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201-217
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU E-03A Pull WRP, Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-217 50-029-20181-01-00 13708 Conductor Surface Intermediate Liner Liner 9048 80 2815 11419 1497 1816 13640 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 9046 31 - 111 31 - 2846 30 - 11449 10983 - 12480 11892 - 13708 31 - 111 31 - 2846 30 - 8328 8103 - 8948 8581 - 9048 13627 520 2670 4760 7020 10530 None 1530 5380 6870 8160 10160 12730 - 13635 4-1/2" 12.6# L-80 27 - 12480 9034 - 9046 Structural 4-1/2" Baker HB Packer 10932 8077 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 0028299, 0028304 27 - 8948 N/A N/A 38 1731 3180 24921 17 164 1300 700 160 840 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 10932, 8077 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 1:14 pm, Jun 26, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.06.26 12:20:31 - 08'00' Torin Roschinger (4662) RBDMS JSB 062724 WCB 9-10-2024 DSR-6/26/24 ACTIVITY DATE SUMMARY 5/5/2024 ***WELL S/I ON ARRIVAL*** R/U SLICKLINE. ***CONTINUED ON 5-6-24*** 5/6/2024 ***WSR CONTINUED FROM 5-5-24*** RAN KJ, 3' x 1.875" R STEM, AND 10' x 1.75" PUMP BAILER. WORKED THROUGH 12,516' SLM, STALLED @ 12,599' SLM. ~ 2 CUPS HARD SCHMOO. RAN KJ, 2.20" CENT, AND 10' x 1.75" PUMP BAILER. STALLED @ 12,599' SLM (BAILER EMPTY). RAN KJ, 2.20" CENT, AND 5' x 1.75" PUMP BAILER. STALLED @ 12,612' SLM. RAN KJ, 2.20" CENT, AND 5' x 1.75" DD BAILER. STALLED @ 12,629' SLM. RAN 3' x 1-7/8" R STEM, KJ, 5' x 1.75" DRIVEDOWN BLR. TAGGED @ 12,781' SLM (BAILER EMPTY). RAN 3' x 1-7/8" R STEM, KJ, 5' x 1.75" PUMP BAILER. TAGGED @ 12,781' SLM (BAILER EMPTY). RAN 3' x 1-7/8" R STEM, KJ, 5' x 2.0" PUMP BAILER. UNABLETO WORK INTO LTP @ 11,588' SLM. RAN 3' x 1-7/8" R STEM, KJ, 5' x 2.0" PUMP BAILER W/ SALMON MOUTHED FLAPPER. TAGGED @ 12,781' SLM (~1 CUP OF MUD). T-BIRD ATTEMPTED TO LOAD TBG W/ CRUDE FOR B&F, LOCKED UP 3000 PSI @ 45 BBLS AWAY. RAN 3' x 1-7/8" R STEM, KJ, 5' x 2.0" PUMP BAILER TO 12,777' SLM (~1 cup sandy fill, 1 small piece of metal, and chunks of cement). RAN 3' x 1-7/8" R STEM, KJ, 5' x 2.0" PUMP BAILER TO 12,778' SLM ( BAILER EMPTY). ***CONTINUED ON 5-7-24*** 5/6/2024 T/IA/OA=2650/550/450 Assist slick line as directed. Pumped 45 bbls crude down TBG to attempt Load Well left in SL control upon departure FWHP's= 2500/1600/450 Daily Report of Well Operations PBU E-03A Daily Report of Well Operations PBU E-03A 5/7/2024 ***WSR CONTINUED FROM 5-6-24*** RAN KJ, 3' x 1.875" ROLLER, 2.20" CENT, 11" EXT, AND 1.75" LIB TO 12,778' SLM. 2 GOUGES FROM DEBRIS ON FACE OF LIB. RAN KJ, 3' x 1.5" STEM, 2.20" CENT, 11" EXT, AND 2.20" MAGNET. STALL AND UNABLE TO WORK DEEPER THAN 12,730' SLM. RAN KJ, 3' x 1.875" ROLLER STEM, AND 2.20" MAGNET. ABLE TO GET TO 12,780' SLM, NO RECOVERY RAN 3' x 1-7/8" R STEM (2.2" whls), KJ, 2.25" MULESHOE BOX TAP TO 12,781' SLM, NO RECOVERY RAN 3' x 1-7/8" R STEM (2.2" whls), KJ, 2.2' CENT, 11" EXT, 1.50" SERRATED AWL (.8" TO 1.42" serration range btm to top) TO 12,781' SLM, NO RECOVERY, 1.38" OD FLAT SPOT ON SERRATIONS RAN 3' x 1-7/8" R STEM (2.2" whls), KJ, 2" P-BLR, SALMON MOUTH FLAPPER TO 12,781' SLM, RECOVERED LESS THAN 1 CUP OF SOLIDS RAN 3' x 1-7/8" R STEM (2.2" whls), KJ, 2.2" CENT, POCKET BRUSH W/ 1.5" BRISTLES TO 12,781' SLM, NO RECOVERY RAN KJ, 2.25" P-BLR, RUBBER GETTER BTM, STALLED OUT @ 12,530' SLM RAN 3' x 1-7/8" R STEM (2.2" whls), KJ, 2-7/8" GR, BAITED 2" HYD BLR W/ 2.25" FLUTTER CAGE & RUBBER GETTER BTM, STALLED OUT @ 12,553' SLM. RAN 2 7/8" GR, 2 7/8" BAIT SUB, KJ, 3' x 1.875" ROLLER STEM, AND HARPOON W/ 4 1/2 SETS OF 1.65" BARBS TO 12,779' SLM (NO BITES). RAN 3' x 1.875" RS, KJ, AND 5' x 2" PUMP BAILER (SALMON MOUTH BOTTOM) TO 12,778' SLM. (~3/4 CUP OF SANDY FILL). RAN 3' x 1.875" ROLLER, AND 1.90" STAR BIT TO 12,778' SLM. WORKED ~30 MINS. ***CONTINUED ON 5-8-24*** 5/8/2024 ***WSR CONTINUED FROM 5-7-24*** RAN 3' x 1.875" ROLLER STEM, AND 10' x 1.75" PUMP BAILER TO 12,778' SLM. 1/4 CUP OF MUD. MAN DOWN DRILL W/ WSL. RAN KJ, 3' x 1.875" ROLLER, AND 2.25" MULESHOE BOX TAP. UNABLE TO WORK DEEPER THAN 12,590' SLM. ***WELL S/I ON DEPARTURE*** 5/8/2024 T/I/O = SSV/1500/750. No AL. PPPOT-IC (eval IAxOA). IC Void in cellar. Cellar 3'7" deep with an undetermined depth of ice. No alemite fitting on wellhead (has not been retrofitted), and may have internal check. McEvoy wellhead with two slotted bleeder screws and one 1" packing port. Unable to do PPPOT-IC at this time. SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:30 5/10/2024 T/I/O = SSV/1490/760. Temp = SI. Bleed IAP & OAP (pre Alemite install). No AL. IA FL & OA FL inconclusive. Bled IAP to OT to 0+ psi in 4 hrs. Bled OAP to BT to 0 psi in 5 hrs (gas). No monitor. Final WHPs = SSV/0+/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30 Daily Report of Well Operations PBU E-03A 5/11/2024 T/I/O = SSV/30/30. Temp = SI. Bleed IA/OA to 0 psi, remove internal check, install alemite. PPPOT-IC (eval IAxOA). Bled IAP to OT to 0 psi in 1.5 hrs. Bled OAP to BT to 0 psi in 1.5 hrs. Bled IC test port and packing port through slotted bleeder screws. Removed 1" plug on test port, removed internal check, and installed alemite fitting. Removed 1" plug from packing port, removed internal check and installed 5k 1/2" Hoke valve. Final WHPs = SSV/0/0. PPPOT-IC: Stung into IC test port (0 PSI). Increased void pressure to 3500 psi for 30 min test. First 15 min lost 200 psi, second 15 min lost 50 psi **PASS**. Bled void to 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 5/18/2024 LRS CTU 1, 1.5" Blue Coil. Job Objective: Fish WRP, Mill CIBP MIRU. Function test BOPs upon installation. Make up and RIH with 2.300" venturi with tattles. RIH and tag 12,802 CTMD. Venturi on the plug, stack 6K down. POOH. Tattle tale pins untouched. ***Job Continued on 5/19/24*** 5/19/2024 LRS CTU 1, 1.5" Blue Coil. Job Objective: Fish WRP, Mill CIBP ***Job continued from 5/18/24*** MU YJ milling assembly w/ venturi burn shoe 2.28". RIH and tag the WRP 12,805 CTMD. Mill for a bit and see WHP fall slowly. POOH to inspect venturi. OOH and have a core of cement in the burnshoe, and was completely plugged off. Make up new 2.300" shoe with 1.28" ID. Tag at 12814 CTMD and reciprocate venturi burnshoe. POOH to check tools. Lay down venturi and recover green cement. Perform weekly BOP test 250/4000. Passing test. MU YJ milling assembly and 2.33 burn shoe. RIH ***Job Continued 5/20/24*** 5/20/2024 LRS CTU 1, 1.5" Blue Coil. Job Objective: Fish WRP, Mill CIBP ***Job continued from 5/19/24*** RIH with YJ milling assembly and 2.33" Burn shoe. Tag WRP. 12815 CTMD. Burn over the WRP. POOH. Pressured up on the well to check for injectivity changed. No change. Pump 5 bbl math cap on the well. Burn shoe cable tattle tales bent around like we are over the fishing neck. RIH with 2.25" DJN and jars to try and equalize the WRP. Tagged down and fired jars multiple times. Pumped a gel sweep and chased to surface. OOH with nozzle and have good impression of shear stud in the center of the nozzle. Make up and RIH with baited, barbelled 2.875" WRP retrieval tool. Stack weight at 12817 CTMD. Begin jarring down. Never saw an indication of equalization. After the 7th jar hit down, PUH to re-cock jars and weight fell off. PUH clean. Able to RIH past set depth. Tagged at depth of next top shot down. POOH to check tools. No WHP response. No WRP, puling tool sheared out. Redress pulling tool with steel pin. RIH. Tag LTP 11,910 CTMD. Working into the liner. Tagged 12563 CTMD 3- 3/16" x 2-7/8" cross over. ***Job continued 5/21/24*** Tag WRP. 12815 CTMD. Burngyg over the WRP. POOH. Pressured up on the well to check for injectivity changed. No jyg change. Pump 5 bbl math cap on the well. Burn shoe cable tattle tales bent aroundg like we are over the fishing neck. RIH with 2.25" DJN and jars to try and equalize thegjy WRP. Tagged down and fired jars multiple times. Pumped a gel sweep and chased gg j g to surface. OOH with nozzle and have good impression of shear stud in the center ofg the nozzle. Make up and RIH with baited, barbelled 2.875" WRP retrieval tool. Stack weight at 12817 CTMD. Begin jarring down. Never saw an indication of equalization. ggjg After the 7th jar hit down, PUH to re-cock jars and weight fell off. PUH clean. Able to jjg RIH past set depth. Tagged at depth of next top shot down. POOH to check tools.gg No WHP response. No WRP, puling tool sheared out. Redress pulling tool with steel g g pin. RIH. Tag LTP 11,910 CTMD. Working into the liner. Tagged 12563 CTMD 3-g 3/16" x 2-7/8" cross over Daily Report of Well Operations PBU E-03A 5/21/2024 LRS CTU 1, 1.5" Blue Coil. Job Objective: Fish WRP, Mill CIBP ***Job continued from 5/20/24*** Working the latched WRP at the LTP 11910 CTMD, worked from LTP to 3-3/16 x 2- 7/8 cross over to see if the element was the issue. Sheared off 12,227. POOH. OOH and retrieval tool sheared. Re-pin (steel) and reconfigure bait with 2.35" centralizer directly above WRP retrieval tool. Could not make it into the LTP. POOH to re- configure. Bottom end of retrieval tool has an impression from the FN on the LTP. Make up and RIH with 2.125"shrouded WRP pulling tool. Tag the LTP 11,906 CTMD. Tried to work though. No success. POOH. Mule shoe damgaged. MU Venturi w/ yankee screwdriver and 2.3" shoe. RIH. ***Job continued 5/22/24*** 5/22/2024 LRS CTU 1, 1.5" Blue Coil. Job Objective: Fish WRP, Mill CIBP ***Job continued from 5/21/24*** RIH with venturi mule shoe 2.3" Ran clean throught he LTP. Ran venturi to 12,400 CTMD. Venturied up through the LTP. POOH. Freeze protect coil and well to 2500' with diesel. RDMO. ***Job incomplete*** 5/23/2024 ****WELL S/I ON ARRIVAL**** (Mill / underream) MULTIPLE ATTEMPTS TO FISH 2 7/8" WRP THROUGH LTP. ***CONTINUED ON 5/24/24 WSR*** 5/24/2024 ***CONTINUED FROM 5/23/24 WSR*** (Mill / underream) FISHED 2-7/8" WRP FROM 11,109' SLM(see log for pieces left in well) RAN MAGNETS TO DEVIATION IN ATTEMPT TO FISH PIECES OF WRP WITH NO SUCCESS. SET 3.813" X-LOCK, 4-1/2" DREAM CATCHER IN X-NIP @ 10,901' MD RAN 4-1/2" CHECK SET TO X-LOCK @ 10,901' MD ***WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 5/27/2024 T/I/O = 170/1450/150. Temp = 70°. TBG FL (Ops request). TBG FL @ near surface. Left for Ops to POP. SV, WV = C. SSV, MV = O. IA, OA = OTG. 5/27/2024 T/I/O = 1670/1700/210. Temp = SI. T & IA FL (ops request). PBGL installed on IA, 2" hardline SI. T FL @ 3002' ( sta #1 , SO, 46 bbls). IA FL inconclusive. Turned over to ops. SV, WV = C. SSV, MV = O. IA, OA = OTG. 17:00 () MULTIPLE ATTEMPTS TO FISH 2 7/8" WRP THROUGH LTP () FISHED 2-7/8" WRP FROM 11,109' SLM(see log for pieces left in well)(g ) RAN MAGNETS TO DEVIATION IN ATTEMPT TO FISH PIECES OF WRP WITH NO SUCCESS. SET 3.813" X-LOCK, 4-1/2" DREAM CATCHER IN X-NIP @ 10,901' MD RAN 4-1/2" CHECK SET TO X-LOCK @ 10,901' MD Working the latched WRP at the LTP 11910 CTMD, worked from LTP to 3-3/16 x 2-g 7/8 cross over to see if the element was the issue. Sheared off 12,227. POOH. OOH and retrieval tool sheared. Re-pin (steel) and reconfigure bait with 2.35" centralizer ()g directly above WRP retrieval tool. Could not make it into the LTP. POOH to re-y configure. Bottom end of retrieval tool has an impression from the FN on the LTP.g Make up and RIH with 2.125"shrouded WRP pulling tool. Tag the LTP 11,906 CTMD. Tried to work though. No success. POOH Daily Report of Well Operations PBU E-03A 5/28/2024 ***WELL S/I ON ARRIVAL*** ATTEMPTED TO SET 4-1/2 SLIP STOP CATCHER, S/D HIGH @ 2813' SLM RAN KJ, 3'x1-7/8'', 3.80'' G-RING, S/D HIGH @ 2813' SLM, WORK TO 2820' SLM RAN 4-1/2'' BLB, 2' x 1-7/8'' STEM, 3'' SAMPLE BAILER (msfb) S/D @ 2827' SLM, WORK DOWN TO 2880' SLM RAN 3.76'' CENT 2' x 1-7/8'' STEM, 3.80 CENT, 3.75'' LIB, S/D @ 2831' SLM ***INCONCLUSIVE*** RAN 4-1/2'' BLB, 2' x 1-7/8'' STEM, 3.50' WIRE GRAB (wg37) S/D @ 2840' SLM, WORK DOWN TO 2854' SLM RAN 2-1/2'' BLB, 2'' SLAMPLE BAILER (msfb) S/D @ 2874' SLM, WORK DOWN TO 2939' SLM ***SAMPLE OF HYDRATES*** PUMPED ~15 BBLS METH w/ TRI-PLEX TBG 1750 TO 2450 (cont pumping on next day) ***WSR CONT ON 5-29-24*** 5/29/2024 T/I/O=2206/1747/228 (MILL / UNDERREAM) Assist SL. Pumped 30 bbls 190* crude down TBG. FWHP=2846/1853/243 Secure Rig Up. Left well in SL Control. 5/29/2024 ***WSR CONT FROM 5-28-24*** RAN 2' x 1-7/8'' STEM, 3.50'' G-RING, S/D @ 2036' SLM, WORK TO 2945' SLM PUMPED TOTAL OF 24BBLS METH w/ TRI PLEX BRUSHED w/ 4-1/2 BLB, 3.80'' G-RING, AREA FROM ~2813' SLM TO ~2945' SLM w/ NO ISSES & TAGGED DREAM CATCHER @ 10926' SLM / 10910' MD LRS PUMPED TOTAL 30BBLS HOT CRUDE SET 4-1/2'' SLIP STOP CATCHER @ 3057' SLM PULLED RM-OGLV FROM ST#1 @ 3002'MD SET RM-OGLV IN ST#1 @ 3002'MD(20/64'') PULLED 4-1/2'' SLIP STOP CATCHER FROM 3057'SLM PULLED 4-1/2'' DREAM CATCHER FROM X-NIP @ 10901'MD(empty) RAN 1-1/2" BOWSPRING CENT, 1-1/2" BOWSPRING CENT, 2.25" LIB, S/D @ 12589' SLM, JAR DOWN & FALL TO 12600' SLM, JAR DOWN & FALL TO 12611' SLM. (possible ring from bottom nose cone of wrp) RAN (2X) 1-1/2" BOWSPRING CENT, 1-1/2" BOWSPRING CENT, 2.25" MAGNET TO 12609 & 12615' SLM (recovered 1 wrp slip) RAN 6' x 2.25'' PUMP BAILER, S/D @ 12582' SLM, WORK DOWN TO 12588' SLM ( no recovery) ***WSR CONT ON 5-30-24*** 5/30/2024 ***WSR CONT FROM 5-30-24*** SET 3.813'' X-LOCK / DREAM CATCHER (oal lih=34") IN X-NIP @ 10930' SLM / 10901' MD ***JOB COMPLETE, WELL LEFT S/I*** 5/31/2024 T/I/O = SI/1910/300. Temp = SI. IA FL ( Ops request). DPBGL installed on IA, ALP= 1900 psi. IA FL inconclusive. SV, WV = C. SSV, MV = O. IA, OA = OTG. 12:00 Daily Report of Well Operations PBU E-03A 6/10/2024 ***WELL S/I ON ARRIVAL*** PULL DREAM CATCHER FROM X NIP @ 10,910' MD RUN LIB UNABLE TO MAKE IT PAST 10,962' SLM (nothing in this area) (no impression recovered) RUN BAILER TO DEVIATION @ 12,578' SLM (deviation @ 70 deg) ***CONTINUE ON 6/11/24*** 6/11/2024 ***CONTINUED FROM 6/10/24*** TAG LINER TOP PACKER 3.5" LIB TO LTP @ 11,884' MD (CLEAN IMPRESSION OF LINER TOP) ***WELL S/I ON DEPATURE*** 6/17/2024 LRS Coil Tubing Unit 1 - 1.5" .134 WT Coil. - Job Scope = Mill CIBP MIRU, function test BOP. MU BOT milling assembly w/ 2.34" reverse clutch mill. RIH. ***Job Continued on 6/18/24*** 6/18/2024 LRS Coil Tubing Unit 1 - 1.5" .134 WT Coil. - Job Scope = Mill CIBP ***Job continued from 6/17/24*** Continue in hole w/BOT milling assembly w/ 2.34" reverse clutch mill. Tagged the LTP, rotated through. Tagged 12649 ctm.Was able to chase down to 12749' CTM with minimal issues, Continue milling down to 12920. Where ROP slowed to .3fpm. Open circ sub, chase gel pill, and trip out of hole for a PDC. Make up and RIH with 2.27" PDC and 2.125" motor. Tag at 12947 CTM and begin milling. Milled down to 13100' and pulled a wiper trip. Had to work to get back to bottom to continue milling. 13108 milling had slowed to .5 fpm. ***Job Continued 6/19/24*** 6/19/2024 LRS Coil Tubing Unit 1 - 1.5" .134 WT Coil. - Job Scope = Mill CIBP ***Job continued from 6/18/24*** Milling ahead with 2.27" PDC and 2.125" motor. Mill down to 13350' ctm. Trip OOH for full gauge mill before milling CIBP at 13340' MD. Signs of dried cement on pipe once at 200' coming OOH. 2.27" PDC mill had minimal wear on side buttons (few small chips taken out), face of mill looked new. RIH w/ 2.35" Pirhanna mill. Grabby milling below 13121'. Continue to stall regularly with Pirhanna mill. Trip OOH for a reverse clutch mill. MU BOT 2.29" Reverse Clutch Junk Mill. RBIH w/ 2.29" mill. Tag @ 13380' and begin milling. ***Job Continued 6/20/24*** 6/20/2024 LRS Coil Tubing Unit #1 - 1.5" 0.134 WT Coil - Job Scope: Mill CIBP ***Job continued from 19-Jun-2024*** Continue milling on plug @ 13380'. Milled for ~4hrs, stacking weight and hitting it @ 30fpm. Able to get some motor work but no stalls. Dry tagged plug same spot after milling. Trip OOH to check tools. Mill looked good. MU Ventturi /burnshoe 2.34" with tempress. RIH. Tag LTP. Tagged 13135, had to RIH slow to make progress. Started seeing motor work 13368', worked down to 13374' Starte dgetting bit stuck and losing ground. Had to work free. POOH slow until above the LTP. ***At surface electronic depth counter ~600' deep****. Break down tools recovered a few metal pieces, barrel packed full of cement. Begin weekly BOP test. ***Job Continued 6/21/24*** Daily Report of Well Operations PBU E-03A 6/21/2024 LRS Coil Tubing Unit #1 - 1.5" 0.134 WT Coil - Job Scope: Mill CIBP ***Job continued from 20-Jun-2024*** Complete BOP Test. Function test BOPs. Make up BOT motor/ 2.29" 4-bladed RC junk mill. Tag 13301 CTM appears to be the plug 13340. Chased down to 13627 CTM. Estimated 13596.MD. POOH. Load the well 125 bbls of diesel. RDMO. ***Job Complete*** 6/22/2024 ***WELL S/I ON ARRIVAL*** RIH W/ KJ, 4-1/2" BLB, 3.74" GAUGE RING ***CONTINUE 6/23/24*** 6/23/2024 ***CONTINUE FROM 6/22/24*** BRUSHED / GAUGED X-NIPPLE @ 10,910' MD SET 4-1/2" DREAM CATCHER IN X-NIPPLE @ 10,910' MD RAN CHECK SET TO DREAM CATCHER, SHEARED ***WELL S/I ON DEPARTURE*** Make up BOT motor/ 2.29" 4-bladed RC junk mill. Tag 13301 CTM appears to be the plug 13340. Chased down to 13627jg CTM. Estimated 13596.MD. POOH. @ SET 4-1/2" DREAM CATCHER IN X-NIPPLE @ 10,910' MD 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU E-03A Squeeze Perfs, Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 201-217 50-029-20181-01-00 13708 Conductor Surface Intermediate Liner Liner 9048 80 2815 11419 1497 1816 12774 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3/16" x 2-7/8" 9043 31 - 111 31 - 2846 30 - 11449 10983 - 12480 11892 - 13708 31 - 111 31 - 2846 30 - 8328 8103 - 8948 8581 - 9048 12650, 13348 520 2670 4760 7020 10530 12774, 13340 1530 5380 6870 8160 10160 12730 - 13635 4-1/2" 12.6# L-80 27 - 12480 9034 - 9046 Structural 4-1/2" Baker HB Packer 10932, 8077 10932 8077 Torin Roschinger Operations Manager Kirsty Glasheen kirsty.glasheen@hilcorp.com 907-564-5258 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 0028299, 0028304 27 - 8948 Perforations 12209' - 12269'MD Squeeze 9-bbls 15.8-ppg Class Cement. Final squeeze pressure = 2000-psi 209 Well Not Online 39436 24 500 1500 760 740 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 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 Samantha Carlisle at 9:47 am, Jan 29, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.01.26 15:16:49 -09'00' Torin Roschinger (4662) RBDMS JSB 013024 DSR-1/29/24WCB 2-13-2025 ACTIVITY DATE SUMMARY 9/8/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Cmt Sqz, Mill CIBP, Pull WRP, Mill CIBP Travel to E-03 from MPB-32. ***Continue WSR on 9/9/23*** 9/9/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Cmt Sqz, Mill CIBP, Pull WRP, Mill CIBP Continue travel to E-03 from MPB-32. Function Test BOP on Well. RIH with YJ MHA, HES GR/CCL log w/2.2" Carrier. Stop on trip OOH to replace bad hydraulic seals on P-14 pump. Closed Slip/Pipe rams during repair. Continue POOH. At surface, complete BOP test - full body, pipe rams, and slips. MU 2.25" BDJSN and stab on to well. Kill well w/ 5 bbls 50/50 MEOH, 271 bbls 1% KCL, 5 bbls 50/50 MEOH. ***Continue WSR on 9/10/23*** 9/10/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Cmt Sqz, Mill CIBP, Pull WRP, Mill CIBP Continue well kill w/ 5 bbls 50/50 MEOH, 271 bbls 1% KCL, 5 bbls 50/50 MEOH. RIH w/ cementing BHA - 2.25" BDJSN. Circ WB to DSL from 12,350'. Sqz Sag perfs (12,209 - 12,269' MD) w/ 9 bbls 15.8 ppg Class G Cement (15 blls pumped - 9 bbls sqz in zone). Clean out to CIBP @ 12,556' CTMD. POOH. WOC. ***Continue WSR on 9/11/23*** 9/11/2023 SLB CTU #9 - 1.75" CT - .156" WT - Job Scope = Cmt Sqz, Mill CIBP, Pull WRP, Mill CIBP MU & RIH w/ YJ 2.30" Venturi/Burnshoe BHA. Venturi packed off with cement. All cutting structure gone from burn over mill. RIH with YJ 2.300" Reverse Clutch 5- blade junk mill. Mill CIBP at 12578'. Push plug to 12650' with no issues. Plug moving freely. FP Tubing with 38 bbls diesel. POOH. RDMO. Turn over for SL to set a dream catcher. End ticket @ midnight. Final T/I/O 800/581/0 ***Job Completed*** 9/16/2023 ***WELL S/I ON ARRIVAL*** RUN 4-1/2" DREAMCATCHER TO X NIPPLE @ 10901' MD ***WELL LEFT S/I ON DEPARTURE*** 9/18/2023 T/I/O = 150/550/60. Temp = 49°. T FL (Ops req). No AL. T FL @ surface. SV, WV = C. SSV, MV = O. IA, OA = OTG. 09:00. 9/25/2023 ***WELL S/I ON ARRIVAL***(Cement squeeze) PULLED DREAM CATCHER FROM 10,901' MD TO 1,732' SLM(Stuck in hydrates) RAN 3.84" GAUGE RING TO 1,732' SLM. BEAT DREAM CATCHER FROM 1,732' SLM TO GLM @ 3002' SLM w/ 1.5" BULLNOSE PULLED 4 1/2" DREAM CATCHER(empty) RAN 2.25" LIB TO 12,548' SLM (Impression of junk in tbg) ***CONTINUED 9/26/23 WSR*** Daily Report of Well Operations PBU E-03A g Mill CIBP at 12578'. Push plug to 12650' with no issues. Plug jg moving freely. FP Tubing with 38 bbls diesel. POOH. Daily Report of Well Operations PBU E-03A 9/26/2023 ***CONTINUED FROM 9/25/23 WSR***(Cement squeeze) RAN 10'x2.25" PUMP BAILER TO 12,510' SLM(Unable to work deeper) RAN 2.25" MAGNET IN MULTIPLE CONFIGURATIONS AS DEEP AS 12,574' SLM(Recovered multiple pieces of milled cibp) ***JOB SUSPENDED FOR HIGHER PRIORITY WORK, WELL S/I ON DEPARTURE*** 11/19/2023 (Assist Coil) TFS U3. Standby to assist coil as needed *Job continues to 11-20-23* 11/19/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP Mobilize CTU 9 from Slb Yard. MIRU. Function BOPs. SLB spare tractor went down, utilize TBS pump truck. Make up YJ Venturi with 2.35" shoe and RIH. ***Continued on 11/20/23*** 11/20/2023 *Job continues from 11-19-23* (Assist coil) TFS U3 Pump as directed 11/20/2023 TFS Unit 4 (Assist Coil Tubing) Contingency pump for coil. 0 BBLS pumped. Coil in control of Well upon Departure. 11/20/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP Continue RIH with Venturi. Tag at 12582' ctm. Hoover down pushing plug to 12704'. PUH and overpull at 12662'. Jar lick down and become free. Circ Diesel to FP well (will NOT INJ). samples diesl w/ water. Pump 60/40 meth, slick 1% kcl w/ SL. 10 bbls PowerVis. Slick 1% kcl w/ SL. 60/40 meth to FP CT. PUH to 12,659' 10K over. Jar hit. Set back down chaulk jar. PUH, 2nd jar hit free. Hung up @ 12,628', pulled 10k over and free. POOH. BD 2.35" mule shoe - two chucks in btm: Chuck of pores Metal 2" x 4" and chunk of CIBP peice 1-3/4" x 1-1/4" body ring and some scrap marks on outside, but NOT bad. Nothing in barrel or screen of Venturi. MU YJ Venturi and 2.30" Mule Shoe. RIH. Hoover from 12440' to 12749'. Slack off 5k and hoover. POOH. LD Venturi. Recover plug debris, piece of slip, and a rubber element. Perform Weekly BOP test. ***Continued on 11/21/23*** 11/21/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP BOP Test. NU BOPs. MU YJ Venturi 2.35" mule shoe wire grabs Assembly. RIH. DRILL on Electrical Cord Fire on MPF. Tagged @ 11,903' LTP. PUH 11K over free up. RIH Venturi twice thru LTP. RIH dry thru LTP. Pump 1/2 bpm tag @ 12,615'. Venturi thru @ 1 bpm. Keep pumping 1 bpm Tag @ 12,675'. Venturi thru. Tag @ 12,749' ctm / 12,765' Mech. PUH and Tag again. POOH. BD YJ 2.35 mule shoe Venturi. Recovered Some slips, chunk metal, rings in mule shoe and above flutter cage. 1/2 cup of chewed up CIBP parts in screen. MU Same 2.35" mule shoe w/ wire grab and RIH. Stacked down 12,590', 12,682' was able PUH and Run past. Tag @ 12,753' ctm / 12,768' Mech. PUH and start Venturi 1.1 bpm. Work 3 times. PUH & 12,730' pull 38K. worked Pull thru. 12,663' pulled 42k, chalked jar, jar hit free. 12,633' pulled 39K, able work thru. 23,602' pulled 42K, jar thru. POOH. BD YJ Mule shoe Venturi. Mule show is bent at uphole side about 1" (NOT point) and scrap marks up outside. btm wire grab bent over, but no scrap marks inside. have three slip pieces 1"x1" above flutter cages. some small band pieces. have a hand full of metal fines in screen. ***Continued on 11/22/23*** Daily Report of Well Operations PBU E-03A 11/22/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP MU YJ Venturi 2.35" mule shoe wire grab BHA. Tag at 11891' ctm, unable to get through LT assembly. POOH. Recover 1 slip. Mule shoe dented on point. Stack down and change packoffs/chain inspection. Make up YJ 2-1/8" milling BHA w/ 2.33" Venturi/ BS (ID: 1.20") and RIH. At surface inspect Venturi BHA...LIH...Lower section of Burn Shoe, approximately 4 inches in length, 2.33" OD. Basket packed off with green cement fines. No flow to burn shoe created excessive heat, broke burn shoe almost in half. Recovered 0.36' of CIBP core however. Discuss with OE, plan to run Venturi Mule Shoe with wire grabs in attempt to recover second half of core/Burn Shoe. ***Continue to 11/23/23*** 11/23/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP MU YJ Venturi BHA with 2.300" Shoe, with 3 wire grabs. No Motor. RIH past LTP with No issues. Continue down to milling area, ~12750'. Did not Recover core or Burn Shoe LIH from Run #6.. Some small cement debris and small chunk of steel core. RIH with YJ 2.28" Venturi/ BS (ID:1.20"). Dry tag at 12753' down/ 12746' up. Stalled 3 times. POOH. Recovered a few chucks of plug parts and metal debris but no core. RIH with YJ 3 blade Reverse Clutch Junk Mill, 2.35". ***Job Continued to 11-24-2023*** 11/24/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP RIH with 3-blade junk mill. Milled down to 12797' down/ 12789' up. (12773' md) Had - 16 correction from tagging LT on previous runs POOH. Mill had wear on outer edges. RIH with YJ Venturi with wire TT pins (2" & 4" from bottom) in 2.35" Muleshoe(. Tag on top of the LTP and unable to pass. POOH. PU YJ/Hailey Screwdriver Index Tool w/Venturi Mule Shoe, 2.35". ***Continued to 11/25/2023*** 11/25/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP PU YJ/Hailey Screwdriver Index Tool (2.13") l w/Venturi Mule Shoe, 2.35". Make it past LTP, 11910' on third attempt, 16 ft/min after indexing 2 times. Run down to bottom at 12807' CTMD, Clean PU 28k. Working the Venturi @ 1 bpm w/Diesel. Up/down multiple times on bottom (12807') to allow the indexing tool to orient the mule shoe in various positions. POOH after setting shoe down 8 times on bottom. FP surface lines and Cap well w/Meth 10 bbls. Inspect BHA...Appears that we were over the WRP fish neck. Wire Grabs in mule shoe are bent upward. Basket almost completely empty. SLB Stacking down to change packoffs and check chains/injector. RIH with baited 2-7/8" WRP retrieval tool with bowspring. Unable to pass PBR Assembly at 10948' ctm. POOH to reconfigure tools. RIH with 2-7/8" WRP retrievel with barbell bowspring. Go past PBR and LTP no issues. Tag down on WRP 5 times, no overpulls. POOH to Check Tools. ***Job Continued to 11/26/2023*** Daily Report of Well Operations PBU E-03A 11/26/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP Found 1.25" Chunk of Hard Cement inside Fishing tool. RIH with WRP Retrieval Tool again. Could not latch WRP again. POOH, 5 bbls meth cap in well. RIH with a 2.25" LIB, sat down at 12593'. POOH. No indication of plug. RIH with WRP OS. Tag at 12796'. Unable to latch. POOH. 38 bbls Diesel FP in Tbg. RDMO. ***Job Continued to 11/27/23*** 11/27/2023 CTU #9 1.75" CT Job Objective: Fish milled CIBP, Pull WRD, & Mill CIBP RDMO. End Ticket @ 0200. WRP still Not retrieved and CIBP not milled, per objective. Suspend job for AFE limit. ***Job Incpomplete*** 12/26/2023 T/I/O=400/400/200 Temp= S/I (TFS UNIT 4 Assist SL with pump down) Pumped 1 BBL of crude down TBG to assist SL with pump down. SL was unable to make it to required depth. SL in control of well upon departure. Final WHPS= 1000/400/200 12/26/2023 ***WELL S/I ON ARRIVAL*** PERFORM WELL CONTROL/MAN DOWN DRILL (DAY CREW) RAN 2.15" CENT, 3' 1-1/2" STEM, 2.34" CENT, 2" LIB, DEVIATE OUT @12,569' SLM (lib inconclusive) RAN KJ, 3' 1-7/8 ROLLER STEM w/ 2.2 WHEELS, 2" LIB, DEVIATE OUT @ 12,569' SLM (lib inconclusive) RAN KJ, 1.90" CENT, 3' 1-1/2" STEM, 2.15" CENT, 1.75" LIB, DEVIATE OUT @12,569' (lib inconclusive) ATTEMPT TO PUMP DOWN W/ THUNDERBIRD (UNABLE TO PUMP DOWN) 2 BBLS CRUDE RAN KJ, 2.15" CENT, 1-3/4" SAMPLE BAILER (MSFB), SD @12,587' SLM (recovered coil shavings) SET 4-1/2" DREAMCATCHER (40" OAL) @ 10,901' MD RAN 4-1/2" CHECKSET, S/D @ 10,901' MD (good set) ***CONTINUE 12/27/23*** 12/27/2023 ***CONTINUE FROM 12/26/23*** RIG DOWN & TRAVEL POLLARD #59 ***WELL TURNED OVER TO PAD OP*** 1/20/2024 T/I/O = 2300/1600/700 Temp = S/I (TFS UNIT 3 ASSIST SL WITH PUMP DOWN) Pumped 10 bbls 60/40 followed by 34 bbls Crude down TBG ***Job continued on 1/21/2024*** 1/20/2024 ***WELL S/I ON ARRIVAL*** ATTEMPT TO PULL 4-1/2" DREAM CATCHER (HYDRATES) PUMP 10 BBLS 60/40 & 34 BBLS CRUDE W/ THUNDERBIRD RAN 3.80" GAUGE RING WHILE PUMPING, S/D @ 10,901' MD ***CONTINUE 1/21/24*** WRP still Not retrieved and CIBP not milled, per objective. Daily Report of Well Operations PBU E-03A 1/21/2024 ***CONTINUE FROM 1/20/24*** PULL 4-1/2" X-LOCK DREAM CATCHER @ 10,901' MD RAN 1.75" LIB TO 12,745' SLM (faint impression of fill) RAN 10' x 1-3/4" PUMP BAILER TO 12,745' SLM, GET MINIMAL DUST METAL & RUNNY CEMENT RETURNS RAN 10' x 2-1/4" PUMPBAILER, S/D IN DOG LEGS @ 12,530' SLM. POOH w/ ~ 1 CUP FINE METAL SHAVINGS & POWDERY CEMENT RAN 10' x 1-3/4" PUMP BAILER TO 12,745' SLM (2 CUPS OF METAL SHAVING & FILL) RAN 10' x 1-3/4" PUMP BAILER TO 12,775' SLM (2 CUPS OF METAL SHAVING & FILL) ***CONTINUE ON 1/22/24*** 1/21/2024 ***Job continued from 1/20/2024*** T/I/O = 2500/1575/700 Temp = S/I (TFS UNIT 3 ASSIST SL WITH PUMP DOWN) Pumped 11 BBLS crude to Assist SLickline with pump down. FWHP2750/1575/700 Slickline in control of well upon departcher. 1/22/2024 ***CONTINUE FROM 1/21/24*** RAN 10' x 1-3/4" PUMP BAILER NUMEROUS TIMES (see log) RECOVERED ~ 4 CUPS OF FILL RAN BOWSPRING w/ 2.25" MAGNET, SD @ 12,590' SLM, WORK DOWN TO 12,628' SLM (unable to get deeper) RAN 2-1/4" SAMPLE BAILER w/ FLAT BRUSH BOTTOM (BRAIDED LINE JUNK CATCHER) S/D @ 12,775' SLM (NO RECOVERY) RAN 2" PUMP BAILER MSFB (JUNK CATCHER BOTTOM) S/D @ 12,776' SLM ***CONTINUE 1/23/24*** 1/23/2024 ***CONTINUE FROM 1/22/24*** RIG DOWN POLLARD # 59 ***WELL LEFT S/I*** RIG DOWN POLLARD # 59 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations DJ Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate H Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 51-4-C/.3P 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 201-217 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20181-01-00 7. Property Designation(Lease Number): ADL 0028304,ADL 0028299 8. Well Name and Number: PBU E-03A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 13708 feet Plugs measured See Attachment feet true vertical 9048 feet Junk measured 13348 feet JUN 15 2017 Effective Depth: measured 12550 feet Packer measured 10950 feet true vertical 8986 feet Packer true vertical 8085.89 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 31-111 31 -111 1530 520 Surface 2815 13-3/8"72#L-80 31 -2845 31 -2845 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12209 12269 feet 12730-12760 feet 12805-12830 feet 12867-12892 feet 13085-13110 feet 13110-13135 feet 13135-13260 feet 13410-13635 feet True vertical depth: 8778-8815 feet feet 9034-9040 feet 9048-9052 feet 9056-9056 feet 9063-9062 feet 9062-9060 feet 9060-9053 feet 9045-9046 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 27-12518 27-8970 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNEDJULV'� 2 � LU!�, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 365 30813 18 600 1527 Subsequent to operation: 445 36307 15 560 771 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations m Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil I1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Derrick,Laurie R Contact Name: Derrick,Laurie R Authorized Title: Petr,pleum Engineer P /�/eContact Email: Laurie.Derrick@bp.com Authorized Signature: /l/� ���714-J, Date: 6/I Sl/q- Contact Phone: +1 907 564 5952 Form 10-404 Revised 04/2017 rkcL 7G --/6 RBDMS VJUN 2 6 2017 Submit Original Only ,e ice//7 • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RECEIVED RE: BP Exploration (Alaska), Inc. JUN 2017 Report of Sundry Well Operations Summary AOGCC June 15, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting a Plug and Addition of Perforations for Well E-03A, PTD # 201-217. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 • • Plugs Attachment PBU E-03A SW Name Date MD Description E-03A 05/18/2017 12550 2-7/8" Baker CIBP E-03A 05/25/2015 12774 2-7/8"WFD WR Plug E-03A 07/31/2007 13340 2-7/8" CIBP a) O rn 000 0 ma 0000 00 0 0 4gMMM �O O- M LOM = LO O O OO r m r 'Cr CO CO 03 CO LO N- O O In O CO O N- `- Cr CO N - N CO N- OO r Cr) O) 0) O) 0 O) N N CO CO CO CO 0) CO H ✓ �- O) V 0 000 N cor- m co N r r In O) O) N N CO CO CO 00 o O D M CO M OO M M 00 r lC) d l(7 O • N N r N N N M N mC ✓ O QMr CO r CO CO r O) 00 O) Nr M� N- j M M N r 0) CO 0 W " 40 %-.. NN Cr r r r • W I- aO O 0 0 0 0 0) JOOO _JJaOao = d = N * * Z , Ncocc00 N N- N- i* co CC)• N • NO) N CO - CON U OBo C) to = N O`ON N r "(;75mm M M N 4 Z 1.0 CO CO N O r 0)O r r O M " LON- O C CO 00 r M CC) In M J N N O) r WW Q Q =OW0 Z O U W W V O u Q X Q W X c Z Z w W W W W W W m O D F � Z Z Z Z D ✓ W Z J J J J 1— • • Packers and SSV's Attachment PBU E-03A SW Name Type MD TVD Depscription E-03A TBG PACKER 10949.67 8085.89 4-1/2" Baker HB Packer E-03A PACKER 11890.59 8579.62 3-1/2" Baker KB Top Packer 0 • .. c w -J / 2 ® &m II II -4 CO w I I a cL T-ZO CV ƒ0 I LU 0 0N- ® / ƒ O<© z co co I- & a- ® 0 -0 s- 0 0 LU C'') 2 ., I- w 0 I ) % / c % w 4 2iI ., «0 w 0 w w 2 D a_ ci O 0 _ / R 0 0 3 3 co o > � ƒ c u) a a E 0 < 8 2 ® U2 0- - • � k Ki E ■ a 2 / _1 0 < mak / el / � / i- 0 O < c/) 0 k • @ � r1 � � ƒ v. co ® o Q Qq 5 =_.-7• e* -O / A 0 w O ,. < U < U "' .. L W E 2 b _1 R w q G q •6 c 0 4-,• n 3 « m @ w q c \ c q i ¢ '-c31— ; ! i ow " m CN « _ ▪ O. a Z Z 6 w I m 3 7 c « oo. : 0 - � � � - () LIR" UCA 0w < k 7 - ƒ E ^ � C & / • « Root ° / 2k nQ 0 ƒ � » ® D � E � / 0 � ww -, ƒ � rx : 7 § a § Ommz l- E@Ew bw zg / ZO O :D � w �ICaCL - � � � 0q . DWk � - � WF- k % CO 0� = / L4t U � k � , ƒ I2 _iQ _jj - � oN / ON"OW R - 1E1 / � / / $ / / / ce / / ƒ % � � q m i E c a k | _1 | k ce R g cT ƒ , E2 ƒ 2 k k / a w < N. N. a I- f CO / ¥ 2a \ to \ < TREE.... 4-1/16"FMC S WELLHEAD= MCEVOY E-03A -03A SAFETY NOTES: WELL ANGLE >70°r• ACTUATOR= OTIS 12570'&>90°@ 12890'. OKB.ELEV= 56.63' BF.ELEV= 27.66' KOP= 3400' Marc Ante= 96°@ 13154' CI 1989° H4-1/2"OTIS SSSVN,D=3.813" [tum MD= 12335' 9-5/8"FOC —1 2095' I--- [tum TVD= 8800'SS 2141' -J TOP OF 9-5/8'BOT PBR 13-3/8"CSG,72#,L-80,ID=12.347" —I 2846' }--" k GAS LFT MANDRELS 9-5/8"FOC —1 2879° I'--- IIID ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3002 2945 1 O115 SO RM 20 11/20/10 Minimum ID =2.377" @ 12532' 3-3/16" X 2-7/8" LNR X-OVER 1090 • H4-1/2"oils xNIP,D=3.813" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,ID=3.958" H 10910' 10910' —I4-1/2"BAKER PBR SEAL ASSY g. '14.M 10932' H 9-5/8"X 4-1/2"BKR HB PKR,D=4.000" 7"BOT PBR H 10983' 9-5/8'X 7"SOT LNR TOP PKR H 11023' 0 0 9-5/8"CSG,47#,N-80,0=8.681" H 11447' 11884' H BAKER KB LNR TOP PKR ID=2.560" II I 11892' H3.70"OD BKR DEPLOYMID BVT SLV, =3.00' D BTM OF BKR SEAL ASSY, =2.390' —I 11896' " 11898' --I TOP OF 3-1/2"LNR,9.3#,ID=2.992' 3-1/2"X 3-3/16"LNR XO,D=2.786' H 12437' 1.4 .4. ' MR LOUT WN�DOW (E-03A) 12518'-12525' TOP OF WF STOCK H 12484' ir vi 4.4 RA PP TAG H 12494' 1v�1� 1 H 12532' H3-3/1&X 2-718'LNR XO,D=2.377" '1,1'41+)1,' �j 12660' H2-7/8"BKR CUP(05/17/17) 11111111111'111: , I 12774' H2-7/8"WFD WRP(05/24/15) PERFORATION SUMMARY 11,1111111111 `," REF LOG:SW5 MCl4 ON 02/12/02 4 j:1/1/111111. ` 13348'ctltl —FISH-COMPOSITE PLUG ANGLE AT TOP PERF:52°@ 12209' 1.111111111►�� MILLED ) 11011111) (01/30111 Note:Refer to Production DB for historical perf data 111111, 43340' H2-7/8"CSP(07/31/07), SCE SIT= INTERVAL Opn/Sqz SHOT SQZ 1111111 2' 6 12209-12269 0 05/17/17 111111 2' 6 12730-12760 C 05/24/15 /1111111/, 6r k2" 6 12805-12830 C 06/23/09 •11111 1 11111111. 1111111 2" 6 12867-12892 C 06/23/09 11111111 2" 4 13110 13135 C 07/31/07 111111111111111^ Kap13640' 4111�1 2" 4 13135-13260 C 02/12/02 111111111111111 1.4 1111111 2" 4 13410-13635 C 02/12/02 111 11111111111ID 11 2-7/8"LNR,6.5#,L-80,.0058 bpf, =2.377" HI 13708' 1111111111111111 1111111111111111 1111111111111111 7"LNR,29#,N-80,ID=6.184' —I 12862' 1.1.1.E 1.1.1.1. DATE REV BY COMMENTS DATE REV BY (X)P? 'TS FRUDHOE BAY UNIT 04/06/76 ORIGINAL COMPLETION 02/12/11 PS/PJC MILL WIFD&PUSH BTM(01/30/11) WELL E-03A 10/24/89 RWO 12/08/13 PJC C8P FISH CORRECTION PERMIT No: 201-2170 02/12/02 CTD SIDETRACK(E-03A) 04/17/14 DM'PJC DEPTH CORRECT-FISH @ 13348' API No: 50-029-20181-01 06/23/09 DBM'TLH PLUG SET,ADP92FS 05/28/15 ATO/AID SET WRRADFERFS(05/24/15) SEC 6,T11N,R14E,1053'FAIL&502'FEL 09/08/09 KDC(TLH GLV C/O(07/27/09) 05/22/17 NXW/JM7 SET RUG&ACPERFS(05/17/17) 11/24/10 WEC/PJC GLV CIO(11/20/10) BP Exploration(Alaska) STATE OF ALASKA "' 4;.; r V D 4LASKA OIL AND GAS CONSERVATION COMM. N REPORT OF SUNDRY WELL OPERATIONS JUN 22 2til` 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operatior> s �n,=.M_ _ El Suspend 0 Perforate H Other Stimulate CI Alter Casing 0 Change AppbOe Progfa , 0 Plug for Rednll 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other i-e-/- WR P v- 2 Operator Name: BP Exploration(Alaska),Inc 4 Well Class Before Work 5. Permit to Drill Number: 201-217 3. Address: P O.Box 196612 Anchorage, Development Elf Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20181-01-00 7. Property Designation(Lease Number): ADL 0028299 8. Well Name and Number PBU E-03A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: Total Depth measured 13708 feet Plugs measured See Attachment feet true vertical 9048 feet Junk measured feet Effective Depth: measured 12774 feet Packer measured See Attachment feet true vertical 9043 feet Packer true vertical See Attachment feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"94#H-40 32-112 32-112 1530 520 Surface 2815 13-3/8"72#L-80 31 -2846 31 -2846 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12730-12760 feet 12805-12830 feet 12867-12892 feet 13085-13110 feet 13110-13135 feet 13410-13635 feet 13135-13260 9048-9052 feet 9056-9056 feet 9063-9062 feet 9062-9060 feet True vertical depth: 9034-9040 feet 9045-9046 feet 9060-9053 4-1/2"12.6#L-80 27-12518 27-8970 Tubing(size,grade,measured and true vertical depth) Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): p Treatment descriptions including volumes used and final pressure' SCANNED , 1 i i,i , ,,-f 13. Representative Daily Average Production or Infection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 544 42064 38 640 1619 Subsequent to operation: 488 24064 52 640 1503 14.Attachments:(required per 20 AAC 25 070 25 071,&25 293) 15.Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development l 1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 11 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature ( - Phone +1 907 564 4424 Date 6/22/15 QRnnec__ 1111 - 1 ;m; E-03A 205-081 Plugs Attachement SW Name Date MD Description E-03A 05/24/2015 12774 2-7/8"WFD WRP E-03A 05/09/2010 11440 2-7/8" MOT CIBP E-03A 07/31/2007 13340 2-7/8" CIBP Packers and SSV's Attachment 205-081 SW Name Type MD TVD Depscription E-03A PACKER 10949.67 8085.89 4-1/2" Baker HB Packer E-03A PACKER 11890.59 8579.62 3-1/2" Baker KB Top Packer co in co N (00 COO N O 00 Lo • O N V Ln 2C) O O co oo (00 to M m (OCOCO McO CO CO I. O O to CO O N r- 00 N r- co M - O) O) O) O O) N CO N CO CO CO O) CO M Lo O O N 'C1- 0) O N CO CO N- M Cr) N 0) to O) N N CO CO CO CO O) 00 CO M CO CO CA tot O _ to N N N N N M N o CO i i i i i i i i co co CO CO Nr 01 Cr)O M •N N N co N N _ x S A-- XI XI Q N ~ 000 (0(0aooa(0 00000 i J Z J 00 J J a) N Z NIt 41k co .N N OCO _) 0, (O O O s- O M N 0\0 (...14 rjM f- 5- O) O) M M N 4 t to co 00 to O7 M U) N r-- O) Cco00cMs— toO) O J (N 0) N to N W W Q Q 0O y• U co D U Z c W W W W W W O D H H Z Z Z Z D U U) Z Z J J J 11 , ± - Ca = O% I � b2 Ek / / *-.4) c • ) . ) co 2 / 0 k § § $ ° c) e b ® Cl)® / 70 k ƒ/ 0 0 C) U3 >q N- ...§ / 97 I0E \ = 2 . CO % - Om = ab 4 2 ® \ _ U) % ° ■ \ 2 § » g Cl) e a) \ gE7 _o o e U [ £ % q 2 & $ / § > 2 c / % f \ 0- c 7▪ 2 > K ° ■ U `- 2 2 £ E a) " 2 w k 2 k LL / f f L / >' ! ■ .- i- 0.� Rf \ 7 / c k 2a) co % / _ ( m20 _. « 222 « ƒ csi % Uk & 8 rx cO . � E ƒ _ ° w 0 4▪- o \ O -CU 2 � � G � a EL EL t Ci O g Q / \ \ 7 § c J o o c 0 < 6 - c U & = 2 § ..' / § 2 c ° # t _ > % t 2 Ce 2 \ � & � &2 % cL� 2a) � % \& LicT CC 2 g a t .§ $ 2 2 2 > 2 05 � c m ? ? � oo� @ H b ▪RI q7 � _I § b / Ok \ ƒ %2 �bf D - m 0 •• n ¥ c n a - a 0 o x U) Q a \ b / 2 U \ o ƒ Omib E ± m & %� 0 / _ a k � � f $ • & ® ° - % 0 : f o @ ¥ 5 o_ = m g , $ a Q _m § co @ m 6 c » e a) R I _ ccl_ - ' > m E E _ > a E f k R k q ® t R S S ^ S o U 5 / / % 2 / \ .. CV k t 1- a) E _ 0 m E - E2 : c.) 0 > - -0 -300a_ > k L0 ƒ w q LU m m ® d d d ® ® \ / � R � & 0 Lo a r « -TREE WELL 4-1/16"FMC E-0 3 A ° W�LHEAD= MCEI/OY SAFETY NOTES: WELL ANGLE >TO°@ ACTUATOR= OTIS 12570'&>90 (12890'. OKB.ELEV= 56.63' BF.fl.EV= 27.66' KOP= 3400' Max Angie= 96°@ 13154• == 1989' --4-1/2"OTIS SSSVN,D=3.813" Datum MD= 12335' 9-5/8"FOC –I 2095' I--- Datum ND= 8800'SS 2141' H TOP OF 9-5/8"BOT FBR 13-3/8'CSG,72#,L-80,D=12.347" –{ 2846' I—, ' ( GAS LFT MANDRILS I 9518"FOC –) 2879' 1— IIP ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3002 2945 1 OTIS SO RM 20 11/20/10 Minimum ID =2.377" @ 12532' 3-3/16" X 2-7/8" LNR X-OVER 1 . 10901' H4-1/2"O11S X Nom,D=3.813" 4-1/2"TBG, 12.6#,L-80,.0152 bpf,D=3.958" H 10910' 10910' –4-1/2"BAKER FBR SEAL ASSY I =, 10932' H 9-5/8'X 4-1/2"BKR HB PKR,D=4.000" 7"BOT PBR –j 10983' 9-5/8"X 7"BOT LNR TOP FKR H 11023' C 0 9-5/8"CSG,47#,I4-80,0=8.681" -i 11447' 11884' H BAKER KB LNR TOP PKR,D=2.560' BTM OF BKR SEAL ASSY,0=2.390" H 11896' I' 11892' –I 3.70'OD BKR DEPLOY WENT SLV,0=3.00" ',, '', 11898' –j TOP OF 3-1/2"LNR,9.3#,D=2.992" 3-1/2'X 3-3/16"LNR XO,D=2.786' H 1243T 1.� V,' MLLOUT WINDOW (E-03A) 12518'-12525' TOP OF W-*'STOCK H 12484' w RA PP TAG –{ 12494' A 1` 12532' ---I 3-3116"X 2-7/8"LNR XO,D=2.377' A11 11.11.1.1#�. 12774' —12-7/8"WFDVVRP(05/24/15) 44144 • 111111'►4 FERFORATION SUMMARY 14 11111111111/ .40,44\00„ 1 4 4.4 1348'curt FISH-COA�OSITE PLUG REF LOG:SWS MCN_ON 02/12/02 111111 It ►1111 ANGLE AT TOP PERE:77°@ 12730' �4114441��� MLLED(01/30/11) 4.1 Note:Refer to Roduction DB for historical pert data 11/111. 13340' –12-7/8'CCP(07/31/07) SEE SPF INTERVAL Opn/Sgz SHOT SQZ ►1111111 `. 2" 6 12730-12760 0 05/24/15 ♦111111 2" 6 12805-12830 C 06/23109 14444s -4,44k1111 .111111'1 2" 6 12867-12892 C 06/23109 11111111. 1111111 2" 4 13110- 13135 C 07/31/07 111111111111111 1 ` 2" 4 13135-13260 C 02/12/02 1111/11/11/1111 PBTD 1-- 13640' 4111 j� 2" 4 13410-13635 C 02/12/02 111111111111111 11111111 1111111111111111 2-7/8'LNR,6.5#,L-80,.0058 bpf,D=2.377" H 13708' 1111111111111111 1111111111111111 7"LNR,29#,N-80,D=6.184" H 12862' 1�1�1,1.1.1.1.1� DATE REV BY COMWBVTS _ DATE REV BY COMMENTS PRUDHOE BAY UKT 04106/76 ORIGINAL COMPLETION 02/12/11 PS/PJC PALL WED&PUSH BTM(01/30/11) WELL E 03A 10124/89 IMO 12/08/13 PJC CBP FISH CORRECTION PERMIT No: 201-2170 02/12/02 CTD SIDETRACK(E-03A) 04/17/14 DM/PJC DEPTH CORRECT-FISH @ 13348' AR No: 50-029-20181-01 06/23/09 DBANTLH PLUG SET,ADR32FS 05/28/15 ATO/JMD SET WRP/ADPERFS(05/24/15) SEC 6,T11N,R14E, 1053'FNL&502'Fa 09/08/09 KDC/TLH GLV 0/0(07/27/09) 11/24/10 WEC/PJC GLV C/O(11/20/10) BP Exploration(Alaska) 02/23/11 Sdkmrerger NO. 5698 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2038 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job M Log Description Date BL Color CD P2 -31A BCRD -00081 TEMP & X/Y CALIPER SURVEY x0 JG //) 02/06/11 1 06iM T 1 E -02 BL65-00015 SCMT .3')/) I —a! 01/27/11 n(o 1 1 —1C7 04 -21 1 BG4H-00031 31 PRODUCTION ,, { '�, 02/02/11 04 -17 BG4H -00029 INJECTION PROFILE / y 01/31/11 1 T . I 11-04A _ BG4H -00032 _ X -FLOW CHECK/IBP _} 02/06 /11 1 `[$5/1 1 W -202 BMSA -00005 ISOLATION SCANNER ) — / 01/30/11 ,,, , 1 1 1 ' 15 -26B 8D88 -00088 MCNL ! / 12/13/10 1 1 1 15 -11C BD88 -00081 MCNL . — /C.0 01/06/11 1 —. ♦ 1 07 -09A BD88 -00078 MCNL K -128 BCUE -00094 MCNL ' 6S r /4/ 11123/10 1 r --wr 1 E -35B 13 D88-00077 MCNL /Q _ / ( 12/05/10 1 1 B -04A BAUJ -00055 MCNL JO — (t) C 5 11/21/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • !M 5 °� AR MAR 1 4: Oil 1? . .EM R = , , STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI1 . ' REPORT OF SUNDRY WELL OPERATIONS Mi`- PC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 MILL/UNDERREAM Performed: Alter Casing ❑ Pull Tubinc❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ 1 Change Approved Program ❑ Operat. Shutdowr0 Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 E xploratory ❑ - 201 -2170 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20181 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO - 028299 30 "1 c iA— _ PBU E -03A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 13708 feet Plugs (measured) 13340' CIBP SET 7/31/07 true vertical 9047.72 feet Junk (measured) None feet Effective Depth measured 13641 feet Packer (measured) 10932 feet true vertical 9046.47 feet (true vertical) 8077 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 94# H-40 SURFACE - 104 SURFACE - 104 1530 520 Surface 2846' 13 -3/8" 72# N -80 SURFACE - 2846 SURFACE - 2846 5380 2670 Production 11449' 9 -5/8" 47# N -80 SURFACE - 11449 SURFACE - 8328 6870 4760 Liner 1497' 7" 29# N -80 10983 - 12480 8103 - 8948 7240 5410 Liner 1818' 3- 1/2 "X3- 3/16 "X2 -7/8" 11890 - 13708 8579 - 9048 Liner 8.81#/6.2#/6.16#L-80 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 10910 SURFACE - 8065 Packers and SSSV (type, measured and true vertical depth 9 -5/8" X 4 -1/2" BKR FIB PKR 10932 8077 NNl. ) FEB 3 2011 _, 12. Stimulation or cement squeeze summary: 3° ,1„01 q ry� �1 � � _� s Intervals treated (measured): Treatment descriptions including volumes used and final pressure:,".! ( Cons. ' 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 182 12,634 8 2,079 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 z Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 , Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE' GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na e Jo. Last ! Title Data Manager Signatur NIP Phone 564 -4091 Date 1/31/2011 Form 10 -404 Revised 10/2010 Flees Fel e11i z'L Gi Z' / Submit Original Only E -03A 201 -217 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base E -03A 2/12/02 PER 13,135. 13,260. 9,060.36 9,053.34 E -03A 2/12/02 PER 13,410. 13,635. 9,045.06 9,046.26 , E -03A 7/31/07 APF 13,110. 13,135. 9,062.22 9,060.36 E -03A 7/31/07 BPS 13,340. 13,340. 9,049.87 9,049.87 E-03A 8/1/07 APF 13,085. 13,110. 9,062.85 9,062.22 E-03A 6/22/09 BPS 13,025. 13,410. 9,059.13 9,045.06 E -03A 6/23/09 APF 12,805. 12,830. 9,047.87 9,051.54 E -03A 6/23/09 APF 12,867. 12,892. 9,055.51 9,056.4 E -03A 1/30/11 BPP 13,025. 13,340. 9,059.13 9,049.87 AB ABANDONED PER PERF APF ADD PERF RPF REPERF . BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE III • . E -03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1/27/2011 « «Continued from 1 -26 -11 » >Coil 8. 1 3/4" Job scope: Drift, run SCMT, mill Icomposite bridge plug. Complete BOP test, ' MU & RIH w /drift assembly w12.25" EJSN, partial kill for well, at 3842 ft had Coil Momentary lost friction (Slippage and little !Runaway), Pump KCL volume try get coil warm, POOH to check Injector, ok, MU F Riser and Same BHA, RIH, tagged CBP @ 13037' wgt back 13,030', digital. POOH :flagged pipe @ 12980' (digital)« «Performed Man down with H2S release Drill » » >RU SCMT logging tools. ««Continued on 1 -28 -11 WSR » » »> { 1/28/2011i « «Continued from 1 -27 -11 » >Coil 8. 1 3/4" Job scope: Drift, run SCMT, mill !composite bridge plug. !Continue MU of SCMT logging tools. Kill well, RIH w /logging tools. Make 2 SCMT ; logging passes @ 28 FPM from flag to 11,800'. POOH. MU & RIH Motor & Mill assy I to flag depth, correct counter EOT@ 12985 ft, Tagged plug 13031' (M 13016') wat. ;back @ 13027', Mill plug, had 15 stalls with no progress, POOH to reconfigure BHA Job in progress. 1/29/2011 « «Continued from 1 -28 -11 » >CT- 8. 1 3/4" Job scope: Drift, run SCMT, mill !composite bridge plug.Continue POOH w /Mill, change out mill on BHA to 2.25" burn (shoe. (2.26" mill measured 2.25" no go, mill still in gauge. Missing some cutters on ; back reamers & across front section of mill.) RIH w/2.25" burn shoe assembly. TOL ll 121.93'. Dry tag plug @ 13042'. Mill from 13038' w/ 15 stalls. WHP dropped, milled thru plug sliding, pushing to top of next plug, 13348' CTD. POOH «« «Job 'in progress. » » »» - 3 €CONDUCTED DRILL, "PACK OFF FAILURE ", { [ 1/30/2011 .« «Continued from 1- 29- 11 » >CT- 8. 1 3/4" (Job scope: Drift, run SCMT, mill ;composite bridge plug.) Conducted Safety Shutdown, discussed vehicle safety, Ref. I "Unsecured Vehicle Policy ". FP well & CT w /MeOH. Burn Shoe was worn /rounded on ! cutter end, showed wear marks on tube indicating probable junk laying on BP. Gauge I ring, 2.25" will fit over end now, under gauge. MOL « « <JOB COMPLETE » »> 1/30/20111« «Continued from 1- 29- 11 » >CT- 8. 1 3/4" (Job scope: Drift, run SCMT, mill !composite bridge plug.) Conducted Safety Shutdown, discussed vehicle safety, Ref. ! "Unsecured Vehicle Policy ". FP well & CT w /MeOH. Burn Shoe was worn /rounded on l cutter end, showed wear marks on tube indicating probable junk laying on BP. Gauge! ring, 2.25" will fit over end now, under gauge. MOL « « <JOB COMPLETE » »> z ; • • FLUIDS PUMPED BBLS 334.5 60/40 McOH 2111 1% XS KCL 2445.5 TOTAL TREE= 4- 1/16" FMC WELLHEAD = MCEVOY SA. NOTES: WELL ANGLE > 70° @ ACTUATOR = , OTIS E-03A 12570' & > 90° @ 12890'. KB. ELEV = 56.63' BF. ELEV = 27.66' MOP = 3400' Max Angle =-: @ 13154' ( 1989' 1-14 -112" OTIS SSSVN, ID = 3.813" 1 Datum MD = 12 335' 1 9 -5/8" FOC H 2095' F Datum TVD = 8 SS 2141' 1-I TOP OF 9 -5/8" BOT PBR I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I--1 2846' 1--■ GAS LIFT MANDRELS 1 9-5/8" FOC H 2879' F — STI MD TV D DEV TYPE VLV LATCH PORT DATE 1 3002 2945 1 OTIS SO RM 20 11/20/10 Minimum ID = 2.377" @ 12532' 3- 3/16" X 2 -7/8" LNR X-OVER 1 10901' H4 -1/2" OTIS X NIP, ID = 3.813" I I 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 10910' 1 10910' 1 - 14 - 1/2" BAKER PBR SEAL ASSY 1 t ��� 10932' 1- 19 -5/8" X 4-1/2" BKR HB PKR, ID = 4.000" I 17" BOT PBR H 10983' 1 9 -5/8" X 7" BOT LNR TOP PKR H 11023' _i ■:� 9 -5/8" CSG, 47 #, N -80, ID = 8.681" H 11447' 1 11884' I-I BAKER KB LNR TOP PKR, ID = 2.560" I 1 BTM OF BKR SEAL ASSY, ID = 2.390" H 11896' � 1 11892' J-I 3.70" OD BKR DEPLOYMENT SLV, ID = 3.00" 1 ., pi I 11898' ` 1 T OP OF 3 -1/2" LNR, 9.3 #, ID = 2.992" I r; , 0 1 3 -112" X 3 -3116" LNR XO, ID = 2.786' H 12437' V4 � � � 4 -1/2" X 7" LNR MILLOUT WINDOW (E -03A) 1 TOP OF WHIPSTOCK H 12484' 1.42 I 12518' - 12525' ( OFF WHIPSTOCK ) 12494' / RA PIP TAG 1 I� V1 _ ∎ 1 1 12532' 1 X 2 -7/8" LNR XO, ID = 2.377" I 141114 4 WO* • 111111 4 13025' 1 — 2 -7/8" WFD COMPOSITE PERFORATION SUMMARY 1 1 1 4 X + ` ►/ PLUG (06/22/07) 11 ►11111 REF LOG: SWS MCNL ON 02/12/02 k4 404 '�' r 13340' — - 7/8" CIBP SET (07/31/07) ►�� 1 111 ANGLE AT TOP PERF: 81 @ 12805' ►111111th ►/∎ Note: Refer to Production DB for historical perf data 111 ♦111' SIZE SPF INTERVAL Opn /Sqz DATE ►'4*t 4� ` 2" 6 12805 - 12830 0 06/23/09 "04 2" 6 12867 - 12892 0 06/23/09 / 2" 4 13110 - 13135 0 07/31/07 r1y11111111/111. 1••••••• 2" 4 13135 - 13260 C 02/12/02 ∎1�1�1�1�1�1�1+ 1 - � 41111. 2" 4 13410 - 13635 0 02/12/02 ■•1•1•1•1•1•1•, PBTD 13640 1�� 1 '1�1�1�1�1 v o , 1 2 - 7/8" LNR, 6.5 #, L - 80, .0058 bpf, ID = 2.377" H 13708' 1 1 1 I 7" LNR, 29 #, N -80, ID = 6.184" H 12862' l.01 x.1.1.1, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/06/76 ORIGINAL COMPLETION 06/23/09 DBM/TLH PLUG SET, ADPERFS WELL: E-03A 10/24/89 RWO 09/08/09 KDC/TLH GLV C/O (07/27/09) PERMIT No: 201 -2170 02/12/02 CTD SIDETRACK (E -03A) 11/24/10 WEC/PJC GLV C/0 (11/20/10) API No: 50- 029 - 20181 -01 03/02/02 CH/TP CORRECTIONS SEC 6, T11 N, R14E, 1053' SNL & 502' WEL 09/17/03 CMO/TLP DATUM MD CORRECTION 1 08/04/07 JGM/SV SET CIBP/ ADPERF (07/31/07) BP Exploration (Alaska) .OPERABLE: E-03A (PTD #20~70) Tubing Integrity Restored Page 1 of 2 ~ Schwartz, Guy L (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeiilntegrityEngineer@BP.comj Sent: Thursday, July 30, 2009 12:02 PM 30'~ ~~ To: GPB, Area Mgr Cen#ral (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Welis Opt Eng; GP6, Optimization Engr; Ramsay, Gavin; Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L {DOAj Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer Subject: OPERABLE: E-03A (PTD #2012170) Tubing Integrity Restored All, Well E-03A (PTD #2012170) passed a MITIA after setting a dummy gas lift valve confirming tubing integrity has been restored. The well has been reclassifed as Operable and may be returned to production. Please be aware that the fA is liquid packed and the IA pressure will increase due to annular fluid expansion as the flowing temperture increases. Action should be taken to bleed off this pressure. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity En9ineer Sent: Tuesday, July 21, 2009 4:04 PM ~t,, ''~n4,ir.~;:-~.~ jG~ •~=;. ,t .._ ~~i~w ~..r..r:. ~ kWrticN .ts _. To: GPB, Area Mgr Centrai (GCi/3/FS3); GPB, GCl OTL; GPS, GC3 Wellpad Lead; Rossberg, R Steven; Engei, Harry R; NSU, ADW Well Operatfons Supe~visor, GP6, Wells Opt Eng; GP6, Optimization Engr; Ramsay, Gavin; 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; Schwartz, Guy (DOA) <guy.schwartr@alaska.gov> Cc: Clingingsmith, Mike ](CH2M Mill); NSU, ADW Well Integrity Engineer Subject: UNdER EVALUATION: E-03A (PTD #2012170) 5ustained casing pressure due to TxIA ~mmunication AlI, Well E-03A (PTD #2012170) has been found to have sustained casing pressure on #he IA. The weii broke MOASP on 07/18/09 with TIO pressures of 8SV/2300/800 psi. A TIFL was conducted on 07/20/09 that failed due to pressure buifd up. The well has been reclassified as Under Evaluation and has been placed under the 28 day Gock. The following corrective action has been put in place. 1. D: TIFL - FAILED 2. S: Set DGLV in STA # 1 3. F: MIT-IA to 3000 psi, LLR if fails A TIO plot and we{Ibore schematic are attached. Please contact me with any questions. « File: E-03A TI4 Plat.doc »« File: ~-p3A.pdf » ?/30/2009 OPERABLE: E-03A (PTD #2012170) Tubing Integrity Restored Page 2 of 2 Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 8/31 /2009 I TREE= 4-1t16" FMC WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 56.63' BF. ELEV = 27.66' KOP = 3400' Max Angle = 96 @ 13154' Datum MD = 12335' Datum ND = 8800' SS • s-sis^ Foc I~ 2095' 13-318" CSG, 72#, L-80, ~= 12.347" ' 2846~ 9-5/8" FOC 2879~ Minimum ID = 2.377" @ 12532' 3-3/16" X 2-7/8" LNR X-OVER 4-1(2" TBG, 12.6#, L-8Q, .0152 bpf, ID = 3.958" ~~ 10910~ ~ ~° BOT PBR ~ 10983' 9-5/8" X 7" BOT LNR TOP PKR 11023~ 9-5/8" CSG, 47#, N-80, ID = 8.681" ~ 1447~ BTM OF BKR SEAL ASSY, ID = 2.390" ~ 11896~ 3-1/2" X 3-3/16" LNR XO, ID = 2.786' 12437' TOP OF WH~STOCK~ 12484~ RA PIP TA G 12494' PERFORATION SUMMARY REF LOG: SWS MCNL. ON 02/12/02 ANGLE AT TOP PERF: $1 @ 12805' Note: Refer to Roduction DB for historical perf data SIZE SPF IMERVAL Opn/Sqz DATE 2" 6 12805 - 12830 O 06l23/09 2" 6 12867 - 12892 O 06/23l09 2" 4 13110 - 13135 C 07/31 /07 2" 4 13135 - 13260 C 02112/02 2" 4 13410 - 13635 C OZ/12l02 7" LNR, 29#, N-80, ID = 6.184" ~~ 12$62~ ~FEfY NOTES: WELL ANGLE > 70° @ E~0 3 A 12570' &> 90° @ 12890'. 1989' 4-1 /2" OTIS SSSV N, ID = 3.813" 2141' ~--~ TOP OF 9-5/8" BOT PBR GAS LIFf MANDRELS MD ND DEV TYPE VLV LATCH PORT DATE 3002 2945 1 OTiS S/O RA 20 02/28/0, 10901 ~ 4-1/2" OTIS X NIP, ID = 3.813" 10910~ -14-112" BAKER PBR SEAL ASSY ~ 10932~ 9-5/8" X 4-1 /2" BKR HB PKR, ID = 4.000" 11884~ --~ BAKER KB LNR TOP PKR ID = 2.560" ~ 11892~ 3.70" OD BKR DEPLOYMENT SLV, ID = 3.00" 11898~ TOP OF 3-112" LNR, 9.3#, ID = 2.992" 4-1/2" X 7" LNR M~LOUT WINDOW (E-03A) ~~ 12518' - 12525' ( OFF WFi1P5TOC1< ) ~ 12532~ 3-3/16" X 2-7(8" LNR XO, ID = 2.377" I 13025' 2-7~s" WFD COMPOSITE ~ ~u~ (osr22io~) _ 13340' 2-7/8" CIBP SET (07/31/07) Ps~ro 13640' ' 2-718" ~NR, 6.5#, L-80, .0058 bpf, ID = 2.377" -r 1 DATE REV BY COMMETffS DATE REV BY COMMENTS 04106R6 ORIGINAL COMPLETION 06l23l09 DBMITLH PLUG SET, ADPERFS 10/24/89 RWO 02/12/02 CTD SIDETRACK {E-03A) 03/02/02 CHfTP CORRECTIONS 09/17/03 CMO/TLP DATUM MD CQRRECTION 08/04/07 JGfvUSV SET CIBPi ADPERF (07/31/07) PRUDHOE BAY UNff WELL: E03A PERMIT No: 201-2170 API No; 50-029-20181-01 SEC 6, T11N, R94E, 1053' SNL & 502' WEL BP Exploration (Alaska) • E-03A (PTD#2012170) TIO Plot ~ -f- T~9 ^ IA -k- OA OOA ~ OOOA ~ On STATE OF ALASKA ALASI~IL AND GAS CONSERVATION COMM~N REPORT OF SUNDRY WELL OPERATIONS ~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r' _ Exploratory I- 201-2170 , 3. Address: P.O. Box 196612 St1"dtigf'BphIC r Service r 6. API Number: Anchorage, AK 99519-6612 50-029-20181-01-00 7. KB Elevation (ft): 9. Well Name and Number: 56.63 KB PBU E-03A ~ 8. Property Designation: 10. Field/Pool(s): ADLO-028299 PRUDHOE BAY Field/ PRUDHOE OIL Pool~ 11. Present Well Condition Summary: Total Depth measured 13708 - feet Plugs (measured) 13340' CIBP SET 7/31/07 true vertical 9047.72 _ feet Junk (measured) None Effective Depth measured 13641 feet true vertical 9046.47 feet Casing Length Size MD ND Burst Collapse Conductor 110' 20" 94# H-40 Surface - 104' Surface - 104' 1530 520 Surface 2846' 13-3/8" 72# N-80 Surface - 2846' Surface - 2846' 5380 2670 Production 11449' 9-5/8" 47# N-80 Surface - 11449' Surface - 8328' 6870 4760 Liner 1497' 7" 29# N-80 10983' - 12480' 8103' - 8948' 7240 5410 3-1/2"x3-3/16" 1818' 8.81# / 6.2# L-80 11890' - 13708' 8579' - 9048' x2-7/8" 6.16# ~~r ~~G~~ P rf ti d th M ~ ~ ~i ~'~~~=~~~~" ora on e ep : easured depth: SEE ATTACHED 1 ~ .. True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 10910' Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" BKR HB PKR 10932' 0 0 0 0 0 0 ~~~~~ ~~~~ 12. Stimulation or cement squeeze summary: ~ Intervals treated (measured): ~~~ ~~ '~ ~ ~Q~~' Alaska Oi: ~ ~.~~1 i.Q€~s. i~~„o~~:~6~sior~ Treatment descriptions including volumes used and final pressure: ~#titi;iiOi~~F: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 826 12709 40 959 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory I`~ Development ~_ Service ~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil r- Gas ~ WAG r GINJ r WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer =-- Signature Phone 564-4944 Date 6/29/2009 Form 10-404 ~ed 04/2006 `~- ~~ ~f'~ j{,jj_ ~ ~ ?~~(~~ ~~ Submit Original Only ~ E-03A 201-217 PFRF OTTerHMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base E-03A 2/92/02 PER 13,135. 13,260. 9,060.36 9,053.34 E-03A 2/12/02 PER 13,410. 13,635. 9,045.06 9,046.26 E-03A 7/31/07 APF ti 13,110. 13,135. 9,062.22 9,060.36 E-03A 7/31/07 BPS 13,340. 13,340. 9,049.87 9,049.87 E-03A 8/1/07 APF 13,085. 13,110. 9,062.85 9,062.22 E-03A 6/22/09 BPS C 13,025. 13,410. 9,059.13 9,045.06 E-03A 6/22/09 APF 12,867. 12,892. 9,055.51 9,056.4 E-03A 6/23/09 APF 12,805. 12,830. 9,047.87 9,051.54 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~ ~ E-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY BBLS 87 KCL 121 50/50 METH 275.1 Total _,. ~----,=-, : • . ~~~~'t ~~~~ _. ~y, , ~ ~~ ~ ~~ ' ~ ~~r~~ci~ ~i~nads~ic ~~RVOC~s, ~e~c. T~: AOGCG Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (507) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT~ The technical data listed below is being submitted herewith. Please acknovuledge receipt by returning a signed eopy of this transmittal letter to the following : BP E~loration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. a 1) Coil Flag 19-Jun-09 2] Coil Flag 22,1un-09 Signed : Print Name: ' ~i~'~~~ ,,'' ' y' ~i.~~~i A~,~~d,~ ,;'~ Anchorage, Alaska 99508 and ~Ui ~I~ ~~dS~ l0 ProActive Diagnostic Services, lnc. /~ ~ - /'3 ~( / ~ ~ I f Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c (907~ 245,8952 05-18A _ , cDE 50-029-21960-01 E 03A E~ . 50-029-20181- Date : PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATtONAL AIRPORT RD SUITE C, AIVCHORAGE, !\K 99518 PHONE: (907)245-8951 Fnx: (907~245-88952 E-MAIL : .: ~ WEBSITE : ~,~~~ C~.~Doaunerts and Settings\Oama~Desktop'~Transmit_BP.docx 01/11/08 ~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII Job # Loe Desrrintinn NO. 4547 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt. Date. RL Cnlnr CD Z-06 11594523 STATIC TEMP LOG - 09/09107 1 14-18B 11975743 SBHP SURVEY 12108/07 14-02C 11767144 SBHP LOG - 11/02/07 1 H-24A 11963073 MEM CBL - j 11/30/07 1 C-35A 11624351 CEMENT BOND 8 GRAVEL PACK -~ 11/03107 1 MPH-19 11982423 USIT (p ~ 12/10/07 1 1 E-03A 11628773 MEM PROD PROFILE _ ( 05/09/07 1 E-116 11434760 OH LDWG EDIT (DSI) - G 10/29/06 1 1 G-06A 11209587 MCNL - (~ L-~ 02/25106 1 1 D-076 11162822 MCNL $'- ~ ~ 12104105 1 1 G-10C 11209607 MCNL Q(p - a 06/15106 1 1 G-09B 11649989 MCNL ~ ~- ~ l () ( b'p~ 09/11/07 1 1 K-086 11745243 MCNL ~ '~- ~ ~ 11/06/07 1 1 V-07 11978425 COMPOSITE CBL 12/06/07 1 V-07 1197842S USIT - ( 12/06!07 1 L2-33 11970801 RST j ' p ~ 07107/07 1 1 03-14A 40013340 OH MWD/LWD EDIT ~ I 04/23/06 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. '~ ~~~ ~'" Anchorage, Alaska 99508 R .1• Fa n Date Delivered: ' ~f~^~ ~~)~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2836 ATTN: Beth ' j Received by: f,. / • C] 09/28/07 ~iri~~~~~~~~i~ Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wQu i..-. ~ ~~;~ N(~~ t~ `~ 2007 ~ .... n.. ..a:.. NO. 4440 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 15-06A 11661158 MCNL #t L 06/21/07 1 F-266 11216200 MCNL >t! ~/ 06/06/06 1 P2-11A 11285926 MCNL ~ 04/19/06 1 1 C-31B 11745223 MCNL ~1-/ 05/31/07 1 1 E-03A 11628773 MCNL ~ C/ 05/09/07 1 1 K-12A 11745224 MCNL p _ ~ 06/02/07 1 1 18-108 11485771 MCNL s / </~-(0 11/08/06 1 1 C-086 11209599 MCNL -v (~ l'JrL 04/22/06 1 1 D-30B 11628774 MCNL .- L 05/10/07 1 1 ~v....v.~rrvv~.~a-vim.. . Y. v.v~~~.~V /'~~~Y nCIYRl911~V Vl9G VVr~ FNV1l IV. BP Exploration (Alaska) Inc. __ Petrotechnical Data Center LR2-1 ~~ 900 E. Benson Blvd. - ' Anchorage, Alaska 99508 Date Delivered: ~~~-x R ~ - ~ ~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • lr ~J u ~~."' =~ -~"~' STATE OF ALASKA ~ ~0~~'~~ ALAS A OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS , sin ~G~n 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ S~t r ~ eb ~ ,,,dd Performed: Alter Gasing ~ Pull Tubing Perforate New Pool ~ Waiver Time Extens tSrr ~ QT Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well ~'' ~~~ ~, 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Num ~~:~.„ ,~ /~/ Name: Development Exploratory 201-2170"'' "~°~/art 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-20181-01-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 56.63 KB PBU E-03A 8. Property Designation: 10. Field/Pool(s): , ADLO-028299 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present We11 Condition Summary: Total Depth measured 13708 ~ feet Plugs (measured) 13340' CIBP SET 7!31107 true vertical 9047.72 feet Junk (measured) None Effective Depth measured 13641 feet true vertical 9046.47 - feet ~~~~ tV~ y ~ ~ ~~~~ Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 94# H-40 Surface - 104' Surface - 104' 1530 520 Surface 2846' 13-3/8" 72# N-80 Surface - 2846' Surface - 2846' 5380 2670 Production 11449' 9-5/8" 47# N-80 Surface - 11449' Surface - 8328' 6870 4760 Liner 1497 7" 29# N-80 10983' - 12480' 8103' - 8948' r... 7240 5410 3-1 /2"x3-3/16" 1818' 8.81 # / 6.2# L-80 11890' - 13708' 8579' - 9048' x2-7/8" 6.16# Perforation depth: Measured depth: 13085' - 13110' 13110' - 13135' 13135' - 13260' C 13410' 13635' True Vertical depth: 9063' - 9062' 9062' - 9060' 9060' - 9053' C 9045' - 9046' Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 Surface - 10910' Packers and SSSV (type and measured depth) 9-5/8"X4-1/2" BKR HB PKR 10932' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): .~ ~F~. sew ~ ~ 2007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1170 41861 43 0 1200 Subsequent to operation: 1445 43119 67 0 310 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' GINJ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 9/20/2007 Form 10-404 Revised 04/2006 ~,~ 1 ~/~~ Submit Original Only • • E-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE ~ SUMMARY 7 7/30/2007,Mem GR/CCUSet CIBPlAdperf/CTU #9. MIRU ""xContinued on 7/31/07 WSR'*" 7/31 /2007' 8/1 /2007 Mem GR/CCVSet CIBP/Adperf/CTU #9. ***Continued from 7/30/07 WSR*"* MU/RIH with PDS mem GR/CCL. Log interval 13,450' - 12,700' ctmd. Flag pipe at 13,340' ctmd. POOH verify good data. Make -9' correction to ref {og dated 12/02/02. MU/RIH with WOT 2 7/8" CIBP -Set CIBP center of element at 13340' - POH - MU/RIH with gun #1-2"-6 PF - 60° - PJ Omega- -Fire guns @ 13135' bottom shot POOH confirm guns fired OK. M/U gun run #2 - 2"-6 PF - 60° - PJ Omega Job in progress __.. _ _ . CTU #9 Continue form 7/31/07 WSR Gun run #2 - 2"-6 PF - 60° - PJ Omega OAL 25~ RIH for gun run #2 @ 13110 bottom shot Launch 1/2" fire guns POOH . At surface confirm guns fired OK . VD guns RDMO Perf intervals; 13085'-13110' 13110' - 13135' „_,,,,,,,,JOB COMPLETE""'"'~ FLUIDS PUMPED BBLS 30 1 % KCL 30 TOTAL Page 1 of 1 Mound®r, Thomas E (DOA) From: Maunder, Thomas E (DOA} Sent: Wednesday, August 15, 2007 9:37 AM To: 'Preble, Gary B (SAIC)' Cc: 'Arthur C Saltmarsh'; 'Stephen F Davies' Subject: PBU E-03A (201-217) "~.i~~6~~~ NOV ~ ~ 2Q07 Gary, I am reviewing the 404 you submitted far the additional perforations on this well. The information on the 404 does not appear to agree with the new worK detailed an the operations summary. The new bridge plug is correctly listed in the upper LH portion of bloct< 11. The new perforated intervals have not been added to those listed on the 404. Also, there is no indication or note that the perfs from 13410 -13635 are now isolated below the new BP at 13340. On the operations summary, I have a comment regarding the pert gun descriptions. The descxiptions of gun #1 and gun #2 are different and #1 is incomplete. From the informatron on #2, it is possible to determine that the new perforated interval is 13085 -13110. The only thing that can be determined from the description or details of #1 is that the bottom shot was at 13135. Would you please pass on my request that the gun descriptions or shot intervals be described more completely. I also request you resubmit the 404 sheet including the correct information. Not sure what you can da about providing more complete information on the gun/interval descriptions but that would be appreciated as well. Call or message with any questions. Tom Maunder, PE AOGCC ~Q~~Q~L~ ~~) ~~~~~~~ ~E~~ ~ ~ ~ _ ~`~ 'R'c ~76r ~' S~1~c_ CJ~C G~,~ ~ ~~ ~~ lam `~ 8/15/2007 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc ) ~- M~ Î--- (j~ ~ DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 Permitto Drill 2012170 Well Name/No. PRUDHOE BAY UNIT E-03A Operator BP EXPLORATION (ALASKA) INC .5.¡4 ~¡ '1 / J~ ö ~ ~ API No. 50-029-20181-01-00 MD 13708 ..-- NO 9048 ,.- Completion Date 2/13/2002 ,-- Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ._- Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ../ -(Ó702 ~D C ! V1ó632 ~ C Well Cores/Samples Information: Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 6 12470 13708 Open 3/15/2002 , ¡ 1 11670 13638 Case 3/5/2002 I ~ Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ,ID Chips Received? ....::£..lli- Daily History Received? @N 8>N Formation Tops Analysis Received? ..Y lli -c, Comments: Compliance Reviewed By: ~ Dale: (7 ~ ~ u.c=c. ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-217 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20181-01 4. Location of well at surface .,:..,~."..,--_..X 9. Unit or Lease Name "'. ,. ~"""-A'){~~" "" 1053' SNL, 502' WEL, SEC. 06, T11 N, R14E, UM . " . , ' ,~"'¡'" ,t.'\..."{~;s.' >' ~ Prudhoe Bay Unit At top of productive interval ~ ,,'¥{ilif;"'i) f ~'~ "~ :..... '/~? (, ~ rf. ' 3792' NSL, 4305' EWL, SEC. 32, T12N, R14E, UM ." --~ .&...~ ~ ~:.J, ' ""'" 1 O. Well Number At total depth "" c,"' . ' ~i ¡~ ' " ..-, ,,'"t Æ"'" E-03A ,., - "",' .. Ic, t ¡. 3176' NSL, 4201' EWL, SEC. 32, T12N, R14E, UM "" .~~ ~.'- _:: ,'" ,", " ""'e",!,""'_"-"'-""'~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Dès¡Q'hãtfðT1"artd Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 56.63' ADL 028299 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 15. Water depth, if offshore 16. No. of Completions 1/31/2002 2/9/2002 2/13/2002 N/A MSL One 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 13708 9048 FT 13641 9046 FT 181 Yes ONo (Nipple) 1989' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, Memory CNL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# H-40 Surface 104' 26" 50 sx Arcticset Lite 13-3/8" 72# N-80 Surface 28461 18-1/2" 4450 sx Permafrost 9-5/8" 47# N-80 Surface 11449' 12-1/4" 1335 sx Lite, 212 sx 'G" 400 sx PF & 200 sx PF, Top Job) 7" 29# N-80 10983' 12480' 8-1/2" 847 sx Class 'G' 3-1/2" x 3-3/16" 8.81# /6.2# L-80 11890' 13708' 3-3/4" 64 sx Class 'G' x 2-7/8" /6.16# 24. Perforations open to Production (MD+ TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 12480' 1 0932' MD TVD MD TVD (TOW) 13135' - 13260' 9060' - 9053' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13410' -13635' 9045' - 9046' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protect with 38 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) March 3, 2002 Flowing Date of Test Hours Tested PRODUCTION FOR OIL -BBL GAs-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 28. CORE DATA -. ,.~~, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chi V-..., I_.J ,- No core samples were taken. APR 2 2002 :.1 ry AI8aOU&GlSConI. ConnniSSIon I: , ',':' AnctIonIg8 I ' i I, 'Ii I: I Form 10-407 Rev. 07-01-80 RBDMS BFL APR \.1 f Submit In Duplicate 8 2002 ( ( 29. Geologic Markers Marker Name Measured True Vertical Depth Depth 25N 12670' 9020' 25P 12688' 9024' Zone 1 B 13010' 9058' Zone 1 B 13080' 9063' 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date 0 .~ .O~ E-03A Well Number 201-217 Permit No.1 A Prepared By Name/Number: Terrie Hubble, 564-4628 roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 1/29/2002 1/30/2002 1/31/2002 (' \ ( BP EXPLORATION Operations Summary Report E-03 E-03A REENTER+COMPLETE NABORS NABORS 38 00:00 - 06:00 From - To Hours Activity Code NPT PRE 06:00 - 13:00 13:00 - 14:00 14:00 - 22:30 22:30 - 00:00 00:00 - 00:30 00:30 - 02:00 02:00 - 04:30 04:30 - 07:00 07:00 - 07:30 07:30 -11:15 11: 15 - 11 :30 11 :30 - 12:00 12:00 - 14:30 14:30 - 21 :00 21 :00 - 00:00 00:00 - 00:50 00:50 - 03:00 03:00 - 05:00 05:00 - 05:45 05:45 - 06:30 06:30 - 07:15 07:15 - 08:10 08:10 - 09:00 09:00 - 09:30 09:30 -10:15 10:15-11:55 11 :55 - 13:30 13:30 -13:40 13:40 - 15:05 6.00 MOB P 7.00 RIGU P 1.00 RIGU P 8.50 RIGU P 1.50 RIGU P 0.50 STWHIP P 1.50 STWHIP P 2.50 STWHIP P 2.50 STWHIP P 0.50 STWHIP P 3.75 STWHIP P 0.25 STWHIP P 0.50 STWHIP P 2.50 STWHIP P 6.50 STWHIP P 3.00 STWHIP P 0.83 STWHIP P 2.17 STWHIP N 2.00 STWHIP P 0.75 STWHIP P 0.75 STWHIP P 0.75 STWHIP N 0.92 STWHIP N 0.83 STWHIP N 0.50 STWHIP N 0.75 STWHIP N 1.67 STWHIP P 1.58 STWHIP P 0.17 STWHIP P 1.42 STWHIP N Phase PRE PRE PRE PRE WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT DFAL WEXIT WEXIT WEXIT WEXIT DFAL WEXIT DFAL WEXIT SFAL WEXIT DFAL WEXIT DFAL WEXIT WEXIT WEXIT WEXIT DPRB WEXIT Page 1 of 7 Start: 1/16/2002 Rig Release: 2/13/2002 Rig Number: Spud Date: 1/20/2002 End: 2/13/2002 Description of Operations Dig out cellar. Complete O/A & ¡/A line hook up. Raise & scope up DRK secure tighten load lines Hook up elec lines between pits. Break out and replace 1" steam line before able to turn steam around. Raise beaver slide set in pipe racks and catwalk. Check pressure on tree. 0 psi. Break tree cap and remove bolts on BOP carrier. Nipple up BOPE. Rig accepted @06:00. Wait on Veco for tanks. Continue rigging up Set BPV. BOPE test. Working on ice plug. P/U injector and change pack offs. Rehead coil. Pull test and pressure test coil connec. M/U milling BHA. Circ MeOH out of coil. Back side line is frozen. RIH w/milling assy. Up wt 42K. Own wt 17K. Found some cement strings. Tag whipstock @12517'. Time milling slot to 12518'. POH to change BHA OOH. PU speed mill and short string reamer. RIH tagged at 12518'. Continue milling window f/12518' to 12524.5' Drill formation to 12529.7' slow drilling. Swapped hole to new Flo-Pro mud. Continue drilling formation but unable to make further footage. Hole has been swapped to Flo-Pro mud. Window: 12519' to 12525' . TOH with window milling assembly. Was able to free-spin the motor by hand. Will teardown later. UD milling BHA and P/U build section BHA with 2.6* motor. RIH to 3540' Shallow hole test Anadrill's MWD and TORC tools. TORC not responding to commands. (PJSM with crews) TOH to p/u TORC back-up tool Download TORC (no data simply did not turn on) Change out TORC tool stab on injector. Nabor's pump not pumping? Swap pumps to Dowell to keep coil form freezing. RIH to 3540' Shallow hole test Anadrill's MWD and TORC tools. Okay RIH to 12320'. (found piece of wood under one of the valves on the Nabors pump) Log tie-in 60'/hr from 12320' to 12400'. -38' correction Update on BHI motor used for milling: Broken upper radial bearing which connects to the "transmission" by way of a slick Morse Taper. When it failed it also took out the top 2 threads of the output shaft pin. Further close inspection and results to follow in the coming days. RIH tagged at 12489.5' This would put the corrected window depths based on log tie-in correction as follows: Top 12480' Bottom 12486' Drilled f/12489.5' to 12490.5'. Frequent stalls. Needed Printed: 2/20/2002 11 :26:05 AM ( (" BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: E-03 Common Well Name: E-03A Spud Date: 1/20/2002 Event Name: REENTER+COMPLETE Start: 1/16/2002 End: 2/13/2002 Contractor Name: NABORS Rig Release: 2/13/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/31/2002 13:40 -15:05 1.42 STWHIP N DPRB WEXIT repeated orientation due to TORC not being able to recognize last "constant" TF setting. (This has been a long standing problem with the TORC orienter.) TORC finally not responding to commands. Bottoms-up sample has small amount of formation w/ cement and metal. Really dont feel good about window area. The bit did drill off but not as expected with the repeated stalls 15:05 - 17:30 2.42 STWHIP N DFAL WEXIT TOH for Weatherford straight motor to cleanout window area and make another 5' of hole. (1 st TORC orienter will be ready to RIH est 4 hrs. found failed acquisition board.) 17:30 - 17:45 0.25 STWHIP N DFAL WEXIT Set back injector. 17:45 - 18:15 0.50 STWHIP N WEXIT Crew change and PJSM on handling BHA. 18:15 - 19:30 1.25 STWHIP N DFAL WEXIT UD build BHA and p/u mills. 19:30 - 21:45 2.25 STWHIP N DFAL WEXIT RIH tag at 12490.5'. 21 :45 - 00:00 2.25 STWHIP N DPRB WEXIT Clean-up window area 200 psi max motor work. Drilled to 12491.5'. 2/1/2002 00:00 - 02:50 2.83 STWHIP N DPRB WEXIT Continue cleaning out window area and drill to 12493'. Max motor work while drilling 300 psi but motor. Concentrated on window area. 02:50 - 05:30 2.67 STWHIP N DPRB WEXIT TOH. Still on the well with the injector. 05:30 - 06:00 0.50 STWHIP N DPRB WEXIT Safety meeting with crew change out. Discuss current weather conditions. -38* with wind chills -80 to -85*. All coil units in the field shutdown for weather. 06:00 - 00:00 18.00 STWHIP N WAIT WEXIT Shutdown due to weather conditions. 0700 RIU and drop circ-sub. RIH to 3500' circulate at 1.5 bpm. 1300 hrs RIH to 5000' for warmer circ temps. 1700 hrs temp -40 w/1 0 mph winds 1900 hrs temp -40 w/ 5 mph winds 2230 hrs temp -42 w/ 3 mph winds 2/2/2002 00:00 - 06:00 6.00 STWHIP N WAIT WEXIT Continue waiting on weather. 0600 hrs temp -39 w/ 3 mph winds 06:00 - 11 :00 5.00 STWHIP N WAIT WEXIT WOW 1100 hrs warming up. -35 11:00-11:15 0.25 STWHIP N WAIT WEXIT PJSM changing BHA's 11:15-12:30 1.25 STWHIP N DPRB WEXIT TOH 12:30 - 14:10 1.67 STWHIP N DPRB WEXIT UD BHA #4 make-up new MHA P/U BHA #5 14:10 - 14:45 0.58 STWHIP N DPRB WEXIT RIH to 3500'. 14:45 - 15:20 0.58 STWHIP N DPRB WEXIT Shallow hole test Anadrill tools. MWD-ok TORC-flunked 15:20 - 16:15 0.92 STWHIP N DFAL WEXIT TOH for Sperry mechanical orienter. 16:15 - 17:00 0.75 STWHIP N DFAL WEXIT Drop TORC p/u Sperry orienter 17:00 - 17:35 0.58 STWHIP N DFAL WEXIT RIH to 3600'. 17:35 - 17:50 0.25 STWHIP N DFAL WEXIT Shallow hole test tools. MWD-ok Sperry orienter ok 17:50 - 19:25 1.58 STWHIP N DPRB WEXIT RIH to 12320'. (temp -30) 19:25 - 20:40 1.25 STWHIP N DPRB WEXIT Log tie-in 20:40 - 20:50 0.17 STWHIP N DPRB WEXIT RIH tagged at 12493' 20:50 - 22:25 1.58 STWHIP N DPRB WEXIT At 55R try to drill but motor giving us weak stalls at 500 psi over FS. Orient to highside and try again but continued stalls at 12491. Orient to 20R with same results. Motor appears to be too weak to drill off. 22:25 - 00:00 1.58 STWHIP N DPRB WEXIT TOH 2/3/2002 00:00 - 00:30 0.50 STWHIP N DPRB WEXIT TOH 00:30 - 01 :40 1.17 STWHIP N DPRB WEXIT No visable problem with motor. Bit #6 has chipped cutters. P/U another Anadrill motor set it up straight. Run used M-09 bit. Printed: 2/20/2002 11 :26:05 AM ( ( BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: E-03 Common Well Name: E-03A Spud Date: 1/20/2002 Event Name: REENTER+COMPLETE Start: 1/16/2002 End: 2/13/2002 Contractor Name: NABORS Rig Release: 2/13/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/3/2002 01 :40 - 04:00 2.33 STWHIP N DPRB WEXIT RIH to EOP flag correct depth. RIH tagged bottom dry at 12489.6' 04:00 - 07:50 3.83 STWHIP N DPRB WEXIT Drill slowly with frequent stalls 700-800 psi range. FS 3400 stalls 4200 from 12489.6' to 12496'. Finally unable to stall motor. Bald bit maybe. 07:50 - 10:35 2.75 STWHIP N DPRB WEXIT TOH 10:35 -11:25 0.83 STWHIP N DPRB WEXIT Change out MWD probe. Reset motor to 2.77* p/u parabolic mill and string reamer. Bit #7 all compacs broken, missing 1 from center 11 :25 - 14:30 3.08 STWHIP N DPRB WEXIT RIH to 12200' correct to EOP. 14:30 - 17:20 2.83 STWHIP N DPRB WEXIT Drill 12496 to 12500'. Orienting to 10-20*R. Samples show no sand, 90% cement 10% metal. Sudden pump pressure increase to 4600 psi may be a plugged jet. 17:20 -18:00 0.67 STWHIP N RREP WEXIT Pumps showing 800 psi trapped pressure when shut down. Traced down to elecrical panels and then reset. 18:00 -18:30 0.50 STWHIP N DPRB WEXIT Orient to 30*R 18:30 - 19:00 0.50 STWHIP N DPRB WEXIT Try to drill ahead but pump pressures are too high 4850 psi, and making little progress. 19:00-21:00 2.00 STWHIP N DPRB WEXIT TOH (All roads at phase II driving condtions) temp -21 winds gusting to 35 mph 21 :00 - 23:10 2.17 STWHIP N DPRB WEXIT Mill was almost completely plugged with metal. One 9" long sliver was wedged up through the middle of mill along with numerous small nodes of metal. Discuss with town crew. Conclusion is we may be riding down the middle of the 7" casing, being "locked-in" with the parabolic mill's concave face. Plan is to p/u regular DP0261 window speed mill and 1 1/2* motor. M/U BHA #9 23:10 - 00:00 0.83 STWHIP N DPRB WEXIT RIH shallow test MWD ok continue RIH 2/4/2002 00:00 - 01 :35 1.58 STWHIP N DPRB WEXIT Continue RIH to log depth. 01 :35 - 02:25 0.83 STWHIP N DPRB WEXIT Log tie-in -19' correction. 02:25 - 02:35 0.17 STWHIP N DPRB WEXIT RIH tagged at 12499'. 02:35 - 07:15 4.67 STWHIP N DPRB WEXIT With 30R TF start milling/drilling away from 7" casing. Last sample at 12503' 90% sand 10% cheart no metal. Drill formation to 12509.6'. 07:15 - 00:00 16.75 STWHIP N WAIT WEXIT Pull up into casing and circulate at min rate while WOW. Phase III conditions. 2/5/2002 00:00 - 06:00 6.00 STWHIP N WAIT WEXIT WOW. Phase III conditions. Fuel delivery at 0200 hrs. 06:00 - 00:00 18.00 STWHIP N WAIT WEXIT WOW. Phase II on Spine road EOAIWOA. Phase III on access roads and pads. Coordinating change out of crews and freshwater f/ rig boilers and camp. Nabors crew chg out at 1000 hrs. Change out Dowell/Anadrill hands at 1800 hrs. All access roads still phase III. Winds 15-25 mph decreasing 2/6/2002 00:00 - 05:00 5.00 STWHIP N WAIT WEXIT WOW Phase II spine road, phase III all access roads. 05:00 - 07:45 2.75 STWHIP N DPRB WEXIT TOH. (At 0500 hrs field wide driving conditions Phase I spine road, Phase II all access roads.) Notified AOGCC of BOP test. Witnessing wavied by Jeff Jones. 07:45 - 08:15 0.50 STWHIP N DPRB WEXIT UD BHA #9. Freeze protect lines. 08:15 - 09:05 0.83 STWHIP N WAIT WEXIT Valve crew stuck on Twin Tower road. Finish up securing outside lines from freezing. 09:05 - 09:50 0.75 BOPSUF P DECOMP Line-up to test BOP stack against master valve. (still waiting on valve crew). 09:50 - 10:20 0.50 BOPSUF P DECOMP Install TWC 10:20 -16:15 5.92 BOPSUF P DECOMP Test BOPE 250 low 5000 high Printed: 2/20/2002 11 :26:05 AM ( ( BP EXPLORATION Page 4 of 7 Operations Summary Report Legal Well Name: E-03 Common Well Name: E-03A Spud Date: 1/20/2002 Event Name: REENTER+COMPLETE Start: 1/16/2002 End: 2/13/2002 Contractor Name: NABORS Rig Release: 2/13/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/6/2002 16:15 - 16:45 0.50 BOPSUF P DECOMP Remove TWC 16:45 - 17:45 1.00 DRILL P PROD1 P/U BHA #10 17:45 -18:00 0.25 DRILL P PROD1 Change to FloPro 18:00 -18:30 0.50 DRILL P PROD1 PJSM stab on to well. 18:30 - 21 :14 2.73 DRILL P PROD1 RIH t012,397'. 21 :14 - 22:20 1.10 DRILL P PROD1 Tie in -36' correction 22:20 - 00:00 1.67 DRILL P PROD1 Tag bottom. Sent Absolute command. NO Go. Orientate. TORC working but not gving one for one. 2/7/2002 00:00 - 01 :42 1.70 DRILL P PROD1 Orientate 60R FS 2800psi. Directionally drill at 2.7 bpm 3150 psi 60 ROP. drill to 12550 01 :42 - 01 :57 0.25 DRILL P PROD1 Survey 01 :57 - 03:04 1.12 DRILL P PROD1 Oriented at 80R FS 2800psi. Directionally drilling at 2.6 bpm 3000psiat12590 03:04 - 03:11 0.12 DRILL P PROD1 Survey 03:11 - 04:55 1.73 DRILL P PROD1 Directionally drill to 12620. 04:55 - 05:07 0.20 DRILL P PROD1 Wiper trip 110'. 05:07 - 05:20 0.22 DRILL P PROD1 Survey. Rate of build to high. 05:20 - 07:15 1.92 DRILL P PROD1 POH to dial down motor 07:15 - 08:25 1.17 DRILL P PROD1 Reset motor to 1.83* download TORC 08:25 - 11 :00 2.58 DRILL P PROD1 RIH to 3500' shallow hole test tools-ok continue RIH. Look for winow but nothing indicated. RIH to bottom dry tag and correct -30'. 11 :00 - 12:00 1.00 DRILL P PROD1 Pull up hole to 12555' bit depth and start log tie-in looking for RA tag at 12494', correction -5'. 12:00 - 12:15 0.25 DRILL P PROD1 RIH and orient TF 12:15 - 13:25 1.17 DRILL P PROD1 Directional drill f/12620' to 12642'. Orienting several times while drilling. Drifting. 13:25 - 13:45 0.33 DRILL N DFAL PROD1 Sending commands to Anadrill TORC with no responce. DEAD 13:45 - 16:00 2.25 DRILL N DFAL PROD1 TOH flag EOP 11700' 16:00 - 16:50 0.83 DRILL N DFAL PROD1 UD TORC and P/U Sperry orienter. 16:50-19:17 2.45 DRILL N DFAL PROD1 RIH shallow test MWD and SS - ok continue RIH to 12,645'. 19:17 - 19:34 0.28 DRILL P PROD1 Survey 19:34 - 20:38 1.07 DRILL P PROD1 Drill to 1268. Stacking tough drilling. 20:38 - 20:50 0.20 DRILL P PROD1 Short trip to window 190'. 20:50 - 22:32 1.70 DRILL P PROD1 Directionally drill to 12,755'. 22:32 - 22:47 0.25 DRILL P PROD1 Survey 22:47 - 23:00 0.22 DRILL P PROD1 Directionally drill to 12,768'. 23:00 - 23:15 0.25 DRILL P PROD1 Short trip to the window 258'. 23:15 - 00:00 0.75 DRILL P PROD1 Directionally drill to 12768'. Stacking 2/8/2002 00:00 - 01 :08 1.13 DRILL P PROD1 Directionally drill to 12,850. Will pull early for target BHA. Build assembly continues to give build rates greater than planned due to the good cementation of the sands. 01:08 - 01:30 0.37 DRILL P PROD1 Short trip 324' 01 :30 - 01 :50 0.33 DRILL P PROD1 Directionally drill to 12850. 01 :50 - 04:50 3.00 DRILL P PROD1 POH for BHA for the horizontal target interval. 04:50 - 07:00 2.17 DRILL P PROD1 Change out MWD probes, p/u new motor set at 1.15* expected DLS 12*/100'. Bit>survey 27.99' 07:00 - 09:20 2.33 DRILL P PROD1 RIH to 3600' shallow test tools-ok continue RIH 09:20 - 10:40 1.33 DRILL P PROD1 Log tie-in at RA tag +17' (plus) correction 10:40 -10:45 0.08 DRILL P PROD1 RIH to bottom tagged at 12850' 10:45 - 11 : 15 0.50 DRILL P PROD1 Orient TF to 60L. 11:15 -15:10 3.92 DRILL P PROD1 Directionally drill f/12850' to 12292'. On bottom 3900 psi off bottom 3340 at 2.5 bpm (plan late afternoon mud swap) Printed: 2/20/2002 11 :26:05 AM (i , ( BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: E-03 Common Well Name: E-03A Spud Date: 1/20/2002 Event Name: REENTER+COMPLETE Start: 1/16/2002 End: 2/13/2002 Contractor Name: NABORS Rig Release: 2/13/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/8/2002 11:15 -15:10 3.92 DRILL P PROD1 Heated both KCL uprights to 120* 15:10 -15:40 0.50 DRILL P PROD1 Wiper trip to window 492'. No problems 15:40 -18:00 2.33 DRILL P PROD1 Directionally drill f/12292' to 13,060. Start mud swap. 18:00 -18:23 0.38 DRILL P PROD1 Crew change PJSM 18:23 -19:20 0.95 DRILL P PROD1 Attempting to orientate (Sperry) 19:20 - 20:20 1.00 DRILL P PROD1 Directionally drill to 13,150'. 20:20 - 21 :00 0.67 DRILL P PROD1 Short trip 640' 21 :00 - 22:30 1.50 DRILL P PROD1 Attempting to orientate. 4 attempts in open hole one in casing NO GO. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 POH for orientator. 2/9/2002 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 Continue to POH. 01 :00 - 02:55 1.92 DRILL N DFAL PROD1 Changeout Sperry orienter for Weatherford. Unable to PU Anadrill real time resistivity tool. Tool requires a special XO which was incorrectly cut. 02:55 - 05:30 2.58 DRILL N DFAL PROD1 RIH to 3500 shallow hole test O.K. Continue to RIH to 12300'. 05:30 - 06:40 1.17 DRILL N DFAL PROD1 Log tie-in down starting at 12300' bit depth -40' correction. 06:40 - 07:00 0.33 DRILL N DFAL PROD1 RIH 07:00 - 07:15 0.25 DRILL P PROD1 Orient to 90R TF. (Weathorford Orientor) 07:15 -10:30 3.25 DRILL P PROD1 Directionally drill f/13150' to 13300'. off bottom 3000 psi on bottom 3450 psi at 2.5 bpm 60-80'/hr 10:30 - 11 :00 0.50 DRILL P PROD1 Wiper trip 750'. 11 :00 - 14:45 3.75 DRILL P PROD1 Directionally drill f/13300' to 13450'. No mud losses drilling through fault at +/- 13345'. 14:45 - 16:00 1.25 DRILL P PROD1 Wiper trip 950'. 16:00 - 16:50 0.83 DRILL P PROD1 Directionally drill f/13450' to 13500' stacking weight. No mud losses. 16:50 - 17:10 0.33 DRILL P PROD1 Wiper trip 500'. 17:10 - 22:20 5.17 DRILL P PROD1 Directionally drill f/13500' to 13678'. 22:20 - 23:10 0.83 DRILL P PROD1 Wiper trip 200'. 23:10 - 23:25 0.25 DRILL P PROD1 Directionally drill f/13678' to 13700' TD 23:25 - 00:00 0.58 DRILL P PROD1 Start wiper trip to window. 2/1 0/2002 00:00 - 00:15 0.25 DRILL P PROD1 Finish wiper up to log tie-in depth 12300' 00:15 - 01:00 0.75 DRILL P PROD1 Log tie-in (down) from 12300' +12' correction. 01 :00 - 01 :45 0.75 DRILL P PROD1 RIH tagged at 13708'. Corrected TO 13708'. Hole in good condition. 01 :45 - 03:50 2.08 DRILL P PROD1 TOH, No overpulls. 03:50 - 04:50 1.00 DRILL P PROD1 UD BHA #14. 04:50 - 06:00 1.17 DRILL P PROD1 Freeze protect coil. 06:00 - 06:30 0.50 DRILL P PROD1 Crew change. PJSM review plans for today and job assignments for running liner. 06:30 - 08:30 2.00 CASE P COMP M/U Baker CTC PT to 3500 psi pull test to 35K. Prep other tools for running liner. 08:30 -11:10 2.67 CASE P COMP P/U 2 7/8" x 3 3/16" x 31/2" liner. 11: 1 0 - 11 :25 0.25 CASE P CaMP P/U CTLRT 11 :25 - 11 :40 0.25 CASE P COMP P/U injector displace methanol with 5 bbls KCL ahead then to mud. M/U CT to liner stab on well. 11 :40 - 15:00 3.33 CASE P COMP RIH w/liner tagged at 13680' worked to bottom 13708'. P/U wt 50K 15:00 -15:50 0.83 CASE P COMP Load .625" ball and pump on seat. Pump up to 4200 psi and shear CTLRT (2888 psi design). P/U and confirm release p/u wt 32K. Top of liner: 11897' 15:50 -17:10 1.33 CASE P COMP Displace liner/hole to 3% KCL (r/u Dowell cemeters). Loading return mud to vac truck and take to Nordic 1. Printed: 2/20/2002 11 :26:05 AM ( ( ( BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: E-03 Common Well Name: E-03A Spud Date: 1/20/2002 Event Name: REENTER+COMPLETE Start: 1/16/2002 End: 2/13/2002 Contractor Name: NABORS Rig Release: 2/13/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/10/2002 17:10 -17:35 0.42 CEMT P CaMP PJSM with all crews. Review cementing procedures and safety issues. 17:35 - 18:00 0.42 CEMT P COMP Freeze protect charge pump and outside lines. 18:00 - 18:30 0.50 CEMT P COMP Crew change PJSM with new crews. 18:30 - 19:00 0.50 CEMT P COMP Batch mix cement and 35 bbls KCL w/ 2# biozan. 19:00 -19:50 0.83 CEMT P COMP PT Dowell lines to 4800 psi. Pump 13 bbls 15.8 ppg cement w/ additives. Shutdown washup lines to CT reel and load CT wiper dart. Launch dart and confirm. Follow cement with 30 bbls KCL w/ bio then 23 bbls KCL (total 53 bbls, 54.1 calculated) CT wiper dart landed at liner wiper dart. Pressure up to 2900 psi and launch liner wiper dart. Continue displacement at 2.5 bpm and land dart at landing collar with total of 64.3 bbls away. (Calculated would have been 65.9 bbls) Hold at 3300 psi bleed off and observe checks holding. CIP @ 1750 hrs. 19:50 - 23:30 3.67 CEMT P COMP With Nabors pump pressure up to 1000 psi. P/U and sting out of liner continue washing top of liner with biozan. Circulate and start POH, flag EOP, circulated some contaminated cement to surface. TOH to 300'. Unable to spool anymore pipe on reel due to ice in the sump. 23:30 - 00:00 0.50 CEMT P COMP RIH 2/11/2002 00:00 - 02:00 2.00 CEMT P COMP RIH to 4000'. Remove ice from reel sump. TOH 02:00 - 02:50 0.83 CEMT P COMP Jet stack and blow down. 02:50 - 04:20 1.50 CASE P COMP Lift off well LID CTRL T set injector on deck. RIU to circ coil and notice CTC leaking (no washouts). Take injector to floor and rehead CTC. Set injector back on deck and r/u to cicrulate same. 04:20 - 09:00 4.67 CLEAN P CaMP P/U BHA #15 and 1 1/4" CSH tbg. 09:00 - 10:30 1.50 CLEAN N COMP TOH change in plans not to make cleanout run. 10:30-11:15 0.75 EVAL N WAIT COMP Wait on tools. 11:15-11:30 0.25 EVAL P COMP PJSM on p/u of logging tools. 11 :30 - 14:30 3.00 EVAL P COMP P/U logging tools and load source. RIH w/ CSH tbg. 14:30 - 16:50 2.33 EVAL P COMP RIH w/ MCNL 16:50 - 19:45 2.92 EVAL P COMP Log MCNL starting at 11700' 30'/min tag bottom at 13665'. Log up to 11800'. RI H to bottom and lay-in 100k LSRV Flo-Pro 1: 1 to top of liner. 19:45 - 20:45 1.00 EVAL P COMP RIH to bottom and lay-in 1 OOK LSRV flo-Pro to top of liner. 20:45 - 00:00 3.25 EVAL P COMP TOH. (Trouble spooling CT on reel evenly) Set injector on deck, rig to circ coil. 2/12/2002 00:00 - 01:15 1.25 EVAL P COMP Contiune TOH w/ CSH tbg. and logging tools. 01:15-01:30 0.25 EVAL P COMP PJSM handling CNL source. 01 :30 - 01 :50 0.33 EVAL P COMP LID MCNL tools. 01 :50 - 02:20 0.50 CASE P COMP Pressure test liner lap. Failed 2000>1250 in 5min twice. 02:20 - 03:15 0.92 RUNCO~ r'N WAIT COMP Wait on tools. 03:15 - 05:00 1.75 RUNCO~ rP COMP P/U KB packer bha (85.06') and stab on injector. 05:00 - 08:30 3.50 RUNCO~ rP COMP RI H w/ packer. 08:30 - 09:40 1.17 RUNCO~ rP CaMP Launch .625" alu. ball landed on seat at 47.1 bbl away. Set KB packer. PT back side to 2500 psi 5/min-ok. Bleed off annulus. Shear off packer with 3400 psi CT pressure. Pull up seen good indication of stinging out of packer. Top of KB packer is 11884.61' md based on correction of liner top at 11892' md from MCNL ran earlier today. PBTD is 13640'md also based on MCNL. 09:40 - 12:30 2.83 RUNCOr fP COMP TOH Printed: 2/20/2002 11 :26:05 AM ( (' BP EXPLORATION Page 7 of 7 Operations Summary Report Legal Well Name: E-03 Common Well Name: E-03A Spud Date: 1/20/2002 Event Name: REENTER+COMPLETE Start: 1/16/2002 End: 2/13/2002 Contractor Name: NABORS Rig Release: 2/13/2002 Rig Name: NABORS 3S Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/12/2002 12:30 - 12:45 0.25 RUNCO~ fJ COMP UD KB running tools 12:45 -13:20 0.58 RUNCO~ fJ CaMP RlU and pressure test casing to 2500 psi for 30 min. Held good no leak-off. (Same time have PJSM about p/u perf guns.) 13:20 - 16:30 3.17 PERF P COMP P/U 512' of perf guns (including blanks) and CSH tbg. 16:30 - 18:20 1.83 PERF P COMP RIH tagged bottom. 18:20 - 18:40 0.33 PERF P COMP Crew change. PJSM covering perforating and lId perf guns. 18:40 -19:30 0.83 PERF P COMP Space out put bottom perf at 13635'. Drop .625" ball. Same time chip out ice from reel sump. Ball on seat. Pressure up to 2500 psi and fire perf guns. good surface indication of firing. Lost +/- 1 bbl. Perf zones: 13135'-13260' & 13410'-13635' 4spf 19:30 - 22:00 2.50 PERF P COMP TOH w/ coil. 22:00 - 22:55 0.92 PERF P COMP Strip off well. FP coil and set on deck. 22:55 - 00:00 1.08 PERF P COMP PJSM. UD 1 1/4" CSH tbg. 2/13/2002 00:00 - 01 :00 1.00 PERF P COMP Finsih UD 1 1/4" CSH tbg. 01 :00 - 01: 15 0.25 PERF P COMP PJSM about LID perf guns and well control procedures. 01:15 - 03:30 2.25 PERF P COMP UD 24 perf guns. All shots fired. 03:30 - 04:20 0.83 PERF P COMP P/U injector and RIH to 2500'. 04:20 - 04:55 0.58 PERF P COMP Lay in 1:1 38 bbls 100% methanol from 2500'md to surface. 04:55 - 05:15 0.33 PERF P COMP Set injector to deck. 05:15 - 07:00 1.75 RIGD P COMP Blow all surface lines to open top tank. Start RID of OS CTU #4. 07:00 - 07:30 0.50 RIGD P COMP Install BPV. 07:30 - 12:00 4.50 RIGD P COMP Continue RID equipment. N/D BOPE install cap and tested to 3500 psi. DS CTU #4 off location 1200 hrs. Nabors 3S released at 1200 hrs. Printed: 2/20/2002 11 :26:05 AM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field........ "'" .......: Prudhoe Bay Ak Well.....................: E-03A API number......... ......: 50-029-20181-01 Engineer. . . . . . . . . . . . . . . . .: E. Roux RIG:.... ..... ............: Nabors 3S / CTU # 4 STATE:...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS....... ....: Mason & Taylor ----- Depth reference -----~----------------- Permanent datum.... ......: Mean Sea Level Depth reference..........: GR Tie-In @ 12316 ft GL above permanent.......: 0.00 ft KB above permanent.......: -50000.00 ft DF above permanent.......: -50000.00 ft ----- vertical section origin---------------- Latitude (+N/S-)....... ..: 0.00 ft Departure (+E/W-)., ......: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 175.10 degrees [(c)2002 Anadrill IDEAL ID6_1C_10J 10-Feb-200206:50:51 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey...,...: MD of last survey........: Page 1 of 2 29-Jan-02 10-Feb-02 29 12450.00 ft 13708.00 ft --" ----- Geomagnetic data ---------------------- Magnetic model..,........: BGGM version 2001 Magnetic date............: 06-Feb-2002 Magnetic field strength..: 1150.18 RCNT Magnetic dec (+E/W-).....: 26.51 degrees Magnetic dip.............: 80.88 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: H. . . . . . . . . . . . . . : Dip............: of G...........: of H... . . . . . . . . : of Dip.........: Criteria --------- 1002.68 mGal 1150.18 HCNT 80.88 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees .~, ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.51 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.51 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 ANADRILL SCHLUMBERGER Survey Report 10-Feb-200206:50:51 Page 2 of 2 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Az i m (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ 1 12450.00 50.84 72.72 0.00 8872.52 -4771.59 5174.99 4504.27 6860.68 41.04 0.00 TIP 2 12480.00 50.91 72.82 30.00 8891.45 -4776.56 5181.88 4526.50 6880.49 41.14 0.35 MWD 3 12522.00 58.54 75.00 42.00 8915.69 -4783.18 5191.35 4559.42 6909.30 41.29 18.65 MWD 4 12564.00 68.40 91.00 42.00 8934.52 -4784.33 5195.68 4596.53 6937.09 41.50 41.31 MWD 5 12592.08 73.45 102.21 28.08 8943.72 -4779.01 5192.59 4622.83 6952.24 41.68 41.78 SP 6 12639.43 76.45 119.59 47.35 8956.11 -4759.16 5176.31 4665.34 6968.47 42.03 35.97 SP - ,..-.... 7 12679.08 76.53 131.69 39.65 8965.40 -4734.16 5153.90 4696.61 6972.86 42.34 29.69 SP 8 12726.48 76.30 145.99 47.40 8976.59 -4697.11 5119.31 4726.85 6967.81 42.72 29.32 SP 9 12767.15 80.13 158.49 40.67 8984.93 -4660.50 5084.15 4745.32 6954.61 43.03 31.51 SP 10 12805.05 80.70 167.99 37.90 8991.26 -4623.98 5048.41 4756.08 6935.90 43.29 24.76 SP 11 12861.02 84.70 178.56 55.97 8998.39 -4568.58 4993.36 4762.55 6900.40 43.64 20.05 SP 12 12900.22 91.60 175.36 39.20 8999.65 -4529.45 4954.27 4764.63 6873.61 43.88 19.40 SP 13 '12940.07 92.25 167.96 39.85 8998.31 -4489.72 4914.89 4770.40 6849.30 44.15 18.63 SP 14 12960.44 89.05 165.56 20.37 8998.08 -4469.57 4895.06 4775.07 6838.34 44.29 19.64 SP 15 13009.20 84.18 158.39 48.76 9000.96 -4422.21 4848.82 4790.11 6815.88 44.65 17.75 SP 16 13049.94 85.25 152.61 40.74 9004.72 -4384.01 4811.92 4806.92 6801.55 44.97 14.37 SP 17 13117.82 94.10 157.06 67.88 9005.10 -4320.42 4750.56 4835.75 6778.81 45.51 14.59 SP 18 13153.64 96.03 161.64 35.82 9001.94 -4286.09 4717.19 4848.33 6764.48 45.79 13.80 SP 19 13241.01 90.45 172.32 87.37 8996.99 -4199.89 4632.35 4867.94 6719.78 46.42 13.78 SP 6-axis 20 13270.61 91.58 176.68 29.60 8996.46 -4170.31 4602.90 4870.77 6701.58 46.62 15.21 SP 6-axis 21 13310.94 92.75 179.89 40.33 8994.94 -4130.07 4562.63 4871.98 6674.86 46.88 8.47 SP ~O 22 13350.54 94.35 184.04 39.60 8992.49 -4090.84 4523.13 4870.62 6646.93 47.12 11.21 SP 23 13421.32 93.26 196.97 70.78 8987.77 -4022.90 4453.84 4857.77 6590.50 47.48 18.29 SP 6-axis 24 13468.00 90.28 201.41 46.68 8986.33 -3980.32 4409.80 4842.44 6549.47 47.68 11.45 MWD - 25 13500.06 90.89 207.39 32.06 8986.00 -3952.38 4380.62 4829.20 6520.04 47.79 18.75 SP 6-axis 26 13544.56 89.01 213.76 44.50 8986.04 -3916.16 4342.32 4806.58 6477.57 47,90 14.92 SP 6-axis 27 13600.98 86.85 224.00 56.42 8988.08 -3875.50 4298.49 4771.24 6421.97 47.98 18.54 SP 6-axis 28 13671.00 89.07 233.62 70.02 8990.58 -3834.14 4252.47 4718.64 6352.09 47.97 14.09 MWD 29 13708.00 89.34 238.70 37.00 8991.09 -3816.24 4231.87 4687.92 6315.49 47.93 13.75 proj 03111/02 Sc~lumbll'uep NO. 1887 Alaska Data & Consulting Services 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay "- Well Job # Log Description Date Blueline Sepia Color Prints CD E-03A dn/-;:;) 17 22082 GR ROP5 DATA 02/09/02 1 E-03A I 22082 MD SLiMPULSE-GR 12/29/01 1 1 E-03A ~ 22082 TVD SLiMPULSE-GR 12/29/01 1 1 K-02C ;:lo 1- ~ J In 22072 GR ROP5 DATA 01/19/02 1 K-02C I 22072 MD SLiMPULSE-GR 01/19/02 1 1 K-02C ..JJ 22072 TVD SLiMPULSE-GR 01/19/02 1 1 _. ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 ATTN: Sherrie Receive~ ']I) 'Ü QOQ(J. .~) Date Delivered: ~" ~ .' - "002 . 'i' . J 1;'-'" I J Lv AJaska Oil & Gas Cons. Commission Anchorage 03/04/02 Schlumbergll' NO. 1862 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay "-' Well Job # Log Descñption Date Blueline Sepia Color Pñnts CD K-098 I G¡ 7-W~ 22069 MCNL 01/31/02 1 1 1 ,J-08 } J -;-04" 22062 RST-SIGMA 01111/02 1 1 1 -E-03A ....:;) n '" ~ ~} 22083 MCNL 02/12/02 1 1 1 ..-U.S. 1-15A Iqc::.",~)1"\ 22085 CNTG 02/08/02 1 1 1 /J-18 /¡¡r..::.<,.--lt}r:;)I 22070 RST-SIGMA 02/01/02 1 1 1 -D.S. 1-06A J ö¡ c: ~ noo 22071 CNTG 01/20/02 1 1 1 (J "- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2- 1 900 Eo Benson Blvd. Anchorage, Alaska 99508 RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 AnN: Sherrie Recelve~ ~ Date Delivered: t'iAR 0 5 2002 . . . I Anchor898 Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No E-O3A Date Dispatched: 14-Feb-O1 InstaliationlRig Nabors 3S 1 SLB CTU # 4 Dispatched By: Nate Rose \,--,/ MWD/LWD Log Product Delivery Data No Of Prints Surveys 2 Rece ived By: ~ L.J} OJ f'Á ,_I LWD Log Delivery V1.1 Dec '97 '-' No of Flo ies 1 . . Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 ~ ( / ~1r~1rŒ (ffi~ ~~~~æ~ ALAS KA. 0 IL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty . Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit E-03A BP Exploration (Alaska), Inc. Permit No: 201-217 Sur Loc: 1453' SNL, 1154' EWL, Sec. 06, T11N,R14E, UM Btmhole Loc. 4005' SNL, 159' EWL, Sec 32, T12N, R14E, UM Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit E-03A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~; 1f Cammy Oe{J¡sli Taylor Chair BY ORDER OF THE COMMISSION DATED this 16th day of November, 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA L AND GAS CONSERVATION COMrJ' PERMIT TO DRILL 20 AAC 25.005 ALASKp( 1 a. Type of work 0 Drill 1m Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1453' SNL, 502' WEL, SEC. 06, T11N, R14E, UM At top of productive interval 1188' SNL, 13501 WEL, SEC. 32, T12N, R14E, UM At total depth 1989' SNL, 1190' WEL, SEC. 32, T12N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028300, 1190' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 124751 MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casin Grade Cou lin 3-3/4" 3-3I16"x2-7/8" L-80 ST-L 1 b. Type of well 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 12862 feet 9191 feet 12791 feet 9146 feet Length Size .., 104' 2846' 11449' 20" X 30" 13-3/8" 9-5/8" ) ,.~ ,"' ,'I ~ 1879' 7" .. ¡. .. ... 20. Attachments Open: 12566' - 12689' Sqzd: 12381' - 12670 true vertical Open: 9002' - 9080' Sqzd: 8886' - 9068 1m Filing Fee 0 Property Plat 1m Drilling Fluid Program 0 Time vs Depth Plot Perforation depth: measured 310N .JM it tI/IÞ./DI ,Ít L { t'S 0 Exploratory 0 ,Stratigraphic Test 1m Development Oil 0 Service 0 Development Gas C'Singl one 0 Multiple Zone 5. Datum Elevation (DF or KB) 1 . 'Field and Pool KBE = 56.63' Prudhoe Bay Field 1 Prudhoe 6. Property Designation Bay Pool Dt:B?£:L/& ADL 028299 51> 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number E-03A 9. Approximate spud date 11/25/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13700' MD 1 9005' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 92 Maximum surface 2344 psig, At total depth (TVD) 8800' 1 3400 psig Setting Depth To Bott m MD TVD MD TVD 11900' 8529' 13700' 9005' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 Plugs (measured) NOV 1. ;j 20tH Junk (measured) Alaska Oil & Gas Cons. Commission Anchorage Cemented MD TVD 104' 104' 2846' 2846' 11449' 8328' 109831 - 12862' 8103'-9191' 50 sx Arctic Set Lite 4450 sx Permafrost 1335 sx Lite; 212 sx 'G'; 400 sx PF (Top Job) 200 sx Permafrost 847 sx Class 'G' 1m BOP Sketch 0 Diverter Sketch 1m Drilling Program 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Thomas McCarty, 564-5697 Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Thomas McCart~ ø Cw Title CT Drilling Engineer API Number 50- 029-20181-01 Samples Required 0 Yes Ii] No Hydrogen Sulfide Measures (gI Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K Other: Original Signed By See cover letter for other re uirements Mud Log Re uir 0 Yes ŒI No Directional Survey Required ri1 Yes 0 No D4K 05K D10K 0 15K '~3.5K psi for CTU by order of the commission Permit Number 2- D (- ;z¡ Conditions of Approval: Rev. 12-01-85 Date " ~. BPX E-03A CTD Sidetrack (' Summarv of Operations: A CTD horizontal sidetrack of well E-03A is proposed targeting 22. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Isolate & integrity test inner annulus (IA). P&A well and annulus. Mill two string window. Planned for November 19, 2001 . Drift well with dummy whipstock to pbtd. . Integrity test IA after fluid packing & installing dummy gas lift valves. . Punch the tubing at approx. 12,000 and 12,520' md. . Set plug in tubing tail in nipple at approx12,538'md. . Set cement retainer at approx. 12,500'md. . P&A existing perforations behind tubing and 4-1/2" x 7" annulus with approx. 13bbls of 15.8ppg cement. . Run whipstock on eline and set top at approx. 9,475'md. Mill two string window with service coil if available. Phase 2: Drill and Complete CTD horizontal Sidetrack: Planned for November 25, 2001 2%" coil will be used to drill a 33,4" open hole sidetrack, approx. 1225' feet. (as per attached plan) A solid and cemented 3-3/16" x 2-7/8" liner completion will be run. Approx. 13bbls of 15.8ppg cement will be useâ to cement the liner in place. The well will be perforated with the rig. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: . No annular disposal on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 3-3/16" l-80 solid liner run from the liner top at approx. 11900'md (TOl, 8529'TVDss) to approx 12,525' md. The 3-3/16" will be crossed over to 2%", l-80, solid liner in the open hole section and will be run to TD at approx 13,700'md (9005'TVDss). Well Control: . BOP diagram is attached. . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,400 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray + Resistivity log will be run over the open hole section. . Memory CNl will be run in the cased hole after reaching TD. Hazards . H2S was measured at 2 ppm on Dec 15, 1997. . One fault crossing is p~ losed which may cause loss circulati~' Reservoir Pressure . Reservoir pressure is estimated to be 3,400 psi (7.43ppg) at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,344 psi. ( I SA FETY NOTES TREE = 4" Ftv'C WB..LHEAD = MCBI OY ACfLLA. TOR = ellS KB. ELEV = 56.63' BF. ELEV = 27.66' KOP= 3432' Max Anqe = 63 @ 11400' Datum MD = 12335' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-BO, ID = 12.347" 2846' Minimum 10 = 3.725" @ 12542' 4-1/2" OTIS XN NIPPLE TOP OF 7" LNR 11023' 9-5/8"CSG,47#,N-80, ID=8.681" I 11447 PERFORATION SUM\i1A RY REF LOG: SWS BHCS ON 12125/75 ANGLEATTOPÆRF: 51 @ 12381' I\bte: Refer to A'oduction DB for hislorical perf da1a SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 12381' - 12411 S OS/23/87 4" 4 12423' - 12438' S OS/23/87 4" 4 12453' - 12483' S OS/23/87 4" 4 12496' - 12526' S OS/23/87 4" 4 12540' - 12575 S OS/23/87 4" 4 12594' - 12624' S OS/23/87 4" 4 12640' - 12655' S OS/23/87 3-318" 1 12640' - 12670' S 09/05/88 2- 7/8" 1 12617' - 12625' 0 10/13/88 2- 7/8" 4 12566' - 12575' 0 10/13/88 3-318" 1 12673' - 12689' 0 11/13/89 3-318" 4 12566' - 12575' 0 11/13/89 3-318" 6 12665' - 12670' 0 11/11/94 4-1/2"TBG, 12.6#, L-80, 0.0152bpf, ID = 3.958" 12544' 12731' 7" LNR, 29#, SM11 0,0.0371 bpf, ID = 6.184" 1-1 12882' I E-O3 8 1989' 4-1/2 OTIS SSSV LANDING NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV lYPE VLV LATCH R:>RT DATE 1 3002 2945 1 OTIS RK 10901' -14-1/2 OTIS X NIP, ID = 3.813" I 10910' -14-1/2" BAKERPBR SEAL ASSY I 10932' --14-1/2" BAKER PKR, ID = 4.0" I 12529' -lBAKERK-22 ANQ-IOR I 12530' -17X 4-1/2" BAKER SAB PKR, ID=4.0" I 12538' --14-1/2" OTIS X NIP, ID= 3.813" I 12542' - 4-1/2" OTIS XN NP, ID = 3.725" I --14-112 ll3G TAL, WLEG I 12544' I 1--1 12548' B..MDTTLOGGED11/10/89 I DATE REV BY COMrvENTS DATE REVBY COMrvENTS 04106/76 ORIGINAL COrvPLErION 10124/89 ~O 01126/01 SIS-QAA COfWERTEDTO CAfWAS 03108/01 SIS-MD ANAL 07/16/01 RN'TP CORRECfIONS ffiLDHOE BA Y UNIT WB..L: E-03 PERMIT No: 75-0650 API No: 50-029-20181-00 Sec. 6, T11N, R14E BP Exploration (Alaska) '. TREE = 4" FMC WELLHEAD = MCEVOY ............,..,..,......,...."..........,......,.......... """""""""",""",.. ACTUA TOR = OTIS -----'-"-""".---".......-....-.."...------- KB. ELEV = 56.63' "",""""""""""""""""""""'" ..,.., ,......,....,...., ,.. BF. ELEV = 27.66' "-"'---""--"-""~"'^"^'..M-""'.W',""""""'.'_""" KOP = 3432' """"""""""""""""""""""""""""""""""""""""""""""'""...,..".. Max Angle = 63 @ 11400' ~...."...._---- Datum MD = 12335' I---,-~--,._-._,--_....,..,--_....- Datum lVD = 8800' SS t E-O3A ( PROPOSED CTD SIDETRACK 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2846' Minimum ID = 3.725" @ 12542' 4-1/2" OTIS XN NIPPLE 1 TOP OF 7" LNR I 9-5/8" CSG, 47#, N-80, ID = 8.681" I PERFORA TION SUMMA RY REF LOG: SWS BHCS ON 12/25/75 ANGLE AT TOP PERF: 51 @ 12381' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 12381' - 12411 S OS/23/87 4" 4 12423' - 12438' S OS/23/87 4" 4 12453' - 12483' S OS/23/87 4" 4 12496' - 12526' S OS/23/87 4" 4 12540' - 12575 S OS/23/87 4" 4 12594'" 12624' S OS/23/87 4" 4 12640' - 12655' S OS/23/87 3-3/8" 1 12640' - 12670' S 09/05/88 2-7/8" 1 12617' - 12625' 0 10/13/88 2-7/8" 4 12566' - 12575' 0 10/13/88 3-3/8" 1 12673' - 12689' 0 11/13/89 3-3/8" 4 12566' - 12575' 0 11/13/89 3-3/8" 6 12665' - 12670' 0 11/11/94 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" I I PBTD 1 17" LNR, 29#, SM110, 0.0371 bpf, ID = 6.184" I) 11023' 11447' 1989' -14-1/2 OTIS SSSV LANDING NIP, ID = 3.813" I GAS LIFT MANDRELS ST MD lVD DEV 1YÆ VLV LATCH PORT DATE 1 3002 2945 1 OTIS RK 10901' -14-1/2 OTIS X NIP, ID = 3.813" 1 10910' -14-1/2" BAKER PBR SEAL ASSY 1 10932' -14-1/2" BAKER PKR, ID = 4.0" 1 112525'1-13-3/16" X 2-7/8" XO I 13-3/16" x 2-7/8" Liner, Cemented & Perf'd 1 12529' 12530' 12538' 12542' -iBAKERK-22 ANCHOR I -17 x 4-1/2" BAKER SAB PKR, ID = 4.0" 1 -14-1/2" OTIS X NIP, ID = 3.813" 1 -14-1/2" OTIS XN NIP, ID = 3.725" I -14-1/2 TBG TAIL, WLEG I 1-1 ELMD IT LOGGED 11/10/89 1 12544' 12548' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/06/76 ORIGINAL COMPLETION 08/27/01 pcr E-03 Sidetrack Proposal 10/24/89 RWO 01/26/01 SIS-QAA CONVERTED TO CANVAS 03/08/01 SIS-MD FINAL 07/16/01 RNlTP CORRECTIONS PRUDHOE BA Y UNIT WELL: E-03A PERMIT No: 75-0650 API No: 50-029-20181-01 Sec. 6, T11N,R14E BP Exploration (Alaska) 0 0 tJ ~ Õi w ^ ---^^"-"^ - "Of-O ~~ ã5CNOO "-0">"'00 "-O">ONN 0,,""'""::;; ~ lõ ~åi is ~~~~: l';50~ (J) ::;; --^^-- ~.- g ~ q~ "~ ~ ~~ ~~ ~ .~ ~¡£~ ~ 0 '" N CO '" CO :;; '" '" :;; .g ,," ~¡ ~ ". . Z 0 :;: " ¡y 0 ~ ~ ~ '. . ~ â ~n ~ 0 w ~ 12 I~ i! ~j ~ r ~ ~ ~ â' ~ '" š cD '" CO 0 CO '" '" '" CO 0 CO ill "" '" '" ill " 0 CO CO " 0 0 en " 0 c~ " " '" '" " "" '" . 0 0 ill '" ~ ~ ~ . g ~ , ! ,~ 0 . . ,""_NO'..," ~ ~ t; ~ ~mmm ~ ~~~~.¡¡¡¡~~ ~mm~§ '" '" ¡g '" en " '" '" CO CO '" '" en '" '" : iiimm '" 0 '" C~ 0 en N en '" '" N en '" en :;; 0 ~ '" CO '" CO 0 '" :¡¡ '" CO 0"> " '" '" m " '" c'O '" "" 0 0 '" .... " C '" -- en -- """" ".... 00 ~~ '" ..... CO + "'...... ".... '" U) 8 III "11.1 '" -- CO ..... CO . "" ...... g'tj C'O C!I ;:'J: en "" " '" '" " " 0 CO '" " '" CO '" " 0 '" ~ '" c~ N " '" 0 N " 0 CO :;; '" 0 :;; 0 C'O '" " 0 0 0 " 0 C'O m '" '" '" ::;; 0 '" 0 0 '" 0 '" en ",en", CO 0 CO '" '" '" m m 0 '" 4~d:a 1~:Þ!;..a^ an~J. m ~ 0 0 :;; '" en 0; ¿ « 0 '" "I ~ '""" ? .- .- "I is N "I 0 c~ N "I 0 0 i? 0 B '""" a a N LD N -- 0) 0 0 " "I 0 co "" "I '" 0 co "I '" c'O 7 '" '" ill "I '" en ~ 0 ~ 0 co i? 0 0 '" "I '" en 7 '" 0 m , "10 00 ~~ "',.... g~ 1".... ~ III l' ¡:: 0 (I 0.- 1=1; ~ 11.1 1" In ¡¿j'i '1 U ~:e '[ CD g> ~ '" co ~ '" 0 " '1 0 co " 1" 0 '" C'O " 0 ¡g " 0 '" ill '1 0 co '" 1" 0 0 'i '" en '" 1" 0 '" ~ 0 C? '" 1" 0 0 l' 0 co GO '1 0 0 0 "? 0 '" N m ObP ( BP Amoco ( Baker Hughes INTEQ Planning Report B.8 BAJCa. ...... lNTEQ [-company: BP Amoc~------------------'- Date: '"9ï25/2001 Time: , 11 :00:35 '-'-pag;~--~1 I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: E-03. True North [' Site: PB E Pad Vertical (TVD) Reference: System: Mean Sea Level : Well: E-O3 Section (VS) Reference: Well (0.00N,0.00E,175.00Azi) ~ Wellpath: Plan#13 E-O3A Survey Calculation Method: Minimum Curvature Db: Oracle I I ,...-..,.., ------- '--' -------"_-,---..,-,-- -- --,..,---- -----,-, - ---, .,---,_.._-----,--- ---..-- ---.--- -"--' - ------""'----'-----------------'---- -'-_..,-,,- -_..",] , ..,_..,..,-- '..'--..-----------..----- ,----, ---,-_.._-,-------,-,_.._-'u,--_.._..,- .._'------,---,-,-,_...._---..----,-,-,-_.._--..-- ..--..-,......- '---'--"'-""'--"-- ..,.._', , Field: Prudhoe Bay . North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) I Sys Datum: Mean Sea Level --,.... ,....-...--_..,.. "..,..' --..,..- '-"""-'..u,,-,... ..--..., "....,,_... '",""'-""-------",,, ..--..-..,-,-....-, ..,..,--,------,-----",-.._--....-.._.....,-_........,......,.. -"..,,-..----......,,-.,. ..',_..., .......-" Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 - -"'-""'-"--""--""""""""-"----"- '-""""-"........- -'----"'-"---'---"'-,-,,"---'--,,-,....'..'u_---_..__.._,--,----, --,-,-_.._--,-,---------,.._.._---,-_...., .. ..-..-..,..,-,.. ,......, -- "'--..... ,.. "'1 Site: PB E Pad I TR-11-14 UNITED STATES: North Slope Site Position: Northing: 5973160,88 ft From: Map Easting: 662538.97 ft Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Latitude: 70 19 59.134 N Longitude: 148 40 53.054 W North Reference: True Grid Convergence: 1.24 deg ....' ...".., .., ,. "-"'---...._-",..,,-, ..,.,..-....,..- '......-..,....'-----,...-......---..-- ,-----_.._-_....,----,..__.._....,-,-..'-,-_......_---,..............--_..,......---.....-,-..-,..- ............ ,--""-",--------"""""""-"-,,,,-,,"""-,,,,,-_...._,.... "_..--..m....' .. '-"""" ....,.....,...--.." ..--..--"......-" ,--,,_...., --..........,..- """',," "',-""'" ",..,......""'..',-,...,,, -.... --"""--"""""""'-""'-"--"-","'-"""" "...-"-,,...-,....,.. ....,....,..-,..,-..-,.., , .."..',-,-'....._,,_.... -, Well: E-03 E-03 Well Position: +N/-S 2806.88 ft +E/-W 1988.46 ft Position Uncertainty: 0.00 ft Slot Name: 03 70 20 26.737 N 148 39 54.969 W Northing: Easting : 5976009.99 ft 664466.00 ft Latitude: Longitude: """'--"""",....",........,.....-....,..,..,..,..,.....,..,-......""-..,,....""".. "'.""""""".......,""""""""-"---"-',-,.,,-,,-, ...._-""..... ,.....,-'.......,..',..,'..'"'...,,'..,,.....,'.. , ...............",..",... ,-,....,...........-...."'..""""..-..... .. """"_.'-""""-"--"""--'--""""-"--'-"'--""""""""" - -,...... -....,....- , "..... -,,'.....,..,...... .. .....""..-... Well path: Plan#13 E-03A 500292018101 Current Datum: E-03 Magnetic Data: 9/25/2001 Field Strength: 57499 nT Vertical Section: Depth From (TVD) +N/-S ft ft -"",.._,..,-"..,..."..",-_...,.."...,.., """""'-"""--"'---"""",""",""'" "'-""""""""_."'-'"....."..,- "'...'.._-'...._-"......"..""""..""...._.."",.."--,.."..,,, 0.00 0.00 Height Drilled From: E-03 Tie-on Depth: 12475.00 ft 56.63 ft Above System Datum: Mean Sea Level Declination: 26.58 deg Mag Dip Angle: 80.82 deg +E/-W Direction ft deg ... ,..,--,.., """"""-""'--"""-"""""""""""""""""""'--""""""--""-'"..-....-"'....,....,.....'" -""'-'..' 0.00 175.00 ..,..-,-,..-",..,...-.."......-..-,...,........,...,...."",-"......".... ", """""'."'","""'_"'" """,.., ,", ,..",-,_.._,..,.. ....., """"-"""'-""""""'n ,-"".."..",-,_..""--"-,-,..,...",,..,,--,,,....,...._,--,,-------------"-"-----""-""""--"--"-""-"-'---"'-""-""""-'",..-,...---....-,-........----,.., , .. -........,.."......., , ---"-""""'-""'-"""""'"""""""""""""""'"""""""",,,,-..--",",-....." ,,-_.. ,...""'.."",,.._, ""..- --"--_...,,,,-_...._, """""""'-"""""""""..,'",..""',,..- "",_""""","""""-,..,..,..,..,"...._""..,-""..,-..,..,,-_....,....,...""",-"....-""....,......,..-..-..,..-,......",..... , Plan: Plan #13 Identical to Lamar's Plan #13 Yes Date Composed: Version: Tied-to: 9/25/2001 1 From: Definitive Path Principal: ..""""",-"""" """"""'-""""""""""""""""--""'--""""""-"""",,""'--""-""-""'-"'-"""',' -"""""""--""""'"""""""", -",-""".._..u.."..,.._",-"",,, ',""",-""""",,- Targets ""',' ¡C::'," '~"--'ï' --; -:.., - ;-~,.. -~'~-'..,..~~"" ~~-~-~ ;,~~,:", :-'"c:'7" ~~"", .:-:-.~' ':--"'";"'T"';- r-"'-- -"ë -,- -~ -c' "-;"""7"" ~'--:':--:'~ '"r. ,",:"';" '~~'"':'~.~- -~:--:-: ..::; .'"',,' . "-'T-~" ,....,"':"": ..::--...';: ;'" '-~".:: ~', -'. -... ..,-;:- "":"'-" .".""",".' ..,"..."..'," '.." '.'.' ",' ,,' ".'.' ," . Map,., ..', Map",,:".<..--,:,,!Latitud,e.....--?';~-Longitude---> .. N;lIne.'.' ""'D~scr¡Pti~n 'J'~D+N/~S', 'tE/';W<"~~rt~i#g',,1;~ås~J~g :~,J)eg':Mh1 Sec:',Deg M1Q'Sec, ' ..: .. "', -" ._,~...,~__:..L..,__::._~"..;..,_:~-".:"..:~."...,:._~,.:c......:c..,._.,~."~...~'~:!~!~:~,L,-,::.::~,;~::,~..:~~._, .,.'~-_..~,-,~..~"..~"....,..~.,:~,::..:~~~. _c...::,~:,~--~~~~::~,..~.::~Z,::_~~,.,_..,~~-_..,:,~_~~L, ~.~,..:_~c~,-~.::.~",:.;,:._...._,~.,., ......:~ ,'.. E-03A Polygon13.1 0.00 4872.11 5109.81 5980992.68 669467.36 70 21 14.636 N 148 37 25.610 W -Polygon 1 0.00 4872.11 5109.81 5980992.68 669467.36 70 21 14.636 N 148 37 25.610 W -Polygon 2 0.00 4343.15 5053.47 5980462.64 669422.64 70 21 9.434 N 148 37 27.267 W -Polygon 3 0.00 4173.10 4819.76 5980287.52 669192.73 70 21 7.763 N 148 37 34.101 W -Polygon 4 0.00 4534.10 4077.26 5980632.12668442.54 70 2111.318N 1483755.796W -Polygon 5 0.00 4875.45 4719.76 5980987.46 669077.35 70 21 14.672 N 148 37 37.011 W E-03A Fault 1 0.00 5049.35 4254.71 5981151.11 668608.63 70 21 16.385 N 148 37 50.601 W -Polygon 1 0.00 5049.35 4254.71 5981151.11 668608.63 70 21 16.385 N 148 37 50.601 W -Polygon 2 0.00 5140.56 5122.95 5981261.33 669474.60 70 21 17.276 N 148 37 25.220 W E-03A T13.2 9000.00 4517.83 4837.14 5980632.52 669202.54 70 21 11.154 N 148 37 33.586 W E-03A T13.1 9005.00 4877.78 4844.85 5980992.53 669202.36 70 21 14.694 N 148 37 33.354 W E-03A T13.3 9005.00 4344.50 4523.34 5980452.36 668892.64 70 21 9.451 N 148 37 42.761 W "..."..-..,.....,.........." ',. ,............-..,-,...--...-.....,......,-,....,...,..".,..,-...-,..-..,""...,.._",.' -..... """"-"'-""""""",.."--"".."""""'--'-""""-""""-""-"-'",..,--"'--.............."'-......-....-..,- -""'-"""--"""""""'--""""--""'-"'--"'" ,'...."" --..-..,.."....- -_.."-..'...,..._,_.._,....,,,.......... """,""""""""-"- Annotation 12450.00 8872.52 TIP 12475.00 8888.30 KOP 12485.00 8894.48 1 12560.00 8930.33 2 12909.01 9005.00 3 13009.01 9005.00 4 ......,..-..,.,..."",..."", " ObP ( BP Amoco ( Baker Hughes INTEQ Planning Report IGiii8 8AK8It ... ... (NT EQ ï'.c~~~~ny: BP Amoco Date: 9Î25/2001' Time: 11 :00:35 Page: 2 'ì i Field: Prudhoe Bay Co..ordinate(NE) Reference: Well: E-03, True North I I Site: PB E Pad Vertical (fVD) Reference: System: Mean Sea Level " I Well: E-03 Section (VS) Reference: Well (O.00N,0.00E,175.00Azi) i "'~~~?!~~~-,..~!~.~-~~.~-~:~~~-, .."'h_".- ,. -,-- ,..."h ',""'- ,....,---_....,..,_....,------,~l!~~l_c::.~I~!!!~~!~.~~~?.~:.._._-,.~i~!!!'~~..,I?~,r:v..~t~~~- -,......, .h"_I!.~.:_, ...9.~~~I:.. ---,...J Annotation ~,.,..,.n"'~D'--"'-'-"'-T~'-' --,..", ---..-..,,-..,....,.. ,--, ....,.._,...._,-,..,--_...._-,-,.. -.. "".--....,...,--,..--,......-....,..,..,..,..--..,...--....",--..--..-,---......---'-------"-----'-.-----"-"'-' ...---. ---I ".-'...._--- ",,---""'."--"""--'..--..,-,-.......-' .,....--.. ,...-... ""h""'_--"'---"""---'.---"""""'---"""""----"--""'--'"..,..-"""---"'--"'----"-----""-"" ---,.,..""'._"'-'-- -"----, ""-"""",,,"."""'--- ,..,..-,..--..,..,--- ""..--1 13109.01 9003.52 5 I 13396.18 8999.10 6 I 13700.00 9004.74 TD ! .. , ,,'...., ....,' ,.., "." _,I Plan Section Information [--.-.. "'MD--"-'-I;~ï "'--".--~im "---"--"-TVD-'-'-----¡N/-S -'---'+E/=W'" -""-.-DLS--" Suiid-""- T~~;'.---""TFO--- T~-;g;t-._--'---"-""'-"-""'" ,'.. ft deg deg ft ft ft deg/10OO deg/1 OOft" deg/1 OOft deg -, ,-'-'..,.. """-""'- ..........,_.._.._-,........---,.,-_...._-,-,-",,-------'---"""'-.._--_....._-~-- ----.,-..-..---- ,,---~-~--~,-"---"-"'------'--- ----,,-..,-,..,,-..-' ,--..- '--""'--"'" "--..,-,-.., 12450.00 50.84 72.72 8872.52 5175.08 4504.27 0.00 0.00 0.00 0.00 12475.00 50.90 72.81 8888.30 5180.83 4522.79 0.37 0.24 0.36 49.35 12485.00 52.72 73.87 8894.48 5183.08 4530.32 20.00 18.17 10.62 25.00 12560.00 70.01 82.18 8930.33 5196.28 4594.47 25.00 23.06 11.08 25.00 12909.01 90.00 169.26 9005.00 5009.58 4838.56 25.00 5.73 24.95 89.00 13009.01 90.00 183.26 9005.00 4910.04 4845.07 14.00 0.00 14.00 90.00 13109.01 91.69 169.36 9003.52 4810.50 4851.49 14.00 1.69 -13.90 277.00 13396.18 90.00 209.53 8999.10 4533.05 4805.30 14.00 -0.59 13.99 92.00 13700.00 87.97 252.03 9004.74 4345.33 4575.34 14.00 -0.67 13.99 93.00 Survey ,....,.., """".........."'" ""u"",,, .....",..,...,...,..---"""-".""""-"-"--""."-"'-""-"-"---"'-,,--,--,-..,..-----..,_..___.m'-- ..,-..-,..-, """,-"---",----"",,,--"-----"""", .., ",.., -,.._'..'c" ..,.,--,.,...~..,..,,-... ,."..,.._..'c"',.,-,.."..,' ,..-,..,- """""""~..,c,-"..,...,c,..,c-,..,~,..,....,."_..,..-c......",.,.....,,.......,,,..."..,......",.,.~.,....,.. ,."""""-",.,,,,",..,-,,""~""""""',,',""",,-..,..,..""'.,," ."""""'--"-':-C""'C,'-"':"""","'.'-.,""c,""',,"'-c-"',,'-""':"."""'" 'T."C"'-"""""""""""""'-""C""""""',' MD' Ind ~h" ,. 'SS'EvD" 'N/S "" '.", E/W, 'M:~þN,' ," '~~p~,.,I)"(.s VS '" ,,', ' ,TFO ,ro~1 . ", ,ft ,', ",,<:Jeg, ,,"" deg "I.ft",' ,', 'fj: '"""ft","."'"ft """",ft,I',cleg(:1QOft'ft:","'deg ,.", ", ..", """.",;";:"..',..:,:,c..":"",, ......,..,:_....",;c...,:":,...,..~~,.:,.::....:,;..J.C....,:",,...,..""";.""::"",:,...',....",..:,i...,.:::'.,.""":,;,:"',,,,,:,,,.':,:;.....:';:"::...:::.."i.."':~."....,,c....,.":',....;,,",:'~"C;"",":.;c:.:'.::';;,....:.."..,c....,...:."..ccc:.....;,;...:...:,C,,:":',c.,';':~:.~"'-i":.",::",:...,:.,,:.....,..:"::,,,L.i,:,."",'.:;,.., ":;'..,..........:..:..,::..,..,-,...,.,..:,,_._..,...,,,..,.. 12450.00 50.84 72.72 8872.52 5175.08 4504.27 5981282.27 668855.36 0.00 -4762.82 0.00 TIP 12475.00 50.90 72.81 8888.30 5180.83 4522.79 5981288.42 668873.75 0.37 -4766.93 49.35 KOP 12485.00 52.72 73.87 8894.48 5183.08 4530.32 5981290.84 668881.22 20.02 -4768.51 24.93 1 12500.00 56.13 75.78 8903.21 5186.27 4542.09 5981294.28 668892.92 24.99 -4770.66 25.04 MWD 12525.00 61.88 78.65 8916.08 5190.99 4562.98 5981299.46 668913.70 25.00 -4773.55 23.89 MWD 12550.00 12560.00 12575.00 12600.00 12625.00 12650.00 12675.00 12700.00 12725.00 12750.00 12775.00 12800.00 12825.00 12850.00 12875.00 12900.00 12909.01 12925.00 12950.00 12975.00 13000.00 13009.01 13025.00 13050.00 13075.00 13100.00 13109.01 13125.00 13150.00 13175.00 67.68 70.01 70.12 70.50 71.12 71.97 73.04 74.30 75.75 77.36 79.11 80.98 82.96 85.00 87.10 89.23 90.00 90.00 90.00 90.00 90.00 90.00 90.27 90.70 91.12 91.54 91.69 91.61 91.48 91.35 81.22 82.18 86.17 92.80 99.38 105.91 112.37 118.75 125.04 131.25 137.38 143.43 149.42 155.36 161.26 167.14 169.26 171.50 175.00 178.50 182.00 183.26 181.04 177.56 174.09 170.61 169.36 171.60 175.10 178.60 8926.73 8930.33 8935.45 8943.88 8952.10 8960.03 8967.55 8974.59 8981.05 8986.87 8991.97 8996.30 8999.79 9002.42 9004.14 9004.94 9005.00 9005.00 9005.00 9005.00 9005.00 9005.00 9004.96 9004.75 9004.35 9003.77 9003.52 9003.06 9002.38 9001.77 5194.93 5196.28 5197.71 5197.92 5195.41 5190.22 5182.41 5172.06 5159.30 5144.29 5127.20 5108.23 5087.61 5065.59 5042.43 5018.40 5009.58 4993.81 4968.99 4944.03 4919.04 4910.04 4894.06 4869.07 4844.14 4819.37 4810.50 4794.74 4769.92 4744.97 4585.24 4594.47 4608.50 4632.02 4655.48 4678.60 4701.11 4722.74 4743.23 4762.34 4779.84 4795.52 4809.20 4820.71 4829.92 4836.72 4838.56 4841.24 4844.17 4845.59 4845.48 4845.07 4844.47 4844.78 4846.59 4849.92 4851.49 4854.13 4857.02 4858.40 5981303.89 5981305.44 5981307.18 5981307.90 5981305.91 5981301.23 5981293.91 5981284.04 5981271.74 5981257.15 5981240.44 5981221.83 5981201.52 5981179.75 5981156.80 5981132.92 5981124.15 5981108.45 5981083.70 5981058.78 5981033.79 5981024.79 5981008.80 5980983.82 5980958.94 5980934.25 5980925.42 5980909.72 5980884.97 5980860.06 668935.87 668945.06 668959.05 668982.56 669006.07 669029.30 669051.98 669073.83 669094.59 669114.02 669131.89 669147.98 669162.11 669174.10 669183.82 669191.14 669193.17 669196.19 669199.68 669201.64 669202.08 669201.86 669201.62 669202.47 669204.83 669208.70 669210.47 669213.45 669216.89 669218.81 25.00 24.96 25.02 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 25.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.01 14.00 14.00 14.00 -, ..,....,......'.. ,......-..""','..... , """"""..'" ,"""'-" ,..,..""....,. -4775.53 -4776.07 -4776.27 -4774.43 -4769.89 -4762.70 -4752.96 -4740.76 -4726.27 -4709.65 -4691.10 -4670.83 -4649.10 -4626.16 -4602.28 -4577.75 -4568.81 -4552.87 -4527.88 -4502.90 -4478.01 -4469.08 -4453.21 -4428.29 -4403.30 -4378.34 -4369.36 -4353.43 -4328.45 -4303.48 22.41 MWD 21.27 2 88.95 MWD 87.64 MWD 85.41 MWD 83.24 MWD 81.17 MWD 79.23 MWD 77.43 MWD 75.80 MWD 74.36 MWD 73.11 MWD 72.06 MWD 71.22 MWD 70.60 MWD 70.19 MWD 70.00 3 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 4 277.00 MWD 276.99 MWD 276.97 MWD 276.91 MWD 276.85 5 92.01 MWD 92.06 MWD 92.16 MWD ,'......',...... ....",..,....,..,.,-..".."- ""....-"'" ObP f' BP Amoco ( Baker Hughes INTEQ Planning Report Bíí8 BAIC8It IlUCI8S INT RQ f'" --..-... ..,.., -.-, ' : Company: BP Amoco Date: 9/25/2001 Time: 11 :00:35 . Field: Prudhoe Bay Co-i)rdinate(NE) Reference: Well: E-03, True North i Site: PB E Pad Vertical (fVD) Reference: System: Mean Sea Level ¡Well: E-03 Section (VS) Reference: Well (0.00N,O.00E,175.00Azi) : Wellpath: Plan#13 E-03A Survey Calculation Method: Minimum Curvature Db: Oracle "'---'---'----'" --,--,-------,..,----'.."- --,_....'---,.._, ".'-"',__"h,,'_,_--.'-'-'--'-"'_..,"'- ""'_n"'" ...... _._,-" "--'--'--"""---"'---'-'-------'-"'-'-" ----------"'-'-----'--"---'-----'---""-'-"-'. ,..- Survey Page: 3 C" ,_..".._-,--,-,-- ,'-' .'-'-,-,-,.. ,,--..-,,-,----..---.______0.... ---... ,--....' ,,-- --"'---"""-" ,--,,-'-'-"'_"_"n-' ..,- ----'--.-"--'-""--" --.' ____n'__'" -'-'-----"---'.'---1 MD Incl Azim SSTVD N/S E/W MapN MapE DLS VS TFO Tool 'I' ft deg deg ft ft ft ft ft deg/100ft ft deg ! ,,---- -----"""-,--",,-------.-,,------,---,,,""""'-'----""-"-.....-. .-... ...--..'-,---".. ---- -,-----,_....,_.._--..".._---,---_..-----..----,--,,_,_.-,h...-'._-,_u_--'--'-'--"'- -""'""".,--- '--""_"'-"""" ,..........., ""--" "'-"'~I , , 13200.00 13225.00 13250.00 13275.00 13300.00 13325.00 13350.00 13375.00 13396.18 13400.00 13425.00 13450.00 13475.00 13500.00 13525.00 13550.00 13575.00 13600.00 13625.00 13650.00 13675.00 13700.00 91.21 91.06 90.92 90.76 90.61 90.45 90.29 90.14 90.00 89.97 89.79 89.61 89.43 89.25 89.07 88.90 88.73 88.57 88.41 88.26 88.11 87.97 182.09 185.59 189.09 192.59 196.08 199.58 203.08 206.57 209.53 210.07 213.56 217.06 220.55 224.05 227.55 231.04 234.54 238.04 241.53 245.03 248.53 252.03 9001.21 9000.72 9000.28 8999.92 8999.62 8999.39 8999.22 8999.13 8999.10 8999.10 8999.16 8999.29 8999.50 8999.79 9000.16 9000.60 9001.12 9001.71 9002.37 9003.09 9003.89 9004.74 4719.98 4695.05 4670.26 4645.71 4621.50 4597.70 4574.42 4551.73 4533.05 4529.73 4508.49 4488.09 4468.61 4450.13 4432.70 4416.40 4401.29 4387.42 4374.85 4363.61 4353.76 4345.33 4858.25 4856.57 4853.38 4848.68 4842.49 4834.84 4825.75 4815.25 4805.30 4803.40 4790.22 4775.77 4760.11 4743.28 4725.37 4706.42 4686.52 4665.73 4644.14 4621.82 4598.86 4575.34 5980835.08 5980810.11 5980785.26 5980760.62 5980736.27 5980712.32 5980688.84 5980665.93 5980647.04 5980643.68 5980622.15 5980601.45 5980581.63 5980562.78 5980544.97 5980528.26 5980512.71 5980498.39 5980485.35 5980473.63 5980463.28 5980454.33 669219.21 669218.08 669215.43 669211.27 669205.62 669198.49 669189.91 669179.92 669170.38 669168.55 669155.84 669141.84 669126.61 669110.20 669092.67 669074.09 669054.52 669034.04 669012.73 668990.67 668967.93 668944.61 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 13.98 14.12 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 14.00 -4278.60 -4253.90 -4229.49 -4205.44 -4181.86 -4158.82 -4136.42 -4114.73 -4096.99 -4093.85 -4073.84 -4054.78 -4036.74 -4019.79 -4003.99 -3989.40 -3976.08 -3964.08 -3953.43 -3944.19 -3936.38 -3930.03 92.25 MWD 92.32 MWD 92.39 MWD 92.45 MWD 92.50 MWD 92.55 MWD 92.58 MWD 92.60 MWD 92.62 6 92.98 MWD 93.00 MWD 92.99 MWD 92.97 MWD 92.94 MWD 92.90 MWD 92.85 MWD 92.79 MWD 92.72 MWD 92.64 MWD 92.54 MWD .. -"""""",,""""""'.""'-""--""-"-""""""""""""""'....,---..-,..,......-"--,..........--..,..,-..-,......"....-.,-..'" .."" , """"""""",-'-""'..-,-, """,........,....._""",-""."""-""",-""'....,_..,..,_..,"""",, ,""'-'-"'" -,...,.,..,""""""'""""""" ,..' ,'.. ..,....'.."", ,_..,-,-- 92.44 MWD 92.37 TD (' 38 CTD BOP Detail (' -- CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure Fire resistant Kelly Hose to Flange by Hammer up 114 Turn Valve on DS Hardline to Standpipe manifold ~ - 7" Riser Methanol Injection gtis 7" WLA Quick onnect - 7-1/16" 10,5000 psi working pressure Ram Type Dual Gate BOPE Manual over Hydraulic Flanged Fire Resistant Kelly Hose to Dual Choke Manifold Annular BOP (Hydril),7-1/16" 10 5000 psi working pressure 8 0 7-1/16" 10, 5000 psi worKing pressure Ram Type Dual Gate BOP~. TOT Manual over Hydraulic I 2 7/811 Combi Pipe/Slip I 2 3/811 Combi Pipe/Slip XO Spool as necessary Single Manual Master Valve (optional depending on RU) 2 flanged gate valves ~ 7" Annulus MOJ 5/21/01 9 5/8" Annulus o~ I I it ... , DATE 09/28/01 CHECK NO. 00198738 H 198738 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 092701 CK092701B PYMT OMMENTS: HANDL NG INST: 100.00 100.00 Per it to Drill ee S/H - Terri Hubb e X4628 f;. 03A TOTAL ~ IE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 198738 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00198738 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 09/28/01 I I AMOUNT $100,001 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 ç¿ ~ ~~.~ III ¡. g a 7 :\ B III I : 0... ¡. 2 0 3 a g 5 I: 0 0 B ....... ¡. Ii III ,., CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT RED RILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LEITER/P ARAGRAPHS TO BE INCLUDED IN TRANSNUTTAL LETTER WELL NAME CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL <-->NO ANNULAR DISPOSAL <--> YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS <--> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates "CLUE" The permit is for a new well bore segment of existing well . Permit No, . API No. . ' Production should continue to be reported as a function .of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . Please note that an disposal of fluids generated. '. . Enclosed is the approved application for permit to drill the above referenced well. The permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. ¿-;' WELL PERMIT CHECKLIST COMPANY WELL NAME e -D3/! PROGRAM: exp - dev ~ redrll FIELD & POOL ~'O./~ INIT CLASS -=ø£V / D/L GEOL AREA ð /Ò ADMINISTRA nON 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate.*~ .e«:Id¡f,;n\. . /.0.- '(c;/. . . . Y; N * SL>r!-¿¿¿a.. I tJC4h~" &4-<- /7Z>t- 02BSdf;; ~ ~~t::-4. ~ :.4L~Vcr /c..-...c;/ 3. Unique well name and number. " . . . . . ./. . . . . . . . . ...J N .r; P. ¿^-' .APL. O¿ßzt?9. ~ 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . N 5. Well located proper distance from drilling unit boundary. .. . Y , N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available' in drilling unit.. . . . . . . . . . . . ') N, 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . j N 11. Permit can be issued without conservation order. . . . . . . . 'g, N 12. Permit can.be issued without administrative approval.. . . . ',,) N 13. Can permit be approved before 15-day wait.. . . . . . . . . . N 14. Conductor string provided . . . . . . . . .. . . . . . . . . . Y N~ 15. Surface casing protects all known USDWs. . . . . . . . . . . Y N ~~ ~ k ... ~.. \ \ 16. CMT vol adequate to circulate on conductor & surf csg. . . .. . Y NN S" ~ ~ ~ \~ '- ~~ ~ 17. CMT vol adequate to ,tie-in long string to surf csg. . . . . . .. 'i N 18. CMT will cover all known productive horizons. . . . . '. . . . . 19. Casing designs adequate for C. T. B & permafrost. . . . . . . N '~ 20. Adequatetankageorreservepit...... .. .... "'" ' N Cé...'C..\~~"~~"\~ ~~~~ ~" 21. If a re-drill, has a 10-403 for abandonment been approved. . . G), NN ~O\ - ? \~ \ 22. Adequate wellbore separation proposed.. . . . . . . . . . . . <ü 23. If diverter required. does it meet regulations. . . . . . . . . . Y N \...) ~ 24. Drilling .fluid program schematic & equip list adequate. . . . . N 25. 80PEs. do they meet regulation. . . . . . . . . . .~. . . . N L\'- DATE 26. BOPE press rating appropriate; test to 3Sö,-> psig. N ~~ <:>~ 'ë.oo:o... \ ~ d- ~ ,,~ ~~' \. . HI l ç . 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N . 28. Work will occur without operation shutdown. . . . . . . . . . . N. ~ f ~ \ 29. Is presence ofH2S gas probable.. .. .. . . . . .. . . . .. Y<1Ð~~\~~~«.~c~--\~"\~ ~'~'~f<.'"~\~~ ~ ~,,~~~ci..\().."~~ 30. Permit can be issued wlo hydrogen sulfide measures. . . . '. YWN. /&3 ,{4 ~ be.;V., .--Ie.. ./ec./e.d~, ,~'bf. /1 ¡: ~ -';1'1. ""'t (z. -1:<;. 9~ ,JÞ 31. Data presented on potential overpressure zones. . . . . . . ~ 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Ay NN ' , , DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . 171/':; .0 1 34. Contact name/phone for weekly progress reports [explorato nlyj Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. " to surface; .' (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING:' UIC/Annular COMMISSION: ~ WM Af1eR DATE -ÞD- ¡l¡Ç".O } ENGINEERING GEOLOGY AP APPR Y N Y N DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) serv wellbore seg _ann. disposal para req - é?//h~(:) ON/OFF SHORE C)n UNIT# c 0 Z ( 0 -t :E ::0 - -t m - z -t J: - en » ::0 / "\ m » ~~, Comments/Instructions: IIIÞ/OI
