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208-120
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 J-08A Install Liner Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-120 50-029-20265-01-00 12294 Conductor Surface Intermediate Production Liner 9111 80 2662 3449 11462 1477 12126 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 9039 30 - 110 29 - 2691 28 - 3477 27 - 11489 10817 - 12294 30 - 110 29 - 2691 28 - 3473 27 - 8658 8158 - 9111 Unknown 2670 4760 5410 7500 12126 4930 6870 7240 8430 12043 - 12123 4-1/2" 12.6# 13Cr80 25 - 10826 9003 - 9038 Structural 4-1/2" Baker S3 Packer 10707, 8076 10707 8076 Torin Roschinger Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 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 0028281 25 - 8165 N/A N/A 345 164 38343 3885 4208 5764 1942 1650 1025 240 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 Kayla Junke at 9:16 am, Apr 21, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.04.20 15:41:56 -08'00' Torin Roschinger (4662) RBDMS JSB 042523 DSR-4/26/23WCB 11-28-2023 ACTIVITY DATE SUMMARY 4/7/2023 *** WELL SI ON ARRIVAL *** INTITAL T/I/O = 350/350/200 YELLOWJACKET ELINE AND NORTHERN SOLUTIONS LOWER PACKER. RIH W/ GR/CCL, #10 SETTING TOOL, AND PKR. STACK OUT AT 6300 FT. MAKE SEVERAL ATTEMPTS TO RIH, PICK UP CLEAN EVERY TIME. POOH AND REGROUP. REHEAD FOR OVER LINE 2-3/4" WEIGHT BARS, RIH 550 LB TOOL (IN AIR) AND STACK OUT AGAIN AT 5100 FT. PUMP W/ TRIPLEX PUMP, MAKE SEVERAL ATTEMPTS, POOH AND REGROUP, JOB TO BE CONTINUED PENDING AVAILABILITY OF PUMPING ASSIST. SDFN, SECURE WELL, NOTIFY DSO. FINAL T/I/O = 200/350/200 *** JOB IN PROGRESS *** 4/8/2023 T/I/O=300/400/200 Assist Eline TFS Unit#3 Pumped 184 BBLS crude down TBG to Assist Eline. 4/8/2023 *** CONTINUED FROM 4/7/23 *** INITIAL T/I/O = 200/400/200 CONTINUING OPERATION FROM YESTERDAY WITH PUMP ASSIST DISPATCHED FOR 9:00 AM. PUMP ARRIVES AT 14:12. RU AND PUMP DOWN PKR AT 3 BPM. 184 BBL PUMP DOWN. CORRELATE AND APPROVE. GOOD INDICATION OF SETTING MID ELEMENT AT 12,074 FT. 1788/1590 LB TENSION.SLACKED 15 FT ON PKR. POOH. WELL SI ON DEPARTURE, DSO NOTIFIED. FINAL T/I/O = 0/400/200 *** ELINE COMPLETE *** 4/15/2023 ***WELL S/I ON ARRIVAL*** RAN 3.70" LIB TO LOWER ANCHOR @ 12,078 MD RAN 18.81' NSAK SNAP LATCH & SNAP LATCH RECEPTACLE S/D @ 12,078' MD (18.81' OAL) RAN HES DPU W/ NSAK SNAP LATCH & NSAK MONO-PAK LTP S/D @ 12,033' MD (19.0' OAL) ***CONTINUE 4/16/23*** 4/16/2023 ***CONTINUE FROM 4/15/23*** RIG DOWN POLLARD 59 ***WELL TURNED OVER TO PAD OP*** Daily Report of Well Operations PBU J-08A GOOD INDICATION OF SETTING MID ELEMENT AT 12,074 FT. The liner patch is shown correctly in the new WBS, below. -WCB @ RAN 18.81' NSAK SNAP LATCH & SNAP LATCH RECEPTACLE S/D @ 12,078' MD (18.81' OAL) RAN HES DPU W/ NSAK SNAP LATCH & NSAK MONO-PAK LTP S/D @ 12,033' () MD 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU J-08A Pull Liner Patch Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 208-120 50-029-20265-01-00 12294 Conductor Surface Intermediate Production Liner 9111 80 2662 3449 11462 1477 12126 20" x 30" 13-3/8" 9-5/8" 7" 4-1/2" 9039 30 - 110 29 - 2691 28 - 3477 27 - 11489 10817 - 12294 30 - 110 29 - 2691 28 - 3473 27 - 8658 8158 - 9111 Unknown 2670 4760 5410 7500 12126 4930 6870 7240 8430 12043 - 12123 4-1/2" 12.6# 13Cr80 25 - 10826 9003 - 9038 Structural 4-1/2" Baker S3 Packer 10707 8076 Stan Golis Sr. Area Operations Manager Josh Stephens Josh.Stephens@hilcorp.com 907.777.8420 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 0028281 25 - 8165 N/A N/A 345 Well Not Online 38343 4208 1942 350 1025 80 N/A 13b. Pools active after work:PRUDHOE OIL No SSSV Installed 10707, 8076 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 ct to the best of my kno March 14, 2023 By Samantha Carlisle at 1:48 pm, Mar 14, 2023 RBDMS JSB 031423 Sundry Number Pull Liner Patch 208-120 N/A DSR-3/14/23 PRUDHOE BAY, PRUDHOE OIL PBU J-08A WCB 11-27-2023 ACTIVITY DATE SUMMARY 2/2/2023 ***WELL S/I ON ARRIVAL*** RIG UP POLLARD 59 RIG DOWN DUE TO LRS CTU NEEDING ROOM FOR HES ***WELL LEFT S/I*** 2/10/2023 FL = 250. Temp - SI. Asist Well Testers with FP FL on J-08. Pumped 9 bbls 60/40 and 40 bbls Crude. Pressured FL to 1500 psi. Tags hung. Pad operator notified upon departure. FL - 1500 psi 2/13/2023 ***WELL S/I ON ARRIVAL*** DRIFT W/ 20' X 3.70" DUMMY WHIPSTOCK, S/D @ 11,992' SLM RUN SBHP'S 10 MINUTE SURFACE STOP 15 MINUTE STOP @ 11,971' MD 15 MINUTE STOP @ 11,794' MD 15 MINUTE STOP @ 11,640' MD 10 MINUTE SURFACE STOP ***CONTINUE 2/14/23*** 2/14/2023 ***CONTINUE FROM 2/13/23*** TAG 45 KB STRADDLE PATCH W/ 3.50" LIB @ 12,036' MD (lib shows 4-1/2" FN) JAR ON 45 KB PATCH @ 12,036' MD PUMP 184 BBLS CRUDE W/ LRS JAR ON PATCH @ 12/036' MD PATCH CAME FREE, HANGING UP @ 10,807' SLM ***CONTINUE 2/15/23*** 2/14/2023 T/I/O=1980/380/210 Assist Slickline Pump 183 bbls crude to load tbg FWHPs=154/362/198 2/15/2023 ***CONTINUE FROM 2/14/23*** JAR ON 45 KB PATCH @ 10,807' SLM PULLED UPPER 45 KB SECTION (missing 2 slips & 3 elements) RAN 4 1/2" BLB & 3.50" WIRE GRAB S/D @ 12,042' SLM (recovered 3 chunks of element) RAN 4 1/2" BLB & 3.50" WIRE GRAB S/D @ 12,042' SLM (no recovery) RAN 3.68" CENT, 3.50" MAGNET S/D @ 12,042' SLM (recovered small metal piece) ***CONTINUE 2/16/23*** 2/16/2023 ***CONTINUE FROM 2/15/23*** RAN 3.68" CENT. KJ, 3.50" MAGNET S/D @ 12,042' SLM (recovered small metal piece) MAKE 1 MORE MAGNET RUN W/ NO RECOVERY PULLED MIDDLE PATCH SECTION FROM 12,045' SLM (fishing neck/ snap latch receptacle from lower packer is still attached to bottom, corroded off 1' down) RAN 3.5" WIRE GRAB TO 12,061' SLM NO RECOVERY PLANTED SLICK CATCH SPEAR IN LOWER PACKER @ 12,061' SLM PULLED SPEAR FREE W/ 5 JAR LICKS. RAN 3.50" LIB TO 12,061' SLM; SHOWED TOP OF FISH, AND IMPRESSION OF SLIP. RAN 3.50" BAR-BELL & 2.70" MAGNET TO 12,053' SLM. NO RECOVERY. ***WSR CONTINUED ON 2-17-23*** Daily Report of Well Operations PBU J-08A RAN 3.68" CENT. KJ, 3.50" MAGNET S/D @ 12,042' SLM (recovered small metal piece)) MAKE 1 MORE MAGNET RUN W / NO RECOVERY PULLED MIDDLE PATCH SECTION FROM 12,045' SLM (fishing neck/ snap latch(g receptacle from lower packer is still attached to bottom, corroded off 1' down) TAG 45 KB STRADDLE PATCH W / 3.50" LIB @ 12,036' MD JAR ON PATCH @ 12/036' MD@ PATCH CAME FREE, HANGING UP @ 10,807' SLM RAN 4 1/2" BLB & 3.50" WIRE GRAB S/D @ 12,042' SLM (no recovery)@(y) RAN 3.68" CENT, 3.50" MAGNET S/D @ 12,042' SLM (recovered small metal piece) JAR ON 45 KB PATCH @ 10,807' SLM@ PULLED UPPER 45 KB SECTION (missing 2 slips & 3 elements) DRIFT W / 20' X 3.70" DUMMY WHIPSTOCK, S/D @ 11,992' SLM RAN 4 1/2" BLB & 3.50" WIRE GRAB S/D @ 12,042' SLM (recovered 3 chunks of (g) element)) Daily Report of Well Operations PBU J-08A 2/17/2023 ***WSR CONTINUED FROM 2-16-23*** RAN 3.48" DE-CENT, AND 3.50" LIB TO 12,057' SLM; LIB SHOWS CLEAN FISH (NO SIGN OF SLIP). RAN 3.50" BAR-BELL, 5' x 1.25" STEM, AND 2.12" SWAGE; DRIFTED SWAGE THROGH PACKER TO 12,066' SLM. PLANTED SLICK CATCH SPEAR & PULLED PACKER FROM 12,060' SLM, LEFT IT IN THE XN NIPPLE @ 10,814' PULLED PACKER FROM XN NIPPLE, FOUGHT THROUGH EVERY NIPPLE & MANDREL. ***MISSING 1 ELEMENT. RAN 4 1/2" BRUSH, AND 3 PRONGED WIRE GRAB TO 12,117' SLM. RECOVERED 1 MISSING ELEMENT. RAN 4 1/2" BRUSH, AND 3 PRONGED WIRE GRAB TO 12,121' SLM. NO RECOVERY. 2/18/2023 ***WSR CONTINUED FROM 2-17-23*** 2.70" MAGNET RUN TO TD @ 12,120' SLM (no recovery, slips aren't ferrous) RAN 20' x 3.70" DUMMY WHIPSTOCK TO TD @ 12,114' SLM RAN HALLIBURTON 40 ARM CALIPER FROM 12,120' SLM TO SURFACE (good data) ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED OF STATUS*** PLANTED SLICK CATCH SPEAR & PULLED PACKER FROM 12,060' SLM, LEFT IT IN THE XN NIPPLE @ 10,814'@ PULLED PACKER FROM XN NIPPLE, FOUGHT THROUGH EVERY NIPPLE & MANDREL. ***MISSING 1 ELEMENT. @(y RAN 20' x 3.70" DUMMY WHIPSTOCK TO TD @ 12,114' SLM@ RAN HALLIBURTON 40 ARM CALIPER FROM 12,120' SLM TO SURFACE (good data) The new WBS, below, correctly shows no patch in the tubing and also shows the fish left behind. -WCB Image Pro~ct Well History File Cov~age 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. p~ (~' ~ - ~ ~ (,,,~ Well History File Identifier Organizing (done) RE AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: ,~wa~ niimiiiuiiuiii o ae,~a~~~~a uiumi0uiiiiu DIGITAL DATA OVERSIZED (Scannable) ^ Di ettes, No. ^ Maps: Other, No/Type: Ci ~ ~O ~ ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY: Maria Date: ~ ` /s/ ~ t Proofin II I II IIII II III I I III Pro~ec g , n n 6Y; Maria Date: /s/ r Y V tion x 30 = ~ ~ + ~ =TOTAL PAGES~~ Scanning Prepara _~ (Count does not include cover sheet) gY; Maria Date: ~ Q /s/ IIIIIIIIIIIIII IIIII Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover heet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: 3 a ~ d /s/ ~n l 'rti Stage 1 If NO in stage 1, pages} discrepancies were found: YES NO BY: Maria Date: /s/ I to at this Dint unless rescanning is required. II I II'I II I II II I I III Scanning is comp e p Rescanned III 111111 IIIII II III BY: Maria Date: /s/ ments about this file: Quality Checked III II IIII III II I~ II Com 10/6/2005 Well History File Cover Page.doc < A OIL AND GAS CONSERVATION ON COMMISSION e ,' REPORT OF SUNDRY WELL OPERATIONS OCT 16 20 i, 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other] f'� Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development el Exploratory ❑ 208-120-0 3.Address: P.O.Box 196612 Stratigraphic Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20265-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028281 PBU J-08A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): RST/Borax PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12294 feet Plugs measured 12126 feet true vertical 9111.28 feet Junk measured None feet Effective Depth measured 12126 feet Packer measured See Attachment feet true vertical 9039.1 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 29-109 29-109 Surface 2663 13-3/8"72#N-80 28-2691 28-2690.94 4930 2670 Intermediate None None None None None None Production 3449 9-5/8"47#N-80 28-3477 28-3473.33 6870 4760 Liner 1477 4-1/2"12.6#13Cr80 10817-12294 8158.16-9111.28 8430 7500 Perforation depth Measured depth 12043-12068 feet 12113-12123 feet 12150-12160 feet True Vertical depth 9002.71-9013.85 feet 9033.52-9037.82 feet 9049.39-9053.68 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 25-10826 25-8164.83 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1002 52498 1889 0 1269 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil Q Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGO 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature Phone 564-4424 Date 10/16/2013 1 /:- sd(02/(, RBDMS OCT 17 1 / /I /13 Form 10-404 Revised 10/2012 Submit Original Only • • Packers and SSV's Attachment ADL0028281 SW Name Type MD TVD Depscription J-08A PACKER 10707 8007.65 4-1/2" Baker S-3 Perm Packer J-08A PACKER 10828 8097.5 5" Baker ZXP Top Packer J-08A PACKER 12036 8930.75 4-1/2" Baker Flo-Guard Packer J-08A PACKER 12071 8946.37 4-1/2" Baker Flo-Guard Packer • 40 c o Cl) 1 ° x > w d 0 o CD 5 as � v) 00 � 'q N w � mao O 0 � N H W 0 cno) 0 OZ 0 76 - c w 0 w J o2 � o -00 UH < CO W W Q'N o W 0 O W rt Y LL J Ln bD = � 0 � 0 N2Ow } N * oO m QcQC70 W ci2 © a . � rn - oxoo - ma a0 I o O � � om ° � XJXp � cJi� C� - 0 0 (6 Q — 0c) � r d LOW L C -000 � H .-- HJ 0 0 O X I CO � QmO HWv= � mW J � U 0 I �- � � < JMMOO (n o73C� w < HZ 0 H `n H � o � W 0 > ocm -- m � WO ctWc = W M LL o CO > m Q Z O rn H J W 0 CO Cl CC M2 � O & F- CUJO R a) O : (1-11 3 Z �QW m ZW co J � W cZ OW — U �O W _2 0 0 Uc U ? .c Z W u Q 0 O-JZ CC Lv2 - * ooHCC OOzw - � J � O N U) 0 Qa`-ornrn � �m1o � m � UZ—U' m � Q oU *� U ° - z m w LOH OW - - com , W H W < W - F- _ 0YM (nW wLn0 0 � � w � 0 cu � � � C�O �* 2 � o � W W � � * � Jo OUQ' aoH c7 `_ 0 � c- U) Q CL-J J J H O O M QU N Z O W N- U r 0 J c oM 1-11-1 is) "U) U) U) NU) u_ rx W `j HU) = U) JO E 4, -...;, c).- d UHU) ii w ON t 0 � F- H oN * NCI'- p NmOZNzd � `LHN H ww00JZ = ct d 0 < QLLLL 2 * M � OM +L OD � W O � H H W * � � OOdpHO W I_ 0* 0 0 U) I ° H @©o'v o d * o W z O O O ' ° °�° oo 2 >< o U x o LHi o0 Jm [p 00 U) - OQM Lt� OZOJOOC7OHU) z ONE >,0HOmmN z >' > YY o - m *k = NO < ZOLUzw0 N LOUD -, O W L° O° Cw � � WaFct22 � NO (n (nUU) > o0E -� wop0 C) "4- r 0 m ] J � OuOa< 22 2 c_ J J J = \ 0 OO o >, = (nw ° JN 0 oo C� J0 > mZ0 : � ° � O ° v z cr) Q2z � � 0D , z oz , a 9 [t2 � � � 00O . F- Z 3jZmbb rnOz mmWZWW rnZx ° WLZ (n rn OJ_ 0mm m _17) — = 2H W O �II Oc0JJHomOH0 Z _ W W w2 < O 3wli Mm-1>" = WZ wW "" JJJ0 M 47-103 :1--- ` 1-L ":; LI W n © O O 5 J J O O J W W < LL W LL = � M _, Z oH Q _,ZZ -- 000HJJF- H -- H = fJf09 = 0O * Q Q o < * * w O O W w O * * Zw w O O o : CC CC oCOO- : U) W dU) U) d : : O FU) d : H a P * CC 0N0U) 003 M co M co co O O O o O N N N N N M O N- N. co m rn rn a Daily Report of Well Operations ADL0028281 Job continued from 9-7-13 WSR Pump down tubing with 44 bbls 1% KCL for load and base logging pass. Pump 3 bbls meth, 120 bbls 100*f Borax, 3 bbls meth tail. Pump 362 bbls 1% KCL for logging passes and flush. Freeze protect tubing with 40 bbls crude. FWHP 0/927/130/0 SLB on well at 9/8/2013 departure. ***JOB CONTINUED FROM 8/SEP/13*** (ELINE SET LOWER PACKER) INITIAL T/I/0/00 = 0/900/220/180 SET BKR 45 FLO-GUARD 9 CHROME LOWER STRADDLE PACKER. SETTING DEPTH (ME) = 12073' CCL TO MID ELEMENT= 15' CCL STOP DEPTH = 12058'. OAL=7.09', OD=3.70", MIN ID=2.45"TOP OF LWR PKR=12071'. LOG CORRELATED TO SLB CEMENT BOND LOG DATED • 20-SEP-2008. WELL SI AND HANDED OVER TO DSO UPON DEPARTURE FINAL T/I/O/OO = 0/900/220/180 9/9/2013 ***JOB COMPLETE*** ***WELL S/I ON ARRIVAL*** (profile modification) RIG UP SWCP 4520 DRIFT TBG W/3.68" CENT., 3.50" LIB TO BKR LWR PKR ASSY.AT 12059' SLM/12071' MD 9/16/2013 ***CONT WSR ON 9/17/13 *** T/I/O=0/1220/210/150 temp=S/I Assist SSL set patch. Pumped 5 bbls meth followed by 100 bbls 180*f crude down tubing. Pumped an additional 76 bbls of 90*f crude down tubing per S-line 9/17/2013 assisting them in getting DH. Final WHP's 0/915/229 SSL on well at departure ***CONT WSR FROM 9/16/13 *** (profile modification) DRIFT TBG W/3.805" G. RING TO 6200' SLM SET BKR PUP JOINT W/SNAP LATCH(OAL=16.5', MAX O.D.= 3.70" MIN I.D. = 2.36")AT 12060' SLM • DRIFT TBG W/3.70" DUMMY WHIPSTOCK TO 12047' SLM (multiple tight spots, see log) LANDED UPPER PATCH W/45 KB BKR PACKER (OAL=19.5', MAX O.D.= 3.70" MIN I.D. = 2.37") INTO SNAP LATCH AT 12051' SLM AND SET, TOP OF KB 45 PATCH ASSY @ 12,036'MD 9/17/2013 ***CONT WSR FROM 9/18/13 *** ***CONT WSR FROM 9/17/13 ***(profile modification) RIG DOWN SWCP 4520 9/18/2013 _***WELL LEFT SHUT IN ON DEPARTURE, PAD OP NOTIFIED *** TREE= CM/ • ' WE.LHEAD= MC B/OY S MOTES: ***CHROME TBG&LBW** ACTUATOR= BAKER J -08A 0RIG KB.ELEV 69.41' ORIG BF.BE 40.13' ORIG KOP= 3477' - -- 2041' 9-5/8"FOC Nix Angie= 65°Q 1212T Datum MD= 11794' I I ' I 2216' H4-1/2"l.ES X Ni?ID=3.813" I DatumTVD= 8800'SS . --I 2060' H9-5/8"HOWL O DV COLLAR I GAS LFT MANDRELS 13-3/8"CSG,72#,NE80,D=12.347' H 2691' ■ ST MD WD DEV TYPE VLV LATCH PORT DATE 4 3391 3388 9 KBG2 DONE BK 16 06/19/13 1 9-5/8"CSG,47#,N-80,ID=8.681" H 3477' 3 6094 5298 59 KBG2 SO BK 20 06/19/13 \ I 2 8222 6411 60 KBG2 DMY BK 0 09/24/08 1 10599 7996 42 IBG2 OW BK 0 09/24/08 Minimum ID =2.36" @ 12036' x BKR 45 KB STRADDLE PATCH 9-518'CSG Nl1OUT IMNDOW(J-08A) 347T-3494' 7"CSG,26#,L-80,TC1,D=6.276" � 4403' 0 0 1 7004' H7'HES ES CEMENTER I ' I 10676' I--14-1/2"I ES X PS'D=3.813" S X I 1070T Hr x 4-1/2"BKR S-3 PKR,D=3.87" I I 10741' 14-1/2"I-ES X NP,D=3.813" I I 10814' H4-1/2"IES XN NIP ID=3.725" I I 10817' I—T x 5"BKR C2 ZXP LT PKR w/11.46' 4-1/2"TBG,12.6#,13CR-80, —I 10826' TI3ACK&I-INC MI HGR,D=4.46" - VAM.0152 bpf,D=3.958" 10826' H4-1/2"MEG I 1--l______IELM3 TTNOTLCGGED T CSG,26#,L-80,BTC-M,D=6.276" —I 11489' I A ■ �— 12036' 4-1/2'BKR KB 45 STRADDLE PATCH D=2.36"(09/17/13) PERFORATION SUMMARY RERTE IN LOG:IBS EWR/DGRIROP 09/08/08 ANGLE AT TOP PERF:64° t 12113' Z Note:Refer to Production DB for historical pert data SIZE SPF MB VAL Opn/Sqz SHOT SQZ 3-3/8" 6 12043-12068 C 10/13/08 3-3/8" 6 12113-12123 0 09/08/13 r I 12126' II4-1/2"PES EZSV(09/21/08) I 3-3/8' 6 12130-12180 S 09/25/08 110■11 I I PBTD I-- 12208' .•••4•S•S• I4-1,2"LNR,12.6#,13CR-80,HY D,.0152bpf,D=3.958' H 12294' .4.1.4.4.4.1 DATE F€/BY CONSENTS DATE REV BY CONSENTS PRtDHOEBAY UNIT 09/77 ORIGINAL COMPLETION 06/25/11 WBY PJC GLV CJO(06/23/11) WB_L: J 08A 01/22/91 N1 ES RWO 11/19/12 MB/PJC PERFORATION CORRECTION FERMT No: 2081200 09/25/08 NOES SIDETRACK(J-08A) 09/13/13 RWINJND ADFUFS/SET LWR PK R(09/08 4 AR No: 50-029-20265-01 10/16/08 DTRIPJC GLV CJO(10/10/08) 09/20/13 SWC/JNU SET BKR PATCH(09/17/13) SEC 9,TI 1 N,R13E,804'F EL&1148 FN. 10/17/08 RRLYPJC PERFS(10/13/08) 11/10/09 F RJSV DRLG DRAFT F IAL BP Exploratlon(Alaska) DATA SUBMITTAL COMPLIANCE REPORT 2/22/2010 Permit to Drill 2081200 Well Name/No. PRUDHOE BAY UNIT J-08A Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20265-01-00 MD 12294 TVD 9111 Completion Date 10/13/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surve Yes / DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES / AZI-DENS / NEU, SC 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/trmt moer Name acme mea~a no start slop i.n rcecervea ~.ommenzs - ~ED~ C Exc Directional Survey 0 12294 Open 10/8/2008 iftpt Directional Survey 0 12294 Open 10/8/2008 rog Induction/Resistivity 25 Col 3477 12294 Open 11!3/2008 MD, ROP, EWR, DGR, ALD, CTN 17-Sep-2008 og Induction/Resistivity 25 Col 3477 12294 Open 11/3/2008 TVD, ROP, EWR, DGR, ALD, CTN 17-Sep-2008 ~~ D C ~ Pds 17125/Induction/Resistivity 3477 12294 Open 11/3/2008 PDS, EMF and CGM graphics for EWR logs Log Cement Evaluation 5 Col 3286 12220 Case 11/7/2008 CBL, CCL, GR, Pres, Temp SCMT 20-Sep-2008 ED C Pds 17159~Cement Evaluation 3286 12220 Case 11/7/2008 CBL, CCL, GR, Pres, - -- _ Temp SCMT 20-Sep-2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments •I ~I DATA SUBMITTAL COMPLIANCE REPORT 2/22/2010 Permit to Drill 2081200 Well Name/No. PRUDHOE BAY UNIT J-O8A MD 12294 TVD 9111 ADDITIONAL INFORMATION ?,, Well Cored? Y JrPI~ Chips Received? -~f-hTd~-+ Analysis ,F-~N-- Received? Operator BP EXPLORATION (ALASKIy INC Completion Status 1-OIL Current Status 1-OIL Daily History Received? ~ N Formation Tops QyN API No. 50-029-20265-01-00 UIC N Completion Date 10/13/2008 Comments: ~ , ~, ~~ ~ d ,,~ ~ ,' ~~ ~) ~ ~c ~ ~ , ~ L c S ~ x+45 ~ ~.~~ ~.~~e~ ~ ~ /`c, ~ ~ ~ l ~ Compliance Reviewed By: ___ `~"'~% ___ ----- -_- ---- Date: ~~-~~`~ 1 • • STATE OF ALASKA `~ ALAS IL AND GAS CONSERVATION COMMIS~N REPORT OF SUNDRY WELL OPERATIONS -'~~'X~- ~ ~i~'~9 ~Uir_ ~ ~. ?C~(1~? 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other V Performed: Alter Casing ~ Pull Tubing Perforate New Pool Waiver Ti~~ '~ Ur ' ,.,. ~a y~ ~ Y~~Ita+~~i~~2 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: De~lopment ~ Exploratory ~~` 2os-o12o 3. Address: P.O. Box 196612 StratlgraphlC r Service L" 6. API Number: Anchorage, AK 99519-6612 50-029-20458-02-00 7. KB Elevation (ft): 9. Well Name and Number: 64.56 KB PBU 06-146 8. Property Designation: 10. Field/Pool(s): ADLO-028311 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12331 feet Plugs (measured) None true vertical 8817.2 feet Junk (measured) None Effective Depth measured 12242 feet true vertical 8837.99 feet Casing Length Size MD TVD Burst Collapse Conductor 110 20"# H-40 Surface - 110 Surface - 110 1490 470 Surface 2685 13-3/8" 72# N-80 Surface - 2685 Surface - 2685 4930 2670 Production 4982 9-5/8" 47# L-80 Surface - 4982 Surface - 4896 6870 4760 Liner 10725 7" 26# L-80 Surface - 10725 Surface - 8685 7240 5410 Liner 1765 4-1/2" 12.6# L-80 10565 - 12330 8577 - 8817 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR SURFACE - 10580' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR S3 PKR 10504' 0 0 0 0 0 p 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: 290 578 5342 347 Subsequent to operation: SI 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 r 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 Prebl ~ -r Title Data Management Engineer Signature ~ Phone 564-4944 Date 7/23/2009 Form 10-404 R ised 04/2006 F Submit Original Only ~ ~ ate"' y"'i,~ ~' r`~~ 06-14B 209-012 PERF OTTOC:HMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 06-14B 4/2/09 PER 11,102. 11,140. 8,907.82 8,920.88 06-146 4/2/09 PER 11,170. 11,190. 8,931.99 8,940.35 06-14B 4/2/09 PER 11,480. 11,790. 8,974.48 8,912.66 06-14B 4/2/09 PER 11,960. 12,020. 8,882.81 8,876.54 06-14B 7/12/09 APF 10,990. 11,010. 8,855.36 8,865.65 06-14B 7/15/09 APF 10,970. 10,990. 8,844.67 8,855.36 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 06-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 7/11/20Q9 "'*WELL SHUT IN ON ARRIVAL*** (ADPERF) ' 'INITIAL T/I/O 1400/1500/0.*"" RIH WITH TS: HEAD/ERS/ PGGT/ 20 FT 3.3/8" PJ HSD 3406 GUN, 20 FT LOADED, 6 SPF. UNABLE TO GET PAST 10813 FT. '***JOB CONTINUED ON 12-JULY-2009.*" ~ 7/11 /2009F T/I/O/00 = 1500/1500/VAC/130. connected, open @ casing valve. I bbl). SV, WV=Shut. SSV, MV=Open. Temp = SI. TBG FL (E-line call in). AL ALP = 1500 psi. TBG FL @ 5580' (85 IA&OA=OTG. NOVP. 7/12/2009 T/I/0= 1300/1500/0 Temp= SI Assist E-line pump as directed- Arrive on location, Sign in with SLB, Spot equipment, Standby for transport, ***WSR `Continued to 07-13-09"*'' 7/12/2009 """JOB CONTINUED FROM 11-JULY-2009.''** UNABLE TO GET DOWN WITH INITIAL TOOLSTRING. PU `107 86 FT. NEEDED TO PULL 2600 LBS TO FREE TS. POOH. RIH WITH 'TS: HEAD/ ERS/ 2-2.13 IN WB/ UPCT/ BNS FOR JEWELRY LOG. LOG JEWELRY LOG. RUN IN HOLE WITH 3 3/8" DRIFT RUN. TAG UP AT 11050'. TAKE SIGNIFICANT OVERPULLS FROM 11050' TO 10500'. AGREE TO RUN 2 7/8" GUNS INSTEAD OF 3 3/8"GUNS. GUN RUN #1: PERFORATE FROM_ 10.990'-11010' WITH 2 7/8" POWERJET CHARGES, 6 ;SPF, 60 DEGREE PHASING. jTOOLS HUNG UP ACROSS GLM #3 AT 8084 FT ON WAY OUT OF HOLE. 3STANDBY FOR LRS TO PUMP HOT DIESEL ***JOB CONTINUED ON 13-JULY-2009."** 7/13/2009 ""*WELL S/I ON ARRIVAL*"" MADE SEVERAL ATTEMPTS TO RETRIEVE PERF GUN PLUG (UNABLE TO RETRIEVE) ANDRELS W/ DOUBLE KNUCKLE 4.5" BLB & 2.81" G-RING RAN 3.70" CENT. & 3 3/8" DUMMY PERF GUN TO 11,065' SLM (UNABLE TO WORK DEEPER) "**CONT. WSR ON 07/14/09*"* ~~ r 7/13/2009 """JOB CONTINUED FROM 12-JULY-2009."*" (ADPERF) SOOL STUCK AT 8052 FT CCL DEPTH. PULLED FREE AT 2350 LBS. POOH. MISSING SMALL PIECE OF FIRING HEAD, APPROX 2"OD AND 4 M ~~TL.JI!`v RUN 3 3/8" DUMMY GUN TO GLM #3 AT 8084'. TAGGED UP. HAD TO STROKE JARS TO PULL FREE. ***WELL SHUT IN ON DEPARTURE*"* FLUIDS PUMPED BBLS 6 NEAT 167 diesel 173 Total """"JOB COMPLETED""" SUN FOR THE TIME BEING. 7/13/2009*"*WSR Continued from 07-12-09**" Temp= SI Assist E-line. (Adperf) ~ Pumped 2 bbls neat methanol spear followed with 140 bbls 180"F diesel ,followed with 21 bbls 50*F diesel and capped with 4 bbls neat methanol down tbg. Released from jobsite. Final WHP's=200/1780/0/100. Valves positions _ at departure: Swab, Wind, SSVclosed. Master, IA, OA & OOA= open. 7/14/2009 *"*CONT WSR FROM 07%13/09*** R/D & SECURE WELL **"LEFT WELL S/I NOTIFY_DSO"*" ~._ _ _~ 009 **"WELL SHUT IN ON ARRIVAL"**~ PERFORATED INTERVAL FROM 10970FT TO 10990FT. USED 2 7/8" HSD GUN WITH 2409 POWERJET HMX CHARGES. API DATA: PENETRATION DEPTH: 25.3" ENTRANCE HOLE: 0.38" 1 1/2 HOUR DELAY WAITING ON SUPPORT EQUIPMENT 2 HOUR DELAY WAITING ON HIGH WINDS. ****JOB COMPLETED"** Page 1 of 1 Maunder, Thomas E (DOA) From: Hubble, Terrie L [Ten'ie.Hubble~bp.com] Sent: Monday, November 10, 2008 3:38 PM To: Maunder, Thomas E (DOA); Roach, Frank Cc: Hobbs, Greg S (ANC) Subject: RE: J-08A (208-120) Hi Tom, I have discussed this with Frank and 1 did report the incorrect volume of cement for the 4-1/2" Liner. The initial amount of cement that was pumped for the 4-1/2" Liner was 294 cu ft. But, since the logging did not show cement around the pipe, the squeeze job cement amount is what should probably be noted on the Completion Report. That amount was 43 bbls (241 cu ft). I will ink that change to our copies. Apologies for the error and thanks for your help. Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.govJ Sent: Monday, November 10, 2008 10:11 AM To: Roach, Frank Cc: Hobbs, Greg S (ANC); Hubble, Terrie L Subject: J-08A (208-120) Frank, I am reviewing the completion report for this well and have a couple of questions. Several "issues" were encountered on this well ... 1. The volume given on the 407 for the 4-1/2" liner doesn't' agree with the volume pumped in the squeeze. The volume given on the 407 is 294 ft"3 or 52.3 bbls. The volume given in the operations summary (9/22) is 43 bbls. Would you please indicate the correct volume? Thanks in advance, Tom Maunder, PE AOGCC 11/10/2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION os i~ ~I ~ ~ Z008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG . r`f~fls ~:f3tl~T°IsslBlflfl 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Com letions One 1 b. Well Class: `'' ~"~"''` ®Development ^ Exploratory ^ Service ^ Strati ra hic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aba d 10/13/2008 ~ 12. Permit to Drill Number 208-120 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/30/2008' 13. API Number 50-029-20265-01-00 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 9/17/2008 ' 14. Well Name and Number: PBU J-08A 1148' FNL, 804' FEL, SEC. 09, 711 N, R13E, UM Top of Productive Horizon: 4523' FSL, 1709' FWL, SEC. 03, 711 N, R13E, UM g. KB (ft above MSL): 68.81' Ground (ft MSL): 40.31' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4777' FSL, 1824' FWL, SEC. 03, 711 N, R13E, UM 9. Plug Back Depth (MD+TVD) 12126' 9039' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 643556 y- 5970205 Zone- ASP4 10. Total Depth (MD+TVD) 12294' ~ 9111' 16. Property Designation: ADL 028281 TPI: x- 645948 y- 5975924 Zone- ASP4 5976180 Zone- ASP4 646057 T l D th t 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y- : x- o a ep 18. Directional Survey ®Yes ^ No r 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): MWD DIR / GR / PWD, MWD DIR / GR / RES / AZI-DENS / NEU, SCMT, GR / CCL ~3~~~%yd ~~~3.3TY/> 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH ND HOB AMOUNT Wi. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED P ~~ - / " 4 # 7 ' -1 /4" 1439 cu ft Howco Light, 250 a ft'G, 110 cu ft PF'C' 11 -1/ " i _ - ~ _ 23. Open to production or inject ion? ®Yes ^ No 24. TuBlric coRD If Yes, list each i & B P MD TVD f T nterval open mb r Si d N f ti S~ DEPTH SEr MD PACIa=R SET MD ): er ora on ze an u e ottom; ( + o op f 3-3/8" Gun Diameter 6 s 4-1/2", 12.6#, 13Cr80 10826' 10707 , p MD TVD MD TVD 12043' - 12068' 9003' -9014' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MO AMOUNT Si KIND OF MATERIAL USED 3477' Pump 55 Bbls Class 'G' cement for Kick Off 12150' -12160' Perf for Remedial Cement'ob on 4-1/2" Liner 12126' Set EZSV, Pum 43 Bbls Class'G' throw h perfs Freeze Protected with 75 Bbls Diesel 26. PRODUCTION TEST Date First Production: October 18, 2008 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test: 10/19/2008 Hours Tested: 6 PRODUCTION FOR TEST PERIOD OIL-BBL: 366 GAS-MCF: 240 WATER-BBL: 421 CHOIR SIZE: 96 GAS-OIL RATIO: 654 Flow Tubing Press. 200 Casing Press: 1,040 CALCULATED 24-HouRRAT>=• OIL-BBL: 1,464 GAS-MCF: g58 WATER-BBL: 1,684 OIL GRAVnY-API (CORK): 31 27. CORE DATA Conventional Core(s) A wired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals coned (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 /~- Ar. . Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE l ~~atix~~~~ D f - ~` r~~; .. ~~oa G r~ ~1 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS ANO MAR RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Ugnu 4 4166' 4093' None Ugnu 3 4399' 4299' Ugnu 1 5213' 4838' WS 2 6226' 5365' WS 1 6618' 5567' CM3 6975' 5757' THRZ 9371' 7080' BHRZ 9629' 7273' Sag River 11492' 8661' Shublik 11544' 8699' Sadlerochit 11652' 8777' Zone 3 /Top CGL 11890' 8925' Zone 2 /Base CGL 11984' 8975' 25N /Zone 2B `, ~ , ' Formation at Total Depth (Name): Jo?~.G6~ ~ ~O~ 25N /Zone 2B ~'~ '~5' 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. / ~ f0 y~ ! ~ v~ Signed Terrie Hubb Title Drilling Technologist Date PBU J-08A 208-120 Prepared ey NameMumber. Te-rie Hubble, 564-4628 Well Number P A od--i~ E~ineer: Frank Roach, 564-4373 IN3TRUCTIONs GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-ARemating-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. Iran 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITaur 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 should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEIN 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. Iran 29: Provide a listing of intervals tested and the conesponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: J-08 Common Name: J-08 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 8/30/2008 LOT 3,485.0 (ft) 3,481.0 (ft) 9.20 (ppg) 700 (psi) 2,364 (psi) 13.07 (ppg) 9/14/2008 FIT 11,514.0 (ft) 8,677.0 (ft) 8.40 (ppg) 950 (psi) 4,736 (psi) 10.51 (ppg) Printed: 10/6/2008 2:14:53 PM BP EXPLORATION Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To Hours Task Code NPT ~ 8/22/2008 00:00 - 15:00 15.00 MOB P 15:00 - 00:00 9.00 MOB P 8/23/2008 00:00 - 06:00 6.00 MOB P 06:00 - 23:30 I 17.50 I MOB I P 23:30 - 00:00 8/24/2008 00:00 - 04:00 04:00 - 08:00 08:00 - 10:30 0.50 MOB P 4.00 RIGU P 4.00 RIGU P 2.50 RIGU P 10:30 - 12:00 1.501 RIGU I P Start: 8/21 /2008 Rig Release: 9/25/2008 Rig Number: 2ES Page 1 of 15 ~ Spud Date: 8/23/1977 End: Phase Description of Operations PRE Moving sub base from Drill Site 2 to J-Pad. PRE Wheels sunk through on Spine Road just west of Frontier Corner. Got moving again temporarily at approximately 19:30, but quickly became stuck again. At 22:00, started putting rig mats down. *NOTE: SLB wireline currently rigged up on DS 02-40 to pull DCK valve for freeze protect. PRE Place rig mats. Wheels on mats and moving ahead at 02:00. Approx 1.2 miles to J Pad. PRE Continue moving rig on mats. Mats being shuttled around rig via GC-1 to GC-2 pipeline access road. PRE Rig on location at 23:30. PRE PJSM. Line up sub. Set herculite. Raise derrick and install A-leg pins. Spot rig over well. PRE PJSM. Rig up floor. Bridle down. Rig up topdrive. PRE PJSM. Spot camp, shop, and pits. Continue with operations to complete Pre-Spud checklist. PRE PJSM. Spot Little Red truck and RU to perform MIT-OA. *Rig Accepted at 12:00 hrs. 12:00 - 13:30 1.50 WHSUR P DECOMP Perform MIT-OA to 2000 psi. LRS pumped 3 bbls dead crude down OA. Good test; bled off 100 psi in first 15 minutes and 40 psi in second 15 minutes. Begin taking on 2% KCI to pits at 12:00. 13:30 - 15:30 2.00 WHSUR P DECOMP PJSM. RU kill line to IA. Test surface equipment to 3500 psi. Perform MIT-IA to 3500 psi. Good test; bled off 10 psi in first 15 minutes and 0 psi in second 15 minutes. 15:30 - 17:30 2.00 WHSUR P DECOMP RU DSM lubricator and test to 500 psi. Pull BPV. LD lubricator. 17:30 - 20:30 3.00 KILL P DECOMP PJSM. RU to circulate out freeze protect. Reverse circulate diesel from tubing with 2% KCI. Switch hoses to pump down tubing and circulate diesel out of IA. 5 bpm, 550 psi. Blow down and rig down circulation lines. 20:30 - 21:30 1.00 W HSUR P DECOMP Set TWC. Test from above and below to 1000 psi for 5 minutes. Good tests. 21:30 - 00:00 2.50 WHSUR P DECOMP PJSM. ND tree and adapter flange. Could not break seal between adapter flange and spool. Apply steam to adapter flange and attempt to pull again; no success. 8/25/2008 00:00 - 02:30 2.50 WHSUR P DECOMP Continue applying steam to adapter flange; try several times to pull flange and tree. 02:30 - 04:00 1.50 WHSUR P DECOMP RU DSM flange spreader and attempt to break flange; no success. Reapply steam. 04:00 - 06:00 2.00 WHSUR P DECOMP Attempt to pull flange and tree with both bridge cranes; no success. Reapply steam. 06:00 - 09:00 3.00 WHSUR P DECOMP PJSM. Stand back tree. Clean groove and apply lubricant to inner profile. Reinstall tree. Install long bolts in bottom flange to control kinetic energy of tree and flange when pulled free. Have Cameron pump hydraulic oil into ports in adapter flange to lubricate seals. Attempt to pull adapter flange, rocking tree with both bridge cranes. No success. 09:00 - 12:00 3.00 WHSUR P DECOMP PJSM. RU to circulate cold water through tubing spool annulus ports, taking returns to pil pit. Circulate water while working Printetl: 10/6/2008 2:14:59 PM • BP EXPLORATION Operations Summary Report Page 2 of 15 Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: ,Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code ~ NPT Phase ~ Description of Operations 8/25/2008 09:00 - 12:00 3.00 WHSUR P DECOMP tree; pulled free after pumping 10 bbls. RD. 12:00 - 13:00 1.00 WHSUR P DECOMP Remove tree and adapter flange from cellar. 13:00 - 16:00 3.00 BOPSU P DECOMP NU BOPE. 16:00 - 21:00 5.00 BOPSU P DECOMP Test ROPE. -Test Upper 3.5" x 6" VBRs to 250 psi low / 3500 psi high with 4.5" test joint. -Test Annular Preventer to 250 psi low / 2500 psi high with 4.5" test joint. -Test Choke manifold, Koomey, and all BOPE related valves. -Will test lower pipe rams after LD tubing. -Test witnessed by WSLs Dick Maskell, Joey LeBlanc, and Adrienne McVey. Witness waived by Jeff Jones of AOGCC. 21:00 - 22:00 1.00 BOPSU P DECOMP LD 4.5" test joint. Blow down choke manifold, top drive, and surface equipment. Suck out stack. 22:00 - 00:00 2.00 WHSUR P DECOMP RU DSM lubricator and extension. Test lubricator; good test. Pull TWC. LD lubricator. 8/26/2008 00:00 - 02:00 2.00 PULL P DECOMP Attempt to Change out wash pipe in top drive. No success 02:00 - 11:30 9.50 PULL P DECOMP PJSM. RU to pull tubing hanger. Back out lock down screws. Pick up landing joint. Recover tubing hanger. Tubing came free with 80K pickup weight. LD landing joint. RU to spool control lines. Pull tubing from cut at -3665'. Recovered 1 SSSV, 91 full joints, 1 cut at 19.17', 27 clamps and 4 SS bands. 11:30 - 14:30 3.00 BOPSU P DECOMP PJSM. Test upper and lower rams with 4" and 5" test joints. Test dart and TIW valves. Test rams to 250 psi low, 3500 psi high. Test annular with 4" test joint, low 250 psi, high 2,500 psi. Test witnessed by WSL's Dick Maskell and Joey LeBlanc and Toolpusher Cleve Coyne. 14:30 - 15:00 0.50 BOPSU P DECOMP Run in wear ring with ID of 8.75". 15:00 - 20:00 5.00 CLEAN N RREP DECOMP Change out swivel packing on top drive. Install new washpipe packing. 20:00 - 22:00 2.00 CLEAN P DECOMP PJSM. PU/MU casing scraper & mill assembly to 310'. 22:00 - 00:00 2.00 CLEAN P DECOMP PJSM. PU 5" drill pipe to 2860'. Up weight 100k, down 97k. 8/27/2008 00:00 - 01:00 1.00 CLEAN P DECOMP PJSM. PU 5" drill pipe to 3649'. Make up top drive. Run in and tag tubing stub at 3673'. 01:00 - 02:30 1.50 CLEAN P DECOMP Circulate hi-vis sweep surface to surface at 540 gpm with 830 psi. Pump dry job. 02:30 - 03:30 1.00 CLEAN P DECOMP POOH to 310'. 03:30 - 05:30 2.00 CLEAN P DECOMP PJSM. Lay down scraper assembly. 05:30 - 07:30 2.00 DHB P DECOMP PJSM. Rig up E-line unit for EZSV set and GR/CCL log to surface. Pick up EZSV and run in hole. Set EZSV at 3500' ELM. 07:30 - 10:00 2.50 EVAL P DECOMP Log up with GR/CCL from 3500' to surface. 10:00 - 11:00 1.00 DHB P DECOMP PJSM. Attempt to test EZSV to 3500 psi -pressure held but volume to pressure up indicated test was against P&A cement plug, not EZSV. 11:00 - 15:30 4.50 WHSUR P DECOMP PJSM. PU 5" drill pipe and RIH. Tag up on EZSV at 3498' DPM. Stacked 25k to verify set. Pull 2 stands and attempt to test EZSV again with no success. 15:30 - 17:30 2.00 WHSUR P DECOMP PJSM. Cut and slip 93' of drilling line. Service rig, drawworks and top drive. Grease crown. 17:30 - 18:30 1.00 WHSUR P DECOMP PJSM. PU RTTS. Set below wellhead. Test to 3000 psi - OK. 18:30 - 19:00 0.50 WHSUR P DECOMP Pull wear ring. 19:00 - 20:30 1.50 WHSUR P DECOMP PJSM. ND stack. LD mouse hole. Remove riser and rnniea: iwoizuua c iy:oy rm BP EXPLORATION Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date !From - To Hours Task Code ~ NPT 8/27/2008 19:00 - 20:30 1.50 WHSUR P 20:30 - 00:00 3.50 WHSUR P 8/28/2008 00:00 - 02:30 2.50 BOPSU P 02:30 - 03:00 0.50 BOPSU P 03:00 - 03:30 0.50 BOPSU P 03:30 - 04:00 0.50 DHB P 04:00 - 05:30 1.50 DHB P 05:30 - 08:00 2.50 STWHIP P 08:00 - 08:30 0.50 STWHIP P 08:30 - 10:00 1.50 STWHIP N 10:00 - 13:30 3.50 STWHIP P 13:30 - 14:30 1.00 STWHIP P 14:30 - 15:30 1.00 STWHIP P 15:30 - 21:00 5.50 STWHIP P 21:00 - 21:30 I 0.501 STWHIPI P 21:30 - 22:00 0.50 STW H I P P 22:00 - 23:00 1.00 STWHIP P 23:00 - 00:00 I 1.001 STWHIPI P 18/29/2008 00:00 - 01:30 1.50 STWHIP P 01:30 - 04:30 3.00 STWHIP P 04:30 - 06:00 I 1.501 STWHIPI P 3482' begin loosing fluid at 75 bph. Pumping at 460 gpm with 925 psi. WOB 2-8k. Rotate at 80-90 rpm with 1-6k torque. Adding LCM to system. Losses slowing to 5 bph. Mill ahead to 3506' with bottom of window at 3494'. Up weight 120k, down 122k, RT 122k. WEXIT Circulate hi-vis sweep surface to surface at 460 gpm with 925 psi. Recirocate pipe to bottom with sweep at bit. Pull up into window. Circulate out sweep. Shut down. WEXIT Attempt to perform LOT. Fluid pumping into formation with no WEXIT WEXIT WEXIT WEXIT WEXIT 06:00 - 08:00 2.00 STWHIP N DPRB WEXIT 08:00 - 10:00 2.00 STWHIP N DPRB WEXIT Continue to mill window to 3516' MD. Work window several times with pump on and off. Window appears in good shape. Circulate hole clean with super sweep. Shut down and monitor well -static. Pump dry job. PJSM. POOH to milling assembly at 911'. PJSM. Stand back HWDP. Lay down drill collars and milling assembly. Clear and clean floor. Pull wear ring. Make up JW flushing tool. Flush stack. Function test rams. Suck out stack and blow down manual valves. Run in wear ring. PJSM. PU and RIH with mule shoe on 5" drill pipe to 3516' MD Circulate BU at 450 gpm with 325 psi. Up and down weight 98k. 10:00 - 13:00 3.00 STWHIP N DPRB WEXIT PJSM. Rig up SCH and cementing equipment. Rig up cement head and pressure test lines to 3000 psi. Pump 14 bbls water. Follow with 50 bbls, 15.8 ppg lead cement at 5 bpm with 320 Pump 5 bbls water. Switch to rig and displace with 40.8 bbls of 9.2 ppg LSND mud at 5 bpm with 115 psi. Pull up out of cement slowly. Pull 10 stands. Drop wiper ball and circulate surface to surface. Close Hydril and squeeze cement to formation, pressuring up Start: 8/21 /2008 Rig Release: 9/25/2008 Rig Number: 2ES Page 3 of 15 ~ Spud Date: 8/23/1977 End: Phase I Description of Operations DECOMP turnbuckles. ND casing spool and remove from cellar. DECOMP Install new 9-5/8" primary packoff and casing/tubing spool with secondary packoff. Test packoff and void to 3500 psi for 30 minutes - OK. Install secondary annulus valve. DECOMP PJSM. NU stack. Install riser and mouse hole. DECOMP RI wear ring with ID of 8.75". DECOMP PJSM. Test stack to 3500 psi for 10 minutes - OK. DECOMP PU RTTS running tool. Pull RTTS lay down. DECOMP POOH. WEXIT PJSM. Pick whipstock tools up beaver slide. MU milling BHA to 911'. Orient and shallow test. Up and down weight 75k. WEXIT Service rig. RREP WEXIT Change out swivel packing and washpipe packing. WEXIT PU drill pipe to 2611'. Up weight 105k, down 110k. WEXIT Run in to 3460'. Orient to 65 degrees RHS. Tag plug at 3498'. Set anchor with 20k down. Pick up 10k overpull to confirm anchor set. Set down 45k and shear off from slide. WEXIT Displace well with 9.2 ppg LSND. WEXIT Begin milling operations with top of window at 3477'. Mill to . PrintBtl: lU/(i/LUUtl G:14:5y YM ~ ~ BP EXPLORATION Page 4 of 15 Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date 'From - To Hours ' Task Code I NPT I Phase ~ Description of Operations 8/29/2008 10:00 - 13:00 3.00 STWHIP N DPRB WEXIT slowly. 200 strokes - 760 psi 250 strokes - 810 psi 300 strokes - 950 psi 350 strokes - 1125 psi 400 strokes - 1005 psi Shut down pump for 5 minutes with pressure dropping to 275 psi. Start pumping again at 1/2 bpm. 480 strokes - 960 psi 550 strokes - 1120 psi 600 strokes - 1275 psi 688 strokes - 1450 psi Shut down pumps. Wait 5 minutes, pressure dropped to 1220 psi. Wait 10 minutes, pressure dropped to 1100 psi. Wait 15 minutes, pressure dropped to 1015 psi. Squeezed away a total of 40 bbls. 13:00 - 13:30 0.50 STWHIP N DPRB WEXIT Circulate BU at 550 gpm with 250 psi. Rotate at 30 rpm. 13:30 - 15:00 1.50 STWHIP N DPRB WEXIT POOH. Lay down mule shoe. 15:00 - 19:00 4.00 STWHIP N DPRB WEXIT Perform rig maintenance and general house keeping while waiting on cement compressive strength. 19:00 - 22:00 3.00 STWHIP N DPRB WEXIT PJSM. PU 8-1/2" drilling assembly to 812'. Shallow test MWD at 450 gpm with 680 psi. 22:00 - 23:30 1.50 STWHIP N DPRB WEXIT RIH to 3079'. Make up top drive and establish circulation at 580 gpm with 1400 psi, Rotate at 80 rpm. Record baseline parameter of 10.0 ppg clean hole ECD. Continue to run in hole and tai preen cement and stringers at 3409'. 23:30 - 00:00 0.50 STWHIP N DPRB WEXIT Wash down to 3430 and to cement. Drill u soft cement to 3447'. Pull up and circulate. 8/30/2008 00:00 - 04:00 4.00 STWHIP N DPRB WEXIT Wait on cement compressive strength. 04:00 - 06:00 2.00 STWHIP N DPRB WEXIT Drill ahead through cement and through top of window at 3477'. ~ Unable to slide through end of window, hanging up. Rotate through at 30 rpm - OK. Pick up above window. Slide through with no problem. Drill new formation to 3536' MD. Pump at 450 gpm with 1000 psi. Rotate at 40 rpm with 1.5k torque. WOB 5-8k. Mud weight in and out 9.2 ppg. Up weight 117k, down weight 115k, RT 115k. 06:00 - 06:30 0.50 DRILL N DPRB INT1 Drill new formation to 3536' MD. Same parameters. 06:30 - 07:00 0.50 DRILL N DPRB INT1 Circulate bottoms up at 450 gpm with 1200 psi. Rotate at 40 rpm. 07:00 - 08:00 1.00 DRILL N DPRB INT1 Pull one stand up into window. Perform LOT to 13.0 ppg EMW with 700 psi. Pick up stand and orient t rou h window. 08:00 - 00:00 16.00 DRILL P INTi Directional drill ahead to 4667' MD, 4519' TVD. Pump at 525 gpm with 1420 psi off bottom, 1600 psi on bottom. Rotate at 50-80 rpm with 4-5k torque on and off bottom. WOB 5-18k. Up weight 137k, down 120k, RT 130k. Pump sweeps as needed. First sweep brought back 35% increase in cuttings. Subsequent sweeps had minimal results. AST - 5.92, ART - 3.3. Mud weight in and out 9.2 ppg. ECD 9.99 ppg. 8/31/2008 00:00 - 08:00 8.00 DRILL P INT1 PJSM. Directional drill ahead to 5060' MD, 4761' TVD. Pump at 530 gpm with 1425 psi off bottom, 1650 psi on bottom. Rotate at 80 rpm with 5k torque off bottom, 6k torque on bottom. WOB 10-20k. Mud weight in and out 9.2 ppg. Up weight 145k, down rnntea: iuio¢uvo z:ia:oarm BP EXPLORATION Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date i From - To Hours Task Code NPT Start: 8/21 /2008 Rig Release: 9/25/2008 Rig Number: 2ES Page 5 of 15 Spud Date: 8/23/1977 End: Phase Description of Operations 18/31/2008 00:00 - 08:00 8.00 DRILL P INT1 08:00 - 09:00 1.00 DRILL P INT1 09:00 - 11:00 2.00 DRILL P INT1 11:00 - 12:00 1.00 DRILL P INTi 12:00 - 13:30 1.50 DRILL P INT1 13:30 - 16:30 3.00 DRILL P INT1 16:30 - 18:30 2.00 DRILL P INT1 18:30 - 21:00 2.50 DRILL P INT1 21:00 - 22:30 1.50 DRILL P INT1 22:30 - 23:00 0.50 DRILL P INTi 23:00 - 00:00 1.00 DRILL P INT1 9/1/2008 00:00 - 00:30 0.50 DRILL P INT1 00:30 - 00:00 23.50 DRILL P INT1 9/2/2008 00:00 - 00:00 24.00 DRILL P INT1 9/3/2008 00:00 - 03:30 3.50 DRILL P INTi 03:30 - 04:30 ~ 1.00 ~ DRILL ~ P ~ ~ INTi 04:30 - 08:30 4.00 DRILL P INT1 08:30 - 10:30 2.00 DRILL P INT1 10:30 - 13:30 3.00 DRILL P INTi 13:30 - 14:30 1.00 DRILL P INT1 123k, RT 130k. ECD 10.0. AST - 3.73, ART - 1.59. Pump hi-vis sweep surface to surface at 510 gpm with 1430 psi. Mud weight in and out 9.2 ppg. Monitor well -static. PJSM. POOH to 3350'. No problems. Perform MAD pass from 3519' to 3243' at 300 fph. Pull in record mode with no pumps or rotation. Continue to POOH to 812'. POOH with drilling BHA. Break and LD bit. Dowload MWD. MU Bit. Set motor to 1.22 degree bend and RIH to 812'. PJSM. Pick up 23 joints of 4" DP, ghost reamer and 55 joints of 4" DP. RIH to 3912'. Shoot surveys every tool joint from 3912' to 4130' to check for magnetic interference. Continue RIH to 4650'. Wash and ream to 4960'. Hanging up at dog legs and one small packoff at 4860'. Hole cleaned up each time. PJSM. Wash and ream to 5060', pumping at 530 gpm with 1600 psi. Directional drill ahead to 6083' MD. Pump at 536 gpm with 1900 psi off bottom, 2070 psi on bottom. Rotate at 100 rpm with 6k torque off bottom, 8-9k torque on bottom. WOB 5-10k. Up weight 155k, down 115k, RT 125k. Mud weight in 9.2 ppg, out 9.2+ ppg. Continue to drill ahead to 7308' MD, 5937' TVD. Pump at 541 gpm with 1900 psi off bottom, 2150 psi on bottom. Rotate at 115 rpm with 9k torque off bottom, 9-11 k torque on bottom. WOB 5-20k. Up weight 180k, down 125k, RT 145k. Mud weight out 9.4 ppg, in 9.2 ppg. ECD 10.0. AST - 2.95, ART - 10.62. Directional drill ahead to 8066' MD. Pump at 541 gpm with 2080 psi off bottom, 2250 psi on bottom. Rotate at 115 rpm with 9-11 k torque off bottom, 10-12k torque on bottom. WOB 5-10k. Up weight 193k, down 130k, RT 150k. Mud weight in 9.2+ ppg, out 9.3+ ppg. Continue to drill ahead to 8764' MD, 6689' TVD. Pump at 541 gpm with 2250 psi off bottom, 2450 psi on bottom. Rotate at 115 rom with 10-13k torque off bottom, 12-14k on bottom. WOB 5-15k. Up weight 210k, down 133k, RT 157k. ECD 10.31. Mud weight in and out 9.2 ppg. AST - 4.95, ART - 10.79. PJSM. Directional drill ahead to 9010' MD, 6827' TVD. Pump at 541 gpm with 2280 psi off bottom, 2560 psi on bottom. Rotate at 110 rpm with 10-13k torque off bottom, 11-13k torque on bottom. WOB 5-10k. Up weight 212k, down 130k, RT 157k. Mud weight in 9.2+ ppg, out 9.3 ppg. ECD 10.36. Pump sweep surface to surface at 541 gpm with 2280 psi. Mud weight 9.2+ ppg in and out. PJSM. POOH to window for wiper trip. No problems. PJSM. Cut and slip 115' of drilling line. Service top drive and drawworks. Run in hole to 8915'. Fill pipe at 5330' and 7214'. No problems. Circulate bottoms up at 525 gpm with 2100 psi. Dump 200 bbls mud for spike weight up. Nnnted: ioiwzuue ri4:sy rnn BP EXPLORATION Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date I From - To Hours Task Code NPT 9/3/2008 114:30 - 00:00 I 9.501 DRILL I P Start: 8/21 /2008 I Rig Release: 9/25/2008 Rig Number: 2ES Page 6 of 15 ~ Spud Date: 8/23/1977 End: Phase Description of Operations INTi Begin drilling and start adding 14.0 ppg spike fluid to weight system up to 10.6 ppg. Drill ahead to 9579' MD, 7237' TVD. Well starting to breath at 9050' MD. Pumoina away 25 to 30 9/4/2008 100:00 - 09:00 9.001 DRILL P INT1 09:00 - 13:30 ~ 4.50 ~ DRILL ~ N ~ RREP ~ INT1 13:30 - 22:00 8.501 DRILL ~ N ~ RREP ~ INT1 22:00 - 00:00 ~ 2.00 ~ DRILL ~ N ~ RREP ~ INT1 9/5/2008 100:00 - 01:30 1.501 DRILL ~ N ~ RREP ~ INT1 01:30 - 02:30 1.001 DRILL N RREP INT1 02:30 - 04:00 1.50 DRILL N RREP INT1 04:00 - 10:00 6.00 DRILL N RREP INT1 10:00 - 12:30 2.50 ~ DRILL ~ N (RREP ~ INT1 12:30 - 13:30 1.00 DRILL N RREP INT1 13:30 - 00:00 10.50 DRILL P INTi 19/6/2008 100:00 - 06:30 6.50 ~ DRILL ~ P ~ i INT1 Pump at 525 gpm with 2600 psi off bottom, 2750 psi on bottom. Rotate at 110 rpm with 10-12k torque off bottom, 12-14k torque on bottom. WOB 5-15k. Up weight 215k, down 143k, RT 157k. Mud weight in and out 10.6 ppg. AST - 4.71, ART - 3.93. ECD 11.41. Calculated ECD 11.08. PJSM. Directional drill ahead to 10173' MD, 7677' TVD. Pump at 519 gpm with 2760 psi off bottom, 3120 psi on bottom. Rotate at 110 rpm with 12-13k torque off bottom, 13-15k torque on bottom. WOB 5-15k. Up weight 223k, down 145k, RT 174k. Mud weight in and out 10.6 ppg. ECD 11.49. Calculated ECD 11.08. AST - 1.34, ART - 4.5. POOH to 3343' inside 9-5/8" window due to mud line washout. Ten gallon leak into secondary containment inside pump room. Repair washout in 4" mudline. Cut out bad section and replace with new 90" elbow and straight section. Modify for easy access. RIH to 6931'. Up weight 165k, down 115k. Filling pipe and breaking circulation every 20 stands. Correct displacement going in hole. No breathing. PJSM. RIH to 10063'. Filling pipe every 15 stands and breaking circulation. Correct displacement going in. Hook up top drive and wash last stand down. Hole taking fluid while washing down. Noticed hydraulic leak in service loop hose. Attempt to circulate bottoms up. ECD to high. Pumping away fluid. Attempt to adjust pump rate with no success. Shut down and prepare to pull to top of HRZ for top drive repairs. Pum ed away 107 bbls. Well breathing back. POOH to 9000'. Replace hydraulic service loop hose. After breathing back total mud lost was 51 bbls. (Got back 56 bbls) At 05:30 moved pipe, everything free and clear. Periodically move pipe and break circulation during repairs. Establish circulation at 80 gpm. Stage pumps up gradually adjusting as needed according to losses encountered and for ECD management. Continue staging pumps up to 525 gpm with 2500 psi until hole clean. RIH to 10053'. Make up top drive. Circulate and ream down last stand at 522 gpm with 2750 psi. No problems. Up weight 230k, down 145k, RT 174k. Directional drill ahead to 10871' MD, 8199' TVD. Pump at 519 gpm with 2873 psi off bottom, 3180 psi on bottom. Rotate at 110 rpm with 13-14k torque off bottom, 15-17k torque on bottom. WOB 5-15k. Up weight 245k, down 150k, RT 185k. Mud weight in and out 10.6 ppg. Calculated ECD 11.09, actual 11.57. AST - 2.00, ART - 4.96. PJSM. Directional drill ahead to 11200' MD. Pump at 519 gpm with 2980 psi off bottom, 3200 psi on bottom. Rotate at 100 rpm with 15-17k torque off bottom, 16-17k torque on bottom. WOB 5-15k. Up weight 245k, down 160k, RT 190k. Mud weight Nrintea: tuitiieuutt L:ia:oa rnn BP EXPLORATION Page 7 of 15 Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date I From - To I Hours I Task I Code I NPT I Phase Description of Operations 9/6/2008 00:00 - 06:30 6.50 DRILL P INT1 in 10.6 ppg, out 10.7 ppg. Calculated ECD 11.09, actual 11.53. 06:30 - 07:30 1.00 DRILL P INT1 PJSM. Change out swab on #1 pump. 07:30 - 13:00 5.50 DRILL P INT1 Drill ahead to 11486' MD. Pump at 524 gpm with 3100 psi off bottom, 3250 psi on bottom. Rotate at 100 rpm with 15-17k torque off bottom, 17-18k torque on bottom. WOB 5-20k. Up weight 275k, down 155k, RT 190k. Mud weight in 10.6 ppg, out 10.7 ppg. Calculated ECD 11.09, ECD 11.52. AST - 1.9, ART - 5.9. 13:00 - 15:30 2.50 DRILL P INT1 Circulate up samples. Drill 3 more feet. Circulate up samples again. Call intermediate TD of 11489' MD, 8658' TVD as per Geolo ist in the Sa transitional phase. Mud weight in 10.6 ppg, out 10.6+ ppg. 15:30 - 17:00 1.50 DRILL P INT1 POOH to 9000' with no problems. 17:00 - 18:00 1.00 DRILL P INTi RIH to 11407'. 18:00 - 21:00 3.00 DRILL P INT1 Break circulation at 400 gpm with 2200 psi. Wash down to 11489'. Pump hi-vis sweep at 525 gpm with 3080 psi. Rotate and reciprocate at 100 rpm. Work ECD down to 11.27 with a calculated ECD of 11.09. Mud weight in and out 10.6+ ppg. 21:00 - 00:00 3.00 DRILL P INT1 POOH to top of HRZ at 9200'. Pump dry job and continue POOH. No problems. Hole appears in good shape. 9/7/2008 00:00 - 01:30 1.50 DRILL P INT1 PJSM. POOH to 3315'. 01:30 - 03:00 1.50 DRILL N RREP INT1 Replace hydraulic line on Iron Roughneck. 03:00 - 05:00 2.00 DRILL P INT1 POOH to 814'. 05:00 - 09:30 4.50 DRILL P INT1 PJSM. Break out and lay down BHA. Clear and clean floor. 09:30 - 10:00 0.50 BOPSU P INT1 Install wear ring. Run in test plug. 10:00 - 11:30 1.50 BOPSU P INT1 PJSM. Pull to 3-1/2" x 6" variable rams and re lace with 7" rams. 11:30 - 12:00 0.50 BOPSU P INT1 Test 7" rams with 7" test joint to 250 psi low, 3500 psi high as per AOGCC. Test witnessed by WSL Bill Decker and Toolpusher Charlie Henley. 12:00 - 12:30 0.50 BOPSU P INT1 Rig down test equipment and pull test plug. 12:30 - 15:00 2.50 CASE P INTi PJSM. Rig up casing running equipment. 15:00 - 00:00 9.00 CASE P INT1 Make up shoe track and RIH. Make up Frank's Tool, fill and check floats - OK. Run 7", 26#, L-80, BTC-M casing as per running order. Fill every joint then circulate down every 15th joint. Circulated 1.5 times the annular volume at the 9-5/8 window at a rate of 5 bpm, staging up slowly. Continued to run in open hole filling every joint and circulating every 10th joint at 4 bpm. 9/8/2008 00:00 - 05:00 5.00 CASE P INT1 PJSM. Run 7", 26#, L-80, BTC-M/TCII casing as per running order. Fill every joint. Circulate down every 10th joint at 4 bpm over 3 minutes. Average torque on BTC-M 8600 ft/Ibs.-,Start to ush mud awa at 6577', while running in and during circulations. 05:00 - 06:00 1.00 CASE P INT1 Stage pumps up to 157 gpm with pressure dropping from 630 psi to 560 psi over one annular volume. Lost 101 bbls during circulation. Hole breathing back after shut down. 06:00 - 15:30 9.50 CASE P INT1 Continue to run in casing. Cross over to TCII. Use torque turn on TCII with average torque of 10,000 ft/Ibs. Circulate joints 233-239 pumping at 4 bpm running in at 7 minutes per joint with 724 psi. Up weight 260k, down 125k. 15:30 - 23:30 8.00 CASE P INTi Starting taking weight at joint 273, 10,075', up weight 325k, wn on roue o wor own to joint 289 which had an f'nnted: tuitiizuut3 e:tn:5a rnn BP EXPLORATION Page 8 of 15 ..Operations. Summary Report Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21 /2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To '~ Hours Task ~ Code NPT Phase Description of Operations __ 9/8/2008 15:30 - 23:30 8.00 CASE P ~ INT1 up weight of 425k, down weight of 60k. Continued to work 23:30 - 00:00 ~ 0.50 ~ CEMT ~ P 19/9/2008 100:00 - 07:30 ~ 7.501 CEMT ~ P 07:30 - 10:00 I 2.501 CEMT I P 10:00 - 10:30 0.501 CEMT P down 'oints 290-292 and u 'oints to bottom: Make up XO and cement head. INT1 Stage pumps up to 1 bpm and increase to 2 bpm at 1/2 bbl increments. Pressure up to 2235 psi -packed off. Work pipe up_ to 380k and breakover. Bleed off pressure and work pipe. Pi a breakin over at 280k. Mark i e. Brin ressure u to, 2300 si a ain and attem t to work i e. No returns. -NT1 Attempted to work pipe and establish circulation with no success. Pressure up in stages, 2300, 2500, 2700 and 3000 psi. ES Cementer opened partially dropping pressure from 3000 to 1500 psi in 5 minutes. Attempt to pressure up and open ES Cementer fully with 3700 psi without success. Drop ES Cementer opening plug and open ES Cementer with 1000_ INT1 INTi 10:30 - 12:00 1.50 CEMT P INT1 12:00 - 13:00 1.00 CEMT P INTi 13:00 - 14:00 1.00 CEMT P INT1 14:00 - 17:00 3.00 CEMT P INT1 17:00 - 00:00 I 7.001 CEMT I P 19/10/2008 00:00 - 12:00 12.00 CEMT P 12:00 - 00:00 12.00 CEMT P INT1 INT1 INT1 circulation. Continue to work pipe. PJSM. RU to pump 2nd stage cement job. Test SLB lines to 4000 psi with 5 bbls MudPush. Pump 25 bbls MudPush, 83 bbls 11.0 ppg LiteCRETE. Drop ES cementer closing plug. Wash up behind plug with 5 bbls water. Switch to rig pumps and displace with 267 bbls. Bump plug and pressure up to 2000 psi. Bleed off pressure; floats held. 63% returns. CIP at 09:30. Wellbore breathing. Close annular preventer and pump down backside to confirm annulus injectivity. Pressure up to 780 psi to establish injectivity; inject at 1 bpm, 750 psi. Pumped 6 bbls; got 2 bbls back when bled off pressure. Inject 2 bbls at 1 bpm, 850 psi; wellbore breathing when bleed off pressure. Pressure up to 890 psi to establish injectivity; pump 3 bbls at 1 bpm, 830 psi. Close annulus valve and monitor for 1 hour; annular pressure 490 psi. Bleed off pressure. Pumping 1 bbl down backside every hour. Pressures to reach breakover/injection pressures are as follows: 14:00 hrs - 910 psi/850 psi 15:00 hrs - 750 psi/710 psi 16:00 hrs - 720 psi/670 psi Well breathing; monitor returns. Rates are as follows: 17:00 hrs - 25 bph 18:00 hrs - 21 bph 19:00 hrs - 15 bph 20:00 hrs - 11 bph 21:00 hrs - 4 bph 22:00 hrs - 3.5 bph 23:00 hrs - 2 bph 00:00 hrs - 2 bph Monitoring returns. Rates decreasing from 2.5 bph at 00:00 to 0.5 bph at 12:00. Monitoring returns. Rates continuing to decrease; less than 0.25 bph at 23:59. Nnntea: iwtiiluua ~:ia:oa rnn • + BP EXPLORATION Operations Summary Report Page 9 of 15 ~ Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To ,Hours Task .Code NPT Phase Description of Operations 9/11/2008 00:00 - 12:00 12.00 CEMT P INT1 Continue to monitor returns. Rate less than 0.25 bph. 12:00 - 17:30 5.50 CEMT P INT1 Montoring returns; slowed down to a trickle. Attempt to suck out BOP stack and found contaminated mud. RU Super Sucker and pump through OA valve to flow line to break up con amina a mu ush stack, function annular preventer and too rams. blow down choke and kill lines. RD Super Sucker. 17:30 - 00:00 6.50 CEMT P INT1 Monitoring returns at the wellhead. Still tnckung. 9/12/2008 00:00 - 13:00 13.00 CEMT P INT1 Continue monitoring returns at the wellhead. Still trickling. 13:00 - 15:00 2.00 CEMT P INT1 Returns stopped at 13:00 hrs. Continue monitoring annulus for flow for an additional 2 hours prior to ND BOPE. Well is static. 15:00 - 16:30 1.50 BOPSU P INTi PJSM. Split BOPE stack. Pull up 250K and set 7" emergency slips in existing tubing spool. Cut 7" casing with Wachs cutter. 16:30 - 19:30 3.00 WHSUR P INT1 PJSM. Install new tubing spool. NU BOPE. Test 7" packoff to 4300 psi for 30 minutes; good test. Install flow nipple. 19:30 - 21:30 2.00 BOPSU P INT1 Clean out BOP stack. 21:30 - 22:30 1.00 BOPSU P INT1 PJSM. Change out top rams from 7" to 3.5"x6" VBRs. 22:30 - 23:30 1.00 BOPSU P INT1 PJSM. Change out top drive saver sub from 5" to 4".Change out dies and stabbing guide. Adjust gripper. SIMOPS: PJSM. Little Red injecting 150 bbls of heated 9.2 ppg brine down OA to clear the annulus for freeze protect. Pumping at 3 bpm and 750 psi. 23:30 - 00:00 0.50 BOPSU P INT1 PJSM. RU to test BOPE. 9/13/2008 00:00 - 05:30 5.50 BOPSU P INT1 Test BOPE. -Test Pipe Rams to 250 psi low / 3500 psi high with 4" and 4.5" test joints. -Test Annular Preventer to 250 psi low / 2500 psi high with 4" test joint. -Test Choke manifold, Koomey, and all BOPE related valves. -Test witnessed by WSLs Adrienne McVey and Bill Decker, and Toolpusher Ken Helf. Witness waived by Jeff Jones of AOGCC. SIMOPS: At 00:20, after injecting 150 bbls of heated brine down OA, Little Red swa ed over to dead crude for freeze protect and pumped 65 bbls at 3 bpm, 800 psi. Pumping com leted at 00:45. 05:30 - 06:00 0.50 BOPSU P INT1 Pull test plug. LD test joint. 06:00 - 06:30 0.50 CEMT P INT1 Install mouse hole in rotary table for laying down 5" DP. 06:30 - 18:30 12.00 CEMT P INT1 LD 270 jts 5" DP. Transfer 26 stands 4" DP from Driller's Side to Off-Driller's Side. 18:30 - 19:30 1.00 CEMT P INT1 Remove mouse hole from rotary table. Clear rig floor. Change out handling equipment and heads in iron roughneck from 5" to 4". 19:30 - 20:00 0.50 CEMT P INT1 Install wear bushing. 20:00 - 21:30 1.50 CEMT P INTi PU 6-1/8" cleanout BHA to 465'. Break circulation at 225 gpm, 240 psi. 21:30 - 22:30 1.00 CEMT P INT1 Slip and cut drilling line. 22:30 - 23:00 0.50 CEMT P INT1 Service crown, drawworks, and top drive. 23:00 - 00:00 1.00 CEMT P INTi RIH, picking up DP from pipe shed, to 1120'. 9/14/2008 00:00 - 06:00 6.00 CEMT P INT1 RIH with 6-1/8" cleanout BHA, picking up 4" DP from pipeshed, to 6910'. Fill pipe and break circulation every 2000'. Wash down and tag ES cementer at 7004'. rnntea: tuitiizuuts zaa:oa rm BP EXPLORATION Page 10 of 15 Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT Phase ~'~ Description of Operations 9/14/2008 06:00 - 06:30 0.50 CEMT P INT1 PJSM. Test ES cementer to 1800 psi for 10 minutes; good test. 06:30 - 07:30 1.00 CEMT P INT1 Drill out ES cementer and chase down 30' to 7034'. Pumping at 230 GPM, 1000 PSI. 110 RPM, 25K WOB, Off/On-Bottom Torque 5K/6K ft-Ibs, Up Weight 125K, Down Weight 92K, Rotating Weight 105K. 07:30 - 11:00 3.50 CEMT P INT1 RIH from 7034' to 10279', picking up DP from pipeshed. Fill pipe and break circulation at 9000'. Wash down and tag baffle collar at 11402'. Attem t to test casin to 3500 si; no test. 11:00 - 12:00 1.00 CEMT P INT1 Drill out baffle collar and chase down 40' to top of float collar at 11444'. Attempt to test casing to 3500 psi; no test. 12:00 - 13:00 1.00 CEMT P INT1 Drill out float collar and chase down 40' to top of float shoe at 11486'. Attempt to test casing to 3500 psi; no test. 13:00 - 14:30 1.50 CEMT P INT1 Displace mud system to 8.4 ppg FloPro. 14:30 - 16:30 2.00 CEMT P INT1 Drill float shoe and 25' of new formation to 11514' MD/8677' T umpsng at 320 GPM, 1530 PSI. 80 RPM, 20K WOB, Off/On-Bottom Torque 4-6K/5-6K ft-Ibs, Up Weight 170K, Down Weight 130K, Rotating Weight 155K. ART=ADT=1.53 hrs. 16:30 - 18:00 1.50 CEMT P INT1 CBU at 535 GPM, 2800 PSI. Perform FIT to 10.5 EMW (8677' TVD, Mud Weight 8.4 ppg, 950 psi surface pressure). 18:00 - 22:00 4.00 CEMT P INT1 Monitor well or 10 minutes; well static. Mud Weight In=Mud Weight Out=8.4 ppg. PJSM. POH from 11514'to 371'. 22:00 - 23:00 1.00 CEMT P INT1 PJSM. LD 6-1/8" cleanout BHA from 371'. Stand back HWDP and jars. LD drill collars. Clear and clean rig floor. 23:00 - 00:00 1.00 CEMT P INT1 PU Champ-IV test packer and RIH on DP to 947'. 9/15/2008 00:00 - 06:00 6.00 CEMT P INTi RIH with Champ-IV test packer from 947' to 11390'. Set Cham -IV at 11390'. 06:00 - 07:00 1.00 CEMT P INT1 Pressure test 7" casin to 3500 si for 30 minutes. Record on chart. Good test; lost 100 psi in first 15 minutes and 20 si in second 15 minutes. 07:00 - 07:30 0.50 CEMT P INT1 Monitor well for 10 minutes; well static. Pump dry job. Install stripping rubbers and air slips. 07:30 - 11:30 4.00 CEMT P INT1 POH and LD Champ-IV test packer. 11:30 - 12:00 0.50 CEMT P INT1 Clear and clean rig floor. 12:00 - 13:00 1.00 CEMT P INT1 PJSM. Jack rig up to open cellar doors for survey crew (measuring for flowline). 13:00 - 16:30 3.50 DRILL P PROD1 PJSM. PU 6-1/8" drilling BHA to 400'. Upload and shallow test MWD, load radioactive :sources. 16:30 - 21:00 4.50 DRILL P PROD1 RIH from 400' to 11,514'. 21:00 - 00:00 3.00 DRILL P PRODi Drill 6-1/8" production interval to 11,540' MD/8671' TVD. 80 RPM, 10K WOB, Off/Ori-Bottom Torque 5K/5-9K ft-Ibs, Up Weight 180K, Down Weight 135K, Rotating Weight 155K. 300 GPM, Off/On Bottom Pressure 2160/2390 psi. ADT=0.75 hrs, ART=0.12 hrs. Mud Weiight In=Mud Weight Out=8.4 ppg. 9/16/2008 00:00 - 12:00 12.00 DRILL P PROD1 Drill 6-1/8" production interval to 11,804' MD/8874' TVD. -90 RPM, 2-10K WOB, Off/On-Bottom Torque 5-6K/6-7K ft-Ibs. -Up Weight 180K, Dowri Weight 130K, Rotating Weight 155K. -300 GPM, Off/On Bottcm Pressure 2350/2500 psi. -ADT=5.61 hrs, ART=1.77 hrs. -Mud Weight In=Mud Weight Out=8.4 ppg. -Calculated clean hole E:CD 9.71 ppg EMW, actual ECD 9.87. 12:00 - 00:00 12.00 DRILL P PROD1 Drill 6-1/8" production interval to 12,175' MD/9059' TVD. Printetl: l U/6/LOUt3 1:14:5y PM BP EXPLORATION Page 11 of 15 Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To ~ Hours ' Task.. Code NPT Phase ~ Description of Operations 9/16/2008 12:00 - 00:00 12.00 DRILL P PROD1 -80 RPM, 12-14K WOB, Off/On-Bottom Torque 6-7K/7-8K ft-Ibs. -Up Weight 185K, Down Weight 130K, Rotating Weight 155K. -300 GPM, Off/On Bottom Pressure 2330/2550 psi. -ADT=6.56 hrs, ART=3.41 hrs. -Mud Weight In=Mud Weight Out=8.5 ppg. 9/17/2008 00:00 - 03:30 3.50 DRILL P PROD1 Drill 6-1/8" roduction hole to TD at 12294' MD/9111' TVD. TD/_ called at 03:10. -80 RPM, 3-14K WOB, Off/On-Bottom Torque 6-7K/7-8K ft-Ibs. -Up Weight 185K, Down Weight 130K, Rotating Weight 155K. -300 GPM, Off/On Bottom Pressure 2400/2600 psi. -ADT=2.47 hrs, ART=1.61 hrs. -Mud Weight In=Mud Weight Out=8.5 ppg. 03:30 - 05:30 2.00 DRILL P PROD1 Pump hi-vis sweep surface to surface at 300 GPM, 2400 PSI. Rotating at 90 RPM. Monitor well for 10 minutes; well static. 05:30 - 09:30 4.00 DRILL P PROD1 MAD pass from 12294' to 11700'. 300 GPM, 35 RPM. Continue backreaming to 7" shoe at 11489'. No hole problems encountered. 09:30 - 11:00 1.50 DRILL P PROD1 Drop dart to open circ sub. Pump hi-vis sweep surface to surface. Monitor well for 10 minutes; well static. Pump dry job, remove blower hose, install stripping rubbers and air slips. 11:00 - 15:00 4.00 DRILL P PROD1 POH from 11489' to 400'. 15:00 - 18:30 3.50 DRILL P PROD1 LD BHA from 400'. Remove radioactive sources, download MWD. Clear and clean rig floor. 18:30 - 19:30 1.00 CASE P RUNPRD RU to run 4.5" liner. 19:30 - 23:30 4.00 CASE P RUNPRD Run 36 joints of 4.5" 12.6# L-80 Hydril 521 production liner to 1485'. -2 centralizers/jt with stop ring on joints #1-19 (open hole) -No centralizer on joint #20 (7" casing shoe) -1 centralizer~t on joints #21-35 (liner lap) -No centralizer on joint #36 Qoint below liner hanger) 23:30 - 00:00 0.50 CASE P RUNPRD Change out handling equipment. MU Baker Flex-Lock liner hanger, ZXP liner top packer, and C-2 running tool. RIH with 1 stand of drill pipe to 1617'. 9/18/2008 00:00 - 07:00 7.00 CASE P RUNPRD Run 4.5" liner from 1617' to 7" casing shoe at 11489'. 07:00 - 07:45 0.75 CASE P RUNPRD Break circ and increase rate up to 5 bpm to clear 1 liner and DP vol (150 bbls). 07:45 - 09:00 1.25 CASE P RUNPRD Go in to open hole and start pushing mud away„ Run to 11800' - still pushing some mud away. Break circulation and circ liner down to bottom at 3 bpm. Total losses were 8 bbls. Talc bottom and PU 1 foot. MU cement head and lines. 09:00 - 09:30 0.50 CEMT P RUNPRD Break circ and ease up to 5 bpm/1100 psi. Reciprocate pipe - OK. 09:30 - 09:45 0.25 CEMT P RUNPRD PJSM for cement job. Continue circ & reciprocate pipe. 09:45 - 10:30 0.75 CEMT P RUNPRD Batch mix spacer and cement. Continue circ and reciprocate - OK. No pressure anomalies observed. 10:30 - 10:45 0.25 CEMT P RUNPRD Pump 5 bbls 11.2 ppg Mudpush spacer. SD. Close lower TIW valve on head and test lines to 3900 psi. Pump 13 bbls additional Mudpush (all). 10:45 - 11:00 0.25 CEMT P RUNPRD Switch to cement. Pump 52.3 bbls (253 sx) Class G GasBlok slurry at 15.8 ppg. 5.2 bpm at 1400 psi start. 5 bpm at -1075 rnrnea: iuioizuuo c.iv:oa rm BP EXPLORATION Page 12 of 15 Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ From - To ~' Hours Task Code NPT Phase ~' Description of Operations 9/18/2008 10:45 - 11:00 0.25 CEMT P RUNPRD psi at end. 11:00 - 11:15 0.25 CEMT P RUNPRD Switch to rig and clear cement line and standpipe with 5 bbls pert pill. Remove cement line from head and install cap. Pump 50 bbls pert pill. Started getting mudpush to surface approx 600 stks (35 bbl) into displacement. 11:15 - 12:30 1.25 CEMT P RUNPRD Continue displacement. Saw dart latch up on liner wiper plug??? at 2795 stks - (55 bbls late). Continue displacement after discussion with Anch staff. Pumped 4000 stks (102 bbls over calculated displacement). Stop displacement after discussion with Anch office. 12:30 - 13:00 0.50 CEMT P RUNPRD Set liner on bottom and emergency release off liner hanger - OK. Did not set LTP or liner hanger. Circ cement up hole 2400 stks (140 bbls). LD cement head and 2 singles. 13:00 - 14:30 1.50 CEMT P RUNPRD Continue circ out cement at 13 bpm. Saw indication of cement at 5000 stks away. Fairly good cement from 5400 to 6400 stks (58 bbls) then tapering off to contaminated mud. Pump -6700 stks total and SD. Flush out BOP stack. 14:30 - 21:00 6.50 CEMT P RUNPRD POH looking for washout in 4" DP. Found washout in slip area of bottom single on stand #31 (2870' from surface) -hole approx 3/4" x 1/4". Continue POH with drillpipe. 21:00 - 00:00 3.00 BOPSU N DFAL RUNPRD Pull wear bushing. RU and test lower rams (2-7/8" x 5" VBRs) to 250 psi low/3500 psi high with 2-7/8" test joint. Test annular preventer to 250 low/2500 high. Good tests. Witnessed by WSL Adrienne McVey and Toolpusher Ken Helf. RD testing equipment. Reinstall wear bushing. 9/19/2008 00:00 - 01:30 1.50 CEMT N DFAL RUNPRD C/O handling equipment for 2-7/8" PAC pipe. 01:30 - 04:00 2.50 CEMT N DFAL RUNPRD PJSM. PU and RIH with 3-3/4" milli BHA and PAC pipe to 1536'. C/O handling equipment and RIH w/ 1 stand of 4" DP. 04:00 - 05:00 1.00 CEMT RUNPRD PJSM. Slip and cut drilling line. 05:00 - 06:00 1.00 CEMT RUNPRD PJSM. Service top drive and drawworks. 06:00 - 15:00 9.00 CEMT N DFAL RUNPRD RIH with 3-3/4" cleanout assembly to top of LTP at 10817'. Wash down to landin collar at 12207 and to u on liner wi a .- plug and pump down lu .NOTE: Encountered possible cement stringers at 11990'. 15:00 - 18:00 3.00 CEMT N DFAL RUNPRD Open circ sub Qust above LTP) and pump 2 hi-vis sweeps at 540 gpm, 2300 psi. Rotating at 60 rpm. POH from 12207' to 10789'. 18:00 - 18:30 0.50 CEMT N DFAL RUNPRD Test 4-1/2" liner and liner la to 3500 si~ no test. 18:30 - 23:00 4.50 CEMT N DFAL RUNPRD Pump dry job and POH from 10789' to 2940'. PJSM. LD 15 stands from 2940' to 1536'. 23:00 - 00:00 1.00 CEMT N DFAL RUNPRD C/O handling equipment and LD 2-7/8" PAC pipe from 1536' to 1532'. 9/20/2008 00:00 - 04:00 4.00 CEMT N DFAL RUNPRD LD PAC pipe and 3-3/4" cleanout BHA from 1532'. Clear rig floor. 04:00 - 11:30 7.50 CEMT N DFAL RUNPRD PJSM. RU SLB E-line. RIH with SCMT tool to log 4.5" liner. Log from landing collar at 12207' up to 3300' (top of window C~3_ 3477'). Continue POH. RD E-line. 11:30 - 13:00 1.50 CEMT N DFAL RUNPRD PJSM. PU dog sub, packoff, and 7" casing scraper to RIH and set ZXP liner top packer. 13:00 - 14:30 1.50 CEMT N DFAL RUNPRD RIH with dog sub assembly to 2082'. 14:30 - 15:30 1.00 CEMT N DFAL RUNPRD Upon further evaluation of SCMT log, cement behind 4.5" liner deemed insufficient to roceed without erformin a remedial cement 'ob.. Per instructions from Anchorage, POH with dog PflMetl: lU/ti/LUU23 "L:14:S'J YM ~ ~ BP EXPLORATION Page 13 of 15 Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task Code NPT .Phase Description of Operations 9/20/2008 14:30 - 15:30 1.00 CEMT N DFAL RUNPRD sub assembly. 15:30 - 17:00 1.50 CEMT N DFAL RUNPRD LD dog sub BHA. Clear and clean rig floor. 17:00 - 18:00 1.00 CEMT P RUNPRD Service top drive. 18:00 - 19:00 1.00 CEMT N WAIT RUNPRD Wait on SLB pert guns to arrive on location. 19:00 - 23:00 4.00 REMCM N DFAL RUNPRD PJSM. PU SLB tools to rig floor. RU wireline pressure control equipment and test to 500 psi for 5 minutes; good test. 23:00 - 00:00 1.00 REMCM N DFAL RUNPRD PU perf guns. MU and RIH with E-line perforating BHA for first run (10' 3-3/8" gun, 6 spf, 60 degree phasing). 9/21/2008 00:00 - 01:30 1.50 REMCM N DFAL RUNPRD RIH with perf guns on E-line and tag 4.5" landing collar at 12207'. 01:30 - 02:00 0.50 REMCM N DFAL RUNPRD Tie in E-line CCL to 4.5" liner tally and shoot perfs from 12150'-12160'. Monitor well; static. 02:00 - 05:00 3.00 REMCM N DFAL RUNPRD POH with E-line. PJSM. LD perf guns. 05:00 - 06:00 1.00 REMCM N DFAL RUNPRD PU perf guns for second run. MU E-line perforating BHA (10' 3-3/8" gun, 6 spf, 60 degree phasing). 06:00 - 08:00 2.00 REMCM N DFAL RUNPRD RIH on E-line for second perf run. Tag up on landing collar at 12,207'. 08:00 - 08:30 0.50 REMCM N DFAL RUNPRD Tie in to liner tally and shoot perfs from 12150'-12160'. Monitor well; static. 08:30 - 09:30 1.00 REMCM N DFAL RUNPRD POH with E-line. 09:30 - 10:30 1.00 REMCM N DFAL RUNPRD PJSM. LD perf guns. RD SLB E-line. Clear and clean floor: 10:30 - 16:00 5.50 REMCM N DFAL RUNPRD PJSM. MU EZSV and running tool, XO, and 2-7/8" PAC pipe to 1393'. 16:00 - 20:30 4.50 REMCM N DFAL RUNPRD RIH with EZSV and 2-7/8" PAC pipe stinger on 4" DP to 12128'. Up Weight 200K, Down Weight 130K. 20:30 - 22:00 1.50 REMCM N DFAL RUNPRD Set EZSV at 12126' er Halliburton Rep. Pressure test drillstring to 2500 psi for 5 minutes; good test. Unsting from EZSV and establish circulation rate and presure: 3 bpm at 890 psi. 22:00 - 22:30 0.50 REMCM N DFAL RUNPRD Sting back into EZSV and attempt to establish circulation/injection. Pumping at 1 bpm, pressure climbed quickly to 3500 psi, no returns. Bleed off pressure and try again with same result. 22:30 - 23:00 0.50 REMCM N DFAL RUNPRD Unsting from EZSV. In order to verify that valve in EZSV not malfunctioning, pressure up DP and annulus to 500 psi, then strip down through annular preventer and sting into EZSV. DP pressure bled off, annulus pressure stayed the same, thus verifying EZSV valve is open. 23:00 - 00:00 1.00 REMCM N DFAL RUNPRD Make third attempt to establish circulation/injection through EZSV. Pumping at 1 bpm. At 3200 psi, pressure dropped off and started getting returns. Increase rate to 2 bpm: 1320 psi. Increase rate to 3 bpm: 1620 psi. Increase rate to 4 bpm: 2180 psi. Slow rate to 2.4 bpm and continue circulating with full return's until cementers ready to begin pumping. 9/22/2008 00:00 - 00:30 0.50 REMCM N DFAL RUNPRD PJSM. RU SLB cementers. Pressure test cement lines to 3600 psi with 5 bbls water; good test. Pump 20 bbls CW 100 preflush at 3 bpm, 1530 psi. 00:30 - 00:45 0.25 REMCM N DFAL RUNPRD Pum 43 bbls 15.8 Class 'G' with GASBLOK at 3-3.4 bpm. Pressures while pumping cement: 10 bbls 1200 psi 20 bbls 900 psi 40 bbls 400 psi 43 bbls 300 psi rnrnea: iuroizuun z:ia:oarnn ~ ~ BP EXPLORATION Page 14 of 15 Legal Well Name: J-08 Operations Summary Report Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABOBS 2ES Rig Number: 2ES Date ', From - To Hours i Task Code NPT Phase Description of Operations 9/22/2008 00:45 - 01:15 0.50 R 01:15 - 02:00 I 0.75 02:00 - 02:30 0.501 REMC 02:30 - 04:00 I 1.50 04:00 - 08:30 I 4.50 08:30 - 10:30 I 2.00 N DFAL RUNPRD Displace cement with 5 bbls water followed by 106.5 bbls mud (NOTE: displacement pumped by SLB). Rates and pressures while displacing: bbls rate (bpm) pressure (psi) 20 4.0 1020 40 4.0 1400 60 4.0 1730 70 4.0 2100 (cmt at perfs; back off„ rate) 80 3.0 1550 90 3.0 1720 100 2.6 1950 111.5 1.5 1620 N DFAL RUNPRD Unsting from EZSV and clear cement unit and lines. Line up rig pumps and circulate out excess cement at 300 gpm. Reciprocate 20' strokes while circulating. Started getting cement back to surface at 3900 strokes (bottoms up strokes=4300). Estimate circulated 19 bbls cement/cement-contaminate mu to su ace. N DFAL RUNPRD Pump 50 bbl pert pill and isp ace wit s mud at 245 10:30 - 13:30 3.00 CLEAN i N 13:30 - 18:00 I 4.501 CLEAN I N 18:00 - 18:30 0.50 CLEAN N 18:30 - 21:00 2.50 CLEAN N 21:00 - 00:00 3.00 CLEAN N 9/23/2008 00:00 - 01:30 1.50 CLEAN N 01:30 - 05:00 3.50 CLEAN N 05:00 - 09:00 4.00 CLEAN N 09:00 - 10:00 1.00 CLEAN N 10:00 - 10:30 0.50 CLEAN N 10:30 - 12:00 1.50 CLEAN N gpm. DFAL RUNPRD POH 14 stands to top of liner at 10816'. Up Weight 220K (-15K drag). Pump 100 bbls viscosified seawater followed by mud at 300 gpm to clean up any remaining cement in 7" casing. Returns looked good. DFAL RUNPRD Pump dry job. POH with EZSV running tool and 2-7/8" stinger from 10816' to 1393'. DFAL RUNPRD Rack back stands of 2-7/8" PAC pipe and LD EZSV setting tool from 1393'. DFAL CLEAN PJSM. PU 3-3/4" liner cleanout BHA and 2-7/8" PAC pipe to 1364'. DFAL CLEAN RIH from 1364' to 4-1/2" liner top at 10816'. Break circulation; 5 bpm at 1290 psi. 60 RPM, Free Torque 5500 ft-Ibs. Up Weight 195K, Down Weight 112K, Rotating Weight 168K. Continue to RIH to 11290'. No drag or obstructions encountered. DFAL CLEAN Wash down from 11290' to EZSV at 12126'. Pumping at 5 bpm, 150 psi. o drag or o struc ions encountered. DFAL CLEAN Displace well to seawater: Pump high-vis sweep surface-to-surface. Displace 4.5" liner to seawater. Drop dart and open circ sub. Pump second high-vis sweep through circ sub and chase with seawater until got clean returns. DFAL CLEAN POH from 12126' to 4911'. DFAL CLEAN POH from 4911' to 3-3/4" cleanout BHA at 1364'. DFAL CLEAN LD 2-7/8" PAC pipe and cleanout BHA from 1364'. Clear and clean rig floor. DFAL CLEAN PJSM. PU and RIH with dog sub and 7" casing scraper. DFAL CLEAN Wash down from 10391' to 10825'. T_ag TOL with 5k down. Up weight 175, down 130k. DFAL CLEAN Circulate sweep S-S at 500 gpm with 2800 psi. DFAL CLEAN Set LTP with 50k down weight. Verified shear. Pick up. Rotate at 10 rpm and set down 50k again. Up weight 185k, down 130k, RT 155k. PJSM. Test casing to 3500 psi. Bleed off 20 psi_ first 15 minutes and 30 psi to 30 minutes. Test OK as per Frank Roach. rnncea: wroizuuo e: w:oa rm BP EXPLORATION Page 15 of 15 Operations Summary Report Legal Well Name: J-08 Common Well Name: J-08 Spud Date: 8/23/1977 Event Name: REENTER+COMPLETE Start: 8/21/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/25/2008 Rig Name: NABORS 2ES Rig Number: 2ES Date 'From - To Hours Task Code NPT Phase ~ Description of Operations 9/23/2008 112:00 - 13:00 I 1.001 CLEAN I P 13:00 - 14:00 1.00 CLEAN P 14:00 - 14:30 0.50 CLEAN P 14:30 - 21:30 7.00 CLEAN P 21:30 - 22:00 0.50 CLEAN P 22:00 - 22:30 0.50 22:30 - 00:00 1.50 9/24/2008 00:00 - 01:00 1.00 01:00 - 17:00 16.00 17:00 - 19:00 I 2.00 19:00 - 20:00 1.00 RU 20:00 - 23:00 3.00 RU 23:00 - 00:00 I 1.001 RUN 19/25/2008 100:00 - 01:00 I 1.00 01:00 - 03:00 ~ 2.00 ~ BOPSUF# P 03:00 - 06:00 3.00 BOPSUFj P 06:00 - 07:00 1.00 BOPSU_df P 07:00 - 10:00 3.00 WHSUR P 10:00 - 11:00 1.00 WHSUR I P 11:00 - 12:30 1.50 WHSUR P 12:30 - 13:30 1.00 WHSUR P 13:30 - 16:30 3.00 WHSUR P 16:30 - 17:30 I 1.001 WHSUR I P 17:30 - 19:00 ~ 1.50 ~ RIGD ~ P CLEAN POOH laying down drill pipe to 10670'. Remove blower hose. Pump dry job. CLEAN PJSM. Cut and slip 93' of drilling line. CLEAN Service top drive, crown and drawworks. CLEAN POOH laying down drill pipe to 21'. CLEAN Lay down dog sub. Confirmed weight to ZXP packer, by shear on dog sub. Clear and clean floor. RUNCMP Pull wear ring. RUNCMP PJSM. Rig up to run 4-1/2", 12.6#, 13Cr-80, Vam Top RUNCMP PJSM. Finish rigging up to run 4-1/2", 12.6#, 13Cr-80, Vam Top completion. RUNCMP PJSM. Run 4-1/2", 12.6#, 13Cr-80, Vam Top completion. Torque turn connections to and average of 4440 ft/Ibs. Up weight 143k, down 105k. RUNCMP Pick up 2 joints run in and tag up. Verify top and bottom of TBR. Space out for landing. Pick up tubing hanger. Land hanger at 1700 hours at 10826'. RUNCMP Clear rig floor. Lay down casing tools. RUNCMP Reverse circulate clean seawater surface to surface at 3 bpm with 250 psi. Spot corrosion inhibitor. Pick up landing joint and run in. Drop ball and rod (roller stem). RUNCMP PJSM. Shut blinds. Pressure up on tubing to 3500 psi for 10 minutes to set packer. Continue to hold pressure for a total of 30 minutes or tubing test. Lost 15 psi in first 15 minutes and 5 osi in second 15 minutes. Bleed to 2000 psi. Pressure up on RUNCMP PJSM. Tesf annulus to 3500 psi for 30 minutes. No pressure loss during test. Bleed off annulus pressure then tubing pressure. Pressure up annulus and shear valve at 2300 psi. Pump both ways at 84 gpm with 370 and 470 psi. RUNCMP Run in TWC. Test from below and above to 1000 si, both OF ow own all surface equipment. RUNCMP Clean rig floor, top drive and drip pans. RUNCMP PJSM. Nipple down BOP stack and set back. RUNCMP PJSM. Nipple up adapter flange, test to 5000 psi for 30 minutes- OK. Nipple up tree. RUNCMP PJSM. Rig up test equipment. Test tree to 5000 psi for 30 minutes - OK. Rig down equipment. RUNCMP PJSM. Rig up DSM lubricator and pull TWC. Rig down. RUNCMP Rig up cellar for freeze protect. RUNCMP Rig up LRS. Test lines to 3000 psi - OK. Pump 75 bbls diesel freeze protect at 2 bpm with 650 psi. Shut down. Rig up lines and allow to U-tube. RUNCMP Run in with BPV, set. Test from below to 1000 si for 10 minutes - K. RUNCMP Prepare cellar and wellhead for moving off. Rig down circulation lines. Remove secondary annulus valves. Install flanges, gauges and tree cap. Secure well. Rig released at 1900 hours Printed: 10/6/2008 2:14:59 PM • J-08A, Well History (Post Rig Sidetrack) Date Summary 9/29/2008 T/I/O =Vac/0/0 Pulled 4-1/16" CIW "H" BPV # 253 , 1-2' ext. used thru tree, tagged C~3 108". Post rig sidetrack, no problems. 10/10/2008 WELL SHUT IN ON ARRIVAL. (Post Rig S/T) PULLED B&R FROM 10,903' SLM. PULLED BEK-DCK FROM STA #3 (6094' MD) & BK-DGLV FROM STA#4 (3390' MD). SET GENERIC GASLIFT DESIGN IN STA'S# 4 & 3. 10/11/2008 PULLED RHC PLUG BODY FROM XN NIPPLE C~ 10,814' MD. TAG TD C~ 12,234' SLM W/ 3 3/8" DMY GUN (3.45" OD). WELL LEFT S/I, DSO NOTIFIED OF STATUS. 10/13/2008 WELL SHUT IN ON ARRIVAL. T/I/O/00 = 60/0/240/150. JEWELRY LOG RUN FROM 8000' - 12200'. PERFORATED 12043' - 12068' WITH 3-3/8" PJ HMX 3406, 6 SPF, 60 DEG PHASING. WELL LEFT SHUT IN, SWAB CLOSED, SSV CLOSED, CASING VALVES OPEN TO GUAGES. FINAL T/I/O/00 = 10/0/240/150. JOB COMPLETE. Page 1 of 1 perry Drilling Service Survey Report Company: BP Amoco Date: 10/6/2008 Time: 11:27:00 Yage: 1 Field: Prudhoe Bay Co-ordinatclNE) Reference: Well: J-08, True No rth Site: PB J Pad Vertical (TVD) Refer ence: J-08A 68.8 Well: J-08 Section (VS) Reference: Well (O.OON,O.OOE,23.83Azi) Wellpath: J-08A Survey Calculation Method: Minimum Curvature Db: Oracle Survey I AID Ind Azirn TVD Sys'fVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft - -- _ 29.31 0.00 0.00 29.31 -39.50 0.00 0.00 5970205.47 643556.42 TIE LINE 101.81 0.47 205.70 101.81 33.00 -0.27 -0.13 5970205.20 643556.29 CB-GYRO-MS 201.81 0.63 208.33 201.80 132.99 -1.12 -0.57 5970204.34 643555.87 CB-GYRO-MS 301.81 0.52 201.94 301.80 232.99 -2.03 -1.00 5970203.43 643555.46 CB-GYRO-MS 401.81 0.60 196.07 401.79 332.98 -2.95 -1.31 5970202.50 643555.16 CB-GYRO-MS 501.81 0.83 186.16 501.79 432.98 -4.17 -1.54 5970201.27 643554.96 CB-GYRO-MS 601.81 0.82 171.92 601.78 532.97 -5.60 -1.51 5970199.84 643555.01 CB-GYRO-MS 701.81 0.53 159.78 701.77 632.96 -6.74 -1.25 5970198.70 643555.30 CB-GYRO-MS 801.81 0.37 149.94 801.77 732.96 -7.46 -0.93 5970198.00 643555.63 CB-GYRO-MS 901.81 0.13 81.25 901.77 832.96 -7.72 -0.66 5970197.74 643555.91 CB-GYRO-MS 1001.81 0.20 44.25 1001.77 932.96 -7.58 -0.42 5970197.89 643556.14 CB-GYRO-MS 1101.81 0.22 40.81 1101.76 1032.95 -7.31 -0.18 5970198.16 643556.38 CB-GYRO-MS 1201.81 0.20 24.13 1201.76 1132.95 -7.00 0.02 5970198.47 643556.57 CB-GYRO-MS 1301.81 0.15 89.16 1301.76 1232.95 -6.84 0.22 5970198.63 643556.77 CB-GYRO-MS 1401.81 0.12 236.87 1401.76 1332.95 -6.90 0.27 5970198.58 643556.82 CB-GYRO-MS 1501.81 0.03 88.84 1501.76 1432.95 -6.95 0.21 5970198.52 643556.76 CB-GYRO-MS 1601.81 0.07 318.61 1601.76 1532.95 -6.91 0.19 5970198.57 643556.74 CB-GYRO-MS 1701.81 0.18 152.15 1701.76 1632.95 -7.00 0.22 5970198.48 643556.78 CB-GYRO-MS 1801.81 0.17 13.72 1801.76 1732.95 -7.00 0.33 5970198.48 643556.88 CB-GYRO-MS 1901.81 0.23 358.82 1901.76 1832.95 -6.65 0.36 5970198.83 643556.91 CB-GYRO-MS 2001.81 0.17 29.68 2001.76 1932.95 -6.32 0.43 5970199.16 643556.97 CB-GYRO-MS 2101.81 0.17 95.19 2101.76 2032.95 -6.21 0.65 5970199.28 643557.19 CB-GYRO-MS 2201.81 0.15 92.59 2201.76 2132.95 -6.22 0.93 5970199.26 643557.47 CB-GYRO-MS 2301.81 0.23 102.79 2301.76 2232.95 -6.28 1.26 5970199.22 643557.80 CB-GYRO-MS 2401.81 0.45 120.17 2401.76 2332.95 -6.52 1.79 5970198.99 643558.34 CB-GYRO-MS 2501.81 0.37 120.79 2501.76 2432.95 -6.88 2.41 5970198.64 643558.96 CB-GYRO-MS 2601.81 0.25 141.40 2601.75 2532.94 -7.22 2.82 5970198.31 643559.38 CB-GYRO-MS 2701.81 0.10 135.42 2701.75 2632.94 -7.45 3.02 5970198.08 643559.58 CB-GYRO-MS 2801.81 1.00 249.47 2801.75 2732.94 -7.82 2.27 5970197.70 643558.83 CB-GYRO-MS Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: J-08 Slot Name: J-08 Well Position: +N/-S 1935.90 ft Northing: 5970205.47 ft Latitude: 70 19 33.881 N +E/-W 2437.65 ft Easting : 643556.42 ft Longitude: 1 48 50 8.937 W Position Uncertainty: 0.00 ft Wellpath: J-08A 500292026501 Drilled From: Tie-on Depth: J-08 3401.81 ft Current Datum: J-08A Height 68.81 ft Above System Datum : Mean Sea Level Magnetic Data: 8/30/2008 Field Strength: 57674 nT Declination: Mag Dip Angle: 23.00 deg 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 29.31 0.00 0.00 23.83 Survey Program for Definitive Wellpath Date: 9/2/2008 Validated: Yes Version: 8 Actual From To Survey Toolcode Tool Name ft ft 101.81 12247.81 1 : Camera based gyro multisho CB-GYRO-MS Camera based gyro multishot 3477.00 12247.21 J-08A MWD+SAG+CA+IIFR+MS (3477 MWD+IFR+MS MWD +IFR + Multi Station perry Drilling Services, Survey Report ~~ Comp nay BP Amoco llate: 10/6/2008 'l'ime: 11 :27:00 Page: 2 ~ Field: Pru dhoe Bay Co-ordinate(NE) Reference: Weli: J-08, True No rth ~ Site: PB J Pad Vertica l (1'Vll) Reference: J-08A 68.8 ~ I Wcll: J-0 8 Section lVS) Referen ce: Well ( O.OON,O.OOE,23.83Azi) ~~ A~Vcllpath: J-0 8A Sur~cy Calculation Method: Minimum Curvature Db: Oracle Surccv i t MD Lul Azim 'CVD Svs TVll N/S E/R' MapN MapE 'fool ft deg - - deg ft ft ft ft ft ft _ _- 2901. 81 1.35 - 265. 01 2901. 73 2832. 92 -8.22 0.28 5970197. 25 643556.85 CB-GYRO-MS 3001. 81 3.62 276 .49 3001. 63 2932. 82 -7.97 -4.04 5970197. 42 643552.54 CB-GYRO-MS 3101. 81 3.43 283. 10 3101. 44 3032. 63 -6.94 -10.09 5970198. 34 643546.47 CB-GYRO-MS 3201. 81 4.93 286. 94 3201. 17 3132. 36 -5.01 -17.11 5970200. 14 643539.41 CB-GYRO-MS 3301. 81 7.23 297. 71 3300. 60 3231. 79 -0.83 -26.79 5970204. 13 643529.65 CB-GYRO-MS 3401. 81 9.72 303 .84 3399. 51 3330. 70 6.80 -39.38 5970211. 52 643516.92 CB-GYRO-MS 3477. 00 12.12 306 .07 3473. 33 3404. 52 14.99 -51.03 5970219. 47 643505.11 MWD+IFR+MS 3506. 38 13.911 317 .58 3501. 96 3433. 15 19.41 -55.91 5970223. 80 643500.15 MWD+IFR+MS 3550. 24 17.67 330 .64 3544. 17 3475. 36 29.11 -62.73 5970233. 37 643493.15 MWD+IFR+MS 3571. 23 19.94 335 .27 3564. 04 3495. 23 35.14 -65.79 5970239. 34 643489.97 MWD+IFR+MS 3600. 35 22.14 340 .62 3591. 22 3522. 41 44.83 -69.69 5970248. 95 643485.89 MWD+IFR+MS 3630. 46 23.97 345 .32 3618. 93 3550. 12 56.10 -73.12 5970260. 15 643482.24 MWD+IFR+MS 3662. 10 25.58 345 .64 3647. 65 3578. 84 68.93 -76.45 5970272. 92 643478.67 MWD+IFR+MS 3693. 43 27.29 351 .57 3675. 71 3606. 90 82.59 -79.18 5970286. 53 643475.68 MWD+IFR+MS 3724. 30 28.90 356 .79 3702. 95 3634. 14 97.04 -80.63 5970300. 95 643473.95 MWD+IFR+MS 3755. 88 29.58 1 .94 3730. 51 3661. 70 112.46 -80.80 5970316. 35 643473.49 MWD+IFR+MS 3787. 74 29.95 8 .53 3758. 17 3689. 36 128.18 -79.35 5970332. 10 643474.64 MWD+IFR+MS 3819. 16 30.62 14 .92 3785. 31 3716. 50 143.68 -76.13 5970347. 65 643477.56 MWD+IFR+MS 3851. 30 30.35 20 .03 3813. 01 3744. 20 159.22 -71.24 5970363. 28 643482.15 MWD+IFR+MS 3881. 99 29.66 22 .47 3839. 59 3770. 78 173.52 -65.68 5970377. 69 643487.44 MWD+IFR+MS 3913. 26 28.64 25 .84 3866. 90 3798. 09 187.42 -59.46 5970391. 70 643493.39 MWD+IFR+MS 3945. 33 27.93 30 .07 3895. 14 3826. 33 200.83 -52.34 5970405. 25 643500.25 MWD+IFR+MS 3976. 44 26.99 32 .68 3922. 75 3853. 94 213.08 -44.88 5970417. 64 643507.47 MWD+IFR+MS 4007. 85 26.52 34 .27 3950. 80 3881. 99 224.88 -37.08 5970429. 58 643515.04 MWD+IFR+MS 4038. 57 26.41 32 .51 3978. 30 3909. 49 236.31 -29.55 5970441. 15 643522.36 MWD+IFR+MS 4069. 51 25.86 30 .95 4006. 08 3937. 27 247.90 -22.38 5970452. 87 643529.30 MWD+IFR+MS 4102. 41 25.67 27 .74 4035. 71 3966. 90 260.36 -15.37 5970465. 46 643536.07 MWD+IFR+MS 4164. 51 25.23 26 .99 4091. 78 4022. 97 284.05 -3.10 5970489. 39 643547.88 MWD+IFR+MS 4257. 01 27.67 28 .70 4174. 59 4105. 78 320.47 16.16 5970526. 16 643566.44 MWD+IFR+MS 4351. 18 28.73 25 .70 4257. 59 4188. 78 360.04 36.48 5970566. 12 643586.00 MWD+IFR+MS 4448. 51 33.78 25 .48 4340. 76 4271. 95 405.58 58.27 5970612. 06 643606.92 MWD+IFR+MS 4478. 40 35.24 26 .02 4365. 39 4296. 58 420.83 65.63 5970627. 44 643613.98 MWD+IFR+MS 4509. 25 35.37 25 .82 4390. 57 4321. 76 436.86 73.43 5970643. 63 643621.47 MWD+IFR+MS 4540. 86 35.26 26 .43 4416. 36 4347. 55 453.27 81.47 5970660. 18 643629.20 MWD+IFR+MS 4635. 90 40.33 24 .72 4491. 44 4422. 63 505.81 106.56 5970713. 18 643653.27 MWD+IFR+MS 4667. 37 40.68 24 .78 4515. 37 4446. 56 524.37 115.12 5970731. 91 643661.48 MWD+IFR+MS 4729. 14 45.70 21 .67 4560. 40 4491. 59 563.22 131.73 5970771. 06 643677.34 MWD+IFR+MS 4759. 81 46.60 21 .91 4581. 64 4512. 83 583.76 139.94 5970791. 75 643685.16 MWD+IFR+MS 4822. 54 48.47 21 .85 4623. 99 4555. 18 626.70 157.19 5970835. 01 643701.57 MWD+IFR+MS 4916. 77 52.28 20 .39 4684. 08 4615. 27 694.39 183.31 5970903. 19 643726.39 MWD+IFR+MS 4950. 33 53.69 20 .73 4704. 28 4635. 47 719.48 192.72 5970928. 45 643735.32 MWD+IFR+MS 4983. 00 56.49 20 .28 4722. 98 4654. 17 744.57 202.10 5970953. 72 643744.22 MWD+IFR+MS 5014. 67 59.98 19 .38 4739. 65 4670. 84 769.90 211.23 5970979. 21 643752.86 MWD+IFR+MS 5045. 50 60.91 19 .91 4754. 86 4686. 05 795.16 220.25 5971004. 64 643761.40 MWD+IFR+MS 5093. 63 60.45 19 .54 4778 .43 4709. 62 834.66 234.41 5971044 .40 643774.80 MWD+IFR+MS 5189. 18 59.98 20 .65 4825 .89 4757. 08 912.54 262.90 5971122 .80 643801.79 MWD+IFR+MS 5284 .67 59.37 19 .88 4874 .10 4805. 29 989.86 291.45 5971200 .65 643828.86 MWD+IFR+MS 5376 .83 59.19 21 .37 4921 .19 4852. 38 1064.01 319.35 5971275 .31 643855.34 MWD+IFR+MS 5470 .99 58.92 20 .22 4969 .60 4900. 79 1139.50 348.03 5971351 .33 643882.55 MWD+IFR+MS 5565 .19 58.41 20 .65 5018 .59 4949. 78 1214.90 376.12 5971427 .25 643909.20 MWD+IFR+MS 5661 .20 57.83 18 .84 5069 .30 5000. 49 1291.62 403.66 5971504 .48 643935.27 MWD+IFR+MS 5755 .73 57.82 17 .20 5119 .64 5050 .83 1367.71 428.41 5971581 .02 643958.55 MWD+IFR+MS ~5perry Drilling Servicesa Survey Report Company: BP AmoCO Field: Prudhoe Bay i Site: PB J Pad Nell: J-OS ~Vcllpath: J-08A Survev MD Incl ft deg zim deg, Vll ft ys TVD ft Date: 10/6/2008 Time: 11:27:00 Pagc: 3 Co-ordinatc(NE) Reference: Well: J-O8, True North Vertical (TVll) Reference: J-08A 68.8 Secfion (VS) Reference: Well (O.OON,O.OOE,23.83Azi) Survev Calculation Mekhod: Minimum Curvature Db: Oracle N/S E/W NIapN MapE Tool ft ft ' ft ft 5847. 60 57. 74 18. 01 5168. 63 5099.82 1441.79 451. 92 5971655. 53 643980.64 MWD+IFR+MS 5878. 48 57. 93 17. 82 5185. 07 5116.26 1466.66 459. 96 5971680. 55 643988.20 MWD+IFR+MS 5941. 31 58. 27 19. 30 5218. 27 5149.46 1517.23 476. 94 5971731. 43 644004.21 MWD+IFR+MS 6037. 98 58. 29 18. 39 5269. 10 5200.29 1595.05 503. 50 5971809. 73 644029.27 MWD+IFR+MS 6131. 40 59. 36 19. 39 5317. 45 5248.64 1670.67 529. 38 5971885. 83 644053.70 MWD+IFR+MS 6226. 66 59. 99 18. 85 5365. 55 5296.74 1748.36 556. 31 5971964. 02 644079.14 MWD+IFR+MS 6320. 44 59. 48 19. 65 5412. 82 5344.01 1824.83 583. 01 5972040. 98 644104.37 MWD+IFR+MS 6414. 32 58. 82 18. 86 5460. 96 5392.15 1900.91 609. 59 5972117. 55 644129.49 MWD+IFR+MS 6508. 73 58. 86 20. 52 5509. 81 5441.00 1976.97 636. 81 5972194. 11 644155.25 MWD+IFR+MS 6603. 22 58. 00 20. 35 5559. 28 5490.47 2052.41 664. 92 5972270. 07 644181.90 MWD+IFR+MS 6697. 52 57. 42 19. 97 5609. 66 5540.85 2127.24 692. 40 5972345. 41 644207.94 MWD+IFR+MS 6790. 26 57. 64 18. 88 5659. 45 5590.64 2201.03 718. 42 5972419. 67 644232.54 MWD+IFR+MS 6885. 28 58. 19 19. 70 5709. 92 5641.11 2277.02 745. 01 5972496. 15 644257.68 MWD+IFR+MS 6979. 16 57. 93 18. 88 5759. 58 5690.77 2352.21 771. 33 5972571. 82 644282.55 MWD+IFR+MS 7074. 64 58. 20 20. 33 5810. 09 5741.28 2428.54 798. 52 5972648. 65 644308.27 MWD+IFR+MS 7167. 66 57. 30 19. 51 5859. 73 5790.92 2502.50 825. 32 5972723. 11 644333.65 MWD+IFR+MS 7261. 78 57. 58 20. 12 5910. 38 5841.57 2577.13 852. 21 5972798. 23 644359.11 MWD+IFR+MS 7356. 44 58. 41 20. 48 5960. 55 5891.74 2652.41 880. 06 5972874. 03 644385.51 MWD+IFR+MS 7452. 62 58. 27 21. 31 6011. 03 5942.22 2728.89 909. 26 5972951. 05 644413.24 MWD+IFR+MS 7547. 26 57. 45 20. 41 6061. 38 5992.57 2803.77 937. 80 5973026. 46 644440.34 MWD+IFR+MS 7642. 42 57. 59 20. 45 6112. 48 6043.67 2879.00 965. 82 5973102. 20 644466.91 MWD+IFR+MS 7736. 92 58. 26 20. 49 6162. 66 6093.85 2954.02 993. 82 5973177. 73 644493.47 MWD+IFR+MS 7830. 99 58. 52 19. 96 6211. 97 6143.16 3029.19 1021. 52 5973253. 42 644519.72 MWD+IFR+MS 7925. 34 58. 81 19. 05 6261. 04 6192.23 3105.15 1048. 43 5973329. 87 644545.17 MWD+IFR+MS 8019. 70 59. 46 19. 55 6309. 45 6240.64 3181.60 1075. 20 5973406. 81 644570.47 MWD+IFR+MS 8114. 63 59. 70 19. 75 6357. 51 6288.70 3258.69 1102. 72 5973484. 41 644596.52 MWD+IFR+MS 8209. 79 59. 97 19. 90 6405. 33 6336.52 3336.09 1130. 63 5973562. 32 644622.93 MWD+IFR+MS 8303. 71 59. 53 18. 76 6452. 64 6383.83 3412.64 1157. 48 5973639. 37 644648.32 MWD+IFR+MS 8399. 88 59. 71 19. 19 6501. 28 6432.47 3491.10 1184. 46 5973718. 32 644673.78 MWD+IFR+MS 8493. 80 59. 10 20. 15 6549. 08 6480.27 3567.23 1211. 67 5973794. 95 644699.53 MWD+IFR+MS 8588. 30 59. 01 20. 16 6597. 68 6528.87 3643.31 1239. 60 5973871. 55 644725.99 MWD+IFR+MS 8681. 75 58. 65 21. 03 6646. 05 6577.24 3718.16 1267. 72 5973946. 92 644752.68 MWD+IFR+MS 8776. 09 57. 93 20. 60 6695. 63 6626.82 3793.18 1296. 24 5974022. 46 644779.76 MWD+IFR+MS 8869. 21 56. 99 21. 34 6745. 72 6676.91 3866.48 1324. 33 5974096. 28 644806.44 MWD+IFR+MS 8963. 76 54. 02 23. 50 6799. 27 6730.46 3938.51 1354. 02 5974168 .86 644834.74 MWD+IFR+MS 9060. 46 50. 10 27. 55 6858. 72 6789.91 4007.32 1386. 80 5974238 .28 644866.20 MWD+IFR+MS 9153. 65 46. 77 29. 27 6920. 55 6851.74 4068.65 1419. 94 5974300 .23 644898.16 MWD+IFR+MS 9248. 93 41. 90 32. 17 6988. 68 6919.87 4125.90 1453 .88 5974358 .11 644930.99 MWD+IFR+MS 9281. 22 40. 70 34. 03 7012. 94 6944.13 4143.75 1465 .51 5974376 .18 644942.28 MWD+IFR+MS 9312. 40 41. 33 35. 17 7036 .47 6967.66 4160.59 1477 .13 5974393 .24 644953.57 MWD+IFR+MS 9344. 09 41. 49 35. 48 7060 .24 6991.43 4177.70 1489 .25 5974410 .57 644965.36 MWD+IFR+MS 9437. 80 41. 01 34. 39 7130 .69 7061.88 4228.35 1524 .64 5974461 .89 644999.77 MWD+IFR+MS 9532. 75 41. 19 33. 92 7202 .24 7133.43 4280.00 1559 .68 5974514 .20 645033.81 MWD+IFR+MS 9627 .63 43. 41 36. 42 7272 .42 7203.61 4332.17 1596 .48 5974567 .05 645069.60 MWD+IFR+MS 9722 .53 42. 56 36. 88 7341 .84 7273.03 4384.08 1635 .10 5974619 .69 645107.22 MWD+IFR+MS 9817 .49 41. 72 36. 60 7412 .25 7343.44 4435.14 1673 .21 5974671 .46 645144.35 MWD+IFR+MS 9912 .28 42. 02 35. 68 7482 .84 7414.03 4486.23 1710 .52 5974723 .26 645180.67 MWD+IFR+MS 10007 .14 41. 26 36. 47 7553 .73 7484.92 4537.17 1747 .63 5974774 .90 645216.80 MWD+IFR+MS 10101 .11 41. 95 35. 75 7624 .00 7555.19 4587.58 1784 .40 5974826 .00 645252.59 MWD+IFR+MS 10189 .37 40 .72 35. 47 7690 .27 7621.46 4634.97 1818 .34 5974874 .02 645285.62 MWD+IFR+MS 10289 .91 41 .09 34. 39 7766 .26 7697.45 4688.94 1856 .03 5974928 .70 645322.27 MWD+IFR+MS 10384 .53 41 .57 34. 29 7837 .31 7768.50 4740.54 1891 .28 5974980 .96 645356.52 MWD+IFR+MS 10478 .77 42 .38 35 .10 7907 .37 7838.56 4792.36 1927 .16 5975033 .45 645391.40 MWD+IFR+MS ~hperry Drilling Servicesa Survey Report Company: BP Amoco Field: Prudhoe Bay Site: PB J Pad Well: J-08 ~~~ Wellpath: J-08A Survcv -- - - MD lncl ft deg nt deg ___ I) `ft ys TVll ft 1)atc: 10/6/2008 1'imr. 11:27:00 Pagc: 4 Co-ordinate(NF,) Reference: Well: J-08, True North Vertical ~TVD) Reference: J-08A 68.8 Section (VS) Reference: Well (O.OON,O.OOE,23.83Azi) Survey Calculation Method: Minimum Curvature Db: Oracle ~ NfS E/W MapN MapE Tool ft ft ft ft 10574.59 42. 21 35. 06 7978 .25 7909 .44 4845.13 1964.22 5975086. 92 645427.44 MWD+IFR+MS 10669.29 42. 08 34. 97 8048 .46 7979 .65 4897.17 2000.68 5975139. 64 645462.89 MWD+IFR+MS 10763.08 41. 98 34. 86 8118 .13 8049 .32 4948.66 2036.62 5975191. 81 645497.84 MWD+IFR+MS 10856.81 42. 27 34. 45 8187 .65 8118 .84 5000.38 2072.37 5975244. 19 645532.59 MWD+IFR+MS 10950.24 42. 09 35. 22 8256 .88 8188 .07 5051.87 2108.20 5975296. 36 645567.43 MWD+IFR+MS 11045.40 41. 68 34. 81 8327 .73 8258 .92 5103.90 2144.66 5975349. 08 645602.88 MWD+IFR+MS 11140.45 41. 50 34. 50 8398 .82 8330 .01 5155.80 2180.54 5975401. 65 645637.75 MWD+IFR+MS 11234.53 42. 29 34. 85 8468 .85 8400 .04 5207.47 2216.28 5975453. 98 645672.50 MWD+IFR+MS 11328.89 42. 10 36. 07 8538 .76 8469 .95 5259.09 2253.04 5975506. 29 645708.27 MWD+IFR+MS 11361.22 41 .54 35. 71 8562 .85 8494 .04 5276.55 2265.68 5975524. 00 645720.57 MWD+IFR+MS 11445.37 41 .73 35. 40 8625 .74 8556 .93 5322.04 2298.19 5975570. 09 645752.20 MWD+IFR+MS 11488.37 41 .76 34. 22 8657 .83 8589 .02 5345.54 2314.53 5975593. 90 645768.09 7" 11536.02 41 .81 32. 92 8693 .36 8624 .55 5372.00 2332.09 5975620. 68 645785.13 MWD+IFR+MS 11569.69 42 .66 31. 73 8718 .29 8649 .48 5391.12 2344.19 5975640. 04 645796.87 MWD+IFR+MS 11632.26 45 .93 32. 35 8763 .07 8694 .26 5428.15 2367.38 5975677. 50 645819.33 MWD+IFR+MS 11662.85 47 .67 32. 83 8784 .00 8715 .19 5446.94 2379.39 5975696. 51 645830.98 MWD+IFR+MS 11754.98 50 .31 31 .97 8844 .45 8775 .64 5505.64 2416.62 5975755. 91 645867.09 MWD+IFR+MS 11787.00 52 .01 31 .14 8864 .54 8795 .73 5526.89 2429.67 5975777. 40 645879.73 MWD+IFR+MS 11817.62 53 .12 29 .62 8883 .15 8814 .34 5547.86 2441.97 5975798. 61 645891.62 MWD+IFR+MS 11849.21 54 .42 28 .67 8901 .82 8833 .01 5570.12 2454.38 5975821. 10 645903.60 MWD+IFR+MS 11880.61 55 .75 26 .87 8919 .79 8850 .98 5592.90 2466.37 5975844. 10 645915.15 MWD+IFR+MS 11910.52 56 .35 25 .46 8936 .50 8867 .69 5615.17 2477.31 5975866. 57 645925.66 MWD+IFR+MS 11941.38 57 .74 24 .70 8953 .28 8884 .47 5638.62 2488.28 5975890. 23 645936.18 MWD+IFR+MS 11975.97 59 .71 23 .51 8971 .24 8902 .43 5665.61 2500.35 5975917. 44 645947.73 MWD+IFR+MS 12007.01 61 .98 23 .64 8986 .36 8917 .55 5690.45 2511.19 5975942. 48 645958.10 MWD+IFR+MS 12033.61 63 .15 24 .09 8998 .62 8929 .81 5712.04 2520.75 5975964. 25 645967.23 MWD+IFR+MS 12065.14 63 .70 23 .99 9012 .72 8943 .91 5737.79 2532.23 5975990. 22 645978.23 MWD+IFR+MS 12127.37 64 .66 24 .32 9039 .83 8971 .02 5788.90 2555.16 5976041. 75 646000.16 MWD+IFR+MS 12220.04 64 .44 24 .46 9079 .65 9010 .84 5865.11 2589.71 5976118. 60 646033.25 MWD+IFR+MS 12247.21 64 .59 24 .23 9091 .34 9022 .53 5887.46 2599.82 5976141. 14 646042.93 MWD+IFR+MS 12294.00 64 .59 24 .23 9111 .42 9042 .61 5926.00 2617.17 5976180. 00 646059.54 BLIND WELLHE4D= MCEVOY ACTUATOR = Baker KB. ELEV = 69.41 BF. ELEV = 40.13' KOP - _ 3477. Max Angle 65 @ 12127' Datum MD = 12294 Datum TV D = 8800' SS 13-3/8" CSG, 72#, 2691' N-80, ID = 12.347" Minimum ID = 3.725" 10814' 4-1 /2" XN NIPPLE WHIPSTOCK ~ 3477' 9-5/8" HES EZSV 3494' (- TUBING CUT 3665' sHrt i r rvv i is esau ana roa a rover stem wan an ~, ~ I 0.625" for the wheels. (4) .~. 2215' 4-1/2" HES X NIP, ID = 3.813" ~' CHAS I IFr MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3390 3388 9 KBG2 DOME BK 16 10/10/08 3 6094 5298 59 KBG2 SO BK 20 10/10/08 2 8222 6411 60 KBG2 DMY BK 0 09/24!08 1 10599 7996 42 KBG2 DMY BK 0 09/24/08 4402' 7" CSG, 26#, L-80, TGII, BPF = .0382, ID = 6.276" 7,004' ~-i7" 26# HES ES Cementer 10676' 10707' 10741' 10814' 10824' - 10825' TOC I-I 10750' ~ 9-5/8" Csg, 47#, N-80 I'i 11422' 7" LNR, 29#, N-80 ~ 12544' I 11489' I- 17" CSG XO, 26#, L-80, TGII X BTGM, ID = 6.276" I 4-1/2" HES X NIP, ID = 3.813" 7" x 4-1/2" BAKER S-3 PKR, ID = 3.875" 4-1/2" HES X NIP, ID = 3.813" 4-1 /2" HES XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, 13Cr-80, Vam TOP, BPF = 0.015: ID - 3.992" 4-1 /2" WLEG 7" x 4-1 /2" Baker ZXP Liner Top Packer Tieback Extension 11' x 5-1 /4" (Top at 10817) 7" CSG, 26#, L-80, BTC-M, BPF = .0382, ID = 6.276" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 6 12,150' - 12,160' SOZ 09/25/08 3-3/8" 6 12043 - 12068 O 10/13/08 12,126' -'j4-1/2" HES EZSV I 12294' 4-1/2" LNR, 12.6#, 13G-80; Vam TOP, BPF = 0.0152, ID = 3.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 09/77 ORIGINAL COMPLETION 01/22/91 RWO 09/25/08 N2ES SIDETRACK (J-08A) 10/03/08 /TLH CORRECTIONS 10/16/08 DTR/PJC GLV C/O (10/10/08) 10/17/08 ?/ PJC PERFS (10/13/08) PRUDHOE BAY UNff WELL: J-08A PERMff No: "1770470 API No: 50-029-20265-01 SEC 9, T11 N, R13E, 804' FEL & 1148' FNL BP Exploration (Alaska) 11 /04/08 i• i• Schlu~nherger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wt.ll .Inh ik N0.4952 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnkerl 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 nn rlocrrinfinn ~ nflfu AI r`nlnr r`fl D-29 12103692 USIT f 10/19/08 1 1 13-16 12103694 INJECTION PROFILE (REVISED) / 10/20/08 1 1 13-19 12103695 INJECTION PROFILE ~l 10/21/08 1 1 03-04 12031526 INJECTION PROFILE 10!22/08 1 1 J-08A 12031514 CBL Q~- Zt ( 09/20/08 1 1 06-17 11970850 PRODUCTION LOG ~-) (p ~ 10/30/08 1 1 01-33 11999052 RST - ~j 10/10/08 1 1 1-45/0-26 12096920 LDL ~-. 10/10/08 1 1 3-05/0-29 12083416 MEM LDL 10/24/08 1 1 L-116 11999055 USIT I ~ / • ~ 10/31/08 1 1 rl_tHat NI:RNVV1ILtUlat Fitl:tlrl t3Y JIViNINta ANU Fit! UFiNINCi UNt t:Uh'Y tA(:M I U: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ' i ~ `; Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99 03-283 ATTN: Beth Received by: ---~' WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: J-08A October 30, 2008 AK-MW-5891251 J-08A: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20265-01 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20265-01 Digital Log Images: 1 CD Rom 50-029-20265-O1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-:3536 ,_, .. Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: 6-Oct-08 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well J-08A Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and one disk. J-08A Tie-on Survey: 3401.81' MD Window Survey: 3477.00' MD Projected Survey: 12,294.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date`-o~~6~ Signed \ y~~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~- c a~ Late BOP test timeline; 2-ES o~08A (PTD 208-120) Maunder, Thomas E (DOA) From: Roach, Frank [Frank.Roach@bp.com] Sent: Tuesday, September 16, 2008 3:16 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Tirpack, Robert B Subject: RE: Late BOP test timeline; 2-ES on J-08A (PTD 208-120) Mr. Maunder, Per our phone conversation this afternoon, here is the current situation with J-08A (PTD 208-120): Page 1 of 3 When the first a-mail was sent, the annulus was flowing back drilling mud and spacer from a charged formation, assumed to be the Ugnu (wellbore breathing conditions were present throughout drilling 8-1/2" hole section). 2- ES wellsite leaders were in daily contact with slope AOGCC representatives providing updates. Flow finally ceased Friday afternoon (09/12/2008) at 13:00 hours. Ensuing wellhead work was completed and the full BOP test was started at midnight (witnessing of test was waived by Jeff Jones). After completing the cement job, returns were noted at 63%. This would put the total cement behind pipe at ~52 bbls (roughly 2,315 ft of annular coverage assuming gauge hole}. If there was no fall back from the stage tool depth, this would put TOC at about 4685 ft MD. Similar to 02-40 (previous well for 2-ES), there is no cement at the 7" casing shoe (casing passed 3,500 psi pressure test and have successful 10.5 ppg FIT at 7" shoe with 20' Sag River formation exposed). On J-Pad, the shallowest production interval is the Sag River formation. In order to bring atop-of-cement 500 feet above hydrocarbon producing zones, the 4-1/2" production finer will be moved up to 10,817 ft MD and fully cemented. In our phone conversation on 09/09/2008, there was discussion of a bond log to determine location of cement behind 7" casing. Our current assumption, given annular breathing, is that cement is not across all Ugnu zones. Shales behind 7" (HRZ and Kingak formations) and cement are providing effective isolation between producing hydrocarbon zones and shallower intervals given our successful FIT to 10.5 ppg at the 7" shoe. Our current view is that the value of bond log data would be minimal because the gathered data would not affect our plan forward on this well with the hydrocarbon zones effectively isolated at this time by the 7" casing string. Please feel free to let us know your thoughts on this issue. Thank you. Regards, -Frank Roach Office: 564-4373 Mobile: 244-1674 From: Roach, Frank Sent: Tuesday, September 09, 2008 2:52 PM To: 'Maunder, Thomas E (DOA)' Cc: Hobbs, Greg S (ANC); Tirpack, Robert B; Regg, James B (DOA) Subject: RE: Late BOP test timeline; 2-ES on ]-08A (PTD 208-120) Mr. Maunder, The prior BOP test was completed on 08/25/2008, at 21:00. Regards, ct~~~J ~~ 1liloi2ao8 ~ ~~-`~' Late BOP test timeline; 2-ES o~08A (PTD 208-120) Page 1 of~ ) Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, September 09, 2008 2:36 PM To: Maunder, Thomas E (DOA) Subject: RE: Late BOP test timeline; 2-ES on J-08A (PTD 208-120) Attachments: 2008-0825_BOP_Nabors2 ES_PBU_J-08A.xls 8/25/2008 was last test I have; good test although we did not witness; last witness was 7/29 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: M nder, Thomas E (DOA) Sent: Tues ,September 09, 2008 2:02 PM To: Roach, Fra Cc: Hobbs, Greg ANC); Tirpack, Robert B; Regg, J~ Subject: RE: Late P test timeline; 2-ES on J-08A Frank, Thank you for the timeline i rmation. When wa ~he Tom Maunder, PE AOGCC From:. Roach, Frank [mailto:Frank.Ro bp.ci Sent: Tuesday, September 09, 2008 :41 To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Tirpa ,Robert B Subject: Late BOP test timeli ; 2-ES on J-08A Mr. Maunder, (DOA) 208-120) prior BOP test completed (date and time)? 208-120) Per our conversa ' n this morning, the timeline below illustrates a nts leading up to missing our 14 day BOP testing window nd our current situation with J-08A (PTD: 208-120). Sunday, 10712008, 15:00: Start running 7" casing string to bottom at 1 489'. Initial projection was to have pipe on ottom by 09:00 on 09/08/2008, cement in place by 14:00, wellhea ork completed and BOPE test starte no later than 19:00 on 09/08/2008. *"Note: Prior to running casing, 7" i drams were installed in the BOP sta and tested to 250 psi tow / 3500 psi high per BP/AOGCC regulations.** 09108/2008, 15:00: 11/10/2008 • • STATE OF ~.~ 11/14/07 OiL AND GAS CONSERVATION ~C{)Mi1~1SS1©N BOPS lest Report ~o: Contractor: Nabors Rig No.: 2ES Rig Rep.: C. Coyne / J. Castle ~9 Phone: 65~-41.44.. Operator: BP AK. DRLG OP. Phone: 659-41ft3 Rep.: J. LeBlanc! A. McVey Field/Unit & Well No.: PBU ,i-08A PTD # 2A~-#2A Operation: Drlg: X Workover: Test: Initial: X Weekly: Test Pressure: Rams: 2511 /3500 Annular: 250 / 2500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Well Sigrt P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec.. P Standing Order Posted P BOP STACK.:.. Quantity Size Test Result Annular Preventer 1 13 5/8 P Pipe Rams 1 3112" X 6" P Lower Pipe Rams 2 718" X 5" P Blind Rams 1 BShears P Choke Ln. Valves 1 3 1/8 5,000 P HCR Valves 2 31/8 5,000 P Kill Line Valves 1 3118 5,000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P DATE: 8/25/2008 Rig Fax 659-4177 Op. Fax: 659-4177 Explor.: Bi-Weekly Valves: 250 / 3500 FLOOR SAFETY VALVES: Quantity Test R Lipper KeNy 1 P Lower Kelly 1 P Bali Type 1 P inside BOP 1 P CIiOKE MANIFOLD: Quantity Test Result No. Values 18 P AAanual Chokes 1 P Hydraulic Ct~kes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1500 P 200 psi Attained 0:20 P FuN Pressure Attained 1:13 P Blind Switch Covers: AI{ stations P Nitgn_ Botts ~avg}: 6 Bottles @ 2150 avg. Test Results Number of Failures: 0 Test Tune: 7~5 Hours Repair or replacement of egt~rmerrt witl be made withiet 0 Inspector 659-3607, f with written conftrmation to Supervises at: Remarks: Tested with 4",4112", and 5" test ion. Good Test YES X NC3 BOP Test (for rigs) BFL 11/14/07 GIVEN Date 08124/08 lime 'est start 16::00.:00 PM Finish Corr~onents tested ALL days. Notify the North Slope Waived By Jeff Jones 10:OOAM Witness A. McVey/J. Castle 23:30:00 PM 2008-0825_BOP_Nabors2ES_PBU_J-08A.xls Late BOP test timeline; 2-ES o~08A (PTD 208-120) • Page 2 of 3 -Frank Roach From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, September 09, 2008 2:02 PM To: Roach, Frank Cc: Hobbs, Greg S (ANC); Tirpack, Robert B; Regg, James B (DOA) Subject: RE: Late BOP test timeline; 2-ES on J-08A (PTD 208-120) Frank, Thank you for the timeline information. When was the prior BOP test completed (date and time)? Tom Maunder, PE AOGCC From: Roach, Frank [mailto:Frank.Roach@bp.com] Sent: Tuesday, September 09, 2008 1:41 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Tirpack, Robert B Subject: Late BOP test timeline; 2-ES on J-08A (PTD 208-120) Mr. Maunder, Per our conversation this morning, the timeline below illustrates events leading up to missing our 14 day BOP testing window and our current situation with J-0$A (PTD: 208-120): Sunday, 09/07/2008, 15:00: Start running 7" casing string to bottom at 11,489'. Initial projection was to have pipe on bottom by 09:00 on 09/08/2008, cement in place by 14:00, wellhead work completed and BOPE test started no later than 19:00 on 09108/2008. "*Note: Prior to running casing, 7" fixed rams were installed in the BOP stack and tested to 250 psi tow / 3500 psi high per BP/AOGCC regulations.*"` Monday, 09/08/2008, 15:00: 800' from TD with casing string. HRZ and Kingak shales starting to give us issues. Becoming harder to run pipe in hole. Monday, 09/08/2008,17:30: Situation report between town engineering and 2-ES wellsite staff. Confirmed that operations would exceed time remaining for BOP test. 2-ES wellsite staff to notify slope-based AOGCC personnel. Monday, 09/08/2008, 18:00: BP wellsite leader Bill Decker contacted AOGCC field representatives John Crisp and Bob Noble to notify tem of impending late BOP test due to hole conditions. Mr. Crisp stated that he would be unable to grant an extension on the test requirement and #o have BP town engineering contact town AOGCC staff the following morning. Monday, 09/0812008,18:12: BP wellsite leader 8i11 Decker contacted BP town engineers Frank Roach and Greg Hobbs. Relayed conversation between himself and Mr. Crisp. Monday, 09/08/2008, 18:35: Mr. Hobbs calls AOGCC engineer Tom Maunder on office phone. Left message on voicemail. Monday, 09/08/2008, 22:30: 7" casing string landed at 11,489'. Attempted to establish circulation. Tuesday, 09J09I2008, 01:30: Unable to establish circulation. 2-ES wellsite staff contacts BP town engineering. Decision made to abandon 1st stage of cement job and open ES cementer. 11/10/2008 Late BOP test timeline; 2-ES o~08A (PTD 208-120) Tuesday, 09/09/2008, 03:45: ES cementer opened. Pumping 5 bpm with no returns. Tuesday, 09/09/2008, 08:00: Started 2 stage of cement job. Started to see returns at surface. Tuesday, 09109/2008, 08:05: BP town engineer contacted AOGCC engineer Tom Maunder. Mr Mr. Maunder of the missed BOP test and current situation on 2-ES. Mr. Maunder instructed Mr. mail with timeline of events to him and to CC Mr. Hobbs. Page 3 of 3 . Roach notified Roach to send e- Tuesday, 09109/2008, 09:30: Cement job completed. 2nd stage 100% away, Returns seen throughout job. Currently, 2-ES is waiting on compressive strengths and monitoring annulus before setting slips and performing wellhead work. Wellsite leader Bill Decker will contact AOGCC field representative with updated BOP test time. If there are any questions or concerns, please don't hesitate to contact myself or Greg Hobbs. Thank you. Regards, -Frank Roach Office: 564-4373 Mobile: 244-1674 11/10/2008 • • Maunder, Thomas E (DOA) From: GPB, Well Integrity Engineer [ GPBWelllntegrityEngineer @bp.com] Sent: Friday, March 16, 2001 6:56 PM To: Maunder, Thomas E (DOA) Subject: Low OA Fluid Levels Hello Tom. During routine outer annulus bleed operations on well S -30, the fluid level in the 9 -5/8" x 13 -3/8" annulus was noted to be near the 13 -3/8" casing shoe. This initiated a review of wells Prudhoe Bay field -wide and the following wells have been identified with OA fluid levels near the surface casing shoe: - J -08: OA FL @ 2590', shoe @ 2691' 4 - S -25: OA FL @ 2526', shoe @ 2680' - S -30: OA FL @ 2544', shoe @ 2681' = � 846- - W -11: OA FL @ 3222', shoe @ 3217' - Z -10: OA FL @ 3190', shoe @ 3186' Evaluation is ongoing on these wells and we will keep you informed of progress. Please call if you have any questions. Joe sv« �s\�s ∎ �� Joe Anders, PE / Kevin Yeager a Well Integrity Engineer BP Exploration, Alaska Inc. c� (907) 659 -5102 - Work (907) 659 -5100, x1154 - Pager M MAR 1 0 all , 4 ? ~ ^ i ~ ~ 1 ~ ~ ~ ~ ~~ ~ a t f ..~< yf yy ~ 777 ~.,A I 1 j~ ` { / ~_ ~ "Y ~ ~ r , 11i F , 0,f . ALASS-A OIL AI~TD GAS CO1~T5ERQATIOr1T COMDIISSIOrT Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 SARAH 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, PBU J-08A BP Exploration Alaska Inc. Permit No: 208-120 Surface Location: 1148' FNL, 804' FEL, SEC. 09, T11N, R13E, UM Bottomhole Location: 5079' FSL, 1958' FWL, SEC. 03, 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 permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Comr:ussion 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 conditiorYS of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). ncerely, Daniel T. Seamount, Jr. i /j Chair DATED thi day of July, 2008 cc: Department of Fish & Game, Habitat Section w/o enc;. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N 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 propbs~~~te-: ~~' ^Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU J-08A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12553' TVD 9148' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028281 Pool FNL, 804 FEL, SEC. 09, T11 N, R13E, UM 1148 Top of Productive Horizon: 4173' FSL, 1504' FWL, SEC. 03, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 3, 2008 Total Depth: 5079' FSL, 1958' FWL, SEC. 03, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 11,700' 4b. Location of Well (State Base Plane Coordinates): Surface: x-643556 y- 5970205 Zone-ASP4 10. KB Elevation (Height above GL): 67' feet 15. Distance to Nearest Well Within Pool: 1,200' 16. Deviated Wells: Kickoff Depth: 3400 feet Maximum Hole An le: 65 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3180 Surface: 2300 18. Casin Pro ram: S ecifications To - Settin De th -Bottom uant~ of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MO TVD includin sta a data NIA 7" 26# L-80 TCII 4200' Surface Surface 4200' 4166' See Below 8-1/2" 7" 26# L-80 BTC-M 7207' 4200' 4166' 11407' 8623' 195 cu ft Class'G' 1106 cu ft LiteCrete 6-118" 4-1/2" 12.6# 13Cr80 Vam To 1296' 11257' 8530' 12553' 9148' 199 cu ft Class'G' 1 g. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 12544' Total Depth TVD (ft): 9157' Plugs (measured): 10809' Effective Depth MD (ft): 12501' Effective Depth TVD (ft): 9126' Junk (measured): -12435' Easing Length ize Cement Volume - MD D Conductor /Structural 110' 20" x 30" 213 cu ft Permafrost 110' 110' Surface 2691' 13-3/8" 5860 cu ft Permafrost II 4 Sta es 2691' 2691' Intermediate 11422' 9-5/8" 1439 cu ft Howco Li ht, 250 cu ft'G', 110 cu ft PF'C' 11422' 8404' Production Liner 1753' 7" 342 cu ft Class'G' 120 cu ft Class'G' 10791' - 12544' 8039' - 9157' Perforation Depth MD (ft): Below Plug: 12130' - 12410' Perforation Depth TVD (ft): 8867' - 9062' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the goi g is true and correct. Contact Frank Roach, 564-4373 Printed Name Gre Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4191 Date / J~ Terrie Hubble, 564-4628 ` Commission Use Oni Permit To Drill Numbern?~~/~~~ API Number: 50-029-20265-01-00 Permit Appr val See cover letter for Date: '~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained shales: ,._,/ Samples Req'd: ^ Yes ~No Mud Log Req'd: ,^~/Yes LrJ No ,~ ,,, ~ HZS Measures: Yes ^ No Directional Survey Req'd: LrI Yes ^ No Other: `` -- Q/ C7~ APPROVED BY THE COMMISSION Q 0 Date ,COMMISSIONER Form 10-401 Revised 12/ 005 ~ ~ ~ n - ~~ Submit In Duplicate 0 R ~\~,i To: Tom Maunder, Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Frank Roach, 2ES Drilling Engineer Date: June 26, 2008 Re: J-08A Sidetrack Permit to Drill Approval is requested for the proposed rotary side track of PBU well J-08. Well J-08 is an Ivishak producer that is currently shut-in due to IA x OA communication to gas. The well has been secured to the formation with an XX plug set at 10809' (CMIT Tx1A to 3500 psi passed 02/24/2008). Well J-08 was originally completed in September 1977 with a workover to downsize tubing in January 1991.. A damaged gas lift valve created T x IA communication in May, 1992. Multiple POGLM straddles have been run and pulled in an attempt to solve the communication problems from November 1996 to October, 2003. IA x OA communication surfaced in March, 2001 and well was waivered for IA x OA. T x IA communication issues were again seen in October 2005 and the IA x OA waiver was cancelled and well swapped to "trouble" status. During this time, nearby well R-13 was put on MI injection and reservoir engineering requested J-08 remain offtine. The J-08A sidetrack is currently scheduled for Nabors 2ES on August 3, 2008. J-08A Permit to Drill Application Page 1 ~~ Planned Well Summary r Well J-08A Well Producer Target Ivishak T e Rotary Sidetrack Ob'ective AFE Number: pgD 4P 2789 API Number: 50-029-20265-01- 00 Surface Northin Eastin Offsets TRS Location 5,970,205.5 643,556.4 4132' FSL / 804' FEL 11 N, 13E, 09 Target Northin Eastin Offsets TRS Locations 5,975,570 645,750 4172' FSL / 3776' FEL 11 N, 13E, 3 5,976,485 646,185 5079' FSL / 3321' FEL 11 N, 13E, 3 Bottom Northin Eastin Offsets TRS Location 5,976,485 646,185 5079' FSL / 3321' FEL 11 N, 13E, 3 Planned KOP: 3400'md / 3,398' tvd Planned TD: 12,553' and / 9,148' tvd Ri Nabors 2ES RTE: 28.5' Surface and Anti Collision Surface Shut-in Wells: Offset wells J-23 is ~33' & J-13 is -99' from each side of this J-08. Therefore, no wells require surface shut-in prior to moving onto the well. Close Approach Shut-in Wells: J-13 and J-24A do not pass BP major risk analysis due to current survey errors (wells have only original gyro runs from 1980 and 1987 respectively). Gyros will be run in these two wells pre-rig to reduce toot error and improve certainty. J-08A Permit to Drill Application Page 2 Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 '/:"Intermediate Hole Maximum anticipated BHP: 3,106 psi at 8,595' TVDss. Maximum surface pressure: 2,246 psi (based upon BHP and a full column of gas from TD @ 0.10 psi/ft) Calculated kick tolerance: 74 bbls with 12.5 pp EMW FIT and 11.0 g MW Planned BOPE test pressure: 250 psi low / 3,500 psi high 7 day test cycle (Pre drilling phase) 14 day test c cle (Drillin o erations) Well Interval: 61/8" roduction interval Maximum antici ated BHP: 3,180 si at 8,800' TVDss. Maximum surface ressure: 2,300 si (based a on BHP and a full column of as from TD 0.10 si/ft Calculated kick tolerance: Infinite with 8.8 EMW FIT. Planned BOPE test pressure: 250 psi low / 3,500 psi high 14 da test c cle (Drillin o erations) Planned com letion fluid: 8.6 seawater / 7.1 Diesel H2S J-Pad is not designated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading J-13 No record J-13 No record J-23A 20 ppm J-19 10 ppm Directional Program Kick Off Point 3,400 ft MD Maximum Hole Inclination: ~65° 11,828 ft MD. Proximity Issues: J-24A and J-13 do NOT currently pass major risk. All other wells pass major risk Surve Pro am: Standard MWD + IFRlMS/Cassandra Nearest Well within ool: Well J-13 1200' to the Southeast Nearest Pro ert Line 11,700' to Unit Boundary to the Southwest J-08A Permit to Drill Application Page 3 Logging Program • Hole Section: Re uired Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR/PWD 6 1/8" roduction: Real time MWD Dir/GR/Res/AzDen/Neutron Cased Hole: USIT\GR\CCL 9 5/8" Casin ) O en Hole: None lanned Mud Program Hole Section / o eration: Cut & Pull tubin .Set EZSV and Whipstock T e Densit MBT PV YP API FL H BRINE 8.6 N/A 9.0 -10.0 Hole Section / o eration: Millin 8 1/2" window at --3,400' and T e Densit Chlorides PV YP API FL H LSND 9.2 <1000 16-30 30 millin < 8.0 9.0 -10.0 Hole Section / o eration: Drillin 8 1/2" interval from 3,400' and to 8,835' and T e Densit Chlorides PV YP API FL H LSND 9.2 - 9.6 <1000 15-25 22-30 5.0 - 7.0 9.0 -10.0 Hole Section / o eration: Drillin 8 1 /2" interval from --8,835' and to 11,407' and T e Densit Chlorides PV YP API FL pH LSND 11.0 <1000 15-22 26-30 4.0 - 6.0 9.0 -10.0 Hole Section / o eration: Drillin 6 1/8" production interval to TD -12,553' and T pe Densit LSRV PV YP API FL pH FloPro SF 8.4 - 8.5 >20,000 8 -12 22 - 28 6 - 8 9.0 -10.0 Casing /Tubing Program Hole Size CasinglTubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd Cased 8 %2" 7" 26# L-80 TC-II 4200' Surface 4,200' / 4,166' 8 %2" 7" 26# L-80 BTC-M 7207' 4,200' /4,166' 11,407' / 8,623' 61/8" 4'h" 12.6# 13Cr-80 VamTOP 1296' 11,257' / 8,530' 12,553'/ 9,148' Tubing 4'/2" .12.6# 13Cr-80 VamTOP 11250' Surface 11,250' / 8,526' J-08A Permit to Drill Application Page 4 Casing /Formation Integrity Testing t. J Test Test Point Test Type Test pressure 9 5/8" casing with EZSV EZSV @ 3,650' 30 min recorded 3,500 psi surface 9 5/8" window (8 %2" OH) 20' new formation FIT 12.5 ppg EMW 7" casing shoe (6 1/8" OH) 20' new formation FIT 8.8 ppg EMW 4'/z" Tubing Packer @ 8,930' MD 30 min recorded 3,500 psi surface 4'/2" tbg x 7" csg annulus Tubing-Casing annulus from acker 8,930" MD 30 min recorded 3,500 psi surface w/1,500 si on Tb Cementing Program Casing String: 7" 26# L-80, BTC-M, Intermediate casing Lead slurry: 6761' of 7" x 8'h" annulus with 40% OH excess plus liner lap. Slurry Design Basis: Lead TOC @ -3,646; MD.~ ° Tail slurry: 1000 of 7 x 8 /z annulus with 40 /o OH excess plus -80 of 7" 26# casin shoe track. Tail TOC 10,407' MD. Spacer 30 bbls MudPush II at 11.0 ppg Fluids Sequence /Volume: Tail Slurry 15.8 ppg Class G - 34.7 bbl (1.17 cu ft/sk) 168 sx. Lead Slurry 11.0 ppg Lite Crete -196.9 bbl (3.35 cu ft/sk) 329 sx. Liner String: 4-1/2" 12.6# 13Cr-80, VamTOP, Production Liner Slurry Design Basis: Tail slurry: 1146' of 4-1 /2" x 6-1/8" annulus with 40% OH excess plus 150' of 7" liner la .Tail TOC 11,257' MD. Fluids Sequence /Volume: Spacer 30 bbls MudPush II at 12.0 ppg Tail Slurry 15.8 ppg Class G - 35.5 bbl (1.17 cu ft/sk) 171 sx. Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j ection. All Class I wastes are to be hauled to Pad 3 for dis osal. for in J-08A Permit to Drill Application Page 5 • Geologic Prognosis Formation Tops(TVDss) and Estimated Pore Pressures Est. Formation To s Uncertain Commercial Hydrocarbon Bearing Est. Pore Press. Est. Pore Press. Formation (TVDss eet) (Yes/No) Psi) ( EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re aired from surface to TD for all new wells SV4 2630 SV3 3085 SV2 3200 Kickoff 3398 SV1 3600 20 UG4 4050 20 UG3 4255 20 UG2 NA 20 UG1 5025 20 WS2 5320 20 WS1 5506 20 CM3 5685 20 CM2 NA NA CM1 6605 20 TH RZ 6985 20 BHRZ 7180 20 TJF 7610 20 TJE 7780 20 TJD 8040 TJC 8260 TJB 8390 Sa River 8555 20 Yes Shublik 8595 20 Yes TSAD / TZ46 8675 20 Yes 3180 psi 8800 TZ4A/42N 8750 20 Yes TCGL / TZ3 8815 20 Yes BCGLITZ2C 8880 20 Yes PGOC 8895 20 Yes POWC 8940 20 NA 25N / T26 8950 30 Possible MHOIHOT 8970 10 Yes/HO 22N / T2B 9030 20 Yes/HO OOWC 9038 10 No 21N 9080 20 No TZ1 B 9125 30 BTD No BSAD 9215 30 BTD TD Criteria: Reach planned TD unless drilling conditions deteriorate. Final TD TBD by both rig and town geologist. J-08A Permit to Drill Application Page 6 Fault Prognosis The J-08A side track will not cross any faults. No fault crossings are expected. Closest fault is 320' NE from BH location Fault Coordinates for Ma in X Y Fault #1 First Point 646,165 6,976,880 Fault #1 Second Point 646,495 5,976,745 Fault #1 Third Point 646,835 5,976,665 J-08A Permit to Drill Application Page 7 J-08A Operations Summary Current Status: - XX plug at 10809' MD. - CMIT - TxIA -Passed to liquid to 3500 psi (2/24/08) - MIT - OA -Passed to 2000 psi (2/24/08) Pre Riq Operations 1. E-LINE: Gyro J-13 from surface to 11,600' and J-24A from surface to 10,500' (for anti-collision). 2. SLICK: Pull XX plug at 10809' MD. Drift tubing through to IBP at 12,435' if possible (Note: equalizing prong fish somewhere below btm perfs). 3. COIL: Lay in 61 bbls of cement from IBP at 12,435' to 10' below 9-5/8 x 4-1/2" Otis production packer at 10,740' (TOC 10,750'). Volume of 7" from 12,435' to 4-1/2" WLEG @ 10,820': 0.0371 bpf, 1615' = 59.9 bbls Volume of 4-1/2" from 10,820' to 10,750': 0.0152 bpf, 70' = 1.1 bbls If unable to tag 12,435' due to fill or junk, contact ODE and discuss adjustment of cement volume to compensate for tagged bottom and potential for bullheading cement. Use squeeze pressure of 500 psi if operations allow. This plug is for zonal isolation. SBHP: 3212 psi @ 8900' TVDSS SBHT: 212 °F @ 8900' TVDSS 4. E-LINE: Punch tubing @ 10,700'. Tubing punch holes used to circulate well dead. 5. FULLBORE: Circ well dead. CMIT TxIA to 3,500 psi. Pressure test required to prove abandon plug. If test fails, contact ODE. 5. E-LINE: Drift tubing to top of GL straddle assembly @ 3,715'. Power Jet cut tubing @ 3,665'. 6. FULLBORE: CMIT TxIA to 3,500 psi. MITOA to 2,000 psi. Tests required to prove barriers to allow rig to MIRU. Freeze protect tubing with diesel to 2200' TVD. Bleed casing and annulus pressures to zero. 7. WELLHEAD: Function tubing and casing LDS. Repair/replace as required. 8. OTHER: Set a BPV. Remove well house and flow line. Level pad as necessary. Note: PPPOT-T (5000 psi) and PPPOT-IC (3500 psi) passed on 2/19/08. Riq Operations 1. Move in. Rig up Nabors rig 2ES. 2. Pull BPV. Circulate out freeze protection and displace with seawater. 3. Run TWC and test to 1000 psi. 4. Nipple down tree. Nipple up BOPE. 5. Test ROPE to 3500 psi high, 250 psi low. Pull TWC. 6. Screw in landing joint. Unseat and pull 4-1 /2" tubing hanger to floor 7. Circulate well, surface to surface. 8. Lay down landing joint and hanger. ~~ W 9. Pull 4-1 /2" tbg to cut at --3700' MD. Spool up control line. Count bands and clamps. 10. Set test plug and test lower set of pipe rams. 11. Pick up and RIH with scraper to 3600' MD. 12. RU E-line. Run USIT/GR/CCL from cut stub to surface. 13. RU Eline. RIH with EZSV. Set @ 3450' MD. POOH. RD Eline. 14. Test 9-5/8" casing to 3500 psi for 30 minutes. Chart test. 15. PU and RIH with whipstock. 16. Orient and set WS at -3400' MD. 17. Displace to 9.2 ppQ LSND milliner fluid. 19. ~+ 20. ,~ 21. ~~1~~ 22. 23. ~~~~ 24. 25. 26. 27. 28. Mill window +20'. Pump a sweep. FIT to 12.5 ppg. POOH, LD window milling assembly. PU 8-1/2" drilling BHA. RIH. Drill to TD, increasing mud weight to 11.0 ppg prior to entering the HRZ. At TD, Circulate sweep. Short trip to the window. Circulate sweep. POH and LD BHA. Change rams to 7" fixed. Test same Rig up casing running equipment. Run 7" 26# casing. Circulate bottoms up at the window. Continue in to TD. Circulate hole prior to cement. Cement casing in place. Change out 9-5/8" packoffs. Test packoff void to 3500 psi. Change 7" rams to 3-1/2" x 6" VBR's. Test same. J-08A Permit to Drill Application Page 8 i • d ~~ `' 29. Drill out ti~shoetrack and pressure test to 3500 psi. Chart same. 30. Pull RBP. 31. MU and RIH with 6-1/8" BHA to top of liner. Circulate bottoms up. 32. Test 7" liner to 3500 psi for 30 minutes. Chart same. 33. Drill cement and float equipment. Displace well to Flo Pro drilling fluid. 34. Drill 20'. Perform FIT (8.8ppg). 35. Drill ahead, per directional proposal and rig site geologist, to well TD at approximately 12,553' MD. 36. Circulate sweep. Short trip. Circulate sweep. POOH, LD BHA. 37. PU and MU 4-1/2" liner. 38. RIH with 4-1/2" liner on DP. 39. RU cement equipment. Circulate liner at TD. 40. Cement liner in place. Set liner hanger/packer and pressure test to 3500 psi. Chart same. 41. POH, LDDP. 42. RU to run tubing. 43. Run 4-1/2" 13CR-80 completion. 44. Space out and land tubing. 45. Reverse in corrosion inhibited brine 46. Set packer. Individually test the tubing and annulus to 3500 psi for 30 minutes. 47. Nipple down the BOPE. Nipple up the tree. 48. Freeze protect the well to 2200' TVD. Install BPV. 49. RDMO. Release rig. Post Rig Operations 1. Pull the ball and rod / RHC plug. 2. Perforate 100' with a-line 3. Install gas lift valves 4. Install well house and instrumentation. 5. "S" riser modifications will be required. J-08A Permit to Drill Application Page 9 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control Cretaceous injection pressures up to 9.1 ppg may be encountered from the top of the UG1 to the base of the West Sak formation. For the production interval of the well, the Ivishak reservoir is expected to be pressured to 7.0 ppg EMW. II. Lost Circulation/Faults The J-08A side track will not cross any faults. No fault crossings are expected. III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for the intermediate hole section is 74 bbls with 11.0 ppg mud, 12.5 ppg FIT, and an 9.1 ppg pore pressure at the casing shoe. This FIT should prove up adequate formation strength for expected ECD's. B. The Kick Tolerance for the production hole section is infinite with 8.6 ppg mud, 8.8 ppg FIT, and an 7.1 ppg pore pressure. This FIT should prove up adequate formation strength for expected ECD's. IV. Integrity Testing Test Point Test Depth Test type EMW Ib/ al 8 %2" KO 20-ft min new formation FIT 12.5 min 7" shoe 20-ft minimum from the 7" shoe FIT 8.8 min V. Stuck Pipe A. Stuck pipe not anticipated. B. There could be slight differential sticking issues within the reservoir, though risk is considered minimal. VI. Hydrogen Sulfide A. J-Pad is not an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading J-13 No record J-13 No record J-23A 20 ppm J-19 10 ppm VIII. Anti-Collision Issues With the J-23 being ~33' 8~ J-13 being ~99' from each side of this location, no surface shut- ins will be required to move onto this well. Close Approach Shut-in Wells: J-13 and J-24A fail major risk scan. Gyro runs will be performed on both wells to lower tool error and increase certainty. J-24, J-24APB1, and J- 24APB2 wells pass a Minor Risk scan at 1/167. All other wells have passed the major risk scan and the close approaches for these wells are all "in-zone" and pose no major risk to people or the environment in the event of a well collision incident. Reference the Anti-collision report in the directional plan for a full list of offset well paths. J-08A Permit to Drill Application Page 10 TREE= 6" CAMERON WELLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 67.00' BF. ELEV = 40.13' KOP = 3400' Max Angle = 61 (a3 8300' Datum MD = 12129 Datum TV D = 8800' SS PERFORAT~N SUMMARY REF LOG: BRCS ON 09/1987 ANGLE AT TOP PERF: 47 Q 12130' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpniSgz DATE 3-3/8" 6 12130 - 12180 O Varous 3-318" 4 12185 - 12195 O 08/11/90 3-3/8" 4 12196 - 12232 O Various 3-3/8" 4 12236 - 12266 O 03/09/90 3-3/8" 4 12276 - 12280 S 06/23/89 3-3/8" 4 12280 - 12290 O 07/18/89 3-3/8" 4 12290 - 12306 S 06/23/89 3-3/8" 4 12318 - 12330 S 06/23/89 3-3/8" 4 12360 - 12410 O 07/18/89 ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3725 3644 20 CAM DMY BK" 0 10/14/03 4 6316 5362 55 CAM RK 3 8506 6667 60 CAM RK 2 10537 7812 55 CAM RK 1 10643 7873 55 CAM RK *'ST# 5 BROKEN. STRADDLE SET=2-318" GLM w/1" DGLV 10818' H.MD TT LOGGED 10/10/93 DATE REV BY COMMENTS DATE REV BY COMMENTS 09!77 ORIGINAL COMPLETION 03/04/06 RCT/PJC SET XX PLUG Q 10809' 01/22191 RWO 03/09/Ofi RCTITLH XX PLUG CORRECT~N 08/04/03 MH/TLP PULL GL STRADDLE ~ 3718' 05129/06 CO/DTM PERF CORRECTIONS (6!13/04) 10/29/03 CJS/TLH GL STRADDLE CORRECTION 09/22/05 TWS/TLH FISH (EQUALIZAVG PRONG) 01/16!06 COMIPA WANERSFTY NOTEDElETEO PRUDHOE BAY UNPf WELL: J-08 PERMIT No: 1770470 API No: 50-029-20265-00 SEC 9, 711 N, R13E, 804' FEL & 1148' FM1N. BP Exploration (Alaska) J -O ~ ~ O ~~ TES. *"'* TROUBLE WELL - DO NOT DATE REV BY COMMENTS DATE REV BY COMMENTS 09/77 ORIGINAL COMPLETION 03!04/O6 RCT/PJC SEf XX PLUG @ 10809' 01!22!91 RWO 03!09!06 RCT/TLH XX PLUG CORRECTION 08!04/03 MH/TLP PULL GL STRADDLE @ 3718' 05!29!06 CO(DTM PERF CORRECTIONS (6113!04) 10!29103 CJS/TLH GL STRADDLE CORRECTION 06/24!08 FVRf2-ES ROTARY SIDETRACK 09/22/05 TWSlTLH FISH {EQUALIZING PRONG) 01/16/06 CObVPA WAIV ER SFTY NOTE DELETE PRUOtiOE BAY UNff WELL: J-OSA PERMIT Na: X1770470 API No: 50-029-20265-01 SEC 9. T11 N, R13E, 804' FEL 81148' FNL BP Exploration (Alaska) COMPANY DETAILS L.'. BP Amoco Iculation Method: Minimum Ci REFERENCE WFORMATION Co-ordinate IN/E) Reference: Well Centre: J-ll%, True North Vertical (TVD) Rekrcnce: 39.SGL+2%.5 6%.UII Section lVSl Reference: Slot-O%(ILfNIN,l1.1111E) Measured Depth Reference: 39.SGL+2%.5 6N.IIU Calculation Method: Minimum Curvature ..,. __.-- - - °0 0 6000 7000 FORMATION TOP DETAILS No. TVDPath MDPath Formation ^ - 1 3653.00 3658.17 S V I ~~ _ - 2 4118.00 4145.92 UG4 3 4323.00 4385.62 UG3 ? , ~-' 4 5093.00 5585.62 UGI ~ 5 5388.00 6074.87 WS2 -- i , 6 5574.00 6383.35 WSI --' ~' 7 5753.00 6680.21 CM3 ~ 8 6673.00 8206.01 CM I ~ - - - 9 7053.00 8836.23 THRZ ____ - _ - 10 7248.00 9159.63 BHRZ ' - 11 7678.00 9871.51 TJF - 12 7848.00 10147.99 TJE - ~ --~ -- -- -- --- -- ---- 13 8108.00 10570.48 TJD - ~-- `~ --~ 14 8328.00 10927.98 TIC --~ -~ - -_ IS 8458.00 11139.23 TJB 16 8623.00 1140736 Sag River 4 ~ ~.. 17 8663.00 11472.96 Shublik -_ _~ I8 8743.00 11614.82 TSAD / TZ46 ~_ _ ~~~~~-~ ~ 19 8818.00 11767.55 TZ4A/42N i I -- - I 20 8883.00 11920.35 TCGL / TZ3 ~.. _ . I ~ 21 8948.00 12075.48 BC'GL/TZ2C I 22 8963.00 12111.28 PGOC ~ _ `~. 23 9001.00 12201.98 POW'C' '.~- _ _ 24 9018.00 1242.56 ~ 25N / T_B ! s 4 _-_ _ _ _ _- 25 9038.00 12_90.29 MHO/HOT ._ -___ _ ~ 26 9098.00 12433.50 22N / T28 27 9106.00 12452.59 OOWC 28 9148.00 12552.83 21N TARGET DETAILS Name TVD +N'-S +E.=W Northing Easting Shape 1-08A TI 8623.00 5322.01 2296.00 5975570.00 645750.01 Poim 1-08A T2 9148.00 6228.59 2748.46 5976485.00 646185.01 Point J-O8A Geo-poly 9148.00 6228.59 2748.46 5976485.00 646185.01 Polygon SURVEY PROGRAM Fm Depth To Survey/Plan Tool Plan: J-OSA Wp 2.0 (1-O8iPlan J-O8A) ~ 12552.%3 Planned: 1-OriA Wp 2.11 V 13 MWD+IFR+MS Created By: Sperry Drilling Date: 2%2512008 WELL DETAILS Name +N/-S +E/-W Northing Ea stiog Latitude Longitude Slot 1-U ri 1935.N% 2437.fi5 597112115,45 fi4355fi.42 7U"19'33.%%I1N 148"511'11%A37W UN Sec MD Inc Azi S TVD E TI N +N/-S DETAIL +Ei-W DLeg TFace VSec Target 1 3400.00 9.69 303.79 3397.71 6.71 -39.24 0.00 0.00 -9.70 2 3420.00 10.19 317.44 3417.41 8.95 -41.63 12.00 85.00 -8.70 3 3720.00 9.47 32.86 3714.09 49.37 -46.40 4.00 130.00 26.44 4 4812.15 52.92 20.79 4626.63 556.96 167.48 4.00 -13.97 577.17 5 6 9725.11 10007.36 52.92 52.02 20.79 35.00 7588.96 7761.46 4221.05 44!8.06 1558.94 1663.05 0.00 0.00 4491.15 4.00 98.87 4713.42 7 11407.36 52.02 35.00 8623.00 5322.01 X296.00 0.00 0.00 5795.95 J-08A T1 8 1143236 52.02 35.00 8638.38 5338.15 2307.30 0.00 0.00 5815.29 9 11827.94 65.23 24.74 8844.29 5630.83 2472.95 4.00 -36.36 6149.93 10 12552.83 65.23 24.74 9148.00 6228.59 2748.46 0.00 0.00 6808.04 J-08A T2 _ _ HALLIBURTON __ _ --~--- BCG 1 4000 500 Vertical Section at '_3.81° [IOOOf~in] ~~ ~ ~ CASING DETAILS 6000 No. TVD MD Name Size 1 8623.00 11407.35 7" Z(01 2 9147.99 12552.80 4 V2" 4.500 COMPANY DETAILS 8P Amoco Co Calculation Method: Minimum Curvature Ertor System: ISCWSA h Scan Method: Trav Cylinder North Error Surface: Elliptical+Casing W aming Method: Rules Based HALLI~lJRTC~N Sperry Grilling Slervicas - REFERENCE INFORMATION SURVEY PROGRAM 'E) Reference: Well Centre: J-0%, True North Depth Fm Depth To Survey/Plan 'DI Reference: 39.5GL+2%.5 fi%.1111 /S) Reference: Slot - U8 (OIION,0.110E) 3400.IX1 12552.83 Planned: J-U8A Wp 2.11 V 13 nth Reference: 39.gGL+28.5 68.1X1 lation Method: Minimum Curvature 1-08A W 2.0 ~~ otal Depth : 12552.83' M , 9148' TVD J-O8A Geo-Poly ~ - _~ ~-- _._. -- I I I I s `2 ~ 3 r 0 N 104 __ I I ---1 _-.-, ~~ - -~-i 1 1 1 1 1 1 I I I I I I I I I -2081 -1041 0 1041 2061 West(-); Easl Tool ( Plan: 1-08A Wp 2.11(1418/Plan 1-0%A) MWD+IFR+MS Creared By: Sperry Drilling Date: 2/25/2WR WELL DETAILS Name +N/-S +FJ-W Northing Fasting Latitude Longitude Slot J-O8 1935.%8 2437.fi5 597U205.45 fi43556.42 70"19'33.%811N 148"50'11%.937W 11% i % c onf. - - --- - --- - FORMATION TOP DETAILS No. TVDPath MDPath Formative --- .- 1 3653.00 3658.17 SVI 2 41 18.00 4145.92 UG4 - _ 3 4323.00 4385.(12 UG3 _ - ~ - ~ 4 5093.00 5585.62 UGI -- ---~-_ -' --~~~ -~ ~ -- ""- I - S 5388.00 6074.87 WS2 - ~ ---° --- ~ ~ ~ --- ~ - 6 5574.00 6383.35 WSI ~ ~ ' I - 7 5753 00 668Q21 CM3 '' I I ~ ~ ~' ' ~ I . 8 6673.00 8206.01 CMI _.__ .~ ~_- ._ -.._:..._ 9 7053.00 8836.23 THRZ .. - - 10 7248.00 9159.63 BHRZ _ _ ___.,___,_ - _ _ _ ll 7678.00 9871,51 TJF _ _ _ _ 12 7848.00 10147.99 TJE 13 8108.00 10570.48 TJD - __._ _. - - 14 6328.00 1092. 8 - ---'-- _-~ - ~ - - - IS 8458.00 11139.23 T]B - ~ -- ~--- - - -~- - - --- -~- - ~-~-~ ~ - ~ - 16 8623.00 11407.36 00 11472 96 17 8663 Sag River Shublik -~-~ ~--! - - --- - r ----~ ! ~ - r '' I - ~ - . . I8 6743.00 11614.82 TS.AD ~ TZ4B , - -. __ ~~...___- -__1 _-. _-_. 19 8818.00 11767.55 TZ4A,42N _ _-_ .._ __-- ___ _-._ 20 8883.00 11920.35 TCGLTZ3 _ - 21 8948.00 12075.48 BCGL~TZ2C 22 8963.00 12111.28 PGOC _ _ _ _ - ____ -_ ____ - _ _ -_ 23 9001.00 12201.98 POWC ' 24 9018.00 12242.56 _SN ~ T2B - ~ ~ ~ - - -_ _- 25 9036.00 12290.29 MHO~HOT ---- --- ----- ----- ~ - - - --- 26 9098.00 12433.50 22N T26 --- - - - - ~ T+------ - - - -- 27 9106.00 12452.59 OOWC ~ ~ .. I ~ _ 28 9148.00 12552.83 21N -tirt -. _. _ ~ .~_ CASING DETAILS - - - - - No. TVD MD Name Size - - ~ I 862 3.00 11407.35 7" 7.000 2 9147.99 12552.80 4112" 4.500 TARGET DETAILS Name TVD +N;-S +E~-W Northing Easing Shape J-08A Tl 8623.00 5322.01 2296.00 5975570.00 645750.01 Point 1-08-0 T2 9148.00 6228.59 2748.46 5976485.00 646185.01 Point J-08A Geo-poly 9148.00 6228.59 2748.46 5976485.00 646185.01 Polygon SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W Dl.eg TFace VSec Target 1 341111.U0 9.69 J(13.79 3397.71 fi.71 -39.24 O.W 0.(NI -9.7(1 2 3421LUU IU.19 317.44 3417.41 8.95 -41.83 12.(X1 RSAU -8.70 3 37211.1X1 9.47 32.86 3714.1X1 49.37 -46.40 4.00 13QU0 26.44 4 4%12.15 52.92 2U.79 4626.63 556.96 167.48 4.W -13.97 577.17 5 9725.11 52.92 211.79 75%X.96 422LU5 155%.94 O.W 0.011 4491.15 6 IINI/17.3h 52.U2 350(1 7761.46 4418.06 Ifi63.115 4.W 98.87 4713.42 7 114117.36 52.112 3511(1 N623.IX1 5322-01 229fi.W O.IN) O.fNI 5795.95 141%A TI % 11432.3h 82.(12 J5.IN1 86]8.3% 833%.IS 23U7.3U O.INI 0.1X1 5815.29 9 I1%27.94 fi5.23 24.74 8844.29 Sfi3U.%3 2472.95 4.1X1 -3fi.36 fiI49.93 IU 12552.83 65.23 24.74 9148.U(1 6228.59 274X.4fi O.W 0.00 fi%UN.04 J-ONA T2 Sperry-Sun BP Planning Report Companyi BP Amoco Date: 2/25/2008 Time: 12:22:12 Page: ' 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: J-0$ True North Site: PB J Pad Vertical (TVD) Reference: 39.5GL+28.5 68.0 Well: J-08 Section (VS) Reference: Well (O.OON,O.OOE,23.81 Azi) Wellpath: Plan J-08A SurveyCalculation Method: Minimum Curvature Db: OraGe Plan: J-08A Wp 2.0 Date Composed: 2/25/2008 Version: 13 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB J Pad TR-11-13 UNITED STATES :North Sl ope Site Position: Northing: 5968224.22 ft Latitude: 70 19 14.845 N From: Map Easting: 641155.79 ft Longitude: 148 51 20.092 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.08 deg Well: J-08 Slot Name: 08 J-08 Well Position: +N/-S 1935.88 ft Northing: 5970205.45 ft Latitude: 70 19 33.880 N +E/-W 2437.65 ft Easting : 643556.42 ft Longitude: 148 50 8.937 W Position Uncertainty: 0.00 ft Casing Points MD TVD biameter Hole Size Name ft ft in in 11407.35 8623.00 7.000 8.500 7" 12552.80 9147.99 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 SV4 0.00 0.00 0.00 SV3 0.00 0.00 0.00 SV2 0.00 0.00 3658.17 3653.00 SV1 0.00 0.00 4145.92 4118.00 UG4 0.00 0.00 4385.62 4323.00 UG3 0.00 0.00 5585.62 5093.00 UG1 0.00 0.00 6074.87 5388.00 WS2 0.00 0.00 6383.35 5574.00 WS1 0.00 0.00 6680.21 5753.00 CM3 0.00 0.00 8206.01 6673.00 CM1 0.00 0.00 8836.23 7053.00 THRZ 0.00 0.00 9159.63 7248.00 BHRZ 0.00 0.00 9871.51 7678.00 TJ F 0.00 0.00 10147.99 7848.00 TJ E 0.00 0.00 10570.48 8108.00 TJD 0.00 0.00 10927.98 8328.00 TJC 0.00 0.00 11139.23 8458.00 TJB 0.00 0.00 11407.36 8623.00 Sag River 0.00 0.00 11472.96 8663.00 Shublik 0.00 0.00 11614.82 8743.00 TSAD / TZ46 0.00 0.00 11767.55 8818.00 TZ4A/42N 0.00 0.00 11920.35 8883.00 TCGL / TZ3 0.00 0.00 12075.48 8948.00 BCGlJTZ2C 0.00 0.00 12111.28 8963.00 PGOC 0.00 0.00 12201.98 9001.00 POWC 0.00 0.00 12242.56 9018.00 25N / T26 0.00 0.00 12290.29 9038.00 MHO/HOT 0.00 0.00 12433.50 9098.00 22N / T26 0.00 0.00 12452.59 9106.00 OOWC 0.00 0.00 12552.83 9148.00 21 N 0.00 0.00 0.00 TZ1 B 0.00 0.00 Sperry-Sun BP Planning Report Company: BP Amoco Date: 2/25/2008 Time. 12:22:12 Pagc : 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: J-08, True North Site: PB J Pad Vertical (TW) Reference: 39. 5GL+28.5 68.0 Well:. J-08 Section (VS) Referenced Well (O.OON,O:OOE,23.81Azi) Wellpath: Plan J-08A Survey Calculation Method: Minimum Curvature Db: OraGe Targets -- Map Map _ ~--- Latitude ~> <__ Longih~de __> Name Description TV D +N/-S +E/-W Northing Fasting Deg :Min -Sec Deg Ali n Sec Dip. Dir. ft ft ft ft ft J-08A T1 8623.00 5322.01 2296.00 5975570.00 645750.01 70 20 26.218 N 148 49 1.869 W -Plan hit target. J-08A T2 9148. 00 6228.59 2748.46 5976485.00 6461 85.01 70 20 35.133 N 148 48 48.642 W -Plan hit target J-08A Geo-poly 9148. 00 6228.59 2748.46 5976485.00 6461 85.01 70 20 35.133 N 148 48 48.642 W -Polygon 1 9148. 00 5437.02 2558.27 5975690.00 646010.01 70 20 27.349 N 148 48 54.206 W -Polygon 2 9148. 00 6107.00 3091.22 5976370.00 646530.01 70 20 33.936 N 148 48 38.630 W -Polygon 3 9148. 00 6384.12 2461.36 5976635.00 645895.01 70 20 36.664 N 148 48 57.028 W -Polygon 4 9148. 00 5543.99 2195.22 5975790.00 645645.01 70 20 28.402 N 148 49 4.811 W -Plan hit target Plan Section Information MI) Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO .Target ft deg: deg ft , ft ft deg/100ft deg/100ft deg7100ft deg --- 3400.00 9.69 303.79 3397.71 6.71 -39.24 0.00 0.00 0.00 0.00 3420.00 10.19 317.44 3417.41 8.95 -41.83 12.00 2.45 68.22 85.00 3720.00 9.47 32.86 3714.09 49.37 -46.40 4.00 -0.24 25.14 130.00 4812.15 52.92 20.79 4626.63 556.96 167.48 4.00 3.98 -1.10 -13.97 9725.11 52.92 20.79 7588.96 4221.05 1558.94 0.00 0.00 0.00 0.00 10007.36 52.02 35.00 7761.46 4418.06 1663.05 4.00 -0.32 5.03 98.87 11407.36 52.02 35.00 8623.00 5322.01 2296.00 0.00 0.00 0.00 0.00 J-O8A T1 11432.36 52.02 35.00 8638.38 5338.15 2307.30 0.00 0.00 0.00 0.00 11827.94 65.23 24.74 8844.29 5630.83 2472.95 4.00 3.34 -2.59 -36.36 12552.83 65.23 24.74 9148.00 6228.59 2748.46 0.00 0.00 0.00 0.00 J-08A T2 Survey MD Incl Azim. TVD Sys TVD VS N/S E1W DLS MapN MapE TooUCo ft deg ' deg ft ft ft ft fit deg/100ft ft ft 3400.00 9.69 303.79 3397.71 3329.71 -9.70 6.71 -39.24 0.00 5970211.41 643517.06 Start Dir 1 3420.00 10.19 317.44 3417.41 3349.41 -8.70 8.95 -41.83 12.00 5970213.60 643514.42 Start Dir 4° 1 3500.00 8.49 334.28 3496.37 3428.37 -2.03 19.48 -49.18 4.00 5970223.98 643506.88 MWD+IFR 3600.00 7.81 2.40 3595.40 3527.40 9.08 32.92 -52.10 4.00 5970237.37 643503.70 MWD+IFR 3658.17 8.32 18.64 3653.00 3585.00 16.96 40.86 -50.59 4.00 5970245.33 643505.06 SV1 3700.00 9.04 28.66 3694.35 3626.35 23.25 46.61 -48.05 4.00 5970251.13 643507.49 MWD+IFR 3720.00 9.47 32.86 3714.09 3646.09 26.44 49.37 -46.40 4.00 5970253.92 643509.09 3800.00 12.60 29.32 3792.60 3724.60 41.63 62.51 -38.55 4.00 5970267.21 643516.68 MWD+IFR 3900.00 16.55 26.76 3889.36 3821.36 66.72 84.75 -26.79 4.00 5970289.67 643528.01 MWD+IFR 4000.00 20.52 25.17 3984.16 3916.16 98.48 113.34 -12.92 4.00 5970318.51 643541.33 MWD+IFR 4100.00 24.50 24.08 4076.52 4008.52 136.74 148.14 3.00 4.00 5970353.61 643556.58 MWD+IFR 4145.92 26.33 23.68 4118.00 4050.00 156.45 166.16 10.97 4.00 5970371.78 643564.21 UG4 4200.00 28.48 23.27 4166.01 4098.01 181.34 188.99 20.88 4.00 5970394.79 643573.68 MWD+IFR 4300.00 32.47 22.65 4252.18 4184.18 232.04 235.68 40.65 4.00 5970441.85 643592.55 MWD+IFR 4385.62 35.88 22.22 4323.00 4255.00 280.11 280.14 59.00 4.00 5970486.64 643610.04 UG3 4400.00 36.46 22.16 4334.61 4266.61 288.59 287.99 62.20 4.00 5970494.56 643613.10 MWD+IFR 4500.00 40.45 21.75 4412.90 4344.90 350.74 345.67 85.44 4.00 5970552.66 643635.22 MWD+IFR 4600.00 44.44 21.40 4486.68 4418.68 418.16 408.42 110.24 4.00 5970615.87 643658.81 MWD+IFR 4700.00 48.44 21.09 4555.58 4487.58 490.54 475.95 136.48 4.00 5970683.89 643683.76 MWD+IFR 4800.00 52.43 20.83 4619.26 4551.26 567.52 547.93 164.05 4.00 5970756.37 643709.94 MWD+IFR 4812.15 52.92 20.79 4626.63 4558.63 577.17 556.96 167.48 4.00 5970765.47 643713.20 End Dir 4900.00 52.92 20.79 4679.60 4611.60 647.15 622.48 192.36 0.00 5970831.45 643736.82 MWD+IFR 5000.00 52.92 20.79 4739.89 4671.89 726.82 697.06 220.68 0.00 5970906.55 643763.71 MWD+IFR 5100.00 52.92 20.79 4800.19 4732.19 806.49 771.64 249.01 0.00 5970981.65 643790.60 MWD+IFR 5200.00 52.92 20.79 4860.49 4792.49 886.15 846.22 277.33 0.00 5971056.75 643817.49 MWD+IFR 5300.00 52.92 20.79 4920.78 4852.78 965.82 920.80 305.65 0.00 5971131.86 643844.37 MWD+IFR 5400.00 52.92 20.79 4981.08 4913.08 1045.49 995.38 333.97 0.00 5971206.96 643871.26 MWD+IFR 5500.00 52.92 20.79 5041.38 4973.38 1125.15 1069.96 362.29 0.00 5971282.06 643898.15 MWD+IFR lent • Sperry-Sun BP Planning Report Company: BP Amoco Date: 2/25/200$ Time: 12:22:12 Page: 3 Field: Prudhoe Bay Co-ordinate(N E) Reference: Well: J-08, True Nort h Site: PB J Pad Vertical (1'VD ) Reference: 39. 5GL+28.5 68.0 Well: J-08 Section (VS) Referencet WeH (O;OON,O.OOE,2 3.81Azi) Wellpathc Pla n J-08A Survey Calculation Method:. Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SysTVD VS N/S E/W : DL5 MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/900ft ft ft 5585.62 52. 92 20.79 5093.00 5025.00 1193.36 1133.81 386.54 0.00 5971346.36 643921.17 UG1 5600.00 52. 92 20.79 5101.67 5033.67 1204.82 1144.54 390.62 0.00 5971357.17 643925.04 MWD+IFR 5700.00 52. 92 20.79 5161.97 5093.97 1284.49 1219.12 418.94 0.00 5971432.27 643951.93 MWD+IFR 5800.00 52. 92 20.79 5222.26 5154.26 1364.15 1293.70 447.26 0.00 5971507.37 643978.81 MWD+IFR 5900.00 52. 92 20.79 5282.56 5214.56 1443.82 1368.28 475.58 0.00 5971582.47 644005.70 MWD+IFR 6000.00 52. 92 20.79 5342.86 5274.86 1523.49 1442.86 503.90 0.00 5971657.58 644032.59 MWD+IFR 6074.87 52. 92 20.79 5388.00 5320.00 1583.13 1498.70 525.11 0.00 5971713.80 644052.72 WS2 6100.00 52. 92 20.79 5403.15 5335.15 1603.15 1517.44 532.23 0.00 5971732.68 644059.48 MWD+IFR 6200.00 52. 92 20.79 5463.45 5395.45 1682.82 1592.02 560.55 0.00 5971807.78 644086.37 MWD+IFR 6300.00 52. 92 20.79 5523.75 5455.75 1762.48 1666.60 588.87 0.00 5971882.88 644113.25 MWD+IFR 6383.35 52. 92 20.79 5574.00 5506.00 1828.88 1728.76 612.48 0.00 5971945.48 644135.66 WS1 6400.00 52. 92 20.79 5584.04 5516.04 1842.15 1741.18 617.19 0.00 5971957.99 644140.14 MWD+IFR 6500.00 52. 92 20.79 5644.34 5576.34 1921.82 1815.76 645.52 0.00 5972033.09 644167.03 MWD+IFR 6600.00 52. 92 20.79 5704.64 5636.64 2001.48 1890.34 673.84 0.00 5972108.19 644193.92 MWD+IFR 6680.21 52. 92 20.79 5753.00 5685.00 2065.39 1950.16 696.56 0.00 5972168.43 644215.49 CM3 6700.00 52. 92 20.79 5764.93 5696.93 2081.15 1964.92 702.16 0.00 5972183.29 644220.81 MWD+IFR 6800.00 52. 92 20.79 5825.23 5757.23 2160.82 2039.50 730.48 0.00 5972258.40 644247.69 MWD+IFR 6900.00 52. 92 20.79 5885.52 5817.52 2240.48 2114.08 758.80 0.00 5972333.50 644274.58 MWD+IFR 7000.00 52. 92 20.79 5945.82 5877.82 2320.15 2188.66 787.13 0.00 5972408.60 644301.47 MWD+IFR 7100.00 52. 92 20.79 6006.12 5938.12 2399.82 2263.24 815.45 0.00 5972483.70 644328.36 MWD+IFR 7200.00 52. 92 20.79 6066.41 5998.41 2479.48 2337.82 843.77 0.00 5972558.81 644355.25 MWD+IFR 7300.00 52. 92 20.79 6126.71 6058.71 2559.15 2412.40 872.09 0.00 5972633.91 644382.13 MWD+IFR 7400.00 52. 92 20.79 6187.01 6119.01 2638.81 2486.98 900.42 0.00 5972709.01 644409.02 MWD+IFR 7500.00 52. 92 20.79 6247.30 6179.30 2718.48 2561.56 928.74 0.00 5972784.12 644435.91 MWD+IFR 7600.00 52 .92 20.79 6307.60 6239.60 2798.15 2636.14 957.06 0.00 5972859.22 644462.80 MWD+IFR 7700.00 52 .92 20.79 6367.89 6299.89 2877.81 2710.72 985.38 0.00 5972934.32 644489.69 MWD+IFR 7800.00 52 .92 20.79 6428.19 6360.19 2957.48 2785.30 1013.70 0.00 5973009.42 644516.57 MWD+IFR 7900.00 52 .92 20.79 6488.49 6420.49 3037.15 2859.88 1042.03 0.00 5973084.53 644543.46 MWD+IFR 8000.00 52 .92 20.79 6548.78 6480.78 3116.81 2934.46 1070.35 0.00 5973159.63 644570.35 MWD+IFR 8100.00 52 .92 20.79 6609.08 6541.08 3196.48 3009.04 1098.67 0.00 5973234.73 644597.24 MWD+IFR 8200.00 52 .92 20.79 6669.38 6601.38 3276.15 3083.62 1126.99 0.00 5973309.83 644624.13 MWD+IFR 8206.01 52 .92 20.79 6673.00 6605.00 3280.93 3088.11 1128.69 0.00 5973314.35 644625.74 CM1 8300.00 52 .92 20.79 6729.67 6661.67 3355.81 3158.20 1155.32 0.00 5973384.94 644651.01 MWD+IFR 8400.00 52 .92 20.79 6789.97 6721.97 3435.48 3232.78 1183.64 0.00 5973460.04 644677.90 MWD+IFR 8500.00 52 .92 20.79 6850.27 6782.27 3515.14 3307.36 1211.96 0.00 5973535.14 644704.79 MWD+IFR 8600.00 52 .92 20.79 6910.56 6842.56 3594.81 3381.94 1240.28 0.00 5973610.24 644731.68 MWD+IFR 8700.00 52 .92 20.79 6970.86 6902.86 3674.48 3456.52 1268.60 0.00 5973685.35 644758.57 MWD+IFR 8800.00 52 .92 20.79 7031.15 6963.15 3754.14 3531.10 1296.93 0.00 5973760.45 644785.46 MWD+IFR 8836.23 52 .92 20.79 7053.00 6985.00 3783.01 3558.12 1307.19 0.00 5973787.66 644795.20 THRZ 8900.00 52 .92 20.79 7091.45 7023.45 3833.81 3605.68 1325.25 0.00 5973835.55 644812.34 MWD+IFR 9000.00 52 .92 20.79 7151.75 7083.75 3913.48 3680.26 1353.57 0.00 5973910.66 644839.23 MWD+IFR 9100.00 52 .92 20.79 7212.04 7144.04 3993.14 3754.85 1381.89 0.00 5973985.76 644866.12 MWD+IFR 9159.63 52 .92 20.79 7248.00 7180.00 4040.65 3799.32 1398.78 0.00 5974030.54 644882.15 BHRZ 9200.00 52 .92 20.79 7272.34 7204.34 4072.81 3829.43 1410.21 0.00 5974060.86 644893.01 MWD+IFR 9300.00 52 .92 20.79 7332.64 7264.64 4152.48 3904.01 1438.54 0.00 5974135.96 644919.90 MWD+IFR 9400.00 52 .92 20.79 7392.93 7324.93 4232.14 3978.59 1466.86 0.00 5974211.07 644946.78 MWD+IFR 9500.00 52 .92 20.79 7453.23 7385.23 4311.81 4053.17 1495.18 0.00 5974286.17 644973.67 MWD+IFR 9600.00 52 .92 20.79 7513.53 7445.53 4391.48 4127.75 1523.50 0.00 5974361.27 645000.56 MWD+fFR 9700.00 52 .92 20.79 7573.82 7505.82 4471.14 4202.33 1551.83 0.00 5974436.37 645027.45 MWD+IFR 9725.11 52 .92 20.79 7588.96 7520.96 4491.15 4221.05 1558.94 0.00 5974455.23 645034.20 Start Dir 4° 1 9800.00 52 .51 24.53 7634.34 7566.34 4550.70 4276.02 1581.88 4.00 5974510.63 645056.09 MWD+IFR 9871.51 52 .24 28.12 7678.00 7610.00 4607.27 4326.77 1606.99 4.00 5974561.84 645080.21 TJ F gent 1S 7S 7S 4S 9S 4S 4S Sperry-Sun BP Planning Report Company: BP Amoco Date: 2/25/2008 Time: 12:22:12 Page: 4 Field: Prudhoe Bay Co-ordinste(N E) Reference: WeII: J-0$ True North Site: PB J Pad Vertical (TVD) Reference: 39. 5GL+28.5 68.0 Well:: J-08 Section (VS) Reference: Well (11.00N,0:00E,23.$1Azi) Wellpath: Plan)-08A Survey.CalcutationMethod: Minimum.Curvature. Db: Oracle Survey MD Incl Azim TVD SysTVD VS N/S E/W DLS MapN MapE TooUCa ft deg deg ft ft ft ft ft deg/100ft ft ft 9900.00 52.16 29.56 7695.47 7627.47 4629.69 4346.50 1617.84 4.00 5974581.77 645090.69 MWD+IFR 10000.00 52.02 34.63 7756.93 7688.93 4707.72 4413.30 1659.74 4.00 5974649.36 645131.29 MWD+IFR 10007.36 52.02 35.00 7761.46 7693.46 4713.42 4418.06 1663.05 4.00 5974654.18 645134.51 End Dir : 1 10100.00 52.02 35.00 7818.47 7750.47 4785.05 4477.88 1704.93 0.00 5974714.78 645175.24 MWD+IFR 10147.99 52.02 35.00 7848.00 7780.00 4822.16 4508.86 1726.63 0.00 5974746.17 645196.34 TJ E 10200.00 52.02 35.00 7880.01 7812.01 4862.38 4542.45 1750.14 0.00 5974780.20 645219.21 MWD+IFR 10300.00 52.02 35.00 7941.55 7873.55 4939.70 4607.01 1795.35 0.00 5974845.62 645263.17 MWD+IFR 10400.00 52.02 35.00 8003.09 7935.09 5017.02 4671.58 1840.56 0.00 5974911.03 645307.13 MWD+IFR 10500.00 52.02 35.00 8064.62 7996.62 5094.35 4736.15 1885.77 0.00 5974976.45 645351.10 MWD+IFR 10570.48 52.02 35.00 8108.00 8040.00 5148.85 4781.66 1917.64 0.00 5975022.56 645382.09 TJD 10600.00 52.02 35.00 8126.16 8058.16 5171.67 4800.72 1930.99 0.00 5975041.86 645395.06 MWD+IFR 10700.00 52.02 35.00 8187.70 8119.70 5249.00 4865.28 1976.20 0.00 5975107.28 645439.02 MWD+IFR 10800.00 52.02 35.00 8249.24 8181.24 5326.32 4929.85 2021.41 0.00 5975172.69 645482.99 MWD+IFR 10900.00 52.02 35.00 8310.78 8242.78 5403.64 4994.42 2066.62 0.00 5975238.11 645526.95 MWD+IFR 10927.98 52.02 35.00 8328.00 8260.00 5425.28 5012.49 2079.27 0.00 5975256.42 645539.26 TJC 11000.00 52.02 35.00 8372.32 8304.32 5480.97 5058.99 2111.83 0.00 5975303.53 645570.92 MWD+IFR 11100.00 52.02 35.00 8433.86 8365.86 5558.29 5123.56 2157.04 0.00 5975368.94 645614.88 MWD+IFR 11139.23 52.02 35.00 8458.00 8390.00 5588.63 5148.89 2174.78 0.00 5975394.61 645632.13 TJB 11200.00 52.02 35.00 8495.39 8427.39 5635.62 5188.12 2202.25 0.00 5975434.36 645658.84 MWD+IFR 11300.00 52.02 35.00 8556.93 8488.93 5712.94 5252.69 2247.46 0.00 5975499.77 645702.81 MWD+IFR 11400.00 52.02 35.00 8618.47 8550.47 5790.27 5317.26 2292.67 0.00 5975565.19 645746.77 MWD+IFR 11407.36 52.02 35.00 8623.00 8555.00 5795.95 5322.01 2296.00 0.00 5975570.00 645750.01 J-08A T1 11432.36 52.02 35.00 8638.38 8570.38 5815.29 5338.15 2307.30 0.00 5975586.36 645761.00 Start Dir 4° 1 11472.96 53.33 33.80 8663.00 8595.00 5847.02 5364.79 2325.54 4.00 5975613.34 645778.72 Shublik 11500.00 54.22 33.02 8678.98 8610.98 5868.53 5383.00 2337.55 4.00 5975631.77 645790.38 MWD+IFR 11600.00 57.52 30.29 8735.09 8667.09 5950.51 5453.46 2380.95 4.00 5975703.04 645832.42 MWD+IFR 11614.82 58.01 29.91 8743.00 8675.00 5962.97 5464.30 2387.23 4.00 5975714.00 645838.50 TSAD / TZ 11700.00 60.87 27.76 8786.31 8718.31 6036.02 5528.56 2422.58 4.00 5975778.92 645872.60 MWD+IFR 11767.55 63.17 26.14 8818.00 8750.00 6095.59 5581.73 2449.60 4.00 5975832.60 645898.60 TZ4A/42N 11800.00 64.27 25.38 8832.37 8764.37 6124.66 5607.93 2462.25 4.00 5975859.03 645910.74 MWD+IFR 11827.94 65.23 24.74 8844.29 8776.29 6149.93 5630.83 2472.95 4.00 5975882.13 645921.01 End Dir : 1 1 11900.00 65.23 24.74 8874.48 8806.48 6215.35 5690.25 2500.34 0.00 5975942.05 645947.25 MWD+IFR 11920.35 65.23 24.74 8883.00 8815.00 6233.82 5707.02 2508.07 0.00 5975958.98 645954.66 TCGL / TZ 12000.00 65.23 24.74 8916.37 8848.37 6306.13 5772.71 2538.35 0.00 5976025.22 645983.67 MWD+IFR 12075.48 65.23 24.74 8948.00 8880.00 6374.66 5834.96 2567.03 0.00 5976088.00 646011.16 BCGUTZ2 12100.00 65.23 24.74 8958.27 8890.27 6396.92 5855.17 2576.35 0.00 5976108.39 646020.09 MWD+IFR 12111.28 65.23 24.74 8963.00 8895.00 6407.17 5864.48 2580.64 0.00 5976117.78 646024.20 PGOC 12200.00 65.23 24.74 9000.17 8932.17 6487.71 5937.64 2614.36 0.00 5976191.56 646056.51 MWD+IFR 12201.98 65.23 24.74 9001.00 8933.00 6489.51 5939.27 2615.11 0.00 5976193.21 646057.23 POWC 12242.56 65.23 24.74 9018.00 8950.00 6526.34 5972.73 2630.53 0.00 5976226.95 646072.01 25N / T26 12290.29 65.23 24.74 9038.00 8970.00 6569.68 6012.09 2648.68 0.00 5976266.65 646089.39 MHO/HOT 12300.00 65.23 24.74 9042.07 8974.07 6578.50 6020.10 2652.37 0.00 5976274.73 646092.93 MWD+IFR 12400.00 65.23 24.74 9083.97 9015.97 6669.28 6102.56 2690.37 0.00 5976357.90 646129.35 MWD+IFR 12433.50 65.23 24.74 9098.00 9030.00 6699.69 6130.18 2703.10 0.00 5976385.75 646141.55 22N / T2B 12452.59 65.23 24.74 9106.00 9038.00 6717.03 6145.93 2710.36 0.00 5976401.63 646148.50 OOWC 12500.00 65.23 24.74 9125.86 9057.86 6760.07 6185.02 2728.38 0.00 5976441.06 646165.77 MWD+IFR 12552.80 65.23 24.74 9147.99 9079.99 6808.01 6228.56 2748.45 0.00 5976484.98 646185.00 41/2" 12552.83 65.23 24.74 9148.00 9080.00 6808.04 6228.59 2748.46 0.00 5976485.00 646185.01 J-08A T2 ent 2 S S S S S S S WFL. UtlAll S ANTI-COLLISION SEITWGS (:1)MPANY UFIAILS Sl/1lVEY PIt(%iAAM N N/-8 .t/-W NnMiog Fancug Lalhude L.uginule 8k4 nP Amsku Ihplh l'm IMplh l„ tilui~eY/Pbu Taul Inlelpola[ion Methnd:MD Interval: 25.IIU N16 1'1,15-8.4 241]0 59]0205.45 G4J5 G.42 i0'-1 Y'li Ii60N 1465U'U\.'J}7W Ila DepW Range From: 341)O.INI TO: 13552.%3 ('ut lata hl Mod:M Clm ~nue 171X1 LYI 1'55?U PlauskJ-RIBA Wp 20 Vli MWU~IFIi-MS Mazimlw Range: 1452.43 Reference: Plan: 1-0%A Wp 2.11 Ilr srstem.- IstwsA Scam Method Iml-[ YUm4r Nunh linen Siufnu•'. F:Ihlnx':J ~ l'asulc Wamme hlclh.N'. IhtY:s tle J 60 50 25 00 0 75 100 125 150 160 'oloJU To MD 250 500 750 - 1000 - 1250 - 1500 - 5500 - 5750 - 6000 - 6250 - 6500 6750 - 7000 7250 - 7500 7750 - 8000 - 8250 8500 - 8750 9000 9250 - 9500 9750 10000 Removed. ;an for Plans le @ No Errors PWU 1416A Yarcut Wcllpath: 14)a Tie uu MlY'. JGM).UII Itig /tel. Ilmsm. 19.5GL'785 08.11011 V Yatiim R@m flsigu Sunmg Angle ~N/S _.~-W Fmm TVU 21xr o.W o.W za.w - P-07 Fan 1-01 }01 }ol 14~z 14)_' N)2 - }u2 1-0'_ MI2 1-05 }U. Nli - 1+15 IuG 1-07, H)] --- 141s lar~, }II - 1-11 }12 }I} }IS }I5 }IS }IG - J-11 }17 }17 1-17 }17 J-1] -- } 16 }Iv }21 1-?: J-_': }21 } i 1-'4 J-_'4 }?q }24 1X-( 1X.1. Risk Huk Irc As TVD -N/-a -G'-W IX+g TFxe V%ez Tanga '/.6Y wJ.7Y }197.71 G.]I -1924 U.W O.W H]0 IO.IY 117.44 341741 6.95 -0I R3 17.W aS.W -a 7U Y.47 72.66 )714.IY/ 4'7.17 -06.40 4.W 170170 26.41 52.Y2 20.]9 4676.61 556.Y6 167.46 a.W -13.Y7 177.17 S. Y2 31.7Y ]Stlft.Yfi 4'_21.05 ISStl.Y9 O.W OW 44Y 1.15 52U2 S2U'_ 15 W }S.W ]-/61.46 6621.W Lila W 5122.UI 166305 '__'9fi.W 4.W O.W Y8.87 U.W 4]1142 5]9S.Y5 }U6A TI 52U2 fiS.21 }S.W 24.]4 8618.}R 684S.2Y Si1R.15 56iU.ft} 210710 ?4]2.95 U.W 4.W O.W -1616 SB Ii 2Y fil4Y.`13 10 1215281 65.21 24.]4 YI4R.IlU 62?a 5'1 2]4R.46 U.W O.W 680804 }OaA T2 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [SOfdin] Sperry-Sun Anticollision Report Company: BP Amoco bate: 2/25/2008 Time: 12:12:01 Page: 1 Field: Prudhoe Bay Reference Site: PB J Pad Co-ordiaate(NE) lieference: Well: J-08, True North Reference Well: J-08 Vertical (TVD) Reference: 39.5GL+28.5 68.0 Reference WeUpath: Plan J-08A Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Princi pal Plan & P LANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 3400.00 to 12552.83 ft Scan Method: Trav Cylinder North Maximum Radius: 1452.43 ft Error Surface: Ellipse + Casing Survey Program for Definitive WeUpath Date: 2/21/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 101.00 3400.00 1 : Camera based gyro multisho (101.00-1 28461$l~`(RO-MS Camera based gyro multishot 3400.00 12552.83 Planned: J-0 8A Wp 2.0 V13 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 12715.04 0.00 4.500 6.125 41/2" Summary -- -- Offsef Wel-path --- -> ' Reference Offset Ctr-Ctr No-Go' Allowable Site WeU WeUpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB F Pad F-07 F-07 V1 Out of range PB F Pad F-30 F-30 V1 Out of range PB J Pad J-01 J-01 V2 4196.10 4150.00 508.96 52.96 456.00 Pass: Major Risk PB J Pad J-01 J-01A V1 4200.30 4175.00 509.01 52.99 456.02 Pass: Major Risk PB J Pad J-01 J-01 B V7 4200.30 4175.00 509.01 52.99 456.02 Pass: Major Risk PB J Pad J-02 J-02 V13 3403.90 3475.00 152.49 54.33 98.16 Pass: Major Risk PB J Pad J-02 J-02A V12 3403.90 3475.00 152.49 54.60 97.88 Pass: Major Risk PB J Pad J-02 J-02B VS 3400.48 3475.00 151.39 54.18 97.21 Pass: Major Risk PB J Pad J-02 J-026P61 V4 3400.48 3475.00 151.39 54.55 96.84 Pass: Major Risk PB J Pad J-02 Plan J-026L1 V4 Plan: 3412.73 3500.00 155.94 54.42 101.52 Pass: Major Risk PB J Pad J-02 Plan J-026L2 V3 Plan: 3412.73 3500.00 155.94 54.42 101.52 Pass: Major Risk PB J Pad J-05 J-OS V16 5837.88 5575.00 142.29 69.74 72.55 Pass: Major Risk PB J Pad J-05 J-05A V7 5837.88 5575.00 142.29 69.63 72.66 Pass: Major Risk PB J Pad J-05 J-05AP61 V11 5837.88 5575.00 142.29 69.63 72.66 Pass: Major Risk PB J Pad J-05 J-05B V14 5853.11 5600.00 144.10 71.48 72.62 Pass: Major Risk PB J Pad J-06 J-06 V1 3427.07 3375.00 418.06 61.87 356.20 Pass: Major Risk PB J Pad J-07A J-07A V1 3432.41 3400.00 375.20 56.82 318.38 Pass: Major Risk PB J Pad J-07 J-07 V1 3432.41 3400.00 375.20 56.82 318.38 Pass: Major Risk PB J Pad J-08 J-08 V1 3401.00 3400.00 0.00 0.44 -0.44 FAIL: NOERRORS PB J Pad J-09A J-09A V1 3403.52 3425.00 163.55 59.17 104.38 Pass: Major Risk PB J Pad J-09 J-09 V1 3403.52 3425.00 163.55 59.17 104.38 Pass: Major Risk PB J Pad J-10 J-10 V1 4923.05 4625.00 445.24 71.47 373.77 Pass: Major Risk PB J Pad J-10 J-10A V3 4923.05 4625.00 445.24 71.47 373.77 Pass: Major Risk PB J Pad J-11A J-11A V1 3456.52 3425.00 546.06 72.96 473.10 Pass: Major Risk PB J Pad J-11APB1 J-11APB1 V1 3456.52 3425.00 546.06 72.96 473.10 Pass: Major Risk PB J Pad J-11 J-11 V1 3456.52 3425.00 546.06 72.96 473.10 Pass: Major Risk PB J Pad J-12 J-12 V1 4385.10 4300.00 150.94 60.76 90.18 Pass: Major Risk PB J Pad J-13 J-13 V1 11457.85 10900.00 1055.53 1 074.76 -19.24 FAIL: Major Risk PB J Pad J-15 J-15 V3 3424.59 3850.00 313.83 174.41 139.42 Pass: Major Risk PB J Pad J-15 J-15A V1 3424.59 3850.00 313.83 174.41 139.42 Pass: Major Risk PB J Pad J-15 J-158 V2 3424.59 3850.00 313.83 174.41 139.42 Pass: Major Risk PB J Pad J-16 J-16 V5 4405.83 4750.00 533.79 90.30 443.48 Pass: Major Risk PB J Pad J-16 J-16A V2 4405.83 4750.00 533.79 90.30 443.48 Pass: Major Risk PB J Pad J-17 J-17 V3 4463.13 4800.00 188.59 58.22 130.37 Pass: Major Risk PB J Pad J-17 J-17A V3 4463.13 4800.00 188.59 58.22 130.37 Pass: Major Risk PB J Pad J-17 J-17B V7 4463.13 4800.00 188.59 58.33 130.26 Pass: Major Risk PB J Pad J-17 J-176P61 V2 4463.13 4800.00 188.59 58.33 130.26 Pass: Major Risk PB J Pad J-17 J-17C V9 4467.10 4800.00 188.63 58.40 130.23 Pass: Major Risk PB J Pad J-18 J-18 V1 3594.31 4500.00 1362.32 90.16 1272.16 Pass: Major Risk PB J Pad J-19 J-19 V1 7694.51 7050.00 164.16 137.54 26.62 Pass: Major Risk PB J Pad J-21 J-21 V1 3428.18 3375.00 492.30 57.76 434.55 Pass: Major Risk PB J Pad J-22 J-22 V3 3429.22 3375.00 573.83 55.85 517.99 Pass: Major Risk PB J Pad J-22 J-22A V1 3429.22 3375.00 573.83 55.85 517.99 Pass: Major Risk PB J Pad J-23 J-23 V1 3406.39 3425.00 76.34 54.97 21.37 Pass: Major Risk r: Sperry-Sun Anticollision Report Company: BP Amoco Date: 2!25/2008 Time: 12:12:01 Page: 2 Fieldd Prudhoe Bay.. Reference S ite:: PB JPad Co-ordinate(NE) Reference: Well: J-08, True North Reference Well: J-08 Vertical (TVD) Reference: 39.5GL+28.5 68A' Reference Wellpath: Plan J-08A Db: Oracle Summary - - <---- Offset Wellpath - > Reference .Offset Ctr-Ctr No-Go Allowable Site Well ' Wellpath MD MD Distance Area Deviation Wa rning ft ft ft ft ft PB J Pad J-23 J-23A V4 3414.00 3425.00 78.29 55.16 23.13 Pass: Major Risk PB J Pad J-24 J-24 V1 1 2475.77 11700.00 692.77 1174.57 -481.80 FAIL: Major Risk PB J Pad J-24 J-24A V4 1 1842.72 11000.00 719.48 1013.70 -294.21 FAIL: Major Risk PB J Pad J-24 J-24APB1 V1 1 2017.23 11250.00 620.38 944.44 -324.06 FAIL: Major Risk PB J Pad J-24 J-24APB2 V1 1 1926.16 11100.00 696.86 1001.45 -304.60 FAIL: Major Risk PB J Pad JX-02A JX-02A V1 3429.99 3375.00 472.43 53.47 418.96 Pass: Major Risk PB J Pad JX-02 JX-02 V1 3429.92 3375.00 472.65 53.48 419.18 Pass: Major Risk Site: PB J Pad Well: J-01 Rule Assigned: Major Risk Wellpath: J-01 V2 Inter-Site Error: 0.00 ft .Reference Offset Semi-Major Axis Ctr-Gtr No-Go Allowable MD TVD MI) TVD Ref . Offset. TFO+AZI TFO-HS Cnsing/HSDistnnce Area Deviation Wa rning ft ft ft ft ft ff deg deg in ft ft ft 3410.61 3408.17 3300.00 3299.96 3.79 2.16 314.12 2.91 13.375 566.32 51.27 515.05 Pass 3434.30 3431.50 3325.00 3324.96 3.81 2.16 314.22 354.21 13.375 562.04 51.32 510.72 Pass 3453.75 3450.67 3350.00 3349.96 3.82 2.13 314.21 350.41 13.375 557.96 51.25 506.71 Pass 3473.24 3469.91 3375.00 3374.96 3.82 2.11 314.17 346.21 13.375 554.10 51.18 502.92 Pass 3492.77 3489.21 3400.00 3399.96 3.82 2.09 314.10 341.60 13.375 550.46 51.11 499.36 Pass 3512.33 3508.56 3425.00 3424.96 3.82 2.07 314.01 336.59 13.375 547.06 51.06 496.00 Pass 3531.91 3527.95 3450.00 3449.96 3.82 2.07 313.89 331.23 13.375 543.88 51.01 492.87 Pass 3551.52 3547.36 3475.00 3474.96 3.82 2.06 313.75 325.57 13.375 540.94 50.96 489.98 Pass 3571.13 3566.79 3500.00 3499.96 3.82 2.06 313.58 319.70 13.375 538.23 50.92 487.31 Pass 3590.76 3586.24 3525.00 3524.96 3.82 2.07 313.39 313.71 13.375 535.76 50.88 484.87 Pass 3610.37 3605.67 3550.00 3549.96 3.82 2.08 313.16 307.74 13.375 533.51 50.85 482.66 Pass 3629.98 3625.09 3575.00 3574.96 3.82 2.10 312.91 301.88 13.375 531.50 50.82 480.68 Pass 3649.56 3644.48 3600.00 3599.96 3.83 2.12 312.62 296.24 13.375 529.73 50.79 478.93 Pass 3669.12 3663.83 3625.00 3624.96 3.83 2.14 312.31 290.88 13.375 528.22 50.80 477.42 Pass 3688.64 3683.13 3650.00 3649.96 3.83 2.18 311.96 285.85 13.375 526.98 50.81 476.17 Pass 3708.13 3702.38 3675.00 3674.96 3.83 2.22 311.59 281.18 13.375 526.04 50.83 475.21 Pass 3731.15 3725.09 3700.00 3699.96 3.83 2.28 311.16 278.93 13.375 525.35 50.87 474.48 Pass 3759.63 3753.08 3725.00 3724.96 3.83 2.38 310.63 279.78 13.375 524.60 50.97 473.63 Pass 3787.86 3780.75 3750.00 3749.96 3.83 2.49 310.05 280.31 13.375 523.69 51.06 472.63 Pass 3815.84 3808.04 3775.00 3774.95 3.83 2.61 309.41 280.60 13.375 522.66 51.17 471.49 Pass 3843.54 3834.94 3800.00 3799.95 3.83 2.72 308.71 280.68 13.375 521.51 51.27 470.24 Pass 3870.94 3861.42 .3825.00 3824.95 3.83 2.86 307.95 280.58 13.375 520.28 51.43 468.85 Pass 3898.03 3887.48 3850.00 3849.95 3.83 2.99 307.14 280.35 13.375 518.99 51.58 467.41 Pass 3924.80 3913.07 3875.00 3874.94 3.83 3.13 306.28 279.98 13.375 517.68 51.75 465.93 Pass 3951.23 3938.20 3900.00 3899.94 3.83 3.27 305.37 279.50 13.375 516.36 51.91 464.45 Pass 3977.32 3962.86 3925.00 3924.93 3.83 3.39 304.40 278.92 13.375 515.07 51.99 463.08 Pass 4003.08 3987.04 3950.00 3949.93 3.83 3.52 303.39 278.26 13.375 513.84 52.08 461.76 Pass 4028.49 4010.75 3975.00 3974.93 3.84 3.64 302.33 277.51 13.375 512.68 52.17 460.52 Pass 4053.56 4033.96 4000.00 3999.92 3.85 3.77 301.22 276.69 13.375 511.63 52.26 459.38 Pass 4078.26 4056.67 4025.00 4024.92 3.86 3.90 300.07 275.79 13.375 510.72 52.36 458.36 Pass 4102.59 4078.88 4050.00 4049.92 3.86 4.03 298.88 274.83 13.375 509.96 52.46 457.50 Pass 4126.54 4100.57 4075.00 4074.92 3.88 4.15 297.64 273.80 13.375 509.38 52.57 456.81 Pass 4150.10 4121.75 4100.00 4099.91 3.89 4.28 296.36 272.71 13.375 509.01 52.69 456.33 Pass 4173.29 4142.41 4125.00 4124.91 3.91 4.41 295.03 271.57 13.375 508.87 52.82 456.05 Pass 4196.10 4162.58 4150.00 4149.91 3.92 4.54 293.67 270.37 13.375 508.96 52.96 456.00 Pass 4218.52 4182.23 4175.00 4174.90 3.94 4.67 292.28 269.13 13.375 509.31 53.12 456.19 Pass 4240.57 4201.39 4200.00 4199.90 3.96 4.79 290.85 267.85 13.375 509.95 53.29 456.65 Pass 4262.23 4220.04 4225.00 4224.90 3.98 4.92 289.39 266.52 9.625 510.89 53.31 457.58 Pass 4283.49 4238.20 4250.00 4249.90 4.00 5.04 287.90 265.16 9.625 512.16 53.50 458.66 Pass 4304.36 4255.85 4275.00 4274.89 4.02 5.16 286.39 263.76 9.625 513.79 53.71 460.09 Pass EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6000000 5950000 5900000 5850000 ~--- 400000 500000 600000 700000 800000 i u Alaska Department of Natural Resources Land Administration System Page 1 of~~ <I~; ~ r~:,~ ~ . , ,:; ~ Jer's vea+~ch State Cabins 1'~~i ue~~ ~~1P~S +aS File Type: AFL File Number: _m?$281 ? ~ Printable Case Fite_Summary See Township, Range, Section and Acreage? ~' Y0S ' NO New Search LAS n~~no, I Case Abstract i Case Detail i Land Abstract ~. F~1e: aDL 28281 ''~"' Sarah for_Status Plat Updates ~~ u1 07!24I~008 Customer" 00010;377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995 1 966 1 2 Case Type: X84 OIL & GAS LEASE COMP DNR Unit: 780 OIL AN.D GAS File Location: DOG DN OIL AND GAS Case Sl~rtus: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office ofPrin~ar}~ Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12!04/2006 Case Subtype : S NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED .1-/eridian; U I n~r~t.~hip: O I I N R~ot,~~ : 013 i~ .~t~cti~~n: 03 Section Acres: 640 Search Plats a'1~rrkliuir: U 7~utirjt.~hii~: 01 I N Ru~r,Lre.~ 013 (_`, S'ectir>il: U4 Sectiurr _~Icre~,~: 610 ~CI'ICilUil: U TUN'I7h'~lli): ~) ~ i N i~L7N~fJ.' O~ 3 i', ,ti~('C/lull.' ~)~~ .ti~eCl1UIY <~C"i'C1': ~ ~~~ ~~~~~~<<a~~,j~: v ~ ~~~,~» c{~i~~ o~ i N ~t<<~t,~~~-_ o i 3 r~ s« ~«~t~: ~ o s~~~~~~~~~t -1~~,-~~s~: f~~u Legal Descrilrii~~n 0~ -28-196 * ~` * SALE NOTICE LEGAL DESCRIPTION ~` Cl~- 9' TIIN, R13E, UM 3, 4, 9, 10 2,60.00 end cad Case Summ~lr Last updated on 07/2412008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28281 &... 7/24/2008 i • TRANSMITTAL LETTER CHECKLIST WELL NAME ~~L/ J'O~~ PTD# ~O ~lp~Op / Devetopment~ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~.G~'!/,Q~OE ~~y POOL: _ f ~!/Q~O~'~q~~ ~~~-, Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in API number are permit No. , AP[ No. 50- - - between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_, from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any pxotest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comoany Name) must contact the Commission to obtain advance approval of such water welt testing ro ram. Rev: Ill 12008 WELL PERMIT CHECKLIST FieM 8 Pool PRUDHOE BAY, PRUDHOE OIL •640150 Weil Name: PRUDHOE BAY UNIT J-08A Program DEV Welt bore seg ^ PTD#:2081200 Company BP EXPLORATION (-ALAS INC Initial ClasslType DEV 1 PEND GeoArea 890 Unit 11650 ONOff Shore 2n Annular Disposal ^ Administration 1 Petmiifeeattach®d---- ---- --- - - -- -- - - NA- - ---- ------ - -- -- -- -- ------ - -- -- -- --- --- - 2 Leasens~mberapproRdate-- - ----- - -- - -- - -Y~ - - ------ -- ------- ---------- -- - -- ----- ---- -- 3 Uniquewell.namesndnumber-- --- -- -- -- -------- Yes - --- ------------ - ---------------- ------ - - - --------- - - - - 4 Well_locakedinadefinedpooL____.___.------------------- ---------Yes-_ __--Prudhoe Bay4'IIPOOi.-------------------------------------------.----.---- 5 WelllocakedProperdistanoefromdrUlingunitlwundary--------------- --------- Yes-- -------------.---------------------------------------....---.---------- 6 UYaIUoC;3kedpropardistan4efromotherwelis------------------- --------Yes-- ---------------------------------------------------------------------- 7 SuffiCiont acreage ayaiiBble in_driUing unit - - - - - - - - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - 8 If deviated,i$weflborePtat_included. ------ - - -- - -- --- YeS-- ---- ----- - --- -- - -- -- --- -- ------- .. ---------- -- 9 OpEratoronlyaftectsdPartY---- - -- -------- -- - - -------- Yas- ------... - - ------ -- -- - --- ----- --- --- - - - - - -- -- 10 Operator has-appropdatebondinforce------------------------ ---__---Yes-- --.--@lanket@ond#61841@3.-.--_____--______-___-__----------------------_----- 11 Petmitoanboissuedwiiboutconsarvationarder------------------ ---------Yes-- -----------....-.--------.------.-.-..------..-----------..-......------ Appr Date 12 PermftcanbelasuedwRhoutadminist[alive-approval---------------- ---------Yes-- --.--------------------------------------------------------------------- ACS 712412008 13 Canpormitbeapprovedbefore15•daywait ---._ --- - - ---- --------- Yes- -- .. - ----- --- ---- --------- --- --- - - - -- ----------- 14 WslllocatedwUhinaroaand_strateauthorizedby_injeotionprder~lpctlS)~"in-comments)-(For- NA__ ____________________________________.--_-_-...-------------------_-._-- 15 A11weUswithinlt4-milearea_ofreviewidentitied(Fotservicewellpnly)------ ----------NA.-- ---------.-.-------------._--.----------------------.----.------------- 16 PJe•producedinjectordurationofPreAroducti9nlessthan3montha(For erviceweionN)-. Nfl__ _____________________________-_.._.__________-___.-__.._-.___-.._.._ 17 Nonoonven,gas_conformstoAS31A6U30Q.t.A),(12.A•p)- ---- - --- NA- -- --- --- ----- ----------------------- ------- -------- --------- Engineering 18 Conductorsirinf~P-rovided-_----------..---------------- ----------NA--- -..__ConduoioraetinJ-98(117.947)------------------------------------------------- 19 Surface casingP-roteotsall_knownU@DWs----------------.---. ---------NA-- -----Alia4urfarsexemptedA@9?,--------.--.---.--------------.-.__......------- 20 CMTvoladequatetosJrculateonc9nduotor8,su~fcsg-------------- ----------NA--- -----Surfas~oasingsetin,!-98-----------------------------------------------. 21 CMTvoladequatetolie•in-long string tost,rfcsg___________________ _________Yes-_ _-_--Cement ispiannedto)uatabovethe-v~indow,_..______-.__________--_..___-.-____._-__ 22 CMTwillcover-ahknawn_prods,ctiveborizons____________________ ____ _--Yes._ _-.__..__.-__.-.-.-_-....-_______________-______.-.-------.-------____-- 23 Casing designs adequate for C,T,@&permafrosi----------------- ________-Y®s.. _..___._.-..__..________-_______-___-_-.__....-.--_____--------.-_----- 24 Adequatetankage.or reserve Pit - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ _ _ _ _ -Rig equipped wHh steal pits, N9leserve pU planned,_All waste to approved disposal v+eli(sa.- - - _ - - - - - - - - - 25 Ifs-re~drill,has_at0~03forabandortmentbeenapprov_ed____________ _________ Yes__ _-.--398-237--------------------------------------------------------------- 26 Adequate-wehbore separetlonproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ . _ - ProximUy analysis performed, Gyros to be-run in offset wells to improve location certainty .... _ . _ _ - _ _ _ - _ 27 If divert8r_required,doe$itmeetregulati9ns_.----_______________ __------ NA___ _-_-@OP$tecl(wlll al[eddy.beinRlaoe,----------------------.---------.-------------- Appr Date 28 Drilling fluid program schematic-& equip list-adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ _ Maximum expected formation pressure ~7 0 EMVy.. MW planned up. to 11,9 ppg in 8.5' hole and 8,$ in zone.- _ _ - TEM 712512008 29 BOPls,dotheymeetregulation-- - ------- --- - - ------Yes. --- --- -- -_ - --- ---- - - - -- --------- ---- -- (} 30 BOPI:-press rating appropriate; lest to_!Rs!t psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ - _ _ - MASP caloulaled at 2300psi, 3500_psiBOP testplanned. - - - - - - - _ - - - - ... _ - . - _ . - - - . _ _ - _ - _ _ ~ 'L 31 Ch9ke.manifold coroRli®sw/APl_RP-53 (May $4)- - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 _WorkYVill9ccurvvithoutoperatlonshutdown--------------------- ---------Yes-- ---------------------------------------------------------------------- 33 is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _t~o- - - _ _ _ _ _ Low H2$ is reporled at d pad, Mud should_pleclude H2S onrig. -Rig has sensors-and alarms, - - . _ . - _ _ _ . _ 34 _rt~echanical_cArlditionofwaliswithinAORyer'Ifiad(FOrserviceweUonty~----- --------- NA--- ----------------------------------------------------------------------- Geology 35 Permitcanbeissuedwtohydrogertsulfidameasures-_---__--_--_ _________ No.- _____WeIIU•23Ahad-Max_Leya120RPm~-------------------------------------------- 36 Data_Presentedonpotentialovetpressurezones. - ------- ----Yes - - ~- - -- --- -- ---------------- ------ - ------ -- --------- ApW Date 37 Seism~anaNsisQfsballowgasz9nas -- ---- -- --- --- ------- ~ ------------------------- --------- - ---- --- -- -- - - ACS 712412008 38 Seat-condltionsurvey_(ifoffshore)------------------------- ---------NA--- - 39 Contactnemelphoneforweekly_progressn3ports[exploratoryonlyJ-------- ---------Yes_ -----FrankRoach-564,4$73.---------------------------------------------------- Geologic Date: Engineering ~~ P ~ Date Commissioner: Commissioner: mis ner ~-L8 ~ 08
