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206-125
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, December 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC A-17A PRUDHOE BAY UNIT A-17A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/21/2022 A-17A 50-029-20520-01-00 206-125-0 W SPT 8702 2061250 2176 856 858 858 858 14 10 12 14 4YRTST P Kam StJohn 11/6/2022 30 MinPretest Initial 15 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-17A Inspection Date: Tubing OA Packer Depth 88 2405 2350 2331IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221108203731 BBL Pumped:6 BBL Returned:6 Wednesday, December 21, 2022 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:206-125 6.50-029-20520-01-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12157 12066 9018 10373 None None 8702 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 32 - 112 32 - 112 Surface 2613-3/8" 31 - 231 - 25380 2670 Intermediate 7817 9-5/8" 29 - 7846 29 - 7033 6870 4760 Liner 2948 7" 7664 - 10612 687 - 8850 7240 5410 Perforation Depth: Measured depth: 10797 - 11955 feet True vertical depth:8958 - 8996 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 27 - 10430 27 - 8737 10373 8702Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 1729 4-1/2" 10425 - 12158734 - 9035 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 00 0 0 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Semmens, Travis travis.semmens@bp.com Authorized Name:Semmens, Travis Authorized Title: Authorized Signature with Date:Contact Phone:+1 9072979672 Treatment descriptions including volumes used and final pressure: 13. Intervention & Integrity Engineer Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG 5 GINJ SUSP SPLUG 16. Well Status after work:Oil Gas Exploratory Development Stratigraphic 15. Well Class after work: 5Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9036 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend 5Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028286 & 047472 PBU A-17A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations By Samantha Carlisle at 1:44 pm, Jun 03, 2020 Travis Semmens Digitally signed by Travis Semmens Date: 2020.06.03 11:02:13 -08'00' MGR05JUN2020 DSR-6/3/2020 RBDMS HEW 6/3/2020 ACTIVITYDATE SUMMARY 4/26/2020 ***WELL S/I ON ARRIVAL*** (SLB ELINE PERFORATING) INTIAL T/I/0=200/0/0. BEGIN RIGGING UP & INSTALL WLV'S ON TREE. WIND SPEEDS GREATER THAN 30 MPH. WELL LEFT NIGHT CAPPED AND TESTED TO 200 PSI. FINAL T/I/0=200/0/0. ***JOB CONTINUED ON 27-APR-2020*** 4/27/2020 ***JOB CONTINUED FROM 26-APR-20*** (SLB ELINE PERFORATING) INTIAL T/I/O=150/0/0. CONTINUE RIGGING UP & PT TO 3900 PSI. RIH W/ 3-3/8" X 20' POWERJET HMX, 6 SPF, 60 DEG PHASE GUN. S/D AT 3320' MD AND UNABLE TO PASS. R/U LRS & PUMP 130 BBL'S OF HOT CRUDE DOWN TBG. S/D AT 3499' MD AND UNABLE TO PASS. POOH & RDMO. WELL LEFT S/I ON DEPARTURE. FINAL T/I/0=400/0/0 ***JOB INCOMPLETE ON 27-APR-2020*** 4/30/2020 ***WELL S/I UPON ARRIVAL*** (perforating) R/U SWCP 4516 SLICKLINE UNIT ***CONT WSR ON 5/1/20*** 5/1/2020 ***CONT WSR FROM 4/30/20*** (perforating) B&F W/ 4 1/2" BRUSH, 3.75" GAUGE RING TO DEVIATION @ 10,930' SLM (lrs pumped 140bbls crude) DRIFTED W/ 20' x 3.70" DUMMY WHIPSTOCK TO 10,912' SLM (Dog leg) E-LINE PERF INTERVAL= 10,798'- 10,838' MD ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 5/3/2020 ***WELL SHUT IN UPON ARRIVAL*** (ELINE ADPERF) INTIAL T/I/0=500/0/0 INTERVAL TO PERF: 10797'-10837' GUN SPECS: 2X 20' 3-3/8" POWERJET HMX 6 SPF 60 DEG MEASUREMENTS: CCL TO TOPSHOT=7.83', TS TO BS=20.0', CCL TO BOTTOM OF GUN STRING=28.46' CCL STOP DEPTH RUN #1=10809.17', PERFORATED INTERVAL=10817'-10837' CCL STOP DEPTH RUN #1=10789.17', PERFORATED INTERVAL=10797-10817' FINAL T/I/0=450/0/0 ***JOB COMPLETED*** Daily Report of Well Operations PBU A-17A STATE OF ALASKA ;;,, 1 t 1:; AKA OIL AND GAS CONSERVATION COMM,.,6ION REPORT OF SUNDRY WELL OPERATIONS AQP;fCC 1 Operations Abandon ❑ Plug Perforations LI Fracture Stimulate Ll Pull Tubing U Operations shutdown ❑ Performed Suspend ❑ Perforate D Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pod Repair Well ❑ Re-enter Susp Well El Other ❑ 2 Operator 4.Well Class Before Work 5 Permit to Dnll Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory❑ 206-125-0 3 Address P O Box 196612 I Stratigraphic ❑ Service 2 6 API Number Anchorage,AK 99519-6612 50-029-20520-01-00 7 Property Designation(Lease Number) 8 Well Name and Number. ADL0047472 PBU A-17A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12157 feet Plugs measured None feet true vertical 9035 56 feet Junk measured None feet Effective Depth measured 12067 feet Packer measured See Attachment feet true vertical 9017 77 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 31.73-111 73 31 73-111 73 0 0 Surface 2672 31 13-3/8"72#L-80 31 23-2703 54 31 23-2703 49 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11640-11670 feet 11700-11730 feet 11760-11790 feet 11820-11955 feet True Vertical depth 8949 06-8952 02 feet 8955 18-8958 54 feet 8962 24-8966 49 feet 8971.3-8995 96 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#L-80 27 12-10431 9 27 12-8738 03 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary ' Intervals treated(measured) Treatment descriptions including volumes used and final pressure EU u�^ 0 9 2'0 115 SCANNV 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 2070 680 1389 Subsequent to operation 0 0 2523 500 1055 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run ❑ Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations 0 16 Well Status after work Oil El Gas ❑ WDSPL El Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 2 GINJ ❑ SUSP ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Garry Catron Email Garry.Catron GSBP.Com Printed Name Garry Catron /� Title PDC PE Signature e alt.., Phone 564-4424 Date 6/10/2015 �v-r , /Igifs RBDMS.\k JUN 1 1 2015 ,4 74 tfr Form 10-404 Revised 10/2012 Submit Onginal Only Packers and SSV's Attachment 206-125 SW Name Type MD TVD Depscription A-17A PACKER 7666.6 6878.06 7" Baker C-2 ZXP Packer A-17A PACKER 10375.23 8703.34 4-1/2" Baker S-3 Perm Packer A-17A PACKER 10438.63 8742.17 5" Baker ZXP Top Packer Cu a o 0 o O o cacorn "— O � o LncNN- U N o 0 o O o 0 L V co Co co CO CO N V (T m CO CO N- CO 'Cr CO CO CO CO 0) M m 7 O N CO .41- Lo tLC) CO CO O cO t0 CO CD cO CD CO O N N- CO 6) N CO 1 1 1 1 1 1 I H r CO CO CO N CD 0 CO N O O CO CO. N 7 r 0) O) N- C7 — N- CO N ) Co I. CO N N CO Co O (D CO0.1 a) O co 6s--) O ✓ ON co N r � C 1 1 1 1 1 1 O N Q N (7) 6) NCO N O CO cp CO N N N C CI � N OO wOco CO CO o 00 b J J CO J J J It N ((O N X r N cn co O CO CO N - - U N N In M +-' co co co O N 0 O (fl CCS V N r C CO CD N- (7) N- CO V Gt01 N N — N O -J w w C OD D F- y U w w w D22 QCT U O w w w w Z Z w w w w O H H Z_ Z_ O O Z Z J J w Packers and SSV's Attachment 206-125 SW Name Type MD TVD Depscription A-17A PACKER 7666.6 6878.06 7" Baker C-2 ZXP Packer A-17A PACKER 10375.23 8703.34 4-1/2" Baker S-3 Perm Packer A-17A PACKER 10438.63 8742.17 5" Baker ZXP Top Packer to % a » o / c ~ \ o - q 2 ® $ _ C ./ _ $ a R 2 ? / E / 2 \ fE c ? R % 2 .g 2 /m $ = 9 © § ® 2 ) 6 $ m 2 = _± ¥ o 2 4_ o \ o c Co o � » k / E -, E \ % \ / w = $ 07 cNir o O R § g ® R = % O o \ c & o v- I-- c 2 0 - / % id % % 7 / ƒ E § f $ \ % / / / Ct % \ 0 / p% b � \ w « § ° o O y a x 9 / 2 \ / / / / 0 / > .2oF» 2 \ % « I << � @ co_ 2 � o = CO o m :1-1 _ CO a ¥ _ 0 2 O & ere; rii) \ - m R m - @ __ o » o a 0 = 3 &� 4i0uJ / $ / a) 0H / ��� � / % o\ mA o \ . = /t z 9 e\ - � 4 \ - \ 5 2 2 a Q. E % o O ƒ & / I t e ¢ r » 0 I q 2 & 2 ƒ _ : $ uj D : G _ .2 a / C / 2 ) � D � £ � G7 2 / CO 2 G w!� 2 c I " E o \ c Z / \ E - \ r f t - , ° 7 ) ?s O H < > L L b w o o. ± co < # t o ® G U t m G en » \ ± a ƒ / ƒ Lo. ƒ ƒ % / ƒ / o CNJ> / // % / / / k ƒ ..2 r m g $ CL Cr uj E o% w 2 ƒ / ƒ w / e .::"X / / < \ - \ 0 < 0 E c - > / \ % / / k / « / \ / \ / ? % / ƒ _ / $ 5 ¢ fxE / % > 2 / 2 - O N O Z > 0 e Z m oto « m ® y = ® _1 Q o R ® L 2 L Q a / Q a ® _i w .e_ o = • e 2 c 2 / / E " § o0CD4 ƒ R N. Z � � wmOtc4tO �0 / $ 0 O \ § II Q 2 2 2 = U 2 § q --.:Z D / % •e ° _ £ E 2 » o i M 47: R f / f J E J E f / £ % { 0 i 0 / G I \ I-- k O O \\ to r r o o o 0 7 3 7 7 7 7 7 a A 9 9 9 9 ® c0 A # a / / / / / / \ t o 0Se3 / '6". a m 0- -C 5 3 a 6 CI \ k / / � \ / I / C + cLD eO o0 =R e O * .g O a) © 0- Ck0- -00 2 / \£ 022 E \ $ 3 / CO E R \ I \ c = F 2 k = / / 3 ± m = .g w = o 2 2 2 \ 2 % q G4 a .f N .g o o - co G n U) : TREE= 4-1/16'CMV SAFEi. fES:H2S READINGS AVERAGE 125 ppm WIUl ON • "VEL`.HEAI FMC ML WELL REQUIRES A SSSV WHEN ON MI.A-17 A RADIO TRANSMITTER IN WEATHER MON ORING SHACK AG"ilY1TOI21OR OTIS = OKB.ELEV= 79.8' MUST BE TURNED OFF BEFORE ANY WELL WORK INVOLVING BF.ELEV= 48.57' NON RADIO SAFE EXPLOSIVES CAN BEGIN.CONTACT PAD KOP= 2800' OPERATOR Will>70°al 10908'. Max Angie= 103°0 11266' Cotum MD= 10661' 2079' -I9-5/8"HES ES CEMENTER Datum TVDss= 8800' 9-8/8"CSG,47#,L-80,TC-11,13=8.681' H 2093' ' I 2204' H4-1/2"HES X NP,ID=3.813" 13-3/8"CSG,72#,L-80,D=12.347' -1 2672' , GAS UFT MANDRELS Minimum ID = 3.813" @ 2204' ST MJ TVD DEV TYPE VLV LATCH PORT DATE H E S X NIPPLE 1 3499 3461 29 KBG2 DMY BK 0 .12/01/06 TOP OF 7'LM -1 7664' } 7664' H9-5/8"X 7"BKR G2 ZXP Pf(R ID=6.280 7682' -19-5/8"X 7"HMC LNR HGR D=6.320' MLLOUf WINDOW(A-17A)7846'-7855' 10311' ---I4-1/2"HES X NP,D=3.813" 10373' -17"X 4-1/2'BKR S-3 PKR,13=3.875' 9-5/8'WHPSTOCK(09/16/06) -1 7846' I 10397' -I4-1/2"HES X NP,ID=3.813" 10417' -{4-1/2'FES X NP,D=3.813' 41h. 10425' -r x 5"ZXP LTP TACK lir4iL (11.41"X 5.25'),D=4-42 I -5/13"EZSV(09/16/06) l-1 7867' \\11\ 10430' H4-1/2'WLEG, D=3.958' ®,����.����.f 10443' 7"X 5"BKR HMC +1�"1 10 LNR I-IGR,D=4.43 t••� . •�••1* ••• 10450' -5"x4-1/2"XO, ►44..1111 9-5/8'CSG,47#,L-80,D=8.681' H 9902' 4....... =3.920' i�i�i�i�i..1 'i 144444444 7"LNR,29#,L-80, 0371 bpf,D=6.184" H 10907' PPIPP# 4-1/2"TBG, 12.6#,L-80,TC-I, -I 10430' 1 , PERFORATION SUMMARY 0152 bpf,D=3.958" REF LOG:BI-CS ON 10/05/06 7'LNR,26#,L-80,BTC-M, --t 10612' ANGLE AT TOP PERF:85'@ 11640 0383 bpf,D=6.276" ,iI,. Nbte:Refer to Production DB for historical perf data PBTD -1 12066' W SIZE SPF NTHRVAL Opn/Sqz SHOT SQZ 2-7/8" 4 11640- 11670 0 05/16/15 2-7/8" 4 11700- 11730 0 05/16/15 4-1/2'LNR, 12.6#,L-80,BT-M,.0152 bpf,ID=3.958' -{ 12154' I 2-7/8' 4 11760- 11790 0 05/16/15 2-7/8' 4 11820- 11955 0 10/05/06 DATE REV BY COMMHJTS DATE REV BY COMMENTS PRUDHOE BAY LINT 01115/81 ORIGINAL COMPLETION 01/17/12 TMNVJMD ADDED I-QS SAFE!Y NOTE WaL: A-17A 10/10/06 N2ES SIDETRACK"A" 03/12/14 TAQ/JMD ADDED SAFELY NOTE PERMT No:'2061250 12/15/04 RDJ/PAG WAIVER SAFEI Y NOTE 05/21/15 JCF/JM) ADR3RFS&PBTD EDIT AR Na: 50-029-20520-01 12/01/06 KSB/TLH GLV GO SEC 35,711N,R13E,2154'FSL&1014'FEL. 01/15/07 STG/PJC DRG DRAFT CORRECTIONS 02/14/11 143/JMD ADDED SSSV SAFELY NOTE BP Exploration(Alaska) • ~ Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of tt~e file. ~Q ~ - ~ ~,~ Well History File Identifier Organizing (done> RE CAN Color Items: ~Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria _ Scanning Preparation BY: Maria ~,wosaea uuiiiiiuiiuuii DIGI AL DATA Diskettes, No. ^ Other, No/Type: ae.~a, ~e.ded iuiuiii0uiiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: Date: 08 Date: ., ~1 P iiiiiiiiiiiiwluum~ ~o _x30=~ Date: "~ ~~© g + ~_ =TOTAL PAGES (Count does not include cover sheet) e~ lsl ~l ~J Production Scanning III I~~III IIII III) Stage 1 Page Count from Scanned File: ~ 3 _ (Count does include cover sheet) Page Count Matches Number in Scan-Wing Preparation: YES NO BY: Maria Date: I ~ ©~ /s/ jjj 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. II I II'I II I II II I I III ReScanned III II'lll IIII IIIII BY: Maria Date: !s/ Comments about this file: Quality Checked ll! !I'II)1II III I!) P 10/6/2005 Well History File Cover Page.doc • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 May 18, 2012 rl 4 PAUG 1 7 2012 Mr. Jim Regg /' �. J ' I Alaska Oil and Gas Conservation Commission lQ 333 West 7 Avenue Anchorage, Alaska 99501 p ( 1.J Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing Teak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, - Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) A -Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement _ pumped cement date inhibitor sealant date , ft bbls ft na gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A -03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A -04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 -a? A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 A -26L1 1971060 50029207946000 0.3 _ NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 A -43 1960860 50029226770000 0.3 NA 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 STATE OF ALASKA ALASKA 111111AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ei BRIGHTWATER Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ TREATMENT Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ e 206 -1250 3. Address: P.O. Box 196612 Stratigraphic Service El 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20520 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 047472 PBU A -17A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12157 feet Plugs (measured) None feet true vertical 9035.56 feet Junk (measured) None feet Effective Depth measured 12067 feet Packer (measured) 7664 10373 10425 feet true vertical 9017.77 feet (true vertical) 6876 8702 8734 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 31 - 111 31 - 111 1490 470 Surface 2642' 13 -3/8" 72# L -80 30 - 2672 30 - 2672 4930 2670 Production 7817' 9 -5/8" 47# L -80 29 - 7846 29 - 7033 6870 4760 Liner 2618' 7" 26# L -80 7994 - 10612 7158 - 8850 7240 5410 Liner 1729' 4 -1/2" 12.6# L -80 10425 - 12154 8734 - 9035 8430 7500 Liner Perforation depth: Measured depth: 0 11820 - 11955 - _ - True Vertical depth: O 8971.3 - 8995.96 'ii �1 <' �' �, Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 28 - 10430 28 - 8737 Packers and SSSV (type, measured and true vertical depth) 7" Baker C -2 ZXP Packer 7664 6876 4 -1/2" Baker S -3 Perm Packer 10373 8702 4 -1/2" Baker S -3 Perm Packer 10425 8734 12. Stimulation or cement squeeze summary: .ECE VE +l Intervals treated (measured): OCT 0 7 2011 Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cons. Commissiag 13. Representative Daily Average Pro1k #9ection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 7,250 636 Subsequent to operation: 7,481 1,325 14. Attachments: 15. Well Class after work: r Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: 011 ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam oe Lastu Title Petrotechnical Data Technologist Sig natu -------\ Phone 564 -4091 Date 10/6/2011 R O CT 1 7 2011 ci eo . r'!( Form 10 -404 Revised 10/2010 79/(9/ Submit Original Only ID • A -17A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY INMVIrilYkrg[F,Pr:-„VZ „It , 9/10/2011; T /I /0= 1120/680/0 Temp =Hot (Brightwater Reservoir Sweep Mod) :Start pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped 56 gal. EC9660A (Low Temp Surfactant) Average of 28 gph for 2 hrs. Pumped a total of 56 gal. since start of project. Pumped 241 gal. EC9398A ( Polymer) Average of 120.5 gph for 2 hr. Pumped a ;total of 241 gal. since start of project 9/11/2011 ' ** *Continued from 09/10/11* ** T /I /0= 1170/720/0 Temp =Hot (Brightwater Reservoir Sweep Mod) Continue pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. :Pumped 734 gal. EC9660A (Low Temp Surfactant) Average of 30.5 gph for 24 hrs. Pumped a total of 790 gal. since start of project. Pumped 3380 gal. EC9398A ( Polymer) Average of 140.8 gph for 24 hr. Pumped E 'a total of 3380 gal. since start of project 9/12/2011' ** *Continued from 09/11/11*** T /I /0= 1333/1060/30 Temp =Hot (Brightwater Reservoir Sweep Mod) !Continue pumping brightwater chemicals down TBG while on water injection @ - 7000 bwpd. Pumped 689 gal EC9660A ( Low Temp Surfactant ) Average of 28.7 gph for 24 hrs. Pumped a total of 1479 gal since start of project. Pumped 3167 gal EC9398A ( Polymer ) Average of 132 gph for 24 hr. Pumped a total of 6788 gal since start of project 9/13/2011i * ** WSR Continued from previous day 09/12/11 * ** T /I /O = 1350/920/20 Temp = Hot; (Brightwater Reservoir Sweep Mod) ;Continue pumping brightwater chemicals down TBG while on water injection @ ;7000 bpwd :Pumped 653 gal EC9660A ( Low Temp Surfactant ) Average of 27.2 gph for 24 hr Pumped a total of 2132 gal since start of project. :Pumped 3228 gal EC9398A ( Polymer ) Average of 134.5 gph for 24 hr Pumped a 'total of 10016 gal since start of project Surf Strap= 32.5 ( 1698 g) gph= 27.5/ Poly Strap= 60.75 ( 5390 g) gph= 134.5/ bwpd= 7000/ 2200 psi on SSV ** *WSR Continued on 14Sep2011 * ** • • 9/14/2011: * * *WSR Continued from 13Sep2011 * ** T /I /0= 1373/940/0, Temp =Inj (Brightwater Reservoir Sweep Mod) 1Continue pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped 693 gal. EC9660A ( Low Temp Surfactant) Average of 28.8 gph for 24 ;hrs. Pumped a total of 2825 gal. since start of project. Pumped 3102 gal. EC9398A ( Polymer) Average of 129.25 gph for 24 hrs. Pumped a total of 13118 gal. since start of project Surf Strap= 24.75 ( 1005 g) gph= 30 / Poly Strap= 37.825 ( 2288 g) gph= 126 / :bwpd = 6900, 2200 psi on SSV 9/15/2011 * * *WSR Continued from 14Sep2011 * ** T /I /0= 1365/880/0, Temp =Inj (Brightwater Reservoir Sweep Mod) Continue pumping brightwater chemicals down TBG while on water injection @ 7000 bwpd. Pumped 495 gal. EC9660A (Low Temp Surfactant) Average of 27.5 gph for 18 hrs.. Pumped a total of 3320 gal. since start of project. Pumped 2288 gal. EC9398A ( Polymer) Average of 143 gph for 16 hrs. Pumped a total of 15406 gal. since start of project ** *job complete * ** Surf Strap= 61.25 ( 5449 g) gph= 50 / Poly Strap= 0 (0 g) gph= 0 / bpd = 7000, .. - i ? 200 psi on SSV FLUIDS PUMPED GALS 3320 EC9660A (LOW TEMP SURFACTANT) 15406 EC9398A (POLYMER) 18726 TOTAL ■II, TREE= 4-1/16" CIW • SAFETY NOTES:a REQUIRES A SSSV WHEN ON M I. WELLHEAD= FMC A-1 7A WARNING: RADI NSMITTER IN WEATHER MONITORING ACTUATOR= OTIS SHACK MUST BE TURNED OFF BEFORE ANY WELL WORK KB. ELEV = 79.77 INVOLVING EXPLOSIVES CAN BEGIN. CONTACT PAD BF. ELEV = — 487E7' • ■ OPERATOR. WELL >70° © 10908'. ■ KOP = 28007 • ■ • 4, ■ : Max Angle = 103 @ 11266' 4 • Datum MD = 10661' ■ • • •V 2079' H - 9 5/8" HES ES CEMENTER 1 Datum TVDss= 8800 • , 9-8/8" CSG, 47#, L-80, TC-11, ID = 8.681" H 2093' • , 1 2204' 1-14-1/2" HES X NIP, ID = 3.813" 1 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2672' I GAS LIFT MANDRELS Minimum ID = 3.813" @ 2204' lir ST MD WD DEV TYPE VLV LATCH PORT DATE 1 3499 3461 29 KBG2 DMY BK 0 12/01/06 HES X NIPPLE [TOP OF 7" LNR1-1 7664' 1 1 7664' H9-5/8" X 7" BKR C-2 ZXP PKR, ID = 6.280 1 7682' H9-5/8" X 7" HMC LNR HGR, ID = 6.320" 1 MILLOUT WINDOW (A-17A) 7846' - 7855' 10311' 1+-1/2" HES X NIP, ID = 3.813" 1 1 10373' 1 X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 19-5/8" WHIPSTOCK (09/16/06) H 7846' 1 10397 H4-1/2'' HES X NIP, ID = 3.813" 1 , . ',. 10417 H4-1/2" HES X NIP, ID = 3,813" I . . . A■ 10425 h 7" X5 (11.41" X 5.25"),ID4.42 ZXP LTP TIEBACK , 19-5/8" EZSV (09/16/06) H 7867' ''''■ 4.. Nii 10430' —14-1/2" WLEG, ID = 3.958" 1 10443' 7" X 5" BKR HMC LNR HGR, ID = 4.43 Ovf•A , v**** tit...•ty 10450' 1-15" x4 X0, 4.0404 9-5/8" CSG, 47#, L-80, ID = 8.681" —J 9902' 1 " - - — - " MYNA. " "S - ID = 3.920" •••••••• ...Oft. 4.0.04 . P M. 1 . 4 ' 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1 — I 10907' 1 4-1/2" TBG, 12.6#, L-80, TC-II, 10430' 0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: BHCS ON 10/05/06 7" LNR, 26#, L-80, BTC-M, 10612' •■ 4•11111. 1 ■ ANGLE AT TOP PERF: 80 @ 11820' ; 0383 bpf, ID = 6.276" •111111111111MI 'NMI/ Note: Refer to Production DB for historical perf data IPBTD 11 10267' 'lir SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 11820 - 11955 0 10/05/06 14-1/2" LNR, 12.6#, L-80, IBT-M, .0152 bpf, ID = 3.958"1-1 12154' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/15/81 ORIGINAL COMPLETION WELL: A-17A 10/10/06 N2ES SIDETRACK "A" PERMIT No: F 2061250 12/15/04 RDJ/PAG WAIVER SAFETY NOTE API No: 50-029-20520-01 12/01/06 KSB/ TLH GLV C/O SEC 35, T11N, R13E 01/15/07 STG/PJC DRLG DRAFT CORRECTIONS 02/14/11 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration (Alaska) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, December 29, 2010 Jim Regg 7 1 I (4 I (( SUBJECT: Mechanical Inte ri Tests P.I. Supervisor ( g �' BP EXPLORATION (ALASKA) INC A -17A FROM: John Crisp PRUDHOE BAY UNIT A -17A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON- CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT A - 17A API Well Number: 50 029 - 20520 - 01 - 00 Inspector Name: John Crisp Insp Num: mitJCr101220075044 Permit Number: 206 - 125 - Inspection Date: 12/17/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A -17A ' Type Inj. G'1 TVD 8702 ' IA 520 2810 ' 2780 2760 2740 2740 P.T.D 2061250 ' TypeTest SPT Test psi 2175 , OA 20 20 20 20 20 20 Interval 4YRTST ' P/F P ' Tubing 2325 2325 2325 2325 2325 2325 Notes: 4.4 bbls pumped for test. w FEB 0 7 2011 Wednesday, December 29, 2010 Page 1 of 1 OPERABLE: Injector A -17A (PTD #2061250) Passed MIT -IA to 4000 psi Page 1 oft Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Monday, December 13, 2010 3:40 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C Well Integrity Coordinator; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Derrick, Laurie R Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany Subject: OPERABLE: Injector R -17A (PTD; #2061250) Passed MIT -IA to 4000 psi Attachments: MIT PBU A-1 7A 12- 11- 10.x1s All, WAG injector A -17A (PTD #2061250) has passed a MIT -1A to 4000 psi while on gas injection confirming the presence of 2 competent barriers. The well has been reclassified as Operable. A copy of the MIT -IA form has been included for reference. <<MIT PBU A-1 7A 12- 11- 10.xls>> Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 XAN*XDR I I U Pager (907) 659 -5100 Ext. 1154 From: AK, &C Well Integrity Coordinator Sent: Friday, ember 10, 2010 4:30 PM To: 'Maunder, Tho E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, D &C Well Integrity Coordinator; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB Ce al Prod Opt Engr; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Derrick, Laurie R Cc: King, Whitney; Quy, Tiffany Subject: UNDER EVALUATION: Injector A -1 PTD #2061250) Passed Cold MIT -IA to 2500 psi All, WAG injector A-1 7A (PTD #2061250) has passed a col IT -IA to 2500 psi. The passing MIT -IA confirms the presence of two competent barriers. The well has been re c sified as Under Evaluation and placed on a 28 day clock until a 4000 psi MIT -IA is obtained. The plan forward: 1. Operations: Resume gas injection 2. Fullbore: MIT -IA to 4000 psi when well is warm A copy of the passing MIT -IA has been included for reference. 12/13/2010 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.regg0alaska.gov: doa .aogcc.prudhoe.bav(balaska.gov: phoebe.brooks(tDalaska.gov: tom.maunder0alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU DATE: 12/11/10 OPERATOR REP: Jerry Murphy AOGCC REP: not witnessed Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A -17A Type In'. I G TVD 1 8,702' ATub2500 2500 2500 2500 Interval O P.T.D. 2061250 T test P Test i 2175.5 80 4000 3960 P/F P Notes: Pre - AOGCC MIT -IA; on gas injection Well I Type IN TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well Type Inj. TVD E[ T�ubing Inte r P.T.D. T test Tet P/F Notes: OA Well I Type In'. I I TVD I Tubing Interval P.T.D. T test Test i Casi P!F Notes: OA Well I Type In'. I TVD I Tubing Interval P.T.D. Type test I I Test psi I CasingP/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring 1= Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT PBU A 7A 12 11 10.)ds UNDER EVALUATION: Injector A -17A (PTD #2061250) Passed Cold MIT -IA to 2500 ... Page 1 of Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Friday, December 10, 2010 4:30 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, D &C Well Integrity Coordinator; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Derrick, Laurie R Cc: Kin Whit Quy 9, Y� Y, Y Subject: UNDER EVALUATION: Injector A-1 7A (PTD #2061250) Passed Cold MIT -IA to 2500 psi Attachments: MIT PBU A -17A 12- 09- 10.xis All, WAG injector A -17A (PTD #2061250) has passed a cold MIT -IA to 2500 psi. The passing MIT -IA confirms the presence of two competent barriers. The well has been reclassified as Under Evaluation and placed on a 28 day clock until a 4000 psi MIT -IA is obtained. The plan forward: 1. Operations: Resume gas injection 2. Fullbore: MIT -IA to 4000 psi when well is warm A copy of the passing MIT -IA has been included for reference. <<MIT PBU A -17A 12- 09- 10.xls>> Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 F Quy, Tiffany Sent: Tu y, December 07, 2010 9:50 AM To: 'Maunder, as E (DOA)'; "Schwartz, Guy (DOA'; 'Regg, James B (DOA)' Cc: AK, D &C Well Integ Coordinator Subject: FW: NOT OPERABL njector A 17 (PTD #2061250) Failed MIT -IA From: AK, D &C Well Integrity Coordinator Sent: Tuesday, December 07, 2010 7:47 AM To: AK, D &C Well Integrity Coordinator; AK, OPS FS2 OSM; OPS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug • Engel, Harry R; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Derrick, Laurie R Cc: King, Whitney; Janowski, Carrie; Quy, Tiffany; Winslow, Jack L (ASRC) Subject: NOT OPERABLE: Injector A -17 (PTD #2061250) Failed MIT -IA 12/13/2010 • • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv jnl617 @conocophillips.com] Sent: Friday, May 14, 2010 3:51 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 3N -04 (PTD 186 -017) Report of failed MITIA Attachments: 3N -04 schematic.pdf Tom, Jim, Guy Kuparuk water injector 3N -04 (PTD 186 -017) failed a diagnostic MITIA. The well is currently injecting under AID 213.029 and under condition 5, the well is being reported due to a suspected change in the well's mechanical condition. The TIC prior to the test was 2450/2885/480. The well has been SI and freeze protected. Further diagnostics will be performed which will include a leak detect log on E -line in an attempt to locate the suspected leak. Following the results of the diagnostics, the plan forward will be discussed and the appropriate paperwork will be submitted. Currently the well is already on the monthly injector report. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pa er 907 659 -7000 pgr. 909 — CHOKE FTP -- — FTT IAP OAP TWO Plot - 3N -04 3000 200 ............................... ............................... ... ............................... 2500 ---- .---- ........ ... ...... ..... ...................... ............ .... ........ ............................... 150 2000 ....................................................................................................................... ............................... - a _ E d d 1500 100 Y ..................:....................................................... ............................... . 0 C) 1000- t 1 50 500 .................................................................. ............................... 0 0 14- Feb -10 27- Feb -10 12- Mar -10 25- Mar -10 07- Apr -10 20- Apr -10 03- May -10 Date 12/13/2010 Injector A -17A (PTD #2061250) Psed Cold MIT -IA to 2500 psi, Reques Permissio... Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, December 10, 2010 3:31 PM To: 'AK, D &C Well Integrity Coordinator' Subject: RE: Injector A-1 7A (PTD #2061250) Passed Cold MIT -IA to 2500 psi, Requesting Permission to Resume Injection to Continue Testing Jerry, It appears that you have demonstrated integrity sufficient to bring the well on as you propose. Keep us informed. Tom Maunder, PE AOGCC From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWellIntegrityCoordinator @bp.com] Sent: Friday, December 10, 2010 3:12 PM To: Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator Subject: Injector A -17A (PTD #2061250) Passed Cold MIT -IA to 2500 psi, Requesting Permission to Resume Injection to Continue Testing Tom, Per our conversation regarding WAG injector A-1 7A. The well passed an initial MIT -IA to 2500 psi on 12/9/2010 with the well shut in. The test lost 20 psi in the first 15 minutes and 0 psi in the second 15 minutes with a final pressure of 2480 psi on the IA. No pressure changes were seen on the tubing and OA. With your permission, our intent is to reclassify the well as Under Evaluation and then put the well back on gas injection to be retested to 4000 psi. Testing the IA to 4000 psi currently will put excessive mechanical strain on both the tubing and packer, with the tubing being loaded with gas. Having the well on gas injection will help limit the potential for tubing collapse and packer failure. I am enclosing a copy of the MITIA for reference. <<MIT PBU A-1 7A 12- 09- 10.xls>> Thank you, Jerry Murphy BPXA Well Integrity Coordinator From: Quy, Tiffany Sent: Tuesday, December 07, 2010 9:50 AM To: 'Maunder, Thomas E (DOA)'; "Schwartz, Guy (DOA'; 'Regg, James B (DOA)' Cc: AK, D &C Well Integrity Coordinator Subject: FW: NOT OPERABLE: Injector A -17 (PTD #2061250) Failed MIT -IA 12/13/2010 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: iim.reaa0alaska.aov: doa .aogcc.pnidhoe.bavD-aIaska.aov: ahoebe.brooks0alaska.aov: tom.maunder0alaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU DATE: 12/09/10 OPERATOR REP: Jerry Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A -17A I Type In'. I N TVD 8,707 Tubi 1930 1920 1920 1920 Interval O P.T.D. 2061250 I Type test I P Testpsj 2175.5 (psi 2500 2480 2480 P/F P Notes: OA Well I Type Ini, I I TVD I T Interval P.T.D. I Type test I I Test pi Casi P/F Notes: OA Well I Type Ini. I I TVD I Tubing Interval P.T.D. I Type test I I Test P/F Notes: OA Well Type In'. TVD JOA Interval P.T.D. T test Test ' P/F Notes: Well Type In'. TVD fTubjng I nterval P.T.D. T test Test asi P/F Notes: OA TYPE ]NJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioact ve Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) Form 10 -426 (Revised 0612010) MIT PBU A-1 7A 12-09-10 (2).xls Injector A -17A (PTD #2061250) o U .sed Cold MIT -IA to 2500 psi, Reques * Permissio... Page 2 of 2 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, December 07, 2010 7:47 AM To: AK, D &C Well Integrity Coordinator; AK, OPS FS2 OSM; AK, OPS FS2 Ops Lead; AK, OPS FS2 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Engel, Harry R; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; Derrick, Laurie R Cc: King, Whitney; Janowski, Carrie; Quy, Tiffany; Winslow, Jack L (ASRC) Subject: NOT OPERABLE: Injector A -17 (PTD #2061250) Failed MIT -IA All, WAG injector A -17 (PTD #2061250) failed a MIT -IA 12/6/10. The well has been reclassified as Not Operable. It will be shut in and freeze protected as soon as safely possible. The plan forward is as follows: 1. DHD: Obtain a IA liquid leak rate 2. Wellhead: PPPOT -T and PPPOT -IC A TIO plot and wellbore schematic are attached for reference. Please contact Well Integrity with any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Torin Roschinger /Gerald Murphy) Projects Well Integrity Engineer phone: (907) 659 -5102 AKDCWelllntegrityCoordinator @bp.com 12/13/2010 Injector A- TIO Plot ,M - 3,000 2.000 OM t -- � -000M E LOW 1 I C I 09AIAO 03/18/10 OMMO 10/wo IWMD 10!16/10 1Q=G 10MAO 11/06/10 11113A0 1180/10 11WA0 17JOVID t t Gulf Disaster Tied to BP's Lack of 'Operating Discipline' - WSJ.com Page 3 of 3 russell.gold@wsj.com Copyright 2010 Dow Jones & Company, Inc. All Rights Reserved This copy is for your personal, non - commercial use only. Distribution and use of this material are governed by our Subscriber Agreement and by copyright law. For non - personal use or to order multiple copies, please contact Dow Jones Reprints at 1- 800 - 843 -0008 or visit www.djreprints.com <�� 67) http: / /online.wsj.com/articl�B 10001424052748704312504575619�1331344070 .html ?... 11/17/2010 • k. _ fi 's~, ~' ,r z'.,.. .n n ~ Y~i a~°. R~ _. "" ~ .. ~.~ MICROFILMED 6/30/2010- DO NOT PLACE. ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc 7 Nom DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061250 Well Name/No. PRUDHOE BAY UNIT A-17A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20 0-01-00 MD 12157 TVD 9036 Completion Date 10/7/2006 Completion Status WAGIN Current Status WAGIN UIC REQUIRED INFORMATION Mud Log No Samples No Directional Su DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR /RES / PWD, MWD DIR / GR /RES / ABI / IFR / CAZ Well Log Information: Log/ Electr Data Digital Dataset Log Log Run (data taken from Logs Portion of Master Well Data Maint Interval OH / type m irrmc rvumoer Name scale media No Start Stop CH Received Comments ,Log Cement Evaluation 5 Col 1 1662 10424 Case 10/20/2006 USIT, CBL, DSLT, GPIT, ~ ~ GR, CCL 2-Oct-2006 ED D Asc Directional Survey 7799 12157 Open 11/9/2006 ~ d ED C Lis 15307 In uction/Resistivity 7702 12156 Open 8/3/2007 LIS Veri, GR, ROP, FET w/Graphics Rpt 153~LI erification 7702 12156 Open 8/3/2007 LIS Veri, GR, ROP, FET ED C 15749 Induction/Resistivity 0 0 Open 12/13/2007 EWR in MD and TVD ~ w/PDF, EMF graphics Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? Y Chips Received? -~ffPl-~ Formation Tops ~N Analysis ~~ Received? Comments: Compliance Reviewed By: Date: 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: MVVD Formation Evaluation Logs : A-17AI A-17AI: Digital Log Images: 50-029-20520-01 December 10, 2007 AK-MW-4603216 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 99518 Date ~~ ~ ,1,1' u1c a~-~a~ BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: '~ ~ 5~~9 • • WELL LOG TRANSNIITTAL To: State of Alaska July 30, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: A-17A, AK-MW-4603216 1 LDWG formatted CD rom with verification listing. API#: 50-029-20520-0 I 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 99518 Date: ~; _~ ~ ~ ~~~n~ ~~ T ~a~si{a iii ?_ ups ~;~ras..~~~~~~~issicr~ BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: UT e- a~~ - r a S '~ i 53~~ MEMORANDUM To: Jim Regg ~ ~~~ ~~ P.I. Supervisor e~~I FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, January 02, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATLON (ALASI:A) INC A-17A PRUDHOE BAY UNIT A-17A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv,~j~ Comm Well Name: PRUDHOE BAY UNIT A-17A Insp Num: mitJJ061222103904 Rel Insp Num API Well Number 50-029-20520-O1-00 Permit Number: 206-125-0 Inspector Name: Jeff Jones Inspection Date: 12/22/2006 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~! A-I7A (Type Inj. ~ ~' ~ TVD j s7oz j IA I o j zsoo ~ za7; I za6o ~ I P.T. ~ zo6lzso TYPeTest ~ sPT I Test psi zt7s.~ OA o I Io Io o ---~- Interval ~IT~ P/F P - :% Tubing ; Iooo Iooo Iooo j Iooo i NOtes 5.4 BBLS methanol pumped. 1 well house inspected; no exceptions noted. Tuesday, January 02, 2007 Page 1 of I TREE = 4-1116" CIW WELLHEAD= FMC ACTUATOR= OTIS KB. ELEV - 79.77 BF. ELEV - 48 5T KOP = 2950' Max Angle = 102 @ 11266' Datum MD = Datum TV Dss= A-1~AI Actual HES ES CEMENTER 2079' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2672' 4-1/2", 12.6#, L-80, TC-IlTubing 7" X 9-5/8" HMC / ZXP PKR 7664' 05/8" Window 7846' Bottom indow 7863' p 9-518" CIBP 7874` 5-1/2" 17#, L-80 Tubing Cut 8150' TOP OF CEMENT 9100` SLIDING SLEEVE, ID = 4.5" 9247' Minimum ID = 3.813" @ 2203' X NIPPLE TOP OF 7" LNR 9391 ` 4-1 /2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9436` 9-5/8" CSG, 47# L-80 BRTS, ID = 8.681" - PERFORATION SUMMARY REF LOG: BHCS ON 10!5/06 ANGLE AT TOPPERF: 80 @ 11820' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8 4 11820-11955 O 10/05/06 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10907' SAFETY :Ball did not seat on X nipple at 10417.3 re not able to get 4000 psi pressure test. 2204' ~-{4-1/2" X LANDING NIPPLE (3.813" GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT DATE 3499 3461 i 29 KBG-2 DMY BK 0 12/01/0 10311' 4-1/2" X Nipple (3.813" ID) 10373' 7" X 4-1/2" Baker S3 Packer 10397' 4-1/2" X Nipple (3.813" ID) 10418' 4-1(2" X Nipple (3.813" ID) 10428' 4-1/2" WLEG 10610' 7" 26#, L-80, IBT-M Liner 10425' 4-1/2" Tieback (4.42" ID) 10443' 4-1/2" Lin Hang (4.43" ID) 12067' 4-112" Land Coll (3.958" ID) 4-1/2" 12.6#, L-80, IBT-M Liner PBTD 12062' DATE REV BY COMMENTS DATE REV BY COMMEMS 09/07/05 JNC ORIGINAL COMPLETION 10/08/06 MGS Sidetrack 10/10(06 /TLH ADD GLV INFO 11/15/06 KSB/TLH CSG & LANDING NIP INFO ADDED 12/01/06 KSB/TLH GLV C/O PRUDHOE BAY UNIT WELL: A-17A PERMff No: API No: 50-029-20520-01 SEC 35, T11 N, R13E BP Exploration (Alaska) ~a°j,o~° ~a~ !RECEIV STATE OF ALASKA DAyIEE~C~~A~~MOp~IL AND GAS CONSERVATION COMMISSION fltaska (lil-R~,as LonOs: Commis~sQo~ OR RECOMPLETtON REPORT AND LOG Anrhnrano Revised: 12/27/06, Put on Injection 1 a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 20AAC 2s.105 2oAAC 2s.»o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 10/7/2006 g' 12. Permit to Drill Number 206-125 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/18/2006 /. 13. API Number 50-029-20520-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/28/2006 14. Well Name and Number: - PBU A-17A 3126 FNL, 1014 FEL, SEC. 35, T11N, R13E, UM Top of Productive Horizon: 3261' FNL, 236' FWL, SEC. 01, T10N, R13E, UM 8. KB Elevation (ft): 79.64' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3648' FNL, 569' FWL, SEC. 01, T10N, R13E, UM 9. Plug Back Depth (MD+TVD) 12067 + 9018 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 654397 y- 5947319 Zone- ASP4 10. Total Depth (MD+TVD) 12157 + 9036 Ft 16. Property Designation: ADL 047472 TPI: x- 655762 y- 5941932 Zone- ASP4 Total Depth: x- 656103 y- 5941552 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes Q No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR /RES / PWD, MWD DIR / GR /RES / ABI / IFR / CAZ, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Con rete 13-3/8" 72# L-80 Surface 2672' Surface 2672' 17-1/2" 3255 cu ft Arcticset II -518" 40# ! 47# L-80 rfac S rface 703 ' 12-1 /4" 1430 cu ft 'G', 130 cu ft AS I, 814 cu ft 'G' 7" 26# L-80 7664' 10612' 6876' 8850' 8-1/2" 404 cu ft Lite rete 197 cu 'G' 4-1/2" 12.6# L-80 10425' 12154' 8734' 9035' 6-1/8" 573 cu ft Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10430' 10373' MD TVD MD TVD 11820' - 11955' 8971' - 8996' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT S~ KIND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel 26. PRODUCTION TEST Date First Production: December 14, 2006 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". , '~` '( None /0'L~~ s -- _~.. ___ ~;:. Form 10-407 Revised 12/2003.` CONTINUED ON REVERSE SIDE ~~ JUI_ ~ r~ 9ttA~ ~~ .~~-F~~~ JLVU 28. GEOLOGIC MARKS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NnMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10614' 8851' None Shublik A 10645' 8870' Shublik B 10704' 8905' Shublik C 10732' 8921' Sadlerochit 10785' 8952' Sadlerochit 11490' 8953' Sadlerochit 11639' 8949' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble - Title Technical Assistant Date l ZI27 i~(p PBU A-17A 206-125 Prepared 8y NameMumber. Te-rie Hubble, 564-4628 Well Number Drilling Engineer: Shane Gagliardi, 564-5251 Permit No. / A royal No. INSTRUCTIONS GeNen~al.: 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 1 a: Classification of Service Welis: 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. Irene 4b: TPI (Top of Producing Interval). Irene 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 AOGGC must be 14 digits (ex: 50-029-20123-00-00}. IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only • C 26-Oct-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well A-17A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,799.87' MD Window /Kickoff Survey: 7,846.00' MD (if applicable) Projected Survey: 12,157.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Mc v ~ ~+ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~ac~ -~as^ STATE OF ALASKA ALAS IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~_ ~~ ~~ ('~~Ir~~l~is~•r n 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 20AAC25.105 zoAACZS.>>o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ° ~ . ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/7/2006 12. Permit to Drill Number 206-125 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/18/2006 13. API Number 50-029-20520-01-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 9/28/2006 14. Well Name and Number: PBU A-17A 3126 FNL, 1014 FEL, SEC. 35, T11N, R13E, UM Top of Productive Horizon: 3261' FNL, 236' FWL, SEC. 01, T10N, R13E, UM 8. KB Elevation (ft): 79.64' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 3648' FNL, 569' FWL, SEC. 01, T10N, R13E, UM 9. Plug Back Depth (MD+TVD) 12067 + 9018 Ft Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 654397 y- 5947319 Zone- ASP4 10. Total Depth (MD+TVD) 12157 + 9036 Ft 16. Property Designation: ADL 047472 TPI: x- 655762 y- 5941932 Zone- ASP4 Total Depth: x- 656103 y- 5941552 Zone- ASP4 11. Depth where SSSV set None MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD DIR / GR 1 RES / PWD, MWD DIR / GR /RES / ABI / IFR / CAZ, USIT 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD: SETTING DEPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRApE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2672' Surface 2672' 17-1/2" 3255 cu ft Arcticset II 9-5l8" 40# / 47# L-80 Surface Surface 7033' 12-1/4" 1430 cu ft'G', 130 cu ft AS I, 814 cu ft'G' 7" 26# L-80 7664' 10612' 6876' 8850' 8-1/2" 404 cu ft LiteCrete 197 cu ft'G' 4-1/2" 12.6# L-80 10425' 12154' 8734' 9035' 6-1l8" 573 cu ft Class'G' 23. Perforations open to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 10430' 10373' MD TVD MD TVD 11820' - 11955' 8971' - H996' ~5, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED Freeze Protect with 150 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. 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 chl~s; If none, state "none". ~ / ~~~ ~r o~w~~a~ ~~~~ M~~~o3y ~~,~ None 0' ~- /•d Form 10-407 Rev ,~ CONTINUED ON REVERSE SIDE 9 ~~~C+ ~~~, ~('~ ~ 'S ~f1f1C 28. GEOLOGIC MARKS 29. ORMATION TESTS Include and brie mmarize test results. List intervals tested, N,aMe MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10614' 8851' None Shublik A 10645' 8870' Shublik B 10704' 8905' Shublik C 10732' 8921' Sadlerochit 10785' 8952' Sadlerochit 11490' 8953' Sadlerochit 11639' 8949' 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. l ' D / Z7~~Cr Signed Terrie Hubble ~ Title Technical Assistant Date PBU A-17A 206-125 Prepared ey Name/Number.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Shane Gagliardi, 564-5251 INSTRUCTIONS GerveRa~: 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). Irene 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date 8/31 /2006 9/1/2006 9/2/2006 From - To I Hours I Task I Code i NPT I Phase 00:00 - 09:00 I 9.00 I MOB P 09:00 - 00:00 15.00 MOB P 00:00 - 12:00 12.00 MOB P 12:00 - 00:00 12.00 MOB P 00:00 - 06:00 6.00 MOB P 06:00 - 00:00 18.00 MOB I P 9/3/2006 00:00 - 06:00 6.00 MOB P 06:00 - 00:00 18.00 RIGU P 9/4/2006 00:00 - 04:30 4.50 RIGU P 04:30 - 08:00 3.50 BOPSU P 08:00 - 11:30 3.50 BOPSU P 11:30 - 15:30 4.00 BOPSU P 15:30 - 18:30 3.00 BOPSU P 18:30 - 19:30 1.00 BOPSU P 19:30 - 00:00 4.50 BOPSU N 9/5/2006 00:00 - 01:00 01:00 - 06:00 1.00 BOPSU~ N 5.00 BOPSU P Description of Operations PRE Start rig move at 00:01 hrs. Move camp, pits and shop to A Pad. Test moving system and prepare sub base for moving. PRE Moving rig sub base from Pad 10 to A Pad. PRE Move rig from Pad 10 to A Pad. Rig is at start of D Pad to A Pad road at 06:00 hrs. Rig sub fell through road at D Pad exit. Wait on malts for road. PRE Moved rig from D-Pad, part way to A-Pad. (1/4 of distance) PRE Moved rig approximately 1/3 of way between D Pad and A Pad on access road. Approximately 1/2 mile. Change out oil on top drive. Work on housekeeping and pit module maintenance projects. Install screens on shakers and prep shakers for milling operations. PRE Reached A Pad at 2200. Staging mats to reach A-17Ai. Complete assembly of iron roughneck. Change oil in spinners. Install chair in sub driver cab. Organize inventory in PPE cabinets. Work on painting and housekeeping projects. PRE Moved rig from A Pad entrance to A-17Ai. Position rig for BOPE assembly. PJSM for raising derrick. Raise derrick. PRE Raise and pin cattle chute, bridle down, pin blocks to top drive, pin torque tube, hang off and secure bridle lines, hang tongs and rig up floor. Prep pits for fluids. Assemble BOP stack and torque flanges. Install hydraulic lines, safety cables and handles. Line up sub over well, lay herculite and spot sub. Berm around sub. Berm and spot pits. Spot camp. PRE Spot shop and service trailers. Hook up interconnect. Take on fresh water and 9.8 ppg NaCI brine. Rig up geronimo line. Rig up and circulate water through lines to check mud system. Identified leaks on shaker system. Blow down lines. DECOMP Hold pre-spud safety meeting with all personnel. Rig accepted at 0600. Address leaks between shakers. Install second annular valve. Rig up circulating lines to well. 0 psi on 9-518" annular. 0 psi on tree above BPV. DECOMP Rig up drill site maintenance lubricator and pull BPV. Check for pressure, 0 psi on tubing. Rig down lubricator. Verify well is static and set TWC. Test from below to 1000 psi, OK. Blow down lines, rig down circulating lines from well. Grease choke and BOP stack valves. DECOMP ND adapter and tree and remove from cellar. Unable to get 7" IJ4S XO to thread into hanger. Will have to spear to pull tubing. DECOMP Nipple up BOPE, turnbuckles and riser. DECOMP Function test BOPE and all preventers and valves. Good test. Annular preventer head locks leaking hydraulic fluid. RREP DECOMP PJSM. Remove riser and riser boot flange. Install lifting equipment. Back out latch jaw screws and remove head. Replace head gasket, inspect inner head seals. Reassemble head and torque head locks. Re-energize accumulator and function bag. RREP DECOMP Nipple up flow riser boot flange, install flow riser, close and secure cellar doors. Install mouse hole. DECOMP Fill up stack, choke and gas buster with fresh water. Circulate mud system to check for leaks. Test BOPE to 250 psi low and 4000 psi high. Test annular to 250 psi low and 2500 psi high. Record on chart. Test witness waived by John Crisp with Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Operations Summary Report Page 2 of 16 Legal Well Name: A-17 Common Well Name: A-17 Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date From - To ~ Hours Task ,Code NPT Phase Description of Operations 9!5!2006 Oi:00 - 06:00 5.00 BOPSU P DECOMP 06:00 - 09:00 3.00 BOPSU N RREP DECOMP 09:00 - 11:00 2.00 BOPSU P DECOMP 11:00 - 14:00 3.00 BOPSU P DECOMP 14:00 - 16:00 2.00 FISH P DECOMP 16:00 - 17:30 1.50 PULL P DECOMP 17:30 - 00:00 6.50 PULL P DECOMP 9/6/2006 00:00 - 09:00 9.00 PULL P DECOMP 09:00 - 16:00 7.00 BOPSU P DECOMP 16:00 - 00:00 8.00 CLEAN P DECOMP 9/7/2006 00:00 - 05:00 5.00 EVAL P DECOMP 05:00 - 07:30 2.50 DHEOP P DECOMP 07:30 - 10:00 2.50 DHB P DECOMP 10:00 - 12:30 2.50 DHB N RREP DECOMP 12:30 - 18:30 6.00 DHB P DECOMP AOGCC. Top pipe rams failed. 3-1/2" x 6" variable. Change out pipe rams to 5-1/2". Resume BOPE test. Lay down test equipment. Blow down mud lines and top drive. Pick up lubricator extention. Pull TWC. Rig down and lay down lubricator. PJSM. Pick up and make up spear, xo, DP single and top drive. Engage hanger. Back off lock down screws. Pull hanger free, release at 175k pull to floor at 180K. Break and lay down spear, xo and DP single. Break out hanger and install safety valve. Clear floor, pick up and make up spooling unit and power tongs. Hang power tongs. Pull and lay down 5.5" IJ4S completion tubing from cut at -8150'. Pull to ball valve and rig down and lay down spooling unit. Clean tloor. Recovered 26 clamps and 7 SS bands. Continue laying down 5.5" tubing from 6029'. Up weight 125K Pull and lay down 5.5" tubing from 5280'. Recovered 206 joints with the cut joint at 21.08'. Pulled 5 GLM and 1 SSSV. Clear floor and pick up test plug, wear bushing and wear bushing tool. Drain stack. Set test plug and change out top pipe rams from 5-1/2" to 3-1/2" x 6" variable. Make up 4" test joint. Fill stack and test joint. Test top rams to 250 psi low and 4000 psi high and record on chart. Test plug not holding. Pull plug, plug clogged with control line plastic. Line up on fresh water, make up test joint to top drive and flush stack. Purge mud cross. Inspect and reset test plug. Run in lock down screws. Test both rams. Test annular to 250 psi low and 2500 psi high with 4" test joint. Back out lock down screws, pull test plug and install wear ring. Break and lay down test joint and clear floor. PJSM. Spot and rig up SWS. Run guage ring and junk basket. Tag 5.5" tubing stump at 8204". Junk basket had approximately 1 to 2 cups of plastic from control lines. Very clean. Change out tools and run USIT. Run USIT log in cement evaluation mode and in corrosion mode to 8170'. POOH with USIT and lay down. Top of hard cement at 2500'. More cement at 2200' making a pull from that depth unlikely. Collar to shoot was at 2090' with the joint to cut at -2070'. Some indications of cement around 3 collars from 1650' to 1740'. Rig up 3 string shot and RIH. Shoot with 12' string from 2084' to 2096'. POOH with all indicators good for a sucsesfull shot. .Run Fasdrill bridge plug and set at 3100'. POOH and rig down wireline. Change out spinners on iron roughneck. Pick up and make up RTTS. RIH to 2073'. Up and down weight 63k. Hold PJSM. Set RTTS with 40k down. Break out top drive. Rig up TIW valve and circulating head on DP. Pump through cement line down DP and test 9-5/8" casing interval from 2070' to 3100' with 4000 psi for 30 minutes. Record on chart. Successful test. Release RTTS. Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To ours. Task ~ Code NPT Phase Description of Operations 9/7/2006 18:30 - 22:00 3.50 STCTPL P DECOMP Rig up Little Red Services to pits and heat 9.8 ppg brine to 110 degrees. Pump hot brine to surface at 5 BPM with 130 psi. 22:00 - 00:00 2.00 STCTPL P DECOMP POOH. Break and lay down RTTS. Clear and clean floor for picking up Multi Cutter Assembly. 9/8/2006 00:00 - 06:00 6.00 STCTPL P DECOMP PU/MU 8-1/4" multi-string cutter, XO, 9- 6.25" DC, 21 joints 5" HWDP, XO). RIH to 2049' locate collar at 2090'. Up weight 95k, down 97k, rotate 95k. Free torque 2k. SPR both #1 and #2 pump 35 spm at 70 psi, 45 spm at 160 psi. Spotted pipe at 2070' and made cut with 195 gpm at 65 rpm and 4k torque. Cut in 15 minutes. Close bag try to establish circulation. Pump up to 700 psi with no returns. Bleed off and check for flow, no flow. Pump back up to 1000 psi then 1500 psi with no returns or pressure at surface. 06:00 - 07:00 1.00 STCTPL P DECOMP Circulate heated brine in 9-5/8" casing at 213 gpm with 520 psi. 07:00 - 08:30 1.50 STCTPL P DECOMP Rig up to reverse circulate 13-3/8" x 9-5/8" annulus. Close bag open upper annulus to cutting tank and stage up to 1500 psi. No pressure at surface or returns to cuttings tank. Bleed off, shut in and blow down cellar circulating lines and rig return line backup on OA. 08:30 - 09:30 1.00 STCTPL P DECOMP Open bag, monitor well and POOH to 1581'. RIH to 1663' and locate casing collar. Pick up 15' and cut 9-5/8" casing at 1648. Free torque 1k at 60 rpm. Cutting torque 1-3k at 300 to 900 psi. Monitor well. 09:30 - 15:00 5.50 STCTPL P DECOMP Close bag, open OA and break circulation with 475 psi. Shut in and hold PJSM. Line up Little Red to cement line. Pressure test lines to 4000 psi. Open bag and pump DP capacity with diesel taking returns to the pits. Shut down, close bag and continue to pump diesel taking returns to the cuttings tank to circulate out arctic pac. Pump out annulur volume and shut down and let diesel soak. Pump remaining 80 bbls of 110 degree diesel and let soak for 1 hour. Line Little Red back up on pits and heat up 9.8 ppg brine. 15:00 - 16:00 1.00 STCTPL P DECOMP Displace diesel out of OA with heated 9.8 ppg brine at 126 gpm with 150 psi initial circulation with a final circulating pressure of 320 psi. 16:00 - 18:30 2.50 STCTPL P DECOMP Shut down pump and monitor well. Shut in OA, blow down circulating lines. Rig down circulating lines, remove blower hose and POOH .Lay down cutter assembly. 18:30 - 21:00 2.50 STCTPL P DECOMP Drain stack, pull wear bushing and install test plug. Change out top rams to 9-5/8". Pick up 9-5/8" test joint and fill stack. Test rams to 250 psi low and 4000 psi high for 5 minutes. Record on chart. 21:00 - 0.00 STCTPL P DECOMP Drain stack, pull and lay down mouse hole and flow riser. Remove turnbuckles and nipple down BOP stack and tubing spool. 9/9/2006 00:00 - 06:30 6.50 STCTPL P DECOMP PJSM. Heat and remove tubing head bushing from casing stump. Remove packoff. Weld emergency slips to casing. Remove old tubing head from cellar. Bring in and install new head. Install secondary annular valve. Set BOP stack and torque flanges. Install turnbuckles, riser and mouse hole. Clear and clean up cellar. 06:30 - 07:30 1.00 STCTPL P DECOMP Fill hole, close blind rams. Line up kill line and test flanges and 13-3/8" casing to 1000 psi for 10 minutes. Test OK, bleed and Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Event Name: REENTER+COMPLETE Start: 9/4/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date i From - To Hours Task I Code NPT Phase I 9/9/2006 06:30 - 07:30 1.00 STCTPL P DECOMP 07:30 - 13:00 5.50 FISH P DECOMP 13:00 - 14:00 1.00 FISH P DECOMP 14:00 - 20:00 6.00 FISH P DECOMP 20:00 - 22:00 2.00 FISH P DECOMP 22:00 - 00:00 2.00 FISH P DECOMP 9/10/2006 100:00 - 01:30 I 1.501 FISH I P I I DECOMP 01:30 - 06:00 4.50 FISH P DECOMP 06:00 - 11:00 5.00 FISH P DECOMP 11:00 - 13:00 2.00 FISH P DECOMP 13:00 - 14:00 1.00 FISH P DECOMP 14:00 - 16:00 2.00 FISH P DECOMP 16:00 - 17:00 1.00 FISH P DECOMP 17:00 - 18:30 1.50 FISH P DECOMP 18:30 - 19:30 1.00 FISH P DECOMP 19:30 - 20:30 1.00 FISH P DECOMP 20:30 - 21:30 1.00 FISH P DECOMP 21:30 - 23:00 1.50 FISH P DECOMP 23:00 - 00:00 1.00 FISH P DECOMP 9/11/2006 00:00 - 00:30 0.50 FISH P DECOMP 00:30 - 01:30 1.00 FISH P DECOMP 01:30 - 03:30 2.00 FISH P DECOMP 03:30 - 05:30 2.00 FISH P DECOMP 05:30 - 09:30 4.00 FISH P DECOMP Page 4 of 16 Spud Date: 12/23/1980 End: 9/22/2006 Description of Operations blow down. PJSM. Change out elevators. Make up Spear assembly. Rig up floor equipment for pulling 9-5/8" casing. Engage spear. Make up top drive and pull 150k increasing to 275k. Would not pull free. Pult 275k and chain down. Bring on pump and pull free at 250 psi. Up weight 110k. Work through stack and set in slips. Remove slip ring, release and pull spear free. Rig up tongs and break out cut joint. Break out spear and lay down. Rig up casing tools. POOH and lay dow 9-5/8" casing from 1648'. Recovered 41 joints and cut joint at 24.72'. Clear and clean up floor from arctic pac. Rig down casing tools. Drain and wash out stack. Install lower test plug. Fill stack with clean water and test tubing spool with bottom flanges to 250 psi low and 4000 psi high. Bleeding off at 150 psi. Run in lockdown screws and retest. Finish testing BOP flanges. BOLDS. Pull test plug and lay down test joint. PJSM. PU/MU washpipe BHA. RIH to 1648'. Install blower hose. Establish parameters. Up weight 90k, down 90k, rotary 90k at 30 rpm with 1 k torque. Pump at 168 gpm with 120 psi. Wash over stump at 1648'. Stage up rotary at 168 gpm with 175 psi. Rotate at 40 rpm with 1-12k torque. Work through cement around collar at 1663' with 5-15k WOB. Wash through to 1708'. Up, down and rotary at 90k at 40 rpm, pumping at 210 gpm with 150 psi. Torque at 4-12k. WOB 2-15k. Increase pump rate tp 252 gpm with 250 psi. Circulate until hole is as clean as possible. Monitor well. Remove blower hose and POOH from 1708'. POOH with washover BHA and stand back. Clear, clean floor and rig down false bowl. Make up 8-1/4" multi string cutter BHA. Cut and slip 78' of drill line. Inspect braking system and under draworks. Change out absorbent. Check loadcell gap, traction motor and service Elmago Spline. Service rig, topdrive and crown. RIH to 1590' and install blower hose. RIH to 1648' and attempt to enter top of 9-5/8" stump. Could not enter stump. POOH to 281'. POOH with multi string cutter. Make up multi string cutter with muleshoe and RIH. Passed through stump at 1648' with no problems. Turn pumps on to 168 gpm, locate collar at 1703' and position cutter at 1708'. Up and down weight 72k. Torque 1 k at 65 rpm. Increase pump to 228 gpm with 950 psi and make cut in 15 minutes with a max torque of 4-6k. Turn off pumps and pull up. Engage pumps move down and verify cut with 10k down. POOH with multi string cutter. Break and lay down multi string cutter. Make up 9-5/8" spear assembly and RIH to 1648'. Up and down weight 71 k. Engage fish, up weight 74k. Monitor well, static. Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Operations Summary Report Page 5 of 16 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To ! A-17 A-17 REENTE NABOBS NABOB Hours R+COM ALASK S 2ES Task ~ I PLET A DRI Code ~ ~ E LLING NPT Start I Rig Rig Phase ~ Spud Date: 12/23/1980 : 9/4/2006 End: 9/22/2006 Release: 10/7/2006 Number: Description of Operations 9/11/2006 09:30 - 10:30 1.00 FISH P DECOMP POOH with fish to 309'. 10:30 - 14:00 3.50 FISH P DECOMP PJSM. Rig up 9-5/8" handling equipment. Lay down jars and bumper sub. POOH and lay down 60' of 9-5/8" casing. 14:00 - 15:00 1.00 FISH P DECOMP Clear and clean up floor of arctic pac. 15:00 - 17:00 2.00 FISH P DECOMP Make up washpipe BHA and RIH to 309'. 17:00 - 20:00 3.00 FISH P DECOMP RIH to 1707' and establish parameters. Up, down and rotate 75k at 30 rpm with 1 k free torque pumping at 168 gpm and 160 psi. Wash over stump to 1767'. Stage up pump and rotary to 40 rpm with 2-7k. Pump at 420 gpm with 550 psi and 2-10k W OB. 20:00 - 21:00 1.00 FISH P DECOMP Circulate bottoms up until clean. Stop pump and monitor well. Static. 21:00 - 22:00 1.00 FISH P DECOMP POOH to 369'. 22:00 - 23:00 1.00 FISH P DECOMP Stand back drill collars and washpipe. Lay down jar, bumper sub and boot baskets. Baskets full of arctic pac. Rig up false bowl. 23:00 - 00:00 1.00 FISH P DECOMP Clear and clean floor. Rig down false bowl. 9/12/2006 00:00 - 02:00 2.00 FISH P DECOMP Clean floor. Pick up spear assembly for 9-5/8" casing and RIH to 322'. Change elevators. 02:00 - 02:30 0.50 FISH P DECOMP RIH to 1708'. 02:30 - 04:00 1.50 FISH P DECOMP Check parameters. Up and down weight 72k. Engage fish and set down 10k on stop ring. Pull free at 125k. Up and down weight 87k. Work pipe and break circulation at 2070'. Stage pumps to 600 gpm with 650 psi. Circulate 2.5 x BU to clean hole. Shut down and monitor. OK 04:00 - 05:00 1.00 FISH P DECOMP POOH 2070' to 322'. 05:00 - 06:00 1.00 FISH P DECOMP Change out elevators, lay down accelerator, stand back drill collars, lay down oil jars, and bumper sub. 06:00 - 07:00 1.00 FISH P DECOMP PJSM with all personnel. Rig up 9 5/8" handling equipment. Lay down spear and cut off joint. 07:00 - 10:30 3.50 FISH P DECOMP Lay down 9 5/8" casing. Recovered top cut off joint 33.90', 8 joints casing, and bottom cut off joint 18.97', total of 362.65'. 10:30 - 11:00 0.50 FISH P DECOMP Rig down 9 5/8" handling equipment. 11:00 - 12:00 1.00 FISH P DECOMP Clear and clean rig floor. 12:00 - 13:30 1.50 FISH P DECOMP Rig up to test BOPE,set lower test plug, run in lock down screws. 13:30 - 19:30 6.00 FISH P DECOMP Test BOPE and related valves to 250 psi (low) 4000 psi (high) hold for 5 minutes and chart. Test Annular preventer to 250 psi (low) 2500 psi (high) hold for 5 minutes and chart.Test witnessed by AOGCC representative Jeff Jones. Rig down test equipment, drain stack, back out lock down screws, and pull test plug. Clear and clean floor. 19:30 - 22:30 3.00 FISH P DECOMP Pick up tools for BHA#9. Clean boot baskets and make up bit to casing scraper. Run in hole to 312' with drill collars and jars. 22:30 - 23:30 1.00 FISH P DECOMP Run in hole from 312' to 1995'. 23:30 - 00:00 0.50 FISH P DECOMP Wash down to casing stump at 2070'. Circulate bottoms up reciprocating pipe. 9/13/2006 00:00 - 00:30 0.50 FISH P DECOMP Circulate bottoms ups 600 gpm,800 psi. Monitor well, blow down surface equipment. 00:30 - 01:30 1.00 FISH P DECOMP POOH from 2070' to BHA C~ 312' change out elevators. 01:30 - 03:00 1.50 FISH P DECOMP Rack back drill collars and lay down boot baskets, scraper and bit. Clear and clean floor. 03:00 - 04:30 1.50 FISH P DECOMP Make up BHA # 10 to 369' change out elevators. Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 9/13/2006 04:30 - 06:00 1.50 FISH P DECOMP 06:00 - 06:30 0.50 FISH P DECOMP 06:30 - 07:00 I 0.501 FISH I P I I DECOMP 07:00 - 08:00 1.00 FISH P DECOMP 08:00 - 08:30 0.50 FISH P DECOMP 08:30 - 12:00 3.50 FISH P DECOMP 12:00 - 14:00 2.001 FISH P I DECOMP 14:00 - 16:30 2.50 FISH P DECOMP 16:30 - 18:00 1.50 FISH P DECOMP 18:00 - 19:00 I 1.001 FISH I P I I DECOMP 19:00 - 19:30 I 0.501 FISH I P I I DECOMP 19:30 - 20:30 1.00 FISH P DECOMP 20:30 - 23:00 2.50 FISH P DECOMP 23:00 - 00:00 1.00 FISH P DECOMP 9/14/2006 00:00 - 00:30 0.50 FISH P DECOMP 00:30 - 01:00 0.50 FISH P DECOMP 01:00 - 01:30 0.50 FISH P DECOMP 01:30 - 02:30 ~ 1.00 FISH ~ P I DECOMP 02:30 - 04:00 1.50 FISH P DECOMP 04:00 - 05:00 1.00 CASE P DECOMP 05:00 - 07:00 2.00 CASE P DECOMP 07:00 - 08:00 1.00 CASE P DECOMP 08:00 - 16:00 I 8.00 CASE P ( DECOMP 16:00 - 17:00 I 1.001 CASE I P I I DECOMP 17:00 - 17:30 I 0.501 CASE I P I I DECOMP Run in hole 369' to 2000'. Up wt. 81 k, down wt. 81 k, rotating wt. 81 k. Wash from 2052' to 2100' at 6 bpm ~ 235 psi. Casing stump at 2070', casing collar at 2090'. Stage pump up to 12 bpm f~ 680 psi. Circulate bottoms up & clean up hole at 2100'. Reciprocate and rotate 12 bpm @ 680 psi. Monitor well (static) blow down top drive. POOH from 2100' to 369'. Change out elevators, stand back drill collars. Lay down BHA from 92' to 59'. Rig up 11 3/4" handling equipment.Lay down wash pipe and shoe. Rig down handling equipment, clear floor. Clean out boot baskets, pick up spear assembly and back out bull nose. Change out grapple, pick up back off tools to floor and send out boot baskets. Make up BHA #11 with 9 drill collars and 21 HWDP to 965' Run in hole 965' to 2367'. Pick up single from pipe shed and rig up headpin and test pump. Space out back off tool across casing collar ~ 2090'. Pressure up to 1500 psi to set anchors. Verify set by slacking off 20k. Pressure up to 4000 psi. Bleed off pressure. Pressure up to 2000 psi (break connection). Continue pressure up / bleed off cycle until 6 turns achieved. Rig down test pump and head pin. Drop circulating sub dart and open with 1800 psi.Lay down single and monitor well (static). POOH from 2367' to 965'. POOH from 965', stand back HWDP and drill collars. Lay down back off tools. Clean and clear drill floor, send tools off rig floor. Make up spear and check grapple. Run in hole 10' to 2070'. Up wt. 61 k,down wt 61 k. Engage fish at 2070'. Set down 10k on stop ring. Pick up 10k over, slack off. Pick up 1 k over, rotate 5 turns left to disengage casing collar. Pick up -stump free. Monitor well (static). POOH 2090' to 10' Lay down fish, recovered 9 5/8" casing stump 19.83'. Break down spear, clear and clean floor. Install long bales. Rig up 9 5/8" casing equipment. PJSM with all personnel, make up and Baker Lok ES cementer. Pick up and make up crossover joint. Run 9 5/8" 401b L-80 TC11 casing .Optimum torque 12,300 ft/Ibs. Centralizer on every joint & fill on every joint. Up wt. 107k, down wt. 107k, rotating wt. 107k. Make up space out pup, and crossover. Run in to 2093' and engage Baker triple connection screw in sub as per Baker representative. Make up and torque to 11 kfUlbs. Pull test to 250k, staging up in 50k increments. Slack off to neutral weight. Make up crossovers to cement head. Make up cement head,and circulating hose. Hold pre-job safety meeting with cementers and all personnel. Pressure up to 1500 psi against casing, bleed off to 0. Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 .Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date I From - To I Hours I Task ~ Code I NPT ( Phase Description of Operations 9/14/2006 17:00 - 17:30 0.50 CASE P DECOMP Pressure up to 2600 psi and open ES cementer. Pump at 6 bpm @330psi while batch mixing cement. 17:30 - 20:00 2.50 CASE P DECOMP Test cement lines to 3500 psi. Cement as per plan, 145 bbl class G 15.8 ppg with gas block tail slurry.Bump plug and close ES cementer at 1500 psi. 35 bbl of 15.8 cement returns back to surface. Bleed off pressure and check floats. Flush BOP stack and flow lines with cement retarder. 20:00 - 21:30 1.50 CASE P DECOMP Rig down cementing equipment, blow down lines and pick up casing string to 100k over string wt. (207k). 21:30 - 00:00 2.50 CASE P DECOMP Drain stack,remove tumbuckles,and nipple down BOP. Set emergency slips as per FMC representatives. Cut off 9 5/8" casing with WACHS cutter. Lay down casing cut off. Remove false bowl and send off rig floor. 9/15/2006 00:00 - 02:30 2.50 CASE DECOMP Rig down WACHS cutter. Install 9 5/8" packoff and run in lock down screws. Nipple up tubing spool and test pack off to 3500 psi. 02:30 - 04:00 1.50 CASE DECOMP Nipple up BOPE. Install mousehole. 04:00 - 05:30 1.50 CASE DECOMP Change riser.Change out top rams from 9 5/8" to 3 1/2" by 6" variables. 05:30.- 08:00 2.50 CASE DECOMP Make up 4" test joint and install test plug. Test 3 1/2" x 6" variable rams to 250psi low and 4000psi high. Test witnessed by BP rep Chris Clemens and Nabors drilling rep Charlie Henley. Pull test plug,and rig down test joint. Set wear ring,clear floor. 08:00 - 10:00 2.00 CASE DECOMP Pick up tools and make up BHA# 14 with used bit and junk baskets to 944'. 10:00 - 11:30 1.50 CASE DECOMP Run in hole from 944' to 1974'. Install Blower hose and establish parameters. Up wt. 95k, down wt. 95k, rotating wt. 95k. Rotary torque 1 k at 40 RPM, 320 psi pump pressure at 350 GPM. 11:30 - 12:00 0.50 CASE DECOMP Wash and rotate from 1974' to 2075',tag cement on top of ES cementer X2075'. Tag ES cementer 2079'. 12:00 - 13:30 1.50 CASE DECOMP Drill ES cementer/plug from 2079',350 GPM X350 psi, 60 PRM ~ 3k ft/Ibs torque, W0B,15-20k. Drill out shoe track and float equipment to 2093'. 13:30 - 14:00 0.50 CASE DECOMP Run in hole from 2093' to 3098' 14:00 - 14:30 0.50 CASE DECOMP Circulate bottoms up 03098' 600 GPM ~ 1120 psi. Reciprocate and rotate. 14:30 - 15:00 0.50 CASE DECOMP Short test 9 5/8" casing and fastdrill plug X3098' to 4000psi. Blow down surface equipment. 15:00 - 16:00 1.00 CASE DECOMP Drill Fastdrill plug ~ 3098'. Up wt. 110k, down wl. 110k, rotating wt. 110k, RPM 60 WOB 20k 356 GPM @450 psi. Circulate bottoms up at 3100',600 GPM ~ 1120psi. Monitor well (static). Remove blower hose. 16:00 - 21:00 5.00 CASE DECOMP Pick up drill pipe from 3100' to 6236'. Annulus became overbalanced causing mud to flow out of drillpipe.Pumped two drill pipe volumes to balance.Run in hole 6236' to top of tubing at 8202'. Up wt. 202k,down wt. 145k, Rotating wt. 170k. 21:00 - 22:00 1.00 CASE DECOMP Pumped 25 bbl hi-vis sweep @ 8202',617 GPM @ 2150 psi. 9.8 ppg in and out. Monitor well (static). Pump dry job,blow down top drive. 22:00 - 00:00 2.00 CASE DECOMP POOH from 8202' to 3376' 9/16/2006 00:00 - 01:30 1.50 CASE P DECOMP POOH 3376' to 945'. Change out handling equipment. Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Event Name: REENTER+COMPLETE Start: 9/4/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To Hours Task Code 9/16/2006 ~ 01:30 - 03:00 1.50 CASE ~ P 03:00 - 06:30 I 3.501 CASE I P 06:30 - 09:30 3.001 CASE P 09:30 - 10:30 1.00 CASE P 10:30-12:30 2.00 STWHIP P 12:30-13:00 0.50 STWHIP P 13:00 - 13:30 0.50 STWHIP P 13:30 - 14:00 0.50 STWHIP P 14:00 - 14:30 0.50 STWHIP P 14:30-18:30 4.00 STWHIP P 18:30 - 19:30 1.001 STWHIP P 19:30 - 20:30 I 1.001 STWHIPI P 20:30 - 00:00 I 3.501 STWHIPI P 9/17/2006 00:00 - 10:00 10.00 STMILL ( P 10:00 - 11:00 1.00 STMILL ~ P 11:00 - 12:00 ~ 1.00 ~ STMILL I P 12:00 - 12:30 0.50 STMILL P 12:30 - 13:30 1.00 STMILL P 13:30 - 14:30 1.00 STMILL P 14:30 - 16:30 2.00 STMILL P 16:30 - 17:30 1.00 STMILL P 17:30 - 18:30 1.00 STMILL P 18:30 - 19:30 1.00 STMILL P 19:30 - 20:00 0.50 STMILL P 20:00 - 21:00 1.00 STMILL P 21:00 - 22:30 1.50 STMILL P 22:30 - 23:00 0.50 STMILL P 23:00 - 23:30 0.50 STMILL P 23:30 - 00:00 0.50 STMILL P 9/18/2006 100:00 - 01:00 I 1.001 STMILL I P NPT I Phase Page 8 of 16 Spud Date: 12/23/1980 End: 9/22/2006 Description of Operations DECOMP POOH with BHA, rack back HWDP and drill collars. Break bit, clean and lay down junk baskets. DECOMP PJSM with wireline and rig crew on wireline operations. Rig up wireline unit for 8 1/2" gauge ring /junk basket run.Run 8 1/2" gauge ring and junk basket on wireline to 8200' POOH. DECOMP Make up EZSV and run in hole on wireline. Correlate to casing collars and set top EZSV at 7874' wireline depth. POOH and rig down wireline unit. DECOMP Test 9 5/8" casing to 4000 psi, chart and hold for 30 minutes. WEXIT PJSM. Make up whipstock assembly to 90'. Orient and upload MWD. WEXIT Make up whipstock assembly to 123'. WEXIT Run in hole with drill collars and HWDP out of derrick to 490'. WEXIT Shallow test MW D tools, 455 gpm ~ 750 psi. WEXIT Run in hole to 1046',change out elevators. WEXIT Run in hole from 1046' to 7773' filling pipe and checking MWD every 3000'. Install blower hose. WEXIT Orient whipstock ~ 7773' to 49 degrees right of highside. 450 gpm ~ 2130psi. Up wt. 202k,down wt. 145k. Tag EZSV at 7867'. Set bottom trip anchor with 18k down.Pull 10k over to confirm anchor set, then set down 35k to shear. Top of window 7846' bottom of window 7863'. WEXIT Pump 45 bbl hi-vis spacer. Displace well to 11.0 ppg LSND milling fluid, 515 gpm C~? 2250 psi. WEXIT Milling 8 1/2" window from 7846' to 7855'. Up wt 175k,down wt. 155k,rotating wt. 165k. Torque off bottom 6k ft/Ibs, on bottom 7k fUlbs. 433gpm C~ 2090 psi. Mud weight in and out 11.0 heavy. WEXIT Milling 8 1/2" window from 7855' to 7872'. Up wt 175k,down wt. 155k,rotating wt. 165k. Torque off bottom 6k ft/Ibs, on bottom 7k fUlbs.433 gpm ~ 2090 psi. Mud weight in and out 11.0 ppg heavy. Recovered 1901bs of metal WEXIT Circulate super-sweep around at 500 gpm ~ 2575 psi. Clean and work window. WEXIT MADD pass formation with LWD from 7860' to 7760' ~ 200 Whr. WEXIT Monitor well (static),pump dry job,blow down top drive. WEXIT Cut and slip 94' of drill line. WEXIT Service top drive /lubricate rig. WEXIT POOH from 7760' to 1024'. Change out elevators. WEXIT Stand back HWDP from 1024' to 377'. Lay down drill collars. WEXIT Download, then stand back MW D tools. WEXIT Caliper and lay down mills. Window mill 1/16" under, watermelon mill in gauge. Clear floor. WEXIT Pull and service wear ring. WEXIT Flush BOP and all surface equipment. Blow down surface equipment. WEXIT Make up 8 1/2" drilling assembly to 81'.Orient motor to MWD. WEXIT Upload MW D tools. WEXIT Make up flex collars and run in 2 stands HWDP to 204'. WEXIT Shallow pulse test MWD tools X204', 460 gpm ~ 900 psi. Blow down surface equipment. WEXIT Make up BHA 204' to 821'. Change out handling equipment Printed: 10/9/2006 10:34:25 AM BP EXPLORATfON Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 2ES Date From - To ; Hours ~ Task Code ~ NPT Start: 9/4/2006 Rig Release: 10/7/2006 Rig Number: Phase 9/18/2006 101:00 - 04:00 I 3.001 STMILL I P I I W EXIT 04:00 - 05:30 I 1.501 STMILL I P I I WEXIT 05:30 - 06:30 I 1.00 I STMILL 1 P I I W EXIT 06:30 - 07:00 I 0.501 DRILL I P I I INTi 07:00 - 14:30 I 7.501 DRILL I P I I INT1 14:30 - 15:00 0.50 DRILL P INT1 15:00 - 00:00 9.00 DRILL P INTi 9/19/2006 100:00 - 09:30 I 9.501 DRILL P I I INT1 09:30 - 14:00 4.50 DRILL N SFAL INTi 14:00 - 00:00 10.00 DRILL P INT1 9/20/2006 100:00 - 05:30 5.501 DRILL I P INT1 05:30 - 07:30 2.00 DRILL N SFAL INTi 07:30 - 22:00 14.50 DRILL P INTi 22:00 - 00:00 I 2.001 DRILL I N I SFAL I INT1 9/21/2006 00:00 - 01:00 1.00 DRILL N SFAL INTi 01:00 - 03:00 2.00 DRILL P INT1 03:00 - 04:00 1.00 DRILL P INT1 04:00 - 05:00 1.00 DRILL P INT1 05:00 - 06:00 1.00 DRILL N SFAL INT1 06:00 - 09:00 3.00 DRILL P INT1 09:00 - 09:30 0.50 DRILL P INT1 09:30 - 15:30 ( 6.00 DRILL I P INT1 Page 9 of 16 Spud Date: 12/23/1980 End: 9/22/2006 Description of Operations Run in hole picking up drill pipe from pipe shed from 821' to 5200' Fill pipe and test MWD at 3000'. Run in hole from derrick 5200' to 7725'. Fill pipe and test MWD at 6000'. Install blower hose. Get parameters,and slow pump rates. Pick up stand and orient toolface to 49 degrees right of highside. Shut pumps down and slide through window to 7868'. Wash to 7872' and drill to 7876'. Up wt. 165k,down wt. 140k, rotating wt. 155k. Circulate well for 10 minutes, shut down pumps and pull above window. Perform FIT X7855' with 11ppg mud weight to 12.5 EMW (550psi). Blow down kill line. Drill 8 1/2" hole from 7876' to 8136', 500 gpm ~ 2950/3150psi. 60-80 RPM with 6k torque off bottom and 7-10k torque on bottom. Up wt. 165k Down wt. 140k, rotating wt. 155k. 11.0 ppg mud weight in and out. Suspend drilling due to problems on A43 (possible well control situation).Circulate bottoms up ~ 8136',502 gpm @ 3175 psi. Drill 8 1/2" hole from 8136' to 8480'. Up wt. 165k down wt. 145k, rotating wt. 155k. 80 RPM, rotary torque 6k off bottom and 7-10k on bottom.Mud weight in and out 11.2 ppg. Drilling ECD +-11.84 ppg. Drill 8 1/2" hole from 8480' to 8918'. Up wt. 175k, down wt. 140k, rotating wt. 155k. 80 RPM, rotary torque 6k off bottom and 7-10k on bottom.Mud weight in and out 11.2 ppg. 500 gpm ~ 3500/3700 psi.Drilling ECD +-11.84 ppg. Replace 2 swabs and 2 liners in both pumps #1 and #2 X8919' circulate at 245 gpm ~ 1100 psi. Drill 8 1/2" hole from 8918' to 9465'. Up wt. 180k, down wt. 145k, rotating wt. 163k. 80 RPM, rotary torque 6k off bottom and 8k on bottom.Mud weight in and out 11.2 ppg. 500 gpm ~ 3750/3900 psi. Drilling ECD +-11.80 ppg. Drill 8 1/2" hole from 9465' to 9751'. Up wt. 180k, down wt. 150k, rotating wt. 165k.W06 13k, 80 RPM, rotary torque 6k off bottom and 8k on bottom.Mud weight in and out 11.2 ppg. 500 gpm ~ 3750/3900 psi. Drilling ECD +-11.77 ppg. Change out pistons and liners on #2 pump, cylinders #1 & #3. Drill 8 1/2" hole from 9751' to 10,393'. Up wt. 190k, down wt. 150k, rotating wt. 170k.W06 13k, 80 RPM, rotary torque 9k off bottom and 10k on bottom.Mud weight in and out 11.2 ppg. 485 gpm ~ 3850/3950 psi. Drilling ECD +-11.80 ppg. Replace discharge valve and seat on pump #1 Cylinder #1. Cracked seat. Circulate at 272 GPM 1400 psi. Reciprocate and rotate. Mud weight in and out 11.2 ppg. Work on mud pump. Mix and pump dry job. Short trip out to window 10,393' to 7811'. Cut and slip 64' of drilling line. Service and inspect drawworks. Service top drive and inspect hoses. Change discharge module on mud pump#1, cylinder #1. Run in hole 7819' to 10,393'. Fill pipe,break circulation, circulate to bring down ECD's, 460 gpm @ 3500 psi. Drill 8 1/2" hole from 10,393' to 10,611'. Up wt. 200k, down wt. Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Page 10 of 16 Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 9/21/2006 09:30 - 15:30 6.00 DRILL P INT1 15:30 - 17:00 1.50 DRILL N DPRB INT1 17:00 - 18:00 1.00 I DRILL I N DPRB INT1 18:00 - 19:00 1.00 DRILL N DPRB INT1 19:00 - 00:00 5.00 DRILL N DPRB INT1 9/22/2006 00:00 - 01:00 1.00 DRILL N DPRB INT1 01:00 - 02:00 1.00 DRILL N DPRB INTi 02:00 - 05:00 3.00 DRILL P INT1 05:00 - 07:30 I 2.501 DRILL I P I I INT7 07:30 - 10:00 2.50 DRILL P INT1 10:00 - 12:00 2.00 DRILL P INT1 12:00 - 13:00 1.00 DRILL P INT7 13:00 - 15:30 2.50 DRILL P INT1 15:30 - 17:00 1.50 CASE P LNR1 17:00 - 18:30 1.50 CASE P LNR1 18:30 - 20:00 1.50 CASE P LNR1 20:00 - 20:30 0.50 CASE P LNR1 20:30 - 00:00 3.50 CASE P LNR1 9/23/2006 00:00 - 02:00 2.00 CASE P INT1 02:00 - 03:00 1.00 CASE P INTi 03:00 - 04:00 1.00 CASE P INT1 04:00 - 06:30 2.50 CASE P INT1 06:30 - 07:30 1.00 CASE P INT1 07:30 - 10:30 3.00 CASE P LNRi 10:30 - 13:30 3.001 CEMT P I LNR1 13:30 - 15:30 2.00 CEMT P LNR1 15:30 - 18:00 2.50 CEMT P LNR1 150k, rotating wt. 173k.WOB 18k, 80 RPM, rotary torque 8k off bottom and 10k on bottom.Mud weight in and out 11.2 ppg. 480 gpm ~ 3880/4000 psi. Drilling ECD +-11.80 ppg. Lost all returns at 10,611.7', shut down pumps. POOH from 10,611' to 8846'. No problems. Fill hole, 6 bbl every 3 stands. Mix and pump 48 bbl LCM pill ~ 8846'. Displace with mud - saw returns to surface with 35 bbl LCM still in drill pipe. Continue to displace LCM pill out bit. Monitor well (static). POOH from 8846' to 7816'. Monitor well (static),clean floor. Monitor well, wait on mud delivery from mud plant. Pump over top of hole,monitor well. Wait on mud. Run in hole from 7719' to 10,612'. Stage pumps up to 450 gpm over 2000 strokes. Circulatel 1/2 times bottoms up at 450 GPM ~ 3240 psi. Mud wt. in and out 11.2 ppg.Spot 48 bbl LCM pill on bottom. Total losses while pumping 14 bbl. POOH from 10,612 to window 9650'. Pump dry job, blow down top drive. POOH from 9650' to 8565',drop rabbit. POOH from 8565'to 7846'. Monitor well,static. POOH from 7846' to 821',loss rate 3 BPH. Lay down HW DP and non mag drill collars from 821' to 81'. Download and flush MWD tools. Lay down BHA from 81'. Clear floor. Rig up 7" handling equipment. Change 3 1/2" x 6" variable rams to 7" rams. Pull wear ring,install test plug and 7" test joint.Test 7" rams to 250 psi low and 4000 psi high. Pull test plug,install wear ring. PJSM. Make up 7" float equipment, check floats. Run 7" 26# L-80 BTC liner to 2420'. Run 7" 26# L-80 BTC liner from 2420 to 2968'. Make up hanger and running tool. Lay down power tongs and change elevators. Make up crossover and pup joint. Change elevators. Circulate 1 liner volume at 3 BPM, 170 psi. Liner up wt. 100k down wt. 90k. Run in 7" 26# L-80 BTC liner on 4" drill pipe, from 2968' to 7800' at 90 feet per minute.Lay down single. Circulate liner volume at 5 BPM, 570 psi. Up wt 180k, down wt. 130k. Run in hole from 7800' to 10,580' at 60 feet per minute. Fill pipe and circulate every 10 stands. Circulate on every other stand from 9900'. Make up cement head and wash to bottom at 10,612'. Break over up wt. 225k,down wt. 130k. Park at up wt. plus one foot at 10,611'. Stage circulating rate up to 5 BPM @950 psi. Circulate and condition .Spot and rig up cementers. Lost returns, fill down backside ~ 3 BPM. Pump 120 BBL and gain returns over the top. Circulate over top of hole at 3 BPM. Wait on mud from mud plant. PJSM with all personnel. Take on mud and batch mix cement. Pump 5 BBL H2O,test lines to 4000 psi. Pump 30 BBL mud push, 72 BBL 12.5 ppg lite Crete lead and 35 BBL 15.8 ppg Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date j From - To Hours ~ Task ~ Code NPT Phase Description of Operations ~_ 9/23/2006 15:30 - 18:00 2.50 CEMT P LNR1 class G tail slurry. Drop plug and displace with 190.5 BBL mud. Pressure up to 3500 psi to set hanger. Set down 50k to verify. Bleed off and check floats, OK. Cement in place 17:55 hrs. 18:00 - 18:30 0.50 CEMT P LNRi Pick up to neutral string weight. Release from hanger with 20 turns to right. Pressure up to 1000, pick up to expose pack-off. Pump 30 BBL, 160 SPM ~ 2000 psi. Slow pump,set down 45k to set packer. Rotate down to verify. 18:30 - 19:30 1.00 CEMT P LNR1 Circulate bottoms up ,160 SPM @ 2050 psi. No cement or mud push to surface. Pump dry job and blow down surface equipment. 19:30 - 20:00 0.50 CEMT P LNR1 Lay down cement head and single. 20:00 - 00:00 4.00 CEMT P LNR1 POOH from 7664' to surface. Lay down running tool,clean and clear floor. 9/24/2006 00:00 - 02:30 2.50 BOPSU P PRODi PJSM Pull wear ring,install test plug. Run in lock down screws,close blind rams and change out top rams to 3 1/2" by 6" variables. 02:30 - 10:00 7.50 BOPSU P PROD1 PJSM Make up test joint,fill stack and manifold. Test BOP and related equipment to 250 psi low and 4000 psi high. Test Annular to 250 psi low and 2500 psi high. Test witnessed by AOGCC rep John Crisp, BP rep Blair Neufeld, and Nabors drilling rep Ron Dalton. Rams tested with 4" and 4 1/2" test joints. 10:00 - 15:00 5.00 DRILL P PROD1 PJSM. Pick up and make up 6 1/8" hole drilling BHA. Orient and upload MWD. Surface test MWD X358', 270 GPM,1600 psi. 15:00 - 19:00 4.00 DRILL P PROD1 Run in hole from 358' to 10,529'. 19:00 - 20:00 1.00 CASE P PROD1 Test 9 5/8" x 7" casing to 4000 psi,hold and chart for 30 minutes. 20:00 - 23:30 3.50 DRILL P PROD1 Drill float equipment and cement from 10,529' to 10,605'. Up wt. 180k, down wt. 140k, rotating wt. 160k. RPM 15, WOB 10-13k, 250 GPM f~ 2050 psi. 23:30 - 00:00 0.50 DRILL P PROD1 PJSM Displace hole to 8.4 ppg Flo-Pro mud. 9/25/2006 00:00 - 02:00 2.00 DRILL P PROD1 Pump 100 BBLS fresh water and follow with 45 BBL hi-vis sweep containing 1 drum of steel tube EP & displace well to 8.4 ppg Flo-Pro mud at 300 GPM,1930 PSI.CIean possum bellies and under side of shakers. Slow pump rates with both pumps. 02:00 - 03:00 1.00 DRILL P PROD1 Drill shoe and 20' of new hole to 10,632' 03:00 - 03:30 0.50 DRILL P PROD1 Pull back into casing. Perform FIT to 10 ppg EMW (750 psi). Mud wt. in and out 8.4ppg. 03:30 - 14:00 10.50 DRILL P PROD1 Drill ahead in 6 1/8" hole 10,632' - 10,792'. Up wt. 185k, down wt. 150k,rotating wt. 168k. 250 GPM 1480 psi off bottom,1590 psi on bottom. Mud wt. in and out 8.4 ppg.Losses begin at 10,755', 1/2 returns losing 150 BPH. 14:00 - 16:30 2.50 DRILL P PROD1 Pump 25 BBL,20 PPB LCM pill around,l/2 returns.Monitor well,static. Spot 25 BBL 20 PPB LCM pill.Pump 1 BBL out of bit every 2 minutes. Monitor well,static.Drill with no returns from 10,792' to 10,796'. Stop and wait on mud as annulus drops below sight. 16:30 - 17:00 0.50 DRILL P PROD1 POOH to shoe,fill backside with 25 BBL, and acheive returns. Wait on orders. 17:00 - 19:00 2.00 DRILL P PROD1 Wait on orders. Fill pits with H2O from reserve pit. Run in hole to 10,796' with no returns. Printed: 10/9/2006 10:34:25 AM BP EXPLORATfON Page 12 of 16 Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase 9/25/2006 19:00 - 00:00 5.00 DRILL P PROD1 9/26/2006 00:00 - 05:30 5.50 DRILL P PROD1 05:30 - 07:00 1.50 DRILL I P PROD1 07:00 - 08:00 1.00 DRILL P PRODi 08:00 - 12:30 I 4.501 DRILL I P I I PROD1 12:30 - 15:30 3.00 DRILL P PROD1 15:30 - 19:30 4.00 DRILL P PROD1 19:30 - 23:30 I 4.001 DRILL I P I I PROD1 23:30 - 00:00 0.50 DRILL P PROD1 9/27/2006 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:00 0.50 DRILL P PROD1 01:00 - 20:00 19.00 DRILL P PRODi 20:00 - 22:00 2.00 DRILL P PROD1 22:00 - 00:00 2.00 DRILL P PROD1 9/28/2006 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 01:30 1.00 DRILL P PROD1 01:30 - 17:30 16.00 DRILL P PROD1 17:30 - 20:00 I 2.501 DRILL I P I I PROD1 20:00 - 21:00 1.001 DRILL P PROD1 21:00 - 23:30 2.501 DRILL I P PROD1 9/29/2006 00:00 - 001:00 01 00 DRILL P I PROD1 PROD1 Description of Operations Drill from 10,796' to 10,918' with fresh water (with clay guard) and mud/lubricant pills. Up wt. 195k, down wt. 150k. 1/2 returns back ~ 10,870',22:00 hrs. Drill 6 1/8" hole from 10,918'. to 11,091'.Up wt. 195k,down wt. 150k,rotating wt. 170k. Off bottom torque 5-7000 fUlbs. 250 GPM,1280 psi off bottom and 1400 psi on bottom. WOB 15-30k. Fresh water with 1/2 to 2/3 returns. Circulate bottoms up, 250 GPM 1300 psi with 75% retums. Short trip 5 stands to shoe at 10612'. Wash and ream tight spot at 10775' to 10760'. Up weight 200k. Drop dart. Establish static loss rate of 120 bph over top of hole. Open circulating sub and pump 70 bbls LCM pill with 20 ppb each of Mix II, Safecarb 250, Safecarb 40 and G-Seal. Displace and spot on backside with dry job. Pull up to 7823' above pill and circulate at 250 gpm with 325 psi to squeeze away LCM pill. Remove blower hose and blow down top drive. POOH to 358' and change out handling equipment. Lay down HWDP and jars. Stand back flex DC's. Down load MWD, break bit and lay down motor. Clear floor. Make up motor, bit and MWD then oreint and upload MWD. Make up BHA to 210'. Surface test MW D at 250 gpm with 1050 psi. Change out handling equipment. RIH to 10567' filling every 3000'. Install blower hose. Up weight 185k, down 155k. Service top drive. Service draworks and replace sperry encoder. RIH to 11090' MD. Drill ahead to 11548' MD. WOB 15k. Up weight 190k, down 145k, RT 170k. Pump at 280 gpm with 1800 psi off bottom, 1950 psi on bottom. Torque 5-7k at 40 rpm. POOH to 10567'. Pump out at 275 gpm with 1700 psi. Back ream at 40 rpm. No problems pulling out of hole. Circulate hi-vis/weighted sweep surface to surface at 280 gpm with 1650 psi. Losses still at 125 bph. Cuttings increased by 40% on bottoms up and 20% with sweep. Bring sweep to surface with 20% increase in cuttings. RIH to 11548' with no problems. Orient and slide to bottom. Drill ahead to 12157' MD, 9036' ND at TD. Up weight 200k, down 140k, RT 170k. Pump at 275 gpm with 1870 psi off, 2000 psi on bottom. Torque 6k off, 7k on at 60 rpm with 5k WOB. Circulate 75 bbls mud sweep surface to surface plus 3500 strokes at 290 gpm with 1900 psi. App. 40% increase in cuttings with sweep. (sand) Short trip to 11400' MD with no problems and back to bottom with no problems. No fill on bottom. Circulate 75 bbls mud sweep surface to surface until cleaned up. App. 30% increase in cuttings but cleaned up shortly after sweep came around. Pump at 290 gpm with 1900 psi. Up weight 190k, down 150k, RT 170k. Torque 4k at 60 rpm. POOH to 11688' MD with no problems. Hole appears in good shape. POOH to 10567' MD at 7" shoe. Up weight 190k. Remove blower hose. Drop dart. Filling over top of hole. Clean pits and Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To ~ Hours Task ~ Code NPT ---- 9/29/2006 00:00 - 01:00 { 1.00 DRILL P 01:00 - 03:00 I 2.00 DRILL P 03:00 - 05:00 2.00 I DRILL P 05:00 - 10:00 5.00 DRILL P 10:00 - 13:00 3.00 DRILL P Start: 9/4/2006 Rig Release: 10/7/2006 Rig Number: Phase PROD1 PROD1 PROD1 PROD1 PROD1 13:00 - 17:00 I 4.001 DRILL I N I DPRB I PRODi 17:00 - 23:00 I 6.001 DRILL I N I DPRB I PROD1 23:00 - 00:00 1.00 EVAL N DPRB PRODt 9/30/2006 00:00 - 02:00 2.00 EVAL N DPRB PROD1 02:00 - 04:00 2.00 EVAL N DPRB PROD1 04:00 - 04:30 0.50 EVAL N DPRB PROD1 04:30 - 06:00 1.50 EVAL N DPRB PROD1 06:00 - 07:30 1.50 EVAL N DPRB PROD1 07:30 - 09:00 1.50 EVAL N DPRB PROD1 09:00 - 10:00 1.00 EVAL N DPRB PROD1 10:00 - 12:30 2.50 EVAL N DPRB PROD1 12:30 - 17:00 4.50 EVAL N DPRB PROD1 17:00 - 21:30 I 4.501 EVAL I N I DPRB I PROD1 21:30 - 00:00 I 2.50 f CASE I P I I RUNPRD 10/1/2006 100:00 - 10:30 I 10.501 CASE I P I I RUNPRD Page 13 of 16 Spud Date: 12/23/1980 End: 9/22/2006 Description of Operations shaker troughs. PJSM. Cut and slip 122' drilling line. Inspect brakes and traction motor brushes. Lube elmago splines. Service top drive and crown. Displace well to fresh water at 525 gpm with 2400 psi. Blow down top drive. POOH to 210'. Lay down BHA. Break bit and lay down motor. Clear and clean floor. Wait on SWS. Spot unit and hold PJSM. PU and rig up tools. MU lubricator and extentions. Run head through lubricator and MU tools. Troubleshoot E-line problem. Check head. Change out DTC tool. Space out lubricator and close upper pipe rams. Fill hole through kill line with charge pump. RIH with 5.975" guage ring and junk basket. Unable to pass 7" liner top at 7664'. POOH. Junk basket full of sludge. Re-run same tool. Still unable to get past top of 7" liner. POOH. Junk basket once again full of sludge. Clean tools and rig down SWS. Clear and clean floor. PU, strap and MU 7" scraper and XO's. PU tandem scraper assembly. Bit, 7" scraper, 32 stands 4" DP, 9-5/8" scraper and jars. RIH to 3030'. RIH to 7600' with 4" DP. Break circulation and work through 7" liner top at 7664'. Pump soda ash surface to surface at 540 gpm. No problems going through liner top. Black water back on circulation. RIH to 10661'. Up weight 180k, down 150k. Circulate and treat fluid with soda ash. Circulate BU and reciprocate at 493 gpm with 2450 psi until clean. Monitor well. POOH to 7664'. Circulate BU at 7" liner top. Pump 493 gpm with 1750 psi until clean. Monitor well. POOH to 3031'. Change out elevators. Break and LD jars and 9-5/8" scraper. Stand back 32 stands 4" DP. Break and LD 7" scraper and bit. Power wash tools. Clear and clean floor. PJSM. Spot and rig up SWS. Pick up lubricator. Make up 5.975" GR/JB. Space out lubricator. Close upper pipe rams. RIH on E-line. Unable to pass 7" liner top. POOH. Open upper pipe rams and pull lubricator. Clean out junk basket. Small amount of sludge in basket but tools covered in sludge. Rig down SWS. Clear and clean floor. PJSM. Rig up to run 4.5" liner. Make up and bakerloc shoe track. Check floats. Run 4.5", 12.6# L-80 BTC-M liner. Fill every 5 joints. RIH with 4-1/2", 12.6# L-80 IBT-M liner. MU torque average at 4k. Fill every 5 joints on the fly. Pick up and make up liner hanger, 10'-4" DP pup and RIH to 1748'. Pump liner volume at 4 bpm with 60 psi. Liner weight 50k. Pick up DP and RIH to 10580', pump DP and liner volume at 168 gpm with 300 psi. Stage up to 210 gpm at 460 psi. Up weight 175k, down 155k. Blow down top drive. Run liner in open hole to 12126'. Make up cement head on single. Rig up cement manifold and hoses. Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ From - To __ --- 10/1/2006 ~ 10:30 - 13:45 10/2/2006 13:45 - 14:15 14:15 - 14:30 14:30 - 15:15 15:15 - 15:25 15:25 - 16:30 16:30 - 18:00 18:00 - 23:00 23:00 -00:00 00:00 - 01:00 01:00 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 09:00 09:00 - 10:30 10:30 - 18:00 18:00 - 20:00 A-17 A-17 REENTE NABOBS NABOBS Hours R+COM ALASK 2ES Task PLET A DRI Code E LLING NPT Start I Rig Rig Phas Spud Date: 12/23/1980 : 9/4/2006 End: 9/22/2006 Release: 10/7/2006 Number: ~ Description of Operations 3.25 CEMT P RUNPRD Break circulation at 147 gpm with 360 psi. RIH to 12157'. Up weight 190k, down 150k. Pick up 3' and circulate 3 x open hole volume at 126 gpm with 370 psi. Losses at 100 bph. Continue to circulate while cementers mix slurry. 0.50 CEMT P RUNPRD Switch to cementers and pump 5 bbl H2O, pressure test to 4000 psi. Mix and pump 29 bbls mud push spacer at 12.2 ppg with 2 ppb Cem Net. 0.25 CEMT P RUNPRD Pump 15.8 ppg class G cement at 4 bpm with 650 psi. No returns initially. Move pipe and started getting returns. Pump at 4.2 bpm and 575 psi with 50 bbls away, 4.2 bpm/600 psi at 75 bbls. Slow to 3 bpm with 85 bbls away. Total 102 bbls total cement pumped. 0.75 CEMT P RUNPRD Flush cement line to flow line. Release DP wiper plug and displace with 8.34 ppg perf pill. Pump 47 bbls at 5 bpm with 275 psi to 2.5 bpm with 92 psi. Switch to H2O. 0.17 CEMT P RUNPRD Continue displacement with H2O. Caught cement with 79 bbls away. Slow to 2 bpm with 85 bbls away. Saw psi increase with 111 bbls away. Pressure continued to run high as if packing off then establish normal circulation. Continue at 2 bpm and bump plug at 132 bbls away. CIP at 15:25 hrs. 1.08 CEMT P RUNPRD Pressure up to 3500 psi to set liner hanger. Slack off and confirm set by Baker Rep. Bleed off pressure and verify float holding. From the time cement rounded the shoe we lost 80-85 bbls until plug bumped. Release from hanger. Put 1000 psi on DP and pick up. Lost pressure. Pick up and circulate 500 strokes at 200 spm. Stopped early because of fluid being pushed away. Pull up to expose dogs and set down to set liner top packer. Set OK. Continue to circulate at max rate of 500 gpm with 3350 psi. Got back spacer and 3 bbls of cement. 1.50 CEMT P RUNPRD PJSM. Break and LD cement head and single. Blow down lines. Clean out cement manifold. 5.00 CEMT P RUNPRD POOH. Change out elevators. Break and LD pup, XO and running tool. Clear and clean hole. 1.00 CLEAN N DPRB CLEAN PU baker tools, mule shoe, 1 jt DP, XO, 9-5/8" scraper. 1.00 CLEAN N DPRB CLEAN MU BHA with 4" HT-40 Muleshoe, single joint 4" DP and 9 5/8" scraper. RIH to 45'. 3.00 CLEAN N DPRB CLEAN RIH to 6544' 0.50 CLEAN N DPRB CLEAN Reverse circulate 2 DP volumes at 367 gpm with 1450 psi. Sludge contaminated fluid back with sludge material. 0.50 CLEAN N DPRB CLEAN RIH to 7" liner top at 7661' and tag up. Pull up to space out and hook up to reverse circulate. 1.00 CLEAN N DPRB CLEAN Reverse circulate DP volume. Work pipe back down to 7" liner top and reverse circulate at 400 gpm with 1850 psi. Monitor well 3.00 CLEAN N DPRB CLEAN Pump dry job. POOH to BHA. 1.50 CLEAN N DPRB CLEAN LD BHA. Clear and clean floor. PU and MU 7" scraper BHA. Used 6-1/8" tri-cone bit, 7" scraper and RIH to 8'. 7.50 CLEAN N DPRB CLEAN RIH to 7823'. PJSM. Rig up circulating head. Line up and reverse circulate at 400 gpm with 2000 psi until clean. RIH to 8652', 9587' and liner top of 10428' and reverse circulate at each depth. Circulate out -2.5 bbls sludge. 2.00 CLEAN N DPRB CLEAN Reverse circulate and displace well to clean, hot seawater at 350 gpm with 1500 psi. Rig down circulating head and blow Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: A-17 Common Well Name: A-17 Spud Date: 12/23/1980 Event Name: REENTER+COMPLETE Start: 9/4/2006 End: 9/22/2006 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/7/2006 Rig Name: NABOBS 2ES Rig Number: Date From - To .Hours Task Code --___ __ L- --- - 10/2/2006 18:00 - 20:00 2.00 CLEAN N 20:00 - 23:00 3.00 CLEAN N 23:00 - 00:00 1.00 CLEAN N 10/3/2006 00:00 - 01:30 1.50 CLEAN N 01:30 - 03:00 1.50 CLEAN N 03:00 - 17:00 14.00 EVAL P 17:00 - 18:00 1.00 I CLEAN P 18:00 - 22:30 I 4.501 CLEAN N 22:30 - 00:00 1.50 CLEAN N 10/4/2006 00:00 - 02:00 2.00 CLEAN N 02:00 - 03:00 I 1.00 I CLEAN I N 03:00 - 03:30 I 0.501 CLEAN I N 03:30 - 06:30 3.00 I CLEAN N 06:30 - 09:00 2.50 CLEAN N 09:00 - 11:30 2.50 CLEAN P 11:30 - 13:30 I 2.00 I CLEAN I N 13:30 - 19:00 5.501 CLEAN I N 19:00 - 00:00 I 5.001 PERFOBI P 10/5/2006 100:00 - 05:00 5.00 ~ PERFOB P 05:00 - 08:00 I 3.001 PERFOBI P NPT Phase ~ Description of Operations DPRB CLEAN down kill line. DPRB CLEAN POOH to 3800'. DPRB CLEAN Cut and slip 72' of drilling line. Inspect brakes, traction motor brushes and tube elmago splines. DPRB CLEAN POOH with 7" scraper. Up weight 85k, down 85k. DPRB CLEAN Lay down BHA. Clean and clear floor. Pipe coated with sludge. OTHCMP PJSM with SWS. PU and rig up logging tools. Surface test tools-OK. Run in hole with USIT log. Log 7" liner from 10400' to 7664'. PJSM. RD SWS. USIT tool packed off with sludge. Attempt to clean USIT assembly. Pull supersucker hose to rig floor and clean sludge out from under rotory table. Clear and clean floor. CLEAN Line up and test casing to 4000 psi for 30 minutes - OK. Recorded on chart. DPRB CLEAN PJSM. PU tools and rig up floor. Power and backup tongs, slips and elevators. MU junk mill and XO. PU 54 joints 2-7/8" PAC DP and XO's to 1687'. RD PAC handling equipment. MU 1 stand of 4" DP and circulate pipe volume. DPRB CLEAN RIH to 3550' for 4.5" liner cleanout run. DPRB CLEAN RIH from 3550' to 7" liner top at 7664'. Break circulation at 120 gpm with 465 psi. DPRB CLEAN RiH to 10428', break circulation and wash through 4.5" liner top. Pump at 184 gpm with 1045 psi. Up weight 165k, down 150k, RT 155k with 2.5k torque. DPRB CLEAN RIH to 12044', break circulation at 184 gpm with 1200 psi. RIH to 12044 break circulation, wash down and tag top of landing collar at 12062', 3' high. DPRB CLEAN Stage pumps up to 245 gpm with 2225 psi. Circulate out pert pill. Spot new pert pill in 4.5" liner at 12062'. Up weight 180k, down 155k, RT 165k. Torque 2.5k DPRB CLEAN Monitor well - OK. POOH to 10362'. Pump dry job. POOH to 6908'. CLEAN D1 drill. D6 drill. Simulate stripping operation with all personnel. Strip in hole from 6908' to 7188'. (3 stands) Bleed off all pressure. Blow down BOPE. Realign valves to normal. DPRB CLEAN POOH to 6908 and retrieve dart and TIW valves. POOH to 1687'. There was sludge buildup on the 4" DP starting at 5696'. The PAC DP came out clean. DPRB CLEAN PJSM. RU 2-7/8" handling equipment. Break and LD 54 joint PAC DP, XO's and Mill. Shut down. PJSM, knock ice out of derrick. Resume lay down of 2-7/8" PAC. Clean floor. OTHCMP PJSM. PU and rig up floor to run guns. MU guns and firing head to 187'. PU 48 joints 2-7/8" PAC DP, XO's and 10' - 4" DP pup to 1697'. RIH to 2630'. OTHCMP RIH from 2630'. Stop and clear derrick of ice. Tag landing collar at 12062' at 0500. Up weight 180k, down 155k. Pull 2 stands and space out for firing depth. Establish pump rates and pressures. OTHCMP PJSM. Perform dummy run firing sequence. Perform primary firing sequence as directed with no indications of firing. Repeat primary sequence with no indication of firing. Perform secondary firing sequence by pressuring up to 3000 psi for 5 minutes. Pressure dropped to 2200 psi and wellbore fluid level Printed: 10/9/2006 10:34:25 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date I From - To 10/5/2006 105:00 - 08:00 A-17 A-17 REENTER+COMPLETE NABOBS ALASKA DRILLING NABOBS 2ES Hours ~) Task Code NPT 3.001 PERFOBI P 08:00 - 00:00 16.00 PERFOB P 10/6/2006 00:00 - 01:30 1.50 PERFOB~ P 01:30 - 05:00 3.50 PERFO P 05:00 - 06:30 ( 1.50 06:30 - 22:00 I 15.50 22:00 - 00:00 I 2.00 10/7/2006 00:00 - 00:30 0.50 00:30 - 04:00 3.50 04:00 - 06:30 2.50 06:30 - 09:00 I 2.50 I BOPSUFi P 09:00 - 12:30 I 3.501 WHSUR I P 12:30 - 14:00 1.50 WHSUR P 14:00 - 18:00 4.00 WHSUR P 18:00 - 19:00 I 1.001 WHSUR I P 19:00 - 22:00 I 3.001 W HSUR I P Page 16 of 16 Spud Date: 12/23/1980 Start: 9/4/2006 End: 9/22/2006 I Rig Release: 10/7/2006 Rig Number: Phase Description of Operations OTHCMP dropped indicating successful firing of guns. POOH to 11775'. Monitor well for 10 minutes with a 2 bbl loss. Blow down top drive and kill line. OTHCMP POOH. LD 4" DP to 1790'. Wire strip sludge off pipe. Shut down twice to knock ice out of derrick. Run in 4" DP from derrick and POOH laying down. RU tongs and handling equipment for 2-7/8" DP and POOH laying down. Loosing approximately 2 to 3 bph. OTHCMP PJSM. POOH laying down 2-7/8" PAC DP. OTHCMP PJSM. POOH laying down pert guns. Rig down 2-7/8" handling equipment. Clear floor, pull wear bushings. Clean floor. RUNCMP PJSM. PU and rig up to run 4.5", 12.6# L-80 TCII tubing. RUNCMP RIH with 4.5" 12.6# L-80 TCII tubing to 10430'. Bakerloc connections below packer. Torque turn connections to 3850 ft/Ibs. Used Jet Lube Seal Guard thread dope. Up weight 135k, down 115k. RUNCMP Tag up on 4.5" liner top. Pull up and space out. PU and MU space out pups totaling 13.82'. (#1 - 2.02, #2 - 9.77, #3 - 2.03) Make up joint #248, hanger and landing joint. RIH and land tubing at 10429.78'. Run in lockdown screws and torque to 450 fUlbs per FMC rep. Rig up lines to reverse circulate. RUNCMP RU circulating lines. Test lines to 4000 psi. RUNCMP Reverse circulate corrosion inhibitor at 126 gpm with 250 psi. RUNCMP Drop 1-7/8" ball and rod. Pressure up to 4000 psi. Set packer. Pressure appears to be leaking past ball and rod. Check all lines and annulus. No leaks. Pressure back up to 4000 psi, won't hold. Bleed tubing to 2050 psi, pump annulur to 4000 psi and test against packer. Thirty minute test on packer and annulus with flat line on chart. Tubing still leaking. Shear DCK valve. Valve sheared ok, test with pumps. Fluid pumped both ways. Set TWC. Test from below to 1000 psi - OK. RUNCMP Blow down all surface lines. Rig down circulating lines. ND BOPE. RUNCMP NU tree and adapter flange. Test tree and adapter to 5000 psi. Record on chart- OK. Bleed off pressure. RUNCMP RU DSM lubricator. Pull TWC. RD lubricator. RUNCMP Rig up Little Red for freeze protection. Pressure test lines to 3000 psi. Pump 150 bbls diesel at 126 gpm with 1200 psi. AIIow to U-tube until balanced. Clean out under rotary table with supersucker while U-tubing. Blow down Tines and rig down. RUNCMP Set BPV and test from below to 1000 psi - OK. Bleed off pressure. Blow down and rig down lines. RUNCMP Remove secondary annulur valve. Pick up tools and clean up cellar area. Prep pits for move. Rig released at 2200 hrs. Printed: 10/9/2006 10:34:25 AM Halliburton Company Survey Report Company: BP Amoco Uare: 10i'10%2006 Time: 15:58:16 Page: ] field: Prudhoe Bay Co -ordina~cl,Af:) Reference: VJeli. A-17 True North Site: PB A Pad ~c rtical II~U) Kc lcrcurc: A-17A_ 79.6 ' Well: A-17 ticc~iou (~5) Refer ence: Well (o oON_O O OE IF1 71Azi) i W'cllpath: A-17A Su r~c~ C~alcul:~lion llcthort: tt4inimum Curva ture Db: Oracle 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 Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: A-17 Slot Name: A-17 Well Position: +N/-S 1169.18 ft Northing: 5947319.00 ft Latitude: 70 15 46.707 N +E/-W 911.67 ft Easting : 654397.00 ft Longitude: 148 45 6.245 W Position Uncertainty: 0.00 ft Wellpath: A-17A Drilled From: A-17 500292052001 Tie-on Depth: 7799.87 ft Current Datum: A-17A: Height 79.64 ft Above System Datum: Mean Sea Level Magnetic Data: 9/3/2006 Declination: 24.20 deg Field Strength: 57643 nT Mag Dip Angl e: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 31.07 0.00 0.00 164.71 Survey Program for Definitive Wellpath Date: 10/10/2006 Validated: Yes V ersion: 4 Actual From To Survey T oolcode Tool Name ft ft 99.87 7799.87 1 : Sperry-Sun BOSS gyro multi B OSS-GYRO Sperry-Sun BOSS gyro multishot 7846.00 12108.26 A-17A IIFR+MS+SAG (7846.00-121 MWD+IFR+MS MWD +IFR + Multi Sta tion Survey MD Inrl ~zim l ~ D tic,.'I ~'D N/S E/W Map\ MapE Tool ~ ft deg deq R ft ft ft tt ft ~, 31.07 0.00 0.00 31.07 -48.57 0.00 0.00 5947319.00 654397.00 TIE LINE 99.87 0.20 178.90 99.87 20.23 -0.12 0.00 5947318.88 654397.00 BOSS-GYRO 199.87 0.37 190.69 199.87 120.23 -0.61 -0.05 5947318.39 654396.96 BOSS-GYRO 299.87 0.08 166.50 299.87 220.23 -1.00 -0.10 5947318.00 654396.92 BOSS-GYRO 399.87 0.07 5.30 399.87 320.23 -1.00 -0.08 5947317.99 654396.94 BOSS-GYRO 499.87 0.12 314.50 499.87 420.23 -0.87 -0.14 5947318.13 654396.87 BOSS-GYRO 599.87 0.33 228.79 599.87 520.23 -0.99 -0.44 5947318.01 654396.58 BOSS-GYRO 699.87 0.17 233.29 699.87 620.23 -1.26 -0.77 5947317.72 654396.25 BOSS-GYRO 799.87 0.02 168.31 799.87 720.23 -1.37 -0.89 5947317.61 654396.14 BOSS-GYRO 899.87 0.60 55.59 899.86 820.22 -1.09 -0.45 5947317.90 654396.57 BOSS-GYRO 999.87 0.27 147.70 999.86 920.22 -0.99 0.11 5947318.01 654397.13 BOSS-GYRO 1099.87 0.10 91.11 1099.86 1020.22 -1.20 0.32 5947317.81 654397.34 BOSS-GYRO 1199.87 0.35 15.80 1199.86 1120.22 -0.90 0.49 5947318.11 654397.51 BOSS-GYRO 1299.87 0.17 259.79 1299.86 1220.22 -0.64 0.43 5947318.37 .654397.44 BOSS-GYRO 1399.87 0.08 214.39 1399.86 1320.22 -0.72 0.24 5947318.29 654397.26 BOSS-GYRO 1499.87 0.13 149.50 1499.86 1420.22 -0.88 0.26 5947318.13 654397.28 BOSS-GYRO 1599.87 0.25 80.40 1599.86 1520.22 -0.94 0.53 5947318.07 654397.55 BOSS-GYRO 1699.87 0.15 80.59 1699.86 1620.22 -0.88 0.88 5947318.14 654397.89 BOSS-GYRO 1799.87 0.28 58.00 1799.86 1720.22 -0.73 1.21 5947318.30 654398.23 BOSS-GYRO 1899.87 0.37 46.20 1899.86 1820.22 -0.37 1.65 5947318.66 654398.66 BOSS-GYRO 1999.87 0.30 54.59 1999.85 1920.21 0.00 2.10 5947319.04 654399.10 BOSS-GYRO 2099.87 0.82 55.90 2099.85 2020.21 0.55 2.91 5947319.61 654399.89 BOSS-GYRO 2199.87 0.47 38.29 2199.84 2120.20 1.28 3.75 5947320.35 654400.72 BOSS-GYRO 2299.87 0.72 65.00 2299.84 2220.20 1.86 4.58 5947320.96 654401.54 BOSS-GYRO 2399.87 0.50 95.41 2399.83 2320.19 2.09 5.58 5947321.20 654402.53 BOSS-GYRO 2499.87 0.40 63.00 2499.83 2420.19 2.21 6.32 5947321.33 654403.28 BOSS-GYRO 2599.87 0.45 64.90 2599.83 2520.19 2.53 6.99 5947321.67 654403.94 BOSS-GYRO 2699.87 0.90 81.69 2699.82 2620.18 2.81 8.12 5947321.98 654405.06 BOSS-GYRO 2799.87 1.37 147.40 2799.80 2720.16 1.92 9.55 5947321.11 654406.50 BOSS-GYRO Halliburton Company Survey Report Company: BP Amoco Darr. 10110;2006 Time: 15:58:16 Page: 2 ~~ F'icld: Prudhoe Bay Co-ordin:uc(~~) Reference: Well: A-17, TrU~ Nafh Site: PB A Pad Vertical ~7~ ll) Reference: A-17A: 79.6 Well: A-17 Section (1ti~ Reference: Well (O.OON,O.OOE,1b1 71Azi) Wellpath: A-17A Survey Calculation Method: Minimum Curvature Db: Oracle Surcev Mll Incl Azim I~'Il ~~~TVD N/S N,/W MapN ~lapl~, 7001 ft deg deg ft ft ft ft ft it __ _ _ _ - 2849.87 3.90 161.00 2849.75 2770.11 -0.19 10.42 5947319.02 654407.42 BOSS-GYRO 2899.87 6.75 159.31 2899.53 2819.89 -4.55 12.01 5947314.70 654409.10 BOSS-GYRO 2949.87 9.85 167.70 2949.00 2869.36 -11.48 13.96 5947307.81 654411.19 BOSS-GYRO 2999.87 12.92 166.20 2998.01 2918.37 -21.09 16.21 5947298.25 654413.64 BOSS-GYRO 3049.87 15.57 167.50 3046.47 2966.83 -33.07 18.99 5947286.33 654416.67 BOSS-GYRO 3099.87 17.02 165.90 3094.46 3014.82 -46.72 22.23 5947272.75 654420.18 BOSS-GYRO 3149.87 18.47 165.70 3142.08 3062.44 -61.49 25.97 5947258.06 654424.22 BOSS-GYRO 3199.87 20.20 163.00 3189.26 3109.62 -77.43 30.45 5947242.22 654429.03 BOSS-GYRO 3299.87 22.97 161.00 3282.24 3202.60 -112.39 41.85 5947207.50 654441.14 BOSS-GYRO 3399.87 25.95 159.11 3373.25 3293.61 -151.29 56.01 5947168.90 654456.10 BOSS-GYRO 3499.87 28.87 159.11 3462.02 3382.38 -194.30 72.42 5947126.24 654473.39 BOSS-GYRO 3599.87 31.80 159.00 3548.31 3468.67 -241.46 90.48 5947079.46 654492.40 BOSS-GYRO 3699.87 35.17 158.90 3631.71 3552.07 -292.94 110.29 5947028.40 654513.27 BOSS-GYRO 3799.87 36.48 158.61 3712.79 3633.15 -347.49 131.50 5946974.30 654535.59 BOSS-GYRO 3899.87 36.32 158.90 3793.27 3713.63 -402.80 153.01 5946919.45 654558.22 BOSS-GYRO 3999.87 36.17 158.61 3873.92 3794.28 -457.91 174.43 5946864.80 654580.77 BOSS-GYRO 4099.87 35.87 158.70 3954.81 3875.17 -512.68 195.84 5946810.48 654603.29 BOSS-GYRO 4199.87 35.75 158.61 4035.90 3956.26 -567.18 217.13 5946756.44 654625.70 BOSS-GYRO 4299.87 35.45 158.81 4117.21 4037.57 -621.42 238.27 5946702.64 654647.94 BOSS-GYRO 4399.87 35.38 159.00 4198.71 4119.07 -675.48 259.13 5946649.02 654669.90 BOSS-GYRO 4499.87 35.37 158.50 4280.25 4200.61 -729.44 280.11 5946595.51 654691.99 BOSS-GYRO 4599.87 35.43 158.40 4361.76 4282.12 -783.32 301.39 5946542.08 654714.36 BOSS-GYRO 4699.87 35.52 158.70 4443.20 4363.56 -837.33 322.61 5946488.52 654736.69 BOSS-GYRO 4799.87 35.47 158.70 4524.61 4444.97 -891.43 343.70 5946434.87 654758.88 BOSS-GYRO 4899.87 35.47 159.11 4606.06 4526.42 -945.57 364.58 5946381.18 654780.87 BOSS-GYRO 4999.87 35.33 159.20 4687.57 4607.93 -999.70 385.20 5946327.48 654802.59 BOSS-GYRO 5099.87 35.13 159.50 4769.25 4689.61 -1053.68 405.54 5946273.93 654824.03 BOSS-GYRO 5199.87 35.23 159.61 4850.99 4771.35 -1107.67 425.67 5946220.37 654845.26 BOSS-GYRO 5299.87 35.03 160.20 4932.77 4853.13 -1161.71 445.44 5946166.75 654866.13 BOSS-GYRO 5399.87 35.35 160.61 5014.50 4934.86 -1216.00 464.76 5946112.87 654886.57 BOSS-GYRO 5499.87 36.00 161.70 5095.73 5016.09 -1271.19 483.60 5946058.08 654906.52 BOSS-GYRO 5599.87 36.00 162.31 5176.63 5096.99 -1327.09 501.76 5946002.57 654925.82 BOSS-GYRO 5699.87 35.92 163.40 5257.58 5177.94 -1383.21 519.07 5945946.83 654944.28 BOSS-GYRO 5799.87 35.78 163.70 5338.63 5258.99 -1439.37 535.65 5945891.02 654962.01 BOSS-GYRO 5899.87 35.77 163.90 5419.76 5340.12 -1495.51 551.96 5945835.23 654979.47 BOSS-GYRO 5999.87 35.65 164.40 5500.96 5421.32 -1551.66 567.90 5945779.42 654996.56 BOSS-GYRO 6099.87 35.72 163.81 5582.19 5502.55 -1607.76 583.88 5945723.66 655013.68 BOSS-GYRO 6199.87 35.58 163.70 5663.45 5583.81 -1663.72 600.18 5945668.06 655031.13 BOSS-GYRO 6299.87 35.40 163.50 5744.87 5665.23 -1719.41 616.57 5945612.72 655048.65 BOSS-GYRO 6399.87 35.65 163.20 5826.25 5746.61 -1775.08 633.22 5945557.40 655066.44 BOSS-GYRO 6499.87 35.45 163.11 5907.61 5827.97 -1830.73 650.07 5945502.12 655084.43 BOSS-GYRO 6599.87 35.27 163.20 5989.17 5909.53 -1886.12 666.84 5945447.09 655102.33 BOSS-GYRO 6699.87 35.25 163.20 6070.82 5991.18 -1941.38 683.53 5945392.18 655120.14 BOSS-GYRO 6799.87 35.03 162.81 6152.60 6072.96 -1996.43 700.35 5945337.50 655138.09 BOSS-GYRO 6899.87 34.62 162.61 6234.69 6155.05 -2050.95 717.32 5945283.34 655156.17 BOSS-GYRO 6999.87 34.42 162.31 6317.08 6237.44 -2104.99 734.40 5945229.67 655174.35 BOSS-GYRO 7099.87 33.98 162.20 6399.79 6320.15 -2158.52 751.53 5945176.50 655192.58 BOSS-GYRO 7199.87 33.60 161.90 6482.89 6403.25 -2211.43 768.67 5945123.96 655210.80 BOSS-GYRO 7299.87 33.10 161.90 6566.43 6486.79 -2263.68 785.75 5945072.07 655228.94 BOSS-GYRO 7399.87 32.43 161.70 6650.52 6570.88 -2315.10 802.65 5945021.02 655246.89 BOSS-GYRO 7499.87 31.63 161.70 6735.29 6655.65 -2365.45 819.31 5944971.02 655264.57 BOSS-GYRO 7599.87 30.95 161.50 6820.75 6741.11 -2414.73 835.70 5944922.09 655281.97 BOSS-GYRO ' ~ Halliburton Company Survey Report Comp:un: BP Amoco DatE~: 10i10r2006 Tiny 15 5d 1F Pa;;c 3 Field: Prudhoe Bay Co-ordinalc~.Ak:) Hc(erenee: well. A-17 Tn~e North time: PB A Pad Vertical ~llU1 Kcfercuce: A-17A~ 79-6 ~~ell: A-17 ticctiou (~~ti~ Nclcrence: Well (O OON.QOOE,164 71Azi} I ~~ellpath: A-17A Curer Calculation Method: Minimum Curvature Db: Oracle - -- ---- -- - -- - I' Su rve~' A1ll lncl ~iim l~D SysTVD N/S Fi1~ Map~V ~~ MapE 7bul ft deg deg ft it ft K ft ft 7699.87 30.52 161.40 6906.70 6827.06 -2463.18 851.96 5944873.98 655299.22 BOSS-GYRO 7799.87 29.43 161.81 6993.32 6913.68 -2510.59 867.73 5944826.91 655315.96 BOSS-GYRO 7846.00 29.40 161.95 7033.51 6953.87 -2532.12 874.77 5944805.53 655323.44 MWD+IFR+MS 7873.84 30.10 164.30 7057.68 6978.04 -2545.34 878.78 5944792.40 655327.72 MWD+IFR+MS 7967.70 34.26 172.30 7137.14 7057.50 -2594.22 888.70 5944743.73 655338.64 MWD+IFR+MS 8060.19 40.14 175.72 7210.79 7131.15 -2649.81 894.41 5944688.28 655345.49 MWD+IFR+MS 8152.48 43.76 178.61 7279.42 7199.78 -2711.40 897.41 5944626.76 655349.75 MWD+IFR+MS 8244.37 45.81 181.07 7344.64 7265.00 -2776.12 897.57 5944562.07 655351.23 MWD+IFR+MS 8336.88 47.61 180.80 7408.07 7328.43 -2843.45 896.47 5944494.74 655351.52 MWD+IFR+MS 8429.05 49.48 184.64 7469.10 7389.46 -2912.42 893.16 5944425.72 655349.62 MWD+IFR+MS 8523.12 51.37 183.67 7529.03 7449.39 -2984.73 887.91 5944353.32 655345.86 MWD+IFR+MS 8616.41 50.46 184.64 7587.85 7508.21 -3056.95 882.67 5944281.01 655342.10 MWD+IFR+MS 8710.02 49.57 183.62 7648.00 7568.36 -3128.49 877.50 5944209.39 655338.40 MWD+IFR+MS 8805.13 50.04 184.13 7709.38 7629.74 -3200.97 872.59 5944136.82 655334.98 MWD+IFR+MS 8897.55 50.80 183.55 7768.27 7688.63 -3272.04 867.82 5944065.68 655331.67 MWD+IFR+MS 8990.99 51.82 185.46 7826.68 7747.04 -3344.74 862.09 5943992.88 655327.42 MWD+IFR+MS 9083.43 52.28 187.00 7883.53 7803.89 -3417.20 854.17 5943920.28 655321.00 MWD+IFR+MS 9176.07 51.18 187.15 7940.91 7861.27 -3489.38 845.22 5943847.94 655313.52 MWD+IFR+MS 9269.86 50.91 186.49 7999.88 7920.24 -3561.80 836.55 5943775.36 655306.35 MWD+IFR+MS 9366.23 50.55 185.99 8060.88 7981.24 -3635.96 828.44 5943701.05 655299.76 MWD+IFR+MS 9452.41 49.57 186.72 8116.20 8036.56 -3701.63 821.13 5943635.25 655293.80 MWD+IFR+MS 9543.89 49.59 184.89 8175.52 8095.88 -3770.91 814.09 5943565.85 655288.18 MWD+IFR+MS 9642.76 50.70 182.67 8238.88 8159.24 -3846.64 809.10 5943490.04 655284.74 MWD+IFR+MS 9735.75 50.36 182.14 8297.99 8218.35 -3918.36 806.09 5943418.28 655283.20 MWD+IFR+MS 9828.91 49.19 183.34 8358.16 8278.52 -3989.40 802.69 5943347.19 655281.26 MWD+IFR+MS 9922.45 49.85 182.22 8418.88 8339.24 -4060.47 799.24 5943276.07 655279.27 MWD+IFR+MS 10015.61 50.46 183.53 8478.57 8398.93 -4131.90 795.65 5943204.58 655277.15 MWD+IFR+MS 10108.34 50.16 184.30 8537.79 8458.15 -4203.09 790.78 5943133.32 655273.74 MWD+IFR+MS 10202.55 51.19 185.80 8597.50 8517.86 -4275.68 784.36 5943060.62 655268.81 MWD+IFR+MS 10295.70 52.27 186.91 8655.19 8575.55 -4348.36 776.26 5942987.79 655262.20 MWD+IFR+MS 10389.45 52.36 184.98 8712.51 8632.87 -4422.14 768.58 5942913.87 655256.03 MWD+IFR+MS 10481.74 51.78 185.49 8769.24 8689.60 -4494.64 761.94 5942841.26 655250.88 MWD+IFR+MS 10569.20 51.05 184.86 8823.78 8744.14 -4562.72 755.77 5942773.07 655246.11 MWD+IFR+MS 10612.00 52.06 180.12 8850.40 8770.76 -4596.19 754.32 5942739.57 655245.35 MWD+IFR+MS 10674.00 53.84 173.50 8887.78 8808.14 -4645.55 757.11 5942690.29 655249.15 MWD+IFR+MS 10767.88 55.21 159.62 8942.44 8862.80 -4719.58 774.88 5942616.64 655268.43 MWD+IFR+MS 10862.11 64.44 152.82 8989.80 8910.16 -4793.89 807.87 5942543.03 655302.94 MWD+IFR+MS 10955.81 77.47 149.50 9020.31 8940.67 -4871.25 850.58 5942466.57 655347.22 MWD+IFR+MS 11049.20 93.75 144.22 9027.44 8947.80 -4948.90 901.34 5942389.98 655399.56 MWD+IFR+MS 11115.45 98.13 142.70 9020.59 8940.95 -5001.83 940.56 5942337.87 655439.85 MWD+IFR+MS 11173.86 102.71 143.54 9010.03 8930.39 -5047.77 975.03 5942292.65 655475.25 MWD+IFR+MS 11266.37 102.77 143.67 8989.63 8909.99 -5120.40 1028.57 5942221.14 655530.27 MWD+IFR+MS 11360.47 98.62 143.15 8972.17 8892.53 -5194.62 1083.67 5942148.07 655586.88 MWD+IFR+MS 11452.69 98.38 144.15 8958.54 8878.90 -5268.08 1137.73 5942075.74 655642.43 MWD+IFR+MS 11499.07 97.57 142.83 8952.10 8872.46 -5305.00 1165.06 5942039.39 655670.51 MWD+IFR+MS 11548.04 92.98 141.39 8947.60 8867.96 -5343.47 1195.00 5942001.55 655701.23 MWD+IFR+MS 11641.05 84.51 139.51 8949.64 8870.00 -5415.10 1254.15 5941931.15 655761.83 MWD+IFR+MS 11733.63 83.33 139.79 8959.44 8879.80 -5485.26 1313.76 5941862.23 655822.85 MWD+IFR+MS 11827.90 79.97 138.61 8973.13 8893.49 -5555.86 1374.69 5941792.90 655885.22 MWD+IFR+MS 11922.01 79.15 139.18 8990.18 8910.54 -5625.59 1435.53 5941724.43 655947.48 MWD+IFR+MS 12015.22 78.71 139.47 9008.08 8928.44 -5694.97 1495.16 5941656.30 656008.50 MWD+IFR+MS 12108.26 78.59 139.36 9026.39 8946.75 -5764.25 1554.50 5941588.26 656069.25 MWD+IFR+MS 12157.00 78.59 139.36 9036.03 8956.39 -5800.50 1585.62 5941552.65 656101.10 PROJECTED TREE= 4-1(16"CNV WELLHEAD= FMC ACTUATOR= OTIS KB. ELEV = 79.77' BF. ELEV = 48.57 KOP = 2950' Max Angle = 102 @ 11266' Datum MD = Datum TV Dss= A-~A1 Actual ~ -~.. HES ES CEMENTER 2079' 4-1/2", 12.6#, L-80, TGII Tubing 7" X 9-5/8" HMC / ZXP PKR 7664' 95/8" Window 7846' B ttom indow 7863' P 9-518" CIBP 7874' ~ 5-112" 17#, L-80 Tubing Cut 8150' TOP OF CEMENT 9100' I I SLIDING SLEEVE, ID = 4.5" 9247' Minimum ID = 3.813" @ 2203' X NIPPLE TOP OF 7" LNR 9391' 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9436' PERFORATION SUMMARY REF LOG: BHCS ON 1015!06 ANGLE AT TOP PERF: 80 @ 11820' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8 4 11820-11955 Opn 10/05!06 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10907' ~. 2672' 13-3/8" CSG, 72#, L-80, ID = 12.347" GAS LIFT MANDRELS MD TVD DEV TYPE VLV LATCH PORT DATE 499 3461 29 KBG-2 DCK 0 10107106 2204' 4-112" X Nipple (3.813" ID} 10311' 4-1/2" X Nipple {3.813" ID) 10373' 7" X 4-112" Baker S3 Packer 10397' 4-1/2" X Nipple (3.813" ID) 10418' 4-1/2" X Nipple (3.813" ID) 4-1/2" WLEG i0y~ 10610' 7" 26#, L-80, IBT-M Liner 10425' 4-112" Tieback (4.42" ID) 10443' 4-112" Lin Hang (4.43" ID} 12067' 4-1/2" Land Coll (3.958" ID) 4-1l2" 12.6#, L-80, IBT-M Liner P.B~ t215y DATE REV BY COMMENTS DATE REV BY COMMENTS 09107/05 JNC ORIGINAL COMPLETION 10/08706 MGS Sidetrack 10/10/06 /TLH ADD GLV INFO PRUDHOE BAY UNff WELL: A-17A PERMfT No: API No: 50-029-20520-01 SEC 35, T11 N, R13E BP Exploration {Alaska) 10/19/06 • .] S~h~n~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i ,.- '' Well Joh !! Inn t)awrrinfinn N0.4001 Company: State of Alaska Alaska Oil 8 Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay r1a4a RI f:nlnr Cr1 1-21/K-25 11226008 LDL 10/02!06 B-2TA 11414394 LDL 09/30/06 M-24A 11216213 MEM PROD PROFILE 09/30/06 1 MPB-09 11212889 PROD PROF/GLS 10/06/06 1 X-OSA 11414278 USIT 09/26/06 1 C-01A 11414279 USIT 09127/06 1 K-11 11414765 USIT 10/01/06 1 A-17A 11414283 USIT 10/02/06 1 r~cNac Nl.nnlvvYLCVUC Ktl,C1Y I CT Alt71VIN17 AIVU Kt l VKNING UNt GUYY tAGFt IU: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suit~40°! Anchorage, AK 99503-2p"$9. __ ATTN: Beth Received by' i~' 'f ;c":5 a ,ar~~i4 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SUITE 100 ANCHOFIAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dave Wesley Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU A-17A BP Exploration (Alaska), Inc. Permit No: 206-125 Surface Location: 3126' FNL, 1014' FEL, Sec. 25, T11N, R13E, UM Bottomhole Location: 3586' FNL, 535' FWL, Sec.01, T10N, R13E, UM Dear Mr. Wesley, 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 required test, contact the Commission's petroleum field inspector at (90 65~-3607 (pager). J DATED this day of August, 2006 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMM .ON PERMIT TO DRILL 20 AAC 25.005 AUG 1 8 2006 Alaska Oil b bas Cons. Commission 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 propAa6fedlibtg@ ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: 3 t zap PBU A-17A !~a[zz 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12107 TVD 9022 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 3126' FNL 1014' FEL UM SEC 3 T11 N R13E 7. Property Designation: ADL 047472 Pool , , . , , 5, Top of Productive Horizon: 2424' FNL, 276' FEL, SEC. 02, T10N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 23, 2006 Total Depth: 3586' FNL, 535' FWL, SEC. 01, T10N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 12,550' 4b. Location of Well (State Base Plane Coordinates): Surface: x-654397 y-5947319 Zone-ASP4 10. KB Elevation Plan (Height above GL): gg feet 15. Distance to Nearest Well Within Pool: 835' 16. Deviated Wells: Kickoff Depth: 7g5p feet Maximum Hole An le: 106 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3370 Surface: 2474 18. Casn P ram`. S cificatio ns To - Settin De th - Bo tt m uanti of Ce ent c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data N/A 9-5/8" 40# L-80 BTC-M 2100' Surface Surface 2100' 2100' 786 cu ft Class'G' N/A 7" 26# L-80 BTC-M 4700' 3000' 2998' 7700' 6906' 758 cu ft Class'G' 8-1/2" 7" 26# L-8 BTC-M 2888' 7700' 6 0 ' 1 588' 832' 404 cu LiteCr to 2 2 cu ft CI 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 1669' 10438' 8832' 12107' 9022' 247 cu ft Class'G' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for. Redrill and Re-entry Operations) Total Depth MD (ft): 10918 Total Depth TVD (ft): Plugs (measured): 9664 None Effective Depth MD (ft): 10864 Effective Depth TVD (ft): 9617 Junk (measured): 10840 :Casing Length'; ize Cement Volume MD TVD Conductor /Structural 110' 20" x 30" 8 cu ds Concrete 110' 110' Surface 2672' 13-3l8" 3255 cu ft Arcticset II 2672' 2672' Intermediate 9902' 9-5/8" 1430 cu ft Class'G' 130 cu Arcticset I 9902' 8767' Production Liner 1516' 7" 453 cu ft Class'G' 9391' - 10907' 8317' - 9655' Perforation Depth MD (ft): 9970' - 10228' Perforation Depth TVD (ft): 8827' - 9056' 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 Shane Gagliardi, 564-5251 Printed Name ve Wesley Title Senior Drilling Engineer Mehrdad Nadem, 564-5941 Prepared By Name/Number: Si nature ~~ ~ ~ ~ ~- Phone 564-5153 Date ~ ~/'~ ~ Terrie nubble, 564-4628 Commission Use Onl Permit To Drill Number:Z ~ API Number: 50-029-20520-01-00 Permit A prov I See cover letter for Date: ' ~ other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas drates, or gas contained shales: j ~e s ~ ~ ~ ~ t f~ 4 n ~o h ~' Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No fl0( ~'~"/ ~~,G„~,t q t.~,o~(~, ~ ~o ~ /'~'^~~d ~ HZS Measures: Yes ^ N irectiona! Survey Req'd: Yes ^ No Other: D Q APPROVED BY THE COMMISSION Date (~ (/ ,COMMISSIONER Form 10-401 Revised 12/2005 pp ~ `../ ~ / ~~ Submit In Duplicate • • Well Name: A-17Ai Planned Well Summary Well A-17Ai Well Type Sidetrack Target Ivishak Z4 Injector Ob'ective AFE Number: PBD4P2421 API Number: 50-029-20520-01 Surface Northin Eastin Offsets TRS Location 5,947,319 654,397 2,153' FSL / 1,013' FEL 11 N, 13 E, 35 Northin Eastin Offsets TRS Target 5,942,758.00 655,232.00 2,424' FNL / 276' FEL 10 N, 13 E, 2 Location 5,942,330.10 655,459.45 2,423' FSL / 58' FEL 10 N, 13 E, 2 5,942,040.00 655,671.00 2,128 FSL / 148' FSL 10 N, 13 E, 1 Bottom Northin Eastin Offsets TRS Location 5,941,613.00 656,067.00 1,693' FSL / 534' FW L 10 N, 13 E, 1 Planned KOP: 7,850' and / 7,036.66' tvd Planned TD: 12,107' and / 9,022' tvd Ri Nabors 2ES CBE: 35.3' ] RTE: 68' Planned S ud Date: 08/23/2006 Planned O eratin Da s: 19.06 Directional Program Approved Well plan: Wp08 Kick Off point: 7,850' and / 7,036.66' tvd Maximum Hole Inclination: -106.38° from 11,188.10' and to 11,400' in the planned 6-1/8" hole section. Proximity Issues: There are no close approach issues. All surrounding wells pass major risk criteria. Survey Program: Standard MWD/IIFR/MS. Nearest Well within ool: A-21, 835' Nearest Pro ert Line 12,550' to the nearest PBU pro erty line. A-17Ai Sidetrack ~/~'l? I~~IZZ- ~Yk-2o 1~2~13 ~A-21 I~Znt4 ~~. z,o t-~S Ua ~2~ 'A-3~trl Zo3~nZ °~ . zo l'~ 2~4d7$ Page 1 • Logging Program Hole Section: Required Sensors /Service 8-1/2" intermediate: Real time MWD Dir/GR/Res/PWD 6-1/8" hole: Real time MWD Dir/GR/Res/ABI/IFR/Caz Cased Hole: USIT from the tubin stub to surface. O en Hole: None tanned Mud Program Hole Section / o eration: Mill section in the 9-5/8" casin T e Densi Viscosit PV YP MBT API FL H LSND 9.0 50-60 10-18 70-90 N/C <6.0 9-10 Hole Section / o eration: Drillin 8-1/2" Int to THRZ T e Densit Viscosit PV YP MBT API FL H LSND 9.0-9.3 35-50 10-18 18-22 <15 4-6 9-10 Hole Section / o eration: Drillin 8-1/2" intermediate HRZ to To Sa River. T e Densi Viscosit PV YP MBT API FL H LSND 1.2 35-50 12-20 18-22 <18 4-6 9-10 ~~...~ Hole Section / o eration: Drillin 6-1/8"" hole interval. T e Densit LSRV PV YP MBT API FL H Flo-Pro SF 8 5 > 20,000 8 - 12 22 - 28 < 3 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 9-5/8" 40# L-80 BTC-M 2,100 Surface 2,100 / 2,100' N/A 7" 26.0# L-80 BTC-M 4,700' 3,000' / 2,998' 7,700' / 6,906' 8-1/2" 7" 26.0# L-80 BTC-M 2,888' 7,700' / 6,906' 10,588' / 8,832' 6-1/8" 4'/z" 12.6# L-80 IBT-M 1,669' 10,438' / 8,832' 12,107' / 9,022' Tubin 4'/2" 12.6# L-80 TCII 10,438' Surface 10,438' / 8,832' A-17Ai Sidetrack Page 2 ~J Cementing Program Casin Strin 9-5/8", 47#, L-80, BTC-M Lead slurry: None Planned. Slurry Design Basis: Tail slurry: 2,100' 15.8 ppg Class G in the 13-3/8" x 9 5/8" annulus with 10- bbl excess. Pre-Flush 10 bbls Heated Seawater Fl id /V l S S acer None Planned u s equence o ume: Lead Slur None Planned ; Tail Slur 140 bbls / 786 ft / 677 xs class G, 15.8 .16 /sk. Casin Strin 7", 26#, L-80, BTC-M Tieback Slurry Design Basis: Lead slurry: None planned. Tail slur :4,700' 9-5/8" X 7" annulus to 3,000' MD with 0% excess. Pre-Flush None Planned Freeze Prot None Planned Fluids Sequence /Volume: S acer 10 bbls of Mud Push II Lead Slur None tanned °" Tail Slur 135 bbl / 758 cf / 653sxs Class `G', 15.8 1.16 of/sk. Casin Strin 7", 26#, L-80, BTC-M intermediate liner Slurry Design Basis: Lead slurry: 1,738' 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. Tail slur :1000' of 7"x8-1/2" with 40% excess, lus 80' of 7" shoe. Pre-Flush None tanned Fl id /V l S S acer 40 bbls Mud P II t 11.40 ~~°" u s equence o ume: Lead Slur 72 bbls / 404 / 147 s Lite Crete, 11.5 , 2.75 /sk Tail Slur 36 bbls / 202 f / 174 xs Class "G", 15.8 ; 1.16 f/sk Casin Strin 4-'/z", 12.6#, L-80, IBT-M Production liner Lead slurry. None planned. Slur Desi n Basis: ry g Tail slurry. 1,519' of 4-'/z" x 6-1/8" annulus with 40% excess, plus 150' of 4- " ' " " " " ' drill pipe x 7 annulus, plus ~80 of 4-'/2 x 7 liner lap, plus 200 of 4 , '/z 12.6#, shoe tract. Pre-Flush: None tanned Spacer Fluid: 20.0 bbls MudPUSH II at 10.0 ppg Lead Slur Slurry Type None planned Tail Slur Slurry Type 44 bbls / 247 cf 213 xs Class "G" 1.16 f/sk ~.~' ~/ A-17Ai Sidetrack Page 3 • Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9-5/8" Casin to surface Bride lu to surface 30 min recorded 4,000 si surface 9-5/8" casin window 20' be and middle of window FIT 12.5 EMW 7" casin to surface Landin collar to surface 30 min recorded 4,000 si surface 7" Scab Landin collar to surface 30 min recorded 4,000 si surface 7" shoe 20' be and middle of window FIT 10.0 EMW Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: Well Interval: 8-1/2" intermediate interval Maximum antici ated BHP: 3,280 psi at 8,755' sstvd. Maximum surface ressure: 2,404 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 12.5 pp EMW FIT Planned BOPE test pressure: Rams : 250psi low / 4,000psi high ; Annular : 250psi low / 2,500psi high 7 da test c cle RWO hase ; 14 da test c cle Drillin hase BOPE configuration for 7" intermediate casin Annular, 7" pipe rams and blind/shear rams. Well Interval: 61/8" production interval Maximum antici ated BHP: 3,370 psi at 8,960' sstvd. Maximum surface ressure: 2,474 pSl (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.0 pp E FIT. Planned BOPE test pressure: Rams : 250psi low / ,000psi high ; Annular : 250psi low / 2,500psi high 14 da test c cle ri hase ~ Planned com letion fluid: 8.5pp seawater / 7.1 pp Diesel BOPE and drilling fluid system schematics are currently on file with the AOGCC. Disposal Annular In'ection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. A-17Ai Sidetrack Page 4 • Geologic Prognosis Est. Formation To s Uncertainty Commercial Hydrocarbon Bearing Est. Pore Press. Est. Pore Press. Formation (TVDss) (feet) (Yes/No) (Psi) ( g EMW) NOTE: All formation tops are required from 1000' above proposed KOP to TD for sidetracks NOTE: All formation tops are required from surface to TD for all new wells CM2 6443 +/- 5' No 2263. 6.8 CMl (A-17Ai KOP is - -7490' SSTVD) 7175 +/- 5' No 2585 6.8 THRZ 7532 +/- 5' No 2742 6.8 BHRZ 7742 +/- S No 2834 6.8 LCU 7742 +/- 5' No 2834 6.8 TJF 7891 +1- 5' No 2900 6.8 TJE 7966 +/- 5' No 2933 6.8 TJD 8355 +/- 5' No 3104. 6.8 TJC 8428 +/- 5' No 3136 6.8 TJB 8560 +/- 10' No 3194 6.8 TJA 8638 +/- 10' No 3229 6.8 TSGR 8755 +/- 10' Yes 3280 6.8 TSHA 8770 +/- 10' No 3287 6.8 TSHB 8801 +/- 10' No 3300 6.8 TSHC 8817 +/- 10' No 33D7 6:8 TSAD 8850 +/- 10' Yes 3322 6:8 To HOT 8960 +/- 10' 3370 6:8 TSAD at well crest 8860 +/- 10' 3326 6:8 TD Criteria TD Criteria: Well will TD to plan to support production at A-37, A-30A, A-20, A-38, A38L1 and X- 35L1. Stopping measurably short of the planned BHL will have a significant adverse effect on all of the wells south of the planned TD (5 of the 6 wells that are targeted to receive su ort from this in~ector . A-17Ai Sidetrack Page 5 • • Fault Prognosis Fault Details Formation Where Encounter MD Subsea TVD Est. Throw Fault Intersect Intersect Throw Direction Uncertaint MD (ft) Fault 1, Z4B 11,710' -8858 -10' D/U NW +/-165' A-17Ai Sidetrack Page 6 • • Operations Summary ,mot Y Pre-Riq Operations: 1. Replace all live gas lift valves with dummy valves and fluid pack as necessary for CT P&A. 2. R/U SL and drift tbg, DO NOT tag up on fish in the hole @ 10,840' and 3. RIH with CT and P&A the A-17 well bore. Pump sufficient cement (61.4 bbls) to leave top up into the tubing tail at 9,100' md. 4. Drift the 5 '/2" tubing to confirm and tag top of cement, to confirm clear to the required depth of 8,150' md. 5. RIH with the appropriate jet cutter and cut the 5-'/2' tubing at 8,150' md. 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,200' and with diesel. 7. Test the 9 5/8" pack-off and tubing hanger seals to 5,000 psi for 30 minutes. Function all lock down screws, repair or replace as needed. PPPOT-IC failed on August 15, 2006, and PPPOT-T passed on the same day. Tubing hanger passed the test when it was pressured up to 5, 000 psi. Inner casing were bled off, and failed when pressured up to 2, 200 psi. 8. Bleed casing and annulus pressures to zero. 9. Set a BPV. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPV. 3. Nipple down tree. Nipple up and test BOPE to 4,000 psi. 4. R/U. Pull 5-%2" tubing from the cut at 8,150' and and above. 5. R/U E-line. M/U 8.5" gauge ring /junk basket / CCL. RIH and tag tubing stump. POOH. Run USIT from tbg stub to surface. 6. Hang off RTTS, test the 9-5/8' for leaks. 7. MU a Baker 9-5/8" cutting assembly. RIH picking up DP. Cut the 9-5/8" casing per Baker representative instructions. Cut ~4' above a casing collar. POOH, L/D assembly. 8. Change out to 9-5/8" rams, and test. 12 9. BOLDS, RU/MU casing spear assembly, and unseat the 9-5/8". Circulate the Arctic Pack ~~~°~ from the annulus with warm diesel followed by seawater and detergent sweeps. Pull the 9- fl 5/8" casing from the cut. 10. MU Wash over assembly, and 13-3/8" casing scraper. 11. RIH, Clean out the 13-3/8" casing, and the 9-5/8" casing stub, POOH, UD the assembly. 12. RU BKR back-off assembly, RIH, and back off the 9-5/8" casing joint. POOH, UD assembly. 13. MU casing spear assembly, RIH, recover cut stub. POOH. 14. MU 9 5/8" ES Cementer on screw in sub and RIH w/ new 9 5/8" cas 15. Shear open ES cementer and cement 9 5/8" x 13 3/8" annulus w/ 40 ~bls class G cement. 16. PU 5" DP and make clean out run through the ES Cementer. 17. RIH with HES EZSV on E-line. Set bridge plug at 7,874' and elm, as required to avoid cutting a casing collar while milling the window. POH. R/D E-line. 18. Pressure-test the 9 5/8' casing to 4,000 psi for 30 minutes. Record test. 19. P/U and RIH with 9 5/8' Baker bottom-trip anchor whip stock assembly on 5" DP. Orient whip / stock as desired and set on bridge plug. Shear off of whip stock. 20. Displace the well to 9.0 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 21. Mill window in 9 5/8' casing at ± 7,850' md, plus approximately 20' beyond middle of window. j Circulate well bore clean. 22. Pull up into 9 5/8' casing and conduct an FIT to 12.5 ppg EMW. POH. ~ 23. M/U 8-'/2" Dir/GR/PWD assembly. RIH, kick off and drill the 8 '/2" intermediate section to 100' above the HRZ with 9.0 - 9.3 ppg LSND. • • 24. By 8,450' and (150' above the top of the HRZ) have the entire circulating system weighted / up to 11.2 ppg with spike fluid from the MI plant. 25. Continue drilling ahead in the 8 '/" hole section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POH. j 26. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. LD 5" DP. 27. Run and cement a 7", 26.0#, L-80 scab liner to within 300' of surface casing shoe as necessary to cover potentially bad portions of intermediate casing indicated by USIT. ~ 28. M/U 6-%8" Dir/GR/Res assembly. RIH to the 7" scab liner landing collar. Test to 4,000 psi. 29. Drill out the 7" scab liner and 7" liner float equipment and cement to the shoe. 30. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 31. Drill out the 7" shoe plus ~20' new formation, pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to TD per directional proposal. 32. Circulate well bore clean, short trip to shoe, circulate. POH. / 33. Run and cement 4 '/2', 12.6#, L-80, IBT-M solid production liner. POH. 34. RIH with DPC pert guns, Perf intervals to be determined from LWD logs. Plan to perforate overbalance. POOH, LD DP and pert guns. 35. R/U and run a 4'/z", 12.6#, L-80, TC-II tubing completion, stinging into the 4-Yz" liner tie back sleeve. 36. Set packer and individually test the tubing and annulus to 4,000 psi for 30 minutes. Record each test. 37. Set a BPV. 38. Nipple down the BOPE. Nipple up the tree and test to 5,000 psi. 39. Freeze protect the well to 2,200' tvd. Secure the well. 40. Rig down and move off. Post-Rig Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 2. Install well house and instrumentation. • • Phase I: Move In / Rig Up /Test BOPE Planned Phase Time Planned Phase Cost 60.96 hours $347,810 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-17A. Well A-38 is 75' to the North and well A- 30A is 54' to the south. As always, care should be taken while moving onto the well. Spotters should be employed at all times. - During MI/RU operations, the A-17 well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and Arctic Pack. - 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-17 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: Annulus valve and Arctic Pack. - Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading A-30 30 ppm A-18A 30 ppm A-38 20 ppm A-37 30 ppm A-43 150 ppm on 3/18/2002 A-43 90 ppm on 6/6/2006 The maximum level recorded of H2S on the pad was 150 ppm in well A-43 recorded on March 18, 2002. The highest current H2S level is on A-43 at 90 ppm on ,lone 6, 2006. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 38 $139,518 A-17Ai Sidetrack Page 9 ~ • 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 FMC/BPXA original Big Bore. It has 9-5/8" intermediate slips and pack offs. - Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Records indicate 7" 1J4S box-up x5-112" buttress A/B mod. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - The current completion has a 5-1/2" CAM SSSV landing nipple 2,121' MD, No records could be located showing the presence or lack of control bands. Please have equipment available to pull control bands, if found during decompletion. - A caliper log dated March 1, 2002 reports that 5.5" tubing ranges from good to poor condition with respect to corrosive damage. An isolated hole is recorded in joint 235 at 9,311. the remainder of the tubing is in fair condition with penetration ranging from 20% to 46% wall thickness. The 4.5" tubing tail is in good condition with respect to corrosive damage. A penetration of 24% wall thickness is recorded in joint 3, as well as a minimum I.D. restriction of 3.71". No significant cross- sectional wall loss, in excess of 6%, is recorded in the 4.5" tubing tail. - USIT log will be run after tubing has been pulled to identify top of cement for cut and pull operations. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 33.20 $225,865 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - Records indicate 15.8 ppg Class G cement should be present behind the 9-5/8" casing at KOP. TOC is expected to be at 6,713' and based on records showing a cement program using 255 bbls of cement with 40% excess, and 80' of 9-5/8' shoe. - 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 Phase 5: Drill 8 1/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 83.8 $506,438 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" A-17Ai Sidetrack Page 10 ~ • • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - For this well, the Kingak will require a mud weight of 11.2 ppg. Maintain mud weight at 11.2 ppg, minimally, 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 12.5 ppg at the 9 5/8" casing window, and 11.2 ppg mud in the hole, the kick tolerance is infinite. - The above kick tolerance is based on an FIT of 12.5 ppg EMW; if this is not reached contact the ODE. - The well plan is not expected to cross any faults in this section. A-17Ai Sidetrack Page 11 • • Phase 6: Run and Cement 7" Intermediate Casing and the Scab liner Planned Phase Time Planned Phase Cost 19.50 $598,612 Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP • "Freeze Protecting an Outer Annulus" RP Issues and Potential Hazards - The completion design 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 scab liner will be run to surface and cemented to 3,000' MD. The scab liner will be 7#, 26#, L- 80, BTC-M. - 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 7: Drill 6 1/8" Production Hole Interval Planned Phase Time Planned Phase Cost 99.70 $492,261 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - Once in Zone4B, no fault appears to cut the well path near the toe, where a small fault, designated fault 1 crosses the well plan. This fault is mapped to be at -11,710' md. - KICK TOLERANCE: In the worst-case scenario of 7.3 ppg pore pressure in the Ivishak, a fracture gradient 10.0 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance is infinite. - The above kick tolerance is based on an FIT of 10.0 ppg EMW, this is the minimum FIT specified in the permit to drill, attempt an FIT to 10.0 ppg EMW for an extra margin of safety. Contact the ODE if a 10.0 ppg EMW FIT is not reached. Phase 9: Run 4~/z" Production Liner Planned Phase Time Planned Phase Cost 13.10 $260,608 A-17Ai Sidetrack Page 12 ~ • Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4 ~/2", 12.6#, L-80 IBT-M solid liner throughout the production interval. - Sufficient 4-'/z" liner will be run to extend -150' back up into the 7" liner shoe. - Differential sticking is possible. The 8.5 ppg Flo-Pro will be over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. - Ensure the 4'/z" liner top packer is set prior to POOH. Phase 10: DPC Perforate Well Planned Job Time Planned Job Cost 32.20 $192,980 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 perf 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 12: Run 4 ~/z", 12.6#, L-80, TCII Completion Planned Phase Time Planned Phase Cost 22.10 hours $448,960 Reference RP • "Completion Design and Running" RP 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 Asia at 100° F. - The completion design will be a 4'/z", 12.6#, L-80, TCII production tubing string with 7" x 4-112" Baker S-3 packer. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 13.40 hours $42,099 A-17Ai Sidetrack Page 13 • • Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off A-17Ai. Well A-38 is 75' to the North and well A- 30A is 54' to the south. As always, care should be taken while moving onto the well. Spotters should be employed at all times. A-17Ai Sidetrack Page 14 • • A-17A Potential Drilling Hazards Post on Rig • Pre-job HAZOP's and Safety meetings are recommended when there is a clear change in workscope. If at any time things don't feel or look right, STOP the job and discuss the situation before making the next move. • Flash Points o Dead Crude= <40degF o Methanol (neat)= 52degF o Diesel=100degF • Hydrogen Sulfide o Standard Operating Procedures for H2S precautions should still be followed at all times. o Max H2S reading: A-43 at 90 ppm on June 6, 2006. H2S concentration in well A-43 was at 150 ppm an March 18, 2002. • Bottom Hole Pressure 0 3,370 psi C~3 8,960'ss o The 8.5 ppg drilling fluid will provide a 590 psi static overbalance in the reservoir. • Maximum anticipated wellhead pressure: 0 2,474 psi w/full column of gas • Potential for loss circulation o Low • Faults: Expect to cross up to 1 faults • First: Once in Zone46, no fault appears to cut the well path near the toe, where a small fault, designated fault 1 crosses the well plan. This fault is considered low risk because the well path crosses fault at right angel. The fault is crossing is expected at 11,710'. • Close Approaches o There are no close approach issues. All surrounding wells pass major risk criteria. A-17Ai Sidetrack Page 15 6., VVELLFiE4D=, FMC ACTUATOR= OTIS KB. E1EV = 79.n' BF. ELEV = 48.57' KOP = 2950' Max Angle = 37 ~ 8200' Datum MD = 10029' Datum TV Dss= 8800' ~ A-77 13-3/8" CSG, 721, L-80, ID =12.347" 2672' Minimum ID ~ 3.725" ~ 9404` OTIS XN NIPPLE SA TES: WARNING RA010 TRANSMITTER IN VY[MONTOAUKIG SHACK M UST BE TURI1®OFF BEFOREANY WELL WORK INVOLVING EXPLOSNES CAN BEIpN. CONTACT PAD OPERATOR WELLHEAD COMPLETEDtN/ EMERt3B11CYSLIPS ON 9-S/8' CSO HNGR DO NOT PRESSUI~ TEST 8-6/8" CSCi HNGR VOID ABOVE 70% OF COLLAPSE OF 9-S/S" CSG. '"'T X IA COM M"" 2121' 5-1/2" CAM SSSV Landing NIP, ID = 4.582" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 14 1 CAMCO RK 6 4152 3917 36 CAMCO RK 5 5754 5222 36 CAMCO RK a 7oao s27o 3a CAMCO RK 3 7656 6788 31 CAMCO RK 2 8305 7334 37 CAMCO RK 1 9181 8057 32 CAMCO RK 9247' SLIDING SLEEVE, O = 5-1/2" TBG, 17#, L-80, ID = 4.892" H 9310' OP OF T' LNR 9391' ~ 14-1/2" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" H 9436' PERFORATION SUMMARY REF LOG: BRCS ON 01 /10/81 ANGLEATTOP PERF: 27 ~ 9970' Note : Refer to Productan ~ for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8" 8 9970 -9990 O 04/22/88 3-1/8" 4 10090-10134 O 06/18/82 2-3/4" 4 10148 -10153 O 08/29/85 3-1/8" 4 10156 -10200 O 08/29/85 2-3/4" 4 10212 - 10219 O 08/29/85 3.1/8" 4 10223 - 10228 O 07/30/88 PBTD H 1 2' T' LNR, 290, L-80, .0371 bpf, ID = 8.184" ~ 9304' H TBG SEAL ASSY 9309' 9-5/8" X 5-1 /2" BAKER PKR 9310' S-1/2"x4-1/2" xo 9373' 4-1/2" OTIS 'X' NIP, ID = 3.958" 9404' 4-1/2" OTiS'XM NIP, ID=3.725" 9436' 4-1/2" BROWN TBG TAIL, ID = 3.958" 9466' ELMD TT -LOGGED 01/14/81 10179' I--I MARKER JOMIT 10840' DATE REV BY COMMENTS DATE REV BY (X)11MIENTS 01/1S/81 ORIgNAL COMPLETKNH 05/16/01 RNITP CORRECTIONS 11/01/01 WBRP SURFLOCCORRECTION 02/20/03 (RH WAVER SAFETY NOTE 02/12/04 GCJKAK PERF CORRECTIONS 12/15/04 RDJIPAG WAVER SAFETY NOTE IWT BARlTEMPiCCL/HP -08/29/84 I PRUDHOE 8AY l~lff WELL: A-17 PERMIT No: 1801220 API No: 50-029-20520-00 S6C 35, T11 N, R13E ~ Expbration (Alaska) TREE = 41 /16" VVELLHEAD= ACTUATOR= _- FMC _O_TIS KB. ELEV = 0_ 79.77' ~~ BF. ELEV = --~ 48.5T --~- - KOP = - 2950' Max Angle = Datum MD = --- Datum TV Dss= )6 ~ 11188' -----__ ___ _--~_~~-_ A -17~ I P ro p o s e d SAF~OTES: fiES FS CEME~lTER ~ `" Si~$~" 7" X 9-5/8" FLEXLOK W/ZXP PKR 3000' 7" X 9-5/8" FLEXLOK W/ ZXP PKR 7700' 9-5/8" WINDOW 7850' Minimum ID = 3.813" @ 2142' X NIPPLE 9-518" CIBP 7874' 5-1/2" 17#, L-80 Tubing Cut 8150' TOP OF CEMENT 9100' SLIDING SLEEVE, ID= 4.5" 9247' TOP OF 7" LNR 9391' 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9436' PERFORATION SUMMARY REF LOG: BHCS ON 01 /10181 ANGLEATTOP PERF: 27 ~ 9970' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10907' 2672' 13-3/8" CSG, 72#, L-80, ID = 12.347" 4-1/2", 12.6#, L-80, TGIITubing 10317' 4-1/2" X Nipple (3.813" ID) 10380' 7" X 4-1/2" Baker S3 Packer 10406' 4-1/2" X Nipple (3.813" ID) 10427' 4-1/2" X Nipple (3.813" ID) 10438' 4-1/2" WLEG 10438' 4-1/2" 12.6#, L-80, IBT-M, Liner Top 10588' 7^ 2s#, L-8o, BTGM Liner • ,,. • 's ,' •• P' $ ~•' .. 4~ • 12021' ~~4-1/2" 12.6#, L-80, IBT-M Liner PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 09/07/05 JNC ORIGINAL COMPLETION WELL: A-17A PERMIT No: API No: 50-029-20520-01 SEC 35, T11 N, R13E BP Exploration (Alaska) n 0 n 3 3 3 F F H ~ ~ < ^ ~ ~ _NN_ Y<w:~0 ~2'"~ -, ~,n /: :nom x w _ ' ;; ,; 9 0 o o 'a L ti ..•J ••J ~O ~O O~O aaaa U is hv~xNV,ax Nno POn nx nn x,nn nNx O ~ G. ~ y ,r. ,r. -x-.-. a^n•r-- oxac n.n-~GN~GMnn ~x - > ~~ M,N~Ca~~NVelr? ~o o~czxo-`~'~ ° a O F ~ rind--o~o<d.on-xriNa~ -~~c°~' ~~iv v°i~~~~ ~`^ - ~ eo ° ooov, ° o r i vi v i r,ee eer„n v, v, Z ~ . ._ xxxxaaacoo ooo00 <_ ~ _ n q ? ~i-ra p F -------- 3 ~ ~ -`~ 3 w ri ooo ,n ut .o ut ~ oo,r-,o,oony.^..o O ' "~ < t n nnn nnnnn nn nnn nn QOO NCO Q ~~O< QOCo 3 x _ ~ ~O ~D ~O ~p ~ {i ooo CxO V x Jemo N OC ~Ot~=o^ ~N ~ ~ ~ Q , ., l\I Q~ O~ O~OO r'~1 N,r, l~vl l`In OG 7[~ ~ p~ ~J' Ors-rte V n a ~ _ 8 ~ $ E. e e V i ^ 1 ri~xxa~vv~, .on xxx xo~ ,, ~ ~ ~ F n n n n n x x x x x x x x x m - ~ - ~+ - o00o ooo- cn 0000000000000 00000ooooo o0 c 9 ° - ~ .c O ~c`-rn p g oricoovoa-ioxooo .-. ~ - Z -ri.-~v~n~rooao_Nr~v~n .~ u ~ n 1 ,O N E z _v > u ~ ~ - VI d eeee ut vl Vt VI ...1 - 3 oznz cno= ?~~: a~ u z ~ F F , W . > viz`O-ago ri o,r;avi oo ri - y s ,nn,oo w + rnae~-,-N.cxa~on,n xzznn xz - , - - w 3 n a a0 n -- - _ y w ~ ~ _viNO e~c ,: a O :J -- - .. .. 3 ~ F J ~ oxzon.:aornoNn rvxxv,0aeonne0e . - _ - < F Vf no nv L q N Z + vie Onnrl r-p.Gp R~GT nNnna NN-e-O-n .. ._ _ - - e0 a,n v~xx 00 rvNNeeee,n ,n vi vni v'^i vni o fir. v, v i •~~ --. p .cNxnoao00-n- O _ 3 Q n oaa O.onNO~;x o- ~ a > _ _ . _-rie .c . ~~n.cnoaN zxaa _F=.. °_ L ~ . ^ ~ ~ - ~~ _ ~ < nno o--00o0oN a0e=rexx0--0 _ ~ _ a .~. .~- e t < 3 3 3 3 ~.o__~ocav~a7aM~ i ~. -_ ~' x -nevi FFFF ~ ;t - Y ~ ~ «« ~ ~ oria asnnoxx onn erl---'V onr C ^ a. ~ ~. -~- i G nnnn . .nn ~.~. p ~ _ _ M1 m Z ~ «« Nn~n nvi .p .,^o 00 ann .___ x _ _ ___._._. o O:_ --- p o ' _ y ~ 00ar,n0e~n-,n x,nN xo e rya _' ~. x^zv1~TT -M o'J O.^..-~~.N ~-~-....-- .. 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't - z _ ~ ~ . . . e S. .., ~ ^ .. ~ - - r - x [J4/U009] (+)4uoN/(-)41nos S err -Sun P Y BP Planning Report Company: BP Amoco Date: 8/10/2006 Time: 10:59:44 Pages 1 .Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: A-17, True North Site: PB A_Pad Vertical (TVD) Refereuce: 48.57+28:5:77.1 Well: A-17 Section (VS) Reference: Well (O.OON,O.OQE,164.86Azi) Wellpath: Plan A-17A Survey Calculation Method: Minimum Curvature Db: Oracle Plan: A-17A wp08 Date Composed: 6/28/2005 Version: 50 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay Nortli 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 Fasting: 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-17 Slot Name: 17 A-17 Well Position: +N/-S 1169.18 ft Northing: 5947319.00 ft Latitude: 70 15 46.707 N +E/-W 911.67 ft Fasting : 654397.00 ft Longitude: 148 45 6.245 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 10588.39 8832.07 7.000 8.500 7" 12107.00 9022.01 4.500 6.125 4 1 /2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 8112.03 7252.07 CM1 0.00 0.00 8636.85 7609.07 THRZ 0.00 0.00 8971.95 7819.07 BHRZ 0.00 0.00 8971.95 7819.07 LCU 0.00 0.00 9209.71 7968.07 TJF 0.00 0.00 9329.38 8043.07 TJE 0.00 0.00 9950.11 8432.07 TJ D 0.00 0.00 10066.60 8505.07 TJC 0.00 0.00 10277.23 8637.07 TJB 0.00 0.00 10401.69 8715.07 TJA 0.00 0.00 10588.39 8832.07 TSGR 0.00 0.00 10612.33 8847.07 TSHA 0.00 0.00 10662.74 8878.07 TSHB 0.00 0.00 10689.61 8894.07 TSHC 0.00 0.00 10747.81 8927.07 TSAD 0.00 0.00 Targets Map. Map <-- Latitude --> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg. Min See Dip. Dir. ft ft ft ft ft A-17A 71 wp07 8832.07 -4577.50 741.35 5942758.00 655232.00 70 15 1.687 N 148 44 44.684 W A-17A poly 8832.07 -4420.97 522.50 5942910.00 655010.00 70 15 3.227 N 148 44 51.048 W -Polygon 1 8832.07 -4420.97 522.50 5942910.00 655010.00 70 15 3.227 N 148 44 51.048 W -Polygon 2 8832.07 -4796.63 549.80 5942535.00 655045.00 70 14 59.532 N 148 44 50.255 W -Polygon 3 8832.07 -6007.39 1545.26 5941345.00 656065.00 70 14 47.623 N 148 44 21.312 W -Polygon 4 8832.07 -5794.08 1874.73 5941565.00 656390.00 70 14 49.720 N 148 44 11.731 W -Polygon 5 8832.07 -4710.67 991.69 5942630.00 655485.00 70 15 0.377 N 148 44 37.404 W -Polygon 6 8832.07 -4430.40 982.44 5942910.00 655470.00 70 15 3.134 N 148 44 37.672 W A-17A T3 wp07 8934.07 -5304.40 1165.57 5942040.00 655671.00 70 14 54.538 N 148 44 32.350 W Sperry-Sun BP Planning Report Company: BP Amoco Date: 8/10/2006 Time: 10:59:44 Page: 2 Field: .Prudhoe Bay Co-ordinate(NE) Reference: Welly A-f7, True North Site: PB A Pad Vertical (TVD) Reference:. 48.57+28:577.1 Well: A-17 Section (VS) Reference: Well (O.OON,O,OOE,164.86Azt) Wellpathr Plan A-17A Survey Calculation Method: Minimum GuNature Db: Oracle Targets Map Map <-- Latitude --> <- Longitude -> Name Description TVI) +Nf-S +E/-W Northing Fasting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft A-17A T4 wp07 9022.07 -5739.47 1552.76 5941613.00 656067.00 70 14 50.258 N 148 44 21.093 W A-17A T2 wp07 9027.07 -5010.00 960.00 5942330.10 655459.45 70 14 57.434 N 148 44 38.326 W Plan Section Information MD ft Incl deg Azim deg TVD ft +N/-S ft +E/-W ft DLS deg/100ft Build deg/100ft Turn deg/100ft TFO deg Target 7850 .00 29.40 161.97 7036.66 -2535 .20 875.78 0.00 0.00 0.00 0.00 7870 .00 31.22 165.07 7053.92 -2544 .88 878.63 12.00 9.11 15.49 42.00 8465 .96 51.19 185.40 7501.98 -2930 .88 896.86 4.00 3.35 3.41 42.05 10588 .39 51.19 185.40 8832.07 -4577 .50 741.35 0.00 0.00 0.00 0.00 A-17A T1 wp07 10608 .39 51.19 185.40 8844.60 -4593 .02 739.89 0.00 0.00 0.00 0.00 10903. 09 67.63 140.81 8999.79 -4822 .96 818.63 14.00 5.58 -15.13 -79.86 10909. 42 67.63 140.81 9002.20 -4827 .49 822.32 0.00 0.00 0.00 0.00 11142. 51 100.00 145.00 9027.00 -5010 .00 960.00 14.00 13.89 1.80 7.67 11188. 10 106.38 145.10 9016.60 -5046 .37 985.42 14.00 14.00 0.21 0.84 11396. 54 106.38 145.10 8957.81 -5210 .37 1099.84 0.00 0.00 0.00 0.00 11513. 83 97.00 145.00 8934.07 -5304 .40 1165.57 8.00 -8.00 -0.08 -179.41 A-17A T3 wp07 11789. 50 76.73 136.26 8949.11 -5516 .02 1338.94 8.00 -7.35 -3.17 -156.81 12107. 26 76.73 136.26 9022.07 -5739 .47 1552.76 0.00 0.00 0.00 0.00 A-17A T4 wp07 Survey MD ft 7850.00 7870.00 7900.00 8000.00 8100.00 8112.03 8200.00 8300.00 8400.00 8465.96 8500.00 8600.00 8636.85 8700.00 8800.00 8900.00 8971.95 9000.00 9100.00 9200.00 9209.71 9300.00 9329.38 9400.00 9500.00 9600.00 9700.00 9800.00 9900.00 9950.11 Incl deg Azim deg TVD ft Sys TVD ft VS ft N/S ft 29 .40 161.97 7036. 66 6959. 59 2675.93 -2535 .20 31 .22 165.07 7053. 92 6976. 85 2686.02 -2544 .88 32 .12 166.58 7079. 46 7002. 39 2701.77 -2560 .15 35 .24 171.11 7162. 68 7085. 61 2757.04 -2614 .53 38 .50 174.97 7242. 68 7165. 61 2816.38 -2674. 06 38 .90 175.40 7252. 07 7175. 00 2823.78 -2681. 55 41 .87 178.32 7319. 08 7242. 01 2879.50 -2738. 44 45 .32 181.24 7391. 50 7314. 43 2946.09 -2807. 37 48 .84 183.83 7459. 59 7382. 52 3015.83 -2880. 50 51 .19 185.40 7501. 98 7424. 91 3063.39 -2930. 88 51 .19 185.40 7523. 31 7446. 24 3088.22 -2957. 28 51 .19 185.40 7585. 98 7508. 91 3161.20 -3034. 86 51 .19 185.40 7609. 07 7532. 00 3188.09 -3063. 45 51 .19 185.40 7648. 64 7571. 57 3234.18 -3112. 45 51 .19 185.40 7711. 31 7634. 24 3307.15 -3190. 03 51 .19 185.40 7773. 98 7696. 91 3380.13 -3267. 61 51 .19 185.40 7819. 07 7742. 00 3432.63 -3323. 43 51 .19 185.40 7836. 65 7759. 58 3453.11 -3345. 19 51 .19 185.40 7899. 32 7822. 25 3526.08 -3422. 78 51 .19 185.40 7961. 99 7884. 92 3599.06 -3500. 36 51 .19 185.40 7968. 07 7891. 00 3606.14 -3507. 89 51 .19 185.40 8024. 66 7947. 59 3672.03 -3577. 94 51 .19 185.40 8043. 07 7966. 00 3693.48 -3600. 74 51 .19 185.40 8087. 32 8010. 25 3745.01 -3655. 52 51 .19 185.40 8149. 99 8072. 92 3817.99 -3733. 10 51 .19 185.40 8212. 66 8135. 59 3890.96 -3810. 69 51 .19 185.40 8275. 33 8198. 26 3963.94 -3888. 27 51 .19 185.40 8338. 00 8260. 93 4036.92 -3965. 85 51 .19 185.40 8400. 67 8323. 60 4109.89 -4043. 43 51 .19 185.40 8432. 07 8355. 00 4146.46 -4082. 31 E/W DLS MapN ft deg/100ft ft 875.78 0.00 5944802.47 878.63 12.00 5944792.86 882.49 4.00 5944777.67 893.12 4.00 5944723.52 900.31 4.00 5944664.16 900.94 4.00 5944656.68 904.02 4.00 5944599.87 904.23 4.00 5944530.97 900.94 4.00 5944457.79 896.86 4.00 5944407.34 894.37 0.00 5944380.89 887.04 0.00 5944303.18 884.34 0.00 5944274.55 879.71 0.00 5944225.47 872.39 0.00 5944147.76 865.06 0.00 5944070.05 859.79 0.00 5944014.14 857.73 0.00 5943992.34 850.41 0.00 5943914.63 843.08 0.00 5943836.92 842.37 0.00 5943829.38 835.75 0.00 5943759.21 833.60 0.00 5943736.38 828.42 0.00 5943681.50 821.10 0.00 5943603.79 813.77 0.00 5943526.08 806.44 0.00 5943448.37 799.12 0.00 5943370.66 791.79 0.00 5943292.95 788.12 0.00 5943254.01 MapE TooUGoi ft 655324.51 Start Dir 1~ 655327.56 Start Dir 4/ 655331.73 MWD+IFR 655343.48 MWD+IFR 655351.88 MWD+IFR 655352.67 CM1 655356.91 MWD+IFR 655358.53 MWD+IFR 655356.75 MWD+IFR 655353.70 End Dir : t? 655351.75 MWD+IFR 655346.02 MWD+IFR 655343.90 THRZ 655340.28 MWD+IFR 655334.55 MWD+IFR 655328.81 MWD+IFR 655324.69 LCU 655323.08 MWD+tFR 655317.35 MWD+IFR 655311.61 MWD+IFR 655311.06 TJF 655305.88 MWD+IFR 655304.19 TJ E 655300.14 MWD+IFR 655294.41 MWD+IFR 655288.68 MWD+IFR 655282.94 MWD+IFR 655277.21 MWD+IFR 655271.47 MWD+IFR 655268.60 TJD ,~ S er -Sun P rY BP Planning Report Company: BP Amoco Date: 8/10/2006 Time: 10:59:44 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: A-17, True North Site: PB A Pad Vertical (TVD) Reference: . 48. 57+2g.5 77:1 Well: A-1 7 Section (VS) Reference: Well (O.OON,O.OOE,1 64.8tiAzi) Weilpath: Plan A-17A Survey Ca[cuilation Method: Minimum Curvature DhE Oracle 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 10000. 00 51.19 185.40 8463.33 8386. 26 4182. 87 -4121. 01 784.46 0.00 5943215.24 655265 .74 MWD+IFR 10066. 60 51.19 185.40 8505.07 8428. 00 4231. 47 -4172. 68 779.58 0.00 5943163.49 655261 .92 TJC 10100. 00 51.19 185.40 8526.00 8448. 93 4255. 85 -4198. 60 777.14 0.00 5943137.53 655260. 00 MWD+IFR 10200. 00 51.19 185.40 8588.67 8511. 60 4328. 82 -4276. 18 769.81 0.00 5943059.82 655254. 27 MWD+IFR 10277. 23 51.19 185.40 8637.07 8560. 00 4385. 18 -4336. 09 764.15 0.00 5942999.80 655249. 84 TJ B 10300. 00 51.19 185.40 8651.34 8574. 27 4401. 80 -4353. 76 762.48 0.00 5942982.11 655248. 54 MWD+IFR 10400. 00 51.19 185.40 8714.01 8636. 94 4474. 77 -4431. 34 755.16 0.00 5942904.40 655242. 80 MWD+IFR 10401. 69 51.19 185.40 8715.07 8638. 00 4476. 01 -4432. 66 755.03 0.00 5942903.08 655242. 71 TJA 10500. 00 51.19 185.40 8776.68 8699. 61 4547. 75 -4508. 92 747.83 0.00 5942826.69 655237. 07 MWD+IFR 10588. 39 51.19 185.40 8832.07 8755. 00 4612. 25 -4577. 50 741.35 0.00 5942758.00 655232. 00 A-17A T1 10600. 00 51.19 185.40 8839.35 8762. 28 4620. 73 -4586. 51 740.50 0.00 5942748.98 655231. 33 MWD+IFR 10608. 39 51.19 185.40 8844.60 8767. 53 4626. 85 -4593. 02 739.89 0.00 5942742.46 655230. 85 Start Dir 1 10612. 33 51.29 184.70 8847.07 8770. 00 4629. 73 -4596. 08 739.62 14.00 5942739.39 655230. 65 TSHA 10662. 74 52.92 175.99 8878.07 8801. 00 4668. 01 -4635. 79 739.41 14.00 5942699.69 655231. 25 TSHB 10689. 61 54.03 171.52 8894.07 8817. 00 4689. 34 -4657. 24 741.76 14.00 5942678.28 655234. 05 TSHC 10700. 00 54.51 169.83 8900.14 8823. 07 4697. 73 -4665. 56 743.13 14.00 5942670.00 655235. 58 MWD+IFR 10747. 81 56.99 162.30 8927.07 8850. 00 4737. 19 -4703. 86 752.67 14.00 5942631.90 655245. 91 TSAD 10800. 00 60.18 154.60 8954.30 8877. 23 4781. 38 -4745. 21 769.06 14.00 5942590.90 655263. 14 MWD+IFR 10900. 00 67.39 141.20 8998.61 8921. 54 4866. 77 -4820. 74 816.83 14.00 5942516.37 655312. 44 MWD+IFR 10903. 09 67.63 140.81 8999.79 8922. 72 4869. 38 -4822. 96 818.63 14.01 5942514.19 655314. 28 End Dir : 1 10909. 42 67.63 140.81 9002.20 8925. 13 4874. 72 -4827. 49 822.32 0.00 5942509.73 655318. 07 Start Dir 1 10998. 94 80.06 142.49 9027.07 8950. 00 4953. 61 -4894. 82 875.54 14.00 5942443.52 655372. 65 A-17A T2 11000. 00 80.20. 142.51 9027.25 8950. 18 4954. 57 -4895. 65 876.17 14.00 5942442.70 655373. 30 MWD+IFR 11100. 00 94.10 144.25 9032.21 8955. 14 5047. 28 -4975. 62 935.59 14.00 5942363.97 655434. 34 MWD+IFR 11142. 51 100.00 145.00 9027.00 8949. 93 5086. 85 -5010. 00 960.00 14.00 5942330.10 655459. 45 MWD+IFR 11188. 10 106.38 145.10 9016.60 8939. 53 5128. 59 -5046. 37 985.42 14.00 5942294.27 655485. 61 End Dir : 1 1 11200. 00 106.38 145.10 9013.24 8936. 17 5139. 33 -5055. 73 991.95 0.00 5942285.04 655492. 33 MWD+IFR 11300. 00 106.38 145.10 8985.04 8907. 97 5229. 62 -5134. 41 1046.85 0.00 5942207.51 655548. 83 MWD+IFR 11396. 54 106.38 145.10 8957.81 8880. 74 5316. 78 -5210. 37 1099.84 0.00 5942132.66 655603. 36 Start Dir 8/ 11400. 00 106.11 145.09 8956.84 8879. 77 5319. 91 -5213. 10 1101.74 8.00 5942129.97 655605. 32 MWD+IFR 11500. 00 98.11 145.01 8935.89 8858. 82 5411. 83 -5293. 18 1157.71 8.00 5942051.06 655662. 91 MWD+IFR 11513. 83 97.00 145.00 8934.07 8857. 00 5424. 72 -5304. 40 1165.57 8.00 5942040.00 655671. 00 A-17A T3 11600. 00 90.66 142.29 8928.32 8851. 25 5504. 82 -5373. 60 1216.51 8.00 5941971.86 655723. 35 MWD+IFR 11700. 00 83.30 139.15 8933.59 8856. 52 5595. 88 -5450. 84 1279.67 8.00 5941895.94 655788. 08 MWD+IFR 11789. 50 76,73 136.26 8949.11 8872. 04 5674. 27 -5516. 02 1338.94 8.00 5941832.00 655848. 66 End Dir : 1 1 11800. 00 76.73 136.26 8951.52 8874. 45 5683. 24 -5523. 40 1346.00 0.00 5941824.76 655855. 87 MWD+IFR 11900. 00 76.73 136.26 8974.48 8897. 41 5768. 69 -5593. 72 1413.29 0.00 5941755.84 655924. 58 MWD+IFR 12000. 00 76,73 136.26 8997.44 8920. 37 5854. 14 -5664. 04 1480.58 0.00 5941686.92 655993. 30 MWD+IFR 12100. 00 76.73 136.26 9020.40 8943. 33 5939. 59 -5734. 36 1547.87 0.00 5941618.00 656062. 01 MWD+IFR 12107. 00 76,73 136.26 9022.01 8944. 94 5945. 57 -5739. 28 1552.58 0.00 5941613.18 656066. 82 41/2" 12107.26 76.73 136.26 9022.07 8945. 00 5945. 80 -5739.47 1552.76 0.00 5941613.00 656067. 00 A-17A T4 Went 4S 7S 1S 1S 7S 1S 07 1S 0 1S 1S 1S 10 0 D7 1S 1S 1S 8 1S 1S 0 1S 1S D7 1S 1S '8 1S 1S 1S 1S D7 • • Terri Hubble BP Exploration AK Inc. PO Box 196612 MB 7-5 Anchorage, AK 99519 PAY TO THE ORDER OF 89-6/1252 295 "Mastercard Check" First National Bank Alaska Anchorage, AK 99501 MEM01._I ~ ~~~ DATE O~ I ~ ~ ~~Cp S ~ fap, vo ~m~<~- ~:L25200060~:99146227~55611' 0295 • TRANSMITTAL LE'T'TER CIIECKLIST WELL NAME _~~ ~ ~j~ Development Service Exploratory Stratigraphic Test Non-Conventiona Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK i ADD-ONS WHAT (OPTIONS) APPLIES ~ MULTI LATERAL (If last two digits in API number are between 60-69) TEXT FOR APPROVAL LETTER The permit is for a new wellbore segment of existing wel l j Permit No. ,API No. 50- - Production should continue to be reported as a function of the original API number stated above. PILOT HOLE ', Irt accordance with 20 AAC 25.005(f), all records. data and logs I ~ acquired for the pilot hole must be clearly differentiated in both +i well name ( PH} and API number (~0- - -_) from records, data and logs I ~ ~ acquired for well i SPACING ~ The permit is approved subject to full compliance with 20 AAC ~ EXCEPTION 12.055. Approval to perforate and produce /infect is contingent j j I upon issuance of a conservation order approving a spacing I I ~ exception. assumes the ~ ~ liability of any protest to the spacing exception that may occur. ~ DRY DITCH ~~ Alt dry ditch sample sets submitted to the Commission must be in SAMPLE i no greater than 30' sample intervals from below the permafrost or 1 ~ ~ from where samples are first caught and l0' sample intervals j through target zones. Non-Conventional Please note the following special condition of this permit: ~ Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and ~ implemented a water well testing program to provide baseline data ~ ~ on water quality and quantity. Com any Name must contact the ~ I Commission to obtain advance approval of such water well testing Rev: l; 2/06 C:`,jody\transmittal checklist • r ',, N m ° m n N ~ o '~ I ' o ~ ~ I Q ~ , Ili ~ ~~I ~ ~'I i O'' II '' iI o i li ~, ~ w' ~i O ; m i I o ~ ', a` I ' o !, i ~ i i Q ~~ r', ~ Q ', ~ i'~ n M ~ W O Q. N !, N '~ a~ N ar a .N a~ N O N (n~ ~ ~ ~ ~ ~~ ~ n~ ~' ~ Ali O. ~ Q, Q '~ , Q, Z ap. , ~' S`, ~~ ~ ~ ~. Q' ~ ~ ~ III ~I, ; ; ; I~~ ; '!, w~ i NI ' i~ ' ' I~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N w N y ~ ~ ~ ~ ~. ~ ~ ~ ~ ~ a~, a~, a~ a~ a~ m a~ a~ d a~ m, a~ d m, Q. Q: Q ! Q. Q. Q Q. d m, m. a~, a~ Q a~ a~ a~ m. a~, a~ a~ o Q. Q Q ¢ ;~ Q ~ } } } } } y } } ~ } } } } z, z z; z, z,z,z,} ~ } } } z,} } } } } } ~ iZ Z,Z,Z Zl III - is c U .. ° I o - ~ I .z c; a~ Ij O. o i i a ' ~ ~ w o o ~ c ~, - ' ; o ~: - ~ li _~ ~' °, m. ~ ~ w' ~ ' O' ~ c c coi o ' O o ~I > ~ ~' ''~ o ~ w~ N ~ ~ N~ N N ¢, N ~ ° ~ ~ d~ ~ O" ~ ~ O~ III W. ~ ~ a m, a •~, m. w a~ c o ' a m N a ~ > } m ~ .C ~ ~ O ~~ 3 O ~ ° M. W U. N, N, O. c O ~ Q ~ 03~ ~ a', a ~~ ~ N, m ~ ZI _. ~. 01 U ~ y, ~ ~ ~ N~ O~ ~~ ~ ~ C' Of t ~~ c ~~ ~~ 6 ~ ~ ~~ ~' ¢~ y N' N' N m w -a ° ~ '° o a~' ~ ~ •~ n _' ~' v ~ > m -°o. ~ m °~ N a ~ c ~ c ~ o. o ° O Q ~, ~ O. O 'O 7. c ~ ~ ~ (6~ N O M' O C in~ ~V F- ~,~ m O otS C. ..O-~ ~ c. N L pl N m, ~ ,. Y a o' o ~ c Q; o; ° o> > U 'Q Q °- a~, ° o ~ a. ° n 3 ', ° >' m ~ ~i Q b ~. C C' C w in O O O' ~ ~ 00. a0 O, tO ~ N (6, f6' O Q f6. ~ W ', T O. p1 O N ° ~, °' ~ ~ ~° a o o c aoi m. m o; Z O ~. ~ ~ ~ 3' ~ O ~ ' s m' 3 •~ °~ ~I a Q ~ ~ ~ m m ~ ~' m' ai ~ t ~ `~' m a; y' ~°' '°' ~ c c :~, voi w m. ._ ~. O1 0 ~' o n 3 li o c; -°' ~, 3 I ~a c. a. m n n ~ a' m' E. a~ ~ ~ M. ~~ ~~ ~~ a~' ~ ~ ,~~ o ° vi m. 3 3, m. ~ ~ .. :a `~ ° .~..' 3 ° ~ o Q, m N, n 3, ~ o. 3 ~ L a~ o °o Z ~~- c c' -° a ~> ~ aai a a ~ ~ ~ ° o o °c ~ ~ °~ a°O m. ~ a o. rn c a Q w ~, a ~ ° m ai m °' °= a~ a~ ° m ~ °' c i o' ::' ~c a~, ° o' N' E' a~ E' r o ~ ° ~«- ° c; on ~, r ~ a~ a a a ° a ~ fl, of w Q ~, ~ aoi v; °- d ~, ~, - ~, ~ N ~ '~, ~ E' c $ '3. N v , N, o' ,°~ c t' v. m ~ ~ o. o aS a~ ~ n ~ w, m. c. w, i m co m m; ~, o >, ~ S !~, a ~N o Q, ' O' :°- a~ c .S a a ~ ~ T m a~' o, m ~3 c, ~ ~ i ~ ~? ~ a. a~' c. ~, ~ '-° .= a ~ ~ o U o U o ° T a ~ Il J. (0' Q _ a a a,. U 00~ L, C. C,. ~. N "J ~, C. N. •~; ~ ~ U~ .y (6' L 3'. ~ ~~ O. N ~~ O. N m ~ C N. c. O N ~'~. ~ w, °? ° 3. m m, m ~ m ~ ~ E. m. 3 a'' >' o v f4 m' - ~ a?; ~?' ~' r-'-' a a E - c ° i, ~ ~ f° ° c I c v v v `o' o _ _ v ~ o. c. '' ~ o o. ~ i~ a. m. ~, w. 3 a~ c ~ ~, a ~, J ml ~ N ~ o o _o ~, ~ a~ m. ~ ~ c ~ 3 n ~ c `° F- H H' ~ v m' °' >' _° a' a' Y' ~' °' ~ '' E m w n `° m 'c, ~' °' ~ ~', a a n ~ ~ m ~ - ~ o o ~ ~' ~; ~, m; a; ~ v ~ ~-, O O, ~ ° °~ ° m m. 'm. af°i o Y T a~ m U ~a,~~~'~;'scn,_,ooaa,U~'¢azl,U,cn.U:000.¢~-¢~ommU~ ~'~ aov~cnU~ W n p ~ N M ~' ~ (O i~ O O O ~ N M V M (O I~ W 6~ O ~ N M a ', ~ CO I~ W O '. ~ N M V ~ (D n W °~ ~ ~ ~ .-- ~ e- ~ ~ ~ ~ N N N N N N N N N N M M M M M 'i M M_ M M M ', U O _... __ _- __- ..__. ___ U m co co ~- m °o m °o ar °o g O O ~ N R~ O N N w ~ N ~!~ ~ ~ N N a ~ w °° I = °° °° N y T J~ .c L U i s QQ c p,U ~~~ a~ ',w a~ ~~ a~ a a a ~I ~I~~ m ~~ i N 'V O ~ '' O C C ° ~I .~ .N c ~ c E w U ', i Y ' ~.~ ~' D ~~ ~^) a~ U C ° i O'y o ,~ lL',~ c°'7Ei o U • • Well f-iisiory File APPENDIX Information of detailed nature that is not particularly germane to the Welf Permitting Process but is part of the history file. To improve the readability of ilie 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 calegory of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Jul 27 15:54:48 2007 Reel Header Service name .............LISTPE Date .....................07/07/27 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/07/27 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER PBU MWD/MAD LOGS WELL NAME: A-17Ai API NUMBER: 500292052001 OPERATOR: BP Exploration (Alaska), Inc. LOGGING COMPANY: Sperry Drillings Services TAPE CREATION DATE: 27-JUL-07 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: MW0004603216 MW0004603216 MW0004603216 LOGGING ENGINEER: M. LEAFSTEDT M. LEAFSTEDT M. LEAFSTEDT OPERATOR WITNESS: C. CLEMENS C. CLEMENS D. MASKEL MWD RUN 4 JOB NUMBER: MW0004603216 LOGGING ENGINEER: M. LEAFSTEDT OPERATOR WITNESS: D. MASKEL SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD OPEN HOLE 35 11N 13E 3126 1014 79.64 51.14 CASING DRILLERS IJ.L-C- a 0 (o -10`3 ~ - 5~~- 4 BIT SIZE (IN) 1ST STRING 8.500 2ND STRING 6.125 3RD STRING PRODUCTION STRING REMARKS: SIZE (IN) DEPTH (FT) 9.625 7846.0 7.000 10612.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE 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-17 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 7846'MD/7033'TVD. THE WHIPSTOCK WAS POSITIONED, THE WAS WINDOW MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 1. 4. MWD RUN 1 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 1. THESE MAD DATA WERE MERGED WITH RUN 1 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUNS 1,2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) MWD RUNS 3,4 ALSO INCLUDED AT-BIT INCLINATION (ABI). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO AN OPEN-HOLE GAMMA RAY LOG RUN IN A-17 ON 10 JANUARY 1981. THESE PDC DATA WERE PROVIDED TO SDS BY D. DORTCH ON 14 JUNE 2007, QUOTING AUTHORIZATION FROM COLE A$EL (BP GEOSCIENTIST) LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THE SHIFTED SGRC LOG IS CONSIDERED THE PDC LOG FOR A-17AI. 7. MWD RUNS 1-4 REPRESENT WELL A-17AI WITH API#: 50-029-20520-01. THIS WELL REACHED A TOTAL DEPTH (TD)OF 12157'MD/9036'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header • Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/27 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; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 7705.5 RPX 7815.5 RPS 7815.5 RPM 7815.5 RPD 7815.5 FET 7815.5 ROP 7844.5 all bit runs merged. STOP DEPTH 12088.0 12095.0 12095.0 12095.0 12095.0 12095.0 12153.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 7705.5 7707.5 7710.5 7712.5 7712.0 7714.0 7719.0 7721.5 7722.0 7724.0 7725.0 7728.0 7739.0 7742.5 7752.0 7754.5 7755.0 7757.0 7759.5 7761.5 7769.0 7771.5 7775.0 7777.0 7777.0 7779.5 7790.5 7793.5 7802.5 7804.5 7804.5 7807.5 7808.0 7810.5 7829.0 7831.5 7833.0 7834.5 7835.5 7837.0 7846.0 7848.0 7851.0 7854.0 12153.5 12156.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 1 7707.5 MWD 2 7872.0 MWD 3 10612.0 MWD 4 11091.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type . ............ .....0 MERGE BASE 7872.0 10612.0 11091.0 12156.5 • 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 7705.5 12153.5 9929.5 8897 7705.5 12153.5 RPD MWD OHMM 0.19 2000 28.6397 8560 7815.5 12095 RPM MWD OHMM 0.18 2000 26.2557 8560 7815.5 12095 RPS MWD OHMM 0.38 2000 24.9389 8560 7815.5 12095 RPX MWD OHMM 0.62 2000 22.147 8560 7815.5 12095 FET MWD HOUR 0.42 87.18 3.64805 8560 7815.5 12095 GR MWD API 14.23 597.05 115.411 8766 7705.5 12088 ROP MWD FT/H 0.01 412.62 76.2674 8619 7844.5 12153.5 First Reading For Entire File..........7705.5 Last Reading For Entire File...........12153.5 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/27 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.......07/07/27 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 GR 7707.5 ROP 7846.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 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): STOP DEPTH 7815.0 7872.0 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): 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 U 17-SEP-06 Insite 68.18 Memory 7872.0 7846.0 7872.0 29.4 29.4 TOOL NUMBER 134745 8.500 7846.0 Fresh Water Gel 11.00 54.0 9.7 1400 4.0 .000 .0 .000 127.4 .000 .0 .000 .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 7707.5 7872 7789.75 330 7707.5 7872 GR MWDO10 API 33.1 80.03 53.4544 216 7707.5 7815 ROP MWDO10 FT/H 0.01 102.11 8.09308 52 7846.5 7872 First Reading For Entire File..........7707.5 Last Reading For Entire File...........7872 File Trailer Service name........... .STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/27 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.......07/07/27 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 7815.5 10565.0 RPX 7818.0 10559.0. RPD 7818.0 10559.0 FET 7818.0 10559.0 RPS 7818.0 10559.0 RPM 7818.0 10559.0 ROP 7872.5 10612.0 LOG HEADER DATA DATE LOGGED: 22-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10612.0 TOP LOG INTERVAL (FT) 7872.0 BOTTOM LOG INTERVAL (FT) 10612.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 30.1 • MAXIMUM ANGLE: 52.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 134745 EWR4 ELECTROMAG. RESIS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 7846.0 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): 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 .IIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Fresh Water Gel 11.20 56.0 9.6 2600 3.8 .900 70.0 .380 175.0 1.500 70.0 1.900 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7815.5 10612 9213.75 5594 7815.5 10612 RPD MWD020 OHMM 0.37 2000 7.8863 5483 7818 10559 RPM MWD020 OHMM 0.64 2000 5.551 5483 7818 10559 RPS MWD020 OHMM 0.69 18 88.91 2.83352 5483 7818 10559 RPX MWD020 OHMM 0.62 17 10.94 2.60499 5483 7818 10559 FET MWD020 HOUR 0.53 37.92 2.29875 5483 7818 10559 • GR MWD020 API 40.54 421.61 141.86 5500 7815.5 ROP MWD020 FT/H 0.6 178.34 74.3602 5480 7872.5 First Reading For Entire File..........7815.5 Last Reading For Entire File...........10612 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/27 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.......07/07/27 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 FET 10559.5 11038.5 RPX 10559.5 11038.5 RPS 10559.5 11038.5 RPD 10559.5 11038.5 RPM 10559.5 11038.5 GR 10565.5 11031.5 ROP 10612.5 11091.0 LOG HEADER DATA DATE LOGGED: 26-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11091.0 TOP LOG INTERVAL (FT) 10612.0 BOTTOM LOG INTERVAL (FT) 11091.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 52.1 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 EWR4 Electromag Resis. 4 48783 10565 10612 • • BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 10612.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G) 8.40 MUD VISCOSITY (S) 26.0 MUD PH: 8.9 MUD CHLORIDES (PPM): 2000 FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 4.000 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.750 168.8 MUD FILTRATE AT MT: 4.000 70.0 MUD CAKE AT MT: 4.000 70.0 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 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10559.5 11091 10825.3 1064 10559.5 11091 RPD MWD030 OHMM 0.38 2000 128.094 959 10559.5 11038.5 RPM MWD030 OHMM 0.38 2000 151.509 959 10559.5 11038.5 RPS MWD030 OHMM 0.38 2000 88.1498 959 10559.5 11038.5 RPX MWD030 OHMM 0.93 14 18.26 23.3903 959 10559.5 11038.5 FET MWD030 HOUR 1.01 87.18 12.3371 959 10559.5 11038.5 GR MWD030 API 18.76 5 58.78 87.7098 933 10565.5 11031.5 ROP MWD030 FT/H 0.55 2 94.66 48.1437 958 10612.5 11091 First Reading For Entire File..........10559.5 Last Reading For Entire File...........11091 ` • • File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/27 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.......07/07/27 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 GR 11032.0 12091.0 RPX 11039.0 12098.0 RPD 11039.0 12098.0 RPM 11039.0 12098.0 FET 11039.0 12098.0 RPS 11039.0 12098.0 ROP 11091.5 12156.5 LOG HEADER DATA DATE LOGGED: 28-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12157.0 TOP LOG INTERVAL (FT) 11091.0 BOTTOM LOG INTERVAL (FT) 12157.0 BTT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.6 MAXIMUM ANGLE: 102.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 10612.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel • MUD DENSITY (LB/G) 8.40 MUD VISCOSITY (S): 33.0 MUD PH: 8.4 MUD CHLORIDES (PPM): 1100 FLUID LOSS (C3) 2.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 6.000 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 4.160 104.0 MUD FILTRATE AT MT: 6.000 70.0 MUD CAKE AT MT: 6.000 70.0 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 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 11032 12156.5 11594.3 2250 11032 12156.5 RPD MWD040 OHMM 0.19 2000 37.6548 2119 11039 12098 RPM MWD040 OHMM 0.18 2000 23.4667 2119 11039 12098 RPS MWD040 OHMM 0.44 2000 53.8472 2119 11039 12098 RPX MWD040 OHMM 0.92 2000 72.1967 2119 11039 12098 FET MWD040 HOUR 0.42 24.09 3.2228 2119 11039 12098 GR MWD040 API 14.23 597.05 65.2245 2119 11032 12091 ROP MWD040 FT/H 0.05 412.62 95.4088 2131 11091.5 12156.5 First Reading For Entire File..........11032 Last Reading For Entire File...........12156.5 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/27 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................07/07/27 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................07/07/27 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File • Scientific Technical Services Scientific Technical Services
