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207-050
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, January 22, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC Z-102 PRUDHOE BAY UN BORE Z-102 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/22/2024 Z-102 50-029-23353-00-00 207-050-0 W SPT 6413 2070500 1603 1585 1584 1584 1583 114 237 233 228 4YRTST P Kam StJohn 12/8/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN BORE Z-102 Inspection Date: Tubing OA Packer Depth 37 2316 2248 2236IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS231208135710 BBL Pumped:2.6 BBL Returned:2.7 Monday, January 22, 2024 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Ra +Ll6I (� DATE: Thursday, December 5, 2019 SUBJECT: Mechanical Integrity Tests BP Exploration (Alaska) Inc. FROM: Brian Bixby Z-102 Petroleum Inspector PRUDHOEBAY UN BOREZ-102 See: Inspector Reviewed By: P.I. Supry J i7P-- NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE Z-102 API Well Number 50-029-23353-00-00 Inspector Name: Brian Bixby Permit Number: 207-050-0 Inspection Date: 12/4/2019 Insp Num: mitBDB191204134459 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well Z-102 Type Inj w 'TVD 6413 " Tubing ass - 41s Ia13 a13 PTD 2070500 Type Test SPT Test psi 1603 IA so z3oo - zzss " zzaa - BBL Pumped: 2.1 BBL Returned: 15 OA9- Interval 4YRTST PAF P Notes: Thursday, December 5, 2019 Page I of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I DATE: Monday,December 28,2015 TO: Jim Regg -Qe� (7-4Z671)5"Zs7()5" SUBJECT: Mechanical Integrity Tests P.I.Supervisor BP EXPLORATION(ALASKA)INC. Z-102 FROM: Guy Cook PRUDHOE BAY UN BORE Z-102 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J '�- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE Z-102 API Well Number 50-029-23353-00-00 Inspector Name: Guy Cook Permit Number: 207-050-0 Inspection Date: 12/22/2015 Insp Num: mitGDC151222190111 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well z-102 Type Inj wTVD 6413 Tubing 1765 • 1769 1770 1770 PTD I 2070500 - Type Test SPT Test psi 1603 - IA 762 2500 - 2466 - 2459 -Intervall4YRTST P/F P V OA 193 287 285 282 Notes: 2.3 bbls pumped to test. MITIA. Kevin Parks not on site. Beau Obrigewitch,a well integrity engineer,on site as operator rep. SCANNED SEP 1 6 2016 Monday,December 28,2015 Page 1 of 1 . , a ` Y it • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON ° " REPORT OF SUNDRY WELL OPERATIONS fi s 1.Operations Abandon U Repair Well Lf Plug Perforations [J Perforate Li •Other U WAG SWAP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac IS Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown0 Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc • Developments Exploratory ❑ 207-050-0 ' 3.Address: P.O.Box 196612 Stratigraphic❑ Service D. 6.API Number: Anchorage,AK 99519-6612 50-029-23353-00-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028245 BRLS Z-102 . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,BOREALIS OIL • 11.Present Well Condition Summary: Total Depth measured 9507 feet • Plugs measured None feet true vertical 6569.21 feet Junk measured None feet Effective Depth measured 9404 feet Packer measured See Attachment feet true vertical 6581.72 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 29-109 29-109 1490 470 Surface 3404 9-5/8"40#L-80 29-3433 29-3093.14 5750 3090 Intermediate None None None None None None Production 8089 7"26#L-80 26-8115 26-6675.31 7240 5410 Liner 1836 4-1/2"12.6#L-80 7614-9450 6540.23-6576.25 8430 7500 Perforation depth Measured depth 7716-7756 feet 7766-7786 feet 9230-9260 feet 9270-9350 feet 9365-9402 feet True Vertical depth 6587.99-6606.18 feet 6610.57-6618.86 feet 6595.53-6594.23 feet 6593.85-6588.3 feet 6586.27-6581.95 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): n 17 . 2 0§3 SCANNED D Y tJ 1 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 13878 1028 0 650 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorL❑ Development❑ Service 119 • Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPLJ GSTOR ❑ WINJ ❑ WAG In GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-466 • Contact Nita Summerhays Email Nita.Summerhays BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician /74at•■■,/./._•1 5"A...4 �i�� Phone 564-4035 Date 6/19/2013 - zoom- .;.- 1 o l C o 3 RBDMS JUN 2 6 20a Form 10-404 Revised 10/2012 /4'' `/ �� Submit Original Only S • Daily Report of Well Operations ADL0028245 T/I/0=1400/100/60 temp=INJ Schmoo-B-Gone (WAG SWAP) Pumped 5 bbls meth followed by 140 bbls Schmoo-B-one, 15 bbls meth. Pad Op notified to POI in 3 hrs. Valve positions=SV WV closed SSV MV open CVs OTG 5/18/2013 FWHP=1550/30/90 ***WELL INJECT ING ON ARRIVAL*** DRIFTED TO DEVIATION @7940' SLM W/2.25 CENT, 1-1/2" SAMPLE BAILER 5/25/2013 ***CONT ON WSR 5/26/13*** ***CONT FROM WSR 5/25/13*** RAN 3.84" NO-GO CENT, 4-1/2" BRUSH, SD IN SSSV NIPPLE @2342' SLM (2367' MD) SET 3-1/2" MCX (MP3-06/ .75" BEAN) ON 4-1/2"X-LOCK WI 4-1/2" EQ DEVICE, 42" OAL, @2367' MD RAN 4-1/2" CHECK SET TO 2367' MD 5/26/2013 ***WELL INJECTING ON DEPARTURE*** FLUIDS PUMPED BBLS 20 METH 146 SCHMOO-BE-GONE 1 DIESEL 167 TOTAL Perforation Attachment ADL0028245 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base ND Depth Top ND Depth Base Z-102 5/24/2012 STO 7716 7756 6587.99 6606.18 Z-102 5/24/2012 STO 7766 7786 6610.57 6618.86 Z-102 5/24/2012 STO 9230 9260 6595.53 6594.23 Z-102 5/24/2012 STO 9270 9350 6593.85 6588.3 Z-102 5/24/2012 STO 9365 9402 6586.27 6581.95 • BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Casing / Tubing Attachment ADL0028245 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" 91.5# H-40 29 - 109 29 - 109 1490 470 LINER 1836 4-1/2" 12.6#L-80 7614 9450 6540.23 - 6576.25 8430 7500 PRODUCTION 8089 7"26#L-80 26 - 8115 26 - 6675.31 7240 5410 SURFACE 3404 9-5/8"40# L-80 29 - 3433 29 - 3093.14 5750 3090 TUBING 7347 4-1/2" 12.6# L-80 24 - 7371 24 - 6429.29 8430 7500 TUBING 217 3-1/2" 9.2#L-80 7371 - 7588 6429.29 - 6528.13 10160 10530 TUBING 353 2-7/8"6.4# L-80 7588 - 7941 6528.13 - 6666.18 10566 11165 • 1 10 1 • • Packers and SSV's Attachment ADL0028245 SW Name Type MD TVD Depscription Z-102 PACKER 7335 6332.18 4-1/2" Baker Premier Packer C Z-102 PACKER 7594 6449.62 4-1/2" Baker ZXP Packer 'TREE= 4-1/16"CAM • WELLHEAD= FMC SA NOTES: WELL ANGLE>70°CS 7829' ACTUATOR-=-------BAKER Z-1 O 2 KB.ELEV= 81.3' BF.ELEV= 28.5 I KOP 400' _- I 2367' H4-1/2"HES X NIP,ID=3.813" I Max Angie= 99"@ 8265' Datum MD= NIA Datum ND= 8800'SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 20"CONDUCTOR H 80' 4 3896 3514 18 KBG2 DMY BK 0 07/13/07 19-5/8"CSG,40#,L-80 BTC-M,ID=8.835" H 3433' 3 6631 6002 37 KBG2 DMY _ BK 0 07/13/07 1 7314' H4-1/2"HES X NIP,ID=3.813" I Minimum ID = 2.387" @ 7588' ►ZA ►z� I 7335' HT'X 4-1/2"BKR PREM PKR,ID=3.870" I 3-1/2" X 2-7/8" XO PIN 7362' H4-112"HES X NIP,10=3.813" j 41/2"TBG,12.6#,L-80 TCII, H 7371' .0152 bpf,ID-3.958" 7371' H41/2"X -112' ,ID=PROD3 UCTION XO MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE _, 2 7392 6439 64 NM DMY RK 0 05/19/07 m 1 7452 6466 63 WAG DMY RK 0 05/19/07 7513' 1 3-1/2"BKR CMD SLD SLV w/X PROFILE,ID=2.813" 7568' 1-13-112"HES XN NIP,ID=2.750" I 3-1/2"TBG,9.2#,L-80 TCII, ---1 7588' ■ L 7588' H3-112'X 2-7/8" XO,ID=2.387" I .0087 bpf,ID=2992' 7"X 5"ZXP LTPw/FLEX LOCK HGR 7594' &11.77'TIEBACK,ID=4.40" I ' 15"X 41/2"XO PIN,ID=3.958" H 7626' MILLOUT WNDOW(Z-102)7712-7725' 7885' H 2-7/8"FLUTED GUIDE SUB,ID=2.390" 1 17"WHIPSTOCK(08/05/07)H 7712' 17'CSG,26#,L-80 TO XO TO L-80 BTC-M H 7989' 7887' 41/2"X 3-5/8"SEAL BORE 1r CSG,26#,L-80 L-80 BTC-M,ID=6.276" H 8115' EXTENSION,ID=3.625" s. PERFORATION SUMMARY 1 7941' 2-7/8"MULE SHOE,ID=2.441" l 'V'CO'1'OT •'• REF LOG: RECORDED MODE 4/29-5/12/07 ,1111111111111111111• I H ELMD NOT LOGGED 1 ANGLE AT TOP PERF:63°@ 7716' ∎•1111111111 0 11111111111 Note:Refer to Production DB for historical perf data 0•1•1•1•1•1•1•1•1•1• 9260' 41/2"RA TAG SIZE SPF INTERVAL OpnlSgz DATE ����������� 2-1/2' 6 7716-7756 0 05/15/07 2-7/8"TBG,6.4#, 7941' Sk 2-1/2" 6 7766-7786 0 05/1.5107 L-80 HYDRIL 511, 2-1/7' 6 9230-9260 0 05/15/07 2-1/2' 6 9270-9350 0 05/15/07 bpf,10=2.441 2-1/2' 6 9365-9402 0 05/15/07 PBTD onion,- - 14-1/2'LNR,12.6#,L-80 IBT-M,.0152 bpf,ID=3.958" H 9450' ,. DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 05/20/07 NOES ORIGINAL COMPLETION 05/03/12 TBDIJMD SET PXN PLUG(04/30/12) WELL: Z-102 06/23/07 KSB/PJC GLV C/O(06/11/07) 05/29/12 MSS/JMD PULLED PXN PLUG(05/24/12) PERMIT No:'1070500 06/27/07 JRP/PJC GLV C/0 AP No: 50-029-23353-00 07/04/07 DTRISV GLV GO SEC.19,T11 N,R12E,4565'FSL&3542'FEL 07/22/07 KSB/PC GLV C/O(07/13/07) 11/26/07 WRR/PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) & \ \ //7 THE STATE ���I �i Alaska Oil and Gas ®f S KA. ..„---C—orrservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Off; Q. Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1 433 SCANNED JAN 2 3 2 Fax: 907.276.7542 Joleen Oshiro SCANNED JAN U West Base Management Borealis PE BP Exploration (Alaska), Inc. 167-05-° P.O. Box 196612 �• ._... Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU Z -102 Sundry Number: 312 -466 Dear Mr. Oshiro: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ifek- Daniel T. Seamount, Jr. Commissioner DATED this f z'day of December, 2012. Encl. JIECEIVED ,0 DEC 07201'4 ` STATE OF ALASKA \ 07Y tz.1 Val ( ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well❑ Stimulate ❑ Alter Casing ❑ Other: Switch to WAG Injector 5• 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 207 -050-0 3. Address: Stratigraphic ❑ Service El . 6. API Number. P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 23353 -00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PRUDHOE BAY UN BORE Z -102 Will planned perforations require a spacing exception? Yes ❑ No ❑ 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0028245 • PRUDHOE BAY, BOREALIS OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9507 • 6569 •• • 9404 6582. None None Casing Length Size MD ND Burst Collapse Structural Conductor 80 20" 91.5# H -40 29 - 109 29 - 109 Surface 3404 9 -5/8" 40# L -80 29 - 3433 29 - 3093.14 5750 3090 Intermediate None None None None None None Production 8089 7" 26# L -80 26 - 8115 26 - 6675.31 7240 5410 Liner 1836 4-1/2" 12.6# L -80 7614 - 9450 6540.23 - 6576.25 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and TVD (ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12. Attachments: 13. Well Class after proposed work: Description Summary of Proposal � - Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG IS • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Joleen Oshiro Email Joleen.Oshiro@BP.Com Printed Name Joleen Oshiro Title West Base Management Borealis PE Signature 0.011LD Phone 5644606 Date �ZIb( Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3' Z_ LAP 7 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: � - v 2 R �C�>�A S DEC 13 2012 it Spacing Exception Required? Yes ❑ No i Subsequent Form Required: / - 1 �' / APPROVED BY /2.-/I 2 l 1 Z Approved by: t / COMMISSIONER THE COMMISSION Date: ® Rr 3 4 j 3 N Approved application is valid for 12 onths from the date of approval. Sub th DuYlicate rk.. �\ • Perforation Attachment - ADL0028245 Well Date Perf Code MD Top MD Base TVD Top TVD Base Z -102 5/24/12 STO 7716 7756 6588 6606 Z -102 5/24/12 STO 7766 7786 6611 6619 Z -102 5/24/12 STO 9230 9260 6596 6594 Z -102 5/24/12 STO 9270 9350 6594 6588 Z -102 5/24/12 STO 9365 9402 6586 6582 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED • APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED 1 RPF REPERF • Casing Summary ADLOO28245 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 80 20" 91.5# H -40 29 109 29 109 1490 470 H-40 LINER 1836 4 -1/2" 12.6# L -80 7614 9450 6540 6576 8430 7500 L -80 PRODUCTION 8089 7" 26# L -80 26 8115 26 6675 7240 5410 L -80 SURFACE 3404 9 -5/8" 40# L -80 29 3433 29 3093 5750 3090 L -80 TUBING 7347 4 -1/2" 12.6# L -80 24 7371 24 6429 8430 7500 L -80 TUBING 217 3 -1/2" 9.2# L -80 7371 7588 6429 6528 10160 10530 L -80 TUBING 353 2 -7/8" 6.4# L -80 7588 7941 6528 6666 10566 11165 L -80 • Packers and SSV's Attachment ADL0028245 Well Facility Type MD Top Description TVD Top Z -102 PACKER 7335 4 -1/2" Baker Premier Packer 6413 Z -102 PACKER 7594 4 -1/2" Baker ZXP Packer 6450 • TREE 41/16" CAN WELLHEAD = FMC • SA. NOTES: WELL ANGLE > 70° @ 7829' ACTUATOR BAKER Z — 1 O 2 KB. 8.EV = a 81.3' ' i3-f. ELEV. -- - 28. I 1 i KOP = 400' Nz A 8265 1 2367' H4 -1/2" HES X NIP, ID= 3.813" 1 Angle _ Datum NO = NIA Datum TVD = 8800' SS GAS LIFT MANDRELS ST MD WO TYPE VLV LATCH PORT DATE 120" CONDUCTOR H 80' ' 4 3896 3514 18 KBG2 MY BK 0 07/13/07 19 -5/8" CSG, 40#, L -80 BTC-M, ID = 8.835" H 3433' 3 6631 6002 37 KBG2 MY BK 0 07/13/07 L 7314' H4-1/2" HES X NIP, ID = 3.813" 1 Minimum ID = 2.387" @ 7588' pm . I 7336' HT' X 4-1/2" BKR PREM PKR, ID = 3.870" 1 3 -1/2" X 2 -7/8" XO PIN 7362' H4 -1 /2" HES X NIP, ID = 3.813" 1 41/7' TBG, 12.6#, L -80 TCII, H 7371' 7371' 1-1 -1 /2" X 3 -1 /2" XO, ID = 2.9 1 .0152 bpf, ID 3.958" ( PRODUCTION MANDRELS W ST MD TVD DEV TYPE VLV LATCH PORT DATE _, 2 7392 6439 64 WAG DMY RK 0 05/19/07 4 m 1 7452 6466 63 AAWG _ DMY RK 0 05/19/07 7513' J-13-1/2" BKR CMD SLD SLV w/ X PROFILE, ID = 2.813" 7668' H3 -1/2" HES XN NIP, ID = 2.750" 1 3-1/2" TBG, 9.2#, L -80 TCII, H 7588' i L 7688' H3-1/2" X 2 -7/8" XO, ID = 2.387' 1 .0087 bpf, ID = 2.997' T' X 5" ZXP LTP w / FLEX LOCK HGR —.1 7594' & 11.77' TIEBACK, ID = 4.40" 15" X 4-1/2" XO RN, ID = 3.958" H 7626' MILLOUT WINDOW (Z -102) 7712 - 7725' 7886' H 2 -7/8" FLUTED GUIDE SUB, ID = 2.390" 1 17" WHIPSTOCK (08/05/07) H 7712' 17" CSG, 26 #, L -80 TCII XO TO L -80 BTC-M H 7989' 7887' 1 4 -12 " X 3 -5/8" SEAL BORE 17" CSG, 26 #, L -80 L -80 BTC-M, ID = 6.276" H 8116' EXTENSION, ID = 3.625" PERFORATION SUMMARY 7941' H2 -718" MULE SHOE, ID = 2.441" 1 REF LOG: RECORDED MODE 4/29 - 5/12/07 ∎1 1•••••••••'; •••• 1 J-1 ELMD NOT LOGGED 1 ANGLE AT TOP PEKE 63° (# 7716' 4.4.4.8904 Note: Refer to Production DB for historical pert data � � � � � A � � � � � � • � � Wei 9260' 41/2" RA TAG SIZE SPF INTERVAL Opn/Sgz DATE 2-1/2" 6 7716 - 7756 0 05/15/07 2 -7/8" TBG, 6.4#, 7941' S 2-1/2" 6 7766 - 7786 0 05/15/07 2 -1/2" 6 9230 - 9260 0 05/15/07 L-80 HYDRIL 511, 2-1/2" 6 9270 - 9350 0 05/15/07 .0058 bpf, ID = 2.441 2 -1/2" 6 9365 - 9402 0 05/15/07 Amass- PBTD 9404' . * *,. ■■. 'U., 14 -1/7' LNR, 12.6#, L -80 IBT -M, .0152 bpf, ID = 3.958" H 9450' '• DATE REV BY CO VvENTS DATE REV BY COMMENTS BOREALIS UNIT 05/20/07 N9ES ORIGINAL COMPLETION ' 05/03/12 TBDIJAl0 SET PXN PLUG (04/30/12) WELL: Z -102 06/23/07 KSB/PJC GLV GO (06/11/07) 05/29/12 MSS/JMD PULLED P(N PLUG (05/24/12) PERMIT No: "2070500 06/27/07 JRP/PJC GLV GO AR No: 50-029-23353-00 07/04/07 DTR/SV GLV C/0 ' SEC. 19, T11 N, R12E, 4565' FSL & 3542' FEL 07/22/07 KSB/PC GLV GO (07/13/07) 11/26/07 VyRR/PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • Z Pad Cement Evaluation Z -06 1 bp General Please note that this document is a summary report based on the logs and information made available to Gerardo Cedillo Coubert as on 02 May 2012. An UltraSonic Imaging Tool USIT with MSIP Sonic Scanner dataset was recorded in well Z -06 on 02 May 2012. The logged interval, which extends from 9300 feet to 300 feet, is completed with 9.625 inch, 47 lbs /ft casing. This tubular has a nominal internal diameter of 8.681 inch and a nominal theoretical wall thickness of 0.472 inch. The UltraSonic Imaging Tool (USIT *) was run in combination with a Cement Bond Log/Variable Density Log (CBL /VDL /MSIP) and a General Purpose Inclinometry Tool (GPIT). All depths and tops are referenced as drilled. e . . s 7 J � { Fluid in hole for USIT logging: 10.3 ppg PowerPro weighted with barite (confirm details with WSL). No details available on casing centralizers run during the completion. � '4' •"��H ! % if r` � G x � ; F i `: ,, F .. /�, ,v.°,r ��' F• � / F FI r F �' J 4'F JvF'F ` �„� B F�. S Fr �,,.,� �„ 5�`' /'f'i'!,//,;1 /,!� /,,, ,� /„ ,�.� }, f"��`�i"f�F��''�"';!�; /r. ., � %,. . ,,���: Z -06 9 -5/8" casing cemented 5/25/88. Started mixing 04:35 5/25/88, CIP 07:22 5/25/88. Pumped 20 bbls water preflush Pumped 168 bbls 13.2 ppg Class G lead at 9 BPM, 0 - 1100 psi followed by 211 bbls of 15.8 ppg Class G tail cement. Reported 50 -75% returns after cement hit shoe. Did not bump plug and found top of cement inside casing at 9143' MD. With 30% washout and 50% returns, cement top calculated to be at 8259' MD in the annulus Down squeeze performed on the 13 - /8" x 9 - /8" annulus with 15.6 ppg 50 bbls Permafrost C cement. Estimated to of down squeeze cement: 2092' md. Z -06 passed an MIT -OA on 6/14/2003 to 2000 psi Objectives • Obtain Isolation • Above top of Schrader (4837' md) • Between Schrader and Kuparuk: 5438 - 7248 • Between Kuparuk and Ivishak: Below 7413' and • annular isolation cumulatively > 100' tvdss Log Quality Control LQC USIT (USI IS MAPC 029PUC) Quality Comments Tool centralization within spec. Radius curves within spec. Good Wireline groove 3730 -2900 ft Thickness curves within spec. Good Clear manufacturing patterns Good Diagnostic Flags Good UFLG not showing flags ZMUD within spec. Good FVEL within spec. Good Repeat section matches the main log. Good 1 May 2012 • • Z Pad Cement Evaluation • bp Z -06 Findings Cement evaluation Interval Bond Hydraulic Comments INI END Quality Isolation 9300ft 8135ft High YES GR correlating with AIAV. USIT Al high , CBL low and VDL formation arrivals . Fig 3 8135ft 7470ft Moderate YES Average acoustic impedance reduced 1 MRay due to isolated liquid pockets and overall cement quality deterioration. CBL gradually increasing 7470ft 7200ft Low NO Mainly liquid interval , VDL strong casing arrivals 7200ft 6910ft Moderate YES VDL attenuated casing arrivals .Comparison between AIMN and AIAV suggest a high side channel of what is tought to be contaminated cement or cemented mud .Fig 4 6910ft 4188ft Low NO Patchy cement .poor isolation 4188ft 2661ft Moderate YES (4148 -4118/ 4080 - 4050/3975- 3925/3590 -3615 / 3506 - 3490 /3440- 3370/3245- 3210/3140 -3090 Isolation intervals )VDL attenuated casing arrivals .Patchy liquid pockets in the high side of the pipe. Possible wireline induced internal radious groove from 3730 -2900 ft MD affecting the cement map interpretation (apparent channel) . 13 3/8 Casing show @ 2661 ft. Fig 5 2661ft 2160ft High toYES Annular isolation between 13 3/8 casing and 9 moderate 5/8 is tought to exist . VDL showing strong formation arrivals . Top opf cement in surface casing @ 2169 ft with isolated free pipe intervals 2514 -2500/ 2440 -2410 ft .Free pipe above .Fig 6 Zone isolation Based on the interpretation This log demonstrates annular isolation above and below the Kuparuk which allows BP to request MI service in nearby Z -1021 . 2 May 2012 • 0 Z Pad Cement Evaluation bp Z -06 Fig 1. Compressed Log ; DATN MD -0.5 dB /ft 4 FEET AIAV 300C 0 Mrayl 5 =500= 1000 1500 =2000 - 2500 13 3/8 Casino shoe at 2661 ft. = .- 3000= - 3500 - - - 4000= 4500 - - - 5000 - - 5500 6000 - = 6500 70001 Top of Kuparuk at 7248 ft MD 7500 8000 - 8500 - = 9000 - 3 May 2012 II 41) Z Pad Cement Evaluation 0 by Z-06 Fig 2. We//Bore Schematic: TREE " MCEVOY U5EATT,E14111141":4274 Z-06 Pre-Rig SAFETY NOTES 1 THIS WELL HAS CONNSCEBNED CRATER. 0131 TRa. coo. WELL TO RELIEVE B ES/ 4 97 ■■ ■■ Max Antl , 40 t51N00 'man TVD " awer w 13-1fr CSC Ass, L, 14- 12414 IT7gliff-A i 451,70 I TJbing kt at at 9151` & 9-338 1 We HTIMSEAL ASSY i . TO ,. 93.96 g,..5.6.- x. 3.4 n- MN MEW ROL D " 1997 1 IP CP M 7 INI T.IT 3 : 1 • 943e f1141.2" OTIS mu., 0 ,,, 2.75" I lit MI .1,2 ans x up. 225 , m , " I '3 -12" TEO, 934,4410 0067 tat, I14 2,292 1111Lji :•..i.o - 3.1t2" TBGTAL, E0 m2,992" I 9-549" CSC 478 L4 0 4 AM 1" ' ' . II=. avarr LO(23H3071211 81 I PERFORATOR SUM * • 1 REF LOG SAIS-EMICS ON 0923768 • , - ANGLE AT TOP ] FOIE Mr @ 10042' Rata Refer 44 Produelal DB kw MORE Wpm( date . , 3 SEE SPF 9411 M. CMINSq.4 OATS . * , J r 8 10042 - 10052 0 0E25/06 r 6 10082 - 10062 0 07,047011 ' 1 341 4 10062 - 1-0106 0 08.023 . -. 16 2- 6 MEV - 111103 0 046:19041 4 ' 111 1_1 RERLIOPIT I 3119' 4 10104 - 10146 0 011619110 ,- - * 2' 6 10104 - 10106 0 °cows - . ' ' • I 3 4 10112 - 10120 0 0303 2 8 10112 - 351 20 0 08.408 r € 10132 - 10154 0 080€08 r 4 1 0132 - lois 0 05731766 44 - r 8 10t74 - 10201 0 01183s106 ' I . . 1 r 4 10174 - 10221 0 08 01188 '", ' 4 ',.I 2-18 " 4 10190-11201 0 06729 21E 4 10X14 - 10221 0 =RES • 2-14 " 4 10232- 12308 0 10726/91 :LI 102er UM 1—Insk mew" 2..6s- van YAP ELEKVIS (awl zaol. , .. &El '11LL67:11• OW•Wes' 1 7'01R 291 , L-03 0383 b�, 2:14 6276" 7r...'4 4 VONA At DATE EEL' BY COMAIROS TATE REV BY COARENTS PRIAIRCE BAY uNT 06EIRS ORIGINAL COM AMON 065009 LINV71114 CV CO 047104091 WELL Z08 06116701 416411 CORRECTORS 06,30108 C14777114 WFF MR (04112/09) PERMTNA 1981320 0835107 A MIRE CV CO 0513(606 wriut PERES (0425,09) APR 504129-21794300 04.36706 TIGISV REWIRES (0437E64 SEC 19, 131 A R12E, E74T RA & 3631' 413_ 10/07706 GIETTLI4 GLV CJO (09234101 0551709 DEFITLI4 MIFFS (6744011) A CORRECTIONS BP Eaplimatiori (Alaska) ... 4 May 2012 111 • Z Pad Cement Evaluation by Z-06 Fig 3. Below Kuparuk , above Ivishak . Good radial coverage and zonal Isolation 8 8 AIRINE1.11 111 0 :s, 1 1 Ar"X XS.,1 10 MO - - FEET (FEET) cF TrAv Atinscsa.....-rexcm_rmr..2 ;wax 91941 ADO" 1 120 0 1 99912 ,,99E la a - 5_37 32767 r ‘a 59 -2e rall 4krayl 33 4, 0 oto ,. H I, 2 9 - W19,1 12 7900 I .7..= .4 '-' '. . :.--- - - 7950 'AM t PM li 1 - : - --1 --i.--- .711 III 1 .'")1 8000 4* . 1 - -''" _ 8050 it. 1 1 fiAit - A 1 W--- :„.... 1 qv 8100 8150 I , ." ... -- Ali -,•■• .„ f.....t4 . vt...... 7250 - - I ".1 ' '''' . "2 .--- -A. 8200 - -.... _ 1 8250 ..,_,..., 1 f : ,./1. --- rl _ -.'=11111 1 ' 'ICI I 4 'I. 4 8300 q ___ i 5:1_111 111 ,,... 8350 • '- ; 4rl u 1JII -s..-, .t ...... 1 _,.....-- 8400 : --- i 1 I i f 110 _ 1 , )_,I:1 1mi --41 ..„ 7500 - 1 8450 I -... -- , - ' • i - Pe- . --,i - 1. - MI :---:. --- 8500 1 ,,..._ii ......-i Al fru 8550 I I -.,,V li 1 , kill-'ici 46 - Ill 8600 ••••• it3:?,...4 --- .-. - 101 • P.' - - 8650 .•••••" - - 8700 - -..."---_ ' .".• ....k, 0" ---Al -A If- --- "N -,...- F4 8750 - •••• MI • Pr 4; I t' - 7750 - --4., 8800 4 ,?..; ..,, .1 • - • -•<- ' 4. „ it _____ 8850 .........., j , _...._, ..ai A „, .. , ......Am...A 1. -1.4 - . 8900 --- 7-= / r 14 1. _ •.,-, — - -• -_ 8950 ,.. ."-- • 1 1-11 _ ___.. -.. • I 11 r : '4,•-• 9000 ...il ,..„. 9050 . -- ( ' . „ ' - 8000 - 9100 41110 i 1 V _ .,,, _ - -1 Air= i . 1 . 11 _ .. .,-.--, 4 , .4., it - - -- — .- _ 9150 9200 9250 -...,--_. 9300 I '--- 5 May 2012 o � y . 1 t & ` ' � ,1 I I I' M ' " 1W, II ' ) ' 1 I i _ti I , ,� , 1�, I �,, ..h4. i on o �1AI* + 1 �- N w « r c E i 1 i.` 0 ■ 1 i MO& , :1,,,,,, , +-- , ____, _ .... _ _ .........9.....,....400... ..., ,, __,,, 400 1- 17, ••••-' 44 , VFW , ra N N a 11,h ' + ��„ d . 1 �ll�� Ill.li41,' �rY� . � gill& poi II MI PI y I t j Plill I 4— 1 VO M CO 12 2 2 11 111111 °I • IT T r Li + Iiiiiiii..�.,.• • k,1 1 ' 1 i I,d... , LI 1Y v 1 A M A v ry MI Firi r �` �rLL,,,,, , , n h r A CI sa. u c � ' y i ulliuiiL ilti t Atli, 0 Q 2i1 ,p p h A h h A h h A A 4 o O o O O o O O O O O i% N N M M �}} V1 V] ,D . '� +O N �0 4S ,O +D N .D ,0 . ---\'`V" • 0 Z Pad Cement Evaluation () Z -06 Fig 5. Above top of Kuparuk 9 p p ASMN 1 Mray! 10 4144 41110 AL4V 4146 TVDSS 12) Mray1 4 -1 Mnyi 10 1 Mrayi 6 0 Mr4y1 5 f � - -f (FEET; (FEET) GR_E_ -- 41AV DIEN A1MX TON VOL _ 1:1200 1:1200 33 gAP: .1 Mny 30 - 44+11 5 . .32006 2600 2700 `. = 2700 Alill 4 { 2650 2750 _ •— r - : 1 e — — � -- 2800 it. , L t I! 2750 2850 �.r '��� AL, 2800 2900 M "` 9 2850 2950 r'� ' _ 38 2980 )00 55.6371 — 316933 1.98477 _ 58.94 I ; — - , s'a 3.16933 6.60335 ' 316933 - 2950 3050_ _ " Oti* i — 3000 3100 _ � ( �� 3050 � �� > 3150 ik c - r — 3100 3200t ' di '` —,t,71.1 x, ; _ _ : 1 1 3150 3250 1 3200 3300 � — _— _ r ......_ — 3250 3350 t ' ;" 3300 3400 .... I 0 ` 3350 3450 � 6i ' _ : ' 3500 - - =— — — � .- ` 3400 -- a Ii h r , 3550 , l — 3450 3500 li — 3500 .1114111111.17- 3650 t — } ;Y - 3550 � 1 4t 3700 —_..1 —� _�■- - - - .i = - 3600 , 3750 X- 1:� - 3650 3800 L M ,r b. 1 - -�� _Mil' - 3700 3850 ,ANNIE 1j 3 900 - 3750 _ — 3950 E-0 — ' - 3800 = v 4000 _ 3850 4050 E� _ _ _ 7 May 2012 • • Z Pad Cement Evaluation � Z -06 Fig 6. Free pipe above 2160 ft MD . AIM 4 'Imp 10 AIM Ai.4v 81A6 ASAV cr pi2 ',... TVDSS MD -1 n..y{ 10 1 N -sp 6 0 M.sy] 5 0.4 M-ayt 1.? .. (FEET) (FEET) ASAV pAm q;»» THAV TM ._ 1:1200 1:1600 .1 Mnyi 10 0 awn S -1 M-syi 2.8 0.46 v+ 0.48 5-S 8SU 950 _ t 1 1 Imo■■ W -_- .. 201 997.171 0.737941 ' -- 0374488 -Q 0361395 0.470243 - 950 1050 itt 4.12541 -' 0.737941 0.737941 T '0 - -- ' - 110-0 � F 1050 1150 li n --1111.1_ --- _ _ - 1100 1200 a - 1150 1250M - 1200 1300 I i _ _._ - - 1250 1350 -IRM - E '°° 1400 t( f r # 1350 1450 1 _ - -: - 1400 1500 FS ��11� 13 3/8 Casino shoe at 2661 ft. - 1450 1550 H — - 1500 1600 = '' - 1550 1650 3 ' - _ - 1600 1700 WM.11 _ - 1650 1750 W + -I -rr. - 1700 1800 __ _____ 1750 1850 �� 1800 1900 M r =AMEN_ EUvat! - 1850 1950 1900 2000 r - 1950 2050 � I _ - i - 2000 z1D0 � , , - 2050 �` - 2150 - ` 7 , —a � �. - 2100 2200 �- r .IIE-: 2150 2250 J - - 2200 2300 J 8 May 2012 • 1 Page 1 of 3 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, December 06, 2012 8:55 AM To: 'Dean, James A' Cc: Oshiro, Joleen; Wallace, Chris D (DOA) Subject: RE: Prudhoe Bay Z -1021 MI Injection (207 -050) Thanks... cement looks adequate to keep injection from migrating up or down from Kuparuk interval... AOGCC would request you provide a 10-403 sundry request to change service to MWAG for Z -1021 well. That way we will have all this documented. Some pdfs of the USIT log from Z -06 (approx 6900 to 7600md on Z -06) could be included just so we have it on record. Call me if you have any questions. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Dean, James A [mailto:James.Dean @bp.com] Sent: Thursday, December 06, 2012 8:39 AM To: Schwartz, Guy L (DOA) Cc: Oshiro, Joleen Subject: RE: Prudhoe Bay Z -102i MI Injection Guy, Here is the information you requested. Z -06 Kuparuk zones: 7248' — 7413' and Z -102i Perforation interval: Perforation Interval Zone 7716' -7756' C4 7766' -7786' C1 9230' -9260' C4 9270' -9350' C4 9365' -9402' C4 Let us know if you need any other information. - -James From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Wednesday, December 05, 2012 3:22 PM 12/11/2012 Page 2 of 3 • To: Dean, James A Cc: Wallace, Chris D (DOA) Subject: RE: Prudhoe Bay Z -102i MI Injection OK.. looking at log. Can you verify where the Kuparuk zones are for me on the USIT log on Z -06.. I see HRZ bottom at 7240' and Kuparuk C and A should be just below that . ... what is perfed for injection in Z -102i ? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Wednesday, December 05, 2012 2:24 PM To: 'Dean, James A' Cc: Oshiro, Joleen; Wallace, Chris D (DOA) Subject: RE: Prudhoe Bay Z -102i MI Injection James, Don't think I have seen it.. Was it electronic ? ?? Or hard copy? Chris ... did you see it yet? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Dean, James A [mailto:James.Dean@bp.com] Sent: Tuesday, December 04, 2012 5:26 PM To: Schwartz, Guy L (DOA) Cc: Oshiro, Joleen Subject: Prudhoe Bay Z -102i MI Injection Guy, We discussed potential miscible injection in Prudhoe Bay well Z -102i a few weeks ago. This well was permitted for only water injection in the Kuparuk formation due to concerns about the cement isolation across the Kuparuk formation in the nearby Z -06 wellbore. When we recently sidetracked the Z -06 well, we ran a bond log which showed good bond across the Kuparuk in the Z -06 wellbore and would like to discuss how to permit the Z -1021 to allow for miscible injection. Did you receive the Z -06 bond log we send a few weeks ago ? If so, how should we proceed with permitting the Z -1021 for miscible injection ? 12/11/2012 Page 3 of 3 - -James James Dean Base Management Team Leader I I 12J11/2012 M RANDUM • ME O State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, February 01, 2012 Jim Regg / P.I. Supervisor 1 \�. SUBJECT: Mechanical Integrity Tests l BP EXPLORATION (ALASKA) INC Z -102 FROM: Chuck Scheve PRUDHOE BAY UN BORE Z -102 Petroleum Inspector Src: Inspector Reviewed B P.I. Supry NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN BORE Z - 102 API Well Number: 50 029 - 23353 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS120129175603 Permit Number: 207 - 050 - Inspection Date: 1/28/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Z -102 Type Inj. W > TVD 6413 IA 1155 - 2185 - 2167 2164 - P.T.D 2070500 TypeTest SPT Test psi 1603 - OA 445 523 526 525 - Interval 4YRTST Pf, P ' Tubing 1685 1687 1687 1686 Notes: Wednesday, February 01, 2012 Page 1 of 1 OPERABLE: Injector Z -102 (PTDS70500) MIT -IA Passed • Page 1 of 2 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Sunday, January 29, 2012 4:31 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad Z; Greaves, Damien C; AK, OPS Well Pad Z; Brooks, Phoebe L (DOA) Cc: King, Whitney; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Injector Z -102 (PTD #2070500) MIT -IA Passed Attachments: MIT PBU Z -102 01- 28- 12.xls All, Injector Z -102 (PTD #2070500) passed an AOGCC witnessed MIT -IA on 01/28/2012 proving two competent barriers in the wellbore. The well is reclassified as Operable and may remain on injection. The MIT -IA form is attached for reference: «MIT PBU Z -102 01- 28- 12.xls» Thank you, Mehreen Vazir (Alternate: Gerald Murphy) PFEB ( (#I . Well Integrity Coordinator f �� BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWelllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, January 16, 2012 7:50 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad Z; Greaves, Damien C; AK, OPS Well Pad Z Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike 3; LeBaron, Michael 3 Subject: UNDER EVALUATION: Injector Z -102 (PTD #2070500) Due for 4 year Compliance Testing All, Injector Z -102 (PTD #2070500) has been shut -in during the drilling of Z -116 and exceeded the date for it's 4 year AOGCC MIT -IA requirement. As the well passed an MIT -IA on 1/14/2012 while shut -in confirming the presence 1/31/2012 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggna alaska.gov; doa. aogcc.prudhoe.bavaalaska.ciov; phoebe.brooks o8.alaska.aovi tom.maunder?a alaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD 1 UNIT / PAD: Prudhoe Bay / PBU / Z Pad DATE: 01/28/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Z -102 Type Inj. W TVD 6,413' Tubing 1685 1687 1687 1686 Interval 4 P.T.D. 2070500 Type test P Test psi 1603.25 Casing 1155 2185 2167 2164 P/F P Notes: 4 year AOGCC witnessed MITIA OA 445 523 526 525 Pumped 0.8 bbls methanol to pressure up IA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi_ Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU Z - 102 01 28 12.xls OPERABLE: Injector Z -102 (PTD.70500) MIT -IA Passed Page 2 of 2 of two competent barriers, the well can return to injection and an AOGCC MIT -IA will be performed as soon as the well is thermally stable. The well is reclassified as Under Evaluation. Plan forward: 1. Fullbore: AOGCC MIT -IA as soon as well is thermally stable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, October 25, 2011 10:00 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad Z; Greaves, Damien C Cc: AK, D &C Well Integrity Coordinator; Arend, Jon (NORTHERN SOLUTIONS LLC); Clingingsmith, Mike J (Swift); Walker, Greg (D &C); King, Whitney Subject: NOT OPERABLE: Injector Z -102 (PTD #2070500) Due for 4 year Compliance Testing All, Injector Z -102 (PTD #2070500) is due for its 4 year AOGCC MIT -IA compliance testing. The well is currently shut in until Z -116 is finished drilling, which will not happen until later in 2011. The last MIT -IA performed was 09/07/2010 to 3000 psi which passed. Until such time that the well is ready to begin injection, the well is reclassified as Not Operable. Once the well is ready to begin injection, the well will be reclassified as Under Evaluation until the AOGCC witnessed test is completed. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1/31/2012 p ' h ao fi4- cs Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Sent: Sunday, January 29, 2012 4:31 PM " To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad Z; Greaves, Damien C; AK, OPS Well Pad Z; Brooks, Phoebe L (DOA) Cc: King, Whitney; Wills, Shane M; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Injector Z -102 (PTD #2070500) MIT -IA Passed Attachments: MIT PBU Z -102 01- 28- 12.xls All, Injector Z -102 (PTD #2070500) passed an AOGCC witnessed MIT -IA on 01/28/2012 proving two competent barriers in the wellbore. The well is reclassified as Operable and may remain on injection. The MIT -IA form is attached for reference: «MIT PBU Z -102 01- 28- 12.xls» V Thank you, Mehreen Vazir (Alternate Gerald Murphy) Well Integrity Coordinator StANNEDFEB 612- BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Monday, January 16, 2012 7:50 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA ', AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline O• = ations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad Z ' reaves, Damien C; AK, OPS Well Pad Z Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clin'' gsmith, Mike J; LeBaron, Michael 3 Subject: UNDER EVALUATION: Injector Z -102 (PTD #20705P d Due for 4 year Compliance Testing All, Injector Z -102 (PTD #2070500) has b= -n shut -in during the drilling of Z -116 and exceeded the date for it's 4 year AOGCC MIT -IA requirement. As the well p -:sed an MIT -IA on 1/14/2012 while shut -in confirming the presence of two competent barriers, the well can return to in''ction and an AOGCC MIT -IA will be performed as soon as the well is thermally stable. The well is reclassified as Uri. -r Evaluation. Plan forward: 1. Fullbore: AOGCC o T -IA as soon as well is thermally stable. 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoo @alaska.aovi doa .aoacc.prudhoe.bav @alaska.aov; phoebe.brooks(rDalaska.cov; tom.maunder(aalaska.aov OPERATOR: BP Exploration (Alaska), Inc. 1 67 de , l 1 1 3u I( FIELD / UNIT / PAD: Prudhoe Bay / PBU / Z Pad 1 DATE: 01/28/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well Z -102 ' Type Inj. W ' TVD '6,413' Tubing 1685 1687 1687 1686 " Interval 4 P.T.D. 2070500 - Type test P Test psi 1603.25 Casing 1155 2185 - 2167 2164 - P/F P Notes: 4 year AOGCC witnessed MITIA OA 445 523 ' 526 525 ' Pumped 0.8 bbls methanol to pressure up IA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU Z - 102 01 - 28 - 12 Pia Lt F- to z- Z 7 O-5 Regg, James B (DOA) ,^� From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] I5t' f / /ci/, Sent: Monday, January 16, 2012 7:50 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East p 9 v Wells Opt Engr; En r; AK, OPS Well Pad Z; Greaves, Damien C; AK, OPS Well Pad Z Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, t , Mike J; LeBaron, Michael J Subject: UNDER EVALUATION: Injector Z -102 (PTD #2070500) Due for 4 year Compliance Testing All, Injector Z -102 (PTD #2070500) has been shut -in during the drilling of Z -116 and exceeded the date for it's 4 year AOGCC MIT -IA requirement. As the well passed an MIT -IA on 1/14/2012 while shut -in confirming the presence of two competent barriers, the well can return to injection and an AOGCC MIT -IA will be performed as soon as the well is thermally stable. The well is reclassified as Under Evaluation. Plan forward: 1. Fullbore: AOGCC MIT -IA as soon as well is thermally stable. Please call if you have any questions. Thank you 51.44iiikED FEB 5 Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, October 25, 2011 10:00 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad Z; Greaves, Damien C Cc: AK, D &C Well Integrity Coordinator; Arend, Jon (NORTHERN SOLUTIONS LLC); Clingingsmith, Mike J (Swift); Walker, Greg (D &C); King, Whitney Subject: NOT OPERABLE: Injector Z -102 (PTD #2070500) Due for 4 year Compliance Testing All, Injector Z -102 (PTD #2070500) is due for its 4 year AOGCC MIT -IA compliance testing. The well is currently shut in until Z -116 is finished drilling, which will not happen until later in 2011. The last MIT -IA performed was 09/07/2010 to 3000 psi which passed. Until such time that the well is ready to begin injection, the well is reclassified as Not Operable. Once the well is ready to begin injection, the well will be reclassified as Under Evaluation until the AOGCC witnessed test is completed. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator 1 • 0 Office (907) 659 -5102 CeII (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 2 OPERABLE: Injector Z -102 (PTD #2070500) OA repressurization manageable Page 1 of'S. Maunder, Thomas E (DOA' From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, November 27, 2010 12:32 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB Central Prod Opt Engr Cc: Janowski, Carrie; AK, D &C Well Integrity Coordinator; Oakley, Ray (PRA) Subject: OPERABLE: Injector Z -102 (PTD #2070500) OA repressurization manageable Attachments: Z -102 TIO Plot 10- 27- 10.doc All, Injector Z -102 (PTD #2070500) was found to have sustained casing pressure on the OA in early November. An OA repressurization test started on 11/19/10 passed as there was 0 psi build -up -rate during the 7 day monitor. The well has been reclassified as Operable and may be placed back on injection. After the well has been placed back on injection and thermally stable, the TIO plot will continue to be monitored for IA repressurization. A TIO plot has been provided for your reference. «Z -102 TIO Plot 10- 27- 10.doc» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: At, B& &,Well Integrity Coordinator Sent: Wednesday, No ter 03, 2010 7:26 PM To: 'Maunder, Thomas E (DOA) , ' - s i James B (DOA); 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; , • • Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team - • • K, D &C Well Services Operations Team Lead; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie Subject: UNDER EVALUATION: Injector Z -102 (PTD #2070500) OA Pressure Over MOASP All, Injector Z -102 (PTD #2070500) has been found to have sustained casing pressure above MOASP. The we - • pressures were tubing /IA/OA equal to 2200/60/1080 on 11/2/2010. The well is reclassified as Under Evaluation. The well may remain on injection while further diagnostics are performed. The plan forward is to: 10/25/2011 Welt Z-102 4,000 _ 3 000 - t Tbg f IA 2,000 - — A-- OA 00A 000A On 11000 - 08/28/10 09/11/10 09/25/10 10/09/10 10/23/10 11/06/10 11/20/10 ii 0-27 -2010 UNDER EVALUATION: Infector Z_102 (PTD #2070500) OA Pressure Over MOASP Page 1 of t • Maunder, Thomas E From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, November 04, 2010 9:49 AM To: Maunder, Thomas E (DOA) Subject: RE: UNDER EVALUATION: Injector Z -102 (PTD #2070500) OA Pressure Over MOASP Tom, The bleed history has been all fluid on the OA. Bleeds were performed on October 5th and November 2nd according to the Operator notes. I believe that the pressure swings are thernally induced, but with the pressure breaking MOASP on this last event, I believe it's prudent to place the well under evaluation to insure it's behaving. These 7" x 4 -1/2" annuli are so pressure responsive due to the smaller volumes (129 bbls on Z -102), I tend to err on the conservative side. My last name is "Murphy ". I'll keep you informed if I see anything further suspect. Regards, Jerry Murphy BPXA Wel Integrity Coordinator From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Thursday, November 04, 2010 7:56 AM To: AK, D &C Well Integrity Coordinator Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: UNDER EVALUATION: Injector Z -102 (PTD #2070500) OA Pressure Over MOASP Hi Gerry, What sort of bleed history does the annulus have? It appears from the plot that the OA pressures are responding to the rate changes indicating a thermal response as you noted in your call. Has it only been fluid being bled off? I seem to remember that there might be some other wells out there that have OA pressurization due to hydrates or shallow gas. It is appropriate to keep the well in service while conducting the diagnostics. Please keep me informed. Call or message with any questions. Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto: AKDCWelllntegrityCoordinator @bp.com] Sent: Wednesday, November 03, 2010 7:26 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie Subject: UNDER EVALUATION: Injector Z -102 (PTD #2070500) OA Pressure Over MOASP All, Injector Z -102 (PTD #2070500) has been found to have sustained casing pressure above MOASP. The wellhead 10/25/2011 UNDER EVALUATION: Infector 7 _ 1 "2 (PTD #2070500) OA Pressure Over MOASP Page 1 of 1 • • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Wednesday, November 03, 2010 7:26 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB Central Prod Opt Engr; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB East Wells Opt Engr; Oakley, Ray (PRA) Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie Subject: UNDER EVALUATION: Injector Z -102 (PTD #2070500) OA Pressure Over MOASP Attachments: Injector Z -102 (PTD #2070500) TIO & Injection Plot.doc; Injector Z -102 (PTD #2070500) Welibore schematic.pdf All, Injector Z -102 (PTD #2070500) has been found to have sustained casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 2200/60/1080 on 11/2/2010. The well is reclassified as Under Evaluation. The well may remain on injection while further diagnostics are performed. The plan forward is to: 1. Outer Annulus Represurization test (OART) A TIO, injection plot and wellbore schematic are included for reference. «Injector Z -102 (PTD #2070500) TIO & Injection Plot.doc» «Injector Z -102 (PTD #2070500) Welibore schematic.pdf» Please call if you have questions or concerns. Thank you, ^� LUI t0,,. . 1 Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 10/25/2011 • • Injector Z -102 (PTD #2070500) TIO Plot 2010 „2d o Welt Z -102 4 0 '0000 - Tbg - -F IA 2 000 - - -A- -- OA 00A —�- 000A On 1,000 08/14/10 00/28. 09/11/10 09/25/10 10/09/1 10,2;110 Injector Z -102 (PTD #2070500) Injection Plot WeFZ -102 2200- - - 20.010 2.090 - - 18000 1020 - 16000 1,600 - - 14,000 1,400 - £ -WHIP 0 1.200 - - 12,000 $ SW PVf MI 3 1000 - 10,000 n GI - B Otlw 800 . - 8.000 On 600 - 400 - d 000 MO - 2000 08107/10 06/14/10 08/21/10 08/28/10 09/04/10 09/11/10 09/18/10 09/25/10 10/02/10 10/09/10 10/16/10 10/23/10 10/00/10 NOT OPERABLE: Injector 1 -102 (PTD #2070500) Due for 4 year Compliance Testi ,g Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Tuesday, October 25, 2011 10 :00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad Z; Greaves, Damien C Cc: AK, D &C Well Integrity Coordinator; Arend, Jon (NORTHERN SOLUTIONS LLC); Clingingsmith, Mike J (Swift); Walker, Greg (D &C); King, Whitney Subject: NOT OPERABLE: Injector Z -102 (PTD #2070500) Due for 4 year Compliance Testing All, tt�� k..)rv.M x bk 4 :13 OS\ injector Z -102 (PTD #2070500) is due for its 4 year AOGCC MIT -IA compliance testing. The well is currently shut in until Z -116 is finished drilling, which will not happen until later in 2011. The last MIT -IA performed was 09/07/2010 to 3000 psi which passed. Until such time that the well is ready to begin injection, the well is reclassified as Not Operable. Once the well is ready to begin injection, the well will be reclassified as Under Evaluation until the AOGCC witnessed test is completed. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) ' "' Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 1 A 1 1 i +i ,~ _ r~ ~~~ ~= ~` ~4 _ Wit. ~~ ~..~~, ~'- a~ ~ mow, ~~ ~ ~ _ .. ""~ ~: ~ ~~ ~~~ ~ ~ ,MICROFILMED 6/30/2010 DO NOT PLACE ANY N EW MATERIAL UN-DER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc ~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 ~~~~~~``~~~~ ~`:~' ~,~ :~ ~ ~~~~v August 14, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB Z-Pad Dear Mr. Maunder, • bp M1 ~~~~~~~ 0 C T 0~ 2009 ~I~sk~ Oil ~ Gas Cons. Gor~u~~ion Anchoraq~ a07-~ ~~~~~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Z- 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 Expioration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Z-Pad 8/13/2009 Well Name PTD # API # Initiai top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al Z-01 B 2081080 50029218300200 NA 0.2 NA 3.40 7/24/2009 Z-02A 1960430 50029218140100 NA 0.4 NA 3.40 7/24/2009 Z-03 1971310 50029227870000 NA 1.3 NA 11.90 7/24/2009 Z-04A 2042300 50029219900~00 NA 1.5 NA 14.50 7/24/2009 Z-05 1900780 50029220560000 NA 1 NA 8.50 7/24/2009 Z-O6 1880320 50029217980000 NA 0.1 NA 1.70 7/24/2009 Z-07A 1931100 50029220460100 NA 2 NA 17.00 7/24/2009 Z-08A 1931280 50029217870100 NA 0.2 NA 2.55 7/24/2009 Z-09A 2081410 50029219670100 NA 0.2 NA 1.70 7/24/2009 Z-10 1891160 50029219860000 NA 1.3 NA 11.10 7/24/2009 Z-11A 2050310 50029220530100 NA 0.2 NA 1.70 7/26/2009 Z-12 1891020 50029219770000 NA 12 NA 8.50 7/26/2009 Z-13A 2042030 50029220690100 NA 3.6 NA 24.66 7/26/2009 Z-146 2060990 50029218440200 NA 0.2 NA 1.70 7/26/2009 Z-15 1880880 50029218490000 NA 0.2 NA 1.70 7/26/2009 Z-16 1920120 50029222450000 NA 0.3 NA 2.55 7/26/2009 Z-17 1891390 50029220010000 NA 3.7 NA 34.00 7/26/2009 Z-t8 1890960 50029219710000 NA 02 NA 1.70 7/26/2009 Z-19A 2061050 50029222510100 NA 0.2 NA 1.70 7/26/2009 Z-20 1881000 50029218590000 NA 0.2 NA 1.70 7/26/2009 Z-21A 2001010 50029219380100 NA 0.2 NA 1.70 7/23/2009 Z-226 1960350 50029220370200 NA 0.5 NA 5.10 7/23/2009 Z-23B 2041080 50029219500200 NA 0.3 NA 1.70 7J23/2009 Z-24 1890180 50029219170000 NA 0.3 NA 2.55 7/23/2009 Z-25 1881590 50029219020000 NA 0.2 NA i.70 7/23/2009 Z-26A 2060790 50029219450100 NA 0.3 NA 3.40 7/23/2009 Z-27 1900310 50029220220000 NA 0.2 NA 2.55 7/25/2009 Z-28 1881270 50029218790000 NA 0.2 NA 1.70 7/25/2009 Z-29 1890650 50029219540000 NA 0.2 NA 1.70 7/25/2009 Z-30A 2032190 50029220130100 NA 0.2 NA 3.40 7/25/2009 Z-31 1881120 50029218710000 NA 0.3 NA 3.40 7/26/2009 Z-32BL1 1970350 50029219246000 NA 0.2 NA 1.70 7/25/2009 Z-33A 1890050 5002921895ot00 NA 0.5 NA 3.40 8/8/2009 Z-35 1980930 50029228840000 NA 1.3 NA t 1.50 7/4/2009 Z-38 1980600 50029228730000 NA 1.2 NA 11.90 7/26/2009 Z-39A 2042240 50029229950100 NA 3.8 NA 39.90 7/25/2009 Z-46A 2052030 50029232800100 NA 1.7 NA 13.60 7/26/2009 Z-t00 2031710 50029231820000 NA 5 NA 45.90 7/23/2009 Z-101 2001620 50029229780000 NA 1 NA 1020 7l23/2009 Z-102 2070500 50029233530000 NA 1.5 NA 15.30 7/25/2009 Z-103 2042290 50029232350000 NA 1.5 NA 1020 7/25/2009 Z-to8 2052010 50029232920000 NA 1.5 NA 11.90 7/24/2009 Z-112 2071720 5002s23380000o NA surface NA lJ ~ u~v~~ DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070500 Well Name/No. PRUDHOE BAY UN BORE Z-102 Operator BP EXPLORATION (ALASI(~ INC API No. 50-029-23353-00-00 MD 9507 TVD 6569 Completion Date 5/18/2007 Completion Status 1WINJ Current Status 1WINJ ~UIC Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: This data area too small for data provided. See 10-407 (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / iy a mearrrmt rvumoer Name acme meaia no star[ stop ~rf tcecervea comments _ og ~ Cement Evaluation 5 Col 1 0 7550 Case 6!11/2007 USIT, CBL, GPIT, PPC, GR< CLL 17-May-2007 D D Asc Directional Survey 0 9507 Open 8/9/2007 pt Directional Survey 0 9507 Open 8/9/2007 D D Lis Directional Survey 0 8130 Open 8/9/2007 PB 1 pt Directional Survey 0 8130 Open 8/9/2007 PB 1 D C Lis 15415 Cement Evaluation 114 7481 Case 9/14/2007 LIS Veri, USIT, CCL, GR w/PDS Graphics D C Lis 15651 Induction/Resistivity 94 9511 Open 11/9/2007 LIS Veri, GR, ROP, FET, RPX, RPM, RHOB, DRHO, NPHI w/PDS graphics og 15651 Induction/Resistivity 25 Blu 100 9467 Open 11/9/2007 MD Vision Service 12-May- 2007 og 15651 Induction/Resistivity 25 Blu 100 9467 Open 11/9/2007 TVD Vision Service 12- May-2007 D C Lis 15652 Induction/Resistivity 94 8134 Open 11/9/2007 PB1 LIS Veri, GR, ROP, FET, RPM, DRHO, NPHI w/PDS graphics i og 15652 Induction/Resistivity 25 Blu 100 8094 Open 11/9/2007 P81 MD Vision Service 12- May-2007 og 15652 Induction/Resistivity 25 Blu 100 8094 Open 11/9/2007 PB1 TVD Vision Service 12-May-2007 DATA SUBMITTAL COMPLIANCE REPORT 6/2/2009 Permit to Drill 2070500 Well Name/No. PRUDHOE BAY UN BORE Z-102 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-23353-00-00 MD 9507 TVD 6569 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? ~'-/-fd^ Analysis Y7td- Received? Completion Date 5/18/2007 Completion Status 1WINJ Current Status 1WINJ Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~ N UIC Y Comments: Compliance Reviewed By: _~ __, Date: ~_~~~"^-3-~ 11/05/07 Sc~tumherg~r Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 4478 Company: Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Awora Borealis Date BL Color CD S-217 11594528 MDT 10/12107 1 S-217 11594528 USIT 10115107 1 5-125P81 REVISED 40015467 OH MWDILWD EDIT ?t ~ 07/07107 1 Z-102 40015187 OH MWDILWD EDIT 05112107 2 1 Z-102PB1 40015187 OH MWDILWD EDIT ~ 05107107 2 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. -- ,;i Anchorage AK 99508-4254 Date Delivered. ,y,^_ fl ^t1~i-~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 / ATTN: Beth n Received by MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~ ~ ~~~~ ~~J FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November O5, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (.ALASKA) INC Z-102 PRUDHOE BAY LJN BORE Z-102 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J< ~ Comm Well Name: PRUDHOE BAY UN BORE Z-102 Insp Num: mitRCN071029065520 Rel Insp Num: API Well Number: 50-029-23353-00-00 Permit Number: 207-050-0 Inspector Name: Bob Noble Inspection Date: t0i25i2007 Packer Depth Pretest Initial 15 Min. 30 vlin. 45 Min. 60 Min. -_ Weil z-102 Type InJ• W ~ TVD 6333 ~A 490 ~ 2200 /~ _I 2140 ~ 2130 ~, i __- _ _ P.T. '~ 2070500 iTypeT@St SPT 'rest pSl 1583 25 ~( OA _ ~ 270- i 320 i 330 ' 330 _ -- Interval ~TAL P/F P ~/ Tubing ~'~ 1600 'i 160o 160o I two ', Notes: Monday, November 05, 2007 Page 1 of l • • Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, October 22, 2007 1:56 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU Z-102 / PTD # 207-050 H i Art, Please reference the following well: Well Name: PBU Z-102 Permit #: 207-050 API #: 50-029-23353-00-00 Top Perf MD: 7716' Bottom Perf MD: 9402' This well began injection on October 14, 2007 Method of Operations is: Water Injection No Well Test Data Available 10/23/2007 -- c~®~-~~~ i~'C:iP..NICAL INTEGRITY REPORT ~liD D'.:_ : ~l~S-O~ OPER ~ FIELD ~~ ~c-~h0~ _ ~j©c'~.~~~ r~^^ '.,V C... _. :.,c-.. =. ~ ~~~V ~. 11':ri_r. 17 U11.1~C.R ~~ ~~~- ~. nr:ul~:s Press Test: _? Comments u ~3 ~ . r '_~CHPNIC~1., iNTEGRIT~ - PART #2 ~Sa~,~,~ Cement Volumes :~ Amt. Liner ~~Os~ ; ~ /( C.~t -rot to cover oers ~~ U ~ _ _- :eoret~cal TOC ~~ S ~ ~•~ czc ~cs.~ Ee CsQ DV ~R ~ Cement Bond Log (Yes or No)_\~_; In AOGCC File~_ Y ~ ~ C3L Fvzluation, gone above perfs ~ ~ ~s~~ ~- ~- -~ `~ ~ •~ ~ ~ Production`i,og~ Tyne :lam N- _ ~ ~ ~ ~ V ~"~~k'~~ a a c ix e r `3~~ '.'~ T'~i ; Set e t ~ C1~ ole S«e ~~ and ~ ~~ ; Perfs to GC~~f~ 3~ ~a-t0~ w~S~c,.~rac~c~ .+~ LL BAT~_ TD : C'l5®~ ?-~.. ~S~O~ 'I'VD ; PBTD : 1~~~ ?'ID ~~~~ ~\ W ~ ~e~J~~~ ~ ~'~ T Corsi^g: ~ Shoe: 1\ t•ID !~`lt~\ ~; LV: ~~- '-~ ~Q -ti`Di -==ie= = (.-~~~~~~ Shoe : ~S~ '~ ~p~~ T`1~ ; :CP . ~5~~-, ?•r~ ~S3` ~'iJ ~;,c?.P?~=C~.~, INTEGR'+_TY - PART #? CONCLJSIONS: Part 11: ~_. Part t2: ~ ~ ~S ~c~ ~t- V~C~-S ~`~C ~V .~ Evaluation 15 min ~0 min ~1~~~~ `~ ,~t,;tlvcv STATE OF ALASKA ~ 6' ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION .;=_l"d 1 5 2007 WELL COMPLETION OR RECOMPLETION REPORT AND L~~a ~; €-, , has Cons. Commission Anchorage 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.>>o ^ GINJ ®WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: ^ Development ^ Exploratory ®Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 5/1 2007 12. Permit to Drill Number 207-050 ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 4/29/2007 ~ 13. API Number 50-029-23353-00-0Oy 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 5/12/2007 ~ 14. Well Name and Number: PBU Z-1021 4565 FSL, 3542 FEL, SEC. 19, T11 N, R12E, UM Top of Productive Horizon: 4909' FSL, 653' FEL, SEC. 24, T11 N, R11 E, UM 8. KB (ft above MSL): 81.3' Ground (ft MSL): 52.8' 15. Field /Pool(s): , Prudhoe Bay Field /Borealis Pool Total Depth: 3209' FSL, 273' FEL, SEC. 24, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 9404 6582 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 599131 y- 5959360 Zone- ASP4 10. Total Depth (MD+TVD) 9507 6569 16. Property Designation: ADL 028245 TPI: x- 597063 y_ 5959678 Zone- ASP4 Total Depth: x- 597465 y- 5957982 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1741' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD / GR, MWD / GR /RES / NEWU /DEN /Sonic / PWD /Stethoscope, MWD / GR /RES /DEN / NEU, ABI, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH'MD SETTING DEPTH. TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM: SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 108' Surface 108' 42" 260 sx Arctic Set A rox. 9-5/8" 40# L-80 29' 3433' 29' 3093' 12-1/4" 535 AS Lite 401 sx Class'G' 7" 26# L-80 26' 7712' 26' 6586' 8-3/4" 223 sx LiteCrete 168 sx Class 'G' 4-1/2" 12.6# L-80 7594' 9450' 6531' 6576' 6-1/8" 250 sx Class'G' 23. Open to production or inject ion? ^Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-1/2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 x 7371' 7335' MD TVD MD TVD 3-1/2", 9.2# x 2-7l8", 6.4#, L-80 7371' - 7941' 7716' - 7756' 6588' - 6606' 7766' - 7786' 6611' - 6619' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9230' - 9260' 6596' - 6594' DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 9270' - 9350' 6594' - 6588' 9365' - 9402' 6586' - 6582' 7712' Set Whipstock (Planned Plugback) 3500' TVD Freeze Protect w/ 133 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N!A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PfeSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oii, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical. results per 20 AAC 250.071. r~r~ri~~iot~ None RBDMS BBL JUN 2 2 20D7 S Form 10-407 Revised 02/2007 ~ ~ ~ ~ ~ A ,~QDNTINUED ON REVERSE .SIDE ~ ~v ~~~ /,' 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Teste ®Yes ^ No Permafrost Top 81.3' 81.3' If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base 1936' 1823' detailed test information per 20 AAC 25.071. Ugnu 3543' 3190' Ugnu M Sands 4517' 4107' Pressure samples were taken. I will submit the results when I submit the revised 10-407 upon when first injection begins. Schrader Bluff N Sands 4749' 4329' Schrader Bluff O Sands 4935' 4507' Base Schrader Bluff /Top Colville 5306' 4860' Top HRZ 7159' 633T Top Kalubik 7581' 6525' Kuparuk C 7710' 6585' Kuparuk B 7813' 6629' Kuparuk A 7914' 6659' Kuparuk A 8251' 6655' Kuparuk B 8430' 6627 Kuparuk C /Base Kalubik 9446' 6577 Formation at Total Depth (Name): Kalubik 9446' 6577' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. /,~ I l-J(~ / ~ - /~ Title Technical Assistant Date Signed Terrie Hubble ~~V 7 PBU Z-1021 207-050 Prepared eyName/Number. Terre Hubble, 564-4628 W211 Number Drilling Engineer: Michael Triolo, 564-5774 Permit No. / A royal No. INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only BP Leak-Off Test Summary Legal Name: Z-102 Common Name: Z-102i Test Date Test Type Test Depth (TMD)~ Test Depth (TVD) AMW Surface Pressure 5/3/2007 LOT 3,433.0 (ft) 3,091.0 (ft) 8.90 (ppg) 1,232 (psi) 5/9/2007 FIT 7,725.0 (ft) 6,592.0 (ft) 10.10 (ppg) 480 (psi) .Leak Off Pressure (BHP) 2,661 (psi) 3,939 (psi) Page 1 of 1 EMW 16.57 (ppg) 11.50 (Ppg) ~~ Printed: 5/21/2007 9:09:31 AM BP Operations Summary Report Page 1 of 18 ~ Legal Well Name: Z-102 Common Well Name: Z-102i Spud Date: 4/29/2007 Event Name: DRILL+COMPL ETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALAS KA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To ~ Hours Task Code ~ NPT Phase i Description of Operations 4/26/2007 04:00 - 07:00 3.00 RIGD P PRE Bridle up, Disconnect service loop, Prepare rig for move, finish offloading 85 bbls from slop tank 07:00 - 19:00 12.00 MOB N WAIT PRE Wait on weather, Phase 2 conditions 19:00 - 21:00 2.00 MOB P PRE PJSM, Trucks on location @ 1900 hrs -Connect to satellite camp, weld shop, truck shop 21:00 - 22:00 1.00 MOB N WAIT PRE Wait on Security to escort convoy 22:00 - 00:00 2.00 MOB P PRE Move Camp, Truck Shop and welding shop to Z-pad 4/27/2007 00:00 - 12:00 12.00 MOB P PRE Move mud pits and rig from V-Pad to Z-Pad 12:00 - 22:00 10.00 MOB N HMAN PRE Exiting from Z-Pad access road and entering Z-Pad, the driller side rear fire of the rig left the roadway. -Cribbed under the outside fire -move rig back on to roadway 22:00 - 00:00 2.00 MOB P PRE Move rig into position on Z-Pad to raise derrick -PJSM, Inspect and raise derrick 4/28/2007 00:00 - 05:00 5.00 DIVRTR P PRE ACCEPT RIG C~3 00:01 4/28/2007 (Back out 12 hrs for phase 2 weather and Work on the Diverter) Install 20" Annular on Conductors starting ring -Install Diverter line behind Sub (Digging out snow for Diverter line) 05:00 - 06:00 1.00 DIVRTR P PRE Spot wellhead equipment behind sub 06:00 - 12:00 6.00 RIGU P PRE Remove snow ,Lay Matting Boards, Spot rig over Z-102, -Spot Pits -Build berms and level rig -M/U interconnects and winterize rig 12:00 - 15:30 3.50 DIVRTR P PRE Take on water, Start making up Spud mud -Install Dump valves on stack & Secure cellar -Prep Rig Floor -M/U Service lines -Bridle Down & Secure back in derrick 15:30 - 21:30 6.00 DIVRTR P PRE Nipple up Riser, Flowlines and Turnbuckles -Secure stack and ready cellar for drilling operations 21:30 - 00:00 2.50 DIVRTR P PRE Drill out ice in conductor -P/U Used 12 1/4" Mill tooth bit, NB Stab, XO 1 stand of 4" DP -Drill from 35' - 100' 550 gpm / 300 psi / 55 rpm 4/29/2007 00:00 - 00:30 0.50 DIVRTR P PRE Pre-spud safety meeting with BP WSL &NAD toolpusher and rig crew. 00:30 - 04:00 3.50 DIVRTR P PRE Pick 2900' 4' HT-40 DP and stand back in derrick P/U 4" HWDP 04:00 - 05:30 1.50 DIVRTR P PRE Clean out Conductor to 100' -50 Rpm / 100 spm Gravel and sand returns 05:30 - 07:30 2.00 DIVRTR P PRE Cut Drilling Line -Service Top Drive, Drawworks, And Crown 07:30 - 08:00 0.50 DIVRTR P PRE Drain stack and clean out knife valve before performing function test 08:00 - 08:30 0.50 DIVRTR P PRE Perform Diverter test Test waived by AOGCC John Crisp Witness by BP WSL Alan Madsen, NAD TP Bill Bixby 08:30 - 09:30 1.00 DRILL P PRE M/U stand with 5" HWDP and Jars, M/U Stand 6 3/4" DC's 09:30 - 11:00 1.50 DRILL P PRE M/U BHA #1; 12 1/4" Bit , 1.83 deg bent motor, NMLC, 12 1/4" Printed: 5/21/2007 9:09:37 AM ~ ~ BP Operations Summary Report Page 2 of 18 ~ Legal Well Name: Z-102 Common Well Name: Z-102i Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To ~ Hours Task Code I NPT Phase Description of Operations 4/29/2007 09:30 - 11:00 ~ 1.50 DRILL P ~ ~ PRE NM Stab MWD 12 1/4" NM Stab, XO, UBHO Sub 11:00 - 12:00 1.00 DRILL P 12:00 - 14:00 2.00 DRILL P 14:00 - 15:00 1.00 DRILL P 15:00 - 20:00 5.00 DRILL P 20:00 - 21:00 1.00 DRILL P 21:00 - 00:00 3.00 DRILL P 14/30/2007 ~ 00:00 - 00:30 ~ 0.50 ~ DRILL ~ P 00:30 - 01:30 I 1.001 DRILL I P 01:30 - 03:30 2.001 DRILL P 03:30 - 04:30 1.00 DRILL P 04:30 - 05:00 0.50 DRILL P 05:00 - 06:00 1.00 DRILL P 06:00 - 12:00 I 6.001 DRILL I P -Orient MWD & UBHO Sub -P/U Collar Stand PRE PJSM, Rig up HES wireline Sheaves and GyroData Survey tool SURF Drill Directionally as per Anadrill Directional Driller, 108 - 442' - 65 Rpm , 1.5k Tq off / 2 Tq On - 550 gpm, 1100 psi off / 1200 psi on - 10-20k WOB Gyro Survey at 261' SURF POH, To collar stand , P/U 8 3/4" Stab., P/U Jar Stand -RIH SURF Drill Directionally as per Anadrill Directional Driller, 442' - 1195' -65Rpm,4kTgoff/5kTgOn - 650 gpm, 1950 psi off / 2050 psi on - 10-30k WOB SURF CBU, Take Multi Shot Gyro survey ,Lay down Survey tool and Rig Down Wireline SURF Drill Directionally as per Anadrill Directional Driller, 1195' - 1578 (1521' tvd) -75Rpm,4kTgoff/SkTgOn - 650 gpm, 1950 psi off / 2050 psi on - 10-30k WOB PUW 78K /SOW 70K / RtWt 75k AST= 3.09 /ART=3.06 for tour SURF Drill Directionally as per Anadrill Directional Driller, 1578' - 1674' (1601' tvd) -75Rpm,4kTgoff/5kTgOn - 650 gpm, 2050 psi off / 2250 psi on - 10-30k WOB PUW 80K /SOW 70K / RtWt 75k SURF CBU 3x, 605 gpm / 2050 psi, 75 rpm, 3k Tq Monitor well, Static 9.0 ppg MW in/out SURF POH to Change Bit and adjust Bend on Motor from 1.83 to 1.5 deg - No problems POH, Proper Fill, - One area of overpull ~ 1130', Work area, no problem after wiping 1x SURF Change Bit and adjust motor SURF Service TDS, Drawworks and Crown -Clean Floor SURF RIH to 1674' -Work through intermediate tight spots without issues -Precautionary ream last stand to bottom SURF Drill Directionally as per Anadrill Directional Driller, 1674' - 3393' (3057' tvd) -80Rpm,5kTgoff/8kTgOn - 700 gpm, 3150 psi off / 3200 psi on - 10-30k WOB PUW 100K /SOW 80K / RtWt 91 k AST = 0.68 /ART = 3.13 / ADT = 3.81 Printed: 5/21/2007 9:09:37 AM BP Operations Summary Report Page 3 of 18 ~ Legal Well Name: Z-102 Common Well Name: Z-102i Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Description of Operations 4/30/2007 06:00 - 12:00 6.00 DRILL P SURF Hydrates ~ 2690' (10% increase in flow), Depleted C~ 2820' 12:00 - 12:30 0.50 DRILL P SURF Circ. Samples up for Geologist -680 gpm / 3325 psi ! 80 rpm / 8.7k Tq 12:30 - 13:00 0.50 DRILL P SURF Drill Directionally as per Anadrill Directional Driller, 3393' - 13:00 - 14:30 I 1.501 DRILL I P 14:30 - 15:30 1.00 DRILL P 15:30 - 16:00 0.50 DRILL P 16:00 - 18:00 2.00 DRILL P 18:00 - 20:00 I 2.001 DRILL I P 20:00 - 21:30 I 1.501 DRILL I P 21:30 - 00:00 I 2.501 DRILL I P 5/1/2007 100:00 - 02:00 2.00 DRILL P 02:00 - 04:30 I 2.501 CASE I P 04:30 - 05:00 0.50 CASE P 05:00 - 13:30 8.50 CASE P 3444 (3102' tvd) TD -80Rpm,5kTgoff/8kTgOn - 620 gpm, 3150 psi off / 3350 psi on (Max psi for liners) - 10-30k WOB PUW 105K /SOW 85K / RtWt 94k AST = 0.34 /ART = 0.0 / ADT = 0.34 SURF CBU 3x's -700 gpm / 3220 psi / 100 rpm / 4k Tq PUW=112k /SOW=91 k Monitor well, Static 9.1 ppg in/out SURF POH 3444 - 2800', O.K. 2800' 25k overpull, wipe hole, hole started taking fluid SURF Monitor for losses, Total loss of 41 bbls -hole static SURF cont. POH from 2800, swabbing with 15-25k overpulls, -Backream out from 2620 - 2533' -hole start swabbing again @ 2341' -pump out ~ 450 gpm / 1200 psi to 1860' -POH 1860' - 1576, O.K. SURF RIH from 1576 - 2730', tight spot, work through O.K. -RIH to 2800' Unable to work through, Ream @ 50 rpm / 50 spm (150 gpm) and work through without problems -Cont. RIH to 3393' SURF Wash last stand to 3444', no fill CBU 3x's -700 gpm / 3220 psi / 100 rpm / 4k Tq PUW=115k /SOW=88k Monitor well, Static 9.4 ppg in/out SURF POH 3444' - 1863' no problem proper fill, no overpulls or swabbing C~ 1862 - 1767 pump out due to 25k overpull & swabbing, work stand 1 x without issue POH to 663' , no problem SURF Finish standing back 4" HWDP, Jars, DC's - UD MW D, Stabs, NMLC, 9 5/8" Motor & Bit Clean up rig floor, UD all third party tools SURF PJSM Make Dummy run with casing hanger -Change out bales and install long bales -M/U Franks fill up tool -R/U casing elevators, Slips, & power tongs -Ready rig floor to run casing SURF PJSM with NAD rig crew, NAD Toolpusher, NAD casing crew and BP WSL SURF -Ran 40# L-80 9 5/8" BTC surface casing to 3433'. -Bakerlock Shoe Track -TO to 9200 ft/Ibs / BOL 2000NM pipe dope -25 -Bow Spring centralizers ran on the first 25 joints into hole -Fill every joint Printed: 5/21/2007 9:09:37 AM N r BP Operations Summary Report Page 4 of 18 Legal Well Name: Z-102 Common Well Name: Z-102i Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABORS 9ES Rig Number: 9ES Date ~ From - To Hours Task Code; NPT Phase ~, Description of Operations 5/1/2007 05:00 - 13:30 8.50 CASE P SURF -Up 180k, Dn 96k -Tight spots at 2032' and 2299' to 2668', pump at 4 bpm HES float shoe ~ 3433' HES float collar @ 3352' 13:30 - 14:00 0.50 CEMT P SURF Rig down Franks tool. Blow down top drive. Make up Cement head 14:00 - 16:00 2.00 CEMT P SURF Stage up pumps and circulate @ 330 gpm / 625 psi. Slow pumps to 220 gpm / 380 psi. Begin dropping fluid funnel viscosity. 16:00 - 17:30 1.50 CEMT N WAIT SURF Wait on Peak Vac Truck 17:30 - 19:00 1.50 CEMT P SURF Circulate and condition mud for cement job. Pump at 220 gpm / 210 psi. Thinned the mud using CF Desco, SAPP, and water for a final YP of 15. 19:00 - 19:30 0.50 CEMT P SURF PJSM with NAD rig crew, NAD Toolpusher, BP WSL, Dowell Cementing Crew 19:30 - 23:30 4.00 CEMT P SURF Shut down rig pumps and swap to Dowell. Pump 5 bbls water and PT lines to 3500 psi. Pump 72 bbls of 10.7 ppg Mudpush at 5.2 bpm, 104 psi. Drop bottom plug. Pump 428 bbls of 10.7 ASL at 6 bpm, 370 psi. Pump 83 bbls of 15.8 ppg G tail cement at 3.5 bpm, 155 psi. Drop top plug. Pump 10 bbls of water to wash cement lines. Swap to rig and chase cement with 235 bbls of 9.2ppg drilling fluid at 6 bpm, 755 psi. Reduce to 2 bpm, 530 psi by plug bump. Bump plug at calculated strokes, pressure up to 1300 psi and check floats - OK. -CIP at 23:19 hrs -Full returns throughout entire cement job -170 bbls of cement returned to surface -Reciprocate pipe 10' when pumping -Land casing 150 bbls into displacement -35 bbls into pumping the tail, the Dowell bulk truck hose stopped sending product to the pump truck. The bulk truck hose was changed and pumping continued. 23:30 - 00:00 0.50 CEMT P SURF Pressure test the surface casing to 3500 psi for 30 minutes - OK. 5/2/2007 00:00 - 02:00 2.00 CEMT P SURF RD cement head and circulating lines. RD casing equipment. Flush landing joint, bag and knife valve. 02:00 - 04:00 2.00 DIVRTR P SURF ND Diverter system. Change 20" adapter to 16" air boot. 04:00 - 07:30 3.50 WHSUR P SURF Move casing and tubing spools into cellar. NU and test wellhead. Test metal to metal seals to 1000 psi for 10 minutes - OK. 07:30 - 11:00 3.50 WHSUR P SURF NU BOPE, flush stack with jetting tool. 11:00 - 12:00 1.00 WHSUR P SURF Service and lubricate the rig and top drive. 12:00 - 12:30 0.50 W HSUR P SURF RU 4" floor valve testing equipment. Fill lines with water. 12:30 - 16:00 3.50 W HSUR P SURF Pressure test BOPE at 250 psi low / 4000 psi high for 5 minutes each Pressure test Annular Preventer 250 psi low / 3500 psi high for 5 minutes each AOGCC rep Jeff Jones waived witness of test Test witnessed by WSL Brian Buzby, NAD TP Bill Bixby, NAD Driller Sean Holcomb Printed: 5/21/2007 9:09:37 AM ~ ~ BP Operations Summary Report Page 5 of 18 ~ Legal Well Name: Z-102 Common Well Name: Z-102i Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code ~ NPT ~ Phase ~ Description of Operations ___ 5/2/2007 16:00 - 16:30 0.50 W HSUR P SURF Rig down testing equipment and blow down lines. Install the wear ring. 16:30 - 23:00 6.50 W HSUR P SURF Pick-up 99 joints of 4" drill pipe to 2970'. POOH 33 stands of 23:00 - 23:30 0.50 DRILL P INTi 23:30 - 00:00 0.50 DRILL P INTi 5/3/2007 00:00 - 01:30 1.50 DRILL P INT1 01:30 - 02:00 0.50 DRILL P INTi 02:00 - 03:00 1.00 DRILL P INT1 03:00 - 03:30 0.50 DRILL P INT1 03:30 - 06:30 3.00 DRILL P INT1 06:30 - 07:30 1.00 DRILL P INT1 07:30 - 08:00 0.50 DRILL P 08:00 - 08:30 0.50 DRILL P 08:30 - 09:00 I 0.501 DRILL I P 09:00 - 12:00 I 3.001 DRILL I P 12:00 - 23:30 I 11.501 DRILL I P 23:30 - 00:00 I 0.501 DRILL I P 5/4/2007 100:00 - 12:00 12.00 DRILL P 12:00 - 18:30 I 6.501 DRILL I P 4" drill pipe. Pick-up 21 joints of 4" drill pipe. POOH 7 stands of 4" drill pipe. Clean and clear rig floor. PJSM for making up the 8.75" BHA #3 Make up 8.75" DSX619M-D2 bit and PDM on BHA #3. Continue making up BHA #3. PU Ecoscope, Telescope, and Stethoscope. Surface function test MWD/LWD tools - OK. PJSM -cover radioactive source handling procedures with rig crew. Continue making up BHA #3. PU Sonic tools, NM DC, HW DP to 200'. Shallow hole test BHA #3 - OK. Continue making up BHA #3. Single in BHA to 2383' and install Ghost Reamer. RIH to 3251'. Wash down and tag float collar at 3352'. Drill shoe track and rat hole to 3444', drill 20' new hole to 3464'.. 510 gpm, 1980 psi off, 2185 psi on, 60 rpm, 5k TO, 5K WOB, 125k up, 75k down, 95k rotating. Begin displacing spud mud with LSND at 3443'. Finish displacing well to 8.8 ppg LSND. Pull up to shoe. Conduct LOT. MD = 3433', TVD = 3091', 1232 psi surface pressure, 8.8 ppg LSND. EMW = 16.56 ppg Obtain benchmark ECD's: 0 rpm, 9.32 ppg 80 rpm, 9.38 ppg Drill from 3464' to 3921'. 118k Up, 85k down, 95k rotating, 20k wob, 585 gpm, 1590 psi off, 1640 psi on, 80 rpm, 4k torque off, 5k torque on bottom. Backream each stand 60' and 75% drilling rate down. Surveys every 90'. Drill from 3921' to 5644'. 145k up, 110k dn, 125k rot, 585 gpm, 2670 psi on, 2330 psi off, 80 rpm, 10-25k wob, 7k tq on, 6.1 k tq off Backream each stand 60' and 75% drilling rate down. Surveys every 90'. Calc ECD's 9.65 ppg, Actual ECD's 10.14 ppg. AST=3.72 hrs, ART=3.17hrs MAD pass from 5644' to 5548' at drilling rate to collect GR, which was not sent up on last stand. Cycle pumps to reset tool. Drill from 5644' to 6476' 161 K up, 111 K down, 133K rot, 30k W OB, 585 gpm, 2460 psi off, 2750 psi on, 80 rpm, 7k TO off, 8k TO on. Backream 60' at 80 rpm 585 gpm, reduce to 75% down. Survey every 90' AST=3.48 hrs, ART=5.92hrs Calc ECD = 9.75, Act ECD = 10.16 Note: Pump 35 bbl hi-vis sweep at 6122'. No increase in cuttings observed. Drill from 6476' to 6865'. INT1 INT1 INT1 INT1 INT1 INTi INT1 INT1 Printed: 5/21/2007 9:09:37 AM ~ ~ BP Operations Summary Report ,Legal Well Name: Z-102 ',Common Well Name: Z-102i 'Event Name: DRILL+COMPLETE (Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date !From - To ;Hours Task Code NPT '.5/4/2007 12:00 - 18:30 ~ 6.50 DRILL P 18:30 - 00:00 I 5.501 DRILL I P 15/5/2007 100:00 - 07:30 I 7.501 DRILL I P 07:30 - 08:00 0.50 DRILL P 08:00 - 08:30 0.50 DRILL P 08:30 - 14:00 I 5.501 DRILL I P 14:00 - 16:00 ~ 2.00 ~ DRILL ~ P 16:00 - 00:00 I 8.001 DRILL I P 15/6/2007 100:00 - 01:30 1.501 DRILL P 01:30 - 03:00 I 1.501 DRILL I P Start: 4/28/2007 Rig Release: 5/19/2007 Rig Number: 9ES Phase INT1 INT1 INT1 INT1 INTi INT1 INT1 INT1 Page 6 of 18 ~ Spud Date: 4/29/2007 End: 5/19/2007 Description of Operations 161 K up, 111 K down, 133K rot, 30k WOB, 585 gpm, 2460 psi off, 2750 psi on, 80 rpm, 7k TO off, 8k TO on. Backream 60' at 80 rpm 585 gpm, reduce to 75% down. Begin adding 13.4 ppg LSND spike fluid, treated with black products, to weight up the mud to 10.6 prior to entering the HRZ. Drill from 6865' to 7290'. 151 k up, 117k dn, 134k rot, 30k wob, 525 gpm, 2960 psi off, 3320 psi on, 80 rpm, 5k TO off, 7k TO on. Backream 60' at 80 rpm 585 gpm, reduce to 75% down. Survey every 90' AST=6.42 hrs, ART=2 hrs Calc ECD = 11.18, Act ECD = 11.68 13.4 ppg spike fluid blended and mud system at 10.6 ppg by 6950' Reduce pump rate from 585 to 525 for drilling HRZ. Drill from 7290' to TD at 8130'. 164k up, 111k dn, 135k rot, 5-30k wob, 525 gpm, 3371 psi off, 3748 psi on, 80 rpm, 6.3k TO off, 8.3k TQ on. Backream 60' at 80 rpm 525 gpm, reduce to 75% down. Survey every 90' Calc ECD=11.18, Act ECD=11.66 AST=1.3hrs, ART=4.3hrs At 7843', gas was seen breaking out at the bell nipple, expect Kuparuk gas. From 7896' to 8130', the neutron generator (PNG) quit working. WSL notified ~ 21:OOhrs. Pumped weighted sweep at 8035', no increase in cuttings observed. CBU at drilling rates, 525 gpm, 3371 psi off. Downlink to MWD tool to shut off neutron generator, which was already off. MAD pass from 8130' to 7680' (above the TKC4) at 100 fph. 525 gpm, 3413 psi, 80 rpm, 5.8k tq, 134k rt wt Increase MAD pass rate to 600 fph. Continue MAD pass. MAD pass from 7680' to 7145' (above the HRZ) at 600 fph. 525 gpm, 3413 psi, 80 rpm, 5.Sk tq, 130k rt wt. Increase pump rate to 585 gpm Continue MAD pass. MAD pass from 7145' to 4304' at 600 fph. 585 gpm, 2800 psi, 80 rpm, 4.5k tq, 105k rt wt. Fault related lost circulation at 4450', 20 bph INTi Continue MAD pass from 4303' to 3930' at 600 fph. 530 gpm, 2130 psi, 80 rpm, 3.7k tq, 97k rt wt Continue fault related lost circulation to 3930' Slow pumps to 450 gpm Add Mix II LCM Regain full returns above 3930' Lost a total of 85 bbls INT1 Continue MAD pass from 3930' to 3433' at 600 fph. 530 gpm, 2104 psi, 80 rpm, 3.7k tq, 94k rt wt Printed: 5/21/2007 9:09:37 AM g p Page 7 of 18 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: Z ell Name: Z e: Name: From - To i -102 -102i DRILL+C NABOBS NABOBS Hours ~ OMPLE ALASK 9ES Task TE A DRI Code LING NPT Start I Rig Rig Phase Spud Date: 4/29/2007 : 4/28/2007 End: 5/19/2007 Release: 5/19/2007 Number: 9ES Description of Operations 5/6/2007 01:30 - 03:00 1.50 DRILL P INT1 Full returns No static losses 03:00 - 03:30 0.50 DRILL P INT1 CBU at surface casing shoe, 530 gpm, 1982 psi. No dynamic or static losses. Downlink to MW D EcoScope and attempt to activate PNG - PNG not responding. 03:30 - 04:30 1.00 DRILL P INT1 Slip & Cut 65' of drilling line. 04:30 - 05:00 0.50 DRILL P INT1 Service top drive, blocks, crown, drawworks. 05:00 - 08:00 3.00 EVAL P INTi RIH from 3433' to 8130'. At 8035' turn on pumps and wash down to 8130' 526 gpm, 3326 psi, 80 rpm, 8.3k tq Hole tight and attempting to pack-off from 8064' to 8130'. Pump rate reduced and the pipe was worked to bottom. 08:00 - 09:00 1.00 EVAL P INT1 CBU. Circulate one BU at reduced rate, 300 gpm. For second BU, staged up pumps to 526 gpm, 3313 psi, 80 rpm, 8.5k tq, 137k rt wt Trip gas seen 20 bbls prior to first bottoms up and cleared up 20 bbls after BU. After the gas clean up, circulated another bottoms-up at 526 gpm. 09:00 - 10:00 1.00 EVAL P INT1 Downlink to MWD tools. Troubleshoot EcoScope and attempt to activate PNG -not responding. Activate Stethoscope Tool and prepare to take pressure samples. 10:00 - 00:00 14.00 EVAL P INT1 POOH from 8130' to 7884' and orient Stethoscope for samples. 185k up, 110k do Rotate packer 20 turns when packer doesn't set, to clear debris from packer. Work pipe and cycle pumpesbefore setting packer on depth. Pump rates while taking samples: Low rate is 430 gpm, 2350 psi and high rate is 525 gpm, 3260 psi. A total of 28 samples were attempted before 00:00, 16 samples from the TKC4 and TKC1 sands were successfully taken. After sample #18, had to downlink to Stethoscope and reset tool - OK. The packer had a difficult time sealing on the last 6 sample depths and no pressure samples were taken. Suspect that the packer rubber had deteriorated. After last TKC4 sample attempt, RIH to attempt A5 samples. 5/7/2007 00:00 - 00:30 0.50 EVAL P INT1 RIH to 7990' and attempt A5 sand pressure sample - no sample. Suspect packer is not sealing. Geologist are ok with previous samples and no more samples are attempted. 00:30 - 01:30 1.00 EVAL P INT1 Wash down from 7990' to 8130', no problems. CBU. 526 gpm, 3282 psi, 95 rpm, 8.2k tq, 139 rt wt. 01:30 - 05:00 3.50 EVAL P INTi Monitor well. POOH from 8130 to 7174', 190k up, 109k down. Pump dry job and continue to POOH to 9 5/8" shoe. 05:00 - 07:30 2.50 DRILL P INT1 Continue POH from 9 5/8" shoe stand back HWDP, UD NM Printed: 5/21/2007 9:09:37 AM BP Operations Summary Report Page 8 of 18 Legal Well Common W Event Nam Contractor Rig Name: Date ~~ Name: Z ell Name: Z e: Name: From - To ~ -102 -102i DRILL+C NABOB NABOB Hours ~ OMPLETE S ALASKA DRILLING S 9ES Task j Code': NPT Spud Date: 4/29/2007 Start: 4/28/2007 End: 5/19/2007 I Rig Release: 5/19/2007 Rig Number: 9ES Phase ~ Description of Operations 5/7/2007 05:00 - 07:30 2.50 DRILL P INT1 Dc's, MWD/LWD motor and bit. 07:30 - 08:00 0.50 DRILL P INT1 Clean & clear rig floor of vendor tools. 08:00 - 10:30 2.50 CASE P INT1 Pull wear ring, tlush stack, and install test plug. Change rams from 3.5"x6" variables to 7" rams. Test 7" rams to 250 psi low and 4000 psi high. 10:30 - 12:00 1.50 CASE P INT1 Make dummy run with 7" casing hanger. Change from short bales to long bales. Rig up the 7" casing handling equipment. Make up the Franks fill up tool. Rig up the casing tongs and scafolding. 12:00 - 12:30 0.50 CASE P INT1 PJSM -Cover casing running and handling. 12:30 - 17:00 4.50 CASE P INT1 RIH with 7", 26#, L-80, BTC-Mod x TC-II casing. Run 7" casing to 3414', just inside the surface casing shoe. BakerLok BTC-M shoe track and make up to mark (9200 fUlbs) Fill and check floats - OK. Cross over to TC-II and continue to run 7" casing per tally. Torque turn every TC-II connection, avg 10100 fUlbs. Dope each TC-II connection with Jet Lube Seal Guard. RIH at 1 minute per joint Fill each joint, break circulation every 20 joints Record PU/SO every 10 joints (at shoe, PU 100k, SO 80k) 17:00 - 18:00 1.00 CASE P INT1 CBU 3x at 3414' 213 gpm, 350 psi No fluid losses 18:00 - 00:00 6.00 CASE P INT1 Run 7", 26#, L-80, BTC-M x TC-II casing into open hole. Run casing to 6606' depth by midnight, PU 210k, SO 133k. RIH at 2 minutes per joint Fill each joint, break circulation every 10 joints for 3 minutes Record PU/SO every 10 joints 5/8/2007 00:00 - 02:30 2.50 CASE P INT1 Run 7", 26#, L-80, TC-II casing to depth at 8114. PU 252k, SO 136k. RIH at 2 minutes per joint Fill each joint, break circulation and wash down every 10 joints ', fora minutes ', Record PU/SO every 10 joints Took string weight at 6892', worked through. No losses while running casing 02:30 - 03:00 0.50 CEMT P INTi Rig down Franks fill-up tool, blow down top drive. Rig up Cement head -verified that plugs are installed Rig up cement circulating lines. 03:00 - 05:00 2.00 CEMT P INT1 CBU. Stage up pumps slowly for BU. 2 bpm = 345 psi 3 bpm = 430 psi 4 bpm = 531 psi 5 bpm = 630 psi Circulate at 5 bpm ~ 05:00 - 05:30 0.50 CEMT P INT1 PJSM -Hold cement job safety meeting with NAD crew and I Dowell crew. 05:30 - 08:00 2.50 CEMT P INT1 Pump 5 bbls water and test lines to 3,500 psi, Pump 42 bbls Mud-push weight to 11.3 ppg, initial rate 5 bpm ~ 457 psi final rate 4.7 bpm ~ 429 psi. Drop bottom plug and pump 98 bbls of 12.0 ppg Crete, initial rate @ 4.8 bpm @ 526 psi, final rate 4.8 Printed: 5/21/2007 9:09:37 AM • ~r BP Operations Summary Report Page 9 of 18 Legal Well Common W Event Nam Contractor Rig Name: Date- , ~ Name: Z ell Name: Z e: Name: From - To -102 -1021 DRILL+C NABOB NABOB I Hours OMPLE S ALASK S 9ES ' Task I TE A DRI Code ` ,~ LING NPT Start I Rig Rig Phase i Spud Date: 4/29/2007 : 4/28/2007 End: 5/19/2007 Release: 5/19/2007 Number: 9ES Description f Operations ~ 5/8/2007 05:30 - 08:00 2.50 CEMT P INTi ~ bpm ~ 475 psi, followed by 35 bbls 15.8 ppg tail cement, initial rate 3.3 bpm @ 223 psi, final rate 3.8 bpm ~ 155 psi, shut down and wash up cement lines through Tee, Switch over to rig drop top plug and displace cement with 8.5 ppg seawater initial rate 5 bpm C~3 100 psi, caught up with cement 25 bbls into displacement, slowed rate to 3 bpm, 1,280 psi with 240 bbls away, pumped the last 20 bbls at 2 bpm FCP 1770 psi. Land casing 7 bbls prior to plug bump, initial up wt = 252k, do wt = 135k, final up wt = 190k do wt = 90k. bump plug with 2300 psi at calculated strokes. CIP ~ 07:15 Bled off pressure and checked floats, ok. Pressure up to 4,000 psi and test casing held for 30 min record on chart. No losses during cement job. 08:00 - 09:00 1.00 CEMT P INTi R/D cement head, back out and lay down landing joint, rig down elevators and change out bails. 09:00 - 09:30 0.50 WHSUR P INT1 Install and test 7" packoff to 5,000 psi, good test. 09:30 - 11:30 2.00 BOPSU P INT1 Flush stack and install test plug, Change top rams from 7" to 3.5" X 6" VBR and test with 4 1/2" test jt to 250 psi low 4,000 psi high, rig down test equipment, pull test plug and install wear ring. 11:30 - 12:00 0.50 STWHIP P PROD1 Lift whipstock and milling tools to rig floor. 12:00 - 13:00 1.00 STWHIP P PROD1 M/U and rack back 9 4 3/4" steel DC's. Perform infectivity test on OA while making up DC's, 10.6 ppg mud, 3091' tvd, pressure attained 930 psi 16.38 EMW 5 bbls pumped. 13:00 - 13:30 0.50 STWHIP P PROD1 R/U 4 1/2" handling equipment and casing tongs. and M/U 7 joints 4 1/2" IBT-M and 10' pup jt to space out whipstock on float collar. 13:30 - 16:30 3.00 STWHIP P PROD1 M/U 7" Baker whipstock and mills, P/U MWD, orient MWD and whipstock, RIH with 9 4 3/4" DC's and 24 joints 4" HWDP to 1420' 16:30 - 17:00 0.50 STWHIP P PROD1 Shallow test MWD, 270 gpm 985 psi ok. 17:00 - 21:00 4.00 STWHIP P PROD1 RIH with whipstock on 4"DP, from 1,420' to 7,597' filling pipe as needed. 21:00 - 22:00 1.00 STWHIP P PROD1 Break circulation orient Whipstock, 46L of highside, up wt = 180k do wt 105k 270 gpm, 1250 psi wash down from 7597' to 7,712' set anchor, sheared with 15k down, picked up 15k over to confirm anchor set, set down 35k and shear off whipstock. Top of Whipstock @ 7,712' Bottom of Whipstock @ 7,725' Freeze protect OA out of critical path, R/U Little Red, pressure test lines to 3,000 psi, freeze protect OA with 75 bbls dead crude C 1.5 bpm 650 psi. 22:00 - 23:00 1.00 STWHIP P PROD1 Pump 50 bbl high vis pill with 10% EP steel Lube. Displace well to 10.1 ppg Flo-Pro mud. 300 gpm, 1,600 psi. 23:00 - 00:00 1.00 STWHIP P PROD1 Shut down pumps, clean pill pit, and trough under shakers. 5/9/2007 00:00 - 03:00 3.00 STW HIP P PROD1 Mill 7" casing window from 7,712' to 7,725'. 308 gpm, 1,775 psi. 100 rpm, 9.3k TO. PU - 145k, SO - 105k, RWT - 121 k, WOB - 5k. 03:00 - 06:00 3.00 STWHIP P PROD1 Drill new hole with window mill from 7,725' to 7,739'. Printed: 5/21/2007 9:09:37 AM ~ ~ gp Page 10 of18~ Operations Summary Report Legal Well Name: Z-102 Common Well Name: Z-102i Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date I From - To 'Hours Task Code i NPT Phase 1 ; ~ 5/9/2007 103:00 - 06:00 I 3.00 STWHIP P ~ PROD1 06:00 - 07:00 I 1.001 STWHIPI P I I PROD1 07:00 - 07:30 I 0.501 STWHIPI P I I PROD1 07:30 - 11:00 I 3.501 STWHIPI P I I PROD1 11:00 - 11:30 0.50 STWHIP P PROD1 11:30 - 12:00 0.50 STWHIP P PROD1 12:00 - 12:30 0.50 STWHIP P PROD1 12:30 - 13:00 0.50 STWHIP P PROD1 13:00 - 13:30 0.50 STWHIP P PROD1 13:30 - 15:00 1.50 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30 - 16:00 0.50 DRILL P PROD1 16:00 - 17:00 1.00 DRILL P PROD1 17:00 - 17:30 0.50 DRILL P PROD1 17:30 - 19:00 1.50 DRILL P PROD1 19:00 - 20:30 1.50 DRILL P PROD1 20:30 - 21:30 1.00 DRILL P PROD1 21:30 - 00:00 I 2.501 DRILL I P I I PROD1 5/10/2007 100:00 - 00:30 I 0.501 DRILL I P I I PROD1 00:30 - 01:30 I 1.001 DRILL I N I DFAL I PROD1 01:30 - 05:00 3.50 DRILL N DFAL PROD1 05:00 - 06:00 1.00 DRILL N DFAL PROD1 06:00 - 07:00 1.00 DRILL N DFAL PROD1 07:00 - 08:30 1.50 DRILL N DFAL PROD1 08:30 - 09:00 0.50 DRILL N DFAL PROD1 Description of Operations 306 gpm, 1,830 psi. 95 rpm, 8.3k TO. WOB - 10k. Circulate bottoms up. 306 gpm, 1,830 psi. 90 rpm, 7.7k TO. Work through window several times with and without pumps - OK. Perform FIT to 11.5 ppg EMW. MD - 7,725', TVD - 6,592'. Test pressure - 480 psi. MW - 10.1 PPg• Monitor well - OK. Pump dry job and POH from 7,725' to 365'. PU - 170k, SO - 111 k. PJSM. Laydown 4 3/4" drill collars. Laydown milling BHA assembly. All mills in gauge. Clear and clean rig floor. Service topdrive, crown and drawworks. Flush BOP stack with jetting tool. PJSM on nuclear source. Pick up and make up BHA #5: 6.125" DTX613M-B15 bit, 1.5 deg PDM AIM, bypass sub, NM STAB, MWD, ADN, tea NM Flex DC, XO, 1 jt 4" DP, JAR. Run in hole with 10 stands of drill pipe from 216' to 1,172'. Shallow hole test MWD. 272 gpm, 1,070 psi - OK. Make up agitator, shock sub, XO and run in hole to 2,155'. Test MWD and agitator. 277 gpm, 1,305 psi - OK. Continue running in hole from 2,155' to 7,600'. Cut and slip drilling line 65'. Clean out from under drawworks. MadPass log down without rotation from 7,600' to 7,702'. 274 gpm, 2,060 psi. Orient 49 deg left of highside. Shut down pump and slide through window without problem. PU - 155k, SO - 115k. Directionally drill from 7,739' to 7,771'. 275 gpm, 2,040 psi off, 2,160 psi on. PU - 155k, SO - 115k. AST - 0.71 hrs, ART - 0.00 hrs. Difficulty sliding due to aired up mud affecting pump pressure. Directionally drill from 7,771' to 7,804'. AIM failure. 275 gpm, 2,070 psi off, 2,150 psi on. PU - 155k, SO - 115k. AST - .8 hrs Pull up above window and circulate bottoms up. 280 gpm, 2,160 psi. No rotation. 10.05 ppg MW Observe well - OK. Pump dry job and POH from 7,710' to 216' PJSM. Stand back JAR stand. Pull nuclear source. Laydown MWD and AIM PDM. Clear rig floor. Pick up fresh AIM PDM and MWD. Load source and complete make up of BHA #6. Run in hole with BHA #6 from 217' to 2,149'. Shallow hole test MWD - OK. Printed: 5/21/2007 9:09:37 AM • 1 gp Page 11 of 18 Operations Summary Report Legal Well Name: Z-102 Common Well Name: Z-102i Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES I i Date ;From - To Hours Task Code NPT Phase I Description of Operations 5/10/2007 08:30 - 09:00 0.50 DRILL N DFAL PROD1 09:00 - 11:00 2.00 DRILL N DFAL PROD1 11:00 - 12:00 1.00 DRILL N DFAL PROD1 12:00 - 14:00 2.00 DRILL N SFAL PROD1 14:00 - 00:00 10.00 DRILL P PROD1 5/11/2007 00:00 - 07:00 7.00 DRILL P PROD1 07:00 - 08:00 1.00 DRILL P PROD1 08:00 - 10:00 2.00 DRILL P PROD1 10:00 - 10:30 0.50 DRILL P PROD1 10:30 - 12:00 1.50 DRILL P PROD1 12:00 - 00:00 12.00 DRILL P PROD1 5/12/2007 00:00 - 12:00 12.00 DRILL P PROD1 12:00 - 15:30 3.50 DRILL P PROD1 15:30 - 16:00 0.50 DRILL P PROD1 16:00 - 20:00 4.00 DRILL P PROD1 282 gpm, 1,750 psi. PU - 62k, SO - 59k. Continue running in hole from 2,149' to 7,676'. Fill pipe every 2,500'. Orient 40 deg left and work through window without pumping. PU - 155k, SO - 110k. 16" air boot seal on drilling nipple failed due to metal shavings. 10 gallons leaked into cellar. Change out air boot. Directionally drill from 7,804' to 8,154'. 279 gpm, 2,070 psi off, 2,150 psi on. PU - 155k, SO - 115k. AST - 5.40 hrs 'Initially experienced trouble with aired up mud. Slight trouble with differential pressure on bit. Taking 6 to 8 tries to pump up a survey. Started mixing in a .25% concentration of Screen Clean and limiting mud mixing to pill pit. Started improving pump pressure stability and pumping up surveys. Directionally drill from 8,154' to 8,250'. 255 gpm, 2,360 psi off, 2,420 psi on. PU - 155k, SO - 115k, RWT - 130k, WOB 10-25k. 60 rpm, 5k TO off, 6.8k TO on. Perform roll test. Had MWD signal interference difficulty. Directionally drill from 8,250' to 8,260'. (Balled bit) 296 gpm, 2,940 psi off, 3,000 psi on. PU - 155k, SO - 115k, RWT - 130k, WOB 20k. 60 rpm, 5.8k TO off, 7.1 k TO on. Pump 30 bbl, 10 ppb NutPlug Fine plus 3.5% vol Screenkleen sweep to clean bit. Bit cleaned up as sweep turned the corner. Directionally drill from 8,260' to 8,312'. 255 gpm, 2,360 psi off, 2,420 psi on. PU - 155k, SO - 115k, RWT - 130k, WOB 10-20k. 60 rpm, 5k TO off, 6.8k TO on. AST - 5.73 hrs, ART - 1.95 hrs. Directionally drill from 8,312' to 8,888' 300 gpm, 3,065 psi off, 3,145 psi on. PU - 145k, SO - 103k, RWT - 124k, WOB 5-15k. 60 rpm, 4.1 k TO off, 5.2k TO on. AST - 2.58 hrs, ART - 2.23 hrs. Directionally drill from 8,888' to 9,333'. •" 320 gpm, 3,400 psi off, 3,800 psi on. PU - 145k, SO - 105k, RWT - 125k, WOB 5-10k. 50 rpm, 4.5k TO off, 6k TO on. AST - 2.43 hrs, ART - 3.53 hrs. Directionally drill from 9,333' to TD C~2 9,507' MD, 6,569' TVD. ,- 320 gpm, 3,520 psi off, 3,790 psi on. PU - 145k, SO - 100k, RWT - 121 k, WOB 5-10k. 50 rpm, 4.3k TO off, 6.1 k TO on. AST - 0.81 hrs, ART - 2.58 hrs. Circulate open hole volume. 320 gpm, 3,500 psi. 50 rpm, 4.3k TO. Backream and Mad Pass log from 9,507' to 8,339'. Printed: 5/21/2007 9:09:37 AM gp Page 12 of 18 Operations Summary Report Legal Well Name: Z-102 Common Well Name: Z-1021 Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date 5/12/2007 From - To I Hours I Task I Code ! NPT i Phase 16:00 - 20:00 4.001 DRILL I P PROD1 20:00 - 00:00 5/13/2007 00:00 - 00:30 0.50 DRILL P 00:30 - 02:00 1.50 DRILL P 02:00 - 02:30 0.50 DRILL P 02:30 - 03:30 1.00 DRILL P 03:30 - 09:00 09:00 - 10:00 4.001 DRILL I P 5.501 DRILL I P 1.00 l DRILL I P PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 10:00 - 14:30 4.50 DRILL P PRODi 14:30 - 15:30 1.00 DRILL P PROD1 15:30 - 16:00 0.50 DRILL P PROD1 16:00 - 17:00 1.00 CASE P RUNPRD 17:00 - 19:30 2.50 CASE P RUNPRD Description of Operations 255 gpm, 2,345 psi. 60 rpm, 5k - 7.5k TO. Started having pack-off problems starting ~? 8,339'. Continued packing off intermitently to 8,191' then unable to go past 8,191'. Able to pull up without pumping. Worked stand a few times without problem, then attempted to MadPass again without success. Backream and Mad Pass log from 8,339' to 8,109'. 255 gpm, 2,345 psi. 60 rpm, 5k - 7.5k TO. Started having pack-off problems starting @ 8,339'. Continued packing off intermitently to 8,191' then unable to go past 8,191'. Able to pull up without pumping. Worked stand a few times without problem, then attempted to MadPass again without success. 'Lost total of 140 bbls of mud from 20:00 hr. No static losses. Hole would only lose mud while packing-off. POH from 8,191' to 7,676' without problem. Circulate 3 times bottoms up. 293 gpm, 2,610 psi. 70 rpm, 4.2k TO. No increase in cuttings. Minor mud losses. Orient 40 deg left and run in hole from 7,676' to 8,441' (1 stand below from first indication of packing off.) Backream and MadPass log from 8,441' to 8,250' without problem. 260 gpm, 2,245 psi. 60 rpm, 4.2k TO. PU - 165k, SO - 120k, RWT - 125k. Started packing off C~3 8,250'. Continue backreaming and MadPass log from 8,250' to 7,867' 260 gpm, 2,350 psi. 60 rpm, 4k - 7k TO. Had packoff problems throughout this interval. Change up pumping, rpm parameters to attempt to improve packoff conditions without success. Reamed and Madpassed down when necessary Did not have any tight hole problems. Able to work pipe without drag when pumps were shut down. Pumped a high vis sweep ~ 8,036'. No increase in cuttings. Pull up hole 2 stands without pumping to 7,676'. Circulate bottoms up. 260 gpm, 2,200 psi 60 rpm, 2,200 psi. PU - 120k, SO - 115k. MW - 10.1 ppg. Monitor well - 6 bpm Static loss rate. POH from 7,676' to 216'. Laydown BHA #6. Bit grade: 0-0-WT-A-X-I-NO-DMF Clean and clear rig floor. Rig up to run 4.5" production finer. PJSM. Pick up and Baker Lok 40' shoe track. Check floats - OK Continue running in hole with 4.5" 12.6# L-80 IBT-M liner to Printed: 5/21/2007 9:09:37 AM • ~ gp Page 13 of 18 Operations Summary Report Legal Well Name: Z-102 Common Well Name: Z-1021 Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To I Hours - ~ j i Task ~ Code; NPT Phase Description of Operations 5/13/2007 17:00 - 19:30 2.50 CASE P RUNPRD 1,818'. Ran total of 42 joints. Make up TO - 2,350 fUlbs. Used BOL 2,00 NM. 19:30 - 20:00 0.50 CASE P RUNPRD Rig up to run 2 7/8" FOX inner string. 20:00 - 21:00 1.00 CASE P RUNPRD Pick up and run 10 jts of FOX tubing inside of 4.5" liner. Make up 5" x 7" Baker Flex Lok liner hanger. Make up 5" x 7" Baker ZXP liner top packer. 21:00 - 21:30 0.50 CASE P RUNPRD Circulate liner volume. 3 bpm, 190 psi. PU - 55k, SO - 53k. (with 33k blocks) Rig down liner and tubing equipment. 21:30 - 00:00 2.50 CASE P RUNPRD Run in hole with 4.5" liner on drill pipe from 1,861' to 4,713'. Fill pipe every 10 stands. Record PU & SO weights every 10 stands. *Lost 328 bbls from midnight to noon. *Lost 52 bbls from noon to midnight. *520 bbls total lost to well. 5/14/2007 00:00 - 02:00 2.00 CASE P RUNPRD Continue running in hole with 4.5" liner on drill pipe from 4,713' to 7,670'. 1 min per stand. Fill pipe every 10 stands. 6 bph loss rate. 02:00 - 02:30 0.50 CASE P RUNPRD Circulate bottoms up. 2 bpm - 330 psi. 3 bpm - 450 psi 5 bpm - 630 psi. PU - 140k, SO - 115k. 02:30 - 04:00 1.50 CASE P RUNPRD Run in hole through window ok. Continue running in open hole to planned liner depth @ 9,450'. 1.5 min per stand. Fill pipe every 10 stands. No excess drag. 4.5" Howco Float Shoe CuJ 9450 Tops: 1 Jt 4.5" 12.6# L-80 IBT-M Liner (#1) ~ 9407 4.5" Howco Float Collar ~ 9405 4.5" Baker Landing Collar(~3 9404 (PBTD) 3 Jts 4.5" 12.6# L-80 IBT-M Liner (#3 - #5) ~ 9280 4.5" 12.6# L-80 IBT-M Pup Jt, w/RA Tag in collar ~ 9260 32 Jts 4.5" 12.6# L-80 IBT-M Liner (#6 - #37) C~3 7930 4.5" x 3 5/8" Baker SBE w/ 3.625" ID Throat @ 7887 6 Jts 4.5" 12.6# L-80 IBT-M Liner (#38 - #43) @ 7631 5" BTC x 4.5" BTC box x IBT pin XO bushing ~ 7626 Baker 5" x 7" Flex-Lok Liner Hanger C~ 7616 "RS" Packoff Seal Nipple ~ 7614 Baker 5" x 7" ZXP liner top packer w/ 11.77' x 5.25" ID Ext @ 7594 (TOL) CENTRALIZER PLACEMENT No cent. on joint #1 2 ea. on joint #3-43 floating with stop in middle of jt. No centralizer on joint #41 Printed: 5/21/2007 9:09:37 AM ! ~- BP Operations Summary Report Legal Well Name: Z-102 Common Well Name: Z-102i Event Name: DRILL+COMPLETE Start: 4/28/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date I From - To I Hours I Task I Code 5/14/2007 02:30 - 04:00 1.50 CASE P 04:00 - 04:30 0.50 CEMT P 04:30 - 07:00 2.50 CEMT P Page 14 of 18 Spud Date: 4/29/2007 End: 5/19/2007 NPT ~ Phase Description of Operations RUNPRD RUNPRD RUNPRD 07:00 - 08:30 1.50 CEMT P RUNPRD 08:30 - 10:00 1.50 CEMT P RUNPRD 10:00 - 11:00 1.00 CEMT P RUNPRD 11:00 - 11:30 0.50 CEMT P RUNPRD 11:30 - 14:30 3.00 CEMT P RUNPRD 14:30 - 15:00 0.50 CEMT P RUNPRD 15:00 - 15:30 0.50 CEMT P RUNPRD 15:30 - 16:30 1.00 BOPSU P RUNPRD 16:30 - 20:30 4.00 BOPSU P RUNPRD 80 total centralizers. 40 total stop rings. Rig up Baker rotating plug head and cement lines. Break circulation and stage pump up to 5 bpm. 3 bpm - 600 psi. 4 bpm - 850 psi. 5 bpm - 1,170 psi. PU - 155k, SO - 115k. Reciprocate liner 15' strokes. Held cementing PJSM while circulating. Loss rate - 14 BPH Cement 4.5" liner. Pump 5 bbls water. Shut down. Pressure test lines to 4,500 psi - OK. Pump 30 bbls of 12.5 ppg MudPush II spacer @ 5 bpm, ICP - 1,085 psi, FCP - 855 psi. Pump Batched mixed Class "G" tail cement C~ 4 bpm, ICP - 760 psi, FCP - 150 psi. Clean up lines with water to Tee. Release DP dart. Displace with rig pumps, reciprocating liner 15' strokes. PU - 145k, SO - 115k. Pump 35 bbls 10.0 ppg Perf Pill @ 5 bpm, ICP - 110 psi, FCP - 110 psi. Pressured up to 450 psi. Stop reciprocating, set liner on depth. Cement around shoe. Pump 12 bbls 10.0 ppg Perf Pill ~ 4 bpm, ICP - 450 psi, FCP - 790 psi. Pump 12 bbls 10.1 ppg mud C~ 4 bpm, ICP - 790 psi, FCP - 1,005 psi. Pump 40 bbls 10.1 ppg mud @ 3 bpm, ICP - 795 psi, FCP - 1,085 psi. 98 bbls total displacement. 2 pressure anomalies while displacing cement: 1st when dart hit top of liner - 2,420 psi. 2nd when dart latched up to wiper plug - 2,985 psi. Bump plug with 3,500 psi. CIP ~ 08:15 hr. *Lost 52 bbls from midnight to 08:15 hr. (572 bbls total to well} Hold 3,500 psi to set liner hanger. Set down 50k to confirm hanger set - OK. Pressure up to 4,000 psi to release setting tool. Pick up to 150k. Rotate to set packer. Set down 75k to confirm set - OK. Pick up 28' and circulate out cement. Returned 17 bbls of "sidewalk" cement to surface. Displace well from 10.1 ppg FloPro to 10.0 ppg brine. 318 gpm, 1,900 psi. Rig down plug head and cementing lines. POH from 7,923' to 357' Rig up to laydown 2 7/8" inner string. Laydown running tool and inner string. (Dogs out) Pull wear bushing, flush BOP stack and rig up to test BOPE. Test BOPE to 250 psi low, 4,000 psi high. Annular test to 250 psi low, 3,500 psi high. Test Accumulator. Test witnessed by AOGCC rep John Crisp, WSL's B. Buzby, R. Printed: 5/21/2007 9:09:37 AM y gp Page 15 of 18 Operations Summary Report Legal Well Name: Z-102 Common W ell Name: Z -1021 Spud Date: 4/29/2007 Event Nam e: DRILL+C OMPLE TE Start : 4/28/2007 End: 5/19/2007 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 5/19/2007 Rig Name: NABOB S 9ES Rig Number: 9ES Date From - To ~ Hours Task Code NPT Phase Description of Operations 5/14/2007 16:30 - 20:30 4.00 BOPSU P _ _-- -._- RUNPRD French, NAD TP's K. Cozby, R. Hunt. *Air actuated IBOP valve on topdrive failed. Changed out valve and retest - OK. 20:30 - 21:00 0.50 BOPSU P RUNPRD Rig down, blow down BOPE test equipment. Install wear bushing. 21:00 - 22:30 1.50 BOPSU N RREP RUNPRD Changed out air actuated IBOP valve and retest - OK. 22:30 - 23:30 1.00 CASE P RUNPRD Pressure test casing to 4,000 psi, 30 min - OK. *UCA test - 1,000 psi @ 14:27 hr. 23:30 - 00:00 0.50 PERFO P OTHCMP Pick up pert tools to rig floor 5/15/2007 00:00 - 01:00 1.00 PERFO P OTHCMP PJSM. Rig up to run DPC pert assembly. 01:00 - 05:00 4.00 PERFO P OTHCMP Pick up 2.5" Power Jet Omega 2506, 6 SPF pert guns. 20T -Loaded guns. 89' -Blanks 49 - jts 2 7/8" PAC DP for pert space out. 05:00 - 09:00 4.00 PERFO P OTHCMP Run in hole with pert assembly on drill pipe from 1,844' to tag-up on PBTD @ 9,404'. 09:00 - 09:30 0.50 PERFO P OTHCMP Set guns in place @ 9,402' PJSM. Circulate air out of system. Close annular. Pressure up drill pipe and annulus to 2,500 psi. Hold pressurefor2minutes. Bleed off pressure. Wait for guns to fire. Good fire indication. 1 bbl initial loss then static. *Perf intervals: Toe: 9,402' - 9,365', 37 ft - 222 shots 9,350' - 9,270', 80 ft - 480 shots 9,260' - 9,230', 30 ft - 180 shots Heal: 7,786' - 7,766', 20 ft - 120 shots 7,756' - 7,716', 40 ft - 240 shots 09:30 - 10:00 0.50 PERFO P OTHCMP POH from 9,402' to 9,148'. Drill pipe flowing while pulling. PU - 155k, SO - 115k. 10:00 - 11:30 1.50 PERFO P OTHCMP Circulate bottoms up 3 times. 5 bpm, 600 psi. MW - 10.0 ppg brine 11:30 - 12:30 1.00 PERFO P OTHCMP Monitor well for 10 minutes -static. POH from 9,148' to 7,556' *Lost 7 bbls from guns fired to noon. 12:30 - 13:30 1.00 PERFO P OTHCMP Cut and slip drilling line 80 ft. Service topdrive and crown. 13:30 - 17:30 4.00 PERFO P OTHCMP POH laying down drill pipe from 7,555' to 1,844'. 17:30 - 18:30 1.00 PERFO P OTHCMP Run in hole with remaining drill pipe out of derrick from 1,844' to 5,766'. 18:30 - 21:30 3.00 PERFO P OTHCMP POH laying down drill pipe from 5,766' to 1,844'. 21:30 - 00:00 2.50 PERFO P OTHCMP Rig up 2 7/8" equipment. Laydown 2 7/8" PAC DP and pert guns from 1,844' to 1,040'. *Lost 20 bbls from noon to midnight. *27 bbls total to pens. 5/16/2007 00:00 - 01:30 1.50 PERFO P OTHCMP Continue laying down 2 7/8" PAC DP and 2.5" pert guns. All guns fired. 01:30 - 02:00 0.50 PERFO P OTHCMP Clear and clean rig floor. 02:00 - 03:30 1.50 EVAL P OTHCMP PJSM. Rig up SLB E-line and tools. 03:30 - 06:00 2.50 EVAL P OTHCMP W L run #1: 6.14" gauge ring and junk basket to top of liner, Printed: 5/21/2007 9:09:37 AM gp Page 16 of18~ Operations Summary Report Legal Well Name: Z-102 Common Well Name: Z-102i Event Name: DRILL+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 9ES Date From - To i Hours Task Code NPT ~ - _ _- 5/16/200703:30 - 06:00 ~ 2.50 EVAL ~ P 06:00 - 08:30 I 2.50 I EVAL I P 08:30 - 11:30 I 3.00 I EVAL I P 11:30 - 14:30 I 3.001 EVAL I P 14:30 - 17:30 I 3.001 EVAL I P 17:30 - 20:00 2.50 EVAL P 20:00 - 23:00 3.00 EVAL P 23:00 - 00:00 1.00 EVAL P 5/17/2007 100:00 - 01:30 1.50 EVAL P 01:30 - 04:00 I 2.50 I EVAL I P 04:00 - 06:00 I 2.00 I EVAL I P 06:00 - 09:00 3.00 EVAL P 09:00 - 10:00 1.00 EVAL P 10:00 - 16:00 6.00 EVAL P 16:00 - 17:00 1.00 EVAL ~ P 17:00 - 18:30 1.50 BUNCO 18:30 - 00:00 I 5.50 Spud Date: 4/29/2007 Start: 4/28/2007 End: 5/19/2007 I Rig Release: 5/19/2007 Rig Number: 9ES Phase ~ Description of Operations OTHCMP 7,594', and back to surface. Recovered 1/2 gal of debris. OTHCMP WL run #2: 6.14" gauge ring and junk basket to top of liner, 7,594', and back to surface. Recovered 1 qt. of debris. OTHCMP WL run #3: 6.14" gauge ring and junk basket to top of liner, 7,594', and back to surface. Recovered 1 pt of debris. OTHCMP W L run #4: 3.5" gauge ring and junk basket to 7,950', 43' below SBE, and back to surface. Recovered 1 cup of debris. Rubber, metal, gun debris. OTHCMP W L run #5: 3.5" gauge ring and junk basket to 7,880', 7' above SBE. Pulled tight and came free when pulling off of obstruction. POH and pick up W L jars. Recovered 1/2 cup of debris. Rubber, metal, gun debris. OTHCMP W L run #6: 3.5" gauge ring, junk basket and jars to 7,950', 43' below SBE, and back to surface. Recovered 1/4 cup of debris. Metal shavings OTHCMP W L run #7: 3.5" gauge ring, junk basket and jars to 7,950', 43' below SBE, and back to surface. Recovered 1/4 cup of debris. Metal chunks and shavings OTHCMP WL run #8: 3.5" gauge ring, junk basket and jars to 7,950', 43' below SBE. No losses for the day. '27 total bbls of 10.0 ppg brine lost to perfs. OTHCMP Continue WL run #8: 3.5" gauge ring, junk basket and jars to 7,950', 43' below SBE. Recovered 1 pt of debris. Metal chunks and shavings. OTHCMP WL run #9: 3.5" gauge ring, junk basket and jars to 7,950', 43' below SBE. Recovered 1/2 pt of debris. Larger metal chunks and shavings. OTHCMP WL run #10: 3.5" gauge ring, junk basket and jars to 7,950', 43' below SBE. Recovered 1/2 pt of debris. Dime size pert debris. OTHCMP WL run #11: 3.5" gauge ring, junk basket and jars to 7,930', 23' below SBE. Recovered 1/2 pt of debris. Dime size and smaller pert debris. OTHCMP Rig up USIT logging tools and surface test same. OTHCMP WL run #12: Run in hole to top of liner C~ 7,594'. USIT log from 7,594' to surface in "Primary Depth Control". OTHCMP Rig down SLB E-line tools and equipment. RUNCMP Rig up to run completion. Make dummy run with hanger and landing joint. RUNCMP Run in hole with completion assembly to 2,877'. 2.875" Mule shoe joint (800 ft/Ibs MU TO with JetLube Sealguard) Bullet Seal assembly w/ 3.76" guide sub 9 jts, 2.875" 6.4# L-80 Hydril 511 tubing 2 ea 2.875" 6.4# L-80 Hydril 511 space out pups XO w/ 5.5" No Go (2,300 fUlbs MU TO with JetLube Sealguard) 3.5" X Nipple Printed: 5/21/2007 9:09:37 AM ~.. • BP Page 17 at 18 Operations Summary Report Legal Well Name: Z-102 Common Well Name: Z-102i Spud Date: 4/29/2007 Event Name: DRILL+COMPLETE Start: 4/28/2007 End: 5/19/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 5/19/2007 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To ~ Hours Task Code NPT Phase j Description of Operations 5/17/2007 18:30 - 00:00 5.50 BUNCO RUNCMP 1 jt, 3.5" 9.2# L-80 TCII tubing Sliding sleeve 1 jt, 3.5" 9.2# L-80 TCII tubing 3.5" MMG-W GLM dummy 1 jt, 3.5" 9.2# L-80 TCII tubing 3.5" MMG-W GLM dummy XO (3,850 fUlbs MU TO with JetLube Sealguard) 4.5" X Nipple w/ RHC Plug 4.5" x 7" Baker Premier Production Packer 4.5" X Nipple 16 jts, 4.5" 12.6# L-80 TCII tubing 4.5" KBG-2 GLM w/ DCK-2 Shear valve, SBEK-2C Top latch 39 jts (55 total) 4.5" 12.6# L-80 TCII tubing at midnight. 5/18/2007 00:00 - 07:30 7.50 BUNCO RUNCMP Continue running in hole with completion assembly from 2,877' to 7,865'. 29 jts, 4.5" 12.6# L-80 TCII tubing 4.5" KBG-2 GLM w/ DCK-2, SBK-2C Top latch 38 jts, 4.5" 12.6# L-80 TCII tubing 4.5" X Nipple 57 jts, 4.5" 12.6# L-80 TCII tubing 07:30 - 09:00 1.50 BUNCO RUNCMP Rig up to circulate. Circulate 2 joints down from 7,865' @ 127 gpm, 270 psi. Note good indication of seal going in SBE with an increase of app. 200 PSI. Bleed pressure and fully insert into SBE with both sets of seal.( No indication of seal drag going into SBE with either set) Tag up on top of SBE with Fluffed, "NO GO" just above seals. Apply 2K down and confirm depths from initial pressure increase to no go point. Laydown 1 joint and space out completion with 3 space out pups and place them just below last joint of tubing (180 total jts of 4.5") Pick up and make up hanger and landing joint. 09:00 - 10:00 1.00 BUNCO RUNCMP Spot corrosion inhibitor from below GLM # 3 to W LEG. Reverse circulate 25 bbls of inhibited 10.0 ppg brine. Follow with 125 bbls of clean 10.0 ppg brine 127 gpm, 340 psi. 10:00 - 10:30 0.50 BUNCO RUNCMP Land tubing and RILDS. 10:30 - 11:00 0.50 BUNCO RUNCMP Rig down circulating equipment. Drop 1 7/8" roller type rod and ball. Laydown landing joint. 11:00 - 14:30 3.50 BUNCO RUNCMP Allow rod and ball to fall to seat on RHC plug ~ 7362. Pressure up on tubing to 4200 to set packer and test tubing. Bleed tubing pressure to 2200 and pressure up annulus to 4,000. (Chart tubing and packer tests for 30 minutes) Bleed annulus to zero, then tubing. Apply 2400 to annulus and observe DCK shear in GLM #3. Pump both ways to confirm a good shear. Install BPV and test to 1,000 from below. 14:30 - 16:00 1.50 BOPSU P WHDTRE PJSM. Nipple down Stack 16:00 - 17:00 1.00 WHSUR P WHDTRE Nipple up adapter flange and test same to 5,000 psi - 30 min - OK. 17:00 - 19:00 2.00 WHSUR P WHDTRE Nipple up double master valve and test same to 5,000 psi - 15 min - OK. 19:00 - 20:00 1.00 WHSUR P WHDTRE Rig up DSM lubricator and pull 2-way check valve. Printed: 5/21/2007 9:09:37 AM w • gp Page 18 of 18 Operations Summary Report Legal Well Name: Z-102 Common W ell Name: Z-102i Spud Date: 4/29/2007 Event Nam e: DRILL+C OMPLE TE Start : 4/28/2007 End: 5/19/2007 Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 5/19/2007 Rig Name: NABOB S 9ES Rig Number: 9ES Date From - To I i Hours Task Code NPT Phase Description of Operations 5/18/2007 20:00 - 22:30 2.50 WHSUR P WHDTRE Freeze protect well to TVD of 3,500'. Reverse circulate 55 bbls of 10.0 ppg inhibited brine # 3 bpm, 1,100 psi. Test LRHOS lines to 3,500 psi. Reverse 133 bbls of 90 deg heated diesel C~ 2 bpm, ICP - 550 psi, FCP - 1,600 psi. 22:30 - 00:00 1.50 WHSUR P WHDTRE Allow diesel to U-tube back to tubing. SI P's: Tubing - 0 psi. IA - 0 psi. OA - 120 psi. 5/19/2007 00:00 - 01:00 1.00 W HSUR P WHDTRE Rig down LRHOS. Set BPV with T-bar. Pressure test from below to 1,000 psi. 01:00 - 02:00 1.00 WHSUR P WHDTRE Remove working valves from tubing spool. Install VR plugs in IA. 02:00 - 03:00 1.00 WHSUR P WHDTRE Complete fluids removal from mud pits. Clean cellar box. `Rig released from operations on Z-102i @ 03:00 hr, 5/19/2007 for move to W-213i. Printed: 5/21/2007 9:09:37 AM .gyp '-~ ` c u b Z-102 Survey Report r . ~ Report Date: 13-May-07 Survey /DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 190.000° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure /Slot: Z-PAD / Z-102 TVD Reference Datum: Rotary Table Well: Z-102 TVD Reference Elevation: 81.30 ft relative to MSL Borehole: Z-102 Sea Bed /Ground Level Elevation: 52.80 ft relative to MSL UWIIAPI#: 500292335300 Magnetic Declination: 23.701 ° Survey Name /Date: Z-102 /May 13, 2007 Total Field Strength: 57637.824 nT Tort /AHD / DDI / ERD ratio: 280.954° / 5236.48 ft / 6.321 / 0.784 Magnetic Dip: 80.884° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: May 10, 2007 Location LatlLong: N 70.29841096, W 149.19719391 Magnetic Declination Model: BGGM 2006 Location Grid NIE Y/X: N 5959359.680 ftUS, E 599130.960 ftUS North Reference: True North Grid Convergence Angle: +0.75581642° Total Corr Mag North -> True North: +23.701 ° Grid Scale Factor: 0.99991116 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 de ft ft ft ft ft ft ft de 100 it ftUS ftUS Hit u.UU U.uU U.uu -t51. 3U U. UU v.w u.vv u.uv v.vv u.vv u.vu aaoaaoa.oa oya i av.ao rv iv.c~aw i uyo vv i 4a. i ai i yaa i GYD CT DMS 100.00 0.06 101.31 18. 70 100. 00 0.00 0.05 0.05 -0.01 0.05 0.06 5959359.67 599131.01 N 70.29841093 W 149.19719349 200.00 0.21 107.58 118. 70 200. 00 0.03 0.29 0.29 -0.08 0.28 0.15 5959359.61 599131.24 N 70.29841075 W 149.19719166 300.00 0.37 92.17 218. 70 300. 00 0.01 0.79 0.79 -0.14 0.77 0.18 5959359.55 599131.74 N 70.29841057 W 149.19718763 400.00 2.19 337.78 318. 68 399. 98 -1.65 2.68 1.66 1.61 0.37 2.37 5959361.30 599131.31 N 70.29841537 W 149.19719087 500.00 2.98 337.25 418. 57 499. 87 -5.46 7.19 5.94 5.78 -1.35 0.79 5959365.44 599129.53 N 70.29842675 W 149.19720486 602.00 3.28 338.91 520. 42 601. 72 -10.19 12.76 11.47 10.95 -3.43 0.31 5959370.58 599127.39 N 70.29844087 W 149.19722167 702.00 8.38 338.40 619. 87 701. 17 -18.85 22.92 21.61 20.40 -7.14 5.10 5959379.98 599123.55 N 70.29846669 W 149.19725174 802.00 11.51 342.91 718. 36 799. 66 -33.94 40.18 38.87 36.71 -12.76 3.22 5959396.22 599117.72 N 70.29851126 W 149.19729722 902.00 14.02 342.53 815. 88 897. 18 -53.57 62.27 60.95 57.81 -19.33 2.51 5959417.22 599110.87 N 70.29856889 W 149.19735041 Last Gyro 1002.00 17.02 332.37 912. 24 993. 54 -75.92 88.96 87.55 82.34 -29.76 4.04 5959441.61 599100.12 N 70.29863590 W 149.1974 MWD+IFR+MS 1040.70 18.41 326.32 949. 11 1030. 41 -84.83 100.73 99.12 92.44 -35.77 5.96 5959451.63 599093.97 N 70.29866351 W 149.1974 1136.74 19.94 321.52 1039. 82 1121. 12 -106.65 132.25 129.82 117.89 -54.37 2.29 5959476.83 599075.04 N 70.29873302 W 149.19763 1233.39 21.97 322.06 1130. 07 1211. 37 -129.69 166.82 163.64 145.05 -75.75 2.11 5959503.70 599053.31 N 70.29880722 W 149.19780728 1328.38 24.75 322.40 1217. 27 1298. 57 -155.01 204.48 200.81 174.82 -98.81 2.93 5959533.17 599029.86 N 70.29888856 W 149.19799403 1424.76 27.16 322.05 1303. 92 1385. 22 -183.35 246.66 242.63 208.16 -124.65 2.51 5959566.16 599003.59 N 70.29897963 W 149.19820329 1520.46 29.08 323.82 1388. 32 1469. 62 -214.09 291.76 287.51 244.16 -151.82 2.19 5959601.79 598975.95 N 70.29907798 W 149.19842326 1615.99 31.48 323.99 1470. 81 1552. 11 -247.49 339.92 335.56 283.08 -180.19 2.51 5959640.33 598947.07 N 70.29918430 W 149.19865302 1709.15 31.36 325.05 1550. 31 1631. 61 -281.54 388.49 384.07 322.62 -208.38 0.61 5959679.50 598918.37 N 70.29929234 W 149.19888129 1804.83 33.10 323.77 1631. 25 1712. 55 -317.23 439.51 435.04 364.11 -238.08 1.95 5959720.58 598888.12 N 70.29940567 W 149.19912185 1900.49 32.46 323.38 1711. 67 1792. 97 -352.93 491.30 486.76 405.78 -268.83 0.70 5959761.84 598856.82 N 70.29951951 W 149.19937088 1996.11 31.98 323.23 1792. 57 1873. 87 -387.90 542.28 537.67 446.66 -299.30 0.51 5959802.31 598825.82 N 70.29963119 W 149.19961758 2090.99 31.89 324.21 1873. 09 1954. 39 -422.59 592.47 587.81 487.12 -328.99 0.55 5959842.37 598795.60 N 70.29974171 W 149.19985808 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-102~Z-102~Z-102~Z-102 Generated 6/13/2007 3:08 PM Page 1 of 4 2186.86 31.61 323.96 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5960606.90 4230.06 18.13 315.41 3750.25 3831.55 -1097.74 1596.71 1589.79 1280.75 -941.86 0.12 5960627.78 4325.62 16.55 318.23 3841.47 3922.77 -1114.78 1625.19 1618.05 1301.49 -961.37 1.87 5960648.26 4422.01 15.72 317.82 3934.06 4015.36 -1131.28 1651.97 1644.72 1321.40 -979.28 0.87 5960667.93 4517.72 16.03 322.34 4026.12 4107.42 -1148.13 1678. t 4 1670.84 1341.47 -996.06 1.33 5960687.78 4613.66 16.63 323.90 4118.19 4199.49 -1166.57 1705.11 1697.81 1363.05 -1012.24 0.77 5960709.14 4709.65 16.76 324.21 4210.14 4291.44 -1185.75 1732.69 1725.38 1385.38 -1028.43 0.16 5960731.25 4805.56 16.83 322.97 4301.96 4383.26 -1204.85 1760.40 1753.09 1407.68 -1044.88 0.38 5960753.33 4901.94 16.67 323.09 4394.25 4475.55 -1223.81 1788.18 1780.87 1429.87 -1061.58 0.17 5960775.30 4997.10 16.89 317.00 4485.36 4566.66 -1241.45 1815.63 1808.26 1450.90 -1079.21 1.86 5960796.08 5092.78 18.79 302.53 4576.48 4657.78 -1255.73 1844.80 1836.50 1469.36 -1101.69 5.02 5960814.25 5188.53 18.86 289.28 4667.15 4748.45 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8360.99 99.03 165.61 6555.93 6637.23 631.75 4093.75 2078.53 -278.29 -2059.82 2.51 5959054.27 597075.18 N 70.29764991 W 149.21387249 8392.54 98.85 166.74 6551.03 6632.33 660.26 4124.92 2075.44 -308.56 -2052.37 3.58 5959024.11 597083.02 N 70.29756724 W 149.21381212 8425.24 98.96 165.29 6545.96 6627.26 689.78 4157.23 2072.63 -339.90 -2044.57 4.39 5958992.87 597091.24 N 70.29748161 W 149.21374884 8456.43 97.64 167.45 6541.46 6622.76 718.05 4188.09 2070.60 -369.90 -2037.29 8.05 5958962.98 597098.91 N 70.29739968 W 149.21368990 8488.66 95.16 162.09 6537.87 6619.17 747.01 4220.12 2068.09 -400.79 -2028.88 18.23 5958932.20 597107.73 N 70.29731530 W 149.21362171 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-102~Z-102~Z-102~Z-102 Generated 6/13/2007 3:08 PM Page 3 of 4 1 8520.41 92.39 158.96 6535.78 6617.08 774.58 4251.79 2063.75 -430.65 -2018.32 13.15 5958902.49 597118.68 N 70.29723372 W 149.21353613 8552.50 90.90 156.54 6534.85 6616.15 801.71 4283.87 2058.31 -460.33 -2006.17 8.85 5958872.97 597131.21 N 70.29715264 W 149.21343773 8584.91 91.41 156.53 6534.20 6615.50 828.74 4316.27 2052.63 -490.06 -1993.27 1.57 5958843.42 597144.51 N 70.29707144 W 149.21333319 8615.75 91.28 158.88 6533.48 6614.78 854.80 4347.10 2048.31 -518.58 -1981.58 7.63 5958815.05 597156.58 N 70.29699352 W 149.21323843 8648.31 91.38 157.85 6532.72 6614.02 882.51 4379.65 2044.61 -548.84 -1969.57 3.18 5958784.96 597168.97 N 70.29691087 W 149.21314120 8680.22 91.24 158.43 6531.99 6613.29 909.61 4411.56 2041.37 -578.45 -1957.70 1.87 5958755.52 597181.24 N 70.29682999 W 149.21304496 8711.49 89.67 157.00 6531.74 6613.04 936.04 4442.82 2038.43 -607.38 -1945.84 6.79 5958726.74 597193.48 N 70.29675096 W 149.21294889 8744.06 89.52 156.57 6531.97 6613.27 963.29 4475.39 2035.35 -637.31 -1933.00 1.40 5958696.99 597206.71 N 70.29666920 W 149.21284488 8776.03 90.15 156.36 6532.07 6613.37 989.94 4507.36 2032.65 -666.62 -1920.24 2.08 5958667.85 597219.86 N 70.29658913 W 149.21274146 8807.36 90.67 157.12 6531.84 6613.14 1016.14 4538.69 2030.65 -695.40 -1907.86 2.94 5958639.24 597232.61 N 70.29651051 W 149.21264123 8839.28 92.75 157.62 6530.89 6612.19 1043.00 4570.60 2029.45 -724.85 -1895.59 6.70 5958609.96 597245.27 N 70.29643007 W 149.21254177 8871.50 93.47 156.90 6529.14 6610.44 1070.06 4602.77 2028.68 -754.52 -1883.15 3.16 5958580.45 597258.10 N 70.29634902 W 149.21244102 8903.15 93.06 158.86 6527.34 6608.64 1096.83 4634.37 2028.77 -783.79 -1871.25 6.32 5958551.34 597270.38 N 70.29626906 W 149.21234463 8934.11 91.02 161.04 6526.24 6607.54 1123.60 4665.31 2030.45 -812.86 -1860.65 9.64 5958522.43 597281.36 N 70.29618967 W 149.2122 8966.63 91.11 160.09 6525.63 6606.93 1151.92 4697.82 2033.07 -843.52 -1849.83 2.93 5958491.91 597292.59 N 70.29610592 W 149.2121 8998.39 92.07 160.11 6524.75 6606.05 1179.44 4729.57 2035.87 -873.37 -1839.02 3.02 5958462.21 597303.78 N 70.29602437 W 149.21208350 9030.52 92.27 161.06 6523.53 6604.83 1207.41 4761.67 2039.47 -903.65 -1828.35 3.02 5958432.08 597314.85 N 70.29594165 W 149.21199703 9062.41 92.10 161.52 6522.32 6603.62 1235.36 4793.54 2043.93 -933.83 -1818.13 1.54 5958402.03 597325.47 N 70.29585920 W 149.21191421 9094.42 91.63 161.82 6521.28 6602.58 1263.52 4825.53 2049.09 -964.20 -1808.07 1.74 5958371.80 597335.93 N 70.29577624 W 149.21183269 9126.06 92.79 161.48 6520.06 6601.36 1291.34 4857.15 2054.67 -994.21 -1798.11 3.82 5958341.93 597346.28 N 70.29569427 W 149.21175204 9158.06 94.36 161.19 6518.06 6599.36 1319.37 4889.09 2060.60 -1024.47 -1787.89 4.99 5958311.81 597356.90 N 70.29561162 W 149.21166923 9189.13 92.71 162.10 6516.15 6597.45 1346.66 4920.10 2066.99 -1053.90 -1778.13 6.06 5958282.52 597367.05 N 70.29553122 W 149.21159012 9221.08 92.68 159.88 6514.64 6595.94 1374.56 4952.01 2073.67 -1084.07 -1767.73 6.94 5958252.49 597377.84 N 70.29544879 W 149.21150590 9252.99 92.44 160.86 6513.22 6594.52 1402.27 4983.89 2080.47 -1114.10 -1757.02 3.16 5958222.61 597388.94 N 70.29536677 W 149.21141914 9284.88 91.67 160.30 6512.07 6593.37 1430.03 5015.76 2087.84 -1144.15 -1746.43 2.98 5958192.70 597399.93 N 70.29528467 W 149.21133329 9317.06 93.95 163.42 6510.50 6591.80 1458.37 5047.90 2096.44 -1174.69 -1736.42 12.00 5958162.30 597410.34 N 70.29520125 W 14921125223 9349.61 98.19 162.10 6507.05 6588.35 1487.14 5080.26 2106.04 -1205.60 -1726.83 13.64 5958131.52 597420.34 N 70.29511682 W 149.21117453 9381.16 96.48 163.21 6503.03 6584.33 1514.94 5111.55 2115.70 -1235.46 -1717.50 6.45 5958101.78 597430.06 N 70.29503523 W 149.21109896 9412.94 96.68 167.23 6499.38 6580.68 1543.59 5143.12 2127.19 -1265.98 -1709.45 12.58 5958071.37 597438.51 N 70.29495186 W 149.21103371 9444.90 97.02 163.42 6495.57 6576.87 1572.42 5174.85 2139.20 -1296.67 -1701.42 11.88 5958040.80 597446.95 N 70.29486802 W 149.21096859 Last MWD+IFR+MS 9458.65 97.09 162.97 6493.88 6575.18 1584.60 5188.50 2144.02 -1309.74 -1697.47 3.29 5958027.79 597451.07 N 70.29483233 W 149.210 TD (Projected) 9507.00 97.09 162.97 6487.91 656921 1627.34 5236.48 2161.38 -1355.61 -1683.42 0.00 5957982.10 597465.72 9 N 70.29470701 W 149.2108 Survey Type: Definitive Survey NOTES: GYD CT DMS - ( Gyrodata -cont. dri llpipe m/s -- Gyrodata pump-down multishot surveys with continuou s tool (RGS-CT) in drill -pipe.) INC+TREND - (Inclination only surveys in near-vertical ho le-where formation dip and experie nce enables direction of drift to be predicted. Replaces ex-BP "Inclinometer (azimuth in known quadrant)" model. ) MWD +IFR + MS - (in-field referenced MWD with mutt-station analysis and correction applied in post-processing. Assumes a BHA sag correction is appl ied to enhan ce inclination accuracy. ) Leaal Description: Northing (Y) [ftUS] Easting (X) [ftUS] Surface : 4564 FSL 3542 FEL S19 T11 N R12E UM 5959359.68 599130.96 BHL : 3208 FSL 273 FEL S24 T1 1 N R11 E UM 5957982.10 597465.72 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Z-1 0212-1 0212-1 0212-1 02 Generated 6/13/2007 3:08 PM Page 4 of 4 Schlumberger L~ I VL r1lldl JUfV~~/ R~~JVfi Report Date: May 13, 2007 Survey 1 DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 190.000° Field: Prudhoe Bay Unit- WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Rig: Nabors 9ES ND Reference Datum: Rotary Table Well: Z-102P61 ND Reference Elevation: 81.3 ft relative to MSL Sea Bed 1 Ground Level Elevation: 54.000 ft relative to MSL UWf1APlff: 50-029-23353-00 Magnetic Declination: 23.698° Survey Name 1 Date: Z-102 I May 13, 2007 Total Field Strength: 57637.956 nT Tort 1 AHD 1 DDI 1 ERD ratio: 280.954° 15236.48 ft / 6.321 10.784 Magnetic Dip: 80.884° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: May 13, 2007 Location Lat/Long: N 7017 54.279, W 14911 49.898 Magnetic Declination Model: MWD+IFR+GMAG Location Grid NIE YIX: N 5959359.680 ftUS, E 599130.960 ftUS North Reference: True North Grid Convergence Angle: +0.75581642° Total Con Mag North •> True North: +23.698° Grid Scale Factor: 0.99991116 Local Coordinates Referenced To: Well Head r, I•__J Comments Measured Inclination Azimuth ND Vertical NS EW DLS Northing Easting Latitude Longitude Survey Tool Depth Section Model ft de de ft) ft ft (ft) (de 100 ft) ftUS) ftUS ) ~~~-ui u.uu u.uu u.uu u.w u.uu u.uv v.uv v.uu oaoasoa.oo oaaisu.ao rv ru ~r ~.zra W 14~ 11 4y.t3ytf 100.00 0.06 101.31 100.00 0.00 -0.01 0.05 0.06 5959359.67 599131.01 N 70 1754.279 W 149 11 49.897 BP_GYD CT DMS 200.00 0.21 107.58 200.00 0.03 -0.08 0.28 0.15 5959359.61 599131.24 N 70 1754.279 W 149 11 49.890 BP_GYD CT DMS 300.00 0.37 92.17 300.00 0.01 -0.14 0.77 0.18 5959359.55 599131.74 N 70 1754.278 W 149 11 49.875 BP_GYD CT DMS 400.00 2.19 337.78 399.98 -1.65 1.61 0.37 2.37 5959361.30 599131.31 N 70 1754.295 W 149 11 49.887 BP GYD CT DMS 500.00 2.98 337.25 499.87 -5.46 5.78 -1.35 0.79 5959365.44 599129.53 N 70 1754.336 W 149 11 49.938 BP_GYD CT DMS 602.00 3.28 338.91 601.72 -10.19 10.95 -3.43 0.31 5959370.58 599127.39 N 70 17 54.387 W 149 11 49.998 BP_GYD CT DMS 702.00 8.38 338.40 701.17 -18.85 20.40 -7.14 5.10 5959379.98 599123.55 N 70 1754.480 W 149 11 50.106 BP_GYD CT DMS 802.00 11.51 342.91 799.66 -33.94 36.71 -12.76 3.22 5959396.22 599117.72 N 70 17 54.641 W 149 11 50.270 BP_GYD CT DMS 902.00 14.02 342.53 897.18 -53.57 57.81 -19.33 2.51 5959417.22 599110.87 N 70 17 54.848 W 149 11 50.461 BP GYD CT DMS 1002.00 17.02 332.37 993.54 -75.92 82.34 -29.76 4.04 5959441.61 599100.12 N 70 17 55.089 W 149 11 50.765 BP_GYD CT~ 1040.70 18.41 326.32 1030.41 -84.83 92.44 -35.77 5.96 5959451.63 599093.97 N 70 17 55.189 W 149 11 50.941 BP_MWD+IFR 1136.74 19.94 321.52 1121.12 -106.65 117.89 -54.37 2.29 5959476.83 599075.04 N 70 17 55.439 W 149 11 51.483 BP_MWD+IFR+MS 1233.39 21.97 322.06 1211.37 -129.69 145.05 -75.75 2.11 5959503.70 599053.31 N 70 17 55.706 W 149 11 52.106 BP_MWD+IFR+MS 1328.38 24.75 322.40 1298.57 -155.01 174.82 -98.81 2.93 5959533.17 599029.86 N 70 17 55.999 W 149 11 52.778 BP MWD+IFR+MS 1424.76 27.16 322.05 1385.22 -183.35 208.16 -124.65 2.51 5959566.16 599003.59 N 70 17 56.327 W 149 11 53.532 BP_MWD+IFR+MS 1520.46 29.08 323.82 1469.62 -214.09 244.16 -151.82 2.19 5959601.79 598975.95 N 70 17 56.681 W 149 11 54.324 BP_MWD+IFR+MS 1615.99 31.48 323.99 1552.11 -247.49 283.08 -180.19 2.51 5959640.33 598947.07 N 70 17 57.063 W 149 11 55.151 BP_MWD+IFR+MS 1709.15 31.36 325.05 1631.61 -281.54 322.62 -208.38 0.61 5959679.50 598918.37 N 70 17 57.452 W 149 11 55.973 BP_MWD+IFR+MS 1804.83 33.10 323.77 1712.55 -317.23 364.11 -238.08 1.95 5959720.58 598888.12 N 70 17 57.860 W 149 11 56.839 BP MWD+IFR+MS 1900.49 32.46 323.38 1792.97 -352.94 405.78 -268.83 0.70 5959761.84 598856.82 N 70 17 58.270 W 149 11 57.735 BP_MWD+IFR+MS 1996.11 31.98 323.23 1873.87 -387.90 446.66 -299.30 0.51 5959802.31 598825.82 N 70 17 58.672 W 149 11 58.623 BP_MWD+IFR+MS yI 2090.99 31.89 324.21 1954.39 -422.59 487.12 -328.99 0.55 5959842.37 598795.60 N 70 17 59.070 W 149 11 59.489 BP_MWD+IFR+MS t ~ Page 1 of 4 vl 0 Comments Measured Inclination Azimuth TVD Vertical NS EW DLS Northing Easting Latitude longitude Survey Tool Depth Section Model (ft) de ) de (ft) ft ft (ft) (de HOOft) (ftUS ftUS L 160.80 31.01 3L3.yb N3O.`J-~ -40/.O`J DL/.`3/ -3~25.D`J U.3L ~yOy825Z.t53 ~`J2f/0~.4/ N /U -I/ O`J.4/Z W l4`J lLV.3~L rsr Mwu+IFK+MJ 2282.15 31.96 322.96 2116.91 -492.21 568.30 -388.47 0.66 5959922.75 598735.06 N 70 17 59.869 W 149 12 1.223 BP MWD+IFR+MS 2378.29 31.49 323.69 2198.69 -526.89 608.84 -418.67 0.63 5959962.89 598704.34 N 70 18 0.267 W 149 12 2.103 BP _MWD+IFR+MS 2473.07 30.83 322.95 2279.79 -560.54 648.18 -447.96 0.81 5960001.83 598674.53 N 70 18 0,654 W 149 12 2.957 BP _MWD+IFR+MS 2569.03 32.18 321.47 2361.61 -594.22 687.79 -478.69 1.62 5960041.04 598643.28 N 70 18 1,044 W 149 12 3.854 BP _MWD+IFR+MS 2664.81 31.59 321.32 2442.94 -627.67 727.33 -510.26 0.62 5960080.15 598611.20 N 70 18 1.433 W 149 12 4.774 BP _MWD+IFR+MS 2760.29 33.36 322.32 2523.48 -661.86 767.63 -541.94 1.94 5960120.03 598578.99 N 70 18 1.829 W 149 12 5.698 BP MWD+IFR+MS 2856.30 32.86 322.43 2603.90 -697.21 809.17 -573.96 0.52 5960161.13 598546.43 N 70 18 2.237 W 149 12 6.631 BP_ MWD+IFR+MS 2951.62 32.74 322.53 2684.03 -732.08 850.12 -605.40 0.14 5960201.67 598514.45 N 70 18 2.640 W 149 12 7.548 BP _MWD+IFR+MS 3048.31 33.10 324.17 2765.19 -768.15 892.28 -636.77 0.99 5960243.40 598482.54 N 70 18 3.055 W 149 12 8.462 BP_ MWD+IFR+MS 3143.54 32.61 324.31 2845.19 -804.20 934.20 -666.96 0.52 5960284.92 598451.80 N 70 18 3.467 W 149 12 9.343 BP _MWD+IFR 3239.24 32.28 324.72 2925.95 -840.19 976.01 -696.76 0.41 5960326.33 598421.45 N 70 18 3.878 W 149 12 10.212 BP_ MWD+IF 3335.16 30.13 326.11 3007.99 -875.57 1016.91 -724.98 2.36 5960366.85 598392.69 N 70 18 4.280 W 149 12 11.035 BP _MWD+IFR+MS 3387.99 29.50 326.84 3053.83 -894.61 1038.80 -739.49 1.38 5960388.55 598377.90 N 70 18 4.496 W 149 12 11.458 BP_ MWD+IFR+MS 3465.49 28.28 327.33 3121.68 -922.03 1070.23 -759.84 1.60 5960419.70 598357.14 N 70 18 4.805 W 149 12 12.051 BP_ MWD+IFR+MS 3561.47 27.98 324.68 3206.33 -954.58 1107.75 -785.13 1.34 5960456.87 598331.36 N 70 18 5.174 W 149 12 12.789 BP_ MWD+IFR+MS 3656.49 25.25 321.07 3291.27 -983.58 1141.71 -810.76 3.34 5960490.49 598305.29 N 70 18 5.508 W 149 12 13.536 BP MWD+IFR+MS 3751.84 22.84 317.87 3378.35 -1008.30 1171.26 -835.96 2.87 5960519.70 598279.70 N 70 18 5.798 W 149 12 14.271 BP_ MWD+IFR+MS 3847.66 18.34 316.06 3468.03 -1028.60 1195.92 -858.90 4.74 5960544.06 598256.43 N 70 18 6.041 W 149 12 14.940 BP_ MWD+IFR+MS 3943.20 17.89 315.56 3558.83 -1045.98 1217.22 -879.61 0.50 5960565.08 598235.45 N 70 18 6.250 W 149 12 15.543 BP_ MWD+IFR+MS 4038.78 18.16 315.70 3649.72 -1063.21 1238.36 -900.29 0.29 5960585.95 598214.50 N 70 18 6.458 W 149 12 16.146 BP_ MWD+IFR+MS 4134.43 18.02 315.56 3740.64 -1080.51 1259.59 -921.06 0.15 5960606.90 598193.45 N 70 18 6.667 W 149 12 16.752 BP MWD+IFR+MS 4230.06 18.13 315.41 3831.55 -1097.74 1280.75 -941.86 0.12 5960627.78 598172.37 N 70 18 6.875 W 149 12 17.359 BP_ MWD+IFR+MS 4325.62 16.55 318.23 3922.77 -1114.78 1301.49 -961.37 1.87 5960648.26 598152.60 N 70 18 7.079 W 149 12 17.927 BP_ MWD+IFR+MS 4422.01 15.72 317.82 4015.36 -1131.28 1321.40 -979.28 0.87 5960667.93 598134.42 N 70 18 7.275 W 149 12 18.450 BP_ MWD+IFR+MS 4517.72 16.03 322.34 4107.42 -1148.13 1341.47 -996.06 1.33 5960687.78 598117.38 N 70 18 7.472 W 149 12 18.939 BP_ MWD+IFR+MS 4613.66 16.63 323.90 4199.49 -1166.57 1363.05 -1012.24 0.77 5960709.14 598100.92 N 70 18 7.684 W 149 12 19.411 BP MWD+IFR+MS 4709.65 16.76 324.21 4291.44 -1185.75 1385.38 -1028.43 0.16 5960731.25 598084.44 N 70 18 7.904 W 149 12 19.883 BP_ MWD+IF 4805.56 16.83 322.97 4383.26 -1204.85 1407.68 -1044.88 0.38 5960753.33 598067.70 N 70 18 8.123 W 149 12 20.363 BP_ MWD+IF 4901.94 16.67 323.09 4475.55 -1223.81 1429.87 -1061.58 0.17 5960775.30 598050.71 N 70 18 8.341 W 149 12 20.850 BP_ MWD+IFR+ S 4997.10 16.89 317.00 4566.66 -1241.45 1450.90 -1079.21 1.86 5960796.08 598032.81 N 70 18 8.548 W 149 12 21.364 BP_ MWD+IFR+MS 5092.78 18.79 302.53 4657.78 -1255.73 1469.36 -1101.69 5.02 5960814.25 598010.08 N 70 18 8.730 W 149 12 22.019 BP MWD+IFR+MS 5188.53 18.86 289.28 4748.45 -1264.14 1482.77 -1129.32 4.46 5960827.29 597982.29 N 70 18 8.862 W 149 12 22.825 BP_ MWD+IFR+MS 5283.94 18.87 279,16 4838.76 -1266.40 1490.32 -1159.11 3.43 5960834.44 597952.40 N 70 18 8.936 W 149 12 23.694 BP_ MWD+IFR+MS 5379.40 19.19 272,10 4929.02 -1264.02 1493.35 -1190.03 2.43 5960837.07 597921.44 N 70 18 8.966 W 149 12 24.595 BP_ MWD+IFR+MS 5475.36 19.89 265,69 5019.46 -1257.81 1492.70 -1222.08 2.35 5960836.00 597889.41 N 70 18 8.959 W 149 12 25.529 BP_ MWD+IFR+MS 5570.45 21.97 256.05 5108.30 -1246.59 1487.20 -1255.48 4.22 5960830.05 597856.08 N 70 18 8.905 W 149 12 26.503 BP MWD+IFR+MS 5666.46 24.30 247.79 5196.60 -1228.76 1475.39 -1291.22 4.16 5960817.78 597820.51 N 70 18 8.789 W 149 12 27.545 BP_ MWD+IFR+MS 5761.45 26.78 241.84 5282.32 -1205.11 1457.90 -1328.19 3.75 5960799.80 597783.78 N 70 18 8.617 W 149 12 28.623 BP_ MWD+IFR+MS 5857.44 28.71 237.19 5367.28 -1176.08 1435.20 -1366.64 3.02 5960776.60 597745.63 N 70 18 8.393 W 149 12 29.744 BP MWD+IFR+MS Page 2 of 4 Comments Measured Inclination Azimuth TVD Vertical NS EW DLS Northing Easting Latitude Longitude Survey Tool Depth Section Model (k) (de ) de ft (k) (k) (ft de I100k ftUS ftUS) oaoJ.GG JG.Vr GJJ.yo b44~.8y -I I4L.IJ 14V/./b -14Ub.Db 3.`JU V`JOU/98.b4 b`J//Vb.U`J IV /U Ii5 iS.IZ3 VV 14y IZ 3U.yUtS t51' MVVU+IFK+MJ 6049.25 35.36 231.38 5529.76 -1102.92 1375.41 -1448.89 3.74 5960715.73 597664.19 N 70 18 7.805 W 149 12 32.142 BP MWD+IFR+MS 6144.93 36.32 230.67 5607.33 -1060.65 1340.17 -1492.44 1.09 5960679.93 597621.11 N 70 18 7.458 W 149 12 33.411 BP _MWD+IFR+MS 6240.27 35.98 230.55 5684.31 -1017.95 1304.48 -1535.90 0.36 5960643.67 597578.12 N 70 18 7.107 W 149 12 34.678 BP _MWD+IFR+MS 6336.03 35.94 229.80 5761.82 -974.99 1268.47 -1579.09 0.46 5960607.09 597535.42 N 70 18 6.753 W 149 12 35.937 BP _MWD+IFR+MS 6432.30 35.44 229.81 5840.01 -931.84 1232.22 -1621.99 0.52 5960570.29 597493.00 N 70 18 6.397 W 149 12 37.188 BP _MWD+IFR+MS 6527.02 34.72 228.03 5917.53 -889.50 1196.46 -1663.03 1.32 5960533.99 597452.45 N 70 18 6.045 W 149 12 38.384 BP MWD+IFR+MS 6622.85 36.61 224.13 5995.39 -844.34 1157.69 -1703.22 3.08 5960494.70 597412.77 N 70 18 5.663 W 149 12 39.556 BP _MWD+IFR+MS 6718.56 41.21 218.85 6069.87 -793.06 1112.61 -1742.90 5.92 5960449.11 597373.69 N 70 18 5.220 W 149 12 40.712 BP _MWD+IFR+MS 6814.46 47.12 216.25 6138.63 -733.82 1059.62 -1783.54 6.44 5960395.59 597333.77 N 70 18 4.699 W 149 12 41.897 BP _MWD+IFR+MS 6909.66 51.27 212.65 6200.84 -668.22 1000.19 -1824.22 5.21 5960335.63 597293.87 N 70 18 4.114 W 149 12 43.082 BP _MWD+IFR 7005.11 55.44 208.36 6257.82 -596.51 934.21 -1863.00 5.66 5960269.15 597255.97 N 70 18 3.465 W 149 12 44.213 BP _MWD+IFI~ 7100.92 59.92 204.55 6309.04 -518.88 861.73 -1898.99 5.76 5960196.21 597220.94 N 70 18 2.752 W 149 12 45.261 BP _MWD+iFR+MS 7196.32 64.32 201.29 6353.65 -436.72 784.08 -1931.78 5.51 5960118.14 597189.19 N 70 18 1.988 W 149 12 46.217 BP _MWD+IFR+MS 7217.26 64.32 200.83 6362.73 -418.20 766.47 -1938.56 1.98 5960100.44 597182.64 N 70 18 1.815 W 149 12 46.414 BP _MWD+IFR+MS 7292.97 64.67 200.68 6395.33 -351.06 702.57 -1962.77 0.50 5960036.24 597159.27 N 70 18 1.187 W 149 12 47.120 BP _MWD+IFR+MS 7387.92 63.56 195.86 6436.80 -266.57 621.49 -1989.56 4.71 5959954.82 597133.56 N 70 18 0.389 W 149 12 47.900 BP MWD+IFR+MS 7484.36 62.75 195.23 6480.35 -180.92 538.59 -2012.62 1.02 5959871.63 597111.60 N 70 17 59.574 W 149 12 48.571 BP_ MWD+IFR+MS 7579.72 62.37 195.04 6524.29 -96.63 456.90 -2034.72 0.44 5959789.66 597090.58 N 70 17 58.770 W 149 12 49.215 BP_ MWD+IFR+MS 7675.54 61.96 194.14 6569.03 -12.17 374.90 -2056.06 0.93 5959707.39 597070.32 N 70 17 57.964 W 149 12 49.837 BP_ MWD+IFR+MS TOW 7712.00 62.11 194.12 6586.13 19.95 343.67 -2063.92 0.41 5959676.07 597062.87 N 70 17 57.657 W 149 12 50.066 BP_BLIND BOW 7725.00 63.49 192.36 6592.07 31.49 332.42 -2066.57 16.05 5959664.78 597060.37 N 70 17 57.546 W 149 12 50.143 BP BLIND 7739.61 62.43 191.80 6598.72 44.49 319.69 -2069.29 8.02 5959652.02 597057.82 N 70 17 57.421 W 149 12 50.222 BP_INC+TREND 7754.78 63.33 191.24 6605.63 57.99 306.46 -2071.99 6.78 5959638.76 597055.30 N 70 17 57.291 W 149 12 50.300 BP_INC+TREND 7786.81 66.60 190.07 6619.18 87.01 277.95 -2077.35 10.73 5959610.18 597050.31 N 70 17 57.010 W 149 12 50.456 BP_INC+TREND 7818.63 69.44 188.95 6631.09 116.51 248.85 -2082.22 9.50 5959581.02 597045.83 N 70 17 56.724 W 149 12 50.598 BP_INC+TREND 7850.17 72.57 187.86 6641.36 146.31 219.35 -2086.58 10.45 5959551.47 597041.86 N 70 17 56.434 W 149 12 50.725 BP INC+TREND 7882.62 74.04 186.78 6650.68 177.36 188.52 -2090.54 5.54 5959520.59 597038.31 N 70 17 56.131 W 149 12 50.840 BP_INC+T 7914.43 74.01 185.74 6659.43 207.88 158.12 -2093.87 3.14 5959490.16 597035.38 N 70 17 55.832 W 149 12 50.937 BP_INC+T 7945.76 77.05 184.73 6667.26 238.10 127.92 -2096.64 10.19 5959459.92 597033.01 N 70 17 55.535 W 149 12 51.017 BP_INC+TR D 7977.66 80.75 183.72 6673.40 269.24 96.70 -2098.94 12.01 5959428.68 597031.12 N 70 17 55.228 W 149 12 51.084 BP_INC+TREND 8010.50 84.13 182.70 6677.72 301.56 64.21 -2100.76 10.74 5959396.16 597029.72 N 70 17 54.908 W 149 12 51.137 BP 'MWD+IFR+MS 8041.53 88.81 183.69 6679.63 332.31 33.29 -2102.49 15.41 5959365.23 597028.41 N 70 17 54.604 W 149 12 51.187 BP_ MWD+IFR+MS 8073.43 93.41 181.92 6679.01 363.94 1.45 -2104.05 15.45 5959333.37 597027.27 N 70 17 54.291 W 149 12 51.233 BP_ MWD+IFR+MS 8105.50 96.09 178.47 6676.36 395.43 -30.51 -2104.16 13.59 5959301.43 597027.58 N 70 17 53.977 W 149 12 51.235 BP_ MWD+IFR+MS 8136.58 97.82 176.74 6672.59 425.56 -61.33 -2102.87 7.84 5959270.63 597029.27 N 70 17 53.673 W 149 12 51.198 BP_ MWD+IFR+MS 8168.94 98.96 173.19 6667.87 456.47 -93.21 -2100.06 11.41 5959238.78 597032.50 N 70 17 53.360 W 149 12 51.116 BP MWD+IFR+MS 8201.00 98.92 171.77 6662.89 486.67 -124.61 -2095.92 4.38 5959207.45 597037.06 N 70 17 53.051 W 149 12 50.995 BP_ MWD+IFR+MS 8232.44 99.17 167.05 6657.94 515.73 -155.12 -2090.21 14.85 5959177.02 597043.16 N 70 17 52.751 W 149 12 50.828 BP_ MWD+IFR+MS 8265.24 99.48 166.19 6652.63 545.44 -186.61 -2082.73 2.75 5959145.63 597051.07 N 70 17 52.441 W 149 12 50.609 BP MWD+IFR+MS Page 3 of 4 . + Comments Measured Inclination Azimuth TVp Vertical NS EW DLS Northing Easting Latitude Longitude Survey Tool Depth Section Model (k) (de ) de ) k) k k k de HOOk) (kUS) kUS) tSLy/.023 `JJ.41 IOO.Oy 004/.3[ 0/4.00 -CI /.~~ -LU/4.`JO 1.254 0`JO`J-I14.25U 0`J/UD`J.ZS N /U 1 / 52.13/ VV 14y lZ OU.325Z t'iY MVVU+IrK+MS 8328.63 99.10 166.43 6642.33 602.55 -247.28 -2067.54 2.85 5959085.17 597067.05 N 70 17 51.845 W 149 12 50.166 BP MWD+IFR+MS 8360.99 99.03 165.61 6637.23 631.75 -278.29 -2059.82 2.51 5959054.27 597075.18 N 70 17 51.540 W 149 12 49.941 BP _MWD+IFR+MS 8392.54 98.85 166.74 6632.33 660.26 -308.56 -2052.37 3.58 5959024.11 597083.02 N 70 17 51.242 W 149 12 49.724 BP_ MWD+IFR+MS 8425.24 98.96 165.29 6627.26 689.78 -339.90 -2044.57 4.39 5958992.87 597091.24 N 70 17 50.934 W 149 12 49.496 BP_ MWD+IFR+MS 8456.43 97.64 167.45 6622.76 718.05 -369.90 -2037.29 8.05 5958962.98 597098.91 N 70 17 50.639 W 149 12 49.284 BP_ MWD+IFR+MS 8488.66 95.16 162.09 6619.17 747.01 -400.79 -2028.88 18.23 5958932.20 597107.73 N 70 17 50.335 W 149 12 49.038 BP MWD+IFR+MS 8520.41 92.39 158.96 6617.08 774.58 -430.65 -2018.32 13.15 5958902.49 597118.68 N 70 17 50.041 W 149 12 48.730 BP_ MWD+IFR+MS 8552.50 90.90 156.54 6616.15 801.71 -460.33 -2006.17 8.85 5958872.97 597131.21 N 70 17 49.749 W 149 12 48.376 BP_ MWD+IFR+MS 8584.91 91.41 156.53 6615.50 828.74 -490.06 -1993.27 1.57 5958843.42 597144.51 N 70 17 49.457 W 149 12 47.999 BP MWD+IFR+MS 8615.75 91.28 158.88 6614.78 854.80 -518.58 -1981.58 7.63 5958815.05 597156.58 N 70 17 49.177 W 149 12 47.658 _ BP MWD+IF 8648.31 91.38 157.85 6614.02 882.51 -548.84 -1969.57 3.18 5958784.96 597168.98 N 70 17 48.879 W 149 12 47.308 - BP MWD+IF ~ 8680.22 91.24 158.43 6613.29 909.61 -578.45 -1957.70 1.87 5958755.52 597181.24 N 70 17 48.588 W 149 12 46.962 BP_ MWD+IFR+MS 8711.49 89.67 157.00 6613.04 936.04 -607.38 -1945.84 6.79 5958726.74 597193.48 N 70 17 48.303 W 149 12 46.616 BP_ MWD+IFR+MS 8744.06 89.52 156.57 6613.27 963.29 -637.31 -1933.00 1.40 5958696.99 597206.71 N 70 17 48.009 W 149 12 46.242 BP_ MWD+IFR+MS 8776.03 90.15 156.36 6613.37 989.94 -666.62 -1920.24 2.08 5958667.85 597219.86 N 70 17 47.721 W 149 12 45.869 BP_ MWD+IFR+MS 8807.36 90.67 157.12 6613.14 1016.13 -695.40 -1907.86 2.94 5958639.24 597232.61 N 70 17 47.438 W 149 12 45.508 BP MWD+IFR+MS 8839.28 92.75 157.62 6612.19 1043.00 -724.85 -1895.59 6.70 5958609.96 597245.27 N 70 17 47.148 W 149 12 45.150 BP_ MWD+IFR+MS 8871.50 93.47 156.90 6610.44 1070.06 -754.52 -1883.15 3.16 5958580.45 597258.10 N 70 17 46.856 W 149 12 44.788 BP_ MWD+IFR+MS 8903.15 93.06 158.86 6608.64 1096.83 -783.79 -1871.25 6.32 5958551.34 597270.38 N 70 17 46.569 W 149 12 44.441 BP_ MWD+IFR+MS 8934.11 91.02 161.04 6607.54 1123.60 -812.86 -1860.65 9.64 5958522.43 597281.36 N 70 17 46.283 W 149 12 44.131 BP_ MWD+IFR+MS 8966.63 91.11 160.09 6606.93 1151.92 -843.52 -1849.83 2.93 5958491.91 597292.59 N 70 17 45.981 W 149 12 43.816 BP MWD+IFR+MS 8998.39 92.07 160.11 6606.05 1179.44 -873.37 -1839.02 3.02 5958462.21 597303.78 N 70 17 45.688 W 149 12 43.501 BP_ MWD+IFR+MS 9030.52 92.27 161.06 6604.83 1207.41 -903.65 -1828.35 3.02 5958432.08 597314.85 N 70 17 45.390 W 149 12 43.189 BP_ MWD+IFR+MS 9062.41 92.10 161.52 6603.62 1235.36 -933.83 -1818.13 1.54 5958402.03 597325.47 N 70 17 45.093 W 149 12 42.891 BP_ MWD+tFR+MS 9094.42 91.63 161.82 6602.58 1263.52 -964.20 -1808.07 1.74 5958371.80 597335.93 N 70 17 44.794 W 149 12 42.598 BP_ MWD+IFR+MS 9126.06 92.79 161.48 6601.36 1291.34 -994.21 -1798.11 3.82 5958341.93 597346.28 N 70 17 44.499 W 149 12 42.307 BP MWD+IFR+MS 9158.06 94.36 161.19 6599.36 1319.37 -1024.47 -1787.89 4.99 .5958311.81 597356.90 N 70 17 44.202 W 149 12 42.009 BP_ MWD+IF 9189.13 92.71 162.10 6597.45 1346.66 -1053.90 -1778.13 6.06 5958282.52 597367.05 N 70 17 43.912 W 149 12 41.724 BP_ MWD+IF 9221.08 92.68 159.88 6595.94 1374.56 -1084.07 -1767.73 6.94 5958252.49 597377.84 N 70 17 43.616 W 149 12 41.421 BP_ MWD+IFR+ S 9252.99 92.44 160.86 6594.52 1402.27 -1114.10 -1757.02 3.16 5958222.61 597388.94 N 70 17 43.320 W 149 12 41.109 BP_ MWD+IFR+MS 9284.88 91.67 160.30 6593.37 1430.03 -1144.15 -1746.43 2.98 5958192.70 597399.93 N 70 17 43.025 W 149 12 40.800 BP MWD+IFR+MS 9317.06 93.95 163.42 6591.80 1458.37 -1174.69 -1736.42 12.00 5958162.30 597410.34 N 70 17 42.724 W 149 12 40.508 BP_ MWD+IFR+MS 9349.61 98.19 162.10 6588.36 1487.14 -1205.60 -1726.83 13.64 5958131.52 597420.34 N 70 17 42.421 W 149 12 40.228 BP_ MWD+IFR+MS 9381.16 96.48 163.21 6584.33 1514.93 -1235.46 -1717.50 6.45 5958101.78 597430.06 N 70 17 42.127 W 149 12 39.956 BP_ MWD+IFR+MS 9412.94 96.68 167.23 6580.68 1543.59 -1265.98 -1709.45 12.58 5958071.38 597438.51 N 70 17 41.827 W 149 12 39.721 BP_ MWD+IFR+MS 9444.90 97.02 163.42 6576.87 1572.42 -1296.67 -1701.42 11.88 5958040.80 597446.95 N 70 17 41.525 W 149 12 39.487 BP MWD+IFR+MS 9458.65 97.09 162.97 6575.18 1584.60 -1309.74 -1697.47 3.29 5958027.79 597451.07 N 70 17 41.396 W 149 12 39.372 BP MWD+IFR+MS Projection to TD 9507.00 97.09 162.97 6569.21 1627.34 -1355.61 -1683.42 0.00 5957982.10 597465.72 N 70 17 40.945 W 149 12 38.962 Page 4 of 4 ACTU/~TOR!- none instl ed Z ~ i~ 2 i Act u a KB!ELEV = 81.3 BF. ELEV = 28.50' ~ , KOP = 400-ft MD Max Angle = 99.5 20" CONDUCTOR $0' Datum MD = f)atum TVf~ i4-1/2" HES X NIP, ID = 3.813" I 9-518" CSG, 40#, L-80 BTC, ID = 8.835" f--~ 3,433' 7335' 7" X4-1l2" Premier PROD PKR ' ~ ~// 1~ 14-112" HES X NIP, ID = 3.813" 4-1 /2" TBG, 12.6#, L-80 TCII, ID = 3.99" 7373' 3-1l2" TBG, 9.2#, L-80 TCII, .0087 bpf, ID = 2.992" / 7567' 3-1/2" HES XN NIP, ID = 2.725" ~ ' Minimum ID = 2.370 @ 2 7/8 tubing pups 7 594' 7" X 5" Flex-Lok hgr. ZXP Packer r~T , w/TIEBACK SLV, ID = 5.25" 7512' ~-~3-1l2" Baker CMD SLIDING SLV, ID = 2.813" 3-112"TCII X 2-7/8" Hyd 511 XO, ID= 2.44" - with 5-1/2" locator donut with mill slotts 2 7!8 6.4# L-80 Hydrill 511 ID = 2.380" 17" BKR WHIPSTOCK TOP r 7" 26#, L-80 TC II ID = 6.276" 7" TC II x 7" BTC-M cross over joint 7" PBTD @ float collar (7" CSG, 26#, L-80 BTC-M, .0383 bpf, ID = 6.276" ~~ 7588' ~ 7589' ~ 7, 712' -t 7989' 7989' I 8114' -I PERFORATION SUMMARY REF LOG: Recorded Mode 4-29 to 5-1 2 ANGLE AT TOP PERF: 53 @ 7756' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2-112" 6 7716-7756 O 05/15!07 2-1/2" 6 7766-7786 O 05/15/07 2-1 /2" 6 9230-9260 O 05/15/07 2-112" 6 9270-9350 O 05/15/07 2-1/2" 6 9365-9402 O 05/15(07 rrcnncau uuu. - ~5M csg head w/7"mandrel hngr & packoff 5Mtubing sppol with 11"x4-1 /2"tubing hangE - 11"x4-1/16", 5M Adaptorflange ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3896 3514 18 KBG2 DMY SBK 1 05/19/07 3 6631 6002 37 KBG2 DCK SBEK 1 05/19/07 2 7392 6439 64 MMGW DMY RK 1.5 05/19/07 1 7452 6466 63 MMGW DMY RK 1.5 05/19/07 7371' ~-~4-112" X3-1l2" TCII XO, ID= 2.992" ,~, ~~.C~~VC~ Z~~ccC~ldti~ CG~U`~111~ V"CCr~~~~`S bt S~~~J~~~S`~J 7886-7906 Baker4-112" x 3-5/8" SBE 3.625 ID 7941' 2-7l8" mule shoe joint 2.441 ID 9260' 20 ft. marker with RA tag P~~ ~~ ~4~~ ~~~~ ~~~~~ 4 1/2 PBTD @ landing collar 9404' /2" 12.6 #, L-80 IBT-M, ID = 3.958" ~~ 9450' DATE REV BY COMMENTS DATE REV BY COMMENTS Borealis Unit 04/11!07 MTT Proposed Completion WELL: Z-102 05/19/07 AM Actual from rig 9-ES PERMIT No: 2070500 05/22/07 SV GLV CORRECTIONS API No: 50-029--233530000 SEC 19, T11N, R12E, 4,565' FSL & 3,542' FEL BP Exploration (Alaska) J l Pr O SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Borealis Well .....................: Z-102 API number ...............: 50-029-23353-00 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.......: 52.80 ft KB above permanent.......: N/A (Topdrive) DF above permanent.......: 81.30 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: 190.00 degrees 13-May-2007 09:41:28 Page 1 of 6 Spud date ................: 25-Apr-07 Last survey date.........: 13-May-07 Total accepted surveys...: 142 MD of first survey.......: 0.00 ft MD of last survey........: 9507.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............: 28-Apr-2007 Magnetic field strength..: 57635.43 LAMA Magnetic dec (+E/W-).....: 23.70 degrees Magnetic dip .............: 80.86 degrees ----- MWD survey Reference Criteria -- ------- Reference G ..............: 1002.68 meal Reference H ..............: 57635.50 GAMA Reference Dip ............: 80.88 degrees Tolerance of G...........: (+/-) 2.50 meal Tolerance of H...........: (+/-)300.00 LAMA Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.70 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.70 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 SCHLUMBERGER Survey Report 13-May-2007 09:41:28 Page 2 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.06 101.31 100.00 100.00 0.00 -0.01 0.05 0.05 101.31 0.06 BP _GYD CT DMS 3 200.00 0.21 107.58 100.00 200.00 0.03 -0.08 0.28 0.29 105.30 0.15 BP _GYD CT DMS 4 300.00 0.37 92.17 100.00 300.00 0.01 -0.14 0.77 0.79 100.49 0.18 BP _GYD CT DMS 5 400.00 2.19 337.78 100.00 399.97 -1.65 1.61 0.37 1.66 13.08 2.37 BP GYD CT DMS 6 500.00 2.98 337.25 100.00 499.87 -5.46 5.78 -1.35 5.94 346.82 0.79 BP _GYD CT DMS 7 602.00 3.28 338.91 102.00 601.72 -10.19 10.95 -3.43 11.47 342.61 0.31 BP - GYD CT DMS 8 702.00 8.38 338.40 100.00 701.17 -18.85 20.40 -7.14 21.61 340.70 5.10 BP _GYD CT DMS 9 802.00 11.51 342.91 100.00 799.66 -33.94 36.71 -12.76 38.87 340.84 3.22 BP _GYD CT DMS 10 902.00 14.02 342.53 100.00 897.18 -53.57 57.81 -19.33 60.95 341.51 2.51 BP GYD CT DMS 11 1002.00 17.02 332.37 100.00 993.54 -75.92 82.34 -29.76 87.55 340.13 4.04 BP _GYD CT DMS 12 1040.70 18.41 326.32 38.70 1030.41 -84.83 92.44 -35.77 99.12 338.85 5.96 BP _MWD+IFR+MS 13 1136.74 19.94 321.52 96.04 1121.12 -106.65 117.89 -54.37 129.82 335.24 2.29 BP _MWD+IFR+MS 14 1233.39 21.97 322.06 96.65 1211.37 -129.69 145.05 -75.75 163.64 332.43 2.11 BP _MWD+IFR+MS 15 1328.38 24.75 322.40 94.99 1298.57 -155.01 174.82 -98.81 200.81 330.52 2.93 BP MWD+IFR+MS 16 1424.76 27.16 322.05 96.38 1385.22 -183.35 208.16 -124.65 242.63 329.09 2.51 BP _MWD+IFR+MS 17 1520.46 29.08 323.82 95.70 1469.62 -214.09 244.16 -151.82 287.51 328.13 2.19 BP _MWD+IFR+MS 18 1615.99 31.48 323.99 95.53 1552.11 -247.49 283.08 -180.19 335.56 327.52 2.51 BP _MWD+IFR+MS 19 1709.15 31.36 325.05 93.16 1631.61 -281.54 322.62 -208.38 384.07 327.14 0.61 BP _MWD+IFR+MS 20 1804.83 33.10 323.77 95.68 1712.55 -317.23 364.11 -238.08 435.04 326.82 1.95 BP MWD+IFR+MS 21 1900.49 32.46 323.38 95.66 1792.97 -352.94 405.78 -268.83 486.76 326.48 0.70 BP _MWD+IFR+MS • 22 1996.11 31.98 323.23 95.62 1873.87 -387.90 446.66 -299.30 537.67 326.17 0.51 BP _MWD+IFR+MS 23 2090.99 31.89 324.21 94.88 1954.39 -422.59 487.12 -328.99 587.81 325.97 0.55 BP _MWD+IFR+MS 24 2186.86 31.61 323.96 95.87 2035.91 -457.69 527.97 -358.59 638.23 325.82 0.32 BP _MWD+IFR+MS 25 2282.15 31.96 322.96 95.29 2116.91 -492.21 568.30 -388.47 688.38 325.64 0.66 BP MWD+IFR+MS 26 2378.29 31.49 323.69 96.14 2198.69 -526.89 608.84 -418.67 738.90 325.49 0.63 BP _MWD+IFR+MS 27 2473.07 30.83 322.95 94.78 2279.79 -560.54 648.18 -447.96 787.91 325.35 0.81 BP _MWD+IFR+MS 28 2569.03 32.18 321.47 95.96 2361.61 -594.22 687.79 -478.69 837.98 325.16 1.62 BP _MWD+IFR+MS 29 2664.81 31.59 321.32 95.78 2442.94 -627.67 727.33 -510.26 888.47 324.95 0.62 BP _MWD+IFR+MS 30 2760.29 33.36 322.32 95.48 2523.48 -661.86 767.63 -541.94 939.66 324.78 1.94 BP MWD+IFR+MS SCHLUMBERGER Survey Report 13-May-2007 09:41:28 Page 3 of 6 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS - - ---- ------ ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- -- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (f t) --------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ - 31 -------- 2856.30 ------ 32.86 ------- 322.43 ------ 96.01 -------- 2603.90 -------- -697.21 ------- 809.17 --------- -573.96 ------- 992.06 -------- 324.65 ----- 0.52 - BP ---- ------ _MWD+IFR+MS 32 2951.62 32.74 322.53 95.32 2684.02 -732.08 850.12 -605.40 1043.66 324.54 0.14 BP _MWD+IFR+MS 33 3048.31 33.10 324.17 96.69 2765.19 -768.15 892.28 -636.77 1096.19 324.49 0.99 BP _MWD+IFR+MS 34 3143.54 32.61 324.31 95.23 2845.19 -804.20 934.20 -666.96 1147.85 324.48 0.52 BP _MWD+IFR+MS 35 3239.24 32.28 324.72 95.70 2925.95 -840.19 976.01 -696.76 1199.20 324.48 0.41 BP MWD+IFR+MS 36 3335.16 30.13 326.11 95.92 3007.99 -875.57 1016.91 -724.98 1248.88 324.51 2.36 BP _MWD+IFR+MS 37 3387.99 29.50 326.84 52.83 3053.83 -894.61 1038.80 -739.49 1275.13 324.55 1.38 BP - MWD+IFR+MS • 38 3465.49 28.28 327.33 77.50 3121.68 -922.03 1070.23 -759.84 1312.54 324.63 1.60 BP _MWD+IFR+MS 39 3561.47 27.98 324.68 95.98 3206.33 -954.58 1107.75 -785.13 1357.77 324.67 1.34 BP _MWD+IFR+MS 40 3656.49 25.25 321.07 95.02 3291.27 -983.58 1141.71 -810.76 1400.30 324.62 3.34 BP MWD+IFR+MS 41 3751.84 22.84 317.87 95.35 3378.35 -1008.30 1171.26 -835.96 1438.98 324.48 2.87 BP _MWD+IFR+MS 42 3847.66 18.34 316.06 95.82 3468.02 -1028.60 1195.92 -858.90 1472.39 324.31 4.74 BP _MWD+IFR+MS 43 3943.20 17.89 315.56 95.54 3558.83 -1045.98 1217.22 -879.61 1501.78 324.15 0.50 BP _MWD+IFR+MS 44 4038.78 18.16 315.70 95.58 3649.72 -1063.21 1238.36 -900.29 1531.03 323.98 0.29 BP _MWD+IFR+MS 45 4134.43 18.02 315.56 95.65 3740.64 -1080.52 1259.59 -921.06 1560.42 323.82 0.15 BP MWD+IFR+MS 46 4230.06 18.13 315.41 95.63 3831.55 -1097.74 1280.75 -941.86 1589.79 323.67 0.12 BP _MWD+IFR+MS 47 4325.62 16.55 318.23 95.56 3922.77 -1114.78 1301.49 -961.37 1618.05 323.55 1.87 BP _MWD+IFR+MS 48 4422.01 15.72 317.82 96.39 4015.36 -1131.28 1321.40 -979.28 1644.72 323.46 0.87 BP _MWD+IFR+MS 49 4517.72 16.03 322.34 95.71 4107.42 -1148.13 1341.47 -996.06 1670.84 323.41 1.33 BP _MWD+IFR+MS 50 4613.66 16.63 323.90 95.94 4199.49 -1166.57 1363.05 -1012.24 1697.81 323.40 0.77 BP MWD+IFR+MS 51 4709.65 16.76 324.21 95.99 4291.44 -1185.75 1385.38 -1028.43 1725.38 323.41 0.16 BP _MWD+IFR+MS S 52 4805.56 16.83 322.97 95.91 4383.25 -1204.85 1407.68 -1044.88 1753.09 323.41 0.38 BP _MWD+IFR+MS 53 4901.94 16.67 323.09 96.38 4475.55 -1223.81 1429.87 -1061.58 1780.87 323.41 0.17 BP _MWD+IFR+MS 54 4997.10 16.89 317.00 95.16 4566.66 -1241.45 1450.90 -1079.21 1808.26 323.36 1.86 BP _MWD+IFR+MS 55 5092.78 18.79 302.53 95.68 4657.78 -1255.73 1469.36 -1101.69 1836.50 323.14 5.02 BP MWD+IFR+MS 56 5188.53 18.86 289.28 95.75 4748.45 -1264.14 1482.77 -1129.32 1863.85 322.71 4.46 BP _MWD+IFR+MS 57 5283.94 18.87 279.16 95.41 4838.76 -1266.40 1490.32 -1159.11 1888.01 322.13 3.43 BP _MWD+IFR+MS 58 5379.40 19.19 272.10 95.46 4929.02 -1264.02 1493.35 -1190.03 1909.52 321.45 2.43 BP _MWD+IFR+MS 59 5475.36 19.89 265.69 95.96 5019.46 -1257.81 1492.70 -1222.08 1929.15 320.69 2.35 BP _MWD+IFR+MS 60 5570.45 21.97 256.05 95.09 5108.30 -1246.59 1487.20 -1255.48 1946.28 319.83 4.22 BP MWD+IFR+MS SCHLUMBERGER Survey Report 13-May-2007 09:41:28 Page 4 of 6 --- Seq -------- Measured ------ Incl ------- Azimuth ------ Course -------- TVD -------- Vertical ------- Displ --------- Displ ------- Total -------- At ----- DLS - ---- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- --- (ft) -------- ------ (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- - type (deg) ---- ------ 61 -- 5666.46 ------ 24.30 ------- 247.79 ------ 96.01 -------- 5196.60 -------- -1228.76 ------- 1475.39 --------- -1291.22 ------- 1960.62 -------- 318.81 ----- 4.16 - BP ---- ------ _MWD+IFR+MS 62 5761.45 26.78 241.84 94.99 5282.32 -1205.11 1457.90 -1328.19 1972.20 317.67 3.75 BP _MWD+IFR+MS 63 5857.44 28.71 237.19 95.99 5367.28 -1176.08 1435.20 -1366.64 1981.79 316.40 3.02 BP _MWD+IFR+MS 64 5953.22 32.07 233.96 95.78 5449.89 -1142.13 1407.76 -1406.55 1990.02 315.02 3.90 BP _MWD+IFR+MS 65 6049.25 35.36 231.38 96.03 5529.76 -1102.92 1375.41 -1448.89 1997.76 313.51 3.74 BP MWD+IFR+MS 66 6144.93 36.32 230.67 95.68 5607.33 -1060.65 1340.17 -1492.44 2005.85 311.92 1.09 BP _MWD+IFR+MS 67 6240.27 35.98 230.55 95.34 5684.31 -1017.96 1304.48 -1535.91 2015.11 310.34 0.36 BP _MWD+IFR+MS 68 6336.03 35.94 229.80 95.76 5761.82 -974.99 1268.47 -1579.09 2025.47 308.77 0.46 BP _MWD+IFR+MS 69 6432.30 35.44 229.81 96.27 5840.01 -931.84 1232.22 -1621.99 2036.96 307.22 0.52 BP _MWD+IFR+MS 70 6527.02 34.72 228.03 94.72 5917.53 -889.50 1196.46 -1663.03 2048.70 305.73 1.32 BP MWD+IFR+MS 71 6622.85 36.61 224.13 95.83 5995.39 -844.34 1157.69 -1703.22 2059.42 304.20 3.08 BP _MWD+IFR+MS 72 6718.56 41.21 218.85 95.71 6069.87 -793.06 1112.61 -1742.90 2067.76 302.55 5.92 BP _MWD+IFR+MS 73 6814.46 47.12 216.25 95.90 6138.63 -733.82 1059.62 -1783.54 2074.56 300.72 6.44 BP _MWD+IFR+MS 74 6909.66 51.27 212.65 95.20 6200.84 -668.23 1000.19 -1824.22 2080.42 298.74 5.21 BP _MWD+IFR+MS 75 7005.11 55.44 208.36 95.45 6257.82 -596.51 934.21 -1863.00 2084.11 296.63 5.66 BP MWD+IFR+MS 76 7100.92 59.92 204.55 95.81 6309.04 -518.88 861.73 -1899.00 2085.37 294.41 5.76 BP _MWD+IFR+MS 77 7196.32 64.32 201.29 95.40 6353.65 -436.72 784.08 -1931.78 2084.84 292.09 5.51 BP _MWD+IFR+MS 78 7217.26 64.32 200.83 20.94 6362.73 -418.20 766.47 -1938.56 2084.58 291.57 1.98 BP _MWD+IFR+MS 79 7292.97 64.67 200.68 75.71 6395.33 -351.06 702.57 -1962.77 2084.73 289.69 0.50 BP _MWD+IFR+MS 80 7387.92 63.56 195.86 94.95 6436.80 -266.57 621.49 -1989.56 2084.37 287.35 4.71 BP MWD+IFR+MS 81 7484.36 62.75 195.23 96.44 6480.35 -180.92 538.59 -2012.62 2083.44 284.98 1.02 BP _MWD+IFR+MS 82 7579.72 62.37 195.04 43.86 6527.74 -109.66 462.58 -1991.88 2044.89 283.07 121.40 BP _MWD+IFR+MS 83 7675.54 61.96 194.14 95.82 6572.48 -25.20 380.58 -2013.22 2048.88 280.70 0.93 BP _MWD+IFR+MS 84 7712.00 62.11 194.12 36.46 6586.13 19.95 343.67 -2063.92 2092.34 279.45 0.41 BP _BLIND 85 7725.00 63.49 192.36 13.00 6592.07 31.49 332.42 -2066.57 2093.13 279.14 16.05 BP BLIND 86 7739.61 62.43 191.80 14.61 6598.71 44.49 319.69 -2069.29 2093.84 278.78 8.02 BP _INC+TREND 87 7754.78 63.33 191.24 15.17 6605.63 57.99 306.46 -2071.99 2094.53 278.41 6.78 BP _INC+TREND 88 7786.81 66.60 190.07 32.03 6619.18 87.01 277.94 -2077.35 2095.86 277.62 10.73 BP _INC+TREND 89 7818.63 69.44 188.95 31.82 6631.09 116.51 248.85 -2082.22 2097.04 276.82 9.50 BP _INC+TREND 90 7850.17 72.57 187.86 31.54 6641.35 146.31 219.35 -2086.58 2098.08 276.00 10.45 BP INC+TREND • ~~ SCHLUMBERGER Survey Report 13-May-2007 09:41:28 Page 5 of 6 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD -------- -------- Vertical ------- ------- Displ --------- --------- Displ ------- ------- Total -------- -------- At ----- ----- DLS ----- ------ ----- ------ Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - --- - (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (f t) -------- (ft) ------- (ft) --------- (ft) ------- (deg) -------- 100f) ----- type (deg) ----- ------ -- 91 -------- 7882.62 ------ 74.04 ------- 186.78 ------ 32.45 -------- 6650.68 -------- 177.36 ------- 188.52 --------- -2090.54 ------- 2099.02 -------- 275.15 ----- 5.54 -- BP_ --- ------ INC+TREND 92 7914.43 74.01 185.74 31.81 6659.43 207.88 158.12 -2093.87 2099.83 274.32 3.14 BP_ INC+TREND 93 7945.76 77.05 184.73 31.33 6667.26 238.10 127.92 -2096.64 2100.54 273.49 10.19 BP_ INC+TREND 94 7977.66 80.75 183.72 31.90 6673.40 269.24 96.70 -2098.94 2101.17 272.64 12.01 BP_ INC+TREND 95 8010.50 84.13 182.70 32.84 6677.72 301.56 64.20 -2100.76 2101.74 271.75 10.74 BP MWD+IFR+MS 96 8041.53 88.81 183.69 31.03 6679.63 332.31 33.29 -2102.49 2102.75 270.91 15.41 BP _ MWD+IFR+MS 97 8073.43 93.41 181.92 31.90 6679.01 363.94 1.44 -2104.05 2104.05 270.04 15.45 - BP MWD+IFR+MS • 98 8105.50 96.09 178.47 32.07 6676.36 395.43 -30.51 -2104.16 2104.38 269.17 13.59 BP_ MWD+IFR+MS 99 8136.58 97.82 176.74 31.08 6672.59 425.56 -61.33 -2102.87 2103.77 268.33 7.84 BP_ MWD+IFR+MS 100 8168.94 98.96 173.19 32.36 6667.87 456.47 -93.21 -2100.06 2102.13 267.46 11.41 BP MWD+IFR+MS 101 8201.00 98.92 171.77 32.06 6662.89 486.67 -124.61 -2095.92 2099.62 266.60 4.38 BP_ MWD+IFR+MS 102 8232.44 99.17 167.05 31.44 6657.94 515.73 -155.12 -2090.22 2095.96 265.76 14.85 BP_ MWD+IFR+MS 103 8265.24 99.48 166.19 32.80 6652.63 545.44 -186.61 -2082.73 2091.07 264.88 2.75 BP_ MWD+IFR+MS 104 8297.58 99.41 165.59 32.34 6647.32 574.55 -217.55 -2074.95 2086.32 264.01 1.84 BP_ MWD+IFR+MS 105 8328.63 99.10 166.43 31.05 6642.33 602.55 -247.28 -2067.54 2082.28 263.18 2.85 BP MWD+IFR+MS 106 8360.99 99.03 165.61 32.36 6637.23 631.75 -278.29 -2059.82 2078.53 262.31 2.51 BP_ MWD+IFR+MS 107 8392.54 98.85 166.74 31.55 6632.32 660.26 -308.56 -2052.37 2075.44 261.45 3.58 BP_ MWD+IFR+MS 108 8425.24 98.96 165.29 32.70 6627.26 689.78 -339.91 -2044.57 2072.63 260.56 4.39 BP_ MWD+IFR+MS 109 8456.43 97.64 167.45 31.19 6622.76 718.05 -369.90 -2037.29 2070.60 259.71 8.05 BP_ MWD+IFR+MS 110 8488.66 95.16 162.09 32.23 6619.16 747.01 -400.79 -2028.88 2068.09 258.83 18.23 BP MWD+IFR+MS 111 8520.41 92.39 158.96 31.75 6617.07 774.58 -430.65 -2018.32 2063.75 257.96 13.15 BP_ MWD+IFR+MS i 112 8552.50 90.90 156.54 32.09 6616.15 801.71 -460.33 -2006.18 2058.31 257.08 8.85 BP_ MWD+IFR+MS 113 8584.91 91.41 156.53 32.41 6615.50 828.74 -490.06 -1993.27 2052.63 256.19 1.57 BP_ MWD+IFR+MS 114 8615.75 91.28 158.88 30.84 6614.77 854.80 -518.58 -1981.58 2048.31 255.33 7.63 BP_ MWD+IFR+MS 115 8648.31 91.38 157.85 32.56 6614.02 882.51 -548.84 -1969.58 2044.62 254.43 3.18 BP MWD+IFR+MS 116 8680.22 91.24 158.43 31.91 6613.29 909.61 -578.45 -1957.70 2041.37 253.54 1.87 BP_ MWD+IFR+MS 117 8711.49 89.67 157.00 31.27 6613.04 936.04 -607.38 -1945.84 2038.43 252.66 6.79 BP_ MWD+IFR+MS 118 8744.06 89.52 156.57 32.57 6613.27 963.29 -637.31 -1933.00 2035.35 251.75 1.40 BP_ MWD+IFR+MS 119 8776.03 90.15 156.36 31.97 6613.36 989.94 -666.62 -1920.24 2032.66 250.86 2.08 BP_ MWD+IFR+MS 120 8807.36 90.67 157.12 31.33 6613.14 1016.14 -695.40 -1907.86 2030.65 249.97 2.94 BP MWD+IFR+MS < ~, SCHLUMBERGER Survey Report 13-May-2007 09:41:28 Page 6 of 6 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 8839.28 92.75 157.62 31.92 6612.19 1043.00 -724.85 -1895.59 2029.45 249.07 6.70 BP _MWD+IFR+MS 122 8871.50 93.47 156.90 32.22 6610.44 1070.06 -754.52 -1883.15 2028.69 248.17 3.16 BP _MWD+IFR+MS 123 8903.15 93.06 158.86 31.65 6608.64 1096.83 -783.79 -1871.25 2028.77 247.27 6.32 BP _MWD+IFR+MS 124 8934.11 91.02 161.04 30.96 6607.53 1123.60 -812.86 -1860.65 2030.45 246.40 9.64 BP _MWD+IFR+MS 125 8966.63 91.11 160.09 32.52 6606.93 1151.92 -843.52 -1849.83 2033.07 245.49 2.93 BP MWD+IFR+MS 126 8998.39 92.07 160.11 31.76 6606.05 1179.44 -873.37 -1839.02 2035.87 244.60 3.02 BP _MWD+IFR+MS 127 9030.52 92.27 161.06 32.13 6604.83 1207.41 -903.65 -1828.35 2039.47 243.70 3.02 BP - MWD+IFR+MS 128 9062.41 92.10 161.52 31.89 6603.62 1235.36 -933.83 -1818.13 2043.93 242.81 1.54 BP _MWD+IFR+MS 129 9094.42 91.63 161.82 32.01 6602.57 1263.52 -964.20 -1808.07 2049.10 241.93 1.74 BP _MWD+IFR+MS 130 9126.06 92.79 161.48 31.64 6601.35 1291.34 -994.21 -1798.11 2054.67 241.06 3.82 BP MWD+IFR+MS 131 9158.06 94.36 161.19 32.00 6599.36 1319.37 -1024.47 -1787.89 2060.61 240.19 4.99 BP _MWD+IFR+MS 132 9189.13 92.71 162.10 31.07 6597.44 1346.66 -1053.90 -1778.13 2066.99 239.34 6.06 BP _MWD+IFR+MS 133 9221.08 92.68 159.88 31.95 6595.94 1374.56 -1084.07 -1767.73 2073.67 238.48 6.94 BP _MWD+IFR+MS 134 9252.99 92.44 160.86 31.91 6594.52 1402.27 -1114.10 -1757.02 2080.47 237.62 3.16 BP _MWD+IFR+MS 135 9284.88 91.67 160.30 31.89 6593.37 1430.03 -1144.15 -1746.43 2087.84 236.77 2.98 BP MWD+IFR+MS 136 9317.06 93.95 163.42 32.18 6591.79 1458.37 -1174.69 -1736.42 2096.44 235.92 12.00 BP _MWD+IFR+MS 137 9349.61 98.19 162.10 32.55 6588.35 1487.14 -1205.60 -1726.83 2106.04 235.08 13.64 BP MWD+IFR+MS 138 9381.16 96.48 163.21 31.55 6584.32 1514.94 -1235.46 -1717.51 2115.70 234.27 6.45 BP _ _MWD+IFR+MS 139 9412.94 96.68 167.23 31.78 6580.68 1543.59 -1265.98 -1709.45 2127.19 233.48 12.58 BP _MWD+IFR+MS 140 9444.90 97.02 163.42 31.96 6576.87 1572.42 -1296.67 -1701.42 2139.20 232.69 11.88 BP MWD+IFR+MS 141 9458.65 97.09 162.97 13.75 6575.18 1584.60 -1309.74 -1697.47 2144.02 232.35 3.29 BP _MWD+IFR+MS • 142 9507.00 97.09 162.97 48.35 6569.21 1627.34 -1355.61 -1683.42 2161.39 231.16 0.00 Projected to TD [(0)2007 IDEAL ID12 OC 09~ v J 1 O `'r d SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ....................: Borealis Well .....................: Z-102PB1 API number................: 50-029-23353-70 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.......: 52.80 ft KB above permanent.......: 0.00 ft DF above permanent.......: 81.30 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: 190.00 degrees 5-May-2007 11:57:56 Page 1 of 4 Spud date ................: 25-Apr-07 Last survey date.........: 05-May-07 Total accepted surveys...: 88 MD of first survey.......: 0.00 ft MD of last survey........: 8130.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2006 Magnetic date ............: 28-Apr-2007 Magnetic field strength..: 57635.43 GAMA Magnetic dec (+E/W-).....: 23.70 degrees Magnetic dip .............: 80.86 degrees ----- MWD survey Reference Reference G ..............: Reference H ..............: Reference Dip ............: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 meal 57635.50 LAMA 80.88 degrees (+/-) 2.50 meal (+/-)300.00 GAMA (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 23.70 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 23.70 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~ SCHLUMBERGER Survey Report 5-May-2007 11:57:56 Page 2 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (f t) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 350.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 100.00 0.06 101.31 100.00 100.00 0.00 -0.01 0.05 0.05 101.31 0.06 BP GYD CT DMS 3 200.00 0.21 107.58 100.00 200.00 0.03 -0.08 0.28 0.29 105.30 0.15 BP _ _GYD CT DMS 4 300.00 0.37 92.17 100.00 300.00 0.01 -0.14 0.77 0.79 100.49 0.18 BP _GYD CT DMS 5 400.00 2.19 337.78 100.00 399.97 -1.65 1.61 0.37 1.66 13.08 2.37 BP GYD CT DMS 6 500.00 2.98 337.25 100.00 499.87 -5.46 5.78 -1.35 5.94 346.82 0.79 BP _GYD CT DMS 7 602.00 3.28 338.91 102.00 601.72 -10.19 10.95 -3.43 11.47 342.61 0.31 BP _GYD CT DMS 8 702.00 8.38 338.40 100.00 701.17 -18.85 20.40 -7.14 21.61 340.70 5.10 BP GYD CT DMS 9 802.00 11.51 342.91 100.00 799.66 -33.94 36.71 -12.76 38.87 340.84 3.22 BP _ _GYD CT DMS 10 902.00 14.02 342.53 100.00 897.18 -53.57 57.81 -19.33 60.95 341.51 2.51 BP GYD CT DMS 11 1002.00 17.02 332.37 100.00 993.54 -75.92 82.34 -29.76 87.55 340.13 4.04 BP _GYD CT DMS 12 1040.70 18.41 326.32 38.70 1030.41 -84.83 92.44 -35.77 99.12 338.85 5.96 BP _MWD+IFR+MS 13 1136.74 19.94 321.52 96.04 1121.12 -106.65 117.89 -54.37 129.82 335.24 2.29 BP _MWD+IFR+MS 14 1233.39 21.97 322.06 96.65 1211.37 -129.69 145.05 -75.75 163.64 332.43 2.11 BP MWD+IFR+MS 15 1328.38 24.75 322.40 94.99 1298.57 -155.01 174.82 -98.81 200.81 330.52 2.93 BP _ MWD+IFR+MS 16 1424.76 27.16 322.05 96.38 1385.22 -183.35 208.16 -124.65 242.63 329.09 2.51 BP _MWD+IFR+MS 17 1520.46 29.08 323.82 95.70 1469.62 -214.09 244.16 -151.82 287.51 328.13 2.19 BP _MWD+IFR+MS 18 1615.99 31.48 323.99 95.53 1552.11 -247.49 283.08 -180.19 335.56 327.52 2.51 BP MWD+IFR+MS 19 1709.15 31.36 325.05 93.16 1631.61 -281.54 322.62 -208.38 384.07 327.14 0.61 BP _ MWD+IFR+MS 20 1804.83 33.10 323.77 95.68 1712.55 -317.23 364.11 -238.08 435.04 326.82 1.95 BP _ MWD.+IFR+MS 21 1900.49 32.46 323.38 95.66 1792.97 -352.94 405.78 -268.83 486.76 326.48 0.70 BP _MWD+IFR+MS 22 1996.11 31.98 323.23 95.62 1873.87 -387.90 446.66 -299.30 537.67 326.17 0.51 BP _MWD+IFR+MS 23 2090.99 31.89 324.21 94.88 1954.39 -422.59 487.12 -328.99 587.81 325.97 0.55 BP _MWD+IFR+MS 24 2186.86 31.61 323.96 95.87 2035.91 -457.69 527.97 -358.59 638.23 325.82 0.32 BP MWD+IFR+MS 25 2282.15 31.96 322.96 95.29 2116.91 -492.21 568.30 -388.47 688.38 325.64 0.66 BP _ MWD+IFR+MS 26 2378.29 31.49 323.69 96.14 2198.69 -526.89 608.84 -418.67 738.90 325.49 0.63 BP _MWD+IFR+MS 27 2473.07 30.83 322.95 94.78 2279.79 -560.54 648.18 -447.96 787.91 325.35 0.81 BP MWD+IFR+MS 28 2569.03 32.18 321.47 95.96 2361.61 -594.22 687.79 -478.69 837.98 325.16 1.62 BP _ MWD+IFR+MS 29 2664.81 31.59 321.32 95.78 2442.94 -627.67 727.33 -510.26 888.47 324.95 0.62 BP _ _MWD+IFR+MS 30 2760.29 33.36 322.32 95.48 2523.48 -661.86 767.63 -541.94 939.66 324.78 1.94 BP MWD+IFR+MS • SCHLUMBERGER Survey Report 5-May-2007 11:57:56 Page 3 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 2856.30 32.86 322.43 96.01 2603.90 -697.21 809.17 -573.96 992.06 324.65 0.52 BP _MWD+IFR+MS 32 2951.62 32.74 322.53 95.32 2684.02 -732.08 850.12 -605.40 1043.66 324.54 0.14 BP _MWD+IFR+MS 33 3048.31 33.10 324.17 96.69 2765.19 -768.15 892.28 -636.77 1096.19 324.49 0.99 BP _MWD+IFR+MS 34 3143.54 32.61 324.31 95.23 2845.19 -804.20 934.20 -666.96 1147.85 324.48 0.52 BP _MWD+IFR+MS 35 3239.24 32.28 324.72 95.70 2925.95 -840.19 976.01 -696.76 1199.20 324.48 0.41 BP MWD+IFR+MS 36 3335.16 30.13 326.11 95.92 3007.99 -875.57 1016.91 -724.98 1248.88 324.51 2.36 BP _MWD+IFR+MS 37 3387.99 29.50 326.84 52.83 3053.83 -894.61 1038.80 -739.49 1275.13 324.55 1.38 BP _ MWD+IFR+MS 38 3465.49 28.28 327.33 77.50 3121.68 -922.03 1070.23 -759.84 1312.54 324.63 1.60 BP _MWD+IFR+MS 39 3561.47 27.98 324.68 95.98 3206.33 -954.58 1107.75 -785.13 1357.77 324.67 1.34 BP _MWD+IFR+MS 40 3656.49 25.25 321.07 95.02 3291.27 -983.58 1141.71 -810.76 1400.30 324.62 3.34 BP MWD+IFR+MS 41 3751.84 22.84 317.87 95.35 3378.35 -1008.30 1171.26 -835.96 1438.98 324.48 2.87 BP _MWD+IFR+MS 42 3847.66 18.34 316.06 95.82 3468.02 -1028.60 1195.92 -858.90 1472.39 324.31 4.74 BP _MWD+IFR+MS 43 3943.20 17.89 315.56 95.54 3558.83 -1045.98 1217.22 -879.61 1501.78 324.15 0.50 BP _MWD+IFR+MS 44 4038.78 18.16 315.70 95.58 3649.72 -1063.21 1238.36 -900.29 1531.03 323.98 0.29 BP _MWD+IFR+MS 45 4134.43 18.02 315.56 95.65 3740.64 -1080.52 1259.59 -921.06 1560.42 323.82 0.15 BP MWD+IFR+MS 46 4230.06 18.13 315.41 95.63 3831.55 -1097.74 1280.75 -941.86 1589.79 323.67 0.12 BP _MWD+IFR+MS 47 4325.62 16.55 318.23 95.56 3922.77 -1114.78 1301.49 -961.37 1618.05 323.55 1.87 BP _MWD+IFR+MS 48 4422.01 15.72 317.82 96.39 4015.36 -1131.28 1321.40 -979.28 1644.72 323.46 0.87 BP _MWD+IFR+MS 49 4517.72 16.03 322.34 95.71 4107.42 -1148.13 1341.47 -996.06 1670.84 323.41 1.33 BP _MWD+IFR+MS 50 4613.66 16.63 323.90 95.94 4199.49 -1166.57 1363.05 -1012.24 1697.81 323.40 0.77 BP MWD+IFR+MS 51 4709.65 16.76 324.21 95.99 4291.44 -1185.75 1385.38 -1028.43 1725.38 323.41 0.16 BP _MWD+IFR+MS • 52 4805.56 16.83 322.97 95.91 4383.25 -1204.85 1407.68 -1044.88 1753.09 323.41 0.38 BP _MWD+IFR+MS 53 4901.94 16.67 323.09 96.38 4475.55 .-1223.81 1429.87 -1061.58 1780.87 323.41 0.17 BP _MWD+IFR+MS 54 4997.10 16.89 317.00 95.16 4566.66 -1241.45 1450.90 -1079.21 1808.26 323.36 1.86 BP _MWD+IFR+MS 55 5092.78 18.79 302.53 95.68 4657.78 -1255.73 1469.36 -1101.69 1836.50 323.14 .5.02 BP MWD+IFR+MS 56 5188.53 18.86 289.28 95.75 4748.45 -1264.14 1482.77 -1129.32 1863.85 322.71 4.46 BP _MWD+IFR+MS 57 5283.94 18.87 279.16 95.41 4838.76 -1266.40 1490.32 -1159.11 1888.01 322.13 3.43 BP _MWD+IFR+MS 58 5379.40 19.19 272.10 95.46 4929.02 -1264.02 1493.35 -1190.03 1909.52 321.45 2.43 BP _MWD+IFR+MS 59 5475.36 19.89 265.69 95.96 5019.46 -1257.81 1492.70 -1222.08 1929.15 320.69 2.35 BP _MWD+IFR+MS 60 5570.45 21.97 256.05 95.09 5108.30 -1246.59 1487.20 -1255.48 1946.28 319.83 4.22 BP MWD+IFR+MS SCHLUMBERGER Survey Report 5-May-2007 11:57:56 Page 4 of 4 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (f t) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5666.46 24.30 247.79 96.01 5196.60 -1228.76 1475.39 -1291.22 1960.62 318.81 4.16 BP MWD+IFR+MS 62 5761.45 26.78 241.84 94.99 5282.32 -1205.11 1457.90 -1328.19 1972.20 317.67 3.75 BP ~MWD+IFR+MS 63 5857.44 28.71 237.19 95.99 5367.28 -1176.08 1435.20 -1366.64 1981.79 316.40 3.02 BP MWD+IFR+MS 64 5953.22 32.07 233.96 95.78 5449.89 -1142.13 1407.76 -1406.55 1990.02 315.02 3.90 BP _ MWD+IFR+MS 65 6049.25 35.36 231.38 96.03 5529.76 -1102.92 1375.41 -1448.89 1997.76 313.51 3.74 BP _ MWD+IFR+MS 66 6144.93 36.32 230.67 95.68 5607.33 -1060.65 1340.17 -1492.44 2005.85 311.92 1.09 BP MWD+IFR+MS 67 6240.27 35.98 230.55 95.34 5684.31 -1017.96 1304.48 -1535.91 2015.11 310.34 0.36 BP _ MWD+IFR+MS 68 6336.03 35.94 229.80 95.76 5761.82 -974.99 1268.47 -1579.09 2025.47 308.77 0.46 BP _ MWD+IFR+MS 69 6432.30 35.44 229.81 96.27 5840.01 -931.84 1232.22 -1621.99 2036.96 307.22 0.52 BP _ MWD+IFR+MS 70 6527.02 34.72 228.03 94.72 5917.53 -889.50 1196.46 -1663.03 2048.70 305.73 1.32 BP ~MWD+IFR+MS 71 6622.85 36.61 224.13 95.83 5995.39 -844.34 1157.69 -1703.22 2059.42 304.20 3.08 BP MWD+IFR+MS 72 6718.56 41.21 218.85 95.71 6069.87 -793.06 1112.61 -1742.90 2067.76 302.55 5.92 BP _ MWD+IFR+MS 73 6814.46 47.12 216.25 95.90 6138.63 -733.82 1059.62 -1783.54 2074.56 300.72 6.44 BP _ MWD+IFR+MS 74 6909.66 51.27 212.65 95.20 6200.84 -668.23 1000.19 -1824.22 2080.42 298.74 5.21 BP _ MWD+IFR+MS 75 7005.11 55.44 208.36 95.45 6257.82 -596.51 934.21 -1863.00 2084.11 296.63 5.66 BP _ MWD+IFR+MS 76 7100.92 59.92 204.55 95.81 6309.04 -518.88 861.73 -1899.00 2085.37 294.41 5.76 BP MWD+IFR+MS 77 7196.32 64.32 201.29 95.40 6353.65 -436.72 784.08 -1931.78 2084.84 292.09 5.51 BP _ MWD+IFR+MS 78 7217.26 64.32 200.83 20.94 6362.73 -418.20 766.47 -1938.56 2084.58 291.57 1.98 BP ~MWD+IFR+MS 79 7292.97 64.67 200.68 75.71 6395.33 -351.06 702.57 -1962.77 2084.73 289.69 0.50 BP MWD+IFR+MS 80 7387.92 63.56 195.86 94.95 6436.80 -266.57 621.49 -1989.56 2084.37 287.35 4.71 BP _ MWD+IFR+MS 81 7484.36 62.75 195.23 96.44 6480.35 -180.92 538.59 -2012.62 2083.44 284.98 1.02 BP MWD+IFR+MS 82 7579.72 62.37 195.04 95.36 6524.29 -96.63 456.90 -2034.72 2085.38. 282.66 0.44 BP _ MWD+IFR+MS 83 7675.54 61.96 194.14 95.82 6569.03 -.12.17 374.90 -2056.06 2089.96 280.33 0.93 BP _ MWD+IFR+MS 84 7771.17 62.36 194.08 95.63 6613.69 72.17 292.89 -2076.68 2097.23 278.03 0.42 BP _ MWD+IFR+MS 85 7866.80 62.47 193.52 95.63 6657.98 156.74 210.58 -2096.89 2107.44 275.73 0.53 BP _ MWD+IFR+MS 86 7962.38 62.48 193.92 95.58 6702.15 241.33 128.23 -2117.00 2120.88 273.47 0.37 BP MWD+IFR+MS 87 8057.78 62.57 193.51 95.40 6746.16 325.79 46.01 -2137.06 2137.56 271.23 0.39 BP _ MWD+IFR+MS 88 8130.00 62.57 193.51 72.22 6779.43 389.77 -16.32 -2152.04 2152.10 269.57 0.00 _ Projected to TD ~~ • [(c)2007 IDEAL ID12 OC 09] Schiuraberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description NO.4401 Company: Alaska Oil & Gas Cons Comm ANn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: voiaris Midnight Sun Borealis Date BL Color CD E-102 11637355 PRODUCTION PROFILE (~ "' 07128107 1 S-215 N/A USIT 08/01/07 1 Z-102 11637125 CH EDIT POC GR USIT Z "~ 05/16107 1 W-213 11638637 CH EDIT PDC GR USIT - $~ 05/31/07 1 C PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH 70: BP E~plo(aUO~, (Alaska) Inc ~.:.,,,, Pafirot~c~nlC~l~~a CehtBC ~R2 ~1 J.UO.E B~'n54pi~lv[1` , ; f.. Anchorage AK 99508-4254 ,f `D~f~~Jeli~red~ ? t`' 117 ,r ~_ I. ~~.h f CIIIl1`!~~^y!C1n~4 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: 08/30/07 ~~ Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer Well No Installation/Rig BP Exploration (Alaska) Inc. Z-102 Nabors-9ES Dispatched To: Helen Warman (AOGCC) Date Dispatched: 14-May-07 Dispatched By: Nate Rose Data No Of Prints No of Floppies. Surveys 2 1 Please sign and return to: James H. Johnson Received By: a BP Exploration (Alaska) Inc. n' Petrotechnical Data CenterjLR2-1) ~7 ] p ,~ r-~ 900 E. Benson Blvd. ` p4`(J l Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhC~bp.com LWD Log DeliveryV1.1,10-02-03 ~,~~-~~~ • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Well No Z-102 P61 Date Dispatched Installation/Rig Nabors-9ES Dispatched By: Helen Warman (AOGCC) 11-May-07 Nate Rose Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: names H. Jonnson Received By: BP Exploration (Alaska) Inc. (`Q ~ ~ ~ Petrotechnical Data Center (LR2-1) `- l~ 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhCa?bp.com LWD Log Delivery V1.1,10-02-03 ~.~?-~~~ • Maunder, Thomas E (QOA) From: Gary Elmore [elmore1Qanchorage.oilfieldslb.com] Sent: Monday, June 25, 20071:27 PM To: 'Thomas Maunder'; 'Gary Elmore ; 'Robin Smyth' Cc: 'Cheve M@yer' Subject: RE: PBU Z-102 Hi Tom... You're right, this one is a BP log which means Robin is off the hookE I'll get with Cheve Meyer when he returns on Wednesday and have him correct the comments. We'll also take a look at the log for orientation. Depending on whether or not a GPIT was run for orientation...it could be that the tool isn't oriented (although it`s possible to make some fairly certain assumptions without one}. If the GPIT sub wasn't ran in the toolstring, and without looking at the log yet, I`d assume what you're seeing is tool rotation. I'll have Cheve look at it and get back to you on Weds if that`s acceptable. If you need me to work it before than just let me know! Thanks, Gary **************************** Gary Elmore Account Manager - BP Exploration (Alaska}, Inc. Schlumberger Oilfield Services (907) 273-1747 Office (907} 830-2931 Cell (907) 746-5159 Home Gary.Elmore@.slb.com Gary.Elmore@bp.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, June 22, 2007 10:15 AM To: Gary Elmore; Robin. Smyth Subject: PBU Z-I02 Gary and Robin, I think this is in Gary's "area", but wanted to cover all bases. I was just reviewing the hard copy of the USIT from this well. Pretty good log. One comment on the "2nd gage of the header", the cement volumes are given. It appears the digits are correct, but the volume should be barrels. As you look at the "text" entries a little further on, the digits and volumes are correct. In the comments, it states that the image is oriented with low side in middle of the track. Interesting to see the swirl in the map. I wonder if the centralization had anything to do with this. It appears that the casing was reciprocated nearly to bumping the plug. Thanks, Tom 1 PBU Z-102 (207-050) i Subject: PBU Z-102 (207-050) From: Thomas Maunder <tom maunder@adntin.state.ak.us> Date: Fri, 22 Jun 2007 09:27:46 -0800 To: Terrie Hubble <hubbletl@bp.com> Terrie, I am reviewing the 407 for this well. On the coversheet, the cementing info for the 7" lists 223 sx LiteCrete and 168 sx Class G. On page 8 of the operations summary, it is stated that 98 bbls of lead and 35 bbl of tail were pumped. Using the yield (1.52 ft3/sx) given in the well plan, I cannot make the 223 and 98 numbers agree. Assuming the 98 bbls given in the ops summary is correct, the sx count would be 361 using 1.52. If both the 223 and 98 numbers are correct, the yield would have to be 2.46. Was a different kind of litecrete used? Thanks for checking. Tom 1 of 1 6/22/2007 9:42 AM Sc6lam~erger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth -~ ., ~, , Well Job # -~ a_ Log Description NO. 4292 Company: Alaska Oit 8 Gas Cons Comm Aftn: Christine Mahnken 333 West 7th Ave, Suite 700 Anchorage, AK 99501 Field: Prudhoe Bay Orion Borealis Date BL Color CD V-278 11661147 MEMORY TEMP SURVEY 05/19107 1 Z-t 02 11637125 CEMENT IMAGEIBOND LOG 05/16/07 1 V-04 V-214 L-250 V-722 40074377 40014206 40012593 40074531 OH EDIT MWD/LWD OH EDIT MWDILWD OH EDIT MWD/LWD OH EDIT MWDILWD 17/28/06 10/30106 11/09105 12/30106 2 2 2 2 t 1 1 1 V-122P81 40014531 OH EDIT MWDILWD 12116106 2 1 V-122P62 40074537 OH EDIT MWD/LWD 12128107 t 1 L-250L1 40012593 OH EDIT MWD/LWD 17175105 t 1 L-250P81 L-04 OWDW-NW 40012593 40014142 11477941 OH EDIT MWD/LWD OH EDIT MWD/LWD RST 10126/05 10109/06 11!14/06 2 2 1 t 1 i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACfi TO: BP Exploration (Alaska)Inc. Petrotechnical Data Cenfer LR2-1 900 E Benson Blvd. Anchorage AK 99506-4254 Date Delivered. o1b~--bS~ Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: as/ono~ 0~ Re: Z-102 • Subject: Re: Z-102 Frorn: Thomas Maunder <tom maunder@,admin.state.ak.us> Date: Fri, 20 Apr 2007 07:26:28 -0800 'l'o: "Triolo, R'like T" ~~-!~1ike.Triolu(crbp.e.om = CC: ~~-hir~ack, Rohcrt L3" ~I:ohert_~hir-pa~~ui.131'.com=. "tich«ltz_ 1~tik~l" -~~N1ikel.Schultz~a; 31'.coni-~, ~~~"oian~„ .lim" ~-Ji~i1.l'oun~~~ci.E3P.com=~=, '~Oaklev. Rav IYR~)~~ ~~Ray.(~al.lt~~(u'BP.co~~~~= Mik, et al, Thanks much for the reply Tom Maunder, PE AOGCC This answers my questions and will allow me to finish my review. Triolo, Mike T wrote, On 4/19/2007 5:16 PM: Tom, Sorry for the delay in responding. It took a bit of time to coordinate with all involved regarding the response. Area Map and Z-102i Injector Service: Please find attached a map at the top Kuparuk showing the Z-102i planned BHL in conjunction with all of the wells within 1/4 mile radius of the two injection points of the horizontal. Also note that some of the wells fall outside of the 1/4 mile circles but were evaluated anyway for completeness. We have included on'the area map the locations of the planned perforations to show that the actual standoff from the perforations is actually greater than the 340-ft noted on the Area Review. Initial injection will be water at the toe of the well to support ongoing production from Z-108. Subsequent water injection at the heel will commence after an additional producer is drilled to the North. At this time no MI is planned to be injected into the toe of the well, only the heel following initial water injection. It is our desire to utilize Z-102i as a water injector only until such time as cement integrity can be confirmed in Z-06. Cement Job on Z-06: 3. NOTE: The as drilled top Kuparuk is at 7,248-ft MD. Z-06 did have a challenging cement job, however according to the cementing report, they did achieve 50-75% returns while pumping the cement, which could put the top of cement above the Kuparuk. 1. If you use 50% returns, the TOC: would be around 7,709-ft MD using 30% excess (461-ft below top Kuparuk). 2. If you use 75% this puts the TOC around 6,400-ft MD using 30s excess (848-ft above top Kuparuk). Looking at the drilling report they noted 60% returns after starting displacement. This certainly falls within the range noted on the cementing report. 1. If you use 60%, that puts the TOC at 7186-ft MD using 30% excess (62-ft above the top Kuparuk). Also, Z-06 passed an MIT-OA on 6/14/2003 to 2,000 psi Z-06 Sidetrack Potential: Z-06 has been on the list for some time now as a potential sidetrack candidate due to high watercut. Pattern optimization is currently underway and Z-06 is a likely candidate for a near term future sidetrack. In the event the well is sidetracked one of the operations will be to run a USIT across this interval to confirm TOC. Remedial work may be conducted on Z-06 pending results from the 1 of 2 4/20/2007 7:32 AM Re: Z-102 • • USIT. This will help provide assurance to future MI infectivity conformance within the pattern. Z-06 Monitoring Plan: Our monitoring plan regarding Z-06 is to conduct an annual temperature and or water flow log to help determine if warm fluids from the Kuparuk are migrating up into the Schrader. We have historically had some successes with these logs in varying scenarios; however they are by no means definitive on every application. We will acquire baseline logs on Z-06 prior to commencing injection activities on Z-1021. We will reevaluate the need and frequency of the monitoring program based on results of the monitoring and changes to the utility of Z-06. Hope this info helps, Michael (Mik) Triolo WRD Projects Drilling Lead * (907) 564-5774 * (907) 240-8076 * tr.iolomteUb . com -----Original Message----- From: Thomas Maunder [mailto:tom maun.deri~:admin.sta.te.ak.u.s] Sent: Wednesday, April 18, 2007 4:20 PM To: Triolo, Mike T Subject: Z-102 Mik, I am reviewing the permit application and have some questions. 1. Can you provide a plan view of the 1/4 mile proximity so I can visualize where the close approaches are. I am curious which wells are near the heal and toe. 2. In your analysis of the cement isolation, you conclude that Z-06 does not have integrity across the Kuparuk and that it will be monitored. How is it proposed to monitor the well? Thanks in advance, Tom Maunder, PE AOGCC 2 of 2 4!2012007 7:32 AM Z-102i Perf Intervals • Z-102i Offset Wells • • EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) :~ 6050000 5850000 ~ _ - - _ _ - ____ _ 400000 500000 600000 700000 800000'i • 8~ ®~i ~D ~7tp~ COlOTSERQA'I'IO1Q CODi1~iISSI®1~T ' Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU Z-102i BP Exploration (Alaska) Inc. Permit No: 207-050 Surface Location: 4565' FSL, 3542' FEL, SEC. 19, T11N, R12E, UM Bottomhole Location: 3126' FSL, 239' FEL, SEC.24, Tl 1N, R11E, UM Dear Mr. Tirpack: Enclosed is the approved application for- permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The Area of Review analysis conducted for this injection well indicates that the top of cement behind the 9-5/8" casing in PBU Z-06 (188-032) is likely not above proposed Kuparuk injection zone. Z-06 is calculated to be about 500' from the nearest perforation in toe section of Z-102. In order to assess the integrity of Z-06, BP proposes to acquire baseline logs over the Kuparuk interval and limit injection in 2- 102 to water only until isolation can be confirmed. The proposed plan is acceptable. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the mission to witness any required test, contact the Commission's petroleum field " pect~r at (907) 659-3607 (pager). DATED this 'day of April, 2007 S,4RlJH PAULA, GOVERNOR cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ~~%f.,p~ ALA~OIL AND GAS CONSERVATION COMMIS510 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory O Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 - 11. Well Name and Number: PBU Z-1021 ' 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9599 ~ TVD 6561 ' 12. Field /Pool(s): Prudhoe Bay Field /Borealis 4a. Location of Well (Governmental Section): Surface: 3542' FEL SEC 4565' FSL 19 T11N R12E UM ~ 7. Property Designation: ADL 028245 Pool , , . , , , Top of Productive Horizon: 4588' FSL, 726' FEL, SEC. 24, T11 N, R11 E, UM ~ 8. Land Use Permit: 13. Approximate Spud Date: April 25, 2007 Total Depth: 3126' FSL, 239' FEL, SEC. 24, T11 N, R11 E, UM ' 9. Acres in Property: 2560 - 14. Distance to Nearest Property: 4650' 4b. Location of Well (State Base Plane Coordinates): Surface: x-599131 y-5959360 Zone-ASP4 10. KB Elevation Plan (Height above GL): 81.3 feet 15. Distance to Nearest Well Within Pool: 2260' 16. Deviated Wells: Kickoff Depth: 400 feet Maximum Hole An le: 99 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3324 Surface: 2655 18_ Casin Pr ram: 5 ' bo ns T -Settin th -Bo ttom uanf f ` " en c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 91.5# H-40 Weld 80' Surface Surface 108' 108' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3476' Surface Surface 3476' 3131' 564 AS Lite 380 sx Class'G' 8- /4" 7" 26# L-80 TC-II 80 3' urfac Surfa 8093' 67 1' 338 sx Lie rete 1 8 sx CI 6-1 /8" 4-1 /2" 12.6# L-80 IBT-M 1981' 7603' 6550' 9584' 6563' 251 sx Class 'G' 19. PRESE NT WELL GONDITION•SUMMARY (To be completed for Redrilland 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 ement Volume MD D Conductor /Structural Surface Intermediate Pr ducti n Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Piat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Michael Triolo, 564-5774 Printed Name Robert Tirpack Title Senior Drilling Engineer -~ Prepared By Name/Number: Si nature ~~ Phone 564-4166 Date ~ J3 ~ Terrie Hubble, 564-4628 Commission Use Oinl Permit To Drill Numb r: O~OS00 API Number: 50- O~y'- o?33S,3Gi~00 Permit Ap royal Date: See cover letter for other re uir men s Conditions of Approval: ~, ~ f,'~L ~y~r~n~C, ~~~~~~ O~~ ~/ ~~,r~~,~ ~Ifnbox is checked, well may nq be use to explore or, tes , or produce coalbed methane, gas hydrates, or gas contained shales:UY/ ~> P`i+ `,7v~ ~~5~'~`i ~,Gnh < ~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes II~J No ©W~~~~~,,p\ HZS Measures: Yes ^ No it io al Survey Req'd: Yes ^ No Other. ~"a\~w~~~ t~r4Vti~ w~.~~E~c~~,~i/nS ~. 1'~00~ :+c~gV c-~Cft ~o ~ APPROVED BY THE COMMISSION Date ~~' ~~ ,COMMISSIONER ~..;j~ .~ 3 ?007 PERMIT TO DRILL (~3 Alaska ~:, ~ Gas Cons. Ctxnm't 20 AAC 25.005 An 1 Form 10-401 Revised 12/2005 ~ ~ ~ ~ • ( ~ ~ ~/ S it~ D~ I • C~' J Well Name: Z-1021 Drill and Complete Plan Summary T pe of Well (service / roducer / injector): WAG Injector Surface Location: 4,565' FSL, 3,542' FEL, Sec. 19, T11 N, R12E X = 599,130.96 Y = 5,959,359.68 Z-102i P61 Top Kup C4 Target (Pilot Hole): 4,911' FSL, 653' FEL, Sec. 24, T11 N, R11 E X = 597,063 Y = 5,959,680 Z = 6,500' TVDss Z-1021 PB1 Kup BHL (Pilot Hole): 4,586' FSL, 771' FEL, Sec. 24, T11 N, R11 E X = 596,949 Y = 5,959,353 Z = 6,700' TVDss Z-102i Kup C4 Target 1: 4,588' FSL, 726' FEL, Sec. 24, T11 N, R11 E X = 596,994 Y = 5,959,356 Z = 6,590' TVDss Z-102i Kup C7 Target 2: 3,880' FSL, 530' FEL, Sec. 24, T11 N, R11 E X = 597,200 Y = 5,958,650 Z = 6,540' TVDss Z-1021 Kup BHL: 3,126' FSL, 239' FEL, Sec. 24, T11 N, R11 E X = 597,500 Y = 5,957,900 Z = 6,480' TVDss AFE Number Estimated Start Date: 4/25/2007 Pilot MD 8,093' (Pilot) Inj KOP 7,728' Inj MD 9,599' Ri Nabors 9ES Operatin days to com lete: 21 TVDrkb: TD 6,781' TVDrkb: KOP 6,598' TVDrkb: TD 6,561' Max Inc. 60° Inc. 62° Max Inc. 99° KBE 81.30' Well Desian: Ultra Slimhole Horizontal Kuparuk Infector ~ Z-1021 injector will provide pressure support at two locations in the Z-Pad Kuparuk: - In order to facilitate selective infectivity control into each injection location along the horizontal, a unique completion design had to be developed. This completion design has resulted in the production packer being more than 200' MD above the top of the Kuparuk injection interval (see attached completion schematic). This risk is mitigated through the use of 7" TCII intermediate casing and cement on the backside of the 7" casing between the Kuparuk and Schrader Bluff reservoirs. Z-1021 Permit application Page 1 • Directional: r Ver. Z-102PB1 P6 and Z-102 P-12 KOP: 400' Maximum Hole An le: 60 de in Z-102PB1 and 99 de in Z-102 Close A roach Wells: All wells ass ma'or risk criteria. Distance to nearest well BHL is 2260' northwest of Z-108 within pool: Distance to Nearest 4,650' East of PBU boundary Pro erty Line: Wells within ~/a mile of this injector @ top Well Name Dist, Ft. Annulus Inte rit Comments reservoir: Z-05 160 ft. TOC calculated to be above injection zone. 50-75% Lost Returns during Cement Job. Unable to tell where losses occur. TOC inconclusive. Many lost returns while drilling '--°-~ Z-06 340 ft. from 5000' down to 8000'. Z-04 690 ft. TOC calculated to be above injection zone. Z-09 1130 ft. TOC calculated to be above injection zone. Pumped additiona1551 cu ft cmt through FO sleeves at 2653' and 2402'. Saw wet cmt returns to surface. Currently plugged and Hi hland State 1 1340 ft. abandoned. PTD #76-017. USIT Log indicates TOC above Injection Z-02 1360 ft. Zones. (2 Passes to Confirm) Bond log offers no conclusive evidence of good cement. There is little if any indication of good cement. Based on the high volume of cement pumped, and the change in borehole fluid density, it would seem possible that a microannulus condition may exist which Z-33 1410 ft. masks the true cement strength. The TOC calculations are based on the cement volumes pumped with 30% excess in the annular space. See attached Area of Review for Z-102i for further review of wells within ~/a mile of this .injector C~ top reservoir. Logging Program: Surface Drilling: MWD / GR Open Hole: None Cased Hole: None Intermediate Hole Drilling: MWD/GR/RES/NEU/DEN/Sonic/PWD/Stethoscope. GR/RES/NEU/DEN/ in real-time (Sonic in recorded). Open Hole: None Cased Hole: None Production Hole Drilling: MWD/GR/RES/DEN/NEU ABI. GR/RES/NEU/DEN (azmuthal) ABI real-time for geosteering. Open Hole: None Cased Hole: USIT Z-102i Permit application Page 2 • • Mud Program: 12-1/4" Surface Hole: Fresh Water S ud Mud Density Viscosity seconds Yield Point Ib/100ft~ API FL mis/30min PH Initial 8.8 - 9.2 300-400+ 50 - 70 NC - 8.0 9.0-9.5 Base PF to TD 9.2 - 9.5 225-250 45 - 60 8.0 9.0-9.5 8-3/4" Intermediate Hole: LSND Interval Density YP PV pH API FL MBT Upper 8.8-9.5 18-24 12-18 9-10 < 6.0 <20 Interval 150' above 10.6 18-28 12-22 9-10 4.0-6.0 <20 Top of HRZ to TD 6-1/8" Production Hole: FloPro NT Reservoir Drill-in Fluid Interval Density YP PV pH LSRV (cP) Modified HTHP @200°F (20 micron disk) Milling @ 10.1 30-40 10-18 9-10 30,000 4.0-6.0 7702' 7702' to TD 10.1 20-24 10-18 9-10 20,000 4.0-6.0 Casing/Tubin Pro ram: Hole Size Csg/ Tb O.D. Wt/Ft Grade Connection Length Top MDl1'VD Btm MDlTVD bkb 42" Insulated 20" 91.5 H-40 WLD 80' GL 108' / 108' 12-1/4" 9-5/8" 40 L-80 BTC 3,476' GL 3,476' / 3,131' $-3/4" 7" 26 L-80 TC-II 8,093' GL 8,093' / 6,781' 6-1/8" 4-1/2" 12.6 L-80 IBT-M 1,981' 7603' 9584' / 6,563' Tubin 4-1/2" 12.6 L-80 TC-II 7,440 GL 7,440' / 6,455' Tubin 3-1/2" 9.2 L-80 TC-II 122' 7,440' 7,562' / 6,516' Tubin 2-7/8" 6.4 L-80 HYD 511 330' 7,562' 7,892' / 6,681' Integrity Testing: Test Point Depth Test Type EMW Surface Casin Shoe 20' - 50' from surface shoe LOT Expected >12.4 pp Test Point Depth Test Type EMW Intermediate Casin Window 20' - 50' from Window FIT Expected >11.5 p Z-1021 Permit application Page 3 r Cement Calculations: • Surface Casing: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casino Size 9-5/8" Surface String Basis: Lead: Based on conductor set at 108', 2018' of annulus in the permafrost @ 250% excess and 458' of open hole from top of tail slurry to base permafrost C~ 30% excess. Lead TOC: To surface Tail: Based on 1,000' MD above the casing shoe + 30% excess + 80' shoe track volume. Tail TOC: At 2,476' MD Total Cement Volume: Lead 451 bbl / 564 sks of Schlumberger Arctic SET Lite 10.5 ppg and 4.49 cuft/sk. Tail 79 bbl / 380 sks of Schlumberger Neat"G" + Durastone at 15.8 ppq and 1.16 cuft/sk. Intermediate Casin Casin Size 7" Intermediate Basis: Lead: Based on 2,477' of open hole with 30% excess. Lead TOC: At 4,476' MD (1,000' MD below surface casing shoe). Tail: Based on 80' shoe track volume and 1,000' above shoe with 30% excess. Tail TOC: 500' MD above the TKUP Total Cement Volume: Lead 91 bbl / 338 sks of Dowell LiteCrete at 12.5 at 1.52 cf/sk Tail 39 bbl / 188 sks of Dowell Premium `G' w/ latex at 15.8 ppg and 1.17 cf/sk. Production Liner: Casino Size 4.5" Prod. Liner Basis: Tail: Based on 80' shoe track + 2,000' of liner in open hole with 40% excess + 100' liner lap + 200' DP x 7" casing annulus. Tail TOC: 200' MD above liner la . Total Cement Volume: Tail 52 bbl / 251 sks of Dowell Premium `G' w/ latex at 15.8 ppg and 1.17 cf/sk. Z-102i Permit application Page 4 ~ • Formation To s(TVDss) and Estimated Pore Pressures Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation (TVDss) (feet) (Yes/No) (Psi) (p EMW) Gl -265 +!- 30' No 119 8.7 SV6 -1015 +/- 30' No 457 8.7 SV5 -1660 +/- 30' No 747 8.7 BPRF -1810 +/- 30' No 815 8.7 SV4 -1790 +/- 30' Yes - h drates 806 8.7 SV3 -2310 +/- 30' Yes - h drates 1040 8.7 SV2 -2500 +f- 30' Yes - h drates 1125 8.7 SVl -2830 +/- 30' Yes - h drates 1274 8.7 UG4 -3130 +/- 30' No -thin coal 1409 8.7 UG4A -3170 +/- 30' Mostly wet w/ poss. residual heavy oil (3170-3240'88) 1427 8.7 UG3 -3460 +/- 30' No -thin coals 1557 8.7 UGl -3920 +/- 30' Heavy oil (3920-4040' 5S) 1764 8.7 Fault #1 -3970 +/- 150' 1787 8.7 UG MA -4060 +/- 50' No 1827 8.7 UG MC -4200 +/- 50' No 1890 8.7 SB NA -4245 +/- 30' Yes 1910 8.7 SB NB -4270 +/- 30' No 1922 8.7 SB NC -4310 +/- 30' No 1940 8.7 SB OA -4435 +/- 30' Yes 1974 8.6 SB_OBa -4495 +/- 30' Yes 2000 8.6 SB OBb -4530 +/- 30' Yes 2016 8.6 SB OBc -4590 +/- 30' Yes 2043 8.6 SB OBd -4640 +/- 30' Yes 2065 8.6 SB OBe -4695 +/- 30' No 2089 8.6 5B OBf -4735 +/- 30' No 2107 8.6 SB OBF BASE -4785 +/- 30' No 2129 8.6 CM2 -5140 +/- 50' No CMl -5780 +/- 30' No TLBK -6070 +/- 30' No THRZ -6240 +!- 30' No TKLB -6470 +/- 30' No K-1 -6480 +/- 30' No TKC4 -6500 +!- 30' Yes - GaslOil 3070 9.2 TKB_LCU (Ku B) -6545 +/- 30' No 3294 9.8 TKAS -6580 +/- 30' Yes -Gas/Oil .3311 9.8 TKA4 -6605 +/- 30' No 3324 9.8 TMLV -6635 +/- 30' No Z-1021 Permit application Page 5 • • Well Control Surface hole will be drilled with a diverter. The production hole section will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Anticipated surface pressures will not exceed 3,OOOpsi, therefore it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency will be 14 days, with a function test every 7 days. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval- • Maximum anticipated BHP: 3,324 psi C«~ 6686' TVD -Kuparuk River A4 • Maximum surface pressure: 2,655 psi @ surface (based on BHP and a full column of gas from TD C~ 0.10 psi/ft) Production Interval- s Maximum anticipated BHP: 3,311 psi C«3 6580' TVD -Kuparuk River A5 • Maximum surface pressure: 2,653 psi @ surface (based on BHP and a full column of gas from TD C«~ 0.10 psi/ft) • Planned BOP test pressure: 250 / 4,000 ps ~ b~~ ®~~` Q~e`~~~ ~'~'`4Z~0'S~~~ ~SSv~.~. • Planned completion fluid: 10.0 ppg brine / 6.8 ppg diesel (3,500' TVD) ~~~~ Kick Tolerance / Int ri Testin Summa Table Casing /Interval Casing Test Maximum Influx Mud Exp Pore LOT /FIT Pressure Volume Wei ht Press Surface Interval 3,500 si NA NA NA NA Intermediate Interval 4,000 psi 54 BBLS (w/ 12.4 LOT) 10.6 9.8 (Kup B) LOT 29 BBLS w/11.3 LOT Production Interval 4,000 si Infinite w/ 11.5 FIT 10.1 9.8 Ku B FIT 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 casing string Development wells may have "kick tolerances" in the 25 bbl range. A heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. Variance Request / • To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. • To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Z-1021 Permit application Page 6 • • Z-102i DRAFT D&C PROCEDURE SUMMARY Pre-Riq Work: The 20" insulated conductor is installed. 1. Weld an FMC landing ring for the FMC Ultra slimhole well head on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Prepare neighboring wells for the rig move and sim-ops production. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Riq Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool & riser. Function test. PU 4" DP as required and stand back in derrick. 2. MU 12-1/a" drilling assembly with Dir/MWD/GR and directionally drill surface hole to approximately 3,476- ft MD /3,131-ft TVD. The actual surface hole TD will be +/-220-ft TVD below the top of the SV1 sand. 3. Run and cement the 9 5/", 40# L-80 surface casing back to surface. A TAM port collar will be run based on hole conditions and will be positioned at ^ 1,000-ft as contingency in the event cement does not fully circulate to surface. Bump plug and test casing to 3,500 psi for 30 minutes. a. NOTE: Ensure surface casing pup below the hanger is Bakerlok'd to the hanger. 4. ND drilling spool and riser and NU casing /tubing head. NU BOPE and test to 4,000 psi. PU additional 4" DP as needed. 5. MU 8-3/a" directional drilling assembly with MWD / GR / RES /PWD/NeuDen /Sonic /Stethoscope and a Weatherford Ghost reamer at ±2,300' from the bit and RIH to float collar while PU 4" DP. 6. Drill out shoe track. Circulate and condition mud. Displace well to new 8.8 ppg LSND drilling fluid. Drill 20' of new formation below rathole and perform an LOT. Establish clean hole PWD ECD baseline. a. NOTE: Notify ODE if 12.4 ppg LOT is not obtained. 7. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.6 ppg and perform short trip as needed. Hold a pre-reservoir meeting highlighting kick tolerance and detection. Continue drilling to TD maintaining sail angle & direction to 130-ft MD below the top Miluveach at 8,093-ft MD / 6,781-ft TVD. 8. Utilize Schlumberger Stethoscope tool to acquire 20 pressure samples in the Kuparuk A & C-sands as per the Wellsite Geologist. Conduct MAD passes as necessary. Clean up the hole and POOH and LD BHA. Retrieve bowl protector. 9. Run and cement the 7", 26#, L-80, TCII intermediate casing. Note: Torque turn 7" TC-II threaded casing. Displace the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Confirm 500 psi cement compressive strength prior to freeze protecting. Freeze protect the 7" x 9 5/8" annulus. a. NOTE: Ensure 7" IBT-M x TCII XO pup below the hanger is Bakerlok'd to the hanger. 10. PU Baker G2 mills, whipsock, and appropriate amount of space-out tubulars and RIH and set whipstock on landing collar. Shear off of whipsotk and displace over to 10.1 ppg FloPro-NT mud. Mill window and ensure 17-ft of open hole is drilled below the center of the window. Conduct FIT to 11.5 ppg EMW. POOH and LD milling assembly. a. NOTE: Set whipstock a minimum of 10-ft MD below top Kuparuk C4 sand 11. PU 6-%8" directional drilling assembly with real time MWD/GR/Res/AIM/AzDen/Neu and Andergauge Agitator RIH to the float collar picking up 4" DP as required. Z-1021 Permit application Page 7 • • 12. Drill the build, land the well, and geosteer through the Kuparuk C sands to TD (9,599' MD / 6,561' TVD) as per the wellsite geologist. Perform wiper trip if needed, circulate and condition mud and POH. Lay down excess drillpipe. 13. MU and run 4-~/z" 12.6# L-80 BTC-M solid liner with 20-ft 4-1/z" x 3-5/" SBR and one short joint with an RA tag 500-ft from TD and cement (ensure 150' overlap). Bump plug with 10 ppg pert pill. PU off liner hanger, set packer and circulate and condition mud. Displace over to 10.0 ppg brine. POOH and lay down liner running tool and innerstring. 14. PU 2.875 and 2.5" tapered perforation assembly, perf 100-ft at the heal and 400-ft at the toe out of 2,000-ft of liner. POH, LD per guns. 15. RU Schlumberger E-line and run GR/JB into the 4-~/z" liner as far as it will go. Run the SCMT and or ,~~' USIT to confirm cement isolation above the Kuparuk reservoir. 16. MU 4-1/z" TCI I x 3-'/z" TCI I x 2 '/8" Hydrill 511 completion assembly with 2 '/8" x 3 5/8" Seal assembly and RIH torque turning each connection. See completion schematic and running detail. Prior to running seal assembly into the SBR, spot corrosion inhibited brine from the SBR to the bottom GLM in the 4-~/z" tubing. a. Tubing Space-out: Position completion via a No-go on the 2'/8" x 5-'/z" locator donut. PU ~10-ft (as per Baker Tubemove) and space out and land tubing hanger. Test hanger pack-off to 5,000 psi. 17. Run in the lockdown screws, drop RHC ball and rod with rollers and set packer as per Baker recommendation and test tubing to 4,000 psi and annulus to 4,000 psi. Give the AOGCC 24 hrs notice prior to testing. Shear DCK-2 valve and pump both ways to confirm circulation ability. a. NOTE: It will not be possible to circulate the ball and rod on seat once the completion is landed and the seals are in the SBR. 18. Install FMC TWC and test from below to 1,000 psi. ND the BOPE. NU and test the tree to 5,000 psi. 19. Pull TWC. Freeze protect the well to 3,500-ft TVD by first pumping 63 bbls of corrosion inhibited brine down the IA with the rig pumps followed by 135 bbls of diesel down the IA with Hot Oiler taking clean brine returns. Allow the diesel to U-tube through the tree. 20. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-~/z" annulus valve and secure the well. Assure that IA/OA are both protected with two barriers. 21. Rig down /move off Nabors 9ES. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod /RHC plug. 2. Replace the DCR shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. 5. Install wellhouse and flowlines. Z-1021 Permit application Page 8 • • POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: Interval Psi EMW TVDss Schrader, OA 1974 8.6 4,435 Ku aruk B 3294 9.8 6,545 II. Hydrates and Shallow gas: A. Gas Hydrates are expected at Z-Pad near the base of the permafrost. Setting casing through the SVi should keep hydrate exposure from extending past the surface hole. Recommended practices for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. III. Lost Circulation /Breathing: A. Lost circulation risk is considered low. Follow Loss Circulation Decision Tree if losses occur. IV. Kick Tolerance /Integrity Testing: A. The 9-5/8"casing will be cemented to surface. The 7" casing will be cemented to within 1,000' MD of the surface casing shoe. Kick Tolerance / Int rit Testin Summar Table Casing /Interval Casing Test Pressure Maximum Influx Valume Mud Wei ht Exp Pore Press LOT /FIT Surface Interval 3,500 si NA NA NA NA Intermediate Interval 4,000 psi 54 BBLS (w/ 12.4 LOT) 29 BBLS w/11.3 LOT 10.6 9.8 (Kup B) LOT Production Interval 4,000 psi Infinite (w/ 11.5 FIT) 10.1 9.8 Ku B) FIT V. Hole instability in Surface Hole A. Running gravels could be an issue when drilling the surface hole. Maintain drilling parameters and mud properties when drilling this interval. High mud viscosity is critical. VI. Hydrogen Sulfide A. Z-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. HgS Summary Table Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level Z-27 NA NA #2 Closest SHL Well H2S Level Z-28 NA NA #1 Closest BHL Well H2S Level Z-108 0 ppm 7/14/2006 #2 Closest BHL Well H2S Level Z-05 10 ppm 1/28/2005 Max. Recorded H2S on Pad/Facilit Other Relevant H2S Data (H2S alarms from rigs, etc.) The only H2S measured at Borealis is associated with miscible injection (MI.) Closest MI is Z-02, 1360' to the east of toe, and in the Ivishak. VII. Fault Details Fault #1 Lower UG1 4,450' MD 3,970' TVDss 180' throw SW +/- 150 ft MD uncertaint CONSULT THE Z-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Z-102i Permit application Page 9 Area of Review - Z-1021 Revised April 10, 2007 This Area of Review for Z-1021 will discuss the wells that are within '/a mile of this injection well BHL. There will be no annular disposal in Z-102i, so that will not be an issue for discussion. Z-1021 is proposed as a WAG injection well with MI injection planned in the future. There are 7 wells that come within '/a mile of Z-102i's target location at the top Kuparuk. The following table displays the 7 wells within'/a mile, their distance from Z-1021, and any annulus integrity comments based on an in depth analysis of each well: Well Name Dist, Ft. Annulus Inte rit Comments Z-05 160 ft. TOC calculated to be above injection zone. Z-06 340 ft. 50-75% Lost Returns during Cement Job. Unable to tell where losses occur. TOC inconclusive. Many lost returns while drilling from 5000' down to 8000'. Z-04 690 ft. TOC calculated to be above injection zone. Z-09 1,130 ft. TOC calculated to be above injection zone. Highland State 1 1,340 ft. Pumped additiona1551 cu ft cmt through FO sleeves at 2653' and 2402'. Saw wet cmt returns to surface. Currently plugged and abandoned. PTD #76-017. Z-02 1,360 ft. USIT Log indicates TOC above Injection Zones. (2 Passes to Confirm) Bond log offers no conclusive evidence of good cement. There is little if any indication of Z-33 1 410 ft. good cement. Based on the high volume of cement pumped, and the change in borehole fluid , density, it would seem possible that a microannulus condition may exist which masks the true cement strength. Cement bond logs were not available for Z-05, Z-06, Z-04, Z-09 and Highland State 1 in the Kuparuk interval. Z-102i will be injecting into the Kuparuk C Sand. Cement bond logs were available for Z-02 and Z-33. The bond log for Z-02 offers no conclusive evidence of good cement across the injection zone. However, the calculated TOC was well above the zone of injection. With the high volume of cement pumped and the change in borehole fluid density, it seems possible that amicro-annulus exists which masks the true cement strength. Z-33's USIT log indicates good cement across the Kuparuk. For Z-05, Z-04, and Z-09, the TOC was calculated using the daily drilling logs found in the original well files. All of these wells recorded no losses during the cement job. The calculations are based on the cement volumes pumped with 30% excess in the annular space. Z-06 was the only well which experienced large losses during the cement job. An estimated 50-75% of returns were lost during the cement job. Losses began and were most prevalent during drilling operations between 5,000' and 8,000'. It is likely that Z-06 does not have cement integrity across the Kuparuk. As a result of this, Z-06 will be monitored in order to determine if injection fluids are migrating out of zone. The TOC for Highland State 1 was also calculated using the daily drilling logs. Losses were not reported during drilling or cementing. The TOC is calculated to be above the injection zone. Also, two FO sleeves were used on this cement job to pump an additional 551 cu ft of cement, where returns were seen at surface. The well has since been plugged and abandoned. Reference state files for Permit to Drill #76- 017. AOR - Z-1021 1/1 TREE= 4-1/18" W~LHFAD= . • FMC a, - ACTUATOR = LEO KB. REV = -..rT__ 81.3 BF. REV __ _ KOP = 400-ft MD Max Angle = Datum MD Datum TV D = Well Info: Z -1 i P ro p o s e d -11 , M csg head w/7"mandrel hngr & packoff - 11 ", 5M tubing sppol with 11"x4-1/2" tubing hanger - 11"x4-1116", 5M Adaptorflange 20" CONDUCTOR $Q' 1000' 9-5/8" TAM PORT COLLAR 2600' 4-1 /2" HES X NIP, ID = 3.813" 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" H 3,476' 7406' i-17" X 4-1/2" Premier PROD PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3500 KBG2 DMY 3 6000 KBG2 DCK 2 tbd MMGW DMY 1 tbd MMGW DMY 7386' -,4-1/2" HES X NIP, ID = 3.813" 7429' 4-1/2" TBG, 12.6#, L-80 TCII, ID = 3.99" 7440 t0 surface ~ 7440' 4-112" X 3-1 /2" TCII XO, 10= 2.992" Minimum ID = 2.44" @ 3-1/2" X 2-7/8" XO Q 7518' 3-112" Baker CMD SLIDING SLV, ID = 2.813'" 3~1/Z' ~..-~ 92#, L-~l~l, .O~lt~f, ~2~' I 1 7541' 3-112" HES XN NIP, ID = 2.725" 3-1 /2"TCII X 2-7/8" Hyd 511 XO, ID= 2.44" I -with 5-112" Inr_.atnr dnni it w irh mill clntts n 7562' 7,603' 7" X 5" BKR ZXP PKR &LNR HGR w/TIEBACK SLV, ID = 4.410" 2-7/8" TBG, 6.4#, L-80 HYD 511, ID = 2.441" 7922 to 7562' 7" BKR WHIPSTOCK TOP 7,703' r 7872-7892 ~ 20' Baker 4-1/2" x 3-5/8" SBR ~ 7" PBTD (Landing Collar) 8013' MD / 7922' 2-7/8" Half mule shoe joint 7" CSG, 26#, L-80 TCII, .0383 bpf, ID = 6.276" 8093' PERFORATION SUMMARY REF LOG: LWD ON ANGLE AT TOP PERF: @ ' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 2-112" 6 7702-7772 O 2-1/2" 6 -400-ft O 2-1/2" 6 O TBD -{ MARKERJT I W/ RA TAG PBTD 9,504' 4-1/2" LNR, 12.6 #, L-80 IBT-M, ID = 3.958" 9584' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/11/07 MTT Proposed Completion Borealis Unit WELL: Z-102 PERMIT No: API No: 50-029- SEC 19, T11 N, R12E, 4,565' FSL & 3,542' FEL BP Exploration (Alaska) by Z-102P61 (P6) Proposal Schlumberger Report Date: March 20, 2007 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Vertical Section Azimuth: O'OZ Vertical Section Origin: 190.000° N 0.000 ft, E 0.000 ft Structure I Slot: Z-PAD! Z-102 /~ O~ TVD Reference Datum: Rotary Table Weli: Plan Z-102 (27.5) ~OVerM ND Reference Elevation: 81.30 R relative to MSL Borehole: Plan Z-102P61 ppp Sea Bed I Ground Level Elevation: 52.80 ft relative to MSL UWIIAPI#: 50029 Magnetic Declination: 23.701 ° Survey Name 1 Date: Z-102P61(P6) /March 20, 2007 Total Field Strength: 57637.824 nT Tort 1 AHD I DDI 1 ERD ratio: 118.655° / 3806.45 ft / 5.73210.561 Magnetic Dip: 80.884° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: May 10, 2007 Location Lat/Long: N 70 17 54.27946065, W 14911 49.89806275 Magnetic Declination Model: BGGM 2006 Location Grid NIE YIX: N 5959359.680 ftUS, E 599130.960 RUS North Reference: True North Grid Convergence Angle: +0.75581642° Total Corr Mag North •> True North: +23.701 ° Gdd Scale factor: 0.9999111 fi Local Coordinates Referenced 10: Well Head • Measured Vertical Gravity Comments Inclination Azimuth Sub-Sea TVD Typ NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face R de d R R R R R de de 100 R de 1100 R de 100 R RUS RUS RIC V.VV V.VV J~V.VV -OIAU V.UU U.UU U.UU U.UU - U.UU U.UU U.UV byb`JSD`J.Ot3 J`9YISU.`9b IV /U I/ J4.Z/`J4bUbb VV "14`J "Il 4`J.25`925UbZ/b G1 346.30 0.00 350.00 265.00 346.30 0.00 0.00 0.00 -- 0.00 0.00 0.00 5959359.68 599130.96 N 70 17 54.27946065 W 149 11 49.89806275 KOP Bld 1.5/100 400.00 0.00 350.00 318.70 400.00 0.00 0.00 0.00 HS 0.00 0.00 0.00 5959359.68 599130.96 N 70 1754.27946065 W 149 11 49.89806275 Bld 2.5/100 500.00 1.50 350.00 418.69 499.99 -1.23 1.29 -0.23 HS 1.50 1.50 0.00 5959360.97 599130.72 N 70 17 54.29213823 W 149 11 49.90468847 Bld 3/100 600.00 4.00 350.00 518.57 599.87 -5.74 6.01 -1.06 32.26E 2.50 2.50 0.00 5959365.68 599129.82 N 70 17 54.33860381 W 149 11 49.92897290 700.00 6.73 336.21 618.12 699.42 -13.89 14.81 -4.03 18.53E 3.00 2.73 -13.79 5959374.44 599126.73 N 70 17 54.42513409 W 149 11 50.01555385 800.00 9.62 330.50 717.10 798.40 -25.21 27.45 -10.51 12.87E 3.00 2.89 -5.71 5959386.99 599120.09 N 70 17 54.54942403 W 149 11 50.20447099 Crv 3/100 812.93 10.00 330.00 729.84 811.14 -26.90 29.36 -11.60 8.61 L 3.00 2.93 -3.85 5959388.88 599118.97 N 70 1754.56823631 W 149 11 50.23634803 900.00 12.59 328.21 815.21 896.51 -39.77 43.98 -20.39 6.85E 3.00 2.97 -2.06 5959403.38 599110.00 N 70 17 54.71196419 W 149 11 50.49230600 1000.00 15.57 326.87 912.20 993.50 -57.69 64.48 -33.46 5.56E 3.00 2.98 -1.33 5959423.71 599096.65 N 70 1754.91365228 W 149 11 50.87358259 1100.00 18.56 325.96 1007.79 1089.09 -78.93 88.92 -49.71 4.68E 3.00 2.99 -0.91 5959447.93 599080.08 N 70 17 55.15395367 W 149 11 51.34719309 SV6 1107.62 18.79 325.90 1015.00 1096.30 -80.69 90.94 -51.08 4.63E 3.00 2.99 -0.76 5959449.93 599078.69 N 70 17 55.17381695 W 149 11 51.38700709 1200.00 21.55 325.29 1101.71 1183.01 -103.43 117.21 -69.08 4.06E 3.00 2.99 -0.66 5959475.96 599060.35 N 70 17 55.43220950 W 149 11 51.91184097 1300.00 24.54 324.78 1193.72 1275.02 -131.12 149.28 -91.52 3.59E 3.00 2.99 -0.51 5959507.73 599037.49 N 70 17 55.74765686 W 149 11 52.5659 1400.00 27.54 324.38 1283.56 1364.86 -161.93 185.05 -116.97 3.22E 3.00 2.99 -0.41 5959543.16 599011.57 N 70 17 56.09943087 8 W 149 11 53.30782 1500.00 30.53 324.05 1370.98 1452.28 -195.77 224.42 -145.35 2.93E 3.00 3.00 -0.33 5959582.14 598982.67 N 70 17 56.48656704 W 149 11 54.13533072 End Crv 1552.96 32.12 323.89 1416.22 1497.52 -214.88 246.68 -161.55 --- 3.00 3.00 -0.29 5959604.19 598966.18 N 70 17 56.70556181 W 149 11 54.60752175 SV5 1840.81 32.12 323.89 1660.00 1741.30 -321.00 370.34 -251.74 -- 0.00 0.00 0.00 5959726.63 598874.38 N 70 17 57.92166039 W 149 11 57.23690057 SV4 1994.30 32.12 323.89 1790.00 1871.30 -377.58 436.28 -299.84 -- 0.00 0.00 0.00 5959791.92 598825.42 N 70 17 58.57015117 W 149 11 58.63907501 Base Perm 2017.92 32.12 323.89 1810.00 1891.30 -386.29 446.42 -307.24 --- 0.00 0.00 0.00 5959801.97 598817.89 N 70 17 58.66991871 W 149 11 58.85479634 S V3 2608.29 32.12 323.89 2310.00 2391.30 -603.93 700.03 -492.22 -- 0.00 0.00 0.00 5960053.10 598629.59 N 70 18 1.16408401 W 149 12 4.24801871 SV2 2832.63 32.12 323.89 2500.00 2581.30 -686.63 796.41 -562.52 -- 0.00 0.00 0.00 5960148.53 598558.04 N 70 18 2.11185508 W 149 12 6.29753861 SV 1 3222.28 32.12 323.89 2830.00 2911.30 -830.27 963.79 -684.61 --- 0.00 0.00 0.00 5960314.27 598433.76 N 70 18 3.75796842 W 149 12 9.85735593 Crv 4/100 3296.26 32.12 323.89 2892.66 2973.96 -857.54 995.57 -707.79 174.89E 0.00 0.00 0.00 5960345.74 598410.17 N 70 18 4.07052212 W 149 12 10.53329443 3300.00 31.97 323.87 2895.83 2977.13 -858.92 997.18 -708.96 174.86E 4.00 -3.98 -0.67 5960347.33 598408.98 N 70 18 4.08628430 W 149 12 10.56739812 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-102\Plan Z-102 (27.5)tPlan Z-102PB1~Z-102P61 (P6) Generated 4/12/2007 9:13 AM Page 1 of 3 Measured Vertical Gravity Comments Iodination Azimuth Subsea ND TVD NS EW DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft d de ft ft ft ft ft de de 100 ft d 100 ft de 100 ft ftUS ftUS 34UU.UU Z/.`J~~J 323.11 Z`JSZ.43 3U63./3 -S~J3.31 lV3 /.34 -/35.6/ 7/4 .ZUL 4.UU -3.815 -U./6 6`J6U35 /.7U b5i53/5./4 N /U 15 4.451 Y5`J`J/ VV l4`J 7Z 11.433/Z6Z`J 9-5/8" Csg Pt 3475.50 24.99 322.38 3050.00 3131.30 -916.18 1064.15 -759.04 173. 56E 4.00 -3.98 -0.96 5960413.63 598358.01 N 70 18 4.74492449 W 149 12 12.02783912 3500.00 24.01 322.11 3072.29 3153.59 -923.01 1072.18 -765.26 173 .31 L 4.00 -3.97 -1.10 5960421.58 598351.69 N 70 18 4.82391570 W 149 12 12.20917815 UG4 3562.59 21.53 321.32 3130.00 3211.30 -939.13 1091.20 -780.26 172. 58E 4.00 -3.97 -1.27 5960440.40 598336.44 N 70 18 5.01096752 W 149 12 12.64661123 3600.00 20.05 320.76 3164.97 3246.27 -947.85 1101.53 -788.61 172 .05E 4.00 -3.96 -1.51 5960450.61 598327.96 N 70 18 5.11249258 W 149 12 12.88997281 UG4A 3605.35 19.83 320.67 3170.00 3251.30 -949.04 1102.94 -789.77 171. 97E 4.00 -3.96 -1.63 5960452.01 598326.79 N 70 18 5.12637980 W 149 12 12.92366122 End Crv 3627.13 18.97 320.29 3190.54 3271.84 -953.74 1108.52 -794.37 --- 4.00 -3.96 -1.72 5960457.53 598322.11 N 70 18 5.18127378 W 149 12 13.05790644 Fit Tgt 1 3637.13 18.97 320.29 3200.00 3281.30 -955.84 1111.02 -796.45 -- 0.00 0.00 0.00 5960460.00 598320.00 N 70 18 5.20587023 W 149 12 13.11846807 UG3 3912.07 18.97 320.29 3460.00 3541.30 -1013.65 1179.79 -853.55 -- 0.00 0.00 0.00 5960528.00 598262.00 N 70 18 5.88211152 W 149 12 14.78353728 UG 1 4398.49 18.97 320.29 3920.00 4001.30 -1115.92 1301.45 -954.58 --- 0.00 0.00 0.00 5960648.31 598159.38 N 70 18 7.07852797 W 149 12 17.72950358 Flt Crossing 4451.36 18.97 320.29 3970.00 4051.30 -1127.03 1314.67 -965.56 -- 0.00 0.00 0.00 5960661.38 598148.23 N 70 18 7.20857230 W 149 12 18.04972275 Ma 4546.53 18.97 320.29 4060.00 4141.30 -1147.04 1338.48 -985.33 --- 0.00 0.00 0.00 5960684.92 598128.15 N 70 18 7.44265194 W 149 12 18.6261 Mc 4694.57 18.97 320.29 4200.00 4281.30 -1178.17 1375.50 -1016.07 - 0.00 0.00 0.00 5960721.54 598096.92 N 70 18 7.80677428 W 149 12 19.522 Na 4742.16 18.97 320.29 4245.00 4326.30 -1188.17 1387.41 -1025.96 -- 0.00 0.00 0.00 5960733.31 598086.88 N 70 18 7.92381351 W 149 12 19.8109 Nb 4768.59 18.97 320.29 4270.00 4351.30 -1193.73 1394.02 -1031.45 -- 0.00 0.00 0.00 5960739.85 598081.31 N 70 18 7.98883525 W 149 12 19.97106200 Nc 4810.89 18.97 320.29 4310.00 4391.30 -1202.62 1404.60 -1040.23 -- 0.00 0.00 0.00 5960750.31 598072.38 N 70 18 8.09286995 W 149 12 20.22724380 OA 4943.07 18.97 320.29 4435.00 4516.30 -1230.42 1437.66 -1067.69 -- 0.00 0.00 0.00 5960783.00 598044.50 N 70 18 8.41797824 W 149 12 21.02781782 OBa 5006.52 18.97 320.29 4495.00 4576.30 -1243.75 1453.53 -1080.86 -- 0.00 0.00 0.00 5960798.69 598031.12 N 70 18 8.57402962 W 149 12 21.41209525 Fit Tgt 2 5011.81 18.97 320.29 4500.00 4581.30 -1244.87 1454.85 -1081.96 -- 0.00 0.00 0.00 5960800.00 598030.00 N 70 18 8.58703389 W 149 12 21.44411844 Crv 4/100 5021.81 18.97 320.29 4509.46 4590.76 -1246.97 1457.35 -1084.04 113 .63E 0.00 0.00 0.00 5960802.47 598027.89 N 70 18 8.61162956 W 149 12 21.50468565 OBb 5043.51 18.64 317.80 4530.00 4611.30 -1251.38 1462.63 -1088.62 111. 28E 4.00 -1.53 -11.47 5960807.70 598023.24 N 70 18 8.66358536 W 149 12 21.63833591 5100.00 17.94 310.95 4583.64 4664.94 -1261.39 1475.03 -1101.26 104 .77E 4.00 -1.24 -12.13 5960819.92 598010.44 N 70 18 8.78545054 W 149 12 22.00681403 OBc 5106.68 17.87 310.11 4590.00 4671.30 -1262.43 1476.36 -1102.82 103. 97E 4.00 -0.99 -12.60 5960821.23 598008.86 N 70 18 8.79857620 W 149 12 22.05233255 OBd 5159.15 17.48 303.32 4640.00 4721.30 -1269.59 1485.88 -1115.57 97. 50E 4.00 -0.75 -12.95 5960830.58 597995.99 N 70 18 8.89217038 W 149 12 22.42399653 5200.00 17.34 297.88 4678.98 4760.28 -1273.89 1492.10 -1126.08 92 .31 L 4.00 -0.34 -13.32 5960836.66 597985.40 N 70 18 8.95329841 W 149 12 22.73043209 OBe 5216.78 17.33 295.62 4695.00 4776.30 -1275.33 1494.35 -1130.54 90. 15E 4.00 -0.09 -13.42 5960838.85 597980.91 N 70 18 8.97542542 W 149 12 22.86062278 OBf 5258.69 17.40 290.01 4735.00 4816.30 -1278.10 1499.19 -1142.06 84. 80E 4.00 0.18 -13.39 5960843.54 597969.33 N 70 18 9.02304404 W 149 12 23.19641470 5300.00 17.63 284.57 4774.40 4855.70 -1279.67 1502.88 -1153.91 79 .61 L 4.00 0.54 -13.17 5960847.07 597957.43 N 70 18 9.05928919 W 149 12 23.54217655 OBf Base 5311.13 17.71 283.13 4785.00 4866.30 -1279.90 1503.69 -1157.19 78. 24E 4.00 0.77 -12.93 5960847.84 597954.14 N 70 18 9.06723388 W 149 12 23.63779052 5400.00 18.75 272.24 4869.43 4950.73 -1278.71 1507.32 -1184.64 67 .89E 4.00 1.17 -12.25 5960851.10 597926.65 N 70 18 9.10290618 W 149 12 24.43809100 5500.00 20.58 261.65 4963.63 5044.93 -1271.00 1505.39 -1218.11 57 .91 L 4.00 1.83 -10.59 5960848.74 597893.21 N 70 18 9.08393654 W 149 12 25.4138 5600.00 22.95 252.93 5056.52 5137.82 -1256.59 1497.12 -1254.15 49 .81 L 4.00 2.37 -8.72 5960839.99 597857.29 N 70 18 9.00247233 W 149 12 0 26.46457 CM2 5691.52 25.45 246.42 5140.00 5221.30 -1237.59 1484.01 -1289.24 43. 87E 4.00 2.74 -7.12 5960826.42 597822.38 N 70 18 8.87348211 W 149 12 27.48762 5700.00 25.70 245.87 5147.65 5228.95 -1235.55 1482.53 -1292.59 43 .38E 4.00 2.90 -6.39 5960824.89 597819.05 N 70 18 8.85891010 W 149 12 27.58526228 5800.00 28.73 240.15 5236.59 5317.89 -1207.97 1461.69 -1333.24 38 .29E 4.00 3.03 -5.72 5960803.53 597778.68 N 70 18 8.65394891 W 149 12 28.77041332 5900.00 31.96 235.47 5322.89 5404.19 -1174.00 1434.72 -1375.90 34 .24E 4,00 3.23 -4.68 5960776.00 597736.38 N 70 18 8.38858697 W 149 12 30.01424873 6000.00 35.33 231.58 5406.14 5487.44 -1133.80 1401.74 -1420.38 31 .00E 4.00 3.37 -3.89 5960742.43 597692.35 N 70 18 8.06411677 W 149 12 31.31070506 End Crv 6071.32 37.80 229.18 5463.42 5544.72 -1101.42 1374.63 -1453.08 --- 4.00 3.46 -3.36 5960714.90 597660.01 N 70 18 7.79745128 W 149 12 32.26401833 Crv 4/100 6421.45 37.80 229.18 5740.08 5821.38 -935.08 1234.35 -1615.47 55 .42E 0.00 0.00 0.00 5960572.51 597499.49 N 70 18 6.41753052 W 149 12 36.99790703 CM1 6472.38 38.99 226.51 5780.00 5861.30 -910.10 1213.12 -1638.91 53. 33E 4.00 2.33 -5.24 5960550.97 597476.34 N 70 18 6.20869154 W 149 12 37.68107640 6500.00 39.65 225.12 5801.37 5882.67 -895.91 1200.93 -1651.46 52 .26E 4.00 2.42 -5.03 5960538.61 597463.96 N 70 18 6.08870306 W 149 12 38.04687032 6600.00 42.20 220.41 5876.93 5958.23 -840.83 1152.82 -1695.86 48 .70E 4.00 2.55 -4.71 5960489.93 597420.19 N 70 18 5.61550312 W 149 12 39.34114130 6700.00 44.92 216.16 5949.41 6030.71 -780.14 1098.72 -1738.48 45 .61 L 4.00 2.72 -4.26 5960435.28 597378.29 N 70 18 5.08332790 W 149 12 40.58347395 6800.00 47.79 212.30 6018.43 6099.73 -714.16 1038.89 -1779.12 42 .95E 4.00 2.87 -3.86 5960374.92 597338.45 N 70 18 4.49477043 W 149 12 41.76781403 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-102\Plan Z-102 (27.5)\Plan Z-102PB1\Z-102P61 (P6) Generated 4/12/2007 9:13 AM Page 2 of 3 Measured VeNwl Gravity Comments Inclination Azimuth Sub-Sea ND ND NS EW DLS Bulkl Rate Walk Rate Northing Easting Latitude Longitude Depth Section Tool Face ft de d ft ft ft ft ft de de 100 ft d 1100 ft de 1100 ft ftUS ftUS I LfS/l Oif/tJ.53 5V.72 209.57 6U/U.UU t)157.3U 6900.00 50.77 208.78 6083.67 6164.97 7000.00 53.85 205.56 6144.81 6226.11 7100.00 57.01 202.58 6201.56 6282.86 THRZ 7172.92 59.36 200.54 6240.00 6321.30 End Crv 7192.73 60.00 200.00 6250.00 6331.30 TKLS 7632.73 60.00 200.00 6470.00 6551.30 K-1 7652.73 60.00 200.00 6480.00 6561.30 TKC4 7692.73 60.00 200.00 6500.00 6581.30 LCU/KupB 7782.73 60.00 200.00 6545.00 6626.30 GOC 7842.73 60.00 200.00 6575.00 6656.30 TKAS 7852.73 60.00 200.00 6580.00 6661.30 TKA4 7902.73 60.00 200.00 6605.00 6686.30 7912.73 60.00 200.00 6610.00 6691.30 TMLV 7962.73 60.00 200.00 6635.00 6716.30 OWC 8002.73 60.00 200.00 6655.00 6736.30 FWL 8052.73 60.00 200.00 6680.00 6761.30 TD ! 7" Csg 8092.73 60.00 200.00 6700.00 6781.30 Leval Description: Surface : 4564 FSL 3542 FEL 819 T11N R12E UM Target : 4732 FSL 719 FEL S24 T11 N R11 E UM BHL : 4585 FSL 772 FEL S24 T11N R11E UM -556.64 966.0/ -7609.57 41.12E 4.UU L.9/ -3.55 591iU3L3./1 59 /306. /4 N /U 76:1.99492/71 W 149 1242.65342749 -643.20 973.61 -1817.57 40.65E 4.00 3.02 -3.40 5960309.14 597300.87 N 70 18 3.85269842 W 149 12 42.88839036 -567.61 903.21 -1853.65 38.68E 4.00 3.08 -3.23 5960238.28 597265.73 N 70 18 3.16024032 W 149 12 43.93974298 -487.75 828.03 -1887.18 36.99E 4.00 3.16 -2.98 5960162.67 597233.19 N 70 18 2.42077006 W 149 12 44.91674972 -427.05 770.41 -1909.93 35.91E 4.00 3.22 -2.80 5960104.76 597211.21 N 70 18 1.85396475 W 149 12 45.57956829 -410.22 754.37 -1915.85 --- 4.00 3.25 -2.71 5960088.64 597205.50 N 70 18 1.69620582 W 149 12 45.75211770 -34.96 396.30 -2046.18 --- 0.00 0.00 0.00 5959728.92 597079.92 N 70 17 58.17426580 W 149 12 49.54878437 -17.90 380.02 -2052.11 -- 0.00 0.00 0.00 5959712.57 597074.21 N 70 17 58.01417708 W 149 12 49.72135151 16.21 34747 -2063.95 --- 0.00 0.00 0.00 5959679.86 597062.79 N 70 17 57.69399949 W 149 12 50.06648355 92.97 274.23 -2090.61 -- 0.00 0.00 0.00 5959606.28 597037.10 N 70 17 56.97359922 W 149 12 50.84301969 144.14 225.40 -2108.38 -- 0.00 0.00 0.00 5959557.23 597019.98 N 70 17 56.49332872 W 149 12 51.36070539 152.67 217.26 -2111.35 -- 0.00 0.00 0.00 5959549.05 59701712 N 70 17 56.41328412 W 149 12 51.446 195.31 176.57 -2126.16 -- 0.00 0.00 0.00 5959508.18 597002.85 N 70 17 56.01306092 W 149 12 51.8783 203.84 168.43 -2129.12 -- 0.00 0.00 0.00 5959500.00 597000.00 N 70 17 55.93301938 W 149 12 51.96465622 246.49 12774 -2143.93 -- 0.00 0.00 0.00 5959459.12 596985.73 N 70 17 55.53279270 W 149 12 52.39604983 280.60 95.19 -2155.77 -- 0.00 0.00 0.00 5959426.42 596974.31 N 70 17 55.21261365 W 149 12 52.74115865 323.25 54.50 -2170.58 --- 0.00 0.00 0.00 5959385.54 596960.04 N 70 17 54.81238958 W 149 12 53.17254046 357.36 21.95 -2182.43 -- 0.00 0.00 0.00 5959352.84 596948.63 N 70 17 54.49219513 W 149 12 53.51765869 Northi ng (Y) [ftUS] Eastin g (X) [ftUS] 5959359.68 599130.96 5959500.00 597000.00 5959352.84 596948.63 `~ u WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-102\Plan Z-102 (27.5)\Plan Z-102PB1~Z-102P61 (P6) Generated 4/12/2007 9:13 AM Page 3 of 3 bE Schlumberger WELL Z-102PB1 (P6) FIEID Prudhoe Bay Unit - WOA STRUC TURE Z-PAD fic Paramela~s Surface loralwn NAD11 Rlaeka Slala Planes. Zone 04. US Ferl Miscella neous Motel BGGM 300E GP 80.884' Uala May 10. 2001 Lal N101> SG 2]9 NorlMrp 5955]59 BB IIUS GIIG Lom b I5561fi42' Slob. 2103 TVG Rel. Rdary Ta01a tBt b A a5nve MSLI Ma9 Gec. X33701' f5'. 5189>BnT Lon. W149 tt 49698 Eas51g: SB9t9098 M15 Srale Fact: 05999t1!fiJ2 Plan. 2~t03P811P61 Srvy Gate MarcM1 20. 2001 -2400 -t600 -800 0 800 0 800 1600 2400 O O 00 3200 c I I 0) 0) U 0 4000 4800 5600 6400 _ _.._.._.._.._.._.._.._ _ ._.._..___ __._.___ _ v~.._.._.._.._.._. _.._.._.._.._.._.._.._. _ _.._.._.._.._ Crv 41100 $Vt 9-518" Csg Pt ' ' ~ End Crv ~' .._.. f.._..~..~..~..~.._..-..-.._.._.._.._..9 .._.. :.-.._..~.._.._.._.._.._.._t._..-.._..-..-..-..-..-.. y..-..-..-..-.._ Flt T t 1 4R G3 Flt Crossio .F.-______ _ G1 ._ -..-..-..-..-.._.._.._ _ ._.. _.._.._ a _..-..- _.._..-.._.._.._.._.._. _ _.._.._..-..-..-..-..-. -..-..-..-.._ FIt Tat 2 G _ - - - (P6) -2400 -1600 -800 0 800 Vertical Section (ft) Azim = 190°, Scale = 1(in):800(ft) Origin = 0 N/-S, 0 E/-V 0 800 1600 2400 3200 4000 4800 5600 6400 O G ~ ao a a N z ~ s R ~o s°~ gg' C ~ ~ F~ ass O M o ~ $ '.° BR a. ~Yo O S~A ~ O O m ~ ~ ~ ±+ ~ ~ ~~ ~ 99 3R~ m ~F ~w O N Z L a A° ~_ ~~~ o O 8. O O ~ ~o a m n m o a N O ~ O O N ~~ ~~ 3 N ~~ • O O O O O N N O r ~ O • O O O O tD M ~ O O O O O C IA N O O M O O O O O (D n A n O w O ~~ O O M C (0 O U O (n N ~~ V V v 0 0 _o N Plan Z-102 (27.5)/Plan Z-102PB1 000 000 000 5 60~~ .~~~0 - -- - PIanZ-102PB1 I ~ KUPARUK PIPELINE 38 ^ Z e 17 0 1a a 37 ^ Op °O ~O 35 ^ Z-PAD 34 ^ - ~ GRID g ^ ^ 33 8 ^ ^ 3L I 1s ~ROJECT AREA 20 7 ^ ^ 3' 6 ^ ^ 30 A n~N 5 ^ i 29 210 L E SEND VICINITY MAP 4 ^ Z - ~ 1721 ^ 2 a N.T.S. 3 ^ ~ I 27 $ AS-BUILT WELL CONDUCTOR SPARE-D 2 ^ SPARE-B SPARE-C --- ^ ~x;sriNC wELL coNDUCTOR 1 ^ SPARE-A ,031 P-5G4A ' ^ P-5o4~ RENAMED CONDUTOR REVISION NOTE WELLS Z-102i, Z-104i, Z-106i, Z-111 i& Z-1141 -- -, THIS AS-BUILT DRAWING IS A REISSUE OF PREVIOUS AS-BUILT DRAWINGS FOR CONDUCTORS ^ 2~ Z-102i, Z-1041, Z-106i, Z-111 i& Z-114i. , ^ 22 RENAMED CONDUCTORS AREAS FOLLOWS: 30 ^ ,1 ^ ^ 23 OLD COND. NAME NEW COND. NAME ^ 12 ^ 24 ; ' Z-114i Z-102i ^ ~ 2.~ Z-102i SPARE-A 1 3 ^ Z-1041 SPARE-B 14 ^ Z-106i SPARE-C , ^ 15 ^ Sloi 2 ^ Sot 1 Z-111i SPARE-D , Slci 4t Z-1GC Z-PAD ,~~ OF q~ °°°° °°° '<P°°° °qS',~ SURVEYOR'S CERTIFICATE NOTES ~ ° °"9 I HEREBY CERTIFY THAT I AM 1. REFERENCE FIELD BOOKS: WOOa-13 WOOa-16 WOOa-19. ~ _° 49 T-" °o sir PROPERLY REGISTERED AND LICENSED , , 2. DATES OF SURVEY: SEPT., NOV.&DEC.,2004. °°°~_°°°°°°°°°°°°°°°°°°°°°°_°°° TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, THIS PLAT REPRESENTS A SURVEY NAD-27. ° ° ° °°°a°°°°°°°°°°°°°°°°°°°°°°°a MADE BY ME OR UNDER MY DIRECT 4. PAD AVERAGE SCALE FACTOR IS 0.999911213. Richard F. AIIiSOrt ~ $ SUPERVISION AND THAT ALL ~ ° 5. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL °° ~ DIMENSIONS AND OTHER DETAILS ARE ~ 10608 `~F ° ust 16 2005 °5~ CORRECT AS OF Au MONUMENTS MON 2 AND MON 3. ° , °° , g . ~ °° 6. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. ° ° ° ° ° ° °`~,P~ ~ 7. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTATION. ESSICNA~ LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 1?_ E., UMIAT MERIDIAN, ALASKA WELL A.Q.P. PLANT GEODETIC GEGDETiC C ~ LLAR SEC TION N0. COORDINATES COORDINATES '~OSITIC!\(DMS) PCS1T!ON(D.D~J) BOX ELEV. OErSETS 1021 Z Y=5,959,359.68 N= 2,174.06 70° 'J'S4.279' 70.2984108° 2 8 4,565' FSL - X= 599,130.96 -= 2,129.70 149° 11'49.898" 149.1971939° 5 . 3,542' EEL SPAsREA Y=5,959,350.08 N= 2,081.9" 70° `7'54.771' 70.2984086° 54 2' x,563' 'ESL ' X= 599,223.10 E= 2,130.09 i49° 11'47.212' 149.1964478' . EEL 3,450 S?AREa Y=5,959,359.89 N= 2,112.08 70° 17'54.274' 70.2984094' 54 5' 4,504` ESL ' X= 599,192.93 E= 2,'29.91 149° 1 ;'48.091' 149.1966919° . FEL 3,480 Y=5,959,359.76 N= 2,127.18 70' 17'54.274' 70.2984094° ' 4,564' SL SPARE-C X= 599,177.83 -= 2,129.78 1~9° 11'48.532' 149.1968144° 53.8 3,495" EEL SPARE-D Y=5,959,360.13 N= 2,142.49 70° 17'54.280" ' " 70.2984111° 53 5' 4,564' ESL ' X= 599,162.52 E= 2,130.15 149° 11 48.978 149."~~969383° . 3,5"'~'~ EEL F. Robert °N"A""" JACOBS CHECKED by FENTIE O DATE'. 12115/04 DRAWING'. SHEET: FRRDS WOZD2-00 GREATER PRUDHOE BAY Z-PAD ~ ((~~((~~11 ((~~ roe No- ~ anaios RENAMEDCONDUCfoRSASNOTED .u ioH ®~ aUUOO l~0 s~E. RENAMED AS-BUILT CONDUCTORS o ivisoa IssuEOFDRwFOR~wTi~ .u JNF WELLS Z-1021, SPARE-A, B, C 8 D 1 of 1 NO. DATE REVISION BV CH .~~~u~. uaw. cw ~~~ • Oilfield Services, Alaska Schlumberger Drilling & Measurements Schlumberger 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Thursday, April 12, 2007 Mike Triolo Prudhoe Bay Z-102P61 (P6) BP Exploration (Alaska) Inc. Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Prooram: Instrument Type Start Depth End Depth GYD GC SS 28.50'md 1000.00'md MWD 1000.00'md 2400.00'md MWD + IFR + MS 1000.00'md 8092.73'md Close Approach Analysis results: Under method (2), note. All wells pass major risk. Global scan has been applied, and then modified by survey specialist to include all wells on Z-Pad. All data documenting .these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drillino Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 04/12/07 BP Alaska Anticollision Report I Company: BP Amoco Field: Prudhoe Bay Reference Site: PB Z Pad . Reference Wells. .Plan Z-102 (27.5} i Reference Wellpatti: Plan Z-102PB1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 5.00 ft ~ Depth Range: 28.50 to 8092.73 ft Maximum Radius:10000.00 ft Survey Program for Definitive Welipath ~, Date: 12/7/2006 Validated: No ~I Planned From 1'o Survey ft ft ~', 28.50 1000.00 Planned: Plan #6 V1 1000.00 2400.00 Planned: Ptan #6 V1 1000.00 3410.00 Planned: Plan #6 V1 ' 3410.00 8092.73 Planned: Plan #6 V1 Casing Points ~' MD TVD Diameter Hp1e Size ft ft in in ' 3475.50 3131.30 9.625 12.250 8092.73 6781.30 7.000 8.750 Summary Date: 3/20/2007 Time: 11:53:37 Page: ] ~ Co-ordinate(NE) Reference: Well: Plan Z-102 (27.5), True Noih ~ Vcrdcal (TVD)Refefencc: Z-102 Plan 81.3 Db: Oracle Reference: Principal Plan & PLANNED PROGRAM ' Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing i Version: 5 Toolcode Tool Name GYD-GC-SS Gyrodata gyro single shots MWD MWD -Standard MWD+IFR+MS MWD +IFR + Multi Station MWD+IFR+MS MWD +IFR + Multi Station Name ~ i 9 5/8" 7" --------------- offset Welipath -----= Reference Offset Ctr-Ctr No-Go Allowable Site WeA. Welipath MD MD Distance Area Deviation Warning ft ft ft ft ~,' i ', PB Z Pad -Exp V2 2d'lan Ivi Z-34 (SF) Plan Z-34 V1 Plan: Pla 393.79 395.00 827.30 7.11 820.18 Pass: Major Risk PB Z Pad -Exp V2 2~lan Ivi Z-40 (SK) Plan Z-40 V1 Plan: Pla 368.80 370.00 908.21 6.67 901.54 Pass: Major Risk ', PB Z Pad -Exp V2 20~1an Ivi Z-41 (SC) Plan Z-41 V2 Plan: Pla 507.21 520.00 775.32 9.17 766.15 Pass: Major Risk PB Z Pad -Exp V2 2~lan Ivi Z-42 (SJ) Plan Z-42 V2 Plan: Pla 515.15 530.00 894.13 9.31 884.82 Pass: Major Risk PB Z Pad -Exp V2 2~lan Ivi Z-44 (NF) Plan Z-44 V1 Plan: Pla 541.12 555.00 805.41 9.77 795.65 Pass: Major Risk ' PB Z Pad -Exp V2 2~lan Ivi Z-45 (SO) Plan Z-45 V1 Plan: Pla 522.69 540.00 1048.32 9.45 1038.87 Pass: Major Risk I. PB Z Pad -Exp V2 20'lan Ivi Z-55 (SB) Plan Z-55 V2 Plan: Pla 528.70 545.00 761.53 9.55 751.98 Pass: Major Risk '~ PS Z Pad -Exp V2 2~lan Ivi Z-57 (NC) Plan Z-57 V2 Plan: Pla 1212.08 1410.00 718.93 29.90 689.03 Pass: Major Risk ' ' PB Z Pad -Exp V2 2a'lan Ivi Z-60 (NK) Plan Z-60 V2 Plan: Pla 514.06 525.00 889.09 9.27 879.82 Pass: Major Risk i PB Z Pad -Exp V2 20~1an Ivi Z-61 (NE) Plan Z-61 V1 Plan: Pla 585.88 605.00 790.68 10.56 780.13 Pass: Major Risk ~, ': PB Z Pad -Exp V2 20'lan Ivi Z-63 (NA) Plan Z-63 V2 Plan: Pla 2657.44 3095.00 157.54 74.48 83.06 Pass: Major Risk ', PB Z Pad -Exp V2 2~lan Kup Z-105 (SP) Plan Z-105 V1 Plan: PI 368.80 370.00 1062.50 6.67 1055.83 Pass: Major Risk ', PB Z Pad -Exp V2 20~1an Kup Z-106 (NP) Plan Z-106 V1 Plan: PI 368.80 370.00 1047.12 6.67 1040.45 Pass: Major Risk j PB Z Pad -Exp V2 2~lan Kup Z-113 (NG) Plan Z-113 V2 Plan: PI 541.08 555.00 820.22 9.75 810.47 Pass: Major Risk PB Z Pad -Exp V2 20~1an Kup Z-115 (NI) Plan Z-115 V2 Plan: PI 549.58 565.00 859.74 9.92 849.82 Pass: Major Risk ', PB Z Pad -Exp V2 2~lan Sch Z-200 (SE) Plan Z-200 V1 Plan: Pl 448.62 455.00 813.38 8.16 805.22 Pass: Major Risk PB Z Pad -Exp V2 2~lan Sch Z-307 (NM) Plan Z-307 V2 Plan: PI 458.79 465.00 1002.81 8.27 994.54 Pass: Major Risk PB Z Pad -Exp V2 2d'lan Sch Z-308 (NN) Plan Z-308 V2 Plan: PI 526.46 540.00 1017.61 9.61 1008.00 Pass: Major Risk ', PB Z Pad -Exp V2 2~lan Sch Z-309 (NO) Plan Z-309 V1 Plan: PI 408.09 410.00 1032.44 7.36 1025.07 Pass: Major Risk PB Z Pad -Exp V2 2~lan Sch Z-310 (SA) Plan Z-310 V1 Plan: PI 935.82 1090.00 700.84 17.56 683.29 Pass: Major Risk ' PB Z Pad -Exp V2 2~lan Sch Z-311 (SM) Plan Z-311 V1 Ptan: PI 403.40 405.00 1019.06 7.28 1011.78 Pass: Major Risk PB Z Pad -Exp V2 2~lan Sch Z-312 (SN) Plan Z-312 V1 Plan: PI 388.79 390.00 1033.59 7.02 1026.57 Pass: Major Risk '~ PB Z Pad -Exp V2 2~lan Sch Z-314 (SG) Pian Z-314 V1 Plan: PI 373.80 375.00 841.40 6.76 834.64 Pass: Major Risk ' PB Z Pad -Exp V2 20~1an Sch Z-322 (NJ) Plan Z-322 V1 Plan: PI 545.02 560.00 874.47 9.84 864.64 Pass: Major Risk PB Z Pad Plan Z-104 (27+30) Plan Z-104 V1 Plan: PI ~ 583.24 585.00 48.06 10.47 37.59 Pass: Major Risk I PB Z Pad Plan Z-110 (30.5) Plan Z-110 V1 Plan: PI 588.45 590.00 105.52 10.61 94.90 Pass: Major Risk ~ ~, PB Z Pad Plan Z-111 (27+15) Plan Z-111 V3 Plan: PI 643.08 645.00 33.41 11.62 21.78 Pass: Major Risk '~, !~ PB Z Pad Plan Z-112 (29.5) Plan Z-112 V2 Plan: PI 1003.55 995.00 58.84 18.11 40.73 Pass: Major Risk PB Z Pad Plan Z-112 (29.5) Plan Z-112P81 V2 Plan: 1003.55 995.00 58.84 18.11 40.73 Pass: Major Risk PB Z Pad Plan Z-114 (27+45) Plan Z-114 V1 Plan: PI 438.17 440.00 62.95 7.89 55.06 Pass: Major Risk PB Z Pad Plan 2-400 (21-35) Plan Z-400 V1 Plan: PI 574.37 580.00 223.41 10.56 212.85 Pass: Major Risk ', ~ PB Z Pad Plan 2-401 (33-35) Plan Z-401 V1 Plan: PI ~ 383.79 385.00 227.72 7.09 220.62 Pass: Major Risk ' PB Z Pad Plan 2-402 (21-70) Plan Z-402 V1 Plan: PI 1329.75 1365.00 114:41 28.20 86.21 Pass: Major Risk PB Z Pad Z-01 Z-01 V1 483.63 500.00 275.80 10.57 265.23 Pass: Major Risk PB Z Pad Z-01 Z-01 APB1 V6 483.63 500.00 275.80 10.31 265.48 Pass: Major Risk i PB Z Pad Z-01 Z-01APB2 V5 483.63 500.00 275.80 10.31 265.48 Pass: Major Risk PB Z Pad Z-01 Z-01AP63 V4 483.63 500.00 275.80 10.31 265.48 Pass: Major Risk PB Z Pad Z-02 Plan Z-026 V2 Plan: PI 464.14 470.00 265.08 8.17 256.91 Pass: Major Risk PB Z Pad Z-02 Z-02 V3 465.03 480.00 265.10 8.19 256.91 Pass: Major Risk PB Z Pad Z-02 Z-02A V1 463.21 470.00 265.07 8.16 256.91 Pass: Major Risk PB Z Pad Z-03 Z-03 V4 407.00 410.00 263.47 7.21 256.26 Pass: Major Risk BP Alaska Anticollision Report I Company: BP AmoCO Date: 3/20/2007 Time: 11:53:37 Page: 2 ! i; Field: ~ Prudhoe Bay Reference Site: ~ PB Z Pad Co-ordinhte(NE) Reference: Well: Pla n Z-102 (27 .5), True North ~ ~' Reference Well: Plan Z-102 (27.5) Vertical (TVD) Refere nce; Z-102 Plan 81.3 Reference Wellpattr: Plan Z-102PB1 Db: Oracle _-_ Summary _ r,_< - - - -- -- t)ffset Wellpath ` ' - -,---- - - -----> r Reference - Offset - Ctr-Ctr - No-Go Allowable ' ~ Site Well Wellpath Mb MR Distance Area. Deviation Warning ' ft ft ft ,' ft ft PB Z Pad Z-04 Z-04 V6 477.00 495.00 260.93 .8.20 252.73 Pass: Major Risk i PB Z Pad Z-04 Z-04A V10 476.11 485.00 260.91 8.33 252.58 Pass: Major Risk PB Z Pad Z-05 Plan#3 Z-05AP61 VO Pla 7552.22 7170.00 169.15 97.72 71.43 Pass: Major Risk PB Z Pad Z-05 Plan#4 Z-05A VO Plan: 7552.22 7170.00 169.15 97.72 71.43 Pass: Major Risk ~ PB Z Pad Z-05 Z-05 V3 7552.22 7170.00 169.15 97.68 71.46 Pass: Major Risk PB Z Pad Z-06 Plan#7 Z-O6A V3 Plan: 446.42 460.00 273.09 7.83 265.26 Pass: Major Risk PB Z Pad Z-06 Z-06 V1 446.42 460.00 273.09 7.66 265.43 Pass: Major Risk '! PB Z Pad Z-07A Z-07A V1 449.64 460.00 285.95 8.11 277.84 Pass: Major Risk PB Z Pad Z-07 Z-07 V1 492.04 505.00 286.62 8.94 277.68 Pass: Major Risk '; PB Z Pad Z-08A Z-08A V1 435.59 445.00 306.09 10.23 295.86 Pass: Major Risk j '~ PB Z Pad Z-08 Z-08 V1 435.59 445.00 306.09 10.39 295.70 Pass: Major Risk PB Z Pad Z-09 Plan Z-09A V3 Plan: PI 511.97 520.00 321.68 10.43 311.25 Pass: Major Risk 'i PB Z Pad Z-09 Z-09 V4 510.80 530.00 321.65 10.40 311.25 Pass: Major Risk i, PB Z Pad Z-100 Z-100 V7 502.11 505.00 500.60 8.33 492.28 Pass: Major Risk PB Z Pad Z-101 Plan Z-101A V3 Plan: Z 2400.11 2595.00 479.82 108.82 371.01 Pass: Major Risk PB Z Pad Z-101 Plan Z-101APB1 VO Plan 2400.11 2595.00 479.82 109.08 370.74 Pass: Major Risk PB Z Pad Z-101 Z-101 VS 2400.74 2595.00 479.81 108.94 370.87 Pass: Major Risk ~' PB Z Pad Z-103 Z-103 V1 338.49 340.00 79.21 5.76 73.45 Pass: Major Risk ', ', PB Z Pad Z-103 Z-103PB1 V3 338.49 340.00 79.21 5.76 73.45 Pass: Major Risk j PB Z Pad Z-103 Z-103P62 V1 338.49 340.00 79.21 5.76 73.45 Pass: Major Risk !, ' PB Z Pad Z-108 Z-108 V5 234.07 235.00 261.96 4.24 257.71 Pass: Major Risk ' PB Z Pad Z-10 Z-10 V1 517.28 535.00 343.86 10.65 333.21 Pass: Major Risk ' PB Z Pad Z-10 Z-10A WPS V1 Plan: Z-1 518.57 530.00 343.89 10.63 333.26 Pass: Major Risk ' PB Z Pad ' Z-11 Z-11 V1 454.99 470.00 431.53 7.55 423.98 Pass: Major Risk PB Z Pad Z-11 Z-11A V3 454.99 470.00 431.53 7.37 424.15 Pass: Major Risk PB Z Pad Z-12 Z-12 V1 482.53 500.00 461.91 9.45 452.46 Pass: Major Risk PB 2 Pad Z-13 Z-13 V3 459.39 475.00 490.03 8.21 481.82 Pass: Major Risk PB Z Pad Z-13 Z-13A V2 458.42 465.00 490.02 8.20 481.82 Pass: Major Risk PB Z Pad Z-13 Z-13APB1 V3 458.42 465.00 490.02 8.14 481.88 Pass: Major Risk ' PB Z Pad Z-14A Z-14A V1 454.42 470.00 520.01 8.83 511.18 Pass: Major Risk PB Z Pad Z-14 Z-14 V1 454.42 470.00 520.01 8.84 511.18 Pass: Major Risk PB Z Pad Z-14 Z-14B V9 453.90 460.00 520.01 8.83 511.18 Pass: Major Risk ~ PB Z Pad Z-15 Z-15 V1 482.06 500.00 549.33 8.46 540.87 ~ Pass: Major Risk j PB Z Pad Z-16 Plan Z-16A V3 Plan: PI 453.72 460.00 584.22 9.19 575.03 Pass: Major Risk i PB Z Pad Z-16 Z-16 V6 453.90 465.00 584.23 9.20 575.03 I Pass: Major Risk PB Z Pad Z-17 Z-17 V1 504.16 525.00 613.43 9.00 604.43 Pass: Major Risk PB Z Pad Z-18 Z-18 V1 495.19 515.00 644.62 9.03 635.59 Pass: Major Risk ' PB Z Pad Z-19 Z-19 V1 585.95 615.00 677.03 14.23 662.79 Pass: Major Risk i PB Z Pad Z-19 Z-19A V8 585.38 610.00 677.01 14.22 662.79 Pass: Major Risk ' PB Z Pad Z-20 Plan Z-20A V6 Plan: PI 485.22 495.00 708.07 10.17 697.90 Pass: Major Risk ~, ! PB Z Pad Z-20 Z-20 V1 481.79 500.00 708.04 9.98 698.06 Pass: Major Risk PB Z Pad Z-210 Z-210 V6 825.70 825.00 19.89 14.32 5.57 Pass: Major Risk '~ ' PB Z Pad Z-210 Z-210PB1 V7 825.70 825.00 19.89 14.32 5.57 Pass: Major Risk ' PB Z Pad Z-21 Z-21 V3 605.36 620.00 260.20 11.33 248.86 Pass: Major Risk PB Z Pad Z-21 Z-21 A V5 602.36 610.00 260.15 11.07 249.08 Pass: Major Risk PB Z Pad Z-22A Z-22A V1 545.03 550.00 294.38 8.71 285.67 Pass: Major Risk PB Z Pad Z-22B Z-226 V1 545.03 550.00 294.38 8.71 285.67 Pass: Major Risk ~ ~ PB Z Pad Z-22 Z-22 V1 545.02 550.00 293.49 8.71 284.78 I Pass: Major Risk i PB Z Pad Z-23 Z-23 V3 617.73 635.00 328.10 12.75 315.35 Pass: Major Risk PB Z Pad Z-23 Z-23A V2 590.91 595.00 328.00 10.37 317.63 Pass: Major Risk PB Z Pad Z-23 Z-23B V7 594.30 600.00 328.05 10.52 317.53 Pass: Major Risk 'i PB Z Pad Z-24 Z-24 V1 497.73 510.00 365.02 11.15 353.87 Pass: Major Risk i PB Z Pad Z-25 Z-25 V1 629.72 650.00 398.15 12.91 385.23 Pass: Major Risk PB Z Pad Z-26 Z-26 V1 600.55 615.00 435.01 10.70 424.32 Pass: Major Risk i~ PB Z Pad Z-26 Z-26A V2 600.55 615.00 435.01 10.44 424.57 Pass: Major Risk PB Z Pad Z-27 Z-27 V1 519.41 530.00 16.88 9.32 7.56 Pass: Major Risk PB Z Pad Z-28 Z-28 V1 614.57 625.00 17.87 10.33 7.54 Pass: Major Risk PB Z Pad Z-29 Z-29 V1 805.46 815.00 49.70 14.41 35.29 Pass: Major Risk PB Z Pad Z-30 Z-30 V7 895.14 900.00 80.47 15.64 64.84 Pass: Major Risk PB Z Pad Z-30 Z-30A V9 894.29 890.00 80.47 15.63 64.84 Pass: Major Risk PB Z Pad Z-31 Z-31 V1 1076.53 1075.00 102.86 21.03 81.83 Pass: Major Risk I PB Z Pad Z-32A Z-32A V7 1104.36 1090.00 137.47 17.98 119.49 Pass: Major Risk PB Z Pad Z-326L1 Z-32BL1 V2 1100.05 1100.00 137.33 17.90 119.43 Pass: Major Risk ; BP Alaska Anticollision Report Company; BP Amoco --- - _ Date: 3/20/2007 --- ---- - --- Time: 11:53'37 ---- g Pa e: 3 ~ Field: Prudhoe Bay ~ Reference Site: PB Z Pad Co-ordinate(NE) Reference: . Well: Pla n Z-102 (27. 5), Tree North Reference W©ll: Plan Z-102 (2Z5) Vertieal'(TVU) Reference: Z-102 Plan 81.3 ~i Reference Wellpatl-: Plan Z-102P61 Db: Oracle `~ Summary I~ < . gffset Wellpath ~->` 13eferegce bffseE _ `Ctr-Ctr No-Co _ Allowable __ - _ ::~ Site Well Wellpath MD Ml) Distance Area Deviation Warning ~ ft ft ft ft ft j PB Z Pad Z-326P61 Z-326P61 V2 1100.05 1100.00 137.33 17.90 119.43 Pass: Major Risk !, PB Z Pad Z-32BPB2 Z-32BP62 V2 1100.05 1100.00 137.33 17.90 119.43 Pass: Major Risk PB Z Pad Z-32B Z-326 V2 1100.05 1100.00 137.33 17.90 119.43 Pass: Major Risk ~ PB Z Pad Z-32 Z-32 V2 1100.05 1100.00 137.33 17.90 119.43 Pass: Major Risk ' PB Z Pad Z-33 Plan Z-33B V2 Plan: PI 1166.54 1165.00 164.59 22.66 141.93 Pass: Major Risk PB Z Pad Z-33 Z-33 V1 1159.99 1160.00 162.93 19.37 143.56 Pass: Major Risk '~ PB Z Pad Z-33 Z-33A V1 1166.54 1165.00 164.59 22.49 142.10 Pass: Major Risk ~ PB Z Pad Z-35P61 Z-35PB1 V2 5507.65 5760.00 402.24 148.44 253.80 Pass: Major Risk j PB Z Pad Z-35 Z-35 V2 477.64 485.00 394.46 7.87 386.59 Pass: Major Risk ~ PB Z Pad Z-38P61 Z-38P61 V3 548.12 560.00 477.24 9.12 468.12 Pass: Major Risk PB Z Pad Z-38 Z-38 V5 548.12 560.00 477.24 9.12 468.12 Pass: Major Risk I~ PB Z Pad Z-39 Z-39 V18 340.25 345.00 404.89 5.53 399.36 Pass: Major Risk PB Z Pad Z-39 Z-39A V4 340.25 345.00 404.89 5.53 399.36 Pass: Major Risk ' '~ PB Z Pad Z-46 Z-46 V14 278.46 280.00 661.21 4.88 656.33 Pass: Major Risk '~ PB Z Pad- Z-46 _ _ _ Z-46A V15 _ 278.46 280.00 661.21 4.88 656.33 Pass: Major Risk ~ • FieldPrudhoe Bay Site PB Z Pad Well:Plan Z-102 (27.5) WellpathElan Z-102PB1 313 300 200 100 0 2 100 200 300 -3 1 3 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t ` ~ Target: Z-102PB 1 Tgt Site: PB Z Pad Well: Plan Z-102 (27.5) Drilling Target Conf.: 95% Based on: Planned Program Description: Vertical Depth: 6610.00 ft below Mean Sea Level Map Northing: 5959500.00 ft Local +N/-S: 168.43 ft Map Fasting :597000.00 ft Local +E/-W: -2129.11 ft Latitude: 70° 17'S5.933N Longitude: 149° 12'51.965 W Shape: Circle Radius: 150 ft \ ~' ~ 50 +0 00 20 0 __- _ _ - _ - _ _ _ - _-- _ 0 D o 0 0 0 0 0 ~~ o 0 0 ~ 0 ~ 0 nI ~ ~ c~ ~ I I/ ~ 1 I ~ I ~ I I I by Z-102 (P12) Pro Report Date: Apri112, 2007 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA ~~ Structure! Slot: Z-PAO I Z-102 Well: Plan Z-102 (27.5) Approve Borehole: Plan Z-102 UWIIAPI#: 50029 Survey Name 1 Date: Z-102 (P12) HA I April 12, 2007 Tort 1 AHD / DDI / ERD ratio: 194.224° / 5343. i9 ft / 6.174 / 0.801 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Location LatlLong: N 70.29841096, W 149.19719391 Location Grid NIE YIX: N 5959359.680 ftUS, E 599130.960 ftUS Gdd Convergence Angle: +0.75581642° r..;a s.~re c~..~,..~ n o000 ~ ~ ~ a ;a~ Schlumberger Survey I DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 190.000° ~ Vertical Section Origin: N 0.000 ft, E 0.000 ft ( ND Reference Datum: Rotary Table ND Reference Elevation: 81.30 ft relative to MSL Sea Bed I Ground Level Elevation: 52.80 ft relative to MSL Magnetic Declination: 23.690° Total Field Strength: 57638.264 nT Magnetic Dip: 80.885° Declinaton Date: May Z0, 2007 Magnetic Declination Model: BGGM 2006 North Reference: True North Total Corr Mag North •> True North: +23.690° Comments Measured Inclination Azimuth SulrSea ND TVD Vertical NS EW Gravely DLS Build Rate Walk Rate Northing Fasting LaOtude Longitude Depth SeMion Tool Fa ce k d de ft ft ft ft ft de de 100 ft de 100 ft de 100 ft ftUS ftUS TKC4 7692 .73 60. 00 200. 00 6500 .00 6581. 30 16. 21 347.47 -2063. 95 HS 0 .00 0.00 0.00 5959679. 86 597062. 79 N 70.29935944 W 149.21390736 7700 .00 60. 00 200. 00 6503 .64 6584. 94 22. 41 341.55 -2066. 11 --- 0 .00 0.00 0.00 5959673. 92 597060. 71 N 70.29934327 W 149.21392479 Top Whipstock 7702 .73 60. 00 200. 00 6505 .00 6586. 30 24. 74 339.33 -2066. 92 HS 0 .00 0.00 0.00 5959671. 69 597059. 94 N 70.29933720 W 149.21393133 Base Whipstock 7715 .73 62. 08 200. 00 6511 .30 6592. 60 35. 94 328.64 -2070. 81 --- 16 .00 16.00 0.00 5959660. 95 597056. 19 N 70.29930800 W 149.21396281 KOP Crv 10/100 7727 .73 62. 08 200. 00 6516 .91 6598. 21 46. 39 318.68 -2074. 43 29. 78E 0 .00 0.00 0.00 5959650. 94 597052. 69 N 70.29928078 W 149.21399215 7750 .00 64. 02 198. 77 6527 .01 6608. 31 65. 97 299.95 -2081. 02 29. 22E 10 .00 8.70 -5.52 5959632. 13 597046. 35 N 70.29922962 W 149.21404545 Base KC1/Top KB 7772. 00 65.94 197. 59 6536. 31 6617.61 85. 70 281.01 -2087. 24 28. 73E 10. 00 8.75 -5.35 5959613. 11 597040. 39 N 70.29917787 W 149.21409576 7800 .00 68. 41 196. 15 6547 .17 6628. 47 111. 32 256.32 -2094. 72 28. 16E 10 .00 8.79 -5.17 5959588. 32 .597033 .23 N 70.29911040 W 149.21415632 7850 .00 72. 83 193. 68 6563 .76 6645. 06 158. 30 210.75 -2106. 84 27. 34E 10 .00 8.85 -4.94 5959542. 61 597021 .71 N 70.29898591 W 149.21425437 7900 .00 77. 28 191. 33 6576 .66 6657. 96 206. 55 163.60 -2117. 29 26. 74E 10 .00 8.91 -4.70 5959495. 33 597011. 89 N 70.29885709 W 149.21433884 7950 .00 81. 76 189. 06 6585 .75 6667. 05 255. 70 115.23 -2125. 98 26. 32E 10 .00 8.95 -4.54 5959446. 84 597003 .84 N 70.29872493 W 149.21440910 8000 .00 86. 25 186. 84 6590 .97 6672. 27 305. 38 65.99 -2132. 85 26. 09E 10 .00 8.97 -4.44 5959397. 53 596997. 62 N 70.29859042 W 149.214 Crv 10/100 8041 .79 90. 00 185. 00 6592 .34 6673. 64 347. 03 24.45 -2137. 15 65. 15E 10 .00 8.98 -4.39 5959355. 94 596993. 86 N 70.29847694 W 149.214 8050 .00 90. 34 184. 26 6592 .32 6673. 62 355. 20 16.27 -2137. 82 65. 15E 10 .00 4.20 -9.07 5959347. 75 596993. 31 N 70.29845459 W 149.2145 2 8100 .00 92. 44 179. 71 6591 .10 6672. 40 404. 68 -33.67 -2139. 55 65. 26E 10 .00 4.20 -9.08 5959297. 80 596992. 24 N 70.29831816 W 14921451862 8150 .00 94. 52 175. 16 6588 .06 6669. 36 453. 38 -83.51 -2137. 32 65. 54E 10 .00 4.16 -9.11 5959248. 00 596995. 12 N 70.29818199 W 149.21450046 8200 .00 96. 58 170. 58 6583 .22 6664. 52 500. 92 -132.87 -2131. 15 65. 98E 10 .00 4.11 -9.16 5959198. 72 597001. 94 N 70.29804714 W 149.21445038 8250 .00 98. 59 165. 96 6576 .62 6657. 92 546. 95 -181.39 -2121. 08 66. 59E 10 .00 4.02 -9.24 5959150. 35 597012. 65 N 70.29791461 W 149.21436875 End Crv 8260 .35 99. 00 165. 00 6575 .03 6656. 33 556. 26 -191.29 -2118. 52 --- 10 .00 3.96 -9.29 5959140. 48 597015. 34 N 70.29788756 W 149.21434796 Crv 10/100 8422 .35 99. 00 165. 00 6549 .69 6630. 99 701. 27 -345.84 -2077. 10 136. 48E 0 .00 0.00 0.00 5958986. 50 597058 .79 N 70.29746536 W 149.21401229 8450 .00 96. 99 163. 08 6545 .85 6627. 15 725. 89 -372.16 -2069. 57 136. 75E 10 .00 -7.27 -6.94 5958960. 28 597066. 66 N 70.29739346 W 149.21395127 Top KB /Base KCl 8480. 00 94. 80 161. 02 6542. 76 6624. 06 752. 24 -400.55 -2060. 38 136. 96E 10. 00 -7.30 -6.87 5958932. 03 597076. 23 N 70.29731592 W 149.21387675 8500 .00 93. 34 159. 65 6541 .35 6622. 65 769. 58 -419.33 -2053. 67 137. 06E 10 .00 -7.31 -6.84 5958913. 33 597083. 19 N 7029726461 W 149.21382235 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Z-1021PIan Z-102 (27.5)\Plan Z-102\Z-102 (P12) HA Generated 4/12/2007 10:48 AM Page 1 of 2 Comments Measured Depth Inclination Azimuth SulrSea ND ND Vertical Section NS EW Gravil y Tool Face DLS Build Rate Waik Rate Northing Easting Latitude Longitude (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (deg) (deglt00ft) (deg1100ft) (deglt00ft) (ftUS) (ftUS) End Crv 8545.50 90.00 156.55 6540.02 6621.32 808.18 -461.53 -2036.71 -- 10.00 -7.33 -6.81 5958871.37 597100.70 N 70.29714935 W 149.21368494 8773.69 90.00 156.55 6540.00 6621.30 998.58 -670.87 -1945.91 90.13R 0.00 0.00 0.00 5958663.26 597194.24 N 70.29657750 W 149.21294937 8788.15 90.00 158.00 6540.00 6621.30 1010.75 -684.21 -1940.33 --- 10.00 -0.02 10.00 5958650.00 597200.00 N 70.29654107 W 149.21290412 Crv 10/100 9021.00 90.00 158.00 6540.00 6621.30 1208.22 -900.10 -1853.10 12.64R 0.00 0.00 0.00 5958435.29 597290.06 N 70.29595132 W 149.21219744 Increase Invert !nc 9050.00 92.83 158.64 6539.28 6620.58 1232.89 -927.04 -1842.39 12.66R 10.00 9.76 2.19 5958408.50 597301.12 N 70.29587774 W 149.21211087 End Crv 9085.65 96.31 159.42 6536.44 6617.74 1263.35 -960.22 -1829.68 --- 10.00 9.76 2.20 5958375.50 597314.28 N 70.29578711 W 149.21200764 TKC4/Base KLBK 9570.00 96.31 159.42 6483.22 6564.52 1677.81 -1410.91 -1660.46 -- 0.00 0.00 0.00 5957927.12 597489.41 N 70.29455595 W 149.21063677 TD / 4-1/2" Lnr 9599.29 96.31 159.42 6480.00 6561.30 1702.88 -1438.17 -1650.22 --- 0.00 0.00 0.00 5957900.00 597500.00 N 70.29448150 W 149.21055388 Les;lal Descriation: Northi ng (Y) [ftUS] Easting (X) [ftUS] Surface : 4564 FSL 3542 FEL S19 T11 N R12E UM 5959359.68 599130.96 Target : 3879 FSL 530 FEL S24 T11 N R11 E UM 5958650.00 597200.00 TD / BHL : 3126 FSL 239 FEL S24 T11 N R11 E UM 5957900.00 597500.00 • WeIlDesign Ver SP 2.1 Bld(doc40x_100) Z-102\Plan Z-102 (27.5)\Plan Z-102\Z-102 (P12) HA Generated 4/12/2007 10:48 AM Page 2 of 2 ~~41 Schlumberger WELL Z-102 (P12) F~`D Prudhoe Bay Unit - WOA STRUCTURE Z-PAD Mapnelic Paramalers 6ue(arx Loralgn NAD3] glaska SMIe Planes. Zwq OC, US Feel n elks Mopol BGGM 2006 Olp. BO.B65' Dale May 2p. Zp0] Ut. 1]51.])9 onMng 5959159 fig ells GnC Lpnv •0)5581602' Slot. 2101 TVD RxI Rplary Ta°k 181 bit a5°va M6L1 Maq Dac: •Z3.690' FS' 5)636.3 nT W109 rt a9696 Ease~g. 5991]0 %eU5 Stork Fatl-. 0.9999tt t6JZ Ltp1 (P11)HA 6rvy Date Apr1 ,1. 100] 0 250 500 750 1000 1250 1500 1750 6500 0 N C 6750 a~ m U F- 7000 0 250 500 750 1000 1250 1500 1750 Vertical Section (ft) Azim = 190°, Scale = 1(in):250(ft) Origin = 0 N/-S, 0 E/-4 6500 6750 7000 • •i l+; Schlumberger Z-102 (P12) `lE`~ Prudhoe Bay Unit - WOA STRDDTDRE Z-PAD Magne0c Parameters Sunaw L xalion NAD1)AWfFa Seale PBnaf. ZOrle Oa. US Feel Macellane0us MDaxl BGGM 3000 Pp 00.085' Dale May 20. 300] Lal. N]01]5a 3]9 Nonbng 5959]5988 bU5 Grq Conv •0 i55btfia3' Sbl Z~t 01 ND Re( Raary Ta01e 1013011 a0ava MSLI Mag Dec •1J 890' FS 5)BJO.J nT Lm Wta9111909b EaMnp. 5991]090005 SrJge Fad 09999ttt0]2 PMn. 2~t 031P 131 NA Srvy Dele. Marcb 20. 300) -2400 -2100 -1800 -1500 600 300 0 n n n Z -300 0 0 M C I I N (0 U ~ -600 V V V -900 1200 -1500 -2400 -2100 -1800 -1500 c« W Scale = 1(in):300(ft) E »> 600 300 0 -300 -600 -900 -1200 -1500 ''~. i ~, I i ~~,! I i' ~', i '. O O 0 ~ O ~ 0 ~ n n O ~ is N I N is I ~ 0 0 ~ '~ ~I N ~~a ~ ' !. • Oilfield Services, Alaska Schlumberger Drilling & Measurements 2525 Gambell, Suite 400 Anchorage, AK 99503 Tel (907) 273-1766 Fax (907) 561-8367 Thursday, April 12, 2007 Mike Triolo BP Exploration (Alaska) Inc. • Schlumberger Prudhoe Bay Z-102 (P12) Nabors 9ES Close Approach Analysis We have examined the potential intersections of subject well with all other potentially conflicting wells, according to the BPA Directional Survey handbook (BPA-D-004) dated 09/99. Method of analysis: 1. A list of wells to be analyzed is created in Compass by performing a global scan with an initial search radius of two thousand feet with an increment of one hundred feet for every one thousand feet of measured depth in the subject well. 2. Wells are analyzed using the Compass Anti-collision module (BP Company setup) with major risk safety factors applied. For problem wells that are plugged and abandoned or that can be shut in, risk-based safety factor may be used, with client notification. 3. All depths are relative to the planned well profile. Survey Procaram: Instrument Type Start Depth End Depth GYD GC SS 28.50'md 1000.00'md MWD + IFR + MS 1000.00'md 9599.29'md Close Approach Analysis results: Under method (2), note. All wells pass major risk. Global scan has been applied, and then modified by survey specialist to include all wells on Z-Pad. All data documenting these procedures is available for inspection at the Drilling & Measurements Directional Planning Center. Close Approach Drilling Aids to be provided: A drilling map and traveling cylinder will be provided. Checked by: Scott DeLapp 04/12/07 BP Alaska Anticollision Report 'Company: BP Amoco Date: 3/20/2007 Time: 12:58:00 Pager ' 1 Field: Prudhoe Bay Reference Site: PB Z Pad Co-ordinate(NE) Reference: Well: Plan Z-102 (27.5), True North Reference Well: Plan Z-102 (27.5) Vertical (TVD) Reference: Z-102 Plan 81.3 ~ Reference Wellpath Plan Z-1.02 Db: Oracle NO GLOBAL SCAN. Using user defined selection & scan criteria Reference: - -- Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Range: 7702.73 to 9599.29 ft Scan Method: Trav Cylinder North Maximum Radius:10000.00 ft L ~_ _------------ ----- - _ _ Error Surface: _ _ ---- -- --- - Ellipse + Casing '; _ ------ --- - ----- Survey Program for Definitive Wellpath Date: 3/20/2007 Validated: No Version: 11 I~ Planned From To Survey Toolcode Tool Name ft ft 28.50 1000.00 Planned: Plan #6 V1 (1) GYD-GC-SS Gyrodata gyro single shots j 1000.00 3410.00 Planned: Plan #6 V1 (1) MWD+IFR+MS MWD +IFR + Multi Station 3410.00 7702.73 Planned: Plan #6 V1 (1) MWD+IFR+MS MWD +IFR + Multi Station 7702.73 9599.29 Planned: Plan #12 V1 MWD+IFR+MS MWD +IFR + Multi Station Casing Points i MD TVD Diameter Hole Size Name j ft ft in in' 3475.50 3131.30 9.625 12.250 9 5/8" 7702.73 6586.30 7.000 8.750 7" 9599.29 6561.30 4.500 6.750 4-1/2" Summary ~ <---- Offset Weflpath - -.> Reference Offset Ctr-Ctr No-Go Allowable i ~ Site Well: Wellpath MD MD Distance Area Deviation .Warning ft ft ft ft ft PB Z Pad -Exp V2 2~lan Ivi Z-34 (SF) Plan Z-34 V1 Plan: Pla Out of range PB Z Pad -Exp V2 20'lan Ivi Z-40 (SK) Plan Z-40 V1 Plan: Pla Out of range PB Z Pad -Exp V2 20'lan Ivi Z-41 (SC) Plan Z-41 V2 Plan: Pla Out of range PB Z Pad -Exp V2 2d'lan Ivi Z-42 (SJ) Plan Z-42 V2 Plan: Pla 9477.91 5150.00 4543.65 85.29 4458.36 Pass: Major Risk PB Z Pad -Exp V2 2~lan Ivi Z-44 (NF) Plan Z-44 V1 Plan: Pla Out of range ', PB Z Pad -Exp V2 2~lan Ivi Z-45 (SO) Plan Z-45 V1 Plan: Pla Out of range PB Z Pad -Exp V2 2~tan Ivi Z-55 (SB) Plan Z-55 V2 Plan: Pla 9600.05 7270.00 2137.37 92.62 2044.76 Pass: Major Risk ~: PB Z Pad -Exp V2 2(Plan Ivi Z-57 (NC) Plan Z-57 V2 Plan: Pla 9529.86 1400.00 5895.53 60.64 5834.88 Pass: Major Risk PB Z Pad -Exp V2 2~lan Ivi Z-60 (NK) Plan Z-60 V2 Plan: PIa 9564.63 1555.00 5954.15 59.87 5894.28 Pass: Major Risk ~' 'I PB Z Pad -Exp V2 2~lan Ivi Z-61 (NE) Plan Z-61 V1 Plan: Pla 9551.75 1440.00 5953.27 58.80 5894.47 Pass: Major Risk PB Z Pad -Exp V2 20'lan Ivi Z-63 (NA) Plan Z-63 V2 Plan: Pla 9470.64 1690.00 5557.64 59.37 5498.27 Pass: Major Risk PB Z Pad -Exp V2 2~lan Kup Z-105 (SP) Plan Z-105 V1 Plan: PI Out of range PB Z Pad -Exp V2 2~lan Kup Z-106 (NP) Plan Z-106 V1 Plan: PI Out of range PB Z Pad -Exp V2 2~lan Kup Z-113 (NG) Plan Z-113 V2 Plan: PI 9556.38 1465.00 5957.97 59.09 5898.88 Pass: Major Risk ', PB Z Pad -Exp V2 2d'lan Kup Z-115 (NI) Plan Z-115 V2 Plan: PI 9548.81 1595.00 5863.28 59.57 5803.71 Pass: Major Risk PB Z Pad -Exp V2 2~lan Sch Z-200 (SE) Plan Z-200 V1 Plan: PI 9598.06 8435.00 5396.11 96.39 5299.72 Pass: Major Risk PB Z Pad -Exp V2 2tPlan Sch Z-307 (NM) Plan Z-307 V2 Plan: PI 9596.48 1445.00 6131.73 60.30 6071.43 Pass: Major Risk PB Z Pad -Exp V2 21PIan Sch Z-308 (NN) Plan Z-308 V2 Plan: PI ~ 9577.93 1800.00 5905.85 62.06 5843.79 Pass: Major Risk ' , PB Z Pad -Exp V2 2(J~lan Sch Z-309 (NO) Plan Z-309 V1 Plan: PI 9582.76 1930.00 5879.08 63.39 5815.69 Pass: Major Risk ' PB Z Pad -Exp V2 2~lan Sch Z-310 (SA) Plan Z-310 V1 Plan: PI 9216.71 5085.98 2309.47 69.18 2240.29 Pass: Major Risk PB Z Pad -Exp V2 20'lan Sch Z-311 (SM) Plan Z-311 V1 Plan: PI Out of range PB Z Pad -Exp V2 20'lan Sch Z-312 (SN) Plan Z-312 V1 Plan: PI Out of range PB Z Pad -Exp V2 2tPlan Sch Z-314 (SG) Plan Z-314 V1 Plan: PI Out of range PB Z Pad -Exp V2 2~lan Sch Z-322 (NJ) Plan Z-322 V1 Plan: PI 9345.57 3665.00 4280.40 69.17 4211.23 Pass: Major Risk PB Z Pad Plan Z-102 (27.5) Plan Z-102P61 V5 Plan: 7705.00 7705.00 0.01 0.66 -0.65 FAIL: NOERRORS PB Z Pad Plan Z-104 (27+30) Plan Z-104 V1 Plan: PI Out of range PB Z Pad Plan Z-110 (30.5) Plan Z-110 V1 Plan: PI 9415.38 1360.00 5581.78 54.00 5527.78 Pass: Major Risk PB Z Pad Plan Z-111 (27+15) Plan Z-111 V3 Plan: PI Out of range PB Z Pad Plan Z-112 (29.5) Plan Z-112 V2 Plan: PI 8089.67 6535.00 685.87 52.51 633.36 Pass: Major Risk PB Z Pad Plan Z-112 (29.5) Plan Z-112PB1 V2 Plan: 8089.67 6535.00 685.87 52.51 633.36 Pass: Major Risk PB Z Pad Plan Z-114 (27+45) Plan Z-114 V1 Plan: PI Out of range PB Z Pad Plan Z-400 (21-35) Plan 2-400 V1 Plan: PI 9600.12 715.00 6297.97 55.53 6242.45 Pass: Major Risk PB Z Pad Plan 2-401 (33-35) Plan Z-401 V1 Plan: PI 9599.92 3840.00 3219.17 55.68 3163.48 Pass: Major Risk PB Z Pad Plan 2-402 (21-70) Plan Z-402 V1 Plan: PI 9545.45 585.00 6416.80 54.87 6361.93 Pass: Major Risk PB Z Pad Z-01 Z-01 V1 9599.63 3450.00 3729.06 60.82 3668.24 Pass: Major Risk PB Z Pad Z-01 Z-01AP61 V6 9599.63 3450.00 3729.06 60.78 3668.28 Pass: Major Risk PB Z Pad Z-01 Z-01AP62 V5 9599.63 3450.00 3729.06 60.78 3668.28 Pass: Major Risk PB Z Pad Z-01 Z-01 AP63 V4 9599.63 3450.00 3729.06 60.78 3668.28 Pass: Major Risk PB Z Pad Z-02 Plan Z-02B V2 Plan: PI 9599.94 3750.00 3426.28 64.15 3362.13 Pass: Major Risk PB Z Pad Z-02 Z-02 V3 9600.15 3760.00 3425.42 64.16 3361.26 Pass: Major Risk '~, BP Alaska Anticollision Report Company: BP Amoco Date: 3/2012007 Time: 12:58:00 Page: 2 ~, Field: Prudhoe Bay I Reference Site: PB Z Pad Cu-ordinate(NE) Reference: Well: Plan Z-102 (27. 5), True North ! I' Reference Wc11: Plan Z-102 (27.5) Vertical (TVD) Reference: Z-102 P lan 81.3 ~: Reference Weilpath Plan Z-102 _ _ _____ DV: Oracle Summary ------------ - Offset Wellpath -> Reference Offset Cfr-Ctr Na-Go Allowable Site Well Wellpath MI) MD Distance Area Deviation Warning ft ' ft ft ft ft j PB Z Pad Z-02 Z-02A V1 9599.71 3750.00 3427.19 64.14 3363.05 Pass. Major Risk PB Z Pad Z-03 Z-03 V4 Out of range PB Z Pad ~ Z-04 Z-04 V6 8693.51 7150.00 687.66 83.60 604.06 Pass: Major Risk ', ; PB Z Pad Z-04 Z-04A V10 8704.58 7125.00 687.92 86.04 601.89 Pass: Major Risk ', PB Z Pad Z-05 Plan#3 Z-05APB1 VO Pla 9952.47 7600.00 437.13 168.29 268.84 Pass: Major Risk PB Z Pad Z-05 Plan#4 Z-05A VO Plan: 9952.47 7600.00 437.13 168.29 268.84 Pass: Major Risk PB Z Pad Z-05 Z-05 V3 9952.47 7600.00 437.13 168.26 268.87 Pass: Major Risk PB Z Pad I Z-06 Plan#7 Z-O6A V3 Plan: 8619.46 7140.00 293.01 97.54 195.47 Pass: Major Risk j , PB Z Pad Z-06 Z-O6 V1 8619.46 7140.00 293.01 97.43 195.58 Pass: Major Risk 'I PB Z Pad Z-07A Z-07A V1 8807.12 2725.00 4282.97 52.53 4230.44 Pass: Major Risk ', PB Z Pad Z-07 Z-07 V1 8807.08 2725.00 4282.98 52.90 4230.08 Pass: Major Risk ', PB Z Pad Z-08A Z-08A V1 8783.68 3710.00 3390.95 55.63 3335.32 Pass: Major Risk ', PB Z Pad Z-08 Z-08 V1 8783.68 3710.00 3390.95 55.85 3335.10 Pass: Major Risk PB Z Pad Z-09 Plan Z-09A V3 Plan: PI 8042.82 7100.00 803.65 95.99 707,67 Pass: Major Risk PB Z Pad Z-09 Z-09 V4 8042.89 7110.00 803.62 95.95 707,67 Pass: Major Risk i PB Z Pad Z-100 Z-100 V7 9415.37 2585.00 4899.06 58.90 4840.16 Pass: Major Risk ' ' PB Z Pad Z-101 Plan Z-101 A V3 Plan: Z 9547.10 995.00 6159.43 56.35 6103.08 Pass: Major Risk PB Z Pad Z-101 Plan Z-101AP61 VO Plan 9547.10 995.00 6159.43 56.61 6102.83 Pass: Major Risk PB Z Pad Z-101 Z-101 V5 9546.84 995.00 6158.83 56.50 6102.33 Pass: Major Risk PB Z Pad Z-103 Z-103 V1 9599.64 1385.00 5636.23 55.93 5580.30 Pass: Major Risk ', PB Z Pad Z-103 Z-103P61 V3 9599.64 1385.00 5636.23 55.93 5580.30 Pass: Major Risk PB Z Pad Z-103 Z-103P62 V1 9599.64 1385.00 5636.23 55.93 5580.30 Pass: Major Risk ~ PB Z Pad Z-108 Z-108 V5 Out of range ', PB Z Pad Z-10 Z-10 V1 9352.49 1595.00 5318.63 54.87 5263.76 Pass: Major Risk PB Z Pad Z-10 Z-10A WPS V1 Plan: Z-1 9354.16 1585.00 5321.77 55.03 5266.75 Pass: Major Risk !, PB Z Pad Z-11 Z-11 V1 Out of range PB Z Pad Z-11 Z-11 A V3 Out of range ', ', PB Z Pad Z-12 Z-12 V1 9600.15 3705.00 3683.12 67.52 3615.60 Pass: Major Risk ', PB Z Pad Z-13 Z-13 V3 9221.09 4075.00 3654.04 69.33 3584.71 Pass: Major Risk ' ~ PB Z Pad I Z-13 Z-13A V2 9219.00 4070.00 3652.28 69.39 3582.89 Pass: Major Risk I PB Z Pad Z-13 Z-13APB1 V3 9219.00 4070.00 3652.28 69.32 3582.95 Pass: Major Risk ! it PB Z Pad Z-14A Z-14A V1 9241.34 4535.00 3710.46 83.30 3627.16 Pass: Major Risk PB Z Pad l Z-14 Z-14 V1 9241.34 4535.00 3710.46 83.30 3627.16 Pass: Major Risk i PB Z Pad Z-14 Z-146 V9 9241.51 4525.00 3710.51 83.29 3627.21 Pass: Major Risk i PB Z Pad Z-15 Z-15 V1 9428.72 2975.00 4863.94 78.17 4785.77 Pass: Major Risk PB Z Pad Z-16 Plan Z-16A V3 Plan: PI Out of range ' PB Z Pad Z-16 Z-16 V6 Out of range ': PB Z Pad Z-17 Z-17 V1 Out of range ! PB Z Pad Z-18 Z-18 V1 Out of range PB Z Pad Z-19 Z-19 V1 9490.81 1810.00 5555.33 66.42 5488.91 Pass: Major Risk PB Z Pad Z-19 Z-19A V8 9491.16 1805.00 5555.76 66.41 5489.35 Pass: Major Risk PB Z Pad Z-20 Plan Z-20A V6 Plan: PI 9432.94 12250.00 7944.41 275.56 7668.85 Pass: Major Risk I~ '~ PB 2 Pad Z-20 Z-20 V1 Out of range PB Z Pad Z-210 Z-210 V6 9599.49 4720.00 5644.84 79.99 5564.85 Pass: Major Risk ~ PB Z Pad Z-210 Z-210P61 V7 Out of range PB Z Pad Z-21 Z-21 V3 9285.40 3140.00 4183.57 57.23 4126.35 Pass: Major Risk PB Z Pad Z-21 Z-21A V5 9284.93 3135,00 4182.28 57.23 4125.05 Pass: Major Risk ', PB Z Pad Z-22A Z-22A V1 9498.47 1180.00 5904.14 54.98 5849.16 Pass: Major Risk !, PB Z Pad Z-22B Z-22B V1 9498.47 1180.00 5904.14 54.98 5849.16 Pass: Major Risk PB Z Pad Z-22 Z-22 V1 9498.48 1180.00 5903.76 54.97 5848.78 Pass: Major Risk PB Z Pad Z-23 Z-23 V3 8947.09 6325.00 2397.98 73.61 2324.37 Pass: Major Risk ~ PB Z Pad Z-23 Z-23A V2 8951.36 6305,00 2394.39 68.76 2325.63 ~ Pass: Major Risk PB Z Pad Z-23 Z-236 V7 8951.58 6305.00 2394.39 68.84 2325.55 Pass: Major Risk ', j PB Z Pad Z-24 Z-24 V1 9257.83 3575.00 3920.57 62.27 3858.30 Pass: Major Risk ', PB Z Pad Z-25 Z-25 V1 9265.59 3580.00 3951.91 63.37 3888.54 Pass: Major Risk ', i PB Z Pad Z-26 Z-26 V1 9280.32 3535.00 4025.43 62.36 3963.06 Pass: Major Risk I 'i PB Z Pad Z-26 Z-26A V2 9280.32 3535.00 4025.43 62.32 3963.11 Pass: Major Risk , PB Z Pad Z-27 Z-27 V1 Out of range PB Z Pad i Z-28 Z-28 V1 Out of range j PB Z Pad Z-29 Z-29 V1 Out of range ~ PB Z Pad Z-30 Z-30 V7 Out of range PB Z Pad Z-30 Z-30A V9 Out of range PB Z Pad Z-31 Z-31 V1 Out of range BP Alaska Anticollision Report Company: ' - BP Amoco Date: 3/20(2007 Time. 12.58:00 Page: 3 i Field; Prudhoe Bay Reference Site: PB Z Pad Co-ordinate(NE) Reference: Well: Plan Z-102 (27. 5), True North Reference Well: Plan Z-102 (27.5) Vertical (TVD) Reference: 2-102 P lan 81.3 I Reference Wellpath: Plan Z-102 Db: Oracle ~ Summary <- -- Offset Wellpath --- -----> Reference Offset Ctr-Ctr Na-Go Allowable' ~ Site Well Wellpath MD 11tU Distance Area Deviation Warning i ft ff' ft ft ft PB Z Pad Z-32A Z-32A V7 Out of range PB Z Pad Z-326L1 Z-326L1 V2 Out of range PB Z Pad Z-326PB1 Z-326P61 V2 Out of range PB Z Pad Z-326P62 Z-32BP62 V2 Out of range PB Z Pad Z-32B Z-32B V2 Out of range PB Z Pad Z-32 Z-32 V2 Out of range PB Z Pad Z-33 Pian Z-336 V2 Plan: PI 9598.84 7450.00 1271.69 104.38 1167.30 Pass: Major Risk PB Z Pad Z-33 Z-33 V1 9385.58 7400.00 1256.66 94.87 1161.79 Pass: Major Risk PB Z Pad Z-33 Z-33A V1 9598.84 7450.00 1271.69 104.27 1167.41 Pass: Major Risk PB Z Pad Z-35P61 Z-35P61 V2 8803.40 3235.00 3781.61 55.19 3726.42 Pass: Major Risk PB Z Pad Z-35 Z-35 V2 7702.73 8410.00 1846.85 86.43 1760.42 Pass: Major Risk PB Z Pad Z-38PB1 Z-38PB1 V3 7722.26 7340.00 1606.95 94.06 1512.89 Pass: Major Risk PB Z Pad Z-38 Z-38 V5 7724.55 7445.00 1889.93 95.48 1794.45 Pass: Major Risk PB Z Pad Z-39 Z-39 V18 Out of range PB Z Pad Z-39 Z-39A V4 Out of range PB Z Pad Z-46 Z-46 V14 Out of range PB Z Pad Z-46 Z-46A V75 Out of range ~. f i -3 1 3 300 200 100 0 2 100 200 !00 31 3 • • FieldPrudhoe Bay ~~ SitePB Z Pad Well:Plan Z-102 (~7.5) G~ellpathElan Z-102 n 0 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre t h Y; Polygon 1 2 3 4 5 6 Target: Z-102 Poly Site: PB Z Pad Drilling Target Conf.: 95% Description: Map Northing: 5958650.00 8 Map Easting :597200.00 ft Latitude: 70° 17'47.548N Xft Yft -282.98 1293.96 -199.87 12.64 128.52 -871.85 508.79 -856.86 170.79 57.76 47.02 1289.61 • Well: Plan Z-102 (27.5) Based on: Planned Program Vertical Depth: 6500.00 ft be low Mean Sea Level Local +N/-S: -684.2 t ft Local+E/-W: -1940.33 ft Longitude: 149° 12'46.455 W MapEft MapNft 596900.00 5959940.00 597000.00 5958660.00 597340.00 5957780.00 597720.00 5957800.00 597370.00 5958710.00 597230.00 5959940.00 6 U U -`too r; ~, Alaska Department of Natural Resources Land Administration Syste~ Page 1 of 3 • r,. ,, ~~tu 1 ~~r€+~s ,~ .~ ~~ ,+ -~~Eele~ s Search Sfate Cabins a r l_A~ " "~n~, !Case Abstract ~ Case Detail ~ Land Abstract File: ADL. 2S2~4S '~~°'~' Se~irch fior Status Plat Updates Customer. 000107377 BP EXPLORATION (.1L.~SKA) INC PO BOX 1 966 1 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Staters: 35 ISS/APPRVIACTV AUTH States Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: OS/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED [c°i~icliur~: L' 7~nrns{ti/~ 1_I I ~'A~ RC~nge: OI1 E .S~ec~/i~~rr ~ I _~ ~S~c°~lir»t : icrrs 6~~0 Search Plats lllericlr~rn.~ ~'~ 7uii>>zchr/~: O l 1 \ Kafr~rc~.~ 01 ~ I S'c~cliun: I ,~ .ti'~~cli~,rr .(c~rc~,: Ci ~(} Meridiu~t.~ l ~ 7uic~t.~{ri/~~ O I I \ ]gun; ~r: t} I I I~; .1'c~clrun: `` ; .~'r~~lion ll<~r~~s.~ 6~IQ ~llei~rrliu~t ~ U To~a~n.~~hi/~. U I I ~' Run~~~r: (1 I I E~ S~>c~lic~~t.~ ,~ S'c~c~[iott 11c~res: (il(I .Legal Description 0~-28-196 * * *S 1LE NOTICE LEGAL DESCRIPTION ~` C1=1-2~ TIIN, RIIE, UM 13,14,23,2-~ 2560.00 O4-01-19?7 *~UNITIZED.LE4SEAND PARTICIPATINGARF.A LEGAL DESCRIPTION*" LEASE COMMITTED IN ENTIRETY TO PR UDHOE BA Y SIT AND OII RIM GAS CAP PA PX UUHOE BAY UNIT http://www. dnr.state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=028245... 4/ 18/2007 • Alaska Department of Natural Resources Land Administration Syste~ Page 2 of 3 • TRAC"T 53 OIL RIMAND G,4S CAP PARTICIPATING AREAS TI l N, R11 E, UM SECTION 13: ALL 6~t0 ACRES, SECTION I=1: ALL 6-10 ACRES; SECTION 2~1: ALL 6=10 ACRES; CONTAINING 1,920 ACRES, MORE OR LESS. * * * 7-1-00 ASSIGNMENT LEGAL DESCRIPTION SEGMENT 1. SAME AS PRUDHOE B 4 Y LnVIT TIIN, R11 E, UM SECTION 13: ALL, 6~0 ACRES: SECTION 1 ~: ALL, 6-~D ACRES; SECTION 2~1: ALL, 6-10 ACRES; CONTAINING 1,920 ACRES, MORE OR LESS. SEGMENT 2, OUTSIDE PR UDHDE BA Y UNIT TIIN, R11 E, UM SECTION 23. ALL, 6~0 ACRES, CONT~ INING 6~F0 ACRES, MORE OR I ESS OZ-UI -200-1 `*FOR~LEITION OF ORLON PARTICIPATING AREA LEGAL DESCRIPTION* LEASF_ COMMITTED IN PART' TO ORLON P~IRTICIPATIl1~'G AREA PRUDHOE BAY UNIT TR,4CT ~3 ORLON PA RTICIP~ 1 TtNG f1 REA http://www. dnr. state.ak.us/Las/Case_Summary. cfm?FileType=ADL&FileNumber=028245 ... 4/ 18/2007 • Alaska Department of Natural Resources Land Administration Syste~ Page 3 of 3 • T. 11 N., R. 11 E., UMIATMERIDIAN, ALASKA SEC770N 13: NI/2, SEU~, ~80.OOACRES,~ SECTION I ~: EI/2NE1/~l, 80.00 ACRES: SECTION2~: EI/2N1/?, SO.OOACRES: CONTAINING APPROXIMATELY Gd0.00 ACRES, MORE OR LESS. 12-01- 200 * * * * *BOREALIS PA EXPANDED, LEASE INCORPORATED IN PART LEGAL DESCRIPTION IS AS FOLLOWS: PR UDHOE BAY UNIT BOREALIS PARTICIPATING AREA TRACT 53 (PARTIAL) T.11 N., R. I1 E., UMIAT MERIDIAN, ALASKA SECTION 13: N2, N2SW~1, SE-l, X60.00 ACRES,- SF,CTION 1=1: NE4, N2SE~1. 2-10.00 ACRES: SECTION 2-1: NE~l, N2SE=l, 210.00 ACRES; TIII,S TRACT CONTAINS 1, 0-10.00 ACRES, MORE OR LESS. Last updated on 04/18/2007. Not sure who to contact? Have a question about DNR? Visit the Pt~lic Infcarn~at~n ~~r~tr. Report technical problems with this page to the ebr~as~r. Site optimized for Netscape 7, IE 6 or above. This site also requires that all COOKIES must be accepted. State of Alaska Natural_Resources LAS Home Gopyrig_ht Privacy System._Status http://www.dnr. state.ak.usllas/Case_Summary.cfm?FileType=ADL&FileNumber=028245... 4/18/2007 • • Terri L. Hubble 89-6/1252 337 BP Exploration AK Inc. "Mastercard Check" PO Box 196612 MB 7-5 ~. t~_D"7 Anchorage, AK 99519 GATE PAY TO THE ~~F~~o~.~r~~~ OROER OF LLLL~~~~~~~\ ~.JWW~~..`~~''~..~ J` ' ~'A =_~~~-`--~t7-\ First National Bank Alaska Anchorage, AK 99501 MEMO. ~~~ ,~ ` ~~.~~ ~:~25200060~:99146227i55611' 0331 ~ • TRAYSMITTAL LETTER CHECKLIST WELL NAME ~/,S'L/ - fQ~ PTD# o?D~p~S'©d Development / Service Exploratory Stratigraphic Test cYon-Conventions[ Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Getter CHECK i ADD-ONS TEXT FOR APPROVAL LETTER WHAT ; (OPTIONS) APPLIES ~ ' i ' i I MULTI LATERAL The permit is for a new we116ore segment of existing j well (If last two digits in I API number are : Permit N°' , AP[ No. ~0- -~_ .. ,between 60-69) Production should continue to be reported as a function of the f original API number stated above. PILOT HOLE in accordance with 20 A.AC 25.00~(f), alt records, data and logs i i ~ acquired for the pilot hole must be clearly differentiated in both ;well name ( PH) and API number I ~ ' (~0- - -_~ from records, data and logs j ~ acquired for welt ' ~ SPACING The permit is approved subject to full compliance with 20 AAC 'EXCEPTION 12~.OS~. Approval to perforate and produce / .inject is contingent i I upon issuance of a conservation order approving a spacing i ~ exception ' . assumes the liability of any protest to the spacing exception that may occur. i ;DRY DCTCH -; ~ AI[ dry ditch sample sets submitted to tlae-Commission must be in j SA.titPLE I no greater than 30' sample intervals from below the permafrost or ~ I from where samples are first caught and 10' sample intervals through target zones. ~oii Conventional i Please note the following. special condition of this permit: ~ production or production testing of coal bed methane is not allowed i ~ for (name. of weU~ until after (Cotnuan„y Name) has designed and implemented a water well testing program to provide baseline data vn water quality and quantity. 1ComEany Name) must contact the I i I ~ Commission to obtain advance approval of such water well testing program I Rev: t 25%06 C:` jody~transmittal_checklist • ~ ^^ ~ . , ~ ~ ~ ~ , rn o N ~ ~ ~ ~ ~ i N O' C OS N N : ~ ~ ~ ~ ~ ~ ~ ~ ..r ~~ ~ t3. ~ m: N: ~ to c r m v' o ~ O ~' ~: ~ ur . ~ a j i c, c. o, • • o. p: .oc a~ y: c, m ~, ~ t ~ ~ ~ ~ ~ ~ ~ a ~ N ~~ 'y~ ~ c 01 j ~ O. , w~ ~ ~ ~ ~ ~ ~ ~ ~ v. ~ .S: ~ 00. m. 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