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207-113
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, March 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC X-20A PRUDHOE BAY UNIT X-20A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 03/01/2024 X-20A 50-029-22478-02-00 207-113-0 W SPT 8764 2071130 2191 1225 1225 1226 1226 9 9 9 8 4YRTST P Adam Earl 1/15/2024 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT X-20A Inspection Date: Tubing OA Packer Depth 24 2514 2469 2460IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240117083115 BBL Pumped:4.2 BBL Returned:3.7 Friday, March 1, 2024 Page 1 of 1 Wallace, Chris D (CED) From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Wednesday, February 5, 2020 11:55 AM To: Regg, James B (CED); Brooks, Phoebe L (CED); Wallace, Chris D (CED); DOA AOGCC Prudhoe Bay Cc: Wyatt Rivard; Alaska NS - Milne - Wellsite Supervisors; Matthew Linder; William Kruskie Subject: Shut-in injector Milne Point 1-15 due for AOGCC MIT -IA All, Milne Point water injector MP J-15 (PTD # 1991070) has been shut in since 8/22/2019 for reservoir management. The well was due for an AOGCC witnessed MIT -IA last month. The well will not be brought online in time for the test and will remain shut-in for the foreseeable future. It will be added to the Quarterly North Slope LTSI injector report. Once the well is ready to be brought online an MIT -IA will be performed. Regards, Darci Horner (Northern Solutions) Regulatory Technologist Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this e-mail message is confidential information intended only for the use of the recipient(s) named above. In addition, this communication may be legally privileged. If the reader of this e-mail is not an intended recipient, you have received this e-mail in error and any review, dissemination, distribution or copying is strictly prohibited. If you have received this e-mail in error, please notify the sender immediately by return e-mail and permanently delete the copy you received. White all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Plugs Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ 9058 Plug for Rednll 11Perforate New Pool ❑ Repair Well ® Re-enter Susp Well ❑ OA Other: Cement Squeeze tl CondcutOr Top Job 13 an 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work feet 5. Permit to Drill Number: 207-113 3. Address: P.O. Bax 196612 Anchorage, Development ❑ Exploratory ❑ 9047 feet Packer AK 99519-6612 Stratigraphic ❑ Service EI 1 6. API Number: 50-029-22478-02-00 7. Property Designation (Lease Number): ADL 028313 & 047472 8. Well Name and Number: PBU X -20A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: 8957-9058 RECEIVED PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Conductor Total Depth: measured 13569 feet Plugs measured None feet true vertical 9058 feet Junk measured None feet Effective Depth: measured 13511 feet Packer measured 10676, 10741 feet true vertical 9047 feet Packer true vertical 8764. 8804 feet 8180 5120 Casing: Length: Size: MD: TVD: Burst Collapse: Structural Conductor 80 20" 34-114 34-114 1490 470 /. Surface 3533 10-3/4" 33-3566 33-3149 5210 2480 Intermediate 10922 7-5/8" 30-10952 30-8923 8180 5120 Production Liner 2543 3-1/2" x 3-3/16" x 2-7/8" 11026 - 13569 8957-9058 RECEIVED Perforation Depth: Measured depth: 11310-13500 feet True vertical depth: 9010-9046 feet OCT 2 1 2019 ®GCC Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 28-10814 28-8797 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Packer 10676 8764 true vertical depth) 4-1/2" Baker SABL-3 Packer 10741 8804 12. Stimulation or cement squeeze summary: OA Squeeze (2/9/2019) Pumped 9.4 bible sgzcmte into OA @ .5 bpm with two 20 min hesitations.. No pressure bump or returns into cellar. Will attempt again with more cement. (03/27/2019) Squeeze 14 ppg SqueezeCrete through leak point at 90' in OA. Pumped 5.8 bbls of SqueezeCrete cement into OA using 1600 psi as max pressure. At 0.8 opts away caught fluid and proceed with bumping pump between 800 - 1200 psi. Conductor Top Job (08/29/2019): TOC = 6' from top lip. Inserted a funnel with tygon tubing to just above top of cement. Used 55 gallons of 15.8 ppg Class G cement to fill conductor within 6" from the top. Sampled returns from conductor till they weighed out to 15.6 # ppg. Monitor for leaks in conductor or cellar. Intervals treated (measured): Surface to 90' Treatment descriptions including volumes used and final pressure: OA Squeeze: 9.4 and 5.8 bbls SqueezeCrete / Conductor Top Job: 55 gallons of 15.8 ppg Class G Cement. Final Pressures: OA = 0 psi, IA = 150 psi, TBG = 709 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Shut In 0 606 Subsequent to operation: Shut In 150 709 14. Attachments: (required per 20 MC 25.07025.071.&26.203) 15. Well Class after work: Daily Report of Well Operations p Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG Z GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318404 Authorized Name: Worthington, Aras J Contact Name: Worthington, Area J Authorized Title: Intepeptions 81r�tegrity Efgineer,,;/' Contact Email: Ams.Worthingt00(Qbp.Lom Authorized Signature: 1i,wr.f���/� �Daatt/e,:���U-jO°//�(J�/� ContactPhh000n/e:: +1 907 564 4102 Form 10404 Revised 04/2017 ////� -u�•Q Lr X1'9 ABIDMS6.4Of Z 2 2 2010Submit Original Only Daily Report of Well Operations PBU X -20A ACTIVITYn ATF 01 IwwwwwnV T/I/O = SSV/0/40. Temp = SI. WHPs (Eval fluid in cellar). There is -4" of dark fluid in cellar. No LEL's T above top of fluid or anywhere else in WH. No bubbling observed in cellar at this time. 1/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:40 T/I/O = SSV/Vac/34. Temp = SI. WHPs (Eval fluid in cellar). No AL. IAP went on a Vac, & OAP decreased 6 psi since 1/2/2019. 5" of dark fluid in cellar @ 3 o'clock position. No active bubbling, or LEL's anywhere in well house at present time. 1/7/2019 WV = LOTO. SV, SSV = C. MV = O. IA, OA = OTG. 14:00 T/I/O=SI/0/35 PRE CEMENT SQUEEZE. Arived on location & OA had 35 psi. R/U & started bleeding 1/7/2019 OA down. Bleed OA to 0 psi. Started one HR monitor. *** Job Countiued on 1/8/2019 *** TWO = SI/0/0 PRE CEMENT SQUEEZE. Job continued from 1/7/2019 One Hr monitor complete with no flow. R/D OA Comp blind & instal 2" intagral. Torqued OA Comp intagral to 188 ft lbs. (L7M RC). R/D 2" OA Valve & Install intagral. Torqued OA intagral to 188 ft lbs. (L7M RC). Installed hardline 1/8/2019 jewelry on OA & OA Comp. RDMO ***Job Complete*** FWHP = SI/0/0 T/I/O = SSV/Vac/0. Temp = SI. WHP's. (Eval fluid in cellar). No change in WHP's overnight. -1" of black fluid in cellar @3 O'clock position. Both OA flanges have integral flanges and 2" HL risers installed. 1/8/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:40 T/I/O = SSV/VAC/20. Temp = SI. WHPs (WIE Req). Black fluid in cellar around wellhead in cellar. Bubbling at 4:00 o'clock. Both OA flanges have 2' HL risers installed. IAP unchanged, OAP increased 20 psi since 1/8/19. 2/1/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:30 Job Scope: OA Down squeeze to repair leak @ 90'. Pum ed 9.4 bb's sgzcrete into OA a.5 bpm with two 20 min hesitations.. No pressure bump or returns into cellar. Noted only minimal bubbling. Cleared surface an out et w/ a -4 gal diesel. 2/9/2019 ***Will attempt againw/ more cement*** 1/0/1 SV/O/SLB Pumping Services Job Scope: Squeeze 14 ppg SqueezeCrete through leak point at 90' in OA. Pumped 5.8 bblls of SqueezeCrete cement into OA using 1600 psi as max pressure. At 0.8 bb's away caught fluid and proceede with bumping pump between 800 - 1200 psi. Called APE and raised max pressure to 1600 psi. At that pressure pump operator was able to stall pump in high gear and as pressure would drop to around 1100 psi pump would stroke on its own. A few weeks earlier squeeze was attempted with no indication of pressuring up. Charge pump was discharging faster than 3/27/2019 positive displacement pump; cement van triplex. ***Job Complete** T/I/O=SI/0/0 Removed integrals and block valves, N/U OA valve on working side and VR plug with blind and bleeder plug on non -working side. Torqued to specs, PT'd. see "Field Charted Tests" FWP's SI/0/0 3/29/2019 see log for details. ****WELL S/I ON ARRIVAL**** (Post Cement Squeeze) RAN 3.60" BELL GUIDE, 2-1/2" JDC, S/D @ 5,987' SLM (Schmoo on tools) RAN 10' x 3" PUMP BAILER TO 10,673' SLM (Bailer full of fluid) RAN 4-1/2" BRUSH, 3.50" G -RING TO 6,500' SLM (Tight spot 5,945' to 6,030' s'm) DRIFTED W/ 4-1/2" BRUSH, 3.805" G -RING TO TOP OF PRONG @ 10,673' SLM (No issues) PULLED 4-1/2" PX -PLUG FROM 10,678' SLM / 10,700' MD 4/2/2019 ****WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE**** TWO = Vac/Vac/0. Temp = SI. _OA Integrity Test PASSED (Eva' SC leak) OA FL @ Near Surface Pressured OAP to 1200 psi with 6 gal of diesel. Monitored for 5 min. OAP dropped off to 260 psi. Repeated 3 more times with similar results, (see log for details). No fluid to cellar. Bled OAP to 0 psi. Final WHPs = Vac/Vac/0. 5/12/2019 SV, WV, SSV = C. MV = O. 'A, OA = OTG. 11:30 TWO = SSV/Vac/10. Temp = SI. WHPs (Post OA cemented). Dark hydrocarbon fluids have inf'owed into the cellar from the 3 around to the 12 o'clock position and is -2.5" deep and 12" out from conductor. Collected cellar sample and dropped off at the lab. 5/15/2019 ISV, WV, SSV = C. MV = O. IA, OA = OTG. 16:15 Daily Report of Well Operations PBU X -20A T/1/0 = SSVNac/10. Temp = SI. WHPs (Post OA cemented). Dark hydrocarbon fluids in cellar from the 3 o'clock to the 12 o'clock position and is -2.5" deep and 12" out from conductor. 5/16/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 T/I/O = SSV/Vac/10. Temp = SI. WHPs (Post OA cemented). Dark hydrocarbon fluids in cellar from the 3 o'clock to the 12 o'clock position and is -2.5" deep and 12" out from conductor. No change in WHPs or fluid depth or dimensions. 5;17,2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 T/I/O = SSVNac/10. Temp = SI. WHPs (Post OA cemented). Dark hydrocarbon fluids in cellar from the 3 o'clock to the 12 o'clock position and is -2.5" deep and 12" out from conductor. No change in WHPs or fluid depth or dimensions. 5/18/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:00 T/I/O = SSV/Vac/10. Temp = SI. WHPs (Post OA cemented). Dark hydrocarbon fluids in cellar from the 3 o'clock to the 12 o'clock position and is -2.5" deep and 12" out from conductor. No change in WHPs or fluid depth or dimensions overnight. 5/19/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:40 TWO = SSV/0/7. Temp = SI. Assist Ops w/ POI. IA FL @ surface. OA cemented to surface. Dark hydrocarbon fluids in cellar from the 3 o'clock to the 12 o'clock position and is -2.5" deep and 14" out 5/20/2019 from conductor. Monitored WHPs & bled as needed. Continued on next day WSR. *** Continued from previous day *** T/I/O = SSV/0/7. Temp = SI. Assist Ops w/ POI. IA FL @ surface. OA cemented to surface. Dark hydrocarbon fluids in cellar from the 3 o'clock to the 12 o'clock position and is -4" deep and 14" out from conductor. SI well @ 19:30 for 24 hrs. Monitored WHPs & bled as needed. Final WHPs = VACNAC/11. 5/21/2019 *** Job continued on 5/22/19 AWGRS*** *** Job continued from 5/21/19 AWGRS *** TWO VACNAC/11. Temp = SI. Assist Ops w/ POP. IA FL @ surface. OA cemented to surface. Dark hydrocarbon fluids in cellar from 3:00 to 12:00 position & is 4" deep about 14" out from conductor. Monitor WHPs & bled as needed. Bled IAP down to 200 psi before departure, IAP increased 20 psi while rigging down. Final WHPs = 840/220/15. 5/22/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:59 TWO = 920/520/20. Temp = 140°. WHPs (UE). On PWI. No change in cellar fluid condition. No active bubbling present at this time TP increased 20 psi, IAP increased 80 psi from 02:00 this morning. 5/24/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30. T/1/0 = 900/440/20. Temp = 1400. WHPs (UE). On PWI. Cellar has - 4" hydrocarbon fluid in cellar. Bubbling @ 1:00, 4:00, & 8:00 positions. TP increased 60 psi, IAP increased 220 psi, OAP increased 5 psi since 5/22/19. 5/24/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 02:00 TWO = 960/500/20. Temp = 1410. WHPs (UE). On PWI. Cellar has -4" hydrocarbon fluid, unchanged from previous day. Bubbling from 4 & 8 o'clock positions in the cellar. No LELs at 1" above bubbling. TP increased 40 psi, IAP increased 40 psi, and OAP unchanged in 11 hours. 5/25/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 02:30 T/I/O = 600/310/20. Temp = 141°. WHPs (UE). On PWI. Cellar has 6" of hydrocarbon fluid, Bubbling from 4 & 8 o'clock positions in cellar. No LELs @ 1" above bubbling. TP decreased 360 psi, IAP decreased 190 psi, & OAP unchanged since earlier in the day. 5/25/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:30 T/I/O = 580/170/20. Temp = 139°. WHPs (UE). On PWI. Cellar has -6" of fluid, 18" out from conductor which appears to be groundwater with a thin film of crude. Active bubbling is present from 4 & 8 o'clock positions in cellar._ No LELs np 1" or V above bubbling or in remainder of wellhouse. Temp increased 1 °, TP increased 10 psi, IAP increased 30 psi from 04:45 this morning. 5/2612019 ISV = C. WV, SSV, MV = O. IA, OA = OTG. 14:00. Daily Report of Well Operations PBU X -20A T/I/O = 570/140/20. Temp = 138°. WHPs (LIE). On PWI. Cellar has 6" of hydrocarbon fluid, Bubbling from 4 & 8 o'clock positions in cellar. No LELs @ 1" above bubbling. TP decreased 30 psi, IAP decreased 170 psi, & OAP unchanged since 13:30 on 5/25/19. 5/26/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:45 TWO = 580/138/15. Temp = 1360. OA Integrity Test (Eval SC Leak). Max Applied Pressure = 1200 psi. On PWI. OA FL @ surface. Pumped -3 gals diesel down OA to reach 1200 psi. Monitored for 30 mins. OAP lost 878 psi in 30 mins w/ no change in cellar activity. Bled OAP from 328 psi to 0+ psi in <1 min. Held open bleed on OA for 30 mins. Cellar fluid sample taken. Final WHPs = 580/130/0. 5/27/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 1215 hrs. T/I/O = 560/140/20. Temp = 1370. WHPs (LIE). On PWI. Cellar has -7" of hydrocarbon fluid. Active bubbling in the 4 and 5 o'clock positions. No LELs @ 1" above bubbling. TP decreased 20 psi, IAP decreased 30 psi, and OAP unchanged in 12 hours. 5/27/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 02:30 T/I/O = 570/110/04. Temp = 1370. WHPs (LIE). On PWI. Cellar has -7" of hydrocarbon fluid. Active bubbling in the 4, 5, & 8 o'clock positions. No LELs @ 1" above bubbling. TP increased 10 psi, IAP decreased 20 psi, and OAP decreased 16 psi in 13 hours. 5/28/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:45 TWO = 600/110/5. Temp = 137°. WHPs (LIE). On PWI. Cellar has 10" of fluid @ 6:00 position measured by conductor. Fluid composition appears to be water with a thin film of crude. Active bubbling is present at the 2 ;00 and 4:00 positions. No LELs detected 1 ", V above bubbling or in the rest of wellhouse. TP increased 30 psi, OAP increased 1 psi from 03:45 this morning. 5/28/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:40. T/I/O = 700/70/5. Temp = 1360. WHPs (LIE). On PWI. Obtained a cellar fluid sample. -7.5" of hydrocarbon fluid. Active bubbling in the 4 o'clock position. No LELs @ 1" above bubbling. TP increased 130 psi, IAP decreased 40 psi, & OAP increased 1 psi overnight. 5/29/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:00 T/I/O = 570/110/5. Temp = 1370. WHPs (LIE). On PWI. Cellar has 12" of fluid @ 6:00 position measured by conductor. Fluid composition appears to be water with a thin film of crude. Active bubbling is present at the 2:00, 4:00 and 8:00 positions. No LELs detected 1", 1' above bubbling or in the rest of wellhouse, all other reads normal. TP decreased 130 psi overnight. 5/30/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:30. T/I/O = 570/110/5. Temp = 137°. WHPs (Eval bubbling in cellar). On PWI. Cellar has 12" of fluid @ 6:00 position measured by conductor. Fluid composition appears to be water with a thin film of crude. Active bubbling is present at the 2:00, 4:00 and 8:00 positions. 8:00 position got 2.8% LEL reading 1" above the fluid & 0% 1' above the fluid. No LELs detected 1", 1' above bubbling in the 2:00 & 4:00 positions or the rest of wellhouse, all other reads normal. No change in TP, IAP decreased 10 psi, OAP increased 1 psi overnight. 5/31/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:55 TWO = 620/70/0+. Temp = 136*. WHPs (LIE). On Inj. Celllar has 13.5" of fluid @ the 6 o'clock position, next to the conductor. Fluid in cellar has a dark layer on top. Active bubbling at the 2 to 4 o'clock positions (0 % LELs @ 1" ablove bubbling or anywhere else in the wellhouse). TP increased 50 psi, IAP decreased 40 psi and the OAP decreased 5 psi overnight. 6/1/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 09:55 T/I/O = 600/120/10. Temp = 138*. WHPs (LIE). On PWI. Cellar has 12.5" of fluid with a dark layer in it (6 o'clock position, next to conductor). Bubbling @ the 4 o'clock position (0% LELs 1" above bubbling or anywhere else). The TP decreased 20 psi, IAP increased 50 psi and the OAP increased 10 psi overnight. 6/2/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 13:40 Daily Report of Well Operations PBU X -20A T/I/O = 600/120/10. Temp = 139*. WHPs (UE). On PWI. Cellar has 13" of fluid in it with a dark layer on top (measured @ the 6 o'clock position next to conductor). Bubbling @ the 4 & 8 o'clock positions (0% LELs 1" above bubbling or anywhere else). The TP, IAP and OAP remained unchanged overnight. 6/3/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:50 T/I/O = 610/210/10. Temp = 1390. WHPs (UE). On PWI. Cellar has 11.5" of fluid in itwith a dark layer on top (measured @ the 6 o'clock position next to conductor). Bubbling @ the 4 o'clock, nothing at the 8 o'clock positions (0% LELs 1" above bubbling or anywhere else). TP increased 10 psi, IAP increased 90 psi and the OAP remained unchanged overnight. 6/4/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:20 T/I/O = 600/260/10. Temp = 140*. UE WHPs (eval bubbling in cellar). On PWI. Cellar has 11.5" of fluid in it with a dark layer on top (measured @ the 6 o'clock position next to conductor). Bubbling @ the 4 & 8 o'clock positions (0% LELs 1" above bubbling or anywhere else). TP decreased 10 psi, IAP increased 50 psi, OAP unchanged overnight. 6/6/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:05 T/I/O = 590/220/10. Temp = 138*. UE WHPs (eval bubbling in cellar). On PWI. Cellar has 11.5" of fluid in it with a dark layer on top (measured @ the 6 o'clock position next to conductor). Bubbling @ the 4 o'clock position (0% LELs 1" above bubbling or anywhere else). TP decreased 10 psi, IAP increased 40 psi, OAP unchanged overnight. 6/7/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 02:00 T/I/O = SSV/Vac/0+. Temp = SI. UE WHPs (eval bubbling in cellar). Cellar has 11.5" of fluid in it with a dark layer on top (measured @ the 12 o'clock position next to conductor). No bubbling seen at this time. Well has been SI since last monitor. WV is LOTO. 6/9/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:12 T/I/O = SSV/Vac/0+. Temp = SI. UE WHPs (eval bubbling in cellar). Cellar has 11.5" of fluid in it with a dark layer on top (measured @ the 12 o'clock position next to conductor). No bubbling seen at this time. Well has been SI since last monitor. 6/10/2019 WV = LOTO. SV, SSV = C. MV = O. IA, OA = OTG. 1530 hrs. T/I/O = SSV/VAC/0+. Temp = SI. UE WHPs (eval bubbling in cellar). No change in the WHPs overnight. Cellar has 10.5" of fluid in it with a dark layer on top (measured @ the 12 o'clock position next to conductor). Bubbling @ 4 o'clock position (- 60 second intervals, 0% LELs 1" above bubbling or any where else in wellhouse). 6/11/2019 SV = C. WV = LOTO. SSV, MV = O. IA, OA = OTG. 11:50 T/I/O = 0/0/0. Removed CV from working IA and installed blind. Torqued to API specs and PT'd to 2500 psi. PASSED*** Job Complete*** 6/12/2019 Final T/I/O = 0/0/0 TWO = SSV/VAC/0+. Temp = SI. UE WHPs (eval bubbling in cellar). No change in the WHPs overnight. Cellar has 10.5" of fluid in it with a dark layer on top (measured @ the 12 o'clock position next to conductor). Bubbling @ 4 o'clock position (- 3 min intervals, 0% LELs 1" above bubbling or any where else in wellhouse). 6/12/2019 SV = C. WV = LOTO. SSV, MV = O. IA, OA = OTG. 14:30 TWO = SSV/VAC/0+. Temp = SI. UE WHPs (eval bubbling in cellar). No change in the WHPs overnight. Cellar has 10.5" of fluid in it with a dark layer on top (measured @ the 12 o'clock position next to conductor). Bubbling @ 4 o'clock position (- 3 min intervals, 0% LELs 1" above bubbling or any where else in wellhouse). 6/13/2019 SV = C. WV = LOTO. SSV, MV = O. IA, OA = OTG. 14:00 TWO = SSV/VAC/0+. Temp = SI. UE WHPs (eval bubbling in cellar). No change in the WHPs overnight. Cellar has 10.5" of fluid in it with a dark layer on top (measured @ the 12 o'clock position next to conductor). Bubbling @ 4 o'clock position - 3 min intervals, 0% LELs 1" above bubbling and throughout wellhouse. 6/14/2019 SV = C. WV = LOTO. SSV, MV = O. IA, OA = OTG. 14:00 Daily Report of Well Operations PBU X -20A T/I/O = SSV/VAC/O+. Temp = SI. UE WHPs (eval bubbling in cellar). No change in the WHPs overnight. Cellar has 10.5" of fluid in it with a dark layer on top (measured @ the 12 o'clock position next to conductor). Bubbling @ 4 o'clock position - 3 min intervals, 0% LELs 1" above bubbling and throughout wellhouse. 6/15/2019 SV = C. WV = LOTO. SSV, MV = O. IA, OA = OTG. 15:00 TWO = SSVNac/0+. Temp = SI. WHPs (eval bubbling in cellar). WHPs unchanged overnight. Cellar has 10.5" of fluid w/ a dark layer on the surface (measured @ 12 o'clock next to conductor). No bubbling observed in cellar during monitor. 6/16/2019 SV = C. WV = LOTO. SSV = C. MV = O. IA, OA = OTG. 17:30 T/I/O = SSVNac/0+. Temp = SI. WHPs (eval bubbling in cellar). WHPs unchanged overnight. Cellar has 13" of fluid w/ a dark layer on the surface (measured @ 12 o'clock next to conductor). No bubbling observed in cellar at this time. 6/18/2019 SV = C. WV = LOTO. SSV = C. MV = O. IA, OA = OTG. 03:30 TWO = SSVNAC/0+. Temp = SI. WHPs (eval bubbling in cellar). WHPs unchanged overnight. Cellar has 13" of fluid w/ a dark layer on the surface (measured @ 12 o'clock next to conductor). No bubbling observed in cellar at this time. 6/19/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 T/I/O =SSVNAC/0+. Temp = SI. WHPs (eval bubbling in cellar). WHPs unchanged overnight. Cellar has 13" of fluid w/ a dark layer on the surface (measured @ 12 o'clock next to conductor). No bubbling observed in cellar at this time. SV, WV, SSV = C. MV = O. IA, OA = OTG. 1440 hrs. 6/21/2019 TWO = SSVNAC/3. Temp = SI. WHPs (eval bubbling in cellar). WHPs unchanged since 06/21/19. Cellar has 13" of fluid w/ a dark layer on the surface (measured @ 12 o'clock next to conductor). No bubbling observed in cellar at this time. 6/23/2019 SV, WV, SSV = C. MV =p O. IA, OA = OTG. 21:00 T/I/O =SSVNAC/3. Tem = SI. WHPs (eval bubbling in cellar). WHPs unchanged since 06/21/19. Cellar has 13" of fluid w/ a dark layer on the surface (measured @ 12 o'clock next to conductor). No bubbling observed in cellar at this time. 6/25/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 T/I/O = VacNac/3. Temp = SI. Prep for excavation. WHPs unchanged since 06/25/19. Cellar has 9.5" of fluid w/ a dark layer on the surface (measured @ 6 o'clock next to conductor). No bubbling observed in cellar at this time. )yacced fluid from conductor (1.8 bbls). Monitored 1 hr. Fluid inflowed 1.5 bbls. Cellar gravel tapers from 23" deep from inside edge of 8' culvert to 44" at conductor. Floor grating is of the yellow composite type. Top of RG 2401 is 7" deep in conductor (13.6 gallons pumped on 12/13/10). No circ ports are visible at this time. 6/30/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00. T/I/O = SSV/0/0. Temp = SI. WHPs (Prep for conductor top job). Conductor is 24" from top lip to hard bottom with -14" of RG -2401. 8/2/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:15 T/I/O = SSV/0/0. Temp = SI. Steam conductor (Pre top job). Steamed conductor for 3 hours before breaking through a layer of gravel. Re -strapped the conductor getting 5.5' in the 12 o'clock position & 6' in the 6 o'clock position. Ran out of time to get a thorough cleaning. Job will continue on 8/27/19. Left WH doors open with copus fan and blower moving air. 8/26/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 T/I/O = SSV/0/0. Temp = SI. Steam Conductor (Pre top Job). Continued steaming the conductor and rinsing the cellar. Unable to get a thorough cleaning will continue 8/28/19. WH doors open with copus fan and blower moving air. 8/27/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:00 Daily Report of Well Operations PBU X-20A = emp = SI. Steam Conductor re top /o team cleaned Conductor for top job. Rinsed the cellar floor numerous times getting a lot of the scum that was stuck on the gravel. Heater on and working. Swab cap bled to 0 psi, WH doors open, and copus fan running upon departure. 8/28/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 17:20 TWO = SSV/0/0. Temp = SI. Conductor top job. TOC = 6' from top lip. Inserted a funnel with tygon tubing to just above top of cement. Used 55 gallons of class G cement 15.8 # to fill conductor within 6" from the top. Sampled returns from conductor till they weighed out to 15.6 # ppg.Removed Copus fans. Heater on and running properly and WH doors open. 8/29/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 12:30 T/I/O = SSV/0/0 TEMP = SI, PPPOT-T Eval Leaky LDS (PASS) PPPOT-T: Stung into test void 50 psi, bled test void to 0 psi. Monitored for 15 min, no change in pressure. Torque all LDS to 450 ft/lbs. R/U test equipment Pump though test void. Hold open bleed on (SBMS Seal). Pressure void to 5,000 psi for 30 min. Lost 100 psi in 15 min, lost 0 psi in second 15 min 9/8/2019 (PASS). Bleed test void to 0 psi, R/D test equipment. T/I/O = VacNac/10. Temp = SI. POP Watch (eval TxIA). IA FL @ near surface, OA FL @ surface (cemented). Monitored WHP's and temp until) stabilized. There is no fluid or LEL's in the conductor or cellar. There is no sign of leaks anywhere on the surface kit. Final WHPs = 470/10/20. 9/19/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 23:59 T/I/O = 500/30/20. Temp = 136*. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. AL gas available next door (X-19). 9/20/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 1615 T/I/O = 550/40/20. Temp = 138*. WHPs (Eval SC leak). On PWI. No signs of leaks in the conductor or cellar. The TP increased 50 psi, IAP increased 10 psi and the OAP remained unchanged overnight. 9/21/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:15 T/I/O = 600/60/20. Temp = 1360. WHPs (eval SC leak). No signs of leaks in the conductor or cellar. TP increased 50 psi, IAP increased 20 psi, and OAP unchanged overnight. 9/22/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 15:30 T/I/O = 600/60/20. Temp = 137*. WHPs (Eval SC leak). On PWI. No signs of leaks in the conductor or in the cellar. The TP increased 50 psi, IAP increased 20 psi and the OAP remained unchanged overnight. 9/23/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 11:15 T/I/O = 620/30/20. Temp = 1370. WHPs (eval SC leak). On PWI. No signs of leaks in the conductor o in the cellar. TP increased 20 psi IAP decreased 30 psi, & OAP unchanged since 9/23/19. 9/25/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 12:30 TWO = 600/50/20. Temp = 139*. WHPs (Eval SC leak). On PWI. No signs of leaks in the conductor or the cellar. Used AL from well #19 to increased the IAP from 50 psi to 300 psi in 30 seconds. The IA & OAP remained unchanged in the 30 minute monitor. FWPs = 600/300/20. 9/27/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:40 TWO = 620/50/20. Temp = 1380. WHPs (Eval SC leak). On PWI. IA & OA FL @ surface. No sign of leaks in the cellar or conductor. Cellar and conductor are dry. IAP increased 30 psi since 9/25/19. 9/27/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 01:50 T/I/O = 590/210/20. Temp = 135*. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. The TP decreased 10 psi, IAP decreased 90 psi and the OAP remained unchanged overnight. 9/28/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:50 1/1/0 = 630/210/20. Temp = 1350. WHPs (eval SC leak). On PWI. No indication of leaks in cellar or ISV conductor. TP increased 40 psi, IAP & OAP unchanged overnight. 9/29/2019 = C. WV, SSV, MV = O. IA, OA = OTG. 16:45 Daily Report of Well Operations PBU X-20A TWO = 670/240/20. Temp = 137*. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. The TP increased 40 psi, IAP increased 30 psi and the OAP remained unchanged overnight. 9/30/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 10:50 TWO = 620/290/20. Temp =140°. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. Temp increased 30. TP decreased 50 psi, IAP increased 50 psi and the OAP remained unchanged since last monitor on 09/30/19. 10/3/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:30 T/I/O = 660/290/30. Temp = 139°. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. TP increased 40 psi, IAP unchanged and the OAP increased 10 psi overnight. 10/4/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:30 T/l/O = 670/170/20. Temp = 1350. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. Temp decreased 4°. TP increased 10 psi, IAP decreased 120 psi and the OAP decreased 10 psi overnight. 10/5/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG 02:30 T/I/O = 690/220/20. Temp = 1380. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. Temp decreased 30. TP increased 20 psi, IAP increased 50 psi and the OAP unchanged overnight. 10/6/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG 00:45 TWO = 670/250/20. Temp = 1410. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. Temp decreased 30. TP decreased 20 psi, IAP increased 30 psi and the OAP unchanged overnight. 10/7/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG 01:40 TWO = 680/290/30. Temp = 141 °. WHPs (eval SC leak). On PWI. No indications of leak in the cellar or conductor. TP increased 10 psi, IAP increased 40 psi and OAP increased 10 psi overnight. 10/8/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 16:30 TWO = 710/240/20. Temp = 1380. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. Temp decreased 30. TP increased 30 psi, IAP decreased 50 psi and the OAP decreased 10 psi overnight. 10/9/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG 01:45 TWO = 670/280/30. Temp = 1400. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. Temp increased 20. TP decreased 40 psi, IAP increased 40 psi and the OAP increased 10 psi overnight. 10/10/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG 04:30 T/I/O = 720/260/30. Temp = 1380. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. TP decreased 50 psi, IAP decreased 20 psi and the OAP unchanged overnight. 10/11/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG 02:30 TWO = 680/200/20. Temp = 139*. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. TP decreased 40 psi, IAP decreased 60 psi and the OAP decreased 10 psi overnight. 10/12/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 04:20 T/I/O = 680/240/20. Temp = 1420. WHPs (Eval SC Leak), On PWI. No signs of leaks in the conductor or cellar. TP unchanged, IAP increased 40 psi and the OAP unchanged overnight. 10/13/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:40 TWO = 690/190/20. Temp = 1390. WHPs (Eval SC Leak). On PWI. No signs of leaks in the conductor or cellar. TP increased 10 psi, IAP decreased 50 psi and the OAP unchanged overnight. 10/15/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:30 T/1/0=7201160/20. Temp = 139°. WHPs (Eval SC Leak). On PWI. No evidence of fresh leaks in the conductor or cellar. TP increased 30 psi, IAP decreased 30 psi from 10/13/19. 10/16/2019 SV = C. WV, SSV, MV = O. IA, OA = OTG. 03:45. 4-1/16' aW ,D= FMC X2= BAKER 68.8' = 68.8' = 38.5' �� 800' I"' `^ 10.3/4' CBG, 45.5#, N! 80, - 3566 LFEB7C, D=9.950' Minimum ID = 2.347" @ 11031' 2-7/8" PUP JOINT BG, 12 .6#, L-80 TO0 .0152 bpf, D = 3.958• 12.6#, L-80 NSCi, 10722' 9)=2.441- 11 11055' 8.81#, L-80 STL, .0087 bpf, D = 2.990' FERFORATTON SL&WARY RE= LOG GRICCL ON 1026/07 ANGLEAT TOP PERF: 88' @ 11310' Note: Refer to Production DB for historical pert data SIZE SPF WE2VAL OpNSgz SHOT SOZ 2' 6 11310 - 11340 O 04/03/15 2" 6 11416 - 11446 O 04/03/15 2" 6 11570 - 11600 O 04/02/15 2" 6 11710 - 11740 O 04102/15 2" 6 13110 - 13500 O 1027/07 SAFETY NOTES: EAVERAGE 125 pp. X -20A WHO MI. WELL REQIRSASSSVWHEN ON '@1105ML WB_LANGLE>70E7'. L jIT4 2244' 4-12-HESXNP,D=3.813' 10655' r14-12° HES X NP, D = 3.813° 10676' 7-5/8' X 4-12' BKR S-3 PKR, D = 10700' 4-12' FIBS X NP, D = 3.813° 1073W 7-5/8'X4-1/2-UNDUEOVERSHO x 4-12° BKR S-3 PKR D = 3.875' OTIS X 11)=3.813' 10803' X17-5/8' X 6.345' TACK, D = 5.75- 10813' 7-5/8• X 6.358' TTN PM D = 575- 46814' 4-1/2' WLEG, D= 3.958' 10818' ELMD TT LOG XXOOIOIX 10821' 7-5/8' X 6.686' TTN DTH HYD HGR D = 499- 10826- 572'X4-12'XO, D=3.91' 11026' X14-12" KB LTP, D = 2.560' 1 11031' 2-7/8' STL PUP Ji, D = 2.347' 11057' 3.70' BTT LNR DEPLOY SLV, D = 3.00' 11063' 3-12' STL PN, 11066' 3-12'XNP,1)=2.813' 1 11099' X13-12•X3-3/16•XO,1D=2.786• I MILLOLIT WINDOW (X -20A) 11285'- 11274' 11643' 33/16' X i iiq!9�D = 2.441' 11)6.2.80TCB, I— ttsa3' 1 �\ D=2.60'' ® 13517' 2-7/8' LNR, 6.16', L-80 STL, .0058 bpf, D = 2441' 73569' DATE RLV BY CoNfAR 5 DATE FST/ BY OOMM34TS 06(22194 NtBE ORDINAL COMPLEDON 04/03/15 JGLJ PJC ADPEiFS 1029197 C l?M & CTD SDTRCK (X-20 08/01/18 LLGIJAD SET X PLl1G (0721118) 05/12/08 W PJC DRLG GRAFT OOF7IRBLRIONS 09/17/18 JNL/JM7 ADD CKB, RIF, & BF & ®N® PER= ORDER 06/04/08 GJS/PJC DFa-G DRAFT CORRBZ; 0 04/03/19 MiVMJ RJLL®PX PLUG (04/02/19) 11/17/10 KLS/PJC MN D CORFECTION 06/18/19 JTGtjm as N OA TO SURFACE 02/76/11 M3/JMJ ADDED SSSV SAFEY NUTE PRLUFI0E BAY LW WELL: X -20A PERN7 No: 1071130 AR 197: 50.029-22478-02 SEC 5, T10T1 R14R 349' FSL & 103' F%AL BP Explwation (Alaska) Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, October 16, 2019 8:23 AM To: Wallace, Chris D (CED); AK, OPS EOC Specialists; Ak, OPS GC1 Field PTL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Glasheen, Brian P; Igbokwe, Chidiebere Cc: Regg, James B (CED); AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Obrigewitch, Beau; Smith, Travis T (CONOCOPHILLIPS); Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J Subject: OPERABLE: Injector X-20 (PTD #2071130) fugitive hydrocarbon emissions repaired with conductor top job All, Injector X-20 (PTD #2071130) was put Under Evaluation on 09/18/19 to monitor the well after a conductor top job was pumped to halt fugitive hydrocarbon emissions that were still present upon completing a surface casing repair. The well was placed on injection on 09/19/19 and daily monitors have demonstrated the conductor top job has remedied the fugitive hydrocarbon emissions. The well will now be classified as OPERABLE. Please respond with any questions. Andrew Ogg Well Integrity Engineer BP Global Wells Organization -Alaska Office: 907-659-8110 rom: AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com> Sen . ednesday, September 18, 2019 2:07 PM To: AK, G ell Integrity Engineer <AKGWOWeliSiteEnginee@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecl ' is@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1Field PTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WeIIpadLea p.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.c >; AK, OPS Well Pad AB <AKOPSWeliPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWeIIPadCX@bp.com>; Ak, est Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; sheen, Brian P <Brian.Glasheen@bp.com>; Igbokwe, Chidiebere <Chidiebere.Igbokwe@bp.com>;'chris.wallace@alask . pv'<chris.wallace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWeIIlntegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp_com>; Cismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.Dempsey1@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>,- Janowski, Carrie <Carrie.janowski@bp.com>; Montgomery, Travis J <Travis.Montgomery@bp.com>; Munk, Corey <Corey.Munk@bp.com>; Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com>; O'connor, Katherine Wallace, Chris D (CED) From: AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com> Sent: Wednesday, September 18, 2019 2:07 PM To: AK, GWO Well Integrity Engineer, AK, OPS EOC Specialists; Ak, OPS GC1 Field PTL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL, Glasheen, Brian P; Igbokwe, Chidiebere; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey, Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras 1; Regg, James B (CED) Subject: UNDER EVALUATION: Injector X-20 (PTD #2071130) Fugitive hydrocarbon emission from cellar after surface casing repair All, Injector X-20 (PTD #2071130) was made Not Operable on 06/10/19 due to anomalous cellar activity indicating the previous OA squeeze was not successful in repairing a surface casing leak. A conductor top job was completed on 08/29/19. At this time the well is reclassified as Under Evaluation and can be put on injection for further diagnostics. Please note that the IA / OA are liquid packed and DHD is available to assist during well start. Please respond with any questions, Ryan Holt Well Integrity Office: 907-659-5102 From: AX,.GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Mondune 10, 2019 1:54 PM To: AK, GWOe Wegrity Engineer <AKGWOWeliSiteEnginee@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists om>; Ak, OPS GC1 Field PTL <AkOPSGC1 Field PTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead@bp.c >; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; A , PS Well Pad AB <AKOPSWeliPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWeIIPadCX@bp.com>; Ak, Ops Wes a TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RESWest Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Glashee rian P <Brian.Glasheen@bp.com>; Igbokwe, Chidiebere <Chidiebere.Igbokwe@bp.com>;'chris.wallace@alaska.gov'< wal lace @a laska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt Com>; AK, GWO DHD Well Integrity <AKD8eCDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity <AK C ojectsWelllntegrityEngineer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, O F Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AKIMS App User <akimsuser.service@bp.com , ismoski, Doug A <CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>; Dempsey, David G <David.De ey1@bp.com>; Dickerman, Eric <Eric.Dickerman@bp.com>; Hibbert, Michael <Michael.Hibbert@BP.com>; Jano i, Carrie Wallace, Chris D (CED) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Monday, June 10, 2019 1:54 PM To: AK, GWO Well Integrity Engineer, AK, OPS EOC Specialists; Ak, OPS GC1 Field PTL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr, AK, RES GPB West Wells Opt Engr, AKOpsProdEOCTL, Glasheen, Brian P; Igbokwe, Chidiebere; Wallace, Chris D (CED) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey, Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (CED) Subject: NOT OPERABLE: Injector X-20 (PTD #2071130) Fugitive hydrocarbon emission from cellar after surface casing repair All, Injector X-20 (PTD #2071130) was made under evaluation on 5/14/2019 in order to perform online diagnostics post surface casing repair. The well was put on injection on 5/21/19 and follow up monitors performed daily show that cellar bubbling and fugitive hydrocarbon emissions are still present. The anomalous cellar activity indicate the OA down squeeze was unsuccessful at repairing the surface casing leak. At this time the well is reclassified as Not Operable an will remain shut in. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 From: AK, GVVQ Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Tuesday, Ma 2019 9:56 AM To: AK, OPS EOC Specialists OPSEOCSpecialists@bp.com>; Ak, OPS GC1 Field PTL <AkOPSGC1Field PTL@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGCl dLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollers co AK, OPS Well Pad AB <AKOPSWeliPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWeIIPadCX@bp.com>; Ak, Ops rea TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr<AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPBAACest Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPC L@bp.com>; Glasheen, Brian P <Brian.Glasheen@bp.com>; Igbokwe, Chidiebere <Chidiebere.lgbokwe@bp.c chris.wallace@alaska.gov' <ch ris.wa I lace @alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO D ell Integrity <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity <AKDCProjectsWelllntegrityEn eer@bp.com>; AK, GWO SUPT Well Integrity <AKDCWellintegrityCoordinator@bp.com>; AK, GWO Well Integrity Well In mation Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Tuesday, May 14, 2019 9:56 AM To: AK, OPS EOC Specialists; Ak, OPS GC1 Field PTL; AK, OPS GC1 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad AB; AK, OPS Well Pad CX; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Glasheen, Brian P; Igbokwe, Chidiebere; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity, AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine, Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector X-20 (PTD #2071130) Surface casing leak repaired with OA downsqueeze All, Injector X-20 (PTD #2071130) was made not operable on 6/22/2018 for having a confirmed surface casing leak. On 3/27/2019 special projects performed an OA downsqueeze under sundry #318-404 and the well passed a subsequent OA integrity test on 5/12/2019. The well is now ready to be brought online to evaluate the success of the repair. At this time the well is reclassified as Under Evaluation. Please note the IA and OA are fluid packed and will require dedicated man watch while bringing the well online. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 From: AK, GWO-W I Integrity Engineer <AKGWOWeliSiteEnginee@bp.com> Sent: Friday, June 22, 2 18,9-.11 AM To:'chris.wallace@alaska.gov' Z " .wallace@alaska.gov>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; AK, OPS GC1 Field O&M TL <AKOPSGCl OMTL2@bp.com>; AK, OPS GC1 Wellpad Lead <AKOPSGC1WellpadLead @bp.com>; AK, OPS P is Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad AB-< KOPSWellPadAB@bp.com>; AK, OPS Well Pad CX <AKOPSWeliPadCX@bp.com>; Ak, Ops West Area TL <AkOps reaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt<g, AKRESGPBWestWellsOpt2@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Boman, Wade <Wade.Boman 96p.com>; Glasheen, Brian P <Brian.Glasheen@bp.com>; Von Tish, Douglas B <Douglas.VonTish@bp.com> Cc:'Regg, James B (DOA) Qim.regg@alaska.gov)' <jim.regg@alaska.gov>; AK, GWO Completio ell Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Integrity <AKD&CDHDWelllntegri@bp.co • AK, GWO THE STATE Alaska Oil and Gas °fALASKA Conservation Commission GOVERNOR BILL WALKER Aras J. Worthington Interventions & Integrity Engineer BP Exploration (Alaska), Inc. P.O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU X -20A Permit to Drill Number: 207-113 Sundry Number: 318-404 Dear Mr. Worthington: 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.oloska.gov 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, Catjy. Foerster Commissioner DATED this day of September, 2018. R60MS�Uci t 36i� STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 ' Operations shutdown Suspend ❑ Perforate ❑ Other -Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter -Casing ❑ Other OA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 207-113 3. Address: P.O. Box 196612 Anchorage, AK 6. qpl Number: 50-029-22478-02-00 99519-6612 Stretigrephic ❑ Service 0 • 7. If perforating: B. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU X -20A 9, Property Designation (Lease Number): 1 10. Field/Pools: ADL 028313 & 047472 PRUDHOE BAY, PRUDHOE OIL - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft), Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13569 • 9058 10700 8779 10700 Casing Length Sin MD TVD Burst Collapse Structural Conductor 80 20" 34-114 34-114 1490 470 Surface 3533 10-3/4" 33-3566 33-3149 5210 2480 Intermediate 10922 7-5/8" 30-10952 30-8923 6180 5120 Liner 462 4-1/2" 10803 - 11265 8840-9008 8430 7500 Liner 2543 3-1/2" x 3-3/16" x 2-7/8" 11026 - 13569 8957-9058 Perforation Depth MO (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (it): 1 11310 -13500 9010 - 9046 4-1/2" 12.6# 28-10814 Packers and SSSV Type: 4-1/2' Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 10676 18764 4-1/Y' Baker SABL-3 Parker 10741 / 8804 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: October 20, 2018 15. Well Status after proposed work. Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 - 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, Area 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: Inteivention4 Integrity Engineer of Authorized Signature: Date: 9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ^ I ^ 1 O 1 1 "JL LJl 1_X1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance ❑ Other: A -C V/ -C VV C C/vl C✓11L S l.Cl�-G /O re -5U/1--5 Wt �A' 419 CG .EJ /s2Glv�l�l,q �rtSS �f`!3�/�tv�vf'S 'i'"o GGil u�. cl vrry -I' bre /Yes ❑ k7 d tri, h / 7 t /in d rr 1r t/a g �`--• Post Initial Injection MIT Req'd? No Spacing Exception Required? Yes ❑ No Subsequent Form Required: (a — f/7 4— APPROVED BYTHE Approved by. COMMISSIONER COMMISSION Date: (TL 91231/8 ORIGINAL RBOMs'�K Form 10403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. p 11019 e �1�ff P7$is Submit Form and Attachments in Duplicate by 'i*W X-20 OA Cement Squeeze Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Wade Boman (907) 564-4674 Expected Start Date: October 201h 2018 History X -20A was a full-time WAG injector, sidetracked from its X-20 parent well in 2007. On 6-20-2018, while the well was on water injection, a pad Operator noted diesel around X-20A's conductor. The Operator notified Well Integrity and on 6-21-2018 a failing Own e_ y est was performed with a LLR of 8 al/min @1190 psi with bubbling and fluid leakage around the circum erence of the surface casing. Current Status The well is classified as "Not Operable" by BP and is secured with a tubing tail plug with a passing MITT to 2250 psi and a passing CMIT TAA to 2250 psi. Objective Pump sealant down the OA two the ink leak and squeeze the surface casing leak. Procedural steps DHD/Special projects 1. Circulate sealant into the OA. 2. Squeeze sealant into the surface casing leak. 3. Wait on sealant to cure. DHD/Well Integrity Engineer 1. POP well Under -Evaluation and monitor conductor/cellar for any leakage. 2. If there is no leakage, convert weTl io Operable status. Loepp, Victoria T (DOA) From: Worthington, Aras J <Aras.Worthington@bp.com> Sent: Tuesday, September 25, 2018 3:39 PM To: Loepp, Victoria T (DOA) Subject: RE: PBU X-20A(PTD 207-113, Sundry 318-404) OA Squeeze to fix SC leak Follow Up Flag: Follow up Flag Status: Flagged Victoria, We went through thorough diagnostic evaluation to make a determination of the surface casing leak but there was not conclusive data to pinpoint the depth. The leak appears to be shallow, somewhere between 90' and 20'. The possible leak depth(s) that are deeper than 20' preclude a Surface Casing Excavation job to repair this well, thus the cement squeeze option was chosen. We plan to base the determination of Operability of the well on the behavior of the well when pumping the cement squeeze (returns to the cellar while pumping the cement squeeze, squeeze pressure ramp, and final squeeze pressure attained -which effectively is a form of pressure test) and then finally, monitoring of the cellar during injection while Under -Evaluation. Aras Worthington Well Interventions & Integrity Engineer BP Alaska Inc. Office: (907) 564-4102 Cell: (907) 440-7692 From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, September 25, 2018 1:34 PM To: Worthington, Aras 1 <Aras.Worthington@bp.com> Subject: PBU X-20A(PTD 207-113, Sundry 318-404) OA Squeeze to fix SC leak Aras, Will the OA be pressure tested after the squeeze? What depth is the surface casing leak, if known? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(dalaska.goy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended TRIS= 4-1/16'CIW Wg.LFE4D= FMC ACTUATOR= -_.__._._____-_..-._______. KB. 9.EV = BAKER 68.8' REF E_B(_ --- 68.6' --- BF. 8.E1/ = 38.5' KOP= Max Ante = 800' 94" @ 12323' Datum MD =--- ----10851' Datum ND= -8600'SS 7CONDUCTOR 110' ? 10-3/4" CSG, 45.5#, NT -80, —1 3568 LHE-BTO, D = 9.950' Minimum ID = 2.347" @ 11031' 2-7/8" PUP JOINT 12.6#, L-80 TCI, .0152 bpf, D = 3.958• 10. 14-1/2' TBG. 12.69. L-80 NSCT..0152 bar. D = 3.958" 1 D = 6.875' ESTIMATED TOP OF CEMENT GE 125 ppm X -20A WHEN ON MAFETY I WELLLLREEQQUIRESASSDINGS SSSVWHEN ON UL WELL ANGLE>70'@11057'. L i 99MA' d-t/2'HFSXNPD=381 4-12' HES X NP, D = 3.813- 7-5/8' X 4-12• BKR S-3 PKR 4-1/2' HES X NP. D = 3.813' 5/8- x 4- VC 13 a SS HCR, U= J. 12'OTIS X NP, D=3.813' 5/8' X 6.345" TEBACK . D = 5.75' 10826' I --I5-1/2• x 4-12' XO, D = 3.91- 11026' 4-12• K13 11 n31' 2-7/8• STL PUP JT. D = 2.347 STL PN, U = X MP. D=2. S 1 L, .UU87 bpi, U = 2.990- I—I 17099'11089' 3-12' X 3-3/16• XO, D = 2.786' (:: I fM4LLOUfTVA4DOW(X-20A) 11265' - 11274' 12-WHPSTOCK00/19/07) 11265' PE2FORATON StA4MARY RE= LOG. GR/CCL ON 10/26/07 ANGLEAT TOP PERF: 88' @ 11310' Note: Refer to Production DB for historical peri data SIZE SPF NTEZVAL Opn/Sgz SHOT SOZ 2" 6 11310-11340 O 04/03/15 2" 6 11416-11446 O 04/03/15 2" 6 11570-11600 O 04/02/15 2" 6 11710-11740 O 04102(15 2' 6 13110-13500 O 1027/07 1 11643' 1 bpf, D=2.80' I POTO 2-7/8' LNR 6.16', L-80 STL, .0058 bpf, D = 2.441' DATE REV BY COMMENTS DATE REV BY I COMMENTS 06/22f94 N11E ORIGINAL COMPLETION 04/03/15 JGU PJC ADPERFS 10/29/07RDIC MO & CTD SDTRCK(X-20J 08/01118 LLG1jmD SEr X PLUG 10721/18) 05/12/08 ?/ PJC DRLG DRAFT CORRECTKM 09/17/18 JIJJJ U ADD OKB, REF, & BF & E RID PERF ORDER 06/04/08 CJWJC DRUG DRAFT CORRE3CTKW 11/17/10 KLSIPJC MIN D CORRECTION 02/16/11 M3/JMD ADDED SSSV SAFETY NOTE X 2-7/8" XO, I I PRUDHDE BAY Wr WELL: X -20A PERMIT No: x1071130 AR No: 50-029-22478-02 SEC 5, TION, R14F, 349' FSL & 103' F BIR Exploration (Alaska) • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Monday,January 25,2016 P.I.Supervisor '1--e,,,,l z (uI SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. X-20A FROM: Johnnie Hill PRUDHOE BAY UNIT X-20A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jew NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT X-20A API Well Number 50-029-22478-02-00 Inspector Name: Johnnie Hill Permit Number: 207-113-0 Inspection Date: 1/16/2016 Insp Num: mitJWH160121124343 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min X-20A W = T 8764 700 _ I 702 • 700 700 - Well � Type Inj � TVD i Tubing I PTD 2071130 - Type Test SPT Test psi 2191 - IA 25 2502 1 2485 • 2486 - Interval 4YRTST - P/F j P v OA 128 402 , 1 393 - 396 - Notes: 3 bbls of meth - SCANNED ,s A ¢i ,p Monday,January 25,2016 Page 1 of 1 STATE OF ALASKA RECEIVED ,SKA OIL AND GAS CONSERVATION COh. .SION APR 2 9 2015 REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate Other ❑ A DGCC Performed. Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver lime Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5 Permit to Dnll Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory 207-113-0 3 Address P.O.Box 196612 Stratigraphic ❑ Service 0 6.API Number Anchorage,AK 99519-6612 50-029-22478-02-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0047472 PBU X-20A 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 13569 feet Plugs measured None feet true vertical 9057 72 feet Junk measured None feet Effective Depth measured 13533 feet Packer measured See Attachment feet true vertical 9051.09 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 77 5 20"91 5#H-40 32 9-110.4 32.9-110 4 1490 470 Surface None None None None None None Intermediate 10925 62 7-5/8"29 7#NT-95 29 5-10955 12 29 5-8924.45 8180 5120 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11310-11340 feet 11416-11446 feet 11570-11600 feet 11710-11740 feet 13110-13500 feet True Vertical depth 9010 48-9011 75 feet 9015.53-9015 92 feet 9019 43-9021 62 feet 9031 29-9033 75 feet 9031 13-9045 65 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) A1C f EDTreatment descnptions including volumes used and final pressure: SCANNED MAY. 1 2 2015 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. 0 0 2943 480 1030 Subsequent to operation 0 0 2125 840 1470 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt. N/A Contact Garry Catron Email Garry.Catron(a.BP.Com Printed Name Garry Catron Title PDC PE Signature p Phone 564-4424 Date 4/29/2015 VTC. S-/& / �� RBDM& APR 2 9 2015 II Fo rn�10-404 Revised 10/2012 Submit Onginal Only 11 i i i Packers and SSV's Attachment ADL0047472 SW Name Type MD TVD Depscription X-20A PACKER 10674.98 _ 8763.46 4-1/2" Baker S-3 Perm Packer X-20A PACKER 10743.5 8805.15 4-1/2" Baker SABL-3 Packer X-20A PACKER 10805.44 _ 8841.84 5-1/2" Baker LT Packer X-20A PACKER 11024.75 8956.94 4-1/2" Baker KB Top Packer j m as TCNI 0) co 0 o � � � � � Oti C) OO ,sOO OaoM MM Ea co M co co Lo co M CO N- NOCOtoCA � CA co co O CO Co co co co CO co c N O Cf) CO O N Cn r CD 1.0 O r N CD N I- co oo O O N r- oc) Co co CO i+ CC) CA CA CA N- W OU) CDO) CDN N- E � CANO dao O M co O 0 Q u) L M �I` MMaoOCSDN r O r O C .— O Q < OiCCOOCOOCCOOCCOOCOO _ J J z J J J *k 4# 4# 4:k 0I CD '- COCOCO CO cn co ON N N 00 N N V N T C O CO co ti D co OD J W cc I— < Co• o V p IX c n u Z Z zwwwwmm p1- zzzDD O Z J J J I- I-- i Y ii k ii N - D U) co 0 (V O 2 () ai Q� V E 2 °- -c-Ni N co 't -O - a) m a)C Z _C 0_ J - d C 4.- Q 0 p a) ? o p I LT)` O O C U V d 4. o f O QO ¢ V (a C aT0 m- O 0 L -a 5 �- `� 't w - N u) 0 c o_ n -o c 0 $ Q-0 o0. a0 aui - Q Ts • 2 0- ad � O `o Jo -5 co � a � .a 0bt u) rn 3 D O- W O C a) Q 2 0 ,- O = o N d M 0 0 .- 3 II -) � d -§ o <- Q ,- 0 ooh OH oM com _c � � oto cc) ap) � o Q- N = ai a) U - 3 g n a) COo (l) US u) 3 U.-J 0 o - c o O m c N � o U) D L a) O j c o •FS o o v I oI- LI- (0 o (,' > 2Oz Q a) a m I- 03(n U ! ! LIii1 Nw * * O7 - Q i� .0 E U) (/) O LI -1 to d OO a) •a .c 0 0 IC) a) .- C O r o o d o cII O U o 0 o " ° o Q o Q - G1 .' Q L Q O - N Z U m 4) U C not Q o 0 0)0 `o co c`i o a O CD U �� o = oo ° oo 0 o C O O 2r o 0�0U , 00O u) Q� Q j LL (n > co N O Q o ° (`I 0 a) 3 o t co 0 t E C a) C c° C a w ,�= O Q�� m o o p CD_ L 1 O O * O -0 W -p "O F' #k , Q _ -p -0 rn LL d Q� -0 O o * -1 * — M 0 (0 a) (0 U o Q� m �t 2 O �+ an -0 ci M (° a) °�° J o N I- ai a c a) 03 o 0)ti oo a�U c a.) a) 0_ m I- -O i > O ; N 0 � 70 m a 5 Q W u- p N 0- ti d ti O O J u) to o 0 5 d J CO a TI) C 0 CU) C 0 0) c 0 co co J CO - N m - TREE= 4-1/16"CIW WELLHEAD= FMC X-201k GE 125 ppm WH O MI.WELL REQUIRESETV NOTES:H2S A READINGS WHEN ON • ACTUATOR= BAKER KB.ELEV= 68' I MI. WBL ANGLE>70°s 11057'. BF. ELEV= 42.0' KOP= 800' 20"CONDUCTOR 110' 2244' H4-1/2'HES X NP,D=3.813" Max Angle= 94°©12323' I Datum MD= 10851' D=? Datum W D= 8800'SS 10-3/4"CSG,45.5#,NT-80, - 3566' LFE-BTC,ID=9.950' Minimum ID =2.347" @ 11031' 10655' H4-1/2"HES x NP,D=3.813" 2-7/8" PUP JOINT 10676' H7-5/8"X 4-1/2"BKR S-3 FKR,D=3.870" ' 10700' H4-1/2"FES X NP,ID=3.813" 4-1/2"TBG,12.6#,L-80 TCL.0152 bpf,D=3.958" - 10721' U10730' H7-5/8"X 4-1/2'UNIQUE OVERSHOT 4-1/2"TBG STUB(TAGGED 10/13/07) -) 10727 10741' H7-5/8"x 4-1/2'BKR S-3 FKR,D=3.875" 10802' H4-1/2"OTs X NP,D=3.813" k, 10803' H7-5/8'X 6.345'TEBACK,D=5.75" 10813' H7-5/8"X 6.358'11W PKR,D=5.75" 4-1/2"TBG,12.6#,L-80 NSCT,.0152 bpf,D=3.958' H 10814' 1-- 10814' H4-1/2'WLEG,D=3.958" 10818' HELM)TT LOG XX/XX/XX 10821' H7-5/8"X 6.686'TW DTH HY D HGR,D=4.99" 7-5/8'CSG,29.7#,NT-95 NSCC,D=6.875" H 10952' -4 10826' -5-1/2'X 4-1/2"XO,D=3.91' 4 11026' -14-1/2"KB LIP,D=2.560" 2-7/8'LNR,6.16#,L-80 STL,.0058 bpf,D=2.441" -I 11055' , 11031' H2-7/8"STL PUP JT,D=2.347" ESTIMATED TOP OF CEMENT H 11056' i 11057' H3.70"BTT LNR DEPLOY SLV,D=3.00" i 4 11063' H3-1/2"STL PIN,D=2.896' r-I 11066' --3-1/2"X NP,D=2.813" 7 • 3-1/2"LNR,8.81#,L-80 STL,.0087 bpi,D=2.990" H 11099' • .� �� 11099' 3-1/2"X 3-3/16"XO,D=2.786" i ►• ML.LOUT VVPDOW(X-20A) 11265-11274' 4-1/2" PSTOO<(10/19/07) -I 11265' 7.7 YVH • PERFORATION SUMMARY • �i'e•i4- REF LOG: GR/CCL ON 10/26/07Oi•i• •�•�•�•4 11643' 1-3-3/16"X 2-7/8"XO, ANGLE AT TOP PERF: 87°©13110' ••••.•• 1 D=2.441" Note:Refer to Production DB for historical pert data ,��.� SIZE SPF MEJWAL Opn/Sqz SHOT SO7 2" 6 13110-13500 O 10/27/07 3-3/16"LNR,6.2",L-80 TCS, H 11643' 2" 6 11310-11340 O 04/03/15 .0076 bpf,N3=2.80" 2' 6 11416-11446 0 04/03/15 PBTD 13511' iii• . 1. 2" 6 11570-11600 0 04/02/15 A•O-..o. 2" 6 11710- 11740 0 04/02/15 2-7/8"LNR,6.16",L-80 STL,.0058 bpf,D=2.441" -I 13569' ' DATE REV BY COMU(TS DATE REV BY COMMENTS FRUDHOE BAY UP(T 06/23/94 N18E ORIGINAL COMPLETION 04/03/15 JGU PJC ADPERFS WELL: X-20A 10/29/07 NORDIC 2 RWO&CTD SDTRCK(X-20A) PERMT Pb:"2071130 05/12/08 ?/PJC DRLG DRAFT CORRECTIONS AR No: 50-029-22478-02 06/04/08 GJS/PJC DRLG DRAFT CORRECTIONS SEC 5,T1ON,R14E,349'FSL&103'FWL 11/17/10 JC MN D CORRECTION 02/16/11 M3411.43 ADDED SSSV SAFETY NOTE I :, BP Exploration(Alaska) -_ 111 I i i • Image Project Well Histary File hover 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. ty~ Q ~ - ~ ~ ~ .Well History File Identifier Organizing (done) RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: o,.os,~a iiiuiimumuu DIG TAL DATA Diskettes, No. ^ Other, No/Type: ., Re=~a~»e~e, iuuim~iiiiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY: Maria Date: ~ ~ ^ Other:: /s/ Project Proofing III II'lII VIII II III. BY: Maria Date: / ~- ~ S ~ !s! Scanning Preparation ~ x 30 = + =TOTAL PAGES lU ^ (Count does not include cover sheet) BY: Maria Date: ~ ~,, I ~ ~ ~ ~ /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does inciude cover sheet) Page Count Matches Number in Scanning Prep ration: _~ES NO BY: Maria Date: ~~ ,~~ Vg /s/ J 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. II I II ~I II I II II I I III ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIII~I III II'I I 10!6/2005 Well History File Cover Page.doc • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 02, 2012 TO: Jim Regg et? SUBJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) INC X -20A FROM: Jeff Jones PRUDHOE BAY UNIT X -20A Petroleum Inspector Src: Inspector Reviewed Bnn P.I. Suprv�rJ�' NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT X -20A API Well Number: 50- 029 - 22478 -02 -00 Inspector Name: Jeff Jones Insp Num: mitJJ120302135854 Permit Number: 207 - 113 - Inspection Date: 2/11/2012 Rd Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well X -20A ' Type Inj. W " TVD 8764 ' IA 488 2580 - 2551 2548 PTD 2071130 ' TypeTest SPT Test psi 2191 OA 162 168 168 169 Interva 4YRTST P/F P Tubing 1517 1518 - 1516 1518 - Notes: 1 well inspected, no exceptions noted. t 1 tti Ir!' MAR ere. Friday, March 02, 2012 Page 1 of 1 !i II I I ~~ h~ ",~.. '` - _. ~, MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER. THIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc C;UMYAN Y WELL NAME FIELD . ~` B4KER Muc~~s Baker Atlas PRINT DISTRIBUTION LI5T BY EXYLUKA'I'lUN (ALASKA) INC CUUN't'Y NUR"1'H SLUPE BUKUUGH X-20A STATE ALASKA PRUDHOE BAY UNIT DATE 2/11/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tttminello SO #: 1626273 Copies of Copia Digi[al Copia of Copia Digital Each Log of Fihn Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR - DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIItKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBII. PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE, AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: ~~c.~ v~ ~ aa~--(r3 I~ Page 1 of 1 ! r Sent by: Terri Tumine to Date: 02/11/2009 ~. - ' °- Received by: Date: - r ' -~ INTEQ Log ~ Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: X-20A 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 - GR Directional TVD Log (to follow) LAC Job#: 1626273 i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 lIIIBMES ~tvi~~ Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 2b7-6612 FAX: (907) 267-6623 v_e 2d~--~ i3 l~ 5~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071130 Well Name/No. PRUDHOE BAY UNIT X-20A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22478-02-00 MD 13569 TVD 9058 Completion Date 10/29/2007 Completion Status WAGIN Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No Sample Interval Set Start Stop Sent Received Number Comments Directional Survey Y~) ~ DATA INFORMATION Types Electric or Other Log s Run: MWD, DIR, GR, RES, GR, CCL Well Log Information: Log/ Electr Data Digital Dataset T e Med/Frmt Number Name D Asc Directional Survey /Rpt Directional Survey ED C Las 15914 Induction/Resistivity C Li 16027 R G s amma ay Samples No (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop OH / CH Received Comments 11245 13569 Open 11/21/2007 11245 13569 Open 11/21/2007 10990 13568 Open 1/24/2008 LAS ATR, RPM, GR, RAM, ROP, RPD in PDF graphics 10423 13424 Open 3/13/2008 LIS Veri, GR Well Cores/Samples Information: Name ADDITIONAL INFORM/}T~ON Well Cored? Y/~) Chips Received? ~~ Analysis Y / N Received? Comments: Compliance Reviewed By: Daily History Received? ~=~' N Formation Tops ~N Date: --_. _. • MEMORANDUM To: Jim Regg P.I. Supervisor ,~~~~~ ~~~~~~~' FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 07, 2008 StiBJECT: Mechanical Integrity 1-ests BP EXPLORATION (ALASKA) INC X-20A PRUDHOE BAY UNIT X-20A Src: Inspector NON-CONFIDENTIAL, Reviewed By: P.I. Suprv ,`J~ =- Comm Well Name: PRUDHOE BAY UNIT X-20A API Well Number: 50-029-22478-02-00 Inspector Name: Bob Noble Insp Num: mitRCN080305080950 Permit Number: 207-113-0 Inspection Date: 3/2/2008 Rel Insp Num: Packer - - - Depth Pretest Initial 15 Min. 30 NIin. 45 Min. 60 Min. -- - Well x-zoo, !Type Inj. j w TVD r-- ~ s7~4 ; IA ~ ~500 7~0 -- 2490 0~---~ p T ao~I Iso iTypeTest SPT !Test psi ~ zsoo A ~ -- 4zo ~, 600 ~ ~ ~ 600 ~ 600 Interval [NIraL p~F P ~ Tubing' I6oo X600 ~ I6oo I two Notes: Friday, March 07, 2008 Page 1 of i 03/06/08 ~~~~~~~ NO.4621 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay,Pt.Mac,Milne Pt,Orion,Lisburne ~n~..u ~..H ~ 1 .,., rlncnrir.fGnn naip RI Cnlnr Cn C-41A 12021141 MEM LDL 02/25/08 1 1 MPS-01A 11970714 SCMT ~} _ C 02/21/08 1 1 P1-06 11975757 PROD PROFILE ~ 03/02/08 1 1 P1-OS 11998992 PROD PROFILE ~ 02/29/08 1 1 Pi-06 11975757 SCMT /~ ~ ~ 03/02/08 1 1 09-23A 12045070 USIT ~ - C ~ 03/02/08 1 1 L5-34 12057596 PROD PROFILE S 02/28/08 1 1 W-40 11970816 PRODUCTION LOG _j 03/04/08 1 1 15-046 12005202 MCNL Q - t~ C 12/28/07 1 1 C-35B 12021139 MCNL ~ 01/26/08 1 1 X-20A 11661178 CH EDIT PDC GR (MEM CORRELATION) _i 10/26/07 ate- 1 L-219 12017479 CH EDIT PDC GR (IBC) - C !CD 01/02/08 1 YLtASt AGKNOWLtI)(at HtGtIF' I tl:Y,SIIiNIFVCd ANL.~ Yit I;UF[hVIN(a VNt GVYY tAI:H I U: BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. i i~i~+ r ~~ Anchorage, Alaska 99508 x~ .I ~ r ~~~~i~ Date Delivered: , r; ,,,i~a~,pn= Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • (3 by Date 01-24-2008 Transmittal Number:92926 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Contents ~a~-- lad ~ I ~,lv 08A JOB-- !Ug ~ t59lt~ 14A a(~`~rtDa ~(5"i/8 NGI-13A tJ~CaO~-- (!~( ~ l 5S(~ X-20A iJS (° 20'x- - t t 3 ~' S`'3 l Y Please Sil;n and Return one copy of this transmittal. Thank Yc-u, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 y~ ~~ ._ 7 ~ a ~ ~~ ~~~st~~ Vii! ~ Gas C~n~. ~~~rrta~~;~ia~? Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 __ STATE OF ALASKA ~~7 ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION D~~ ~ 4 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 2007 A(aslca tli4 ~ ~~ i~anc_ t'nmmcr~~,,.. 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1 b. WeII CIS; ~Or ^ Developmen~~~ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 10/29/2007 12. Permit to Drill Number 207-113 " 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 10/20/2007' 13. API Number S0-029-22478-02-00 " 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 10/24!2007 ~ 14. Well Name and Number: X-20A 349 FSL, 103 FWL, SEC. 05, T10N, R14E, UM Top of Productive Horizon: 1146' FSL, 1128' FWL, SEC. 07, T10N, R14E, UM 8. KB (ft above MSL): 68" Ground (ft MSL): 38.1' 15. Field /Pool(s): f Prudhoe Bay Field / Prudhoe Bay Total Depth: 1133' FSL, 4270' FWL, SEC. 12, T10N, R13E, UM 9. Plug Back Depth (MD+TVD) 13533' 9051 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 665978 y- 5940480 Zone- ASP4 10. Total Depth (MD+TVD) 13569' 9058 16. Property Designation: ~~~~ ADL~494483 TPI: x- 662063 y- 5935912 Zone- ASP4 Total Depth: x- 659926 y- 5935853 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed info mation per 20 AA 25.071): MWD, DIR, GR ,RES, GR, CCL ~//I~dO/~/~ !!o?65iyD (,~ ~ j'y~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE /+ 4EMENTfNG RECORD PULLED 20" 91.5# H-40 30' 110' 30' 110' 30" 260 sx Arctic Set A rox. 10-3l4" 45.5# NT-80 30' 3566' 30' 3149' 13-1/2" 1150 sx Coldset III 350 sx Class'G' 7- / " 2 .7# NT95HS 27' 1 52' 27' 892 ' 9-7/8" 265 sx Class 'G' 4-1/2" 12.6# L-80 / 13Cr 10821' 112 8851' 9008' 6-3/4" 320 sx Class 'G' s-~iz° x 3-3116" x z-~ra° s.za ~ s.2#, s.~sa L-80 11026' 13569' 8957 9058' 4-1l8" 137 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24.- TU81NG RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter 6 SPF 4-1/2", 12.6#, L-80 10814' 10676' & 10741' , MD TVD MD TVD 13110' - 13500' 9031' - 9046' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 2000' Freeze Protected with 30 Bbls Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. CaSing PreSS: CALCULATED 24-HOUR RATE.• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photo~gra hsQ d lta}}borrratyory analyytical results per 20 AAC 250.071. _. &~~ L1FS, L' ~ ~~OI _ ~ U~~ p None ~~ ~~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS ' NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. (From Parent Wellbore) None Sadlerochit 11259' 9008' Formation at Total Depth (Name): Sadlerochit 11259' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr Stewman Title Drilling Technologist Date ~ - 3" ~~ X-20A 207-113 Prepared By NameMumber.~ Sondra Stewman, 564-4750 Well Number Drilling Engineer: Greg Sarber, 564-4330 Permit No. / A royal No. INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only TREE = 4" CNV 5M WELLHEAD= FMC ACTUATOR = BAKER KB. ELEV = 68.8' BF. ELEV = 42.0' KOP = 800' Max Angle = 92 @ 11594' Datum MD = 10852' Datum ND = 8800' SS DRLG DRAFT II 10-3/4" CSG, 45.5#, NT-80, LHE-BTC, D = 9.953" ~ Chemical Cut Tubing @ 10,710' ~4-1/2" TBG, 12.6#, L-80, .0152bpf, D = 3.958" ~~ 10814' ~ 5-1/2" X 4-1/2" XO , ID= 3.91" 10826 7-5/8" CSG, 29.7", NT 95, NSCC, ID = 6.875" 10952 11056' Top cr 11056' 3 5.. :, [, 11066` PERFORATION SUMMARY REF LOG: MWD/GR 06/10/94 ANGLE AT TOP PERF: 86 @ 11284' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2-3/4" 6 11284 -11304 ,r >oc- 3-3/8" 6 11395 -11435 ~ .,oc 2-3/4" 6 11488 -11508 ~scdaed propos 2" 6 13110-13500 Open 10/27/07 I4-1/2" X 6-3/4" CTC (ECP), ID = 3.980" ~~ 12037' ~- 4-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, D= 3.958" 1217'. TOP OF 4-1/2" SLTD LNR 12177 I~~I 13-CR-80 NSCT, .0152 bpf, D = 3.953" DATE REV BY COMMENTS DATE REV BY COMMENTS 06122/94 MDO ORIGINAL HORZ COMPLETION 01/23/04 SRB/KK CORRECTIONS 04/19/06 RPHJPJC WANER SAFETY NOTE 12/16/06 JRP/PJC PULL IBP @ 10743' & FISH (E1ENiENTS) 10130/07 NORDIC2 CTD SIDETRACK (X-20A) 11/03/07 lTLH CORRECTIONS PRUDHOE BAY UNff WELL: X-20 PERMff No: 1940607 API No: 50-029-22478-70 SEC 7, T10N, R14E BP Exploration (Alaska) X-20A I SA~f~Ta: Q ~~ 2,244' - 4-1/2" HEX X Nipple, L-80, 3.813" ID -10655' - 4-1/2" HES X Nipple, L-80, 3.813" ID 10676' - 7-5/8" x 4-1/2" Baker S3 Packer -10700' - 4-1/2" HES X Nipple, L-80, 3.813" ID - 7-518" x 4-1 /2" Unique Machine Overshot 10741' 7-5/8" x 4-1/2" BKR SABL-3 PKR, D = 3.875" 10802 4-1/2" OTIS X NIP, ID = 3.813" 10803 TOP OF TIEBACK SLV, ID = 6.358" 4r1St~Z' 7_5/R" TIVV NAN(:FR PKR r. .....-...-....... ... r 10814' 4-1/2" WLEG, ID = 3.958" 10821' 5-1/2" X 7-5/8" TMJ HYD HANGER 10820' ~~nno rr From Pic dog 11026' 4 5" KB Packer 4" GS FN 11643' 3-3/16 x 2-7/8 X-over 3-3/16" X 2-7/8" cmt'ed and perfed~ 13569' 11270' Mechanical Whipstock 11298' Cement Retainer BP EXPLORATION Page 1 of 15 Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date.: From - To Hours Task Code NPT Phase Description of Operations 10/10/2007 18:00 - 00:00 6.00 MOB P PRE Move rig from X-30 to X-20. Spot herculite. Spot BOPs behind 10/11/2007 100:00 - 01:30 ( 1.501 MOB I P 01:30 - 06:00 I 4.501 MOB I P 06:00 - 13:30 I 7.50) MOB I P 13:30 - 13:45 I 0.251 MOB I P 13:45 - 18:00 I 4.251 MOB I P 18:00 - 18:30 I 0.501 MOB I P 18:30 - 19:30 I 1.001 MOB P 19:30 - 00:00 4.50 MOB P 110/12/2007 100:00 - 04:30 I 4.501 MOB I P 04:30 - 08:30 4.00 BOPSU P 08:30 - 09:30 1.00 RIGU P 09:30 - 12:30 3.00 PULL P 12:30 - 01:30 13.00 PULL P 01:30 - 16:30 I 15.001 PULL I P 16:30 - 18:00 I 1.501 PULL I P 18:00 - 00:00 I 6.001 PULL I P 110/13/2007 106:00 - 06:45 I 0.0751 PULL I P 06:45 - 09:30 I 2.751 DHB I P 09:30 - 11:00 ( 1.501 DHB I P wellhead. Lay rig mats around wellhead. PRE Adjust rig mats. Spot and center rig over well head. Level rig. Set down. Accept rig at 0130 hrs. PRE Spot and run hardline to tiger tank. Spot cuttings box. Berm cellar area. Rig up in cellar to circulate through tree. Take on KCL water in pits. PRE RU Valve Crew and pull BPV. PT surface lines to 3500 psi. Circulated 60 bbl down the IA and then switch to pumping down the tubing at 4.00 with 2% KCL and SafeSurf. Checked flow, well underbalance. Circulated 4862 strokes and well is balanced. Install TWC as per BP RWO programme, SOP's and policy. PT below the TWC to 500 psi, (OK). PRE Held PJSM on ND tree. Review the procedure and delegated the work force in handling the tree PRE ND tree in 3 pieces. Working to check the threads on the NSCT hanger. Requires a extended neck crossover. PRE Crew change. Make rounds on rig. Hold PJSM to discuss testing landing/test joint rig up. PRE MU extended 4-1/2" NSCT XO on landing joint. Engage in tubing hanger. PRE Trolley in BOPS. Lift with bridge crane. MU to tbg head. MU kill and choke lines. NU shooting flange and lubricator. PRE Continue to NU 13-5/8" BOPs. NU shooting flange and lubricator. Get high pressure body test on BOPs. Call AOGCC. Witness waived by J. Crisp. PRE Pressure test BOP equipment as per SOPs and Permit to Drill. DECOMP RU and pull TWC as per SOP's DECOMP Held PJSM on ND shooting flange and installing riser. DECOMP Make ready to pull 4-1/2" completion FMC backed LDS out 4-3/4" DECOMP PU on tubing at 120k, picked up out of tubing spool. Pulled heavy up to 130ik. PU 5 ft and circulated bottoms up. No gas or solids was seen at the shaker. PUH and string wt constant at 120k. Fluid level in hole remaining constant. Pulled hanger to surface and rig down same. LD landing joint. RU to pull tubing and control line. Control line looks good at surface. RU trip tank and make ready to pull and lay down 4-1/2" completion. DECOMP POOH (117k constant) and laying down tubing at 1:1 with control lines. Some of the pipe is getting crushed while trying to break it out. The threads looked over torqued and pulled. DECOMP Crew change. Continue to pull pipe. Connections are breaking out easier. 56 jts pulled. LD SSSV. DECOMP Continue to pull 4-1/2" completion. 155 jts layed down DECOMP Crew change, PJSM and conduct walk around with spill champion. DECOMP RU HES 7-5/8" RTTS packer with valve, 3 jts 3-1/2" DP. Install RTTS at 60 ft below GL PT to 1000 psi. Bleed OA down to 0 psi and monitor. DECOMP RU to pull pack-off and bleed down OA in preparation of pulling Printed: 11/12/2007 4:36:07 PM BP EXPLORATION Page 2 of 15 Qperations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date: From - To Hours Task Code NPT Phase Description of Operations 10/13/2007 09:30 - 11:00 1.50 DHB P DECOMP packoff 11:00 - 12:00 1.00 DHB P DECOMP RU and pulled RTTS out of hole. OA still spitting gas to surface. 12:00 - 13:30 1.50 CASE P DECOMP POOH laying down 4-1/2" tubing. 4-1/2" collars are starting to have corrosion caused by electrolysis where the collar is laying next to the 7-5/8" casing.The tubes look good and the threads that are not over torqued are in good shape. Area of concern is the surface of the 5" collar about 3" in width along the length of the collar. Checked the OA pressure and its finally dead. Monitored OA while POOH laying down tubing Lay down a total of 175 jts, 79 jts to go. OA is dead. 13:30 - 17:30 4.00 BOPSU P DECOMP Hand to change collars out in the hole. Made up XO and RTTS with 3 jts of 3-1 /2" DP and RIH and set at 65 ft below grown level. Set RTTS and PT top at 1000 psi. Change out packoff without incident, RILDS and PT to 5000 psi. RIH and pull RTTS out of hole, LD 3 jts of 3-1/2" DP RD HES equipment off the rig floor. 17:30 - 22:30 5.00 PULL P DECOMP Continue to POOH laying down 4-1/2" completion. External corrosion lessend with depth. Cut joint section was 21.45' in length. The chemical cut was good with a slight flare, and a max OD of 4.625". 22:30 - 23:45 1.25 PULL P DECOMP Remove all used tubulars from pipe shed. Joints 137, 143, 144, 148, 173, 174, 188, 189, 206, and 207 were marked with white joint numbers on red paint on each end of joint. 23:45 - 00:00 0.25 EVAL P DECOMP Hold PJSM with SLB slickline crew. Review job scope, hazards, handling procedures. Also discuss rigging up unit to allow simops loading of pipe shed. 10/14/2007 00:00 - 03:30 3.50 EVAL P DECOMP Continue to run 6.65" GR/JB on SLB slickline. Tag tbg stub at 10,722' SL depth (ELM of stub was 10,710'). POOH. Junk basket basically empty of junk. Hole should be clean. Begin to load pipe shed with 4-1/2" TCII tbg. 03:30 - 10:00 6.50 EVAL P DECOMP Run 6" od lead impression block on slickline. Tag at 10,722'. POOH. Round, shallow impression. RIH with 3.8" TS. Ran through stump without any restriction at the top. Tagged the top of the Fast Plug at 10,765 ft. Reran the 6.65" LIB and seen the same small inprint. Continue to load pipe shed. 10:00 - 10:30 0.50 EVAL P DECOMP RD Wireline 10:30 - 16:30 6.00 RUNCO RUNCMP Load Pipe shed and RU to run tubing. Cut Drilling Line, RU Doyon Casing Torque Turn. 16:30 - 17:00 0.50 RUNCO RUNCMP PJSM on PU and handling completion tubulars and jewelry 17:00 - 18:00 1.00 RUNCO RUNCMP Running 4-1/2" Completion 18:00 - 18:30 0.50 RUNCO RUNCMP Crew change. Change out and make rig rounds. 18:30 - 00:00 5.50 RUNCO RUNCMP Continue to run 4-1/2" completion. 79 jts of 260 as of midnight. 10/15/2007 00:00 - 13:30 13.50 RUNCO RUNCMP Continue to run 4-1 /2" completion. 185 jts in the hole at crew change. RIH with 262 jts of 4-1/2" 12.6#/ft L-80 TC II tubing and stabbed 4 ft over stump. Shear pins at 10k and stack out 3' later. Spaced out using 1-5.79" 4-1/2" Pup Joint. Bottom of ', Overshot at 10,730 ft. Ran a total of 260 jts of 4-1/2" 12.6#/ft L-801 TCII tubing using torque turn. RD Doyon Casing and clean rig floor Printed: 11/12/2007 4:36:07 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date- ' `From - To 10/15/2007 13:30 - 14:30 14:30 - 14:45 14:45 - 21:00 X-20 X-20 Spud Date: 5/13/1994 REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Hours Task Coc 1.00 RUNCO 0.25 RUNCO 6.251 RU i 21:00 - 23:00 2.00 RU 23:00 - 00:00 1.00 RU 10/16/2007 00:00 - 02:00 2.00 RU BP EXPLORATION Page3of15~ Operations Summary Report 02:00 - 02:45 0.75 RU 02:45 - 04:00 1.25 RU Rig Release: Rig Number: NPT Phase Description of Operations RUNCMP RILDS. Changed out to shorter landing joint for slickline work. RUNCMP Held PJSM on RU Wireline for drifting the stump and setting RHC plug RUNCMP RU to run 3.80" drift to confirm the Ran 3.8" TS and tagged at 10, 755 ft. No issues with the top of the 4-1 /2" stump. RIH with RHC plug and set in X Nipple at 10, 700 ft. Rig down SLB slickline. RUNCMP Hold PJSM with crew and crane operator. Spot and rig up crane. Lift spoolling unit, 3 reels, and several large boxes of thread protectors from rig to ground level. Rig down crane and move materials to edge of pad. RUNCMP Hold PJSM with Baker and crews. Displace IA to inhibited KCL water. Pump 290 bbls. Pump 65 bbls diesel to freeze protect IA. RUNCMP Continue to displace IA to inhibited KCL water at 3.0 bpm and 1200 psi. RUNCMP Freeze protect IA with 65 bbls of diesel. 2.0 bpm at 875 psi. RUNCMP Drop rod and ball assembly. Pressure tubing to 3500 psi to set packer. Pressure tubing to 4000 asi. Chart for 30 minutes. No bleed 04:00 - 04:45 0.75 RUNCO RUNCMP Re-configure chart recorder. Bleed tbg to 1500 psi. Pressure IA to 3500 si. Record on chart. Bleed off IA and tbg. 04:45 - 06:50 2.08 BOPSU P RUNCMP Remove landing joint. Drain BOP stack. Set two way check in hanger. 06:50 - 11:00 4.17 BOPSU P RUNCMP ND BOP' 11:00 - 17:00 6.00 WHSUR P RUNCMP Installed tree adaptor and pressure test to 5000 psi NU tree and PT to 5000 psi 17:00 - 17:30 0.50 RIGD P RUNCMP Prep to move rig off well 17:30 - 17:45 0.25 RIGD P RUNCMP PJSM-move rig off well 17:45 - 20:00 2.25 RIGD P RUNCMP Back rig off well. Remove used tree pieces. Set 7-1/16" BOPE on cellar mats and hoist w/ blocks Use VECO crane to remove 13-5/8" BOPE and set on moving skid and move to side of Pad Move rig back over well and set down 20:00 - 00:00 4.00 BOPSU P RUNCMP NU 7-1/16" BOPE MI VECO lowboy and load used 2-3/8" E-CT reel #14373 into reelhouse. RU hardline 10/17/2007 00:00- 02:30 2.50 BOPSU P RUNCMP Fin NU ROPE Fln prep E-CT reel and hardline 02:30 - 03:30 1.00 BOPSU N RUNCMP Body test/chase leaks 03:30 - 09:50 6.33 BOPSU P RUNCMP Test BOPE. AOGCC waived their right to witness the test 09:50 - 10:05 0.25 BOPSU P RUNCMP PJSM for pulling TWC 10:05 - 11:00 0.92 WHSUR P RUNCMP PU lubricator and tools, Stab on well and test to 500 psi, Pull TWC, RD tools and lubricator. 11:00 - 11:15 0.25 FISH P RUNCMP PJSM for RU slickline and pulling ball & rod and RHC plug 11:15 - 12:35 1.33 FISH P RUNCMP Spot slickline unit. New SL crew so take time to lead through the RU. Lift tools to floor. RU SL tools. 12:35 - 16:00 3.42 FISH P RUNCMP Pull ball and rod then RHC plug. 16:00 - 16:15 0.25 RIGU P WEXIT PJSM for stabbing packoff, lifting the injector and stabbing coil. 16:15 - 18:00 1.75 RIGU P WEXIT Stab packoff, lift injector. After minor problems with the winch the coil anchor was pull tested. Pull the coil across the rig and stabbed into the injector. Printed: 11/12/2007 4:36:07 PM f BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code :NPT Phase Description of Operations 10/17/2007 18:00 - 20:45 2.75 RIGU N WEXIT Meg test line and line tests okay. Find problem at collector and need SWS ET 20:45 - 21:00 0.25 RIGU N WEXIT Safety mtg re: fill CT and pump slack 21:00 - 21:50 0.83 CLEAN P WEXIT Stab onto well. Reverse circ CT full w/ 2% KCI/2 ppb biozan 1.75/245 at start and 1.75/1300 after 60 bbls. Incr rate to 4.4/3900 and pump slack back. Had 2.5% slack in reel before pumping slack back 21:50 - 22:30 0.67 BOPSU P WEXIT Pressure test inner reel valve and packoff 200/3500 as part of BOPE test 22:30 - 22:40 0.17 CLEAN P WEXIT Safety mtg re: cut CT 22:40 - 00:00 1.33 CLEAN P WEXIT RU hyd cutter and cut 17' and find wire. Dress end of CT and install CTC SWS electrician fix short in collector 10/18/2007 00:00 - 02:00 2.00 CLEAN P WEXIT Begin Cement/Ball Pumping Test Thru E-CT Fin install CTC and SWS a-line anchor sub according to SWS procedure. PT 35k. PT to 3100 psi and lower set screw leaked. Replace O-ring and add thread sealant to gap between set screws. PT to 4000 psi. Ball drop is 180 deg out of optimal. Have trouble loading ball due to no way to move pipe in/out 02:00 - 03:45 1.75 CLEAN P WEXIT Load 5/8" steel ball and displace 2.1/1700 w/ 2% KCI w/ 2 ppb biozan to ball catcher while take returns to bung hole. CTV talc 57.5 bbls. Ball left launch port, but did not arrive at catcher at talc volume + 2.5 additional bbls. Incr rate to 3.3/2700 and hear ball rolling and pump additional 52 bbls and ball went on seat. Reload same 5/8" steel ball. Launch ball and pump 2.5/2300. Hear ball quit at -30.1 bbls. Incr rate to 3.25/2800 and got ball rolling so gradually slow to 3.0 bpm where ball quit again. Incr rate thru remainder of job to 3.25/2820 to keep ball rolling. Ball seated at 66.5 bbls. Recover ball. RD catcher. RU/PT floor lines to take cement returns from CT to open top tank 03:45 - 04:00 0.25 CLEAN P WEXIT Safety mtg re: pump cement 04:00 - 04:45 0.75 CLEAN P WEXIT SWS cementers batch up cement 04:45 - 05:10 0.42 CLEAN P WEXIT SWS pump 5 bbls KCI to CT. PT @ 4000 psi. Load CT w/ 27.1 bbls 15.8#'G' cement w/ latex and retarder at 2.0/1600 @ 82F while taking bio returns to open top tank 05:10 - 05:40 0.50 CLEAN P WEXIT Rig displace cement at 2.6/4000 w/ 2% KCI w/ 2 ppb biozan. Rate/press with cement at end of CT 2.60/4030, w/ 15 bbls in tank 3.0/3780 and start hearing slack move forward occasionallly, with all cement in tank 4.0/3300. Pump additional 15 bbls to clear lines and FCP 4.0/3180 05:40 - 06:40 1.00 CLEAN P WEXIT RD floor lines to open top tank. RU ball catcher and circ CT over bung hole at min rate RD SWS cementers, blow down line to the open top tank. 06:40 - 09:00 2.33 CLEAN P WEXIT Load 5/8" steel ball to reel a circulate at 2.5 bpm. Can hear the ball moving, will keep someone in the reel house to ensure it keeps moving. Ball stopped somewhere between 15 and 30 bbls. Bump rate up to 3.0 bpm and still no ball movement. Bump rate up to 3.5 bpm and still no ball movement. RU to reverse then pump 5 bbl / 3.5 bpm. Pump forward and heard ball but it stopped after 5 bbl. Try the reverse trick again same results. Drop rate to zero then pump and hear the ball move Printed: 11/12/2007 4:36:07 PM BP EXPLORATION Page 5 of 15 Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/18/2007 06:40 - 09:00 2.33 CLEAN P WEXIT just a little. Keep pumping at 3.4 bpm with no ball movement for 30 bbl. Check ball catcher sub and did not find ball. 09:00 - 09:30 0.50 CLEAN N WEXIT Wait on BOT to bring out Circ sub and DFCV 09:00 - 09:15 0.25 CLEAN P WEXIT PJSM: MU BHA and line up to tiger tank 09:15 - 10:00 0.75 CLEAN P WEXIT MU DFCV, Circ sub (5/8" seat), and nozzle to the anchored e-line sub. 10:00 - 12:00 2.00 CLEAN P WEXIT RIH pumping at min rate taking completion fluid to the tiger tank. At 1000' bring rate up to 2.5 bpm and still no audible ball movement. Continue in hole at min rate to the Fas drill plug. Tag at 10786.4 CTMD. Correct to 10775'. 12:00 - 12:20 0.33 CLEAN P WEXIT PU to 10750'. Pump at 2.5 bpm / 1860 psi. No sounds of ball movement in reel house. Given the volumes the ball stopped moving it should be off the reel. Saw a pressure spike after pumping 31 bbls. 12:20 - 15:00 2.67 CLEAN P WEXIT POH while displacing completion fluid to the tiger tank. Dirty, Dirty, Dirty completion fluid, lots of solids coming out. Finally cleaned up after -300 bbls. PJSM: for LD BHA, testing eline, and cutting coil while coming out of the hole. 15:00 - 15:40 0.67 CLEAN P WEXIT LD nozzle, Circ sub (w/ ball on seat), DFCV and anchor sub. Meg and continuity test was good. Cut off CTC then 50' of coil and cable. No kinks, birdnest, or damage to the cable. 15:40 - 19:20 3.67 CLEAN C WEXIT MU CTC and pull test to 35k. MU BHI tools and test. Open valves in reel house and flush w/ biozan. Displace CT volume thru bypass Bring BTT milling and WS tools to floor and put in pipeshed Offload additional 290 bbls 2% KCI w/ 2 ppb biozan into pits End Cementing Test 19:20 - 20:15 0.92 CLEAN C WEXIT MU BOT up/down jars, 1 jts of PH6, 2-7/8" motor, and 3.70" 5 blade junk mill on BHI MWD assy w/ DGS 20:15 - 22:30 2.25 CLEAN C WEXIT RIH w/ BHA #2 Circ thru mill 0.5/1000. RIH 22k and tag at 10789' CTD at min rate. PUH 52k Start pump 2.3/2360 PVT 171 /431 22:30 - 23:00 0.50 CLEAN C WEXIT Ease in hole 0.1'/ 2 min from 10787.4' and had a little MW at 10788.4'. Lost circ (2 bbls), then regained nearly full returns 2.32/2.0/2330. Ease in hole then had two stalls. PUH clean at 52k. Resume pump and ease back down to MW at 10788.35'. Drill Fas-Dril plug 2.32/2.10/2400 w/ 9.46 ECD w/ <50 psi MW in 5 min. Appears to be gone by 10789.0' 23:00 - 23:30 0.50 CLEAN C WEXIT RIH 17.8k slowly from 10789.5' w/ no wob while circ 2.32/2.14/2330. Had 100 psi incr in CTP at 10845'. PUH was clean so assume plugged a jet 2.32/2.20/2450. Continue RIH 15-20'/min while circ. Lost wt and had MW at 11302.0' CTD. SD pump, PUH clean. Retag at min rate 23:30 - 23:45 0.25 CLEAN C WEXIT Wiper up hole to 11050' was clean. Bottoms up had no gas in retums PVT 421 23:45 - 00:00 0.25 CLEAN C WEXIT Log tie-in down from 11050' 0.42/0.35/900 10/19/2007 00:00 - 01:00 1.00 CLEAN C WEXIT Continue log tie-in down to 11222'. Corr -4' 01:00 - 01:10 0.17 CLEAN C WEXIT RIH and retag TD at 11298'-plenty of room for WS 01:10 - 01:30 0.33 CLEAN C WEXIT POH circ 1.5/1600 w/ 53k. Pull tite to 65k and had MW at 10350'. RBIH, then 'out' MM started plugging off. Incr rate to 2.5/2520 and PUH slow thru 10350' w/ no problem. Blow Printetl: 11/12/2007 4:36:07 PM • n BP EXPLORATION Page 6 of 15 Qperations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours ?ask Code NPT Phase Description of Operations 10/19/2007 01:10 - 01:30 0.33 CLEAN C WEXIT unknown debris out of MM and WHP returned to normal 01:30 - 03:30 2.00 CLEAN C WEXIT Resume POH 2.5/2500 w/ +/-5k higher than normal string wt of 51k 03:30 - 04:20 0.83 CLEAN C WEXIT LD milling assy. Mill had no wear Purge hyd oil from weight cell and lost 6k weight 04:20 - 07:20 3.00 STWHIP P WEXIT MU BHA#3 BTT 4-1/2" monobore WS assy with 2 RA tags. 07:20 - 09:20 2.00 STWHIP P WEXIT RIH with Whipstock and setting assembly. EDC open and pumping at min rate. Set 2k down at 10828'. PU and run past with no problem. 09:20 - 09:40 0.33 STWHIP P WEXIT Log GR tie-in from 11140' to 11200'. Corr -3' 09:40 - 10:00 0.33 STWHIP P WEXIT Put TOWS at 11265' Highside trayface. Close EDC pressure up to 4000 psi and set WS. Set 4k on WS to verify no movement. 10:00 - 12:20 2.33 STWHIP P WEXIT POH to BHA pumping at 1.5 bpm. Lost 5 bbls on the trip out. IAP: 271 OAP:228 PJSM while POOH for LD BHA and PU milling assembly. 12:20 - 14:00 1.67 STWHIP P WEXIT LD WS setting adapter, HOT, and DGS MU BHA#4 whipstock milling assembly (no DGS, 1 jt of PH6) 14:00 - 16:30 2.50 STWHIP P WEXIT RIH with milling assembly, pumping min rate through open EDC. Lose signal to the CoiITRAK tools. Set down at 10680'. PU to 10671 and fix communication problem with the tools and close the EDC. Bring up rate to 1.0/ 1300psi. Tag at 10,703' and 10,775'. Suspect junk from Fas-Drill Plug. Bring up rate to 2.6 bpm / 2743psi. RIH to 11240' clean lower rate to 0.5 bpm for the tag. Tag pinch point at 11,270.4'. Correct to 11,265' -4.6' . 16:30 - 17:40 1.17 STWHIP P WEXIT Bring up rate to 2.53/ 2620 FS. Start milling window 11265' 2.53/ 2.51/ 2760 psi / 1110 WOB / 9.57 ECD. X•~ ~ 17:40 - 19:00 1.33 STWHIP P WEXIT Milling Window at 11266' 2.50/2.50/2780psi/1580 WOB/ 9.59 ECD PVT 415 19:00 - 20:30 1.50 STWHIP P WEXIT Mill window from 11267.0' 2.5/2700 w/ 50-100 psi dill, 2.5-3.Ok wob 9.49 ECD 20:30 - 22:00 1.50 STWHIP P WEXIT Mill window from 11268.0' 2.5/2680 w/ 50-100 psi dill, 3.0-3.7k wob 9.49 ECD 22:00 - 00:00 2.00 STWHIP P WEXIT Mill window from 11270.0' 2.5/2650 w/ <100 psi dill, 2.0-2.5k wob w/ 9.49 ECD Milled to 11272.0' 10/20/2007 00:00 - 01:00 1.00 STWHIP P WEXIT Mill from 11272.0' to 11273.8' which is the BOW 01:00 - 02:00 1.00 STWHIP P WEXIT Drill open hole from 11273.8' to 11284' 2.5/2780 w/ 100-150 psi dill, 2.5k avg wob w/ 9.49 ECD Drill to 11284' 02:00 - 02:45 0.75 STWHIP P WEXIT Dress window and dry drift Preliminary depths TOWS/TOW 11265', RA 11273.6', BOW 11273.8' 02:45 - 05:00 2.25 STWHIP P WEXIT POOH circ thru mill 2.5/2400 05:00 - 05:45 0.75 STWHIP P WEXIT LD milling assy. Mill gauged 3.79", SR 3.78" w/ center wear 05:45 - 07:50 2.08 DRILL P PROD1 Prep for MU BHA#5- lateral assy. Crew change and PJSM for PU lateral assembly. PU HCC rebuild bicenter bit, 1.0 deg motor, and resistivity. 07:50 - 09:00 1.17 DRILL P PROD1 RIH with BHA#5 circulating at min thru open EDC. DPS tools lost comms followed by the P&C sub. 09:00 - 10:10 1.17 DRILL N DFAL PROD1 POH to BHA from 6134'. 10:10 - 15:15 5.08 DRILL N DFAL PROD1 LD LOC, P&C, and DPS and they tested fine. The a-line tested good. Test new LOC, P&C and DPS sub and it doesn't work. Printed: 11/12/2007 4:36:07 PM . t M BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/20/2007 10:10 - 15:15 5.08 DRILL N DFAL PROD1 Scratch head then find the new LOC was bad. PU old LOC, new P&C, and new DPS. Stab on well and find more tool problems. LD entire tool string and discover the resistivity was the source of the problems. No back up RES tool on the slope. PU CoiITRAK tool minus RES. 15:15 - 16:15 1.00 DRILL N DFAL PROD1 RIH with BHA#6 circulating at min thru open EDC. 16:15 - 17:10 0.92 DRILL P PROD1 Back on planned time. Continue in hole. 17:10 - 17:40 0.50 DRILL P PROD1 Log GR tie-in (-4.0 Corr) 17:40 - 18:30 0.83 DRILL P PROD1 Run thru window slick. Tag bottom at 11287.0'. Pull back thru slick. Drill a few feet, but stops on orientor are on wrong side. Took a while to orient around 18:30 - 22:45 4.25 DRILL P PROD1 Drill from 11289' 2.46/3100/50-908 w/ 100-400 psi dill, 2.0-2.5k wob w/ 9.82 ECD while swap to reconditioned Flo Pro mud. Drill to 11400' First good survey at 11377 22:45 - 23:05 0.33 DRILL P PROD1 Wiper to window was clean. PUH thru window, open EDC. PUH to log 23:05 - 00:00 0.92 DRILL P PROD1 Log tie-in to mother wellbore/RA down from 11160' while circ thru EDC 2.48/2670 10/21/2007 00:00 - 00:15 0.25 DRILL P PROD1 Finish log tie-in with mother wellbore. Corr +1.1'. RA pip is at 11274.7' 00:15 - 00:30 0.25 DRILL P PROD1 Close EDC. Wiper back to TD 00:30 - 03:40 3.17 DRILL P PROD1 Drill from 11400' 2.5/3060/70-908 w/ 200-400 psi dill, 2.5-3.5k wob w/ 10.01 ECD at 89 deg. Drill to 11550' 03:40 - 04:05 0.42 DRILL P PROD1 Wiper to window was clean PVT 370 04:05 - 06:50 2.75 DRILL P PROD1 Drill from 11550' 2.47/3100/1008 w/ 100-400 psi dill, 1.8-3.Ok wob w/ 10.06 ECD at 87 deg. Drill to 11700'. 06:50 - 07:30 0.67 DRILL P PROD1 Wiper to window was clean. Bleed OA from 500 psi to 215. PVT 358. 07:30 - 09:45 2.25 DRILL P PROD1 Drill from 11700' 2.49/3580/908 w/ 200-400 psi dill, 1.8-2.8k wob w/ 10.10 ECD at 86 deg. Drill to 11850'. 09:45 - 11:10 1.42 DRILL P PROD1 Wiper above window was clean. Open EDC and circ at high rate to to 10800'. Log GR tie-in (+2.5') Clean back to bottom. 11:10 - 13:50 2.67 DRILL P PROD1 Drill from 11850' 2.60/3570/30L w/ 200-400 psi dill, 2.3-3.5k wob w/ 10.16 ECD at 87 deg. Drill to 12000'. 13:50 - 14:45 0.92 DRILL P PROD1 Wiper to window was clean. PVT 344. 14:45 - 16:50 2.08 DRILL P PROD1 Drill from 12000' 2.68/3710/60L w/ 200-400 psi dill, 2.3-3.5k wob w/ 10.20 ECD at 92 deg. Drill to 12150'. 16:50 - 17:50 1.00 DRILL P PROD1 Wiper to window was clean. PVT 339. 17:50 - 20:00 2.17 DRILL P PROD1 Drill from 12150' 2.63/3750/90L w/ 200-400 psi dill, 2.3-3.5k wob w/ 10.28 ECD at 93.7 deg. Drill to 12300'. 20:00 - 21:05 1.08 DRILL P PROD1 Wiper to window was clean. Pull thru window, open EDC. PUH circ 2.91/3000 to 10600' to remove solids from high angle portion prior to mud swap 21:05 - 21:20 0.25 DRILL P PROD1 Close EDC. Log tie-in to RA pip and Corr -4' 21:20 - 22:00 0.67 DRILL P PROD1 Wiper back to TD was clean PVT 322 22:00 - 00:00 2.00 DRILL P PROD1 Drill from 12300' 2.65/3240/90L w/ 200-500 psi dill, 2-3.5k wob w/ 10.30 ECD at 92 deg. Drill to 12428' 10/22/2007 00:00 - 00:25 0.42 DRILL P PROD1 Drill from 12428' 2.68/3340/80L w/ 200-500 psi dill, 2-3.5k wob w/ 10.38 ECD at 91 deg. Drill to 12450'. Swap to fresh Flo Pro mud 00:25 - 01:40 1.25 DRILL P PROD1 Wiper to window was clean both ways. Finish mud swap. Swap TF to right side Printed: 11/12/2007 4:36:07 PM r ~ BP EXPLORATION Page 8 of 15 Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - Ta Hours Task Code NPT 'Phase Description of Operations 10/22/2007 01:40 - 02:30 0.83 DRILL P PROD1 Drill from 12450' 2.57/2980/908 w/ 200-400 psi dill, 2-4k wob w/ 9.95 ECD at 90.5 deg Drill to 12496' and stacking. Wiper (42k) above 12440'. Drill to 12509' and stacking 02:30 - 03:30 1.00 DRILL N STUC PROD1 Diff stuck BHA on bottom at 12509'. Try a couple times at 25k over w/o success. SD pump and wait. Orientor works freely, wob does not change. First tries at 70k unsuccessful. Wait 30 min again. Pull 40k over and came free 03:30 - 03:50 0.33 DRILL P PROD1 200' wiper was clean. Slow ream TF change at 12450'. Wiper back to TD tagged at 12503' (counter slippage due to prior overpulls) 03:50 - 04:20 0.50 DRILL P PROD1 Drill from 12503' 2.64/3060 to 12517' and had very ratty drilling and assume formation change 04:20 - 05:15 0.92 DRILL P PROD1 Wiper to window from 12517' while circ up sample to check for pyrite or Shublik. Also, gained 3 deg angle at 12492' 05:15 - 05:30 0.25 DRILL P PROD1 Log tie-in to RA, Corr +6' ', Sample has pyrite. Geo's decide we will drop 2' TVD after ', resuming drilling 05:30 - 06:15 0.75 DRILL P PROD1 Wiper back to TD, set down at 11,670' 06:15 - 09:10 2.92 DRILL P PROD1 Drill from 12517 2.44/3130/1508 w/ 200-500 psi dill, 2-3.5k wob w/ 9.95 ECD at 92 deg. Ratty drilling. NBI is getting bounced around pretty good. The NBI is -87 deg at 12600'. Turn TF to 908. Drilled to 12650'. 09:10 - 10:45 1.58 DRILL P PROD1 Wiper to window. Overpull and MW at 11,670'. Minor MW at 11670' on the trip back in. PVT 335. 10:45 - 13:05 2.33 DRILL P PROD1 Drill from 12650' 2.51/3400/908 w/ 200-500 psi dill, 2.5-4.1k wob w/ 10.02 ECD at 88.3 deg. Seeing same shale stringers as we are coming down, assume we are just following dip. Point TF to 1058 to come down a little more in attempt to get away from the shale. Drilled to 12800'. 13:05 - 14:55 1.83 DRILL P PROD1 Clean wiper up to window. Set down 2x at 11674'. Popped thru at min rate. Backream up thru and it was clean. Clean back thru. 14:55 - 16:45 1.83 DRILL P PROD1 Drill from 12800' 2.53/3730/908 w/ 300-600 psi dill, 2.5-3.5k wob w/ 10.14 ECD at 87.6 deg. Still seeing pyrite in samples. Drilled to 12950'. 16:45 - 18:00 1.25 DRILL P PROD1 Wiper up to window. 300# MW at 11670'. Open EDC above window and circulate at 3.0 bpm to 10800'. 18:00 - 18:15 0.25 DRILL P PROD1 Log tie-in to RA, corr +5' 18:15 - 19:50 1.58 DRILL P PROD1 Wiper to TD was clean 19:50 - 22:45 2.92 DRILL P PROD1 Drill from tag at 12952' 2.45/3000/908 w/ 200-500 psi dill, 2-3.5k wob w/ 10.27 ECD at 87 deg. Drill to 13094' 22:45 - 00:00 1.25 DRILL P PROD1 Wiper to window 10/23/2007 00:00 - 00:55 0.92 DRILL P PROD1 Wiper back to TD tagged at 13092' was clean PVT 298 00:55 - 03:20 2.42 DRILL P PROD1 Drill from 13092' 2.5/3290/90L w/ 200-450 psi dill, 2.5-3.5k wob w/ 10.33 ECD at 86 deg. Drill to 13236' and stacking and dill sticky the last 50' Not getting the planned turn so will possibly graze the polygon 03:20 - 04:20 1.00 DRILL P PROD1 Wiper to window 2.8/3580 was clean 04:20 - 04:50 0.50 DRILL P PROD1 Pull thru window, open EDC and jet 3.1/3330 to 10800' and back to window. Close EDC 04:50 - 05:05 0.25 DRILL P PROD1 Log tie-in down ro RA pip, corr +5' 05:05 - 06:30 1.42 DRILL P PROD1 Wiper back to TD w/.set down at 11670' 06:30 - 08:05 1.58 DRILL P PROD1 Drill from 13236' 2.5/3640/90L w/ 200-450 psi dill, 2.5-3.Ok wob Printed: 11!12(2007 4:36:07 PM BP EXPLORATION Page 9 of 15 Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 1.0/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/23/2007 06:30 - 08:05 1.58 DR-LL P PROD1 w/ 10.40 ECD at 88.4 deg. Drill to 13350'. 08:05 - 10:25 2.33 DRILL P PROD1 Wiper to window with 5k overpull and MW at 11,670'. Weight bobble and MW on the way in at 11,900'. 10:25 - 11:40 1.25 DRILL P PROD1 Drill from 13350' 2.46/3690/90L w/ 200-450 psi dill, 1.3-2.8k wob w/ 10.54 ECD at 89.97 deg. Swap hole to new Mud. Pressure dropped to 3200 psi and 9.57 ECD. Much more differential sticking tendency with new mud around. Last time we were differentially stuck it was just after a a mud swap as well.? Can't explain it the mud is cleaner and the pressures are down. Differential stuck at 13433'. 11:40 - 12:20 0.67 DRILL N STUC PROD1 Pull to 74k and nothing on the WOB sub. Stuck above the DPS sub. Circulate clean fluid above the window then relax hole for 20 mins. Pull to -90k. Call for crude: ETA 3 hrs. Work pipe to 90k a few times. Let it relax while waiting on crude. 12:20 - 17:00 4.67 DRILL N STUC PROD1 Give a try after 30mins (5x to 90k) without luck. Wait 30 mins and give another couple pulls. Close choke and pull with 700 psi WHP. No Luck. Continue to wait on crude. PJSM. Chk VP @ 1.0 psi 17:00 - 17:30 0.50 DRILL N STUC PROD1 Start 15 bbls of dead crude from tanker at 2.6/3220. Displace w/ mud 2.6/3560 to place 5 bbls outside of bit 17:30 - 18:30 1.00 DRILL N STUC PROD1 Wait 5 min then work CT twice to 90k w/o success. Pump 5 more bbls and SD pump for changeout 18:30 - 18:40 0.17 DRILL N STUC PROD1 Pulled to 90k, popped free. Circulate crude out of coil. RIH to bottom & circulate crude from well bore while POH. 18:40 - 20:25 1.75 DRILL P PROD1 Wiper to window, divert crude returns to cuttings box. Open EDC & circ high rate to 10,800'. Bottom's up revealed large piece of rubber from bridge plug, possible stator rubber & lots of cuttings. 20:25 - 20:40 0.25 DRILL P PROD1 Wiper to window. Close EDC & run past window. 20:40 - 20:50 0.17 DRILL P PROD1 Log down for tie-in (+12ft). 20:50 - 22:10 1.33 DRILL P PROD1 Wiper to bottom -clean. 22:10 - 23:00 0.83 DRILL P PROD1 Drilling lateral from 13434' TF at 110E HS Op = 2.46 / 2.40 bpm FS 2850 psi w/ 200-400 psi dill BHP 4689 psi ECD = 10.06 ppg at 86 deg. BHT = 174 WOB / ROP = 1.75-2.25k1bf / 80-100 fph Working out of Pits 2, PVT = 105 Drill to 13470', PU to orientate, move fluids in pits around 23:00 - 23:10 0.17 DRILL P PROD1 Wiper 150ft & back to bottom. 23:10 - 23:35 0.42 DRILL P PROD1 Drilling lateral from 13470' TF at 120E HS Op = 2.69 / 2.66 bpm FS 3000 psi w/ 200-400 psi dill BHP 4751 psi ECD = 10.17 ppg at 86 deg. BHT = 172 WOB / ROP = 1.75-2.9klbf / 80-100 fph Drill to 13494', wiper. 23:35 - 23:55 0.33 DRILL P PROD1 Wiper 200' & back to bottom -clean. Start centrifuges. 23:55 - 00:00 0.08 DRILL P PROD1 Drilling lateral from 13494' TF at 90L HS Op = 2.63 / 2.58 bpm FS 3100 psi w/ 200-400 psi dill BHP 4708 psi ECD = 10.10 ppg at 87 deg. BHT = 172 WOB / ROP = 3.0-4.6klbf / 10-40 fph PVT=194 10/24/2007 00:00 - 00:20 0.33 DRILL P PROD1 Drilling lateral from 13494' TF at 90L HS Op = 2.63 / 2.58 bpm FS 3100 psi w/ 200-400 psi dill BHP 4708 psi ECD = 10.10 ppg at 87 deg. BHT = 172 Printed: 11/12/2007 4:36:07 PM BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Event Name: REENTER+COMPLETE Contractor Name: Rig Name: Date' From -To Hours Task Code NPT 10/24/2007 00:00 - 00:20 0.33 DRILL P 00:20 - 01:40 1.33 DRILL P 01:40 - 03:10 1.50 DRILL P 03:10 - 03:50 0.67 DRILL P 03:50 - 06:10 2.33 DRILL P 06:10 - 06:55 0.75 DRILL C 06:55 - 09:30 2.58 DRILL P 09:30 - 10:45 1.25 DRILL P Spud Date: 5/13/1994 Start: 10/1/2007 End: 10/30/2007 Rig Release: Rig Number: ..Phase Description of Operations PROD1 WOB / ROP = 3.0-4.6klbf / 10-40 fph PVT=194 Drilled to 13516' PROD1 Wiper to window -clean. PROD1 Wiper to bottom -clean. Bottom's up sample revealed trace HOT sample. PROD1 Drilling lateral from 13514' TF at 90L HS Op = 2.63 / 2.58 bpm FS 3100 psi w/ 200-400 psi dill BHP 4751 psi ECD = 10.19 ppg at 90 deg. BHT = 174 WOB / ROP = 3.0-4.6klbf / 70-100 fph PVT=184 Drilled to TD of 13565' (30' out of polygon & 50' past HOT sample) PROD1 Pump 25 bbls of hi-vis pill. Wiper to window. Bottom's up sample revealed more HOT. Wiper to window was clean. Pull thru window and park at 11248' PROD1 Open EDC. Launch 5/8" steel ball (as part of cement test) and displace w/ 25 bbls hi-vis pill 2.4/2600. Chase pill with mud 2.6/2600 until ball was calculated to be on seat at the UOC PROD1 POOH circ thru EDC 3.05/3200 PROD1 LD 3" drilling BHA. Recover ball. Remove flow sub for 3" tools and find 2" hardline rubber gasket in one flow port and plastic trash on the other side. Ball was resting above the rubber gasket. Rubber gasket had caused the flow sub to be flow-cut into the bronze portion of the sub Circ 0.3/800 to warm up the CT before installing the flow sub for the 2-3/8" tools and the slack moved forward about 1.5' out the end of CT. Could not push slack back 10:45 - 11:00 0.25 BOPSU P PROD1 Function test BOP rams as part of biweekly ROPE test 11:00 - 12:15 1.25 DRILL N DFAL PROD1 Cut off slack and rehead 12:15 - 13:15 1.00 DRILL N DFAL PROD1 MU 2-3/8" drilling BHA w/ resistivity tool (the 3" backup resistivity tool is still in transit) 13:15 - 15:15 2.00 DRILL N DFAL PROD1 RIH w/ BHA #7 (0.8 deg motor, 3" bi bit) circ thru bit 0.27/970 15:15 - 16:00 0.75 DRILL N DFAL PROD1 Log tie-in to RA pip logging down from 11292' 0.26/1150 Missed it, so relogged from 11275'. Corr -4' Change data rate for logging w/ res tool PVT 187 16:00 - 17:25 1.42 DRILL N DFAL PROD1 Log resistivity at 300'/hr from 11309' while circ 1.53/2280 17:25 - 23:30 6.08 DRILL N DFAL PROD1 11740' Hole is clean past known setdown area at 11670'. Very 23:30 - 00:00 I 0.501 DRILL I N 110/25/2007 100:00 - 03:00 I 3.001 DRILL I N 03:00 - 04:20 I 1.331 DRILL I P little character change on resistivity invasion profiles. Will continue logging for now to condition the hole and hope that the data obtained can be used for pert picks. BHI has 3" res tool in Anchorage and will try to get it on the SSA charter tonite in case it is needed. Tag TD at 13569'. Lay in new flo-pro from TD while POH. PROD1 POH. Bring new 3" RES tool to catwalk & begin testing/setting tool up for possible next run. This RES tool was last used in X-30A (was stuck in hole& had acid pumped through it, rebuilt). PROD1 Continue to POH. Open EDC above window. PJSM while POH regarding BHA handling & liner running. PROD1 At surface. Flow check well. Purge BHI tools & LD on catwalk & break apart for shipping to N1. Simultaneously bring BOT tools to RF, PU eckel tongs & prep end of a-line w/ SLB anchor & PT same -good test. Printed: 11/12/2007. 4:36:07 PM BP EXPLORATION Operations Summary Report Page 11 of 15 ~ Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/25/2007 04:20 - 11:00 6.67 CASE P RUNPRD MU 2-7/8" x 3-3/16" x 3-1/2" liner by program 11:00 - 12:00 1.00 CASE P RUNPRD RU false table. RU to run CSH 12:00 - 15:30 3.50 CASE P RUNPRD MU BTT 19' stinger on 77 jts 1-1/4" CSH plus 4 pups jts. Didn't see the O-ring sub/FV w/ stinger so bottomed out at top of stinger to determine spaceout 15:30 - 17:00 1.50 CASE P RUNPRD Fill void in liner w/ FW. RU BTT test assy. PT annulus of CSH/liner to 500 psi. RD test equipment 17:00 - 18:30 1.50 CASE P RUNPRD MU 'X' nipple and BTT deployment sub and pup along w/ CTLRT PT SWS anchor assy 18:30 - 00:00 5.50 CASE P RUNPRD RIH with liner. WT ck @ 11200' = 54k. RIW = 20k. Tag bottom at 13569' (corrected). PU wt=58k. Tag bottom again at 13569'. Circulate 0.64bpm in @ 1978psi, 0.57bpm out. Mix casutic & 2ppb bio in pil pit. Call cementers. Drop 5/8" steel ball w/ flo-pro, launch w/ 500psi & confirm via hearing the ball, pump bal at 2.3bpm @ 3100psi. Ball landed at 49bb1 away & sheared as pumps tripped out' 4800psi. Circulate a total of 60 bbls. PU 10ft, CT wt = 45k, released from liner. Set back down & swap well to 2% slick KCL @ 2.28bpm. Haul flo-pro to MI for reconditioning. RU cementers. 10/26/2007 00:00 - 00:30 0.50 CASE P RUNPRD Continue to circ well to 2% KCL. Clean out #2 pit. 00:30 - 00:45 0.25 CASE P RUNPRD PJSM regarding cementing procedures. 00:45 - 01:20 0.58 CASE P RUNPRD Prime up & batch up cement truck. PU to reconfirm release of liner - 45k up. 01:05 cement was up to weight, send sample to SLB lab. Pump 5 bbls of Bio to fluid rig pump & lines. Pump 3 bbls of fresh water to warm lines & P.T. to 4000 psi -good test. 01:20 - 02:30 1.17 CEMT P RUNPRD Pump 28.3bbls of 15.8ppg class 'G' cement. SD & clean out SLB cementers. Zero in MM & displace cement with 60 bbls of 2ppb biozan via rig pump @ 2bpm 2000psi. Zero out MM when cement is @ shoe, 1.70bpm @ 3850 psi. Pump 60.5 bbls (max displacement vol). 26.3bbls of cement behind pipe. PU 10ft & open choke to test floats - no flow. Unsting from o-ring sub & tag flapper -closed. 02:30 - 05:55 3.42 CEMT P RUNPRD POH while pumping min rate to contaminate liner & top of liner. POH replacing voidage. 05:55 - 06:15 0.33 CEMT P RUNPRD Tag up & flow check well. Crew change/PJSM 06:15 - 09:45 3.50 CEMT P RUNPRD LD CTLRT Standback CSH. LD stinger. Load out BTT tools 09:45 - 13:15 3.50 CASE P RUNPRD MU 2.27" D331 mill, motor, 2 jts CSH, SWS memory GR/CCL tool, MHA RIH w/ 38 stds CSH w/ 2 singles, MHA 13:15 - 14:50 1.58 CASE P RUNPRD RIH w/ CT circ 2% KCI 0.34/200. Load CT w/ 10 bbls bleach pill 14:50 - 16:45 1.92 CASE P RUNPRD Log GR/CCL down at 30'/min from 10500' to PBD while fin circ 0.42/650 bleach to mill. No wt loss entering TOL @ 11057'. Log to tag at 13513' CTD 16:45 - 17:50 1.08 CASE P RUNPRD POOH logging 60'/min 56k while leaving bleach in the liner Start getting cement returns back at surface up to 9.24 ppg. Dump approx 90 bbls of KCI contaminated w/ cement 17:50 - 20:00 2.17 CASE P RUNPRD POOH w/ CT 1.0/990. PJSM while POH regarding handling BHA. 20:00 - 20:20 0.33 CASE P RUNPRD Tag up. Continue to circulate until returns clean up. Printed: 11/12/2007 4:36:07 PM BP EXPLORATION Page 12 of 15 Qperations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Event Name: REENTER+COMPLETE Contractor Name: Rig Name: Date From - To Hours Task Code NPT 10/26/2007 20:20 - 20:25 0.08 CASE P 20:25 - 23:25 3.00 CASE P 23:25 - 00:00 0.58 CASE P 10/27/2007 00:00 - 00:30 0.50 CASE P 00:30 - 01:30 1.00 CASE P 01:30 - 01:50 0.33 PERFO P 01:50 - 02:30 0.67 PERFO P 02:30 - 05:30 3.00 PERFO P 05:30 - 05:50 0.33 PERFO P 05:50 - 08:10 2.33 PERFO P 08:10 - 08:25 0.25 PERFO P 08:25 - 09:15 0.83 PERFO P 09:15 - 12:00 2.75 PERFO P 12:00 - 12:15 0.25 PERFO P 12:15 - 15:15 3.00 PERFO P 15:15 - 15:30 0.25 PERFO P 15:30 - 16:20 0.83 PERFO P 16:20 - 17:40 1.33 PERFO P 17:40 - 18:45 1.08 DHEQP P 18:45 - 19:45 1.00 DHEQP P 19:45 - 22:50 3.08 DHEQP P 22:50 - 23:10 0.33 DHEQP P 23:10 - 00:00 0.83 DHEQP P 10/28/2007 00:00 - 01:20 1.33 DHEQP P Spud Date: 5/13/1994 Start: 10/1/2007 End: 10/30/2007 Rig Release: Rig Number: Phase Description of Operations RUNPRD Flow check well. RUNPRD Pop off. Set injector over bung hole. Drop 1/2" ball & open circ sub, sheared at 2500psi. stand back CSH RUNPRD Fill hole. Close swab. MU swizzle stick. Stab onto well. Jet stack & return line dead legs clean. RUNPRD Continue to jet stack & deg legs & all return routes. Clean out high pressure filter in reel house. RUNPRD Pop off well. RU tree cap to test pump. Pressure test liner lap to 2500 psi. Repeat pressure test 4 times -failed. Bled off 1000 psi in 2 min on each attempt. Bleed off pressure. RD tree cap & test hose. LOWER1 PJSM regarding handling pert BHA. LOWER1 Hoist perforator's equipment to RF. RU safety joint. Ensure hole is full. RU lifting equipment. Barricade cellar. LOWER1 RU perforating BHA. LOWER1 PU injector & MU to BHA. Stab on to well. LOWER1 RIH with pert BHA circ thru firing head 0.38/110 Wt chk @ 13000' 49.2k LOWER1 Tag at 13512' CTD. PUH 52.2k 13507' is up depth. PUH 50', clean. RIH 17.2k and retag at 13512' and correct to 13509'. PUH to ball drop at 13474'. Load 1/2" steel ball LOWER1 Launch ball w/ KCI at 1.5/1600 psi. RIH and get on depth. Incr rate to 2.3/3400 and hear ball rolling. After 45 bbls, slow to 1.15/1.11/870. Ball went on seat at 58.4 bbls and red rate to 0.6 bpm. Perform mini-drive by and shot on depth when ball seat sheared at 2640 psi. Lost -1.0 bbl KCI immediately, then lost additional 1.0 bbl while continuing to PUH 53k 0.74/310 at 40'/min thru pert area which was clean. SWS shot detector confirmed that the guns fired Perforated v PDC log 13110-13500' w/ 2" PJ2006 guns at 6 spf in bleach LOWERI POOH w/ CT circ 0.7/300 losing 14 additional bbls LOWER1 Flow check/safety mtg LOWER1 Set back injector. LD 78 CSH singles. Load out of pipeshed LOWER1 Safety mtg re: LD perf guns LOWER1 RU Farr tongs and SWS sling LOWER1 LD perf guns-all shots fired. Load out guns. LOWER1 RD floor tools. Crew change. Wait for BTT. LOWER1 Bring BTT equipment to RF. PJSM regarding MU KB packer. MU KB packer BHA. PU injector & MU to BHA. Stab injector onto well. LOWER1 RIH with KB packer BHA circ 0.15115. WT ck @ 10600' = 50k up. Set down at 11058' while pumping min rate, still have 100% returns -not stung into liner. PU 55k up wt. Attempt 3 times & at faster speeds. Try higher pump rate to straighten coil. Try at 1 bpm - no go. Try at 1.5 bpm -bobble through & no-returns. Bottom out at 11064' & 10k down at 11068'. LOWER1 P.T. backside to 2500 psi -failed. Injecting ' 1 bpm @ 2500psi, CTP=Opsi. PU to confirm depths (11060' - WT broke back), repeat -same results. PU to ball drop position. LOWER1 Unsting from liner, 11056'. Drop 5/8" steel ball w/ KCL at 2/1200 psi. Sting back into liner. LOWER1 59 bbls away -exactly as calculated while using a-line coil & Printed: 11/12/2007 4:36:07 PM ~ ~ BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT' Phase: Description of Operations 10/28/2007 00:00 - 01:20 1.33 DHEQP P LOWER1 a-line anchoring system. Pressure up & cycle Baker choke to get ball on seat. Inject into formation at 0.5bpm @ 2100psi. 01:20 - 01:35 0.25 DHEQP P LOWER1 Ball is on seat at 60 bbls. RIH to 11068' & set 10k down. 01:35 - 02:20 0.75 bHEOP P LOWER1 Pressure test backside to 2500psi -failed, bled to 500 psi in 3 min. Begin isolating valves. Pressure test backside to 2500psi -failed, bled to 500 psi in 3 min. Isolate more valves. PU 1' to 11066' to verify element is engaged. Test -holding! Bleed off pressures. PU to verify depths. Set down 10k at 11065 (bottom 3 seals of the KB packer assembly is at the middle of polish bore of the deployment sleeve). 02:20 - 04:30 2.17 DHEQP P LOWERI Pressure test backside to 2500psi for 30 min -failed, lost 300 psi in 30 min. Isolate valves. Repeat 4 times, lost 300 psi in 30 min each time. 04:30 - 04:35 0.08 DHEQP P LOWER1 Under time constraints due to freezing temps. Elect to pull KB packer. Pull 91 k & pull KB packer from TOL. Wait 5 min to let elements relax. 04:35 - 07:20 2.75 DHEQP P LOWER1 POH with KB packer. Fill across top while POH. Lost 10k at 10870'. 07:20 - 08:45 1.42 DHEQP N DPRB LOWER1 Tag up w/ CT. Break off injector and can't go down w/ CT. Pull injector up and find the top of PH6 jt is about 6' above the rig floor so KB must be at the tubing hanger. Strip injector high enough to break connection at top of PH6. Circ over bung hole (CT was not frozen). Pull PH6 w/ KB assy from wellbore w/ tugger. Seals on stinger were intact as run. Soft cement evident in ring grooves. KB was missing 1/2 of the lower sealing rubber and the complete smaller/softer middle rubber. Recover ball. Load out KB for redress at BTT shop. PT CTC/WL anchor assy to 3600 psi. MU BTT polish mill w/ 3.72" no-go on motor assy 08:45 - 10:40 1.92 DHEQP N LOWER1 RIH w/ polishing mill assy BHA #12 circ thru mill 0.53/170 11000' 52k, 18.8k RIH to 11063.8' CTD at 0.5 bpm. Enter DS @ +/-11060' 10:40 - 11:20 0.67 DHEQP N LOWER1 PUH, start motor 2.53/2330. Start 30 bbl hi-vis pill. Backream tubing to 11030' while circ pill to mill. RIH and see mill enter TOL at 11059'. Ease in hole and stack 6k w/ 600 psi dill at 11064' which is the stop setting on TOL 2.53/2.45/2000. PUH, clean. Repeat at 2.8/2800 11:20 - 13:15 1.92 DHEQP N LOWERI POOH circ 2.64/2200 pill to surface and had no visible solids or rubber returned 13:15 - 14:15 1.00 DHEQP N LOWER1 LD and load out the polishing assy. MU redressed KB packer assy as before 14:15 - 16:45 2.50 DHEQP N LOWER1 RIH w/ BHA #13 circ 0.38/90 11000' 49.7k, 19.8k 16:45 - 17:30 0.75 DHEQP N LOWER1 RIH to TOL tagged at 110057.8' and stack wt to 5k. Try it at a faster RIH speed and set down on TOL again. Incr rate to 1.0/370 and set down. Try 1.5/850. Try different speeds and other combinations w/o success 17:30 - 19:55 2.42 DHEQP N LOWERI POH 0.65/125 w/ KB packer assy to change BHA configuration/check mule shoe on seal assy. PJSM while POH regarding handling BHA. 19:55 - 20:55 1.00 DHEQP N LOWER1 Tag up. Flow check. Pop off well. Break apart BHA & inspect KB packer. Hard Schmoo covering slips & rubber elements. Printed: 11./12/2007 4:36:07 PM BP EXPLORATION Page 14 of 15 Operations Slumrnary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date' From - To Hours Task Code NPT Phase Description of Operations 10/28/2007 19:55 - 20:55 1.00 DHEQP N LOWER1 Clean BHA & packer. Re-bevel mule shoe (end of mule shoe was bent from tagging TOL). Add in 9' & 4' pup joint with cementralizer on bottom of 4' pup joint for more stand off. MU BHA checking each connection. PU injector & stab onto well. 20:55 - 23:15 2.33 DHEQP N LOWERI RIH w/ KB packer circ 0.29bpm/48psi. 23:15 - 00:00 0.75 DHEQP N LOWER1 WT ck = 50k @ 11040', RIW=20k. Stab into liner on first attempt with no problems @ 11060'. No-go out with 10k down at 11068'. PU, break over point = 11062'. Pressure up coil & monitor returns -none (still stung into liner). PU to see pressure bleed off - 11058' (out of liner). Repeat to confirm results. PU to 11049', launch 5/8" steel ball w/ KCI w/ 500psi. Circ ball at 2 bpm/1300psi & confirm it's over the goose neck via listening in reel house (19bbls away). Slow down pump rate at 45bbls away, 0.62bpm/117psi. Ball landed at 48.3bbls away, dump pressure. 10/29/2007 00:00 - 00:15 0.25 DHEQP N LOWER1 RIH, slight bobble at 11058' & tag w/ 10k down at 11068'. PU to breakover point + 2' = 11060'. Pressure up coil to 2800psi no reutrns (still stung into liner). Set 10k down. Bleed of coil pressure & set down 10k again. 00:15 - 02:10 1.92 DHEQP N LOWER1 Pressure test backside to 2500psi for 30 min. Failed on multiple testing, leak rate of 100psi in 5 min. Isolate valves through out rig & confirm leak is down hole. Bleed off pressure. 02:10 - 02:40 0.50 DHEQP N LOWER1 Reposition KB packer & set 20k down. Pressure test backside to 2500psi -failed, leak rate of 100 psi in 5 min. Bleed off pressures. 02:40 - 02:45 0.08 DHEQP N LOWER1 Call town engineer & discuss options. Previous to drilling, cement retainer set at 11280' failed MIT. HES Fas drill plug set at 10775' passed MIT. Therefore, possible leak exist from 10775' to 11026'. 02:45 - 02:50 0.08 DHEQP N LOWER1 Pressure up coil to 3500psi. Set 4.5" KB packer. Top of 4.5" KB packer is at 11026'. 02:50 - 05:20 2.50 DHEQP N LOWER1 POH circ 0.75bpm/157psi. Send Baker hand to shop to retrieve PIP test tool. PJSM while POH regarding handling BHA. 05:20 - 06:15 0.92 DHEQP N LOWERI Tag up. Flow check. Pop off well. Place injector over bung hole & circ at min rate. RD KB packer setting tool. Recover 5/8" steel ball. 06:15 - 06:30 0.25 DHEQP P LOWER1 Crew change/safety mtg 06:30 - 08:00 1.50 DHEQP N LOWER1 RU coil cutter & cut 105ft of coil and +/-110' a-line. Install CTC/SWS e-line anchor. PT 35k, 3600# 08:00 - 08:45 0.75 DHEQP N LOWER1 MU BTT 3-3/8" thru tubing inflatable packer assy w/ 5/8" steel ball on seat and pinned to shear at 3780-5670 psi if necessary. Packer also has an emergency 5.5k pull release which dumps the pressure to deflate the element 08:45 - 11:15 2.50 DHEQP N LOWER1 RIH w/ BHA #15 to determine leak point in liner w/o circ and taking returns from wellbore to 10884' CTD. PUH 55k (which broke back to 50.Ok) to 10863.7' CTD at the end of tool which puts center of element at 10860' ELMD for first test point 11:15 - 11:30 0.25 DHEQP N LOWER1 Pump down CT to pressure up and inflate packer, but CT circulated 1/1. We apparently pull-released the dump valve upon picking up from 10884', so there is no way to inflate the tool. Will have to repin on surface 11:30 - 13:30 2.00 DHEQP N LOWER1 POH filling from the BS Pdnted: 11/12/2007 4:36:07 PM • BP EXPLORATION Page 15 of 15 .Operations Summary Report Legal Well Name: X-20 Common Well Name: X-20 Spud Date: 5/13/1994 Event Name: REENTER+COMPLETE Start: 10/1/2007 End: 10/30/2007 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 10/29/2007 13:30 - 13:45 0.25 DHEOP P LOWER1 LD BHA. Inflatable BP was intact w/ all rubbers and the dump valve had been shear released. Did not appear that it had inflated. Found sticky solids/hydrocarbons and a 1/2" dia piece of hard cement just above the bottom nose Received word from the Asset to end leak hunting operations 13:45 - 14:00 0.25 WHSUR P POST MU nozzle BHA 14:00 - 15:15 1.25 WHSUR P POST RIH w/ 3" nozzle circ 0.55/120. Swap to diesel. FP wellbore to 2000' w/ 30 bbls diesel while POH. SIP 0, IA 110, OA 43 15:15 - 15:30 0.25 WHSUR P POST Break off nozzle assy. RU to blow down CT w/ air 15:30 - 17:15 1.75 RIGD P POST Blow down surface lines w/ air. Vac pits Blow down reel w/ air to vac truck 17:15 - 18:00 0.75 BOPSU P POST ND BOPE while wo BPV crew Finish vac and clean pits 18:00 - 18:30 0.50 BOPSU P POST CO w/ day crew. PJSM regarding ND BOPE. 18:30 - 22:00 3.50 BOPSU P POST Continue to ND BOPE. Dry rod 4" 'H' BPV. Continue to vac out cuttings box. Warm up moving system. 22:00 - 22:30 0.50 BOPSU P POST Dress tree w/ new gauges. Install tree cap. Fill w/ diesel. P.T. for 5 min to 5000psi -good. Bleed off pressure. 22:30 - 23:00 0.50 DEMOB P POST Do quick walk around rig. Call DSO. Add air to 1 tire. 23:00 - 00:00 1.00 DEMOB P POST Move off well and down to the pad entrance. Clean up around well. Rlg released at midnight. Printed: 11/12/2007 4:36:07 PM • by BP Alaska r Baker Hughes INTEQ Survey Report LNTE Q Compaay: BP Amoco Date: 11/6/2007 Time: 09:21;18 Page: 1 Field: Prudhoe Bay Co-®rdinate(NE) Reference: ' Weih X-20, T('ue North Site: PB X Pad Vertical (1'VD) Refer~ce: 30:20 5/13/t994 00:00 68.0 Well: X-20 Section (VS) Refereecec Wep {O.OON,OOOE,233.86Azi) Wellpath:- X-20A Snrvey Calcrlatio® Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordiuate System: Weil Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB X Pad TR-10-14 UNITED STATES :North Slope Site Position: Northing: 5937417.97 ft Latitude: 70 14 7.207 N From: Map Fasting: 664667.65 ft Longitude: 148 40 13.706 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.25 deg Well: X-20 SbYName: 20 X-20 Well Position: +N/-S 3033.25 ft Northing: 5940480.35 ft Latitnde: 70 14 37.038 N +E/-W 1376.63 ft Fasting : 665877.63 ft Longitude: 148 39 33.683 W Position Uncertainty: 0.00 ft Wellpath: X-20A Drilled From: X-20 500292247801 Tie-on Depth: 11245.00 ft Current Datum: 30:20 5/13!1994 00:00 Height 68.00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/10/2007 DecHnadon: 23.64 deg Field Strength: 57651 nT Mag Dip Angle: 80.87 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.00 0.00 0.00 233.86 Survey Program for Definitive Wellpath Date: 8/10/2007 Validated: Yes Version: 7 Actual From To Survey Toolcode Tool Name ft ft 98.20 10899.20 1 : MWD -Standard (98.20-1089 MWD MWD -Standard 10935.00 11245.00 1 : MWD -Standard (10935 .00-1 MWD MWD -Standard 11265.00 73569.00 MWD (11265.00-13569.00) MWD MWD -Standard AOOOtatlon MD TVD ft ft 11245.00 9005.95 TIP 11265.00 9007.69 KOP 13569.00 9057.34 TD Survey: MWD Start Date: 10!22/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path • by BP Alaska r Baker Hughes INTEQ Survey Report 1NTE Q Compaey: BP Amoco Date: 1116!2007 Time: 09:2T;18 Page: 2 Fiehi: Prudhoe Bay Co-ordu~atc(NE} Reference: ' Wep: X-20, True`North Site: PB X Pad Verticat (1'VD) Reference: 30:20 5/1 311 994 00:00 68.0 Weli: X-20 S ection (VS) Reference: Well (0.OON,O.OOE,233.86Azi) Wellpath: X-20A Survey Cah:nlatiea Method: Minimum Curvature Dh: Orade Survey MD Inel Azim TVI)' Sys TVD N/S E/W MapN MapE _ VS DLS Tool ft deg deg ft ft ft ft ft ft $ deg/100ft 11245.00 84.50 234.30 9005.95 8937.95 -4474.95 -4000.95 5935918.69 662076.45 5870.23 0.00 MWD 11265.00 85.53 235.07 9007.69 8939.69 -4486.47 -4017.21 5935906.82 662060.45 5890.15 6.42 MWD 11284.30 87.20 237.02 9008.91 8940.91 -4497.23 -4033.19 5935895.71 662044.72 5909.40 13.29 MWD 11314.40 87.55 240.06 9010.29 8942.29 -4512.92 -4058.83 5935879.46 662019.43 5939.36 10.16 MV1~ 11344.34 87.61 243.08 9011.55 8943.55 -4527.16 -4085.13 5935864.65 661993.44 5969.00 10.08 MWD 11377.70 86.46 246.44 9013.28 8945.28 -4541.36 -4115.26 5935849.79 661963.64 6001.71 10.63 MWD 11407.90 87.57 246.37 9014.85 8946.85 -4553.43 -4142.90 5935837.11 661936.27 6031.15 3.68 MWD 11437.30 89.85 251.74 9015.51 8947.51 -4563.94 -4170.34 5935826.01 661909.08 6059.50 19.84 MWD 11467.49 89.45 257.64 9015.70 8947.70 -4571.90 -4199.45 5935817.40 661880.15 6087.71 19.59 MWD 11502.01 87.85 261.54 9016.51 8948.51 -4578.14 -4233.38 5935810.42 661846.37 6118.79 12.21 MWD 11531.94 88.80 264.86 9017.39 8949.39 -4581.68 -4263.08 5935806.23 661816.75 6144.87 11.53 MWD 11564.04 86.56 268.44 9018.69 8950.69 -4583.55 -4295.09 5935803.65 661784.79 6171.82 13.15 MWD 11593.57 85.49 272.86 9020.74 8952.74 -4583.22 -4324.54 5935803.33 661755.35 6195.41 15.36 MWD 11622.91 85.18 276.87 9023.12 8955.12 -4580.74 -4353.67 5935805.17 661726.17 6217.47 13.66 MWD 11653.39 84.65 281.93 9025.83 8957.83 -4575.78 -4383.62 5935809.46 661696.13 6238.73 16.63 MWD 11685.16 84.86 286.55 9028.73 8960.73 -4568.00 -4414.27 5935816.57 661665.31 6258.90 14.50 MWD 11719.51 85.17 291.93 9031.72 8963.72 -4556.73 -4446.57 5935827.13 661632.77 6278.33 15.63 MWD 11749.85 85.79 296.89 9034.11 8966.11 -4544.24 -4474.10 5935839.01 661604.97 6293.20 16.42 MWD 11787.14 85.45 297.36 9036.96 8968.96 -4527.28 -4507.19 5935855.23 661571.52 6309.93 1.55 MWD 11814.05 85.37 294.93 9039.11 8971.11 -4515.47 -4531.27 5935866.51 661547.19 6322.40 9.01 MWD 11848.66 85.69 290.92 9041.81 8973.81 -4502.03 -4563.04 5935879.25 661515.13 6340.13 11.59 MWD 11880.20 89.45 289.00 9043.15 8975.15 -4491.27 -4592.66 5935889.35 661485.29 6357.71 13.38 MWD 11911.79 90.58 286.20 9043.14 8975.14 -4481.72 -4622.77 5935898.23 661454.98 6376.39 9.56 MWD 11944.71 91.63 282.76 9042.51 8974.51 -4473.49 -4654.63 5935905.76 661422.95 6397.27 10.92 MWD 11979.49 92.46 280.01 9041.26 8973.26 -4466.63 -4688.70 5935911.86 661388.74 6420.73 8.25 MWD 12011.75 92.40 276.44 9039.90 8971.90 -4462.02 -4720.59 5935915.77 661356.75 6443.77 11.06 MWD 12043.81 93.04 272.36 9038.37 8970.37 -4459.57 -4752.52 5935917.52 661324.78 6468.10 12.87 MWD 12079.28 93.34 268.49 9036.40 8968.40 -4459.30 -4787.92 5935917.01 661289.38 6496.54 10.93 MWD 12111.43 93.44 265.30 9034.50 8966.50 -4461.04 -4819.96 5935914.56 661257.39 6523.44 9.91 MWD 12147.32 93.31 261.45 9032.38 8964.38 -4465.18 -4855.55 5935909.65 661221.91 6554.62 10.71 MWD 12182.44 94.03 257.53 9030.14 8962.14 -4471.57 -4890.00 5935902.50 661187.61 6586.21 11.33 MWD 12221.22 93.50 252.89 9027.59 8959.59 -4481.44 -4927.40 5935891.80 661150.43 6622.24 12.02 MWD 12254.04 93.16 249.19 9025.68 8957.68 -4492.09 -4958.38 5935880.48 661119.69 6653.54 11.30 MWD 12291.45 93.78 245.73 9023.42 8955.42 -4506.40 -4992.87 5935865.42 661085.54 6689.83 9.38 MWD 12323.24 94.39 241.82 9021.15 8953.15 -4520.41 -5021.31 5935850.78 661057.41 6721.06 12.42 MWD 12358.11 93.84 238.34 9018.65 8950.65 -4537.75 -5051.45 5935832.78 661027.67 6755.63 10.08 MWD 12392.08 92.43 235.10 9016.79 8948.79 -4556.36 -5079.80 5935813.55 660999.73 6789.50 10.39 MWD 12421.55 90.95 232.17 9015.92 8947.92 -4573.83 -5103.52 5935795.57 660976.41 6818.95 11.13 MWD 12451.35 91.41 224.80 9015.30 8947.30 -4593.56 -5125.81 5935775.35 660954.56 6848.59 24.77 MWD 12481.77 92.64 230.79 9014.23 8946.23 -4613.97 -5148.32 5935754.45 660932.50 6878.81 20.09 MWD 12512.82 92.09 234.25 9012.95 8944.95 -4632.85 -5172.93 5935735.04 660908.31 6909.82 11.27 MWD 12542.05 89.97 236.42 9012.42 8944.42 -4649.47 -5196.97 5935717.89 660884.65 6939.03 10.38 MWD 12578.47 85.83 237.95 9013.76 8945.76 -4669.19 -5227.55 5935697.51 660854.51 6975.36 12.12 MWD 12606.62 87.02 241.42 9015.51 8947.51 -4683.37 -5251.80 5935682.80 660830.58 7003.30 13.01 MWD 12635.47 88.43 248.61 9016.66 8948.66 -4695.53 -5277.91 5935670.06 660804.75 7031.57 25.38 MWD 12665.99 89.45 248.45 9017.22 8949.22 -4706.70 -5306.31 5935658.27 660776.61 7061.08 3.38 MWD 12694.32 89.45 254.65 9017.50 8949.50 -4715.66 -5333.17 5935648.72 660749.95 7088.06 21.88 MWD 12726.06 89.08 256.91 9017.90 8949.90 -4723.46 -5363.93 5935640.25 660719.37 7117.50 7.21 MWD 12759.69 89.08 262.61 9018.44 8950.44 -4729.43 -5397.01 5935633.55 660686.44 7147.74 16.95 MWD 12794.49 87.82 267.94 9019.38 8951.38 -4732.30 -5431.66 5935629.92 660651.85 7177.41 15.73 MWD 12825.04 91.10 272.76 9019.67 8951.67 -4732.11 -5462.20 5935629.44 660621.32 7201.96 19.08 MWD 12857.30 90.00 277.81 9018.36 8951.36 -4729.14 -5494.31 5935631.70 660589.16 7226.14 16.02 MWD 12894.07. 88.65 284.26 9019.80 8951.80 X722.11 -5530.38 5935637.94 660552.95 7251.12. 17.92 MWD by BP Alaska ~ Baker Hughes INTEQ Survey Report 1NTE Q Compapy: BP Amoco Date: 11/6!2007 Time: 09:21:18 Page: 3 Fteld:` Prudhoe Bay Co-ordinate(NE) ltefereece: Well; X-2Q True North Site: PB X P~ Vertical (1'VD)1Zeference: 30:20 5/13/t 994 00:00 68.0 Well: X-20 Sectiou(VS)Reference: Weil.(O.OONO .OOE,233. S6Azi) Welipath: X-20A Survey Cakelation Method: Minimum Curvature Db: OraGe Survey MD Iecl Azim 1`VD Sys TVD N/S E/W Map1V MapE VS DLS Tool ft deg deg.. ft ft' ft ft ft' ft ft deg/100ft 12922.96 87.64 288.89 9020.73 8952.73 -4713.87 -5558.04 5935645.56 660525.11 7268.61 16.39 MWD 12960.66 86.62 294.16 9022.62 8954.62 -4700.06 -5593.06 5935658.59 660489.80 7288.74 14.22 MWD 12989.80 86.74 298.80 9024.31 8956.31 -4687.10 -5619.09 5935670.98 660463.49 7302.12 15.90 MWD 13018.94 87.15 302.97 9025.86 8957.86 -4672.16 -5644.06 5935685.36 660438.20 7313.47 14.36 MWD 13048.34 87.09 306.94 9027.34 8959.34 -4655.34 -5668.12 5935701.65 660413.78 7322.98 13.49 MWD 13078.09 86.50 305.19 9029.00 8961.00 -4637.86 -5692.13 5935718.60 660389.39 7332.06 6.20 MWD 13106.93 87.17 303.45 9030.60 8962.60 -4621.62 -5715.91 5935734.31 660365.26 7341.69 6.46 MWD 13135.84 87.21 299.95 9032.01 8964,01 -4606.45 -5740.47 5935748.93 660340.37 7352.58 12.09 MWD 13172.66 87.63 296.97 9033.67 8965.67 -4588.93 -5772.80 5935765.74 660307.66 7368.36 8.17 MWD 13204.02 88.25 294.47 9034.80 8966.80 -4575.33 -5801.04 5935778.71 660279.14 7383.14 8.21 MWD 13237.29 87.73 292.29 9035.97 8967.97 -4562.13 -5831.55 5935791.23 660248.34 7400.00 6.73 MWD 13271.06 88.37 290.01 9037.12 8969.12 -4549.96 -5863.03 5935802.71 660216.60 7418.24 7.01 MWD 13310.03 90.03 287.66 9037.66 8969.66 -4537.38 -5899.91 5935814.47 660179.46 7440.60 7.38 MWD 13339.92 89.88 286.45 9037.68 8969.68 -4528.61 -5928.48 5935822.61 660150.70 7458.51 4.08 MWD 13370.64 89.79 284.27 9037.77 8969.77 -4520.47 -5958.10 5935830.09 660120.91 7477.63 7.10 MWD 13398.79 88.89 281.75 9038.10 8970.10 -4514.14 -5985.52 5935835.82 660093.36 7496.04 9.51 MWD 13432.87 88.18 279.13 9038.97 8970.97 -4507.97 -6019.03 5935841.25 660059.73 7519.45 7.96 MWD 13468.82 84.01 278.07 9041.42 8973.42 -4502.60 -6054.48 5935845.83 660024.17 7544.92 11.97 MWD 13498.09 81.93 276.15 9045.00 8977.00 -4499.01 -6083.30 5935848.79 659995.28 7566.08 9.64 MWD 13530.68 79.39 274.20 9050.29 8982.29 -4496.10 -6115.33 5935850.99 659963.20 7590.23 9.78 MWD 13569.00 79.39 274.20 9057.34 8989.34 -4493.35 -6152.89 5935852.92 659925.59 7618.94 0.00 MWD FW: ~-20a anomaly • • Maunder, Thomas E (DOA) From: McMullen, John C [McMuIIJC@BP.com} Sent: Tuesday, November 27, 2007 3:19 PM To: Maunder, Thomas E (DOA) Cc: Subekti, Herry; Schmoyer, AI Subject: FW: X-20a anomaly Attachments: X-20ai.ZIP ~ ~ `~ .= 1 ~, Tom -Thanks for discussing the well. Here's the other info you requested: 10/16/2007. (tail end. of the RWO after setting new production packer at 1 Q676' MD): Page 1 of 2 • Drop ball and rod assembly. Pressure tubing to 3500 psi to set packer. Pressure tubing to 4000 psi. Chart for 30 minutes. No bleed off. Bleed tbg to 1500 psi. Pressure IA to 3500 psi. Record on chart. Bleed off IA and tubing. It is understood that a post completion successful MIT-IA, witnessed by the AOGCC, is needed shortly after putting the well on injection. We will not put the well on injection until we get the green light from you. Let me know if you need anything else. Thanks, John From: McMullen, John C Sent: Tuesday, November 27, 2007 7:30 AM To: 'tom.maunder@alaska.gov' Cc: ~hmoyer, AI; Subekti, Henry Subject: X-20a anomaly «X-20ai.ZIP» Tom -- As a follow-up to our conversation yesterday, I'm sending you a Wellbore Schematic of injector X-ZOai for our discussion later today (I'll call sometime this afternoon}. X-20a is a recently completed RWO and CTD sidetrack (PTD #2071130). Here's a quick overview of the issue: - During the completion phase of the sidetrack, we discovered that we had a small teak somewhere below our new production packer (note: MIT-lA passed} and above our coil sidetrack liner top packer. - Post-rig diagnostics revealed an extremely small leak past the originally completed (1994) 4-1/2" finer top packer. The leak path is identified by the green line in life schematic. Again, this leak is extremely small - we were unable to establish a leak rate and the bleed-off was 3000 psi ~ 2880 psi in 10 minutes during the 12/5/2007 FW: X-24a anomaly ~ . Page 2 of 2 ultrasonic teak log. - V1fe are not sure where the leak is exiting the system, but we're confident that it below the top of Sag {within our permitted zone of injection). We are comfortable operating the well in its current state. Future diagnostics will be perfom~ed based on normal reservoir management criteria or changing well conditions. if you agree, let's talk. about plan forward papennrork or othervvise. Thanks, John 12/5/2007 TREE = 4" CNV 5M WELLHEAD= FMC ACTUATOR= BAKER KB. ELEV = 68.8' BF_ ELEV = 42.0' KOP = 800' _ Max Argk: = Datum MD = --------- Datum ND = 92 ~ 11594' 10852' - ----------------- 8800' SS DRLG DRAFT 110-3t4" CSC, 45.5#, NT-80, LHEBTC, D = 9.953" t-{ 3$86 op of Cement Logged at 9650` MD. ottom logged depth at top of 4-1/2" liner 0.81?` ~~n Chemical Cut Tubing @ 10,710' ~,i I41 /2" TBG, 12.6#, L-80, .b152bpf, D = 3.958° 10814' Leak Path during ultrasonic log. 10655' - 4-1/2" HES X Nipple, L-80, 3.813" ID 10676' - 7-5/8" x 4-1/2" Baker S3 Packer 10700' - 4-1/2" HES X Nipple, L-80, 3.813" ID 7-5/8" x 4-1/2" Unique Machine Overshot 10741' 7-5/8" x 4112" BKR SABL-3 PKR, D = 3.875" 10802' H41/2' OTIS X NIP, D = 3.813" Top of Sag (top of permitted zone of injection) = 10,922' MD. 10803' f'"I TOP OF TIEBACK SLV, D = 6.358" 10813' 7-518" TNV HANGER PKR 10814' 4112" WLEG, D = 3.958" 10821' I-15-112" X 7-5/8" TfJV HYD HANGER - 10952' 7-5/8" Casing Shoe 11026' 4.5" KB Packer 4" GS FN Top of Cement I--I 11056' TOP OF 3-3/16" LN 11056' r41 /2" X 6-314° CTG (ECP}, D = 3.980" 1203T j 4112" LNR, 12.6, L-80 NSCT, .0152 6pf, D = 3.958" 1217 TOP OF 41/2" SLTD LNR 1217T 3-3/16" X 2-7/8" crtt'ed and perfedH 13569' 11270' Mechanical Whipstock 11298' Cement Retainer I PBTD 4112' SLTD LNR, 12.6#, 13-CR-80 NSCT, .0152 bpf, ID = 3.953" 12720' DATE REV BY CORRu~.M'S DATE REV BY COMv£NfS 06/22/44 M DO ORIGINAL tlOlt2 COMPLETI 11!20!07 DTR/PJC MRJ ID CORRECTION 01/23'04 SRBlKK CORRECTIONS 04,'19F06 RPWPJC WANERSAFEN NOTE t 21161'.}5 JRPfPJC PULL BP ~ 10743' 8 FISH (ELETAEJYTS) 10130`+37 NflR1~iC? iCTD SIDETRACK (X-20A) - ~ PRUDHOE BAY UNrr WELL: X-20 PERWPrNo: 1940607 API No: 50-029-22478-70 SEC 7, T10N, R14E BP exploration (Alaska) X-2 oA I SAFETY NOTES. O ~- 2,244' - 4-1/2" HEX X Nipple, L-80, 3.813" ID • INTEQ To Whom It May Concern: BAKER NuCsNES 7260 Homer Drive Anchorage, Alaska 99~ 18 Te1907-267-6600 Fax 907-267-6623 November 16, 2007 Please find enclosed directional survey data for the following wells: G-09B OS-lOC OS-22C K-08B X-30APB 1 X-30APB2 X-30A X-20A -' Enclosed for each well is: tea copies of directional survey reports lea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. G ~ RECEIVED BY: .~+~~ ~ ~~ ,State of Alaska AOGCC DATE: ~ ~ ~' ~ Cc: State of Alaska, AOGCC II v?- ~ ~ X-20A (PTD #2071130) Internal Waiver Cancellation -Not Operable Well Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.comj~n,~ Z ti-t -~ 7 Sent: Tuesday, October 30, 2007 10:56 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, GC2 Wellpad Lead; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, Wells Opt Eng; GPB, Prod Controllers; Engel, Harry R Cc: Subekti, Herry; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: X-20A (PTD #2071130) Internal Waiver Cancellation -Not Operable Well All, f An internal waiver was issued for TxIA communication on well X-20A (PTD #2071130) on 04/19/06. A corresponding AOGCC Administrative Approval was approved 03/22/06. This well has been sidetracked with new tubing and therefore the waiver and AA are no longer needed. A witness MITIA will be conducted for UIC compliance once the well is on injection. The well has been reclassified as Not Operable until released for injection post rig work. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. The corresponding sundry cancellation will be sent to the AOGCC. Please calf if you have any questions. 11 / 1 /2007 ~_ ~~ 11/09(04 STATE OF ALASKA OIL AND GAS CONSERVATION COIWMISSION RO PE Test Report Submit to: Contractor: Nordic Rig No.: 2 DATE: 10/17/07 Rig Rep.: Mckeiman / Sloan Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: McLaughlin / Sevcik E-Mail Wel! Name: PBU X-20A PTD #2071130 Operation: Drag: XXX Workover: Explor.: Test: Initial: XXX Weekly: Bi-Weekly Test Pressure: Rams: 250-3500 Annular: 250-3000 Valves: 250-3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Drl. Rig P Lower Kelly NA PTD On .Location P Hazard Sec. P Bail Type 1 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity SizelType Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit Level Indicators P P #1 Rams 1 Blind /Shear P Flow Indicator P P #2 Rams 1 2 3/8"combi'~ P Meth Gas Detector P P #3 Rams 1 2 3/8"x3 1/2" P H2S Gas Detector P P #4 Rams 1 Z 3/8"combi'~ P #5 Rams WA NA Quantity Test Result Choke Ln. Valves 1 31/8" P Inside Reel valves 1 P HCR Valves 2 31/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2300 P Quantity Test Result 200 psi Attained 23 sec P No. Valves 14 P Full Pressure Attained 70 sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 P Nitgn. Bottles (avg}: 4 2100 Test Results Number of Failures: 0 Test Time: 5.5 Hours Components tested 29 Repair or replacement of equipment will be made within 0 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at. Remarks: Distribution: 24 HOUR NOTICE GIVEN prig-Well File YES )OOC NO c - Oper./Rig Waived By Jeff Jones c -Database Date 10/16/07 Time 0600 c -Trip Rpt File Witness c -Inspector Test start 0400 Finish 0930 Coil Tubing BFL 11/09/04 Nordic 2 BOP 10-17-07p.xls • ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Saltmarsh, Arthur C (DOA) Sent: Thursday, September 20, 2007 10:16 AM To: Maunder, Thomas E (DOA); Davies, Stephen F (DOA) Cc: 'Hubble, Terrie L' Subject: RE: P8U X-20A /PTD # 207-113 Morning Terrie, 1 discussed the PBU X-20A /PTD #207-113 and the API numbering with Steve. I just wanted to confirm that we are unable to use the 01 designation for this well as we already have that well and the associated PTD number in our Data base. We physically cannot do this. We have cancelled the original PTD and it has a XX designation after the well name. You can use the same name, just not the 01 API number. Sorry about the inconvenience of this, but we have about 10-15 of these in our DB. Art Edmund Burke Art Saltmarsh Sr. Petroleum Geologist Ak. Oil & Gas Conservation Commission (907)793-1230 From: Maunder, Thomas E (DOA) Sent: Wednesday, September 19, 2007 12:08 PM To: Davies, Stephen F (DOA); Saltmarsh, Arthur C (DOA) Cc: Hubble, Terrie L Subject: FW: PBU X-20A /PTD # 207-113 Gentlemen, Can you provide an answer to Terrie? Thanks, Tom From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, September 19, 2007 12:03 PM To: Maunder, Thomas E (DOA) 9/20/2007 "The only thing necessary- for the triumph of evil i~ for good men to do nothing". • Page 2 of 2 Cc; Engel, Narry R; Douglas, David W (Landmark) Subject: PBU X-20A / PTD # 207-113 Hi Tom, I need to raise the issue again on this new approved Permit to Drill. This is the well where we had previously submitted a Permit to Drill, but did not drill the well before the Permit expired. The appropriate API number (50-029-22478-01-00) was assigned to that original Permit to Drill for the sidetrack. When we submitted a new Permit to Drill (August 2007) to go ahead and sidetrack this well, I assumed that the API number would still be assigned that -01 extension, signifying that it is the first sidetrack for this well. Art Saltmarsh called to discuss this and informed me that the -01 extension can not be reused due to restrictions in the "RBDM System", therefore he changed the API number to have the -02 extension. I am uncomfortable with this extension being out of sync and feel that it will just cause lots of confusion in the future. It would seem that the "system" could be forced to make corrections for these sorts of situations. You and I have both dealt with a number of confusing NaminglAPl issues through the years, and it would seem we ought to be able to fix this now and avoid that future confusion. Is there anything that can be done? Your assistance is greatly appreciated. Thanks! Terrie 9/20/2007 • • d ~ ~ ~ ` ~ SARAH PALIN, GOVERNOR ~+~1 ~s-~~tt~~r~ ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 C~H-Sa4RQ~ii~~ COMMI$Sjp~ ANCHORAGE, ALASKA 99501-3539 ,1 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Sarber CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-661 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU X-20A BP Exploration Alaska, Inc. Permit No: 207-113 Surface Location: 349' FSL, 103' FWL, SEC. O5, T10N, R14E, UM Bottomhole Location: 4321' FNL, 1123' FEL, SEC. 12, TlON, R13E, UM Dear Mr. Sarber: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness ny required test, contact the Commission's petroleum field inspector at (9 ) 65~-3607 (pager). DATED this ~~ day of August, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI iON PERMIT TO DRILL 20 AAC 25.005 ~~.~-.~ ~~CEIV'~' ~.~~ AUG 1 4 2001 ~faska pil $ Gas Cons. Cafnrttiss~tt~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is propos prage ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU X-20A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13600 TVD 8975ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 349' FSL 103' FWL T10N R14E UM SEC 05 7. Property Designation: ADL 047472 Pool , , , , . , Top of Productive Horizon: 4126' FNL, 3912' FEL, SEC. 07, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date; September 22, 2007 Total Depth: 4321' FNL, 1123' FEL, SEC. 12, T10N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 7,410' 4b. Location of Well (State Base Plane Coordinates): Surface: x-665978 y-5940480 Zone-ASP4 10. KB Elevation (Height above GL): 68 feet 15. Distance to Nearest Well Within Pool: 830' 16. Deviated Wells: Kickoff Depth: 11270 feet Maximum Hole An le: 94 de tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3299 Surface: 2419 18. Casin Pro ram: S cificatio ns To - in De th -Bo ttom anti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" 3-3/16" x zaia" 6.2# / 6.16# L-80 TCII / STL 2550' 11050' 8898' 13600' 8975' 102 sx Class 'G' 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12964 Total Depth TVD (ft): 9004 Plugs (measured): None Effective Depth MD (ft): 12717 Effective Depth TVD (ft): 9015 Junk (measured): Yes, Unknown Casing Length Size ement Volume MD TVD Conductor /Structural 80' 20" 260 sx Arcticset A rox 110' 110' Surface 3536' 10-3/4" 1150 sx Coldset III 350 sx Class 'G' 3566' 3149' Intermediate 10925' 7-5/8" 265 sx Class'G' 10952' 8922' Prou in Liner 1899' 4-112" 320 sx Class 'G' 10821' - 12720' 8851' - 9015' Perforation Depth MD (ft): (& Slots) 11284' - 12718' Perforation Depth TVD (ft): 9009' - 9015' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that a foregoing is true and correct. Contact Greg Sarber, 564-4330 Printed Name G Sarber Title CT Drilling Engineer G Prepared By Name/Number: Si nature Phone 564-4330 Date O S ~~L Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: o~Dy~//~j'0 API Number: 50-029-22478-0 -00 Permit A proval See cover letter for Date: ~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ,../ ~~~ ` ~,3v~ ~'`~~' • M ~~ • ~., Samples Req'd: Yes ~No Mud Log Req'd: Yes I]0 No V ~~~,,,,~~-~ O ~Cr''Ot~Uh~S~~n.C~C~C'D~ v.J I A~©~ HZS Measures: ~ Y irecti al Survey Req'd: ~ Yes ^ No Other: p I PROVED BY THE COMMISSION Date ~ / ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Dupli to 1 ORIGIN,[ by BP Prudhoe Bay X-20Ai CTD Sidetrack August 13, 2007 CTD Sidetrack Summary Pre-Rig Work: 1. O Functions test LDS 2. O PPPOT-T, IC 3. S Drift to top perforation at 11,284'. Recover IBP element fish if needed. 4. C Pump cement P&A on existing perforations/slotted liner. 5. S Drift to top of cement plug, and for chemical cut in 4-1/2" tubing. 6. C If needed, under ream cement below 11,280' for whipstock placement. 7. E Chemical cut at 10,710', (Middle of first full joint above the pkr) 8. O CMIT T x IA to 3500 psi. MIT OA to 2000 psi. 9. O Load T and IA with seawater circ thru Chem cut and FP T & IA to 2000' with diesel. 10. O Bleed T, IA, OA to zero. 11. O Set BPV 12. O Bleed production flow lines and GL lines down to zero and blind flange 13. O Remove wellhouse, level pad Rig Workover Operations: (Scheduled to begin on September 15, 2007) 1. MIRU Nordic rig #2, pull BPV. 2. Circulate well to clean KWF thru tubing cut, set TWC. 3. ND tree, NU BOPE and test. Pull TWC 4. Pull old 4-1/2" L-80 production tubing from chemical cut at 10,710'. 5. RU Slickline. Make 8-1/2" gauge ring junk basket and LIB runs. 6. Begin running new 4-1/2" completion below Haliburton RTTS storm packer. 7. Set storm packer. 8. Replace IC Packoffs 9. Retrieve storm packer. 10. Continue running 4-1/2" L-80, TCII tubing string with new 7-5/8" packer, Unique overshot. Packer 10,640'. 11. Space out. Circ Inhibited brine and diesel freeze protect into IA and tubing. e~ 12. Set packer. Test IA and Tubing. ~~ l ' c~ ~Q 13. Set TWC. ND BOPE, NU Production tree and test. Rig Sidetrack Operations: (Scheduled to begin on September 22, 2007) 1. NU 7-1/16" CT Drilling BOPE and test. 2. RU Slickline. Retrieve ball and rod, RHC plug. 3. RU E-line. RIH, set whipstock with top at -11,270'. 4. Mill 3.80" window at 11,270'. 5. Drill build/turn section with 3.75" x 4.125" bicenter bit, and land well. 6. Drill lateral section to 13,600'. 7. Run and cement a 2-7/8" x 3-3/16" L-80 liner string. 8. Make a cleanout run with mill and motor and SWS GR-CCL logging tool. 9. Perforate well. 10. Pump bleach treatment across perforation interval to break mud polymer. 11. Circulate well to KWF brine above liner top. FP well to 2000' with diesel. 12. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 13. RDMO Nordic 2. ~,.~~~ Post-Rig Work: 1. Re-install wellhouse and FL'S~ 2. Pull BPV. 3. POP well Mud Program: • Well kill: 8.4 ppg brine. • Workover: 8.4 ppg brine. With biozan sweeps • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.7 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.75"x4-1 /8" (bi-center bits used) Casing Program: fully cemented liner • 3-3/16", L-80 6.2# TCII 11,050' and - 11,600' and • 2-7/8", L-80 6.16# STL 11,600'md -13,600'md • A minimum of 21 bbls 15.8 ppg cement will be used for liner cementing. (Assuming TD @ 13,600', and planning on 40% excess in the 3.75" and 4.125" open hole interval) • TOC planned at 11,050' (Top of liner). Existing casinst/tubing Information 10-3/4", NT-80 45.5#, Burst 5210, collapse 2480 psi 7 5/8", NT-95 29.7#, Burst 6890, collapse 4790 psi 4-1/2", L-80 12.6#, Burst 8430, collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 93.77 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property- 7,410 ft. • Distance to nearest well within pool - 830 ft. (X-22A) Logging • MWD directional, Gamma Ray, Resistivity will be run over all of the open hole section. • A cased hole GR/CCL log will be run. Hazards • The maximum recorded H2S level on X Pad is 210 ppm on well X-10. • The maximum recorded H2S level on X-20 has not been recorded. • Lost circulation risk is low. Reservoir Pressure • The max reservoir pressure was measured at 3299 psi at 8800'ss in July 2007. (7.21 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2419 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble • 4" CIW SM X 20A i P mposed C TD S ilel3ack • QATE REV BY CON1vENTS DATE REV BY COMMEMS PFdJDI-IOEBAY UNT 00!22194 M00 ORIGINALHORZCOMPLETI O 12/02/05 RWLlRH IBPSET(11l24l05) WELL. X-20 04/Oa102 -V~YTLH ECLPSE~ATCH 04/19/06 RPWPJC WANERSAFETY NOTE PERMTNo:'1940607 07/17/02 CAOliP ECL PSE TBG PATCH 10/29/06 CJWPAG R.AI BKR IBP /FISH QEMBYfS AR No: 50-029-2247&70 0123!04 SRB/KK CORRECTIONS 1122/06 TELPAG SET BKR IBP Q 10743' SEC 7, T10N, R14E 0429104 M1A/KAK SET BKR IBP 12/16106 JRR'PJC PULL IBP ~ 10743' b FISH (ELEMENTS) 07l1aAa PNEJKAK PULL BR FISH I BP lxploratlon (Alaska) Rig Floor'~6Top of Lubricator Well X-20Ai 2.25 9.23 5.00 • 12.65 •~ ~ 13.56 ~_ 2 1'16" 5000 psi . R-2a I!,,, r~.,..,- - 14.89 HC M t st5r to Top it AnnWar ? 1 `16' Annular x 5000 psi ' 1 '16" 5000 psi. RX-46 rai ~;h~=.~~ -. ;r r;r:nU•is 7 1'16" SCOC esi RX-46 Choke Line Kill Line 16.10 F- -~ ® 2 1'16" 5000 ps 16.66 ~ ~ _,:aT'ii ~ ~, ~,,, ~ 7 t 16' X 3 1'8" Flanges Adap*er T`. 20.04 ~ ''~ ~ Swab Valve Tree Size " 0 - Flow Line -- 22.88 .~ I; " SSV ,' ~ r,. 24.86 ~~ '~,~~'~ Master Valve ~~ 26.68 Lock Down Screws 31.00 ~ Ground Level • • by BP Alaska ~~ Baker Hughes INTEQ Planning Report INTE Q Compaayc BP Amoco Date: ' 8/10!2007 Time: 16:51:21 Pager 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Welh X-2Q, True'North Site:, PB X Pad Vertical (TVD) Reference: 30 ; 20 5/13/1994 00:00 68.0 Wet!: X-20 Section (VS) Reference: Well (O.OON,O.OOE;233. 32Azi) Wellpath: Plan 1, X-20A Survey Calculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordiuate System: Well Centre Sys Datnm: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB X Pad TR-10-14 UNITED STATES :North Slope Site Position: Northing: 5937417 .97 ft Latitude: 70 14 7.207 N From: Map Easting: 664667 .65 ft Longitude: 148 40 13.706 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.25 deg Well: X-20 Slot Name: 20 X-20 Well Position: +N/-S 3033.25 ft Northing: 5940480 .35 ft Latitude: 70 14 37.038 N +E/-W 1376.63 ft Easting : 665977 .63 ft Lougitude: 148 39 33.683 W Position Uncertainty: 0.00 ft Wellpath: Plan 1, X-20A Drilled Fram: X-20 Tie-on Depth: 11 245.00 ft Current Datum: 30:20 5/13/1994 00 :00 Height 68 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 8/10/2007 Declination: 23.64 deg Field Strength: 57651 nT Mag Dip Angle: 80.87 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 30.00 0.00 0.00 233.32 Plan: Date Composed: Version: Principal: Tied-to: Targets Map.. Map <---- Latitude ---> <- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting: Deg Min Sec. De$ Mia Sec Dip. Dir. ft ft ft ft ft X-20A, PIan1 Polygon 9008.00 -4286.00 -4073.27 5936106.00 662000.00 70 13 54.874 N 148 41 32.038 W -Polygon 1 9008.00 -4286.00 -4073.27 5936106.00 662000.00 70 13 54.874 N 148 41 32.038 W -Polygon 2 9008.00 -4443.67 -5362.14 5935920.00 660715.00 70 13 53.315 N 148 42 9.485 W -Polygon 3 9008.00 -4549.75 -6449.81 5935790.00 659630.00 70 13 52.264 N 148 42 41.086 W -Polygon 4 9008.00 -4833.00 -6306.01 5935510.00 659780.00 70 i3 49.479 N 148 42 36.901 W -Polygon 5 9008.00 -4818.89 -5130.33 5935550.00 660955.00 70 13 49.627 N 148 42 2.742 W -Polygon 6 9008.00 -4716.44 -3877.68 5935680.00 662205.00 70 13 50.642 N 148 41 26.349 W -Polygon 7 9008.00 -4286.00 -4073.27 5936106.00 662000.00 70 13 54.874 N 148 41 32.038 W X-20A, PIan1 Target 2 9010.00 -4601.77 -5450.65 5935760.00 660630.00 70 13 51.760 N 148 42 12.054 W X-20A, PIan1 Fault 1 9010.00 -4400.55 -5412.21 5935962.00 660664.00 70 13 53.739 N 148 42 10.941 W -Polygon 1 9010.00 -4400.55 -5412.21 5935962.00 660664.00 70 13 53.739 N 148 42 10.941 W -Polygon 2 9010.00 -4582.52 -5416.21 5935780.00 660664.00 70 13 51.949 N 148 42 11.054 W -Polygon 3 9010.00 -4913.65 -5233.45 5935453.00 660854.00 70 13 48.694 N 148 42 5.737 W -Polygon 4 9010.00 -4582.52 -5416.21 5935780.00 660664.00 70 13 51.949 N 148 42 11.054 W X-20A, PIan1 Fault A 9010.00 -4267.60 -5317.25 5936097.00 660756.00 70 13 55.047 N 148 42 8.185 W -Polygon 1 9010.00 -4267.60 -5317.25 5936097.00 660756.00 70 13 55.047 N 148 42 8.185 W -Polygon 2 9010.00 -4121.46 -4594.81 5936259.00 661475.00 70 13 56.489 N 148 41 47.195 W -Polygon 3 9010.00 -3735.84 -3800.07 5936662.00 662261.00 70 14 0.286 N 148 41 24.108 W -Polygon 4 9010.00 -4121.46 -4594.81 5936259.00 661475.00 70 13 56.489 N 148 41 47.195 W X-20A, PIan1 BHL 9043.00 -4668.47 -6282.38 5935675.00 659800.00 70 13 51.097 N 148 42 36.218 W X-20A, PIan1 Target 1 9044.00 -4504.40 -4648.25 5935875.00 661430.00 70 13 52.723 N 148 41 48.742 W • • by BP Alaska s Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 8/10/2007 Time: 16:51:21 Page: Z Field: Prudhoe Bay Co-ordiuate(NE) Reference: Welt: X-20, True North: Site: PB X Pad Vertica l (TVD) Reference: 30:20 5/13/1994 00:00 68.0 Welly X-20 Section (VS) Reference: tNeN (O.OQN,O.OOE,233.32Azi) Wellpatb: Plan 1, X-20A Survey Calculation Method:. Minimum. Curvature bb; Grade Annotation MD TVD ft ft 11245.00 9005.95 TIP- Tie on to X-20 11270.00 9008.06 KOP 11290.00 9009.26 3 11310.00 9009.66 4 11410.00 9013.07 5 11575.00 9024.85 6 11825.00 904121 7 11925.00 9044.23 8 12025.00 9040.97 9 12450.00 9016.54 10 12750.00 9010.00 11 12850.00 9012.63 12 13250.00 9031.46 13 13600.00 9042.81 TD Plan Section Information MD Incl. Azim TVD +N/-S +E/-W DIS Bnild Turn TFO Target Survey MD Ind A7rm SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg tt ft ft ft ft degN OOft ft deg 30.00 0.00 0.00 -38.00 0.00 0.00 5940480.35 665977.63 0.00 0.00 0.00 TIE LI 98.20 0.50 262.50 30.20 -0.04 -0.30 5940480.30 665977.33 0.73 0.26 0.00 MWD 195.20 0.30 97.30 127.20 -0.13 -0.46 5940480.21 665977.17 0.82 0.45 185.54 MWD 287.20 0.60 60.00 219.20 0.08 0.19 5940480.44 665977.82 0.44 -0.21 295.99 MWD 379.20 0.70 73.70 311.19 0.48 1.15 5940480.86 665978.76 0.20 -1.21 64.22 MWD 472.20 1.20 222.50 404.18 -0.08 1.04 5940480.30 665978.66 1.97 -0.79 160.20 MWD 564.20 3.70 214.50 496.09 -3.23 -1.30 5940477.09 665876.40 2.74 2.97 348.20 MWD 656.20 6.20 190.80 587.75 -10.56 -3.91 5940469.70 665973.95 3.46 9.44 308.50 MWD 748.20 9.10 179.20 678.93 -22.72 -4.74 5940457.53 665973.39 3.56 17.37 326.13 MWD 841.20 11.20 175.30 770.47 -39.08 -3.90 5940441.20 665974.59 2.37 26.47 339.95 MWD 934.20 12.40 171.50 861.50 -57.95 -1.68 5940422.37 665977.22 1.54 35.97 325.20 MWD 1027.20 14.20 170.10 952.00 -79.07 1.76 5940401.34 665981.12 1.97 45.82 349.17 MWD 1119.20 16.50 170.10 1040.72 -103.06 5.95 5940377.45 665985.84 2.50 56.79 0.00 MWD 1212.20 17.50 170.40 1129.65 -129.86 10.55 5940350.76 665991.03 1.08 69.11 5.16 MWD 1303.20 20.70 173.60 1215.63 -159.34 14.62 5940321.38 665995.75 3.70 83.45 19.64 MWD 1397.20 22.70 177.50 1302.97 -193.97 17.27 5940286.82 665999.16 2.62 102.02 37.62 MWD 1490.20 25.80 174.60 1387.76 -232.06 19.96 5940248.80 666002.68 3.57 122.62 337.65 MWD 1582.20 27.20 172.90 1470.09 -272.86 24.44 5940208.11 666008.06 1.73 143.39 330.79 MWD 1676.20 29.80 175.70 1552.70 -317.48 28.85 5940163.60 666013.45 3.11 166.51 28.43 MWD 1769.20 29.80 177.10 1633.40 -363.60 31.75 5940117.56 666017.37 0.75 191.74 90.61 MWD 1859.20 31.60 179.20 1710.79 -409.52 33.21 5940071.68 666019.84 2.33 217.99 31.69 MWD 1952.20 33.20 178.50 1789.31 -459.34 34.22 5940021.90 666021.94 1.77 246.95 346.51 MWD 2045.20 33.70 179.90 1866.90 -510.60 34.93 5939970.68 666023.78 0.99 276.99 57.65 MWD 2135.20 35.20 184.10 1941.13 -561.45 33.12 5939919.81 666023.09 3.12 308.82 59.48 MWD 2228.20 36.10 184.80 2016.70 -615.49 28.91 5939865.69 666020.08 1.06 344.47 24.67 MWD 2321.20 35.90 184.10 2091.94 -669.98 24.66 5939811.12 666017.03 0.49 380.43 243.79 MWD 2414.20 36.10 189.10 2167.19 -724.25 18.38 5939756.73 666011.95 3.17 417.88 88.13 MWD 2506.20 36.70 190.50 2241.24 -778.04 9.08 5939702.75 666003.84 1.11 457.47 54.73 MWD 2599.20 36.80 195.00 2315.77 -832.28 -3.19 5939648.26 665992.76 2.90 499.72 89.68 MWD 2691.20 37.30 202.40 2389.24 -884.69 -20.96 5939595.47 665976.16 4.87 545.27 86.56 MWD 2783.20 36.60 207.30 2462.78 -934.85 -44.16 5939544.82 665954.06 3.29 593.84 105.32 MWD 2876.20 36.70 211.90 2537.40 -983.09 -71.57 5939495.99 665927.73 2.95 644.64 89.76 MWD 2969.20 36.70 217.90 2611.99 -1028.62 -103.33 5939449.77 665896.97 3.85 697.32 92.41 MWD • • by BP Alaska r Baker Hughes INTEQ Planning Report 1NTE Q CompaoyE BP Amoco Date: 8/10/2007 Time: 16:51::21 :`Page: 3 Field; Prudhoe Bay Co-ordinate(NE) Reference: Well: X-20, True North Site: PB X Pad Vertiea l (1'VD) Reference: 30 : 2U 5/13/1994A0:00 68 .0 Well: X-20 Section (VS) Reference: Well (O.OON,OAOE,233.32Azi) Wellpath5 .. Pla n 1, X-20A Survey Caknlation Method: Minimum. Curvature Db: Orade Survey MD Incl Azim SS TVI) IY/S FJW MapN MapE DL5 VS TFO Toel 'ft deg deg ft ft ft ft ft deg/100ft ft deg 3067.20 38.00 220.00 2689.90 -1074.84 -140. 72 5939402.74 665860.62 1.86 754.91 45.26 MWD 3154.20 39.10 223.90 2757.95 -1115.13 -176. 96 5939361.66 665825.27 3.07 808.04 67.18 MWD 3247.20 38.80 229.80 2830.30 -1155.09 -219. 57 5939320.79 665783.56 4.00 866.07 96.92 MWD 3340.20 38.40 229.10 2902.98 -1192.80 -263. 65 5939282.11 665740.32 0.64 923.96 227.24 MWD 3432.20 38.10 230.20 2975.23 -1229.68 -307. 06 5939244.29 665697.74 0.81 980.80 114.21 MWD 3504.20 37.90 228.80 3031.97 -1258.47 -340. 76 5939214.77 665664.68 1.23 1025.03 256.39 MWD 3593.20 37.90 230.20 3102.20 -1293.97 -382. 33 5939178.36 665623.90 0.97 1079.57 90.55 MWD 3614.20 38.00 230.20 3118.76 -1302.24 -392. 26 5939169.88 665614.17 0.48 1092.47 0.00 MWD 3706.20 38.00 229.50 3191.25 -1338.76 -435. 55 5939132.42 665571.69 0.47 1149.00 269.72 MWD 3798.20 37.70 229.50 3263.90 -1375.42 -478. 47 5939094.82 665529.59 0.33 1205.33 180.00 MWD 3891.20 37.90 229.50 3337.38 -1412.44 -521. 82 5939056.86 665487.07 0.22 1262.20 0.00 MWD 3984.20 38.00 228.80 3410.72 -1449.85 -565. 08 5939018.51 665444.65 0.48 1319.24 282.80 MWD 4075.20 38.20 227.70 3482.33 -1487.24 -606. 97 5938980.21 665403.59 0.78 1375.17 285.99 MWD 4168.20 38.10 228.10 3555.47 -1525.75 -649. 59 5938940.77 665361.83 0.29 1432.36 112.19 MWD 4260.20 37.90 227.40 3627.96 -1563.83 -691. 52 5938901.77 665320.76 0.52 1488.74 244.83 MWD 4353.20 38.10 228.40 3701.25 -1602.22 -734. 00 5938862.47 665279.13 0.70 1545.74 72.40 MWD 4446.20 38.30 228.10 3774.33 -1640.52 -776. 91 5938823.24 665237.08 0.29 1603.02 317.03 MWD 4537.20 38.10 226.70 3845.85 -1678.60 -818. 33 5938784.25 665196.51 0.98 1658.99 256.44 MWD 4628.20 38.20 227.70 3917.41 -1716.79 -859. 58 5938745.16 665156.12 0.69 1714.88 81.20 MWD 4721.20 38.10 227.00 3990.55 -1755.72 -901. 83 5938705.32 665114.74 0.48 1772.02 256.70 MWD 4814.20 38.10 228.10 4063.73 -1794.45 -944. 17 5938665.67 665073.26 0.73 1829.11 90.43 MWD 4905.20 37.40 228.40 4135.68 -1831.54 -985. 73 5938627.67 665032.53 0.80 1884.61 165.42 MWD 4997.20 36.50 227.70 4209.21 -1868.51 -1026. 86 5938589.81 664992.22 1.08 1939.67 204.78 MWD 5090.20 35.90 228.10 4284.25 -1905.33 -1067. 62 5938552.10 664952.29 0.69 1994.35 158.67 MWD 5183.20 36.60 227.00 4359.25 -1942.45 -1108 .19 5938514.10 664912.55 1.03 2049.06 316.66 MWD 5277.20 36.80 227.40 4434.62 -1980.62 -1149. 41 5938475.04 664872.19 0.33 2104.92 50.24 MWD 5369.20 37.00 228.80 4508.19 -2017.51 -1190 .52 5938437.25 664831.90 0.94 2159.93 77.18 MWD 5461.20 36.70 229.10 4581.81 -2053.74 -1232 .13 5938400.12 664791.10 0.38 2214.94 149.17 MWD 5554.20 36.20 228.80 4656.62 -2090.03 -1273 .80 5938362.92 664750.24 0.57 2270.03 199.50 MWD 5646.20 36.10 227.00 4730.91 -2126.41 -1314 .06 5938325.67 664710.79 1.16 2324.06 263.89 MWD 5738.20 36.60 227.70 4805.01 -2163.35 -1354. 17 5938287.85 664671.51 0.71 2378.29 39.97 MWD 5829.20 36.60 227.40 4878.06 -2199.97 -1394. 20 5938250.36 664632.30 0.20 2432.27 269.88 MWD 5921.20 37.00 226.70 4951.73 -2237.52 -1434. 54 5938211.94 664592.80 0.63 2487.05 313.37 MWD 6013.20 37.00 226.30 5025.20 -2275.63 -1474. 70 5938172.95 664553.49 0.26 2542.03 269.84 MWD 6107.20 37.00 226.30 5100.28 -2314.72 -1515. 60 5938132.98 664513.46 0.00 2598.17 180.00 MWD 6198.20 37.80 226.70 5172.57 -2352.76 -1555 .69 5938094.07 664474.22 0.92 2653.05 17.05 MWD 6291.20 38.40 227.40 5245.75 -2391.86 -1597 .70 5938054.06 664433.09 0.79 2710.09 36.03 MWD 6383.20 38.90 226.70 5317.60 -2431.01 -1639 .75 5938013.99 664391.91 0.72 2767.21 318.56 MWD 6474.20 38.90 227.70 5388.42 -2469.83 -1681 .68 5937974.25 664350.85 0.69 2824.02 90.39 MWD 6568.20 37.90 225.30 5462.09 -2510.01 -1724 .03 5937933.16 664309.39 1.91 2881.99 235.21 MWD 6663.20 38.10 223.50 5536.96 -2551.79 -1764 .95 5937890.49 664269.41 1.19 2939.77 279.52 MWD 6758.20 37.40 222.80 5612.07 -2594.22 -1804 .73 5937847.19 664230.58 0.86 2997.01 211.20 MWD 6853.20 35.00 223.90 5688.73 -2635.03 -1843 .23 5937805.55 664192.99 2.62 3052.26 165.30 MWD 6949.20 34.00 223.20 5767.84 -2674.44 -1880 .69 5937765.33 664156.40 1.12 3105.85 201.34 MWD 7044.20 33.30 223.90 5846.93 -2712.59 -1916 .96 5937726.39 664120.99 0.84 3157.72 151.30 MWD 7138.20 33.60 222.10 5925.36 -2750.48 -1952 .29 5937687.73 664086.50 1.10 3208.69 286.07 MWD 7232.20 33.90 223.90 6003.52 -2788.67 -1987 .91 5937648.77 664051.74 1.11 3260.07 74.05 MWD 7327.20 34.30 222.80 6082.18 -2827.40 -2024 .46 5937609.25 664016.05 0.77 3312.52 302.51 MWD 7420.20 34.20 223.20 6159.06 -2865.68 -2060 .16 5937570.20 663981.20 0.26 3364.02 114.12 MWD 7512.20 34.50 222.80 6235.01 -2903.65 -2095 .56 5937531.46 663946.65 0.41 3415.09 322.88 MWD 7606.20 34.90 222.80 6312.29 -2942.91 -2131 .92 5937491.41 663911.17 0.43 3467.70 0.00 MWD 7701.20 34.70 222.50 6390.30 -2982.79 -2168 .65 5937450.74 663875.32 0.28 3520.98 220.44 MWD • • by BP Alaska ~~S Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: .8/1.0/2007 Time: 16:51:21 Page: 4 Field; Prudhoe Bay Co-ordioate(NE) Reference:: Well; X-20, True North Site: PB X Pad Vertical (TVD) Reference: 30:20 5/13/1994 00:00 68 .0 Well: X-20 Section (VS) Reference: Well (O.OON,O.OOE,233.32Az~ Wellpatb: Plan 1, X-20A Survey Caknlation Metbod: Minimum Curvature Db: :Orate Survey MD Incl Azim SS TVD N/S E/W MapN MxpE DLS VS TFO Tool ft deg _ deg ft tt ft ft ft deg/100ft ft_ deg. 7795.20 34.70 223.50 6467.59 -3021.92 -2205.15 5937410.81 663839.70 0.61 3573.63 90.41 MWD 7889.20 35.30 224.20 6544.59 -3060.80 -2242.50 5937371.12 663803.22 0.77 3626.81 34.08 MWD 7984.20 35.50 225.30 6622.02 -3099.88 -2281.24 5937331.20 663765.35 0.70 3681.22 73.02 MWD 8077.20 35.60 225.60 6697.69 -3137.81 -2319.78 5937292.43 663727.66 0.22 3734.78 60.30 MWD 8172.20 35.70 224.20 6774.89 -3177.03 -2358.86 5937252.37 663689.46 0.87 3789.55 276.42 MWD 8265.20 36.00 226.00 6850.27 -3215.47 -2397.44 5937213.09 663651.73 1.18 3843.45 74.85 MWD 8358.20 36.80 227.40 6925.13 -3253.31 -2437.60 5937174.37 663612.41 1.24 3898.27 46.65 MWD 8453.20 37.30 227.00 7000.95 -3292.21 -2479.60 5937134.57 663571.29 0.58 3955.18 334.11 MWD 8545.20 37.40 226.30 7074.08 -3330.52 -2520.19 5937095.37 663531.56 0.47 4010.62 282.97 MWD 8639.20 37.40 226.30 7148.76 -3369.96 -2561.46 5937055.03 663491.16 0.00 4067.29 0.00 MWD 8731.20 37.40 227.00 7221.84 -3408.32 -2602.10 5937015.79 663451.39 0.46 4122.79 90.28 MWD 8825.20 37.80 226.70 7296.32 -3447.55 -2643.94 5936975.66 663410.42 0.47 4179.77 335.29 MWD 8919.20 38.00 228.10 7370.49 -3486.63 -2686.44 5936935.65 663368.79 0.94 4237.20 77.46 MWD 9015.20 37.40 228.80 7446.45 -3525.57 -2730.37 5936895.76 663325.73 0.77 4295.70 144.77 MWD 9110.20 36.60 228.80 7522.32 -3563.23 -2773.39 5936857.16 663283.56 0.84 4352.69 180.00 MWD 9204.20 36.50 228.10 7597.84 -3600.36 -2815.28 5936819.12 663242.49 0.46 4408.47 256.23 MWD 9299.20 36.20 230.20 7674.35 -3637.18 -2857.87 5936781.37 663200.73 1.35 4464.62 104.40 MWD 9394.20 36.10 228.80 7751.06 -3673.58 -2900.48 5936744.05 663158.93 0.88 4520.53 262.53 MWD 9489.20 36.00 230.50 7827.87 -3709.77 -2943.08 5936706.93 663117.14 1.06 4576.32 96.39 MWD 9584.20 36.20 229.80 7904.63 -3745.64 -2986.05 5936670.13 663074.97 0.48 4632.21 295.59 MWD 9678.20 37.20 231.60 7980.00 -3781.21 -3029.53 5936633.61 663032.30 1.56 4688.32 47.81 MWD 9773.20 37.50 232.30 8055.52 -3816.73 -3074.91 5936597.10 662987.71 0.55 4745.94 55.04 MWD 9867.20 38.10 233.40 8129.80 -3851.52 -3120.84 5936561.31 662942.57 0.96 4803.55 48.77 MWD 9960.20 38.90 233.00 8202.58 -3886.20 -3167.19 5936525.62 662896.99 0.90 4861.44 342.55 MWD 10053.20 42.70 232.70 8272.97 -3922.89 -3215.61 5936487.87 662849.39 4.09 4922.19 356.93 MWD 10148.20 45.10 234.10 8341.41 -3962.15 -3268.50 5936447.46 662797.38 2.73 4988,06 22.53 MWD 10243.20 45.80 233.70 8408.06 -4002.04 -3323.20 5936406.38 662743.58 0.80 5055.76 337.70 MWD 10336.20 46.10 233.70 8472.72 -4041.61 -3377.07 5936365.63 662690.60 0.32 5122.60 0.00 MWD 10431.20 47.70 236.50 8537.64 -4081.27 -3433.96 5936324.73 662634.60 2.73 5191.91 52.92 MWD 10528.20 48.90 236.20 8602.16 -4121.40 -3494.25 5936283.29 662575.21 1.26 5264.23 349.33 MWD 10622.20 51.40 235.80 8662.39 -4161.76 -3554.07 5936241.63 662516.30 2.68 5336.31 352.87 MWD 10718.20 52.60 234.80 8721.50 -4204.83 -3616.26 5936197.20 662455.08 1.50 5411.92 326.40 MWD 10812.20 54.40 234.40 8777.41 -4248.60 -3677.85 5936152.09 662394.47 1.95 5487.46 349.75 MWD 10899.20 57.20 235.10 8826.30 -4290.12 -3736.61 5936109.29 662336.64 3.29 5559.38 11.88 MWD 10900.00 57.20 235.09 8826.74 -4290.50 -3737.16 5936108.89 662336.10 1.00 5560.05 302.79 MWD 10935.00 58.40 235.10 8845.39 -4307.45 -3761.45 5936091.42 662312.19 3.42 5589.66 0.33 MWD 10954.20 57.50 234.55 8855.57 -4316.82 -3774.75 5936081.75 662299.10 5.28 5605.92 207.24 MWD 10960.00 57.15 234.71 8858.71 -4319.65 -3778.73 5936078.84 662295.18 6.51 5610.80 159.72 MWD 10965.00 59.50 234.80 8861.33 -4322.11 -3782.21 5936076.31 662291.76 47.11 5615.06 1.97 MWD 10996.00 62.90 234.90 8876.26 -4337.74 -3804.41 5936060.19 662269.91 10.97 5642.21 1.50 MWD 11026.00 66.60 235.20 8889.06 -4353.28 -3826.65 5936044.16 662248.02 12.37 5669.33 4.26 MWD 11059.00 70.30 235.30 8901.18 -4370.77 -3851.87 5936026.12 662223.20 11.22 5700.00 1.46 MWD 11089.00 74.30 234.80 8910.30 -4387.14 -3875.29 5936009.24 662200.15 13.43 5728.56 353.13 MWD 11119.00 76.80 235.10 8917.78 -4403.83 -3899.07 5935992.04 662176.74 8.39 5757.60 6.67 MWD 11149.00 78.30 234.90 8924.25 -4420.63 -3923.06 5935974.71 662153.12 5.04 5786.88 352.56 MWD 11180.00 80.70 234.70 8929.90 -4438.20 -3947.97 5935956.60 662128.61 7.77 5817.34 355.30 MWD 11213.00 83.20 236.00 8934.52 -4456.77 -3974.85 5935937.44 662102.15 8.52 5850.00 27.34 MWD 11245.00 84,50 234:30 8937.95 -4474.95 -4000.95 5935918.69 662076.45 6.66 5881.79 307.47 TIP- Ti 11250.00 84.76 234.49 8938.42 -4477.85 -4005.00 5935915.71 662072.47 6.45 5886.77 36.88 MWD 11270.00 85.79 235.27 8940.06 -4489.32 -4021.30 5935903.88 662056.42 6.45 5906.69 36.87 KOP 11290.00 87.35 236.17 8941.26 -4500.56 -4037.80 5935892.28 662040.18 9.00 5926.64 30.00 3 11300.00 88.85 238.77 8941.59 -4505.93 -4046.23 5935886.72 662031.87 30.00 5936.61 60.00 MWD 11310.00 90.36 241.36 8941.66 -4510.92 -4054.89 5935881.54 662023.32 30.00 5946.54 59.91 4 • • by BP Alaska $ Baker Hughes INTEQ Planning Report INTE Q Company: BP Amoco Date: 8/10/2007 Time: 1fi:51:21 Paler 5 Field: Prudhoe $ay Co-ordinate(NE) References WeII: X-20, True North Site: PB X Pad Vertical (TVD) Reference: 30:20 5113!1994 00:00 68.0 We1L X-20 Sectioe wS) Reference: Well (O.OON,O.OOE,233.32Azi) Wellpath: Pla n 1, X-20A Survey Calculation Method: Minimum. Curvature ' Db: Orade Survey MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO Toof ft deg deg ft ft ft ft ft deg/100ft ft deg 11320.00 89.89 244.33 8941.64 -4515.49 -4063.79 5935876.79 662014.53 30.00 5956.40 99.00 MWD 11330.00 89.42 247.29 8941.70 -4519.58 -4072.91 5935872.49 662005.50 30.00 5966.16 99.01 MWD 11340.00 88.95 250.25 8941.84 -4523.20 -4082.23 5935868.67 661996.26 30.00 5975.80 98.99 MWD 11350.00 88.48 253.22 8942.07 -4526.34 -4091.72 5935865.32 661986.84 30.00 5985.28 98.95 MWD 11360.00 88.02 256.18 8942.37 -4528.97 -4101.36 5935862.48 661977.26 30.00 5994.59 98.88 MWD 11370.00 87.57 259.15 8942.76 -4531.11 -4111.12 5935860.13 661967.55 30.00 6003.69 98.79 MWD 11380.00 87.12 262.12 8943.22 -4532.73 -4120.98 5935858.29 661957.74 30.00 6012.56 98.68 MWD 11390.00 86.68 265.09 8943.76 -4533.84 -4130.90 5935856.96 661947.84 30.00 6021.19 98.54 MWD 11400.00 86.25 268.07 8944.38 -4534.44 -4140.86 5935856.14 661937.90 30.00 6029.53 98.38 MWD 11410.00 85.82 271.04 8945.07 -4534.52 -4150.84 5935855.85 661927.93 30.00 6037.58 98.19 5 11425.00 85.83 272.85 8946.16 -4534.01 -4165.79 5935856.02 661912.97 12.00 6049.26 90.00 MWD 11450.00 85.84 275.86 8947.98 -4532.12 -4190.65 5935857.37 661888.08 12.00 6068.07 89.87 MWD 11475.00 85.86 278.87 8949.79 -4528.92 -4215.37 5935860.02 661863.29 12.00 6085.99 89.65 MWD 11500.00 85.90 281.87 8951.59 -4524.43 -4239.90 5935863.96 661838.67 12.00 6102.98 89.43 MWD 11525.00 85.94 284.88 8953.37 -4518.67 -4264.15 5935869.20 661814.29 12.00 6118.99 89.22 MWD 11550.00 86.00 287.89 8955.12 -4511.63 -4288.08 5935875.70 661790.22 12.00 6133.97 89.00 MWD 11575.00 86.07 290.89 8956.85 -4503.35 -4311.60 5935883.46 661766.53 12.00 6147.89 88.79 6 11600.00 86.08 287.89 8958.56 -4495.07 -4335.12 5935891.22 661742.83 12.00 6161.81 270.00 MWD 11625.00 86.09 284.88 8960.27 -4488.04 -4359.05 5935897.72 661718.75 12.00 6176.80 270.21 MWD 11650.00 86.12 281.87 8961.97 -4482.27 -4383.31 5935902.96 661694.37 12.00 6192.81 270.41 MWD 11675.00 86.16 278.87 8963.65 -4477.78 -4407.85 5935906.91 661669.75 12.00 6209.80 270.62 MWD 11700.00 86.20 275.86 8965.32 -4474.58 -4432.58 5935909.56 661644.95 12.00 6227.73 270.82 MWD 11725.00 86.26 272.85 8966.96 -4472.69 -4457.45 5935910.90 661620.04 12.00 6246.55 271.02 MWD 11750.00 86.33 269.85 8968.58 -4472.10 -4482.39 5935910.94 661595.10 12.00 6266.19 271.22 MWD 11775.00 86.41 266.84 8970.16 -4472.82 -4507.33 5935909.67 661570.19 12.00 6286.62 271.41 MWD 11800.00 86.50 263.84 8971.71 -4474.85 -4532.19 5935907.10 661545.37 12.00 6307,78 271.60 MWD 11825.00 86.60 260.84 8973.21 -4478.17 -4556.92 5935903.23 661520.72 12.00 6329.60 271.79 7 11850.00 87.43 257.95 8974.51 -4482.77 -4581.46 5935898.09 661496.30 12.00 6352.02 286.00 MWD 11875.00 88.27 255.07 8975.45 -4488.60 -4605.75 5935891.73 661472.14 12.00 6374.98 286.15 MWD 11900.00 89.11 252.19 8976.03 -4495.64 -4629.73 5935884.16 661448.33 12.00 6398.42 286.26 MWD 11925.00 89.95 249.31 8976.23 -4503.89 -4653.32 5935875.40 661424.92 12.00 6422.27 286.32 8 11950.00 90.91 246.46 8976.04 -4513.30 -4676.48 5935865.49 661401.98 12.00 6446.46 288.70 MWD 11975.00 91.87 243.62 8975.43 -4523.84 -4699.14 5935854.45 661379.56 12.00 6470.93 288.68 MWD 12000.00 92.83 240.77 8974.41 -4535.49 -4721.23 5935842.31 661357.73 12.00 6495.61 288.61 MWD 12025.00 93.77 237.92 8972.97 -4548.21 -4742.70 5935829.12 661336.55 12.00 6520.42 288.49 9 12050.00 93.77 240.93 8971.32 -4560.90 -4764.18 5935815.97 661315.36 12.00 6545.23 90.00 MWD 12075.00 93.75 243.94 8969.68 -4572.44 -4786.29 5935803.94 661293.51 12.00 6569.85 90.20 MWD 12100.00 93.73 246.94 8968.05 -4582.81 -4808.97 5935793.08 661271.06 12.00 6594.24 90.40 MWD 12125.00 93.69 249.95 8966.43 -4591.97 -4832.17 5935783.40 661248.06 12.00 6618.32 90.59 MWD 12150.00 93.65 252.95 8964.83 -4599.91 -4855.83 5935774.95 661224.60 12.00 6642.03 90.79 MWD 12175.00 93.59 255.96 8963.26 -4606.59 -4879.86 5935767.74 661200.72 12.00 6665.30 90.98 MWD 12200.00 93.52 258.97 8961.70 -4612.01 -4904.21 5935761.79 661176.49 12.00 6688.06 91.17 MWD 12225.00 93.45 261.97 8960.18 -4616.14 -4928.82 5935757.12 661151.98 12.00 6710.27 91.35 MWD 12250.00 93.36 264.97 8958.70 -4618.98 -4953.61 5935753.73 661127.26 12.00 6731.84 91.54 MWD 12275.00 93.27 267.98 8957.25 -4620.51 -4978.52 5935751.65 661102.39 12.00 6752.74 91.72 MWD 12300.00 93.17 270.98 8955.85 -4620.74 -5003.48 5935750.88 661077.45 12.00 6772.89 91.89 MWD 12325.00 93.05 273.98 8954.49 -4619.66 -5028.41 5935751.41 661052.50 12.00 6792.24 92.06 MWD 12350.00 92.93 276.98 8953.19 -4617.27 -5053.26 5935753.24 661027.60 12.00 6810.74 92.22 MWD 12375.00 92.80 279.99 8951.94 -4613.59 -5077.95 5935756.38 661002.84 12.00 6828.35 92.38 MWD 12400.00 92.67 282.99 8950.74 -4608.62 -5102.42 5935760.82 660978.27 12.00 6845.00 92.53 MWD 12425.00 92.52 285.99 8949.61 -4602.37 -5126.60 5935766.53 660953.96 12.00 6860.66 92.67 MWD 12450.00 92.37 288.98 8948.54 -4594.87 -5150.42 5935773.50 660929.98 12.00 6875.28 92.81 10 • • b BP Alaska B ~ P Baker. Hughes INTEQ Planning Report 1!NTEQ Company: BP Amoco Dater SNO/2007 Time: 16:53::21 Page: 6 Fields 1?rudhoe Bay Co-ordiuate(NE) Referet-ce: We11: X-20, True North Site: PB X Pad Vertical ('f VD) Reference: 30 ; 20 5/13/1994 00:00 68.0 Well: X-20 Sectio n (VS) Referenct: WeN (t)OON,O.OO E,233:32Azi) Wellpath: Plan 1, X-20A Survey Calculation Method:. Minimum Curvature Db: Orade Survey MD . Ind Azim SS TVD N/S E/W MapN Map& DIS VS TFO Tool- ft deg deg ft ft ft ft ft deg/100ft ft deg 12475.00 92.20 285.99 8947.54 -4587.36 -5174.24 5935780.48 660906.00 12.00 6889.90 266.80 MWD 12500.00 92.03 282.99 8946.62 -4581.11 -5198.43 5935786.20 660881.68 12.00 6905.56 266.68 MWD 12525.00 91.85 279.99 8945.77 -4576.14 -5222.91 5935790.63 660857.10 12.00 6922.23 266.57 MWD 12550:00 91.66 277.00 8945.01 -4572.44 -5247.62 5935793.78 660832.32 12.00 6939.84 266.47 MWD 12575.00 91.47 274.00 8944.33 -4570.05 -5272.50 5935795.63 660807.40 12.00 6958.36 266.38 MWD 12600.00 91.27 271.01 8943.73 -4568.96 -5297.46 5935796.17 660782.41 12.00 6977.73 266.30 MWD 12625.00 91.07 268.01 8943.22 -4569.17 -5322.45 5935795.41 660757.44 12.00 6997.89 266.22 MWD 12650.00 90.87 265.02 8942.80 -4570.69 -5347.40 5935793.34 660732.53 12.00 7018.81 266.16 MWD 12675.00 90.66 262.03 8942.46 -4573.51 -5372.24 5935789.97 660707.76 12.00 7040.41 266.11 MWD 12700.00 90.46 259.04 8942.22 -4577.62 -5396.89 5935785.32 660683.21 12.00 7062.64 266.07 MWD 12725.00 90.25 256.04 8942.06 -4583.01 -5421.30 5935779.39 660658.93 12.00 7085.44 266.04 MWD 12750.00 90.04 253.05 8942.00 -4589.67 -5445.39 5935772.20 660634.99 12.00 7108.74 266.02 11 12775.00 89.27 250.15 8942.15 -4597.56 -5469.11 5935763.79 660611.45 12.00 7132.47 255.00 MWD 12800.00 88.49 247.25 8942.64 -4606.64 -5492.40 5935754.21 660588.37 12.00 7156.57 255.02 MWD 12825.00 87.72 244.35 8943.47 -4616.88 -5515.19 5935743.47 660565.81 12.00 7180.96 255.07 MWD 12850.00 86.96 241.45 8944.63 -4628.26 -5537.41 5935731.61 660543.84 12.00 7205.58 255.17 12 12875.00 86.96 244.45 8945.95 -4639.61 -5559.65 5935719.77 660521.87 12.00 7230.20 90.00 MWD 12900.00 86.97 247.46 8947.28 -4649.78 -5582.44 5935709.10 660499.30 12.00 7254.55 89.84 MWD 12925.00 86.99 250.46 8948.59 -4658.74 -5605.74 5935699.62 660476.21 12.00 7278.59 89.68 MWD 12950.00 87.02 253.46 8949.90 -4666.47 -5629.48 5935691.37 660452.65 12.00 7302.24 89.52 MWD 12975.00 87.06 256.47 8951.19 -4672.95 -5653.58 5935684.37 660428.69 12.00 7325.45 89.37 MWD 13000.00 87.11 259.47 8952.46 -4678.15 -5678.00 5935678.63 660404.40 12.00 7348.14 89.21 MWD 13025.00 87.16 262.47 8953.71 -4682.07 -5702.66 5935674.17 660379.84 12.00 7370.25 89.06 MWD 13050.00 87.22 265.48 8954.94 -4684.69 -5727.49 5935671.01 660355.07 12.00 7391.73 88.91 MWD 13075.00 87.29 268.48 8956.14 -4686.00 -5752.42 5935669.14 660330.18 12.00 7412.51 88.76 MWD 13100.00 87.36 271.48 8957.30 -4686.01 -5777.39 5935668.58 660305.21 12.00 7432.54 88.62 MWD 13125.00 87.45 274.48 8958.43 -4684.71 -5802.33 5935669.33 660280.26 12.00 7451.77 88.48 MWD 13150.00 87.54 277.48 8959.53 -4682.11 -5827.17 5935671.39 660255.37 12.00 7470.13 88.34 MWD 13175.00 87.64 280.49 8960.58 -4678.21 -5851.83 5935674.75 660230.62 12.00 7487.58 88.21 MWD 13200.00 87.74 283.49 8961.59 -4673.02 -5876.27 5935679.39 660206.08 12.00 7504.08 88.08 MWD 13225.00 87.85 286.49 8962.55 -4666.56 -5900.39 5935685.32 660181.82 12.00 7519.57 87.96 MWD 13250.00 87.96 289.49 8963.46 -4658.85 -5924.15 5935692.51 660157.90 12.00 7534.02 87.85 13 13275.00 87.97 286.49 8964.35 -4651.13 -5947.91 5935699.70 660133.97 12.00 7548.46 270.00 MWD 13300.00 87.98 283.48 8965.24 -4644.67 -5972.05 5935705.62 660109.71 12.00 7563.96 270.11 MWD 13325.00 87.99 280.48 8966.12 -4639.49 -5996.48 5935710.27 660085.16 12.00 7580.46 270.21 MWD 13350.00 88.01 277.48 8966.99 -4635.59 -6021.16 5935713.63 660060.41 12.00 7597.92 270.32 MWD 13375.00 88.03 274.48 8967.86 -4632.98 -6046.01 5935715.68 660035.51 12.00 7616.29 270.42 MWD 13400.00 88.06 271.48 8968.71 -4631.69 -6070.95 5935716.43 660010.54 12.00 7635.52 270.53 MWD 13425.00 88.10 268.48 8969.54 -4631.70 -6095.94 5935715.87 659985.57 12.00 7655.57 270.63 MWD 13450.00 88.14 265.47 8970.36 -4633.01 -6120.89 5935714.00 659960.66 12.00 7676.36 270.73 MWD 13475.00 88.19 262.47 8971.17 -4635.64 -6145.73 5935710.83 659935.88 12.00 7697.86 270.83 MWD 13500.00 88.24 259.47 8971.95 -4639.56 -6170.41 5935706.37 659911.30 12.00 7719.99 270.92 MWD 13525.00 88.29 256.47 8972.70 -4644.76 -6194.85 5935700.63 659886.98 12.00 7742.70 271.02 MWD 13550.00 88.35 253.47 8973.44 -4651.24 -6218.98 5935693.62 659863.00 12.00 7765.92 271.11 MWD 13575.00 88.42 250.47 8974.14 -4658.98 -6242.74 5935685.36 659839.42 12.00 7789.59 271.20 MWD 13600.00 88.49 247.47 8974.81 -4667.94 -6266.06 5935675.88 659816.30 12.00 7813.66 271.28 3 3/16" • • x ,~ s 's ~ : ~ tt I +r s y° - N I f j ~ ~~-. .t..-L ti g t_ 1 1 I; (( I.I.. 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I, .. r, ~+ 1 I; ~ t~~ } z. 1 kt I. jz I t ~ ~ [~ ail l ~~i -t~ i~ ~~ I' ~ f I 1 ~ ~-t ~~1 ~~~1 - ~ i rtl l g N I S j$ ~_ a BFI 8 a ~ . . ~ ~ i cwn,oou ciiwNrwaw,Nrs $ ~ 0- d " ~ r 0 x a-- N 3 a~ 3n5i tt / « ~ w ~~p~ ~#I~'l~fi ~~ k~~~ rFk~ ~ ~~ ~~~ f~ ~~ x 8 i ~ ,: ~ b B •~ °~ 8 SeaQ, ~ ~~~ ~~~~i#~ € eaaR 1 ~ ~ 1 ft~l+ C - _ I(~ r Q ~ ~~ ~A ~ ° i~;~~a ~ p~p~[~(8~8~ a(~a8!8~ t ~ I I i ~77tT} # ~ I~ ~ 9 a~ ~' ~ gYEt~ ~ tii~ii~l~~ ,~~ ~ l l }I ~ {+ m s ~ 1~ " - H s ~ 1 ~ ;, !Ilfii~t~-~ li, C:~~ I~~~ +t 1 iil I~;' 1' ~ ~ ' i~i~~:~~~:i~~~ ~ 9 88888888888888 ~ eegiq aciesi: l ........ t:aos ' :y ~ ~ g g g ~ g 8 ~ 8 8 $ 8 8 8 8 ~ 8 i~ii~~iii~~~~i 8 : : 3 : 8 V °~°'° I~MwoL] VWoO Ih!L+aA r++l r.+O.S ap BP Alaska Anticollision Report ~.-r s"s 1NTEQ Company: BP Amoco Date: 8/1.0!2007 Time: .15:38:10 Page: 1 Field: Prudhoe Bay Reference Site: PB X Pad. Go-ordinate(NE) Reference: WeII: X-2Q True Noah Reference Well: X-20 Vertical. (TVD) Reference; 30:20 5/1 3/1994 00:00 68.0 Reference Weppath: Plan 1, X-20A Db: Orade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There are'~f~teeltc in this Rlehtrpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 11270.00 to 13600.00 ft Scan Method: Trav Cylinder North Maximum Radius: 2500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/10/2007 Validated: No Version: 0 Plauued From To Survey Toolcode Tool Name ft ft 98.20 10899.20 1 : MWD -Standard (98.20-1089 MWD MWD -Standard 10935.00 11245.00 1 : MWD -Standard (10935.00-1 MWD MWD -Standard 11245.00 13600.00 Planned: Plan #1 V1 MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 13600.00 9042.81 3.188 4.125 3 3/16" Summary <-- Offset Wellpath - ~ Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Dfstaace Area Deviation Waruiug ft ft _ft ft ft EX PRST01 PRST01 PRST01 V1 Out of range PB X Pad Plan X-37 Plan X-37 VO Plan: X-3 Out of range PB X Pad X-01 Plan X-01 a V1 Plan: X- Out of range PB X Pad X-01 X-01 V1 Out of range PB X Pad X-02 X-02 V1 Out of range PB X Pad X-03A X-03A V11 Out of range PB X Pad X-03 X-03 V1 Out of range PB X Pad X-04 X-04 V1 Out of range PB X Pad X-05 X-05 V1 Out of range PB X Pad X-06 X-06 V1 Out of range PB X Pad X-07 X-07 V1 Out of range PB X Pad X-08 X-O8 V3 Out of range PB X Pad X-08 X-08A V5 Out of range PB X Pad X-09 X-09 V9 Out of range PB X Pad X-09 X-096 V23 Out of range PB X Pad X-09 X-09L1 V4 Out of range PB X Pad X-10 X-10 V1 Out of range PB X Pad X-11A X-11A V1 Out of range PB X Pad X-11 X-11 V1 Out of range PB X Pad X-12 X-12 V1 Out of range PB X Pad X-17 X-17 V1 Out of range PB X Pad X-18 X-18 V1 Out of range PB X Pad X-19A X-19A V1 Out of range PB X Pad X-19BL1 X-196L1 V11 11293.75 12700.00 1725.44 583.86 1141.59 Pass: Major Risk PB X Pad X-196PB1 X-19BP61 V2 Out of range PB X Pad X-196 X-198 V5 11290.00 12700.00 1725.49 585.74 1139.75 Pass: Major Risk PB X Pad X-19 X-19 V1 Out of range PB X Pad X-20 X-20 V2 11299.97 11300.00 0.52 403.90 -403.39 FAIL: Major Risk PB X Pad X-20 X-20P61 V3 11314.79 11386.20 171.51 112.14 59.37 Pass: Major Risk PB X Pad X-22 X-22 V1 13389.53 12700.00 944.04 496.04 448.00 Pass: Major Risk PB X Pad X-22 X-22A V2 13520.79 13100.00 804.01 577.07 226.94 Pass: Major Risk PB X Pad X-22 X-22PB1 V2 11813.49 11400.00 1456.85 425.46 1031.39 Pass: Major Risk PB X Pad X-28 X-28 V1 Out of range PB X Pad X-30 Plan 9, X-30A V1 Plan: Out of range PB X Pad X-30 X-30 V1 Out of range PB X Pad X-30 X-30P61 V1 Out of range PB X Pad X-32 X-32 V1 Out of range PB X Pad X-33PB1 X-33PB1 V1 Out of range PB X Pad X-33 X-33 V2 Out of range PB X Pad X-36 X-36 V1 Out of range • by BP Alaska Anticollision Report r~.r B~ ~s 1NTEQ Company: BP Amoco Date: 8/10/2007. Times 15:38:10 Page: 2 Field: Prudhoe Bay Reference Siter PB X Pad Co-ordinate(NE) Reference: Well: X-20, True North Reference Well: X-20 Vertical (TVD) Reference: 30 `. 20 5/1 311 994 00: 00 68.0 Reference Wellpath: Plan 1, X-20A Db: Orade Site: PB X Pad Well: X-198L1 Rule Assigned: Major Risk Wellpath: X-196L1 V11 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSi)istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft- ft_ ft 11293.75 9009.42 12700.00 8941.01 73.99 107.65 149.41 272.26 1725.44 583.86 1141.59 Pass 11304.28 9009.65 12800.00 8940.31 73.13 106.79 152.12 272.24 1764.89 578.57 1186.32 Pass 11313.78 9009.64 12900.00 8948.70 72.16 105.75 154.40 271.92 1807.79 572.37 1235.42 Pass 11320.00 9009.64 13000.00 8956.69 71.40 105.02 155.95 271.63 1854.54 567.63 1286.90 Pass 11330.00 9009.70 13100.00 8964.37 70.01 103.30 158.64 271.35 1904.69 561.25 1343.44 Pass 11330.00 9009.70 13138.00 8967.06 70.01 103.37 158.56 271.27 1924.68 566.46 1358.21 Pass Site: PB X Pad Well: X-196 Rule Assigned: Major Risk Wellpath: X-196 V5 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSflistance Area DevjatlOn Wnroing ft ft ft ft ft ft deg deg in ft ft ft 11290.00 9009.26 12700.00 9008.17 74.28 107.83 146.24 270.07 1725.49 585.74 1139.75 Pass 11300.00 9009.59 12800.00 9009.91 73.52 107.13 148.77 270.00 1764.73 581.05 1183.68 Pass 11310.00 9009.66 12900.00 9013.06 72.62 106.21 151.24 269.88 1805.84 575.25 1230.59 Pass 11320.00 9009.64 13000.00 9015.97 71.40 104.85 154.12 269.79 1848.73 567.16 1281.57 Pass 11330.00 9009.70 13100.00 9019.08 70.01 103.19 157.00 269.71 1896.14 557,63 1338.51 Pass 11340.00 9009.84 13200.00 9021.51 68.43 101.26 159.89 269.63 1946.23 546,78 1399.44 Pass 11345.34 9009.95 13300.00 9022.32 67.50 100.28 161.47 269.64 1999.47 540.69 1458.78 Pass 11350.00 9010.07 13400.00 9022.67 66.69 99.39 162.88 269.66 2055.97 535.24 1520.73 Pass 11360.00 9010.37 13500.00 9023.93 64.78 96.89 165.80 269.62 2116.93 521.66 1595.27 Pass 11365.62 9010.58 13600.00 9027.00 63.62 95.50 167.41 269.56 2180.62 513.69 1666.92 Pass 11370.00 9010.76 13699.97 9030.71 62.72 94.43 168.66 269.50 2246.53 507.43 1739.11 Pass 11380.00 9011.22 13800.00 9033.58 60.50 91.41 171.52 269.40 2314.07 491.36 1822.71 Pass 11380.00 9011.22 13900.00 9043.93 60.50 91.69 171.37 269.25 2385.61 491.88 1893.73 Pass 11390.00 9011.76 14000.00 9064.44 58.14 88.37 173.81 268.72 2461.33 474.55 1986.78 Pass Site: PB X Pad Well: X-20 Rule Assigned: Major Risk Wellpath: X-20 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSflistance Area .Deviation Warning` ft ft ft ft ft ft deg deg in ft ft ft 11299.97 9009.59 11300.00 9009.87 73.52 72.52 116.04 237.28 0.52 403.90 -403.39 FAIL 11388.85 9011.70 11400.00 9013.12 58.41 57.64 172.15 267.40 31.50 381.94 -350.44 FAIL 11456.83 9016.48 11500.00 9013.95 48.03 47.44 188.25 271.57 92.27 320.18 -227.91 FAIL 11513.03 9020.52 11600.00 9012.19 41.63 41.16 196.39 272.95 162.56 282.02 -119.46 FAIL 11557.61 9023.65 11700.00 9012.28 36.39 35.96 201.52 272.72 240.03 250.94 -10.91 FAIL 11667.25 9031.13 11800.00 9013.47 47.09 46.50 192.98 273.18 319.06 314.47 4.59 Pass 11980.07 9043.26 11900.00 9013.54 78.27 77.28 157.73 274.68 364.13 500.89 -136.76 FAIL 12074.67 9037.71 12000.00 9012.66 79.02 77.98 157.77 273.87 371.99 505.74 -133.76 FAIL 12129.08 9034.17 12100.00 9013.52 76.48 75.44 163.47 273.03 391.20 490.90 -99.70 FAIL 12180.24 9030.93 12200.00 9014.59 73.26 72.24 168.81 272.22 422.24 471.62 -49.38 FAIL 12227.74 9028.02 12300.00 9015.97 69.61 68.60 173.80 271.50 461.91 449.44 12.48 Pass 12270.80 9025.49 12400.00 9015.26 65.77 64.79 178.62 271.15 511.13 426.04 85.09 Pass 12309.61 9023.32 12500.00 9014,75 61.93 60.96 183.00 270.87 567.30 402.63 164.67 Pass 12344.03 9021.49 12600.00 9014.35 58.26 57.29 186.92 270.65 630.28 380.06 250.21 Pass 12375.00 9019.94 12700.00 9014.80 54.77 53.80 190.41 270.43 699.13 358.54 340.59 Pass 12400.00 9018.74 12800.00 9012.99 51.84 50.93 193.40 270.42 772.32 340.86 431.46 Pass 12933.27 9017.03 12900.00 9008.48 85.05 83.56 162.07 270.61 798.26 542.01 256.25 Pass 12955.89 9018.20 12964.00 9003.52 83.81 82.30 165.20 271.03 816.49 534.45 282.03 Pass • by BP Alaska Anticollision Report ~.r BAKiR HUGNES INTEQ Company: BP Amoco Date: 8/10/2007 Time: 15:38'10 Page: 3 Field: Prudhoe Bay Reference Site: PB X Pad Co-ordinate(NE) Reference: Well: X-20, True North Reference Wellh X-20 Vertical (TVD) Reference: 30 :20. 5/13/1994 00: 00 68.0 Reference Wellpath: Plan 1, X-20A Db; OraGe Site: PB X Pad Well: X-20 Rule Assigned: Major Risk Wellpath: X-20P61 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Azis Ctr-Gtr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasingJHSI)istance Area. Deviation Warning ft ft ft ft ft ft deg deg in ff ft ft 11314.79 9009.64 11386.20 9181.05 72.04 71.24 64.69 181.90 171.51 112.14 59.37 Pass Site: PB X Pad Well: X-22 Rule Assigned: .Major Risk Wellpath: X-22 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Azis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casiog/HSUistauce Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11688.11 9032.53 10700.00 8752.21 49.87 52.87 357.16 79.87 1604.03 337.68 1266.35 Pass 11700.00 9033.32 10800.00 8806.10 51.44 54.86 357.35 81.49 1559.23 349.43 1209.79 Pass 11725.00 9034.96 10900.00 8857.44 54.64 57.80 356.08 83.22 1520.55 368.79 1151.76 Pass 11750.00 9036.58 11000.00 8901.36 57.73 60.64 354.59 84.74 1483.47 387.24 1096.23 Pass 11775.00 9038.16 11100.00 8932.67 60.67 63.27 352.64 85.80 1436.18 404.31 1031.86 Pass 11789.53 9039.06 11200.00 8957.42 62.30 65.18 351.66 86.56 1383.97 415.31 968.66 Pass 11812.43 9040.46 11300.00 8973.69 64.79 67.58 349.43 87.08 1337.09 430.30 906.79 Pass 11837.61 9041.91 11400.00 8987.27 67.34 69.96 346.92 87.54 1300.54 445.38 855.16 Pass 11864.88 9043.12 11500.00 9001.13 69.86 72.38 344.30 88.07 1278.79 460.52 818.27 Pass 11892.88 9043.90 11600.00 9006.39 72.25 74.67 341.25 88.25 1264.29 474.83 789.46 Pass 11925.00 9044.23 11700.00 9006.51 74.75 76.76 337.54 88.23 1257.46 488.80 768.66 Pass 12575.00 9012.33 11800.00 9008.00 63.30 67.46 3.73 89.73 1211.33 424.78 786.55 Pass 12600.00 9011.73 11900.00 9012.06 66.48 70.67 0.96 89.95 1169.07 444.16 724.91 Pass 12625.00 9011.22 12000.00 9015.99 69.51 73.75 358.20 90.18 1132.97 462.67 670.31 Pass 12650.00 9010.80 12100.00 9020.16 72.37 76.71 355.46 90.44 1103.00 480.26 622.74 Pass 12683.48 9010.37 12200.00 9024.53 75.91 79.97 351.70 90.69 1079.28 500.72 578.56 Pass 12713.82 9010.12 12300.00 9027.73 78.85 82.76 348.27 90.89 1060.25 518.19 542.07 Pass 12750.00 9010.00 12400.00 9030.38 81.99 85.47 344.10 91.05 1048.07 536.09 511.98 Pass 13331.39 9034.34 12500.00 9032.31 66.61 71.34 9.54 89.82 1034.40 446.94 587.46 Pass 13359.53 9035.32 12600.00 9033.45 70.63 75.50 6.16 89.82 986.35 471.50 514.85 Pass 13389.53 9036.35 12700.00 9034.83 74.69 79.62 2.57 89.84 944.04 496.04 448.00 Pass Site: PB X Pad Well: X-22 Rule Assigned: Major Risk Wellpath: X-22A V2 Inter-Site Error: 0.00 ft Reference Otfset Semi-Major Axis Ctr-Ctr Nato Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSOdstance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11688.11 9032.53 10700.00 8752.21 49.87 52.87 357.16 79.87 1604.03 337.68 1266.35 Pass 11700.00 9033.32 10800.00 8806.10 51.44 54.86 357.35 81.49 1559.23 349.43 1209.79 Pass 11725.00 9034.96 10900.00 8857.44 54.64 57.80 356.08 83.22 1520.55 368.79 1151.76 Pass 11750.00 9036.58 11000.00 8901.36 57.73 60.64 354.59 84.74 1483.47 387.24 1096.23 Pass 11775.00 9038.16 11100.00 8932.67 60.67 63.27 352.64 85.80 1436.18 404.31 1031.86 Pass 11789.53 9039.06 11200.00 8957.42 62.30 65.18 351.66 86.56 1383.97 415.31 968.66 Pass 11812.43 9040.46 11300.00 8973.69 64.79 67.58 349.43 87.08 1337.09 430.30 906.79 Pass 11837.61 9041.91 11400.00 8987.27 67.34 69.96 346.92 87.54 1300.54 445.38 855.16 Pass 11864.88 9043.12 11500.00 9001.13 69.86 72.38 344.30 88.07 1278.79 460.52 818.27 Pass 11892.88 9043.90 11600.00 9006.39 72.25 74.67 341.25 88.25 1264.29 474.83 789.46 Pass 11925.00 9044.23 11700.00 9006.51 74.75 76.76 337.54 88.23 1257.46 488.80 768.66 Pass 12575.00 9012.33 11800.00 9008.00 63.30 67.46 3.73 89.73 1211.33 424.78 786.55 Pass 12600.00 9011.73 11900.00 9012.06 66.48 70.67 0.96 89.95 1169.07 444.16 724.91 Pass 12625.00 9011.22 12000.00 9015.99 69.51 73.75 358.20 90.18 1132.97 462.67 670.31 Pass 12650.00 9010.80 12100.00 9020.16 72.37 76.71 355.46 90.44 1103.00 480.26 622.74 Pass 12683.48 9010.37 12200.00 9024.53 75.91 79.97 351.70 90.69 1079.28 500.72 578.56 Pass • by BP Alaska Anticollision Report ~.r Bps f.NTEQ Company: BP Amoco Date: 8/10/2007 Time: 15:38:10 Page: - 4 Field: Prudhoe Bay :Reference Site: PB X Pad Co-ordinate(NE) Reference: WeIL• X-20, True North Reference Well: X-20 Vertical (TVD) Reference: 30:20.5/13/1994 00:00..6$.0 Reference Weilpath: Plan 1, X-20A Db: Orade Site: PB X Pad Well: X-22 Rule Assigned: Major Risk Weilpath: X-22A V2 Inter-Site Error: 0.00 ft Reference Offset Semi Major Aaic Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSflistance .Area Deviation WarninS ft ft ft ft ft ft deg. deg in ft ft ft 12713.82 9010.12 12300.00 9027.73 78.85 82.76 348.27 90.89 1060.25 518.19 542.07 Pass 12750.00 9010.00 12400.00 9030.38 81.99 85.47 344.10 91.05 1048.07 536.09 511.98 Pass 13331.39 9034.34 12500.00 9032.31 66.61 71.34 9.54 89.82 1034.40 446.94 587.46 Pass 13359.53 9035.32 12600.00 9033.45 70.63 75.50 6.16 89.82 986.35 471.50 514.85 Pass 13389.51 9036.35 12700.00 9034.86 74.69 79.60 2.58 89.84 943.95 495.96 447.99 Pass 13420.23 9037.38 12800.00 9034.48 78.58 83.14 358.79 89.74 900.71 518.27 382.45 Pass 13450.00 9038.36 12900.00 9029.10 82.08 86.25 354.77 89.29 852.33 538.07 314.27 Pass 13483.96 9039.45 13000.00 9023.25 85.66 89.35 350.17 88.78 811.83 558.04 253.80 Pass 13520.79 9040.58 13100.00 9020.19 89.13 92.25 345.44 88.46 804.01 577.07 226.94 Pass 13556.11 9041.61 13200.00 9015.16 91.96 94.56 340.83 88.10 831.18 592.51 238.67 Pass 13586.95 9042.47 13300.00 9010.52 94.04 96.17 336.88 87.85 881.75 603.97 277.77 Pass Site: PB X Pad Well: X-22 Rule Assigned: Major Risk Wellpath: X-22P61 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TF0.HS Casing/HSi)istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11688.11 9032.53 10700.00 8752.21 49.87 52.60 357.16 79.87 1604.03 336.85 1267.18 Pass 11700.00 9033.32 10800.00 8806.10 51.44 54.57 357.35 81.49 1559.23 348.57 1210.66 Pass 11725.00 9034.96 10900.00 8858.72 54.64 57.44 356.13 83.28 1521.14 367.76 1153.38 Pass 11750.00 9036.58 11000.00 8914.41 57.73 60.18 355.13 85.29 1491.70 386.08 1105.62 Pass 11765.51 9037.56 11100.00 8978.25 59.55 62.10 355.62 87.64 1470.71 397.94 1072.77 Pass 11783.04 9038.66 11200.00 9051.62 61.58 63.94 356.34 90.47 1457.12 409.56 1047.56 Pass 11800.00 9039.71 11300.00 9131.12 63.48 65.58 357.42 93.58 1452.33 419.35 1032.98 Pass 11813.49 9040.52 11400.00 9215.75 64.91 66.93 359.09 96.88 1456.85 425.46 1031.39 Pass 11813.77 9040.54 11402.00 9217.46 64.94 66.96 359.13 96.94 1457.01 425.57 1031.44 Pass a s R a a 4 ~ S R s a ilt~l~llllllli{I~11 II it}~rilt~FIb141FH Ihlt k ~ Ii-i~ I Ik I t: ~~ I I 111~~11 ~~I~r 1 Ijft { ~ S ° (((IL~ } tt ~ I I '-` ~ S S g :G~ l~ ~ ~ , ~ ~ m ~ g }t j I ~ a o I '.' -m . 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Xz~t~txXX~txxXxxx~taa ~ 1 1 II .j. ~ II_.g s 8 ~ Ri$3$$$C7$;7a7 X FII_. f . 4 - -~-I ' -y $ tl €8 '° i~f~95I27dd'F ~ -~ '~ !y ~~~' ~t I ~ _ r .~ a zB = 8$$88$88,8$8$8 ~ ~~ ~ ~ T - -- j~Q~ I Som ,.. 7 ~ a -~u' ~ SYYti$7% % d ~.f: ~-- I I t{ J`Fit 1- f} I (A ? a a ~ a ^:s:% Y :~ I I I ~ 1 II 1{ f j ~, °P Q 9 ~ '$ ~a ~ 3RsSi~ ~ 4 :sg~*geaasst%= .:E-. f "r ~~~ ~f.~ -i: t j ~ - ~ ~. a ~ $ ~ ~rF~g x . i i . }- II ~~ ~L }(} ~ ~4t 71 ~ ~ w a .Y ~ Q :td•ia:: 8~ r I r I{ I~~ I I i ~ ~~1- .1- i ~~ ~f~ ~~ 1_3 ~ ¢ crc¢5~ @~~~7$€D€YYY~€ i. - ~~ ~_ 1 I, t -:I 'lI } I p> ° S:CYEiit S:YiCY $ .,.rrrrrrr,r-rrr.1rTT~,-rr-~T.g,.~r~ ~-~-~-I-.::-I~-,-~.-~~-,T,-1,-r-r R ,T-~ - Trr,T~rr.,-Trr„R do$~ 55263Y&)~ RRg ~ Rg. agj $ y ~ ~ ~ Sgi 9g} ~ ,~ Page 1 of Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 22, 2007 2:13 PM To: 'Barber, Greg J' Subject: RE: X-20A Greg, Thanks for the plots. Only thing to consider when establishing the %4 mile radius is that it does extend around the heal and toe of a penetration as well. In this case, based on my hand sketch, adding the semi-circles does not bring in any other wells. I will let you know if anything more is needed. Tom Maunder, PE AOGCC From: Barber, Greg J [mailto:Barber7G@BP.com] Sent: Tuesday, August 21, 2007 3:51 PM To: Maunder, Thomas E (DOA) Subject: RE: X-20A Hi Tom, Attached you will find the X-20A sidetrack in plan view with a boundry drawn around the sidetrack wellbore at the 1/4 mile radius. The only wells that fall within this distance for the proposed sidetrack are wells X-22 and X- 22A. Well X-22A is a horizontal extension of well X-22. The X-22A lateral was drilled and slotted liner was run. The top of the slotted liner in X-22A is at the same depth as the top of the slotted liner in X-22. A copy of the schematic is attached to this email. There are 2 purposes for the workover and sidetrack on X-20. The first is to restore production tubing integrity. The second is to reposition the wellbore for injection conformance. The X-20i wellbore was drilled flat and very close to TSAD. Due to low kv/kh, injection is not communicating with all sands in Zone 4B. This may possibly explaining why X-22/X-22A has experianced a production and BHP decline and the decline appears to be higher since X-20i went offline in 2004. The reservoir engineer reports that an injectionNRR skin plot indicates local pattern voidage that was created before periphery injection began has not been replaced. The pattern voidage is about 40% low. Repositioning the wellbore will improve injection support in this pattern. Basically, well X-20Ai will support X-22A, and that is the reasoning for the positioning of this sidetrack wellbore. There are no other wells impacted within the 1/4 mile radius of the X-20A sidetrack. With reguards to the cementing, I think we covered that in another email, but to confirm, X-20 was origionally permitted as an injector, and a cement bond log was run that confirms cement quality in the parent well bore. The proposed sidetrack window on X-20A is within zone 4, so my interpretation is that no additional bond logs are needed pre or post sidetrack. Please let me know if this information addresses your requirements, and if any additional bond logs will be required. Also, let me know if you need additional information. Cheers, Greg From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, August 16, 2007 3:44 PM To: Barber, Greg J Subject: X-20A Greg, I am reviewing your permit application. Since this is planned to be an injection well, the wells and more importantly the penetrations into the reservoir within %4 mile radius mus# be identified and an assessment of the isolation (cementing) at the penetration must be made. Since this is a horizontal well, the quarter mile radius should extend along the wellbore. A plan view map of the area should also be included. 8/22/2007 BP Alaska N[ufpTp //ruu q.e +, Xao. fnnnl NJbFM: Xa0 Tle en Mp: 11/X/.0/ rRl/: Merpk 1 W. ea i/:f//M//1//X//9/ //A/M V}.cll.n ~y ~:y M/M ~ NIJ ~~# Fn:n NC REFERENCE INFORMATION ai v' ~ ow D .-.~ T Phn. PIFn pt (X-20IPYn 1, %-zon) xo+.i /Is ' iX-0'` M Mmutlu m Tnr NFnn Cn/brd BY: BP DFN: 8212007 xa:Xaz BAKER J y cn.eba: o.N:_ zaaa~~a~I 19 M.pn.oa wnn: zBa+• %mx~~ NuaNE by 6DIF+wIn~ ~~'I ,,~rr i,lnrr„al,~6a~,i~baaiA~ .~,, Xa, -:~:m~~ NTEQ ~I Mo~abppmzap~~ :nirl~o,;»,.>>,~ E~mart bill.nrrclrgalagn®inlaq.cgm Coordinate ((NIE) Ra}eranca: WaN Centre- X-20, True North '~ Veroral ~ND1 Ra}arenca. 30:20 5/13/1884 00'00 68.00 Section (VS)Raleranca: Slot-20 (O.OON.O.OOE) ~i - Measured DeOih Reference 30 20 5/13/1984 00:00 66.00 - Calculabon Method. Minimum Curvature i - --_ - Frre -- _ -_.. -_: -- • Iw< I • • n. . ..Far i - -zeoo ` X-31 X-31L1 aooo 6700 ,{' 6300 E I 17600 -3200 -3400 r r i X00 - ~ ~ 1 6100 •3600 ~ X22 X-22A ~ ~ -' -4000 ~ ~ 18400 4200 p ~~ r1 ~~ / 8700 G t ~ ~~ Pla-3rX-20 _ -ae6o \- ~ -sooo (~ ~j \ -szoo -s46o -SBOO - -5800 ~- .6200 -6400 j X-~ (X -Beoo -6soo -8400 az6o -eooo -~eoo -~fioo a4oo -noo -006 shoo ~soo -6406 szoo ~aoo -seoo shoo -s4ao -szoo -soon .46oD -46ao a4oo szoo -4000 seoo asoo -3400 -3za6 ao6o -2660 -zsoo -z4ac -2200 -2000 -iaoo West(-)/East(+) (200itlin] 6900 7200 7500 7800 8100 8400 6700 I -szoo -moo TRFF= 4" 5M CR WB_LHEAD = 5M FMC ACTUATOR = OTIS KB. ELEV = 68.64' BF. ELEV = 39.0' KOP = 3763' Max Angle = 94 13542' Datum MD = 10926' DatumTVD = 8800' SS 10-3/4" CSG, 45.5#, L-80, ID = 9.953" I--I 3200' MinimLm ID = 2.37" @11961' 2-7/8" FL4S LNR X 2-7/8" STL LNR XO X-~~~ SAFEfYNOTES:CHROMETBG/LNR.7-5/8"TM/PKR MAY FAIL AT 2100 PSI DIFF IF EXC~D® CTD. 2-7/8" WR HAS BAN PREDPoLLED VW3/8" HOLES @ 4 HOLES FER FT. 4-1/2" SWN NIP @ 10719' MLL® OUT TO 3.80" ID BY CTD 2101' 4-1/2" OTIS HXO SSSV NIP, ID= 3.813" GAS LIFT MANDRELS ST ND TVD DEV TYPE VLV LATCH SIZE DATE 6 3584 3513 8 CA KBMG DOME BK 16 09/19/02 5 6017 5521 49 CA KBWG DOME BK 16 09/19/02 4 8057 6906 48 CA KBNG DOME BK 16 09/19/02 3 9387 7818 43 CA KBMG DMY BK 0 06/14/01 2 10441 8532 53 CA KBMG DMY BK 0 06114/01 1 10586 8618 55 CA KBMG SO BK 22 09/19/02 4-112" PARKHt SWS NP, ~ = 3.813" I' 41/2" TBG, 12.6#, 13CR, 0.0152 bpf, ID= 3.958" j TOP OF 41/7' LNR I 7-5/8" CSG, 29.7#, ID = 6.875" I 10672' F--I7-5/8" x 41/2" 71W HBBP HCR, ID =4.0" 10702' H4-1l2" PARKfft SWS NP, ID = 3.813" 10719' H4-1 /2" PARKffZ SWN NP (AALLED BY CTD) ~ =FROM 3.725" TO 3.80" 10731' I--~4-112" WLEG, ID= 3.958" ELMD- NOTLOGG® ~T1W SCOOR'OVERSHOTASSY I 3.70" BKR D~LOY SLV, ID= 3.00" 11960' ~--I3-1 /2" X 2-7/8" XO, ID = 2.44" 4-1/2" LNR, 12.6#, 13CI~80, 0.0152 bpf, ID = 3.953" 11275' ~~ 12025' 2 7/8" PR€DRLL® LNR, ID =2.37" rnvOF4-1!2"SLOTT.GnLNR 1+1-'- ~~ ~ ~ ~~ ~ ~~ ~~ ~\ ~• ~` `- ~\ ~~ ~ ~~ ~~ 4-112" LNR, 13-CR-80, SLOTTED, 0.0152 bpf, ID= 3.953' 12688' , \~~ ~• PBTD 13984 ~~ 2-718" LNR, 6.1~, L-80STL, .0057b~, ~= 237" 14f1i' DATE REV BY COMNBJTS DATE REV BY OOMMENTS 10/27/93 FARGO ORIG HORIZ OOM'LETION O6/25~01 CH/TP CORR~TIONS 02/24/01 SISOAA CONVERIEDTOCANVAS 09/19102 DTR/KK GLV C/D 03/02/01 SIS-ND FINAL 05118101 RN/KAK CORRECTIONS 06/04/01 CTD SDETRACK PRUDHDEBAY UNTf WE1L- X 22A P~tMT rb: 2010740 API No: 50-029-22399-01 4909' FSL & 525T FH. Sec 8, T10N, R74E BP Exploration (Alaska) • Page 1 of 2 Maunder, Thomas E (DOA) From: Sarber, Greg J [SarberJG@BP.com] Sent: Monday, August 20, 2007 2:51 PM To: Maunder, Thomas E (DOA) Subject: RE: X-20A Hi Tom, BHI will get the 1/4 mile data prepared and I will get it to you as soon as they finish with it. Probably tomorrow. As far as when we run cement evaluation logs on CT wells, the technology is available from Schlumberger. They do have a 1-11/16" in diameter cement bond tool that is run in memory mode when we run it in horizontal wells. The log it gives is analogous to a conventional CBL. We don't run them aften. Atypical use of this logging service would be to ensure isolation from a loss zone at a fault or fracture. Often our cement isolation between the perforations and the thief zone is a question, so we will run an SCMT bond log to confirm adequate standoff. Cheers, Greg From: Maunder, Thomas E (DOA) [maifto:tom.maunder@afaska.gov] Sent: Monday, August 20, 2007 12:56 PM To: Sarber, Greg 7 Subject: RE: X-20A Greg, In zone, there shouldn't be an isolation issue with X-20A. One question, how frequently are bond logs run on CT wells? The need is to examine other wells that might penetrate within the '/o mile radius. X-20 is already an injector and should have been reviewed previously so I don't think there will be an issue here. Hope this answers your question. Tom Maunder, PE AOGCC From: Sarber, Greg ] [mailto:SarberJG@BP.com] Sent: Monday, August 20, 2007 10:40 AM To: Maunder, Thomas E (DOA) Subject: RE: X-20A Tom, I'll work the 1/4 mile radius issue today. With respect to the cementing assessment, does that mean the AOGCC requires a cement bond log on the new liner to be run, even if it is sidetracked in zone, or does that mean you would like to see the log for the parent welt casing above the sidetrack depth? Thanks for the feed back. Cheers, Greg from: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, August 16, 2007 3:44 PM To: Sarber, Greg J Subject: X-20A Greg, 1 am reviewing your permit application. Since this is planned to bean injection well, the wells and more 8/22/2007 • Page 2 of 2 importantly the penetrations into the reservoir within %. mite radius must be identified and an assessment of the isolation (cementing) at the penetration must be made. Since this is a horizontal well, the quarter mile radius should extend along the wellbore. A plan view map of the area should also be included. Call or message with any questions. Tom Maunder, PE AOGCC 8/22/2007 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000~!~ • Alaska Department of Natural Resources Land Administration System Page 1 of 2 aka 1 1-,,,-~, „~~! .... ,.;,.~. t' „t: ,~corder`sSearch State Cabins ~~U~ 5~d'i41CC9eS ~ _ , Alaska DIVR Case summary File Type' aoL ~ File Number: 47472 +,o+ Printable Case File_Summary. See Township, Range, Section and Acreage? New Search C Yes ~~ No ----------~-------~- LAS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract ~. File: AllL 47472 '~''°' Search for Status Plat Updates As of 0~%1 ~!'~[107 Custo~ner.~ OOOI07377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BLATTN: LAND MANAGER- . ALASKA ANCHORAGE AK 495 1966 1 2 Ccrse Type.• 7~4 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/30/1969 Total Acres: 2560.000 Date Initiatecl.~ 0811 I/1969 Office'of Prirrtary Responsibility: DOG DIV OIL AND GAS Last Transaction Dcrte: ] 2/04/2006 Case ~S'ubtype: ~!~ NORI~H SLOPE Last Tranrac~rnrz AA-NRB ASSIGN>/1BNT APPROVED .1/ericliaft: ii Tnis~nship: OION Peurgc~: Ol ~E Sc~c~tiorl: O1 Scc[ion~lcr~~s: 640 Search Plats dle~riclian: ~ ~ Tulvnsltr~~: 01 UN K~rr~,~re: 0 i 3 E ,Sccliun.~ 02 ,ti'~~ctrun ~1 cre.~~: 6~!-0 ;11c~riciian.' U Tuu~ts{ri~~: OION Rart~c: 01 ~E ,S'c~cliurt.~ I I .Seclrun -lcr~es: 6=iQ Llc~ri~lian: U Tnit~~tshij~: 0 I (_)N R~r:~<~c~: 0l ~ E Secliof~: I ? Sec[ior: ~1cre~s: 640 Le ;al Ucscription 08-I1-1969 * * *SALE NOTICE LEGAL DESCRIPTION* C23-057 TI DN-R13E-UM GENERAL DI 6~t0. DD ALL 02 60.00 ALL 11 6.0.00 ALL 12 6;0.00 ALL TOTAL ACRES - 2560.00 End Q Case Sumimary http: //www. dnr. state. ak. us/las/C ase_Summary.cfm?FileType=ADL&FileNumber=47472&... 8/ 15/2007 • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~ ~~~ PTD# v?47f/~O Development / Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) 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. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well 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. ~Com~any Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 • • ^^ ~ N : ~ o a~ a : N N ~ ~ O ~ O p N, a ~ N n . , X. cn N N O ° - 3; W ~ , ~, , ~ ~ ~ X, ; a v°i ~, v' , ~ C• ~ dj, ~ L, V. d. ~ m o. ~ ~, ~ ~ 3. , °. . o y °, , o - a, a r .ol c' O' N' Z' t0 ~' ~ N ~ C ~ ~ ~ ~ ~ , ~ ~ 7. ~ X: N ~ ~ Z' a1 N r N N' ~ i n N 4 ~ 3 , YC , Q ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Z, ~ Z, ~, D: M, ~ ~ -a~ O O Q ~ ~ ~ O, ~ ~ ~ O Q. X' C ~ N• ~ ~ ~., ~ ' ~ ~ ~ ~ ~ ~ N N C ~~ T w~ a @ N Q ~ X C f0 ~ M pp ~ ~ ~ ~ , ~ ~ ~ ~ . , ~ X. d ~, rn L. ~ ' f h: a, N. ~ ° ~ ~ ~ , c. ° ' X , ~ ~ , a, ~ m ~ ~ ~ ~ ~ , ~ ~ ~ ~ ~~ 5 ua o 3 'ur m. ~ ~, a °, c o, ~, , , ~ ~ ~ a ~ ~ ai Qo ~ N a ~ ~3 ~ ~, ~ cp C9 m: ~, ~~ O• O' ~ ~~ w V, ~, ~ m' O: ~ ~~ : r M' o' a O = > 7 Z ~ ~ ~ ~ ~ ~ ca ~ ~ O. ~ ~ CO~ ~ ~: O. ~ ~ rn ~, _ O. ~~ X N' ~ ~ Q ~ Q N O X (6 ~ ~ ~ N a ~ ~ ~ ~ ~ ~ f Q. Q, Z ~ N. N. N, t/h N~ N, N, N N N } } }' }' }' ~ ~ N, N N N }' }' N~ N, N N }' }' N N }' N. N }' N N } N N, } : N, ~ ~ N O O, }' Z~ Z Q, Q, Q, Q Z Z Z Z~ N~ N, } N N, N, N, N N } }' ~-' N. g N N, Z, N, } Z } N~ N~ N N, N N } ~' }' N N N~ N, N N r }' }' ~ O Z~ Q Z' N~ Q Q, N Z' Z, ~- A O' ~ ~ E, 3. : - E. o ~, , , . , ~ ~ ~ Z, ; , ~ ~ ~ v 3. ~ 3, o. O. °~: M w ; ° ~ O ~ C N O' : W ~ ~ ~, ~ ~ ~ ~ ~~ o N. uNi~ N' ~ rn ~ ~ ~~ ~ ,~,~ ~ ~, O, ~ , ~ ~ O, N: ~ ~ ~ n ~ ~ X, 7~ N: ~ ~ ' ~ ~ C. a p. ~ N. O: 7. O: ~ ~ . iA ~ (0 C >, ' N, ~ ~ V V ~.: ~ ~ OD 3, " ~ ~ C O. 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N' ~' Y OJ O• N' N N ~ N a ~ I ~ ~: a °~ ~ • a~, m ~ O ~ ~: a o~ o n O c' fD f0~ ~: o, ~ f6; ~ ~ S 0 ~ ,~~ Z, a ~~ m Q °~ 3' o ° o~ ~, i + ~, ~, • 3' w~ a~ 3; ~ ' a Q ' °' a' ~' ~ : ~ °, o: ~, ~, m °' ~ ~, €~ ~ a. ~ ~~ N' ' ~ ~~ ~~ ` , •-~ ~ ° a ~ N' ~' o a 3, ' o: ~ ' o ~ i o' ~ E W o a~ i a 4? m ~ N ~ s a~ _ a° a; s, , ~ m a~ >, m o' °` ° a~ m ° f6' ~' ~ o, ° ~ ~ ~ Y, o °; ~' N' ~°' E' a~ ~0' E s o a~ a w c ' ~" ° °= o; a' ° °' ai ~' a i' ~' o' °' a ~' v ° Q °' m m' - , a m ~ ~' v °' ~' rn o' . tA' ,_; ' ' °' c' , i, v o' o °~ ~ ~ m E, ~ o o ~ °~ ~ ~ .N', N; m ~ ~- c N; of a N N N O ~ m' o m' ~ ~ c: v. 3 a' 2. N °~ ~' o. fl. v p :4. m c; Q. °. ~: ~, >; ~, °~ o, a~ 3, ~, a' rn ~' ~' ar ~ a`r c. ~, ~, ~: ~ a ~: ~°~ a ~~ a ~, o, ~~ ~ ~ ~: o: E. m. ~ ~ a;: °' a, o. z, c, c a~ ~' c' a a o N - 3. v' o N 'c a~ f' W ~ ~ o o ° °; v ti, ' ~ ~ o - `. ~ m ~, ~~ d ~' a~ c' °' ~' v - ; ~ ° , ~ o , a~ o, v m ui W o J m E' ~ ~ .6 ~, ~, ~ ~, a ' a`a az ~ ~, c ~, 3. ~ c ~', '°t, ~' ~' ' ' F.: ' ' n ~ m a~i, ? ~ ~ a; a; o Y`o' n ~, i ~ ° .~ m c m M Y >, c , o a~~ c, ~; S'; ~; ~ ~ o, v rn ~-; a n O O; ai a; a~ a; m U ~; - o; Q; a; z o ~, ~ ~ ~ U; ~ U U; ~ U; m; a ° U Q; ~; a, ° w; o; Q O, O r. m m; U o i ~; ~; ~' ' a~. a ia, o a~, a~ o, ~ cn; U D U w Q _ ~ -, - , , , , O r N M ~ ~ (O I~ , , M O O r N , M~~ , CO 1~ M , , O O , , N M 'cr ~ O ~ W O ~ ~ ~ .-- ~ ~ ~ r- ~ ~ N N N N N N N N N N M M M M M M M M M M U O ___.__ _ _ __- _____. _ _ _ ~ U ~ 0 i ~ o j ~ o .. ~ C +~.' N r N 1 a0+ N V O IY M C ~ ~ _ 01 D O CM 0~ _ my _O N o y ~ C7 E ~ N ~ ~ ~] ~~ a a s w a ~ ~ a s Well History File APPENDIX ~~ Infarrr~aiion 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 APPEt~O(X. No special effort has been made to chronologically . organize this category of information. °~~~~t ~~~ ~ ~ Z~~a • **** REEL HEADER **** MWD 09/02/09 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 07/10/25 1626273 Ol tapescan.txt 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 10987.5000: Starting Depth STOP.FT 13560.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: X-20A FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 14' 37.038"N 148 deg 40' 33.683"w CNTY. COUNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 25 OCt 2007 API API NUMBER: 500292247802 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 07 TOWN.N T10N RANG. R14E PDAT. MSL EPD .F 0 LMF KB FAPD.F 68 DMF KB EKB .F 0 EDF .F 68 EGL .F 0 Page 1 Description section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level l~-C ~~~- -1 I~ ~~5~- • • 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 lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by schlumberger GR CSG dated 26 oct 2007 per BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from x-20 off the whipstock set at 11266 feet MD (8940 feet TVDSS) through the 5 1.2 inch liner. Top of window 11266 ft.MD (8940 ft.TVDSS) Bottom of window 11275 ft.MD (8940 ft.TVDSS) (9) Tied to x-20 at 11140 feet MD (8923 feet TVDSS). (10) The resistivity interval from 11260 feet to 13544 feet MD (8939 feet to 8985 feet TVDSS) was MAD Passed on run 6 between 12 and 94 hours after drilling. (11) Baker Hughes INTEQ runs 1, 2 and 3 were used to mill a Fas-Dril plug, set a permanent whipstock and mill a window. (12) Baker Hughes INTEQ run 4 not completed due to malfunctions in the USR. (13) The Gamma interval from 11134 feet to 11255 feet MD (8921 feet to 8939 feet TVDSS) was logged on a MAD Pass on run 5. (14) The interval from 13544 feet to 13569 feet MD (8985 feet to 8989 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP~4VG -> Rate of Penetration, feet/hour RACHX -> Resistivity (AT)(LS) 2MHz-Compensated Borehole Corrected, ohm.m RACLx -> Resistivity (AT)(LS) 400kHz-Compensated Borehole corrected, ohm.m RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TvDSS -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 10992.4, 10989.7, ! -2.64844 10998.5, 10995, ! -3.53125 11000.5, 10997.3, ! -3.17773 11002.1, 11000.5, ! -1.58887 11004.6, 11004, ! -0.529297 11009.8, 11008.4, ! -1.41309 11016, 11014.6, ! -1.41211 11019.9, 11017.4, ! -2.47168 11022, 11020.1, ! -1.94141 11026.6, 11024.2, ! -2.47168 11028.6, 11028.6, ! 0 11034, 11033.3, ! -0.706055 11042.2, 11039.3, ! -2.82422 11043.6, 11041, ! -2.64746 11049.4, 11047.2, ! -2.2959 11055.1, 11052.8, ! -2.29492 11056.3, 11054.2, ! -2.11816 11066, 11065.7, ! -0.353516 Page 2 • 11067.5, 11066.7, 11071.2, 11070.8, 11076.1, 11073.5, 11081, 11079.3, 11085.3, 11083.5, 11088.6, 11086.5, 11092.4, 11090.4, 11095.9, 11093.3, 11104, 11104, 11108.7, 11108, 11109.9, 11109.4, 11116.4, 11115.2, 11126.7, 11126.7, 11128.1, 11127.9, 11130.2, 11130.9, 11132.5, 11133.2, 11135.9, 11136, 11139.7, 11139.7, 11142.9, 11143.5, 11144.5, 11144.9, 11149.5, 11151, 11152.8, 11152.8, 11160.4, 11160.6, 11165.1, 11165, 11170.8, 11171, 11174.7, 11173.4, 11177.3, 11177.7, 11184.2, 11181.7, 11189.2, 11185.1, 11193.2, 11189.3, 11200.5, 11196.7, 11213.9, 11210.5, 11214.9, 11211.9, 11225, 11221.5, 11227.6, 11224.1, 11229.4, 11226.4, 11234.1, 11231, 11235.4, 11232.7, 11257.8, 11253.4, 11262.4, 11257.5, 11268, 11263.5, 11271.2, 11266.8, 11273.7, 11268.6, 11274.9, 11270, 11276.5, 11271.6, 11281.5, 11276.9, 11284.7, 11279.4, 11289.1, 11283.3, 11291.7, 11287, 11295.8, 11289.8, 11303, 11297.9, 11306.2, 11301.8, 11308.5, 11303.6, 11309.6, 11305.2, 11312.4, 11307.1, 11314.3, 11309.9, 11317.7, 11313.1, 11322.3, 11315.4, 11325.4, 11318.4, 11328.8, 11321.9, 11330.6, 11325.1, 11335.7, 11330.6, 11338.9, 11332.8, tapescan.txt -0.706055 -0.353516 -2.64844 -1.76562 -1.76562 -2.11816 -1.94238 -2.64746 -0.706055 -0.529297 -1.23633 -0.176758 0.706055 0.706055 0.175781 0 0.530273 0.353516 1.58984 0 0.176758 -0.176758 0.176758 -1.23633 0.352539 -2.47168 -4.06152 -3.88477 -3.70703 -3.35449 -3.00195 -3.53125 -3.53125 -3.00098 -3.17773 -2.64844 -4.41309 -4.94336 -4.58984 -4.41309 -5.12012 -4.94336 -4.94336 -4.59082 -5.29688 -5.82715 -4.7666 -6.00293 -5.12012 -4.41406 -4.94336 -4.41406 -5.29688 -4.41406 -4.59082 -6.88477 -7.0625 -6.88574 -5.47363 -5.11914 -6.00293 Page 3 C ICJ 11344.4, 11340.7, 11350.2, 11346, 11352.1, 11347.4, 11355.5, 11350.4, 11357.6, 11353.7, 11358.5, 11356.2, 11359.7, 11357.8, 11364.5, 11361.1, 11372.3, 11364.9, 11377.7, 11370.2, 11384.8, 11378.8, 11387.6, 11382, 11390.6, 11384.4, 11394.7, 11389.2, 11398.9, 11391.9, 11402.1, 11397.5, 11411.3, 11402.3, 11450.3, 11444.8, 11460.3, 11457.9, 11463.9, 11461.8, 11503.7, 11497.9, 11507.9, 11503.3, 11514.3, 11509.2, 11519.7, 11514.1, 11527.2, 11521, 11599.3, 11590.5, 11615.9, 11607.6, 11619.1, 11610.6, 11666.2, 11658.8, 11674.3, 11669, 11679.3, 11675.4, 11684.2, 11681.2, 11687.1, 11683.2, 11688.6, 11685.1, 11696, 11691.2, 11697.9, 11693.7, 11779, 11775.4, 11785, 11782, 11789, 11785.2, 11792.9, 11788.2, 11796.6, 11791.2, 11797.7, 11793.1, 11800.2, 11796.3, 11803.2, 11798.8, 11841.2, 11835.8, 11848.9, 11843, 11852.2, 11846.2, 11859.4, 11853.4, 11862.4, 11857.7, 11864.7, 11859.3, 11870.4, 11863.9, 11873.9, 11867.9, 11875.9, 11869.7, 11886.6, 11879.5, 11891.9, 11885.3, 11897.3, 11891.1, 11900.5, 11895.4, 11903.9, 11897.9, 11915.4, 11910.6, 11919.8, 11914.1, 11948.9, 11941.5, 11953.2, 11946.1, 11963.2, 11957.4, tapescan. ! -3.70801 ! -4.2373 ! -4.76758 ! -5.12012 ! -3.88379 ! -2.29492 ! -1.94238 ! -3.35449 ! -7.41504 ! -7.5918 ! -6.00293 ! -5.64941 ! -6.17969 ! -5.47363 ! -7.0625 ! -4.59082 ! -9.00391 ! -5.47266 ! -2.47168 ! -2.11816 ! -5.82617 ! -4.59082 ! -5.11914 ! -5.64941 ! -6.17871 ! -8.82812 ! -8.29785 ! -8.47461 ! -7.41504 ! -5.29688 ! -3.88477 ! -3.00195 ! -3.88379 ! -3.53125 ! -4.7666 ! -4.2373 ! -3.53125 -3.00195 ! -3.88477 ! -4.7666 ! -5.47363 ! -4.59082 ! -3.88477 ! -4.41406 ! -5.47266 ! -5.82617 ! -6.00293 ! -6.00293 ! -4.76758 ! -5.47363 ! -6.53223 ! -6.00293 ! -6.17969 ! -7.06152 ! -6.53223 ! -6.17969 ! -5.12012 ! -6.00293 ! -4.7666 ! -5.65039 ! -7.41504 ! -7.0625 ! -5.82617 txt • Page 4 11965.9, 11960, 11983.9, 11977.3, 11999.8, 11996.3, 12005.8, 12002.3, 12027.7, 12022.9, 12037.9, 12034, 12048.2, 12042, 12064.9, 12061, 12067.9, 12064.2, 12070.6, 12067.1, 12073.6, 12069.6, 12106.5, 12101.9, 12115.5, 12110.5, 12137.4, 12134.1, 12145, 12141, 12150.5, 12148.4, 12153.2, 12150.9, 12159.5, 12154.7, 12171.7, 12167.8, 12180.3, 12176.1, 12185.3, 12180.5, 12212.8, 12208.4, 12217, 12213, 12221.6, 12218.1, 12228.9, 12224.8, 12231.7, 12227.6, 12236.5, 12232, 12243.7, 12240.2, 12246.5, 12243, 12250.7, 12247, 12262.9, 12260.3, 12267.3, 12264.1, 12275.6, 12270, 12277.7, 12273.5, 12360.5, 12350.9, 12367.5, 12358.5, 12376.5, 12367, 12381.8, 12370.8, 12389.7, 12382.1, 12395.7, 12388.5, 12408.6, 12400.9, 12417.6, 12407.4, 12424.9, 12418, 12438.1, 12429.8, 12442, 12432.6, 12448.2, 12441.5, 12451, 12445.9, 12455.1, 12448.9, 12460.2, 12453.9, 12471.7, 12463.4, 12485.5, 12475.8, 12487.8, 12481.8, 12501.7, 12495, 12508.8, 12502.4, 12516.2, 12508.4, 12532.6, 12526.4, 12540.9, 12535.7, 12547.6, 12540.9, 12552.5, 12546.3, 12560.1, 12553.9, 12563.8, 12557.1, 12565.9, 12559.4, 12566.6, 12560.6, tapescan ! -5.82617 ! -6.53223 ! -3.53125 ! -3.53125 ! -4.76758 ! -3.88379 ! -6.17969 ! -3.88379 ! -3.70703 ! -3.53125 ! -4.06055 ! -4.59082 ! -4.94336 ! -3.35449 -4.06055 ! -2.11914 ! -2.2959 ! -4.7666 ! -3.88477 ! -4.2373 ! -4.76758 ! -4.41406 -4.06055 ! -3.53125 ! -4.06055 ! -4.06055 ! -4.41406 ! -3.53027 ! -3.53125 ! -3.70703 ! -2.64844 ! -3.17871 ! -5.65039- ! -4.2373 ! -9.53418 ! -9.00488 ! -9.5332 ! -10.9463 ! -7.5918 ! -7.23926 ! -7.76855 ! -10.2402 ! -6.88574 ! -8.29785 ! -9.35742 ! -6.70898 ! -5.12012 ! -6.17871 ! -6.35547 ! -8.29785 ! -9.71094 ! -6.00293 ! -6.70898 ! -6.35547 ! -7.76855 ! -6.17871 ! -5.11914 ! -6.70898 ! -6.17969 ! -6.17969 ! -6.70898 ! -6.5332 ! -6.00293 txt • Page 5 12569.3, 12563.1, 12571.8, 12565.1, 12581.1, 12574.4, 12583.1, 12577.1, 12586.6, 12579.6, 12590.3, 12583.4, 12591.2,. 12585.6, 12600.9, 12595.8, 12611.7, 12604.3, 12612.9, 12605.9, 12614.2, 12607.6, 12619.8, 12614.1, 12626.5, 12621.2, 12629.7, 12624, 12633.6, 12627, 12637.6, 12631.3, 12641.9, 12635.5, 12643.6, 12637.6, 12645, 12640.3, 12646.5, 12641.9, 12651.9, 12648.6, 12653.9, 12650.3, 12660.1, 12655.3, 12662.2, 12656.7, 12674.9, 12665.4, 12680.6, 12672.3, 12732.3, 12726.3, 12734.5, 12728.3, 12742.4, 12738.5, 12765.3, 12758.8, 12768.9, 12763, 12775.7, 12769.6, 12782.1, 12777.3, 12786, 12780.9, 12796, 12790.7, 12817.6, 12810.7, 12835.4, 12828.2, 12839, 12832.3, 12840.7, 12834.4, 12846.2, 12842.1, 12853.1, 12849.2, 12862.3, 12857.2, 12868.8, 12863, 12872.5, 12866.7, 12876, 12872, 12889.6, 12885, 12900.4, 12898.8, 12910.1, 12905.9, 12915.6, 12911, 12918.9, 12913.8, 12924.6, 12919.8, 12936.7, 12934.3, 12946.6, 12940.8, 12953.2, 12948.4, 12972, 12968.3, 12983.9, 12976.3, 12988.6, 12981.2, 12990, 12983.9, 13005.6, 12999.2, 13008.4, 13001.7, 13010.9, 13004.2, 13013, 13007.2, 13017.1, 13010, tapescan.txt ! -6.17969 ! -6.70898 ! -6.70898 ! -6.00293 ! -7.06152 ! -6.88574 ! -5.64941 ! -5.11914 ! -7.41602 ! -7.06152 ! -6.53223 ! -5.65039 ! -5.29688 ! -5.64941 ! -6.53223 ! -6.35645 ! -6.35547 ! -6.00195 ! -4.76758 ! -4.59082 ! -3.35547 ! -3.53125 ! -4.7666 ! -5.47266 ! -9.53418 ! -8.29785 ! -6.00293 ! -6.17871 ! -3.88477 ! -6.53223 ! -5.82617 ! -6.17969 ! -4.7666 ! -5.12012 ! -5.2959 ! -6.88574 ! -7.23828 ! -6.70898 ! -6.35645 ! -4.06055 ! -3.88477 ! -5.12012 ! -5.82617 ! -5.82617 -4.06055 ! -4.59082 ! -1.58887 ! -4.2373 ! -4.59082 ! -5.12012 ! -4.7666 ! -2.47266 ! -5.82617 ! -4.7666 ! -3.70801 ! -7.5918 ! -7.41504 ! -6.17969 ! -6.35547 ! -6.70898 ! -6.70898 ! -5.82617 ! -7.06152 Page 6 C~ 13031.9, 13023.8, 13040.4, 13033.3, 13043, 13038.8, 13049.7, 13043.6, 13051.9, 13047.3, 13055.6, 13049.6, 13069.6, 13066.6, 13147.3, 13144.3, 13150.8, 13147.6, 13153.1, 13150.1, 13155, 13151.7, 13159.4, 13156.6, 13168.3, 13164.2, 13172.9, 13167.6, 13178.7, 13174.6, 13185, 13181.2, 13198.3, 13195, 13202.5, 13199.1, 13205.5, 13201.8, 13213.7, 13209.4, 13216.2, 13211.7, 13220.4, 13215.6, 13237.5, 13231.7, 13244.2, 13239.3, 13258.2, 13253, 13266.8, 13261.2, 13271, 13265.3, 13277.7, 13272.9, 13286.7, 13281.6, 13288.8, 13284.2, 13299.7, 13295.2, 13302.9, 13297.1, 13304.9, 13300.1, 13314.1, 13309.5, 13316.7, 13312, 13319, 13315.1, 13322.9, 13318, 13329.1, 13326.3, 13338.3, 13334.9, 13341.5, 13339, 13347.8, 13344.6, 13350.6, 13346.6, 13357.4, 13355.6, 13360.2, 13357.4, 13363.9, 13360.6, 13365.5, 13362.5, 13369, 13365.7, 13371.9, 13370.3, 13376.1, 13374.3, 13378.9, 13377.7, 13381, 13378.9, 13391.6, 13388.8, 13404.9, 13394.9, 13411, 13403.3, 13414.2, 13406.8, 13415.6, 13408.9, 13424.6, 13416, tapescan.txt ! -8.12109 ! -7.0625 ! -4.2373 ! -6.17969 ! -4.58984 ! -6.00293 ! -3.00195 ! -3.00195 ! -3.17773 ! -3.00195 ! -3.35449 ! -2.8252 ! -4.06152 ! -5.29688 ! -4.06055 ! -3.88477 ! -3.35449 ! -3.35449 ! -3.70703 ! -4.2373 ! -4.41406 ! -4.7666 ! -5.82617 ! -4.94336 ! -5.12012 ! -5.65039 ! -5.64941 ! -4.7666 ! -5.12012 ! -4.59082 ! -4.59082 ! -5.82617 ! -4.7666 ! -4.58984 ! -4.7666 ! -3.88379 ! -4.94336 ! -2.8252 ! -3.35449 ! -2.47168 ! -3.17773 ! -4.06055 ! -1.76562 ! -2.8252 ! -3.35449 ! -3.00195 ! -3.35449 ! -1.58887 ! -1.76562 ! -1.23633 ! -2.11816 ! -2.8252 ! -10.0635 ! -7.76855 ! -7.41504 ! -6.70898 ! -8.65039 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 410 records... • Page 7 • • Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR cSG dated 26 Oct 2007 per NP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) optical Lod 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: FRAME SPACE = 0.500 * F tapescan.txt 10 bytes 132 bytes 1 ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 143 Tape File start De th = 10987.500000 Tape File End Depth = 13560.500000 Tape File Level spacing = 0.500000 Tape File Depth units = feet Page 8 • tapescan.txt **** FILE TRAILER **** Tape Subfile: 2 156 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! 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 Lod 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: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code Samples units 68 1 F%HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 287 Tape File start De th = 10990.000000 Tape File End Depth = 13569.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet Page 9 • tapescan.txt **** FILE TRAILER **** Tape Subfile: 3 300 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 07/10/25 1626273 O1 **** REEL TRAILER **** MWD 09/02/09 BHI Ol 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 10987.5000 90.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10988.0000 97.4740 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11000.0000 110.5399 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11100.0000 62.5058 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11200.0000 83.7967 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11300.0000 46.4328 17.8065 1685.0596 3.3575 5.1697 3.4748 Page 10 • tapescan.txt 11400.0000 89.1820 48.2795 4.5764 5.3281 6.0235 6.4399 11500.0000 131.2010 49.5997 3.8353 4.8446 5.8527 7.6950 11600.0000 33.6368 49.7774 5.8665 5.8335 6.4093 6.4023 11700.0000 37.2308 83.6694 5.6335 5.9178 7.2030 8.6228 11800.0000 53.8134 60.6940 5.2774 5.6003 6.4030 6.9958 11900.0000 52.1845 48.2586 7.4017 6.7302 7.2218 6.8385 12000.0000 31.9000 91.2000 5.9200 6.7740 8.1340 9.7840 12100.0000 37.5544 79.3029 5.1008 5.3578 6.2605 7.2014 12200.0000 52.1958 85.7241 5.4860 5.4610 5.9969 6.2485 12300.0000 35.7656 105.5387 4.8153 4.5797 4.6160 4.5210 12400.0000 82.9757 71.7696 4.0813 4.7376 5.8035 6.5337 12500.0000 74.3958 107.1042 3.4137 5.3623 6.5203 6.8251 12600.0000 38.1526 82.6740 1.2343 2.6458 3.6527 6.6859 12700.0000 53.0197 73.9398 3.3573 4.9899 5.8380 7.5828 12800.0000 55.8116 120.7582 2.9277 5.2803 4.8373 6.2582 12900.0000 52.1868 98.5451 2.9563 4.3211 5.3088 5.7146 13000.0000 81.3239 91.8061 3.6009 3.7049 4.3818 4.7362 13100.0000 36.2000 90.4000 4.4940 4.5720 5.2690 5.9310 13200.0000 35.2989 99.7993 4.3470 3.9330 4.4400 4.8000 13300.0000 41.7695 100.9027 4.9410 4.4800 5.0490 .5.4120 13400.0000 53.9015 106.5719 5.6274 5.3769 6.1150 6.7146 Page 11 • tapescan.txt 13500.0000 34.4387 59.2422 7.2602 6.6938 7.3949 7.5927 13560.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 10987.500000 Tape File End Depth = 13560.500000 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 10990.0000 90.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10990.2500 92.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11000.0000 122.9000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11100.0000 63.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11200.0000 64.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 11300.0000 33.9000 26.5000 2162.8501 3.6270 4.2120 3.5220 11400.0000 84.4000 57.3000 4.9280 5.5900 6.2960 6.5530 11500.0000 97.1000 51.9000 4.1950 5.2500 6.6570 8.8870 11600.0000 30.7000 47.3000 5.5800 5.4670 5.9720 6.0010 11700.0000 41.5000 50.6000 5.6690 6.1300 7.4980 9.1880 11800.0000 69.3000 66.8000 5.0190 5.4000 5.9960 6.4350 11900.0000 168.3000 48.6000 7.3000 6.5040 7.4980 7.6030 12000.0000 35.1000 71.0000 5.8430 6.6150 7.8090 8.9720 12100.0000 32.2000 81.5000 5.0430 5.2840 5.9970 6.6480 12200.0000 54.1000 89.3000 5.0770 4.8590 5.3200 5.5290 Page 12 tapescan.txt 12300.0000 34.8000 90.7000 4.5000 4.5280 12400.0000 80.6000 76.8000 6.1330 6.7260 12500.0000 81.5000 100.2000 6.7400 9.2170 12600.0000 43.3000 102.1000 1.7710 2.4720 12700.0000 49.7000 84.7000 5.6670 7.1350 12800.0000 58.4000 111.4000 6.9780 9.5030 12900.0000 50.4000 100.0000 5.1570 5.6060 13000.0000 38.6000 94.2000 3.8970 3.9450 13100.0000 37.4000 101.1000 5.1780 5.9700 13200.0000 29.8000 100.4000 4.6790 5.1370 13300.0000 34.4000 97.9000 5.5630 6.2090 13400.0000 54.6000 90.6000 6.0530 6.8970 13500.0000 41.8000 117.3000 8.5540 9.4110 13569.0000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File start De th = 10990.000000 Tape File End Dept h = 13569.000000 Tape File bevel Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS 4.6680 4.1440 2.9730 1.3110 3.4240 2.5940 2.8830 3.4460 4.3780 4.4590 5.0080 5.2830 7.5160 -999.2500 4.3990 5.1300 7.3670 1.4100 4.8370 13.0510 4.1260 3.6760 4.4300 4.0780 4.8450 5.1580 7.3410 -999.2500 Page 13
