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Home My WebLink About205-152 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Pull HEX Plug Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 205-152 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-23281-00-00 7. Property Designation(Lease Number): ADL 0028239 8. Well Name and Number: ORIN L-250 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,SCHRADER BLUF OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 9186 p feet Plugs measured feet true vertical 4464 feet Junk measured feet SEP 2 7 2016 a16 Effective Depth: measured 9186 feet Packer measured 6242 feet true vertical 4464 feet Packer true vertical 4206.22 feet ((�� C(� _ Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 79 20"X 34"215.5#A 32-111 32-111 Surface 3326 10-3/4"45.5#L-80 31-3356 31-2627 5210 2480 Intermediate 7393 7-5/8"29.7#L-80 28-7420 28-4430 6890 4790 Production Liner 1939 4-1/2"12.6#L-80 6695-8634 4320-4439 8430 7500 Perforation Depth: Measured depth: 7524-8460 feet feet True vertical depth: 4430-4429 feet feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 26-6358 26-4235 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED FE:E I 3 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 183 81 260 1166 382 Subsequent to operation: 98 71 1114 1341 418 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature VC/' Phone +1 907 564 4424 Date 9/27/16 Form 10-404 Revised 512015 rrL D/.4F l y RB DMS 0/ SEP 2 8 2016 Submit Original Only 4 reg,% • • Packers and SSV's Attachment ORIN L-250 SW Name Type MD TVD Depscription L-250 TBG PACKER 6241.78 4206.22 4-1/2" Baker Premier Packer L-250 PACKER 6705.77 4322.04 5-1/2" BAKER ZXP PACKER L-250 PACKER 8522.71 4432.33 4-1/2" Swell Packer • • 0) c° ID w 'C a) 'O Q ~ 03 m N ° a) a) c O _2 O o E 18- co O -o v C) (° CO 7 -p co N O @ 'O fl- OO ~ � a) zs a) a) o o 0o Q-oo2 • '3 z 1 o 0 -a o as o � O rn 0a) 12 - � O 2 0 E c o o Z O - 0a_ O@ co - `c w d a O c Eo N 3 2 d U a3 m_ �,.) U C L O is .F2 -o 5 a) r• O L a) '� w N 2 tea) - 03NLc) £ -' p = O c 3 Q .c Q ma o O 0 �' Q 2 n 2 D C i d >, O b m m O as i c -o Cu Q 2 co co E cis -co o (� c 2 2 i° a) 2I 1-).N- 6 6 •c cn � � co m� ca 0 0 axi is O in rn as CO o Ca) (tea dm2 UL o Qa) — Lo „. LL LL_ O c c�0 0 ()i -C N -6 2 y a O Q4- O " .c O - I, CCD ns a) c-d m co Q ami a) o w = a o Ern d o `� O d 0 0 a) O ° m a) o m 2 O : LL C ° 3 * ii c o . LL E. O O cn y > o o 81 0,O O o O N 0 .c o Co (n a E c o c � .r Cu H H C , �' rrj � � C0 � _CD - O 0 cow o Od N .O • D a) = a .ac° a. Q NaD O a- LL N m O N - 6 0- C a) O= -c N w H Q c N a) c N M p a Q w _ Q O a) E o os a) : c ao Nin CI) Z X (n u) XZoD oLn c° u) 0_ Y a) ,, ao Qa O w — XZo oco (° -o x w Cu 0 - x � � .u) u) X c LL 2 m w O 0 �n o Cl) Cl) a) c 2 rn O D -_ E 2 0 cm ° o ,- Q x E 2 a) c I r -rill Q : O — c a) O Q O : O E 5 o E - _ a) : E w C a a) C° c N (° O 0 .0 N d a) -a � D O O O vim O , cp Er) a � � � a a a) , N O a Q O _O O O N O .0 C N = •C ; a) d 2 O `11 opo °DU o020 � Uch Cu � � U � L� � � (j " m � co N wVao kV c Et * >,m o o E a) f * > c n a) * • o) (n r (..,:1, Qp ct .02 RI (n o2 _1Lo O Qp `n N (/) - 2 0 o) L Q : - 2 W ) (n * 2 2 (n U m • U 7 +. .0 N E Q-N .- U a) m o O 6 o a) a) CS) o O > O a) � � c � D � � � a c a>i � � Cu a U � o c0 -) UX c Ln a) (° O Ln a) 2 -c ' c +_. O In a) C C D L a) a) Q a) O - N C o > J a) O (On Q) Q (>° N- > p r,..1.-0 > 7 •C > a) o) O O N C_ O N ~ o)N (° _� O m C •, N N_ (LB N > (Y6 O C N ii) C Q Q U C L a) fI a) - an Q L E - O m E4 OD .� Qo a) o) 2 c *k aoo2 0 * 112 'c4O N otc o m UF- o - jUC0 w UF- ow O °op xl-,50E o ° UH o co U U -) H : U -, 2 QQcnYcoL� L : U -32 ;� d E : 0 -3v) I— � : U -, u) (n . LU I- 0 CO CO O O CO rN-- >- >-5 o N O O N ~ \ N M N N N N a0 co CO co 0 Q ' • • Ca ± c 0 ¢ o ¢ E co 2 L t O / / 0- % 2 nI- 0� 70 22 ƒ _- //CO D a - 2 E % o - m Ce $ I -J � / a / >I ( C C3 CO \ Im k Bic : / k \ G a = 2 75 C _I 5 w / 2 .o e E CO U / a) � a/ 2 ƒ k = \ E \ 2f5 \ / / i / / 2 to G_ n ,- � \ ƒ % f2 00 TRS= 4-1/6"aW • L-250 WELLHEAD 11"FRAC• L SR L2 SAFE OTEs: WELL ANGLE 70° 5978' ACTUATOR= LEO KB.ELEV= 77.30- ( BF.Ei.EV= 48.8' KOP= 700' 1000' H 10-3/4"TAM FORT COLLAR Max Angle= 93°@ 8857' 20"CONDUCTOR, 109' Datum AO= 9253' ' 1 2669' H4-1/2"FES X NP,D=3.813" Datum TVD= 4400'SS GAS LFT MAR�S 10-3/4"CSG,45.5#,L-80 BTC,D=9.950" — 3354' ST MD TVD DEV TYPE VLVNDLATCH FORT DATE I 4 3148 2505 54 KGB-2 DOME BK 16 10/26/10 ji y 3 4824 3510 53 KGB-2 DOLE BK 16 10/26/10 PHOENIX DISCHARGE --f 6180' I-- — 2 5961 4126 69 KGB-2 DRAY BK 0 12/20/08 PRESS GUNGE,,0=3.948" I I � 1 6071 4162 73 KGB-2_ SO BK 18 10/26/101 6192' 4.1/2"BKR CMD-BX SLD SLV,D=3.813" PHOENIX INTAKE PRSSURE —{ 6216' _' CLOS®(07/19112) GAUGE,D=3.994" R 6240' --I7-5/8"X 4-1/2"BKR PREM PKR,D=3.870" Minimum ID = 3.688" ft, 6386' BAKER SEALING LEM I •---I 6308' H4-1/2"FES xMRD=3.813" 7-5/8"RA TAG 633 H7' ' • 6328' H4-1/2"FES X NP,D=3.813" 6356' H4-1/2"GLIDE SHOE w 5.6"NO-GO,D=3.958' 7-5/8"X 5-1/2" BKR ZXP LTP,D=4.950" H 6349' 6368' —I5-1r2"X 4-1/2"XO,D=3.958' 4-1/2'TBG,12.6#,L-80 TCI, —1 6356' .0152 bfp,D=3.958' ■ Oa — -.0 — -U 20 — / \ BAKER HOOK HANGER —I 6386' L2 (Nb) •w/L2 SEALING Lal,u=3.688" -- • MI — — — RI — y ® — / L2(Nb)LEM ONNIDOW 74° 7-5/8"X 5-1/2" BKR ZXP LTP,D=5.75" H 6545' 6391'-6403" OFEWIG WIDTH=3.33" 7-5/8"RA TAG —{ 6547' I---s t� f 6564' H5-1/2"BKR SEAL BORE EXTENSION, =4.75" LEM#2LOWER SEAL ASSY,D=3.880" H 6574' / � D 6583' H5-1/2"X 4-1/2"XO,D=3.958" BAKER HOOK HANGER —I 6601' I-- N. -a —®— — — — — a- — w/LISEALNGLEM,0=3.688" L1 (Nb) i 123 a- — L1 (Nb)LEM WNDOW78° 6606'-6617° BKR TACK EXTENSION D=5.75" —{ 6693' \ °PEW*WITH=3.33" 7-5/8'X 5-1/2" BKR ZXP LIP, —{ 6704' ---....4 6716' --I4-314"BKR SEAL BORE EXT,D=4.75' w/HMG LNR HGR,D=4.820" CI /t 6736' H5-1/2"X 4-1/2'XO,D=3.910" LEN#1 LOWER R SEAL ASSY,D=3.880" —I 6728' 7-5/8'LIR,29.7#,L-80 BTC-M H 7418' I .0459 bpf,D=6.875" — _ PERFORATION SUMMARY ------__________2:2.60 OA REF LOG: • _ ANGLE AT TOP PERF: Note:Refer to Roduction DB for historical perf data SIZE SPF I INTERVAL Opn/Sqz I DATE SEE PAGE 2 FOR LATERAL INFORMATION 4-1/2'SOLD LIR,12.6#,L-80 BT, 8632' I I I I .0152 bpf,D=3.958" DATE REV BY COMMENTS DATE REV BY CDMNEMTS ORION UNIT 12102/05 N9ES INITIAL COMPLETION 02/27/11 _MW/PJC LAR CORRECTION WELL.: L-250 SJ 01/13/09 JKCISV BROKE DISK(12/15/08) 07/17/12 W/JMD SET HEX PLUG(07/15/12) PERMT Nb: 2051520(530)(540) 01/15/09 KDC/SV GLV GO(12/20/08) 07/23/12 CDJMD CONS)HEX(07/23/12 AR Pb: 50-029-23281-00(60)(61) 07/29/09 TW/PJC PERF DATE ACTIONS 07/23/12 G!F/JMJ CLOSE)SLD SIV(07/19/12) SEC 34,T12N,R11E,2563'FSL&3721'FEL 02/10/10 GBR/TLH AR NO.CORRECTIONS 08/29/16 JCF/JMD PULLED HEX PLUG(8/21/16) 11/18/10 BSE/PJC GLV GO(10/26/10) BP Exploration(Alaska) • L-250 S " (L1 & L2) 1 I 1 1 4 II I I SEE TALLY'S FOR MORE DETAIL L2 4"SOLID/SCREEN LNR(11130/05) NM L1 4"SOLID SCREEN LNR(11/14/05) R Z 1 I 1 1 6403'-12635'L2(NB) • 4"SCREB1 LNR, 10.9#&15.2#, L-80 BTM, D=3.476&3.548' K )x OPEN HOLE TD " * ■ ® — - ---. El — —II 124 — 4"SWELL PKR's @ 6443',8158'&9739' 4"RA TAGS @ 6435',8149'&9731" Cgt — — 1 MI — 1 ® — L2 PBTD H 12259' 6618" -11423' 6-3/4"L1 (NB) • 4"SCREEN LNR,10.9#&15.2#, L-80 BT-M, D=3.476&3.548" OREN HOLE TD 11423' PERFORATION SUMMARY ,\ i REF LOG. 4"SWELL PKR @ 6667'&10262" ANGLE AT TOP PERF: 4"RA TAGS @ 6658'&10253 Note:Refer to Production DB for historical pert data — i SIZE SPF ZONE INTERVAL Opn/Sqz DATE 4" SCRN Nb 8262-12175 0 11/30/05 L1 FBTD H 11272' 4" SCRN Nb 6932-11151 0 11/30/05 I 4-1/2" SLID Oa 7524-8460 0 11/30/05 6773' 8632' 6-3/4"Oa 4-1/2'SLID SCREEN LNR,12.6#, L-80 BT,.0152 bpf,D=3.958" Al 8521' J4-1/2"SWE.L PKR,ID=3.813" OPEN HOLE TD 9186' 4-1/2'SOLD LNR,12,6#,L-80 IBT, .0152 bpf,ID=3.958" — 7524' �, 1111 Oa PBTD J— 8630' 4-1/2"SOLD LNR, 12.6#,L-80 IBT,.0152 bpf,D=3.958' 8632' ) DATE REV BY COMM ENTS DATE REV BY CONSENTS ORION UNIT 12/02/05 N9E5 IMTIAL COMPLETION _ 02/27/11 MW/PJC LNR CORRECTION WELL: L-250 01/13/09 JKC/SV BROKE DISK(12/15/08) 07/17/12 SJW/JMD SET I-EX RUG(07/15/12) PERMIT ND. 2051520(530)(540) 01/15/09 KDCISV GLV C/O(12/20/08) 07/23/12 CLYJMD CORRECTED I-EX(07/23/12 AR hb 50-029-23281-00(60)(61) 07/29/09 TW/PJC PERF DATE CORRECTIONS 07/23/12 GJF/JMD CLOSED SLD SLV(07/19/12) SEC 34,T12N,R11 E,2563'FSL&3721'FEL 02/10/10 GBRTLE API NO.CORRECTIONS 08/29/16 JCF/JMD PULLED HEX RUG(8/21/16) 11/18/10 BSE/PJC GLV C/O(10/26/10) BP Exploration(Alaska) r 111 ri � >. - ii o ; i • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aQ ~ - 1 ~ ~ Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria Scanning Preparation BY: Maria Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cov heet) V Scanning is complete at this point unless rescanning is required. Page Count Matches Number in Scanning Preparation: YES _ BY: Maria Date: ~...I ~ ~ D U Stage 1 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: NO /s/ NO "fuumuuuuu ReScanned BY: Maria Date: /s/ Comments about this file: ~.,~,ded iiumiiuiiiiui DIGITAL DATA iskettes, No. ^ Other, No/Type: ~, ae,~a~~~ded iiiuiiiisiiiiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Date: ,~ u mP iuuiuuiuiuu Date: ~, r ~ a O /s/ ~~ x 30 = ~ V + o~~ =TOTAL PAGES (Count does not include cover sheet) Date: ~ I (..~ ~ ~ /s/ o~a ~~ ~a~.aa iiumiuuuiuu ~' 10/6/2005 Well History File Cover Page.doc ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 i;.~',~d~:~U~'~~.~ '`' ~` .~ 'w ~ ~lt~~ • bp ~~~~~~~~ Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, OCT 0 5 2009 f~ias~~ ~ii & Gas Cons. Commi~sio~, Anchorage ~~ ~ -. ~ s~:.. ~-- ~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surtace Casing by Conductor Mnulus Cement, Corrosion inhibitor, Sealant Top-oN Report ot Sundry Operations (10~04) '~~ Date L pad 8N 3/2009 WeN Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor C.OffOSIO11 inhibitod sealant date ft bbis ft na al L-01 2010720 50029230110000 NA 6 NA 612 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2,8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 1-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L•102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 50029230900000 NA 12 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 22 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2~40010 5002923191000~ NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 ~-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-21 B 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6J2812009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 • ~.aa;, ~~~ ~v® DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051520 Well Name/No. PRUDHOE BAY UN GRIN L-250 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23281-00-00 MD 9186 TVD 4464 Completion Date 12/3/2005 REQUIRED INFORMATION Mud Log No Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Surd DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR /RES !DEN ! NEU ! PWD, MWD f GR /RES / Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D Asc Directional Survey 'C~ Directional Survey !~D D Asc Directional Survey ,fir Directional Survey I ~ C Lis 15200 Induction/Resistivity (,6g 15200 Induction/Resistivity ~i,dg 15200 Induction/Resistivity C Lis 15201 Gamma Ray ~Lo g 15201 Gamma Ray / ~ ~, JCog ( 15201 Gamma Ray Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH / CH Received Comments -- - - _ _ 0 - 9186 _ Open 11/21/2005 0 9186 Open 11/21!2005 0 3340 Open 11/21/2005 PB 1 0 3340 Open 11/21/2005 PB 1 54 9187 Open 6/11/2007 LIS Veri, GR, ROP, FET, DRHO w/Graphics TIF 25 Blu 52 9186 Open 6/11/2007 TVD Vision Service 9-Nov- 2005 25 Blu 52 9186 Open 6/11/2007 MD Vision Service 9-Nov- 2005 54 3340 Open 6/11/2007 P61 LIS Veri, GR, ROP, wlGraphics TIF 2 Blu 52 3340 Open 6/11/2007 TVD Power pulse, GR 26- Oct-2005 2 Blu 52 3340 Open 6/11/2007 MD Power pulse, GR 26- Oct-2005 Sample Interval Set Name Start Stop Sent Received Number Comments 0 0 I--_. ~----- - --- -- - -- -- - - - -- -~ DATA SUBMITTAL COMPLIANCE REPORT 2/6/2008 Permit to Drill 2051520 Well Name/No. PRUDHOE BAY UN ORIN L-250 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23281-00-00 MD 9186 TVD 4464 Completion Date 12/3/2005 ADDITIONAL INF ORMATION Well Cored? t_.iN ~ ~ ~,~ ~~ Chips Received? ~~"7 Analysis Y~N Received? Comments: Completion Status 1-OIL Current Status 1-OIL Daily History Received? ~N. Formation Tops ~/ N UIC N Compliance Reviewed By: --__- ----_~~_ __ _ Date: ----s4~.1--~J~' OC!~ U ~~~ .,; Schle~gerger `,~ ~a~h ~~, ~~. ~.(] _ , ~ , _; ~ ~'r~Y~~°~0ra~6C+E~ Schlumberger-DCS , r- ~,.-.~ 2525 Gambell St, Suite 400 ~~°. - - Anchorage,AK 99503-2838 ~ ^~.~"r"'""---~', /~~ ATTN: Beth Well Job # Log Description NO. 4292 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken ~ 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Orion Borealis Date BL Color CD V-218 11661147 MEMORY TEMP SURVEY 05/19107 1 Z-102 11637125 CEMENT IMAGE/BOND LOG 05!16/07 1 V-04 V-214 L-250 40014377 40014206 40012593 OH EDIT MWD/LWD OH EDIT MWD/LWD OH EDIT MWD/LWD 11/28/06 10/30106 11/09105 2 2 2 1 1 1 V-122 40014531 OH EDIT MWD/LWD 12/30/06 2 1 V-122PB1 40014531 OH EDIT MWD/LWD 12/16106 2 1 V-122P82 40014531 40012593 OH EDIT MWD/LWD OH EDIT MWDILWD 12/28107 11/15/05 1 1 1 1 L-250P81 40012593 OH EDIT MWDILWD 10126105 2 1 L-04 40014142 OH EDIT MWD/LWD 10/09106 2 1 OWDW-NW 11477941 RST 11/14/06 1 1 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: gas-rya ~ ~sa~~ ~ lSao~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 06/07/07 C~ by Terrie Hubble Technical Assistant GPB Drilling & Wells March 17, 2006 • Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-23281-00-00 Permit # 205-1.52, PBU L-250 Direct: (907) 564-4628 hubbletl~bp.com To Whom It May Concern.: DECEIVED MAR 2 0 2006 A{aska Oil & Gas Cons. Commission Anchorage Attached please find for your records, the Side Wall Core Analysis for the above mentioned well. This report was not yet complete when I submitted the 10- 407 for this well last month. I had made a note at the bottom of the Completion Report that I would submit the analysis upon receipt. Thank you very much for your assistance in this matter. Sincerely, Terrie Hubble ~~~~ .,, ~~~ :~~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-51 1 1 xc: Well Files PDC Performance Unit • • Oil Viscosity Prediction vs. Depth in the L-250 Well (Orion Field, North Slope, Alaska) Based on Gas Chromatographic Analyses of Sidewall Core Extracts (OT Report No. 05-345) by Mark A. McCaffrey, David K. Baskin and Mark A. Beeunas OilTracers, L.L.C. Prepared for BP Exploration Alaska, Inc. CONFIDENTIAL January 11, 2006 OilTracers, L.L.C 3500 Oak Lawn, Suite 400 Dallas, TX 75219 Telephone: 214-5 84-9169 Fax:214-523-9695 e-mail: info@oiltracers.com oxr~~ • OBJECTIVES r~ This project develops 18 mathematical equations (transforms) that relate oil viscosity to specific Gas chromatography characteristics of oils in the Orion field. These transforms are then used to predict oil viscosity in frozen sidewall cores (5WC) from Well L- 250 from GC analyses of the SWC eztracts. For the U~nu sands, viscosity is predicted at 3 temperatures (95,°F, 85°F, and 75°F); for the Schrader Bluff sands. the viscosity is predicted at 1 temperature: 90°Fl CONCLUSIONS • The predicted viscosities of oil in the SWC from well L-250 are provided in Figure la (OA - Nb sands @ 90°F) and Figure lb-lg (Mc - UGl sands @ 95°F, 85°F, and 75°F). Numerical results are provided in Tables 4a-4d. • Oil in the SWC from the Nc sand (49-105 cSt @ 90 °F) is lower viscosity (Figure la) than oil from either the overlying Nb sand (130-151 cSt @ 90 °F) or the underlying OA sand (159-161 c5t @ 90 °F), Oil in the SWC from the OA sand (159-161 cSt @ 90 °F) is slightly higher viscosity than the oil in SWC from the Nb sand (130-151 cSt @ 90 °F). Oil in the SWC from the OA-Nb sands (49-161 c5t @ 90 °F) is substantially lower viscosity than oil in the overlying Mc-UGl sands (4,645 -12,375 cp @ 95°F). Note that the units in which the OA - Nb sand data are reported (cSt @ 90 °F) are different than the units in which the Mc - UG 1 sand data are reported (cp @ 95°F, 85°F, and 75°F). The difference in units is due to differences in the viscosity data available for the OA-Nb calibration oils vs the M sand calibration oils (Tables 2a-2b). • Oil in BOTH the Mbl sand (10,478-14,191 cp @ 95°F) and the Mc sand (9,436-11,410 cp @ 95°F) is substantially MORE VISCOUS than oil in the Mb2 sand (4,811-9,557 cp @ 95°F), MA sand (5262-5662 cp @ 95°F), and UGl sand (4,655-8522 cp @ 95°F), as shown in Figure lb. In the deeper sands in the Orion field (e.g., O and N sands), the primary control on oil viscosity variations is variability in the relative abundance of a condensate-like secondary oil charge that reduces the viscosity of the primary, biodegraded charge of oil. This conclusion is suggested by the extremely high correlation (Figures 2-4) of Orion oil viscosity with GC parameters that are a ratio of a light-end component (n-octane or n-C8) and a Oil Viscosity in the L-2S0 Well p. 2 OilTracers, LLC • heavy end component of the oil (as measured by the abundance of three azomatic compounds that elute from the GC in the C»-C20 molecular weight range). • In the shallower M sands, the primary control on oil viscosity variations is variability in the extent of biodegradation of the primary oil charge. This conclusion is suggested by the high correlation for three M-sand oils of oil viscosity vs. 5 GC parameters that are ratios of biomazker compounds with differing susceptibilities to biodegradation (Figures 5-19). INTRODUCTION: Both Drozd (1995) and Smalley et al. (1996) have noted that the Schrader Bluffoils in the Milne Point field consist of a mix of biodegraded oil and a subsequently added, non- degraded secondary charge of condensate-like material. Similaz observations have been made on the West yak field to the southeast, where the secondary charge has been interpreted to be a retrograde condensate formed from condensate-rich gas leaking from the underlying Kuparuk accumulation (Masterson, 2001; Masterson, et al., 2001). Drozd (1995) and Smalley et al. (1996) noted that lateral and vertical variations in oil quality (viscosity, gravity) in the Milne Point field are controlled by two phenomena: (1) Lateral and vertical variations in the extent of oil biodegradation (a process that increases oil viscosity and decreases oil gravity), and (2) Lateral and vertical variations in the relative abundance of the secondary, condensate- like charge, a material that reduces the oil viscosity and raises the oil gravity. At Milne Point, the abundance of the secondary charge varies from 0-20 wt. % (Smalley et al., 1996). McCaffrey and Beeunas (2004) noted a similar two-stage chazge history for Orion field oils and developed transforms that relate viscosity to the relative abundance of the secondary condensate-like charge that forms the light tends of many Orion oils. Prediction of Oil Viscosity from SWC Material The reason that fluid properties of oil in SWC material must be predicted geochemically and cannot be measured directly is that: • Under most circumstances, insufficient oil can be centrifuged from either conventional core or sidewall cores to allow physical properties to be directly measured. • Evaporative loss oflow-molecular-weight hydrocarbons from SWC during handling and centrifugation would raise the appazent viscosity and lower the apparent gravity of oil centrifuged from the core.. • Using solvent (in place of centrifugation) to extract oil from SWC will cause the extract to be of no use for direct gravity and viscosity measurements, since it is Oil Viscosity in the L-2S0 Well p. 3 OilTracers, LLC • • not possible to remove all the solvent from the extract without also losing much of the light ends of the oil. Therefore, oil properties must be inferred by using one or more transforms to convert a geochemical analysis of a core extract into a calculated gravity and/or viscosity value. ANALYTICAL METHODS 42 SWC (Table 1) from the L-250 well were rigorously preserved following collection by: i. Immediately wrapping the SWC in tin foil after collection, and then placing them in sample bottles. ii. Immediately sealing the bottles with Teflon tape. iii. Immediately freezing the bottles, shipping them frozen, and then storing them in the lab frozen. The solvent extracts of the SWC were analyzed by Gas Chromatography (GC) at Baseline Resolution (Shenandoah, Texas) using a Hewlett Packard GC equipped with a 60 m DB-1 column (J&W Scientific); the injector was at 275°C, and the heating program was: 35°C (hold 5 minutes), 3°/min ramp to 320°C (hold for 20 minutes). The carrier gas was hydrogen. Solvent extracts of the core plugs were NOT blown to dryness, but rather were injected into the GC in solvent (carbon disulfide) to minimize the loss of light ends. RESULTS AND DISCUSSION One page plots of the GC traces of the SWC are reproduced in Appendix 1. One page plots of the GC traces of various produced oils reproduced in Appendix 2. The measured viscosities of a subset of the oils are listed in Tables 2a and 2b. In the deeper sands in the Orion field (e.g., O and N sands), the primary control on oil viscosity variations is variability in the relative abundance of a condensate-like secondary oil charge that reduces the viscosity of the primary, biodegraded charge of oil. This conclusion is suggested by the extremely high correlation (Figures 2-4) of Orion oil viscosity with GC parameters that are a ratio of a light-end component (n- octane or n-C$) and a heavy end component of the oil (as measured by the abundance of three aromatic compounds that elute from the GC in the Cl~-CZO molecular weight range). These transforms are only applicable to the O and N-sand oils, since the shallower oils (M-sand) due not contain a secondary charge) In the shallower M sands, the primary control on oil viscosity variations is variability in the extent of biodegradation of the primary oil charge. This conclusion is suggested by the high correlation for three M-sand oils of oil viscosity vs. 5 GC parameters that are ratios of biomarker compounds with differing susceptibilities to biodegradation (Figures 5-19). Oil Viscosity in the L-250 Well p. 4 OilTracers, LLC .f • • The predicted viscosities of oil in the SWC from well L-250 are provided in Figure la (OA - Nb sands @ 90°F) and Figure lb-lg (Mc - UGl sands @ 95,°F, 85°F, and 75°F). Numerical results are provided in Tables 4a-d. Oil in the SWC from the Nc sand (49-105 cSt @ 90 °F) is lower viscosity (Figure la) than oil from either the overlying Nb sand (130-151 cSt @ 90 °F) or the underlying OA sand (159-161 cSt @ 90 °F). Oil in the SWC from the OA sand (159-161 cSt @ 90 °F) is slightly higher viscosity than the oil in SWC from the Nb sand (130-151 cSt @ 90 °F). Oil in the SWC from the OA-Nb sands (49-161 cSt @ 90 °F) is substantially lower viscosity than oil in the overlying Mc-UGl sands (4,645 -12,375 cp @ 95°F). Note that the units in which the OA - Nb sand data are reported (cSt @ 90 °F) are different than the units in which the Mc - UG1 sand data are reported (cp @ 95,°F, 85°F, and 75°F). The difference in units is due to differences in the viscosity data available for the OA-Nb calibration oils vs the M sand calibration oils (Tables 2a-2b). Oil in BOTH the Mbl sand (10,478-14,191 cp @ 95°F) and the Mc sand (9,436- 11,410 cp @ 95°F) is substantially MORE VISCOUS than oil in the Mb2 sand (4,811-9,557 cp @ 95°F), MA sand (5262-5662 cp @ 95°F), and UGl sand (4,655- 8522 cp @ 95°F), as shown in Figure lb. Oil Viscosity in the L-250 Well p. S OilTracers, LLC • • REFERENCES D. K. Baskin and M. A. McCaffrey (2003) Geochemical Evaluation of Core Extracts from Well V-111 PB1: Implications for Oit Quality Variations and Vertical Reservoir Continuity; OilTracers Report No. 03- 142, September 14, 2003. Drozd, R. J. (1995) Preliminary geochemical assessment of sixteen Schrader Bluff oil, 1995 Sampling Program. Westport Technology Center International Report # WTCI-95-154 (September, 1995). Masterson, W. D., 2001, Petroleum Filling History of Central Alaskan North Slope Fields: Ph.D. thesis, University of Texas at Dallas, Dallas (May 2001), 159 p. Masterson, W. D., L. I. P. Dzou, A. G. Holba, A. L. Fincannon, and L. Ellis, 2001, Evidence for biodegradation and evaporative fractionation in West Sak, Kuparuk, and Prudhoe Bay field azeas, North Slope, Alaska: Organic Geochemistry, v. 32, p. 411-441. McCaffrey M. A. (2003) Geochemical Chazacterization of Oil from S-33i Sidewall Cores, Milne Point Field, North Slope Alaska (OT Report No. 03-103, March 21, 2003). McCaffrey M. A. and M. A. Beeunas (2004) New Tools for Oil Viscosity Prediction in the Orion Field, North Slope, Alaska: Viscosity Transforms Based on Gas Chromatographic Analyses of Core Extracts (OT Report No. 04-171, February 25, 2004). Smalley, P. C., N. S. Goodwin, J. F. Dillon, C. R. Bidinger, and R. J. Drozd, 1996, New Tools Tazget Oil Quality Sweetspots in Viscous Oil Accumulations: Society of Peroleum Engineers, Paper # 36652, p. 911- 917. Oit Viscosity in the L-250 Well p. 6 OilTracers, LLC STATE OF ALASKA ALAS IL AND GAS CONSERVATION CO SIGN WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED FEB 0 8.2000 Alaska Oil & Gas Cons. Conurtission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.ios 20AAC25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/3/2005 12. Permit to Drill Number 205-152 3. Address: P.O.Box196612,Anchorage,Alaska 99519-6612 6. Date Spudded 10/24/2005 13. API Number 50-029-23281-00-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/9/2005 14. Well Name and Number: PBU L-250 2563 FSL, 3721 FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 1897' FSL, 2277' FEL, SEC. 27, T12N, R11 E, UM 8, KB Elevation (tt): 77.3' 15. Field /Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 3958' FSL, 2442' FEL, SEC. 27, T12N, R11 E, UM 9. Plug Back Depth (MD+TVD) 9186 + 4464 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583195 y- 5978286 Zone- ASP4 10. Total Depth (MD+TVD) 9186 + 4464 Ft 16. Property Designation: ADL 028239 TPI: x- 584577 y- 5982914 Zone- ASP4 Total Depth: x- 584385 Y- 5984973 Zone- ASP4 11 • Depth where SSSV set None 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: MWD / GR, MWD / GR /RES /DEN /NEU /PWD, MWD / GR /RES / Azimuthal DEN /NEU /AIM /PWD 2. ASING, INER AND EMENTING ECORD CASINO ETTII~ EPTH MD ETTINO EPTH TVD HOLE OUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE CEMENTINf3 RECORD PULLED 20"x34" 215.5# A-53 Surface 108' Surface 108' 48" 60 sx Arctic Set A rox. 10-3/4" 45.5# L-80 29' 3354' 29' 2626' 13-1 /2" s sx As Lne, as2 ax ~G~, 17s ax As Lice 7-5/8" 29.7# L-80 26' 7418' 26' 4430' 9-7/8" 36 sx Class 'G' 4-1/2" 12.6# L-80 6693" 8632' 4319' 4439' 6-3/4" Uncemented Slotted Liner 4-1/2" .12.6# L-80 6545' 6728' 4286' 4327' N/A LEM Tieback No Cement 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TusIN~ RECORD BOttOm Interval, Size and Number; if none, State none ): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1/2", 12.6#, L-80 6356' 6240' MD TVD MD TVD 7524' - 8460' 4430' - 4429' Q5. ACID, FRACTURE,<CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Bi KIND OF MATERIAL USED Freeze Protect w/ 110 Bbls of Diesel 26. PRODUCTION TEST Date First Production: January 5, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 213!2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 27 GAS-MCF 149 WATER-BBL -0- CHOKE SIZE 176 GAS-OIL RATIO 5,552 Flow Tubing Press. 34 Casing Pressure 1,040 CALCUUTED 24-HOUR RATE OIL-BBL 160 GAS-MCF 891 WATER-BBL -0- ~ t GBAVIT.Y-API (CORK) !'•'`" 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or w tert( se arate sheet, if necessary). Submit core chips; if none, state "none". }: Sidewall Cores were taken from the main wellbore (L-250). The only analysis being done is geochemical. This analysis is in progress, final data not yet available. The geologist, Greg Bernaski, expects it to be completed by the end of the month. I.yvill submit this data when it is ompleted. Form 10-407 Revised 12/2003 ® ~ ^ ~ ~O~y71~ED ON REVERSE SIDE ~ ~w~'~ wr ~ + Lv ~, z c vvv 28. GEOLOGIC MARKE 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary.. If no tests were conducted, state "None". Ugnu 3700' 2826' None Ugnu MA 5651' 3992' Ugnu MB1 5735' 4033' Ugnu MB2 5890' 4100' Ugnu MC 6138' 4180' Schrader Bluff NA 6348' 4232' Schrader Bluff NB 6445' 4259' Schrader Bluff NC 6567' 4292' Schrader Bluff NE 6614' 4303' Schrader Bluff NF 6866' 4356' Schrader Bluff OA 7110' 4398' Schrader Bluff OA 8777' 4442' Schrader Bluff OA 9125' 4452' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the f re oing is true and correct to the best of my knowledge. o Signed t D T h A i ~ Titl i a e e n ss stant ec cal Terrie Hubble' 1 PBU L-250 205-152 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal NO. Drilling Engineer: Michael Triolo, 564-5774 INSTRUCTIONS GENeaa~: This form is designed for submitting a complete and correct well completion report and log on ail types of lands and leases in Alaska. ITEM 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. ITEM 4b: TPI (Top of Producing Interval). ITEM 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. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 12/5/2005 11:10:39 AM BP EXPLORATION Page 1 of 22 Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Spud Date: 10/24/2005 Event Name: DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: ~, Date '; From - To Hours Task Code NPT Phase Description of Operations 10/23/2005 06:00 - 09:00 3.00 MOB P PRE Move rig, well to well, around well row to L-250 09:00 - 12:00 3.00 MOB P PRE Spot sub base over L-250, lay mats & herculite for mud pits. 12:00 - 13:00 1.00 MOB P PRE Spot mud pits. 'Rig accepted for L-250 operations C~? 13:00 hr 10/23/2005 13:00 - 17:00 4.00 RIGU P PRE Change out 16" riser nipple to 20" adapter. NU surface diverter system and riser. 17:00 - 18:00 1.00 RIGU P PRE Prepare rig floor for picking up drill pipe. 18:00 - 23:00 5.00 RIGU P PRE Pick up 105 jts 4" HT-40 drill pipe and rack in derrick. Pick up 24 jts. 4" HT-40 HWDP and rack in derrick. 23:00 - 00:00 1.00 RIGU P PRE Pick up BHA #1 jewelry from beaver slide. 10/24/2005 00:00 - 00:30 0.50 RIGU P PRE Perform diverter function test. `Witnessing of test waived by AOGCC rep. John Crisp' 00:30 - 03:00 2.50 RIGU P PRE Pick up, make up, 13 1/2" directional drilling assembly. 03:00 - 03:30 0.50 RIGU P PRE Fill hole, check for leaks. 03:30 - 07:00 3.50 DRILL P SURF Spud in L-250 C~ 03:30 hr 10/24/2005. Directionally drill 13 1/2" surface hole from 108' to 280'. 550 gpm, 700 psi on bottom, 425 psi off bottom, 5k WOB, 40 rpm, 1.5k torque, PU - 55k, SO - 53k, ROT - 54k. 07:00 - 12:00 5.00 DRILL N MISC SURF Flowline plugged off. POH to surface. Found chunks of conductor cement in flowline. Clear flowline and RIH to 280'. 12:00 - 12:30 0.50 DRILL P SURF Directionally drill 13 1/2" surface hole from 280' to 360'. 700 gpm, 1200 psi off bottom, 1320 psi on bottom, 60 rpm, 3k torque, 25k WOB. 12:30 - 13:00 0.50 DRILL P SURF POH from 360' to 171'. Pick up jar stand and RIH. 10' fill. 13:00 - 00:00 11.00 DRILL P SURF Directionally drill 13 1/2" surface hole from 360' to 1,191'. 700 gpm, 2,000 psi off bottom, 2,170 psi on bottom, 60 rpm, 2k torque off bottom, 5k torque on bottom, 25k WOB. PU - 79k, SO - 71 k, ROT - 73k. AST - 5.08 hrs, ART - 5.72 hrs 10/25/2005 00:00 - 07:00 7.00 DRILL P SURF Directionally drill 13 1/2" surface hole from 1,191' to 1,656'. 700 gpm, 2,350 psi off bottom, 2,500 psi on bottom, 60 rpm, 3k torque off bottom, 5k torque on bottom, 35k WOB. PU - 82k, SO - 71 k, ROT - 74k, AST - 4.3, ART - 2.34. 07:00 - 08:00 1.00 DRILL P SURF Circulate 2X bottoms up. 08:00 - 10:00 2.00 DRILL P SURF RU and RIH with Gyrodate gyro and survey every 100' to 1,500'. RD Gyrodata. 10:00 - 13:30 3.50 DRILL P SURF Monitor well -stable. POH from 1,656'. PU - 90K, SO - 60K. Work through tight spots from 1,052' to 973' and at 790', 580', 525', 425' using pumps as needed. Stand back BHA components and break out the 13-1/2" bit. 13-1/2" MXC-1 graded: 3/5/W T/A/E/1 /RG/B HA. 13:30 - 14:00 0.50 DRILL P SURF MU new 13-1/2" MXC-1, adjust motor bend to 1.5 degrees, orient with MWD and RIH with BHA#2 to 78'. 14:00 - 14:30 0.50 DRILL P SURF Lubricate rig, top drive and crown. 14:30 - 17:00 2.50 DRILL P SURF RIH to 109'. Break connection between the first and second collar and install a stabilizer. RIH. Hit obstruction and pump down from 720' to 1,100' - 700 gpm, 2,050 psi. RIH without pumps from 1,100' to 1,566. Precautionary wash and ream the last stand down to 1,656'. 17:00 - 21:00 4.00 DRILL P SURF Drill ahead directionally from 1,656' to 2,126' - PU - 95K, SO - 67K, ROT - 78K, 80 rpm, TQ on - 5k, TO off - 3k, 2,900 psi on, 2,730 psi off. Encountered hydrates at -1,900' MD. 21:00 - 22:00 1.00 DRILL P SURF POH 1 stand. Hydrates breaking out in the pits caused the Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Event Name: DRILL+COMPLETE Start: 10/23/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To ' Hours Task Code NPT Phase 10/25/2005 21:00 - 22:00 1.00 DRILL P SURF 22:00 - 00:00 2.00 DRILL P SURF 10/26/2005 00:00 - 06:30 6.50 DRILL P SURF 06:30 - 08:00 1.50 DRILL P SURF 08:00 - 11:00 3.00 DRILL P SURF 11:00 - 12:00 I 1.001 DRILL I N I STUC I SURF 12:00 - 19:30 I 7.501 FISH I N I STUC I SURF 19:30 - 21:00 I 1.501 FISH I N I STUC I SURF 21:00 - 00:00 I 3.00 l FISH I N I STUC I SURF 10/27/2005 ~ 00:00 - 02:00 2.00 (EVAL ~ N ~ STUC ~ SURF 02:00 - 06:00 4.00 ~ FISH ~ N ~ STUC ~ SURF 06:00 - 08:00 I 2.001 FISH I N I STUC I SURF 08:00 - 10:00 I 2.001 FISH I N I STUC I SURF 10:00 - 12:00 2.00 ~ FISH ~ N ~ STUC ~ SURF 12:00 - 13:30 1.50 FISH N WAIT SURF 13:30 - 15:00 1.50 FISH N STUC SURF Page 2 of 22 Spud Date: 10/24/2005 End: 12/3/2005 Description of Operations mud pump, desilter pump and mix pump to lock up. Work to get the equipment back to working efficiently. Circulate to ensure proper operation of surface equipment. Drill ahead directionally from 2,126' to 2,312' - PU - 95K, SO - 67K, ROT - 78K, 80 rpm, TO on - 5k, TO off - 3k, 2,900 psi on, 2,730 psi off. From noon to midnight: AST - 1.1, ART - 2.45. Drill ahead directionally from 2,312' to 3,340' (TD) - PU - 103K, SO - 70K, ROT - 84K, 80 rpm, TO on - 9k, TO off - 5k, 3,180 psi on, 2,830 psi off, AST - 1.65, ART - 3.66. Circulate 3X bottoms up - 680 gpm, 3,320 psi, 100 rpm. Monitor the well - stab{e. POH from 3,340' - PU - 112K, SO - 72K. Encountered 40K overpull at 1,872'. Work pipe without pumps to get past - no go. Pump out from 1,872' to 1,800' - 330 gpm, 700 psi. POH without pumps from 1,800' to 1,675'. Encountered 40K overpull. Attempt to work by without pumps - no go. Pump out of the hole from 1,675' to 1,657' -hole pulling tight, 40K overpull. Attempt to move the pipe down - no go. Torque up on the pipe and attempt to move the pipe down with pumps, 200 gpm, 790 psi - no go. Attempt to jar down without success. Starting to pump mud away. Lost 70 bbls for the tower. Commence jarring operations. Jar up with 240K and SO to 40K - no success. Pump occasionally to check for returns - lost 20 bbls during the tower. Inspect the derrick after jarring operations -good. Changeout to long bails. PJSM with Schlumberger E-line. RU rig floor to run Free Point Locator Tool. Run SLB Free Point Locator Tool. Drilllstring appears to be free across the NMDC below the 9-7/8" Stab. POH. LD FPT. String Shot #1: MU 240 grain string shot and RIH. Apply 1-1/4 turns to the left in the pipe while making up the string shot and lock in place. Fire string shot across connection at 1,548' - between 9-7/8" Stab and NMDC below the 9-7/8" stab -did not release. POH with E-line for another string shot. String Shot #2: MU 480 grain string shot and RIH. Apply 1-1/4 turns to the left in the pipe and lock in place. Fire string shot across connection at 1,548' -between 9-7/8" Stab and NMDC below the 9-7/8" stab -did not release. POH with E-line for another string shot. String Shot #3: MU 480 grain string shot and RIH. Position string shot across connection at 1,512' -between the NMDC's above the 9-7/8" stab. Apply 1-1/4 turns to the left in the pipe - string broke blind prior to firing string shot. POH and LD string shot #3. Engage the top drive and retorque drill string. String Shot #3: MU 480 grain string shot and RIH. Apply 1-1/4 turns to the left in the pipe and lock in place. Fire string shot across connection at 1,512' -between the NMDC's above the 9-7/8" stab -did not release. POH with E-line for another string shot. Wait on more primer cord to be brought out for string shots. String Shot #4: MU 560 grain string shot and RIH. Apply 1-1/4 turns to the left in the pipe and lock in place. Fire string shot Printed: 12/5!2005 11:10:45 AM BP EXPLORATION Page 3 of 22 Operations Summary Report Legal Well Name: L-250 Common W ell Name: L-250 Spud Date: 10/24/2005 Event Nam e: DRILL+C OMPLE TE Start : 10/23/2005 End: 12/3/2005 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/3/2005 Rig Name: NABOB S 9ES .Rig Number: Date ' From - To Hours '~ Task Code NPT Phase Description of Operations 10/27/2005 13:30 - 15:00 1.50 FISH N STUC SURF across connection at 1,512' -between the NMDC's above the 9-7/8" stab -did not release. POH with E-line for another string shot. 15:00 - 16:00 1.00 FISH N STUC SURF String Shot #5: MU 560 grain string shot and RIH. Apply 1-1/4 turns to the left in the pipe and lock in place. Fire string shot across saver sub at 1,479' -string backed off. POH with E-line. Rotate 5 turns to the left to finish backing out the connection - PU - 90K. 16:00 - 17:00 1.00 FISH N STUC SURF Circulate bottoms up at 1,451' - 715 gpm, 1,600 psi. 17:00 - 18:30 1.50 FISH N STUC SURF POH with 1 stand breaking each connection and re-doping to 1,389'. RD Schlumberger E-line. Change out to short bails. 18:30 - 22:00 3.50 FISH N STUC SURF POH from 1,389' breaking each connection and re-doping - recovered drill string down to the jar stand. BHA#2 remains in the ground from the saver sub to the bit. 22:00 - 23:00 1.00 FISH N STUC SURF PU fishing tools to the rig floor. 23:00 - 00:00 1.00 FISH N STUC SURF RU the rig floor and top drive to PU Fishing BHA. 10/28/2005 00:00 - 03:30 3.50 FISH N STUC SURF PU Fishing BHA components and RIH. Fishing BHA: cut lip guide shoe, drive sub, xo, 2 x bumper sub, jars, xo, 6 x 8" collars, xo, accelerator jar, xo, 9 x 6-3/4" collars. 03:30 - 08:30 5.00 FISH N STUC SURF RIH with Fishing BHA while PU 5" DP. Ran into tight spot at 1,051'. Wash and ream down to 1,082' - 540 gpm, 500 psi, 45 rpm, TO - 3K. 08:30 - 12:00 3.50 FISH N STUC SURF POH from 1,108' to 985'. Hole pulling tight. Run back in the hole to 1,108' and ream out to 980' - 220 gpm, 30 rpm, PU - 95K, SO - 88K. POH from 980' standing back DP and collars. LD Fishing BHA. 12:00 - 16:30 4.50 FISH N STUC SURF MU Cleanout BHA and RIH on 5" DP. Cleanout BHA: used 13-1/2" MXC-1, near bit stab, xo, bumper sub, jar, xo, 6 x 8" DC's, xo, 9 x 6-3/4" DC's. Started to take weight at 991'. Ream down to 1,147' - PU - 90K, SO - 80K, ROT - 87K, 60 rpm, 700 gpm, 1,150 psi -suspect open hole sidetrack of the well. 16:30 - 17:30 1.00 FISH N STUC SURF Circulate bottoms up at 700 gpm, 1,150 psi. 17:30 - 21:00 3.50 FISH N STUC SURF POH standing back 5" DP and LD Cleanout BHA. 21:00 - 22:00 1.00 FISH N STUC SURF Clear and clean the floor. 22:00 - 23:00 1.00 STKOH N STUC SURF Change out the quill, service the top drive and crown. 23:00 - 23:30 0.50 STKOH N STUC SURF Arrange DP in the derrick. 23:30 - 00:00 0.50 STKOH N STUC SURF PU 5" DP and stand back in the derrick. 10/29/2005 00:00 - 02:30 2.50 STKOH N STUC SURF PU 5" DP and stand back in the derrick. 02:30 - 05:30 3.00 STKOH N STUC SURF MU BHA#5 and RIH. BHA#5: 13.5" MXC-1, 9.5" motor 4.5 stg 3R/4S 1.5 degree, nm lead collar, 12.25" nm stab, MWD, 12.25" nm stab, nm xo, nm dc, nm stab, 2 x nm dc's, saver sub, 1 x hwdp, jar, 16 x hwdp. 05:30 - 06:00 0.50 STKOH N STUC SURF RIH with BHA#5 on 5" DP from 730' to 1,147'. 06:00 - 07:00 1.00 STKOH N STUC SURF Circulate and condition the mud - 300 gpm, 475 psi. 07:00 - 18:30 11.50 STKOH N STUC SURF Drill 13.5" directionally as an open hole sidetrack from 1,147' to 3,364'(TD). PU - 115K, SO - 81 K, ROT - 95K, 80 rpm, 700 gpm, 2,300 psi on, 1,950 psi off, 9K TO on, 5K TQ off, AST - 3.68, ART - 4.03. Observed hydrates from 1,800' to TD. 18:30 - 20:30 2.00 STKOH N STUC SURF Circulate 3 x bottoms up - 100 rpm, 700 gpm, 1,850 psi, 5.5K TO. 20:30 - 21:45 1.25 STKOH N STUC SURF POH standing back 5" DP from 3,364' to 1,770' - MW in - 9.5 ppg, MW out - 9.6 ppg. Hole starting to swab. Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Page 4 of 22 Legal Well Name: L-250 Common Well Name: L-250 Spud Date: 10/24/2005 Event Name: DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: Date I! From - To Hours Task Code' NPT Phase Description of Operations 10/29/2005 121:45 - 22:00 ~-- - - '' - - - - 0.25 STKOH N STUC ~ SURF Pump out of the hole from 1,770' to 1,657 due to hole trying to 22:00 - 00:00 2.00 STKOH ~ P 10/30/2005 100:00 - 01:30 I 1.501 STKOH I P 01:30 - 02:00 I 0.501 STKOH I P 01:00 - 02:00 I 1.001 STKOH I P 02:00 - 03:15 1.25 STKOH P 03:15 - 06:30 3.25 STKOH P 06:30 - 08:00 1.50 STKOH P 08:00 - 08:30 0.50 STKOH P 08:30 - 10:00 1.50 STKOH P 10:00 - 12:00 2.00 CASE P 12:00 - 15:00 ~ 3.00 ~ CASE ~ P 15:00 - 00:00 I 9.001 CASE I P 10/31/2005 100:00 - 10:00 I 10.001 CASE I P 10:00 - 10:30 I 0.501 CASE I P 10:30 - 11:00 0.50 CASE P 11:00 - 13:00 2.00 CASE P 13:00 - 16:15 I 3.251 CEMT I P swab - 700 gpm, 1,550 psi. SURF Pump out of the hole from 1,657' to 730' due to hole trying to swab - 700 gpm, 1,550 psi. SURF RIH from 730' to 3,364'. Precautionary wash and ream the last stand to bottom. Worked pipe with pumps on at 975' and from 1,100' to 1,150' - 575 gpm, 1,000 psi. Worked pipe without pumps from 1,540' - 1,610', 1,740' - 1,760' and 1,800' - 1,810'. SURF Circulate and condition the hole - 700 gpm, 1,800 psi, 80 rpm, 6k TO. SURF Set clocks back one hour due to daylight savings time. Continue to circulate and condition the hole - 700 gpm, 1,800 psi, 80 rpm, 6k TO. SURF POH standing back 5" DP from 3,364' to 1,840'. SURF Hole started to pull -40K over and swab. Backream out of the hole from 1,840' to 730' - 700 gpm, 1,500 psi, 80 rpm, 4k TO. SURF LD BHA#5. 13-1/2" MXC-1 graded: 2/1/WT/M/E/I/NO/TD SURF Clean and clear the floor. SURF Change out the top drive saver sub to HT-40. SURF Change over to long bails and RU the fill-up tool, RU casing handling equipment and make a dummy run with hanger - good. SURF PJSM. PU 10-3/4" float equipment, Bakerloc connections and RIH. Check floats -holding. PU 10-3/4" 45.5# L-80 BTC casing and RIH to 1,330' -hit obstruction. SURF Hit obstruction at 1,330'. Attempt to work past obstruction without pumps -unsuccessful. Work pipe with pumps on to 1,393' - 425 gpm, 600 psi, PU - 100K, SO - 82K. SURF Continue to work pipe from 1,393' to 1,506' - 425 gpm, 600 psi. RIH without pumps from 1,506' to 1,676'. Work pipe from 1,676' to 3,354' - 336 gpm, 343 psi. SURF Circulate and condition the mud through the fillup tool - 420 gpm, 560 psi. Reciprocated while circulating, PU - 195K, SO - 100K. SURF RD the fillup tool and RU the cement head. SURF Circulate and condition the mud. - 460 gpm, 780 psi. Reciprocated while circulating, PU - 195K, SO - 100K. SURF Hold PJSM. Line up to Schlumberger and pump 5 bbls of water ahead. Shut down and pressure test the lines to 3,500 psi. Bleed off pressure. Attempt to reciprocate - unsuccessfu{. Land casing on the ring. Pump 20 bbls of CW100. Shut down and batch up 10.1 ppg Mudpush II spacer. Pump 70 bbls of spacer at 7 bpm, ICP - 330 psi, FCP - 350 psi. Shut down, drop bottom plug and batch 10.7 ppg ArcticSet Lite lead slurry. Pump 551 bbls of lead cement at 8.4 bpm, ICP - 500 psi, FCP - 640 psi. Batch up 15:8 ppg Class G tail slurry. Pump 99.5 bbls of tail slurry at 5 bpm, ICP - 660 psi, FCP - 740 psi. Shut down, drop top plug and displace with 10 bbls of fresh water. Shut down and swap lines from Schlumberger to the rig. Displace with mud using the rig at 12 bpm, ICP - 900 psi. Dropped rate to 4 bpm and bumped the plug to 2,000 psi with 305 bbls pumped and 97% efficiency. Check floats -holding. Had full returns throughout the cement job. NO CEMENT TO Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Event Name: DRILL+COMPLETE Start: 10/23/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: Date ,~ From - To ~ Hours Task ~ Code ~ NPT ~ Phase ~__ 10/31/2005 13:00 - 16:15 3.25 CEMT P SURF 16:15 - 18:00 1.75 CASE P SURF 18:00 - 21:00 3.00 CEMT P SURF 21:00 - 00:00 I 3.001 CEMT I P I I SURF 11/1/2005 100:00 - 00:30 I 0.501 CEMT I P I I SURF 00:30 - 02:30 I 2.001 CEMT I P I I SURF 02:30 - 03:00 0.50 CEMT P SURF 03:00 - 04:00 1.00 CEMT P SURF 04:00 - 05:00 1.00 CEMT P SURF 05:00 - 07:30 2.50 CASE P SURF 07:30 - 08:30 1.00 CASE P SURF 08:30 - 11:00 2.50 BOPSU P SURF 11:00 - 12:00 1.00 WHSUR P SURF 12:00 - 17:00 5.00 BOPSU P SURF 17:00 - 17:30 0.50 BOPSU P SURF 17:30 - 20:30 3.00 BOPSU P SURF 20:30 - 21:00 I 0.501 BOPSUFI P I I SURF 21:00 - 22:00 1.00 DRILL P SURF 22:00 - 00:00 2.00 DRILL P SURF 11/2/2005 00:00 - 01:00 1.00 DRILL P SURF Page 5 of 22 Spud Date: 10/24/2005 End: 12/3/2005 Description of Operations SURFACE. CIP C~3 1548 10/31/2005. RD casing handling equipment, changeout to short bails and changeout the quill on the top drive. MU TAM port collar shifting tool and RIH to 1,000' on 5" DP. Activate the sliding sleeve and expose the circulation ports. Circulate and condition the mud - 9 bpm, 155 psi. Wait for materials for 2nd stage cement job. No cement circulated to surface while circulating through the port collar. Hold PJSM. Line up to Schlumberger and pump 5 bbls of water ahead. Shut down and pressure test the lines to 3,500 psi. Bleed off pressure. Pump 15 bbls of fresh water. Shut down and batch 10.7 ppg ArcticSet Lite slurry. Pump 140 bbls of lead cement at 7 bpm, ICP - 220 psi, FCP - 333 psi. Drop rate to 4 bpm after 96 bbls pumped due to thick, contaminated mud returning to surface, ICP - 140, FCP - 150. Chase the cement with 5 bbls of fresh water to clear the cementing lines. Shut down and swap lines from Schlumberger to the rig. Displace with 15 bbls of mud using the rig at 7 bpm, FCP - 400 psi. Had full returns throughout the cement job. 25 bbls of cement returned to surface. CIP @ 0030 11/1/2005. PU and close the TAM port collar. Verify closure with 1,000 psi pressure test while running tool still across port collar. Apply 3/4 turn to the right and PU out of the collar. Pressure up and shear the burst disc at 2,400 psi. Observe pressure drop off. Attempt to circulate -unsuccessful -observe pressure increase to 3,100 psi. POH wet standing back 5" DP. LD TAM port collar running tool. Tool appeared to be plugged below the circulation ports. MU mule shoe and RIH with 5" DP to 1,030'. Circulate the 5" DP and the casing clean - 650 gpm, 150 psi. LD 5" DP from 1,030'. MU 10-3/4" casing pup to the split landing joint. Attempt to breakout the landing joint with chain tongs -unsuccessful. RU casing tongs and attempt to breakout landing joint - unsuccessful. RD casing tongs and RU rig tongs. Breakout and LD the landing joint. Clean underneath the rotary table and drain surface lines. ND riser and changeout 20" riser nipple to 16". ND diverter system and secure in the cellar. Bring wellhead equipment into the cellar area. Install speed head and tubing spool. Test to 1,000 psi -good. Install secondary annulus valves. NU BOP stack and riser. Flush stack. RU BOP testing equipment. Test ROPE and related equipment to 250 psi low and 3,500 psi high. No failures during the test. Test was witnessed by Jeff Jones of the AOGCC, Nabors Rig Supervisor Roy Hunt and BP Wellsite Leader James Franks. Blow down all surface lines and RD testing equipment. Install wear ring. RIH with 5" DP and HW DP from the derrick. LD 5" DP and HWDP. Continue to LD 5" DP. Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Page 6 of 22 Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To Hours ~ Task Code NPT ~ ~ ~ 11/2/2005 01:00 - 02:00 1.00 DRILL P 02:00 - 02:30 0.50 DRILL P 02:30 - 09:00 6.50 DRILL P 09:00 - 10:00 1.00 DRILL P INT1 10:00 - 13:00 3.00 DRILL P INTi Spud Date: 10/24/2005 Start: 10/23/2005 End: 12/3/2005 I Rig Release: 12/3/2005 Rig Number: Phase Description of Operations INT1 PU 4" DP and RIH. INTi Stand back 4" DP in the derrick. INT1 PJSM. MU BHA#6. Orient the MWD. Hold PJSM prior to loading nuclear source. RIH with BHA and rotate at 8 rpm to get past the TAM port collar at 1,000'. RIH to 1,095'. Flow test the MWD @ 600 spm, 1,032 psi -good. Test the 10-3/4" casing to 1,000 psi to verify the port collar is closed. 13:00 - 14:00 I 1.001 CASE I P I I SURF 14:00 - 14:30 0.501 DRILL P INT1 14:30 - 15:30 1.00 DRILL P INT1 15:30 - 16:00 0.50 DRILL P INT1 16:00 - 00:00 I 8.001 DRILL I P I I INT1 11/3/2005 100:00 - 12:00 12.00 DRILL P INT1 12:00 - 00:00 I 12.001 DRILL I P I I INT1 11/4/2005 100:00 - 05:00 I 5.001 DRILL I P I I INTi 05:00 - 05:30 0.50 DRILL P INT1 05:30 - 06:00 0.50 DRILL P I INTi 06:00 - 15:00 ( 9.00 DRILL P I INT1 15:00 - 19:00 I 4.001 DRILL I P I I INT1 19:00 - 19:30 I 0.501 DRILL P I INTi 19:30 - 21:00 1.50 DRILL P INT1 21:00 - 00:00 3.00 DRILL P INT1 BHA #6: 9-7/8" Hycalog DSX199GUW, 8-1l4" motor 4R/5S 5.3 stg 1.5 degree, xo nm stab, ARC, MWD, ADN, nmdc, LWD (Sperry MIRL), 1 x 5" HWDP, jar, 1 x 5" HWDP, xo, 24 x 4" HWDP. Slip and cut drilling line. Inspect brakes. Service the top drive. RIH with BHA#6 on 4" DP to 2,031'. Crossover and add Weatherford Ghost Reamer to the drillstring. Crossover and continue to RIH with 4" DP from the derrick to 3,160'. RU to test 10-3(4" 45.5# L-80 BTC surface casing. Pressure test casing to 3,500 psi -chart and hold for 30 minutes -good test. Wash down from 3,160' and tag cement at 3,248'. Drill out the float equipment and 20' of new hole to 3,384' - PU - 115K, SO - 62K, 550 gpm, 1,150 psi, 60 rpm. Displace the well over to new 8.8 ppg LSND drilling fluid. Place the bit inside the surface casing shoe at 3,354'. Conduct an LOT of the surface shoe with 8.8 ppg fluid, 470 psi surface pressure fora 12.24 ppg EMW LOT. Drill 9-7/8" directionally from 3,384' to 4,371'. PU - 125K, SO - 75K, ROT - 88K, 80 rpm, 580 gpm, 2,050 psi on, 1,800 psi off, TQ on - SK, TQ off - 5K, AST - 1.77, ART - 3.31. Drill 9-7/8" directionally from 4,371' to 5,956'. PU - 140K, SO - 84K, ROT - 104K, 80 rpm, 590 gpm, 2,390 psi on, 2,275 psi off, TO on - 8K, TO off - 5K, AST - 2.38, ART - 5.88. Pumped a high visc sweep at 5,125' - returned ~10°!° additional cuttings. Drill 9-7/8" directionally from 5,956 to 6,890'. PU - 122K, SO - 87K, ROT - 105K, 80 rpm, 590 gpm, 2,480 psi on, 2,260 psi off, TO on - 8K, TQ off - 5K, AST - 7.08, ART - 2.48. Pumped a high visc sweep at 6,000' -returned -25% additional cuttings. Drill 9-7/8" directionally from 6,890' to 7,429' (TD). PU - 130K, SO - 90K, ROT - 102K, 80 rpm, 590 gpm, 2,700 psi on, 2,2570 psi off, TO on - 7K, TO off - 5K, AST - 2.13, ART - 1.68. Circulate open hole volume, 9.2 ppg fluid going in and coming out. Drop 2-3/8" hollow rabbit and circulate down at 230 gpm, 770 psi. MAD pass log from 7,429' to 5,760' - 585 gpm, 2,500 psi, 80 rpm, 6k TO. Backream from 5,760' to 3,354' (surface casing shoe) - 585 gpm, 2,300 psi, 80 rpm, 6k TO. Circulate and condition mud at the casing shoe - 585 gpm, 1,800 psi, 80 rpm, 4k TO. POH standing back 4" from 3,354' to 266'. PJSM. LD BHA#6. LD 1 x 5" HWDP, jar and 1 x 5" HWDP. Download Sperry MRIL and LD. LD nm dc. Remove nuclear Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Page 7 of 22 L-250 L-250 Spud Date: 10/24/2005 DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 NABOBS 9ES Rig Number: Date 'From - To Hours Task I' Code ~ NPT ;_ 11/4/2005 121:00 - 00:00 ~ 3.00 ~ DRILL ~ P 11 /5/2005 11 /6/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 06:00 5.50 EVAL P 06:00 - 08:00 I 2.001 EVAL I P 08:00 - 10:00 2.00 EVAL P 10:00 - 12:00 2.00 EVAL P 12:00 - 14:30 2.50 EVAL P 14:30 - 15:30 1.00 EVAL P 15:30 - 17:30 2.00 EVAL P 17:30 - 20:00 2.50 EVAL P 20:00 - 20:30 0.50 EVAL P 20:30 - 23:00 I 2.501 BOPSUp P 23:00 - 23:30 I 0.501 CASE I P 23:30 - 00:00 00:00 - 01:30 01:30 - 20:00 0.50 CASE P 1.50 CASE P 18.50 CASE P Phase Description of Operations INTi source. LD ADN, MWC, ARC, nm stab, xo, motor and 9-7/8" bit. 9-7/8" Hycalog DSX199GUW graded: 1/3/WT/A/X/I/CT/TD. INTi Clean and clear the floor. INTi PJSM. RIH with 45 sidewall coring barrels on 4" DP to 5,200'. Break circulation every 1,000' in casing and every 5 stands in OH. INTi RU side-door entry sub and wireline on rig floor. RIH with wireline and latch up. Function test wireline tools -good. INT1 RIH with SWC and wireline on 4" DP from 5,200' to 7,200'. INT1 Correlate SWC with logs from 7,200' to 7,023'. RIH to 7,278'. INT1 POH from 7,278' taking sidewall cores - i st shot taken at 7,228', 45th shot taken at 5,406'. Log out of the hole to 5,223'. INT1 POH with wireline and RD wireline tools on the rig floor. INTi Circulate and condition the hole - 210 gpm, 290 psi, 9.2 ppg mud going in and coming out. INTi POH standing back the 4" DP and 4" HWDP. INT1 LD gamma ray tool and sidewall cores. Recovered 45 core barrels and 43 of 45 samples -one misfire and one barrel filled with mud. INTi Drain the BOP stack and flush with water. Pull wear ring and install test plug with landing joint. Change out the top set of rams to 7-5/8" and test to 250 psi low / 3,500 psi high -good. RD testing equipment and pull test plug. INTi PU landing joint and casing hanger. Make a dummy run and mark pipe. LD landing joint and casing hanger. INT1 RU the rig floor to run 7-5/8" casing. Changeout to long bails. INTi RU the rig floor to run 7-5/8" casing. INTi Hold PJSM. PU 7-5/8" 29.7# L-80 BTC-M shoe track and RIH. Bakerlok all shoe track connections. Check floats -holding. PU 7-5/8" 29.7# L-80 BTC-M casing joints and RIH. Space out pups and run centralizers per running order. Utilize BOL NM thread lubricant and torque to mark with 8,000 ftlbs. Fill every joint while running in. Break circulation for 5 minutes every 10 joints while in the casing and for 15 minutes every 15 joints in the open hole. Circulate a bottoms up at 5,547' - 250 gpm, 388 psi. Land hanger with float shoe @ 7,418' - PU - 200k, SO - 115k. Float shoe: 7,418' Float collar: 7,332' 20:00 - 20:30 20:30 - 21:30 21:30 - 00:00 Top of L1 window joint: 6,589' L1 RAT tag: 6,547' Top of L2 window joint: 6,379' L2 RAT tag: 6,337' Ran a total of 179 joints of 7-5/8" 29.7# L-80 BTC-M casing, 97 centralizers and 31 stop rings 0.50 CASE P INT1 LD the Franks fillup tool and RU the Schlumberger double plug cement head. 1.00 CEMT P INTi Circulate and condition mud for cement job. Reciprocate pipe while circulating. 2.50 CEMT P INT1 Hold PJSM with Schlumberger and rig personnel. Continue to Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Page 8 of 22 Legal Well Common W Event Nam Contractor Rig Name: Date Name: L ell Name: L e: Name: From - To , -250 -250 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 9ES Task i TE A DRI Code LING NPT Start I Rig Rig Phase Spud Date: 10/24/2005 : 10/23/2005 End: 12/3/2005 Release: 12/3/2005 Number: Description of Operations 11/6/2005 21:30 - 00:00 2.50 CEMT P INTi circulate while Schlumberger batched up cement. Continue to reciprocate. 11/7/2005 00:00 - 02:00 2.00 CEMT P INT1 Line up to Schlumberger and pump 5 bbls of fresh water ahead. Shut down and pressure test the lines to 3,500 psi - good. Pump 25 bbls of CW100 followed by 50 bbls of 10.5 ppg Mudpush II spacer at 4 bpm, ICP - 220 psi, FCP - 175 psi. Drop bottom plug. Chase plug with 69 bbls of 15.8 ppg Gasblok slurry at 5 bpm, ICP - 270 psi, FCP - 200 psi. Switch to 16.5 ppg DuraSTONE on the fly and pump 67 bbls at 6 bpm - ICP - 260 psi, FCP - 250 psi. Shut down and drop the top plug. Kick the plug out with 10 bbls of fresh water. Shut down and pump remainder of displacement with the rig pumps. Pumped seawater at 7 bpm, ICP - 100 psi, FCP - 800 psi. Reduce rate to 4 bpm after 294 bbls pumped, ICP - 600 psi, FCP - 700 psi. Reduced rate to 2 bpm after 326 bbls pumped, ICP - 650 psi, FCP - 700 psi. Bumped the plug with 332 bbls of seawater, 95% efficiency and with 2,000 psi -hold for 5 minutes. Bleed off pressure and check floats -holding. Good lift and full returns seen throughout entire job. Pipe was reciprocated until 276 bbls into the displacement when it was landed on the hanger. Cement in place on 11/7/2005 C~3 0145 hours. 02:00 - 03:30 1.50 CEMT P INTi LD the cement head and the landing joint. Flush stack. Change long bails to short bails. RD casing handling equipment. Clean and clear the rig floor. 03:30 - 04:30 1.00 CASE P INT1 Install packoff and test to 5,000 psi -good. 04:30 - 06:30 2.00 BOPSU P INT1 Changeout the top rams from 7-518" to 3-1/2" x 6" variables. RU testing equipment. Test door seals to 3,500 psi. RD testing equipment. 06:30 - 07:00 0.50 DRILL P PROD1 Hold PJSM to pick up BHA#7 - 6-3/4" BHA. 07:00 - 09:30 2.50 DRILL P PROD1 MU BHA#7 and RIH. BHA components: 6-3/4" Hycalog DS146, 4-3/4" AIM motor - 1.5 degree - 4R/5S - 6 stg, bypass sub with float, nm stab, MWD/LWD, PWD, ADN, 2 x nm dc's, circ sub, xo, 1 x 4" DP, jars and 1 x 4" DP. 09:30 - 12:00 2.50 DRILL P PROD1 PU 4" DP singles and RIH with BHA#7 to 2,383'. Simops: Perform LOT down the 7-5/8" x 10-3/4" annulus - 12.09 ppg EMW. Inject 135 bbls of 9.2 ppg LSND drilling fluid to clear the annulus - 3 bpm, 600 psi. 12:00 - 15:00 3.00 DRILL P PROD1 PU 4" DP from 2,383' to 6,199'. 15:00 - 15:30 0.50 DRILL P PROD1 RIH with BHA#7 on 4" DP from the derrick. 15:30 - 16:30 1.00 CASE P PROD1 Line up and pressure test the casing to 3,500 psi. Chart and hold for 30 minutes -good test. 16:30 - 17:30 1.00 DRILL P PRODi Cut and slip drilling line. Inspect brakes. Service and lubricate the top drive. 17:30 - 18:00 0.50 DRILL P PROD1 Ready the rig floor for MOBM. 18:00 - 19:00 1.00 DRILL P PROD1 Wash down and tag up on cement at 7,273'. Drill cement and shoe track down to 7,414' - PU - 160k, SO - 80k, TO - 8.5k, 290 gpm, 60 rpm, 1,880 psi. 19:00 - 20:30 1.50 DRILL P PROD1 Pump 50 bbls spacer and displace the well over to 9.2 ppg MOBM. 20:30 - 21:00 0.50 DRILL P PROD1 Drill remainder of the shoe track, rathole and 20' of new formation to 7,449' Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To ~ Hours Task Code I NPT 11/7/2005 21:00 - 21:30 ~ 0.50 DRILL P 21:30 - 22:00 I 0.501 DRILL I P 22:00 - 23:00 I 1.001 DRILL I P 23:00 - 00:00 I 1.001 DRILL I P 11/8/2005 100:00 - 00:00 I 24.001 DRILL I P 11/9/2005 ~ 00:00 - 01:00 ~ 1.00 ~ DRILL ~ P 01:00 - 02:00 I 1.001 DRILL I P 02:00 - 09:00 I 7.001 DRILL I P 09:00 - 10:30 1.50 DRILL P 10:30 - 11:00 0.50 DRILL P 11:00 - 12:00 1.00 DRILL P 12:00 - 15:00 3.00 DRILL P 15:00 - 20:00 5.00 DRILL P 20:00 - 22:00 2.00 DRILL P 22:00 - 22:30 0.50 DRILL P 22:30 - 00:00 1.50 CASE P 11/10/2005 00:00 - 03:00 3.001 CASE P Start: 10/23/2005 Rig Release: 12/3/2005 Rig Number: Phase PROD1 PROD1 PRODi PROD1 PROD1 Page 9 of 22 Spud Date: 10/24/2005 End: 12/3/2005 Description of Operations Circulate and condition fluid. Pull bit inside the casing shoe at 7,418'. Perform FIT with 9.2 ppg MOBM fluid, 300 psi surtace pressure and 4,429' TVD for 10.5 ppg EMW. Circulate and obtain baseline ECD readings -calculated ECD - 10.14ppg, actual ECD - 10.13 ppg. Drill 6-3/4" hole directionally from 7,449' to 7,508', PU - 125k, SO - 90k, ROT - 100k, TQ - 4k, 290 gpm, 2,655 psi on, 2,500 psi off. AST - 0.35, ART - 0.15. Drill 6-3/4" hole directionally from 7,508' to 9,092', PU - 140k, SO - 60k, ROT - 100k„ 60 rpm, TO - 5.9k, 301 gpm, 2,925 psi on, 2,560 psi off. AST - 9.13, ART - 4.12. CECD - 10.23, AECD - 10.81. Crossed unexpected 20' fault Q 8,567' MD, 4,437' TVD. Drilled out of OA top @ 8,777' MD, 4,443' TVD. Turn down and drill ahead per Geology to find and confirm top of OA. Simops: Freeze Protect the 7-5/8" x 10-3/4" annulus with 105 bbls of dead crude. PROD1 Drill 6-3/4" hole directionally from 9,092' to 9,186', PU - 143k, SO - 56k, ROT - 95k, 60 rpm, TO - 5.9k, 300 gpm, 2,925 psi on, 2,550 psi off. CECD - 10.15, AECD - 10.75. AST - 0.00, ART - .74 Top of OA @ 9,125' MD, 4,453' TVD 'TD 6.75" OA Target @ 9,186' MD, 4,465' TVD, 11/9/05, 01:00 hr PROD1 Circulate bottoms up for ECD's. 250 gpm, 2,100 psi, 60 rpm, TO - 5.3k CECD - 10.14, AECD - 10.74. ECD's straight lined Q 10.74 with 1.5 x bottoms up. Shakers clean. MW - 9.2 ppg PROD1 Mad pass, backream from 9,186' to 7,976 ~ 300 fph'. 60 rpm, TO 5.6k, 260 gpm, 2,225 psi. PROD1 Mad pass, backream from 7,976' to 7,418' @ 600 fph'. 60 rpm, TO 5.6k, 260 gpm, 2,225 psi. PROD1 Service top drive and crown, monitor well. PROD1 RIH from 7,418' to 9,186' PROD1 Circulate bottoms up. 300 gpm, 2850 psi, 60 rpm, TO - 5.8k. Displace well with 9.2 ppg SFMOBM. PROD1 Monitor well.. POH from 9,186' to 236'. PROD1 Lay down 6.75" drilling BHA #7. PROD1 Clean rig floor, clear floor of vendor tools. RUNPRD Rig up to run 4.5" 12.6# L-80 BTC /IBT, Slotted /Solid liner assembly. RUNPRD PJSM. RIH with 4.5" slotted liner assembly to 1,954'. Used Best-O-Life pipe lubricant. BTC TO - 3,600 fUlbs, IBT TO - 6,000 ft/Ibs. PU - 55k, SO - 51 k. Ran total of 19 Jts 4.5" 12.6# L-80 IBT solid liner 23 Jts 4.5" 12.6# L-80 BTC slotted liner 2 crossover Jts IBT x BTC Shoe set @ 8,632' Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 11/10/2005 100:00 - 03:00 11/11/2005 11 /12/2005 L-250 L-250 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABORS9ES Hours' Task ~i Code NPT 3.00 CASE P 03:00 - 12:30 9.50 CASE P 12:30 - 13:00 0.50 CASE P 13:00 - 13:30 0.50 CASE P 13:30 - 17:30 17:30 - 18:00 18:00 - 21:00 21:00 - 00:00 00:00 - 01:30 01:30 - 02:00 02:00 - 02:30 02:30 - 03:30 03:30 - 07:30 07:30 - 08:30 08:30 - 09:30 09:30 - 13:00 13:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 20:30 20:30 - 21:00 21:00 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 01:00 01:00 - 02:00 4.00 CASE P 0.50 STWHIP P 3.00 STWHIP P 3.00 STWHIP P 1.50 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 4.00 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 3.50 STWHIP P 1.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 4.00 STWHIP P 0.50 STWHIP P 2.00 STWHIP P 0.50 STWHIP P 0.50 DRILL P 1.00 DRILL P 1.00 DRILL P Start: 10/23/2005 Rig Release: 12/3/2005 Rig Number: Phase (RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD2 PROD2 PROD2 Page 10 of 22 Spud Date: 10/24/2005 End: 12/3/2005 Description of Operations FC set C~ 8,58T 4.5" x 6.3" Swell Packer set @ 8,521' - 8,531' 7.625" x 5.5" Baker ZXP Liner Top Packer set C~ 6,704' Liner Top set Q 6,693' 28 HES 4.5" x 5.75" x 8" centralizers as follows: 1 ea, locked on top of shoe, 1 ea above and below swell packer, 1 ea on jts 1-25 RIH with 4.5" slotted liner assembly on 4" HT-40 drill pipe to 8,632' @ 90 fpm, tilling every stand. Set hanger with 2,000 psi, set down 25k. Set packer with 3,200 psi, bleed to 0 psi. Pressure test packer with 1,500 psi - 5 min - OK. Release liner setting tool. Pressure up to 1,000 psi and pull out of seals. Pressure bled to 0 psi Circulate bottoms up C~ 270 gpm, 1110 psi, PU - 115k, SO - 185k. POH from 6,632'. Lay down running tool. Pick up whipstock tools to rig floor. Pick up, make up whipstock assembly. RIH with whipstock assembly on 4" HT-40 drill pipe. RIH with whipstock assembly to 6,521 Q 50 fpm Orient whipstock to 20L from highside. PU - 137k, SO - 86k RIH and tag top of tieback sleave @ 6,693.5'. Set trip anchor with 10k, pick up 5k over to verify. Set down 20k and shear mills for whipstock. Test backside to 1,500 psi - 5 min - OK. Displace well from 9.2 ppg SFMOBM to 9.2 ppg MOBM @ 300 gpm, 2,200 psi. Obtain slow pump rates. Mill window from 6,606' to 6,618'. 325 gpm, 2,480 psi, 60 rpm, TO - 5k. Drill 17' of new hole from 6,618' to 6,635'. 331 gpm, 2,525 psi, 80 rpm, TO - 5k, WOB - 3-5k, PU - 137k, SO - 86k, RW - 96k. Pump 45 bbl high vis sweep surface to surface C 330 gpm, 2,520 psi, 60 rpm, TO - 4.1 k. Work mills through window while circulating. POH from 6,606' to 461'. MW - 9.2 ppg, PU - 132k, SO - 88k. Lay down 4 3/4" DC's and milling assembly BHA #8. Clean and clear rig floor, lay down vendor tools. Flush and function BOP stack. Rig up to test BOPE. Pull wear bushing, install test plug. Test BOPE and floor related equipment to 250 psi low pressure - 5 min each, 3,500 psi high pressure - 5 min each. Witnessing of test waived by AOGCC rep Lou Grimaldi. Test witnessed by BP reps Alan Madsen, Robert French and NAD Toolpushers Bill Bixby, Brian Tiedemann. Rig down BOPE test equipment. Blow down lines, pull test plug, install wear bushing. Change out lower (BOP on top drive. Test same to 250 psi, 3,500 psi. Service top drive. PJSM for BHA. Pick up tools for BHA #9. Pick up, make up 6.75" directional drilling assembly. (BHA #9) Orient tools. PJSM on nuclear source. Make up same and complete make Printed: 72/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date ~ From - To Hours Task I Code i NPT 11/12/2005 01:00 - 02:00 1.00 DRILL P 02:00 - 05:00 3.00 DRILL P 05:00 - 06:30 I 1.501 DRILL I P 06:30 - 12:30 ~ 6.00 ~ DRILL ~ P 12:30 - 13:00 0.50 DRILL P 13:00 - 16:30 3.50 DRILL P 16:30 - 18:00 1.50 DRILL P 18:00 - 19:00 1.00 DRILL P 19:00 - 20:30 1.50 DRILL P 20:30 - 23:00 I 2.501 DRILL I P 23:00 - 23:30 0.50 DRILL P 23:30 - 00:00 0.50 DRILL P 11/13/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 01:00 0.50 DRILL P 01:00 - 02:00 1.00 DRILL P 02:00 - 04:00 2.00 DRILL P 04:00 - 04:30 0.50 DRILL P 04:30 - 00:00 19.50 DRILL P 11/14/2005 ~ 00:00 - 06:00 ~ 6.00 ~ DRILL ~ P 06:00 - 07:00 1.00 DRILL P 07:00 - 00:00 17.00 DRILL P 11/15/2005 100:00 - 01:00 01:00 - 03:00 1.00) DRILL IP 2.001 DRILL I P Start: Rig Release; Rig Number: Phase PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 10/23/2005 12/3/2005 Page 11 of 22 Spud Date: 10/24/2005 End: 12/3/2005 Description of Operations up of BHA. RIH with BHA #4 on 4" HT-40 drill pipe to 6,576'. Shallow hole tested MWD C~? 1167'. Circulate and condition mud. Obtain benchmark ECD's, 10.47 ppg non-rotating, 10.68 ppg rotating. 300 gpm, 2560 psi, 60 rpm, TO - 3.5k. Orient high side and run bit through window. PU - 125k, SO - 90k. Directionally drill from 6,635' to 7,038'. 300 gpm, On psi - 3,100, Off psi - 2,800, rpm - 60, TO off - 4.4k, TO on - 5.8k. Calc. ECD - 10.65 ppg, Act. ECD - 10.83 ppg. AST - 1.27 hr, ART - 2.44 hr. The resistivity tool working intermittently. Mad passed from 6,843' to 6,946'. Circulate bottoms up for trip for LWD C~3 300 gpm, 2,650 psi. Montor well. PU - 143k, SO - 72k, mud weight - 9.2 ppg. POH to 6,550'. Drop ball and open circulating sub (sheared ~ 2,270 psi). Pump 15 bbls. of 11.2 dry job. Continue POH from 6,550 to 417'. PJSM on nuclear source. Lay down BHA #9. Change out washpipe on top drive: PJSM on nuclear source. Pick up, make up 6.75" directional drilling assembly. (BHA #10) Orient tools. RIH with BHA #4 on 4" HT-40 drill pipe to 6,118'. Shallow hole tested MWD C~3 1168'. Service top drive, grease crown sheaves. Cut and slip drilling line 72' Continue cut and slip drilling line. Clean under drawworks and inspect brakes. RIH from 6,118' to 6,818'. RIH from 6,818' to 7,038' taking 30' surveys. Directionally drill from 7,038' to 7,319'. PU - 130k, SO - 76k, ROT - 97k, WOB - 5k, 304 gpm, 2,780 psi off, 2820 psi on, 40 rpm, 4k TO off, 5k TO on. CECD 10.19 ppg, AECD 10.8 ppg Circulate for ECD's. Act ECD from 10.8 ppg to 10.6 ppg. Directionally drill from 7,319' to 9,184'. PU - 137k, SO - 70k, ROT - 100k, WOB - 5-15k, 300 gpm, 2,920 psi off, 3,070 psi on, 60 rpm, 6.2k TO off, 7.5k TO on. OECD 10.34 ppg, AECD 10.97 ppg. AST - 5.26 hrs, ART - 4.01 hrs. Backream each stand. Survey every 30'. Directionally drill from 9,184' to 9,930'. PU - 137k, SO - 67k, ROT - 98k, WOB - 5-15k, 300 gpm, 2,990 psi off, 3,100 psi on, 60 rpm, 6.2k TO off, 7.5k TO on. CECD 10.44 ppg, AECD 11.12 ppg. Backream each stand. Survey every 30'. Clean frost from top drive blower intake due to low air flow. Directionally drill from 9,930' to 11,050'. PU - 160k, SO - 36k, ROT - 79k, WOB - 5-15k, 300 gpm, 3,015 psi off, 3,180 psi on, 60 rpm, 7.8k TO off, 9.1k TO on. CECD - 10.77 ppg, AECD - 11.19ppg. AST - 3.74 hrs, ART - 6.11 hrs. Backream each stand. Survey every 30'. Directionally drill from 11,050' to 11,184'. PU - 160k, SO - 48k, ROT - 98k, WOB - 10k, 300 gpm, 3,130 psi off, 3,500 psi on, 60 rpm, 8.6k TO off, 9k TO on. CECD - 10.64 ppg, AECD - 11.55 ppg. Backream each stand. Survey every 30'. Not able to orient or slide. CBU for ECD's. CECD - 10.64 ppg, Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Page 12 of 22 Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Spud Date: 10/24/2005 Event Name: DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To Hours Task ,Code NPT - - ~ '~ Phase I Description of Operations --- ' 11/15/2005 01:00 - 03:00 2.00 DRILL P PROD2 AECD - 11.55 ppg. Circulated to ECD of 11.2 ppg. Circulate 15 bbls 11.5 ppg weighted sweep surf -surf. 300 gpm, 3,180 psi, 60 rpm, 8.2k TO, PU - 100k, SO 77k. RECD after sweep - 11.05 ppg. Sweep returned 5-10% increase in cuttings. 03:00 - 06:00 3.00 DRILL P PROD2 Directionally drill from 11,184' to 11,423'. PU - 170k, SO - 36k, ROT - 97k, WOB - 15k, 300 gpm, 3,060 psi off, 3,450 psi on, 60 rpm, 8.1 k TO off, 9.3k TO on. CECD - 10.56 ppg, AECD - 11.34 ppg. Backream each stand. Survey every 30'. TD L-250 L1 NB C~3 11,423' MD, 4,323' TVD ~ 06:00 hr 11 /15/2005. 06:00 - 07:00 1.00 DRILL P PROD2 Circulate bottoms up. 300 gpm, 3,060 psi, 60 rpm, 8k TO. 9.2 ppg MW, CECD - 11.05 ppg, AECD - 11.34 ppg. 07:00 - 12:00 5.00 DRILL P PROD2 Backream /Madpass log, 600 fph from 11,423' to 10,489'. 297 gpm, 3,070 psi, 60 rpm, 8-10k TO, PU - 98k. CECD - 10.56 ppg, AECD - 11.02 12:00 - 14:00 2.00 DRILL P PROD2 Difficulty going back down to set tool joints in position for connections. Slowdown Mad Pass logging to 200 fph in shales from 10,489' to 10,023'. 300 gpm, 2,990 psi, 60 rpm, 8k TO. 14:00 - 20:30 6.50 DRILL P PROD2 Backream /Madpass log, 600 fph from 10,023' to 7,850. Started to have minor packoffs. CECD - 10.04 ppg, AECD - 10.72 PPg• 20:30 - 00:00 3.50 DRILL P PROD2 Backream /Madpass log, from 7,850' to 7,800. Slow down as needed to control packoffs & ECD's. 275 gpm, 2,240 psi, 55 rpm, 5.5k TO. CECD - 10.04 ppg, AECD - 10.62 ppg 11/16/2005 00:00 - 04:00 4.00 DRILL P PROD2 Backream /Madpass log, from 7,800' to 7,497. Slow down as needed to control packoffs & ECD's. 275 gpm, 2,260 psi, 60 rpm, 5k TO. CECD - 10.04 ppg, AECD - 10.56 ppg 04:00 - 07:00 3.00 DRILL P PROD2 Backream /Madpass log, 600 fph from 7,497' to 6,853'. 295 gpm, 2,340 psi, 40 rpm, 5k TO. CECD - 10.02 ppg, AECD - 10.46 ppg. 07:00 - 09:30 2.50 DRILL P PROD2 Attempt Madpass log from 6,853' to 6,761'. Packing off. Made several attempts. Abandon logging operations. Pull dry OK working tight spots. 09:30 - 10:30 1.00 DRILL P PROD2 POH without pumping from 6,761' to 6,577'. Work intermitent tight spots. PU - 135k, SO - 90k. 10:30 - 12:00 1.50 DRILL P PROD2 Circulate bottoms up. 287 gpm, 2,100 psi, 60 rpm, 4k TO. CECD - 10.02 ppg, AECD - 10.24 ppg. 12:00 - 12:30 0.50 DRILL P PROD2 Service top drive and crown. 12:30 - 15:30 3.00 DRILL P PROD2 RIH from 6,577' to 11,290'. PU - 130k, SO - 87k (Q shoe). Obtain PU & SO weights every 500'. Filled pipe C~ 8,440' & 9, 830'. 15:30 - 18:00 2.50 DRILL P PROD2 Wash from 11,290' to 11,423', circulate and condition mud. 300 gpm, 3,125 psi, 80 rpm, 7.Sk TO. CECD - 10.73 ppg, initial AECD - 11.31 ppg, final AECD - 10.99 ppg 18:00 - 19:30 1.50 DRILL P PROD2 Displace well from 9.2 ppg MOBM to 9.2 ppg SFMOBM C 300 gpm, 3,125 psi, 80 rpm, 7.8k TO. 19:30 - 22:00 2.50 DRILL P PROD2 Monitor well - OK. POH with BHA #10 from 11,423' to 6,575'. No problems. 22:00 - 22:30 0.50 DRILL P PROD2 Drop ball, open circulating sub and pump CaCI dry job. 22:30 - 00:00 1.50 DRILL P PROD2 POH from 6,575' to 4,200' to pick up whipstock retrieval assembly. 11/17/2005 00:00 - 01:00 1.00 DRILL P PROD2 POH with BHA #10 from 4,200' to 235' Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Page 13 of 22 Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Spud Date: 10/24/2005 Event Name: DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours ~ Task ~ Code 11/17/2005 01:00 - 03:00 2.00 DRILL ~ P 03:00 - 04:00 1.00 DRILL P 04:00 - 05:00 1.00 WHIP P 05:00 - 06:00 1.00 WHIP P 06:00 - 07:00 1.00 WHIP P 07:00 - 07:30 0.50 WHIP P 07:30 - 08:30 1.00 WHIP P 08:30 - 11:30 I 3.001 WHIP I P 11:30-12:00 0.50 WHIP P 12:00 - 12:30 0.50 WHIP P 12:30 - 13:30 I 1.001 WHIP I P 13:30 - 14:00 0.50 WHIP P 14:00 - 15:00 1.00 WHIP P 15:00 - 18:00 3.00 WHIP P 18:00 - 19:00 1.00 WHIP P 19:00-20:00 1.00 WHIP P 20:00 - 20:30 0.50 WHIP P 20:30 - 21:30 1.00 CASE P 21:30 - 00:00 2.50 CASE P 11 /18/2005 ~ 00:00 - 06:30 6.50 ~ CASE ~ P 06:30 - 10:00 I 3.501 CASE I P 10:00 - 12:30 2.50 CASE P 12:30 - 13:00 0.50 CASE P 13:00 - 14:00 1.00 CASE P 14:00 - 15:00 1.00 CASE P NPT i Phase Description of Operations PROD2 PJSM for nuclear source. Lay down drilling assembly BHA #10. PROD2 Clean and clear rig floor of vendor tools. Function rams. RUNPRD Pick up whipstock fishing tools to rig floor. RUNPRD Make up whipstock retrieval tools BHA #11. RUNPRD RIH with BHA #11 on 4" HT-40 DP to 2,426' RUNPRD Shallow hole test MWD. 275 gpm, 830 psi. RUNPRD RIH from 2,426' to 5,037' with 8 stands of 4" HT-40 HWDP, 20 stands 4" DP RUNPRD RIH from 5,037' to 5,995' picking up (30) 4.75" drill collars 1 x 1. RUNPRD RIH on drill pipe trom 5,995' to 6,603'. RUNPRD Orient retrieval lug. PU - 149k, SO 100k. Insert lug on 3rd attempt ~ 6,611'. Verify latch-up with 215k PU weight. Pulled free on second pick up. Pick up to 6,575'. RUNPRD Circulate bottoms up. 275 gpm, 1980 psi. Monitor well - OK. 9.2 ppg mud wt. RUNPRD POH slow from 6,575' to 6,048'. PU - 150k. RUNPRD POH from 6,048' to 5,037' standing back 10 stands of 4.75" drill collars. RUNPRD POH from 5,037' to 102'. RUNPRD PJSM with Baker rep. Lay down whipstock retrieval assembly. RUNPRD Lay down whipstock, break out trip anchor assembly. *Visual inspection of whipstock slide indicated a full 12' window. RUNPRD Clean and clear rig floor of vendor tools. Function rams. RUNPRD Rig up to run 4" solid /screened liner. RUNPRD PJSM on liner job. Pick up 4.5" float bent shoe joint, (1) 4.5" 12.6# L-80 IBT-M Solid liner jt (3,000 ft/Ibs MU TO) and RIH with 4" 10.9# L-80 IBT-M Solid liner alternating per running detail with 4" 15.2# L-80 IBT-M Screened liner (3,200 fUlbs MU TO) Lubricate pipe threads with Best 0 Life 2000 NM. RUNPRD RIH with 4" 10.9# L-80 IBT-M Solid liner alternating per running detail with 4" 15.2# L-80 IBT-M Screened liner to 4,682' @ 90 fpm. Record up & down weights every 1000' in casing. PU - 80k, SO - 65k C 4,682' RUNPRD RIH with screened liner on 4" HT-40 drill pipe to 6,606'. PU - 106k, SO - 75k. Exit casing on 3rd attempt. RUNPRD Continue RIH on 4" HT-40 drill pipe from 6,606' to 8,884' RUNPRD RIH with 8 stands 4" HT-40 HWDP from 8,884' to 9,621'. RUNPRD RIH with 10 stands 4 3/4" drill collars from 9,621' to 10,540'. RUNPRD RIH on drill pipe from 10,540' to 11,271'. Worked through fright spot from 10,920' to 10,960'. PU & SO weights taken every 500' in open hole. *Did not see any centralizers going through window. 15:00 - 15:30 0.50 CASE P RUNPRD Set down on Hook Hanger. PU - 180k, SO - 75k. Worked down hanger 5' past hook twice working out pipe compression, pick up and turn 180 deg, and set down 40k on hook. Verify hanger set 2 times. 15:30 - 16:00 0.50 CASE P RUNPRD Drop ball and pump to seat Q 2 bpm. Pressure up to 3,000 psi for 1 minute. Pressure up to 4,230 psi, shear out. Pick up and Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Page 14 of 22 Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Spud Date: 10/24/2005 Event Name: DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Task 'Code NPT I Phase I Description of Operations -- - Hours ~ _ - - -_ _ - - - _ 11/18/2005 15:30 - 16:00 0.50 CASE P RUNPRD verify HR tool released. PU - 150k, 50'. Ran total of: 2 jts 4.5" 12.6# L-80 BTC tubing 69' jts 4" 10.9# L-80 BTC tubing 44 jts 4" x 4.95" OD 15.2# Screened tubing w/ 9.5# L-80 BTC ends & w/ 5 3/4" integral blade centralizers in mid joint 4 1/8" x 5 3/4" rigid blade centralizers on solid joints #1-69 2 centralizers each above and below Swell packers. 73 total centralizers. Tops: Shoe @ 11,273.57 1 bent jt and 1 solid jt 4.5" 12.6# L-80 BTC @ 11,191' 4" 10.9# L-80 BTC solid joints & 4" x 4.925" screened joints alternating 1 x 1 @ 10,407' Solid @ 10,285' Swell packer @ 10,262' RA tag @ 10,254' Solid @ 10,083' Alternate Screened & Solid @ 8,635' Solid @ 8,391' Alternate Screened & Solid @ 6,932' Solid @ 6,689' Swell packer @ 6,667' RA tag @ 6,659' Top of Liner @ 6,601' 16:00 - 17:00 I 1.001 CASE. I P 17:00 - 17:30 0.50 CASE P 17:30 - 18:30 1.00 CASE P 18:30 - 00:00 5.50 CASE P 11/19/2005 00:00 - 00:30 0.50 CASE P 00:30 - 04:00 3.50 CASE P 04:00 - 08:00 08:00 - 09:30 4.00 CASE P RUNPRD Circulate bottoms up. 272 gpm, 1,680 psi. Stand back 1 stand. RUNPRD Cut & slip 84' drilling line. RUNPRD Service rig & top drive. RUNPRD POH with liner running tool from 6,509' to 12' RUNPRD Break down, lay down liner running tool. RUNPRD PJSM. Make up Baker LEM assembly. 3,200 ft/Ibs MU TO. Rig up false table and pick up 2 3/8" inner string. Make up Baker ZXP packer & HR running tool RUNPRD RIH with Lat 1 LEM assembly from 195' to 6,614'. Wash down to SBE @ 6,717', p{us 11' for LEM {atch up @ 6,601'. Verify latch up with 30k set down weight. Ran total of (1) jt 4.5" 12.6# L-80 IBT (2) 4.5" 12.6# L-80 IBT space out pups 1.50 CASE P RUNPRD Drop and pump down ball to seat. Pressure up to 4,000 psi and set ZXP packer. Release running tool. Test packer integrity to 1500 psi - OK. Printed: 12/5!2005 11:10:45 AM BP EXPLORATION Page 15 of 22 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: L-250 L-250 Spud Date: 10/24/2005 DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 NABOBS 9ES Rig Number: Date From - To j Hours ~~ Task Code; NPT 11/19/2005 08:00 - 09:30 1.50 CASE P 09:30 - 10:30 1.00 CASE P 10:30 - 11:30 1.00 CASE P 11:30 - 13:00 1.50 CASE P 13:00 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 20:00 20:00 - 00:00 2.001 CASE I P 0.50 CASE P 0.50 CASE P 1.00 CASE P 1.00 STWHIP P 2.00 STWHIP P 4.00 STWHIP P 11/20/2005 100:00-01:30 01:30 - 02:30 02:30 - 03:00 03:00 - 08:00 1.50 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 5.00 STWHIP P Phase Description of Operations -- - - _ - - - RUNPRD TOPS: 4.75" ID x 6.27" OD x 19.67' Seal Bore Extension C~? 6,563.61' ZXP liner top packer w/ 5.75" ID x 6.45" OD x 11' Tie back sleeve Q 6,544.59'. RUNPRD Circulate 1 1/2 x bottoms up C~ 295 gpms, 1,740 psi. 9.2 ppg mud wt. RUNPRD POH from 6,523' to 5,962'. RUNPRD POH from 5,962' to 4,948' laying down 21 4 3/4" drill collars and racking back 3 stands DC's. RUNPRD POH from 4,948' to liner running tool standing back HWDP and drill pipe. RUNPRD Service break and lay down liner running tool. RUNPRD Lay down 5 joints 2 3/8" EUE inner string. RUNPRD Clear rig floor of LEM equipment. Function rams. WEXIT Pick up whipstock tools to rig floor. WEXIT PJSM. Make up whipstock BHA #12. Orient tools. WEXIT RIH from 260' to 3,337' with 3 stands 4 314" DC's and 4" drill pipe @ 45 fpm per Baker rep. Shallow hole tested MWD @ 1,460' - OK. WEXIT RIH from 3,337 to 6,500' on 4" drill pipe and 8 stands of HW DP @ 45 fpm per Baker rep. Orient whipstock to 15 deg left. PU - 135k, SO - 85k, 348 gpm, 2,875 psi. WEXIT Tag no go on liner top 5' deep Q 6,550'. Set down 12k. Shear out whipstock bolt with 35k set down weight. Establish free rotation. Test backside to i 500 psi - 5 minutes - OK. 'Top of window @ 6,391' WEXIT Displace well from 9.2 ppg SFMOBM to 9.2 ppg MOBM. 348 gpm, 2,875 psi. WEXIT Mill 7 5/8" window from 6,391 to 6,403. 343 gpm, 2520 psi, 70 rpm, 5.4k TO, PU - 135k, SO - 85k, RT - 98k, WOB - 2k. 'Top of window Q 6,391' 'Bottom of window ~ 6,403' 08:00 - 09:00 1.00 STWHIP P WEXIT Drill 17' NB L2 new hole from 6,403' to 6,420' with same parameters. 09:00 - 12:00 3.00 STWHIP P WEXIT Circulate high viscosity sweep surface to surface while reciprocating and rotating through window @345 gpm, 2535 psi, PU - 98k, SO - 85k, RPM - 80, TO - 4.3k. MW - 9.2 ppg. Monitor well, pump dry job. 12:00 - 14:00 2.00 STWHIP P WEXIT POH from 6,403' to 348'. PU - 130k, SO - 95k. 14:00 - 15:00 1.00 STWHIP P WEXIT Lay down 9 4 3/4" DC's and bumper sub. 15:00 - 15:30 0.50 STWHIP P WEXIT Lay down whipstock mill assembly BHA #12. 15:30 - 16:30 1.00 STWHIP P WEXIT Clean and clear rig floor of vendor tools. Function rams. 16:30 - 17:00 0.50 STWHIP P WEXIT Flush out BOP stack with jet sub. Blow down lines. 17:00 - 18:30 1.50 DRILL P PROD3 Make up directional drilling assembly BHA #13. PJSM on nuclear source. Load same. RIH with flex DC's to 231'. 18:30 - 19:00 0.50 DRILL P PROD3 RIH from 231' to 1,166' with BHA #13 on 4" HT-40 drill pipe. 19:00 - 19:30 0.50 DRILL P PROD3 Shallow hole test MWD. 290 gpm, 1,460 psi. OK. 19:30 - 22:00 2.50 DRILL P PROD3 RIH from 1,166' to 6,302' with BHA #13 on 4" HT-40 drill pipe. 22:00 - 23:00 1.00 DRILL P PROD3 Circulate bottoms up X 2. 300 gpm, 2,585 psi, PU - 115k, SO - 78k. Establish base line ECD readings. CECD - 10.36 ppg. Rotating AECD - 10.47 ppg C~? 60 rpm, 275 gpm, 2,210 psi. Orient bit 15 deg. right. Shut down pumps and go through Printed: 12/5/2005 11:10:45 AM BP EXPLORAT[ON Page 16 of 22 Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Spud Date: 10/24/2005 Event Name: DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: Date i From - To Hours Task '' Code NPT ' Phase 11/20/2005 22:00 - 23:00 1.00 DRILL P PROD3 23:00 - 00:00 1.00 DRILL P PROD3 11/21/2005 00:00 - 07:00 7.00 DRILL P PROD3 07:00 - 08:00 I 1.001 DRILL I P I I PROD3 08:00 - 09:00 1.00 DRILL P PROD3 09:00 - 10:00 1.00 DRILL N RREP PROD3 10:00 - 10:30 0.50 DRILL P PROD3 10:30 - 18:00 7.50 DRILL P PROD3 18:00 - 19:30 i 1.50i DRILL i P i ~ PROD3 19:30 - 20:30 I 1.001 DRILL I P I I PROD3 20:30 - 21:00 0.501 DRILL P PROD3 21:00 - 00:00 I 3.001 DRILL I P ( I PROD3 11/22/2005 00:00 - 04:30 4.501 DRILL P PROD3 04:30 - 05:30 1.001 DRILL P PROD3 05:30 - 23:30 I 18.001 DRILL I P I I PROD3 23:30 - 00:00 0.50 DRILL P PROD3 11/23/2005 00:00 - 00:30 0.50 DRILL P PROD3 00:30 - 12:00 11.50 DRILL P PROD3 12:00 - 00:00 12.00 DRILL P PROD3 Description of Operations window. PU- 120k, SO - 85k. Wash down from 6,407' to 6,420'. 275 gpm, 2,210 psi. Directionally drill from 6,420' to 6,774'. 269 gpm, 2,060 psi off bottom, 2,180 psi on bottom. PU - 118k, SO - 76k, WOB 5-10K. CECD - 10.39 ppg, AECD - 10.27 ppg. All sliding Circulate bottoms up. 269 gpm, 2060 psi. Monitor well. MW - 9.2 PP9 POH from 6,774' to 6,302'. PU - 138k, SO - 75k. Replace topdrive brake caliper pins. RIH from 6,302' to 6,774'. Orient to drill. Directionally drill from 6,774' to 7,572'. 275 gpm, 2,300 psi off bottom, 2,475 psi on bottom. PU - 128k, SO - 71 k, RW - 95k, WOB 5K, RPM - 60, TO off - 4.2k, TO on - 5.2k. CECD - 10.57 ppg, AECD - 10.86 ppg. Circulate for geology. Pump 11.2 ppg weighted high vis sweep surface to surface. 275 gpm, 2,300 psi, 60 rpm, 4k TO, PU - 105k, SO - 95k. CECD - 10.58 ppg, initial AECD - 10.57 ppg, final AECD - 10.84 ppg Directionally drill from 7,572' to 7,664'. 275 gpm, 2,300 psi off bottom, 2,475 psi on bottom. PU - 128k, SO - 71 k, RW - 95k, WOB 5K, RPM - 60, TO off - 4.2k, TO on - 5.2k. CECD - 10.58 ppg, AECD - 10.86 ppg. Circulate for geology. 275 gpm, 2,300 psi, 60 rpm, 5k TO, PU - 100k, SO - 95k. CECD - 10.62 ppg, initial AECD - 10.69 ppg, final AECD - 10.49 ppg. Log down from 7,595' to 7,630'. Directionally drill from 7,664' to 7,850'. 275 gpm, 2,300 psi off bottom, 2,600 psi on bottom. PU - 129k, SO - 71 k, RW - 100k, WOB 5-10K, RPM - 60, TO off - 5k, TO on - 6.4k. CECD - 10.50 ppg, AECD - 10.58 ppg. AST - 9.77 hrs, ART - 1.18 hrs. Directionally drill from 7,850' to 8,244'. 270 gpm, 2,450 psi off bottom, 2,600 psi on bottom. PU - 136k, SO - 68k, RW - 98k, WOB 5-10K, RPM - 60, TO off - 5.5k, TO on - 7k. AST - 2.62, ART - 0.32. Calculated ECD - 10.42 ppg, Actual ECD - 11.1 PP9• Circulate for ECD's @ 250 gpm, 2130 psi, 60 rpm, 5k TO. Following circulation, Calculated ECD - 10.6 ppg, Actual ECD - 10.7 PP9• Directionally drill from 8,244' to 10,022'. 270 gpm, 2,650 psi off bottom, 2,850 psi on bottom. PU - 145k, SO - 37k, RW - 96k, WOB 5-10K, RPM - 60, TO off - 6k, TO on - 7k. AST - 4.56, ART - 3.3. Calculated ECD - 10.8 ppg, Actual ECD - 11.2 ppg. Having difficulty sliding. Circulate sweep around to clean up hole. Having difficulty sliding. Circulate sweep around to clean up hole. No appreciable cuttings returned to surface. Directionally drill from 10,022' to 10,954' - 275 gpm, 2,650 psi off bottom, 2,950 psi on bottom. PU - 150k, SO - 35k, RW - 96k, WOB 5-10K, RPM - 60, TO off - 7k, TO on - 8k. AST - 3.0, ART - 1.62. Directionally drill from 10,954' to 12,074' - 275 gpm, 2,920 psi off bottom, 3,070 psi on bottom. PU - 165k, SO - 38k, RW - 92k, WOB 5-10K, RPM - 60, TO off - 8k, TO on - 9k. AST - 3.02, ART - 2.37. Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Page 17 of 22 .Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date ,~~ From - To j Hours ~I, Task Code NPT __- _ - 11l24/2005 ~ 00:00 - 07:30 ~ 7.50 ~ DRILL I P 07:30 - 09:00 I 1.501 DRILL I P 09:00 - 00:00 15.00 DRILL P 11125!2005 00:00 - 08:30 8.50 DRILL P 08:30 - 09:30 I 1.001 DRILL I P 09:30 - 11:30 I 2.001 DRILL I P 11:30 - 13:30 I 2.001 DRILL I P 13:30 - 14:30 ~ 1.00 ~ BOPSUFj P 14:30-18:00 ~ 3.50~BOPSUpP 18:00-19:00 ~ 1.OO~DRILL ~P 19:00 - 20:00 I 1.001 DRILL I P 20:00 - 00:00 I 4.001 DRILL I P 11/26/2005 100:00 - 00:30 I 0.501 DRILL I P 00:30 - 03:30 I 3.001 DRILL I P 03:30 - 05:30 I 2.001 DRILL f P 05:30 - 09:30 I 4.001 DRILL I P Spud Date: 10/24/2005 Start: 10/23/2005 End: 12/3/2005 I Rig Release: 12/3/2005 Rig Number: Phase Description of Operations PRODS Directionally drill from 12,074' to 12,635' (TD) - 275 gpm, 2,945 psi off bottom, 3,160 psi on bottom. PU - 173k, SO - 35k, RW - 95k, WOB 5-10K, RPM - 60, TO off - 9k, TO on - 10k. AST - 1.75, ART - 1.62. PRODS Circulate sweep around - 290 gpm, 3,200 psi - 9.2 ppg fluid going in and coming out. PRODS Monitor the well -stable. Backream /MAD pass from 12,635' to 8,345' at 600'/hour max, 270 gpm, 2,800 psi, 60 rpm, TO 6K. PRODS Continue to Backream /MAD pass from 8,345' to the window at 600'/hour max, 270 gpm, 2,800 psi, 60 rpm, TO 6K. Hole started trying to pack off at 8,260'. Reduced backreaming rate to -100'/hour and were able to backream without packing off to 8,020'. At 8,020', the backreaming rate was gradually increased back to --600'/hour without packing off. Backream out of the hole to 6,500'. Shut down the pumps and rotary and pull pipe dry across the window and into the casing from 6,500' to 6,302'. PRODS Circulate 1.5 x bottoms up - 300 gpm, 2,225 psi, 60 rpm, TO - 5k. Calculated ECD - 10.08 ppg, Initial Actual ECD - 10.38 ppg, Final Actual ECD - 10.28 ppg PRODS Cut and slip 85' of drilling line. Clean under the drawworks and service the top drive. PRODS PJSM. MU Halliburton RTTS/Storm Packer. RIH 30' and apply 1/4 turn to the right. Slack off 50k. Apply 22 turns to the left and unsting from the packer. LD single and pressure test above the packer to 1,000psi -good. PRODS Change out the air boots on the riser, pull wear ring, and clean the floor. PRODS RU and test the BOPE and all related equipment. Test the BOPE to 250 psi / 3,500 psi - no failures. Witness of the test was performed by Tom Anglen (BP), Kelly Cozby (NAD), and was waived by Jeff Jones of the AOGCC. RD testing equipment, blowdown all surface lines and install wear ring. PRODS PU single joint of 4" DP. RIH to the top of the RTTS/Storm Packer. Apply 6 turns to the right and screw into the packer. MU the top drive and apply 21 turns to the right to release the packer. Pull packer to the rig floor. LD RTTS/Storm Packer. PRODS Orient the bit to high side and RIH from 6,302' to 6,372' -taking weight. Circulate bottoms up - 300 gpm, 2,050 psi, 40 rpm. PRODS With the bit oriented high side, RIH through the window without problems. Continue to RIH with 4" DP and 8 stands of 4" HWDP from the derrick to 7,879'. PU 24 more joints of 4" HWDP and continue to RIH with 4" DP from the derrick to 11,833' -started to take weight at 10,000', but still able to work pipe down. PRODS Continue to RIH with 4" DP from the derrick from 11,833' to 12,635' taking intermittent weight, but able to work pipe down. PRODS Circulate and condition the hole - 280 gpm, 3,100 psi. Calcuated ECD - 10.8, Actual ECD - 11.1 PRODS Displace the well over to 9.2 ppg solids free MOBM - 280 gpm, 3,100 psi. PRODS Monitor the well -stable. MW in - 9.2 ppg, MW out - 9.2 ppg. POH standing back 4" DP and 4" HWDP from 12,635' to Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date From - To 11 /26/2005 05:30 - 09:30 09:30 - 10:30 L-250 L-250 DRILL+COMPLETE NABOBS ALASKA DRILLING I NABOBS 9ES Start: 10/23/2005 Rig Release: 12/3/2005 Rig Number: Hours I! Task Code NPT ' Phase 4.00 DRILL P PRODS 1.00 DRILL P PRODS 10:30 - 12:00 1.50 DRILL P PRODS 12:00 - 15:00 3.00 DRILL P PRODS 15:00 - 18:00 3.00 DRILL P PRODS 18:00 - 19:00 1.00 DRILL P PRODS 19:00 - 21:00 2.00 WHIP P RUNPRD 21:00 - 23:30 2.50 WHIP P RUNPRD 23:30 - 00:00 0.50 WHIP P RUNPRD 11/27/2005 00:00 - 00:45 0.75 WHIP P RUNPRD 00:45 - 01:15 0.50 WHIP P RUNPRD 01:15 - 01:30 0.25 WHIP P RUNPRD 01:30 - 02:00 ~ 0.50 WHIP ~ P ~ ~ RUNPRD 02:00 - 02:15 0.25 WHIP P RUNPRD 02:15 - 02:30 0.25 WHIP P RUNPRD 02:30 - 03:15 0.75 WHIP P RUNPRD 03:15 - 06:00 2.75 WHIP P RUNPRD 06:00 - 13:00 I 7.001 WHIP I P I I RUNPRD 13:00 - 14:30 I 1.501 WHIP I P 1 I RUNPRD 14:30 - 15:30 1.00 WHIP P RUNPRD 15:30 - 16:00 0.50 CONDH P RUNPRD 16:00 - 17:30 1.50 CONDH P RUNPRD 17:30 - 19:30 I 2.001 CONDHU P I I RUNPRD 19:30 - 23:00 I 3.501 CONDHU P I I RUNPRD Page 18 of 22 Spud Date: 10/24/2005 End: 12/3/2005 Description of Operations 6,361'. Drop ball and open the circ sub -observe shear at 2,400 psi. Circulate bottoms up with 400 gpm, 2,230 psi. Monitor the well - stable. Pump dry job. POH standing back 4" DP from 6,361' to 5,561'. LD 4" DP from 5,561' to the top of the jars at 233'. PJSM for LD BHA and handling nuclear source. LD 6-3/4" BHA#13 from 233' -jars, 1 x 4" DP, xo, circ sub, 2 x nm flex dc, ADN, VPWD, MWD/LWD, nm stab, AIM motor and 6-3/4" bit. 6-3/4" Hycalog RR DS146 graded: 4/3/BT/A/X/2/CT/TD. Clear and clean rig floor. PJSM. Bring Baker whipstock retrieval tools to the rig floor. MU Whipstock retrieval BHA to 99' -fixed lug retrieval hook, 1 x 3-1/2" HWDP, float sub, MWD, bumper sub, jars, xo. RIH with Whipstock retrieval BHA on 31 stands of 4" DP and 16 stands of 4" HWDP to 4,446'. PU 10 x 4-3/4" DC's and RIH to 4,750'. PU remaining 20 x 4-3/4" DC's and RIH to 5,367'. RIH with 4" DP from the derrick to 6,330. Orient the retrieval hook to be 180 degrees out from the retrieval slot - RIH with 4" DP. PU single joint of 4" DP. Screw in with the top drive and wash down over the slide to ensure slot clean for retrieval. Orient the retrieval hook to the retrieval slot. Engage the whipstock and pull free with -70k overpull. LD single and POH standing back 4" DP to 5,865'. At 5,865', there was an increase in the amount of drag seen while pulling out of the hole -max overpull of 100k. Screw in with the top drive to verify orientation of the BHA. Cock the jars and then PU to 100k overpull to fire the jars. Repeat process making minor gains to 5,853'. Whipstock pulled free at 5,853'. Saw -30K to 50K drag while pulling out of the hole slowly, standing back 4" DP, HWDP and 4-3/4" collars to 4,630'. Saw expected drag from 4,630' to the top of the retrieval BHA at 99'. LD retrieval BHA and whipstock assembly. Recovered all whipstock assembly: slide, ported sub, debris sub, unloader valve, shear sub, retrievable BTA, double pin sub, blank sub, 3 jts 3-1/2" HWDP, 4 DP pups, unloader valve, locator sub and seals. Significant damage to the debris sub on the whipstock BHA. Remove all tools from the rig floor. Clean rig floor. Service the top drive and crown. PJSM. Bring Baker junk baskets, boot baskets and tools to the rig floor. MU and RIH with baker Junk Basket BHA -junk basket, reverse junk basket, xo, boot basket, boot basket, xo, locator bumper sub, jars. PU 30 jts of 4-3/4" Drill Collars from the pipe shed and RIH to 963'. RIH with 4" HWDP and 4" DP from the derrick. Wash down from 6,326' and tag the top of the L1 liner at 6,544' - 290 gpm, 2,500 psi. Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Page 19 of 22 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date i Name: ell Name: e: Name: From - To ~ L-250 L-250 DRILL+C NABOB NABOB Hours OMPLE S ALASK S 9ES ~~ Task TE A DRI ~ Code': LING NPT ~ Start I Rig Rig Phase Spud Date: 10/24/2005 : 10/23/2005 End: 12/3/2005 Release: 12/3/2005 Number: ~ Description of Operations 11/27/2005 _ 23:00 - 00:00 1.00 CONDH P RUNPRD Circulate bottoms up and condition the mud - 290 gpm, 2,500 psi. Pump dry job. 11/28/2005 00:00 - 03:45 3.75 CONDH P RUNPRD POH from 6,544' to the top of the Junk Basket BHA at 39'. Hole trying to swab. POH with reduced pulling speed to manage swab tendency. 03:45 - 05:30 1.75 CONDH P RUNPRD LD Junk Basket BHA. Recovered ~1" diameter x 0.25" thick flat rock and brass lug from whipstock. Clear and clean the floor. 05:30 - 07:00 1.50 CASE P RUNPRD RU liner running handling tools and prepare to run L2 4" screen/solid liner. 07:00 - 07:30 0.50 CASE P RUNPRD Hold PJSM for running liner. 07:30 - 16:30 9.00 CASE P RUNPRD PU and RIH with 4" liner per tally on Baker running tool to 5,884'. Liner shoe track consists of 4.5" float shoe, 4.5" 12.6# L-80 IBT-m bent joint, 4.5" 12.6# L-80 IBT-m full joint and xo. The remaining liner consists of 4" L-80 9.5# IBT-m solid joints, 4" 10.9# L-80 IBT-m solid joints, 4" L-80 15.2# IBT-m screens, 3 "Swell" packers, casing swivel assembly and hook hanger assembly. Utilized BOL 2000 NM thread lubricant and torqued to 3,200 ftlbs. Ran 1 straight blade centralizer on each solid joint. 16:30 - 17:00 0.50 CASE P RUNPRD RD casing handling equipment and clear the floor. 17:00 - 18:00 1.00 CASE P RUNPRD RIH with 4" DP from the derrick to the window. Work pipe through the window on the first try - PU - 95k, SO - 64k. 18:00 - 00:00 6.00 CASE P RUNPRD RIH with remaining 4" DP from the derrick (total of 31 stands). RIH with 4" HWDP from the derrick (total of 16 stands) to 10,232'. Worked pipe with slight rotation (<2,800 ftlbs torque) over tight spots at 7,145', 9,050', 9,500' in short amount of time. Set down hard at 10,130' and saw overpull of -30k while working pipe after -37' of travel. While speaking to engineer in town about options, we were able to work past the tight spot at 10,130' after -2 hours of working pipe. 11/29/2005 00:00 - 01:00 1.00 CASE P RUNPRD Continue to RIH with 4" solid/screen liner. RIH with 2 stands of 4-3/4" Drill Collars and tag up at 10,362'. Unable to get past without rotation and cannot rotate the DC's. POH and stand back DC's and RIH with 4" DP. 01:00 - 02:30 1.50 CASE P RUNPRD RIH with 4" DP. Work past tight spot at 10,362' with rotation and work pipe down to 10,442'. Unable to get past 10,442'. PU and stand back a stand of DP. POH with next stand to position liner shoe above previous tight spot at 10,362'. Set down at 10,362'. Confirmed that the tight spots at 7,145', 9,500', 10,130', 10,362' and 10,442' closely match when the top collar of a solid joint with a floating centralizer was at the bottom of the window. Confer with engineer in town. Decision made to POH with the liner and remove the centralizers from the solid joints down to 4" 10.9# L-80 IBT-m joint #14 per liner tally -the joint that was across the window at shoe depth of 10,130'. 02:30 - 07:00 4.50 CASE N DPRB RUNPRD Pump solids free dry job and POH standing back 4" DP and 4" HWDP to the top of the liner at 5,884' 07:00 - 08:00 1.00 CASE N DPRB RUNPRD RU casing handling tools. 08:00 - 12:00 4.00 CASE N DPRB RUNPRD POH and LD hook assembly, swivel assembly, swell packer assembly, 41 joints of 4" 10.9# L-80 IBT-M solid liner and swell packer assembly. LD 4" 10.9# L-80 IBT-M solid / 4" 15.2# L-80 Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Page 20 of 22 Operations Summary Report Legal Well Name: L -250 Common W ell Name: L -250 Spud Date: 10/24/2005 Event Nam e: DRILL+C OMPLE TE Start : 10/23/2005 End: 12/3/2005 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 12/3/2005 Rig Name: NABOB S 9ES Rig Number: Date From - To Hours ~ Task Code NPT ~I Phase Description of Operations 11/29/2005 08:00 - 12:00 4.00 CASE N DPRB RUNPRD IBT-M screen liner to 3,370'. Remove all centralizers from the solid liner joints. Found 2 joints, #17 and #18 of the 10.9# liner) with a centralizer crimped onto each of the joints - replaced both of the joints in the liner string. 12:00 - 14:30 2.50 CASE N DPRB RUNPRD PU and RIH with 4" liner per tally - no centralizers on solid joints from 10.9# #10 joint. Utilized BOL 2000NM thread lubricant and torqued to 3,200 ft-Ibs. 14:30 - 15:00 0.50 CASE N DPRB RUNPRD RD casing handling equipment. 15:00 - 15:30 0.50 CASE N DPRB RUNPRD RIH with liner on 4" DP through the window on the first attempt to 6,550'. 15:30 - 20:00 4.50 CASE N DPRB RUNPRD Continue to RIH with 4" solid/screen liner on 4" DP, 4" HWDP, and 4-3/4" DC's to 10,442'. Worked pipe across tight spots at 6,760', 8,914' and 9,739'. 20:00 - 00:00 4.00 CASE P DPRB RUNPRD Continue to RIH with liner from 10,442' to 11,872'. Worked through tight spots at 10,517' and 11,872'. 11/30/2005 00:00 -.03:00 3.00 CASE P RUNPRD Work pipe down from 11,872' to 12,265'. Weight was lost at -11,872'. RIH 9' past casing landing depth to ensure hook hanger went past and wipe the interval numerous times from 12,230' to 12,260' to reduce the drag to aid in the identification of when the hanger would be landed. 03:00 - 06:00 3.00 CASE P RUNPRD PU to 12,230'. Slack off and rotate 1/4 turn. Work pipe down to 12,260' and set down -hook hanger on depth. PU to 12,230'. Slack off and rotate 1/4 turn. Work pipe down and set down at 12,260'. POH to 12,230'. Slack off and rotate 1/4 turn. Work pipe down and set down at 12,263'. PU to 12,230'. Slack off and rotate 1/4 turn. Work pipe down and set down at 12,263'. PU to 12,230'. Slack off and rotate 1/4 turn. Work pipe down and set down at 12,260' -believe hook hanger to be on depth, but due to lack of weight and having to work the pipe down it is difficult to tell. PU to 12,230' to re-verify. Slack off and rotate 1/2 turn. Work pipe down and set down at 12,255' - unexplained result. PU to 12,230' to re-verify. Slack off and rotate 1/2 turn. Work pipe down and set down at 12,260'. PU to 12,230'. Slack off and rotate 1/2 turn. Work pipe down and set down at 12,263'. PU to 12,230'. Slack off and rotate 1/2 turn. Work pipe down and set down at 12,260' -hook hanger in place. Prepare to release running tool. 06:00 - 06:30 0.50 CASE P RUNPRD Drop ball and pump onto seat. Pressure up to 3,500 psi and release from the liner. PU out of the liner top and pressure up to 4,200 psi to shear out the ball seat. 06:30 - 08:00 1.50 CASE P RUNPRD Circulate a bottoms up. Pump dry job and prepare to trip out of the hole. MW in - 9.2 ppg, MW out - 9.2 ppg. 08:00 - 08:15 0.25 CASE P RUNPRD POH standing back 2 stands of 4" DP to 6,215'. 08:15 - 11:30 3.25 CASE P RUNPRD LD 60 joints of 4-3/4" drill collars from 6,215' to 4,371'. 11:30 - 13:00 1.50 CASE P RUNPRD POH standing back 16 stands of 4" HWDP and 31 stands of 4" DP to the top of the running tool. 13:00 - 13:30 0.50 CASE P RUNPRD Make service breaks and LD Baker HR running tool. 13:30 - 14:30 1.00 TIEBAC P OTHCMP RU the rig floor to run LEM #2. Bring tools and materials to the floor. 14:30 - 17:30 3.00 TIEBAC P OTHCMP PJSM. MU Baker non-locating seal assembly with 4.5" L-80 full XO joint from STL pin to IBT-m box, 2 joints of 4.5" 12.6# L-80 IBT-M liner, 3 x 4.5" pup joints and LEM hanger assembly. RU false rotary table and MU 2-3/8" 8rd EUE inner string. MU Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Page. 21 of 22 Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Spud Date: 10/24/2005 Event Name: DRILL+COMPLETE Start: 10/23/2005 End: 12/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 12/3/2005 Rig Name: NABOBS 9ES Rig Number: Task Code NPT I Phase Description of Operations Date From - To Hours _ ~ _ _ - - -- 11/30/2005 14:30 - 17:30 3.00 TIEBAC P OTHCMP baker HR running tool/ZXP packer assembly down to 237' 17:30 - 18:30 1.00 TIEBAC P OTHCMP Slip and cut drilling line. Service the top drive and the crown. 18:30 - 00:00 5.50 TIEBAC P OTHCMP RIH with LEM #2 on 4° HWDP and 4" DP to 6,376', PU - 140K, SO - 75K. Tag the top of the L2 hook on depth at 6,386'. Rotate the string 1/2 turn. RIH to 6,540'. Screw in with the top drive and circulate down and enter the seal assebly. Latch into the hook hanger with the LEM on depth and verify with 30k down and 10k up. Drop ball and pump down onto seat. Pressure up to 4,200 psi to set the packer and release from the LEM. PU to expose dogs. Slack back off and verify release from LEM. PU 30' and get ready to displace over to 9.1 ppg brine. Bottom of Non-locating seal assembly - 6,574', Top of LEM #2 - 6,375', Top of ZXP liner top packer - 6,349' (11' tieback extension). 12/1/2005 00:00 - 02:00 2.00 TIEBAC P OTHCMP Displace the well over to 9.2 brine. 02:00 - 03:30 1.50 TIEBAC P OTHCMP Clean possum belly, shakers, trough and trip tank of MOBM. 03:30 - 10:30 7.00 TIEBAC P OTHCMP POH LD 4" DP and 4" HWDP. LD packer setting tool and i 2-3/8" inner string. RIH with 9 stands of 4" from the derrick. LD 27 joints of 4" DP. 10:30 - 11:30 1.00 TIEBAC P OTHCMP Flush the BOP stack and pull the wear ring. 11:30 - 13:00 1.50 BUNCO RUNCMP Bring tubing handling equipment to the rig floor. RU tools to run 4.5" 12.6# L-80 TCII completion. Make a dummy run with the landing joint and the tubing hanger and mark pipe. 13:00 - 20:00 7.00 BUNCO RUNCMP PJSM. PU and RIH with 4.5" 12.6# L-80 TCII completion per tally to 2,491 - 4.5" 12.6# L-80 IBT-M guide shoe, TCII box x IBT-M pin xo, 4.5" TCII X nipple assembly(3.813" ID), 4.5" TCII X nipple assembly w/ RHC-M plug profile (3.813" ID), 1 jt 4.5" 12.6# TCII tubing, 7.625" x 4.5" Premier Packer assembly, Phoenix Jet Pump Sensor assembly, Baker CMD sliding sleeve / Phoenix Discharge Pressure Sensor assembly. RU I-wire and tie in. Check conductivity -good. Continue to RIH with completion - 2 jts of 4.5" TCII tubing, GLM #1 assembly with DCK shear valve, 2 jts 4.5" TCII tubing, GLM #2 assembly, 27 jts 4.5" TCII tubing, 23 jts of 4.5" TCII tubing to 2,490'. All tubing connections utilized Jet Lube Seal Guard thread lubricant and Torque Turned to 3,850 tt-Ibs. 20:00 - 22:00 2.00 BUNCO RREP RUNCMP Splash plate on the high drum clutch broke. Re-weld into position. 22:00 - 00:00 2.00 BUNCO RUNCMP Continue to RIH with 4.5" completion. RIH with 18 jts of 4.5" TCII tubing to 3,192'. 12/2/2005 00:00 - 06:45 6.75 BUNCO RUNCMP Continue to RIH with 4.5" 12.6# L-80 TCII completion from 3,192' to 6,365' to space out WLEG into Tieback. Lay down excess pipe and P/U proper space out pups below last full joint of tubing. P/U and M/U tubing hanger and install 12 ea. blast rings around pup joint below hanger body. Place 1 stop ring below blast rings once they were positioned onto pup, so as to prevent fluid erosion from incoming annulus fluids. RU I-wire through the tubing hanger. Land the tubing on the hanger. Tubing tail located at 6,356'. 06:45 - 07:30 0.75 BUNCO RUNCMP RD the rig floor and clear of all vendor tools. 07:30 - 09:00 1.50 BUNCO RUNCMP RU to reverse circulate the well. Reverse circulate 5 bbls of Printed: 12/5/2005 11:10:45 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-250 Common Well Name: L-250 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Date From - To Hours Task I' Code NPT 12/2/2005 07:30 - 09:00 I 1.501 RUNCOf~ Start: Rig Release: Rig Number: Phase RUNCMP 09:00 - 12:00 I 3.001 RUNCOHVP I I RUNCMP 12:00 - 17:00 ~ 5.00 RUNCOI~P ~ ~ RUNCMP 17:00 - 21:00 4.00 BOPSUFI P ~ ~ RUNCMP 21:00 - 00:00 ~ 3.001 BOPSUp P RUNCMP 12/3/2005 100:00 - 03:30 3.501 WHSUR P RUNCMP 03:30 - 05:30 ~ 2.00 RUNCON9P ~ RUNCMP 05:30 - 08:30 I 3.001 RUNCOMP I I RUNCMP 08:30 - 10:30 1 2.001 WHSUR I P I I RUNCMP 10/23/2005 12/3/2005 Page 22 of 22 Spud Date: 10124!2005 End: 12/3/2005 Description of Operations 9.2 corrosion inhibited brine chased with 160 bbls of clean brine -spotting the CI brine between the lower GLM and the packer - 3 bpm, 210 psi. Drop 1-7/8" ball and roller rod assmbly and allow to seat. Pressure up the inside of the tubing to 4,200 psi to set the Premier packer and then reduce the pressure to 3,500 psi - chart and hold for 30 minutes -good. Bleed the tubing pressure to 2,500 psi and then pressure up on the annulus to 3,500 psi -chart and hold for 30 minutes -good. Bleed off the annulus pressure and then the tubing pressure. Re-pressure up on the annulus and observe the DCK-2 shear at 2,350 psi. Install TWC with T-bar and test from below to 1,000 psi -good. Witness of the tubing and annulus pressure test was done by John Crisp of the AOGCC. Blow down all the surface lines and clean the rig of the MOBM. LD tools from the rig floor and pressure was the rig floor to remove MOBM. Remove the top rams, blind rams and the bottom rams from the BOPE. ND BOPE, riser and set back in the cellar. NU the adapter flange and tie in .with the I-wire. Test Adapter to 5,000 psi -good. Surface conductivity test of the 1-wire was good. Continue to NU the tree. Test to 5,000 psi -good. Pull TWC with lubricator. RU circulation lines and reverse circulate 90 bbls of corrosion inhibited brine. Blow down all surface lines. RU LRHOS. Freeze protect the well with 110 bbls of diesel pumped by LRHOS. Allow to u-tube in place.**** While finishing up with the freeze protection app. 1/2 gal. of diesel was released from a hose and leaked onto the rig floor. It was reported to Bill @ 5700.**** Install BPV with Lubricator and test from below to 1,000 psi - good. Install VR plugs in both tubing spool outlets. Rig released to Maintenance Q 1030 hours. Printed: 12/5/2005 11:10:45 AM / b~ +~.,~~~ t. ,w „. a~ ~. ~~ :~ ,,.,~ L-250PB1 Su Report gchlumberger Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: L-PAD / L-250 (NM-15 ) Wetl: L-250 Borehole: L-250PB1 UWVAPIY: 500292328170 Survey Name /Date: L-250PB1 /October 30, 2005 Tort /AHD ! DDI / ERD ratio: 62.424° / 1677.81 ft / 5.125 / 0.639 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaVlong: N 70 21 2.318, W 14919 28.397 Location Grid WE Y/X: N 5978285200 ftUS, E 583192.780 RUS Grid Convergence Angle: +0.63611620° Vertical Section Azimuth: 10.200° Vertical Section Origin: N 0.000 ft, E 0,000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 77.30 ft relative to MSL Sea Bed I Ground Level Elevation: 48.80 ft relative to MSL Magnetic Declination: 24.437° Total Field Strength: 57576.904 nT Magnetic Dip: 80.848° Declination Date: October 27, 2005 Magnetic Declination Model: BGGM 2005 North Reference: True North Total Corr Mag North -> True North: +24.437° 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 Sectlon Departure ft de de ft ft fl ft ft ft tt de 1100 it ftUS itUS K I t U.UU U.UU U.UU -//.3U U.UU U.UU U.UU U.UU U.UU U.UU U.UU by/tS"Ltlb.ZU 5ti31yZ./i7 N /U Y1 Y.3'I 25 W 14y "ly Z23. Sy/ First GYD GC SS 100.00 0.18 72.13 22.70 100.00 0.07 0.16 0.16 0.05 0.15 0.18 5978285.25 583192.93 N 70 21 2.318 W 149 19 28. 393 200.00 0.28 91.26 122.70 200.00 0.19 0.55 0.55 0.09 0.54 0.12 5978285.30 583193.32 N 70 21 2.319 W 149 19 28. 381 300.00 0.33 67.69 222.70 300.00 0.38 1.08 1.07 0.19 1.05 0.13 5978285.41 583193.83 N 70 21 2.320 W 149 19 28. 366 400.00 0.48 65.03 322.70 400.00 0.77 1.79 1.77 0.48 1.70 0.15 5978285.70 583194.47 N 70 21 2.323 W 149 19 28. 347 500.00 0.38 60.50 422.69 499.99 1.23 2.54 2.51 0.82 2.37 0.11 5978286.05 563195.14 N 70 21 2.326 W 149 19 28. 328 600.00 4.63 0.90 522.58 599.88 5.42 6.78 5.71 5.02 2.72 4.45 5978290.25 583195.44 N 70 21 2.367 W 149 19 28. 317 700.00 7.22 2.14 622.04 699.34 15.63 17.10 15.63 15.34 3.02 2.59 5978300.57 583195.63 N 70 21 2.469 W 149 19 28. 309 800.00 9.47 358.78 720.97 798.27 29.92 31.61 30.00 29.85 3.08 2.30 5978315.07 583195.53 N 70 21 2.611 W 149 19 28. 307 900.00 10.55 0.97 819.45 896.75 47.02 48.99 47.32 47.22 3.06 1.14 5978332.45 583195.31 N 70 21 2.782 W 149 19 28. 308 1000.00 12.85 1.98 917.36 994.66 67.06 69.27 67.59 67.49 3.60 2.31 5978352.72 583195.63 N 70 21 2.982 W 149 19 2 1100.00 18.01 1.78 1013.73 1091.03 93.38 95.86 94.18 94.08 4.46 5.16 5978379.31 583196.20 N 70 21 3.243 W 149 19 1200.00 21.99 2.92 1107.68 1184.98 127.26 130.06 128.38 128.24 5.90 4.00 5978419.49 583197.25 N 70 21 3.579 W 149 19 2 . 1300.00 25.18 3.83 1199.31 1276.61 166.98 170.06 168.38 168.17 8.27 3.21 5978453.44 583199.18 N 70 21 3.972 W 149 19 28. 155 1400.00 29.78 4.66 1288.01 1365.31 212.87 216.19 214.50 214.18 11.71 4.62 5978499.47 583202.11 N 70 21 4.424 W 149 19 28. 055 Last GYD GC SS 1500.00 34.96 4.69 1372.44 1449.74 266.14 269.71 268.00 267.52 16.08 5.18 5978552.85 583205,88 N 70 21 4.949 W 149 19 27. 927 First MWD+IFR+MS 1596.82 41.90 6.11 1448.24 1525.54 326.07 329.85 328.11 327.38 21.79 7.23 5978612.78 583210.93 N 70 21 5.538 W 149 19 27. 760 1693.87 42.21 6.32 1520.30 1597.60 390.92 394.86 393.07 392.01 28.83 0.35 5978677.47 583217.25 N 70 21 6.173 W 149 19 27. 554 1786.66 44.42 5.35 1587.81 1665.11 454.38 458.51 456.70 455.33 35.29 2.49 5978740.85 583223.01 N 70 21 6.796 W 149 19 27. 365 1879.45 45.17 6.07 1653.66 1730.96 519.56 523.89 522.06 520.38 41.80 0.98 5978805.97 583228.79 N 70 21 7.436 W 149 19 27. 175 1972.65 48.33 6.03 1717.51 1794.81 587.26 591.76 589.91 587.88 46.95 3.39 5978873.53 583235.20 N 70 21 8.099 W 149 19 26. 966 2066.16 51.49 5.05 1777.72 1855.02 658.55 663.29 661.44 659.08 55.84 3.47 5978944.79 583241.30 N 70 21 8.800 W 149 19 26 .765 2161.01 53.00 3.95 1835.79 1913.09 733.16 738.28 736.42 733.83 61.72 1.84 5979019.60 583246.34 N 70 21 9.535 W 149 19 26 .593 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-250 (NM-15)\L-250\L-250P81\L-250P61 Generated 11/8/2005 11:08 AM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k de de k ft tt ft k ft ft de /100 k ftUS ftUS LGJJ.~Y JL.IV J./4 101..71 IyOtl.Ll OVO./O OIL.J~ OIU.40 0Ul./4 00.00 U.J/ oa/avaJ.oo 2346.11 52.99 3.65 1947.58 2024.88 879.77 885.81 883.93 881.04 71.42 0.32 5979166.90 2439.91 52.53 2.98 2004.35 2081.65 953.90 960.49 958.59 955.59 75.74 0.75 5979241.48 2533.07 52.28 3.06 2061.18 2138.48 1027.14 1034.30 1032.38 1029.30 79.63 0.28 5979315.23 2627.31 51.52 2.24 2119.33 2196.63 1100.65 1108.46 1106.51 1103.38 83.06 1.06 5979389.33 2720.18 51.47 3.41 2177.15 2254.45 1172.73 1181.13 1179.16 1175.97 86.64 0.99 5979461.95 2813.86 52.66 3.82 2234.74 2312.04 1246.12 1255.02 1253.04 1249.71 91.30 1.32 5979535.73 2906.66 53.08 3.54 2290.76 2368.06 1319.63 1329.01 1327.02 1323.54 96.05 0.51 5979609.60 3000.78 53.37 3.51 2347.11 2424.41 1394.51 1404.39 1402.41 1398.79 100.68 0.31 5979684,89 3094.90 53.37 3.12 2403.26 2480.56 1469.50 1479.93 1477.93 1474.19 105.05 0.33 5979760.33 3187.58 53.76 5.14 2458.31 2535.61 1543.64 1554.49 1552.49 1548.56 110.42 1.80 5979834.74 Last MWD+IFR+MS 3281.49 54.16 5.20 2513.56 2590.86 1619.28 1630.42 1628.41 1624.18 117.27 0.43 5979910.43 TD (Projected) 3340.00 54.00 5.20 2547.89 2625.19 1666.48 1677.81 1675.79 1671.37 121.56 0.27 5979957.66 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata - gyro sing le shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD +IFR + MS - (In-field referenced MWD with mult-station analys is and correction applied in post-pro cessing. Assumes a BHA sag correction is appli ed to enhance inclination accuracy. ) Legal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 2563 FSL 3721 FEL S34 T12N R11 E UM 5978285.20 583192.78 BHL : 42 34 FSL 3597 FEL S34 T12N R11 E UM 5979957.66 583295.77 00JLOU.4`J IV /U CI lU.LOL VV 14y ly Zb.44i3 583254.41 N 70 21 10.983 W 149 19 26.309 583257.90 N 70 21 11.716 W 149 19 26.183 583260.97 N 70 21 12.441 W 149 19 26.069 583263.58 N 70 21 13.169 W 149 19 25.969 583266.35 N 70 21 13.883 W 149 19 25.864 583270.19 N 70 21 14.608 W 149 19 25.728 583274.12 N 70 21 15.335 W 149 19 25.589 583277.92 N 70 21 16.075 W 149 19 25.454 583281.45 N 70 21 16.816 W 149 19 25.326 583286.00 N 70 21 17.548 W 149 19 583292.00 N 70 21 18.291 W 149 19 583295.77 N 70 21 18.755 W 149 19 24.843 • SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-250 (NM-15 )\L-250\L-250PB11L-250P61 Generated 11/8/2005 11:08 AM Page 2 of 2 ~~ +~~~ ~~; L-250 Su Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: L-PAD I L-250 (NM-15 ) Well: L-250 Borehole: L-250 UWIIAPI#: 500292328100 Survey Name 1 Date: L-250 I November 9, 2005 Tort 1 AHD 1 DDI I ERD ratio: 255.476° 17009.30 ft 16.566 11.570 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet location LaULong: N 70 212.318, W 14919 28.397 Location Grid NIE YIX: N 5978285.200 ftUS, E 583192.780 ftUS Grid Convergence Angle: 10.63611620° Schlumberger ort Survey 1 DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 10.200° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 77.30 ft r~ative to MSL Sea Bed 1 Ground Level Elevation: 48.80 ft relative to MSL Magnetic Declination: 24.429° Total Field Strength: 57577.085 nT Magnetic Dip: 80.848° Declination Date: November 04, 2005 Magnetic Declination Model: BGGM 2005 North Reference: TNe North Total Corr Mag North -> True North: +24.429° 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 ft de d ft ft ft ft ft ft ft de 1100 ft ftUS ftUS Rl E U.UU U.UU U.UU -~ i.su V.vu u.uu u.vu u.uu u.w u.vu u.vv JA/VLV:l.LV First GYD GC SS 100.00 0.18 72.13 22.70 100.00 0.07 0.16 0.16 0.05 0.15 0.18 5978285.25 200.00 0.28 91.26 122.70 200.00 0.19 0.55 0.55 0.09 0.54 0.12 5978285.30 300.00 0.33 67.69 222.70 300.00 0.38 1.08 1.07 0.19 1.05 0.13 5978285.41 400.00 0.48 65.03 322.70 400.00 0.77 1.79 1.77 0.48 1.70 0.15 5978285.70 500.00 0.38 60.50 422.69 499.99 1.23 2.54 2.51 0.82 2.37 0.11 5978286.05 600.00 4.63 0.90 522.58 599.88 5.42 6.78 5.71 5.02 2.72 4.45 5978290.25 700.00 7.22 2.14 622.04 699.34 15.63 17.10 15.63 15.34 3.02 2.59 5978300.57 800.00 9.47 358.78 720.97 798.27 29.92 31.61 30.00 29.85 3.08 2.30 5978315.07 900.00 10.55 0.97 819.45 896.75 47.02 48.99 47.32 47.22 3.06 1.14 5978332.45 1000.00 12.85 1.98 917.36 994.66 67.06 69.27 67.59 67.49 3.60 2.31 5978352.72 Tie-In Survey 1100.00 18.01 1.78 1013.73 1091.03 93.38 95.86 94.18 94.08 4.46 5.16 5978379.31 First MWD iFR MS 1142.48 17.42 2.28 1054.19 1131.49 106.17 108.79 107.11 106.99 4.92 1.43 5978392.23 _ _ 1238.55 23.54 359.82 1144.15 1221.45 139.32 142.38 140.69 140.58 5.43 6.43 5978425.82 1333.71 28.06 359.38 1229.80 1307.10 180.02 183.79 182.06 181.98 5.13 4.75 5978467.21 1426.70 33.77 1.48 1309.55 1386.85 227.09 231.54 229.80 229.73 5.56 6.25 5978514.96 1521.00 39.49 3.27 1385.20 1462.50 282.80 287.78 286.03 285.92 7.95 6.17 5978571.16 1615.30 41.59 2.81 1456.86 1534.16 343.62 349.06 347.30 347.12 11.20 2.25 5978632.39 1709.51 43.47 4.55 1526.28 1603.58 406.88 412.74 410.95 410.66 15.30 2.35 5978695.97 1803.55 48.15 5.70 1591.81 1669.11 474.03 480.15 478.28 477.80 21.35 5.05 5978763.16 1897.74 50.17 6.38 1653.41 1730.71 545.09 551.41 549.41 548.66 28.85 2.21 5978834.09 1992.59 50.39 5.96 1714.02 1791.32 617.87 624.36 622.27 621.19 36.69 0.41 5978906.70 2087.57 50.71 5.82 1774.37 1851.67 691.00 697.70 695.55 694.14 44.22 0.36 5978979.73 2182.43 50.72 6.03 1834.43 1911.73 764.22 771.13 768.92 767.17 51.80 0.17 5979052.83 J V J 1 .7 L. I V I Y I V L I G. J I V ~' - - 583192.93 N 70 21 2.318 W 149 19 28.393 583193.32 N 70 21 2.319 W 14919 28.381 583193.83 N 70 21 2.320 W 14919 28.366 583194.47 N 70 21 2.323 W 149 19 28.347 583195.14 N 70 21 2.326 W 149 19 28.328 583195.44 N 70 21 2.367 W 149 19 28.317 583195.63 N 70 21 2.469 W 149 19 28.309 583195.53 N 70 21 2.611 W 149 19 28.307 583195.31 N 70 21 2.782 W 14919 28.308 583195.63 N 70 21 2.982 W 14919 28.292 583196.20 N 70 21 3.243 W 149 19 2 583196.51 N 70 21 3.370 W 149 19 2 583196.65 N 70 21 3.700 W 149 19 28. 8 583195.89 N 70 21 4.108 W 149 19 28.247 583195.79 N 70 21 4.577 W 149 19 28.234 583197.55 N 70 21 5.130 W 14919 28.165 583200.12 N 70 21 5.732 W 149 19 28.070 583203.52 N 70 21 6.357 W 149 19 27.950 583208.82 N 70 21 7.017 W 149 19 27.773 583215.54 N 70 21 7.714 W 149 19 27.554 583222.57 N 70 21 8.427 W 149 19 27.324 583229.29 N 70 21 9.145 W 14919 27.105 583236.05 N 70 21 9.863 W 149 19 26.883 SurveyEditor Ver SP 1.0 Bld{ doc40x 56) L-250 (NM-15)\L-250\L-250\L-250 Generated 11/16/2005 5:25 PM Page 1 of 4 2278.30 50.98 6.67 1894.96 1972.26 838.40 845.47 843.20 841.06 60.02 0.58 5979126.80 583243.46 N 70 21 10:590 W 14919 26.643 2371.54 50.42 6.76 1954.02 2031.32 910.42 917.63 915.29 912.72 68.46 0.61 5979198.54 583251.10 N 70 21 11.294 W 149 19 26.396 2466.47 50.95 6.67 2014.16 2091.46 983.73 991.07 988.67 985.66 77.05 0.56 5979271.56 583258.87 N 70 21 12.012 W 149 19 26.145 2561.66 51.25 6.75 2073.94 2151.24 1057.67 1065.15 1062.70 1059.24 85.70 0.32 5979345.22 583266.71 N 70 21 12.735 W 149 19 25.892 2655.99 50.76 6.72 2133.30 2210.60 1130.85 1138.46 1135.96 1132.04 94.30 0.52 5979418.11 583274.50 N 70 21 13.451 W 149 19 25.641 2750.38 51.58 6.48 2192.48 2269.78 1204.24 1211.99 1209.46 1205.09 102.75 0.89 5979491.24 583282.14 N 70 21 14.170 W 149 19 25.394 2842.88 54.02 5.92 2248.40 2325.70 1277.73 1285.67 1283.11 1278.33 110.70 2.68 5979564.56 583289.27 N 70 21 14.890 W 149 19 25.161 2938.01 54.48 5.76 2303.98 2381.28 1354.71 1362.87 1360.31 1355.13 118.56 0.50 5979641.44 583296.27 N 70 21 15.645 W 149 19 24.931 3030.50 54.05 5.73 2358.00 2435.30 1429.56 1437.95 1435.38 1429.83 126.07 0.47 5979716.21 583302.96 N 70 21 16.380 W 149 19 24.712 3124.67 53.78 5.75 2413.46 2490.76 1505.43 1514.05 1511.48 1505.55 133.68 0.29 5979792.00 583309.73 N 70 21 17.125 W 14919 24.489 3217.96 53.69 5.83 2468.65 2545.95 1580.43 1589.27 1586.69 1580.39 141.27 0.12 5979866.91 583316.49 N 70 21 17.861 W 149 19 24.267 3304.80 54.42 5.76 2519.62 2596.92 1650.52 1659.57 1656.99 1650.33 148.37 0.84 5979936.92 583322.81 N 70 21 18.549 W 149 19 24.060 3377 66 54 50 7.88 2561.98 2639.28 1709.70 1718.86 1716.25 1709.19 155.41 2.37 5979995.85 583329.19 N 70 21 19.127 W 149 19 23.854 . 3460.47 . 55.12 11.54 2609.71 2687.01 1777.36 1786.53 1783.70 1775.88 166.83 3.69 5980062.66 583339.87 N 70 21 19.783 W 149 19 2~ 3553.53 54.96 16.27 2663.05 2740.35 1853.43 1862.78 1859.12 1849.88 185.15 4.17 5980136.85 583357.36 N 70 21 20.511 W 14919 2 3646.38 54.07 21.14 2716.97 2794.27 1928.17 1938.37 1932.83 1921.46 209.36 4.38 5980208.68 583380.78 N 70 21 21.215 W 149 19 22.277 3739.41 53.06 24.30 2772.23 2849.53 2001.22 2013.21 2004.69 1990.49 238.25 2.94 5980278.02 583408.90 N 70 21 21.894 W 149 19 21.432 3833.63 53.64 25.65 2828.48 2905.78 2074.31 2088.80 2076.66 2059.01 270.17 1.30 5980346.88 583440.05 N 70 21 22.568 W 149 19 20.499 3926.05 51.52 27.14 2884.63 2961.93 2144.79 2162.19 2146.22 2124.75 302.78 2.63 5980412.98 583471.93 N 70 21 23.214 W 149 19 19.546 4019.45 51.26 27.27 2942.92 3020.22 2214.58 2235.18 2215.32 2189.66 336.15 0.30 5980478.25 583504.57 N 70 21 23.853 W 149 19 18.570 4112.37 51.19 26.85 3001.11 3078.41 2283.91 2307.62 2284.19 2254.17 369.11 0.36 5980543.12 583536.80 N 70 21 24.487 W 14919 17.607 4204.46 51.42 26.73 3058.68 3135.98 2352.79 2379.49 2352.84 2318.33 401.50 0.27 5980607.63 583568.48 N 70 21 25.118 W 149 19 16.659 4297.65 51.71 29.80 3116.62 3193.92 2422.18 2452.48 2422.19 2382.61 436.06 2.60 5980672.28 583602.33 N 70 21 25.750 W 149 19 15.649 4392.61 51.45 30.78 3175.63 3252.93 2492.05 2526.88 2492.26 2446.85 473.59 0.85 5980736.93 583639.13 N 70 21 26.382 W 149 19 14.552 4485.21 53.60 29.48 3231.97 3309.27 2561.13 2600.36 2561.79 2510.41 510.46 2.58 5980800.89 583675.30 N 70 21 27.007 W 14919 13.474 4578.62 54.11 29.11 3287.06 3364.36 2632.41 2675.79 2633.71 2576.20 547.37 0.63 5980867.07 583711.47 N 70 21 27.654 W 14919 12.394 4671.65 53.80 29.11 3341.80 3419.10 2703.57 2751.01 2705.69 2641.92 583.96 0.33 5980933.19 583747.33 N 70 21 28.300 W 149 19 11.324 4764.31 53.21 29.31 3396.91 3474.21 2774.00 2825.50 2777.10 2706.93 620.32 0.66 5980998.60 583782.95 N 70 21 28.940 W 149 19 10.262 4857.56 52.79 29.02 3453.03 3530.33 2844.43 2899.98 2848.67 2771.96 656.61 0.51 5981064.02 583818.51 N 70 21 29.579 W 149 19 9.200 4952.03 52.51 29.57 3510.35 3587.65 2915.40 2975.07 2920.94 2837.46 693.35 0.55 5981129.91 583854.53 N 70 21 30.223 W 149 19 8.126 5045.33 51.88 29.69 3567.54 3644.84 2984.92 3048.79 2991.91 2901.54 729.80 0.68 5981194.39 583890.26 N 70 21 30.854 W 149 19 7.060 5138.73 54.44 29.12 3623.53 3700.83 3055.50 3123.53 3064.07 2966.65 766.49 2.78 5981259.90 583926.22 N 70 21 31.494 W 149 19 5230.90 54.90 28.89 3676.83 3754.13 3126.68 3198.73 3136.92 3032.42 802.95 0.54 5981326.06 583961.94 N 70 21 32.141 W 149 19 5324.74 54.48 28.53 3731.07 3808.37 3199.30 3275.31 3211.32 3099.58 839.74 0.55 5981393.62 583997.98 N 70 21 32.801 W 149 19 3.845 5417.84 53.82 28.79 3785.60 3862.90 3270.88 3350.77 3284.74 3165.80 875.93 0.74 5981460.23 584033.43 N 70 21 33.452 W 149 19 2.787 5511.05 55.75 28.85 3839.35 3916.65 3343.04 3426.92 3358.87 3232.51 912.64 2.07 5981527.34 584069.39 N 70 21 34.109 W 149 19 1.714 5603.61 57.96 28.05 3889.95 3967.25 3416.64 3504.41 3434.52 3300.65 949.55 2.49 5981595.88 584105.54 N 70 21 34.779 W 149 19 0.634 5697.17 60.88 28.88 3937.54 4014.84 3493.11 3584.95 3513.22 3371.45 987.94 3.21 5981667.09 584143.14 N 70 21 35.475 W 149 18 59.511 5791.86 63.76 30.59 3981.53 4058.83 3572.12 3668.79 3594.82 3444.24 1029.54 3.44 5981740.33 584183.93 N 70 21 36.191 W 149 18 58.295 5884.27 66.66 32.01 4020.27 4097.57 3650.38 3752.68 3676.03 3515.91 1073.13 3.43 5981812.47 584226.71 N 70 21 36.895 W 14918 57.020 5977.84 70.06 33.79 4054.78 4132.08 3730.59 3839.64 3759.72 3588.91 1120.38 4.04 5981885.99 584273.14 N 70 21 37.613 W 149 18 55.638 6071.32 73.16 35.09 4084.27 4161.57 3811.46 3928.33 3844.58 3662.05 1170.54 3.57 5981959.68 584322.49 N 70 21 38.333 W 149 1854.171 6164.43 75.10 34.05 4109.73 4187.03 3893.04 4017.89 3930.38 3735.80 1221.36 2.34 5982033.97 584372.47 N 70 21 39.058 W 14918 52.685 6257.98 76.40 29.96 4132.76 4210.06 3977.20 4108.56 4018.44 3812.67 1269.39 4.46 5982111.37 584419.65 N 70 21 39.814 W 14918 51.280 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-250 (NM-15)\L-250\L-250\L-250 Generated 11/16/2005 5:25 PM Page 2 of 4 6351.55 74.80 26.84 4156.04 4233.34 4063.28 4199.18 4107.71 3892.38 1312.50 3.65 5982191.54 584461.86 N 70 21 40.598 W 149 18 50.019 6443.94 73.29 21.48 4181.45 4258.75 4149.45 4288.01 4196.09 3973.38 1348.85 5.81 5982272.94 584497.31 N 70 21 41.394 W 149 18 48.956 6538.08 74.98 15.33 4207.21 4284.51 4239.03 4378.55 4286.59 4059.26 1377.41 6.53 5982359.12 584524.91 N 70 21 42.239 W 149 18 48.120 6630.38 77.85 10.78 4228.90 4306.20 4328.60 4468.26 4375.84 4146.63 1397.64 5.71 5982446.70 584544.17 N 70 21 43.098 W 149 18 47.528 6723.78 77.89 11.17 4248.52 4325.82 4419.90 4559.57 4466.36 4236.28 1415.03 0.41 5982536.52 584560.56 N 70 21 43.980 W 149 18 47.019 6817.07 77.35 9.10 4268.53 4345.83 4511.02 4650.69 4556.53 4325.97 1431.06 2.24 5982626.38 584575.60 N 70 21 44.862 W 14918 46.550 6910.48 78.03 2.85 4288.46 4365.76 4601.98 4741.95 4645.68 4416.69 1440.55 6.58 5982717.19 584584.08 N 70 21 45.754 W 149 18 46.272 7004.98 80.97 358.06 4305.69 4382.99 4693.52 4834.85 4734.28 4509.56 1441.27 5.87 5982810.06 584583.77 N 70 21 46.667 W 14918 46.250 7097.29 81.98 356.52 4319.37 4396.67 4782.50 4926.14 4819.93 4600.75 1436.95 1.98 5982901.18 584578.44 N 70 21 47.564 W 149 18 46.376 7190.18 82.73 355.81 4331.73 4409.03 4871.81 5018.21 4905.88 4692.60 1430.79 1.11 5982992.96 584571.26 N 70 21 48.468 W 149 18 46.556 7284.22 83.53 354.98 4342.98 4420.28 4962.07 5111.57 4992.83 4785.66 1423.30 1.22 5983085.92 584562.73 N 70 21 49.383 W 149 18 46.774 7356.67 86.29 354.30 4349.41 4426.71 5031.59 5183.73 5059.84 4857.51 1416.56 3.92 5983157.67 584555.19 N 70 21 50.089 W 14918 46.971 7427.46 88.49 353.07 4352.63 4429.93 5099.38 5254.44 5125.21 4927.79 1408.78 3.56 5983227.86 584546.64 N 70 21 50.781 W 149 18 47.1 8 7458.64 88.51 352.97 4353.45 4430.75 5129.16 5285.61 5153.93 4958.73 1404.99 0.33 5983258.75 584542.50 N 70 21 51.085 W 149 18 4 7490.33 90.95 354.86 4353.60 4430.90 5159.57 5317.30 5183.34 4990.23 1401.63 9.74 5983290.22 584538.80 N 70 21 51.395 W 14918 4 7521.41 90.58 355.82 4353.18 4430.48 5189.61 5348.37 5212.49 5021.21 1399.11 3.31 5983321.16 584535.93 N 70 21 51.699 W 149 18 47.480 7551.52 91.13 357.92 4352.73 4430.03 5218.90 5378.48 5241.01 5051.27 1397.46 7.21 5983351.19 584533.95 N 70 21 51.995 W 149 18 47.528 7582.86 92.05 358.05 4351.86 4429.16 5249.52 5409.81 5270.90 5082.58 1396.36 2.96 5983382.48 584532.50 N 70 21 52.303 W 14918 47.560 7614.56 91.80 358.31 4350.80 4428.10 5280.51 5441.49 5301.18 5114.24 1395.36 1.14 5983414.13 584531.14 N 70 21 52.614 W 14918 47.590 7645.50 90.43 356.18 4350.19 4427.49 5310.65 5472.42 5330.60 5145.14 1393.87 8.18 5983445.01 584529.32 N 70 21 52.918 W 149 18 47.633 7677.09 92.40 356.12 4349.41 4426.71 5341.29 5504.00 5360.47 5176.64 1391.75 6.24 5983476.49 584526.85 N 70 21 53.228 W 149 18 47.695 7708.37 92.13 356.22 4348.18 4425.48 5371.61 5535.26 5390.05 5207.83 1389.66 0.92 5983507.65 584524.41 N 70 21 53.535 W 149 18 47.756 7739.65 91.92 355.95 4347.07 4424.37 5401.93 5566.52 5419.64 5239.02 1387.53 1.09 5983538.80 584521.93 N 70 21 53.841 W 149 18 47.818 7770.79 92.56 355.55 4345.86 4423.16 5432.06 5597.63 5449.06 5270.05 1385.22 2.42 5983569.80 584519.28 N 70 21 54.147 W 14918 47.885 7803.87 92.68 355.20 4344.34 4421.64 5464.01 5630.68 5480.25 5302.99 1382.56 1.12 5983602.71 584516.25 N 70 21 54.471 W 149 18 47.963 7833.54 92.81 354.89 4342.92 4420.22 5492.61 5660.32 5508.18 5332.51 1380.00 1.13 5983632.20 584513.36 N 70 21 54.761 W 14918 48.038 7864.49 92.06 354.30 4341.61 4418.91 5522.39 5691.24 5537.26 5363.30 1377.08 3.08 5983662.95 584510.11 N 70 21 55.064 W 149 18 48.123 7895.44 91.97 354.46 4340.52 4417.82 5552.15 5722.17 5566.34 5394.08 1374.05 0.59 5983693.69 584506.74 N 70 21 55.367 W 14918 48.211 7926.91 92.49 355.05 4339.30 4416.60 5582.46 5753.61 5595.98 5425.39 1371.18 2.50 5983724.97 584503.52 N 70 21 55.674 W 149 18 48.295 7957.62 92.77 354.68 4337.89 4415.19 5612.05 5784.29 5624.94 5455.95 1368.43 1.51 5983755.49 584500.43 N 70 21 55.975 W 149 18 48.375 7988.90 90.76 354.14 4336.92 4414.22 5642.13 5815.56 5654.39 5487.06 1365.39 6.65 5983786.56 584497.04 N 70 21 56.281 W 14918 48.464 8019.19 88.51 353.65 4337.12 4414.42 5671.20 5845.84 5682.85 5517.18 1362.17 7.60 5983816.64 584493.49 N 70 21 56.577 W 14918 48 8050.10 86.35 350.97 4338.50 4415.80 5700.58 5876.72 5711.57 5547.77 1358.04 11.13 5983847.18 584489.02 N 70 21 56.878 W 149 18 4 8081.64 86.25 350.71 4340.54 4417.84 5730.28 5908.19 5740.58 5578.85 1353.03 0.88 5983878.20 584483.66 N 70 21 57.184 W 149 18 48.825 8113.13 86.23 351.01 4342.60 4419.90 5759.93 5939.62 5769.56 5609.87 1348.03 0.95 5983909.16 584478.33 N 70 21 57.489 W 149 18 48.971 8144.17 86.03 351.23 4344.70 4422.00 5789.19 5970.59 5798.21 5640.47 1343.25 0.96 5983939.70 584473.21 N 70 21 57.790 W 149 18 49.111 8175.64 86.13 350.58 4346.85 4424.15 5818.83 6001.98 5827.23 5671.47 1338.29 2.09 5983970.64 584467.90 N 70 21 58.095 W 14918 49.256 8207.31 90.74 355.71 4347.71 4425.01 5849.07 6033.63 5856.94 5702.88 1334.52 21.77 5984002.01 584463.78 N 70 21 58.404 W 149 18 49.366 8237.02 90.67 355.79 4347.35 4424.65 5877.84 6063.34 5885.30 5732.51 1332.32 0.36 5984031.60 584461.25 N 70 21 58.695 W 149 18 49.430 8268.31 88.79 355.43 4347.50 4424.80 5908.12 6094.63 5915.15 5763.70 1329.92 6.12 5984062.77 584458.51 N 70 21 59.002 W 14918 49.500 8299.41 87.59 355.12 4348.48 4425.78 5938.16 6125.71 5944.77 5794.68 1327.36 3.99 5984093.72 584455.61 N 70 21 59.306 W 149 18 49.575 8331.10 89.10 355.55 4349.39 4426.69 5968.77 6157.39 5974.97 5826.25 1324.78 4.95 5984125.25 584452.68 N 70 21 59.617 W 14918 49.650 8361.35 88.88 356.43 4349.93 4427.23 5998.09 6187.63 6003.93 5856.42 1322.67 3.00 5984155.39 584450.23 N 70 21 59.914 W 14918 49.712 8392.28 89.37 355.64 4350.40 4427.70 6028.08 6218.56 6033.56 5887.28 1320.53 3.01 5984186.22 584447.75 N 70 22 0.217 W 149 18 49.774 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-250 (NM-15)\L-250\L-250\L-250 Generated 11/16/2005 5:25 PM Page 3 of 4 8423.17 89.04 357.34 4350.83 4428.13 6058.08 6249.45 6063.23 5918.10 1318.64 5.61 5984217.02 8454.96 89.47 356.83 4351.24 4428.54 6089.04 6281.23 6093.87 5949.85 1317.02 2.10 5984248.74 8485.52 86.91 358.02 4352.21 4429.51 6118.83 6311.78 6123.37 5980.36 1315.65 9.24 5984279.23 8515.88 84.77 356.03 4354.41 4431.71 6148.31 6342.05 6152.57 6010.60 1314.08 9.61 5984309.45 8546.40 84.55 355.97 4357.25 4434.55 6177.77 6372.44 6181.73 6040.91 1311.96 0.75 5984339.73 8577.84 85.48 356.57 4359.98 4437.28 6208.17 6403.76 6211.85 6072.16 1309.92 3.52 5984370.96 8609.40 89.14 355.97 4361.46 4438.76 6238.76 6435.28 6242.17 6103.62 1307.87 11.75 5984402.39 8640.74 88.92 355.29 4361.99 4439.29 6269.09 6466.62 6272.23 6134.86 1305.48 2.28 5984433.60 8671.05 88.40 353.10 4362.70 4440.00 6298.21 6496.92 6301.08 6165.01 1302.42 7.42 5984463.70 8703.09 88.29 350.37 4363.63 4440.93 .6328.59 6528.95 6331.14 6196.70 1297.82 8.52 5984495.34 8734.21 89.02 349.48 4364.36 4441.66 6357.77 6560.06 6360.02 6227.33 1292.37 3.70 5984525.91 8764.25 89.35 347.81 4364.78 4442.08 6385.70 6590.09 6387.66 6256.78 1286.46 5.67 5984555.28 8795.14 91.67 349.30 4364.51 4441.81 6414.41 6620.98 6416.09 6287.05 1280.33 8.93. 5984585.48 8826.24 92.57 352.60 4363.36 4440.66 6443.75 6652.06 6445.20 6317.74 1275.44 10.99 5984616.11 8856.95 92.91 356.18 4361.89 4439.19 6473.26 6682.73 6474.53 6348.26 1272.44 11.70 5984646.60 8888.27 91.58 359.84 4360.66 4437.96 6503.84 6714.03 6504.98 6379.53 1271.36 12.43 5984677.85 8920.38 91.09 1.51 4359.92 4437.22 6535.50 6746.13 6536.53 6411.63 1271.74 5.42 5984709.95 8950.87 90.71 0.83 4359.44 4436.74 6565.61 6776.62 6566.55 6442.11 1272.36 2.55 5984740.43 8981.77 90.72 0.70 4359.05 4436.35 6596.09 6807.51 6596.95 6473.00 1272.77 0.42 5984771.32 9013.02 88.56 359.99 4359.25 4436.55 6626.87 6838.76 6627.64 6504.25 1272.96 7.28 5984802.57 9043.88 83.78 358.64 4361.31 4438.61 6657.10 6869.54 6657.78 6535.03 1272.59 16.09 5984833.34 9074.98 80.33 358.22 4365.61 4442.91 6687.25 6900.34 6687.84 6565.81 1271.75 11.17 5984864.11 9105.05 78.86 357.84 4371.04 4448.34 6716.16 6929.92 6716.67 6595.37 1270.73 5.04 5984893.65 Last MWD+IFR+MS 9137.02 78.67 357.71 4377.27 4454.57 6746.78 6961.27 6747.21 6626.70 1269.52 0.72 5984924.96 TD (Projected) 9186.00 78.67 357.71 4386.89 4464.19 6793.67 7009.30 6793.99 6674.69 1267.60 0.00 5984972.92 Survey Type: Definitive Survey NOTES: GYD GC SS - (Gyrodata -gyro single shots -- Gyrodata gyro orientation surveys. Not to be run above 70 degrees inclination. ) MWD +IFR + MS - (In-field referenced MWD with mult~tation analysis and correction applied in post-processing. Assumes a BHA sag correction is appl ied to enhance inclination accuracy. ) Legal D escrlotion: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 2563 FSL 3721 FEL S34 T12N R11 E UM 5978285.20 583192.78 BHL : 4234 FSL 3597 FEL S34 T12N R11 E UM 5979957.66 583295.77 584445.52 584443.55 584441.84 584439.93 584437.48 584435.09 584432.69 584429.96 584426.56 584421.60 584415.82 584409.58 584403.12 584397.89 584394.55 584393.12 584393.14 584393.43 584393.50 584393.34 584392.63 584391.44 584390.10 584388.53 584386.08 N 70 22 0.520 W 149 18 49.829 N 70 22 0.833 W 149 18 49.876 N 70 22 1.133 W 14918 49.916 N 70 22 1.430 W 149 18 49.962 N 70 22 1.728 W 149 18 50.024 N 70 22 2.036 W 149 1850.083 N 70 22 2.345 W 149 18 50.143 N 70 22 2.652 W 149 18 50.213 N 70 22 2.949 W 149 18 50.302 N 70 22 3.260 W 14918 50.437 N 70 22 3.562 W 149 18 50.596 N 70 22 3.851 W 149 18 50.769 N 70 22 4.149 W 149 18 50.948 N 70 22 4.451 W 14918 5~ N 70 22 4.751 W 14918 5 N 70 22 5.058 W 149 18 51.210 N 70 22 5.374 W 149 18 51.198 N 70 22 5.674 W 149 18 51.180 N 70 22 5.978 W 14918 51.168 N 70 22 6.285 W 149 18 51.162 N 70 22 6.588 W 149 18 51.173 N 70 22 6.891 W 149 18 51.197 N 70 22 7.181 W 14918 51.227 N 70 22 7.489 W 149 18 51.262 N 70 22 7.961 W 149 18 51.318 • SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-250 (NM-15)\L-250\L-250\L-250 Generated 11/16/2005 5:25 PM Page 4 of 4 I TRFF = FMC 4-1/R" 5M WELLHEAD = FMC GEN 5 ACTUATOR = KB. ELEV -` 77.30' BF. ELEV - 48.8' KOP = 700 Max Angle=L1 100 @ 6899' Datum MD = xxxx' Datum TV D - -xxxx' SS ~20" CONDUCTOR ~ 109' 10-3/4" CSG. 45.5 L-80, ID = 9.95" 3354' ~ Minimum ID = 3.688" @ 6386' and 6601 in the LEM ~ ~ 4.5"PHOENIX DSCHRGE-PRESS SUB,ID = 3.948" ~-i 6180' (4.5" PHNO< MULTI-PRESS SENSOR, ID = 3.994" ~ 6215' RA TAG 6337' 7-5/8" x 5.5" BKR ZXP PACKER, ID = 4.95" 6-, 349' ~. ~ ~ BKR HUGHES HOOK HGR, ID = 5.62" ~-~ 6386' ~ 7-5/8" x 5.5" BKR ZXP PACKER, ID = 5.75" ~-~ 6544' RA TAG -1 6547' BKR HUGHES HOOK HGR, ID = 5.62" --~66Q1' 17-5l8" x 5.5" BKR ZXP PACKER, ID = 4.82" 1~ 6693' PERFORATION SUMMARY REF LOG : ANGLEATTOP PERF: 92° @ 8262' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" SCRN NB L2 8262-12174 O 11/30/05 4" SCRN NB L1 6932-11191 O 11/14/05 4 1/2" SLTD QA 7523-8460 O 11/09/05 L-250 L-250 L1 L-250 L2 S~info: 1000' ~ 10 3/4" TAM Port Collar 2669' 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3148 2505 54 KBG-2 DOME BK 16 12/08/05 3 4824 3510 53 KBG-2 DOME BK 16 12/08(05 2 5961 4126 68 KBG-2 DMY BK 0 12/02/05 1 6071 4161 73 KBG-2 SO BK 22 12!08105 6191' 4.5" Baker CMD-BX Sliding Sleeve, 3.812" ID 6240' 7.625" x 4.5" Premier Packer 3.87" ID .......... Pp...__.... _..._......- - 6307' 4.5" HES X ni le, ID 3.813" 6328' 4.5" HES X nipple, ID 3.813" 6356' 4.5" Guide Shoe `---a~_==_~___~ ^ 6443-6453 4" x 6.4" Swell Packer 3.476" ID-RA Tag @ 6436' 8158-8168 4" x 6.4" Swell Packer 3.476" ID-RA Tag @ 8150' 8262-12175 4" L-80 9.5/10.9 IBT-M solid/screen 3.476 ID - L2 9739-9749 4" x 6.4" Swell Packer 3.476" ID-RA Tag @ 9731' 12260' 4.5" 12.6# L-80 IBT-M shoe (12,258' PBTD) - L2 I 6574' I -~4-1/2" Seal Assembly from LEM # 2 ~ ^ - - - - - - - - - - - - \ ~ 6563-6583 rr Baker Seal Bore Extension with 4.75 ID- L1 6666-6677 4" x 6.4" Swell Packer 3.476" ID-RA Tag @ 6659' 6635-11191 4" 10.9# L-80 IBT-M solid/screen 3.476 ID - L1 10262-10362 4" x 6.4" Swell Packer 3.476" ID-RA Tag @ 10254' 11273' 4.5" 12.6# L-80 IBT-M shoe (11271' PBTD) - L1 6728' 4-1/2" Seaf Assembly from LEM #1. 6717-6736 Baker Seal Bore Extension w ith 4.75 ID ~ 6762-6763 Magnumdisk Ceramic shear sub (Not sheared) 7418' 7 5/8 29.7# L-80 BTGM casing w ith 6.875 ID 1 -- - _ - ~ - _ - 7523-8460 4 1/2 BTC 12.6# slotted liner w ith 3.958 ID 8521-$531 Sw ell packer elements w ent in the hole at 6.4 OD g5$7' 4 1/2 F/C (PBTD once shear disk is gone @ 6762) 8632' I~ 4 1/2 IBT L-80 12.6# solid liner from 8460-8E DATE REV BY COMMENTS DATE REV BY COMMENTS 12(02/05 ANUJF ORIGINAL COMPLETION 12/08!05 KDGPJC GLV C/0 ORION UNIT WELL: L-250, L-250 L1, L-250 L2 PERMff No: 205-152 (153) (154) API No: 50-029-23281-00 {60) (61) SEC 34, T12N, R11 E, 2563' NSL & 3721' WEL BP Exploration (Alaska) • gyro data Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 November 7, 2005 Ms. Sharmaine Copeland BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Re: L-Pad, Well #L-250 Prudhoe Bay, Alaska Enclosed, please find one (1) original, two (2) copies, and two (2) disks of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Rob oup North American Operations Manager RS:tf Serving the Worldwide Energy Industry with Precision Survey Instrumentation • • gyrodafa Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP ~-PAD #L-250 NABORS #9ES PRUDHOE BAY, AK AK1005G_566 OCTOBER 26, 2005 ORIGINAL Serving the Worldwide Energy Industry with Precision Survey Instrumentation ,,,,, a A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) INC. Lease: L-Pad We11: L-250, Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1005G 566 Run Date: 26 Oct 2005 Surveyor: Steve Thompson Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.350644 deg. N Longitude: 149.324555 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location • • A Gyrodata Directional Survey BP Exploration (Alaska) Inc. Lease: L-Pad Well: L-250 Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK1005G 566 MEASURED I N C L AZIMUTH BORE HOLE DOGLEG VERTICAL CLOSURE DEPTH BEARING SEVERITY DEPTH DIST. AZIMUTH feet deg. deg. deg. min. deg./ feet feet deg. 100 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 0.0 0.0 0 - 1570 FT. RATE GYROSCOPIC MULTISHOT SURVEY ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9ES R.K.B. OF 77.30 FT. AMSL 100.00 0.18 72.13 N 72 8 E 200.00 0.28 91.26 S 88 44 E 300.00 0.33 67.69 N 67 41 E 400.00 0.48 65.03 N 65 2 E 500.00 0.38 60.50 N 60 30 E 600.00 4.63 0.90 N 0 54 E 700.00 7.22 2.14 N 2 8 E 800.00 9.47 358.78 N 1 13 W 900.00 10.55 0.97 N 0 58 E 1000.00 12.85 1.98 N 1 59 E 1100.00 18.01 1.78 N 1 47 E 1200.00 21.99 2.92 N 2 55 E 1300.00 25.18 3.83 N 3 50 E 1400.00 29.78 4.66 N 4 40 E 1500.00 34.96 4.69 N 4 42 E 1570.00 37.88 6.32 N 6 19 E Final Station Closure: Distance: 309.51 ft Az: 3.72 deg. HORIZONTAL COORDINATES feet 0.00 N -0.00 E • 0.18 100.00 0.2 72.1 0.05 N 0.15 E 0.12 200.00 0.6 80.4 0.09 N 0.54 E 0.13 300.00 1.1 79.5 0.20 N 1.05 E 0.15 400.00 1.8 74.2 0.48 N 1.70 E 0.10 499.99 2.5 70.9 0.82 N 2.37 E 4.45 599.88 5.7 28.4 5.02 N 2.72 E 2.59 699.34 15.6 11.1 15.34 N 3.02 E 2.30 798.27 30.0 5.9 29.84 N 3.07 E 1.15 896.75 47.3 3.7 47.22 N 3.05 E 2.30 994.66 67.6 3.0 67.49 N 3.60 E 5.16 1091.03 94.2 2.7 94.07 N 4.46 E 4.01 1184.98 128.4 2.6 128.23 N 5.90 E 3.20 1276.62 168.4 2.8 168.16 N 8.27 E 4.62 1365.31 214.5 3.1 214.16 N 11.71 E 5.17 1449.74 268.0 3.4 267.50 N 16.08 E 4.40 1506.07 309.5 3.7 308.86 N 20.09 E • 2 BP Exploration (Alaska) Inc. Well: L-Pad L-250 Location: Nabors #9ES, Prudhoe Bay, Alaska 300 250 200 w C7 z 150 O z 100 50 0 Inrun Gyrodata AK1005G_566 DEFINITIVE i BOTTOM HOLE ' ~ LOCATED MD: 1570.00 - ~ ' I * - - 0.0 2.5 5.0 7.5 10.0 12.5 FASTING (ft) 15.0 17.5 20.( • • BP Exploration (Alaska) Inc. Well: L-Pad L-250 Location: Nabors #9ES, Prudhoe Bay, Alaska 15.0 12.5 Inrun Gyrodata AK1005G_566 DEFINITIVE • 10.0 0 0 rn v v ._. 7.5 w w C7 w J 0 5.0 2.5 0.0 250 500 750 1000 1250 1500 1 MEASURED DEPTH (ft) • BP Exploration (Alaska) Inc. Well: L-Pad L-250 Location: Nabors #9ES. Prudhoe Bav. Alaska 35 30 25 z 0 Q 20 z J U z 15 10 5 Inrun Gyrodata AK1005G_566 DEFINITIVE BOTTOM i LOCATED MD: 157C • i • ~' 250 500 1250 1500 17 • 750 1000 MEASURED DEPTH (ft) BP Exploration (Alaska) Inc. Well: L-Pad L-250 Location: Nabors #9ES, Prudhoe Bav, Alaska 80.0 60.0 Q 40.0 20.0 0.0 Inrun • Gyrodata AK1005G_566 DEFINITIVE • ~, •~ - _-i •' I •i •i BOTTOM HOLE LOCATED MD: 1570.00 • ~ 250 500 1500 17 750 1000 1250 MEASURED DEPTH (ft) SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Orion Well .....................: L-250 API number ...............: 50-029-23281-00 Engineer .................: St. Amour 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.......: 48.80 ft KB above permanent.......: N/A (Topdrive) DF above permanent.......: 77.30 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: 10.20 degrees 9-Nov-2005 07:29:59 Page 1 of 7 Spud date ................: 10-October-2005 Last survey date.........: 09-Nov-05 Total accepted surveys...: 154 MD of first survey.......: 0.00 ft MD of last survey........: 9186.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 23-Oct-2005 Magnetic field strength..: 1151.54 HCNT Magnetic dec (+E/W-).....: 24.44 degrees Magnetic dip .............: 80.85 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............: Tolerance of G............ Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 1151.54 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.44 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.44 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 ~, ~ ~' - l s--~ • ~~ SCHLUMBERGER Survey Report 9-Nov-2005 07:29:59 Page 2 of 7 --- --- 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) -------- (f t) --------- (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 None 2 100.00 0.18 72.13 100.00 100.00 0.07 0.05 0.15 0.16 72.13 0.18 BP_ GYD_CT_DMS 3 200.00 0.28 91.26 100.00 200.00 0.19 0.09 0.54 0.55 80.49 0.12 BP_ GYD_CT_DMS 4 300.00 0.33 67.69 100.00 300.00 0.38 0.19 1.05 1.07 79.52 0.13 BP_ GYD CT_DMS ~ 5 400.00 0.48 65.03 100.00 399.99 0.77 0.48 1.70. 1.77 74.20 0.15 BP GYD CT DMS 6 500.00 0.38 60.50 100.00 499.99 1.23 0.82 2.37 2.51 70.88 0.11 BP GYD CT DMS 7 600.00 4.63 0.90 100.00 599.88 5.42 5.02 2.72 5.71 28.45 4.45 _ BP_ _ _ GYD_CT_DMS 8 700.00 7.22 2.14 100.00 699.34 15.63 15.34 3.02 15.63 11.13 2.59 BP_ GYD_CT_DMS 9 800.00 9.47 358.78 100.00 798.27 29.92 29.85 3.08 30.00 5.89 2.30 BP_ GYD_CT_DMS 10 900.00 10.55 0.97 100.00 896.75 47.02 47.22 3.06 47.32 3.71 1.14 BP GYD CT DMS 11 1000.00 12.85 1.98 100.00 994.66 67.06 67.49 3.60 67.59 3.05 2.31 BP_ GYD_CT_DMS 12 1100.00 18.01 1.78 100.00 1091.03 93.38 94.08 4.46 94.18 2.72 5.16 BP_ GYD_CT_DMS 13 1142.48 17.42 2.28 42.48 1131.49 106.17 106.99 4.92 107.11 2.63 1.43 BP_ MWD+IFR+MS 14 1238.55 23.54 359.82 96.07 1221.45 139.32 140.58 5.43 140.69 2.21 6.43 BP_ MWD+IFR+MS 15 1333.71 28.06 359.38 95.16 1307.10 180.02 181.98 5.13 182.06 1.61 4.75 BP MWD+IFR+MS 16 1426.70 33.77 1.48 92.99 1386.85 227.09 229.73 5.56 229.80 1.39 6.25 BP_ MWD+IFR+MS 17 1521.00 39.49 3.27 94.30 1462.50 282.80 285.92 7.95 286.03 1.59 6.17 BP_ MWD+IFR+MS 18 1615.30 41.59 2.81 94.30 1534.16 343.62 347.12 11.20 347.30 1.85 2.25 BP_ MWD+IFR+MS 19 1709.51 43.47 4.55 94.21 1603.58 406.88 410.66 15.30 410.95 2.13 2.35 BP_ MWD+IFR+MS 20 1803.55 48.15 5.70 94.04 1669.11 474.03 477.80 21.35 478.28 2.56 5.05 BP MWD+IFR+MS 21 1897.74 50.17 6.38 94.19 1730.71 545.09 548.66 28.85 549.42 3.01 2.21 BP_ MWD+IFR+MS 22 1992.59 50.39 5.96 94.85 1791.32 617.87 621.19 36.69 622.27 3.38 0.41 BP_ MWD+IFR+MS • 23 2087.57 50.71 5.82 94.98 1851.67 691.00 694.14 44.22 695.55 3.64 0.36 BP_ MWD+IFR+MS 24 2182.43 50.72 6.03 94.86 1911.73 764.22 767.17 51.80 768.92 3.86 0.17 BP_ MWD+IFR+MS 25 2278.30 50.98 6.67 95.87 1972.26 838.40 841.06 60.02 843.20 4.08 0.55 BP MWD+IFR+MS 26 2371.54 50.42 6.76 93.24 2031.32 910.42 912.72 68.46 915.29 4.29 0.61 BP_ MWD+IFR+MS 27 2466.47 50.95 6.67 94.93 2091.46 983.73 985.66 77.05 988.67 4.47 0.56 BP_ MWD+IFR+MS 28 2561.66 51.25 6.75 95.19 2151.24 1057.67 1059.24 85.70 1062.70 4.63 0.32 BP_ MWD+IFR+MS 29 2655.99 50.76 6.72 94.33 2210.60 1130.85 1132.04 94.30 1135.96 4.76 0.52 BP_ MWD+IFR+MS 30 2750.38 51.58 6.48 94.39 2269.78 1204.24 1205.09 102.75 1209.46 4.87 0.89 BP MWD+IFR+MS SCHLUMBERGER Survey Report 9-Nov-2005 07:29:59 Page 3 of 7 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) (f t) (ft) ift) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2842.88 54.02 5.92 92.50 2325.70 1277.73 1278.33 110.70 1283.11 4.95 2.68 BP MWD+IFR+MS 32 2938.01 54.48 5.76 95.13 2381.28 1354.71 1355.13 118.56 1360.31 5.00 0.50 BP _ MWD+IFR+MS 33 3030.50 54.05 5.73 92.49 2435.30 1429.56 1429.83 126.07 1435.38 5.04 0.47 BP _ MWD+IFR+MS 34 3124.67 53.78 5.75 94.17 2490.76 1505.43 1505.55 133.68 1511.48 5.07 0.29 BP _ MWD+IFR+MS 35 3217.96 53.69 5.83 93.29 2545.94 1580.43 1580.39 141.27 1586.69 5.11 0.12 BP _ MWD+IFR+MS 36 3304.80 54.42 5.76 86.84 2596.92 1650.52 1650.33 148.37 1656.99 5.14 0.84 BP MWD+IFR+MS 37 3377.66 54.50 8.43 72.86 2639.28 1709.72 1709.16 155.69 1716.23 5.20 2.98 BP _ MWD+IFR+MS • 38 3377.66 54.50 7.88 72.86 2639.27 1709.70 1709.19 155.41 1716.25 5.20 2.37 BP _ MWD+IFR+MS 39 3460.47 55.12 12.65 82.81 2687.01 1777.36 1775.66 168.08 1783.60 5.41 4.23 BP _ MWD+IFR+MS 40 3460.47 55.12 11.54 82.81 2687.01 1777.36 1775.88 166.83 1783.70 5.37 3.69 BP _ MWD+IFR+MS 41 3553.53 54.96 17.06 93.06 2740.35 1853.35 1849.35 187.62 1858.85 5.79 3.89 BP MWD+IFR+MS 42 3553.53 54.96 16.27 93.06 2740.35 1853.43 1849.88 185.15 1859.12 5.72 4.17 BP _ MWD+IFR+MS 43 3646.38 54.07 21.75 92.85 2794.27 1927.95 1920.63 212.71 1932.38 6.32 4.22 BP _ MWD+IFR+MS 44 3646.38 54.07 21.14 92.85 2794.27 1928.17 1921.46 209.36 1932.83 6.22 4.38 BP _ MWD+IFR+MS 45 3739.41 53.06 24.30 93.03 2849.53 2001.22 1990.49 238.25 2004.69 6.83 2.94 BP _ MWD+IFR+MS 46 3739.41 53.06 24.67 93.03 2849.53 2000.86 1989.41 242.19 2004.10 6.94 2.75 BP MWD+IFR+MS 47 3833.63 53.64 25.97 94.22 2905.77 2073.83 2057.74 274.52 2075.97 7.60 1.27 BP _ _MWD+IFR+MS 48 3833.63 53.64 25.65 94.22 2905.77 2074.31 2059.01 270.17 2076.66 7.48 1.30 BP MWD+IFR+MS 49 3926.05 51.52 27.14 92.42 2961.93 2144.79 2124.75 302.78 2146.22 8.11 2.63 BP _ MWD+IFR+MS 50 3926.05 51.52 26.87 92.42 2961.93 2144.31 2123.47 307.17 2145.57 8.23 2.42 BP _ MWD+IFR+MS 51 4019.45 51.26 28.14 93.40 3020.22 2213.99 2188.21 340.87 2214.60 8.85 1.10 BP MWD+IFR+MS 52 4019.45 51.26 27.27 93.40 3020.22 2214.58 2189.66 336.15 2215.32 8.73 0.30 BP _ MWD+IFR+MS • 53 4112.37 51.19 27.35 92.92 3078.41 2283.06 2252.32 374.60 2283.26 9.44 0.67 BP - MWD+IFR+MS 54 4112.37 51.19 26.85 92.92 3078.41 2283.91 2254.17 369.11 2284.19 9.30 0.36 BP _ MWD+IFR+MS 55 4204.46 51.42 27.12 92.09 3135.98 2351.78 2316.22 407.49 2351.80 9.98 0.32 BP _ MWD+IFR+MS 56 4204.46 51.42 26.73 92.09 3135.98 2352.79 2318.33 401.50 2352.84 9.83 0.27 BP MWD+IFR+MS 57 4297.65 51.71 30.07 93.19 3193.92 2421.03 2380.30 442.42 2421.07 10.53 2.50 BP _ MWD+IFR+MS 58 4297.65 51.71 29.80 93.19 3193.92 2422.18 2382.61 436.06 2422.19 10.37 2.60 BP _ MWD+IFR+MS 59 4392.61 51.45 31.47 94.96 3252.93 2490.68 2444.23 480.48 2491.00 11.12 1.19 BP _ MWD+IFR+MS 60 4392.61 51.45 30.78 94.96 3252.93 2492.05 2446.85 473.59 2492.26 10.95 0.85 BP _ MWD+IFR+MS SCHLUMBERGER Survey Report 9-Nov-2005 07:29:59 Page 4 of 7 --- --- 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) ------- (f t) ------ (ft) -------- (ft) -------- (ft) -------- (ft) -------- (ft) --------- (deg) ------ 100f) ----- - type (deg) ---- ------ --- 61 -------- 4485.21 ------ 53.60 ------- 29.48 ------ 92.60 -------- 3309.27 -------- 2561.13 -------- 2510.41 -------- 510.46 --------- 2561.79 ------ 11.49 ----- 2.58 - BP ---- ------ _MWD+IFR+MS 62 4485.21 53.60 29.41 92.60 3309.27 2559.63 2507.59 517.69 2560.47 11.66 2.92 BP _MWD+IFR+MS 63 4578.62 54.11 28.98 93.41 3364.37 2630.95 2573.43 554.48 2632.49 12.16 0.66 BP _MWD+IFR+MS 64 4578.62 54.11 29.11 93.41 3364.36 2632.41 2576.20 547.37 2633.71 12.00 0.63 BP _MWD+IFR+MS 65 4671.65 53.80 28.94 93.03 3419.11 2702.18 2639.25 590.91 2704.59 12.62 0.34 BP _MWD+IFR+MS 66 4671.65 53.80 29.11 93.03 3419.10 2703.57 2641.92 583.96 2705.69 12.46 0.33 BP MWD+IFR+MS 67 4764.31 53.21 29.31 92.66 3474.21 2774.00 2706.93 620.32 2777.10 12.91 0.66 BP _ _MWD+IFR+MS . 68 4764.31 53.21 31.86 92.66 3474.22 2772.07 2703.49 628.59 2775.60 13.09 2.61 BP _MWD+IFR+MS 69 4857.56 52.79 29.02 93.25 3530.33 2844.43 2771.96 656.61 2848.67 13.33 0.51 BP _MWD+IFR+MS 70 4857.56 52.79 28.96 93.25 3530.35 2841.95 2767.70 666.28 2846.77 13.54 2.52 BP MWD+IFR+MS 71 4952.03 52.51 29.57 94.47 3587.65 2915.40 2837.46 693.35 2920.94 13.73 0.55 BP _MWD+IFR+MS 72 5045.33 51.88 29.69 93.30 3644.84 2984.91 2901.54 729.80 2991.91 14.12 0.68 BP _MWD+IFR+MS 73 5138.73 54.44 29.12 93.40 3700.83 3055.50 2966.65 766.49 3064.07 14.49 2.78 BP _MWD+IFR+MS 74 5230.90 54.90 28.89 92.17 3754.13 3126.68 3032.42 802.95 3136.92 14.83 0.54 BP _MWD+IFR+MS 75 5324.74 54.48 28.53 93.84 3808.37 3199.30 3099.58 839.74 3211.32 15.16 0.55 BP MWD+IFR+MS 76 5417.84 53.82 28.79 93.10 3862.90 3270.88 3165.80 875.93 3284.74 15.47 0.74 BP _MWD+IFR+MS 77 5511.05 55.75 28.85 93.21 3916.64 3343.04 3232.51 912.64 3358.87 15.77 2.07 BP _MWD+IFR+MS 78 5603.61 57.96 28.05 92.56 3967.25 3416.64 3300.65 949.55 3434.52 16.05 2.49 BP _MWD+IFR+MS 79 5697.17 60.88 28.88 93.56 4014.84 3493.11 3371.45 987.94 3513.22 16.33 3.21 BP _MWD+IFR+MS 80 5791.86 63.76 30.59 94.69 4058.83 3572.12 3444.24 1029.54 3594.82 16.64 3.44 BP MWD+IFR+MS 81 5884.27 66.66 32.01 92.41 4097.57 3650.38 3515.91 1073.13 3676.03 16.97 3.43 BP _MWD+IFR+MS 82 5977.84 70.06 33.79 93.57 4132.08 3730.59 3588.91 1120.38 3759.72 17.34 4.04 BP - MWD+IFR+MS • 83 6071.32 73.16 35.09 93.48 4161.56 3811.46 3662.05 1170.54 3844.58 17.73 3.57 BP _MWD+IFR+MS 84 6164.43 75.10 34.05 93.11 4187.02 3893.04 3735.80 1221.36 3930.38 18.10 2.34 BP _MWD+IFR+MS 85 6257.98 76.40 29.96 93.55 4210.06 3977.20 3812.67 1269.39 4018.44 18.41 4.46 BP MWD+IFR+MS 86 6351.55 74.80 26.84 93.57 4233.34 4063.28 3892.38 1312.50 4107.71 18.63 3.65 BP _MWD+IFR+MS 87 6443.94 73.29 21.48 92.39 4258.75 4149.45 3973.38 1348.85 4196.09 18.75 5.81 BP _MWD+IFR+MS 88 6538.08 74.98 15.33 94.14 4284.51 4239.03 4059.26 1377.41 4286.59 18.74 6.53 BP _MWD+IFR+MS 89 6630.38 77.85 10.78 92.30 4306.19 4328.60 4146.63 1397.64 4375.84 18.63 5.71 BP _MWD+IFR+MS 90 6723.78 77.89 11.17 93.40 4325.82 4419.90 4236.28 1415.03 4466.36 18.47 0.41 BP MWD+IFR+MS SCHLUMBERGER Survey Report 9-Nov-2005 07:29:59 Page 5 of 7 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) (f t) (ft) (f t) (ft) (ft) (ft) (deg) 100f) type (deg) 91 6817.07 77.35 9.10 93.29 4345.82 4511.02 4325.97 1431.06 4556.53 18.30 2.24 BP MWD+IFR+MS 92 6910.48 78.03 2.85 93.41 4365.76 4601.98 4416.69 1440.55 4645.68 18.06 6.58 BP _ _MWD+IFR+MS 93 7004.98 80.97 358.06 94.50 4382.99 4693.52 4509.56 1441.27 4734.28 17.72 5.87 BP _MWD+IFR+MS 94 7097.29 81.98 356.52 92.31 4396.67 4782.50 4600.75 1436.95 4819.93 17.35 1.98 BP _MWD+IFR+MS 95 7190.18 82.73 355.81 92.89 4409.03 4871.81 4692.60 1430.79 4905.88 16.96 1.11 BP MWD+IFR+MS 06 97 720^ '7 '] V~GG 7356.67 07 C7 V.J ...JJ 86.29 ']Cn nn J.:JY70 354.30 nn nn 7`YVY 72.45 nnnn nn YYLVLO 4426.71 nncn nn Y70LV0 5031.59 r~"i 4705.0/ 4857.51 14233V 1416.56 4992.0 5059.84 10.7 16.26 1LL 3.92 rsP BP MWD+IFR+MS _MWD+IFR+MS • 98 7427.46 88.49 353.07 70.79 4429.93 5099.38 4927.79 1408.78 5125.21 15.95 3.56 BP _MWD+IFR+MS 99 7458.64 88.51 352.97 31.18 4430.75 5129.16 4958.73 1404.99 5153.93 15.82 0.33 BP _MWD+IFR+MS 100 7490.33 90.95 354.86 31.69 4430.89 5159.57 4990.23 1401.63 5183.34 15.69 9.74 BP MWD+IFR+MS 101 7521.41 90.58 355.82 31.08 4430.48 5189.61 5021.21 1399.11 5212.49 15.57 3.31 BP _MWD+IFR+MS 102 7551.52 91.13 357.92 30.11 4430.03 5218.90 5051.27 1397.46 5241.01 15.46 7.21 BP _MWD+IFR+MS 103 7582.86 92.05 358.05 31.34 4429.16 5249.52 5082.58 1396.36 5270.90 15.36 2.96 BP _MWD+IFR+MS 104 7614.56 91.80 358.31 31.70 4428.10 5280.51 5114.24 1395.36 5301.18 15.26 1.14 BP _MWD+IFR+MS 105 7645.50 90.43 356.18 30.94 4427.49 5310.66 5145.14 1393.87 5330.60 15.16 8.18 BP MWD+IFR+MS 106 7677.09 92.40 356.12 31.59 4426.71 5341.29 5176.65 1391.75 5360.47 15.05 6.24 BP MWD+IFR+MS 107 7708.37 92.13 356.22 31.28 4425.48 5371.61 5207.83 1389.66 5390.05 14.94 0.92 BP _ _MWD+IFR+MS 108 7739.65 91.92 355.95 31.28 4424.37 5401.93 5239.02 1387.53 5419.65 14.83 1.09 BP MWD+IFR+MS 109 7770.79 92.56 355.55 31.14 4423.15 5432.06 5270.05 1385.22 5449.06 14.73 2.42 BP _ MWD+IFR+MS 110 7803.87 92.68 355.20 33.08 4421.64 5464.01 5302.99 1382.56 5480.25 14.61 1.12 BP _ MWD+IFR+MS 111 7833.54 92.81 354.89 29.67 4420.22 5492.61 5332.51 1380.00 5508.18 14.51 1.13 BP _MWD+IFR+MS 112 7864.49 92.06 354.30 30.95 4418.91 5522.39 5363.30 1377.08 5537.27 14.40 3.08 BP - MWD+IFR+MS • 113 7895.44 91.97 354.46 30.95 4417.82 5552.15 5394.08 1374.05 5566.34 14.29 0.59 BP MWD+IFR+MS 114 7926.91 92.49 355.05 31.47 4416.59 5582.46 5425.39 1371.18 5595.98 14.18 2.50 BP _ _MWD+IFR+MS 115 7957.62 92.77 354.68 30.71 4415.18 5612.05 5455.95 1368.43 5624.94 14.08 1.51 BP MWD+IFR+MS 116 7988.90 90.76 354.14 31.28 4414.22 5642.13 5487.06 .1365.39 5654.39 13.97 6.65 BP MWD+IFR+MS 117 8019.19 88.51 353.65 30.29 4414.41 5671.20 5517.18 1362.17 5682.85 13.87 7.60 BP ` MWD+IFR+MS 118 8050.10 86.35 350.97 30.91 4415.80 5700.58 5547.77 1358.04 5711.57 13.75 11.13 BP _ MWD+IFR+MS 119 8081.64 86.25 350.71 31.54 4417.83 5730.28 5578.85 1353.03 5740.58 13.63 0.88 BP _ _MWD+IFR+MS 120 8113.13 86.23 351.01 31.49 4419.90 5759.93 5609.87 1348.03 5769.56 13.51 0.95 BP MWD+IFR+MS SCHLUMBERGER Survey Report 9-Nov-2005 07:29:59 Page 6 of 7 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) (f t) (ft) (ft) (deg) 100f) type (deg) 121 8144.17 86.03 351.23 31.04 4422.00 5789.19 5640.47 1343.25 5798.21 13.40 0.96 BP MWD+IFR+MS 122 8175.64 86.13 350.59 31.47 4424.15 5818.83 5671.47 1338.29 5827.23 13.28 2.09 BP MWD+IFR+MS 123 8207.31 90.74 355.71 31.67 4425.01 5849.07 5702.88 1334.52 5856.94 13.17 21.77 BP _ MWD+IFR+MS 124 8237.02 90.67 355.79 29.71 4424.65 5877.84 5732.51 1332.31 5885.3.0 13.08 0.36 BP _ MWD+IFR+MS 125 8268.31 88.79 355.43 31.29 4424.79 5908.12 5763.70 1329.92 5915.15 12.99 6.12 BP _ MWD+IFR+MS 126 8299.41 87.59 355.12 31.10 4425.78 5938.16 5794.68 1327.36 5944.77 12.90 3.98 BP MWD+IFR+MS 127 8331.10 89.10 355.55 31.69 4426.69 5968.77 5826.25 1324.78 5974.97 12.81 4.95 BP _ _MWD+IFR+MS 128 8361.35 88.88 356.43 30.25 4427.22 5998.09 5856.42 1322.67 6003.93 12.73 3.00 BP _MWD+IFR+MS 129 8392.28 89.37 355.64 30.93 4427.70 6028.08 5887.28 1320.53 6033.56 12.64 3.01 BP MWD+IFR+MS 130 8423.17 89.04 357.34 30.89 4428.13 6058.08 5918.10 1318.64 6063.23 12.56 5.61 BP _ MWD+IFR+MS 131 8454.96 89.47 356.83 31.79 4428.54 6089.04 5949.85 1317.02 6093.87 12.48 2.10 BP MWD+IFR+MS 132 8485.52 86.91 358.02 30.56 4429.50 6118.83 5980.36 1315.65 6123.37 12.41 9.24 BP _ MWD+IFR+MS 133 8515.88 84.77 356.03 30.36 4431.71 6148.31 6010.60 1314.08 6152.57 12.33 9.61 BP _ _MWD+IFR+MS 134 8546.40 84.55 355.97 30.52 4434.55 6177.77 6040.91 1311.96 6181.74 12.25 0.75 BP _MWD+IFR+MS 135 8577.84 85.48 356.57 31.44 4437.28 6208.17 6072.17 1309.92 6211.85 12.17 3.52 BP MWD+IFR+MS 136 8609.40 89.14 355.97 31.56 4438.76 6238.76 6103.62 1307.87 6242.17 12.09 11.75 BP MWD+IFR+MS 137 8640.74 88.92 355.29 31.34 4439.29 6269.09 6134.86 1305.48 6272.23 12.01 2.28 BP _ _MWD+IFR+MS 138 8671.05 88.40 353.10 30.31 4440.00 6298.21 6165.01 1302.42 6301.08 11.93 7.42 BP MWD+IFR+MS 139 8703.09 88.29 350.37 32.04 4440.92 6328.59 6196.70 1297.82 6331.15 11.83 8.52 BP _ MWD+IFR+MS 140 8734.21 89.02 349.48 31.12 4441.66 6357.77 6227.33 1292.37 6360.02 11.72 3.70 BP _ MWD+IFR+MS 141 8764.25 89.35 347.81 30.04 4442.08 6385.71 6256.78 1286.46 6387.66 11.62 5.67 BP _MWD+IFR+MS 142 8795.14 91.67 349.30 30.89 4441.81 6414.41 6287.05 1280.33 6416.09 11.51 8.93 BP MWD+IFR+MS 143 8826.24 92.57 352.60 31.10 4440.66 6443.75 6317.74 1275.44 6445.20 11.41 10.99 BP _ MWD+IFR+MS 144 8856.95 92.91 356.18 30.71 4439.19 6473.26 6348.26 1272.44 6474.53 11.33 11.70 BP _ _MWD+IFR+MS 145 8888.27 91.58 359.84 31.32 4437.96 6503.84 6379.53 1271.36 6504.98 11.27 12.43 BP MWD+IFR+MS 146 8920.38 91.09 1.51 32.11 4437.21 6535.50 6411.63 1271.74 6536.54 11.22 5.42 BP _MWD+IFR+MS 147 8950.87 90.71 0.83 30.49 4436.73 6565.61 6442.11 1272.36 6566.56 11.17 2.55 BP MWD+IFR+MS 148 8981.77 90.72 0.70 30.90 4436.35 6596.09 6473.00 1272.77 6596.95 11.12 0.42 BP _ _MWD+IFR+MS 149 9013.02 88.56 359.99 31.25 4436.54 6626.88 6504.25 1272.96 6627.65 11.07 7.28 BP MWD+IFR+MS 150 9043.88 83.78 358.64 30.86 4438.61 6657.10 6535.03 1272.59 6657.78 11.02 16.09 BP _ MWD+IFR+MS • .] SCHLUMBERGER Survey Report Seq Measured Incl Azimuth # depth angle angle - (ft) (deg) (deg) 151 9074.98 80.33 358.22 152 9105.05 78.86 357.84 153 9137.02 78.67 357.71 154 9186.00 78.67 357.71 [(c)2005 IDEAL ID10_2C_O1] Course TVD length depth (ft) (ft) 31.10 4442.90 30.07 4448.33 31.97 4454.56 48.98 4464.19 9-Nov-2005 07:29:5 Vertical Displ section +N/S- (ft) (ft) 6687.25 6565.81 6716.16 6595.37 6746.79 6626.70 6793.67 6674.69 9 Page Displ Total +E/W- displ (ft) (ft) 1271.75 6687.84 1270.73 6716.67 1269.52 6747.21 1267.60 6793.99 7 of 7 At DLS Srvy Tool Azim (deg/ tool Corr (deg) 100f) type (deg) 10.96 11.17 BP_MWD+IFR+MS 10.91 5.04 BP_MWD+IFR+MS 10.85 0.72 BP_MWD+IFR+MS 10.75 0.00 Projected to TD C, Y SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ..................... Orion Well ...................... L-250PB1 API number ...............: 50-029-23281-70 Engineer .................. F. Medina Rig :...................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference..........: GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 48.80 ft N/A Top Drive 77.30 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: 10.20 degrees 30-Oct-2005 11:05:44 Page 1 of 3 Spud date ................: 24-October-2005 Last survey date.........: 26-Oct-05 Total accepted surveys...: 36 MD of first survey.......: 0.00 ft MD of last survey........: 3340.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2005 Magnetic date ............: 23-Oct-2005 Magnetic field strength..: 1151.54 HCNT Magnetic dec (+E/W-).....: 24.44 degrees Magnetic dip .............: 80.85 degrees ----- MWD survey Reference Reference G ..............: Reference H ..............: Reference Dip ............: Tolerance of G............ Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 1151.54 HCNT 80.85 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections ------------------- Magnetic dec (+E/W-).....: 24.44 degrees Grid convergence (+EJW-).: 0.00 degrees Total az corr (+E/W-)....: 24.44 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 acsS-II"z L` r SCHLUMBERGER Survey Report 30-Oct-2005 11:05:44 Page 2 of 3 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 - (f t) (deg) (deg) (f t) (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 None 2 100.00 0.18 72.13 100.00 100.00 0.07 0.05 0.15 0.16 72.13 0.18 BP GYD CT DMS 3 200.00 0.28 91.26 100.00 200.00 0.19 0.09 0.54 0.55 80.49 0.12 BP _ _ _ GYD CT DMS 4 300.00 0.33 67.69 100.00 300.00 0.38 0.19 1.05 1.07 79.52 0.13 BP _ _ _ CT GYD DMS 5 400.00 0.48 65.03 100.00 399.99 0.77 0.48 1.70 1.77 74.20 0.15 BP _ _ _ GYD CT DMS 6 500.00 0.38 60.50 100.00 499.99 1.23 0.82 2.37 2.51 70.88 0.11 BP GYD CT DMS 7 600.00 4.63 0.90 100.00 599.88 5.42 5.02 2.72 5.71 28.45 4.45 BP _ _ _ GYD CT DMS 8 700.00 7.22 2.14 100.00 699.34 15.63 15.34 3.02 15.63 11.13 2.59 BP _ _ _ GYD CT DMS 9 800.00 9.47 358.78 100.00 798.27 29.92 29.85 3.08 30.00 5.89 2.30 BP _ _ GYD`CT DMS 10 900.00 10.55. 0.97 100.00 896.75 47.02 47.22 3.06 47.32 3.71 1.14 BP _ _ GYDJCT DMS 11 1000.00 12.85 1.98 100.00 994.66 67.06 67.49 3.60 67.59 3.05 2.31 BP GYD CT DMS 12 1100.00 18.01 1.78 100.00 1091.03 93.38 94.08 4.46 94.18 2.72 5.16 BP _ _ _ CT DMS GYD 13 1200.00 21.99 2.92 100.00 1184.98 127.26 128.24 5.90 128.38 2.63 4.00 BP _ _ _ CT GYD DMS 14 1300.00 25.18 3.83 100.00 1276.61 166.98 168.17 8.27 168.38 2.82 3.21 BP _ _ _ GYD CT DMS 15 1400.00 29.78 4.66 100.00 1365.31 212.87 214.18 11.71 214.50 3.13 4.62 BP _ _ _ GYD CT DMS 16 1500.00 34.96 4.69 100.00 1449.74 266.14 267.52 16.08 268.00 3.44 5.18 BP GYD CT DMS 17 1596.82 41.90 6.11 96.82 1525.54 326.07 327.38 21.79 328.11 3.81 7.23 BP _ _ _ MWD+IFR+MS 18 1693.87 42.21 6.32 97.05 1597.60 390.92 392.01 28.83 393.07 4.21 0.35 BP _ MWD+IFR+MS 19 1786.66 44.42 5.35 92.79 1665.11 454.38 455.33 35.29 456.70 4.43 2.49 BP _ MWD+IFR+MS 20 1879.45 45.17 6.07 92.79 1730.96 519.56 520.38 41.80 522.06 4.59 0.98 BP _ MWD+IFR+MS 21 1972.65 48.33 6.03 93.20 1794.81 587.26 587.88 48.95 589.91 4.76 3.39 BP MWD+IFR+MS 22 2066.16 51.49 5.05 93.51 1855.02 658.55 659.08 55.84 661.44 4.84 3.47 BP _ MWD+IFR+MS 23 2161.01 53.00 3.95 94.85 1913.09 733.16 733.83 61.72 736.42 4.81 1.84 BP _ MWD+IFR+MS 24 2253.94 52.70 3.74 92.93 1969.21 806.78 807.74 66.68 810.48 4.72 0.37 BP _ MWD+IFR+MS 25 2346.11 52.99 3.65 92.17 2024.88 879.77 881.04 71.42 883.93 4.63 0.32 BP _ MWD+IFR+MS 26 2439.91 52.53 2.98 93.80 2081.65 953.90 955.59 75.74 958.59 4.53 0.75. BP MWD+IFR+MS 27 2533.07 52.28 3.06 93.16 2138.48 1027.14 1029.30 79.63 1032..38 4.42 0.28 BP _ MWD+IFR+MS 28 2627.31 51.52 2.24 94.24 2196.63 1100.65 1103.38 83.06 1106.51 4.30 1.06 BP _ MWD+IFR+MS 29 2720.18 51.47 3.41 92.87 2254.45 1172.73 1175.97 86.64 1179.16 4.21 0.99 BP _ MWD+TFR+MS 30 2813.86 52.66 3.82 93.68 2312.04 1246.12 1249.71 91.30 1253.04 4.18 1.32 BP _ MWD+IFR+MS • • • SCHLUMBERGER Survey Report 30-Oct-2005 11:05:44 Page 3 of 3 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 - (f t) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2906.66 53.08 3.54 92.80 2368.06 1319.63 1323.54 96.05 1327.02 4.15 0.51^ BP MWD+IFR+MS 32 3000.78 53.37 3.51 .94.12 2424.41 1394.51 1398.79 100.68 1402.41 4.12 0.31 _ BP MWD+IFR+MS 33 3094.90 53.37 3.12 94.12 2480.56 1469.50 1474.19 105.05 1477.93 4.08 0.33 _ BP MWD+IFR+MS 34 3187.58 53.76 5.14 92.68 2535.61 1543.64 1548.56 110.42 1552.49 4.08 1.80 _ BP MWD+IFR+MS 35 3281.49 54.16 5.20 93.91 2590.86 1619.28 1624.18 117.27 1628.41 4.13 0.43 _ BP MWD+IFR+MS 36 3340.00 54.00 5.20 58.51 2625.19 1666.48 1671.37 121.56 1675.79 4.16 0.27 Projection to TD [(c)2005 IDEAL ID10 2C O1] • • • Schlumherger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman (AOGCC) Well No L-250 Date Dispatched: 16-Nov-05 Installation/Rig Nabors 9ES Dispatched By: Mauricio Perdomo LWD Log DeliveryV1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 1 /~ Please sign and return to: ,lames H. Jonnson Received By: v BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1 j J ~~,~ ~.,C ~-- 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojh~bp.com • • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaska) Inc. L-250 PB 1 Nabors-9ES Dispatched To: Helen Warman (AOGCC) Date Dispatched: 0-Jan-00 Dispatched By: Mauricio Perdomo Data No Of Prints No of Flo ies Surveys 2 1 /~ Please sign and return to: James H. Jonnson Received By: V BP Exploration (Alaska) Inc. ~p Petrotechnical Data Center (LR2-1) ~ 900 E. Benson Blvd. ~ V f ~ o~ (TQ ~ Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address: johnsojh@bp.com ~.vvu wog ueitvery v.l..l, _IU-uz-u~ ~d.S' - /~'~".~ Ir l ~. 1 ; ,~ . ,) ;~ ~~ ,, +,; ,~ ~ , , i ~~°'~ .~ ~ .~ '°~~ ~ FRANK H. MURKOWSKI, GOVERNOR I ~~~~ ~~~~+rg~ ~ta~ ~~~+ 7~T ~+t~r1 ~- -m7~1aT 0~ ~ ~ ~i 333 W. 7"' AVENUE, SUITE 100 C01~-7s7RQAiio`s Co~'IISS"'I~~ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU L-250 BP Exploration (Alaska) Inc. Permit No: 205-152 Surface Location: 2564' FSL, 3719' FEL, SEC. 34, T12N, R11E, UM Bottomhole Location: 4435' FSL, 2421' FEL, SEC. 27, T12N, R1 lE, 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 eventit was erroneousiy 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). DATED this ~7 day of October, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~tir~ ~~ STATE OF ALASKA ~ ~~.~ ~ ~ ~~~~ ALAS OIL AND GAS CONSERVATION C MISSION PERMIT TO DRILL Alaska Oil & cas cobs. colnmSS101't 2n aAC ~s nns ~ 1~rlchaaae 1a. Type of work ®Drill ^ Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU L-250 ' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9670 TVD 4428 12. Field /Pool{s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 2564' FSL, 3719' FEL, SEC. 34, T12N, R11 E UM (As staked) 7. Property Designation: ADL 028239 Schrader Bluff , Top of Productive Horizon: 1953' FSL, 2253' FEL, SEC. 27, T12N, R11E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 20, 2005 Total Depth: 4435' FSL, 2421' FEL, SEC. 27, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 2555' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583195 y-5978286 Zone-ASP4 10. KB Elevation (Height above GL):plan 77.2 feet 15. Distance to Nearest We11 Within Pool 350'to L-118 16. Deviated Wells: Kickoff Depth: 500 feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25:035) Downhole: 1884 Surface: 46 1' . asing Program: Size Spec cations Setting Depth To Bottom ua' o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 48" 20" x 34" 215.5# A-53 Weld 80' 29' 29' 109' 109' 60 sx Arctic Set A rox. 13-1 /2" 10-3/4" 45.5# L-80 BTC 3191' 29' 29' 3220' 2545' 85 sx AS Lite, 441 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 6695' 29' 29' 6724' 4305' 00 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 BTC 2970' 6700' 4301' 9670' 4427' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMM ARY (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 Size Cement Volume MD TVD tr trl n tr I 't Pr ti n i r Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Michael Triolo, 564-5774 Printed Name Robert Tirpack Title Senior Drilling Engineer ~_~..---~ Prepared By Name/Number: Si nature ~~a~~-~'~1;~ '-~ Phone 564-4166 Datefl/i ?"" Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: Z~ -,~ API Number: 50- ®2. W ,L Z, Permit Approval Date: ~, , See cover letter for other requirements Conditions of Approval: Sample quired Hydr en ulfide Measures Other: ` ~ G,-~- ' F ..~ 5 ~~ c7 r~C,,..E' , A roved B ^ Yes ~No Mud Log Required ^ Yes ~lo ^ Yes ~No Directional Survey Required Yes ^ No APPROVED BY /D /~~1~ ~~ THE COMMIS ON Date Form 10-401 Revised Ofj11004 t ,`~~ ~~i \f~~-) K~SJ/~~~ ~~ J ~ ~/'`~"-'' S(ibmit ~ Duplicate Well Plan Summary G oe Bay L-250 ML Permit Well Name: L-250, L-250 L1 & L-250 L2 T e of Well roducer or in'ector : Schrader OA and Nb Multilateral Producer Surface Location: As-stake 2,564' FSL, 3,719' FEL, Sec. 34, T12N, R11 E X = 583,194.82 Y = 5,978,285.78 L-250 OA Target Start: 733' FSL, 2,664' FEL, Sec. 27, T12N, R11 E X = 584,600 Y = 5,982,970 Z = 4,305' TVDss L-250 OA Target End: 4,434 FSL, 2,421' FEL, Sec. 27, T12N, R11 E / X = 584,400 Y = 5,985,450 Z = 4,350' TVDss L-250 L1 Nb Target Start: 733' FSL, 2,664' FEL, Sec. 27, T12N, R11 E X = 584,380 Y = 5,983,500 Z = 4,200' TVDss L-250 L1 Nb Target End: 1,071' FSL, 2,566' FEL, Sec. 22, T12N, R11 E X = 584,230 Y = 5,987.365 Z = 4.265' TVDss L-250 L2 Nb Target Start: 826' FSL, 1,228' FEL, Sec. 27, T12N, R11 E X = 585,640 Y = 5,981,855 Z = 4,195' TVDss L-250 L2 Nb Target End: 4,672' FSL, 1,991' FEL, Sec. 35, T12N, R11 E X = 590,175 Y = 5,980,475 Z = 4,285' TVDss AFE Number: ORD5M3596 KBE = 77.20' Ri Nabors E Estimated Start Date: October 20 2005 O eratin days to com lete: 32.11 OA MD 9,670' Nb-Li MD 11,615' Nb-L2 MD 12,548' Current Well Information Distance to Nearest Property: Distance to Nearest Well in Pool L-250 Original Well API #: L-250 L1 API Nb #: L-250 L2 API Nb #: Well Type: Current Status: H2S: BHT: BHP: Mechanical Condition L-250 Conductor: Base Flange height: Nabor 9ES: Materials Needed Well TVDrkb: TD 4,428' Well TVDrkb: TD 4,343' Well TVDrkb: TD 4,363' Max Inc. 91 ° Max Inc. 97° Max Inc. 96° L-250: 2,555' to unit boundary in OA, L-250 L1: 2,445' to unit boundary in Nb, L-250 L2: 4,430' to unit boundary in Nb. L-250: 350' to L-118 at Top Na 50-029-xxxxx-00 50-029-xxxxx-60 KOP 500' KOP 6,648' KOP 6,238' 50-029-xxxxx-61 Schrader O/N-sand Trilateral Producer ~ New well, conductor is set 0 ppm from produced fluids (approximated to be around 10 ppm due to contaminated gas lift gas) 82 °F @ 4,100' TVDss (Estimated) 8.6 - 8.7 ppg in Schrader N/O-Sands (Based on MDT's taken on L-216 in May `04) 20" X 34", 215.5 Ib/ft, A53 ERW set at 109' RKB Above MSL = 48.70' KB = 28.50 Permit 10/10!05 Grea~rudhoe Bay L-250 ML Permit Materials Needed Surface Casin Amount Descri tion 3,220' 10-3/a", 45.5#, L-80, BTC Casing (Burst: 5,210; Collapse: 2,470) 1 each 10-3/a", BTC Float Shoe and Float Collar 25 each 10-3/a" x 13-'/2" Bow Spring Centralizers 1 assembly FMC 11" 5m Gen 5 Wellhead System 1 lot 10-3/a" casing pups 5', 10', 20'. 1 each 10-3/a" TAM Port Collar I Intermediate Casina: Amount Descriotion 1 6,725' 7-5/8" 29.7# L-80 BTC-M Casing (Burst: 6,890; Collapse: 4,790) 1 each 7 5/8" BTC-M Float Shoe and Float Collar 95 each 7 5/" x 9-%6" Rigid Straight Blade Centralizers 50 each 7 5/8' Stop Rings 2 lots 7 5/$" casing pups 5', 10', 20' 4 each 7 5/8" RA Tag ProductionLiner; Amount - Descri tion 3 x Production Liners: 3,300' 4'/z", 12.6#, L-80, IBT-Mod Slotted Liner See Note below 5,651' 4.8" x 4", 15.5# Baker Excluder 2000 Screen (Medium mesh) See Note below 5,651' 4", 10.9#, L-80 IBT-M solid liner 75 each 4'/z" x 5 3/a" x 8" Straight Blade Centralizers 3 each 7 5/8' x 4-~/z" Baker ZXP Liner Top Packer 1 each 4-'/z" Halliburton Float Shoes 2 each 4" Halliburton Float Shoes 5 each 6.4" x 15' EWS Swell Packer (Packer OD may be 6.3") 150 each 4" x 5 3/a" x 8" Straight Blade Centralizers 2 assemblies Baker Level 3 Hookwall Hangers with LEM 1 each Halliburton Glass / com osite shear out lu 3.958" ID after shear NOTE: The base plan is to utilize 50/50 screen blank. This may change based on the as-drilled profile and log interpretations. Have extra pipe on location and in inventory to accommodate. Com letion: Amount Descri tion 6,200' 4-~/z", 12.75 Ib/ft, L-80, TCII tubing 1 each Baker PRM Production Packer 7 5/8" X 4-'/z" 1 each 11" X 4-'/z" FMC tubing hanger 1 each 4-'/,s", 5m Cameron Tree 2 each Halliburton X-Nipple (3.813" ID) 1 each 4-~/z" Baker CMD Sliding Sleeve ~ 4 each Camco 4-~/z" X 1" KBG-2 Gas Lift Mandrels 2 each Phoenix pressure gauge 6,200' Encapsulated I-wire for the Phoenix gauge 1 each 5.6" x 4-'/z" Fluted WLEG Uni ue Machine Surface and Anti-Collision Issues Surface Shut-in Wells: L-200 will require surface shut-in and wellhouse removal in order to move over well L-250. No other wells should require wellhouse removal and surface shut-in. NOTE: The rig Toolpusher may require other well houses to be removed to accommodate the rig positioning on L-250. Close Approach Shut-in Wells: There are NO wells requiring subsurface isolation for this profile. The toe of the L2 lateral does come within 100' center to center of the L-2101 P61, and as such had to be risk based to pass anti-collision. Close A roach Well List: . _, etE~~i`liina , ~ ~ ` ~l'"e~i rt.;> ~'F~t~e'ttM~-re ~ri~~ ' ~ F: r~; L-200 15.5-ft 320-ft 9.8-ft Use Travelin C tinder G ro L-2121 46.3-ft 460-ft 38.5-ft Use Travelin C tinder G ro L-202 31.0-ft 761-ft 18.1-ft Use Travelin C tinder G ro L-118 31.6-ft 1,1.17-ft 12.0-ft Use Travelin C tinder G ro L-212i 48.0-ft 1,579-ft 20.7-ft .Use Travelin C tinder G ro 2 Permit 10/10/05 - Grea~rudhoe Bay L-250 ML Permit Survey and Logging Program 13-~/2" Hole Section: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) O en Hole Drillin MWD / GR Cased hole: None 9-'/8" Hole Section: Surveys will need to be IFR + MS corrected real time Open Hole Drilling: MWD / GR / Res /Den / Neu /PWD Den / Neu recorded Open Hole: None Cased Hole: USIT Bond Lo onl as contin enc if oor cement 'ob 6-3/a" Hole Section: Surveys will need to be IFR + MS corrected real time Open Hole Drilling: MWD / GR / Res / Azimuthal Den / Neu /AIM /PWD Den / Neu recorded Cased Hole: None Mud Program Summary 13-'/2" Surface Hole Mud Pro erties: Spud -Freshwater Mud Interval /Densit Funnel vis YP Tauo PH Plastic Vis FL 0-1,800 8.6-9.2 250-300 50-70 10-18 8.5-9.0 20-45 NC-8 1,800 - 2,500 9.0 - 200 - 250 30 - 45 8 - 16 8.5 - 9.0 20 - 40 6 2,500 - 3,200 9.3 9. 200 30 - 40 9 - 14 8.5 - 9.0 14 - 20 5.5 - 7 Interval Specific Maintain Viscosity greater then 250 above the permafrost Objectives: Ensure fluid loss below permafrost is less then 6 ° Maintain mud tem erature below 50 F 9-'/8" Intermediate Hole Mud Pro erties: Freshwater Mud LSND PH: 9.0 - 9.5 Interval /Densit Funnel vis YP Tauo PV API Filtrate MBT 8.8-9.3 45-60 22-30 3-6 12-18 4-6 <20 Maintain proper fluid rheology & lubricant concentration to achieve the directional Interval Specific requirements Objectives: Optimize mud rheology to maximize ROP while following ECD guidelines Reduce shaker blindin while drilling the UGNU (Drill-n-Slide or EMI-697 ). 6-3/a" Production Hole Mud Pro erties: LVT-200 MOBM (Versa-Pro) Interval /Densit Stabilit YP Oil : H2O Ratio PV API Filtrate MBT 9.2 650 - 900 16 - 19 80:20 Initial < 19 < 5 < 6 Utilize PST to periodically check fluid bypass through screen sections to ensure proper PSD throughout each interval. Interval Specific Allow Oil /Water ratio to drift between 80:20 and 70:30 while maintaining standard Objectives: rheological properties. Minimize solids/liquid invasion by maintaining optimum PSD of bridging agents. Maintain minimal ECD's by reducing drill solids accumulation through utilization of the rigs solids control s stem and effective dilution. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the BOP period should not be requested. BOPE and drilling fluid system schematics are on file with the AOGCC. Intermediate and Production Intervals • Maximum anticipated BHP: 1,884 psi C«3 4,160' TVDss (8.7 ppg EMW). Based on L-216 MDT's ~ • Maximum surface pressure: 1,468 psi C~ surface (based on BHP & a full column of gas from TD C~ 0.10 psi/ft) • Planned BOP test pressure: 3,500 psi (7 5/8" casing will be tested to 3,500 psi) • Test Frequency: 14 day test cycle • Planned completion fluid: Estimated 9.1 ppg Brine / 6.8 ppg Diesel Permit 10/10/05 Grea~rudhoe Bay L-250. ML Permit 5,000 psi Working Pressure 3,500/250 psi Rams & Valves entire stack and valves 2,500/250 si Annular • Kick Tolerance/Integrity Testing: The 10-3/a" casing has been cemented to surface. The 7-5/a" casing will be cemented with 15.8 Ib/gal cement to (minimum of 700' MD above the Ma sand) within 1,000' of the surface casing shoe. Kick Tolerance / Inte ri Testin Summa Table Casin /Interval Acce table In x Volume Mud Wei ht Ex Pore Press Min LOT /FIT Surface / 9-'/e" 51.1 9.2 8.7 11.1 LOT Intermediate / 6-3/a" Infini 9.2 8.7 10.5 FIT NOTE: FIT's will only b ne on the first horizontal lateral due to pressure connectivity between subsequent laterals. NOTE: All LOT /FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the previous casin strin NOTE: If the LOT /FIT is less then the minimum notify the ODE immediately Disposal NO ANNULAR INJECTION ON THIS WELL. Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. Formation Markers formation Ta " :'."' ~ . F~ T~3s~ .F#: Ntd: :Pore sf, ~ EMV1t- H ctrocarbons _ ' G1 255 Xx 115 8.7 No SV6 890 Xx 401 8.7 No Fault #1 980 Xx 441 SV5 1,480 Xx 666 8.7 No SV4 1,600 Xx 720 8.7 Poss. Gas H drates Base Permafrost 1,680 1,937 756 8.7 No SV3 1,965 2,276 884 8.7 Poss. Gas H drates SV2 2,125 2,536 956 8.7 Poss. Gas H drates SV1 2,445 3,056 1,100 8.7 Poss. Gas H drates UG4 2,740 3,535 1,233 8.7 Thin coal UG4A 2,770 3,584 1,247 8.7 100' net Heavy Oil between 2770 - 2940' SS UG3 3,125 4,174 1,406 8.7 Thin coals/ oss. Hea oil Fault #2 3,545 4,878 1,595 UG1 3,640 5,037 1,638 8,7 80' net Heavy Oil between 3770 - 3910' SS Ma 3,920 5,507 1,764 8.7 40' net Heavy Oil between 3915 - 3950' SS Mb1 3,960 5,579 1,782 8,7 45' net Heavy Oil between 3960 - 4010' SS Mb2 4,015 5,688 1,807 8.7 60' net Heavy Oil between 4015 - 4090' SS Mc 4,090 5,867 1,841 8.7 15' net heavy oil between 4090 - 4130' SS Na 4,135 5,985 1,861 8.7 No Nb 4,160 6,051 1,884 8.7 Yes Nc 4,205 6,192 1,900 8.7 Yes OA 4,310 Xx 1,930 8.6 Yes Permit 10/10/05 Grea~rudhoe Bay L-250 ML Permit Casing/Tubing Program ll~~ W}~IYf'.: ' S r ` .. ~~ •r'~ ~/V~,`.~4't5f S i~:~ M .k ' 4 Y ,:.tip S. ~-, .. r T Y..4{ L~ .~-_ ,,.. .. aAi l~~V~a S..'~~ J`~.. { r .7/Sx~ ~ 'Y~11~r f ... . ~,.y.. } 1 1F.~+Vy~~~ ~ _ f '},=V'L1r ~~~ . ~. .. ~.. '+}~~!{~, .n 'n4 '1: ~M3.~IT; _. , 48" 20" X 34" 215.5# A53 Weld 80' 29'/29' 109'/109' 13-'h" 10-3/a" 45.5# L-80 BTC 3,191' 29'/29' 3,220'/2,545' 9-%8" 7 5/a" 29.7# L-80 BTC-M 6,695' 29'/29' 6,724'/4,305' 6-3/a" OA 4-~h" slotted 12.6# L-80 BTC 2.970' 6.700'/4,301' 9.670'/4.427' 6-3/4 L1 Nb " 8 Sc,.. 4 .x 4 reen _.. 15.5# -. L-80 ,, _ _ , _, . IBT _ _ . 2,490' _ _ ... - 289' 6 '/ _ ... ..,. ~ _ 11 4 34 ' ' , 6- /a L1 Nb , 4 Solid 10.9# L-80 IBT 2,490 ,636 4, , ,616 3 / 6-3/a„ L2 Nb 4" x 4.8" Screen 15.5# L-80 IBT 3,161; 214' 6 '/ 4 ' ' 6-3/4 L2 Nb 4 Solid 10.9# L-80 IBT 3,161 ,226 4, ,363 12,548 / Tubin 4-~/z" 12.75# L-80 TCII 6,217' 29'/29' 6,226'/4,214' NvTE: Un N-sand laterals, the base case plan is to run 50% screens and 50% blank pipe. This may change based on the as-drilled profile and LWD logs. Cement Calculations Casin Size 10-3/a -in 45.5-Ib/ft L-80 BTC surface casing Basis 250% excess in permafrost. 30% excess below permafrost. To of tail cement 1,000' MD above shoe Cement Vol: Wash 20-bbl CW Spacer S acer 70-bbl 10 - / al MudPush s acer Lead 464-bbl -sx 10.7-Ib/ al ASL - .4 /s-~ Cement to surface Tail 92-bbl 44 -sx 15.8-Ib/ al Premi G 1.1 t /sx To of tail: 2,219' MD Temp BHST = 55°F from SOR, BHCT 60°F estimated bV Dowell 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 7 5/a -in 29.7-Ib/ft L-80 BTC-M intermediate casing Basis Top of tail cement 700-ft MD above top of Schrader Ma-sand. 30% excess over gauge. Total Cement Vol: Wash 25-bbl Water S acer 45-bbl 10. / al MudPush S acer ~--- Tail 128 bbl, -sx 15.8-Ib/gal Premium - .20 /sx with D600G - 2gal/sk; D047 - 0.2ga1/s , 174 - 3% BWOC~ 8153 - 5gal/sk to of tail at 4,219-ft MD 'To Ma: 5,507' MD Temp BHST = 82°F from SOR, BHCT 77°F estimated by Dowell Drilling and Completion Scope of Work Pre-Rig Work: 1. A 34" x 20" insulated conductor has already been set and surveyed. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Prepare neighboring wells for the rig move and production simops. Drilling Riq Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and riser. Function test diverter. PU 4" DP and stand back in derrick. 2. MU 13-'/z" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,219' MD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sand. 3. Run and cement the 10-3/a", 45.5#, L-80 surface casing back to surface (NOTE: TAM port collar to be used at WSL ~, discretion). ND drilling spool and riser and NU casing /tubing head. NU BOPE and test to 3,500 psi. 5 Permit i0/10105 . Grea~rudhoe Bay L-250 ML Permit 4. MU 9-'/" directional drilling assembly with MWD/GR/Res/Den/Neu/PWD and a Weatherford Drill-Mill at 11,000' from the bit. RIH to float collar. Test the 10-3/a" casing to 3,500 psi for 30 minutes. 5. Drill out shoe track. Circulate and condition mud. Displace well to new 8.8 ppg LSND drilling fluid. Drill 20' of new /r formation below rathole and perform a LOT. Directionally drill ahead to TD (Into top OA as per geologist) as per directional profile to 6,724' MD. 6. Make short trip as needed, work tight spots as seen. Circulate and condition mud at TD. Make sure hole is clean prior to POOH. POOH for casing stand back 4" DP. h~ ~~`~ ~~~. '~ 7. MU and run 7 5/8" 29.7# L-80 BTC-M casing to TD. Cement in one stage to 1,000' MD•:atie~e~the surface casing shoe. Bump plug with seawater. Land casing on mandrel hanger. ~' NOTE: With cementing so close to the surface casing shoe, verify circulation down the annulus prior to the cement reaching 500 psi compressive strength. Minimize the volume pumped away prior to freeze protecting. 8. Clean pits for displacement. Freeze protect 7 5/" x 9 5/8" annulus with dead crude to 2,200' TVD. PU 4" DP. 9. PU 6-3/a" directional assembly with MWD / GR /Res / Azimuthal Den /Neu /PWD /AIM and RIH to the float collar. ~- Test the 7 5/8" casing to 3,500 psi for 30 minutes. Displace well over to new 9.2 ppg Versapro MOBM. Drill out shoe track, circulate and condition mud. Drill 20' of new form below rathole and perform an FIT to 10.5 ppg EMW. 10. Directionally drill ahead to TD geosteering through the O to TD at 9,670' MD / 4,428' TVD (prognosed). Backream out of hole to the shoe, circulate and condition hole, to TD and displace well to 9.2 ppg SFMOBM as per BP / MI displacement procedures. 11. POOH to near L1 Nb window depth, log up across the Nb, Nc sands to ensure proper window milling placements for subsequent laterals. POH LD drilling assembly. 12. MU and run 4-~h" 12.6# L-80 IBT-M slotted liner with hanger and liner top packer to TD. Position liner top packer 90' ~ below the planned L1 BOW. POOH and LD liner running assembly. NOTE: This assembly will require a plug to be run below the casing seal bore receptacle. See details in W P. 13. PU the 7 5/e' whipstock assembly. Set the whipsock on the OA liner top packer such that the top of the window is in the optimum position below the Nb sand to allow for at least 60' MD prior to entering the Nb sand (planned window exit: 6,623' MD). Orient whipstock to 15° left of highside. Shear off Whipstock. Displace wellbore back to MOBM as per BP / MI displacement procedures & mill window. POOH, LD milling assembly. 14. RIH with -3/a'j drilling assembly with MWD / GR /Res / Azimuthal Den/ Neu /PWD /AIM to whipstock. Directionally drill the 1 N,k~i lateral to TD. Planned TD is 11,615' MD. Backream out of hole to the window, circulate and condition hole, RI TD and displace well to 9.2 ppg SFMOBM as per BP / MI displacement procedures. POOH. /. 15. Pull whipstock #1, LD whipstock and retrieval BHA. 16. Run and set the 4" x 4.8" Baker Excluder 2000 screen assembly, Swell Packers, and Baker Hook Hanger, POOH and ~. LD liner running assembly. Run Baker Lateral Entry Module #1 with ZXP liner top packer. Circulate and condition mud, POOH and LD running tools. 17. PU the 7 5/8" whipstock assembly.. Set the whipsock on the L1 Nb liner top packer such that the top of the window is in the optimum position above the Nb sand to allow for at least 60' MD prior to entering the Nb sand (planned window exit: 6,213' MD). Orient whipstock to 15° left of highside. Shear off of Whipstock, displace well back to MOBM as per BP / MI displacement procedures & mill window. POOH 18. RIH with - "drilling assembly with MWD / GR /Res / Azimuthal Den/ Neu /PWD /AIM to whipstock. Directionally drill the 2 b lateral to TD. Planned TD is 12,548' MD. Backream out of hole to the window, circulate and condition hole, RI , o TD and displace well to 9.2 ppg SFMOBM as per BP / MI displacement procedures. POOH. 19. Pull whipstock #2, LD whipstock and retrieval BHA. 20. Run and set the 4" x 4.8" Baker Excluder 2000 screen assembly, Swell Packers, and Baker Hook Hanger, POOH and LD liner running assembly. Run Baker Lateral Entry Module #2 with ZXP liner top packer. Circulate and condition ~ mud. Clean pits for displacement. Displace over to 9.1 ppg KCL brine as per MI displacement procedures. POOH. 21. MU 4-~h" 12.75# TCII, L-80 completion assembly and RIH. See completion schematic for details. Land tubing hanger/ and run in lockdown screws. 22. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK-1 valve. 23. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 24. Pull two-way check. Reverse in brine with Corexit to protect the annulus and freeze protect the well to 2,200' TVD. Install VR plug in 7 5/8" casing annulus valves. 25. Install BPV. Secure the well and rig down /move off Nabors 9ES. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod /RHC plug. 2. Pull out DCK-1 shear valve, install GLV in all of the other mandrels as per the PE. 6 Permit 10/10/05 Grea~rudhoe Bay L-250 ML Permit Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE Well Control /Reservoir Pressures: Sand Heal Psi (ppgj TVDss Comments Nb 1,884(8.7) 4,160 Based on L-216 MDT pressures OA 1,930 (8.6) 4,310 Based on L-216 MDT pressures II. Hydrates and Shallow gas: A. Gas Hydrates are expected at L-pad near the base of the permafrost. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. If hydrates are encountered follow the recommended practice and apply good drilling operational practices. III. Lost Circulation/Breathing: A. Lost circulation is not expected at the L-Pad fault. In addition the fault will be crossed at high angle and move away quickly. B. We do not expect breathing on this well as we are above the more prevalent breathing shale's i.e. Seabee. IV. Kick Tolerance/Integrity Testing: A. The 10-3/a" casing has been cemented to surface. B. The 7 5/" casing will be cemented with 15.8 Ib/gal cement to within 1,000' of the surface casing shoe. C. Integrity Testing: NOTE: If the LOT /FIT is less then the minimum notify the ODE immediately Kick Tolerance / Inte rit Testin Summa Table Casin /Interval Acce table Influx Volume Mud Wei ht Exp Pore Press Min LOT /FIT Surface / 9'/e" 51.1 9.2 8.7 11.1 LOT Intermediate / 6-3/a" Infinite 9.2 8.7 10.5 FIT NOTE: FIT's will only be done on the first horizontal lateral due to pressure connectivity between subsequent laterals. NOTE: All LOT /FIT will be taken with a minimum of 20-ft and a maximum of 50-ft of new hole drilled outside of the revious Casin strin V. Stuck Pipe A. There could be slight differential sticking across the reservoir while running the slotted liners. Keep the liners moving as much as possible and run one centralizer per joint to help with standoff. VI. Hydrogen Sulfide L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at L pad as a result of the use of Ivishak gas lift gas. All L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. VII. Faults A. Two faults are expected to be crossed at L-202. No losses are expected to be associated with this fault. Details are listed below for reference: Fault Location MD TVDss Throw Direction Uncertainty Fault #1 - SV6 1,065' 980' 60' to 80' West +/- 150' MD Fault #2 - UG3 5,008' 3,545' 50' to 70' South +/- 150' MD Fault #3 - OA Leg 8,543' 4,348' 0' to 10' North +/- 250' MD Fault #4 - L1 Nb Leg 5,171' 4,216' 0' to 10' North +/- 250' MD CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 7 Permit 10/10/05 POST RIG -COMPLETION TREE: FMC 4-1/16" SM Orig KB elev (N-9ES) - 28.5' L-250, L-250 L1 & L-250 L2 WELLHEAD: FMC Gen 5 System 11", 5M csg.head w/ 7" mandrel hanger & packoff 11" x 11", 5M, tbg spool w/ 11" x 4-1/2" tubing hanger with control line ports 11" X 4-1/16" Adaptor Flange 20" X 34" 215.5 Ib/ft, A53 ERW Insulated i_ 109' X-Nipple (3.813" ID) 2,200' TVD 4-1/2", 12.75 Ib/ft, L-80, TCII Coupling OD: 4.932" Drift/ID : 3.833"/3.958" 10-3/4", 45.5# L-80 BTC Csg @ 3,219' MD 4.5" Baker sliding sleeve with 3.813" ID 7-5/8" X 5-1/2" Baker PRM Packer Phoenix Pressure Gauge with encapsulated I-wire to surface RA Tag TBD 4" x 6.4" OD Swell Packer on 4",10.9# base pipe 6-3/4" NB-2 Lateral 6,225'-12,548' Baker Hughes Hookwall Hanger @ 6,209' MD ~ TOW in 7-5/8" casing @ 6,213' MD BOW in 7-5/8" casing @ 6,225' MD Well Inclination @ Window = 75° RA Tag TBD bObC 5bb~ ~ Nb laterals will have 4" x 4.8" OD Baker Excluder screens and 4" 10.9 liner throughout. Minimum ID= 3.476", Drift:3.351" 6-3/4" NB-1 Lateral x,635'-11,615' Halliburton X-Nipple (3.813" ID) 4.5" WLEG -6,184' Junction Specifications: Junction ID through LEM Module without diverter: 3.65" 9.2 PPG Versapro SFMOBM below Completion Baker Hughes Hookwall Hanger @ 6,620` MD TOW in 7-5/8" casing @ 6,623' MD BOW in 7-5/8" casing @ 6,635` MD Well Inclination @ Window = 80° RA Tag TBD Baker ZXP Liner Top Packer & Hanger 7-5/8", 29.7#, L-80, BTC-M Casing Drift: 6.75" 7-5/8" Casing Shoe @ ,72,,4' MD Casing ID: 6.875" ~/ DATE ~ REV. BY ~ COMMENTS 66`'M D C~tDC tuGl~ 6-314" OA Lateral ~ 6,724'- 9,670' GP ~df~l",~"rv'~o~ ~ ~ r API NO: 50-029-xxxxx-00 ORION 50-029-xxxxx-00 WELL: L-250 ML 5o-029-xxxxx-01 10I11I2005 ~ MIK TRIOLO ~ Level 3Multi-lateral, 4-112" GL Completion OA lateral will have 4- 1/2" 12.6# slotted liner. Minimum ID= 3.958", Drift:3.833" by L-250 (P12) Schlumberger Proposal Report Date: September 9, 2005 Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 9.570° Field: Structure 1 Slot: Prudhoe Bay Unit - WOA L-PAD / L-250 (NM-15) ~~ Vertical Section Origin: N 0.004 ft, W 0.005 ft ~ TVD Reference Datum: Rotary Table Well: Plan L-250 (NM-15) ~f ~~ TVD Reference Elevation: 77.50 ft relative to MSL Borehole: ~~~ Plan L-250 ~~ Sea Bed 1 Ground Level Elevation: 49.00 ft relative to MSL UWIIAPM: 50029 Magnetc Declination: 24.428° Survey Name 1 Date: L-250 (P12) I September 7, 2005 Total Field Strength: 57577.107 nT Tort 1 AHD 1 DDI 1 ERD ratio: 149.847° 17493.27 ft 16.389 / 1.691 Magnetic Dip: 80.848° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: November 05, 2005 Locaton LatlLong: N 70.35064557, W 149.32453840 Magnetic Declination Model: BGGM 2005 Location Grid NIE YIX: N 5978285.860 ftUS, E 583194.780 ftUS North Reference: True North Grid Convergence Angle: +0.63613156° Total Corr Mag North -> True North: +24.428° Grid Scale Factor. 0.99990786 Local Coordinates Referenced To: Well Head • Measured Vertical Comments Inclination Azimuth SulrSea TVD TVD NS EW Tool Face DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft ft ft ft ft de de 100 ft de 100 ft de H00 ft ftUS ftUS rtIC V .VV U.UU V.VU -// AU U.UU U .UU U.UU V.VV U.VUIVI U.UU V.UV U.UU b`J/8Lt5b.tSb O7i31`J4./O IV /U.30Ub4bb/ VV 14y. 3L403if4U KOP Bld 1.5/100 500 .00 0.00 0.00 422. 50 500.00 0 .00 0.00 0.00 O.OOM 0.00 0.00 0.00 5978285.86 583194.78 N 70.35064557 W 149. 32453840 Bld 3/100 600 .00 1.50 0.00 522. 49 599.99 1 .29 1.31 0.00 O.OOM 1.50 1.50 0.00 5978287.17 583194.77 N 70.35064914 W 149. 32453840 700 .00 4.50 0.00 622. 34 699.84 6 .45 6.54 0.00 O.OOM 3.00 3.00 0.00 5978292.40 583194.71 N 70.35066344 W 149. 32453840 Crv 4/100 800 .00 7.50 0.00 721. 78 799.28 16 .75 16:99 0.00 6.01G 3.00 3.00 0.00 5978302.85 583194.59 N 70.35069199 W 149. 32453840 900 .00 11.49 2.10 820. 39 897.89 33 .07 33.48 0.37 3.94G 4.00 3.99 2.10 5978319.33 583194.77 N 70.35073702 W 149. 32453544 1000 .00 15.48 3.13 917. 62 995.12 56 .21 56.76 1.46 2.94G 4.00 3.99 1.03 5978342.63 583195.61 N 70.35080063 W 149. 32452655 1100 .00 19.47 3.74 1012. 98 1090.48 86 .06 86.73 3.28 2.35G 4.00 4.00 0.61 5978372.61 583197.09 N 70.35088250 W 149. 32451179 1200 .00 23.47 4.16 1106. 02 1183.52 122 .49 123.24 5.81 1.97G 4.00 4.00 0.41 5978409.14 583199.22 N 70.35098225 W 149. 32449123 1300 .00 27.47 4.45 1196. 28 1273.78 165 .30 166.11 9.04 1.70G 4.00 4.00 0.30 5978452.05 583201.98 N 70.35109937 W 149. 327 1400 .00 31.47 4.68 1283. 33 1360.83 214 .30 215.14 12.97 1.50G 4.00 4.00 0.23 5978501.11 583205.36 N 70.35123331 W 149. 324A~314 1500 .00 35.47 4.86 1366. 73 1444.23 269 .24 270.09 17.56 1.35G 4.00 4.00 0.18 5978556.10 583209.33 N 70.35138342 W 149. 32439588 1600 .00 39.47 5.01 1446. 09 1523.59 329 .86 330.68 22.79 1.23G 4.00 4.00 0.15 5978616.74 583213.90 N 70.35154895 W 149. 32435338 1700 .00 43.46 5.13 1521. 01 1598.51 395 .86 396.62 28.64 1.14G 4.00 4.00 0.12 5978682.74 5$3219.02 N 70.35172910 W 149. 32430586 1800 .00 47.46 5.24 1591. 13 1668.63 466 .92 467.60 35.09 1.06G 4.00 4.00 0.11 5978753.77 583224.67 N 70.35192300 W 149. 32425353 1900 .00 51.46 5.34 1656. 11 1733.61 542 .69 543.26 42.09 1.OOG 4.00 4.00 0.09 5978829.50 583230.84 N 70.35212969 W 149. 32419666 End Crv 1913 .99 52.02 5.35 1664. 77 1742.27 553 .65 554.20 43.12 O.OOG 4.00 4.00 0.09 5978840.45 583231.74 N 70.35215958 W 149. 32418835 SV3 2275. 95 52.02 5.35 1887. 50 1965.00 838. 19 838.27 69.71 O.OOG 0.00 0.00 0.00 5979124.77 583255.17 N 70.35293564 W 149. 32397244 SV2 2535. 97 52.02 5.35 2047. 50 2125.00 1042. 60 1042.34 88.81 O.OOG 0.00 0.00 0.00 5979329.02 583272.01 N 70.35349314 W 149. 32381732 SV1 3056. 00 52.02 5.35 2367. 50 2445.00 1451. 41 1450.48 127.02 O.OOG 0.00 0.00 0.00 5979737.52 583305.67 N 70:35460814 W 149. 32350707 10-3/4" Csg Pt 3218. 51 52.02 5.35 2467. 50 2545.00 1579. 16 1578.02 138.96 O.OOG 0.00 0.00 0.00 5979865.18 583316.20 N 70.35495657 W 149. 32341011 3368 .84 52.02 5.35 2560. 00 2637.50 1697 .33 1696.00 150.00 O.OOG 0.00 0.00 0.00 5979983.26 583325.93 N 70.35527888 W 149. 32332041 Crv 4/100 3388 .84 52.02 5.35 2572. 31 2649.81 1713 .05 1711.70 151.47 93.39G 0.00 0.00 0.00 5979998.97 583327.22 N 70.35532176 W 149. 32330848 WeIlDesign Ver SP 1.0 Bld(doc40x_56) L-250 (NM-15 )\Plan L-250 (NM-15)1PIan L-250\L-250 (P12) Generated 9/9/2005 9:21 AM Page 1 of 3 Measured Vertical Comments Inclination Azimuth Sub-Sea TVD TVD NS EW Tool Face DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft ft (ft ft ft de de 1100 ft de 100 ft de 1100 ft fIUS ftUS 34w. w b2. uu 5 .91 25/9.113 2ti5ti .titf 1 /21. 133 1 /20 .45 152.33 93.U5Ci 4.UU -U.22 5.U/ 5913000/.73 5133327.99 N /U.3553451i8 W 149 .32330147 3500. 00 51. 89 10 .99 2640.84 2718 .34 1800. 51 1798 .30 163.90 89.91 G 4.00 -0.10 5.08 5980085.69 583338. 69 N 70 .35555834 W 149 .32320754 UG4 3535. 10 51. 91 12. 78 2662.50 2740. 00 1828. 11 1825. 32 169.59 88.81G 4.00 0.04 5.08 5980112.78 583344. 08 N 70. 35563217 W 149. 32316135 UG4A 3583. 76 51, 98 15. 25 2692.50 2770. 00 1866. 31 1862. 49 178.86 87.29G 4.00 0.14 5.08 5980150.05 583352. 94 N 70. 35573372 W 149. 32308602 3600. 00 52. 01 16 .07 2702.50 2780 .00 1879. 03 1874 .81 182.32 86.78G 4.00 0.21 5.07 5980162.41 583356. 25 N 70 .35576738 W 149 .32305798 3700. 00 52. 34 21 .12 2763.85 2841 .35 1957. 00 1949 .64 207.50 83.69G 4.00 0.33 5.05 5980237.50 583380. 60 N 70. 35597178 W 149 .32285350 3800. 00 52. 89 26 .10 2824.59 2902 .09 2034. 03 2022 .40 239.31 80.66G 4.00 0.55 4.99 5980310.60 583411. 61 N 70. 35617056 W 149 .32259511 End Crv 3871. 50 53. 40 29. 62 2867.48 2944 .98 2088. 34 2072 .96 266.05 O.OOG 4.00 0.72 4.92 5980361.45 583437. 77 N 70. 35630868 W 149 .32237800 UG3 4173.46 53. 40 29. 62 3047.50 3125. 00 2316. 08 2283. 71 385.87 O.OOG 0.00 0.00 0.00 5980573.50 583555. 24 N 70. 35688442 W 149. 32 Fault Crossing 4877. 96 53. 40 29. 62 3467.50 3545. 00 2847. 41 2775. 41 665.43 O.OOG 0.00 0.00 0.00 5981068.22 583829. 29 N 70. 35822763 W 149. 1 319 UG1 5037.31 53. 40 29. 62 3562.50 3640. 00 2967. 59 2886. 62 728.66 O.OOG 0.00 0.00 0.00 5981180.12 583891. 28 N 70. 35853145 W 149. 3186 0 Crv 4/100 5476. 75 53. 40 29 .62 3824.48 3901 .98 3299. 01 3193 .33 903.04 O.OOG 0.00 0.00 0.00 5981488.71 584062. 23 N 70 .35936929 W 149 .31720435 5500. 00 54. 33 29 .63 3838.19 3915 .69 3316. 65 3209 .65 912.32 O.OOG 4.00 4.00 0.03 5981505.14 584071. 33 N 70 .35941388 W 149 .31712895 Ma 5507. 42 54. 63 29. 63 3842.50 3920. 00 3322. 33 3214. 90 915.30 O.OOG 4.00 4.00 0.03 5981510.42 584074. 25 N 70. 35942821 W 149. 31710471 Mb1 5579. 07 57. 50 29. 65 3882.50 3960. 00 3378. 16 3266. 57 944.70 O.OOG 4.00 4.00 0.03 5981562.40 584103. 07 N 70. 35956936 W 149. 31686591 5600. 00 58. 33 29 .65 3893.61 3971 .11 3394. 81 3281 .97 953.47 O.OOG 4.00 4.00 0.02 5981577.91 584111. 67 N 70. 35961145 W 149 .31679466 Mb2 5688. 04 61. 86 29. 67 3937.50 4015. 00 3466. 47 3348. 28 991.23 O.OOG 4.00 4,00 0.02 5981644.62 584148. 69 N70. 35979257 W149. 31648791 5700. 00 62. 33 29 .68 3943.10 4020 .60 3476. 40 3357 .46 996.47 O.OOG 4.00 4.00 0.02 5981653.86 584153. 82 N 70. 35981766 W 149 .31644539 5800. 00 66. 33 29. 70 3986.40 4063 .90 3561. 02 3435 .75 1041.10 O.OOG 4.00 4.00 0.02 5981732.63 584197. 57 N 70. 36003152 W 149 .31608284 L-250 Tgt 1 5816. 66 67. 00 29. 70 3993.00 4070 .50 3575. 38 3449 .04 1048.67 23.14G 4.00 4.00 0.02 5981746.00 584205. 00 N 70. 36006781 W 149 .31602128 End Crv 5831. 33 67. 54 29. 95 3998.67 4076 .17 3588. 08 3460 .78 1055.41 O.OOG 4.00 3.68 1.70 5981757.82 584211. 60 N 70. 36009989 W 149 .31596658 Mc 5867. 53 67. 54 29. 95 4012.50 4090. 00 3619, 44 3489. 76 1072.11 O.OOG 0.00 0.00 0.00 5981786.98 584227. 98 N 70. 36017907 W 149, 31583091 Na 5985.32 67. 54 29. 95 4057.50 4135. 00 3721. 48 3584. 08 1126.45 O.OOG 0.00 0.00 0.00 5981881.89 584281. 27 N 70. 36043671 W 149. 31538942 Crv 4/100 6026. 18 67. 54 29. 95 4073.11 4150 .61 3756. 87 3616. 80 1145.30 O.OOG 0.00 0.00 0.00 5981914.81 584299. 75 N 70. 36052609 W 149 .31523627 Nb 6051. 32 68. 55 29. 95 4082.51 4160. 01 3778. 73 3637. 00 1156.94 O.OOG 4.00 4.00 0.02 5981935.14 584311. 17 N 70. 36058127 W 149. 31514169 6100. 00 70. 49 29. 96 4099.54 4177 .04 3821. 47 3676. 51 1179.71 O.OOG 4.00 4.00 0.02 5981974.90 584333. 50 N 70. 36068920 W 149. 31495669 Nc 6192. 16 74. 18 29. 98 4127.50 4205. 00 .3903. 76 3752. 57 1223.57 O.OOG 4.00 4.00 0.02 5982051.43 584376. 50 N 70. 36089696 W 149. 31460038 6200. 00 74. 49 29 .98 4129.62 4207 .12 3910. 84 3759 .11 1227.35 O.OOG 4.00 4.00 0.02 5982058.01 584380. 20 N 70. 36091483 W 149 .31 6300. 00 78. 49 29 .99 4152.97 4230 .47 4001. 95 3843 .31 1275.93 O.OOG 4.00 4.00 0.02 5982142.74 584427. 85 N 70. 36114484 W 149 .314 97 L-250 Tgt 2 6337. 68 80. 00 30 .00 4160.00 4237 .50 4036. 64 3875 .37 1294.44 -91.38G 4.00 4.00 0.02 5982175.00 584446. 00 N 70. 36123241 W 149 .31402461 6400. 00 79. 95 27 .47 4170.85 4248 .35 4094. 60 3929 .18 1323.94 -90.94G 4.00 -0.08 -4.06 5982229.12 584474. 90 N 70. 36137939 W 149 .31378491 6500. 00 79. 91 23 .41 4188.34 4265 .84 4189. 29 4018 .07 1366.22 -90.23G 4.00 -0.04 -4.06 5982318.47 584516. 18 N 70. 36162222 W 149 .31344135 6600. 00 79. 92 19 .34 4205.87 4283 .37 4285. 64 4109 .73 1402.10 -89.52G 4.00 0.01 -4.06 5982410.52 584551. 04 N 70. 36187261 W 149 .31314981 6700. 00 79. 98 15. 28 4223.33 4300 .83 4383. 18 4203. 72 1431.39 -88.81 G 4.00 0.06 -4.06 5982504.81 584579. 28 N 70. 36212935 W 149 .31291172 7-5/8" Csg Pt 6724. 04 80. 00 14. 31 4227.51 4305. 01 4406. 76 4226. 61 1437.44 -88.64G 4.00 0.09 -4.06 5982527.77 584585. 08 N 70. 36219189 W 149. 31286257 Crv 6/100 6726. 64 80. 00 14 .20 4227.96 4305 .46 4409. 31 4229 .09 1438.07 -90.46G 4.00 0.10 -4.06 5982530.25 584585. 68 N 70. 36219865 W 149 .31285746 6800. 00 79. 99 9. 73 4240.71 4318 .21 4481. 47 4299 .74 1453.04 -89.68G 6.00 -0.01 -6.09 5982601.06 584599. 86 N 70. 36239167 W 149 .31273572 6900. 00 80. 08 3. 64 4258.02 4335 .52 4579. 79 4397 .52 1464.50 -88.63G 6.00 0.09 -6.09 5982698.95 584610. 24 N 70. 36265878 W 149 .31264249 End Crv 6989. 92 80. 26 358. 17 4273.39 4350 .89 4667. 35 4486. 07 1465.90 O.OOG 6.00 0.19 -6.09 5982787.51 584610. 65 N 70. 36290070 W 149. 31263102 Crv 6/100 7171. 58 80. 26 358. 17 4304.13 4381 .63 4842. 84 4665. 01 1460.17 -147.42G 0.00 0.00 0.00 5982966.36 584602. 93 N 70. 36338955 W 149. 31267727 End Crv 7176. 64 80. 00 358. 00 4305.00 4382 .50 4847. 73 4670. 00 1460.00 O.OOG 6.00 -5.05 -3.28 5982971.34 584602. 71 N 70. 36340317 W 149. 31267862 WeIlDesign Ver SP 1.0 Bld(doc40x_56) L-250 (NM-15)\Plan L-250 (NM-15)1PIan L-250\L-250 (P12) Generated 9!9/2005 9:21 AM Page 2 of 3 Measured Vertical Comments Inclination Azimuth SulrSea ND ND NS EW Tool Face DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section ft de de ft ft ft ft ft (de de 100 ft de 100 ft de 1100 ft ftUS ftUS Grvti/lUU /19(1.64 BU.UU 358.00 4308.4/ 4385.9/ 488/.03 41189.68 1459.31 -19.8UG U.UU U.UU U.UU 5982991.01 5846UL8U N 70.36345695 W 149.31268417 7200.00 80.19 357.93 4309.05 4386.55 4870.27 4692.99 1459.20 -19.79G 6.00 5.65 -2.06 5982994.32 584601.65 N 70.36346599 W 149.31268512 7300.00 85.84 355.90 4321.21 4398.71 4967.07 4792.06 1453.84 -19.54G 6.00 5.65 -2.03 5983093.31 584595.20 N 70.36373663 W 149.31272844 End Crv 7326.45 87.34 355.37 4322.78 4400.28 4992.70 4818.38 1451.83 O.OOG 6.00 5.66 -2.01 5983119.61 584592.90 N 70.36380855 W 149.31274473 Crv 6/100 7664.39 87.34 355.37 4338.49 4415.99 5319.95 5154.86 1424.56 -56.28G 0.00 0.00 0.00 5983455.73 584561.89 N 70.36472778 W 149.31296576 7700.00 88.52 353.59 4339.78 4417.28 5354.31 5190.28 1421.13 -56.22G 6.00 3.33 -4.99 5983491.10 584558.07 N 70.36482454 W 149.31299352 L-250 Tgt 4 7709.79 88.85 353.10 4340.00 4417.50 5363.71 5200.00 1420.00 -40.36G 6.00 3.34 -4.99 5983500.81 584556.83 N 70.36485110 W 149.31300273 End Crv 7723.34 89.47 352.57 4340.20 4417.70 5376.68 5213.44 1418.31 O.OOG 6.00 4.57 -3.89 5983514.23 584554.99 N 70.36488782 W 149.31301643 Crv 6/100 8712.15 89.47 352.57 4349.36 4426.86 6322.26 6193.92 1290.51 93.85G 0.00 0.00 0.00 5984493.14 584416.33 N 70.36756645 W 149.314 L-250 Tgt 5 8769.38 89.24 356.00 4350.00 4427.50 6377.46 6250.85 1284.81 89.80G 6.00 -0.40 5.99 5984550.00 584410.00 N 70.36772199 W 149.314 8800.00 89.25 357.84 4350.40 4427.90 6407.33 6281.42 1283.17 89.78G 6.00 0.02 6.00 5984580.55 584408.02 N 70.36780550 W 149.3141 0 End Crv 8825.87 89.25 359.39 4350.74 4428.24 6432.73 6307.28 1282.54 O.OOG 6.00 0.02 6.00 5984606.40 584407.10 N 70.36787616 W 149.31411785 Crv 6/100 9140.34 89.25 359.39 4354.84 4432.34 6742.22 6621.70 1279.19 59.15G 0.00 0.00 0.00 5984920.73 584400.26 N 70.36873513 W 149.31414462 L-250 Tgt 6 9164.61 90.00 0.64 4355.00 4432.50 6766.15 6645.97 1279.20 -0.34G 6.00 3.08 5.15 5984945.00 584400.00 N 70.36880143 W 149.31414454 End Crv 9174.16 90.57 0.64 4354.95 4432.45 6775.58 6655.52 1279.30 O.OOG 6.00 6.00 -0.04 5984954.54 584400.00 N 70.36882751 W 149.31414366 TD / 4-1/2" Lnr 9669.68 -' 90.57 0.64 4350.00 4427.50 7265.07 7150.99 1284.81 O.OOG 0.00 0.00 0.00 5985450.00 584400.00 N 70.37018108 W 149.31409823 • WeIlDesign Ver SP 1.0 Bld( doc40x_56) L-250 (NM-15)\Plan L-250 (NM-15)\Plan L-250\L-250 (P12) Generated 9/9/2005 9:21 AM Page 3 of 3 by Schlumberger WELL L-250 (P12) FIELD Prudhoe Bay Unit - WOA STRD`nRE L-PAD Ma9n&ic Parameters Surlaw Lwab°n NRp2] Alsska Salta PLSnes.2°re 66. US Feat M1scelaneous MoCaL BGGM 2005 piV. BO.B6B° Dale. NUYembel05. 21105 Lal N]0312316 NenReq. 59]B2BS.B8 RUS GnC Conv .0 fi3fi131 Sfi" SI°r. L-250 ~NM-151 ND ReI- P°Mry Tabk (]l SORabOVe MSLI Magpec'. X26 a28° F5. tnT Lon W169192B ]3B Eastvg. 583190 ]B RUS Bcalo Fad 099990]8fi25 PMn. L-2501P12) Srry Date SeplemBerO). 2005 0 1000 2000 3000 4000 5000 6000 7000 0 1000 O 0 2000 C N U 0 I- 3000 4000 KOP 81d 1.SN00 Bid 31100 crv moo End CTv -.....-..-p_.._..-..-..-..-.._. ). _..-..-..-..-..-.._.._..y.. ° - - - - _ _.._.._.. _.. _.._..70.3!0' C -.._.._.._4_.._.._.._..-..-..-.._. _i._.._.._.. ...-.. _.. _ p _..-..-..-.. -..-.. _.._.. _I. _.. _..-.. -..-.. _.. _.. _.. y.. -.._..-.. .. _.. _.. _..-..-.._..-. _i. .._.._.._.._.._..-..-. ...-..-..-..-..-..-..-..i.._.._..-..-..-.._..-..-..y.._.._.._..-..-.._.._.._.~_..-..-..-..-..-..-.._.._ i.-.. _.....-..-..-..-..-..->._..-..-..-..-..-... Csg Pt i 4N 00 ..._.._.._.. _..-..-..-..~..-..-..-..-..-..-.._..-..}..-..-..-.._.._.._.._.._.1_.._..-..-..-..-..-..-..-s._..-.._.. _.. _.. _..-..-..y._.._..-..-..-.._... End Crv Fault Crossing crv anoo ......-..-..-..-..-..-. ' ._.. .._.._.._..-. i..._.._.._.._.._.._.._.._.i-..-..-..-..-..-.._.._.._ _.._..-..-..-..-..- .-. - - .~.._. _ L-2507gqt~:1 .. .. ..-..-..-..- End C '~ Crv 4110 7- 6" gPt L-~50 Tgt 5 ...-..-..-.._.._.._.. _.. ~.. _.._ .._. Il• ~.._..i•..~.250 Tat 2..J.,kSY~~Y15_.._.._.._..-..-..-.._.._o-_.._.. ~..-..-..-..-. ' -250 (P72) Crv 6110 End Crv Crv 61100 End Crv Crv 6/100 ~ Crv 61100 End ~rv End Crv ;L-250 Tgt 4 L-250 Tgt 6 • 1000 ?000 3000 4000 0 1000 2000 3000 4000 5000 6000 7000 Vertical Section (ft) Azim = 9.57°, Scale = 1(in):1000(ft) Origin = 0.00442948 N/-S, -0.00458698 E/-V by Schlumberger WELL FIELD STRUCNRE L-250 (P12) Prudhoe Bay Unit - WOA L-PAD Ma9neec Parameters Su~ace Lacalicn NA022 Alaska Slate Pbnas. Zone 09. US Feel ~ cellaneous Mc~el BGGM 2005 Di0 BO B<6' Date: November 05. 2005 Lal. N]0212 J2< n~ing S9)62B5 N6 aU5 GnO COnv. bb]61J~56' Slor L~2`A ~NM~'.51 ND ReI. Rotary Tale 1/)509 afwve AlSLi Ma9 Dec: ~2S a2B' FS 515]]'. nT Lon' 4V`a9 '926 ]l8 Eastng 59J'9e /6'tt15 Sule Fact 099990)6625 Plan L-2501P'21 Sny Dale. Segem0er 0/ 2005 -1000 0 1000 l 2000 3000 7000 6000 5000 n A n Z x 4000 0 O O C 0) t0 ~ 3000 V V V 2000 1000 TD 14-112" Lnr - 0 (P72) End Crv L-250 Tgt 6 crv shoo End Crv: L-250 Tgt 5 N crvsnoQ End Crv L-250 Tg14 Crv 61100 ................................................................:..................................y......... ....................-i..................................:........... End CK. crv w~9o End Crv - 50 Poy Crv 91100 -918" Csg Pt End Cry Crv 61100: L-250 Tgt 2 Crv 41100 End Crv L-250 Tgt 1 Crv 4/100 Eauk Crosain - Flt 2 OA L- 50 FIK3 O End CN ............................. ~.................................. ~....... .........................;.................................. i.................................. ~........... Crv 4N 00 L-250 Flt 1 OA 10314" Csg Pt: ~ P End Crv Crv 4/700 Bld 3N00 .............................:....... ... ....... RTE .....................:..................................:..................................:........... KOP Bld 1.51100 7000 6000 5000 4000 3000 2000 1000 -1000 0 1000 2000 300 «< W Scale = 1(in):1000(ft) E »> • BP Alaska Anticollision Report - -- - - Company: BP Amoco Date: 9!9/2005 Time: 15:03:41 Page: 1 Field: Prudhoe Bay r Keference Site: PB L Pad Co-ordinate(NE) Keferencr. Well: Plan L-250 (NM-15), True North Reference Wcll: Plan L-250 (NM-15) Vertical ('CVD) Refere nce: L-250 Pla n 77.5 ~ Reference Wcllpath: - Plan L-250 Db: Oracle _ __ _ _ NO GLOBAL SCAN: Using user defined selection & scan criteria _ Reference: Principal Plan & PLANNED PROGRAM ~ Interpolation Method: MD Interval: 20.00 ft Erro r Model: ISCWSA Ellipse Depth Range: 28.50 to 9669 .68 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft Erro r Surface: Ellipse + Casing Iii Survey Program for Definitive Wcllpath I Date: 5/12/2005 Validated: No Version: 2 I Planned From To Survey Toolcode Tool Name ft ft ', ~ 28.50 1500.00 Planned: Plan #12 V1 GYD-GC-SS Gyrodata gyro single shots 1500.00 2900.00 Planned: Plan #12 V1 MWD MWD - Standard 1500.00 9669.68 Planned: Plan #12 V1 MWD+IFR+MS MWD +IFR + Mu lti Station Casing Points MD fVD Diameter Hole Size Name ft ft in in 3344.46 2622.50 - - - - 10.750 - -_ 13.375 10 3/4" _ 7176.64 4382.50 7.625 9.875 7-5/8" 9669.68 4427.50 4.500 6.750 41/2" I' Summary <____--_______ p ffset Wcllpath ------ ------> Reference Offset Ctr-Ctr No-Go Allowable Site W'cll Wcllpath MD ly1D llistancc Arca Deviation Warning - -- - ft - - ft ft ft ft - PB L Pad -- - -- L-01 - - __ _ L-01 V14 - 360.79 360.00 182.13 6.04 176.09 I _ _ I Pass: Major Risk ' PB L Pad L-02 L-02 V1 691.82 700.00 140.52 11.39 129.13 Pass: Major Risk PB L Pad L-02 L-02A V5 677.98 680.00 140.33 11.31 129.03 Pass: Major Risk PB L Pad L-02 L-02AP61 V2 677.98 680.00 140.33 11.31 129.03 Pass: Major Risk PB L Pad L-02 L-02P61 V21 691.82 700.00 140.52 11.50 129.02 Pass: Major Risk ~~ PB L Pad L-03 L-03 V5 744.46 760.00 156.95 13.91 143.05 Pass: Major Risk I PB L Pad L-101 L-101 V4 1277.26 1320.00 143.94 23.63 120.31 Pass: Major Risk ', PB L Pad L-102 L-102 V2 278.50 280.00 255.44 4.55 250.89 Pass: Major Risk PB L Pad L-102 L-102P61 V10 278.50 280.00 255.44 4.64 250.80 Pass: Major Risk PB L Pad L-102 L-102P62 V2 278.50 280.00 255.44 4.64 250.80 Pass: Major Risk PB L Pad L-103 L-103 V23 680.53 680.00 109.23 11.04 98.18 Pass: Major Risk PB L Pad L-104 L-104 V7 398.39 400.00 233.14 6.72 226.42 Pass: Major Risk PB L Pad L-105 L-105 V4 498.67 500.00 212.97 9.10 203.87 Pass: Major Risk PB L Pad L-106 L-106 V14 838.47 860.00 193.58 14.28 179.30 Pass: Major Risk PB L Pad L-107 L-107 V14 240.16 240.00 183.04 5.29 177.74 Pass: Major Risk PB L Pad L-108 L-108 V18 725.84 740.00 184.45 13.17 171.28 Pass: Major Risk ', i PB L Pad L-109 L-109 V12 341.09 340.00 188.14 7.10 181.04 Pass: Major Risk ~I PB L Pad L-110 L-110 V11 280.39 280.00 206.84 5.20 201.64 Pass: Major Risk PB L Pad L-111 L-111 V24 281.29 280.00 274.50 5.09 269.41 Pass: Major Risk ' PB L Pad L-112 L-112 V8 375.44 380.00 162.67 7.89 154.78 Pass: Major Risk PB L Pad L-114 L-114 V15 614.01 620.00 248.18 9.85 238.33 Pass: Major Risk PB L Pad L-114 L-114A V4 614.01 620.00 248.18 9.85 238.33 Pass: Major Risk j ', PB L Pad L-115 L-115 V7 638.60 640.00 81.23 10.92 70.31 Pass: Major Risk PB L Pad L-116 L-116 V10 669.44 680.00 190.44 10.65 179.79 Pass: Major Risk ', PB L Pad L-117 L-117 V11 619.79 620.00 72.31 10.07 62.23 Pass: Major Risk I PB L Pad L-118 L-118 V9 1116.70 1120.00 31.59 19.57 12.01 Pass: Major Risk li PB L Pad L-119 L-119 V9 518.77 520.00 153.51 8.85 144.66 Pass: Major Risk PB L Pad L-120 L-120 V8 298.38 300.00 182.22 5.21 177.01 Pass: Major Risk i i PB L Pad L-121 L-121 V14 221.08 220.00 224.06 4.08 219.98 Pass: Major Risk PB L Pad L-121 L-121A V1 221.08 220.00 224.06 4.08 219.98 Pass: Major Risk PB L Pad L-122 L-122 V5 360.50 360.00 115.93 6.04 109.89 Pass: Major Risk PB L Pad L-124 L-124 V11 658.60 660.00 171.35 11.72 159.64 Pass: Major Risk ', PB L Pad L-124 L-124P61 V5 658.60 660.00 171.35 11.72 159.64 Pass: Major Risk !, PB L Pad L-124 L-124PB2 V4 658.60 660.00 171.35 11.72 159.64 Pass: Major Risk i PB L Pad L-200 L-200 V7 319.81 320.00 15.53 5.72 9.80 Pass: Major Risk PB L Pad L-200 L-200L1 V3 319.81 320.00 15.53 5.72 9.80 Pass: Major Risk PB L Pad L-200 L-200L2 V6 319.81 320.00 15.53 5.72 9:80 Pass: Major Risk PB L Pad L-200 Plan L-200L3 OA V1 Pla 319.81 320.00 15.53 5.94 9.59 Pass: Major Risk PB L Pad L-200 Plan L-200L3P61 OA V4 319.81 320.00 15.53 5.84 9.69 Pass: Major Risk PB L Pad L-201 L-201 V6 298.78 300.00 135.34 5.22 130.12 Pass: Major Risk ~ PB L Pad L-201 L-201 L1 V9 298.78 300.00 135.34 5.22 130.12 Pass: Major Risk • BP Alaska Anticollision Report Company: BP Amoco Field: Prudhoe Bay Reference Site: PB L Pad Reference Well: Plan L-250 (NM-15) Reference We{{path: Plan L-250 Summary <- ------- Offset Wellpath --- Site Well Wellpath i~ PB L Pad L-201 L-201 L1P61 V10 PB L Pad L-201 L-201 L2 V5 PB L Pad L-201 L-201 L3 V2 " PB L Pad L-201 L-201L3PB1 V6 PB L Pad L-201 L-201 PB1 V12 '! PB L Pad L-201 L-201 P62 V3 PB L Pad L-202 L-202 V5 j PB L Pad L-202 L-202L1 V7 PB L Pad L-202 L-202L2 V6 PB L Pad L-202 L-202L3 V6 ~~~ PB L Pad L-210 L-210 V6 i PB L Pad L-210 L-210PB1 V8 PB L Pad L-211 L-211 V6 PB L Pad L-211 L-211 P61 V6 PS L Pad L-212 L-212 V11 PB L Pad L-212 L-212PB1 V9 PB L Pad L-212 L-212PB2 V2 PB L Pad L-214 L-214 V9 PB L Pad L-215 L-215P61 V2 Plan: Plan PB L Pad L-215 Plan L-215 V5 Plan: PI PB L Pad L-216 L-216 V6 PB L Pad L-218 L-218 V4 PB L Pad NWE1-01 L-100 V2 PB L Pad NWE1-01 NWE1-01 V5 PB L Pad Plan L-123 (S-U) Plan L-123 V3 Plan: PI PB L Pad Plan L-125 (N-F) Plan L-125 VO Plan: PI PB L Pad Plan L-125 (N-F) Plan L-125P61 V1 Plan: ', PB L Pad Plan L-213 (S-Q) Plan L-213 V5 Plan: PI ', PB L Pad Plan L-50 (S-D) Plan L-50 V2 Plan: Pla ', PB L Pad Plan L-51 (S-B) Plan L-51 V1 Plan: Pla PB L Pad Plan L-52 (S-E) Plan L-52 V1 Plan: Pla Date: 9/9/2005 Time: 15:03:41 Page: 2 Co-ordinate(NI!:) Reference: Well: Plan L-250 (NM-15), True North Vertical (TVD) Reference: L-250 Plan 77.5 Db: Oracle Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft 298.78 300.00 135.34 5.22 130.12 Pass: Major Risk 298.78 300.00 135.34 5.22 130.12 Pass: Major Risk 298.78 300.00 135.34 5.22 130.12 Pass: Major Risk 298.78 300.00 135.34 5.22 130.12 Pass: Major Risk 298.78 300.00 135.34 5.22 130.12 Pass: Major Risk 298.78 300.00 135.34 5.22 130.12 Pass: Major Risk 760.64 760.00 30.99 12.88 18.11 Pass: Major Risk 760.64 760.00 30.99 12.88 18.11 Pass: Major Risk 760.64 760.00 30.99 12.88 18.11 Pass: Major Risk 760.64 760.00 30.99 12.88 18.11 Pass: Major Risk 238.20 240.00 165.11 4.12 160.99 Pass: Major Risk 238.20 240.00 165.11 4.12 160.99 Pass: Major Risk 639.37 640.00 89.57 11.30 78.27 Pass: Major Risk 639.37 640.00 89.57 11.30 78.27 Pass: Major Risk 1578.89 1560.00 47.97 27.32 20.66 Pass: Major Risk 459.59 460.00 46.32 7.83 38.49 Pass: Major Risk 1560.70 1540.00 49.61 27.04 22.57 Pass: Major Risk 458.19 460.00 241.56 8.42 233.14 Pass: Major Risk 419.18 420.00 121.07 8.06 113.01 Pass: Major Risk 419.18 420.00 121.07 7.95 113.12 Pass: Major Risk 259.09 260.00 90.36 4.58 85.78 Pass: Major Risk 599.41 600.00 187.44 10.40 177.04 Pass: Major Risk 280.48 280.00 315.78 4.97 310.81 Pass: Major Risk 280.48 280.00 315.78 4.97 310.81 Pass: Major Risk 818.75 840.00 219.53 15.53 204.00 Pass: Major Risk 464.83 460.00 131.09 8.83 122.25 Pass: Major Risk 464.83 460.00 131.09 8.78 122.30 Pass: Major Risk 379.39 380.00 195.82 7.21 188.62 Pass: Major Risk 576.88 580.00 241.79 11.02 230.77 Pass: Major Risk 557.74 560.00. 262.46 10.55 251.91 Pass: Major Risk 740.93 760.00 219.28 14.17 205.11 Pass: Major Risk i ~ Field: Prudhoe Bay '~ Site: PB L Pad Well: Plan L-250 (NM-15) i Wellpath: Plan L-250 l5V Travelling Cylinde[ Azimath (TFO+AZ1) [deg] vs Centre [o Centre Separation [SONin] • ~ olygon 1 2 3 4 5 6 7 8 9 10 ~ Site: PB L Pad Drilling Target Conf.: 95% Description: Map Northing: 5982970.00 ft Map Easting : 584600.00 ft Latitude: 70°21'48.239N X ft -150.00 -144.12 -262.46 -258.08 -252.47 -72.47 -78.07 -72.46 60.89 100.00 Target: L-250 Poly ft 1.67 531.68 1583.16 1978.17 2483.18 2481.19 1976.17 1581.05 529.41 -1.11 Welt: Plan L-250 (NM-15) Based on: Planned Program Vertical Depth: 4300.00 ft below Mean Sea Level Local +N/-S: 4668.68 ft Local +E/-W: 1457.27 ft Longitude: 149° 18'45.723 W Map E ft Map N ft 584450.00 5982970.00 584450.00 5983500.00 584320.00 5984550.00 584320.00 5984945.00 584320.00 5985450.00 584500.00 5985450.00 584500.00 5984945.00 584510.00 5984550.00 584655.00 5983500.00 584700.00 5982970.00 '~ 8+00 8000 X600 - ;; - - ~~DO- _--- 6800 i! ~, N ~' 6+00 6000 ', 5600 ~~, ~'~~ 15200 ', ~~ 4-800 ', '~ x+4-00 - ~ x+000 ° ° ~ o ~ o o / ~~ - - ~~, ~ • • TERRIE L RUBBLE ss-sn252 227 BP EXPLORATION AK 1NC "Mastercard Check" PO BOX 196612 MB 7-5 10, ~n ~~ .ANCHORAGE,. AK 9.9519-6612. oarE aC. PAY TO rHE ~~ $ / ORDER OF 1 DOLLARS First ational Bank Alaska - Anchorage, AK 9950:1 MEMO • 25O ~o~_ ~;L25200060~;gq~4~~~6227~.~L55611• 0227 ~~/ • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(1), all (PIS records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/SO) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checklist WELL PE MIT C ECKLIST Field & Pool PRUDHOE BAY, ORION SCHR BL OIL - 640135 Well Name: PRUDHOE BAY UN ORIN L-250 Program DEV Well bore seg ^ PTD#:2051520 Company BP EXPLORATION (ALASKA) INC Initial Classliype DEV11.01E GeoArea Unit On1Off Shore On Annular Disposal ^ Administration 1 Permit-fee attached - - - - Yes - - - - - - - - 2 Lease number appropriate____________________________________ _____Yes_ __________________-___._ - - - - - 3 Uniquewellnameandnumber_________________________________ _____Yes_ ________-_______..-,._____._____- ----------------------------------------- 4 Well locatedin_a-d_efinedpool---------------------------------- -----Yes. .-.-.__. - - -- 5 Well located properdistancefromdrillingunitboundary_________________- -.--.Yes- ______________________-_--_-_-_-_--.-____--__--__----.--__-______-_--_- 6 Well locatedpcoperdistancefromotherwells_________________________ _____Yes- ______-_-_--__-__--_--.-.--_-_ ------------------------------------------ 7 Su_fficientacreageayailablein-drillingun~----------------------_-._ _--_-Yes. -_--_-----__-_____-________-__ -------------------------------------------- 8 If_deyiated,is-wellboreplat-included-- --------------------------- -_--Yes_ -__-.---.---.-_-_________________________-____ -------------------------- 9 Operator Only affected party- - - - - - - - - - - - -Yes - - - --------------------------------------------- 10 Operatorhas-appropriate-bond in force____________________________ _____Yes_ ____--__--__-_________-._.- 11 Permit can be issued without conservation order Yes Appr Date 12 Permit_can be issued without ad_ministrative_approval - _ - - - _ - - - - _ _ _ _ - - _ - _ - - - _ Yes _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ RPC 10/1212005 13 Can permit be approved before 15-day wait Yes 14 Well located within area ands#raiaauthorizedbylnjectignOrde[#(put1O#in_commen ts)-(F4r_ NA__ ___________________________ ______________________-_-._-----_-__-_-_____- 15 All wells within 114_mi)e area of review identified (For service well gnly) ...... . . .. . .... NA.. - _ _ _ _ - _ _ _ _ _ _ - _ . _ _ _ _ _ - - _ --------------------------------------------------- 16 Pre-produced injector, duration of preproduction Less than_3 months_(For service well only) - - NA- _ - 17 AC_M_P_FindingofConsistency-hasbeenissued_forthisproject__--_-_____ -----NA__ ____________________________-_-___----.---.-__-___-_----.______________ Engineering 18 Conductarstring_pravided------------------------------------ -----Yes_ --__--20"x34"-@109'.-_________________-_-_- ---------------------------------- 19 Surface casing_prgtectsoll-known. USDWs - - Yes - - - - - - - 20 CMT_v_oladequate_tocirc_ul_ate_onconductor_&surf_csg___________________ _____Yes_ ______Adequateexcess._-__--_--_-_-_--__ - - 21 CMT_v_ol-adequate_totie-in long string to surfcsg----------------------- ----- No_- ---__-_____--____________ 22 CMT_willcoyer_allknownpro_ductivehorizon_s___________________ __Yes_ ____--___.- 23 Casing designs adequatefo[C,_T,B&permafCost--------------------- Yes- ------.---.---------------------------------------------------------- 24 Adequate tankage-o_r reserve pit - _ .. - Yes Nabors 9ES, - _ _ - _ _ _ . - - 25 Ifa_re-drill,has_a10-40$forabandonmentbeenapproved_.--_______---_- -__-- NA-- _-.-_.Newwell,.__________________________-----_ - - - 26 Adequatewellboreseparatior_proposed ~ -- ----.... -- - -- -- -Yes- -- -- - ---------- -- --------- - ..-.. - -- -- ------- --- - 27 Itdiverterrequired,doesitmeetregulations__________________________ _____Yes- --___-----.--__-_--__-__--__--__________ ---------------------------------- Appr Date 28 Drillingfluid_programschematic&equiplistadequate____________________ _____Yes- _-_--Max MW-9,5ppg,_-__--_--__.-_____________________ -____--__-._-___ WGA 10!1312005 29 BOPEs,dotheymeetregulotion------------------------ ------- -----Yes- -_--_._-_ ______-_______________---_-_---_---_.-__-.__-..-._____________ 30 B_OPE_pressratingappropriate;testto_(putpsigincomments)_______________ _____Yes_ -___-Test to 3500psi._MSP1468psi.-__---_-______________________--___-__---___ 31 Choke_manifoldcomplieswlAPI_RP-53(May84)_______________________ _____Yes_ ___--.--_---_--_ --------------------------------------------------------- 32 Work will occur without operation shutdown_________________________ __ _Yes_ _--_--.---.-______-__--__-___________________-_______--_-__-___-___.-____ 33 Is presence-of H2S gasprobable NO - - - NQt an H2S pad. - - - - - - - - - - - - 34 Mechanical condition of wells within AOR verified (Forservice well onlya _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ -------------------------------------------------------------------------- Geology 35 Permit_ean be issued wlo hydrogen-sulfide measures - - - -- - - - - - - -- - - - - Yes -- - - - - -- 36 Data-presentedon_potential overpressure zones______________________ _____ NA-_ -_-_------.---___--__--_--__--_-__-___________________--_--__-__________ Appr Date 37 Seismic analysis-of shallow gas-zones- - - - - - - - - - - - - - - - - - - -- - - NA -- - --- - RPC 10!12/2005 38 Seabed condition suruey_(if off_-shore) NA - - - - - - -- ---- 39 _Contact namelphone_forweeklyprogress-reports [exploratory only]- - _ - - - N_A_ Geologic Engineering Publ' Date: Date Date m si Commissioner: Commissioner/: ,~j s' /p J ,i~ J~ ~° j~'.~~i, /d ~~~ 1 ~a ~~~,~ • •