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206-185
Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 07/18/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230718 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MP F-92 50029229240000 198193 7/11/2023 READ Caliper Survey MPU C-02 50029208660000 182194 7/11/2023 AK E-LINE Whipstock Setting Record PBU W-210 50029233390000 206185 6/28/2023 AK E-LINE IPROF Please include current contact information if different from above. T37855 T37856 T37857PBU W-210 50029233390000 206185 6/28/2023 AK E-LINE IPROF Kayla Junke Digitally signed by Kayla Junke Date: 2023.07.18 13:24:05 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, June 1, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-210 PRUDHOE BAY UN POL W-210 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/01/2023 W-210 50-029-23339-00-00 206-185-0 G SPT 4743 2061850 1500 1981 1990 1985 1985 41 75 77 77 4YRTST P Sully Sullivan 5/1/2023 tested to 2500psi for 500psi dp 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL W-210 Inspection Date: Tubing OA Packer Depth 26 2650 2587 2573IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230501183905 BBL Pumped:3.3 BBL Returned:2.7 Thursday, June 1, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 9James B. Regg Digitally signed by James B. Regg Date: 2023.06.01 15:48:25 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg --7> P.I. Supervisor 1,`7(l q /-7 ltq DATE: Monday, June 3, 2019 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. FROM: Jeff Jones W-210 Petroleum Inspector PRUDHOE BAY UN POL W-210 Ste: Inspector Reviewed By: P.I. Supry .T bp-- NON -CONFIDENTIAL r,,,,,,,„ Well Name PRUDHOE BAY UN POL W-210 API Well Number 50-029-23339-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ190531174024 Permit Number: 206-185-0 Inspection Date: 5/312019 Rel Insp Num: Packer Well W-210 Type Inj W TVD PTD 2061850 " Type Test SPT Test psi BBL Pumped: 1.2 - BBL Returned: Interval 4YRTST PAF Notes: I well inspected, no exceptions noted. Monday, June 3, 2019 Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 4743 Tubing 1269 127E 1270 - 1270 -� 1500-�-- IA soy 2000 _ Io4; . I934 1.7 OA 238 411 , a09 _ 404 - P ✓ - Paee I otI MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 13,2015 TO: P.I.m Regg i<�,�,�� fir' I/S PSupervisor � l t SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC W-210 FROM: Lou Grimaldi PRUDHOE BAY UN POL W-210 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-210 API Well Number 50-029-23339-00-00 Inspector Name: Lou Grimaldi Permit Number: 206-185-0 Inspection Date: 5/10/2015 Insp Num: mitLG150510195901 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-210 • Type Inj G-TVD 4743 - Tubing 2983 - 2978 2977• 2955 PTD I 2061850 ' Type Test SPT Test psi 1500 - IA 407 2515 - 2449 - 2432 - Interval 4YRTST P/F P ✓ OA 38 53 - 54 • 54 Notes: 1.9 bbl's diesel pumped, 1.9 returned.Good test.All required paperwork supplied prior to test. .- A4' c () Cc,rl ,d-- ' f" c s. Z) clirsret. 142.1.1 4- SCANNED JUL 1 0 2015 Wednesday,May 13,2015 Page 1 of 1 w 1.r\, 4•A z,--o,_. _,. 0 ---,, ++ H ..._, ...v 1 2 _.> 1 t I i k.• r.r. •:::', r; 1 1 iI ?-..... '•-• 1_.,,__ rr:i ".. It I II 5,,1 ..`*; 1%. ,.. ,..,.• "--; , '•..*, r 'It ___::.-. ...-• L__ :.... ,--: .1 1). ...-. L P LI .. ? ... :...! '). I.' .r . •.k 41/16"CNV WELLHEAD= FMC 1 0 SAF IOTES: WELL REQUIRES A SSSV WHEN WELLHEAD VV ON A.__ "HES PKR @ 6811'IS"PULL TO RELEASE"BUT ACTUATOR= BAKER C CAN ALSO BE RELEASED BY PRESSURE DO NOT OKB.13EV= 80.1 EXCEED 2000 PSI ON THE A w/OUT PERFORMING TBG BF.13EV= 81' 4-1/2"X 3-1/7 XO, H 26' I l MOVEMENT CALC'S&DISCUSSING w/APE"" Angle= 58° 43107 D=2.992" Max n9 ° ■ 2516' -13-1J2"HES X NIP,D=2.813" Datum MD= 7350' Datum TVD= 5000'SS' 1 GAS LFT MANDRELS 20"CONDUCTOR —I 108' ,} , ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 6732 4696 54 MMG DMY RK 0 05/11/07 9-5/8"CSG,40#,L-80 BTC,D=8.833" — 4362' WATER INJECTION MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7"LNR 26#,L-80 TCI XO TO L-80 BTC-M ---1 6373' }-- x 6 6837 4758 54 MMG W DMY RK 0 05/19/07 5 7194 4975 49 MMG-W DMY RK 0 03/08/07 7"MARKER JOM w I RA TAG --, 6392' 4 7232 5001 48 MMG-W P-15XJR RK 11 12/12/14 MP 3 7297 5044 48 MMIr W DMY RK 0 03/08/07 2 7335 5070 47 MMG-W P-15XJR RK 11 08/31/13 Minimum ID =2.813" @ 2616' 1 7403 5116 47 MMG-W P-15XJR RK 16 08/31/13 3-1/2" HES X NIPPLE 1 1 6791' --i 3-1/2'HES X MP,D=2.813" Z 6811' H7"X 3-1/2"HES DUAL FEEDTFRU PKR,D=2.965" • 6825' H PHOENNDX PRESS/TBvP SENSOR SUB,D=2.875" INI I:1 1 1 6865' —13-1/2"HES X NIP,D=2.813" 3-1/2"MARKER JOINT w/RA TAG —1 6876' _ 7171' H7"X 3-1/2"HES DUAL F®THRU PKR,D=2.965" En 0PERFORATION SLAuMARY REF LOG:UST(LOD,FDC MODE ON 03/06/07 MP ANGLE AT TOP FERF: 54°Qa 6869' 1 1 7261° H3-1/2"HES X MP,D=2.813' Note:Refer to Ftoduction DB for historical perf data SIZE SPF ZONE INTERVAL Opn/Sgz SHOT SQZ X] . . 7281' Hr X 3-1/2"FES SINGLE FEEDTHRU PKR,D=2.965" 41/2" 5 Nb 6869-6879 0 03/06/07 • 7290' —1 PHOS NtX PRESS/1ENP SENSOR SUB,0=2.875" 4-1/2" 5 OBa/OBb 7191-7243 0 03/06/07 4-1/2" 5 OBc 7307-7345 0 03/06/07 Mr 0 4-1/2" 5 OBd 7387-7443 0 03/06/07 III /11s . X 7359' �7"X 3-1/2'HES SINGLE FEEDTHRU PKR,D=2.965' 1 1 —17'7382' —13-1/2"I-ES X MP,D=2.813" 7"MARKER JOINT w/RA TAG —1 7356' 11.1a 1 I _ 7431' —I3-112"HES XNIP,D=2.813" 0lt 03 7452' H3-1/2" ESXNP,D=2.813" 3-1/2"TBG,9. ,L-80 TCI _0087 bfp,D=2.992" JI 7474' 7452' 131/2"RMX PLUG(12/15/14) PM —1 7662' 1 111• 7474' —3-1/2"WLEG,D=2.992" 111111111111111111114 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" — 7745' 1.1.1.1.1.1.1.1.1.1.1 DATE REV BY COMMENTS DATE REV BY COMNBNTS ORION UNIT 03/08/07 N9ES ORIGINAL COMPLETION 01/02/14 RCT/JM7 PILL PX/SET RMX PLUG(12/15/14) 1N13L: W-210 02/16/11 MB/J11421 ADDED SSSV SAFETY NOTE PERMIT No:"2061850 02/26/11 MW/PJC SFTY NOTE(FES FKR) AR No: 50-029-23339-00 03/31/11 GJB/PJC WFR C/O(03/26/11) SEC 21,T11N,R12E,4344'FSL&1186'Fa 09/11/13 STF/JMD GLV C/O-RESET F9(PLUG(08/29-30/13) 01/02/14 RCT/JMD WFR CIO(12/12/14) BP Exploration(Alaska) STATE OF ALASKA , _SKA OIL AND GAS CONSERVATION COM. .SION , REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon LJ Repair Well U Plug Perforations LJ Perforate U Other U First MI Injection Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill] 2.Operator 4 Well Class Before Work: 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development❑ Exploratory ❑ 206-185-0 3 Address: P 0 Box 196612 Stratigraphic❑ Service ❑✓ 6.API Number Anchorage,AK 99519-6612 50-029-23339-00-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028263 PLRS W-210 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s). PRUDHOE BAY,POLARIS OIL 11 Present Well Condition Summary RECEIVED Total Depth measured 7750 feet Plugs measured 7452 feet true vertical 5352 03 feet Junk measured None feet APR 2 3 2 015 Effective Depth measured 7452 feet Packer measured See Attachment feet �, true vertical 5149 3 feet true vertical See Attachment feet ) GCC Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"X 34"215 5#A53 29-109 29-109 0 0 Surface 4287.01 9-5/8"40#L-80 29 06-4316.07 29.06-3333 67 5750 3090 Intermediate 7719 35 7"26#L-80 26 28-7745 63 26 28-5349 06 7240 5410 Production None None None None None None Liner None None None None None None Perforation depth Measured depth 6869-6879 feet 7191-7243 feet 7307-7345 feet 7387-7443 feet True Vertical depth 4776 66-4782 48 feet 4973 32-5007 98 feet 5051 03-5076 7 feet 5105 15-5143.18 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9 2#L-80 23 71-7474 48 23 71-5164 58 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary Intervals treated(measured): SCANNED i`v1A r i .2 2015 7191'-7243',7307'-7345',7387'-7443' 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 0 0 1197 0 1200 Subsequent to operation 0 1312 0 0 300 14.Attachments 15 Well Class after work ' Copies of Logs and Surveys Run Exploratory❑ Development❑ Service❑✓ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP ❑ SPLUC-❑ ' 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt. AIO#25A.015 Contact Nita Summerhays Email Nita.Summerha s• b..com Printed Name Nita Summerhays/ Title Petrotechnical Data Engineer 1. --,,tor,mt 1 - /���j�,,� Phone 564-4035 Date 4/21/2015 vTi- 5-/�/ 5- RBDMS APR 2 B 2015 Form 10-404 Revised 10/2012 Submit Onginal Only Daily Report of Well Operations ADL0028263 Y ***WELL INJECTING ON ARRIVIAL***(wag s,,--� ' `' `� "' � R/U SWCP 4519 12/7/2014 ***WSR CONT ON 12/8/14*** ***WSR CONT FROM 12/7/14***(wag swap) MADE 4 RUNS W/2.5"x 13' PUMP BAILER ( recovered 6 gallons schmoo total) PULL P-PRONG FROM 7432' SLM 12/8/2014 ***WSR CONT ON 12/9/14*** T/I/0=1100/50/20 Temp=SI Assist S-line F-protect F-line ( UIC)Attempted to pump down F-line from S-riser F-line frozen Pumped 5 bbls neat meth down FL. Pumped 22 bbls neat meth down TBG to freeze protect. ***Continued on 12/8/2014 next WSR*** ***WSR CONT FROM 12/8/14***(wag swap) MADE 9 BAILER RUNS TOTAL W/2.50" &2.25" PUMP BAILER MADE HOLE DOWN TO 7444' SLM 12/9/2014 ***WSR CONT ON 12/10/14 ***WSR CONT FROM 12/9/14***(wag swap) MAKE 6 BAILER RUNS TO PX PLUG BODY @ 7443' SLM(4 gallons schmoo recovered total) MAKE ONE ATTEMPT TO PULL PX PLUG 12/10/2014 ***WSR CONT ON 12/11/14*** ***Continued on 12-10-14 WSR***Assist Slickline w/B&F Pumped 3 bbls neat meth followed by 9 bbls of 180*diesel down TBG in attempt to free SL tool string. Pumped an additional 51 bbls for a total of 60 bbls 10*diesel to load TBG. Bleed TBG, bled back—3 bbls. SL tool free from plug. ***Continued on 12/10/2014 12-11-14 WSR*** ***WSR CONT FROM 12/10/14***(wag swap) RAN 2.50" PUMP BAILER TWICE, RECOVERED —3 GAL OF SCHMOO BRUSH TBG W/ LRS 3-1/2" BRUSH &2.50"G.RING TO PLUG BODY. RAN 3-1/2" DOGLESS GS TO 7443' SLM (7452' MD) (unsheared pin) 12/11/2014 ***WSR CONT ON 12/12/14*** ***CONTINUE FROM 12/11/2014***(wag swap) RAN 3-1/2" DOGLESS GS TO PX PLUG BODY AT 7,452' MD (GS not sheared) RAN 2.70" CENT, 2'x 1-7/8" STEM, 2.75" CENT, 1.75" LIB TO PX-PLUG BODY AT 7,452' MD (impression of RK latch) PULLED ST#4 RK-P15-XJR WFR FROM PX-PLUG BODY AT 7,443' SLM (7,452 MD) RAN 1.75" LIB TO STA#2 AT 7331' SLM (7335' MD) (impression of latch, mistook#4 wfr for#2, prep to tag#4 pocket) RAN 1.75" LIB TO STA#4 AT 7,221' SLM (7,232' MD) (impression of empty pocket) RAN POCKET BRUSH/POKER TO STA#4 AT 7,221' SLM (7,232' MD) SET 3-1/2"X-SELECTIVE TEST TOOL IN X-NIPPLE AT 7,251' SLM (7,261' MD) SET STA.#4 RK-P-15XJR AT 7,221' SLM (7,232' MD) (11/64" ports" light spring, 160 bwpd) 12/12/2014 ***CONTINUE ON 12/13/2014** Daily Report of Well Operations ADL0028263 ***CONTINUE FROM 12/12/14***(wag swap) LRS PERFORM STEP RATE TEST ON STA.#4 (SEE LRS AWGRS) PULLED 3-1/2"X-SELECTIVE TEST TOOL IN X-NIPPLE AT 7,251' SLM (7,261' MD) RAN 1.75" LIB TO STA#4 AT 7,221' SLM (7,232' MD), IMPRESSION OF LATCH RAN 10'x2.5" PUMP BAILER TO 7371' SLM, -1-1/2 GALS OF SCHMOO/SAND MIX RAN 3-1/2" BRUSH, 2.50" G. RING TO 7439' SLM/7452' MD, LRS PUMPED-11 BBLS OF DIESEL MADE 3 RUNS W/ 10'x2.5" PUMP BAILER TO 7428' SLM, RECOVERED -3 GALLONS OF SCHMOO ***CONTINUE ON 12/14/2014*** ***SUBSIDENCE DRIFT TO 2,600' SLM W/20'x 2.70" DUMMY WHIP 12/13/2014 STOCK WITH NO ISSUES*** ***CONTINUE FROM 12/13/2014*** (wag swap) RAN DOGLESS 3-1/2" GS TO PX PLUG BODY AT 7,430' SLM (7,452' MD) (unsheared) RAN 1.75" LIB TO 7,433' SLM (no impression) RAN 3-1/2" GS, BAIT SUB, 5' x 1-7/8" STEM, 3-1/2" GR(brass)TO 7428' SLM MULTIPLE TIMES, SHEAR OFF RAN 10'x2.5" PUMP BAILER TO 7424' SLM, RECOVERED - 1-1/2 GALS OF SCHMOO, METAL MARKS ON BTM RAN 3-1/2" GS, BAIT SUB, 5' x 1-7/8" STEM, 3-1/2" GR(steel) TO 7452' MD, SHEARED. RAN 3-1/2" GS, BAIT SUB, 5'x 1-7/8" STEM, 3-1/2" GS(steel)TO 7452' MD. PULLED 3-1/2" PX PLUG BODY @ 7452' MD. 12/14/2014 ***WSR CONTINUED ON 12/15/14*** ***WSR CONTINUED FROM 12/14/14***(Wag Swap) BRUSH & FLUSH TUBING &WFR MANDRELS FROM 6,700' SLM TO 7,455' SLM, RAN PDS 24 ARM CALIPER FROM 7,445' SLM TO SURFACE WITH GOOD DATA. SET 3 1/2" RMX PLUG BODY IN X-NIPPLE @ 7452' MD. VERIFIED WITH CHECK SET. SET RM-DUMMY PRONG IN RMX PLUG BODY. SET 3 1/2" MCX( serial# bpx-333) IN SVLN @ 2516' MD. VERIFIED SET WITH CHECK SET. 12/15/2014 ***WELL LEFT SHUT IN, DSO WALK THROUGH UPON DEPARTURE*** T/I/O = 2100/0+/40. Temp = 96*. WHPs (UIC). On injection. No AL on either side of well. 3/24/2015 SV=C. WV, SSV, MV=O. IA, OA=OTG. NOVP. 23:42 T/I/O =2020/0/40. Temp= 96*. Increase IAP to 300 psi. (UIC). Well on MI INJ. IA& OA FLs near surface. Increased IAP from 0 to 280 psi with N2, with -1 bottle of N2. Monitored WHPs for 30 mins. IAP decreased 5 psi, OAP remained unchanged at 40 psi. IA FL @ 120' (2.8 bbls). Final WHPs = 2020/275/40. Job Complete. See log for detail. Tag hung. 3/27/2015 SV= C. WV, SSV, MV= O. IA, OA= OTG. • Daily Report of Well Operations ADL0028263 FLUIDS PUMPED BBLS 223.46 DIESEL 33 METH 256.46 TOTAL L L Y Y N - U U - co (6 = co cod p- a, d d 7 r L O. L L L_ • L -6 D O. a) LL LL (6 o) Q) p 0 u) Cl) W W W W 4 = 2 2 2 CD N = M M M M RS iJ Q QCO (NJ O M (J) M CO Cr)os- N ~ O O O V) O L() O 10 Q C R'S L a) N co —NC in O in r O d) R - r CO CL co N- N- N- • d W W W W O.YYYY >+000U W d W d E O o 0co Z C N ( 1 N> Cn I TREE= 41/16'CNV TY NOTE: WELL REQUIRES A SSSV WHEN WELLHEAD= F -21 ON MI. ""FES PCR I. 6811'6"RLL TO RELEASE"BUT ACTUATOR= BAKER C , CAN ALSO BE RELEASED BY PRESSURE DO NOT OFCB ELEV= 80.1' EXCEED 2000 PSI ON THE IA w/OUT P32FORI.IG TBG BF.ELEV= 81' 41/2°X 3-1/7 XO, --J 26' I ` 1 MOVEMENT CALCS 8 DISCUSSING w/APE"' �- �,� D=2.992" Max Angle 2516' 3 1/7 FES X NIP,D=2.813" Datum MD= _. ...7350' Datum TVD= 5000'SS ()I GAS LFT MANDRELS 20"CONDUCTOR H 108' , ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 6732 4696+ 54 MMG DM( RK 0 05111/07 9-5/8"CSG,400,L-80 BTC,13=8.833" — 4362' WATER INJECTION M4NDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 7"LM,26#,L-80 TCI XO TO L-80 BTC-M H 6373' X 6 6837 4758 54 MNGW DMY RK 0 05r19i07 5 7194 4975 49 P.IG-W DMY RK 0 03108/07 7"MARKER JONT w/RA TAG H 6392' 1-4 4 7232 5001 48 M►rrW 1:4-15XR RK 11 12/12/14 MP 3 7297 5044 48 MMG-W DMY RK 0 03/08/07 2 7335 5070 47 MUGW P-15XJR RK 11 08/31/13 Minimum ID =2.813" @ 2516' 1 7403 5116 47 14N3-W P-15XJR RK 16 08/31/13 3-1/2" HES X NIPPLE ' ' 6791' —13-1/7 HES X NIP,13=2.813" X l 6811' H7'x 3-1/2"FES DUAL F DJ TFR PKR,D=2.965" /� • 6825' H PH106Ix FRESS/TEMP SENSOR SUB,D=2.875" ME 0 I I 6865' H3-1/2"HES X NP,D=2.813" 3-1/7 MARKER JOf IT w/RA TAG H 6876' _ 7171' Hr x 3-1/2"FES DUAL F®T1- (U PKR,13=2.965" WI PERFORATION SIMAARY 0 REF LOG:USA-LOD,PCC MODE ON 03/06/07 WI ANGLE AT TOP PERF: 54°©6869' I 7261' —13-1/2'HES X NP,D=2.813" We:Refer to Production DB for historical pert data pp�� 7281• —{7'X 3-1/2'FES SINGLE F�THRt I PCR D=2.965' SEE SPF ZONE INTERVAL C)pn/S� SHOT SOZ pl 4-1/7 5 Nb 6869-6879 0 03/06/07 7290' H PHOB4X S!^ Ta43 SENSOR SW,D=2.875' 4-1/7 5 06a/OB, 7191-7243 0 03/06/07 4-1/7 5 OOc 7307-7345 0 03/06/07 MP 0 4-1/7 5 00d 7387-7443 0 03/06/07 W �J 7358' H7"x 3-12'FES SINGLE FEEDTHRU PKR,D=2.965" I I 7382' —13-1/2"FES X NP,D=2.813" 7"MARKER J(X+TT w/RA TAG H 7366' WI D ' 1---1 7431' H 3-1/7 FES X NP,13=2.813" 1181 7452' H 31/7 HES X NP,D=2.813" 3-1/2"TBG,9.2#,L-80 TC1,.0087 bfp,D=2.992" —1 7474' I-- 745r 131/7 RIO(PLUG(12/15/14) Pin) 7662" 7474' H3-1/2"WLEG,D=2.992" 7"LM,26#,L-80 BTC-M,.0383 CO,13=6.276" -1 7745' DATE REV BY COAMANTS DATE REV BY OOMMENTS ORION LINT 03/08/07 N IES ORIGINAL COMPLETION 01/02/14 RCT/J11)RLL PX/SET F21 C(PLUG(12/15/14) WELL W-210 02/16/11 1443/JM) ADCEDSSSV SAFETY NOTE PERMIT ND:'1061850 02/26/11 MVV/PJC SFT' NOTE(HES P(F) AR No: 50-029-23339-00 03/31/11 GE/PJC WFR GO(03/26/11) SEC 21,T11N,,R12E 4344'FAL 8 1186 FEL 09/11/13 SIF/JMJ GLV C/O-RESET P9(PLUG(08/29-30/13) 01/02/14 RCT/JM)WFR GO(12/12/14) 1 if 1 BP Exploration(Alaska) I Ima a Pro'ect Well Histo File Cove~age 9 1 rN 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. ~~~ - ~ ~ S Well History File Identifier Organizing (done) .6,a~ imimiii iu ,_ a.~a~~e~e, iiuuuuiiuuu RE AN DIGIT L DATA OVERSIZED (Scannable) Color Items: iskettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: 5 / /s/ Pro'ect Proogn III II'III II III I I III 1 g BY: Maria Date: ~ ~ /s/ in Pre aration ,~_ x 30 = O + ~ ~ =TOTAL PAGES / 0 Scann g p (Count does not include cover sheet) BY: _ Maria Date: ~I~ l D lsl Production Scanning Stage 1 Page Count from Scanned File: I ~ (Count does include cov r sheet) Page Count Matches Number in Scanning P eparation: YES NO BY: ~Maria~ Date: 3 ~ I D /sl ~~/~ C.~^ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scannin is com late at this point unless rescanning is required. II I II II II I II II I I III 9 P ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III (I'I'I III II'I I I 10/6/2005 Well History File Cover Page.doc • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 07, 2011 TO: Jim Regg gig q P.I. Supervisor gig q, SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W -210 FROM: John Crisp PRUDHOE BAY UN POL W -210 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN POL W -210 API Well Number: 50- 029 - 23339 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr110604145705 Permit Number: 206 -185 -0 Inspection Date: 6/3/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well W-210 Type Inj. TVD 4743 IA 10 1980 " 1920 1910 P.T.DI 2061850 1 TypeTest SPT Test psi 1500 OA 0 100 100 80 Interval 4YRTST P/F P Tubing 1200 1200 1200 1200 Notes: 1.9 bbls pumped for test. - Tuesday, June 07, 2011 Page 1 of 1 ::~. ~, N ~SA4: ss~µq t v. ~ -: ~ _ .~5' ~ o-4 ~ i `^R ~~~T 4° ~ ~ ~ i~ r V tl ~.. ~..:^. ~., ,.+^y, 1 t~ s`6~~Wi^ ~~y"~ MICROFILMED 6/30!20.10 DO NOT PLACE ANY NEW MATE RIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ ~~, ~ DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061850 Well Name/No. PRUDHOE BAY UN POL W-210 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23339-00-00 MD 7750 TVD 5352 Completion Date 3/8/2007 Completion Status WAGIN Current Status WAGIN UIC Y __ __ - - -- - - _ -___ -- - ___ - '~ REQUIRED INFORMATION ~~Y Mud Log No Samples IVo Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: / GR, GR / RES / AZI-DEN / NEU / PWD, MDT, USIT (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments ~pt Directional Survey 0 7750 Open 3/13/2007 ED D Asc Directional Survey 0 7750 Open 3/13/2007 g ement Evaluation C 5 Col 1 0 7610 Case 4/30/2007 USIT, GR, CCL 6-Mar-2007 £D C Las ~ 15156'~Downhole Equipmen 6593 7426 Case 5/24/2007 Jewelry Log GE, CCL w.Graphics PDF, LAS, Tif ~g Formation Tester 5 Col 1 6550 7568 Open 5/31/2007 Modular Dynamic Tester, MDT - GR 27-Feb-2007 -ED C Pdf 15273/See Notes 0 0 7/9/2007 PVT Study Report pt 15273°~See Notes 0 0 7/9/2007 PVT Study Report C Lis 15439~Casing collar locator 9 7577 Case 9/28/2007 LIS Veri, USIT, CCL, GR w/PDS and TIF graphics " D C Lis 15597~duction/Resistivity 48 7752 Open 10/26/2007 LIS Veri, GR, ROP, FET, RA, DRHO, NPHI w/PDS graphics -Induction/Resistivity ~~~ ~u-4v~ 25 Blu 1 ~,~((~,~ 108 7750 Open 10/26/2007 MD Vision Service 26-Feb- 2007 g ajE Induction/Resistivity ~~~~~1- 25 Blu 1 Cwu~.~, 108 7750 Open 10/26/2007 TVD Vision Service 26-Feb- 2007 ED C Lis ~61~Induction/Resistivity 48 7752 ~ ~~ 2/13/2009 LIS Veri, GR, ROP, FET, DRHO, NPHI, TRPM u g Induction/Resistivity ~ ~~~ ~ 25 Blu 108 7750 Cas~ 2/13/2009 ~ REVISED 26-Feb-2007 DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061850 Well Name/No. PRUDHOE BAY UN POL W-270 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23339-00-00 MD 7750 TVD 5352 Completion Date 3/8!2007 Completion Status WAGIN Current Status WAGIN UIC Y (~Cog --- Induction/Resistivity ~ laic ~ ~ 25 Blu 108 7750 ~ae~ 2/13/2009 ~Jltr~ TVD Vision Service REVISED 26-Feb-2007 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments r,~~ ,.~3 pp33 ygyg-~* { f (g~~ 11 (~ Ubr/~1111~1~6~~~G~ ..n ,,; Ig ~- :w.~.°tlrr48rs;:~r'7]"v~ H NO.5072 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Joh # Loa Description Date BL Coler CD 02/09/09 W-210 40014842 OH MWD/LWD EDIT (REVISED) 'j 02/26/07 2 1 W-36 11968735 RST 03/07/08 1 1 C-30A AMJI-00009 MCNL - / ~ 12/04/08 1 1 W-O1A AWJB-00020 MEMORY LDL ~~ ~ ~~(0 5(0 01/26/09 1 1 E-37A AXBD-00012 MEMORY PROD PROFILE {j - 01/26/09 1 1 F-19 AP3O-00019 CORROSION EVALUATION i 02/01/09 1 1 ~ - ~- f r~tA~t w~rrvuw~tuut rtt~t~r~ tsr siurv~rvu Arvu ttt~ urcrvtrvu urvt wrr tA~n ~ u: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street. Suite 4 J/ j~ Anchorage, AK 9950 -2838 ! ~ ATTN: Beth i' / Received by: /`._®..---------~-~/ •I ~I Schlam~erger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage,AK 99503-2839 ATTN: Beth Well Job # Log Description NO. 4454 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Orion Borealis Date BL Color CD W-213 V-215 Z-108 5.124 11661175 11594491 11212828 40014242 MEM TEMPIPRESS SURVEY CH EDIT PDC GR USIT OH WIRELINE PEX EDIT ` OH MWDILWD EDIT 09/29107 04123/07 02105/06 11/05106 1 2 3 1 1 1 S-125PB1 V•121 V-222 40018467 40015007 40015319 OH MWDILWD EDIT -~ OH MWDILWD EDIT ~ OH MWDILWD EDIT 07/07/07 03124/07 06/08107 2 2 2 1 1 1 W-210 V-218 W-204 W-204PB1 W-204L7 400141142 40015066 40014837 40014637 40014637 OH MWDILWD EDIT OH MWD/LWD EDIT OH MWDILWD EDIT OH MWDILWD EDIT OH MWDILWD EDIT 02/26/07 04/07/07 01/29/07 01/24107 02107/07 2 2 2 2 1 1 1 1 1 1 W-204L2 40014637 OH MWDILWD EDIT /` 02/20107 9 1 PLEASE ACKNOWLEDGE RECEIPT BV SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-L ~ - 900 E Benson Blvd - Anchorage AK 99508-4254, _ ., Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Belh n 10119/07 Date Delivered: ,(l~"~-s e~ ~?+ °5 ('/iii' _ Received byl ~.J~~ /~--~~ _. 09125/07 l~ u Sc~lu~~erger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage,AK 99503.2838 ATTN: Beth Well Job # Log Description NO. 4425 Company: Alaska Oil B Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 700 Anchorage, AK 99501 Field: Polaris Orion Midnight Sun Date BL Color CD E-102 11637355 RST O /,^^ / 07/27/07 7 7 W-210 11626075 CH EDIT PDC GR USIT 03/08107 7 V-2T2 11636644 CH EDIT PDC GR USIT 06/10107 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. _ ~~ •~~~•~ Petrotechnical Dala Center LR2-1 I"~ _ ~ ~: 900 E Benson Blvd. ,i^ „ {~ , Anchorage AK 99508-4254 ~' - Dete Delivered: ~.4 ~.- ~.~'~ r}i A ~ ~~~' Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: ~~ ~_ ~, ,,.<.:~ _. ;VH v~., .~ ~~ Date 07-03-2007 Transmittal Number:92895 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 5(4-4(191 SW Name Date Contractor Log Run Top De th Bottom De th Lo T e W-210 06-01-2007 SCH SAND PVT REPORT Please Sign and Return one copy of this transmittal. Thank You, Andy Farmer ~ ~ ~ ~ ~ v o 7 Petrotechnical Data Center Attn: Don Ince Susan Nisbet Scottt A. Cooley Glenn Fredrick Howard Okland JS ~~3 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 a,©~ - 1$} ~~` ECE~VED ~ ~ STATE OF ALASKA ~ ~~ ~'i`'~~~'% ,I~)N 2 7 2.0(~gSKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas ~p1~E~~~RLETION OR RECOMPLETION REPORT AND LOG 8 Revised 06/27/07: Put on Injection 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.uo ^ GINJ ^ WINJ ^ WDSPL ®WAG ^ Other No. of Completions One 1b. Well Class: ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 3/8/2007 12. Permit to Drill Number 206-185 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/20/2007 13. API Number 50-029-23339-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/26/2007 14. Well Name and Number: PBU W-210i 4344 FSL, 1186 FEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 1967' FSL, 2837' FEL, SEC. 22, T11 N, R12E, UM 8. KB (ft above MSL): 80.1' Ground (ft MSL): 51.6' 15. Field /Pool(s): Prudhoe Bay Field /Polaris Pool Total Depth: 1584' FSL, 2293' FEL, SEC. 22, T11N, R12E, UM 9. Plug Back Depth (MD+TVD) 7662 5292 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 612049 y- 5959321 Zone- ASP4 10. Total Depth (MD+TVD) 7750 5352 16. Property Designation: ADL 028263 TPI: x- 615717 y- 5957000 Zone- ASP4 Total Depth: x- 616268 y- 5956626 Zone- ASP4 11. SSSV Depth (MD+TVD) N/A 17. Land Use Permit: 18. Directional Survey ®Yes ^ No ubmit el tunic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): DIR / GR, GR / RES / AZI-DEN / NEU / PWD, MDT, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD' SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM ' TOP, SBOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 4362' 29' 3358' 12-1 /4" 470 sx AS Lite 410 sx Class 'G' 7" 26# L-80 26' 7745' 26' 5349' 8-3/4" 44 sx LiteCrete 320 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TuelNC RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter 5 spf 3-1/2", 9.2#, L-80 7445' 6811', 7171', , MD TVD MD TVD 7281' & 7359' 6866' - 6876' 4775' - 4781' 7188' - 7240' 4971' - 5006' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7304' - 7342' 5049' - 5075' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 7384' - 7439' 5103' - 5140' 2850' Freeze Protected w! 100 Bbls of Diesel 26. PRODUCTION TEST Date First Production: June 10, 2007 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CARE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None S BFL JUL 0 61D07 Form 10-407 Revised 02/2007 (~i~NTINUEO ON REVERSE SIDE `/~~~ J~~~~ ~- 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 2016' 1925' detailed test information per 20 AAC 25.071. Top Ugnu 4,536' 3,454' MDT was ran. Attached is a summary of MDT results. Ugnu MA 6,508' 4,568' Ugnu MB1 6,542' 4,587' Ugnu M62 6,622' 4,633' Ugnu MC 6,723' 4,691' Schrader Bluff NA 6,823' 4,750' Schrader Bluff NB 6,869' 4,777' Schrader Bluff NC 6,930' 4,812' Schrader Bluff NE 6,946' 4,822' Schrader Bluff NF 7,047' 4,882' Schrader Bluff OA 7,117' 4,925' Schrader Bluff OBa 7,193' 4,975' Schrader Bluff OBb 7,234' 5,002' Schrader Bluff OBc 7,308' 5,052' Schrader Bluff OBd 7,389' 5,107' Schrader Bluff OBe 7,496' 5,179' Schrader Bluff OBf 7,557' 5,221' Schrader Bluff OBf Base 7,633' 5,272' Formation at Total Depth (Name): 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is true and correct to the best of my knowledge. ~ ~ Signed Terrie Hubble Title Technical Assistant Date /~~/Q 7 PBU W-2101 206-185 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mark Staudinger, 564-4337 Permit No. / A royal No. INSTRUCTIONS GeweRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only MEMORANDUM To: Jim Regg n E~~~ ~~zv~~ ~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commi~~5n DATE: Friday, June 22, 200? SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-210 PRUDHOE BAY UNIT W-210 Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv Comm Well Name: PRUDHOE BAY UNIT W-210 Insp Num: mitCS070617101714 Rel Insp Num: API Welt Number 50-029-23339-00-00 Permit Number: 206-185-0 Inspector Name: Chuck Scheve Inspection Date: 6/16/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~'-210 Type Inj. W TVD 4763 IA 1l0 19so 1900 1s9o P.T.D 2061850 TypeTest SPT Test psi 1500 OA 120 340 320 320 Interval ~T~- P/F P Tubing 560 600 600 600 Notes: Friday, June 22, 2007 Page I of I 05/29/07 ~ I Schlumgerger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.4267 Company: Alaska Oil 6 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Polaris Date BL Color CD V-217 40014668 OH EDIT MWDILWD 01112/07 2 1 S-4D1 40014121 OH EDIT MWDILWD 10/21/06 2 1 5-401PB1 40014121 OH EDIT MWDILWD 10108/06 2 1 W-210 11708631 MDT 02127/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc .~.~ ~ Petrotechnical Data Center LR2-1 - ,_ fff333 900 E Benson Blvd. Anchorage AK 99508-4254 ~~'~' ~ ~ 2007 Date Delivered: r1,~`„~-~',p@t~ ~ ~'`g aw, (=t~A,'°7 A,.,.n«`~~i,. br~]~~lec)x~{~.ar~ 8~~~I~nt Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ Received by: _=->-~ ProActive Diagnostic ~~~ ~®~ 1~~'4/il~~®~~4L Services, Inc. To: ApGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 The technical data listed below is being subm' returning a signed copy of this transm' wed herewith. F~ease acknowled e ~tal letter to the attention of : 9 receipt by RE : Cased Hole/Open Hole /Mechanical Logs and/or Tubing Inspection[Caliper/ ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 89518 Fax (907'] 2458952 1] 2) 3J 4) 5) 6) 7J EDE Disk t W - 210 Jewelry log Og..Ma ~ Y-0 ~~ Signed Print Name: ~-r--C~.a-~ ~-t~ ~~Zi . ~~.-~n,1~. ~-(,~z-r Date ~,~,-~°` ~~ r'' . , PROgCTNE DrgGNps v jo •nC SERVtCF.S, (NC., 130 IN, INTERNATIONAL AIRPORT IZD SUITE C, PHONE; (907)245-8951 FAX: 907 ANCHORAGE, qK 99818 E-MAIL. ~~5,•-~asct~+~~, ( )245-8952 . dam, y.t»'.~:~7 WEBSITE: ~MrtRJ~i,~flE1B19;?°f,, y~..~,~Pdd D:\Mazter CoPY_00_PDSANC.20aoAZ WordlDistnbutionlY}anmtithat Sheets\'ttansmit OriBinat.doc 04/25/07 • C~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503.2838 ATTN: Beth Well Job # log Description NO.4223 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Date BL Colar CD L-213 ~ W-210 S-104 11649950 11626075 10563057 MEMORY (PROF USIT INJECTION PROFILE 03117/07 03/06107 05/03103 1 7 1 L-218 L-218 5.111 PB1 S-111P62 L-202 L-202L1 L-202L2 L-202L3 S-122 5-122PB7 S-122P82 S-122P63 10913045 10913045 40011960 40011960 40012011 40012011 40012011 40012011 40012137 40012137 40012137 40012137 CEMENT/PERF EVALUATION MDT OH EDIT MWD/LWD OH EDIT MWD/LWD OH EDIT MWD/LWD OH EDIT MWD/LWD OH EDIT MWD/LWD OH EDIT MWDILWD OH EDIT MWD/LWD OH EDIT MWD/LWD OH EDIT MWDILWD OH EDIT MWDILWD 08!04105 09/04/05 05/24/05 06106/05 06177105 06124105 06129105 07/05105 08N7/05 08/09/05 08/14/05 08/15/05 2 2 2 2 2 2 2 2 2 2 1 1 1 1 1 1 1 t 1 1 1 t PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: A~~ a 200 r~~$ ~I ~ ~~ Ca{JP~VrrlE~C31U Ar Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received ~' . .,i RE~EIU'D- APf~ O ~ ~~~ S STATE OF ALASKA • ~LASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil. & Gas C0149l~~t1~f~LETION OR RECOMPLETION REPORT AND LOG Anchara~e 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAaczs.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One O 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Dat Comp usp., or 3/8/2007 ,~ 12. Permit to Drill Number 206-185 ' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/20/2007 13. API Number 50-029-23339-00-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/26/2007 14. Well Name and Number: PBU W-210i' 4344 FSL, 1186 FEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 1967' FSL, 2837' FEL, SEC. 22, T11 N, R12E, UM 8. KB Elevation (ft): 80.1' 15. Field /Pool(s): Prudhoe Bay Field /Polaris Pool Total Depth: 1584' FSL, 2293' FEL, SEC. 22, T11 N, R12E, UM 9. Plug Back Depth (MD+TVD) 7662 + 5292 Ft ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5959321 Zone- ASP4 10. Total Depth (MD+TVD) 7750 + 5352 Ft 16. Property Designation: ADL 028263 ' TPI: x- 615717 y_ 5957000 Zone- ASP4 Total Depth: x- 616268 y- 5956626 Zone- ASP4 11. Depth where SSSV set N!A MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: DIR / GR, GR / RES / AZI-DEN / NEU / PWD, MDT, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD ,HOLE AMOUNT SIZE WT. PER FT. GRADE TOP - BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 215.5# A-53 Surface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 4362' 29' 3358' 12-1/4" 470 sx AS Lite 410 sx Class 'G' 7" 26# L-80 26' 7745' 2 ' 5349' 8- /4" 44 sx LiteCret 20 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24.' TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 4-1/2" Gun Diameter, 5 spf 3-1l2", 9.2#, L-80 7445' 6811', 7171', MD TVD MD TVD 7281' & 7359' 6866' - 6876' 4775' - 4781' 7188' - 7240' 4971' - 5006' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7304' - 7342' 5049' - 5075' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 7384' - 7439' 5103' - 5140' 2850' Freeze Protected w/ 100 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCUwrED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ,GO~~R~='V~~O~f - ~F~ APR ~ i 20D7 3_~'T~~ None „____._.._--~ Form 10-407 Revised 12/2003 ORI~!N41 ~~. CONTINUED ON REVERSE SIDE ~~ ~ 28. GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NnME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top Ugnu 4,536' 3,454' MDT was ran. Attached is a summary of MDT results. Ugnu MA 6,508' 4,568' Ugnu MB1 6,542' 4,587' Ugnu MB2 6,622' 4,633' Ugnu MC 6,723' 4,691' Schrader Bluff NA 6,823' 4,750' Schrader Bluff NB 6,869' 4,777' Schrader Bluff NC 6,930' 4,812' Schrader Bluff NE 6,946' 4,822' Schrader Bluff NF 7,047' 4,882' Schrader Bluff OA 7,117' 4,925' Schrader Bluff OBa 7,193' 4,975' Schrader Bluff OBb 7,234' 5,002' Schrader Bluff OBc 7,308' 5,052' Schrader Bluff OBd 7,389' 5,107' Schrader Bluff OBe 7,496' 5,179' Schrader Bluff OBf 7,557' 5,221' Schrader Bluff OBf Base 7,633' 5,272' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. w, , / ' (~ / J ~ Signed Terrie Hubble Title Technical Assistant Date ( "~ D PBU W-2101 206-185 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Dolling Engineer: Mark Staudinger, 564-4337 INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only W-210i MDT State Data weu: ', W-2101 I Date:' 2/27-28/2007 Depth Hydrostatic Formation MWE Point Planned Actual TVDSS Before After Diff ' Pressure _,..r_ 1 6550 6550 4511.6 2275.0 2257.0 i; _ ,._ 2130 0 ...._~..._ 8.92 2 6555 6555 4514.5 2269.0 2248.0 ~ 2131.3 8.92 3 6592 6592 4535.6 2283.0 2261.4 21.6 2142.3 j 8.93 4 6632 ~ 6632 4558.5 2298.6 2274.0 24.6 2143.5 1 i 8.89 _ 5 __ 6737 6737 4619.1 2329.0 2305.1 23.9 2161.7 i 8.85 6 6746 6746 4624.4 2332.0 '~, 2306.3 25_7. 2163.0 8.84 7 6784 6784 4647.0 2342.7 ' 2319.0 23.7 ~ 2172.5 0.00 _ 8 _ 6798 6799 4655.4 2345.0 2323.0 22 0 ~ 2177.3 8.84 9; 6874 6874 4699.5 2373.0 2350.6 22 4 I 2166.7 ~ __ 8.72 10! 6880 ; 6880 ! 4703.0 2373.0 2347.5 ~ 25 5_ ~ 2169.8 ~ 8.73 -- 11 6886 6886 4706.5 2374.0 2347.0 `. 27.0 . j 2171.7 873 _ _ 12; 7124 7124 4849.5 2445.0 '~, 2415.0 _ 30.0 2079.4 I 0.00 1311 7130 7130 4853.3 2447.0 2417.0 30.0 ~ 2079.7 _8.11 14 i 7205 7205 4902.6 2473.0 2439.0 34.0 ~ - 1896.1 ; 0.00 15 ~ 7222 ~ I 7222 , 4913.8 2477.0 ', 2451.5 ~ i 25.5. _ I 1904.1 ~ _ 7.33 16i 7226 ~ 7226 4916.6 2472.0 2448.0. 24.0 ~ 1 0:00__ 17 ~ 7226 7225 4915.7 2474.0 I 2453.5: 20.5 _ _ I 1904.7 7.33_ 18~ 7239 7239 4925.2 2484.0 2448.7 35.3__ ~ 1936.2 ~ 7.44 19~ 7315 ~ 7315 4976.3 2513.0 2477.0 36.0 ; 1845.8 ', 7.02 201 7322 ~ 7322 ', 4981.0 2513.6 2475.0 38.6 _ I 1843.0 i __0.00 21 % 7341 7341 4994.0 2509.0 2480.8 28.2 ' 1815.6 ~ ~ 0.00 --- Drawdown Temp On Set ~ Comments PIF ability (mdlcp) (minutes) 158.6 91 0 16.0 20cc, Good test P!f 53.7 91.4 ~ _ 10.0 10+10 cc, Good test P 11.4 __ 92.0 j 10.0 20cc. Good test P 20.5 ! 92.5 ' 13.0 20cc, Good test P 31.2 93.0 10.0 ---- 20cc, Good test 11.9 j 93.6 13.0 ~ 20cc, Good test, slight dray 2.6 94.0 11.0 20cc, Good test, tighter 13.9 __94.3 I 5.0 20cc, Good test 47.6 94.8 l 10.0 ' 20cc, Good test __ 26.6 94.9 i 7.0 ;20cc, Good test 26.2 1 95.1 9.0 ' 20cc, Good test 0.8 ', 95.7 ~ 13.0 ~20cc, Good test _ 3.5 ~ 95.9 ~ 13.0 i 20cc, Good test _ 3.0 ; 96.3 , 17.0 ' 10+10 cc, Good test 73.8 ~ 96.7 13.0 110+10 cc, Good test 97.0 9.0 ;Lost seal 56.1 97.3 7.0 20cc, good test 4.6 97.4 18.0 10+10cc, good test 5.8 97.6 16.0 ~ 10+10cc, good test Interval Mb1 __ Mb1 _ Mb1 _ Mb2 _ __ Mc _ Mc __ Mc Mc Nb Nb Nb P/F I OBa P ; OBa 1.8 i 97.8 18.0 10+10cc, good test, low mobility , P ! OBc _ 0.2 1 98.1 31.0 ',10+10cc, good test, slow buildup ~ P OBc _ 22! 7394 ! 7394 5029.8 2539.5 2503.0 36.5 f 1953.7 ~ 0.00 - _ 3.0 _ 98.5 _ I 15.0 ~20cc, good test -- - P i OBd 231 7404 7404 5036.5 2542.2 2506.5 35.7 I 1955.4 ~ 7.35 9.9 98.8 , 15.0 ~.10+10cc, good test P ~ OBd 24i 7416 ! 7416 5044.8 2547.0 2508.5 38.5 ;I _ 1955 3 I 7.34 6.0 - 99.0 ~ __ 18.0 10+10cc good test P ! OBd 25~ 7425 7425 5050.9 2547.0 2520.0 27.0 ~ 1956.0 .7.33 21.7 99.3 , 11.0 20cc good test P/F IIII OBd 26 ~ 7434 7434 5057.0 2548 0 2515.0 33 0 - 1963 2 ' 7.35 - 3.2 I 99.4 13.0 20cc, good test P OBd 27~ 7504 7504 5104.6 2580 0 2546.0 34.0 ; _. ~ 2235 9 8.30 14.3 99.7 11.0 10+10cc, good test _ ~ P OBe 28' 7508 7508 5107.3 2570.0 2541.0 29.0 ~ 2237.3 ~ 8.30 - 4.9 - 100.0 12.0 10+10cc, good test _ P OBe 29 7564 7564 5145.6 2588.0 _ 2557.0 I 31.0 i 2280.5 i 0.00 ---_ 1.8 _ 100.2 _ 15.0 ' 10+10cc, good test _ P ( OBf 30 7568 7568 5148.0 2583.0 2557.0 ~6.0 2282.0 0.00 1.6 100.6 ' 15.0 ' 20cc, good test P OBf ~ u p a e p s y i Temp PUMP TIM E SEE COMMENTS @ END OF TABLE P/F Interval t ' Planned Actual TVDSS Before After Diff Pressure Start End ~ ~ n _ .~ _._.. ,_... .- ._ ~ , .._, . had hard time flowing, oil is 16.8-17.8 API 1 - - 7425 7425 5050.9 2544.0 ; 1956.0 2317 I _ _____ , 2.37 _.. - - 98.0 _ 120.0 gravity __ F ~ OBd ! i ~' good flowing pressure, oil is 16.3-17.2 API ~ f OBa 2 7222 7222 4913.8 2488.0 2444.0 1900.0 3:00 6:06 96.0 120.0 gravity F ~ On only 1/2 pump -slow to flow, oil is 18.0- OBc 3 7315 7315 4976.3 2505.0 2472.0 6:15 10:00 97.0 180.0 18.7 API Gravity F 4 6880 6880 4703.0 2370.0 2331.0. 11:23 a rox 1500 hrs 93.0 200.0 Began to flow - plu99ed. Pump failed _ _ F 1 Nb 5 6746 6737 2296.0 2425.0 23:36 - 0:00 86.0 -- COULD NOT FLOW _ F ! _- Mc 6746 6746 4624.4 2313.0 2297.0 0:30 1:07 86.0 COULD NOT FLOW F Mc 6746 6799 2322.0 2314.0. 1:18 1:45 87.0 COULD NOT FLOW F I Mc Flowed -filled two 450 cc chambers, one 6 6550 6550 4511.6 2258.0 2239.0 2:30 7:00 87.0 240.0 .was water, one was oil + water _ -- F _ I - Mb1 _ _ 6880 ........ _ _ 6880 ........ 4703.0 .-...n n 2349.0 nn ~.. .. 2322.0 _ nnnn n 7:52 .n... 10:30 ~. 89.0 nn n 120.0 mpsr COULD NOT FLOW !"!ll 11 n AIl1T CI ll1A/ -- - F ; r th H drostatic Formation Time Time id S m l -- De Fl Nb ... Page 1 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: W-210 Common Name: W-210 Test Date Test T e YP Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure ~~ Leak Off Pressure (BHP) EMW _ _ _- 2/25/2007 LOT 4,362.0 (ft) 3,374.0 (ft) 8.80 (ppg) 710 (psi) 2,252 (psi) 12.85 (ppg) Printed: 3/12/2007 12:01:04 PM BP EXPLORATION Page 1 cif 14 Operations Summary Report Legal Well Name: W-210 Common Well Name: W-210 Spud Date: 2/20/2007 Event Name: DRILL+COMPLETE Start: 2/19/2007 End: 3/8/2007 '.Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/8/2007 ',Rig Name: NABOBS 9ES Rig Number: 9ES Date j From - To ~ Hours Task Code NPT Phase ~ Description of Operations 2/18/2007 20:00 - 21:30 1.50 MOB P PRE Move mechanic shop and truck shop from V-Pad to W-Pad 21:30 - 00:00 2.50 RIGD P PRE Secure topdrive un-pin blocks from topdrive, bridle up and 2/19/2007 00:00 - 01:30 1.50 MOB P 01:30 - 04:00 2.50 MOB P 04:00 - 09:30 5.50 MOB P 09:30 - 11:00 1.50 RIGU P 11:00 - 13:00 2.00 RIGU P 13:00 - 20:30 7.50 RIGU P 20:30 - 21:00 0.50 RIGU P 21:00 - 00:00 3.00 RIGU P 12/20/2007 100:00 - 02:30 I 2.501 RIGU I P 02:30 - 03:00 I 0.501 RIGU I P 03:00 - 04:00 I 1.001 RIGU I P 04:00 - 05:30 1.50 RIGU P 05:30 - 07:00 1.50 RIGU P 07:00 - 08:00 I 1.001 RIGU I P prepare floor for move, lower cattle chute. Lay down derrick. Install jeep on pits, pull pits away from sub. PRE Move Sub off V-205 and stage on Pad. PRE Move Camp and Pits from V-Pad to W-pad. Stage pits on W-pad, spot camp and Shops PRE Move Sub from V-Pad to W-Pad PRE Nipple up Diverter tine PRE Spot Rig over W-210, Raise and Pin Derrick PRE PRE PRE PRE PRE PRE PRE PRE PRE 08:00 - 09:00 1.00 RIGU P PRE 09:00 - 15:30 6.50 RIGU P PRE 15:30 - 16:30 1.00 RIGU P PRE 16:30 - 17:30 1.00 RIGU P PRE 17:30 - 20:00 2.50 RIGU P PRE 20:00 - 21:00 I 1.001 BOPSUp P I I PRE Accepted rig ~ 13:00 hrs 2/19/2007 Set Rig mats, lay hreculite and berm, -Set equipment behind rig -Spot Pit complex -Spot MWD, Mud and Geologist shacks -Hook up service lines, hook up interconnects, set stairs, -Take on water into pits -Load Pipe shed with Drill pipe -PJSM, Bridle Down and R/U rig Floor, Hang rig tongs Change Out Top Drive Swivel Packing, Service Top Drive Finish Nipple up on Diverter system -Install 4" valves on conductor -Prep DP in pipe shed -Make up spud mud Finish nippling up riser and flowline, -Install turnbuckles and center riser -prep rig for spud PJSM, Ready rig floor for picking up drill pipe and racking back in derrick P/U 4 Drill Pipe, Tag C~3 50' Clean out 20" conductor -Locate XO's, and drilling tools -Bring to rig floor, steam and strap tools M/U 12 1/4" bit, mud motor, 3 - XO's, 1 stand of 4" DP Pressure test Mud lines to 3500 psi, O.K. Fill stack check for leaks, Install lower 4" valves below lower quick disconnect flange RIH, Tag @ 50', Drill ice down to 105' 310 gpm / 150 psi - 50 rpm / <1 k tq UD motor, bit, and XO's P/U and stand back 108 jts (36 stds) of 15.7# HT40 DP P/U 24 jts of 4" HWDP and rack back into Derrick M/U Jar Stand and one stand of 7" NMDC's P/U and M/U BHA #1 -12 1/4" Bit, 9 5/8" PDM (1.5 deg bend), NMLC, NM Stab, MWD, NM Stab, XO, UBHO, 3-NMDC Diverter Test, -Perform Accum. test -Actuated Annular, pressure dropped to 1800 psi, 200 Psi build 18 secs., Full recovery 1:30 minutes Printed: 3/12/2007 12:01:10 PM ~' BP EXPLORATION Page 2 of 14 Operations Summary Report Legal Well Name: W-210 Common Well Name: W-210 Spud Date: 2/20/2007 Event Name: DRILL+COMPLETE Start: 2/19/2007 End: 3/8/2007 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 3/8/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To ~ Hours Task Code NPT Phase Description of Operations 12/20/2007 20:00 - 21:00 1.00 BOPSU P PRE - 6 Nitrogen Bottles -Avg 2050 psi 21:00 - 21:30 0.50 RIGU P PRE 21:30 - 22:00 0.50 RIGU P PRE 22:00 - 00:00 2.00 DRILL P SURF 2/21/2007 00:00 - 03:00 3.00 DRILL P SURF 03:00 - 04:30 1.50 DRILL N WAIT SURF 04:30 - 12:00 7.50 DRILL P SURF 12:00 - 14:00 2.00 DRILL P SURF 14:00 - 18:00 4.00 DRILL P SURF 18:00 - 19:00 1.00 DRILL P SURF 19:00 - 20:30 1.50 DRILL P SURF 20:30 - 00:00 3.50 DRILL P SURF -checked gas alarms and PVT alarms Good Test Test Witness by BP WSL, Dave Newlon, NAD TP Roy Hunt Witness of test waived by Lou Grimaldi, AOGCC PJSM, On rig up of gyro sheaves Rig up slick line unit for gyros Pre-Spud Meeting with NAD rig crews, NAD Toolpusher, BP WSL Reviewed safety concerns and hazards associated with drilling W-210i Spud ~ 22:00 hrs 2/20/2007 Gyro survey and drill as per Anadrill directional driller from 108-267' 510 GPM - 700 PSI, WOB 5-10k, 65 RPM 1k tq on/off Up wt 49k - Dn wt 49 - Rt wt 49k. Gyro survey and drill as per Anadrill directional driller from 267' to 451' 550 GPM - 1040 PSI, WOB 10-15k, Up wt 60k - Dn wt 60 - Rt wt 60k. Wait on Supersuckers, Discharge valves freezing up on trucks when trying to offload Gyro survey and drill as per Anadrill directional driller from 451' to 1194' -75 Rpm , 3k Tq off / 5 Tq On -550 gpm 1600 psi on / 1450 off 20 - 35k WOB PUW= 65k, SOW=60k, RtWt= 63k 9.2 ppg & 300+ vis. AST = 3.55 hrs /ART = 2.72 hrs. /Total ADT = 6.27 hrs Gyro survey ~ 800,900,1000,1100' -Rig down Gyrodata and HES wireline Drill as per Anadrill directional driller from 1194' to 1671' -80 Rpm , 3k Tq off / 5 Tq On -650 gpm 2400 psi on / 2100 off 20 - 35k WOB PUW= 78k, SOW=72k, RtWt= 75k 9.2 ppg & 300+ vis. CBU 3x - 650 gpm, 2100 psi Monitor well, static 9.2 in/out Short trip to BHA, 1671 - 268' 25k overpull ~ 1130' & 1060' -work ix, O.K. RIH to 1576' 20k Drag @ 1310 - 1330' Wash last stand down to 1671', no fill Drill as per Anadrill directional driller from 1671' to 1989 -80 Rpm , 3k Tq off / 5 Tq On -650 gpm 2500 psi on / 2250 off 20 - 35k WOB PUW= 85k, SOW=70k, RtWt= 78k Printed: 3/12/2007 12:01:10 PM BP EXPLORATION Page 3 of 14 Operations Summary Report Legal Well Name: W-210 Common Well Name: W-210 Spud Date: 2/20/2007 Event Name: DRILL+COMPLETE Start: 2/19/2007 End: 3/8/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/8/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date j From - To Hours Task j Code ~ NPT Phase Description of Operations 2/21 /2007 ~ 20:30 - 00:00 ~ 3.50 ~ DRILL ~ P ~ ~ SURF 9.3 ppg & 300+ vis. 2/22/2007 100:00 - 14:00 I 14.001 DRILL I P 14:00 - 16:00 2.00 DRILL P 16:00 - 20:00 4.00 DRILL P 20:00 - 22:00 I 2.001 DRILL I P 22:00 - 00:00 I 2.001 DRILL I P 12/23/2007 100:00 - 01:00 1.00 ~ DRILL ~ P 01:00 - 05:30 I 4.501 DRILL I P 05:30 - 07:30 2.00 DRILL P 07:30 - 09:30 2.00 CASE P 09:30 - 16:00 I 6.501 CASE I P Drilling time for the last 12 hrs AST = 4.3 hrs /ART = 1.38 hrs. / ADT = 5.68 hrs SURF Drill as per Anadrill directional driller from 1989' to 4370' (TD) -80 Rpm , 3k Tq off / 8 Tq On -614 gpm 3200 psi on / 3400 off 15-30kW06 9.8 ppg & 200+ vis. 104k PUW, 79k SOW, 91k RtWt SURF CBU 3x -656 gpm / 3378 psi, 100 rpm / 4k Tq SURF Monitor well, static POH 4370 - 1671' Worked areas of Intermittent 25k overpulls Precautionary backream sections of 40k overpulls - 3360-3290' and 2340-2244' - 500 gpm- 1600 psi / 50 rpm - 5k Tq SURF TIH 1671 - 4370' Wiped the following depths; 2378-2435, 2640-2722, 2940-3009,3895-3966 Wash down through the tight spots with 3 bpm / 50 rpm Backreamed full stand @ 100 spm , 290 gpm / 1450 psi ran through 1 x after reaming out, no problems cleaning areas up Washed and reamed last stand to bottom, No Fill SURF CBU 3x -100 rpm / 4k Tq -Initial circ. rate ~ 610 gpm / 3400psi -Final circ rate @ 610 gpm / 3200 psi First bottoms up cover 80% of shaker area, Second bottoms 40% of shaker area SURF CBU 3x -100 rpm / 4k Tq -Final circ rate ~ 610 gpm / 3200 psi Pumped 40 bbl , 20 ppb nut plug medium sweep to help clean up of sticky clays Nut plug returned @ 8600 stks. - 602 bbls Shakers cleaned up, less than 5% cuttings return SURF Monitor well, static 9.8 ppg in/out POH 4370 - 2470 without problems, @2470 started pulling with 25-40k overpulls, -washed throught 2470 - 2240' with 80 rpm / 100 spm worked 1x without rotary or pump, O.K. POH to BHA without further problems SURF Laydown BHA #1 - MWD, Stabs, UBHO subs, Mud Motor & Bit Clear tools and equipment from rig floor SURF P/U 9 5/8" Landing joint and make Dummy Run, O.K. C/O Bales and P/U Franks Fill up tool R/U elevators, slips, and power tongs Ready Rig Floor for running 9 5/8" casing SURF PJSM with NAD rig crew, NAD casing crew, Toolpusher and Printed: 3/12/2007 12:01:10 PM ~ ~ BP EXPLORATION Operations Summary Report Page 4 of 14 ~ Legal Well Name: W-210 .,Common Well Name: W-210 Spud Date: 2/20/2007 Event Name: DRILL+COMPLETE Start: 2/19/2007 End: 3/8/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/8/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours ' Task I Code ~ NPT Phase 2/23/2007 09:30 - 16:00 6.50 CASE ~ P ~ ~ SURF Description of Operations BP WSL -P/U Shoe tract Bakerlock all connections below Float collar -Check Floats, O.K. -Dope with BOL 2000, Torqued t/8000 fUlbs -Fill every joint -RIH to 4332' Ran 106 jts of 9 5/8" 40# BTC L-80 casing 25 bow spring centralizers Landing weights - 155k PUW / 90k SOW 16:00 - 16:30 I 0.501 CEMT P SURF 16:30 - 17:00 0.501 CEMT P SURF 17:00 - 18:00 1.00 CEMT P SURF 18:00 - 21:00 3.00 CEMT N WAIT SURF 21:00 - 22:30 I 1.501 CEMT I P I I SURF 22:30 - 00:00 I 1.501 CEMT I P I I SURF 12/24/2007 100:00 - 03:00 I 3.001 CEMT ~ P ~ ~ SURF No problems running casing to bottom / P/U Landing joint and break circ, staged up 8 bpm / 790 psi CBU 1 x with Franks tool, -Reciprocating pipe 10 - 15' -rig down slips ,tongs and other handling equip. Rig down Franks Fill up tool and RU Dowell cement head and cement lines Stage pumps up to 8 bpm / 350 psi -Reciporating pipe 10 - 15' Wait on Supersuckers, continued to Circulate and condition mud C~ 8 bpm / 350 psi -Reciprocating 10-15' Hole In good shape, thinning Mud back to 80 vis. Spot all Vac trucks and Supersuckers Hold PJSM with Dowell/Schlumberger cement hand, NAD rig crew, NAD toolpusher and BP WSL Hold PJSM with Veco and Peak truck drivers, MI mud man and BP WSL Batch up 90 bbl of tail cement -cont. to Condition mud ~ 8 bpm / 350 psi Reduced YP to 17 with 68 vis Swap over DS cementers -Pump 5 bbls of water -Pressure test lines to 3500 psi, O.K. -Pump 70 bbls of 10.0 ppg MUD Push II -Drop bottom plug -pump 10.7 ppg of Artic Set Lite Lead Cement, 250 bbls of lead away C~? midnight Continued pumping surface cement - Pumped a total of 376 bbls of 10.7 ppg ArcticSet LiteCrete cement C~ 5-6 bpm avg. - 129 bbl short, planned to pumped 505 bbls/ 629 sks, Pumped a total of 470 sks calculated. Continue with pumping Tail Pumped 82.5 bbls of 15.8 ppg Class "G" cement @ 5 bpm avg, Last 20 bbls with Durastone added in tail cement, Drop top plug and kick out same with 10 bbls of water. Switch to rig pump and displace cement with 315 bbls of 9.6 ppg mud @ 5 bpm, Stop reciprocating pipe after switching to rig pumps due to pipe drag increasing, Siowed pump to 2 bpm/ 1350 psi with 5 bbls prior to bumping plug. Bump plug on schedule @ 95% efficiency 4525 stks with 1,850 psi. CIP ~ 02:24 hr. Bleed off pressure and check floats - OK. Full returns during all of circulating, cementing and displacement. Returned - 60bbls of cement back to surface. Printed: 3/12/2007 12:01:10 PM BP EXPLORATION Page 5 of 14 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: ~ From - To W-210 W-210 DRILL+ NABOB NABOB Hours COMPL S ALAS S 9ES Task ETE KA DRI Code LING NPT Star I Rig Rig Phase Spud Date: 2/20/2007 t: 2/19/2007 End: 3/8/2007 Release: 3/8/2007 Number: 9ES Description of Operations 2/24/2007 00:00 - 03:00 3.00 CEMT P SURF PU - 198k, SO - 100k prior to landing casing. VECO Supersucker truck # 36014 overfilled truck spilling 80 gals.of cement returns out of secondary containment. Reported to x5700, Sandy Reader, Follow up call from ACS spill tech Greg Giles, Plan forward is to clean up and disposed to G&I. -IR # to follow when recieved from VECO 03:00 - 06:00 3.00 CEMT P SURF Flush all surface equipment, riser, Hydril, UD landing joint, cleanout cellar box and remove 4" valves 06:00 - 09:00 3.00 DIVRTR P SURF Remove Riser, Nipple Down Diverter line and remove Surface Stack 09:00 - 12:00 3.00 WHSUR P SURF Install FMC 11" Through bore Gen 5 Wellhead system and adaptor flange. Torque tubing head to casing head bolts to 350 ft/Ibs. Test metal to metal seal to 1,000 psi - 10 minutes - OK. 12:00 - 15:30 3.50 BOPSU P SURF N/U BOP's, drilling nipple & flowline 15:30 - 16:30 1.00 BOPSU P SURF PJSM, Flush Stack, Set test plug and 4"test joint, R/U to test 16:30 - 22:00 5.50 BOPSU P SURF PJSM, Install test joint and plug, R/U test equip. fill stack, manifold & lines, -Test BOPE, 250 low, 4000psi high, holding each test for 5 min. -Test #1 -Top Rams, Dart, HCR Kill, and choke manifold valves 1,2&3 -Test #2 -choke manifold valves 4, 5 & 6° -Test #3 -choke manifold valves 7, 8, 9 -- -Test #4 -hydraulic choke & manual choke -Test #5 -choke manifold valves 10, 11, 14 -Test #6 -choke manifold valve #15 -Test #7 -HCR Choke& Kill valves -Test #8 -Manual Choke & Kill valve, Lower IBOP ~, -Test #9 -Lower Pipes & Upper IBOP -Test #9 -Annular to 250psi low, 3500 psi High -Test #10 -choke manifold valves 12, 13 & Blind Rams Install 3 1/2" test joint -Test #11 -Lower Pipes Rams with 3 112" test joint -Test #12 -Upper Pipes Rams with 3 1/2" test joint Accumulator test Initial pressure 3000, 1,550 psi after functioning all valves, 36 sec for 200 psi recovery, 2:51 for full recovery to 3,000 psi Average charge for 6 bottles of Nitrogen is 2,050 psi Test of Witness waived by AOGCC Jeff Jones, Witness by BP WSL Alan Madsen, Dave Newlon and NAD TP Kelly Cozby, Brian Tiedemann 22:00 - 23:00 1.00 BOPSU P SURF Install Wear Bushing and blow down Choke and mud lines 23:00 - 00:00 1.00 BOPSU P SURF P/U 27 joints of 15.7# 4" DP 1x1 and stand back in derrick 2/25/2007 00:00 - 02:00 2.00 DRILL P PROD1 M/U BHA #2 -Bit, PDM, NM stab, LWD/MWD, 2xNMDC, HWDP, Jars, HWDP 02:00 - 03:00 1.00 DRILL N DFAL PROD1 Shallow hole test MWD/LWD -530 gpm 1230 psi Attempted ~ 990' & 1450' Printed: 3/12/2007 12:01:10 PM BP EXPLORATION Operations Summary Report Legal Well Name: W-210 Common Well Name: W-210 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To Hours Task Code NPT Start: 2/19/2007 Rig Release: 3/8/2007 Rig Number: 9ES Page 6 of 14 ~ Spud Date: 2/20/2007 End: 3/8/2007 Phase Description of Operations 2/25/2007 02:00 - 03:00 1.00 DRILL N DFAL PROD1 03:00 - 06:00 3.00 DRILL P 06:00 - 07:00 1.00 EVAL P 07:00 - 08:30 I 1.501 DRILL I P 08:30 - 09:00 I 0.501 DRILL I P 09:00 - 10:00 1.00 DRILL P 10:00 - 10:30 I 0.501 DRILL I P 10:30 - 12:00 I 1.501 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 12/26/2007 100:00 - 08:00 I 8.001 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Unsuccessful Test, will try again MWD tested O.K. while drilling out shoe track. RIH to 4154' picking up 4" DP 1x1 Break circ. and Perform casing pressure test Pumped 79 stks (4.5 bbls) @ 10 stks /min Test held 3500 psi for 30 min., Good Test _ Charted & recorded test every 5 stks. Wash down and tag cement, -clean out cmt down to FC, Tag ~ 4275', -Drill Shoe track @ 550 gpm, 2360 psi on / 2250 psi off - 60 rpm, 4k tq off / 6k tq on, 4k WOB Tag Float shoe on depth @ 4361' Displace to new 8.8 LSND mud, Continued to drill rat hole & 20' of new hole 4370-4390' (3374') " 550 gpm 1500 psi on / 1200 psi off, 100 rpm 5k tq Perform LOT @ csg. depth of 4362 (3374' tvd)- -LOT with 8.8 ppg mud -charted test -Pumped C~3 10 spm (.58 bpm) -Pressure leak off @ 710 psi -EMW 12.85 ppg -held pressure for 10 min. - bleed off and blow out lines Obtain bench mark ECD readings and slow pump rates 9.49 ECD C~ 585 gpm / 100 rpm Drill Directionally as per Anadrill Directional Driller, 4390' - 4728' (3562'tvd) -100Rpm,5kTgoff/6TgOn - 585 gpm, 1400 psi off / 1700 psi on - 5-15k WOB -PUW= 113k, SOW=75k, RtWt= 94k - CECD = 9.5 /AECD = 10.0 - Backream 60' /stand each connection full drilling rates, AST=0.0 hrs /ART=0.83 hrs. PROD1 Drill Directionally as per Anadrill Directional Driller, 4728' - 7021' (4866'tvd) -100Rpm,7kTgoff/9TgOn - 585 gpm, 2600 psi off / 2900 psi on - 10-25k WOB - PUW= 137k, SOW=90k, RtWt= 108k - CECD = 9.75 /AECD = 10.39 - Backream 60' /stand each connection full drilling rates, - Pumped 40 bbl Hi-Vis Sweep @ 5033', 50% increase in cuttings - Pumped 40 bbl Hi-Vis Sweep ~ 6133', 0% increase in cuttings AST=2.48 hrs /ART=4.88 hrs. PROD1 Drill Directionally as per Anadrill Directional Driller, 7021' - 7750' (5352') -100Rpm,8kTgoff/10TgOn Printed: 3!122007 12:01:10 PM BP EXPLORATION Page 7 of 14 ~ Operations Summary Report Legal Well Name: W-210 Common Well Name: W-210 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING j Rig Name: NABOBS 9ES Date From - To ~ Hours Task 'Code NPT 2/26/2007 00:00 - 08:00 8.00 DRILL P 08:00 - 13:00 5.00 DRILL P 13:00 - 16:30 3.501 DRILL P 16:30 - 17:00 I 0.501 DRILL I P 17:00 - 18:30 ~ 1.50 ~ DRILL P 18:30 - 21:30 3.00 DRILL P 21:30 - 22:00 0.50 DRILL P 22:00 - 00:00 2.00 DRILL P 12/27/2007 00:00 - 00:30 0.50 DRILL P 00:30 - 04:30 4.00 EVAL P 04:30 - 05:00 0.50 EVAL P 05:00 - 10:00 5.00 EVAL P 10:00 - 12:00 2.00 EVAL P 12:00 - 12:30 0.50 EVAL P 12:30 - 23:30 11.00 EVAL P Spud Date: 2/20/2007 Start: 2/19/2007 End: 3/8/2007 I Rig Release: 3/8/2007 Rig Number: 9ES Phase Description of Operations PROD1 - 585 gpm, 2850 psi off / 3100 psi on - 10-25k WOB -PUW= 150k, SOW=96k, RtWt= 117k - CECD = 9.78 / AECD = 10.51 - Backream 60' /stand each connection full drilling rates, - Pumped 40 bbl 11.2ppg Hi-Vis Sweep ~ 7033', 10% increase in cuttings PROD1 Monitor well, static - 9.3 ppg in/out PUW-164 /SOW-102 no pumps Backream 7750 to 6430' -585 gpm, 2800 psi / 100 rpm, Tq 8-10k Backreamed C~ 1000fph except in areas required MAD passing Mad passed ~ 300 fph - 7200-7000, 6590-6430' PROD1 Reduced pump rate due to 10 bbl. loss continued to Backream 6430 to 4362' (shoe) -490 gpm, 2100 psi / 100 rpm, Tq 8-10k Backreamed ~ 1000fph PROD1 CBU ~ shoe -reciprocating pipe -550 gpm, 1900 psi Monitor well, Static PROD1 Slip and cut drilling line -service Top Drive, Crown and drawworks PROD1 POH to BHA PROD1 Pre-job safety meeting on handling RA source on surface PROD1 L/D DC's, Remove RA source from LWD collar, L/D LWD & MWD, Break Bit and lay down mud motor -Clear floor and lay down Stabs & subs off of rig floor and ready to pick-up logging tools PROD1 Clear and clean rig floor. OTHCMP Pre-job Safety meeting on picking up and running drill pipe conveyed MDT logging tools -Meeting attended by SWS personnel, NAD rig crew and toolpusher, BP WSL Pick up Logging tools and equipment from outside, -Make up logging tools Plug in and verify tools OTHCMP Secure wireline sheave in derrick. OTHCMP Run in hole with MDT logging tools on drill pipe to 6,283'. Circulate 10 minutes each at 2,000', 4 bpm, 155 psi and at 4,300', 4 bpm, 305 psi. PU - 107k, SO - 69k at shoe. Circulate down every 5 stands to avoid solids build-up on DWCH in open hole. OTHCMP Make up side door entry sub. Pump down, RIH and latch up with wet connect at 44 gpm, 200 psi. Confirm latch up. OTHCMP Continue running in hole from 6,283' to 6,556'. OTHCMP Take MDT pressure samples from 6,556' to 7,574'. Total of 29 ' samples taken. 6,556', 6,561', 6,598', 6,638', 6,743', 6,752', 6,790', 6,804', 6,880', 6,886', 6,892', 7,130', 7,136', 7,211', 7,228', 7,232', 7,245', 7,321', Printed: 3/72/2007 12:01:70 PM s BP EXPLORATION Operations Summary Report Legal Well Name: W-210 Common Well Name: W-210 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date ~ From - To j Hours ~ Task ~ Code NPT ~ ~ EVAL P 2/27/2007 112:30 - 23:30 I 11.00 23:30 - 00:00 0.50 EVAL P '2/28/2007 00:00 - 15:30 15.50 EVAL P 15:30 - 16:30 1.00 EVAL N DFAL 16:30 - 18:30 2.00 EVAL N DFAL 18:30 - 21:30 3.00 EVAL N DFAL 21:30 - 23:30 2.00 EVAL N DFAL 23:30 - 00:00 0.50 EVAL N DFAL 3/1/2007 00:00 - 01:00 1.00 CLEAN N DFAL 01:00 - 03:00 ~ 2.00 CLEAN N DFAL 03:00 - 03:30 0.50 CLEAN N DFAL 03:30 - 05:00 1.50 CLEAN N DFAL 05:00 - 07:00 2.00 CLEAN N DFAL 07:00 - 09:00 2.00 CLEAN N DFAL 09:00 - 10:30 1.50 CLEAN N DFAL 10:30 - 11:30 1.00 CLEAN N DFAL 11:30 - 12:00 0.50 CLEAN N DFAL 12:00 - 13:00 1.00 EVAL N DFAL 13:00 - 15:30 2.50 EVAL N DFAL 15:30 - 18:30 3.00 EVAL N DFAL 18:30 - 19:30 1.00 EVAL N DFAL 19:30 - 21:00 1.50 EVAL N DFAL 21:00 - 23:00 2.001 EVAL I N ~ DFAL 23:00 - 23:30 0.50 EVAL N DFAL 23:30 - 00:00 0.50 EVAL P 3/2/2007 00:00 - 02:00 2.00 EVAL P 02:00 - 07:30 5.50 EVAL P 07:30 - 12:30 5.00 EVAL P Start: 2/19/2007 Rig Release: 3/8/2007 Rig Number: 9ES Page 8 of 14 Spud Date: 2/20/2007 End: 3/8/2007 Phase Description of Operations OTHCMP 7,328', 7,347', 7,400', 7,410', 7,422', 7,431', 7,440', 7,510', 7,514', 7,570', 7,574'. All readings good. OTHCMP Take MDT fluid samples starting at 7,425'. s OTHCMP Continue DPC MDT fluid sampling at 7,425', 7,222', and 6,880'. , MDT pump failed while taking sample C~ 6,880'. OTHCMP POH from 6,880' to side door entry sub @ 6,283'. OTHCMP POH with W L wet connect. Rig down side door entry sub. OTHCMP Monitor well -static. Break circulation ~ 4 bpm, 400 psi. Pump dry job and POH with DPC MDT tools from 6,283' to 121'. OTHCMP PJSM. Lay down MDT logging tools. OTHCMP Clear and clean rig floor. ', CLEAN Pick up and make up BHA #4 clean out assembly: 8 3/4" HTC MXL-01 used bit, NB STAB, XO, 3ea 5" HWDP, JAR, lea 5" HWDP, XO, 24ea 4" HWDP. CLEAN Run in hole with clean out assembly from 899' to 4,325'. Fill pipe ~ 2,950'. CLEAN Service topdrive and crown. CLEAN Continue running in hole from 4,325' to 7,688' without problem. PU - 190k, SO - 85k without pumps. Precautionary wash from 7,688' to bottom at 7,750'. CLEAN Stage pumps up to 450 gpm, 1,775 psi, 80 rpm, 8.7k TO, and circulate 1 bottoms up. PU - 168k, SO - 82k, RWT - 114k. Pump 20 bbl weighted sweep and Increase pump rate to 585 gpm, 2,560 psi, 100 rpm, 8.5k TO. No increase in cuttings with sweep back to surface. CLEAN Monitor well -static. 9.2 ppg MW. PU - 170k, SO - 90k. POH from 7,750' to 4,362'. CLEAN Monitor well @ shoe -static. Continue POH from 4,362' to 998'. CLEAN Stand back 4" HWDP. Lay down remaining BHA. CLEAN Clear and clean rig floor. OTHCMP PJSM. Pick up and make up MDT logging tools. OTHCMP Test and trouble shoot latch head and MDT tools. OTHCMP Run in hole with DPC MDT logging tools from 87' to 4,266'. Broke circulation C 2,163' with 4 bpm, 140 psi. OTHCMP Circulate bottoms up. 4 bpm, 240 psi. PU - 105k, SO - 68k. OTHCMP Continue running in hole, circulating down every 5 stands C~ 4 bpm, 250 psi from 4,262' to 6,248' OTHCMP Make up side door entry sub and pump down wet connect ~ 4 bpm, 370 psi. Latch in and test wet connect. OTHCMP Run in hole from 6,248' to 6,737'. OTHCMP Obtain MDT fluid sample ~ 6,737'. OTHCMP Attempt to recover MDT fluid samples ~ 6,737', 6,746', and 6,799' (Mc sands) without success. Viscous sands plugging up tools. Formation problem, not a tool problem. Move tools up to 6,550'. OTHCMP Recover MDT fluid sample @ 6,550' (Mb1 sands). OTHCMP Move downhole to 6,880'. Attempt to recover MDT fluid samples ~ 6,880' and 6,886' (Nb sands) without success. Tool plugging up with sand. Suspend logging operations. Yfl(lt2tl: :3/7"L/LVU/ 11:U1:1U YM BP EXPLORATION Operations Summary Report Page 9 of 14 Legal Well Name: W-210 Common Well Name: W-210 Spud Date: 2/20/2007 Event Name: DRILL+COMPLETE Start: 2/19/2007 End: 3/8/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/8/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date ,From - To li Hours Task Code ( NPT Phase I .,3/2/2007 12:30 - 13:30 1.00 EVAL P OTHCMP '~ 13:30 - 15:00 1.50 EVAL P OTHCMP 15:00 - 16:00 I 1.001 EVAL I P I I OTHCMP 16:00 - 17:30 I 1.501 EVAL I P I I OTHCMP 17:30 - 18:30 1.00 EVAL P OTHCMP 18:30 - 19:00 0.50 EVAL P OTHCMP 19:00 - 20:00 1.00 BOPSU P RUNPRD 20:00 - 21:30 1.50 BOPSU P RUNPRD 21:30 - 00:00 ~ 2.501 CASE P I RUNPRD X3/3/2007 100:00 - 02:30 2.501 CASE I P RUNPRD 02:30 - 03:00 0.50 CASE P RUNPRD 03:00 - 08:00 5.00 CASE P RUNPRD 08:00 - 08:30 I 0.501 CASE I P I I RUNPRD 08:30 - 15:30 I 7.001 CASE I P I I RUNPRD Description of Operations POH from 6,886' to 6,236'. Unlatch and POH with wet connect. Rig down side door entry sub. Remove WL sheave from derrick. Monitor well -static. 9.1 ppg MW. PU - 142k, SO - 79k. POH with DPC MDT logging tools from 6,236' to 4,330'. Monitor well at shoe -static. Continue POH from 4,330' to MDT tools. PJSM. Lay down MDT tools. Clear and clean rig floor. Pull wear bushing, flush BOP stack, and install BOP test plug. Change out upper pipe VBR rams to 7". Test 7" rams to 250 psi and 4,000 psi for 5 minutes each. Test witnessed by NAD TP Brian Tiedemann. Pull test plug. Make dummy run with 7" hanger and landing joint - 26'. Change out bales. Rig up to run casing. Pick up and make up 7" shoe track. Check floats - OK. Continue running in hole with 7" 26# L-80 BTC-M casing to TCII crossover @ 1,372'. Make up BTC-M connections to 10,000 fUlbs TO, using Best-O-Life 2000 NM pipe dope. Ran in hole @ 1.5 minutes per joint. Circulated down every 15 ~ joints for 3 minutes. Ran total of 32 BTC-M casing joints and 2 BTC Marker pup joints. '~, Rig up TCII torque turn equipment. Continue running in hole with 7" BTC-M x 7" 26# L-80 TCII casing from 1,372' to 4,342". Make up TCII connections to ', 10,100 ft/Ibs TO, using Jet Lube Seal Guard pipe dope. Ran in hole ~ 1.5 minutes per joint. Circulated down every 15 joints for 3 minutes. Circulate bottoms up @ 208 gpm, 380 psi. PU - 135k, SO - 95k. Continue running in hole with 7" casing from 4,342' to 7,716' without problem. Displacement good. Ran in hole at 2 minutes per joint, filling every joint and circulating down every 10 joints ~ 4 bpm for 5 minutes. Recorded PU and SO weights every 10 joints. Make up hanger and landing joint and land casing on depth ~ 7,745'. HES Float Shoe 2 Jts 7", 26#, L-80 BTC-Mod (#1-2) HES Float Collar ~ 7,661' (PBTD) 7 Jts 7", 26#, L-80 BTC-Mod (#3-9) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ RA ~ 7,356' 23 Jts 7", 26#, L-80 BTC-Mod (#10- 32) 7", 26#, L-80 BTC-Mod Marker Pup Jt. w/ RA ~ 6,391' 7", 26#,L-80 TC-II X BTC-Mod Crossover Jt. ~ 6,372' 156 Jts 7", 26#, L-80 TC-II (#1 - 156) 7" 26# L-80 TC-II Pup Jt. FMC Hanger 7 1/8" x 8 1/4" Rigid Straight Blade Centralizers: Jt. # 1 2 cent. locked down next to shoe. BTC-M Jt. # 2 2 ea. Per joint separated by Printed: 3/12/2007 12:01:10 PM BP EXPLORATION Page 10 of 14 Operations Summary Report Legal Well Name: W-210 Common W ell Name: W-210 Spud Date: 2/20/2007 Event Nam e: DRILL+C OMPLE TE Start : 2/19/2007 End: 3/8/2007 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 3/8/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To ~ Hours Task Code ~ NPT Phase ! Description of Operations 3/3/2007 08:30 - 15:30 7.00 CASE P RUNPRD stop ring Skip Jt. # 3 BTC-M Jts. # 4 thru # 32 2 ea. Per joint separated by stop ring marker and cross over pup 1 ea. floating over entire length TCII Jts. # 1 thru # 11: 2 ea. Per joint separated by. stop ring TCII Jts. # 12 thru # 26: 1 free floating over entire length 102 Total Centralizers, 41 Stop Rings 15:30 - 16:00 0.50 CEMT P RUNPRD Rig down casing fill up tool and rig up cement head. 16:00 - 19:00 3.00 CEMT P RUNPRD Break circulation and stage pump slowly to 5 bpm, 495 psi while reciprocating casing 15' strokes. Lost appx. 5 bbls prior to bottoms up then stopped losing and started gaining back. YP - 16, MW - 9.3 ppg. Held PJSM with Dowell while circulating. 19:00 - 20:30 1.50 CEMT P RUNPRD Switch to Dowell. Pump 5 bbls water. Pressure test lines to 4,000 psi - OK. Pump 32 bbls 10.5 ppg of MudPush II viscosified spacer ~ 4 bpm, 475 psi. Drop bottom wiper plug. Mix on the fly and pump 19 bbls of 12.0 ppg LiteCrete lead cement @ 4 bpm followed by 67 bbls of Class "G" 15.8 ppg tail cement @ 3 bpm avg, 100 psi. Wash cement lines to Tee on rig floor. Drop top plug. 20:30 - 22:30 2.00 CEMT P RUNPRD Switch to rig and displace cement with 294 bbls of 8.5 ppg ', seawater. 1st 234 bbls ~ 5 bpm, 110 psi ICP, 630 psi FCP. Next 26 bbls C~ 2 bpm, 550 psi ICP, 750 psi FCP. Next 34 bbls @ 1 bpm, 735 psi ICP, 940 FCP. Reciprocated casing 15' strokes during entire cement job until121 bbls prior to bump. Bumped plug at calculated strokes with 95% pump efficiency to 1,500 psi. CIP ~ 22:30 hr. Attempted to pressure test casing ', without success due to leaking connection between cement head crossover and landing joint. Tightened connection but !, still leaked. Bleed off pressure, check for flowback - OK. 'Did not have full returns after tail was around float shoe. 22:30 - 00:00 1.50 WHSUR P RUNPRD Install and test 7" x 9 5/8" packoff to 5,000 psi - 10 min- OK. 13/4/2007 00:00 - 00:30 0.50 W HSUR P RUNPRD Rig down packoff running tools. 00:30 - 01:00 0.50 CASE P RUNPRD Pressure test 7" casing to 4,000 psi - 30 min - 30 psi loss. 01:00 - 01:30 0.50 CASE P RUNPRD Bleed off test pressure and blowdown lines. 01:30 - 02:00 0.50 CASE P RUNPRD Perform 7" x 9 5/8" LOT and infectivity test: 4,325' MD / 3,374' TVD 9.3 ppg MW / 390 psi leak off pressure EMW - 11.52 ppg Injection - 3 bpm - 820 psi, pumped total of 4.6 bbls during leak off and infectivity test. 02:00 - 03:00 1.00 CASE P RUNPRD Rig down casing and cement equipment. Clear floor. 03:00 - 03:30 0.50 BOPSU P RUNPRD Flush BOP stack. Install BOP test plug. 03:30 - 05:00 1.50 BOPSU P RUNPRD Change upper rams from 7" to 3.5" x 6" VBR's. 05:00 - 05:30 0.50 BOPSU P RUNPRD Rig up to test rams. 05:30 - 06:00 0.50 BOPSU P RUNPRD Test rams to 250 psi low, 4,000 psi high, 5 min each - OK. 06:00 - 06:30 0.50 BOPSU P RUNPRD Rig down test equipment. Install wear busing and blow down lines. 06:30 - 07:30 1.00 PERFO P OTHCMP Pick up to rig floor and rig up perforation running equipment. Printed: 3/12/2007 12:01:10 PM BP EXPLORATION Page 11 of 14 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To 3/4/2007 107:30 - 10:30 3/5/2007 10:30 - 15:00 W-210 W-210 DRILL+COMPLETE NABOBS ALASKA DRILLING NABOBS 9ES Hours Task Code NPT 3.00 ~ PERFOt~ P 4.501 PERFOBI P 15:00 - 16:00 1.00 PERFO P 16:00 - 16:30 0.50 PERFO P 16:30 - 19:30 3.00 PERFO P 19:30 - 22:00 2.50 PERFO P 22:00 - 22:30 0.50 ~ PERFOB P Spud Date: 2/20/2007 Start: 2/19/2007 End: 3/8/2007 I Rig Release: 3/8/2007 Rig Number: 9ES Phase Description of Operations OTHCMP Pick up and make up DPC perforation assembly: 11 ea 4.5" Power Jet Omega Guns loaded at 5 SPF. 24 ea blanks, including 8 ea blank punchers. XOs, bumper sub and MWD. 'Sim Ops -Injected 2 bbls of 9.3 ppg mud every 2 hours ~ 1/2 bpm: 550 psi, 320 SIP 600 psi, 390 SIP 650 psi, 470 SIP 680 psi, 530 SIP OTHCMP Run in hole with DPC pert assembly from 750' to 7,146'. Shallow hole tested MWD ~ 3,025', 294 gpm, 630 psi - OK. 'Sim Ops - OA injection and freeze protection: UCA compressive strength - 500 psi ~ 10:07 hr. 127 bbls 9.3 ppg mud ~ 1/2 bpm, 830 ICP, 2 bpm, 950 psi, 3 bpm, 1,010 FCP, 680 SIP. 67 bbls 80 deg dead crude C~3 1 bpm, 850 ICP, 3 bpm, 1,300 FCP, 900 SIP. OTHCMP OTHCMP OTHCMP OTHCMP OTHCMP 22:30 - 23:00 0.50 PERFO P OTHCMP 23:00 - 00:00 1.00 PERFO P OTHCMP 00:00 - 06:00 6.00 PERFO P OTHCMP 06:00 - 09:00 3.00 PERFO P OTHCMP 09:00 - 10:00 1.00 PERFO P OTHCMP 10:00 - 11:00 1.00 PERFO P OTHCMP 11:00 - 12:00 I 1.001 PERFOBI P I I OTHCMP 12:00 - 13:30 I 1.501 PERFOBI P I I OTHCMP Log for upper RA Tag from 6,571' to 6,510' (GR depths). 235 gpm, 700 psi. GR log found RA 7 ft high compared to casing pipe tally. Continue RIH from 7,146' to 7,613'. Make up toprive, lower pipe and tag float collar @ 7,655', 6 ft high. PU 152k, SO - 88k. Start displacement of well from 8.5 ppg seawater to 9.0 ppg brine ~ 245 gpm, 685 psi. Pumped brine for 1 drill pipe capacity. Finish hole displacement while logging with MWD from 7,655' to 7,422'. Logs correlated 2 ft high from previous log. Make 2 ft adjustment to drill pipe measurement and confirm perforation shooting depths - OK. Wait on cement for UCA compressive strength to reach 1,000 psi. Lowered topdrive to rig floor and circulated ~ 2 bpm, 100 psi to keep from freezing while WOC. UCA reached 1,000 psi ~ 21:44 hr. Pick up string to position for bottom pert ~ 7,444' and top pert ~ 6,870' DPM. Initiate firing sequence by pump and bleed. Wait 5 minutes for guns to fire. Good indication of guns firing. Well initially lost 8 bbls then was static POH from 7,444' to 6,850'. ' Circulate 2 bottoms up ~ 240 gpm, 950 psi. Lost appx 6 bbls up to 1 1/2 times bottoms up then stopped losing fluid. Shut down pump and observed well -static. MW - 9.0 ppg. `Lost total of 14 bbls of 9.0 ppg brine from perforating time to midnight. POH laying down drill pipe from 6,850' to pert assembly. PJSM. Lay down pert gun assembly. All guns fired. Clear tools and clean rig floor of gun residue. Run in hole with remaining drill pipe out of derrick to 1,800'. Monitor well -static. Cut and slip drilling line 78'. 'Lost 10 bbls of 9.0 ppg brine from midnight to noon. POH laying down drill pipe from 1,800' to surface. Printed: 3/12/2007 12:01:10 PM • BP EXPLORATION Page 12 of 14 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To W-210 W-210 DRILL+C NABOBS NABOBS ~ Hours i OMPLE ALASK 9ES Task ~ TE A DRI Code LING NPT Start I Rig Rig Phase i Spud Date: 2/20/2007 : 2/19/2007 End: 3/8/2007 Release: 3/8/2007 Number: 9ES Description of Operations 3/5/2007 13:30 - 14:30 1.00 EVAL P OTHCMP PJSM. Rig up SLB E-line and GR/JB assembly. 14:30 - 17:00 2.50 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 1: 6.125" tool ran into obstruction C~ 7,206'. POH. Recovered 1/3 Ib perf debris. 17:00 - 19:30 2.50 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 2: 6.125" tool ran into obstruction ~ 7,400'. Beat down on obstruction, taking 1,500 Ibs of overpull to free up. POH. Recovered small amount of perf debris. 19:30 - 22:00 2.50 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 3: 6.125" tool ran into obstruction ~ 7,400'. POH. Recovered 1/8 Ib perf debris. 22:00 - 00:00 2.00 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 4: 6.050" tool to FC ~ 7,655'. POH. Had slight indication of drag ~ 7,400'. *Lost 4 bbls of 9.0 ppg brine from noon to midnight. *Lost 14 bbls total for the day. *Lost 28 bbls total from perforating. 3/6/2007 00:00 - 00:30 0.50 EVAL P OTHCMP Finish POH w Gauge ring /Junk basket Run # 4. Recovered 1 - gallon of perf debris. 00:30 - 03:00 2.50 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 5: 6.125" tool ran into obstruction CAB 7,400'. Beat down on obstruction, taking 1,500 Ibs of overpull to free up. POH. Recovered small amount of perf debris. 03:00 - 05:30 2.50 EVAL P OTHCMP Gauge ring /Junk basket w/ GR run # 6: 6.050" tool to 7,500'. - Made several passes through trouble spot C 7,400 without any drag while running in hole. POH. No debris. 05:30 - 06:00 0.50 EVAL P OTHCMP Rig up USIT tools. 06:00 - 11:00 5.00 EVAL P OTHCMP USIT log 7" casing from 7,617' to surface. Top of cement stringer ~ 4,790'. Top of good cement C~ 5,570'. Logs indicated perfs on depth as reported on 3/4/2007. 11:00 - 12:00 1.00 EVAL P OTHCMP Lay down USIT tools and rig down E-line. -- 12:00 - 15:00 3.00 BUNCO RUNCMP Rig up to run 3.5" Quad Packer completion with I-wire. 15:00 - 23:30 8.50 BUNCO RUNCMP PJSM. Pick up and make up 3.5" 9.2# L-80 TCII completion assembly to last HES packer C~? 673'. Terminate I-wire on packers, test connections to 5,000 psi - OK. Make up assembly using Torq Turn equipment to 2,300 ft/Ibs and dope connections with JetLube Seal Gaurd. All connections below 1st packer in hole Baker Loked. 23:30 - 00:00 0.50 BUNCO P RUNCMP Rig down I-wire spools. *No fluid loss for the day. 3/7/2007 00:00 - 02:00 2.00 BUNCO RUNCMP Pick up control line spools to rig floor. Hang sheaves, splice lines into top packer and Phoenix valve. Test lines to 5,000 psi - OK. 02:00 - 19:00 17.00 BUNCO RUNCMP Continue running in hole with 3.5" completion assembly to 7,482'. Space out and set completion on depth in reference to pipe tally. Checked I-wire integrity every 1,000' while running in hole. 19:00 - 20:30 1.50 BUNCO RUNCMP Rig up SLB E-line. 20:30 - 22:30 2.00 BUNCO RUNCMP Run in hole with CUGR tools and log-in tubing. Corrected tally -8 ft. POH with wireline. 22:30 - 00:00 1.50 BUNCO RUNCMP Rig down SLB E-line. Pull up hole to top joint of tubing. 3/8/2007 00:00 - 02:00 2.00 BUNCO RUNCMP Pick up and make up landing joint and tubing hanger. Terminate I-wire and control lines to hanger. Test same to 5,000 psi - OK. ', 00:00 - 02:00 2.00 BUNCO RUNCMP Land tubing. PU - 92k, SO - 59k with blocks. Printed: 3/12/2007 12:01:10 PM • BP EXPLORATION Page 13 of 14 Operations Summary Report Legal Well Name: W-210 Common Well Name: W-210 Spud Date: 2/20/2007 Event Name: DRILL+COMPLETE Start: 2/19/2007 End: 3/8/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/8/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date !From - To ~ Hours Task Code NPT Phase Description of Operations 3/8/2007 00:00 - 02:00 2.00 BUNCO RUNCMP 3.5" 9.2 # WLEG, 3.5" TC-II 3.5" HES 'X' Nipple: 2.813" ID 3.5" HES 'X' Nipple: 2.813" ID RHC-M Plug GLM #1 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 3.5" HES 'X' Nipple: 2.813" ID 3.5" x 7" HES single feedthru Packer (1 port) #1 packer GLM #2 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch GLM #3 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch Phoenix Sensor sub 3.5" x 7" HES single feedthru Packer (1 port) # 2 packer 3.5" HES 'X' Nipple: 2.813" ID GLM #4 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch GLM #5 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch 3.5" x 7" HES Dual feedthru Packer (2 ports) #3 packer 9 jts 3.5" 9.2# L-80 TC-I I Tubing (# 1-9) RA pip in joint # 2 3.5" HES 'X' Nipple: 2.813" ID GLM #6 - 3.5" x 1.5" MMG-W w/ RD Dummy- RK latch Phoenix Sensor sub 3.5" x 7" HES Dual feedthru Packer (2 ports) # 4 packer 3.5" HES 'X' Nipple: 2.813" ID 1 jts 3.5" 9.2# L-80 TC-11 Tubing (# 10 ) GLM#7 -3.5"x1.5" MMG w/DCR-1 w/RKP latch 133 jts 3.5" 9.2# L-80 TC-II Tubing (#11 - 143) 3.5" HES 'X' Nipple: 2.813" ID 77 jts 3.5" 9.2# L-80 TC-II Tubing (# 144 - 220 ) 2 ea space out pup jts. 3.5" 9.2# L-80 TC-II 5.8 and 7.8 1 jt 3.5" 9.2# L-80 TC-II Tubing (# 221 ) pup jt 3.5" 9.2# L-80 TC-II 4.5" X 3.5" TC-II Crossover FMC Tubing Hanger w/4 1/2" TC-II Lifting Threads 15 ea half I-wire clamps 126 ea full clamps 02:00 - 02:30 0.50 BUNCO RUNCMP Run in tubing head lock down screws. Rig up lines to set and test packer. 02:30 - 04:00 1.50 BUNCO RUNCMP Drop 1 5/16 ball rod with rollers. Lay down landing joint. Pressure up tubing to 500 psi, hold for 3 minutes. Continue pressure up to 4,000 psi. Had indication of packers setting ~ 2,500 psi. Hold 4,000 psi for 30 minute tubing test -Good test. Bleed tubing pressure down to 2,500 psi. Pressure test inner annulus to 4,000 psi for 30 minutes -Good test. Tubing pressure started tracking annulus pressure starting at 3,300 psi. Bleed annulus pressure to 0 psi. Tubing pressure stayed at 3,500 psi. Bleed tubing pressure to 0 psi. Pressure up inner ', annulus to shear DCR valve. Sheared at 2,700 psi. Confirm pumpability by pumping both ways through DCR valve - OK. 04:00 - 04:30 0.50 BUNCO RUNCMP Install 2-way check and test same to 1,000 psi from below - il OK. 04:30 - 05:00 0.50 BUNCO RUNCMP Lay down HES I-wire equipment. 05:00 - 07:00 2.00 BOPSU P RUNCMP Nipple down BOPE. Printed: 3/12/2007 12:01:10 PM • BP EXPLORATION Page 14 of 14 ~ Operations Summary Report Legal Well Name: W-210 Common Well Name: W-210 Spud Date: 2/20/2007 Event Name: DRILL+COMPLETE Start: 2/19/2007 End: 3/8/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/8/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date {From - To ; Hours I Task I Code I NPT 3/8/2007 107:00 - 10:30 ( 3.501 WHSUR P 10:30 - 11:30 1.00 WHSUR P 11:30 - 12:00 0.50 WHSUR P 12:00 - 13:00 1.00 WHSUR P 13:00 - 14:00 1.00 WHSUR P 14:00 - 16:00 2.00 WHSUR P 16:00 - 17:30 I 1.50 I W HSUR I P 17:30 - 19:00 1.50 WHSUR P 19:00 - 20:00 1.00 WHSUR P 20:00 - 22:00 I 2.001 WHSUR I P 22:00 - 00:00 I 2.001 RIGD I P Phase ~ Description of Operations RUNCMP Install SBMS, nipple up tree adapter. Terminate I-wires and check wire integrity. Test I-wire and adapter flange to 5,000 psi - OK. RUNCMP Nipple up production tree. RUNCMP Fill tree with diesel and test to 5,000 psi - OK. RUNCMP Rig up lubricator and pull 2-way check valve. RUNCMP Rig up to reverse circulate and test lines to 3,000 psi - OK. RUNCMP Reverse circulate 236 bbls of 9.0 ppg clean brine down IA, followed by 78 bbls of 9.0 ppg inhibited brine ~ 3 bpm, 370 psi. / RUNCMP Rig up LRHOS. PJSM. Pressure test lines to 3,000 psi - OK. + Reverse circulate 100 bbls of 60 deg diesel ~ 2 bpm, 220 psi ICP, 550 psi FCP, 400 psi SICP. RUNCMP Line up to U-tube diesel. U-tube diesel from IA to tubing. Well freeze protected to 2,850 MD, 2,500 ND. RUNCMP Rig up lubricator and install BPV. Test BPV to 1,000 psi from below - OK. Final pressures: Tubing - 0 psi IA - 0 psi OA - 120 psi RUNCMP Install VR plugs in IA and OA. Remove working valves and secure cellar. RUNCMP Finish cleaning pits and empty remainder of mud pit fluids. Prepare for rig move. 'Release rig from W-210i operations for move to V-201 i ~ 23:59 hr, 3/8/2007. Printed: 3/12/2007 12:01:10 PM by _I~~ ~~ ~i,,,~ Schl~ qe ~R ~~~d ,~'~~ •~^ w~ w A w r ~d ~ ,IWi_. vv-c i u purvey r~epvr~ Report Date: February 26, 2007 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 123.170° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 it Structure /Slot: W-PAD / W-210 TVD Reference Datum: Rotary Table Well: W-210 drilliing ND Reference Elevation: 80.10 ft relative to MSL Borehole: W-210 Sea Bed /Ground Level Elevation: 51.60 ft relative to MSL UWUAPI#: 500292333900 Magnetic Declination: 23.841 ° Survey Name /Date: W-210 /February 23, 2007 Total Field Strength: 57639.016 nT Tort /AHD / DDI / ERD ratio: 98.960° / 5015.71 ft / 5.857 / 0.937 Magnetic Dip: 80.889° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: February 23, 2007 Location LaULong: N 70.29781003, W 149.09259910 Magnetic Declination Model: BGGM 2006 Location Grid NIE Y/X: N 5959321.230 ftUS, E 612048.880 ftUS North Reference: True North Grid Convergence Angle: +0.85428766° Total Corr Mag North -> True North: +23.841 ° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head • Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure tt de de n tt n n it n ft de ao tt ftUS ttUS Hit U.UU V.VV V.UU -tfU.1V U.VV V.VU U.VV V.UU V.VV V.VV V.VV 0~0~3L I.LJ OICV90.00 IV /V.L.7/OIVVJ VV IH.7.VyG'~71V GYD CT DMS 100.00 0.18 178.41 19.90 100.00 0.09 0.16 0.16 -0.16 0.00 0.18 5959321.07 612048.89 N 70.29780960 W 149.09259907 200.00 0.23 191.30 119.90 200.00 0.25 0.51 0.51 -0.51 -0.03 0.07 5959320.72 612048.86 N 70.29780863 W 149.09259935 300.00 0.19 170.66 219.90 300.00 0.44 0.88 0.87 -0.87 -0.04 0.08 5959320.36 612048.85 N 70.29780765 W 149.09259945 400.00 0.27 193.75 319.90 400.00 0.63 1.27 1.27 -1.26 -0.07 0.12 5959319.97 612048.83 N 70.29780658 W 149.09259969 500.00 3.50 88.03 419.84 499.94 3.21 4.31 3.24 -1.39 2.92 3.58 5959319.89 612051.82 N 70.29780624 W 149.09257543 600.00 4.28 87.19 519.61 599.71 8.72 11.09 9.76 -1.10 9.70 0.78 5959320.27 612058.60 N 70.29780702 W 149.09252055 700.00 4.96 90.44 619.28 699.38 15.38 19.15 17.78 -0.95 17.75 0.73 5959320.54 612066.64 N 70.29780743 W 149.09245537 800.00 5.71 99.76 718.85 798.95 23.58 28.42 27.04 -1.83 26.98 1.14 5959319.81 612075.88 N 70.29780504 W 149.09238066 900.00 6.50 111.19 818.28 898.38 33.68 39.03 37.46 -4.72 37.16 1.45 5959317.07 612086.10 N 70.29779714 W 149.09229823 1000.00 8.14 114.32 917.47 997.57 46.22 51.76 49.84 -9.68 48.89 1.69 5959312.28 612097.90 N 70.29778359 W 149.0922 Last GYD CT DMS 1100.00 10.93 116.83 1016.07 1096.17 62.64 68.32 66.00 -16.87 63.80 2.82 5959305.31 612112.92 N 70.29776393 W 149.0920 MWD+IFR+MS 1135.40 12.48 119.07 1050.74 1130.84 69.79 75.50 73.00 -20.25 70.14 4.56 5959302.03 612119.31 N 70.29775471 W 149.09203 1230.25 15.03 118.44 1142.86 1222.96 92.27 98.05 95.14 -31.09 89.92 2.69 5959291.49 612139.24 N 70.29772510 W 149.09187105 1326.73 18.04 114.90 1235.34 1315.44 119.53 125.50 122.40 -43.34 114.47 3.29 5959279.61 612163.98 N 70.29769163 W 149.09167221 1421.54 22.32 113.23 1324.31 1404.41 151.81 158.20 155.05 -56.62 144.35 4.55 5959266.77 612194.04 N 70.29765533 W 149.09143032 1516.79 25.64 114.36 1411.33 1491.43 190.00 196.90 193.73 -72.26 179.75 3.52 5959251.66 612229.67 N 70.29761260 W 149.09114365 1612.68 27.24 116.68 1497.19 1577.29 232.31 239.59 236.35 -90.68 218.26 1.99 5959233.83 612268.45 N 70.29756230 W 149.09083182 1707.74 27.40 117.74 1581.65 1661.75 275.70 283.22 279.85 -110.63 .257.06 0.54 5959214.46 612307.54 N 70.29750780 W 149.09051767 1803.70 28.36 119.40 1666.47 1746.57 320.42 328.09 324.56 -132.09 296.46 1.29 5959193.58 612347.25 N 70.29744915 W 149.09019865 1898.67 32.43 121.00 1748.37 1828.47 368.40 376.13 372.35 -156.29 337.96 4.37 5959170.01 612389.10 N 70.29738303 W 149.08986266 1993.33 36.67 121.97 1826.32 1906.42 422.05 429.80 425.70 -184.34 383.71 4.52 5959142.65 612435.26 N 70.29730639 W 149.08949219 2089.28 37.90 121.61 1902.66 1982.76 480.15 487.92 483.53 -214.96 433.12 1.30 5959112.77 612485.12 N 70.29722274 W 149.08909217 SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-210\W-210 drilliing\W-210\W-210 current Generated 4/5/2007 12:30 PM Page 1 of 3 Comments Measured Inclination Azimuth SuaSea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de tt ft ft ft ft tt ft de 00 ft ttUS ftUS L7t50.4L :SiS.tlL 1Ll,UJ ly/i5.U4 LVb25.14 bay./i5 54/.5y C)4J.UU -L45.y/ 2280.21 40.91 123.22 2050.80 2130.90 600.52 608.34 603.52 -278.30 2375.44 43.56 123.45 2121.30 2201.40 2470.39 46.00 123.11 2188.69 2268.79 2566.34 48.14 122.31 2254.04 2334.14 2662.23 49.86 122.19 2316.95 2397.05 2758.38 51.94 122.58 2377.58 2457.68 2854.65 53.83 121.74 2435.67 2515.77 2949.71 56.50 122.53 2489.97 2570.07 3044.98 56.14 122.46 2542.80 2622.90 3140.93 55.72 122.30 2596.55 2676.65 3236.60 55.11 122.62 2650.86 2730.96 3331.87 56.83 123.94 2704.17 2784.27 3427.53 56.68 124.17 2756.62 2836.72 3522.87 56.52 124.21 2809.10 2889.20 3618.73 56.21 123.82 2862.19 2942.29 3714.70 55.93 124.17 2915.76 2995.86 3810.85 3906.31 4002.71 4098.67 4193.81 4289.80 4311.79 4387.76 4464.63 4559.98 4655.99 4751.73 4847.26 4942.89 5037.78 5133.49 5228.87 5324.31 5420.09 5515.06 5611.41 5706.66 5802.14 5897.31 55.14 55.68 55.38 54.83 56.74 57.45 57.57 56.99 56.46 55.86 55.36 55.27 54.10 54.18 54.39 123.92 124.82 124.39 124.15 124.78 125.43 125.56 125.91 126.39 124.98 125.01 125.08 126.04 125.89 124.01 664.53 731.40 801.65 874.01 948.61 1025.36 1103.37 1182.64 1262.11 1340.87 1419.82 1499.81 1579.39 1659.20 1738.82 672.34 739.22 809.47 881.84 956.45 1033.21 1111.23 1190.51 1269.99 1348.75 1427.70 1507.71 1587.30 1667.11 1746.74 2970.17 3050.27 1818.08 1826. 01 3024.37 3104.47 1896.65 1904. 60 3078.93 3159.03 1976.10 1984. 07 3133.82 3213.92 2054.79 2062. 78 3187.32 3267.42 2133.44 2141. 45 3239.47 3319.57 2213.98 2222. 04 3251.28 3331.38 2232.51 2240. 59 3292.34 3372.44 2296.36 2304. 50 3334.52 3414.62 2360.54 2368. 77 3387.62 3467.72 2439.66 2447. 96 667.22 -313.47 733.84 -350.17 803.91 -388.12 876.16 -426.73 950.67 -466.70 1027.35 -507.55 1105.29 -549.06 1184.49 -591.65 1263.90 -634.22 1342.61 -676.49 1421.45 -719.82 1501.30 -764.62 1580.75 -809.35 1660.44 -853.99 1739.96 -898.51 1819.13 -942.89 1897.60 -987.26 1976.95 -1032.39 2055.57 -1076.71 2134.15 -1121.24 2214.60 -1167.58 2233.11 -1178.35 2296.88 -1215.68 2360.98 -1253.59 2440.02 -1299.79 4t54.Uy 535.52 588.99 644.90 704.02 765.22 828.23 893.22 959.28 1026.14 1093.26 1159.72 1225.72 1292.00 1357.84 1423.99 1490.01 1555.70 1620.56 1685.97 1751.02 1815.87 1881.80 1896.91 1948.79 2000.68 2065.00 I.V:S 5`J5yUt5L.bL 2.66 5959050.97 2.79 5959016.60 2.58 5958980.75 2.31 5958943.68 1.80 5958905.99 2.19 5958866.97 2.08 5958827.09 2.89 5958786.58 0.38 5958744.99 0.46 5958703.44 0.69 5958662.17 2.14 5958619.83 0.25 5958576.03 0.17 5958532.29 0.47 5958488.64 0.42 5958445.11 0.85 5958401.72 0.96 5958358.33 0.48 5958314.18 0.61 5958270.83 2.08 5958227.29 0.93 5958181.93 0.74 5958171.39 0.86 5958134.84 0.86 5958097.71 1.38 5958052.48 3441.85 3521.95 2518.85 2527.19 2519.16 -1345. 23 2129.91 0.52 5958008.02 3496.33 3576.43 2597.53 2605.92 2597.79 -1390. 44 2194.36 0.11 5957963.79 3551.55 3631.65 2675.41 2683.87 2675.62 -1435. 76 2257.77 1.47 5957919.41 3607.57 3687.67 2752.83 2761.37 2752.99 -1481. 28 2320.50 0.15 5957874.84 3662.97 3743.07 2829.83 2838.41 2829.96 -1525. 41 2383.65 1.62 5957831.66 54.82 125.16 3718.40 3798.50 2907.82 2916.43 2907.93 -1569.70 2447.88 1.08 5957788.34 55.57 124.16 3772.85 3852.95 2986.11 2994.75 2986.20 -1614.23 2512.30 1.17 5957744.77 55.62 123.61 3826.77 3906.87 3064.85 3073.49 3064.93 -1658.13 2577.67 0.48 5957701.85 56.25 123.15 3880.42 3960.52 3144.19 3152.84 3144.27 -1701.79 2643.92 0.77 5957659.20 55.39 123.59 3933.78 4013.88 3222.75 3231.40 3222.83 -1745.00 2709.54 0.98 5957616.97 55.33 123.28 3988.54 4068.64 3302.02 3310.67 3302.09 -1788.68 2775.69 0.27 5957574.29 56.02 123.42 4042.25 4122.35 3380.69 3389.33 3380.75 -1831.92 2841.40 0.73 5957532.03 57.16 123.55 4094.83 4174.93 3460.39 3469.03 3460.45 -1875.90 2907.87 1.20 5957489.06 57.08 123.90 4146.49 4226.59 3540.31 3548.96 3540.36 -1920.27 2974.34 0.32 5957445.68 t)lLS;it).b4 N /U.L`J/1;it5U1 W 14y.UtStSli/y4tf 612588.44 N 70.29704969 W 149.08826305 612642.43 N 70.29695358 W 149.08783011 612698.88 N 70.29685333 W 149.08737744 612758.54 N 70.29674963 W 149.08689885 612820.31 N 70.29664412 W 149.08640333 612883.90 N 70.29653491 W 149.08589323 612949.48 N 70.29642328 W 149.08536707 613016.15 N 70.29630987 W 149.08483225 613083.64 N 70.29619349 W 149.08429091 613151.38 N 70.29607718 W 149.08374750 613218.46 N 70.29596167 W 149.0832 613285.09 N 70.29584327 W 149.08267520 613352.02 N 70.29572085 W 149.08213861 613418.52 N 70.29559862 W 149.08160562 613485.32 N 70.29547662 W 149.08107009 613551.99 N 70.29535495 W 149.08053565 613618.33 N 70.29523367 W 149.08000393 613683.84 N 70.29511243 W 149.07947887 613749.91 N 70.29498909 W 149.07894936 613815.60 N 70.29486797 W 149.07842286 613881.11 N 70.29474629 W 149.07789785 613947.72 613962.98 614015.40 614067.85 614132.85 614198.42 614263.53 614327.61 614391.01 614454.80 614519.67 614584.74 614650.76 614717.65 614783.89 614850.68 614917.02 614984.14 615051.26 N 70.29461963 W 149.07736418 N 70.29459020 W 149.07724194 N 70.29448819 W 149.07682199 N 70.29438458 W 149.07640195 N 70.29425832 W 149.07588131 N 70.29413414 W 149.07535597 N 70.29401059 W 149.0748 N 70.29388671 W 149.0743 N 70.29376231 W 149.07381329 N 70.29364169 W 149.07330220 N 70.29352065 W 149.07278234 N 70.29339892 W 149.07226096 N 70.29327892 W 149.07173189 N 70.29315960 W 149.07119565 N 70.29304149 W 149.07066461 N 70.29292210 W 149.07012922 N 70.29280389 W 149.06959743 N 70.29268369 W 149.06905946 N 70.29256239 W 149.06852148 SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-210\W-210 drilliing\W-210\W-210 current Generated 4/5/2007 12:30 PM Page 2 of 3 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS byy3.L/ 5b.i5J ILS.bL 47`Ji5.25L 4L/rS.yL 3bLV./4 3bLy.4U JbLV./`J -1yb4.y/ JV41.LL U.3b 5y5/4U1.`Jy b1b1125./`J IV /V.YyL44ULV VV 74y .Ub/ytfULC 6088.61 56.15 123.91 4251.45 4331.55 3700.23 3708.89 3700.27 -2009.15 3107.30 0.76 5957358. 80 615185.52 N 70.29231943 W 149 .06744547 6184.09 56.13 124.74 4304.65 4384.75 3779.50 3788.18 3779.53 -2053.86 3172.78 0.72 5957315. 08 615251.65 N 70.29219721 W 149 .06691557 6279.53 55.95 124.98 4357.97 4438.07 3858.62 3867.34 3858.65 -2099.11 3237.74 0.28 5957270. 81 615317.27 N 70.29207353 W 149. 06638992 6374.29 55.37 124.96 4411.42 4491.52 3936.83 3945.58 3936.85 -2143.95 3301.85 0.61 5957226. 93 615382.04 N 70.29195094 W 149. 06587106 6471.17 55.20 125.74 4466.60 4546.70 4016.40 4025.21 4016.41 -2190.02 3366.81 0.68 5957181. 83 615447.67 N 70.29182499 W 149. 06534545 6566.63 55.24 124.91 4521.05 4601.15 4094.75 4103.62 4094.76 -2235.36 3430.77 0.72 5957137. 46 615512.30 N 70.29170106 W 149. 06482780 6661.29 55.01 124.72 4575.17 4655.27 4172.38 4181.28 4172.38 -2279.70 3494.53 0.29 5957094. 08 615576.70 N 70.29157985 W 149. 06431186 6757.53 53.73 124.91 4631.24 4711.34 4250.57 4259.50 4250.57 -2324.35 3558.75 1.34 5957050. 39 615641.58 N 70.29145777 W 149. 06379218 6853.27 54.43 125.29 4687.40 4767.50 4328.06 4337.03 4328.06 -2368.94 3622.19 0.80 5957006. 76 615705.66 N 70.29133589 W 149. 06327889 6948.13 54.23 124.85 4742.72 4822.82 4405.08 4414.10 4405.08 -2413.22 3685.26 0.43 5956963. 43 615769.38 N 70.29121484 W 149. 06276852 2 7044.67 52.92 124.27 4800.04 4880.14 4482.73 4491.77 4482.74 -2457.28 3749.23 1.44 5956920. 33 615833.99 N 70.29109437 W 149. 062 7140.73 49.43 125.12 4860.26 4940.36 4557.53 4566.60 4557.54 -2499.86 3810.75 3.70 5956878. 68 615896.14 N 70.29097796 W 149. 06175304 7235.80 47.89 125.62 4923.05 5003.15 4628.86 4637.98 4628.87 -2541.18 3868.96 1.67 5956838. 24 615954.95 N 70.29086501 W 149. 06128208 7331.24 47.48 125.17 4987.30 5067.40 4699.38 4708.55 4699.39 -2582.05 3926.49 0.55 5956798. 23 616013.08 N 70.29075326 W 149. 06081659 7427.48 47.18 125.39 5052.53 5132.63 .4770.09 4779.31 4770.12 -2622.92 3984.25 0.35 5956758. 23 616071.44 N 70.29064152 W 149. 06034918 7523.27 47.18 125.52 5117.64 5197.74 4840.30 4849.57 4840.33 -2663.68 4041.49 0.10 5956718. 33 616129.27 N 70.29053010 W 149. 05988610 7618.88 47.06 125.57 5182.70 5262.80 4910.30 4919.63 4910.34 -2704.41 4098.49 0.13 5956678. 46 616186.88 N 70.29041874 W 149. 05942485 Last MWD+IFR+MS 7680.94 47.13 124.67 5224.95 5305.05 4955.73 4965.09 4955.78 -2730.56 4135.67 1.07 5956652. 87 616224.44 N 70.29034724 W 149. 05912401 TD (Projected) 7750.00 47.13 124.67 5271.93 5352.03 5006.32 5015.71 5006.38 -2759.35 4177.30 0.00 5956624. 70 616266.49 N 70.29026852 W 149. 05878720 Survey Type: Definitive Survey NOTES: GYD CT DMS - ( Gyrodata -cont. d rillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) indrill-pipe.) MWD +IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is appl ied to enhance inclination accuracy. ) Leaal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surtace : 4344 FSL 1186 FEL S21 T11 N R12E U M 5959321.23 612048.88 BHL : 1583 FSL 2295 FEL S22 T11 N R12E U M 5956624.70 616266.49 r ~ ~J SurveyEditor Ver SP 2.1 Bld( doc40x_100) W-210\W-210 drilliing\W-210\W-210 current Generated 4/5/2007 12:30 PM Page 3 of 3 .E ~ ~- :NELLHEAD = FMc ACTUATOR = ___..w.. HYD KB. ELEtI= _. ~~~ 28_S BF. ELEV = $1' KOf~ .. Max Angle = -`~0; 57° ~ 4311' ',Datum MD = - Datum TVD = 634 -- 4~18Q' • 9 518" CSC, 441At, L-80, .07583 bpt, ~ = 8.835" ~ 43s1'~ 7" 26# L-80 TC-11 X BTC-M XO Joint ""~'~~~. Minimum Ia - 2.813" 3-1/Z" HES X MPPL.E 7' MARKER JOINT WI RA TAG - 6391" ~ 3-112 TBG Wt RA Tag ~ MARKER JOINT"w/ RA TAG I-I ~~' PERFORATION St11ARY REF Lt3G: ANGLE AT T4P PERF: S4° ~r Note: SQE SPF __ INTERVAL OpnlSgz DATE ~ 5 ~ ~~~, 4 ,3rs- C o3J04/Q7 ,_,:" 5 _ 1 ,43? O 1x3/04/07_ 4 t, t"" 5 '' . r, '3t)s t 0 0 3 1 {I4K37 .y ~t-~. ~ P'54-1 ~. ~f ~ . . V yy ~~ Y 5 ©aL04liJ7 __... .. ~L 3112° TBG, 9,2#, L-Fitt, .tM7871 1D = 29,.92" PBTD 7" CSC, 2611, L=84, .0382 bpf, ID = 6.276" 7661" ~uo-rES: +cc~n's ~ sTA ~~ - ARE -1 /2'" X 1=112" Nf M G-W W HI!CIi ARE WATT-tUt~l~ MATUDR~L~. 2515' 3-112" HES X NIP, ID ~ 2.813° WATERFLOOt11GASLlFT MANDRELS ST MD TV D DEV Tf PE V LV LATCH PORT DATE 7 57a2 4636 54 MMG DCR-i RKP 9 03!1381`07 6 6;,31 4758 54 MMGW [h'3'f RiC J 03/138107 5 7'!94 4975 4!1 MMG-W L~.J[~`f RK 0 03108107 ~ 7232 5001 48 MMGW i~M'f Riff ~ 03t08/07 3 7:~~7 5044 4~; N-W Ca'fr R1E t7 03108!07 2 7335 507Q 4I MMG-W C?~If~ RK ~7 03/08/07 1 74L73 5116 47 hN+/fG-W t}MY 0 fJ3/08107 679" ~ 3-1/7• HES X NIP. ID = 2.813" 6$11' 7"X3-it2" HES AHR Packnr, IL1= 2 555' 6$2s1" phoenix 6er~tsr Sub, iD = 2.875" 6865' 3-112" HES X NIP, tD = 2.813•' 7170' 1._.. 7""X3-112"' HES AHR Packer, ID = 2.965" 7261' ~ 3-112" HE5 X N1P, ID ^ 2.833" 72$1' 7"X3-112" HES AHR Packet', ID = 2.9~" 72~ Phenix Sensor Sub,. ID = 2.875" 7358' ~~ 7"X3-112" HES AHR Packcer, fD - 2985' ~ 73$2' 3112" HES X Nip, fD = 2.813" 7431' _ 3-112" HES X NIP, iD = 2.833" wtRHGm plug 7452 3112" HES X tJlp, ID = 2&13" 7474' ~ 3112" WLEG, ID = 2.9115' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/08/07 9-es Original Drill & Complete 43110107 tPAG DRLfa DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: W-2101 Permit No: 206-185 API No: 50-029-23339-00 SEC 21, T11 N, R12E, UM BP Exploration (Alaska} I SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Polaris Well .....................: W-210 API number ...............: 50-029-23339-00 Engineer .................: Bezerra RIG :.....................: Nabors 9ES STATE :...................: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 51.60 ft KB above permanent.......: 80.10 ft DF above permanent.......: 80.10 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)......... 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 0.00 degrees O [(c)2007 IDEAL ID12_OC_01] 26-Feb-2007 10:43:35 Page 1 of 4 Spud date ................: 20-Feb-07 Last survey date.........: 26-Feb-07 Total accepted surveys...: 84 MD of first survey........: 0.00 ft MD of last survey........: 7750.00 ft ----- Geomagnetic data ---------------------- Magnetic model............: BGGM version 2006 Magnetic date ............: 20-Feb-2007 Magnetic field strength..: 57639.01 GAMA Magnetic dec (+E/W-).....: 23.85 degrees Magnetic dip .............: 80.89 degrees ----- MWD survey Reference Reference G ..............: Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57639.00 GAMA 80.89 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections -------------------- Magnetic dec (+E/W-).....: 23.85 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.85. degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction • • t SCHLUP'IBERGER Survey Report 26 -Feb-2007 10:43:35 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (f t) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0..00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.18 178.41 100.00 100.00 -0.16 -0.16 0.00 0.16 178.41 0.18 BP_ GYD CT DMS 3 200.00 0.23 191.30 100.00 200.00 -0.51 -0.51 -0.03 0.51 183.43 0.07 BP_ GYD CT DMS 4 300.00 0.19 170.66 100.00 300.00 -0.87 -0.87 -0.04 0.87 182.83 0.08 BP_ GYD CT DMS 5 400.00 0.27 193.75 100.00 400.00 -1.26 -1.26 -0.07 1.27 183.27 0.12 BP_ GYD CT DMS 6 500.00 3.50 88.03 100.00 499.94 -1.39 -1.39 2.92 3.24 115.39 3.58 BP_ GYD CT DMS 7 600.00 4.28 87.19 100.00 599.71 -1.10 -1.10 9.70 9.76 96.47 0.78 BP_ GYD CT DMS • 8 700.00 4.96 90.44 100.00 699.38 -0.95 -0.95 17.75 17.78 93.06 0.73 BP_ GYD CT DMS 9 800.00 5.71 99.76 100.00 798.95 -1.83 -1.83 26.98 27.04 93.87 1.14 BP_ GYD CT DMS 10 900.00 6.50 111.19 100.00 898.38 -4.72 -4.72 37.16 37.46 97.23 1.45 BP_ GYD CT DMS 11 1000.00 8.14 114.32 100.00 997.57 -9.68 -9.68 48.89 49.84 101.20 1.69 BP_ GYD CT DMS 12 1100.00 10.93 116.83 100.00 1096.17 -16.87 -16.87 63.80 66.00 104.81 2.82 BP_ GYD CT DMS 13 1135.40 12.48 119.07 35.40 1130.84 -20.25 -20.25 70.14 73.00 106.10 4.56 BP_ MWD+IFR+MS 14 1230.25 15.03 118.44 94.85 1222.96 -31.09 -31.09 89.92 95.14 109.07 2.69 BP_ MWD+IFR+MS 15 1326.73 18.04 114.90 96.48 1315.44 -43.34 -43.34 114.47 122.40 110.74 3.29 BP_ MWD+IFR+MS 16 1421.54 22.32 113.23 94.81 1404.41 -56.62 -56.62 144.35 155.05 111.42 4.55 BP_ MWD+IFR+MS 17 1516.79 25.64 114.36 95.25 1491.43 -72.26 -72.26 179.75 193.73 111.90 3.52 BP_ MWD+IFR+MS 18 1612.68 27.24 116.68 95.89 1577.29 -90.68 -90.68 218.26 236.35 112.56 1.99 BP_ MWD+IFR+MS 19 1707.74 27.40 117.74 95.06 1661.75 -110.63 -110.63 257.06 279.85 113.28 0.54 BP_ MWD+IFR+MS 20 1803.70 28.36 119.40 95.96 1746.57 -132.09 -132.09 296.46 324.56 114.02 1.29 BP_ MWD+IFR+MS 21 1898.67 32.43 121.00 94.97 1828.47 -156.29 -156.29 337.96 372.35 114.82 4.37 BP_ MWD+IFR+MS • 22 1993.33 36.67 121.97 94.66 1906.42 -184.34 -184.34 383.71 425.70 115.66 4.52 BP_ MWD+IFR+MS 23 2089.28 37.90 121.61 95.95 1982.76 -214.96 -214.96 433.12 483.53 116.40 1.30 BP_ MWD+IFR+MS 24 2185.42 38.82 121.03 96.14 2058.14 -245.97 -245.97 484.09 543.00 116.94 1.03 BP_ MWD+IFR+MS 25 2280.21 40.91 123.22 94.79 2130.90 -278.30 -278.30 535.52 603.52 117.46 2.66 BP MWD+IFR+MS 26 2375.44 43.56 123.45 95.23 2201.40 -313.47 -313.47 588.99 667.22 118.02 2.79 BP_ MWD+IFR+MS 27 2470.39 46.00 123.11 94.95 2268.79 -350.17 -350.17 644.90 733.84 118.50 2.58 BP_ MWD+IFR+MS 28 2566.34 48.14 122.31 95.95 2334.14 -388.12 -388.12 704.02 803.91 118.87 2.31 BP_ MWD+IFR+MS 29 2662.23 49.86 122.19 95.89 2397.05 -426.73 -426.73 765.22 876.16 119.15 1.80 BP_ MWD+IFR+MS 30 2758.38 51.94 122.58 96.15 2457.68 -466.70 -466.70 828.23 950.67 119.40 2.19 BP MWD+IFR+MS [(c)2007 IDEAL ID12_OC_01] SCHLiJl~'IBERGER Survey Report 26 -Feb-2007 10:43:35 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2854.65 53.83 121.74 96.27 2515.77 -507.55 -507.55 893.22 1027.35 119.61 2.08 BP _MWD+IFR+MS 32 2949.71 56.50 122.53 95.06 2570.07 -549.06 -549.06 959.28 1105.29 119.79 2.89 BP _MWD+IFR+MS 33 3044.98 56.14 122.46 95.27 2622.90 -591.65 -591.65 1026.14 1184.49 119.97 0.38 BP _MWD+IFR+MS 34 3140.93 55.72 122.30 95.95 2676.65 -634.22 -634.22 1093.26 1263.90 120.12 0.46 BP _MWD+IFR+MS 35 3236.60 55.11 122.62 95.67 2730.96 -676.49 -676.49 1159.72 1342.61 120.26 0.69 BP _MWD+IFR+MS 36 3331.87 56.83 123.94 95.27 2784.27 -719.82 -719.82 1225.72 1421.45 120.42 2.14 BP _MWD+IFR+MS 37 3427.53 56.68 124.17 95.66 2836.71 -764.62 -764.62 1292.00 1501.30 120.62 0.25 BP _MWD+IFR+MS • 38 3522.87 56.52 124.21 95.34 2889.20 -809.35 -809.35 1357.84 1580.75 120.80 0.17 BP _MWD+IFR+MS 39 3618.73 56.21 123.82 95.86 2942.29 -853.99 -853.99 1423.99 1660.44 120.95 0.47 BP _MWD+IFR+MS 40 3714.70 55.93 124.17 95.97 2995.86 -898.51 -898.51 1490.01 1739.96 121.09 0.42 BP _MWD+IFR+MS 41 3810.85 55.14 123.92 96.15 3050.27 -942.89 -942.89 1555.70 1819.13 121.22 0.85 BP _MWD+IFR+MS 42 3906.31 55.68 124.82 95.46 3104.47 -987.26 -987.26 1620.56 1897.60 121.35 0.96 BP _MWD+IFR+MS 43 4002.71 55.38 124.39 96.40 3159.03 -1032.39 - 1032.39 1685.97 1976.95 121.48 0.48 BP _MWD+IFR+MS 44 4098.67 54.83 124.15 95.96 3213.92 -1076.71 - 1076.71 1751.02 2055.57 121.59 0.61 BP _MWD+IFR+MS 45 4193.81 56.74 124.78 95.14 3267.42 -1121.24 - 1121.24 1815.87 2134.15 121.69 2.08 BP _MWD+IFR+MS 46 4289.80 57.45 125.43 95.99 3319.56 -1167.58 - 1167.58 1881.80 2214.60 121.82 0.93 BP _MWD+IFR+MS 47 4311.79 57.57 125.56 21.99 3331.38 -1178.35 - 1178.35 1896.90 2233.11 121.85 0.74 BP _MWD+IFR+MS 48 4387.76 56.99 125.91 75.97 3372.44 -1215.68 - 1215.68 1948.79 2296.88 121.96 0.86 BP _MWD+IFR+MS 49 4464.63 56.46 126.39 76.87 3414.62 -1253.59 - 1253.59 2000.68 2360.98 122.07 0.86 BP _MWD+IFR+MS 50 4559.98 55.86 124.98 95.35 3467.72 -1299.79 - 1299.79 2065.00 2440.02 122.19 1.38 BP _MWD+IFR+MS 51 4655.99 55.36 125.01 96.01 3521.94 -1345.23 - 1345.23 2129.91 2519.16 122.28 0.52 BP _MWD+IFR+MS • 52 4751.73 55.27 125.08 95.74 3576.43 -1390.44 - 1390.44 2194.36 2597.79 122.36 0.11 BP _MWD+IFR+MS 53 4847.26 54.10 126.04 95.53 3631.65 -1435.76 - 1435.76 2257.77 2675.62 122.45 1.47 BP _MWD+IFR+MS 54 4942.89 54.18 125.89 95.63 3687.67 -1481.28 - 1481.28 2320.50 2752.99 122.55 0.15 BP _MWD+IFR+MS 55 5037.78 54.39 124.01 94.89 3743.07 -1525.41 - 1525.41 2383.65 2829.96 122.62 1.62 BP MWD+IFR+MS 56 5133.49 54.82 125.16 95.71 3798.50 -1569.70 - 1569.70 2447.88 2907.93 122.67 1.08 BP _MWD+IFR+MS 57 5228.87 55.57 124.16 95.38 3852.95 -1614.23 - 1614.23 2512.30 2986.20 122.72 1.17 BP _MWD+IFR+MS 58 5324.31 55.62 123.61 95.44 3906.87 -1658.13 - 1658.13 2577.67 3064.93 122.75 0.48 BP _MWD+IFR+MS 59 5420.09 56.25 123.15 95.78 3960.52 -1701.79 - 1701.79 2643.92 3144.27 122.77 0.77 BP _MWD+IFR+MS 60 5515.06 55.39 123.59 94.97 4013.88 -1745.00 - 1745.00 2709.54 3222.83 122.78 0.98 BP MWD+IFR+MS [(c)2007 IDEAL ID12_OC_01] SCHLUMBERGER Survey Report 26 -Feb-2007 10:43:35 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5611.41 55.33 123.28 96.35 4068.64 -1788.68 -1788.68 2775.69 3302.09 122.80 0.27 BP_ MWD+IFR+MS 62 5706.66 56.02 123.42 95.25 4122.35 -1831.92 -1831.92 2841.40 3380.75 122.81 0.73 BP_ MWD+IFR+MS 63 5802.14 57.16 123.55 95.48 4174.93 -1875.90 -1875.90 2907.87 3460.45 122.83 1.20 BP_ MWD+IFR+MS 64 5897.31 57.08 123.90 95.17 4226.59 -1920.27 -1920.27 2974.34 3540.36 122.85 0.32 BP_ MWD+IFR+MS 65 5993.27 56.83 123.62 95.96 4278.92 -1964.97 -1964.97 3041.22 3620.79 122.87 0.36 BP_ MWD+IFR+MS 66 6088.61 56.15 123.91 95.34 4331.55 -2009.15 -2009.15 3107.30 3700.27 122.89 0.76 BP_ MWD+IFR+MS 67 6184.09 56.13 124.74 95.48 4384.75 -2053.86 -2053.86 3172.78 3779.53 122.92 0.72 BP_ MWD+IFR+MS • 68 6279.53 55.95 124.98 95.44 4438.07 -2099.11 -2099.11 3237.74 3858.65 122.96 0.28 BP_ MWD+IFR+MS 69 6374.29 55.37 124.96 94.76 4491.52 -2143.95 -2143.95 3301.85 3936.85 123.00 0.61 BP_ MWD+IFR+MS 70 6471.17 55.20 125.74 96.88 4546.69 -2190.02 -2190.02 3366.80 4016.41 123.04 0.68 BP_ MWD+IFR+MS 71 6566.63 55.24 124.91 95.46 4601.15 -2235.36 -2235.36 3430.77 4094.76 123.09 0.72 BP_ MWD+IFR+MS 72 6661.29 55.01 124.72 94.66 4655.27 -2279.70 -2279.7.0 3494.53 4172.38 123.12 0.29 BP_ MWD+IFR+MS 73 6757.53 53.73 124.91 96.24 4711.34 -2324.35 -2324.35 3558.75 4250.57 123.15 1.34 BP_ MWD+IFR+MS 74 6853.27 54.43 125.29 95.74 4767.50 -2368.94 -2368.94 3622.19 4328.06 123.19 0.80 BP_ MWD+IFR+MS 75 6948.13 54.23 124.85 94.86 4822.82 -2413.22 -2413.22 3685.26 4405.08 123.22 0.43 BP MWD+IFR+MS 76 7044.67 52.92 124.27 96.54 4880.14 -2457.28 -2457.28 3749.23 4482.74 123.24 1.44 BP_ MWD+IFR+MS 77 7140.73 49.43 125.12 96.06 4940.35 -2499.86 -2499.86 3810.75 4557.54 123.26 3.70 BP_ MWD+IFR+MS 78 7235.80 47.89 125.62 95.07 5003.15 -2541.18 -2541.18 3868.96 4628.87 123.30 1.67 BP_ MWD+IFR+MS 79 7331.24 47.48 125.17 95.44 5067.40 -2582.05 -2582.05 3926.49 4699.39 123.33 0.55 BP_ MWD+IFR+MS 80 7427.48 47.18 125.39 96.24 5132.63 -2622.92 -2622.92 3984.25 4770.11 123.36 0.35 BP MWD+IFR+MS 81 7523.27 47.18 125.52 95.79 5197.74 -2663.68 -2663.68 4041.49 4840.33 123.39 0.10 BP_ MWD+IFR+MS • 82 7618.88 47.06 125.57 95.61 5262.80 -2704.41 -2704.41 4098.49 4910.34 123.42 0.13 BP_ MWD+IFR+MS 83 7680.94 47.13 124.67 62.06 5305.05 -2730.56 -2730.56 4135.67 4955.78 123.43 1.07 BP_ MWD+IFR+MS 84 7750.00 47.13 124.67 69.06 5352.03 -2759.35 -2759.35 4177.30 5006.38 123.45 0.00 Project to TD [(c)2007 IDEAL ID12_OC_01] Re: W-210i USIT . Subject: Re: W-Z10i USIT From: Thomas Maunder <tom maunderwadmin.state.ak.us> Date: Tue, 10 Apr 2007 14:40:27 -0800 To: "Peltier, Brandon" <Brandon.Peltier@bp.com> CC; "Tirpack,Rob~rt B"<Robert.Tirpack~BP.com>, "Staudinger, Mark" <M~k.Staudirrger c~BP.com> Thanks much. Peltier, Brandon wrote, On 4/10/2007 2:35 PM: Tom Attached is the W-2101 USIT log from March 6, 2007. Brandon Peltier BP Exploration (Alaska), Inc. Operations Drilling Engineer GPB Rotary Drilling (907) 564-5912 (Direct) (907) 748-7838 (Mobile) Brandon.Peltier{a}bp.com «W-2101 USIT 03062007.zip» Psu w-ZIO ~ZO6-ISS) Subject; PB1J W-210 (20b-18s) From: Thomas Maunder <tom_maunder@admin~.state.ak us> Date: Tue; 10 Apr 2007 1 ~ : l c: x:42 -0800 '(~o: -~n~lr~~v Fai-~ner .~r~dr~~~.Farn~~r ~r hP.c~~m=~; Cl~ct'e'~Tt~er ct~lever(u:pnuihoe-bav.oiltield.slb.con~=> CC: Rohert I`irpack~:Robcrt.Tii-pa~k~Bl'.ccrn~ ~~~ ~~~~ Gentlemen, I am reviewing the completion report for this injection well. Could you please send an electronic copy of the USIT run of March 6. Thanks in advance, Tom Maunder, PE AOGCC ~ ~ Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Christine Mahnken ~AOGCC) Well No W-210 Date Dispatched: 6-Mar-07 Installation/Rig Nabors 9ES Dispatched By: Nate Rose LWD Log Delivery V1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: ,lames H.,lonnson Received By: BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) .~ ^ ' C/y~ ~ 900 E. Benson Blvd. `/ , ~/~ Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~bp.com oZow-r~i r 11T~FItQA~'I®11T C~rY1~IISSi®1Q Robert Tirpack Senior Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519 • SdIRAO~I P,4LlN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit, Polaris. Pool, W-2101 BP Exploration Alaska, Inc. Permit No: 206-185 Surface Location: 4344' FSL, 1186' FEL, Sec. 21, Tl 1N, R12E, UM Bottomhole Location: 1606' FSL, 2288' FEL, Sec. 22, T11N, R12E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness equired test, contact the Commission's petroleum field inspector at (907 659- 607 (pager). C DATED this day of January, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASiG4 ~ALA~OIL AND GAS CONSERVATION COM N 0 PERMIT TO DRILL 20 AAC 25.005 ti~ RECEIV~t ~ DEC 2 1 2006 =~~~ska ~~(~ 6as Cans. Coi~ttnisson 1 a. Type of work ® Drill ^Redrill Q Re-Entry 1 b. Current Well Class O Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is pr ^ 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 W-2101 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 7755' TVD 5368' 12. Field /Pool(s): Prudhoe Bay Field /Polaris Pool 4a. Location of Well (Governmental Section): UM + 4344' FSL 1186' FEL SEC 21 T11 N R12E 7. Property Designation: ADL 028263-2 ~ , ~ P ~ ~~ ,, , , , , , Top of Productive Horizon: 1824' FSL, 2607' FEL, SEC. 22, T11N, R12E, UMW 8. Land Use Permit: 13. Approximate Spud Date: Janu 6-2QOT- Total Depth: J 1606' FSL, 2288' FEL, SEC. 22, T11 N, R12E, UM 9. Acres in Property: 2560 ~ 14. Distance to Nearest Property: 14670' 4b. Location of Well (State Base Plane Coordinates): Surface: x-612049 y-5959321 Zone-ASP4 10. KB Elevation _ (Height above GL): 51.6 feet 15. Distance to Nearest Well Within Pool: 308' away from W-05 16. Deviated Wells: Kickoff Depth: 500 feet Maximum Hole Angle: 56 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2400 Surface: 1870 18. Casin Pro ram: S ecifications Top - Settin De th -Bottom Quanti of Cement, c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 WLD 108' Surface Surface 108' 108' 260 sx Arctic Set A rox. 12-.1 /4" 9-5/8" 40# L-80 BTC 4394' Surface Surface 4394' 3386' 647 sx AS Lite, 406 sx Class 'G' 8-3/4" 7" 26# L-80 TCII/BTGM 7755' Surface Surface 7755' 5368' 56 sx LiteCrete, 291 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): Casing Length ze Cement Volume MD TVD Conductor /Structural Surface Intermediate Producti n Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program O Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mark Staudinger, 564-4337 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~~ ~'1--.~ ~ Phone 5~~/~L/ ~. Date Oa ~~ Dry Sondra Stewman, 564-4750 Commission Use Onl y )r1War Z ub7 Permit To Drill Number: v?O~C,- /~S API Number: 50- po?9-3339 da-oo Permit pprov~ Date: ~ See cover letter for other requirements Conditions of Approval: _ If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales ~~` ~ ~~'~~ ~~~~`~ `~ S Samples Req'd: 'Yes ^ No Mud Log Req'd~ ~, Yes (~No ~i~ ~~~\ ~`'~4t~'Tp ~5 ~ ~~ ~~~ HZS Measures: [~ Yes ^ No Directions Survey Req'd: ~ Yes ^ No Other: ~~~~ S`c «~ ~ ~'~ © ~c~~~'O~SF~ 0.0001 f n~ c~ ~ ~ ~l ~~ ~S t OVED BY THE COMMISSIO Date ~" ~ 3-0 ,COMMISSIONER Form 10-401 Revised 12/2005 E /' ~ / v ~ Submit In Duplicate &~ ~ ~ ~ Well Name: W-2101 Drill and Complete Plan Summary. T e of Well service / roducer / in'ector : Injector Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface Location 612049 5959321 0 11 N 12E 21 4344 1185 T t1: To OBa 615950 5956860 4900 11N 12E 22 1824 2607 T t2: 250' below OBe 616273 5956647 5287 11 N 12E 22 1606 2288 AFE Number: API Number: 50-029-xxxxx Estimated Start Date: January 20, 2007 O eratin da s: 18 Ri Nabors 7ES TMD 7,755' TVD rkb: 5,368' RKB/GL 28.5'/51.6' RTE 80.1' Well Design: USH Grassroots Schrader Bluff Injector 3-'/z", L-80, TC-II, multi acker, zonal in'ection, and zonal monitorin com letion Current Status: New drill General Well Information: Estimated BHP: 2391 psi (8.7 ppg EMW) at 5287' TVD Estimated BHT: 105 deg F at 5287' TVD Formation Markers: Est. Est. Commercial Pore Est Est. Formation Formation Uncertainty Hydrocarbon . press. Pore Tops Tops Bearing press. Formation MD (TVDss) (feet) (Yes/No) (Psi) (ppg EMW G1 391 -310 +/-50' No 140 8.7 SV6 1283 -1190 +/-50' No 536 8.7 SV5 2011 -1835 +/-50' No 826 8.7 Base 2036 Permafrost -1855 +/-50' No 835 8.7 Possible gas or gas SV4 2190 -1980 +/-50' h drates 891 8.7 Possible gas or gas SV3 2945 -2495 +/-50' h drates 1123 8.7 Possible gas or gas SV2 3312 -2700 +/-50' h drates 1215 8.7 Possible gas or gas SV1 3884 -3020 +/-50' h drates 1359 8.7 UG4 4537 -3385 +/-50' Thin Coal 1523 8.7 Heavy Oil 3440 - UG4A 4635 -3440 +/-50' 3525' SS 1548 8.7 UG3 5261 -3790 +/-50' Thin Coals 1706 8.7 UG1 6146 -4285 +/-50' No 1928 8.7 Fault 1 6655 -4570 +/- 150' MD UG Ma - n/a n/a n/a W-210i Permit to Drill Page 1 • • Faulted out UG_Mb1 - Faulted out n/a n/a n/a UG_Mb2 6664 -4575 +/-50' No 2059 8.7 UG_Mc 6753 -4625 +/-50' Heavy Oil 4625 - 4665' SS 2081 8.7 SB_Na 6852 -4680 +/-50' No 2106 8.7 SB Nb 6896 -4705 +/-50' Heavy Oil 4705 - 4725' SS 2117 8.7 SB_Nc 6959 -4740 +/-50' No, wet 2133 8.7 SB_Ne 6973 -4748 +/-50' No, ti ht 2137 8.7 SB_OA 7113 -4845 +/- 25' Yes 2156 8.6 SB OBa 7208 -4900 +/- 25' Yes 1920-2050 7.5-8.0 SB_OBb 7246 -4927 +/- 25' Yes 2217 8.7 SB OBc 7317 -4977 +/- 25' Yes 2070-2180 8.0-8.5 SB_OBd 7393 -5031 +/- 25' Yes 1970-2090 7.5-8.0 SB OBe 7498 -5105 +/- 25' No 2297 8.7 SB_OBf 7554 -5145 +/- 25' No 2315 8.7 Base SB OBf 7622 -5193 +/- 25' No 2337 8.7 TD Colville 7755 -5286 +/- 25' No 2391 8.7 Wells within a ~/a mile of this injection well, scanned from the top of the reservoir to TD Well Name Distance ft Annulus Inte rit Comments W-05 308 _ TOC calculated to be in UG_Ma sand. Distance between wells for injection zones is 400'-460'. W-08 46 6 TOC calculated to be in Colville Shale below Schrader Bluff. W-01 . 64 TOC calculated to be in the UG_Mb2 interval. W-203 1220 Offset roducer. Distance is for OBa-OBd. W-07A 1274 TOC calculated to be in Colville Shale below the Schrader Bluff. The TOC calculations are based on the cement volumes pumped with 30% excess in the annular space. W-08 and W-07A both have a calculated TOC to be below the injection zones. The TOC for these two wells is in the Co ville Sha e~elow the Schrader Bluff. ~--- This issue has been identified as a primary risk, and the four offset wells within'/a mile will be monitored in order to determine if injection fluids are migrating out of zone. Monitoring~he offset wells will help to ensure that water injection remains safe and determine if future MI injection is possible. -------- Casing/Tubing Program: Hole Size Csg/ Tbg O.D. WbFt Grade Connection Length (ft) Top MD/TVD RTE ft Btm MDlTVD RTE ft 42" Insulated 20" 215.5 A-53 WLD 108 GL 108/108 12-'/a" 9-5/8" 40 L-80 BTC 4394 GL 4394/3386 8-3/a" 7" 26 L-80 TC-II 5867 GL 5867/4210 8-3/a" 7" 26 L-80 BTC-M 1888 5867/4210 7755/5368 Tubin 3-'/z" 9.2 L-80 TC-II 7482 GL 7482/5175 W-210i Permit to Drill Page 2 • • Directional: Directional Plan: Schlumber er Feasibilit Stud P7b Ref Elev: 80.8' MD KOP: 500' MD, be in 1.5/100 build Close A roach Wells: All Wells ass Ma'or Risk Scan, reference anti-collision re ort Surve Pro ram: GYD-GC-SS 1000' ,MWD + IFR + MS 7755' Maximum Hole An le: 56.0 de rees tan ent section Distance to Nearest Pro ert Line: 14670' from PBU bounda Distance to Nearest Well in Pool: 308' from W-05 Mud Proaram: 12-'/a" Surface Hole Mud Pro erties Spud -Freshwater Mud Interval Density PV YP PH Funn Vis FL 0-2036' BPRF 8.8-9.2 30-55 50 - 70 9.0 - 9.5 300-400 NC - 8 2036'-4394' SV1 9.2-9.5 30-55 45 - 60 9.0 - 9.5 250-300 < 8.0 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Density PV YP PH API Filtrate MBT 4394'-7755' OBf Base 8.8-9.3 8-14 18-24 9.0-9.5 4 - 7 < 15 Survey and Logginq Program: 12-~/a" Hole Section: Surface Gyro until MWD surveys are clean. MWD /LWD: Dir/GR O en Hole: None Cased hole: None 8-3/a" Hole Section: Sample as required by well site Geologist MWD /LWD: GR/RES/Azi-Dens/Neu/PWD real time and recorded O en Hole: DPC MDT fluid and pressure sampling Cased Hole: USIT in primary depth control mode W-210i Permit to Drill Page 3 • • Cement Calculations: Casin Size Surface Casing - 9 5/8" 40 Ib/ft L-80 BTC -Single Stage Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface Tail: O en hole volume + 40% excess + 80' shoe track. TOC 1000' MD above shoe 1970' MD . Fluid Sequence and Tam Port collar located at 1,000' as a contingency for cement to surface Volume: S acer 70 bbls of MudPush II wei hted to 10.3 Lead 518 bbls 647 sks 10.7 Ib/ al Arctic Set Lite cement - 4.49 cuft/sk Tail 85 bbls (406 sks) 15.8 Ib/aal Class G + Durastone - 1.16 cuft/sk Temp I BHST ~ 55° F from SOR In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Size Intermediate Casing - 7" 26 Ib/ft L-80 BTC-M x TC-II -Single Stage Basis Lead: Open hole volume + 30%. TOC 1000' below surface shoe. Tail: O en hole volume + 30% excess + 80' shoe track. TOC 500' above Ma 6100' MD . Fluid Sequence and This cement job is planned for one stage using two slurries. Volume: Wash 40 bbl of CW100 wash wei hted to 8.33-Ib/ al S acer 40 bbl of MUDPUSH XL S acer wei hted to 10.3-Ib/ al Lead 25 bbl 56 sks 12.0 LiteCRETE Lead - 2.46 cuft/sk Tail 61 bbl (291 sks) 15.8 ppa Class G cement + Latex - 1.17 cuft/sk Temp I BHST = 105° Centralizer Recommendations: 9-5/8" Casing Centralizer Placement: a) Run (25) 9 5/g" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 1,000' MD above the shoe. b) Run 2 bow-spring centralizers on either side of the TAM Port Collar (if run). c) This centralizer program is subject to change due to actual hole conditions. 7" Casing Centralizer Placement: a) Run two floating straight blade centralizers and a stop ring centered on every joint of casing from TD to 500' over the Ma sands. b) Above the Ma, run one centralizer per joint, floating across the entire joint up to 1000' below the surface casing shoe. Surface and Anti-Collision Issues: • Surface Shut-in Wells: The closest existing surface wells are W-212 (30' away), and W-215 (30' away). • Close Approach Shut-in Wells: All wells have passed the major risk scan. No wells will require subsurface shut-in during drilling operations. Reference the Anti-collision report in the directional plan for a full list of offset well paths. W-210i Permit to Drill Page 4 \~® ~. C~~ ~r ~-~ 'ell Control :~ Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maxi potential surface pressures. Based upon calculations below, BOP equipment will be tested to 0 psi. Anticipated surface pressures will not exceed 3,OOOpsi, therefore it will not be necessary to ha a two sets of pipe rams installed at all times. BOP regular test frequency will be 14 days, with a function test every 7 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Surface Section • BOPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 9-5/8" Casing Test: • Kick Tolerance: Hydril GK, 21-1/4", 2000 psi 1500 psi - SV1 (8.7 ppg EMW ~ 3305' TVD) 1,170 psi -Based on a full column of gas C~ 0.10 psi/ft Function Test 3,500 psi surface pressure test NA Intermediate Section Kick Tolerance and Integrity Testing • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 2400 psi - OBf Base (8.7 ppg EMW @ 5287' TVD) • Maximum surface pressure: 1870 psi -Based on a full column of gas ~ 0.10 psi/ft • Planned BOP test pressure: t-tC0~r.3;500 psi/250 psi Rams and 2,500 psi/250 psi Annular • 7" Casing Test: 4,000 psi surface pressure test • Integrity Test - 8-3/4" hole: LOT 20' - 50' from 9 5/8" shoe • Kick Tolerance: 51.2 bbl KT with a 9.0 ppg mud and a 10.7 ppg LOT • Planned completion fluid: Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. W-2101 Permit to Drill Page 5 • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: The Schrader Bluff sands are expected to be pressured at 7.5-8.7 ppg EMW. II. Hydrates and Shallow gas: Gas hydrates and/or free gas may be present on W-pad in the SV5 through SV1 surface hole interval below base the base of Permafrost. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Setting the surface casing below the deepest SV1 sand hydrate zone will isolate gas bearing intervals behind cemented pipe in the surface hole. 111. Lost Circulation /Breathing: Lost circulation is considered low at the faults in the production hole section. Seepage losses could occur in the Schrader O-sands. In the event of lost circulation in the production interval, follow the ADW LCM lost circulation tree for slotted liners (no fibrous LCM) to prevent plugging the MDT. Also, do not pump super sweeps. IV. Kick Tolerance /Integrity Testing: Production Section Kick Tolerance and Integrity Testing • Integrity Test - 8-3/4" hole: LOT 20' - 50' from 9 5/s" shoe • Kick Tolerance: 51.9 bbl KT w/ 9.0 ppg mud, a 10.7 ppg LOT, and 8.7 ppg pore pressure. v. Stuck Pipe There could be slight differential sticking across the open hole while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. H2S levels across the pad are typically in the 5 to 60 ppm range based on the latest samples taken. VII. Faults There is a low risk of losses incurred when crossin the fault in the 8-3/4" hole section. Formation Where Encounter MD TVDSS Est. Throw Fault Intersect Intersect Throw Direction Uncertaint +/- 150' Fault #1 - U nu UG1 6655' -4570' -160 Southwest MD CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION W-2101 Permit to Drill Page 6 W-2101-Drill and Complete Procedure Summary -~' Pre-Rig Work: 1. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the 20" conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Prepare neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 7ES. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 2. MU 12-~/a" drilling assembly with MWD/GR and directionally drill surface hole to approximately 80' TVD above UG4. The actual surface hole TD will be 4394' (-3305' tvdss). An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the permafrost. POOH and laydown BHA. 3. Run and cement the 9-5/8", 40.0-Ib/ft. surface casing back to surface. A TAM Port Collar may be run at 1000' MD as a contingency. f 4. ND diverter spool and NU casing /tubing head. NU BOPE and test to 4,000 psi / 2500 psi annular. 5. MU 8-3/a" drilling assembly with MWD/GR/Res/Azi-Den-caliper/Neu/PWD and RIH to float collar. Confirm 1,000 psi cement compressive strength prior to testing casing. Test the 9 5/e" casing to 3,500 psi for 30 minutes. 6. Drill shoe track and displace over to new 8.8 ppg LSND mud. Drill new formation to 20' below 9-5/8" shoe and perform LOT (Notify ODE if 10.7 ppg LOT is not obtained). 7. Drill ahead to Production hole Target TD at 7755' MD, (250' MD below Top OBe marker). Circulate one BU, back-ream out of hole to run casing. 8. Run drill pipe conveyed MDT for fluid and pressure sampling. Perform cleanout run if necessary. 9. Run and cement the 7", 26#, L-80, BTC-M x TCII production casing. Note: Torque turn 7" TC-II threaded casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/8" annulus. 10. PU DPC guns and RIH w/ 140' of 4.5" Power Jet 5 spf, perf guns (total assembly length to be 550') with Anadrill LWD GR for gun correlation. Tag PBTD, Circulate over to 9.0 brine. 11. Space out perf. guns utilizing GR and RA tags in 7" casing. Once correlated correctly, Gently tag TD and w/ guns on bottom. Pull back to shooting depth & confirm cement compressive strength is at least 1,000 psi. Perforate Nb, OBa, OBc, and OBd. POOH standing DP back. 12. RU Schlumberger E-line. RIH with gauge ring and junk basket to recover any perf debris. Repeat until clean to at least 50' below the bottom perforation (OBd perf predicted 7390'-7450'). 13. Run USIT/GR log following Primary Depth Control procedures as USIT log will be primary depth control for future well work. 14. Run the 3-~h", 9.2#, L-80 TCII completion with a 7" x 3-~/2" straddle packer assembly, I-wire, gauges, and injection mandrels. Torque turn TC-II threaded tubing. Note: Do not circulate inhibited brine down the backside yet. 15. Run in the lockdown screws and set the packers. Give AOGCC 24 hrs notice, then test the production casing/tubing annulus and tubing to 4,000 psi each. Shear the DCR shear valve and pump both ways to confirm circulation ability. 16. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 17. Freeze protect the well to 2,400 MD /~2,200TVD by first pumping 69 bbls corrosion inhibited brine down the IA with rig pumps followed by diesel down IA w/ Hot Oiler, taking clean brine returns to surface. Allow diesel to u- tube into tubing. 18. Install BPV in tubing hanger. Install a VR plug in the 7"x 3-'/2" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 19. Rig down and move off. W-2101 Permit to Drill Page 7 • • Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. W-210i Permit to Drill Page 8 TREE = 41 /8" WELLHEAD= FMC ACTUATOR = Baker KB. ELEV = xxx' BF. ELEV = xxx' KOP = 500' Max Angle = 56° @2940' Datum MD = xxxx' DatumTVD= xxxx'SS W-2101 Proposed W BD ~'~~ 9-5/8" CSG, 40#, L-80, ID = 8.835" 4394' ~XOfromTGlltoBTGM f--~ 5867' Minimum ID = 2.813" 3-1 /2" HES X NIPPLE 7" MARKER JOINT W/ RA TAG 6664' Phoenix gauge ID=xx 6885' er Wire run from surface H xxxx 7" MARKER JOINT W/ RA TAG ~--{ 7393' PERFORATION SUMMARY REF LOG: ANGLEAT TOP PERF: Note: SIZE SPF INTERVAL Opn/Sqz DATE 4.5" 5 Nb 4.5" 5 OBa 4.5" 5 Obc 4.5" 5 OBd ~ 3-1/2" TBG, 9.2#, L-80, .0087 bpf, ID = 2.992" ~ PBTD 7" CSG, 26#, L-80, ID = 6.276" FETY NOTES: GLM'S @ STA #1-#6 ARE 1l2" X 1-112" MMGW W RICH ARE WATERFLOOD MANDRELS. J~ 3-1/2" HES X NIP, ID = 2.813" WATERFLOOD/GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 6770 MMG DCR-1 RKP 1.5" 6 6897 MMGW DUM RK 1.5" 5 7210 MMGW DUM RK 1.5" 4 7259 MMGW DUM RK 1.5" 3 7314 MMGW DUM RK 1.5" 2 7358 MMGW DUM RK 1.5" 1 7420 MMGW DUM RK 1.5" 6851' ~ 3-1/2" HES X NIP, ID = 2.813" 8872' 7" X 3-1/2" HES AHR Packer, ID = 2.921" 6926' N 3-1 /2" HES X NIP, ID = 2.813" 71$7' 7" X 3-1/2" HES AHR Packer, ID = 2.921" 727$' ~ 3-1 /2" HES X NIP, ID = 2.813" 7298' 7" X 3-1/2" HES AHR Packer, ID = 2.921" 7312' Phoenix gauge ID = xx" 7377' 7" X 3-1/2" HES AHR Packer, ID = 2.921" 'i 7400' H 3-1/2" HES X NIP, ID = 2.813" 7449' 3-1/2" HES X NIP, ID = 2.813" w /RHGm plug 7470' 3-1/2" HES X NIP, ID = 2.813" 7481' 3-112" WLEG, ID = 3.00" DATE REV BY COMMENTS DATE REV BY COMMENTS 11/28/06 MIS Proposed Completion Ver. 1.0 12/06/06 MIS Proposed Completion Ver. 1.1 ORION UNfT WELL: W-210i PERMIT No: API No: Sec Tw p Rge BP Exploration (Alaska) SEC 16 - - I _ ~ - _ _ _ SEC 21 , , ~ ~~ \ - - I I ``~ `~ ~` i6 A21°I_ 15 I I I W ` I 1 I I ~ I I ~ -------- I N 2904 ` 11 ~ ~ ~~ I` PA I ~ I ~ ~ ~ I N 2822-_---- i I `~ U ~ I `~ ~ I ~-~ I ` ~ C_ WEST END \~ I ~ Q N0.1 m/\ ~~rT I , , I ` ~ r17\/HGV 4 I I I I I \I~ 21` I I I I ~ • I I I - N - KUP UK SfA 22 ~ I I ^ 291 ______________ N0.1 ~ I I ^ 26B I - ~ ' m I I I ^ 24 I ~ I 1 ~ ^ 23 i srnclNCAREA ---' ~ ~: z; ! W-PAD VICINITY M A P N2414.5-( i i ^~ I I N.T.S. 33 ^ i i ^ 19 32 ^ i i ^ 18 s2~ 31 ^ i i ^ 17 i ~c ~ F / I 29 ^ i i ^ 15 i .`Po°°°°°° V 211^ i i ^ 14 i -Je ° •O°~~ z7 ^ I z1z I I ae }( I I ~- W-210i >~ 0 49 ~ y M1 i 26 ^ I I ^ 215 I r _1 ~` , yg^ i ~ ^ 207 , eeeee°e°°°°°••e••°•°°••eeeeee L J m I -__J L-___J H I Iy 1 •eeeeee°••oo°°00•00 W I m ~ ~ I ,~ •'~, ~° Leonard J. O'Hanley • .°• I I I W I I I 11386 I ,.2 t I } I I 3 I ~* i i l~ 4 i ~"'~'C~IONPI~- 38i i i li g 37 i i + 7 36 tTI 39^ ~ ~ a ~ SURVEYOR'S CERTIFICATE ~ e i ~ I i 9 i I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED 42 i i I $ fl i TO PRACTICE LAND SURVEYING IN SPARE ; ; I * 12 ~ THE STATE OF ALASKA AND THAT ~ ~ i i z05 I THIS AS-BUILT REPRESENTS A SURVEY 203 MADE BY ME OR UNDER MY DIRECT I I ; SUPERVISION AND THAT ALL ~,i i I DIMENSIONS AND OTHER DETAILS ARE I CORRECT AS OF DEC. 3, 2006. ~, .. ~~ ~ ~~ ~_ ~~ NOTES: ~~ I 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD27. I 2. BASIS OF LOCATION IS W PAD MONUMENTS W-1 & W-2. 3. BASIS OF ELEVATION IS W PAD MONUMENT W-2. 1.E.CtEdQ ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. GEODETIC POSITIONS ARE NAD27. -~ AS-BUILT CONDUCTOR 5. PAD MEAN SCALE FACTOR IS 0.99991426. 6. DATE OF SURVEY: DEC. 3, 2006. ^ EXISTING CONDUCTOR 7. REFERENCE FIELD BOOK: WO 06-22 PGS.25-26. LOCATED WITHIN PROTRACTED SECTION 21, T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS W-210i Y= 5,959,321.23 N= 2,127.18 70'17'52.116" 70.297810' 51 6' 4,344' FSL " X= 612,048.88 E= 2,129.83 149'05'33.357" 149.092599' . FEL 1,186 :~ MIIYIJII Ry ~E~~~BARNHART ~p O Q DA~rE: 12 6/06 DRAWING' ~ y ~j. FRBe6 wow a,-ee WOA W-PAD SNEET: ¢ ~ llI~UOO Uo ~o- AS-BUILT CONDUCTOR B ~z B e tssrlm roR INAnoN ADM ni "'°`°""°'"°"""°" WELL W-2101 1 aF 1 '" .ar ""°'® `"" i": 300' u NQ DAn: REVISION BY CHK ~~. ~~ aIm by Schlumberger W-210 (P7b) Proposal Report Date: November 21, 2006 Survey 1 DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 123.170° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: W-PAD / W-210 ~~~~' ~~ s TVD Reference Datum: Rotary Table Well: Plan W-210 ~ TVD Reference Elevation: 80.80 ft relative to MSL Borehole: Plan W-210 ~ Sea Bed I Ground Level Elevation: 52.30 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 23.879° Survey Name 1 Date: W-210 (P7b) I November 21, 2006 Total Field Strength: 57637.575 nT Tort 1 AHD I DDI 1 ERD ratio: 67.731 ° 15005.40 ft 15.690 10.93° Magnetic Dip: 80.886° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: January 21, 2007 Location LatlLong: N 70.29780666, W 149.09259828 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5959320.000 ftUS, E 612049.000 ftUS North Reference: True North Grid Convergence Angle: +0.85428842° Total Corr Mag North -> True North: +23.879° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Measured Vertical Gravity Comments Inclination Azimuth Subsea TVD TVD NS ~ DLS Build Rate Walk Rate Northing Fasting LatRude Longitude Depth Section Tool face ft de de it ft ft ft ft d de 1100 ft de 100 it de 100 ft ftUS itUS Kit U. UU V.VU `JU.UU -i5UR3U V. UU U.UU U.UU U.UU --- U.UU U.UU U.UU b`Jb`J3LV.UU blLU4`J.UU rv/U.L`J/ifUbbb VV l4y.VyZbytSZtf G 1 390.80 0.00 90.00 310.00 390. 80 0.00 0.00 0.00 --- 0.00 0.00 0.00 5959320.00 612049.00 N 70.29780666 W 149.09259828 I, KOP Bld 1.5/100 500. 00 0.00 90.00 419.20 500. 00 0.00 0.00 0.00 HS 0.00 0.00 0.00 5959320.00 612049.00 N 70.29780666 W 149.09259828 ', Bld 2.5/100 600. 00 1.50 90.00 519.19 599. 99 1.10 0.00 1.31 12.69R 1.50 1.50 0.00 5959320.02 612050.31 N 70.29780666 W 149.09258768 700. 00 3.98 97.94 619.07 699. 87 5.33 -0.48 6.05 4.76R 2.50 2.48 7.94 5959319.61 612055.06 N 70.29780535 W 149.09254927 !, 800. 00 6.47 99.78 718.64 799. 44 13.64 -1.92 15.04 2.92R 2.50 2.49 1.84 5959318.31 612064.07 N 70.29780143 W 149.09247647 II Crv 2.5/100 821. 16 7.00 100.00 739.65 820. 45 15.92 -2.34 17.49 24.OOR 2.50 2.50 1.05 5959317.92 612066.52 N 70.29780026 W 149.09245668 900. 00 8.84 105.22 817.74 898. 54 26.10 -4.77 28.06 18.82R 2.50 2.33 6.63 5959315.65 612077.13 N 70.29779364 W 149.09237104 1000. 00 11.23 109.37 916.21 997. 01 42.87 -10.01 44.67 14.74R 2.50 2.40 4.14 5959310.65 612093.81 N 70.29777930 W 149.09223661 1100. 00 13.66 112.06 1013.85 1094. 65 63.92 -17.68 64.80 12.11 R 2.50 2.43 2.69 5959303.29 612114.05 N 70.29775835 W 149.09207356 1200. 00 16.12 113.95 1110.49 1191. 29 89.21 -27.76 88.44 10.29R 2.50 2.45 1.89 5959293.57 612137.84 N 70.29773084 W 149.09 218 SV6 1283. 22 18.17 115.14 1190.00 1270. 80 113.46 -37.96 110.74 9.15R 2.50 2.46 1.43 5959283.70 612160.28 N 70.29770296 W 149.09 1300. 00 18.58 115.35 1205.93 1286. 73 118.70 -40.21 115.53 8.95R 2.50 2.47 1.25 5959281.52 612165.10 N 70.29769680 W 149.0 84 1400. 00 21.06 116.43 1300.00 1380. 80 152.33 -55.04 146.02 7.93R 2.50 2.47 1.08 5959267.15 612195.81 N 70.29765631 W 149.09141598 1500. 00 23.53 117.30 1392.52 1473. 32 190.04 -72.19 179.85 7.13R 2.50 2.48 0.86 5959250.50 612229.89 N 70.29760944 W 149.09114204 1600. 00 26.02 118.00 1483.31 1564. 11 231.75 -91.65 216.96 6.49R 2.50 2.48 0.71 5959231.61 612267.28 N 70.29755628 W 149.09084156 1700. 00 28.50 118.60 1572.19 1652. 99 277.38 -113.37 257.28 5.96R 2.50 2.49 0.59 5959210.49 612307.91 N 70.29749694 W 149.09051511 1800. 00 30.99 119.10 1659.01 1739. 81 326.85 -137.31 300.72 5.52R 2.50 2.49 0.50 5959187.20 612351.71 N 70.29743152 W 149.09016331 1900. 00 33.48 119.54 1743.59 1824. 39 380.06 -163.43 347.22 5.16R 2.50 2.49 0.44 5959161.77 612398.59 N 70.29736015 W 149.08978683 End Crv 1974. 43 35.33 119.83 1805.00 1885. 80 422.04 -184.26 383.76 --- 2.50 2.49 0.39 5959141.50 612435.43 N 70.29730325 W 149.08949102 SV5 2011. 20 35.33 119.83 1835.00 1915. 80 443.27 -194.84 402.20 --- 0.00 0.00 0.00 5959131.20 612454.03 N 70.29727435 W 149.08934164 Base Perm 2035. 72 35.33 119.83 1855.00 1935. 80 457.42 -201.89 414.50 - 0.00 0.00 0.00 5959124.33 612466.43 N 70.29725509 W 149.08924206 Crv 2.5/100 2104. 43 35.33 119.83 1911.06 1991. 86 497.09 -221.65 448.98 10.16R 0.00 0.00 0.00 5959105.08 612501.19 N 70.29720109 W 149.08896294 WeIlDesign Ver SP 2.1 Bld( doc40x_100) W-210\Plan W-210\Plan W-210\W-210 (P7b) Generated 11/21/2006 8:10 AM Page 1 of 2 Measured Vertical Gravity Comments Inclination Azimuth Sub-Sea ND ND NS EW DLS Build Rate Walk Rate Northing Easting latitude Longitude Depth Secfion Tool Face ft de de ft ft ft ft ft de de 1100 ft d 1100 ft de 1100 ft ftUS ftUS JV4 Z7yU.U/ 3/.44 7ZU.4b 7ytfU.UU ZUdU.tfU D4 /.tiZ -Z4/.7/ 4'JZ.'J7 'J.66K GbU Z.4t7 U./3 5Yb'JUtlU.Z3 t)7Zb4b.DU N /U.Zy/1313M W 74'J.UtStf6U/Y4 2200.00 37.69 120.52 1987.87 2068.67 553.87 -250.24 498.12 9.60R 2.50 2.46 0.69 5959077.24 612550.76 N 70.29712299 W 149.08856502 2300.00 40.15 121.16 2065.67 2146.47 616.63 -282.44 552.05 9.10R 2.50 2.47 0.65 5959045.84 612605.16 N 70.29703499 W 149.08812837 2400.00 42.62 121.75 2140.69 2221.49 682.71 -316.95 608.44 8.66R 2.50 2.47 0.58 5959012.19 612662.05 N 70.29694072 W 149.08767181 2500.00 45.09 122.28 2212.79 2293.59 751.98 -353.68 667.19 8.28R 2.50 2.47 0.53 5958976.34 612721.33 N 70.29684036 W 149.08719620 2600.00 47.57 122.76 2281.83 2362.63 824.30 -392.57 728.17 7.94R 2.50 2.48 0.49 5958938.36 612782.88 N 70.29673409 W 149.08670245 2700.00 50.05 123.22 2347.68 2428.48 899.55 -433.55 791.28 7.65R 2.50 2.48 0.45 5958898.34 612846.59 N 70.29662214 W 149.08619150 2800.00 52.53 123.63 2410.22 2491.02 977.57 -476.53 856.40 7.38R 2.50 2.48 0.42 5958856.34 612912.33 N 70.29650469 W 149.08566432 2900.00 55.01 124.03 2469.32 2550.12 1058.22 -521.43 923.39 7.15R 2.50 2.48 0.39 5958812.44 612979.98 N 70.29638199 W 149.08512192 End Crv 2939.66 55.99 124.18 2491.79 2572.59 1090.90 -539.76 950.46 --- 2.50 2.48 0.38 5958794.52 613007.32 N 70.29633192 W 149.08490281 SV2 3311.90 55.99 124.18 2700.00 2780.80 1399.41 -713.08 1205.74 -- 0.00 0.00 0.00 5958625.03 613265.13 N 70.29585831 W 149.0 15 SV1 3883.99 55.99 124.18 3020.00 3100.80 1873.57 -979.47 1598.08 - 0.00 0.00 0.00 5958364.55 613661.36 N 70.29513036 W 149.0 O6 9-5/8" Csg 4393.52 55.99 124.18 3305.00 3385.80 2295.86 -1216.72 1947.51 --- 0.00 0.00 0.00 5958132.56 614014.26 N 70.29448199 W 149.07683154 UG4 4536.54 55.99 124.18 3385.00 3465.80 2414.40 -1283.32 2045.59 - 0.00 0.00 0.00 5958067.43 614113.32 N 70.29429998 W 149.07603760 UG4A 4634.87 55.99 124.18 3440.00 3520.80 2495.89 -1329.10 2113.03 -- 0.00 0.00 0.00 5958022.66 614181.42 N 70.29417485 W 149.07549178 UG3 5260.60 55.99 124.18 3790.00 3870.80 3014.50 -1620.46 2542.15 --- 0.00 0.00 0.00 5957737.76 614614.80 N 70.29337851 W 149.07201851 UG1 6145.56 55.99 124.18 4285.00 4365.80 3747.96 -2032.53 3149.05 --- 0.00 0.00 0.00 5957334.82 615227.73 N 70.29225215 W 149.06710678 Fault Crossing 6655.08 55.99 124.18 4570.00 4650.80 4170.26 -2269.78 3498.48 --- 0.00 0.00 0.00 5957102.83 615580.62 N 70.29160358 W 149.06427906 Mb2 6664.02 55.99 124.18 4575.00 4655.80 4177.67 -2273.94 3504.61 -- 0.00 0.00 0.00 5957098.76 615586.81 N 70.29159220 W 149.06422945 Mc 6753.41 55.99 124.18 4625.00 4705.80 4251.75 -2315.56 3565.91 -- 0.00 0.00 0.00 5957058.06 615648.72 N 70.29147841 W 149.06373338 Na 6851.74 55.99 124.18 4680.00 4760.80 4333.25 -2361.35 3633.35 -- 0.00 0.00 0.00 5957013.29 615716.83 N 70.29135324 W 149.06318771 Nb 6896.43 55.99 124.18 4705.00 4785.80 4370.29 -2382.16 3664.00 --- 0.00 0.00 0.00 5956992.94 615747.78 N 70.29129635 W 149.06293968 Crv 4/100 6933.08 55.99 124.18 4725.50 4806.30 4400.66 -2399.22 3689.13 180.00E 0.00 0.00 0.00 5956976.25 615773.16 N 70.29124970 W 149.06273633 Nc 6958.67 54.97 124.18 4740.00 4820.80 4421.74 -2411.07 3706.57 180.00E 4.00 -4.00 0.00 5956964.67 615790.78 N 70.29121732 W 149.06259517 Ne 6972.51 54.41 124.18 4748.00 4828.80 4433.04 -2417.41 3715.92 180.00E 4.00 -4.00 0.00 5956958.47 615800.22 N 70.29119998 W 149.06251956 7000.00 53.31 124.18 4764.21 4845.01 4455.23 -2429.88 3734.28 180.00E 4.00 -4.00 0.00 5956946.27 615818.77 N 70.29116588 W 149.06237093 7100.00 49.31 124.18 4826.71 4907.51 4533.26 -2473.72 3798.85 180.00E 4.00 -4.00 0.00 5956903.41 615883.97 N 70.29104603 W 149.06184849 OA 7112.66 48.81 124.18 4835.00 4915.80 4542.82 -2479.09 3806.76 180.00E 4.00 -4.00 0.00 5956898.16 615891.96 N 70.29103135 W 149.06178449 7200.00 45.31 124.18 4894.49 4975.29 4606.74 -2515.00 3859.65 180.00E 4.00 -4.00 0.00 5956863.04 615945.38 N 70.29093317 W 149.0 50 End Crv / Tgt 7207.81 45.00 124.18 4900.00 4980.80 4612.28 -2518.11 3864.23 --- 4.00 -4.00 0.00 5956860.00 615950.00 N 70.29092467 W 149.0 44 OBa 7207.82 45.00 124.18 4900.01 4980.81 4612.29 -2518.12 3864.24 --- 0.00 0.00 0.00 5956859.99 615950.01 N 70.29092465 W 149.06 1937 OBb 7245.99 45.00 124.18 4927.00 5007.80 4639.27 -2533.28 3886.57 --- 0.00 0.00 0.00 5956845.17 615972.56 N 70.29088320 W 149.06113869 ~~ OBc 7316.70 45.00 124.18 4977.00 5057.80 4689.27 -2561.36 3927.93 --- 0.00 0.00 0.00 5956817.71 616014.34 N 70.29080642 W 149.06080397 OBd 7393.07 45.00 124.18 5031.00 5111.80 4743.26 -2591.70 3972.61 --- 0.00 0.00 0.00 5956788.04 616059.46 N 70.29072348 W 149.06044248 OBe 7497.72 45.00 124.18 5105.00 5185.80 4817.25 -2633.26 4033.83 --- 0.00 0.00 0.00 5956747.40 616121.29 N 70.29060984 W 149.05994711 7504.79 45.00 124.18 5110.00 5190.80 4822.25 -2636.07 4037.97 --- 0.00 0.00 0.00 5956744.65 616125.46 N 70.29060216 W 149.05991364 OBf 7554.29 45.00 124.18 5145.00 5225.80 4857.24 -2655.73 4066.92 -- 0.00 0.00 0.00 5956725.43 616154.71 N 70.29054840 W 149.05967934 OBf Base 7622.17 45.00 124.18 5193.00 5273.80 4905.23 -2682.69 4106.64 -- 0.00 0.00 0.00 5956699.06 616194.81 N 70.29047468 W 149.05935802 TD / 7" Csg 7754.79 45.00 124.18 5286.78 5367.58 4999.00 -2735.37 4184.22 --- 0.00 0.00 0.00 5956647.55 616273.17 N 70.29033066 W 149.05873027 WeIlDesign Ver SP 2.1 Bld(docAOx_100) W-210\Plan W-210\Plan W-210\W-210 (P7b) Generated 11/21/2006 8:10 AM Page 2 of 2 by • Schlumberger WELL W-210 (P7b) FIELD Prudhoe Bay Unit - WOA STRUC TURE W-PAD Magnetic Parameters Su~ace Location NAD31 Alaska Slate PUnes. Zone 04, US Feet Miscella neous MoEel'. BGGM 200fi Dip 80.686` Date' Januxy 21, 200] Lat. N]01]53104 NorMing'. 595932000 hUS GIM COnv'. M.85428842° Sld'. W-210 TVD ReI-. Rdary Table 160.8011 above MSL) Mag Oec'. .23.8]9° FS-. 5)63]6nT Lan: 49533354 Easting'. fi12049.00 f1U5 Srab Fact 0.9999t42fi22 Plan. W~210 (Plbl Srvy Date: N ember 21.2006 0 800 1600 2400 3200 4000 4800 800 1600 2400 0 0 c I I 0) OS ~ 3200 4000 4800 5600 ........................ i..................................:...................................:.................................. i ..................................:...................................:.. KOP Bid 1.5/100 Bld 2.51100 Crv 2.SN00 _ Js._.._.._.._.._.. _ ._.._.._.._.._.._.._.._ _..-.._..-.._.._..-..-.. _..-..-..-..-..-..-..-. _.._..-.. End Crv ::g::i:: S::3::.:. ..r.._.._.._..-.._ s::;:: _.. _.. e........ e:: s::.: p::. Crv ........................................... s.....................................................................:.................................. ~.... _ ._.i_..-..-..-..-..-..-..-..-t.-..-..-..-..-..-.._.._...4._.._.._.._.._.._.._.._..i.._.._.._.. _.. _.._.._.._.. i-.._ ._.._.:_.._.._ i_.._.._.._.._i._.._.._.._.._.._.._.._..~.._.._.._.._.._.._.._.._..~.._.._.._.._.._.._.._.._..~.._ s-SIB" CsB ....................:..................................:..................................:.... i..._.._.._..-..-.._.._.. ._.._.._.._.._.._.._.. .._.._.._.._.._..-..-.._i. _.._.._.. _..-.._. .._.._..-.._.._.._..-..s.._.._..-..-.._..-..-..- - ~ Fault Crossing T.. _.._..-..-.._.. _.. _.._ ._..-.._.._.._..-.._.._,_.._.._.._.._.._.._.._.._, _.._.._.. _.._.._.._.._. _.._.._.._.. _.._.._.._ - tx.. _.. _.. _.._.._ _ 0 800 1600 2400 3200 4000 .... -,.-„ 4800 ._.. i.. _.. _.._. ~~ s -2 0 (P7b) TD I T' Csg ........_ ............. 5600 0 800 1600 2400 3200 4000 4800 Vertical Section (ft) Azim = 123.17°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V by Schlumberger WELL FlELO STRUCNRE W-210 (P7b) Prudhoe Bay Unit - WOA W-PAD Magnetic Parameters Surtace Lwalion NA02J NasNa STNS Plares, Zone 0a, US Feet Miscellaneous MortSl'. 9GGM 2006 Dip: 80.886° Data: JaNrary 21, 2110] la[ NJ01)62.106 NoM1Nng'. 6969320001tt15 Grtl DOnV'. X085628862° Slot W-210 ND Ref: Rotary Tahle (60.60 ka6ove MSL) Meg Dec: ~23.8J9° FS'. 6Jfi3].6 nT Lon: Wta9533.356 Eazlirg'. 612069.00 fluS Scale Faq: 0.9999162622 Plan: W-210 (P]6f Srvy Dale'. Novem5er 2t. 2006 son ~nno ~snn ~nnn ~snn soon asnn anon u -500 n n -1000 z `o 0 c a~ -1500 v v v -2000 -2500 ...................................... ~..................................~..................................s...................................~..................................i..................................; ..................... ...........~ ro~~°( w-zio V -500 -1000 -1500 -2000 -2500 0 500 1000 1500 2000 2500 3000 3500 4000 «< W Scale = 1(in):500(ft) E »> BP Alaska Anticollision Report Company: BP Amoco Date: 11/21/2006 Time: 08:15:17 Page: t Fieid: Prudhoe Bay Reference Site: PB W Pad Co-ordinate(NE) Reference: Well: Plan W-210, True North Reference WeII: Plan W-210 Vertical (TVD) Reference: W-210 plan 80.8 Reference Wellpath: Plan W-210 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan 8 PLANNED PROGRAM i Interpolation Method : MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 7754.79 ft Scan Method: Trav Cylinder North ~, Maximum Radius:10000.00 ft Error Surface: Ellipse + Casing ~ Survey Program for Definitive Wellpath Date: 7/28/2006 Validated: No Version: 12 I Planned From To Survey Toolcode Tool N ame I ft ft i 28.50 1000.00 Planned: Plan #7 V2 GYD-GC-SS Gyrodata gyro single shots 1000.00 2400.00 Planned: Plan #7 V2 MWD MWD -Standard 1000.00 4300.00 Planned: Plan #7 V2 MWD+IFR+MS MWD +IFR + Mu lti Station 4300.00 7754.79 Planned: Plan #7 V2 MWD+IFR+MS MWD +IFR + Mu lti Station Casing Points MD TVD Diameter Hole Size Name ft ft in in ', 4366.70 3370.80 9.625 12.250 9 5/8" - 7754.79 5367.57 7.000 8.750 7" Summary <------------- Offset Wellpath -------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft - ft ft ft ft PB W Pad Plan W-204 Plan W-204 V6 Plan: PI -- 775.48 - - 785.00 517.57 14.65 502.92 Pass: Major Risk PB W Pad Plan W-204 Plan W-204L1 V3 Plan: 775.48 785.00 517.57 14.76 502.80 Pass: Major Risk I, PB W Pad Plan W-204 Ptan W-204L2 V3 Plan: 775.48 785.00 517.57 14.76 502.80 Pass: Major Risk PB W Pad Plan W-213 Plan W-213 V5 Plan: PI 478.99 480.00 532.33 8.63 523.70 Pass: Major Risk ', PB W Pad Plan W-214 Plan W-214 V5 Plan: PI 680.26 685.00 547.31 12.24 535.07 Pass: Major Risk PB W Pad Plan W-401 Plan W-401 V1 Plan: PI 654.61 670.00 360.07 11.99 348.08 Pass: Major Risk l PB W Pad Plan W-45 Plan W-45 V1 Plan: Pla 1363.72 1375.00 661.50 24.94 636.56 i Pass: Major Risk ~, PB W Pad W-01 W-01 V3 2399.20 2380.00 129.25 71.85 57.40 Pass: Major Risk !I PB W Pad W-01 W-01A V4 2399.20 2380.00 12925 71.85 57.40 Pass: Major Risk ~, PB W Pad W-01 W-01AP61 V1 2399.20 2380.00 129.25 71.85 57.40 Pass: Major Risk I PB W Pad W-02 W-02 V4 810.11 810.00 256.06 12.93 243.14 Pass: Major Risk PB W Pad W-02 W-02A V20 811.30 810.00 256.09 12.95 243.14 Pass: Major Risk ~, PB W Pad W-03 W-03 V4 1348.37 1340.00 277.04 24.15 252.89 Pass: Major Risk l PB W Pad W-03 W-03A V1 1348.37 1340.00 277.04 24.15 252.89 i Pass: Major Risk PB W Pad W-04 W-04 V1 1428.61 1425.00 309.09 25.69 283.41 Pass: Major Risk PB W Pad W-05 W-05 V3 5707.48 5595.00 190.36 163.51 26.85 Pass: Major Risk PB W Pad W-05 W-05A V2 5707.48 5595.00 190.36 163.51 26.85 Pass: Major Risk i~ PB W Pad W-06A W-06A V2 1339.61 1300.00 421.57 26.29 395.28 Pass: Major Risk PB W Pad W-06 W-06 V1 1339.61 1300.00 421.57 26.29 395.28 Pass: Major Risk PB W Pad W-07 W-07 V1 589.99 600.00 398.57 13.99 384.58 Pass: Major Risk ~ PB W Pad W-07 W-07A V7 589.02 590.00 398.55 13.96 384.59 Pass: Major Risk PB W Pad W-08 W-08 V1 7753.49 7745.00 338.75 155.61 183.14 Pass: Major Risk PB W Pad W-08 W-08A V12 7754.41 7740.00 338.67 155.54 183.13 Pass: Major Risk PB W Pad W-09 Plan W-09B V1 Plan: PI 554.30 555.00 502.17 10.63 491.54 Pass: Major Risk PB W Pad W-09 W-09 V1 555.00 565.00 502.19 10.32 491.87 Pass: Major Risk l PB W Pad W-09 W-09A V4 552.01 550.00 502.12 10.31 491.81 i Pass: Major Risk i PB W Pad W-09 W-09AP61 V9 552.01 550.00 502.12 10.25 491.87 Pass: Major Risk PB W Pad W-10 W-10 V3 568.63 570.00 537.45 12.07 525.39 Pass: Major Risk I PB W Pad W-10 W-10A V4 568.63 570.00 537.45 12.07 525.39 Pass: Major Risk PB W Pad W-11 W-11 V1 724.96 730.00 572.46 12.48 559.97 Pass: Major Risk PB W Pad W-12A W-12A V3 492.92 495.00 607.92 10.48 597.44 Pass: Major Risk PB W Pad W-12 W-12 V1 492.92 495.00 607.92 10.48 597.44 Pass: Major Risk PB W Pad W-15 W-15 V1 684.25 695.00 101.95 11.85 90.10 Pass: Major Risk PB W Pad W-15 W-15A V10 684.25 695.00 101.95 11.85 90.10 Pass: Major Risk PB W Pad W-15 W-15PB1 V6 684.25 695.00 101.95 11.85 90.10 Pass: Major Risk II PB W Pad W-15 W-15PB2 V1 684.25 695.00 101.95 11.85 90.10 Pass: Major Risk ~i PB W Pad W-16 W-16 V3 708.77 720.00 135.88 12.45 123.43 Pass: Major Risk 'I PB W Pad W-16 W-16A V3 708.77 720.00 135.88 12.30 123.58 Pass: Major Risk !, PB W Pad W-16 W-16APB1 V1 708.77 720.00 135.88 12.30 123.58 Pass: Major Risk PB W Pad W-16 W-16L1 V3 708.77 720.00 135.88 12.45 123.43 Pass: Major Risk PB W Pad W-17 W-17 V4 746.52 750.00 169.24 13.34 155.90 Pass: Major Risk BP Alaska Anticollision Report Company: BP Amoco Date: 11/21/2006 Time: 08:15:17 Page: 2 Field: Prudhoe Bay Reference Site: PB W Pad Co-ordinate(NE) Reference: Well: Pla n W-210, Prue North Keference We11: Plan W-210 Vertical ('fVD) Refere nce: W-210 p lan 80.8 Reference Wellpath : Plan W-210 DV: Oracle Summary < - Offset Wellpath -> Reference Offset Ctr-Ctr No-Co Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft ~i PB W Pad W-17 W-17A V9 _ _ 743.58 749.96 169.20 13.30 155.90 _ _ __ Pass: Major Risk ~~ PB W Pad W-18 W-18 V1 760.35 765.00 204.96 14.00 190.96 Pass: Major Risk ~ PB W Pad W-19 W-19 V2 732.12 745.00 240.26 12.58 227.68 Pass: Major Risk PB W Pad W-19 W-19A V1 729.30 735.00 240.22 12.54 227.68 Pass: Major Risk PB W Pad W-19 W-19AL1 V3 729.30 735.00 240.22 12.54 227.68 Pass: Major Risk PB W Pad W-19 W-19AL1 P61 V1 729.30 735.00 240.22 12.38 227.84 Pass: Major Risk ~ PB W Pad W-19 W-19AL1 PB2 V1 729.30 735.00 240.22 12.38 227.84 Pass: Major Risk '~ PB W Pad W-200PB1 W-200P61 V7 752.68 760.00 452.88 13.19 439.69 Pass: Major Risk PB W Pad W-200 W-200 V6 752.69 760.00 452.85 13.12 439.74 Pass: Major Risk PB W Pad W-201 W-201 V4 676.68 680.00 484.00 11.21 472.80 Pass: Major Risk PB W Pad W-203 W-203 V10 3387.25 3235.00 192.24 59.35 132.89 Pass: Major Risk 'i PB W Pad W-203 W-203L1 V8 3387.25 3235.00 192.24 59.14 133.10 Pass: Major Risk i ~ PB W Pad W-203 W-203L2 V4 3387.25 3235.00 192.24 59.14 133.10 Pass: Major Risk 'i PB W Pad W-205 W-205 V6 3471.11 3220.00 359.10 70.90 288.19 Pass: Major Risk ' PB W Pad W-205 W-205L1 V2 3471.11 3220.00 359.10 70.94 288.16 Pass: Major Risk PB W Pad W-205 W-205L1P61 V4 3471.11 3220.00 359.10 70.93 288.16 Pass: Major Risk ', PB W Pad W-205 W-205L2 V4 3471.11 3220.00 359.10 70.93 288.16 Pass: Major Risk ~ I, PB W Pad W-207 W-207 V10 1630.51 1605.00 75.98 26.47 49.52 I Pass: Major Risk ~ PB W Pad W-207 W-207P61 V2 1630.51 1605.00 75.98 26.47 49.52 Pass: Major Risk PB W Pad W-209 W-209 V9 509.28 510.00 188.84 9.13 179.72 Pass: Major Risk PB W Pad W-209 W-209P61 V6 509.28 510.00 188.84 8.97 179.87 Pass: Major Risk i PB W Pad W-20 W-20 V1 735.12 740.00 276.13 12.31 263.81 Pass: Major Risk i PB W Pad W-211 W-211 V9 2399.91 2570.00 261.36 58.11 203.25 Pass: Major Risk i PB W Pad W-212 W-212 V12 669.58 675.00 34.27 10.23 24.04 Pass: Major Risk ', PB W Pad W-215 W-215 V7 419.65 420.00 29.36 7.40 21.96 Pass: Major Risk PB W Pad W-215 W-215PB1 V2 419.65 420.00 29.36 7.40 21.96 Pass: Major Risk 'i ~ PB W Pad W-21 W-21 V3 745.68 760.00 312.80 17.93 294.87 Pass: Major Risk PB W Pad W-21 W-21A V12 745.01 750.00 312.78 17.91 294.87 Pass: Major Risk PB W Pad W-22 W-22 V1 824.93 835.00 344.70 15.46 329.24 Pass: Major Risk PB W Pad W-23 W-23 V3 730.51 745.00 380.62 12.52 368.10 Pass: Major Risk PB W Pad W-23 W-23A V5 730.02 735.00 380.61 12.51 368.10 Pass: Major Risk PB W Pad W-24 W-24 V1 771.96 780.00 418.17 14.34 403.83 Pass: Major Risk '. i PB W Pad W-25 W-25 V1 584.05 600.00 265.47 10.18 255.29 Pass: Major Risk PB W Pad W-26A W-26A V6 597.28 605.00 262.16 10.45 251.71 Pass: Major Risk PB W Pad W-26 W-26 V1 597.28 605.00 262.16 10.45 251.71 Pass: Major Risk PB W Pad W-27 W-27 V3 570.12 585.00 261.63 10.28 251.35 Pass: Major Risk PB W Pad W-27 W-27A V3 570.12 585.00 261.63 10.28 251.35 Pass: Major Risk PB WPad W-29 W-29 V1 610.77 630.00 275.45 12.44 263.01 Pass: Major Risk PB W Pad W-30 W-30 V1 589.28 605.00 289.11 11.54 277.57 Pass: Major Risk ' PB W Pad W-31 W-31 V1 611.69 630.00 305.05 11.26 293.78 ~I Pass: Major Risk ~ I PB W Pad W-32 W-32 V6 602.79 620.00 328.41 11.50 316.91 Pass: Major Risk i ~ PB W Pad W-32 W-32A V3 605.27 620.00 328.48 11.57 316.91 Pass: Major Risk I '~ PB W Pad W-32 W-32AP61 V13 605.27 620.00 328.48 11.31 317.16 I Pass: Major Risk ' PB W Pad W-34 W-34 V1 616.44 635.00 385.39 11.01 374.38 Pass: Major Risk i PB W Pad W-34 W-34A V1 616.44 635.00 385.39 11.01 374.38 Pass: Major Risk PB W Pad W-34 W-34APB1 V1 616.44 635.00 385.39 10.85 374.54 Pass: Major Risk PB W Pad W-35 W-35 V1 584.12 600.00 411.34 12.51 398.84 Pass: Major Risk PB W Pad W-36 W-36 V1 583.75 600.00 440.47 10.12 430.35 Pass: Major Risk '; PB W Pad W-37 W-37 V3 537.21 550.00 468.02 10.18 457.84 Pass: Major Risk ', PB W Pad W-37 W-37A V3 537.21 550.00 468.02 10.18 457.84 Pass: Major Risk ~ PB W Pad W-38 W-38 V2 504.68 515.00 500.60 9.17 491.43 Pass: Major Risk PB W Pad W-38 W-38A V10 507.16 515.00 500.66 9.12 491.54 Pass: Major Risk PB W Pad W-39 W-39 V1 597.79 615.00 528.26 12.06 516.20 Pass: Major Risk PB W Pad W-39 W-39A V2 597.79 615.00 528.26 12.22 516.05 Pass: Major Risk PB W Pad W-400 W-400 V5 904.65 925.00 573.88 15.19 558.69 Pass: Major Risk PB W Pad W-40 W-40 V1 657.51 680.00 559.51 11.94 547.57 Pass: Major Risk PB W Pad W-42 W-42 V4 640.22 659.95 622.74 11.16 611.58 Pass: Major Risk PB W Pad W-44 W-44 V1 706.96 730.00 684.35 11.32 673.03 Pass: Major Risk ~ • FieldPrudhoe Bay Site PB W Pad Well:Plan W-210 WellpathPlan W-210 -3 1 3 300 200 100 0 2 100 200 300 313 0 Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre t + Site: PB W Pad • Drilling Target Conf.: 85% Description: Map Northing: 5956860.00 ft Map Easting :615950.00 ft Latitude: 70° 17'27.329N Target: W-210 Tgt OBa /~_ ~ o ~o D ~ ~ D~ ~ ~ } iQ Shape: Circle - __ __ 0 0 0 o ~ o ~ ~ ~ m m m Plan W-210 Based on: Planned Program Vertical Depth: 4900.00 ft below Mean Sea Level Local +N/-S: -2518.11 ft Local +E/-W: 3864.22 ft Longitude: 149°03'40.750W -- --- -_ Radius: 50 ft 25( 25` 26( 0 0 ~n o ~ o m ~ Re: [Fwd: W-210i Area of Review] • • Subject: Re: [Fwd: W-210i Area of Review] From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Mon, 08 Jan 2007 14:06:07 -0900 To: Marlc Staudinger <Mark.Staudinger@bp.com> CC: Art Saltmarsh <art_salhnarsh(u~admin.state.ak.us>, Jim Regg <jim_regg~c~admin.state.ak.us> Mark, I have looked at your Area of Review determination. I have used the information available in the AOGCC well files to perform my own assessment for comparison. The Commission well files for the listed W pad Ivishak wells do not have a lot of detailed information regarding the cementing operations and no formation top information for the shallow horizon objectives. I would appreciate if you could provide additional information concerning the cementing operations and formation tops on the Ivishak wells. W-203 and its laterals are the newest wells identified for the AOR. I agree with your assessment on W-203. Using 30% XS factor, I also agree that the TOCs for W-OS and W-O1 are likely around 4500' tvd and that the TOC for W-08 is likely below the Schrader. For W-07, I calculate a TOC near 4650' tvd. Details comments for each well are included below. I look forward to the additional information. On receipt, I should be able to conclude the AOR evaluation. I would also appreciate if you would have another look at the information for W-07 so we can reconcile. Call or message with any questions. Also, is the potential spud date still around January 20? Tom Maunder, PE AOGCC ------------------------------------------------------------- 4 - ~~ G' W-203 (202-097)--The AOGCC well file has sufficient information to verify AOR statements provided. Based on 30% XS washout, the TOC in the 8-1/2" x 7" annulus would be about 5079' md. A USIT log was run in this well and indicates a TOC of about 5235' and which is about 4000' tvd in agreement with the provided AOR statement. Based on the 5300' and TOC, the XS hole size is about 40%. The L2 window top is at 7120' and (5030' tvd). ---- r, 7 W-OS (189-043)--The AOGCC well file does not have sufficient information to verify AOR statements provided. Based on 30% XS washout, the TOC in the 12-1/4" x 9.625" annulus would be about 6332' and (4500' tvd). --114th ~-------------------------------------------------- W-01(188-107)--The AOGCC well file does not have sufficient information to verify AOR statements provided. Based on 30% XS washout, the TOC in the 12-1/4" x 9.625" annulus would be about 5751' and (4507' tvd). ~ -- --------------~2'-` ~? `--k ~-------------------------------- W-08 (189-007)--Although limited operations information is available, there is sufficient information to conclude that the TOC is likely below the Schrader. File does indicate that the plug was not bumped and cement was tagged at 11279' (1494' above FC). This essentially means that no tail slurry was pumped outside the casing. Using only the lead cement volume and 30% XS washout, the TOC in the 12-1/4" x 9.625" annulus would be about 7131' and (5200' tvd). W-07 (189-019)--The AOGCC well file does not have sufficient information to verify AOR ?~ ~. r l ~ 1 ~.C.1~j `~,~\4 ~\\\C.~.\ \ ~~c 6"~C.c~~ O t~c~~ t~ _E C4~~ S (J ~ J S I~~C..~C, V~i3 _ ~O U M CU ~ cQMc.•..~ ~~~ .ti `~~, C1~~`~lfc S ~O ~• \ v\ 1/8/2007 2:09 PM I of? Re: [Fwd: W-210i Area of Review] • statements provided. Based on 30% XS washout, the TOC in the 12-1/4" x 9.625" annulus would be about 6508' and (4641' tvd). Art Saltmarsh wrote, On 1/8/2007 12:23 PM: -------- Original Message -------- Subject:W-2101 Area of Review Date:Tue, 02 Jan 2007 13:13:07 -0900 From:Staudinger, Mark <'Mark.Staudinye~•(rvbp.com=> To:al-t saltmt~rsh;;ri~admn.state.ak.us «W-210i_map_TopOBa_gtr_mile_circle (2).ZIP» «W-2101 Area of Review.doc» Art- ', Here are a couple items for the Area of Review needed for W-2101. I wrote up the word document that basically summarizes the cement integrity of the wells within 1/4 mile of W-2101. The powerpoint has an annotated W-2101 map. Our geophysicist created the map, and this is what he said - "I chose the Top OBa interval (highest injection zone) to show W-2101 in relation to it's neighbor wells. The map is pretty busy - I only showed the well spiders for W-210 and the wells w/I the 1/4 mile circle -you can zoom in to see the detail. There are dots on the map to show where each well is at TopOBa. I can easily make other versions to show the same sort of thing for the Top of the Pool/PA (UG_Mc Top), or any other Schrader zone." Let me know if this information is sufficient, or if more information will be needed. Thanks, Mark Staudinger GPB Rotary Drilling (907)564-4337 (907) 440-7403 cell 2 of 2 1/8/2007 2:09 PM ~ • Area of Review - W-2101 Revised January 2, 2007 This Area of Review for W-210i will discuss the wells that are within '/ mile of this injection well. There will be no annular disposal in W-210i, so that will not be an issue of discussion. W-210i is proposed as a water injection well, with possible MI injection in the future. There are 5 wells that come within '/4 mile of W-210i's projected well path. The following table displays the 5 wells within'/4 mile, their distance from W-210i, and any annulus integrity comments: .Well Name Distance ft Annulus Integrity Comments W-05 308 TOC calculated to be in UG_Ma sand. Distance between wells for in'ection zones is 400'-460'. - W-08 646 TOC calculated to be in Colville Shale below Schrader, Bluff. W-01 1164 TOC calculated to be in the UG Mb2 interval. W-203 1220 Offset roducer. Distance is for OBa-OBd. W-07A 1274 TOC calculated to be in Colville Shale below the Schrader Bluff. Cement bond logs were not available for W-05, W-08, W-01, and W-07A in the Schrader Bluff interval (4680' to 5193' TVD). In particular, W-210i will be injecting into 3 zones, OBa, OBb, and OBd, located within the Schrader Bluff sands. These three injection zones range from 4900' to 5031' TVD. A cement bond log was available for W-203 (the offset producer of W-210i) and shows that there is good cement integrity across the injection zones (actual TOC 4000' TVD). For W-05, W-08, W-01, and W-07A, the TOC was calculated using the daily drilling logs found in the original well files. All of these wells recorded no losses during the cement job. The calculations are based on the cement volumes pumped with 30% excess in the annular space. The TOC for W-05 is calculated to be above the injection zone, up to the UG_Ma sands. W-01 also has a calculated TOC above the injection zone, up to the UG Mb2 formation. However, W-08 and W-07A both have a calculated TOC to be below the injection zones. The TOC for these two wells is in the Colville Shale below the Schrader Bluff. This issue has been identified as a primary risk, and the four offset wells will be monitored in order to determine if injection fluids are migrating out of zone. Monitoring the offset wells will help to ensure that water injection remains safe and determine if future MI injection is possible. AOR - W-2101 1/1 r Bluff Top OBa De pth Structure Map, with selected well p. W-201 ~ ~, 49 509 '~ \ -~ p W- 00 B1 -17A O II 1, fi * • • n V O / -4. O ~ f 4g9 4978 N,_ I -4 W 2 WET j • 5p .9 / • r -20 - 85~ -211 ~ \ *" zalll ~~> ~ • ~' - rla ~: ~ 221 1 2 `S \ZOv 49 • O ( -5 ~ -50 1 UP T- 1 ~ '/< mile radius W-01 ~ 1 48. a circle '~ , _® , C1 W -210 - w-os o i _ ~ _ W-07A ~ W-203, L1 L2 ` , W_08 i I cD O OI ~O\ 612,000 is approximate. 616,000 a a over 620,000 pe 624,000 i 5,962,000 5,958,000 I 5,954,000 ~ I~=ooo~ 6 ---~ ~ • ~ AukaShapes - ~ ~~ ^ ~ ~ ~n~ ~ ;, ~ - .~ - . -:._: a~-- 4 ...... .,. Slide 1 of 1 ~ Defaulk Design ~~ _ile Edit View Insert Formak Tools Slide Show Vdindaw Help Adabe PDF _ _-~ ~ "«r '' ,~ ' 250°Io - ~ _>~ Arial 18 .~ B I U ':, - = ry A c: _ Common Tasks. V pT __ Alaska Department of Natural Resources Land Administration System Page 1 of 14 ~lasl<a Mapper hand Records/Status Plats Recorder's Search State Cabins ~~~~'~~ ~~sa~urc~~ leaks Case stract ---, 0 Fiie Type: ADL... ', File Number: 28263 `_ Printable Case File Abstract See Township, Range, Section and Acreage? i '~ ~'' YeS '~ NO New Search 1 L...A..S Menu... (Case Summary I Case Detail I Land Abstract ~., File: ADL 28263 ~ ~`'~~'~ As of 12/26/2006 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISS/APPRV/ACTV AUTH Status Date: 08/11/1965 Total Acres: 2560.000 Date Initiated.• 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O11N Range: 012E Section: 15 Section Acres: 640 Search Plats Meridian: U Township: O11N Range: 012E Section: 16 Section Acres: 640 Meridian: U Township: O11N Range: 012E Section: 21 Section Acres: 640 Meridian: U Township: O11N Range: 012E Section: 22 Section Acres: 640 Case Actions OS-28-1965 TRACT DEFINED SALE DATE 07-14-1965 STATUS (11) 11 TRACT DEFINED BID TYPE 1 FIXED ROYALTY RATE SALE NUMBER 14 TRACT NUMBER 59 FORM NUMBER 5 DL-lOCTOBER 1963 CONDITIONAL Y/N N PRIMARY TERM 10 http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber=028263... 12/26/2006 rAlaska Department of Natural Resources Land Administration System 07-14-1965 BID RECEIVED Page 2 of 14 STATUS (12} 12 BID RECEIVED BID TYPE 1 FIXED ROYALTY RATE TOTAL BONUS BID 7680 DEPOSIT AMOUNT 1536 ROYALTY SHARE % 12.500000 SOCONYMOBIL OIL COMPANY, INC., 50%; PHILLIPS PETROLEUM COMPANY, SO% 07-14-1965 NOTIFICATION LESSEE DESIGNATED NEW REL (20) 20 NOTIFICATION LESSEE OLD REL CODE 21 DISPOSAL NAME NOTIFICATION CID NUMBER 126677 SOCONY MOBIL OIL COR OLD CID # (SALE NO) 4568 SALE 14 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000126677 SOCONY MOBIL OIL COR WORKING INTEREST % 50 ROYALTY INTEREST % 43.750000 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000127093 PHILLIPS PETROLEUM C WORKING INTEREST % 50 ROYALTY INTEREST % 43.750000 07-14-1965 INITIAL OWNER SEGMENT CODE 1 CID NUMBER 000004568 SALE 14 ROYALTY INTEREST % 12.500000 07-16-1965 LEASE AWARDED STATUS (13) 13 LEASE AWARDED 08-11-1965 LEASE ISSUED EFFECTIVE DATE 09-01-1965 EXPIRATN DATE 08-31-1975 STATUS (20) 20 ACTIVE OS-20-1966 CUSTOMER CHANGED NAME NEW NAME: MOBIL OIL CORPORATION OLD NAME: SOCONYMOBIL OIL CORPORATION 11-28-1969 INITIAL OWNER http://www.dnr.state. ak.us/las/Case_Abstract. cfin?FileType=ADL&FileNumber=028263... 12/26/2006 Alaska Department of Natural Resources Land Administration System SEGMENT CODE 2 CID NUMBER 000126677 MOBIL OIL CORPORATIO WORKING INTEREST % 50 ROYALTY INTEREST % 43.750000 11-28-1969 INITIAL OWNER SEGMENT CODE 2 CID NUMBER 000127093 PHILLIPS PETROLEUM C WORKING INTEREST % 50 ROYALTY INTEREST % 43.750000 11-28-1969 INITIAL OWNER SEGMENT CODE 2 Page 3 of 14 CID NUMBER 000004568 SALE 14 ROYALTY INTEREST % 12.500000 11-28-1969 ASSIGNMENT APPROVED EFFECTIVE DATE 11-28-1969 SEGMENT CODE 2 ASSIGNOR'S CID 00012667? MOBIL OIL CORPORATIO ASSIGNEE'S CID 000127564 STANDARD OIL CO OF C WORKING INTER % ASSIGNED 16.666660 ROYALTY INTER % ASSIGNED 14.583330 11-28-1969 ASSIGNMENT APPROVED EFFECTIVE DATE 11-28-1969 SEGMENT CODE 2 ASSIGNOR'S CID 000127093 PHILLIPS PETROLEUM C ASSIGNEE'S CID 000127564 STANDARD OIL CO OF C WORKING INTER % ASSIGNED 16.666670 ROYALTY INTER % ASSIGNED 14.583330 12-17-1971 COMMENTS WELL DATA REQUIRED FOR KUPARUK STATE #1, WITHIN 30 DAYS OF RECEIPT OF NOTICE. 04-04-1974 PATENT RECEIVED EFFECTIVE DATE 03-27-1974 EXPIRATN DATE 03-27-1984 LEASE TERM ADJUSTED. TITLE ACQ UISITION FILE NUMBER NOT ON DOCUMENT. 03-18-1976 WELL CERTIFIED CAPABLE OF PRODUCING EFFECTIVE DATE 03-18-1976 http://www. dnr. state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028263... 12/26/2006 ' ~ Alaska Department of Natural Resources Land Administration System Page 4 of 14 KUPAR UK STATE #1 DETERMINED CAPABLE OF PRODUCING OIL IN PAYING QUANTITIES. MINIMUM ROYALTYAPPLICABLE, DUE 09-01-1977. 03-07-1977 ASSIGNMENT APPROVED EFFECTIVE DATE 03-02-1977 SEGMENT CODE 2 ASSIGNOR'S CID 000127564 STANDARD OIL CO OF C ASSIGNEE'S CID 000106859 CHEVRON USA INC WORKING INTER % ASSIGNED 33.333330 ROYALTY INTER % ASSIGNED 29.166660 04-01-1977 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 04-01-1977 UNIT CODE 1 PB PRUDHOE BAY UNIT TRACT 55& TOTAL LEASE ACRES 2560 UNITIZED ACRES 1 2560 PARTICIPATING ACRES 1 2560 ENTIRE LEASE COMMITTED TO OIL RIM & GAS CAP PA'S 04-01-1977 COMMENTS OIL RIM AND GAS CAP DECISION NOT IN FILE 04-01-1977 UNITIZED EFFECTIVE DATE 04-01-1977 UNIT CODE PB PRUDHOE BAY TOTAL ACRES 2560 UNIT ACRES 2560 DECISION DOCUMENT NOT IN CASE FILE. 07-01-1985 COMMENTS EFF. 7-1-85, CHEVRON USA INC MERGED INTO GULF OIL CORP AND THE SURVIVING CORP, GULF OIL CORP, CHANGED ITS NAME TO CHEVRON USA INC. 12-18-1986 COMMENTS APLN. REQUIREMENTS ARE WAIVED, AND TRANSFER OF RECORD TITLE INTEREST FROM CHEVRON USA INC TO GULF OIL CORP IS APPROVED EFFECTIVE 2-6-86. 12-18-1986 ASSIGNMENT APPROVED EFFECTIVE DATE 02-06-1986 SEGMENT CODE 2 ASSIGNOR'S CID 000106859 CHEVRON USA 1NC ASSIGNEE'S CID 000106539 CHEVRON USA INC http://www.dnr. state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028263... 12/26/2006 Alaska Department of Natural Resources Land Administration System WORKING INTER % ASSIGNED 33.333330 ROYALTY INTER % ASSIGNED 29.166660 11-30-1995 NOTIFICATION LESSEE CHANGED NEW NL (20) 20 NOTIFICATION LESSEE OLD NL (20) 20 NOTIFICATION LESSEE NEW NOTIF LESSEE CID# 33073 MOBIL ALASKA E&P INC OLD NOTIF LESSEE CID# 126677 MOBIL OIL CORP 12-19-1995 ASSIGNMENT APPROVED EFFECTIVE DATE 11-30-1995 SEGMENT CODE 1 ASSIGNOR'S CID 000126677 MOBIL OIL CORP ASSIGNEE'S CID 000033073 MOBIL ALASKA E&P INC WORKING INTER % ASSIGNED 50 ROYALTY INTER % ASSIGNED 43.750000 12-19-1995 ASSIGNMENT APPROVED EFFECTIVE DATE 11-30-1995 SEGMENT CODE 2 ASSIGNOR'S CID 000126677 MOBIL OIL CORP ASSIGNEE'S CID 000033073 MOBIL ALASKA E&P INC WORKING INTER % ASSIGNED 33.333340 ROYALTY INTER % ASSIGNED 29.166670 11-01-1999 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 11-01-1999 UNIT CODE 1 PB PRUDHOE BAY UNIT TRACT 55& TOTAL LEASE ACRES 2560 UNITIZED ACRES 1 2560 PARTICIPATING ACRES 1 1800 LEASE COMMITTED IN PART TO INITIAL POLARIS PA OS-10-2000 CUSTOMER CHANGED NAME NEW NAME: PHILLIPS ALASKA, INC. OLD NAME: ARCO ALASKA, INC. 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000033073 MOBIL ALASKA E&P INC ASSIGNEES CID 000107377 BP EXPLORATION (ALAS Page 5 of 14 http://www.dnr.state. ak.us/las/Case_Ab stract. cfin?FileType=ADL&FileNumber=028263... 12/26/2006 Alaska Department of Natural Resources Land Administration System Page 6 of 14 • WORKING INTER % ASSIGNED 13.157370 ROYALTY INTER % ASSIGNED 11.512700 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000033073 MOBIL ALASKA E&P INC ASSIGNEES CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED 17.776450 ROYALTY INTER % ASSIGNED 15.554390 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000033073 MOBIL ALASKA E&P INC ASSIGNEES CID 000106600 EXXON MOBIL CORPORAT WORKING INTER % ASSIGNED 35.822830 ROYALTY INTER % ASSIGNED 31.344980 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000033073 MOBIL ALASKA E&P INC ASSIGNEES CID 000106600 EXXON MOBIL CORPORAT WORKING INTER % ASSIGNED 14.890360 ROYALTY INTER % ASSIGNED 13.029070 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000033073 MOBIL ALASKA E&P INC ASSIGNEES CID 000034758 FORCENERGY INC WORKING INTER % ASSIGNED .020000 ROYALTY INTER % ASSIGNED .017500 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000127093 PHILLIPS PETROLEUM C ASSIGNEES CID 000106600 EXXON MOBIL CORPORAT WORKING INTER % ASSIGNED 8.991530 ROYALTY INTER % ASSIGNED 7.867580 http://www.dnr.state. ak.us/las/Case_Abstract. cfm?FileType=ADL&FileNumber=028263... 12/26/2006 Alaska Department of Natural Resources Land Administration System i ~ 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 ASSIGNORS CID 000127093 PHILLIPS PETROLEUM C ASSIGNEES CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED 13.507300 ROYALTY INTER % ASSIGNED 11.818890 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 2 ASSIGNORS CID 000127093 PHILLIPS PETROLEUM C ASSIGNEES CID 000034758 FORCENERGY INC WORKING INTER % ASSIGNED .013330 ROYALTY INTER % ASSIGNED .011660 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000127093 PHILLIPS PETROLEUM C ASSIGNEES CID 000106346 PHILLIPS ALASKA, INC WORKING INTER % ASSIGNED 36.492700 ROYALTY INTER % ASSIGNED 31.931110 08-03-2000 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2000 SEGMENT CODE 1 ASSIGNORS CID 000127093 PHILLIPS PETROLEUM C ASSIGNEES CID 000106346 PHILLIPS ALASKA, INC WORKING INTER % ASSIGNED 24.328470 ROYALTY INTER % ASSIGNED 21.287410 08-03-2000 NOTIFICATION LESSEE CHANGED NEW NL (20) 20 NOTIFICATION LESSEE OLD NL (20) 20 NOTIFICATION LESSEE NEW NOTIF LESSEE CID# 000107377 BP EXPLORATION (ALAS OLD NOTIF LESSEE CID# 000033073 MOBIL ALASKA E&P 1NC 01-02-2001 COMMENTS OVERRIDING ROYALTY INTERESTS ARE NOT TRACKED AFTER INITIAL SEPARATION FROM THE WORKING INTEREST. CHECK THE APPROPRIATE RECORDER'S OFFICE. 03-30-2001 ASSIGNMENT APPROVED Page 7 of 14 http://www. dnr.state. ak.us/las/Case_Abstract. cfin?FileType=ADL&FileNumbeY-028263... 12/26/2006 Alaska Department of Natural Resources Land Administration System Page 8 of 14 • EFFECTIVE DATE 02-01-2001 SEGMENT CODE 1 ASSIGNORS CID 000034758 FORCENERGY INC ASSIGNEES CID 000004134 FOREST OIL CORPORATI WORKING INTER % ASSIGNED .020000 ROYALTY INTER % ASSIGNED .017500 03-30-2001 ASSIGNMENT APPROVED EFFECTIVE DATE 02-01-2001 SEGMENT CODE 2 ASSIGNORS CID 000034758 FORCENERGY INC ASSIGNEES CID 000004134 FOREST OIL CORPORATI WORKING INTER % ASSIGNED .013330 ROYALTY INTER % ASSIGNED .011660 07-09-2001 COMMENTS A SUMMATION OF OVERRIDING ROYALTYINTERESTS HAS OCCURRED. INDIVIDUAL OVERRIDING ROYALTYINTERESTS ARE NO LONGER TRACKED SEPARATELY. 07-31-2001 CUSTOMER CHANGED NAME NEW NAME: EXXONMOBIL ALASKA PRODUCTION, INC. OLD NAME: MOBIL ALASKA E&P INC. 09-21-2001 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2001 SEGMENT CODE 1 ASSIGNORS CID 000106600 EXXON MOBIL CORPORAT ASSIGNEES CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED 35.822830 ROYALTY INTER % ASSIGNED 31.344980 09-21-2001 ASSIGNMENT APPROVED EFFECTIVE DATE 07-01-2001 SEGMENT CODE 2 ASSIGNORS CID 000106600 EXXON MOBIL CORPORAT ASSIGNEES CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED 23.881890 ROYALTY INTER % ASSIGNED 20.896650 OS-31-2002 COMMENTS FIXED TRANSACTIONS THAT APPEARED TO BE DUPLICATES BECAUSE OF IDENTICAL DATE AND TIME, BY CHANGING THE TIME ON THE TRANSACTIONS http://www.dnr. state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber--028263... 12/26/2006 ' Alaska Department of Natural Resources Land Administration System Page 9 of 14 • 09-26-2002 CUSTOMER CHANGED NAME NEW NAME: CONOCOPHILLIPS ALASKA, INC. OLD NAME: PHILLIPS ALASKA, INC. 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000107377 BP EXPLORATION (ALAS ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .309314 ROYALTY INTER % ASSIGNED .270650 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000106346 CONOCOPHILLIPS ALASK ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .423315 ROYALTY INTER % ASSIGNED .370401 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 2 ASSIGNORS CID 000106539 CHEVRON U.S.A. INC ASSIGNEES CID 000004134 FOREST OIL CORPORATI WORKING INTER % ASSIGNED .006438 ROYALTY INTER % ASSIGNED .005633 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 2 ASSIGNORS CID 000106539 CHEVRON U.S.A. INC ASSIGNEES CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED 11.847071 ROYALTY INTER % ASSIGNED 10.366187 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 1 ASSIGNORS CID 000033073 EXXONMOBIL ALASKA PR ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .427139 http://www.dnr.state.ak.us/las/Case Abstract.cfm?FileType=ADL&FileNumber=028263... 12/26/2006 Alaska Department of Natural Resources Land Administration System • • ROYALTY INTER % ASSIGNED .373747 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 2 ASSIGNORS CID 000106539 CHEVRON U.S.A. INC ASSIGNEES CID 000106346 CONOCOPHILLIPS ALASK WORKING INTER % ASSIGNED 11.740915 ROYALTY INTER % ASSIGNED 10.273301 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-OI-2002 SEGMENT CODE 1 ASSIGNORS CID 000004134 FOREST OIL CORPORATI ASSIGNEES CID 000106539 CHEVRON U.S.A. INC WORKING INTER % ASSIGNED .000232 ROYALTY INTER % ASSIGNED .000203 12-04-2002 ASSIGNMENT APPROVED EFFECTIVE DATE 11-01-2002 SEGMENT CODE 2 ASSIGNORS CID 000106539 CHEVRON U.S.A. INC ASSIGNEES CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED 8.578906 ROYALTY INTER % ASSIGNED 7.506543 12-31-2002 STATUS CODE STANDARDIZED STATUS CODE 35 ISS/APPRV/ACTV AUTH * * * * * STATUS CODE STANDARDIZATION STATUS CODE CHANGED BYBATCH UPDATE 03-31-2004 PARTICIPATING AREA ESTABLISHED EFFECTIVE DATE 02-01-2004 UNIT CODE 1 PB PRUDHOE BAY UNIT TRACT 55& TOTAL LEASE ACRES 2560 UNITIZED ACRES 1 2560 PARTICIPATING ACRES 1 600 LEASE INCORPORATED IN PART INTO THE ORION PA. 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 Page 10 of 14 http://www. dnr. state. ak.us/las/Case_Abstract.cfin?FileType=ADL&FileNumber=028263... 12/26/2006 Alaska Department of Natural Resources Land Administration System Page 11 of 14 • • ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000106346 CONOCOPHILLIPS ALASK WORKING INTER % ASSIGNED .007361 ROYALTY INTER % ASSIGNED .006441 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED .00521 I ROYALTY INTER % ASSIGNED .004560 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 1 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000033073 EXXONMOBIL ALASKA PR WORKING INTER % ASSIGNED .007196 ROYALTY INTER % ASSIGNED .006296 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 2 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000106346 CONOCOPHILLIPS ALASK WORKING INTER % ASSIGNED .007361 ROYALTY INTER % ASSIGNED .006440 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 2 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000107377 BP EXPLORATION (ALAS WORKING INTER % ASSIGNED .005211 ROYALTY INTER % ASSIGNED .004559 12-04-2006 ASSIGNMENT APPROVED EFFECTIVE DATE 09-01-2006 SEGMENT CODE 2 ASSIGNOR'S CID 000004134 FOREST OIL CORPORATI ASSIGNEE'S CID 000033073 EXXONMOBIL ALASKA PR http:!/www.dnr.state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028263... 12/26/2006 •Alaska Department of Natural Resources Land Administration System Page 12 of 14 • WORKING INTER % ASSIGNED .007196 ROYALTY INTER % ASSIGNED .006294 Legal Description OS-28-1965 * * * SALE NOTICE LEGAL DESCRIPTION C14-59 TIIN, R12E, UM I5, 16, 21, 22 2560.00 11-28-1969 SEGMENT I T 11 N, R 12E, UM SECTION 15: 640 ACRES SECTION 16: 640 ACRES CONTAINING 1280 ACRES, MORE OR LESS. SEGMENT 2 -LANDS ASSIGNED T I IN, R 12E, UM SECTION 21: 640 ACRES SECTION 22: 640 ACRES CONTAINING 1280 ACRES, MORE OR LESS. 04-01-1977 * * * * UNITIZED AND LEASE LEGAL DESCRIPTION * * ENTIRE LEASE COMMITTED TO PR UDHOE BAY UNIT PRUDHOE BAY UNIT TRACT SS T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA SECTION 1 S: 640 ACRES http://www.dnr.state.ak.us/las/Case Abstract.cfin?FileType=ADL&FileNumber=028263... 12/26/2006 Alaska Department of Natural Resources Land Administration System SECTION 16: 640 ACRES SECTION 21: 640 ACRES SECTION 22: 640 ACRES CONTAINING 2,560.00 ACRES, MORE OR LESS. 04-01-1977 ****PARTICIPATINGAREALEGALDESCRIPTION**************** ENTIRE LEASE INCORPORATED INTO OIL RIM AND GAS CAP PA'S T. I1 N., R. 12 E., UMIAT MERIDIAN, ALASKA SECTION I5: 640 ACRES SECTION 16: 640 ACRES SECTION 21: 640 ACRES SECTION 22: 640 ACRES CONTAINING 2, 560.00 ACRES, MORE OR LESS. 11-O1-1999 * * *PARTICIPATING AREA LEGAL DESCRIPTION * * * * * * * * * * * * * LEASE INCORPORATED IN PART INTO INITIAL POLARIS PA T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA SECTION 1 S: 640 ACRES SECTION 16: E/2, 320 ACRES; SECTION 21: NE/4, NE/4NW/4, NE/4SE/4, 240 ACRES; SECTION 22: N/2, N/2SW/4, SE/4SW/4, SE/4, 600 ACRES; CONTAINING 1,800.00 ACRES, MORE OR LESS. Page 13 of 14 02-O1-2004 * *FORMATION OF ORLON PARTICIPATING AREA LEGAL DESCRIPTION* LEASE COMMITTED INPART TO ORIONPARTICIPATING AREA PRUDHOE BAY UNIT TRACT 55 ORLON PARTICIPATING AREA T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA http:!/www.dnr. state. ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028263... 12/26/2006 ' Alaska Department of Natural Resources Land Administration System Page 14 of 14 SECTION 16: SWI/4, Sl/2NW1/4, 240.00 ACRES; CONTAINING APPROXIMATELY 240.00 ACRES, MORE OR LESS. PRUDHOE BAY UNIT TRACT SSA ORLON PARTICIPATING AREA T. I1 N., R. 12 E., UMIAT MERIDIAN, ALASKA SECTION 21: SWI/4, SI/2NW1/4, NWI/4NW1/4, Wl/2SEI/4, 360.OOACRES; CONTAINING APPROXIMATELY 360.00 ACRES, MORE OR LESS. h O'~ I:~SE'. 1' C~ Last updated on 12/26/2006. Not sure who to contact? Have a question about DNR? Visit the Pu_b__~i_c__I__nfo_ ratio„Center. Report technical problems with this page to the Wbmaster. Site optimized for Netscape 7, IE 6 or above. This site also requires that all CQKIE must be accepted. State of Alaska Natural Resaurces LAS Home Copyright Privacy. System_Status http://www.dnr. state.ak.us/las/Case_Abstract.cfm?FileType=ADL&FileNumber=028263... 12/26/2006 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 8000001 • Wnlle within 11d mi H190'1 of inioefinn uwll 6,14nn rocnnrnir • Tag TOC in Cemeni Volume Injection Nearby Well Setting depth Setting depth Formation @ Cement Volume Float collar tubing after pumped in Calculated TOC, 0°h Well Name Name Dist, Ft. Casing size Wt. per Ft. (Ft) MD (Ft) TVD shoe depth Hole Size pumped (CF) depth (Ft) pump) (Ft) annular (CF) Excess 1 ~~ PAL -SI since W-210 W-08 91712006 64 ' 9 518 47 12853 . 891.6 12114 ?905 12728 11279 2258 5643 W-05 PAL - on-line 308' 9 5!8 47 3972 8735 121!4 3089 13855 13794 3016 4343 W-01 P - on-line 1164' 9 5!8 47 12027 8623 12 114 2533 11911 11723 . 2408 4338 W-203 PAL-on-line 1220' _ :~ i ~~ V / W07 PAL - on-line 1274' 9 518 47 13984 .8680 121!4 3035 13864 12550. 2446 6175 Note: Injection in Oba, Obc, and Obtl intervals. This range is ftom -5035' to -4850' TVD. Band Loa intervals • TOC ND, 0% Excess Calculated TOC MD, 30°~ Excess TOC ND, 30% Excess Top of MA TVD Top of MC ND Top of OBa TVD Formation Top of Cement, w13D% Excess WI Status MITOA tests comments (from Digital Wellfile) Band Lag across SB? Top Depth Bottom Depth Normal - Bradenhead welded OA has been down squeezed > 09103/02: MIT OA Passed 4332.5 7307 5318 4539 470D 4977 Colville IC sealant squeezed io 2400 psi no 12,572. 13,412. --~--~ > 03120104: MIT OA PASSED 3412.3 &565 4559 4549 471D 4987 UG MA Normal - OA downsqueezed 8110102 to 2400 psi no 13,640. 14,448. > 08!02!04: MITOA Passed 3651.8 6113 4720 4584 4725 5002 UG MB2 Normal to 2400 psi. no 11,800. 12,6D7. 4582 4749 4981 Normal no data 4474.1 7977 5419 4669 4830 5147 Colville Normal no data no 13,696. 14,697. • Volume for unit)ength (Csg -9 5l8, tiS -12114) TOC above Injection Annulus Integrity Annular Annular Tubular Tubular , Zones? Comments (ft3/ft) {ftlft3) _ (ft3lft) (ftlft3) Top of t~ment calculated to be in Colville Shale below the N Schrader Bluff. 0.313188 3.19297 0.411024 2.43295 Y 0.313188 3.19297 0.411024 2.43295 Y 0.313188 3.19297 0.411024 2.43295 Offset producer Top of cement calculated to be in Colville Shale below the N Schrader Bluff. 0.313188 3.19297 0.411024 2.43295 Comments Offset distances are based on W-210iwp07. Top of Polaris PooIIPA is Top UG Mc Offset distances are based on W-210iwp07. Top of Polaris PooVPA is Top UG Mc Offset distances are based on W-210iwp07. Top of Polaris PooVPA is Top UG Mc Offset distances are based on W-210iwp07. Top of Polaris PoollPA is Top UG Mc Offset distances are based on W-210iwp07. Top of Polaris PooIIPA is Top UG Mc • • • Sondra D. Stewman as-sn25z 151 BP Exploration AK INC. ~~Mastercard Check" PO Box 196612 MB 7-5 I -~~ Anchorage, AK 99519-6612 DATE ~- PAY TO THE ~~~~ ~ ~ l ~~ t ~-'~~ ORDER OF ~ r/// f^°1./1.r~ ~-~LIr . ,n~. r'.o.-~ a ~~ ;~r~~ DOLLARS First National Ba?Sk Alaska Anchorage, AK 99501 MEMO ~~ ~:i25200060~:99L46227156411' OLS~ • • ~'RAYS1dIITTAL LETTEIa CI~ECI{I.IST i~VELL NAIVtE x,61/ `/-a2/Di~ PTD# ~~~ ' /~~ _ Development ~/ Service Exploratory Stratigraphic Test ~lon-Conventional Welt Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER Vb'HAT 1 (OPTIONS) i I APPLIES L MliLTI LATERAL ~ The permit is for a new wel(bore segment of existing i ~ we[I (If last two digits in i Permit No. , API No. 30- , API number ' between 60-69) are !Production should continue to be reported as a function of the i , original API number stated above. PILOT HOLE i Irt accordance with 20 AAC 25.005(f), all records, data and logs ! acquired for the pilot hole must be clearly differentiated in both ~ i ~ well name ( PH) and API number ~ ! ~ (~0_ _ -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC ~ EXCEPTION 125.05. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing j .exception. assumes the ~ ~ liability of any protest to the spacing exception that may occur. i ' ;DRY D[TCH ~ A1[ dry ditch sample sets submitted to the Commission must be in i SAMPLE i no greater than 30' sample intervals from below the permafrost or from where samples are first caught and l0' sample intervals j ,through target zones. ;Please note the following special condition of [his permit: Non-Conventional ~ production or production testing of coal bed methane is not allowed j Well '~ foc jname of well) until after ~Com~anv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. LCompany Name) must contact the !Commission to obtain advance approval of such water well testing I _i Proms I Rev: (2~i06 C: `j ody~transmittal_ch eckl ist `Nc::'~ PERMIT CHECKLIST Field & Pool PRUDHOE BAY, POLARIS OIL - 640160 __ _ ___ __ Well Name: _PRUDHOE BAY UNIT W-210i _____.__Program SER _ _ Well bore seg [] PTD#:2061850 Company BP EXPLORATION (ALASKA) INC Initial Class/l'ype SER / PEND _GeoArea Unit 11650 OnlOff Shore On-_-__-_ Annular Disposal !`~ Administration 1 Permit fee attached- Yes 2 Lease number appropriate_ _ _ _ _ Yes . _ - 3 Unique well-name and number Yes i4 Well located in a-defined pool - - Yes - Prudhoe Bay Field-Polaris Pool ~i5 Well located proper distance. from drilling unitboundary_ - Yes . - 6 Well located proper distance f(om other wells- Yes - - - J Sufficient acreage ayail_able in-drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - . - - _ _ _ _ _ _ _ - _ . - - _ - - _ - - j 8 If deviated, is.wellbore platincluded - - - Yes - - - ~ 9 Operator only affected party_ ._-.. _.. Yes 10 Ope[akorhasappr9priate-bondinforce-_-._-____ Yes_ _____ ___ __ _____________ ___________ ______-__-_ ~ 11 Permit-can be issued without conservatignorder- . _ _ _ - _ - _ - - _ Yes - - - - ~ 12 Pe[mitcan be issued without administrative-approval .. - . - - - - - . _ _ Yes _ _ _ - - AIO-25A applies. Appr Date 13 Can permit be approved before 15-day_wait- - - - - - - - - - - - - - - _ Yes _ _ _ _ _ ~ 1!22/2007 14 Well located within area and strata authorized by_ Injection Order # (put_IQ# in_comments)_(For Yes - - AIO.25A applies. - - .. - .. - - 15 All wells within 1/4_mile area of review identified (FO[ service well only)- - .. - - . - . - - Yes - 5 welts in AQR:- W-05, W-08, W-01, W-20$, W-07A 16 Pre-produced injector: duration_of pre production less than 3 months. (For service well only) NA I 17 tJonconve-n:ga-s conforms to AS$1,05,030.1.A),(~.2.A-D)-------------_-______ NA__ __-- --,.,,_____________---_._---__ 18 Conductor string provided Yes Engineering 19 Surface casing_protectsall_known_U$DWs___________________ _ ________ NA__ ______Welllocated-withinAEQ_1.______.--___________-- _-__.- -_,-_____ ,- 20 CMT_vo(adequate_to circul_ate.on conductor & surf-csg - - - - , - Yes i 21 C_MT-vol adequate-to tie-in long string to surf csg_ _ _ _ _ _ _ - _ _ _ No. - . - -- ~ 22 _C_MT-will cover-all kno_wn_productive horizon_s_ Yes 23 Casing design&adequatef_orC,TB&_permafr_ost___________________ Yes_ ___ ______ 24 Adequate tankage-or reserve pit .. - - - - Yes - - Rig is_equipped with steel-pits.-No reserve_pitplanned, All waste to approved disposal_well(s). 25 If_a_re-dill, has_a_ 1.0-403 for abandonment been approved - NA_ - - - 26 Adequate wellbote separationproposed Yes Proximity analysis performed, Traveling cylinder path calculated. 27 If diverter required, does it meet regulations_ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ - - - -- 28 Drilling fluid_program schematic_& equip listadequate_ Yes Maximum expected formation pressure 8.7-EMW.- Planned mud w_ei ht_u to 9.3 Appr Date 29 BQPEs, do they meetregulation - - _ Yes - - TEM 1119!2007 30 BOPS-press rating appropriate; test to-(put prig in comments)_ Yes - MA$P calculated at 1870psi, 4000_psi_BQP test based onplanned casingpressuretest. - - - - .~ 31 Choke_manifoldcomplieswlAPl_RP-53 (May84)__ Yes_ ___________________________________ 32 Work will occur without operation shutdown- - . - - - - - - - - Yes - ~ 33 Is presence_of H2S gas probable - - Yes - - - H2S is reported_on W pad. -Mudshou_Id preclude on rig... Rig has-sensors and ala[ms. _ _ 34 ~- Mechanical condition of wells within AOR verified (FO[se[vice well gnly) - - . - Yes 2 wells-(W-OS &_W,07) do-not have cement over SB._ Water injection allowed per AIO 25A. ~ 35 Petmitcan be issued w/o hydrogen. sulfidemeasuns_ _ _ _ _ _ _ _ _ _ _ _ _ _ No- _ --- . - - - - . _ _ - _ _ _ _ _ _ _ _ _ _ _ - - _ - _ - ------------------- Geology 36 Data_presented on potential overpressure zones - - - - tJA- - - - - - - - - - .. _ 37 Seismic analysis-of shallgwgas-zones- - - - - - - - - - - - - NA- - - - - _ - _ _ Appr Date 38 Beaked condition suryey_(ifaff-shore) NA- - _ _ _ _ _ _ _ _ _ - - - - --- ACS 1!9!2007 39 Contact namelphone for weekly_p_rogress reports_(exploratoryanly] NA_ - Geologic Engineering Pu Commissioner: Date: Com issioner: Date Co i i Date • Welt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Schlumherger • • c u~ er er Analysis of Bottomhole Reservoir-Fluid Samples BP Alaska Prudhoe Bay W-210 PVT Study Report Prepared for Greg E. Bernaski BP Alaska Standard Conditions Used: Pressure: 14.696 psia Temperature: 60°F Prepared by Stefan Smuk Schlumberger Oilphase-DBR 16115 Park Row, Suite 150 Houston, Texas, 77084 USA + 1 281 285 6370 May 10, 2007 Report 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Table of Contents Schlumberger List of Figures ............................................................................................................................ List of Tables ............................................................................................................................ EXECUTIVE SUMMARY ............................................................................................................ Objective ............................................................................................................................ Introduction ............................................................................................................................ Scope of Work ............................................................................................................................. Results ........................................................................................................................ Compositional.Analysis.of.Sampl.e..1.11;.fi55O.ft. MD. (-.4952.'.TVDSS-,.Mb.1. Sand ................ PVT Analysis. of. S.ample.1.1.1;. 655Q ft..MD .(-..4952'. TVD.SS),. Mh1..Sand ................................. . Constant Composition Expansion.Testing .............................................................................................. .Appendix A: Nomenclature.end .Definitions ........................................................................... Appendix B: Molecular.lN.eights.and.Densities.Used ........................................................... Appendix C: EIIUIPMENT ......................................................................................................... Fluid Preparation.and.Validation ......................................................................................................... Fluid Volumetric (P. VTJ.and.Viscasity.Equipment ...................................................................................... Appendix D: PROCED.URE ........................................................................................................ Fluids Preparation.and.V.alidation ........................................................................................................ Constant Composition Expansion P. racedure .............................................................................................. Differential Vaporization P. racedure ........................................................................................................ Multi-Stage Separation.Test ................................................................................................................. Liquid Phase Viscositl!and. Densixy.M. easurements. During D.V. SteR ............................................................... . Stock-Tank Oil (STO1.lliscosityand.Density.M.easurements .......................................................................... Asphaltene, Wax.and.SulfurGonient Measurements .................................................................................. SAR(PJA Anal ysis .............................................................................................................................. . High-Temperature H. igh. Pressure Filtration.Test ........................................................................................ • z 2 3 3 3 3 3 6 9 10 12 13 14 14 14 17 17 17 17 17 18 18 18 19 19 Oilphase-DBR 1 File 2007068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger • List of Figures figure 1: Stock Tank.O.il.Chromatogram.(.Sample.1._11.) .............................................................................. 8 figure 2: k-Plot.for.Eq.uilibrium.Check ~Sam~le.1.1.1) ................................................................................ 8 figure 3: Constant J;ompasitian.Expansion.at.87.°F.-.Relative.yolum.e ............................................................ 11 List of Tables Table 1: Sample.1,dentificati.on ................................................................................. ........................ 5 Table 2: Sampling.and.Transfer.Summan< ................................................................... ........................ 5 Table 3: Reservoir.FluidProperties ............................................................................ ........................ 5 Table 4: Stock-Tank.Ligliitl.Praperties ........................................................................ ........................ 5 Table 5: C30+ Composition, GOR,.°AP.I.-.Single-Stags.Elash.Sample.l_1.1) .............................. ........................ 6 Table 6: Calculate:tl.F.luid.Prnperties ........................................................................... ........................ 7 Table 7: Summary.of.P.VT.Results.:Sample.l_1.1 ............................................................ ........................ 9 Table 8: Constantl;ompasitinn.Expansion.at.87.°F.(.Sample.l_11.- ......................................... ........................ 10 • Oilphase-DBR 2 File 200700068 • Client: BP Alaska Well: W-210 Field: Prudhoe Bay Sand: Mb1 Schlumberger EXECUTIVE SUMMARY Objective To evaluate the compositions and properties of bottomhole reservoir-fluid samples collected during Modular Formation-Dynamics Testing (MDT) operations. Introduction At the request of BP Alaska, Oilphase-DBR has conducted a fluid analysis study on two bottomhole fluid samples collected during wireline operations in well W-210, drilled in the field Prudhoe Bay ,Alaska. Scope of Work • Homogenize the received bottomhole-fluid samples at the reservoir conditions with rocking for five days. • Conduct a preliminary evaluation of the bottomhole fluid samples, including determination of single- stageflash Gas-Oil Ratio (GOR-, reservoir fluid composition, stock-tank oil (STO) density, and calculated monophasic-fluid properties. • For one acquired hydrocarbon-fluid sample, conduct a partial PVT study consisting of Constant Composition Expansion (CCE) analysis, at reservoir temperature. Results • Two received bottomhole (MDT) samples, both orginating from the Mb1 sand (6550' MD-, were homogenized at the reservoir conditions for five days. • One of the recovered samples (1.10- was found to contain only water, while one X1.11) contained emulsified hydrocarbon fluid with co-sampled water. • The water sample (1.10) underwent disposal, while the hydrocarbon sample (1.11) was subjected to demulsification. The latter procedure consisted of treatment with chemical tlemulsifier, followed by homogenization and gravity-settling, at elevated temperature. Subsequent to demulsification, a GOR (direct-flash) analysis was conducted, together with water-content analysis of the flashed oil. The residual water content of the hydrocarbon liquid was 3.0 wt%. Thus, the sample was judged valid for PVT testing. • AConstant-Composition Expansion test was conducted at reservoir temperature for the demulsified reservoir-fluid sample. Viscosity analysis was subsequently attempted. The fluid was found to be excessively viscous for reliable measurement using Electromagnetic Viscometry (µ » 10,000 cp @ 125°F-. Summary of Analytical Data • Sample Sampling GOR Flash Liq. Gas Relative Bubble Point FVF Density Depth Density Density at Tres at Psat/Tres at Psat/Tres ft. MD scf/stb g/cm 3 Yg / Yair psia V ~ / V sro g/cm 3 1.11 6,550 119 0.994 0.5712 1050 1.014 0.995 Oilphase-DBR 3 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger • Quality Assurance Process Oilphase-DBR Schlumberger is committed to providing unsurpassed services in bottomhole reservoir fluid sampling and fluid property analyses while maintaining high standards of safety and quality. Our objective is to deliver the most accurate and reliable sampling processes and fluid property measurements available in the industry. This objective requires persistent innovation and ongoing development of state-of-the-art technologies and equipment. A rigorous quality assurance program, continuous employee training and enforcement of strict safety standards maintain our compliance with Quality, Health, Safety and Environment (QHSE) requirements. Proactive integration of QHSE objectives and management goals at every level supports the communication and implementation of QHSE policies and standards. Schlumberger requires that qualified engineering technologists perform all laboratory measurements according to specified analytical procedures designed for obtaining accurate and reliable data. Rigorous quality assurance programs and instrument calibration protocols are in place to ensure and maintain the validity of the procedures. Details of these programs are available upon request. The lab-generated data undergoes the following five levels of quality checks to establish the integrity of the reported results. a) Establish quality of measurement during data generation. b) Establish quality of processed data as per checklist during data processing by Data Quality Engineer. c) Data Quality Supervisor confirms the overall quality of the processed data and ensures cross correlative consistency. d) The responsible Project Engineer confirms consistency of reported data. e) Engineering Project Manager reviews the results/report for overall consistency. Hence the completion of each project requires that a qualified and experienced team of engineers perform a variety of independent review of all technical data to confirm the consistency and accuracy of the report as per pre-established quality checklists designed for each operation and based on the level of complexity. All property measurements and calculation procedures are maintained in company archives for a period of one year. This information is available for review by clients upon request. The file and laboratory records information are listed below to provide access reference to all records related to this project. For any questions, please do not hesitate to contact the undersigned Project Engineer. • File No.: 200700068 Data Analysis Data Review and Reporting Doris Lucia Gonzalez Data Quality Engineering Supervisor Stefan Smuk Special Projects Leader • Oilphase-DBR 4 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger • Table 1: Sample Identification Sample ID Receiving Chamber Sampling Date Opening Pres. Reservoir Conditions Chamber Volume in the field Pressure Temperature Depth (cc) (psia) (psia) (°F) (ft MD) 1.10 MPSR 1295 450 01 March 2007 4,700 Cc3 62 F 2,130 87.0 6,550 1.11 MPSR 1402 450 01 March 2007 4,600 C~ 62 F 2,130 87.0 6,550 Table 2: Sampling and Transfer Summary • Opening Transfer Transfer Closing Opening Transferred Sample ID Receiving conditions Cylinder conditions conditions conditions Sample Chamber in the field ID in the field in the field in the Lab Volume (psia) (psia/°F) (psia/°FI (psia/°FI (cc) 1.10 MPSR 1295 4,700 C~ 62 F 7608-CA 5,000 @ 120 F 100 C~ 62 F 425 C~ 76 F 430 1.11 MPSR 1402 4,600 Q 62 F 14180-D,4 5,000 Ca3120 F 400 C~ 62 F 780 Ca3 76 F 430 Table 3: Reservoir Fluid Properties Single-Stage Flash Saturation Molar Mass of Monophasic Sample ID Cylinder # Depth GOR Bo Pressure monophasic fluid water at Tres fluid cornent (ft MDI (scf/stb) Ibbl/stbl (psia) (g/mol) % (w/w) 1.10 7608-QA 6,550 -Water Sample - 1.11 14180-QA 6,550 119 1.014 1,050 313.2 3.0 Table 4: Stock-Tank Liquid Properties • Properties of Flashed Liquid Phase Sample ID Cylinder # Depth Molar Mass Density Gravity (ft MD) (g/mol) (g/cc) (°API) 1.10 7608-QA 6,550 -Water Sample - 1.11 14180-OA 6,550 532.1 0.994 10.87 Oilphase-DBR 5 File 200700068 • • Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger Table 5: C30+ Composition, GOR, °API -Single-Stage Flash (Sample 1.11) Sample 1.11; Cylinder CSB 14180-QA; Depth 6550 ft. MD (- 4952' NDSS-, Mb1 Sand Component MW Flashed Gas Flashed Liquid Monophasic Fluid (g/mole) WT % MOLE % WT % MOLE % WT % MOLE Carbon Dioxide 44.01 1.52 0.57 0.00 0.00 0.02 0.16 Hydrogen Sulfid 34.08 0.00 0.00 0.00 0.00 0.00 0.00 Nitrogen 28.01 2.14 1.27 0.00 0.00 0.03 0.35 Methane 16.04 94.55 97.51 0.00 0.00 1.38 27.01 Ethane 30.07 0.69 0.38 0.00 0.00 0.01 0.11 Propane 44.10 0.30 0.11 0.01 0.07 0.01 0.08 I -Butane 58.12 0.08 0.02 0.00 0.00 0.00 0.01 N -Butane 58.12 0.12 0.04 0.00 0.00 0.00 0.01 I -Pentane 72.15 0.04 0.01 0.00 0.00 0.00 0.00 N -Pentane 72.15 0.05 0.01 0.00 0.00 0.00 0.01 C6 84.00 0.10 0.02 0.01 0.06 0.01 0.05 M-C-Pentane 84.16 0.02 0.00 0.00 0.00 0.00 0.00 Benzene 78.11 0.03 0.01 0.00 0.00 0.00 0.00 Cyclohexane 84.16 0.02 0.00 0.00 0.00 0.00 0.00 C7 96.00 0.09 0.01 0.04 0.18 0.04 0.13 M-C-Hexane 98.19 0.04 0.01 .0.00 0.00 0.00 0.00 Toluene 92.14 0.05 0.01 0.00 0.00 0.00 0.00 C8 107.00 0.05 0.01 0.01 0.03 0.01 0.03 E-Benzene 106.17 0.00 0.00 0.01 0.02 0.01 0.02 M/P-Xylene 106.17 0.01 0.00 0.00 0.02 0.00 0.01 0-Xylene 106.17 0.00 0.00 0.00 0.01 0.00 0.01 C9 121.00 0.03 0.00 0.14 0.49 0.14 0.36 C10 134.00 0.03 0.00 0.15 0.46 0.14 0.34 C11 147.00 0.02 0.00 0.42 1.21 0.41 0.87 C12 161.00 0.00 0.00 0.64 1.69 0.63 1.22 C13 175.00 0.00 0.00 1.04 2.55 1.03 1.84 C14 190.00 0.00 0.00 1.57 3.54 1.55 2.56 C15 206.00 0.00 0.00 1.58 3.28 1.56 2.37 C16 222.00 1.93 3.71 1.90 2.68 C17 237.00 2.53 4.56 2.50 3.30 C18 251.00 2.30 3.91 2.26 Z.82 C19 263.00 2.80 4.54 2.76 3.28 C20 275.00 2.53 3.92 2.49 2.84 C21 291.00 2.69 3.95 2.65 2.86 C22 300.00 2.71 3.85 2.67 2.79 C23 312.00 2.61 3.57 2.57 2.58 C24 324.00 2.69 3.55 2.65 2.57 C25 337.00 2.53 3.20 2.49 2.32 C26 349.00 2.34 2.86 2.31 2.07 C27 360.00 2.51 2.97 2.47 2.15 C28 372.00 2.72 3.12 2.68 2.25 C29 382.00 2.68 2.99 2.64 2.17 C30 394.00 2.28 2.47 2.25 1.79 C31 404.00 2.1 Z 2.24 2.09 1.62 C32 415.00 1.88 1.93 1.85 1.39 C33 426.00 1.86 1.86 1.83 1.35 C34 437.00 1.93 1.88 1.90 1.36 C35 445.00 1.73 1.66 1.70 1.20 C36+ 850.00 47.02 23.61 46.33 17.07 Total 100.00 100.00 100.00 100.00 100.00 100.00 M W 16.54 426.84 313.19 MOLE RATIO 0.2770 0.7230 Oilphase-DBR File 200700068 • • • Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger Table 6: Calculated Fluid Properties Sample 1.11; Cylinder CSB 14180-QA; Depth 6550 ft. MD (- 4952' TVDSS-, Mb1 Santl Properties Flashed Gas Flashed Liquid Monophasic Fluid Cn+ Composition Mass % Mole % Mass % Mole % Mass % Mole C7+ 0.41 0.07 99.98 99.86 98.52 72.22 C12+ 0.01 0.00 99.22 97.43 97.76 70.44 C20+ - - 84.82 69.65 83.58 50.36 C30+ - - 47.02 23.61 46.33 17.07 Molar Mass C7+ 100.46 427.34 427.26 C 12+ - 434.67 434.67 C20+ - 519.78 519.78 C30+ - 850.00 850.00 Density C7+ - 0.970 - C 12+ - 0.972 0.972 C20+ - 0.998 0.998 C30+ 1.100 1.100 Fluid at 60°F 0.994 Gas Gravity (Air =1 ~ 0.571 Dry Gross Heat Content (BTU/scf~ 1,004 Wet Gross Heat Content (BTU/scf 986 Stock Tank Oil Properties at Standard Conditions: Measured Calculated C30+ Properties MW 532.10 426.84 850.00 Density (g/cm3- 0.994 0.970 1.100 Single Stage Flash Data Original STO GOR ~scf/stb) 119 STO Density Ig/cm3- 0.994 STO API Gravity 10.9 Oilphase-DBR File 200700068 ~J Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger Figure 1: Stock Tank Oil Chromatogram (Sample 1.11) Sample 1.11; Cylinder CSB 14180-QA; Depth 6550 ft. MD (- 4952' TVDSS~, Mb1 Sand rm~ a. ,,..~~. ,~. ~9 ~ ._~. e.a,cr+~+~eo c~ Norm. a5o aoo 350 i 300 I 250 200 150 U 1W ~ ~ a m Q fmV 4l lD N m rvUf~l mlmlC1~ `~ U .»~~ O U~ccc c~ oc~c u a rv m ~ 1O ?v+r~~ ~ p ~ K~ 0 20 25 30 36. 0 5 10 15 i• i• s.uu 2.50 2.00 a 1.50 0 1.00 0.50 0.00 Figure 2: k-Plot for Equilibrium Check (Sample 1.11) Sample 1.11; Cylinder CSB 14180-QA; Depth 6550 ft. MD (- 4952' TVDSS~, Mb1 Sand • C3 -2.00 -1.50 -1.00 -0.50 0.00 F 1- ~r~-rc~~ r~ 0.50 1.00 1.50 2.00 Oilphase-DBR 8 File 200700068 C Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumherger PVT Analysis of Sample 1.11; 6550 ft. MD (- 4952' TVDSSI, Mb1 Sand Table 7: Summary of PVT Results -Sample 1.11 Sample 1.11; Cylinder CSB 14180-QA; Depth 6550 ft. MD (- 4952' NDSS-, Mb1 Sand • Reservoir Conditions: Pressure: 2131 psia Temperature: 87.0 °F Summary of Fluid Properties: Water Content: 3.0 Wt% STO Basis Bubble Point Pressure At Tres 1,050 psia Gas-Oil Ratio Single-stage Flash: 119 scf/stb Properties at 60°F STO °API Gas Gravity (Average) Single-stage STO: 10.9 0.571 Properties at Reservoir Conditi ons Viscosity: N/M cP Compressibillity (Cod: 5.OS 10-6/psi Density: 1.001 g/cc Properties at Saturation Condi tions Viscosity: N/M cP Compressibillity (Co-: 5.50 10-6/psi Density: 0.995 g/cc Formation Volume Factor C~?Pres & Tres @Psat & Tres Single-stage Flash: 1.008 1.014 Note: Standard conditions are 14.696 psia and 60°F • Oilphase-DBR File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger • • Constant Composition Expansion Testing Pi Ps Oilphase-DBR Table 8: Constant Composition Expansion at 87°F (Sample 1.11) Sample 1.11; Cylinder CSB 14180-QA; Depth 6550 ft. MD (- 4952' NDSS-, Mb1 Sand Pressure Relative Vol % Liquid % Liquid Liquid Density Compressibility (psial IVtotNsa~l IVrQ/Vsatl (Vrq/Vrarl (g/cm 1 (10 /psial 9019 0.9680 100.0 96.8 1.027 3.04 7021 0.9740 100.0 97.4 1.021 3.53 5017 0.9810 100.0 98.1 1.014 4.11 3017 0.9890 100.0 98.9 1.006 4.76 2517 0.9910 100.0 99.1 1.004 4.94 2130 0.9940 100.0 99.4 1.001 5.08 2022 0.9940 100.0 99.4 1.001 5.12 1418 0.9980 100.0 99.9 0.996 5.36 1315 0.9990 100.0 99.9 0.996 5.40 1220 1.0000 100.0 99.9 0.995 5.43 1185 1.0000 100.0 97.7 0.995 5.45 1173 1.0000 100.0 100.0 0.995 5.45 1105 1.0010 100.0 100.1 0.994 5.48 1050 1.0000 100.0 100.0 0.995 5.50 985 1.0240 917 1.0410 855 1.0650 10 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger • • J Figure 3: Constant Composition Expansion at 87°F -Relative Volume Sample 1.11; Cylinder CSB 14180-QA; Depth 6550 ft. MD (- 4952' NDSS-, Mb1 Sand 1.0 1.0 1.0 a d ~_ E 1.0 0 0 m a .~ m 1.0 0.9 0.96 0 Oilphase-DBR iuuu zuuu uuuu 4uuu 5uuu buuu iuuu uuuu ~uuu iuuuu Pressurelpsia) 11 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger Appendix A: Nomenclature and Definitions API Gravity American Petroleum Institute gravity Bg Bo CCE DV GLR GOR LO n OBM P Pb PV Pi R Rs T V Vr . STL STO %, w/w Z Gas formation volume factor Oil formation volume factor Constant composition Expansion Differential Vaporization Gas Liquid Ratio Gas Oil Ratio Live Oil Number of moles Oil Based Mud Absolute pressure Bubble point pressure Pressure-Volume Method Initial Reservoir Pressure Universal gas constant Solution gas oil ratio Temperature Volume Relative volume Stock Tank Liquid Stock Tank Oil Weight Percent Gas deviation factor Dry Gross Heating Value is defined as the total energy transferred as heat in an ideal combustion reaction at a standard temperature and pressure in which all water formed appears as liquid. Wet Gross Heating Value is defined as the total energy transferr Molar masses, densities and critical values of pure components are from CRC handbook of Chemistry and Physics and those of pseudo components are from Katz data. Gas viscosity is calculated from the correlation of Carr, Kobayshi and Burrows as given in the "Phase Behavior of Oilfield Hydrocarbon Systems" by M.B. Standing Compressibility inconstant mass study is obtained from mathematical derivation of relative volume. Gas gravity is calculated from composition using the perfect gas equation (Gas deviation factor, Z=1) The Stiff and Davis Stability Index is an extension of the Langlier Index and is used as an indicator of the calcium carbonate scaling tendencies of oil field brine. • A positive index indicates scaling tendencies. • A negative index indicates corrosive tendencies. An index of zero indicates the water is in chemical equilibrium and will neither deposit nor dissolve calcium carbonates. Oilphase-DBR 12 File 200700068 • • • Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Oilphase-DBR Schlumberger Appendix B: Molecular Weights and Densities Used Components MW Density ~g/cc) C02 44.01 0.827 H2S 34.08 0.993 N2 28.013 0.808 C 1 16.043 0.300 C2 30.07 0.356 C3 44.097 0.508 I-C4 58.124 0.567 N-C4 58.124 0.586 I-C5 72.151 0.625 N-C5 72.151 0.631 C6 84 0.660 MCYC-C5 84.16 0.753 BENZENE 78.11 0.884 CYCL-C6 84.16 0.781 C7 96 0.688 MCYCL-C6 98.19 0.773 TOLUENE 92.14 0.871 C8 107 0.749 C2-BENZEN 106.17 0.870 M&P-XYLEN 106.17 0.866 0-XYLENE 106.17 0.884 C9 121 0.768 C10 134 0.782 C11 147 0.793 C12 161 0.804 C13 175 0.815 C14 190 0.826 C 15 206 0.836 C16 222 0.843 C 17 237 0.851 C 18 251 0.856 C19 263 0.861 C20 275 0.866 C21 291 0.871 C22 300 0.876 C23 312 0.881 C24 324 0.885 C25 337 0.888 C26 349 O.S92 C27 360 0.896 C28 372 0.899 C29 382 0.902 13 File 200700068 Client: BP Alaska Field: Prudhoe Bay S~hliimhpnnpn Well: W-210 Sand: Mb1 • Appendix C: EQUIPMENT Fluid Preparation and Validation The opening pressure of the cylinder is measured using a Heise pressure gauge soon after the sample arrives in the laboratory. Subsequently, the sample bottle is pressurized to the reservoir pressure using water-glycol mixture at the bottomsitle of the piston cylinder. Custom made heating jacket is wrapped around the cylinder to heat the sample bottle to the reservoir temperature. The sample bottle is then placed into a rocking stand and rocked for 5 days to homogenize the reservoir fluid. Live reservoir fluid analysis is necessary in the sample validation process as well as during the completion of various fluid studies. A description of the experimental equipment used for these analysis follows. All live fluid analyses are completed with a JEFRI Gasometer. This unit in conjunction with GC analysis (see below) provides the full fluid compositional analysis, GOR, density at sampling P&T corrected to standard conditions. The JEFRI gasometer consists of amotor-driven piston in a stationary cylinder. The piston displacement is monitored to determine the swept volume of the cylinder. The cylinder pressure is automatically held at ambient pressure. Piston motion is tracked by a linear encoder, which is subsequently, converted to measure the gas volume in the cylinder. The total Gasometer volume is 10 L. The evolved gas can be re-circulated through the system to facilitate equilibrium at a maximum flow rate of 40 L/hr. The operating pressure of the Gasometer is ambient pressure (up to a maximum of 40 psia) and the operating temperature ranging from room temperature to 40°C. Following the flash of the live fluid sample to ambient conditions in the gasometer, compositional analysis of residual hydrocarbon liquid and evolved gas phase is conducted using gas chromatography (GC-. • Analysis of hydrocarbon liquids is conducted using an HP6890 liquid injection gas chromatograph equipped with flame ionization detector (FID). In this system, separation of individual components is carried out in a 30m long, 530mm diameter "Megabore" capillary column made of fused silica with 2.6-micrometer thick methyl silicone as the stationary phase. The operating temperature range of the stationary phase is 60 to 400°C. Over this temperature range, the components eluted are from C, to C36 along with naphthenes and aromatics components. Based on the physical properties, these components are retarded in a segregated fashion by the stationary phase during the flow of carrier gas (helium) through the column. With prior knowledge of the amount of "retention" for known compounds contained in calibration standards, the same compounds can be identified in the unknown hydrocarbon sample by matching "retention" times. The relative concentration of each component is determined by the concentration of ions hitting the FID upon the elution of each component. The analysis of hydrocarbon gases is carried out using an HP6890 gas injection GC equipped with two separation columns. The first column is a combination of a 100 mesh packed column and 100 mesh molecular sieve using high purity helium as a carrier gas. The molecular sieve is used to achieve separation of the light gaseous components (nitrogen, oxygen, and methane) while the packed column serves to separate ethane, propane, butanes, pentanes, and hexanes along with carbon dioxide and hydrogen sulfides. The second column is a packed column as described previously in liquid analysis. This column is capable of achieving separation of components up to C,Z+, along with the associated naphthenes and aromatics that are lumped into the Cs+fraction during analysis and reporting. Components up to C4 are analyzed using a thermal conductivity detector (TCD) while the C5+ components are analyzed for using a FID detector. The instrument has programmable air actuated multiport valves that allow the flow of the sample mixture to be varied between the two columns, and hence, allowing for the correct separation and analysis of the • Fluid Volumetric (PVTJ and Viscosity Equipment Oilphase-DBR 14 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger • The preliminary saturation pressure, constant composition expansion (CCE-, differential vaporization (DVj, multi-stage separation tests (MSST) are measured using apressure-volume-temperature (PVT) apparatus. The PVT apparatus consists of a variable volume, visual JEFRI PVT cell. The main component of the cell consists of a Pyrex glass cylinder 15.2-cm long with an internal diameter of 3.2 cm. An especially designed floating. piston and a magnetically coupled impeller mixer are mounted inside the Pyrex cylinder to allow for mercury-free operation. The bottom section of the piston is furnished with o-rings to isolate the hydraulic fluid from the cell content. The piston allows liquid level measurements as small as 0.005 cc. The magnetically coupled impeller mixer, mounted on the bottom end cap of the PVT cell, allow quick equilibration of the hydrocarbon fluid. The effective volume of the cell is approximately 120 cc. The Pyrex cylinder is housed inside a steel shell with vertical tempered glass plates to allow visual observation of the internal tube contents. A variable. volume JEFRI displacement pump controls the volume, and hence, the pressure of the fluids under investigation by means of injection or withdrawal of transparent hydraulic fluid connected to the floating piston from the top of the JEFRI PVT cell. The same hydraulic fluid is also connected to the outer steel shell to maintain a balanced differential pressure on the Pyrex cylinder. The PVT cell is mounted on a special bracket, which can be rotated 360°. The bracket along with the PVT cell is housed inside a temperature controlled, forced air circulation oven. The cell temperature is measured with a platinum resistance thermal detector (RTD) and displayed on a digital indicator with an accuracy of 0.2°F. The cell pressure is monitored with a calibrated digital Heise pressure gauge precise to ± 0.1 of full scale. The temperature and pressure ratings of this PVT system are 15,000 psi (103 MPa~ and 360°F (182°C-. The fluid volume in the PVT cell is determined using a cathetometer readable to the nearest 0.01 mm. The cathetometer is equipped with ahigh-resolution video camera that minimizes parallax in readings and uses a high- . resolution encoder producing both linear and volumetric readings. The height measurements by the cathetometer have been precisely calibrated with the total cell volume prior to the start of the test. The floating piston is designed in the shape of a truncated cone with gradually tapered sides, which allows measurement of extremely small volumes of liquid (0.005 cc) corresponding to roughly 0.01 % of the cell volume. The viscosity of the live reservoir fluid is measured at the reservoir temperature and pressure conditions using Cambridge SPL440 electromagnetic viscometer, which consists of one cylindrical cell containing the fluid sample and a piston located inside the cylinder. The piston is moved back and forth through the fluid by imparting an electromagnetic force on the piston. Viscosity is measured by the motion of the piston, which is impeded by viscous flow around the annulus between the piston and the sample cylinder wall. Various sizes of pistons are used to measure the viscosity of various fluids having different levels of viscosity. The temperature is maintained at the experimental condition using a re-circulating fluid heating system. The internal temperature is monitored using an internal temperature probe. The temperature rating of the viscometer is 190°C and pressure rating is 15,000 psig. The accuracy is ±1.5% of full scale for each individual piston range. The total volume of fluid sample required for viscosity maasiiramPnt is , rr. A cylindrical piston cell (carrier chamber) with a maximum internal volume of 25 mL is attached at the top of the viscometer. The purpose of this cell is to allow the operator to conduct the differential vaporization pressure steps within the viscometer. The back and forth motion of the piston within a narrow clearance provides sufficient agitation to achieve phase equilibration and allow gases to escape and accumulate at the top of the carrier chamber. The heating jacket is wrapped around the viscometer and the carrier chamber and maintains experimental temperature • uniformly throughout the system. Oilphase-DBR 15 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger The JEFRI PVT cell is also equipped with fiber optic light transmittance probes to measure the onsets of hydrocarbon solids nucleation (OHSP) due to changes in the temperature, pressure and/or composition. These fiber optic probes are mounted across the windows of the visual cell. The principle behind the measurement is based on the transmittance of a laser light in the near infra red (NIR) wavelength through the test fluid undergoing temperature, pressure or the fluid composition changes. In this system, a computerized pump is controlled to maintain the system pressure during isobaric temperature sweeps for wax nucleation, isothermal pressure drop and/or isobaric injections of precipitating solvents for asphaltene nucleation studies. The process variables (i.e., temperature, pressure, solvent volume, time and transmitted light power level) are recorded and displayed from the detector. The fiber optic light transmittance system referred to here that detects the conditions of OHSP is termed as the light scattering system (LSS-. High pressure filters are also used during the asphaltene nucleation study to quantify the amount of asphaltene in the fluid at the specified conditions. The filter manifold used is rated for 10,000 psia. The filter assembly consists of two plates screwed together with the hydrophobic filter sandwiched between them. • Oilphase-DBR 16 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schfumberger • Appendix D: PROCEDURE Fluids Preparation and Validation After homogenizing, a small portion of the single-phase reservoir fluid is first subjected to a single stage flash experiment to determine flash Gas-Oil-ratio (GOR). The flashing is conducted from some pressure above the bubblepoint pressure at reservoir temperature into an atmospheric Gasometer and measuring the corresponding volumes of gas and liquid. The atmospheric flash also provides parameters such as GOR and stock tank oil density. The flashed fluids (gas and liquid) are then subjected to compositional analysis using gas chromatographic technique. Subsequently, live oil composition is calculated based on the measured gas and liquid compositions and GOR values. In addition, asub-sample taken from each cylinder is isobarically transferred into the PVT cell at the reservoir temperature. Subsequently, a quick P-V relationship is established to determine the saturation pressure. Constant Composition Expansion Procedure A sub-sample of the test fluid is initially charged to the PVT apparatus and the system temperature stabilized at the reservoir temperature. The CCE experiment is then conducted by incrementally reducing the pressure from some pressure above the bubblepoint pressure to a pressure well below the bubblepoint pressure in a number of discrete steps. At each pressure step, the magnetic stirrer is used to make sure that the subject fluid achieved equilibrium. Total fluid volume (with visual observation of a single or two phase condition in the cell) is measured at each pressure stage, and subsequently, apressure-volume (P-V) plot is created identifying the phase state at each P-V condition. The intersection of the two lines plotted using the pressure and volume data above and slightly below the observed phase change corresponded to the measured saturation pressure of the fluid. In this manner, the P-V plot confirms the saturation pressure observed visually in the PVT cell. The measured pressure and volume data are then used to • compute live oil compressibility above the bubblepoint pressure and relative oil volumes over the entire pressure range Differential Vaporization Procedure Subsequent to the completion of the CCE experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. A differential vaporization (DV) experiment is then conducted by incrementally reducing the pressure in the PVT cell indiscrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a DV test is described below: • The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the DV test. • The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the DV test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. • The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section- • The previous two steps are repeated until either an atmospheric pressure or a predetermined abandonment pressure is reached. • Multi-Stage Separation Test Oilphase-DBR 17 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger • Subsequent to the completion of the DV experiment, another sub-sample of the test fluid is charged to the PVT apparatus and the cell contents are then mixed with the magnetic mixer to allow for phase equilibration at the reservoir temperature and pressure conditions. Amulti-stage separation experiment is then conducted by incrementally reducing the pressure and temperature conditions in the PVT cell in discrete steps. In these steps, the pressure is reduced below the saturation pressure, and hence, allowing the gas phase to evolve. A typical pressure stage in a separation test is described below: • The pressure in the PVT cell is reduced to a pressure just above the bubblepoint pressure of the oil. This is the starting point of the separation test. • The temperature of the PVT cell are then reduced to the first-stage separation test temperature and allowed the cell content to equilibrate. The pressure of the fluid is then reduced to the first pressure stage (below the bubblepoint pressure) of the separation test allowing free gas to evolve. The magnetic mixer is then used to achieve equilibration between the free gas and the pressurized liquid. • The evolved gas phase is then isobarically removed from the PVT cell into an evacuated pycnometer for gravimetric density and compositional analysis by the flash procedure (see Fluid Analysis Equipment Section] The previous two steps are repeated in five stages to stock tank conditions. Liquid Phase Viscosity and Density Measurements During DV Step Prior to measuring the viscosity, a suitable size piston is selected with the proper viscosity range and the electromagnetic viscometer is calibrated using a fluid with known viscosity. • A portion of the live reservoir fluid used in the DV test is then transferred into ahigh-pressure high-temperature electromagnetic viscometer. The viscometer is initially evacuated and kept at the same temperature as that of the PVT cell. During the transfer of approximately 15 cc of live hydrocarbon liquid to the evacuated viscometer, flashing of oil takes place, and hence, the viscometer system is flushed with live oil twice to make sure a representative live oil sample is taken. Subsequent to transfer of live reservoir fluid into the viscometer, the fluid system is allowed to achieve thermal and pressure equilibration. Then, the viscosity reading is taken. Following the viscosity reading, incremental pressure reduction steps are repeated as those used in DV steps. At each pressure point, the piston was allowed to run back and forth for sufficient time to achieve pressure equilibration and allow the liberated gas to migrate vertically upwards and accumulate at the top of the carrier chamber. Experiments are also conducted independently using a PVT cell for phase equilibration. The viscosity measurements done on liquid sample transferred from the PVT cell after equilibration compares very well with the measurements done on liquid sample subjected to pressure steps within the viscometer. Stock-Tank Oil (STO) Viscosity and Density Measurements A sample of STO is taken in a known capillary tube to measure the STO viscosity at a preset temperature. The temperature bath is maintained at the preset temperature. A small sample of the liquid is also transferred into the Anton Paar DMA45 densitometer to measure the density of the liquid phase. The viscosity and density measurements are repeated for data consistency check. Asphaltene, Wax and Sulfur Content Measurements • Asphaltene content of stock-tank oil samples is conducted using the IP-143 (French Institute of Petroleum) procedure. In this procedure, the asphaltenes are characterized as the n-heptane insoluble fractions of the crude oil. Wax content of the STO is measured using UOP (Universal Oil Product) 46-64 procedure. The sulfur content of the STO is measured using ASTM D 2494 procedure.. All other STO analysis were measured according to industrial standards. Oilphase-DBR 18 File 200700068 Client: BP Alaska Field: Prudhoe Bay Well: W-210 Sand: Mb1 Schlumberger • SAR(P)A Analysis A spinning band distillation was carried out on the original sample to establish two fractions. The initial boiling point to 300°C fraction was then analysed using a supercritical fluid chromatographic (ASTM 5186-91) method to determine the saturates and aromatics content. The greater than 300°C fraction first subjected to a gravimetric analysis to determine the pentane insoluble content (asphaltenes-. This method dissolves the fraction in an equal weight of toluene, then 40 volumes of pentane were added to precipitate the insoluble portion of the sample. The precipitate was filtered, dried and weighed. The solvent was removed from the soluble portion of the sample, which was referred to as the maltenes. The maltenes were then redissolved in pentane and were chromatographically separated into saturates, aromatics and resins ~polars) fraction by elution from a column filled with activated alumina, using various solvents and solvent mixtures. The solvents were then removed from each fraction and the amount of material The data from the three methods were combined to determine the amount of each component type in the original sample. Mass balances were calculated throughout the procedure to assure accurate data. High-Temperature High Pressure Filtration Test During the filtration process, it is important that the monophasic fluid remains monophasic as it passes through the filter manifold. Hence, high pressure nitrogen is used on the back side of the filter so that the equal pressure is maintained on both sides of the filter. This procedure prevents any flashing of the fluid in the filter manifold and assures filtration of a representative fluid. • • Oilphase-DBR 19 File 200700068
