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208-027
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 G-11B Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-027 50-029-20583-02-00 12829 Conductor Surface Intermediate Liner Liner 9022 80 2716 8516 2004 2527 12792 20" x 30" 13-3/8" 9-5/8" 7" 2-3/8" 9021 35 - 115 35 - 2751 33 - 8549 8351 - 10355 10302 - 12829 35 - 115 35 - 2688 33 - 6838 6696 - 8532 8483 - 9022 10273 2670 4760 7020 11780 None 5380 6870 8160 11200 10930 - 12780 4-1/2" 12.6#, 3-1/2" 9.2# 13cr80, L-80 30 - 10355 8989 - 9020 Structural 4-1/2" HES TNT Packer 8901 7129 Torin Roschinger Operations Manager Finn Oestgaard finn.oestgaard@hilcorp.com 907-564-5026 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028280 30 - 8532 N/A N/A 222 142 16771 10969 0 48 850 0 240 200 323-303, 324-371 13b. Pools active after work:Prudhoe Oil No SSSV Installed 8901, 7129 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 3:46 pm, Jan 21, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.01.21 14:31:33 - 09'00' Torin Roschinger (4662) DSR-1/22/25JJL 2/27/25 RBDMS JSB 012925 A.Dewhurst 12FEB25 ACTIVITY DATE SUMMARY 12/21/2023 T/I/O=537/316/25 CMIT TxIA to 3000 max applied 3300 FAILED Pressured TxIA to 3300 psi with 19 bbls crude. upon reaching test pressure TBG pressure fell off rapidly. final WHP's 1075/965/23 12/28/2023 T/I/O = SSV/975/25. Temp = SI. PPPOT-T (PASS), PPPOT-IC (FAIL) (pre RWO). No AL. PPPOT-T: Stung into test port (800 psi). Bled void to 0 psi. Monitor pressure for 10 min, no increase in void pressure. Function LDS, all moved freely, Torqued to 500 lb/ft. Unable to pump through void, the offside SBS is stuck closed. Pressured test void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (30 psi), bled void to 0 psi. Monitor for 10 min, no increase in pressure. Unable to pressure void above 500 psi, pressure decreased to 0+ as soon as pump was shut down (FAIL). 7/28/2024 ***WELL S/I ON ARRIVAL*** RAN 3-1/2" GR, 20' x 2.74" DUMMY WHIPSTOCK TO TOP OF CIBP @ 9192' MD (no issues) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 8/3/2024 ***WELL S/I ON ARRIVAL*** RAN 2.69" CENT, 5' x 1.875" STEM, AND 2.65" LIB TO TAG @ 9182' SLM (LIB INCONCLUSIVE). SET 3 1/2" EVO-TRIEVE PLUG @ 9171' SLM. LRS PERFORMED A PASSING CMIT TxIA TO 3,000 PSI SET SLOTTED JUNK CATCHER ON EVO @ 9,171'SLM ***WELL S/I ON DEPARTURE*** 8/3/2024 T/I/O= 489/473/5 LRS 46 - Assist Slickline (RWO EXPENSE) CMIT-TxIA to 3124/3112 psi ***PASSED*** Pumped 10.6 bbls down TxIA to reach 3248/3239 psi. 1st 15-minute loss of 86/89, 2nd 15-minute loss of 38/38 psi, for a total loss of 124/127 psi in 30 minutes. Bled back ~8.7 bbls. SL in control of well upon departure. FWHPs= 484/481/8 8/5/2024 *** WELL S/I ON ARRIVAL *** PULL SLOTTED JUNK CATCHER FROM 9150' SLM *** WELL LEFT S/I ON DEPARTURE *** 8/7/2024 *** WELL S/I ON ARRIVAL*** OBJECTIVE DRIFT RUN/WELLTEC TBG CUT RIG UP YJ ELINE. PT PCE 300 PSI LOW / 3000 PSI HIGH RIH WITH WB/CCL RUN A DRIFT TO 9191' TAGGED EVO PLUG CORRALATED TO SCHLUMBERGER SETTING RECORD 05-JUNE 2018 RIH W/ WELLTEC 3 1/8" MECHANICAL CUTTER CUT 3 1/2" TBG @ 8998'MD PRE CUT T/I/O/500/500/0 PSI, POST CUT T/I/O/= 500/500/0 AT SURFACE TATTLE TAIL SHOWED BLADES WENT OUT TO 4.47" RDMO YELLOWJACKET ELINE JOB COMPLETE ***WELL S/I ON DEPARTURE**** Daily Report of Well Operations PBU G-11B Daily Report of Well Operations PBU G-11B 8/12/2024 T/I/O= 516/514/2. LRS 72 Circulate Well Bore (RWO EXPENSE). Pumped 2 bbls 60/40 Meth and 100 bbls DeepKleen and 900 bbls 1% KCL into TBG taking returns up IA into G-31 FL. Pumped 125 bbls 125* Diesel into IA taking returns into TBG to G- 31 FL. U-tube TxIA for 1 hr. 4 hour wait for fluid. Pad Op notified upon LRS departure. Final WHPs = 79/79/120 8/13/2024 T/I/O = VAC/VAC/90. Temp = SI. Bleed WHPs to 0 psi (pre RWO). OA FL near surface. Bled OAP to BT to 0+ psi in 45 min (gas). Monitored for 30 min. OAP increased 10 psi. Final WHPs = VAC/VAC/10. SV, WV = C. SSV, MV = O. IA, OA = OTG. 17:15 8/15/2024 T/I/O = SSV/vac/20. Temp = SI. Bleed OAP to 0 psi (Pre RWO). OA FL @ near surface. Bled OAP to BT to 0 psi in 20 min (gas). Held open bleed for 30 min. Monitor for 30 min, OAP unchanged. FWHP's = SSV/VAC/0 SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:15 8/27/2024 T/I/O=0/0/0. Pre RWO. (CDR2) Set 3" CTS "H" BPV #CTS 3-2 @ 115" wth CIW lubricator. BPV LTT Passed. RD 3" FMC 120 upper tree and install SV from upper tree as dryhole tree. Torqued flanges to spec. Presure tested SV against MV to 300/5000 psi. Passed. ***Job Complete*** Final WHP's BPV/0/0. 9/15/2024 T/I/O = BPV/20/6. Temp = N/A. Bleed IAP, OAP and C/B lines for rig. Drilling tree installed w/ BPV. IA FL @ surface, OA FL @ near surface. Bled IAP to BT to 0 psi in 20 min (fluid). Bled OAP to BT to 0 psi in 35 min (fluid). Bled control and balance lines to 0 psi (gas). Monitor for 30 min, no increase in pressure. SV = C, MV = O. IA & OA = OTG. 17:30. 9/16/2024 CDR2 RWO. Job Scope: Tubing Swap. Begin Rig move to G-11 @ 12:00. Spotting up at 19:30. Disconnect Hauler trucks. Use Rig Foot (stomper). Rig Accepted at 00:01, 9/17. Job Continued to 9/17/2024... 9/17/2024 CDR2 RWO. Job Scope: Tubing Swap. ND Production Tree, NU BOPs, NU Flowcross. Rig Gas Alarms Tested. Test BOPE to 250/3000 psi, Annular 250/2500 psi per Sundry. Witness Waived by AOGCC Rep Sean Sullivan. B1 Fail/Replace/Pass. Drawdown Test Pass. Job Continued to 9/18/2024... 9/17/2024 Bleed off hanger void & (2) non-continuous control lines, nipple down THA, clean hanger void, hanger lift threads, & BPV profile, make up CTS plug to BPV, make up 3- 1/3" TDS lift sub to hanger lift threads 9-3/4 RH & back out, lay down, function tubing hanger lock down screws one at a time to 4-1/8" clear bowl, all functioned as should, re-torqued to 500 ft/lbs, install new BX-160 9/18/2024 Pull CTS plug, pull 3 1/2" CTSHBPV. M/U 3 1/2" TDS XO to LJ. RIH, m/u to TBG HGR. BOLDS. Pull TBG HGR to rig floor. Terminate (2) 1/4" Control lines. Daily Report of Well Operations PBU G-11B 9/18/2024 CDR2 RWO. Job Scope: Tubing Swap. B1 Fail/Replace/Pass. BOPE Test Complete. Prep Rig to Pull CTS BPV, and PU Landing Joint. Thread Landing Jt, BOLDS. Circ Well w/ 1% KCl. Pull & LD Tubing Hanger. LD 3-1/2" 9.2# TDS Completion. Recovered all control line and 72 SS clamps. Perform WC Drill kick while tripping. ***Job Continued on WSR 9/19/2024*** 9/19/2024 M/U P/O R&R tool to working joint. RIH, J into P/O set down top drive weight. Ensure OA @ 0 PSI. BOLDS. Go to neutral weight on top drive, working joint traveled up (+/-) 8". Unable to push back down. S/B for further instructions. Pull P/O. S/B for rig to run completion. 9/19/2024 CDR 2 RWO Job Scope: Tubing Swap Complete pulling 3-1/2" 9.2# TDS completion. Clear rig floor and pull 9-5/8" casing packoff, casing grew ~8" after BOLDS. Discuss plan forward with OE and decided to run most of completion then hang off string in 9-5/8" with RTTS to compress CSG. Start running 4.5" 13 Cr gas lift completion. ***Job Continued on WSR 9/20/24*** 9/20/2024 RWO, Install 9-5/8" IC-PO Rig set storm packer with 4-1/2" completion tubing in the holeto mitigate ~8" of casing growth, 85K up wt, 72K dwn wt, drain and rinse stack, hanger flutes visible, MU PO RT to joint of DP and RIH with OA open, 9-5/8" IC-PO landed ~2-1/2" high with 20K top drive weight, POOH, noted seal damage, strip seals from old IC-PO and redress new IC-PO while rig processes 4-1/2" completion tubing, MU PO RT to 3-1/2" drill collar and RIH with old IC-PO with no interference seals and landed ~2-1/2" high, set top drive weight, IC-PO ~1/2" high, verified through LDS, POOH, standby for rig to pull storm packer and RIH with more tubing. 9/20/2024 CDR 2 RWO Job Scope: Tubing Swap Continue running 4-1/2" 12.6# 13Cr gas lift completion. MU & RIH 9-5/8" Storm Packer on 3 Jts. of DP. Set Packer ~90'. Attempt to set 9-5/8" casing pack off but hanger was ~.5" off seat. Pull storm packer and run an additional 47 JTS of 4.5" completion. ***Job Continued on WSR 9/21/24*** 9/21/2024 FP IA for CDR 2 ***Job continued to 9-22-2024**** 9/21/2024 CDR 2 RWO Job Scope: Tubing Swap Make up BOT 9-5/8" storm packer to 4.5" completion and set at ~55'. Install 9-5/8" casing pack off and pressure test to 500/3500psi. Continue RIH with 4-1/2" completion. Tagged on Jt #217. Sheared both sets of tattletale pins. Space out to land completion, MU & RIH with tubing hanger. Rolled seal element and fell in hole. Recovered half of element. Run backup hanger and land without issue. Reverse circulate inhibited brine in IA. Drop ball and rod and set packer, MIT-T to 3,200psi, MIT-IA-3,200psi. Shear SOV and pump 180bbls of diesel down IA for FP. (T-bird to come back after rig is gone to u-tube FP). ***Job Continued on WSR 9/22/24*** Daily Report of Well Operations PBU G-11B 9/21/2024 RWO, Install new 9-5/8" IC-PO, PPPOT-IC (PASS) M/U packoff to R&R tool, RIH. Land packoff, set down top drive weight. Verify landed through LDS. RILDS, Torque to 450 ft lbs. R/U injection equipment. Inject seal until pressure stabilizes at 4500 psi. R/U test equipment and test ICPO to 500 psi for 5 min. Pass. test to 3500 psi for 30 min. 0 psi loss first 15 min, 0 psi loss second 15 min, Pass. R/D test and injection equipment, bleed test pressure. S/B for finish run completion. 9/22/2024 RWO, Completion, PPPOT-T (PASS) Clean THA test void, install CTS plug, re-torque LDS and GNs to 500 ft/lbs, clean & inspect ring groove, install new BX-160, fill void with hyd oil, PU THA & dry hole tree, clean and inspect ring groove and DX seal, remove hanger neck protector, clean and inspect DX profile, wellhead orientation is not squared with piperack, confirm correct THA / tree orientation, orient and set, rig crew torqued THA, top off test void with hyd oil, test to 500 / 5 min, pass, pressure up to 5000 psi, lost 325 first 15 min, lost 50 psi second 15 min, pass, bleed test psi and drain hyd fluid, RD test equipment and stand by for rig to test tree to 500 / 5000 for 5 min each, pass, bleed test psi, pull CTS plug, pull 4" H CTS BPV, close master, and swab valves, cap tree. 9/22/2024 **Job continued from 9-21-2024*** Pumped 5 bbls 60/40 followed by 180 bbls DSL folowed by 5 bbls 60/40 to Freeze Protect IA 9/22/2024 CDR 2 RWO Job Scope: Tubing Swap Set BPV, Remove BOPs, install TWC, and NU dry hole tree. PT tubing hanger void & tree to 500/5000 psi. Rig Released at 14:00. RDMO ***Job Completed*** 9/22/2024 M/U TBG HGR to string, RIH. Land at confirmed RKB. Halliburton hand wants to pick up off seat. TBG HGR body seal rolled while coming up. Pull TBG HGR to rig floor. Install new seal. Was able to fish out 1/2 of failed seal element. RIH w/ TBG HGR and land. Verify through IA valve. RILDS torque to 450 ft lbs. Close annular pressure up to 500 psi. pass. S/B for circulate. Set 4" CTSHBPV. S/B for N/D BOP... 9/23/2024 T/I/O= 0/0/0 (TFS Unit 1 - Perform U-Tube) TBG/IA U-tube'd Well shut in upon TFS departure FWHPS = 0/0/0 9/24/2024 T/I/O=VAC/0/0. RU lubrictor. Pressure tested upper tree against MV 300/5000 PSI. Passed. Pulled 4" H BPV #130. RD lubricator. Installed tree cap. Pressure tested tree cap to 500 PSI. Passed. ***Job Complete*** . Final WHP's Vac/0/0. 9/24/2024 ***WELL S/I ON ARRIVAL*** PULLED BALL & ROD FROM 4-1/2'' RHC BODY @ 8972' SLM ***WSR CONT ON 9-25-24*** 9/24/2024 T/I/O = 0/0/0 Set 4" H BPV #130 RDMO Final Pressures BPV/0/0 Daily Report of Well Operations PBU G-11B 9/25/2024 ***WSR CONT FROM 9-25-24*** PULLED RK-DGLV FROM ST#2 @ 6984' MD PULLED RK-SHEAR VLV FROM ST#3 @ 3951' MD SET ST#3 RK-LGLV (16/64''ports, 1500# tro) @ 3951' MD SET ST#2 RK-OGLV (20/64''ports) @ 6984' MD PULLED 4-1/2" RHC BODY FROM 8972' MD PULLED 3-1/2" EVO FROM 9173' SLM (element split but all there) ***WELL LEFT S/I ON DEPARTURE, NOTIFY PAD OP OF WELL STATUS*** 9/27/2024 LRS CTU #1 - 1.50" Blue Coil Job Objective: Mill CBP and CIBP MIRU CTU. Make up 2-1/8" milling BHA with 2.70" venturi burnshoe. RIH. Tag CBP at 9192', mill and push down to liner top. Attempt to mill with only stalls. POOH. Recovered apx 2-3 cups of CBP debris, slips, set screw, pieces of the composite and other small debris. M/U 1.69" milling BHA w/ 1.75" reverse clutch mill. RIH, tag at liner top and mill on CBP at 10294' CTMD. Heavy milling with signs of heavy debris. Push CBP pieces into the liner and drift to 10305' CTMD. POOH. Make up 1.69" milling BHA with 1.77" venturi/burnshoe and RIH. ...Continued on WSR 9-28-24... 9/28/2024 ***WELL S/I ON ARRIVAL*** R/U SLICKLINE. ***CONTINUED ON 9-29-24*** 9/28/2024 LRS CTU #1 - 1.50" Blue Coil ***Continued from WSR 9-27-24*** Job Objective: Post RWO mill CBP and CIBP Continue to RIH with 1.77" venturi/burnshoe milling BHA. Work top of LTP at 10294' CMD and able to enter liner. Push 3-1/2" CBP remanants down to top of CIBP at 11550'. Mill CIBP and push to TD at 12789' CTMD. POOH. overpull at liner top 10285CTMD. Multiple attempts to get free but unsuccessful. pump 1/2" disconnect ball. Released, POOH. L/D remaining baker BHA. M/U Freeze protect BHA. RIH to freeze protect tubing down to 2500' w/diesel 38bbls. L/D BHA. RDMO ***Job Complete*** *****Fish Left in hole: 1.69" TJ Disconnect lower sub x 1.03' len (1/2" ball on seat), 1.69" circ sub with 5k burst disc x 1.01' len, 1.69" X-treme AD motor x 8.33' len, 1.69" body venturi with 1.77" Burnshoe x 5.24' len. OAL 15.61'. GS will need a deep catch, see Well Pictures Info for dimensions'****** 9/29/2024 ***CONTINUED FROM 9-28-24*** JAR DOWN ON COIL FISH @ 10,260' SLM FOR 4 HOURS & 45 MINUTES RAN 2.60" BELL GUIDE W/ TATTLE TELL PINS INSIDE TO COIL FISH @ 10,263' SLM, ALL PINS SHEARED ATTEMPTED TO PLANT 2.78" WEATHERFORD RELEASABLE OVERSHOT ON FISH @ 10,262' SLM, UNABLE TO GET A BITE. RAN 2 3/8" GS, JARRED 1400 - 1700# ON FISH 1 HOUR 15 MINS W/ NO MOVEMENT. ***CONTINUED ON 9-30-24*** Daily Report of Well Operations PBU G-11B 9/30/2024 ***WSR CONTINUED FROM 9-29-24*** JARRED ON COIL FISH @ 10,260' SLM FOR 5 HRS & 40 MIN (7 hrs total) REATTEMPTED TO PLANT RELEASABLE OVERSHOT, NO SUCCESS. RAN DE-CENT & 2.85" LIB TO 10,260' SLM; SHOWS COIL FISH ON LOW SIDE. WILL HAVE A NEW RELEASABLE OS SKIRT MADE & RETURN. ***WELL S/I ON DEPARTURE*** 10/4/2024 ***WELL S/I ON ARRIVAL*** RAN 2.79" BOWEN OVERSHOT W/ 1 11/16" GRAPPLE TO FISH @ 10,264' SLM. (Only bottom 2 teeth of grapple engaging; grapple & keeper ring deformed). RAN 2.79" BOWEN OVERSHOT W/ 1 3/4" GRAPPLE TO FISH @ 10,264' SLM. 2000# OJ LICKS 10 MINS AND STRIP OFF FISH (was fully engaged). ***CONTINUED ON 10-5-24*** 10/5/2024 ***CONTINUED FROM 10-4-24*** PLANTED BAITED 2.79" BOWEN OVERSHOT W/ 1 11/16" GRAPPLE ON FISH @ 10,263' SLM. RAN 3 1/2" PRGS. JARRED ON OVERSHOT 2500 -3000# FOR 25 MINS AND STRIPPED GRAPPLE (Was fully engaged). PLANTED BAITED 2.79" BOWEN OVERSHOT W/ 1 5/8" GRAPPLE ON FISH @ 10,263' SLM PULLED 10' OF COIL FISH FROM 10,263' SLM - BALL RECOVERED FROM DISCO. RAN 2.60" LIB TO 10,273' SLM, IMPRESSION OF MOTOR ROD ~0.87" OD RAN 2.60" BELL GUIDE w/ TATTLE TALE PINS TO 10,273' SLM, OVER FISH 16" NEW OVERSHOT BEING MADE, WILL RETURN ***WELL S/I ON DEPARTURE*** 10/9/2024 ***WELL S/I ON ARRIVAL*** PLANTED 2.79" BOWEN OVERSHOT (MULE SHOE BOTTOM), w/ 1-5/8" GRAPPLE ON COIL FISH @ 10,273' SLM. RAN 3 1/2" GS TO OVERSHOT @ 10,267' SLM. OVERSHOT SLIPPED OFF QUICKLY W/ 3000# OJ LICK. (FLAT MARK ON MULESHOE). PLANTED 2.79" BOWEN OVERSHOT (FLAT BOTTOM), w/ 1.66" GRAPPLE ON COIL FISH @ 10,273' SLM. RAN 3 1/2" GS TO OVERSHOT @ 12,267' SLM. HIT 2500 - 3000# OJ LICKS 1 HOUR; SHEARED OFF. ***CONTINUED ON 10-10-24*** 10/10/2024 ***CONTINUED FROM 10-9-24*** JAR ON FISH @ 10,269' SLM FOR 5 HRS @ 3,000-3,200# (TOTAL OF 6 HRS) NON RELEASABLE OVERSHOT PLANTED ON FISH OAL = 48", MAX OD = 2.79", 3-1/2" G-F/N w/ 2-7/8" BACK UP F/N 3" INSIDE OF BAITSUB NOTE: PRGS WILL NOT SHEAR ***WELL S/I ON DEPARTURE*** 11/1/2024 LRS 72 Assist CTU (RWO EXPENSE). Heat UR tank to 130*F. 11/1/2024 LRS CTU #2 2" Tapered Blue Coil. Job Objective: Fish BHA MIRU CTU #2. BOP Test & Annual Slip Test. NU BOPs & Fnc Test. MU BOT Fishing BHA w/ 3" GS. RIH Tag 10268' CTMD. Jar 50+ licks. No go. POOH to change things up. ***Job continued 11/2/24*** Daily Report of Well Operations PBU G-11B 11/2/2024 LRS CTU #2 2" Tapered Blue Coil. Job Objective: Fish BHA ***Job continued from 11/1/24*** MU BOT Fishing BHA and Tempress w/ 3" GS. Load the well with safelube. RIH. Tag Bait Sub 10,263' ctm / 10,292' Mech. Pumped down CT Tempress for 20mins down. Start Jarring up/down. 31 jar licks up and jars stopped firing. Relaese off bait sub and POOH. ***Job Continued 11/3/24*** 11/3/2024 LRS CTU #2 2" Tapered Blue Coil. Job Objective: Fish BHA ***Job continued from 11/2/24*** MU BOT Fishing Hip Tripper BHA . RIH. Tag 10267'CTMD. Hip trip on fish downward for 40 mins. FP CT. PUH lost wgt 25k overpull. POOH. Pulled 7k heavy at 8965' ctm. Worked CT. POOH. RDMO CTU 2. 3" GS btm section left in hole below the Top Sub. See well pic folder for details. ***Job Not Complete*** 11/27/2024 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD UNIT 61 ***WSR CONT. ON 11-28-2024*** 11/28/2024 ***WSR CONT. FROM 11-27-2024*** RECOVERED SPRING, BODY AND CORE FROM 3" GS @ 10,271' SLM. (all parts recovered) ***WSR CONT. ON 11-29-2024*** 11/29/2024 ***WSR CONT. FROM 11-28-2024*** JARRED ON BAITED OVERSHOT @ 10271' SLM, FOR 1 HOUR WITH NO MOVEMENT. ***WELL LEFT S/I ON DEPARTURE*** 12/27/2024 ***WELL S/I ON ARRIVAL*** R/U .25" BRAIDED LINE. ***CONTINUED ON 12-28-24*** 12/28/2024 ***CONTINUED FROM 12-27-24*** JARRED ON FISH @ 10,283' BLM @ 5000-5600# FOR 1.5 HRS (broke overshot @ threaded connection, recovered baitsub & threaded ext). SET DREAM CATCHER ON 3.81" X LOCK @ 2182' MD. RAN CHECK SET TO DREAMCATCHER (PIN 1/2 SHEARED). ***CONTINUED ON 12-29-24*** 12/29/2024 ***CONTINUED FROM 12-28-24*** RAN CHECK SET TO DREAM CATCHER @ 2182' MD (SHEARED). ***WELL S/I ON DEPARTURE*** 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU G-11B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-027 50-029-20583-02-00 N/A ADL 0028280 12829 Conductor Surface Intermediate Liner Liner 9022 80 2716 8516 2004 2527 9192 20" x 30" 13-3/8" 9-5/8" 7" 2-3/8" 7406 35 - 115 35 - 2751 33 - 8549 8351 - 10355 10302 - 12829 2420 35 - 115 35 - 2688 33 - 6838 6696 - 8532 8483 - 9022 None 2670 4760 7020 11780 9192, 11550 5380 6870 8160 11200 10930 - 12780 3-1/2" 9.2# L-80 30 - 103558989 - 9020 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com 907-903-5990 PRUDHOE BAY 8/1/2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Update to Sundry 323-303 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2024.06.27 05:51:50 - 08'00' Torin Roschinger (4662) 324-371 By Grace Christianson at 11:01 am, Jun 27, 2024 MGR28JUN24 10-404 * BOPE test to 3000 psi. Annular to 2500 psi. DSR-7/8/24SFD 7/15/2024*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.07.15 13:20:42 -08'00'07/15/24 RBDMS JSB 071624 RWO Tubing Swap G-11 PTD: 208-027 Well Name:G-11B API Number:50-029-20583-02-00 Current Status:Shut-In – Non-Operable Rig:Nordic 2 Estimated Start Date:8/1/2024 Estimated Duration:6days Reg.Approval Req’std?Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:208-027 First Call Engineer:Michael Hibbert Contact:907-903-5990 Current Bottom Hole Pressure:3,300 psi @ 8,800’ TVD 7.22 PPGE | offset well recent SBHP Max. Anticipated Surface Pressure:2,420 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2059 psi (FB RU on 5/18/21) Min ID:1.870” @ 10,296’ Baker 35 KB LTP Max Angle:97 Deg @ 11,196’ MD Brief Well Summary: G-11B is a GC1 GD natural flow producer with multiple tubing leaks. In 2011, TxIA was discovered. A patch was set and subsequently failed pressure tests. It was determined the lower anchor was not set properly so the patch was pulled and reset. After 3 years of on time, the well developed TxIA. A solution was not sought at this time. The patch was pulled to allow plug to be set in the well. In 2013, a leak detect log found leaks at 4675’, 4613’, 4626’ MD. Slickline set a new patch but the well still failed pressure tests. After some diagnostics the well was left shut in with a plug and has been left alone until recently. In 2018, there was an attempt to set an extended patch in the well. After the new patch again failed, a new LDL was run and found another leak at 8154’. The well has remaining value from the Ivishak and Sag, so a RWO is being pursued to repair the well to operable status. Objective: Prepare well for RWO. Pull the existing 3-1/2” tubing. Run new 13-Cr 4-1/2” completion with 4-1/2”x7” packer to repair tubing leaks. Achieve a passing MIT-IA & MIT-T. Mill out 3.5” and 2-3/8” CIBPs post-rig. Pre RWO work: Wellhead: 1. PPPOT-T to 5,000 psi. Function all LDS. PPPOT-IC to 3,500 psi. Function all LDS. Fullbore: 1. CMIT-TxIA to 3,000 psi. E-line/Fullbore: 1. Cut3.5” tubing @ ~9,250’ MD (5’-10’ below collar in full joint) 2. Circulate well with 8.3 ppg KWF + freeze protect. DHD: 1. Bleed WHP to 0 psi Valve Shop: 2. Set and test TWC. 3. Nipple down tree and tubing head adaptor. Inspect threads. 4. NU BOPE configuration top down: Annular, 2-7/8”x5” VBRs, blinds and integral flow cross. RWO Tubing Swap G-11 PTD: 208-027 Proposed RWO Procedure: 1. MIRU Nordic #2 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). A. Record accumulator pre-charge pressures and chart tests. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8”x 5” VBRs with 3-1/2” test joints. E. Test the annular with 3-1/2” test joint. F. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. RU and pull TWC. 4. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Expected PU weightin 8.3ppg = 75,117 lbs. 5. Pull 3-1/2” tubing to floor. 6. Run 4-1/2” 13Cr tubing as detailed on proposed schematic. a. Drift overshot with cut joint. b. Torque turn connections. 7. Land Hanger and reverse in corrosion inhibited 8.3 ppg KWF. 8. Drop ball and rod and set packer. 9. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 10. Shear valve in upper GLM. 11. Set TWC. 12. Rig down Nordic #2. Post rig valve shop work 1. ND BOPE. 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC. 5. Freeze protect to 2000’ with diesel. Post-rig Work Slickline 1. Set LGLVs. 2. Pull Ball and rod and RHC profile. CTU 3. Mill 3.5” NS CIBP at 9192’. 4. Mill 1.71” CIBP @ 11,550’ and push to PBTD. 5. RDMO & POP well. RWO Tubing Swap G-11 PTD: 208-027 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Revision Change Form RWO Tubing Swap G-11 PTD: 208-027 Figure 1: WBS C C RWO Tubing Swap G-11 PTD: 208-027 Figure 2: Proposed WBS RWO Tubing Swap G-11 PTD: 208-027 Proposed BOPE Stack 2-7/8” x 5” Variable Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: June 26, 2024Subject: Changes to Approved Sundry Procedure for Well G-11BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU G-11B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-027 50-029-20583-02-00 N/A ADL 0028280 12829 Conductor Surface Intermediate Liner Liner 9022 80 2716 8516 2004 2527 9192 20" x 30" 13-3/8" 9-5/8" 7" 2-3/8" 7406 35 - 115 35 - 2751 33 - 8549 8351 - 10355 10302 - 12829 2420 35 - 115 35 - 2688 33 - 6838 6696 - 8532 8483 - 9022 None 2670 4760 7020 11780 9192, 11550 5380 6870 8160 11200 10930 - 12780 3-1/2" 9.2# L-80 30 - 103558989 - 9020 Structural No Packer No SSSV Installed No Packer No SSSV Installed Date: Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com PRUDHOE BAY 6/15/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 907-903-5990 323-303 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.05.23 15:19:13 -08'00' Torin Roschinger (4662) 10-404 BOPE test to 3000 psi. Annular to 2500 psi. DSR-5/24/23 2420 MGR02JUN23 SFD 6/5/2023GCW 06/06/2023 JLC 6/6/2023 06/06/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.06 15:09:32 -08'00' RBDMS JSB 060723 RWO Tubing Swap G-11 PTD: 208-027 Well Name:G-11B API Number:50-029-20583-02-00 Current Status:Shut-In – Non-Operable Rig:Thunderbird Estimated Start Date:6/15/2023 Estimated Duration:6days Reg.Approval Req’std?Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker Permit to Drill Number:208-027 First Call Engineer:Michael Hibbert Contact:907-903-5990 Current Bottom Hole Pressure:3,300 psi @ 8,800’ TVD 7.22 PPGE | offset well recent SBHP Max. Anticipated Surface Pressure:2,420 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2059 psi (FB RU on 5/18/21) Min ID:1.870” @ 10,296’ Baker 35 KB LTP Max Angle:97 Deg @ 11,196’ MD Brief Well Summary: G-11B is a GC1 GD natural flow producer with multiple tubing leaks. In 2011, TxIA was discovered. A patch was set and subsequently failed pressure tests. It was determined the lower anchor was not set properly so the patch was pulled and reset. After 3 years of on time, the well developed TxIA. A solution was not sought at this time. The patch was pulled to allow plug to be set in the well. In 2013, a leak detect log found leaks at 4675’, 4613’, 4626’ MD. Slickline set a new patch but the well still failed pressure tests. After some diagnostics the well was left shut in with a plug and has been left alone until recently. In 2018, there was an attempt to set an extended patch in the well. After the new patch again failed, a new LDL was run and found another leak at 8154’. The well has remaining value from the Ivishak and Sag so a RWO is being pursued to repair the well to operable status. Objective: Prepare well for RWO. Pull the existing 3-1/2” tubing. Run new 13-Cr 4-1/2” completion with 4-1/2”x7” packer to repair tubing leaks. Achieve a passing MIT-IA & MIT-T. Mill out 3.5” and 2-3/8” CIBPs post-rig. Pre RWO work: Wellhead: 1. PPPOT-T to 5,000 psi. Function all LDS. PPPOT-IC to 3,500 psi. Function all LDS. Fullbore: 1. CMIT-TxIA to 3,000 psi. E-line/Fullbore: 1. Cut 3.5” tubing @ ~9,250’ MD (5’-10’ below collar in full joint) 2. Circulate well with 8.3 ppg KWF + freeze protect. DHD: 1. Bleed WHP to 0 psi Valve Shop: 2. Set and test TWC. 3. Nipple down tree and tubing head adaptor. Inspect threads. 4. NU BOPE configuration top down: Annular, 2-7/8”x5” VBRs, blinds and integral flow cross. RWO Tubing Swap G-11 PTD: 208-027 Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). A. Record accumulator pre-charge pressures and chart tests. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8”x 5” VBRs with 3-1/2” test joints. E. Test the annular with 3-1/2” test joint. F. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. RU and pull TWC. 4. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Expected PU weight in 8.3ppg = 75,117 lbs. 5. Pull 3-1/2” tubing to floor. 6. Run 4-1/2” 13Cr tubing as detailed on proposed schematic. a. Drift overshot with cut joint. b. Torque turn connections. 7. Land Hanger and reverse in corrosion inhibited 8.3 ppg KWF. 8. Drop ball and rod and set packer. 9. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 10. Shear valve in upper GLM. 11. Set TWC. 12. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE. 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC. 5. Freeze protect to 2000’ with diesel. Post-rig Work Slickline 1. Set LGLVs. 2. Pull Ball and rod and RHC profile. CTU 3. Mill 3.5” NS CIBP at 9192’. 4. Mill 1.71” CIBP @ 11,550’ and push to PBTD. 5. RDMO & POP well. Risk assess for pressure under TWC. Lubricate if risk of pressure. -mgr RWO Tubing Swap G-11 PTD: 208-027 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Revision Change Form RWO Tubing Swap G-11 PTD: 208-027 Figure 1: WBS RWO Tubing Swap G-11 PTD: 208-027 Figure 2: Proposed WBS RWO Tubing Swap G-11 PTD: 208-027 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: May 23, 2023Subject: Changes to Approved Sundry Procedure for Well G-11BSundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Aras Worthington Integrity and Interventions Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU G-1 1B Permit to Drill Number: 208-027 Sundry Number: 320-057 Dear Mr. Worthington: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a o g c c. a l a s k a. g o v Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, v.vf,— rice DATED this L day of February, 2020. 3BDMS P FLe 0 7 2020 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 I A lul n n rnry L 7LU U 1. Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well M - s shutdown p D��.OpeZio - Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ pC� �rogramm 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ h ze RI 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development m 5. Permit to Drill Number. 208-027 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Strati graphic ❑ Service ❑ 6. API Number: 50-029-20583-02-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No m PBU G-11 B 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028280 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD' Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD). 12829 9022 10230 8416 2370 10230,11550 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 30" 35-115 35-115 Surface 2716 13-3/8" 35-2751 35-2688 5380 2670 Intermediate 1 8516 9-5/8" 33-8549 33-6 838 6870 4760 Liner 2004 7" 8351-10355 6696 - 8532 8160 7020 Liner 2533 2-3/8" 1 10302 - 12829 8483-9022 11200 1 11780 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade:Tubing MD (ft): 10930 - 12780 8989-9020 3-1/2" 9.29 L-80 30-10355 Packers and SSSV Type: No Packer Packers and SSSV MD (ft) and TVD (ft): No Packer No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic g 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 15, 2020 15. Well Status after proposed work: Oil EI - WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Worthington, Arae be deviated from without prior written approval. Contact Email: Aras.Worthington@bp.com Authorized Name: Worthington, Ares Contact Phone: +1 907 564 4102 Authorized Title: Integrity 8 lis, entions En ineer Authorized Signature: r Date: 1h1 h?rA,D COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may Witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test vl�Location 13 1 Clearance ❑ Othe:r/E AiJ s-� /Y% /T-1�.4 SGV u 7 y2 Y�VhRt�rres7'a 2a�0- 2s L'e'* ,' ea�Lo+�zE7►7E.t1rP.��XF, P.��Pa��p jy ���ANK-TV 00734 4110A.31.VO-Zi¢CE�ME'NTi.✓(r g11Mea-ePP-47--t .E1rd!;45,RF_ on6,.,w� POs m is Injection MIT Req'd? Yes ❑ No ❑ /�G / LE7F/65 . V/�GJ �f'�//, M(,GTv � �j4p L#,q Y� Spacing Exception Required? Yes No LY Subsequent Form Required:/6-94-7 FOQ WAZ;k-�/��-ocze/ AD BVTHE ^ Approved by: COMMISSIONER COMMISSION Date: o UU 3BDMS-%^-rE8 0 7 2020 r ORIGINAL 11,4 ;.3m_ ubmit Form and Form 10403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate G-11 B IA Cement Squeeze Well Interventions Engineer: Aras Worthington (907) 564-4102 Pad Engineer: Joleen Oshiro (907) 564-4606 Expected Start Date: February 15, 2020 Well: G -11B History G-11 B is a natural flow producer with multiple tubing leaks. In 2011 TxIA was discovered. A patch was set at 4637' MD and subsequently failed pressure tests. It was determined the lower anchor was not set properly so the patch was pulled and reset. After 3 years of on time the well again developed TxIA. A solution was not sought at this time. The patch was pulled to allow a securing plug to be set in the well In 2013 a leak detect log found leaks at 4675', 4613', 4626' MD. Slickline set a new patch but the well still failed pressure tests. After some diagnostics the well was left shut in with a plug and has been left alone until recently. In 2018, there was an attempt to set an extended patch in the well. After the new patch again failed, a new LDL was run and found another leak at 8154'. The plan forward is to pull the patch, pump a cement job though GLM #1. Then push the cement down the IA to GLM#2 to establish circulation through this GLM. Pump the second stage of cement through GLM#2 up to —4150' MD to regain the integrity of the well. Thereby repairing the primary barrier.C,67S6 Co�3G ioe>iszto 17-U0 Sc7d A4,.V The plan leaves the TOC 1052' TVD below the SC shoe and 868' MD above the UG4. This leaves a 4150' monitorable IA. Current Status The well is currently classified as "Not -Operable" by BP. Objective Perform a cement squeeze and return the well to "Operable" status. Economics By repairing this well with an IA cement squeezed, it is estimated that an incremental 66 mbo can be produced over the next several years. Without an IA remedial squeeze, this well has no utility in the foreseeable future. by Well: G -11B Procedure Slickline/Relay 1. Pull patch assembly 2. Pull GI -Vs 3. Set DGLVs in St. #2 & #3 4. Pull IBP from 10230' MD. 5. Set composite bridge plug @ -9170' MD 6. Circulate tubing & IA to diesel 7. Pull DGLV from St. #2 Coil Tubing 1. Set retainer at 9170' MD 2. Circulate 36 bbls of cement through GLM #1 taking returns from IA 3. Unsting from the cement retainer and lay -1-2 bbl of cement in the TBG @ 1:1. 4. PUH above Sta #2 at 8154' MD. 5. Contaminate & begin reversing cement out down the IA and up the coiled tubing. Push the cement down the IA with diesel. Hold CT at this depth until clean returns are observed at surface. Once the excess IA cement has been cleaned out, continue down to within 10' of the retainer then POOH. 6. At surface, verify GLM#2 is still open and free of cement by pumping 10 bbls diesel down the TBG and up the IA. 7. Set CBP at -8160' MD 8. Set retainer -8145' MD 9. Circulate 233 bbls of cement through GLM#2 through retainer taking returns from IA. TOC after squeeze expected to be 4150 MD, 3705' TVD. 10. WOC until compressive strength reaches 500 psi. 11. Mill out cement retainer and composite bridge plugs. Slickline/Fullbore pp 1. SCMT to determine TOC. /` e v i e w SG/YJ% Gs/jQOG Gr! 2. Set TTP. 3. MIT -T & CMIT-TxIA to 2500 psi. see icC-G-rb w /TitlLcsS 4. Pull TTP. DHD/Well Integrity Engineer Well: G -11B 1. Update AKIMS to include MIT -Ts and CMIT-TxlAS every 2 years. Proposed Cement Blend Parameters Cement Type/Weight 15.8 ppg Class G batch mixed. Field blend to be equal to lab ppg +/- 0.1 ppg Slurry Temp Between 80° and 110°F Fluid Loss 20-100cc/30min Compressive Strength 2000 psi in 48 hrs Thickening Time 6 hours Batch Mix Activit Time Hours Shearing time, Quality Control, PJSM 1 Cement Displacement 2 Cement Contamination 2 Safety 1 Minimum Required Thickening Time 6 3 VB' 5M FAC 4_J!P MMM! nIVD- 880Ir:83 1 sw GSG� 7?U. i -tz� [� �,f.. t Y -T2 I— J -i_ 27bt' Minimum 1 UG4 = 5018'MD = 4301'TVD Well: G -11B G.7 --I I B��� I 7" CHROMF UR `E"t' MA7( WEQEG 27 1 @ 12282' 1 1 1 1{ r I TOC = 4150' MD = 3734' TVD; I CA8 17 MANWA 3 0W RK 16 -__�'"� ��91Li0 1376 14 I KBUG pFY 8K 0 1?lO5rR12 IOYOP 7'LNi 8361' 8$81 H 5r8•XB IR'&1RTMKSY,(l.T.:b` T�OF 7'LM 8$99• 6369• "9alA^x r•RKxLm.n.e Irl 3E2-1- OF ikA , 6648' y .8399' I is vlr x r 6LCR I r1•, FICA ri twAix, iO. s ai1r� 9300' 13CR•8o wx FEFaX ATMS~RY FEF LOGSNB k'1cN.1T;rva3. CF 64lR'1A6 ANGLEATTOPPFF* 84"h#109:W N &: Per" ID FY6 tcbn6 C43 For Ms10Iiral par169Pa SEE SPFI NiERVAL q#Y 0 - SHS'FIOT O9fl1110= I SM 158^ 6 110EM-11080 138' 8 111210-11510 O W,'02118) 15W 6 111570-11646 c �04r02/06' 1 88' 6 111760-11810 c 0410M 1.56• 6 .11830-12330 c (MA75118l 158' 6 X12400-12490 C BM&NOS1 156' 6 12550-12580 c 04.,02168 15r 6 12890 -12780 c 04.102M 1_ 31f2' BKR WIPDTOCL((OY16IU6I - FOR R 29k,131 Aki711gN. U -b '. Y6' LW 4.70, L 80 STL.. MLLOUT W8d70W (G-1IA) 8549'-8599' j tUYfU' �-�UKft ]5 KA LT ROM.D-1>!70• x10902 - 2.N'ohR�VY 5LV,0=Y-92P MLLIXfT W{VOOW {G118i1W55'-1036A'� f16b6'�- I rt•tNMP(OOry1nU1 DATE RN BY I M Eidllb 1351E Fe VV BY lDM4,Q41',5 06rT3181 014(.1N4L CObMPLETKN4 11125/15 SETVNBt(11A7I15 11121N93 0.14 810ETRACN(G11A) 105/29/16 ZV1JId3 PPALEDWRP(052 M) 04=08 c1D8F0BRACK(G116j 08+11175 CWJMO C,LV (7O (gEk13r15j {06ICJ7//8 08/17/15C.B1J NILLFDVAdPf09f1311�_ _ _ _ 18N/JE4 GT-VG'C•(05'23r18) .i SFTV47Y#+AIX KKPR HP-- ':0827!18 MFFY SET LMPk�4tQYAgC PF02S OGL 11125115 D787J1F9 GP.V pD i11A1Tt116) I 12792' -1 1 w m I WBAMAEBAY tW %ARL: G 118 PE MIT N9: "!080210 AR N5: 50 629-2056.102 Tt'IN, R13F, 2444" RA 8 7W.. FSP FxphMion (Alaska) Cement plug #2 circulated down # tubing, through perfs and up OA&IA L from-1300'MD to surface Minimum ID =1.75" @ 4567' SL.M 3-112" WFT •- ------ ' --'- UG4 = 5018'MD = 4301'TVD �tric+c r•I.t4t -�. &357'-.. _f - IWC TOCl03115&81 -19300__}- ..__--_ 7' LNR :To 4xR•ea rsc ----' FHSORATM SLAVARY FUF LOG- SN6 MAYIGRC/,]_ p DWI= AWA -E AT TOP R7S 84" A 10930 We I*'m b R9duction OB for hKWic9l part dWa -S-PF SQE 11Mtl93 0.14__1I —2VIAO. M6FR7AL on CV 53407Soz BP Fxpiaration (Mr,04) 1.58' 6 .10930-11050 0 OBl41it0j- 1 W 6 11210 - 11510 0 03102%8 1 58- 8 111570 -11840 C 04;02`Y}8) 108' 8 lino - 11810C MAVAM 1 5C 0 119M -12330 G 04102'08 1 59- S 12400 - 12490 C MK72'09 4.58' 8 112550- 125M C 04Al2%8 158• 8 12M -127W C 04f001 L3 -1'r BKR V'WFSTOCAC (03/18Na) M. LAO 111%, 0OR7 W,. 81-2997 T 037t ,>p!, D=8.184' Well: G -11B G-11 B@;2282 ------ 7196, A lr?' r xM RSSV LANDMV ID 2-M-'-1 TOC = 4150' MD = 3734' TVD; z) 4708'-..3-t'2'WFFW3Y_FAC7 WRF] "..at•(fMl04!18j _I AS I FT MAN%W A i� 1V51 46LAK 101iT N i 4874 4281 43 MMG i10ML RK 18 25/13!18$ Z 8151 8555 a5 AK1G pptrlF RK 19 OSf13118 I 9180 7378 t4 K8t1t. BM5' BK 0 1 ___ _.... 876i � �52'X&,K•&CFtT®Y(SlY, 0.t-1,50' 8359• 5/a' X 7" ftKR I lP. n.428• 8399' l 111 W X l' NF(N IIP, WA a TF-S\A(i(, e).6 l78;-] Reservior plug #1 circulated down tubing, either with coil or FB. TOC -8000'MD. DPZ3 top = 10729'MD. a 10198'FR35KBLTR0;0-1.81V j to3aZ j-,z.1o'an-n�arsiv,o-uay MLLOUT NMnGW (Csit H} 10355'- 40304' f Mill 1 R3.C♦iCEBAY iNr VVELL G1/B PgBM W:"2p80270 ARW50-02970:31-02 SW 12, T11K R13F, 2444' FN 8 ?Y18' FFI DATE R LV BY CohM9415 MTF f4Y BY 000450475 025023081 018GINAL Ct3A4pLET4oN 1141615'/15 RTIJhA SETVWW(Ilwi 51 11Mtl93 0.14__1I —2VIAO. 0400CTD IOFIRCKl94B) %1AV 7115 Gei'.M17 C,YO (fJ9ti3146) - 09+17015&BJM[ IL.LEDVW(M13/15) ,05218TZVfJA GV o (05231 8} _ 08fi711B ,ih SkT'Y.-7!'XPA C)t FKRa NG 08127118.MTWOMO SU UPFM VADS*, jC FeM oCLL BP Fxpiaration (Mr,04) 7125115 0081JFD�GLY pO (11/OZHS) J`_ _ - _ -- - . TREE = 11/11' RM FMO WELLHEAD, 135/8-5/8 ACTUATOR= AXELSON OKB. ELEV = 64.71' REF ELEV = 7125' BF. ELEV = 35.46' KOP = 1900' Max le = 97° 11196' Datum MD = 10729' Datum TVD = 8800' SS 13-3/e' CSG, 729, L-80 BTRS, D = 12.347" Minimum ID =1.75" @ 4567' SLM 3-1/2" WFT WIDEPACK UPPER PATCH I TOP OF 7- LNR I Alt, L-80 BTRS, D = 8.681- —86r 9-5/8' BRDGE PLUG �. 7' LNR 29.1, L-80 NSOC XO TO 13CR-80 NSC PERFORATION SL AMMRY REF LOG: SMS MCN./GWOCL OF 04/01/08 ANGLEATTOP F9iF 64° @ 10930' NDle: Refer to Production DB for historical pert data SIZE SPF I INTERNAL OPWSQZ I SHOT IIISQZ 1.56" 6 10930 - 11050 O 09/11/10 1.56" 6 11210-11510 O 04/02/08 1.56" 6 11570-11640 C 04/02/08 1.56" 6 11760-11810 C 04/02/08 1.56" 6 11930 - 12330 C 04/02/08 1.56" 6 12400-12490 C 04/02/08 1.56" 6 12550 - 12580 C 04/02/08 1.56" 6 12630 - 12780 C 04/02/08 S, .0087 bpf, D = 2.992' R, 299, 13CR-80 NSCC, bpf, D=6.184" SAFETY NOTE WELL ANGLE > 70'@10978'... =11B T' CHROME LNR •" MAX DOGLEG 27.1" @ 12262' 0 2196' 3-1/2'0T6XD8 SSSV LAND NP,D=2.75' 2631' 9-5/8 DV PKR 3-1/2' FT WDEPACK UPPH2 PATCH w/4 JTS QCLL SPACB2 PPE, D = 1.75' (06/10/18) 3-1/2' WFT WDEPACK PKP-D = 1 e1" /ne/n/1R1 GAS LFT 3 �4874142611 2 8154 1 9160 6555 7376 43 45 14 MNG AMG KBUG DOA£ DONE OM1' RK] RK BK --16 0: 18 DE 0 12 8361' 9-5/e' X 8-1/4' BKR TEBK SLV, D = 7.50' 8369' 9-5/e' X 7' BKR LTP, D = 6.28' 8399' 9-5/8' X T BKR LTP. HGR 8 TEBACK D= MILOUT WNDOW (G-1110) 8549' - 8599' 35 KB ( lusuz- I—L[./U- tlKH UEROY SLV, D = 1.920' MILOUT WNDOW (G-116) 10355'- 10364' 11 12-3/8' LNR, 4.711, L-80 STL, .0039 bpf, D = 1.995' I DATE REV BY COMMEMS DATE REV BY COMMENTS 06.23181 ORIGINAL COMPLETION 11/25/15 JMG/JMD SET WRP 11/02115 1120103 D-14 SMETRACKIG41N 0529/18 N/JMD PULLED WRP(0523/18) 04102108ORDK: CTD SDETRACK (G -11B) 05/29/18 N/JMD GLV CAD (0523(18) 09/ 17/15 CJWJMD GLV C/009/13115) 06/07/18 NXW/JM SET WIDEPACKPKR&IBP 09/17/15 GJB/JMDI PULLED WRP 09/13/15 0627/18 MTH/JMD SET UPPERWDEPACK PKR&OCL 1125115 DJS/JMD GLV CAD (11/02115) 012920 JNL/JMD ADDED OKB, REF, & BF ELEV 1 12792' 1 PRUDHOE BAY UNIT WELL G11B PERMrTNo: 1080270 API No: 50-029-20583-02 T11 N, R1 3E, 2444' FNL & 2361 BP Exploration (Alaska) STATE OF ALASKA • • ALASKA OIL AND GAS CONSERVATION COM�ION APPLICATION FOR SUNDRY APPROI�RLS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well H Operations shutdown 0 I Suspend 0 Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Sus Well 0 PAlter Casing 0 Other Cement IA Q • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: Exploratory ❑ Development Q 3. Address: P.O.Box 196612 Anchorage,AK 5. Permit to Drill Number: 208-027 - 99519-6612 Stratigraphic6. 7. If perforating: 0 Service 0 API Numb r: 50-029-20583-02-00 What Regulation or Conservation Order governs well spacing in this pool? 8. Well N Will planned perforations require a spacing exception? n umber: Yes 0 No 21 PBU 1 RE 1" 9. Property Designation(Lease Number): '1') 10. Field/Pools: ry ADL 0028240" PRUDHOE BAY,PRUDHOE IL. . SEP 2 1 2016 11. PRESENT WELL CONDITION SUMMARY / .r'1 Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): )1 G4 F 8455 12829 • 9022 10271 Plugs(MD): Junk' Dj�+ as 10271/11550 Casing Length Size MD ` Structural i. Burst Collapse fib Conductor 80 20"x30" 38-118 _ 37-117 Surface 2715 13-3/8"72#L-80 36-2751 36-2689 4930 Intermediate 8515 9-5/8"47#L-80 --- 2670 35-8549 -6838 6870 Production 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): TubingSee Attachment Size: I Tubing Grade: I Tubing MD(ft): See Attachment See Attachment 3-1/2"9.2#L-80 L-80 Packers and SSSV Type: See Attachment 32-10355 ers nd SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed �� No SSSV Installed 12.Attachments: Proposal Summa 0 Wellbore Schem - , el Class after proposed work: Detailed Operations Program BOP.. tcment ❑ Expl tory 0 Stratigraphic 0 Development H - Service 0 14.Estimated Date for Commencing Operations: 441/4.0444. 15. Well Status after proposed work: Oil H - WINJ 0 16.Verbal Approval: WDSPL 0 Suspended 0 �-� Date: �, GAS ❑ WAG 0 Commission Representative: GSTOR 0 SPLUG 0 GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Tempel,Troy be deviated from without prior written approval. Email Troy.Tempel@bp.com Printed Name Tempel,Troy Title Well Integrity Engineer Signature Phone +1 907 564 5698 Date 7 9- SEe- Zp/( COMMISSION USE ONLY Conditions of approval:Notify Commission o that a representative may witness Sundry Number: y Plug Integrity LI BOP Test 0 Mechanical Integrity Test 0 l 9 tYLocation Clearance ❑ Other: I� c,i +i@�lll l d : he6 4 , e u iU Post Initial Injection MIT Req'd? Yes 0 No ❑ Spacing Exception Required? Yes 0 No ® /n 4-'(...74''Subsequent Form Required: C l/ Approved by: APPROVED BYTHE COMMISSIONER COMMISSION Date: ORIGINAL 1. , ft. =8 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. q �� (/ � Attachments in Duplicate r S m RN 0 0 0 co 0 CN N CO M O O� O O r- Lo 0 y 0 0 0 0 0 0 7 r-0 N O m V Cfl 00 m O 00 O O N N CO M r Cr) N CO CO CO M O LO N CO 00 CO O) 00 C1 1 1 1 1 1 I- CO (0 l() O) cam- a N CO M Cr) CO r M CO CO CO 4.0 M to , N N L0 M O M CO M N 00 O O N O r � r V M I . 1 1 1 1 1 Q MN CO I MM M M M M N M � M O O W ~ a o M o 0 0 woo O M o0 00 J J M I J J • • E N x N.1,t r J M N f/) rn 0)* OD - N V N N N W NM w M M O co M M M N = CO f- Lf) M M LCD M J N OO c- V- N O CC I W = - O O .N 0 U O O Cr X EXr Z Z erW W W W m ODS- ZZ Z0 U W Z J J J • N a7 m c- N- 6) co M CO CO CO CO CO CA •cl' CO c- lf) r CO co M p, O O (A N N O - 6066 d O O N N r- `- CD O N p 0 0 0 O 0 0 0 O 0 0 0 0 0) O) O O) O) 0) O) O) O) 0 0 H v N- 0) in rt Tt co co N d' .0 CO O •:1" CO CO N CO CO Z. 12°. 0 0 0 O N N O O ti 0 O O T M N N O 0 c- W 0 M 0 0 0 O O O O O O O > p M M M M M M M M M M 0 2 0 F- w O a w a) U O > °t° 00000000000 0 - w O O w w CO a) CNI n- Cr) O) CO CO J J J a s U) Z O y O) O) O O Ln CO CO M LC) I- Q Q < W CD C D O O N N N N C_) U_ Z_.) J W W O J O r r r r r Z Z Op p J p -� Q Q Q = a W a O 2 2 2 Z p p O I- O 0 0 0 w a a V m w w w a H Q J < 2 2 O co v) (n (n (n (� r r < 60 • Q M (O O N t` (fl M O Ln M Y.1 0 0 0 0 '- '- r c- N (N N to � a � s• ` f v_) Y 0O ) ce 2 2 2 0 (~n w (ai) (Ji) (an d a. v 0 o• f/) U) Cl) Cl) Cl) Cl) Cl) Cl) Cl) Cl) Cl) Q mmmmammmmmmm 0 a) (u a d H o L() Ln Ln LO LO LO LO IC) LO LO Ln C00000000000 w Z O N N N N N N N N N N N Z1-1- .11; Q w N N N N N N N N N N N O W p N LL y . c- . .. . cam- S Z a J 0 pW W LL w v- T T T T T T r T < 0 J F- 0 M a W J JTt QQa (oLLLLLL � a � a) E Zmmmmmmmmmmm V) r LL. a Cl) 0 LL N a' U- 66666666666 L t t t t t � t t t t t m a g a J 66666066 U' ( QQm (nELIdgaa' • • Packers and SSV's Attachment PBU G-11 B SW Name Type MD VD G-11 B PACKER 8359.87 6702.66 Depseription G-11 B PACKER 8405.97 7"Tieback Packer G-11B PACKER 6735.74 7" Baker Packer 10296 8477.92 3-1/2" Baker KB Top Packer • I_::`• ar 41, Well: G-11B G-11 B IA Cement Job Intervention Engineer Troy Tempel (907) 570-1351 Production Engineer Joleen Oshiro (907) 564-4606 History G-11 B was completed in March 2008 as a CTD sidetrack in Western G-Pad with -2500' of 2-3/8" liner. Prior to drilling this sidetrack, G-11A had known TxIA communication between 4613' MD and 4645' MD of the 3-1/2" production string. It was decided to run a 35' KB Straddle patch post-CTD operations. The patch was successfully installed in April 2008 after completing the G-11 B sidetrack. Initial tests on G-11B showed competitive rates and the well was produced fulltime until January 2009 when it hit marginal GOR. Attempts to cycle the well showed that G-11 B had little recharge and the well was shut-in for the majority of 2009 and 2010. In September 2010 a CIBP was set across the toe interval of the well and perfs were added into the heel. Initial tests were competitive and the well was again produced full time until February 2011, at which the well's GOR again became marginal. The well was reclassified as Under Evaluation due to a failing TIFL in March 2011. The patch was pulled and a tubing caliper was ran, showing increased corrosion and 20%-80% wall penetrations. The GLVs were also dummied off and a washed out orifice valve was thought to be the cause of the failing TIFL. The patch was reset. In November 2011 the well failed an MIT-IA with a 0.15 bmp LLR. The patch was pulled and a leak detect log was ran, showing several leak points between 4613' MD and 4675' MD; this range is 62' MD of tubing length. An IA squeeze is proposed to restore the integrity of the tubing. The well is currently secured with a WRP at 10,271' MD Reserves/Economics There are 114,000 bbls of oil estimated to be recovered from G-11B. This 3-1/2" tubing integrity repair is • proposed to restore operation of G-11 B. Objective Cement the IA to cover up compromised 3-1/2" tubing interval at 4600' MD. Tubing punches will shot at 9000' MD and cement will be circulated up the IA via a Coil Tubing unit. The new IA cement top will be targeted at 3500' MD to cover up all questionable 3-1/2"joints. Post-Job Evaluation This well is a producer so an AA will not be applied for, however the following BP internal criteria will evaluate the integrity of the non-rig workover: ➢ MITIA and MITT ➢ SCMT to locate Top of Cement (TOC) 0 • Long-Term Integrity Monitoring ➢ Record WHPs daily ➢ 4-year (quadrennial) MITIAs and MITTs 2 • • TREE= 3-1/8"5M FMC G-1 1 B WELLHEAD 13-5/8"McEVOY SAFETY NOTE: WELL ANGLE>70°@ 10978'**' ACTUATOR AXELSON Current 7"CHROME LNR***MAX DOGLEG:27.1°@ 12262' OKB.ELEV: 64.7' BE ELEV= 36.26' KOP= 1900' 2196' —3-1/2"OTIS XDB SSSV LAND NIP,D=2.75" Max Angle= 97"@ 11196' AF ISL Datum MD= 10729' Datum ND= 8800'SS 2631' 9-5/8"DV PKR 13-3/8"CSG,72#,L-80 BTRS,D=12.347" H 2744' 3-1/2"Tubing Holes -4613'-4675' = GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE L 3 4874 4261 43 MAG DMY RK 0 11/02/15 2 8154 6555 45 MMG DMY RK 0 11/02/15 TOP OF 7"LNR- 8351' 1 9160 7376 14 KBUG DMY BK 0 12/05/02 8351' —9-5/8"X 8-1/4"BKR TEBK SLV,D=7.50" TOP OF 7"LNR H 8399' � 8359' —9-5/8"X 7"BKR LTP,D=6.28" TOP OF CEMENT — $549' I 8399' _-9-5/8"X 7"BKR LTP,HGR&TEBACK,ID=6.278" 9-5/8"CSG,47#,1-80 BTRS,ID=8.681" — —85494. do k. 9-5/8"BRIDGE PLUG —i 8800' j. elo lotie Minimum ID =1.65"@ 4595' \ MLLOUTWNDOW(G-11A) 8549'-8599' 3-1/2"WFD PATCH TOC(03/15/08) 9300' 4.7"LNR,29#,L-80 NSCC XO — 9921' r." TO 13CR-80 NSC r PERFORATION SUMMARY 10234' -7"MARKER JONT REF LOG: SWS MCNL/GR/CCL OF 04/01/08 10271'J—3-1/2"WFD SPECIAL CLEARANCE WRP(11/2/15) ANGLE AT TOP PERF:64"@ 10930' 10296' —BKR 35 KB LT PKR ID=1.870" Note:Refer to R oduction DB for historical perf data SCE SPF INTERVAL OPWSQZ SHOT SQZ 10302' -2.70"BKR DEPLOY SLV,D=1.920" 1.56" 6 10930-11050 C 09/11/10 1.56" 6 11210-11510 C 04!02/08 MILLOUT WINDOW (G-11B)10355'-10364' 1.56" 6 11570-11640 C 04/02/08 6y Irkip 1.56" 6 11760-11810 C 04/02/08 ► ad 1 1.56" 6 11930-12330 C 04/02/08 .1111 1.56" 6 12400-12490 C 04/02/08 4` 11550' -1.71"CBP(09/11/10) 1.56" 6 12550-12580 C 04/02/08 •* 1.56" 6 12630-12780 C 04/02/08 . �16 1. . , �r t 3-1/2"BKR WI-APSTOCK(03/18/08) 10355' : 1.1 * ,,, I.I. �!Ei� 3-1/2"TBG,9.2#,L-80 TDS,.0087 bpf,D=2.992" - 10355 , 12792' - PBTD 7"LNR,29#,13CR-80 NSCC, - —10355 .0371 bpf,13=6.184" 94 31, 2-3/8"LNR,4.7#,L-80 Sm,.0039 bpf,D=1.995" — 12829' N eV If DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/23/81 ORIGINAL COMPLETION 09/17/15 CJWJMD GLV GO(09/13/15) WELL: G-118 11/20/93 0-14 SIDETRACK(G-11A) 09/17/15 GJB/JMD PULL®WRP(09/13/15) PERMfT No:"2080270 04/02/08 NORDIC 1 CTD SIDETRACK(G-11B) 11/25/15 DJS/JMD GLV CJO(11/02/15) API No: 50-029-20583-02 08/13/14 PJC CSG/LNR/PATCH CORRECTIONS 11/25/15 JMG/JMD SET WRP(11/02/15) SEC 12,T11 N,R13E,2444'FNL&2368'R3 10/16/14 GJB/PJC PULL PATCH(10/15)SET WFD WRP 10/23/14 PJC PLUG CORRECTION Exploration(Alaska) 3 • TREE= 3-1/8"5M FMC G-11 B WELLHEAD 13-5/8"WIcEVOY SAFETY NOW: WELL ANGLE>70°@ 10978'*** ACTUATOR AXELSON Proposed IA Cement 7"CHROME LNR***MAX DOGLEG:27.1°@ 12262' .-- ____ OKB.ELEV= 64.7 BF.ELEV= 36.26' KOP= 1900' I 2196' H3-1/2"OTIS XDB SSSV LAND NIP,D=2.75" 1 Max Angle= 97°@ 11196' Datum MD= 10729' Datum TV D= 8800'SS — 1 — 2631' H9-5/8"DV PKR O 1 13-3/8"CSG,72#,L-80 BTRS,D=12.347" H 2744' I 2"Z u I 3500' j�Proposed LA TOC J 13-1/2"Tubing Holes I-4613'-4675 •V,0%.4' GAS LET MANDRELS e fi ST MD TVD DEV TYPE VLV LATCH PORT DATE ��//►♦► * 3 4874 4261 43 MMG DMY RK 0 11/02/15 i 2 8154 6555 45 MMG DMY RK 0 11/02/15 1 TOP OF 7"LNR I—{ 8351' 10t 1 9160 7376 14 KBUG DMY BK 0 12/05/02 TOP OF 7"LNR H 8399' P. r 8351' J- 19-5/8"X 8-1/4"BKR TIEBK SL V,D=7.50" 1 li'4 8359' H9-5/8"X 7"BKR LTP,ID=6.28" e 'TOP OF CEMENT 1_1 8549' 8399' J I9-5/8"X 7"BKR LTR HGR&TIEBACK,ID=6.278" • 11,4 IA 19-5/8"CSG,47#,L-80 BTRS,U=8.681" 1-1 —8549 rIV VI eve- 6,00 elf 19-5/8"BRDGE PLUG 1— 8800' \'' e � IvRLLOUTWINDOW(G-11A) 85as'-85ss' Minimum ID = 1.65" @ 4595' 3-1/2" WFD PATCH !e : 1 1TOC(03/15/08) I--I 9300' I 7"LNR,29#,L-80 NSCC XO JH 9921' --TO 13CR-80 NSC • b PERFORATION SLAMIARY 10234' J—7"MARKER JOINT RQ-LOG: SWS MCNL/GR/CCL OF 04/01/08 ANGLE AT TOP PERF:64°@ 10930' , 10296' J-1 BKR 35 KB LT PKR,D=1.870" 1 Note:Refer to Production DB for historical pert data *. .-. SIZE SPF NTERVAL OFTUSOZ SHOT SOZ .L. , !fi:- 10302' J--12.70"BKR DEPLOY SLV,D=1.920" 1 1.56" 6 10930-11050 C 09/11/10 1.56" 6 11210-11510 C 04/02/08 1.56" 6 11570-11640 C 04/02/08 MILLOUT WINDOW (G-11B)10355'-10364' 1.56" 6 11760-11810 C 04/02/08 *y 1.56" 6 11930-12330 C 04/02/08 1.56" 6 12400-12490 C 04/02/08 - . ti.N. 11550' -11.71"CEP(09/11/10), 1.56" 6 12550-12580 C 04/02/08 " 1.56" 6 12630-12780 C 04/02/08 /,+ **`./ , 13-1/2"BKR WHIPSTOCK(03/18/08) 1— 10355' 'k 1�1 : ►: 3-1/2"TBG,9.2#,L-80 TDS,.0087 bpf,D=2.992" I--1 —10355 1 Ar*. 11N, 1 12792' 1-1 PBTD 1 7"LNR,29#,13CR-80 NSCC, —1 —10355 I , .0371 bpf,D=6.184" *. 12-3/8"LNR,4.7#,L-80 SIL,.0039 bpf,D=1.995" 1— 12829' „,,,„„4„. DATE REV BY COMMENTS DATE REV BY COMMENTS ._ PRUDHOE BAY UNIT 06/23/81 ORIGINAL COMPLETION 09/17/15 CJN/JMJ GLV C/O(09/13/15) WELL: G-11B 11/20/93 D-14 SIDETRACK(G-11A) 09/17/15 GJB/JMD PULLED WRP(09/13/15) _ PERMIT No:'12080270 04/02/08 NORDIC 1 CTD SIDETRACK(G-11B) 11/25/15 DJS/JMD GLV CIO(11/02/15) 08/13/14 PJC CSG/LNR/PATCH CORRECTIONS 11/25/15 JMG/JMD SET W11/02/15RP API 24 ( ) SEC 12,T11 N.R13E 244444''FN 0582L&2368'FEL 10/16/14 GJB/PJC FULL PATCH(10/15)SET WFD WRP 10/23/14 PJC PLUG CORRECTION Si'Exploration(Alaska) 4 • • Tom= 3-1/8"5M FMC G-11B WELLHEAD 13 5/8"AAcEVOY SAFETY NOTE: WELL ANGLE>70°@ 10978'*** ACTUATOR AXEISON Proposed P&A. 7"CHROME LNR***MAX DOGLEG:27.1°@ 12262' B - .Cement plug#2 pumped from ' �` .{ia� surface to fill u annuli L � {;;;$ 2196' 3-1/2"OTIS XDB SSSV LAND NP,0=2.75" I - 1900' y j 0 Max Angle 97°@ 11196' 0 -1600 Perforate 3-1/2"and 9-5/8"and fill both annuli Datum MD= 10729' I from surface,pumping down the tubing Datum TVD= 8800'SS — 1 2631' I—9-5/8"DV PKR H 1 13-3/8"CSG,72#,L-80 BTRS,U=12.347" 2744' 1 13-1/2"Tubing Holes J-4613'467511 ''•i{. - f,: 715GAS LIFT MANDRELS ••':5 •:; ST MD TVD DEV TYPE VLV LATCH PORT DATE " ••;::tir ! • 3 4874 4261 43 MMG DMY RK :::::} 0 11/02/15 .A.:.1 P ..,1'... 2 8154 6555 45 MMG DMY RK 0 11/02/15 'TOP OF 7"L NR I--I 8351' 44.;.:::.:..AN./.P-* 1 9160 7376 14 KBUG DMY BK 0 12/05/02 TOP OF 7"LNR -1 8399' ge.:%":::•:::.:.:::, 8351' _H9-5/8"X 8-1/4"BKR TURK SLV,ID=7 50" 1 CI • 8359' J-19-5/8"X 7"BKR LTP,ID=6.28" •571.,,5 , TOP OF CEMENT H 8549' :.* 8399' —19-5/8"X 7"BKR LTP,HGR&TIEBACK,ID=6.278" 1 19-5/8"CSG,47#,L-80 BTRS,U=8.681" 1- 1 -8549 Vf::~:.+ •• • e%...::"715,...:5;xk• 19-5/8"BRIDGE PLUG 1- •'�:� ► 8800' • „,.,,.,.• *' •:• •f,, r Cement plug#1 pumped fullbore .*.. ‘4.4.;..p::1.*:, .+ or laid in with coil tubing ... ?:;•f.r 1 TOC 03/15/08 M,•ti'ti” ( ) 1-i 9300' 1 715:5:. 1.:;:::::-, 7"LNR,29#,L-80 NSCC XO H 9921' I-- ••rf*.;* TO 13CR-80 NSC • •d's:S'.• • •;rtif:.. 10234' i--17"MARKER JONT 1 •PERFORATION SUMMARY . } • REF LOG: SWS MCNL/GRJCCL OF 04/01/08 -*:%•.:::•4••:6.• ANGLE AT TOP PERF:64°@ 10930' •f: .•y Note:Refer to Production DB for historical pert data •;ti{{r 10296' J—I BKR 35 KB LT PKR,D=1.870" 1 SIZE SPF INTERVAL OPWSQZ SHOT SQZ ••••• Ai f.7. + 10302' 2.70"BKR DEPLOY SLV,ID=1.920" 1 1.56" 6 10930-11050 C 09/11/10 �, 1.56" 6 11210-11510 C 04/02/08 .►�ti N V, 1.56" 6 11570-11640 C 04/02/08 • P r;• 1.56" 6 11760-11810 C 04/02/08 +{�I,+01 1.56" 6 11930-12330 C 04/02/08 . l!rr:- 1.56" 6 12400-12490 C 04/02/08 ' 1.56" 6 12550-12580 C 04/02/08 f:: 1.56" 6 12630-12780 C 04/02/08 / • ♦ , :ti;:7171• 13-1/2"BKR WHIPSTOCK(03/18/08) 1— 10355' • ,&$ "+ +f 3-1/2"TBG,9.2#,L-80 TDS,.0087 bpf,U=2.992" H '�' -10355 0,_;. i 12792' I� PBTD I ( 7"LNR,29#,13CR-80 NSCC, �"��',. -� -10355 1 *-' .0371 bpf,ID=6.184" .4.: 4'4 12-3/8"LNR,4.7#,L-80 STL,.0039 bpf,O=1.995" H 12829' ' DATE REV BY COMMENTS DATE REV BY COBS 06/23/81 ORIGINAL COMPLETION _09/17/15 CJN/JMD WELL GLV CIO(09/13/15) P BAY UNIT D-14 SIDETRACK(G-11A) 09/17/15 GJB/JMD PULLED WRP 09/13/15) - 04/02/08 NORDIC 1 CTD SIDETRACK(G-11B) 11/25/15 DJS/JMD GLV CIO(11/02/15) PERMIT No.'00802802 50-029-20583-02 08/13/14 PJC CSG/LNR/PATCH CORRECTIONS 11/25/15 JMG/JMD SET WRP 11/02/15 - API No: 44'FNL& 36 ( ) SEC 12,T11 N,R13E 2444' &2368'FEL 10/16/14 GJB!PJC PULL PATCH(10/15)SET WFD WRP 10/23/14 PJC PLUG CORRECTION BP Exploration(Alaska) 5 • • • Recent T/I/O Trends _ . tr-��-� j +r Rte_ �1}I{It•+rt LT ��� ''ST3 lflSla 12W14 41WIT5 72145 3tt4't5 C*t5 YDTS Cb2fr5 07,7,13 Matnr MY2t,t 16.15 ,x�M5,:2305 @QtM zersn 3tffit4 XS xQS1 Cement Calculations IA Fill up volume to 3500' MD 319 bbls Total cement to pump 320 bbls Cement Type/Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 7 hours Cement thickening time: Mix on the fly Activity Time (hours) Shearing time, quality control, PJSM 0 Cement displacement 5 Cement contamination 1 Safety 1 Minimum required thickening time: 7 Cement Ramp for Blend Time Volume Pumped Temperature Pressure (bbls) (°F) (psi) 0:30 22 165 2370 1:30 100 135 2060 2:30 150 120 1865 3:30 200 100 1655 4:00 250 80 1445 5:00 300 65 1235 5:30 320 55 1155 6 • • Cement Volumes Casing Diameter Tubing OD Annular Capacity Length Annular Volume Comments (in) (in) (bbls/ft) (ft) (bbls) 6.184 3.5 0.025250 807 20.38 7"Linerx 3-1/2"Tubing 6.280 3.5 0.026412 40 1.06 7"LTP x 3-1/2"Tubing 7.500 3.5 0.042743 8 0.34 9-5/8"Tie Back x 3-1/2"Tubing 8.681 3.5 0.061307 4851 297.40 9-5/8"Casing x 3-1/2"Tubing Cased Hole Volume 5706 319.18 Percent Excess 0% 0 Total Cased Hole Volume 319 Procedure Slick Line 1. Pull 3-1/2" WRP from 10,271' MD E-Line 1. Set 3-1/2" CBP at -9220' MD, target mid joint 2. Punch the 3-1/2" tubing across the collar at 9206' MD, punch 5' Confirm by pressure response or by pumping crude or diesel down the IA, taking returns up the tubing 7 • Coiled Tubing 1. Rig up a Micromotion to take IA returns 2. PT CT connector & CT to -4800 psi in anticipation of high circulating pressures towards the end of the cement job. Note: usually pressures do not get higher than 4000 psi during IA cement jobs, but they have in isolated cases so best to be prepared. 3. Run in hole with Weatherford 1-Trip cement retainer. Displace CT x TBG backside to heated 160F -6.8 ppg diesel while RIH. 4. Tag up on CBP at -9220' MD. Pick up 30' MD and set retainer at -9190' MD, target mid-joint. Establish diesel circulation down CT and up IA to tanks. Verify coil backside is SI. Pump the following fluid schedule. Note: Do not pump any freezable fluids through retainer into the IA as these fluids will remain in the IA after the cement job. ➢ *500 bbls of heated diesel (160F) 320 bbls cement per design CT volume of FW (un-sting from retainer with last 1-2 bbls of cement in CT) *Note: There are two reasons for the heating the diesel: 1. The cement in the IA acts as an extended packer. Tubing movement models indicate that heating the entire wellbore to -140F before setting a packer on a rig is the optimum temperature for locking the tubing in place in PBU (prevents buckling when the tubing is heated up via producing or injecting). Heating the entire wellbore for this type of job to 160F will approximate this (wellbore fluids will cool before cement sets). 2. Heating the entire wellbore helps the cement to cure. There have been a couple of IA cement jobs where fluids were not heated prior to cementing and the cement took much longer to cure. In one case it took about 2 weeks before the well would pass an MITIA. 5. This should place the TOC in the IA at -3500' MD. Keep track of return from the IA to track the TOC in the IA. In order to keep a rate of -1 bpm be prepared for CT pressures to be over 4000 psi towards the end of the cement job (when water is displacing cement out of the CT). See Coil Contingency Procedure #1 below if cement locks up while pumping into the IA. Note that the CT x TBG backside is expected to pressure up -650 psi as cement in the IA rises above the tubing leak. Do not bleed off this pressure as it will only allow for cement to enter the tubing from the IA via the tubing leak at -4600' MD 6. While maintaining Tubing x CT backside pressure (expected to be -650 psi but hold whatever pressure it settles out at), un-sting from the cement retainer with 1 bbl of cement still in the CT and lay remainder of cement in 1:1 on top of cement retainer. Monitor CT x Tubing pressure closely as the stinger is pulled out to ensure retainer seals. 8 • • Coiled Tubing Cont. 7. With the same pressure (650 psi or more; depending on the retainer sealing) trapped on the CT X TBG backside, POOH pumping only CT displacement down the CT x TBG backside. This can be achieved by POOH and pumping just enough down the backside to maintain whatever pressure the CT x TBG backside equalized at. Verify that for every 100' of CT pulled, -0.3 bbls of fluid is pumped into the well. 8. Leave the well with shut-in with 650 psi WHP. Freeze protect CT with MEOH/water as needed with the well shut-it. Coil Contingency Procedure If at some point the cement locks up and cannot be pumped into the IA, then hold whatever CT x TBG backside pressure has already been established, cut cement at surface, un-sting from the retainer, and lay the cement into the tubing 1:1 maintaining CT x TBG backside pressure. Ful!bore' 1. Wait on cement to cure for at last 5 days 2. MIT-IA to 2500 psi Coil Tubing 1. Make up junk mill and RIH, tag TOC (expected -9190' MD). 2. Mill through cement, retainer, cement, and the CBP. 3. Pick up 1.80" or 1.75" mill and push CBP remnants down to -11,550' MD (to top of CIBP). Slickline 1. Set 3-1/2" WRP above 35 KB LTP 2. MIT-T to 2500 psi 3. Run SCMT log from deployment sleeve to surface to find TOC and relative bond 4. Pull 3-1/2" WRP Integrity Engineer Add Quadrennial (every four years) MIT-T and MIT-lAs to AnnComm. 9 - • •• -. r • ::><::<:>:;:::>:::;>::.> B?' . .::::..::::: :. . i.:.,:;::::..::::;.1. ;:;:;:%;:}: 11r................;,...........11 1:1y!o.F3Na 1::iiii:;iii:t::;;:;::;<::i;;;:::is:;:;:;::::;::;i::i::i:f:i:x i•:, .. .:�::.:::::::,.::::::::: . �+. ..............,............................................................................................ :Y��:�l�:il�l�i.11 �.>:i::;:;::'` ��``�"��'���?���fi`����'���?� ���:� `? >:?�?' ?`i: ;;���: i'2�'���::<�:� ::5 <'•.`•'.?5�?:: ?r< ''i''ii�����'? 'S?�?� R ... .. ... .. ........ . . ... \:t:i:'liii:ii.:'i:iiiiiii: . :..:..:::. ............ .....::.:: ::i:i+::::: ::::::i:: : vi ^:: `:i:i:::: ::::: `iii ii.'•iii:^i%i:�iiii�:F'iii::':::::i+':?fS:>:i::ii:!':'L�:::::::i::::::i:::i::i: :;;f:;::;:i;:;:j:: HORIZONAL COMPLETION .................................................:.:::.::..::.:.::::::::::. >< >-.5�����:.:�-._.:;<, ,�,,,a.--; .;, , :: ;>': »>»'»'�<><>':<�'' � >��''>> <r::«::>:.:<:> `:=::�xrx:;:-:;;r:•s%<i3cs '�� =<'gi :;kj:i.;,�:_;::: ;::::>:=>i::>;>:::�: :»: :;»< > ii:.::: .;:.::;:.;.:;:..... oN;RAQt15.................::.::::ii.;:.;;:.::,.;..:.::.;:.:<::.:.;:.:;:.;:.;:.33 :.:.:::::::.•T$R .........:::.:::. L i:<:i::i<:::i;;:;;:;;::;: x.96:::>: ..<::: r:>.>>:nlIl<:::>::::> :<:::>:>::::;:>::>::::>:::«::::::::::::::::::::::::::::>:=:<:::::>>: <:>:<:»<::::>:<:>::>:::>:<:>::>::>s:::::>::>:<:_:<:;::»::::>«>::>:::3:::z:::a:'sigig::>:>:::::: :::<:::; : 115 F'C �N pA+�� � :::.::. . :. ;ii:i.;:i.;;:.;:.;:.. . ::: :,:.::;:..:.:�i.::.:.:�:.::.;>:.::ii.;:.;;:.;:::::::::::::::..::.::.::>:.:: 7 LINER TOP 8351' ITEM ID OD LENGTH TOP BOTTO ; 3.5" WLEG 2.992 4.260 .93 10898.72 1 . ' - !, .65 3.5" 9.2# L-80 PUP JT. TDS 2.992 4.280 10.08 10888.64 0898.72 3.5" 9.2# "SWN" NIPPLE TDS 2.635 4.260 1.21 10887.4 10888.64 3.5" 9.2# L-80 PUP JT. TDS 2.992 4.280 10.08 i877.35 10887.43 3.5" 9.2# "SWS" NIPPLE TDS 2.750 4.280 1.39 10875.96 10877.35 _ 3.5" 9.2# L-80 PUP JT. TDS 2.992 4.280 !4.i.08 10865.88 10875.96 4.5" TDS BOX-3.5" TDS PIN XO 3.000 5.2�:. 2.18 10863.70 10865.88 4.5" NSCT BOX-4.5" TDS PIN XO 3.958 ".000 9.55 10854.15 10863.70 7" SABL-3 HYD. SET PKR. BAKER 5 5.875 4.27 10849.88 10854.15 KBH-22S ANCHOR SEAL ASSY. BAKER 3.875 5.500 .85 10849.03 10849.88 4.5" TDS BOX-4.5" NSCT PIN XO <t4"''. 3.958 5.250 9.74 10839.29 10849.03 3.5" TDS BOX-4.5" TDS PIN • 3.000 4.500 2.14 10837.15 10839.29 JT# 1-3.5" 9.2# L-80 - TBG. MILLED OUT•500 31.59 10805.56 10837.15 3.5" 9.2# L-80 T► •• 'UP JT. @ 10355' -280 10.09 10795.47 10805.56 3.5" "SWS" :.IPPLE TDS 9.2# 280 1.39 10794.08 10795.47 FOR G-11 B 3.5' .# L-80 PUP JT. TDS , .x.280 10.09 10783.99 10794.08 9-2# L-80 TDS TBG. #2-52 2A9; a.500,, 1607.35 9176.64 10783.99 3.5" 9.2# L-80 TDS PUP JT. 2.992 4.270 9.82 9166.82 9176.64 CAMCO KBUG W/1"BK LATCH GLM#1 2.875 5.313 6.54 9160.28 9166.82 3.5" 9.2# L-80 TDS PUP JT 2.992 4.270 9.76 9150.52 9160.28 3.5" 9.2# L-80 TDS TBG. #53-83 2.992 3.500 978.75 8171.77 9150.52 3.5" 9.2# L-80 PUP JT. TDS 2.992 4.280 9.79 8161.98 8171.77 CAMCO MMG W/ 1.5" RK GLM #2 2.875 6.059 8.44 8153.54 8161.98 3.5" 9.2# L-80 TDS PUP JT. 2.992 4.280 9.60 8143.94 8153.54 3.5" 9.2# L-80 TDS TBG. #84-186 2.992 3.500 3251.20 4892.74 8143.94 3.5" 9.2# L-80 TDS PUP JT. 2.992 4.280 10.41 4882.33 4892.74 CAMCO MMG W/ 1.5 RK 2900S-#3 2.875 6.059 8.43 4873.90 4882.33 3.5" 9.2# 1-80 TDS PUP JT. 2.992 4.280 10.01 4863.89 4873.90 3.5" 9.2# L-80 TDS TBG. #187-270 2.992 3.500 2649.68 2214.21 4863.89 3.5" 9.2# L-80 TDS PUP JT. 2.992 4.280 10.06 2204.15 2214.21 3.5" FLOW COUPLING 2.882 4.280 5.97 2198.18 2204.15 3.5" OTIS "HXO" SVLN 2.750 4.840 2.54 2195.64 2198.18 3.5" FLOW COUPLING 2.882 4.280 5.98 2189.66 2195.64 3.5" 9.2# L-80 TDS PUP JT. 2.992 4.280 10.09 2179.57 2189.66 3.5" 9.2# L-80 TDS TBG. #271-338 2.992 3.500 2147.01 32.56 2179.57 3,5" 9.2# L-80 TDS PUP JT. 2.992 3.500 1.46 31.10 32.56 MCEVOY TBG. HANGER3.5"TDS T&B .70 30.40 31.10 ROTARY TABLE TO TUBING SPOOL 30.40 . 30.40 10 • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Thursday, March 08, 2018 2:11 PM To: Carlisle, Samantha J (DOA) Subject: FW: Please withdraw 3 sundries Sam, Please handle. I have placed these 3 unapproved sundries in your confidential box. Thanx, Victoria From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent:Thursday, March 08, 2018 1:32 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Worthington,Aras J<Aras.Worthington@bp.com> Subject: Please withdraw 3 sundries Victoria, Please withdraw the following unapproved IA Squeeze sundries: G-11B(PTD#208-027) 15-48C(PTD#211-030) Y-24(PTD#186-113) If you have any questions or need additional information please let me know. Thank you, Joe Lastufka SIM Specialist Cell: (907) 227-8496 I Office: (907) 564-4091 444,4pSubsurface&Wells tetformation Martveretem BP Exploration Alaska 1900 E. Benson Blvd. I Room: 778C I Anchorage, AK 1 Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Monday, June 15, 2015 8:40 AM To: 'AK, D&C Well Integrity Coordinator' Subject: RE: Producer G-11B (PTD #2080270) Floe for Economic Evaluation Kevin, Yes, as discussed, I do not foresee any problems with this evaluation period. Thanks and Regards, Chris Wallace Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 r��VNE� JUN 3 0 21)15 (907)793-1250(phone) �` (907)276-7542(fax) chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. From: AK, D&C Well Integrity Coordinator [mailto:AKDCWelllntegrityCoordinator@bp.com] Sent: Sunday, June 07, 2015 1:06 PM To: Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator Subject: Producer G-11B (PTD #2080270) Floe for Economic Evaluation Chris, This is a follow up email from a conversation that you had with Whitney. BP would like to flow producer G-11B (PTD#2080270) for future well work economic evaluation. The well has known tubing x inner annulus communication, but has competent production casing demonstrated by a passing CMIT-TxIA on October 16, 2014.The plan would be to flow for a period of up to 28 days, with monitoring. We would revisit with you after 14 days of testing. I have enclosed a copy of the wellbore schematic for reference. Let us know if you need more information. Thank you, Kevin Parks (Alternate: Whitney Pettus) 1 BP Alaska-Well Integrity Coordinator G VV Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator(nlbp.com 2 ~ ~o ®rgan%Z®ng (done) ^ Two-sided III 11111111111 II III ^ Rescan Needed RES AN for Items: Greyscale Items: 1 ~~ ^ Poor Quality Originals: DI TAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: NOTES: ^ Logs of various kinds: ^ Other:: BY: Maria Date: ~ ~ /s/ Pro "ect Proofin II I I I II ~) I I III I I III J g BY: Maria Date: /s/ Scannin Pre aration ,_~ x 30 = + ~ =TOTAL PAGES g p (Count does not include cover sheet) gY: Maria ,_ Date: ~,,' O D /s/ Production Scanning """"""" ""' Stage 1 Page Count from Scanned Fite: _~. (Count does include cove heel) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: a,,, V ~O /s/ r ~/ I 11 Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s II I I I it 11 I II II 11111 Scanning is complete at this point unless rescanning is required. ~eScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III Ililll III IIII III 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg 2Q12. Alaska Oil and Gas Conservation Commission sti tED AUG 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB G -Pad G"' Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad G that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, o-� Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) G -Pad Date: 03/05/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal G -01A 1931710 50029202140100 3.0 NA 3.0 NA 10.2 5/10/2010 G -02B 2081580 50029202170200 0.5 NA 0.5 NA 2.6 5/10/2010 G -03A 1970700 50029202210100 0.7 NA 0.7 NA 6.0 5/27/2010 G-04B 2061400 50029202250200 0.1 NA 0.1 NA 1.7 5/10/2010 G -05 1780970 50029203510000 0.0 NA 0.0 NA 0.0 5/10/2010 G-06A 2060120 50029203580100 0.6 NA 0.6 NA 5.1 5/12/2010 G -07 1790180 50029203590000 0.5 NA 0.5 NA 3.4 5/11/2010 G-08A 2061830 50029205810100 0.1 NA 0.1 NA 0.9 5/27/2010 G -09B 2071100 50029205820200 9.0 NA 9.0 NA 69.7 5/20/2010 G -10C 2060090 50029205530300 0.9 NA 0.9 NA 8.5 3/5/2012 ,-3P G -11B 2080270 50029205830200 0.0 NA _ 0.0 NA 0.0 5/21/2010 G -12B 2031410 50029205970200 0.5 NA 0.5 NA 2.6 5/13/2010 G -13A 2001630 50029206000100 0.0 NA 0.0 NA Trace 5/12/2010 G -14B 2090680 50029206460200 0.7 NA 0.7 NA 5.1 5/22/2010 G -15B 2080650 50029206470200 26.0 4.0 0.5 7/16/2011 3.4 7/19/2011 G -16A 2090560 50029206430100 0.0 NA 0.0 NA Trace 5/22/2010 G -17A 2060760 50029206190100 21.4 4.0 0.6 7/16/2011 3.4 7/19/2011 G -18A 1990320 50029206200100 71.7 14.0 1.0 7/16/2011 8.5 7/19/2011 G -19B 2071240 50029215990200 0.0 NA 0.0 NA Trace 5/22/2010 G -21 1951540 50029226040000 0.5 NA 0.5 NA 3.4 5/12/2010 G -23B 2091440 50029216800200 0.5 NA 0.5 NA 4.3 5/11/2010 G -24A 2060820 50029216710100 0.1 NA 0.1 NA 0.9 5/11/2010 G -258 2070860 50029216520200 5.3 NA 5.3 NA 23.8 5/28/2010 G -26B 2050480 50029216610200 2.0 NA 2.0 NA 6.8 5/11/2010 G -27A 2070310 50029216460100 0.5 NA 0.5 NA 2.6 5/30/2010 G -298 2101410 50029216500200 2.8 NA 3.0 NA 17.0 5/13/2010 G -30C 2091510 50029216130300 1.0 NA 1.1 NA 5.1 5/30/2010 G -31B 2090310 50029216160200 0.8 NA 0.8 NA 6.0 5/21/2010 G -32A 1970010 50029216360100 0.8 NA 0.8 NA 3.4 5/21/2010 2a'1=o27 25 -JAN -2012 RECEIVE 21321 - Schkindie w r.. ■ r 7 ----, 5873 Alaska Data & Consulting Services an State of Alaska 2525Gamboa Street, Suite 400 °� ®. ... ^°�� "�°'•` �de illF P Y' Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 APAArage Attn: Christine Shartzer ATTN: Stephanie Pacific) 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD G -11B BINC-00051 RESERVOIR SATURATION TOOL LOG 7- Jul -11 1 1 K -05D BUTT -00010 MEMORY COMPENSATED NEUTRON LOG 26- Aug -11 1 1 04 -22AL1 BAUJ -00054 MEMORY COMPENSATED NEUTRON LOG 19- Nov -10 1 1 J -22A BJGT -00049 RESERVOIR SATURATION TOOL LOG 6- Jul -11 1 1 F -01A BINC -00049 RESERVOIR SATURATION TOOL LOG _ 5Jul -11 1 1 11 -28A BRRJ -00017 RESERVOIR SATURATION TOOL LOG 27- Oct -11 _ 1 1 H -26 BJGT -00062 RESERVOIR SATURATION TOOL LOG 22- Aug -11 1 1 07 -13C BD88 -00148 MEMORY COMPENSATED NEUTRON LOG 7- Aug -11 1 1 F-30 BINC -00048 RESERVOIR SATURATION TOOL LOG 4-Jul-11 1 1 H -04B BUTT -00033 MEMORY COMPENSATED NEUTRON LOG 6- Oct -11 , 1 1 J -19 BINC-00057 RESERVOIR SATURATION TOOL LOG 13- Aug -11 1 1 15-17 BVYC -00006 RESERVOIR SATURATION TOOL LOG 29- Sep -11 1 1 M -21A BBSK -00074 RESERVOIR SATURATION TOOL LOG 6-Jun-11 1 1 E -19C BD88 -00132 MEMORY COMPENSATED NEUTRON LOG 6-Jul-11 1 1 2- 04/M -19 AV1P-00100 RESERVOIR SATURATION TOOL LOG 9- Aug -11 1 1 - G -21 BG4H-00070 ' IRESERVOIR SATURATION TOOL LOG 6- Aug -11 1 1 04 -23A BBSK -00091 RST SIGMA W/ BORAX 26- Aug -11 i 1 1 $4 13CRb1 U (1 'l 194u1 -11 1 OWDW -SW AV1P -00091 RESERVOIR SATURATION TOOL LOG 16-Jul-11 1 1 . ,.' F' " ,� � S T 1 T" Z"�`w,, nip ".�.: 4 « ,.;,..1iF:mi f ii-F 11 1 R.0 ...' .17. 7 "= 71'; , . -; : -- T'i""'= r` 7 7i tOOLL.;z i 11 1 Prints already disbibided _ I 0 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 NOT OPERABLE: Producer G -11 B (PTD #20270) Secured With Downhole Plug • Page 1)5,2' Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Sunday, November 27, 2011 9:22 PM R? l( To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operatons Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Ramsay, Gavin; AK, OPS Well Pad DG Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); LeBaron, Michael J Subject: NOT OPERABLE: Producer G -11 B (PTD #2080270) Secured With Downhole Plug All, Producer G -11 B (PTD #2080270) has been secured with a downhole plug and passed a CM_ IT -TxIA to 3000 psi on 11/26/2011. The well is reclassified as Not Operable. Plan forward: 1. E -line: Leak Detect Log Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) ; .� °s, : r Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Monday, October 24, 2011 8:54 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM• AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel yan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Eng2, K, RES GPB East Wells Opt Engr; Ramsay, Gavin; AK, OPS Well Pad DG � Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney; Arend, Jon ORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer G -11B (PTD #2080270) Sustained Casin. 'ressure Above MOASP All, Producer G -11 B (PTD #2080270) has confirmed susta ed IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 232' 340/410 on 10/23/2011 during a wellbore monitor by the DHD crew. The well has been reclassified -, Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity Plan forward: 1. Fullbore: MIT -IA to 3000 psi 2. Wireline: Pending results of MIT -I DL if required A TIO plot and wellbore schema have been included for reference. 11/29/2011 UNDER EVALUATION: Producer G -11B (PT,080270) Sustained Casing Pressure live ... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, October 24, 2011 8:54 PM �� /1 1 z l k To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Ramsay, Gavin; AK, OPS Well Pad DG Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer G -11 B (PTD #2080270) Sustained Casing Pressure Above MOASP Attachments: G -11 B (PTD #2080270) TIO Plot.doc; G -11 B (PTD #2080270) wellbore schematic.pdf All, Producer G -11 B (PTD #2080270) has confirmed sustained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2320/2340/410 on 10/2=11 during a wellbore monitor by the DHD crew. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. Fullbore: MIT -IA to 3000 psi 2. Wireline: Pending results of MIT -IA, LDL if required - A TIO plot and wellbore schematic have been included for reference. <<G-11B (PTD #2080270) TIO Plot.doc» <<G-11B (PTD #2080270) wellbore schematic. pdf» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator A'Lv = 667Of . Office (907) 659 -5102 SCE' " 34 t Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 nd hce 61 11/2/2011 PBU G-11 B PTD #2080270 10/24/2011 TIO Pressures Plot Well: G-11 „ . . 4,000 3,000 --- T bg —II-- LA • 2,000 OA 0 OA 000A — On L000- 41111 07/30/11 08/06/11 08/13/11 08/20/11 08/27/11 09/03/11 09/10/11 09/17/11 09/24/11 10/01/11 10/08/11 10/15/11 10/22/11 • TREE = 3 -1/16" 5M FMC SAFETY NOTE: WELL LE 70° @ 9548'. WELLHEAD = 13 -5/8" McEVOY o * * *7" CHROME LINER * * *ORIG WELLBORE ACTUATOR = AXELSON KB. ELEV = 64.7' G-11 A NOT SHOWN BELOW WHIPSTOCK * ** BF. ELEV = 36.26' 1 I KOP = 11900' _ Max Angle = 97° 0 11196' 2196' I 13 -1/2" OTIS HXO SSSV LAND NIP, ID = 2.75" Datum MD = 10729' Datum TV D = 8800' SS 2631' H9-5/8" DV PKR I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H I 2744' Minimum ID = 1.75" @ 4609' I 4609' - 4647'' - 13-1/2" WRD ER PKR, ID = 1.75" (04/21/11) I 3 -1/2" WRD ER PACKER GAS LiFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3 4874 4261 43 MMG DMY RK 0 03/21/11 2 8154 6555 45 MMG DMY RK 0 03/21/11 1 9160 7376 14 KBUG DMY BK 0 12/05/02 (TOP OF 7" SCAB LNR H 8351' 1 TOP OF 7" LNR H 8399' 1 TOP OF CEMENT I 8549' ■ .49 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8549' , � v / 9 -5/8" BRIDGE PLUG 8 800' -+ NrSy� = 6�,c�Ps; I H - I TOC (03/15/08) I 9300' (l 1�1 4 PERFORATION SUMMARY + 1 10296' I BKR 35 KB LT PKR, ID = 1.870" 1 REF LOG: SWS MCNL /GR/CCL OF 04/01/08 1 1� • �. ANGLE AT TOP PERF: 64 @ 10930' H , 4 r �,4 10302' H 2.70" BKR DEPLOYMENT SLV, ID = 1.920" Note: Refer to Production DB for historical pert data �� SIZE SPF INTERVAL OPN/SQZ DATE N 1 +� 1 1.56" 6 10930 - 11050 0 09/11/10 1� X14, +• 4 1.56" 6 11210 - 11510 0 04/02/08 1 � � 1 4 � 1.56" 6 11570 - 11640 C 04/02/08 �� 44 i MILLOUT WINDOW (G -11 B) 10355' - 10364' 1.56" 6 11760 - 11810 C 04/02/08 0 :4 4 1.56" 6 11930 - 12330 C 04/02/08 Ve∎ V 44 1.56" 6 12400 - 12490 C 04/02/08 ► t 1 : � t� .4 1.56" 6 12550 - 12580 C 04/02/08 !� i�+ I 4, 1.56" 6 12630 - 12780 C 04/02/08 /I (t�� )$ s1 ` 11550' H1.71" GBP (09 /11/10) I ■ 13 -1/2" BKR WHIPSTOCK (03 /18/08) H 10355' 11 ','1-' S 4 1 3 -1/2" TBG, 9.2 #, L -80 TDS, .0087 bpf, ID = 2.992" I 10355' R +� - A ` 7" LNR, 29 #, 13CR -80 NSCC, 10850' .0371 bpf, ID= 6.184" W 1 PBTD ht.. 12790' 1 4v4 V4v . 4� • ■ 12 -3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.995" H 12829' I DATE REV BY COMMENTS ] DATE REV BY r COMMENTS PRUDHOE BAY UNIT 06/02/81 ORIGINAL COMPLETION 03/31/11 JCM/PJC PULL PATCH (03 /19/11) WELL: G -11B 11/19/93 D-14 SIDETRACK (G -11A) 04/28/11 ALH/ PJC SET PATCH (04/21/11) PERMIT No: 2080270 04/02/08 NORDIC 1 CTD SIDETRACK (G -11B) API No: 50- 029 - 20583 -02 12/14/09 AW /JMD DRLG DRAFT CORRECTIONS SEC 12, T11 N, R13E, 2444' FNL & 2368' FEL 09/23/10 CJS /PJC CIBP/ PERFS (09/11/10) 03/31/11 JCM/PJC GLV C/O (03/21/11) BP Exploration (Alaska) STATE OF ALASKA ALASKA OAND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 PATCH 4609 -4647 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. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ g 208 -0270 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 20583 -02 -00 8. Property Designation (Lease Number) : r 9. Well Name and Number: ADLO- 028240 o PBU G-11B 10. Field /Pool(s): _ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12829 feet Plugs (measured) 11550 feet true vertical 9022.29 feet Junk (measured) None feet Effective Depth measured 12790 feet Packer (measured) SEE BOTTOM feet true vertical 9020.79 feet (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20 "91.5# H-40 34 - 114 34 - 114 1490 470 Surface 2735' 13 -3/8" 72# L -80 33 - 2749 33 - 2687 4930 2670 Production 8768' 9 -5/8" 47# L -80 32 - 8800 32 - 7040 6870 4760 Liner 2013' 7" 29# 13CR80 8351 - 10364 6696 - 8540 8160 7020 Liner 2529' 2 -3/8" 4.7# L -80 10300 - 12829 8482 - 9022 11200 12829 Liner Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.2# L -8 , AY 0 - 1 20); 30 - 8482 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" DV Packer 2636 2594 3 -1/2" WFD ER PKR 4604 4640 4063. 4089 7" Liner Too Packer s tir im £33.,93 67026731 BKR 35 KB TPKR . 102967 12. Stimulation or cement squeeze summary: ) 3 Intervals treated (measured): I'a '� 1 r 0 oMISsion Treatment descriptions including volumes used and final pressure:, & Gas tens- gtslt 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 204 14,239 1 867 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ID Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil IS Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ 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 - . - Last ilk Title Petrotechnical Data Technologist Signat NAB! Phone 564 -4091 Date 4/29/2011 _ .' RBDMS MAY 0 2 201I -- ‘-2-1( Form 10 -404 Revised 10/2010 � ••0.,04 Submit Original Only G -11 B 208 -027 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base G -11B 4/2/08 PER 11,210. 11,510. 9,030.65 9,022.18 G -11 B 4/2/08 PER 12,550. 12,580. 9,007.82 9,008.86 G -11 B 4/2/08 PER 12,400. 12,490. 9,009.23 9,006.88 G -11 B 4/2/08 PER 12,630. 12,780. 9,011.34 9,020.36 G -11B 4/2/08 PER 11,760. 11,810. 9,022.84 9,019.18 G -11B 4/2/08 PER 11,570. 11,640. 9,022.64 9,021.53 G -11 B 4/2/08 PER 11,930. 12,330. 9,009.78 9,011.4 G -11B 9/9/10 BPS 11,550. 11,552. 9,022.67 9,022.69 G -11 B 9/10/10 APF 10,960. 10,990. 9,000.61 9,010.97 G -11B 9/10/10 APF 10,990. 11,020. 9,010.97 9,019.49 G -11B 9/10/10 APF 11,020. 11,050. 9,019.49 9,026. G -11B 9/11/10 APF 10,930. 10,960. 8,988.5 9,000.61 • G -11B 9/11/10 BPS 11,550. 11,570. 9,022.67 9,022.64 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 4110 • • G -11B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/7/2011; ** *WELL SHUT -IN ON ARRIVAL * * *(E -LINE PATCH) !INITIAL T /I /O = 800/500/200 1 RIGUP WHE AND ELINE TOOLS. CONDUCT GOOD PT. WAITING ON MODIFIED WEATHERFORD AND BAKER TOOLS ** *JOB CONTINUED ON 8- APR -2011 E 1 4/8/20 ** *JOB CONTINUED FROM 7- APR - 2011 * * *(ELINE PATCH) RIH WITH MH- 22(7X3)/1- 11/16" WEIGHT /CCUFIRING HEAD/ BAKER- E 110/WEATHERFORD LOWER PAKER: OD = 2.72, OAL = 19', WEIGHT = 220, 1 FISHING NECK = 1 -3/8 ". CORRELATE TO MEMORY JEWELRY LOG DATED 4- , 1MAR -2008. SET 3.5" ER LOWER PACKER AT 4647' MID ELEMENT DEPTH: CCL ITO MID ELEMENT = 9.3', CCL STOP DEPTH = 4637.7'. OAL PACKER LENGTH = 12.86'. MIN. I.D. = 1.810 ". TOP OF LOWER PACKER = 4644.6'. GOOD 'INDICATION OF FIRE, TAG TO CONFIRM. FINAL VALVES: WING CLOSED, 1 MASTER OPEN, SSV CLOSED, SWAB CLOSED. RDMO AND HANDOVER TO DSO. ** *JOB COMPLETED*** _ � 4/20/2011 ** *WELL S/I ON ARRIVAL * * *(p /t integrity) 1MADE ONE ATTEMPT AT SETTING 3 -1/2" ECLIPSE PATCH & 3 -1/2" ER PKR. I * ** WSR CONTINUES ON 4/21/11 * ** 3 3 4/21/20111 ** *WSR CONTINUED FROM 4/20/11 * * *(p /t integrity) SET WFR 3 -1/2" ECLIPSE PATCH & 3 -1/2" ER PKR W/ HES DPU, SNAP LATCH 1AT4635' SLM. (top of patch approx. 4597 SLM) ** *WELL S/I ON DEPARTURE, PAD OPERATOR NOTIFIED * ** 3 1 1 • • 4/24/2011 psi O 2nd attempt) 6 Pumped 10.7 bbls V of 80 *F crude down IA to reach A test pressu e IA lost 120 psi. in the first 15 min. and 40 psi. in the 2nd 15 min. for a total loss of 1601 jpsi. in a 30 min. test. Blend back 19 bbls to Final WHP= 2100/600/200. SV,WV,SSV- closed / MV IA, OA -open. 1 FLUIDS PUMPED BBLS 9 DIESEL 11 CRUDE 20 TOTAL EE _. TR ACTUATT R = AXELSON 3 - c FMC • SAFETY N. WELL ANGLE > 70° @ 9548'. • WELLHEAD 5/8 MEVOY G-1 1 B * * *7" CHROME LINER***ORIG WELLBORE AND ACT B. ELEV = 64.7" G-IIA NOT SHOWN BELOW WHIPSTOCK* ** BF. ELEV = 36.26' 11 i KOP = 1900' Max Angle = 97° @ 11196' 2196' , - 1/2" OTIS HXO SSSV LAND NP, ID = 2.75" I Datum MD = 10729' Datum TV D = 8800' SS 2631' H 9 -5/8" DV PKR I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" I — I 2744' I 1 Minimum ID =1.75" @ 4609' 0 : 1 4609' - 4647' I— I 3 -1/2" WRD ER PKR, ID = 1.75" (04/21/11) I 3 -1/2" WRD ER PACKER GAS LIFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH PORT DATE L 3 4874 4261 43 MMG DMY RK 0 03/21/11 2 8154 6555 45 MMG DMY RK 0 03/21/11 1 9160 7376 14 KBUG DMY BK 0 12/05/02 'TOP OF 7" SCAB LNR I — 1 8351' TOP OF 7" LNR 1-1 8399' ' I TOP OF CEMENT H 8549' , 7 r 19-5/8" CSG, 47 #, L -80, ID = 8.681" H 8549' i I. ■41 4 I9 -5/8" BRIDGE PLUG H 8800' ■ (TOC (03/15/08) I 9300' /` /# ■ PERFORATION SUMMARY 1 • 1 10296' H BKR 35 KB LT PKR, ID = 1.870" I REF LOG: SWS MCNL/GR/CCL OF 04/01/08 � �L ` 4 ANGLE AT TOP PERF: 64° @ 10930' • ∎ I «! 10302' I- 1 2.70" BKR DEPLOYMENT SLV, ID = 1.920" I Note: Refer to Production DB for historical perf data 1 SIZE SPF INTERVAL OPN/SQZ DATE ► 4 r 1.56" 6 10930 - 11050 0 09/11/10 W4 ■••• 1.56" 6 11210 - 11510 0 04/02/08 V• 4 1.56" 6 11570 - 11640 C 04/02/08 W■ 4 1.56" 6 11760 - 11810 C 04/02/08 'fir'∎ °4•N; MILLOUT WINDOW (G - 11 B) 10355' - 10364' 1.56" 6 11930 - 12330 C 04/02/08 ► Ir , 4 1 1.56" 6 12400 - 12490 C 04/02/08 ► � � 1.56" 6 12550 - 12580 C 04/02/08 1�' ��N� 1.56" 6 12630 - 12780 C 04/02/08 ► + I�Oi t.�1 •,• ■ 11550' H 1.71" CIBP (09/11/10) I ■ I3 - 1/2" BKR WHIPSTOCK (03/18/08) H 1 0355' 1• "4 • 1 . 1 3 -1/2" TBG, 9.2 #, L -80 TDS, .0087 bpf, ID = 2.992" I—I 10355' I. ! V iiiiipto 7" LNR, 29 #, 13CR -80 NSCC, 10850' ` ` .0371 bpf, ID = 6.184" I PBTD H 12790' + 12-3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.995" H 12829' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/02/81 ORIGINAL COMPLETION 03/31/11 JCM/PJC PULL PATCH (03 /19/11) WELL: G-11B 11/19/93 D -14 SIDETRACK (G -11A) 04/28/11 ALH/ PJC SET PATCH (04/21/11) PERMIT No: '2080270 04/02/08 NORDIC 1 CTD SIDETRACK (G -11 B) API No: 50- 029 - 20583 -02 12/14/09 AW /JMD DRLG DRAFT CORRECTIONS SEC 12, T11 N, R13E, 2444' FNL & 2368' FEL 09/23/10 CJS /PJC CIBP/ PERFS (09/11/10) 03/31/11 JCM/PJC GLV C/O (03/21/11) BP Exploration (Alaska) - NOT OPERABLE: Producer G -11B IF #2080270) Secured With Kill Weigliluid and Down... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, March 21, 2011 9:00 AM ( 1 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Ramsay, Gavin; Walker, Greg (D &C) Subject: NOT OPERABLE: Producer G-11B (PTD #2080270) Secured With Kill Weight Fluid and Downhole Plug Attachments: G-11B TIO Plot 02- 25- 11.doc; G -11 B.pdf All, Producer G-11B (PTD #2080270) has been secured after loading the well with kill weight fluid and setting a downhole plug on 3/20/2011. The well has been reclassified as Not Operable. The plan forward 11'5 continue evaluating tubing integrity for patch options. Please call if you have questions, Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 _ A � `', Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, February 25, 2011 7:50 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Ramsay, Gavin; Walker, Greg (D &C) Subject: UNDER EVALUATION: Producer G-11B (PTD #2080270) Sustained casing pressure on the IA AII, Producer G-11B (PTD #2080270) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to SSV/2050/250 on 2/23/2011. The well has been reclassified as Under Evaluation and may be placed on production for diagnostics when weather permits. The plan forward is as follows: 1. DHD: TIFL 2. WIE: Evaluate setting DGLVs and performing an MITIA (pending TIFL results) A TIO plot and wellbore schematic have been included for reference. «G-11B TIO Plot 02- 25- 11.doc» «G -11 B.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/21/2011 PBU G -11B PTD 2080270 3/21/2011 TIO Pressures Plot Well: 6-11 4,000 • 3,000 I li w —0— Tbg —f— IA 2000 - • —� OA 00A —♦— 000A On 1,000 • 9 12/04/10 12/18/10 01/61/11 01/15/11 01 /29/11 02/12/11 TREE = 3-1/16" 5M FMC • SAFETY : WELL ANGLE > 70° @ 9548'. WELLHEAD = 13 -5/8" McEVOY ACTUATO - w AXEi_SON **'7" CHROME LINER* **ORIG WELLBORE AND ��R = � 1 G-11 A NOT SHOWN BELOW WHIPSTOCK*** KB ELEV = 70.21' BE ELEV = 36.26' I KOP = 1900' I hi 3 -1 2" OTIS FIXO SSSV LAND NIP, ID = I Max Angle = 97° @ 11196' • i Datum MD = 10729' Datum TVD = — 8800' SS , ; I 2631' I I 9- 5 /8 "DVPKR (13 -3/8" CSG, 72 #, L -80, ID - 12.347" H J f 2744 ' I 1 is , 4604' - 4645' H 3-1/2" WFD ER PKR, ID = 1.75" (04/24/08) • Minimum ID =1.75" @ 4604' 3 -1/2" ECLIPSE PATCH GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4874 4261 43 MMG DOME RK 16 04/07/08 2 8154 6555 45 MMG SO RK 20 04/07/08 1 _9160 7376 14 _ KBUG DMY _ BK 0 _12/05/02 TOP OF 7" SCAB LNR H 8351' I TOP OF 7" LNR I 8399' I TOP OF CEMENT J-1 8549' ' N 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8549' �, 1 I9 -5/8" BRIDGE PLUG H 8800' A ( TOC(03 /15/08) I 9300' 0 r r4 4 PERFORATION SUMMARY IA � , 1 10296' BKR 35 KB LT PKR, ID = 1.870 I I REF LOG: SWS MCNL/GR/CCL OF 04/01/08 � ♦ .. � j ANGLE AT TOP PERF: 64° @ 10930' ANv 4 - 10302' 1--{2.70" BKR DEPLOYMENT SLV, ID = 1.920" I Note: Refer to Production DB for historical perf data ( :4 1 :1 SIZE SPF INTERVAL OPN/SQZ DATE /141 444 1.56" 6 10930 - 11050 0 09/11 /10 H 414 1.56" 6 11210 - 11510 0 04/02/08 1 1 .� ■ 1.56" 6 11570 - 11640 C 04/02/08 II+ ∎�� •s 1.56" 6 11760 - 11810 C 04/02/08 (� �� � S�� � � 1.56" 6 11930 - 12330 C 04/02/08 ( + 11 ��0 1.56" 6 12400 - 12490 C 04/02/08 ►�1 ! �� �' 14 ►rk44 1.56" 6 12550 - 12580 C 04/02108 14' 1 0. �� + MILLOUT WINDOW (G -11 B) 10355' - 10364' 1.56" 6 12630 - 12780 C 04/02/08 ► + 1� 4 i� � 4 4 4 e.,,, 11550' 1H 1 J1" CIBP (09 /11/10) I 13-1/2" BKR WHIPSTOCK (03/18/08) I 10355' 14 4 11 4 13 -1/2" TBG, 9.2 #, L -80 TDS, .0087 bpf, ID = 2.992" I 10355' ►1 1. �� 7" LNR, 29 #, 13CR -80 NSCC, 10850' ` .0371 bpf, ID = 6.184" PBTD ( 12790' * ∎ ■ a I2 -3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.995" h1 12829' 1 DATE REV BY COMMENTS ® DATE REV BY COMMENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 12/12/09 SV GLV CORR WELL: G -11B 11/19/93 SIDETRACK (G -11A) 12/14/09 AW /JMD DRLG DRAFT CORRECTIONS PERMIT No: 2080270 04/02/08 NORDIC 1 CTD SIDETRACK (G -11 B) 09/23/10 CJS /PJC CIBP/ PERFS (09/11/10) API No: 50- 029 - 20583 -02 -00 03/02/08 JCM/TLH PATCH PULLED (PRE CTD) SEC 12, T11 N, R13E, 2444' FNL & 2368' FEL 04/18/08 JCM/TLH GLV C/O & CORR (04/09/08) 05/05/08 CJN/PJC SET ER PKR (04/24/08) BP Exploration (Alaska) UNDER EVALUATION: Producer GiB (PTD #2080270) Sustained casing *sure on the IA Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Friday, February 25, 2011 7:50 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Ramsay, Gavin; Walker, Greg (D &C) Subject: UNDER EVALUATION: Producer G -11 B (PTD #2080270) Sustained casing pressure on the IA Attachments: G -11 B TIO Plot 02- 25- 11.doc; G -11 B.pdf All, Producer G -11 B (PTD #2080270) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to SSV/2050/250 on 2/23/2011. The well has been reclassified as Under Evaluation and may be placed on production for diagnostics when weather permits. The plan forward is as follows: 1. DHD: TIFL 2. WIE: Evaluate setting DGLVs and performing an MITIA (pending TIFL results) A TIO plot and wellbore schematic have been included for reference. «G-11B TIO Plot 02- 25- 11.doc» «G -11 B.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Ira484WELI MAR 1) 2 2011 Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/2/2011 PBU G -11B PTD 2080270 2/25/2011 TIO Pressures Plot Well: 6 -11 4,000 - • 3,000 - —�►— Tbg �— IA 2,000 - --A OA 00A 000A On 1,000 I • 12/04/10 12/18/10 01/01/11 01/15/11 01/29/11 02/12/11 TREE = 3 - 1116" 5M FMC • SAFETY: WELL ANGLE > 70° @ 9548'. ACTUATOR OR = AXE SON McEVOY G 1 1 B G-11A NOT SHOWN BELOW WHIPSTOCK*** KB. . SON � 7" CHROME LINER ACTU II KB ELEV = 70.21' BF. ELEV = 36.26' I I KOP = 1900' Max Angle = 97 @ 11196' 2196' H3 -1/2" OTIS HXO SSSV LAND NIP, ID = 2.75" I i Datum MD = 10729' Datum TV D = 8800' SS - I 2631' H9-5/8" DV PKR I 113 -3/8" CSG, 72 #, L -80, ID = 12.347" j--I 2744' 1 k71 CI 4604' - 4645' I— I3 -1/2" WFD ER PKR, ID = 1.75" (04/24/08) I • • C4 C4 Minimum ID =1.75" @ 4604' 3 -1/2" ECLIPSE PATCH GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4874 4261 43 MMG DOME RK 16 04/07/08 2 8154 6555 45 MMG SO RK 20 04/07/08 1 9160_ 7376 14 KBUG DMY BK _ 0 12/05/02 !TOP OF 7" SCAB LNR I--I 8351' TOP OF 7" LNR IH 8399' I (TOP OF CEMENT I 8549' 9 -5/8" CSG, 47 #, L -80, ID = 8.681" (--1 8549' + , 1 I9 -5/8" BRIDGE PLUG H 8800' ' TOC (03/15/08) I 9300' 1 PERFORATION SUMMARY 1 t 1�1 t 10296 ' H BKR 35 KB LT PKR, ID = 1.870" I REF LOG: SWS MCNL /GR/CCL OF 04/01/08 t -wit ANGLE AT TOP PERF: 64° @ 10930' 11 '(11 10302' H2.70" BKR DEPLOYMENT SLV, ID = 1.920" I Note: Refer to Production DB for historical perf data (.t MI SIZE SPF INTERVAL OPN/SQZ DATE 114 r � � �t� 1.56" 6 10930 - 11050 0 09/11/10 1441 �1► +t� 1.56" 6 11210 - 11510 0 04/02/08 1441 t 44 1.56" 6 11570 - 11640 C 04/02/08 1 , 4 t 44 NN t 14 1.56" 6 11760 - 11810 C 04/02/08 I .0* 0.1 1.56" 6 11930 - 12330 C 04/02/08 ' 1 . +1l 1.56" 6 12400 - 12490 C 04/02/08 ( ♦ � �11t� 1.56" 6 12550 - 12580 C 04/02/08 (•1/ +` ••tits MILLOUT WINDOW (G -11B) 10355' - 10364' 1.56" 6 12630 - 12780 C 04/02/08 1 ►t �t� +� . 1 *1 4 �4 t ' W � kV4tt`' +' 11550' - -11.71" CIBP (09/11/10) I I3 -1/2" BKR WHIPSTOCK (03 /18/08) I 10355' 11 � NI* t t 13 -1/2" TBG, 9.2 #, L -80 TDS, .0087 bpf, ID = 2.992" I 10355' 11 .t �� ` CI C4 7" LNR, 29 #, 13CR -80 NSCC, 10850' .0371 bpf, ID = 6.184" I PBTD H 12790' I � t4S*F. 4. I2 -3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.995" h I 12829' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT ORIGINAL COMPLETION 12/12/09 SV GLV CORR WELL: G-11B 11/19/93 SIDETRACK (G -11A) 12/14/09 AW /JMD DRLG DRAFT CORRECTIONS PERMIT No: "2080270 04102/08 NORDIC 1 CID SIDETRACK (G -11B) 09/23/10 CJS /PJC CIBP/ PERFS (09/11/10) API No: 50- 029 - 20583 -02 -00 03/02/08 JCM/TLH PATCH PULLED (PRE CTD) SEC 12, T11 N, R13E, 2444' FNL & 2368' FEL 04/18/08 JCM/TLH GLV C/O & CORR (04/09/08) 05/05/08 CJN/PJC SET ER PKR (04/24/08) BP Exploration (Alaska) OPERABLE: Producer G -11B (PTD #180270) Verified tubing integrity Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Sunday, January 30, 2011 5:28 AM �� Z- I l To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr Cc: Walker, Greg (D &C); Ramsay, Gavin; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer G -11 B (PTD #2080270) Verified tubing integrity All, Producer G -11 B (PTD #2080270) passed a TIFL on 1/29/11 after it was reported to have sustained casing pressure on the IA. The passing test verifies tubing integrity. The well has been reclassified as Operable and may continue on production. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Sunday, January 23, 2011 8:23 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; , OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad L-.d; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Oper. 'ins Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, . S GPB East Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); King, itney Subject: UNDER EVALUATION: Producer G -11B (PTD #2080270) :ustained IA Casing Pressure Above MOASP All, Producer G -11B (PTD #2080270) has confirmed su- ained IA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2 ; 0/2320/230 on 1/21/2011. The well has been reclassified as Under Evaluation. The well ma emain online while work is conducted to attempt to restore integrity. Plan forward: 1. DHD: TIFL 2. WIE: Pending TIFL result , develop work request to conduct MIT of the IA if required A TIO plot and wellbore schematic have been included for reference. 2/1/2011 OPERABLE: Producer G -11B (PTD #80270) Verified tubing integrity • Page 2 of 2 « File: Producer G -11 B (PTD # 2080270) TIO Plot.doc » Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2/1/2011 DATA SUBMITTAL COMPLIANCE REPORT 2/112010 Permit to Drill 2080270 Well Name/No. PRUDHOE BAY UNIT G-11 B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20583-02-00 MD 12829 TVD 9022 Completion Date 4/2/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR, GR /CCL /CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments og Leak Col 0 9400 Case 5/5/2008 LDL, WLD, UMT, CCL, Temp, 27-Apr-2008 ED C Lis 16393//N~utron 9979 12751 Case 6/6/2008 LIS Veri, CNT, GR ED C Pdf 16186 - Leak 0 9400 Case 5/5/2008 LDL, WLD, UMT, CCL, Temp, 27-Apr-2008 og Neutron 5 Col 9988 12746 Case 6/6/2008 MCNL, GR, CCL, CNL 1- Apr-2008 D Asc Directional Survey 10278 12829 Open 5/23/2008 ~ Di i l 10278 12829 O 5/23/2008 apt rect ona Survey pen L IS Verification 10250 12830 Open 6/27/2008 LIS Veri, GR, ROP D C Lis E~ 16514riGamma Ray 10250 12830 Open 6/27/2008 LIS Veri, GR, ROP og Gamma Ray 25 Col 10355 12829 Open 6/27/2008 MD GR 30-Mar-2008 clog Gamma Ray 25 Col 10355 12829 Open 6/27/2008 TVD GR 30-Mar-2008 og See Notes 2 Col 10240 12829 Open 6/27/2008 Monitor Plot Well Cores/Samples Information: • ~ Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 2/1/2010 Permit to Drill 2080270 Well Name/No. PRUDHOE BAY UNIT G-11B MD 12829 TVD 9022 ADDITIONAL INFORMATION Well Cored? Y ,~ Chips Received? ~N- Analysis Y /'I~ Received? Completion Date 4/2/2008 Operator BP EXPLORATION (ALASKI~ INC API No. 50-029-20583-02-00 Completion Status 1-OIL Current Status 1-OIL UIC N Daily History Received? Formation Tops ~/ N omments: Compliance Reviewed By: Date: • s STATE OF ALASKA ~~ ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG V~1 V G~' N1AY 0 9 2008 ~~a Csii ~ Gas Cons. Commission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1b. Well Class: At~Ct"fOfage 20AAC 25.105 2oAAC zs.11o ®Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aba ~ 12. Permit to Drill Number BP Exploration (Alaska) Inc. 4/2/2008 .Q 208-027 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3/26/2008 ~ 50-029-20583-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 3/30/2008 PBU G-11 B FEL, SEC. 12, T11 N, R13E, UM 2444 FNL, 2367 Top of Productive Horizon: 8. KB (ft above MSL): 70.21' 15. Field /Pool(s): 4295' FNL, 1725' FEL, SEC. 11, T11N, R13E, UM Ground (ft MSL): 35.61' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 4813' FNL, 3324' FEL, SEC. 11, T11N, R13E, UM 12790' 9021" 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 657856 y- 5969197 Zone- ASP4 12829' 9022' ADL 028280 TPI: x- 653259 y- 5967250 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 651672 y- 5966700 Zone- ASP4 None 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): ' Submit electronic and tinted information er 20 AAC 25.050 N/A ft MSL (Approx.) 1900 21. Logs Obtained (List all logs here and submit electronic and printed informatio er 20 AAC 25.071): MWD DIR/GR, GR/CCL/CNL !~//^/DUs,/ /0 .356 ~~O ~.S.~f5~rY1S 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD( SETTING DEPTH TVD H06E AMOUNT Wi. PER FT. GRADE TOP BOTTOM r- TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2744' Surface 2683' 17-1/2" 3589 cu ft Arcticset II 9-5/8" 47# L-80 Surface 8549' Surface 6838' 12-1/4" 1518 cu ft Class'G' 140 cu ft AS 7" 29# 13Cr80 8351' 6696' 8532' 8-1/2" 366 cu ft Class'G' 2-3/8" 4.7# L-80 10296' 12829' 8478' 9022' 3" 62 cu ft Class'G' 23. Open to production or inject ion? ®Yes ^ No 24. TuewG RECORD If Yes, list each i nterval open S D S SET MD PA KER (MD+TVD of Top & Bottom; Pe rforation Size and Number): IZE EPTH ET MD . C 1 56" Gun Diameter 6 spf 3-1/2", 9.2#, L-80 10900' 10850' . , MD TVD MD TVD 11210' - 11510' 9031' - 9022' - CEMENT SQUEEZE, ETC. FRACTURE ACID 25 11570' - 11640' 9023' - 9022" , , . 11760' - 11810' 9023' - 9019'- DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 11930' - 12330' 9010' - 9011' 12400' 12490' 9009' 9007' 2500' Freeze Protected w/ McOH - - 12550' - 12580' 9008' - 9009' 12630' - 12780' 9011' - 9020' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Yet N/A Date Of Test: HOUrS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: TEST PERIOD Flow Tubing CaSing PreSS: CALCULATED OIL-BBL : GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): PreSS. 24-HOUR RATE 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~;OP,~t~L~T iC3fi1 None 0 ~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~~~ !~f ~ ~ ~oo~ ~~ ~,~` nRl~~nia ~ J L 28. GE(SLOG~C MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit /Zone 46 10348' 8526' None Zone 3 10539 8707' Zone 2C 10606' 8769' Zone 1 B / 23SB 10647' 8805' 22TS 10712' 8858' Zone 2A / 21TS 10778' 8904' Zone 1 B 10900' 8975' Zone 1A /TDF 11012' 9017' Formation at Total Depth (Name): Zone 1A /TDF 11012' 9017' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~s ~ , 4g~o g Signed Terrie Hubble Title Drilling Technologist Date PBU G-11 B 208-027 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Abby Warren, 564-5480 INSTRUCTIONS GeNeRa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 0212007 Submit Original Only BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: I I Task Code NPT Phase Description of Operations Date I From - To Hours 3/22/2008 00:00 - 01:40 1.67 MOB N WAIT PRE Rig arrives G-pad. Set down at pad entrance to swap reels. Spot empty trailer to receive a-free coil. 01:40 - 02:00 0.33 MOB N WAIT PRE SAFETY MEETING. Discuss hazards and mitigations for changing out reels. 02:00 - 03:30 1.50 MOB N WAIT PRE Lower a-free coil onto empty trailer. Lift a-line reel into reel house. Close reel bay door and insert drive pins into reel drum. 03:30 - 06:00 2.50 MOB N WAIT PRE Prepare to swap out CT injectors. Hang off BOP stack so CT injector can be picked up. Drop stripper off of injector. Remove gooseneck and pipe straightener. Unhook hydraulic hoses. 06:00 - 08:30 2.50 MOB N WAIT PRE Remove hose bundle and miscellaneous equipment from injector. 08:30 - 09:30 1.00 MOB N WAIT PRE PJSM .Pull injector onto catwalk 09:30 - 13:30 4.00 MOB N WAIT PRE Remove injector and bring replacement injector in and spot on cat walk. 13:30 - 16:00 2.50 MOB N WAIT PRE Hard line and junction box. 16:00 - 23:00 7.00 MOB N WAIT PRE Continue to grade around well G-11 to prepare to move rig over. Try to function test injector, weight cell is tripped can't move chains. Repair load cell, wrong one is installed. Get correct load cell from SLB base in Deadhorse. 23:00 - 23:15 0.25 MOB P PRE SAFETY MEETING. Discuss hazards and mitigations for pulling CT across pipe shed. 23:15 - 00:00 0.75 MOB P PRE Continue grading around well G-11. MU stuffing box to injector. MU internal grapple to CT, prepare to pull it across. Pull test grapple against reel brake. 3/23/2008 00:00 - 01:30 1.50 MOB P PRE Pull CT across. Finish hooking up load cell on injector. 01:30 - 01:45 0.25 MOB P PRE SAFETY MEETING. Discuss procedure, crew placement and mitigations for cutting 2,000 ft of CT. 01:45 - 04:30 2.75 MOB P PRE Attach hydraulic cutter to injector. Cut off 2,000 ft of CT. BOP test witness waived by AOGCC Lou Grimaldi. 04:30 - 05:00 0.50 MOB P PRE SAFETY MEETING. Discuss procedure, hazards and mitigations for moving over well. 05:00 - 06:00 1.00 MOB P PRE Move over well and set rig down. (accept riq at 06:OOhrsl 06:00 - 09:00 3.00 MOB P PRE Bank snow around the cellar wall, move heater trunk inside to warm up the tree. NU BOP. 09:00 - 14:00 5.00 BOPSU P PRE Test BOP 250 psi low and 3500 psi hi. No failures. 14:00 - 17:00 3.00 STWHIP P WEXIT Fill CT. Pump 2 bbl MEOH, 3bbl H2O. PT hardline in reel to 4100 psi. Fill CT with 2# bio double slick. 17:00 - 18:30 1.50 STWHIP P WEXIT Pump slack. Trim 15 ft to find cable. Install cable head and test, good. Install pressure test plate and PT to 4,000 psi, good. 18:30 - 18:50 0.33 STWHIP P WEXIT SAFETY MEETING. Discuss procedures, hazards and mitigations for picking up BHA. 18:50 - 20:20 1.50 STWHIP P WEXIT MU BHA #1. 2.74" Diamonds eed mill +string mill, 2.13" Printed: 5/1 Z/20o8 10:55:()4 AM BP EXPLORATION Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Event Name: REENTER+COMPLETE Start: 3/19/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ~ Hours Task ~ Code ~ NPT ~ Phase 3/23/2008 18:50 - 20:20 1.50 STW H I P P 20:20 - 23:00 2.671 STWHIPI P 23:00 - 23:15 0.251 STWHIPI P 23:15 - 23:30 I 0.251 STWHIPI P 23:30 - 0.001 STWHIPI P 3/24/2008 00:00 - 20:30 20.50 STWHIPI P 20:30 - 20:50 0.331 STWHIPI P Page 2 of 10 Spud Date: 6/2/1981 End: 4/2/2008 Description of Operations WEXIT Xtreme motor, 2 x weight bar, DPS, EDC, Power & Comms, LOC, UOC, CTC. BHA Length = 47.92 ft. WEXIT RIH BHA #1. Pump 0.2 bpm through circ sub while RIH. Nothing seen going through SSSV landing nipple or area where tubing patch was. 22:40 -Stop at 10,300 ft and close EDC. No response from EDC. Pick up slowly with no pump, up weight is 31 Klbs. WEXIT Continue POOH slowly while troubleshooting EDC. Freeze protect line to flowback tank. EDC closes after recycling power to it. WEXIT Bring pump rate up to 1.0 bpm. RIH slowly to tag whipstock. Tag at 10,336 ft. Correct +19 ft to a-line measured setting depth of WS. Bring pump to 1.5 bpm / 2,850 psi off bottom. WEXIT RIH slowly with pumps on, tag at 10,353 ft. Correct another 2 ft. Pick up is 35 Klbs. Go back to 10,354.6 ft and start time drilling C~ 0.1 ft / 5 min. WEXIT Contin 00:00 - 10,355.2 ft 3,100 psi / 1.46 bpm 00:30 - 10,355.8 ft 3,160 psi / 1.46 bpm, WOB = 1.01 Klbs. Stall at 10,356 ft. 01:00 - 10,355.9 ft 3,100 psi / 1.46 bpm, WOB = 0.50 K1bs. 01:30 - 10,356.3 ft 3,220 psi / 1.46 bpm, WOB = 1.15 Klbs. 02:00 - 10,356.5 ft 3,170 psi / 1.45 bpm, WOB = 0.92 Klbs. Metal on ditch magnets. 02:30 - 10,356.8 ft 3,240 psi / 1.46 bpm, WOB = 1.15 Klbs. 03:00 - 10,357.0 ft 3,220 psi / 1.45 bpm, WOB = 1.37 Klbs. 03:30 - 10,357.2 ft 3,270 psi / 1.46 bpm, WOB = 1.45 Klbs. 04:00 - 10,357.4 ft 3,340 psi / 1.46 bpm, WOB = 1.90 Klbs. 04:30 - 10,357.5 ft 3,380 psi / 1.45 bpm, WOB = 1.68 Klbs. 05:00 - 10,357.7 ft 3,310 psi / 1.45 bpm, WOB = 1.68 Klbs. 05:30 - 10,357.8 ft 3,300 psi / 1.45 bpm, WOB = 1.65 Klbs. 06:00 - 10,358.0 ft 3,220 psi / 1.45 bpm, WOB = 1.50 Klbs. 06:30 - 10,358.3 ft 3,281 psi / 1.46 bpm, WOB = 1.86 Kbls 07:00 - 10,358.5 ft 3,259 psi / 1.45 bpm, WOB = 1.93 Kbls 07:30 - 10,358.6 ft 3,289 psi / 1.45 bpm, WOB = 1.97 Kbls 09:00 - 10,359.3 ft 3,322 psi / 1.45 bpm, WOB = 2.70 Kbls 10:00 - 10,359.6 ft 3,322 psi / 1.45 bpm, WOB = 2.90 Kbls 11:00 - 10,360.2 ft 3,420 psi / 1.47 bpm, WOB = 3.60 Kbls 12:00 - 10,360.6 ft 3,428 psi / 1.47 bpm, WOB = 3.81 Kbls 13:00 - 10,361.0 ft 3,420 psi / 1.47 bpm, WOB = 3.80 Kbls 14:00 - 10,361.2 ft 3,460 psi / 1.47 bpm, WOB = 4.10 Kbls 15:00 - 10,361.4 ft 3,453 psi / 1.47 bpm, WOB = 4.17 Kbls 16:00 - 10,361.5 ft 3,424 psi / 1.47 bpm, WOB = 4.18 Kbls 18:00 - 10,362.11ft 3,453 psi / 1.47 bpm, WOB = 5.30 Kbls 19:00 - 10,362.36 ft 3,440 psi / 1.46 bpm, WOB = 5.27 Klbs. 20:00 - 10,362.65 ft 3,450 psi / 1.46 bpm, WOB = 5.66 Klbs. WEXIT Pick up to establish free spin and up weight. Up weight is 26 Klbs. Off bottom motor pressure is 3,130 psi. rnniea: oiiu~wo i~aa:vv„m BP EXPLORATION Operations Summary Report Page 3 of 10 Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: Date From- To I Hours Task ; Code ~ NPT i Phase Description of Operations 3/24/2008 ~ 20:30 - 20:50 20:50 - 21:40 21:40 - 00:00 3/25/2008 100:00 - 01:40 01:40 - 03:10 03:10 - 05:30 05:30 - 12:00 12:00 - 13:00 0.33 STWHIP P 0.83 STWHIP P 2.33 STWHIP P 1.67 STWHIP P 1.50 STWHIP P 2.331 STWHIP P 6.501 STWHIPIP 1.001 STWHIPI P 13:00 - 16:00 3.001 STWHIP P WEXIT WOB falls to 0.04 Klbs off bottom. Run back in slowly to tag and continue window milling. Some motor work seen at 10,360.1 ft. WEXIT Continue milling window. 21:00 - 10,361.82 ft 3,270 psi / 1.45 bpm, WOB = 3.09 Klbs. Pick up and run back to 10,359.7 ft, RIH slowly to tag. Tag at 10,362.15 ft with 3.77 Klbs WOB and 200 psi motor work. WEXIT 22:00 - 10,362.22 ft 3,330 psi / 1.46 bpm, WOB = 3.87 Klbs. Progress is extremely slow. Set down to 10,362.3 ft with 4.07 Klbs WOB and 3,350 psi / 1.46 bpm. Based on 7.2 ft of progress the centerpoint of the mill is working on the midpoint of the 7" csg. 23:00 - 10,362.67 ft 3,370 psi / 1.46 bpm, WOB = 4.71 Klbs. 00:00 - 10,363.20 ft 3,410 psi / 1.45 bpm, WOB = 5.72 Klbs. WEXIT Continue millin from 10 363.20 01:00 - 10,363.45 ft 3,410 psi / 1.45 bpm, WOB = 6.05 Klbs. 01:10 - 100 psi increase in motor work, WOB starts dropping slowly from 6.55 to 6.30 Klbs. WEXIT Pick up slowly from 10,363.8 ft. Up weight is 27 Klbs clean pickup. Circ pressure drops back to 3,080 psi. Run back down to TD. Still getting metal returns back. Sample at 10,363.8 ft shows no formation, no cement. Continue pushing down to 10,363.4 ft, getting 200 - 300 psi motor work with WOB = 5.51 Klbs. Stall at 10,363.7 ft. Up weight is 30 Klbs without pumps. WEXIT Pull up to 10,350 ft and re-establish free spin pressure of 3,130 psi / 1.47 bpm. Run back in slowly to bottom. Take motor work at 10,361.74 ft, slow down and allow it to drill off. Stop at 10,363.1 ft, circ pressure slowly climbing past 3,700 psi. Stall at 10,363.1 ft, pick up is 27 Klbs. Work back down slowly. Stall at 10,363.14 ft. WEXIT Mill from 10,362.90 ft. Park here and allow it to drill off, good motor work. Stall at 10,363.05 ft. Work back down slowly and get good motor work at 10,362.81 ft. Stall.. PU. FS = 3325 PSI, PU wt 30 k. 3425psi ~ 1.55 bpm. PU. ~ 10362.25 Zero wob previously 3K. WEXIT Ream 10362 with 500-970 WOB. 111363 1100 WOB 3400 psi drill off. WEXIT Mill at 10363.1 1.4 K WOB drill off. Stall PU 29K. Mill at 1.56 bpm 3350 psi FS. At 10362 .4K WOB. Stall at 10363.05 4150 psi. Pu 29K. At 10362.9 no WOB or differential.At 10363.02 3360 psi .8K WOB, Drill off. Mill to 10363.5.Exit window. Printetl: 5/12/2008 10:55:V4 AM ~ ~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: Date From - To 'Hours Task Code ~ NPT Phase Description of Operations 3/25/2008 13:00 - 16:00 3.00 STWHIP P WEXIT Continuous drill off. Stall at 10364.5. PU 28.5K, Pu above window. 16:00 - 18:30 2.50 STWHIP P WEXIT Drill 10' rat hole. Ream window. 18:30 - 19:00 0.50 STWHIP P WEXIT Dry run through window good 19:00 - 19:40 0.67 STWHIP P WEXIT Empty and clean pits, start flopro down coil 19:40 - 22:00 2.33 STWHIP P WEXIT POOH 22:00 - 22:30 0.50 STWHIP P WEXIT Lav down window BHA. Wear on BHA, small grooves around circumfrence of Baker tool string 42 inches from top of EDC. Mill 2.73" go, 2.72" no-go. More than average wear on face of mill but still has most of it's cutting structure in place String reamer 2.74" go, 2.73" no-go 22:30 - 23:00 0.50 STWHIP P PROD1 MU build BHA 23:00 - 00:00 1.00 STWHIP P PROD1 RIH pumping 0.2 BPM 3/26/2008 00:00 - 01:15 1.25 STWHIP P PROD1 Continue RIH with build BHA 01:15 - 01:45 0.50 STWHIP P PROD1 Tie in, +6' correction 01:45 - 02:00 0.25 STWHIP P PROD1 Continue to RIH 02:00 - 03:00 1.00 STWHIP P PROD1 Tag up at 10374' and start drilling, 1.56 BPM at 2900 psi. -80 FPH. 03:00 - 03:40 0.67 STWHIP P PROD1 Did not see PIP taa in whipstock (E-line WSR from 3/17 and 3/18 says two pip tags were installed in whipstock) while drilling ahead. Loa up across window/whipstock to varifv rianth stun n 03:40 - 08:20 4.67 STWHIP P PROD1 Directionally drill 1.67 / 1.66 bpm @ 3344 psi, ROP 40, WOB 1.1 K, Inc 15, Drill to 10575. 08:20 - 08:45 0.42 STWHIP P PROD1 Wiper to window. 08:45 - 13:40 4.92 STWHIP P PROD1 Directionally drill 1.66/1.66 bpm X4050 psi. Drill to 10591 lost total returns. Continue t ril 1.67/1.44 bpm ~ 3950 psi, ~ 10,625', ROP 38, WOB 1.3. Drill to 10715 Trip for bit. 13:40 - 14:00 0.33 STWHIP P PROD1 POH to 10270. 14:00 - 14:45 0.75 STWHIP P PROD1 Mad pass from 10270 to 10398 14:45 - 16:20 1.58 STWHIP P PROD1 POH To surface. 16:20 - 17:10 0.83 STWHIP P PROD1 BHA bit swap only 7-3 rung out. 17:10 - 19:15 2.08 STWHIP P PROD1 RIH. 19:15 - 19:45 0.50 STWHIP P PROD1 Tie in from 10363' down at 100 FPH. +5' correction 19:45 - 00:00 4.25 STWHIP P PROD1 Directionally drill 1.54 / 1.52 bpm ~ 3120 psi, ROP 20-30, WOB 1.9K, Inc 32, Drill to 10845 at midnight. 3/27/2008 00:00 - 00:15 0.25 STWHIP P PROD1 Directionally drill 1.57 / 1.5 bpm ~ 3550 psi, ROP 20-30, WOB 1.9K, Inc 54 00:15 - 01:00 0.75 STWHIP P PROD1 Wiper trip to window 01:00 - 04:45 3.75 STWHIP P PROD1 Directionally drill 1.6 / 1.53 bpm C~ 3600 psi, ROP 30, WOB 2K, Inc 55 04:45 - 05:30 0.75 STWHIP P PROD1 Wiper trip to window 05:30 - 08:00 2.50 STWHIP P PROD1 Continue drilling, 1.55/1.5 bpm ~ 3750 psi, ROP 80, 2-3 K WOB, Inc 73. 11048, losing .4 BPM .Continue drilling 1.51/1.4 bpm 3900 psi ,ROP100' ,WOB 2.3, Inc 93. Drill to 11225' 08:00 - 10:00 2.00 STWHIP P PROD1 P Up Wt 28K.Bit grade 6-3. 10:00 - 10:45 0.75 STWHIP P PROD1 BHA swa~LD 1.5 motor and PU 1.1 motor. 10:45 - 12:50 2.08 STWHIP P PROD1 RIH 10360 12:50 - 13:00 0.17 STWHIP P PROD1 Log tie-in +5' correction. 13:00 - 13:30 0.50 STWHIP P PROD1 RIH tag at 11228'. Printed: 5/12/2008 10:55:04 AM ~ ~ BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task ', Code' NPT Phase ~ Description of Operations 3/27/2008 13:30 - 15:30 2.00 STWHIP P PROD1 Directionally drill 1.46 / 1.34 bpm ~ 4000 psi., 3700 psi FS. 90 ROP, WOB 1.8K, INC 89, CT pressure 5840, Annular pressure 5190 psi.ECD 11.16. Drill to 11400 15:30 - 16:30 1.00 STWHIP P PROD1 Wiper to window. 16:30 - 19:00 2.50 STWHIP P PROD1 Directionally drill 1.47/1.42 bpm ~ 3724 psi. SWAP MUD once back on bottom drilling. 19:00 - 20:00 1.00 STWHIP P PROD1 Wiper trip to window 20:00 - 23:45 3.75 STWHIP P PROD1 Continue drilling ahead, 1.5/1.5 bpm ~ 3500 psi. 11590', seem to have aplugged/balled bit, stacking weight with no stalls. Drilled to 11602' and unable to push any further. Trip to check bit/motor 23:45 - 00:00 0.25 STWHIP N DFAL PROD1 POH for bit/motor. Rubber coming across shaker indicating 3/28/2008 00:00 - 02:00 2.00 STWHIP N DFAL PROD1 02:00 - 03:45 1.75 STWHIP N DFAL PROD1 03:45 - 05:30 1.75 STWHIP N DFAL PROD1 05:30 - 06:30 1.00 STWHIP N PROD1 06:30 - 07:00 0.50 STWHIP N 07:00 - 09:30 2.50 STWHIP P 09:30 - 10:55 1.42 STWHIP P 10:55 - 13:30 2.58 STWHIP P 13:30 - 15:00 1.50 STWHIP P 15:00 - 19:45 4.75 STWHIP P 19:45 - 21:00 1.25 STWHIP P 21:00 - 21:05 0.08 STWHIP P 21:05 - 23:00 1.92 STWHIP P 23:00 - 00:00 1.00 STWHIP P 3/29/2008 00:00 - 00:25 0.42 STWHIP P 00:25 - 01:00 0.58 STWHIP P 01:00 - 01:55 0.92 STWHIP P 01:55 - 02:05 02:05 - 03:00 0.17 STWHIP P 0.92 STWHIP P 03:00 - 04:30 04:30 - 06:00 1.50 STWHIP P 1.50 STWHIP P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Continue POH for motor failure Lay down BHA. Motor locked up, can not turn with wrenches. Bit is still in good shape, had one side jet and one pilot jet plugged. 1-1- PM-A-X-I-WT-PR. Changed out DPS, serviced LOC, tested tools. PU new motor, 1.1 AKO and rerun bit.., PU BHA, MU to coil and test at surface RIH 10330. Tie in. +33' (While OOH it was noticed that the wheel on injector had shifted with respect to the coil tubing.) RIH tae at 1160 ' Directionally drill 1.62/1.61 bpm ~ 3750 psi. FS = 3500psi, 80 ROP.1.12,WOB, ECD 10.17, Drill to 11750. W iper to window. Directionally drill 1.59 /1.61 bpm C~ 3820 psi. FS = 3500psi, 85 ROP.2.08,W0B, ECD 10.48, Drill to 11833. Unable to drill stacking. Wiper Directionally drill 1.60 /1.56 bpm ~ 3820 psi. FS = 3500psi,30-50 ROP.2.98,W08, ECD 10.63. Drill to 11906'. Slow drilling through shales. Directionally drill 1.36 /1.29 bpm ~ 3610 psi. FS = 3300psi, 39-60 ROP, 2.86 WOB, ECD 10.55. Drill to 11957'. Frequent stalling. Short wiper to 11750'. Directionally drill 1.42 /1.42 bpm C~ 3940 psi. FS = 3500psi, 1.73-1.26 WOB, ECD 10.89. Drill to 12050'. Frequent stalling. Lube pills helped increase ROP temporarily. Wiper trip to window. Tie in +11 ft. RIH Directionally drill 1.30/1.26 bpm ~ 3620-3900 psi. FS = 3430psi, 100-70 ROP, 0.69-1.89 WOB, 10.8-11.04 ECD, Drill to 12116'. Pump tube pill. BHA length wiper trip. Directionally drill 1.30/1.27 bpm ~ 3940-3980 psi. FS = 3500 psi, 100-105 ROP, 2.07-2.28 WOB, 11.04 ECD, Drill to 12200'. Wiper trip to window. Directionally drill 1.29/1.24 bpm ~ 3875 psi. FS = 3400 psi, Printed: 5/12/2008 10:55:04 AM • • BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase 3/29/2008 04:30 - 06:00 1.50 STWHIP P PROD1 06:00 - 07:05 1.08 STWHIP P PROD1 07:05 - 07:50 I 0.751 STWHIPI N I STUC I PROD1 07:50 - 08:30 0.67 STWHIP P PROD1 08:30 - 09:20 0.83 STWHIP P PROD1 09:20 - 11:15 1.92 STWHIP P PROD1 11:15 - 13:00 1.75 STWHIP P PROD1 13:00 - 14:00 1.00 STWHIP P PROD1 14:00 - 14:10 0.17 STWHIP P PROD1 14:10 - 15:00 0.83 STWHIP P PROD1 15:00 - 18:00 3.00 STWHIP P PROD1 18:00 - 20:10 2.17 STWHIP P PROD1 20:10 - 21:00 0.83 STWHIP P PROD1 21:00-00:00 I 3.OOISTWHIPIN ISTUC IPRODI 13/30/2008 100:00 - 01:20 1.331 STWHIP N ~ STUC ~ PROD1 Description of Operations 115 ROP, 2.01 WOB, 11.04 ECD, Drill to 12255'. Start mud swap. Drill to 12271. Inc dropping from 12240 without TFchange. PU differentially stuck at 12237.Continue to pump new mud to surface. ECD = 10.58 ~ 1.57 bpm. Slack off wt. -1 K PU 36K. Up wt 29K. ECD 10.28 with new mud around. No losses. Shut down and let pipe relax. Holding 38K. PU 61 K. SO to neutral. Oriet 90R. Stack out. PU 48k. Circulate to warm coil. SD pump Hold 40K. Orient. PU 60k. free. Short wiper to 11700. RIH 1.5 bpm C~3 3200 psi. 11858 MW. Directionally drill 1.53 / 1.50 bpm ~ 3675 psi. FS = 3250 psi, 129 ROP, .4 WOB, 10.31 ECD, Drill to 12,354'. Wiper to window. 10370'. RIH 1.5 bpm ~ 3130 psi. Directionally drill 1.53 / 1.48 bpm ~ 3911 psi. FS = 3250 psi, 100 ROP, 3.54 WOB, 10.38 ECD, Drill to 12,485 POH to 10348. Log tie-in. Correction +11.5' Wiper RIH. Clean trip. Directionally drill 1.51 / 1.43 bpm ~ 3980 psi. FS = 3300 psi, 130 ROP, 2.42 WOB, 10.51 ECD, Drill to 12653. W iper trip to window 10370'. No overpulls. On bottom. Drill to 12717'. Stacking wt. PU and differentially stuck at 12687'. Work pipe at full circulation. Shut down pumps to relax pipe at neutral wt. PU, still stuck. Circulate 8 bbls. SD pumps hold 10k down wt. PU 55k, pump 1.6 bpm. Spot tube pill and alternate relaxing and working the pipe while waiting for crude to arrive. Differentially stuck. Attempted relaxing the pipe and overpulls. Waiting on crude. 01:20 - 01:30 0.17 STWHIP N STUC PROD1 01:30 - 02:30 1.00 STWHIP N STUC PROD1 02:30 - 04:45 ~ 2.251 STWHIP P ~ ~ PROD1 04:45 - 05:45 1.00 STWHIP P PROD1 05:45 - 06:05 0.33 STWHIP P PROD1 06:05 - 07:00 0.92 STWHIP P PROD1 07:00 - 09:20 2.33 STWHIP P PROD1 09:20 - 10:00 0.67 STWHIP P PROD1 10:00 - 10:30 0.50 STWHIP P PROD1 10:30 - 13:00 2.50 STWHIP P PROD1 13:00 - 13:15 0.25 STWHIP P PROD1 13:15 - 14:45 1.50 STWHIP P PROD1 PJSM covering hazards, procedures, and job assignments for pumping crude pill. Pump 20 bbl crude pill. SD pumps, relax coil at neutral weight for 20 min. PU 65k, slack off wt, then yo-yo wt up to 55k. Unstuck. Drill to 12753' followed by BHA wiper trip. Drill to 12819' at 1.50 / 1.30 bpm C~ 3840 psi. FS = 3300 psi, 166 ROP, 1.47 WOB, 10.48 ECD. Wiper to 12600'. Drill to ahead. Frequent stacking and overpulls. TD called at 12828'. Wiper trip to window. Tie in at 10345'. +7' RIH and tag at 12829'. POH lay in liner running pill. Seen slight over pulls 4-5K 11936-11890 LD drilling BHA. Bit grade 1:1. Function Test BOP's. Swap CT to H2O, inhibit Ct and pump MEOH. Blow reel down with N2 .Unstab from well. Cut off CTC. Install grabble in CT. PJSM for pulling back CT. Pull back CT to reel and secure. Printetl: 5/72/2008 10:55:04 AM ~ ~ BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 3/30/2008 14:45 - 15:00 0.25 STWHIP P PROD1 PJSM for swap reel swap 15:00 - 17:00 2.00 STWHIP P PROD1 E-coil out, a-free coil in, MU inner reel iron and fill with fluid. 17:00 - 20:30 3.50 STWHIP P PROD1 Weld on coil connector, fill hole, load tools for liner into rig, Pull test coil connector to 40k, fill coil and P/T, Pump dart-volume is 41.7 bbl. 20:30 - 20:50 0.33 CASE P RUNPRD PJSM covering hazards, mitigations, & job assignments to MU liner. 20:50 - 00:00 3.17 CASE P RUNPRD Run liner as per proc7ram: 2-3/8" Guide Shoe, 2-3/8" STL float collar, 1 jt 2-3/8" STL 4.7 ppf L-80 solid liner, 2-3/8" STL float collar, 2-3/8" STL 4.7 ppg L-80 solid liner pup, 2-3/8" STL Baker Latch Collar, 78 jtS 2-3/8" STL 4.7 f L-80 solid liner w/ cementralizers, 2 solid pups, BOT Deployment Sleeve. Total Liner BHA Len the 2526.66' Torque each connection between 800-1100 psi, then drift each connection. 3/31/2008 00:00 - 01:10 1.17 CASE P RUNPRD Continue MU liner. Total Liner BHA Length: 2526.66' Torque each connection between 800-1100 psi, then drifted each connection. 01:10 - 04:00 2.83 CASE P RUNPRD RIH at 80-90 ft/min in cased hole RIH at 50 fUmin through window RIH 50-6H fUmin in OH. Stacking at 11777, 11810, 12381, & 12783'. Liner to bottom at 12784' MD (tagged four times to confirm, SLB counter is most likely off) 04:00 - 04:45 0.75 CASE P RUNPRD Drop 5/8" AL ball Pump at 1.34 bpm in / 0.70 bpm out De to ment sleeve release confirmed b ressure s ikes and PU wts. 04:45 - 07:00 2.25 CASE P RUNPRD Displace to 2% double slick KCL Pump 0.97 bpm in / 0.37 out ~! 1120 psi. KCL turned the corner, 1.10 in / 0.81 out 07:00 - 08:45 1.75 CASE P RUNPRD Mix comtaninent pill. RU cementers 09:00 - 09:15 0.25 CEMT P RUNPRD PJSM 09:15 - 10:15 1.00 CEMT P RUNPRD Batch up cement. Flood lines with KCL. PT to 6000 psi. Circulate well .62/.45 bpm 428 psi. 10:15 - 11:30 1.25 CEMT P RUNPRD Pum 11 bbl 15.8 cement. BBIs Pressure in/out PT 3 1344 1.05/.83 290 6 1545 1.04/.83 292 8 1700 1.02/.80 293 10 1813 1.01/.81 295 11 1850 1.01/.81 295 Insert dart and launch wih 500 psi.. Displace dart with 30 bbl bio. 15 2210 1.26/.97 292 20 1530 1.24/1.0 292 25 1890 1.59/1.2 292 30 1530 1.42/1.2 292 35 1740 1.42/1.17 292 40 1776 1.43/1.2 291 45 1765 1.42/1.16 285 50 1886 1.41/1.14 284 Printed: 5/12/2008 10:55:04 AM ~ ~ BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig -Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/31/2008 10:15 - 11:30 1.25 CEMT P RUNPRD 51.5 cement at shoe Zero out MM. 53.0 PU liner wiper plug and shear at_4000 psi( Calculate_52.5 bbl to LWP 55 2470 1.27/1.02 283 3.4 BBI out total 57 2850 1.14/.97 4.3 58 2850 1.13/1.03 5.5 59 2850 1.16/1.0 6.7 60 2850 1.16/1.1 7.3 61 2850 1.18/.97 8.2 62 2850 1.18/1.01 8.9 62.7 bumped right on the calculated vol 10.0 Lost 1.2 bbl to f rmation Check floats held. 11:30 - 13:45 2.25 CEMT P RUNPRD POH filling displacement 13:45 - 14:25 0.67 CEMT P RUNPRD LD BHA. 14:25 - 16:30 2.08 CEMT P RUNPRD PU cleanout BHA and 42 stands of 1"CSH. 16:30 - 19:30 3.00 CEMT P RUNPRD RIH 10,000' PU Wt 24.5K DN WT 17K. Continue to RIH ~ .8 bpm Tag bottom at 12786'y pull up 100' and paint EOP at 10064'. 19:30 - 21:35 2.08 CEMT P RUNPRD POH 21:35 - 21:45 0.17 CEMT P RUNPRD PJSM covering hazards, mitigation, job assignments, and procedure for LD BHA & standing back hydrill. 21:45 - 00:00 2.25 CEMT P RUNPRD Standback CS hydril and LD BHA. 4/1/2008 00:00 - 00:45 0.75 CEMT P RUNPRD Stab injector, Jet stack, standback injector 00:45 - 01:00 0.25 EVAL P LOWERI PJSM covering radiation hazards with MCL and procedure for MU BHA. 01:00 - 03:20 2.33 EVAL P LOWERI PU MCNL Logging BHA 03:20 - 05:15 1.92 EVAL P LOWERI RIH to 10000' 05:15 - 06:45 1.50 EVAL P LOWERI Log down at 30 fpm 06:45 - 07:30 0.75 EVAL P LOWERI Log up at 60 fpm to 10,000'. Laid in new FloPro pert pill while Logging up. 07:30 - 09:10 1.67 EVAL P LOWERI POH to surface. 09:10 - 10:30 1.33 EVAL P LOWERI Stand back CSH. 10:30 - 10:45 0.25 EVAL P LOWERI PJMS for LD of source tool/ memory log. 10:45 - 11:00 0.25 EVAL P LOWERI LD BHA. Send MCNUGR log to Anc GEO. 11:00 - 12:00 1.00 EVAL P LOWERI Attem t to Press test liner la to 2000 si. Bleed off to 1800 in 3 min. Failed Test. 12:00 - 15:00 3.00 EVAL N WAIT LOWERI Wait on orders from Anc. Geo. Told to pert liner as per original program. 15:00 - 15:15 0.25 PERFO P LOWERI Safety Meeting. Review procedure, hazards and mitigation for running SWS perforating guns. 15:15 - 18:30 3.25 PERFO P LOWERI M/U SWS 1.56" pert guns as per program. Run a total of 74 guns with blanks. M/U 18 stds of 1"CSH. M/U Hyd Disc, locking swivel, dual BPV and CTC. BHA OAL = 2,700.99'. Perforating Intervals--11210-11510, 1 1 570-1 1 640, 11760-11810,11930-12330,12400-12490,12550-12580, and 12630-12780. 18:30 - 19:40 1.17 PERFO P LOW ER1 Circ at surface with 0.2 bpm, until good returns. RIH with erforatin BHA #8 to 5518'. Printed: 5/12/2008 10:55:04 AM BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code I, NPT ! Phase I! Description of Operations 4/1/2008 18:30 - 19:40 1.17 PERFO P LOWERI Oring is leaking on the lower connection of the lubricator between the injector and the annular preventor. 19:40 - 20:30 0.83 PERFO N SFAL LOWERI POH to surface. 20:30 - 20:35 0.08 PERFO N SFAL LOWERI PJSM covering hazards, mitigations, communication, and procedure for rolling the spare oring on the lubricator down to replace the leaking oring. 20:35 - 21:05 0.50 PERFO N SFAL LOW ER1 Roll spare oring on lubricator into place. Pump at 0.3 bpm, no leak detected. 21:05 - 21:35 0.50 PERFO N SFAL LOWERI RIH to 5518' monitoring connection for leaks 21:35 - 23:05 1.50 PERFO P LOWERI RIH with perforating BHA #8 Pump 5 bbl Flo-Pro pill starting at 11800'. 23:05 - 00:00 0.92 PERFO P LOWERI Tao bottom PU until in tension. then correct depth to 12790'. PU to 12777', launch ball, rezero counter, pump 5 bbl Flo-Pro pill. RIH to 12788', PU to 12780.7', Pump ~ 1.3 bpm Decrease to 0.5 bpm, RIH then PU to 12785' Ball on seat at 34.9 bbl. PU slowly while pressure up. Fire auns at 12780 8' confirmed by pressure decrease aid SLB TCP sensor. 4/2/2008 00:00 - 00:50 0.83 PERFO P LOWERi POH 30-50fpm to 10,000' 00:50 - 01:05 0.25 PERFO P LOWERI Flow check 01:05 - 02:20 1.25 PERFO P LOWERI POH 100 fpm to surface 02:20 - 02:30 0.17 PERFO P LOWERI Flow check 02:30 - 02:35 0.08 PERFO P LOWERI PJSM covering hazards, mitigations, and procedures to standback CSH. 02:35 - 04:05 1.50 PERFO P LOWERI standback injector and CSH 04:05 - 04:15 0.17 PERFO P LOWERI PJSM covering hazards, mitigations, and procedures for L/D pert guns. 04:15 - 08:45 4.50 PERFO P LOWERI UD 74 pert guns and blanks. Load out fired guns from pipe shed... All shots fired. 08:45 - 09:00 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for running BTT Liner top packer. 09:00 - 09:45 0.75 CASE P RUNPRD M/U BTT 2.74" OD Liner top Packer with seal assembly and running tools; BHA OAL = 29.25'. 09:45 - 11:40 1.92 CASE P RUNPRD RIH with BTT LT Packer BHA #9. Circ at 0.2 bpm, 150 psi. RIH to 10,250'. Up Wt at 10,250' = 27k. 11:40 - 13:10 1.50 CASE P RUNPRD RIH with BTT LT Packer. Seals went in at 12,289'. Stacked 10K at 10,293.3'. Press backside of coil to 500 psi, lost to 150 psi in 2 min. Pick up wt at 10,286.4'. Pick up to 10260'. Insert ball and pump on seat at 33.1 bbls. RIH and stack 10K at 10,293.3'. Pick up to 2' off bottom with packer at 10,284.4'. Set Packer slips with 2750 psi BlPari nff nrass_RIH. stark 10K at 10,290.9'. Sli s are holdin .Packer element is ener ized. 13:10 - 14:15 1.08 CASE P RUNPRD Pressure test Liner to Packer with 2000 si for 30 min. IAP = 320 si before PT. Full communication between tubing and IA. IAP = 2350 psi. Press test with 2030 psi at 1320 hrs. Chart test for 30 min. Nrinted: ~i~i~uus IU:~S:U4 HM ~ r BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: G-11 Common Well Name: G-11 Spud Date: 6/2/1981 Event Name: REENTER+COMPLETE Start: 3/19/2008 End: 4/2/2008 Contractor Name: NORDIC CALISTA Rig Release: 4/2/2008 Rig Name: NORDIC 1 Rig Number: Date ~ From - To Hours '~ Task Code NPT Phase Description of Operations 4/2/2008 13:10 - 14:15 1.08 CASE P RUNPRD Pressure u and I ase from LT Packer 14:15 - 16:00 1.75 CASE P RUNPRD POH with running tools. 16:00 - 17:00 1.00 CASE P RUNPRD Freeze Protect 3-1/2" tubing with MEOH from 2500'to surface. Left 3 bbls MEOH in coil. 17:00 - 17:30 0.50 CASE P RUNPRD Lay out BTT LT Packer running tools. Top of BTT 35 KB Packer is at 10,296'. Packer has 15K Release Ring and 3" GS Profile. 17:30 - 17:45 0.25 WHSUR P POST SAFETY MEETING. Review procedure, hazards and mitigation for setting BPV with valve crew. 17:45 - 18:30 0.75 WHSUR P POST Set BPV with Valve Crew using Tee Bar. Well is dead. 18:30 - 21:00 2.50 WHSUR P POST Grease tree with new Clare Grease. Nipple down BOPE. Nipple up tree cap and press test. RELEASED RIG AT 2100 hrs 04/02/200 TOTAL DAYS ON WELL FROM RIG ACCEPT TO RELEASE WAS 10 DAYS, 15 HOURS. Move rig to DS 15-25B. All further DIMS information will be under DS 15-25B well. Printed: 5/12/2008 10:55:04 AM ~ ~ by BP Alaska s Baker Hughes INTEQ Survey Report INTEQ Compa®y: BP Amoco Date: 3/31/2008 Time: 14:43:44 Fage: 1 Field: Prudhoe Bay Co-ordinate(NE) lieterence: Well: G-11, True North Site: PB G Pad Vertical (TVD)Rekrence: 17:1.1:10/30/1993.00:00 70.2 Well: G-11 ' Section (VS) Reference: Weii (O.OON,O.OOE249.19Azi) Wellpath: G-116 Survey Calculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Wetl Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.19 deg Well: G-11 Slot Name: 11 G-11 Well Position: +N/-S 2331.40 ft Northing: 5969196.98 ft Latitude: 70 19 21.139 N +EJ-W 1603.60 ft Easting : 657855.99 ft Longitude: 148 43 12.211 W Position Uncertainty: 0.00 ft Wellpath: G-11 B Drilled From: G-11 A 500292058302 Tie-on Depth: 10278.33 ft Current Datum: 17:11 10/30/1993 00:00 Height 70.21 ft Above System Datum: Mean Sea Level Magnetic Data: 3/11/2008 Declination: 23.32 deg Field Strength: 57668 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.60 0.00 0.00 249.19 Survey Program for Definitive Wellpath Date: 1/11/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 5.51 8505.50 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 8549.00 10278.33 2 : MWD -Standard (8549.00-12 MWD MWD -Standard 10355.00 12829.00 MWD (10355.00-12829.00) MWD MWD -Standard AnnOtatlOn MD TVD ft ft 10278.33 8461.46 TIP 10355.00 8531.88 KOP 12829.00 9022.29 TD Survey: MWD Start Date: 3/27/2008 Company: Baker Hughes INTEQ Tool: MWD;MWD -Standard Engineer: Tied-to: From: Definitive Path ~ r by BP Alaska ~ Baker Hughes INTEQ Survey Report 1NTE Q Company: BP Amoco Date: 3!31!2008 Time: 14:43:44 Page: 2 Field:. Prudhoe Bay Co-ordinate(NE) Reference: WeIL G-11, True North Site: PB G Pad Vertical (TVD) Reference: 17:11 10/30/1993 QO'00 70.2 Well: G-11 Section (VS) Reference: Well (O.OON,O .OOE,249.19Azi) Wellpath: G-118 Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Inc! Azim TVD SysTVD N/S E/W MapN MapE VS DLS Tool ft deg deg:.. ft ft ft ft ft ft ft deg/100ft 10278.33 20.79 268.45 8461.46 8391.25 -1496.49 -4594.16 5967604.31 653294.65 4826.10 0.00 MWD 10355.00 25.86 257.16 8531.88 8461.67 -1500.57 -4624.10 5967599.59 653264.81 4855.54 8.79 MWD 10370.09 22.04 254.51 8545.67 8475.46 -1502.06 -4630.04 5967597.98 653258.90 4861.62 26.29 MWD 10401.45 18.73 248.52 8575.06 8504.85 -1505.48 -4640.40 5967594.35 653248.62 4872.51 12.46 MWD 10430.97 17.33 242.30 8603.14 8532.93 -1509.26 -4648.70 5967590.39 653240.39 4881.62 8.06 MWD 10460.69 15.04 235.53 8631.68 8561.47 -1513.50 -4655.80 5967586.00 653233.39 4889.76 9.97 MWD 10491.17 13.51 218.56 8661.23 8591.02 -1518.52 -4661.29 5967580.87 653228.01 4896.67 14.55 MWD 10521.75 16.23 201.14 8690.80 8620.59 -1525.31 -4665.06 5967574.01 653224.38 4902.61 17.02 MWD 10551.56 19.85 185.70 8719.15 8648.94 -1534.24 -4667.06 5967565.04 653222.57 4907.66 20.02 MWD 10581.66 23.37 175.73 8747.14 8676.93 -1545.28 -4667.13 5967553.99 653222.74 4911.64 16.86 MWD 10612.88 26.45 167.19 8775.46 8705.25 -1558.24 -4665.12 5967541.08 653225.01 4914.37 15.15 MWD 10642.94 30.77 160.99 8801.85 8731.64 -1572.05 -4661.13 5967527.36 653229.29 4915.55 17.42 MWD 10672.04 34.75 156.41 8826.32 8756.11 -1586.70 -4655.38 5967512.84 653235.35 4915.38 16.10 MWD 10701.12 39.28 151.31 8849.54 8779.33 -1602.38 -4647.64 5967497.32 653243.41 4913.72 18.81 MWD 10731.16 43.70 155.65 8872.04 8801.83 -1620.19 -4638.79 5967479.70 653252.64 4911.77 17.55 MWD 10762.82 47.01 161.49 8894.30 8824.09 -1641.15 -4630.60 5967458.92 653261.27 4911.56 16.77 MWD 10790.84 50.68 164.38 8912.74 8842.53 -1661.31 -4624.43 5967438.89 653267.86 4912.96 15.22 MWD 10820.56 53.31 169.70 8931.04 8860.83 -1684.12 -4619.20 5967416.20 653273.57 4916.17 16.65 MWD 10850.88 56.06 176.00 8948.58 8878.37 -1708.65 -4616.14 5967391.74 653277.14 4922.03 19.22 MWD 10881.98 58.26 179.53 8965.45 8895.24 -1734.75 -4615.13 5967365.67 653278.70 4930.37 11.87 MWD 10912.48 62.16 185.48 8980.61 8910.40 -1761.17 -4616.32 5967339.23 653278.07 4940.86 21.21 MWD 10942.92 65.96 189.98 8993.93 8923.72 -1788.28 -4620.01 5967312.06 653274.94 4953.95 18.23 MWD 10975.68 69.87 193.52 9006.25 8936.04 -1817.99 -4626.21 5967282.23 653269.38 4970.29 15.58 MWD 11006.10 73.59 197.58 9015.79 8945.58 -1845.80 -4633.96 5967254.26 653262.21 4987.42 17.61 MWD 11035.76 77.65 201.89 9023.15 8952.94 -1872.83 -4643.66 5967227.04 653253.08 5006.09 19.63 MWD 11066.94 81.31 207.48 9028.85 8958.64 -1900.66 -4656.47 5967198.94 653240.87 5027.95 21.17 MWD 11096.50 84.59 214.04 9032.48 8962.27 -1925.85 -4671.47 5967173.44 653226.40 5050.92 24.66 MWD 11132.50 87.94 218.23 9034.83 8964.62 -1954.85 -4692.64 5967144.01 653205.84 5081.02 14.88 MWD 11165.88 92.61 224.15 9034.67 8964.46 -1979.95 -4714.61 5967118.45 653184.41 5110.48 22.59 MWD 11196.20 96.68 229.48 9032.21 8962.00 -2000.63 -4736.63 5967097.32 653162.83 5138.40 22.07 MWD 11226.54 95.90 233.69 9028.88 8958.67 -2019.36 -4760.25 5967078.10 653139.61 5167.14 14.03 MWD 11257.60 96.40 237.34 9025.56 8955.35 -2036.84 -4785.70 5967060.08 653114.53 5197.14 11.79 MWD 11289.60 94.03 240.01 9022.65 8952.44 -2053.40 -4812.92 5967042.95 653087.67 5228.47 11.13 MWD 11323.04 91.20 241.48 9021.12 8950.91 -2069.73 -4842.06 5967026.02 653058.88 5261.51 9.53 MWD 11354.62 89.57 245.83 9020.91 8950.70 -2083.74 -4870.35 5967011.42 653030.89 5292.93 14.71 MWD 11385.40 89.14 250.91 9021.26 8951.05 -2095.08 -4898.96 5966999.48 653002.54 5323.70 16.56 MWD 11416.98 89.05 256.05 9021.75 8951.54 -2104.05 -4929.22 5966989.87 652972.47 5355.18 16.28 MWD 11450.30 90.34 261.82 9021.93 8951.72 -2110.45 -4961.90 5966982.79 652939.93 5388.00 17.74 MWD 11480.94 89.60 266.05 9021.95 8951.74 -2113.68 -4992.37 5966978.92 652909.55 5417.62 14.02 MWD 11511.12 89.48 270.88 9022.19 8951.98 -2114.49 -5022.52 5966977.48 652879.41 5446.10 16.01 MWD 11541.32 89.08 272.63 9022.57 8952.36 -2113.57 -5052.71 5966977.77 652849.22 5473.99 5.94 MWD 11577.54 91.04 270.26 9022.53 8952.32 -2112.65 -5088.91 5966977.92 652813.01 5507.50 8.49 MWD 11608.98 91.60 266.07 9021.81 8951.60 -2113.66 -5120.32 5966976.25 652781.63 5537.22 13.44 MWD 11642.58 89.23 261.86 9021.56 8951.35 -2117.19 -5153.72 5966972.02 652748.31 5569.70 14.38 MWD 11673.40 89.14 256.95 9022.00 8951.79 -2122.86 -5184.00 5966965.72 652718.16 5600.02 15.93 MWD 11705.48 89.72 254.62 9022.32 8952.11 -2130.73 -5215.10 5966957.19 652687.24 5631.88 7.48 MWD 11736.50 88.34 248.63 9022.85 8952.64 -2140.50 -5244.52 5966946.80 652658.03 5662.85 19.81 MWD 11766.72 92.64 247.18 9022.59 8952.38 -2151.87 -5272.51 5966934.85 652630.29 5693.05 15.02 MWD 11797.27 95.63 249.34 9020.39 8950.18 -2163.15 -5300.81 5966922.98 652602.23 5723.52 12.06 MWD 11828.57 94.64 254.07 9017.58 8947.37 -2172.93 -5330.40 5966912.57 652572.86 5754.65 15.38 MWD 11858.40 94.02 257.18 9015.33 8945.12 -2180.32 -5359.21 5966904.59 652544.21 5784.20 10.60 MWD 11892.09 95.11 263.14 9012.65 8942.44 -2186.06 -5392.28 5966898.15 652511.27 5817.16 17.93 MWD 11926.83 93.69 266.24 9009.98 8939.77 -2189.26 -5426.77 5966894.23 652476.86 5850.53 9.79 MWD '.. BP Alaska ~~ by Baker Hughes INTEQ Survey Report LNTEQ Company: BP Amoco Dstr. 3/31/2008 Time: 14:43.44 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL• G-11, True North Site: PB G Pad - Vertical (TVD) Reference: 17 : 11-10/30/1993 00:00 70.2 Well: G-11 Section (VS) Referenee: Well (O.OON,O.OOE,249.19Azi) Wellpatb: G11 B Survey Calculation Method: Minimum Curvature Db: OrnGe Snrvey MD Inel Azim TVD Sys TVD N/S E/W MapN MapE YS DLS Tool ft deg deg ft ft ft ft ft ft ft degl100ft 11955.77 92.55 270.82 9008.41 8938.20 -2190.00 -5455.65 5966892.88 652448.01 5877.79 16.29 MWD 11987.71 92.58 275.83 9006.97 8936.76 -2188.15 -5487.49 5966894.06 652416.13 5906.90 15.67 MWD 12018.65 90.28 280.32 9006.20 8935.99 -2183.81 -5518.10 5966897.76 652385.44 5933.97 16.30 MWD 12050.81 89.08 282.42 9006.38 8936.17 -2177.47 -5549.63 5966903.43 652353.79 5961.19 7.52 MWD 12080.39 89.36 287.65 9006.78 8936.57 -2169.80 -5578.18 5966910.50 652325.08 5985.15 17.70 MWD 12111.01 89.57 292.40 9007.07 8936.86 -2159.32 -5606.94 5966920.37 652296.11 6008.31 15.53 MWD 12140.59 88.86 289.69 9007.48 8937.27 -2148.70 -5634.55 5966930.41 652268.29 6030.34 9.47 MWD 12170.65 89.48 286.56 9007.91 8937.70 -2139.35 -5663.11 5966939.15 652239.54 6053.71 10.61 MWD 12200.75 89.42 281.82 9008.20 8937.99 -2131.97 -5692.28 5966945.92 652210.22 6078.36 15.75 MWD 12231.63 89.69 277.82 9008.44 8938.23 -2126.70 -5722.70 5966950.54 652179.70 6104.92 12.98 MWD 12262.49 84.53 271.24 9010.00 8939.79 -2124.27 -5753.40 5966952.33 652148.96 6132.75 27.07 MWD 12295.35 89.60 269.94 9011.68 8941.47 -2123.93 -5786.20 5966951.98 652116.16 6163.29 15.93 MWD 12325.99 91.14 268.36 9011.48 8941.27 -2124.39 -5816.83 5966950.88 652085.54 6192.09 7.20 MWD 12357.27 90.52 262.68 9011.03 8940.82 -2126.83 -5848.00 5966947.78 652054.44 6222.09 18.26 MWD 12388.11 93.66 259.87 9009.90 8939.69 -2131.50 -5878.46 5966942.47 652024.09 6252.22 13.66 MWD 12422.47 91.35 256.05 9008.40 8938.19 -2138.66 -5912.02 5966934.60 651990.68 6286.14 12.98 MWD 12454.57 91.54 251.60 9007.59 8937.38 -2147.60 -5942.83 5966925.02 651960.07 6318.12 13.87 MWD 12485.53 90.89 249.53 9006.94 8936.73 -2157.90 -5972.02 5966914.11 651931.11 6349.06 7.01 MWD 12516.79 89.02 246.18 9006.96 8936.75 -2169.68 -6000.97 5966901.73 651902.42 6380.30 12.27 MWD 12548.01 88.06 244.46 9007.76 8937.55 -2182.71 -6029.33 5966888.10 651874.34 6411.44 6.31 MWD 12578.79 88.00 240.02 9008.81 8938.60 -2197.03 -6056.54 5966873.21 651847.43 6441.97 14.42 MWD 12611.37 86.53 236.01 9010.37 8940.16 -2214.27 -6084.14 5966855.40 651820.21 6473.89 13.10 MWD 12641.57 88.13 231.81 9011.78 8941.57 -2232.03 -6108.51 5966837.13 651796.22 6502.98 14.87 MWD 12671.73 88.25 229.58 9012.73 8942.52 -2251.13 -6131.83 5966817.55 651773.30 6531.57 7.40 MWD 12703.77 84.96 227.77 9014.63 8944.42 -2272.24 -6155.85 5966795.93 651749.74 6561.52 11.71 MWD 12732.25 84.61 223.17 9017.22 8947.01 -2292.13 -6176.06 5966775.63 651729.95 6587.48 16.13 MWD 12764.47 86.93 218.07 9019.59 8949.38 -2316.51 -6196.97 5966750.82 651709.56 6615.69 17.35 MWD 12792.59 87.79 213.59 9020.89 8950.68 -2339.28 -6213.41 5966727.71 651693.60 6639.14 16.21 MWD 12829.00 87.79 213.59 9022.29 8952.08 -2369.58 -6233.54 5966696.99 651674.12 6668.73 0.00 MWD ~, TREE = 3-1116" SM FMC WELLHEAD = 13-518" McEVOY ACTUATOR= AXELSON KB. ELEV = 70.25' BF. ELEV = 36.26' KOP = 1900' Max Angk: = 97° ~ 11196' Datum MD = 10729' Datum TV D = 8800' SS G -11 B DRLG DRAFT I ® I 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2744. Minimum ID =1.755" @ 4604' 3-112" ECLIPSE PATCH TOP OF 7" LNR 8351' TOP OF 7" INf11A L LNR 8399' TOP OF CEMENT $549' 9-5/8' CSG, 47#, L-80, ID = 8.681" $$4g' 9-5/8" BRIDGE PLUG $800' PERFORATION SUMMARY REF LOG: SWS MCNL/GR/CCL OF 04/01/08 ANGLE AT TOP PERF: 96° @ 11210' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPWSOZ DATE 1.56" 6 11210 - 11510 O 04/02!08 1.56" 6 11570 - 11640 O 04/02/08 1.56" 6 11760 - 11810 O 04/02/08 1.56" 6 11930 - 12330 O 04/02/08 1.56" 6 12400 - 12490 O 04/02/08 1.56" 6 12550 - 12580 O 04/02/08 1.56" 6 12630 - 12780 O 04/02/08 3-112" BAKER WHIPSTOCK (03!18!08) 10355' ~ Haui Ez sv 10400' 2.55" BKR QUICK DRILL (03/09/08) 10700' PATCH & SL TOOLSTRING (03/02/08) 10737' SLM 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 10900' I SAFETY NOTE: 2196' -j 3-112" OTIS HXO SSSV LA ND NIP, ID = 2.75" 2631' s-s/s° DV PKR - 4645 -13-1 J2" WFD ER PACKER, ID = 1.75" (04/24108) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4874 4261 43 MMG DOME RK 16 04/07/08 2 8154 6555 45 MMG SO RK 20 04/07/08 1 9160 7376 14 KBUG DRAY BK 0 12/QS/02 MILLOUT WINDOW (G-116) 10355' -' 9300' (-iTOPOF CMT PKR 10296' --~ Top of BTT 35 KB LT PACKER 10302' Top of 2 318" liner, top of cement PBTD 12790' 2-3/8" STL 4.7 ppf L-80 liner cmt'ed and perfed ~~ 12,829' TOP OF 4-1 /2" LNR 11264' 11243' PKR SCOOP TOP, ID = 3.910" ~ ~ ~ ~ 11262' 7" SS TMJ PKR, ID = 4.000" 11267' 4J-1/2" PORTED JT, ID = 3.958" 7" LNR, 29#, 13-CR-80, .0371 bpf, ID = 6.184" 11389' I ??? FISH - 2 RUBBER PKR ELEMENTS 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 12553' (~ FROM PATCH (05/14(04) I I l , DATE REV BY COMMENTS DATE REV BY COMMEMS ??? ORIGINAL COMPLETION 11119193 SIDETRACK (G-11A) 04102/08 NORDICI CTDSIDETRACK(G-11B) 03102/08 JCM/TLH PATCH PULLED {PRE CTD) 04118/08 JCIWTIH GLV GO & CORRECTION (04/09108) OS/05/08 CJWPJC SET ER PKR (04124108) PRUDHOE BAY UNff WELL: G-11 B PERMIT No: 82080270 API No: 50-029-20583-02 SEC 12, T11 N, R13E, 2444' FNL & 2367' FWL BP Exploration (Alaska) i BAKER f Nuc~MEs Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLUKA'1'lUN (ALASKA) 1NC CUUN'1'Y WELL NAME G-11B STATE FIELD PRUDHOE BAY UNIT THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #: 1893161 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC Company Person PETROTECHNICAL DATA CENTER Person Address LR2-1 Address 900 E BENSON BLVD. ANCHORAGE. AK 99508 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address GSC EMB 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 1 Company DNR-DIVISION OF OIL & GAS Company Person KRISTIN DIRKS Person Address 550 WEST 7TH AVE Address SUITE 802 ANCHORAGE. AK 99501 Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~~~ ~2~- NUR'1H SLUYE BURUUGH ALASKA DATE 6/25/2008 Page 1 of 1 INTEQ I,og & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7`h Ave. Suite 100 Anchorage, Alaska 9950.1 Attention: Christine Mahnken Reference: G-11S '~~~! Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color prints - GR Directional Measured Depth Log (to follow) 1 color prints - GR Directional TVD Log (to follow) LAC Job#: 1893161 Sent by: Catrina Guidry Date: 06/26/08 Received by: Date: - ~ - PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (9U7) 267-6623 Baker Hughes INTEQ ~~~ ' 7260 Homer Drive ,~ Anchorage, Alaska 99518 ~`S~~ ~" Direct: (907) 267-6612 -~,~° INTEQ FAX: (907) 267-6623 ~~ ~~~ ~~ osroaro8 ~~II~~h41'~I' N0.4736 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Wpll .Inh S 1 .,r. ne~...anf~.,.. nti~s c~ r•..i.,. rn L-220 11975963 CH EDIT PDC GR (USIT) / 04/22/08 1 L-221 11962592 CH EDIT PDC GR (USIT) 04/07/08 1 V-223 40016679 OH MWD/LWD EDIT ^ 03/20/08 2 1 W-30 12034892 RST ~ -( (/ 04/11/08 1 1 G-116 11963085 MCNL 0`6-~ / 04/01/08 1 1 05-286 11649987 MCNL (o- 08/17/07 1 1 P2-36A 11209594 MCNL - 03/26!06 1 1 07-018 12021155 MCNL `j~ 04/28/08 1 1 OS-34 11966251 CH EDIT PDC GR (USIT) 04/13/08 1 17-12 12057613 PRODUCTION PROFILE - (~ 05/23/08 1 1 VU-31 11999015 LDL - 05/25/08 1 1 GNI-02A 12057618 PRESS/TEMP SURVEY (o - 3 ~ 05/24/08 1 1 13-12 11982434 USIT _ L ~~- 05/29/08 1 1 r~cna~ s~~.nrvvw~euut FItGtIF• I rST JllarvlNG HrvU Fit I UHIVINt9 UIVt GUF'Y tAGFi I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 00 Anchorage, AK 99503- 83 ATTN: Beth Received by: STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COM ~ 200 ...~G~~' Sag-~~ REPORT OF SUNDRY WELL~~~~~~~FS. ~~~~~,~~si~~~ 1. Operations Abandon ~ Repair Well ~ i Plug Perforations ~ Stimulate ®,fC~C;•~~~ Other ~ TUBING PATCH ~ 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 ~` ~ Exploratory 2os-o27o ' 3. Address: P.O. Box 196612 Stratigraphic Service ' 6. API Number: Anchorage, AK 99519-6612 50-029-20583-02-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: 70.21 KB ' PBU G-11 B , 8. Property Designation: 10. Field/Pool(s): ADLO-028240 • PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12829 ~ feet Plugs (measured) None true vertical 9022.29 feet Junk (measured) 10737 Effective Depth measured 12790 feet true vertical 9021 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 20" SURFACE - 80' SURFACE - 80' SURFACE 2744' 13-3/8" 72# L-80 SURFACE - 2744' SURFACE - 2683' 4930 2670 PRODUCTION 8549' 9-5/8" 47# L-80 SURFACE - 8549' SURFACE - 6838' 6870 4760 LINER 3038' 7" 29# 13CR80 8351' - 11389' 6696' - 9021' 8160 7020 LINER 2533' 2-3/8" 4.7# L-80 10296' - 12829' 8478' - 9022' 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ - True Vertical depth: _ _ _ - = Tubing: (size, grade, and measured depth) 3-1/2" 9.2# L-80 SURFACE - 10900' 0 0 - Packers and SSSV (type and measured depth) 3-1 /2" WFD ER PKR 4604-4645 BTT 35KB LT PKR 10296' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: SHUT-IN Subsequent to operation: 1575 2933 48 291 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 Preble Title Data Management Engineer Signature hone 564-4944 Date 5/23/2008 ~ ~'~"~~~'~ ~~~~ Fj~~ ~ ~ Submit Ori anal Onl Form 10-404 Revised 04/200 (~ ~ (~ ~ ~ /- ~ QQ~ 9 Y G-11 B 208-027 PERF ATTACHMENT Sw Name Operation Date Perf Operation C Meas Depth Meas Depth Base Tvd Depth Top Tvd Depth Base G-11 B 4/2/08 PER 11,210. 11,510. 9,030.65 9,022.18 G-11B 4/2/08 PER 11,570. 11,640. 9,022.64 9,021.53 G-11B 4/2/08 PER 11,760. 11,810. 9,022.84 9,019.18 G-11B 4/2/08 PER 11,930. 12,330. 9,009.78 9,011.4 G-11 B 4/2/08 PER 12,400. 12,490. 9,009.23 9,006.88 G-11 B 4/2/08 PER 12,550. 12,580. 9,007.82 9,008.86 G-11 B 4/2/08 PER 12,630. 12,780. 9,011.34 9,020.36 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REM OVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED _ MIR MECHANICAL ISOLATED REMOVE D SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • G-11B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/7/20008" ***WELL S/I ON ARRIVAL*** (post ctd) -SET 3.5" KEYLESS X-LOCK CATCHER ON LINER TOP C~ 10276' SLM. PULLED DGLVS FROM STA.#3 C«3 4856' SLM (4874' MD) & #2 @ 8137 SLM (8154' MD) SET GENERIC GASLIFT DESIGN IN STA.# 3 & 2 PULL 3.5" EMPTY KEYLESS X-LOCK CATCHER FROM 10276' SLM i RAN DUMMY PATCH DRIFT (2.74" CENT, 10' OF 1 7/8" STEM, W/ 2.74" I WEATHERFORD DRIFT) TO 2 3/8" LINER TOP @ 10,276' SLM ***LEFT WELL S/I NOTIFY DSO*** 4/9/2008 ***WELL SHUTIN ON ARRIVAL*** INITIAL WHP T/I/0=300/0/0 !SET 1-11/16" BAKER IBP MID-ELEMENT @ 9400'. 1-3/8" FISH NECK. ~ RU BAKER PATCH. SHEAR PINS OVERTIGHTENED @ SURFACE, DOGS DEPLOYED. PATCH REBUILT. ***CONTINUED 10-APR2-2008"** 4/10/2008' ***CONTINUED FROM 9-APR-2008*"* ATTrlI AflTrfl T/l G~rT nnvrn !1 ~A~~ n[ POOH & RIG DOWN. FINAL T/I/O 120/0/0. ***WELL LEFT S/I, PAD-OP NOTIFIED*** 'ATCH. '~ 4/20/2008 ***WELL S/I ON ARRIVAL***(pre patch /post ctd) MIRU SWCP LL #1 O TO DRIFT W/ 2.74" x 10' DUMMY PATCH. ***JOB IN PROGRESS, CONTINUED ON 4/21/08 WSR*** 4/21/2008' ***CONTINUED FROM 4/20/08 WSR***(pre patch /post ctd) i DRIFT TUBING TO 4800' SLM (target 4700') W/ 2 74" x 10' DMY PATCH 3 BRUSH SVLN C~ 2,196' MD W/ 3 1/2" BLB, 2.74" x 10' DUMMY PATCH ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR*** ~.. . ~.. 4/22/2008 MATERIAL AND MACHINE SHOP COSTS TO MODIFY TWO WFD 3-1/2" ECLIPSE PACKERS AND SNAP LATCH ASSY. 4/24/2008 ***WELL SHUT-IN ON ARRIVAL*"* INITIAL WHP 150/0/0 CCT 4_i /O" \A/C4TI-IGRCIIRfI G(`I IPCG I (11A/GR PA( l~R ACCG~ARI V' , MID ELEMENT AT 4.645'. WELL LEFT SHUT IN. FINAL WHP 150/0/0 ***JOB COMPLETE*** r 4/25/2008: **"WELL S/I ON ARRIVAL***[post "SET WFD 3 1/2" x 3T PATCH W/ NOTE: MIN ID= 1.75", LENGTH BETWEEN ELEMENTS= 35' LRS PERFORMED MIT-T TO 3000psi. FAILED, LOST 2260psi/ 15 MINUTES LRS PERFORMED CMIT TxIA. PASSED, LOST 60psi/ 30 MINUTES. [see LRS `WSR] LRS CURRENTLY IN PROCESS OF ESTABLISHING LLR ""*CONT. JOB ON 4/26/08 WSR""" 4/25/2008': T/I/0=200/0/0 temp=s/i Assist s-line MIT T to 3000 psi """*FAIL""""; CMIT TxIA 3000 psi **"*PASS"""" (post CTD ST) Pumped 21.4 bbls crude down 'TBG. Attempted to MIT-T to 3000 psi. TBGP dropped upon SD. Attempted to 'LLR TBG. Could not establish an accurate LLR. IA tracking with TBG. CMIT- ' TxIA to 3000 psi. Lost 40 psi/40 psi in 1st 15 min. Lost 20 psi/20 psi in 2nd 15 !::min. Total loss of 60 psi/60 psi in 30 min. Pass. '`**Continued on 04-25-08 WSR""`* **"Continued from 04-25-08 WSR**" LLR TBG (CTD) Pumped 3.2 bbls crude down TBG to establish a LLR to IA. IA returns went down jumper line to G-21. 'Unable to estblish an accurate LLR. FP jumper lin w/3 bbls 60/40. Slickline still on 'well. *"*Tags hung. Casing valves open to gauges**" FWP=900/900/0 4/26/2008°". **"WELL S/I ON ARRIVAL***(post ctd) 'CURRENTLY RUNNING PDS TECWEL LDL FROM 9,399' SLM TO SURFACE '"`*JOB IN PROGRESS, CONTINUED ON 4/27/08 WSR**" 4/26/2008?: T/I/0= 550/560/40 -Assist Slick-line with TecWell LDL -Pumped 41 bbls 105" .crude down TBG taking returns from IA to G-21 while slickline runs log. *** Job continued on 04/27/08 WSR '** • IN @ 3000 PSI. [see LRS WSR] DRIFTED THRU PATCH TO 4800' SLM W/ 1.71" CENT ALL CLEAR. NOTE: HARDLINE LEFT RIGGED UP FROM G-11 IA TO G-21 TREE CAP. ***RDMO. LEFT WELL S/I, TURNED WELL OVER TO PAD-OP*'"' 4/27/2008' "*'`CONTINUED FROM 4/26/08 WSR*"*(post ctd) =RAN PDS TECWEL LDL FROM 9,399' SLM TO SURFACE Leaking at lower SET STANDING VALVE INTO TOP ER PKR C«~ PULLED 3-1/2" x 37' WFD ER PKR & SNAP LATCH AT 4589' SLM (missing 4 pieces of pkg). CURRENTLY RIH W/ 2.50" x 5' PUMP BAILER MULE SHOE FLAPPER BOTTOM TO PKR. """JOB IN PROGRESS, CONTINUED ON 4/28/08 WSR"** 4/27/2008 *"" Job continued from 04/26/08 WSR """ Assist slickline w/LDL TecWel -Pumped 52.7 bbls (93.7 total) 105" crude down TBG taking returns from IA to G-21 flowline while slickline runs log. Freeze protect hardline w/4 bbls neat meth. FWP's = 400/175/40 *'"` Casing valves open to guages, DSO notified of well status **" 4/28/2008; "'"`CONTINUED FROM 4/27/08 WSR""(post ctd) RAN 2.50" x 5' PUMP BAILER TWICE TO 4,630' SLM (recovered ~3 pieces of pk . BRUSH WFD ER PACKER @ 4630' SLM W/2.50" CENT, 5' x 1-1/2" STEM, 1.83" BLB ""*WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR""` 4/30/2008 _.____m___~__. _ __._. _ __ __~_______ __.~._ 4/26/2008="""CONT. JOB FROM 4/25/08 WSR`**[post ctd] 'LRS UNABLE TO ESTABLISH LLR > .30 BBLS "WELL S/I ON ARRIVAL`*"(post ctd) RAN CAT STANDING VALVE, W/WFD SNAP LATCH TO ER PKR AT 4,630' SLM, (pkg was torn, shredded, and missing a few chunks. Not missing-any fu11 piecE ""*JOB IN PROGRESS. CONTINUED ON 5/1/08 WSR"*" • r 5/1/2008:: ***CONTINUED FROM 4/30/08 WSR***(post ctd) RE-RAN CAT STANDING VALVE W/WFD SNAP LATCH TO ER PACKER AT 4,630' SLM, (ea. piece of pkg & back rings heavily coated w/climax grease, pkg came back in good shape) `:SET WFD 3 1/2" x 37' PATCH W/ ER PACKER INTO LOWER ANCHOR C~ NOTE: MIN ID= 1.75", LENGTH BETWEEN ELEMENTS= 35' PERFORMED SUCCESSFUL MIT-T & CMIT-TxIA TO 3000PS1 W/ TRI- 'RAN BRUSH, 1.70" CENT. SD C 4614' SLM, ABLE TO WORK (elements `:4618' SLM "`**JOB IN PROGRESS, CONTINU_E_D_ON 5/2/08 WSR""" 5/2/2008> "*CONTiNUED FROM 5/1/08 WSR*""(post ctd) ~~~~~~~~__ _____~n_ ~___~_.~.. FISHED ~75% OF 6" SEALING ELEMENTS FROM BAKER IBP W/ BLB, V n n w n n NOTE: BOTH ELEMENTS FISHED WERE ~75% INTACT (little pieces torn away) ""''WELL LEFT S/I ON DEPARTURE, NOTIFIED PAD OPERATOR""" .~..__. _._a.__ ____,_ ~~__, _.. __w.~~____,e~_. _.___~ __~,~~w ...~_____,~_ ~.~~..~. ~~_ 5/12/200& ASRC Unit #2, move to G-1~1, standby for snow removal **job in progress"" 5/13/2008 ASRC Unit #2, MIRU, standby for water to pressure test vessel, P/T to 1000 psi- ~' ok ""job in progress"" 5/14/2008:. • ___._.____.~._....._.r..~___,__ _ _ _~__ _ __~____ ._._....._ ASRC unit #2 standby for CH2Mhiil to re-install PBGL checkvalve, POP well, increasing choke **job in progress** 5/15/2008 ASRC Unit #2 NWK, continue to open choke <.25% solids "*job in progress"" v_.._~~___~_ ~._._ _._w.._ __~.__. _~_.. ~ ~ ._._ _.__..~ K_..__r. _~..._~ ____.~~ ..~____ ~_.._m ~.~ 5/16/2008 ASRC Unit #2 obtain 4 hour test with gas lift, begin RDMO *"job in progress"` 5/17/2008 ASRC Unit #2 complete RDMO to DS01 ""job complete"* FLUIDS PUMPED BBLS 10 DIESEL 10 TOTAL . , TR13== 3-1116" 5M FMC 1f~IF1.LHEAD= 13-518" McEVOY ACTUATOR = AXELSON KB. ELEV = 70.25' $F. ELEV = 3626' KOP = 1900' Max Angle = 97° ~ 11196' Datum MD = 10729' Datum TV D = 8800' SS G-11 B DRLG DRAFT 13-318' CSG, 72#, L-B0, ®= 12.347" H 274' Minimum ID =1.755" ~ 4604' 3-112" ECLIPSE PATCH TOP OF T LNR H 8351' TOP OF 7" IJfT1AL LNR 8399' TOP OF CEMENT 9-518" CSG, 47#, L-~. D - 8.681" 8549' 9-518" BRDGE PLUG $800' PERFORATION SUMMARY REF LOG: SWS MCNUGRiCCL OF 04/01/08 ANGLE AT TOP PERF: 96° @ 11210' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPN/SOZ DATE 1.56" 6 11210 - 11510 O 04/02/08 1.56" 6 11570 - 11640 O 04/02/08 1.56" 6 11760 - 11810 O 04/02/08 1.56" 6 11930 - 12330 O 04/02/08 1.56" 6 12400 - 12490 O 04/02/08 1.56" 6 12550 - 12580 O 04/02/08 1.56" 6 12630 - 12780 O 04/02/08 3-1 /2" BAKER NMESTOCK (Halli ¢ SV H 10400' 2.55" BKR QUICK DRILL (03/09/08) 10700' PATCH & SL TOOLSTRING (03/02/08) 10737' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, D = 2.992" 10900' TOP OF 41 /2" LNR 11264' SA OTE: ~3-112' 0715 HXO SSSV LA PA NP, D = 2.75" I 9-5/8' DV PKR 4604 -4645' ~-13-1 /2" WFD ER PA CICHZ, D = 1.75" GAS LFTMANORELS S MD TV D DEV TYPE V LV LATCH PORT DATE 3 4874 4261 43 MMG DONE RK 16 04!07108 2 8154 6555 45 MMG SO RK 20 04/07/08 1 9160 7376 14 KBUG DMY BK 0 12/05!02 M~LOUT WINDOW (G-11 B) 10355' - ' ITOP OF CMT PKR ~ 10296' Top of BTT 35 KB LT PACKER 10302' Top of 2 318" liner, top of cement PBTD H 12790' 2-3/8" STL 4.7 ppf L-80 liner cmt'ed and perfed H 1 11243' ~-{PKR SCOOPTOP, D = 3.910" • ~ ~ • 11262' 7" SS TNV PKR, ID = 4.000' 11267 4J-112" PORTED JT, ID = 3.958" I 7" LNR, 29#, 13-CR-80, .0371 bpf, D = 6.184" I 11389' I ??? FlSH - 2 RUBBER PKR CEMENTS 4112" SLTD LNR, 12.6#, L-80, .0152 bpf, D = 3.953" 12553' i ~ FROM PATCH (05114104) l I GATE REV BY COMMENTS GATE REV BY COAM9VTS ??? ORIGINAL COMPLETION 11119193 SIDETRACK (G-11Aj 04/02108 NORDIC? CTD SIDETRACK (G-11B) 03!02/08 JCMrT1H PATCH PULLED {PRE CTD) 04/18108 JCMrfLH GLV C/0 & CORRECTION {04!09!08) 05105108 CJWPJC SET ER PKR {04!24!08) PRUDHOE BAY lA+9T V11Etl: G11 B PERMIT No: 82080270 API No: 50-029-20583-02 SEC 12, 711 N, R13E, 2444' FNL 8 2367 FVVL BA Expbration {Alaska) r 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: May 23, 2008 Please find enclosed directional survey data for the following wells: P2-08APB 1 P2-08A G-11B 15-25B 07-O1B Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: Q ,State of Alaska AOGCC DATE: ~ 3 .. ~~ Cc: State of Alaska, AOGCC ~~~ ~~~~ VV~LL., LSO ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTI~ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Jnc. :..Attn: Robert A.. Richey 130 West International Airport Raad Suite C Anchorage, AK 99518 Fax: (907 245.8952 c~~ ~ /Co!$~ 1) Leak Detection - WLD 27 Apr-08 G11 B 2) i i Signed Print Name: ~ r ~ ~ f i ~ ~ ~ ail ~ 1 Color Log / EDE 50-029-2083-02 `% Date ~ v PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL: $9E35~n~5?37~'a£~~Ct~973~~39G~'?#"145~1.~~173 WEBSITE:~1~i;g.1hV.5g°£9'~R48.Y?lle3t3.y~ C:\Documents and Settings\Ownet\Desktop\Ttansmit BP.doc y ~ SARAH PAL/N, GOVERNOR ois[>•-7~ OIL ~ ~-7 333 W. 7th AVENUE., SUITE 100 CO1~T5I' R~ATIOI~T COrII-TIS5I01`T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Abby Warren CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU G-11 B BP Exploration Alaska, Inc. Permit No: 208-027 Surface Location: 2444' FNL, 2367' FEL, SEC. 12, T11N, R13E, UM Bottomhole Location: 4988' FNL, 3241' FEL, SEC. 11, T11N, R13E, UM Dear Ms. Warren: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this26 day of February, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~ STATE OF ALASKA a?~~~-~p~ ALAS~IL AND GAS CONSERVATION COMMIN FEB 2 2 20p~ PERMIT TO DRILL ~ ~-(~ Alaska ®i1 & Gas Gans. Cat~mia~eion 20 AAC 25.005 Ant;horaae 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU G-11B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12870 TVD 8952ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2444' FNL 2367' FEL SEC 12 T11N R13E UM 7. Property Designation: ADL 028240 Pool , , . , , , Top of Productive Horizon: 3943' FNL, 1710' FEL, SEC. 11, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: April 1, 2008 Total Depth: 4988' FNL, 3241' FEL, SEC. 11, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 15,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-657856 y-5969197 Zone-ASP4 10. KB Elevation (Height above GL): 70.21 feet 15. Distance to Nearest We11 Within Pool: 550' 16. Deviated Wells: Kickoff Depth: 10350 feet Maximum Hole An le: 96 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3229 Surface: 2349 18. Casin Pr ram: S ' lio ns To - e in De th -Bo ttom Quanti of Gem nt c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.7# L-80 STL 2720' 10150' 8268' 12870' 8952' 79 cu ft Class'G' 19. PRESE NT WELL CONDITION S UMMARY (Ta be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12553 Total Depth TVD (ft): g00g Plugs (measured): None Effective Depth MD (ft): 12547 Effective Depth TVD (ft): 9009 Junk (measured): Yes, Unknown MD asing Length Size Cement Volume MI) D Conductor /Structural 110' 20" x 30" 8 cu ds Concrete 110' 110' Surface 2744' 13-3/8" 3589 cu ft Arcticset I I 2744' 2683' Intermediate 8549' 9-5/8" 1518 cu ft Class 'G' 140 cu ft AS 8549' 6838' Pr cti n Liner 3039' 7" 366 cu ft Class'G' 8351' - 11390' 6696' - 9025' Liner 1289' 4-112" Uncemented Slotted Liner 11264' - 12553' 9018' - 9009' Perforation Depth MD (ft): 11115' - 12537' Perforation Depth TVD (ft): 8990' - 9010' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Abby Warren, 564-5480 Printed Name Abby Warren Title CT Drilling Engineer Prepared By Name/Number: Si nature " / Phone 564-5480 DateO ~~~$ Terrie Hubble, 564-4628 Comrnission Use Ont Permit To Drill Number. ®~ API Number: 50-029-20583-02-00 Permit A rova See cover letter for Date: ~ other re uirements Conditions of Approval: ,,~~(( If box is checked, well may not be used to explore for, test, or produce Coalbed meth~a e, gas hydrates, or gas contained shales: ~!J Samples eq'd: ^ Yes LrJ No Mud Log Req'd: ^~es l1Q No ~r~ H2S Meas es: Yes ^ No Directional Survey Req'd: L/J Yes ^ No Other: ~j~~ ~S~ `~V~~~~~5 ~ ~C~.ir\~' Date APPROVED BY T COMMInSSIONER Form 10-401 Revised 12/2005 01'1 1 ~ I t~ ' ~ 1/ Submit In Duplicate by To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Abby Higbie, CTD Engineer Date: February 14, 2008 Re: Prudhoe Bay G-11B Permit to Drill Request The sidetrack, G-11B, is scheduled to be drilled by Nordic 1 around April 1. The plan calls for a slimhole lateral with a solid liner and 1000 ft of perforations in Zone lA. Pre-Rig Work: The pre CTD work is slated to begin on March 1, 2008. 1. O Passed MIT-IA, -OA Done 1/1/08 2. S Pull Patch 3. O Load tubing and IA 4. S Drift for 3-1/2" cement retainer, 3-1/2" whipstock and set SWS plug at 10,876' 5. E Punch tubing for cement packer 6. O CMTT-T x IA 7. E Run 3-1/2" Cement retainer at 10,700' ~~~ ~~~ `~ 8. C Pump cement packer in IA through retainer G 9. C POOH laying cement on top of cement retainer 10.E Set Baker 3-1/2" Monobore whipstock lowside at 10350' 11. O PPPOT-IC, -T; LDS 12. O PT MV, SV, WV 13. O Blind and bleed lines, remove well house, level pad Rig Work: 1. MIRU and test BOPE to 250 psi low and 3500 psi high 2. Mi112.74" window at 10,350' and 10' of openhole. Swap the well to Flo-Pro. 3. Drill Build: 3" OH, 790' (20 deg/100 planned) ~ 4. Drill Lateral: 3" OH, 1730' horizontal (12 deg/100 planned) ~ 5. Run 2 3/8" solid liner leaving TOL at 10,150' ~~~ ~ 6. Pump primary cement job to TOL ~~~ 7. Run CO assembly 8. Run MCNL/GR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate, planned 1000ft. 11. Freeze protect well, Set BPV, RDMO Post-Rig Work 1. Install GLV, Set Baker patch 2. Install well house. Hook up flow line. Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2 3/8", 4.7# , L-80, STL connection Solid liner - 10,150' to TD • A minimum of 14 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 10,150 ft (TOL). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 96 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 15000' • Distance to nearest well within pool - 550' ft to G-19B Anticollision Summary • G-19B: 567' ctr-ctr, Status: active well • G-15A: 695' ctr-ctr, Status: shut in with a marginal GOR • G-11 (parent wellbore): 391' ctr-ctr, Status : P&A'd in 1993 Logging • MWD directional and Gamma Ray will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • The maximum recorded H2S level on G pad is 25 ppm on G-02 (6-11-06) • Lost circulation risk is low. Reservoir Pressure • Res. press. is estimated to be 3,229 psi at 8,800'ss (7.05 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2349 psi. Abby Higbie CTD Drilling Engineer 564-5480 CC: Well File Sondra Stewman/Terrie Hubble = 1-1116" SM FMC WELLHFAD= M5/8" McEVOY ACTUATOR = AXELSON KB. ELEV = 70.25' BF. ELEV = 36.26' KOP = 1900' Max Angle = 93 ~ 12510' Datum MD = 10826' Datum TV D = 8800' SS -11 A wAFE~OTE. CHROM E LINER -HORIZONTAL 2196' 3-112" OTIS XBD SSSV LAND NIP, ID = 2.75" 2631' 9-5/8" DV PKR 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2744' Minimum ID =1.740" ~ 4586' 3-1 /2" ECLIPSE PATCH TOP OF T' LNR 8351' TOP OF 7" INRIAL LNR l 8399' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8648' TOP OF CEMENT 8549' I 9-5/8" BRIDGE PLUG I 4586' -4646' ~-{3-1r2" -NFD Ecl-IPSE SLICKSTK'ac PATCH (07107/04), ID =1.740" T MD TV D DEV TYPE V LV LATCH PORT DATE 3 4874 4191 43 CA-KBUG DMY RK 0 12/05!02 2 8154 6423 45 CA-KBUG DRAY RK 0 1 9160 7304 14 CA-MMG DMY BK 0 12/05/02 SIDETRACK WINDOW 8549' -8599' I 10784' ~-~ 3-1/2" PARKER SWS NIP, ID = 2.75" 1850' ~7" x 3-1/2" BAKER SABL-3 PKR, ID = 3.875" W/KBH-22 S ANCHOR, ID = 3.875" 10876' 3-1/2" PARKER SWS NIP, ID = 2.75" 1088T 3-1C2" PARKER SWN NIP, ID = 2.635" s-5/8° CSG, a7#, L-so, ID = 8.681 ° ~~ 10690' ~- 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" I 10900' I TOP OF4-1/2" LNR ~-1 7" LNR. 29#. 13-CR-80..0371 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: NNW/GRON 11/15193 A NGLE AT TOP PERF: 74 ~ 11115' Note: Refer to Product~n DB for historical perf data SQE SPF INTERVAL OPN/SQZ DATE 6 11115 - 11140 O 03/30/02 41/2" 11385 - 1 2537 SLTD 11 /17/93 11264' •aaa 11388' PBTD 12547' 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 12563' DATE REV BY CON~NTS DATE REV BY COMNCNTS ORIGINAL COMPLETION 07/07/04 MDGKAI SET ECLIPSE PATCH ~ 4586' 11118/83 SIDETRACK (G-11A) 07/02/05 ???ITCH CORRECTED N9N ID 08/03/01 RN/TP CORRECTIONS 12/24/07 JLJ/TLH PATCH ID CORRECTION 03/30/02 OAV/KK ADPERF & ELNO TT 12!08102 RLlfLH GLV GO 05/14/04 KSB/KAK PULL PATCH /FISH 10800' --~ 3-1/2° rn wLEc 10885' H ELMD TT LOGGED 03/30/02 11243' PKR SCOOP TOP, ID = 3.910' 11262' 7" SS TIW PKR, ID = 4.000" 11267' 4J-112" PORTED JT, ID = 3.958" ??? FISH - 2 RUBBER PKR ELEMENTS FROM PATCH (05/14/04) 11385' I-ITOPOF 4-1/2" SLOTTED LNR \' '~ \ \ ~ ~ \ \ ~ ~ \ ~ \ \ ~~ PRUDHOE BAY UNff WELL: G-11A PERMfT No: 1931600 API No: 50-029-20583-01 SEC 12, T11 N, R7 3E, 2444' FNL & 2367: FWL BP Exploration (Alaska) = f-1 /16" SM FMC WELLHEAD= f-5/8" McEVOY ACTUATOR = AXELSON KB. ELEV = 70.25' BF. ELEV = 36.26' KOP = 1900' Max Angle = 93 ~ 12510' Datum MD = 10826' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I-j 2744 Minimum ID =1.745" ~ 4586' 3-112" ECLIPSE PATCH TOP OF 7" LNR I 8361' TOP OF 7" INffIAL LNR 8399' TOP OF CEMENT ~ 8548' 9-518" CSG, 47#, L-80, ID = 8.681" 8b49' . ~ -11 B SAF TE: Proposed CTD Sidetrack 9-5/8" BRIDGE PLUG I 8800' PERFORATION SUMMARY REF LOG: MWDVGR ON 11/15/93 ANGLE AT TOP PERF: 74 ~ 11115' Note: Refer to Production ~ for historical pert data SQE SPF INTERVAL OPNISQZ DATE 6 11115 - 11140 0 03/30/02 4-1/2" 11385-12537 SLTD 11/17/93 3-1/2" Baker w hipstock-j 10350' ~~ Cement Retainer 10700' TBG punch 10810'-10820' 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" 10800' TOP OF4-1/2" LNR 11264' 7" LNR, 29#, 13-CR-80, .0371 bpf, ID = 6.184" ~~ 11389' i I I 4-1/2" SLTD LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 126b3' I I 2186' --{3-112" OTIS XBD SSSV LAND NIP, ID = 2.75" 2631' 9-5/8" DV PKR 86' - 4848' ~ 3-112° WFO ECLIPSE SLICKSTICK PATCH (07!07/041, ID = 1.745" TO BE ~'ULLEU S ReRun eflar CTST r`~AS LIFT MANDRELS T MD TVD DEV TYPE VLV LATCH PORT DATE 3 4874 4191 43 CA-KBUG DMY RK 0 12/05/02 2 6154 6423 45 CA-KBUG DMY RK 0 1 9160 7304 14 CA-MMG DMY BK 0 12/05/02 SIG"f_T"RACI<ININDOV~ 8549' - 8599' 9500' HTop of cement packer 101 b0' Top of 2 3/8" liner, top of cement 2-3/8" cn#'ed and perfed H 12870' 10784' 3-1/2" PA RKER SWS NIP, ID = 2.75" 10850' ~ 7" x 3-1/2" BAKER SABL-3 PKR, ID= 3.875" IW/KBH-22 S ANCHOR, ID=3.875" 10876' 3.1/2" PARKERSWS NIP, ID=2.75" W! PLl1G t 10887' 3-1/2" PARKER SWN NIP, ID = 2.635" 10800' 3-1/2" TTL WLEG 10885' ELMD TT LOGGED 03/30/02 11243' PKR SCOOP TOP, ID = 3.910' 11282' 7" SS TW PKR, ID = 4.000" ~~~• 11287' 4J-1/2" PORTED JT, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS ORIGINAL COMPLETION 07/07/04 MDGKA K SET ECLIPSE PATCH ~ 4586' 11/19/93 SIDETRACK (G-11A) 07/02/05 ???lTLH CORRECTED MIN ID 08/03/01 RWTP CORRECTIONS 03/30/02 DAV/KK A DPERF 8 ELMD TT 12/08/02 RL/TLH GLV GO 05/14/04 KSB/KAK PULL PATCH /FISH FISH - 2 RUBBER PKR ELEMENTS FROM PATCH (05/14/04) PRUDHOE BAY UNfr WELL: G-11A PERMIT No: 1931600 API No: 50-029-20583-01 SEC 12, T11 N, R13E, 2444' FNL & 2367' FWL BP Exploration (Alaska) e '~ BP Alaska P Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 1/1512008 Time: 15:56:19 Page: 1 ~ Field: Prudhoe Bay Co-ordinate(NE)Refereuce: Well: G-11, True North ~ ~ Site: PB G Pad VCrticatl (TVA?) Reference: 17 :11 10!30/1993 00:00 70.2 Well: G-11 Section (VS) Reference: WeU (O.OON,O.OOE,220.OOAzi) Wellpath: Plan 9, G-11 B Survey Calculation Method: Minimum Curvature Db: Sybase Field: Prudhoe Bay North Slope UNITED STATES ' Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB G Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5966832.87 ft Latitude: 70 18 58.211 N From: Map Easting: 656301.39 ft Longitude: 148 43 59.013 W Position Uncertainty: 0.00 ft North Reference: True Ground Leveh 0.00 ft Grid Convergence: 1.19 deg _ ~ Well: G-11 Slot Name: 11 G-11 WeII Position: +N/-S 2331.40 ft Northing: 5969196.98 ft Latitude: 70 19 21.139 N +E/-W 1603.60 ft Easting : 657855.99 ft Longitude: 148 43 12.211 W Position Uncertainty: 0.00 ft i -- - - - Wellpath: Plan 9, G-11 B Drilled From: G-11 A 500292058302 Tie-on Depth: 10278.33 ft Current Datum: 17:11 10/30/1993 00:00 Height 70. 21 ft Above System Datum: Mean Sea Level Magnetic Data: 3/11/2008 Declination: 23.32 deg Field Strength: 57668 nT Mag Dip Angle: 80.93 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.60 0.00 0.00 220.00 -- Plan: Plan #9 Date Composed: 1/11/2008 Copy Mary's Plan 9 Vernon: 3 Principal: Yes T-ed-to: From: Definitive Path J Targets Map Map <---- Latitude ----> <--- Longitude ---> ' Name Description TVD +N/-S +E!-W Northing Easting Deg Min Sec Deg Min Sec .Dip. Dir. ft ft ft` ft ft G-11 B Polygon 70.21 -1694.56 -4703.01 5967404.00 653190.00 70 19 4.458 N 148 45 29.438 W -Polygon 1 70.21 -1694.56 -4703.01 5967404.00 653190.00 70 19 4.458 N 148 45 29.438 W -Polygon 2 70.21 -1739.26 -4432.88 5967365.00 653461.00 70 19 4.021 N 148 45 21.555 W -Polygon 3 70.21 -2213.27 -4771.94 5966884.00 653132.00 70 18 59.357 N 148 45 31.440 W -Polygon 4 70.21 -2769.31 -6204.06 5966298.00 651712.00 70 18 53.878 N 148 46 13.210 W -Polygon 5 70.21 -2173.07 -6444.59 5966889.00 651459.00 70 18 59.740 N 148 46 20.243 W -Polygon 6 70.21 -1944.20 -4866.31 5967151.00 653032.00 70 19 2.002 N 148 45 34.198 W ' G-11 B Fault 1 70.21 -674.83 -3820.31 5968442.00 654051.00 70 19 14.492 N 148 45 3.697 W -Polygons 70.21 -674.83 -3820.31 5968442.00 654051.00 70 19 14.492 N 148 45 3.697 W -Polygon 2 70.21 -1022.78 -3827.63 5968094.00 654051.00 70 19 11.070 N 148 45 3.906 W -Polygon 3 70.21 -1383.26 -3952.25 5967731.00 653934.00 70 19 7.524 N 148 45 7.537 W -Polygon 4 70.21 -1717.98 -4065.32 5967394.00 653828.00 70 19 4.232 N 148 45 10.831 W ~ -Polygon 5 70.21 -1383.26 -3952.25 5967731.00 653934.00 70 19 7.524 N 148 45 7.537 W -Polygon 6 70.21 -1022.78 -3827.63 5968094.00 654051.00 70 19 11.070 N 148 45 3.906 W G-11 B Fault 2 70.21 -1607.10 -7624.03 5967430.00 650268.00 70 19 5.295 N 148 46 54.672 W -Polygon 1 70.21 -1607.10 -7624.03 5967430.00 650268.00 70 19 5.295 N 148 46 54.672 W -Polygon 2 70.21 -1800.48 -7085.94 5967248.00 650810.00 70 19 3.398 N 148 46 38.965 W -Polygon 3 70.21 -1857.47 -6849.07 5967196.00 651048.00 70 19 2.840 N 148 46 32.052 W -Polygon 4 70.21 -1893.40 -6377.69 5967170.00 651520.00 70 19 2.491 N 148 46 18.298 W -Polygon 5 70.21 -1857.47 -6849.07 5967196.00 651048.00 70 19 2.840 N 148 46 32.052 W ! -Polygon 6 70.21 -1800.48 -7085.94 5967248.00 650810.00 70 19 3.398 N 148 46 38.965 W I G-11B Fault3 70.21 -3091.40 -5823.72 5965984.00 652099.00 70 18 50.713 N 148 46 2.107 W -Polygon! 70.21 -3091.40 -5823.72 5965984.00 652099.00 70 18 50.713 N 148 46 2.107 W -Polygon 2 70.21 -2885.98 -5508.31 5966196.00 652410.00 70 18 52.736 N 148 45 52.910 W -Polygon 3 70.21 -2675.86 -5415.86 5966408.00 652498.00 70 18 54.803 N 148 45 50.217 W b ~ BP Alaska p Baker Hughes INTEQ Planning Report u~ a uat Company; BP Amoco Field: Prudhoe Bay Site: PB G Pad Well: G-11 Wellpath: Plan 9, G-118 Targets N D G ame -Polygon 4 -Polygon 5 -Polygon 6 -Polygon 7 -Polygon 8 G-11 B Target 1 G-11 B Target 2 G-11 B Target 4 G-11 B Target 3 escnp on Dip, Dir.. Date:. i/15l2008 Time• 15:56:19 Page: 2 Co-ordinate(NE)Reference: Well: G-11, True North Vertical (TVA) Reference: 17:11 10/30/1993 00:00 70.2 Section (VS)')teference: Well (O.OON,O.OOE,220.OOAzi) Survey Calculation Method: Minimum Curvature Dh: Sybase TVD +N/-S ft ft 70.21 -2626.03 70.21 -2955.86 70.21 -2626.03 70.21 -2675.86 70.21 -2885.98 +E/-W ft -5121.73 -4611.52 -5121.73 -5415.86 -5508.31 Map Map Northing' Fasting ft ft -- - , 5966464.00 652791.00 5966145.00 653308.00 5966464.00 652791.00 5966408.00 652498.00 5966196.00 652410.00 <---- Latitude ----> <--- Longitude ---> Deg Min Sec Deg Min Sec 8525.21 -1497.21 -4621.84 5967603.00 653267.00 9016.21 -1814.67 -4604.51 5967286.00 653291.00 9020.21 -2559.60 -6139.63 5966509.00 651772.00 9032.21 -2153.04 -5494.89 5966929.00 652408.00 70 18 55.295 N 148 45 41.637 W 70 18 52.054 N 148 45 26.746 W 70 18 55.295 N 148 45 41.637 W 70 18 54.803 N 148 45 50.217 W 70 18 52.736 N 148 45 52.910 W 70 19 6.400 N 148 45 27.073 W 70 19 3.278 N 148 45 26.562 W 70 18 55.941 N 148 46 11.336 W 70 18 59.944 N 148 45 52.534 W Annotation f -- MD TVll n ft 10278.33 8461.46 TIP 10350.00 8527.34 KOP 10370.00 8545.52 End of 9 Deg/100' DLS 10470.00 8641.24 4 10670.00 8821.60 5 11140.00 9036.02 End of 20 Deg/100' DLS i 11190.00 9032.10 7 11260.00 9027.38 8 11370.00 9027.32 9 11550.00 9029.56 10 11650.00 9030.36 11 11770.00 9032.56 12 12070.00 9032.99 13 12370.00 9033.34 14 ' 12470.00 9033.04 15 12670.00 9028.19 16 12870.00 0.00 TD Plan Section Information ~ MD Incl Azim TVD +N/-S +E/-W DLS- Build Turn ft deg deg ft fl' ft deg/i00ft deg/100ft degl100ft 10278.33 - 20.79 268.45 -- - 8461.46 -1496.49 -~ __-- -459416 ' e_- 0.00 0.00 - - - 0.00 10350.00 25.53 268.11 8527.34 -1497.34 -4622.33 6.62 6.61 -0.47 10370.00 23.73 268.11 8545.52 -1497.61 -4630.66 9.00 -9.00 0.00 10470.00 11.64 210.14 8641.24 -1507.10 -4656.09 20.00 -12.09 -57.97 10670.00 41.38 133.66 8821.60 -1572.88 -4616.79 20.00 14.87 -38.24 11140.00 93.00 226.31 9036.02 -1925.02 -4691.70 20.00 10.98 19.71 11190.00 95.98 231.53 9032.10 -1957.76 -4729.25 12.00 5.97 10.44 11260.00 91.75 238.80 9027.38 -1997.61 -4786.53 12.00 -6.05 10.39 11370.00 88.32 251.55 9027.32 -2043.68 -4886.15 12.00 -3.12 11.59 11550.00 90.27 273.07 9029.56 -2067.63 -5063.46 12.00 1.09 11.95 11650.00 88.81 261.15 9030.36 -2072.66 -5163.15 12.00 -1.46 -11.91 11770.00 89.10 246.75 9032.56 -2105.74 -5278.15 12.00 0.24 -12.00 12070.00 90.74 282.72 9032.99 -2132.81 -5571.99 12.00 0.55 11.99 12370.00 89.13 246.75 9033.34 -2159.89 -5865.84 12.00 -0.54 -11.99 12470.00 91.22 234.93 9033.04 -2208.52 -5953.01 12.00 2.09 -11.82 12670.00 91.52 210.93 9028.19 -2353.84 -6088.20 12.00 0.15 -12.00 12870.00 91.79 186.92 9022.33 -2541.56 -6152.57 12.00 0.14 -12.00 TFO Target -- _- i deg 0.00 _ _ _ _ _ 358.23 180.00 210.00 270.00 90.00 60.00 120.00 105.00 85.00 263.00 271.00 87.50 267.50 280.00 271.00 271.00 i b # BP Alaska P Baker Hughes INTEQ Planning Report ri.~ ,: 11~ 11J~ Company; BP Amoco Field: Prudhoe Bay Site: PB G Pad Well: G- 11 ', Wellpath: Plan 9, G-11 B Survey MD Incl Azim ft deg deg i 10278.33 20.79 - 268.45 10300.00 22.22 268.33 10325.00 23.88 268.21 10347.64 25.37 268.12 ' 10350.00 25.53 268.11 10370.00 23.73 268.11 10375.00 22.87 266.82 10400.00 18.76 258.76 10425.00 15.17 246.74 10450.00 12.56 228.80 10470.00 11.64 210.14 10475.00 11.68 205.20 ~ 10500.00 13.07 182.62 10525.00 15.96 166.21 10550.00 19.70 155.27 10575.00 23.88 147.87 10600.00 28.32 142.61 10625.00 32.91 138.70 10650.00 37.59 135.66 10670.00 41.38 133.66 10675.00 41.39 135.17 10700.00 41.74. 142.70 10725.00 42.56 150.05 10750.00 43.84 157.11 10775.00 45.54 163.80 10800.00 47.60 170.08 10825.00 49.97 175.93 10850.00 52.63 181.36 10875.00 55.51 186.41 10900.00 58.59 191.11 10925.00 61.82 195.50 10950.00 65.19 199.63 10975.00 68.67 203.54 10994.40 71.43 206.44 11000.00 72.23 207.26 11007.61 73.33 208.36 11025.00 75.86 210.84 11050.00 79.54 214.30 ' 11075.00 83.26 217.68 11100.00 87.00 221.02 11125.00 90.75 224.32 11140.00 93.00 226.31 11150.00 93.60 227.35 11175.00 95.09 229.96 11190.00 i 95.98 231.53 I 11200.00 95.38 232.58 11225.00 93.87 235.18 11250.00 92.36 237.77 11260.00 91.75 238.80 11275.00 91.28 240.54 11300.00 90.50 243.44 11325.00 89.72 246.34 11350.00 88.94 249.23 Date: 1/}5/2008. Time:. 15:56.19 Page: 3 Go-ordinate(NE)Reference: Well: G-11, True North ~ Vertical (TVI)) Reference: 17:11 10/30/1993 00:00 70.2 Section (VS) Reference: Well (O.OON,O.OOE,220.OOAzi) Survey Calculation Method: Minimum Curvature Db: Sybase SS TVD N/S E/W -- MapN - ft ft ft _ft 8391.25 1496.49 -4594.16 5967604.31 8411.41 -1496.71 -4602.10 5967603.92 8434.42 -1497.00 -4611.89 5967603.42 8455.00 -1497.31 -4621.32 5967602.92 8457.13 -1497.34 -4622.33 5967602.86 8475.31 -1497.61 -4630.66 5967602.41 8479.90 -1497.70 -4632.63 5967602.29 8503.27 -1498.75 -4641.43 5967601.05 8527.18 -1500.83 -4648.39 5967598.82 8551.46 -1503.92 -4653.44 5967595.63 8571.03 -1507.10 -4656.09 5967592.40 8575.92 -1507.99 -4656.56 5967591.50 8600.36 -1513.11 -4657.77 5967586.35 8624.57 -1519.28 -4657.08 5967580.20 8648.37 -1526.44 -4654.50 5967573.09 8671.58 -1534.56 -4650.04 5967565.07 8694.03 -1543.56 -4643.74 5967556.20 8715.54 -1553.38 -4635.66 5967546.56 8735.95 -1563.95 -4625.84 5967536.20 8751.39 -1572.88 -4616.79 5967527.46 8755.14 -1575.19 -4614.43 5967525.20 8773.85 -1587.68 -4603.55 5967512.94 8792.40 -1601.64 -4594.28 5967499.19 8810.63 -1616.95 -4586.69 5967484.04 8828.42 -1633.50 -4580.83 5967467.61 8845.61 -1651.17 -4576.74 5967450.03 8862.09 -1669.82 -4574.47 5967431.44 8877.73 -1689.32 -4574.03 5967411.96 8892.40 -1709.50 -4575.42 5967391.75 8906.00 -1730.22 -4578.62 5967370.97 8918.43 -1751.32 -4583.63 5967349.77 8929.58 -1772.64 -4590.39 5967328.32 8939.38 -1794.01 -4598.86 5967306.77 8946.00 -1810.53 -4606.56 5967290.10 8947.75 -1815.28 -4608.96 5967285.30 8950.00 -1821.71 -4612.35 5967278.80 8954.62 -1836.28 -4620.64 5967264.05 8959.95 -1856.86 -4633.79 5967243.21 8963.68 -1876.85 -4648.31 5967222.92 8965.81 -1896.10 -4664.10 5967203.34 8966.30 -1914.48 -4681.04 5967184.61 8965.81 -1925.02 -4691.70 5967173.85 8965.23 -1931.85 -4698.98 5967166.87 8963.34 -1948.31 -4717.69 5967150.02 8961.89 -1957.76 -4729.25 5967140.33 8960.90 -1963.88 -4737.10 5967134.05 8958.88 -1978.57 -4757.22 5967118.94 8957.52 -1992.35 -4778.03 5967104.72 8957.17 -1997.61 -4786.53 5967099.29 8956.77 -2005.18 -4799.47 5967091.45 8956.38 -2016.92 -4821.54 5967079.25 8956.33 -2027.52 -4844.18 5967068.17 8956.63 -2036.98 -4867.32 5967058.23 MapE DLS VS TFO To ft deg/100ft ft deg 653294.65 0.00 4099.44 0.00 MWD 653286.72 6.62 4104.72 358.23 MWD 653276.94 6.62 4111.23 358.34 MW D 653267.52 6.62 4117.53 358.45 G-11 a 653266.51 6.62 4118.20 358.53 MWD 653258.19 9.00 4123.77 180.00 MWD 653256.22 20.00 4125.11 210.00 MWD 653247.44 20.00 4131.57 211.18 MWD I 653240.53 20.00 4137.63 218.73 MWD 653235.55 20.00 4143.24 230.24 MWD 653232.96 20.00 4147.38 247.66 MWD 653232.51 20.00 4148.37 270.00 MWD 653231.41 20.00 4153.06 274.84 MWD 653232.23 20.00 4157.34 296.91 MWD 653234.97 20.00 4161.18 312.81 MWD 653239.59 20.00 4164.53 323.23 MWD 653246.08 20.00 4167.38 330.11 MWD 653254.37 20.00 4169.70 334.83 MWD 653264.40 20.00 4171.48 338.20 MWD ~ 653273.64 20.00 4172.51 340.69 MWD' 653276.05 20.00 4172.76 90.00 MWD 653287.18 20.00 4175.34 88.87 MWD 653296.75 20.00 4180.07 83.23 MWD! 653304.66 20.00 4186.92 77.78 MWD 653310.87 20.00 4195.83 72.63 MWD 653315.32 20.00 4206.75 67.87 MWD 653317.98 20.00 4219.57 63.55 MWD 653318.83 20.00 4234.22 59.69 MWD 653317.87 20.00 4250.57 56.29 MWD 653315.10 20.00 4268.51 53.33 MWD 653310.54 20.00 4287.89 50.77 MWD 653304.23 20.00 4308.56 48.59 MWD 653296.22 20.00 4330.38 46.74 MWD 653288.86 20.00 4347.99 45.21 G-11 a 653286.56 20.00 4353.17 44.22 MWD 653283.30 20.00 4360.27 43.96 G-11 a 653275.33 20.00 4376.76 43.64 MWD 653262.62 20.00 4400.98 42.98 MWD 653248.52 20.00 4425.63 42.24 MWD 653233.14 20.00 4450.53 41.74 MWD 653216.59 20.00 4475.49 41.45 MWD 653206.16 20.00 4490.41 41.39 MWD 653199.02 12.00 4500.33 60.00 MWD 653180.66 12.00 4524.97 60.06 MWD 653169.30 12.00 4539.63 60.26 MWD 653161.59 12.00 4549.37 120.00 MWD 653141.78 12.00 4573.56 120.10 MWD 653121.27 12.00 4597.49 120.31 MWD 653112.88 12.00 4606.98 120.45 MWD 653100.10 12.00 4621.10 105.00 MWD 653078.29 12.00 4644.27 105.05 MWD ' 653055.88 12.00 4666.95 105.09 MWD 653032.95 12.00 4689.06 105.10 MWD b # BP Alaska ~ ~ p Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 1 /1 512 0 0 8 Time: 15:56x9 Page: 4 Field: Prudhoe Bay Co-ordinate(NE}Reference: Well: G -11, True North i Site: PB G Pad Vertical (TVI)) Reference: 17:11 10/30/199 3 00:00 70. 2 We1L• G-11 Section (VS) Reference: Well (O .OON,O.OOE,220.OOAz i) Wellpath: Plan 9, G-11 B Survey Calculation Method: Minimu m Curvatu re Db: Sybase Survey MD Lucl Azim SS TVD ' N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ' ft ft ft degll QOft ft deg 11370.00 88.32 251.55 8957.11 -2043.68 -4886.15 5967051.13 653014.26 12.00 4706.31 105.06 MWD1 11375.00 88.37 252.15 8957.25 -2045.24 -4890.90 5967049.47 653009.54 12.00 4710.55 85.00 MW D 11400.00 88.63 255.14 8957.90 -2052.28 -4914.88 5967041.93 652985.72 12.00 4731.36 84.98 MWD ~ 11425.00 88.90 258.13 8958.44 -2058.06 -4939.19 5967035.65 652961.54 12.00 4751.41 84.90 MWD 11450.00 89.17 261.12 8958.86 -2062.56 -4963.77 5967030.63 652937.05 12.00 4770.66 84.84 MWD 11475.00 89.44 264.10 8959.17 -2065.77 -4988.56 5967026.89 652912.34 12.00 4789.06 84.79 MWD 11500.00 89.72 267.09 8959.35 -2067.69 -5013.48 5967024.45 652887.47 12.00 4806.55 84.75 MWD 11525.00 90.00 270.08 8959.41 -2068.31 -5038.47 5967023.31 652862.50 12.00 4823.09 84.73 MWD 11550.00 90.27 273.07 8959.35 -2067.63 -5063.46 5967023.47 652837.50 12.00 4838.62 84.72 MWD 11575.00 89.91 270.09 8959.31 -2066.94 -5088.45 5967023.63 652812.51 12.00 4854.16 263.00 MWD ~ 11600.00 89.54 267.11 8959.43 -2067.55 -5113.44 5967022.49 652787.54 12.00 4870.69 263.00 MWD 11625.00 89.18 264.13 8959.71 -2069.46 -5138.36 5967020.06 652762.66 12.00 4888.17 263.01 MWD 11650.00 88.81 261.15 8960.15 -2072.66 -5163.15 5967016.34 652737.95 12.00 4906.56 263.04 MWD 11675.00 88.87 258.15 8960.66 -2077.15 -5187.73 5967011.33 652713.47 12.00 4925.80 271.00 MWD 11700.00 88.92 255.15 8961.14 -2082.92 -5212.05 5967005.05 652689.28 12.00 4945.85 271.06 MWD 11725.00 88.98 252.15 8961.60 -2089.95 -5236.03 5966997.52 652665.45 12.00 4966.65 271.12 MWD 11750.00 89.05 249.15 8962.03 -2098.23 -5259.62 5966988.74 652642.05 12.00 4988.15 271.17 MWD 11770.00 89.10 246.75 8962.35 -2105.74 -5278.15 5966980.85 652623.68 12.00 5005.82 271.22 MWD 11775.00 89.13 247.35 8962.43 -2107.69 -5282.75 5966978.81 652619.12 12.00 5010.27 87.50 MWD 11800.00 89.26 250.35 8962.78 -2116.70 -5306.07 5966969.30 652596.00 12.00 5032.16 87.49 MWD 11825.00 89.39 253.35 8963.07 -2124.49 -5329.82 5966961.02 652572.42 12.00 5053.39 87.45 MWD 11850.00 89.53 256.34 8963.31 -2131.02 -5353.94 5966953.98 652548.44 12.00 5073.91 87.41 MWD . 11875.00 89.67 259.34 8963.49 -2136.29 -5378.38 5966948.20 652524.12 12.00 5093.65 87.38 MWD 11900.00 89.80 262.34 8963.60 -2140.27 -5403.06 5966943.70 652499.53 12.00 5112.56 87.36 MWD 11925.00 89.94 265.34 8963.66 -2142.95 -5427.91 5966940.50 652474.74 12.00 5130.59 87.35 MWD 11950.00 90.08 268.33 8963.65 -2144.33 -5452.87 5966938.59 652449.82 12.00 5147.69 87.34 MWD 11975.00 90.22 271.33 8963.58 -2144.41 -5477.87 5966937.99 652424.83 12.00 5163.81 87.34 MWD 12000.00 90.36 274.33 8963.46 -2143.17 -5502.83 5966938.70 652399.85 12.00 5178.92 87.35 MWD ~ 12025.00 90.50 277.32 8963.27 -2140.64 -5527.70 5966940.71 652374.93 12.00 5192.96 87.37 MWD 12050.00 90.63 280.32 8963.02 -2136.80 -5552.40 5966944.03 652350.16 12.00 5205.90 87.39 MWD 12070.00 90.74 282.72 8962.78 -2132.81 -5571.99 5966947.61 652330.49 12.00 5215.44 87.42 MWD 12075.00 90.71 282.12 8962.72 -2131.73 -5576.88 5966948.58 652325.58 12.00 5217.75 267.50 MWD 12100.00 90.58 279.12 8962.44 -2127.13 -5601.45 5966952.67 652300.93 12.00 5230.01 267.49 MWD 12125.00 90.45 276.12 8962.21 -2123.81 -5626.22 5966955.46 652276.09 12.00 5243.40 267.46 MWD 12150.00 90.31 273.13 8962.05 -2121.80 -5651.14 5966956.95 652251.14 12.00 5257.87 267.43 MWD 12175.00 90.18 270.13 8961.94 -2121.09 -5676.12 5966957.14 652226.15 12.00 5273.39 267.41 MWD 12200.00 90.04 267.13 8961.89 -2121.68 -5701.11 5966956.01 652201.17 12.00 5289.91 267.40 MWD 12225.00 89.90 264.14 8961.90 -2123.59 -5726.04 5966953.59 652176.30 12.00 5307.39 267.39 MWD 12250.00 89.77 261.14 8961.98 -2126.79 -5750.83 5966949.86 652151.58 12.00 5325.78 267.39 MWD 12275.00 89.63 258.14 8962.11 -2131.28 -5775.42 5966944.85 652127.09 12.00 5345.03 267.40 MWD 12300.00 89.50 255.14 8962.30 -2137.06 -5799.74 5966938.57 652102.90 12.00 5365.08 267.42 MWD 12325.00 89.37 252.15 8962.54 -2144.10 -5823.72 5966931.03 652079.07 12.00 5385.89 267.44 MWD 12350.00 89.23 249.15 8962.85 -2152.38 -5847.31 5966922.25 652055.67 12.00 5407.39 267.47 MWD ' 12370.00 89.13 246.75 8963.13 -2159.89 -5865.84 5966914.36 652037.30 12.00 5425.06 267.51 MWD 12375.00 89.23 246.16 8963.21 -2161.88 -5870.42 5966912.26 652032.76 12.00 5429.53 280.00 MWD 12400.00 89.76 243.21 8963.43 -2172.57 -5893.02 5966901.10 652010.40 12.00 5452.25 280.01 MWD i 12425.00 90.28 240.25 8963.42 -2184.41 -5915.03 5966888.80 651988.64 12.00 5475.47 280.03 MWD 12450.00 90.80 237.30 8963.18 -2197.37 -5936.41 5966875.40 651967.54 12.00 5499.13 280.03 MWD 12470.00 91.22 234.93 8962.83 -2208.52 -5953.01 5966863.91 651951.18 12.00 5518.34 280.01 MWD 12475.00 91.23 234.33 8962.72 -2211.41 -5957.09 5966860.93 651947.16 12.00 5523.18 271.00 MWD 12500.00 91.28 231.33 8962.18 -2226.51 -5977.00 5966845.42 651927.57 12.00 5547.55 270.99 MWD 12525.00 91.32 228.33 8961.61 -2242.63 -5996.10 5966828.90 651908.82 12.00 5572.17 270.92 MWD b ~ BP Alaska P Baker Hughes INTEQ Planning Report ~%l~ is Company: BP Amoco Field: Prudhoe Bay Site: PB G Pad Weli: G-11 Wellpath: ---- Plan 9, G-11 B Survey Date: 1/15/2008 Time: 15:56:19 Page: 5 Co-ordinate(NE)Reference: Well: G-11, Troe North Vertical (TVD) Reference: 17:11 10/30/1993 00:00 70.2 Section (VS) Reference: Well (O.OON,O.OOE,220.OOAzi) Survey Calculation Method: Minimum Curvature llb: Sybase f Nlll Iucl Azim SSTVD ft deg deg ft _. - -- - - - 12550.00 91.37 225.33 8961.02 12575.00 91.41 222.33 8960.42 ~ 12600.00 91.44 219.33 8959.80 12625.00 91.47 216.33 8959.16 12650.00 91.50 213.33 8958.51 ', 12670.00 91.52 210.93 8957.98 12675.00 91.53 210.33 8957.85 12700.00 91.58 207.33 8957.17 12725.00 91.62 204.33 8956.47 12750.00 91.66 201.33 8955.76 12775.00 91.70 198.33 8955.02 12800.00 91.73 195.32 8954.27 12825.00 91.76 192.32 8953.51 12850.00 91.78 189.32 8952.74 12870.00 91.79 186.92 8952.12 N/S E/W ft ft -2259.72 -6014.33 -2277.75 -6031.63 -2296.66 -6047.97 -2316.39 -6063.30 -2336.91 -6077.57 -2353.84 -6088.20 -2358.14 -6090.75 -2380.03 -6102.80 -2402.52 -6113.68 -2425.55 -6123.38 -2449.05 -6131.85 -2472.97 -6139.09 -2497.23 -6145.06 -2521.77 -6149.75 -2541.56 -6152.57 _..__ MapN - MapE DLS VS TFO -, Tool ft ft deg/100ft - ft deg - 5966811. 43 651890.96 -- - 12.00 - 5596.98 270.85 MWD 5966793. 04 651874.03 12.00 5621.92 270.78 MW D 5966773. 80 651858.10 12.00 5646.90 270.71 MWD 5966753. 74 651843.19 12.00 5671.87 270.64 MWD 5966732. 94 651829.35 12.00 5696.76 270.56 MWD 5966715 .79 651819.08 12.00 5716.56 270.48 MWD 5966711 .43 651816.63 12.00 5721.50 271.00 MWD 5966689 .30 651805.04 12.00 5746.01 270.98 MWD 5966666 .58 651794.63 12.00 5770.24 270.90 MWD 5966643 .36 651785.42 12.00 5794.11 270.82 MWD 5966619 .68 651777.45 12.00 5817.56 270.73 MWD 5966595 .62 651770.72 12.00 5840.53 270.64 MWD 5966571 .24 651765.26 12.00 5862.96 270.55 MWD ~ 5966546 .60 651761.09 12.00 5884.77 270.46 MWD ~ 5966526 .76 651758.68 12.00 5901.74 270.37 2.375' LEGEND aun rra,re tc ~a c e v~veme BP Alaska ~l~ _ G,,,G-"' - G-,11G-1,A) G 1e or - eM BAKER b - PIa~~9 - ro ~~ ~~R~ WELV.TR DETMLE Nuc,NES y ;.r~em ~3a ~~N~~a,.e~ a~ Me~aean~ ~.n, D. EDD=szo,:~o~ NTEQ ~ ~ef I9a„3a,,3=~~ Ema o m<~a<, ~ <rom ra.. rD: mns-oz we. wL~°: +i.+++azanwzoouo io.z.n Y i DFl~n 'IartITVD q « nOW 0L © ~O ' - . Mf N • EM K . 9D.0 ~ ___. 0.00 0.00 0.60 St0A0' f ~ REFERENCE iNFORMAT ON ~ ~ - CoaUineh((N/E)Reference: Well CeMre:G it True NO~in VarLral (TVDI Relerenw: Syafem Mean See Lere ~aao V51R ca-blot- LOODN,O.OOE) _ - --. -.. _. -_ -_ ~ ~ _ - - ~__ T-l .. t) 1 10/30119930000 ]0.21 Mee Ceculaf o~Mef~ on M~-m ~~-C~rvaf~'e . . .. -._...i_--_ . M r r Y i1f0 wa Al fE.~ TrOn ~aoo .. ~ - ~.~Y I ~~ 11 ° 7 .,,.. ,..a e.... ~.. o 0 o 0 - - ~ ,~: ,..n _ a o ~ - ~ _ ~ ...o...f.Na q ~ ~ j _ ` - o ~ M - - - = -. . nra rN .n ' v~ ~ L,, . -zmo-+.. 0 _ ., Dw.aa~ af.. e _- _. --_. - __- , ~ I - az. D.a,.D r, h a Li .~,.,. ,a.,a m ,. ... ,a.. D ,. - ~ .f. E D.,,. -. __ -_- .~- _ J ~. -- _ __ . .~_ ~ - ,.. a.aa . _ - - ~~ -- + . .. ~ .., ._. , a _. - - _ - _ ._~ - EM.f. „Da o ~ , - --- - ~ 1 _ 4, ~. ~-T- T--+ ,-~ _, ~ , ~ - ,_ ,- ,~ , - i L_ _ - - - - _ - ~~_ o ,~ ~ .1 i - - - ~ - -- -- _ o ,.aa .am .,m < . ,m maa .aaoo _ _~ ~- . o =,oo m <am a~ a.m bma b,m d,m ~m ~am 3,oa sm .~aoo ~weat[-ueaat[., [,o0tt,~n~ .am „m .am am raa - . ~ r~ ~ ~ r_ ; ~ a„ ~ _ _ ~ ~ _ ~. _ ~ - ~.~. T-- _ , _ - -- _ ' -- , . . . _ . r. . ~1 1 _ T • L D u ~ ~L _ { 1 + ~y _- _ r L1 T __ F ~ 1 a ~ ~ ',,ra _ - .. .« - a -,-T E .o -.- ^ P -. - -.. rm - - ,t -1T- 1-. ~ 1 G .. Ene.y zo novo '~ 0 +a a o ~ _ II _.. _- l ~ ~ _ :~~ 1 ': -- 1 ._ ._ ~- ..r. ~ ~_ -..`. _ - -... _-_-... - _.. -~ ... _ - _ . _ _- _ 1 ~~ __.. _ `- 1 ~ ~ .. _. ILL '. _ _ + .. _ - T 7 i ~ ~_ ~ -. - - ., - .-r ~ ~- ` I ~ _., ___ - aaw .ooo .aw s1m s1w .zm .sm um um .am ..eo .s oo .sso .em .am .gym a,m Vertleal SeetiDn at 220.00' [sottnnl s1m sm sxoo szao sam vs~ saoo sa sa ssm ssm sem saso a,m s~so NDO aem Eam • • i b ~ BP Alaska ~ P Anticollision Report INTEQ Company: BP Amoco ~~~ ~ ~ ~~~~ _. ~ ` Date: 1/18/2008 ~~~ ~~~~Time: 15:20:35 Page: 1 Fieldi Prudhoe Bay Reference Site: PB G Pad Co-ardinate(NE) Reference: WeIL G-11, True North Reference Well: G-11 Vertical (TVD) Reference: 17:11 10/30/1993 00:00 70.2 Reference Wellpath: Plan 9, G-116 Db: Oracle ~ GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'Rfeeells in this~feetdlipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 10350.00 to 12870.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1483.54 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/11/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft --_ - - - - - ~ 105.51 8505.50 1 : Sperry-Sun BOSS gyro multi BOSS-GY RO Sperry-Sun BOSS gyro multi shot 8549.00 10278.33 2 : MWD -Standard (8549.00-12 MWD MWD -Standard 10278.33 12870.00 Planned: P lan #9 V3 MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 12870.00 9022.33 2.375 3.000 2.375" Summary - - - - --- <___~_,_~_________ Offset Wellpath =--------___.___> - Reference "'.Offset ' Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft -- PB D Pad D-07 D-07A V1 Out of range PB F Pad F-26 F-26A V1 10540.72 12345.50 1049.56 721.45 328.11 Pass: Major Risk PB G Pad G-08 G-08 V8 Out of range PB G Pad G-08 G-08A V3 Out of range PB G Pad G-09 G-09 V1 Out of range PB G Pad G-09 G-09A V2 Out of range PB G Pad G-09 G-096 V2 Out of range PB G Pad G-10 G-10 V5 Out of range PB G Pad G-10 G-10A V1 Out of range PB G Pad G-10 G-10B V2 10765.63 11240.38 1459.07 184.99 1274.08 Pass: Major Risk ~ PB G Pad G-10 G-10C V3 Out of range PB G Pad G-11 G-11 V2 12315.89 11425.00 391.66 0.00 391.66 Pass: Minor 1/10 PB G Pad G-11 G-11A V3 10350.00 10350.00 0.00 837.80 -837.80 FAIL: Major Risk PB G Pad G-12 G-12 V1 Out of range PB G Pad G-12 G-12A V1 Out of range PB G Pad G-12 G-126 V4 Out of range PB G Pad G-13 G-13 V1 Out of range PB G Pad G-13 G-13A V5 Out of range PB G Pad G-14A G-14A V1 Out of range PB G Pad G-14 G-14 V1 Out of range PB G Pad G-15A G-15A V1 10712.99 9925.00 694.50 0.00 694.50 Pass: Minor 1/10 PB G Pad G-15 G-15 V1 10775.00 10270.61 753.47 582.45 171.02 Pass: Major Risk PB G Pad G-16 G-16 V1 11032.71 10188.11 1164.90 889.71 275.18 Pass: Major Risk ~ PB G Pad G-19 G-19 V3 Out of range PB G Pad G-19 G-19A V6 Out of range PB G Pad G-19 G-19B V16 11201.56 13225.00 567.40 0.00 567.40 Pass: Minor 1/10 PB G Pad G-21 G-21 V1 Out of range PB G Pad G-21PB1 G-21PB1 V1 11375.00 12450.00 1480.40 882.38 598.01 Pass: Major Risk PB G Pad G-26 G-26 V3 Out of range PB G Pad G-26 G-26A V6 Out of range PB G Pad G-26 G-26B V6 Out of range PB G Pad G-27 G-27 V1 Out of range PB G Pad G-27 G-27A V1 Out of range PB G Pad G-29 G-29 V1 Out of range PB G Pad G-29 G-29A V2 Out of range PB G Pad G-30 G-30 V1 Out of range PB G Pad G-30 G-30A V1 Out of range PB G Pad G-30 G-30B V3 Out of range PB G Pad G-31A G-31A V6 Out of range PB G Pad G-31AP61 G-31AP61 V2 Out of range PB G Pad G-31 G-31 V1 Out of range PB G Pad G-32A G-32A V4 Out of range L PB G Pad G-32 G-32 V1 .,Out of range i • are i of bag . BAG Dowell of bag ps Blind/Shears TOTs middle of pipes 2~~ combi pipe/slips Mud Cross I I Mud Cross of flow cross middle of blind/shears 2 3/$~~ combi pipe/slip TOTs of pipe/slips 2~~ combi pipe/slips Swab Flow Tee Alaska Department of Natural Resources Land Administration System Page 1 of 4 i M ~~;r , `1'..i . ; :is ~. Borders Spar<~i~ State Ga6ins ~1~l:ur~ ~~s+~~r+c~es S C ___ File Type: A~~ File Number:. 28240 -Printable Case Fiie_Summary See Township, Range, Section and Acreage? ~ Yes NO New Search t_,AS I*Jlenu I Case Abstract I Case Detail I Land Abstract ltle: ADL ?ti1411 `~"' Searrl~ for St~~tus P13t_U~cf~tr.s 1> cif 0~%'??'2008 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case Type: ~~~t OIL 8i GAS LEASE COMP DNR Unit: 780 OIL AND GAS .File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: OS/28/196~ Office of Primary Responsibility: DOG DN OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype : ~S NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED J~Ic~t~ic/iaji.~ l ~ Township: O1 ~N Range: O1 LE tie~~tr<~n: 0l ,S'rc[Inn Acres: 640 Search Plays :~le'i'Icilclll: ~ TDYt~UC~~RIJ: 01 ~ ~ IZLm~'L': 01 1 E .~CClll)11: 02 :~Cc"1lUn .~iCi'eS': 640 ME'i'l~~l(!!1: U I'oYPn.~'~IlJ7: ~)~ ~~~ ~LXn~2: 01 ~ ~ .~t'ClIUI7: ~ ~ .~~~'i'!/(~)7.ICi'NS'.~ (~-~~) l~erZdlCl/7: ~ ~ iO14n~{]1~~.' ~) ~ ~ 1\i 1\Ull~'c'.~ ~) ~ ~ ~_ ~tiec'/lUn.' ~ ~ ,~('CIIQ7?r~t'1'CS: O~~) Legal Descripiion 0~ -?8-196 * ~` *SALE NOTICE L EGAL DESCRIPTION* C1=i-I9 OIIN-011E-UM 1,2,11,12 260.00 0=1-01-19?7 * ~ UNITIZED,LEASE ~iND PARTfCIPATING AREA LEGAL DESCRIPTION* LEASE COIL~MITTED IN ENTIRETY TO PRUDHOE 13AY UNIT AND OIL RIM GAS CAP PA PRUDNOE&AY UNIT http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 2/22/2008 'Alaska Department of Natural Resources Land Administration System Page 2 of 4 • TR4 CT ~ 0 OIL IZIMAND GAS C'AP PARTICIPATING AREAS T. 11 N., R. II E., UMIAT MERIDIAN, ALASI~1 SECTION 1: ALL, 640.00 ACRES; SECTION ?: ALL, 640.00 ACRES; SECTION II:.ALL, 6=10.00 ACRES: SECTION 12: ALL, 6=10.00 ACRES; CONTAIMNG APPROXIMATELY 2, 560.00 ACRES, MORE OR LESS. :k~~k:g;kz~~k********~#*~k~x;k##~~k~~*#~~ <*~,#*#~~**~k*;kx~;k >k~~k ~k~~k ~k*x*~~*~*x~>;c*#~ 11-01-?001 *'~FORMATION OF BOREALIS PARTICIPATING AREA LEGAL DESCRIPTION LEASE INCORPORATED IN PART INTO THE I3PA * ~` PRUDHOE 13AY UNIT BOREALIS PARTICIPATING AREA TRACT 50 (PARTIAL) T.11 N., R.11 E., UMIAT MERIDIAN, AI ASKA SECTION 1: W2. W2E2, 480.00 ACRES: SECTION 2: ALL, 640.00 ACRES, SECTION 11: N2, N2S2, 480.00 ACRES, SECTION 12: NW4, W2NE4. 210.00 _ACRES; THIS TRACT CONTAINS 1, 8=10.00 ACRES, MORE OR LESS. ~k**%k~~**~~*~k;k~.k*~=kx.k~x=k**:k;k*##*~~k~k:k~~k*#~#**~~k**x***~;k,k~~k <#>;:x~~#**~x~x* 0~-01-2004 "~FORILIATION OF ORLON PARTICIPATING AREA LEGAL DESCRIPTION* LEASE COMMITTED IN PART TO ORLON PARTICIPATING AREA PRUDHOE BAY UNIT TRACT~0 ORLON PARTICIPATING AREA T 11 N, R. I l E., U~I~IIAT MERIDIAN, ALASfiA http://www.dnr. state. ak.us/Las/Case_Summary. cfm?FileType=ADL&FileNumber=28240&... 2/22/2008 Alaska Department of Natural Resources Land Administration System Page 3 of 4 • SECTION 1: _ALL, 640. UO ACRES, SECTION 2: ALL, 640.00 ACRES, SEC'"LION 11: El/?, EI/2NW1/=1, 400.OOACRES; SECTION 12: ALL, 640.00 ACRES, CONTAINING APPROXIMATELY 2, 320.00 ACRES, 11%IORE OR LESS. 1 ?-01-2004 * * * *BOREALIS PA E.~PANDED, LEASE INCORPORATED IN PART *"'~` * ~ * * ~` LEGAL DESCRIPTION IS AS FOLLOWS: PRUDHOE BAY UNIT BOREALIS PARTICIPATING AREA TRACT ~0 (PARTIAL) T.11 N., R. I1 E., U1l~IIAT MERIDIAN, ALASKA SECTION 1: E2E2, 160.00 ACRES; SECTION 11: S2SE4, 50.00 ACRES: SECTION 12: S2, E2NE4, 400.00 ACRES: THIS TRACT CONTAINS 640.00 ACRES, MORE OR LESS. * *THE ACREAGE NOW INCORPORATED INTO 'THE 13PA IS DESCRIBED AS FOLLOWS: PRUDHOE BAY UNIT BOREALIS PARTICIPATING AREA TRACT ~0 (PARTIAL) 7:IIN, T IIE., UMIATMERIDIAN, ALASKA SECTION 1: ALL, 6-10.00 ACRES; SECTION 2: ALL, 640.00 ACRES; SECTION 11: N2, SE4, N2SW4, ~ 60 ACRES,' SECTION 12: AIL, 640.00 ACRES; http://www.dnr. state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 2/22/2008 Alaska Department of Natural Resources Land Administration System Page 4 of 4 THLS' TR4CT CONT,4Tl~S Z-180.00 ~1CIZFS, Il10RE OR LESS. :~x:~:<X~r~~*>;<xY-r-*x=k~~x~:;<:~a<;~ ~:k*x~x~k:e*~~;<~k~~:~:k~~~*~ < <a~;;:x~>•,<~:;<xk~:<~~:~;:~~;< <~k*kx Last updated on 02/22/2008. Not sure who to contact? Have a question about DNR? Visit the Public Infcsra~t~a Center. Report technical problems with this page to the Nfebrnaster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all C(~C3~CIE must be accepted. State of Alaska Natural_Resources LAS Hame Copyright Privacy System Status http: //www.dnr. state.ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28240&... 2/22/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~.~~ ~-If~ PTD# c~?D(J'~o~ /Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~ieL?D.~o~ /~y POOL: /~,~'L!/Jis~OE /3Ay Q t \ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing L ~ I program. Rev: 1!11/2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOEOlL-640150 ___Well Name: PRUDHOE BAY UNIT G-116 __._ Program DEV __ Well bore seg ^ PTD#: 2080270 Company BP EXPLORATION (AtA$KA) INC __ Initial ClassRype _ DEV 1 PEND _ GeoArea 890 Unit 11650 __ On/Off Shore On Annular Disposal ^ Administration 1 Permit_fee attached - -- - NA 2 Lease number appropriate- - - Yes 3 Unique well-name and number____________________________ _______._ Yes_ -__---__-__ --------------------------------------------------------------- 4 Well located in_a_defined_pool- Yes - - - - ..Prudhoe Bay Field!_Prudhoe Ba-y Oil_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 5 Well located proper distance from drilling unit_boundary- - Yes ~ 6 Well located proper distance from other wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ ~ 7 Sufficient acreage-availablein-drillingunit_____________________ ______ ____ Yes_ --_---2560 acres________-__....---__--_--_. ' 8 Ifdeyiated, is_we_Ilbore plat_included _ _ - Yes _ _ _ 9 Operator only affected party_ Yes 10 Opera#orhas-appropriate-bond inforce----------------------- ----------Yes_ -___„BalnketBond#6194193..__..__.__-___.--..-..-_-__--.-_..--..----___-.-_.. 11 Permit can be issued _w_ithout conservation order_ _ _ _ _ _ _ _ _ _ _ _ _ _ „ - - _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ . Appr Date 12 Permit can be issued _w_ithout administrativ_e.approyal - - - - - . - . _ - Yes . - - . 13 Can permit be approved before 15-day wait Yes ACS 2/22/2008 14 Well located within area and-strata authorized by Injection Orde[ # (put 10# in _comments)_ (For_ NA_ _ - . - . 15 All wells_within 1!4_mile area_of review identified (For service well only)_ _ - _ _ - _ _ _ _ NA_ _ _ _ - - . _ - . 16 Pre-produced injector: duration_ofgre-production less than 3 months_ (For-service well only) NA_ - - - 17 Nonconyen: gas conforms to AS31.05:030(j.1_.A),(1.2.A-D) - NA - - - Engineering 18 Conductor string provided NA_ Conductorset_inG-11_(1.81-050).- 19 _Surfacecasingprotects allknown USDWS _ _ _ _ _ _ _ _ . NA- - _ _ _ All aqufers exempted AE01__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 20 CMT-v_ol adegua#e-to circulate-on conductor & surf_csg _ _ _ _ - NA - - . - _ Surface casing set in G-11. - _ - - _ _ - - _ - 21 CMT-v_ol adequate_to tie-in long string tosurf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ Production casing set in-G-11. _ _ _ _ - . _ _ _ _ _ 22 _C_MT will cover-all known-productive horizons- - - - Yes X 23 Casing designs adequate for C,_T, B & permafrost_ _ _ . _ _ _ _ _ .. - _ _ _ _ Yes - - - - - - - - - - - - - _ .. - - - - 24 Adequate tankage-or reserve pit - . Y_es Rig equipped with steel pits. No reserve pit planned. All waste_to approved disposal well(s). 25 If-a-re-drill, has.a 10-403 forabandonment been approved - - . _ _ _ _ _ _ _ _ - Yes - 308-062 - - - 26 Adequate.wellbore separationproposed- - _ _ _ _ _ - - - - - - - - - - - - -- - - - - Yes . . - - .. -Proximity analysis performed, Nearest segement_is abandoned portion of G-11A and paths diverge.- . _ - .. - - . 27 If diverter required, does it meet regulations- - _ NA_ BOP stack will already_be in place, - - - _ - - - Appr Date 28 Drilling fluid_ program schematic_& equip list.adequate_ Yes ... Maximum expected fo[mation pressure 7,0_ EMW, MW planned 8.6 ppg. - TEM 2/25!2008 29 BO_PES,-do they meet regulation - - Yes ~~~ 30 BOPE-press rating appropriate; test to-(put prig in comments)_ - _ Yes _ _ _ _ MASP calculated at 2349 psi. 3500_psi BOP test,planned: _ _ _ _ _ _ P 31 Choke_manifold complies wlAPt RP-53 (May 84)_ Yes 32 Work will occur without operation shutdown- Yes 33 Is presence of H2S gas probable- . - - Yes . . - - H2S is reported_at G_pad._ Mud should p[eclude_ H2S_on-rig: Rig-has sensors and_ alarms._ .... - - - - - '34 Mechanical-condition of wells within AOR verified (For service well only) NA- - Geology 35 Permit can be rssued w!o hydrogen- sulfide measures - - - _ No- G pad max H2s = 25ppm Well G-Q2-(6/11/06) 36 Data_presented on potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - . _ Appr Date 37 Seismic analysis ofshallow gas_zones - _ NA ACS 2122!2008 38 Seabed condition survey_(ifoff-shore) IdA- ,39 Contact namefphone for weekly_progress reports (exploratory only] - - _ Yes . .... -Abby Warren - 564-5480 Geologic Engineering Date Date: Date Commissioner: mmiss Commissioner: ~~~.~ z zs fl~ L -~ Z- ~-0 ~ Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efiforl has been made to chronologically organize this category of information. ~~ **** REEL HEADER **** MWD 08/06/20 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/03/30 1893161 Ol 2.375" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 10250.0000: Starting Depth STOP.FT 12830.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: G-11B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 21.139"N 148 deg 43' 12.211"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 16 Mar 2008 API API NUMBER: 500292058302 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 12 TOWN.N T11N RANG. R13E PDAT. MSL EPD .F 0 LMF DF FAPD.F 70.21 DMF DF EKB .F 0 EDF .F 70.21 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks Description Section Township. Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and. a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 01 Apr 2008 per the request of Mike McTeague with BP Exploration (Alaska), Inc. (8) Tied to G-11A at 10261 feet MD (8375.8 feet TVDSS). (9) The sidetrack was drilled from G-11 through a milled window in 3 1/2 inch and 7 inch liner. Top of window 10355.0 ft.MD (8534.2 ft.TVDSS) Bottom of window 10363.5 ft.MD (8542.0 ft.TVD55) (10) The interval from 12806 feet to 12829 feet MD (8951.2 feet to 8952.1 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m ohm.m ohm.m ohm.m RACLX -> Resistivity (AT)(LS) 400kHz-Compensated Borehole Corrected, RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, TVD -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 10259.3, 10259.5, ! 0.207031 10262, 1 0261.8, ! -0.208008 10263, 1 0262.8, ! -0.207031 10270.7, 10271.3, ! 0.62207 10274.4, 10275.2, ! 0.829102 10280.6, 10279.8, ! -0.829102 10290.4, 10288.5, ! -1.86621 10294.1, 10292, ! -2.07324 10298, 1 0296.6, ! -1.95117 10301.6, 10299.3, ! -2.28027 10304.7, 10302.6, ! -2.07227 10307.2, 10308, ! 0.829102 10312.1, 10312.1, ! 0 10322.3, 10318.4, ! -3.93945 10325.1, 10321.2, ! -3.93848 10327.6, 10325.1, ! -2.4873 10337.7, 10335.2, ! -2.4873 10344.2, 10344.6, ! 0.414062 10347.5, 10347.9, ! 0.415039 10351.4, 10352, ! 0.62207 10357.6, 10358.7, ! 1.03711 10362.8, 10363, ! 0.207031 10365.7, 10365.9, ! 0.207031 10367.5, 10368.1, ! 0.62207 10375.6, 10376.4, ! 0.829102 10406.9, 10407.7, ! 0.829102 10413.1, 10413.9, ! 0.829102 10415.1, 10416.6, ! 1.45117 10419.5, 10420.1, ! 0.62207 10431.5, 10432.9, 10436.4, 10437.7, 10453.2, 10454.6, 10456.5, 10457.9, 10461.9, 10463.3, 10481, 10482.4, 10504, 10505.6, 10508.5, 10509.6, 10538.6, 10540.1, 10601.9, 10604.4, 10620.1, 10623, 10632.8, 10635.5, 10648.8, 10651.9, 10658.9, 10662.9, 10691, 10685.6, 10693.7, 10687.7, 10694.3, 10689.3, 10696.2, 10692.2, 10698.7, 10695.6, 10700.7, 10698.9, 10707.6, 10707.2, 10710.5, 10710.9, 10718.6, 10718, 10732.1, 10731.3, 10733.5, 10732.9, 10741.8, 10742, 10774.9, 10774.5, 10798.4, 10797.3, 10802.7, 10802.1, 10809.1, 10807.7, 10814.1, 10812.5, 10817.8, 10816.8, 10820.7, 10821.6, 10827.6, 10826.8, 10833.8, 10831.9, 10843.5, 10842.5, 10848.5, 10848.5, 10851.8, 10851.6, 10854.5, 10854.9, 10858.5, 10858.9, 10863.6, 10863.4, 10870.3, 10870.1, 10875.7, 10873.2, 10877.5, 10875.7, 10880.4, 10879, 10886.6, 10885.8, 10902.1, 10900.3, 10908.8, 10907.9, 1091.9.1, 10917.3, 10926, 10924.1, 10929.5, 10926, 10932.2, 10930.1, 10946.9, 10945.2, 10950.2, 10948.3, 10952.7, 10953.1, 10955.8, 10954.9, 10984, 10984.2, 10988.3, 10987.7, 10995.6, 10996.2, 10999.2, 10999.2, 11014, 11014.2, 11022.5, 11021.6, 11027, 11026.4, 11030.6, 11031.1, 11036, 11035.2, 11056.2, 11055, 11071.6, 11071.2, 1.45117 1.24316 1.45117 1.4502 1.45117 1.4502 1.65918 1.03711 1.45117 2.4873 2.90137 2.69434 3.10938 3.93848 -5.38965 -6.01172 -4.97559 -3.93848 -3.10938 -1.86523 -0.414062 0.414062 -0.62207 -0.829102 -0.62207 0.207031 -0.415039 -1.03613 -0.62207 -1.45117 -1.65918 -1.03711 0.829102 -0.829102 -1.86523 -1.03711 0 -0.208008 0.415039 0.415039 -0.207031 -0.207031 -2.48828 -1.86523 -1.45117 -0.829102 -1.86621 -0.830078 -1.86523 -1.86523 -3.52441 -2.07227 -1.6582 -1.86523 0.414062 -0.829102 0.208008 -0.62207 0.621094 0 0.208008 -0.829102 -0.621094 0.415039 -0.829102 -1.24316 -0.414062 11080.9, 11079.7, 11087.1, 11085.2, 11099.3, 11097.4, 11118.1, 11115.8, 11122.5, 11119.6, 11132.8, 11131, 11143.2, 1.1142.1, 11148.6, 11149.4, 11170.4, 11167.3, 11182.4, 11181, 11189, 11188, 11244.2, 11247.7, 11261.1, 11259.2, 11264.2, 11262.1, 11268.1, 11265.7, 11276.7, 11274.7, 11318.4, 11316.5, 11321.1, 11319.7, 11327.1, 11325.5, 11334.6, 11332.1, 11339.1, 11336.6, 11341.8, 11340, 11355.3, 11351, 11390.4, 11391, 11430.4, 11431.5, 11440.8, 11441.4, 11445.6, 11445.6, 11501.2, 11501.8, 11508.2, 11508.6, 11513, 11514.8, 11516.9, 11518.6, 11519.8, 11522.1, 11525, 11528.1, 11531.6, 11535.1, 11551.9, 11554.4, 11554.6, 11557.1, 11556.2, 11560, 11559.3, 11563.9, 11566.6, 11570.1, 11569.7, 11573.2, 11577.8, 11580.1, 11624.2, 11623.2, 11628.1, 11627.1, 11644.5, 11644.1, 11657.2, 11655.9, 11662.6, 11663.4, 11664.4, 11665, 11674, 11674.4, 11678.8, 11677.8, 11686.3, 11687.1, 11692.4, 11692.4, 11694, 11694.4, 11698, 11698, 11706.8, 11705.6, 11720.8, 11723.1, 11754.5, 11758.3, 11757, 11762, 11760.6, 11765.1, 11768.8, 11769.7, 11781.5, 11783.7, 11814.4, 11816.5, 11822.3, 11823.1, 11824.2, 11826.2, 11829.3, 11830.2, 11833.7, 11833.9, 11837.6, 11836.7, 11848.4, 11847.7, -1.24414 -1.86523 -1.86523 -2.28027 -2.90137 -1.86523 -1.03711 0.829102 -3.10938 -1.4502 -1.03613 3.52344 -1.86621 -2.07324 -2.4873 -2.07324 -1.86523 -1.45117 -1..6582 -2.4873 -2.4873 -1.86621 -4.35254 0.62207 1.03613 0.62207 0 0.621094 0.414062 1.86523 1.6582 2.28027 3.10938 3.52441 2.4873 2.4873 3.73145 4.56055 3.52441 3.52441 2.28027 -1.03711 -1.03711 -0.414062 -1.24414 0.829102 0.62207 0.415039 -1.03711 0.829102 0 0.415039 0 ! -1.24316 ! 2.28027 ! 3.73145 4.97461 ! 4.56055 ! 0.829102 ! 2.28027 ! 2.07324 ! 0.829102 ! 2.07227 ! 0.829102 ! 0.207031 ! -0.829102 ! -0.62207 • 11850.2, 11851.7, 11853.6, 11853.8, 11859.7, 11859, 11865.7, 11864.8, 11867.7, 11866.7, 11869.2, 11868.4, 11875.4, 11875.6, 11876.6, 11877.9, 11879.6, 11879.1, 11884.3, 11885.6, 11895.5, 11896.5, 11897.9, 11899.2, 11904.2, 11903.1, 11908.7, 11908.3, 11916.6, 11913.5, 11926.1, 11923, 11929, 11924.9, 11931.1, 11927, 11980.8, 11981.3, 11983.3, 11984, 11985.6, 11985.2, 11987.1, 11987.1, 11990.2, 11990.2, 12001.8, 12000.5, 12010.7, 12010.5, 12074.5, 12073.2, 12076.7, 12075.3, 12080.5, 12079.2, 12087.9, 12086.1, 12091.3, 12089.6, 12092.7, 12091.7, 12096.9, 12095.2, 12104.3, 12103.7, 12114.5, 12112.9, 12199.8, 12198.1, 12257.7, 12260.4, 12336.7, 12335.1, 12343, 12340.3, 12346.5, 12343.2, 12350.8, 12348.4, 12356, 12355, 12358.7, 12359.6, 12365.4, 12366.4, 12370.5, 12369.5, 12384, 12382.1, 12385.7, 12384.2, 12392, 12393.1, 12401.2, 12399.1, 12431.2, 12429.3, 12435.6, 12434.5, 12444.3, 12443, 12491.6, 12484.6, 12493.3, 12487.5, 12497.6, 12490.6, 12502.4, 12498, 12510.5, 12508.6, 12515.7, 12514, 12523.5, 12520.8, 12527.7, 12525, 12532.5, 12528.9, 12542.4, 12539.3, 12573.7, 12568.5, 12578.3, 12572.9, 12582.4, 12578, 12585.9, 12580.3, 12588, 12583.6, 12594.3, 12590, ! 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BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 321 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN G-11B 5.xtf LCC 150 CN BP Exploration (Alaska) Inc. WN G-11B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log prodived by Schlumberger GR CNL dated O1 Apr 2008 per the request of Mike McTeague with BP Exploration (Alaska), Inc. *** INFORMATION TABLE: LIFO MNEM CHAN DIMT CNAM ODEP GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 62 1 Size Length 4 4 4 4 8 Tape File Start Depth = 10250.000000 Tape File End Depth = 12829.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 71 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU WDFN G-11B.xtf LCC 150 CN BP Exploration (Alaska) WN G-11B APIN FN Prudhoe Bay Unit COUN North Slope STAT Alaska *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 8 Total Data Records: 123 Tape File Start Depth = 10250.000000 Tape File End Depth = 12828.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 132 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/03/30 1893161 01 **** REEL TRAILER **** MWD 08/06/20 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP 10250.0000 -999.2500 -999.2500 10250.5000 -999.2500 -999.2500 10300.0000 62.4564 -999.2500 10400.0000 37.2598 81.3400 10500.0000 20.8134 26.4599 10600.0000 23.5525 34.8000 10700.0000 31.9487 14.6628 10800.0000 38.9045 57.0337 10900.0000 62.5194 90.6442 11000.0000 74.4470 83.1893 11100.0000 76.9081 101.7088 11200.0000 50.6945 97.9910 11300.0000 49.6114 94.5397 11400.0000 60.7107 88.6322 11500.0000 43.2231 84.0776 11600.0000 32.9084 49.5637 11700.0000 85.8248 73.9524 11800.0000 39.0399 101.0000 11900.0000 78.3230 33.7367 12000.0000 55.5096 83.8484 12100.0000 56.9417 64.4590 12200.0000 46.4813 114.9660 12300.0000 42.2435 131.0910 12400.0000 41.6241 142.2188 12500.0000 75.7285 139.8847 12600.0000 130.6856 49.2759 12700.0000 72.9118 104.8703 12800.0000 46.0199 237.3002 12829.0000 -999.2500 -999.2500 Tape File Start Depth = 10250.000000 Tape File End Depth = 12829.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP 10250.0000 -999.2500 -999.2500 10250.2500 33.1000 -999.2500 10300.0000 59.9000 -999.2500 10400.0000 39.4000 80.5000 10500.0000 23.3000 29.9000 10600.0000 22.1000 34.8000 10700.0000 28.8000 34.5000 10800.0000 41.2000 56.3000 10900.0000 42.6000 91.6000 11000.0000 74.4000 83.2000 11100.0000 76.1000 102.9000 11200.0000 51.0000 97.8000 11300.0000 59.1000 97.3000 11400.0000 68.6000 55.2000 11500.0000 45.0000 99.7000 11600.0000 32.1000 50.1000 11700.0000 92.9000 74.9000 11800.0000 41.3000 104.8000 11900.0000 76.2000 31.1000 12000.0000 48.7000 84.5000 12100.0000 60.7000 70.6000 12200.0000 52.8000 103.1000 12300.0000 43.0000 126.3000 12400.0000 49.0000 125.6000 12500.0000 63.7000 145.1000 12600.0000 177.1000 41.8000 12700.0000 57.2000 108.0000 12800.0000 45.5000 165.4000 12828.7500 -999.2500 -999.2500 Tape File Start Depth = 10250.000000 Tape File End Depth = 12828.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet Tape Subfile 4 is type: LIS
