE OF ALASKA · ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Add Perfs Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchora~le, AK 99519-6612 5. Type of Well: Development _X Exploratory_ Stratigraphic._ Sen/icL 4. Location of well at surface 1963' FNL, 879' FEL, Sec. 19, T11 N, R14E, UM At top of productive interval 763' FNL, 821' FEL, Sec. 25, T11N, R13E, UM At effective depth 505' FNL, 1741' FEL, Sec. 25, T11N, R13E, UM At total depth 517' FNL, 1801' FEL, Sec. 25, T11N, R13E, UM (asp's 664516, 5959256) (asp's 659704, 5955074) (asp's 6587791, 5955313) (asp's 658719, 5955299) 12. Present well condition summary Total depth: measured true vertical 12988 feet Plugs (measured) 8994 feet 6. Datum elevation (DF or KB feet) RKB 55 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number C-05A 9. Permit number / approval number ~.~.~g, ,... 10. AI~'~Mf~~=~-'',~ 50-029-20126-01 11. Field / Pool Prudhoe Bay Oil Pool Effective depth: measured true vertical 12926 feet Junk (measured) 8999 feet Casing Length Conductor 119' Surface 2660' Size Cemented Measured Depth True Vertical Depth 20" x 30" 135 sx AS 139' 139' 13-3/8" 3250 sx AS 2680' 2680' Production 9878' 9-5/8" 1819 Howco Lite, 1400 9898' 7589' sx Class 'G', 185 sx PF Liner 2332' Sidetrack Liner 2094' 7" 1100 sx Class 'G' 9353' - 11685' 7213' - 8873' 2-3/8" 67.4 c.f. Class 'G' 10892' - 12986 8304' - 8994' Perforation depth: measured Open Perfs 11975' - 12050', 12500' - 12920' RECEIVED true vertical Open Perfs 8989' - 8996', 8996' - 8999' FEB 1 5 2002 Tubing (size, grade, and measured depth) 4-1/2", 12.75#, N-80 TBG @ 10958'. 4-1/2 Tubing to 11076'. Naska0il&GasCa~.C0mmissi0n Packers & SSSV (type & measured depth) 9-5/8" x 7" BOT Packer @ 9373'. 4-'1/2" x 2-3/8" Baker Tieback SLV @ 10891'. 7" x 4-1/2" BOT Packer @ 10996', 4-1/2" Otis SSSV Landing Nipple @ 2098'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 01/15/2002 Subsequent to operation 01/19/2002 Representative Daily Avera,qe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Well Shut-In 398 2085 12 Casing Pressure Tubing Pressure 160 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. ,~~~~)~.~~ Title: Technical Assistant DeWayne R. Schnorr Form 10-404 Rev 06/15/88 · Date January 2512002 Prepared by DeWayne R. S~hnorr 564-5174 SUBMIT IN DUPLICAT'~ (' C-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/23/2001 SBHP/FBHP SURVEY: SBHPS 11/28/2001 PERF(ADD-PERF): DRIFT W/1.7" D.G. (PRE CTU APERF) 01/16/2002 PERF(ADD-PERF): MEN LOG/ADD PEI:IF 01/17/2002 PERF(ADD-PEI:IF): ADD-PERF 01/18/2002 PERF(ADD-PERF): N2 LIFT EVENT SUMMARY 10/23/01 OBTAIN PRESSURE STOPS @ 8600', 8700' & 8800' TYD SS. GOOD DATA. PRESSURE @ 8800 TVD SS = 3203 PSI. RDMO. WELL LEFT SHUT IN. 11/28/01 DRIFT W/1.7" D.G. TO 11,500' SLM (DID NOT SIT DOWN). RDMO. LEFT WELL SHUT-IN. ***DRIFTED 600' INSIDE OF THE 2 3/8" LINER, UPCOMING CTU ADD PERF*** 01/16/02 MIRU DS CTU #1. MU WFD 1-11/16" MHA & SWS MEMORY TOOLS, LOG GR/CCL FROM 11,700' TO 12,150'. FLAG AT 11,900' CT EOP. POOH. MU 25' SWS 1.56" 6 SPF GUNS. RIH TO FLAG, CORRECT DEPTH - DROP 1/2" STEEL BALL- SHOOT INTERVAL FROM 12025'-12050'. POOH, CUT OFF 1' OF PIPE, PUT ON NEW CONNECTOR AND 1-11/16" MHA AND 25' SWS 1.56" 6 SPF GUN. RIH. 01/17/02 MU 25' SWS 1.56" 6 SPF GUNS (2ND GUN RUN). RIH TO FLAG, REPAINT, AND CORRECT DEPTH. DROP 1/2" STEEL BALL AND FIRE GUNS FROM 12000'- 12025', POOH. MU FINAL 25' SWS - 1.56" PJ GUN, RIH TO FLAG AND CORRECT DEPTH (23' CORRECTION). DROP 1/2" STEEL BALL AND FIRE GUNS FROM 11975'-12000', POOH. BREAK OFF GUN #3, MU 1.75" JSN. RIH PUMPING N2 @ 300 SCF/MIN. ***JOB IN PROGRESS*** 01/18/2002 FINISH PUMPING N2 IN WELL AT 500 SCF/MIN FROM 7000'- PUMP TOTAL OF 6500 GALS OF N2. LEFT WELL FLOWING AT 250 BOPD, 1500 BWPD, 2.5 MMSCFD GAS - FLOWLINE TEMP IS 75 DEGF. FLUIDS PUMPED BBLS 175 60/40 METHANOL WATER 155 6500 GALS NITROGEN (155 BBLS) 33O TOTAL ADD PERFS 01/16-17/2002 THE FOLLOWING INTERVAL WAS PERFORATED USING THE 1.56" PJ, 6 SPF, RANDOM ORIENTATION. 11975'-12050' Page I ,~" STATE Of ALASKA ' ALASK OIL AND GAS CONSERVATION ~,~.,~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1963' FNL, 879' FEL, Sec 19, T11N, R14E UM At top of productive interval 763' FNL, 821' FEL, Sec 25, T11N, R13E UM At effective depth 503' FNL, 1727' FEL, Sec 25, T11N, R13E Um At total depth 517' FNL, 1801' FEL, Sec 25, T11N, R13E UM CTD Pre & Post-Work, Acid 5. Typel~ well: Development [] Exploratory [] Stratigraphic [] Service (asp's 66516, 5959256) (asp's 659704, 5955074) (asp's 658793, 5955315) (asp's 658719, 5955299) 6. Datum Elevation (DF or KB) KBE = 55.35 feet 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number C-05A 9. Permit Number / Approval No. 201-002 10. APl Number 50- 029-20126-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12988 feet true vertical 8994 feet Effective depth: measured 12912 feet true vertical 8999 feet Casing Length Size Structural Conductor 110' 20" Surface 2655' 13-3/8" Intermediate 9873' 9-5/8" Production Liner 2332' 7" Sidetrack Liner 2093' 2-3/8" Plugs (measured) Junk (measured) Window @ 11685' - 11691'. Abandoned 7" csg from 11685' to 11936'. Cemented MD 135 Sx AS 135' 3250 Sx AS 2680' 1819 Howco Lite, 1400 Sx Class 'G', 9898' 1100 Sx Class 'G' 12 Sx Class 'G' 9353'-11685' 10892'-12985' TVD BKB 135' 2680' 7589' 7214'-8873' 8304'-8995' Perforation depth: measured Open Perfs 12500' - 12920' true Vertical Open Perfs 8996' - 8999' Tubing (size, grade, and measured depth) 4-1/2" N-80 tubing to 10958' with 4-1/2" tailpipe to 11076' Packers and SSSV (type and measured depth) 9-5/8" Packer (DOT) @ 9373', 7" Packer (DOT) @ 10996', 4-1/2" Otis SSSVLN @ 2098'. 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure RECEIVED JUN 0 8 Z001 Alaska Oil & Gas Cons. Commission 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Anchorage Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby ceGify th.at the foregoing i~ true and correct to the best of my knowledge Signed ~ ~'~~ DeWayne R. 8~hnorr t... ....... Tit. le Technical Assistant Prepared By Name/Number: Form 10-404 Rev. 06/15/88 ORIGINAL DeWayne Schnorr 564-5174 ~bmit In DupliCate C-05A (' DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/27/2001 05/15/2001 05/22/2001 05/23/2001 05/24/2001 OTD-POST WORK: N2-LIFT TO FLOW (POST-OTD) ACID: TIFL ACID: ACID STIM / N2 KICK OFF ACID: ACID STIM / N2 LIFT --DAY 2-- ACID: N2 LIFT POST ACID --DAY 3-- SUMMARY 02/27/01 MIRU DOCT #3, LINE UP WELL TO TEST SEPARATOR. RIG UP N2- PUMPER. RIH WITH 3" JSN. START LIFTING FROM 6000' CTM (295 PSI FLOWLINE PRESSURE). RIH LIFTING FROM 6000' AT 100 FPM, 750 SCF/MIN N2 RATE. TAG LINER TOP AT 10908' CTMD (DOWN WT). LIFT WELL OFF FROM LINER TOP. LOOKS LIKE WELL FLOWING W/305 PSI WHEN PUMPER EMPTY. APPROX. 152 MSCF (1650 GAL) OF N2 PUMPED. POH WHILE MONITORING WELL. CONTINUE TO MONITOR WELL WHILE DOING CHAIN INSPECTION AND PACK-OFF CHANGE OUT. WELL APPEARS TO BE HOLDING ITS OWN AND CLEANING UP. FWHP = 230 PSIG, FWHT = 89 DEG F, 2700 BOPD, 2000 BWPD, 7 MMSCF/D. *** JOB COMPLETE - WELL TO REMAIN IN TEST 05/15/01 TIFL PASSED 05/22/01 RIH WITH 1.75" SLICK- CRC/DCK/2 EA STING/JSN, BULLHEAD KILL W/FILTERED 2% KCL. 5 BPM, 850 PSI WHP. KILL W/250 BBLS KCL, LOAD W/120 BBLS CRUDE. TAG AT 12726' ABD 12753'. ATTEMPT JET THRU, AND RIH NOT PUMPING. TAG PBTD AT 12912'. JET ACID 05/23/01 ***CONT... TAG BOTTOM AT 12,912', UNABLE TO RIH PUMPING AT MAX RATE, JET30 BBLS ACID FROM 12900' TO 12475', SOAK 30 MIN. JET 2ND STAGE OF 45 BBLS AS REClP ACROSS PERFS. JET W/FILTERED KCL AND OVERFLUSH W/100 BLS. JET N2 FROM 6000' JETTING TO LINER TOP, PUH TO HELP BRING ON, RBIH TO LINER TOP. LIFT WELL W/N2 @ 500- 700 SCF/D. 05/24/01 ***CONT*** RIH PUMPING N2 TO 7500' PUMPING 750 SCF/MIN. CONTINUE RIH TO 9500' PUMPING SAME. WHP=170. FL TEMP RANGE: 90 - 110 DEG, RIH TO 10,750 AND PUMP N2 @ 1500 SCF/MIN FOR 30 MIN. BRING BACK TO TIGER TANK TO SAMPLE WELL FLUID---100% THICK CRUDE. POOH. TEST WELL TO TANK W/OUT N2 LIFT SUPPORT. FLOW FOR 1 HR @ 420 PSI--SAMPLE IS SAME--THICK CRUDE, TEMP = 100 DEG. >>>WELL LEFT FLOWING TO SYSTEM--LP W/96 BEAN (WIDE OPEN) CHOKE<<< ***NOTIFY PCC AND PAD OPERATOR WELL IS TO REMAIN FLOWING AND TEST WHEN FACILITY BECOMES AVAILABLE*** Fluids Pumped BBLS. Description 750 2% KCL WATER 25 60/40 METHANOL WATER 120 CRUDE 75 12%/10% HCL/XYLENE 125.8 5285 GALLONS OF NITROGEN 1095.8 TOTAL C-05A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/27/2001 05/15/2001 05/22/2001 05/23/2001 05/24/2001 CTD-POST WORK: N2-LIFT TO FLOW (POST-CTD) ACID: TIFL ACID: ACID STIM / N2 KICK OFF ACID: ACID STIM / N2 LIFT --DAY 2-- ACID: N2 LIFT POST ACID --DAY 3-- SUMMARY 02/27/01 MIRU DOCT #3, LINE UP WELL TO TEST SEPARATOR. RIG UP N2- PUMPER. RIH WITH 3" JSN. START LIFTING FROM 6000' CTM (295 PSI FLOWLINE PRESSURE). RIH LIFTING FROM 6000' AT 100 FPM, 750 SCF/MIN N2 RATE. TAG LINER TOP AT 10908' CTMD (DOWN WT). LIFT WELL OFF FROM LINER TOP. LOOKS LIKE WELL FLOWING W/305 PSI WHEN PUMPER EMPTY. APPROX. 152 MSCF (1650 GAL) OF N2 PUMPED. POH WHILE MONITORING WELL. CONTINUE TO MONITOR WELL WHILE DOING CHAIN INSPECTION AND PACK-OFF CHANGE OUT. WELL APPEARS TO BE HOLDING ITS OWN AND CLEANING UP. FWHP = 230 PSIG, FWHT = 89 DEG F, 2700 BOPD, 2000 BWPD, 7 MMSCF/D. *** JOB COMPLETE - WELL TO REMAIN IN TEST 05/15/01 TIFL PASSED 05/22/01 RIH WITH 1.75" SLICK- CRC/DCK/2 EA STING/JSN, BULLHEAD KILL W/FILTERED 2% KCL. 5 BPM, 850 PSI WHP. KILL W/250 BBLS KCL, LOAD W/120 BBLS CRUDE. TAG AT 12726' ABD 12753'. ATTEMPT JET THRU, AND RIH NOT PUMPING. TAG PBTD AT 12912'. JET ACID 05/23/01 ***CONT... TAG BOTTOM AT 12,912', UNABLE TO RIH PUMPING AT MAX RATE, JET30 BBLS ACID FROM 12900' TO 12475', SOAK 30 MIN. JET 2ND STAGE OF 45 BBLS AS RECIP ACROSS PERFS. JET W/FILTERED KCL AND OVERFLUSH W/100 BLS. JET N2 FROM 6000' JETTING TO LINER TOP, PUH TO HELP BRING ON, RBIH TO LINER TOP. LIFT WELL W/N2 @ 500- 700 SCF/D. 05/24/01 ***CONT*** RIH PUMPING N2 TO 7500' PUMPING 750 SCF/MIN. CONTINUE RIH TO 9500' PUMPING SAME. WHP=170. FL TEMP RANGE: 90 - 110 DEG. RIH TO 10,750 AND PUMP N2 @ 1500 SCF/MIN FOR 30 MIN. BRING BACK TO TIGER TANK TO SAMPLE WELL FLUID---100% THICK CRUDE. POOH. TEST WELL TO TANK W/OUT N2 LIFT SUPPORT. FLOW FOR 1 HR @ 420 PSI--SAMPLE IS SAME--THICK CRUDE. TEMP = 100 DEG. >>>WELL LEFT FLOWING TO SYSTEM--LP W/96 BEAN (WIDE OPEN) CHOKE<<< ***NOTIFY PCC AND PAD OPERATOR WELL IS TO REMAIN FLOWING AND TEST WHEN FACILITY BECOMES AVAILABLE*** Fluids Pumped BBLS. Description 750 2% KCL WATER 25 60/40 METHANOL WATER 120 CRUDE 75 12%/10% HCL/XYLENE 125.8 5285 GALLONS OF NITROGEN 1095.8 TOTAL Transmittal Form BAKER HUGHES Baker Atlas Canada GEOSciences Centre To: State of Alaska, Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Lisa Weepie Reference: Pmdhoe Bay North Slope, Alaska C-05A Contains the following: 1 LAS Format disk 1 Film 1 Measured Depth GR print 1 TVD-GR print Sent By: J0sef~l~rg " Date: May 18, 2001 Received ~~/~~,~~)''" Date: [ .. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING A COPY TO BP EXPLORATION (ALASKA) PETROCHEMICAL DATA CENTER 900 E. BENSON BLVD.. , ANCHORAGE, ALASKA 99508 Baker Atlas #1300, 401-9th Ave. S.W. Calgary, Albert a, Canada T2P 3C5 Direct: (403).537-3752 FAX: (403) 537-3767 RECEIVED flAY 23 ?.001 LL,;,..:i,..2; "2 :,:,, ',";:,'L 2,~,L7,';~ ~ ~ ' . :;r:":::'..: ;~ :J,','C:&,I. ., ~..'. ' ,.....L .... '-,, ,,, ?.'i :, ,, ~'; ............. .... ';.' .~ I. ' r", '"! ~ ................ "; .............. I T'" ~'''" .............. ...... ...~ ......... , ...... ~ ........... . t~.' , . ' '~ ~., (~.:.,-.,,.,i "'i,2':,J;.I ', :,. .... ,.,~,¥" ....... "' ......... ' ........ :.:.:.':2':'?Z~z.~':"."' .',..' }:.,:,:::~::,,,:: 4~, ......... i~ ........ "'"'~ ': , ;.~ ...... Ii .......... .:?~... Y~':;;:".":: ~ ?::::::¢::'::'5,;::; ',/, ........ :; i ............. '. ,',,L...: !r~7,'2,;,.,:2.,[ LJ.3 ,L':., 5,.'... ~.1i.,..,[ ........ ~ ~ ..................... ; r.: .~ ...... ?' ~, · ,. ~ ...... ~ ..... ','.2,,'.;.. :'.'~ . 3,,';' :.*,'~'.:',; ,.. '..' -~. ~, :, ,, .,,a.,,~;,." ....................... Z,S&Z2':':.:;,i .... ~. ,~ ~,. .... ~.. ................. ~.. ..... ":'.;' :7-:,,':, ~ ' :.'.:...":. :':. ': ,~.["J';,:'.":2 2..&."2J "~,2 .... ,...; L.:';, I ......................... ........ i ~,,'," ...... : .... ,' ..... I '' '." ..... ,..,... ,,. ~ i,~ ....... ,,~: ........... . ~.... ..... ~ ................. , .............. ~ ; ..................... Naska Oil & Oas Cons. Commisdon Anchorage i ,........., : 4/3/01 Schlumkerger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrle NO. T29 Company: State of Alaska Alaska Oil & Gas Cons Comm Afln: Lisa Weepie 333 West 7Ih Ave, Suite 100 Anchorage, AK 99601 Field: Prudhoe Bay Color Well ,lob # Log Description Date Blueline Sepia Prints CD D.$.5-11A /~/~..-Oc~_~ 21142 MCNL 03/08/01 1 1 1 D.S. 4-48 / ~/..//'"O4~ 21131 RST-SIGMA 02/13/01 1 1 1 H-20 ) ~"0~'~ 21141 RST-SIGMA 03112/01 1 1 1 C-05A ,,,-~C)J-'C)O~ 21121 MCNL 02/17/01 1 1 1 -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED APR 0 6 2001 J""~l~ VII ~.~ V~ ~ ....... Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie STATE OF ALASKA (" ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well OIL r~ GAS F'~ SUSPENDED D ABANDONED r=] SERVICE [~~ .2. Name of Operator .,,,,,,-~e,~'~a i~ 7. Permit Number BP Exploration (Alaska), Inc. ,'~'~, 201-002 :3. Address i~ ~ 8. APl Number P. O. Box 196612 Anohorage, AK 99519-6612 !'~~ 50-029-20126-01 4. Location of well at surlace ...... . .:. :~.;.-. ~ 9. Unit or Lease Name 1963' FNL, 879' FEL, Sec. 19, T11 N, R14E, UM (asp's 664516, 5959256) i ,j ,. ;.: ~ Pmdhoe Bay Unit At Top Producing Intewal i ...~.~../.? ;--~ i 10. Well Number 763' FNL, 821' FEL, SEC 25, T11N, R13E, UM (asp's 659704, 5955074) i ..~: ~.::. ..... ,..: ~ C-05A At Total Depth i _,/~_L~ .~ 11. Field and Pool 517' FNL, 1801' FEL, SEC 25, T11 N, R13E, UM (asp's 658719, 5955299) ................... Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serfal No. RKB 55.4 feetI ADL 28286 Prudhoe Bay Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. J 15. Water Depth, if offshore, 16. No. of Completions February 6, 2001 February 13, 2001 February 18, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug BacR Depth (MD + TVD) 19. Directional Suwey J2o. Depth where S~SV set 21. Thickness of Perrnatmst 12988' MD / 8994' TVD 12926' MD / 8999' TVD YES I~1 No r"lJ 2098' feet MD 1900' (approx) 22. Type Electric or Other Logs Run MWD GR & Mem QR/CClJCNL 23. CASING, LINER AND CEMENTING RECORD SE'ri'lNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FrOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20' 133# H-40 Surface 119' 26' 135 Sx AS 13-3/8' 68#/72# N-80 Surface 2680' 18-1/2' 3250 Sx AS 9-518' 47# N-80 Surface 9898' 12-114' 1819 Howco Ute, 1400 Sx Class G, & 185 Sx PF 7' 29# N-80 9353' 11685' 8-1/2' 1 lO0 Sx Class G 2-3/8' 4.6# L-80 10892' 12985.5' 3" 12 bbls Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD latewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2' 10958' 10996' (Used 1-11/16' carriers & all perfs in Zone 2,4) 4-1/2' 11080' 937.3' 12500' - 12920' MD; 8996' - 8999' TVD; O 4 SPF 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See Sidetrack Summary for details) 27. PRODUCTION TEST Date.First Production Method of Operation (Flowing, gas lift, etc.) February 27, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 3/10/2001 4.0 Test Period > ~ 2806 Row Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. -229 psi 24-Hour Rate > 1356 3805 28 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pmssence of o11, gas orwater. Submit core chips. * This 10-407 is submitted as directed per lhe 10-401 form approved January 17, 2001 (Permit #201-002) MAR Z 8 2001 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit ia duDIIoate A~oh0rage 2~. ~,, 30. ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data. all fluids recovered and MEAS. DEPTH TRUE VERT. DEPTH gravity, GOR. and time o! each phase. Top of Sag River Sand 11103' 8453' Top of Shublik 11143' 8481' Top of Sadlerochit 11254' 8560' Top of Zone 2A 11953' 8988' 31. LIST OF ATTACHMENTS Summary of C-05A CT Sidetrack Drilling Operations + End of Well Survey. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed , -~ v ~ Title Coil Tublncl Drillin'_cl Eneineer Date_ March 27, 2001 Larnar Gantt , Prepared by Paul Rauf 564-5799. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg 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: Ind'ic~ate 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Item 28: If no cores taken, indicate 'none'. ORIGINAL. Form 10-407 RECEIVED MAR 2 8 2001 0ii & 6ss C~s. ~i0r BP EXPLORATION Final Well I Event Summary Page 1 of 1 Legal Well Name: C-05 Common Well Name: C-05A Event Name: DATE 2/2/2001 2/3/2001 2/4/2001 2/512001 2/6/2001 2/7/2001 2/812001 2/9/2001 2/10~2001 2/1112001 2/12/2001 2/1312001 2/1412001 2/1512001 2/1612001 2/1712001 2118/2001 REENTER+COMPLETE TMD (ft) (ft) 11,648.o (ft) 11,7Ol.O (ft) 11,701.0 (ft) 11,701.0 (fi) 11,981.0 (fi) 12,275.0 (ft) 12,547.0 (ft) 12,612.0 (ft) 12,960.0 (ft) 12,988.0 (ft) 12,987.0 (ft) 12,987.0 (ft) 12,987.0 (ft) 12,987.0 (ft) 12,967.0 (ft) Start Date: 2/2/2001 End Date: 24 HOUR SUMMARY Moved Rig on well and Rigging up Install engine clutch and modification on hydraulic tugger. NU BOP's and PT same. Pull BPV and MU BH^ #1. RIH and drilled cement ramp, casing exit and formation BHA backed-off while being M/U. Fished lost BHA with braided wireline. Installed 2" P-S in btm TOT. P/T. RIH wi BHA#4. Dressed window. POO Finish dressing window. Chk out electric chair. Start drilling. Land well in HOT at 12275'. Run PDS mem ind log. MU BHA. RIH BHA#6 to bottom. Drilled ahead to 12547'. POOH BHA#6. Tested BOPE. RIH BHA#7. Drilled to 12612'. .Continue drilling to 12960°. TD well at 12987'. Condition hole. Function test TIW equip. Run liner. RIH 2-3/8" liner to HUD ~ 11965'. POOH liner. RIH & conditioned hole. Picked up & ran 2 3~8" FL4S liner. Cemented in place. WOW Logged CNL/GR/CCL. Lay-in new FIo-Pro. P/test liner lap to 2k - OK. IJD & download memory log. RIH guns & perforate fl 12500'- 12920'. L/D perf guns, FP well. Set BPV, ND BOPE. Release rig. RD CTD equipt RECEIVED MAR 2 8 2001 Alaska 011 & Gas Cons. Commissio Anchorage Printed: 3/27/2001 12:46:10 PM BP EXPLORATION Page I of 6 Operations Summary Report Legal Well Name: C-05 Common Well Name: C-05A Spud Date: 5118/1973 Event Name: REENTER+COMPLETE Start: 2/212001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: 2/18/2001 Group: COIL 'Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code 2/2/2001 00:00 - 06:00 6.00 MOB PRE . Move CTD from C-33A to C-05A '06:00 - 18:00 12.00 MOB PRE Spot CT trailer, pits Gen set, cat walk, spread herculite for MP's, Lay matsand spot MP. MU HP lines, suction lines, repair camera on derrick, raise derrick 18:00 - 19:00 1.00 MOB PRE Raised Catwalk 19:00 - 21:00 2.00 MOB PRE Attempted to NU, need 2nd master valve for height 21:00 - 22:00 1.00 MOB PRE Remove stand pipe from derrick 22:00 - 00:00 2.00 MOB PRE Remove clutch from prime mover, welder installing tugger base, work on berms, Clean C-33a location 2/3/2001 00:00 - 06:00 6.00 MOB PRE RU CDR#l, Installing tugger on floor and repacing drawworks clutch. Tested deck engine. OK 06:00 - 00:00 18.00 MOB PRE Working on Tugger and stand, finish RU associated equipment 2/412001 00:00 - 01:00 1.00 MOB PRE Finish RU associated equipment and tugger. Rig accepted at 00:01 hrs 2-4-2001. 01:00- 10:30 9.50 MOB PRE NU BOPE. 10:30 - 19:00 8.50 MOB PRE Pressure Test BOP as per AOGCC regulations. AOGCC rep J. Jones waived witnessing test. 19:00 - 20:00 1.00 MOB 'PRE Rack back injector. Prep to pull BPV. 20:00 - 20:30 0.50 MOB PRE Held Operational & Safety Meeting.concerning PU window BHA's and overall concept of project. 20:30 - 22:00 1.50 MOB PRE Pull BPV from tubing hanger with lubricator. 22:00 - 00:00 2.00 STWHIP WEXlT RU and surface test orienter - OK. MU whipstock BI-IA #1. 21512001 00:00 - 00:30 0.50 STVVHIP WEXlT PU Cement ramp milling BI-IA ~00:30 - 01:30 1.00 STWHIP WEXlT Displaced CT MEOH to 2% KCL VP = 43 bbl's 01:30 - 05:15 3.75 STWHIP WEXlT RIH and conducted shallow hole MWD test (OK) 05:15 - 07:00 1.75 STWHIP WEXlT Ran Tie-in log from 11500' to 11620', (-80' Correction) RIH and tagged to top of the cement at 11648' 07:00 - 08:15 1.25 STWHIP WEXlT Drilling cement ramp at 250 psi Delt P and approximately 30 fph 08:15 - 08:57 0.70 STWHIP WEXlT Drilled to 11677' and PU and Orient TF to HS 08:57 - 10:20 1.38 STWHIP WEXlT Finished Ramp at 11685' Reactive TF, Pumped 10 bbl Biozan around. Painted white flag at 11684' 10:20 - 13:00 2.67 STWHIP WEXlT POOH, painted flag at EOP at 11400', 13:00 - 14:30 1.50' STWHIP WEXlT OOH, Stand back injector head, change out BHA. Change out counter wheel (electric) 14:30 - 17:07 2.62 STWHIP WEXlT RIH with window exit BHA 17:07 - 18:45 1.63 STWHIP WEXlT Stopped at 11519 to tie-in. Orient TF to HS, Tie-in from 11506' down. Make +4' depth corr'n for TOW at 11684' corrected depth. 18:45 - 00:00 5.25 STWHIP WEXIT Start milling window per schedule from programme. 1.611.6 bpm. 2650 psi. 45L. Mill down to 11686' for midnight - 2' progress. 1.6/1.6 bpm. 2915 psi. 60L. 21612001 00:00 - 03:45 3.75 STWHIP WEXlT Continue milling window from 11684'.to 11691' (6 it) through window. 03:45 - 04:45 1.00 STWHIP WEXIT On formation ~ 11691', Pump 10 bbl biozan pil at 11693, some mill stacking Drilled fromation from 11691' to 11701' TOW ~ 11684' and BOW ¢~ 11691', TOC~ 11648' 04:45 - 07:22 2.62 STWHIP WEXlT POOH to 500' and stopped to monitor the well conditions 07:22 - 07:35 0.22 STWHIP WF_.XlT PUH to surface .07:35 - 08:30 0.92 STWHIP WEXIT OOH change out BHA. 08:30 - 09:30 1.00 STWHIP WEXIT Stab on Well and unable to go in the hole. PUH and found the BHA ,CF~,iV ~ D had backed off below the circ sub. Length of fish = 103' with a 2.375" " OD FN and 2.00" ID. The cyber system shut the 2" TOT combi and "' while making up BHA, the connection above the DC backed off. With ,~P~ ~ 8 ~0(~ ~ the inability of the tool string to go in the hole, the crew found that the 2" combi were inadvertently closed and then ordered to open. Still was R£C BP EXPLORATION Page 2 of 6 Operations Summar Report Legal Well Name: C-05 Common Well Name: C-05^ Spud Date: 5118/1973 Event Name: REENTER+COMPLETE Start: 2/2/2001 End: Contractor Name: N^BORS TRANSOCEAN Rig Release: 2/18/2001 Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code 2/6/2001 08:30 - 09:30 1.00 STWHIP WEXlT unable to RIH. Set injector back and found the tool string below the circulating sub backed off and was dropped in the hole. 09:30 - 12:45 3.25 STWHIP BARR 'WEXlT Wait on Wireline to fish BHA. Rig on repair time from 0930 hrs on 2/6101. Will go to zero dayrate at 1730 hrs per contract. 12:45 - 14:00 1.25 STWHIP BARR WEXlT HES slickline arrive on location. Spot unit and start PU tools to floor. 14:00 - 14:30 0.50 s'rWHIP WEXlT PJSM for non routine operation with HES slickline, Nabors, BPX drilling and WL supv to discuss hazards & RU of job. = 14:30 - 17:00 2.50 STWHIP BARR WEXlT Continue RU of HES slickline. MU overshot and jars. Install riser and WL packoff. 17:00 - 18:00 1.00 STWHIP BARR WEXlT RIH with 3" OD OS to engage 2.375" OD fish. Tag TOF at 11810' WLM. 18:00 - 18:15 0.25 STWHIP BARR WEXlT Engage OS over fish and set same. Attempt to move fish pulling up to 2200 lbs - no success. Shear off overshot and leave fish baited. POH with slickline. 18:15 - 20:30 2.25 STWHIP:BARR WEXlT OOH. R/D slick line and R/U braided line. 20:30 - 22:30 2.00 s'rWHIP BARR WEXlT RIH with O/shot and engaged fish. Jarred and pulled fish free with 4000 lbs. POOH and recovered fish 100%. 22:30 - 00:00 1.50 STWHIP BARR WEXlT Secured and L/D BHA. R/D HES wireline. 2/7/2001 00:00 - 00:30 0.501 STWHIP BARR WEXlT Finish LD BHA dropped in hole. No indication of damage but LD as precaution. 00:30 - 01:00 0.50 STWHIP BARR WEXlT Fill hole and observe well - stable. 01:00 - 02:30 1.50 STWHIP BARR WEXlT Pressure test 2 3~8" combis - OK. 02:30 - 04:00 1.50 STWHIP BARR WEXlT Service injector. 04:00 - 04:45 0.75 STWHIP. BARR WEXIT General maintenance and housekeeping. 04:45 - 05:15 0.50 STWHIP BARR WEXlT H2S alarm in cellar went off. Evacuate rig. Call pad operator. Re-enter with air packs and sniff area with 4 monitors - all negative. Allow re-entry & electrician to check and re-calibrate sensor. 05:15 - 08:00 2.75 STWHIP BARR WEXlT Cent general maintenance and housekeeping. 08:00 - 11:00 3.00 STWHIP BARR WEXlT Install 2" combis in bottom TOT cavity. Test to 300/3500 psi. De-energise upper TOT ram. Body test stack. = 11:00 - 12:00 1.00 STWHIP WEXlT MU BHA #.4 for dressing window - crayola mill. 12:00 - 14:30 2.50 STWHIP WEXlT RIH with BHA ~4. Shallow test MWD. Tie into EOP flag, ( -15' correction). 14:30 - 15:15 0.75 STWHIP WEXlT Log tie in wi GR, (+7' correction). 15:15 - 22:30 7.25 STWHIP WEXlT RIH and tag-up ~ 11684'. Attempted thrice to pass thru window at 30R 'TF - no success. Reamed down at 30 - 50R. Made several backream passes. POOH above TOC. RIH dry & backreamed. Could not pass thru window dry at 30-60L. Passed thru with pumps on & backreamed. Observed orientor not clicking. Pumped 10 bbls biozan sweep. 22:30 - 00:00 1.50 STWHIP WEXlT POOH BHA#.4. Paint EOP flag ~ 11400'. 2/8/2001 00:00 - 01:20 1.33 STWHIP WEXlT Continue POOH with BHA ~4. 01:20 - 01:45 0.42 STWHIP WEXlT OOH. LD BHA#4. 01:45 - 13:00 11.25! STWHIP BARR WEXlT H~ec checked out cyber controls. 13:00 - 13:30 0.50 DRILL PROD1 MIU BHA#5, build assembly. 13:30 - 16:30 3.00 DRILL PROD1 RIH BHA#5, shallow hole test - OK. Continue RIH and tie into EOP flag, ( -22' correction). 16:30 - 17:05 0.58 DRILL PROD1 Log tie in wi GR, (+6' correction). 17:05 - 17:15 0.17 DRILL PROD1 Continue RIH and tag-up ~ 11,700'. 17:15 - 18:05 0.83 DRILL PROD1 Drill ahead to 11,750', wi 20R TF, 2750 psi freespin ~ 1.6 bpm, 3K E~ ~8:~D WeB, 200 dp on motor, PIU into liner and circulate hole to new Fie-Pro mud. 100 fph ReP. ~%EC 9:00 0.92 DRILL PROD1 19:00 - 20:40 1.67 DRILL PROD1 Orient to 90R and drill ahead to 11,809' wi 2750 psi freespin @ 1.6 bpm, 3K WeB, 200 dp on motor, 90 fph ReP. 120 degs reactive MAR 2~ 8 ~)001 torque. Anchorage Printed: 2/26/2001 3:09:29 PM BP EXPLORATION Page 3 of 6 Operations Summa Report Legal Well Name: C-05 Common Well Name: C-05A Spud Date: 5118/1973 Event Name: REENTER+COMPLETE Start: 2/2/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: 2/18/2001 Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code 21812001 20:40 - 21:30 0.83: DRILL PROD1 Orient to 90L and drill ahead to 11,830' wi 2750 psi freespin ~ 1.6 bpm, 3K WOB, 250 dp on motor, 60 fph ROP. 21:30 - 22:15 0.75 DRILL PROD1 Orient to 90R and drill ahead to 11,870' w/2750 psi freespin @ 1.6 bpm, 3K WOB, 250 dp on motor, 90 fph ROP. 22:15 - 00:00 1.75 DRILL PROD1 Orient to 20-60R and drill ahead to 11,981' wi 2750 psi freespin ~ 1.6 bpm, 3K WOB, 250 dp on motor, 90 fph ROP. 21912001 00:00 - 05:45 5.75 DRILL PROD1 Drill ahead and land well at 8955' 'FVD. Samples indicate HOT approx 11' TVD deep to prog ~ 8954' TVD. 05:45 - 06:30 0.75 DRILL PROD1 Circ up sample while POH to window. 06:30 - 06:45 0.25 DRILL PROD1 15 min flow check. 06:45 - 09:30 2.75 DRILL PROD1 POH for memory induction log to look for water contact. Flowcheck at 500' - OK. 09:30 - 10:00 0.50 DRILL PROD1 Stand back injector. LD BHA. 10:00 - 10:45 0.75 EVAL PROD1 RU For PDS memory induction log. 10:45 - 11:00 0.25 EVAL PROD1 PJSM and hazard analysis for running log. 11:00 - 14:00 3.00 5VAL :~ROD1 MU tool. Stab injector. RIH with ind log. Correct depth at EOP flag at 11400' (-22'). 14:00 - 16:30 2.50 EVAL PROD1 .Log down from 11430' to TD at 1276'. Work past tight spot at 11770-11810'. Circ at 1.0 bpm to bottom and log back out at 30 fpm. 16:30 - 19:30 3.00 EVAL PROD1 POH. Stand back injector. LD logging tool. 19:30 - 23:00 3.50 EVAL PROD1 Install double gate valves on BOP stack outlet below bottom ram for WHP transducer while waiting on data from memory induction log. Test 'to 3500 psi - OK. 23:00 - 00:00 1.00! DRILL PROD1 Induction log showed good resistivity >20 ohm from 11950'-12150'. Prep to PU BHA to drill ahead. 2110/2001 00:00 - 00:30 0.50 DRILL PROD1 MU BHA #6. Test orienter. Stab injector. 00:30 - 03:30 3.00 DRILL PROD1 RIH to flag at 11400' EOP. Correct depth (-29'). 03:30 - 05:10 1.67 DRILL PROD1 Log down from 11520' for tie in (corr'n -1'). 05:10 - 05:40 0.50 DRILL PROD1 RIH to bottom. 05:40 - 06:45 1.08 DRILL PROD1 Orient to 15-30R and drill ahead to 12331' wi 3100 psi off-btm ~ 1.6 bpm, 3K WOB, 150 dp on motor, 120 fph ave ROP. ' 06:45 - 06:55 0.17 DRILL PROD1 Short 100' wiper trip due to weight stacking. 06:55 - 09:10 2.25 DRILL PROD1 Drill ahead to 12390' ~ 20-30R, wi 3100 psi off-btm ~ 1.6 bpm, 5K WOB, 150 dp on motor, 45 fph ave ROP. 09:10 - 10:30 1.33 DRILL PROD1 Orient to 90R and drill ahead to 12410° w/3100 psi off-btm ~ 1.6 bpm, 6K WOB, 150 dp on motor, 50 fph ave ROP. 10:30 - 12:00 1.50 DRILL PROD1 Wiper tripped to tubing tail and observed tight spots ~ 11940' and 11760'. 12:00 - 20:15 8.25 DRILL PROD1 Pumped 10bbls of LubeTex pill around to improve weight transfer. Orient to 80-130L and drill ahead to 12472' wi 3100 psi off-btm ~ 1.6 bpm, 6-7K WOB, 150 dp on motor, 15 fph ave ROP. Swap hole to new FIo-Pro mud. 20:15 - 22:35 2.33 DRILL PROD1 Orient to 60-95L and drill ahead to 12547' wi 3000 psi off-btm ~ 1.55 bpm, 3-4K WOB, 150 dp on motor, ROP dropped from 80 fph to continous stall-out and no progress. Suspect severe bit wear due to 30-95% chert in drilled formation samples. 22:35 - 00:00 1.42 DRILL PROD1 POOH BHA#6. Paint EOP flag ~ 11400'. Monitor well - stable. Continue POOH. 211112001 00:00 - 02:00 2.001 DRILL PROD1 POH with BI-IA #6. Flowcheck well at 11400' - OK. 02:00-02:30 0.50 DRILL PROD1 OOH. Stand back injector. LD BHA. p~ksr~ot(Le~w~i~d EvD 02:30 - 06:00 3.50 BOPSUF PROD1 RU to test BOPE. Displace CT to MeOH. Wit AOGCC Rep J Jones. 06:00-15:00 9.00 BOPSUI~ PROD1 Test BOPE 300/3500 psi. During the test, obse~i~tr~l~p~d ~r . . Alaskt"l~frd& ~b~?~i/ttnissio~ Anchorage BP EXPLORATION Page 4 of 6 Operations Summar Report Legal Well Name: C-05 Common Well Name: C-05A Spud Date: 5/18/1973 Event Name: REENTER+COMPLETE Start: 21212001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: 2/18/2001 Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code 2111/2OOl 06:00 - 15:o0 9.00 BOPSUF PROD1 on the koomey BOP accumulator control preventing any stack functions from operating. Fixed same & arranged a spare breaker. 15:00 - 15:45 0.75 DRILL PROD1 MU BHA #7. 15:45 - 18:30 2.75 DRILL ~PROD1 ~,IH w/BI-IA #7. Shallow hole test - OK. Continue RIH. 18:30 - 18:35 0.08 DRILL PROD1 RIH to EOP flag ~ 11400' (-32' depth correction). 18:35 - 19:00 0.42 DRILL PROD1 Log and tie-in to GR marker (+8' correction). 19:00 - 19:45 0.75 DRILL PROD1 Continue RIH to bottom. 19:45 - 20:40 0.92 :)RILL PROD1 Drilled to 12559' and stalled out. 20:40 - 00:00 3.33 DRILL PROD1 Orient to 60-90L & drilled to 12612' wi 3000 psi off-btm @ 1.5 bpm, 4K WOB, 200 dp on motor, 25 fph ave ROP & 180degs reactive torque. Had frequent stalling & hard drilling with ~ 50% Chert, 211212001 00:00 - 04:15 4.25 DRILL PROD1 Cont drilling ahead. Slow drilling in Z2 with abundant chert in samples. 04:15 - 05:15 1.00 DRILL PROD1 Wiper trip to window to clean hole and try to improve ROP. 05:15 - 07:00 1.75 DRILL PROD1 Cont drilling ahead - 35-50% chert. 12730': 1,611.6 bpm, 3400 psi. 07:00 - 07:30 0.50 DRILL PROD1 Stuck briefly & work free, Wiper trip up to 12530' to clean hole. 07:30 - 15:30 8.00~ DRILL PROD1 Drill to 12870'. Still much chert in samples. 15:30 - 16:00 0,50 DRILL PROD1 Wiper trip up to 12500'. 16:00 - 18:00 2.00 DRILL PROD1 Drill to 12930', 18:00 - 20:30 2.50 DRILL PROD1 Wiper trip up to window to clean hole. Work tight spot 11955-11990'. 20:30 - 00:00 3.50 DRILL PROD1 Cont drilling to 12960' - 8941' TVD. 1.611.6 bpm. 3400 psi. 2113/2001 00:00 - 03:30 3.50 DRILL :PROD1 Drill to TD at 12986' MDI8939' TVD. Poor ROP and geologist called it good. 03:30 - 05:30 2.00 DRILL PROD1 POH to 11715'. RIH - work tight spot 11920'-12000'. Shale. '05:30 - 06:00 0.50 :)RILL PROD1 Tie in wi gamma, add 2'. 06:00 - 09:30 3.50 DRILL PROD1 Clean & condition hole prior to running liner. 09:30 - 14:00 4.50 DRILL PROD1 POOH laying in new FIo Pro in open hole. 14:00 - 15:00 1.00 DRILL PROD1 MD drilling BI-IA. 15:00 - 16:15 1.25 DRILL PROD1 Displace coil to methanol/water 16:15 - 18:00 1.75 DRILL PROD1 Weld on 1.27" ID coil connector, pull test & pressure test, OK. 18:00 - 20:00 2.00 DRILL PROD1 Displace coil to KCL. M/U (2) 2" valves below mud cross fl testing TIW equipment. 20:00 - 00:00 4.00 CASE COMP PIU (3) its 2 3~8" FL4S & TIW running tools. Ball seat sheared ~, 4000 psi, dart on seat ~ 40.9 bbls away. Sheared wiper plug ~ 3400 psi. LD tools & FL4S. Plug sheared OK. L/D tools & redress. 211412001 00:00 - 00:30 0.50 CASE COMP Pre job on picking up liner. HIIHM. Body positioning, communication. 00:30 - 04:00 3.50 CASE COMP Pick up 2 3~8" FL4S liner & TIW liner running tools. 04:00 - 04:30 0.50 CASE COMP MIU to coil. 04:30 - 07:45 3.25 CASE COMP Correct ~ EOP flag ~ 11,500'. Subtract 23'. 07:45 - 09:15 1.50 CASE COMP Thru window, no bobbles. RIH ~ 40-50 fpm, set down hard @ 11,965'. Try various techniques, pump off, Iow rate, slow run in speed, not penetrating past 11,965'. 09:15 - 13:30 4.25 CASE STAB COMP POOH to pick up drilling assembly & condition hole. 13:30 - 17:00 3.50 CASE STAB 'COMP Lay down liner running tooLs. Ready rack back 2 3/8" FL4S. ,17:00 - 17:30 0.50 DRILL STAB PROD1 M/U hole conditioning BHA. 0.8 degree motor 17:30 - 19:40 2.17 DRILL STAB PROD1 RIH wi drilling assembly to condition hole, shallow hole test OK. 19:40 - 20:00 0.33 DRILL STAB PROD1 RIH to EOP flag (-29' depth correction). I'~ I"/',, ~ t ~ · ,,- ~ 20:00- 20:50 0.83 DRILL STAB PROD1 Log and tie-in to GR marker (-2' correction). K t:: L I:: ! . .V 'i~ U 20:50 - 21:05 0.25 DRILL STAB PROD1 Continue RIH to 12050' without resistance. Passed freely ttiru o ri§~n held-up depth ~ 11965'. 21:05-21:50 0.75 DRILL STAB PROD1 Made several backream passes from 12050'to 111~R 28 2001 21:50 - 22:15 0.42 DRILL STAB PROD1 Continue RIH to 12950' without resistance. 4~aska Oi~ & Ga~ '~s. Corrirrlis Printed: PM ~Jon BP EXPLORATION Page 5 of 6 Operations Summa Report Legal Well Name: C-05 Common Well Name: C-05^ Spud Date: 5118/1973 Event Name: REENTER+COMPLETE Start: 2/212001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: 2118/2001 Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From-To Hours Task Code 2/1412001 22:15 - 22:30 0.25; DRILL . STAB PROD1 Worked/wiped tight spot ~} 12950' and RIH to TD ~12987'. 22:30 - 00:00 1.50 DRILL STAB PROD1 Wiper tripped to window and RIH with pumps off to TD without resistance. 211512001 00:00 - 03:00 3.00 DRILL STAB PROD1 POOH laying in new FIo Pro in open hole. 03:00 - 03:30 0.50 DRILL STAB PROD1 L/D drilling BHA. 03:30 - 04:00 0.50 CASE COMP Safety meeting on picking up liner out of ready rack. Emphasis on body positioning, winch operator maintaining line of sight & good communiction techniques. 04:00 - 07:30 3.50 CASE COMP MlU liner & RIH w/liner & jewelry. MIU liner running tool & M/U to coil. 07:30 - 11:15 3.75 CASE COMP RIH, correct ~ EOP flag, subtract 39' correction. 36K up wt, 24K dh. No bobbles going in thru window & throughout open hole. Tag up ~ 12,987'. 11:15 - 12:45 1.50 CASE ~COMP Drop 518" ball to disconnect. Circulate to seat ~ .9 bpm11700 psi. Slow rate down wi 28 bbls away to .4 bpm/1000 psi. Ball on seat wi 33.7 bbls , away, pressure to 4600 psi & shear ball seat & release tool. PIU to verify, OK. 12:45 - 13:00 0.25 CEMT COMP Pre job on cementing job. Emphasis on communication skills, staying clear of HP lines & monitoring fluids. 13:00 - 13:30 0.50 CEMT COMP Mix cement & circulate 1:1 returns. Cmt to weight ~ 13:30. 15.8 ppg neat cement thickening time 4 hrs 19 min. 13:30 - 14:45 1.25 CEMT COMP Pump 2 bbls KCL/water, pressure test lines to 4500 psi, OK. Pump 17 bbls cement, 1.5 bbls kcl/water & launch dart. Displace dart w/total of 41.5 bbls & latched up to wiper plug. Pressure up to 5000 psi, unable to shear plug. Bleed & ramp up again to 5000 psi, still no shear. Safety alert on radio to go to safe zones, prepare for excessive pressures. Pressure up to approximately 6100 psi, wiper plug sheared. Plug bump wi 49.5 bbls total displacemnt away. Test floats, OK. ClP ~ 1445. 1:1 returns throughout job. '14:45 - 16:30 1.75 CEMT COMP Pick up & pull liner packoff bushing out & circulate. POOH slowly wi circulating. No cement back as TOC projected to be 11,300'. TOL ~ 10,891'. PBTD ~ 12,923'. Will correct wi memory log. 16:30 - 23:30 7.00 CEMT VVTHR COMP Phase 3 driving, wind 50-65 mph, very Iow visibility. Stop ~ 2700' & circulate ~ minimum rate. Maintain rig & restrict exposure. No crew change. 23:30 - 00:00 0.50 CEMT WTHR COMP Down graded to Phase 2 driving. Continue to circulate rain rate ~;} 2700'. Convoy fl crew change. 211612001 00:00 - 02:00 2.00 CEMT COMP Complete crew change, & finish POOH. 02:00 - 02:30 0.50 CEMT COMP L/D liner running tool. 02:30 - 07:30 5.00 CASE COMP MIU logging tool & plu 1": CS Hydril tubing. 07:30 - 11:45 4.25 CASE COMP RIH wi memory log tool. Tag TOL. Check BHA, Baker x/o above logging tool 2" OD ..... 11:45 - 14:30 2.75 CASE COMM COMP POOH to replace crossover w/one 1.69" OD. 14:30 - 16:30 2.00 CASE COMM COMP Ready rack back 1" CS Hydril 16:30 - 17:15 0.75. CASE COMM COMP B/O tool, reprogram & M/U wi smaller x/over. 17:15 - 20:00 2.75 CASE COMM COMP Pick up 1" CS Hydril out of ready rack and MIU to coil. 20:00 - 22:00 2.00 CASE COMM COMP RIH wi logging assembly on coil. 22:00 - 00:00 2.00 CASE COMP Log down fl 10750' to PBTD, (12954'), ~ 30 fpm, log up f/PBTD ~ 30 fpm to 10750'. 2/1712001 00:00 - 00:45 0.75 CASE COMP Run back in hole to lay in new FIo Pro. 00:45 - 01:45 1.00 CASE COMP POOH laying in 150,000 LSRV FIo Pro in liner. 01:45 - 03:00 1.25 CASE COMP Test liner lap, staged up & tested ~ 2000 psil30 min. Zero bleed off. 03:00 - 05:30 2.50 CASE COMP Paint EOP flag ~ 8735' & POOH. Observe well ~ 500', stable. 05:30 - 06:00 0.50 CASE COMP Rack back injector & prep to ready rack 1" CS Hydril. Printed: 2/26/2001 3:09:29 PM BP EXPLORATION Page 6 of 6 Operations Summa Report Legal Well Name: C-05 Common Well Name: C-05^ Spud Date: 511811973 Event Name: REENTER+COMPLETE Start: 2/2/2001 End: Contractor Name: NABORS TRANSOCEAN Rig Release: 2/1812001 Group: COIL Rig Name: CDR-1 Rig Number: 1 Sub Phase Description of Operations Date From - To -Iours Task Code 2/1712001 06:00 - 06:30 0.50 CASE COMP Crew change, new hands, focus on body positioning, no hurry & good communication. 06:30 - 09:00 2.50 CASE COMP Ready rack back 1" CS Hydril tbg. 09:00 - 09:15 0.25 CASE COMP Pre job on handling radio active source. 09:15 - 09:30 0.25= CASE COMP L/D memory logging tool. 09:30 - 11:15 1.75 CASE COMP Down load info. Corrected liner top ~} 10,882' & PBTD (landing collar) ~ 12,926'. No surprises on log, no changes to perf depths. Call fl guns. 11:15 - 11:45 0.50 CASE COMP Offioad perfguns. 11:45 - 12:15 0.50 CASE COMP Safety meeting on picking up perf guns. (3) new hands. Emphasize communication, HA/HM, & going slow so as to allow everyone to be comfortable. Winch operator to maintain line of sight while operating. Man to watch line wraps. 12:15 - 15:30 3.25 CASE COMP Pick up 1 11116" perf guns & mlu to 55 jts 1" CS Hydril. 15:30 - 18:00 2.50' CASE COMP RIH, subtract 40' {~ EOP flag. Tag ~ 12,913' & add 13' correction to correlate wi memory log. Perforating interval = from 12500' - 12920'. Position to drop 112" ball. 18:00 - 20:00 2.00 CASE COMP PJSM. Drop & circulate 112" ball wi KCL through coil. Pump 59.6 bbls & observe ball still in Iow side of CT reel. Pump 10bbls of FIo-Pro & flush ball out of reel. Chase with 15 bbls KCL. Ball seats & guns fire ~ 2850 psi. Lose 2 bbl fluid. 20:00 - 23:00 3.00 CASE COMP POOH. Paint EOP flag ~ 10000'. Monitor well ~ 500' - No losses. 23:00 - 00:00 1.00 CASE COMP PJSM. Rack back injector and circulate coil. 211812001 00:00 - 02:15 2.25 CASE COMP Rack back 1" CS Hydril tbg. 02:15 - 02:30 0.25 CASE COMP Pre job safety meeting, handling perf guns. Good communication, line of sight for winch operator, body positioning. 02:30 - 03:30 1.00 CASE COMP Lay down perf guns, ASF. Hole fill 2.5 bbls. 03:30 - 04:00 0.50 CASE COMP M/U stinger & nozzle. '04:00 - 05:30 1.50, CASE COMP 'RIH to 2000' & displace well to methanol/water, POOH. 05:30 - 06:30 1.00 CASE COMP Set BPV. 06:30 - 07:30 1.00 CASE COMP Lay down 1" CS Hydril out of ready rack. L/D mouse hole. Empty outside rack and fold-up rack. 07:30 - 11:00 3.50 RIGD COMP PJSM for RE) operations. Blow discharge, orienter, kill and mud lines. Drain BOP stack. Blow pumps, suction lines & manifold, and outside lines to tanks. Clean pits. 11:00 - 15:00 4.00 RIGD COMP Lay-over catwalk. Nipple down BOPE. Nipple down extra master valve & install tree cap. Rig released ~} 15:00 hfs, 2/18/2001. 15:00 - 18:00 3.00 RIGD POST Scope down and lay-over mast. Knock off pump lines. 18:00 - 20:00 2.00 RIGD POST PJSM. L/D coil tower, set coil trailer down & lay-over sling shot. 20:00 - 00:00 4.00= RIGD POST Load out mud pumps. PIU mats. Move pits. RECEIVED MAR 2 8 2001 Alaska 011 & ~a~ Cons. Commissior~ Anchorage Printed: 2/26/2001 3:09:29 PM 6-3/8" CIWJ MCEVOYJ 6" OTISJ B..EV = 55.35'I BF. ELEV = 35.70'J ~0.= @3~°°'1 19~"~°c H Datum TV D= 8800'I 2091' 2146' 2080' JMinimum ID = 1.91"@ 10896' FROM TIVV DEPLOYMENT SLV TO 2-3/8" 4.6" LNR 9-518" CSG, 47~, BTC, L-80, D=8.681" H I TOP OF 2-3/8" LIaR XO, FL4S PIN X 81;O ACNE BOX, ID= 1.91" 4-112" TBG, 12.75#, N-80, CS-HYDRL 0.0152 bpi', D =3.958" IXNPF~.E. ID=3.427" H 11023' JTOP OF CEMENT RLOT HOLE 11648' IMARKER JOINT H 11661' C-05A 2098' SAFETY NOTE~: Cl'DHORIZONI'AL SIDETRACK. Caulion: Well has 6" Tree, but has a tubing hanger with a 4-112" openhg only! Easy to have trouble getting through Ihe "donut." HOTIS SSSV LANDING NPPt. E, ID =3.813" J GAS LIFT IV~NDRELS STA MD TVD DB/ TYPE IVI~N LATCH NOI~E 9353' H7,, 9373' H7'' PACKER (BOT) 10896' t 0915' 10956. 10973' 10996. HTIW DEPLOYIVENI' SLV, ID = 2.25" H4-1/2" OTISXA SUDING SLV, ID=3.813" I J'-J4-1/2" PBR(BOT),3.5" SEALASSENIBLY J h3.572" SEAL BORE DOWN TO 10973' H?'' x 4-112" PACKER (BO'r) 11050' RN NIPR. E, ID = 3.1" I 11076' HTTL B. IVD 7/29/89 I 11685' i'"ITOP OF 2.8" WII~DOW IN 7" LINER I I 11691' HBOTrOMof2.8"WlNDOWNT"LII~ERI FERFORATDN SUIVlVlARY REF LOG: CI~.IGR/CCL Memory Log on 02/16/2001 ANGLEAT TOP PEI~: 90° ~ 12500' Note: Refer to Production DB for historical perf data 12500'- 12920' 11794' I'"~ CF-MENT TOP BLINE 6/~195 I 11831' I--ICAREOLrrE TOP I I 12926' ~ I FISH 10/15/89 11914' 12-3/8" LI~, 4.6#, L-80 FL4S, 0.0039 bpf, ID=1.995" H 12985' I'/" UNER, 29#, N-80, 0.0371 bpf, ID=6.184" H 11936' DATE REV BY COMIVENTS 1/1178 ORIGINAL COIVPLEI'ION 7/3190 HA RTZ ~ C DIAGRAM 6/8195 DTR F:OST SQUI~_.ZE PERF 02/18/01 CDR1 HORIZONTAL SIDEBTRACK 03/08/01 CH/KAK CORRECTIONS ..................... PRUDHOE BAY IJ~IIT WELl: C-05A PERMII' No: 201-002 BP Exploration (Alas_ka) IVI~I'~ ~ ~,v¥~ ObP BP Amoco (' Baker Hughes INTEQ Survey Report Company: BP Amooo Fidd: Prudhoe Bay Site: PB C Pad Well: C-05 Date: 4/9/2001 Time:. 16:49:40 Page: I Co-ordinate(NE) Reference: Well: C-05, True Norlh Veraeal (TVD) Reference: 6: 05 5/18/1973 00:00 55.4 Scetion (VS) Reference: Well (0.00N,0.00E,280.00Azi) Surve~ Calculation Metliod: Minimum Curvature Db: Oracle FieM: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomapetic Model: BGGM2000 Site: PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft (;round Level: 0.00 ft 5957218.72 ft Latitude: 70 17 22.367 N 662550.03 ff Longitude: 148 41 2.797 W North Reference: True Grid Convergence: 1.24 deg Well: C-05 Slot Name: 05 C-05 Well Position: +NI-S 1994.44 ft Northing: 5959256.00 ft Latitude: 70 17 41.980 N +K/-W 2009.70 ff Easting: 664516.00 ff Longitude: 148 40 4.223 W Position Uncertainty: 0.00 ff Wellpath: C-05A Drilled From: C-05 500292012601 Tie-on Depth: 11685.00 ff Current Datum: 6: 05 5118/1973 00:00 Height 55.40 ff Above System Datum: Mean Sea Level Magnetic Data: 1/23/2001 Declination: 26.77 deg Field Strength: 57477 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 280.00 Survey: MWD Start Date: 2118/2001 Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation MD TVD 11685.00 8873.12 Kick-off Point 12986.00 8994.46 Projected to TD Survey MD Incl Azim TVD SSTVD N/S E/W MapN ' MapE DLS VS ff deg deg ff ff ff fl. fi' ff deg/100ff 11685.00 42.61 243.75 6873.12 6817.72 -4041.73 -4672.04 5955113.26 659933.86 0.00 3899.22 11743.00 59.70 242.30 8909.37 6853.97 -4062.21 -4712.12 5955091.92 659894.25 29.54 3935.14 11775.00 63.70 258.80 8924.62 8869.22 -4071.47 -4738.57 5955082.08 659868.00 47.04 3959.58 11806.00 64.00 262.70 8938.28 8882.68 -4075.94 -4768.03 5955077.01 659840.65 11.33 3985.84 11847.00 63.30 260.60 8956.48 8901.08 -4081.27 -4802.38 5955070.68 659804.43 4.90 4020.71 11682.00 69.00 269.70 8970.65 8915.25 -4083.92 -4834.22 5955067.54 659772.65 28.81 4051.61 11 923.00 77.50 277.40 8982.47 8927.07 -4081.43 -4873.33 5955069.17 659733.50 27.43 4090.56 11971.00 86.20 286.90 8989.29 8933.89 -4071.41 -4919.67 5955078.17 659686.95 26.67 4137.94 12005.00 86.60 292.20 8991.42 8936.02 -4060.06 -4951.64 5955068.82 659854.75 15.60 4171.39 12030.00 83.50 301.00 8993.59 8938.19 -4048.92 -4973.89 5955099.47 659632.27 37.19 4195.23 12072.00 83.80 294.00 8998.24 8942.64 -4029.68 -5010.89 5955117.91 659594.85 16.58 4235.02 12110.00 87.50 286.60 9001.12 8945.72 -4016.53 -5046.40 5955130.26 659559.07 21.72 4272.27 12152.00 82.40 281.30 9004.82 8949.42 -4006.45 -5086.97 5955139.46 659518.29 17.47 4313.98 12197.00 64.50 279.20 9009.95 8954.55 -3998.49 -5130.98 5955146.44 659474.14 6.58 4358.68 12229.00 91.40 282.40 9011.10 8955.70 -3992.50 -5162.35 5955151.74 659442.63 23.76 4390.63 12258.00 90.30 285.50 9010.67 8955.27 -3985.51 -5190.49 5955158.11 659414.35 11.34 4419.55 12292.00 89.40 291.50 9010.76 8955.36' -3974.73 -5222.71 5955168.19 659381.89 17.64 4453.16 12323.00 91.23 293.60 9010.59 8955.19 -3962.84 -5251.34 5955179.45 659353.01 8.99 4483.42 BP Amoco (' Baker Hughes INTEQ Survey Report Company: BP Amoco Bate: 4/9/2001 Time: 16:49:40 Page: 2 FleM: Prudhoe Bay Ce-ordinate(NE) Reference: Well: C-05, True Norlh Site: PB C Pad Vertical (TVD) Reference: 6: 05 5/18/1973 00:00 55.4 Wen: C-C)5 Section (VS) Reference: Well (0.00N,0.00E~80.00Azi) Wdlpath: C-05A Snrvey Calenlation Method: Minimum Curvature Db: Oracle Survey MD lid Azim TVD SSTVD N/S E/W MapN MapE DLS VS It deg deg It It It It It It deg/100it It 12357.00 94.04 298.53 9009.02 8953.62 -3947.93 -5281.84 5955193.69 659322.20 16.68 4516.04 12383.00 95.98 300.99 9006.75 8951.35 -3935.07 -5304.32 5955206.05 659299.44 12.02 4540.42 12411.00 98.68 303.80 9003.66 8948.26 -3920.17 -5327.82 5955220.44 659275.63 10.28 4568.15 12449.00 96.30 298.18 8999.37 8943.97 -3900.74 -5360.17 5955239.15 659242.86 14.73 4601.38 12503.00 89.90 292.60 8996.44 8941.04 -3877.64 -5408.84 5955261.17 659193.70 15.71 4653.32 12536.00 91.20 291.20 8998.13 8940.73 -3685.34 -5439.46 5955272.81 659162.82 5.79 4685.61 12564.00 91.10 287.30 8995.57 8940.17 -3856.11 -5465.88 5955281.45 659136.20 13.93 4713.24 12609.00 89.00 286.60 8995.53 8940.13 -3642.99 -5508.92 5955293.63 659092.89 4.92 4757.90 12641.00 89.80 284.50 8995.86 8940.46 -3834.41 -5539.75 5955301.53 659061.68 7.02 4789.75 12693.00 89.03 281.65 8996.39 8940.99 -3822.65 -5590.39 5955312.18 659011.00 5.68 4841.67 12739.00 89.47 277.08 8997.00 8941.60 -3815.17 -5635.76 59553 18.68 658965.48 9.98 4687.65 12776.00 68.77 274.27 8997.56 8942.16 -3811.51 -5672.57 5955321.51 658928.60 7.83 4924.53 12807.00 68.33 271.46 8998.35 8942.95 -3809.96 -5703.52 5955322.39 658897.63 9.17 4955.28 12837.00 87.98 267.94 8999.31 8943.91 -3810.12 -5733.50 5955321.57 656867.66 11.79 4984.78 12864.00 68.33 267.59 9000.18 8944.78 -3811.17 -5760.47 5955319.93 658840.72 1.83 5011.15 12889.00 91.14 264.78 9000.30 8944.90 -3812.83 -5785.41 5955317.72 656815.83 15.89 5035.42 12926.00 94.10 262.30 8998.61 8943.21 -3816.99 -5622.13 5955312.76 658779.21 10.43 5070.86 12962.00 93.90 257.40 8996.09 8940.69 -3823.32 -5857.47 5955305.68 658744.02 13.59 5104.57 12988.00 93.90 257.40 8994.33 8938.93 -3828.98 -5682.78 5955299.45 656718.64 0.00 5128.51 3600 3650 3700 3750 3800 3850 3~X) 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 4450 4500 4550 46(]0 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 52G0 5250 5300 5350 5400 5450 5500 Vertical Sectioa at 2aO.O0' [lOft/ia] 3/2312001 4:52 PM ProActive Diagnostic Sewices, Inc. TRANSMITTAL To: State of Alaska AOGCC 333 W. 7~Street Suite # 700 Anchorage, Alaska 99501 RE' Distribution - Final Print(s) 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' Joey Burton / Jerry Morgan ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 BP Exploration (Alaska), Inc. Petrotechnical Data Center LR2-1 9130 E. Benson Blvd. Anchorage, AK 99508 Log DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S) OR CD-ROM FILM COLOR C~05a 02'~39~1 Open Hole I I 1 Res. Eval. CH I I 1 Mech. CH 1 Caliper Survey Signed' Print Name: Date ' RECEIVED FEB ?..001 Alasl~ 0il & .~as. Cotm, ~mm~t0~' ProActive Diagnostic Services, Inc., 310 K Street Suite 200, Anchorage, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pclsanchomge~mcmo~log.com Wcbsite: 7~'.?.O~:'.:..~E~.!.!!.~.~.3:'..[gg,..c.,.P.:!E Re: CDR-1 Subject: Re: CDR-1 Date: Tue, 06 Feb 2001 14:48:15 -0900 From: Tom Maunder <tom_maunder~}admin.state.ak. us> To: John Spaulding <John_Spauldingl~admin.state.ak. us> Thanks for the heads up, John. I did receive a call and fax from CDR. I'll call the rig and wish them luck. Tom John Spaulding wrote: > Tom, · You will be receiving call from CDR. f shortly after 1pm 2-06-01. They · have had a malfunction with their 2 3/8" rams - they closed for no · apparent reason (possibly computer generated). They dropped there BHA · and want to make some changes in their stack config, to be able to fish · the BHA. I told them to call you - I have no problem with what they are > wanting to do. Any questions, please give me a call- either in the > office or the pager, ihs Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of I 216101 2:48 PM Feb-06-01 15:21 From-CDR1 9076595547 T-669 P.01/02 F-760 Nabor~ Alaska Drilllag, Inc. Ahmys looking for better ways to provide safe, environmentally sound, cost-efficient service to our customers. . e. Facsimile Cover Sheet ! i i i i i it i To: 'Company: Phone: · Tom Maunder AOGCC 907-793-1250 907-276-7542 From: Company: Phone:. Fax: Rob Kennedy CDR1 659-5544 659-5547 Date: 02/06/00 Pages including this cover page: 2 Tom, We had a problem with the 2" combi rams closing on their own. We would like to leave them empty and replace the 2 3/8 combis just for this fishing job. Lost BHA. The people are on their way to fix the rams. We will put them back the way they are now and retest after the fishing job. We just cut the window and 10' of open hole. Well is stable with KCL. Thanks, Beto Feb-06-01 4' 15:21 From-CDR1 CDR1 9076595547 Drilling Wellhead Detail 4-41 a T-669 P.OZ/02 F-760 '~CT Injector Head Rig Floor Otis O.C. thread half Traveling plate 21.5" 4.70' Dual G~e' ., I · I T.O.T. 5,000 psi W.P. -- R_a_[n Type Dual Gate BOPE -T -: 5-1/2" lubricator Jacking Frame Top Stationary Plate Annular BOP (Hydril),7-1116" ID Annular BOP (Hydril),7-1/16" ID Top blind I shear Bottom 2" pipes I" Kill Line Btm 2 318 Manual Master Valve -- Tubing Hanger 9-5/8" Annulus I slips Rer~lace 0.66' I Matt Ground Level 13-318" Annulus ALAS~ OIL AND GAS CONSERVATION COPlPllSSION TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276- 7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 g.e~ Prudhoe Bay Unit C-05A BP Exploration (Alaska) Inc. Permit No: 201-002 Sur Loc: 1966'SNL, 879'WEL, Sec. 19, T11N, R14E, UM Btmhole Loc. 1123'SNL, 1385'WEL, Sec. 25, T11N, RI3E, UM Dear Mr. Stagg.: ., Enclosed is the approved application for permit to redrill the above referenced Well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not' authorize conducting drilling operations until ali other required permitting determinations are made. . · Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the' Commission to witness a test of BOPE installed priOr to drilling new hole. Notice may'be' given by contacting the Commission petroleum field inspector on the North SloPe pager at 659-3607. Commissioner BY ORDER OF THE COMMISSION 'DATED this / 7'/4' day of January, 2001 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Enviromnental Conservation w/o encl. · STATE OF ALASKA ALASK~ ,L AND GAS CONSERVATION COMI~'r SION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test ~' Development Oil/~l~ la. Type of work [][] Re-EntryDrill Be[] DeepenRedrill lb. Type of well [] Service [] Development Gas [] S~ngle Zone~! Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 55.40 Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 o.7-~"~,~DL 028286 4. 'Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1966' SNL, 879' WEL, SEC. 19, T11 N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 595' SNL, 331' WEL, SEC. 25, T11N, R13E, UM C-05A Number 2S100302630-277 At total depth 9. Approximate spud date 1123' SNL, 1385' WEL, SEC. 25, T11N, R13E, UM 01/05/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028285, 1123' MDI No Close Approach 2560 13021' MD / 8950' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11790' Maximum Hole Angle 94.2 ° Maximum surface 2420 psig, At total depth (TVD) 8800' / 3300 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casin,q Wei,qht Grade Couplin,q Len,qth MD TVD MD TVD (include sta,qe data) 3" 2-3/8" 4.6# L-80 FL45 2021' 11000' 8325' 13021' 8950' 28 cuft Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. "~'I/V g'2-~'u2nn! Present well condition summary '~a O#& Gas Total depth: measured 11938 feet Plugs (measured) true vertical 9061 feet Effective depth: measured 11785 feet Junk (measured) Cement top at 11783' MD (06/95) true vertical 8990 feet Casing Length Size Cemented MD TVD Structural Conductor 100' 20" 135 sx Arctic Set (Approx.) 119' 119' Surface 2661' 13-3/8" 3250 sx Arctic Set 2680' 2680' Intermediate 9879' 9-5/8" 1819 SX HOWCO Light, 1400 sx Class 'G", 185 sx PF 9898' 7590' Production Liner 11917' 7" 1100 sx Class 'G' 9353' - 11936' 7209' - 9055' Perforation depth: measured Open: 11715'- 11721' (2 Intervals), 11830'- 11859' (8 Intervals) Sqzd: 11668' - 11686', 11696' - 11715', 11759' - 11784' (3 Intervals), 11815' - 11820', true vertical Open: 8919' - 8924' (2 Intervals), 9004' - 9026' (8 Intervals) Sqzd: 8884' - 8898', 8905' - 8919', 8952' - 8970' (3 Intervals), 8938' - 8997' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Ted ~tagg'~'~~- '~' J,,~ ~/~'~ Title CT Drilling Engineer Date ~,~ ... ..... .~ .... ~i~ .... ~ ~ ~ ~'. ~ =~ ~ ,~ ,,~i~,~..~ ~ ~,~ ~.. · ~,,.,. ~.~,,~ ~ ~;~ ~.~ ~; ~ '~ ~ ,,,~ i~ .... ..'.',::. ........ ~ .... ~ ...... ,',:l~,~:..~.'~:' ..... ~I~..~,,~,,,::~ ~,,,= ,.~..~ .~,,,~;.~.,.,s.~ ........ ~i, lh,,..~ ~! .'~.'L~.,~',~". ~,~i~ ~ ~mber I AP, Number Approval_Date I See cover'etter 2.-C~/--4.~'Z.. 50- 029-20126-01 ~,.--/r.-~--D( for other requirements Conditions of Approval: Samples Required [] Yes [] No Mud Log Required [] Yes [] No Hydrogen Sulfide Measures I~ Yes [] No Directional Survey Required [] Ye.s [] No Required Working Pressure for BOPE [] 2K [] 3K [] 4K [] 5K [] 10K [] 15K ~3.5K psi for CTU Other: ORIGINAL SIGNED ~'y' by order of Approved By D Taylor Seamount Commissioner the commission Date ["" Form 10-401 Rev. 12-01-85 ORIGINAL Submit In Triplicate BPX C-05a Sidetrack Summary of Operations: C-05 is being sidetracked to target lower Zone I reserves. This sidetrack will be conducted in two phases. Phase 1: P&A existing perforations, mill window off cement plug: Planned for Jan I, 2000. · The well passed an MITIA on 12/07/00 · A 2.8" centralizer drift was run to 11783' · Service coil will be used to cement the existing perforations and pressure test. · Service coil will be used to mill the window off of a cement ramp. Phase 2: Drill and Complete sidetrack: Planned for Jan 5, 2000. Drilling coil will be used to drill and complete the directional hole as per attached plan. Mud Program: · Phase l& 2: Seawater · Phase 3: FIo-Pro (8.5 - 8.7 ppg) Disposal: · No annular injection on this well. · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 3/8", 4.6#, L-80, FL4S liner will be run from TD to approx. 11,000' MD (8325'tvdss, TOL) and cemented with approx. 12 bbls. To bring the top of cement to approx. 11,490'md (8,675'tvdss, TOC). The liner will be pressure tested to 2100 psi and perforated with coiled tubing conveyed guns. Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. The annular preventer will be tested to 400 psi and 2000 psi. ~CEiVED Directional · See attached directional plan · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · A Memory CNL will be run in cased hole. Hazards No faults are expected to be crossed therefore this well is considered Iow risk for lost circulation. Res. pressure is normal. C-Pad is not an H2S Pad - No test on this well. Reservoir Pressure Res. pressure is approx. 3300psi @ 8800ss. Max. surface pressure with gas (0.1 psi/ft) to surface is 2420 psi. C-05a Potential Drilling Hazards Post on Rig , Please perform pre-job Hazard ID and Safety meetings prior to every change in work scope during the operation. Also, if things don't feel right shut-down the operation and discuss the situation before making the next operational move. SAFETY FIRST. 2. H2S is not expected on this well. C-Pad is not an H2S Pad - No test on this well. 3. BHP is expected to be 3300psi (7.21ppg) @ 8800ss. 4. Maximum anticipated well head pressure w/full column of gas 2420psi. 5. Lost circulation risk is Iow with no anticipated faults in the well plan. 6. The well plan calls for positively identifying the HOT by cuttings, limit drilling time in the HOT to maximize Z1A drilling. RECE/'t/ED JA/V 0'2. ~001 ~t~or~' ,, DS C-05A ! .{OPOSED CT HORIZONTAL( ,DETRACK ~-5/8" FOC [~ @ 2091 7" FOC @ 2146' & 3568' ~" DV @ 93541 RN or QN nipple 11050' (3.1" id) ~ SSSV @ 2098' (3.813"id) 13-3/8" @ 2680' 4-1/2", 12.75#, N80 Hydril Tubing to 10958' 7" PBR @ 9353' 7" BOT Packer @ 9373' Sliding Sleeve OTIS XA @ 10915' (3.813"id) 4-1/2" PBR, 3-1/2" seal assembly @ 10958 7" x 3-1/2" BOT Packer @ 10996' Top of 2-318" @ -11,000 BOT SOS 11,080' DPM = 11,076' ELMD o' -- Mill Window @ 11790' 3" Open Hole 7" 29# Liner & Perforations P&A'd w/Cement TD @ 13021' Cement top @ 11783' 2-3/8" FL4S 4.6# Liner Cemented & Perforated 7"@ 1193{l' TMM 12/27/2000 CDR1 Drilling Wellhead I~-tail Rig Floor ~ CT Injector Head Otis Q.C. thread half Traveling plate 21.5" Choke line HCR 4.70' Dual Ga I T.O.T. 5,000 psi W.P. R~_[n Type Dual Gate BOPE 5-1/2" lubricator Jacking Frame Top Stationary Plate Annular BOP i~:!~. ;:1(Hydril),7-1/16" ID Annular BOP (Hydril),7-1/16" ID i · "1 .! Top blind/shear Bottom 2" pipes Kill line HCR I I~111 Line -- _.__~Top 2" pipe / slips Btm 2 3/8" pipe/slips Manual Master Valve ~ Tubing Hanger 9-5/8" Annulus 0.66' Ground Level 13-3/8" Annulus JAN 0'2 2001 Alaska 011 & Gas Cons. Commission Anohor~ BP An~oco REFERENCE iNFORMATION Co~rd~ftate N/E) Referer~ce Well Centre C-05.1 rue North 3/23/2001 4:52 PM (~"' BP Amoco (. © ' bp Baker Hughes INTEQ Planning Report i'~';:i-"~ ........... Company: BP Amoco Date: 12/1512000 Time: 14:39:29 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: C-05, True North Site: PB C Pad Vertical (TVD) Reference: System: Mean Sea Level Well: C-05 Section (VS) Reference: Well (0.00E,0.00N,280.00Azi) Wellpath: Plan#2 C-05A Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay i North Slope .. UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 ' Gao Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ! Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 ' ~-~2~ '.'-'. :~- :-....'7 -' :--:. ~--':~ :: .:.:: :: ~:.':;:::~'-'-:" .-'~* ~-. .... ~.~ ~.':-~-~ .:..'.-::-~'.-.'.."-..:-" ':-':-" .:: ~-.':" :""".-:~-.--'::~-.':..:-.:"-':---.: :~-: ~-~ ': :--~.~-:-:'-:.'~.' :: .:.:-' ".~'-'.'.---.~'~- ~lte' I-'aG · TR-11-14 _ x ,~ UNITED STATES: North Slope Site Position: Northing: 5957218.72 ft Latitude: 70 17 22.367 N From: Map Easting: 662550.03 ft Longitude: 148 41 2.797 W ~-/~, '7," '~, Position Uncertainty: 0.00 ft North Reference: True ~_. ~ ~. d Ground Level: 0.00 ff Grid Convergence: 1.24 deg '-~-i~we,,: u--u~~d2-%~'Z-~f--"-'.::-._'.:?_';'.2-_7_-_-2L2:-' ';"-2'- ......... -" ...... .:2- ....... .-_' '"-_-_ ...... 7':¥..-"--_' --- ~-~-~-~ .................... £'"~--'0~ "Z--2Z2_'__-::;'-'.' ............. ~I~. 't~'-~ .... '~C;2,----~ ...... C-05 ' Well Position: +N/-S 1994.44 ft Northing: 5959256.00 ft Latitude: 70 17 41.980 N .+E/-W 2009.70 ft Easting: 664516.00 ft Longitude: 148 40 4.223 W 0.00 ft Position Uncertainty: Wellpath: Plan#2 C-05A Drilled From: C-05 500292012601 Tie-on Depth: 11790.00 ft Current Datum: 6 · 05 5/18/1973 00:00 Height 55.40 ft Above System Datum: Mean Sea Level Magnetic Data: 12/15/2000 Declination: 26.81 deg Field Strength: 57476 nT Mag Dip Angle: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 280.00 Plan: Plan #2 Date Composed: 12/15~2000 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets ['~'!'"!~.'.'1:7".'i';'i'~ !~',?ii"!'.!~'~!?.i'=:~'i!i'*~"'i"i-,:i;!~7!';i!!i !: ::: Z'!'~ ~iii.!~ !!'.ii.~i!'?,~.i!~,iZi! ",~!i~!~!!!!!;i~;ii~'i',!:i',i ii~i~:~?~:~!!~I!~::~i~i~i!?~i~!~i!!i~;~i!~i~!II~I~Z~;~!!:~i!~!i~iZi~i!~i~: !'i~i~i~i~:'~:.~a~aa~'=, ~ Annotation 11700.00 8828.76 Tie-in Point 11790.00 8895.29 Kick-off Point 11940.10 8955.00 1 11990.10 8953.17 2 12415.40 8940.00 3 13023.55 8950.00 TD .............................................................................................................................................................................................................. Plan Section Information 11700.00 42.55 243.86 8828.76 -4046.21 -4681.15 0.00 0.00 0.00 0.00 11790.00 42.13 243.58 8895.29 -4073.05 -4735.50 0.51 -0.47 -0.31 204.08 11940.10 90.00 265.00 8955.00 -4104.10 -4864.08 34.21 31.89 14.27 27.88 11990.10 94.20 268.31 8953.17 -4107.01 -4913.94 10.70 8.40 6.63 38.20 12415.40 89.16 313.87 8940.00 -3957.88 -5300.00 10.77 -1.19 10.71 95.28 13023.55 89.15 250.69 8950.00 -3835.00 -5864.51 10.39 0.00 -10.39 -90.52 (' BP Amoco (' 0 bp t\~ ~a~g$~gkes INTEQ Planning Report '-'"'"-"'--"" '-'------'"company:-'"BP-Am-oco ...................... ~J-~/I/'-U Z2001'" ""'-'-- D,te. 12115/2000 T, me 143929 ?age 2 Field: Prudhoe Bay ,,'. Co-ordinate(NE) Reference: Well: C-05, True North Vertical (TVD) Reference: System: Mean Sea Level Site: PB C Pad a 0~ & Gas C0115. Cofi]lT~ Section (vs) Reference: Well (0.00E,0.00N,280.00Azi) Well: C-O5 Anchorage Wellpath: Plan02 C-05A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ff ft ft deg/100ft ft deg 11700.00 42.55 243.86 8828.76 -4046.21 -4681.15 5955108.59 659924.85 0.00 3907.42 0.00 MWD 11725.00 42.43 243.78 8847.19 -4053.66 -4696.30 5955100.81 659909.87 0.51 3921.05 204.08 MWD 11750.00 42.32 243.71 8865.66 -4061.11 -4711.42 5955093.02 659894.92 0.51 3934.63 204.13 MWD 11775.00 42.20 243.63 8884.17 -4068.57 -4726.48 5955085.24 659880.02 0.51 3948.18 204.19 MWD 11790.00 42.13 243.58 8895.29 -4073.05 -4735.50 5955080.56 659871.11 0.51 3956.28 204.25 MWD 11800.00 45.18 245.83 8902.52 -4076.00 -4741.74 5955077.48 659864.93 34.21 3961.91 27.88 MWD 11825.00 52.95 250.56 8918.90 -4082.96 -4759.27 5955070.14 659847.56 34.21 3977.97 26.25 MWD 11850.00 60.88 254.40 8932.54 -4089.23 -4779.23 5955063.44 659827.74 34.21 3996.54 23.14 MWD 11875.00 68.90 257.68 8943.14 -4094.66 -4801.19 5955057.52 659805.91 34.21 4017.21 21.04 MWD 11900.00 76.98 260.62 8950.47 -4099.14 -4824.64 5955052.53 659782.57 34.21 4039.53 19.65 MWD 11925.00 85.09 263.38 8954.36 -4102.57 -4849.07 5955048.57 659758.22 34.21 4063.00 18.78 MWD 11940.10 90.00 265.00 8955.00 -4104.10 -4864.08 5955046.71 659743.25 34.25 4077.51 18.33 MWD 11950.00 90.83 265.66 8954.93 -4104.91 -4873.95 5955045.69 659733.40 10.70 4087.09 38.20 MWD 11975.00 92.93 267.31 8954.11 -4106.44 -4898.88 5955043.61 659708.50 10.69 4111.38 38.17 MWD 11990.10 94.20 268.31 8953.17 -4107.01 -4913.94 5955042.71 659693.47 10.69 4126.11 38.23 MWD 12000.00 94.10 269.37 8952.45 -4107.21 -4923.81 5955042.29 659683.60 10.77 4135.80 95.28 MWD 12025.00 93.85 272.06 8950.72 -4106.90 -4948.75 5955042.06 659658.67 10.77 4160.41 95.36 MWD 12050.00 93.58 274.75 8949.10 -4105.42 -4973.65 5955043.00 659633.74 10.77 4185.19 95.54 MWD 12075.00 93.31 277.43 8947.60 -4102.77 -4998.46 5955045.10 659608.88 10.77 4210.08 95.72 MWD 12100.00 93.03 280.11 8946.22 -4098.96 -5023.13 5955048.36 659584.14 10.77 4235.04 95.88 MWD 12125.00 92.74 282.79 8944.96 -4094.01 -5047.60 5955052.78 659559.57 10.77 4260.00 96.03 MWD 12150.00 92.45 285.47 8943.82 -4087.91 -5071.81 5955058.35 659535.22 10.77 4284.90 96.16 MWD 12175.00 92.15 288.15 8942.82 -4080.68 -5095.72 5955065.05 659511.16 10.77 4309.70 96.28 MWD 12200.00 91.85 290.83 8941.94 -4072.35 -5119.27 5955072.86 659487.44 10.77 4334.34 96.39 MWD 12225.00 91.55 293.50 8941.20 -4062.92 -5142.41 5955081.78 659464.10 10.77 4358.77 96.48 MWD 12250.00 91.24 296.18 8940.60 -4052.42 -5165.09 5955091.78 659441.20 10.77 4382.93 96.56 MWD 12275.00 90.93 298.85 8940.12 -4040.88 -5187.26 5955102.84 659418.78 10.77 4406.76 96.63 MWD 12300.00 90.61 301.53 8939.79 -4028.31 -5208.86 5955114.93 659396.91 10.77 4430.22 96.68 MWD 12325.00 90.30 304.20 8939.59 -4014.74 -5229.86 5955128.03 659375.62 10.77 4453.25 96.72 MWD 12350.00 89.98 306.88 8939.53 -4000.21 -5250.20 5955142.11 659354.97 10.77 4475.81 96.74 MWD 12375.00 89.66 309.55 8939.61 -3984.75 -5269.84 5955157.14 659335.00 10.77 4497.84 96.74 MWD 12400.00 89.35 312.22 8939.82 -3968.39 -5288.74 5955173.09 659315.75 10.77 4519.29 96.73 MWD 12415.40 89.16 313.87 8940.00 -3957.88 -5300.00 5955183.34 659304.26 10.76 4532.20 96.55 MWD 12425.00 89.15 312.87 8940.14 -3951.29 -5306.98 5955189.78 659297.14 10.39 4540.22 269.48 MWD 12450.00 89.13 310.27 8940.52 -3934.70 -5325.68 5955205.95 659278.08 10.39 4561.51 269.49 MWD 12475.00 89.11 307.68 8940.90 -3918.98 -5345.11 5955221.24 659258.32 10.39 4583.38 269.53 MWD 12500.00 89.09 305.08 8941.29 -3904.16 -5365.23 5955235.62 659237.87 10.39 4605.77 269.57 MWD 12525.00 89.07 302.48 8941.69 -3890.26 -5386.01 5955249.06 659216.80 10.39 4628.64 269.61 MWD 12550.00 89.06 299.88 8942.10 -3877.32 -5407.39 5955261.53 659195.14 10.39 4651.95 269.66 MWD 12575.00 89.05 297.29 8942.52 -3865.36 -5429.34 5955273.01 659172.94 10.39 4675.64 269.70 MWD 12600.00 89.04 294.69 8942.93 -3854.41 -5451.80 5955283.46 659150.24 10.39 4699.67 269.74 MWD 12625.00 89.03 292.09 8943.36 -3844.48 -5474.75 5955292.88 659127.09 10.39 4723.98 269.78 MWD 12650.00 89.02 289.49 8943.78 -3835.61 -5498.11 5955301.24 659103.53 10.39 4748.54 269.83 MWD 12675.00 89.02 286.89 8944.21 -3827.81 -5521.86 5955308.52 659079.63 10.39 4773.28 269.87 MWD 12700.00 89.01 284.30 8944.64 -3821.09 -5545.93 5955314.71 659055.41 10.39 4798.15 269.92 MWD 12725.00 89.01 281.70 8945.07 -3815.47 -5570.28 5955319.80 659030.94 10.39 4823.11 269.96 MWD 12750.00 89.01 279.10 8945.50 -3810.96 -5594.87 5955323.77 659006.27 10.39 4848.10 270.01 MWD 12775.00 89.02 276.50 8945.93 -3807.56 -5619.63 5955326.62 658981.44 10.39 4873.08 270.05 MWD 12800.00 89.02 273.91 8946.36 -3805.30 -5644.52 5955328.34 658956.51 10.39 4897.99 270.10 MWD 12825.00 89.03 271.31 8946.79 -3804.16 -5669.49 5955328.93 658931.52 10.39 4922.77 270.14 MWD 12850.00 89.04 268.71 8947.21 -3804.16 -5694.48 5955328.39 658906.53 10.39 4947.39 270.19 MWD 12875.00 89.05 266.11 8947.62 -3805.28 -5719.45 5955326.71 658881.60 10.39 4971.78 270.23 MWD 12900.00 89.06 263.51 8948.04 -3807.54 -5744.35 5955323.91 658856.76 10.39 4995.90 270.27 MWD ' BP Amoco ' bp mw~ Baker Hughes INTEQ Planning Report i~yE~)~ ................... Company: BP Amoco Date: 1211512000 Time: 14:39:29 Page: 3 Field: Pmdhoe Bay Co-ordinate(NE) Reference: Well: C-05, True North Site: PB C Pad Vertical (TVD) Reference: System: Mean Sea Level Well: C-05 Section (VS) Reference: Well (0.00E,0.00N,280.00Azi) Wellpath: Plan#2 C-05A Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Inel Azim SSTVD NIS E/W MapN MapE DLS VS TFO Tool ff deg deg ff ff ff ff ff deg/100ff ff deg 12925.00 89.08 260.92 8948.44 -3810.93 -5769.11 5955319.98 658832.08 10.39 5019.70 270.32 MWD 12950.00 89.10 258.32 8948.84 -3815.44 -5793.70 5955314.94 658807.60 10.39 5043.13 270.36 MWD 12975.00 89.12 255.72 8949.23 -3821.05 -5818.05 5955308.79 658783.37 10.39 5066.14 270.40 MWD 13000.00 89.14 253.12 8949.61 -3827.76 -5842.13 5955301.56 658759.45 10.39 5088.69 270.44 MWD 13023.55 89.15 250.69 8950.00 -3835.00 -5864.51 5955293.83 658737.24 10.33 5109.47 270.32 MWD RECEIVED JAN 0'2 ZOO1 ,. Alalka Oil & Gas Cons. Commission bp December 27, 2000 To: Attention: Subject: Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Tom Maunder Petroleum Engineer C-05 CTD Sidetrack Prep BP Exploration Alaska Inc. Drilling & Wells Coiled Tubing Drilling Team Well C-05 is scheduled for a through tubing sidetrack to be drilled with coiled tubing. The following summarizes the procedure required to prep C-05 for drilling and is submitted as an attachment to Form 10-403. A schematic diagram of this proposed completion is attached. :t. The gas lift mandrels were dummied off and the well passed an MITIA on 12/07/00. 2. A 2.8" drift was run and tagged pbtd at 11783'md. 3. Service coil will pump approx. 5 bbls of cement to P&A the existing perforations. 4. The window will be milled off of a cement ramp with service coil (time permitting). The KOP will be at approximately 11,790'md (8895'tvdss). 5. A sidetrack of approx. 1230 ft into lower Zone 1 will be drilled with CT. 6. The sidetrack will be completed with a cemented 2 3/8" liner that will overlap the existing 3 ~" tubing to ~11,000'md (TOL). The estimated Top of cement is planned for 300' above the window to approx. 10,490'md The coil tubing operations are expected to commence January 1. Drilling coil is expected to begin the sidetrack drilling on January 5, 2001. Thomas M. McCarty CT Drilling Engineer Tel: 564-5697 Fax: 564-5510 Cell' 240-8065 mccarttm@bp.com Well File Petrotechnical Data Center Terrie Hubble RECEIVED JAN 0 '2, ZOO1 Oil & Gas Co~s. Comn~/ss~ .. TREE: 6-3/8' CIW TBG HANGER: 4-1/2" WELLHEAD: ? ACTUATOR:6" OTIS 9-5/8' FOCI 2091 13-3t8-, L-60. BTRS I 2680'1 KOP: 3000' MAX ANGLE: 57 ° ¢~ 8400' 4-1/2', 12.75f#ft, N-80, CS HYDRIL TUBING ID: 3.958" .0152 BBL/FT TOP OF I 9375"t LINER 7" DV I 9-5/8", 4Wflft, L-80, BTRS 19898' 9354 PERFORATION SUMMARY REF: LOG: FDC/CNIJGR 6-1~ ~73 2-7/8"I4 I 11668-11886 SQZ'D 2-718 J 4 I 11696-11715SQZ'D 2-112 { 4 I 11715-11716Sqz/mshot 2'1/21 ~ I 11715-11721 0~n5-6-95 2-7/81 4 I saz'D 2-1/21 4 I 2-1/21 4 I "'01 I 2'?/81 ~ I OPE.- 11759-11784 11770-11774 11815-11820 11830-11835 11835-11859 11835-11845 C-5 KB. ELEV = 55.35 BF. ELEV = 35.70 NIPPLE ( OTIS )( 3.813" ID) J 2098' Caution: Well has 6" Tree but has a tubing hanger with a 4-1/2" opening onlyl Easy to have trouble getting through the "donut" GAS LIFT MANDRELS ( OTIS W/RA LATCH) N MD(BKB) TVDss NONE PBR ("OT)("ID) I 9353 I PACKER (BOT)("ID) I 9373 SLIDING SLEEVE OTIS XA ( 3.813" MIN. ID) I 10915' 4-112" PBR (BDT) I 10958 3.5" SEAL ASS'Y 7" PACKER (BOT)("ID) I 10996 ~ RN OR QN" NIPPLE I 11050 ( 3.1" ID) "BDT SOS L 11080 i 11076 ] MARKER JOINT L 11661 J Cement top 11,794' E-line 6-6-95 Carbolite top ~ 11,831' RECEIVED JAN 0 '2 Z0111 Oil & Gas Cons. Commission Anchorage PBTD [ 11914~ 7", 29~/ff. N-SO, BTRS I 11936" DATE I REV. BY I COMMENTS 1-1-78 COMPLETION 7-3-90 i HARTZ I MAC DIAGRAM 6-6-95 I DTR I Post Squeeze Perf NOTE: 10115/89 FISH IN HOLE 3" MILLX 7" LENGTH PRUDHOE BAY UNIT WELL: C-5(25-11-13) APl NO: 50-029-20126 SEC 19; T11N ; RG 14 E BP Exploration (Alaska) H 17 g 412 ~o~z~oo VENDOR AI_ASKASTAT 10 DA~ I~OCE I CREDff ME~ DE~RI~ION GR~ DI~UNT 101200 CKlO1200H 100. O0 100. O0 PYHT I:DHENTS: PER~IZT TO DRZLL I~EE HANDL::NG INST: S/H SONDRA X4750 O0 O0 0~. O0 .... . :,BP.!.EXpLORAT:I.O...N (ALASKA)~ .lNG, ';::'...'. !'i':.~.0;.';§~'..19~'127i...:':'i::;ii,?:~ ' '?,i;:':i!. i'.:':' ::/i?~.?:i!?. "~!'i:'!.i,:' i 'i :':;:..':.. ..~,d~.;,~^~sA~!' ~ ~ ~,~ ~ ';i.i:i!i ! ~: :.:' '.'"~..~.. ::,'..,:.~" ;i .".....:...,'" .. pay ,' I, ? f-. [, & .P,' '.'0 [, & ilo 36 R 5~.' O0,EI, [, h I, WELL PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. ~i- OZ..-Ot 13. WELL NAME ~ -~..~ PROGRAM: exp ENGINEERING INIT CLASS ~ ~V/ ~"~)//,-.. GEOL AREA Permit fee attached ............ , .......... Lease number appropriate~:~ ~ .'~..~/.~..~-~. / ./O. T Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available, in drilling unit ............ If deviated, is wellbore plat included ............... APPR DATE Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit canbe issued without administrative approval ...... Can permit be approved before 15-day wait ........... 14. Conductor stdng provided ................... 15. Surface casing protects all known USDWs.... ........ 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed .............. 23. If diverter required, does it meet ragula.tions .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulatiOn ................ · 26. BOPE press rating appropriate; test to ~ ~O psig. 27. Choke manifold complies w/APl RP-53 (May 84).. ~ ..... 28. Work will occur without operation shutdown .... , ...... 29. Is presence of. H2S gas probable ................. GEOLOGY 30. 31. 32. APPR DATE 33. ,.,<~P o-.L32~01.. 34. dev reddl i,/ serv wellbore seg .ann. disposal para req ~ UNIT# ~//~,~'F_~ ON/OFF SHORE (~/'/ i' Y N N . . , ~N C.h~ ~~1 ~ ~(~l,'a~ ~ ~ rr~v~c~L~i ~Oved ~1 ~ c-8~A ~1: ~N' ' ' , . Pe~it ~n be issued w/o hydrogen sulfide measures... '.. Y~ ,, ,~ .. Da~ presented on potential ove~ressure zones ....... Seismic analysis of shallow gas zones .............. ~~ Seab~ ~ndition suwey (if off-shorn) ...... ~ .... / ~' Y N " Con~ name/phone for weekly progress repo~s [~~o~ only] Y N DISPOSAL35. With proper, cementing records,, this plan (A) will contain waste in a suitable receiving zonei ........ ~,PPR .. DATE (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the'well used for disPosal; (D) 'will not damage pro. ducing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N Y N Y N Y N Y N ,, . , GEOLOGY:'. ENGINEERING~ ..UICIAnnular :, WMv~,, I!,~.o I . COMMIS~I.O.N: ' ". Comments/Instructions: Co'[ c-os r: JMH ,dV~H-- ~[.3~ 1 ,. 1:3 0 Z 0 .-I I ( ITl c:Vnsoffice\wordian~iana\checklist.(rev.. 11101//00) " ,. Well History File APPENDIX Information of detailed nature that is not particula.rly germane' to the Well Permitting ProCess but is part of the history' file, To improve {he roadability of the Well History file and to Simplify finding infOrmation, informatii)n of this nature' is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically ' · organize this category of information. **** REEL HEADER **** MWD o1/os/lS BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD Ol/O5/lS 110262 01 1.75" NaviGamma - Gamma Ray *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: glen.las -Version Information VERS. 1.20: WRAP. NO: -Well Information Block #MNEM.UNIT Data Type STRT.FT 11680.0000: STOP.FT 13000.0000: STEP.FT 0.5000: NULL. -999.2500: COMP. COMPANY: WELL WELL: FLD FIELD: LOC LOCATION: CNTY COUNTY: STAT STATE: SRVC SERVICE COMPANY: TOOL TOOL NAME & TYPE: DATE LOG DATE: API API NYUMBER: -Parameter Information Block #MNEM.UNIT Value SECT 19 : TOWN N llN : RANG 14E : PDAT MSL : EPD F 0 : LMF RKB : FAPD F 55.40 : DMF KB : EKB F 55.40 : EDF F N/A : EGL .F N/A : CASE.F N/A : OS1 . DIRECTIONAL : -Remarks CWLS log ASCII Standard -VERSION 1.20 One line per frame Information Starting Depth Ending Depth Level Spacing Absent Value BP Exploration Inc. C-05A Prudhoe Bay Unit 1966' FSL, 879' FEL North Slope Alaska Baker Hughes INTEQ 1.75" NaviGamma - Gamma Ray 12-Feb-01 500292012601 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line i (1) Ail depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) Ail Gamma Ray data (GRAX) presented is realtime data. (4) Baker Hughes INTEQ runs 1-3 utilized directional and gamma services to mill the casing window at 11,685' MD (8818' SSTVD), and to drill formation from 11,685' to 11,701' MD (8818 to 8828' SSTVD). (5) Baker Hughes INTEQ run 4 utilized directional and gamma services to dress the window. (6) Baker Hughes INTEQ runs 5 - 7 utilized directional and gamma services from 11,701' to 12,988' MD (8828' to 8939' SSTVD). (7) Well C-05A was drilled to TD @ 12,988' MD (8939' SSTVD) on Run 7. (8) The interval from 12,970' MD (8940' SSTVD) to 12,988' MD (8939' SSTVD) was not logged due to sensor to bit offset. (9) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) supplied by BPX (SWS, 17-Feb-01). (10) A Magnetic Declination correction of 26.77 degrees has been applied to the Directional Surveys. to the Directional Surveys. MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour SSTVD -> Subsea True Vertical Depth, feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL i 17.78 22.76 2 17.58 22.56 3 18.26 23.24 4 18.33 23.31 5 18.44 23.42 6 18.15 23.11 7 18.03 22.99 CURVE SHIFT DATA BASELINE 11709 1 11720 3 11731 7 11732 6 11745 5 11756 9 11770 7 11774 0 11778 3 11783 11787 11825 11925 11936 11940 11943 11964 12048 12092 12167 12199 12214 12352 12366 12372 12375 12386 12406 12409 12632 12715 12831 12841 MEASURED, 11706.2 11716.4 11727.3 11729.7 11742.2 11754.1 11768.3 11770.7 11776.3 4 11781.4 7 11785.3 3 11823.3 5 11922.8, 2 11932.8 9 11937.6 7 11941.5 0 11961.9 I 12046.3 6 12088.5 5, 12164.2 1, 12194.6 9, 12212.8 .6, 12349.7 .7, 12364 9, .2, 12371 6 .7, 12374 5 .7, 12384 8 .5, 12404 3 .2, 12406 1 .6, 12630 7 .5, 12712 6 .0, 12828 7 .6, 12839 4 DISPLACEMENT -2.93457 -3.91309 -4.30371 -2.93457 -3 32617 -2 73828 -2 34766 -3 3252 -1 95605 -1 95605 -2 34766 -1 95703 -2 73926 -3 32617 -3 32617 -2 15234 -2 15137 -1 76074 -4 10742 -3 3252 -4 49902 -2 15234 -2 93457 -1 76074 -0 586914 -1.17383 -1.95605 -2.15137 -3.12988 -1.95605 -2.93457 -2.34766 -2.15137 12845.7, 12843.0, 12861.4, 12858.8, 12902.4, 12898.5, 12908.1, 12903.8, Tape Subfile: 1 Minimum record length: Maximum record length: -2.73828 -2.54297 -3.91309 -4.30371 119 records... 8 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN mwd.xtf LCC 150 CN BP Exploration Inc. WN C-05A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!AA!AAA!!!!!! Remark File Version 1.000 1. The data presented has been edited from the field raw data. 2. The data has been depth shifted to match the PDC supplied by BPX 3. The PDC used is a Schlumberger Gamma Ray dated 17-Feb-01. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GR GRAXl2 0.0 2 ROP ROPS12 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value=' 0) Datum Specification Block Sub-type is: FRAME SPACE = ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool 1 GR MWD 2 ROP MWD 0.500 * F Code Samples Units Size Length 68 1 API 4 4 68 1 F/HR 4 4 8 Total Data Records: 32 Tape File Start Depth = 11680.000000 Tape File End Depth = 13000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 41 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU, WDFN mwd.xtf LCC 150 CN BP Exploration Inc. WN C-05A FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is the unedited field raw data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP 1 GRAX GRAX 0.0 2 ROPS ROPS 0 . 0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: IF ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units i GRAX MWD 68 i API 2 ROPS MWD 68 i F/HR Total Data Records: 32 Size Length 4 4 4 4 8 Tape File Start Depth = 11680.000000 Tape File End Depth = 13000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 Minimum record length: Maximum record length: 41 records... 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 01/05/lS 110262 01 **** REEL TRAILER **** MWD 01/05/15 BHI 01 Tape Subfile: 4 Minimum record length: Maximum record length: 2 records... 132 bytes 132 bytes Tape Tape Subfile 1 is type: LIS Subfile 2 is type: LIS DEPTH GR 11680.0000 -999.2500 11680.5000 -999.2500 11700.0000 15.8081 11800.0000 14.8998 11900.0000 16.3534 12000.0000 16.2110 12100.0000 -999.2500 12200.0000 22.2631 12300.0000 19.9882 12400.0000 14.3594 12500.0000 25.8154 12600.0000 17.2141 12700.0000 15.7732 12800.0000 18.0555 12900.0000 29.8529 13000.0000 -999.2500 ROP -999.2500 -999.2500 149.9251 90.7374 141.2266 166.1540 200 3984 99 8731 59 6186 20 9917 27 0768 44 1900 23 3510 51 5661 45 1861 -999 2500 Tape Tape File Start Depth = 11680.000000 Tape File End Depth = 13000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Subfile 3 is type: LIS DEPTH 11680.0000 11680 5000 11700 0000 11800 0000 11900 0000 12000 0000 12100 0000 12200 0000 12300 0000 12400 0000 12500 0000 12600 0000 12700 0000 12800 0000 12900 0000 13000 0000 GRAX -999 2500 -999 2500 16 3420 15 8660 17 5760 15 7020 -999 2500 24 1190 -999 2500 14 3870 13 7630 16 7030 14. 7500 16.7510 18.3880 -999.2500 ROPS -999 -999 31 86 106 147 211 9O 107 22 38 56 42 56 23 -999 2500 2500 4960 O700 2830 2910 2210 1100 7300 1110 9240 1350 8600 9550 0590 2500 Tape File Start Depth = 11680.000000 Tape File End Depth = 13000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS