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Development Exploratory Service 5 Permit to Drill Number:210-077 6.50-029-20435-02-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12003 11200 9037 10155 11200, 11795 11200 8860 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 40 - 120 40 - 120 1490 470 Surface 2641 13-3/8" 39 - 2680 39 - 2680 5380 2670 Intermediate 7363 9-5/8" 37 - 7400 37 - 6463 6870 4760 Liner 3054 7" 7256 - 10310 6361 - 8928 8160 7020 Perforation Depth: Measured depth: 10870 - 11860 feet True vertical depth:9038 - 9045 feet Liner 1841 3-1/2" x 3-3/16" x 210162 - 12003 8863 - 9061 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1010650168484 123318608 650 40773 385 812 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Worthington, Aras J Aras.Worthington@bp.com Authorized Name:Worthington, Aras J Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4102 12. Stimulation or cement squeeze summary: Intervals treated (measured):6XUIDFH2$ Treatment descriptions including volumes used and final pressure:3XPSSSJ6T]FUHWHLQWR2$ZLWKUHWXUQVIURP2$3XPS#PLQLPXPUDWH aESP DOORZLQJ FHPHQWWRIDOODQGVZDSRXW&RQWLQXHSXPSLQJFHPHQWIRUKUVDFURVVWRS#PLQUDWHWRDOORZFHPHQWWRFOHDQXSEEOVDZD\6TXHH]HGWRSVLZEEO FHPHQW+HOGVTXHH]HSUHVVXUHIRUKUVE\EXPSLQJWKHSUHVVXUHXSHYHU\PLQV2FFDVLRQDO\SXPSHGDFURVVZHOOWRGLVSODFHK\GURFDUERQVZKLOHKROGLQJ VTXHH]HSUHVVXUHEEOVWRWDOFHPHQWXVHG586/%FHPHQWSXPSEDWFKXSSSJ&ODVV*&HPHQW&KDUJHSXPSEEOVLQWR2$WKHQVTXHH]HWRSVL 2$:HOO/RFN7UHDWPHQW )LOOYRLGZJDO:HOO/RFNE\SXPSLQJWKUXW\JRQWEJWRGHOLYHU:HOO/RFNWRERWWRPDQGSXPSDGGLWLRQDOJDOORQRIZHOOORFNWRHQVXUHDQ\ FRQWDPLQDWHVDUHUHPRYHG JDOORQVXVHG 5HULJIRUVTXHH]HE\DGGLQJHOERZVDQG SXSVWRERWKVLGHVRI2$)LOOH[WUDULJXSFRPSRQHWVZJDO ZHOOORFN JDOWRWDODZD\ 6TXHH]HWRSVLZDGGLWLRQDOJDORI:HOO/RFN6TXHH]HIRUKRXUVDQGVT] GDZD\JDORI:HOO/RFN7RWDO:HOO/RFNJDO 3XPSDGGLWLRQDOJDOORQVRYHUKUV7KLVEDWFKRI:HOO/RFNKDVDFFHOHUDWRUDGGHG7KLFNHQLQJWLPHKUDQGVKRXOGVHWFRPSOHWHO\LQKUV:/VDPSOHIURP KDUG/HIWRYHU:HOORFNLQPHWDOEXFNHWDOVRKDUG)LQDO3UHVVXUHV 2$ SVL,$ SVL7%* SVL 13. Interventions & Integrity Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9061 Sundry Number or N/A if C.O. Exempt: 320-041 Junk Packer Printed and Electronic Fracture Stimulation Data 5 OA Squeeze Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028285 PBU D-11B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 4-1/2" 12.6# 13Cr80 35 - 10211 35 - 8887 10155 8860 Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer No SSSV Installed By Samantha Carlisle at 8:23 am, Jun 25, 2020 Aras Worthington Digitally signed by Aras Worthington Date: 2020.06.25 05:49:27 -08'00' MGR26JUN20 DSR-6/25/2020 RBDMS HEW 6/25/2020 SFD 6/30/2020 ACTIVITYDATE SUMMARY 3/5/2020 T/I/O=SSV/390/440, Temp=SI. PPPOT-IC (PASS), eval IAxOA com. PPPOT-IC: Stung into test port (500 psi), bled void to 0 psi (fluid). Single port, unable to pump through void. Pressured void to 3000 psi for 30 min test, lost 80 psi in 15 min, lost 35 psi in second 15 min (PASS). bled void to 0 psi. 3/5/2020 T/I/O = SSV/410/410. Temp = SI. Fluid pack IA & OA IT FAILED (Cement squeeze). IA FL @ near surface. OA FL @ near surface. Used 0.6 bbls of DSL to pressure up OAP to 1200 psi. OAP slowly lost pressure and the IA sloly gained pressure. Performed a LLR OA x IA to 1195 ps (0.4 gal/min). Cameron performed PPOT-IC while holding 400 psi on OA. Pumped OAP up to 1200 psi while Cameron was stung into test void (See Cameron WSR). Bled OAP to 10 psi (0.4 bbls returned). Hung tags. Final WHPs = SSV/390/10. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:40 4/1/2020 T/I/O = 500/400/260. Temp = SI. Bleed IAP & OAP to 0 psi (Valve Shop Request). No AL. IA FL @ near surface, OA FL @ surface. Bled IAP to BT from 400 psi to 220 psi in 15 minutes (0.80 bbls energized fluid), OAP decreased from 260 to 220 psi. Bled OAP to BT from 220 psi to 0+ psi, IAP increased from 220 psi to 250 psi. Bled IAP from 250 psi to 120 psi in 30 minutes (1.1 bbls energized fluid, 1.9 bbls total), OAP increased from 0+ psi to 60 psi. Monitored for 30 minutes. IAP increased 20 psi, OAP increased 30 psi. Final WHPs = 500/140/90. SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:30 4/1/2020 T/I/O = 490/150/140. Temp = SI. Bleed IAP & OAP to 0 psi (VS request). IA & OA FL @ near surface. Bled IAP to BT from 150 psi to 6 psi in 6 hrs 30 min (all gas). TP decreased 20 psi, OAP decreased 96 psi. Bled OAP to BT from 44 psi to 19 psi in 1 hr (all gas). Monitored for 30 min. IAP increased 8 psi, OAP decreased 4 psi. Final WHPs = 470/14/15. Heater installed in wellhouse, treecap bled to 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30 4/1/2020 T/I/O = 450/19/19. Temp = SI. Bleed IAP & OAP to 0 psi (Pre- VS). No AL. IA FL @ near surface, OA FL @ surface. Bled IAP to BT from 19 psi to 0 psi in 1.2 hours (all gas), OAP decreased from 19 psi to 15 psi. OA bleed to 0 psi in progress. ***WSR continued on 04/02/2020*** 4/2/2020 ***WSR continued from 04/01/2020*** T/I/O = 440/5/9. Temp = SI. Bleed IA & OA to 0 psi (Pre- VS). No AL. IA FL @ near surface, OA FL @ surface. Continue bleeding OAP to BT from 9 psi to 0 psi in 1.8 hours (mostly gas, 0.14 bbls energized fluid). Held open bleed on IA & OA for 2.25 hrs once IAP & OAP @ 0 psi. Monitored for 30 minutes. IAP increased 2 psi, OAP increased 3 psi. Void above SSV bled to 0 psi for heater in well house, front door open. Final WHPs = 420/2/3. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:15 4/4/2020 T/I/O = SI / 0 / 0. Removed Blind flange on Companion side of OA and installed Integral flange w. Block valve. Removed working side OA valve and installled Integral flange with block valve and jewelry for upcoming cement / well lock job on OA casing. (See log for details.). RDMO SV, WV and SSV = SI. MV Open. IA and OA valves = OTG. ***Job Complete*** 4/5/2020 T/I/O = SSV/10/10. Temp = SI. Bleed OAP to 0 psi, Plumb OA cement top (pre cement). No AL. Bled IAP & OAP to 0 psi in 1 min, held open bleed on IA & OA for 1 hr. Strapped OA TOC @ ~236.5', unable to get 1/2" hose down OA, ~8' section of chain left in OA. Final WHPs = SSV/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 05:15. Daily Report of Well Operations PBU D-11B Daily Report of Well Operations PBU D-11B 4/6/2020 Job Scope: OA Squeeze. Pump 14 ppg Sqzcrete into OA with returns from OA complanion valve to half drum and vac truck. Held open IA bleed through entire job. Pump @ minimum rate (~.05 bpm) allowing cement to fall and swap out. Dirty diesel returns until 3 bbls away. Trace of hydocarbons in returns. Continue pumping cement for 2.5 hrs across top @ min. rate to allow cement to cleanup. 12 bbls away. Still traces of hydrocarbons in returns. Squeezed to 1200 psi w/ .1 bbl cement. Held squeeze pressure for 2.4 hrs by bumping the pressure up every 10 mins. Lost ~175 psi / 10 mins w/no improvement throughout. Occasionaly pumped across well to displace hydrocarbons while holding squeeze pressure. 16 bbls total cement used. Blew across wellhead w/ N2 to clear cement. Noted gas returns from IA as soon as N2 cleared the wellhead. No returns from IA throughout job until N2 displacement. ***Job Complete*** 4/9/2020 T/I/O=SSV/25/30, Temp=SI. LPE-IC w/ N2. (post cement squeeze). Stung into IC test void (50 psi), bled void to 0 psi (hyd fluid returns). DHD pressured OA w/ N2 to 950 psi, no pressure increase in test void. IAP increased 200 psi in 20 minutes, OAP decreased 180 psi in 20 minutes. Test void pressure remained at 0 psi. 4/9/2020 T/I/O = SSV/100/100. Temp = SI. LPE - OA, Strap TOC in OA (post OA squeeze). No AL. IA FL @ near surface, OA FL @ surface. Bled IAP & OAP from 100/100 to 22/27 (all gas, FTS). Increase OAP to 950 psi w/ 2 bottles N2 to depress OA FL while taking returns out IA (returned 3 gallons to BT). No communication detected in IC test void when OAP @ 950 psi. Bled IAP & OAP to 0 psi and monitored for observable flow for 1 hour. Removed hard line and block valves to strap TOC. Strapped TOC in OA @ 3 o'clock @ ~10.5", strapped TOC in OA @ 9 o'clock @ ~102' (obstruction found @ ~80' from surface). OA FL @ bottom of VR profile. Reinstalled block valves and hardline on OA. Final WHPs = SSV/2/0+. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:30 4/12/2020 T/I/O=SSV/53/38, Temp=SI. Prep OA (cement sqz). RU bleed hoses to IA & OA, bleed IAP & OAP to 0 psi. Pressured IAP to 1200 psi with N2 to attempt to purge the OA of fluid (all gas). Inserted 3/8" hose into casing (OA), attached bleed hose to 1502 with inserted hose. Pressured OAP from companion OA valve taking returns out off side port (returned 2 gal). 4/12/2020 T/I/O = SSV/53/38. Temp = SI. Prep OA (Cement sqz). IA FL @ near surface. OA FL @ surface. Used 3 bottles of N2 to pressure up the IA to ~1200 psi while taking returns from the OA (all gas). Bled TBG, IAP & OAP. Maintained an open bleed on the IA and rigged down OA jewelry and 1502 block valve from the 9 o'clock position. Inserted a weighted 3/8" hose into the casing before bottoming out (~20'). Attached hose to the inside of a 1502 wing half and tighten to integral. Attached a bleed hose from the other side of the 1502 wing half to a bleed tank. Applied N2 pressure (~50 psi) to the 3 o'clock OA valve. Purged 2 gallons of fluid from the OA before returns turned to gas. Let OA settle and bumped again after 15 minutes (gas). FWPs = 0/0+/0+. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 4/13/2020 T/IO = 50/30/20. Temp = SI. Prep OA cement job / eval OA (cement sqz). No AL. IA & OA FLs @ near surface. Bleed IAP & OAP to 0 psi, held open bleed for 1 hour for no observable flow. Held open bleed on IA. Removed hard line jewelry from OA @ 9 o'clock position and installed 50'x1/4" hose down IAxOA annular void and evacuated 2.9 bbls fluid from OA to BT w/ N2. Reinstalled hard line jewelry on OA. Final WHPs = 40/0+/0+. SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:30 Daily Report of Well Operations PBU D-11B 4/14/2020 T/I/O = SSV/28/10. Temp = SI. Prep OA (cement sqz). IA FL @ near surface. Bled the OAP to 0 psi in 10 seconds (all gas). Maintained an open bleed for 1 hour and performed a no-flow check. Maintained an open bleed on the IA throughout job. Connected and inserted another 50' of hose into the OA (100' total). Applied N2 to the other side of the OA to lift fluid. Purged 3.1 bbls of liquid from the OA before getting gas returns (6.1 bbls total since 4/12/20). FWPs = SSV/0+/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 4/19/2020 T/I/O = SSV/97/1. Temp = SI. OA cement prep (pre top job). No AL. Performed passing No-Flow test on OA. Poured 1/2 gallons of Musol and 1/2 gallon of F-103 down the OA & filled with hot water. Overflushed from one outlet of the OA casing taking returns to a drum under the opposite side till clean returns were observed. Filled the remaining OA void with neat methanol (~5 gallons). Applied N2 pressure to one side of the OA while taking returns up a hose inserted down the OA to 100' (5.9 bbls returned). FWPs = SSV/0+/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 18:00 4/21/2020 Job scope: Remove 1/4" hose from OA in prep for OA down squeeze. Bled OAP to 0 psi & held open for 1 hr for no flow test. Removed 1502 cap & 100' of 1/4" hose from OA. Installed 1502 cap. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 4/22/2020 T/I/O= SSV,/20/0+ Temp = SI Job Scope: OA down sqz. Preform 1 hour no flow test. RU SLB cement pump batch up 15.8 ppg Class G Cement. Charge pump 6 bbls into OA then squeeze to 1200 psi. Held for one hour with a loss of 40 psi. Increased pressure again to 1200 psi held for second hour with a loss of 20 psi.. Sample on THA with magnetic thermometer attached on OA spool piece. Tags hung and monitors will be taken each tower. until compressive strenth of cement at 2000 psi. ***Job Complete*** 4/23/2020 T/I/O = SSV/250/280. Temp = SI. Increase OAP w/N2 (Post cement). Cement sample is fully cured. Increased OAP to 1150 psi with N2. OAP slowly decreasing. Left OA open to bottle pressure (1100 psi) for an additional 10 min. OAP decreased to 730 psi. Checked all connections with Snoop (good). SI N2. Monitored for an additional 15 min. OAP decreased to 480 psi. FWHP's = SSV/250/480. SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:30. 4/25/2020 T/I/O = SSV/280/280. Temp = SI. WHPs (post cement). No AL. Cement sample is fully cured. IAP increased 30 psi and OAP decreased 200 psi since N2 increase on 04/23/2020. Heater in well house working properly. SH temp = 8°. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:00 5/2/2020 T/I/O = SSV/280/280. Temp = SI. Install OA gauge (Ops call in). Removed analog gauge and installed wireless OA gauge. OA has integrals installed with 1502 caps. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30 5/4/2020 T/I/O = SSV/280/280. Temp = SI. Strap TOC (pre Wellock). No AL. Bled IAP & OAP to 0 psi in ~2 min & held open bleed on both IA & OA for 1 hr. No visible flow on the OA. Strapped OA TOC @ 12" @ the 3 o'clock position with no fluid & 16" @ the 9 o'clock position with ~2" of fluid. SV, WV, SSV = C. MV = O. IA, OA = OTG. 10:30 Daily Report of Well Operations PBU D-11B 5/11/2020 Job Scope: OA WellLock Treatment. Insert tygon tubing to bttm of void. Fill and soak 18" (3.5 gal) void w/ musol. Soak 1 hour and displace. Fill void w/ 4 gal WellLock by pumping thru tygon tbg to deliver WellLock to bottom and pump additional 2 gallon of welllock to ensure any contaminates are removed (6 gallons used) Re-rig for squeeze by adding elbows and 2' 1502" pups to both sides of OA. Fill extra rig-up componets w/ 1 gal welllock (8 gal total away) Squeeze to 1200 psi w/ additional .5 gal of WellLock. Squeeze for 12 hours and sqz'd away 6.6 gal of WellLock. Total WellLock 15.1 gal. Final WH temp = 84°. Final WHPs after removing manifold = SSV/0/400. SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:00 (5/11/20). 5/12/2020 Job Scope: Continue pumping WellLock. T/I/O SSV/0/0. Pump additional 2.5 gallons over 11 hrs. This batch of WellLock has accelerator added. Thickening time 1 hr and should set completely in 48 hrs. Maintain ~75F on wellhead. Cont. pumping WellLock on WSR 5/13/20 5/12/2020 T/I/O = SSV/0/0. Temp = SI. WHPs (post wellock). No AL. Heater had blown out of wellhouse. Secured heater inside wellhouse and positioned it to heat up cellar/OA. OAP decreased to 0 psi since earlier this morning. Heater working properly. Wellhead temp reading taken from the 11 o'clock position next to the OA flange = 49°. Wellock sample has the consistency of luke warm surup. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:30 5/13/2020 Cont from WSR 5/12/20. Squeezed for 12 hours and sqz'd away 2.72 gal of WellLock. Monitored for 1 hr. OAP decreased 500 psi. Final WH temp = 79° (07:00). Flushed out manifold and gauge with hyralic fluid. Pressured up OAP with tydralic fluid 5 x's using a total of ~4 tablesoons. Monitored for 30 minutes. OAP lost 500 psi. Final WHPs = SSV/0/700. Temp on Wellhead = 74° @ 10:00. OAP decreased to 300 psi @ 17:00. Pressured up to 1200 psi w/hydraulic pump. WH temp ~70° (Houlton). 5/14/2020 T/I/O = SSV/0/150. Temp = SI. WHPs (post Wellock). AL disconected. WH temp = 56°. Wellock sample consistency of molasses. Adjust the heater. Placed magnetic thermometer on the OA casing @ the 11 o'clock position. OAP decreased 1050 psi. Bumped up OAP to 1200 psi. FWHP = SSV/0/1200. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30 5/14/2020 T/I/O = SSV/0/350. Temp = SI. WHPs (post Wellock). AL disconnected. WH temp = 90°. Wellock sample not set up, consistency of molasses. Adjust heater. OAP decreased 850 psi overnight. Bumped OAP to 1200 psi. Final WHPs = SSV/0/1200. SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:30 5/15/2020 T/I/O = SSV/60/200. Temp = SI. WHPs (post Wellock). No AL. Wellock not set up, has the consistancy of honey. WH temp = 110°. Opened wireline door a bit. OAP decreased 140 psi12 hrs. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30 5/15/2020 T/I/O = SSV/0/340. Temp = SI. WHPs (post Wellock). No AL. Wellock sample not set up, has the consistency of honey. WH temp = 62°. Adjusted heater and from wireline door vent. OAP decreased 860 psi in 12 hrs. SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30 5/16/2020 T/I/O = SSV/60/80. Temp = SI. WHPs (post Wellock). Wellock sample with activator in it from the 12th is set up. Wellock sample from the 11th not set up and has the consistency of warm honey. Heat was off on arrival. Restarted burner. WH temp = 40°. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:30 Daily Report of Well Operations PBU D-11B 5/16/2020 T/I/O = SSV/60/50. Temp = SI. WHPs (post Wellock). Wellock is not set up has consistency of cold honey. WH temp = 62°. Adjusted heater. OAP decreased 150 psi in 9 hrs. SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:30 5/17/2020 T/I/O = SSV/90/50. Temp = SI. WHPs (post Wellock). No AL. Wellock sample not set up, does not pour when tipped but soft enough to squeeze easily. WH temp = 82°. OAP decreased 30 psi in 10 hrs. SV, WV, SSV = C. MV = O. IA, OA = OTG. 02:30 5/18/2020 T/I/O = SSV/100/20. Temp = SI. WHPs (post Wellock). No AL. Wellock from 5/11/20 is not set up it will not pour but is soft enough to squeeze. Wellock sample from 5/12/20 appears to be set up. WH temp = 50°. Restart the burner on the heater and leave its door open. IAP increased 10 psi, OAP decreased 30 psi overnight. SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:30 5/19/2020 T/I/O = SSV/120/20. Temp = SI. WHPs (Post Wellock). No AL. WH temp = 58°. Heater working. Wellock sample from 5/12/20 is set up. Wellock sample from 5/11/20 is not set up and has the consistency of honey. IAP increased 20 psi, OAP unchanged since 01:30 yesterday. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:40 5/22/2020 T/I/O = SSV/160/20. Temp = SI. WHPs (Post Wellock). No AL. WH temp = 60°. Heater is working. Wellock sample from 5/12/20 is set up. Wellock sample from 5/11/20 is not set up and has the consistency of cold honey. IAP increased 40 psi since 5/19/20. OAP unchanged. SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 5/23/2020 SSV/0/0. Post well lock. RD 3" working side O/A 5000 integral. RU 3" working side O/A Cameron valve. Torqued to API spec. RD 3" 5000 companion side integral. RU 3" companion side 5000 blind flange. Torqued to API spec. Job Complete. See log. Final WHP,s SSV/0/0. 5/23/2020 T/I/O = SSV/160/0. Temp = SI. WHPs (post Wellock). No AL. Wellock sample from the 11th not set up has consistency of cold honey. WH temp = 55°. Valve crew just swapped the hardline out for CV on OA. IAP unchanged. Valve crew in control of valves upon departure. 02:00 5/26/2020 T/I/O = SSV/200/0. Temp = SI. WHPs (post Wellock). No AL. Wellock sample from 5/11/20 is not set up it does not pour but is easily squeezable. WH temp = 75°. IAP increased 40 psi, OAP unchanged from 5/23/20. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 5/29/2020 T/I/O = SSV/230/0. Temp = SI. WHPs (post WellLock). No AL. Well lock sample is mostly setup, still able to be indented slightly. WH temp = 48°. IAP increased 30 psi, OAP unchanged since 05/29/2020. Heater in well house working properly, front wireline door slightly ajar. SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:45 5/30/2020 T/I/O = SSV/740/10 Temp= S/I. WHPs (Post Wellock) WH temp 50 deg Heater working. WL sample from treatment 5/11/20 hard, WL sample from 5/12/20 hard. left over Wellock in metal bucket also hard. 6/6/2020 ***WELL S/I UPON ARRIVAL*** (Cement Squeeze) PULLED P-PRONG FROM 4-1/2" PX-PLUG @ 10,126' SLM / 10,144' MD. ***JOB CONTINUED ON 07-JUN-2020*** 6/7/2020 ***JOB CONTINUED FROM 06-JUN-2020*** (Cement Squeeze) PULLED 4-1/2" PX-PLUG BODY FROM 10,132' SLM / 10,144' MD. ***JOB COMPLETE ON 07-JUN-2020*** THE STATE Alaska Oil and Gas OfAT e SKA Conservation Commission GOVERNOR MIKE DUNLEAVY Aras Worthington Interventions and Integrity Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU D-1 IB Permit to Drill Number: 210-077 Sundry Number: 320-041 Dear Mr. Worthington: 333 West seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a 0gc c.a laska.g 0v 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, 4ChairJ re rice ((�� DATED this j0day of January, 2020. ,gDMSL L -'JA% 31 IS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well RI4 a ffr Bois a Suspend ❑ Perforate L P ❑ Other Stimulate ❑ Pull Tubing ❑ Cham p ro a ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other OA Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: - Exploratory ❑ Development 0 5. Permit to Drill Number: 210-077 ' Address: P.O. Box 196612 AnchorageAK 3 , 99519-6612 Stratigrephic ❑ Service ❑ 6. API Number: 50-029-20435-02-00 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 0 PBU D-118 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028285 ' 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 12003 9061 10144 8855 10144.11200 11200,11795 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 40-120 40-120 lass 470 Surface 2641 13-3/8" 39-2680 39-2680 5380 2670 Intermediate 7363 9-5/8" 37-7400 37-6463 6870 4760 Liner 3054 7" 7256 - 10310 8361 - 8928 8160 7020 Liner 1841 3-1/2" x 3-3/16" x 2-7/8" 10162 - 12003 8863-9061 Peroration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grace: Tubing MD (ft): 10870-118 0 9038-9045 4-1/2" 12.fi# 13Cr80 35-10211 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer Packers and SSSV MD (ft) and TVD (ft): 10155/8860 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 5, 2020 15. Well Status after proposed work: Oil 0 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, Arcs J be deviated from without prior written approval. Contact Email: Aras.Worthington@bp.com Authorized Name: Worthington, Area J Contact Phone: +1 907 564 4102 Authorized Title: Interventipps & Integrity Engineer J Authorized Signature: Date: //,-2 -3j/a,O COMMISSION USE ONLY/�(/'l Conditions of approval: Notify Commission so that a representative may witness Sundry Number: rD I I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: BDMS ��.IAN 312020 Post Initial Injection MIT Req'd? Yes ❑ No ❑ — 4/04/ Spacing Exception Required? Yes ❑ No W' Subsequent Form Required: 4/0 APPROVED BYTHE -/ /� Approved by: COMMISSIONER COMMISSION Date: 1 /Vf0 O VU gvG il3a1 a6 ORIGINAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate D-11 OA Squeeze Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Chris Stone (907) 564-5518 Expected Start Date: February 511 2020 History D-11 B is a 2010 coil sidetrack producer. The OA was downsqueezed with cement in 2004 with the BOC at the SC shoe and the TOC displaced to —350' MD. In September 2018 rapid IA x OA communication was observed after dummying off GLV's and fluid packing the IA. In February 2019, the well was brought online Under Evaluation and it exhibited rapid IA x OA communication that was not manageable by Operator bleeds thus was classified as Not Operable. Current Status The well is Not Operable and a TTP was set at 10,144' MD with a passing MITT to 2388 psi. A passing MITIA was obtained in 2017 to 2677 psi. Objective The objective of this down squeeze to repair IA x OA communication and restore the well to an Operable producer. Procedural steps DHD/Special projects 1. Pump sealant (squeezecrete, Well Lock, or similar product) into the OA taking returns from the opposite OA valve and allowing time for sealant to swap with OA fluids. 2. Squeeze sealant in OA to 2500 psi. 3. Wait on sealant to cure. 4. Top job and squeeze with selant a second time to squeeze off any micro -annuli to 2500 psi. DHD/Well Integrity Engineer 1. POP well Under -Evaluation and monitor for IA x OA communication. 2. If communication is repaired convert well to Operable status. VAUHEAD= FMC ACTUATOR= UWSH3000 71.6' KOP= 2800' b6x Angle = 94" @ 11141' Datum MD= -- 10204' DatumTVD= 8800 SS 3" CSG 72#, L-80BTRS, D=12-347' 2668' Minimum ID = 2.3' 10162' 45 KB LINER TOP PACKER "X7'TNVSM6ATTBPKP D=7.38" 725 � 9-815'X7"TIWLFRFGRD=8.249" -- 791M 9-5/8" MLLOUT WINDOW (011A) 7400'- 1455' -NR, 29#, L-80 BTG XO TO 13CR NSCC 91 4-12- TBG, 12.6#, 13CR NSCT, .0152 bpf, D = 3.958' D=6.184• PERFORATION SLMMRY RIF LOG: SLB MCNL ON 0721/10 ANGLEAT TOP PERF. 86" @ 10870' Note: Defer b Production DB for historical pert data SIZE SPF I INTERVAL Opn/Sqz SEDT SOZ 2" 6 10870 -10900 O 01105/15 RM 2" 6 10840 -11000 O 09!29114 43 2" 6 11000 - 11060 O 01104115 4 2' 6 11220 -11250 c 1128112 RA 2' 6 11420-11720 C 0720/10 23 2" 6 11760 -11860 C 0720110 2 D=2.80' SAFETY NOTES: WELL ANGLE> 70' Q 10334"' BEFORE RUNNING 1' BTM LATCH GLV N'OLD STY LE KBG-2LS GLM, MOVE NO-GO ON RUNNING HEAD 12" "'4-12' CHROAE TBG & 7' LNR - ORIG &'A' WELLBORE NOT SHOVMU -518' DV PKR GAS LIFT MANDRELS ST M) TVD ITVJ TYPE VLV LATCH I PORT DATE 6 3075 3074 7 F6 TB OA4t' RM 0 1028/17 5 5476 6068 43 I-6 TB DIM' RM 0 1028/17 4 7141 6278 44 FSS 7B DAM RA 0 01110/96 3 8010 6970 23 KBG2LS -Dk1Y M 0 03/18/98 2 9124 7984 24 KBG2LS "RIMY M 0 03/18/98 1 10077 6818 54 KBG2LS '"DMY M 0 03/18198 "PROBLEM MAMOR :S R87URING SPECIAL VALVES (NOTE STA #3=DMY IRS BM OED PWG) FEX NS D=3.813" PX FLOG (03/14/19) K 4-12' BKR S-3 PNB, ID= 3.875" -NR TOP PNB, D=2.370' BTT GEN DEPLOY SLV, D = 3.00" '-ES X NP, D = 3.813' (BE#ND LF OTIS X NP. D= 2.812' 101 OW 4-12• HFS XN NP, D= 3.79' CONTYENTS (MELEE) 0629110) BEHIND 10211' 4-12"WLEG0=3.958" LINER 10211'ELADTTLOGON?7/7717? 10109/14 TFffJhc FISWSETC13pADPEFFS(9127-28114) 10287 3-12" X 3-3116' XO, D= 2.786• CTOSIDETRACK(Q71A) MLLOUT WTAOW (p-110) 10310'- 10317 0724110 DATE RFV BY CONTYENTS DATE REV BY ICOrvT43Ji5 04/29180 ORIGINAL COMPLETION 10109/14 TFffJhc FISWSETC13pADPEFFS(9127-28114) 01114196 D-09 CTOSIDETRACK(Q71A) Tl 3/15JCF/JMD ADPEFS(Ol/04-05/15) 0724110 CTDSIDETRACK(D-118j 0127/15 GdPJD OKE OOMMaTION(ASBULT) 12/02112 JJL/PJC CJBR ADPHFS(1128/12) 08/03117 KP/JND TRE=M( 77/28/17) 01/17/13 DLWAC GLV CYO (01/02113) 10131117 OIMJM) GLV 00 (10/28117) 0422/13 JAD VERF®&0OW3=GLV'S 03/18/19 JMJW SET PX PLUG (03/14/19) D = 2.377" BKR FRLOHOE RAY UHT WELL D -11B PU MT No: X2100770 AR No: 50-029-2043502 TI IN, ME 2239' FSL & 1067 FFL BP Exploration (Alaska) RECEIVED STATE OF ALASKA AL .(A OIL AND GAS CONSERVATION COMM. .JN JAN 21 2015 � REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate Other ❑ AOGCC OGCC Performed. Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4 Well Class Before Work. 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory❑ 210-077-0 3 Address. P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-20435-02-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028285 PBU D-11B 9 Logs(List logs and submit electronic and printed data per 20AAC25 071). 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary: Total Depth measured 12003 feet Plugs measured 11200 feet true vertical9061 11 feet Junk measured 11199/11795 feet Effective Depth measured 11200 feet Packer measured See Attachment feet true vertical 9037 2 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 38 75-118.75 38 75-118 75 1490 470 Surface 2644 13-3/8"72#L-80 38 25-2682 25 38.25-2682 01 4930 2670 Intermediate 7364.8 9-5/8"47#L-80 36.35-7401 15 36 35-6464 2 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10870-10900 feet 10940-10970 feet 10970-11000 feet 11000-11060 feet 11220-11250 feet 11420-11720 feet 11760-11860 feet True Vertical depth 9043.02-9044 97 feet 9045 02-9043 54 feet 9043 54-9042 12 feet 9042.12-9040.55 feet 9038 1-9040 38 feet 9042 1-9040 79 feet 9040 89-9044.03 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured). SCANNED 1 NED C,I', it,' L U 15 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 718 34533 0 0 1030 Subsequent to operation 1010 14213 180 0 1718 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work Oil 0 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 0 Exempt N/A Contact Garry Catron Email Garry.Catron(a BP.Com Printed Name Garry Catron Title PDC PE Signature LV- Phone 564-4424 Date 1/21/2015 Y V.r- 1/2g/ ,3-- RBDMS(irk JAN 11 2015 4 '/z1/, Form 10-404 Revised 10/2012 Submit Onginal Only Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD Depscription D-11B PACKER 7256.9 6361.92 7" Liner Top Packer D-11B PACKER 10156.15 8860.58 4-1/2" Baker S-3 Perm Packer D-11B PACKER 10162.12 8863.43 3-1/2" Baker 45 KB Packer D-11B PACKER 10455.66 8978.58 4-1/2" Top Packer w Ncl c) oCCD 0eCDo 10000 Rr—SID � cDseD O ti N CO N- U y0000 COooOo i O) N- O up M M ct 00 • � CO O O) m CO 00 r 00 N- 00 up N N ch 0000 CO r O Ln O Z8 06 6) ch N N I0 N r L!) 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Cl.) m / / _ w 2 o\ / E _ Cyfl« � 0- 7- 1* E 0EL '- - > \ / 5 2 / / (Ti § / a _o k \ / + 02 % \ � % •c/ 0a2 % 7 % $ O \ E / c a e z -f % � < � � � / _o � \ xU › y 0)m w o o - = E e o ° _ re awe w / \ � - X co • I ® 2 E.' I „ / \ Z �I _ I I4" kb § I c k > 7 � H — o) ) H r O \ / \ § •/ g o @ = U : R = y b ° : ® -- b o d / 0E c& 02 a® = E � 0 � c 02 * 3 / ) Go2 _ ° - a) = f R D -cs)R 0 o b a / /N. W Z & § © \ ) 0 ' \ - w . x e • § f £ % 0 % 2 ® CI CO 32 f \ \ $ b k / 2 § t / / @ $ / / a) o _ ,- / / / § ± $ I'll 2 0 2 2 : 0 2 O W c ) : O 0 .R Ret rr r 7 \7 ,_ CV 9 e A'' = 0 f 9 1REE= CIW SAFE TES: WELL ANGLE>70°@ 10334'"BEFORE ACTUATOR FON D—11 B NO GO ON RUNNING HEAD 1/1/2""4-1/2'f BTM LATCH GLV N'OLD STYLE 6G-2LS GLM, ()HROME TBG& 1�CTUATOR- AXEt.SON OKB.ELEV= 71.7" 7"LN/2"ORIG&"A"WELLBORE NOT SHOWN" BF.ELEV= 46.56' I 1 350' NEW TOP OF CESWENIT 11/23/04 KOP= 2800' / rf 1 Max Angle= 94"@ 11141' 20"COND --{ 100' 4 �•� 2215' —4-1/2"HES SSSV NP,D=3.813" Datum M.)= 10204' I. O •,. Datum TVD= 8800'SS :::: Iii 2613' -19 5/8"DV PKR 13-3/8"CSG,72#,L-80B -TRS,0=12.347" f 2668' GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE Minimum ID =2.370" @ 10162' 6 3075 3074 7 HES TB DOME RM 16 01!02/13 46 KB LINER TOP PACKER 5 5479 5068 43 HES TB DOME RM 16 01/02/13 4 7141 6278 44 HES TB DMY RA 0 01/10/96 LI I 3 8010 6970 23 KBG2LS "DMY NT 0 03/18/98 9-8/5"X T TIN SN-6 AT TB FKR,D=7.38" --I 7256' 2 9124 7984 24 KBG2LS "DMY NT 0 03/18/98 9-8/5"X 7'TW LNR HGR,ID=8.249" H 7269' 1 10077 8818 54 KBG2LS "DM Y NT 0 03/18/98 "PROBLEM MANDREL'S RBQURING SPECIAL VALVES 9-5/8"CSG,47#,L-80 BTRS,D=8.681" —{ 7400' (NOTE STA#3=DMY HAS EXTEND®PKG) X X/ 10144. H4-1/2"HESXNP,D=3.813" MLLOUT WTDOW (D-11A)7400'-7455' 10155' —19-58"X 4-1/2"BKR S-3 PKR D=3.875" 17"LMR,29#,L-80 BTC,XO TO 13CR NSCC H 9668' ,7 �-�.. 10162' H45 KB LNR TOP PKR,D=2.370" ESTATTOP OF CEMENT H 10170' " " M ® 10171' H3-1/2"BTT GEN DEPLOY SLV,13 3.00" I . 10178' —{4-1/2"HES X NP,D=3.813"(BEHIND LNR) �i le 10192'3-1/2"OTISXNP,D=2.81T ►H • •4 ► • 1 •' 10199' H 4-12"HES XN NP,D=3 79" I 4-1/2"TBG,12.6#,13CR NSCT, -L 10211' ►1 ir1 (MLLE 06/29/10) BEHIND • .0152 bpf,D=3.958" i•H .• • • 10211' H4-1/T WLEG,ID=3.958" LINER � • •1 •• 10211' —I BJA)TT LOG ON 7?/"?/7? 3-1/2"LMR,9.3#,L-80 STL,.0087 bpf,D=2.992" --I 10287' O• it i �• •. • 10287" —13-1/2"X 3-3!16'XO,ID=2.786" T WFIPSTOCK(06/27/10) H 10300' %` ►% _.__ T LM 29#,L-80 BTC,.0371 bpf,D=6.184" H 10300' ss`:� FALLOUT WINDOW (1)-11B)10310'-10317' •i�i�i�i�i•i 10384' H3-3/16"X 2-7/8"XO,D=2.377" •••••••••••• PERFORATION SLIM?MIARY 10386' —12-718"MARKER JONT REF LOG:SLB MCtL ON 07/21/10 ANGLE AT TOP PERE:86°@ 10870' ^11200' FISH:CEP DEBRIS Note:(defer to Roduction DB for historical perf data (09/28/14) SIZE SPF NTERVAL Opn/Scg SHOT SQZ 11200' 2-7/8'BKR CUP 2" 6 10870-10900 0 01/05/15 (09/28/14) 2" 6 10940-11000 0 09/29/14 3-3/16-LMR,6.2#,L-80 STL, 10384' i Ar T 6 11000-11060 O 01/04/15 •0075 bpf,ID=2.80" ` 11795' FEET CEP T 6 11220-11250 C 11/28/12 (09/27/14) T 6 11420-11720 C 07/20/10 2" ` 6 11760-11860 C 07/20/10 PBTD H 11963' 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf,ID=2.441" H 12003' DATE REV BY COMMENTS DATE REV BY COMMENTS PRIDHOE BAY UNIT 04/29/80 ORIGINAL COMPLETION 10/09/14 TRR/JMD FISH/SET CBR'ADFERFS(927-28/14) WELL: D-11B 01/14/96 D-09 CTD SIDETRACK(D-11A) 01/13/15 JCF/JMD ADPERFS(01/04-05/15) F } AT No:1100770 07/24/10 NORDIC 1 CTD SIDETRACK(D-11 B) API No: 50-029-20435-02 12/02/12 JJU PJC CEP/ADPERFS(11/28/12) SEC 23,T11N,R13E,2239'FSL&1067'FE 01/17/13 DLW/JMO GLV C/O(01/02/13) 04/22/13 JMD VERIFIED&CORRECTEDGLV'S BP Exploration(Alaska) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. al 0 - 0 7.7 Well History File Identifier Organizing(done) 10 Two-sided I ❑ Rescan Needed III 111111111 111111 RE AN DIGITAL DATA OVERSIZED (Scannable) Co r Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: Other, No/Type: G� NO. I. ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: 1/131/9. /s/ P Project Proofing 11111E111U IIIII BY: C Maria Date: / tg.31 l 1# /s/ 6' P_.....)_____ Scanning Preparation x 30 = j + ic:77. = TOTAL PAGES 7c9—n does not include cover set (Count eet)BY: Date: ` 3 /s/ u Production Scanning 111111111111111 Stage 1 Page Count from Scanned File: 3 7 (Count does include coy sheet) Page Count Matches Number in Sca/3_3jILJ ping Preparation: YES NO BY: , Date: ` /s/ Mr) Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I ReScanned II I ON BY: Maria Date: /s/ Comments about this file: Quality Checked 1111111111M ICI 12/22/2011 Well History File Cover Page.doc o C 9 o g 0 <0 o ra U U a H 7 a a y O c Z W Z a O cn u ic- N9 (4 1 U 111 C E Z ce w ce m 0 C7 o a)~ 0 00 a) O ar '� E _Z 8 O yce00 a g w o g o Z,- > a >c d 2 0 L z o 0 U c cn EZ E to 0 - 0 a CT. 2 0 - 0 `o> = m 2 1- 2 0 0 < o C 0) o o ° a d ° 0 0 0 0 0 0 J N W y N N N N N N N N N U 0 J0 N N N N N N Z E N N N N N N C y N 'O� o = = v N C C C a) 0) m C C a a C C C C a) a a) a) E < m co ! C 00 N U 0 a a a U O O O a a O O 0. a s a 0 0 0 0 E Ce a w m a ° °) 0 0 o rn 0) 0 0 0 0°) 1. OZ m o 0 0 0 0 0 0) rn 0 0 0 0) m 0) CL 0 0 No o a EccnE W a�i co Z 03 C "t N O Q) o O O CO CO O ° Lo co a to a) rn '- rn rn co co N- rn .- '- r- rn W w v � 1 J a1 v m O. O 1 •y ` r C a) O 3 O Q. Q z v i 0 j J d a � t0 Y CL p � o � ° = o 0 0 o C N o ZI J 2 m 0 0 0 0 N CC r C N d y N O v a cu a) co co co co E N C0 E J N N N to N to t0 0 ca < 0. U 0 0 H ~_ ° Z _ Cl) N A 2 d. CO a m• N C O a) t Cn o co as 0• 0 Q C O. IF — 0I a °' Z w . w w ICC Z E > > Q a1 0 0 .N C .N .N .N in z 7 2 o cc v ' cC Q' a, ct C C C y d O CO O O. 0 C O 0 0 ca a) °o a as > > o > > > a a E E c Z a) m v cn v v v as m O O W Z Z 0 0 C J C C C Ur Ur ID N- co O N- V O+ N -0 a) 0 N n 0 o 0 I— O Q Z L C W o Z N N N N N 2 o p •2 as Ip R 0 •� M Z i1 o �? N y N N CC CO ILI O �' �- J < J J z 5 CD E 5 Q W J �� J \U� + a\0 �\ \\ V � 5 N y 0 0 �' a y a) `5 a 0 o o a 0 a a 0 0 0 0 m d C4 0 H J 0 I- J W W Q' W d' W J J J J o N 0 re U) `_ o Z N N V re o 5 o to Z a a J I U O 1 \ Z 1 4 i ..hi., CO N ea J t7 CI Ce Q N 0 0 �Z Z L I U /�r t Q o o Z F-_m o:6 =cn >, E? Z(00770 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, March 19, 2013 2:14 PM To: 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; Meixueiro, Paulina; AK, OPS Well Pad DG; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Walker, Greg (D&C) Subject: OPERABLE: Producer D-11 B (PTD#2100770)Tubing Integrity Confirmed Attachments: Producer D-11B (PTD#2100770)TIO Plot.docx All, Producer D-11B (PTD#2100770) passed a TIFL on 03/18/2013. The passing TIFL confirms tubing integrity. The well is reclassified as Operable. A copy of the TIO plot is included for reference. Please call if you have any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator rim A GIObal Wens r eni ati n Office: 907.659.5738 WIC Email:AKDCWeIIIntegritvCoordinator @bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, March 17, 2013 2:35 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1,,' Vellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lea , AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Meixueiro, Paulina; AK, OPS Well Pad DG; 'jim.regg @alaska.gov'; 'Schwartz, Guy L (DOA)' Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Walker, Greg (D&C); Clin•'nigsmith, Mike J Subject: UNDER EVALUATION: Producer D-11B (PTD #2100770) Sustained Out Annulus Pressure Above MOASP All, Producer D-11B (PTD#2100770)was found with sustained outer annul -s pressure above MOASP. The wellhead pressures were tubing/IA/OA equal to 850/1480/1210 psi on 03/16/20 . The well has been reclassified as Under Evaluation and is placed on a 28-day clock, and may remain on pro',uction to facilitate evaluation. Plan forward: 1. DHD: Warm TIFL. If TIFL fails evaluate well for sl' kline gas lift valve work. A copy of the TIO plot and a wellbore schematic are incl .ed for reference. 1 • 1 a �lls1lo886 Iii H 11 � I M UI 1,4 111 u1 o' er U g 1,1 0 II • II II M 1, a ' 1, g u1 0 1,1 I III co 111 °r.-- 111 U1 , 111 11 M II 65 Ii a " 0 en F d 1 R O • Cn ,1 t 11 11 O 11 M 11 lV I' r il II O 4. I M II 11 11 n 11 11 II II fV A Qy I i'', 0 0 0 � /� II . 1I I N o ti 03 c) 3 ° � l § § § § 1 d n'i ry 6a It p a a0_ M I- b—i(d3 • "L(UO77c: Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWellIntegrityCoordinator @bp.com] �� ilk�/,3 Sent: Sunday, March 17, 2013 2:35 PM '( ! To: 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; Meixueiro, Paulina; AK, OPS Well Pad DG; Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: AK, D&C DHD Well Integrity Engineer; Holt, Ryan P; Walker, Greg (D&C); Clingingsmith, Mike J Subject: UNDER EVALUATION: Producer D-11B (PTD#2100770) Sustained Outer Annulus Pressure Above MOASP Attachments: Producer D-11 B (PTD#2100770)Wellbore Schematic.pdf; Producer D-11 B (PTD#2100770) TIO Plot.docx All, Producer D-11B (PTD#2100770)was found with sustained outer annulus pressure above MOASP. The wellhead pressures were tubing/IA/OA equal to 850/1480/1210 psi on 03/16/2013. The well has been reclassified as Under Evaluation and is placed on a 28-day clock, and may remain on production to facilitate evaluation. Plan forward: 1. DHD: Warm TIFL. If TIFL fails evaluate well for slickline gas lift valve work. A copy of the TIO plot and a wellbore schematic are included for reference. Please call if you have any questions. Thank you, Jack Disbrow OA- SC'r BP Alaska-Well Integrity Coordinator G Global +''ells MCP I Z(0r Orgaruzaliion Office: 907.659.5738 WIC Email:AKDCWelIlntegrityCoordinator Pbp.com ())0 N(JjF ZZ.D p AO/et ok- 1 a $' aoo c 1- 0000 i1 # I M_ i r " p oO II ro II � r o i p O OAS O N O. CD a CO °o CO H QQ QQ QQ tal T T T O C7 U C ° N .- co O aa_ r.- H TREE= CM/ SAFETY, S.: WELL ANGLE>70'@ 10334'""BEFORE WELLHEAD-=- FMC RUNNSNO 1-BIM LATCH GLV IN'OLD STYLE'KBG-2LS GLM, ACTIJATOR= AXELSON D-11B MOVE NO-GO ON RUNNING HEAD 1/2"*"4-1/2'CHROME TBG& KB.ELEV= 711" 7"LNR""ORIG&"A"WELLBORE NOT SF-OWN BE.ELEV= 46.56' I I KOP= 3221' r, f41 350' 1--1NEVV TOP OF CEMENT 11/23104 •I Max Anqle= 94°_@ 11141' 120"COW) H 100' 4 •• 2215* H4-1/2"HES SSSV NP,FD=3.813" I Datum MD= 10204' I • I 4 Datum TVD= 8800'SS 0 2613' —19-5/8"DV PKR /-1.4T-li p = 5315cf--, & N 13-3/8"CSG,72#,L-8087RS,0=12,347* --1 2668' GAS LET MANDRaS ST ND 11/0 DEV TYPE VLV LATCH FORT DATE Minimum ID = 2.370" @ 10162' 6 3075 3074 7 FES TB DMY RM 0 06/19/12 5 5479 5068 43 I-ES TB DMY RM 0 06/19/12 45 KB LINER TOP PACKER 4 7141 6278 44 I-ES TB DMY RA 0 01/10/96 , , p 3 8010 6970 23 KBG2LS "DMY NT 0 03/18/98 9-8/5"X r TM/SN-6 AT TB PKR ID=7.38" —1 7256' .1--------1,-. 2 9124 7984 24 KBG2LS **DMY NT 0 03/18/98 9-8/5"X 7"TIVV LNR HGR,ID=8.249" —1 7269' r 1 10077 8818 54 KBG2LS **DMY INT 0 03/18/98 **PROBLEM MA•EREL'S REQUIRING SPECIAL VALVES 9-5/8"CSG,47#,L-80 BTRS,ID=8.681" —1 7400' (NOTE STA#3=DMY HAS EXTENDED PM) X X 10144' —14-112"HES X NP,O=3.813" N1LLOUT WINDOW (D-11A)7400'-7455' 10155* H9-518"X 4-1/2"BKR S-3 FKR,ID=3.875" 7"LbR,29#,L-80 BTC,XO TO 13CR NSCC — 9668' 2 r .. 10162' —45 KB LbR TOP PKR,ID=2.370" IP Em ESTIMATED TOP OF CEMENT — 10170' 10171' H3-1/2"BIT GENI DEPLOY SLV,D=3.00" • • .1 ,..1 1 • 10178' —I4-1/2"FES X l'AP,ID=3.813'(BEHIM)LNR) 1 o 4 0 o' 10192' j I--13-1/2 OTIS X NW,Er=2.812'.1 • 0 4 • 0 0 • 0 1 • I 10199' .—4-1/2"FES XNNP,V=3.79" 4-1/2"113G, 12.6#,13CR NSCT, — 10211' N .4 (MILLED 06/29/10) , BEHIND • ■ .0152 bpf,ID=3.958" ■ ••• 10211' —14-1/2"INLEG,ID=3.958' 1 LINER • I . • . 1 0211. H EiND IT LOG ON??/??/?? • • 3-1/2"LNR 9.3#,L-80 S1L,.0087 bpf,ID=2.992" —1 10287' •• • •• 1••• 10287' —13-1/2-X 3-3/16"X0,ID=2.786" • , 0.• 7"W-IIPSTOCK(06/27/10) H 10300' **, ft 4., 4 r LNR,29#,L-80 BTC,.0371 bpf,ID=6.184" H 10300' s, . MILLOUT WINDOW (D-11 B) 10310'-10317' - - vi•'",-4 ••••• 1 •••••• i 10385' —I 3-3/16"X 2-7/8"XO,E)=2.377" • ••••4 ••••• ••••••4 ■•■•.•.•&•A FERFORATION SUN1kAARY / REF LOG:SLB Mat ON 07/21/10 10386* 1-12-7/8"MARKER JOKE ANGLE AT TOP PERE:91°@ 11420' Note:Refer to Production DB for historical perf data SIZE SFF INTERVAL Opn/Sqz SHOT SQZ , 11350' 2-7/8"CEP 2" 6 11220-11250 0 11/28/12 3-3/16"LW,6.2#,L-80 STL, —f 10384' (11/28/12) 2" 6 11420-11720 C 07/20/10 A r 2" 6 11780-11860 C 07/20/10 .0075 bpf,ID=2.80" Nso‘ PBTD — 11963' :h. 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf,10=2441" —1 12003' J lir DATE REV BY CONWENTS DATE REV BY 0014AENTS PRUD1OE BAY LU!' 04/29/80 ORIGINAL COM PLEFION 01/11/11 AK/PJC FINAL DRLG CORRECTIONS WELL: 0-11B 01/14/96 D-09 CTD SIDETRACK(13-11A) 06/26/12 ARIVYJMD GLV 00(06/19/12) PERMIT No:' 100770 07/24/10 NORDIC 1 CTD SIDETRACK(D-11B) 12/02/12 JJLJ PJC.CISFY A ORRES(11/28/12) AF1No: 50-029-20435-02 07/27/10 PJC ORIG DRAFT CORRECTIONS SEC 23,T11N,R13E,2239'FSL&1067'FEL 08/27/10' ?/AGR GLV C/O(08/03/10) 09/13/10 PJC GLV CORRECTIONS Exploration(Alaska) RECEIVED STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMM!, iN DEC 2 7 2012 REPORT OF SUNDRY WELL OPERATIONS AOGGC 1.Operations Abandon U Repair Well Li Plug Perforations U Perforate U Other Li Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown0 Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development ISI Exploratory ❑ - 210-077-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 " 50-029-20435-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028285 PBU D-11 B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12003 feet Plugs measured 11350 feet true vertical 9061.11 feet Junk measured None feet Effective Depth measured 11350 feet Packer measured See Attachment feet true vertical 9042.43 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 36-116 36-116 1490 470 Surface 2644 13-3/8"72#L-80 36-2680 36-2679.76 4930 2670 Intermediate None None None None None None Production 7364 9-5/8"47#L-80 36-7400 36-6463.39 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11220-11250 feet 11420-11720 feet 11760-11860 feet True Vertical depth 9038.1-9040.38 feet 9042.1 -9040.79 feet 9040.89-9044.03 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 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: 614 38502 372 0 1059 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development is Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil , U Gas Li WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCE 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 Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature 14(' C�,_71 , Phone 564-4424 Date 12/21/2012 � r4,'_-. Lit 2 3 201 j L. z 8-/L • Packers and SSV's Attachment ADL0028285 SW Name Type MD TVD _ Depscription D-11B PACKER 10155 8777.12 4-1/2" BakerS-3 Packer D-11 B PACKER 10162 8780.46 3-1/2" Baker 45 KB Packer m a ° ce) 1110000 pd r— vNCNO N- V Ernc° o c0 O ( P ° ro) °v co) M .— COr) CO c) co o) Lo r- cf) CO M O O O CO CO M CO CO CO CO co O CO N CO N M N LO MMOOMMMCCi O CO COO CO co C — co co 0 0 co Lo O O N M O N O N Q N ON •Ct CO CD LO CD N M O O O M C) M M _ 0 � J O O co 000 C = U o0co vf co c9 J J M M! J N4 03 V y O N N CO 00 00 M _ p - '— — N- In CV L O E co Ca O LO CO N CO0C OI CD () COCe) JC•) ' — f— N z O W CM 0 0 0 �i Daily Report of Well Operations ADL0028285 '• w . Job Scope: MR AdF RU. Kill well down backside. FP w/40 bbls 60/40. RIH w/2.25" JSN & 2.20" Memory GR/CCL in carrier. Got good data +20' correction. RIH w/WFD setting tool & CIBP max OD 2.22" 11/27/2012 «<In Progress>>> Caw%T7b" CT. Job Scope: CIBP,AdPerf RU. Kill well down backside. FP w/40 bbls 60/40. RIH w/2.25" JSN & 2.20" Memory GR/CCL in carrier. 11/27/2012 «<In Progress>>> CTU#9 w/ 1.75" CT. Job Scope: CIBP,AdPerf RU. Kill well down backside. FP w/40 bbls 60/40. RIH w/2.25" JSN &2.20" Memory GR/CCL in carrier. Log up from 11,944'CTM (TD) to 9,800'CTM at 50 fpm. POOH. Got good data +20' correction. RIH w/WFD setting tool & CIBP max OD 2.22". At flag correct to Ref Log: BKR MWD Multi Propagation Resitivity/GR dated 19-July-10. Set mid element of 2-7/8" WFD DB-10 CIBP at 11,350.2'ELM (top of plug is 11,349.7'ELM, good indication of set). POOH. Recover 172"baTERlR T t 2' 3D'PYflMX 6 SPF 60 Deg 11/27/2012 Perf Guns. «<In Progress>>> CTU#9 w/ 1.75" CT. Job Scope: CIBP,AdPerf «<Continued from 11/27/12>>> RIH w/SLB 2"x 30' PJ HMX 6 SPF 60 Deg Perf Guns. Tag top of CIBP at 11,331'CTM. Corrrect depth to bottom shot using CIBP tag. PU to shooting depth. Performs 1.1,220- 11/28/2012 11.250'ELM. POOH. Left well FP w/ >40 bbls of 60/40. «<Job Complete>>> TREE= • CAN SAFETI ES: WELL ANGLE>70"©10334'"BEFORE 1tUT3 ACTUATOR FMC D-1 1 B MOVE NO-GO ON RUNNING STYLE "4-1/2'KG-2 NE TBG& ACTUATOR= AXELSON KB.ELEV= 71.7" 7'LW*"ORIG&"A"VVELLBORE NOT SHOWN" BF.ELEV= 46.56' I 1 KOP= 3221' Fr V* 350' H NEW TOP OF CEMENT 11/23/04 Max Angle --I__„__94°011141' 20'COND — 100' 1•� To I 2215' H4-1/2”HES SSSV NP,D=3.813" I Datum MD= 10204' 1•• O 44 Datum TVD= 8800'SS li 4 4 i 2613' 9-5/8'DV PKR 13-3/8'CSG,72#,L-8OBTRS,D=12.347" H 2668' ITA ei. GAS LFT MANDRELS ST MD TVD DEV TYFE VLV LATCH FORT DATE Minimum ID =2.370" @ 10162' 6 3075 3074 7 FESTB DMY RM 0 06/19/12 45 KB LINER TOP PACKER 5 5479 5068 43 I-ES TB DMY RM 0 06/19/12 L 4 7141 6278 44 I—S TB DMY RA 0 01/10/96 3 8010 6970 23 KBG2LS "DMY NT 0 03/18/98 9-8/5'X 7"71W SN-6 AT TB FKR,13=7.38" —I 7256' / 2 9124 7984 24 KBG2LS "DMY NT 0 03/18/98 I9-8/5'X 7"TNV LNR HGR,D=8.249" 7269' 1 10077 8818 54 KBG2LS "ENV NT' 0 03/18/98 "PROBLEM MANDRQ'S REQUIRING SPECIAL VALVES 9-5/8'C-G,47#,L-80 BTRS,D=8.681" I 7400' (NOTE STA#3=DMY HAS EXTB4 "3)PKG) X 10144' H4-1/2"I-E5X NP,D=3.813" MLLOUT WINDOW (DQ11A)7400'-7455' ' 10155' —19-5/8'X 4-1/2"BKR S-3 PKR,D=3.875" I 7"LNR,29#,L-80 BTC,XO TO 13CR NSCC —I 9668' . v, A 2 C.A' 10162' H45 KB LNR TOP PKR,D=2.370' I ESTIMATED TOP OF CEMENT — 10170' q : I 10171' H 3-1/2 BIT'G8l DEPLOY SLV,D=3.00" I .1 10178' H4-1/2'FES X NP,D=3.813"(13801)LNR) I 11 i 10192' Jh3- 1/2'OTS X NP,D=2.812" I 1 #� I I 1 10199' 4-1/2"HES XN NP,D=3.79 4-1/2"TBG, 12.6#,13CR NSCT, -I 10211' • • (NiLED 06/29110) BEHIND .0152 bpf,D=3.958' V s4. 10211' H4-1/2"WLEG,D=3.958" I LINER � •� • 10211' --I B MO TT LOG ON??/??/??J• 3-1/2'LNR,9.3#,L-80 STL,.0087 bpf,D=2.992' 10287' ,4, •.■ � •∎ /•�• 10287' I--{3-1/2"X 3-3/16'XO,E)=2.786"• 7'vH IPSTOcK(06/27/10) H 10300' I •:;` .. •. 7"LNR,29#,L-80 BTC,.0371 bpf,D=6.184" —I 10300' . MLLOUT WINDOW (D-11B)10310'-10317' ••••••■ � •�•�•�••• I 10385' 3-3/16"X 2-7/8"XO,D=2.377" I PERFORATION SUMAARY REF LOG:SLB MGM ON 07/21/10 ANGLE AT TOP PI32F:91°0 11420' I 10386' —{2-718'MARKER JOINT Note:Refer to Production DB for historical pert data `2.4,_I i z-o SIZE SFF INTERVAL Opn/Sqz SHOT SOZ 2" 6 11220-11250 0 11/28/12 s/ 11350' 2-7/8"CEP LM,6.2#,L-80 STL, — 10384' I (11/28112) 2' 6 11420-11720 C 07/20/10 0075 bpf,D=2.80' 2" 6 11760-11860 C 07/20/10 ` FBTD 11963' I2-718"LNR,6.4#,L-80 STL,.0058 bpf,D=2.441" H 12003' I ii f "( �( -u Pm ow 0 7-7D Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator @bp.com] �� /� Sent: Tuesday, June 05, 2012 11:55 AM I To: 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; 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; Glasheen, Brian P; AK, OPS Well Pad DG Cc: AK, D&C Well Integrity Coordinator; Walker, Greg (D&C); LeBaron, Michael J; King, Whitney Subject: UNDER EVALUATION: Producer D-11B (PTD#2100770) Sustained OA Casing Pressure Above MOASP Attachments: D-11 B (PTD#2100770) TIO Plot.doc; D-11 B (PTD#2100770)wellbore schematic.pdf All, Producer D-11B (PTD# 2100770) has confirmed sustained OA casing pressure above MOASP. The wellhead pressures were tubing/IA/OA equal to 1260/1060/1060 on 6/4/2012. 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. Pumping: MIT-IA to 3000 psi 2. Downhole Diagnostics: Monitor well for 5 days online to establish OA build up rate - A TIO plot and wellbore schematic have been included for reference. «D-11B (PTD#2100770) TIO Plot.doc» «D-11B (PTD#2100770) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Sef ce-P to60 Gerald Murphy (alt. Mehreen Vazir) c f P= 5'3 P5,, Well Integrity Coordinator a r- 1 9.1 64, Office (907)659-5102 v1alrct Pie" Cell (907) 752-0755 Email: AKDCWeIIIntegrityCoordinatorCa�BP.com 1 0 2 400c 1— g0000 'III IF I r- C.3.1 tia 4- 3=3 CNI r_ C.‘1 4- 8 th CN 3 444 c-N-1 4* 0•31 4. 1 031 a _ IF " c, t7;"1 CO C) Ci) CI) C CN tO 8 G, c:J 6 CL N CO I— I-0 TREE= ‘ ' CMV SAFETY N : WELL ANGLE>70'@ 10334'**BEFORE ATCH WELLAA = FMC D-1 B MOVE NO-GO ONLRUNNI GLHEAD 1/22'**4 1/2 C RO ET G&KBG-2LS GLM, ACTUATTOR R= AXELSON KB.ELEV= 71.7" 7"LNR**ORIG&"A"WELLBORE NOT SHOWN** BF.ELEV= 46.56' ( i KOP= 3221' vs >',. 350' I-I NEW TOP OF CEMENT 11/23/04 I Max Angle= 94°@ 11141' 20"CONDUCTOR 100' I� ��� 2215' 1-14-112"HES SSSV NIP,ID=3.813" 1 Datum MD= 10204' 0 0 �� Datum TV D= 8800'SS r� .- 2613' H9-5/8"DV PKR I 13-3/8"CSG, 72#,L-80BTRS. ID=12.347" H I 2668' , '•# GAS LIFT MANDRELS in 'L-q P= 53 0 P c; ST MD TV D DEV TYPE VLV LATCH PORT DATE Minimum ID =2.370" @ 10162' 6 3075 3074 7 HES TB DOME RA 16 08/03/10 45 KB LINER TOP PACKER 5 5479 5068 43 HES TB SO RA 20 08/03/10 L 4 7141 6278 44 HES TB DMY RA 0 01/10/96 3 8010 6970 23 KBG2LS **DMY INT 0 03/18/98 9-8/5"X 7"TM/SN-6 AT TB PKR,ID=7.38" -I 7256' r, i 2 9124 7984 24 KBG2LS **DMY INT 0 03/18/98 9-8/5"X 7"TIW LNR HGR, ID=8.249" -I 7269' r 1 10077 8818 54 KBG2LS **DMY INT 0 03/18/98 **PROBLEM MANDREL'S REQUIRING SPECIAL VALVES 9-5/8"CSG,47#,L-80 BTRS,ID=8.681" -I 7400' I (NOTE:STA#3=DMY HAS EXTENDED PKG) 'kl?= 6(670rVi X 10144' .1-j 4-1/2"HES X NIP,ID=3.813" I MILLOUT WINDOW (D-11A)7400'-7455' , 10155' H9-5/8"X 4-1/2"BKR S-3 PKR, ID=3.875" I 7"LNR,29#,L-80 BTC,XO TO 13CR NSCC -I 9668' y '. A'1 F1" 10162' 1-145 KB LNR TOP PKR,ID=2.370" I ESTIMATED TOP OF CEMENT -1 10170' I 4 . I 10171' H3-1/2"BTT GEN DEPLOY SLV, ID=3.00" I I I 10178' I-14-1/2"HES X NIP,ID=3.813"(BEHIND LNR) I 4 i 10192' 1-13-1/2"OTIS X NIP, ID=2.812" I 4 4 1 . 10199' I 4-1/2"HES XN NIP, ID=3.79" 4-1/2"TBG, 12.64,13CR NSCT, --I 10211' j� j (MILLED 06/29/10) BEHIND .0152 bpf, ID=3.958" V j4. 10211' I-14-112"WLEG, ID=3.958" I LINER : : 10211' -I ELMD TT LOG ON??/??/??1 3-1/2"LNR,9.3#,L-80 STL,.0087 bpf, ID=2.992" 10287' V, 4!'4 � •, ■�•�• 10287' _I-13-1/2"X 3-3/16"XO,ID=2.786" I• 7"WHIPSTOCK(06/27/10) 10300' ••• 1' 7"LNR,29#,L-80 BTC, .0371 bpf,ID=6.1$4" --I 10300' ,�+� , MILLOUT WINDOW (D-11B) 10310'- 10317' � •••�••• 10385' 1-13-3/16"X 2-7/8"XO,ID=2.377" I PERFORATION SUMMARY I 10386' H2-7/8"MARKER JOINT I REF LOG:SLB MCNL ON 07/21/10 / `` ANGLE AT TOP PERF:91°@ 11420' 3-3/16"LNR,6.2#,L-80 STL, --I 10384' I Note:Refer to Production DB for historical perf data .0075 bpf,ID=2.80" `` PBTD -i 11963' SIZE SPF INTERVAL Opn/Sqz DATE ` 2" 6 11420- 11720 0 07/20/10 ` 2" 6 11760- 11860 0 07/20/10 ■ 2-7/8"LNR,6.4#,L-80 STL, .0058 bpf, ID=2.441" 12003' !... DATE REV BY COMMENTS ; DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/29/80 ORIGINAL COMPLETION t 01/11/11 AK/PJC FINAL DRLG CORRECTIONS WELL: D-11B i 01/14/96 D-09 CTD SIDETRACK(D-11A) PERMIT No: 2100770 07/24/10 NORDIC 1 CTD SIDETRACK(D-11 B) API No: 50-029-20435-02 07/27/10 PJC DRLG DRAFT CORRECTIONS SEC 23,711N.R13E,2239'FSL&1067'FEL 08/27/10 ?/AGR i GLV C/O(08/03/10) i 09/13/10 PJC _GLV CORRECTIONS BP Exploration(Alaska) by BP Exploration(Alaska)Inc. Attn:Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage,Alaska 99519-6612 March 06, 2011 a I 0 0 177 P- 1Y Mr. Tom Maunder RECEIVED Alaska Oil and Gas Conservation Commission 333 West 7th Avenue ;.? Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB D Pad Altrka Oil&08S Con:.CrO ;n !Inchon Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator i N 0 ... 0 " w T r T r T r r r , r0 r r 6 - - 0�V N N N N N N N O N N N N 0�V N N N N N N N N N N N 0�V N N N -,. co ,- 0, 00 , Cnaatc rtntn0m . 000. 0 0) 0 CD o) o O _ w r a - rar o ra .- TC mTr aaaaaaa aa rr CA a . _ 0 H C i ' O) . < pp 0 V 0 0 0 0 o S o o o o o O S O O- O to S O M O 0 o N O N R C 2 -0 as V VvVtn 7Lq °Z! CDCDV Vr CD ao V ►� n— �C D3O MMMMWR W N OOOMAMrMCOMSMT1 c"_ N 1. U O Cl) U _ . o o a — o ;p mta < < < < < < < < < < aaaaaa < < < < < < < < < < < < aaa ■ c C z z z z z z z z z z z z z z z z z z z z z z z z z z z z z z z 1 0 N C o C U i-► 2 o -y c 6 CC at i 6. %.' O N Q .q. to t0 M F, M O M to N N r V aD Co N N . O M M M M N M N U) G W aEi ZT � OOOOOC�iMr0000rtri00cidmd OOOMC■iMN CO co V o LE Q C r . `. 0.1 0 _ C E o ' d o EV o I ( o E� zzzzzzzzzzzzzzzzzzzzzzzzzzzzzzz CO i . a • to 0 0_0 C > 0 < 'C o x L w o cam - ' d. o o 8g88888'88 0 0 0 0 0 0 0 0 0 0 0 0 0 0 , CO O S $ $ $ o $ O o 0 0 1 0 0 0 o 88 S 0 0 0 0 r r N O r N r O r p0 r r r r N r N p0 M r p O r N pN O N r d0' COO W S N N OT S) too C7 Oo) S O CO) N OV � O aD - UOD CO N S CC') CO 0 t00 N N 88886-68883388888888888 "MO0M �c) `O�) � � T < N N N N N N N N N N N N N N N N N N N N N N N N N N N 0) C) to O) C) C) C) C) O) O) 0) 0) 0) C) O 0) C) O) O) C) 0) O) 0) 0) C) 0) O) C) C) C) O) N o o 0 0 0 0 0 0 0 0 0 0 6 o o oo0000000 08 o o o to o o o o o o o o o o o o o o o uo o U) Uo o o u) o o to U y V o 0 p p 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 M V S CO M r M to M r to M N CO T M N N CD C) V U M C) M V t0 CO d 0 n M r 0 -1 Co N CD to "n r aD CO T N r O r 0 ,,, 000 § § 0C900/ 2 0 r r 0 r r 00 08 0 0p r N O r r r cc0 .0. .,- ,- N r O N it Q M 0 O P N 0 0 S n r a0D 0 0 0 0 0 0 0 W C0 O O) U) 0 0000 ) S L r N N r r N N r r N r N r r N N N N r r N r r N N N N T N r T Cl) W < < a) ,0 Q m Q Q 0 m N 0 0 0 Q m Q m 0 r U Q V < m Q m 0 m Q M FS M V O n M r r r M V to CO " CC) O N N N M N to CO f� RI N O M z 0 0 0 O O O O T N N N N N N M M m a a a ° a a a a a 0 a 0 0 0 0 0 O 0 0 0 0 th 0 a 0 a th th a 0 $ INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage,Alaska 99501 , " Attention: Christine Mahnken Reference: D-11B 6 3� '% 0 Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print—GR Directional Measured Depth Log (to follow) 1 color print—MPR/Directional TVD Log (to follow) 1 color print—MPR/Directional Measured Depth Log (to follow) LAC Job#: 3270986 bra Sent by: Lauren Veronie Date: 2/22 i Received by: ( ' Date: FEB 2 4 2011 O l C ,r= PLEASE ACKNOWLEDGE RECEIPT BY SIGNINtricARTURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 0/0 7260 Homer Drive �u�. BAICER Anchorage,Alaska 99518 00 HUGHES Direct: (907)267-6612 INTEQ .. FAX: (907)267-6623 7, FEB. 2011 .; Anhwei,' . BALKIER 1411.1147.141111115 Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION(ALASKA)INC COUNTY NORTH SLOPE BOROUGH WELL NAME D-11B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 2/22/2011 THIS DISTRIBUTION LIST AUTHORIZED BY: LAUREN VERON IE SO#:3270986 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION(ALASKA)INC 1 Company DNR-DIVISION OF OIL&GAS Person PETROTECHNICAL DATA CENTER Person CORAZON MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE,AK 99508 ANCHORAGE,AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON,TX 77002 1 Company STATE OF ALASKA-AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W.7TH AVE Address SUITE 100 ANCHORAGE,AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv:BAKER ATLAS-PDC 17015 Aldine Westfield,Houston,Texas 77073 This Distribution List Completed By: giO Page 1 of 1 Air t STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ®Oil ❑Gas ❑SPLUG ❑Other ❑Abandoned ❑Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑Exploratory ❑GINJ ❑WINJ ❑WAG ❑WDSPL ❑Other No.of Completions One ❑ Service ❑Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska)Inc. 07/24/2010 210-077 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 7/15/2010 50-029-20435-02-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 7/19/2010 PBU D-11 B 3040'FNL, 1067'FEL, SEC.23,T11 N, R13E, UM 8. KB(ft above MSL): 82.91 15.Field/Pool(s): Top of Productive Horizon: 1622'FNL,4947'FEL, SEC.23,T11 N, R13, UM GL(ft above MSL): 45.16 Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 1853'FNL,3919'FEL, SEC.23,T11 N, R13, UM 11963' 9054' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 654116 y- 5957961 Zone- ASP4 __ 12003' 9061' ADL 028285 TPI: x- 650207 y- 5959301 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 651239 y- 5959090 Zone- ASP4 None None 18.Directional Survey: ® Yes ❑No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD DIR, GR, RES, ROP, CCL, Memory CNL 10308' 8928' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE Top I BOTTOM TOP I BOTTOM SIZE CEMENTING RECORD PULLED 20"x 30" Insulated Conductor Surface 110' Surface 110' 36" 10.6 cu vds Arctic Set Concrete 13-3/8" 72# L-80 Surface 2669' Surface 2669' 17-1/2" 3841 cu ft Permafrost II 9-5/8" 47# L-80 Surface 7400' Surface_ 6463' 12-1/4" 1382 cu ft'G'. 130 cu ft PF'C' , 7" _ 29# 13CR/L-80 7256' 10308', 6361' - 8928' 8-1/2" 320 Cu ft Class'G' _ , 3-1/2"x 3-3/160 9.2#/6.2# L-80 10170' 8867' 12003' 9061' 4-1/8" 112 cu ft Class'G' ✓ x 2-7/8" /6.4# 24. Open to production or injection? 0 Yes ❑No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND) (MD+TVD of Top&Bottom;Perforation Size and Number): 2"gun diameter,6 SPF 4-1/2", 12.6#, 13Cr 10211' 10155'/8860' MD ND MD ND 11420'-11720' 9042'-9041' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 11760'-11860' 9041'-9044' ------- :� !EPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1 cots^PLETION 2500' Freeze Protected with Diesel 4 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): August 7,2010 _ Flowing ____ Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 08/11/2010 6 Test Period ♦ 275 4755 214 176 17267 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 929 560 24-Hour Rate♦ 1101 19020 856 Not Available 28. CORE DATA Conventional Core(s)Acquired? ❑Yes ®No Sidewall Core(s)Acquired? ❑Yes IS No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and prey essence�f Ril, !-s • - er (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical resia1 , . i i 1 i 071. None 4 2010 RBDMS AUG 2 5 .201 14117 . . °° Ails,..4CATIMISSIC n , 'qn me Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 7Z /,Z/.// Submif Original Only , G 29. GEOLOGIC MARKERS(List all formations and marKers encountered): 30. ,-ORMATION TESTS NAME MD ND Well Tested? ❑Yes IS No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 25N/Zone 2B 10448' 8976' None 24N/Zone 2B 10550' 9006' Formation at Total Depth(Name): TDF/Zone 1A 12003' 9061' 31.List of Attachments: Summary of Daily Drilling and Post-Rig Reports,Well Schematic Diagram,and Surveys 32.I hereby certify that the f• egoing is true and correct to the best of my knowledge. Signed: S•■dra Ste rf Ol - Title: Drilling Technologist Date: Ce, ��1 s3— I 1 PBU D-11 B 210-077 Prepared By Name/Number. Elizabeth Barker, 564-4628 Well Number Permit No./Approval No. Drilling Engineer: Amanda Suddreth, 564-5543 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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. Item 1 a: 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. Item 4b: TPI(Top of Producing Interval). Item 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. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: 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. Item 30: 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 12/2009 Submit Original Only s D-11 B, Well History Date Summary 24-Jul-2010 T/I/O =0/0/0 SET 6" CIW J BPV#421 THRU STACK @ 78" USING 4-5' 1-2' EXT. NORDIC 1 RDMO 26-Jul-2010 T/I/O=VAC/80/120 PRESSURE TESTED LUBRICATOR LOW: 300 PSI/PASS HIGH: 3500 PSI/PASS. PULLED 6-3/8" CIW "J" BPV#421 THRU TREE, 1-2' EXT USED ..TAGGED @ 108". REPRESSURE TESTED LUBRICATOR PASS ON BOTH HIGH AND LOW TESTS, SET, 6-3/8" CIW "J"TWC#406 WITH SAME EQUIPMENT....POST CTD..NO PROBLEMS. 26-Jul-2010 T/I/0=0/50/120 TESTED LUBRICTOR : LOW-300 PSI/5 MIN,-PASS, HIGH-3500 PSI/5 MIN.- PASS; SHELL TESTED TREE TO LOW-500 psi/5 MIN.-PASS, HiIGH- 5000 psi/PASS; PULLED 6-3/8" CIW "J"TWC#406, 1-2' EXT., USED, TAGGED @ 114" ; POST NORDIC 1 26-Jul-2010 T/I/O=0/80/120 TORQUED ALL TREE FLANGES TO API SPECS FOR 1 3/8" STUD. POST NORDIC 1. 2-Aug-2010 RIG UP UNIT 4517 CURRENTLY RIH W/4-1/2"WHIDDON C-SUB ***CONT WSR ON 8/3/10*** 3-Aug-2010 CONT WSR FROM 8/2/10*** SET 4-1/2"WHIDDON C-SUB AT 10,141'SLM. PULL RA-DGLV FROM STA# 5(5,463'SLM) STA#6(3,057'SLM). SET RM-LGLV IN STA#6 AT 3,057'SLM/3,074'MD. SET RM-S/O IN STA#5 AT 5,463'SLM/5,479'MD. PULL 4.5 WHIDDON C-SUB FROM 10,141' SLM (empty) ***WELL LEFT S/I*** PAD OP NOTIFIED 9-Aug-2010 T/I/O=850/1120/1130. TEMP= 146°. IA&OA FL PRE-BLEED). AL SI @ CASING VALVE ALP =0 psi. DIRTY GAS LIFT JUMPER FROM D-12 IS SI (2450 psi). IA FL @ 5479' STA#5 SO (293 bbls). OA FL @ 210' (12.2 bbls), TOC IS @ 350' PER SCHEMATIC. FO REPORTS BLEEDING MULTIPLE TIMES YESTERDAY. BLED OAP FROM 1130 psi TO 0+psi IN 1 MIIN. SI AND MONITOR FOR 30 MIN. OAP INCREASED 450 psi. PPPOT T& IC PASSED 12-09. FW H Ps =850/1120/450. 10-Aug-2010 TIO=520/1150/1150. TEMP=152°. BLEED IAP - 500 psi, OAP TO 0 psi EVAL IAxOA COMM AL SI @ CASING VALVE. ALP=0 psi. INITIAL IA FL @ 5478' STA#5, OA FL @ 206'? BLED IAP DOWN PRODUCTION TO 550 psi IN 1.7 HRS., OAP IS TRACKING IAP. BLED OAP to 0+ psi <5 MINS (ALL GAS). SI BLEED MONITOR PRESSURES FOR 30 MINS. IAP REMAINED UNCHANGED, OAP INCREASED 380 psi. FINAL WHPs=540/550/380. JOB COMPLETE 11-Aug-2010 T/I/0=1350/560/560.TEMP=147°. WHP's, OA GAS SAMPLE (EVAL HIGH-OAP). ALP=0 psi, SI CO CASING VALVE. **OBTAINED OA GAS SAMPLE. Page 1 of 1 North America-ALASKA- BP Page 1 of 9 Operation Summary Report Common Well Name: D-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 7/13/2010 End Date: 7/19/2010 X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.:NORDIC 1 I Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/13/2010 15:10 - 15:30 0.33 RIGU P WEXIT PJSM REGARDING PULLING COIL ACROSS& STABBING COIL. 15:30 - 16:05 0.58 RIGU P WEXIT PU INJECTOR. PULL TEST STABBING WINCH CTC-OK.REMOVE SHIPPING BAR. PULL COIL ACROSS&STAB INTO INJECTOR. 16:05 - 16:10 0.08 RIGU P WEXIT RD STABBING CTC&WINCH CABLE. 16:10 - 16:40 0.50 RIGU P I WEXIT TEST E-LINE CABLE-GOOD TEST.SEAL END OF WIRE.STAB ONTO WELL. '16:40 - 18:00 1.33 RIGU P WEXIT SLOWLY FILL COIL WITH 8.34PPG 2%KCL. 18:00 - 18:20 0.33 BOPSUR P WEXIT PRESSURE TEST INNER REEL VALVE& PACKOFFS,25OPSV3500PSI. 18:20 - 18:35 0.25 RIGU P WEXIT PUMP SLACK INTO REEL. 18:35 - 21:30 2.92 RIGU P WEXIT POP OFF WELL.RU COIL CUTTER, CUT 325 FT OF COIL(NO E-LINE) INSTALL CTC AND PULL TEST TO 35,000#'S. INSTALL SWIZZLE STICK STAB ON WELL AND PUMP SLACK FORWARD.UNSTAB INJECTOR 21:30 - 22:30 1.00 J RIGU P WEXIT INSTALL BHI-UQC AND PT TO 3500 PSI 22:30 - 23:40 1.17 RIGU P WEXIT PU WINDOW MILLING BHA WITH NEW WINDOW MILL AND USED STRING REAMER BOTH WERE 3.80 GO 3.79 NO GO. STAB ON TEST TOOLS AND OPEN EDC. 23:40 - 00:00 0.33 RIGU , P WEXIT RIH WITH WINDOW MILLING BHA(BHA#1) DISPLACING FP FLUIDS TO TT 7/14/2010 00:00 - 01:45 1.75 STWHIP P WEXIT CONTINUE TO RIH TO 8880 FT TO TIE IN 01:45 - 02:25 0.67 STWHIP N MAN-, WEXIT LOG FROM 8880 FT TO 8910 FT STOP AND RIH TO NEW/RIGHT DEPTH TO LOG FROM 9880 FT 02:25 - 03:30 1.08 STWHIP P WEXIT LOG DOWN FROM 9880 FT TO 10000 FT NO CORRECTION 03:30 - 04:30 1.00 STWHIP P WEXIT RIH TO 10262 FT AND CIRCULATE WELL I OVER TO USED POWER VIS SYSTEM THROUGH OPEN EDC AT 3.6 BPM 04:30 - 04:50 0.33 STWHIP P WEXIT CLOSE EDC RIH AND DRY TAG AT 10,308 FT PU WT=44K/BO=46K PU AND BRING PUMPS UP FS=2330 @ 2.5 BPM TAG AT 10307.8 FT 04:50 - 06:15 1.42 STWHIP P WEXIT TIME MILL WINDOW PER WINDOW MILLING._ RP'S AND BTT TOOL HAND SLOW MILL FIRST 1 FT OF WINDOW SO AS NOT TO EXCEED 300 PSI OF MW 06:15 - 08:30 I 2.25 STWHIP P WEXIT C/O WITH NIGHT CREW. CONTINUE TO TIME MILL WINDOW FROM 10309.4FT USING USED 8.63PPG POWER-VIS AT 2.46BPM,2330PS1,100-150PSI MW,1 FT/HR ROP,0.6-1.5K WOB,9.47PPG ECD,PVT=319. MILL TO 10311.4FT 08:30 - 11:20 2.83 STWHIP N DFAL 10,311.40 WEXIT POH DUE TO P&C ISSUES.TOOL WILL WORK FINE FURTHER UP HOLE. 11:20 - 11:35 0.25 STWHIP N DFAL WEXIT FLOW CHECK&PJSM REGARDING LD MILLING BHA. 11:35 - 12:00 0.42 STWHIP N DFAL WEXIT POP OFF.STAND BACK INJECTOR.BLOW DOWN&LD MILLING BHA. MILLS WERE 3.80". Printed 8/19/2010 2:50:41 PM North America -ALASKA- BP Page 2 of 9 Operation Summary Report Common Well Name: D-11 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:7/13/2010 End Date:7/19/2010 X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 13:20 1.33 STWHIP N DFAL WEXIT TEST SLB COLLECTOR&JUNCTION BOX- i OK.MEG E-LINE IN REEL-OK. CHECK CTC- OK.PREVIOUS BHA TESTED FINE ON SURFACE. 13:20 - 13:40 0.33 STWHIP N DFAL WEXIT MU WINDOW MILLING BHA.CONDUCT D1 TRIPPING DRILL. HOLD AAR.STAB ONTO WELL. POWER UP&TEST TOOLS.SET COUNTERS. 13:40 - 14:30 0.83 STWHIP N DFAL WEXIT _RIH WITH WINDOW MILLING BHA(BHA#2). 14:30 - 15:00 0.50 STWHIP N SFAL WEXIT STOP AT 4256FT&REPAIR BADLY WORN GOOSENECK ROLLER. 15:00 - 16:05 1.08 STWHIP N DFAL WEXIT CONTINUE TO RIH. 16:05 - 16:15 0.17 STWHIP N DFAL WEXIT LOG DOWN:FOR'TIE-IN FROM 9900FT.MINUS 1 FT CORRECTION. 16:15 - 16:45 I 0.50 STWHIP N DFAL WEXIT CONTINUE TO RIH. 16:45 - 19:05 2.33 STWHIP P WEXIT CONTINUE TO TIME MILL WINDOW FROM 10311.2FT USING USED 8.63 PPG POWER-VIS I AT 2.52 BPM,2315 PSI,100-150 PSI MW,1 FT/HR ROP,2.0-2.5K WOB,9.80 PPG ECD,PVT =324.MILL TO 10314.3FT 19:05 - 20:10 1.08 STWHIP f P WEXIT STILL MILLING AHEAD BUT GETTING I INTERMITEN TOOL COMS 20:10 - 20:50 0.67 STWHIP P WEXIT AT 20:10 TOOL COMS FAILED COMPLETLY CONTINUED TO MILL AHEAD WATCHING MW OF 200 TO 300 PSI HAD 2 PRESSURE SPIKES AT 10314.4 FT OF 3200 PSI AND 10,314.6 FT OF 3000 PSI THAT BROKE OVER AND CONTINUED TO MILL NORMAL-NO PICK UPS. 20:50 - 22:00 1.17 STWHIP P WEXIT AT 20:50 AFTER TROUBLE SHOOTING ALMOST ALL SURFACE EQUIPMENT WE SUSPECTED"DIRTY"RIG POWER. SWITCHED TO SATELLITE CAMP GENERATOR AND ISOLATED FROM RIG POWER. CONNECTION TO TOOL COMS WAS REESTABLISHED AND WORKING FINE. STILL MILLING AHEAD WITH 200 TO 300 PSI OF MW AND-3300#'S OF DH WOB. 22:00 - 22:45 0.75 STWHIP P I WEXIT AT 10,315.7 WINDOW MILL IS AT THEORETICAL EXIT STARTED ABU SAMPLE AND CONTINUE TO TIME MILL AHEAD WITH 200 TO 300 PSI OF MW AND ALLOWING FOR MORE TIME AS NEEDED TO LET WEIGHTS AND PRESSURES MILL OFF AVERAGE DH WOB-3200#'5 BELIEVE THE BIT IS OUT THE WINDOW AT 10,316.3 FT 22:45 - 23:30 0.75 STWHIP P WEXIT CONTINUE TO TIME MILL ALOWING STRING REAMER TO CLEAN UP THE WINDOW. BY 10,317.2 FT THE STRING REAMER SHOULD BE OUT THE WINDOW TOO. 23:30 - 00:00 0.50 STWHIP P WEXIT MILL RAT HOLE BHA HAS BEEN WORKING GREAT ON SAT CAMP POWER.@ 23:40 SWITCHED BACK TO RIG POWER TO SEE IF PROBLEMS COME BACK. 7/15/2010 00:00 - 01:20 1.33 STWHIP P WEXIT CONTINUE TO MILL RAT HOLE FROM 19,319.6 FT TO 10,326.3 FT Printed 8/19/2010 2:50:41 PM North America-ALASKA- BP Page 3 of 9 Operation Summary Report Well Name: D-11 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 7/13/2010 End Date: 7/19/2010 X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:20 - 03:15 1.92 STWHIP P WEXIT DRESS WINDOW FIRST UP PASS CLEAN. FIRST DOWN PASS HAD SMALL AMOUNT OF MW AT TOP OF WINDOW. ALL SUBSAQUENT PASSES WERE CLEAN DRY DRIFT WINDOW WAS CLEAN TOOL COMS WERE LOST AGAIN @ 01:25 AND 01:40 WHILE BACK ON RIG POWER SWITCHED BACK TO SATELLITE CAMP POWER AND COMS WERE REASTABLISHED. TRIED TO SET DOWN ON BOTTOM AND PUT WEIGHT ON TOOLS TO SEE IF IT MADE ANYDIFFERANCE AND TOOLS CONTINUED TO WORK FINE. 03:15 - 05:10 1.92 STWHIP P WEXIT OPEN EDC AND POOH AT 3 BPM PVT=326 BBLS ON BOTTOM PULL SLOW THROUGH 7" 05:10 - 06:05 0.92 STWHIP P WEXIT TAG UP&FLOW CHECK WELL UNSTAB INJECTOR AND LD MILLING BHA WINDOW MILL WAS 2.78 NO GO AND 2.79 GO STRING MILL WAS 2.79 NO GO AND 2.80 GO 06:05 - 06:50 0.75 DRILL P PROD1 MU BUILD BHA WITH RESISTIVITY,2.7AKO MOTOR&REBUILT HYC T-REX. 06:50 - 08:40 1.83 - DRILL P PROD1 RIH WITH BUILD BHA(BHA#3).CIRCULATE AT 0.25BPM/980PSI. 08:40 - 08:50 0.17 - DRILL P I PROD1 'LOG DOWN FOR TIE-IN FROM 9860FT.NO CORRECTION NEEDED. 08:50 - 09:05 0.25 DRILL P PROD1 RIH 0.25BPM/.RUN THROUGH WINDOW- 1 CLEAN. 09:05 - 10:50 1.75 DRILL P PROD1 DRILL BUILD FROM 10323 FT USING USED 8.6PPG POWER VIS AT 2.51 BPM,2400PSI, 75-100PSI MW,30-40FT/HR ROP,1.4-1.82K WOB,9.82PPG ECD,PVT=326. DRILL TO 10380.9FT.PVT 329. 10:50 - 11:50 1.00 DRILL P PROD1 DURING INSPECTION OF CABLES GOING FROM SATTELITE OFFICE TO RIG, BHI ETHERNET CABLE WAS DAMAGED. PUH. PULL THROUGH WINDOW-CLEAN.SLOWLY PUH&CIRCULATE 0.66BPM/1 106PSI. 11:50 - 12:00 0.17 DRILL P PROD1 RIH.CLEAN PAST WINDOW. 12:00 - 16:30 4.50 DRILL P PROD1 DRILL BUILD FROM 10380 FT USING USED 8.6PPG POWER VIS AT 2.56BPM,2360PS1, 75-100PSI MW,30-40FT/HR ROP,1.4-2.2K WOB,9.88PPG ECD,PVT=328. DRILL TO 10505FT.PVT 340. 16:30 - 16:45 0.25 DRILL P PROD1 WIPER TO THE WINDOW-CLEAN. 16:45 - 21:25 4.67 DRILL P PROD1 DRILL BUILD FROM 10505 FT USING USED 8.6PPG POWER VIS AT 2.51 BPM,2345PS1, 75-100PSI MW,40-60FT/HR ROP,1.8-2.8K WOB,9.90PPG ECD,PVT=341. DRILL TO 10,650 FT. PVT 338. 21:25 - 21:50 0.42 DRILL P PROD1 WIPER TO WINDOW AND BACK FS=2520 PSI @ 2.46 BPM Printed 8/19/2010 2:50:41 PM 0 North America -ALASKA- BP Page 4 of 9 Operation Summary Report Common Well Name: D-11 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 7/13/2010 End Date: 7/19/2010 X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 1 r Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA 1 UWI:500292043500 Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date i From-To Hrs Task i Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:50 - 00:00 2.17 DRILL P PROD1 DRILL AHEAD FROM 10,650 FT WITH 8.6 PPG GEO VIS 1 200-300 PSI OF MW @ 2.55 BPM ECD=9.93 . PPG I DH WOB= 1,200 TO 2000#'S WE ARE GETTING SMALL PIECES OF RUBBER AT i SURFACE AND NOZZLES PLUGGING AND l UNPLUGGING WHILE DRILLING. ROP'S-40FPH AND SEVXYXOF2TO4 ', MAINLY 3&4 THOUGH. I LOTS OF STALLING IF WE PUSH TO HARD- ROUGH DRILLING ALSO HELD A FIRE DRILL WHILE DRILLING- ] � CREW RESPONSE WAS GOOD AND NO CHANGE TO PROCEDURES WERE NOTED DURING AAR 7/16/2010 00:00 - 02:00 2.00 DRILL P PROD1 CONTINUE TO DRILL AHEAD FROM 10,698 FT STILL HARD DRILLING WITH LOTS OF STALLS. FS=2440 PSI @ 2.5 BPM GEO SAMPLES HAVE OVER 50%CHERT STILL DRILLING WITH"LOW"MW OF ABOUT 150 PSI AND 1,200#'S WOB RUBBER COMING OVER THE SHAKER TOO. LANDED THE BUILD AT 10,710 FT WITH 89 DEG INCLINATION 02:00 - 04:50 2.83 DRILL P PROD1 POOH FOR BHA SWAP PVT ON BOTTOM=335 BBLS PULL THROUGH WINDOW AND OPEN EDC I AND JET OUT 7"LINER POOH @ 3.25 BPM PVT=278-TRIP SHEET WAS ONE FOR ONE. 04:50 - 05:35 0.75 DRILL N RREP 71 PROD1 AFTER TAGGING UP STOP AND INSTAL NEW ROLLER IN GOOSE NECK BEFORE 1 UNSTABING INJECTOR. 05:35 - 05:45 0.17 DRILL P PROD1 UNSTAB INJECTOR AND INSPECT THE LAST 30 FT OF COIL FOR CHROME WEAR. NO ■ SIGNIFICANT WEAR TO THE COIL. 05:45 - 06:05 0.33 DRILL P PROD1 UNSTAB COIL AND STAND BACK INJECTOR 1 I LD BUILD SECTION BHA BIT WAS 2-3 BEARING ASSEMBLY ON DRIVE SUB(ABOVE BIT BOX)IS SHOWING. 06:05 06:30 0.42 DRILL P ' PROD1 MU LATERAL BHA. STAB ONTO WELL. POWER UP&TEST TOOLS.OPEN EDC. 06:30 - 08:50 2.33 DRILL P PROD1 RIH WITH LATERAL BHA(BHA#4). CIRCULATE AT 1.5BPMI1500PSI 108:50 - 09:25 0.58 DRILL P PROD1 CLOSE EDC.LOG DOWN FROM 10300FT 1 ACROSS RA TAG.ADJUST BHI ENCODER. 09:25 - 09:37 0.20 DRILL 1 P PROD1 PUH&RELOG.MINUS 1 FT CORRECTION. 09:37 - 09:55 0.30 DRILL P PROD1 WIPER TO TD.0.5BPM/1100PSI.SLIGHT ISSUE AT 10450FT. 09:55 - 11:10 1.25 DRILL P PROD1 DRILL LATERAL FROM 10712.8 FT USING USED 8.67PPG POWER VIS AT 2.51 BPM, 2450PSI,75-100PSI MW,30-40FT/HR ROP, 0.5-1.82K WOB,9.91 PPG ECD,PVT=321. DRILL TO 10804FT.PVT 329.40K OP. 11:10 - 11:40 0.50 DRILL P PROD1 WIPER TO THE WINDOW&TO TD-CLEAN. 2.5BPM/2400PS1 BOTH WAYS FOR HOLE CLEANING ISSUES. Printed 8/19/2010 2:50:41 PM North America -ALASKA- BP Page 5 of 9 Operation Summary Report Common Well Name: D-11 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 7/13/2010 End Date: 7/19/2010 X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth j Phase Description of Operations (hr) (ft) 11:40 - 12:40 1.00 DRILL P PROD1 DRILL LATERAL FROM 10804 FT USING USED 8.67PPG POWER VIS AT 2.49BPM,2420PSI, 75-100PSI MW,90-110FT/HR ROP,0.5-1.0K WOB,9.99PPG ECD,PVT=329. DRILL TO 10851 FT.PVT 328. 12:40 - 13:30 0.83 DRILL N DPRB PROD1 WIPER TO THE WINDOW-CLEAN. 13:30 - 15:50 2.33 DRILL N DPRB PROD1 OPEN EDC.JET 7"TUBING.POH FOR LARGER BEND MOTOR.CUTTINGS FROM 7" CASING JETTING ACTION WAS OBSERVED GOING OVER SHAKER. JOG AT SURFACE. CLOSE EDC.PJSM REGARDING HANDLING BHA WHILE POH. 15:50 - 16:30 0.67 DRILL N DPRB PROD1 POP OFF.STAND INJECTOR BACK. BLOW DOWN&PURGE BHA.STAND BACK BHA. BIT WAS 1-1, BALLED UP. LD MOTOR&DIAL UP TO 1.5AKO,SCRIBE SAME. 16:30 - 17:15 0.75 DRILL N DPRB PROD1 MU LATERAL BHA WITH 1.5AKO MOTOR& 3.75"PDC GAUGE BIT. 17:15 - 19:15 2.00 DRILL N DPRB PROD1 RIH WITH LATERAL BHA(BHA#5). 19:15 - 19:45 0.50 DRILL N DPRB PROD1 LOG FOR GR TIE IN AT 10,340 FT MADE-1/2 FT CORRECTION 19:45 - 20:45 1.00 DRILL P PROD1 DRILL AHEAD FROM 10,851 FT FS=2380 PSI WITH 8.6 PPG MUD HARD SPOT AT 10,890 STILL DROPING TVD LOOKING FOT HMO/HOT DRILL TO 10,925 FT 20:45 - 21:25 0.67 DRILL P • PROD1 GEO WIPER TO CIRCULATE OUT 10,900 AND 10,925 FT SAMPLES 21:25 - 23:30 2.08 DRILL P PRODL CONTINLIF TC)WRIT t AHFAI)FROM 10925 FL. INCREASING INCLANATION NOW FS=2450 PSI @ 2.5 BPM FAST ROP-90 FPH WITH 2,700#'S WOB&350 PSI MW ECD=10.02 PPG AND NBI=93 DEG VIBRATIONS=2 NEW MUD OUT THE BIT AT 22:45 WHILE DRILLING AHEAD FROM 11,010 FT DRILLED TO 11,050 FT 23:30 - 00:00 0.50 DRILL P PROD1 WIPER TO WINDOW FROM 11,050 FT 7/17/2010 00:00 - 00:20 0.33 DRILL P PROD1 CONTINUE WIPER TO 11,050 FT 00:20 - 03:50 3.50 DRILL P PROD1 !FS=2520 @ 2.5 BPM DRILL AHEAD FROM 11,050 FT INITIAL DRILLING WITH LOW WOB AND 200-400 PSI OF MW UNDULATE THROUGH ZONE PER GEO SLOWER ROP'S WITH ABOUT 1,500#'S WOB TOWARD END OF THIS SECTION MADE SEVERAL BHA WIPERS WHILE CHANGING TOOL FACES. ECD=10.02 PPG BEFORE MUD SWAP AND 9.91 PPG AFTER MUD SWAP AND AT END OF THIS DRILLING SECTION DRILLED TO 11,250 FT 03:50 - 04:45 0.92 DRILL P PROD1 WIPER TO WINDOW Q=2.7 BPM WHILE COMMING UP HOLE @ 30 FPM WIPER IN HOLE WITH REDUCED RATE AND 45 FPM-TAGGED AT 11,050 IN TF CHANGE PU OK AND PASS THROUGH GOOD Printed 8/19/2010 2:50:41 PM North America-ALASKA- BP Page 6 of 9" Operation Summary Report Common Well Name: D-11 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:7/13/2010 End Date:7/19/2010 X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth! Phase Description of Operations (hr) (ft) _ 04:45 - 05:50 1.08 DRILL P PROD1 DRILL AHEAD FROM 11,250 FT FS=2380 PSI @ 2.5 BPM DRILLING WITH 2,600#'S&500 PSI MW ROP=-60 FPH NBI=86 DEG AND VIBRATIONS=3 DRILL TO 11284FT 05:50 - 06:36 0.77 DRILL P PROD1 WIPER WHILE C/O.ASSESS PAST DRILLING OPERATIONS&CURRENT PLAN FORWARD. 06:36 - 07:05 0.48 DRILL P PROD1 DRILL LATERAL FROM 11280 FT USING USED 8.52 PPG POWER VIS AT 2.45BPM,2360PSI, 50-150PSI MW,30-40FT/HR ROP,0.5-1.0K WOB,9.85 PPG ECD, PVT=336.DRILL TO 11290FT.PVT 334. 07:05 - 07:55 0.83 DRILL P PROD1 WIPER TO THE WINDOW-CLEAN. CIRCULATE 2.53BPM/2400PSI.PULL THROUGH WINDOW-CLEAN. 07:55 - 10:15 2.33 DRILL P PROD1 OPEN EDC.JET WHILE POH.3BPM/2200PSI. INCREASE IN AMOUNT OF CUTTINGS COMING OVER THE SHAKER. 10:15 - 10:40 0.42 DRILL P PROD1 FLOW CHECK.POP OFF WELL.PLACE INJECTOR OVER BUNG HOLE. PURGE& BLOW DOWN BHA. LD BHA IN THREE SECTIONS.BIT WAS 3-4, PLUGGED NOZZLE, STILL IN GAUGE. 10:40 - 13:00 2.33 DRILL P PROD1 LD UQC.CUT OFF CTC. RU COIL CUTTER. CUT 100FT OF COIL.TEST LINE-OK. DRESS COIL TUBING&INSTALL CTC. PULL TEST TO + 35K. INSTALL UQC. HEAD UP BHI. 13:00 - 13:10 0.17 DRILL P • PROD1 1PRESSURE TEST CTC TO 250PS V4000PSI- PASS. 13:10 - 13:35 0.42 DRILL P PROD1 MU LATERAL BHA. 13:35 - 13:45 0.17 DRILL P PROD1 STAB ONTO WELL POWER UP&TEST TOOLS.OPEN EDC. 13:45 - 14:15 0.50 DRILL P PROD1 PUMP SLACK FORWARD TO COMPLETE E-LINE SLACK MANAGEMENT. 14:15 - 16:00 1.75 DRILL P PROW RIH WITH LATERAL BHA(BHA#6).STOP AT 9700FT. 16:00 - 17:00 1.00 DRILL N MISC 9,700.00 PROD1 'SLB INJECTOR SURGING WHILE RIH.STOP& TROUBLE SHOOT.SWITCHED SCR ASSIGNMENTS&RIH. 17:00 - 17:15 0.25 DRILL P PROD1 CONTINUE TO RIH. 17:15 - 17:25 0.17 DRILL P PROD1 LOG DOWN FOR TIE-IN ACROSS RA TAG.NO CORRECTION. 17:25 - 17:50 0.42 DRILL P PROD1 •WIPER TO TD.CIRC 2BPM/1960PSI.SLIGHT MW AT 10460FT. INCREASE TO 2.5BPM/2400PSI WHEN PAST BUILD.MW& SET DOWN AT 10933FT.WORK THRU AT 1BPM.BACK REAM AT 15FT/MIN& 2.56BPM/2500PS1.WIPER PAST 10933- CLEAN.STILL HAVING PROBLEMS GETTING TO BOTTOM 17:50 - 18:35 0.75 DRILL P PROD1 BACK REAM THROUGH 11,150 FT TO 11,295 FT 118:35 - 19:10 0.58 DRILL P PROD1 TRYING TO DRILL AHEAD STILL STACKING NEG WT 19:10 - 19:40 0.50 DRILL P PROD1 BACK REAM AT 5 FT/MIN FROM 11,150 FT TO 11,295 FT WIPER BACK TO BOTTOM CLEAN Printed 8/19/2010 2:50:41 PM • North America -ALASKA- BP Page 7 of 9 Operation Summary Report Common Well Name: D-11 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:7/13/2010 End Date: 7/19/2010 X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date ! From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:40 - 21:15 1.58 DRILL P PROD1 DRILL AHEAD AT 50 FT/HR DRILLING WITH 1000-2000#'S WOB AND 140 -200 PSI OF MW 21:15 - 22:00 0.75 DRILL N STUC PROD1 DRILLED OFF TRY PU AND STUCK NO MOVEMENT UP RELAXED HOLE AND PU 80 K UP CAN ORIENTATE THE TOOL FACE AND STILL HAVE 1 FOR 1 WITH NO EXTRA PRESSURES. CALLED FOR MINERAL OIL CIRCULATE OUT CUTTINGS FROM BU 22:00 - 23:00 1.00 DRILL N STUC PROD1 SHUT PUMPS DOWN AND RELAX HOLE DH WOB INCREASING WHILE SHUT DOWN TRY PU TO 80 K AND NO CHANGE-DH WOB CONTINUE TO INCREASE INSTEAD OF GO NEG. RETURN TO 5 K OVER NEUTRAL WEIGHT AND CONTINUE TO WAIT ON MINERAL OIL 23:00 - 23:42 0.70 DRILL N STUC I PROD1 CIRCULATE IN 15 BBL HIGH VIS PILL-15 BBL MINERAL OIL-15 HIGH VIS PILL SHUT DOWN PUMPS WITH HIGH VIS PILL OUT AND MINERAL OIL STILL IN COIL PULL 80 K AND HOLD FOR A FEW MIN FINISH CIRCULATEING OUT OPEN HOLE WITH MINERAL OIL CIRCULATE TILL MINERAL OIL IS OUT • AROUND OPEN HOLE ANNULUS. 23:42 - 23:50 0.13 DRILL N STUC I PROD1 SHUT DOWN PUMPS WITH MINERAL OIL IN OPEN HOLE ANNULUS WAIT A COUPLE MIN THEN YO-YO PIPE ONCE AND THEN PULL FREE PULLING HEAVY FOR A FEW FT THEN CLEANED UP. 23:50 - 00:00 0.17 DRILL i N STUC PROD1 WIPER TO WINDOW 7/18/2010 00:00 - 00:45 0.75 DRILL i N STUC 11,355.00 PROD1 CONTINUE WIPER TO WINDOW @ 2.5 BPM 00:45 - 01:05 0.33 DRILL N STUC 11,355.00 PROD1 LOG FOR GR TIE IN AT WHIPSTOCK RA MADE+7.5 FT CORRECTION 01:05 - 01:55 0.83 DRILL N STUC 11,355.00 PROD1 1JET THE 7"LINER THROUGH OPEN EDC CONTINUE TO WIPER IN HOLE 101:55 - 04:20 2.42 DRILL P PROD1 FS=2490 PSI @ 2.5 BPM DRILL AHEAD FROM 11,355 FT 20,000 COIL WT AND 400#'S DH WOB DRILL AHEAD FAST TRYING TO KEEP WOB FOR DD 400-600 PSI MW AND 1.2 TO 1.6#'S WOB ROP'S OF 100 TO 160 FPH DRILLED TO 11,500 FT 04:20 - 05:30 1.17 DRILL P PROD1 !WIPER TO WINDOW 05:30 - 07:20 1.83 DRILL P PROD1 DRILL AHEAD FROM 11,500 FT FS=2620 PSI @ 2.5 BPM DRILLING AHEAD-90 FPH DH WOB=400#'S AND 200 PSI OF MW ECD=10.03 PPG AND VIB=2 L- DRILL TO 11606FT.PVT 312. 07:20 - 07:35 0.25 DRILL P PROD1 300FT WIPER-CLEAN. 07:35 - 08:10 0.58 DRILL P PROD1 DRILL LATERAL FROM 11606 FT USING USED 8.56 PPG POWER VIS AT 2.37BPM,2446PS1, 50-150PSI MW,70-150FT/HR ROP,0.5-1.0K WOB,10.05 PPG ECD,PVT=312. DRILL TO 11650FT.PVT 311. Printed 8/19/2010 2:50:41 PM • North America -ALASKA- BP Page 8 of 9 Operation Summary Report Common Well Name: D-11 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 7/13/2010 End Date: 7/19/2010 X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.:NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 li Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:10 - 09:00 j 0.83 DRILL P PROD1 WIPER TO THE WINDOW USING 2.51 BPM/2550PSI.5K OP&MW AT 11000FT TO 10900FT. PULL HEAVY AT WINDOW 0.25BPM/1200PSI.CUT PUMPS&PULL J THROUGH FINE. 09:00 - 09:25 0.42 DRILL P PROD1 PUMP THROUGH BIT AT 2.5BPBM/2500PSI TO TUBING TAIL&BACK DOWN TO TOP OF 'WHIPSTOCK. 09:25 - 10:35 1.17 DRILL P ; PROD1 TAG UP AT 10302FT THREE TIMES.WORK THROUGH&STOP AT 10340FT.OPEN EDC. JET WS TRAY&UP TO 10200FT.WINDOW WAS CLEAN PULLING THROUGH. RUN IN HOLE TO TOP OF WHIPSTOCK. PUMP 15BBL LO-VIS PILL&JET TUBING WALLS RECIPROCATE FROM 10340FT TO 10200FT. RUN THROUGH WINDOW-CLEAN. 10:35 - 11:20 0.75 DRILL P PROD1 CLOSE EDC.WIPERTOTD,MW FROM 10900FT-11000FT(SHALE&TF CHANGE).SET DOWN AT 11270FT,WORK THROUGH AT 2BPM. BOTTOM'S REVEALED SOME CUTTINGS. 11:20 - 14:15 I 2.92 DRILL P ' I PROD1 DRILL LATERAL FROM 11648 FT USING USED 8.58 PPG POWER VIS AT 2.45BPM,2500PSI, 50-150PSI MW,70-110FT/HR ROP,1-2 WOB (SURFACE WT), 10.04 PPG ECD, PVT=317. BHI DPS SUB FAILED.ADD 4 DRUMS OF V KLAGARD TO MUD&BRING TO 14PPB. DRILL TO 11802FT.PVT 313. 14:15 - 15:40 1.42 DRILL P I PROD1 WIPER TO THE WINDOW.OP'S&MW AT 11280FT,11000FT-10900FT,10460FT. 15:40 - 15:45 0.08 DRILL P PROD1 LOG DOWN FOR TIE-IN. PLUS 7.5FT _ ! + CORRECTION. 15:45 - 16:25 0.67 DRILL P PROD1 WIPER TO TD,PASS THRU 11250FT WITH '2BPM-NO PROBLEMS.NO MW OR SET DOWNS.SLIGHT LOSSES NOW. 16:25 - 17:30 1.08 DRILL P PROD1 DRILL LATERAL FROM 11809 FT USING USED 8.61 PPG POWER VIS AT 2.45BPM,2420PSI, 75-175PSI MW,75-110FT/HR ROP,1-2 WOB (SURFACE WT), 10.04 PPG ECD, PVT=309. BHI DPS STILL NOT WORKING. DRILL TO 11902FT.PVT 308. 17:30 - 17:40 0.17 DRILL P PROD1 100FT WIPER. 17:40 - 18:25 0.75 DRILL P PROD1 DRILL LATFRAI FROM slum FT USING USED 8.61 PPG POWER VIS AT 2.42BPM,2420PSI, 75-175PS1 MW,60-110FT/HR ROP,1.5-2.2 WOB (SURFACE WT), 10.14 PPG ECD,PVT=307. BHI DPS STILL NOT WORKING.POINT TF AT 180&SEARCH FOR 22N SHALE. DRILL TO 11,940 FT.PVT 304 bbls. 18:25 - 18:40 0.25 DRILL P PROD1 100 FT WIPER TO TRY AND GET BETTER DRILLING CONDITIONS 18:40 - 18:50 0.17 DRILL P ! PROD1 TRYING TO GET IT TO DRILL BUT STILL HAVING HEAVY PU'S/HARD TIME SLIDING AND LOTS OF STALLS ECD'S UP TO 10.11 PPG Printed 8/19/2010 2:50:41 PM North America -ALASKA- BP Page 9 of 9 Operation Summary Report Common Well Name:D-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:7/13/2010 End Date: 7/19/2010 `X3-00VW7-C(995,300.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.:NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.70ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth!, Phase Description of Operations (hr) (ft) 18:50 - 21:00 2.17 DRILL P PROD1 WIPER TO WINDOW AT 20 FPM OUT WITH Q =2.6BPM HAD OVER PULLS AND MW PULLING THROUGH SHALES-SLOW REAM THROUGH. PULL THROUGH WINDOW AND WIPER UP TO TUBING TAIL.AND BACK TO WINDOW. 21:00 - 21:50 0.83 DRILL P PROD1 WIPER IN HOLE FROM WINDOW AT 40-45 FPM AND 2.0 BPM THROUGH BUILD 21:50 - 00:00 2.17 DRILL P I PROD1 DRILL AHEAD FROM 11,942 FT FS=2600 PSI @ 2.5 BPM DRILLING SLOW 30 T040 FPH 1 'WITH 300 TO 500 PSI OF MW ECD=10.13 PPG WITH NO OTHER DATA AVAILABLE FROM DPS TOOL DRILLED TO 11,970 FT 7/19/2010 00:00 - 00:25 0.42 DRILL P I PROD1 CONTINUE TO DRILL AHEAD SLOW WITH NO ' , DPS ABOUT 18 K COIL WT AND 300 TO 500 PSI OF MW ROP—40 FPH I „DRILLED TO 12,000 FT 00:25 - 02:40 2.25 DRILL P PROD1 WIPER TO WINDOW WITH LOW SIDE TOOL i FACE @ 20-25 FPH 1 , Q=2.7 BPM ' STILL SEEING SOME SMALL OVER PULLS , AND SMALL MW THROUGH SHALES, BUT I I WAY BETTER THAN LAST WIPER. SLOW 1_ 1_-_ DOWN TO 10 FPH IN SHALE INTERVALS. IP 02:40 - 03:00 0.33 DRILL P PROD1 LOG FOR GR TIE IN AT WHIPSTOCK RA TAG MADE+5 FT CORRECTION 03:00 - 03:40 0.67 DRILL P I PROD1 WIPER IN HOLE FROM WINDOW AT 40 FPM AND Q=2.3 BPM ONE SMALL TAG AT 10925 FT BUT POPED THROUGH OK / 'TAG BOTTOM AT 12,003 FT 03:40 - 04:45 1.08 DRILL P PROD1 WIPER OUT OF HOLE LAYING IN CLEAN 8.6 PPG GEO VIS FOR LINER PILL. 04:45 - 05:15 0.50 DRILL P PROD1 PULL EDC THROUGH WINDOW AND OPEN- JET 7"AT4.1 BPM 05:15 - 05:35 0.33 DRILL P PROD1 'MAKE A CCL LOG OF 4-1/2"JEWLERY AND TAIL PIPE FOR LINER TOP PLACEMENT BU FROM 7"STARTED TO PACK OFF OUT MM LARGE ROCK OR CEMENT PIECES IN THE 1 I CUTTINGS TROUGH AFTER BLOW DOWN. 05:35 - 07:45 2.17 DRILL P PROD1 POOH PUMPING 3.2 BPM THROUGH EDC PAINT EOP FLAGS AT 9935 FT AND 8235 FT 07:45 - 08:45 1.00 DRILL P ' 1 ' PROD1 FLOW CHECK-OK.POP OFF.PLACE INJECTOR OVER BUNG HOLE.BLOW DOWN& PURGE BHA. LD BHA. BIT WAS 3-1. BEARING WAS SHOWING ON THE DRIVE SUB. Printed 8/19/2010 2:50:40PM North America -ALASKA- BP Page 1 of 8 Operation Summary Report Common Well Name: D-11 'AFE No Event Type: COM-ONSHORE(CON) Start Date: 7/19/2010 End Date: 7/24/2010 X3-00W/7-C(1,025,450.00) Project: Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292043500 Active Datum: D-11 Orig RKB @71.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/19/2010 08:35 - 09:40 1.08 CASING P RUNPRD PUMP SLACK OUT OF REEL. 08:45 - 08:35 CASING P RUNPRD PU INJECTOR.CUT OFF BHI UQC. FILL OUT HOT WORK PERMIT. BOOT E-LINE CABLE. PLACE 1JT OF 2-3/8"PH6 INTO WELL.MU COIL TO PH6 TUBING.STAB ONTO WELL. PUMP OUT E-LINE CABLE. 09:40 - 11:00 1.33 CASING P RUNPRD POP OFF WELL.PULL OUT E-LINE CABLE. RECOVERED 247FT OF CABLE.CUT 15FT TO FIND GOOD COIL.BOOT E-LINE CABLE. DRESS END OF COIL.MU BOT CTC.PULL TEST CTC TO 35K. PRESSURE TEST TO 4000PSI. 11:00 - 12:10 1.17 BOPSUR P RUNPRD STAB ONTO WELL.PUMP 3/4"DRIFT BALL WHILE JETTING STACK. POP OFF WELL. LD NOZZLE. RECOVERED 3/4"BALL.PLACE INJECTOR ON LEGS OVER BUNG HOLE. 12:10 - 12:30 0.33 BOPSUR P RUNPRD PREP 2-3/8"PH6 TUBING AS SAFETY JT, TORQUE ALL CONNECTIONS.FUNCTION TEST BOPE PER AOGCC REGS. 12:30 - 12:40 0.17 CASING P RUNPRD PJSM REGARDING MU LINER. 12:40 - 14:00 1.33 CASING P RUNPRD MU LINER PER PROGRAM. 14:00 - 14:20 0.33 CASING P RUNPRD SWAP NORDIC CREWS. FILL LINER. 14:20 - 14:35 0.25 CASING P RUNPRD PSJM WITH NEW CREW. •.// 14:35 - 17:25 2.83 CASING P RUNPRD CONTINUE TO MU LINER PER PROGRAM.C/O ELEVATORS AS NEEDED.SLIGHT LOSSES. PU&MU INJECTOR TO BHA.STAB ONTO WELL. 17:25 - 18:30 1.08 CASING P RUNPRD FILL LINER WITH 0.35BPM/1000PSI. RIH WITH LINER BHA. 18:30 - 19:40 1.17 CASING P RUNPRD STOP AT 4100 FT AND CIRCULATE TILL ONE FOR ONE- OUT MM WAS NOT READING RIGHT AS IT WAS SHOWING A GAIN WHEN PITS WERE NOT GAINING FLUID AT ALL. CIRCULATE TO SEE IF WE HAD MORE AIR COMMING STILL SHOWING.20 BPM OVER IN WITH—6.4 PPG MW. BLOW DOWN OUT MM AND GOT APPROPRIATE READINGS PVT=271 BBLS 19:40 - 21:00 1.33 CASING P RUNPRD CONTINUE TO RIH CIRCULATING.5 BPM @ 1300 PSI 1 UP WT @ 10,290 FT=46 K AND 41K STATIC. 21:00 - 21:35 0.58 CASING P RUNPRD RIH THROUGH OPEN HOLE STACKED ONCE AT 11,275 FT POPPED THROUGH OK AND RIH WITH A FEW SMALL BOBBELS TAG BOTTOM AT 12,006 UNCORRECTED PU FOR BO WEIGHT OF 46K STACK 10 K DOWN STILL 12,006 FT Printed 8/23/2010 3:06:36PM North America-ALASKA- BP Page 2 of 8 Operation Summary Report Common Well Name: D-11 'AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2010 End Date: 7/24/2010 X3-00VW7-C(1,025,450.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:35 - 23:10 1.58 CASING P RUNPRD PU FOR BALL DROP AND LAUNCH 5/8"STEEL BALL WITH 1500 PSI HEARD BALL MOVING AND GO OVER GOOSE NECK AT 21.7 BBLS @ 2.0 BPM @ 2100 PSI SLOW PUMPS DOWN AT 30 BBLS TO 0.5 BPM @ 1414 PSI AT 60 BBLS AWAY STILL NO BALL ON SEAT CYCLE PUMPS UP 3 TIMES AND THEN HOLD 1.0 BPM BALL ON SEAT AT 68.9 BBLS SHEAR OUT AT 4600 PSI 23:10 - 23:30 0.33 CASING N DFAL RUNPRD PU AND BO @ 12,001 FT WITH 40 K-NOT CLEAR WEATHER DRILLER STOPPED OR WE HAD BO STACK BACK DOWN AND DO OVER AT 11,999.4 FT @46K EASE DOWN AND PU AGAIN SEE THE SAME EASE DOWN&SET 10 K ONTO LINER.PUMP 2 BPM @ 2070 PSI FOR 11 BBLS BLEED OFF AND PU WT OF 46 K @ 11,999.4' CONTINUE UP TO 11,996'AND WEIGHT DOES NOT BREAK OVER BUT COMES UP TO 48 K TRY AGAIN AND SAME STOP AN CONSULT BTT MANAGEMENT& TOWN ENGINEER 23:30 - 00:00 0.50 CASING N DFAL RUNPRD CONSULT WITH BTT TEAM AND DOE 7/20/2010 00:00 - 01:15 1.25 CASING N DFAL 12,006.0 RUNPRD START WORKING TO RELEASE LINER PU AND SET DOWN 9 TIMES MAX HEIGHT UP WAS 11,994,5 FT WITH 54 K UP WT SET DOWN WITH CT WT=3 K @12,0008 FT WE WOULD PU SLOW THEN SET DOWN A LITTLE FASTER AND HARDER EACH TIME TRYING TO SHAKE FREE. / SET DOWN TO CT WT=-1870#'S AND ✓ CIRCULATE 2 BPM @ 2070 PSI FOR 10 BBLS THEN 3 BPM @ 2765 PSI FOR 5 BBLS AND SHUT DOWN/BLEED OFF PRESSURE EASE UP AND HAVE 50 K @ 11,995 FT STOP SET DOWN TO 11,989 FT PU 10 FT STILL 49 K UP WT STOP SET DOWN REPEAT FOR A TOTAL OF 3 TIMES SET DOWN FINAL AT 11,997 FT WITH 10 K ROLL PUMPS ON AND PRESSURED UP TO 3,000 PSI SHUT PUMPS DOWN AND BLEED OFF PRESSURE. CALL BOT AGAIN AND EVALUATE. 01:15 - 01:30 0.25 CASING N DFAL 12,006.0 RUNPRD PRESSURE UP TO 600 PSI AND SHUT DOWN PUMPS PU AND AT 11,894.86 FT SAW NO PRESSURE RELEASE JUST VERY SLOW CONTINUED BLEED OFF. MADE MORE CALLS TO BOT AND TOWN DOE TO ADVISE 01:30 - 01:55 0.42 CASING N DFAL 12,006.0 RUNPRD PJSM FOR POOH DISCUSS PLAN FORWARED AND WELL CONTROL CONTINGANCIES. 01:55 - 02:35 0.67 CASING N DFAL 12,006.0 RUNPRD POOH PUMPING AROSS THE TOP HOLDING 300 TO 400 PSI WHP. INITIAL UP WT=48 K WT SLOWLY DECREASING TO 45 K TO 46 K AT 40 FPM Printed 8/23/2010 3:06:36PM North America -ALASKA- BP Page 3 of 8 Operation Summary Report Common Well Name: D-11 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2010 End Date:7/24/2010 X3-00VW7-C(1,025,450.00) Project:Prudhoe Bay Site:PB D Pad Rig Name/No.:NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum:D-11 Orig RKB @71.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 02:35 - 02:50 0.25 CASING N DFAL 12,006.0 RUNPRD FLOW CHECK WELL JUST ABOVE THE WINDOW AT 10,300 FT PAINT NEW EOP FLAG PVT=90 BBLS UP WT=38 K NOW 02:50 - 05:20 2.50 CASING N DFAL 12,006.0 RUNPRD CONTINUE TO POOH HOLDING 300 TO 400 PSI WHP 05:20 - 05:35 0.25 CASING N DFAL 12,006.0 RUNPRD FLOW CHECK WELL AND PJSM FOR LD OF SELRT TOOLS 05:35 - 06:30 0.92 CASING N DFAL 12,006.0 RUNPRD STAND BACK INJECTOR AND LD 2-3/8 PH6 LD SELRT TOOLS AND BREAK DOWN LINER WIPER PLUG IS STILL ATTACHED TO BOTTOM BALL IS ON SEAT IN TOOL PEE WEE DART IS STILL UP IN TOOL-NOT IN LINER WIPER PLUG SIDE EXHAUSE PORTS WERE OPEN AND CLEAN WE DID HAVE SOME SMALL THIN JUNK METAL IN THE SPRINGS ON THE SIDE OF THE SETTING TOOL AND STUCK IN THE MUD ON THE SIDE OF THE TOOL IN VARIOUS LOCATIONS. 06:30 - 07:00 0.50 _ CASING N DFAL 12,006.0 RUNPRD RD FROM LINER TOOL AND PREP FISHING TOOLS 07:00 - 08:10 1.17 CASING N DFAL 12,006.0 RUNPRD CREW CHANGE OUT,WALK AROUNDS AND PJSM'S 08:10 - 09:25 1.25 CASING N DFAL 12,006.0 RUNPRD CLEAN AND TEST HP FILTER SCREANS PT TO 4 K 09:25 - 11:50 2.42 CASING N ' DFAL 12,006.0 RUNPRD TEST SLB INJECTOR WEIGHT CELLS TEST GOOD 11:50 - 12:15 0.42 CASING N DFAL 12,006.0 RUNPRD PT CTC TO 1000 PSI AND 3500 PSI STAB ONTO FISHING BHA 12:15 - 14:35 2.33 CASING N DFAL 12,006.0 RUNPRD RIH WITH FISHING BHA PVT=37 BBLS 14:35 - 15:00 0.42 CASING N DFAL 12,006.0 RUNPRD WT CHK PUMPS OFF 25 K DOWN AND 44 K UP @ 10,000 FT 15:00 - 15:15 0.25 CASING N DFAL 12,006.0 RUNPRD STAB INTO FISH @ 10,166 FT PU FISH WITH 55 K UP WT 15:15 - 17:00 1.75 CASING N DFAL 12,006.0 RUNPRD STACK DOWN AND PUMP BU AT 1.73 BPM @ 2260 PSI 17:00 - 18:35 1.58 CASING N DFAL 12,006.0 RUNPRD PUMP 139 BBL PILL 18:35 - 20:15 1.67 CASING N DFAL 12,006.0 RUNPRD POOH WITH LINER PUMPING ACROSS THE TOP HOLDING 300 TO 400 PSI WHP AT 15 TO 25 FPM WITH 52 K UP WT PVT=109 BBLS 20:15 - 20:30 0.25 CASING N DFAL 12,006.0 RUNPRD FLOW CHECK AT THE WINDOW 52 K HANGING WT PAINT YELLOW EOP FLAG AT 8220 FT 20:30 - 23:10 2.67 CASING N DFAL 12,006.0 RUNPRD CONTINUE TO POOH CIRCULATING ACROSS THE TOP HOLDING 300 TO 400 PSI WHP AND 60 TO 65 FPM FINAL PVT=53 BBLS LOST 1 BBL ON TRIP 23:10 - 23:25 0.25 CASING N DFAL 12,006.0 RUNPRD FLOW CHECK AT SURFACE AND PJSM FOR LD OF FISHING TOOLS AND SECURRING THE WELL WITH LINER IN HOLE AND AT SURFACE 23:25 - 00:00 0.58 CASING N DFAL 12,006.0 RUNPRD UNSTAB INJECTOR AND STAND BACK LD PH6 JOINTS Printed 8/23/2010 3:06:36PM North America -ALASKA- BP Page 4 of 8 Operation Summary Report Common Well Name: D-11 AFE No Event Type: COM-ONSHORE(CON) Start Date:7/19/2010 End Date:7/24/2010 X3-00VW7-C(1,025,450.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292043500 Active Datum: D-11 Orig RKB @71.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/21/2010 00:00 - 00:40 0.67 CASING N DFAL 12,006.0 RUNPRD LD FISHING TOOLS,DEPLOYMENT SLEEVE, AND PUP JOINT. NO OBVIOUS SIGHNS OF ANY DAMAGE ETC. SECURE WELL WITH 2-3/8"PH6 AND 1-1/2' FLOOR SAFETY JOINT OFF LOAD TOOLS AND SEND BACK TO BAKER TO REDRESS 00:40 - 01:05 0.42 CASING N DFAL 12,006.0 RUNPRD RU 2"HP HOSE TO TOP OF FLOOR SAFTY VAVLE CLOSE BAG AND UPPER 2-3/8" COMBIS ON 2-3/8"SAFETY JOINT. 01:05 - 01:30 0.42 CASING N DFAL 12,006.0 RUNPRD PJSM REGARDING CIRCULATING AND TESTING OF THE SHOE TRACK. 01:30 - 02:00 0.50 CASING N DFAL 12,006.0 RUNPRD CIRCULATE AT.34 BPM INTO TOP OF LINER. TOOK 2 BBLS TO FILL LINER AND GET RETURNS TO THE SHAKER AFTER 4 BBLS- PUMP.9 BPM @ 200 PSI FOR A TOTAL OF 21 BBLS. SHUT DOWN AND RE-ROUTE FOR PT OF SHOE TRACK. PRESSURE UP TO 271 BBLS THROUGH KILL LINE AND HOLD FOR 5 MIN-NO FLOW BUT DID LEAK OFF TO FORMATION TO 170 PSI PRESSURE UP TO 450 PSI AND HOLD 5 MIN TO 300 PSI-STILL NO FLOW. 02:00 - 02:30 0.50 CASING N DFAL 120,006.2 RUNPRD WAIT ON RE-DRESSED SELRT TOOLS 02:30 - 02:45 0.25 CASING N DFAL 12,006.0 RUNPRD PJSM WITH BOT HAND AND CREW REGAURDING MU OF SELRT TOOLS 02:45 - 04:25 1.67 CASING N DFAL 12,006.0 RUNPRD LOAD SELRT TOOL FROM HOT SHOT TRUCK TO PIPE SHED STAB SELRT TOOL ONTO TOP OF LINER MU 7 JNT'S OF PH6 STAB ON INJECTOR AND ESTABLISH 1 FOR 1 RETURNS 04:25 - 06:00 1.58 CASING N DFAL 12,006.0 RUNPRD RIH WITH LINER ON RE-DRESSED GEN II- SELRT TOOL. 0.47 BPM AND STARTING PVT=50 BBLS 06:00 - 06:05 0.08 CASING N DFAL 12,006.0 RUNPRD WEIGHT CHECK AT WINDOW WITH PUMPS OFF 29 STATICK PU LOOKED LIKE A VERY QUICK AND SHORT BOAT 46 K FOLLOWED BY WT SLOWLY INCREASING TO 50 K SLACK BO AT 47.5 K WITH WEIGHT INCREASING TO 49 K SLACK OFF AND PULLED FASTER HAD A CLEAN BREAK AT 48 K BUT WEIGHTS STILL INCREASING TO 51 K 06:05 - 06:30 0.42 CASING N 12,006.0 RUNPRD CREW CHANGE OUT 06:30 - 08:30 2.00 CASING N DFAL 12,006.0 RUNPRD CHECK WEIGHTS AT WINDOW WITH PUMPS OFF 28K RIW. BREAK OVER AT 48K WITH WEIGHT INCREASING. RIH TO TD THROUGH OPEN HOLE. 08:30 - 11:00 2.50 CASING N DFAL 12,006.0 RUNPRD TAG TD AT 12004'UNCORRECTED. DISPLACE COILED TUBING AND WELL TO XS 2%KCL WITH 0.6%SAFELUBE. OBSERVED DEFINITIVE BREAK OVER OF COIL AND 5K LESS SURFACE WIEGHT WITH XS KCL W/0.6%SAFE-LUBE IN HOLE Printed 8/23/2010 3:06:36PM North America -ALASKA- BP Page 5 of 8 Operation Summary Report Common Well Name: D-11 AFE No Event Type: COM-ONSHORE(CON) Start Date:7/19/2010 End Date:7/24/2010 X3-00VW7-C(1,025,450.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292043500 Active Datum: D-11 Orig RKB @71.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 12:00 1.00 CASING N DFAL 12,006.0 RUNPRD DROP 5/8"STEEL BALL TO DISCONNECT FROM LINER. BALL SHEARED AT 38BBLS AWAY. PUW=42K AFTER DISCONNECTING 12:00 - 13:00 1.00 CEMT P ._ RUNPRD PJSM WITH CEMENT CREW AND RIG CREW. BEGIN TO RIG UP CEMENTERS. 13:00 - 14:00 1.00 CEMT P - RUNPRD BATCH MIX 30 BBLS CEMENT AND PRESSURE TEST CEMENT TREATING LINES. 14:00 - 17:45 3.75 CEMT P RUNPRD BEGIN PUMPING 22 BBL,15.8 PPG CLASS G CFMFNT STAGF SWAP TO RIG PUMP AT 22 BBLS ON MM. PUMP 53.5 BBLS AND SHUT DOWN PUMP WITH 2BBLS CEMENT LEFT IN COIL. G tir PU TO BREAKOVER PLUS ADDITIONAL 13'(11983') SLACKED BACK OFFF AND NOTED TAG 10' HIGHER(11994') LAUNCH PEE WEE DART WITH.3 BBLS AND 500 PSI. PUH AND NOTED PRESSURE FALL OFF. SIDE EXHAUST 2BBLS CEMENT PLUS 3 BBLS 2PPB BIOZAN. LAUNCH LWP WITH 2990 PSI. NOTED BUMP AT 10.9 BBLS. HELD 2220 PSI ON PLUG. OPEN CHOKE AND CHECK FLOATS. NO FLOW OBSERVED AT SHAKER. PRESSURE UP 500 PSI ON COIL AND UNSTING FROM LINER. CONTAMINATE TOP OF LINER WITH 5 BBLS 2 PPB BIOZAN. POOH PUMPING ADDITIONAL.75 BPM. 17:45 - 19:00 1.25 CEMT P RUNPRD - I R ■ ■ •• . I e A. PREP FLOOR FOR RUNNING MCNL AND CLEANOUT BHA. 19:00 - 22:00 3.00 EVAL P OTHCMP PJSM&MU CLEAN OUT/MEMORY LOGGING BHA WITH 30 STANDS OF CSH AND 4 JOINTS OF PH6. STILL USSING OLD 2.30 AES CLEAN OUT MILL.STILL IN GAUGE AT 2.30" 22:00 00:00 2.00 EVAL P ■- OTHCMP FT WITH LOGGING/CLEAN OUT INGT09500 FT PUMPING.3 BPM WHILE SENDING CEMENT RETURNS TO CUTTINGS BOX. 7/22/2010 00:00 - 01:40 1.67 EVAL P OTHCMP LOG DOWN FROM 9,500 FT AT 30 FPM AT TOL BRING PUMPS UP TO 1.5 BPM UP WT AT 9,500 FT=39 K TAG PBTD AT 11,957.5 FT UNCORRECTED WITH 4K DOWN PU AND TAG AGAIN AT 11,958 K WITH 3 K DOWN 01:40 - 02:25 0.75 EVAL P ■- OTHCMP LOG UP 60 FPM WHILE LAYING IN 15 BBL PERF PILL IN LINER LOG UP TO 9,500 FT 02:25 - 04:10 1.75 EVAL P OTHCMP POOH WITH CLEAN OUT BHA STILL TAKING RETURNS TO CB AND PUMPING IN CLEAN 2% KCL DOUBLE SLICK. PAINT EOP FLAG AT 7,000 FT RETURNS WERE 1 FOR 1 ON TRIP 04:10 - 04:20 0.17 EVAL P OTHCMP PJSM FOR STAND BACK OF WORK STRING Printed 8/23/2010 3:06:36PM North America-ALASKA- BP Pages of 8 Operation Summary Report Common Well Name: D-11 AFE No Event Type: COM-ONSHORE(CON) Start Date:7/19/2010 End Date:7/24/2010 X3-00VW7-C(1,025,450.00) Project: Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292043500 Active Datum: D-11 Orig RKB @71.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:20 - 07:30 3.17 EVAL P OTHCMP PU INJECTOR AND STRIP OUT LAST 100 FT OF COIL FOR INSPECTION -NO FLAT SPOTS. LD PH6 JOINTS STAND BACK 30 STANDS OF CSH 07:30 - 08:00 0.50 EVAL P OTHCMP PJSM TO LAY DOWN SWS SOURCE 08:00 - 09:00 1.00 EVAL P OTHCMP JET STACK WITH SWIZZLE STICK 09:00 - 09:30 0.50 PERFOB P OTHCMP LOAD PERFORATING GUNS IN PIPE SHED 09:30 - 12:30 3.00 EVAL P OTHCMP DISCUSS INCOMPLETE LOGGING DATA WITH SWS LOGGER. SEND PARTIAL PASS TO ASSET AND DRILLING ENGINEER FOR REVIEW. 12:30 - 13:00 0.50 PERFOB P OTHCMP PJSM BEFORE DEPLOYING PERFORATING GUNS. 13:00 - 16:00 3.00 PERFOB P OTHCMP BEGIN MU PERFORATING BHA. 16:00 - 18:30 2.50 PERFOB P OTHCMP RIH WITH PERF GUNS TAG BOTTOM AT 11,960 FT 18:30 - 18:50 0.33 PERFOB P OTHCMP UP WT ON BOTTOM=45 K PU AND RE TAG AT 11,960 FT PU TO BO AT 11,956.4 FT AND CORRECT DEPTH TO 11,962 FT PU TO 11,860.7 FT 18:50 - 19:55 1.08 PERFOB P OTHCMP RU AND PRESSURE TEST LINER LAP 19:18=2070 PSI 19:33=1860 PSI 19:48=1760 PSI TEST FAILED CALL DOE TO CONFIRM NO SECOND TEST AND TO MOVE ON 19:55 - 20:25 0.50 PERFOB P OTHCMP RIH AND RE PU TO 11,861.7 FT FOR E-FIRE PUMP SEQUENCE. RUN PUMP SEQUENCE USING 0.5 BPM AND 1.7 BPM �/ PU SLOW WHILE WAITING ON FIRE OF GUNS GOOD INDICATION OF SHOTS FIRED @ 4 11,861.1 FOR BOTTOM SHOT FIRED AT 211,860.4 FT AND WELL WENT ON LOSSES -SEE OPEN WELLS PERFORATION REPORT FOR FURTHER INFO- 20:25 - 23:55 3.50 PERFOB P OTHCMP POOH WITH PERF GUNS PUMPING.7 BPM WITH WELL TAKING SMALL LOSSES of-.30 to.40 BPM INITIAL PVT=336 BBLS LOSSES AT TOL IS-.11 BPM CONTINUE TO POOH STOP AT 8285 AS OUT RATE STARTED TO INCREASE WITH LOWER DENSITY. CLEANED UP FAST.NO ALARMS Q=1.01/.92 BPM WITH COIL S TOPED&8.34 PPG/8.47 PPG MONITOR CONDITIONS AND ALL FLOWS AND DENSITIES ARE STABLE CONTINUE OOH. FINAL PVT AT TAG UP=256 BBLS FOR A 25 BBL LOSS Q=1.14/1.1 BPM&8.35/8.46 PPG 23:55 - 00:00 0.08 PERFOB P OTHCMP TAG UP AND FLOW CHECK WELL/PJSM FOR STAND BACK OF CSH AND LD OF BHA. 7/23/2010 00:00 - 00:15 0.25 PERFOB P OTHCMP CONTINUE TO FLOW CHECK WELL AND FINISH PJSM HOLE TOOK ADDITIONAL BBL TO FILL AFTER FLOW CHECK&BEFORE UNSTABING Printed 8/23/2010 3:06:36PM Page North America -ALASKA- BP Pa g Operation Summary Report Common Well Name: D-11 AFE No Event Type: COM-ONSHORE(CON) Start Date: 7/19/2010 End Date: 7/24/2010 X3-00VW7-C(1,025,450.00) Project:Prudhoe Bay I Site:PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292043500 Active Datum: D-11 Orig RKB @71.7ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (ft) 00:15 - 02:05 1.83 PERFOB P OTHCMP PU INJECTOR AND STRIP OUT LAST 50 FT OF COIL INSPECTING FOR CHROME WEAR-NO NOTICABLE WEAR SPOTS(RUN 6) STAND BACK INJECTOR, LD PH6,AND STAND BACK CSH 02:05 - 02:25 0.33 PERFOB P OTHCMP PJSM WITH SLB PERFORATORS&RIG CREW 02:25 - 03:20 0.92 PERFOB P OTHCMP FILL HOLE-TOOK 4 BBLS LD PERF GUNS HELD KICK WHILE TRIPING DRILL WHILE LD OF PERF GUNS CONTINUED TO LD PERF GUNS 03:20 - 03:40 0.33 PERFOB P OTHCMP SECURE WELL BY CLOSING THE SWAB VALVE AND INSTALLING THE NIGHT CAP RD PERFORATORS AND OFF LOAD EQUIPMENT 03:40 - 04:15 0.58 PERFOB P OTHCMP HOLD AAR WITH RIG CREW AND PERFORATORS ON KICK WHILE TRIPPING DRILL. GOOD PERSONAL/CREW LEARNING'S BUT NO PROCEDURAL CHANGES. HELD PJSM FOR MU OF LTP BHA AND OFF LOAD OF PERF GUNS 04:15 - 05:10 0.92 DHB P OTHCMP BRING LINER TOP PACKER TO RIG FLOOR MU LINER TOP PACKER BHA STAB ON INJECTOR AND ESTABLISH CIRCULATION PVT=246 BBLS 05:10 - 07:20 2.17 DHB P OTHCMP RIH WITH LINER TOP PACKER 5.ETTING BHA CIRULATEING 0.35 BPM 07:20 - 09:40 2.33 DHB P OTHCMP WT CK AT 10100'RIH=28K,PUW=45K ENGAGE DEPLOYMENT SLEEVE AND SPACE OUT. DROP 5/8"BALL AND SET PACKER PER BAKER RECOMMENDATION PRESSSURE TEST LTP TO 2000 PSI FOR 30 MINUTES. PASS SHEAR OFF LTP AND POOH 09:40 - 11:35 1.92 DHB P OTHCMP POOH 11:35 - 12:00 0.42 DHB P OTHCMP TAG UP,FLOW CHECK WELL AND RIG BACK INJECTOR. 12:00 - 12:45 0.75 DHB P OTHCMP LD LINER RUNNING TOOL. MU FREEZE PROTECT BHA 12:45 - 13:40 0.92 RIGD P PRE RIH TO FREEZE PROTECT DEPTH 13:40 - 14:25 0.75 RIGD P PRE WAIT ON LRS 14:25 - 15:25 1.00 RIGD P PRE PJSM WITH LRS 15:25 - 15:50 0.42 RIGD P PRE RU LRS 15:50 - 17:00 1.17 RIGD P PRE POOH AND FREEZE PROTECT WELL FROM 2500'WITH DIESEL 17:00 - 20:30 3.50 RIGD P PRE OOH, PT LUBRICATOR TO 3800 PSI. BEGIN PUMPING CORROSION INHIBITOR STAGE. BLOW DOWN WITH N2 AND UNSTAB INJECTOR 20:30 - 21:00 0.50 RIGD P PRE PJSM/GREASE TREE 21:00 - 22:00 1.00 RIGD P PRE PJSM/SET BPV WITH LUBRICATOR-PER WELLS GROUP POLICY WELL WAS ON A VAC PRIOR TO SETTING BPV Printed 8/23/2010 3:06:36PM North America-ALASKA- BP Page 8 of 8 Operation Summary Report Common Well Name: D-11 AFE No Event Type:COM-ONSHORE(CON) Start Date:7/19/2010 End Date:7/24/2010 X3-00VW7-C(1,025,450.00) Project:Prudhoe Bay Site: PB D Pad Rig Name/No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292043500 Active Datum: D-11 Orig RKB @71.7ft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 RIGD P PRE PJSM/INSPECT ALL RAMS ON BOP STACK, AND CHANGE OUT VARIABLE RAM INSERTS AND TOP SEALS ON THE BLIND SHEAR RAMS. 7/24/2010 00:00 - 01:00 1.00 RIGD P PRE NIPPLE DOWN BOP'S 01:00 - 02:03 1.05 RIGD P PRE NIPPLE UP TREE CAP SPOT IN LRHOS/PJSM/PT TREE CAP/RD LRHOS NORDIC 1 RELEASED FROM D-11 B AT 02:30 SEE F-47 B 07/24/10 REPORT FOR FURTHER OPERATIONS Printed 8/23/2010 3:06:36PM BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB D Pad D-11 - Slot 11 D-11B Survey: MWD Survey Report - Geographic 19 July, 2010 by raiill BAKER HUGHES Survey Report-Geographic by 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-11 -Slot 11 Project: Prudhoe Bay TVD Reference: 20: 11 5/31/1996 10:06 @ 82.91ft(generic drillinc Site: PB D Pad MD Reference: 20: 11 5/31/1996 10:06 @ 82.91ft(generic drillinc Well: D-11 North Reference: True Wellbore: D-11B Survey Calculation Method: Minimum Curvature Design: D-11B Database: EDM.16-Anc Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB D Pad,TR-11-13 Site Position: Northing: 5,955,590.34ft Latitude: 70°17'8.492 N From: Map Easting: 652,165.06ft Longitude: 148°46'6.316 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.16 ° Well D-11 API No 500292043500 Well Position +N/-S 0.00 ft Northing: 5,957,960.99 ft Latitude: 70°17'31.413 N +El-W 0.00 ft Easting: 654,116.00 ft Longitude: 148°45'8.072 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore D-11B API No 500292043502 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) (°) (nT) BGGM2009 3/10/2010 22.24 80.92 57,682 Design D-11B Audit Notes: Version: Phase: ACTUAL Tie On Depth: 10,290.79 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 42.41 0.00 0.00 292.59 Survey Program Date: 7/19/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 121.21 7,321.21 1 :Gyrodata gyrocompassing m/(D-11) GYD-GC-MS Gyrodata gyrocompassing m/s 7,405.00 10,290.79 MWD(D-11A) MWD MWD-Standard 10,302.50 12,003.00 MWD(D-11B) MWD MWD-Standard J 7/19/2010 8:29:01 AM Page 2 COMPASS 2003.16 Build 71 Mal BAKER HUGHES Survey Report-Geographic bP INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-11 -Slot 11 Project: Prudhoe Bay TVD Reference: 20: 11 5/31/1996 10:06 @ 82.91ft(generic drillinc Site: PB D Pad MD Reference: 20: 11 5/31/1996 10:06©82.91ft(generic drillinc Well: D-11 North Reference: True Wellbore: D-11B Survey Calculation Method: Minimum Curvature Design: D-11 B Database: EDM.16-Anc Prod-WH24P I Survey ! 'Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,290.79 67.47 285.08 8,921.25 1,500.60 -3,673.70 5,959,385.85 650,412.58 70° 17'46.163 N 148°46'55.151 W TIP 10,302.50 68.73 284.85 8,925.62 1,503.40 -3,684.20 5,959,388.44 650,402.03 70° 17'46.190 N 148°46'55.457 W I!i KOP 10,334.04 70.45 275.59 8,936.64 1,508.63 -3,713.25 5,959,393.07 650,372.87 70°17'46.242 N 148°46'56.304 W 10,364.92 70.48 266.49 8,946.99 1,509.15 -3,742.31 5,959,393.00 650,343.81 70°17'46.247 N 148°46'57.151 W I 10,396.52 69.14 256.54 8,957.92 1,504.79 -3,771.60 5,959,388.04 650,314.62 70° 17'46.204 N 148°46'58.005 W 10,425.12 69.16 251.03 8,968.10 1,497.33 -3,797.25 5,959,380.06 650,289.13 70°17'46.130 N 148°46'58.752 W 10,462.00 71.27 237.40 8,980.64 1,482.26 -3,828.39 5,959,364.35 650,258.30 70°17'45.982 N 148°46'59.660 W 10,492.24 72.01 224.93 8,990.20 1,464.30 -3,850.69 5,959,345.94 650,236.38 70°17'45.805 N 148°47'0.310 W 10,530.08 76.20 211.57 9,000.60 1,435.77 -3,873.13 5,959,316.96 650,214.54 70°17'45.524 N 148°47'0.963 W 10,570.58 74.38 196.97 9,010.94 1,400.18 -3,889.20 5,959,281.05 650,199.20 70° 17'45.174 N 148°47'1.431 W 10,605.92 75.14 184.57 9,020.26 1,366.76 -3,895.55 5,959,247.51 650,193.54 70°17'44.845 N 148°47'1.616 W 10,628.62 75.86 176.11 9,025.96 1,344.80 -3,895.67 5,959,225.56 650,193.86 70° 17'44.630 N 148°47'1.619 W 10,655.84 80.80 169.17 9,031.47 1,318.39 -3,892.25 5,959,199.22 650,197.83 70°17'44.370 N 148°47'1.519 W 10,667.02 83.20 166.18 9,033.02 1,307.58 -3,889.89 5,959,188.46 650,200.41 70°17'44.264 N 148°47'1.450 W 10,697.81 86.99 157.11 9,035.66 1,278.50 -3,880.23 5,959,159.59 650,210.66 70°17'43.978 N 148°47'1.168 W 10,727.45 88.80 149.54 9,036.75 1,252.06 -3,866.94 5,959,133.42 650,224.49 70°17'43.718 N 148°47'0.780 W 10,772.29 87.57 146.92 9,038.17 1,213.96 -3,843.35 5,959,095.82 650,248.85 70°17'43.343 N 148°47'0.092 W 10,804.03 88.22 145.89 9,039.34 1,187.54 -3,825.80 5,959,069.77 650,266.94 70°17'43.083 N 148°46'59.580 W 10,836.90 86.62 142.54 9,040.82 1,160.90 -3,806.60 5,959,043.53 650,286.68 70°17'42.821 N 148°46'59.020 W 10,866.64 85.83 138.16 9,042.78 1,138.06 -3,787.67 5,959,021.08 650,306.07 70°17'42.597 N 148°46'58.468 W 10,895.26 86.43 133.83 9,044.71 1,117.53 -3,767.84 5,959,000.96 650,326.32 70°17'42.395 N 148°46'57.890 W 10,929.30 91.41 129.08 9,045.35 1,095.01 -3,742.34 5,958,978.98 650,352.27 70°17'42.174 N 148°46'57.146 W 10,961.22 93.32 123.40 9,044.03 1,076.16 -3,716.63 5,958,960.66 650,378.36 70°17'41.988 N 148°46'56.397 W 10,999.94 92.31 116.29 9,042.13 1,056.93 -3,683.11 5,958,942.12 650,412.27 70°17'41.799 N 148°46'55.419 W 11,039.16 91.26 108.21 9,040.90 1,042.10 -3,646.86 5,958,928.04 650,448.81 70°17'41.654 N 148°46'54.362 W 11,080.66 90.06 113.07 9,040.43 1,027.48 -3,608.04 5,958,914.22 650,487.92 70°17'41.510 N 148°46'53.231 W 11,110.02 92.61 118.23 9,039.74 1,014.78 -3,581.59 5,958,902.06 650,514.62 70°17'41.385 N 148°46'52.460 W 11,140.94 93.75 125.68 9,038.02 998.45 -3,555.41 5,958,886.28 650,541.13 70°17'41.225 N 148°46'51.697 W 11,171.68 90.28 132.01 9,036.94 979.19 -3,531.50 5,958,867.51 650,565.42 70°17'41.036 N 148°46'50.999 W 11,199.76 88.68 126.16 9,037.20 961.50 -3,509.72 5,958,850.27 650,587.56 70°17'40.862 N 148°46'50.364 W 11,230.12 84.92 120.25 9,038.89 944.91 -3,484.37 5,958,834.20 650,613.24 70°17'40.699 N 148°46'49.625 W 11,267.10 87.82 115.45 9,041.23 927.67 -3,451.75 5,958,817.65 650,646.21 70°17'40.529 N 148°46'48.674 W 11 302.86 88.74 110.37 9,042.31 913.77 -3,418.84 5,958,804.41 650,679.40 70°17'40.393 N 148°46'47.715 W 11,330.58 90.28 108.18 9,042.55 904.62 -3,392.68 5,958,795.80 650,705.74 70°17'40.303 N 148°46'46.952 W 11,363.94 90.46 104.41 9,042.33 895.26 -3,360.66 5,958,787.10 650,737.93 70°17'40.211 N 148°46'46.019 W 11,395.40 90.00 99.95 9,042.20 888.62 -3,329.92 5,958,781.10 650,768.81 70°17'40.146 N 148°46'45.123 W 11,436.52 90.83 92.92 9,041.91 884.02 -3,289.09 5,958,777.33 650,809.72 70° 17'40.101 N 148°46'43.933 W 11,467.06 92.03 89.05 9,041.14 883.49 -3,258.57 5,958,777.43 650,840.24 70° 17'40.096 N 148°46'43.043 W 11,505.78 91.97 82.88 9,039.79 886.21 -3,219.98 5,958,780.95 650,878.76 70° 17'40.122 N 148°46'41.919 W 11,535.56 91.35 79.28 9,038.93 890.83 -3,190.58 5,958,786.16 650,908.06 70° 17'40.168 N 148°46'41.062 W 11,570.84 91.75 72.81 9,037.97 899.33 -3,156.37 5,958,795.36 650,942.08 70° 17'40.252 N 148°46'40.065 W 11,602.08 88.22 69.19 9,037.98 909.50 -3,126.85 5,958,806.13 650,971.39 70° 17'40.352 N 148°46'39.205 W 11,625.94 88.28 64.46 9,038.71 918.88 -3,104.93 5,958,815.96 650,993.11 70° 17'40.444 N 148°46'38.566 W 11,661.00 88.25 60.74 9,039.77 935.00 -3,073.82 5,958,832.72 651,023.88 70°17'40.603 N 148°46'37.660 W 11,699.90 89.05 55.90 9,040.69 955.42 -3,040.74 5,958,853.81 651,056.54 70°17'40.804 N 148°46'36.696 W 11,725.78 90.74 52.62 9,040.74 970.53 -3,019.73 5,958,869.35 651,077.22 70°17'40.953 N 148°46'36.084 W 11,755.60 88.96 49.84 9,040.81 989.20 -2,996.49 5,958,888.49 651,100.08 70°17'41.136 N 148°46'35.406 W 11,785.40 88.62 46.18 9,041.44 1,009.13 -2,974.35 5,958,908.87 651,121.81 70°17'41.332 N 148°46'34.761 W 11,818.34 87.27 40.19 9,042.63 1,033.12 -2,951.83 5,958,933.31 651,143.83 70°17'41.568 N 148°46'34.105 W 11,845.36 88.49 37.94 9,043.63 1,054.09 -2,934.81 5,958,954.62 651,160.41 70° 17'41.775 N 148°46'33.610 W 11,875.62 88.22 34.43 9,044.49 1,078.50 -2,916.96 5,958,979.39 651,177.76 70° 17'42.015 N 148°46'33.089 W 11,909.02 85.94 30.73 9,046.20 1,106.60 -2,899.00 5,959,007.85 651,195.13 70° 17'42.291 N 148°46'32.566 W 11,936.54 82.12 29.23 9,049.06 1,130.30 -2,885.33 5,959,031.82 651,208.32 70° 17'42.524 N 148°46'32.168 W 7/19/2010 8:29:01AM Page 3 COMPASS 2003.16 Build 71 • RIM BAKER HUGHES Survey Report-Geographic 0 bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-11 -Slot 11 Project: Prudhoe Bay TVD Reference: 20: 11 5/31/1996 10:06 @ 82.91ft(generic drillinc Site PB D Pad MD Reference: 20: 11 5/31/1996 10:06 @ 82.91ft(generic drillinc Well D-11 North Reference: True Wellbore: D-11B Survey Calculation Method: Minimum Curvature Design: D-11B Database: EDM.16-Anc Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (0) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 11,956.98 79.08 28.75 9,052.40 1,147.94 -2,875.55 5,959,049.66 651,217.73 70°17'42.698 N 148°46'31.883 W 12,003.00 79.08 28.75 9,061.11 1,187.55 -2,853.82 5,959,089.71 651,238.64 70° 17'43.088 N 148°46'31.250 W TD-2-7/8" 7/19/2010 8:29:01AM Page 4 COMPASS 2003.16 Build 71 f f TREE= CM/ SAFETY. S: WELL ANGLE>70°@ 10334'**BEFORE WELLHEAD UTR= FMC D 11 B MOVE NO-GO ON RUNNING HEAD%D2"**4-1/2'CHROME TBG& ACTUATOR= AXELSON KB.ELEV= 71.7" PJC DRAFT 7"LNR**ORIG&"A"WELLBORE NOT SHOWN** BF.ELEV= 46.56' I i KOP= 3221' I �•� 350' H NEW TOP OF CEMENT 11/23/04 I Max Angle= 9°@ 11411' 20"CONDUCTOR 100' ,I• To- 4 'I't I 2215' H4-1/2"HES SSSV NIP,ID=3.813" I Datum MD= 10204' *( Datum TVD= 8800'SS V A 2613' I-19-5/8"DV PKR I • 13-3/8"CSG,72#,L-80BTRS, ID=12.347" —I 2668' O. •v.i1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =2.370" @ 10162' 6 3074 3001 8 HES TB DMY RA 0 11/23/02 45 KB LINER TOP PACKER 5 5479 4985 43 HES TB DMY RA 0 11/23/02 4 7141 6196 44 HES TB DMY RA 0 01/10/96 3 8010 6886 23 KBG2LS **DMY INT 0 03/18/98 9-8/5"X 7"TIW SN-6 AT TB PKR,ID=7.38" —I 7245' 2 9124 7902 24 KBG2LS **DMY INT 0 03/18/98 9-8/5"X 7"TM/LNR HGR,ID=8.249" —I 7269' 1 10077 8735 54 KBG2LS **DMY INT 0 03/18/98 **PROBLEM MANDREL'S REQUIRING SPECIAL VALVES 9-5/8"CSG,47#,L-80 BTRS,ID=8.681" —I 7400' I (NOTE STA#3=DMY HAS EXTENDED PKG) X X 10144' —14-1/2"HES X NIP,ID=3.813" I MILLOUT WINDOW (D-11A)7400'-7455' 7"LNR,29#,L-80 BTC,XO TO 13CR NSCC H 9668' 10155' --I9-5/8"X 4-1/2"BKR S-3 PKR,ID=3.875" A 2 6-�'A 10162' --145 KB LNR TOP PKR,ID=2.370" I ESTIMATED TOP OF CEMENT H 10170' 1 10171' --13-1/2"BTT GEN DEPLOY SLV,ID=3.00" I 1 4 I 10178' H4-1/2"HES X NIP, ID=3.813"(BEHIND LNR) I 1 is 10192' —I 3-1/2"OTIS X NIP, ID=2.812" 1 0 1 •i 1 �i 4 k 10199' 1 4-1/2"HES XN NIP,ID=3.79" 4-1/2"TBG, 12.6#,13CR NSCT, —I 10211' 4 *� 1(MILLED 06/29/10) BEHIND .0152 bpf,ID=3.958" ��1 0� .1 ��� 10211' H4-1/2"WLEG,ID=3.958" I LINER•V e. 10211' —I ELMD TT LOG ON??/??/?? I 3-1/2"LNR,9.3#,L-80 STL, .0087 bpf, ID=2.992" 10287' �l ■ �•' �•• 10287' 1-13-1/2"X 3-3/16"XO,ID=2.786" I 7"WHIPSTOCK(06/27/10) —1 10300' I •;4 '%• / 7"LNR,29#,13CR NSCC,..0371 bpf,ID=6.184" --I 10300' I/ MILLOUT WINDOW (D-11 B)10310'- 10317' � •�•�•�•�•�•� I 10385' 1-13-3/16"X 2-7/8"XO,ID=2.387" PERFORATION SUMMARY I 10386' —12-7/8"MARKER JOINT 1 REF LOG:SLB MCNL ON 07/21/10 / ANGLE AT TOP PERF:91°@ 11420' 3-3/16"LNR,6.2#,L-80 STL, —1 10384' I ` Note:Refer to Production DB for historical perf data ` PBTD H 11963' I p 0075 bpf, ID=2.80" SIZE SPF INTERVAL Opn/Sqz DATE ■ 2" 6 11420- 11720 0 07/20/10 ` 2" 6 11760- 11860 0 07/20/10 % 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf, ID=2.441" 12003' ••• Nor DATE REV BY COMMENTS I DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/29/80 ORIGINAL COMPLETION WELL: D-11B 01/14/96` D-09 CTD SIDETRACK(D-11A) PERMIT No:'2100770 07/24/10 NORDIC 1 CTD SIDETRACK(D-11 B) API No: 50-029-20435-02 07/27/10 PJC DRLG DRAFT CORRECTIONS SEC 23,T11 N,R13E,2239'FSL&1067'FEL BP Exploration(Alaska) bp Date 10-22-2010 Transmittal Number:93166 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 02-36A 940-011C 9-0 02-36APB1 15-32B �l O-fito c�C72—' 15-32B 2BPB1 D-11B /D--O?-7 0a"" .E-O2 B 0/0-01 ?, a 0 84 —E-37AL1 c910 - CUfo aOaga 40 Please •21 • • Return one copy of this transmittal. Thank e •, Doug Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E.Benson Blvd.PO Box 196612 Anchorage,AK 99519-6612 wvmv s�Ns moms i'im E. g. m a cn m y d mg-Fm —ohm I 01 Q?o« F�N=.i uoi nriN9N7C V =. xie. 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TTr t v 7 t •1t ..i 7C m m w o C 1 7 *i ° 3 i 79 • • 0 0 • 0 slpmE [] ALLAs - A SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-11 B BP Exploration (Alaska), Inc. Permit No: 210-077 Surface Location: 3040' FNL, 1067' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 1827' FNL, 3910' FEL, SEC. 23, T11 N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill 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. Sincerely, Daniel T. Seamount, Jr. Chair Cfrc DATED this "" day of June, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ., ALAS )IL AND GAS CONSERVATION COMM! 7N JUN 1 4 20106-/S/D PERMIT TO DRILL 20 AAC 25.005 Alaska Oil&eGas Cans.Commission 1a.Type of work: lb.Proposed Well Class: ®Development Oil ❑Service-Winj ❑Single Zone 1c. Specify i , IIOnoosed for: ❑ Drill ®Redrill ❑ Stratigraphic Test ❑Development Gas ❑Service-Supply ❑Multiple Zone ❑Coalbed Gas ❑Gas Hydrates ❑ Re-Entry ❑ Exploratory ❑Service-WAG ❑Service-Disp ❑Shale Gas 2. Operator Name: 5.Bond: ® Blanket ❑Single Well 11. Well Name and Number: BP Exploration(Alaska)Inc. Bond No. 6194193 PBU D-11 B 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 12000' TVD 8938'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028285 3040'FNL, 1067'FEL, SEC.23,T11N, R13E, UM Top of Productive Horizon: ,75,11-n" 8. Land Use Permit: 13. Approximate Spud Date: 1574'FNL,4401'FEL, SEC.23,T11N, R13UM 00 July 14,2010 Total Depth: evi °� 9.Acres in Property: 14.Distance to Nearest Property: 1827'FNL,3910'FEL,SEC.23,T11N, R13UM 2560 25,600' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 82.91 feet 15.Distance to Nearest Well Open Surface: x- 654116 y-5957961 Zone- ASP4 GL Elevation above MSL: 45.16 feet to Same Pool: 1272' 16.Deviated Wells: Kickoff Depth: 10320 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 102 degrees Downhole: 3500 - Surface: 2620 • 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 4-1/8" 3-1/7 x 3-3/16' 9.2#/6.2# L-80 STL/TCII, 1812' 10188'_8793'ss 12000' 8938'ss 124 cu ft Class'G' x 2-7/8" /6.4# 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 12125' 901Z 12013' 12013' 9011' None Casing Length Size Cement Volume MD ND Conductor/Structural 110' 20"x 30" 10.6 cu vds Arctic Set Concrete 110' 110' Surface 2669' 13-3/8" 3841 cu ft Permafrost II 2669' 2669' Intermediate 7400' 9-5/8" 1382 cu ft'G'. 130 cu ft PF'C' 7400' 6463' Production Liner 3267' 7" 320 cu ft Class'G' 7256'- 10523' 6361'-8964' Liner 1660' 4-1/2" 234 cu ft Class'G' 10455'- 12115' 8958'-9012' Perforation Depth MD(ft): 10360'-11980' Perforation Depth ND(ft): 8943'-9011' 20.Attachments: ❑ Property Plat ®BOP Sketch IS Drilling Program ❑Time vs Depth Plot ❑Shallow Hazard Analysis ❑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 Amanda Suddreth,564-5543 Printed Name John M Title Engineering Team Leader Prepared By Name/Number Signature ./Z.� Phone 564-4711 Date h/4-(/d Terrie Hubble,564-4628 Commission Use Only Permit To Drill API Number: Permi Ap oval Date See cover letter for Numbers?/QO?� 50-029-20435-02-00 �'(OI j/l) other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: gJ Other: 35049 105:: 6 OP 73.5.1- Samples Req'd: E Yes LI No Mud Log Req'd: a Yes I No 2 Annµ,(we �s Cam.;,,S Measures: Yes ❑No Directional Survey Req'd: Yes ❑No Sod psi- 6 1J L / l O '''''E-71-- ------e-- `' APPROVED BY THE COMMISSION Date - ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 oimoGhtneAar.oval(20 AAC 25.005(g)) Submit In Duplicate • D-11B - Coiled Tubing Drk....ig To: Alaska Oil & Gas Conservation Commission From: Amanda Suddreth bp CTD Engineer Date: May 18, 2010 Re: D-11 B Permit to Drill Application Coil Tubing Sidetrack: Drill and Complete Summary Pre-Rig Work: (scheduled to begin June 25, 2010) 1. S Dummy off GLMs 2. F MIT-IA to 3000psi, MIT-OA to 2000psi 3. W PPOT-T, function LDS. PT tree (MV, SV, WV) 4. S Dummy WS drift to 10,400' 5. E RIH w/through-tubing whipstock (4.5"x 7"); set TOWS @ 10,300' 6. C Squeeze cement past whipstock to abandon perfs-42 bbls of 15.8ppg 7. C Mill out XN Nipple @ 10,199'to 3.80" 8. C Freeze protect well 9. F Post-cement job MIT-T to 2500psi, 30 minutes 10. D Bleed wellhead pressures to zero 11. 0 Remove wellhouse, level pad, remove flowline Rig Work: (scheduled to begin on July 14, 2010) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Swap the well to Geo-Vis. Mill 3.8"window at -10.300 and 10'of rathole. 3. Drill Build: 4.125"OH, 500' (35 deg/100 planned) with resistivity• 4. Drill Lateral: 4.125"OH, 1200' (12 deg/100 planned) with resistivity(TD @ 12,000') • 5. Run 3-1/2"x 3-3/16"x 2-7/8" solid carbon liner leaving TOL at 10,188' . 6. Pump primary cement leaving TOC at 10,188', 22 bbls of 15.8 ppg liner cmt planned • • ( 7. Cleanout liner and MCNL/GR/CCL log 8. Test liner lap to 2000 psi P-ro 9. Perforate liner per asset instructions (--600') . 10. RIH w/Baker KB LTP; stab into liner and set LTP • 11. Freeze protect well, RDMO • Post-Rig Work: 1. Re-install wellhouse and flowlines . 2. Generic GLV's 3. RU test separator, flow test well 6/3/2010 • D-11 B - Coiled Tubing Dri....ig Mud Program: • Well kill: 8.6 ppg seawater/brine • Milling/drilling: 8.6 ppg Geo-vis or biozan for milling, new Geo-vis 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: 4.125", 10,300' - 12,000' Casing Program: • 3-1/2" 9.2#, L-80, STL solid liner 10,188' MD- 10,250' MD " • 3-3/16" 6.2#, L-80, STL solid liner 10,250' MD-10,500' MD - • 2-7/8" 6.4#, L-80, STL solid liner 10,500' MD- 12,000' MD . • A minimum of 22 bbls of 15.8 ppg cement will be to cement the solid liner(TOC at 10,188') • • Short liner lap; plan to run 4.5" Bkr KB LTP, top at-10,178' Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 2,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 102 deg (toe of well dips up after lateral section). • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line-25,600'to the South • Distance to nearest well within pool- 1272' (D-19B, to the east) Anticollision Summary • No anti-collision issues Logging • MWD directional, GR and Resistivity will be run over all of the open hole section. • A cased hole GR/CCUCNL log will be run. - Hazards • The maximum recorded H2S level on D-Pad is 50ppm on well D-15A (1/2/2005). D-Pad is not considered a high-level H2S pad. • Lost circulation risk is moderate, due to potential crossing of small unmapped faults. If losses are encountered, take appropriate steps for lost circulation mitigation. Reservoir Pressure • Reservoir pressure is estimated to be 3,500 psi at 8,800'TVDss (7.6 ppg EMW). • Maximum surface pressure with gas (0.10 psi/ft)to surface is 2,620 psi. • Amanda Suddreth CTD Engineer 6/3/2010 TREE= 6"MCEVOY SAFETY NOTES: BEFORE RUNNING 1"BTM LATCH GLV WELLHEAD= FMC IN'OLf "LE KBG-2LS GLM,MOVE NO-GO ON ACTUATOR= CIW OTIS 0-I 1 A RUNNIN— ._CAD 1/2". CHROME LNR&TBG. 90°@ 11206' KB.ELEV= 82.9' BF.ELEV= 46.56' KOP= 3221' Max Angle= 95 @ 11781' 350' I-I NEW TOP OF CEMENT 11/23/04 Datum MD= 10204' X11 11� Datum TVD= 8800'SS 0 + 2215' 4-1/2"HES SSSV NIP, ID=3.813" X11 1. O 1"� 2613' H9-5/8"DV PKR1 13-3/8"CSG,72#, L-80, ID=12.347" -I 2668' I• A GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" @ 10199' 6 3074 3001 8 HES TB DMY RA 0 11/23/02 4-1/2" HES XN NIPPLE I 5 5479 4985 43 HES TB DMY RA 0 11/23/02 I-1 4 7141 6196 44 HES TB DMY RA 0 3** 8010 6886 23 KBG2LS DMY INT EXT PKG 2** 9124 7902 24 KBG2LS DMY NT 0 1**, 10077 8735 54 KBG2LS DMY INT 0 TOP OF 7"LNR -I 7245' I -7 *"NOTE PROBLEM MANDRELS;REQUIRE SPECIAL VALVES �. 7245' I-19-5/8"X 1" I I ■ SN-ti-A I I B VKK, IU= /.3c I ■ 7269' -19-5/8"X 7"TIW LNR HNGR, ID=8.249" • 9-5/8"CSG,47#, L-80, ID=8.681" H 7400' I '♦,∎1 �11��1�1�1 MILLOUT WINDOW-7400'-7455' •�Qj11j11j1 11111 EZSV H 7600' I ��1111 ��1111111 x,11111, • • I 10144' H4-1/2"HES X NIP, ID=3.813" I 1' $ g 10155' H X 4-1/2"BKR S-3 PROD PKR, ID=3.875" I I I 10178' I-14-1/2"HES X NIP, ID=3.813" I 4-1/2"TBG, 12.6#, 13-CR, .0152 bpf, ID=3.958" H 10211' I IN i i 10199' H4-1/2"HES XN NIP, ID=3.725" PERFORATION SUMMARY 10211' 4-1/2"WLEG, ID=3.958" I REF LOG:ATLAS PDK ON 07/28/96 — 10211' ELMD TT LOG NOT AVAILABLE I ANGLE AT TOP PERF: 75 @ 10360' — Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz s DATE $' L I 10455' H7"X 4-1/2"BKR HGR PKR, ID=4.48" I 2-7/8" 6 10360-10390 0 06/22/05 4 1 2-7/8" 6 10460- 10490 0 06/22/05 3-3/8" 6 10560- 10575 0 04/30/97 I 2-7/8" 6 10708- 10738 0 06/22/05 3-3/8" 6 10880- 11180 0 06/09/99 2" 6 11425- 11450 0 07/27/07 2" 6 11485 11510 0 07/27/07 I 10831' H UNKNOWN OBSTRUCTION, EST. I0=2.8" I 2" 6 11550- 11575 0 07/27/07 I3-3/8" 6 11800- 11980 O i 06/09/99 7"LNR,29#, 13-CR,NSCC&L-8u 10523' , 0.0371 bpf, ID=6.184" PBTD H 12031' 12013' H4-1/2"HES EZ DRILL PLUG I . , 4-1/2"LNR, 12.6#, 13-C R, .0152 bpf, ID=3.953" ....12115' 1,,1,1,1,1, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/28/80 ORIGINAL COM PLETION 04/03/06 WTS/PJC GLV LATCH CORRECTIONS WELL: D-11A 01/14/96 M.LINDER SIDETRACK COM PLETION 01/02/07 RCT/TLH PROB GLV MANDREL NOTE PERMIT No:'1951830 11/23/02 DTR/TP GLV C/O 01/02/07 /TLH WAIVER SAFETY NOTE UPDATE AR No: 50-029-20435-01 11/23/04 MJA/TLP NEW TOC POST OA SQZ 05/09/07 RDW/PJC WAIVER SFTY NOTE DELETED SEC 23,T11 N, R13E,3040'FNL&1067'FEL 12/12/04 RDJ/TLH WAVER SAFETY NOTE 08/04/07 JRA/SV PERFS&CORRECTIONS 06/22/05_WTS/PJC PERFS 03/10/10 MSE CORRECTIONS BP Exploration (Alaska) TREE= , 6"MCEVOY WELLHEAD= FMC D _ SAFETY MOTES: BEFORE RUNNING 1"BTM LATCH GLV IN'OL 'LE KBG-2LS GLM, MOVE NO-GOON ACTUATOR= CM✓OTIS RUNNIN.,MEAD 1/2". CHROME LNR&TBG. 90°@ 11206' KB. ELEV= 82.9' BF.ELEV= 46.56' Proposed CTD Sidetrack KOP= 3221' Max Angle= 95 @ 11781' �� 350' I—I NEW TOP OF CEMENT 11/23/04 Datum MD= 10204' �11i 1•� Datum TVD= 8800'SS '1�v ;1; 2215' I�4-1/2"HES SSSV NIP, ID=3.813" .1A 0 .1.4 2613' I—I 9-5/8"DV PKR I 11� 1V4 13-3/8"CSG,72#, L-80, ID=12.347" —I 2668' ��' •�� GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =2.3" @ 10188' 6 3074 3001 8 HES TB DMY RA 0 11/23/02 3-1/2" TOE f y I I . 5 5479 4985 43 HES TB DMY RA 0 11/23/02 4 7141 6196 44 HES TB DMY RA 0 3** 8010 6886 23 KBG2LS DMY INT EXT PKG 2** 9124 7902 24 KBG2LS DMY INT 0 1** 10077 8735 54 KBG2LS DMY INT 0 TOP OF 7"LNR —I 7245' I **NOTE PROBLEM MANDRELS;REQUIRE SPECIAL VALVES 7245' H 9-5/8"X 7"TM/SN-6-AT TB PKR,ID=7.38" I 1 9-5/8"CSG,47#, L-80, ID=8.681" —i 7400' I ,1�1 MILLOUT WINDOW-7400'-7455' .111111 ♦1111 `11111111111 111 TSGR 9713' X11111 EZSV —I 7600' 4::%1111 ��`11111� I 1 10144' —14-1/2"HES X NIP, ID=3.813" I 1' H 10155' H7"X 4-1/2"BKR S-3 PROD PKR, ID=3.875" 3.70"BKR LNR DEPLOYMENT SLV,ID=2.30" H 10188' 10178' I—F4-1/2"HES X NIP, ID=3813" I TOC 10188' I f 10178' (-{4-1/2"BKR KB LTP ID=2.4?" 1 4-1/2"TBG, 12.6#, 13-CR, .0152 bpf, ID=3.958" 10211' 10199' —14-1/2"HES XN NIP,ID rolled to=3.80" I 4-1/2"x -, H 10300' k 10211' -14-1/2"WLEG, ID=3.958" I BCGL 10230' PERFORATION SUMMARY 10211' ELMDTT LOG NOT AVAILABLE REF LOG:ATLAS PDK ON 07/28/96 t -J 10250' I H 1 ANGLE AT TOPPERF:75 @ 10360' 68' lam\ XO Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE '- 1I 2-7/8" 6 10360-10390 0 06/22/05 3-1/2"x 3-3116"x 2-7/8"cmt'd&perf'd 1 12000' 2-7/8" 6 10460- 10490 0 06/22/05 _ 3-3/8" 6 10560- 10575 0 04/30/97 1-17"X 4-1/2"BKR HGR PKR, ID=4.48" 2-7/8" 6 10708- 10738 0 06/22/05 3-3/8" 6 10880- 11180 0 06/09/99 31k 2" 6 11425- 11450 0 07/27/07 2" 6 11485- 11510 0 07/27/07 1 2" 6 11550- 11575 0 07/27/07 J 3-3/8" 6 11800- 11980 0 06/09/99 ' 10831' I--I UNKNOWN OBSTRUCTION, EST. 10=2.8" I 7"LNR,29#, 13-CR,NSCC&L-80 — 1 0523' , 0.0371 bpf, ID=6.184" PBTD —I 12031' 12013' H4-1/2"HES EZ DRILL PLUG I 4-1/2"LNR, 12.6#, 13-CR, .0152 bpf, ID=3.953" —I 12115' 1'111'N DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/28/80 ORIGINAL COMPLETION 04/03/06 WTS/PJCGLV LATCH CORRECTIONS WELL: D-11 01/14/96 M.LINDEI\SIDETRACKCOMPLETION 01/02/07 RCT/TLH PROB GLV MANDREL NOTE PERMIT No: 11/23/02 DTR/TP GLV C/O 01/02/07 /TLH WAIVER SAFETY NOTE UPDATE API No: 50-029-20435-0 11/23/04 MJA/TLP NEW TOC POST OA SQZ 05/09/07 RDW/PJC WAIVER SFTY NOTE DELETED SEC 23,T11 N,R13E,3040'FNL&1067'FEL 12/12/04 RDJ/TLH WAIVER SAFETY NOTE 08/04/07 JRA/SV PERFS&CORRECTIONS 06/22/05 WTS/PJC PERFS e 03/11/10 MSE PROPOSED CTD SIDETRACK BP Exploration (Alaska) D-11 B - Coiled Tubing Drik j All Measurements are from top of Riser 5/28/2010 i CU U) CC D-11 B top of bag BAG bttm of bag J middle of blind/shears Blind/Shears I I TOTs middle of pipe slips 2 38" combi ram:slips I I middle of floe; cross Li Mud Cross Mud Cross I I miadle of rams 2 3/8" x 3 1/2" V B R's l''''''•.......... 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MIS■ ■i ■1111■1111■■N•■IIIiU v 111,1■■■ice■•■■■■■ ■■ _ •■ 1 _w ■■■■■ 1111■ x � � ,_ - ■■■■■ • v _ 11.11■■■ A m . r b h O Q M en N 8 O - g',, 3 '6, 1� r u v. h -1 7• .; (ui/J cc)(+)qio1•1/011unog (6u 6wpup Duaua6)SL 6'Z9 @ 90.01 9661/LE/9 l OZ ■ BPPASSPORT MAKER 1WW01 5 Travelling Cylinder Report 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-11 -Slot 11 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB D Pad MD Reference: 20: 11 5/31/1996 10:06 @ 82.91ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: D-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 8, D-11 B Database: EDM .16-Anc Prod-WH24P Reference Design: Plan 8 Offset TVD Reference: Offset Datum Reference Plan 8 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 10,290.79 to 12,000.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,395.76ft Error Surface: Elliptical Conic Survey Tool Program Date 6/3/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 121.21 7,321.21 1 :Gyrodata gyrocompassing m/(D-11) GYD-GC-MS Gyrodata gyrocompassing m/s 7,405.00 10,290.79 MWD(D-11A) MWD MWD-Standard 10,290.79 12,000.00 Plan 8(Plan 8, D-11 B) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 12,000.00 8,937.71 2-7/8" 2.875 4.125 CC-Min centre to center distance or covergent point,SF-min separation factor.ES-min ellipse separation 6/3/2010 11:08:08AM Page 2 of 15 COMPASS 200316 Build 71 ■ BPPASSPORT • MAKER 111111811ES Travelling Cylinder Report IiNTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well D-11 -Slot 11 Project: Prudhoe Bay ND Reference: Mean Sea Level Reference Site: PB D Pad MD Reference: 20: 11 5/31/1996 10:06 @ 82.91ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: D-11 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 8, D-11 B Database: EDM.16-Anc Prod-WH24P Reference Design: Plan 8 Offset TVD Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB D Pad D-01 -D-01 -D-01 11,650.00 10,200.00 1,308.40 520.08 801.76 Pass-Major Risk D-01A-D-01A-D-01A 11,675.00 9,775.00 1,337.98 456.25 885.79 Pass-Major Risk D-08-D-08-0-08 Out of range D-08-D-08A-D-08A Out of range D-08-D-08A-D-08A WP05 Out of range D-09-D-09-D-09 Out of range D-09A-D-09A-D-09A Out of range D-10-D-10-D-10 Out of range D-11 -D-11 -D-11 10,420.00 10,375.00 541.89 94.36 460.51 Pass-Major Risk D-11 -D-11A-D-11A 10,324.99 10,325.00 0.49 2.64 -1.63 FAIL-Major Risk D-16-D-16-D-16 Out of range D-16-D-16A-D-16A Out of range D-17-D-17-D-17 Out of range D-17-D-17A-D-17A Out of range D-17-D-17B-D-17B 11,211.05 10,300.00 1,364.01 374.84 990.27 Pass-Major Risk D-17-D-17B-D-17B wp05 11,200.00 10,334.46 1,369.78 369.25 1,001.97 Pass-Major Risk D-18-D-18-D-18 Out of range D-18-D-18A-D-18A 10,775.00 10,375.00 1,264.15 132.29 1,132.77 Pass-Major Risk D-18-D-18A-D-18A wp4 10,786.43 10,275.00 1,279.74 134.06 1,147.84 Pass-Major Risk D-19-D-19A-D-19A 11,984.16 9,600.00 357.56 108.14 249.36 Pass-Major Risk D-20-D-20-D-20 Out of range D-26-D-26-D-26 Out of range D-26-D-26A-D-26A Out of range D-26-D-26B-D-26B Out of range D-26-D-26B-Plan#6 Out of range D-31 -D-31 -D-31 Out of range D-31A-D-31A-D-31A Out of range CC-biro Gentle b rx er distance or oarergent point SF-min separation factor.ES-min el pse separation 6/3201011,OBtOBAM Page 3 of 15 COW ASS 2003.16 Budd 71 Alaska Department of Natural n sources Land Administration System Page 1 oft24 Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28285 Printable Case File Summary See Township,Range, Section and Acreage? ® Yes 0 No New Search LAS Menu I Case Abstract I Case Detail l Land Abstract File: ADL 28285 "'aP_- Search for Status Plat s U date A As of 06/15/2010 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 013E Section: 13 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 013E Section: 14 Section Acres: 640 Meridian: U Township: 011N Range: 013E Section: 23 Section Acres: 640 Meridian: U Township: O11N Range: 013E Section: 24 Section Acres: 640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-96 T11N-R13E-UM 13,14,23,24 2,560.00 LISBURNE PARTICIPATING AREA DESCRIPTION T. 11., R. 13 E., U.M. SECTION 13:ALL 640 ACRES CONTAINING 640 ACRES, MORE OR LESS. http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=2828... 6/15/2010 TRANSMITTAL LETTER CHECKLIST WELL NAME z/ I,8 PTD# �?10 777 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: �.e6�/J 2O 2 9Y POOL: Z,e4/D�D� Z4/ ©' 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 through target 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 program. Rev: 1/11/2008 • N N N. I 92 ❑ 1 a• 3 • c Q 1 0 a) 0 > L W ❑ O D N E C E 0 o) m - a a c 3 co N W a t L 3 0 ° N E 3 o Lo, O E Y N co_ O U r f6 'v N '3 co C a) > > O _ D 2 m N 0 m a = s g o u a) caa 3 w o E 3 u 0 o o a) o) m c I- a) 7 U a co U) 0 Z Q ) N n CO o a E r a a) a co >- -to 3 z° •- -- 0 o m p Q t Q m n m co i N w c a 0 _c c aNi aci a) 0 < D 0 0 d ° N 3 2 rn Q °� .S m 0 3 M N m �'I C) v ,_ p Cl)c a) -o aa) a) i iN -c a w M. 07 E N (1) N o- D N 0) ❑ a co ❑ a� ) m c r D a) N CE c a) C N U C a) 'N a) .... a O co o) N E 3 >. 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N O _a 7 L-a� O �° o •S n n N > N 0 3 r ° °) c a2i _00 0>> m c ai o a w N ° c7) o o ) >' 'o a) a a a� E m a°i a�i aai 0 a o r c c coi E N a a o 'n �° — 3 ° p N c o 0 m C aci CO @ x 7 U) U) N a3 a3 @ 3 7 Cl) 00 co a7 a7 = p 4) = Cl) 5 -o CD CO — c U a3 N a) U C Ll.l -- C a) 0 0 0 N (O ° ° Y w a) 0 N O c U a) o o — c a) "o (O ) yj a E ?� a) C .0 E V 'o U • a a) N N a O 7 U > > 3 0) 7 7 Cl) O) — W a) a) c a 2 0 0 j m E co Q - = = .2- aa) a`) a`) E E c = 3 o c .c2 'C i- t- 1- 'a-) a°) `) a°) > '5 a a o Y ,- 0 E m c a) Y a� a 'E a) a) a) c -o a a o 5 m °) - m o o c 2 2 2 co -2 a) -o a E 0 0 C O a a) 5 as a� 0° o p V L a 23 ❑ co 0 0 a a 0 a d z 0 co 0 c) 0 0 0 s Q o m m 0 N 2 a ❑ co rn 0 co U...���.W' a O N M V LU O r W 0) O N M V O r a0 O) O N M C �O (O N- O O EO ,- N co V LU co N- N O CD N N N N N N N N N N C'') C'') o') o') o') C) C) P') P') c') 0 O O _O .. _ _ 1� a) O a) O N O a) Ii O C fC N 16 N f6 N V o W ° m S co a o r a) E - N "./ 'NI a) C) O l Q Q U W a Q c Q Q Q CD 0 wo Well History File APPENDIX Infoi cation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 4 tapescan.txt **** REEL HEADER **** MWD 11/02/14 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 10/07/19 3270986 01 3" CTK *** LIS COMMENT RECORD *** mmmm1111111111111 Remark File Version 1.000 � � III111111IIIIIIII 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 9801.5000: Starting Depth STOP.FT 12002.7500: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska) , Inc. WELL. WELL: D-11B FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 17' 31.413"N 148 deg 45' 8.072"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 19 Jul 2010 API . API NUMBER: 500292043502 Parameter Information Block #MNEM.UNIT Value Description SECT. 23 Section TOWN.N T11N Township RANG. R13E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . KB Log Measured from FAPD.F 82.91 Feet Above Perm. Datum DMF . KB Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 82.91 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 2/U - o9-R tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 Remarks (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 Primary Depth Control (PDC) log provided by schlumberger GR CNL dated 21 Jul 2010 per Jennifer Flight with BP Exploration (Alaska) , Inc. The MWD data is now the SDCL for well D-11B. (8) The sidetrack was drilled from D-11A through a milled window in a 7 inch liner. Top of window 10307 ft.MD (8844.4 ft.TVDSS) Bottom of window 10315 ft.MD (8847.4 ft.TVDSS) (9) Tied into D-11A at 10302 feet MD (8842.7 feet TVDSS) . (10) The interval from 11963 ft to 12003 ft MD (8970.1 ft. to 8978.2 ft. 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 RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9802.46, 9802.87, ! 0.410156 9803.48, 9804.51, ! 1.02637 9805.54, 9805.54, ! 0 9806.36, 9807.18, ! 0.821289 9808.61, 9808.82, ! 0.205078 9810.05, 9810.26, ! 0.205078 9811.08, 9812.1, ! 1.02637 9814.98, 9815.18, ! 0.205078 9817.44, 9817.44, ! 0 9822.78, 9822.37, ! -0.411133 9826.47, 9825.85, ! -0.616211 9828.93, 9828.11, ! -0.821289 9831.19, 9830.17, ! -1.02637 9832.22, 9832.22, ! 0 9833.65, 9833.24, ! -0.410156 9836.12, 9835.3, ! -0.820312 9838.38, 9837.96, ! -0.410156 9843.92, 9843.92, ! 0 9862.42, 9862.01, ! -0.410156 9864.48, 9864.68, ! 0.205078 9874.12, 9873.51, ! -0.615234 9877.41, 9878.64, ! 1.23145 9881.72, 9882.95, ! 1.23145 9884.18, 9885, ! 0.821289 Page 2 tapescan.txt 9897. 5, 9898.32, ! 0.821289 9900.17, 9901.19, ! 1.02637 9906. 53, 9907.14, ! 0.615234 9909.61, 9910.63, ! 1.02637 10294.2, 10294.8, ! 0.615234 10311.5, 10311.3, ! -0.205078 10313.3, 10315.2, ! 1.84668 10324.4, 10325.6, ! 1.23145 10333, 10333.8, ! 0.821289 10347.6, 10349, ! 1.43652 10365.4, 10365.8, ! 0.411133 10368.9, 10369.1, ! 0.205078 10381.2, 10381.8, ! 0.616211 10386.2, 10385.9, ! -0.205078 10390.7, 10391.1, ! 0.411133 10427.9, 10426.9, ! -1.02637 10431.6, 10430.6, ! -1.02637 10437, 10437, ! 0 10442.9, 10442.9, ! 0 10446.2, 10446.6, ! 0.410156 10456.2, 10457.8, ! 1.6416 10460.9, 10462.3, ! 1.43652 10465.2, 10466.2, ! 1.02637 10470.1, 10471.2, ! 1.02637 10477.1, 10477.9, ! 0.821289 10480.8, 10482.5, ! 1.6416 10492.3, 10493.5, ! 1.23145 10501.3, 10502.2, ! 0.820312 10503.6, 10505.2, ! 1.6416 10509.1, 10510.7, ! 1.6416 10512.8, 10514.2, ! 1.43652 10520.3, 10521.4, ! 1.02637 10537, 10538.8, ! 1.84766 10539.4, 10541.3, ! 1.84766 10552.1, 10553.2, ! 1.02637 10555.2, 10556, ! 0.821289 10560.6, 10561.8, ! 1.23145 10563.2, 10564.9, ! 1.6416 10566.7, 10568.4, ! 1.6416 10604.1, 10606.7, ! 2.66895 10647, 10649, ! 2.05273 10651.1, 10652.7, ! 1.6416 10757.1, 10755.7, ! -1.43652 10788.2, 10784.8, . -3.48926 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 143 records. . . Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 Page 3 tapescan.txt *** LIS COMMENT RECORD *** IIIIII1111IIIIIIIII Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 21 Jul 2010 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0. 500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 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 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 123 Tape File Start Depth = 9801.500000 Tape File End Depth = 11999.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 136 records. . . Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 Page 4 tapescan.txt *** LIS COMMENT RECORD *** I III ! ! ! 1111 1111111 Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 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: 36 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 6 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 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 245 Tape File Start Depth = 9801.000000 Tape File End Depth = 12002.750000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 258 records. . . Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 10/07/19 3270986 01 Page 5 tapescan.txt **** REEL TRAILER **** MWD 11/02/14 BHI 01 Tape Subfile: 4 2 records. . . Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9801. 5000 194.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9802.0000 190.0525 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11999.5000 -999.2500 8.8652 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9801. 500000 Tape File End Depth = 11999. 500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9801.0000 194.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9801.2500 192.4000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12002.7500 -999.2500 46.6000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9801.000000 Page 6 ... . ...__._ tapescan.txt Tape File End Depth = 12002.750000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet U Tape subfile 4 is type: LIS Page 7
