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206-128
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, April 4, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC A-05A PRUDHOE BAY UNIT A-05A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 04/04/2023 A-05A 50-029-20116-01-00 206-128-0 W SPT 8666 2061280 2166 1466 1466 1471 1466 78 104 105 105 4YRTST P Brian Bixby 2/17/2023 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 UNIT A-05A Inspection Date: Tubing OA Packer Depth 265 2462 2429 2423IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230217120305 BBL Pumped:2.3 BBL Returned:2.4 Tuesday, April 4, 2023 Page 1 of 1 MEMORANDUM State of Alaska Permit Number: 206-128-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg�j/ r—�I I / 19 DATE: Tuesday, February 12, 2019 P.I. Supervisor �cj l ""L SUBJECT: Mechanical Integrity Tests Packer Depth Pretest Initial BP EXPLORATION (ALASKA) INC. WEO A -05A FROM: Austin McLeod - PRUDHOE BAY UNIT A -05A Petroleum Inspector Tubing 975 Ste: Inspector 975. Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT A -05A API Well Number 50-029-20116-01-00 Inspector Name: Austin McLeod Permit Number: 206-128-0 Inspection Date: 2/5/2079 ' Insp Num: mi[SAMI90205124302 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WEO A-05A Type Inj w - TVD 8666 Tubing 975 975 - 975. 976 PT6lzso " Type Test sPT Test psi 2166 IA 331 zsoz - za7s zan BBL Pumped: 8 BBL Returned: z OA 9 94 96 96 ' Interval 4YRTST p/F P Notes: MIT -IA Tuesday, February 12, 2019 Page I of I • 0 0 0 0 0 0 0 0 0 0 0 ca oco •r cr::L) as —• op LL' N St St Sr LO LC) I� N- U 17' 0 0 0 0 0 0 0 0 0 0 L ON N N N- f� I� t sr Cr) CO • 0, CO 0 0 CO CO CO N N Sr V CO N LC) Lfl CO CO CO I- N- CO CO LU CO CO N O — 0) Cr) CO C)) Lvj N CO 0) CO N N CO CO CO O - LO N I� O a0 O O M Cp O I- - N N e- N CO CO CO C)) CO I- • N- N r CO O sr A- CO CO O CO N N Lf) 00 CO O N CO I- N N CO CO CD MM I-- c.1aaa (c) '1" N CO C) r CO N r LC) I- 00 Ln N I-- O 00 O 00 O N N A- N CT 00 O 'Tr O COV Q M CO r-- N O 0 0) CO O rY CO Sr M • L N N LC) N N- CO CO O N O N N 00 • COC ICE EL 0O O LC) co 00 O CO CO co CO CO CD CD 5 —IZ ~ ZZooaoJJ d -0 * Z �# J J CSO CSO •(n N cO M co Cfl N N 0 0\0 00 N N _ U O b M ( c0\0 a s N N N Ch M (A O) 00 r 0) V V t O r+ 0)to C)) `- N - V' N C)) N C)) O) co d co a) LC) O) LC) Ns N- O N ci 0 N- CO N M C) W W W W I— F- HHH 810 Q Q Q Q Q _ W 0 0 0 0 0 U LNoOQQ2 2 2 2 vZLi. 11W W W W W CC ZDDIHF- HHH D 0o) u) ZZZZZZZJI— • • Packers and SSV's Attachment PBU A-05A SW Name Type MD TVD Depscription A-05A PACKER 1846.8 1846.75 9-5/8"TIW PIN Packer A-05A PACKER 8053.74 6668.13 7" Baker ZXP Top Packer A-05A TBG PACKER 10626.98 8664.21 4-1/2" Baker S-3 Perm Packer A-05A PACKER 10689.98 8714.07 5" Baker ZXP Top Packer 0 0 I p / _ $ ( / / \ / m co E § $ # I o n / F• ) o/ § / � I- 9 / E R ® _ 0 CIS aL ® a 20 .90 U) / a _ . \e - . w .o 2 / ) / 0 / e o - o = N- .o \ 7 § 2 � \ & R / / g / % o e m / o _E — '— o Z T _0 a) 1D \ O ƒ / � ƒ / \ 0-E e a 0 2b c o c -0 0 - D " � -1cCi- a # = o 0- 1 k k \ / \ 2 06CO k L a 0 2 q _ o 5 \ » E o o f - o » U _1 ._ _ o = » # Uo = — # nn � onU) \ C m o/ b / i \c \ / = t \ CDDn 2 ƒ a c 0 f a a $ / 2 © •® 2 a E ■ 4 F 7 © 7 r F / _& m w@ = E o k moo _ to \\ \ / k\ / � � � 2 oacaN- 2 \ AIm # 2G / _� _j 0 (0 % _N a ® I q = I _j < _5 ± = 2 = D 2 .) 9 / � 02 � / % ,- Q- eLi / 0 � Q -0 e I m I o o - o ® \ + - e — 2 e — = e _ r o o c % f ƒ \ c / o_ o_o = ƒ 6 .§ " 0 ƒ _ \ 2 6 / 2 2 .F a) / \ \ / � Z ,- \ % ,- \ :-0 Ce f \ 0 • 0 / / / 2 / \ % >, _ / c 0 a = 2 a _n = Q ,- -0 m q k / % / � % 4- ƒ I � 2 / \ § 4, 0 co o 1 ° / _ E / — « /f - 7 / ? -15 $ 5 / 9 © - o / 4, 2 = o2 b = 0 - = 3ao � $ E/ � \ \ /5 / /» � �� \ _1 ° w , @ 0 0 o \ m E CD U \ \ _0 o \ w_ m b b e ¥ » o 0 a % a � »G 2 \ k0 � k � % / f 2 $ 5 / 2 I / § G f § = 2 / / 7 G _ o » CO + — o S w o = G - 6 y U 2 (..f..),.0 0 2 I G w I o U < : r S- ± / CO/ CO CO M \ \ 7:-, co\A # rEr » / \ / \ < 1Fttt= 4-1/16"CM •" WELLHEAD MCEVOY SA S:H2S READINGS AVERAGE 125 ppm WHEN ON ACTUATOR= BAKER C A_u 5A ON EMERGENCY SLIPS .S A SSWEiL ANGSV WHENLE N�0°@ 11106'. SET ORIG KB.BEV 65.89' ORIG BF.ELEV 46.17' 1 1 ORFG KOP= 2800' ! Max Angle= 99°@ 13227' 1 Datum MD= 10896' #1 4'• C*.Datum TVD= 8800'SS II 1554' H18-518"X20"X0 ��� I �. 13-3/8"CSG,68#,L-80,13=12.415" H 79' I• 1839' -I 13-3J8"X 9-5/8"TNV PKR 111 1846' --I TOP OF 9-5/8"PBR(12') 13-3/8"CSG,72#,N-80 — 2018' BTRS,D=12.347" " 2018' �BOTTOM 9-518"DUPLEX SHOE 'At ��1�� --I Minimum ID =3.725" @ 10673' 2065' j---IFOCi 4-1/2" HES XN NIPPLE [ 214x' 1--{Foci 20"CSG,133#/ft, H 2278' ' , 2190' -{4-1/2"FES X NP(9CR(,D=3.813" K-55 B IRS,D=18.730" ,►l f1' 2800' —j TOP OF CEMENT , 7"LNR 26#,L-80,BTC,13=6.276" —{ 8044' r.I60\ 8044' —111.6'BKR TACK SLEEVE 8055' —9-5/8"x 7"BKR C-2 ZXP LT PKR,ID=6.28" 9-5/8"TBG,47#,L-80,.0732 bpf,ID=8.681" H 8216' &MAC LNR HGR 9-5/8"CSG FALLOUT WINDOW(A-05A):8206'-8222' ' I 10608' H4-1/2"FES X NP(SCR),D=3.813" X- 10629' I-17"x 4-1/2" BAKER S-3 PKR,ID=3.87" ' I 10652' —14-1t2"FES X NP(SCR),D=3.813" I I 10673' H 4-1/2"FES XN NP(9CR),13=3.725" 4-1/2"TBG,12.6#,L-80 Tql H 10685' 10680' —7"x 5"BKR ZXP LT PKR,ID=4.41" .0152 bpf,D=3.958" Cw/11'TEBACK&HMC LNR HGR 7"LW,26#,L-80,BTC,D=6.276" H 10843' \ PERFORATION SUMMARY REF LOG: HALLBURTON/GRJEWR MWD ON 02/04/07 ANGLE AT TOP FE2F: 98°@ 13440' Note:Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SOZ I 2-3/4" r 6 13440-13470 0 09/14/16 2-3/4" r 6 13500-13530 0 09/14/16 2-3/4" r 6 13580-13610 0 09/14/16 I 2-3/4" ' 6 13690-13720 0 09/14/16 2-7/8" ' 4 13950-14090 C 02/07/07 13800' —4-1/2"WFD CEP(09/13/16) I FBTD —I 14091' Oi�i�i 4-1/2"LM,12.6#,L-80 BTM, H 14178' L...'•'1 i .0152 bpf,D=3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/29/77 ORIGINAL COMPLETION 01/17/12'TMWJMD ADDED HRS SARI Y NOTE WELL: A-05A 08/08/91 RWO 04/07/16 MB/JVD UPDATED PERF SUMMARY LOG PERMIT No. 2061280 12/11/94 MO 09/19/16 LLVJMD SET CBF/ADPE2FS(09/13-14/16) API No: 50-029-20116-01 11/16/95 FANO SEC 35,T11N,R13E,1895'FM_&922'F13 02/12/07 N2ES SIDETRACK(A-05A) 02/14/11 MBIJMD ADDED SSSV SAF-EIY NOTE BP Exploration(Alaska) STATE OF ALASKA ' •ALASKA OIL AND GAS CONSERVATION COMMI N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations I 1 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well ❑ Other: ‘f--(4- L'1(3P 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 206-128 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ® 6. API Number: 50-029-20116-01-00 7. Property Designation(Lease Number): ADL 0047472 8. Well Name and Number: PBU A-05A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 1-4 ii.- Cf; 4 Total Depth: measured 14180 feet Plugs measured 13800 feet "l i" k true vertical 9067 feet Junk measured feet f1L E3 L. CUI0 Effective Depth: measured 13800 feet Packer measured 10627 feet true vertical 8981 feet Packer true vertical 8664.21 feet '-'t, "Cr Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 85 30"Conductor 29-113.5 29-113.5 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 13440-13470 feet 13500-13530 feet 13580-13610 feet 13690-13720 feet 13950-14090 feet True vertical depth: 8985-8981 feet feet 8978-8976 feet 8974-8973 feet 8972-8973 feet 9012-9045 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 23-10684 23-8709 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): p� I Treatment descriptions including volumes used and final pressure: SCAb-SCANNED F 2 3 20I?, 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 4905 320 1207 Subsequent to operation: 4129 300 1368 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory 0 Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-425 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature A(t4.1 C`,,,��-- Phone +1 907 564 4424 Date 10/4/16 Form 10-404 Revised 5/2015 V ��/l 6 RBDMS Lc- OCT 1 0 2016 Submit Original Only f/�' / • or 71 ew",\\\11/ iss,, THE STATE Alaska Oil and Gas __ of L1-1 Conservation Commission 1$ ==_ 333 West Seventh Avenue ^R GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 -• Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov ��®� SEA 3 0 2Dq) , Brian Glasheen ` Production Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-05A Permit to Drill Number: 206-128 Sundry Number: 316-425 Dear Mr. Glasheen: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, Cathy . Foerster Chair s/- DATED this I day of September, 2016. RBDMS Li' 5rr - 1 2016 STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COM N APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 • Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend 0 Perforate 0, Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other pr o fi 7c vva c ei 'IT 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 206-128 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development ❑ 99519-6612 Stratigraphic ❑ Service 0• 6. API Number: 50-029-20116-01-00• 7. If perforating: _ What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No IJ PBU A-05A . 9. Property Designation � p � (Lease Number): 10. Field/Pools: ADL 0047472 • PRUDHOE BAY,PRUDHOE OIL • Hyy A 016 11. PRESENT WELL CONDITION SUMMARY £ / 3 / Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): .s 14180 - 9067 - 14091 9045 — Casing Length Size MD TVD Burst Collapse Structural Conductor Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment I See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 13950-14090 9012-9045 4-1/2"12.6#L-80 L-80 23-10684 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and ND(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 0 Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program ® BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 0 Service 0- 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 • GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Glasheen,Brian P be deviated from without prior written approval. Email Brian.Glasheen@bp.com Printed Name Glasheen,Brian P Title Production Engineer A//0/Signature I Phone +1 907 564 5905Date COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: mgr>k Post Initial Injection MIT Req'd? Yes El No Spacing Exception Required? Yes❑ NoI Subsequent Form Required: /a --• 40 Y ,O'--)6.41,4,10,‘.... APPROVED BYTHE Date:/"—/— (/lc Approved by: / COMMISSIONER COMMISSION a/etty 1/7/L 8/3!/16 ORIGINAL RBDMS (, VSEP - 1 2016 ,066 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • 0 a o 0 0 0 0 0 0 0 0 0 0 co0 (0 (0 (000- a- 00 °pNY- (0 �p '- vvv (0N- C) MCD N N Ns Ns rs O O O -4 001 M 0 M00000000N (V V m NOto (000 (ON- NOD00 MM N- NOr- CAMCOCD N 00 CD CO N N 0 M CO O U1 N 1s 0 00 0 0 (0 00 0 Ns N N a- N 00 (0 CO C)) CO c M ti CO Ns O O rsNtiOOd T- (O (0OM N (A N N- 00 00 O N (O N- N V ' V- N 0000 4.0 d MM NN000o ' COd' N OD C- CO N (- O c0 ti 00 U1N O0 W O 00 O O 1- 0 _ ' N N '- NO) OO . O = a a01 CD Ns N N- 00 CD 4 '- CO CV coM N O N Ns OO 00 O N O co N =a VrN 00 � • .Q M � M . (, (0 (0000 0 (0 4 se 00 Y `n -1Zf— z - - ZZz03aocD *k *k •N N „ M00co CO CO NN C = 00 - 0D 00 N N _ V N MACO N N c0 d d OM_ NrcRulmLo � N0NNrC00 ti O CV M W W W W W F- < < < < < 0 0 0 0 0 NUUWWWWW Uu_ u WWWWWQ' XWZ m w W W W W W W W W m 00I- 1- 1- 1- 1— ZZZD � � ZZZZZ JJ • • • Packers and SSV's Attachment PBU A-05A SW Name Type MD TVD Depscription A-05A PACKER 1846.8 1846.75 9-5/8"TIW PIN Packer A-05A PACKER 8053.74 6668.13 7" Baker ZXP Top Packer A-05A TBG PACKER 10626.98 8664.21 4-1/2" Baker S-3 Perm Packer A-05A PACKER 10689.98 8714.07 5" Baker ZXP Top Packer MUM • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD, EAZ,BPG 10/12/15) General Information Well Name: A-05A Well Type: WAG Injection Well API Number: 50-029-20116-01 Well Activity I Conventional 4 Classification: Activity Description: Perforating - Cost Code/AFE: APBINJEC Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Add Pert+ Prof Mod Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory None requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Yes Primary Secondary Required? Engineer: Brian Glasheen Contact numbers: (907) 564-5905 (907) 545-1144 Well Intervention Engineer: Michael Hibbert Contact numbers: (907) 564-4351 (907) 903-5990 Lead Engineer: Brian Glasheen Contact numbers: (907) 564-5905 (907) 545-1144 Date Created: July 21, 2015 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Oil Rate lnj Rate Gas Injection GOR Gas Lift Rate Date Pressure (bopd) (bwpd)Water Rate (scf/stbo) Choke Setting (Mscf/Day) Cut(%) (Mscf/Day) (psi) 3/15/2016 1,141 0 732 Current Status: Operable Flowing Inclination>70°at Depth(ft) 11,106' MD Recent H2S (date,ppm) NA 0 ppm Maximum Deviation (Angle and 99° 13,227' MD Depth) Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 21' 11,387' MD Reservoir pressure(date, no presure, psig) used Y-35A 3,300 psi Minimum ID and Depth 3.725" 10,673 MD Reservoir Temp,F 220° F Shut-in Wellhead Pressure 320 psi Known mech. integrity None problems(specifics) Last downhole operation (date, operation) 9/30/2013 Pull plug post drill by Most recent TD tag(date,depth, 2/7/2007 14,083' MD 4"drill pipe,TD hasn't been tagged since the well was toolstring OD) initially completed Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, Orginally completed in 1977,A-05 was RST to its current location in 2007 and renamed A-05A The first background information, steps in the RST were to repair the IAxOAxOOA communication by effectivaly cementing up the OOA. etc: During drilling the well encountered two faults and one area of lost returnes. Returns were lost first lost in the heel of the well at 10893' MD. The first fault was crossed at 12070' and the well began to flow,this was interpreted as being a result of the Shublik"breathing." The second fault was crossed at 13262' MD, this fault caused no operational issues. The cement job went resonably well, loosing 37 bbls of mud during cement pumping, and circulating 17.5 bbl of cement to surface after. With this informantion, we are resonably sure that there is enough quality cement in the proposed perforation interval to provide injection within the target zone. • The well was first put on injection on 3/23/07. Since that time, the well has injected a total of 3.8 Bcf of MI and 5.7 MMbbls of produced water into the single 140' perforated interval at the toe of the well. The vast majority of the MI that has been injected into this well was in two slugs, the first was in the second half of 2007,followed by a second slug injected through most of 2009. With the high total volumes of water and MI injected, the oil saturation is likely at residual volumes. i The purpose of this program is to expose a new section of Z4B to WAG injection. Injection into a new zone will provide additional support to Y-35B as well as potential support to A-40.-After both slugs of MI were injected in A-05A, there was an approximate 6 month travel time to Y-35B, which resulted in 120 IOR and C1/C3 values near 10 for nearly 2 years. We expect a similar EOR benefit as seen with the most recent slug of MI injected. • • Well Intervention Details Suspected Well Problem: Mature injection interval Specific Intervention or Well Objectives: 1 'Expose an unswept area to WAG injection through setting a CIBP and perforating 120' uphole. 2 3 Key risks,critical issues: Mitigation plan: 1 H2S readings average 125 ppm while on MI Follow RP 2 3 Summary Service Line Activity Step# 1 C Set plug and perforate according to attached perforating form - 2 3 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1) Drift to TD with GR/CCL, and JSN (Sized for a 4-1/2"CIBP). Flag pipe for depth control and tie into tie in log. Contiune logging up to surface to get a jewelry log for future well work. 1 C 2) Set Weatherford 4-1/2"CIBP at 13,800' MD 3) Perforate according to attached perforating form using the CIBP for depth control. 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 2000 Expected Production Rates: - — FTP(psi): Choke setting: PI (bfpd/psi dp) Post job POP instructions: POI ASAP Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: • • ^ Injector Minilog ;. y Techlog r,rcaec:+ P8U WWF 1 aura wA �1 wA • Auit«a l.ausa J Larson Same 14ttLt0 l� �M ltiatt^ 1012212015 ... -.e rr**I .ai_it A KWiV;, 24:.1.1*030340 t`t,.+n,OA..... r:i-itt.s K71 r SM id M i.,,,,a 1. „. )01/47.91014101 4 'ia 1prw7AU 44 ? 4 yq ” >. 44.1 14.0.1..s.!+y 7w7Dtr�T iiae.ds 90.31gaIs :Awr 9r.,, ., 110/..4,:.dIX1 L'nbq.rts VX♦ GR., ;.....ems............... .. ..._. orsTa� , x a API 24.0,1 PE Info Nure of ieeetro n , , lLpis. mo 111 Mit CI �" 8t 5T9U7r (FEET, IfEEi, • O i ¢x TVOSS !lEs' GN.RME0 { �' 4Wt7 ft 8 S0 1uMISA 136 Aa:,•' '"' 1110 t i a , 1Ma { r. .404:10, i 1030 1121 7'WO ; _7.4 ea r0 f i_.„ixo ± «- d 19i�1 i a40 i1931f l-` t1916 1974 i ). a w44 _ _. �'....._�. 19EG a 9920 1PS00 ,. 1001 89X7 -z. "Sc 8964 t . f i., .11000> ."" ._.._._._ ._..... ._..._.._..�_.,_.._..._..._._........ 8919 1 4 . - rt r. 1th 9 ! .. ..�.14121 1410 { 7iliK 8914 . Ii( ` Ilk 1020 1 �T nn�n ++ lvto t t 1tlt, ( 5y F i 11510 1 T 1\1 •S f•`1-�.1 I 1900 i 4_ ^'" farti .116 ,, 19.44 f C.; ` . 19:0 i e . 1910 + 11 PC'/41, ; 1470 + 1'1419 1618 _..... : 8953 .itXkl• .. .._. > 1919 _.. . ' i 1494 ,. • • • - LIMN,I re tau_ 1 HALLIBURTCM ROP Rate of Penetration DGR Dual Gamma Ray EWR-Phase 4 'bIINSITE Horizontal Presentation - .'410loommosommoommomme.....— -4 OH r 1 : 600 i 1 : 240 1 Sperry Drilling Services Comp BP BP Exploration (Alaska) Inc I , Rtg Nabors 2ES Wi- A-05A1 Prudhoe Bay Unit , .... S. .., Country a United States -, (..., i API Nor1.1*- 50-029 20116-01 -,, Er° 4 .., ''- % at /3 15' 53 812- Notth .... - c. ctrl- 1 0 fiC/ 14:1 44$' 3 647- Wert . A14 At 'Mt Ificf=nztfion L _ < ' DOS Onitstfing ) ns PVIDP,esstre fi.ffile Crlf"IJ • rileato Sea I,este, I--. , , 0 00 ft ' ''',:. 0 00 ft Doll Floor 74 7 ff; ; • —; . ,,t ,', _ 74 67 ft A 46 17 ft troll r toor I MO L O ; j % ' 0,00 ft 8.206.00 ft 14 180.00 ft , ' NI. 116 ,: % AA-1,474-txa6479914 13-Jan-07 04-Fet)-0/ i ''.:4.00rt .' A Otil it ft ,° . ., I-loaf 1 .1.,n-81 ' ' ,' - 1I•Ser oti . r ,.. RN n r ' .1• n-, ' 1Vi...`._ . !' P. -... . *1_„.. _ 1.. __ . , , - - . ' 1 • 0.2 ohm-metre 2000 SROP SEMP ..„........_ .........., . . 500 feet per hr 0 0.2 ohm-metre 20c: SGRC SEDP .._ • . • • MD I 150 api 300 1:600 '2 Ohm-metre 2000 I I ... _._. 1. ._ I I _ t\ ..., f 1 ,....:_ , * �..,.....rt._ 5 , —1....,_ _ _ �_ w w,.. i S } t y ........,......4.. _.._._. _, �._.tor_, I . ......,.... ._.. - ...._ I ................-...-. woo._ ,r , t i k._ _ . t s ....„....�.»...,....- { 1 r) % ti l I t j.5.00 s m i .. 1 U --.''. * - .,. 0 { {« _ :lUEx1' SECS' f r i _.,, . _. ___. x 1 471. 4 . j 1 • • _ ,t. - .. IBM .._. 01 II�� P -----4 _. ,. F iliM s I/ •P MIN , i, t 4 t +. _ _,., 1\a- .i....-....,... II, „:- I min 4,4_ r4 t . p 4 ......44::::::. 4 „44.44:4,,, 4. .4.. .4_444 13500 WM. r ! t fallatala)1/4 SE i. a i tI' „_______ 1 4 1 NM 1 4/0111 1----t iy p t , Q t zr F 4 i . t affr44 „.....„.1...__________, 0 [E aii.Mr R ''''"""*.. .............4— '''.. , • • • + () _ _ . 4 . L i ... . ,.__ • a. 1 .. .. t------«.-... .... y..,... .A ,.......,. .,1-1,------ ,......- —..,......,..-«..",......,.,w,-,.�,,.,,-- ,, { .._..,..... A j Z 4 4- 4 e t (p • tit... — .. t .I ? -...''. Y • ,ice ! ---.�. ...,. ,.__ .....,.a,... ._.,..,,.....,_ "__ ,, ... .� -. 3— s .. s.- ,...,.. ....... : ¢. '7- _,,.,,D. _ d ... ___.,.,� 0 __ „i t3 w_., ° ,w Mr im e. I .d 4....._ • 4;7'''' , > , f ... 1M ��* 4,...4, k. tea.-..., . �,_. '* 4 IL. ) ' .._ ..— § — i. s nom-. i e — Te:....-” .a L w i .... _.. „_._. • ....e..w» ..+ V ii 4. .1 -.. . ...„... 4..."'" -F w • • • .._. <*-- i rr- i t _,._... ----4,.....„... ,,:v „..._ .___4____._.__ ... y - y_.. i . ,_»t-.»—......, , , p ,......_ .. 4 R w J ,— Ti .,,. jtt. Jjjr. •....a.. iS{ TREE= 4-1/16"C1W • SA -ES.H2S READINGS AVERAGE 125 ppm VVHE34 ON . 1WELLHEAD= MCEVOY 1 MI. WE REQUIRES A SSSV WHEN ON Af I. 9-5/8"CSG SET ACTUATOR BAKER CI A-05A ON EM ERGENCY SLIPS. —*WELL ANGLE>70*al 11106. OF1G KB. ELEV 65 89'1 ()FIG BF. ELEV 46.17' )4144'41;14:111 I. 4 1839' I--1133/8"X 9-5/8'T1WKR OM KOP= 28001 0 I Max Angle= 99"@ 13227 0l Datum MD= 10896' A iC4.. 1.palurn TVD= 3800'SS1 A '. 0 f 1554' j—18-5/8"X 20"X0 I t - P 1 13-3/8"CSGID= —1,68#,L-80, 12 415" 1 79' ' T I. I. 1846' 1--I TOP OF 9-5/8"RIR(12') 113-3/8"CSG,72#,N-80 H 2018' LBTD12.341o. 2018' —BOTTOM 9-5/8PL "DUEX SHOE triii 1 RS, = " OA ._., . Minimum ID =3.725" @ 10673' L 2065' __ if-1757c 4-1/2" HES XN NIPPLE 120"CSG, 133#/ft, — 2278' I I 1 2190' H4-1/2"FES X NP(9CR),13=3.813" K-55 BTRS,ID=18.730' vi I ie• VA 2800 11--1 TOP OF CEVENT t A 7'LNR,26#,L-80,BTC,13=6.276' 1-1_ 8044' C,1 8044' j-H 11.6'BKR TACK SLEEVE 8055' 1-9-5/8'x 7'BKR C-2 ZXP LT FKR,ID=6_28" 1 19-5/8"TBG,47#, L-80,.0732 bpf,13=8,681" H 8206' i&HMC LM R HGR 9-5/8"CSG&CLOUT VVINDOW(A-05A):8206'-8222' I 1 10608' 1-14-1/2"FES X NIP(9CR), ID=3.813' C X 10629']H r x 4-1/2" BAKER S-3 FKR,0=3_87" I 1 f 10652' H4-1/2'HES X 11P(OCR),ID=3.813' 1 1 10673' —14-1/2"FES XN NP(SCR),ID=3.725" 4-1/2"TBG, 12.6#.L-80 Tat H 10685' i 10680' 1-7"x 5"BKR ZXP LT PKR ID=4.41' .0152 bpf,U=3.958" C. w/11'TIEBACK&HMG LNR HGR 1 7"LM,26#,L-80,BTC,ID=6.276" —1 10843' PERFORATION SUMMARY _ .... REF LOG: HA LLIBERTON GR/EWR PAM)ON 02/04/07 .,._. ANGLE AT TOP PERE- 77'@ 13950' Note:Refer to Production DB for historical perf data SIZE 1 SPF INTERVAL Opn/Sqz 1 SHOT SQZ ,> - A \?IP 2-7/8" 4 13950- 14090 0 1 02/07/07 i -- ._ I 1 R3TD H 14091' I 1.01.1 4....t 14-1/2"LW, 12.6#.L-80 13TM, 1— 14178' i. .0152 bpf,CI=3.958" 1 DATE i REV BY 1 03MMENTS DATE 1 REV BY COMMENTS PRUDHOE BAY INT ! I i 10/29/77 i ORIGINAL COMPLETION 02/14/11 fvf3JJMD ACOED SSSV SAFETY NOTE 1MB_L A-05A 08/08/91 RWO 01/17/12 TM4/J0.13 A DDEDH2S SAFETY NOTE PERIVIT No: 2061280 12/11/941 RWO 03/12/14 TAQ/JMD ADOED SAFETY NOTE Al No 50-029-20116-01 11/16/95 RWO 02/10/16 TK/JM) REMOVED SAFE I Y NOTE SEC 35,T11N,R13E 1895'F14...&922'FEL 02/12/07) N2ES SIDETRACK(A-05A) 04/07/16 M3/JMD UPDATE)PERF SUMMARY LOG 11/09/091 SV DPG DRAFT FINAL 1 BP Exploration(Al as ka) ____ .—_. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,February 24,2015 Jim Regg P.I.Supervisor I leo z/2 is SUBJECT: Mechanical Integrity Tests C BP EXPLORATION(ALASKA)INC A-05A FROM: Lou Grimaldi PRUDHOE BAY UNIT A-05A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Jr NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT A-05A API Well Number 50-029-20116-01-00 Inspector Name: Lou Grimaldi Permit Number: 206-128-0 Inspection Date: 2/15/2015 Insp Num: mitLG150215135408 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min We'l l A 05A - IType Inj T WTTVD 8666 "Tubing 1006 1006 1006 1006 • PTD _—r-2061280 Type TestLSPT Test psi 2166 - IA 958 -1 2503 - 2485 2484 T Interval I4YRTST P/F P OA 72 . III 115 113 - i. Notes: 1 3 Bbl's Neat McOH pumped 1.5 returned.Good solid test.All required paperwork provided prior to start of test.Noticed less than 100 psi differential IA/Tubing this morning Ryan Hayes will investigate cause Otherwise good solid test fl (Ct1k",Zdrs T64—CL* -r o p c• u:ps 00- SCANNED MAR RF u,5 Tuesday,February 24,2015 Page 1 of 1 i71,c ,--(7c4 (pr1cotzec kith 4v e 44-4 M if Lq 1St)z15 135 Lower Upper BARO Chassis Module Module Module Left Scale Right Scale Serial Number 072721 073142 073115 073142 073115 Model NV 10KPSI 10KPSI Run Start Time 15-Feb-15/09:29:41 Run Duration 40 minutes 10 seconds Run Tag Run# 2 Logging Interval 1.0 Data Points Point# Time OA psiG IA psiG Tubing psiG 1 00:00:00.0 72 958 1006 79 00:01:18.0 72 959 1006 499 00:08:18.0 111 2503 1006 1400 00:23:19.0 115 2485 1006 2300 00:38:19.0 113 2484 1006 2411 00:40:10.0 113 2484 1006 OAP 2-15-15 A-05 AOGCC MIT- IA IAP/Tubing 120 - 2400 100 - — 2200 -OA psi — 2000 80 - -IA psi — 1800 Tubing psi 60 — 1600 40 — 1400 — 1200 20 — — 1000 0800 00 0 alb �0 PO 00 41 00. 0�. P\ N. r10. 06. t0. 00. 00. 00. 00. 00. 00. 00. Elapsed Time hh:mm:ss • A3. ++ i + I I I r` t. • • • • • { I I T t • 1 � rH ° TREE= 4-1116"OW SAFETY NOTES:MS READINGS AVERAGE 125 ppm WHEN ON 'WELLHEAD= MCEVOY ACTUATOR= B ER C A�'05 A ON EMERGE ICY SLIPS. WARNNG:RADIO TRANSMITTER IN 'ORtG KB REV 65 89' WEATHER MONITORING SHACK MUST BE TURNED OFF OIRIG BF.REV 46.1T , , BEFORE ANY WB.LWORK INVOLVING NON RADIO SAFE ORIG KOP= 2800' 1' 1 EXPLOSIVES CAN BEGIN.CONTACT PAD Max Angle= 99°Q 13227' # 1( OPE RATOR"""WRL ANGLE>70°@ 11106'. Datum MD= 10896' #4 ,44 Datum TVD - 8800'SS ►• 4 v '+ 1654' 1 16-5/8"X 20-X01 ►.: I I 1839' 13-3/8 X 9-518 TNY PKR 3318_CSG,68#,L 80,ID=12 415"j - 79' • ►�i 14 •---- i V 1` 1846' 1 ff.&OF 9-5/8"P8R(12')l 13-3/8"CSG,72#,N-80 -( 2018' ► 1• • _—- _ _ BTRS,D=12.347' _ 2018' BOTTOM 9-5/8"DUPLOC SHOE . _ . . ##, 0444 ---___-J-L_. . _ --- - _. ._i ►DD, ,e'. _ Minimum ID =3.726"@ 10673' (- Ross' 1-fF1 4-112" HES XN NIPPLE i 2146' -{FOC j 20"CSG,133#/ft, -{ 2278'- ' ` [ 2190' 1-14:1'/2;'HES X NP(9CF�,D=3.813", K- .. 55 BTRS,D=18.730' ) ___ 1ry' ' 2800' I•-fTOP OFB�lT C"LNR 26#,L-80,BTC,13=6.276" -r 8044' ►�4 ►i4 _8044'J--111.6'BKR TEBACK SLEEVE 1 8055' 1 9-5/8"x 7"BKR C-2 ZXP LT PKR ID=6.28" .} — " MACLNRHGR T 5/S_TBG,47#,L-80,.0732 bpf,ID=8_681"1 {- 8206'J -- - __ — 9-5/8"CS[ GvIJourvwioW(A.o5A):8206'-5222' 1 N r r10608'-114-1/2"-1/2"HES X NP(9CR),D=3.813'1 g L 10625' I-L7"x 4-1/2" BAKE R S-3 FCR,D=3.87" ( I i 10652'J--4-112"FES X NP(9CR),D=3.813' 1 IL 1067371--E4-1/2"FES XN NP(9CR),D=3.725" 4-112"TBG,126#,L=80 TCJI ]-110685' ( 106 _j-rxx "BKR ZXP FKR,ID=4.41"=1 .0152 bpf,D=3.958" - ----- w/11'5TACK 8 MACLT LNR IiGR L7"LW,26#,L_80,BTC,D=_6.276" ,I--1•-10843' '--J PERFORADON SUAN ARY REF LOG: GR/CCL 01/09/07 ANGLE AT TOP PERF: 77"@ 13950' Note:Refer to Production 136 for historical perf data SIZE SPF INTERVAL OprdSgz SHOT SQZ 2-7/8" 4 13950-14090 0 02/07/07--- PBTD -{-14091" 1 ,,11 4.1/2"LW{12.6#,Lao ETN( 1-1 14178' - 1'1. .0152 bpf,13=3.958" DATE REV BY COMMENTS ' DATE REV BY GOA/WITS - FRUDHOE BAY INT 10/29/77 * ORIGINAL COMPLETION02/14/11 1.43/JM) ADDEDSSSV SAFETY NOTE_ WELL: A-05A 08/08/91 RWO 01/17/12 TMWJMD ADD®112S SAFETY NOTE PERMIT Pb: 2061280 12/11/94 RWO 03/12/14 TAQ/JMD ADDED SAFETY NOTE AR No: 50-029-20116-01 11/16/95 RWO r SEC 35,T11N,R13E,1895'FII_&922 FES. 02112107 N2ES SIDETRACK(A-05A) �_ 11/09/09 SV DRG DRAFT FINAL -r BP Exploration(Alaska) Image Project Well History File hover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. - ~~,~ Well History File Identifier Organizing (done> ^ Two-sided III IIIIII II III II III ^ Rescan Needed III IIIIII II II III III RE AN Color Items: DIGITAL DATA Diskettes, No. 1 OVERSIZED (Scannable) ^ Maps: ~Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Project Proofing III IIIIIIIIIII IIIII BY: Maria Date: ~ ~ /s/ a i P aration S 30 = ~ + ~ ~ =TOTAL PAGES rep cann ng x D (Count does not include cover sheet) / / SY: Maria ate: s Production Scanning III IIIIII IIIII IIIII Stage 1 Page Count from Scanned File: -~~ (Count does include cov r sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Dater ~ ~ r~ Is/ ~ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II')I) IIIII IIIII ReScanned BY: Maria Date: /s/ Comments ab{~~ut this file: Quality Checked III IIIII III II'I III 10/6/2005 WeII History File Cover Page.doc • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March 14, 2011 TO: Jim Regg .3) 2s1 r P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC A -05A FROM: Jeff Jones PRUDHOE BAY UNIT A -05A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ,J} NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT A - 05A - API Well Number: 50 Inspector Name: Jeff Jones Insp Num: mitJJ110313175119 Permit Number: 206 - 128 - Inspection Date: 3/11/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 A -05A ( Type Inj. W'I TVD 8666 '` IA 30 2520 ' 2480 2480 ' p 2061280 ' TypeTest SPT Test psi 2166 ' OA o 0 0 0 ■ Interval 4YRTST P/F P i Tubing I 920 920 920 920 Notes: 2.4 BBLS methanol pumped. 1 well inspected; no exceptions noted. 0. `(fit 1 1 Monday, March 14, 2011 Page 1 of 1 • ~~~~` ~~ ` ~,. ~y ~~ tea: ~_ ~-_~. .~~ ` ~. „ ~ ,~ ~~~ MICROFILMED 6/30/2010: DO NOT PLACE ANY NEW MATERIAL UNDER THLS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc q ~~ DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061280 Well Name/No. PRUDHOE BAY UNIT A-05A Operator BP EXPLORATION (ALASKA) INC MD 14180 TVD 9067 Completion Date 2/9/2007 REQUIRED INFORMATION Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: DIR / GR / PWD, MWD DIR / GR / RES / ABI / IFR, USIT / CBL Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No o~ Cement Evaluation 5 Col 1 ~',~ED D Asc Directional Survey ~D C Lis 15310 ~amma Ray ~~ Rpt 15310 L IS Verification ~ E c~ED C 1696~/See Notes C}iC~og Induction/Resistivity 25 Col ;~ S,eg Induction/Resistivity 25 Col Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y /~1 Chips Received? SPY Analysis ~- Received? Completion Status WAGIN Current Status WAGIN API No. 50-029-20116-01-00 Directional Survey (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 50 8605 Case 2/20/2007 USIT, CCL, GR 4 Jan-2007 28 14180 Open 4/4/2007 7928 14189 Open 8/3/2007 LIS Veri, GR, ROP, FET w/Graphics 7928 14189 Open 8/3/2007 LIS Veri, GR, ROP, FET 0 0 9/30/2008 PDF, EMF and CGM ~' graphics for EWR logs 8206 14180 Open 9/30/2008 MD ROP, DGR, EWR 6796 9067 Open 9/30/2008 TVD DGR, EWR Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~/ N Formation Tops ~ N ~.~ Comments: DATA SUBMITTAL COMPLIANCE REPORT 11 /18/2008 Permit to Drill 2061280 Well Name/No. PRUDHOE BAY UNIT A-05A MD 14180 TVD 9067 Completion Date 2/9/2007 Compliance Reviewed By: __ - __ __ _ ______ Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20116-01-00 Completion Status WAGIN Current Status WAGIN ,~n ~ ~U~I~G~ Y Date: __ _ ~ I " ~- °w,2 -`2 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: A-OSAi September 18, 2008 AK-MW-4730559 A-OSAi: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-20116-01 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-20116-01 Digital Log Images: 50-029-20116-01 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 9951-8 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~'~ Uz~a~-ray ~` 169~a I~'C:iA14ZCAL lTTTgGRITY R :PORT • ~:-(JD i:,._~ : ,` 1'Z ~Q~ QPER ~ FIELD ~~ ~~v~~~ :~G rC~~~~~. al~'C7~ h.7-i• NUMBER ~°-®~~ .n ~ LL DAT_ ~_ TD : I~SS~ _i~.. cl~; (~ ~TVD ; ?BTD : ~ ~~_MD ~C,~S ?~VD c;as ing : ~ ` Shoe : 1~~~~ ~ID ~TVD ; liV : ~.l{~ ?~ ~Ttr-'?i -=.,e.. ~~_ Shoe : ~~_'~ `~~~ TTTD ~ _Cr . 1~G`13 *_-s.D~_:';D _~oi~~ w~ Pacice: ~~~. '.~ TVD; het ~t ~C~~~~ =o1e Sipe ~il~. ena ~Pi~~ Perfs ~~C15~ to i~ ~~ ~'~'L'r'..r~?~=C~._., ZtITEGRTTY - ?A.RT #' raaulus Press Test: _? 15 nin ~0 min Corse:~t s : -k~b: v~ ~ S~- ~ S~J t-rc s - _ V ~~ `C~~N ~-~ _~ ~ '~'CH~NZC~ ~.. INTEGRT'f'`~ -PART #2 Cement Volumes:. ~.mt. Liner ~h~~S ; Csg DV Cw~ JoI to cover oeZ's _ =eOre~3Ca1 TOC ~i ~~y~ In AOGCC File Cement Bond Log (Yes or No) ~ ; ~~~h ~- ~ ~, i ~ • CBL Evaluation, gone above perfs _ ~~~~ ~,.5'~~ ©~ Production I.og: TpPe : Evaluation CON~LJS ~ Ot1S : ?arm :I: ?ar~ r2: Page 1 of 3 Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA) Sent: Wednesday, October 31, 2007 3:51 PM To: Cheve Meyer Cc: Gary Elmore; Robin Smyth Subject: RE: A-05A USIT Thanks Cheve. Got it. Tom From: Cheve Meyer {mailto:cmeyer@prudhoe-bay.ollfieldslb.com] Sent: Wednesday, October 31, 2007 2:19 PM To: Maunder, Thomas E (DOA) Subject: RE: A-05A USIT Tom, Hopefully this works. I will send the hard copy via Terrie. thanks, Cheve At 01:59 PM 10/31/2007, you wrote: Thanks Cheve, I thought this matter was wrapped up as well, but when I recently checked on receipt of the log I could not locate it. Can you zip the file? I can get some pretty big files zipped. Otherwise, drop it on a CD and get with Terrie Hubble in drilling. She can put the CD and hard copy in the "pouch" that the courier brings over. Tom From: Cheve Meyer [.mailto:cmeyer@prudhoe-bay.oilfield.slb.com] Sent: Wednesday, October 31, 2007 1:26 PM To: Maunder, Thomas E (DOA) Subject: RE: A-05A USIT Tom, I talked with Gary Elmore today and he said that you still haven't received a copy, when I talked with Andy I thought he was going to wrap this up. I have both an electronic copy and a hard copy for you, but the electronic copy is just over l OMB, is that to large to email to you? If it is do you have an FTP site I could dump it on for you? I have a meeting for the rest of this afternoon, but I should be able to breakaway tomorrow do deliver it to you, where is your office located? cheers, Cheve 1 /31 /2008 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 31, 2047 2:41 PM To: Gary Elmore Subject: RE: A-05A Bond Log Page 1 of 1 i Gary, I did get a message from him. I responded back and included your by ebox. One thing, unless a log or other communication is specifically addressed to me, it just may go to the files. Last time I looked, the deep USIT from A-05A was not there in hard or imaginary form. Thanks, Tom From; Gary Elmore [mailto:elmorei@anchorage.oilfield.slb.com] Sent: Wednesday, October 31, 2007 2;36 PM To: Maunder, Thomas E (DOA) Subject: A-05A Bond Log Hi Tom, I stopped by the BP office after speaking with you at lunch and spoke Cheve concerning the Bond log. Cheve will get it to you ASAP. Please let me know if you don't here from him right away. Thanks Tom... -Gary Gary Elmore Account Manager - BP Exploration (Alaska), Inc. Schlumberger Oilfield SenriceS (907) 273-1747 Office (907) 830-2931 Cell (907) 746-5]59 Home Gary. Elmore@. slb.com_ Gary. E Im ore@bp.com 1 /31 /2008 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 10, 2007 2:49 PM To: 'Farmer, Andrew W (SAIC) ;Cheve Meyer Cc: 'Christine Mahnken' Subject: RE: A-05A USIT Andy and Cheve, I hate to return to what I thought was a closed issue, but I have not been able to find a copy of the January 29 USIT for A-05a. Would one of you please send a hard copy? Thanks in advance. Tom Maunder, PE AOGCC From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, May 22, 2407 7:30 AM To: Farmer, Andrew W (SAIC) Cc: Christine Mahnken Subject: Re: A-05A USIT Andy, Christine and I have checked and it does not appear that we have received a copy of the January 29, 2007 USIT for A-OSA. I'd appreciate your sending a hard copy as soon as practical. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 5/17/2007 5:41 PM: Andy, I will have to check, I think the proper lag came in. Tom Farmer, Andrew W (SAIC) wrote, On 5/16/2007 1:28 PM: Tom, Did you receive A-05A USIT dated 1-29? Andy Farmer »At 02:54 PM 3/13/2007, Thomas Maunder wrote: »>Rob, Terrie, Andrew and Robin, »>Not sure who can best handle this. I am reviewing the completion »>report for PBU A-05A. A companion report was also sent for the »>abandonment of the original well A-05. Since A-05A is completed as »>an injection well an assessment of the primary cementing of strings »>in/near the reservoir is part of the review. Any available cement »>assessment logs are also examined. »>The log available in the AOGCC file is not the correct log. 2 USIT 10/11/2007 • Page 2 of 2 »>logs were run in the well. The copy I currently have looked at was »>run on January 4 prior to the major tubular replacements done in the »>well. »>Although the well name and API number listed on the log are for »>A-05A, I believe that the correct name and number should be A-d5. »>The 7" casing examined by this log was either pulled or abandoned »>below the EZSV subsequently set at 8200'. New hole was not drilled »>until January 17. »>The correct log for A-05A was run on January 29 and examined the new »>7" liner as well as the tieback string. It would be appreciated if a »>hard copy of that log could be submitted. »>Terrie and I recently exchanged messages regarding when work on an »>"old° well (in this ease A-05} ends and the "new" well (A-05A} »>begins. The protocol used by the Commission is that the new well »>begins when the window is cut and new formation drilled. When »>drilling permits and sundry notices are reviewed, a "line" is usually »>drawn across the page with a notation made where the new permit to »>drill takes effect. It is recognized that the work scope of »>operations such as accomplished here is complicated. However it is »>requested that for labeling and naming purposes that work »>accomplished prior to actually making new hole be credited to the »>original wellbore. »>Although it is likely that there are a number of logs in the »>Commission files that do not conform to the protocol described here, »>it is not necessary to attempt to reconcile the naming. However, for »>the future your attention to this matter will be appreciated. Call »>or message with any questions. »>Tom Maunder, PE »>AOGCC 10/11/2007 WELL LOG TRANSMITTAL To: State of Alaska July 25, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: A-OSA, AK-MW-4799186 1 LDWG formatted CD rom with verification listing. API#: 50-029-20116-0 l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~ ~~r Dat~i~ ~ ~ ~~~~ Signed: ~, ~,.or~~ssic~`t >~{ ~ ,~s v'~°` '' ~~~ 2c~-~a~s ~ ~s3rd iti MEMORANDUM To: Jim Regg `~~~ f ~ ~ ~+ ~ 7 P.I. Supervisor ~"( FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Friday, April 13, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC A-OSA PRUDHOE BAY UNIT A-OSA Src: Inspector NON-CONFIDENTIAL 06 - ~~~ Reviewed By: P.I. Suprv `)~- Comm Well Name: PRUDHOE BAY UNIT A-OSA Insp Num: miUJ070410072530 Rel Insp Num: API Well Number: 50-029-201 t6-01-00 Permit Number: 206-128-0 Inspector Name: Jeff Jones Inspection Date: 4/8/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A-OSA Type Inj. w TVD 8666 IA 1a7s 2azo zalo zoos P.T.D 2o61zso TypeTest sPT Test psi 2166.5 OA 60 I]0 IIO Ios Interval ~IT'~- P/F P / Tubing Iaso i Iaso Iaso Iaso ~ NOteS' Post initial injection MIT. 1.1 BBLS methanol pumped. Friday, April 13, 2007 Page 1 of 1 r 'TREE = 7-1 i 16" SM CIV~J lNELLHEAD =13-5!8" MC~JOY-CON'J ACTUATOR = OTIS KB. ELEJ - _ 65.89. BF. ELEV = 46.17 '<OP = Pv1ax Angle 2800' 54' Datum \-1D = 10852` DatumT~~G= 8800'SS 4- : 2" NJiS X NIP. III = 3.813" ~~~~ SAFETY~ES: **V'~ARNING: RAOIt3 TRANSMITTER IN 1111 FATHER IVIONITORING SI!-IACbC Mt}ST BE T4IRNEL9 OFF BEFORE ANY WELL1lUC}Rlt INVOLVING EXPLOSIVES CA.€~ BEGIN. CONTACT PAI3 OPI=RATC3R** °" ~IllffYtUi'71 ~ _ ~.'~~~3°f '~~~i7~a' 13-318" CSG, 72#, N-80 2018` BTRS, ID =12.347" 20" CSG 133#lfi, 227$' K-55 BTRS, ID = 18.730" Top of Tie-back Cement 277$' Top of 9-518" YIW'irtdoW ' 8200' 7" Inter cut ~ -8500' 4-112", 12.6#, L-8f7 Tbg cut ~ 8700' -TOP OF 40' TNV PSR 9272' Est top of P8A Cement 9000' X 7" TM/ LNR TOP PKR/HGR W/40" PBR [-{ 9312' 9-5/8"' TBG, 47#, L-80, _0732 bpf, ID = 8.681" 9$14' 9340' 41!2" CUT OFF TBG STUB .....9341`. 5-314" CUSTOM OVERSHOT, ID = 4.655" 9348` 7" BKR SABL-3 PKR lull KBH-22 ANCHOR, ID = 3.875" ~~ I 10516• 4-112" WLEG 41/Z" 7'BG, 12.6#, L-80 NSCT, 10516` .0152 bpf, ID = 3.958" PeTD 11259` 7" LiVR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 1136fl` 11259' (--~2 SLIPS OFF SCAB LNR ON BTIIA (11116/95} DATE REV BY COMMENTS DATE REV BY COMMENTS 10!29177 ORIG~JAL COMPLET~N 05/09101 CFUKAK CORRECT~NS 08!08191 RWO i f /f 7/42 BM!KAK 9-518" TBG D1=P7N CORRECTIO 12/11/94 RWO 02103,'07 D1WBN Rig Skietrack & Corr~pleYion .11/16/95 RWO 02!12/07 1PAG DRLGDRAFTCORRECTIONS 01/22101 SIS-MH CONVI=f2TED TO CA M!k S 03102101 SIS-LG FINAL ~ 1,554` I-I 18-5/8' x 20" XO 1,75Q` - 13-318" L-80, 6811, I.D =12.415' 1$39` 13-318" X 9-518" TNV PKR '~$q.6' --TOP OF 9-5/8" PBR (12') 1857' BOTTOMS-5i8" SEALASSEMIBLY 2fl18' BOTTOtU19-5/8" DUPLIX SHOE 2 800` TOC in 7" Tieback 8,044` 7" x 9-5/8" BKR PKR/Han er ` 4-1/2" 12.8", L-80, TCII 10,60$' 4112" X Nipple {3.813" 1D} 1 pg2g• 7" x 41 /2" Baker S3 Packer 10,652' 4112" X Ripple {3.813" ID} '[ 0673' 41 f2" XN N~tple {3.725" ~} 106$0' ~'• x 7" €iKR F4Gt2~~{R 10685' 4 1!2" UVi.1=G 40,843' 7" 26# L-80 (6.276" ID} 4-112'• 12.61#, L-80, [BT-M Firoducfion Liner.. 1417$' PBTD - 14090' PRUDHOE BAY UNfT WELL: A-05Ai PERMIT No: 206-128 A Pt No: 50-029-20116-01-00 SEC 35, Ti 1 N, R13E, 1895' FNL & 922' FEL BP Ekplaration (Alaska} Re: PBU A-OSA (206-128) • Subject: Re: PBU A-OSA (206-128) From: Thomas Maunder <tom_maunder rz~admin.state.ak.us> Date: Tue, 1(~ ,Apr 2007 08:41:58 -0800 "Tv: Ancir~~~ }~ari~~cr ~~:~~ndre~~'.f-~u~n~rr!crbp.~x~m-', Cheve Meyer cincv~r~u'.pni~h~c-hav.~~il{iel6.slb.com-~~~ C'C: Rohert ~l~ir~~ack ~'-Ri~h~rt.I~ir~~~ick'uE3['.com%, ~~errie t [uf~hle ~_hubhl~tl ~r!f~~~.c~~rz1-=. Ki~bin Smith ~~"rsm~ih uanch~~ras~~.~~ilfirlcl.sih.c~»n:>, ! I~~~~~ard Okl~~nd ~=hc~~-~ar~l oklan~l u,admin.sta[c.~~k.u~~~. All, The 407 documenting that this well is injecting has been received. It still does not appear that the January 29 USIT log has been submitted. I would appreciate if someone would send me a pds copy of the log. Thanks. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 3/13/2007 2:54 PM: Rob, Terrie, Andrew and Robin, Not sure who can best handle this. I am reviewing the completion report for PBU A-05A. A companion report was also sent for the abandonment of the original. well A-05. Since A-05A is completed as an injection well an assessment of the primary cementing of strings in/near the reservoir is part of the review. Any available cement assessment logs are also examined. The log available in the AOGCC file is not the correct log. 2 USIT logs were run in the well. The copy I currently have looked at was run on January 4 prior to the major tubular replacements done in the well. Although the well name and API number listed on the log are for A-05A, I believe that the correct name and number should be A-05. The 7" casing examined by this log was either pulled or abandoned below the EZSV subsequently set at 8200'. New hole was not drilled until January 17. The correct log for A-05A was run on January 29 and examined the new 7" liner as well as the tieback string. It would be appreciated if a hard copy of that log could be submitted. Terrie and I recently exchanged messages regarding when work on an "old" well (in this case A-05) ends and the "new" well (A-05A) begins. The protocol used by the Commission is that the new well begins when the window is cut and new formation drilled. When drilling permits and sundry notices are reviewed, a "line" is usually drawn across the page with a notation made where the new permit to drill takes effect. It is recognized that the work scope of operations such as accomplished here is complicated. However it is requested that for labeling and naming purposes that work accomplished prior to actually making new hole be credited to the original wellbore. Although it is likely that there are a number of logs in the Commission files that do not conform to the protocol described here, it is not necessary to attempt to reconcile the naming. However, for the future your attention to this matter will be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 4/11/2007 11:35 AM ~~~~iV ^` ~~ STATE OF ALASKA • ,x'9'0 APRA~~Q IL AND GAS CONSERVATION COMMISSION Alaska Oil~~a~L<'efi~~i~+~S~M OR RECOMPLETION REPORT AND LOG Anchora e Revised 04/05/07: Put on Injection 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG zoAAC zs.~o5 zoAAC zs.»o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One th 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Dat Comp Susp., or Aband. 2/9/2007 12. Permit to Drill Number 206-128 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/18/2007 13. API Number 50-029-20116-01-00 4a. Location of Well (Governmental Section): Surface: 1 ' FNL 23' 9 7. Date T.D. Reached 2/4/2007 14. Well Name and Number: PBU A-05Ai , 9 8 6 FEL, SEC. 35, T11 N, R13E, UM Top of Productive Horizon: 2910' FNL, 747' FEL, SEC. 34, T11 N, R13E, UM g KB Elevation (ft): 74 67' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 262' FNL, 90' FWL, SEC. 02, T10N, R13E, UM 9. Plug Back Depth (MD+TVD) 14091 + 9045 Ft Pool 4b. Location of Wel! (State Sase Plane Coordinates): Surface: x- 654462 y- 5948551 Zone- ASP4 10. Total Depth (MD+TVD) 14180 + 9067 Ft 16. Property Designation: ADL 047472 TPI: x- 649380 y- 5947435 Zone- ASP4 Total Depth: x- 650273 y- 5944820 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: DiR / GR / PWD, MWD DIR / GR / RES / ABI / IFR, USIT / CBL 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 30" Conductor Surface 99' Surface 99' 36" Cemented to Surface with PF II 20" x 18-5/8" 133# / 96.5# K-55 Surface 2278' Surface 2278' 26" 8700 sx PF ii Multi le Sta es 13-3/8" x 9-5/8" 68# / 47# N-80 Surface Surface 6770' 12-1 /4" ~szs sx class'G', 525 sx PF 11, 1878 sx AS I 9-5/8" x 10-3/4" 47# / 55.5# N-80 1839' 2015' 1839' 2015' Tieback 100 sx PF II (Top 3 Jts 11-3/4" x 9-518" Thermocase) 7" 26# L-80 Surface 10843' Surface 8835' 8-1/2" 171 sx LiteCrete, 168 sx 'G', 653 sx'G' 4-1/2" 12.6# L-80 10673' 1417 ' 8701' 9067' 6-1/8" 429 sx Class 'G' 23. Perforations open to Production (MD + TVD of Top and 24. Tuerivc RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10685' 10629' MD TVD MD TVD 13950' - 14090' 9012' - 9045' 25. Aclo, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED Freeze Protect w/ 80 Bbls of Diesel 26. PRODUCTION TEST Date First Production: March 22, 2007 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27• CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~ ~~~d~~ b ~_ ' ~~ s '~ 4 None ~ ~. APR ~ ?007 -'~'0 Form 10-407 Revised 12/20 1 ~(~\\~ 4 CONTINUED ON REVERSE SIDE ~1~ L ~ 2$ - GEOLOGIC MARKER 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAnne MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10839' 8831' None Shublik A 10870' 8856' Shublik B 10922' 8892' Shublik C 10948' 8909' Sadlerochit 10990' 8932' HOT 12910' 9040' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. , L Si d O~ f ~ ~ gne Title Technical Assistant Date Q Terrie Hubble PBU A-05Ai 206-128 Prepared By Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Mehrdad Nadem, 564-5941 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. Irene 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM ZT: if no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 09-Mar-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well A-05ai Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,183.78' MD Window /Kickoff Survey 8,206.00' MD (if applicable) Projected Survey: 14,180.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ w~ 1 ~4 Si ned Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a~~- jz~ PBU a-osa ~zo6-i2s> Subject: PBU A-OSA (206-128) From: Thomas Maunder <to~n_maundcrwadmin.state.ak.us> Date: Tue, 13 Mar 2007 14:5429 -0800 To: Robert Tirpaek <Rob~rt.Tirpack a,BP.com> CC`: ~~crric° LL~ihhl~ <hubbl~~lubp.com>, -~ndrrluFarmer ~~~~~lrrw.Fanncr~~;hE,.r~,n~.. I:ohin Smctl~ <rsnt~~th~ian~h~~ra~,~e.oilfi~f~i.~lh.cc,m~ , ~tcvc U,~vie~ ~:<<c~c ~l;i~i~s(a~adnZin.~t~it~•.~~L.t~~>, Ho~~~~u~cl Okland<h~~~~ar~l_okland~admin.state.akus= , :1rt Sal[m~u~sh ~<<rt 5al~mar>1~41acltl~in.~[ate.ak.us.. Rob, Terrie, Andrew and Robin, Not sure who can best handle this. I am reviewing the completion report for PBU A-05A. A companion report was also sent for the abandonment of the original well A-05. Since A-05A is completed as an injection well an assessment of the primary cementing of strings in/near the reservoir is part of the review. Any available cement assessment logs are also examined. The log available in the AOGCC file is not the correct log. 2 USIT logs were run in the well. The copy I currently have looked at was run on January 4 prior to the major tubular replacements done in the well. Although the well name and API number listed on the log are for A-05A, I believe that the correct name and number should be A-05. The 7" casing examined by this log was either pulled or abandoned below the EZSV subsequently set at -8200'. New hole was not drilled until January 17. The correct log for A-05A was run on January 29 and examined the new 7" liner as well as the tieback string. It would be appreciated if a hard copy of that log could be submitted. Terrie and I recently exchanged messages regarding when work on an "old" well (in this case A-05) ends and the "new" well (A-05A) begins. The protocol used by the Commission is that the new well begins when the window is cut and new formation drilled. When drilling permits and sundry notices are reviewed, a "line" is usually drawn across the page with a notation made where the new permit to drill. takes effect.. It is recognized that the work scope of operations such as accomplished here is complicated. However it is requested that for labeling and naming purposes that work accomplished prior to actually making new hole be credited to the original wellbore. Although it is likely that there are a number of logs in the Commission files that do not conform to the protocol described here, it is not necessary to attempt to reconcile the naming. However, for the future your attention to this matter will be appreciated. Call or message with any questions. Tom Maunder, PE AOGCC 1 of 1 3/13/2007 3:03 PM - - - '~~~,~ ~'~~~I~l~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION~~`3I WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~~ MAC d 9 2007 Alaska Oii & Cas Cons. Ctxnmiss'tOn 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 2oAa,czs.,os zoAAC2s.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: AnChOraQe ^ Development ^ Exploratory ^ Stratigraphic ®Service 2 BPeExploration.(Alaska) Inc. 5. Date Comp.2 9 20t)7 r Ab • ~~ 12. 206-128 frill Number 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/18/2007 13. API Number 50-029-20116-01-0Or 4a. Location of WeN (Governmental Section): Surface: ' ' 7. Date T.D. Reached 2/4/2007 14. Well Name and Number: PBU A-05Ai '~ 1896 FNL, 923 FEL, SEC. 35, T11 N, R13E, UM Top of Productive Horizon: 2910' FNL, 747' FEL, SEC. 34, T11 N, R13E, UM 8. KB Elevation (ft): 74.67' 15. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Bay Total Depth: 262' FNL, 90' FWL, SEC. 02, T10N, R13E, UM 9. Plug Back Depth {MD+TVD) 14091 + 9045 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 654462 y- 5948551 Zone- ASP4 10. Total Depth (MD+TVD) 14180 + 9067 Ft 16. Property Designation: ADL 047472 TPI: x- 649380 y- 5947435 Zone- ASP4 Total Depth: x- 650273 y- 5944820 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: 'T~ L/i~/QIO DIR / GR / PWD, MWD DIR / GR / RES / ABI / IFR, USIT / CBL M ~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD - HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM ' SIZE CEMENTWG RECORD PULLED 30" Conductor Surface 99' Surface 99' 36" Cemented to Surface with PF II 20" x 18-5/8" 133# / 96.5# K-55 Surface 2278' Surface 2278' 26" 8700 sx PF ii Multi le Sta es 13-3/8" x 9- /8" 68# / 47# N-80 Surface Surface 6770' 12-1/4" ,625 sx Class'G', 525 sx PF II, 1878 sxAS I 9-5/8" x 10-3/4" 47# / 55.5# N-80 1839' 2015' 1839' 2015' Tieback ,00 sx PF II (Top 3 Jts 1,314" x 9-5/B" Thermocase) 7" 26# L-80 Surface 10843' Surface 8835' 8-1l2" 171 sx I_iteCrete, 168 sx 'G', 653 sx'G' 4-1 /2" 12. L-80 1 673' 1417 ' 701' 90 7' 6-1 /8" 42 x Cla s 'G' 23. Perforations open to Production (MD + TVD of Top and 24. TuBINGRECDRD Bottom Inlerval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10685' 10629' MD TVD MD TVD 13950' - 14090' 9012' - 9045' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT S~ KIND OF MATERIAL USED Freeze Protect w/ 80 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Injection Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO FIOW TUbing PreSS. CBSIng PreSSUre CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate she~S,~jf,necessary). Submit core chips; if none, state "none". s;U ~ , None °~ ~--b~ _ 1~=€~ ~' ~ 1'>~ ~ ("'ai ~ s 'O~ Form 10-407 Revised 12/2003 I CONTINUED ON REVERSE SIDE ~ ~ tt¢J ~ R ~€ll~l 28. R 29. ~ T GEOLOGIC MARKE RMATION ESTS Include and briefly summarize test results. List intervals tested, NnME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10839' 8831' None Shublik A 10870' 8856' Shublik B 10922' 8892' Shublik C 10948' 8909' Sadlerochit 10990' 8932' HOT 12910' 9040' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~/ Signed Terrie Hubble Title Technical Assistant Date ~ 7/Q~ PBU A-05A1 206-128 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. onuing Engineer: Mehrdad Nadem, 564-5941 INSTRUCTIONS GeaEw+~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. ITEM 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). ITEM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: A-05 Common Name: A-05 Test Date Test Type 1/17/2007 LOT 1 /26/2007 LOT Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 8,206.0 (ft) 6,767.0 (ft) 9.00 (ppg) 740 (psi) 3,904 (psi) 11.11 (ppg) 10,863.0 (ft) 8,835.0 (ft) 8.40 (ppg) 600 (psi) 4,455 (psi) 9.71 (ppg) i Printed: 2/12/2007 10:13;10 AM BP EXPLORATION Page 1 of 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To Hours Task ;Code NPT Ph _- - - _ _ ~~ 12/29/2006 ~ 14:30 - 16:30 2.00 ~ MOB P ~ (PRE 16:30 - 19:30 3.00 MOB P PRE 19:30 - 21:00 1.50 MOB P PRE 21:00 - 00:00 3.00 MOB P PRE 12/30/2006 00:00 - 12:00 12.00 MOB P PRE 12:00 - 15:00 3.00 MOB N WAIT PRE 15:00 - 18:00 3.00 MOB P PRE 18:00 - 20:30 2.50 RIGU P PRE 20:30 - 00:00 I 3.50 ~ RIGU P PRE ~ 12/31/2006 00:00 - 01:00 1.00 RIGU P DEC 01:00 - 01:30 0.50 KILL P DEC 01:30 - 03:00 1.50 KILL P DEC 03:00 - 04:00 1.00 DHB P DEC 04:00 - 06:00 2.00 KILL P DEC 06:00 - 09:00 I 3.001 KILL P I DEC 09:00 - 10:00 I 1.001 WHSUR I P I I DEC 10:00-18:00 I 8.00IWHSURIP I IDEC Spud Date: 3/14/1972 Start: 12/25/2006 End: 2/9/2007 Rig Release: 2/9/2007 Rig Number: ase _ Description of Operations Hook up pits to truck. Pull pits away and stage on pad. Pull mats. Set top drive in slips. Bridle up blocks, Lower cattle chute. PJSM. Lower derrick. Secure rig. Prepare to move rig. Move rig from DS 15-126 to Pad A-05Ai. Move rig from DS 15-126 to Pad A-05Ai. Waiting on DSM to sand entrance leading into A Pad. PJSM. Move rig on location and spot sub on well. PJSM. Spot pits and cuttings box. Hook up interconnect. Spot and set shop, camp and out buildings. Build berms. Hook up power to shop, camp and pits. PJSM. Raise derrick and pin. Chink cracks. Raise cattle chute. PJSM. Bridle down. Pin up top drive and torque tube. Hang bridal lines. OMP Rig floor rigged up and cleaned. Rig accepted at 0000 hrs. OMP Pre-spud safety meeting. OMP PJSM. Rig up to kill well and pull BPV. OMP Pull BPV with DSM. OMP Make up circulating lines. Install secondary annulus valves on the IA, OA. Test lines to 3500 psi. Had trouble securing proper crossover equipment for OOA secondary valves. Equipment found at Nabors yard and will be installed during NU of BOPE. OMP Displace diesel and circulated 9.8 ppg brine around. Start displacement with 0 psi IA, 50 psi OA, 25 psi OOA. Pumped down annulus with 30 bbls seawater at 168 gpm with 500 psi to displace diesel. Pumped down tubing with 405 bbls 9.8 ppg brine back to surface at 252 gpm with 500 psi. OA/1020 psi, OOA/700 psi. OMP Safety meeting with John Rose and Cleve Coyne for upcoming CMIT. OMP Install TWC and test from above to 4000 psi. IA OA OOA TWC tested. 0 700 600 Pressure up IA 500 1400 700 Shutdown 500 1300 800 Bleed OOA 400 950 0 All Gas Bleed OA 0 650 0 Gas + 14 bbls Bleed OA 0 150 0 50 bbls Bleed OA 0 0 0 20 bbls Pack OOA with fluid. 0 Tr Tr 18:00 - 21:30 3.50 W HSUR P DECOMP Retest for CMIT. Pump with 9.8 ppg brine. Time bbls IA OA OOA 1832 13.4 0 150 30 1834 16.4 0 150 30 1836 18.5 0 150 30 1838 21.5 0 400 50 1840 22.5 0 500 100 1850 0 450 200 1852 23.5 100 500 150 1855 100 620 400 1858 24.5 300 800 450 1908 225 800 500 Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 2 of 22 ~ Operations Summary Report .Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 '.Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 ',Rig Name: NABOBS 2ES Rig Number: Date ~ From - To ~ Hours Task Code NPT Phase Description of Operations 12/31/2006 ~ 18:00 - 21:30 ~ 3.50 ~ W HSUR ~ P 21:30 - 23:00 23:00 - 00:00 1 /1 /2007 00:00 - 02:30 02:30 - 06:00 06:00 - 10:00 10:00 - 12:00 12:00 - 12:30 12:30 - 15:00 15:00 - 16:30 16:30 - 17:00 17:00 - 19:00 19:00 - 21:00 21:00 - 21:30 21:30 - 00:00 1 /2/2007 00:00 - 02:00 1.50 WHSUR P 1.00 WHSUR P 2.50 WHSUR P 3.50 BOPSU P 4.00 BOPSU P 2.00 BOPSU N 0.50 BOPSU N 2.50 BOPSU N 1.50 BOPSU N 0.50 BOPSU N 2.00 BOPSU N 2.00 BOPSU N 0.501 BOPSUp N 2.50 BOPSU~P 2.00 BOPSU P DECOMP 1910 25.3 450 1000 525 1915 400 1000 600 1917 25.9 600 1100 650 1922 525 1100 700 1925 26.3 700 1250 750 Held pressue for 15 minutes, held OK. 1945 650 1200 750 1945 26.7 750 1300 750 Held pressure for 15 minutes, held OK. Bled off OA to 0 psi, got back all fluid. Bled off OOA, got back all gas. All annulus bled to 0 psi and monitor for 30 minutes. All OK. DECOMP PJSM. Pick up cellar and build platform around tree. DECOMP Nipple down tree. Bleed all voids as per Cameron. DECOMP ND tree and adapter. Inspect lifting threads on tubing hanger. Cameron hand ran the XO into threads and recommends we not try to lift tubing with the threads and use a spear instead. Remove tree from cellar. DECOMP NU BOPE. Will test to 250 psi low, 4000 psi high as per AOGCC. Test witness waived by Chuck Sheve. Performed hazard assessment for Inclement Weather Equipment Operating Procedure due to ambient temperatures below -35 degrees. Temperature currently at - 36 ambient. DECOMP PJSM. Rig up to test BOPE with 4-1/2" test joint. Test to 250 psi low, 4000 psi high as per AOGCC regulations. BOPE test witness waived by Chuck Sheve. Choke and blinds tested good. SFAL DECOMP Pick up 4-1/2" test joint. Close top pipe rams. Bleeding off on low test. Trouble shoot and determine pressue leaking downhole. Possible TWC problem. OA at 10 psi, OOA at 50 psi. Bleed to 0, all gas. SFAL DECOMP Wait on DSM to remove TWC. SFAL DECOMP PJSM, Pick up lubricator. Wait on Oft lubricator extension to pull TWC. Rig up rig tongs. OA at 8 psi, bleed to 0, all gas. SFAL DECOMP PJSM, Test TWC against blinds, kill, choke and both HCR's. Good test. Pick up test joint, test dart and top rams. Low test good. High test held and bled off 5 minutes into test. TWC failed again. SFAL DECOMP Rig down test joint. Blow down and lay down alf surface equipment. OA 10 psi, bled to 0. All gas. SFAL DECOMP Secure well. Safety stand down. SFAL DECOMP PJSM. Rig up DSM lubricator. Attempt to pull TWC with no success. Pump out stack to check for debris. OA at 10 psi, bleed to 0. All gas. SFAL DECOMP PJSM. Relaxed bag and pulled slips to center lubricator. Slipped pulling tool into hanger. Close bag. RIH and retrieve TWC. Pull and rig down lubricator. Pick up T-bar. RIH and set new TWC as per Cameron. Verified travel of 1-11/16" on plug as per Company Man. DECOMP PJSM. Pick up and run in 4-1/2" test joint. Test BOPE to 250 psi low, 4000 psi high. DECOMP PJSM. Test BOPE to 250 psi low, 4000 psi high as per AOGCC. Chuck Sheve waived witness of test. Rig up top drive and test. Tested Hydril to 2500 psi. Test OK. OA holding at 5 Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Operations Summary Report Page 3 of 22 Legal Well Common W Event Nam Contractor Rig Name: Date 1 Name: ell Name: e: Name: From - To A-05 A-05 REENTE NABOB NABOB Hours R+COM S ALASK S 2ES Task - - _ __ PLET A DRI Code _ E LLING NPT ~ Start 1 Rig Rig Phase Spud Date: 3/14/1972 : 12/25/2006 End: 2/9/2007 Release: 2/9/2007 Number: Description of Operations _ ___ - _- 1/2/2007 00:00 - 02:00 2.00 BOPSU P DECOMP _ psi. 02:00 - 02:30 0.50 BOPSU P DECOMP PJSM. Rig down and blow down test equipment. OA still at 5 psi. 02:30 - 04:00 1.50 BOPSU P DECOMP PJSM. Rig up DSM lubricator and pull TWC. Rig down lubricator. Pump 40 bbls 9.8 ppg brine over the top. No fluid show at top of tubing hanger. 04:00 - 07:00 3.00 PULL P DECOMP PJSM. Pick up spear as per Baker rep. Run in and spear hanger. Bleading IA with 10 psi, OA with 100 psi and OOA with 150 psi before pull hanger free. Back out lock down screws and pull hanger free with 115k 07:00 - 07:30 0.50 PULL P DECOMP PJSM Lay down spear, and tubing hanger 07:30 - 09:00 1.50 PULL P DECOMP PJSM. Circulate 9.8 ppg brine surface to surface. ~~ Took 73 bbls to fill hole. 164 GPM X225 psi, OA ~ 400 psi,00A ~ 50 psi. Bleed down OA to 200 psi,gas and fluid. 09:00 - 09:30 0.50 PULL P DECOMP PJSM. Rig up to pull 4 1/2" tubing. 09:30 - 19:00 9.50 PULL P DECOMP PJSM, POOH laying down 4 1/2" tubing from 8669',207 joints,l pup joint,X nipple,and 20.63' cut joint. Monitor well for 10 minutes,dead. 19:00 - 20:00 1.00 PULL P DECOMP PJSM. Rig down tongs and 4 1/2" handling equipment. Clear and clean floor,bring test plug to floor. 20:00 - 22:30 2.50 BOPSU P DECOMP Install new flange, valve and gauges on OOA. 22:30 - 00:00 1.50 BOPSU P DECOMP PJSM. Pick up test joint and install test plug.Test annular preventer,top and bottom rams with 4" and 5" test joints. 1/3/2007 00:00 - 02:00 2.00 BOPSU P DECOMP Test Upper and lower rams with 4" & 5" test joints to 250psi low and 4000psi high. Test Annular to 250psi low and 2500psi high with 4" and 5" test joints. 02:00 - 03:00 1.00 BOPSU P DECOMP Pull test plug,and lay down test joints.Blow down surface equipment. ', 03:00 - 04:00 1.00 CLEAN P DECOMP Pick up tools to floor. 04:00 - 05:30 1.50 CLEAN P DECOMP PJSM. Make up 9 5/8" scraper and scrape top joint of 9 5/8" casing to 52'. Pull back to surface and lay down. 05:30 - 06:00 0.50 CLEAN P DECOMP PJSM. Install wear ring. 06:00 - 07:00 1.00 CLEAN P DECOMP Make up 7" casing scraper and run in hole to 120'. 07:00 - 10:00 3.00 CLEAN P DECOMP Run in hole picking up drill pipe from pipe shed, from 120' to 2928'. 10:00 - 13:00 3.00 CLEAN N RREP DECOMP Repair and function test pipe skate. 13:00 - 17:00 4.00 CLEAN P DECOMP Run in hole picking up 4" drill pipe from pipe shed, from 2928' to stump at 8669'. Tag stump,up wt. 147k,down wt. 118k. 17:00 - 20:00 3.00 CLEAN P DECOMP Establish rates for 162 GPM X460 psi, then 200 GPM ~ 654 psi. Pump high vis sweep and circulate surface to surface. 20:00 - 22:30 2.50 CLEAN P DECOMP PJSM. Slip and cut drill line. Service draworks and top drive. Grease crown. 22:30 - 00:00 1.50 CLEAN P DECOMP POOH from 8669' to 4421'. 1/4/2007 00:00 - 01:00 1.00 CLEAN P DECOMP PJSM. POOH from 4421' to 1805'. ~I 01:00 - 03:00 2.00 CASE P DECOMP PJSM. Pick up and set RTTS at 35'. Test to 2000 psi. NOTE: All path-forward work as associated with replacing the tubing spool with afull-bore "spacer" spool and the wellhead/BOP pressure testing which will be associated with that work until such time as a new starter ring has been installed on the new 13-3/8" casing which will be run on this Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 4 of 22 ~ Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: Date I From - To I Hours I Task I Code 1/4/2007 01:00 - 03:00 2.00 CASE ~ P 03:00 - 03:30 0.50 CASE P 03:30 - 08:00 4.50 CASE P 08:00 - 10:00 I 2.001 CASE I P 10:00 - 10:30 0.50 CASE P 10:30 - 11:00 0.50 CASE P 11:00 - 14:00 3.00 CASE P 14:00 - 17:30 3.50 CASE P 17:30 - 00:00 6.50 CASE P 1/5/2007 00:00 - 01:00 1.00 CASE P 01:00 - 01:30 0.50 CASE P 01:30 - 06:00 4.50 CASE P 06:00 - 07:00 1.00 CASE P 07:00 - 09:00 I 2.001 CASE I P 09:00 - 10:30 1.50 CASE P 10:30 - 12:30 2.00 CASE P 12:30 - 14:00 1.501 CASE ( P 14:00 - 14:30 I 0.501 CASE I P 14:30 - 16:00 1.501 CASE ~ P 16:00 - 17:30 I 1.501 CASE I P NPT Phase Description of Operations ___ 1_ - - - __ - -- DECOMP well has been waivered to 2000 psi tests per AOGCC (L. Grimaldi/J. Rose) This waiver was requested on the basis that the lower-wellhead/out casing strings would not be sulitable to the 4000 psi testing currently permitted for this planned injector sidetrack. DECOMP Pull wear ring. DECOMP PJSM.Nipple down BOP and attempt to remove tubing spool.Primary seal on 9 5/8" pack off leaking by.Attempt to bleed OA and OOA off, would not bleed to O.Could not remove tubing spool. DECOMP PJSM. Nipple up BOP and test 9 5/8" to tubing flange to 2500 psi with Cameron. Dispensation to not test to 4000 psi from AOGCC rep Lou Grimaldi. DECOMP Test tubing flange to BOP with Rig to 4000psi. DECOMP PJSM. Install wear ring. DECOMP Screw into storm packer,release and pull to floor. 14 bbl. required to fill well after pulling packer. Lay down packer and POOH from 1805',lay down BHA. DECOMP PJSM. Rig up wireline unit with pressure control head. Rig up USIT logging tools. DECOMP Run in hole with USIT tool and log 7" casing from 8600'to surface. Top of cement ~ 2040' E-line measurement.Rig down E-line and clear floor. DECOMP Rig down wireline. DECOMP Make up RTTS and run in hole with collars. DECOMP Run in hole with RTTS to find 7" casing leak. DECOMP PJSM.Set RTTS and test 7" casing below 8043' to 1000 psi. OA pressure increases to 1200 psi, failed test. Test above 8043' to 1500 psi. Good test, OA and OOA remain static. Run in hole to 8135' and test to 1500 psi above RTTS,good test. DECOMP PJSM. Run in hole to 8669',tag stump. Pick up and set RTTS 038661'. Test below to 2000 psi for 30 minutes,good test. Lay down 2 singles and blow down top drive. Rig up to circulate OA. DECOMP POOH from 8669' to 8135'. Set RTTS.Open OA to cuttings tank and bleed to 0 psi. DECOMP Establish pump rates of 27 GPM @44 psi. Bring rate up to 1 BBUmin. ~ 50 psi. Circulate 9.8 ppg brine displaceing OA. OOA = 120 psi open to bleed tank and bring rate up to 3 BBUmin @ 410 psi,continue bleeding OOA,mostly gas with small amounts of fluid (1/2 BBL). Circulate until 9.8 ppg brine all the way surface of the OA. DECOMP Blow down line to cuttings tank. Rig up to circulate through secondary choke line and take returns to mud pits. Circulate at 2 BBUmin. 03228 psi for full circulation, 6400 strokes. DECOMP Pick up and release RTTS. Blow down top drive and choke Iine.Rig up OOA to cuttings tank and leave open. Well back flowing through drill pipe. DECOMP PJSM. Circulate 9.8 ppg brine surface to surface. Monitor well for 15 minutes,blow down top drive and bleed 350 psi off OA. DECOMP PJSM. Make up storm packer and set ~ 35'. Test to 2000 psi for 5 minutes. Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 5 ofi 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: Date j From - To ~ Hours Task Code ~ NPT ~ ~ 1/5/2007 17:30 - 18:00 0.50 CASE P 18:00 - 20:00 2.00 CASE P 20:00 - 22:00 2.00 CASE P 22:00 - 22:30 0.50 CASE P 22:30 - 23:30 I 1.001 CASE I P 23:30 - 00:00 0.50 CASE P 1/6/2007 00:00 - 03:30 3.50 CASE P 03:30 - 04:00 0.50 CASE P 04:00 - 04:30 0.50 CASE P 04:30 - 08:00 3.50 CASE P 08:00 - 08:30 I 0.50 I CASE I P 08:30 - 09:00 0.50 CASE P 09:00 - 11:30 2.50 CASE P 11:30 - 12:00 I 0.501 CASE I P 12:00 - 13:30 1.50 CASE P 13:30 - 15:00 1.50 CASE P 15:00 - 16:30 I 1.501 CASE I P 16:30 - 18:30 I 2.001 CASE I P 18:30 - 19:30 I 1.001 CASE I P 19:30 - 20:30 1.00 CASE P 20:30 - 21:00 0.50 CASE P 21:00 - 21:30 0.50 CASE P 21:30 - 22:00 0.50 CASE P 22:00 - 23:00 1.00 CASE P 23:00 - 00:00 I 1.001 CASE 1 P 1/7/2007 00:00 - 00:30 0.501 CASE P 00:30 - 02:00 1.50 CASE P 02:00 - 02:30 0.50 CASE P Phase ~ Description of Operations DECOMP PJSM. Pull wear ring. DECOMP Nipple down BOP and remove tubing spool. DECOMP Nipple up spacer spool and BOP. DECOMP Test spacer spool and lower mud cross & spacer spool x 9 5/8" flange to 2000 psi. Dispensation to not test to 4000 psi from AOGCC rep Lou Grimaldi. DECOMP PJSM. Run in and screw into storm packer, release, pull packer to floor, and lay down. DECOMP POOH from 8140' to 7768'. DECOMP POOH from 7768' to BHA ~ 120'. DECOMP Rack back drill collars and lay down RTTS.CIear Floor. DECOMP PJSM. Make up 7" casing cutter BHA. DECOMP Run in hole with 7" casing cutter to 8320'. Up wt. 142k,down wt. 115k. Install blower hose. DECOMP Break circulation and bring pumps up to 105 gpm ~ 350 psi. Locate collar at 8314' with casing cutter, pick up to 8300' and initiate cut on 7" casing. 157 gpm @ 756 psi,72 RPM,rotating wt. 130k,free torque 3700 ft/Ibs,cutting torque 5-6000 fUlbs. DECOMP Remove blower hose and blow down top drive. DECOMP POOH from 8320' to 4586'.Up wt. 90k,down wt. 90k.torque off bottom 1100 ft/Ibs. Bring pumps up to 184 gpm ~ 800 psi. Start cut with 70 RPM,cut casing and confirm by slacking off. DECOMP Blow down top drive,remove blower hose. Well out of balance,make up top drive and circulate. OA=O psi OOA;15 psi. DECOMP PJSM. POOH from 4586' to 1969'. DECOMP PJSM. Install blower hose, break circulation and tag collar ~ 1955',Cut 7" casing at 1951'. Monitor well IA x OA is U-tubing.. DECOMP PJSM. Pick up storm packer,set, and test to 2000 psi.Good test. DECOMP PJSM. Change out 3 1/2" x 6" variables to 7" rams.Test door seals to 2000 psi. Requirement for 4000 psi body test waived by AOGCC rep. Lou Grimaldi. DECOMP PJSM.Run in hole and screw into storm packer. Release,retrieve,and lay down packer. DECOMP PJSM. POOH from 1969' to 97'. DECOMP PJSM. Lay down 4 3/4" collars and 7" casing cutter. DECOMP Clean and clear rig floor. DECOMP Pick up spear to floor. DECOMP Make up 9 5/8" casing spear assembly.Bleed down OA and OOA, DECOMP PJSM. Run 9 5/8" casing spear in hole and engage. Pull up 5k to confirm engaged. Slack off and back out lock down screws. Pull casing free with 190k,string wt. 145k. Pull casing slips to floor and remove. DECOMP Fill hole after pulling 9 5/8",10 bbl. to fill. PJSM on breaking out 9 5/8" joint and laying down cut off & BHA. DECOMP Rig up false bowl & break out / laydown 9 5/8"joint.Clear floor,rig down 9 5/8" handling equipment. Length of 9 5/8" joint 25.53'. DECOMP PJSM Rig up 7" casing equipment. Printed: 2/12/2007 10:13:15 AM • BP EXPLORATION Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date ~ From - To ~ Hours ~ Task Code NPT Start: 12/25/2006 Rig Release: 2/9/2007 Rig Number: Phase Page 6 of 22 Spud Date: 3/14/1972 End: 2/9/2007 Description of Operations 1/7/2007 02:30 - 11:00 8.50 CASE P DECOMP POOH with 7" casing. Every joint hanging up until 30 joints out then intermittent snagging until out of hole. Cut in joint #46 not all the way through, some visible signs of cut on outside of joint. Pull and lay out 107 joints and 1 x 39.28' cut joint. 11:00 - 12:00 1.00 CASE P DECOMP Monitor well for 10 minutes. Rig down 7" casing equipment,clearand clean floor. 12:00 - 13:00 1.00 CASE P DECOMP PJSM. Pick up baker 7" spear up beaver slide. 13:00 - 15:00 2.00 CASE P DECOMP PJSM. Make up 7" spear assembly. 15:00 - 16:00 1.00 CASE P DECOMP PJSM. Run in hole to 324' picking up drill collars. 16:00 - 19:30 3.50 CASE P DECOMP Run in hole from 324' to 4598'. Assembly hung up at 13 3/8" x 9 5/8" liner lap and required rotation to pass through. 19:30 - 20:00 0.50 CASE P DECOMP Tag top of 7" casing and set down 25k to engage spear.Pull up to 200k and let jars open. Straight pull to 240k and casing comes free. String weight of casing 210k. 20:00 - 23:30 3.50 CASE P DECOMP POOH from 4598' to 324'. Casing collars started to hang up at 1610' and hanging up every 41' pulling 25k to 50k over to pull past. Stand back drill collars. 23:30 - 00:00 0.50 CASE P DECOMP PJSM. Lay down spear assembly and casing cut off. 1/8/2007 00:00 - 01:00 1.00 CASE P DECOMP PJSM. Lay out spear,casing cut off (3.24'), and one joint of 7"casing. 01:00 - 07:00 6.00 CASE P DECOMP POOH laying down 7" casing from 3702'. Casing collars hanging up on every joint up to joint # 45 out. Pulled and layed down 86 full joints and 1 cut off 31.01'. Monitor well for 10 minutes. 07:00 - 08:00 1.00 CASE P DECOMP Rig down 7" handling equipment,clear and clean floor. 08:00 - 10:00 2.00 CASE P DECOMP PJSM. Set test plug,change out upper rams from 7" to 9 5/8". Test door seals to 2000 psi for 5 minutes,good test. Requirement for 4000 psi test waived by AOGCC rep. Lou Grimaldi. 10:00 - 10:30 0.50 CASE P DECOMP Install wear ring, ID 12.5". 10:30 - 11:00 0.50 CASE P DECOMP Break down spear assembly as per Baker rep. 11:00 - 14:00 3.00 CASE P DECOMP PJSM. Make up 13 3/8" scaper assembly to 322'. 14:00 - 15:00 1.00 CASE P DECOMP Run in hole from 322' to 1853',tag top of 9 5/8" tie-back. 15:00 - 16:00 1.00 CASE P DECOMP Pump 50 bbl Hi-Vis soap sweep around,525 GPM C~ 660 psi. 16:00 - 17:00 1.00 CASE P DECOMP POOH from 1853' to 322'. 17:00 - 18:30 1.50 CASE P DECOMP PJSM. Stand back drill collars,lay down 13 3/8" assembly. 5 lbs. of scale recovered from boot baskets. 18:30 - 19:00 0.50 CASE P DECOMP Clear floor of 13 3/8" scraper BHA. 19:00 - 19:30 0.50 CASE P DECOMP PJSM. Bring 9 5/8" casing scaper assembly tools to floor. 19:30 - 21:00 1.50 CASE P DECOMP PJSM. Make up 9 5/8" casing scraper assembly and run in drill collars to 326'. 21:00 - 00:00 3.00 CASE P DECOMP Run in hole from 326' to 6682'. 1/9/2007 00:00 - 01:30 1.50 CASE P DECOMP Run in hole from 6682' and tag stump at 8301'.Make up top drive,break circulation. 01:30 - 03:30 2.00 CASE P DECOMP Get slow pump rates. Circulate at 406 GPM @ 1378 psi,pump Hi-Vis soap pill. Increase rate to 470 GPM ~ 1795 psi, and reciprocate pipe. Shut down and break off top drive,well out of balance,flowing out of drill pipe,screw in top drive and circulate white cutting Printed: 2/12/21x17 10:13:15 AM ~ s BP EXPLORATION Page 7 of 22 ~ Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: ~ i Date From - To Hours I Task Code NPT Phase Description of Operations 1 -~-- 1/9/2007 01:30 - 03:30 2.00 CASE P DECOMP and slipping line. 03:30 - 05:30 2.00 CASE P DECOMP Cut and slip drill Iine.Service top drive,and draworks. 05:30 - 06:00 0.50 CASE P DECOMP Monitor well for 10 minutes,pump dry job and blow down top drive. 06:00 - 09:00 3.00 CASE P DECOMP POOH from 8300' to 1855',pulled 5k over at liner top. Worked scraper through until free. 09:00 - 09:30 0.50 CASE P DECOMP POOH from 1855' to 326'. 09:30 - 11:30 2.00 CASE P DECOMP PJSM. Rack back drill collars and lay down BHA. 11:30 - 12:30 1.00 CASE P DECOMP Pull wear ring install test plug, and rig up to test BOPE. 12:30 - 17:00 4.50 CASE P DECOMP PJSM. Test BOP and related equipment to 250 psi low and 4000 psi high,test annular to 250 psi low and 2500 psi high,hold for 5 minutes, record and chart.Test witness waived by AOGCC rep John Crisp, Test witnessed by Nabors drilling rep Charlie Henley and BP rep John Rose. 17:00 - 17:30 0.50 CASE P DECOMP Rig down test equipment and blow down lines. 17:30 - 18:00 0.50 CASE P DECOMP Install wear ring. 18:00 - 19:30 1.50 CASE P DECOMP Bring logging tools to floor up beaver slide. 19:30 - 21:00 1.50 CASE P DECOMP PJSM. Rig up wireline,with shooting nipple. 21:00 - 00:00 3.00 CASE P DECOMP Run CCL,GR,USIT log on wireline. 1/10/2007 00:00 - 05:30 5.50 CASE P DECOMP Run CCL,GR,USIT log on wireline. 05:30 - 06:30 1.00 CASE P DECOMP Lay down logging tools. 06:30 - 10:00 3.50 CASE P DECOMP PJSM.Rig up to run Fasdrill plug. Discuss depth placement of FASDRILL. Review USIT/CBL Logging Results. Blow down choke and kill lines. 10:00 - 12:30 2.50 CASE P DECOMP Mak ~o pl~,and run in hole to 2179'. Pick up to 2085' and set plug. POOH from 2085' and lay down running tools. Rig down shooting nipple. 12:30 - 13:00 0.50 CASE P DECOMP Test Fasdrill plug to 1500 psi,for 15 minutes,good test. 13:00 - 14:30 1.50 CASE P DECOMP Load casing puncher and rig up shooting nipple. 14:30 - 16:00 1.50 CASE P DECOMP Run in hole with casing punch to 2063'. Fire and punch holes ~ 2063'. 16:00 - 16:30 0.50 CASE P DECOMP PJSM. Establish circulation through holes ~ 2063' to OA.Annulus broke at 310 psi, pump 6 bb1,500 gpmC 30 psi. 29 bbl required to fill hole after circulating. 16:30 - 18:00 1.50 CASE P DECOMP PJSM. Rig up wireline with string shot and run in hole to 75'. Fire string shot across collar at 75'. 18:00 - 19:30 1.50 CASE P DECOMP Rig down wireline unit and shooting nipple.Clear and clean floor. 19:30 - 21:30 2.00 CASE N WAIT DECOMP Wait on trucks for displacing OA. 21:30 - 00:00 2.50 CASE P DECOMP PJSM. Circulate oil out of 13 3/8" x 18 5/8"annulus. Pump 100 bbl hot water with soap,followed by 700 bbl. hot 9.8 ppg brine. 210 GPM ~ 390 psi. 1/11/2007 00:00 - 01:00 1.00 CASE P DECOMP Circulate OA clean with hot 9.8ppg brine and soap pill. 206 GPM ~ 446 psi. Brine cleaned up after soap pill comes back to surface. Blow down all lines and rig down cellar. 01:00 - 01:30 0.50 CASE P DECOMP Pull wear ring. 01:30 - 04:30 3.00 CASE P DECOMP Install blower hose,make up cutter assembly to 75'. Run in hole and tag casing collar at 80'. Pick up 20' and cut 13 3/8" casing. Free torque 1000 fUlbs,cutting torque 3-4k fVlbs.270 GPM ~ 790 psi. Cut 13 3/8" casing and shut down rotary and pump.Pick up 5' Printed: 2/12/2007 10:13:15 AM • BP EXPLORATION Operations Summary Report Legal Well Name: ,Common Well Name Event Name: Contractor Name: Rig Name: Page 8 of 22 A-05 A-05 Spud Date: 3/14/1972 REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 NABOBS 2ES Rig Number: Date From - To Hours Task :Code - - - - -- - 1/11/2007 01:30 - 04:30 3.00 CASE P 04:30 - 05:30 1.00 CASE P 05:30 - 07:30 2.00 CASE P 07:30 - 09:00 1.50 CASE P 09:00 - 13:00 4.00 CASE P 13:00 - 14:00 1.00 CASE P 14:00 - 15:00 1.00 CASE N 15:00 - 15:30 0.50 CASE P 15:30 - 19:00 3.50 CASE P 1/12/2007 +00,30 - 03.30 3.00 CASE P 03:30 - 04:00 I 0.501 CASE I P 04:00 - 07:00 3.00 CASE P 07:00 - 08:30 1.50 CASE P 08:30 - 11:00 2.50 CASE P 11:00 - 12:00 1.00 CASE P 12:00 - 15:00 3.00 CASE P 15:00 - 17:30 2.50 CASE P 17:30 - 18:30 1.00 CASE P 18:30 - 20:00 1.50 CASE P 20:00 - 20:30 0.50 CASE P 20:30 - 22:00 1.50 CASE P 22:00 - 00:00 2.00 CASE P 1/13/2007 100:00 - 01:00 1.001 CASE ~ P 01:00 - 04:00 I 3.001 CASE I P 04:00 - 05:00 I 1.001 CASE I P NPT Phase ~ Description of Operations DECOMP and bring pumps back up to 189 GPM,slack off to verify cut. DECOMP POOH, lay down casing cutter BHA,clear and clean floor. DECOMP PJSM. Remove mouse hole and drip pan. Suck fluids out of BOP with Vac truck,install 20" bell nipple to drip pan. DECOMP Nipple down BOP and set back. DECOMP PJSM. Bleed down all voids on wellhead, remove spacer spool, and 20" x 13 5/8" McEvoy casing spool. Casing was growing and pushing wellhead up. Install long studs to control upward movement. Remove spool, casing rose a total of 11 inches. Remove spacer spool and intermediate spools from cellar. DECOMP PJSM. Pick up 13 5/8" casing spear from beaver slide. RREP DECOMP Trouble shoot crown saver. DECOMP Make up 13 3/8" casing spear assembly. DECOMP Run spear into 13 3/8" and engage, pulled free with no overpull. Remove casing slips. 13 3/8" pack-off was in one piece and could not fit through rotary table. Release spear,remove pack-off and engage spear. Pull 13 3/8" casing and lay down.Recovered 21.51' of casing. DECOMP PJSM. Nipple up 20" riser and clean cellar area. DECOMP PJSM. Fill riser and check for leaks. DECOMP PJSM. Pick up wash pipe assembly to 70'. Hung up on stump, layed down jars. DECOMP Make up top drive to single and wash down over stump to 90',47 GPM @ 4 psi. DECOMP Lay down wash pipe assembly.Clear and clean floor. DECOMP PJSM. Pick up back off assembly up beaver slide. DECOMP Make up back off assembly. DECOMP Set bottom anchors 95'and top anchor at 70'. Casing started to back off at 2500 psi. Back off casing 5 turns. DECOMP Pull out back off tools and lay down. Clear and clean floor. DECOMP Make up 13 3/8" spear and 2 singles of drill pipe to 60'. Spear casing stub and back out. Pull and lay down spear & 19.22' cut off. DECOMP Rig up to run 13 3/8" casing. DECOMP Make up 2 joints of 13 3/8" casing. Make up crossovers to top drive and screw into casing ~ 80'. Torque to 13k and test with 50k overpull. Break out top drive and lay down crossovers. DECOMP Rig down and lay down casing equipment. DECOMP PJSM. Cut 13 3/8" casing off at drill floor. Rig up false bowl.' DECOMP Make up cement retainer and run in hole to 2038'. Set packer at 2035'. DECOMP Break out top drive,set 25K down into retainer. Pull out false bowl & rig up circulating head pin. Break circulation,200 psi ~ 3 BPM,460 psi @ 5 BPM. DECOMP PJSM. Pump 5 bbl. fresh water and pressure test lines to 2500 psi. Pump 5 bbl. fresh water with dye followed by 311 bbl. 15.7 ppg. ArticSet 1 cement. 4 BPM @ 1300 psi. Cement to surface./ Displace with 20 bbl. 9.8 ppg brine. J DECOMP Rig up false bowl. Break out pup joint and head pin. Pick up single and rack back stand.Flush and pump out riser,flush Printed: 2/12/2007 10:13:15 AM • BP EXPLORATION Page 9 of 22 ~ Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES ~ 3 i Date ~ From - To ~ Hours Task Code NPT 1/13/2007 04:00 - 05:00 1.00 CASE P 05:00 - 06:30 1.50 CASE P 06:30 - 11:00 I 4.501 CASE I P 11:00 - 12:00 I 1.001 CASE I P 12:00 - 14:00 I 2.001 CASE 1 P 14:00 - 15:00 1.00 CASE P 15:00 - 18:30 3.50 CASE N 19:00 - 22:00 3.00 CASE P 22:00 - 00:00 2.00 CASE P 1/14/2007 00:00 - 05:30 5.50 CASE P 05:30 - 12:30 7.00 CASE P 12:30 - 14:30 I 2.001 CASE I P 14:30 - 16:30 I 2.001 CASE I N 16:30 - 17:30 1.00 CASE N 17:30 - 20:30 3.00 CASE N 20:30 - 00:00 3.50 CASE N 1/15/2007 00:00 - 02:30 2.50 CASE N 02:30 - 09:00 6.50 CASE N 09:00 - 14:00 5.00 CASE P 14:00 - 15:00 1.00 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 17:00 1.50 CASE P 17:00 - 18:30 1.50 CASE P 18:30 - 19:30 1.00 CASE P 19:30 - 20:00 0.50 CASE P 20:00 - 00:00 4.00 CASE P 1/16/2007 00:00 - 03:00 3.00 CASE P 03:00 - 04:00 1.00 CASE P 04:00 - 04:30 I 0.501 CASE I P 04:30 - 06:30 I 2.00 I CASE I P Spud Date: 3/14/1972 Start: 12/25/2006 End: 2/9/2007 Rig Release: 2/9/2007 Rig Number: Phase Description of Operations DECOMP cement manifold. ' DECOMP POOH with retainer running tool.Lay down crossover and stinger. DECOMP PJSM. Cut riser to acess & cut off 13 3/8" casing.Lay down cut off and finish cutting off upper section of riser, remove from ~ cellar. Measure, mark, and cut lower section of riser. DECOMP PJSM. Rig up WACHS cutter and cut 13 3/8" casing,rig down cutter. DECOMP Open cellar doors and bring in new well head.Perform dye penetrant test on 13 3/8" casing stub. Install,and level new well head. DECOMP Wrap new well head with heat blanket to pre-heat. SFAL DECOMP Generator would not pull the load for the heat blanket. Trouble shoot problem and call for new generator. Wait on generator. DECOMP Heat wellhead to 500 degrees. DECOMP Begin welding on starting head. DECOMP Weld starting head on to 13 3/8" casing. DECOMP Welding complete, wrap, and heat to 900 degrees then cool to 100 degrees. DECOMP Perform dye penetrant test,grind inside weld and inspect. Perform nitrogen test on wellhead. Test failed. SFAL DECOMP Weld support gussetts from 20" conductor to wellhead for support, while Binding out inner weld. SFAL DECOMP Rig up heat blanket and wrap wellhead. SFAL DECOMP Heat wellhead to 500 degrees. SFAL DECOMP Weld and grind inner weld. Perform nitrogen test.failed. SFAL DECOMP Re-weld and re-test wellhead.Passed. SFAL DECOMP Complete heating and cooling cycles on wellhead. DECOMP PJSM. Nipple up BOP,change out bell nipple flange. DECOMP PJSM. Change top set of rams to 3 1/2" x 6" variables. DECOMP Install secondary annulus valve. DECOMP Rig up 4" test joint,install test plug. Test bottom flange & top 3 1/2" x 6" variable rams to 250 psi low and 4000 psi high. Pull test plug,install wear ring. DECOMP Make up clean out BHA to 311'. Change out handling equipment. DECOMP Run in hole from 311' to 1997',install blower hose. Tag cement at 2025'. DECOMP Test 13 3/8" casing to 2000 psi for 10 minutes,hold and chart. Blow down surface equipment. DECOMP Drill cement from 2025' to 2035'. Drill EZSV at 2035'. Up wt. 75k,down wt. 70k,rotating wt. 80k. WOB 25k off bottom torque 950,on bottom torque 1500-3500. DECOMP Drill EZSV and cement from 2035 to 2072'. DECOMP Test casing to 2000 psi,failed. Pressure bled 500 psi in 5 minutes. Bumped pressure up to 2000 psi,bled 200 psi in 2 minutes then 250 psi more in 8 minutes. DECOMP Re-test casing to 2000 psi. Wait on orders from town. Test passed,held 2000 psi for 10 minutes. Changed suspect sensor boot in cellar,possible reason for failed test. DECOMP Drill cement and FasDrill plug from 2072' to 2091'.WOB Printed: 2/12/2007 10:13:15 AM s ~- BP EXPLORATION Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Event Name: REENTER+COMPLETE Start: 12/25/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: Date I From - To I Hours I Task 1/16/2007 ~ 04:30 - 06:30 06:30 - 08:30 08:30 - 10:00 10:00 - 13:30 13:30 - 15:00 15:00 - 18:00 18:00 - 22:00 22:00 - 23:00 23:00 - 00:00 1/17/2007 00:00 - 03:00 03:00 - 07:30 ~P ~ ` 3~\~ 07:30 - 09:00 09:00 - 12:00 12:00 - 19:30 19:30 - 20:30 20:30 - 21:00 21:00 - 00:00 1/18/2007 00:00 - 00:30 00:30 - 04:00 04:00 - 06:00 Page 10 of 22 Spud Date: 3/14/1972 End: 2/9/2007 i Code NPT Phase Description of Operations P DECOMP 20k-28k,RPM 60-100,f1ow rate 400-450GPM ~ 500-600 psi. 9.8 ppg brine in and out. P DECOMP RIH and tag 7" stump at 8299'. P DECOMP Pump 35 bbl hi-vis sweep surface to surface at 540 gpm with 2700 psi. Pump dry job and blow down top drive. P DECOMP POOH to 311'. Change out handling equipment. P DECOMP POOH and lay down BHA. Empty boot baskets. Clear floor. P DECOMP PJSM. Rig up SWS. RIH with junk basket and 8-1/4" gauge ring on wireline. POOH. Very little junk in baskets. No other run necessary. P DECOMP Make up running tools and 9-5/8" EZSV. RIH and locate collar at -8238'. Set EZSV at 8230'. POOH and rig down SWS. P DECOMP Test 13-3/8" x 9-5/8" casing to 2000 psi for 30 minutes. Pressure bled off 200 psi over 30 minutes, 150 psi in the first 10 minutes, then trending toward a flat line. Pumped pressure back up to 2000 psi and held for 10 minutes with pressue dropping 40 psi. Test passed. Blow down surface equipment. 2.OO CASE 2.00 CASE 1.50 CASE 3.50 CASE 1.50 CASE 3.00 DHB 4.00 DHB 1.00 DHB 1.00 3.00 STWHIP STWHIP P P WEXIT WEXIT Pick up and make up 9-5/8" whipstock and milling assembly to 80'. MU BHA. Upload and surface test MWD. Pick up and MU whipstock slide. Bring up scribe line on way in. Make up bum er ub dr' 4.50 STWHIP P WEXIT RIH with whipstock and mill assembly. Orient whipstock to 73 deg RHS. Install blower hose.. Pick up single joint of DP and last stand. Tag EZSV at 8233'. Down weight 120k up weight 160k. Set 20k down and set whipstock anchor. Pick up and confirm. Set 35k down and shear off lug. Pick up and confirm free. Top of window at 8206' at 73 degrees right. 1.50 STWHIP P WEXIT Pump 45 bbl hi-vis spacer and displace well to 9.0 ppg LSND mud at 500 gpm with 1550 psi. 3.00 STWHIP P WEXIT Mill window from 8206' to 8210'. Torque 4.5 to 8k at 65 rpm. Pump at 495 gpm with 1600 psi. WOB 2-3k. RT weight 142k. 7.50 STWHIP P WEXIT Mill window and 20' of new formation to 8234' - (from mid point of window). Up weight 160k, down weight 120k, RT weight 140k. Rotate at 90 rpm with 5k torque off bottom, 7k torque on bottom. WOB 8-10k. Pump at 400 gpm with 1180 psi. TOW = 8206'. BOW = 8222'. 1.00 STWHIP P WEXIT Circulate sweep surface to surface at 495 gpm with 1650 psi. Work mill and clean up hole. Mud weight 9.0+ ppg in and out. Recovered 90 Ibs of metal from hole. 0.50 STWHIP P WEXIT Attempt FIT to 12.0 ppg EMW at 6767 TVD with 1060 psi. Pressure deviated from straight line at 740 psi fora 11.1 ppg EMW leak off. FIT not obtained. Pressure dropped to 600 psi in 10 minutes. Verified OK to drill ahead with LOT of 11.1 ppg EMW as per Mehrdad Nadem. AOGCC -rep Chuck Scheve was notified of the FIT test, and also left a message on Tom Maunders Voice Mail. An Email was sent to Tom Maunder on 1/18/2007 summarizing FIT discussions with him. 3.00 STWHIP P WEXIT Pump dry job. Remove blower hose. POH to 1210'. 0.50 STWHIP P WEXIT POOH with whipstock assembly to 366'. 3.50 STWHIP P WEXIT PJSM. Lay down DC's and bumper sub. Download MWD and lay down. Break mills. Mills in guage. LD HWDP. Clear floor. 2.00 STWHIP P WEXIT Pick up bit, stabilizer and circulating sub. Change out handling Printed: 2/12/2007 10:13:15 AM • BP EXPLORATION Page 11 of 22 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: A-05 A-05 Spud Date: 3/14/1972 REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 NABOBS 2ES Rig Number: Date I From - To I Hours ~ Task I Code f NPT 1/18/2007 04:00 - 06:00 06:00 - 08:30 2.00 STWHIP P 2.50 STWHIP P 08:30 - 10:30 10:30 - 13:30 13:30 - 15:00 15:00 - 16:00 16:00 - 00:00 2.00 STWHIP P 3.00 STWHIP P 1.50 STWHIP P 1.00 STWHIP P 8.00 DRILL P 1/19/2007 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 12.00 DRILL P 1/20/2007 00:00 - 12:00 12.00 DRILL P 12:00 - 17:00 5.00 DRILL P 17:00 - 19:00 2.00 DRILL P 19:00 - 20:30 1.50 DRILL P 20:30 - 22:00 22:00 - 00:00 1.501 DRILL I P 2.001 DRILL I P Phase ! Description of Operations WEXIT equipment. Pull wear ring, Flush out stack. Function rams. Lay down tools. Blow through choke and kill lines. Install wear ring. Lay down test joint. Change out elevators WEXIT PJSM. Pick up motor. Make up bit, stabilizer, MWD and 1st flex collar. Surface test MWD. Pick up flex collars, HWDP, jars, circulating sub and XO to 814'. WEXIT PJSM. PU 57 joints of 4" DP to 2590'. WEXIT RIH to 8106'. Fill pipe every 30 stands and test MWD. WEXIT Slip and cut 108' of drill line. Service crown and drawworks. Inspect brakes and brushes. Service top drive. WEXIT Record baseline ECD at 9.41 ppg. Orient to 75 degrees right, high side. Pumps off and slide through window at 82• 34; ~V' INT1 Drill 8-1/2" hole to 8600' MD, 7051' TVD. Up weight 155k, down 130k, RT 140k. Torque off bottom 6k, on bottom 9k at 80 rpm. WOB - 10k. Pump at 455 gpm with 1770 psi off bottom, 2000 psi on bottom. SPR's at 8234'/1400 hrs, both pumps 30/330, 45/380. Mud weight in and out 9.0+ppg. INT1 Drill ahead to 9228' MD, 7484' TVD. Up weight 175k, down 130k, RT 150k. Add 16 ppg spike fluid at 8946' to weight up to 10.6 ppg before HRZ. Pump at 450 gpm with 2350 psi off bottom, 2600 psi on bottom. Torque 7k off bottom, 8k on bottom at 80 rpm. WOB 8 to 10k. SPR's at 9133'/1000 hrs both pumps 30/430, 45/520. ECD at 11.35 ppg EMW. Mud weight in and out 10.7 ppg. Losses 80 bbls for tour. Adding 10 sx/hr each of Mix II and SafeCarb 40. INTi Drill ahead to 9976' MD, 8147' TVD. Up weight 190k, down 140k, RT 160k. Torque 9-11 k on bottom, 8-9k off bottom at 80 rpm. WOB 8-20k. Pump at 455 gpm with 2950 psi on bottom, 2730 psi off bottom. SPR's at 9602'/1730 hrs, both pumps 30/380, 45/470. Mud weight in and out 10.5+ ppg. ECD at 11.14 ppg EMW. Losses 217 bbls for tour, total tosses for day Added up to 1750 Ibs of LCM per hour and brought losses down to 7 bph at midnight. Used Safecarb 40 and 50 (CaC03), Mix II medium (fibre) and Nut Plug medium (pecan shells). INT1 Drill ahead to 10628' MD. Up weight 205k, down 140k, RT 170k. Torque off bottom 9-10k, on bottom 10-11k at 80 rpm. Pumping at 455 gpm with 3150 psi on bottom, 2850 off bottom. Losses for tour 140 bbls. INT1 Drill ahead to TD of 10843' MD, 8835' TVD. Up weight 210k, down 145k, RT 175k. Torque 10-11 k off bottom, 13k on bottom at 80 rpm. WOB 12-16k. Pump at 455 gpm with 3200 psi on bottom, 2860 psi off bottom. Mud weight 10.6 ppg. SPR's both pumps at 10843'/1900 hrs, 30/330, 45/410. INT1 Circulate up sample. Rotate and reciprocate. TD called at 10843' MD. INTi Pump 45 bbl hi-vis sweep surface to surface and circulate until clean. Rotate and reciprocate at 100 rpm, pumping at 500 gpm with 3350 psi. INT1 POOH to 8292' MD. Up weight 235k, down 125k. Rough spot at 9240'. Pulled 300k up, down 100k. INT1 Log MAD pass at 250 fpm from 8278' to 7960' with pumps off Printed: 2/12/2007 10:13:15 AM • • BP EXPLORATION Page 12 of 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: Date , From - To ~ Hours Task i Code NPT Phase ; Description of Operations 1/20/2007 122:00 - 00:00 ~ 2.00 ~ DRILL P INT1 going through the window. Pump at 460 gpm with 2350 psi 1/21/2007 00:00 - 01:30 1.50 DRILL P 01:30 - 04:00 2.50 DRILL P 04:00 - 07:00 ( 3.001 DRILL I P 07:00 - 13:00 I 6.001 DRILL I P 13:00 - 18:00 I 5.001 DRILL I P 18:00 - 21:30 3.50 BOPSU P 21:30 - 22:30 1.00 CASE P 22:30 - 00:00 1.50 CASE P 1/22/2007 00:00 - 05:00 5.00 CASE P 05:00 - 05:30 0.50 CASE P 05:30 - 10:00 4.50 CASE P 10:00 - 11:00 I 1.001 CASE I P 11:00 - 12:30 ~ 1.50 ~ CASE ~ P 12:30 - 16:00 I 3.501 CASE I P 16:00 - 17:00 ~ 1.00 ~ CEMT ~ P 17:00 - 20:00 I 3.001 CEMT I P 20:00 - 20:20 I 0.331 CEMT I P 20:20 - 20:35 I 0.25 ~ CEMT ~ P 20:35 - 20:50 I 0.251 CEMT I P Total losses for day 200 bbls. INT1 PJSM, Service and lubricate rig, the top drive and crown. INT1 PJSM. RIH from 8000' to 10843'. Took weight at 9240', 10044', 10388' and 10650'. Weight between 20 and 30k down, 20 to 60k up. Wiped through and down and cleaned up fine. INT1 Make up top drive and wash last stand down at 350 gpm with 2460 psi. Circulate BU to window and increase pump rate when ECD dropped to 10.9. Pumps to 450 gpm with 2973 psi then 500 gpm with 3440 psi. ECD at 11.1. Pump 50 bbl hi-vis sweep surface to surface and pump BU until clean. Clean ECD at 10.89. Blow down top drive. INT1 PJSM. POH to 8000'. Pulled slick with no problems. Blow down kill line. Remove blower hose. Make up top drive, pump dry job at 206 gpm with 674 psi. Blow down top drive. POH to 814'. Retrieve rabbit. Pull air slips. INTi PJSM. Lay down BHA. Download MWD. Flush MWD tools. Break off bit. LD MW D tools. Clear and clean floor. LNR1 PJSM. Install test plug. Change out upper rams to 7". PJSM. Pick up 7" test joint, XO and I va ve. i stac an test 7" rams to 250 si low 4000 si hi has er AOGCC. Pull test plug. Install wear ring. Break and lay down test joint. LNR1 PJSM. Rig up floor and casing equipment. LNRf PJSM. Pick up and make up shoe track, check floats. LNR1 Continue running 68 jts 7" 26# L-80 BTC-M liner. MU liner hanger. LNR1 Circ 1 x liner volume at 264 gpm with 174 psi. LNR1 RIH with 7" liner on 4" DP. Up weight 90k, down 87k. Run in to window at 8200'. LNR1 Break circulation and circulate 1.5x liner and DP volume at window. LNR1 Run in to open hole with liner at 60-75 fpm. Run without problems to 10410'. LNR1 Liner started taking weight at 10410' and had to be worked all the way to bottom from that point. Slacking off to 60-90 klbs down weight and see normal slack off weight of 110 klbs come back slowly on weight indicator. Pick up to 275-320 klbs to break pipe free and then continue down slowly making progress to 10800'. LNR1 MU liner cement head and hook up lines. Re-rig lines because of frozen cementing standpipe. RIH to bottom at 10843' and break circulation at 1.5 bpm C~ 500 psi. LNR1 Stage pumps up slowly over 20 minutes to 6 bpm at 1220 psi and circulate 3+ open hole annular volumes. No losses observed. LNR1 PJSM for cement job. Pump 5 bbls water. Pressure test lines to 4000 psi. At 2010 hrs pump 20 bbls of 11.5 ppg Mud Push II at 5 bpm with 1057 psi. LNR1 Pump 69 bbls (168 sx) 12.5 ppg LiteCrete GasBlok lead slurry. Start at 4.8 bpm with 1144 psi. With 40 bbls away at 4.8 bpm at 1048 psi. At 2035 finish with 69 bbls at 4.8 bpm with 943 psi LNR1 Pump 35 bbls (170 sx) 15.8 ppg Class G, GasBlok tail slurry at 2043 hrs. Pump at 5.1 bpm with 975 psi. With 20 bbls away Printed: 2/12/2007 10:73:15 AM • i BP EXPLORATION Page 13 of 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours II Task Code NPT Phase 1/22/2007 ~ 20:35 - 20:50 ~ 0.25 ~ CEMT I P ~ ~ LNR1 20:50 - 22:15 I 1.421 CEMT I P I I LNR1 22:15 - 22:30 ~ 0.25 ~ CEMT ~ P ~ ~ LNR1 22:30 - 23:30 I 1.001 CEMT I P I I LNR1 23:30 - 00:00 0.50 CEMT P LNR1 1/23/2007 00:00 - 04:00 4.00 CEMT P LNR1 04:00 - 05:00 1.00 CEMT P LNR1 05:00 - 09:00 4.00 CEMT P LNR1 09:00 - 10:30 1.50 CASE P LNR1 10:30 - 14:00 3.501 CASE P LNR1 14:00 - 00:00 I 10.00 I CASE I P I I LNR1 1/24/2007 100:00 - 03:00 I 3.001 CASE I P I I LNR1 03:00 - 04:00 I 1.001 CASE I P I I LNR1 04:00 - 05:00 ~ 1.00 ~ CASE ~ P ~ ~ LNR1 Description of Operations pumping at 5.1 bpm with 1140 psi and at 35 bbls away pumping at 4.5 bpm with 650 psi. Drop dart and verify left plug head. Pump 5.7 bbls of water followed by 10.6 ppg mud. With 25 bbls away pumping at 5.4 bpm pressure at 385 psi, 50 bbls at 5.0 bpm with 760 psi, 70 bbls at 5.0 bpm with 850 psi. At 2109 hrs latched up, (verified with 1000 psi pressure spike), with 78 bbls away. At 2119 hrs pumped away 130 bbls at 4.9 bpm with 1450 psi showing good lift. At 2120 with 135 of 179.5 bbls displacement away, the hole packed off and the pressure spiked to 2900 psi. Shut down and let pressure bleed off. Started back up at 1/2 bpm with 900 psi and no returns. Increased rate to 1 bpm with 1900 psi and no returns. Continued to pump at 1 bpm until 177 bbls away and returns were re-established at that time. Continued to pump at 1 bpm until plug was bumped at 179.5 bbls away and pressured up to 3500 psi to set liner hanger. Bleed pressure with 1.8 bbls back, float check showed floats holding. CIP at 2215 hours. Estimated losses to formation during cement job at 42 bbls of cement slurry. Calculate that annulus contains 35 bbls tail slurry and 27 bbls lead slurry. With 40% washout factor, TOC at -8900'. Turn over to rig. Pump up to 1000 psi. Unsting and pump any cement off liner top at 500 gpm. Slow to 126 gpm. Set down 50k and set packer. Pick up and rotate down to confirm. Circulate bottoms up at 450 gpm with 2400 psi. No cement in returns . Break and lay down cement head and 1 single joint. Displace the well to seawater from liner top at 8044' MD. Perform top. job on 18-5/8"" x 13-3/8" annulus with 2 bbls of 15.7 ppg Arctic Set 1 cement. Slip & cut drilling line. POH with liner running tool. Lay down and clear floor. Pull wear ring. Check lock down screws. PJSM. Test casing to 1500 psi for 30 minutes. Test OK. PJSM. Bring 7" handling equipment to floor. Change out bails. Rig up casing air slips, power tongs, short scaffolding and rig floor to run 7" tieback. Make up shoe track and Bakerlok. Run 115 joints of 7" 26#, L-80 BTC-M casing. Rig up computers. Make up TC-II floor valve. Make up XO joint and run 35 joints of 7", 26#, L-80, TC-II. Finish RIH with 7", 26#, L-80, TC-II tieback to joint #83. Up weight 200k, down 165. Clear and clean floor. Laydown short scaffolding, thread protector bags, casing air slips and equipment. Pick up joint #84 and tag no go at 2.80'. Bottom collar 4.29' above tubing spool at 27.12'. Lay down joint #84. Pick up 5' pup and 3' crossover. Load plugs in cement head and pick up. Make up cement head and hose. Pressure up to 500 psi and Printed: 2/12/2007 10:13:15 AM • r BP EXPLORATION Page 14 of 22 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date ,I Name: ell Name: e: Name: From - To A-05 A-05 REENTE NABOBS NABOBS Hours R+COM ALASK 2ES Task PLET A DRI Code ~ E LLING NPT 1 Start I Rig Rig Phase ~ Spud Date: 3/14/1972 : .12/25/2006 End: 2/9/2007 Release: 2/9/2007 Number: Description of Operations 1/24/2007 04:00 - 05:00 1.00 CASE P LNR1 verify. Pull up 200k to take compression out. Bleed pressure. Pull up 7' and pressure up to 200 psi. Pull 1 more foot and pressure released to verify holes open. Establish circulation at 118 gpm with 110 psi. 05:00 - 07:00 2.00 CEMT P LNR1 While circulating, rig up cementers and hot oil. Prepare for cement job and hold PJSM. 07:00 - 07:30 0.50 CEMT P LNR1 Cement 7" tieback as per program. Pump 5 bbls water. Pressure test lines to 4000 psi. Test OK. 07:30 - 10:30 3.00 CEMT P LNR1 Switch over to rig. Pump 40 bbl hi-vis Flo-Pro spacer at 218 gpm with 168 psi. Shut down turn over to Little Red Services. Pump 220 bbls diesel at 5 bpm with 900 psi. Drop bottom plug. Mix and pump 136 bbls of Class G, Gas Blok, 15.8 ppg cement. Drop plug. Displace with 307 bbls of seawater. Shut down with spacer to surface. Close annular preventer and divert returns to cuttings tank. Continue to pump and bump plug with 2200 psi. CIP at 1015 hrs. Open bag bleed pressure slowly and stab seal assembly into liner hanger top to the no go. 10:30 - 11:00 0.50 CEMT P LNR1 Pressure up to 1500 psi and hold for 30 minutes. Test OK. 11:00 - 13:00 2.00 CEMT P LNRi PJSM. Clear and clean floor. ', 13:00 - 17:00 4.00 BOPSU P LNR1 PJSM. Pick up supersucker hose and suck out casing. Latch '~ on and pull 150k. Remove slips and bushings. Clean out under rotary table. Lay down mouse hole. ND BOP stack and raise. Align casing. Set emergency slips with primary packoff as per Cameron rep. Set with 135k tension in slips. Rig up Wachs cutter. Cut casing and lay down cut pipe. Cut joint at 8.89'. Pull riser and stand back BOP stack. 17:00 - 20:30 3.50 BOPSU P LNR1 PJSM. Bring in tubing head and secondary packoff to cellar. Prep wellhead. Install tubing spool and test packoffs to 4000 psi for 30 minutes. Test OK. 20:30 - 00:00 3.50 BOPSU P PRODi Nipple up BOP stack. Install mouse hole. PJSM. Change upper rams from 7" to 3.5" x 6" variables. Prepare to test ROPE. 1/25/2007 00:00 - 06:00 6.00 BOPSU P PROD1 PJSM. Line up and test BOPE to 250 psi low, 4000 psi high on 4" test joint. Test Hydril to 250 psi low, 2500 psi high. Test upper rams with 4-1/2" test joint to 250 psi low, 4000 psi high. Test witnessed by Chuck Scheve with AOGCC. 06:00 - 07:00 1.00 BOPSU P PROD1 Rig down test joint. Blow down lines. Install wear ring. 07:00 - 12:00 5.00 DRILL P PROD1 PJSM. Pick up 6-1/8", 1.83 degree bend, BHA. Try running in hole. Problems getting down with BHA. Pick up flex collar and work into 7". Up load MWD. Continue running into hole with BHA to 373'. 12:00 - 16:00 4.00 DRILL P PROD1 Pick up 4" DP to 3170'. Test MWD. 16:00 - 17:30 1.50 DRILL P PROD1 RIH to 7938'. Install blower hose. 17:30 - 19:00 1.50 DRILL P PROD1 Wash and ream to 8022' at 250 gpm with 1750 psi. Rotate at 40 rpm. Taking weight from 7950'. Tag and drill plug at 8022'. WOB 5k. Circulate bottoms up with cement and rubber with returns. Up weight 155k, down 100k, RT 125k. 19:00 - 20:30 1.50 DRILL P PROD1 Pushing junk ahead. Hanging up every 40'. Wash and ream to 8687', pipe clear. Blow down top drive. 20:30 - 21:00 0.50 DRILL P PROD1 RIH to 9151'. Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 15 of 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Event Name: REENTER+COM Contractor Name: NABOBS ALASK Rig Name: NABOBS 2ES ~ ~ ~ Task ~ Date !From - To Hours ~ PLET A DRI Code ~ - E LLING NPT Spud Date: 3/14/1972 Start: 12/25/2006 End: 2/9/2007 I Rig Release: 2/9/2007 Rig Number: Phase ~ Description of Operations 1/25/2007 21:00 - 22:30 1.50 DRILL P PROD1 PJSM. Perform 5 stand stripping drill with all crew members. Blow down choke and kill line. POOH and retrieve floor valves. 22:30 - 23:30 1.00 DRILL P PROD1 RIH to 10739'. 23:30 - 00:00 0.50 DRILL P PROD1 Break circulation at 245 gpm with 2550 psi. Rig up guage to 9-5/8" x 7" annulus. Rig up for casing test. 1/26/2007 00:00 - 00:30 0.50 DRILL P PROD1 PJSM. Circulate at 250 gpm with 1800 psi. 00:30 - 01:30 1.00 DRILL P PROD1 PJSM. Rig up and test casing to 4000 psi for 30 minutes and record on chart. Test passed. Blow down kill line. 01:30 - 04:00 2.50 DRILL P PROD1 Drill out shoe track and float equipment at 250 gpm with 2150 psi off bottom, 2350 psi on bottom. Rotate at 40 rpm with 9-10k torque off bottom and 10-11 k torque on bottom. Up weight 210k, down 135k, RT 150k. Pump hi-vis sweep with Steel Lube. Lower torque to 9k on bottom. 04:00 - 07:00 3.00 DRILL P PROD1 Pump 100 bbl water spacer followed by 45 bbls hi-vis sweep with Steel Lube. Follow spacer with new 8.4 ppg Flo-Pro mud. Displace at 250 gpm with 1900 psi. Bring new mud around as per Mud Engineer. Shut down. Blow down top drive. Clean possum bellies. 07:00 - 10:00 3.00 DRILL P PROD1 Drill remaining cement. Tag and drill shoe and 20' of new formation to 10864'. Circulated bottoms up at 250 gpm with 1850 psi. 10:00 - 11:00 1.00 DRILL P PROD1 Line up and perform FIT to 9.7 ppg EMW with 600 psi. Tom Maunder on 1/18/07 approved FIT of 9.7 ppg. Mehrdad nadem sent an Email on 1/18/2007 to 11:00 - 13:30 2.50 DRILL P PROD1 Drill ahead to 10894'. Up weight 175k, down 140k, RT 160k. Pump at 250 gpm with 1850 psi off bottom, 1950 psi on bottom. Lost returns. 13:30 - 14:30 1.00 DRILL N DPRB PROD1 14:30 - 17:00 2.50 DRILL N DPRB PROD1 17:00 - 19:30 2.50 DRILL N DPRB PROD1 19:30 - 20:30 1.00 DRILL N DPRB PROD1 20:30 - 21:00 0.50 DRILL N DPRB PROD1 21:00 - 21:30 0.50 DRILL N DPRB PROD1 21:30 - 22:30 1.00 DRILL N DPRB PROD1 22:30 - 23:30 1.00 DRILL N DPRB PROD1 23:30 - 00:00 0.50 DRILL N DPRB PROD1 Pull back to shoe at 10844'. Establish static losses of 300 boh. Drop bail to open up CCV, (Centurion Circulating Valve). Pump at 84 gpm with 457 psi. Seat and pressure up to 2000 psi. Hold and wait 1 minute. Bring pressure up to 2100 psi and open CCV. Rack back 1 stand, blow down top drive and kill line. Drop ball to close off BHA. Build LCM pill. Circulate over the top with losses at 120 bph. Pump 66 bbl, 47 ppb LCM pill at 262 gpm with 814 psi. Reciprocate pipe. Up weight 175k, down 120k. Chase with 125 bbls mud. Shut down. Blow down top drive. Circulate over the top and iet pill soak down. Static losses down to 12 bph. POOH to 9713'. Change shaker screens to be able to handle higher pump rates. Establish circulation at 1 bpm with 354 psi for 10 minutes with no returns. Bring pumps up to 2 bpm with 404 psi and establish returns. losses at 84 bph. Bring pumps up to 282 gpm with 833 psi. Losses at 110 bph. Pump remaining LCM pill into formation. Shut down and blow down top drive. RIH to 10833'. Make up top drive. Pump 71 bbl, 80 ppb LCM pill at 245 gpm with 1050 psi. Chase out of CCV. Blow down top drive. Circulate over the top with 2 bph static losses. POOH to 8965', above the LCM pill. Up weight 202k, down 143k. Establish circulation at 157 gpm with 470 psi. Losses starting Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Weli Name: Event Name: Contractor Name: Rig Name: Date I From - To 1 /26/2007 123:30 - 00:00 A-05 A-05 REENTER+COMPLETE NABOBS ALASKA DRILLING NABOBS 2ES i Hours Task Code ~ NPT ~ 0.501 DRILL I N DPRB Start: Rig Release: Rig Number: Phase PROD1 1/27/2007 100:00 - 01:30 I 1.501 DRILL I N I DPRB I PROD1 01:30 - 02:30 1.00 DRILL N DPRB PROD1 02;30 - 03:30 1.00 DRILL P PROD? 'I 03:30 - 04:00 0.50 DRILL P PROD1 it 04:00 - 12:00 8.00 DRILL P PROD1 I 12:00 - 20:00 8.00 DRILL P PROD1 20:00 - 20:30 0.50 DRILL N DPRB PROD1 ~~ 20:30 - 22:00 1.50 DRILL N DPRB PROD1 22:00 - 00:00 2.00 DRILL N DPRB PROD1 1/28/2007 00:00 - 01:00 1.00 DRILL N DPRB PROD1 01:00 - 01:30 0.50 DRILL N DPRB PROD1 01:30 - 02:30 1.00 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 03:30 0.50 DRILL N DPRB PROD1 12/25/2006 2/9/2007 Page 16 of 22 Spud Date: 3/14/1972 End: 2/9/2007 Description of Operations at 84 bph, falling to 61 bph. Increase pumps to 250 gpm with 693 psi. Losses at 140 bph. Increase pumps to 350 gpm with 968 psi. Losses at 74 bph. Continue pumping pill away. Circulate above LCM pill. Pump at 350 gpm with 968 psi. Loosing 74 bph, falling to 29 bph. Pump away 59 bbls of LCM pill and losses stop. Hole breathing slightly, with 5 bbl gain. New Fto-Pro coming to surface. Shut down and drop Operating Ball to close CCV. Paramaters for ball drop, 84 gpm with 340 psi. Dropped ball and seated 13 minutes later. Eased pressure up to 2020 psi and valve closed, opening to BHA. Parameters at 200 gpm with 1200 psi. RIH to 10894'. Directional drill ahead to 10899. Losses at approximately 5 bph. LCM overloading shakers on returns. Pull up and back off pumps. Circulate out LCM. Change screens and pick up rate. Directional drill ahead to 11046'. Pumping at 247 gpm with 1820 psi on bottom, 1650 psi off bottom. Up weight 195k, down 130k, RT 160k. WOB 15-20k. Torque at 9-10k on bottom, 8k off bottom with 23 to 40 rpm. Pumped 40 bbl hi-vis sweep, at 11021' hole packing off with high drag. Taking weight going down. SPR Pump #1, 30/570, 45/660. Pump #2, 30/570, 45/650. Both SPR's taken at depth of 10894' and a time of 0230 hrs. Pump 40 bbl hi-vis sweep at 11046', hole packing off. Drill ahead to 11209'. Circulate sweep at 250 gpm with 1630 psi. Up weight 215k, down 135k, RT 165k. Losses at 80 bph. Torque 9-13k off bottom, 10-16k on bottom. Packing off at times. SPR #1, 30/580, 45/660. Pump #2, 30/580, 45/640. Both rates taken at 2000 hrs at a depth of 11100'. POOH to 10833' with no problems. Checked parameters. Pumping at 245 gpm with 1450 psi. Drop Operating Ball to open CCV. Pump at 2 bpm, land and open valve with 3025 psi. Drop BHA Shut Off Ball and chase with 40 bbl, 50 ppb LCM pill at 402 gpm with 1257 psi. Shut down and blow down top drive. Loss rate during pumping averaged 37 bph. POOH to 9432'. Make up top drive. Pump away 50 bbls fluid to push LCM pill into formation. Pump at 235 gpm with 459 psi. Reciprocate pipe. Losses at 688 for last 24 hours. Drop CCV Operating Ball to close circ sub. Pump at 84 gpm with 105 psi. Ball seated. Valve closed with 2690 psi. Parameters after closing, pump rate 247 gpm with 1384 psi confirming valve closed. PJSM. RIH to 7" shoe at 10834'. PJSM. Slip and cut 64' of drilling tine. Service top drive. RIH to 11209' with no problems. Hole appears to be cleane_d_ 03:30 - 12:00 8.50 DRILL P PROD1 Drill ahead to 11418'. At 0400 hours swap over to 8.4 ppg Flo-Pro. Up weight 180k, down 130k, RT 165k. WOB 16k. Torque off bottom 5-6k, on bottom 6-7k at 20 rpm. Pumping at 250 gpm with 2100 psi on bottom, 1950 psi off bottom. Mud weight 8.4 ppb in and out. Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 17 of 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To ~ NPT Phase Hours ', 1 _ l Task Code -- 1/28/2007 ~ 12:00 - 00:00 ~ 12.00 DRILL ~ P ~ PROD1 1/29/2007 100:00 - 01:00 I 1.001 DRILL I P I I PROD1 Description of Operations Drill ahead to 11661'. Up weight 180k, down 130k, RT 165k. Pump at 250 gpm with 2140 psi on bottom, 1970 psi off bottom. Rotate at 20 rpm with 5-6k torque off bottom, 6-8k on bottom. SPR both pumps, 30/770, 45/880 at 11486'/1500 hrs. Mud weight in and out 8.4 ppg. Loosing -50 bph at end of drilling. Total losses for last 24 hours 1179 bbls. Drill ahead to end of build at 11690' MD, 9000' TVD. Up weight 185k, down 130k, RT 160k. Pump at 250 gpm with 1940 psi off bottom, 2040 psi on bottom. Rotate at 20 rpm with 5-6k torque off bottom, 7-8k on bottom. WOB 15k. Losses still at -50 bbls 01:00 - 02:30 1.50 DRILL P PROD1 PJSM. Pump hi-vis sweep surface to surface. 02:30 - 03:00 0.50 DRILL N DPRB PROD1 POOH to 11209', putting CCV above shoe at 10843' MD. Monitor well. OK 03:00 - 03:30 0.50 DRILL N DPRB PROD1 Drop CCV Operating Ball and pump down at 84 gpm with 800 psi. Reciprocate pipe. Ball seated and opened CCV at 3060 psi. Pump and verify pressure release. Valve open. Drop BHA closing ball. 03:30 - 04:30 1.00 DRILL N DPRB PROD1 Pump 78 bbl, 80 ppb, LCM pill out CCV. Chase out of circ sub. 04:30 - 07:00 2.50 DRILL N DPRB PROD1 POOH above pill at 9245'. Circulate out circ sub and let LCM soak into open formation. 07:00 - 09:00 2.00 DRILL N DPRB PROD1 PJSM. Circulate above LCM pill at 140 gpm with 605 psi. Pushed away 71 bbls. Pumped dry job. Remove blower hose. Monitor well. Seepage losses. 09:00 - 14:00 5.00 DRILL P PROD1 PJSM. POOH to 372'. 14:00 - 17:30 3.50 DRILL P PROD1 PJSM. POOH with BHA. Lay down CCV and ball catcher sub. Recovered 8 balls from ball catcher. Monitor well. OK. Download MWD. Pull MWD tools. Drain motor and break bit. 17:30 - 18:30 1.00 DRILL P PROD1 PJSM. Clear and clean floor. Lay tools down the beaver slide. 18:30 - 20:30 2.00 EVAL P PROD1 PJSM. Pick up wireline tools for USIT/CBL. Circulate over the top. ~ ~ ~ ' 20:30 - 00:00 3.50 EVAL P PROD1 RIH with SWS USIT/CBL logging tools. Log up from 10800 . Mud weight 8.4 ppg. Losses for 24 hour period 158 s. Loosing 10 bbls per hour static while running logs. TOC - 2690' 1/30/2007 00:00 - 02:00 2.00 EVAL P PROD1 Log 7" liner/casing from 10800' in USIT/CBL mode. 02:00 - 03:00 1.00 EVAL P PROD1 PJSM. Rig down SWS. Clear and clean floor. 03:00 - 04:00 1.00 DRILL P PROD1 PJSM. Pick up BHA to rig floor. 04:00 - 08:00 4.00 DRILL P PROD1 PJSM. Make up BHA to 374'. Shallow test MW D,230 gpm ~ 650 psi. 08:00 - 13:00 5.00 DRILL P PROD1 PJSM. Run in hole from 374' to 8315',break circulation at 3173',and 5976'. Hole started taking fluid at 5508',no pipe displacement when running in at 90 sec. per stand. Run in at 60 sec. per stand 0 gains and 0 losses. 13:00 - 14:30 1.50 DRILL P PROD1 Make up top drive and break circulation at 2 BPM @ 551 psi. Establish returns and bring rate up to 125 gpm @718 psi. Increase rate to 135 gpm 0760 psi,losses increase ,reduce rate to 125 gpm and reciprocate pipe, monitor losses. 140k up wt.,120k down wt.,mud wt. in and out 8.4ppg. 14:30 - 16:00 1.50 DRILL P PROD? Run in hole from 8315' to 10,690',fill pipe at casing shoe. Install blower hose and blow down top drive. Up wt 200k,down wt. Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 18 of 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To Hours Task i Code NPT - -' -~ ~- 1/30/2007 14:30 - 16:00 1.50 DRILL P 16:00 - 17:00 1.00 DRILL P 17:00 - 00:00 I 7.001 DRILL I P 1 /31 /2007 (00:00 - 03:00 ~ 3.00 ~ D R I LL ~ P Spud Date: 3/14/1972 Start: 12/25/2006 End: 2/9/2007 I Rig Release: 2/9/2007 Rig Number: Phase Description of Operations PROD1 140k. PROD1 Run in hole from 10,835' to 11,690',wash down last stand at 250 gpm,1930 psi. No fill on bottom. PROD1 Drill 6 1/8" hole from 11,690' to 11,957'. Up wt.176k,down wt. 125k,rotating wt. 150k. Torque off bottom 4-5k and on bottom 6-7k at 60 RPM. WOB 6-8k. Mud wt. in and out 8.4 ppg,vis 52,YP 29. Losses started at 20 BPH then increased to 60 BPH. Continuing to treat with SafeCarb 40 & 250,nut plug,and G-seal while drilling. Daily losses 485 bbls. Sliding as per revised well plan,TVD on plan and 5'right of plan. Surveys are currently not being IFR corrected due to a communications problem. PROD1 Drill 6 1/8" hole from 11,957' to 12,070'. Flow increased from 32% to 36% with no increase in pit volume due to losses. Picked up off bottom and flow checked well. Well flowing,shut in well and record pressures shut valve in front of super Shut in casing pressure 130psi,shut in drill pipe 30psi. 03:00 - 06:30 3.50 DRILL N DPRB PROD1 Noti drillin mana er and AOGCC re .John Cris . Circulate out using drillers method, 40stks/min. Open up well and monitor well static. Hole took 115 bbls of fluid when circulating through choke. 06:30 - 13:30 7.00 DRILL P PROD1 Drill 6 1/8" hole from 12,070' to 12,332',circulate sweep and POOH due to level 3 driving conditions on pads access roads. Up wt. 175k,down wt. 125k,rotating wt 150k.W06 6-8k,RPM 60,off bottom torque 4-5k,on bottom 8k.282 GPM @ 2100 psi off bottom and 2310 psi on bottom.Mud wt. in and out 8.4 ppg. Losses at 40-60 BPH while drilling,treating mud with SafeCarb 40 & 250,nut plug,G-Seal,Mix 11,and MI Seal. Starting drop for first planned TVD drop,TVD on proposed and 18'right of planned direction. Surveys not IFR corrected due to network being down. 13:30 - 14:30 1.00 DRILL N WAIT PROD1 Circulate Hi-Vis sweep,surface to surface,286 GPM ~ 2091 psi. 14:30 - 16:30 2.00 DRILL N WAIT PROD1 PJSM. POOH from 12,332' to 10,071'. Circulate over top of hole. Hole in good condition,no tight spots. Monitor well at shoe,no losses or gains. 16:30 - 23:30 7.00 DRILL N WAIT PROD1 Wait on weather. Static losses 3-8 BPH. At 22:30 hole took an instantaneous 3 bbls loss. ~ 23:30 - 00:00 0.50 DRILL N WAIT PROD1 Install blower hose and prepare to run in hole. 2/1/2007 00:00 - 01:30 1.50 DRILL N WAIT PROD1 PJSM. Run in hole from 10,741' to 12,332',no fill, hole in good condition. i Hole did not give back pipe displacement due to losses. 01:30 - 12:00 10.50 DRILL P PROD1 Drill 6 1/8" hole from 12,332' to 12,706' Up wt. 180k,down wt. 125k,rotating wt 155k.W06 8-10k,RPM 60,off bottom torque 7-9k,on bottom 6-7k.282 GPM ~ 2100 psi off bottom and 2400 psi on bottom.Mud wt. in and out 8.4 ppg. Losses at 60-70 BPH while drilling,treating mud with SafeCarb 40 & 250,nut plug, G-Seaf,Mix 11,and M I Seal. Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 19 of 22 ~ Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 'Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: F Date ~ rom - T~ Hours ~ Task~ode NPT Phase 2/1/2007 01:30 - 12:00 10.50 DRILL P PROD1 12:00 - 13:30 1.50 DRILL P PROD1 13:30 - 15:00 1.50 DRILL N DFAL PROD1 15:00 - 19:00 4.00 DRILL P PROD1 19:00 - 00:00 I 5.001 DRILL I N I DFAL I PROD1 2/2/2007 ~ 00:00 - 06:30 ~ 6.50 ~ DRILL ~ N ~ DFAL ~ PRODi 06:30 - 08:00 I 1.501 DRILL I N I DFAL I PROD1 08:00 - 09:00 1.00 ~ DRILL N DFAL PROD1 09:00 - 10:00 1.00 DRILL N DFAL PROD1 10:00 - 11:30 1.50 DRILL N DFAL PROD1 11:30 - 12:30 1.00 DRILL N DFAL PROD1 12:30 - 13:00 0.50 DRILL N DFAL PROD1 13:00 - 13:30 0.50 DRILL N DFAL PROD1 13:30 - 18:30 5.00 DRILL N DFAL PROD1 18:30 - 19:30 1.00 DRILL P PROD1 19:30 - 20:00 0.50 DRILL P PROD1 20:00 - 21:30 1.50 DRILL N DFAL PROD1 21:30 - 00:00 I 2.50 i DRILL I P i I PROD1 12/3/2007 100:00 - 12:00 I 12.001 DRILL A P I I PROD1 Description of Operations Surveys are now IFR corrected. PJSM.Drill 6 1/8" hole from 12,706' to 12,809'. Assembly stopped drilling appearing to be downhole motor failure. Up wt. 180k,down wt. 125k,rotating wt 155k.W0B 8-10k,RPM 60,off bottom torque 7-9k,on bottom 6-7k.282 GPM ~ 2100 psi off bottom and 2400 psi on bottom.Mud wt. in and out 8.4 ppg. Losses at 60-70 BPH while drilling,treating mud with SafeCarb 40 & 250,nut plug, G-Seal,Mix 11,and M I Seaf. Increase lubricant concentration from 2% to 3% to aid sliding. Well path on line for TVD and 1' right of plan, Circulate H-Vis sweep,288 GPM@2029 psi surface to surface. PJSM. POOH from 12,799', pump out due to well not taking displacement. MAD pass log from 11,770' to 11,030' at 600 fUhr. Up wt. 190k down wt. 135k. Monitor well at shoe for 10 minutes,static. Attempt pulling,hole swabbing/breathing.Pump out at 100 GPM, still swabbing,pump out at 240 GPM to 8221' Pump out of hole at 240 GPM from 8221'to 3450'. Attempt to pull without pump every 5 stands. Hole swabbing/breathing. Pump dry job. Pull out of hole from 3450' to 374'. Total losses on trip out of hole 170 bbl. PJSM. Change out handling equipment,flush BHA with 20 bbls water. Lay down BHA to motor and rack back MWD. Break bit and lay down mud motor.Clear and clean floor. PJSM. Pick up new mud motor,make up to bit. Pick up MWD, scribe to motor. Upload MWD. Static losses while out of hole less than 1 BPH. PJSM. Pick up remaning BHA to 374'. Shallow pulse test MWD,282 GPM @ 889 psi. PJSM. Run in hole from 374' to 10,835'. Break circulation at 3173',5976', and 8781'. PJSM. Cut and slip 105' of drilling line. PJSM. Service top drive. PJSM. Run in hole from 10,835' to 12,809',no trouble. Total losses while running in hole 171 bbl. PJSM.Drill 6 i/8" hole from 12,809' to 12,840' Up wt. 205k,down wt. 125k,rotating wt 155k.W0B 5-8k,RPM 80,off bottom torque 6k,on bottom 7k.282 GPM @ 1900 psi off bottom and 2280 psi on bottom.Mud wt. in 8.4ppg and out 8.5 PPg• Losses at 60-70 BPH while drilling,treating mud with SafeCarb 40 & 250,nut plug, G-Seal,Mix 11,and M I Seal. Beginning build to final ascent target. PJSM.Drill 6 1/8" hole from 12,840' to 13,212'. Up wt. 185k,down wt. 125k,rotating wt 150k.W0B 5-8k,RPM 80,off bottom torque 7-8k,on bottom 9k.282 GPM @ 1900 psi off bottom and 2280 psi on bottom.Mud wt. in 8.4ppg and out 8.5 pPg• Losses at 60-70 BPH while drilling,treating mud with SafeCarb 40 & 250,nut plug, G-Seal,Mix 11,and M I Seal. Running centrifuge and mud cleaner to control mud weight. Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 20 of 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Date 1 From - To ~ Hours `Task i Code NPT 2/3/2007 12:00 - 00:00 2.00 ~ DRILL ~ P 2/4/2007 100:00 - 10:30 10.501 DRILL ~ P 10:30 - 13:00 13:00 - 20:30 20:30 - 22:30 22:30 - 00:00 2/5/2007 00:00 - 03:30 04:00 - 06:30 06:30 - 07:30 07:30 - 08:30 08:30 - 12:00 12:00 - 13:00 13:00 - 14:00 14:00 - 19:00 19:00 - 20:00 20:00 - 23:00 23:00 - 00:00 2.50 DRILL P 7.50 DRILL P 2.00 DRILL P 1.50 DRILL P 3.50 DRILL P 2.50 DRILL P 1.00 CASE P 1.00 CASE P 3.50 CASE P 1.00 CASE P 1.00 CASE P 5.00 CASE P 1.00 CASE P 3.00 CASE P 1.00 CASE P Spud Date: 3/14/1972 Start: 12/25/2006 End: 2/9/2007 Rig Release: 2/9/2007 Rig Number: Phase i Description of Operations PROD1 PJSM.Drill 6 1/8" hole from 13,212' to 13,680'. Up wt. 185k,down wt. 120k,rotating wt 155k.W06 5-10k,RPM 80,off bottom torque 7k,on bottom 8k.282 GPM @ 2000 psi off bottom and 2280 psi on bottom.Mud wt. in 8.4ppg and out 8.5 PPg• Losses at 60-70 BPH while drilling,treating mud with SafeCarb 40 & 250,nut plug, G-Seal,Mix 11,and M I Seal. Running centrifuge and mud cleaner to control mud weight. Starting final drop in anglelTVD. PROD1 PJSM.Drill 6 1/8" hole from 13,680' to 14,180' Up wt. 185k,down wt. 120k,rotating wt 15k.W06 5-10k,RPM 80,off bottom torque 7k,on bottom 8k.282 GPM @ 2060 psi off bottom and 2400 psi on bottom.Mud wt. in 8.5ppg and out 8.5 PPg• Losses at 60-70 BPH w it drilling,treating mud with SafeCarb 40 & 250,nut plug, G-Seal,Mix 11,and M I Seal. Running centrifuge and mud cleaner to control mud weight. PROD1 Circulate Hi -Vis sweep around,280 GPM Q 2300 psi PRODi POOH pumping out from 14,180' to 10,835' PROD1 PJSM. Establish presure at 850 psi, 84 GPM. Drop circulation sub opening ball and pump down at 84 GPM. Seat ball and pressure up to 2470 psi to open. Pump 35 bbl Hi-Vis sweep,490 GPM ~ 1950 psi. Rotate and reciprocate pipe. Pump dry job,remove blower hose and drop 2.375" rabbit. Monitor well,breathing. PROD1 PJSM POOH from 10,835' to 9080',wet. Hole not taking displacement, but not flowing (breathing). PROD1 POOH from 9060' to BHA at 374' Turn hole fill pump on at 4277' as hole starts to take some displacement. At 2600' hole starts to take correct displacement. PROD1 Monitor well,static.Lay down BHA from 374', download MWD.CIear and clean floor. RUNPRD Rig up to run 4 1/2", 12.6# liner RUNPRD PJSM with all personnel,make up and check float equipment. RUNPRD Make up 4 1/2", 12.6#, IBT-Mod liner to 3465'. Average make up torque 3800 ft/Ibs. Change out handling equipment. RUNPRD PJSM. Pick up and make up liner hanger,change out handling equipment RUNPRD PJSM. Circulate one liner volume,130 GPM X270 psi. RUNPRD PJSM. Run in hole from 3611' to 10,805,filling every 10 stands, breaking circulation and recording up and down wts. RUNPRD Circulate bottoms up at shoe,164 GPM @ 800 psi. RUNPRD PJSM.Run in hole from 10,805' to 14,167',no trouble. RUNPRD PJSM. Pick up cement head and tag bottom at 14,180'. Break circulation and start reciprocating pipe. Pipe started to rotate to the right when being worke so stopped after second reciprocation 2' off bottom.Did not want to release liner. Stage pump up to 108 GPM C~ 890 psi. Stage pump up top 135 GPM C~ 980 psi. Circulate 2 open hole volumes,lost 93 bbls of mud while circulating. Slow pumps to Printed: 2/12/2007 10:13:15 AM BP EXPLORATION Page 21 of 22 Operations Summary Report Legal Well Name: A -05 Common W ell Name: A -05 Spud Date: 3/14/1972 Event Nam e: REENTE R+COM PLET E Start : 12/25/2006 End: 2/9/2007 Contractor Name: NABOBS ALASK A DRI LLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: ~ ~ Date From - To Hours Task Code NPT Phase Description of Operations 2/5/2007 23:00 - 00:00 1.00 CASE P RUNPRD 65 GPM while batch mixing cement. Up wt,200k,down wt. 130k,mud weight in and out 8.5 ppg. 2/6/2007 '00:00 - 01:30 1.50 CEMT P RUNPRD PJSM with all personnel. Circulate @ 65 GPM,780 psi while batch mixing cement. 01:30 - 03:00 1.50 CEMT P RUNPRD Pump 2 bbls water and pressure test lines to 4000 psi. Pump 27.8 bbls mud push with dye and last 15 bbl with 1 Ib/bbl Cen Net. Pump 89.5 bbl, 15.8 ppg, class G cement, at 6 BPM.(ist 5 bbls Neat, next 30 bbls 2 Ib/bbl Cen Net, remaining 54 bbls Neat) Clear lines through tree with 5 bbls water. Drop plug. Pump 55.4 bbl pert pill. i Pump 67 bbls,cement at shoe,slow to 4 BPM Pump to 101 bbl away, slow to 3 BPM. 105.2 bbl away, latch up plug, return to 4 BPM. 150 bbl away, slow to 2 BPM 157.7 bbl. bump plug and pressure up to 3500 psi to set hanger. '~ Bleed off pressure and check floats,good. ~ Set down 60K to set packer. Release from hanger as per Baker rep. 37 bbl mud lost while cementin 03:00 - 04:00 1.00 CEMT P RUNPRD Circulate out cement at 190 SPM ~ 2700 psi. 17.5 bbl cement to surface. 04:00 - 04:30 0.50 CEMT P RUNPRD Rig down cement head and lay down single. 04:30 - 06:00 1.50 CEMT P RUNPRD PJSM. Displace well to Seawater,l0 BPM ®1890 psi,rotate and reciprocate above liner top. Pump dry job,blow down surface equipment. 06:00 - 07:00 1.00 CEMT P RUNPRD Cut 110' of drilling line,service and inspect drawworks. 07:00 - 07:30 0.50 CEMT P RUNPRD Service top drive. 07:30 - 12:00 4.50 CEMT P RUNPRD POOH from 10,672' to surface,lay down running tool. 12:00 - 13:00 1.00 PERFO P OTHCMP Pre-Job safety meeting,rig up to run perforating guns. 13:00 - 15:00 2.00 PERFO P OTHCMP Wait on cement (1000 psi compressive strength). 15:00 - 16:00 1.00 PERFO P OTHCMP Pressure test 4 1/2" liner to 4000 psi,chart and hold for 30 minutes. 16:00 - 21:00 5.00 PERFO P OTHCMP Pick up and run guns in hole picking up 2 7/8" pipe to 3438'. 21:00 - 21:30 0.50 PERFO P OTHCMP PJSM. Rig down 2 7/8" handing equipment. 21:30 - 00:00 2.50 PERFO P OTHCMP Run in hole with pert guns from 3438' to 9418'. Up wt. 140k,down wt. 115k. 2/7/2007 00:00 - 02:30 2.50 PERFO P OTHCMP Run in hole from 9418'. Tag up at 14,086', pick up to string wt,190k. 02:30 - 03:30 1.00 PERFO P OTHCMP Break circulation then shut in well with 30psi on it. Hold pre-job safety meeting with all personnel. Hold two practice runs pressuring up and bleeding down. Run pressure cycle to fire guns. Hold 30 psi for 2 minutes. Pressure up to 400 psi and hold for 1 minute. Pressure up to 600 psi and hold for 1 minute. Bleed pressure to 30 psi and hold for 2 minutes. Pressure up to 1200 psi and hold for 2 minutes. Bleed pressure off to 0 and open pipe rams. Printed: 2/12/2007 10:13:15 AM s • BP EXPLORATION Page 22 of 22 Operations Summary Report Legal Well Name: A-05 Common Well Name: A-05 Spud Date: 3/14/1972 'Event Name: REENTER+COMPLETE Start: 12/25/2006 End: 2/9/2007 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/9/2007 Rig Name: NABOBS 2ES Rig Number: Date From - To ~ Hours ~ Task ;Code; NPT Phase Description of Operations 12/7/2007 102:30 - 03:30 I 1.001 PERFOBI P I I OTHCMP I Guns fired, initial loss 10 bbl. then well static. Perforations 13,950' to 14,090',2 7/8" powerjet ~ 4 shots per _ 03:30 - 04:00 0.50 PERFO P OTHCMP POOH 2 stands to clear perforations. Pump dry job and blow down surface equipment. 04:00 - 12:00 8.00 PERFO P OTHCMP POOH laying down 4"drill pipe. 12:00 - 12:30 0.50 PERFO P OTHCMP PJSM. Rig up 2 7/8" handling equipment. 12:30 - 17:00 4.50 PERFO P OTHCMP PJSM. Lay down 2 7/8" pipe from 3441' to 167'. 17:00 - 17:30 0.50 PERFO P OTHCMP PJSM. La down uns. All uns fired. 17:30 - 19:00 1.50 BUNCO RUNCMP PJSM. Clear floor of perforating tools, and 2 7/8" handling 19:00 - 20:30 20:30 - 23:00 23:00 - 23:30 23:30 - 00:00 2/8/2007 00:00 - 01:30 01:30 - 02:00 02:00 - 11:30 11:30 - 12:00 12:00 - 15:00 15:00 - 18:00 18:00 - 18:30 18:30 - 22:00 22:00 - 23:00 23:00 - 00:00 2/9/2007 00:00 - 02:00 02:00 - 02:30 equipment. 1.50 BUNCO RUNCMP Run in hole with remaining pipe out of derrick. 2.50 BUNCO P RUNCMP Lay down 4 " dril pipe. 0.50 BUNCO RUNCMP PJSM. Pull wear ring. 0.50 BUNCO P RUNCMP PJSM. Pick up tools for running tubing from beaver slide. 1.50 BUNCO RUNCMP Rig up to run 4 1/2",12.6#, TC11, tubing. Hang double stack tongs. 0.50 BUNCO RUNCMP Run 4 1/2",12.6#, TC11 tubing. Torque turn connections and Baker Lok below S3 packer.Pre-job safety meeting with all personnel. Make up packer assembly. 9.50 BUNCO RUNCMP Make up 4 1/2", 12.6#,.L-80,TC11 tubing to 8546'. Make up torque 3850 fUlbs. 0.50 BUNCO RUNCMP Safety meeting with Nabors, BP and RLG representatives. 3.00 BUNCO RUNCMP PJSM. Run in hole with 4 1/2", 12.6#, L-80, TCII tubing from 8546'. 3.00 BUNCO RUNCMP Tag up and space out with 5 pups joints,9.5', 9.81', 5.78', 2.0', 7.7T. Land tubing and run in lock down screws with wireline entry guide set at 10,685.43'. Total of 253 jts 4 1/2" tubing run. 0.50 BUNCO RUNCMP PJSM. Rig up to reverse circulate,corrosion inhibitor and freeze ~ protection. 3.50 BUNCO RUNCMP PJSM. Reverse circulate 165 bbls seawater,160 bbls inhibited seawater at 126 GPM ~ 220 psi,followed by 80 bbls diesel freeze protect. Diesel pumped down 7 x 4 1/2" annulus. 1.00 BUNCO RUNCMP Close blind rams and let well U-tube diesel from IA to tubing. 1.00 BUNCO RUNCMP Drop ball & rod and wait for 25 minutes to seat._Pressure up tubin to 4000 si. Hold and chart for 30 minutes. 2.00 BUNCO RUNCMP Test tubing to 4000 psi.,hold for 30 minutes and chart. 0.50 (BOPSUFI P 02:30 - 04:30 2.00 BOPSU P 04:30 - 08:30 4.00 WHSUR P 08:30 - 09:30 1.00 WHSUR P 09:30 - 10:30 1.00 WHSUR P i est a iiz° x i- annulus to 4uuu si witn ume rtea Un Services. Hold for 30 minutes and chart. Bleed off pressure and suck out diesel from BOPE. RUNCMP Dry rod TWC. Test from above to 1000 psi. Blow down all surface lines. RUNCMP Nipple down BOPE. RUNCMP Nipple up tree and adaptor. Test to 5000 psi - OK. RUNCMP RU lubricator & pull TWC. RD lubricator. Install BPV. RUNCMP PJSM. Remove secondary annulus valve & secure well. Install needle valves and gauges. Release rig at 10:30 hrs on 02/09/2007. Printed: 2/12/2007 10:13:15 AM Halliburton Company Survey Report Company: BP Amoco Date:. 3/7!2007 Time. 11:58;15 Page: 1 Field:. Prudhoe Bay Co-ordinate(IVE) Reference: Well: A-05, True North Site: PB A Pad Vertical (TVD) Reference: A-05A: 74.7 Well: A-05 Sectioa(VS) Reference: Well {O.OON,t).OOE,1 80.OOAzi) Wellpath: A-05A Survey Calculation Method: Mi nimum Curvature Db: Oracle Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Pla ne Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: A-05 Slot Name: A-05 Well Position: +N/-S 2399.91 ft Northing: 5948551.20 ft Latitude: 70 15 58.812 N +E/-W 1000.78 ft Easting : 654461.00 ft Longitude: 148 45 3.647 W Position Uncertainty: 0.00 ft Wellpath: A-05A Drilled From: A-05 500292011601 Tie-on Depth: 8183.78 ft Current Datum: A-05A: Height 74.67 ft Above System Datum: Mean Sea Level Magnetic Data: 1/13/2007 Declination: 24.04 deg Field Strength: 57650 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28 .50 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 3/7/2007 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 108.78 8183.78 A-05 GYRODATA (108.78-8640.48) GYD-CT-CMS Gyrodata cont.casing m/s 8206.00 14107.88 A-05A IIFR+MS+Sag (8206.00-141 MWD+IFR+MS MWD +IFR + Multi Station Survey MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 28.50 0.00 0.00 28.50 -46.17 0.00 0.00 5948551.20 654461.00 TIE LINE 108.78 0.14 205.82 108.78 34.11 -0.09 -0.04 5948551.11 654460.96 GYD-CT-CMS 208.78 0.32 177.98 208.78 134.11 -0.48 -0.09 5948550.72 654460.92 GYD-CT-CMS 308.78 0.15 227.92 308.78 234.11 -0.84 -0.17 5948550.35 654460.84 GYD-CT-CMS 408.78 0.13 236.73 408.78 334.11 -0.99 -0.37 5948550.20 654460.66 GYD-CT-CMS 508.78 0.35 207.64 508.78 434.11 -1.33 -0.60 5948549.86 654460.43 GYD-CT-CMS 608.78 0.43 245.87 608.77 534.10 -1.75 -1.09 5948549.43 654459.95 GYD-CT-CMS 708.78 0.30 268.67 708.77 634.10 -1.91 -1.69 5948549.26 654459.35 GYD-CT-CMS 808.78 0.40 269.87 808.77 734.10 -1.92 -2.30 5948549.24 654458.74 GYD-CT-CMS 908.78 0.40 272.97 908.77 834.10 -1.90 -3.00 5948549.24 654458.04 GYD-CT-CMS 1008.78 0.42 277.78 1008.77 934.10 -1.83 -3.71 5948549.29 654457.33 GYD-CT-CMS 1108.78 0.44 290.70 1108.76 1034.09 -1.65 -4.43 5948549.46 654456.60 GYD-CT-CMS 1208.78 0.36 288.14 1208.76 1134.09 -1.41 -5.09 5948549.68 654455.94 GYD-CT-CMS 1308.78 0.51 305.77 1308.76 1234.09 -1.06 -5.75 5948550.03 654455.27 GYD-CT-CMS 1408.78 0.53 314.40 1408.75 1334.08 -0.47 -6.44 5948550.60 654454.57 GYD-CT-CMS 1508.78 0.52 327.74 1508.75 1434.08 0.24 -7.01 5948551.29 654453.98 GYD-CT-CMS 1608.78 0.57 343.60 1608.75 1534.08 1.10 -7.40 5948552.14 654453.58 GYD-CT-CMS 1708.78 0.72 1.11 1708.74 1634.07 2.20 -7.53 5948553.25 654453.43 GYD-CT-CMS 1808.78 0.78 18.17 1808.73 1734.06 3.48 -7.30 5948554.53 654453.63 GYD-CT-CMS 1908.78 0.80 21.86 1908.72 1834.05 4.77 -6.83 5948555.83 654454.08 GYD-CT-CMS 2008.78 0.69 31.26 2008.71 1934.04 5.93 -6.26 5948557.00 654454.62 GYD-CT-CMS 2108.78 0.45 30.94 2108.71 2034.04 6.79 -5.74 5948557.87 654455.12 GYD-CT-CMS 2208.78 0.41 23.04 2208.70 2134.03 7.45 -5.40 5948558.54 654455.45 GYD-CT-CMS 2308.78 1.28 357.35 2308.69 2234.02 8.90 -5.31 5948559.99 654455.51 GYD-CT-CMS 2408.78 1.58 357.53 2408.66 2333.99 11.39 -5.42 5948562.48 654455.35 GYD-CT-CMS 2508.78 1.12 346.27 2508.63 2433.96 13.72 -5.71 5948564.80 654455.01 GYD-CT-CMS 2608.78 4.09 239.02 2608.55 2533.88 12.83 -9.01 5948563.84 654451.73 GYD-CT-CMS 2708.78 8.46 229.71 2707.93 2633.26 6.23 -17.68 5948557.07 654443.20 GYD-CT-CMS 2808.78 11.11 257.24 2806.52 2731.85 -0.66 -32.70 5948549.87 654428.33 GYD-CT-CMS LJ Halliburton Company Survey Report Company: BP Amoco Date: 3/7/2007 Time: 11:58:15 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well; A-05, True Notth Site: PB A Pad Vertical (TVD) Reference: A- 05A: 74.7 Well: A-05 Section (VS)Reference: Well (Q.OON,O.OOE,180.OOAzi) Wellpatb A-05A Survey Calculation Method: M inimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N!S FJW MapN MapE TooC ft deg deg ft ft ft ft ft ft 2908.78 13.50 261.19 2904.22 2829.55 -4.57 -53.63 5948545.53 654407.48 GYD-CT-CMS 2933.78 13.84 261.21 2928.51 2853.84 -5.48 -59.47 5948544.51 654401.66 GYD-CT-CMS 2958.78 14.17 260.99 2952.76 2878.09 -6.41 -65.45 5948543.45 654395.70 GYD-CT-CMS 2983.78 14.48 260.99 2976.99 2902.32 -7.38 -71.56 5948542.35 654389.62 GYD-CT-CMS 3008.78 14.85 260.95 3001.17 2926.50 -8.37 -77.81 5948541.23 654383.39 GYD-CT-CMS 3033.78 15.45 260.93 3025.30 2950.63 -9.40 -84.26 5948540.07 654376.96 GYD-CT-CMS 3058.78 15.74 261.05 3049.38 2974.71 -10.46 -90.90 5948538.88 654370.34 GYD-CT-CMS 3083.78 16.19 261.23 3073.42 2998.75 -11.51 -97.69 5948537.68 654363.57 GYD-CT-CMS 3108.78 16.61 261.49 3097.40 3022.73 -12.57 -104.67 5948536.48 654356.62 GYD-CT-CMS 3133.78 17.00 261.85 3121.33 3046.66 -13.62 -111.82 5948535.29 654349.49 GYD-CT-CMS 3158.78 17.37 262.22 3145.22 3070.55 -14.64 -119.14 5948534.12 654342.20 GYD-CT-CMS 3183.78 17.62 262.45 3169.06 3094.39 -15.65 -126.58 5948532.96 654334.77 GYD-CT-CMS 3208.78 17.94 262.79 3192.87 3118.20 -16.63 -134.16 5948531.82 654327.22 GYD-CT-CMS 3233.78 18.12 262.78 3216.64 3141.97 -17.60 -141.83 5948530.70 654319.57 GYD-CT-CMS 3258.78 18.30 262.87 3240.39 3165.72 -18.57 -149.58 5948529.56 654311.84 GYD-CT-CMS 3283.78 18.69 263.11 3264.10 3189.43 -19.54 -157.45 5948528.43 654303.99 GYD-CT-CMS 3308.78 19.05 263.28 3287.75 3213.08 -20.50 -165.48 5948527.31 654295.98 GYD-CT-CMS 3333.78 19.41 263.54 3311.36 3236.69 -21.45 -173.66 5948526.20 654287.83 GYD-CT-CMS 3358.78 19.69 263.74 3334.92 3260.25 -22.37 -181.98 5948525.10 654279.53 GYD-CT-CMS 3383.78 20.12 264.01 3358.42 3283.75 -23.28 -190.44 5948524.02 654271.09 GYD-CT-CMS 3408.78 20.68 264.24 3381.85 3307.18 -24.17 -199.11 5948522.95 654262.44 GYD-CT-CMS 3433.78 20.94 264.38 3405.22 3330.55 -25.05 -207.95 5948521.89 654253.63 GYD-CT-CMS 3458.78 21.29 264.62 3428.54 3353.87 -25.92 -216.91 5948520.84 654244.68 GYD-CT-CMS 3483.78 21.57 264.75 3451.82 3377.15 -26.76 -226.01 5948519.81 654235.61 GYD-CT-CMS 3508.78 21.90 264.94 3475.04 3400.37 -27.59 -235.23 5948518.79 654226.41 GYD-CT-CMS 3533.78 22.27 265.14 3498.20 3423.53 -28.41 -244.59 5948517.78 654217.06 GYD-CT-CMS 3558.78 22.77 265.32 3521.30 3446.63 -29.20 -254.13 5948516.79 654207.54 GYD-CT-CMS 3583.78 23.21 265.70 3544.31 3469.64 -29.97 -263.87 5948515.83 654197.82 GYD-CT-CMS 3608.78 23.62 265.95 3567.25 3492.58 -30.69 -273.78 5948514.90 654187.93 GYD-CT-CMS 3633.78 24.06 266.09 3590.12 3515.45 -31.39 -283.86 5948514.00 654177.87 GYD-CT-CMS 3658.78 24.51 266.22 3612.91 3538.24 -32.08 -294.11 5948513.10 654167.63 GYD-CT-CMS 3683.78 24.92 266.38 3635.62 3560.95 -32.75 -304.55 5948512.21 654157.21 GYD-CT-CMS 3708.78 25.36 266.46 3658.25 3583.58 -33.42 -315.15 5948511.33 654146.63 GYD-CT-CMS 3733.78 26.00 266.79 3680.78 3606.11 -34.05 -325.96 5948510.47 654135.83 GYD-CT-CMS 3758.78 26.57 266.90 3703.20 3628.53 -34.66 -337.01 5948509.63 654124.79 GYD-CT-CMS 3783.78 27.28 266.90 3725.49 3650.82 -35.28 -348.32 5948508.79 654113.50 GYD-CT-CMS 3808.78 27.80 266.99 3747.65 3672.98 -35.89 -359.86 5948507.94 654101.98 GYD-CT-CMS 3833.78 28.32 267.04 3769.71 3695.04 -36.50 -371.60 5948507.08 654090.25 GYD-CT-CMS 3858.78 28.82 267.08 3791.67 3717.00 -37.12 -383.54 5948506.22 654078.33 GYD-CT-CMS 3883.78 29.30 267.14 3813.52 3738.85 -37.73 -395.67 5948505.36 654066.21 GYD-CT-CMS 3908.78 29.87 267.29 3835.26 3760.59 -38.33 -408.00 5948504.51 654053.90 GYD-CT-CMS 3933.78 30.16 267.33 3856.91 3782.24 -38.92 -420.49 5948503.67 654041.43 GYD-CT-CMS 3958.78 30.57 267.37 3878.48 3803.81 -39.50 -433.12 5948502.82 654028.82 GYD-CT-CMS 3983.78 31.05 267.40 3899.95 3825.28 -40.08 -445.91 5948501.98 654016.04 GYD-CT-CMS 4008.78 31.52 267.49 3921.32 3846.65 -40.66 -458.88 5948501.13 654003.09 GYD-CT-CMS 4033.78 32.17 267.67 3942.55 3867.88 -41.22 -472.06 5948500.31 653989.92 GYD-CT-CMS 4058.78 32.57 267.69 3963.67 3889.00 -41.76 -485.43 5948499.49 653976.56 GYD-CT-CMS 4083.78 33.10 267.95 3984.68 3910.01 -42.28 -498.98 5948498.70 653963.03 GYD-CT-CMS 4108.78 33.77 268.27 4005.54 3930.87 -42.73 -512.74 5948497.96 653949.28 GYD-CT-CMS 4133.78 34.26 268.40 4026.26 3951.59 -43.14 -526.72 5948497.27 653935.31 GYD-CT-CMS 4158.78 34.80 268.64 4046.86 3972.19 -43.50 -540.89 5948496.61 653921.16 GYD-CT-CMS 4183.78 35.33 268.83 4067.32 3992.65 -43.82 -555.25 5948496.00 653906.81 GYD-CT-CMS i • Halliburton Company Survey Report Company: BP AmoCO Date: 3/7/2007 Time: 11:58:15 Page:. 3 Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: A-05, True North Site: PB A Pad Vertical (TVD) Reference: A-05A: 74.7 Well: A-05 Section (VS) Reference: Well (O.OON,O,OOE,1&O.OOAzi) Wellpat6: A-05A Survey Calculation Method: Minimum. Curvature Db: OraCle Survey MD Inc! Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 4208.78 36.05 269.07 4087.62 4012.95 -44.09 -569.83 5948495.43 653892.24 GYD-CT-CMS 4233.78 36.70 269.35 4107.75 4033.08 -44.29 -584.65 5948494.93 653877.42 GYD-CT-CMS 4258.78 37.17 269.52 4127.73 4053.06 -44.44 -599.68 5948494.47 653862.41 GYD-CT-CMS 4283.78 37.96 269.90 4147.55 4072.88 -44.52 -614.92 5948494.08 653847.17 GYD-CT-CMS 4308.78 38.42 270.24 4167.20 4092.53 -44.50 -630.37 5948493.78 653831.72 GYD-CT-CMS 4333.78 38.91 270.67 4186.72 4112.05 -44.37 -645.99 5948493.59 653816.10 GYD-CT-CMS 4358.78 39.23 270.82 4206.13 4131.46 -44.17 -661.75 5948493.47 653800.35 GYD-CT-CMS 4383.78 39.54 270.92 4225.45 4150.78 -43.93 -677.61 5948493.38 653784.48 GYD-CT-CMS 4408.78 39.71 271.22 4244.71 4170.04 -43.63 -693.55 5948493.35 653768.54 GYD-CT-CMS 4433.78 39.99 271.37 4263.90 4189.23 -43.27 -709.57 5948493.39 653752.52 GYD-CT-CMS 4458.78 40.28 271.51 4283.01 4208.34 -42.86 -725.68 5948493.46 653736.41 GYD-CT-CMS 4483.78 40.76 272.07 4302.02 4227.35 -42.35 -741.91 5948493.64 653720.17 GYD-CT-CMS 4508.78 41.16 272.20 4320.90 4246.23 -41.74 -758.29 5948493.91 653703.78 GYD-CT-CMS 4533.78 41.72 271.85 4339.64 4264.97 -41.16 -774.82 5948494.16 653687.24 GYD-CT-CMS 4558.78 42.11 270.68 4358.24 4283.57 -40.79 -791.52 5948494.18 653670.54 GYD-CT-CMS 4583.78 42.21 268.79 4376.78 4302.11 -40.87 -808.30 5948493.76 653653.77 GYD-CT-CMS 4608.78 41.83 266.37 4395.35 4320.68 -41.57 -825.01 5948492.71 653637.07 GYD-CT-CMS 4633.78 41.48 264.55 4414.03 4339.36 -42.89 -841.58 5948491.06 653620.54 GYD-CT-CMS 4658.78 40.77 263.10 4432.86 4358.19 -44.66 -857.92 5948488.96 653604.24 GYD-CT-CMS 4683.78 40.86 262.67 4451.78 4377.11 -46.68 -874.14 5948486.60 653588.07 GYD-CT-CMS 4708.78 41.09 262.47 4470.66 4395.99 -48.80 -890.39 5948484.15 653571.86 GYD-CT-CMS 4733.78 41.28 261.60 4489.47 4414.80 -51.08 -906.70 5948481.53 653555.61 GYD-CT-CMS 4758.78 41.10 259.81 4508.29 4433.62 -53.74 -922.94 5948478.54 653539.42 GYD-CT-CMS 4783.78 40.18 257.25 4527.26 4452.59 -56.97 -938.90 5948474.98 653523.54 GYD-CT-CMS 4808.78 39.61 255.55 4546.44 4471.77 -60.74 -954.48 5948470.89 653508.03 GYD-CT-CMS 4833.78 38.89 253.55 4565.80 4491.13 -64.95 -969.73 5948466.37 653492.88 GYD-CT-CMS 4858.78 38.23 250.77 4585.35 4510.68 -69.72 -984.56 5948461.30 653478.15 GYD-CT-CMS 4883.78 37.88 248.44 4605.04 4530.37 -75.09 -999.00 5948455.63 653463.82 GYD-CT-CMS 4908.78 37.59 246.34 4624.81 4550.14 -80.97 -1013.12 5948449.46 653449.82 GYD-CT-CMS 4933.78 37.90 245,30 4644.58 4569.91 -87.24 -1027.08 5948442.91 653436.00 GYD-CT-CMS 4958.78 38.35 244,85 4664.24 4589.57 -93.75 -1041.08 5948436.12 653422.14 GYD-CT-CMS 4983.78 38.83 244,56 4683.78 4609.11 -100.41 -1055.18 5948429.17 653408.18 GYD-CT-CMS 5008.78 39.30 244,53 4703.19 4628.52 -107.18 -1069.40 5948422.11 653394.10 GYD-CT-CMS 5033.78 39.83 244.58 4722.47 4647.80 -114.02 -1083.7$ 5948414.97 653379.86 GYD-CT-CMS 5058.78 40.81 244,64 4741.53 4666.86 -120.96 -1098.40 5948407.74 653365.40 GYD-CT-CMS 5083.78 41.57 244.80 4760.34 4685.67 -127.99 -1113.28 5948400.41 653350.66 GYD-CT-CMS 5108.78 42.36 244.91 4778.93 4704.26 -135.09 -1128.42 5948393.00 653335.67 GYD-CT-CMS 5133.78 42.90 244.97 4797.32 4722.65 -142.26 -1143.76 5948385.51 653320.49 GYD-CT-CMS 5158.78 43.39 245.00 4815.56 4740.89 -149.49 -1159.25 5948377.97 653305.15 GYD-CT-CMS 5183.78 43.87 245.15 4833.66 4758.99 -156.76 -1174.89 5948370.38 653289.66 GYD-CT-CMS 5208.78 44.37 245.23 4851.61 4776.94 -164.06 -1190.69 5948362.75 653274.01 GYD-CT-CMS 5233.78 44.87 245.30 4869.40 4794.73 -171.41 -1206.64 5948355.08 653258.22 GYD-CT-CMS 5258.78 45.51 245.37 4887.02 4812.35 -178.81 -1222.76 5948347.35 653242.26 GYD-CT-CMS 5283.78 46.22 245.38 4904.43 4829.76 -186.29 -1239.07 5948339.54 653226.11 GYD-CT-CMS 5308.78 47.12 245.42 4921.58 4846.91 -193.86 -1255.60 5948331.63 653209.73 GYD-CT-CMS 5333.78 47.70 245.44 4938.50 4863.83 -201.51 -1272.34 5948323.64 653193.16 GYD-CT-CMS 5358.78 48.16 245.48 4955.25 4880.58 -209.22 -1289.22 5948315.59 653176.44 GYD-CT-CMS 5383.78 48.47 245.69 4971.88 4897.21 -216.94 -1306.22 5948307.52 653159.60 GYD-CT-CMS 5408.78 48.70 245.85 4988.42 4913.75 -224.63 -1323.32 5948299.48 653142.66 GYD-CT-CMS 5433.78 48.64 246.20 5004.93 4930.26 -232.26 -1340.47 5948291.50 653125.67 GYD-CT-CMS 5458.78 48.93 246.29 5021.40 4946.73 -239.84 -1357.68 5948283.58 653108.62 GYD-CT-CMS 5483.78 49.02 246.38 5037.81 4963.14 -247.41 -1374.96 5948275.65 653091.51 GYD-CT-CMS 5508.78 49.11 246.46 5054.19 4979.52 -254.96 -1392.27 5948267.75 653074.36 GYD-CT-CMS i Halliburton Company Survey Report Company: BP Amoco Date: 3/7/2007 Time: 11:58:15. Page: 4 Field: Prudhoe Bay Co-oedinate(NE) Reference: Well: A-05, True North .Site: PB A Pad Vertical (TVD) Reference:. A-05A: 74.7 Well: A-05 Section (VS) Reference: Well (O.OON,O.OOE ,180.OOAzi) Wellpath: A-05A Survey Calculation Method: Mi nimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE TooF ti deg deg tt ft ft ft ft fit 5533.78 49.14 246.59 5070.55 4995.88 -262.49 -1409.61 5948259.86 653057.18 GYD-CT-CMS 5558.78 49.02 246.70 5086.92 5012.25 -269.98 -1426.95 5948252.02 653039.99 GYD-CT-CMS 5583.78 49.26 246.84 5103.28 5028.61 -277.44 -1444.33 5948244.21 653022.78 GYD-CT-CMS 5608.78 49.24 247.01 5119.60 5044.93 -284.86 -1461.75 5948236.43 653005.51 GYD-CT-CMS 5633.78 49.27 247.20 5135.91 5061.24 -292.23 -1479.20 5948228.71 652988.22 GYD-CT-CMS 5658.78 49.47 247.31 5152.19 5077.52 -299.56 -1496.70 5948221.01 652970.87 GYD-CT-CMS 5683.78 49.62 247.45 5168.41 5093.74 -306.88 -1514.25 5948213.34 652953.47 GYD-CT-CMS 5708.78 49.84 247.49 5184.57 5109.90 -314.19 -1531.87 5948205.67 652936.01 GYD-CT-CMS 5733.78 49.94 247.59 5200.68 5126.01 -321.50 -1549.54 5948198.00 652918.49 GYD-CT-CMS 5758.78 49.93 247.82 5216.77 5142.10 -328.75 -1567.25 5948190.39 652900.94 GYD-CT-CMS 5783.78 49.86 247.99 5232.88 5158.21 -335.95 -1584.96 5948182.83 652883.38 GYD-CT-CMS 5808.78 49.81 248.18 5249.00 5174.33 -343.08 -1602.69 5948175.34 652865.80 GYD-CT-CMS 5833.78 49.88 248.30 5265.12 5190.45 -350.16 -1620.43 5948167.89 652848.21 GYD-CT-CMS 5858.78 49.92 248.46 5281.23 5206.56 -357.21 -1638.21 5948160.48 652830.58 GYD-CT-CMS 5883.78 49.72 248.71 5297.36 5222.69 -364.18 -1655.99 5948153.15 652812.95 GYD-CT-CMS 5908.78 49.61 248.94 5313.54 5238.87 -371.06 -1673.76 5948145.90 652795.32 GYD-CT-CMS 5933.78 49.53 249.06 5329.75 5255.08 -377.88 -1691.53 5948138.72 652777.70 GYD-CT-CMS 5958.78 49.41 249.13 5346.00 5271.33 -384.66 -1709.28 5948131.58 652760.10 GYD-CT-CMS 5983.78 49.34 249.23 5362.27 5287.60 -391.41 -1727.02 5948124.47 652742.50 GYD-CT-CMS 6008.78 49.31 249.18 5378.57 5303.90 -398.14 -1744.74 5948117.38 652724.92 GYD-CT-CMS 6033.78 49.40 249.19 5394.85 5320.18 -404.88 -1762.47 5948110.27 652707.33 GYD-CT-CMS 6058.78 49.18 249.20 5411.16 5336.49 -411.61 -1780.19 5948103.18 652689.76 GYD-CT-CMS 6083.78 49.13 249.22 5427.51 5352.84 -418.32 -1797.87 5948096.11 652672.22 GYD-CT-CMS 6108.78 49.08 249.33 5443.88 5369.21 -425.01 -1815.54 5948089.06 652654.69 GYD-CT-CMS 6133.78 49.21 249.35 5460.23 5385.56 -431.68 -1833.24 5948082.03 652637.14 GYD-CT-CMS 6158.78 49.13 249.50 5476.58 5401.91 -438.33 -1850.95 5948075.02 652619.57 GYD-CT-CMS 6183.78 49.03 249.60 5492.95 5418.28 -444.93 -1868.65 5948068.06 652602.01 GYD-CT-CMS 6208.78 48.92 249.70 5509.36 5434.69 -451.49 -1886.33 5948061.14 652584.47 GYD-CT-CMS 6233.78 48.84 249.85 5525.80 5451.13 -458.00 -1904.00 5948054.27 652566.93 GYD-CT-CMS 6258.78 48.63 250.01 5542.29 5467.62 -464.45 -1921.65 5948047.46 652549.42 GYD-CT-CMS 6283.78 48.54 250.24 5558.83 5484.16 -470.82 -1939.28 5948040.72 652531.93 GYD-CT-CMS 6308.78 48.47 250.41 5575.39 5500.72 -477.13 -1956.92 5948034.06 652514.43 GYD-CT-CMS 6333.78 48.48 250.47 5591.96 5517.29 -483.39 -1974.55 5948027.43 652496.93 GYD-CT-CMS 6358.78 48.72 250.51 5608.50 5533.83 -489.66 -1992.23 5948020.81 652479.38 GYD-CT-CMS 6383.78 48.50 250.54 5625.03 5550.36 -495.91 -2009.91 5948014.19 652461.83 GYD-CT-CMS 6408.78 48.32 250.58 5641.62 5566.95 -502.13 -2027.54 5948007.61 652444.33 GYD-CT-CMS 6433.78 48.13 250.65 5658.28 5583.61 -508.32 -2045.13 5948001.06 652426.88 GYD-CT-CMS 6458.78 47.75 250.75 5675.02 5600.35 -514.46 -2062.65 5947994.57 652409.49 GYD-CT-CMS 6483.78 47.63 250.83 5691.85 5617.18 -520.54 -2080.11 5947988.13 652392.16 GYD-CT-CMS 6508.78 47.39 250.85 5708.74 5634.07 -526.59 -2097.52 5947981.73 652374.88 GYD-CT-CMS 6533.78 47.50 250.95 5725.65 5650.98 -532.62 -2114.92 5947975.34 652357.61 GYD-CT-CMS 6558.78 47.61 251.02 5742.52 5667.85 -538.63 -2132.36 5947968.98 652340.29 GYD-CT-CMS 6583.78 48.01 251.13 5759.31 5684.64 -544.63 -2149.89 5947962.61 652322.90 GYD-CT-CMS 6608.78 48.48 251.31 5775.96 5701.29 -550.64 -2167.54 5947956.25 652305.37 GYD-CT-CMS 6633.78 48.89 251.55 5792.46 5717.79 -556.62 -2185.34 5947949.90 652287.70 GYD-CT-CMS 6658.78 49.57 251.67 5808.79 5734.12 -562.59 -2203.31 5947943.56 652269.86 GYD-CT-CMS 6683.78 50.08 251.87 5824.92 5750.25 -568.57 -2221.45 5947937.22 652251.84 GYD-CT-CMS 6708.78 50.57 252.05 5840.88 5766.21 -574.52 -2239.75 5947930.89 652233.67 GYD-CT-CMS 6733.78 51.08 252.21 5856.67 5782.00 -580.47 -2258.19 5947924.56 652215.36 GYD-CT-CMS 6758.78 51.54 252.43 5872.30 5797.63 -586.40 -2276.78 5947918.26 652196.89 GYD-CT-CMS 6783.78 52.08 252.65 5887.75 5813.08 -592.29 -2295.53 5947911.98 652178.27 GYD-CT-CMS 6808.78 52.23 252.95 5903.09 5828.42 -598.13 -2314.39 5947905.76 652159.54 GYD-CT-CMS Halliburton Company Survey Report Company: BP Amoco Date: 3/7/2007 Timee 11:58;15 Pagep 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIGA-05, True North Site: PB A Pad Vertical (TVD) Refe rence: A-05A: 74.7 Well: A-05 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: A-05A Survey Calculation Method: Mi nimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S FJW MapN MapE Tool ft deg deg ft ft ft ft ft ft 6833.78 52.81 253.12 5918.30 5843.63 -603.92 -2333.36 5947899.58 652140.69 GYD-CT-CMS 6858.78 53.50 253.26 5933.30 5858.63 -609.71 -2352.51 5947893.40 652121.66 GYD-CT-CMS 6883.78 53.98 253.55 5948.08 5873.41 -615.46 -2371.83 5947887.25 652102.47 GYD-CT-CMS 6908.78 54.48 253.67 5962.69 5888.02 -621.19 -2391.29 5947881.13 652083.13 GYD-CT-CMS 6933.78 54.55 253.79 5977.21 5902.54 -626.89 -2410.83 5947875.03 652063.71 GYD-CT-CMS 6958.78 54.67 253.79 5991.69 5917.02 -632.58 -2430.41 5947868.94 652044.26 GYD-CT-CMS 6983.78 54.67 253.76 6006.14 5931.47 -638.28 -2449.99 5947862.84 652024.80 GYD-CT-CMS 7008.78 54.40 253.77 6020.65 5945.98 -643.97 -2469.54 5947856.75 652005.37 GYD-CT-CMS 7033.78 54.55 253.78 6035.17 5960.50 -649.66 -2489.07 5947850.66 651985.96 GYD-CT-CMS 7058.78 54.36 253.74 6049.71 5975.04 -655.34 -2508.60 5947844.57 651966.55 GYD-CT-CMS 7083.78 54.22 253.74 6064.30 5989.63 -661.03 -2528.09 5947838.49 651947.19 GYD-CT-CMS 7108.78 54.17 253.72 6078.93 6004.26 -666.71 -2547.56 5947832.41 651927.85 GYD-CT-CMS 7133.78 54.08 253.70 6093.58 6018.91 -672.39 -2567.00 5947826.33 651908.52 GYD-CT-CMS 7158.78 54.07 253.68 6108.24 6033.57 -678.08 -2586.43 5947820.25 651889.22 GYD-CT-CMS 7183.78 53.81 253.61 6122.96 6048.29 -683.77 -2605.82 5947814.16 651869.95 GYD-CT-CMS 7208.78 53.42 253.62 6137.79 6063.12 -689.44 -2625.13 5947808.09 651850.76 GYD-CT-CMS 7233.78 53.56 253.62 6152.66 6077.99 -695.11 -2644.41 5947802.03 651831.60 GYD-CT-CMS 7258.78 53.35 253.69 6167.55 6092.88 -700.76 -2663.68 5947795.99 651812.45 GYD-CT-CMS 7283.78 53.28 253.60 6182.49 6107.82 -706.41 -2682.92 5947789.95 651793.33 GYD-CT-CMS 7308.78 53.09 253.58 6197.47 6122.80 -712.06 -2702.12 5947783.90 651774.26 GYD-CT-CMS 7333.78 52.79 253.54 6212.53 6137.86 -717.71 -2721.25 5947777.86 651755.24 GYD-CT-CMS 7358.78 52.75 253.52 6227.66 6152.99 -723.35 -2740.34 5947771.83 651736.28 GYD-CT-CMS 7383.78 52.57 253.50 6242.82 6168.15 -728.99 -2759.40 5947765.80 651717.34 GYD-CT-CMS 7408.78 52.47 253.53 6258.03 6183.36 -734.62 -2778.42 5947759.78 651698.44 GYD-CT-CMS 7433.78 52.16 253.47 6273.32 6198.65 -740.24 -2797.39 5947753.77 651679.59 GYD-CT-CMS 7458.78 52.04 253.45 6288.67 6214.00 -745.86 -2816.30 5947747.77 651660.80 GYD-CT-CMS 7483.78 52,01 253.49 6304.06 6229.39 -751.47 -2835.20 5947741.78 651642.02 GYD-CT-CMS 7508.78 51.79 253.44 6319.48 6244.81 -757.06 -2854.06 5947735.79 651623.28 GYD-CT-CMS 7533.78 51.68 253.43 6334.97 6260.30 -762.66 -2872.87 5947729.81 651604.59 GYD-CT-CMS 7558.78 51.57 253.43 6350.49 6275.82 -768.25 -2891.66 5947723.84 651585.93 GYD-CT-CMS 7583.78 51.29 253.40 6366.07 6291.40 -773.83 -2910.39 5947717.88 651567.31 GYD-CT-CMS 7608.78 51.27 253.45 6381.71 6307.04. -779.39 -2929.08 5947711.93 651548.74 GYD-CT-CMS 7633.78 51.10 253.44 6397.38 6322.71 -784.94 -2947.76 5947706.00 651530.18 GYD-CT-CMS 7658.78 50.97 253.47 6413.10 6338.43 -790.48 -2966.39 5947700.08 651511.67 GYD-CT-CMS 7683.78 50.77 253.51 6428.88 6354.21 -795.99 -2984.98 5947694.19 651493.19 GYD-CT-CMS 7708.78 50.70 253.47 6444.70 6370.03 -801.49 -3003.54 5947688.31 651474.76 GYD-CT-CMS 7733.78 50.65 253.54 6460.54 6385.87 -806.98 -3022.08 5947682.44 651456.33 GYD-CT-CMS 7758.78 50.52 253.57 6476.42 6401.75 -812.45 -3040.61 5947676.60 651437.92 GYD-CT-CMS 7783.78 50.27 253.61 6492.35 6417.68 -817.89 -3059.08 5947670.78 651419.56 GYD-CT-CMS 7808.78 50.12 253.64 6508.36 6433.69 -823.31 -3077.51 5947664.99 651401.25 GYD-CT-CMS 7833.78 49.96 253.61 6524.42 6449.75 -828.71 -3095.90 5947659.21 651382.98 GYD-CT-CMS 7858.78 49.76 253.53 6540.53 6465.86 -834.11 -3114.23 5947653.43 651364.77 GYD-CT-CMS 7883.78 49.66 253.56 6556.70 6482.03 -839.52 -3132.52 5947647.65 651346.60 GYD-CT-CMS 7908.78 49.38 253.57 6572.93 6498.26 -844.90 -3150.75 5947641.90 651328.47 GYD-CT-CMS 7933.78 49.32 253.56 6589.21 6514.54 -850.26 -3168.95 5947636.16 651310.40 GYD-CT-CMS 7958.78 49.01 253.65 6605.56 6530.89 -855.60 -3187.09 5947630.45 651292.36 GYD-CT-CMS 7983.78 48.95 253.65 6621.97 6547.30 -860.91 -3205.19 5947624.77 651274.38 GYD-CT-CMS 8008.78 48.75 253.54 6638.42 6563.75 -866.23 -3223.25 5947619.09 651256.44 GYD-CT-CMS 8033.78 48.59 253.59 6654.93 6580.26 -871.54 -3241.26 5947613.41 651238.54 GYD-CT-CMS 8058.78 48.60 253.56 6671.46 6596.79 -876.84 -3259.24 5947607.74 651220.67 GYD-CT-CMS 8083.78 48.33 253.58 6688.04 6613.37 -882.13 -3277.19 5947602.08 651202.84 GYD-CT-CMS 8108.78 48.27 253.63 6704.67 6630.00 -887.40 -3295.10 5947596.44 651185.04 GYD-CT-CMS 8133.78 48.13 253.53 6721.33 6646.66 -892.67 -3312.98 5947590.81 651167.28 GYD-CT-CMS -.J Halliburton Company Survey Report • Company: BP Amoco Date: 3/7/2007 Time: 11:58:15 Page: 6 Field: Prudhoe Bay Co-ord inate(NE) Reference: Well: A-05, True North Site: PB A Pad Vertical (TVD) Reference: A-05A: 74.7 Well: A-05 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: A-05A Survey Calculation Method: Mi nimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Toot ft deg deg ft ft ft ft ft ft 8158.78 47.99 253.60 6738.04 6663.37 -897.93 -3330.81 5947585.19 651149.55 GYD-CT-CMS 8183.78 47.94 253.64 6754.78 6680.11 -903.17 -3348.63 5947579.59 651131.85 GYD-CT-CMS 8206.00 47.71 253.68 6769.70 6695.03 -907.80 -3364.43 5947574.63 651116.15 MWD+IFR+MS 8234.84 47.81 254.69 6789.09 6714.42 -913.62 -3384.97 5947568.39 651095.73 MWD+IFR+MS 8284.30 46.69 256.51 6822.66 6747.99 -922.66 -3420.14 5947558.64 651060.75 MWD+IFR+MS 8328.44 45.30 258.23 6853.33 6778.66 -929.60 -3451.12 5947551.06 651029.93 MWD+IFR+MS 8378.02 42.99 260.28 6888.91 6814.24 -936.05 -3485.04 5947543.91 650996.15 MWD+IFR+MS 8421.80 41.29 262.21 6921.37 6846.70 -940.53 -3514.07 5947538.84 650967.23 MWD+IFR+MS 8471.90 39.25 264.55 6959.60 6884.93 -944.28 -3546.23 5947534.43 650935.15 MWD+IFR+MS 8514.55 37.36 266.68 6993.06 6918.39 -946.31 -3572.58 5947531.86 650908.85 MWD+IFR+MS 8564.82 35.72 269.56 7033.46 6958.79 -947.30 -3602.48 5947530.25 650878.97 MWD+IFR+MS 8610.41 35.34 269.90 7070.56 6995.89 -947.43 -3628.98 5947529.58 650852.49 MWD+IFR+MS 8703.08 36.85 268.89 7145.44 7070.77 -948.02 -3683.57 5947527.88 650797.93 MWD+IFR+MS 8796.04 38.47 266.02 7219.03 7144.36 -950.56 -3740.29 5947524.17 650741.27 MWD+IFR+MS 8889.85 37.54 264.66 7292.95 7218.28 -955.25 -3797.86 5947518.30 650683.82 MWD+IFR+MS 8981.74 38.23 265.46 7365.47 7290.80 -960.10 -3854.07 5947512.30 650627.72 MWD+IFR+MS 9075.99 38.58 268.05 7439.34 7364.67 -963.41 -3912.52 5947507.79 650569.36 MWD+IFR+MS 9170.39 37.90 269.17 7513.48 7438.81 -964.83 -3970.93 5947505.17 650510.99 MWD+IFR+MS 9264.57 39.02 269.17 7587.23 7512.56 -965.68 -4029.50 5947503.12 650452.46 MWD+IFR+MS 9358.00 38.79 269.35 7659.93 7585.26 -966.44 -4088.17 5947501.16 650393.82 MWD+IFR+MS 9450.91 38.29 268.15 7732.61 7657.94 -967.70 -4146.04 5947498.71 650335.99 MWD+IFR+MS 9544.63 37.52 268.20 7806.55 7731.88 -969.53 -4203.59 5947495.70 650278.49 MWD+IFR+MS 9637.48 36.74 268.92 7880.58 7805.91 -970.95 -4259.62 5947493.14 650222.51 MWD+IFR+MS 9732.38 38.33 267.83 7955.83 7881.16 -972.59 -4317.41 5947490.30 650164.77 MWD+IFR+MS 9825.87 38.76 268.10 8028.95 7954.28 -974.66 -4375.63 5947487.04 650106.61 MWD+IFR+MS 9918.40 38.20 268.18 8101.39 8026.72 -976.53 -4433.17 5947483.99 650049.12 MWD+IFR+MS 10012.04 37.12 268.02 8175.52 8100.85 -978.43 -4490.35 5947480.92 649991.99 MWD+IFR+MS 10105.79 36.16 269.07 8250.74 8176.07 -979.85 -4546.28 5947478.35 649936.11 MWD+IFR+MS 10199.27 37.25 267.81 8325.69 8251.02 -981.38 -4602.13 5947475.68 649880.31 MWD+IFR+MS 10290.71 37.73 267.12 8398.24 8323.57 -983.85 -4657.73 5947472.07 649824.78 MWD+IFR+MS 10384.63 36.91 267.25 8472.93 8398.26 -986.64 -4714.60 5947468.11 649767.98 MWD+IFR+MS 10478.85 37.90 268.52 8547.78 8473.11 -988.75 -4771.79 5947464.83 649710.85 MWD+IFR+MS 10570.88 38.46 271.25 8620.12 8545.45 -988.85 -4828.66 5947463.56 649653.99 MWD+IFR+MS 10665.41 37.56 270.42 8694.60 8619.93 -988.00 -4886.87 5947463.22 649595.79 MWD+IFR+MS 10759.21 38.00 265.46 8768.76 8694.09 -990.08 -4944.25 5947459.96 649538.46 MWD+IFR+MS 10783.24 38.25 264.72 8787.66 8712.99 -991.35 -4959.03 5947458.39 649523.71 MWD+IFR+MS 10856.56 38.37 263.85 8845.19 8770.52 -995.87 -5004.26 5947452.94 649478.59 MWD+IFR+MS 10889.53 43.30 262.03 8870.13 8795.46 -998.54 -5025.64 5947449.83 649457.27 MWD+IFR+MS 10919.36 49.33 259.53 8890.73 8816.06 -1002.02 -5046.92 5947445.92 649436.07 MWD+IFR+MS 10949.55 54.02 258.96 8909.44 8834.77 -1006.44 -5070.18 5947441.02 649412.91 MWD+iFR+MS 10981.38 58.19 256.88 8927.19 8852.52 -1011.98 -5096.01 5947434.96 649387.20 MWD+IFR+MS 11012.41 61.63 252.98 8942.75 8868.08 -1018.97 -5121.91 5947427.43 649361.44 MWD+IFR+MS 11044.08 65.64 250.87 8956.81 8882.14 -1027.78 -5148.88 5947418.07 649334.67 MWD+IFR+MS 11074.56 67.77 248.26 8968.87 8894.20 -1037.56 -5175.11 5947407.76 649308.65 MWD+IFR+MS 11106.42 70.82 245.30 8980.13 8905.46 -1049.31 -5202.49 5947395.45 649281.52 MWD+IFR+MS 11136.81 73.30 240.29 8989.50 8914.83 -1062.53 -5228.18 5947381.70 649256.10 MWD+IFR+MS 11169.19 74.89 235.83 8998.38 8923.71 -1079.01 -5254.60 5947364.69 649230.03 MWD+IFR+MS 11200.06 78.06 234.52 9005.59 8930.92 -1096.15 -5279.23 5947347.05 649205.75 MWD+IFR+MS 11230.96 80.14 229.45 9011.44 8936.77 -1114.83 -5303.12 5947327.89 649182.25 MWD+IFR+MS 11262.66 85.98 227.55 9015.27 8940.60 -1135.67 -5326.68 5947306.56 649159.13 MWD+IFR+MS 11292.82 91.36 229.02 9015.97 8941.30 -1155.73 -5349.18 5947286.05 649137.05 MWD+IFR+MS 11323.94 93.58 227.11 9014.63 8939.96 -1176.50 -5372.30 5947264.81 649114.36 MWD+IFR+MS Halliburton Company Survey Report C~ Companya BP Amoco Date: 3/7/2007 Time: 11:58:15 Page: 7 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: A-05, True North Site: PB A Pad Vertical (TVD) Reference: A-05A: 74.7 Well: A-05 Section (VS) Reference: Well (O.OON;I).OOE, 180.OOAzi) Wellpath: A-05A Survey Calculation Method: Mi nimum Curvature Db: OraCle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 11355.47 96.12 221.56 9011.96 8937.29 -1198.96 -5394.25 5947241.91 649092.88 MWD+IFR+MS 11386.69 96.19 214.87 9008.61 8933.94 -1223.34 -5413.44 5947217.15 649074.19 MWD+IFR+MS 11417.73 98.05 209.68 9004.76 8930.09 -1249.37 -5429.89 5947190.79 649058.29 MWD+IFR+MS 11447.32 95.32 204.57 9001.31 8926.64 -1275.51 -5443.28 5947164.37 649045.44 MWD+IFR+MS 11479.76 93.21 199.39 8998.90 8924.23 -1305.50 -5455.38 5947134.14 649033.95 MWD+IFR+MS 11510.54 91.11 194.52 8997.74 8923.07 -1334.91 -5464.34 5947104.56 649025.59 MWD+IFR+MS 11542.25 91.17 189.29 8997.11 8922.44 -1365.92 -5470.88 5947073,42 649019.69 MWD+IFR+MS 11573.56 90.56 183.35 8996.63 8921.96 -1397.02 -5474.33 5947042,26 649016.89 MWD+IFR+MS 11604.27 89.20 178.71 8996.70 8922.03 -1427.72 -5474.88 5947011.56 649016.97 MWD+IFR+MS 11634.96 91.30 173.60 8996.56 8921.89 -1458.33 -5472.82 5946981.00 649019.65 MWD+IFR+MS 11666.96 92.78 169.83 8995.43 8920.76 -1489.97 -5468.21 5946949.47 649024.91 MWD+IFR+MS 11698.32 92.84 169.17 8993.89 8919.22 -1520.77 -5462.51 5946918.79 649031.24 MWD+IFR+MS 11747.84 92.47 168.94 8991.59 8916.92 -1569.33 -5453.11 5946870.43 649041.63 MWD+fFR+MS 11792.09 92.47 168.74 8989.69 8915.02 -1612.71 -5444.56 5946827.25 649051.07 MWD+IFR+MS 11837.14 92.22 168.86 8987.84 8913.17 -1656.86 -5435.81 5946783.29 649060.72 MWD+IFR+MS 11884.86 91.91 168.48 8986.12 8911.45 -1703.62 -5426.44 5946736.73 649071.05 MWD+IFR+MS 11936.10 92.96 166.50 8983.95 8909.28 -1753.59 -5415.36 5946687.00 649083.16 MWD+IFR+MS 11978.33 92.96 165.41 8981.77 8907.10 -1794.51 -5405.12 5946646.31 649094.23 MWD+IFR+MS 12011.26 92.47 164.07 8980.21 8905.54 -1826.24 -5396.46 5946614.76 649103.53 MWD+IFR+MS 12041.09 92.28 163.80 8978.97 8904.30 -1854.88 -5388.22 5946586.30 649112.37 MWD+IFR+MS 12070.83 92.22 162.44 8977.80 8903.13 -1883.32 -5379.59 5946558.05 649121.58 MWD+IFR+MS 12103.27 91.85 160.21 8976.65 8901.98 -1914.03 -5369.21 5946527.56 649132.58 MWD+IFR+MS 12134.77 91.79 159.16 8975.65 8900.98 -1943.55 -5358.28 5946498.27 649144.12 MWD+IFR+MS 12164.72 91.60 157.64 8974.76 8900.09 -1971.39 -5347.26 5946470.67 649155.70 MWD+IFR+MS 12228.66 89.14 154.02 8974.35 8899.68 -2029.70 -5321.08 5946412.90 649183.07 MWD+IFR+MS 12260.47 88.58 152.58 8974.98 8900.31 -2058.12 -5306.79 5946384.79 649197.93 MWD+IFR+MS 12307.81 86.48 152.21 8977.02 8902.35 -2100.03 -5284.88 5946343.34 649220.70 MWD+IFR+MS 12353.11 84.06 150.17 8980.76 8906.09 -2139.58 -5263.13 5946304.25 649243.26 MWD+IFR+MS 12403.75 83.20 150.60 8986.38 8911.71 -2183.33 -5238.26 5946261.02 649269.02 MWD+IFR+MS 12447.10 83.01 149.88 8991.58 8916.91 -2220.69 -5216.90 5946224.10 649291.14 MWD+IFR+MS 12509.80 83.57 148.10 8998.91 8924.24 -2274.06 -5184.82 5946171.41 649324.31 MWD+IFR+MS 12540.21 84.06 146.34 9002.19 8927.52 -2299.48 -5168.45 5946146.34 649341.19 MWD+IFR+MS 12572.14 83.81 146.47 9005.56 8930.89 -2325.93 -5150.88 5946120.26 649359.30 MWD+IFR+MS 12634.18 83.44 146.34 9012.45 8937.78 -2377.28 -5116.76 5946069.61 649394.46 MWD+IFR+MS 12665.58 83.13 145.72 9016.12 8941.45 -2403.15 -5099.34 5946044.12 649412.41 MWD+IFR+MS 12727.16 83.70 145.21 9023.18 8948.51 -2453.54 -5064.66 5945994.45 649448.11 MWD+IFR+MS 12776.54 83.26 145.08 9028.79 8954.12 -2493.80 -5036.62 5945954.78 649476.97 MWD+IFR+MS 12820.80 84.31 144.91 9033.58 8958.91 -2529.84 -5011.38 5945919.26 649502.94 MWD+IFR+MS 12863.78 85.80 144.17 9037.28 8962.61 -2564.71 -4986.54 5945884.91 649528.49 MWD+IFR+MS 12914.57 86.29 145.04 9040.79 8966.12 -2606.02 -4957.19 5945844.22 649558.68 MWD+IFR+MS 12945.41 88.70 145.45 9042.14 8967.47 -2631.33 -4939.63 5945819.27 649576.76 MWD+IFR+MS 13006.24 91.67 146.74 9041.94 8967.27 -2681.81 -4905.70 5945769.50 649611.71 MWD+IFR+MS 13040.78 93.52 148.02 9040.38 8965.71 -2710.87 -4887.10 5945740.83 649630.90 MWD+IFR+MS 13071.43 96.37 147.07 9037.73 8963.06 -2736.63 -4870.72 5945715.41 649647.81 MWD+IFR+MS 13101.71 96.68 146.57 9034.29 8959.62 -2761.81 -4854.26 5945690.58 649664.78 MWD+IFR+MS 13132.06 98.05 146.45 9030.40 8955.73 -2786.91 -4837.65 5945665.82 649681.90 MWD+IFR+MS 13163.84 98.05 146.42 9025.95 8951.28 -2813.13 -4820.25 5945639.97 649699.83 MWD+IFR+MS 13195.72 97.49 145.97 9021.64 8946.97 -2839.38 -4802.68 5945614.09 649717.94 MWD+IFR+MS 13226.61 99.05 146.23 9017.20 8942.53 -2864.75 -4785.63 5945589.08 649735.50 MWD+IFR+MS 13257.82 98.99 146.36 9012.31 8937.64 -2890.39 -4768.52 5945563.79 649753.13 MWD+IFR+MS 13289.28 98.93 146.08 9007,41 8932.74 -2916.22 -4751.24 5945538.32 649770.93 MWD+IFR+MS 13320.62 98.80 145.97 9002.58 8927.91 -2941.90 -4733.94 5945513.01 649788.76 MWD+IFR+MS 13349.36 98.61 146.32 8998.23 8923.56 -2965.50 -4718.11 5945489.75 649805.07 MWD+IFR+MS • Halliburton Company Survey Report C~ Company: BP Amoco Date: 3/7/2007 Time: 11 :58:15 Page:. 8 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: A-05, True: North Site: PB A Pad Vertical (TVD) Reference: A-05A: 74.7 Wells A-0 5 Section (VS) Reference: Well (O.OON,t)OOE,180.OOAzij Wellpath: A-05A Survey Calculation Method: Minimum Curvature Db; Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 13380.98 98.36 146. 43 8993.56 8918.89 -2991.54 -4700.79 5945464.07 649822.91 MWD+IFR+MS 13412.12 98.30 146. 57 8989.05 8914.38 -3017.23 -4683.79 5945438.73 649840.44 MWD+IFR+MS 13443.22 97.93 146. 72 8984.66 8909.99 -3042.95 -4666.86 5945413.37 649857.89 MWD+IFR+MS 13475.46 96.43 146. 57 8980.63 8905.96 -3069.66 -4649.27 5945387.02 649876.02 MWD+IFR+MS 13508.25 94.76 146. 94 8977.43 8902.76 -3096.96 -4631.38 5945360.10 649894.47 MWD+IFR+MS 13537.41 92.78 146. 32 8975.52 8900.85 -3121.26 -4615.38 5945336.14 649910.97 MWD+IFR+MS 13567.84 92.47 145. 60 8974.12 8899.45 -3146.44 -4598.36 5945311.30 649928.49 MWD+IFR+MS 13618.59 91.05 146. 06 8972.56 8897.89 -3188.41 -4569.87 5945269.93 649957.84 MWD+IFR+MS 13660.65 90.68 146. 25 8971.93 8897.26 -3223.34 -4546.45 5945235.49 649981.97 MWD+IFR+MS 13692.79 89.32 144. 77 8971.93 8897.26 -3249.83 -4528.25 5945209.39 650000.71 MWD+IFR+MS 13724.26 86.48 144. 43 8973.08 8898.41 -3275.46 -4510.04 5945184.14 650019.44 MWD+IFR+MS 13754.83 85.43 144. 62 8975.24 8900.57 -3300.30 -4492.34 5945159.67 650037.64 MWD+IFR+MS 13785.00 82.64 144. 98 8978.37 8903.70 -3324.81 -4475.05 5945135.52 650055.44 MWD+IFR+MS 13816.30 79.01 145. 55 8983.36 8908.69 -3350.20 -4457.44 5945110.50 650073.56 MWD+IFR+MS 13847.99 77.87 146. 43 8989.71 8915.04 -3375.94 -4440.08 5945085.13 650091.45 MWD+IFR+MS 13896.34 77.50 146. 52 9000.03 8925.36 -3415.32 -4413.99 5945046.29 650118.33 MWD+IFR+MS 13942.34 77.05 146. 52 9010.16 8935.49 -3452.74 -4389.23 5945009.39 650143.85 MWD+IFR+MS 14036.22 76.23 146. 70 9031.85 8957.18 -3529.00 -4338.97 5944934.18 650195.67 MWD+IFR+MS 14107.88 75.66 147. 01 9049.25 8974.58 -3587.21 -4300.96 5944876.77 650234.86 MWD+IFR+MS 14180.00 75.66 147. 01 9067.12 8992.45 -3645.81 -4262.91 5944818.96 650274.09 PROJECTED to TD TREE = 7-1/16" 5M CIW WELLHEAD=13-5/8" MCEVOY-CONV ACTUATOR = OTIS KB. ELEV = 65.89' BF. Fl EV = 46.17' KOP = _ .._ --._..._- 2800' ..,..._~.._ Max Angle = . F4 Datum MD = DatumTVD= 82," " /2" HES X NIP, ID = 3.813" A -0 5A FROM DRLG -DRAFT Minimum ID = 3.725" ~ 10673' 4-1 /2" HES XN NIPPLE ' 13-318" CSG, 72#, N-80 2018' BTRS, ID = 12.34T' 20" CSG, 133#/ft, 227$' K-55 BTRS, ID = 18.730" Top of Tie-back Cement 2778' Top of 9-5/8" Window -~ 82,(~S' 7" N71Bf CUf ~ '-~ ~~~ 4112", 12.Ei#, L-80 Tbg cut ~ ~ I~fOO~ TOP OF 40' TM! PBR 9272' Est top of P$A Cement L 9°°°' 1v'~~~ 119-5/8" X 7" TM! LNR TOP PKR/HGR W/40' PBR ~, s 9-518" TBG, 47#, L-80, .0732 bpf, ID = 8.681" 9814' ®` `. $ s 2,800' I-I TOC in 7" Tieback 10,608' 1--14112" X Nipple {3.813" D) 10629' H7" x 41/2" Baker S3 Packer 10,652' 4 112" X Nipple (3.813" ID) 10673' 41/Z" XN Nipple (3.725" ID) 10680' 5" X 7" BKR HGR PKR 10685' 4112" WLEG 4-1 /2", 12.6#, L-80, IBT-M Production Liner 14178' PBTD - 14090' 9340' 4-1/2" CUT OFF TBG STUB 9341' 5-314" CUSTOM OVERSHOT, IO = 4.655" 9348' T' BKR SABL-3 PKR W/ KBH-22 ANCHOR, ~ = 3.875" 10516' 4-1/Z'• WLEG • 4-112" TBG, 12.6#, L-80 NSCT, 10516' .0152 bpf, ID = 3.958" PBTD 11259' 7" LNR, 29#, L-80, .0371 bpf, ~ = 6.184" 11360' SAFETY NOTES: **WARNING: RADIO TRANSMITTER IN W FATHER MONITORING SHACK MUST BE TURNED OFF BEFORE ANY W ELLW ORK INVOLVING EXPLOSNES CAN BEGIN. CONTACT PAD OPERATOR** 1,750' - 13-318" L-80, 88N, I.D.=11.415' 1839' 13-3/8" X 9-5/8" TNV PKR 1846' TOP OF 9-518" PBR (12') 1857' BOTTOMS-518" SEAL ASSEMBLY 2018' BOTTOM 9-518" DUPLEX SHOE 112$9' I~ 2 SLIPS OFF SCA 8 LNR ON BTM (11 /16/95) DATE REV BY COMMENTS DATE REV BY COMMENTS 10/29/77 ORIGINAL COMPLETION 05/09/01 CH/KAK CORRECTIONS 08/08/91 RWO 11 /17/02 BANKA K 9-5/8" TBG DEPTH CORRECTIO 12!11 /94 RWO 02/09/07 DM/8N Rig Sidetrack 8 Completion 11!16195 RWO 02/12/07 /PAG DRLGDRAFTCORRECTIONS 01/22/01 SIS-MH CONVERTED TO CANVAS 03/02/01 SIS-LG FINAL PRUDHOE BAY UNff WELL: A-OSAi PERMfT No: 206-128 API No: 50-029-20116-01-00 SEC 35, Ti t N, R13E, 1895' FNL & 922' FEL BP Exploration (Alaska) 02/12/2007 ~chlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well -lnh it ~-1~~ 1 .... ns ..s:.. NO. 4131 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n_a_ L5-25 11538589 LDL 12/28/06 Y-16 11626467 LDL 01/19/07 1 L-04 11603118 MEM LDL 12/30/06 1 11-24A 11638611 USIT 01/24/07 1 1-33 11631645 USIT 01/09/07 1 A-OSA 11533393 USIT 01/04107 1 DS 05-10B 11626469 SCMT 01/22107 1 W-29 11536193 USIT 01/05/07 1 R-15A 11626266 USIT (CEMENT EVALUATION) 01111107 1 R-15A 11626266 USIT (CORROSION) 01/11/07 1 MPF-99 11637306 CEMENT EVALUATIONICBL 01/14107 1 R-12 11414757 RST 09/01106 1 1 NK-38A 40011271 OH EDIT MWD/LWD 03/11/05 3 1 NK-38A PB1 40011271 OH EDIT MWDlLWD 02/26/05 2 1 MPC-28A 11649937 MEM INJECTION PROFILE 01/05!07 1 D5 07-04A 11533394 LDL 01/05107 1 F-23A 11626066 LDL 01/08!07 1 P2-19 11630449 LDL 01/14/07 1 Y-09A 11630450 LDL 01/16107 1 OI CACG Af~Vw1A\w11 __. .____.___~--~~~~~..~~~.. ... ...v....~V r„~V .~~, v,~1~11~V VI~G VVI-1 GI~VII 1V. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Cons 2525 Gambell Street, i Anchorage, AK 99503-2838 ATTN: Beth ~° ~y M~ ~1.~ ~ ~ ~~~~ Received by: ~~~k~ ~SAA !~ ~~~ ~.~arl~. > ~ii~~@t~t a9 [Fwd: Well Control incident on well A-OSi] • Subject: [Fwd: Well Control incident oil well A-05i] From: John Crisp <john_crisp@admin.state.ak.us> Date: Thu, O1 Feb 2007 09:56:15 -0900 To:.~im Red;~~'=jimie:;~~r~i%admin.sla~e.akus= ~.~( ~~~ -O"1 • -------- Original Message -------- Subject: Well Control incident on well A-05i Date: Thu, O1 Feb 2007 09:50:23 -0900 From: NSU, ADW Drlg Rig 2es <NSUADWDrlgRig2es~~~b~'com> To: john crisut~adtnin.state.ak.us John, John, Per your request: the following is an account of the recent well control incident on 2ES: Date: 1/31/07 Time: 03:00 Hrs. Rig: Nabors 2ES Well: A-05i Depth Q time of kick: 12,070' MD, 8978' TVD. Formation ~ kick point: Ivishack - Zone 4 Operation at time of incident: Drilling 6 1/8" production hole loosing 40 to 60 Bbls / Hr into Shublig limestone fractures (at 10,894' MD). Incident Scenario: While drilling ahead @ 12,070; driller observed an increase in flow rate. He immediately picked up, shut down the pumps and checked for flow. The well was flowing. The driller shut the well in with the upper variable rams and began recording pressures. Pressures stabilized ~ 30 psi DP and 130 psi csg. I was woken by my night WSL and appraised of the situation. I notified my Drilling Manager, Mike Schultz and called you, John, at AOGCC. I went up to the floor and we began circulating out the influx using the driller's method. we observed no increase in casing pressure while circulating it out; nor was there any gas or oil in the mud coming out of the gas buster. I circulated an additional 1000 stokes(58 Bbls) because of our continuing losses. After circulation was complete: we checked for pressure - none. we opened up and monitored the well for 15 minutes. Well was dead - static. We continued drilling ahead. We ha been expecting a fault @ 12,000 MD; and our geologists feel that, although it is not visible on LWD logs, we probably crossed it or a fracture ~ kick point. It is presently 09:45 AM, Feb 1st. We are drilling ahead in the same zone at 12,610' MD and have had no further problems. Contact me if you require any further information. Regards, Bill Decker WSL - Nabors 2es BPXA, GPB Drilling Tel: 659-4103 Fax: 659-4177 1 of 1 2/1/2007 10:00 AM Re: A-OSAi (206-128) • Subject: Re: A-OSAi (206-128) From: Thomas Maunder <tommaunder~~admin.state.ak.us> Date: Thu, 18 Jan 2007 1 1:04:05 -0900 To: "Nadem, Nt~hrdad" <NademM(c~?BP.con3> Mehrdad, Thanks for the information. It would appear that the FIT values and planned mud weights should be compatible. Good luck with the operations. Ca11 or message with any questions. Tom Maunder, PE AOGCC Nadem, Mehrdad wrote, On 1/18/2007 10:58 AM: Tom, This is a follow up and recap of our discussion regarding FIT testing of the 8.5" in A-05Ai. The day shift Well Site Leader reviewed the FIT data performed by the night crew, and concluded that FIT is 11.1 ppg EMW, not 11.5 ppg. 1 had reported the FIT of 11.5 ppg EMW to AOGCC last night. We also revised the mud program to reflect the latest directional plan for A-05Ai. This directional plan was developed after we had a gyro survey done on A-05 before Christmas. Based on the Kingak Polar plot, we plan to weight up the mud to 10.6 ppg before HRZ, and will maintain that during the remainder of the intermediate hole interval. Additionally, we plan to perform the FIT in the production section to 9.7 ppg EMW. Our kick tolerance calculator shows kick tolerance to be infinite at this equivalent mud weight. Best regards, Mehrdad Nadem Operations Drilling Engineer Phone: 907/564-5941 Cell: 907/440-0213 Email: nademmb ,com ~~~~ ~ ~~~ a ~~cL 1 of 1 3/13/2007 12:02 PM f Robert Tirpack Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHOAAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27&7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-05Ai BP Exploration (Alaska) Inc. Permit No: 206-128 Surface Location: 1896' FNL, 923' FEL, SEC. 35, T11N, R13E, UM Bottomhole Location: 241' FNL, 42' FWL, SEC. 02, T10N, R13E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to redrill 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) ~9-3607 (pager). f Jo K. orma DATED this' day of September, 2006 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~L~D ~ ALAS LAND GAS CONSERVATION COMMIS~t PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is prop~~~~~e ^ Coalbed Methane as ates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number,;l,Z/~ PBU A-05Ai ~~ l 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13833 TVD 9044 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1896' FNL 923' FEL SEC 35 T11 N R13E UM 7. Property Designation: ADL 047472 Pool , , , , , . Top of Productive Horizon: 3328' FNL, 803' FEL, SEC. 34, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spu te: Septemb r 28, 006 Total Depth: 241' FNL, 42' FWL, SEC. 02, T10N, R13E, UM 9. Acres in Property: 2560 14. Distance to Near Property: 14,775' 4b. Location of Well (State Base Plane Coordinates): Surface: x-654462 y-5948551 Zone-ASP4 10. KB Elevation (Height above GL): 74.67 feet 15. Distance to Nearest Well Within Pool: 445' 16. Deviated Wells: Kickoff Depth: 8200 feet Maximum Hole An le: 100 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3285 Surface: 2397 18' Casio P "ram: bo ns To -`Se in De th -Bo ttom uanti of Cement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data N/A 7" 26# L-80 TCII 3300' Surface Surface 3300' 3278' See Below N/A 7" 26# L-80 BTC-M 4750' 3300' 3278' 8050' 6665' 666 sx Class 'G' -1/2" 7" 26# L-80 BT -M 272 ' 8050' 6665' 1 770' 8835' 1 2 sx Lie rete 168 sx Lite r 6-1/8" 4-1l2" 12.6# L-80 IBT-M 3213' 10620' 8711' 13833' 9044' 393 sx Class'G' 1 g. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11370 Total Depth TVD (ft): 9349 Plugs (measured): 10504 Effective Depth MD (ft): 11259 Effective Depth TVD (ft): 9245 Junk (measured): 11259 'Casing tength;° ize Cement Volume MD D Conductor /Structural g0' 300 sx 90' 90' Surface 2278' 18-5/8" x 20" 8700 sx 2278' 2278' Intermediate 9814' 13-3/8" x 9-5/8" 2150 sx 9814' 7965' Production 11360' 9-518" x 7" 48 sx 11360' 9339' Liner Perforation Depth MD (ft): 10806' - 10942' Perforation Depth TVD (ft): 8823' - 8949' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mehrdad Nadem, 564-5941 Printed Name Robert Tirpack Title Senior Drilling Engineer Prepared By Name/Number: Si nature ~~``-' Phone 564-4166 Date ~ 3% Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: Z API Number: 50-029-20116-01-00 Permit Approval See cover letter for Date: • ~ ' other re uirem nts Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: j .e c~ '~ [3 O ~ ('~, ~p 4v/ o,/a ~ S r, • Samples Req'd: ^ Yes~No Mud Log Req'd: ^ Yes ~No ~, L T ~ C.2-1~~rc.~ ~ ~ (.+. (-`~ ~~ ~ Ye` ~1,~ ~ ' HZS Measures: Yes ^ No Dire tonal Survey Req'd: Yes ^ No Other: to,,~,~~ttia~.t {-o Zo~~i-c2s.o3a (G~)(rl~ al~~w~.~e. (~Di~E y®' r7~s ~~aw~ted. ~ 0 ~ APPROVED BY THE COMMISSION Date ,COMMISSIONER EI'~ °c CEP 0 1 2006 Alaska Oil ~ ~ Form 10-401 Revised 12!2005 I ~-~(~ / (' /- / `~ ~ Submit In Duplicate • • To: Winton Aubert, Petroleum Engineer Alaska Oil & Gas Conservation Commission ~.J From: Mehrdad Nadem, Drilling Engineer IJ Date: August 10, 2006 Re: A-OSAi Sidetrack Permit to Drill The sidetrack, A-OSAi, is scheduled to be drilled by Nabors Rig 2ES during the first week of October. The plan is to exit the parent A-OSi well bore at 8,200' MD. A whipstock will be run and an 8-1/2" window will be milled in the 9-5/8" casing. An 8-1/2" hole will be drilled to the Top of the Sag River forma ' n. 1~ 7" drilling liner with tieback to the surface will be run and cemented. Cement top will be at ,800''. The 6-1/8" well bore be drilled to Zone 4B. The planned injection segment of this well run for approximately 3,063'. A solid 4-1/2" liner will be run and cemented with 150' liner lap into the 7" drilling liner. The 4-1/2" production liner will be perforated. Planned Well Summary Well A-05Ai Well Horizontal Target Zone 4B T e Sidetrack Ob'ective AFE Number: PBD4P2420 API Number: 50-029-20116-01 Surface Northin Eastin Offsets TRS Location 5,948,551.02 654,461.99 1,896' FNL / 923 FEL 11 N,13E, 35 Northin Eastin Offsets TRS 5,947,015.52 649,332.80 1952' FSL / 803' FEL 11 N, 13E, 34 Target 5,946,295.00 649,240.00 1,233' FSL / 911' FEL 11 N, 13E, 34 Locations 5,945,770.00 649,615.00 701 FSL / 548 FEL 11 N, 13E, 34 5,945,245.00 649,965.00 169' FSL / 209' FEL 11 N, 13E, 34 Bottom Northin Eastin Offsets TRS Location 5,944,840.00 650,225.00 241' FNL / 42' FWL 10 N, 13E, 2 l Planned KOP: 8,200' and / 6,766' TVD Planned TD: 13,833' and / 9,044' tvd Ri Nabors E CBE: 46.17' RTE: 74.67' 6-13A Sidetrack Page 1 Directional Program A roved Well tan: W 06 Exit oint: 8,200' and / 6,766' tvd Maximum Hole Inclination: 99.71° in the tanned 6 1/8" hole section. Proximity Issues: All wells pass major risk after resurveying with gyro data-Tolerable risk worksheet com leted for this well. Survey Program: Standard MWD/IFR/MS. Nearest Well within ool: A-16, 445' Nearest Pro ert Line 14,775' Logging Program Hole Section: Required Sensors /Service 8 1/2" intermediate: Real time Dir/GR/PWD 6 1/8" production: Real time MWD Dir/GR/Res/ABI/IFR Cased Hole: USIT will be run in the 7" cased hole ~ O en Hole: None tanned Mud Program Hole Section / o eration: Mill window in the 9 5/8" casin at 8,200' and T e Densit MBT PV YP API FL H LSND 9.0 <12 15-22 30-40 <6.0 9.0 -10.0 Hole Section /operation: Drilling 8 1 /2" interval from 8,200' and to TSAG at 10,770 and T e Densi MBT PV YP API FL H LSND 9.0- 0. <15 15-22 20-24 4.0 - 6.0 9.0 - 10.0 Hole Section / o eration: Drillin 6 1/8" hole interval to 13,833' and T e Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.6 >20,000 8 - 12 22 - 28 6 - 8 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd N/A 7 " 26.0# L-80 TCII 3,300' Surface 3,300' / 3,278' N/A 7 " 26.0# L-80 BTC-M 4,750' 3,300' / 3,278' 8,050' /6,665' 8 1 /2" 7" 26.0# L-80 BTC-M 2,720' 8,050' /6,665' 10,770' / 8,835' 6 1/8" 4 ~/z" 12.6# L-80 IBT-M 3,213' 10,620' / 8,711' 13,833' / 9,044' Tubin 4'h" 12.6# L-80 TCII 10,620' Surface 10,620' / 8,711' 6-13A Sidetrack Page 2 • • Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Bride lu to surface 30 min recorded 4,000 si surface 9 5/8" casin window 20' new formation be and FIT 11.8 EMW 7" tieback Baffle collar to surface 30 min recorded 4,000 si surface 7" casin Float a ui ment to surface 30 min recorded 4,000 si surface 7" casin shoe 20' new formation be and FIT 10 EMW 4'/z" roduction liner Float a ui ment to surface 30 min recorded 4,000 si surface Cementing Program Casin Strin 7", 26#, L-80, BTC-M x TC-II Tieback Slurry Design Basis: Lead slurry: None planned. ° Tail slur :5,250 of 9-5/8 X 7 annulus to 2,800 MD with 0 /° excess. Pre-Flush None Planned Freeze Prot 72 bbls of diesel Fluids Sequence/ Volume: S acer 20 bbls of Mud Pus :Nat 11 Lead Slur 137.5 bbls / 772 / 66 sxs Class `G', 15.8 1.16 /sk. Tail Slur None tanned ~~ Casin Strin 7", 26#, L-80, BTC-M intermediate liner Lead slurry: 1,570' of 7" x 8-1/2" annulus with 40% excess, plus 150' of 7" x 9-5/8" liner lap, plus 200' of 9-5/8" x 4" drill pipe annulus, plus 80' of shoe Slurry Design Basis: track. ° Tail: 1,000 of 15.8 ppg Class G cement with 40 /° excess plus 80 of 7 shoe track. Pre-Flush None tanned Fl id S /V l S acer 20 bbls Mud PU at 1.5 u s equence o ume: Lead Slur 65 bbls / 365 cf xs Lite Crete, 15.8 2.2 cf/ Tail Slur 34.7 bbls/ 195 cf / 8 xs Lite Crete, 15.8 ppg; Class "G", 1.16 /sk Casin Strin 4-~/z", 12.6#, L-80, IBT-M Production liner Lead slurry. None planned. Slurr Desi n Basis: y g Tail slurry. 3,063'of 4-~h" x 6-1/8" annulus with 40% excess, plus 150' of 4- " " " ' " " ' of 4-'/2 x 7 liner lap, plus 200 of 4 drill pipe x 7 annulus, plus ~80 , '/z 12.6#, shoe tract. Pre-Flush: None planned Spacer Fluid: 40.0 bbls MudPUSH II at 10.5 ppg Lead Slur Slur T e None tanned Tail Slur Slur T e 81 bbls / 455 cf 39 sxs 15.8 p ,Class "G", 1.1 cf/sk ~~~ 6-13A Sidetrack Page 3 CJ Well Control • ,~v Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum anticipated BHP: 3,230 psi at 8,755' TVD. Maximum surface pressure: Si (based upon BHP and a full column of gas from TD (~ 0.10 psi/ft) Calculated kick tolerance: tnfini with 11.5 ppg EMW FIT Planned BOPE test pressure: psi low / 4,000 psi high 7 day test cycle (Pre drilling phase) 14 da test c cle Drillin o erations BOPE configuration for 7" drilling liner. C/O to 7" pipe rams before running the 7" liner and the 7" tieback. Well Interval: 6 1/8" production interval Maximum antici ated BHP: 3,285 psi at 8,880' TVD. Maximum surface ressure: 2 SI (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: nfin' a with 10.0 pp EMW FIT. Planned BOPE test ressure: ~2 0 si low / 4,000 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.4 pp seawater / 7.1 pp Diesel BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Disposal Annular Injection: No annular injection in this well. Cuttings Handling• Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 6-13A Sidetrack Page 4 • • Geologic Prognosis Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. ~ Formation (TVDss) eet) (Yes/No) (Psi) ( EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation to s are re aired from surface to TD for all new wells WS2 5405 WSl 5690 CM3 5888 +!- 5' 1969 CM2 (A-05Ai KOP is 8200' 6698' SSTVD) 6365 (isochore) +/- 5' No 6.8 CMl 7115 (isochore) +/- 5' No 6.8 THRZ 7435 ( 'd) +/- 5' No 2649 6.8 BHRZ 7605 (isochore) +/- 5' No 6.8 LCU 7630 (isochore) +/- 5' No 6.8 TJF 7900 ( 'd) +/- 5' No 2854 6.8 TJE ( rids to TD) 7960 +/- 5' No 2880 6.8 TJD 8325 +/- 5' No 3041 6.8 TJC 8455 +/- 5' No 3098 6.8 TJB 8560 +/- 10' No 3144 6.8 TJA 8670 +/- 10' No 3193 6.8 TSGR 8755 +/- 10' Yes 3230 6.8 TSHA 8780 +/- 10' No 3241 6.8 TSHB 8809 +/- 10' No 3254 6.8 TSHC 8828 +/- 10' No 3262 6.8 TSAD 8855 +/- 10' Yes 3274 6.8 To HOT 8965 +/- 10' 3323 6.8 TSAD at 1st well crest 8880 +/- 10' 3285 6.8 TSAD at 2nd well crest 8880 +/- 10' 3285 Used primarily A-Ol and A-14 for isochores 6-13A Sidetrack Page 5 • Fault Prognosis L~ Formation Where Encounter Fault MD Intersect Subsea TVD Intersect Est. Throw Throw Direction Uncertainty MD (ft) Fault 1, Z4B 11700' -8928 20-25' Down to SSE 220' Fault 2, Z4B 12960' -8946 15' Down to N 110' Fault Coordinates for Ma in X Y Fault 1 First Coordinate 648775 5946480 Fault 1 Wellbore Intersection 649091 5946620 Fault 1 Intermediate Coordinate 649810 5946647 Fault 1 Last Coordinate 650619 5946908 Fault 2 First Coordinate 649072 5945409 Fault 2 Wellbore Intersection 649750 5945570 Fault 2 Last Coordinate 650905 5945290 Comments Fault 1 parallels wp05 from KO to the turn to the south. Drill to plan and avoid drifting to the south side of target polygon before azimuth of 200 degrees to avoid drilling into and parallel to the damage zone of fault 1 and increasing lost circulation risk. Both fault 1 and fault 2 strike E-W, so the lost circulation risk crossing them should be minimized due to compression by NW-SE maximum regional stress. Nevertheless, Y-34A experienced 2,100 bbls lost circulation when it penetrated the western extent of fault 1 and an intersection with a small north-south fault. Presumably the LC was due to a higher fracture concentration near the intersection and tip out zone of both faults. 6-13A Sidetrack Page 6 • Wells within 1/4 mi. of this injection well @ top reservoir Well Name Dist, Ft. A-16 445 Y-34A 925 Y-35A ' 700 • Igo I 1 3 (~ ! l~ I~t4DO4 2dt L37 I I B!!!U lSaM! !5!U! !5x00 !5!}O I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I i I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I ~~ I I L_________ _____________________________________________________J BPXA KURD 112008 FEET \ o }ao eoa vw iooo uao ieao N CDR 29-Ru uat-2006 6-13A Sidetrack Page 7 C Operations Summary Current Condition: / SI since October 2002. / 7" 1 J4S x 5.5" BTC-M cross over with top at 24.81 ' / 5.5" x 4.5"cross over wit top at 26.49' / HES 4.5" "X" Nipple, 9 CR; 2,213.32' to 2,214.46' / Baker S-3 packer at 9,199.82' to 9,203.62' / PXN plug (top load plus) at 9,316'. • Pre-Riq Work: 1. Rig up slick line. Drift 4-1/2" tubing to WLEG at 10516'. Do not RIH below WLEG due to slips being left in the hole. 2. Fluid pack the tubing and inner annulus. 3. P&A perfs in 7" liner from the top of the fish (11,259') to 9,200' MD. R1H with coil to PBTD. Lay in 47.6 bbls of cement to 9,200' MD. Wash down to confirm TOC. POH with coil. a. Cement Calculations: • 743' of 7", 29# liner, 11,259' - 10,516'= 27.6 BBLS • 1,316' of 4-1 /2", 12.6# tubing, 10,516' - 9,200' = 20.0 BBLS • Total cement volume of 47.6 BBLS 4. Rig up slickline, drift 4-1/2" tubing. Tag TOC. 5. Chemical cut the 4-1/2", 12.6#, L-80 tubing at ~ 8,700' MD. 6. Pressure test T X IA to 3,500 psi for 30 minutes. Pressure test the OA to 2,000 psi for minutes. 7. Circulate the well to sea water through the Chemical cut. Freeze protect the IA and tubing with diesel to 2,200'. 8. Bleed OA, IA & TBG to zero. Test the 9-5/8" pack-off to 3,500 psi and tubing hanger seals to 5,000 psi. Function all lock-down screws. Repair or replace as needed. 9. Bleed casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 10. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 4-1/2" tubing from the pre-rig Chemical cut 8,700'. 5. RIH with BOT casing cutter and cut 7", 29# liner at 8,500'. 6. Make cleanout run with casing scraper. 7. RU a-line. Run Gauge Ring /Junk basket and Gamma Ray tool for 9-5/8", 47# casing with CCL to tubing stub at ~ 8,500'. 8. RIH with 9-5/8" EZSV on a-line. Set EZSV at 8,224 or as required to avoid cutting a casing collar during window milling operations. RD a-line. ~-, 9. Close rams and pressure test the 9-5/8" casing and bridge plug. If PT fails PU RTTS to find leak. If there is a leak a contingency plan will be sent to the rig. ), 10. PU 9-5/8" whipstock and bottom trip anchor with an 8-1/2" window milling assembly. RIH picking up 4" DP to EZSV. Orient and set the whipstock. Swap well over to 9.0 ppg milling fluid. Note: If MWD signals are too weak to obtain toolfaces, swap over to milling fluid before setting the whipstock. 11. Mill a window in the 9-5/8" casing at ± 8,200' MD plus 20' from mid window. Perform FIT to 11.8 ppg. POOH for Drilling BHA. Note: Verify that the mud weight is 9.0 ppg prior to cutting the window. 12. MU the 8-1/2" drilling assembly with DIR/GR/PWD and RIH. Kick off and drill 8-1/2" intermediate interval to 7" --. casing point 10,770' top setting the Sag River. Mud weight will be increased to 10.9 ppg before drilling into the O THRZ. ~- 13. Run a 7", 26#, L-80 drilling liner with 150' liner lap inside the 9-5/8" casing. Pump enough cement to cover the bottom 100' of the 7" liner, displace cement with mud and POH. 14. RU and run 7" Tie-back liner to surface. Top 3,300' of 7" will have premium threads. Cement will be brought up fl to 2,800' MD. Remainder of 9-5/8" by 7" annulus will be freeze protected to surface. j ` 15. MU 6-1/8" BHA with DIR/GR/RES and RIH to the 7" tie-back landing collar. 6-13A Sidetrack Page 8 • • 16. Pressure test wellbore to 4,000 psi for 30 minutes. ~ 17. Drill tie-back cementing equipment and RIH to 7" drilling liner landing collar. 18. Pressure test wellbore to 4,000 psi for 30 minutes. 19. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 10.0 ppg. 20. Drill the 6-1/8" production interval as per ' ectional; plan. 21. Run a 4-1/2", 12.6#, L-80 solid liner wit 10 'finer lap inside the 7" drilling liner. ~ 22. Spot a perf pill inside the 4-1/2" liner an elease. Displace well to clean seawater. 23. RU DPC pert guns, RIH and perforate. Perf intervals to be supplied by asset 24. Run the 4-1/2", 12.6#, L-80 completion tying into the 4-1/2" liner top. 25. Set packer and individually test the tubing to 4,000 psi and annulus to 4,000 psi for 30 minutes each. 26. Set and test TWC. 27. ND BOPE. NU and test the tree to 5,000 psi. 28. Freeze protect the IA and Tubing to 2,200' and secure the well. 29. RDMO. Post-Rig Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 6-13A Sidetrack Page 9 • • Phase 1: Move In / Rig Up /Test ROPE Planned Phase Time Planned Phase Cost 55.30 $344,831 includes re-ri costs Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP • "Hydrogen Sulfide" SOP. • "ADW Rig Move" RP. Issues and Potential Hazards - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move onto A-05A. Wells A-06 and A-03 are adjacent to A-05A. The distance between each of these wells to the target well is greater than 99'. However, care should be taken while moving in on the well. Spotters should be employed at all times. - During MI/RU operations, the A-05A well bore will be secured with the following barriers: o Tubing: cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: 100 sacks of cement between FOC at 2,146', and 372 bbls of residual oil. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPE operations, the A-05A well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: 100 sacks of cement between FOC at 2,146', and 372 bbls of residual oil. .•. - H2S Monitoring. Use extra caution while working at this drill site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Date of Wall Name N2C T.PVPI Rr+arlina #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H25 Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility A-40 20 m 4/12/2005 A-04 10 m 5/6/2005 A-41 20 m 7/9/2000 A-14 50 m 6/2/2005 A-43 150 3/18/2002 The maximum level recorded of H2S on the pad was 150 pp/m in well A-43 recorded on March 18, 2002. The highest current H2S level is on A-43 fit 90 pm on June 6, 2006. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud 6-13A Sidetrack Page 10 • • Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 63.60 $243,000 Reference RP • "De-completions" RP • "Casing Cut and Pull with Baker Back Off Tool" RP • "Surface Casing Port Collar" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a 13-5/8" 5M McEvoy - CONV with 7-1/16" 5m CIW. Verify with Cameron that all replacement parts and required equipment is available. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de-completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has an HES X Nipple with ID=3.183" at 2,213. No controls bands are expected to be encountered. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 34 $227,871 `Reference RP • "Whip stock Sidetracks" RP • "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled - Once the milling BHA is out of the hole, the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. - Fit to 11.8 ppg EMW Phase 4: Drill 8 1/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 78.20 $503,640 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" RP • "Lubricants for Torque and Drag Management" RP 6-13A Sidetrack Page 11 • • • "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards - For this well, the Kingak will require a mud weight of 10.9 ppg. Maintain mud weight at 10.9 ppg to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 8.5 ppg pore pressure, a fracture gradient of 11.8 ppg at the 9 5/8" casing window, and 10.9 ppg mud in the hole, the kick tolerance is infinite. - The above kick tolerance is based on an FIT of 11.8 ppg EMW; if this is not reached contact the ODE. Phase 5: Run and Cement 7" Intermediate Casing and Tieback Planned Phase Time Planned Phase Cost 18.20 $622,741 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP • Schlumberger Cementing Program Issues and Potential Hazards - The design for the liner is to run a 7", 26#, L-80, BTC-M solid liner. - Sufficient 7" liner will be run to extend 150' back up into the 9-5/8" casing. - A tieback will be run to surface and cemented to 2,800' MD. Two different connections will be run (BTC-M and TC-II) in the tie-back. - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Phase 6: Drill 6 1/8" Production Hole Interval Planned Phase Time Planned Phase Cost 193.20 $919,192 Reference RP Reference RP • "Leak-off and Formation Integrity Tests" SOP • "Prudhoe Bay Directional Guidelines" RP • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - Fault O1 parallels wp05 from kick off point to the urn to the south. Drill to plan and avoid drifting to the south side of the target polygon before azimuth of 200 degrees to avoid drilling into and parallel to the damaged zone of fault 1 and increasing lost circulation risk. Please note that Y-34A experienced 2,100 bbls lost circulation when it penetrated the western extent of fault 1, and an 6-13A Sidetrack Page 12 • intersection with small north-south fault. Presumably the lost circulation was due to a higher fracture concentration near the intersection. - Fault 2 is expected at 12,960' md. Fault 2, similar to fault 1, strikes E-W, so the lost circulation risk crossing them should be minimized due to compression by NW-SE maximum regional stress. Phase 7: Run 4~h" Production Liner Planned Phase Time Planned Phase Cost 25.50 $277,262 Reference RP • "Modified Conventional Liner Cementing' RP • Schlumberger Cement Program. Issues and Potential Hazards - The completion design is to run a 4'/i", 12.6#, L-80 IBT-M throughout the production interval. - Sufficient 4- ~/2" liner will be run to extend -150' back up into the 7" liner shoe. - Ensure the 4'/z" liner top packer is set prior to POOH. Phase 8: DPC Perforate Well Planned Job Time Planned Job Cost 36.80 $221,014 Reference RPs • DPC Perforating RP • Schlumberger DPC Perforating Guidelines Issues and Potential Hazards - The production interval of the well will be DPC perforated prior to running the completion. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POOH with pert guns. - The Asset will provide a minimum clean out depth. This will define how far off depth the guns can be and still be fired without coming out of the hole to perform a clean out trip in the event the guns cannot tag the landing collar due to cement/fill. Phase 9: Run 4 ~/z", 12.6#, 13Cr, VamTop Completion Planned Phase Time Planned Phase Cost 22.10 $461,891 Reference RP • "Completion Design and Running" RP • "Tubing connections" RP • "Handling and Running 13 Chrome" RP 6-13A Sidetrack Page 13 ~ ~ Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion design will be a 4Yz", 12.6#, 13Cr, VamTop production tubing string with 7" x 4-1/2" Baker S-3 packer. Phase 10: ND/NU/Release Riq Planned Phase Time Planned Phase Cost 13.50 hours $42,350 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off A-06. As always, care should be taken while moving onto the well. Spotters should be employed at all times. 6-13A Sidetrack Page 14 _ , V ~ F F F F F p - _ ~' o^ ~ o ~ ? 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F. ?C t R S `o `o r^c'r ~ p., a-zcracrnc0xccc .orN,n .rr ~.c r.' c r< r. ^ xc ~bTaa , , , , rr0xoaaaa0o0aaa0 ~o .cr zax zx zaa az xxa i NT-MVl FF-F-FF ~ -N,n ,no~iNO ~,co--oNN "' ~ r.DT Tt~r`rrv, vl ,Orr xxx ~000~ cccccv-tRVRCR ~INNNN-~~-~~~~~~-~~ . z ««< ~~ ATP ,p-NNON ^. vlh= _ ~ _ -. T N O ? ~^. x K7M.M~a as nzaas a~~ _-.C-?~r~NR-Nt vl~^ v ~o t- ~N~ x xx x TTr Mr M ' ~ -N~"~V,n .C [v 3 ~ ~a ~~> 3 ~ ~NL ^~ fi.r L9 7 Ein~ c~~Ep aSN~~ j 3 5 err -Sun P Y BP Planning Report Company: BP Amoco Date: 8/10/2006 Time: 14:56:04 Page: 1 .Field: Prudhoe Bay Co-ordinate(NE) leference: W eIL A-05, True North Site: PB A Pad Vertical (TVD) Reference: 46.17+28,5 74.7. Well: A-05 Section ryS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: Plan A-05A Survey Calculation Method: Minimum Curvature Dbc Oracle- Plan: A-05A wp06 Date Composed: 6/28/2005 Version: 27 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB A Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5946131.57 ft Latitude: 70 15 35.209 N ' From: Map EasHng: 653509.42 ft Longitude: 148 45 32.775 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.17 deg Well: A-05 Slot Name: 05 A-05 Well Position: +N/-S 2399.67 ft Northing: 5948550.98 ft Latitude: 70 15 58.809 N +E/-W 1001.77 ft Easting : 654462.00 ft Longitude: 148 45 3.618 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 10770.66 8834.67 7.000 8.500 7" 13833.00 9044.55 4.500 6.125 41/2" Formations MD ft TVD ft Formations Lithology Dip Angle deg Dip Direction deg 0.00 WS2 0.00 0.00 0.00 WS1 0.00 0.00 0.00 CM3 0.00 0.00 0.00 CM2 0.00 0.00 8752.09 7189.67 CM1 0.00 0.00 9144.76 7509.67 THRZ 0.00 0.00 9353.37 7679.67 BHRZ 0.00 0.00 9384.04 7704.67 LCU 0.00 0.00 9715.36 7974.67 TJF 0.00 0.00 9788.98 8034.67 TJE (grids to TD) 0.00 0.00 10236.87 8399.67 TJD 0.00 0.00 10396.39 8529.67 TJC 0.00 0.00 10525.24 8634.67 TJB 0.00 0.00 10660.22 8744.67 TJA 0.00 0.00 10764.52 8829.67 TSGR 0.00 0.00 10795.20 8854.67 TSHA 0.00 0.00 10831.63 8883.67 TSHB 0.00 0.00 10856.95 8902.67 TSHC 0.00 0.00 10895.65 8929.67 TSAD 0.00 0.00 12609.75 9039.67 Top HOT 0.00 0.00 10935.49 8954.67 TSAD at 1st well crest 0.00 0.00 10935.49 8954.67 TSAD at 2nd well crest 0.00 0.00 Targets Map Mag <--- Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft A-05A T2 8964.67 -2148.52 -5267.57 5946295.00 649240.00 70 15 37.660 N 148 47 36.888 W A-05A T4 8964.67 -3213.25 -4564.22 5945245.00 649965.00 70 15 27.193 N 148 47 16.404 W S err -Sun ! P Y BP Planning Report Company: BP Amoco Date: 8/10/2006 Time: 14:56:04 Page: 2 Field: Prudhoe Bay Caordinate(NE) Reference:. W eIL• A-05, True North Site: PB A Pad Vertical (TVD) Reference: 46. 17+28.5 74.7 Well: A-05 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: Plan A-05A Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <-- Latitude - --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec: Dip. I)ir. ft ft ft ft ft A-05A T1 9034 .67 -1430 .00 -5160 .00 5947015.52 649332.80 70 15 44.728 N 148 47 33.772 W A-05A Poly 9034 .67 -1430 .00 -5160 .00 5947015.52 649332.80 70 15 44.728 N 148 47 33.772 W -Polygon 1 9034 .67 -1059 .13 -4735 .07 5947395.00 649750.00 70 15 48.378 N 148 47 21.414 W -Polygon 2 9034 .67 -1519 .57 -5694 .79 5946915.00 648800.00 70 15 43.843 N 148 47 49.333 W -Polygon 3 9034 .67 -3811 .66 -4406 .45 5944650.00 650135.00 70 15 21.309 N 148 47 11.804 W -Polygon 4 9034 .67 -3588 .36 -4076 .78 5944880.00 650460.00 70 15 23.507 N 148 47 2.217 W -Polygon 5 9034 .67 -1609 .21 -5226 .50 5946835.00 649270.00 70 15 42.965 N 148 47 35.704 W -Polygon 6 9034 .67 -1364 .09 X741 .33 5947090.00 649750.00 70 15 45.379 N 148 47 21.590 W A-05A T3 9044. 67 -2681. 14 -4903 .40 5945770.00 649615.00 70 15 32.424 N 148 47 26.282 W A-05A T5 9044. 67 -3623. 53 -4312 .56 5944840.00 650225.00 70 15 23.160 N 148 47 9.076 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg. ft ft ft deg/100ft deg/100ft deg/100ft deg 8200.00 47.96 252.91 6765.80 -1040.77 -3326.66 0.00 0.00 0.00 0.00 8220.00 48.21 256.12 6779.17 -1044.74 -3341.00 12.00 1.27 16.04 85.00 8545.31 35.42 259.75 7021.16 -1090.82 -3552.41 4.00 -3.93 1.11 170.63 10800.39 35.42 259.75 8858.90 -1323.48 -4838.47 0.00 0.00 0.00 0.00 11197.39 90.00 247.00 9034.67 -1430.00 -5160.00 14.00 13.75 -3.21 -15.51 A-05A T1 11906.07 96.82 147.72 8977.51 -2021.72 -5347.69 14.00 0.96 -14.01 -83.09 11971.41 96.82 147.72 8969.74 -2076.57 -5313.04 0.00 0.00 0.00 0.00 12056.72 90.00 147.70 8964.67 -2148.52 -5267.57 8.00 -8.00 -0.02 -179.85 A-05A T2 12171.12 81.15 145.36 8973.49 -2243.57 -5204.75 8.00 -7.74 -2.05 -165.28 12559.77 81.15 145.36 9033.27 -2559.50 -4986.44 0.00 0.00 0.00 0.00 12707.64 90.00 146.00 9044.67 -2681.14 -4903.40 6.00 5.98 0.44 4.18 A-05A T3 12871.65 99.71 147.61 9030.81 -2817.71 -4814.02 6.00 5.92 0.98 9.30 13182.45 99.71 147.61 8978.38 -3076.39 -4649.89 0.00 0.00 0.00 0.00 13344.69 90.00 148.30 8964.67 -3213.25 -4564.22 6.00 -5.98 0.43 175.89 A-05A T4 13541.61 78.19 148.52 8984.90 -3379.80 -4461.79 6.00 -6.00 0.11 178.94 13833.58 78.19 148.52 9044.67 -3623.53 -4312.56 0.00 0.00 0.00 0.00 A-05A T5 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 8200.00 47.96 252.91 6765.80 6691.13 1040.77 -1040.77 -3326.66 0.00 5947442.25 651157. 63 MWD+IFR 8220.00 48.21 256.12 6779.17 6704.50 1044.74 -1044.74 -3341.00 12.00 5947437.99 651143. 38 MWD+IFR 8300.00 45.05 256.85 6834.09 6759.42 1058.34 -1058.34 -3397.54 4.00 5947423.23 651087. 14 MWD+IFR 8400.00 41.12 257.90 6907.11 6832.44 1073.29 -1073.29 -3464.18 4.00 5947406.92 651020. 82 MWD+IFR 8500.00 37.19 259.12 6984.64 6909.97 1085.89 -1085.89 -3526.03 4.00 5947393.05 650959. 24 Start Dir 1 8520.00 36.41 259.39 7000.66 6925.99 1088.13 -1088.13 -3537.80 4.00 5947390.58 650947. 52 Start Dir 4/ 8545.31 35.42 259.75 7021.16 6946.49 1090.82 -1090.82 -3552.41 4.00 5947387.59 650932. 98 MWD+IFR 8600.00 35.42 259.75 7065.72 6991.05 1096.46 -1096.46 -3583.59 0.00 5947381.31 650901. 91 MWD+IFR 8700.00 35.42 259.75 7147.22 7072.55 1106.78 -1106.78 -3640.62 0.00 5947369.82 650845. 11 MWD+IFR 8752.09 35.42 259.75 7189.67 7115.00 1112.15 -1112.15 -3670.33 0.00 5947363.84 650815. 52 CM1 8800.00 35.42 259.75 7228.71 7154.04 1117.09 -1117.09 -3697.65 0.00 5947358.34 650788. 31 MWD+IFR 8828.85 35.42 259.75 7252.22 7177.55 1120.07 -1120.07 -3714.11 0.00 5947355.03 650771. 92 End Dir 8900.00 35.42 259.75 7310.20 7235.53 1127.41 -1127.41 -3754.68 0.00 5947346.85 650731. 51 MWD+IFR 9000.00 35.42 259.75 7391.70 7317.03 1137.73 -1137.73 -3811.71 0.00 5947335.37 650674. 71 MWD+IFR 9100.00 35.42 259.75 7473.19 7398.52 1148.05 -1148.05 -3868.74 0.00 5947323.89 650617. 91 MWD+IFR 9144.76 35.42 259.75 7509.67 7435.00 1152.66 -1152.66 -3894.27 0.00 5947318.75 650592. 48 THRZ 9200.00 35.42 259.75 7554.69 7480.02 1158.36 -1158.36 -3925.77 0.00 5947312.40 650561. 11 MWD+IFR 9300.00 35.42 259.75 7636.18 7561.51 1168.68 -1168.68 -3982.80 0.00 5947300.92 650504. 30 MWD+IFR 9353.37 35.42 259.75 7679.67 7605.00 1174.19 -1174.19 -4013.24 0.00 5947294.79 650473. 99 BHRZ 9384.04 35.42 259.75 7704.67 7630.00 1177.35 -1177.35 -4030.73 0.00 5947291.27 650456. 57 LCU Went S err -Sun A Y BP Planning Report Company: BP Amoco Date: 8/10/2006 '15me: 14:56:04 Page: 3 '` Field: Prudhoe Bay Co-ordinatetNE}References W e1L• A-05, True North Site:. PB A Pad Vertical (TVD) Reference: 46. 17+28.5 74.7 WeIL• A-05 Section (VS) Reference: Well (O.OON,O.OOE,1 80.OOAzi) , Wellpath: Plan A-05A Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Incl Azim TVD Sys TVD V5 N/S E/W DLS MapN MapE TooUGo ft deg deg ft ft ft ft ft deg/100ft ft ft 9400.00 35.42 259.75 7717.67 7643.00 1179.00 -1179.00 -4039.83 0.00 5947289.43 650447.50 MWD+IFR 9500.00 35.42 259.75 7799.17 7724.50 1189.31 -1189.31 -4096.86 0.00 5947277.95 650390.70 MWD+IFR 9600.00 35.42 259.75 7880.66 7805.99 1199.63 -1199.63 -4153.89 0.00 5947266.47 650333.90 MWD+IFR 9700.00 35.42 259.75 7962.15 7887.48 1209.95 -1209.95 -4210.92 0.00 5947254.98 650277.10 MWD+IFR 9715.36 35.42 259.75 7974.67 7900.00 1211.53 -1211.53 -4219.68 0.00 5947253.22 650268.37 TJF 9788.98 35.42 259.75 8034.67 7960.00 1219.13 -1219.13 -4261.67 0.00 5947244.76 650226.55 TJE (grids 9800.00 35.42 259.75 8043.65 7968.98 1220.27 -1220.27 -4267.95 0.00 5947243.50 650220.30 MWD+IFR 9900.00 35.42 259.75 8125.14 8050.47 1230.58 -1230.58 -4324.98 0.00 5947232.01 650163.49 MWD+IFR 10000.00 . 35.42 259.75 8206.63 8131.96 1240.90 -1240.90 -4382.01 0.00 5947220.53 650106.69 MWD+IFR 10100.00 35.42 259.75 8288.13 8213.46 1251.22 -1251.22 -4439.04 0.00 5947209.04 650049.89 MWD+IFR 10200.00 35.42 259.75 8369.62 8294.95 1261.53 -1261.53 -4496.06 0.00 5947197.56 649993.09 MWD+IFR 10236.87 35.42 259.75 8399.67 8325.00 1265.34 -1265.34 -4517.09 0.00 5947193.33 649972.15 TJD 10300.00 35.42 259.75 8451.11 8376.44 1271.85 -1271.85 -4553.09 0.00 5947186.08 649936.29 MWD+IFR 10396.39 35.42 259.75 8529.67 8455.00 1281.80 -1281.80 -4608.07 0.00 5947175.01 649881.54 TJC 10400.00 35.42 259.75 8532.61 8457.94 1282.17 -1282.17 -4610.12 0.00 5947174.59 649879.49 MWD+IFR 10500.00 35.42 259.75 8614.10 8539.43 1292.48 -1292.49 -4667.15 0.00 5947163.11 649822.69 MWD+IFR 10525.24 35.42 259.75 8634.67 8560.00 1295.09 -1295.09 -4681.55 0.00 5947160.21 649808.35 TJB 10600.00 35.42 259.75 8695.60 8620.93 1302.80 -1302.80 -4724.18 0.00 5947151.62 649765.88 MWD+IFR 10660.22 35.42 259.75 8744.67 8670.00 1309.01 -1309.01 -4758.52 0.00 5947144.71 649731.68 TJA 10700.00 35.42 259.75 8777.09 8702.42 1313.12 -1313.12 -4781.21 0.00 5947140.14 649709.08 MWD+IFR 10764.52 35.42 259.75 8829.67 8755.00 1319.78 -1319.78 -4818.01 0.00 5947132.73 649672.43 TSGR 10770.66 35.42 259.75 8834.67 8760.00 1320.41 -1320.41 -4821.51 0.00 5947132.02 649668.95 7" 10795.20 35.42 259.75 8854.67 8780.00 1322.94 -1322.94 -4835.50 0.00 5947129.21 649655.01 TSHA 10796.01 35.42 259.75 8855.33 8780.66 1323.02 -1323.02 -4835.97 0.00 5947129.11 649654.55 Start Dir 1 10800.00 35.42 259.75 8858.58 8783.91 1323.44 -1323.44 -4838.24 0.00 5947128.65 649652.28 MWD+IFR 10831.63 39.65 257.91 8883.67 8809.00 1327.18 -1327.18 -4857.13 13.83 5947124.53 649633.48 TSHB 10856.95 43.09 256.65 8902.67 8828.00 1330.87 -1330.87 -4873.45 14.00 5947120.50 649617.24 TSHC 10895.65 48.38 255.01 8929.67 8855.00 1337.66 -1337.66 -4900.30 14.00 5947113.16 649590.53 TSAD 10900.00 48.98 254.84 8932.54 8857.87 1338.51 -1338.51 -4903.46 14.00 5947112.24 649587.39 MWD+IFR 10935.49 53.85 253.58 8954.67 8880.00 1346.07 -1346.07 -4930.14 14.00 5947104.15 649560.87 TSAD at 2 d 11000.00 62.73 251.64 8988.55 8913.88 1362.49 -1362.49 -4982.44 14.00 5947086.65 649508.92 MWD+IFR 11100.00 76.53 249.15 9023.28 8948.61 1393.95 -1393.95 -5070.50 14.00 5947053.39 649421.53 MWD+IFR 11197.39 90.00 247.00 9034.67 8960.00 1430.00 -1430.00 -5160.00 14.00 5947015.52 649332.80 A-05A T1 11200.00 90.04 246.64 9034.67 8960.00 1431.03 -1431.03 -5162.40 14.00 5947014.44 649330.42 MWD+IFR 11300.00 91.71 232.73 9033.13 8958.46 1481.37 -1481.37 -5248.51 14.00 5946962.35 649245.37 MWD+IFR 11400.00 93.28 218.81 9028.75 8954.08 1550.88 -1550.88 -5319.92 14.00 5946891.40 649175.40 MWD+IFR 11500.00 94.65 204.84 9021,80 8947.13 1635.42 -1635.42 -5372.40 14.00 5946805.80 649124.67 MWD+IFR 11600.00 95.75 190.83 9012.69 8938.02 1729.98 -1729.98 -5402.84 14.00 5946710.64 649096.18 MWD+IFR 11700.00 96.51 176.77 9001.96 8927.29 1828.93 -1828.93 -5409.41 14.00 5946611.58 649091.64 MWD+IFR 11800.00 96.88 162.68 8990.24 8915.57 1926.40 -1926.40 -5391.74 14.00 5946514.50 649111.31 MWD+IFR 11900.00 96.84 148.57 8978.23 8903.56 2016.60 -2016.60 -5350.87 14.00 5946425.17 649154.02 MWD+IFR 11906.07 96.82 147.72 8977.51 8902.84 2021.72 -2021.72 -5347.69 14.00 5946420.11 649157.30 MWD+IFR 11912.29 96.82 147.72 8976.77 8902:10 2026.94 -2026.94 -5344.39 0.00 5946414.96 649160.71 End Dir : 1 1 11971.41 96.82 147.72 8969.74 8895.07 2076.57 -2076.57 -5313.04 0.00 5946365.99 649193.07 MWD+IFR 11977.63 96.33 147.72 8969.03 8894.36 2081.79 -2081.79 -5309.74 8.00 5946360.84 649196.47 Start Dir 8/ 12000.00 94.54 147.71 8966.92 8892.25 2100.62 -2100.62 -5297.85 8.00 5946342.26 649208.75 MWD+IFR 12056.72 90.00 147.70 8964.67 8890.00 2148.52 -2148.52 -5267.57 8.00 5946295.00 649240.00 A-05A T2 12100.00 86.65 146.82 8965.93 8891.26 2184.90 -2184.90 -5244.18 8.00 5946259.11 649264.13 MWD+IFR 12171.12 81.15 145.36 8973.49 8898.82 2243.57 -2243.57 -5204.75 8.00 5946201.27 649304.76 MWD+IFR 12177.34 81.15 145.36 8974.44 8899.77 2248.62 -2248.62 -5201.25 0.00 5946196.28 649308.35 End Dir : 1 12200.00 81.15 145.36 8977.93 8903.26 2267.04 -2267.04 -5188.52 0.00 5946178.13 649321.46 MWD+IFR 12300.00 81.15 145.36 8993.31 8918.64 2348.33 -2348.33 -5132.35 0.00 5946098.01 649379.28 MWD+IFR nent 7S 7S 9S 7S T 7S QS 4S ~S 1S 1S 1S 1S 1S 1S 0 1S 1S wel 1S 1S 11 1S 0 1S 1S 1S 7 • S err -Sun P Y BP Planning Report Company: BP Amoco Date: 8/10/2006 Timer 14:56:04. Pager 4 .Field: Prudhoe Bay Co-ordinate(NE) Reference: W elf: A-0S, True North Site: PB A Pad Vertical (TVD) Reference: 46,17+28.5 74:7 Well: A-05 Section (VS) Reference: Well (O,OON>O.OOE,180.OOAzi) Wellpath: Plan A-0SA Survey Calculation Method: . Minimum Curvature DbE Oracle Survey MI) ft 12400.00 12500.00 12559.77 12565.99 12600.00 12609.75 12700.00 12707.64 12800.00 12871.65 12877.86 12900.00 13000.00 13100.00 13182.45 13188.67 13200.00 13300.00 13344.69 13400.00 13500.00 13541.61 13547.83 13600.00 13700.00 13800.00 13833.00 13833.58 Incl deg Azim deg TVD ft Sys TVD ft VS ft N/S ft E/W ft DIS deg/100ft MapN ft 81.15 145 .36 9008.70 8934. 03 2429. 62 -2429. 62 -5076.18 0.00 5946017. 90 81.15 145 .36 9024.08 8949. 41 2510. 91 -2510. 91 -5020.01 0.00 5945937. 78 81.15 145 .36 9033.27 8958. 60 2559. 50 -2559. 50 -4986.44 0.00 5945889. 90 81.52 145 .38 9034.21 8959. 54 2564. 56 -2564. 56 -4982.94 6.00 5945884. 91 83.56 145 .53 9038.63 8963. 96 2592. 34 -2592. 34 -4963.82 6.00 5945857. 54 84.14 145 .58 9039.67 8965. 00 2600. 33 -2600. 33 -4958.34 6.00 5945849. 66 89.54 145 .97 9044.64 8969. 97 2674. 81 -2674. 81 -4907.67 6.00 5945776. 24 90.00 146 .00 9044.67 8970. 00 2681. 14 -2681. 14 -4903.40 6.00 5945770. 00 95.47 146 .90 9040.27 8965. 60 2758. 00 -2758. 00 -4852.43 6.00 5945694. 21 99.71 147. 61 9030.81 8956. 14 2817. 71 -2817. 71 -4814.02 6.00 5945635. 30 99.71 147. 61 9029.76 8955. 09 2822. 88 -2822. 88 -4810.74 0.00 5945630. 20 99.71 147. 61 9026.02 8951. 35 2841. 31 -2841. 31 -4799.04 0.00 5945612. 02 99.71 147. 61 9009.16 8934. 49 2924. 54 -2924. 54 -4746.24 0.00 5945529. 90 99.71 147. 61 8992.29 8917. 62 3007. 76 -3007. 76 -4693.43 0.00 5945447. 77 99.71 147. 61 8978.38 8903. 71 3076. 39 -3076. 39 -4649.89 0.00 5945380. 06 99.34 147. 63 8977.36 8902. 69 3081. 57 -3081. 57 -4646.60 6.00 5945374. 95 98.66 147. 68 8975.58 8900. 91 3091. 02 -3091. 02 -4640.62 6.00 5945365. 63 92.67 148. 11 8965.71 8891. 04 3175. 28 -3175. 28 -4587.76 6.00 5945282. 48 90.00 148. 30 8964.67 8890. 00 3213. 25 -3213. 25 -4564.22 6.00 5945245. 00 86.68 148. 36 8966.27 8891. 60 3260. 30 -3260. 30 -4535.20 6.00 5945198. 56 80.68 148. 47 8977.27 8902. 60 3344. 93 -3344. 93 -4483.17 6.00 5945115. 02 78.19 148. 52 8984.90 8910. 23 3379. 80 -3379. 80 -4461.79 6.00 5945080. 59 78.19 148. 52 8986.17 8911. 50 3384. 99 -3384. 99 -4458.61 0.00 5945075. 47 78.19 148. 52 8996.85 8922. 18 3428. 54 -3428. 54 -4431.95 0.00 5945032. 48 78.19 148. 52 9017.32 8942. 65 3512. 02 -3512. 02 -4380.84 0.00 5944950. 07 78.19 148. 52 9037.80 8963. 13 3595. 50 -3595. 50 -4329.73 0.00 5944867. 67 78.19 148. 52 9044.55 8969. 88 3623. 05 -3623. 05 -4312.86 0.00 5944840. 47 78.19 148. 52 9044.67 8970. 00 3623. 53 -3623. 53 -4312.56 0.00 5944840. 00 MapE TooUC~ ft 649437.10 MWD+IFf 649494.93 MWD+IFf 649529.49 MWD+IFf 649533.08 Start Dir E 649552.77 MWD+IFf 649558.41 Top HOT 649610.60 MWD+IFf 649615.00 A-05A T3 649667.53 MWD+IFf 649707.16 MWD+IFf 649710.54 End Dir 649722.61 MWD+IFf 649777.11 MWD+IFf 649831.61 MWD+IFf 649876.54 MWD+IFf 649879.93 Start Dir E 649886.11 MWD+IFf 649940.69 MWD+IFf 649965.00 A-05A T4 649994.98 MWD+IFf 650048.73 MWD+IFf 650070.81 MWD+IFF 650074.10 End Dir 650101.65 MWD+IFf 650154.46 MWD+IFf 650207.27 MWD+IFf 650224.69 41/2" 650225.00 A-05A T5 = 7-1/16"5M CM! 'LHEAD ~ f-518' ' MCEVOY-CONY _ CTUATOR = ~ __O_TIS . ELEV = 65.89' F. ELEV = _ 46.17' OP = _ 2800' x Angle = tum_MD =_ tum TV D = ~Y~ 54' ___ 10_8_52' v 8800' SS Minimum ID = 3.725" ~ 10600' 4-1 /2" HES XN NIPPLE 13-3/8" CSG, 72#, N-80 2018' BTRS, ID = 12.347" 20" CSG, 133#/ft, 2278' K-55 BTRS, ID = 18.730" Top of Tie-back Cement 2778' Top of 9-5/8" Window 8200' 7" liner cut ~ 8500' 4-1/2", 12.6#, L-80 Tbg cut (~ 8700' TOP OF 40' TMI PBR 9272' Est top of P8A Cement 9000' 9-518" X 7" TNV LNR TOP PKR/HGR W/40' PBR 9312' '.~-bJS" I t3G 4/iF L-SU .0/32 b t ID = 6.661" PERFORATION SUMMARY REF LOG: BRCS 04!09/72 ANGLEATTOPPERF: 23 ~ 10806' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-118" 4 10806 - 10826 S 08/08/91 4" 4 10914 - 10924 S 08/08!91 4" 4 10932 - 10942 S 08/08/91 4" 4 10952 - 10964 S 08/08/91 4" 4 10974 - 10994 S 08!08/91 3-3/8" 6 10806 - 10826 O 09/19/91 3-3/8" 6 10912 - 10942 O 08/15!91 • A -O 5 ~ SAFETY N~: 9-5/8" CSG SET ON EM ERGENCY SLIPS. WARNING: 10 TRANSMITTER IN WEATHER Proposed Completion MONITORINGSHACKMUSTBETURNEDOFFBEFORE ANY WELLWORK INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD OPERATOR 44' 9-5l8" X 7" XO, ID = 6.06" 1554' 18-5/8" X 20" XO 1839' 13-3i8" X 9-5/8" TNV PKR 1846' TOP OF 9-5/8" PBR (12') 1857' BOTTOM 9-5/8" SEAL ASSEMBLY 2018' BOTTOM 9-5l8" DUPLEX SHOE ', 10540' 4 1/2" X Nipple (3.813" ID) 10580' 7" x 4 1/2" Baker S3 Packer 10580' 4 1/2" X Nipple (3.813" ID) 10800' 4 1 /2" XN Nipple (3.725" ID) 10620' 4 1/2" WLEG 10770' 7" 26# L-80 (6.276" ID) 9-5/4-1/2", 12.6#, L-80, IBT-M Production Liner 13833' i :~ 9340' 4-1/2" CUT OFF TBG STUB • • ' 9341' S-3/4" CUSTOM OVERSHOT, ID = 4.655" ~~ a' 9348' 7" BKR SABL-3 PKR W/ KBH-22 ANCHOR, ID = 3.875" ~a s 14' 10516' 4-1/2" WLEG ;• A 41 /2" TBG, 12.6#, L-80 NSCT, 10516' .0152 bpf, ID = 3.958" PBTD 11259' DATE REV BY COMMENTS DATE REV COMMENTS 10/29/77 ORIGINAL COMPLETION 05!09/01 CWKAK CORRECTIONS 08/08/91 RWO 11/17!02 BNVKAK 9-5/8" TBG DEPTH CORRECTIO 12/11/94 RWO 11 /16/95 RWO 01/22/01 SIS-MH CONVERTED TO CANVAS 03/02101 SIS-LG FINAL ~2 SLIPS OFF SCAB LNR ON BTM (11/16/95) PRUDHOE BAY UNfr WELL: A-05 PERMff No: 1720080 API No: 50-029-20116-00 SEC 35, T11 N, R13E, 1895' FNL & 922' FEL BP Exploration (Alaska) E= 7-1/16"SMCNV _LHEA D g 1-5/8" MCEVOY-CONY ~ SAFETY N~ 9~/8" CSG SET ON EM ERGENCY SLIPS. IUATOR = OTB A ~O 5 / WARNING: O TRANSMITTER IN WEATHER ELEV = 65.89' MONITORING SHACK M UST BE TURNED OFF BEFORE ELEV = 46.1 T ANY WELLWORK INVOLVING EXPLOSIVES CAN BEGIN. '= 2~' CONTACT PAD OPERATOR Angle = 54' im MD = 10857 44' 9-5/8" X 7" XO, O = 8.06" im TV D = 8800' SS 1554' 18-s/e" X 20" x0 1838' ~-~ 13-3/8" X 9-5/8" TNV PKR 13-3/8" CSG, 72#, N-8o 2018' BTRS, ID = 12.347' Minimum ID = 3.725" ~ 9328' 4-1/2" HES XN NIPPLE 20" CSG, 133#/ft, 2278' K-55 BTRS, ID = 18.730" TBG, 12.8#, L-80 NSCT, .0152 bpf, ID = 3.958" ESTIMATED TOP OF CEMENT 8$00' 1857' H BOTTOM 9-5/8" SEAL ASSEMBLY 2018' BOTTOM 9-5/8" DUPLEX SHOE 2213' ~-{4-1/2" HES X Nom, IS = 3.813" 9190' ~4-1/2" HES X NtP, ID = 3.813" 8200' T' BAKER S-3 PKR, ID = 3.875' TOP OF 4tY TM/ PBR H 9272' NOTE: HOLES IN T' LNR BETWEEN T' BKR STRADDLE ` PKRS (10420-10468). PROD LOG OF 03/03/96 FOUND LEAKS ~ 9285' (BTM OFT' SCAB LNR 89336') (5-3/4" OVERSHOT ON4-1/2" TBG) X 7" TNV LNR TOP PKR/HGR W/40' PBR H s312' 8283' H BTM OF T' TIEBACK STINGER 9308' - -~4-1/2" HES X NIP, ID = 3.813" 9318' ELMDTTLOGNOTAVAILABLE 9328' 4-1/2" HES XN NIP, ID = 3.725" 9340' 4-1/2" CUT OFF TBG STUB 9341' 5-3/4" CUSTOM OVERSHOT, ID = 4.655" = 14' ~ g$48' 7" BKR SABL-3 PKR W/ KBH-22 ANCHOR O = 3 875" , . PERFORATION SUMMARY REF LOG: BHCS O4~9l72 NOTE RWO OF 11 /16/95 LEFT OLD 7" BKR SABL-3 ANGLEAT TOP PERF: 23 ~ 10806' STRADDLE PKRS IN WELL. NEW 3.725" O XN NIP PREVENTS Note: Refer to Productan DB for historical perf data VWL ACCESS FOR STD PLUG SETS ON LOWER NAPLES. S¢E SPF INTERVAL OpnlSgz DATE 3-1 /8" 4 10806 - 10826 S 08/08/91 10449' 4-1/2" HES X NIP, ID = 3.813" " 4 " 4 10914 - 10924 S 08/08/91 10472' 7' BKR SABL-3 PKR W/ HY D S HEA R A NCHOR, ID = 3.875" 4 4 10932 - 10942 S 08/08/91 4" 4 10952 - 10984 S 08/08/91 10488' 4-1/2" HES X NIP, O = 3.813" 4" 4 10974 -10994 S 08/08/91 3-3/8" 8 10806 -10828 C 09/19/91 10504' 4-1/2" HE3 XN NIP, ID = 3.725" 3-3/8" 6 10912 -10942 C 08/15/91 10604' 4-1/2" PXN TTP (10/16/02) 10518' 4-1/2" WLEG 10500' ELMD TT LOGGED03103/96 10734' MARKER JOpVT (2t7) 4117' TBG, 12.6N, L-80 NSCT, 10516' .0152 bpf, ID = 3.958" 11259' 2 BLIPS OFF SCAB LNR ON BTM (11/18/95) PBTD 11259' DATE REV BY COMMENTS DATE REV BY COIIINIENTS PRUDFIOE BAY UNIT 10/28/77 t>tiltilNAL COMPLETION MR/TLH TIP SET (10/16f02) WELL' A-05 08/08/81 RINO PERMT No: 1720080 12N1/84 RWO API No: 50-029.20118.00 11/i SEC 35, 711 N, R13E, 1886' FNL 8 927 FEL BP 6rploration (Alaskay • Terri Hubble BP Exploration AK Inc PO Box 1966T2 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF "Mastercard Check" ~lJ First National Bank Alaska Anchorage, AK 99CC5O1 MEMO~i ~J • as-s~r2ez 298 DATE ~ ' - T $ 10C~ . °~ ~: L 2 5 200060:99 L46 2 2 7 L 5 56~~' 0 298 • .7 TRANSMITTAL LETTER C'~IECKLIST WELL NAME ~ ~ Qrj -j~ PTD# Zc~.- /Z~ Development \~~Service Ex lorato Strat' P ry igraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-ONS WHAT i (OPTIONS) APPLIES J TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing ~ ~ well (If last two digits in ~ permit No. , API No. 50- API number a - - a between 60-69) re ~ Production should continue to be reported as a function of the I original API number stated above. r PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both ~ well name ( PH) and API number (~0- - -__) from records, data and logs f acquired for well SPACING ~ The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the I liability of any protest to the spacing exception that may occur. DRY DITCH j All dry ditch sample sets submitted to the Commission must be in SAMPLE i no greater than 30' sample intervals from below the permafrost or ;' from where samples are first caught and 10' sample intervals I through target zones. i Non-Conventional Please note the following special condition of this permit: Well i production or production testing of coal bed methane is not allowed i for (name of well) until after (Company Name) has designed and I ! implemented a water well testing program to provide baseline data ~ ~ on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing j I program. I Rev: 1 %2~i06 C:\jodyltransmittal checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 PTD~:2061280 Company BP EXPLORATION (ALASKA) INC _ _ _ __ Initial ClasslType _ Well Name: PRUDHOE BAY U_N_ IT A-05A Program SER __ ___ Well bore seg SER!WAGIN _ GeoArea 890 ___ ________ _ Unit 11650__.. ______ On1Off Shore On Annular Disposal ',; Administration '1 Permit fee attached Yes _ _ ~2 Lease number appropriate Yes I3 Unique well-name and number Yes ~4 Well located in a_defined pool _ Yes 115 Well located proper dstancefrom drilling unit boundary- Yes '6 Well located proper distance_f[om other wells. Yes 7 Sufficient acreage available in drilling unit- Yes I8 If deviated, is_wellbore plat included Yes 119 Operator only affected party.... Yes ',10 Operator has_appropriate bond in force Yes 11 Permit can be issued without conservation order Yes 12 Permit. can be issued without administrative_approval _ _ Yes _ Appr Date i 13 Can permit be approved before 15-daywait Yes RPC 916/2006 !14 Well located within area and strata authorized by Injection Order # (put 10# in_comments)_(For Yes AIO -3 15 All wells within 1l4_mile area of review identified (For service well only) Yes A-16, Y-34A, Y-35A 1,16 Pre-produced injector; duration ofpre-production less_than_3 months (forseryceweltonly) NA_ _ 117 Nonconven, gas conforms to AS31 05.030(j.1.A),Q.2.A-D) _ NA_ X18 Conducto[string_pravided NA_ Engineering !19 Surface casing_protectsoll known USDWs NA_ '20 CMT vol. adequate to circulate on conductor_& surf csg NA_ 21 CMT vol_ adequate. to tie-in long string to surf csg _ _ _ NA _ _ _ _ _ _ 1122 CMT. will coyer all known productive horizons. Yes Adequate excess. 1 23 Casing designs adequate for C, T, B & permafrost Yes 1 24 Adequate tankage_or reserve pit Yes Nabors 2ES.. '125 If a.re-drill, has_a_ 10-403 for abandonment been approved Yes _ _ _ _ _ 8/2212006..... 26 Adequate wellbore separation.proposed Yes 1,27 If diverter required, does it meet- regulations NA_ Sidetrack. ;28 Drilling fluid_program schematic.&_equip list adequate Yes Max MW 10.9ppg. Appr Date 129 BOPEs, do they meet. regulation Yes _ WGA 917!2006 30 BOPE press rating appropriate; test to_(put psig in comments) Yes - - - - - Test to 4000. psi. _M$f? 2397 psi.- ',31 Choke manifold complies w/API_RP-53 (May 84)_ _ _ _ _ Yes X132 Work will occur w~hout operation shutdown _ _ _ _ _ _ _ _ - - _ Yes _ _ _ _ _ _ _ 33 Is presence_of H2S gas. probable. _ Yes 90 ppm on pad recently.. 134 Mechanical condition of wells within AOR verified (For_service well only) Yes All_AOR wells reviewed. ~,35 Permit. can be issued w/o_ hydrogen sulfide measures No _ - -- --- Geology X36 Data_presented on potential overpressure zones NA 37 Seismic analysis of shallow gas zones_ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ Appr Date !38 Seabed condition survey_(ifoff-shore) NA_ _ _ RPC 9/6/2006 1139 Contact namelphone for weekly progress reports [exploratory only] NA_ Geologic Engineering P Date: Date Date Commissioner: Commissioner: C miss' e s Well I-iistory File APPENDIX i Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~.J Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 25 11:10:18 2007 Reel Header Service name ............. LISTPE Date ..................... 07/07/25 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number...... 01 Previous Reel Name....... UNKNOWN Comments ................. STS LIS Writing Library Tape Header Service name ............. LISTPE Date ..................... 07/07/25 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Writing Library Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 1 JOB NUMBER: W-0004799186 LOGGING ENGINEER: M. BUCKLEY OPERATOR WITNESS: D. MASKELL MWD RUN 4 JOB NUMBER: W-0004799186 LOGGING ENGINEER: M. BUCKLEY OPERATOR WITNESS: W. DECKER SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • Scientific Technical Services Scientific Technical Services A-OSAi 500292011601 BP Exploration (Alaska) Inc Sperry Drilling Services 25-JUL-07 MWD RUN 2 MWD RUN 3 W-0004799186 W-0004799186 M. BUCKLEY M. BUCKLEY D. MASKELL W. DECKER MWD RUN 5 W-0004799186 O. OBI W. DECKER 35 11N 13E 1896 923 74.67 46.17 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8206.0 2ND STRING 6.125 7.000 10843.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE use a~(o- ~~'~ ~ ~ sorb NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE A-OS WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 8206'MD/6770'TVD. THE WHIPSTOCK WAS POSITIONED, THE WAS WINDOW MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. 4. MWD RUNS 1,2 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. UPHOLE TIE-IN GAMMA DATA WERE ACQUIRED WHILE POOH AFTER REACHING TD FOR MWD RUN 2. THESE MAD DATA WERE MERGED WITH RUN 1 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 5. MWD RUNS 3-5 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND AT-BIT INCLINATION (ABI) EWR4 MAD PASS DATA WERE ACQUIRED OVER MOST OF THE MWD RUN 3 INTERVAL (11690'MD-11027'MD, BIT DEPTHS) WHILE POOH AFTER REACHING TD FOR MWD RUN 4. THESE MAD DATA WERE SUBSTITUTED FOR RUN 3 MWD DATA BECAUSE THE RUN 3 EWR4 MWD DATA WERE DEEMED INVALID. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE BLOCK SHIFTED 8.77'(9') DEEPER, PER E-MAIL INSTRUCTIONS PROVIDED TO SDS BY D. DORTCH ON 14 JUNE 2007. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THE BLOCK-SHIFTED SGRC LOG IS CONSIDERED THE PDC LOG FOR A-OSAI. 7. MWD RUNS 1-5 REPRESENT WELL A-OSAI WITH API#: 50-029-20116-01. THIS WELL REACHED A TOTAL DEPTH (TD)OF 14180'MD/9067'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. File Header Service name ........... ..STSLIB.001 Service Sub Level Name. .. Version Number......... ..1.0.0 Date of Generation..... ..07/07/25 Maximum Physical Record ..65535 File Type .............. ..LO Previous File Name..... ..STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 • • FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 7928.0 14132.0 ROP 8215.5 14189.0 RPX 10985.5 14139.0 FET 10985.5 14139.0 RPS 10985.5 14139.0 RPD 10985.5 14139.0 RPM 10985.5 14139.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 7927.8 7919.0 14188.8 14180.0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 1 7919.0 8234.0 2 8234.0 10843.0 3 10843.0 11690.0 4 11690.0 12805.0 5 12805.0 14180.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7928 14189 11058.5 12523 7928 14189 RPD MWD OHMM 1.74 91.27 6.86436 6308 10985.5 14139 RPM MWD OHMM 1.98 429.34 6.7565 6308 10985.5 14139 RPS MWD OHMM 1.66 57.13 6.48941 6308 10985.5 14139 RPX MWD OHMM 1.77 52.16 6.58439 6308 10985.5 14139 FET MWD HOUR 0.45 131.04 25.6388 6308 10985.5 14139 GR MWD API 15.17 446.52 82.6531 12409 7928 14132 ROP MWD FT/H 0.06 618.31 81.3074 11948 8215.5 14189 First Reading For Entire File..........7928 Last Reading For Entire File...........14189 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type.. . ..............LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7919.0 8196.0 ROP 8206.5 8234.0 LOG HEADER DATA DATE LOGGED: 17-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8234.0 TOP LOG INTERVAL (FT) 8206.0 BOTTOM LOG INTERVAL (FT) 8234.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 175785 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 8206.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) 54.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 1400 FLUID LOSS (C3) 9.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 127.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): • REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWDO10 API 4 1 68 4 2 ROP MWDO10 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7919 8234 8076.5 631 7919 8234 GR MWDO10 API 37.92 86.01 61.5556 555 7919 8196 ROP MWDO10 FT/H 0.15 16.04 3.54375 56 8206.5 8234 First Reading For Entire File..........7919 Last Reading For Entire File...........8234 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8196.5 10805.0 ROP 8234.5 10843.0 LOG HEADER DATA DATE LOGGED: 20-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10843.0 TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: 8234.0 10843.0 35.3 47.8 TOOL NUMBER 175785 8.500 8206.0 Lignosulfanate 10.60 49.0 9.6 4800 4.0 1.100 64.0 .440 169.0 1.050 64.0 1.000 64.0 Data Format Specification Record Data Record Type ............... ...0 Data Specification Block Type.. ...0 Logging Direction .............. ...Down Optical log depth units........ ...Feet Data Reference Point ........... ...Undefined Frame Spacing .................. ...60 .lIN Max frames per record .......... ...Undefined Absent value ................... ...-999 Depth Units .................... ... .Datum Specification Block sub-t ype...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD020 API 4 1 68 4 2 ROP MWD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8196.5 10843 9519.75 5294 8196.5 10843 GR MWD020 API 38.73 399.03 137.09 5218 8196.5 10805 ROP MWD020 FT/H 0.36 193.88 81.3738 5218 8234.5 10843 First Reading For Entire File..........8196.5 Last Reading For Entire File...........10843 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 • • File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10805.5 11633.5 ROP 10843.5 11690.0 LOG HEADER DATA DATE LOGGED: 29-JAN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11690.0 TOP LOG INTERVAL (FT) 10843.0 BOTTOM LOG INTERVAL (FT): 11690.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.4 MAXIMUM ANGLE: 98.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 ABI AT-BIT INCLINATION 130887 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 10843.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL. .MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Polymer 8.40 35.0 9.0 14000 .0 1.900 61.0 .630 197.0 2.400 61.0 1.900 61.0 • REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD030 API 4 1 68 4 2 ROP MWD030 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10805.5 11690 11247.8 1770 10805.5 11690 GR MWD030 API 15.88 446.52 58.0232 1657 10805.5 11633.5 ROP MWD030 FT/H 1.36 350.31 54.938 1694 10843.5 11690 First Reading For Entire File..........10805.5 Last Reading For Entire File...........11690 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB,005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 10976.5 12755.0 RPD 10976.5 12755.0 RPS 10976.5 12755.0 RPX 10976.5 12755.0 RPM 10976.5 12755.0 GR 11634.0 12748.0 ROP 11690.5 12805.0 LOG HEADER DATA DATE LOGGED: O1-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12805.0 TOP LOG INTERVAL (FT) 11690.0 BOTTOM LOG INTERVAL (FT) 12805.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 83.0 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 153663 ABI AT-BIT INCLINATION 10815493 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 10843.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.40 MUD VISCOSITY (S): 52.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 4200 FLUID LOSS (C3): 9.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.100 62.0 MUD AT MAX CIRCULATING TERMPERATURE: .520 1 97.0 MUD FILTRATE AT MT: .900 62.0 MUD CAKE AT MT: 1.300 62.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .1IN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10976.5 12805 11890.8 3658 10976.5 12805 RPD MWD040 OHMM 1.74 91.27 7. 59195 3558 10976.5 12755 RPM MWD040 OHMM 1.98 429.34 7. 68773 3558 10976.5 12755 RPS MWD040 OHMM 1.66 57.13 7.26315 3558 10976.5 12755 RPX MWD040 OHMM 1.77 52.16 7.40049 3558 10976.5 12755 FET MWD040 HOUR 0.45 131.04 43.4545 3558 10976.5 12755 GR MWD040 API 15.93 149.46 38.6737 2229 11634 12748 ROP MWD040 FT/H 1.09 265.22 83.8369 2230 11690.5 12805 First Reading For Entire File..........10976.5 Last Reading For Entire File...........12805 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/25 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12748.5 14123.0 FET 12755.5 14130.0 RPD 12755.5 14130.0 RPM 12755.5 14130.0 RPS 12755.5 14130.0 RPX 12755.5 14130.0 ROP 12805.5 14180.0 LOG HEADER DATA DATE LOGGED: 04-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 14180.0 TOP LOG INTERVAL (FT) 12805.0 BOTTOM LOG INTERVAL (FT) 14180.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 75.7 MAXIMUM ANGLE: 99.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 153663 ABI AT-BIT INCLINATION 10815493 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 10843.0 • • BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) 8.50 MUD VISCOSITY (S) 56.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 4800 FLUID LOSS (C3): 9.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 1.200 64.0 MUD AT MAX CIRCULATING TERMPERATURE: .580 140.0 MUD FILTRATE AT MT: 1.100 64.0 MUD CAKE AT MT: 1.300 64.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO50 OHMM 4 1 68 4 2 RPM MWDO50 OHMM 4 1 68 8 3 RPS MWDO50 OHMM 4 1 68 12 4 RPX MWDO50 OHMM 4 1 68 16 5 FET MWDO50 HOUR 4 1 68 20 6 GR MWDO50 API 4 1 68 24 7 ROP MWDO50 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12748.5 14180 13464.3 2864 12748.5 14180 RPD MWDO50 OHMM 2.19 14.92 5.92298 2750 12755.5 14130 RPM MWDO50 OHMM 2.03 15.28 5.55166 2750 12755.5 14130 RPS MWDO50 OHMM 1.89 14.13 5.48833 2750 12755.5 14130 RPX MWDO50 OHMM 1.82 13.29 5.52851 2750 12755.5 14130 FET MWDO50 HOUR 0.45 35.1 2.58847 2750 12755.5 14130 GR MWDOSO API 15.17 145.87 34.107 2750 12748.5 14123 ROP MWDO50 FT/H 0.06 618.31 96.9575 2750 12805.5 14180 First Reading For Entire File..........12748.5 Last Reading For Entire File...........14180 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number........... 1.0.0 Date of Generation....... 07/07/25 Maximum Physical Record.. 65535 File Type ................ LO Next File Name........... STSLIB.007 ~ ~ • Physical EOF Tape Trailer Service name .............LZSTPE Date .....................07/07/25 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/07/25 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
