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Home My WebLink About208-0497. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU K-20C Tbg Patch, Attempt IA Cmt Repair Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-049 50-029-22555-03-00 12696 Conductor Surface Intermediate Production Liner 8755 3681 9066 2541 1560 1233 8903 10-3/4" 7-5/8" 4-1/2" 3-1/2" x 3-3/16" 2-3/8" 8108 35 - 3716 32 - 9098 8936 - 11477 9917 - 11477 11463 - 12696 35 - 3712 32 - 8259 8133 - 8790 8670 - 8790 8790 - 8755 None 2460 5210 7500 10530 11780 8903 5210 8180 8430 10160 11200 11080 - 12662 4-1/2" 12.6# L80 30 - 8936 8779 - 8756 Structural 75 20" 36 - 111 36 - 111 4-1/2" TIW HBBP-T Packer 8878 8088 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907.564.5026 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028303 30 - 8133 IA from 4080 - 8878'MD Pump 109.7-bbls of 15.8-ppg Class G cement. Final pressure = 1587-psi. Pump/Squeeze 30-bbls Class G Cement. Final pressure = 555-psi. 287 Well Not Online 10763 118 350 100 180 180 321-124 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 8878, 8088 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:40 am, Sep 18, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.09.18 06:03:05 - 08'00' Torin Roschinger (4662) RBDMS JSB 092525 J.Lau 11/6/25 ACTIVITY DATE SUMMARY 5/23/2021 ******WELL S/I PRIOR TO ARRIVING ****** RUN AND BAIL FINE SANDS FROM 4 1/2" RBP @ 8620' MD W/2.50" X 10 PUMP BAILER W/3.70" X 25" EQUIL. SB FOR RBP (RETRIVE 2 GAL FINE SANDS) ATTEMPTED TO PULL 4 1/2" RBP @ 8620' MD W/ 25" X 3.72" G-BATED EQUILIZING/PULLING TOOLS ****** JOB IN PROGRESS CONTINUE IN AM ***** 5/24/2021 *****CONTINUED FROM 5-23-21 WSR ***** CONTINUE BAILING SAND 1/2 GAL MORE FROM RBP @ 8620' MD ATTEMPTING TO SHIFT EQUILIZING SLEEVE ON RBP @ 8620' MD W/ BAKER TOOL RAN 2.5" X 10' P.BAILER W/ 25" X 3.70" TATTLE TAIL, BELL TO 8605 SLM, 8620 RUNNING OTHER ASSORTED TOOLS TO INSURING REACHING SLEEVE ****JOB IN PROGRESS ****** 5/25/2021 ******CONTINUE FROM 5-24-21 WSR***** BAIL TO & EQUILIZE,BAKER RBP PULL 4 1/2" RBP W/BAKER RETRIEVAL TOOL MODIFIED SHORT BOTTOM @ 8620' MD, OOH W/ ALL ELEMENTS AND SLIPS **** JOB IN PROGRESS ****** 5/26/2021 ***CONTINUED FROM 5-25-21 WSR**** PT D&D @ 4850 MD 1 BBL PRESSURE UP TO 1670PSI 15 MIN 80PSI LOSS PT D&D @ 4800' MD 1 BBL PRESSURE UP TO 1548PSI 15 MIN 60PSI LOSS DRIFTED W/ 20'x3.66"DUMMY GUNS & SAMPLE BAILER S/D @ 5250'- 5277' SLM BEAT TO PASS TAGGED 8624' SLM (no sample) DRIFTED W/ 10'X3.66" DUMMY GUNS S/D @ 5250'-5260' SLM TAP DOWN TO PASS DRIFTED W/ 5' X 2 1/8" STEM & 40"X 3.70" WRP DRIFT - PASS FREELY 5350 SLM *** SLICKINE JOB PORTION COMPLETE AT THIS TIME*** 5/26/2021 T/I/O= 475/521/50 Temp= SI. LRS unit 72 Assist Slickline (CEMENT SQEEZE (OA/IADWNSQZ)). Pump as directed to assist with D&D Hole Finder. Pumped 2 bbls of crude. TBG lost 80 psi in 15 minutes during the first test. TBG lost 67 psi in 15 minutes during the second test. Final T/I/O= 500/520/50. S/L had control of the well upon departurre. 6/29/2021 ***WELL S/I ON ARRIVAL, DSO NOTIFIED***(plug set/tubing punch/cement retainer) SET NORTHERN SOLUTIONS COMPOSITE BRIDGE PLUG AT 8620'. CCL TO MID-ELEMENT OFFSET: 9'. CCL STOP DEPTH: 8611'. PUNCH TUBING ACROSS THE COLLAR AT 8587'. INTERVAL: 8584.5'-8589.5'. CCL TO TOP CHOT OFFSET: 8.5'. CCL STOP DEPTH: 8576'. CORRELATED TO TUBING TALLY RECORD DATED 26-UG-1998 ...JOB TO CONT ON 30-JUN-2021... Daily Report of Well Operations PBU K-20C Daily Report of Well Operations PBU K-20C 6/30/2021 ...CONT FROM 29-JUN-2021 WSR... SET NOTHERN SOLUTIONS CEMENT RETAINER MID-ELEMENT AT 8568'; TOP OF CEMENT RETAINER AT 8567.3'. CCL TO MID-ELEMENT OFFSET: 8.2'. CCL STOP DEPTH: 8559.8'. CORRELATED TO TUBING TALLY RECORD DATED 26-AUG-1998. JOB COMPLETE 11/18/2021 CTU6 1.75" CT Job Objective: IA Cmt Squeeze, Mill, FCO liner. MIRU CTU6. Completed weekly BOP testing. Wind 30mph Temp -2, SLB management is refusing to continue work. Shut down unit and go on no rate after BOP test. ***Job Continued on 11/19/21 WSR*** 11/18/2021 LRS Heat 2 transports for DSL for CTU ***Job continued on 11-19-21 WSR*** 11/19/2021 CTU6 1.75" CT Job Objective: IA Cmt Squeeze, Mill, FCO liner. Continue to standby for SLB managment approval to resume work. MU NS Stinger BHA & RIH. Establish baseline injection down coil before stinging into retainer .5 bpm @ 1226 psi. Baseline after stinging into retainer .5 bpm @ 2200 psi. Circulate 225 bbls of diesel down coil, through retainer, and up the IA through choke 1:1 returns. Pump 110.7bbls of 15.8-ppg Class G cement and displaced with diesel, layed 1bbl of cement on top of retainer while POOH. Lost IA returns 9bbls short of full displacement. Estimated TOC in IA = 4,653'. POOH pumping pipe displacement maintaining 590psi WHP. ***Job Continued on 11/20/21 WSR*** 11/19/2021 ***Job continued from 11-18-21 WSR*** Continue to heat DSL on transport to 80* for CTU. 11/20/2021 CTU #6 w/1.75 CT .145 WT Job Objective: IA cement squeeze, Mill, FCO Standby for cement to reach compressive strength. MU BOT Milling BHA and RIH. Dry tagged stringer 5,270' ctm, milled through and instant T x IA communication. Discuss plan forward w/OE. Tagged cement 6,237' ctm. Milled cement from 6,237' - 6462' ctm while pumping 5 bbl gel sweeps. Pump bottoms up and PUH to 5000' and reciprocate pipe while Worley catches up with fluid supply/returns. ROP 1-2 fpm, Pooh w/BHA to swap mill to PDC. RIH w/Baker milling BHA w/3.80" PDC. Continue milling 6,484' ctm - 6560' ctm. ***Job continued on WSR 11/21/21*** 11/21/2021 CTU #6 w/1.75" CT .145" Job Objective: IA cement squeeze, mill, FCO Continue milling cement from 6555' - 8125 ctm. Maintain 1:1 returns taking 65' bites with gel sweeps. ***Job Continued on WSR 11/22/21*** Daily Report of Well Operations PBU K-20C 11/22/2021 CTU #6 w/1.75" CT .145" Job Objective: IA cement squeeze, mill, FCO Continue milling cement from 8125'-8462 ctm. Maintain 1:1 returns taking 65' bites with gel sweeps. At 8,550' ctm, pumped 1.5 times bottoms up. Establish injection rates down tubing 1 bpm @ 180 psi, 2 bpm @ 211 psi, 2.5 bpm @ 205 psi. IA pressure remained constant during injection indicating T x IA x PC leak. Estimated TOC in Tbg/IA = 6200' MD. Discussed plan forward w/OE. Milled through NS cement retainer @ 8,567' MD. Milled cement down to 8,610' MD. Pumped bottoms up with gel pill and make wiper trip up to 5200'. Milled through NS CBP @ 8,620' MD. Work mill in hole to 8,640', discuss plan forward w/OE. Pump gel sweeps on bottom and chase to surface w/BHA. MIT-IA to 1500 psi for 30 minutes- Pass see log for details. ***Job Complete*** 1/8/2022 ***WELL S/I UPON ARRIVAL*** RUN 1: PERFORM 3.77" DRIFT TO 5800.0' RUN 2: SET NS CBP AT 5300.0', CCL TO ME = 12.1', CCL STOP DEPTH = 5287.9' ***WELL READY FOR FULLBORE*** 1/15/2022 T/I/O=200/0/60 Injectivity Test (Post Cement) Pump 25 BBL's of crude with safe lube at 1 BPM @ 350 psi. Pumped additional 45 BBL's at 2 BPM @ 550 psi. FWHPs=400/0/45 12/10/2022 T/I/O = SSV/240/90. Temp = SI. IA FL (CT). Temp ALP = 330 psi, SI @ CV. IA FL near surface. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:00 12/16/2022 LRS CTU#2 2.0" Blue Coil, Job Objective: IA down sqz, mill CBP MIRU LRS CTU#2. MU LRS cementing BHA and RIH. ***Job continued on 12-17-22*** 12/17/2022 LRS CTU#2 2.0" Blue Coil, Job Objective: IA down sqz, mill CBP Tag CBP at 5306 e/ 5298 m. Circulate diesel into tubing then perform injectivity test at 1 and 2 bpm (531 psi). Rig up cementers and start mixing cement. Pump 30 bbls of 15.8 ppg class "G" cement. Displacement 25 bbls out the tubing / into PC leak and shut down to hesitate. Pump the remaining 5 bbls at increments of 1 bbl every 10 minutes. POOH pumping pipe displacement. WOC to reach ~ 500 psi compressive strength. Pressure test cement to 500 psi (lost 24 psi in 5 minutes) = Pass. MU Yellowjacket 2-7/8" milling BHA w/ 3.80" X-caliber mill and RIH. Tag cement at 5236' CTM and start milling. Mill to CBP at 5300'. Pump gel sweep to clear well. Continue milling thru CBP and push downhole to 2nd CBP/sand at 8633' CTM. Try milling but repeated stalls. POOH to swap tools. ***Job continued on 12-18-22*** 12/18/2022 LRS CTU#2 2.0" Blue Coil 0.156 wall Job Objective: IA down sqz, mill CBP Continue POOH. Swap out mill for 3.77" venturi/burnshoe (2.00" ID) and RBIH. Tag at 8654' and mill down to 8770' before getting repeated stalls. POOH to check tools and the venturi is full of CBP debris. RBIH with same 3.77" venturi/burnshoe. Cleanout sand from 8770 - 9010 and pump a bottoms up. Dry tag at 9010'. POOH and recover ~ 1/2 cup of CBP debris. MU LRS slim FCO BHA w/ 2" JSN. RIH and tag fill at 9021' CTM and start FCO. ***Job in Progress*** Daily Report of Well Operations PBU K-20C 12/19/2022 LRS CTU#2 2.0" Blue Coil 0.156 wall Job Objective: IA down sqz, mill CBP, FCO Continue FCO down to the 2-3/8" liner top at 11,463' MD. Pump 10 bbl gel pill and chase OOH. Freeze protected the tubing to 2500' TVD. ***Job Complete on 19-DEC-2022*** 12/31/2022 T/I/O = Vac/Vac/70. Temp = SI. T & IA FL (slickline request). ALP = 200 psi, SI @ CV. T FL near surface. IA FL near surface. Slickline in control of well upon departure. SV, WV = C. SSV, MV = O. IA, OA = OTG. 13:15 12/31/2022 ***WELL S/I ON ARRIVAL*** (Cement squeeze) DRIFT TO 8,950' SLM W/ 4-1/2" BRUSH, 3.65" G-RING (No issues). SET 4-1/2" x 2-7/8" X-NIPPLE REDUCER AT 8,893' SLM / 8,903' MD. RAN 4-1/2" CHECK SET TO X-LOCK AT 8,893' SLM (Tool sheared indicating good set). SET 2-7/8" XX PLUG W/ FILL EXTENSION AT 8,903' MD. LRS CURRENTLY ATTEMPTING TO GET CMIT-T x IA TO 1500 PSI. ***JOB IN PROGRESS, CONTINUED ON 1/1/23 WSR*** 12/31/2022 T/I/O=0/0/70 (Cement Squeeze) Assist Slick Line Pumped 40 bbls crude down tbg to assist SL with plug set. Pumped 3 bbls 30* crude down TxIA via jumper to reach pressure of 1550 psi. 1st15 min lost 59/66 psi and 2nd 15 min lost 39/23 psi for a total loss of 98/89 psi in 30 min *** job continued to 01-01-23*** 1/1/2023 ***CONTINUED FROM 12/31/22 WSR*** (Cement squeeze) LRS PERFORMED SUCCESSFUL CMIT-T x IA TO 1515 PSI. UNABLE TO PASS 5,258' SLM W/ DUMMY 45KB x 30' STRADDLE PATCH (Left in hole). PULL DUMMY 45KB x 30' STRADDLE PATCH FROM 5,258' SLM (No obvious damage). TROUBLE-SHOOT RESTRICTION AT 5,258' SLM W/ VARIOUS DRIFTS (See log). ***JOB IN PROGRESS, CONTINUED ON 1/2/23 WSR*** 1/1/2023 *** job continued from 12-31-22*** CMIT TxIA to 1500 psi ( max applied 1550) Pressured TxIA to 1550 psi with 2.5 bbls crude TxIA lost 20/20 psi 1st 15 min and 15/15 psi 1n 2nd 15 min for a total loss of 35/35 in 30 min test with TxIA jumper open. bleed back to 500 psi Final WHP' 500/500/67 1/2/2023 ***CONTINUED FROM 1/1/23 WSR*** (Cement squeeze) TROUBLE-SHOOT RESTRICTION AT 5,258' SLM W/ VARIOUS TOOLS (See log). RAN HALLIBURTON CBL FROM 8,625' SLM TO 3,000' SLM (Good data). CURRENTLY LOGGING OUT OF HOLE W/ READ 40 ARM CALIPER FROM 8,890' SLM. ***JOB IN PROGRESS, CONTINUED ON 1/3/23 WSR*** 1/3/2023 ***CONTINUED FROM 1/2/23 WSR*** (Cement squeeze) RAN RCH 40 ARM CALIPER FROM 8,890' SLM TO SURFACE (Good data). CALIPER DATA SHOWED BUCKLING IN TROUBLE AREA OF ~5,258' SLM. ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** 1/6/2023 T/I/O= 317/278/66 Temp= SI. TFS unit 4 Pre AOGCC (MIT-T, CMIT-TxIA) Pumped 7 bbls cude down TxIA to attempt in getting a CMIT-TxIA. ***Job continued on 01/07/2023*** Daily Report of Well Operations PBU K-20C 1/7/2023 ***Job continued from 01/06/2023*** TFS unit 4 (Pre AOGCC CMIT-TxIA, MIT-T) CMIT-TxIA ***Failed*** Pumped 3.5 bbls crude to Achieve max psi of 1500. 1st 15 min TxIA lost 44/46 psi. 2nd 15 min TxIA lost 37/38 psi. Total loss of 81/84 psi in 30 min. MIT-IA ***PASSED*** to 1492 psi, Pumped .1 bbls crude to reach max applied psi of 1516. Target psi of 1350. 1st 15 min IA lost 19 psi, 2nd 15 min IA lost 5 psi, Total loss of 24 psi in 30 min. Bled back 2 bbls crude. Tag hung on IAC, MV. FWHP= 340/310/68 1/9/2023 T/I/O=0/355/0 CMIT-TxIA Pumped .3 bbls to reach MAX psi of 1515, 1st 15 min TBG lost 41 psi, IA lost 39 psi, 2nd 14 min TBG lost 33 psi, IA lost 34 psi , Total loss of 74 psi on the TBG and 73 psi on the IA in 30 min test ***FAIL*** see log for details FWHP= 328/327/69 1/14/2023 T/I/O= 0/325/50 MIT-IA/MIT-T MIT-IA***PASS*** Pumped 3.8 BBSL crude to reach MAX psi on MIT-IA of 2511 PSI 1st 15 min IA lost 116 psi, 2nd 15min IA lost 28 psi, total loss ot 144 psi in 30 min test. Bled back .7 bbls. MIT-T pumped 1.4 bbls to reach MAX psi MIT-T of 2512 PSI, 1st 15 min TBG lost 255 psi, 2nd 15 min TBG lost 157 psi, total loss of 412 psi 30 min test, Bled back 1.4 bbls FWHP=300/300/50 1/16/2023 ***WELL S/I ON ARRIVAL*** RAN 3.68" WRP DRIFT, 3' x 1-3/4" STEM. 3.69" SWAGE S/D @ 5,268' SLM. WORK THROUGH. DRIFT TO 5,350' SLM. RAN KJ, 10' x3.62" DUMMY WHIP, S/D @ 5,268' SLM UNABLE TO WORK THROUGH RAN KJ, 3.61" CENT, 1' x 1-1/2" STEM, 3.60" CENT, DRIFTED TO 5,350' SLM (no issues) *** WELL S/I ON DEPATURE*** 4/15/2023 CTU #9 1.75" 0.0156" CT Job Scope Mill restriction, Drift Travel to K pad, rig up, Make up Yellow jacket milling BHA with 3.78" mill, RIH dry drift to 5400' no tag. PUH to 5200' Mill from 5200' to 5400' two passes. Drift clean dry again. POOH freeze protect well. At surface did see some cement residue on the mill. RDMO to F-01. ***Job Complete*** 4/22/2023 ***WELL S/I ON ARRIVAL***(cement squeeze) DRIFTED TBG W/ 20' x 3.70" DUMMY WHIPSTOCK, TOOLS S/D @ 5267' SLM.(unable to work past) ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 4/24/2023 ***WELL S/I ON ARRIVAL*** RAN 10' x 3.68" DRIFT TO SD @5,263' SLM. UNABLE TO WORK DEEPER ***CONT ON 4/25/23 WSR*** 4/25/2023 ***CONT FROM 4/24/23 WSR*** RAN 3.68" BAITSUB, 21" STEM, 3.68" WRP DRIFT (=81" oal), SD @5,263' SLM. REPEAT @50 FPM, 100 FPM, & 125 FPM, SAME RESULTS RAN 3.68" DMY WRP (=42" oal), NO ISSUES GETTING THRU TROUBLE AREA. PASS THRU @50 FPM, 100 FPM, 150, FPM, 200 FPM ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU K-20C 5/11/2023 ***WELL S/I ON ARRIVAL*** RAN 4-1/2" GR, 3.72" DDIC PATCH DRIFT TO 6,000' SLM (sd in restriction @ 5,268' slm but fall through w/ ease, repeat 3 times w/ same result) RAN 36' x 3-3/8"(3.66") DMY PERF GUNS TO RESTRICTION @ 5,275' SLM, UNABLE TO WORK PAST ***CONTINUE ON 5-12-23 WSR*** 5/12/2023 ***CONTINUE ON FROM 5-11-23 WSR*** RAN 24' x 3-3/8" (3.66") DMY PERF GUNS TO RESTRICTION @ 5,277' SLM & WORK DOWN TO 5,278 SLM' BUT UNABLE TO WORK ANY DEEPER RAN 36' x 2.78" DMY PERF GUNS TO 6,000' SLM (no issues through restriction) RAN 12' x 3-3/8" DMY PERF GUN W/ 4-1/2" GR, 3.72" DDIC PATCH DRIFT TO 5,277' SLM (unable to work deeper) RAN 12' x 2-7/8" DMY PERF GUN W/ 4-1/2" GR, 3.72" DDIC PATCH DRIFT 5,268' SLM BUT ABLE TO WORK PAST W/ EASE, DRIFT TO 6,000' SLM (pull 200#lbs heavy thro restriction) RAN 12' x 3-3/8" DMY PERF GUN TO 5,271' SLM, UNABLE TO WORK ANY DEEPER LOCATE STA.# 4 @ 3,261' SLM / 3,265' MD FOR A -4' CORRECTION RAN 10' x 3.50" SPACER PIPE & UNABLE TO WORK PAST 5,271' SLM RAN 4-1/2" GR W/ 140" x 2-7/8" SPACER PIPE (2.87" od on top & btm) TO 5,274' SLM, UNABLE TO WORK TOOLS PAST RAN 10' x 2-7/8" SPACER PIPE, 4-1/2" GR W/ C-4 cent, 3.72" DDIC PACTCH DRIFT TO 5,271' SLM (unable to work past) RAN 20' x 2-7/8" SPACER PIPE (2.78" max od) TO 5,500' SLM (no issues sd in restriction) RAN 20' x 2-7/8" SPACER PIPE W/ 3.70" CENT, XO, 5' x 1.5" STEM, XO, 3.705" CENT TO 5,500' SLM (pull small over pull thro restriction) RAN 3.70" CENT, XO, 5' x 1.5" STEM, XO, 3.705" CENT TO 5,500, NO ISSUES THRO RESTRICTION (barbell set up 92" oal) ***CONTINUE ON 5-13-23 WSR*** 5/13/2023 ***CONTINUE ON FROM 5-12-23 WSR*** R/D HES 759 ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** 6/3/2023 ***WELL S/I ON ARRIVAL*** PT PCE 250LP-3000HP ATTEMPTED TO DRIFT THROUGH OBSTRUCTION AT 5264' MD WITH 33' NORTHERN SOLUTIONS ONE TRIP PATCH. TIED INTO READ CALIPER REPORT DATED 2-JAN-2023. TRIED 50, 100, 150 FPM WITH NO LUCK. 200-400# OVERPULLS TO GET FREE. REDRESSED 1 TRIP PATCH INTO 2 TRIP PATCH WITH SAME RESULTS, UNABLE TO DRIFT PATCH AT 20, 40, 60, 80, 100, 150, 175 FPM THROUGH RESTRICTION AT 5264' MD. ***WELL LEFT S/I, PAD OP NOTIFIED*** Daily Report of Well Operations PBU K-20C 7/26/2023 CTU #9 - 1.75" Coil x 0.156"wt Job Objective: Drift, Set Patch MIRU CTU. Perform weekly BOP Test. MU & RIH w/ HES GR/CCL logging tool & 3.70" x 5.03' WRP Drift OAL = 21.82'. RIH and log up 5800' - 3198' CTMD. Painted tie-in flag at 5100'. POOH pumping pipe displacement down CTBS. ...Job in Progress... 7/27/2023 CTU #9 - 1.75" Coil x 0.156"wt Job Objective: Drift, Set Patch Continue POOH w/ HES GR/CCL logging tool & 3.70" x 5.03' WRP Drift. At surface, BD logging tools/drift. Perform no flow - good. Establish circulation across the top & monitor trip tank for open hole patch deployment. RIH w/ & set NS one trip patch - Set depth = 5254' MD (UME), 5277' MD (LME). POOH. BD NS Tools. MU slb BHA w/ 2" JSN. RIH to 2500' & FP well w/ Diesel. POOH. RDMO CTU 9. ...Job Complete... 7/27/2023 T/I/O= 0/488/75 Temp= SI (MIT-T) TFS U3. Pumped 1.1 bbl of crude down the TBG to pressure up to 1740 and monitor integrity. Pumped 1.2 bbls of crude down the TBG to pressure up for an MIT-T MAP @ 1750 psi. Reached test pressure at (1759/517) psi. First 15 minutes TBG lost 131 psi, IA lost 0 psi. Second 15 minutes TBG lost 93 psi, IA lost 6 psi. ***FAIL***. *Job continues to *7-28-23* 7/28/2023 *Job continues from 7-27-23* (CMIT-TxIA) TFS U3. Pumped .1 bbls of crude down the TBG to pressures for integrity. Pumped .3 bbls of crude down the IA and TBG to monitor both strings for integrity. Pumped .1 bbls of crude down the TBG and IA to attempt a CMIT-TxIA MAP @ 1750 psi. Reached test pressure @ (1744/1750) psi. First 15 minutes TBG 51 psi, IA lost 44 psi. Second 15 minutes TBG lost 38 psi, IA lost 39 psi. ***FAIL***. Bleed back 1.5 bbls from both the IA and TBG to take both strings to starting pressures. FWHPS=0/275/50 SV/WV/SSV=C MV=O I/O=OTG 7/29/2023 T/I/O = 0/270/80. Temp = SI. MIT-T (FAIL)/ CMIT-TxIA (FAIL) LLR if fails (Eval TxIA). AL tied into K-317 (FP'd) SI @ CV. MIT-T: Pumped 2.9 bbls DSL down TBG to attempt MIT-T @ 1610 psi (Target 1500 psi). Lost 353 psi in 15 min/ IAP increased 3 psi (FAIL). Re-pressured TBG to 1610 psi ( .25 bbls), lost 202 psi in 15 min/ IAP lost 5 psi FAIL). Roll into LLR. LLR= .74 gpm @ 1610 psi. CMIT-TxIA: Equalized TBG & IAP @ 1350/1350 psi. Pumped 1 bbl DSL to achieve test pressure of 1750/1760 psi (Target 1500 psi). Lost 140/153 psi in 15 min, lost 127/127 psi in second 15 min (FAIL). Roll into LLR. LLR = .74 gpm @ 1750 psi. Bled WHP's back to starting pressures. Returned 1.5 bbls. FWHP's = 40/210/85 SV, WV, SSV = C. MV = O. IA & OA = OTG. 16:00 Daily Report of Well Operations PBU K-20C 8/8/2023 ***WELL S/I ON ARRIVAL*** RAN 4-1/2" CAT-VLV x 2-3/8" STL, 3" QCLL TEST TOOL TO 5,273' SLM. (ATTEMPT MIT-T) RAN 4-1/2" CAT-VLV x 2-3/8" STL, 3" QCLL TEST TOOL TO 5,273' SLM (FAILED MIT-T x2) EQUALIZED 2-7/8" XX-PLUG @ 8,911' SLM / 8,903' MD PULLED 2-7/8" XX-PLUG FROM 8,911' SLM / 8,903' MD LRS LOADED TBG 174bbls crude SET 2-7/8" XX-PLUG @ 8903' MD LRS PERFORMED FAILING MIT-T (see log) RAN KJ, 2.25" CENT, 2-7/8" SHEARABLE EQ PRONG (cont on next day) ***WSR CONT ON 8-9-23*** 8/8/2023 T/I/O= 37/26/78 LRS Unit 72 Assist Slickline as directed. Pump 174 BBLS Crude to load the TBG. Attempted MIT-T Failed. LLR= 1.68 GPM. ***Job Continued 8/9/23*** 8/9/2023 ***Job Continued 8-8-23*** (ANN-COMM) Assist Slickline. Attempted MIT-T Failed. LLR .14 GPM. Retest MIT-T. (See log for details) Pumped 4 bbls crude for MIT-T. Final MIT-T Passed. 15 min Loss 42 Psi. 30 min Loss 14 Psi. FWHP=336/0/82. Left well in SL Control. 8/9/2023 ***WSR CONT FROM 8-8-23*** RAN 2.25" CENT, 2-7/8" SHEARABLE EQ PRONG, EQUALIZE 2-7/8" XX-PLUG @ 8906' SLM / 8903' MD PULLED 2-7/8" XX-PLUG FROM NIP REDUCER @ 8906' SLM / 8903' MD SET 2-7/8" XX-PLUG (41" LIH, 18" fill ext, 2x7/32" EQ-ports, 5pc packing facing up,o- ring, 1pc packing facing down) IN NIP REDUCER @ 8906' SLM / 8903' MD LRS PERFORMED FAILING MIT-T's (see log) RAN 4-1/2" CAT-VLV x 2-3/8" STL, 3" QCLL TEST TOOL (OAL 50") TO PATCH @ 5,273' SLM LRS PERFORMED FAILING MIT-T's (see log) RAN 4-1/2" GR, 4-1/2" D&D HOLE FINDER, START @ 5250' SLM (fail) PUH TO 4750' SLM (pass) RAN 4-1/2" GR, 4-1/2" D&D HOLE FINDER, START @ 5250' SLM (fail) PUH TO PUH TO 5151' SLM, -100#psi PUH 5200' -100#psi PUH TO 5151' SLM, LOSS OF - 72#psi IN 15min, LRS MIT-T STARTING TBG 1482#psi 1st 15min TBG - 42#psi / IA 0# 2nd 15min TBG 14#psi / IA -0# (pass) (possible leak between 5151'SLM to 5200' slm) ***JOB COMPLETE, WELL LEFT S/I*** 8/28/2023 T/I/O = 120/25/80, Temp = SI. MIT-T (PASS), CMIT-TxIA (PASS) to 1500 psi (post patch). AL tied into K-317, SI @ CV. IA FL @ surface, TBG FL @ surface. MIT-T: Pumped 1.3 bbls DSL down TBG to achieve 1725 psi (1500 psi target). Lost 41 psi in 15 min, lost 19 psi in second 15 min (PASS). CMIT-TxIA: Pumped 1.3 bbls DSL TBG & IA to achieve 1723/1720 psi, lost 63/64 psi in 15 min, lost 23/23 psi in second 15 min (PASS). Bled back TBG & IAP to BT, returned 1.3 bbls fluid. FWHP's = 50/25/80 SV, SSV, WV = C. MV = O. IA & OA = OTG. 14:30 Daily Report of Well Operations PBU K-20C 8/30/2023 T/I/O = 190/2-/76. Temp = SI. MIT-T (FAIL), CMIT-TxIA (FAIL) to 1500 psi (post patch). AL tied into K-317 SI @ CV, freeze protcted. TBG FL @ surface, IA FL @ surface. MIT-T: Pumped 1.3 bbls DSL down TBG to achieve 1691 psi (1500 psi target). Lost 130 psi in 15 min, lost 121 psi in second 15 min. Called grease crew to service wing valve. Re-pressured TBG to 1710 psi, lost 112 psi in 15 min, lost 96 psi in second 15 min (FAIL). Equalized TP & IAP 842/836 psi. CMIT-TxIA: Pumped 1.4 bbls DSL down TBG & IA to achieve 1716/1720 psi (1500 psi target). OAP increased to 123 psi. Lost 167/27 psi in 15 min, lost 143/ 18 psi in second 15 min (FAIL). Bled TBG & IAP to 0 psi. Pumped 3.4 bbls total job, returned 2 bbls fluid. FWHP's = 0/0/70. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:45. 9/8/2023 ***WELL SHUT IN ON ARRIVAL*** Pressure test PCE from 200lp- 3000hp RUN #1 = RIH with RIH with 1 7/16" Cable Head, 1.69" CCL, 1.81" EWST, 1.69" Test Pressure EV, 1.69" Bellville Disconnect, 1.69" Baffle Sub, 1.69" Hydraulic Running Tool, 1.69" RIBP (MAX OD = 1.81" , MAX LENTH = 21.42') RUN #2 = RIH with 1 7/16" Cable Head, 1.69" Weight Bar, 1.69" CCL, 1.81" EWST, 1.69" Test Pressure EV, 1.69" Bellville Disconnect, 1.69" Baffle Sub, 1.69" Hydraulic Running Tool, 1.69" RIBP (MAX OD = 1.81" , MAX LENTH = 28.42') Plug failed to set Rig down/Move off ***WELL SHUT IN ON DEPARTURE*** (JOB INCOMPLETE) 9/25/2023 *** WELL SI ON ARRIVAL *** INITIAL T/I/O = 0/1350/100 CCL - MID ELEMENT = 17.7, CCL STOP = 8819.3, MID ELEMENT SET DEPTH = 8837.0 FT. BAKER REPORTS GOOD INDICATION OF SETTING. ELINE COMPLETE. FINAL T/I/O = 0/1350/100 *** WEL LSI ON DEPARTURE, DSO NOTIFIED *** 9/26/2023 T/I/O = 29/1365/28. Temp - SI, Conduct MIT-T and CMIT-TxIA. MIT-T ***PASSED*** @ 1675 psi. Pumped 1.5 bbls DSL to achieve max applied pressure of 1765 psi. 1st 15 min, TBG lost 65 psi. 2ns 15 min, TBG lost 26 psi. CMIT-TBG x IA ***PASSED*** @ TBG/IA - 1714/1695 psi. Pumped .7 bbls 50* DSL into TBG/IA to reach max applied pressure of TBG/IA - 1754/1748 psi. 1st 15 min, TBG/IA lost 26/43 psi. 2nd 15 min, TBG/IA lost 14/10 psi. Bled back 1.7 bbls. Tags hung. Pad operator notified upon departure. FWHP's = 35/1304/30 Daily Report of Well Operations PBU K-20C 9/27/2023 OGCC MIT-IA (ANN-COMM) AOGCC CMIT-T x IA to 2250 PSI ***PASS*** Target = 2250 PSI Max Applied = 2250 PSI Pumped 2 BBLS DSL down the TBG and IA to take pressure TBG to 2245 PSI and IA to 2255 PSI for CMIT-T x IA. TBG lost 84 PSI and IA lost 83 PSI first 15 mins and lost TBG 35 PSI and IA lost 36 PSI second 15 mins for total loss of TBG 119 PSI and IA loss 119 PSI in 30 mins. Bled IA back to starting pressure and got back 1 BBLS. **MIT-T FAILED** Pumped .26 BBLS down TBG to bring to test pressure of 2270 PSI for MIT-T. TBG lost 45 PSI first 15 mins and 32 PSI second 15 minutes for total loss of 77 PSI in 30 mins test. Bled TBG to starting pressure and got back 1.1 bbls. Pad Op notified of well status. Well is shut in. IA/OA=OTG ***Witnessed by WSS Ryan and State Rep Austin. **Tag hung on IA** 9/28/2023 T/I/O = 655/925/0. Temp = SI. Bleed T & IA to 200 psi (pre MIT). AL SI @ CV (tied into K-317). TBG FL @ surface, IA FL @ near surface. Bled IAP to BT to 190 psi in 5 min (FTS). Bled TP to 185 psi in 5 min. Monitor for 30 min, IAP increased 10 psi, TP increased 5 psi. FWHP's = 190/200/0. SV, WV, SSV = C. MV = O. IA & OA = OTG. 15:45. 10/7/2023 T/I/O = SSV/250/50. Temp = SI. Attempt 3 MIT-Ts. Last MIT-T **PASSED** to 1750 psi w/ Diesel (Eval TxIA). Max applied = 1760 psi, Target = 1500 psi. T FL near surface. Used 1.3 bbl to pressure TP to 1756 psi. TP decreased 24 psi in the 1st 15 min and 19 psi in the 2nd 15 min for a total loss of 43 psi in 30 min. Flowline pressure unchanged. Bled TP to BT from 1710 psi to 400 psi in 4 min. Tags hung. Final WHPs = SSV/330/50. SV, SSV, WV = C. MV = O. IA & OA = OTG. 16:30 10/14/2023 T/I/O = SSV/260/50. Temp = SI. MIT-T to 1500 psi target **PASSED** (Eval TxIA). ALP = Vac. Max applied = 1754 psi, Target = 1500 psi. T FL near surface. Used 0.8 bbls to pressure TP to 1754 psi. TP decreased 78 psi in the 1st 15 mins and 35 psi in the 2nd 15 mins for a total loss of 113 psi in 30 mins (PASSED). Flowline pressure unchanged. Bled TP to BT from 1641 psi to 400 psi in 4 mins (1.2 bbls). Monitored while RD. TP unchanged. IA & OA both increased 10 psi. Tags hung. Final WHPs = SSV/270/60. SV, WV, SSV = C. MV = O. IA & OA = OTG. 13:00 10/22/2023 T/I/O= 490/247/57 (CEMENT SQUEEZE (OA/IA DWNSQZ)) (**EARL**) AOGCC MIT-T to 2,257 psi ****PASSED**** Target Pressure= 2,250 psi - Max Pressure= 2,500 psi - Pumped 1.8 bbls of Crude down TBG to reach 2,484 psi. 1st 15-minute loss of 162 psi, 2nd 15-minute loss of 65 psi, for a total loss of 227 psi in 30 minutes. Bled back ~1.3 bbls. Valve Positions - SV/WV/SSV/AL= Closed, MV= Open, IA/OA= OTG FWHPs= 485/265/60 10/26/2023 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD #61 ***WSR CONT ON 10-27-23*** Daily Report of Well Operations PBU K-20C 10/27/2023 WSR CONT FROM 10-26-23 SET WHIDDON CATCHER @ 5254' MD PULL BK-DMY FROM STA #4 @ 3265' MD PULL CATCHER @ 5254' MD EQ & PULL 1.69'' IBP FROM 8837'MD SET 4-1/2'' WHIDDON CATCHER @ 5254'MD SET BK-OGLV IN ST#4 @ 3265'MD(20/64'') PULLED 4-1/2'' WHIDDON CATCHER FROM 5254'MD EQ & PULLED 2-7/8'' XX-PLUG FROM NIP-REDUCER @ 8903'MD SET 3.81'' ROCK SCREEN IN SSSV- NIP @ 2222'MD(18' 7''lih) ***WELL LEFT S/I ON DEPARTURE*** 10/30/2023 T/I/O = 917/919/31 LRS 70 Hot Oil Treatment (HOT OIL TBG WASH) Pumped 3 bbls 60/40 meth and 140 bbls 190* Crude. ***Job Continued to 10-31-2023*** Performed Well Control Drill 10/31/2023 ***Continue Job from 10-30-2023*** Hot Oil Treatment (HOT OIL TBG WASH) Rig down and travel. SV/WV = S, SSV/MV/PB = O, IA/OA = OTG. Pad Op notified upon LRS departure. 1/21/2024 *** WELL S/I ON ARRIVAL *** PULLED 4-1/2" ROCKSCREEN FROM 2,222' MD. *** WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED *** 8/22/2025 LRS Test Unit 6, Begin WSR on 8/22/25, CTU Assist w/ FCO, IL-K-20, OL K-317, Unit Move, Begin RU, Continue WSR on 8/23/25 8/23/2025 (CEMENT SQUEEZE (OA/IA DWNSQZ)) Assist well testers. Flush vessel. Pumped 75 bbls diesel through test unit into return tank. 8/23/2025 LRS Test Unit 6, Continue WSR from 8/22/25, CTU Assist w/ FCO, IL-K-20, OL K- 317, Continue RU, PT, Continue WSR on 8/24/25 8/24/2025 LRS Test Unit 6, Continue WSR from 8/23/25, CTU Assist w/ FCO, IL-K-20, OL K- 317, Continue SB for OSL, POP, SI, Blow down, Begin RD, Continue WSR on 8/25/25 8/24/2025 LRS CTU #1 1.5" CT .134" WT HT-110 Job Objective: Drift liner/FCO Travel from D-01 to K-20, Start rigging up and found well was making 5,000 BWPD at 80 degree WHT. Discussed likely PC leak with OE and decided to RDMO. Rig down CTU and head to 06-18. 8/25/2025 LRS Test Unit 6, Continue WSR from 8/24/25, CTU Assist w/ FCO, IL-K-20, OL K- 317, Continue RD, Job Complete, END WSR 8/25/2025 T/I/OA=1350/1350/0 TFS unit 4 Freeze Protect for Testers Post Well Tester Freeze Protect. Pumped 9 bbls 60/40 followed by 20 bbls crude down K-317 FL using west side recipe Pumped 38 bbls crude down K-20 TBG Pumped 9 bbls 60/40 followed by 19 bbls crude down K-20 FL using west side recipe. FWHP's= 1000/1370/0 Tags hung on WV Pad op notified of well status upon departure 8/26/2025 LRS Test Unit 6, Vessel Clean Out, Begin WSR on 8/26/25, perform vessel Clean out, Unit Maintenance, End WSR on 8/26/24 8/26/2025 T/I/O = SSV/1420/40. Temp = SI. IA FL (OE request). ALP = 150 psi, SI @ CV. Hard Line rigged up from IA to K-14 tree cap, SI @ BV. IA FL @ 3265' (sta # 4 SO, 86 bbls). SV, WV, SSV, = C. MV = O. IA, OA = OTG. 10:00 Daily Report of Well Operations PBU K-20C 9/5/2025 ***WELL S/I ON ARRIVAL*** RAN 2-7/8" BRUSH & 2.20" GAUGE RING TO BRUSH 2.31" X-NIP AT 8,903' MD SET 4-1/2" WHIDDON ON PATCH AT 5,254' MD PULLED BK-OGLV AT ST# 4 (3,265' md) LOADED IA WITH 100bbls OF CRUDE SET BK-DGLV IN ST# 4 (3,265' md) PULLED 4-1/2" WHIDDON AT 5,254' MD (empty) ***CONTINUE ON 9/6/25 WSR*** 9/5/2025 T/I/O=932/1374/36 Assist SL with L&T Loaded IA with2 bbls 60/40, 100 bbls 80* crude, and TBG with 170 bbls 80* crude ***job continued to 09-06-25*** 9/6/2025 ***CONTINUED FROM 9/5/25 WSR*** LRS LOADED TBG W/ 200 BBLS CRUDE SET 2.31" PX PLUG AT 8,903' MD LRS ATTEMPTED TO PRESSURE UP TBG (see log) ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 9/6/2025 ***job continued from 09-05-25*** MIT IA PASSED @ 2352 PSI Pumped an additional 30 bbls (200 total) 80* crude down tbg to load. Pumped 50 bbls crude down TBG at 5 bpm LLR = 5 bpm @ 700 psi. RDMO FWHPs = 533/355/46 IA and OA = OTG. Info tag and fluid packed annulas hung on IA valve. SL in control of well upon LRS departure. 1 Regg, James B (OGC) From:PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent:Monday, October 23, 2023 5:49 AM To:Regg, James B (OGC) Cc:Wallace, Chris D (OGC); Oliver Sternicki; Torin Roschinger Subject:OPERABLE: Producer K-20 (PTD #2080490) Passing AOGCC MIT-T & CMIT-TxIA Mr. Regg, Producer K‐20 (PTD #2080490) passed AOGCC MIT‐T on 10/22 and previously passed AOGCC CMIT‐TxIA on 09/27. The passing MIT’s verify well barrier integrity post IA cement and satisfy requirements in sundry #321‐124. The well is now classified as OPERABLE. 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: Saturday, September 7, 2019 1:47 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@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 DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@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>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Stone, Christopher <Christopher.Stone@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 K‐20 (PTD #2080490) LDL identified production casing leak CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. 2 All, Producer K‐20 (PTD #2080490) was made Under Evaluation on 08/12/19 for sustained IA casing pressure above NOL and failing a warm TIFL. On 09/05/19 Slickline set a TTP and could not obtain a passing MIT‐T or CMIT‐TxIA. A subsequent LDL was performed and identified a production casing leak ~5,268’ MD. The failed MIT‐T and production casing leak indicate multiple failed barriers and the well is now classified as NOT OPERABLE and will remain secured with a TTP. The Anchorage engineers will evaluate for repair. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 907-659-8110 From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, August 12, 2019 1:05 PM To: 'Regg, James B (DOA) (jim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC1 Facility PTL <AkOPSGC1FacilityPTL@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1FieldPTL@bp.com>; AK, OPS GC1 OSM <AKOPSGC1OSM@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 DG <AKOPSWellPadDG@bp.com>; AK, OPS Well Pad EKG <AKOPSWellPadEKG@bp.com>; AK, OPS Well Pad YP <AKOPSWellPadYP@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>; Derrick, Laurie R <Laurie.Derrick@bp.com>; Stone, Christopher <Christopher.Stone@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 K‐20 (PTD #2080490) sustained IA casing pressure above NOL, failed warm TIFL All, Producer K‐20 (PTD #2080490) was reported to have sustained IA casing pressure above NOL on 08/09/19. On 08/11/19 DHD performed a failing warm TIFL. The failed 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. 3 Andrew Ogg Well Integrity Engineer BP Global Wells Organization – Alaska Office: 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, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, December 6, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC K-20C PRUDHOE BAY UNIT K-20C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/06/2023 K-20C 50-029-22555-03-00 208-049-0 N SPT 8088 2080490 2022 490 2484 2322 2257 57 61 63 64 OTHER P Adam Earl 10/22/2023 MIT-T tested as per Sundry 321-124 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT K-20C Inspection Date: Tubing OA Packer Depth 247 374 380 379IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE231025105505 BBL Pumped:1.8 BBL Returned:1.3 Wednesday, December 6, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 2LOSURGXFHUWHVWDIWHU,$UHPHGLDOFHPHQW Sundry 321-124 James B. Regg Digitally signed by James B. Regg Date: 2023.12.06 09:37:41 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC K-20C PRUDHOE BAY UNIT K-20C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 K-20C 50-029-22555-03-00 208-049-0 N SPT 8088 2080490 2022 481 2245 2161 2126 35 86 86 85 OTHER P Austin McLeod 9/27/2023 Producer. CMIT TxIA. Cemented IA. TOC @ 4770 ft MD. Sundry 321-124. Tubing not bled. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT K-20C Inspection Date: Tubing OA Packer Depth 488 2255 2172 2136IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230929110603 BBL Pumped:3 BBL Returned:1 Tuesday, October 17, 2023 Page 1 of 1 9 9 9 9 9 99 99 9 9 9 9Producer. CMIT TxIA. James B. Regg Digitally signed by James B. Regg Date: 2023.10.17 16:39:53 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC K-20C PRUDHOE BAY UNIT K-20C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 K-20C 50-029-22555-03-00 208-049-0 N SPT 8088 2080490 2022 1990 2265 2210 2174 34 37 37 37 OTHER F Austin McLeod 9/27/2023 Producer. MITT. Sundry 321-124. Failing test that was bumped up. Bump up on separate report. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT K-20C Inspection Date: Tubing OA Packer Depth 515 537 537 535IA 2143 37 45 Min 531 60 Min Rel Insp Num: Insp Num:mitSAM230929111128 BBL Pumped:0.1 BBL Returned: Tuesday, October 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 7EJWHVWIDLOHGWRGHPRQVWUDWHVWDELOL]DWLRQSUHVVXUHORVV! 9 9 Producer. MITT. James B. Regg Digitally signed by James B. Regg Date: 2023.10.17 16:37:32 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 17, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC K-20C PRUDHOE BAY UNIT K-20C Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/17/2023 K-20C 50-029-22555-03-00 208-049-0 N SPT 8088 2080490 2022 2143 2270 2225 2193 37 46 46 46 OTHER F Austin McLeod 9/27/2023 Producer. MITT. Sundry 321-124. Bump up from previous fail. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT K-20C Inspection Date: Tubing OA Packer Depth 531 1045 1025 1020IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM230929111449 BBL Pumped:0.3 BBL Returned:1.1 Tuesday, October 17, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 )DLOWRGHPRQVWUDWHVWDELOL]DWLRQSUHVVXUHORVV! Producer. MITT. James B. Regg Digitally signed by James B. Regg Date: 2023.10.17 16:32:09 -08'00' Kyle Wiseman Hilcorp Alaska, LLC Geotechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: Kyle.Wiseman@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 01/11/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230111 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# PBU 05-30 50029222130000 191115 1/2/2023 HALLIBURTON RMT3D PBU 15-07D 50029211660400 215158 12/29/2022 HALLIBURTON RMT3D PBU K-20C 50029225550300 208049 1/2/2023 HALLIBURTON RBT PBU L1-13 50029235630000 216003 1/4/2023 HALLIBURTON RMT3D PBU Z-223 50029237200000 222080 12/22/2022 HALLIBURTON WFL-TMD3D-RMT3D PBU L-112 50029231290000 202229 1/6/2023 READ MemoryRadialCementBondLog Please include current contact information if different from above. By Meredith Guhl at 3:24 pm, Jan 11, 2023 T37435 T37436 T37437 T37438 T37439 T37440 PBU K-20C 50029225550300 208049 1/2/2023 HALLIBURTON RBT Meredith Guhl Digitally signed by Meredith Guhl Date: 2023.01.11 15:32:54 -09'00' Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:208-049 6.API Number:50-029-22555-03-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028303 Property Designation (Lease Number):10. 341H 8. PBU K-20C 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 12696 Effective Depth MD: L80 11. 3/24/2021 Commission Representative: 15. Suspended Contact Name:Aras Worthington Contact Email:Aras.Worthington@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8755 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8878, 8088 No SSSV Installed Date: Liner 1233 2-3/8" 11463 - 12696 8790 - 8755 11200 11780 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 35 - 3716 35 - 3712 14. Estimated Date for Commencing Operations: BOP Sketch 36 - 111 Structural 8180 Proposal Summary 13. Well Class after proposed work: 4-1/2" TIW HBBP-T Packer 11080 - 12662 8779 - 8756 4-1/2" 12.6#30 - 8936 Production 12662 8756 None None 36 - 111 10-3/4" 7-5/8" Contact Phone:907.564.4763 Date: 5210 75 20"Conductor 2460 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3681 5210 Intermediate 9066 32 - 9098 32 - 8259 2541 4-1/2"8936 - 11477 8133 - 8790 8430 7500 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2520 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. IA Cement Repair, Patch Tubing 55 By Samantha Carlisle at 11:41 am, Mar 11, 2021 321-124 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.03.11 08:25:03 -09'00' Stan Golis (880) MGR12MAR21 DLB03/10/2021 DSR-3/11/21 *CBL to AOGCC *State witnessed CMIT-TxIA, MIT-T *Biennial CMIT-TxIA, MIT-T SFD X 10-404Yestion Required? Comm 3/12/21 dts 3/12/2021 RBDMS HEW 3/15/2021 IA Cement for PC/Tbg Leak Well: K-20C Well:K-20 API Number:50-029-22555-03-00 Current Status:Not Operable Ivishak Producer Rig:N/A Estimated Start Date:March 20, 2021 Estimated Duration:N/A Reg.Approval Req’d?Yes Regulatory Contact:Abbie Barker First Call Engineer:Noel Nocas 907-564-5278 (O) Second Call Engineer:Aras Worthington 907-564-4763 (O) Current Bottom Hole Pressure (est):3300 psi @ 8800’ TVD Maximum Expected BHP:3400 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2520 psi Gas Column Gradient (0.1 psi/ft) History K-20 is a natural flow Ivishak producer that developed a PC and Tubing leak in 2019. Cretaceous water killed the well through the tubing leak and a subsequent TIFL failed on 8/11/2019. Cretaceous sand also inflowed into the well. Current Status Not Operable well with PC and Tubing leaks both @ ~5270’ MD. Objective Execute an IA cement repair to seal of the PC and tubing leaks. The proposed TOC the IA is ~4770’ MD which is ~500’ MD above the PC and Tubing leaks @ 5270’ MD (a general-rule minimum of cement above a PC leak needed for a reliable cement repair). The proposed TOC is ~1040’ TVD below the SC shoe and ~70’ deeper than the estimated top of the UG4 marker @ ~4700’ MD (UG4 is estimated because there is no shallow log on this well and offset well logs were used to estimate it). Post-job Evaluation o MIT-T and CMIT-TxIA o SCMT to confirm the Top of Cement (TOC) Long-Term Integrity Monitoring o Biennial MIT-T and CMIT-TxIA o Monitor and Record WHPs daily IA Cement for PC/Tbg Leak Well: K-20C Procedural steps Slickline 1. Pull Baker RBP from ~8620’ MD. 2. Set retrievable plug @ ~4800’ MD. 3. PT tubing to verify tubing integrity above 4800’ MD. 4. Pull retreivable plug. E-Line & Fullbore 1. Set 4-1/2” CBP @ ~8620’ MD. 2. Establish LLR of Tubing x IA & CBP @ 500 psi and 1500 psi to test CBP. 3. Punch tubing in the middle of the first collar above the CBP. 4. Pump diesel down the tubing while taking returns up the IA, to confirm circulating rates and pressures through tubing punch. 5. Set 4-1/2” cement retainer just above the tubing punch. Coiled Tubing 1. Sting into cement retainer. 2. Pump down CT: ¾225 bbls diesel (Freeze-protect for IA after the cement job is in place) ¾105 bbls 15.8 ppg Class G cement ¾Chase w/diesel Cement Calculations ¾7-5/8” x 4-1/2” volume from 4770’ – 8620’ MD: 101 BBLS Coiled Tubing 1. Mill out cement retainer, cement, and CBP. 2. FCO sand in tubing down to LTP and/or down through slotted liner as needed. Slickline & Fullbore 1. Set Plug in one of the landing nipples between 8868’ MD and 8934’ MD. 2. CBL from ~8600’ MD to ~4000’ to identify TOC in IA. 3. Conduct AOGCC witnessed MIT-T and CMIT-TxIA to 1500 psi. Ensure 24-hour notice provided for AOGCC. E-Line/Slickline (Contingent) 1. If MIT-T above fails, set Nipple Reducer and plug in one of the landing nipples between 8868’ MD and 8934’ MD. 2. Set patch across Tubing leak @ ~5270’ MD. 3. Conduct AOGCC witnessed MIT-T to 1500 psi. 4. Pull plug from nipple reducer. Well Diagnostics & WIE 1. Update AKIMS and add biennial MIT-T and CMIT TxIA. CBL to AOGCC. IA Cement for PC/Tbg Leak Well: K-20C Tubing and PC Leaks @ ~5270’ MD IA Cement for PC/Tbg Leak Well: K-20C K-20 IA Cement Proposed TOC in IA ~4770’ MD Contingent Patch over Tubing Leak @ ~5270’ MD IA Cement for PC/Tbg Leak Well: K-20C K-20 Proposed P&A Surface Cement Plug Reservoir Cement Plug • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday,August 23, 2017 7:50 AM To: AK, GWO Well Integrity Engineer;AK, GWO SUPT Well Integrity;AK, OPS GC1 Facility OTL;AK, OPS GC1 Field O&M IL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad EKG;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Alatalo,Travis; Cerveny, Philip F; Derrick, Laurie R; Frankenburg,Amy; Haffener,Jordan;Oshiro,Joleen; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer K-20C (PTD#2080490)Well Barriers Restored All, Producer K-20(PTD#2080490)was made under evaluation on 07/17/2017 for exceeding NOL on the inner annulus and failing a subsequent TIFL. Slickline performed a gas lift change out on 08/1/17 and the well passed a subsequent warm TIFL on 8/22/17. With the passing PPPOT-T on 3/10/16, MIT-IA on 3/2/11 and recent TIFL,the well meets operability criteria. The well now has two competent barriers and is reclassified as Operable. Plan Forward: 1. Downhole Diagnostics:warm TIFL—Failed 07/15/17 2. Slickline: Change out orifice gas lift valve—Complete 08/01/17 3. Downhole Diagnostics:TIFL—Complete 08/22/17 4. Well Integrity Engineer/Anchorage PE:Additional diagnostics as required Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering Office 907-659-8110 Cell 907-980-0552 SCANNED AUG Harmony 4530 � �� 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Sunday,August 13, 2017 12:49 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC1 Facility OTL;AK, OPS GC1 Field O&M IL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad EKG;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Alatalo, Travis;Cerveny, Philip F; Derrick, Laurie R; Frankenburg, Amy; Haffener,Jordan;Oshiro,Joleen; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer K-20C (PTD#2080490) Sustained IA Pressure Over NOL - Roll Clock for an additional 28 days All, Producer K-20(PTD#2080490)was made under evaluation on 07/17/2017 for exceeding NOL on the inner annulus and failing a subsequent TIFL. Slickline performed a gas lift change out on 08/1/17, but could not pop the well for a warm TIFL due to a pad shutdown resulting from a TAR on GC1. The current estimate for K pad to come back online is 08/18/17. The under evaluation clock will be rolled 28 days to accommodate the pad shutdown and allow time for diagnostics. The well is still classified as Under Evaluation, and is on a 28 day clock to confirm or restore barriers,or be secured. Plan Forward: 1. Downhole Diagnostics: warm TIFL—Failed 07/15/17 2. Slickline: Change out orifice gas lift valve—Complete 08/01/17 3. Downhole Diagnostics:TIFL 4. Well Integrity Engineer/Anchorage PE:Additional diagnostics as required Please reply if in conflict with proposed plan. Matt Ross (Alternate: Josh Stephens) Well Integrity Engineering SCANNED lair1 ' Office 907-659-8110 ' Cell 907-980-0552 Harmony 4530 1 . • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com> Sent: Monday,July 17, 2017 1:32 PM To: AK, OPS GC1 Facility OTL;AK, OPS GC1 Field O&M IL;AK, OPS GC1 OSM;AK, OPS GC1 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad EKG; Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;Alatalo,Travis;Cerveny, Philip F; Derrick, Laurie R; Frankenburg,Amy; Haffener, Jordan; Oshiro,Joleen; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK,GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R;Worthington, Aras J;Wallace, Chris D (DOA) Subject: Producer K-20C (PTD#2080490) Sustained IA Pressure Over NOL Attachments: K-20C.pdf; Producer K-20C (PTD#2080490)TIO Plot 2017-07-17.docx All, Producer K-20C(PTD#2080490)was reported to have sustained Inner Annulus(IA)casing pressure over NOL on 07/15/17.Confirmed pressures were TBG/IA/OA=2150/2120/20 psi.A Tubing Integrity Fluid Level (TIFL)test failed, indicating a lack of two competent well barriers.The well is now classified as Under Evaluation,and is on a 28 day clock to confirm or restore barriers,or be secured. Plan Forward: 1. Downhole Diagnostics:warm TIFL—Failed 07/15/17 2. Slickline: Change out orifice gas lift valve 3. Downhole Diagnostics:TIFL 4. Well Integrity Engineer/Anchorage PE:Additional diagnostics as required A wellbore schematic and 90-day TIO plot are attached. Please reply if in conflict with proposed plan. Thanks, SCANNED AUG 1 02017 Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 1 o Regg, James B (DOA) Z�_"?�'`v� From: Regg, James B (DOA) q �� Sent: Thursday, April 07, 2016 9:34 AM To: AK, OPS FF Well Ops Comp Rep Cc: DOA AOGCC Prudhoe Bay Subject: RE: K-20 Notification and Authorization Attachments: PBU K-20 SVS ✓ Weather looks challenging through the weekend. OK to keep PBU K-20 (PTD 1950560) online until you have an opportunity to safely test. Inspector has already provided guidance to Pad Operator— attached. Notify AOGCC Inspector 24hrs in advance for witness opportunity. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 SCANNED SEP 2 12016 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Jim Regg at 907- 793-1236 or iim.regg@alaska.gov. From: AK, OPS FF Well Ops Comp Rep[mailto:AKOPSFFWel]OpsCompRep(d)bp.com] Sent: Thursday, April 07, 2016 6:03 AM To: Regg, James B (DOA) Cc: AK, OPS FF Well Ops Comp Rep Subject: K-20 Notification and Authorization Jim, K-20 was put on production on 4-2-16 and the request to witness was sent on 4-3-16 (to be tested in conjunction with D - Pad Wells). Due to blowing snow and limited Pad access Operations have not been able to perform the SVS test. We are approaching the 5 days of stabilized flow limit to test the SVS system and are planning on executing the test as soon as possible. This note is to notify AOGCC of the potential for delay and to seek Authorization to keep the Well online until safe access is obtained to perform the SVS system test. Have a good day. Vince Vince Pokryfki Field Well Compliance Advisor BP Exploration (Alaska) Inc. PBOC - B103 Office: (907) 659-5332 Pl'a4 1C—Zv Regg, James B (DOA) From: Grimaldi, Louis R (DOA) Sent: Thursday, April 07, 2016 5:58 AM \<,e To: owensmc@bp.com Cc: DOA AOGCC Prudhoe Bay Subject: PBU K-20 SVS Monty, In our phone discussion it appears that K-20 was brought on Saturday April 2"d. The blowing snow has had pad access restricted and you wish to test the SVS system today (fifth day). You may test the well at your earliest convenience. Please find out when the pad will be opened up and let me know when the snow removal equipment can make a pass through the pad. I am somewhat concerned that the operators may not have easy access to the wells for their regular surveillance. This wind is forecasted to last for the next week. Reply all please. Lou OPERABLE: Producer K -20C (PTD # 80490) Tubing integrity restored - Pas ' g MITIA Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelIIntegrityCoordinator @bp.com] 3/3/ i( Sent: Thursday, March 03, 2011 10:30 AM 'vfit To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: King, Whitney; Ramsay, Gavin; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer K -20C (PTD # 2080490) Tubing integrity restored - Passing MITIA Attachments: MIT PBU K -20C 03- 02- 11.xis All, / Producer K -20C (PTD # 2080490) passed an MITIA on 03/02/11 after dumm g_y as lift valves were set. The passing test verifies tubing integrity - has been restored. The well has been reclassified as Operable. Please be careful of thermal expansion when placing the well on production as the IA is fluid packed. An MIT form has been included for reference. «MIT PBU K -20C 03- 02- 11.xis» Thank you, i l MAC? a Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, February 25, 2011 8:44 PM To: AK, D &C Well Integrity Coordinator; 'Maunder, Thomas E (DOA)'; 'Regg, Jame B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 W- •ad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Oper. eons Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK ' S GPB East Wells Opt Engr Cc: Walker, Greg (D &C); Ramsay, Gavin Subject: NOT OPERABLE: Producer K -20C (PTD # 2080490) IA , essure stable N 900 psi, Further diagnostics to be completed when weather permits All, Producer K -20C (PTD # 2080490) failed a TIF •n 02/16/11. On 02/22/11, siickline was in the process of setting DGLVs to mitigate the communication. However, the work was unable to be completed safely due to high winds and low visibility causing th- lickline unit to rig down. The IA pressure has remained stable —900 psi since the TIFL; therefore, the ell will be reclassified as Not Operable until further intervention can be completed when weather per- its. A wellbore schematic and TIO • of have been included for reference. 3/3/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(rD.alaska.aov; doa .aogcc.prudhoe.bav(6alaska.gov; phoebe.brooksCcdalaska.aov; tom.maunder(rialaska.cov OPERATOR: BP Exploration (Alaska), Inc. FIELD 1 UNIT / PAD: Prudhoe Bay / PBU / K -Pad DATE: 03/02/11 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth _ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well K -20C Type Inj. N ' TVD 8,088' Tubing 1780 2200 2160 2100 Interval ID P.T.D. 2080490 Type test M Test psi 2022 Casing 1760 3000 i- 2840 2800 '' P/F P Notes: MITIA to verify tubing integrity OA 400 320 300 PrccL - ct .ue.Q — Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Ini. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) I Form 10 -426 (Revised 06/2010) MIT PBU K - 20C 03 02 11.xls NOT OPERABLE: Producer K -20C (P # 2080490) IA pressure stable - 900 i, Further diag... Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] Sent: Friday, February 25, 2011 8:44 PM J ` P l l Z �� To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: Walker, Greg (D &C); Ramsay, Gavin Subject: NOT OPERABLE: Producer K -20C (PTD # 2080490) IA pressure stable — 900 psi, Further diagnostics to be completed when weather permits Attachments: K- 20C.pdf; K -20 TIO Plot 02- 25- 11.doc All, Producer K -20C (PTD # 2080490) failed a TIFL on 02/16/11. On 02/22/11, slic kline was in the process of setting DGLVs to mitigate the communication. However, the work was unable to be complgted safely due to high winds and low visibility causing the slickline unit to rig down. The IA pressure has remained stable —900 psi since the TIFL; therefore, the well will be reclassified as Not Operable until further intervention can be completed when weather permits. A wellbore schematic and TIO plot have been included for reference. «K- 20C.pdf» «K -20 TIO Plot 02- 25- 11.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator MAR 0 2 2011 Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, January 28, 2011 10:36 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; , OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controll- Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C W' ine Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); R. ay, Gavin Subject: UNDER EVALUATION: Producer K -20C (PTD # 20:e 20:e'90) Sustained Casing Pressure on the IA - POP to perform TxIA diagnostics All, Producer K -20C (PTD # 2080490) was -ssified as Not Operable during the shut down due to sustained casing pressure. The wellhead press es were tubing /IA/OA equal to 2080/2080/0 psi on 01/14/2011. The well has been reclassified as Unth Evaluation so that it may be placed on production to perform diagnostics. Please be careful . ' en placing the well on production as the OA is fluid packed. 3/2/2011 PBU K -20C PTD 2080490 2/25/2011 TIO Pressures Plot Well: K -20 4.001 i • 3,000 —0— T bg —U— IA 2,000 —A— OAA �— 000A On L000 • I i -- - --.- _ 12/04/10 12/18/10 01/01/11 01/15/11 01/29/11 02/12/11 3 TREE = 4-1/16" CIVV • SAFETY Nfiltp: WELL ANGLE > 70 @ 9859' *** 4- WELLHEAD = FMC 112" CHRIPPLES *** ORIGINAL WELLBORE, ACTUATOR BAKER I( 1.20C K-20A & K-20B NOT SHOWN KB. ELEV = 52.13' ' • BF. ELEV' = 24.2' I kor).-= ' 4350 = 98° @ 12034' I I 2222' 1-14-112" HES X NIP (9-CR), ID = 3.813" Max Angle I Datum MD = NA GAS LIFT MANDRELS Datum TVD -; 8800 SS [ ST MD TVD DEV TYPE VLV LATCH PORT DATE 11 4 3265 3261 2 TMPDX DOME BK 16 03/18/10 3 5739 5599 38 TMPDX DOME BK 16 03/18/10 I 10-3/4" CSG, 45.5#, NT-80 OTC, ID = 9.950" I-1 3716' I-A 2 7633 7098 38 TMPDX DOME BK 16 03/18/10 1 8801 8027 38 TMPDX SO BK 20 02/10/11 Minimum ID = 1.995" @ 11528' 8868' H4-1/2" HES X NIP (9-CR), ID = 3.813" I 1 1 TOP OF 2-3/8" LNR 8878' H7-5/8" X 4-1/2" TAN HBBP-T PKR, ID = 3.912" I I 111 8903' H4-1/2" HES X NIP (9-CR), ID = 3.813" I 1 i I 8924' H4-1/2" HES XN NIP (9-CR), MILLED ID = 3.8" I 8936' H4-1/2" WLEG w /MULESHOE GUIDE ID = 3.958" 1 4-1/2" TBG,12.6#, L-80 BUTT, -1 8936' I H ELMO TT NOT LOGGED I IK .0152 bpf, ID= 3.958" 8936' 1-17-5/8" X 4-1/2" BKR ZXP PKR, ID = 5.50" I 1 g 8950' H 7 -5/8" X 4-1/2" BKR HMC HGR, ID = 4.875" I 7-5/8" CSG, 29.7#, NT-95HS --I 10212' NSCC, ID = 6.875" ,er., ! 4 9910' H4-1/2" KB LTP, ID = 2.37" I 4 4 * s * s * * s 9917' 1—[3.7" BKR DEPLOY SLV, ID = 3.00" , I S S .# . • ' lor, 9935' H3-1/2" HOWCO XN NIP, ID = 2.750" I C 1 1 9936' H 3-1/2" X 3-3/16" X0, ID = 2.786" I I 1 1 * 3-3/16" TOC LNR PER SCMT H 10304' r4 1$ • 4 4 A I L 11463' H2.70" BTT DEPLOYMENT SLV, ID = 2.250" I 13-3/16" WHIPSTOCK (06/04/08) ]-1 11477' N A 14 A 4 #t N 11528' H2-3/8" TOP OF PRE-DRILLED LNR, ID = 1.995" 4 [RA TAG (06/04/08) I 11482' P kb, i N N A N . MILLOUT WINDOW (K-20C) 11477' - 11484' 4-1/2" LNR, 12.6#, L-80 NSCT, -I 13108' A . 4 # N .0152 bpf, ID = 3.958" i ° N N PERFORATION SUMMARY II N N = REF LOG: MWD ON 06/06/08 KM N N ANGLE AT TOP PERF: 88° @ 11080' N N Note: Refer to Production DB for historical perf data N N SIZE SPF INTERVAL Opn/Sqz DATE N N. 2" 6 11080 - 11440 0 06/10/08 I PBTD 1 2" SLTD 11528 - 12662 SLOT 06/09/08 N ■■• Alm .0111' 2-3/8" PRE-DRILLED LNR, 4.6#, L-80 STL, -I 12696' 1 .0039 bpf, ID = 1.995" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/03/95 D-9 ORIGINAL COMPLETION WELL: K-20C 08/28/98 D-16 SIDETRACK (K-20A) PERMIT No: 2080490 12/09/02 JLM/KK CTD SIDETRACK (K-20B) API No: 50-029-22555-03-00 06/11/08 NORDICI CTD SIDETRACK (K-20C) SEC 4, T1 1N, R14E, 2028' FNL & 1210' FWL 09/23/10 SM/JMD DRLG DRAFT CORRECTIONS 02/11/11 WEC/PJC GLV C/O (02/10/11) BP Exploration (Alaska) UNDER EVALUATION: Producer K- (PTD # 2080490) Sustained Casing ssure on the I... Page 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] ' q ►�2�f // Sent: Friday, January 28, 2011 10:36 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Ramsay, Gavin Subject: UNDER EVALUATION: Producer K -20C (PTD # 2080490) Sustained Casing Pressure on the IA - POP to perform TxIA diagnostics All, Producer K -20C (PTD # 2080490) was classified as Not Operable during the shut down due to sustained casing pressure. The wellhead pressures were tubing /IA/OA equal to 2080/2080/0 psi on 01/14/2011. The well has been reclassified as Under Evaluation so that it may be placed on production to perform diagnostics. Please be careful when placing the well on production as the OA is fluid packed. The plan forward is as follows: 1. Operations: POP FEB (I 1 201i 2. DHD: TIFL 3. Well Integrity Engineer: Write work request to mitigate TxIA communication pending TIFL results - Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, January 18, 2011 1:40 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy (DOA)'• • oski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C W - • e Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 0 0, 'K, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS G - acility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS . - Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, • • Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL ° ', RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinate , ing, Whitney; Bommarito, Olivia 0; Ramsay, Gavin; Kirchner, Carolyn J; Holt, Ryan P (ASRC) Subject: Producers with s ' -ined casing pressure on IA and OA due to proration All, 1/28/2011 Producers with sustained casing pressurn IA and OA due to proration • Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] / f Sent: Tuesday, January 18, 2011 1:40 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Ops Lead; AK, OPS FS2 OSM; AK, OPS FS2 OSS; AK, RES GPB East Wells Opt Engr; AK, OPS GC3 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC1 OSM; AK, OPS Prod Controllers; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; AK, OPS GC2 Wellpad Lead; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSS; AK, OPS Well Pad DFT N2; AK, OPS GC1 Wellpad Lead; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Bommarito, Olivia 0; Ramsay, Gavin; Kirchner, Carolyn J; Holt, Ryan P (ASRC) Subject: Producers with sustained casing pressure on IA and OA due to proration All, The following producers were found to have sustained casing pressure on the IA during the proration January 15 -18. The immediate action is to perform a TIFL on each of the wells and evaluate for IA repressurization. If any of the wells fail the TIFL, a follow up email will be sent to the AOGCC for each individual well. 04 -24 (PTD #1853010) c/f -20C (PTD #2080490) Xit FEB 0 C 201 V -02 (PTD #2040770) Z -14B (PTD # 2060990) The following producer was found to have sustained casing pressure on the OA during the proration January 15 -18. The immediate action is to perform an OA repressurization test and evaluate if the IAxOA pressure is manageable by bleeds. If the IAxOA communication is unmanageable, a follow up email will be sent to the AOGCC notifying you of the remedial plan. Z -11A (PTD #2050310) All the wells listed above will be classified as Not Operable until start -up operations are complete and are stable or the well passes a pressure test proving integrity. After start -up, the wells will then be reclassified as Under Evaluation with POP parameters to prevent any over - pressure incidents. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/25/2011 DATA SUBMITTAL COMPLIANCE REPORT 2/2!2010 Permit to Drill 2080490 Well Name/No. PRUDHOE BAY UNIT K-20C Operator BP EXPLORATION (ALASKA INC API No. 50-029-22555-03-00 MD 12696 TVD 8755 Completion Date 6/11/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMAT~N Mud Log No Samples No Directional rvey Yes DATAINFORMATgN Types Electric or Other Logs Run: MWD DIR, GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ly a mevirrm[ rvumuer Name o~aie ~n~wa rvv a[ar[ atop a.n rcecervev wnnnGnw D D Asc Directional Survey 11995 12696 Open 6/30/2008 t Directional Survey 11995 12696 Open 6/30/2008 ' -t~pt ~~D Asc ~ Directional Survey 11469 12588 Open 6/30/2008 PB 1 Rpt Directional Survey 11469 12588 Open 6/30/2008 PB 1 pt L IS Verification 11028 12696 Open 11/7/2008 LIS Veri, GR, ROP C Lis / 17114 Gamma Ray 11028 12696 Open 11/7/2008 LIS Veri, GR, ROP pt LIS Verification 11028 12588 Open 11/7/2008 P61 LIS Veri, GR, ROP D C Lis 17115/Gamma Ray 11028 12588 Open 11/7!2008 PB1 LIS Veri, GR, ROP og Gamma Ray 2 Col 11475 12696 Open 11/7/2008 MD GR 9-Jun-2008 og Gamma Ray 2 Col 11475 12696 Open 11/7/2008 TVD GR 9-Jun-2008 CCog Gamma Ray 2 Col 11475 12588 Open 11/7/2008 MD GR 6-Jun-2008 1'v3( og Gamma Ray 2 Col 11475 12588 Open 11/7/2008 TVD GR 6-Jun-2008 /g i C Las 17281 ,amma Ray 11028 .12695 Open GR, ROP FIELD DATA ED C Las 17282/Gamma Ray 11028 12588 Open P61 GR, ROP FIELD DATA Well Cores/Samples Infonnation: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/2/2010 Permit to Drili 2080490 Well Name/No. PRUDHOE BAY UNIT K-20C Operator 8P EXPLORATION (ALASKIy INC API No. 50-029-22555-03-00 MD 12696 ND 8755 Completion Date 6/11/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMATION Well Cored? Y Daily History Received? Chips Received? ~ Formation Tops ~`/ N Analysis Received? Comments: Compliance Reviewed By: I~~ `~ Date: i NOT OPERABLE: K-20C (P1~2080490) TxIA Communication ~ Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ 3l ~% a~ Sent: Tuesday, February 17, 2009 9:49 AM ( l To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad EKG; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Randall, Jaclyn S Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer Subject: NOT OPERABLE: K-20C (PTD #2080490) TxIA Communication All, ,/ Well K-20C (PTD #2080490) has been secured with a tubing tail plug and reclassified as Not Operable. Work will continue to troubleshoot gas lift valves to restore In egrl Please let us know if you have any questions. Thank you, Anna 1~?u6e, ~.~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, February 06, 2009 8:31 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GP6, GCi OTL; GPB, GCl Wellpad Lead; GPB, Well Pad EKG; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Randall, Jaclyn S Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: K-20C (PTD #2080490) TxIA Communication All, Well K-20C (PTD #2080490) has been found to have sustained casing pressure on the IA. The TIOs were 2030/2030/30 psi on 02/04/09. The well failed a subsequent on 02/06/09. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Because the well does not have a permanent gas lift installed, there are no immediate plans to return the well to production. The plan forward for the well is as follows: 1. D: TIFL -FAILED 2. S: Set DGLVs 3. F: MITIA to 2500 psi A wellbore schematic and TIO plot have been included for reference. Please call with any questions or concerns. 3/9/2009 NOT OPERABLE: K-20C (P~#2080490) TxIA Communication ~ Page 2 of 2 Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 3/9/2009 UNDER EVALUATION: K-2~ (PTD #2080490) TxIA Communicate Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, February 06, 2009 8:31 PM Page 1 of 1 ~~~ ~1~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad EKG; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Wells Opt Eng; GPB, Optimization Engr; GPB, Prod Controllers; Randall, Jaclyn S Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: K-20C (PTD #2080490) TxIA Communication Attachments: K-20C.pdf; K-20C TIO Plot.doc All, s~~ Well K-20C (PTD #2080490) has been found to h ve sustained casinq pressure on the IA. The TIOs were 2030/2030/30 psi on 02/04/09. The well failed a ubsequent on 02/06/09. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Because the well does not have a permanent gas lift installed, there are no immediate plans to return the well to production. The plan forward for the well is as follows: 1. D: TIFL -FAILED 2. S: Set DGLVs 3. F: MITIA to 2500 psi A wellbore schematic and TIO plot have been included for reference. «K-20C.pdf» «K-20C TIO Plot.doc» ~- Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 2/ 12/2009 PBU K-20C PTD 208-049 2/6/2009 g 4,J00 ~# t 3;.~aa z,aaa 1:a0rJ t 7 zliFlQd -iF-- Tbg --~- ~ --~ OA - OOA - ~ - OOOA -~- On 12t11a3 ~2f2a103 t~,zilCG; a~l03lG8 01l~afa9 a11171a9 a112dta9 - at~lla3 TIO Plot TREE = 4-1 f 16" CNV WELLHEAD = FMC ACTUATOR= BAKER _...,,- ~.~ KB. ELEV = .,a. 52.13' BF. ELEV..- _ 24.2' KOP = 4350' _ ,_ Da#um MD = -..T NA DatumTVD=~ 8800'SS ~ 10-314" CSG, 45.5#, NT-80 BTC, ID = 9.950" ~ ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3265 3261 2 TMPDX DOME BK 16 08/01/08 3 5739 5599 38 TMPDX DOME BK 16 08/01!08 2 7633 7098 38 TMPDX DOME BK 16 08101!08 1 8801 8027 38 TMPDX DMY BK 20 08/01(08 6C~11'i~1.6911 ~ = '~ .~"~ '~ R $$s$" -j 4-1/2" HES X NIP, ID = 3.813" `"{"~ ~" °°°°°°---- 8$78' 7-518" X 4-1(2" TMJ HBBP-T PKR ID = 3.912„ 8903' ~-r 4-112" HES X NIP, ID = 3.813" ~ BKR TIEBACK SLEEVE. ID =? I 4-112" TBG,12.6#, L-80 BUTT, .0152 bpf; ID = 3.958" 7-518'" CSG, 29.7#, NT-95HS NSCC, ID = 6.875" ~` ~C~ $92~-~ 4-1i2" HES X NIP, MILLED ID = 3.8" i $936' 4-112" WLEG w tMULESHOE GUIDE, ID = 3.958" ELMD TT NOT LOGGED 8936' 7-518" X 4-112" BKR ZXP PKR, ID = 5.50" $g5{3' 7-5/8" X 4-112" BKR HMC HGR; ID = 4.875" '~ - j 4-1l2'< KB LNR TOP PF,t;KER, iD = 2.36" 9917' 3.7" BKR DEPLOY SLV, ED = 3.0" 9935' 3-112" HOWCO XN NIP, ID = 2.750"' 993$" 3-112" X 3-3/16" XO; ID = 2.786" I TOC 3 3116" LINER PER SCMT I 11462' ?_ 313'' ~P OF SOLID LiNER~ {1jt 1147T TOP t16°'AJH2e ~ ~~OCK RA T<ac~ ;~ 11, "n... 4-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf. ID = 3.958" 131 Q$' ~ ~ {~~ R~ LOG: tti4`JJD ON i ~C~ A NGLE AT TOP PERP: 88 ~c7~ 11040` ~ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 2" 6 11080 - .I 1440 O 0611 Ct!C"i8 PRE DRILLED LN#Z ? 1527 - 12662 (:} OG'0°108 2-7/8" LNR, 6.16#, L-80 STL, .0058 bpf, iD=2.441" 11 a28° 2 318" TOP OF Pre-[>riile~ti i...INL R `, 3-3(16" LNR, 6.2#, L-80, 11568' ~ ` ~ TCiI, .0076 bpf, ID = 2.80" 12562' ..i..D -~C 2-3r8" Pre-Driiied LNR, 4.711, L-80 STL, iD=1.995" 12696 -~ DATE REV BY COMMENTS DATE REV BY COMMENTS 06f03f95 D-9 ORIGINAL COMPLETION 06(25108 KDCaSV GLV CIO (06116108} 08128498 D-16 SIDETRACK {K-20A} 09/01/08 TLH/PJC SLTD LNR CORRECTION 12t09t02 JLMtKK CTD SIDETRACK (K-20B} 09/01J08 KSBtPJC GLV GO {O8/01108) 06111!08 NORDICI CTD SIDETRACK (K-20B} 06r12r08 rTLH CORRECTONS 06114/08 1TLH CORRECTIONS PRUDHOE BAY UNIT WELL: K-20B PERMIT No: 2022240 API No: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL & 4070' WEL BP Exploration (Alaska} _ _ _ .. SA~ NOTES: -~_ r 2222' S-{4-1/2" HES X NIP, ID = 3.813" GA5 LIFT MANDRELS OPERABLE: K-20C (PTD #2080490) Confirmed tubing integrity Page 1~ Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, November 22, 2008 9:42 AM ~~~ I(I~4 ~Ze~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad EKG; GPB, Wells Opt Eng; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Prod Controllers; Randall, Jaclyn S; GPB, Optimization Engr; GPB, Well Pad EKG Cc: Holt, Ryan P (ASRC); Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: K-20G (PTD #2080490) Confirmed tubing integrity All, Well K-20C (PTD #2080490) passed a TIFL an 11!19108 after poping the well confirming tubing integrity. The well has been reclassified as Operable. Please let us know if you have any questions. Thank you, Anna NSU, ADW Well Integrity Engineer Sent: onday, November 10, 2008 4:08 PM To: 'Regg, mes B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GCl Wellpad Lead; GPB, Well Pad EKG; GPB, Wells Opt E • Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Prod Controllers; Randall, Jaclyn S; GPB, Optimization Engr Ce: NSU, ADW Well Integrity meer; Winslow, Jack L. Subject: UNDER EVALUATION: K- C (PTD #2080490) for Sustained Casing Pressure All, Well K-20C (PTD #2080490) has been found to ve sustained casing pressure on the IA. The TIOs were 2030/2020/20 psi on 11/08/08 when a TIFL failed; confirming Txl ommunication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. WOE: POP Well 3. DHD: Re-TIFL 4. SL: If TIFL fails, change out gas lift valves 5. DHD: Re-TIFL A TIO plot and wellbore schematic have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator 11 /24/2008 ®i~.® BAKER NVGNES Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY 1rXYLUKA110N (ALASKA)1NC COUNTY NUK'I'H 5LUYE BOKUUGH WELL NAME K-20C, & K-20CPB1 STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 10/16/2008 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 2011705 Copies of Copies Digital Copies of Copies Digital Each Log 2 of Film Data Company BP EXPLORATION (ALASKA) INC Each Log 1 of Film Da[a Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE. AK 99508 ANCHORAGE. AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE. AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv' BAKER ATLAS-PDC 17015 Aldine Westfield. Houston. Texas 77073 This Distribution List Completed Bv: / , ~- i~({ ~~ Page 1 of 1 UNDER EVALUATION: K-20C (PTD #2080490) for Sustained Casing Pr~ure Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~~~ 1lIIO IZ~~ Sent: Monday, November 10, 2008 4:08 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad EKG; GPB, Wells Opt Eng; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Prod Controllers; Randall, Jaclyn S; GPB, Optimization Engr Cc: NSU, ADW Well Integrity Engineer; Winslow, Jack L. Subject: UNDER EVALUATION: K-20C (PTD #2080490) for Sustained Casing Pressure Attachments: K-20C TIO Plot.doc; K-20C.pdf All, Well K-20C (PTD #2080490) has been found to have sustained casing pressure on the IA. The TIOs were 2030/2020/20 psi on 11/08/08 when a TIF_ L failed; confirming TxIA communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. -- The plan forward for the well is as follows: 1. DHD: TIFL -FAILED 2. WOE: POP Well 3. DHD: Re-TIFL 4. SL: If TIFL fails, change out gas lift valves / 5. DHD: Re-TIFL A TIO plot and wellbore schematic have been included for reference. «K-20C TIO Plot.doc» «K-20C.pdf» Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 I l /10/2008 PBU K-20C TIO Plot TREE = 4-1/16" CMJ WELLHEAD = FMC ACTUATOR= BAKER KB. ELEV = 52.13' BF. ELEV = __.. 24.2' KOP = 4350' ~ Mu,~ ; ~ = ....,.~-..,~sw 98 L 12033' Datum MD = NA Datum TV D =-- _ ~~~ 8800' SS ~ 10-314" CSG, 45.5#, NT-80 BTC, 1D = 9.950'° 0 BKR TIEBACK SLEEVE, ID =? 4-112" TBG,12.6#, L-80 BUTT, .0152 bpf, ID = 3.958" 7-518" CSG, 29.7#, NT-95HS I NSCC, iD = 6.875" `!' ~ t 0~, ,_ --.. ,-r SAF~IOTES: 2222' I~ 4-112" HES X NIP, ID = 3.813" GA5 LIEF MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3265 3261 2 TMPDX DOME BK 16 08/01/08 3 5739 5599 38 TMPDX DOME BK 16 08/01/08 2 7633 7098 38 TMPDX DOME BK 16 08/01/08 1 8801 8027 38 TMPDX DMY BK 20 08/01/08 $$6$' 4-1/2" HES X NIP, ID = 3.813" 8878° 7-5/8" X 4-1/2" TIUV HBBP-T PKR, ID = 3.912" 890- 4-1l2" HES X NIP, ID = 3.813" 8924' 4-1/2" HES X NIP. MILLED ID = 3.8" 8936' 4-1/2" WLEG wIMULESHOE GUIDE, ID = 3.958" ELMD TT NOT LOGGED $936' 7-518" X 4-1)2" BKR ZXP PKR, ID = 5.50" 8950' 7-518" X 4-112" BKR HMC HGR; ID = 4.875°' .~ 9910' I- -j=1-1%2" KB LNR TOP PACKER. iD = 2.36„ 9917° 3.7" BKR DEPLOY SLV, ID = 3.0°' 9935' 3-1/2" HOWCO XN NIP, ID = 2.750"" 9936' 3-112" X 3-3116" XO, ID = 2.786" TOC 3 311 Ei" LINER PER SCMT ~-{ 1{1304` 1142' 2 31~" _I~OP ~!~~sOLID LIN~~, {1jt €ap;r 1 "~ 477' TOP :; 3; OC;K F_ . T 11 ~.„i 4-112" LNR, 12.6#, L-80 NSCT, ~ .0152 bpf, ID = 3.958" 13108' ~ -~ ~.., "°` Ail ,L; AT TOP PE1iR. f?t3 11C'i/I+i' ^~ Note: Refer to Production DB far historical per! data SIZE SPF INTERVAL OpniSgz DATE 2" 6 1100- O 06r1C"'v8 PREDRiLL~LNR 115,~I- 2 ! ~~ O(-')9'08 2-718" LNR, 6.16#, L-80 STL, 13004' .0058 bpf, ID = 2.441" 11 2$, 2 3i8" ~'I~OP OF I-~e-1:3rilleJ ~[____~ LINER _.+ 3-3!16" LNR, 6.2#, L-80, 1156$° " ~ TCiI; .0076 bpf, ID = 2.80" 162° PBT"D -~ 'r 8" P-e-Drilled i._NR, 4.7zx, L-80 STL, ID=1.:395" 12596' DATE REV BY COMMENTS DATE REV BY COMMENTS 06103!95 D-9 ORIGINAL GOM PLETION 06125;08 KDC,'SV GLV C!O (O6?16.'08} 08!28198 D-16 SIDETRACK {K-20A} 09/01!08 TLHlPJC SLTD LNR CORRECTION 12109!02 JLMIKK CTD SIDETRACK (K-20B} 09/01!08 KSBlPJC GLV C%O {08101!08) 06!11108 NORDIG1 GTD SIDETRAGK {K-20B} O6i12108 rTLH CORRECTIONS 06r'14(08 1TLH CORRECTKNS PRUDHOE BAY UNIT WELL: K-206 PERMfF No: 2022240 API No: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL & 4070' WEL BP Exploration {Alaska} INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: K-20C & K-20CPB1 `~ Contains the following: ~~ ~:~ 1 LDWG Compact Disc ;~ (Includes Graphic Image files) 1 LDWG lister summary ~~ j 1 color print - GR Directional Measured Depth Log (to follow) ~ 1 color print - GR Directional TVD Log (to follow) ~~ ~(s( ,.p 3 ~~ / ~ns~ '~ LAC Job#: 2011705 f a Guidry Sent by: Catrin Date: 10/16/08 ~ Received by: f Date: „- - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive ~~~ Anchorage, Alaska 99518 Direct: (907) 267-6612 [NTEQ FAX: (907) 267-6623 ~~~ BAKlR iN/6NES 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: June 26, 2008 Please find enclosed directional survey data for the following wells: K 04CPB1 K 04CPB2 K 04C G15B K-20CPB1/ K-20C-~ 15-18A Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ,State of Alaska AOGCC DATE: ~ ~ ~,~,~ }~$ Cc: State of Alaska, AOGCC STATE OF ALASKA ~~6 U~ ALASKA OIL AND GAS CONSERVATION COMMISSION .!UN 3 0 2008 WELL COMPLETION OR RECOMPLETION REPORT AND ~~~q~ ~,~ ~,~~ ~,~~~ ~~~~~~~~~~ t'1 !^S P^'~a t4~ wren 1 a. Well Status: ®~Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development` ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration {Alaska) Inc. 5. Date Comp., Susp., or Ab 6/11/2008 ~ ~ 12. Permit to Drill Number 208-049 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/4/2008 ~ 13. API Number 50-029-22555-03-00 " 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/9/2008- 14. Well Name and Number: PBU K-20C ; 3251 FSL, 4070 FEL, SEC. 04, T11 N, R14E, UM Top of Productive Horizon: 331' FNL, 4631' FEL, SEC. 09, T11 N, R14E, UM 8. KB (ft above MSL): 52.13 ~ Ground (ft MSL): 24.2' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 1569' FNL, 3034' FEL, SEC. 09, T11 N, R14E, UM 9. Plug Back Depth (MD+TVD) 12696' 8755' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 671480 y- 5975192 Zone- ASP4 10. Total Depth (MD+TVD) 12696' 8755' 16. Property Designation: ADL 028303' TPI: x- 671011 y- 5971598 Zone- ASP4 Total Depth: x- 672639 y- 5970398 Zone- ASP4 11. SSSV Depth (MD+IVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed "nformation per 20 C 25.071): MWD DIR, GR ~/i1~dOi/~ I~"~~S/~d ~~~f 6 ~TYd 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' urface 110' 30" 260 sx Arctic Set A rox. 10-3/4" 45.5# NT-80 35' 3716' 35' 3712' 13-1/2" 1045 sx PF'E' 735 sx Class'G' 7-5/8" 29.7# L-80 32' 9098' 32' 8259' 9-7/8" 264 sx Class 'G' 4-112" 12.6# L-80 8936' 7 ' 8133' 8790' 6" 460 sx Class 'G' 2-3/8" 4.6# L-80 11463' 12696' 8790' 8755' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rtoration Size and Number): S¢E DEPTH SET MD PACKER SET MD 2-3/8" Slotted Section 2" Gun Diameter 6 spf 4-1/2", 12.6#, L-80 8936' 8878' , MD TVD MD TVD 11528' - 12662' 8792' - 8756' 11080' - 11440' 8779' - 8790' 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect with McOH 26. PRODUCTION TEST Date First Production: June 19, 2008 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date Of Test: 6/27/2008 HOUrS Tested: $ PRODUCTION FOR TEST PERIOD OIL-BBL: 271 GAS-MCF: 522 WATER-BBL: 12 CHOKE SIZE: 96 GAS-OIL RATIO: 1,923 Flow Tubing Press. 200 CaSing PfeSS: 1,900 CALCULATED 24-HOUR RATE• OIL-BBL: 814 GAS-MCF: 1,566 WATER-BBL: 36 OIL GRAVITV-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. CJ£~,~Ll~Tf01i None ~ ~ ~~~ ,i Form 10-407 Revised 02/200 ~ ~ ~ ~ ~ (~ ~ ~ + CONTINUED ON REVERSE SIDE S 6dF~ JUL Lr .G, 2QOB ~~'t~ ~' ~.. f v L D 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS RKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. TDF /Zone 1A 10283' 8762' None (From parent wellbore) Formation at Total Depth (Name): TDF /Zone 1 A 10283' 8762' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~ ??~~ ~~.)lJ Signed Terrie Hubble Title Drilling Technologist Date ~~ PBU K-20C 208-049 Prepared By Name/fVumber. Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: John McMullen, 564-4711 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End:. 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ~ Hours Task Code NPT Phase Description of Operations 6/1/2008 03:00 - 04:00 1.00 MOB P PRE Prep for rig move 04:00 - 07:00 3.00 MOB P PRE PJSM on rig move operations, Turnkey Rig move from G-15 to K-Pad 07:00 - 10:00 3.00 MOB P PRE Spot rig mats and layout herculite liner at well, PJSM on backing over well, move in and spot rig over well Accept rig at 10:OOHrs on 6/1/08 10:00 - 13:00 3.00 BOPSU P PRE NU BOP's, changing out gripper blocks in injector for 2" coil. 13:00 - 15:00 2.00 BOPSU P PRE Adjust accumulator pressure switch 15:00 - 22:30 7.50 BOPSU P PRE Perform accumulator draw down test, Testing BOP's, Upper Combi failed, changed out upper 2" combi and 2 3/8" combi, continued with BOP test of all rams, valves and lines to 250 -3500 psi, annular to 250 - 2500psi, 5 minutes per test, as per AOGCC and BP regulations Jeff Jones with AOGCC waived witnessing BOP test. Send BOP Test report to AOGCC. 22:30 - 22:45 0.25 BOPSU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for R/U BPV lubricator and pulling BPV. 22:45 - 23:45 1.00 BOPSU P PRE Pull BPV. Well on slight vacuum. 23:45 - 00:00 0.25 RIGU P PRE Rig up injector head to pull coil stub from reel to injector. 6/2/2008 00:00 - 01:00 1.00 RIGU P PRE R/U internal grapple and tugger to pull coil across. 01:00 - 01:15 0.25 RIGU P PRE SAFETY MEETING discussing hazards, mitigations, and job assignments to pull CT to injector. 01:15 - 04:30 3.25 RIGU P PRE Pull test internal grapple. Remove crossbar on reel. Pull coil across to injector. Coil became stuck in injector, back out and pull through again. 04:30 - 05:00 0.50 RIGU P PRE Change out CT injector packoff to 2". 05:00 - 06:45 1.75 RIGU N SFAL PRE Replaced the hydraulic pump for the CT packoff in operations cab. 06:45 - 07:30 0.75 RIGU P PRE Stabbed through packoff and took out a chunk of the seal. Install new CT injector packoff and reboot a-line. 07:30 - 09:00 1.50 RIGU P PRE CT a-line slack management, boot a-line, reverse circ with 50 bbls of 2% double slick KCL, 25bbls of FW, cut 50' of CT and 5' of a-line cable, test cable, ok 09:00 - 11:30 2.50 EVAL P WEXIT MU Kindall CTC, Pull test to 35k. MU UOC. PT UOC to 4000psi, Test and chart inner reel valve 250-4000psi, 11:30 - 12:00 0.50 EVAL P WEXIT MU Baker Seal Assy BHA #1 with seal assy, locator, X-O's, 2 Jts of 2 3/8" PH6, X-O's, blind sub, DPS, EDC, powercomms, wear sub, LQC 12:00 - 14:25 2.42 EVAL P WEXIT RIH with Baker Seal Assy BHA #1, 1.43bpm, 1121 psi, Up wt 40.7k at 9800', Dn wt at 19.5k Tagged and stung in deployment sleeve at 9920' CTD, pump pressure started to increase when seals were engaged, shut down pump, open Baker choke, stacked 10k down 2 RA Tags installed in Whipstock 5.35' below TOWS 14:25 - 14:40 0.25 EVAL P WEXIT Pressure test cement retainer down CT to 2000psi, monitor for 10 mins, lost 50psi in 5 min, held tight next 5 mins, good test, bled pressure off to 0 psi 14:40 - 16:00 1.33 EVAL P WEXIT POH to BHA #1, std bk inj 16:00 - 16:35 0.58 EVAL P WEXIT POH with BHA #1, LD coil trak tools and Baker seal assy 16:35 - 17:35 1.00 EVAL P WEXIT Adjust and center Traveling Block over well while installing and rnntea: asoaw° a:°rva rim ~ ~ BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ~ Code NPT Phase Description of Operations 6/2/2008 16:35 - 17:35 1.00 EVAL P WEXIT 17:35 - 17:45 0.17 WHIP P WEXIT 17:45 - 18:00 0.25 WHIP P WEXIT 18:00 - 18:15 0.25 WHIP P WEXIT 18:15-21:10 I 2.921WHIP IP I IWEXIT 21:10-22:10 1.OOWHIP IP IWEXIT 22:10 - 22:30 0.331 WHIP P IWEXIT 22:30 - 23:00 0.50 WHIP P WEXIT 23:00 - 00:00 1.00 WHIP P WEXIT 6/3/2008 00:00 - 01:30 1.50 WHIP P WEXIT 01:30 - 01:45 0.25 WHIP P WEXIT 01:45 - 02:30 0.75 WHIP P WEXIT 02:30 - 03:40 1.171 STWHIP P 03:40 - 06:00 2.331 STWHIP P WEXIT WEXIT X~ 06:00 - 08:00 2.00 STWHIP P WEXIT ~~, 08:00 - 09:00 1.00 STWHIP P WEXIT 09:00 - 10:00 1.00 STWHIP P WEXIT 10:00 - 11:00 1.00 STWHIP P WEXIT 11:00 - 13:30 2.50 STWHIP P WEXIT 13:30 - 15:30 2.00 STWHIP P WEXIT 15:30 - 21:00 5.50 STWHIP P WEXIT surface test DGS and HOT tools MU 3 3/16" monobore WS BHA #2 with coil trak tools, found two lines on DGS tool, questioned scribe line used LD and confirmed correct scribe line used MU 3 3/16" monobore WS BHA #2 with coil trak tools, CTC, stab Injector RIH with BHA #2 with BTT 3-3/16" Gen II Whipstock on CoilTrak. BHA OAL = 66.68'. Circ at 0.25 bpm, 70 psi thru open EDC. Log down with GR from 11,056' at 100 fph to tie-in with mother well bore. correct -16' CTD. RIH and positioned top of BTT 3-3/16" Gen II Monobore whipstock top at 11,475'. Tray set at lowside tool face 180 deg ROHS. Closed EDC. Pressure up and Setting tool sheared at 3600 psi. Stacked 2K down on whipstock. It is in place. Pick up clean off top of whipstock. Circ well to 2# Biozan / 2% KCL water. 2.0 bpm, 2400 psi. POH with CoilTrak and BTT running tools while Circ. 2.0 bpm, 2800 psi. POH to surface. SAFETY MEETING discussing hazards, mitigations, and procedures to UD whipstock BHA. UD Whipstock setting BHA#2. Found part of Whipstock deployment key was left in hole, metal 2" by 3/4" bar broke off while setting whipstock. It should wedge between the tray on the highside of the hole and the 3-3/16" liner. PU window milling BHA #3 with 2.74" HCC window and string mill, 2-1/8" BOT Xtreme motor, 2 jts 2-1/16" CSH and CoilTrak tools. BHA OAL = 99.81' RIH with BHA #3. Circ at 0.3 bpm, 1100 psi. RIH the last 500' with no pump to push key below whipstock to wedge it into place while milling. Stop pump and dry tag top of whipstock at 11,496', correct depth -21' CTD to 11475'. ~~ Mill 2.74" Lowside Dual exit window from 11475 to 11475.6', ~ 1.5 bpm, 2942psi, 2842psi free spin, 400# WOB Mill window from 11475.6 to 11476', 1.49/1.49 bpm, 2975psi, 1.Ok WOB Mill window from 11476 to 11476.3', 1.49/1.49 bpm, 3054psi, 1.28k WOB Mill window from 11476.3 to 11476.7', 1.49/1.49 bpm, 3000psi, 1.4 - 2k WOB Mill window from 11476.7 to 11478', 1.48/1.48 bpm, 2944psi, 2k WOB Mill window, 1.5 bpm, 2990 psi, 2.6 k WOB, 0.5 fph, Milled to 11479'. Mill window, 1.5 bpm, 3000 psi, 2.7 k WOB, 0.5 fph, Milled to Nnntea: riisuizuus a:~t:aa Hnn BP EXPLORATION Operations Summary Report Page 3 of 10 ~ Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours II Task Code NPT I, Phase Description of Operations 6/3/2008 15:30 - 21:00 5.50 STWHIP P WEXIT 11480'. 19:00 - 11,480.5 ft, 2950 psi ~ 1.47 / 1.47 bpm, 2.9 Klbs DWOB, 9 Klbs CT weight. Stall at 11,480.9 ft, Up weight 31 Klbs Clean pickup. Work back down slowly. 20:00 - 11,480.7 ft, 3250 psi ~ 1.62 / 1/62 bpm, 2.7 Klbs DWOB, 12.2 Klbs CT weight. Stall at 11,481.0 ft, clean pickup 31 Klbs. 21:00 - 11,480.5 ft, 3160 psi ~ 1.61 / 1.60 bpm, 1.1 Klbs DWOB, 13 Klbs CT weight. 21:00 - 21:40 0.67 STWHIP P WEXIT 700 psi motor work and drill off at 11,480.6 ft. Drill at 3 ft/hr, 0.2 Klbs DWOB, 3000 psi ~ 1.60 / 1.60 bpm. 21:40 - 00:00 2.33 STWHIP P WEXIT Drill rathole from 11,482 ft to 11,492 ft at 10 - 15 fUhr. Sample from 11,485 ft is 85% formation. Pull back through window at 0.3 ft/min, 50 - 100 psi motor work seen. Ream to TD at 1 ft/min, nothing seen. 6/4/2008 00:00 - 01:10 1.17 STWHIP P WEXIT Conduct 2nd and 3rd up/down pass through window, little motor work seen. 01:10 - 03:30 2.33 STWHIP P WEXIT Shut down pump, dry pass through window is clean. Swap well to Flo-Pro while POOH. 03:30 - 03:45 0.25 STWHIP P WEXIT SAFETY MEETING. Discuss crew positions and hazards for laying down milling BHA, and for levelling rig. 03:45 - 04:15 0.50 STWHIP P WEXIT Tag stripper, lay down window mill. DSM is 2.72" no-go, String reamer 2.73" no-go. 04:15 - 05:15 1.00 DRILL N MISC PROD1 Unchain BOP stack, pull containment tub and level rig. SLB inspect injector chains. 05:15 - 06:00 0.75 DRILL P PROD1 P/U BHA - 3" bicenter bit, 2-3/8" Xtreme with 1.2 deg AKO + 2-3/8" CoilTrack BHA. 06:00 - 07:50 1.83 DRILL P PROD1 RIH with CoilTrak Build BHA #4 with 1.2 deg motor and HCC re-build BC Bit #1. 07:50 - 10:00 2.17 DRILL P PROD1 Log GRtie-in with original hole. -19' CTD correction. 10:00 - 12:15 2.25 DRILL P PROD1 Drill Zone 1A turn section, 1.5 bpm, 3000-3400 psi, 90L TF, 1-2K WOB, 9.6 ecd, 90 fph, RA tag came in at 11,482', so top of whipstock and window at 11,477'. Drilled to 11,650'. 12:15 - 12:30 0.25 DRILL P PRODi Wiper trip to window. Clean hole. RIH clean to bottom. 12:30 - 14:50 2.33 DRILL P PROD1 Drill Zone 1A turn section, 1.5 bpm, 3000-3400 psi, 110E TF, 1-2K WOB, 9.7 ecd, 70 fph, Drilled to 11,770'. 14:50 - 15:00 0.17 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 15:00 - 17:40 2.67 DRILL P PROD1 Drill Zone 1A turn section, 1.6 bpm, 3100-3400 psi, 90L TF, 1-2K WOB, 9.7 ecd, 70-170 fph, Drilled to 11,950'. 17:40 - 17:50 0.17 DRILL P PRODi Wiper trip to window. Clean hole. 17:50 - 18:05 0.25 DRILL P PROD1 Log GR tie-in at RA tag. Added 2' CTD. 18:05 - 18:20 0.25 DRILL P PROD1 RIH clean to bottom. 18:20 - 19:50 1.50 DRILL P PROD1 Drill from 11,950 ft. Stacking weight from 12,040 ft - 12,060 ft, drilling at 120 - 160 ft/hr after this. Drill to 12,100 ft. 19:50 - 20:20 0.50 DRILL P PROD1 Wiper trip from 12,100 ft to window. Pickup is 40 Klbs off bottom. 20:20 - 21:30 1.17 DRILL P PROD1 Drill from 12,100 ft at 1.40 / 1.38 bpm, 300 - 600 psi motor Printed: 6/30/2008 9:31:49 AM BP EXPLORATION Operations Summary Report Legal Well Name: K-20 Page 4 of 10 ~ Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase '~ Description of Operations 6/4/2008 20:20 - 21:30 1.17 DRILL P PROD1 work, 120 - 150 ft/hr with 1 - 3 Klbs DWOB. Stacking weight after 12,170 ft, bring inclination down to 90 deg to get back in sand. Drill to 12,180 ft, directional objectives have been met with build assembly. 21:30 - 00:00 2.50 DRILL P PRODi POOH. Pull through window and open EDC. 6/5/2008 00:00 - 00:15 0.25 DRILL P PROD1 SAFETY MEETING. Discuss procedures and hazards for change out drilling BHA. 00:15 - 01:15 1.00 DRILL P PROD1 Tag stripper. Stand back injector and UD BHA #4. Change out DGS, adjust AKO for next motor to 1.0 deg. Re-string winch cable on rig floor. 01:15 - 02:00 0.75 DRILL P PROD1 Pick u BHA #5 -Lateral drillin assembl 3" Hycalor STR bi-center bit + 2-3/8" Xtreme motor with 1.0 deg AKO + 2-3/8" CoilTrack. BHA OAL = 58.18'. 02:00 - 05:10 3.17 DRILL P PROD1 RIH. Log tie in from 11,490 ft down at 100 ft/hr. Correct -18 ft, continue RIH. 05:10 - 06:30 1.33 DRILL P PROD1 Drill from 12,180 ft at 1.47 / 1.47 bpm, 200 - 400 psi motor work. DWOB 2 - 3 Klbs with CT weight < 0. Initial ROPs 40 - 60 ft/hr. Maintain 90 - 91 deg Inc to get back into sand. Drilled to 12240'. 06:30 - 09:00 2.50 DRILL P PROD1 Drill Z1A Lat, 1.6 bpm, 3000-3500 psi, 2-3K wob. Slow ROP in shale. Stacking wt. Drilled to 12,332'. 09:00 - 10:00 1.00 DRILL P PROD1 Wiper trip to window. RIH clean to bottom. 10:00 - 11:00 1.00 DRILL P PROD1 Drill Z1A lat, drilling shale, 1.6 bpm, 3000-3500 psi, 9.7 ecd, Stacking wt, slow rop, Drilled to 12340'. 11:00 - 11:30 0.50 DRILL P PROD1 Wiper trip. Clean hole. 11:30 - 11:50 0.33 DRILL P PROD1 Rig evacuation drill, all personnel responded to muster area. 4 extra personnel accounted for with sign in sheet. 11:50 - 13:30 1.67 DRILL P PROD1 Wiper trip while swapping to new FloPro. 13:30 - 16:00 2.50 DRILL P PROD1 Drill Z1A lat, 1.6 bpm, 3000-3500 psi, 40L TF, 9.6 ecd, Stacking wt, not sliding, slow rop, Drilled to 12373'. 16:00 - 16:40 0.67 DRILL P PROD1 Wiper trip to window. RIH clean to bottom. 16:40 - 17:30 0.83 DRILL P PROD1 Drill Z1A lat, 1.6 bpm, 3000-3500 psi, 100E TF, 9.5 ecd, Stacking wt, Wt transfer is poor, Drilled to 12,428'. 17:30 - 20:10 2.67 DRILL P PROD1 POH for Agitator. Clean trip to window. Open EDC above window and circ at 2.0 BPM to surface. 20:10 - 20:25 0.25 DRILL P PROD1 SAFETY MEETING. Discuss hazards and procedures for changing BHA. 20:25 - 21:50 1.42 DRILL P PRODi Tag stripper, stand back injector. Change out bit, add agitator and dart style checks. Remove flapper check valves from UOC. 21:50 - 00:00 2.17 DRILL P PROD1 RIH with BHA #6 - 3.0 HCC bicenter bit, 2-3/8" Xtreme motor with 1.0 deg AKO, 2-1/8" Agitator, BHI weight bar, dart style tandem check valves, 2-3/8" CoilTrack with flapper check valves removed. Pump 2 bpm through open EDC after 5,000 ft. 6/6/2008 00:00 - 00:30 0.50 DRILL P PROD1 Log GR down from 11,490 ft at 100 ft/hr for depth tie-in. Correct -19 ft. Close EDC. 00:30 - 01:00 0.50 DRILL P PROD1 RIH to find bottom. Nnntea: tii'suieuuu a:si:aa Hnn ~ ~ BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To I', Hours I Task Code' NPT Phase Description of Operations 6/6/2008 01:00 - 02:55 1.92 DRILL P PROD1 Ta bottom at 12 422 ft and drill at 1.42 / 1.37 bpm, 100 - 500 psi motor work. Initial ROP is 50 - 80 ff/hr with 1 - 2 Klbs DWOB and 12 Klbs CT weight. Reduce inclination from 93 deg to 90 as per Geo. Stacking weight periodically. Drill to 12,550 ft. Inclination dropping < 85 deg despite high side toolface. 02:55 - 04:10 1.25 DRILL P PROD1 Wiper trip from 12,550 ft to window, clean pass up and down. 04:10 - 04:30 0.33 DRILL P PROD1 Drill from 12,550 ft to 12,588 ft, stack more weight to try and get better directional control. Not able to build angle even with HS toolface, POOH for AKO change. 04:30 - 07:00 2.50 DRILL N DPRB PROD1 POOH. Pull through window and open EDC, pump 2 bpm on the way out. 07:00 - 07:15 0.25 DRILL N DPRB PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing BHA. 07:15 - 08:45 1.50 DRILL N DPRB PROD1 Adjust motor to 1.5 deg, Check Bit, still new condition, Press test CTC, OK. M/U CoilTrak L t #7 with HCC BC Bit #4, 1.5 deg Xtreme Motor, Agitator and CoilTrak tools. BHA OAL = 70.66'. 08:45 - 09:00 0.25 DRILL N WAIT PROD1 Wait on orders. Anc. Geo considering open hole sidetrack to et more a sand. Plan forward is to run BTT AL Billet and openhole anchor, set top of billet at 12,010' for highside kickoff. 09:00 - 09:30 0.50 STKOH C PROD1 Lay out drilling BHA. 09:30 - 11:30 2.00 STKOH X WAIT PROD1 Wait for BTT open hole Anchor and Billet to arrive. 11:30 - 11:45 0.25 STKOH C PROD1 Pick up tools to rig floor. 11:45 - 12:00 0.25 STKOH C PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for M/U BTT billet, anchor and CoilTrak. 12:00 - 13:30 1.50 STKOH C PROD1 M/U BTT Open Hole Billet with Anchor BHA #8, M/U to CoilTrak tools. BHA OAL - 68.67'. 13:30 - 15:40 2.17 STKOH C PROD1 RIH with Billet /Anchor BHA #8. Circ thru open EDC at 0.2 bpm, 700 psi. Up wt at 11250' = 30K. Went thru window clean. Closed EDC. 15:40 - 16:00 0.33 STKOH C PROD1 Log GR tie-in at RA tag. -18' CTD. 16:00 - 16:30 0.50 STKOH C PROD1 RIH clean. Position Top of Billet at 12,010'. Bottom of Anchor at 12 021'. Hi h side to Set AL Billet, sheared at 3800 psi, stacked 2K, OK. Billet is set. POH slow for 20', no overpull. 16:30 - 19:40 3.17 STKOH C PROD1 POH. Installed Coil Inspect above window. POH while inspect Coil wall thickness. Shut down pump at 500 ft and close EDC. 19:40 - 19:50 0.17 STKOH C PRODi SAFETY MEETING. Crew placement and procedures for change out BHA, also SIMOPs for removing CT inspect. 19:50 - 20:50 1.00 STKOH C PROD1 Tag stripper. Lay down Billet /Anchor running tools, tools appear to have functioned normally. Pick up BHA #9 -Kickoff assembly. Remove CT inspect tool from reel. 20:50 - 23:20 2.50 STKOH C PROD1 M/U CT riser and RIH with BHA #9 - 2.73" PDC bit, 2-3/8" Xtreme motor with 1.8 deg AKO, 2-3/8" CoilTrack. BHA OAL = rnntea: tiituieuuu a:si:ay iann BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task ~ Code NPT Phase I Description of Operations 6/6/2008 20:50 - 23:20 2.50 STKOH C PROD1 58.06 ft. 23:20 - 23:40 0.33 STKOH C PROD1 Log GR down from 11,500 ft at 100 ft/hr. Correct -24 ft. 23:40 - 00:00 0.33 STKOH C PROD1 RIH and dry tag billet at 12,013 ft. 6/7/2008 00:00 - 03:40 3.67 STKOH C 03:40 - 04:50 1.17 STKOH C 04:50 - 07:00 2.17 STKOH C 07:00 - 07:15 0.25 DRILL C 07:15 - 08:45 1.50 DRILL C 08:45 - 09:30 0.75 BOPSU C 09:30 - 12:30 3.00 DRILL C 12:30 - 13:00 0.50 DRILL C 13:00 - 13:15 0.25 DRILL C 13:15 - 15:15 2.00 DRILL C 15:15 - 17:00 1.75 DRILL C 17:00 - 18:00 1.00 DRILL C 18:00 - 18:50 0.83 DRILL C 18:50 - 19:50 1.00 DRILL C 19:50 - 23:45 3.92 DRILL C 23:45 - 00:00 0.25 DRILL C 6/8/2008 00:00 - 00:40 0.67 DRILL C 00:40 - 05:05 4.42 DRILL C Pick up to get weight back and establish free spin of 2,850 psi. Set pump trip at 3,100 psi. PROD1 Time drill from 12,008 ft at 15R toolface off billet at 1 fUhr for 1 ft, then 2 fUhr for 3 ft. Increase to 7 Whr at 12,012 ft, and to 30 ft/hr after 12,020 ft. Drill to 12,030 ft, good indication of sidetrack. PROD1 Backream to 11,990 ft at 15R toolface. Slight overpull seen at 12,013 ft. Ream back past billet and backream at 45R and 45L. Dry pass through sidetrack is clean, slight weight change at 12,020 ft. PROD1 POOH. Pull through window and open EDC, pump 2 bpm on the way out. PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for changing out BHA. PROD1 M/U CoilTrak lateral BHA #10 w/ HCC BC Bit, 1.2 deg Xtreme motor, Agitator and CoilTrak tools. BHA OAL = 66.05' PROD1 Function test BOPE. Send test report to AOG PROD1 wit of ra PROD1 Log GR tie-in at RA tag, -18' CTD. PRODi RIH clean to bottom. PRODi Drill Z1A lat, 1.5 bpm, 3580-4000 psi, 90L TF, 1-2K wob, 30 fph, 9.5 ecd, 98 deg incl, Drilled to 12080'. PROD1 Drill Z1A lat, 1.5 bpm, 3580-4000 psi, 160E TF, 1-2K wob, 40 fph, 9.5 ecd, 93 deg incl, Dilled to 12,110'. PROD1 Drill Z1A lat, 1.5 bpm, 3580-4000 psi, 120R TF, 1-2K wob, 40 fph, 9.6 ecd, 95 deg incl, Drilled to 12,150'. PROD1 Drill Z1A lat, 1.5 bpm, 3580-4000 psi, 120R TF, 1-2K wob, 40 fph, 9.6 ecd, 95 deg incl. Stacking weight occasionally. Drill to 12,173 ft. PROD1 Not much cuttings on shakers, pull wiper trip from 12,173 ft to window. Add flo-vis to system. Reduce pump pulling through sidetrack. PROD1 Drill from 12,173 ft at 1.48 / 1.43 bpm, 3,600 - 3,900 psi, 1 - 2 Klbs DWOB with 9 - 13K CT weight. Try to maintain 89 - 90 deg inc as per Geo. Pump an 18 bbl viscous pill prior to wiper trip. Drill to 12,300 ft. PROD1 Wiper trip from 12,300 ft to window. Clean pickup off bottom 30 Klbs. Reduce pump going through sidetrack. PROD1 Continue wiper trip from 12,300 ft. PROD1 Drill from 12,300 ft at 1.49 / 1.45 bpm, 3,600 - 4,000 psi. rnntea: oiavi~wa a:a i:va rim BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To 'Hours Task Code NPT Phase Description of Operations 6/8/2008 00:40 - 05:05 4.42 DRILL C PROD1 DWOB is 1 - 2.5 Klbs with 9 - 12 Klbs CT weight. ROP is 30 - 50 ft/hr, stacking weight occasionally. Pull 60 Klbs off bottom at 12,430 ft, and at 12,436 ft. Pump 10 bbl viscous sweep around prior to wiper trip. Drill to 12,450 ft. 05:05 - 06:25 1.33 DRILL C PROD1 Wiper trip from 12,450 ft to window. Tie in depth from 11,500 ft. Correct +6 ft. Resume wiper trip to bottom. 06:25 - 07:30 1.08 DRILL C PROD1 Drill from 12,456 ft. Stacking weight repeatedly. Drilled to 12517'. 07:30 - 10:00 2.50 DRILL C PROD1 Long wiper trip to 9200' to clean out cuttings from high angle hole. Open EDC above window. Circ at 2.0 bpm at 3550 psi. RIH clean to bottom. 10:00 - 12:00 2.00 DRILL C PROD1 Drill Z1A lat, 1.5 bpm, 3500-4000 psi, 110E TF, 1-2K WOB, Stacking wt. Swap to new FloPro at 12,535' Drilled to 12535'. 12:00 - 14:00 2.00 DRILL C PROD1 Drill Z1A lat, 1.5 bpm, 3200-3600 psi, 110E TF, 2K WOB, Stacking wt. Drilled into 200 API GR shale at 12,510'. Slow drilling at 20 fph. Drilled to 12,550'. 14:00 - 16:00 2.00 DRILL C PROD1 Drill Z1A lat, 1.6 bpm, 3400-3800 psi, 110E TF, 2K WOB, 9.5 ecd, Slow drilling in shale at 20 fph. Early stalls. Drilled to 12,575'. 16:00 - 19:00 3.00 DRILL X DFAL PRODi POH to check BHA. Open EDC above window and circ at 2.0 bpm, 2900 psi. 19:00 - 19:15 0.25 DRILL X DFAL PRODi SAFETY MEETING. Discuss crew positions, hazards and procedures for changing out BHA. 19:15 - 21:15 2.00 DRILL X DFAL PROD1 Lay down BHA #10. Bit comes out 1/1, no plugged jets. Hole approximately 15 mm X 4 mm is found washed in DPS housing. Pressure test CT connector to 3,500 psi, good. Make up new DPS sub on catwalk, new agitator, new motor, and re-run previous bit. 21:15 - 00:00 2.75 DRILL X DFAL PROD1 Test tool at surface and RIH. Stop at 500 ft and test agitator, working. 6/9/2008 00:00 - 00:30 0.50 DRILL X DFAL PROD1 Log GR down from 11,500 ft. Correct -22 ft. 00:30 - 01:10 0.67 DRILL X DFAL PROD1 RIH to find bottom. 01:10 - 02:15 1.08 DRILL P PROD1 Tag bottom and drill at 1.58 / 1.53 bpm, 3500 - 4000 psi. Initial ROP is 50 - 90 ft/hr with 2.3 Klbs DWOB and 12 - 14 Klbs CT weight. Plan is to hold 92 dea inc to find. sansi_ Stacking weight periodically. Drill to 12,622 ft. 02:15 - 02:45 0.50 DRILL X SFAL PROD1 Ops cab loses power. Start pulling pulling back to window. Orient highside to pull past billet. 02:45 - 05:15 2.50 DRILL X SFAL PRODi UPS in Ops cab gives up at CT depth of 11,768 ft. Injector brake sets, no power to injector controls. Park here and circ at 0.6 bpm until power is restored. Nordic 2 rig electrician comes out to repair faulty breaker. 05:15 - 05:25 0.17 DRILL X SFAL PROD1 Power is restored. Boot up computers and reset depths. 05:25 - 06:15 0.83 DRILL X SFAL PROD1 Continue wiper trip back to window then to TD. Clean pass through 11,768 ft. 06:15 - 08:00 1.75 DRILL P PROD1 Drill Z1 A lateral, 1.5 bpm, 3300-4000 psi, 60L TF, 89 deg rnrnea: oiswzuun as i:aa nm ' • BP EXPLORATION Operations Summary Report Legal Well Name: K-20 Page 8 of 10 ~ Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To ' Hours ~ Task Code NPT Phase Description of Operations - - -~ 6/9/2008 06:15 - 08:00 1.75 DRILL P PROD1 incl, 40 fph, Drilled to 12 699'. Anc. Geo's called well at TD. 08:00 - 08:40 0.67 DRILL P PROD1 Wiper trip up to window. Clean hole. 08:40 - 09:05 0.42 DRILL P PROD1 Log GR tie-in at RA tag, added 2' CTD. 09:05 - 09:45 0.67 DRILL P PROD1 RIH clean to bottom. Clean past Billet. RIH Clean to TD. Tagged TD at 12,696'. 09:45 - 10:15 0.50 DRILL P PROD1 POH while laying in 30 bbl new FloPro liner pill with 2 PPB Beads. Circ at 1.0 bpm, 2100 psi. 10:15 - 12:00 1.75 DRILL P PROD1 Open EDC at window. Circ at 2.0 bpm and POH. 12:00 - 12:15 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out drilling BHA. 12:15 - 13:15 1.00 DRILL P PROD1 Lay out drilling BHA. 13:15 - 13:30 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for laying out drilling BHA. 13:30 - 16:00 2.50 CASE P RUNPRD M/U Indexing Guide shoe, 1 jt 2-3/8", STL Solid Liner, BTT O-Ring Sub, 20 Jts, 2-3/8" STL Pre-Drilled liner, 17 Jts, 2-3/8" STL Pre-Drilled Liner with straight Centralizers. 2 jts, 2-3/8", STL Solid liner and BTT Deployment sleeve with 3" GS profile. Liner total len th = 1 233.11'. 16:00 - 16:45 0.75 CASE P RUNPRD M/U BTT 3" Pump off GS Spear to deployment sleeve and CoilTrak tools. BHA OAL = 1263.71'. 16:45 - 19:00 2.25 CASE P RUNPRD RIH with 2-3/8" liner BHA #12. Circ at 0.3 bpm, 700 psi. Tag at 12,714 ft. Up weight is 34 Klbs. Run back and tag at same spot, stack 10 Klbs on BHA. Close EDC. Pump 1.85 bpm C~3 3,800 psi. Pick up slowly and leave liner behind, up weight now is 26 Klbs. 19:00 - 22:00 3.00 CASE N FLUD RUNPRD Wait on KCI or pert pill to arrive to swap well over. 22:00 - 00:00 2.00 CASE P RUNPRD Start pert pill down the CT. Pump 30 bbl pill, save the rest for pert ball chasing. Lay in new Flo-Pro 1:1 from 11,450 ft, and KCL on top of that. 6/10/2008 00:00 - 01:00 1.00 CASE P RUNPRD Continue POOH. 01:00 - 01:15 0.25 CASE P RUNPRD Tag stripper and flow check well. SAFETY MEETING. Discuss crew placements, hazards and mitigations for UD liner running tools. 01:15 - 01:30 0.25 CASE N DFAL RUNPRD Break off injector and stand back. Liner deployment sleeve and rest of liner is still caught in GS s r. 01:30 - 03:00 1.50 CASE N DFAL RUNPRD Break off deployment sleeve and GS spear, send back to BTT shop. Wait for new GS spear. Leave liner hanging in well, with stabbing valve installed. Monitor well and fill occasionally. 03:00 - 03:50 0.83 CASE N DFAL RUNPRD New GS spear arrives. M/U GS spear and CoilTrack assembly to liner. Liner OAL = 1,233.11 03:50 - 07:00 3.17 CASE N DFAL RUNPRD RIH -BHA #14 Liner + CoilTrack. Weight check at 11,400 ft is 31 Klbs. Landed liner at 12,720' uncorrected depth, true TD = 12,696'. Normal correction = -20'. Up wt off bottom with no pump = 31.5K, BHI WOB showed rnrneo: oiawcuua a:a ~.r~ wvi BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code ~ NPT Phase Description of Operations 6/10/2008 103:50 - 07:00 3.171 CASE I N DFAL RUNPRD -2.4K (tool in tension). 07:00 - 07:30 0.50 CASE P 07:30 - 09:15 1.75 CASE P 09:15 - 09:30 0.25 CASE P 09:30 - 10:15 0.75 CASE P 10:15 - 10:30 0.25 PERFO P 10:30 - 14:45 4.25 PERFO P 14:45 - 17:30 2.75 PERFO P 17:30 - 18:30 1.00 PERFO P 18:30 - 19:15 0.75 PERFO P 19:15 - 19:50 0.58 PERFO P 19:50 - 21:50 I 2.001 PERFOBI P 21:50 - 22:20 I 0.501 PERFOB P 22:20 - 00:00 1.67 PERFO P 6/11/2008 00:00 - 00:20 0.33 PERFO P 00:20 - 00:40 0.33 PERFO P 00:40 - 02:00 1.33 PERFO P 02:00 - 02:40 0.67 BOPSUFj P 02:40 - 03:10 0.50 BOPSU P Staked 6.3K on tool from BHI WOB. Pumped 1.85 bpm at 4000 psi. BHI measured 2000 psi differential, Picked up off liner with 28.5K and BHI WOB measured 0.6K, so no tension or drag on tool. Very good indication that we are released from liner and. liner is set at TD. Too of 2-3/8" liner deolovment sleeve is at 11.463'. RUNPRD Lay in 20 bbl new FloPro pert pill inside 3-3/16" liner. RUNPRD POH while circ at 0.6 bpm, 800 psi, BHI WOB indicates liner left in hole. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for laying out CoilTrak /Spear BHA. RUNPRD Lay out CoilTrak. Liner was left at TD as Manned. LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for Running pert guns and BHA. LOWERI M/ W 2" P 6 f rf 6' f erfs ,firing head, Hyd Disc, 36 jts CSH, 2.8" landing profile, Hyd Disc, 22 jts CSH, Swivel, and Baker CTC. Perf BHA Total length = 2202.68'. LOWERI RIH tag at 11452. Correct to 11448 and pu to ball drop position. LOWERI Launch 1/2" steel ball with 10 bbl ahead and 15 bbl pill behind. Circulate ball to firing head 1.8 bpm at 3000 psi. LOWERi Ball doesn't land. Stop pumping, bleed off. Remove cap of ball drop "T" and tap on 1502 elbow in reel, 1/2" ball is there. LOWERi Roll reel to ball drop position, launch with 2,000 psi. Ball is heard rolling. Over the gooseneck at 22.0 bbls. Ball seats at 44.0 bbls. Pressure up to 3,400 psi and shear ball seat while moving coil at 11,440 ft. Good shot indication on acoustic. PERFINTERVAL: 11 080 ft - 11 440 ft 2.00" 6SPF 2006PJ Omega LOWERI POOH, hold 300 - 400 psi WHP and limit speed to 50 fUmin until out of liner. 08:25 -Stop at 9,890 ft and flow check. No flow. Continue POOH holding 300 - 400 psi WHP. LOW ER1 Tag stripper. Flow check well. SAFETY MEETING. Discuss procedures and crew placement for UD CSH. LOWERi Break off well, stand back injector. L/D CSH and BTT tools. Remove 289 ft of cable and cut it off. LOWERi Continue to L/D CSH and BTT running tools. LOWERi SAFETY MEETING. Discuss crew responsibilities, hazards and mitigations for pulling fired pert guns. LOWERi Pull and lay down 17 full and 1 partial gun. All guns fired. ~` Load out spent guns and running tools. LOWERI M/U cable boot and swizzle stick for cleaning out stack. LOWERI Jet stack with swizzle stick up and down 2 times. Printed: 6/30/2008 9:31:49 AM • • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: K-20 Common Well Name: K-20 Spud Date: 4/22/1995 Event Name: REENTER+COMPLETE Start: 5/29/2008 End: 6/11/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/11/2008 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours i Task Code NPT Phase ', Description of Operations 6/11/2008 03:10 - 04:10 1.00 BOPSU P - - LOW ER1 -- P/U BHA #14 - Liner to acker, 4" GS running tool, 4 jts of PH-6 tbg. BHA OAL = 147.92 ft. 04:10 - 06:00 1.83 BOPSU P LOWERi RIH BHA #14. Tag at 9,932 ft uncorrected. Put ball in reel, launch with 2,000 psi. 06:00 - 07:30 1.50 BOPSU P LOWERI Circulate ball to setting tool After 50 bbls.( calculated 44bbls to seat) Ball may be hanging up in check valves. 07:30 - 08:15 0.75 BOPSU P LOWERI Set acker on de th. Pressure back side to confirm acker incerted in the de to ment sleeve. Pressure to 4 i. Ramp up pump bull head 3 bpm. Pressure to 1000 psi almost immediately look like ball was in checks hold pressure uo to 2000 psi, hold. Attempt to slack off. Packer set. Test back side to 1000 osi OK. Bleed off backside and Pressure CT to 350 _ 08:15 - 10:15 2.00 BOPSU P LOWERI POH. 10:15 - 10:30 0.25 BOPSU P LOWERi LD BHA 10' cable exposed. 10:30 - 10:45 0.25 BOPSU P POST MU nozzle for freeze protection. 10:45 - 13:00 2.25 BOPSU P POST Freeze protect well with MEOH to 2500'. Clean pits. 13:00 - 14:00 1.00 BOPSU P POST Flow check well. Blow down choke and kill lines. Set BPV. 14:00 - 18:00 4.00 RIGD P POST ND BOP Ri Relea .All further data on Well 15-18 report. 18:00 - 00:00 6.00 RIGD P POST Move to Well 15-18. Pri ntetl: 6/30/2008 'J::S1:4y AM R i ~ by BP Alaska B~`~s Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 6!9/2008 Time: 15:29:20 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-20, True North Site: PB K Pad Vertical (TVD) Reference: K-20A 52.1 Well: K-20 Section (VS) Reference: Well (O.OON,O.OOE,168.84Azi) R'ellpath: K-20CP61 Survey Calculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordiuate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007 Site: PB K Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973161.33 ft Latitude: 70 19 57.435 N From: Map Easting: 670342.10 ft Longitude: 148 37 5.245 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.30 deg Well: K-20 Slot Name: K-20 Well Position: +N/-S 2004.90 ft Northing: 5975192.46 ft Latitude: 70 20 17.152 N +E/-W 1184.03 ft Easting : 671480.22 ft Longitude: 148 36 30.663 W Position Uncertainty: 0.00 ft Wellpath: K-20CPB1 Drilled From: K-20A 500292255571 Tie-on Depth: 11469.95 ft Current Datum: K-20A Height 52.13 ft Above System Datum: Mean Sea Level Magnetic Data: 1/9/2008 Dedinafion: 23.48 deg Field Strength: 57670 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 27.93 0.00 0.00 168.84 Survey Program for Definitive Wellpath Date: 2/19/2008 Validated: No Version: 1 Actual From To Survey Toolcode Tool Name ft ft 180.88 9097.76 1 : MWD -Standard (180.88-109 MWD MWD -Standard 9122.92 11469.95 3 : MWD -Standard (9122.92-13 MWD MWD -Standard 11477.00 12588.00 MWD (11477.00-12588.00) MWD MWD -Standard Annotation n7D Tw ft ft 11469.95 8789.81 TIP 11477.00 8789.67 KOP 12588.00 8776.40 TD Survey: MWD Start Date: 6/9/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path { by BP Alaska s Baker Hughes INTEQ Survey Report llYTEQ Company: BP AfT10C0 Date: 6/9!2008 Time: 15:29:20 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-20, True North Site: PB K Pad Vertical (TVD) Reference: K-20A 52.1 Well: K-20 Section (VS) Reference: Well (O.OON,O.OOE,168.84Azi) Wellpath: K-20CPB1 Survey Calculation Method: Minimum Curvature Db: Orade Survey MD ft Inc! deg :1zim deg TVD ft Sys TVD ft N/S ft E/W ft 11469.95 91.70 146.56 8789.81 8737.68 -4662.84 -84.36 11477.00 90.63 145.43 8789.67 8737.54 -4668.69 -80.41 11499.32 87.24 141.87 8790.09 8737.96 -4686.65 -67.19 11531.16 86.84 136.77 8791.73 8739.60 -4710.76 -46.47 11561.38 88.68 131.93 8792.91 8740.78 -4731.86 -24.88 11602.44 90.37 124.28 8793.25 8741.12 -4757.18 7.40 11631.32 90.74 120.38 8792.97 8740.84 -4772.62 31.80 11664.54 91.57 114.05 8792.30 8740.17 -4787.80 61.32 11696.28 89.35 109.72 8792.05 8739.92 -4799.63 90.76 11729.14 90.95 111.05 8791.96 8739.83 -4811.07 121.56 11763.10 91.75 113.81 8791.16 8739.03 -4824.03 152.94 11797.08 91.01 106.77 8790.34 8738.21 -4835.80 184.78 11827.10 93.22 101.39 8789.23 8737.10 -4843.09 213.87 11867.96 92.92 94.73 8787.04 8734.91 -4848.81 254.24 11900.52 92.79 90.04 8785.42 8733.29 -4850.16 286.72 11935.00 92.70 83.05 8783.77 8731.64 -4848.09 321.08 11967.04 91.41 77.17 8782.62 8730.49 -4842.59 352.61 11995.16 92.43 71.70 8781.68 8729.55 -4835.05 379.67 12024.76 91.23 66.50 8780.73 8728.60 -4824.50 407.30 12056.78 93.41 68.66 8779.43 8727.30 -4812.30 436.87 12088.68 92.73 74.40 8777.72 8725.59 -48Q2.22 467.07 12121.16 92.46 82.87 8776.25 8724.12 -4795.83 498.85 12150.34 90.18 88.40 8775.58 8723.45 -4793.61 527.93 12181.62 90.80 91.40 8775.31 8723.18 -4793.55 559.20 12211.42 89.57 95.42 8775.21 8723.08 -4795.33 588.94 12246.34 88.80 100.38 8775.71 8723.58 -4800.12 623.52 12275.86 89.54 104.41 8776.14 8724.01 -4806.46 652.34 12305.44 89.85 105.49 8776.30 8724.17 -4814.09 680.92 12336.32 92.46 103.57 8775.67 8723.54 -4821.83 710.80 12372.94 95.75 101.98 8773.05 8720.92 -4829.91 746.42 12401.92 95.10 98.99 8770.31 8718.18 -4835.16 774.78 12431.12 92.76 97.26 8768.31 8716.18 -4839.28 803.62 12459.48 90.15 98.36 8767.59 8715.46 -4843.13 831.70 12481.38 87.66 97.36 8768.01 8715.88 -4846.12 853.39 12510.74 85.14 96.96 8769.85 8717.72 -4849.77 882.46 12588.00 85.14 96.96 8776.40 8724.27 -4859.10 958.88 MapN MapE ft ft 5970529.22 671502.52 5970523.47 671506.59 5970505.81 671520.22 5970482.19 671541.49 5970461.58 671563.55 5970437.01 671596.40 5970422.14 671621.14 5970407.63 671651.00 5970396.48 671680.70 5970385.75 671711.76 5970373.52 671743.42 5970362.48 671775.52 5970355.85 671804.77 5970351.06 671845.26 5970350.45 671877.76 5970353.31 671912.06 5970359.52 671943.45 5970367.68 671970.33 5970378.86 671997.71 5970391.73 672026.99 5970402.50 672056.95 5970409.62 672088.58 5970412.50 672117.59 5970413.27 672148.86 5970412.18 672178.63 5970408.17 672213.30 5970402.50 672242.26 5970395.52 672271.00 5970388.46 672301.05 5970381.20 672336.84 5970376.61 672365.32 5970373.15 672394.24 5970369.94 672422.40 5970367.44 672444.15 5970364.46 672473.29 5970356.88 672549.90 VS DLS Tool ft deg/100ft 4558.29 0.00 MWD 4564.79 22.07 MWD 4584.97 22.02 MWD 4612.64 16.05 MWD 4637.52 17.12 MWD 4668.60 19.08 MWD 4688.48 13.56 MWD 4709.09 19.21 MWD 4726.39 15.33 MWD 4743.58 6.33 MWD 4762.36 8.46 MWD 4780.08 20.83 MWD 4792.87 19.36 MWD 4806.29 16.29 MWD 4813.91 14.39 MWD 4818.53 20.25 MWD 4819.24 18.78 MWD 4817.08 19.78 MWD 4812.08 18.02 MWD 4805.83 9.58 MWD 4801.78 18.09 MWD 4801.67 26.06 MWD 4805.12 20.49 MWD 4811.12 9.79 MWD 4818.62 14.11 MWD 4830.02 14.37 MWD 4841.82 13.88 MWD 4854.83 3.80 MWD 4868.22 10.49 MWD 4883.04 9.97 MWD 4893.68 10.51 MWD 4903.30 9.96 MWD 4912.52 9.99 MWD 4919.65 12.25 MWD 4928.86 8.69 MWD 4952.81 0.00 MWD • • by BP Alaska s Baker Hughes INTEQ Survey Report T ilY EQ Company: BP Amoco Date: 6/9/2008 Time: 15:30:30 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Refereuce: Well: K-20, True North Site: PB K Pad Vertical (TVD) Reference: K-20A 52.1 Well: K-20 Section (VS) Refereuce: Well (O.OON,O.OOE,167.73Azi) R'ellpath: K-20C Survey Calculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB K Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973161.33 ft Latitude: 70 19 57.435 N From: Map Fasting: 670342.10 ft Longitude: 148 37 5.245 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.30 deg Well: K-20 Slot Name: K-20 Well Position: +N/-S 2004.90 ft Northing: 5975192.46 ft Latitude: 70 20 17.152 N +E/-W 1184.03 ft Fasting : 671480.22 ft Longitude: 148 36 30.663 W Position Uncertainty: 0.00 ft Wellpath: K-20C Drilled From: K-20CP61 500292255503 Tie-on Depth: 11995.16 ft Current Datum: K-20A Height 52.13 ft Above System Datum: Mean Sea Level Magnetic Data: 6/9/2008 Declination: 23.24 deg Field Strength: 57679 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 27.93 0.00 0.00 167.73 Survey Program for Definitive Wellpath Date: 6/9/2008 Validated: No Version: 1 Actaal From To Survey Toolcode Tool Name ft ft 180.88 9097.76 1 : MWD -Standard (180.88-109 MWD MWD -Standard 9122.92 11469.95 3 : MWD -Standard (9122.92-13 MWD MWD -Standard 11477.00 11995.16 MWD (11477.00-12588.00) (4) MWD MWD -Standard 12010.00 12696.00 MWD (12010.00-12696.00) MWD MWD -Standard Annotation hiD TVD ft ft 11995.16 8781.68 TIP 12010.00 8781.12 KOP 12696.00 8755.13 TD Survey: MWD Start Date: 6/9/2008 Company: Baker Hughes INTEQ Engineer: BP Tool: MWD;MWD -Standard Tied-to: From: Definitive Path • • b BP Alaska p Baker Hughes INTEQ Survey Report ~i~~ s 1NTEQ Company: BP Amoco Date: 6!9/2008 Time: 15:30:30 Page: 2 Field: Prudhoe Bay Co-ordiuate(NE) Refereuce: Well: K-20, True North Site: PB K Pad Vertical (TVD) Reference: K-20A 52.1 Well: K-20 Section (VS) Refereuce: Well (O.OON,O.OOE,167.73Azi) ~Vellpath: K-20C Survey Calculation Method: Minimum Curvature Db: Orade Survey MD ft Incl deg Azim deg T4~ ft Sys "I'VD ft N/S ft E/W ft 11995.16 92.43 71.70 8781.68 8729.55 -4835.05 379.67 12010.00 91.83 69.09 8781.12 8728.99 -4830.08 393.64 12033.53 98.41 67.17 8779.02 8726.89 -4821.36 415.38 12064.99 97.39 62.32 8774.70 8722.57 -4808.06 443.55 12096.01 94.51 61.81 8771.48 8719.35 -4793.61 470.81 12127.61 94.12 67.99 8769.10 8716.97 -4780.25 499.33 12158.77 90.65 71.42 8767.81 8715.68 -4769.46 528.52 12188.47 87.72 76.45 8768.23 8716.10 -4761.24 557.04 12218.27 86.80 80.42 8769.65 8717.52 -4755.28 586.20 12248.74 87.63 85.88 8771.14 8719.01 -4751.65 616.40 12282.41 89.23 92.40 8772.06 8719.93 -4751.14 650.04 12312.40 92.21 98.52 8771.68 8719.55 -4754:00 679.87 12342.60 95.08 103.75 8769.76 8717.63 -4759.81 709.43 12372.92 94.61 109.36 8767.20 8715.07 -4768.42 738.38 12397.32 92.18 114.38 8765.75 8713.62 -4777.49 760.97 12428.17 91.44 118.14 8764.78 8712.65 -4791.13 788.62 12458.80 93.01 113.91 8763.59 8711.46 -4804.55 816.12 12490.64 92.86 107.88 8761.96 8709.83 -4815.89 845.81 12521.06 92.02 103.19 8760.66 8708.53 -4824:03 875.08 12554.91 90.49 96.11 8759.92 8707.79 -4829:69 908.42 12598.59 91.91 90.16 8759.00 8706.87 -4832:08 952.01 12632.29 92.86 84.03 8757.60 8705.47 -4830.38 985.62 12662.01 92.03 79.30 8756.33 8704.20 -4826.07 1014.99 12696.00 92.03 79.30 8755.13 8703.00 -4819:77 1048.37 MapN NIapE ft ft 5970367.68 671970.33 5970372.97 671984.18 5970382.19 672005.71 5970396.12 672033.57 5970411.19 672060.49 5970425.20 672088.70 5970436.65 672117.63 5970445.52 672145.96 5970452.15 672174.97 5970456.47 672205.08 5970457.74 672238.69 5970455.57 672268.58 5970450.44 672298.26 5970442.49 672327.40 5970433.94 672350.19 5970420.94 672378.14 5970408.15 672405.94 5970397.49 672435.88 5970390.03 672465.33 5970385.12 672498.79 5970383.73 672542.41 5970386.21 672575.97 5970391.18 672605.24 5970398.25 672638.46 VS DLS Tool ft deg/100ft 4805.28 0.00 MWD 4803.38 18.02 MWD 4799.48 29.12 MWD 4792.48 15.61 MWD 4784.15 9.43 MWD 4777.16 19.54 MWD 4772.82 15.65 MWD 4770.85 19.60 MWD 4771.22 13.66 MWD 4774.09 18.10 MWD 4780.75 19.93 MWD 4789.88 22.69 MWD 4801.84 19.72 MWD 4816.40 18.50 MWD 4830.07 22.82 MWD 4849.27 12.42 MWD 4868.24 14.72 MWD 4885.63 18.92 MWD 4899.80 15.65 MWD 4912.42 21.39 MWD 4924.02 14.00 MWD 4929.50 18.39 MWD 4931.54 16.14 MWD 4932.47 0.00 MWD TREE= 4-1/16" CM! WELLHEAD = FMC ACTUATOR = BAKER KB. ELEV = 52.13' BF. ELEV = 24.2' KOP = 4350' tilax Angle = 98 @ 12033' Datum MD = NA Datum TV D = 8800' SS DRLG DRAFT 10-3/4" CSG, 45.5#, NT-80 BTC, ID = 9.950" Minimum ID =1.995" @ 11465' TOP OF 2-3/8" LINER K-20C SAFEfY NOTES: 2222' ~-~ 4-1 /2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 4 3265 3261 2 TMPDX DOME BK 16 06/16/08 3 5739 5599 38 TMPDX SO BK 20 06/16/08 2 7633 7098 38 TMPDX DMY BK 0 08/20/01 1 8801 8027 38 TMPDX DMY BK 0 08/20!01 4-1/2" HES X NIP, ID = 3.813" 8878' ~-i 7-5/8" X 4-112" TM/ HBBP-T PKR, ID = 3.912" 8903' (~4-1/2" HES X NIP, ID = 3.813" ~ BKR TIEBACK SLEEVE, ID =? ~ 4-1/2" TBG,12.6#, L-80 BUTT, .0152 bpf, ID = 3.958" 9098' 7-518" CSG, 29.7#, NT-95HS NSCC, ID = 6.875" ~` ~O 8924' ~ 4-1/2" HES X NIP, MILLED ID = 3.8" $9~ 4-112" WLEG w /MULESHOE GUIDE, ID = 3.958" ELMD TT NOT LOGGED 8936' 7-5/8" X 4-1/2" BKR ZXP PKR, ID = 5.50" 8950' 7-518" X 4-1/2" BKR HMC HGR, ID = 4.875" 9910' -14-1i2" KB LNR TOP PACKER, ID = 2.36" 9917' 3.7" BKR DEPLOY SLV, ID = 3.0" 9935' ~ 3-1/2" HOWCO XN NIP, ID = 2.750" 99~36~ 3-1 /2" X 3-3/16" XO, ID = 2.786" TOC 3 3/16" LINER PER SCMT ~~ 10304' 11462' ~-I z 3/8" i 1 it lai 11477' TOP 3 3116" WHIPSTOCK RA Tag @ 11.482' 4-1/2" LNR, 12.6#, L-80 NSCT, 13108' .0152 bpf, ID = 3.958" 11504' REF LOG: MWD ON 06/06/08 ~O ANGLE AT TOP PERF: 88° @ 11040' ~ Note: Refer to Production DB for historical perf data SIZE 5PF INTERVAL Opn/Sqz DATE ~' ?~ ~'~80- 11n40 O nF 10'08 PRE DRILLED LNR ~ }8 2-7/8" LNR, 6.16#, L-80 STL, I 13004' .0058 bpf, ID = 2.441" l ( J 11528' 2 3/8" TOP OF Pre-Drilled 1 LINER 3-3116" LNR, 6.2#, L-80, 11568' ~ ' ~ , TCII, .0076 bpf, ID = 2.80" 12662' PBTD ` ~ K-20C 2-.3 8" Pre-Drilled LNR. 4.7#, L-80 STL, ID=1.995" 12696' K-20B DATE REV BY COMMENTS DATE REV BY COMMENTS 06103195 D-9 ORIGINAL COMPLETION 06/11/08 NORDICI CTD SIDETRACK (K-20B) 08128/98 D-16 SIDETRACK (K-20A) 06/12/08 ITCH CORRECTIONS 12109/02 JLM/KK CTD SIDETRACK (K-20B) 06/14/08 ITCH CORRECTIONS 08/17/07 JMC/ PJC SET KP PKR (07/27/07) 06/25/08 KDC/SV GLV GO (06/16/08) 09/15/07 PJC WBS CORRECTIONS 09/15/07 JLJ/PJC GLV GO PRUDHOE BAY UNfT WELL: K-20B PERMff No: 2022240 API No: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL 8 4070' WEL BP Exploration (Alaska) ~~.~~ ~ ~ ~ =~ f y9J-~,~~ ~ x¢11 ALASS~i OIL AHD GrA,S COHSERQATIOIIT COMIrII55IO1Q Abby Higbie CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU K-20C BP Exploration Alaska, Inc. Permit No: 208-049 Surface Location: 3251' FSL, 4070' FEL, SEC. 04, T11N, R14E, UM Bottomhole Location: 1540' FNL, 3542' FEL, SEC. 09, T11N, R14E, UM Dear Ms. Higbie: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. ~`j Chair DATED this ~ ~ day of April, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMM PERMIT TO DRILL 20 AAC 25.005 MAR 2 4 2008 AIx4~ llrif, f~ t~~ (`.nnr f`rurrrmi_ccine°; 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is [~~ or: ^Coalbed Meth~ne"'L~ Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU K-20C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13040' TVD 8705' ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2 1' FS 4 70' FE T1 1 M S C 7. Property Designation: ADL 028303 Pool 3 5 L, 0 L, E . 04, 1 N, R 4E, U Top of Productive Horizon: 116' FNL, 4643' FEL, SEC. 09, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 1, 2008 Total Depth: 1540' FNL, 3542' FEL, SEC. 09, T11 N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 17500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-671480 y-5975192 Zone-ASP4 10. KB Elevation (Height above GL): 52.13 feet 15. Distance to Nearest Well Within Pool: 2100' 16. Deviated Wells: Kickoff Depth: 11470 feet Maximum Hole An le: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3283 Surface: 2403 18' a in Pr `ram: S ecfications To - Se in ' De th - Bo om uantit of Cem nt c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.7# L-80 STL 1598' 11442' 8791' 13040' 8705' ss Uncemented Slotted Liner 1`g. PRESE NT-WELL CONDITION SUMMARY (To tie completed for Redrill and Re-entry Operation&) Total Depth MD (ft): 13004 Total Depth TVD (ft): 8707 Plugs (measured): 12260 & 12680 Effective Depth MD (ft): 12971 Effective Depth TVD (ft): 8707 Junk (measured): 12740 asing Length Size Cement Volume MD D Conductor /Structural 110' 20" 260 sx Arctic Set A rox. 110' 110' Surface 3681' 10-3/4" 1045 sx PF 'E' 735 sx Class 'G' 3716' 3712' Intermediate Pr i n 7-5/8" 4 sx CI 9 8' 2 ' Liner 2568' 4-1/2" 460 sx Class 'G' 8936' - 11504' 8133' - 8789' Liner 3094' 3-1/2" x 3-3/16" x 2-7/8" 135 sx Class 'G' 9910' - 13004' 8668' - 8707' Perforation Depth MD (ft): 12015' - 12960' Perforation Depth TVD (ft): 8755' - 8707' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Abby Higbie, 564-5480 Printed Name Abby Higbie Title CT Drilling Engineer Prepared ey Name/Number: Si nature • Phone 564-5480 Date Sondra Stewman, 564-4750 Gommissian Use Onl Permit To Drill Number: O!7 API Number: 50-029-22555-03-00 Permit Ap royal Date: ~ See cover letter for other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me~tha/ne, gas hydrates, or gas contained shales: ,.,/ Samples Req'd: es C~ No Mud Log Req'd: ^~ es It7 No _ ;~ f~ HZS Measures: ~ Yes ^ No Directional Survey Req'd: ®Yes ^ No Other: ~~ ~ ~ ~S ~ \~v ~ "~rc~'~ APPROVED BY THE COMMISSION ~~ Date ,COMMISSIONER Form 10-401 Revised 2/2005 ~ A ~ ~ ~ ~ f Submit In Duplicate O ~ ~` by To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Abby Higbie, CTD Engineer Date: March 21, 2008 Re: Prudhoe Bay K-20C Permit to Drill Request • The sidetrack, K-20C, is scheduled to be drilled by Nordic 1 around June 1. The plan calls for a slimhole lateral with a slotted liner. Pre-Rig Work: The pre CTD work is slated to begin on April 1, 2008. 1. F MIT-IA, -OA 2. S Dummy GLV's #3 and #4 3. C Pull 4.5" HYD KB packer w/4" S Profile (ID = 2.56") 4. C Set Cement Retainer ate" " ~\'~~~ ~ ,~r Sv~~ ~C~6_ 1 ~ ~j 5. C Pump cement job, 3.5 bbls 6. C Whipstock drift down top of cement retainer 7. W PPPOT-IC, -T; LDS 8. W PT MV, SV, WV 9. O Blind and bleed lines, remove well house, level pad Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high 2. Set Baker 3-3/16"x 4-1/2" TT whipstock lowside at 11,472' 3. Mi112.74" window at 11,472 and 10' of openhole. Swap the well to Flo-Pro. 4. Drill Build: 3" OH, 710' (15 deg/ 100 planned) ~ ~ ~ 5. Drill Lateral: 3" OH, 858' horizontal (12 deg/100 planned) _ 6. Run 2 3/8" slotted liner leaving TOL 1 joint inside the window at 11,442' ~ ~t ~ `~ 7. Perforate the old 3-3/16" liner above the new slotted liner at 11,080-11,370' 8. Freeze protect well, Set BPV, RDMO Post-Rig Work 1. Install GLV, Set Baker patch 2. Install well house. Hook up flow line. Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • 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. Hole size: 3" Casing Program: • 2 3/8", 4.7# , L-80, STL connection Slotted liner - 11,442' to TD Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 92 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 17500' • Distance to nearest well within pool - 2100' ft to K-16AL1 Anticollision Summary W'v~b~ • K-20: -209.6' ctr-ctr, Status: s~i'in ~7 ~ ~. '~ • K-20A: -267.3' ctr-ctr, Status: m '~~'P. T'n • K-20B: -267.29' ctr-ctr, Status: s m; the well K-20C kicks out of --mot p~:~hs~c~ F ~~~ ~~ Logging ~ • MWD directional and Gamma Ray will be run over all of the open hole section. ~~~ Hazards • The maximum recorded H2S level on G pad is 25 ppm on K-16AL1 (1/13/2006) • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 3,283 psi at 8,800'ss (7.17 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2403 psi. Abby Higbie CTD Drilling Engineer 564-5480 CC: Well File Sondra Stewman/T'errie Hubble TREE= 4-1/16" CNV WELLHEAD = FMC ACTUATOR= BAKER KB. ELEV = 52.13' BF. ELEV = 24.2' KOP = 4350' Max Angle = 97 @ 11965' Datum MD = NA Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, NT-80 BTC, ID = 9.950" Minimum ID = 2.440" @ 11568' 3-3/16" X 2-7/8" XO 4-1/2" HES X NIP, ID = 3.813" i7-5/8" X 4-1/2" TM/ HBBP-T PKR ID = 3.912" ~ 4-1/2" HES X NIP, ID = 3.813" 8924' H4-1/2" HES X NIP, MILLED ID = 3.8" BKR TIEBACK SLEEVE, ID =? ',4-1/2" TBG,12.6#, L-80 BUTT, ', .0152 bpf, ID = 3.958" 7-5/8" CSG, 29.7#, NT-95HS I NSCC, ID = 6.875" TOP OF WHIPSTOCK ~ 11500' BKR TORQUE MASTER PKR 11514' 4-1/2" BKR CIBP (08/19/00) 12030' PERFORATION SUMMARY REF LOG: MWD ON 12/07/02 ANGLEATTOPPERF: 97° @ 12015' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2" 4 12015 - 12175 O 12/08/02 2" 4 12330 - 12365 C 12/08/02 2" 4 12390 - 12410 C 12/08/02 2" 4 12440 - 12490 C 12/08/02 2" 4 12530 - 12550 C 12/08/02 2" 4 12590 - 12660 C 12/08/02 2" 4 12695 - 12715 C 12/08/02 2" 4 12730 - 12960 C 12/08/02 4-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" 1/2" HES X NIP, 10 = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3265 3261 2 TMPDX DOME BK 1/4" 09/15/07 3 5739 5599 38 TMPDX SO BK 5/16" 09/15/07 2 7633 7098 38 TMPDX DMY BK 0 08/20/01 1 8801 8027 38 TMPDX DMY BK 0 .08/20/01 8936' 4-1/2"WLEGw/MULESHOEGUIDE,ID=3.958" - ELMD TT NOT LOGG~ 8936' 7-5/8" X 4-1/2" BKR ZXP PKR ID = 5.50" $950' 7-5/8" X 4-1/2" BKR HMC HGR, ID = 4.875" 9900' 45 HYD KB PKR w / 4" GS PROFILE (07/27/07) 9917' 3.7" BKR DEPLOY SLV, ID = 3.0" 9935' 3-1/2" HOWCO XN NIP, ID = 2.750" 9936' 3-1/2" X 3-3/16" XO, ID = 2.786" 11504' 11510' MILLOUT WINDOW (K-20B) - 3-3/16" X 2-718" XO, ID = 2.440" 2-7/8" CIBP (8/7/05) 2680' 2-7/8" CIBP (3/18/05) 12740' FISH -CIBP 3-3/16" LNR, 6.2#, L-80, TCII, .0076 bpf, ID = 2.80" (PBTO ~- j 12971' 2-7/8" LNR 6.16#, L-80 S~- .0058 bpf, ID = 2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03/95 D-9 ORIGINAL COMPLEf10N 09/08/07 JPK/PJC GLV TVDCORRECTIONS 08/28/98 D-16 SIDETRACK (K-20A) 09/15/07 PJC WBS CORRECTIONS 12/09/02 JLM/KK CTD SIDETRACK (K-20B) 09/15/07 JLJ/PJC GLV GO 05131/O6 CO/DTM TRH CORRECTION (6/13/04) 03/29/07 SPF/PJC GLV GO 08/17/07 JMG PJC SET KP PKR (07127/07) PRUDHOE BAY UNfT WELL: K-20B PERMff No: s2022240 API No: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL & 4070' WEL BP 6cploration (Alaska) • K-zog TREE= 4-1/16"CMJ WELLHEAD = FMC ACTUATOR = BAKER KB. E1EV = 52.13' BF. ELEV = 24.2' KOP = 4350' Max Angle = 97 @ 11965' Datum MD = NA Datum TV D = 8800' SS 10-3/4" CSG, 45.5#, NT-80 BTC, ID = 9.950" Minimum ID =XXX" @XXX' XXX 8924' 1~4-1/2" HES X NIP, MILLED ID = 3.8" 14-1/2" HES X NIP,ID = 3.813" I BKR TIEBACK SLEEVE, ID =? 4-1/2" TBG,12.6#, L-80 BUTT, .0152 bpf, ID = 3.958" 7-5/8" CSG, 29.7#, NT-95HS NSCC, ID = 6.875" ~` O 8936' 4-1/2" WLEG w /MULESHOE GUIDE, ID = 3.958" ELMD TT NOT LOGGED 8936' 7-5/8" X 4-1/2" BKR ZXP PKR, ID = 5.50" 8950' 7-5/8" X 4-1/2" BKR HMC HGR, ID = 4.875" 14-1/2" HES X NIP, ID = 3.813" I 4-1/2" HES X NIP,ID = 3.813" 7-5/8" X 4-112" TM/ HBBRT PKR, ID = 3.912" 45 HYD KB PKRw/ 4" GS PROFILE (07/27/07) ID=2.56" TO BE PULLED 9917' --13.7" BKR DEPLOY SLV, ID = 3.0" 9935' 3-1/2" HOWCO XN NIP, ID = 2.750" 9936' 3-1/2" X 3-3/16" XO, ID = 2.786" 3 3/16" LINER PER SCMT I~ 10304' Cement Retainer I~ 1 4-1/2" LNR, 12.6#, L-80 NSCT, ~ .0152 bpf, ID = 3.958" 13108' 11504 abbv PERFORATION SUMMARY ~~ REF LOG: MWD ON 12/07/02 O ANGLE AT TOP PERF: 97° @ 12015' ~ Note: Refer to Production DB for historical pert data 2" 4 12015-12175 O 12/08/02 2" 4 12330-12960 C 12/08/02 10290-11430 S? K-20A 2-7/8" LNR, 6.16#, L-80 STL, 130 .0058 bpf, ID = 2.441" PERFS U 11442' -j2 3/8" TOP OF LINER (1jt lap) I 1 11472' TOP 3 3/16" WHIPSTOCK 3-3116" LNR, 6.2#, L-80, 11568' TCII, .0076 bpf, ID = 2.80" ` , ~ K-20C 2-3/8" LNR, 4.7#, L-80 STL, 0.00387BPF, ID=1.995" 13040' K-20B DATE REV BY COMMENTS DATE REV BY COMMENTS 06/03/95 D-9 ORIGINAL COMPLETION 09/08/07 JPK/PJC GLV TVD CORRECTIONS 08/28/98 D-16 SIDETRACK(K-20A) 09/15/07 PJC WBSCORRECTIONS 12/09/02 JLM/KK CTD SIDETRACK (K-206) 09/15/07 JLJ/PJC GLV GO 05/31/06 CO/DTM TREE CORRECTION (6/13104) 03/29/07 SPF/PJC GLV GO 08/17/07 JMG PJC SET KP PKR (07/27107) PRUDHOE BAY UNfr WELL: K-208 PERMIT No: F2022240 API No: 50-029-22555-02 SEC 4, T11 N, R14E, 3251' NSL 8~ 4070' WEL BP Exploration (Alaska) ~ K-20C Proposed CTD Sidetrack ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3265 3261 2 TMPDX DOME BK 1/4" 09/15/07 3 5739 5599 38 TMPDX SO BK 5/16" 09/15/07 2 7633 7098 38 TMPDX DMY BK 0 08/20/01 1 8801 8027 38 TMPDX DMY BK 0 08/20/01 GAS LIFT MANDRELS by ~ BP Alaska Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Dater 2/19/2008 Time: 10:49:55 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: K-20, True North Site: PB K Pad Vertical (TVD) Reference: K-20A 52.1 Well: K-20 Section (VS) Reference: Well (O.OON,O.OOE,95.OOAzi) Wellpath: Plan 7, K-20C Survey Calculation Method: Minimum Curvature Db: Oracle Field: Prudhoe Bay ~ North Slope ~~ UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre I, Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 I~ Site: PB K Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5973161. 33 ft Latitude: 70 19 57.435 N From: Map Easting: 670342. 10 ft Longitude: 148 37 5.245 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.30 deg J -- - --- - Well: K-20 Slot Name: I K-20 ', Well Position: +N/-S 2004.90 ft Northing: 5975192. 46 ft Latitude: 70 20 17.152 N +E/-W 1184.03 ft Easting : 671480. 22 ft Longitude: 148 36 30.663 W Position Uncertainty: 0.00 ft Wellpath: Plan 7, K-20C Drilled From: K-20A 500292255503 Tie-on Depth: 11 469.95 ft I Current Datum: K-20A Height 52. 13 ft Above System Datum: Mean Sea Level ~ Magnetic Data: 1/9/2008 Declination: 23.48 deg Field Strength: 57670 nT Mag Dip Angle: 80.95 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 27.93 0.00 0.00 95.00 Plan: Plan #7 Date Composed: 1/9/2 008 copy Mary's plan 7 Version: 6 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <--- Latitude ---> <-- Longitude --> ' Name Description TVD +N/-S +E!-W Northing Easting Deg Min Sec Deg Min Sec Dir. Dip. ft ft ft ft ft .... ~ ' K-20C Polygon 52.13 -4785.83 78.37 5970410.00 671668.00 70 19 30.084 N 148 36 28.375 W -Polygon 1 52.13 -4785.83 78.37 5970410.00 671668.00 70 19 30.084 N 148 36 28.375 W -Polygon 2 52.13 -4851.93 81.86 5970344.00 671673.00 70 19 29.434 N 148 36 28.273 W ', -Polygon 3 52.13 -4915.66 331.48 5970286.00 671924.00 70 19 28.807 N 148 36 20.987 W ~ -Polygon 4 52.13 -4996.44 1458.00 5970231.00 673052.00 70 19 28.011 N 148 35 48.107 W -Polygon 5 52.13 -4575.76 1346.59 5970649.00 672931.00 70 19 32.149 N 148 35 51.356 W i K-20C Fault 1 52.13 -2572.23 3189.01 5972694.00 674727.00 70 19 51.848 N 148 34 57.553 W -Polygon 1 52.13 -2572.23 3189.01 5972694.00 674727.00 70 19 51.848 N 148 34 57.553 W -Polygon 2 52.13 -3583.52 2793.75 5971674.00 674355.00 70 19 41.904 N 148 35 9.104 W -Polygon 3 52.13 -4188.64 2483.81 5971062.00 674059.00 70 19 35.953 N 148 35 18.158 W -Polygon 4 52.1.3 -5025.26 1668.41 5970207.00 673263.00 70 19 27.728 N 148 35 41.965 W -Polygon 5 52.13 -4188.64 2483.81 5971062.00 674059.00 70 19 35.953 N 148 35 18.158 W -Polygon 6 52.13 -3583.52 2793.75 5971674.00 674355.00 70 19 41.904 N 148 35 9.104 W i ~ K-20C Fault 2 52.13 -5534.70 1111.58 5969685.00 672718.00 70 19 22.718 N 148 35 58.220 W i -Polygon 1 52.13 -5534.70 1111.58 5969685.00 672718.00 70 19 22.718 N 148 35 58.220 W i t -Polygon 2 52.13 -5260.09 1876.11 5969977.00 673476.00 70 19 25.418 N 148 35 35.905 W K-20C Fault 3 52.13 -4119.96 1493.06 5971108.00 673067.00 70 19 36.631 N 148 35 47.078 W ~ -Polygon 1 52.13 -4119.96 1493.06 5971108.00 673067.00 70 19 36.631 N 148 35 47.078 W -Polygon 2 52.13 -4398.37 1288.62 5970825.00 672869.00 70 19 33.894 N 148 35 53.047 W K-20C Fault 5 52.13 -3797.44 31.95 5971397.00 671599.00 70 19 39.805 N 148 36 29.730 W ', -Polygon 1 52.13 -3797.44 31.95 5971397.00 671599.00 70 19 39.805 N 148 36 29.730 W 'i -Polygon 2 52.13 -4803.40 146.99 5970394.00 671737.00 70 19 29.911 N 148 36 26.372 W K-20C Fault 7 52.13 -3954.60 823.62 5971258.00 672394.00 70 19 38.259 N 148 36 6.620 W BP Alaska ~' by Baker Hughes INTEQ Planning Report INTEQ ~ Company: BP Amoco Date: __ 2/19/2008 Time: __ 10:49:55 Page: 2 Field: Prudhoe Bay Co-ordioate(NE) Reference: Well: K-20, True North Site: PB K Pad Vertical (TVD) Reference: K-20A 52.1 Weil: K-20 Section (VS) Reference: Well (O.OON,O.OOE,95.O OAzi) Welipa[h: Plan 7, K-20C Survey Calculation Method: Mi nimum Curvature Db: Oracle Targets -- Map Map <--- Latitude ---> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Mi n Sec Dip. Dir. ft ft ft ft ft -Polygon 1 52.13 -3954.60 823.62 5971258.00 672394.00 70 19 38.259 N 148 36 6.620 W -Polygon 2 52.13 -4380.19 799.88 5970832.00 672380.00 70 19 34.073 N 148 36 7.314 W ', K-20C Fault 6 52.13 -3754.96 580.10 5971452.00 672146.00 70 19 40.222 N 148 36 13.728 W ~' -Polygon 1 52.13 -3754.96 580.10 5971452.00 672146.00 70 19 40.222 N 148 36 13.728 W -Polygon 2 52.13 -4542.79 474.05 5970662.00 672058.00 70 19 32.474 N 148. 36 16.825 W K-20C Fault 4 52.13 -4105.57 -2984.08 5971020.00 668591.00 70 19 36.768 N 148 37 57.772 W ' -Polygon 1 52.13 -4105.57 -2984.08 5971020.00 668591.00 70 19 36.768 N 148 37 57.772 W -Polygon 2 52.13 -4558.18 -2308.21 5970583.00 669277.00 70 19 32.320 N 148 37 38.038 W -Polygon 3 52.13 -5209.13 -1619.87 5969948.00 669980.00 70 19 25.919 N 148 37 17.941 W I i -Polygon 4 52.13 -5428.53 886.93 5969786.00 672491.00 70 19 23.763 N 148 36 ~ 4.776 W -Polygon 5 52.13 -6624.90 2198.01 5968620.00 673829.00 70 19 11.994 N 148 35 26.521 W -Polygon 6 52.13 -6892.62 2663.04 5968363.00 674300.00 70 19 9.359 N 148 35 12.954 W -Polygon 7 52.13 -6624.90 2198.01 5968620.00 673829.00 70 19 11.994 N 148 35 26.521 W -Polygon 8 52.13 -5428.53 886.93 5969786.00 672491.00 70 19 23.763 N 148 36 4.776 W -Polygon 9 52.13 -5209.13 -1619.87 5969948.00 669980.00 70 19 25.919 N 148 37 17.941 W -Polygon 10 52.13 -4558.18 -2308.21 5970583.00 669277.00 70 19 32.320 N 148 37 38.038 W K-20C Target 2 8757.13 -4880.71 1383.63 5970345.00 672975.00 70 19 29.150 N 148 35 50.277 W K-20C Target 1 8777.13 -4791.39 540.39 5970415.00 672130.00 70 19 30.029 N 148 36 i 14.889 W Annotation _ _ _ _ _ __ - MD ._.TVD. _ _ ft ft _ _ __ 11469.95 8789.77 TIP 11472.00 8789.71 KOP 11492.00 8789.43 End of 9 Deg/100' DLS 11522.00 8790.50 4 11612.00 8793.11 5 11732.00 8791.71 6 11832.00 8789.69 7 111962.00 8785.23 8 12067.00 8781.19 9 12182.00 8776.94 End of 15 Deg/100' DLS 12432.00 8768.39 11 ', 12632.00 8763.09 12 12812.00 8759.94 00 8757 02 13 TD . 113040. _ _ _ 1 Plan Section Information _ '~ MD iuci Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg I_ _ 11469.95 91.70 - - 146.56 - _ 8789.77 __- -4662.97 _ -84.36 - - _ - _ 0.00 0.00 0.00 _ 0.00 i~ 11472.00 91.70 146.24 8789.71 -4664.68 -83.23 15.60 0.00 -15.61 270.01 11492.00 89.90 146.24 8789.43 -4681.30 -72.12 9.00 -9.00 0.00 180.00 i 11522.00 86.00 143.99 8790.50 -4705.89 -54.98 15.00 -12.99 -7.51 210.00 11612.00 90.68 131.31 8793.11 -4772.21 5.50 15.00 5.20 -14.08 290.00 11732.00 90.65 113.31 8791.71 -4836.09 106.49 15.00 -0.03 -15.00 270.00 11832.00 91.66 98.34 8789.69 -4863.28 202.40 15.00 1.01 -14.97 274.00 11962.00 92.23 78.84 8785.23 -4860.11 331.66 15.00 0.44 -15.00 272.00 12067.00 92.15 63.08 8781.19 -4825.99 430.53 15.00 -0.08 -15.01 270.00 12182.00 92.05 80.34 8776.94 -4790.06 539.23 15.00 -0.08 15.01 90.00 12432.00 91.78 110.36 8768.39 -4813.08 785.16 12.00 -0.11 12.01 90.00 ', 12632.00 91.22 86.35 8763.09 -4841.92 981.53 12.00 -0.28 -12.00 269.00 12812.00 90.76 107.95 8759.94 -4864.20 1159.04 12.00 -0.25 12.00 91.00 j X13040.00 90.68 80.59 8757.02 -4881.02 1384.24 12.00 -0.04 -12.00 270.00 ' ~ BP Alaska by Baker Hughes INTEQ Planning Report °~ Company: BP Amoco Date: 2/19/2008 Time: 10:49:55 Page: 3 Field: Pru dhoe Bay Co-ordinate(NE) Reference: Well: K-20, True North Site: PB K Pad Vertical (TVD) Reference: K-20A 52.1 Wett: K-20 Section (VS) Reference: Well (O.OON,O.OOE,95.OOAzij Wellpath: Pla n 7, K-20C Survey Calculation Method: Minimum Curvature Db: Oracle Survev r- _ _ MD Incl Azim --- - SS TVD -_ _~ _ _ N/S _- E/W -- MapN MapE DLS VS TFO Tool ~ ft deg deg ft ft ft ft ft deg/100ft ft deg 11469.95 91.70 146.56 8737.64 -4662.97 -84.36 5970529.09 671502.51 0.00 322.36 0.00 MWD 11472.00 91.70 146.24 8737.58 -4664.68 -83.23 5970527.41 671503.69 15.60 323.64 270.01 MWD 11492.00 89.90 146.24 8737.30 -4681.30 -72.12 5970511.05 671515.17 9.00 336.16 180.00 MWD 11500.00 88.86 145.64 8737.39 -4687.93 -67.64 5970504.53 671519.80 15.00 341.20 210.00 MWD 11522.00 86.00 143.99 8738.37 -4705.89 -54.98 5970486.86 671532.87 15.00 355.38 210.01 MWD 11600.00 90.05 133.00 8741.06 -4764.16 -3.40 5970429.79 671585.77 15.00 411.84 290.00 MWD 11612.00 90.68 131.31 8740.98 -4772.21 5.50 5970421.94 671594.84 15.00 421.40 290.38 MWD 11700.00 90.66 118.11 8739.95 -4822.21 77.67 5970373.61 671668.13 15.00 497.66 270.00 MWD 11732.00 90.65 113.31 8739.58 -4836.09 106.49 5970360.40 671697.26 15.00 527.58 269.84 MWD 11800.00 91.35 103.13 8738.40 -4857.32 170.98 5970340.64 671762.22 15.00 593.68 274.00 MWD 11832.00 91.66 98.34 8737.56 -4863.28 202.40 5970335.40 671793.77 15.00 625.50 273.82 MWD I, 11900.00 91.99 88.14 8735.39 -4867.12 270.17 5970333.11 671861.60 15.00 693.34 272.00 MWD 11962.00 92.23 78.84 8733.10 -4860.11 331.66 5970341.53 671922.91 15.00 753.99 271.67 MWD 12000.00 92.22 73.14 8731.62 -4850.92 368.49 5970351.56 671959.51 15.00 789.87 270.00 MWD 12067.00 92.15 63.08 8729.06 -4825.99 430.53 5970377.90 672020.97 15.00 849.50 269.78 MWD ! . 12100.00 92.14 68.03 8727.82 -4812.34 460.54 5970392.23 672050.66 15.00 878.21 90.00 MWD ~, 12182.00 92.05 80.34 8724.81 -4790.06 539.23 5970416.31 672128.81 15.00 954.66 90.19 MWD 12200.00 92.05 82.50 8724.17 -4787.37 557.02 5970419.40 672146.53 12.00 972.15 90.00 MWD ~ 12300.00 91.99 94.51 8720.63 -4784.77 656.74 5970424.28 672246.16 12.00 1071.26 90.08 MWD 12400.00 91.84 106.51 8717.27 -4802.97 754.83 5970408.33 672344.63 12.00 1170.56 90.50 MWD 12432.00 91.78 110.36 8716.26 -4813.08 785.16 5970398.91 672375.19 12.00 1201.66 90.91 MWD 12500.00 91.62 102.19 8714.25 -4832.12 850.36 5970381.38 672440.79 12.00 1268.27 269.00 MWD ' 12600.00 91.32 90.19 8711.67 -4842.88 949.56 5970372.88 672540.21 12.00 1368.03 268.76 MWD 12632.00 91.22 86.35 8710.96 -4841.92 981.53 5970374.58 672572.15 12.00 1399.80 268.45 MWD 12700.00 91.06 94.51 8709.61 -4842.43 1049.46 5970375.61 672640.07 12.00 1467.51 91.00 MWD 12800.00 90.80 106.51 8707.98 -4860.65 1147.58 5970359.65 672738.58 12.00 1566.85 91.16 MWD 12812.00 90.76 107.95 8707.81 -4864.20 1159.04 5970356.36 672750.12 12.00 1578.58 91.36 MWD 12900.00 90.75 97.39 8706.65 -4883.48 1244.77 5970339.05 672836.26 12.00 1665.66 270.00 MWD 13000.00 90.70 85.39 8705.37 -4885.90 1344.55 5970338.91 672936.06 12.00 1765.27 269.86 MWD 13040.00 90.68 80.59 8704.89 -4881.02 1384.24 5970344.70 672975.62 12.00 1804.38 269.71 2 3/8" LEGEND ' aoa^rx ~ BP Alaska ~'i~i K.zD,K-zD) ~ a .av,~~, - K-20 (K-20A) BAKER __ K-so a-2D61 ~nneN~a~ z1.~ wELVATn oEruL9 B1B ^dABJl~ hy~ - K-20 (K-20P61) io"~ ~_,iaci i~.io~m fr~BYYVVBB77ii uF(_J Plan ], K-20C Plan a7 suo~ad~q~~ m .. ;~pu,,,o2 INTEQ n~r~am~e Ema~°,~~m°~aa, ~m .o°~ ~~„ Tb en 11b9.99 Ic 1 Ka. wt.w,. K u.12n v.9.euoo o iii ~Fl-w .r~w.~TZrO K.20C Fault B en918 .~ 9s.oo• o.ao o.ao n.92 mo- ... REFERENCE NFORMAT ON -aw0- it ~ t _ ~ - .. I ' __,. .. - 1N .. Go ad nale NIEI Relerence We Cenlre.K30, True NOM ~ ~ ~ ~ ~ ~K-20G Fault? 1f.~. _ 1 ~ ~ - VeNCa 01 Reference System Mean Sea Lave ~ I ~~ Stt1 o0n (VS1 Reference 5 I0005000E1 I ' "_~ i I.. Mea a Oeptl Reference M30A 213 ~° IT ~ I-'-~ ~ - L - . +1 } • .. u ca cu al on Me nm nm,m CUrvewm - -~. - ~ h YY' " }T~ 9KS a' i ~ -- ~ ~ - - K•20G Fault 3 ~ ~ ~ wa 91.9 n. tti T~9.1 ~ ~ j - K-20 K-20B _ t t } 111rxu 9W 11w 1r ~ Tr19 r ui»v'ur nu 92a n~~1 xl~ 1 t K•20 KdOPB1 -_ 1x1,91x...1. 1..,. .I.r.1 «.,. :.x .,.~ ...9..9.. w. ... .,.... ..1e 1x..9. ,x.9 ,...a I . -+ -T": rt ~ 1 i. . I ~~ I ~ I I t `! -. r9 ~ KD An o~.1,en ~,r L5 ,~.w a a,~ ~ 1 ~ ,~ ~ ~. ~ 'ttr ~ r+i r ; t f ,: T, iiii a 11n2 as K•20G Tar a! 1 b200 Enda9oey199'DLS ~ ~ TIP sna iT iisxxm ~ L - ] < ins~s'~i iiiii 9~0 a "~ my i KOP ~. ~ f naT b 119x: m T yaon "~ rBO ° m End of 9 D 100' DL ^ naz to 1198:ro s Kzoc.a~smz .eea:'se i980~ 'va" nx9 m t2a9T ro 9 K:ac Ta~cM 1 m 9T2d s1121ex00 Eeda tso.ytoo•o1.9 iseao- ._, _. ^S _ ,-. L.. 11 K-20C TK st2 9716 M 12b2.00 t1 T - - - 1]10.98128]2.00 13 .3'.. _ ~ ^7 ~-' 9701 x1 txslz.m 12 =r~ I -... ~--~..... 13 .>w 99 twb.o9 TD ; I © <. _...-^ u , t2 'a°o ~~ } t - - End of 75 D 100' DL - Plan 7 K-20C - j;1 II •~- IIII ~1 ~ i I soax .- ~) i ~ 1 .. K-20 K-20 r~_ 51 ]] + } I I i+} rt rr-- f +~ i it~r .t ~ -,: t ~ t .. `t I* _ .. .. e ~'.f t t~ tt I ' I-- I I - - ~. K-20 K-20A .- r sloe I y+ ~ ~~. ~- ewe I Y 1~ t~`~ T~t.. { {. ~ ~ . r. PlanT K-20G. _ f i rt t t I 1 ~' r I I t t.., ~-yr . I 1 i K-20C Fault 2 i 1 ~~ soo - ; I + ,' ~' ). 1 ~T'TTTT'~T,~-r^~~ r~TT}rrrr}~-r rrr ~ ~ -.~-~ Tf-.-.~-*-tsaa~T m eao ~ ~aa f •r, Tao m - r~~-+ gym.-.T,~-rr. I t ~- I,T ~ r ~ >oo ~ ~ .~ ~ ,~ ~ ~ „~ ,~n ,300 ,.oo , , a , o ,~ ~nn 1,W f .- 7TT r I '. ~ T •~ west(-)/Ea9tN1 [t oottnn) -_.-. -- ~ T y; 0 K-20 K30PD1 ~ ~~ ~ ~ ~ K-200 Ta 812 a et a _ ,..- "'--1--. - .. - 12 ~ Plan r K30C : . F ~ K20 K-20 G ._.-_.-__ 8.. .. ~^ .. .. ~` End of l8 -..100'DL \ 11 -..__ _,. .~_'_ ~ 0 i--~-h-~~~ su ~ i T r t I.. ^ ~ ~^ ~ ^ ^. 9 1 ~. -.. _... . K-z0 K30A e ~ u r na I n ~ _ ~ '-- rfr tIIi?- I '`~,~ K.zac r.re.x~ ,,, h'~ - i_-tl 1 ) ~1 I Ili 'r X11 1 L~I f~j i Ij-~_":I I tI.T~I- K~OPJ IEnd N0. ..100M ~rr1 1f r ~ ~.r r } t-I ) I~ I r, .. I ~~ ~1 ! ~ t ! ~~ I t+ I ~ ~ L x ~ - -. ._ ~ ~ f ,1 II7 ~ z - II I-I (.i I t l t' '~) `r{_ ._~ - _i t. -..-1 ~ , ~ T I t~t t.~~. ~~ , T+ ~" ~,, ~ ~ (.:f 1~~ r - r ~ f r f I-[fit t f~ - ~~ i+ ~ }~f = x~ L ~ , I 1 }. I T}_'. ~ ~_..' _. r~l 11.~ i- t )~ ~ ~rlr 1 -{~ : t ~ ICI ~ ~ {'. {,- f E ~~- •~~ ~ i {, ~ r-~~ ~ 121 } ~ ~~ ~ 1{ t a~a { I' _ err , 1 t f ' = ~: ` . ~ ~-+ ~~ F F1 ,I t , ~' `+ t I ~ I Y ~~ ~ _ . ..:` ~~ ~~i I ~ ~ t ;.- t } a ~ 7 r t ~ I . t ! • • ` ' f ~I t * I j `"++ 7 f . ' r 1 ~ ~ r ~ i-It C~ I~ ~ F .,. I I ~ ~ I I ~ I. t -~i~~-rr~ ~-'t-„,-rT;r{Trrr I j ;,,~ri~_, ~ ,~`TT,~ ,~~ mT Ti~~` a~ sx ,50 ~ ~ ~ M~ aax .5~ soo 5~ ~ ~ >an ,sn aoo esn ~,, ~ ,~, ,e „a ,ate ,R,n ,sw ,tea ~ ~ ,~ ,xsa ~ z,~e ven~~al seoemn ae es.oo•,sowln) i 4'~ LEGEND T Plan: Plan #7 (K-20/Plan 7, K-20C) M Created By: BP Date: 2/1912008 BP A~aSka -'-'- K-05 K-05A) ~~~ - K-05 K-0SC) AximuUS to True NOM K-14 K-14) ~~/~ Magnelk NOM:2649° Check9tl: Dale: K-14 K-14A) B/11~s~ agur0 _- - K-16 (K-1fi) n M Fie10 WELIPITN DETIIIa K-1fi (PIaNtS K-18AL2) ~~R r Svengrh. 57870nT K-20 (K-20) Dip Angle: 8095' Cnnldcl lnfwmanon ~In~T~K 900 K-20 (K-20A) Dare- tl9/2008 B I MinJrbleo 66606 K-20 (K-20B) Matlal: 6ggm200] ... n.lrwar: K-20 (K-20PB1) NTEQ 1 ]l , TI9 an K0: 33489.95 Plan """!!/ K-20C i ~e, ~ Plan #! qif Ic , Rn1. DaNw: 1[.i0ap1 OS.]]H V.Nclian O 9J ~FI-W FrviniTVD Male r0 9s.oD• Oa0 aaD n.9] REFERENCE INFORMATION Coartlinale (N/E) Reference: Well Centre: K-20, True North Vertical (ND Reference: K-20A 52 13 Section (VS Reference: Slat- (O.OON,O.OOE) Measuretl Depth Reference: K-20A 52.13 Calculation Meihotl- Minimum Curvature MO Me MI TVD BEOTwi DETM F9W Dip TFeu V898 TerOnl 83.]0 148.38 J4.M 0.00 0.00 O 91.]0 14634 Ja1a 33.b 9T ].00 89.90 ~ •BB]30 -19.12 ~ ~13b23.00 • 00 14].89 6190.50 1TO3AB 00 910.00 633.]8 0 90:81 1N.]3 6.30 13:00 990.00 3 11]]200 b 1]31 9]81.13 .WBA9 33].38 Baz.oD 9tiaea 3w.a+ ~aea3a zoz:w aii]s ea.oe i3s:ao no.oD Iw.b 99.05 36916 412A0 11.18 ]10:]8 ]83.18 32A0 Y0:00 9,.u ~iABi 9e,.b ,zAO m9.b ii iisiAO 90.16 ] ien'ai i1e43o ,1a9A4 uAD i]aia.w -3900__ i _.. .. :6400 ~. . - I ', 6450 i :t~$ti~ '-i-~}ii t 1 -F:,. t r~ r -T ~ r~ ~ ( 1 r . _ r • ~ ~. ~} _ 8500 ~ ~ `r' if, , { 6550 } . I I 7{ T Trf f r } 8850 ~ K•20 K-200 Ir 1: {. It rti TT 1r-• -r~tr_ +r r '6750 i .: '~ ) j~, ~I 6800/ , 1 r L 1 { 1 I~~ ~ 1 ~ «1 r I '8850 ~. ~ ti } l _.. I `r ~ t K-20 K.20PB, -T rC ~ E. ~y~ ~ I~( 8750 16950 .. II :{~' F ~ .. r I C 8750 `7000 / __ 1~. I_ r ~ tl i rlr i a 7050 % I I t ~r l- r ~ l_ r~ i 8750 .. O 7100 T I I I) _{ t- C. p I ~ r a-7 .'... ~ ,.. 17,56 1 ~ - ~, rl ~} 4~~ T + -17200 __ I }1 i 1 r { 11~ ~ j _ ~ 7250 ^i'- -~ 1 Iti r `. ~ r~. t t ~r t ,. _. ~ is-. '',~7~~ *: (Tr-r ~rtt )_i1 rl~; ~I~~ I~, 7 ~ {~i4oo v1.D 7 K-toe a75o ~ I L 17 r r ~ t l ... l ~ ~~ }r { ~_~~ ~-r{ 1 1f + r {f rr M _ 7a5~, _ T` T r i I H K-20 K-20 it 7500 \\` ~-•Y I ~ T Y I +t ~ `: I +' ~ ~ i , 7550 T r 17600 i. _,. - 1~ -+# F +_ Z}t _. i ~ .r _ -5200. t 17650 ~. I __ ~ _ _ _ ~ _ 1 i -,'~+ {- r -F ~ ~- r}j r - 775D K-20 K-20A rT1 r -5300. _. ...... ..... .. :. I ~-Y F l~1 +.r '-I I 7eoo ~ i I j t{ F t-~ 'r~Tr ~+ l i f T~ ,{ r{ I I ~ I -rte ~ 78 :. I ' -' - t --~i ` I L - E ( -a F Ta I 1 I Ti-~ r r t i79oD {T -1~ )~ ~- $~ I -swo _ f +r-t }.. :-.I~r.~:.-1 il' t -i r~r. l"~=r.~.T !~:~~r -.. ~~~ .. I 'I >- 1+~ ~1 r I T ~' r Try ~{ril_ I ,r rl 1 -5600. - r- .:.. l ... _.. .. ._ _ _... 18050 .. ....: (._ _. :. I. 8,00 T I I _ _ I . _ , , K•14 K•19A I _ rTr ~ ~ rTT -r -r • rr rTrr~rri~f-r - l -,T -rrr r .-...:-. - ~.., i~ ri'rri-T T r K.16 K.16 ` -r -5700- ~ ~ ~ I ~r }'r^ ~ I "T f ~ ^ i r i ). i., I ..... I -9 T -7 r1Trr TrT 300 - 00 -100 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 250 1000 00 -800 00 -6W 500 400 0 2600 2700 2800 2900 West(-)/East(+) [100ft/in] = I ~ ~# 7 rr i . ~ t i ~~~~ f 00 I { ( Ttr ~ TI ~ I _ 10 _ ' ~) r }- ~ I ~ 1 I 1 - 4200. _ 1 '~ - ' I 1- Y _ - - ~ t r _ - r r - - ~ 4300 t , I I 1.. .. ~ r Y i 1 ~ -. y _ ii 400 - h, 1 r.- _~ -I_ ~t I 4500 ~ i' t ,-~ -t ~ r F _ II i +L ~r 460o- _ ~ i ~ ~ ii- ' r ~ i J1 i I tt._ 4700-~ i 1 { _ I i t - y i T I 4800 - _ J. ~~~ I ~T i_ I tr~ I*..r. r ~r{ 1~ 4so 1 I ~ I r 5000- i ~'~ I ~ T _ YT T ~ T ~_ 1 - { -( ~ F ~ { r ~1 't+ "~ 5100 $ t ~.. ~ r I.. r~ i I .1__. 1~ Y1 f - T.? t~ 4 4 4 - ._ ~-.: u • rements are i N (n bag .- .- BAG Dowell 2" combi pipe/slips of bag of slips Blind/Shears 1 TOTs Mud Cross I I Mud Cross of flow cross of blind/shears 2 3/$" combi pipe/slip TOTs of pipe/slips 2" combi pipe/slips Swab Valv Flow Tee 5950000 5900000 • Alaska Department of Natural Resources Land Administration System • ~- ~~, ~,3:;: ~ -.. _ .: _ _ ~ .~ ~ __- ~ ~carcler`s S~~~r;h State Gabins Page 1 of 2 a r File Type: ADS File Number: „ w ry28303~ ~ Printable Case File. _$ummary. See Township, Range, Section and Acreage? ; New Search ~` Yes ~`' No _~ _...w _..._ W _ __ _ ~~ i_AS Men`.a I Case Abstract I Case Detail I Lanri Abstract 1~'rle: AllL ZS303 Search for Status Flat U~~dat^~. ~s cif O=t 1)?%~UQ$ Custoh~er: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- . ALASKA ANCHORAGE AK 995 1 966 12 Case Type: ~~~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/1/1965 TotalAcres: 2560.000 Date Initiated: 05/28/1965 Once of Prinurry Responsibilitt~: DOG DIV OIL AND GAS ~,ast Tf~ansaction Date: 12/04/2006 Case Subtype: ~t NORTH SLOPE Last Ti•unsaction: AA-NRB ASSIGNMENT APPROVED Mericdran.~ l 7~nvnsJtip: O L ~N l~~ur,~r: 01 X41: ,section: 0~ 5'~~clion ,lrr~c~.~: (~=l(_1 Search Plats 1lleridiu~z.~ t_' 7rn>>nship: O1 I N Rurt,~e: O l ~1 F, S'~ c~r~,n.~ U~ Section _-I c~~t~,~: 6~0 Me~•iclian: ~! %~ou~il.~~lrr~~: O l I ~,` Ku~i,c~.~ 01 X41 ; S'rc~lion.~ 0~> Section ~Icrc~s: 6=10 Met^idiara: L! 1 o~rnshi~~: O L f ~,' l~~nr~~ : O l -11~: ,tiectiora: I U Section :1~:rc•s: 6=-10 LE~aI Ucscription 0~ -28-196 * * * SALE NOTICE LEGAL DESCRIPTION* C1=t-1?~ IIN 1 ~E U11~13, ~l, 9,10 ?~ 60.00 U- 3- 7 t°C.~ tP SE a1" Last updated on 04/02/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28303 &... 4/2/2008 ~ -Alaska Department of Natural Resources Land Administration System Page 2 of 2 • • Not sure who to contact? Have a question about DNR? Visit the uiie Inforrrsaton Center. Report technical problems with this page to the ~lebaster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all C3}~IE=S must be accepted. State of Alaska Natural Resources LAS Home Copyright Priuacy System_Sfatus http://www. dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28303 &... 4/2/2008 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME /~,~~ /~ ~C>~ PTD# o~®~py~9~ / Development Service Exploratory Stratigraphic Test Non-Conventional Well ~ \ ti FIELD: ~.~1/O~E' ~y ~~z,D POOL: ~,C~/>~/~' ,~t~~ ~OOL Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Comuany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comuany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/11/2008 WELL PER~l1T CF#ECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL • 640150 Well Nama; PRUDHOE BAY UNIT K-20C Program DEV Well bwe seg ^ PTD#:2080490 Company ~ EXPLORATION (ALAS ) INC Initial ClassRype DE V! PEND GeoArea 890 Unit 11fi50 On10ff Shore Qn Annular Disposal ^ Administratian ~ 1 Pemlitfeeattached----- - ----- ----- - - - ---- ------- NA --- --- --- - - --- - - ---- ------- - --------- ---- 2 LsasenumbQrappropnate--- ------ ----- -_ --- - -- ---- Yes- - ---- - -- - - -- ----- -- - ------- -- - -- - 3 Uniqu®Hreltnameandnumbe[--- ----- ----- -- ~------Yes---- - ... -- --- ...------ --------- - - -- -- ----- -- 1 4 welUQCatedin_a_definedpool- ------- - --- -- -- -- -- Yes- ---PrudhoeBaYPOOt-- --- -- ------ ----- -- -- - -- ----- - 5 WeillQCatedpi'oPardistancefromdrillingunitbounda~y------------ ------------Yes--- ---------------------------------------------------------- - -- 6 -V~aIIIQeatedPrcPQrdistanoefromothsr~vslls--- - -- -- ------ --Yes--- - ---- - -- -- --- --- --- - - ---- -- - - ----- ~ 7 SufFicientacreageayailablein_dtihingunJt------------------- ------_.-_--Yes--- ---2560AOres-------_.-----_-.._--_-__-__-------_-.------------------- 8 If deviated,iswellboreWat_incl0.ded----- - --- - --- - -- --- -__Yes.- ---- -- -- -- - -- ----- -- -- --- - -- ----- ~ 9 Operataron~CaffectedParty----- ------- ------ ---- -- --- ---Yes-- --- - --- -- -~ - -- - ------------------ - -- - ------ ~ 10 Opa[atorbaa-apprApriatebondnJorCa--------------------- ------------Yes---- ---61ank®i@ond#6194193----------------..---------.--------.--.------------ ~ 11 PermitcanbeissuadwlthQutconsenlationarder- -- --- --~ -- --- ------ Yes---- ---- -- -- --- -- - ~---- ------------- -- -- - -- --~---------- Appr Date X 12 Pe[mltaanbeiasuestwitbQUtadministtati+~e-apPreval------------- ------------Yes---- ---------------.------------------------------~-------------------- - - ACS 41212008 I 13 Canpermi#bsaPProvedt~sforo15-daywak--- - -- ------ - ------------Yes---- -- ---- --- -- ---- --------...----- --- -- ---------- --- --------- ~ 14 1NelllocatedwJthinareaandstrataauthorizedby-Injection9rde[#(putl9~ in_comments)_(For__IVA---- -----------------------_---_---_---.--_---_----__------------_-.-_--.- I 15 A)IwelJs_within1(4-mile_afea-o}teyig+wide[~iifiad(fo[flenciceweUon~!)--- ------------NA----- ---------------------------------------------------------------- ------ I 16 P1e•ProduoedinJeaor,duration-oJP~Droduciion lessthan3montbs.(ForsQrvicawallonly)---NA----- ------------------------------------------------------------------ - -- 17 .NoliCOnVen,gas_c9nfonnftoAS31A5:03QCG1.A)>G,2.A•Q) - --- ------- -~---- --- ---~--- ------ ------------------ -- -- -- --- ---- ------ Engineering 18 Conductor9t[inp.pmvldad----------------------------- -_------.--NA---- ---ConduGtorsetinK-20(195.055),.----------------.--.------..--.----....------- 19 Su[face_casing.ProtoctSallknownUSDWs------------------ -------------NA----- ---ABaquifersaxemPted~AEQ1.-----------------.----------.-------..----------- 20 GMTvoladaquatetooirculate_onognductor5$urf_csg_______---- ---------__NA-_--. -.-SurfaoeoasingsetinK-2Q._---.________--_--_--_.-----------------.---_----- 21 CMTvoladequatetotie•Ulongstringtosu[fosg---------------- -------------NA----- ---Productiortcasin9s@tin-K•20.---------------.----------.----------------------- ~22 CMT-wilJcovecall)mown-praductiveborizons------------------ -------------K°----- ---SloUedlinercomplationplanned~----..--------.--------...-.-------..----------. 23 Casing designs adequate fo[ C, L 6 8_permafrost- - - - --- - - - - - - - - - - --- - - - - - - - NA_ . - - _ - - _ Anginal well met design specificatiops. _ NA fo[ stoned liner._ _ - _ _ _ . - . - . _ - - _ .. - _ - - - - - _ - - . _ _ - - i24 Adequate tankage-or reserve pit - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - -Yes - - . - - . -Rig equipped with steel pits, NoJeserve ph Planrted,_ All waste-to aAProved disposal well(s), . - . - . - _ - - - _ - - ~25 Ita_re-drilGhes-a10~40~forabandonmentbeanaPRroved---------- -----------?'es---- ---308-105..---------_--------------------------------------.----------- 26 Adequate-welltzore separation-proposed- - - - - - - - -- - - - - - - - - - - - - -- - - - - - - - - -Yes - - _ - - ..Proximity analysis perfo[med, Nearest segment is abandoned portion of K~206 and paths diverge,- - . - . - _ - - - ~27 If-divetterrequUed,doesJtmeetregulattons------------------- -------__---htA----- ---SOPStaokwillalready.beinpiaoe~----.-..-------------------------.--.--------- Appr Date I28 Drilling 8uld program sohematic.l3<~quip list adequate- - - - -- - - - - - - - - - - - - - - - - - - -Yes - _ . - - _ -Maximum expected resfln<oirptessure 7.2 EMW. -MW_planned_8.8 ppg, _ _ _ - - - _ - - - - . - _ - - - _ - - _ _ - - - TEM 411012008 129 BOPEs,-do-theymeatragutation - - ---- ---- - -- - ---- Yes--- - --- ------ -- - ------ -------- -- ---- ----- ----- -------- 30 BOPE_prQSS [sting aPp[op[iate; test to_(pui psig in commants)- - - - - - - - - - - - - - - - - - - -Yes _ _ - . _ - - MASP calou}ated at 2403psi, 3500-Psi-t}OPtestplanned, - _ - - - - - . - .. - - - - - - _ - . - - - - - - - - _ . - - _ 131 Choke.manlfoldcomRlieswlAPI-RP-53 (May 84)-- ------ -- ------ Yea--- -- ---- -- -- - ------ -------- -- ------ -- -- -------- ~32 -UYorkwilt9ccu[wifh9uloparaionshutdown------------------- -----------Yes--- ---.------------------------------------------------------------------- 33 Is Presence of li2S gas probable - - - - - - - - - - - - - - - - - - _ _ - - - _ - - - _ - - - _ - _ _ No_ - - - _ - . - H2S on K pad_is tow._ Mud should preclude H2$ on_ ng, Rig has sensors and alarms.- _ _ _ _ _ - , - - - - _ - - - _ - 34 Mechanical_c~ndhlonofwellswBhinAORyerifiad(ForservicsweUonly)-- ------------ NA---- ------------------.---------------------------------------------------- Geology 35 Pem]it4anbeissUedwlohtrdrogen-sulfidemsasute$------------- -------------t~o___ ---_MaxH2$?G Pad=25ppmonK15AL1j1113106)__---_-------.-_-----.__------_---_- I36 Data-plesentedon potential °ve7Pressurazonas --- - -- -- ---- --~--- - - --- ----- ------ - -------- -- ------ --- --- - ------ - Appr Date 37 Seism~analysisafshaliowgaszcnes---------------------- -----____-- NA___ .-_---__---_---____-----_-------- --. . ACS 41212008 38 SeabedconditiDnsuNey-(ifoffsho[e)----------.---------- -------------NA--- 39 Coniactnamelphoneforyvaak_ty_prograssrepotls_(exploratoryonlyl----- -----------Yes--- ----AbbyHigbie-;;84-5489------------------------------------------------------ Geologic Commissioner: Eng~eedng Public. Date: Commissioner: Dat® ~ ~ ~ er Date ~70'UO p ~J 'yff ~~0 i • iNelt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~ ~ **** REEL HEADER **** MWD 08/10/02 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/06/09 2011705 O1 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!! ~!!!!~~!~ Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version I nformation VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 11028.0000: Starting Depth STOP.FT 12696.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: K-20C FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 20' 17.152"N 148 deg 36' 30.663"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 08 Jun 2008 API API NUMBER: 500292255503 Parameter Information Block #MNEM.UNIT Value Description SECT. 4 Section TOWN.N T11N Township RANG. R14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF DF Log Measured from FAPD.F 52.13 Feet Above Perm. Datum DMF DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 52.13 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. C~ (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and the MWD data will serve as the PDC (Primary Depth Control) log for this well per Doug Dortch with BP Exploration (Alaska), Inc. (8) Tied to K-20A at 11064 feet MD (8725.9 feet TVDSS). (9) K-20CPB1 was drilled from K-20A through a milled window in a 3 3/16 inch liner. Top of window 11477 ft.MD (8737.5 ft.TVDSS) Bottom of window 11483 ft.MD (8737.4 ft.TVDSS) (10) K-20C was drilled from K-20CPB1 with an open hole whipstock at 12010 ft MD (8728.9 ft TVDSS). (11) The interval from 12666 feet to 12696 feet MD (8704 feet to 8703 feet TVDSS) was not logged due to sensor to bit offset at well TD. (12) Runs 5 through 7 were logged on K-20CPB1. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 70 records... 14 bytes 132 bytes *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN K-20C 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN K-20C APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** ~~!!!!!!!!!!!~~!~!! Remark File Version 1.000 The data presented here is final and the MWD data will serve as the PDCL for this well per Doug Dortch with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 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: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 40 Tape File Start Depth = 11028.000000 Tape File End Depth = 12696.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 49 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU ----------------- WDFN K-20C.xtf LCC 150 CN BP Exploration (Alaska) WN K-20C APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!~!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 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: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 80 Tape File Start Depth = 11028.000000 Tape File End Depth = 12695.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 89 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes • **** TAPE TRAILER **** MWD 08/06/09 2011705 01 **** REEL TRAILER **** MWD 08/10/02 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes i Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 11028.0000 -999.2500 -999.2500 11028.5000 44.7000 -999.2500 11100.0000 35.8000 -999.2500 11200.0000 30.7000 -999.2500 11300.0000 41.0000 -999.2500 11400.0000 47.1000 -999.2500 11500.0000 81.3000 93.4000 11600.0000 60.1000 83.3000 11700.0000 93.7000 148.8000 11800.0000 84.7000 111.3000 11900.0000 64.5000 153.9000 12000.0000 55.8000 135.9000 12100.0000 91.0000 26.1000 12200.0000 75.5000 61.3000 12300.0000 119.3000 40.3000 12400.0000 80.4000 48.9000 12500.0000 60.9000 82.5000 12600.0000 111.3000 110.7000 12696.0000 -999.2500 -999.2500 Tape File Start Depth = 11028.000000 Tape File End Depth = 12696.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP 11028.0000 -999.2500 -999.2500 11028.2500 41.2000 -999.2500 11100.0000 35.8000 -999.2500 11200.0000 30.7000 -999.2500 11300.0000 41.0000 -999.2500 11400.0000 47.1000 -999.2500 11500.0000 81.3000 93.4000 11600.0000 60.1000 83.3000 11700.0000 93.7000 148.8000 11800.0000 84.7000 111.3000 11900.0000 64.5000 153.9000 12000.0000 55.8000 135.9000 12100.0000 91.0000 26.1000 12200.0000 75.5000 61.3000 12300.0000 119.3000 40.3000 12400.0000 80.4000 48.9000 12500.0000 60.9000 82.5000 12600.0000 111.3000 110.7000 12695.7500 -999.2500 -999.2500 Tape File Start Depth = 11028.000000 Tape File End Depth = 12695.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet L J Tape Subfile 4 is type: LIS 1 **** REEL HEADER **** MWD 08/10/06 BHI Ol LIS Customer Format Tape **** TAPE HEADER **** MWD 08/06/06 2011705 01 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 11028.0000: Starting Depth STOP.FT 12588.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: K-20CPB1 FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 20' 17.152"N 148 deg 36' 30.663"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 06 Jun 2008 API API NUMBER: 500292255571 Parameter Information Block 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 1 (1) All depths are Measured Depths (MD) unless otherwise noted. #MNEM.UNIT Value #--------- ------------------------- SECT. 4 TOWN.N T11N RANG. R14E PDAT. MSL EPD .F 0 LMF DF FAPD.F 52.13 DMF DF EKB .F 0 EDF .F 52.13 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks ~ ~ (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and the MWD data will serve as the PDC (Primary Depth Control) log for this well per Doug Dortch with BP Exploration (Alaska), Inc. (8) Tied to K-20A at 11469 feet MD (8737.6 feet TVDSS). (9) K-20CPB1 was drilled from K-20A through a milled window in a 3 3/16 inch liner. Top of window 11477 ft.MD (8737.5 ft.TVDSS) Bottom of window 11483 ft.MD (8737.4 ft.TVDSS) (10) The interval from 12553 feet to 12588 feet MD (8721.3 feet to 8724.2 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 68 records... Minimum record length: 14 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN K-20CPB1 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN K-20CPB1 APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and the MWD data will serve as the PDCL for this well per Doug Dortch with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 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: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 38 Tape File Start Depth = 11028.000000 Tape File End Depth = 12588.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 47 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN K-20CPBl.xtf • s LCC 150 CN BP Exploration (Alaska) WN K-20CPB1 APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!! " '!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 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: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 75 Tape File Start Depth = 11028.000000 Tape File End Depth = 12588.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 84 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/06/06 ~ ~ 2011705 O1 **** REEL TRAILER **** MWD 08/10/06 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 11028.0000 -999.2500 -999.2500 11028.5000 44.7000 -999.2500 11100.0000 35.8000 -999.2500 11200.0000 30.7000 -999.2500 11300.0000 41.0000 -999.2500 11400.0000 47.1000 -999.2500 11500.0000 81.3000 93.4000 11600.0000 60.1000 83.3000 11700.0000 93.7000 148.8000 11800.0000 84.7000 111.3000 11900.0000 64.5000 153.9000 12000.0000 55.8000 135.9000 12100.0000 92.2000 156.6000 12200.0000 117.0000 50.7000 12300.0000 116.5000 64.5000 12400.0000 100.1000 80.0000 12500.0000 86.0000 84.0000 12588.0000 -999.2500 167.0000 Tape File Start Depth = 11028.000000 Tape File End Depth = 12588.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP 11028.0000 -999.2500 -999.2500 11028.2500 41.2000 -999.2500 11100.0000 35.8000 -999.2500 11200.0000 30.7000 -999.2500 11300.0000 41.0000 -999.2500 11400.0000 47.1000 -999.2500 11500.0000 81.3000 93.4000 11600.0000 60.1000 83.3000 11700.0000 93.7000 148.8000 11800.0000 84.7000 111.3000 11900.0000 64.5000 153.9000 12000.0000 55.8000 135.9000 12100.0000 92.2000 156.6000 12200.0000 117.0000 50.7000 12300.0000 116.5000 64.5000 12400.0000 100.1000 80.0000 12500.0000 86.0000 84.0000 12588.0000 -999.2500 167.0000 Tape File Start Depth = 11028.000000 Tape File End Depth = 12588.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet i Tape Subfile 4 is type: LIS