The URL can be used to link to this page

Home My WebLink About208-1757. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU N-18A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-175 50-029-20906-01-00 10415 Conductor Surface Intermediate Intermediate 2 Liner 9051 80 2682 3031 9719 827 10104 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8825 30 - 110 29 - 2712 27 - 3058 25 - 9744 9587 - 10414 30 - 110 29 - 2712 27 - 3056 25 - 8563 8444 - 9050 10152 2670 4760 5410 7500 10104, 10109, 10153 5380 6870 7240 8430 10003 - 10175 4-1/2" 12.6# 13Cr80 23 - 9595 8752 - 8877 Structural 4-1/2" Baker S-3 Perm Packer 9519 8392 Torin Roschinger Operations Manager Brenden Swensen brenden.swensen@hilcorp.com 907-748-8581 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028282 23 - 8450 N/A N/A 117 Well Not Online 1722 4453 1300 1450 280 1340 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 9519, 8392 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 4:03 pm, Mar 20, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.03.19 16:02:48 - 08'00' Torin Roschinger (4662) RBDMS JSB 032725 JJL 4/9/25 DSR-3/28/25 ACTIVITY DATE SUMMARY 3/13/2025 *** WELL S/I ON ARRIVAL*** (ADPERF) MIRU YELLOW JACKET E-LINE. PT PCE 300 PSI LOW./3000 PSI HIGH, FUNCTION TEST WLVS CORRELATE TO SLB PERFORATION RECORD DATED 13-MAR-2018 DRIFT 10' 2" DMY GUN TO 10082' PERFORATE 10050' - 10060' WITH 2'' G6SPF 60PHASE HSC W/GEO RAZOR CHARGES CCL TO TOP SHOT=7.4' CCL STOP DEPTH=10042.6', CONFIRM SHOTS FIRED PERFORM WELL CONTROL DRILL WITH WSL ***WELL S/I ON DEPARTURE*** JOB COMPLETE Daily Report of Well Operations PBU N-18A 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU N-18A Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-175 50-029-20906-01-00 10415 Conductor Surface Intermediate Intermediate 2 Liner 9051 80 2682 3031 9719 827 10104 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 8825 30 - 110 29 - 2712 27 - 3058 25 - 9744 9587 - 10414 30 - 110 29 - 2712 27 - 3056 25 - 8563 8444 - 9050 10152 2670 4760 5410 7500 10104, 10109, 10153 5380 6870 7240 8430 10003 - 10175 4-1/2" 12.6# 13Cr80 23 - 9595 8752 - 8877 Structural 4-1/2" Baker S-3 Perm Packer 9519, 8392 9519 8392 Torin Roschinger Operations Manager Leslie Manning lreavis@hilcorp.com (907)777-8326 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028282 23 - 8450 N/A N/A 167 Well Not Online 1695 2134 1106 1850 215 1740 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 8:09 am, May 02, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.05.02 04:54:01 -08'00' Torin Roschinger (4662) RBDMS JSB 051324 WCB 7-29-2024 DSR-5/2/24 ACTIVITY DATE SUMMARY 4/4/2024 ***WELL S/I ON ARRIVAL***(drift 30' x 2.29" dmy perf gun, pre-eline) RAN 30' x 2" DMY PERF GUN (2.29" od), 1.75" SAMPLE BAILER, DRIFT CLEAN TO 10,080 ' SLM *** WELL LEFT S/I ON DEPARTURE .. DSO NOTIFIED *** 4/24/2024 ***WELL S/I ON ARRIVAL*** (PERFORATE INTERVAL WITH 10' OF 2'' GUN GEO RAZOR 6spf 60 DEG PHASE) RIG UP YJ ELINE. PT PCE 300 PSI LOW /3000 PSI HIGH RUN #1 W/CHX2 1.69" GUN GAMMA-CCL 10' OF 2" GEO RAZOR GUN 6 spf 60 DEG PHASE TO PERFORATE INTERVAL 10072' - 10082 TOP SHOT 8.2' CCL STOP DEPTH 10063.8' MD RUN#2 W/CH/1.69'' WB/1.69 CCL/2.30'' OD HEX PLUG, PLUG COULDN'T PASS TROUGH THE PATCH AT 9991' TO 10026' , ON THE SECOND ATTEMPT THE TOOL STUCK AND PULL COUPLE LBS OVER AND GET FREE WSL MAKE DECISION TO POOH AND AWAIT PLAN FORWARD FROM TOWN GR-CCL CORRELATED TO SLB PERFORATING RECORD DATED 13-MARCH- 2018 ***WELL S/I ON DEPARTURE*** Daily Report of Well Operations PBU N-18A DEG PHASE TO PERFORATE INTERVAL 10072' - 10082 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 10/17/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20231017 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 212-26 50283201820000 220058 9/2/2023 AK E-LINE Perf KBU 14-6Y 50133205720000 207149 9/18/2023 AK E-LINE GPT/Plug KBU 23-05 50133206300000 214061 9/9/2023 AK E-LINE GPT/Perf MP S-21 50029230650000 202009 10/7/2023 READ CaliperSurvey MPU C-23 50029226430000 196016 9/21/2023 AK E-LINE Perf MPU M-22 50029236450000 219111 9/20/2023 AK E-LINE Mechanical Cutter Paxton 7 50133206430000 214130 9/8/2023 AK E-LINE Tubing Punch/RCT PBU 06-16B 50029204600200 223072 10/7/2023 HALLIBURTON RBT PBU D-18B 50029206940200 215001 9/14/2023 BAKER RPM PBU J-19 50029216290000 186135 9/26/2023 AK E-LINE TTBP/Cement PBU J-23A 50029217120100 204193 10/4/2023 BAKER SPN PBU N-18A 50029209060100 208175 9/4/2023 BAKER SPN PBU P1-02A 50029217790100 202065 9/11/2023 BAKER SPN PBU P1-13 50029223720000 193074 9/15/2023 HALLIBURTON IPROF PBU R-12A 50029209210100 211055 9/7/2023 BAKER SPN Please include current contact information if different from above. T38062 T38063 T38065 T38064 T38066 T38067 T38068 T38069 T38072 T38073 T38074 T38075 T38076 10/20/2023 T38070 T38071 PBU N-18A 50029209060100 208175 9/4/2023 BAKER SPN Kayla Junke Digitally signed by Kayla Junke Date: 2023.10.20 08:34:04 -08'00' Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 06/01/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 6/1/2023. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 6/1/2023. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/01/2023Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateL-2072210815002923702003.371.31/23/2023123/1/2023L-2312230105002923746003.003.0-393/27/2023M-111810575002920589002.602.6-105/29/2023M-311920325002922256001.501.5-165/29/2023M-331941165002922504001.301.3-145/29/2023N-171830095002920898001.201.2-115/30/2023N-18A2081755002920906010.500.5-65/30/2023N-21A1961965002921342011.001.0-85/30/2023N-272071045002923365000.500.5-45/30/2023N-292141105002923521002.302.3-245/30/2023N-31215175500292356000-0--205/30/2023V-2342220045002923707006.3210.91/23/2023243/1/2023W-2412221545002923741002.502.5-263/1/2023Z-121891025002921977000.700.7-45/23/2023Z-34212061500292346900-0--155/27/2023Z-402111735002923462000.700.7-65/27/2023Z-46A2052035002923280010.500.5-35/23/2023Z-502120015002923463000.500.5-35/27/2023Z-662121955002923482000.700.7-85/27/2023Z-116211124500292345500-0--175/27/2023Z-210204181500292322600-0--125/27/2023Z-2292221045002923726003.8361.23/5/2023363/27/20230.500.5-5/30/2023N-18A2081755002920906016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS nest` n-) - 1. Operations Performed Abandon ❑ Plug Perforations m Fracture Stimulate ❑ Pull Tubing ❑ Operations,srutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing-_ ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Set Liner Patch 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ® Exploratory ❑ 5. Permit to Drill Number. 208-175 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-20906-01-00 7. Property Designation (Lease Number): ADL 0282828. Well Name and Number PBU N -18A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary. Total Depth. measured 10415 feet Plugs measured 10109, 10153 feet true vertical 9051 feet Junk measured 10152 feet Effective Depth: measured 10105 feet Packer measuretl9519 feet true vertical 8826 feet Packer true vertical 8392 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" x 30" 30-110 30-110 Surface 2682 13-3/8" 29-2711 29-2711 5380 2670 Intermediate 3031 9-5/8" 27-3058 27-3056 6870 4760 Intermediate 9719 7" 25-9744 25-8563 7240 5410 Liner 827 4-1/2" 9587-10414 8444-9050 8430 7500 Perforation Depth: Measured depth: 10003 - 10175 feet True vertical depth: 8752-8877 feet Tubing (size, grace, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 23-9595 23-8450 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 9519 8392 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13_ Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 444 26716 78 1961 337 Subsequent to operation. 238 2123 1492 1929 191 14.Attachments: (required per 28 MC 25.070.23071,125.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ® Service ❑ Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Rl Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 herebycertify that the foregoing fY regoing is true and correct to the best of my knowletlge. Sundry Number or N/A if C.O. Exempt. NIA Authorized Name: Stechauner, Bernhard Contact Name: Stechauner, Bernhard Authorized Title: FS2 ead PE Contact Email: Bemhard.Stechauner(cQbp.com Authorized Signature: Date: 811 //19 Contact Phone: +1 907 564 4594 Form 10- 406 Revised OV2017 �`'/�/'/ 6"0^'0, 4• RBDMS-14P.06 0 8 2019 Submit Original Only Daily Report of Well Operations PBU N -18A 7/18/2019 CTU#9 1.75" CT. Job Scope: Depth Log / Set Baker Patch MIRU CTU. ***Continue Job on 7/19/19 WSR*** CTU#9 1.75" CT. Job Scope: Depth Log / Set Baker Patch Finish Weekly BOP Test. Make up and RIH with 3.700" DJN and 2.375" PDS GR/CCL Carrier. Tagged bottom at 10106' CTM. Log up at 50fpm to 8500. Flagged pipe at 9950.56'. Pooh. Received good data ( 0' Correction). Corrected TD at 10104.34'. Correlated to Baker Hughes RPM Log 21 -June -2016. RIH w/ Baker Lower Patch ( LIH Length = 8.21'). Lightly tag TOC & correct depth. Set Lower Patch Element at 10022'. Btm of patch at 10026.31'. Pooh. 7/19/2019 ***Continue Job on 7/20/19 WSR*** CTU#9 1.75" CT. Job Scope: Depth Log / Set Baker Patch Continue Pooh. Make up R Rih w/ Baker Upper Patch Section ( LIH Length= 27.95'). Tag/snap into lower patch. Overpull 3.5k to confirm latched in. Set Patch setting upper element at 9993.1'. Top of patch at 9991.41'. Pooh. Freeze Protect Tbg w/ 39 bbls of Methanol. 7/20/2019 ***Job Complete*** TREE= CJW V1aLHEAD= MCEVOY ACTUATOR= BAKER OKB. BB/ = 6920' BF. E -B/ = 40.46' KOP= 3050' Max Angle = 44° @ 9847 Datum MD= 10163' Datum TVD= 8800 -SSI 1 2712' 1 Minimum ID = 2.36"@ 10017' SNAP LATCH 9-5/8" WHPSToCK(12/16m8) 3068' IG, 26#, L-50 TG XO TO L-80 BTC 9-5/8' CSG, 47#, L-60, D = 6.681' N— SAFETY NOTES:One lock down screw on 9-5/8" 1 8A casing packolf broke; replaced with blank "'4-12" CHROME TBG, LNR & NIPPLES "°ORIG WBS NOT SHOWN BELOW WHIPSTOCK— 2236' 4-12' HES X NIP, D =3.813' 2590' 9-5/8" OV PKR GAS LFT MANDRELS PERFORATION SUMMARY REF LOG: SWS MWD LOG 1228108 ANGLE AT TOP PERF: 44'@ 10095' Note: Refer to Production DB for Nstodcal data SIZE SPF INTERVAL OPrVSqz SHOT SQZ 3318" 6 10003 -10013 C 03/31/09 051 2-12" 6 10095 -10100 O 03/13/18 BK 33/8' 6 10112-10127 S 03130189 11/30/17 3318" 6 10126 -10146 S 03111 /09 11/30/17 2-718" 6 10130-10150 S 0227109 11/30/17 33/8" 6 10155-10175 C 01/06/09 11/30/17 3-3/8' 6 10155-10175 C 01/06/09 11/30/17 4-12' TBG, 12.6#. 13 It VAM TOP, 9695 .0152 bpf. D = 3.958' :, 26#, L-80 BTG .0383 bpf, D = 6.276' 9744' 13 -CR VAM TOP, .0152 5 3811 3779 19 KBG2-1R DONE BK 16 051 4 6269 5824 36 KBG2-7R DONE BK 20 051 3 7849 7109 36 KBG2-1R DMY BK 0 121 2 8880 7908 41 KBG2-1R DAM BK 0 12 1 9411 8310 40 KBG2-1R DAM BK 0 121 MLLOUT WINDOW (N -18A) 3058'-3075- PBTDH 10329' IT J—t�-1/2' HES X NP, D = 3.813" 9519' 7' X 4-12" BKR S-3 PKR. D = 3.870" 8667 4-1/2' HES X NIR ID = 3.813" 9683' 4-12" FES XN NP, D = 3.725- 9687' 17' X 5' HR ZXP LTP VAEBACK SLV, D =4.460' DATE I REV BY COMMENTS DATE REV BY COMMENTS 022B1113 I ORIGINAL COMPLETION 0225/19 BTWJMD SET WFT WRP 02/17/19 03105189 RWO 0621/19 MTH/JMD PULLED WRP (05r2811 9) 12182186 N7ES SIDETRACK (N -118A) 07/31179 JDM/JMD SET PATCH 0720/19 12/05/17 TFA/JMD SETCMT RET&MLLEDDH 03/19/18 BTWJMD ADPERFS 03/13/18 0827/18 NXW/JMD SETCBP/rOC 08/22-23118 9605 7' X 5' BKR FLEXLOCK LNR HGR, D = 4.450' 9612' 5'X4 -1/2'X0,0=3. 9991' - 10026' PATCH. D = 2.36.1 4-1/2- WFT BIG BOY CIBP (0822/18) FFISH-- 4-12" BKR MAGNUM RET PALLED & PUSHED1/29/17) 1 10153' 1 W4 CV 1111 PRUDHOE BAY UNIT WELL: N -18A PERMrr No: 1081750 API No: 50-029-21906-01-00 BP Exploration (Alaska) LI 1 • 0 Cv" CO s Ic-- co e- � rr � rrr a X (o N CO g a 2 2 O '� L.) M O7 0o 4'' to >, I,,, N _ NY o v C° ( Y 0J Z_. r^ r T P r r U i-, G > O K; co +. O ) O) O U a a c c — a) c >, co ,3v c 15 a - c Q _> t U E a c Q 0 Q ur 00 00 00 00 00 00 00 " a O m W r r of J Q c .� Q 2 R .�C O V1 O LL LL LL LL L @ v) eN f` NM L th Z Q .- O LUUO OC ,_ 0000000 OA v ❑ O "'I.' } W W W W W W W U `� H U. LL LL LL LL LL LL 4-, 0) Q) 0) -0 a Q > L O) a z Z Z Z Z Z Z u Cu 0 O *Cr ❑ N LL LL LL LL LL LL LL > .G U O1 C 4, N C O) 4/ O a O EC Q1 a O! u 4J z U -_ _n c o meA r- N a • E a L > U v +J .c u• o 0 I- > > I- Q 1-6 a co.. c a C U N 2 CC w 2 0 o Wo N m 2 Q 0 vv., m H °' w uvi o- m ,, > O m m FU E Ca L O z v v) U U a) • C OI .I W = to C — O > > d U In Q31 W. +a) a a Ol Y 0-3 ❑ m OJ o C7 > Q 'C OA a s-' —4, 7 06 t O1 CC3 -0 C i Z O ^ t°Do Z E O! U f0 >> p w _ � 6 > > > ar c > 0 z N > C V a O J O O O J O is O Q Q Q m Q 1,> E2 d ani a1) 00)) m ` JO <n v`�) VI 2 E E E 2 E E • o 2m0mQmm OZ z00 000 0 gy m' 00 oxxQxxxx ° H' L., > > > Q = > a I At,:�I Li/ CO 0 " a a a a a , ° a' W°'..,: On 03 :' ❑ W oVI N M M 00 C) MM M M NM X V = Q CO O O O O r O a O E ■■ 0 0 Oo 0 0 0 0 O a) cc cc d = O O a O O al W ❑ X h CO I', w N ,.00 0 0 0 0 0 0 to [f 00o5 CA BVI N - N N el 44:3M N 0 O 0 J N (1 N N (1 N N N L Q OR a) O) Q) T O) O) 6) O1 , N N N N N N N 'y p) 0 O O O O O O _ OO O O O O O c C in in O O O Q 0 Y CC CLIw u-) .c9J CO O1 Q� Z 01 E d •> aU_, 03 sa F Q pCl OC 1 i 7 a v v .{ ` Q cr, QCIO Q o Q Q 4, .4, +3+ an y Z ...' bD di Z N �f) r N 0 co 01 V E d H Ft vi )2 N 40 N r C (O a C = a N w. 0 ,02 %- (40Z ❑ Cl)C - Z H Y N U N Cit; 11111 C ra vl Q i 'V' C L Q) co O CID a H a a Q i'..44*04414-0;ii id ICY STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION CO ION q ��q REPORT OF SUNDRY WELL OPER NS APR 1 to 1. Operations Performed Abandon 0 Plug Perforations IZI Fracture Stimulate 0 Pull Tubing 0 OperatiAGGCC Suspend 0 Perforate II Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Cement Squeeze ESI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-175 3. Address: P.O.Box 196612 Anchorage, Development 21 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20906-01-00I 7. Property Designation(Lease Number): ADL 028282 8. Well Name and Number: PBU N-18A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 10415 feet Plugs measured 10153 feet true vertical 9051 feet Junk measured 10152 feet Effective Depth: measured 10153 feet Packer measured 9519 feet true vertical 8861 feet Packer true vertical 8392 feet Casing: Length: Size: MD: ND: Burst: Collapse: Structural Conductor 80 20"x 30" 30-110 30-110 Surface 2681 13-3/8" 29-2711 29-2711 5380 2670 Intermediate 3031 9-5/8" 27-3058 27-3056 6870 4760 Intermediate 9689 7" 25-9711 25-8538 7240 5410 Liner 827 4-1/2" 9587-10414 8444-9050 8430 7500 Perforation Depth: Measured depth: 10095-10100 feet True vertical depth: 8819-8822 feet Q Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 23-9595 23-8450 Packers and SSSV(type,measured and 4-1/2"Baker S-3 Perm Packer 9519 8392 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10003-10150-21 Bbls SqueezeCrete,22 Bbls Class'G' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 413 18800 19 0 1206 Subsequent to operation: 0 0 0 700 620 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory 0 Development p Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil IZI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt. N/A Authorized Name: Bergene,Matthew Contact Name: Bergene,Matthew Authorized Title: Production Engineer Challenger Contact Email: Matthew.Bergeneabp.com Authorized Signature: _-o''' Date: Li G/t O(' Contact Phone: +1 9075644849 Form 10-404 Revised 04/2017 j/77- 4/2-6` `a RBDMS;f ,PR 1 12015 Submit Original Only� �rte • Daily Report of Well Operations N-18A ACTIVITYDATE SUMMARY T/I/0=2378/900/0 (LRS Unit 42 Assist CTU - Load IA) Pumped 5 bbls 60/40 followed by 120 bbls crude to load the IA. Hang AFE sign, notify DSO FWHP's 2069/1150/9. SSV SV WV AL = C MV= 0 CVs = OTG **Well S/I upon 11/27/2017 departure** CTU#8 1.75" CT Job Scope: Drift/Set Cmt retainer/Cement MIRU CT. Test BOP's. 11/27/2017 ***In Progress*** CTU#8 1.75" CT Job Scope: Drift/Set Cmt retainer/Cement MIRU CTU. Perform Weekly BOP Test. MU & RIH w/HES 2-7/8" Logging Carrier&3.70" JSN. 11/27/2017 ***Continue Job on 11/28/17 WSR*** CTU#8 1.75" CT. Job Scope: Depth Log/Set Cmt Retainer/Cement/Mill. Continue RIH w/HES 2-7/8" HES Logging Carrier&3.70"JSN. Bullhead 195 bbls 1% KCL w/Safelube. Tag CIBP at 10155'. Log from compression from 10155'to 9000'. Flagged pipe at 9900'. Pooh. Receive good data ( -5' Correction). Tied into Slb Jewelry Log 6-Jan-2009. MU & RIH w/Baker Composite 4-1/2" Cement Retainer. Correct Depth at Flag. Set top of Cement Retainer at 9970'. Puh to 9930' & Pressure Test Retainer to 1500psi -Good Test, no losses. Pooh. MU & RIH w/Baker Stinger BHA. Unable to sting into retainer by trying various methods. Pooh to reconfigure BHA. Trim 100'of pipe&re- head. MU & RIH w/Baker Stinger BHA w/longer bar-bell configuration. At 4000' circulate 60/40 Freeze Protect around. Continue RIH. Tag retainer at 9980'. Unable to sting into retainer by trying various methods. 11/28/2017 ***Continue Job on 11/29/17 WSR*** CTU#8 1.75" CT. Job Scope: Depth Log/Set Cmt Retainer/Cement Sqz/Mill. Continue to attempt to sting into retainer. No luck trying various methods. Pooh. No marks on stinger. Add double knuckle joints &re-run Baker Stinger BHA. Tag retainer at 9979'. No getting stung in trying various methods. Pooh. No marks on stinger. MU & RIH w/Baker 3.70"Junk Mill. Tag retainer at 9977'. Mill/push retainer to PBTD at 10156'. Pump 15 bbls of powervis &chase to surface at 80%. Freeze Protect Coil & pump 10 bbl meth cap in well. 11/29/2017 ***Continue job on 11/30/2017*** • • Daily Report of Well Operations N-18A CTU#8 1.75"CT. Job Scope: Cement Sqz MU & RIH w/2.50" BDJSN. Bullhead 230 bbls KCL& 120 bbls Diesel to underbalance well. Tag PBTD at 10158' down/ 10155' up. Same depth Mill Tagged TD. Puh 5' & flagged pipe at 10150'. Puh to 9900'. Finish pumping KCL&diesel. Baseline Static Pressure= 350psi. Pump 1% KCL down Coil &perform Injectivity Test. Baseline Injection Pressure at 1 bpm = 1350psi. 0.5bpm= 1000psi. Batch mix SqueezeCrete&Class G Cement. Pump 21 bbls of 14ppg SqzCrete &22 bbls of 15.8ppg Class G Cement. RIH to Flag at 10150' (5' above PBTD). Let 1 bbl around nozzle. Lay in Cement up to 8950'. Close choke & pump 18bbls to get 1000psi bump over baseline injection pressure. Was able to get almost all SqzCrete behind pipe—18 bbls when initial bump was applied.. Open choke&continue to lay in remaining cement. Puh to safety. Circulate meth over gooseneck. Work up to a Final Sqz Pressure of 3000psi. —26.5 bbls behind pipe. Able to hold final squeeze for—35 mins due to thickening time. Launch 3/4" ball &contaminate cement down to flag. Make down/up/down passes from TOC to Flag. Reduce rate to 1 bpm jetting across perfs. During 2nd contamination down pass, had sudden whp drop. Appears Squeeze broke but still able to get returns. Continue cleanout&chase ooh at 80%. Discuss w/APE. Lay in 60/40 Freeze Protect from 2500'tvd. Wash BOP's. Rig Down CTU. 11/30/2017 ***Job Complete*** ***WELL S/I ON ARRIVAL SWCP 4518***(cement squeeze) RAN 10' x 2.50" DUMMY GUN, 1 3/4"S-BAILER T/D @ 10,147' SLM (10,152' MD) +5' CORRECTION RAN 4 1/2"X-CATCHER FOR CORRECTION S/D IN X-NIP @ 9547' SLM (9552' MD) +5' CORRECTION 12/28/2017 ***WELL LEFT S/I PAD OP NOTIFIED ON DEPARTURE*** T/I/O=VAC/670/0/0. Temp= SI. TBG FL (APE Request). ALP = 900 psi, AL SI @ casing valve. Increased TP with AL to 10 psi. Tbg FL @ 970' (15 bbls). Final WHPs= 10/670/0/0. 1/4/2018 SV, WV, SSV= C. MV= O. IA, OA= OTG. 11:00 Installed Wireless Pressure Gauges on IA/OA. Awaiting FCO pending Honeywell. SV= C. WV, SSV, MV= O. IA, OA= OTG. 1700 hrs. 2/9/2018 ***JOB STARTED ON 12-MARCH-2018***(SLB ELINE IPROF) WELL SHUT IN ON ARRIVAL. INITIAL_T/I/O/OO =0/725/0/0 MIRU. RIH W/PFCS. PERFORM BASELINE PASS DOWN AT 60 FPM. LRS LOAD TBG WITH 170 BBLS CRUDE @ 1BPM AND 2000 PSI. TAG TD @ 10123'. PERFORM 30/60/90 FPM UP/DOWN PASSES OVER 10123'-9900'. PERFORM STATION PASSES AT 10121', 10108', 10050', 9970',AND 9900'. ANOMALY AT 10,000'. 3/12/2018 LRS PUMP .5 BBL/MIN @ 1800 PSI DURING LOGGING. T/I/O= 0/731/12. Assist E-line Pumped 160 bbls crude to load TBG and establish an injection rate of 1 bpm @ 1975 psi. Pumped 52 bbls crude down TBG while E-line ran log. 3/12/2018 ***Job continues 03-13-18***. 3/13/2018 ***Job continued from 03-12-18*** Assist E-line. RDMO E-line on well upon departure. • • • Daily Report of Well Operations N-18A ***JOB CONTINUED FROM 12-MARCH-2018*** RUN 2. RIH W/2.5"X 5' PJO. PERFORATE 10095' - 10100', CCL TO TOP SHOT= 5.41', CCL STOP DEPTH = 10089.59'. WELL SHUT IN ON DEPATURE. FINAL T/I/O = 0/700/0/0 3/13/2018 ***JOB COMPLETE ON 13-MARCH-2018*** Fluids Summary Bbls Type 516.7 Bbls 60/40 Methanol 1397.1 Bbls 1% KCL w/Safelube 208.5 Bbls 1% KCL 122 Bbls PowerVis 41.8 Bbls Fresh Water 21 Bbls SqueezeCrete 22 Bbls Class'G' 417 Bbls Crude TREE=. CNV • k down screw on �ACTUATQR SOC N -18A Wing packofff broke;replaced with blank OKB.BB/= _69.20' ***4-1/2"CHROME TBG,LNR&MPPLES***ORI 3 BF.Et EV= 40.46' I 1 I WBS NOT SHOWN BELOW WHIPSTOCK** KOP= 3050' 1Vbx Angle= 44° 1-,9_842' Datum M __— D= . 10163 2236' —14-1/2"HES X NP D=3.813' 1. tum1VD= 8800 SS 2690' 9-5/8"DV PKR GAS LFT MAS 13-3/8'CSG,72#,LSo.D=12.3x7" H 2712' 11ST M4 TVD DEV TYPE VLVNLATCH FORT DkTE1 5 3811 3779 19 ' KBG2-1R DOME BK r 16 05/17/114 4 6269 5824 36 KBG2-1R DOME BK ' 20 05/17/14 Minimum ID =3.725" @ 9583' 3 7849 7109 36 KBG2-1R DMY BK ' 0 1226/08 4-112" XN NIPPLE 2 8880 7908 41 KBG2-1R DM ' BK ' 0 1226/08 1 9411 8310 40 KBG2-1R OW BK ' 0 1226/08 9-5/8"W- TOCK(12/16/08)V—I 3068' MLLOUT~OW(N-18A) 3058'-3075' 17"CSG,26#,L-80 TCti XO TO L-8013TC H 4297' 9-5/8"CSG,47#,L-80,D=8.881' H 9560' 1 , 9447' ---I4-1/2"HES X NP,D=3.813" PERFORATION SUMMARY 9519' I--'7"X 4-12"BKR S-3 PKR �i4 D=3.870" REF LOG:SV'IS MWD LOG 1228/08 ANGLE AT TOP PERF:44°@ 10095' �i , 9662' H4-1/2'FEB X NP D=3.813" Note:Refer b Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ Ilit 3-38" 6 10003-10013 S 03/31/09 11/30/17 9683' —14-1/2"HES XN MP.D=3.725" 2-12" 6 10095-10100 0 03/13/18 3-38' 6 10112-10127 S 03/30+09 11/30/17 3-38' 6 10126-10146 S 03/11/09 11/30/17 2-718" 6 10130-10150 S 02/27/09 11/30/17 9587' 7"X 5"F iR ZXP LIP w ITEBACK, 3-3/8" 6 10155-10175 C 01106/09 11/30/17 SLV,D=4.460" 3-3/8" 6 10155-10175 C 01/06/09 11/30/17 8696' H4-1/2"1NLEG,D=3.958" A9605' 1—r X 5"BKR FLEXLOCK 4-12"TBG,12.61/,13-CR VAM TOP, H 9595' LNR HCS D=4.450" .0152 bpf,0=3.958' 9612' H5"X 4-1/2"XO,0=3.93 17-CSG,26#,L-80 BTC,.0383 bpf,D=6276" —{ 9744' • 10152' —FISI-t 4-12"BKR MAGNUM CMT RET MLLE)&RJSI-EJ DH(11/29117) 10153' 4-112"HES EZ DRI.L 1CBP(0227/09) a% PBTD 10329' Vii1444:4A 4-1/2'LNR,12.6#,13-CR VAM TOP,.0152 bpf,D=3.958" —I 10414' DATE REV BY COMVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/28/83 ORIGINAL COM PLET ON 03/13/17 JGUJMD PUJ_E)DH CHOKE(03/09/17) WELL N-18A 03/05/89 RWO 07/18/17 MSS/JM)PULS)MP&ASH PB3MT No:'2081750 12/02/08 N7ES SIDETRACK(N-18A) 12/06/17 TFA/JM) SET CMT RET 8 MUM DH API No: 50-029-20906.01-00 05/19/14 SWC/JM)GLV C/O(05/17/14) 03/19/18 BTWJM)ADPERFS(03/13/18) SEC 8,T11N,R13E,1820'FPL&769'FSM. 08/04/16 CJWJM) SET DH CHOKE(07/27/16) 11/16/16 JTGJJM) RESET CH CHOKE(11/15/16) BP Bcploration(Alaska) I -2_01'- ki b BA ERCO 4111 PRINT DISTRIBUTION LIST UGHES a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska IRECEIVEr BP Exploration(Alaska) Inc. Petrotechnical Data Center,LR2-1 DATA LOGGED WELL NAME N-18A SEP 0 2017 900 E. Benson Blvd. t2011 Anchorage,Alaska 99508 K BENDER FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY PRUDHOE BAY CC LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska --- LOG DATE July 23,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares(a�bakerhughes.com TODAYS DATE August 26,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #OF PENIN I S #OF COPIES #OF COPIES #OF COPIES V 4 4 4 1 [BP North Slope. 0 1 1 1 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. (Anchorage,Alaska 99508 it 2 ConocoPhillips Alaska Inc. 0 0 1 1 0 Attn:Ricky Elgarico ATO 3-344 1700 G Street Anchorage,AK 99510 3 i ExxonMobil,Alaska 0 0 1 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 0 1 1 1 0 State of Alaska -AOGCC 41 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division ofOil&Gas *** 0 0 1 1 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 SCANNED SEP 1 2201Z ***Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,LR2-1 1900 E.Benson Blvd. 'Anchorage,Alaska 99508 Attn: Dodie Stinson TOTALS FOR THIS PAGE: 0 2 5 5 0 plc- \1$ RECEI\eD • 7._--1 39 -Z MR JUL 19 2616 PRINT DISTRIBUTION LIST BAKER HUGHES AOGCC Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska Inc. BP Exploration(Alaska) Inc. Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME N-18A 900 E. Benson Blvd. -11 2-1 BEND R Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY North Slope Borough LOG TYPE RPM:PNC3D BHI DISTRICT Alaska --- LOG DATE June 21,2016 AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bakerhughes.com TODAYS DATE July 14,2016 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM LOGS LOGS (las,dlis,PDF,META, (Compass)SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) CGM,Final Surveys) PERSON ATTENTION #OF PRINTS #UI-THIN I S #OF COPIES #OF COPIES #OF COPIES 4 4 4 4 _ 1 BP North Slope. 0 0 0 0 0 EOA,PBOC,PRB-20(Office 109) D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 1 1 0 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 1 1 0 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 1 0 1 1 0 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas *** 0 1 1 0 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 *5*Stamp"confidential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. 0 0 I 0 I 0 0 Petrotechnical Data Center,LR2-1 900 E.Benson Blvd. eCpNNEO NOV 1 '8 2016 Anchorage,Alaska 99508 Attn:David Itter TOTALS FOR THIS PAGE: 4 4 0 0 TOTALS FOR ALL PAGES: 0 4 4 0 0 • s Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q $ - ~ ~~ Well History File Identifier Organizing (done) RE AN //Color Items: ~Greyscale Items: ^ Poor Quality Originals: o.w„a„ IIIIIIIIIIINIIIIII DIGITAL DATA ~skettes, No. ^ Other, No/Type: o Re,~~~~~ iiiuiuuuiiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: Q ~s~ Project Proofing III II'III II III I I III BY: Maria Date: /s~ Scannin Pre aration g P ~ x 30 = lG~~ + ~ I =TOTAL PAGES ~ (Count does not include cover sheet) t/- /~ BY: Maria Date: !.l-~~ I ~~ ls/ 1r U~~I .I Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ /D ~s~ 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 II II I II II I I II ReScanned III 111111 IIIII II III BY: Maria Date: /s~ Comments about this file: Quality Checked III II'lll III III III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 4/1/2010 Permit to Drill 2081750 Well Name/No. PRUDHOE BAY UNIT N-18A Operator BP EXPLORATION (ALASI(A) INC MD 10415 ND 9051 Completion Date 1/6/2009 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20906-01-00 UIC N REQUIRED INFORMATION - 1 Mud Log No Samples No Directional Survey es DATA INFORMATION Types Electric or Other Logs Run: DIR / GR /RES / PSD, DIR / GR /RES / NEU /DEN Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / Ty Med/Frmt Number Name scale meaia no star[ stop ~.n Kecewea ~.omrnenw ED Asc Directional Survey 0 10415 Open pt Dir~tonal Survey 0 10415 Open D C Lis 17515°'Induction/Resistivity 2860 10414 Open 1/28/2009 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, RAM, NPHI, TRPM Log Cement Evaluation 5 Col 2900 9525 Case 1/28/2009 USIT Cement, GR, CCL 26- Dec-2008 D C Pds /~ 17529vCement Evaluation 2900 9525 Case 1/28/2009 USIT Cement, GR, CCL 26- Dec-2008 g Completion 25 Blu 0 10282 Case 1/28/2009 Jewelry Log, Pres, Temp, GR, CCL 6-Jan-2009 ~C Pds 17530~ompletion 0 10282 Case 1/28/2009 Jewelry Log, Pres, Temp, ~ GR, CCL 6-Jan-2009 C D Pds 17735 ~oduction 0 10152 Case 3/20/2009 PPL, Pres, Temp, GR, CCL, Spin 11-Mar-2009 og Production 25 Blu 0 10152 Case 3/20/2009 PPL, Pres, Temp, GR, CCL, Spin 11-Mar-2009 og 17515 Induction/Resistivity 25 Blu 2860 10374 Open 1/28/2009 MD GR, ROP, FET, RPX, RPS, RPM, RPD, RAM, NPHI, TRPM Log 17515 Induction/Resistivity 25 Blu 2860 10374 Open 1/28/2009 TVD GR; ROP, FET, RPX, RPS, RPM, RPD, RAM, NPHI, TRPM \, DATA SUBMITTAL COMPLIANCE REPORT 4/1/2010 Permit to Drill 2081750 Well NamelNo. PRUDHOE BAY UNIT N-18A MD 10415 TVD 9051 Well Cores/Samples Information: Completion Date 1/6/2009 Name ADDITIONAL INFORMATION Well Cored? Y N Chips Received? Analysis Y / N Received? Interval Start Stop Operator BP EXPLORATION (ALASKIy INC Completion Status 1-OIL Current Status 1-OIL Sample Set Sent Received Number Comments API No. 50-029-20906-01-00 UIC N Daily History Received? '~/~~J~/ N Formation Tops V N Comments: Compliance Reviewed By: Date: c LQ s From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Tuesday, April 28, 2009 3:42 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Winslow, Jack L_.; Roschinger, Torin T.; Starck, Jennifer L Subject: OPERABLE: N-18A (PTD #2081750) Tubing Integrity Restored All, Well N-18A (PTD #2081750) passed a TIFL on 04/27/09 after gas lift valves were changed out. The passing test ;~ confirms that tubing integrity has been restored. The well has been reclassified as Operable. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, April 23, 2009 2:08 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Winslow, Jack L.; Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; Starck, Jennifer L Subject: UNDER EVALUATION: N-18 (PTD #2081750) Eval high IAP All, ~,t~ WeIIJ>!~I'~(PTD #2081750) has been found to have sustained casing pressure on the IA. The TIOs were 2270/2240/140/35 on 4/20/09. The IA was bled down to 750 psi and a TIFL, that failed, was performed on 04/20/09. It is suspected that a faulty or malfunctioning screened orifice is a possible cause for the failing TIFL. However, due to SimOps issues because the pad is temporarily shut-in we cannot peform further diagnostics on the well. The well has been reclassified as Under Evaluation. The plan forward for the well, once the pad is back online, is as follows: 1. S: Pull and re-run SO. 2. D: Re-TIFL. A wellbore schematic and TIO plot have been included for reference. Please contact me with any questions or concerns. Thank you. 8/6/2009 OPERABLE: N-18A (PTD #2050) Tubing Integrity Restored ~ Page 2 of 2 « File: N-18 (PTD #2081750) TIO.pdf» « File: N-18A.pdf» ,~ason E. ~DahCem forAndrea .~fughes alternate -Taylor Wellman by Alaska -Well Integrity Engineer office: 907-659-5098 cell: 713-299-2651 pager: 659-5100 x1446 harmony: 758-2418 8/6/2009 N-1 ~l}(PTD #2081750) TIO 4,000 x,000 2,DOD 1,DDD ~- Tbg -~ IA -~ OA OOA -~ OOOA -~- On •i TREE = CAM (McEwy} 4 118" WELLHEAD = MCEVOY ACTUATOR = OT15 KB. ELEV = 67.87' BF. ELEV = 40.46' KOP = 3000' Max Angle = 44° @ 9842' Datum MD = 10163' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~--) 2711, Min I®= 3.725'° ~ 9583' 4-1J2°' XN NIPPLE ST MD TVD DEV TYPE VLV LATCH POR DATE 5 3811 3779 19 KBG2-1R DOME BK 16 01/04!09 4 6269 5824 36 KBG2-1R SO 20 0 01/04/09 3 7849 7109 36 KBG2-1R DMY BK 0 12/26/08 2 8880 7908 41 KBG2-1R DMY BK 0 12/26/08 1 9411 8310 40 KBG2-1R DMY BK 0 12/26/08 9-5/8" MILL WINDOW (N-18A) 3058' - 3075' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 305$" 9-5/8" Top of Whipstock ~ 3058' 9-518" EZSV TBG CUT (12!01108) 42$7" ~ 7" CSG, 26# L-80, TCII, .0383 bpf, ID = 6,276" gQ4?' ~° -i4-1l2" FfF~ X NIP, ~ = 3.818" 1 T8G PUNCH 9189` 0000 ~ ~~ ' " " " ~ $519 X4-1 d2 BIER S-3 PF(R, ID = 3.87 7 P&A roc 9204' "~ ` 952' -~4-112" NES X t~P, El = 8.813 958` 4-112"NES XN N, dD - 3.725"' TOP OF 5" LNR TOP OF 7" LNR PERFORATION SUMMARY REF LOG: SWS MWD LOG 12/28!08 ANGLE AT TOP PERF: 44° @ 10126' No te: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpntSgz DATE 3-3l8" 6 10126 - 10146 O 03/11/09 2-718" 6 10130 - 10150 O 02127!09 3-3/8" 6 10155 - 10175 C 01/06/09 DATE REV B COMMENTS DATE REV B COMMENTS 02128/83 ORIGINAL COMPLETION 03/04/09 RRD/S SET CIBP /ADPERF (02/27109} 03!05189 RWO 03/19/09 RRK/S ADPERF (03/11109} 12101/08 JER PROPOSED SIDETRACK 12/28108 N7E5 5IDETRACK (N-18A) 01/13109 LLI/SV PERF (01/06109} 01/15/09 JCM/SV GLV CiO (01104/09) 9595" --~4-1/2" WLEG 9595' 4-1/2" TBG, 12.6# 13GR, VAM TOP, .0383 bpf, ID = 6.276" 905" F~ngerlLlner top packer _Q388 bpf, ID = 6.27fi'" 10152' 4-1/2" HES EZ DRILL CIBP {02(07/09) 10330" ~ PBTD 10414" 4-1/2" LNR, 12.6# 13CR VAM TOP, ID = 3.958" PRUDHOE BAY UNIT WELL: N-18A PERMIT No: '1830180 API No: 50-029-20906-01 SEC 8, T11N, R13E, 1820' 5NL & 769' EWL BP Exploratian (Alaska) STATE OF ALASKA ~ ~G~~~~~~~ ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~R ~ '~ ~~~;~ REPORT OF SUNDRY WELL OPERATIONS®,__,__ ~., „ „ „ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ er ' Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ _ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ ~ Exploratory ~ 208-1750- 3. Address: P.O. Box 196612 Stratigraphic ~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-20906-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 69.2 KB - PBU N-18A- 8. Property Designation: 10. Field/Pool(s): ADLO-028282 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10415 - feet Plugs (measured) 10156 3/30/09 true vertical 9051.01 - feet Junk (measured) None Effective Depth measured 10330 - feet true vertical 8989.42- feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2711 13-3/8" 72# L-80 Surface - 2711 Surface - 2711 5380 2670 Intermediate 3058 9-5/8" 47# L-80 Surface - 3058 Surface - 3056 6870 4760 Production 9744 7" 26# L-80 Surface - 9744 Surface - 8563 7240 5410 Liner 827 4-1 /2" 12.6# 13CR80 9588 - 10415 8445 - 9051 8430 7500 Perforation depth: Measured depth: See attached _ _ True Vertical depth: _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13cr80 Surface -9595' 0 0 - Packers and SSSV (type and measured depth) 7"x4-1/2" bkr s-pkr 9519' Hanger/Liner Top PKR 9605 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 88 2193 3014 340 Subsequent to operation: 99 2362 3076 370 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~' - Service ~` Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~- Gas ~` WAG ~ GINJ WINJ 1! WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature ~~ Phone 564-4944 Date 4/7/2009 Form 10-404 Re ised 04/2006 Syb~ ~O~riginal O ly~~~~ N-18A 208-175 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas De th Base Tvd Depth Top Tvd De th Base N-18A 1/6/09 PER 10,155. 10,175. 8,862.2 8,876.65 N-18A 2/27/09 BPS 10,153. 10,155. 8,860.76 8,862.2 N-18A 2/27/09 PER 10,130. 10,150. 8,844.14 8,858.59 N-18A 3/42/09 RPF 10,126. 10,146. 8,841.25 8,855.71 N-18A 3/30/09 APF 10,112. 10,127. 8,831.12 8,841.97 N-18A 3/31/09 APF 10,003. 10,013. 8,751.88 8,759.16 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE N-18A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY ~ 3/29/2009 ""*WELL SI ON ARRIVAL*** (ELINE ADPERF) INITIAL T/I/O = 250/0/150. RIG UP ELINE UNIT. ~ ~ "**JOB CONTINUED ON 30 MAR 2009 *"* ~ R ' 3/30/2009' ***JOB CONTINUED FROM 29 MAR 2009*** (ELINE ADPERF) PERFORATE INTERVAL 10,112 - 10,127 FT WITH 3 3/8" 3406 POWERJET HMX 6 SPF. API: ENTRANCE HOLE 0.37 IN; PENETRATION 36.5 IN. MAX SWELL IN LIQUID: 3.66 IN. FIRST 20 FT GUN DID NOT GET DOWN TO SHOOTING DEPTH, REPEATEDLY SAT DOWN AT I 9936 FT. SHOT INTERVAL WITH (1) 10 FT, AND (1) 5 FT GUN IN SEPERATE [ ~ RUNS. RIH WITH 10 FT GUN TO SHOOT TOP INTERVAL 10003' - 10013'. PERFORATIONS CORRELATED TO SLB JEWELRY LOG DATED 06 JAN 09. ~ TAGGED HES EZ DRILL CIBP 3 FT LOWER THAN WERE IT WAS SET ON 27 ~ ~ FEB 09. ""*JOB CONTINUED ON 31 MAR 09""" 3/31/2009 .*'"'"CONTINUED FROM 30 MAR 2009*'"* ! OBJECTIVE IS TO PERFORATE FINAL INTERVAL 10.003 - 10.013 WITH 3 63/8" 3406 POWERJET HMX 6 SPF. API: ENTRANCE HOLE 0.37. IN; PENETRATION 36.5 IN. MAX SWELL IN LIQUID: 3.66 IN. T/I/O = 90/0/150 NO I .CHANGE. CONFIRMED ALL SHOTS FIRED AT SURFACE, RD ELINE, 'CLOSE PERMIT W/ DSO. ALL VALVE POSITIONS AS FOUND UPON ARRIVAL. SWAB CLOSED. """JOB COMPLETE*** s .___~_ _ ~ ______ _ _ _ _ _ . ~___~___ __ ____ __--____-____. a FLUIDS PUMPED BBLS 1 diesel 1 Total ti~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3,1~~ ~~ 3 X009 REPORT OF SUNDRY WELL OPERATIONS~~j~~~~ ~`_ ~~ ~~~ ~:sr~ I'.nmmie~inn 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~~- Change Approved Program ~ Operat. Shutdown ~ Perforate Q , Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ - Exploratory ~~ 208-1750 - 3. Address: P.O. Box 196612 Stratigraphic r Service 6. API Number: Anchorage, AK 99519-6612 50-029-20906-01-00 - 7. KB Elevation (ft): 9. Well Name and Number: 69.2 KB - PBU N-18A 8. Property Designation: 10. Field/Pool(s): ADLO-028282 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: _ , Total Depth measured 10415 ~ feet Plugs (measured) 10153 2/7/09 true vertical 9051.01 - feet Junk (measured) None Effective Depth measured 10330 ~ feet true vertical 8989.42 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2711 13-3/8" 72# L-80 Surface - 2711 Surface - 2711 5380 2670 Intermediate 3058 9-5/8" 47# L-80 Surface - 3058 Surface - 3056 6870 4760 Production 9744 7" 26# L-80 Surface - 9744 Surface - 8563 7240 5410 Liner 827 4-1/2" 12.6# 13CR80 9588 - 10415 8445 - 9051 8430 7500 Perforation depth: Measured depth: See attached True Vertical depth: Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13cr80 Surface -9595' 0 0 - Packers and SSSV (type and measured depth) 7"x4-1/2" bkr s-pkr 9519' Hanger/Liner Top PKR 9605 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 77 6106 4048 403 Subsequent to operation: 42 3581 2242 200 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory Development ~ ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ' Gas ~ WAG ~ GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 3/19/2009 Form 10-404 Revisrsd 04/2006 ~ ~ ~ A,~~ i~ [:,~~1~~~ Submit Original Only ~t N-18A 183-018 PERF OTTOCHMENT Sw Name Operation Date Perf Operation Code - ---- - -- Meas Depth Top -- ----------- Meas Depth Base Tvd Depth Top Tvd Depth Base N-18A 1/6/09 APF 10,155. 10,175. 8,862.2 8,876.65 N-18A 2/27/09 BPS 10,153. 10,155. 8,860.76 8,862.2 N-18A 2/28/09 APF 10,130. 10,150. 8,844.14 8,858.59 N-18A 3/12/2009 RPF 10,126 10,146 8,841.25 8,855.71 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ''. N-18A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/11/2009.1'"*'`WELL IN TEST ON ARRIVAL""' INITIAL T/1/O: 550 (FLOWING)/225/150 PSI. LOGGED ACROSS PERFORATION INTERVAL (10130-10150 FT) WITH PL ISTRING. STOP COUNTS DONE FROM PLUG UP EVERY 5 FT (10125 FT-TD). , ~ POOH. ~--P 4.1 MMSCF GAS, 3070 BWPD, 91 BOPD. ~--- I"""JOB CONTINUED ON 12-MAR-09*'"` I 3/12/2009 **"JOB CONTINUED FROM 11-MAR-2009**" PERFORATED INTERVAL OF 10126-10146 FT, 3.38" HSD PJ 3406. API DATE: SHOT PENETRATION= 31.4 IN, ENTRANCE HOLE=.44 IN. ;SWELL OD OF GUN IN LIQUID IS 3.66 IN. SURFACE AND VISUAL CONFIRMATION OF GUN FIRING. SSV OPEN, MASTER OPEN, SWAB CLOSED, WING CLOSED, GAS LIFT OFF. j .TREE CAP INSTALLED, PT. NOTIFIED DSO FINAL T/I/O: 300/130/0 PSI """JOB COMPLETED""" j 1 i FLUIDS PUMPED BBLS 1 DIESEL 3 MEOH 4 TOTAL 03/18/09 ~~~tUm~~~~~~ N0.5133 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall .Inh !t ~'/0~ li ~~ p~~t) i1.,,. ~~~ ~ ~® ~ n- ~~ ~ ,~~ .. J-27A AY3J-00010 CBL - ( 02/21!09 1 1 S-107 AWJB-26 MEM L L U ~ 'a- 02/25/09 1 1 09-34A AZ4D-00005 USIT (REVISED) 02/07/09 1 1 V-210 AWJB-00025 INJECTION PROFILE 0?J23/09 1 1 MPB-22A AXBD-00005 MEM SCMT & TEMP PROFILE ~ 12/23/08 1 1 V-219 12103700 USIT (REVISION #2) . ~ ( 11/21/08 1 1 11-18 BOCV-00006 PRODUCTION LOG / - C/ 03/02/09 1 1 B-25 AVYS-00023 USIT - /'~"" /~ 03/06/09 1 1 N-18A AYKP-00013 PRODUCTION LOG `~- /~,-S f~ ~ 03/11/09 1 1 F-18 AVY5-00022 USIT / ,- ~'%^ - ~- 03/04/09 1 1 3-19/R-28 AZ4D-00009 LDL ( - 03/06/09 1 1 V-117 BOOR-00003 MEM PRODUCTION PROFILE ~p - ( ~ 03/12/09 1 1 V-211 AY3J-00014 (PROF/RST WFL - ~ 03/16/09 1 1 V-214 AY3J-00013 (PROF/RST WFL - 03/15/09 1 1 K-06B AWJI-00017 MCNL ~ - 01/28/09 1 1 L5-15 12113027 RST - /o ~ ) • ~ 12/09/08 1 1 07-18 12071915 RST ~j 12/01/08 1 1 15-15C AWJI-00015 MCNL . ( 01/02/09 1 1 W-218 40018337 OH MWD/LWD EDIT _ 12/07/08 2 1 R-41 40018496 OH MWD/LWD EDIT ./s• ( 01/04/09 2 1 H-18 11999064 RST / - t ~- 12/03/08 1 1 • ~'- r~eAaC At.nrv~vv~tulst tlt~:tlr I CST ,IIarvINt9 ANU Mt I UMNINCi UNt LUNY tA(:ti l U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~~ r~ -a ~~s ~I 5 ~. ~ ~ ~ C~3 v~l dl- ~ ~ cY Co ~ ~ reG f 2t,- eca1 3 ~a l p~ Alaska Data & Consulting Services 2525 Gambell Street~~~,,,t 0 Anchorage, AK~d4160. ~~ ^~ ~~ " ATTN: Beth _ _ ~ ' Received by:A [~ ~,, `; (~~ ,4; aliE~~ an- g a~fi . Pi.'._ ~i ~i STATE OF ALASKA ` ALAS OIL AND GAS CONSERVATION COMM SION REPORT OF SUNDRY WELL OPERATIONS i~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated e' ~ ~ 3~ b®f)~. ~0rnrttjs~, Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ ~RCi10('8~~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r' - Exploratory 208-1750 . 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20906-01-00 7. KB Elevation (ft): 9. Well Name and Number: 67.87 RT PBU N-18A 8. Property Designation: 10. Field/Pool(s): ADLO-028282 - PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10415 ' feet Plugs (measured) 10153 2/7/09 true vertical 9051.01 - feet Junk (measured) None Effective Depth measured 10330 - feet true vertical 8989. feet Casing Length Size MD TVD Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 Surface 2711 13-3/8" 72# L-80 Surface - 2711 Surface - 2711 5380 2670 Intermediate 3058 9-5/8" 47# L-80 Surface - 3058 Surface - 3056 6870 4760 Production 9744 7" 26# L-80 Surface - 9744 Surface - 8563 7240 5410 Liner 827 4-1/2"12.6# 13cr80 9588 - 10415 8445 - 9051 8430 7500 Perforation depth: Measured depth: see attached - _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13cr80 Surface - 9595' 0 0 - Packers and SSSV (type and measured depth) 7"X4-112" BKR S-3 PKR 9519' HAGER/LINER TOP PKR 9605' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 87 3737 4573 202 Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development - Service C' Daily Report of Well Operations X 16. Well Status after proposed work: Oil -Gas 1! WAG ~ GINJ WINJ ~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 3/5/2009 . ~~ ~ ., Form 10-404 Re ised 04/2006 '~. °^ ~ "~ i [ ~ Submit Original Only !~'Y'`, I Iff ~ N-18A 183-018 PERF ATTA[:HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base N-18A 1/6/09 APF 10,155. 10,175. 8,862.2 8,876.65 N-18A 2/27/09 BPS 10,153. 1,/ 10,155. 8,860.76 8,862.2 N-18A 2/28/09 APF 10,130. 10,1.50. 8,844.14 8,858.59 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP . BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE r 1 N-18A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/27/2009 """ADPERF, CIBP"*" ~ WELL SHUT IN ON ARRIVAL. INITIAL T/ I/ O/ 00= 1960/1000/100/0. PERFORATED (Z3 SAND) 4.5" LINER FROM 10130'-10150' WITH 2 7/8" PJ .OMEGA 2906. SET HES EZ DRILL CIBP AT 10153' TO ISOLATE NEW/EXISTING IPERFORATION ZONES. ~***CONTINUED ON 28-FEB-2009""" 2/27/2009 T/I/O/00 = 1950/1950/100/10. Temp = SI. TBG & IA FLs (EL). AL blinded @ casing valve (0 psi). TBG FL @ 8220' (below sta #3)(125 bbls). IA FL @ ..6269' (sta #4, s/o)(110 bbls). SV, WV=C. SSV, MV=O. IA, OA=OTG. NOVP. 2/28/2009 *""JOB CONTINUED FROM 27-FEB-09**"' ADPERF, CIBP =COMPLETE RIG DOWN. :WELL LEFT SHUT IN. TURNED OVER TO DSO. ALL VALVE CHECKED ::AND ALL GAUGES OPEN TO PRESSURE. "**JOB COMPLETE*** FLUIDS PUMPED BBLS 1 diesel 1 Total ~ ~ Saltmarsh, Arthur C (DOA) Page 1 of 1 From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, February 23, 2009 12:39 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU N-18A / PTD # 208-175 Hi Art, Please reference the following well: Well Name: PBU N-18A Permit #: 208-175 API #: 50-029-20906-01-00 Top Perf MD: 10155' Bottom Perf MD: 10175' This well began Production on January 31, 2009 Method of Operations is: Flowing Date of Test: 02/07/09 Hours Tested: 6 24-Hour Rate / ®il-Bbl: 87 24-Hour Rate /Gas-Mcf: 3,843 24-Hour Rate /Water-Bbl: 4,396 Test Rate /Oil-Bbl: 22 Test Rate /Gas-Mcf: 961 Test Rate /Water-Bbl: 1,099 Choke Size:. 176 Gas-Oil Ration: 44,293 Flow Tubing Pressure: 200 Casing Pressure: 1,400 Oil Gravity-API: 25 2/23/2009 ry~~~~~`~ STATE OF ALASKA ~"~ ~9 ALASK~IL AND GAS CONSERVATION COSIOI~~g ~} ~ ~Qpg WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil ~ Gas C®ns. Commissioo~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,as zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 1/6/2009 12. Permit to Drill Number 208-175 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/17/2008 ' 13. API Number S0-029-20906-01-00 - 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/24/2008 -~ 14. Well Name and Number: N-18A 1820 FNL, 769 FWL, SEC. 08, T11N, R13E, UM Top of Productive Horizon: 5046' FNL, 3539' FWL, SEC. 05, T11 N, R13E, UM 8. KB (ft above MSL): 69.20' ' Ground (ft MSL): 38.66' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 5121' FNL, 3758' FWL, SEC. 05, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) 10330' 8989' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 634586 y- 5969367 Zone- ASP4 10. Total Depth (MD+TVD) 10415' 9051' 16. Property Designation: ADL028282 TPI: x- 637312 y_ 5971470 Zone- ASP4 - 5971400 Zone- ASP4 Total De th: x- 637532 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: p y 18. Directional Survey ®Yes ^ No i i r 2 2 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 information per 20 AAC 25.071): DIR / GR /RES / PSD, DIR / GR !RES / NEU /DEN L//NDOl,1 ~.3Os8'/'!~ .30.S6T" .D 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT Wi. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED I `I r rf 11 n 7 / r / " rf 2-1/ " 4 i 7" 744' rfa i 1 ' ~~ ~ ~ ~ ~ , 23. Open to production or inject ion? ®Yes ^ No 24. TUBING F'2ecoRo If Yes, list each interval open (MD+TVD of To 8 Bottom Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD ~ ; p 3-3/8" Gun Diameter 6 spf 4-1/2", 12.6#, 13Cr80 9595' 9519' , MD TVD MD TVD 10155' -10175' 8862' - 8877 25. Aclo, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERWL USED 2200' Freeze Protect w/ 77 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Janus 31, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowin Date Of Test: HOUr'S Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24HouR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Cores A uired? ^Yes ® No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~: ~ ~ ~) f) ~~~~ ~ Form 10-407 Revised OZT~O ~ h~ I ij ~ ~s ~ CONTINUED ON REVERSE SIDE I , ~~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS ` NAME MD TVD Well Tested? ^ Yes ®No PermafrOSt Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, ff needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 4 3813' 3781' None Ugnu 3 4130' 4076' West Sak 2 5388' 5107' West Sak 1 5633' 5306' Colville Mudstone 5860' 5492' Top HRZ 7464' 6795' Base HRZ 7736' 7017' Sag River 9727' 8550' Shublik 9770' 8583' Sadlerochit 9871' 8656' 42N /Zone 4A 9982' 8737' Top CGL /Zone 3 10079' 8807' Base CGL /Zone 2 10187' 8885' Formation at Total Depth (Name): Zone 2 10187 8885' 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. S ~~~~ igned Terrie Hubble Title Drilling Technologist Date N-18A 208-175 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number P ~• / A Drilling Engineer: Jovy Roach, 564-4352 INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 1004 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-ARernating-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. ITer~ 4b: TPI (Top of Producing Interval). ITerr 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well shoukl show the details of any mukiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (mukiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 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. ITeM 29: Prove a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: N-18 Common Name: N-18 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) '. EMW - - - - 12/17/2008 LOT 3,098.0 (ft) 3,096.0 (ft) 9.00 (ppg) 483 (psi) 1,930 (psi) 12.00 (ppg) 12/23/2008 LOT 9,764.0 (ft) 8,564.0 (ft) 8.40 (ppg) 1,202 (psi) 4,939 (psi) 11.10 (ppg) Printed: 1/5/2009 11:32:41 AM BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: N-18 Common Well Name: N-18 Spud Date: 2/9/1983 Event Name: REENTER+COMPLETE Start: 12/12/2008 End: 1/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/13/2008 00:00 - 02:30 2.50 MOB P PRE Rig move from H-38. Stage pits and satellite camp on N-pad. Bridle up, lay derrick over. Move sub off well. 02:30 - 08:30 6.00 MOB N WAIT PRE Sub move delayed due to power outage on H-Pad; waiting on 08:30 - 11:30 3.00 MOB P 11:30 - 12:00 0.50 RIGU P 12:00 - 15:30 3.50 RIGU P 15:30 - 17:30 2.00 RIGU P 17:30 - 20:30 I 3.001 WHSUR I P 20:30 - 22:00 1.50 DHB P 22:00 - 00:00 2.00 WHSUR P 12/14/2008 100:00 - 01:00 I 1.001 WHSUR I P 01:00 - 04:30 3.50 WHSUR P 04:30 - 07:00 2.50 BOPSU P 07:00 - 13:30 6.50 BOPSU P 13:30 - 14:30 1.00 PULL P 14:30 - 16:30 2.00 PULL P 16:30 - 17:00 I 0.501 PULL I P 17:00 - 18:30 1.50 PULL P 18:30 - 23:30 I 5.001 PULL I P 23:30 - 00:00 ~ 0.50 ~ PULL i P orders from Pad Operator. PRE Resume rig move. Arrive on N-Pad at 11:00 hrs. Spot sub over well. PRE Begin rigging up on location. Lay plywood in cellar, put grating around cellar box, build berms around cellar. PRE PJSM. Raise derrick. Bridle down. RU top drive and rig floor. Spot pits and rig up interconnect lines. PRE RU and test tubing and IA to 2000 psi for 30 minutes. Did not pass; pressure bled off 170 psi in first 15 minutes and 310 psi in second 15 minutes (480 psi total). DECOMP Rig Accepted at 17:30 hrs. Spot cuttings tank and take on 130 deg 8.5 ppg seawater. Test OA. Did not pass; started getting returns out IA valve with 200 psi on OA, indicating 9-5/8" packoff leak. Bleed off pressure and RD lines. DECOMP PJSM. RU DSM lubricator and pressure test to 500 psi. Pull BPV with lubricator. DECOMP PJSM. RU and reverse circulate diesel freeze protect out of tubing with 50 bbl 130 deg 8.5 ppg seawater at 4 bpm/252 psi. RU and circulate down tubing with 130 deg seawater and a 50 bbl Safe-Surf-O sweep at 4 bbl/min/80 psi to clean tubing of residual crude. DECOMP Continue circulating 130 deg seawater down tubing until returns are clean seawater. Recovered 49 bbl diesel. RD and blow down lines. DECOMP PJSM. Install and test TWC. ND tree and adapter flange. Function lockdown screws; all were good. Confirm hanger threads good (7" IJ4S crossover made up to hanger with 5-1/2 turns). DECOMP PJSM. NU BOPE. DECOMP RU and test BOPE to 250 psi low/3500 psi high with 4" and 5-1/2" test joints. Test witnessed by BP WSL Duncan Ferguson and Nabors Toolpusher Chris Weaver. Witness of test waived by Chuck Scheve of AOGCC. DECOMP PJSM. RU to pull 5.5" tubing. DECOMP PJSM. RU DSM lubricator and test to 500 psi; good test. Pull TWC. RD lubricator. DECOMP PJSM. MU landing joint. Break out lockdown screws. Pull tubing hanger to floor with 85 klbs hookload (60 klbs string weight). DECOMP CBU (175 bbl) at 6 bpm, 70 psi. Still getting Safe-Surf-O at surface; continue circulating for 2 BU. SIMOPS: RU control line spooling unit. DECOMP PJSM. Pull and LD 5.5" 17 Ib/ft L-80 AB/BTC tubing from pre-rig cut at 4000'. Clean jet cut. Some internal corrosion and pitting. -Pulled 98 full joints + cut joint (20.03'), 1 GLM, and SSSV (with dual encapsulated control lines) -Average breakout torque 8500 ft-Ibs -Recovered 26 control line clamps and 4 stainless steel bands DECOMP RD tubing handling equipment. Clear and clean rig floor. Printed: 1/5/2009 11:19:40 AM • BP EXPLORATION Operations Summary Report Legal Well Name: N-18 Common Well Name: N-18 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 7ES Date From - To Hours Task Code NPT 12/15/2008 00:00 - 02:00 02:00 - 04:00 04:00 - 06:30 06:30 - 07:30 07:30 - 09:00 09:00 - 10:00 10:00 - 15:30 15:30 - 17:30 17:30 - 18:00 18:00 - 00:00 12/16/2008 00:00 - 02:30 02:30 - 06:00 06:00 - 07:30 07:30 - 08:30 08:30 - 11:00 11:00 - 11:30 11:30 - 12:30 Start: 12/12/2008 Rig Release: Rig Number: Phase Page 2 of 10 ~ Spud Date: 2/9/1983 End: 1 /3/2009 Description of Operations 2.00 BOPSU P DECOMP RU and test lower pipe rams to 250 psi low/3500 psi high with 4" test joint. Good test. Test witnessed by BP WSL Adrienne McVey and Nabors Toolpusher Lenward Toussant. RD testing equipment. 2.00 CLEAN P DECOMP PJSM. PU 9-5/8" casing cleanout BHA with 8-1/2" bit, 9-5/8" casing scraper, bit sub w/float, and Whipstock string mill. RIH with BHA, drill collars, and HWDP to 850'. 2.50 CLEAN P DECOMP RIH picking up 4" drill pipe from 850' to 4000'. Tag up on 5.5" tubing at 4000' 1.00 CLEAN P DECOMP Ciruclate 1 1/2 x bottoms up. 1.50 CLEAN P DECOMP POH with casing scraper BHA. Stand back HWDP and lay down bit, scraper and mill. 1.00 CLEAN P DECOMP Service rig and top drive. 5.50 CLEAN P DECOMP Pick up 69 joints 4" drill pipe and RIH. Waiting on Schlumberger E-line unit. Logging unit held up behing a rig move on the Spine road. Weather conditions worsening, heavy snow and high winds. POH 4" drill pipe in stands and stand back. Pull out slowly due to high winds blowing hoses and top drive service loop around and snagging in the derrick. Wind gusting to 30+ MPH 2.00 DHB P DECOMP Rig up Schlumberger E-line unit 0.50 DHB P DECOMP Pick up CCUGR and bridge plug running tool. Make up Halliburton 9 5/8" EZSV bridge plug and RIH to 200' 6.00 DHB N WAIT DECOMP Stop all operations. Monitor well. Phase three declared across the field. Heavy blowing snow, very poor visibility, wind gusting to 45+ MPH 2.50 DHB N WAIT DECOMP Continue waiting on weather; Phase Three. Heavy blowing snow, poor visibility, wind gusting to 45+ MPH. -Phase 2 Level 2 conditions declared at 0200 hrs (main roads; Level 3 on access roads and pads); made crew change in convoy. 3.50 DHB P DECOMP Resumed E-line operations at 0200 hrs. RIH with 9-5/8" EZSV and tag tubing stub at 4000'. Log up from 4000' to 2800'. Sent logs to Town Geo and consult about EZSV setting depth; set EZSV at 3079' (mid-element), 5' above casing collar at 3084'. Good indication at surface of set. POH; verified that tension sleeve in EZSV setting tool sheared. -Rig crew changeout at 0230 hrs. 1.50 DHB P DECOMP RU testing equipment. Test EZSV to 3500 psi for 10 minutes. Good test. RD testing equipment. SIMOPS: Rlg down E-line unit 1.00 WHSUR P DECOMP Pick up 4" drill pipe and RIH in singles while waiting on Cameron. Phase 2 across field, travel permitted in convoy only. POH and stand back drill pipe. Heat casing spool with steam for 30 minutes. 2.50 WHSUR P DECOMP Cameron tech pull 9 5/8" casing packing from casing spool. No over pull. Packing retrieved complete. Clean casing spool and install new packing. Run in lock down screws. One lock down screw broken and 1 1/4" stub left in spool. Install blank plug. 0.50 WHSUR P DECOMP Test 9 5/8" casing packing in casing spool to 5000 psi for 30 minutes. OK. 1.00 WHSUR P DECOMP Rig up to IA and test to 3500 psi for 30 minutes. OK. Rig Printed: 1/5/2009 11:19:40 AM BP EXPLORATION Operations Summary Report `~ - Legal Well Name: N-18 Page 3 of 10 Common Well Name: N-18 Spud Date: 2/9/1983 Event Name: REENTER+COMPLETE Start: 12/12/2008 End: 1/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/16/2008 11:30 - 12:30 1.00 WHSUR P DECOMP down lines. 12:30 - 15:00 2.50 STWHIP P WEXIT PU Whipstock BHA 15:00 - 16:30 1.50 STWHIP P WEXIT RIH with Whipstock BHA on 4" DP to 3,032' md. Shallow test 16:30 - 17:00 7:00 - 18:00 srrrrr=-nrrnn MWD tools at 1,311' md. 0.50 STWHIP P WEXIT Orient and set Whipstock 57 degrees right of high side at 3,079' and with 25k set down weight. PU 10k over to confirm. Shear bolt with 38k down weight. Pick up to confirm free from anchor. 1.00 STWHIP P WEXIT Displace to 9.0 ppg LSND drillin fluid. 12/17/2008 00:00 - 02:00 2.00 STW H I P P 02:00 - 02:15 0.25 STWHIP P 02:15 - 02:45 0.50 STWHIP P 02:45 - 03:00 0.25 STWHIP P 03:00 - 06:00 3.00 STWHIP P 06:00 - 07:30 I 1.501 STWHIPI P 07:30 - 09:30 2.00 STWHIP P 09:30 - 11:30 2.00 STWHIP P 11:30 - 14:00 2.50 STWHIP P 14:00 - 14:30 0.50 STWHIP P 14:30 - 00:00 I 9.501 DRILL I P W IT Mill 8 1/2" window in 9 5/8" casing. Top of window at 3,058'- md; bottom of window at 3,075' md. Drill new hole to 3,093'; no indication of cement behind casino. s -504 gpm, 894 psi -PUW 100k, SOW 100k, ROT Wt 96k -85 rpm, 2k ft/Ibs torque, 6k weight on mil WEXIT Drill new hole from 3,093' to 3,098' and _ -Circulate bottoms up to evaluate cuttings from milling. Circulate 50 bbls Hi-Vis sweep to clean metal debris from wellbore. Total of 246 pounds of metal cuttings retrieved across shaker magnets. Returns show some clay in cuttings. pumps -504 gpm, 894 psi -PUW 100k, SOW 100k, ROT Wt 96k -85 rpm, 6k ft/Ibs WOM, 2k Wlbs torque WEXIT RU test equipment for LOT WEXIT Pull into window conduct LOT to EMW of 12.0 MW in stem 9.0 ppg, TVD 3098, EMW psi equals 483 psi. -Monitor well -Static WEXIT RD test equipment. WEXIT POH with miliing BHA. Stand back 4" DP and 4" HWDP. LD rest of BHA. -Inspect mills -mills in gauge WEXIT Clear and clean rig floor -Power jet stack to clean metal debris from cavities / pockets WEXIT PU 4" DP one-by-one to 1,720'. Stand back in derrick. WEXIT PU 8 1/2" drilling BHA -PJSM with incoming crew WEXIT RIH with BHA on 4" DP to 3,012' and WEXIT Move through window with BHA with no rotation or circulation -5k down weight at 3,067'; PU 5' and rotate 1/4 turn. Able to move throw h window with no roblems. -Establish ECD baseline at 3,081' of 9.28 ppg; record slow pump rates INTi Drill ahead in 8 1/2" hole from 3,098'to 4,166' and -555 gpm, 1721 psi on, 1632 psi off -6k WOB, 3k ft/Ibs torque on, 2k ft/Ibs torque off, 80 rpm -PUW 108k, SOW 100k, ROT Wt 105k -9.79 ppg calc ECDs, 9.84 ppg actual ECDs -AST 3.15 hrs, ART 2.62 hrs, ADT 5.74 hrs, Bit 5.74 hrs, Jars 109.97 hrs with incoming crew Printed: 1/5/2009 11:19:40 AM ~ ~ BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: N-18 Common Well Name: N-18 Spud Date: 2/9/1983 Event Name: REENTER+COMPLETE Start: 12/12/2008 End: 1/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date I From - To 'Hours Task 'Code '' NPT Phase Description of Operations 12/18/2008 00:00 - 12:00 12.00 DRILL P INTi Drill ahead in 8 1/2" hole from 4,166' to 5,520' and -550 gpm, 2120 psi on, 2032 psi off -11 k WOB, 6k ft/Ibs torque on, 4k fUlbs torque off, 80 rpm -PUW 120k, SOW 100k, ROT Wt 113k -9.81 ppg calc ECDs, 9.97 ppg actual ECDs -AST 2.97 hrs, ART 5.10 hrs, ADT 8.07 hrs, Bit 8.07 hrs, Jars 118.4 hrs -Slow pump rates taken and recorded at 5,314' and -Adding LCM form 5000' at 6 sacks per hour of Mix II Medium and 6 sacks per hour of Mix II fine -No losses noted while drillin ahead 12:00 - 00:00 12.00 DRILL P INT1 Drill ahead in 8 1/2" hole from 5,520' to 6,651' and -550 gpm, 2755 psi on, 2590 psi off -10k WOB, 6k ft/Ibs torque on, 4k ft~bs torque off, 80 rpm -PUW 145k, SOW 115k, ROT Wt 125k -10.11 ppg calc ECDs, 10.57 ppg actual ECDs -AST 1.30 hrs, ART 7.63 hrs, ADT 8.93 hrs, Bit 17.34 hrs, Jars 127.3 hrs -Slow pump rates taken and recorded at 6,365' md; Pump 1: 2 bpm=310 psi, 3 bpm=400 psi; Pump 2: 2 bpm=320 psi, 3 bpm=400 psi -Adding LCM from 5000' at 6 sacks per hour of Mix II Medium and 6 sacks per hour of Mix II fine -No losses noted while drilling ahead 12/19/2008 00:00 - 12:00 12.00 DRILL P INTi Drill ahead in 8 1/2" hole from 6,651' to 7,578' and -500 gpm, 3031 psi on, 2809 psi off -10k WOB, 6k ft/Ibs torque on, 5k ft/Ibs torque off, 80 rpm -PUW 165k, SOW 120k, ROT Wt 138k -Slowly add spike fluid to raise MW to 10.5 at 6,800 ; MW 10.5 at 6,890' and -11.07 ppg calc ECDs, 11.07 ppg actual ECDs, MW 10.55 -ART 7.27 hrs, AST 1.98 hrs, ADT 9.25 hrs, Bit 32.33 hrs cumulative, Jars 136.6 -Adding LCM from 5000' at 6 sacks per hour of Mix II Medium and 6 sacks per hour of Mix II fine -No losses noted while drillin ahead -Slow pump rates taken and recorded at 7,510' and 12:00 - 00:00 12.00 DRILL P INT1 Drill ahead in 8 1/2" hole from 7,578' to 8,350' and -500 gpm, 3160 psi on, 2975 psi off -12k WOB, 7.5k ft/Ibs torque on, 6.5k fUlbs torque off, 80 rpm -PUW 180k, SOW 128k, ROT Wt 145k -11.11 ppg calc ECDs, 11.37 ppg actual ECDs, MW 10.55 ppg -Slow pump rates taken at 8,084' -ART 5.16 hrs, AST 3.58 hrs, ADT 8.74 hrs, Bit 41.15 hrs cumulative, Jars 145.3 -Adding LCM from 5000' at 6 sacks per hour of Mix II Medium and 6 sacks per hour of Mix II fine; stopped adding at 8,200' and and continue to monitor losses. No losses noted while drillin ahead 12/20/2008 00:00 - 12:00 12.00 DRILL P INT1 Drill ahead in 8 1/2" hole from 8,350'to 9,195' and -500 gpm, 3380 psi on, 3150 psi off -15k WOB, 9k ft/Ibs torque on, 7.5k fUlbs torque off, 80 rpm -PUW 195k, SOW 137k, ROT Wt 152k Pri ntetl: 1/5/2009 11:19:40 AM BP EXPLORATION Operations Summary Report Legal Well Name: N-18 Common Well Name: N-18 Event Name: REENTER+COMPLETE Start: Contractor Name: NABORS ALASKA DRILLING I Rig Release: Rig Name: NABORS 7ES Rig Number: Date ~ From - To Hours Task ~, Code NPT ', Phase 12/20/2008 100:00 - 12:00 12.00 DRILL P 12:00 - 20:00 8.00 DRILL P 20:00 - 22:00 I 2.001 DRILL I P 22:00 - 00:00 2.00 DRILL P 12/21/2008 100:00 - 01:00 1.00 DRILL P 01:00 - 03:00 2.00 DRILL P 03:00 - 07:00 I 4.001 DRILL I P 07:00 - 07:30 0.50 DRILL P 07:30 - 08:30 1.00 DRILL P 08:30 - 13:00 4.501 DRILL P 13:00 - 14:00 I 1.00 DRILL ~ P 14:00 - 15:00 1.00 DRILL P 15:00 - 17:30 2.50 DRILL P Description of Operations INTi -ART 7.53 hrs, AST 1.58 hrs, ADT 9.11 hrs, Bit 49.84 hrs -11.08 ppg calc ECDs, 11.25 ppg actual ECDs, MW 10.55 -No losses noted while drilling ahead -Slow pump rates taken and recorded at 9,040 and INT1 -Drill ahead in 8 1/2" hole from 9,195' to TD at 9,745' and -500 gpm, 3725 psi on, 3460 psi off -16k WOB, 9k ft/Ibs torque on, 7k ft/Ibs torque off, 80 rpm -PUW 205k, SOW 135k, ROT Wt 155k -ART 4.46 hrs, AST 1.31 hrs, ADT 5.77 hrs, Bit 56.42 hrs, Jars 160.53 hrs -11.25 ppg calc ECDs, 11.52 ppg actual ECDs, MW 10.55 -No losses noted while drilling ahead -Slow pump rates taken at Tour change INT1 Circulate bottoms up for geological evaluation. Geologist, confirmed casin oint. Continue to circulate bottoms up while reciprocating and rotating to ensure cuttings removal. Shakers look good -small amounts of shale noted. -500 gpm, 3425 psi, 100 rpm -PUW 205k, SOW 135k, ROT Wt 105k -10.5 ppg MW in and out -No losses noted during circulation -Monitor well -static INTi Blow down top drive and POH to 7,318'. Minor swabbing in areas but no tight spots. INT1 POH from 7,318' to 5,887' and (upper Ghost Reamer into window). No recorded tight spots. -PUW 143k, SOW 103k -Monitor well -Static INT1 RIH from 5,887' to 9,745' and -Took 25k set down weight to work through areas at 9,400'-9,475' and and at 9,540' and INTi Break circulation slowly, pump 40 bbl LCM sweep while reciprocating and rotating -Stage from 430 gpm to 500 gpm, initial 3635 psi, final 3250 psi, 110 rpm, 9k ft/Ibs torque -MW in 10.5 ppg; MW spiked to 11.3 ppg with return of LCM sweep -Large increase of cuttings across shakers from short trip -Circulate, reciprocate full stand and rotate to condition mud, -Stand back one stand every 30 min INT1 RIH back to TD to clean cuttings and establish mud properties INT1 Circulate, reciprocate full stand and rotate to condition mud -110 rpm, 9k ft/Ibs torque, 500 gpm, ROT Wt 157k -Initial circulating pressure 3300 psi, Final circulating pressure 3250 psi -Monitor well -Static INTi POH from TD to 2,817' md. -MAD Pass from 3,115' to 2,885' and INT1 PJSM on Cut and Slip drilling line -Cut 137' of line -Service Top Drive INTi POH from 2,817' to 810' and INT1 Stand back HWDP and LD BHA. Inspect bit; grade Page 5 of 10 ~ Spud Date: 2/9/1983 12/12/2008 End: 1 /3/2009 Printed: 1/5/2009 11:19:40 AM BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: N-18 Common Well Name: N-18 Event Name: REENTER+COMPLETE Start: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase 12/21/2008 115:00 - 17:30 I 2.501 DRILL I P 17:30 - 19:30 2.00 BOPSU~ P 19:30 - 21:30 2.00 CASE P 21:30 - 00:00 2.50 CASE ~ P 12/22/2008 100:00 - 03:00 3.001 CASE P 03:00 - 03:30 0.50 CASE P 03:30 - 14:30 11.00 CASE P 14:30 - 16:30 2.001 CEMT ~ P 16:30 - 18:00 I 1.50 I CEMT I P 18:00 - 21:30 3.501 CEMT P -19 bbls of 15.8 ppg Class 'G' Tail Slurry -Drop Top Plug and kick out with 10 bbls water; positive indication plug left head -Average pump rate of 5 bpm during cement job -Swap to rig pumps for 371 bbls displacement of 10.5 ppg mud. Pump at 5 bpm ,slow to 3.5 bpm after 235 bbls, to 2.5 bpm after 270 bbls and to 1 bpm at 340 bpm until plug bumped. -Full returns throughout job. -The casing was not reciprocated. -Bump plug at 371 bbls (6274 strokes), 880 psi. Pressure up to Spud Date: 2/9/1983 12/12/2008 End: 1 /3/2009 Description of Operations I NT1 2-1-CT-N-X-I-BU-TD -Clear and clean rig floor INT1 Chan a out u er ram to 7". Test u er rams with 7" test'oint to 250 psi low and 3500 psi high. Record on chart. Good test. INTi RU to run 7" casing -Mobilize and RU 350 ton elevators and slips -RU casing power tongs and Torque turn computer. INTi PJSM on running 7" casing. Make up shoe track, check floats. Run 7" 26# L-80 BTC-M casing to 1,000'. Average MU torque is 7.5k ft/Ibs. -PJSM with incoming crew on running casing. INTi RIH with 7" 26# L-80 BTC-M casing to 3,021' and -Average make-up torque for BTC-M at 7.5k ft/Ibs, jts 3-134 INT1 Float shoe at window. Circulate 1 1/2 times casing volume at 170 gpm, 350 psi. INT1 Continue to RIH with BTC-M casing to 5,447' md. -PU crossover from T -M to TC-I I -RU torque turn equipment for TC-II casing -RIH with 7" 26# L-80 TC-II casing from 5,447' to 9,744' Qts 137-245) -Filled pipe while lowering slowly every 10th joint. During run of both BTC and TC-II, fill with warm fluid each fill; stop to circulate annular volume every 30th joint to circulate warm fluid through casing and into annulus. Stopped circulating and just ran to bottom once casing reached HRZ. -Tag bottom at 9,745' md; pick up 1' to 9,744' and -PUW 300k, SOW 145k -Float Shoe at 9,744' and and Float Collar at 9,660' and -No noticeable losses Burin casin run -Total of 249 centralizers run according to well plan INT1 RD Frank's Tool and RU SLB cement head and lines. Blow down top drive. INTi Stage up pumps to 5 bpm ~ 720 psi. Continue to circulate 2 1/2 times bottoms up to condition mud for cement job. -PJSM withSLB, crew, Tourpusher, WSL on cement job INTi Use SLB pumps to pressure test cement lines to 4000 psi with 10 bbl MudPush; good test. Pump MudPush and cement as follows: -20 bbl of 11.0 ppg MudPush -Drop Bottom Plug; positive indication plug left head -163 bbls of 11.0 ppg LiteCRETE Lead Slurry (1 ppb CemNET Printed: 1/5/2009 11:19:40 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ;From - To 12/22/2008 18:00 - 21:30 21:30 - 22:00 22:00 - 22:30 22:30 - 00:00 12/23/2008 00:00-01:00 01:00 - 02:00 02:00 - 07:00 N-18 N-18 REENTER+COMPLETE Start: NABOBS ALASKA DRILLING I Rig Release: NABOBS 7ES Rig Number: !, Hours Task ;Code NFT'~, Phase 3.50 CEMT P 0.50 CEMT d P 0.50 BOPSU P 1.501 WHSUR I P 1.00 WHSUR P 1.00 WHSUR P 5.001 BOPSU 07:00 - 08:00 1.00 CASE P 08:00 - 10:00 2.00 DRILL P 10:00 - 14:30 4.50 DRILL P 14:30 - 15:30 1.00 DRILL P 15:30 - 18:00 2.50 DRILL P 18:00 - 19:00 1.00 DRILL P 19:00 - 20:00 1.00 EVAL P 20:00 - 00:00 4.00 DRILL P ,12/24/2008 100:00 - 16:00 I 16.001 DRILL I P 12/12/2008 Page 7 of 10 Spud Date: 2/9/1983 End: 1 /3/2009 Description of Operations INT1 1380 qsi to confirm plug bump and check floats. Floats held. INT1 Rig down 7" casing equipment and SLB cementers. INT1 PJSM on ND of BOP. ND BOP and raise to insert emergency slips. INTi Install 7" Cameron emergency slips and packoff in casing spool with 175k -Cut casing with Wachs cutter INTi Complete cutting 7" casing with Wachs cutter INT1 MU 13 5/8" 5k tubing spool -Pressure test secondary packoff to 4328 psi for 30 minutes; good test INT1 NU BOP, change upper rams from 7" to 3 1/2" x 6" variables -Pull wear ring, install test plug. Test upper 3 1/2" x 6" variable rams with 4" and 41 /2" test joint to 250 psi low and 3500 psi high. -Pump 5 bbls and pressure broke over at 600 psi, dropped down to 550 psi immediately. Pump 1 bbl of 10.5 ppg mud every 30 minutes until Little Red Hot Oil Service RU and began freeze protect. Pump 90 bbls 10.5 ppg mud down OA to confirm clear annulus for freeze protect. Pump 25 bbls of 14.5 ppg mud followed by 56 bbls 80 degree diesel. -RD and blow down test equipment -Install wear ring -Clear and clean rig floor INTi n ressure test 7" casin to 3500 si for 30 min. Record on chart; good test. PROD1 PU and RIH with 6 1/8" drilling BHA. PROD1 RIH with 6 1/8" drilling BHA to 9,605 -Shallow hole test MWD and calibrate MWD depth at 1,770' and -Shallow hole test with 250 gpm, 1500 psi PROD1 Wash down and tag cement wtih 5k down weight at 9,650' md. Drill cement and float collar to 9,732' md. -220 gpm, 1945 psi, 40 rpm, WOB 4k -PUW 220k, SOW 115k, ROT Wt 150k PROD1 Displace 10.5 ppg LSND with 8.4 ppg Flo-Pro PRODi Continue to drill out shoe track and 20' of new hole to 9,765' and -220 gpm, 1580 psi, 6k fUlbs torque on, 40 rpm -PUW 187k, SOW 142k, ROT Wt 155k PROD1 FIT -MW 8.4 ppg in and out, 11.1 ppg EMW,, 9,765' md, 8,564 tvd, 1202 psi -Recorded on chart for 10 min; good test PROD1 Drill ahead in 6 1/8" hole to 9,828' and -10k WOB, 250 gpm, 1860 psi on, 1490 psi off, 6k ft/Ibs torque on, 5k ft/Ibs torque off -PUW 187k, SOW 140k, ROT Wt 150k, 40 rpm -AST 2.82 hrs, ART .47 hrs, ADT 3.29 hrs, Bit 3.29 hrs, Jars 47.39 hrs -Slow pump rates taken and recorded at 9,792' and PROD1 Drill ahead in 6 1/8" hole to TD at 10,415' and - -12-15k WOB, 250 gpm, 1885 psi on, 1651 psi off, 6k ft/Ibs torque on, 5k fVlbs torque off Printed: 1/5/2009 11:19:40 AM BP EXPLORATION Page 8 of 10 Operations Summary Report Legal Well Name: N-18 Common Well Name: N-18 Spud Date: 2/9/1983 Event Name: REENTER+COMPLETE Start: 12/12/2008 End: 1/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date ~ From - To ,Hours Task ~ Code NPT Phase ~~ Description of Operations __ 12/24/2008 00:00 - 16:00 16.00 DRILL P PROD1 -PUW 200k, SOW 143k, ROT Wt 162k, 60 rpm -AST 3.34 hrs, ART 8.96 hrs, ADT 12.3 hrs, Bit 15.59 hrs, Jars 58 hrs -Slow pump rates taken and recorded at tour change (midnight) 16:00 - 17:00 1.00 DRILL P PROD1 Circulate and reciprocate 50' at 250 gpm, 1620 psi, 80 rpm 17:00 - 22:00 5.00 EVAL P PRODi MAD pass from TD to 9,760' -Obtain slow pump rates at 10,415' before logging run -MW in and out 8.4 ppg -Monitor well before logging run -Static 22:00 - 22:30 0.50 DRILL P PROD1 POH from 9,760' to 9,735' and (BHA in 7" shoe) -Monitor well; 1/2 bbl loss in 30 min -8.4 MW in and out -Pump dry job -Drop 2 1/2" drift 22:30 - 00:00 1.50 DRILL P PROD1 POH with 6 1/8" BHA on 4" DP to 7,312' and -PJSM with incoming crew 12/25/2008 00:00 - 02:00 2.00 DRILL P PROD1 POH with 6 1/8" drilling BHA to 815' md, standing back 4" DP 02:00 - 04:00 2.00 DRILL P PROD1 Lay down 6 1/8" BHA -PJSM with NAD Rig Crew and Anadrill MWD on removing RA sources and laying down BHA 04:00 - 05:00 1.00 CASE P RUNPRD Rig up to run 4 1/2" production liner 05:00 - 07:00 2.00 CASE P RUNPRD RIH with 4 1/2" 12.6# 13CR Vam-To liner with torque-turn -Check floats -floats held -Average make-up torque 4400 Wlbs -One centralizer on joint 1 at 10' from shoe -One centralizer on joint 2 in middle of joint -Two centralizers free floating on joints 3-15 with stop ring in middle 07:00 - 07:30 0.50 CASE P RUNPRD Circulate 1.5 times liner volume (19 bbls) at 125 gpm, 85 psi -1-2 bbls of fluid loss 07:30 - 14:30 7.00 CASE P RUNPRD RIH with liner on 4" DP to 9,724' and filling every 10 stands -1-2 bbls of fluid loss 14:30 - 15:30 1.00 CASE P RUNPRD Circulate to stage pumps up to 4 bpm, 596 psi, PUW 170k, SOW 183k -1-2 bbls of fluid loss 15:30 - 17:00 1.50 CEMT P RUNPRD RIH with liner on 4" DP to 10,393' and -MU cement head to joint and slolwy slack off until tag bottom with 8k down weight at 10,415' and -PUW 183k, SOW 145k -1-2 bbls of fluid loss during liner RIH 17:00 - 19:00 2.00 CEMT P RUNPRD Circulate at 4 bpm, 695 psi and reciprocate string 5' -6 bbls loss per hour during circulation 19:00 - 21:00 2.00 CEMT P RUNPRD Cement liner per cement plan: -Pump 4 bbls of 12 ppg MudPush II and pressure test cement lines to 4,500 psi -Pump 25 bbls of 12 ppg MudPush II -Pump 26 bbls of Class G tail C~ 15.8 ppg at 2.5-3 bpm, 800 psi average -Switch over to rig pumps, kick plug out with 25 bbls pert pill -Positive indication plug left cement head -Displace cement with 210 bbls 8.5 ppg FloPro mud -95 bbls to latch liner wiper plug at 3 bpm, spike to 1610 psi -Total of 106 bbls to bump the plug at 2 bpm, bumped plug with Nrinted: v5izuua ii:ia:aur~rn • BP EXPLORATION Page 9 of 10 Operations Summary Report Legal Well Name: N-18 Common Well Name: N-18 Spud Date: 2/9/1983 Event Name: REENTER+COMPLETE Start: 12/12/2008 End: 1/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/25/2008 19:00 - 21:00 2.00 CEMT P RUNPRD 1797 psi -Reciprocated pipe 5-10' strokes through whole job until just riot to latch -Cement in place at 20:20 hrs -Pressure to 3500 psi to set liner hanger; slack off to confirm liner set -Bleed pressure to zero and check floats; monitor well at floor for flow -Static -Pick up to expose dogs on ZXP liner packer, set down 75k, re eat 3 times -Slack off, rotate 18 turns to right to release, pull up 20', drill pipe pressure dropped off -To of liner at 9 587' shoe at 10,414' and -Full returns throughout cement job 21:00 - 22:30 1.50 CEMT P RUNPRD Circulate out cement at 431 gpm, 1305 psi while reciprocating drill string to clear cement in well above liner -Returns show 10 bbls cement to surface, -Blow down lines, RD cement head and all cementing equipment -Displace well to seawater -Clear and clean rig floor 22:30 - 23:00 0.50 CEMT P RUNPRD Monitor well -Static -Obtain and record slow pump rates 23:00 - 00:00 1.00 CEMT P RUNPRD POH with 4" DP and packer running tool, laying down drill pipe 12/26/2008 00:00 - 05:30 5.50 CEMT P RUNPRD POH with 4" DP and packer running tool, laying down drill pipe -Lay down running tool 05:30 - 06:00 0.50 CEMT P RUNPRD Cut and slip 75' drilling line 06:00 - 08:30 2.50 EVAL P OTHCMP RU Schlumberger E-line for USIT run -PJ M with LB E-Line crew, rig crew, WSL -USIT log from 9,744' to 2,900' for 7" cement analysis -Spot and RU logging unit 08:30 - 10:30 2.00 EVAL N SFAL OTHCMP No communication during surface communication check between USIT and receiver in truck. Troubleshoot problems, change out computer in truck. 10:30 - 14:30 4.00 EVAL P OTHCMP Re-test USIT at surface, good test. RIH with USIT to 9,530' and and log from 9,530' to 2,900' md. POH with USIT. LD and RD logging unit. 14:30 - 15:30 1.00 CEMT P RUNPRD RU test a ui ment and ressure test 4 1/2" liner shoe to 3500 psi. Record on chart for 30 min. Bled 20 psi first 15 min, 0 psi second 15 min. Good test. RD and blow down lines. 15:30 - 16:00 0.50 BUNCO RUNCMP Pull wear ring, MU tubing anger and make dummy run with hanger. RKB height 22.70'. 16:00 - 17:30 1.50 BUNCO RUNCMP PJSM on rigging up torque turn equipment with Nabors casing hand, rig crew. RU equipment. 17:30 - 00:00 6.50 BUNCO RUNCMP RIH with 4 1/2" 12.6# 13Cr Vam Top completion -PJSM with crew, Nabors casing hand, Baker completion hand, Tool Pusher, WSL -MU tail pipe assembly -RIH with completion assembly -Make-up torque 4440 ft/Ibs 12/27/2008 00:00 - 06:00 6.00 BUNCO RUNCMP Continue to RIH with 4 1/2" 12.6# 13Cr Vam Top completion to 9,593' and -Make-up torque 4440 ft/Ibs Printed: 1/5/2009 11:19:40 AM • • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: N-18 Common Well Name: N-18 Spud Date: 2/9/1983 Event Name: REENTER+COMPLETE Start: 12/12/2008 End: 1/3/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: Rig Name: NABOBS 7ES Rig Number: Date ' I'I From - To Hours Task Code NPT ~ Phase Description of .Operations _ _ . __ ! _ 12/27/2008 00:00 - 06:00 6.00 BUNCO RUNCMP -Tag packer bore receptacle at 9,599.6' md, Landed ~ 9,595.6_' and -PU and tag again with 10k down two times to confirm -Calculate space out at 5.11 ; MU 5.81' pup, one full joint and landing hanger with pup -Land completion, run in lock-down screws -PUW 135k, SOW 110k 06:00 - 07:30 1.50 BUNCO RUNCMP Reverse circulate clean seawater followed by 108 bbls seawater treated with corrosion inhibitor and displace with 71 bbls of clean seawater to position inhibited water between GLM #5 and the packer. Pumped at 3 bpm. 07:30 - 09:00 1.50 BUNCO RUNCMP Dro ball and rod to set acker. Test tubing to 3500 psi, charted. Bleed to 1500 psi. Pressure up to 3500 psi to test annulus to 3000 psi to shear DCK valve in GLM #2 at 3,589' md. Good tests. Pump 10 bbls each way to confirm shear. Positive flow confirmed shear. 09:00 - 09:15 0.25 BUNCO RUNCMP Install TWC and test from below via DCK shear valve to 1000 psi 09:15 - 14:30 5.25 BOPSU P RUNCMP ND BOP 14:30 - 17:30 3.00 BOPSU P RUNCMP NU adapter and tree. Test adapter, tree and packoff to 5000 psi with diesel. Good test. 17:30 - 18:00 0.50 WHSUR P RUNCMP RU Drill Site Maintenance lubricator and ull TWC. 18:00 - 18:30 0.50 WHSUR P RUNCMP RU Little Red Hot Oil services to freeze protect. Test lines to 3500 psi. 18:30 - 19:00 0.50 WHSUR P RUNCMP Reverse circulate 77 bbls diesel into inner annulus. Line up and allow to U-tube into tubing. Freeze protect to 2,200' md. 19:00 - 20:00 1.00 WHSUR P RUNCMP RU DSM and install BPV. Test Little Red from below to 1000 psi. RD Little Red. Secure well. Release rig. RD and Move off. Move to F-33A. Printed: 1/5/2009 11:19:40 AM ~ ~ N-18A, Well History (Post Rig Sidetrack) Date Summary 12/28/2008 T/I/O 0/0/0 Pulled 4" CIW TWC'H' plug then set 4" CIW BPV so Rig 7 ES can move off. Used 1-2" ext and tagged at 104', no problems. 12/30/2008 T/I/0=vac/0/0 Pull BPV: 4-1/16 CIW H BPV thru tree, post rig. (7es) 1-2 ext. used tagged 0108. No problems. 1/4/2009 WELL S/I ON ARRIVAL. PULL B&R FROM RHC C~ 9593' SLM. PULLED BK-DGLV FROM STA #4 C~3 6274' SLM & BEK-DCK VALVE FROM STA #5 C~ 3808' SLM. CURRENTLY RUNNING INTO SET LGLV. 1/5/2009 SET BK-LGLV IN STA #5 (3808' SLM), BK-OGLV IN STA #4 (6278' SLM). PULLED 4 1/2 RHC PLUG BODY FROM XN-NIPPLE Q 9595' SLM. TAG TD C~3 10279' SLM (-12' FROM RHC CORRECTION = 10267' MD) W/ 3-3/8" DMY GUN & SAMPLE BAILER (NO SAMPLE). LEFT WELL S/I, NOTIFY PAD- OPERATOR. 1/5/2009 WELL SHUT-IN ON ARRIVAL. INITIAL WHP 0/0/0 INITIAL T/I/O = 0/0/0. RIG UP E-LINE FOR JEWELRY LOG AND INITIAL PERFORATIONS. 1/6/2009 RUN JEWELRY GR/CCL/PRESS/TEMP LOG FROM TD TO SURFACE, TIED INTO SLB MWD _ MEASURED DEPTH LOG DATED 24-DEC-2008. PERFORATE FROM 10155' - 10175' WITH 3-3/8" HSD PJ 3406 6 SPF 60 DEG PHASING GUN, 0.37" EH, 36.5" PENE, 22.7 GMS. FINAL T/I/O = 100/0/0 WELL LEFT SHUT-IN. DSO NOTIFIED. JOB COMPLETE. Page 1 of 1 N-18A Survev Report ~~~I~ ~~$~ Report Date: 24-Dec-08 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration (Alaska) Vertical Section Azimuth: 56.740° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: N-PAD / N-1 B TVD Reference Datum: Rotary Table Well: N-18 TVD Reference Elevation: 67.87 ft relative to MSL Borehole: N-18A Sea Bed /Ground Level Elevation: 39.28 ft relative to MSL UWVAPI#: 500292090601 Magnetic Declination: 22.820° Survey Name /Date: N-18A /December 24, 2008 Total Field Strength: 57687.176 nT Tort /AHD / DDI / ERD ratio: 163.929° / 4195.64 ft / 5.898 / 0.464 Magnetic Dip: 80.907° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: December 20, 2008 Location LadLong: N 70.32424174, W 148.90866695 Magnetic Declination Model: BGGM 2008 Location Grid N1E Y/X: N 5969367.000 ftUS, E 634586.000 ftUS North Reference: True North Grid Convergence Angle: +1.02762760° Total Corr Mag North -> True North: +22.820° Grid Scale Factor: 0.99992058 Local Coordinates Referenced To: Well Head 1U Comments Measured Inclination Azimuth SuaSea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS rrotectea-up v.uv u.uu u. uu -o/. a/ v.uu ~.vv v.vv v.vv ~.vv v.vv u.u~ oaoa3o/. ~~ o34~ao. v~ rv /V. 3L4G41/W vv iwa.auaonnao WRP 29.21 0.00 0. 00 -38. 66 29.21 0.00 0.00 0.00 0.00 0.00 0.00 5969367. 00 634586. 00 N 70. 32424174 W 148.90866695 SPERRY 3/5/83 AK- 98.71 0.05 313. 31 30. 84 98.71 -0.01 0.03 0.03 0.02 -0.02 0.07 5969367. 02 634585. 98 N 70. 32424180 W 148.90866713 BO-30021 GYRO 198.71 0.05 201. 10 130. 84 198.71 -0.05 0.08 0.07 0.01 -0.07 0.08 5969367. 01 634585. 93 N 70. 32424177 W 148.90866751 298.71 0.12 42. 19 230. 84 298.71 0.01 0.14 0.05 0.05 -0.01 0.17 5969367. 05 634585. 98 N 70. 32424187 W 148.90866707 398.71 0.13 128. 11 330. 84 398.71 0.15 0.33 0.15 0.05 0.14 0.17 5969367. 06 634586. 14 N 70. 32424189 W 148.90866577 498.71 0.27 134. 81 430. 84 498.71 0.24 0.67 0.44 -0.18 0.40 0.14 5969366. 83 634586. 40 N 70. 32424124 W 148.90866369 598.71 0.18 127. 70 530. 84 598.71 0.34 1.07 0.82 -0.44 0.69 0.09 5969366. 57 634586. 70 N 70. 32424053 W 148.90866133 698.71 0.05 301. 40 630. 84 698.71 0.37 1.20 0.94 -0.52 0.78 0.23 5969366. 50 634586. 79 N 70. 32424033 W 148.90866063 798.71 0.15 276. 20 730. 84 798.71 0.25 1.37 0.78 -0.48 0.61 0.11 5969366. 53 634586. 62 N 70. 32424043 W 148.90866198 898.71 0.32 336. 50 830 .84 898.71 0.19 1.75 0.43 -0.21 0.37 0.28 5969366. 80 634586. 37 N 70. 32424117 W 148.90866 998.71 0.32 336. 81 930 .84 998.71 0.29 2.31 0.34 0.30 0.15 0.00 5969367. 31 634586. 14 N 70. 32424257 W 148.90866 1098.71 0.30 304. 31 1030 .83 1098.70 0.24 2.83 0.73 0.71 -0.18 0.17 5969367. 70 634585. 81 N 70. 32424367 W 148.90866838 1198.71 0.55 295. 00 1130 .83 1198.70 -0.11 3.57 1.34 1.06 -0.83 0.26 5969368. 04 634585. 15 N 70. 32424463 W 148.90867366 1298.71 0.55 280. 20 1230 .83 1298.70 -0.71 4.53 2.20 1.35 -1.74 0.14 5969368. 31 634584. 24 N 70. 32424541 W 148.90868102 1398.71 0.55 269. 39 1330 .82 1398.69 -1.47 5.49 3.04 1.43 -2.69 0.10 5969368. 38 634583. 29 N 70. 32424563 W 148.90868874 1498.71 0.60 288. 70 1430 .82 1498.69 -2.19 6.48 3.99 1.59 -3.66 0.20 5969368. 52 634582 .31 N 70 .32424608 W 148.90869665 1598.71 0.60 291 .40 1530 .81 1598.68 -2.82 7.53 5.04 1.95 -4.65 0.03 5969368. 86 634581 .32 N 70 .32424706 W 148.90870462 1698.71 0.40 289 .81 1630 .81 1698.68 -3.33 8.40 5.91 2.26 -5.46 0.20 5969369. 16 634580 .50 N 70 .32424790 W 148.90871124 1798.71 0.50 323 .20 1730 .81 1798.68 -3.57 9.16 6.64 2.72 -6.05 0.28 5969369. 61 634579 .90 N 70 .32424918 W 148.90871602 1898.71 0.45 338 .20 1830 .80 1898.67 -3.52 9.99 7.32 3.44 -6.46 0.13 5969370. 32 634579 .48 N 70 .32425113 W 148.90871932 1998.71 0.18 26 .69 1930 .80 1998.67 -3.30 10.51 7.63 3.94 -6.54 0.36 5969370. 82 634579 .40 N 70 .32425251 W 148.90871993 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-18\N-18\N-18A\N-18A Generated 1/14/2009 1:20 PM Page 1 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft it de OOft ftUS ftUS LUy6./1 U.:i:i 1L1.1U "LU:iU.tiU 'LU`Jtf.b/ -:7.U5 1V.23/ /.:iU J. y:i -I~.LL U.;iy 5`ibyJ/U. iSL IiJ4b/`J./1 N /U.:iG4'Lb14/ W 14tS. yUif/1/:i25 2198.71 0.72 138. 20 2130.80 2198.67 -2.83 11.78 6. 47 3. 31 -5.56 0.41 5969370. 21 634580.38 N 70.32425078 W 148. 90871201 2298.71 0.67 138. 40 2230.79 2298.66 -2.66 12.99 5. 32 2. 40 -4.75 0.05 5969369. 32 634581.21 N 70.32424830 W 148. 90870547 2398.71 0.57 136. 81 2330.78 2398.65 -2.49 14.08 4. 33 1. 60 -4.02 0.10 5969368. 53 634581.95 N 70.32424612 W 148. 90869956 2498.71 0.73 146. 70 2430.78 2498.65 -2.40 15.21 3. 41 0. 71 -3.33 0.19 5969367. 65 634582.66 N 70.32424367 W 148. 90869397 2598.71 0.73 156. 00 2530.77 2598.64 -2.50 16.48 2. 75 -0. 41 -2.72 0.12 5969366. 54 634583.28 N 70.32424063 W 148. 90868903 2698.71 0.52 210. 00 2630.76 2698.63 -3.01 17.49 3. 03 -1. 38 -2.69 0.60 5969365. 57 634583.33 N 70.32423796 W 148. 90868877 2798.71 1.47 244. 50 2730.75 2798.62 -4.68 19.19 4. 69 -2. 33 -4.08 1.08 5969364. 60 634581.97 N 70.32423538 W 148. 90870000 2848.71 2.72 255. 39 2780.71 2848.58 -6.44 21.01 6. 49 -2. 90 -5.80 2.61 5969363. 99 634580.25 N 70.32423381 W 148. 90871400 2898.71 4.23 270 .00 2830.62 2898.49 -9.11 24.02 9. 36 -3. 20 -8.80 3.48 5969363. 64 634577.26 N 70.32423299 W 148. 90873826 2948.71 6.38 277 .31 2880.40 2948.27 -12.76 28.64 13. 70 -2. 85 -13.40 4.50 5969363. 91 634572.66 N 70.32423396 W 148. 90877555 2998.71 8.63 286 .11 2929.97 2997.84 -17.32 35.16 19. 81 -1. 45 -19.76 5.04 5969365. 19 634566.27 N 70.32423777 W 148. 9088 Tie-In Survey 3048.71 9.88 286 .40 2979.32 3047.19 -22.54 43.20 27. 49 0. 80 -27.48 2.50 5969367. 31 634558.52 N 70.32424392 W 148. 90888 Top Window (Blind) 3058.00 10.10 286 .00 2988.47 3056.34 -23.58 44.81 29. 05 1. 25 -29.02 2.48 5969367. 73 634556.96 N 70.32424515 W 148. 90890226 Base Window (Blind) 3075.00 11.20 294 .60 3005.18 3073.05 -25.44 47.95 32. 04 2. 35 -31.96 11.35 5969368. 77 634554.01 N 70.32424815 W 148. 90892605 Inc+Trend 3098.00 11.20 294 .60 3027.74 3095.61 -27.81 52.42 36. 26 4. 21 -36.02 0.00 5969370. 56 634549.91 N 70.32425323 W 148. 90895898 Inc+Trend 3141.32 11.87 296 .80 3070.19 3138.06 -32.27 61.08 44. 54 7. 97 -43.82 1.85 5969374. 18 634542.05 N 70.32426350 W 148. 90902223 Inc+Trend 3236.24 15.29 301 .70 3162.44 3230.31 -42.45 83.35 65. 97 18. 95 -63.19 3.80 5969384. 81 634522.49 N 70.32429350 W 148. 90917927 MWD+IFR+MS 3332.17 17.92 305 .69 3254.37 3322.24 -53.10 110.75 92. 50 34. 21 -85.94 2.99 5969399. 66 634499.46 N 70.32433519 W 148. 90936374 3427.55 17.08 321 .23 3345.38 3413.25 -59.72 139.27 119 .40 53. 70 -106.64 4.96 5969418. 77 634478.42 N 70.32438844 W 148. 90953157 3522.61 15.85 332 .77 3436.57 3504.44 -59.70 166.13 143 .24 76. 13 -121.33 3.67 5969440. 94 634463.34 N 70.32444973 W 148. 90965064 3618.51 18.24 337 .84 3528.25 3596.12 -55.43 194.22 167 .40 101 .68 -132.98 2.93 5969466. 27 634451.22 N 70.32451953 W 148. 90974515 3714.40 18.40 353 .86 3619.34 3687.21 -45.64 224.19 191 .69 130 .65 -140.27 5.24 5969495. 10 634443.42 N 70.32459865 W 148. 90980421 3816.46 18.61 4 .29 3716.15 3784.02 -28.37 256.50 215 .31 162 .91 -140.77 3.25 5969527. 35 634442.34 N 70.32468679 W 148. 90980831 3912.05 20.06 13 .41 3806.37 3874.24 -7.14 288.09 236 .89 194 .08 -135.83 3.50 5969558. 59 634446.72 N 70.32477193 W 148. 90976822 4007.71 21.96 21 .15 3895.68 3963.55 19.35 322.34 259 .17 226 .73 -125.57 3.51 5969591 .42 634456.40 N 70.32486113 W 148. 90968503 4103.39 23.85 27 .08 3983.82 4051.69 50.71 359.55 283 .02 260 .64 -110.30 3.12 5969625 .60 634471.05 N 70.32495379 W 148. 90956127 4199.68 29.77 33 .78 4069.75 4137.62 89.68 402.92 310 .65 297 .89 -88.12 6.89 5969663 .23 634492.55 N 70.32505554 W 148. 90938146 4294.64 33.04 33 .06 4150.78 4218.65 135.11 452.39 344 .61 339 .19 -60.89 3.47 5969705 .01 634519.04 N 70.32516837 W 148. 9091 4390.71 33.98 38 .10 4230.90 4298.77 184.54 505.41 383 .45 382 .27 -30.03 3.06 5969748 .64 634549.12 N 70.32528608 W 148. 90891 4485.96 33.46 39 .94 4310.13 4378.00 234.91 558.28 423 .37 423 .35 3.25 1.20 5969790 .31 634581.66 N 70.32539831 W 148. 90864056 4580.51 36.08 41 .85 4387.79 4455.66 286.77 612.19 465 .69 464 .09 38.57 3.00 5969831 .66 634616.24 N 70.32550958 W 148 .90835422 4677.36 35.33 41 .26 4466.44 4534.31 341.32 668.71 512 .06 506 .38 76.06 0.85 5969874 .62 634652.97 N 70.32562513 W 148 .90805020 4773.08 36.28 42 .19 4544.07 4611.94 395.41 724.71 559 .76 548 .17 113.34 1.14 5969917 .07 634689.48 N 70.32573929 W 148 .90774798 4868.41 36.79 42 .12 4620.66 4688.53 450.33 781.46 609 .36 590 .24 151.43 0.54 5969959 .81 634726.80 N 70.32585422 W 148 .90743915 4964.65 36.42 41 .03 4697.92 4765.79 505.72 838.85 660 .92 633 .17 189.51 0.78 5970003 .41 634764.11 N 70.32597150 W 148 .90713036 5060.27 36.90 40 .67 4774.63 4842.50 560.63 895.94 713 .38 676 .35 226.85 0.55 5970047 .26 634800.67 N 70.32608947 W 148 .90682757 5156.12 35.78 40 .87 4851.83 4919.70 615.23 952.74 766 .26 719 .37 263.94 1.18 5970090 .93 634836.97 N 70.32620699 W 148 .90652683 5250.95 35.89 40 .97 4928.71 4996.58 668.65 1008.26 818 .41 761 .32 300.30 0.13 5970133 .52 634872.58 N 70.32632159 W 148 .90623195 5345.53 36.93 40.70 5004.83 5072.70. 722.64 1064.39 871 .59 803 .80 337.01 1.11 5970176 .65 634908.51 N 70.32643762 W 148 .90593431 5441.77 36.11 41 .46 5082.17 5150.04 777.78 1121.67 926 .13 846 .97 374.64 0.97 5970220 .48 634945.36 N 70.32655556 W 148 .90562916 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-18\N-18\N-18A\N-18A Generated 1/14/2009 1:20 PM Page 2 of 4 Comments Measured Inclination Azimuth SulS-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de ft ft ft ft ft ft tt de OOtt ftUS ftUS bb:i/..ib .iS.1S 4L.V`J b7by.i5b bLL/./.S 25.SI,b/ 11//. 34 ~/~.Lb 25i5i5.bV 411./3 I.VtS b`J/ULbL. bb bS4`J251./U IV /U.SLObb`JVU VV 1415. `JVS.SLtS.S`J 5632. 39 35.00 40.67 5237.64 5305.51 884.23 1231. 96 1031.73 929.47 447.83 0.87 5970304. 28 635017. 06 N 70.32678094 W 148. 90503564 5728. 40 34.92 40.87 5316.33 5384.20 937.12 1286. 97 1084.95 971.14 483.76 0.15 5970346 .58 635052. 23 N 70.32689476 W 148. 90474431 5823. 89 34.72 40.07 5394.72 5462.59 989.46 1341. 50 1137.94 1012.61 519.15 0.52 5970388. 68 635086. 86 N 70.32700806 W 148. 90445732 5919. 09 35.83 42.19 5472.44 5540.31 1042.41 1396. 47 1191.35 1054.01 555.32 1.74 5970430 .71 635122. 28 N 70.32712115 W 148. 90416402 6015. 68 36.00 41.91 5550.67 5618.54 1097.22 1453. 13 1246.34 1096.08 593.26 0.24 5970473 .45 635159. 46 N 70.32723608 W 148. 90385628 6110. 86 35.74 40.63 5627.80 5695.67 1150.96 1508. 90 1300.77 1138.00 630.05 0.83 5970516 .02 635195. 49 N 70.32735057 W 148. 90355796 6206. 60 35.78 40.32 5705.49 5773.36 1204.67 1564. 85 1355.64 1180.56 666.37 0.19 5970559 .22 635231. 04 N 70.32746684 W 148. 90326344 6301. 88 35.74 42.59 5782.81 5850.68 1258.38 1620. 52 1410.14 1222.28 703.23 1.39 5970601 .60 635267. 14 N 70.32758082 W 148. 90296454 6398. 21 35.78 42.55 5860.98 5928.85 1312.96 1676. 82 1465.12 1263.74 741.31 0.05 5970643 .73 635304. 47 N 70.32769407 W 148. 90265570 6493. 03 35.79 44.46 5937.90 6005.77 1366.93 1732. 26 1519.17 1303.95 779.47 1.18 5970684 .61 635341. 90 N 70.32780391 W 148. 90234 6588. 21 35.61 43.67 6015.19 6083.06 1421.11 1787 .80 1573.29 1343.86 818.10 0.52 5970725 .20 635379. 80 N 70.32791292 W 148. 6 9020 6683. 75 35.44 43.22 6092.95 6160.82 1475.14 1843 .31 1627.61 1384.16 856.28 0.33 5970766 .18 635417. 25 N 70.32802302 W 148. 90172331 6778. 78 35.47 42.49 6170.36 6238.23 1528.65 1898 .44 1681.73 1424.57 893.77 0.45 5970807 .26 635454. 00 N 70.32813340 W 148. 90141926 6873. 57 36.67 42.41 6246.98 6314.85 1582.73 1954 .24 1736.66 1465.75 931.43 1.27 5970849 .10 635490. 92 N 70.32824589 W 148. 90111376 6968. 64 36.37 44.12 6323.38 6391.25 1637.75 2010 .82 1792.26 1506.95 970.21 1.12 5970890 .98 635528. 95 N 70.32835842 W 148. 90079932 7065. 26 35.84 43.47 6401.45 6469.32 1693.23 2067 .75 1848.18 1548.04 1009.61 0.68 5970932 .77 635567. 60 N 70.32847068 W 148 .90047974 7160. 46 35.47 42.92 6478.80 6546.67 1747.18 2123 .24 1902.83 1588.50 1047.59 0.51 5970973 .90 635604. 85 N 70.32858118 W 148 .90017167 7255. 71 35.59 42.54 6556.31 6624.18 1800.89 2178 .60 1957.48 1629.16 1085.15 0.26 5971015 .22 635641. 67 N 70.32869224 W 148 .89986704 7351. 54 34.51 42.02 6634.77 6702.64 1854.18 2233 .63 2011.90 1669.87 1122.18 1.17 5971056 .59 635677. 96 N 70.32880346 W 148 .89956673 7446. 81 34.53 45.08 6713.27 6781.14 1906.73 2287 .61 2065.13 1708.99 1159.37 1.82 5971096 .37 635714. 44 N 70.32891031 W 148 .89926512 7542. 79 35.45 48.83 6791.91 6859.78 1960.95 2342 .63 2118.81 1746.53 1199.59 2.44 5971134 .62 635753. 97 N 70.32901284 W 148 .89893891 7638. 29 36.02 51.72 6869.43 6937.30 2016.35 2398 .40 2172.52 1782.16 1242.48 1.87 5971171 .01 635796. 22 N 70.32911016 W 148 .89859101 7733. 56 35.23 54.26 6946.88 7014.75 2071.72 2453 .89 2225.32 1815.56 1286.78 1.76 5971205 .20 635839. 91 N 70.32920140 W 148 .89823174 7829. 57 35.27 60.82 7025.31 7093.18 2127.05 2509 .26 2276.65 1845.27 1333.47 3.94 5971235 .73 635886. 06 N 70.32928252 W 148 .89785302 7926. 09 36.92 68.80 7103.34 7171.21 2183.23 2566 .06 2326.44 1869.35 1384.86 5.16 5971260 .73 635937. 00 N 70.32934829 W 148 .89743622 8021. 39 38.57 77.53 7178.75 7246.62 2239.04 2624 .33 2373.36 1886.13 1440.60 5.86 5971278 .51 635992. 43 N 70.32939410 W 148 .89698418 8117. 42 39.13 80.28 7253.55 7321.42 2294.81 2684 .56 2418.76 1897.71 1499.70 1.89 5971291 .14 636051. 31 N 70.32942571 W 148 .89650488 8213. 44 39.00 80.96 7328.10 7395.97 2350.15 2745 .07 2463.85 1907.57 1559.40 0.47 5971302 .08 636110. 82 N 70.32945262 W 148 .89602 8308. 26 38.97 80.55 7401.80 7469.67 2404.63 2804 .72 2508.85 1917.16 1618.28 0.27 5971312 .71 636169. 51 N 70.32947877 W 148 .89554 8403. 74 39.77 81.40 7475.62 7543.49 2459.86 2865 .28 2554.99 1926.65 1678.10 1.01 5971323 .28 636229. 14 N 70.32950468 W 148 .89505811 8499. 10 40.05 81.59 7548.76 7616.63 2515.42 2926 .47 2601.86 1935.70 1738.60 0.32 5971333 .41 636289. 47 N 70.32952936 W 148 .89456739 8595. 33 40.83 81.24 7622.00 7689.87 2572.14 2988 .89 2650.33 1945.02 1800.32 0.84 5971343 .83 636351. 01 N 70.32955478 W 148 .89406684 8689 .98 40.11 81.29 7694.01 7761.88 2628.03 3050 .32 2698.70 1954.35 1861.04 0.76 5971354 .25 636411 .55 N 70.32958022 W 148 .89357440 8786 .23 39.18 81.29 7768.12 7835.99 2683.89 3111 .73 2747.55 1963.65 1921.74 0.97 5971364 .64 636472 .07 N 70.32960559 W 148 .89308211 8881 .59 40.99 81.94 7841.07 7908.94 2739.59 3173 .13 2796.68 1972.60 1982.49 1.95 5971374 .67 636532 .64 N 70.32962999 W 148 .89258946 8976 .87 40.51 82.09 7913.26 7981.13 2795.83 3235.32 2846.68 1981.24 2044.08 0.51 5971384 .41 636594 .06 N 70.32965355 W 148 .89208995 9072 .59 41.45 82.14 7985.52 8053.39 2852.55 3298 .10 2897.56 1989.85 2106.26 0.98 5971394 .14 636656 .07 N 70.32967702 W 148 .89158568 9167 .85 41.39 80.95 8056.95 8124.82 2909.75 3361 .12 2949.45 1999.11 2168.59 0.83 5971404 .52 636718 .22 N 70.32970229 W 148 .89108014 9262 .88 40.61 80.76 8128.67 8196.54 2966.65 3423 .46 3001.62 2009.02 2230.15 0.83 5971415 .53 636779 .58 N 70.32972931 W 148 .89058094 9358 .48 39.71 81.13 8201.73 8269.60 3022.89 3485.11 3053.54 2018.73 2291.03 0.97 5971426 .32 636840 .28 N 70.32975577 W 148 .89008715 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-18\N-18\N-18A\N-18A Generated 1/14!2009 1:20 PM Page 3 of 4 Comments Measured Inclination Azimuth SulrSea TVD TVp Vertical Along Hole Closure NS EW DLS Northing Easting Latitude longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de OOft ftUS ftUS 7" @ 9744'md 9454.98 9550.68 9645.79 9682.98 9745.87 9778.12 39.9/ 80.53 8"L/5.83 8343./U 3U/y.33 3b4b.`J4 J1 Uti.UL 'LUL8.b25 41.10 78.22 8348 .56 8416.43 3136.73 40. 68 77.68 8420 .46 8488.33 3194.77 40. 40 77.75 8448 .73 8516.60 3217.34 40. 58 79.26 8496 .56 8564.43 3255.26 41. 39 79.80 8520 .90 8588.77 3274.76 3609.13 3671.39 3695.56 3736.39 3757.54 3784.45 3800.85 3820.91 3845.04 3866.91 9818.17 43.20 90.59 8550.57 8618.44 3298.36 9841.89 44.30 95.39 8567.70 8635.57 3311.58 9870.69 44.02 92.59 8588.37 8656.24 3327.54 9905.47 43.84 92.10 8613.42 8681.29 3347.16 9937.06 43.77 90.92 8636.21 8704.08 3365.12 9968.82 43.57 96.33 8659.20 8727.07 3382.65 10000.46 43.36 100.44 8682.16 8750.03 3398.91 10032.74 43.03 99.48 8705.70 8773.57 3415.01 10063.73 43.41 102.62 8728.28 8796.15 3430.19 10096.28 43.67 103.73 8751.88 8819.75 3445.65 3888.83 3910.59 3932.68 3953.90 3976.32 3159.95 3214.97 3236.45 3272.56 3291.14 3313.37 3325.62 3340.44 3358.78 3375.68 3392.14 3407.31 3422.35 3436.56 3451.04 2040.06 2053.06 2058.20 2066.34 2070.18 2072.39 2071.52 2070.13 2069.14 2068.56 2067.18 2064.01 2060.19 2056.12 2051.01 L:iSL. Vt) V.425 5y/14;5/.L/ t):itSyUl.1L N /V.JLy /25Lt):i W 1415. i525y5yLl/ 2413. 18 1.96 5971449. 84 636962.01 N 70.32981394 W 148. 88909650 2474. 07 0.58 5971463. 93 637022.65 N 70.32984940 W 148. 88860267 2497. 69 0.76 5971469. 49 637046.17 N 70.32986343 W 148. 88841111 2537. 70 1.59 5971478. 34 637086.03 N 70.32988562 W 148. 88808658 2558. 50 2.74 5971482. 56 637106.76 N 70.32989609 W 148. 88791789 2585. 28 18.67 5971485. 25 637133.49 N 70.32990210 W 148. 88770074 2601. 65 14.74 5971484. 68 637149.87 N 70.32989973 W 148. 88756798 2621. 66 6.84 5971483. 64 637169.90 N 70.32989589 W 148. 88740570 2645. 77 1.11 5971483. 08 637194.02 N 70.32989317 W 148. 88721018 2667. 63 2.60 5971482. 90 637215.88 N 70.32989158 W 148. 88703291 5 2689 .50 11.78 5971481. 91 637237.77 N 70.32988777 W 148. 8868 2711 .02 8.96 5971479. 12 637259.35 N 70.32987909 W 148. 88668101 2732 .78 2.28 5971475. 69 637281.17 N 70.32986863 W 148. 88650454 2753 .60 7.05 5971472. 00 637302.07 N 70.32985749 W 148. 88633568 2775 .44 2.48 5971467. 28 637323.98 N 70.32984351 W 148. 88615865 10128.61 43.68 107.67 8775.27 8843.14 3460.30 3998.65 3464.77 2044.97 2796.92 8.42 5971461. 63 637345.57 N 70.32982699 W 148. 88598443 10160.01 43.81 109.44 8797.95 8865.82 3473.72 4020.36 3477.35 2038.06 2817.50 3.92 5971455. 09 637366.27 N 70.32980809 W 148. 88581755 10191.42 43.52 107.73 8820.67 8888.54 3487.12 4042.04 3490.00 2031.15 2838.06 3.87 5971448. 55 637386.94 N 70.32978919 W 148. 88565088 10223.46 43.25 108.13 8843.96 8911.83 3500.91 4064.05 3503.13 2024.37 2858.99 1.20 5971442. 15 637408.00 N 70.32977066 W 148. 88548109 10255.76 42.97 108.86 8867.54 8935.41 3514.57 4086.12 3516.21 2017.37 2879.93 1.77 5971435. 53 637429.05 N 70.32975151 W 148. 88531134 10287.21 42.96 110.11 8890.55 8958.42 3527.55 4107.56 3528.71 2010.22 2900.13 2.71 5971428 .74 637449.38 N 70.32973195 W 148. 88514749 10319.34 43.98 110.49 8913.87 8981.74 3540.68 4129.66 3541.42 2002.55 2920.87 3.28 5971421 .45 637470.25 N 70.32971098 W 148. 88497939 10351.78 43.63 109.76 8937.28 9005.15 3554.07 4152.12 3554.49 1994.82 2941.95 1.89 5971414 .10 637491.46 N 70.32968985 W 148. 88480843 Last Survey 10367.16 43.49 110.44 8948.43 9016.30 3560.39 4162.72 3560.69 1991.18 2951.90 3.18 5971410 .64 637501.48 N 70.32967989 W 148. 88472773 TD (Projected) 10415.00 43.49 110.44 8983.14 9051.01 3579.89 4195.64 3579.94 1979.68 2982.75 0.00 5971399 .69 637532.53 N 70.32964844 W 148. 88447757 Survey Type: Definitive Survey NOTES: BOSS GYRO - (Sperry-Sun BOSS gyro multishot -Sperry Sun BOSS multishot surveys ) INC+Trend - ( Inclinometer + known azi trend -- Inclination only surveys in near-vertical hole-where formation dip and experience enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. ) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enhance inclination accuracy. ) Legal Description: Northing (Yl IftUSI Easting (Xl ~ftUSl Surface : 3459 FSL 451 1 FEL S8 Ti 1 N R13E UM 5969367.00 634586.00 BHL : 158 FSL 1521 FEL S5 Ti 1 N R13E UM 5971399.69 637532.53 SurveyEditor Ver SP 2.1 Bld( doc40x_100) N-18\N-18\N-18A\N-18A Generated 1/14/2009 1:20 PM Page 4 of 4 WELLHEAD = McEvoy ACTL~4TOR = OTIS KB. ELEV = 67.87' BF. ELEV = 40.46' KOP = 3000' Max Angle = 44° @ 9$42' Datum MD = 10163' Datum TV D = 8800' SS -18A S NOTES: One loclpdown screw on 9 5/8" c packoff broke; re laced with blank. **CHROME TBG &LNR** 2232' 4-112" HES X NIP, tD - 3.813`" A-917'° x 1" l;AS t_IFT MANDRELS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2711' Min ID = 3.725" @ 9583' 4-1 /2" XN NIPPLE ST MD NU D7=V '' TYPE VLV LATCH 1=t3R DATE 5 3811 3779 19 KBG2-1R DOME BK 16 01/04/09 4 6269 5824 36 KBG2-1R SO 20 0 01/04/09 3 7849 7109 36 KBG2-1R DMY BK 0 12/26/08 2 8880 7908 41 KBG2-1R DMY BK 0 12/26/08 1 9411 8310 40 KBG2-1R DPIY BK ~ 0 12/26/08 9-5/8" MILL WINDOW (N-18A) 3058' - 3075' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 3058' 9-5/8" Top of Whipstock 3058' I9-5/8" Ezsv ~ 3073' TBG CUT (12/01/08) 4000' TBG PUNCH ~ 9189' P&A TOC 9204' TOP OF 5" LNR TOP OF 7" LNR PERFORATION SUMMARY REF LOG: SWS MWD LOG 12/28/08 ANGLE AT TOP PERF: 44° @ 10155' Notes Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10155 - 10175 O 01/06/09 I7" GSG, 26# L-80, TCII, .0383 bpf, ID = 6.276" g4t(7' --i 4-1 t2" NES X NIP, ID = 3.813" I +~~~ 9' 7" X 41 J2" BKR S-3 PKR, ID = 3.87" 9552` 4-112" t11=S X NIP, tD = 3.813^ 95$3' 4-1/2" NES XN NIP, ID = 3.725" 9595' 4-1/2" WLEG 9595' 4-1/2" TBG, 12.6# 13CR, VAM TOP, .0383 bpf, ID = 6.276" 9605` HangerlLiner top packer 9744' T` CSG, 26# -80, BTC, _0383 bpf, ID - 6.27fi" 10330' PBTD 10414' 4-1/2" LNR, 12.6# 13CR VAM TOP, ID = 3.958" DATE REV B COMMENTS DATE REV B COMMENTS 02/28/83 ORIGINAL COMPLETION 03/05/89 RWO 12/01/08 JER PROPOSED SIDETRACK 12!28/08 N7ES SIDETRACK (N-18A) 01/13/09 LLI/SV PERF (01/06/09) ' I U1/15/U`J IJI;M/SVI CiLV G/U IU"I/U4/UL~ I ~ I PRUDHOE BAY UNIT WELL: N-18A PERMIT No: °1830180 API No: 50-029-20906-01 SEC 8, T11N, R13E, 1820' SNL & 769' EWL BP Exploration (Alaska! 01 /23/09 ~C~~~~~h~~~ Alaska Data & Consulting Services a(`~ 2525 Gambell Street, Suite 400 \ asp Anchorage, AK 99503-2838 0~ () ATTN: Beth ~J QC ~~~~~ ` N0.5047 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 H-35 11970840 PRODUCTION PROFILE 08/12/08 1 1 -11 12111927 IBP & CROSS-FLOW STP 1 11/24/08 1 1 MPS-41 11966291 SCMT - ~~ 11/24/08 1 1 K-05C AWJB-00016 MEM PROD PROFILE p _ ~-5 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE ~ Q -~() 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~"-'" 12!30108 1 1 K-16AL2 AXIA-00009 MEM PROD PROFILE 0 () 01/10/09 1 1 01-29 AP3O-00011 USIT '$ ~ ~ 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP -.-- L.1 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESS/TEMP - ~' 01/06/09 1 1 R-24 AY3J-00004 USIT - 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILE/WFL .r j~'(~ 01/08/09 1 1 07-OAA AYOO-00009 USIT - L 01/22!09 1 1 N-12 12014053 RST - 09/30/08 1 1 E-326 AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) t ]~.~ 06/15/07 1 B-27A 11999059 RST ~ O1 ~ !,35 + 11/07/08 1 1 12-37 40018138 OHM D/LWD EDIT ~ -/ '~~- 11/07/08 2 1 N-18A 08AKA0037 OH MWDlLWD EDIT ~b~ ~- /2/24!08 2 1 H-38 08AKA0031 OH MWD/LWD EDIT C 12/07/08 2 1 - G s- c '~- -o .... r.v....v ..rrv yr ••rvr•• • •+• vV•~••~vl r••~Y flL• VI71~11\V VIYG \.Vr~ GM\.fl 1 V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 n Date Delivered Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 0 „ ~,~,~ Anchorage, AK 5J5b~-, ~ ~ , ATTN: Beth ,, ~ ~~ 'r' Received by: f ~,,-~ t., ~~ e- , r. . am_a.M~,.>:~ i~ ~_ .-*t, A ~rtai'a19„'~~!!~t`I P , .,. "~, 01 /23/09 Schlumbe~ger Alaska Data & Consulting Services a(" 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ a ATTN: Beth ~J ~p QG "~ ata~k W/ all \ O -Inh 4 ~ .... n........:.-a: NO.5047 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 H-35 11970840 PRODUCTION PROFILE 08/12/08 1~ 1 -11 12111927 IBP & CROSS-FLOW STP ~ j 11/24/08 1 1 MPS-41 11966291 SCMT - ~ 11/2q/Og 1 1 K-O5C AWJB-00016 MEM PROD PROFILE p _ ~ ~'S 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE • p -~} 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- '~" 12/30/08 1 1 K-16AL2 ARIA-00009 MEM PROD PROFILE 0 - Q J 01/10/09 1 1 01-29 AP30-00011 USIT $ - r ( 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP =- L.~ 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESS/TEMP - ~ 01/06/09 1 1 R-24 AY3J-00004 USIT ~ 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXED-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILE/WFL .~ (~"~ 01/08/09 1 1 07-0$A AYOO-00009 USIT - L 01!22/09 1 1 N-12 12014053 RST 09/30/08 1 1 E-32B AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) i )~.t° 06/15/07 1 B-27A 11999059 RST ®D~ (~SI 11/07/08 1 1 12-37 40018138 OHM D/LWD EDIT - _~L "~'~' 11/07/08 2 1 N-18A 08AKA0037 OH MWD/LWD EDIT Q~ ~ •~ 12/24/08 2 1 H-38 08AKA0031 OH MWD/LWD EDIT ~ 12/07/08 2 1 - G o~ enema nrv~~n.^n ~nn~ n BP Exploration (Alaska) Inc. _ - -M ^ -r '~. v...'.,'M v"~ vvr ~ ~^v~ ~ ~ v• Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 n Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 , ~~ ~,~ , Anchorage, AK 99 X03 S~g~ , ,, `_ ~ -, a,~ ATTN: Beth F, Received by: ,,; ,® i:~ .,...1 _ . ~~i~ ~ ~ 6ru S~~ ~r s a Client .................... Field ..................... Well ...................... API number ...............: Engineer .................. NSB ....................... STATE :.................... ----- Survey calculation m Method for positions.....: Method for DLS...........: BP Prudhoe Bay N-18A 50-029-20906-01 E. Galotta 7ES AK ethods------------ Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: DRILLERS DEPTH GL above permanent.......: 39.28 ft KB above permanent.......: N/A DF above permanent.......: 67.87 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft SCHLUMBERGER Survey report 24-Dec-2008 22:07:50 Page 1 of 6 Spud date ................: 16-Dec-08 Last survey date.........: 24-Dec-08 Total accepted surveys...: 130 MD of first survey.......: 0.00 ft MD of last survey........: 10415.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2008 Magnetic date ............: 19-Dec-2008 Magnetic field strength..: 57688.31 GAMA Magnetic dec (+E/W-).....: 22.82 degrees Magnetic dip .............: 80.91 degrees ----- MWD survey Reference Criteria --------- Reference G ..............: 1002.68 meal Reference H ..............: 57688.50 GAMA Reference Dip ............: 80.91 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-)300.00 GAMA Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 22.82 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 22.82 degrees (Total az corr = magnetic dec - grid cony) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correctio Azimuth from Vsect Origin to target: 0.00 degrees N ~1 ~O ~ [(c)2008 IDEAL ID13_OC_13~ .,- SCHLUMBERGER Survey Report 24-Dec-2008 22:07:50 Page 2 of 6 ~J r1 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 BP _BOSS GYRO 2 29.21 0.00 0.00 29.21 29.21 0.00 0.00 0.00 0.00 0.00 0.00 BP _BOSS GYRO 3 98.71 0.05 313.31 69.50 98.71 0.02 0.02 -0.02 0.03 313.31 0.07 BP _BOSS GYRO 4 198.71 0.05 201.10 100.00 198.71 0.01 0.01 -0.07 0.07 278.20 0.08 BP _BOSS GYRO 5 298.71 0.12 42.19 100.00 298.71 0.05 0.05 -0.01 0.05 342.37 0.17 BP _BOSS GYRO 6 398.71 0.13 128.11 100.00 398.71 0.05 0.05 0.14 0.15 69.37 0.17 BP _BOSS GYRO 7 498.71 0.27 134.81 100.00 498.71 -0.18 -0.18 0.40 0.44 114.36 0.14 BP _BOSS GYRO • 8 598.71 0.18 127.70 100.00 598.71 -0.44 -0.44 0.69 0.82 122.65 0.09 BP _BOSS GYRO 9 698.71 0.05 301.40 100.00 698.71 -0.52 -0.52 0.78 0.94 123.55 0.23 BP _BOSS GYRO 10 798.71 0.15 276.20 100.00 798.71 -0.48 -0.48 0.61 0.78 128.11 0.11 BP _BOSS GYRO 11 898.71 0.32 336.50 100.00 898.71 -0.21 -0.21 0.37 0.43 119.52 0.28 BP _BOSS GYRO 12 998.71 0.32 336.81 100.00 998.71 0.30 0.30 0.15 0.34 26.26 0.00 BP _BOSS GYRO 13 1098.71 0.30 304.31 100.00 1098.70 0.71 0.71 -0.18 0.73 345.96 0.17 BP _BOSS GYRO 14 1198.71 0.55 295.00 100.00 1198.70 1.06 1.06 -0.83 1.34 321.94 0.26 BP _BOSS GYRO 15 1298.71 0.55 280.20 100.00 1298.70 1.35 1.35 -1.74 2.20 307.78 0.14 BP BOSS GYRO 16 1398.71 0.55 269.39 100.00 1398.69 1.43 1.43 -2.69 3.04 297.94 0.10 BP _BOSS GYRO 17 1498.71 0.60 288.70 100.00 1498.69 1.59 1.59 -3.66 3.99 293.43 0.20 BP _BOSS GYRO 18 1598.71 0.60 291.40 100.00 1598.68 1.95 1.95 -4.65 5.04 292.73 0.03 BP _BOSS GYRO 19 1698.71 0.40 289.81 100.00 1698.68 2.26 2.26 -5.46 5.91 292.44 0.20 BP _BOSS GYRO 20 1798.71 0.50 323.20 100.00 1798.67 2.72 2.72 -6.05 6.64 294.23 0.28 BP BOSS GYRO 21 22 1898.71 1998.71 0.45 0.18 338.20 26.69 100.00 100.00 1898.67 1998.67 3.44 3.94 3.44 3.94 -6.46 -6.54 7.32 7.63 298.02 301.10 0.13 0.36 BP BP _BOSS _BOSS GYRO GYRO 23 2098.71 0.33 122.20 100.00 2098.67 3.93 3.93 -6.22 7.36 302.28 0.39 BP _BOSS GYRO 24 2198.71 0.72 138.20 100.00 2198.66 3.31 3.31 -5.56 6.47 300.76 0.41 BP _BOSS GYRO 25 2298.71 0.67 138.40 100.00 2298.66 2.40 2.40 -4.75 5.32 296.82 0.05 BP BOSS GYRO 26 2398.71 0.57 136.81 100.00 2398.65 1.60 1.60 -4.02 4.33 291.72 0.10 BP _BOSS GYRO 27 2498.71 0.73 146.70 100.00 2498.64 0.71 0.71 -3.33 3.41 281.98 0.19- BP _BOSS GYRO 28 2598.71 0.73 156.00 100.00 2598.64 -0.41 -0.41 -2.72 2.75 261.50 0.12 BP _BOSS GYRO 29 2698.71 0.52 210.00 100.00 2698.63 -1.38 -1.38 -2.69 3.03 242.82 0.60 BP _BOSS GYRO 30 2798.71 1.47 244.50 100.00 2798.62 -2.33 -2.33 -4.08 4.69 240.28 1.08 BP BOSS GYRO [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 24-Dec-2008 22:07:50 Page 3 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2848.71 2.72 255.39 50.00 2848.58 -2.90 -2.90 -5.80 6.49 243.43 2.61 BP_ BOSS GYRO 32 2898.71 4.23 270.00 50.00 2898.49 -3.20 -3.20 -8.80 9.36 250.00 3.48 BP_ BOSS GYRO 33 2948.71 6.38 277.31 50.00 2948.27 -2.85 -2.85 -13.40 13.70 258.00 4.50 BP_ BOSS GYRO 34 2998.71 8.63 286.11 50.00 2997.84 -1.45 -1.45 -19.76 19.81 265.79 5.04 BP_ BOSS GYRO 35 3048.71 9.88 286.40 50.00 3047.19 0.80 0.80 -27.48 27.49 271.66 2.50 BP_ BOSS GYRO 36 3058.00 10.10 286.00 9.29 3056.34 1.25 1.25 -29.02 29.05 272.46 2.48 BP_ BLIND • 37 3075.00 11.20 294.60 17.00 3073.05 2.35 2.35 -31.96 32.04 274.20 11.35 BP_ BLIND 38 3098.00 11.20 294.60 23.00 3095.61 4.21 4.21 -36.02 36.26 276.66 0.00 BP_ BLIND 39 3141.32 11.87 296.80 43.32 3138.06 7.97 7.97 -43.82 44.54 280.30 1.85 BP_ INC+TREND 40 3236.24 15.29 301.70 94.92 3230.31 18.95 18.95 -63.19 65.97 286.69 3.80 BP_ INC+TREND 41 3332.17 17.92 305.69 95.93 3322.24 34.21 34.21 -85.94 92.50 291.70 2.99 BP_ MWD+IFR+MS 42 3427.55 17.08 321.23 95.38 3413.25 53.70 53.70 -106.64 119.40 296.73 4.96 BP_ Min7D+IFR+MS 43 3522.61 15.85 332.77 95.06 3504.43 76.13 76.13 -121.33 143.24 302.11 3.67 BP_ MWD+IFR+MS 44 3618.51 18.24 337.84 95.90 3596.12 101.68 101.68 -132.98 167.40 307.40 2.93 BP_ MWD+IFR+MS 45 3714.40 18.40 353.86 95.89 3687.21 130.65 130.65 -140.27 191.69 312.97 5.24 BP_ MWD+IFR+MS 46 3816.46 18.61 4.29 102.06 3784.02 162.91 162.91 -140.77 215.31 319.17 3.25 BP_ MWD+IFR+MS 47 3912.05 20.06 13.41 95.59 3874.24 194.08 194.08 -135.83 236.89 325.01 3.50 BP_ MWD+IFR+MS 48 4007.71 21.96 21.15 95.66 3963.55 226.73 226.73 -125.57 259.17 331.02 3.51 BP_ MWD+IFR+MS 49 4103.39 23.85 27.08 95.68 4051.69 260.64 260.64 -110.30 283.02 337.06 3.12 BP_ MWD+IFR+MS 50 4199.68 29.77 33.78 96.29 4137.61 297.89 297.89 -88.12 310.65 343.52 6.89 BP_ MWD+IFR+MS • 51 4294.64 33.04 33.06 94.96 4218.65 339.19 339.19 -60.89 344.61 349.82 3.47 BP_ MWD+IFR+MS 52 4390.71 33.98 38.10 96.07 4298.77 382.27 382.27 -30.03 383.45 355.51 3.06 BP_ MWD+IFR+MS 53 4485.96 33.46 39.94 95.25 4378.00 423.35 423.35 3.25 423.37 0.44 1.20 BP_ MWD+IFR+MS 54 4580.51 36.08 41.85 94.55 4455.66 464.09 464.09 38.57 465.69 4.75 3.00 BP _MWD+IFR+MS 55 4677.36 35.33 41.26 96.85 4534.30 506.38 506.38 76.06 512.06 8.54 0.85 BP MWD+IFR+MS 56 4773.08 36.28 42.19 95.72 4611.93 548.17 548.17 113.34 559.76 11.68 1.14 BP _MWD+IFR+MS 57 4868.41 36.79 42.12 95.33 4688.53 590.24 590.24 151.43 609.36 14.39 0.54 BP _MWD+IFR+MS 58 4964.65 36.42 41.03 96.24 4765.79 633.17 633.17 189.51 660.92 16.66 0.78 BP _MWD+IFR+MS 59 5060.27 36.90 40.67 95.62 4842.50 676.35 676.35 226.85 713.38 18.54 0.55 BP _MWD+IFR+MS 60 5156.12 35.78 40.87 95.85 4919.70 719.37 719.37 263.94 766.26 20.15 1.18 BP _MWD+IFR+MS [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 24 -Dec-2008 22:07:50 Page 4 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5250.95 35.89 40.97 94.83 4996.58 761.32 761.32 300.30 818.41 21.53 0.13 BP_ MWD+IFR+MS 62 5345.53 36.93 40.70 94.58 5072.70 803.80 803.80 337.01 871.59 22.75 1.11 BP_ MWD+IFR+MS 63 5441.77 36.11 41.46 96.24 5150.04 846.97 846.97 374.64 926.13 23.86 0.97 BP_ MWD+IFR+MS 64 5537.35 35.15 42.09 95.58 5227.73 888.50 888.50 411.73 979.26 24.86 1.08 BP_ MWD+IFR+MS 65 5632.39 35.00 40.67 95.04 5305.51 929.47 929.47 447.83 1031.73 25.73 0.87 BP_ MWD+IFR+MS • 66 5728.40 34.92 40.87 96.01 5384.19 971.14 971.14 483.76 1084.95 26.48 0.15 BP_ MWD+IFR+MS 67 5823.89 34.72 40.07 95.49 5462.59 1012.61 1012.61 519.15 1137.94 27.14 0.52 BP_ MWD+IFR+MS 68 5919.09 35.83 42.19 95.20 5540.31 1054.01 1054.01 555.32 1191.35 27.78 1.74 BP_ MWD+IFR+MS 69 6015.68 36.00 41.91 96.59 5618.54 1096.08 1096.08 593.26 1246.34 28.42 0.24 BP_ MWD+IFR+MS 70 6110.86 35.74 40.63 95.18 5695.67 1138.00 1138.00 630.05 1300.77 28.97 0.83 BP MWD+IFR+MS 71 6206.60 35.78 40.32 95.74 5773.36 1180.56 1180.56 666.37 1355.64 29.44 0.19 BP_ MWD+IFR+MS 72 6301.88 35.74 42.59 95.28 5850.68 1222.28 1222.28 703.22 1410.14 29.91 1.39 BP_ MWD+IFR+MS 73 6398.21 35.78 42.55 96.33 5928.85 1263.74 1263.74 741.31 1465.12 30.40 0.05 BP_ MWD+IFR+MS 74 6493.03 35.79 44.46 94.82 6005.77 1303.95 1303.95 779.47 1519.17 30.87 1.18 BP_ MWD+IFR+MS 75 6588.21 35.61 43.67 95.18 6083.06 1343.86 1343.86 818.10 1573.29 31.33 0.52 BP_ MWD+IFR+MS 76 6683.75 35.44 43.22 95.54 6160.82 1384.16 1384.16 856.28 1627.61 31.74 0.33 BP_ MWD+IFR+MS 77 6778.78 35.47 42.49 95.03 6238.23 1424.57 1424.57 893.77 1681.73 32.10 0.45 BP_ MWD+IFR+MS 78 6873.57 36.67 42.41 94.79 6314.84 1465.75 1465.75 931.43 1736.66 32.43 1.27 BP_ MWD+IFR+MS 79 6968.64 36.37 44.12 95.07 6391.25 1506.95 1506.95 970.21 1792.26 32.77 1.12 BP_ MWD+IFR+MS 80 7065.26 35.84 43.47 96.62 6469.31 1548.04 1548.04 1009.61 1848.17 33.11 0.68 BP_ MWD+IFR+MS • 81 7160.46 35.47 42.92 95.20 6546.67 1588.50 1588.50 1047.59 1902.83 33.40 0.51 BP_ MWD+IFR+MS 82 7255.71 35.59 42.54 95.25 6624.18 1629.16 1629.16 1085.15 1957.48 33.67 0.26 BP_ MWD+IFR+MS 83 7351.54 34.51 42.02 95.83 6702.63 1669.87 1669.87 1122.18 2011.90 33.90 1.17 BP_ MWD+IFR+MS 84 7446.81 34.53 45.08 95.27 6781.13 1708.99 1708.99 1159.37 2065.13 34.15 1.82 BP_ MWD+IFR+MS 85 7542.79 35.45 48.83 95.98 6859.77 1746.53 1746.53 1199.59 2118.81 34.48 2.44 BP_ MWD+IFR+MS 86 7638.29 36.02 51.72 95.50 6937.30 1782.16 1782.16 1242.48 2172.52 34.88 1.87 BP_ MWD+IFR+MS 87 7733.56 35.23 54.26 95.27 7014.74 1815.56 1815.56 1286.78 2225.32 35.33 1.76 BP_ MWD+IFR+MS 88 7829.57 35.27 60.82 96.01 7093.18 1845.26 1845.26 1333.47 2276.65 35.85 3.94 BP_ MWD+IFR+MS 89 7926.09 36.92 68.80 96.52 7171.21 1869.35 1869.35 1384.86 2326.44 36.53 5.16 BP_ MWD+IFR+MS 90 8021.39 38.57 77.53 95.30 7246.62 1886.13 1886.13 1440.60 2373.35 37.37 5.86 BP_ MWD+IFR+MS [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 24 -Dec-2008 22:07:50 Page 5 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 8117.42 39.13 80.28 96.03 7321.41 1897.71 1897.71 1499.70 2418.76 38.32 1.89 BP _MWD+IFR+MS 92 8213.44 39.00 80.96 96.02 7395.97 1907.57 1907.57 1559.40 2463.85 39.27 0.47 BP _MWD+IFR+MS 93 8308.26 38.97 80.55 94.82 7469.67 1917.16 1917.16 1618.28 2508.85 40.17 0.27 BP _MWD+IFR+MS 94 8403.74 39.77 81.40 95.48 7543.48 1926.65 1926.65 1678.10 2554.99 41.06 1.01 BP _MWD+IFR+MS 95 8499.10 40.05 81.59 95.36 7616.63 1935.70 1935.70 1738.60 2601.86 41.93 0.32 BP _MWD+IFR+MS 96 8595.33 40.83 81.24 96.23 7689.87 1945.02 1945.02 1800.32 2650.33 42.79 0.84 BP _MWD+IFR+MS 97 8689.98 40.11 81.29 94.65 7761.87 1954.35 1954.35 1861.04 2698.70 43.60 0.76 BP _MWD+IFR+MS 98 8786.23 39.18 81.29 96.25 7835.99 1963.65 1963.65 1921.74 2747.55 44.38 0.97 BP _MWD+IFR+MS 99 8881.59 40.99 81.94 95.36 7908.94 1972.60 1972.60 1982.49 2796.68 45.14 1.95 BP _MWD+IFR+MS 100 8976.87 40.51 82.09 95.28 7981.12 1981.24 1981.24 2044.08 2846.68 45.89 0.51 BP MWD+IFR+MS 101 9072.59 41.45 82.14 95.72 8053.38 1989.85 1989.85 2106.26 2897.56 46.63 0.98 BP _MWD+IFR+MS 102 9167.85 41.39 80.95 95.26 8124.82 1999.11 1999.11 2168.59 2949.45 47.33 0.83 BP _MWD+IFR+MS 103 9262.88 40.61 80.76 95.03 8196.54 2009.02 2009.02 2230.15 3001.62 47.99 0.83 BP _MWD+IFR+MS 104 9358.48 39.71 81.13 95.60 8269.60 2018.73 2018.73 2291.03 3053.54 48.62 0.97 BP _MWD+IFR+MS 105 9454.98 39.97 80.53 96.50 8343.70 2028.58 2028.58 2352.06 3106.02 49.22 0.48 BP MWD+IFR+MS 106 9550.68 41.10 78.22 95.70 8416.43 2040.06 2040.06 2413.18 3159.95 49.79 1.96 BP _MWD+IFR+MS 107 9645.79 40.68 77.68 95.11 8488.33 2053.06 2053.06 2474.07 3214.97 50.31 0.58 BP _MWD+IFR+MS 108 9682.98 40.40 77.75 37.19 8516.59 2058.20 2058.20 2497.69 3236.45 50.51 0.76 BP _MWD+IFR+MS 109 9745.87 40.58 79.26 62.89 8564.42 2066.34 2066.34 2537.70 3272.56 50.85 1.59 BP _INC+TREND 110 9778.12 41.39 79.80 32.25 8588.77 2070.18 2070.18 2558.50 3291.14 51.02 2.74 BP _MWD+IFR+MS • 111 9818.17 43.20 90.59 40.05 8618.43 2072.38 2072.38 2585.28 3313.37 51.28 18.67 BP _MWD+IFR+MS 112 9841.89 44.30 95.39 23.72 8635.57 2071.52 2071.52 2601.65 3325.62 51.47 14.74 BP _MWD+IFR+MS 113 9870.69 44.02 92.59 28.80 8656.23 2070.13 2070.13 2621.66 3340.44 51.70 6.84 BP _MWD+IFR+MS 114 9905.47 43.84 92.10 34.78 8681.28 2069.14 2069.14 2645.77 3358.78 51.97 1.11 BP _MWD+IFR+MS 115 9937.06 43.77 90.92 31.59 8704.08 2068.56 2068.56 2667.63 3375.67 52.21 2.60 BP _MWD+IFR+MS 116 9968.82 43.57 96.33 31.76 8727.06 2067.18 2067.18 2689.50 3392.14 52.45 11.78 BP _MWD+IFR+MS 117 10000.46 43.36 100.44 31.64 8750.03 2064.01 2064.01 2711.02 3407.31 52.72 8.96 BP _MWD+IFR+MS 118 10032.74 43.03 99.48 32.28 8773.56 2060.19 2060.19 2732.78 3422.35 52.99 2.28 BP _MWD+IFR+MS 119 10063.73 43.41 102.62 30.99 8796.15 2056.12 2056.12 2753.61 3436.56 53.25 7.05 BP _MWD+IFR+MS 120 10096.28 43.67 103.73 32.55 8819.75 2051.01 2051.01 2775.44 3451.04 53.54 2.48 BP MWD+IFR+MS [(c)2008 IDEAL ID13_OC_13] 5CHLiTMBERGER Survey Report 24 -Dec-2008 22:07:50 Page 6 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 10128 61 43.68 107.67 32.33 8843.13 2044.97 2044.97 2796.92 3464.77 53.83 8.41 BP_MWD+IFR+MS 122 10160.01 43.81 109.44 31.40 8865.82 2038.06 2038.06 2817.50 3477.36 54.12 3.92 BP_MWD+IFR+MS 123 10191.42 43.52 107.73 31.41 8888.54 2031.15 2031.15 2838.06 3490.00 54.41 3.87 BP_MWD+IFR+MS 124 10223.46 43.25 108.13 32.04 8911.83 2024.37 2024.37 2859.00 3503.13 54.70 1.20 BP_MWD+IFR+MS 125 10255.76 42.97 108.86 32.30 8935.41 2017.37 2017.37 2879.93 3516.21 54.99 1.77 BP_MWD+IFR+MS 126 10287.21 42.96 110.11 31.45 8958.42 2010.22 2010.22 2900.14 3528.71 55.27 2.71 BP_MWD+IFR+MS 127 10319.34 43.98 110.49 32.13 8981.74 2002.55 2002.55 2920.87 3541.42 55.57 3.28 BP_MWD+IFR+MS 128 10351.78 43.63 109.76 32.44 9005.15 1994.82 1994.82 2941.95 3554.49 55.86 1.89 BP_MWD+IFR+MS 129 10367.16 43.49 110.44 15.38 9016.30 1991.18 1991.18 2951.90 3560.69 56.00 3.18 BP_MWD+IFR+MS 130 10415.00 43.49 110.44 47.84 9051.00 1979.68 1979.68 2982.75 3579.94 56.43 0.00 Projected_TD [(c)2008 IDEAL ID13_OC_13] I ~~ ALASSA OIL AI~TD GAS CO1~T5ERQATIOI~T COMI~IISSIOI~T Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAN PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 fAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, N-18A BP Exploration Alaska Inc. Permit No: 208-175 Surface Location: 1820' FNL, 769' FWL, SEC. 08, T11N, R14E, UM Bottomhole Location: 5130' FNL, 3658' FWI,, SEC. 05, T11N, R13E, UM Dear Mr. Hobbs: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt -you from obtaining additional pe 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. Vy~hen providing notice for a representative of the Commission to witness an,' required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ 3 day of November, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. `~ ~ STATE OF ALASKA ~/ 6 8 /'~,/~~ t`~~p ALAS~JIL AND GAS CONSERVATION COMMON '' u. PERMIT TO DRILL 20 AAC 25.005 ~_ :~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^Coalbed Methane ' ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: N-18A 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Proposed Depth: MD 10564' TVD 8914' ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1820' FNL 769' FWL SEC T11 N 08 R13E UM 7. Property Designation: ADL028282 Pool , , . , , , Top of Productive Horizon: 4967' FNL, 3009' FWL, SEC. 05, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 18, 2008 Total Depth: 5130' FNL. 3658' FWL, SEC. 05, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 20600' 4b. Location of Well (State Base Plane Coordinates): Surface: x-634586 y-5969367 Zone-ASP4 10. KB Elevation (Height above GL): 69.20 feet 15. Distance to Nearest Well Within Pool: 108' 16. Deviated Wells: Kickoff Depth: 3250 feet Maximum Hole An le: 63 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3761 Surface: 2910 1 'n ifi i n T i m f m .f. r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data _1 7" Tcu / erc-nn 7 76 ' $ 77' LI r 1 7 ' -1/ " 4-1/ " 1 1 Vam T 7 8 77' 10 981' 14 c la ' b ~ -~ 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10370 Total Depth TVD (ft): 43 Plugs (measured): 9381' Effective Depth MD (ft): 10313 Effective Depth TVD (ft): 9194 Junk (measured): 10045' Casin ' `Len th Size `Cement Volume MD TVD Conductor /Structural ~ " Surface / ° 7 r I 7 1' 2711' Intermediate 174 ' Liner 1 7' ° I ' - 1 7 ' 2 ' 4 ' i r 1 7' 1 '-1 71'- Perforation Depth MD (ft): Below Plug 9710' - 9850' Perforation Depth TVD (ft): Below Plug 8671' - 8792' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name Gr `bbs Si nature Contact Jovy Roach, 564-4352 Title En ineerin Team Leader Prepared By Name/Number: Phone 564-4191 Date / s" o Sondra Stewman, 564-4750 ` Commission Use On Permit To Drill r: oTO~'- ~ API Number: 50-029-20906-01-00 Permit Apr val See cover letter for r it n s Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me~~th//ane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes MNo Mud Log Req'd: ,^,/Yes G~No 1 HZS Measures: Yes ^ No Directional Survey Req'd: 1U Yes ^ No Other: ~ ~~ ~ PS ~ ~ ~ ~ ~ ~ '~~ / "' APPROVED BY THE COMMISSION Date COMMISSIONER Form 10-404 Revised 17/2005 ` i Submit In Duplicate by To: Alaska Oil & Gas Conservation Commission From: Jovy Roach, ODE Date: November 12, 2008 Re: N-18A Sidetrack Permit to Drill The N-18A well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location ~ December 19, 2008. The plan is to exit the parent N-18 wellbore from the 9-518" casing at 3250' MD with an 8-1/2" BHA. The 81/2" hole will then be drilled to the top of the Sag River formation where 7" casing will be run to surface and cemented below the window. A 6-1/8" hole will then be drilled to TD in the Ivishak Zone 2. A solid 4-1/2" production liner will be run and cemented in place, and a 4-1/2" completion will be run. Well history/current status: Well Construction: N-18 was drilled in 1983 and completed in Zone 4, with down squeezed with Arctic Pack. In 1989 a RWO was performed to replace the 5-1/2" tubing and clean out rocks in the tailpipe. A 5" liner was cemented in place after the perforations were squeezed to repair the erosion damage to the 7" liner. In 1992 the well was frac'd to improve production rates. Oil rate reduction was noticed following water reduction in late 1990's. Well experienced premature breakthrough from N-08Ai/N-23Ai/M-29i. Feb 2000 the welt was squeezed for water shut off. March 2004 caliper shows the worst penetration at 64% and the deepest line corrosion at 58%. Anncomm: N-18 was waivered in 2002 for T x IA communication, which is no longer permissible. The waiver was cancelled 11105. The well was secured with a TTP in 2006 after failing a NFT-IA with FTS @ 300psi. In Oct 07 N-18 failed a CMIT TxIA with a LLR established; 4bpm @ 1060#. The well failed subsequent MIT-T and MIT-OA with fluid, however, MITOA passed to gas. REASON FOR SIDETRACK: N-18 is currently SI as a low value producer with ratty tubing and annular communication issues. The well was evaluated as a sidetrack candidate with no options in the immediate area. The current location is already drained by N-13/25/26. Replacing N-06 in the N-06/N-14 drainage pattern will allow for off take in this area identified in the J/N pad APE review. N-06 repair will then be available to provide future UZI injection. Please note the following Well Summary as detailed on the next few pages. N-18A Permit to Drill Application Page 1 To: Alaska Oil & Gas Conservation Commission From: Jovy Roach, ODE Date: October 30, 2008 Re: N-18A Sidetrack Permit to Drill The N-18A well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location ~ December 19, 2008. The plan is to exit the parent N-18 wellbore from the 9-5/8" casing at 3250' MD with an 8-1/2" BHA. The 8-1/2" hole will then be drilled to the top of the Sag River formation where 7" casing will be run to surface and cemented below the window. A 6-1/8" hole will then be drilled to TD in the Ivishak Zone 2. A solid 4-1/2" production liner will be run and cemented in place, and a 4-1/2" completion will be run. Please note the following Well Summary as detailed on the next few pages: N-18A Permit to Drill Application Page 1 • Well N-18A Well Slant Target Zone 3 T e Sidetrack Ob'ective API Number: 50-029-20906-01 Current Status N-18 Shut-in Estimated Start Date: 18-Dec-2008 Time to Com lete: 22 Da s Surface Northin Eastin Offsets TRS Location 5,969,367 634,586 1820' FNL / 769' FWL 11 N, 13E, 8 Northin Eastin TVDss Offsets TRS Target 5,971,540 636,780 -8510 4967' FNL / 3009' FWL 11 N, 13E, 5 Locations 5,971,500 637,140 -8755 5014' FNL / 3368' FWL 11 N, 13E, 5 Bottom Northin Eastin TVDss Offsets TRS Location 5,971,389 637,432 -8919 5130' FNL / 3658' FWL 11 N, 13E, 5 Planned KOP: 3250'MD / 3176'TVDss Planned TD: 10564'MD / 8914' TVDss Ri Nabors 7ES RT-GF: 28.2' RT-BF: 25.65' Directional - SLB (P10) Planned Well Summary KOP: 3250' MD Maximum Hole Angle: 49° in the 8-1/2" intermediate section 63° in the 6-1/8" roduction section Close A roach Wells: All wells pass major risk criteria for close approach. Surve Pro ram: MWD Standard + IFR / MS Nearest Pro ert Line: 20,600' (North) to the PBU property line Nearest Well within Pool: N-20 is the closest well at 108' ctr-ctr with 56' of allowable deviation at tanned de th of 4180' MD. Contacts Drilling Engineer Geologist Pad Engineer Name Phone # Jovy Roach 564-4352 Roger Sels 564-5215 Chris Zamora 564-4138 E-mail iow.roach @ bp.com Roger.Sels C~ bp.com ch ris.zamora C«~ bp.com N-18A Permit to Drill Application Page 2 Formation Markers N-18A (Based on SOR) Estimated Formation To ~s Formation TVDss Plannned MD SV3 2907 SV2 3035 Kickoff 3176 3250 SV1 3390 3472 UG4 3720 3813 UG3 4010 4123 UG1 4285 4430 WS2 5055 5292 WS1 5250 5510 CM3 5430 5711 THRZ 6730 7168 BHRZ/TKUP 6950 7432 LCU 6950 7432 TKNG/TJG 7235 7822 TJF 7555 8310 TJE 7730 8577 TJD 7943 8901 TJC 8205 9301 TJB 8335 9499 TSGR 8510 9766 TSHU 8610 9924 TSAD 8610 9924 42N/Zn4A 8690 10072 TCG L 8760 10225 PGOC 8760 10225 POWC 8822 10362 BCGL 8836 10393 25N 8925* MHO/HOT 8980* 22N/Zn2A 9000* TZ1 B 9092" TDF 9140* BSAD 9189" Casina/Tubina Proaram Hole Size Csg / Tb O.D. Wt/Ft Grade Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 8-'/z" 7" 26# L-80 TC II 7,240 5,410 4500' Surface 4500' / 4415' 8-'h" 7" 26# L-80 BTC-M 7,240 5,410 5266' ' / 9766' / 8577 6-1/8" 4 ~/z" 12.6# 13Cr-80 Vam To 10,160 10,530 798' / 8577' 10564' / 8981' Tubin 4'h" 12.6# 13Cr-80 Vam To 10,160 10,530 9,604' Surface 9604' / 8471' CSc~~~ N-18A Permit to Drill Application Page 3 • Mud Proaram Whi stock Millin Mud Pro erties: LSND Whip Stock Window 9-5/8", 47# Densit PV YP API FL HTHP FL MBT PH 9.0 16-30 30-35 <6.0 N/C N/C 9.0-10 Intermediate Mud Pro erties: LSND 8-1/2" hole section Depth Interva Density (pp PV YP API FL HTHP FL MBT PH 3250'-6968' 9.0 - 9.5 10-18 20-30 <6.0 N/C <12 9.0-10 6968'-9766' HRZ to Sa 11.0 12-22 20-25 4.0-6.0 <10.0 <15 9.0-10 Production Mud Pro erties: FLOPRO SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densit PV YP LSVR API FI H MBT 9766' - 10564' 8.4 - 8.5 8-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 3 Loaaina Proaram 8-1/2" Intermediate: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drillin Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Cement Proaram Casin Size: 7" 26#, L-80 Lon strin Intermediate section Basis: Lead: 4766' of 7" x 8-1/2" o en hole with 40% excess Tail: 1000' of 7" x 8-1/2" open hole with 40% excess, plus 80' shoe track Tail TOC: 8766' MD Total Cement Volume: Spacer 30 bbls of Viscosified Spacer (Mud Push II) Lead 150 bbls, 826 cu ft, 286 sks, 11.5 Lite Crete, Yield = 2.89 cuft/sk Tail 35 bbls, 197 cu ft, 166 sks 15.8 Class G, Yield = 1.19 cuft/sk Tem BHST = 174° F at TOC, BHCT TBD b Schlumber er Casin Size 4.5" 12.6#, 13-Cr-80 Production Liner Basis: Lead: None Tail: 798' of open hole with 40% excess, 80' shoe track, 150' 4-~/z" x 6-1/8" liner lap, and 200' of 7" x 4" DP excess. Tail TOC: 9564' MD (TOL) Total Cement Volume: Spacer 30 bbls of Viscosified Spacer (Mud Push II) Lead None Tail 25 bbls, 140 cuft, 120 sks 15.8 Ib/ al Class G, Yield = 1.17 cuft/sk Tem BHST = 217° F, BHCT TBD b Schlumber er N-18A Permit to Drill Application Page 4 Surface and Anti-Colll~ n Issues Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface N-19 to the north and N-17 to the south are nearest at 110' centers. Close Approach Shut-in Wells: All wells pass major risk criteria. Hydrogen Sulfide N-Pad is not designated as an H2S site. Recent H2S data from the pad is as follows: Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) N-19 10 m 5/3/06 N-17 10 m 7/31/07 N-25 45 m 4/8/07 N-26 60 m 8/1/07 N-26 100 m 2/1/02 Most recent reading on N-18 is 20 ppm on 9/11/06. Faults Before reaching the target polygon the well will cross a fault in the Kingak, probably not far below the TJC marker, at about 9400 MD. The direction is D to the SW, with about 30 ft of offset. Crossing this fault at right angles in the predominately shale Jurassic section is not expected to cause lost circulation problems. Faults in the area: a 20-35 ft, D to South fault located about 270 ft North (at TZ1 B) of the planned well path. This fault was cut by the N-06 well in the Shublik, where it had 33 ft of missing section. The lost circulation database does not list any losses in the N-06 in the vicinity of this fault. N-18A Permit to Drill Application Page 5 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for N-18A will be 14 days during drilling phase and 7 days during decompletion and surface casing work. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum antici ated BHP 3761 psi 8510' TVDss (8.5 EMW) Maximum surface ressure 2910 psi (.10 psi/ft as radient to surface) Kick tolerance 85 bbl over 11.6 pp FIT assumin 8.5 ore pressure and 4" drill i e Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface ressure Inte ri Test - 8-1/2" hole 11.6 p FIT after drillin 20' from middle of window Production Interval Maximum antici ated BHP 3200psi @ 8800' TVDss (7.0 pp EMW) Maximum surface ressure 2320 si (.10 si/ft as radient to surface) Kick tolerance Infinite with a 10.0 FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin /7" Liner Test 3500 psi surface pressure Inte ri Test - 6-118" hole 10.0 FIT after drillin 20' of new hole Planned com letion fluids 8.5 pp Seawater / 7.2 pp Diesel Variance Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. Disposal • No annular injection in this well.. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject (GNI) at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: All Class II liquid waste (including drilling muds and/or brines that have been downhole) are to be hauled to GNI at DS-04 for injection. For the disposal of Class I wastes, contact the GPB Environmental Advisors (659-5893) for the appropriate disposal method at Pad 3 or GNI. NOTE: Generally, Class I solids will be directed to the GNI on DS-04 and Class liquids will be directed to Pad 3. N-18A Permit to Drill Application Page 6 Drilli~ H z r n i i i q a a ds a d Cont ngenc es POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 7.0 ppg EMW, based on offset well pressures. All casing strings will be tested to 3500 psi, in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation/Breathing The area where the N-18A sidetrack will be drilled is located within the moderate loss province from the WURD lost circulation study. According to the lost circulation database, the nearest significant LC incident was 1925 ft South in N-14, which lost 330 BBL "below BSAD". Based on this information, the risk of lost circulation in N-18A is rated as moderate. Well Type BBL MD TVDSS Zone X Y J-09A rig 145 11823 8959 ZONE 1 639557 5969963 J-21 rig 155 7152 6758 Above SAG RIVER-LCU 642257 5971577 N-14 rig 330 10205 9355 Below BSAD 636325 5969727 N-14A rig 100 9406 ? N-23 rig 4282 10400 8775 ZONE 2 631382 5971809 N-25 rig 265 9436 8553 ? 632092 5969530 III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate section is 132 bbl and that for the production section is infinite with planned mud weights. The FIT will prove up adequate formation strength for expected ECD's. B. Integrity Testing Test Point Test De th Test a EMW Ib/ al 9 5/8" window 20-ft minimum from the 9 5/8" window FIT 11.6 minimum 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. H-PAD is not designated as an H2S site; H2S levels of potentially lethal concentrations have been recorded on this pad, however, current levels are below the 100 ppm threshold to be considered an H2S pad. VII. Faults A. Before reaching the target polygon the well will cross a fault in the Kingak, probably not far below the TJC marker, at about 9400 MD. The direction is D to the SW, with about 30 ft of offset. Crossing this fault at right angles in the predominately shale Jurassic section is not expected to cause lost circulation problems. See Section II on lost circulation for more details. VIII. Anti-Collision Issues B. All wells pass major risk criteria for close approach. N-20 is the closest well at 108' ctr-ctr with 56' of allowable deviation at planned depth of 4180' MD. CONSULT THE NPAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION N-18A Permit to Drill Application Page 7 Operations Summary Current Condition and history: 1. MIT - T failed 10/12/07. Too small to detect LLR. 2. CMIT - T x IA passed to 2500 psi 12/29/2007. 2. MIT - OA passed to 500 psi with N2 7/14/2008. 5. PPPOT-T passed 5000 psi 10/13/07. 6. PPPOT-IC passed 3500 psi 10/13/07. 7. Currently has a WRP set at 9365' SLM / 9381' MD. Scope Notify the field AOGCC representative with intent to plug and abandon. Pre-Riq Work: S 1 RU, drift 5-1/2" tubing to WRP at 9381 MD. Pull WRP plug. Drift 5" liner. (Fish - WL prong 127" x 1.9" est. at 10045'; Last to at 9802' 11 /03/03. C 2 P & A the perforations in the N-18A wellbore with 19.7 bbl + excess 15.8 ppg Class G cement. Bullheading is acceptable. Planned TOC at 9215' (9-5/8" x 5-1/2" TIW HBBP packer). Test to 2500 si er AOGCC Re s. E 3 Punch tubin at ~ 9210' MD, ~ust above TOC. F 4 Circulate the well to seawater through the tubing punch. Freeze protect the IA and tubing with diesel to 2,200'. E 3 Jet cut the 5-1/2", 17#, L-80 tubin in the middle of a full ~oint of tubin at ~ 4000' MD. O 5 Bleed OA, IA & TBG to zero psi. PPPOT - IC (9-5/8") 3500 psi, PPPOT-T (5-1/2") 5,000 psi. Function all lock-down screws. O 6 Pressure test the OA (13-3/8" casing) to 2000 psi for 30 minutes. CMIT T x IA to 3,500 psi for 30 minutes. O 7 Bleed all casin and annulus ressures to zero. Set a BPV in tubin han er. Secure well. O 8 Remove the well house. Level the pad. Provide total well preparation cost on the handover form. Riq Operations: ~~ ~ ` "10 1. MIRU. 2. MIT-OA 2000 psi. If the MIT fails, obtain a LLR. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC and test from below to 1000 psi (also test TxIA) and from above to 3500 psi. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. RU and pull the 5-1/2" tubing from the pre-rig jet cut ~ 4000'. Spool up SSSV control lines. Count bands and clamps retrieved. 5. Pick up 9-5/8" casing scraper. RIH to 4000', ensure casing is clean. POOH. LD scraper assembly. 6. RU a-line. Run GR/CCL from TOC to surface to confirm EZSV setting depth. Set EZSV at ~ 3282' MD, to ensure top of window at 3250' MD. 7. PU 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. Swap well over to fresh water LSND millin fluid. F8. Mi a win ow in e - casing rom ~ plus ' of formation from mid-window. Note: Verify that the mud weight is correct prior to cutting the window. 9. Perform an FIT. POOH for Drilling BHA. 10. MU the 8-1/2" drilling assembly with DIR/GR/RES/PWD and RIH. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the Top of the Sag River (9766' MD). CBU, short trip to window and ~ ~ back to TD, circulate well clean and POOH. Consider 2-stage cement job if there are losses -expect ~ .. ~ 11. a fault in Kingak near TJC marker. Run a 7" longstring from TD of the 8-1/2" hole to surface. Cement 7" casing with TOC at 4000' MD ~~1`'~~ (750' below window at 3250' MD). " ~ 12. casing to 3,500 psi for 30 min charted. Immediately after bumping the top plug, test the 7 N-18A Permit to Drill Application Page 8 13. Confirm infectivity through 7" x 9-5/8" annulus. Monitor well. r 14. MU 6-1/8" BHA with DIR/GR/RES/NEU/DEN and RIH to the 7" landing collar. 15. After confirming 500 psi compressive strength has been reached, freeze protect 7" x 9-5/8" annulus with diesel. 16. Drill out the shoe tract. Swap over to Flo Pro SF mud and drill 20' of new formation. Perform an FIT. 17. Drill ahead building to 63° slant landing point 10094' MD. POOH for bit & BHA change. 18. MU 6-1/8" BHA with DIR/GR/RES/DEN/NEU. RIH and MAD pass build section. Drill ahead in the slant as per plan to an estimated TD of 10564' MD. 19. CBU, short trip, circulate until clean and spot a liner running pill. POOH. 20. Run and cement a 4-1/2", 12.6#, L-80, IBT-M liner throughout the 6-1/8" wellbore and 150' back into the 7" intermediate casing to 9616' MD. Set liner top packer and displace well to clean seawater above the liner top. NOTE: A pen` pill will be left in the 4-1/2"liner. 21. Run the 4-1/2", 12.6#, 13Cr, Vam Top completion. Tie into the 4-1/2" liner top. 22. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 23. Set and test TWC. 24. ND BOPE. NU and test the tree to 5,000 psi (Change to a 4-1/16" tree and use a new adapter flange). 25. Freeze protect the IA and tubing to 2,200' and secure the well. 26. RDMO. Estimated Pre-rig Start Date: Estimated Spud Date: 11 /18/2008 12/18/2008 N-18A Permit to Drill Application Page 9 TREE _ 6" MCEV OY ACTUATOR = OTIS KB. ELEV = 69.20' BF. ELEV = 40.46' KOP = 3050' Max Angle = 38 @ 7300' "~+um MD = 9938' ,Im TV D = 8800' SS 9-5/8" DV PKR 13-3/8" CSG, 72#, L80, ID = 12.347" Minimum ID = 4.455" @ 9237' 5-112" OTIS XN NIPPLE N-18 S NOTES: 5-1/2" CAM SSSV LANDING NIP, ~ = 4.562" I (SAS LIFT MANDRELS S NtD TVD DEV TYPE VLV LATCH PO DATE 6 3020 3019 9 OTIS DONE RA 16 05/28100 5 5406 5109 31 OTIS DONE RA 16 05/28/00 4 7045 6491 37 OTIS DONE RA 16 05/28/00 3 8327 7510 36 OTIS DMY RA 0 02/12/00 2 9139 8181 33 OTIS DMY RA 0 03!89 1 9168 8205 33 OTIS SO RA 22 11/28/01 OTIS X NIP, ~ = 4.562" 9-5/8" X 5-1/2" TIW HBBP PKR W/ LATCH, ID = 4.75" 5' M~LOUT EX'fBVSION, ID = ? 5-1/2" OTIS X NIP, ID = 4.562" 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" TOP OF 5" LNR TOP OF 7" LNR ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" ) PERFORATION SUNAIAARY REF LOG: GEARHART BRCS ON 02/21/83 ANGLE AT TOP PERF: 29 @ 9710' Note : Refer to Production DB for historical pert data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 9710 - 9735 C 06/14/00 3-3/8" 4 9768 - 9800 C 04/11/89 3-3/8" 4 9812 - 9850 C 04/11 /89 PBTD 5" LNR 18#, L-80 FL4S, .0177 bpf, ID = 4.276" ~ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I 9237' ~ 5-1/2" OTIS XN NIP, ID = 4.455" I 9244' 5-1/2" TM/ SEAL ASSY W/O SEALS 9243' ELN1D TT LOGG®04/11/89 9381' S" WRP(12/22/07) 10045' I-I FISH - WL PRONG 127" X 1.9" PRUDHOE BAY UNIT WELL: N-18 PERMIT No: 1830180 API No: 50-029-20906-00 SEC 8, T11 N, R13E, 1820' SNL & 769' EWL BP 6cploration (Alaska) TREE= 4" CAMERON -WELLHEAD McEvoy ACTUATOR OTIS KB. ELEV = 69.20' BF. ELEV = 40.46' KOP = 3250' Max Angle = -__... s._,.._,_ _ __-- - 63.34@10231' - - ----------- __ . Datum_MD = _ ~~ _ 7856' Datum ND = 8800' SS fT18A DRAFT ~ '~"`"""' ~ 2000• Hain" HES X l~P, D = 3.813° 1I~~13-318' CSG, 72i, L-B0, ID = 12.347" GAS LIFT MANDRELS Minimum ID = 3.725" @ - 9803' 4-1 /2" XN NIPPLE 9-518" Whipstock 3250' KOP 3250' 9-5/8" EZSV 3274` Top of 5-1/2" TBG Cut 1~ 4000' Tubing punch 9210' Proposed TOG 9215' TOP OF 5" LNR TOP OF 7" LNR 9-5/8" CSG, 47#, L-80, ID = 8.681" ST MD ND DEV TYPE VLV LATCH POR DATE 9 2856 2850 xxlxx/zoos 8 4894 4750 xxrxxrzooa 7 6028 5750 xxrxx/zoos 6 6920 6500 xxrxxrzooa 5 7545 7000 xx/xxr2oo8 4 8221 7500 xxrxxrzoos 3 9034 8000 2 9846 8500 1 10849 9000 ^- 4000 Planned TOC 4500• T csg Crossover STGMto TCII 953T '< 41 n" HES X N~, ID = 3.813" -- 8547' T X 41/2" BKR S-3 PKR -. 457d• 4117' HES X NP. D = 3.813" 9594' -~ 4117' HES XN NIP, D = 3.725" 9604' =x 41/2" SBR Qf~1 A• Hanaer/Li~er too packer 17" CSG, 26lf L-80, .0383 bpf, ~ = 6.276" 1 PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: SIZE SPF INTERVAL Opn/Sqz DATE PaTO 10230' 1 10564' I DATE REV BY COMMENTS DATE REV BY COMMENTS 02/28/83 ORIGINAL COMPLETION 03/05/89 RWO 10/23/08 JER PROPOSED SIDETRACK PRUDHOE BAY UNIT WELL: N-18A PERMff No: 1830180 API No: 50-029-20906-01 SEC 8, T11 N, R13E, 1820' SNL & 769' EWL BP Exploration (Alaska) by Schlumberger N-18A (P10) Proposal Report Date: October 28, 2008 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration (Alaska) Vertical Section Azimuth: 56.420° Field: Structure I Slot: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft N-PAD I N-18 M ~~ ay TVD Reference Datum: Rotary Table Well: ~ f'~ N-18 • ND Reference Elevation: 67.0 ft relative to MSL Borehole: ~ Plan N-18B e'asl Base Flange Elevation: 40.46 ft relative to MSL UWIIAPI#: 500292090601 ^ Magnetic Declination: 22.809° Survey Name I Date: N-18A (P10) I October 28, 2008 Total Field Strength: 57688.019 nT Tort 1 AHD 1 DDI I ERD ratio: Grid Coordinate System: 130.007° 14273.93 ft 15.815 10.476 NAD27 Alaska State Planes, Zone 04, US Feet Magnetic Dip: 80.907° Declination Date: December 28, 2008 Location LaULong: N 70.32424174, W 148.90866695 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 5969367.000 ftUS, E 634586.000 ftUS North Reference: True North Grid Convergence Angle: +1.02762760° Total Corr Mag North -> True North: +22.809° Grid Scale Factor. 0.99992058 _ Local Coordinates Referenced To: Well Head Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag I Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ff de de ff ff ff k k de de 1100ft Index ffUS ftUS ,~ ,n ee ~, nn o~ cm n ,n ~ ~n FOROQ7S 4d RRdS'Id (N N 7n 39d9R97n W 1dR An99d993 ue-rnsurvey 3L4l. 04 IO AO G/l.GV JIIJ .AA JGVV. aa -J-r. ~i iv. c+ -,....< <. .~~~ ~.,.. ....... .•...•_...... _. __._... _. .-.-. --.__-.- --..-.--_--_-- Top Whipstock 3250. 00 16 .72 277.08 3176 .06 3243. 06 -54. 64 10. 31 -72.43 60. OOR 3.50 3.30 5969376. 01 634513. 40 N 70. 32426991 W 148.90925422 Base Whipstock 3266. 00 17 .75 282.54 3191 .34 3258. 34 -58. 08 11. 13 -77.10 --- 12.00 3.36 5969376. 74 634508. 72 N 70 .32427213 W 148.90929204 KOP Crv 4/100 3279 00 17 75 282 54 3203 72 3270. 72 -60. 83 11. 99 -80.97 131. 31 R 0.00 3.38 5969377. 53 634504. 84 N 70 .32427448 W 148.90932341 . 3300. 00 17 . .21 . 284.67 3223 . .75 3290. 75 -65. 12 13. 47 -87.10 129. 28R 4.00 3.42 5969378. 90 634498. 68 N 70. 32427853 W 148.90937312 3400. 00 14 .99 296.72 3319 .85 3386. 85 -81. 38 23. 03 -112.97 117. 69R 4.00 3.59 5969388. 00 634472. 64 N 70 .32430466 W 148.90958289 SV1 3472. 43 13. 88 307.47 3390. 00 3457. 00 -88. 84 32. 53 -128.24 107. 28R 4.00 3.68 5969397. 22 634457.21 N 70. 32433061 W 148.90970664 3500. 00 13 .59 311.96 3416 .79 3483. 79 -90. 72 36 .71 -133.27 102 .92R 4.00 3.72 5969401. 31 634452. 10 N 70 .32434203 W 148.90974745 3600. 00 13 .27 329.19 3514 .09 3581. 09 -93. 10 54 .43 -147.89 86 .15R 4.00 3.83 5969418. 77 634437. 17 N 70 .32439044 W 148.90986600 3700. 00 14 .10 345.78 3611 .29 3678. 29 -88. 51 76 .11 -156.77 70 .02R 4.00 3.93 5969440. 28 634427. 91 N 70 .32444966 W 148.90993795 3800. 00 15 .91 359.62 3707 .90 3774 .90 -76. 96 101 .64 -159.85 56 .65R 4.00 4.02 5969465. 75 634424. 37 N 70 .32451940 W 148.909962 UG4 3812. 59 16. 19 1.13 3720. 00 3787. 00 -75. 01 105. 12 -159.83 55. 21R 4.00 4.03 5969469. 23 634424. 33 N 70. 32452891 W 148.909962 3900. 00 18 .41 10.25 3803 .47 3870 .47 -58. 51 130 .90 -157.13 46 .49R 4.00 4.11 5969495 .05 634426. 56 N 70 .32459933 W 148.90994091 4000. 00 21 .35 18.24 3897 .51 3964 .51 -33. 25 163 .74 -148.62 38 .98R 4.00 4.20 5969528 .03 634434. 48 N 70 .32468906 W 148.90987190 4100. 00 24 .59 24.29 3989 .59 4056 .59 -1. 31 200 .01 -134.35 33 .40R 4.00 4.28 5969564 .55 634448. 09 N 70 .32478814 W 148.90975627 UG3 4122. 52 25. 34 25.45 4010. 00 4077. 00 6. 79 208. 63 -130.36 32. 35R 4.00 4.30 5969573. 24 634451. 93 N 70. 32481169 W 148.90972385 End Crv 4160 91 26 65 27 28 4044 51 4111 .51 21. 36 223 .70 -122.88 --- 4.00 4.33 5969588 .44 634459. 14 N 70 .32485287 W 148.90966322 UG1 4429. . 99 26. . 65 . 27.28 4285. . 00 4352. 00 126. 79 330. 98 -67.55 - 0.00 4.46 5969696. 69 634512. 53 N 70. 32514594 W 148.90921463 WS2 5291. 54 26. 65 27.28 5055 .00 5122. 00 464. 35 674. 45 109.60 --- 0.00 4.73 5970043. 25 634683. 48 N 70. 32608428 W 148.90777826 WS1 5509. 72 26. 65 27.28 5250 .00 5317. 00 549. 84 781. 43 154.46 - 0.00 4.77 5970131. 02 634726. 77 N 70. 32632191 W 148.90741449 CM3 5711. 12 26. 65 27.28 5430 .00 5497. 00 628. 75 841. 73 195.88 - 0.00 4.81 5970212. 03 634766. 73 N 70. 32654126 W 148.90707868 Crv 4/100 6981 .26 26 .65 27.28 6565.19 6632 .19 1126 .40 1348 .10 457.04 68 .54R 0.00 5.01 5970722 .97 635018 .76 N 70 .32792459 W 148.90496076 WeIlDesign Ver SP 2.1 Bld( doc40x_100) N-18\N-18\Plan N-186\N-18A (P10) Generated 10/28/2008 1:54 PM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ff ft tt ff ff de de 100 ft Index ffUS NUS wi ~ on~n~~nc ~ni yea eneenQCe ruvu.vv co.yo co.oc vav i.a i vvtiv.~ ~ 7100.00 28.71 36.51 6670.38 6737.38 THRZ 7168.45 30.15 41.26 6730.00 6797.00 7200.00 30.86 43.30 6757.19 6824.19 7300.00 33.33 49.23 6841.91 6908.91 7400.00 36.05 54.40 6924.15 6991.15 BHRZ / TKUP / LCU 7432.16 36.96 55.92 6950.00 7017.00 7500.00 38.96 58.91 7003.49 7070.49 7600.00 42.02 62.88 7079.55 7146.55 7700.00 45.20 66.40 7151.96 7218.96 7800.00 48.48 69.54 7220.36 7287.36 End Crv 7815.66 49.00 70.00 7230.68 7297.68 TKNG / TJG 7822.23 49.00 70.00 7235.00 7302.00 TJF 8309.99 49.00 70.00 7555.00 7622.00 TJE 8576.74 49.00 70.00 7730.00 7797.00 TJD 8901.40 49.00 70.00 7943.00 8010.00 TJC 9300.76 49.00 70.00 8205.00 8272.00 TJB 9498.91 49.00 70.00 8335.00 8402.00 TSAG 9765.64 49.00 70.00 8509.99 8576.99 N-18A Tgt Sag 9765.66 49.00 70.00 8510.00 8577.00 7" Csg Pt 9765.67 49.00 70.00 8510.01 8577.01 Crv 12/100 9785.66 49.00 70.00 8523.12 8590.12 9800.00 49.29 72.24 8532.51 8599.51 9900.00 52.44 87.19 8595.83 8662.83 TSHU/TSAD 9923.52 53.45 90.50 8610.00 8677.00 10000.00 57.30 100.63 8653.53 8720.53 42N 10071.65 61.59 109.29 8690.00 8757.00 End Crv 10093.81 63.02 111.82 8700.30 8767.30 N-18A Tgt PGOC 10214.39 63.02 111.82 8755.00 8822.00 TCGL/PGOC 10225.41 63.02 111.82 8760.00 8827.00 PO WC 10362.07 63.02 111.82 8822.00 8889.00 BCGL 10392.93 63.02 111.82 8836.00 8903.00 TD / 4-1/2" Lnr 10564.39 63.02 111.82 8913.78 8980.78 1176.50 1208.56 1224.09 1276.35 1333.04 1352.16 1393.87 1458.56 1526.78 1598.21 1609.67 1614.49 1972.32 2168.00 2406.18 2699.15 2844.52 3040.19 3040.21 3040.22 3054.88 3065.37 3136.15 3151.98 3200.60 3241.31 3252.80 1394.71 1420.85 486.23 60.36R 4.00 5.06 5970770. 09 635047 .10 N 70. 32805193 W 148. 90472402 507.35 56.23R 4.00 5.08 5970796. 60 635067. 75 N 70. 32812333 W 148. 90455274 518.13 54.46R 4.00 5.10 5970808. 64 635078 .31 N 70. 32815569 W 148. 90446535 556.55 49.44R 4.00 5.13 5970845. 94 635116 .06 N 70. 32825574 W 148. 90415380 601.30 45.19R 4.00 5.17 5970881. 82 635160 .17 N 70. 32835158 W 148. 90379090 617.00 43.97R 4.00 5.18 5970893. 03 635175. 67 N 70. 32838143 W 148. 90366355 652.16 41.61 R 4.00 5.21 5970916. 10 635210 .43 N 70. 32844274 W 148. 90337840 708.89 38.59R 4.00 5.25 5970948. 61 635266 .58 N 70. 32852879 W 148. 90291832 771.22 36.04R 4.00 5.28 5970979. 20 635328 .36 N 70. 32860929 W 148. 9024128 838.83 33.89R 4.00 5.32 5971007. 71 635395 .46 N 70. 32868387 W 148. 901864 849.87 --- 4.00 5.32 5971011. 98 635406 .43 N 70 .32869498 W 148. 9017750 854.53 - 0.00 5.33 5971013. 76 635411. 06 N 70. 32869962 W 148. 90173720 1200.45 - 0.00 5.40 5971145. 83 635754. 64 N 70. 32904345 W 148. 89893186 1389.63 - 0.00 5.44 5971218. 06 635942. 53 N 70. 32923146 W 148. 89739765 1619.88 --- 0.00 5.48 5971305. 98 636171. 23 N 70. 32946028 W 148. 89553027 1903.10 - 0.00 5.53 5971414. 11 636452. 53 N 70. 32974172 W 148. 89323323 2043.63 - 0.00 5.55 5971467. 77 636592. 11 N 70. 32988135 W 148. 89209346 2232.79 - 0.00 5.58 5971540. 00 636779. 99 N 70. 33006929 W 148. 89055921 2232.80 --- 0.00 5.58 5971540 .00 636780 .00 N 70 .33006930 W 148. 89055912 2232.81 --- 0.00 5.58 5971540. 00 636780. 01 N 70. 33006931 W 148. 89055904 2246.98 81.08R 0.00 5.58 5971545 .42 636794 .09 N 70 .33008339 W 148. 89044408 2257.25 79.61 R 12.00 5.59 5971549 .11 636804 .29 N 70 .33009297 W 148. 89036083 2333.21 70.14R 12.00 5.65 5971564 .02 636879 .99 N 70 .33012992 W 148. 88974475 2351.97 68.14R 12.00 5.67 5971564. 73 636898 .74 N 70. 33013093 W 148. 88959262 2414.45 62.37R 12.00 5.71 5971559 .63 636961 .31 N 70 .33011390 W 148 .88908591 2473.94 57.96R 12.00 5.75 5971544. 70 637021 .07 N 70. 33007013 W 148. 88860353 2492.30 --- 12.00 5.76 5971538 .14 637039 .56 N 70 .33005128 W 148 .88845460 2592.05 --- 0.00 5.78 5971500 .00 637140.00 N 70 .32994208 W 148 .887645 2601.17 - 0.00 5.78 5971496. 51 637149 .18 N 70. 32993210 W 148. 8875718 2714.24 -- 0.00 5.79 5971453. 28 637263 .03 N 70. 32980831 W 148. 88665500 2739.77 - 0.00 5.80 5971443. 52 637288 .74 N 70. 32978036 W 148. 88644799 2881.62 --- 0.00 5.82 5971389 .28 637431 .57 N 70 .32962505 W 148 .88529780 Fasting (X) (ftUSI 634586.00 636780.00 637140.00 637431.57 Legal Description: Surface : 3459 FSL 4511 FEL S8 T11 N R13E UM N-18A Tgt Sag : 312 FSL 2271 FEL S5 T11N R13E UM N-18A Tgt PGOC : 265 FSL 1912 FEL S5 T11 N R13E UM BHL : 149 FSL 1622 FEL S5 T11 N R13E UM 1432.70 1469.32 1504.40 1515.33 1537.78 1569.28 1598.76 1626.06 1630.13 1631.83 1757.73 1826.59 1910.39 2013.47 2064.62 2133.47 2133.48 2133.48 2138.64 2142.15 2155.70 2156.07 2149.86 2133.85 2126.96 3313.81 2087.02 3319.39 2083.37 3388.54 2038.10 3404.16 2027.88 3490.92 1971.08 Northing (Y) [ftUS] 5969367.00 5971540.00 5971500.00 5971389.28 WeIlDesign Ver SP 2.1 Bld( doc40x_100) N-18\N-18\Plan N-186\N-18A (P10) Generated 10/28/2008 1:54 PM Page 2 of 2 • • by Schlumberger WELL N-18A (P10) FIELD Prudhoe Bay Unit - WOA STRUCTURE N-PAD MpneOC Pammeten Surha Location NRG2] Rlaska SMa Plarea, Zore 00, U8 Feet MiuNh reoua ' Maael: fiGGM 2(108 Dip: 80.90]° tbte'. Gecembar 28.3006 Lot MOt93].2]0 NoMieq 895938]00 M15 Geq Gonv .t 02]62]fi0' Sbt. J.006 a1me M6L) N-18 NDReI'. Retary Tade l6 MN Gac'. ~238(B' FS'. 5]868.0 nT Lon. W1a85a J1 Z11 Eastiiq 63aS85.008U6 Sale Fact: 09999205 ]6e Pbn: K1891P10) Sny Gate CKroEer 28. 3008 0 800 1600 2400 3200 3200 Survey Nhipstack,....°..• .... ........................... Whipstock :rv atoo 3200 4000 4800 5600 0 0 4000 4800 5600 c N ~ 6400 H 6400 7200 8000 8800 Crv ~....,...,.,.,...,.,aa.Ta.,m.~. ,.,,,.. :_.._.._.._--_.._.._.._.._.E_.._.._.. ~ ~N-1 SA Tgt Sag _° crv tztoo -.._..-..-.._..-..-..-..-.-.._.._.._.._.._.._.._.. 'F' YSQIS.._.._.. {sa:^»~u~n^::~u~su~t::i::: r.: r.:::::::~:»:: ~::::_- °'~C1~?~b ~°° N-18A Tgt PGOC TD 14-tit" Lnr N-1 BA (P1 ) 0 800 1600 2400 3200 Vertical Section (ft) Azim = 56.42°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V 7200 8000 8800 by Schlumberger WELL N-18A (P10) FIELD Prudhoe Bay Unit - WOA STRUCTURE N-PAD Maprelic Palameten Sulfate L ocaBon NRD3> Naska Slate Plares, Zore 04. US Feet MbcelMneouz Matlel: BGGM 2000 Dq: 80.90]' Dab: Dacem0er 36. 3008 Laf. fJ10192].2]0 Norotinp. 5968]61WM15 Grkl Carl V: +103]63]W' 6b1: N-18 TVD RN'. Ropry Tads (81W Rabow MSL) Map pat: +21809' FS'. 5]680.0 nT Lon: W1a85131.201 Eas0~q: 630.586.W flU6 Scale FaR: 0.9998205]fiA PMn'. KIfl4 (P10) 6rvy Date'. Oclo8er 38, 2008 -500 0 500 1000 1500 2000 2500 3000 2500 2500 •I 2000 n n ~ 1500 Z x 0 0 c ~ 1000 c`~ v v v 500 0 -500 0 500 1000 1500 2000 2500 3000 «< W Scale = 1(in):500(ft) E »> 2000 1500 1000 500 0 BP Alaska Anticollision Report Company: BP Amoco ---- Date: 10!28/2008 Time: 13:58:22 Page: 1 yield: Prudhoe Bay Reference Site: PB N Pad Co-ordinate(NE) Reference: Well: N-18, True North Reference Well: N-18 Vertical (TVD) Reference: N-18A Plan 67.0 Reference Wellpath: Plan N-18A - - _ __ Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1[f@Ii9isYells in thisRlrildlpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 3250.00 to 10564.39 ft Scan Method: Trav Cylinder North !i Maximum Radius:. 1253.60 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 9/11/2007 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 97.64 3249.84 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 3249.84 9766.00 Planned: Pla n #10-2 N-18A V2 MWD+IFR+MS MWD +IFR + Multi Station 9766.00 10564.39 Planned: Pla n #10-2 N-18A V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD CVD Diameter Hole Sue Name ft ft in in 2709.00 2708.92 13.375 17.500 13 3/8" 3250.00 3243.05 9.625 12.250 9 5/8" 9765.66 8577.00 7.000 8.500 7" 10564.39 8980.78 4.500 6.500 4-1/2" Summary <-- -Offset Wellpath -- -> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB N Pad N-06 N-06 V2 5157.88 5800.00 369.62 88.01 281.61 Pass: Major Risk PB N Pad N-15 N-15 V1 5390.43 5860.00 686.00 166.23 519.77 Pass: Major Risk i PB N Pad N-16 N-16 V1 3250.04 3275.00 258.95 50.18 208.77 Pass: Major Risk PB N Pad N-17 N-17 V1 9259.77 3275.00 187.72 105.13 82.59 Pass: Major Risk PB N Pad N-18 N-18 V2 3292.80 3295.00 1.32 55.63 -54.31 FAIL: Major Risk PB N Pad N-19 N-19 V1 3254.07 3265.00 128.16 49.55 78.61 Pass: Major Risk PB N Pad N-20A N-20A V7 4179.50 4135.00 108.39 50.78 57.61 Pass: Major Risk PB N Pad N-20 N-20 V1 4179.50 4135.00 108.39 52.36 56.03 Pass: Major Risk PB N Pad N-21A N-21A V2 3250.17 3730.00 813.00 60.57 752.43 Pass: Major Risk ', PB N Pad N-21 N-21 V2 Plan: Undefine 3250.02 3730:00 813.75 60.92 752.82 Pass: Major Risk • ~ • 313 300 200 100 0 2 100 N- 200 300 313 FieldPrudhoe Bay Site PB N Pad Well :N-18 WellpathPlan N-18A 0 I ill Travelling Cylinder Azimuth (TFO+A21) (deg] vs Centre t __ __ ',From KOP - TD Scan interval 100 ft Scale 1:100 l Site: PB N Pad Drilling Target Conf.: 95% Description: Map Northing: 5971500.00 ft Map Easting :637140.00 ft Latitude: 70° 19'47.791 N Polygon X ft 1 -102.14 2 359.68 3 438.62 4 -18.47 Target: N-18A Tgt PGOC Poly Well: N-18 Based on: Planned Program • Vertical Depth: 8755.00 ft below Mean Sea Level Local +N/-S: 2087.04 ft Local +E/-W: 2592.05 ft Longitude: 148°53' 15.525W Yft MapEft MapNft -118.20 637040.00 5971380.00 -301.52 637505.00 5971205.00 -82.89 637580.00 5971425.00 85.35 637120.00 5971585.00 ._.._........ _ 2+00 2300 2200 • N • ! To: Alaska Oil & Gas Conservation Commission From: Jovy Roach, ODE Date: November 12, 2008 Re: N-18A Sidetrack Permit to Drill The N-18A well is scheduled to be drilled by Nabors Rig 7ES which is currently scheduled to move onto the location ~ December 19, 2008. The plan is to exit the parent N-18 wellbore from the 9-5/8" casing at 3250' MD with an 8-1/2" BHA. The 8-1/2" hole will then be drilled to the top of the Sag River formation where 7" casing will be run to surface and cemented below the window. A 6-1/8" hole will then be drilled to TD in the Ivishak Zone 2. A solid 4-1/2" production liner will be run and cemented in place, and a 4-1/2" completion will be run. Well history/current status: Well Construction: N-18 was drilled in 1983 and completed in Zone 4, with down squeezed with Arctic Pack. In 1989 a RWO was performed to replace the 5-1/2" tubing and clean out rocks in the tailpipe. A 5" liner was cemented in place after the perforations were squeezed to repair the erosion damage to the 7" liner. In 1992 the well was frac'd to improve production rates. Oil rate reduction was noticed following water reduction in late 1990's. Well experienced premature breakthrough from N-08Ai/N-23Ai/M-29i. Feb 2000 the well was squeezed for water shut off. March 2004 caliper shows the worst penetration at 64% and the deepest line corrosion at 58%. Anncomm: N-18 was waivered in 2002 for T x IA communication, which is no longer permissible. The waiver was cancelled 11/05. The well was secured with a TTP in 2006 after failing a NFT-IA with FTS @ 300psi. In Oct 07 N-18 failed a CMIT TxIA with a LLR established; 4bpm @ 1060#. The well failed subsequent MIT-T and MIT-OA with fluid, however, MITOA passed to gas. REASON FOR SIDETRACK: N-18 is currently SI as a low value producer with ratty tubing and annular communication issues. The well was evaluated as a sidetrack candidate with no options in the immediate area. The current location is already drained by N-13/25/26. Replacing N-06 in the N-06/N-14 drainage pattern will allow for off take in this area identified in the J/N pad APE review. N-06 repair will then be available to provide future UZI injection. Please note the following Well Summary as detailed on the next few pages. N-18A Permit to Drill Application Page 1 Page 1 of 2 Maunder, Thomas E (DOA) From: Roach, Jovy [Jovy.Roach@bp.comJ Sent: Wednesday, November 12, 2008 9:56 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: N-18 (183-018) Sorry for the confusion. 1. The correct crossover depth for TC II x BTC-M is 4500' MD, as shown in the schematic. 2. The 4-1/2" top of liner should be at 9616' MD, 150' above the shoe, also correct in the schematic. Thanks, Jovy From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, November 12, 2008 9:45 AM To: Roach, Jovy Cc: Hobbs, Greg S (ANC) Subject: RE: N-18 (183-018) Jovy, I was taking a close look at the "new" procedure you enclosed. The main change I see is the more complete history, etc on page 1. One thing I did note is on page 3 regarding the 7" casing types and on page 3 and the 401 sheet for the 4-1/2" liner. 1. The and/tvd of the bottom of the TC II is not the same as the and/tvd of the BTC-M. Which depths are correct? 2. The top of the 4-1/2" liner is the same as the TD of the 7" casing. I believe the regulations require a minimum of 100' overlap. Message back with a response. I think I can make hand corrections for these. Tom Maunder, PE AOGCC From: Roach, Jovy [mailto:Javy.Roach@bp.com] Sent: Wednesday, November 12, 2008 8:48 AM To: Maunder, Thomas E (DOA); Williamson, Mary J (DOA) Cc: Hobbs, Greg S (ANC); Stewman, Sandra D Subject: RE: N-i$ (183-018) Tom, Jane, Attached is an updated Permit to Drill application. Please consider this in tandem with the Sundry application, as it covers the well history and reason for sidetracking. Let me know if you need anything else. I will be on the slope the rest of the week, and I will be checking email regularly. Thanks, Jovy From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] 11/12/2008 Alaska Department of Natural Resources Land Administration System Page 1 of~ ~ .:. , ~ ~,,,,F. _ ~ , ~~ .. vr-~sr~pr`s ~aa;~ch State Cabins l~i~tural ~~59;341 5 ,,, .~ __. r"y File Type: ADL =. File Number: 28282 ~ Prin. table Case Fite_Summary See Township, Range, Section and Acreage? ~,,, , y New Search ~ Yes ~~ No ~-~~-~ I..AS F_nEa I Case Abstract I Case Detail I Land Abstract bile: ~l)L ?82R? ''~ ScarCh for Status Plat Upd<~tns :~s ~~f 11i06'2(lOS Cztstonzer~.~ 000107377 BP EXPLORATION (ALASKA) INC PO BOX l 96612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case 7yRe: ~ OIL & GAS LLASE COMP DNR U~~zit.~ 780 O1L AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19!1965 Total .Acres: ?469.000 Date Initiated: 05/28/ 1965 Office of Primary Responsibility: DOG DIV O1L AND GAS Last Transaction Date: 12/04/2006 Case Subtype : ~t~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED 1Iri~icliur~: Ci 7~>>ri~~{~rj~: I)i l\ Kuil,~r: (II ~F .ti'ec~liurt~ (1> Sec~lr~~it:lcr~~s (x-1(1 Search.. ~,,} ; ;lkri-i~G<u~: l' ~oirr~s~l~i/~: 01 I\ Rcrf~~rc~.~ 01 ~I Sccliujt.~ 06 .ti~~~clrnit_~Icf~c~s: ~~); lrricli~~~r: l_= 7~~i~~,i~~1ii~~: C111N ,Range: (11 ;I~; S'~~<~~irnr.~ (17 ,5'rrliun.~l~~re~~.~ ~~)6 Meridian: l' 7~n~~,rshr~~: OI1N Range: OJ3E Sectiuri: (1~ .~'ectiun ;9~:~~~~~- (;~lll Legal Descriptiun 0~-2<g-I96~ * * ~ SALE NOTICE LEGAL DESCRIPTIONS C1=1-93 TIIN-RISE-UM S, 6,7,82469.00 04-01-19?7 * x * * * * UNITIZED AND LEASE LEGAL DESCRIPTION * * * * * * x I'NTIRE LEASE COILINIITTED TO PRUDHOE BAY UNIT pRUD1I0E I3AY UNIT http://www. dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2$282&... 11 /6/2008 • i TRANSMITTAL LETTER CHECKLIST WELL NAME ~L/ ~/_ /~A PTD# ao~ /~s Developments __ Service _____ Exploratory Strati _,_ Non-Conventional Well -- ~phic Test FIELD: __ ~.~CID<,/p~ AY POOL: __ ~.e~O.~oE /~iqY Oi~ Circle Appropriate Letter /Paragraphs to be Incladed in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) ~~. FOR APPROVAL LETTER APPLIES MULTI LA'T`ERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. API number are . APt No. SO- _ 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), alt records, data and logs acquit~ed for the pilot hole must be clearly differentiated in both well name ( PIS and AP[ 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 / infect is contingept 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 fmrn below the from where samples are first caught and 10' sample intervals throu et canes. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed me~ane is not allowed for jn_ame of wet until after LComeanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity.lComoanv Name} must contact the Commission to obtain advance approval of such water well testing Dro¢ram_ Rev: 1/! 1/Z008 WEt.L PEAT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHDE OIL -640150 Well Name: PRUDHOE BAY UNIT N-18A Program DEV Well bore seg ^ PTD#:2081750 Company BP EXPLORATION (ALASKAN INC Initial Classil'ype DEV / PEND GeoArea 890 Unft 11650 On10ff Shore ~- Annutar Disposal ^ Administration 1 Pe[mit-feeattached--- ----- - - ---- -- -- ---- NA -- -- --- -- -- ------- - - -- - --- -- - - -- - 2 Lease numberapproR~ate--- -- -- --- - - ------ -Yes - ---- - - -- ------ -- - - -- 3 Unique well-name and number--- -------- - ------ - -Yes----- --- --------- -- - - - --- -- --- - - - -------- 4 WelUocated in a_definedpool- - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - ~ 5 Well located properdistanceframdrillingunitboundary_______________ ____---Yes------ --------------------------------------------------------------_--- 6 WeIIIQCatedProperdistancefro-m4therwells_________________._ ___-_____ Yes______ __--_-_--_ ---------------------------------------------------------- 7 Sufficient acreageay2ilablein_dnllingunit----------------------- --------Yes_----- -2560 acres.-----------------------------_--_----------------- _- -- 8 IfdeYiated,is_wellbareplat_included__________________________ _______ Yes_____- _______-___--_____-__- --------------------------------------------- 9 OpsratoronlyaftectedparlY--- --- ----- - -- --- -- - Yes- -- --- --- -- ------- - - - -- -- 10 Operatolhas_appropriatebondinfQrCe------------------------ ---------Yes------ -131enketBond#fi1~193,--------------------------------------------------- 11 Pe[mitcanbeissuedwithouiconservationorder__--_________-- _______--Yes----- ----------------------------------------------------------__ Appr Date 12 Pe[mitcanbeissuedwithoutadminist[ativ_e_approval_______________ ____-__Yes------ -------------------------------------------------------------_--_--- ACS 11110!2006 13 Canpermitbeapprovedbefore15-day wait________---------- ---- ---YeS_---_- ------_____-_--_---_--_---________-.--------------_--- 14 WeIIIQC~tedwithinareaand_strataauthprizedbylnjection0[de[#(put_10#in_comments)_(For_ NA______- _--__-----------------------_---_-_-------_--------_--_.----_--- 15 All wells within1l4_mileareaofreyiewident~ed(Fo[se_rvicewellonly)-_____ ________ NA------- -----------_.___-_______---_-_-_-______.-_--_---------___-_ 16 Pte-producedinjecior, duration oi'pre~roduction~ssthan3months-(Forss[vicewe{lQnly)--NA------- -------------------------------------------------------------------- 17 Koncanven: gas conforms to A531.05:03QU.1.A)aU.2.A-D) - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - Englneering 18 Conducto[stung-provided_-_____------.-.______----- _-------NA______- _Conduetorset_inN-18j183-018)•_-------------------------------------------- 19 Su[face_casingproiectsall known USDWs--------------------- ----_---- NA_______ _Allaquifersexempted,AE01.------------__----------------------------____-- 20 CMT_v_oladequate.tocirculateonrAnducto[&surf.csg_--_-___-___-_ -_____ NA______- _$urfacecasingsetinN-18._-------------------------__---_-------._.-___- 21 CMT_v_oladequate_totie-inlQngstring to surf csg___________________ _________ NA_______ _Producticn_casingsetin_N-18._-_.-___-_____________-_____--__--_______________ 22 CMT_willcoverallkoown_produotivehorizons-__--__--___-------- ---------Yes----- ---------------------------------------------------------------_--- 23 CasingdesgnsadequateforC,TB&_permafrost------------------ ---- Yes--.--- -----------------------------------------.------------------_-- 24 Adequete tankage_or reserve pik - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes _ - - _ _ _ -Rig equipped with steel pits, Noleserve pit planned,- Ali waste-tQ approved disposal well(s). - _ _ _ _ _ _ _ _ _ _ _ _ 25 If-a-re-d[ill,hasa10-403forabandQnment been aRRroved------------- ---------Yes----- -308.403-------------------------------------------------------------- 26 Adequate wellbo-re separationpraposed_ _ _ _ _ _ - - - - - - - - - - - - - - - - - - _ Yes - - - _ - - _ Proximity analysis performed, No close app[oaohes identified. _ _ _ - - _ _ - - _ - _ - - - _ - - _ - _ - 27 If diverterlequired,doesitmeetregulations__-__--__-_____---- --------- NA_____ _1}OPstackwipslreadY-be inplaee,---------------------------------------------- Appr Date X28 Driiling fluid program schematic & equip list adequate_ - - _ - - - - - - _ - - - Yes - - - - _ Maximum expected formation pressure 8,5_EMW_ MW planned 11.Q ppgin HRZlSag and 6,5 ppg in zone._ - - - - TEM 1111212008 29 BOPI=s,-dotheymeet regulation- --- --------- - ------ - YeS - --- -- -- - --- --- ------- -- -- -- - -- ~, /~ 30 BOPS-press rating approp[iate; test to_(put prig in comments)- - - - - - - - - - - - - - Yes - - _ - - - BOP testplanned, _ _ _ _ _ _ _ _ , _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ MASP calculated at 2910psit 3500_psi Y~y/II 31 Choke_manifoldcamptieswlAPl_RP-53 (May 84)___________________ _________Yes____ = _ _ _ = _ _ _ ____-- 32 Work wiltoccu[withouioperationshuidown___---------------- ---____--Yes------ ----------------------------------------------------------____.-- 33 Is presenee-of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ - _ _ _ UR to_10Q ppm reported ai N pad. _Mud_shouid preclude H2S on rig._ Rig has sensors and arms. _ _ _ - _ _ _ _ _ - 34 Mechanical-condihonoturflllswithinAQRyerified(FOrserviceweilonly~----- ----_-_- NA------- --------------------_------------------.--------------------- Geology 35 Pe[mitcanbeissuedwiohyd[ogensulfidemeasures---------------- --------- No_______ -MaxleveiH2SonweIIN-261QQppm_(211192),__.___._______-_-___--_---_---_---_----- 36 Data_presented on potential gverpr8ssurezones- - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 37 Seismicanaysisofshatlowgaszones ---- ------ -- -- - - - NA------- -------------------- ---- - - ------------ --- ACS 111612006 38 ~ Seabed eenditiQn survey_(if Off-shore) - - - - - - - - .---_--- NA---- - - - - - - - - - - - - - - - - - - - - - - - ~ - - - 39 Contectnamelphone.farweekiy-pro9rassreports[exploratoryonlyl-------- ---------Yes------ -~ovyROachr584.4352..--------------------------------------------------- Geologic Engineering Pub' Date Date; Date Commissioner: Comm s ner Commissioner: ~~r~... ~~az ~ 1~~~z.a~ 1,