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209-025
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ®~ - ©~~ Well History File Identifier Organizing (done) RE CAN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~.~.,aen iuuiuiiuiuiii DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: R~~a~~eed~ iuiuiiin!iiiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: Date: ^ Other:: ® /s/ III II~IIIIIIII VIII Project Proofing BY: Maria Date: ~ ~ d /s/ Scanning Preparation ~_ x 30 = d + ~ =TOTAL PAGES_ t~, (Count does not include cover sheet) BY: ___ Maria Date: (~ /~~j ~~/ /s/ _~ Production Scanning Stage 1 Page Count from Scanned File: _~1,~ (Count does include cover eet) Page Count Matches Number in Sc,,anning Preparation: YES NO BY: Maria Date: ~ ~ ~ ~~ ls/ Y Y 1 Stage 1 If NO in stage 1, page(s) discrepanci s were found: YES NO 4I BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I (I II I I III ReScanned III 111111 VIII V III BY: Maria Date: /s/ Comments about this file: Quality Checked III (11111 III II'I III 10/6/2005 Well History File Cover Page.doc Pv OF Ty • • �w�� I % %sv THE STATE Alaska 1 Gas � 1L1 1sKA Coriservati `1' n Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue * h' OF ALAS' Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 John McMullen SCANNED JUN 0 7 2013 Engineering Team Leader BP Exploration (Alaska), Inc. © a P.O. Box 196612 I Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D -16A Sundry Number: 313 -264 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P.koerster Chair DATED this L day of June, 2013. Encl. STATE OF ALASKA , \' DTS 6i/ �/ /3 Jo ALASKA OIL AND GAS CONSERVATION COMM 6- MAY 2013 APPLICATION FOR SUNDRY APPROVAL AOGCC 20 AAC 25.280 1. Type of Request: ❑ Abandon ® Plug for Redrill • ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. 209 -025 • ❑ Exploratory 0 Stratigraphic 3. Address: ►�� Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 20683 -01 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU D -16A • Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior . 10. Field / Pool(s): ADL 028285 & 028286 Prudhoe Bay Field / Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10410' 9083' • _ 10320' 9041' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' _ 110' Surface 2662' 13 -3/8" 2662' 2662' 4930 2670 Intermediate 8416' 9 -5/8" 8416' 7677' 6870 4760 Production Liner 1083' 7" 8261' - 9344' 7545' - 8505' 7240 5410 Liner 1243' 4 -1/2" 9165' - 10408' 8346' - 9082' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9972' - 10126' 8887 - 8955' 4 - 1/2 ", 12.6# 13Cr80 9172' Packers and SSSV Type: 7" x 4 Baker S -3 Packer Packers and SSSV 9053' / 8245' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: • IS Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation. June 5, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG IS Suspended • 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nathan Sperry; 564 -4258 Printed Name: j;- ,,. Title: Engineering Team Leader Em 11: Nathan.Sperry@bp.com Signature:� A.--- Phone: 564 -4711 Date: j' l c /1.3 ! ..- Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: "61 �L/ — ❑ Plug Integrity b BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance VJ O t h e r : d r # 20 191} 2 5 , 1 / Z ( 1 t t is' - f c p / y /4c cn-2 t�1 ap ro vc Pc 0 (7p tc5/ f 35-06 /s �/ RBDMS JUN — 7 Lv Spacing Exception Required? ❑ Yes 121 No Subsequent Form Required: /0 – ¢e 7-- ( APPROVED BY Approved By: t' ' 1 COMMISSIONER THE COMMISSION Date: e ° 0 ""l --> Form 10-403 Revised 0/2012 Approved application is valid for 12 months from the date of approval `�' I`� p'ca VF 4 l 1s �1 1 L V • • To: Alaska Oil & Gas Conservation Commission From: Nathan Sperry by CTD Engineer Date: May 28 2012 Re: D -16A Sundry Approval Sundry approval is requested to plug the D -16A perforations as part of the drilling and completion of proposed D -16B coiled tubing sidetrack. History and current status: D -16 was originally completed in 1981. A rig sidetrack to D -16A was drilled in 2009 as a high angle Zone 2B /2C well. Fluid tops came in high so the well was completed in Zone 3. Initial test results were 650bopd, 42% WC, and 25MMcfd. Due to high initial GOR and rapidly declining oil rate, D -16A produced for less than one year. Z2C perfs were added in April 2012 which resulted in additional water but no additional oil. The well is no longer a competitive producer. • Proposed plan: Sidetrack D -16A to the D -16B location using Nordic 1 Coiled Tubing Drilling rig on or . around June 17th, 2013. The D -16B sidetrack will exit the existing 4.5" liner and kick off in Zone 4 and land in Zone 2B. This sidetrack will be completed with a 2 -7/8" L -80 liner and cemented in place. This Sundry covers plugging the existing D -16 perforations via the D -16B primary liner cement iob and a liner top packer if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. Gd nCV(. Ike v wat per a irom r4e 4vr�er cent' Q tt ro �s rode. a Me mil 4a r, el��y ti iio lute R� r ti 90% tV C . ,C61% f(/1(Ity CUffe / u' d io•e Sb Sro(1'rat k c4 4erdd a flow ;e roved fern , boa, roils of 4c. Pot • • Required Permit? Pre -Rig Work (scheduled to begin June 5 2013) 10-403 PTD 1. F Load and kill well No No 2. C Mill XN at 9159' MD to 3.80" No No 3. C Drift to 9,650' MD for 4 -1/2" KB packer whipstock No No 4. V PT MV, SV, WV. Set TWC No No 5. 0 Remove wellhouse and level pad No No Required Permit? Rig Work (scheduled to begin June 17 2013) 10-403 PTD 1. MIRU and test BOPE 250 psi low and 3,500 psi high. Yes No 5v1-7 e/f' 2. Bullhead kill well. No No 3. Set 4 -1/2" KB packer whipstock at 9,595' MD. No No 4. MIT -T to 2,000 psi. No No 5. Mill 3.8" window at 9,595' and 10' of rathole. No Yes 6. Drill build: 4.25" OH, 509' (25 deg DLS planned). No Yes 7. Drill lateral: 4.25" OH, 1935' (12 deg DLS planned). No Yes 8. Log with OH triple combo. No Yes 9. Run 2 -7/8" liner leaving TOL at 9,500' MD. No Yes PTO 10. Pump primary cement job: 27 bbls, 15.8 ppg, TOC at 9,500' MD. Yes* Yes 11. Perform liner cleanout and GR /CCL log. No Yes 12. Test liner lap to 2400 psi. No Yes 13. Perforate liner based on log interpretation ( -50'). No Yes 14. Freeze protect well to 2500' MD. No Yes 15. Set BPV; RDMO. No Yes * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set GLV's 3. Set liner top packer with slickline as needed if failed liner lap pressure test in Rig Work step 10 above. 4. ASRC flowback/well test Nathan Sperry CTD Engineer 564 -4258 CC: Well File Joe Lastufka 'KEE = CIW • ViE31.1-EAC MOEVOY D -1 6A SAY NOTES: 4-112" CHROME TEIG & UM"' ACTUATOR= BAKER C INITIAL WELLBORE SHOWN BELOW 1* REV -;--- - - - - — - - — 78757' WHIPSTOCK*" BF. B_EV = 42.97' I i 16 ------ max - Angle = 1 I I 2184 1 HES X14 1) 3.813' = 1 Datum RC = 9934 — — 2641 H mc I Datum TVD = 8800' SS GAS LFT MANDRILS 13-3/8' CSG, 72#, L- , ID = 12.34r 1 2662' 1 ST 14) TVD CEV TYPE VLV LATCH FORT DATE 4 3508 3508 1 WAG DAN R( 0 04/25/13 3 5090 4997 35 INC DAY FE 0 04/25/13 L 2 6595 6200 39 1.41.43 DMY RK 0 09/10/09 1 7976 7305 33 114.43 CAW FE 0 09/10/09 Minimum ID = 3.725" @ 9159' 8261' I-- 9-5/8" X 7" BKR I-RD ZXPN LTP w TIEBACK 4-1/2" HES XN NIPPLE SLV, D= 6.19" — .T,1 I 8277' —19-5/8" X 7" BKR FLEXLOCI( OR HGR, 13= 624" 1 1 ■ 4 t FALLOUT MI:OW(0-16A) 8416' - 8433' I 19-5/8" 1.4.4-Fs 1-1 841W 4'4 , & ( "' 9022' H4-1r2 FES X WO= 3.813" I 19-5/8" CSG 47#, L-:. , D = 8.681' 1-L 9357' — t 9053' 1-17" X 4-1/2" BKR S-3 PM, D = 3.875" 1 1 .44, 9086' . -14-1/2" 1-ES X NP, ID= 3.813" `tp: 44, PERFORATION SLAWARY ‘t 915W H4-1/2" HES XN MP, 0 = 3.725' Nor REF LOG: SLB-MAO 09/07/09 ‘ 9185' 1— 7' X 5" 14DZXPN LW ANGLE AT TOP PERF: 64° @9972' w /TIEBACK SLV, Note: Refer to Roduction CIB for historical perf data 13= 4.180' SIZE . SW INTERVAL Opn/Sqz DATE 3-3/8" 6 9872 - 99132 0 09/23/09 L 9172' H 4-1 WLEG. ID= 3.958' 1 2-7/8' 6 10118 - 10126 0 04/11/12 11 1. I 9181' I- 7" X 5' BKR K FLEXLOC . Lf421-1GR, D = 4230" 9191' I x 4-irr xo, 4-1/2" TBG, 12.04, 13CR-80 VAM TOP, H 9172' 0= 3.900' .0152 bpf, I) = 3.958' 1 7" LM, 26#, L-80 BTC-M, .0383 bpf, 1) =6.278' H 9344' • • I Fs --L 10320' 4: 4 11:t 14-1/2 LM, 12.6#, 13CR-80 VAM TOP, .0152 bpf, D = 3.958' —1 10408' 1 \.• DATE REV BY COMMENTS 1 DATE REV BY COMENTS F4U)HOE BAY UNIT 1228/81 ORIGINAL COMPLETION I 04/20/12 JTO PJC FEFFORAT1ONS (4/11/12) WEL D-16A 09/12/09 NUB SIDETRACK (D-16A) 04/29/13 RCT/ PJC GLV CA) (04/24/13) FERMI No: t090250 09/19/09 PJC CRLG HO CORRECTIONS AR No: 50-029-20683-01-00 10/02/09 JECIPJC FERFS (09/07/09) SEC 23, T11N, R13E, 210' RI_ & 1692 FE. 10)02/09 DIR/PJC GLV CIO (09119I09) 04/09/10 RC/44) CMG DRAFT CORRECTIONS BP Exploration (Alaska) TREE= CNV SA YHR_LI EAT = MCEVOY D -1 6A INITIAL OTE ORE SHOWN BELOW _ & LNR*** ACTUATOR = BAKER C KB. ELEV = 78.57' WHIPSTOCK * ** BF. E_EV = 42.9T KOP= - - 8416' kilx Angle = ' 2184' — 14 -1/2" HES X MP, D = 3.813" ---- -- - - - - -- 1 x Angle = 66° @ 9866' Datum M3= 9934' r . 2661' FOG Datum ND= 8800' SS GAS LIFT MANDRELS 13 -3/8" CSG, 72#, L -80, ID = 12.347" — 2662' ST MD ND DEV TY FE VLV LATCH PORT DATE 4 3508 3508 1 MMG DM' RK 0 04/25/13 3 5090 4997 35 MMG DMY RK 0 04/25/13 L 2 6595 6200 39 MMG DMY RK 0 09/10/09 1 7976 7305 33 MMG DMY RK 0 09/10/09 Minimum ID =3.80" @ 9159' 8261' H 9 -5/8" X 7" BKR I-RDZXPN L T P 4 -112" HES XN NIPPLE sLV, D =6.19" 1 2 1V 8277' H9 X 7" BKR FLEXLOCK LNR HGR, ID = 6.24" IV • 7. T I, MLLOUT WINDOW (D-16A) 8416' - 8433' • 9-5/8" WFAPSTOCK H 8416' �4 4 4 4 4 v. 9022' — 14 -1/2" HES X NP, D = 3.813" 9-5/8" CSG, 47 #, L -80, D = 8.681" H 935T • 9053' H7" X 4 -1/2" BKR S -3 PKR, D = 3.875" ;� 9086' J I4-1/2" I 4 -1 /2" HES X NP, D = 3.813" 4-1/2" I ES XN MP, ID = 3.725" PERFORATION SUMMARY �� 91 �' 1 kV to 3.80" REF LOG: SLB MV4D 09/07/09 , 9165' — 7" X 5" HRD ZXPN LW ANGLE AT TOP PERF: 64° @ 9972' w /TEBACK SLV , Note: Refer to Production DB for historical pert data D = 4.180" SIZE SPF INTERVAL Opn/Sqz DATE 3 -3/8" 6 9972 - 9982 0 09/23/09 9172' — 14 - 1/2" WLEG, ID = 3.958" r 2 -7/8" 6 10118 - 10126 0 04/11/12 ` 9181' I�7" X 5" BKR FLIXLOCK 1 a LNR HGR, D = 4.230" N 9191' H X 4 - 1/2" Xo, 4 -1/2" TBG, 12.6#, 13CR -80 VAM TOP, H 9172' D = 3.900" .0152 bpf, D = 3.958" 7" LNR, 26#, L -80 BTC-M, .0383 bpf, D = 6.276" H 9344' • • PBTD .04%k 4 -1/2" LNR, 12.64, 13CR -80 VAM TOP, .0152 bpf, D = 3.958" — 10408' ■■• DATE REV BY COMMB■ffS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/28/81 ORIGINAL COMPLETION 04/20/12 JTC/ PJC PERFORATIONS (4/11/12) WELL: D-16A 09/12/09 N9ES SIDETRACK (D -16A) 04/29/13 FACT/ PJC GLV GO (04/24/13) PERMT No: '2090250 09/19/09 PJC DRLG HO CORRECTIONS 05/28 /13 NNVS PROPOSED FR -RIG AR Na: 50- 029 - 20683 -01 -00 10/02/09 JED/PJC PERFS (09/07/09) SEC 23, TI 1 N, R13E, 210' FN._ & 1692' FEL 10/02/09 DTR/PJC GLV CJO (09/19/09) 04/09/10 RCJJMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) TREE= CNV VVELLHEAD MCEVOY D -1 6 SAIllk NOTES: 4 -1/2" CHROME TBG& LNR * ** ACTUATOR= BAKER INITIAL WELLBORE SHOWN BELOW KB. ELEV = 78.5T WHIPSTOCK * ** BF. ELEV= _42.9_T I _KOP= 8416' 2184' — �4 -1/2" HES X NIP, D= 3.813" Max Angle = 66° @ 9866' Datum MD = 9934' - -- — 2661' --I FOC Datum TVD= 8800' SS GAS LIFT MANDRELS 13 -3/8" CSG, 72#, L -80, ID = 12.347" — 2662' ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3508 3508 1 NM DMY RK 0 04/25/13 3 5090 4997 35 WAG DMY RK 0 04/25/13 L 2 6595 6200 39 MD DMY RK 0 09/10/09 1 7976 7305 33 AUG DMY RK 0 09/10/09 Minimum ID = 3.725" @ 9159' ______— 8261' — 9- 5/8 "X7 " BKR FRDZXFN LIP w/11BACK 4-1/2" HES XN NIPPLE SLV,D =6.19" l� I 1■ 8277' 9-5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6 -24" 1 1. '4 MLLOUT W1JDOW (D - 16A) 8416 - 8433' • 9 -5/8" WHPSTOCK —I 8416' �4 4 4 4 X �A � ' 4 9022' —14-1/2" HES X NP, E)= 3.813" 9-5/8" CSG, 47 #, L -80, ID = 8.681" H 9357' • 1 9053' — X 4 -1/2" BKR S -3 PKR, D = 3.875" 9086' J 4- 1 /2 " HES X NP, D =3 -813" ; 9159' � 4 -112" HES XN NP, D = 3 -725 ", PERFORATION SUMMARY �i mil to 3.80" REF LOG: SLB AMVD 09/07/09 , 9165' I 7" X 5" HRD ZXPN LW ANGLE AT TOP PEW: 64° @ 9972' w /TRACK SLV, Note: Refer to Production DB for historical pert data D = 4.180" SIZE SPF INTERVAL Opn/Sgz DATE 3 -3/8" 6 9972 - 9982 0 09/23/09 9172' — 14 -1 /2" WLEG, ID = 3.958" i 2 -7/8" 6 10118 - 10126 0 04/11/12 +Alik 9181' 17" X 5" BKR FLEXLOCK, Ilk LNR HGR, D = 4.230" N 9191' — s" x 4 -1/2" xo, 4 -1/2" TBG, 12.6#, 13CR -80 VAM TOP, —I 9172' TOL 9,500 D = 3.900" .0152 bpf, ID = 3.958" TOC @ TOL TOWS 9595' 4 -1/2" KB 7" LNR, 26 #, L -80 BTC-M, .0383 bpf, D= 6.276" —I 9344' \ ` Packer WS (orient 90 LOHS) 2 -7/8" x 3 -1/4" XO 11,200' —49 deg 12,039' MD TD PBTD 10320' ih 4 -1/2" LNR, 12.6#, 13CR - 80 VAM TOP, .0152 bpf, D = 3.958" 10408' \.• DATE REV BY COMvB"ffS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/28/81 ORIGINAL COMPLETION 04 /20/12 JTC/ PJC PERFORATIONS (4/11/12) WELL: D-16 09/12/09 N9ES SIDETRACK (D -16A) 04/29/13 RCT/ PJC GLV C/O (04/24/13) PERMIT No= '2090250 09/19/09 PJC DRLG HO CORRECTIONS 05/13/13 NWS Proposed CTD Sidetrack API No: 50- 029 - 20683 -01 -00 10/02/09 JED PJC PERFS (09/07/09) SEC 23, T11 N, R13E, 210' FNL & 1692' FEL 10/02/09 DTR/PJC GLV C/O (09/19/09) 04/09/10 RC/JM) DRLG DRAFT CORRECTIONS BP Exploration (Alaska) NORDIC - CALISTA RIG 1 CHOKE / REEL/CIRCULATION MANIFOLD DIAGRAM V12 . la, V14 1 7- 1116" 5000 psi BOP's 10 = 7.06 " V15 V11 2TFr7 /I7 1H6°5000 Pei. Rxrs L-- J Transducers 0 ■ f POOR BOV 1 DEGASSER V2 V1 V 16 =C 111.". �,. - „. Hot typical BOP / 1 \ j arrangement for ]3 :lore tubing drilling III III ilr i mg! I 7 1/16” 5000 pal, RXJ6 ' V17 HCR I IC Ys/uu _ �' IK OK To Poor Boy Gas Buster 0:,,4 I I ^^. I 016 � K V18 V19 I 3.00 "5000 pat HCR Y �� r ]1/16 "5000 psi. RxZ1 • i meiger I • -. '- 1 rr' ■- 2- 1116 "5000 psi CHECK VALVE I Manual Choke - - IOU 71 /16 Cameron FOV Gate Valve n 5000 psi ■ 8 0 EOH /Diesel -e6!' FP Line CoFlex Hose ._ fin 114 Tam Nalco I Ill= SWACO 10WOG To Production Tree or Cross Over • Pr es a transducers - CoFlex Hose CV11 11 4110 CV12 To Coiled Tubing Bleed Off Inner Reel Valve l w. - t.. - M - CV13 Cement Line In • Ground Level Tie -in I CV30 -1 CV3 CV2 ---- T Stand Pipe Manual Choke - -- - _ +: • • 7- -- - -- "" - - Pressure Transducers I _ ■ a CV9 Mo 40 I ' 1 CV17 411 a • - nxiw6 0/ CVi MI/ IMF IMP' NB v _ i I 111111 Tiger Tank '•• Mud Pump �I ....a O . _ - In From - Baker MP, 8 MP 2 Choke • • CV14 to Pits Rig Floor ir Mud Pump 81 41 CV16 Reverse CI ■"l Cir CT while OOH SM -- ---- - -_ - -� _ III 0 .wa To Manifold CV15 1- Jun -2010 4 Ream.. rirrnlatinn lion/ CT while (1r1H CoFlex Hose • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve / D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and ,/ operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 -02 22525 0 ' .1 O 00) 00 KA T 0 0 0 0 r . 0 0 0 0 0 0 �..'' I,'/ r r P r P P tll . O •�� 1 0 O U C4 0 co '.�, a.V, r 0 � , .:z �- y � `z w � v.) ., [-■ O +' (f a�i v m PI 0 rn 5 N 0 CO a) z on (n rn ;.a tr7 a l7 rn = Q h C� - N N N -.<...j 7 Ln N ,� cd ash r , : 0Q � ? ? � -- o os '.' (t2 vi N N r N N Q t;13$.0- ___,fif..,1 } �� fa X a 0• E J , Z N H -. N N 0 U) (7) , V1' LL LL LL LL LL LL cu- 0 0 0 0 0 0 O` F- F- F- F- F- F- d" 0' O O O O D O 0 W W W W W W C's 000000 r.I C I C I O C C I O J J J J J J A4 t7) a . . moo rl M .. Q , x x x X x x M N ii in I- O F- . F- u) s^E C9 C9 ..... a y w o 0 0 0 0 °o 0 = c>O p p 0 0 �' ,cc O O p 0 0 0 p 0,2 O O ti h 4' F` U _ o r� O U CO v o M 0000:100 0 0 0 i. N a, - N Q m Cr) rty am el U 'J 0 .-1 C Y ro 0_ N 49 a Q rn w m to CO Q m p C N ON N ro C m z ro no w z 2 J (n 0 co N v u °, o L ® o r .- yr O w _C 0 v N Y ± N L, .. AA 41 a O C v) 0 C/9 5 N a \` RECEIVED • STATE OF ALASKA • APR 2 6 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon 11 Repair Well U Plug Perforations LJ Perforate Li Other LJ Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska) , Inc. Developmenttjloratory ❑ -, 209 -025 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: - Anchorage , Alaska 99519 -6612 50- 029 - 20683 -01 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL- 028285 & 028286 PBU D -16A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10410 feet Plugs measured NONE feet true vertical 9083 feet Junk measured NONE feet Effective Depth measured 10320 feet Packer measured 9053 feet true vertical 9041 feet true vertical 8245 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 74' 20" Conductor 36'-110' 36' -110' Surface 2627' 13 -3/8" 72# L -80 35' -2662' 35' -2662' 4930 2670 Production 8362' 9 -5/8" 47# L -80 34' -8416' 34' -7677' 6870 4760 Liner 1083' 7" 26# L -80 8261' -9344' 7545' -8505' 7240 5410 Liner 1243' 4 -1/2" 12.6# 13Cr80 9165'- 10408' 8344' -9082' 8430 7500 Perforation depth Measured depth SEE ATTACHEDfeet '+,.- NNED APR 3 0 2012 True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 33' -9172' 33'-8352' Packers and SSSV (type, measured and true vertical depth) 4 -1/2" BKR S -3 PKR 9053' 8245' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 133 9496 925 13 4 0 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development © Service ❑ Stratigraphic ❑ Daily Report of Well Operations 16. Well Status after work: Oil • ® Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: Contact Nita Summerhays Printed Name Nita Summer ;Ifs Title Data Manager ; ,,,,nrs 0 %����j�� ��� Phone 564-4035 Date 04/25/2012 RBDM ' 'R 2 20 7 E, L{ -Z7 12 Form 10-404 Revised 11/2011 Submit Original Only D -16A 209 -025 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D -16A 9/23/09 PER 9,972. 9,982. 8,886.57 8,891.03 D -16A 4/11/12 APF 10,118. 10,126. 8,951.52 8,955.06 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • • • D -16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/19/2012 ***WELL S/I UPON ARRIVAL* ** RIH W/ 5' 2 5/8" , 1 3/4" OJ, 1 7/8' SSS, 10' 3 3/8" DUMMY GUN (.125 CARBON) !DEVIATED OUT @ 9753' SLM, POOH SWAP TO ROLLER STEM. NO SAMPLE RIH W 8' 1 7/8" RS, 1 3/4" OJ, SSS, 10' 2 1/4 DUMMY PERF. GUN (MAX O.D. !2.50), SAMPLE BAILER ISD @ 9753' SLM(36' CORRECTION TO 9789' KB -BF), WORKED TOOLS, !TAGGED TD @ 10177' SLM !231' OF RATHOLE BELOW BOTTOM PERF @ 9982' RKB 'OOH, SAMPLE BAILER FULL OF FINE SAND,ICE & HYDRATES ' ** *WELL S/I UPON DEPARTURE, NOTIFY DSO OF STATUS * ** 4/10/2012 ** *WELL SHUT IN ON ARRIVAL * * *(E -LINE ADPERF) INITIAL T /I /O = 1200/950/0 PSI RIGGED UP AND BEGAN LOW PT @ 300 PSI FINAL T /I /O = 1200/950/0 PSI ** *JOB CONTINUED ON 11- APR - 2012 * ** _ _ 4/11/2012, * * *WSR continued from 4-10-12*** Assist E -line (perforating) Did not pump any ,fluid. Was not needed as a 4/11/2012 **JOB CONTINUED FROM 10 012* (E -LINE ADPERF) !INITIAL T /I /O = 1200/950/0 'RIH WITH HEAD(4X3 WP, 1.38" FISHING NECK) /ERS /ROLLER/2.125" ! WEIGHTBAR/UPCT /ROLLER/FIRING HEAD/ 10' (8' OF CHARGES) x 2.875" POWER JET OMEGA 2906 HMX GUN PERFORATED INTERVAL (a7 10118' - 10126' FINAL T /I /O = 1250/950/0 SWAB /SSV/WING = CLOSED MASTER = OPEN ** *JOB COMPLETE. WELL LEFT SHUT -IN UPON DEPARTURE. DSO '; NOTIFIED * ** FLUIDS PUMPED BBLS 2 DIESEL 4 METH 6 TOTAL • - TREE= C1W • WEL LHEAN MCEVOY 1 6A SAFElliktOTES: 4-1/2" CHROME MG& LNR* - ** ACTUATOR= BAKERC INTIAL WELLBORE SHOWN BELOW KB. ELEV = 7857 WHIPSTOCK*** BF ELEV = 42.97 1 KOP = 8416' I 2184' H4-1/2" HES X NIP, ID = 3.813" I Max Anite= 66° 9866' Datum Mb= 6934. 2661. H FOC Caturn TVD = 8800' SS GAS LIFT MANDRELS I 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2662' I ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3508 3508 1 MMG DOME RK 20 0919/09 3 5090 4997 35 MMG SO RK 22 09/19/09 2 6595 6200 39 WAG CMY RK 0 09/10/09 1 7976 7305 33 WAG CMY _ RK 0 09/10/09 Minimum ID = 3.726" @ 916W 8261' — 9-5/8" X 7" BKR HRDZXPN LTPw /TIEBACK 4-112" HES XN NIPPLE SLV, ID = 6.19" 827T - 19 - 5/8" X 7" BKR FLEXLOCK LNR HGR, ID = 6.24" I v ■ • MILLOUT WINDOW (0-18A) 8416 - 8433' 9-5/8" WHIPSTOCK H 8416. 444 9022' —14-1/2" HES X NIP, = 3.813" I 19-518" CSG, 47#, L -80, 10 = 8.681°' –I 9357 1- 9063' —i 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" I 9088' H4-1/2" HES X NIP, ID = 3.813" I 44, Nr PERFORATION SUMMARY 9159' H4-1/2" HES XN NIP, ID = 3.725" No. REF LOG: SLB-WID09/070) 9165 I — 7" X 5" HRD ZXPN LTP ANGLE AT TOP PERF: 64" (.2 9972' • w /TIEBACK SLV, Note: Refer to Ftoduction 06 for historical perf data ID = 4.180" SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9972 - 9982 0 09/23/09 9172' —14-1/2" VVLEG, ID = 3.958" 1 2-7/8" 6 10118 10126 0 04/11/12 11,, 9181' H 7" X5 BKR FLEXLOCK, LNR HGR, ID = 4.230" 9191' . 1— 5" X 4-1/2" X0, 4-117' TBG, 12.6#, 13CR-80 VAM TOP, —I 9172' ID = 3.900" .0152 bpf, ID g 3 9 5 8 " 7" LNR 26#, L-80 BTC-M, .0383 bpf, ID = 6.278" H 9344' I PBTD 10320' 4■24.7.■ It 14-1/2" LNR 12.6#, 13CR-80 VAM TOP, .0152 bpf, = 3.958" H 10408' DATE REV BY COMVENTS DATE REV BY COMMENTS PRLDHOE BAY um - 12128/81 ORIGINAL COMPLETION 04/20/12 JTC/ PJC PERFORATIONS (4/11/12) WELL: D-16A 09/12/09 N9ES SIDETRACK (0.16A) PERMT No: '2090250 09119109 PJC DRLG HO CORRECTIONS ARM): 50-029-20683-01-00 10/02/09 JED/PJC PERFS (09/07/09) SEC 23, T11N, R13E, 21a FM.. & 1692' FEL 10/02/09 DTR/RIC GLV CIO (09/19/09) 04/09/10 RCIJMO DRLG DRAFT CORRECTIONS BP BcploratIon (Alaska) 2 ,, ° q, —e WELL LOG TRANSMITTAL \ L93 c To: Alaska Oil and Gas Conservation Comm. October 13, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: D -16A Run Date: 10/8/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 D -16A Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 20683 -01 Cement Bond Log 1 Color Log 50- 029 - 20683 -01 14 "kZ MAY 1 6 Z0_12 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907- 273 -3535 klinton.wood@halliburton.com Date: Signed: iff 03/30/11 Schlemberger NO. 5715 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambetl Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job* Log Description Date BL Color CD P1.07A BJGT -00020 PRODUCTION PROFILE ter'• —C' _ 03/05/11 1 1 8L65.00020 MEMORY DOL - "M i te frtWnIIIIIIIMIIIIIIIIIIIIIIIMIDMSEEIIMEIIIIMMTAMIIIIIIIIIII r• BG4H -00035 LDL _ 0=T,1111111.111_- 09-02 BBSK -00052 RST i t - 0 j fp 111=11110 1 - -- i 0 -16A BG4H -00034 RST o. —. __ � 0 ���e 1111 . 11=1-- _ - - - - -- . ■ ■ ■ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • V " / , ' V . ; f / ''' i • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 , , , 41 b MAR' I `ZOt a©ci-oas Mr. Tom Maunder 6/1 NECEIVE-C, Alaska Oil and Gas Conservation Commission T 333 West 7 Avenue ' Ak 0 4 ;lid Anchorage, Alaska 99501 44 jcka a i & Gas Corns. Ct j"lN SS Subject: Corrosion Inhibitor Treatments of GPB D Pad 31iC11ir%gL' Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger 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) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbls ft na gal D -01A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 0-05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 0-10 1790530 50029203890000 NA 2.3 NA 8.50 3/212011 D -11B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 D -12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A _ 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 _ NA 0.1 NA 0.85 2/20/2011 D -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 0-19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 0-27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 D -33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 DATA SUBMITTAL COMPLIANCE REPORT 8/24/2010 Permit to Drill 2090250 Well Name/No. PRUDHOE BAY UNIT D-16A Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20683-01-00 MD 10410 TVD 9083 Completion Date 9/23/2009 Completion Status 1-OIL Current Status 1-OIL UIC N --- - - -- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATIDN Types Electric or Other Logs Run: mwd gr/ res /dir, mwd gr / res / neu / azi dems /dir (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH ly tYleQ/t•rmi ~9U1nUC1 ,I lame .~~.a~c n~cu~a iw awn awN ~+n nci.owc~a vvnu nv~~w ' ED C Lis 19086 n cul dd tion/Resistivity 8201 10413 Open 12/3/2009 LIS Veri, ROP, GR, RPS, RPM, RPS, RPD, DRHO, NPHI og Induction/Resistivity 25 Blu 8200 10365 Open 12/3/2009 MD Vision Service og InductionlResistivity 25 Blu 8200 10365 Open 12/3/2009 TVD Vision Service Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~ / N Daily History Received? (~/ N Chips Received? a4'7l~-' Formation Tops ~-~"N Analysis ~'7 1'~~ Received? Comments: III • DATA SUBMITTAL COMPLIANCE REPORT 8/24/2010 Permit to Drill 2090250 Well Name/No. PRUDHOE BAY UNIT D-16A Operator BP EXPLORATION (ALASYCa INC API No. 50-029-20683-01-00 MD 10410 TVD 9083 ompletion Date 9/23/2009 Completion Status 1-OIL Current Status 1-OIL ''U``IC N Compliance Reviewed By: -'~ Date: ~lTl VJ li ~~~ ~clil~bep~r Alaska Data & Consulting Services 2525 Gambell Stroet, Suite 400 Mehorag®, AK 99503-2838 ATTN: Beth Well Job # Log Description NO. 5180 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 retrotechnical Data Center LR2-1 Alaska Data & Consulting Services 900 E. BenSOn Blvd. 2525 Gambell Street, Sufte 400 Anchorage, AK 99503.2838 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,CEIVED J C~ ~ 1 4 2009 WELL COMPLETION OR RECOMPLETION REPORT AA~c#t~GasCons.Comrrns 1 a. Well Status: ®Oil ~ ^ Gas ^ SPLUG ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAa,czs.~~o ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions One 1 b. Well Class: AnC Ofage +® Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. . Dat Com Susp., or Aband.: 9/23/2009 ~ 12. Permit to Drill Number: 209-025 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded: 9/1/2009 ~ 13. API Number: 50-029-20683-01-00 ' 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached: 9/6/2009 14. Well Name and Number: PBU D-16A 2210 FNL, 1692 FEL, SEC. 23, T11 N, R13E, UM Top of Productive Horizon: 48' FNL, 1938' FEL, SEC. 26, T11 N, R13E, UM 8. KB (tt above MSL): 69,68 GL (ft above MSL): 41.47' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 575' FNL, 2039' FEL, SEC. 26, T11 N, R13E, UM 9. Plug Back Depth (MD+ND): 10320' 9041' Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 653474 y_ 5958778 Zone- ASP4 10. Total Depth (MD+ND): 10410' 9083' 16. Property Designation: ADL 028285 & 028286 TPI: x- 653294 y- 5955657 Zone- ASP4 Total Depth: x- 653204 Y- 5955127 Zone- ASP4 11. SSSV Depth (MD+ND): None 17. Land Use Permit: 18. Directional Survey: ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore: N/A ft MSL 20. Thickness of Permafrost (ND): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD GR /RES /DIR, MWD GR /RES / NEU / AZI DENS /DIR 22. Re-Drill/Lateral Top Window MD/ND: 8416' 7677' 23• CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM .SIZE CEMENTING RECORD PULLED 20" x 30" Insulat d Conductor Surface 110' S rfa 110' 36" 8 cu ds Concrete 1 - / " 72 - 0 Surfa 2 62' rf 17-1/2" 883 cu P r o I 9-5/8" 47# L-80 Surface 4 Surface 7677' 12-1/4" 1267 cu ft la s'G' 1 c PF'C' 7" 26# L-80 8261' 9344' 7545' 5 -1/2" 258 cu ft Class'G' ''~ 4-1/ " 1 L-80/ 13Cr80 9165' 1 4 834 ' 2' -1/ " 214 c ft las 'G' ~'' 24. Open to production or injection? ®Yes ^ No 25. TuewG RECORD If Yes, list each interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD / ND 3-3/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9172' 9053' / 8245' MD TVD MD TVD 9972' - 9982' 8887 - 8891' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD AMOUNT AND KIND OF MATERIAL USED 2196' Freeze Protect w/ 151 Bbls of Diesel 27. PRODUCTION TEST Date First Production: October 6, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test: 10/2/2009 Hours Tested: 6 Production For Test Period OIL-BBL: 143 GAS-MCF: 6,540 WATER-BBL: 131 CHOKE SIZE: 60 GAS-OIL RATIO: 45,931 Flow Tubing Press. 1,900 Casing Press: 1,060 Calculated 24-Hour Rate ~ OIL-BBL: 570 GAS-MCF: 26,158 WATER-BBL: 525 OIL GRAVITY-API (CORK): 41 28. CORE DATA Conventi onal Core(s) Acqui red? ^Yes ® No Sidewall Core(s) Acquired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analyticaF'rit~{~r`I-AAC 250.071. ~ . OAS ` None '~ Ids i~~c `~I Form 10-407 Revised 07/2009 CONTINUED ON REVERSE ~ ',s~ bmit Original Only Ion ~ 1 29. GEOLOGIC MARKERS (List all formations and m rs encountered): 30. rORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 9342' 8503' None Shublik 9375' 8533' Sadlerochit 9473' 8616' Top CGL /Zone 3 9810' 8816' Base CGL /Zone 2C 9992' 8895' 26N 10106' 8946' 24N 10207' 8991' 23N 10247 9008' Formation at Total Depth (Name): Zone 2 9992' 8895' 31. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. ~ l ~~ Signed: Terrie Hubble Title: Drilling Technologist Date: ~/ PBU D-16A 209-025 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Ryan Ciolkosz, 564-5977 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 07/2009 Submit Original Only BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: D-16 Common Name: D-16 - Test Date Test Type - - -_ Test Depth (TMD) Test Depth (TVD) AMW Surface Pressur L ak Off Pressure (BHP) EMW 8/31/2009 FIT 8,433.0 (ft) 7,694.0 (ft) 10.20 (ppg) 520 (psi) 4,597 (psi) 11.50 (ppg) 9/4/2009 FIT 9,340.0 (ft) 8,506.0 (ft) 8.50 (ppg) 480 (psi) 4,236 (psi) 9.59 (ppg) Printed: 9/29/2009 11:38:59 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ', From - To 8/24/2009 ~ 18:00 - 20:30 20:30 - 00:00 18/25/2009 100:00 - 06:00 D-16 D-16 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Hours ', Task Code II NPT j 2.50. MOB P 3.50 MOB N WAIT 6.00 MOB P 06:00 - 16:30 I 10.501 MOB I P 16:30 - 21:30 5.00 RIGU P 21:30 - 00:00 2.50 RIGU P 8/26/2009 00:00 - 01:00 1.00 RIGU P 01:00 - 03:00 2.00 RIGU P 03:30 - 07:30 I 4.001 EVAL I P 07:30 - 09:00 I 1.501 DHB I P 09:00 - 15:00 I 6.001 KILL I P 15:00 - 16:00 I 1.001 DHB I P 16:00 - 17:00 ~ 1.00 ~ MOB N ~ SFAL 17:00 - 21:00 I 4.001 BOPSUFi P 21:00 - 00:00 I 3.001 BOPSUFi P 8/27/2009 100:00 - 04:00 I 4.001 BOPSUR P Start: 8/17/2009 Rig Release: 9/12/2009 Rig Number: 9ES Page 1 of 13 Spud Date: 12/7/1981 End: 9/12/2009 Phase Description of Operations PRE Prepare shops and pits module for move from U-05A to D-16A. Remove pins and lower derrick. PRE Waiting on trucks from Peak to move camp, truck shop, welding shop, and pit module. PRE With Peak trucks on location, spot truck shop, welding shop and satellite camp ready for move. Unable to jack-up Substructure due to an over cycled breaker. Repaired hydraulic jack-up braker. Jacked up Substructure and move Substructure off U-05A. PRE. Move rig from U-05A to D-16A. Spot rig mats, jockey Sub into position to move onto well. PRE Move over well. Spot pits module, level, make up connections. PRE Raise derrick. Begin taking on seawater. Continue RU while taking on fluids. PRE Complete taking on seawater. Rig accept at 00:00. DECOMP Continue prepping rig for decompletion operations. Load 4" drill pipe into pipe shed, prepare wellhead for RU with Little Red Hot Oil Services (LRHOS) for pressure testing IA / OA. (LRHOS truck late to rig due to road conditions). Pre-spud meeting with Nabors crew, MI Mud Engineer, Tourpusher and WSL. DECOMP RU LRHOS to tree. Test lines to 3500 psi. Pressure test barriers. Test OA to 2000 psi for 30 minutes on chart. Test IA to 2500 psi for 30 minutes on chart. Bleed OA to 0 psi, monitor constantly in preparation for replacing 9 5/8" packoff. RD LRHOS. DECOMP RU Drill Site Maintenance (DSM) lubricator. Test lubricator to 1000 psi. Check for pressure below BPV; no pressure. Pull BPV. RD DSM. DECOMP RU to circulate out Freeze Protect at 3 bpm, 350 psi; dispose of into vacuum truck. Once diesel is circulated out, continue to circulate surface-to-surface with 140 deg seawater at 7 bpm, 480 psi. RD from tree. DECOMP Install TWC. RU, pressure test from below to 1000 psi and from above to 4000 psi. Good test. DECOMP Re-spot rig over well with plumb bob by jacking rig up and down, allowing it to move over. Previous spot off-center due to use of faulty laser sighting and settling of pad. DECOMP ND old tree, move out of cellar. Inspect threads on hanger; able to makeup crossover with 4 1/8th turns but notice galled thread approximately 2/3rds down. Continue to remove bolts from tubing spool. Function test LDS /gland nuts. OA at 0 psi at 1800 hrs. DECOMP Attempt to place BOP stack over tubing adapter. Unable to clear tubing crossover profile with BOP stack. Set stack back down on pedestal, ND spacer spool from BOP. Place spacer spool on tubing spool and NU. Place BOP stack onto spacer spool and NU BOP stack. OA at 0 psi at 2100 and 2300 hrs. DECOMP NU BOP, Koomie lines, HCR and Choke lines. Fill BOP stack with seawater; leaking from IA valve. Troubleshoot, test against TWC. Cannot test against TWC. Call Drill Site Maintenance to have on standby to possibly lubricate out TWC Printed: 9/29/2009 11:39:04 AM BP EXPLORATION Page 2 of 13 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Date '~ From - To 8/27/2009 00:00 - 04:00 04:00 - 08:00 08:00 - 13:00 13:00 - 15:30 15:30 - 18:00 18:00 - 20:00 20:00 - 22:00 22:00 - 00:00 18/28/2009 100:00 - 02:00 02:00 - 08:30 08:30 - 13:00 13:00 - 14:00 D-16 D-16 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Hours Task Code NPT Spud Date: 12/7/1981 Start: 8/17/2009 End: 9/12/2009 Rig Release: 9/12/2009 Rig Number: 9ES Phas~ Description of Operations 4.00 BOPSU P DECOMP and and replace. Monitor OA: 0 psi at 0100 and 0300 hrs. 4.00 BOPSU N SFAL DECOMP Test TWC from below to 1000 psi; good test. Attempt to test from above to 2500 psi. No go on test; pressure keeps bleeding by and allowing fluid to trickle from IA valve. Pull test joint with crossover to rig floor and inspect. Closed Blind Rams, run into TWC with rig pumps, popit closed and pressure test to 1700 psi. Reinsert test joint and crossover, stack drained through IA, TWC would not hold hydrostatic pressure. Pressure test again to 1000 psi from below; good test. Re-attempt test to 3500 psi from above with same bleed by. Pull test joint with crossover to floor. Attempt to test TWC with pumps; difficulty to get popit to seat. Popit seated and passed 3500 psi test. Reinsert test joint with crossover, TWC held hydrostatic pressure. Body test to 3500 psi; good test. 5.00 BOPSU P DECOMP RU test a ui ment to test BOP. Test BOP 3 1/2" x 6" upper variable rams with 5 1/2" and to 250 psi low and 3500 psi high. AOGCC rep ck S ,Toolpusher Roy Hunt and WSL Dick Maskel on hand to witness tests. 2.50 BOPSU P DECOMP Safety standown: Discussion focused on hazard identification and mitigation. Nabors 9ES day tour crew, Toolpusher, WSL, Nabors Safety, Dan Heber of Nabors Alaska Drilling, BP Field Superintendant, and BP Safety in attendance. Crew actively participated in discussions and gave input on better ways to approach jobs or engineer out hazards. 2.50 BOPSU P DECOMP Test annular with 4" test joint to 250 psi low and 3500 psi high. AOGCC rep Chuck Scheve and WSL Dick Maskell on hand to witness tests. RD BOP test equipment. 2.00 WHSUR P DECOMP RU DSM lubricator. Pressure test to 1000 psi. Pull TWC. RD lubricator. Applying steam to hanger in cellar. 2.00 PULL P DECOMP PJSM on spearing 5 1/2" tubing string and pulling hanger to floor. Mobilize spear assembly to pull 5 1/2" tubing hanger to floor. OA at 200 psi due to steaming of tubing hanger. Bleed off to 0 psi. 2.00 PULL P DECOMP PU joint of drill pipe. MU TIW connection to joint. MU spear to joint. RIH, spear tubing and set grapple. Back out lock down screws. PU string with no overpull; hanger released at 125k PUW. Pull hanger to floor, release spear. LD hanger and RD spear assembly. 2.00 PULL P DECOMP RU double stack power tongs and spooling reel to pull 5 1/2" tubing while circulating bottoms up at 525 gpm, 250 psi. PJSM on pulling tubing, hazards associated with task, HSE discussion on laying down tubing. 6.50 PULL P DECOMP Pull and la down 5 1/2" 17# L-80 tubing from cut at 4925'. Spool control line. 25 rubber control line clamps, 20 pins and 2 stainless steel bands recovered. Rig down spooling unit. 4.50 PULL P DECOMP Continue pulling 5 1/2" tubing string from cut at 4925'. Tubing / cut at 4925' below GLM 11 due to tubing patch in string. Total 117 joints recovered. Tubing patch recovered. RD double stack power tongs. 1.00 EVAL P DECOMP Pull wear bushing, RU BOP test equipment. Test lower variable 2 7/8" x 5" rams with 4" test joint to 250 psi low and Printed: 9/29/2009 11:39:04 AM BP EXPLORATION Operations Summary Report Page 3 of 13 Legal Well Name: D-16 Common Well Name: D-16 Spud Date: 12/7/1981 Event Name: REENTER+COMPLETE Start: 8/17/2009 End:. 9/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/12/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To ~I Hours Task Code NPT __ __ _ 8/28/2009 13:00 - 14:00 1.00 EVAL P 14:00 - 20:00 I 6.001 PULL I P 20:00 - 21:30 I 1.501 PULL I P 21:30 - 00:00 ~ 2.50 ~ FISH ~ P 8/29/2009 100:00 - 05:00 I 5.001 FISH I P 05:00 - 05:30 I 0.501 FISH I P 05:30 - 07:00 1.50 PULL P 07:00 - 09:30 2.50 PULL P 09:30 - 11:00 I 1.501 PULL I P 11:00 - 13:30 I 2.50) PULL I P 13:30 - 20:30 I 7.001 PULL I P 20:30 - 21:30 I 1.001 PULL I P 21:30 - 00:00 2.50 CLEAN P 8/30/2009 00:00 - 06:00 6.00 CLEAN P 06:00 - 07:30 1.50 CLEAN P 07:30 - 11:00 3.50 CLEAN P 11:00 - 12:30 1.50 CLEAN P 12:30 - 15:30 3.00 DHB P 15:30 - 16:30 I 1.001 DHB I P 16:30 - 18:30 I 2.001 DHB I P Phase Description of Operations DECOMP 3500 psi high. State AOGCC representative Chuck Scheve waived witness due to his witnessing full BOP test on 8/27/0 and dispensation for testing lower rams after pulling tubing hanger and initial string of tubing. DECOMP Reinstall wear bushing. RU SLB wireline unit to RIH with jet cutter. RIH with j,et cutter. tag stub at 4925'. Continue to RIH with cutter; tagged up and could not move past at 8551'. W Correlate depths, move cutter to 8536' and cut tubing 3' below collar. POH. RD wireline unit. DECOMP Safety Standdown with crew, Nabors Safety, Tourpusher, BP Field Superintendant and WSL. Discussion on recent injuries, hazard identification and mitigation, how to improve pre-job meetings. Focus of leadership was to get crew to come up with their own ideas on process improvements and working safely. DECOMP Mobilize BHA to rig floor, pipe shed. PJSM on MU and RIH with fishing spear. MU spear assembly. DECOMP RIH with 5 1/2" spear assembly on 4" DP to tubing stub at 4925'. PUW 130k, SOW 120k. DECOMP Tag up with 5 1/2" tubing stub at 4925'. Latch fish with spear. PU 180k to confirm spear. DECOMP Circulate bottoms up at 490 gpm, 1545 psi. DECOMP POH with 5 1/2" tubing on spear assembly BHA on 4" DP from cut at 8536'. Stand back DP. DECOMP Safety Standdown with crew, Nabors Safety, Tourpusher, and WSL. Discussion on recent injuries, hazard identification and mitigation, how to improve pre-job. meetings. Focus of leadership was to get crew to come up with their own ideas on process improvements and working safely. DECOMP POH with last stand of 4" DP and drill collars. LD bumper sub, jars and spear assembly. 3" of collar was left on joint 118 from previous mechanical cut. DECOMP RU double stack power tongs. Continue to POH with 5 1/2" 17# L-80 tubing, laying down. RD double stack power tongs. Total of 198 joints and 12 GLMs recovered. Tubing cut from jet cut 3.27'. DECOMP PJSM on MU, RIH with Gauge run BHA. Mobilize BHA components to drill floor and pipe shed. BHA: 8 1/2" tri-cone bit, full gauge watermelon mill, bumper sub, jar, 9-6 1/4" drill collars, 18 HWDP DECOMP MU Gauge run BHA and RIH on 4" DP out of pipe shed one-by-one. DECOMP RIH with 8 1/2" Gauge run BHA on 4" DP out of pipe shed one-by-one and tag 5 1/2" tubing stub at 8530'. PU to 8460'. PUW 185k. DECOMP Circulate at 570 gpm, 2030 psi. DECOMP POH with Gauge run BHA. DECOMP Stand back HWDP. LD Gauge run BHA. DECOMP RU SLB wireline to run EZSV. RIH with CCL / GR logging tool and HES EZSV. DECOMP Calibrate collar locations against CCL log. Collar at 8448'. Set EZSV at 8438'. DECOMP POH with EZSV running tool and CCL / GR logging tool. Begin ~ S3~ Printed: 9/29/2009 11:39:04 AM ~ ~ BP EXPLORATION Operations Summary Report Page 4 of 13 Legal Well Name: D-16 Common Well Name: D-16 Spud Date: 12/7/1981 Event Name: REENTER+COMPLETE Start: 8/17/2009 End: 9/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/12/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT Phase Descriptio of Operations 8/30/2009 16:30 - 18:30 2.00 DHB P DECOMP applying steam to casing ad. 18:30 - 20:00 1.50 DHB P DECOMP RU test equipment. T 9 5/8" casing and EZSV to 3500 psi for 30 minutes on art. Good test. RD test equipment. 20:00 - 22:30 2.50 WHSUR P DECOMP RU to pull 9 5/ 'casing head packoff. Check OA - 0 psi. Back out LDS an heck for any casing growth -okay. Pull packoff with 40 verpull. Replace with new packoff and run in LDS. Pre re test packoff to 5000 psi for 30 min. RD tools. 22:30 - 00:00 I 1.501 WHIP I P I I WEXIT 8/31 /2009 00:00 - 02:00 2.00 WHIP P ,/ W EXIT 02:00 - 02:30 0.50 WH P WEXIT 02:30 - 04:30 0 WHIP N RREP WEXIT 04:30 - 05:30 1.00 WHIP P WEXIT 05:30 - :30 5.00 WHIP P WEXIT 10:30-12:30 2.OOWHIP P (WEXIT 12:30 - 18:00 5.501 STWHIP( P WEXIT 18:00-22:00 4.OOSTWHIPP (WEXIT 22:00 - 22:30 I 0.50 I EVAL I P I I W EXIT 22:30 - 23:00 0.50 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP P WEXIT 9/1/2009 00:00 - 02:30 2.50 STWHIP P WEXIT 02:30 - 04:00 I 1.501 STWHIP( P I I WEXIT 04:00 - 06:30 I 2.501 DRILL I P I I INT1 P Mon MU of whipstock assembly. Mobilize BHA components to rig floor and pipe shed. MU 9 5/8" Gen 2 whipstock BHA: Anchor, whipstock with 45k shear bolt, 8 7/16" window mill, lower 8 3/8" watermelon mill, flex joint, upper 8 1/2" watermelon mill, float sub, MWD tool, UBHO sub, 9-6 1/4" DCs, 18-4" HWDP MU 9 5/8" Gen 2 whipstock BHA: Anchor, whipstock with 45k shear bolt, 8 7/16" window mill, lower 8 3/8" watermelon mill, flex joint, upper 8 1/2" watermelon mill, float sub, MWD tool, UBHO sub, 9-6 1/4" DCs, 18-4" HWDP RIH with whipstock assembly on 4" DP to 1415'. Attempt shallow hole test of MWD. 4" DEMCO valve on Pump #2 leaking. Inspect 4" DEMCO valve on pump #2; washed out. Continue to RIH with whipstock assembly on 4" DP while waiting on valve to arrive (runner going to pick up new valve while crew continues to trip into hole). Replace valve while RIH with whipstock assembly. Conduct shallow hole test for MW D at 3900' at 550 gpm, 1660 psi. Orient whipstock to 73 deg left of high side, tag EZSV at 8438'. PUW 193k, SOW 173k. Set down, shear anchor with 18k down weight. PU 10k over PUW to verify anchor set. Set down, shear whipstock bolt at 47k over SOW. Pump Hi-Vis sweep. Displace 8.5 ppg seawater to 10.2 ppg LSND. Obtain and record slow pump rates. Mill window. Exited window at 1730 hrs. Top of window at 8416', bottom of window at 8433'. Drill ahead into new formation from 8433' to 8457'. Continue to work mills through window with ROT Wt varying from 161 k to 178k; no increase in torque noted. Pump 50 bbl Hi-Vis "super sweep". Total of 310 pounds metal recovered from shakers and magnets. Pull into window and flow check. PUW 190k, SOW 165k, ROT Wt 175k, torque 5.5-8k, Weight on Mill 15-20k. Conduct FIT to 11.5 ppg EMW. Current properties: 10.2 ppg MW, TVD 7694', MD 8433', test pressure 520 psi. Chart test for 10 minutes. Monitor well-static. Blow down equipment, install air slips. POH with whipstock running BHA from 8430' to 7794'. POH with whipstock running BHA on 4" DP from 7794' to BHA at 935' Rack back HWDP. LD BHA. Upper 8 1/2" watermelon mill in gauge. Blow down choke and HCR lines into stack. Flush stack to clear any metal shavings. Clear and clean rig floor to prep for drilling. Mobilize BHA equipment to pipe shed and rig floor. Printed: 9/29/2009 11:39:04 AM ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: D-16 Common Well Name: D-16 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 9ES ' Date From - To Hours Task Code NPT 9/1/2009 06:30 - 08:30 2.00 DRILL P 08:30 - 13:00 4.50 DRILL P 13:00 - 15:00 2.00 DRILL P 15:00 - 16:30 I 1.501 DRILL I P 16:30 - 00:00 I 7.501 DRILL I P 9/2/2009 100:00 - 04:00 I 4.001 DRILL I P 04:00 - 07:00 I 3.001 DRILL I P 07:00 - 08:30 ~ 1.50 ~ DRILL ~ P Start: 8/17/2009 Rig Release: 9/12/2009 Rig Number: 9ES Phase INT1 INT1 INT1 INT1 INT1 INTi INTi INT1 08:30 - 09:00 0.50 DRILL P INT1 09:00 - 11:30 2.50 DRILL N SFAL INT1 11:30 - 12:00 I 0.501 DRILL I P I I INT1 12:00 - 16:00 I 4.001 DRILL I P I I INTi 16:00 - 19:00 3.00 DRILL P INT1 19:00 - 20:30 1.50 DRILL P LNR1 20:30 - 00:00 I 3.501 EVAL I P I I LNR1 Page 5 of 13 ~ Spud Date: 12/7/1981 End: 9/12/2009 Description. of Operations PJSM on MU drilling BHA. MU 8 1/2" drilling BHA: 8 1/2" Hycalog PDC bit, 1.83 deg motor, ARC6, Powerpulse MWD, NM stabilizer, 3- NM Flex collars, float, 1-5" HWDP, jars, 18-jts 4" HWDP. Shallow hole test at 300', 500 gpm, 770 psi. RIH on 4" DP to 8172'. Cut and slip 104' of drilling line, service topdrive and crown, inspect drawworks. RIH with drilling BHA on 4" DP to 8235' for Geologists tie-in. Continue to RIH to 8456'. No problems exiting window. Drill ahead in 8 1/2" hole from 8456' to 8890'. -PUW 190k, SOW 150k, ROT Wt 170k, 530 gpm, 2400 psi, 60 rpm, torque on 7k fUlbs, torque off 5k fUlbs -Shales coming across shakers. Pump Hi-Vis sweep. Sweep. brought back approximately 20% increase in returns across shakers. -ART 2.02 hrs, AST 2.10 hrs, ADT 4.12 hrs -Slow pump rates taken and recorded -MW in and out 10.2 ppg as of midnight; begin to add Barite to system very slowly to increase MW to 10.3 ppg. Drill ahead in 8 1/2" hole from 8890' to 9345'. -PUW 200k, SOW 160k, ROT Wt 170k, 530 gpm, 2710 psi on, 2640 psi off, 80 rpm, torque on 6-7k fUlbs, torque off 5k fUlbs, WOB 10-12k -AST 1.07 hrs, ART 3.38 hrs, ADT 4.45 hrs -MW in and out 10.3 ppg as of 0100. Continuing to monitor 1 1/2-2" shale splinters across shakers. Drilling parameters holding steady and no packoffs noted. Begin to add Barite slowly at 0200 hrs to bring MW up to 10.4 ppg over 2 hour period. -MW in and out 10.4 ppg at 0400 hrs. Drilling break at 9345'. Circulate bottoms up for geological samples at 530 gpm, 2580 psi. Shale splinters continuing to come across shakers. Samples showed good casing point at 9345'. Monitor well -static. Wiper trip to window with no significant overpulls. PUW 200k, SOW 165k. RIH to bottom with no problems. No fill noted on bottom. Circulate bottoms up at 530 gpm, 2630 psi. During circulation, leak developed in air boot on riser. Approximately 44 gallons drilling mud leaked out. 9 gallons leaked into uncontained cellar and the rest onto herculite in the cellar. SRT was contacted. Cleanup initiated, cellar cleaned with cellar pump and guzzler. IR 2009-IR-3212841 has been created. Resume circulation at 530 gpm, 2700 psi. Mud properties look good, shale cuttings no concern. POH to window at 8363'. Monitor well -static. Continue to POH to BHA. Stand back HWDP, LD rest of 8 1/2" drilling BHA. Clear and clean rig floor. Begin mobilizing liner running equipment to rig floor. Change out 7" rams. Test BOP with 7" test joint to 250 psi low Panted: 9/29/2009 11:39:04 AM BP EXPLORATION Operations Summary Report Legal Well Name: D-16 Common Well Name: D-16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date I From - To Hours Task Code' NPT Start: 8/17/2009 Rig Release: 9/12/2009 Rig Number: 9ES Page 6 of 13 Spud Date: 12/7/1981 End: 9/12/2009 Phase ~ Description of Operations 9/3/2009 00:00 - 00:30 0.50 EVAL P LNR1 00:30 - 02:00 1.50 CASE P LNR1 RD test equipment. RU casing equipment to run 7" drilling liner. PJSM on running 02:00 - 05:30 3.50 CASE P LNR1 MU 7" 26# L-80 BTC-M drilling liner to optimum torque of 5500 ft/Ibs. Shoe track Baker-locked; test floats-held. Total 26 joints. One centralizer locked down on joint #1 and joint #2. MU liner hanger and liner top packer assembly. PU one stand 4" DP and circulate 1.5 times liner volume at 220 gpm, 130 psi. PUW 75k, SOW 65k. 05:30 - 10:30 5.00 CASE P LNR1 RIH with 7" drilling liner on 4" DP to window at 8334', filling every 10 stands. PUW 185k, SOW 150k. 10:30 - 12:00 1.50 CASE P LNR1 Establish circulation slowly. Stage pumps up from 2 to 6 bpm. ICP 365 psi, FCP 660 psi. Circulate surface-to-surface volume. 12:00 - 13:00 1.00 CEMT P LNRi Continue RIH with 7" 26# L-80 BTC-M liner on 4" DP from 8416' to 9321'. Wash down last 23' to 9345' at 1 bpm, 450 psi. 13:00 - 14:30 1.50 CEMT P LNR1 Circulate and condition, staging pumps up to FCP of 6 bpm, 250 gpm, 980 psi. 14:30 - 15:30 1.00 CEMT P LNR1 Cement casin er SLB cement plan - Pump 10 bbls of MudPUSH II @ 13.0 ppg @ 2 bpm - Pressure test cement lines to 4500 psi with MudPUSH II -Pump 20 bbls of MudPUSH II @ 13.0 ppg @ 6 bpm, 700 psi - Pumo 48.5 bbls, 234 sacks at 1.16 cuft/sx of 15.8 pPQ Class G tail cement at 5 b m -Drop Wiper Dart; positive indication dart left head. Chase dart with 5 bbls water from cementers. - Switch to rig pumps - Displace cement with 114 bbls of 10.4 ppg LSND mud at 5 bpm and 2 bpm for last 10 bbls per pumping schedule - Bump the plug at 119 bbls (1930 strokes), 1329 psi. Continue to pressure up and set liner hanger at 3000 psi. Bleed off pressure and check floats -floats holding. - Full returns throughout the job - Cement in place at 1553 hrs - 7" casing shoe set @ 9344' NOTE: Tail cement 1000 psi compressive strength 9:14 hrs 15:30 - 17:00 1.50 CEMT P LNR1 Set ZXP packer as per Baker Rep. PU, set back down to confirm set. Liner top packer set at 8260'. PU and circulate at 420 gpm, 1880 psi to clear above packer. PU and reciprocate while pumping bottoms up. 100 bbls of Mudpush II, cement and contaminated mud back to surface. 17:00 - 17:45 0.75 CEMT P LNR1 RD equipment from cement job. 17:45 - 18:00 0.25 CEMT P LNR1 After Action Review (AAR) of cement job with crew that was involved. Discussion ranged from how pre-job meeting got everyone on same page to how the rigging up went to monitoring the third-party service hands to the pumping of the displacement. In the crews opinion, job went well overall due to "everyone being on same page". A lesson learned is that welded fittings are not allowed on cement jobs per SLB standards (a 90 deg elbow being used was changed out due to weld). 18:00 - 18:30 0.50 CEMT P LNR1 Clear and clean rig floor from cement job. 18:30 - 23:30 5.00 CEMT P LNR1 Stand back one stand, pump dry job. POH with liner running Printed: 9/29/2009 11:39:04 AM BP EXPLORATION Page 7 of 13 Operations Summary Report Legal Well Name: D-16 Common Well Name: D-16 Spud Date: 12/7/1981 Event Name: REENTER+COMPLETE Start: 8/17/2009 End: 9/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/12/2009 Rig Name: NABOBS 9ES Rig Number: 9ES .Date From - To Hours ~ Task Code NPT Phase Description of Operations 9/3/2009 18:30 - 23:30 5.00 CEMT P LNR1 tool on 4" DP. Inspect liner running tool, confirm dog sub pins sheared. 23:30 - 00:00 0.50 BOPSU P PROD1 Prep cellar to change out top 7" rams back to the variable 3 1/2"x6". 9/4/2009 00:00 - 00:30 0.50 BOPSU P PROD1 Prep to change out 7" rams to 3 1/2" x 6" variable rams. Flush stack, blow down top drive. 00:30 - 00:45 0.25 BOPSU P PROD1 PJSM on changing out rams, RU for testing rams. 00:45 - 03:00 2.25 BOPSU P PROD1 Change out 7" rams to 3 1/2" x 6" variable rams. 03:00 - 04:30 1.50 BOPSU P PROD1 RU test a ui ment. Test u er 3 1/2" x 6" rams with 4" and 4 1/2" test joints to 250 psi low and 3500 psi high. Test lower 2 7/8" x 5" rams with 4 1 2 test joint to psi ow an psi 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 08:00 3.00 DRILL P PROD1 08:00 - 13:00 5.00 DRILL P PROD1 13:00 - 15:00 2.00 DRILL P PROD1 15:00 - 16:00 1.00 DRILL P PROD1 16:00 - 16:30 0.50 EVAL P PROD1 16:30 - 17:30 1.00 DRILL P PROD1 17:30 - 19:30 2.00 DRILL P PROD1 19:30 - 20:00 0.50 DRILL P PROD1 20:00 - 20:30 0.50 DRILL P PROD1 20:30 - 21:00 0.50 EVAL P PROD1 21:00 - 22:30 1.50 DRILL P PROD1 high. RD test equipment. PJSM on MU, RIH with 6 1/8" drilling BHA. Mobilize BHA to pipe shed and to drill floor. MU 6 1/8" drilling BHA: 6 1/8" PDC bit, 1.83 deg bend mud motor, NM stabilizer, NM flex collar, Implulse MWD, ADN4, 3 NM flex collars, PBL circulation sub, 1 jt 4" HWDP, jars, 18 jts 4" HWDP. Clear rig floor when loading nuclear source. Test MWD tools. RIH with driling BHA on 4" DP singles picked up out of shed. Continue to RIH with stands of 4" DP racked back in derrick to 8742'. PUW 190k, SOW 145k. Crew conducted stripping in drill following discussion on Shublik Phenomenom of fractured formations and allowing hydrocarbons to enter wellbore. Each crew member spent time on Super Choke adjusting and holding casing pressure. Also discussed recent dropped object (dropped pipe tote while trying to winch) and not being able to use any welded connections during cementing operations. Continue to RIH from 8742' and tag up with cement stringers at 9246'. PUW 205k, SOW 145k. Ru equipment for pressure test. Conduct 7" casing pressure test to 3500 psi for 30 minutes on chart. Good test. RD equipment. Drill cement out of shoe track to 9310' at 230 gpm, 1260 psi, 35 rpm, 6.6k ft/Ibs torque Displace 10.4 ppg LSND to 8.5 PPG FloPro at 235 gpm, 1550 psi. Continue to drill out shoe track and into formation. Drill 20' of new formation to 9365'. POH into shoe at 9340'. Monitor well -static. MW in and out 8.5 PPg• Conduct FIT. Parameters: MW 8.5 ppq, EMW 10.5 pp , TVD 8506,. t_st to 885 osi. Broke over at 553 psi, bled to 480 psi over 5 minutes, held steady and stopped bleeding at 460 psi over 12 minutes. Recorded on chart for 13 minutes. Calculated EMW of 9.6 ppg. Drill ahead in 6 1/8" hole from 9365' to 9.90'. -235 gpm, 1330 psi on, 40 rpm, 3-4k ft/Ibs torque on, PUW 205k, SOW 145k, 175k ROT Wt -AST .57 hrs, ART .47 hrs, ADT 1.04 hrs -MW in and out 8.5 ppg -Slow pump rates taken and recorded (~ Pri ntetl: 9/z9/zVOS 11:Jy:U4 AM • i BP EXPLORATION Operations Summary Report Page 8 of 13 Legal Well Name: D-16 Common Well Name: D-16 Spud Date: 12/7/1981 Event Name: REENTER+COMPLETE Start: 8/17/2009 End: 9/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/12/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To 'Hours Task 'Code NPT Phase Description of Operations 9/4/2009 22:30 - 00:00 1.50 DRILL ( P PROD1 New mud blinding off on shakers due to being cold, not sheared. Circulate at 60 gpm, 380 psi while reciprocating to try and shear mud through bit. Shaker screens blinding off with very fine sand sticking to mud polymers. 9/5/2009 00:00 - 02:30 2.50 DRILL P PROD1 Screen down shaker screens to help with solids control. Immediate results. Increase pump rates to 240 gpm, 1155 psi to shear mud. Reciprocating pipe during circulation. 02:30 - 12:00 9.50 DRILL P PROD1 Drill ahead in 6 1/8" hole from 9390' to 9 697' -240 gpm, 1300 psi off, 1438 psi on, 10k WOB, 3-5k ft/Ibs torque off, 5.7k ft/Ibs torque on, PUW 195k, SOW 165k, 183k ROT Wt -AST 4.74 hrs, ART 4.74 hrs, ADT 9.48 hrs -MW in and out 8.5 ppg -Slow pump rates taken and recorded 12:00 - 22:30 10.50 DRILL P PROD1 Drill ahead in 6 1/8" hole from 9697' to 10208' -240 gpm, 1350 psi off, 1471 psi on, 40 rpm, 4.3k ft/Ibs torque off, 6k Wlbs torque on, PUW 205k, SOW 165k, 180k ROT Wt -AST 1.00 hrs, ART 6.38 hrs, ADT 7.38 hrs -MW in and out 8.5 ppg -Slow pump rates taken and recorded NOTE: Hydraulic leak from Super Sucker was reported at 1845 hrs. Leak came from hydraulic line controlling the boom and was noticed during changeout inspection. Approximately 2 cups leaked onto the ground. SRT, BP Field Superintendant, Pad Operator were notified. SRT directed cleanup with. absorb, shovel contanimated soil into oily waste bag for pick up. Leak was not considered reportable since it was less than 1 gallon and able to be cleaned up. 22:30 - 00:00 1.50 DRILL P PROD1 Unable to drill ahead while sliding or rotating. ROP dropped to 0 unless rotating. Stick slip and torque increasing. Pump weighted, low-vis sweep at 235 gpm, 1335 psi while rotating at ', 80 rpm and reciprocating. 9/6/2009 00:00 - 01:00 1.00 DRILL P PROD1 Complete circulating weighted, low-vis sweep around. No ', significant increase in cuttings. 01:00 - 01:15 0.25 DRILL P PROD1 Tag bottom and attempt to drill ahead. Unable to drill. 01:15 - 02:15 1.00 DRILL P PROD1 POH to shoe. No problems with hole. PUW 203k SOW 170k. Monitor well at shoe -static. MW in and out 8.5 ppg 02:15 - 07:00 4.75 DRILL P PROD1 OH to BHA. 07:00 - 10:00 3.00 DRILL P PROD1 Stand back HWDP, jars, collars. LD BHA to download MWD information. Inspect, change out bit. Bit grade: 8-8-RO-A-X-1-LC-BHA. 10:00 - 11:30 1.50 DRILL P PROD1 MU 6 1/8" tri-cone bit and same BHA. Shallow hole test MWD at 222 gpm, 726 psi. 11:30 - 15:00 3.50 DRILL P PROD1 RIH with 6 1/8" drilling BHA on 4" DP. Break circulation at shoe. 15:00 - 16:00 1.00 DRILL P PROD1 Service top drive, drawworks, crown, install blower hose and fill pipe 16:00 - 16:30 0.50 DRILL P PROD1 Safety standdown to discuss Nabors 10 Tenets of Operations Excellence 16:30 - 17:30 1.00 DRILL P PROD1 Continue RIH to 10180'. Break circulation and wash down to 10208'. 17:30 - 20:30 3.00 DRILL P PROD1 Drill ahead in 6 1/8" hole from 10208' to 10,410'. Printed: 9/29/2009 11:39:04 AM BP EXPLORATION Operations Summary Report Legal Well Name: D-16 Common Well Name: D-16 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To i~ Hours I Task Code NPT 9/6/2009 17:30 - 20:30 3.00 DRILL P Start: 8/17/2009 Rig Release: 9/12/2009 Rig Number: 9ES Phase ' PROD1 20:30 - 00:00 I 3.501 DRILL I P I I PROD1 9/7/2009 00:00 - 05:30 5.501 EVAL P PROD1 05:30 - 08:00 2.501 DRILL ~ P ~ ~ PROD1 08:00 - 11:30 I 3.501 DRILL I P I I PROD1 11:30 - 15:00 I 3.501 DRILL I P I I PROD1 15:00 - 19:30 I 4.501 DRILL I P I I PROD1 19:30 - 22:00 I 2.501 CASE I P I I RUNPRD 22:00 - 22:30 I 0.501 CASE I P I I RUNPRD 22:30 - 00:00 I 1.501 CASE I P I I RUNPRD 9/8/2009 100:00 - 03:30 I 3.501 CASE 1 P ( I RUNPRD 03:30 - 04:00 I 0.501 CASE I P I I RUNPRD Page 9 of 13 ~ Spud Date: 12/7/1981 End: 9/12/2009 Description of Operations -PUW 210k, SOW 165k, ROT Wt 175k, 240 gpm, 1450 psi off, 1580 psi on, 40 rpm, WOB 10k, 4.3k fUlbs torque off, 5.4k fUlbs torque on -AST .20 hrs, ART 1.82 hrs, ADT 2.02 hrs -MW in and out 8.4 ppg J~ -Slow pump rates taken and recorded Circulate botoms up for samples. Good samples, Geologists call TD at 10.410'. Continue to circulate at 240 gpm, 1381 psi, 90 rpm, 4.6k fUlbs torque and reciprocate until shakers clean up. MAD Pass from 10410' to 9,505' at 350 ft/hr, 80-100 rpm, 250 gpm. POH into shoe at 9320'. Monitor well -slight loss. Open PBL circ sub. Circulate bottoms up 1.5x at 580 gpm, 1649 psi with reciprocation. MW in and out 8.5 ppg. Continue to POH to BHA. NOTE: WSL was contacted by Peak Safety Advisor regarding hydraulic leak from sow truck at Price Pad during Wrangell Camp move from Price Pad to Mobile Pad. At approximately 1020 hrs, a hydraulic leak from on o-ring failure on the PTO lever inside the truck cab was discovered. A small amount dripped to the ground below the truck. SRTwas notified. The crew was directed to gather the soiled gravel into a bag. They did and dropped the bag at the SRT office. The oily waste gathered from the cab was taken to Peak base camp for disposal. The unit has been repaired and back into service. No spill report will be generated since volume was less than one gallon. Cut and slip drilling line. Service top drive, service crown, service drawworks, adjust brakes, replace glycol hose in drawworks. Conduct After Action Review (AAR) on cut and slip drilling line with crew, Nabors Safety Paul Holly and WSL. LD BHA. Handle nuclear source. Complete laying down BHA. Bit grade: 1-0-WT-A-E-I-NO-TD Clear and clean rig floor. Mobilize liner running equipment to floor. RU to run 4 1/2" 12.6# 13Cr Vam Top liner. PJSM on running 4 1/2" liner with crew, Baker rep, Nabors casing rep, Toolpusher, Nabors Safety Observer, and WSL. Discussed handling of pipe in shed, skate operations, PU of pipe off of skate, handling tongs and fluids. MU shoe track, test float-held. Baker lock shoe track. One centralizer on jts 1-3, two centralizers with stop ring on jts 4-24 and 27-29. RIH with two jts 4 1/2" 12.6# 13Cr Vam Top liner. Have huddle to discuss operation, continue on with operation. RIH with 4 1/2" 12.6# 13Cr Vam Toa production liner. Have huddle after five joints to discuss operation, continue on with operation. Fill every joint, top off every 10 jts. Centralizers on jts 1-24, 27-29. Optimum make-up torque 4440 fUlbs. Total 29 jts, 51 centralizers run (stop rings in middle of jts 4-24 and 27-29). MU liner hanger, liner top packer, and running tool to liner. RD liner running equipment while waiting on protection gel to set in Printed: 9/29/2009 11:39:04 AM • BP EXPLORATION Page 10 of 13 Operations Summary Report Legal Well Name: D-16 Common Well Name: D-16 Spud Date: 12/7/1981 Event Name: REENTER+COMPLETE Start: 8/17/2009 End: 9/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/12/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date I From - To Hours i Task Code NPT 9/8/2009 103:30 - 04:00 0.501 CASE P 04:00 - 09:30 ~ 5.50 ~ CASE ~ P 09:30 - 11:00 ~ 1.50 ~ CASE ~ P 11:00 - 12:00 I 1.001 CASE I P 12:00 - 13:00 I 1.001 CASE I P Phase Description of Operations RUNPRD liner top packer. MU one stand 4" DP, circulate 2x liner volume at 250 gpm, 90 psi. PUW 83K, SOW 68k. RUNPRD Continue to RIH with 4 1/2" production liner on 4" DP from 1254' MD to 9282' MD (inside 7" liner shoe) filling pipe every 10 stands. PUW 180k, SOW 152k. MW in /out 8.5 ppg. RUNPRD Break circulation slowly to circulate one annular volume (505 bbls) at 250 gpm with 549 psi by stagging pumps as follows: 85 gpm with 268 psi 132 gpm with 317 psi 166 gpm with 365 psi 210 gpm with 422 psi 250 gpm with 549 psi RUNPRD Make up cement head with 4" DP single, set on pipe skate and secure. RUNPRD RIH with 4 1/2" production liner on 4" DP from 9282' MD to 10410' MD. PUW 190k, SOW 163k. MW in /out 8.5 ppg. NOTE: Total of 41 bbls of 8.5 ppg FloPro SF lost throughout 4 1/2" production liner run. 13:00 - 14:30 1.50 CEMT P RUNPRD Lay down 4" DP single, pick up 15' pup and make up to cement head. Pick up cement head. 14:30 - 16:00 1.50 CEMT P RUNPRD Pick up 2' off bottom and stage pump rates up to 6 bpm as follows: 2 bpm with 359 psi 3 bpm with 464 psi 4 bpm with 530 psi 5 bpm with 630 psi 6 bpm with 820 psi 16:00 - 17:30 1.50 CEMT P RUNPRD PJSM with SLB cementers and rig personnel. Cement 4.5", 12.6# 13Cr-80 VamTogArod ~ tion lin .r as fnllnws~ _. 15:40 Start batching Mud Push 16:00 Start batching 15.8 ppg Tail Cement 16:24 Pump 5.0 bbl of 12.0 ppg Mud Push. 16:30 Test lines to 4500 psi -good. 16:42 Pump remaining 17.8 bbl of 12.0 ppg Mud Push 16:46 Pump 38.1 bbl of 15.8 ppg, Class G with Gasblok Tail Cement at 5 bpm with Initial Circulating Pressure of 141 psi and Final Circulating Pressure of 68 psi. Swap over to rig pumps. Drop dart; kick out with 30 bbl pert pill; tattletale indicated that dart dropped. 17:04 Start displacement; 20 bbl away at 6.6 bpm with 6 psi 17:10 40 bbl displaced at 6.6 bpm with 6 psi 17:13 60 bbl displaced at 6.6 bpm with 6 psi 17:15 70 bbl displaced at 5.7 bpm with 428 psi 17:17 80 bbl displaced at 5.3 bpm with 772 psi Slow pumps from -5.3 bpm to 3.8 bpm in anticipation for dart latch to wiper plug. 17:18 Plug latched in liner top; pressure spiked to 883 psi. Pnntetl: 9/L9/LUUy 11:Sy:U4 AM BP EXPLORATION Page 11 of 13 Operations Summary Report Legal Well Name: D-16 Common Well Name: D-16 Spud Date: 12/7/1981 Event Name: REENTER+COMPLETE Start: 8/17/2009 End: 9/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/12/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date I From - To I Hours ~ Task I Code I NPT 9/8/2009 116:00 - 17:30 I 1.501 CEMT I P Phase Description of Operations RUNPRD 17:20 90 bbl displaced at 3.5 bpm with 886 psi 17:22 100 bbl displaced at 5 bpm with 1242 psi Plug bumped at 17:23 104 bbl displaced, 5 bpm with 3027 psi. Reciprocate pipe while pumping and displacing cement. Reciprocate only pipe stretch when cement exits shoe ensuring to have shoe 2' off bottom at 10,408' MD. Full returns throughout entire job. CIP at 17:25 hrs. Cement job volume: 38.1 bbls 15.8 ppg Class G with Gasblok cement pumped; 25 sacks at 1.17 cufUsack. Compressive Strength: 500 psi 9.18 hrs 1000 psi 9.9 hrs 17:30 - 19:00 I 1.501 CEMT I P 19:00 - 21:30 2.50 CEMT P 21:30 - 22:30 1.00 CEMT P 22:30 - 00:00 1.50 CEMT P 9/9/2009 00:00 - 05:30 5.50 CEMT P 05:30 - 06:30 1.00 CEMT P 06:30 - 08:00 1.50 CEMT P 08:00 - 09:00 1.00 CEMT P 09:00 - 11:00 2.00 CEMT P 11:00 - 12:00 1.00 CEMT P 12:00 - 12:30 0.50 BUNCO P 12:30 - 13:30 1.00 BUNCO P At plug bump, held pressure at 3020 psi to ensure liner hanger set, then continue to pressure up to 4200 psi to release hanger setting tool. Bleed off pressure and check floats; good. PU to verify tool release; good. Continue to pick up to 'dogs out' and slack off to set ZXPN liner top packer. PU again and repeat slack off with rotation to ensure packer set. RUNPRD PU out of liner top and circulate at 12 bpm with 1230 psi while reciprocating pipe at 45' strokes for a total of one bottoms up pumped. All Mud Push returned to surface together with -10 bbls of cement-contaminated mud. Clean pits in preparation for seawater displacement. RUNPRD Circulate wellbore over to clean 8.5 ppg seawater at 6.5 bpm with 580 psi. RUNPRD Continue to clean pits, under shakers and ditch in preparation for seawater displacement. RUNPRD Pump dry job, lay down cement head and 1 joint of 4" DP. RUNPRD POH laying down 4" DP from 9165' MD to 1790' MD. MW in /out 8.5 ppg. RUNPRD Safety Stand Down. HSE Review with Well Site Leader Blair Neufeld and Tool Pusher Kelly Cozby. RUNPRD POH laying down 4" DP from 1790' MD to 660' MD. MW in /out 8.5 ppg. RUNPRD Pick up remaining 4" DP from derrick and RIH from 660' MD to 1530' MD. MW in /out 8.5 ppg. RUNPRD POH laying down 4" DP from 1530' MD to Baker liner running tools at 43' MD. MW in /out 8.5 ppg. RUNPRD Service break Baker Liner Running Tool and lay down. No cement found on drill pipe or liner running tool. RUNCMP Pull wear bushing, clean and clear floor. RUNCMP Close Dine rams and pressure test 4 1/2" ro action liner to ,, 3500 psi for 30 charted minutes. Lost 20 psi during first 15 minutes an 0 psi uring second 15 minutes -good test. Pressure test witnessed by Well Site Leader Blair Neufeld and Printed: 9/29/2009 11:39:04 AM BP EXPLORATION Page 12 of 13 Operations Summary Report Legal Well Name: D-16 Common Well Name: D-16 Spud Date: 12/7/1981 Event Name: REENTER+COMPLETE Start: 8/17/2009 End: 9/12/2009 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 9/12/2009 Rig Name: NABOBS 9ES Rig Number: 9ES Date From - To Hours Task Code NPT i Phase Description of Operations 9/9/2009 12:30 - 13:30 13:30 - 16:30 16:30 - 00:00 1.00 3.00 7.50 BUNCO BUNCO BUNCO P P P RUNCMP RUNCMP RUNCMP Tool Pusher Kelly Cozby. RU to run 4 1/2" 12.6# 13Cr -80 Vam Top Tubing; change out bails, RU compensator and stabbing board. Make dummy run with 4 1/2" Cameron Tubing Hanger. MU and run 4 1/2" 12.6# 13Cr-80 Vam Top tubing from surface to 3601' MD. Baker-Lok all connections below Baker S-3 Packer. Torque turn each joint to 4440 ft-Ibs utilizing torque-turn equipment and double-stack tongs. 9/10/2009 00:00 - 14:00 14.00 BUNCO RUNCMP Continue to run 4 1/2" 12.6# 13Cr-80 Vam Top tubing from 3601' MD to depth inside PBR (bottom at 9176' MD). Completion weight; 144k up, 130k down. Torque turn each joint to 4440 ft-Ibs utilizing torque-turn equipment and double-stack tongs. Tag up inside PBR and LD 2 joints of tubing; PU 5.80' pup joint and space out completion. PU final joint and tubing hanger. MU landing joint and RIH; land completion with bottom of WLEG at 9171.54' (6.7' inside Production Liner PBR). MW in /out 8.5 ppg. No fluid loss noted throughout entire completion run. RILDS as per Cameron hand with 600 ft-Ibs. 14:00 - 17:30 3.50 BUNCO P RUNCMP RU to reverse circulate. Reverse circulate 140 bbls clean seawater followed by 296 bbls of corrosion inhibited seawater followed by 187 bbls of seawater at 3 bpm with 120 psi. 17:30 - 19:30 2.00 BUNCO RUNCMP 4rop 1-7/8" ball and rod. Close rams and pressure up against ball and rod i t t Hold pressure for 30 charted mintues, lost 10 psi during first 15 min and 5 psi during last 15 minutes -good test. Bleed pressure to 2000 psi. Pressure IA to 3500 psi for 30 charted minutes, lost 0 psi during entire test -good test. Bleed off IA pressure first then bleed tubing pressure to zero. Pressure up IA to shear DCR valve; sheared at 2500 psi with good indication of shear. Bleed off pressure and establish circulation through DCR, pump 2 bbls each way at 2.2 bpm with 160 psi. 19:30 - 20:30 1.00 BUNCO P RUNCMP Install TWC with T-bar as per Cameron Rep. Test TWC from below to 1500 psi for 10 charted minutes; good test. 20:30 - 00:00 3.50 BOPSU P RUNCMP Pull mouse hole and riser. Lossen turnbuckles. Commence to ND BOP. 9/11/2009 00:00 - 05:30 5.50 BOPSU P RUNCMP Continue to ND BOP, remove bolt from top and bottom of spacer spool, move BOP clear of spacer spool. Move spacer spool to pedestal 05:30 - 11:00 5.50 WHSUR P RUNCMP Place BOP on spacer spool and secure. NU adapter flange and 4 1/8" Carbon Tree. Test adapter flange and tubing anger me a - o-me a seal to 5000 psi for 10 minutes; good test. 11:00 - 12:00 1.00 WHSUR P RUNCMP Prepare rig floor for move, A-leg spreader, 4" and cement union. Secure roughneck. 12:00 - 16:00 4.00 WHSUR P RUNCMP Attempt to pressure test 4 1/8" tree -fail. Check all surface equipment. 16:00 - 17:30 1.50 WHSUR N WAIT RUNCMP Change out valves on manifold and test all surface equipment - good. 17:30 - 18:00 0.50 WHSUR P RUNCMP Test 4 1/8" Tree to 5000 psi for 10 minutes -good test. 18:00 - 20:00 2.00 WHSUR P RUNCMP tes ing equipmen . secon ary va ve on to ing spool. Printed: 9/29/2009 11:39:04 AM BP EXPLORATION Page 13 of 13 Operations Summary Report Legal Well Name: D-16 Common Well Name: D-16 Spud Date: 12/7/1981 Event Name: REENTER+COMPLETE Start: 8/17/2009 End: 9/12/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 9/12/2009 Rig Name: NABORS 9ES Rig Number: 9ES Date From - To II Hours Task ', Code ! NPT Phase i Description of Operations __ 9/11/2009 20:00 - 21:30 1.50 WHSUR P RUNCMP RU DSM, test lubricator to 500 psi and lubricate out TWC. LD lubricator on floor. 21:30 - 00:00 2.50 WHSUR P RUNCMP RU to freeze protect. 9/12/2009 00:00 - 09:30 9.50 WHSUR P RUNCMP PJSM with Little Red Services and rig crew. LRS rigged up to the IA (9 5/8" x 4 1/2") and pressure tested their lines to 3000 psi. Reverse circulate 151 bbls of 68 deg F diesel down the inner annulus in order to freeze protect to 2196' TVD. LRS pumped diesel at an average rate of 2.0 bpm with 300 psi. Allow diesel to U-tube from annulus to tubing for 2 hrs. RU DSM and lubricate in BPV. Test BPV with LRS from below to 1500 psi for 10 min -good test. RD DSM and LRS Secure well with flanges, bull plugs with needle valves and pressure gauges -all annular valves closed. Rig Released at 09:30 hrs. Printed: 9/29/2009 11:39:04 AM • D-16A, Well History (Post Rig Sidetrack) Date Summary 9/18/2009 WELL S/I ON ARRIVAL. PULLED BALL & ROD FROM RHC-M PLUG BODY IN XN NIP C~1 9144' SLM. SET 4 1/2" SLIP STOP CATCHER C~ 5250' SLM. 9/19/2009 PULL RK-DGLV FROM ST# 3 C~ 5080' SLM / 5090' MD, & RKP-DCR FROM ST# 4 C~ 3495' SLM / 3508' MD. SET ST#4 RK-LGLV & ST#3 RK-OGLV. PULLED EMPTY 4 1/2" SLIP STOP FROM 5250' SLM. PULL RHC-M PLUG BODY FROM XN NIP Q 9142' SLM / 9132' MD. DRIFT TBG W/ 3 3/8" DMY GUN & S-BAILER, SAT DOWN IN MUD C~? 9614' SLM, NO RECOVERY. RAN 3.00" BAILER SEVERAL TIMES FROM 9614' SLM & MADE TOTAL OF 15'. RECOVERED TOTAL OF 5 gal MUD. 9/20/2009 RAN 3.00" x 10' DD-BAILER, CLEARED OUT SAND/MUD BRIDGE FROM 9629' - 9656' SLM. RECOVERED 6 gal TOTAL OF MUD. RAN 4 1/2" BRUSH & 3.70" G.RING, SAT DOWN C~ 10,211' SLM NO RESTRICTIONS. DRIFTED TBG W/ 10' x 3 3/8" DMY GUN & S.BAILER TO SOFT TD C«~ 10,229' SLM (needed 9982' MD). WELL S/I ON DEPARTURE, PAD OP NOTIFIED. 9/22/2009 WELL SHUT-IN ON ARRIVAL. SSV=O, MV = O, WV = C, IA/OA=OTG, INITIAL T/I/O = 150/0/0, UNABLE TO RIG UP DUE TO HIGH WINDS. WELL SHUT-IN ON DEPARTURE. 9/23/2009 WELL SI ON ARRIVAL. INITIAL T/I/O = 150/0/0. ELINE INITIAL PERFORATION 9972' - 9982'. •~ PERFORATED USING 3-3/8" 3406 PJ HSD. API DATA: 6 SPF, 60 DEGREE PHASING, 0.45" ENTRANCE HOLE, 38.6" PENETRATION. WELL LEFT SHUT IN. M, SSV =OPEN. S, W =CLOSED. CSV = OTG. PAD OPERATOR NOTIFIED OF STATUS. FINAL T/I/0=100/0/0 JOB COMPLETE. Page 1 of 1 by Schlumberger D-16A Surve Report Report Date: 7-Sep-09 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 181.32° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: D-PAD / D-16 ND Reference Datum: Rotary Table Well: D-16 ND Reference Elevation: 69.68 ft relative to MSL Borehole: D-16A Base Flange Elevation: 42.97 ft relative t0 MSL UWIIAPI#: 500292068301 MagneOc Declination: 22.497° Survey Name 1 Date: D-16A I September 7, 2009 Total Field Strength: 57667.347 nT Tort 1 AHD 1 DDI 1 ERO ratio: 156.963° / 3748.08 ft / 5.829 / 0.413 Magnetic Dip: 80.918° Gdd Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: August 30, 2009 Location LaUlong: N 7017 39.577, W 148 45 26.292 Magnetic Declination Model: BGGM 2009 Location Grid NIE YIX: N 5958778.000 ftUS, E 653474.000 ftUS North Reference: True North Grid Convergence Angle: +1.16994167° Total Corr Mag North •> True North: +22.497° Gdd Scale Factor: 0.99992676 Local Coordinates Referenced To: Well Head ~~ Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Dapth Tree Section Departure True North True North ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS rrolec[ea-up u.uu u.uu u.uu -va.vo v.vu u.vu u.uu u.vu u.uu u.uu u.uu aaaorro.uu OaJ4/4.VU IV !U I! Ja.arr VV 1404.7LV.L.yL WRP 28.21 0.00 0.00 -41.47 28.21 0.00 0.00 0.00 0.00 0.00 .0.00 5958778.00 653474.00 N 70 17 39.577 W 148 45 26.292 SPERRY 1!14/82 g1.11 0.20 182.60 21.43 91.11 0.11 0.11 0.11 -0.11 0.00 0.32 5958777.89 653474.00 N 70 17 39.576 W 148 45 26.292 BOSS-16957 GYRO 191.11 0.37 80.19 121.43 191.11 0.22 0.50 0.38 -0.23 0.31 0.46 5958777.78 653474.31 N 70 17 39.575 W 148 45 26.283 291.11 0.48 71.00 221.43 291.11 0.01 1.24 1.02 -0.04 1.02 0.13 5958777.98 653475.02 N 70 17 39.576 W 148 45 26.263 391.11 0.35 84.90 321.42 391.10 -0.17 1.96 1.72 0.13 1.72 0.16 5958778.16 653475.72 N 70 17 39.578 W 148 45 26.242 491.11 0.38 89.19 421.42 491.10 -0.21 2.60 2.36 0.16 2.36 0.04 5958778.21 653476.35 N 70 17 39.578 W 148 45 26.224 591.11 0.55 84.59 521.42 591.10 -0.28 3.41 3.17 0.21 3.16 0.17 5958778.27 653477.16 N 70 17 39.579 W 148 45 26.200 691.11 0.52 104.81 621.41 691.09 -0.23 4.33 4.08 0.14 4.08 0.19 5958778.22 653478.08 N 70 17 39.578 W 148 45 26.173 791.11 0.73 115.00 721.41 791.09 0.13 5.42 5.10 -0.25 5.10 0.24 5958777.86 653479.10 N 70 17 39.574 W 148 45 26.144 891.11 0.87 121.81 821.40 891.08 0.77 6.81 6.39 -0.92 6.32 0.17 5958777.21 653480.34 N 70 17 39.568 W 148 45 26.108 991.11 0.88 128.11 921.39 991.07 1.62 8.34 7.78 -1.79 7.57 0.10 5958776.36 653481.60 N 70 17 39.559 W 148 45 26.072 1091.11 0.82 121.20 1021.38 1091.06 2.43 9.82 9.17 -2.64 8.79 0.12 5958775.54 653482.84 N 70 17 39.551 W 148 45 26. 1191.11 0.92 114.50 1121.36 1191.04 3.11 11.34 10.66 -3.34 10.13 0.14 5958774.87 653484.19 N 70 17 39.544 W 148 45 25. 1291.11 0.87 112.31 1221.35 1291.03 3.69 12.90 12.22 -3.96 11.56 0.06 5958774.28 653485.64 N 70 17 39.538 W 148 45 25.955 1391.11 0.87 106.00 1321.34 1391.02 4.16 14.42 13.74 -4.46 12.99 0.10 5958773.81 653487.08 N 70 17 39.533 W 148 45 25.914 1491.11 0.83 100.11 1421.33 1491.01 4.46 15.90 15.21 -4.79 14.44 0.10 5958773.50 653488.53 N 70 17 39.530 W 148 45 25.871 1591.11 0.70 116.11 1521.32 1591.00 4.83 17.23 16.53 -5.19 15.70 0.25 5958773.13 653489.80 N 70 17 39.526 W 148 45 25.835 1691.11 0.72 106.20 1621.31 1690.99 5.25 18.46 17.77 -5.64 16.85 0.12 5958772.71 653490.96 N 70 17 39.521 W 148 45 25.801 1791.11 0.30 114.81 1721.31 1790.99 5.51 19.35 18.65 -5.92 17.69 0.43 5958772.44 653491.81 N 70 17 39.519 W 148 45 25.777 1891.11 0.57 140.31 1821.31 1890.99 5.99 20.10 19.34 -6.41 18.25 0.33 5958771.96 653492.37 N 70 17 39.514 W 148 45 25.760 1991.11 0.52 128.50 1921.30 1990.98 6.64 21.05 20.20 -7.08 18.92 0.12 5958771.31 653493.06 N 70 17 39.507 W 148 45 25.741 2091.11 0.60 104.81 2021.30 2090.98 7.04 22.01 21.15 -7.49 19.78 0.24 5958770.91 653493.93 N 70 17 39.503 W 148 45 25.716 2191.11 0.62 113.70 2121.29 2190.97 7.36 23.07 22.21 -7.85 20.78 0.10 5958770.58 653494.94 N 70 17 39.500 W 148 45 25.687 2291.11 0.52 119.41 2221.29 2290.97 7.78 24.07 23.20 -8.29 21.67 0.11 5958770.16 653495.84 N 70 17 39.495 W 148 45 25.661 2391.11 0.68 130.00 2321.28 2390.96 8.37 25.11 24.21 -8.89 22.52 0.19 5958769.57 653496.70 N 70 17 39.489 W 148 45 25.636 SurveyEditor Ver SP 2.1 Bld( users) D-16\D-16\D-16A\D-16A Generated 10/7/2009 10:51 AM Page 1 of 4 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub•Sea TVD TVD Closure DLS Northing Easting Latitude Longitude Dept TNe Section Departure True North True North ft de de ft ft ft ft ft ft ft de H00 ft ftUS ftUS 14y1.11 U./5 1Z/.5U Z4ZLZ/ Z4`JU.yS y.13 ZC5.3U Y0.41 -`J.b/ ZJ.bU V.Utf ~`Jbif/6tS.t51 tl534`J/.6`J N /U 1 / 3`J.4tfZ VV 14tf 45 Zb.6U/ 2591.11 0.62 123.31 2521.27 2590.95 9.80 27.55 26.57 -10.37 24.47 0.14 5958768.14 653498.67 N 70 17 39.475 W 148 45 25.579 2691.11 0.40 140.11 2621.26 2690.94 10.35 28.44 27.42 -10.93 25.14 0.26 5958767.59 653499.36 N 70 17 39.469 W 148 45 25.559 2791.11 0.52 132.81 2721.26 2790.94 10.91 29.24 28.16 -11.51 25.70 0.13 5958767.02 653499.93 N 70 17 39.464 W 148 45 25.543 2891.11 0.58 130.61 2821.25 2890.93 11.53 30.20 29.08 -12.14 26.42 0.06 5958766.40 653500.66 N 70 17 39.457 W 148 45 25.522 2991.11 0.50 125.00 2921.25 2990.93 12.10 31.14 29.99 -12.72 27.16 0.10 5958765.83 653501.41 N 70 17 39.452 W 148 45 25.501 3091.11 0.40 128.50 3021.25 3090.93 12.55 31.92 30.76 -13.19 27.79 0.10 5958765.38 653502.05 N 70 17 39.447 W 148 45 25.482 3191.11 0.58 141.81 3121.24 3190.92 13.15 32.78 31.56 -13.81 28.38 0.21 5958764.78 653502.65 N 70 17 39.441 W 148 45 25.465 3291.11 0.75 132.90 3221.24 3290.92 13.97 33.93 32.64 -14.65 29.17 0.20 5958763.95 653503.46 N 70 17 39.433 W 148 45 25.442 3391.11 0.75 129.31 3321.23 3390.91 14.81 35.24 33.91 -15.51 30.15 0.05 5958763.11 653504.46 N 70 17 39.424 W 148 45 25.413 3491.11 0.72 136.40 3421.22 3490.90 15.66 36.52 35.14 -16.38 31.09 0.10 5958762.26 653505.42 N 70 17 39.416 W 148 45 25.386 3591.11 2.03 140.81 3521.19 3590.87 17.45 38.92 37.38 -18.21 32.65 1.31 5958760.46 653507.01 N 70 17 39.398 W 148 45 25.341 3691.11 3.67 169.40 3621.07 3690.75 21.93 43.80 41.19 -22.73 34.35 2.12 5958755.98 653508.81 N 70 17 39.353 W 148 45 25. 3791.1.1 5.27 168.81 3720.76 3790.44 29.55 51.59 46.98 -30.38 35.83 1.60 5958748.36 653510.44 ~ N 70 17 39.278 W 148 45 25. 3891.11 8.18 168.90 3820.06 3889.74 40.98 63.30 56.61 -41.87 38.10 2.91 5958736.92 653512.94 N 70 17 39.165 W 148 45 25.182 3991.11 10.78 160.31 3918.69 3988.37 56.66 79.74 71.70 -57.66 42.62 2.95 5958721.23 653517.78 N 70 17 39.010 W 148 45 25.050 4091.11 12.42 161.40 4016.64 4086.32 75.50 99.85 91.09 -76.66 49.20 1.65 5958702.37 653524.75 N 70 17 38.823 W 148 45 24.858 4191.11 14.65 167.61 4113.87 4183.55 97.90 123.23 113.60 -99.20 55.34 2.66 5958679.96 653531.35 N 70 17 38.601 W 148 45 24.679 4291.11 16.22 171.11 4210.26 4279.94 123.93 149.84 139.07 -125.35 60.22 1.82 5958653.91 653536.76 N 70 17 38.344 W 148 45 24.537 4391.11 18.72 175.40 4305.64 4375.32 153.65 179.84 167.71 -155.15 63.66 2.81 5958624.19 653540.81 N 70 17 38.051 W 148 45 24.437 4491.11 20.95 177.81 4399.71 4469.39 187.46 213.77 200.09 -189.02 65.63 2.37 5958590.37 653543.47 N 70 17 37.718 W 148 45 24.379 4591.11 22.82 181.89 4492.50 4562.18 224.70 251.02 .235.61 -226.27 65.68 2.41 5958553.13 653544.28 N 70 17 37.351 W 148 45 24.378 4691.11 25.80 184.10 4583.63 4653.31 265.84 292.18 274.80 -267.37 63.48 3.12 5958512.00 653542.92 N 70 17 36.947 W 148 45 24.442 4791.11 28.35 186.00 4672.66 4742.34 311.24 337.69 318.29 -312.70 59.44 2.69 5958466.61 653539.81 N 70 17 36.501 W 148 45 24.560 4891.11 30.83 189.79 4759.62 4829.30 360.26 387.05 385.38 -361.57 52.60 3.11 5958417.60 653533.97 N 70 17 36.021 W 148 45 24.759 4991.11 32.85 191.50 4844.57 4914.25 412.31 439.80 415.62 -413.41 42.83 2.21 5958365.58 653525.26 N 70 17 35.511 W 148 45 25.044 5091.11 34.77 193.19 4927.66 4997.34 466.92 495.44 468.77 -467.75 30.92 2.14 5958311.01 653514.46 N 70 17 34.976 W 148 45 25.391 5191.11 36.02 194.39 5009.17 5078.85 523.47 553.36 524.28 -524.00 17.10 1.43 5958254.50 653501.80 N 70 17 34.423 W 148 45 25.794 5291.11 36.75 195.19 5089.68 5159.36 581.15 612.68 581.35 -581.35 1.96 0.87 5958196.85 653487.83 N 70 17 33.859 W 148 45 26.235 5391.11 37.08 196.00 5169.63 5239.31 639.36 672.74 639.36 -639.20 -14.19 0.59 5958138.69 653472.86 N 70 17 33.290 W 148 45 26.706 5491.11 37.22 196.19 5249.34 5319.02 697.75 733.13 697.91 -697.23 -30.93 0.18 5958080.34 653457.31 N 70 17 32.720 W 148 45 27. 5591.11 37.50 196.50 5328.82 5398.50 756.36 793.81 756.98 -755.45 -48.01 0.34 5958021.78 653441.43 ~ N 70 17 32.147 W 148 45 27. 5691.11 37.95 196.79 5407.92 5477.60 815.37 855.00 816.71 -814.08 -65.54 0.48 5957962.82 653425.10 N 70 17 31.570 W 148 45 28. 5791.11 38.07 197.29 5486.71 5556.39 874.65 916.58 876.95 -872.95 -83.58 0.33 5957903.59 653408.26 N 70 17 30.991 W 148 45 28.728 5891.11 37.97 196.00 5565.49 5635.17 934.05 978.17 937.44 -931.96 -101.23 0.80 5957844.23 653391.83 N 70 17 30.411 W 148 45 29.242 5991.11 35.52 190.89 5645.63 5715.31 992.47 1037.97 996.76 -990.08 -115.20 3.92 5957785.85 653379.05 N 70 17 29.839 W 148 45 29.649 6091.11 34.70 186.19 5727.45 5797.13 1049.49 1095.46 1054.21 -1046.92 -123.76 2.82 5957728.85 653371.65 N 70 17 29.280 W 148 45 29.899 6191.11 35.40 185.39 5809.32 5879.00 1106.74 1152.89 1111.63 -1104.05 -129.55 0.84 5957671.62 653367.03 N 70 17 28.718 W 148 45 30.067 6291.11 36.58 185.89 5890.23 5959.91 1165.34 1211.65 1170.38 -1162.53 -135.33 1.22 5957613.04 653362.45 N 70 17 28.143 W 148 45 30.236 6391.11 37.40 187.00 5970.10 6039.78 1225.26 1271.82 1230.55 -1222.32 -142.08 1.06 5957553.13 653356.91 N 70 17 27.555 W 148 45 30.433 6491.11 38.05 188.00 6049.20 6118.88 1286.09 1333.00 1291.72 -1282.98 -150.07 0.89 5957492.32 653350.16 N 70 17 26.959 W 148 45 30.665 6591.11 38.70 189.29 6127.59 6197.27 1347.66 1395.08 1353.77 -1344.35 -159.41 1.03 5957430.78 653342.08 N 70 17 26.355 W 148 45 30.937 6691.11 39.08 190.29 6205.43 6275.11 1409.76 1457.86 1416.46 -1406.21 -170.09 0.73 5957368.71 653332.67 N 70 17 25.747 W 148 45 31.248 6791.11 39.48 191.29 6282.84 6352.52 1472.21 1521.17 1479.63 -1468.40 -181.94 0.75 5957306.30 653322.09 N 70 17 25.135 W 148 45 31.594 6891.11 39.32 191.50 6360.11 6429.79 1534.70 1584.65 1542.93 -1530.63 -194.48 0.21 5957243.84 653310.82 N 70 17 24.523 W 148 45 31.959 SurveyEditor Ver SP 2.1 Bld( users) D-16\D-16\D-16A\D-16A Generated 10/7/2009 10:51 AM Page 2 of 4 Measured Azimuth Vertical Along Hole NS EW Comments Inclination SutrSea ND ND Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS naai.~i aa.oa ia~.~u o4si.aa D~U/A3 IOy0.0I 104r.A4 IOU9.OG -l~yY.Yb -ZU/.UZ U.tl`J 5`J~/1t51.'JU tl53Z`J~y.b4 rvN1/'C3.y1/ W1484531.3Z5 7091.11 38.17 190.79 6516.22 6585.90 1657.81 1709.66 1667.65 -1653.20 -219.03 0.64 5957120.79 653288.78 N 70 17 23.318 W 148 45 32.674 7191.11 37.62 190.60 6595.13 6664.81 1718.41 1771.08 1728.98 -1713.56 -230.43. 0.56 5957060.22 653278.62 N 70 17 22.724 W 148 45 33.007 7291.11 36.92 190.19 6674.71 6744.39 1778.21 1831.64 1789.47 -1773.12 -241.36 0.74 5957000.46 653268.91 N 70 17 22.138 W 148 45 33.325 7391.11 36.32 190.19 6754.97 6824.65 1837.15 1891.29 1849.07 -1831.83 -251.91 0.60 5956941.55 653259.56 N 70 17 21.561 W 148 45 33.632 7491.11 35.73 189.69 6835.85 6905.53 1895.29 1950.10 1907.84 -1889.76 -262.06 0.66 5956883.43 653250.59 N 70 17 20.991 W 148 45 33.928 7591.11 35.17 190.29 6917.31 6986.99 1952.63 2008.10 1965.80 -1946.88 -272.12 0.66 5956826.12 653241.70 N 70 17 20.429 W 148 45 34.221 7691.11 34.57 189.60 6999.36 7069.04 2009.15 2065.27 2022.94 -2003.19 -282.00 0.72 5956769.62 653232.98 N 70 17 19.875 W 148 45 34.509 7791.11 34.15 189.39 7081.91 7151.59 2065.02 2121.71 2079.36 -2058.85 -291.31 0.44 5956713.78 653224.81 N 70 17 19.328 W 148 45 34.780 7891.11 33.70 189.00 7164.88 7234.56 2120.30 2177.52 2135.16 -2113.95 -300.23 0.50 5956658.52 653217.01 N 70 17 18.786 W 148 45 35.040 7991.11 33.35 188.79 7248.25 7317.93 2175.05 2232.75 2190.39 -2168.51 -308.77 0.37 5956603.80 653209.59 N 70 17 18.250 W 148 45 35.289 8091.11 32.48 189.19 733220 7401.88 2228.90 2287.09 2244.72 -2222.18 -317.26 0.90 5956549.97 653202.20 N 70 17 17.722 W 148 45 35.536 8191.11 32.37 189.39 7416.61 7486.29 2282.00 2340.71 2298.33 -2275.10 -325.92 0.15 5956496.89 653194.63 N 70 17 17.201 W 148 45 35. 8291.11 31.97 189.39 7501.25 7570.93 2334.72 2393.95 2351.56 -2327.63 -334.60 0.40 5956444.20 653187.01 ~ N 70 17 16.685 W 148 45 36 8391.11 31.77 189.00 7586.18 7655.86 2387.02 2446.75 2404.35 -2379.75 -343.04 0.29 5956391.92 653179.64 N 70 17 16.172 W 148 45 36.287 Tie-In Survey 8391.11 31.77 189.00 7586.18 7655.86 2387.02 2446.75 2404.35 -2379.75 -343.04 0.00 5956391.92 653179.64 N 70 17 16.172 W 148 45 36.287 TOW (Blind) 8416.00 31.71 188.92 7607.34 7677.02 2400.00 2459.84 2417.44 -2392.68 -345.08 0.29 5956378.95 653177.87 N 70 17 16.045 W 148 45 36.346 BOW (Blind) 8433.00 32.37 185.28 7621.76 7691.44 2408.97 2468.86 2426.45 -2401.63 -346.19 12.00 5956369.98 653176.94 N 70 17 15.957 W 148 45 36.379 Inc+Trend 8493.48 28.94 182.48 7673.78 7743.46 2439.76 2499.69 2457.20 -2432.38 -348.31 6.14 5956339.20 653175.45 N 70 17 15.654 W 148 45 36.440 8589.02 27.82 175.52 7757.86 7827.54 2485.07 2545.06 2501.98 -2477.72 -347.57 3.65 5956293.89 653177.11 N 70 17 15.209 W 148 45 36.419 MWD+IFR+MS 8685.11 25.31 164.54 7843.85 7913.53 2527.07 2587.92 2542.78 -2519.90 -340.34 5.73 5956251.87 653185.20 N 70 17 14.794 W 148 45 36.208 8716.61 24.66 161.43 7872.40 7942.08 2539.70 2601.22 2554.87 -2532.62 -336.45 4.65 5956239.23 653189.35 N 70 17 14.669 W 148 45 36.095 8741.28 23.96 162.49 7894.89 7964.57 2549.28 2611.38 2564.03 -2542.28 -333.31 3.34 5956229.64 653192.69 N 70 17 14.574 W 148 45 36.003 8780.53 24.75 161.69 7930.64 8000.32 2564.56 2627.56 2578.66 -2557.68 -328.33 2.18 5956214.35 653197.98 N 70 17 14.422 W 148 45 35.858 8812.24 26.02 157.82 7959.29 8028.97 2577.19 2641.15 2590.71 -2570.42 -323.62 6.59 5956201.70 653202.95 N 70 17 14.297 W 148 45 35.721 8875.37 25.96 156.30 8016.04 8085.72 2602.41 2668.82 2614.68 -2595.89 -312.83 1.06 5956176.45 653214.25 N 70 17 14.046 W 148 45 35.407 8907.09 26.76 155.32 8044.46 8114.14 2615.12 2682.90 2626.75 -2608.74 -307.06 2.87 5956163.73 653220.29 N 70 17 13.920 W 148 45 35.238 8938.73 26.17 155.18 8072.79 8142.47 2627.79 2697.00 2638.79 -2621.55 -301.16 1.88 5956151.05 653226.45 N 70 17 13.794 W 148 45 35.066 8970.48 25.87 156.16 8101.32 8171.00 2640.34 2710.93 2650.75 -2634.24 -295.42 1.65 5956138.48 653232.45 N 70 17 13.669 W 148 45 34.899 9002.36 25.39 155.83 8130.06 8199.74 2652.81 2724.72 2662.65 -2646.83 -289.81 1.57 5956126.00 653238.31 N 70 17 13.545 W 148 45 34.736 9033.94 25.94 157.13 8158.52 8228.20 2665.22 2738.40 2674.53 -2659.37 -284.35 2.49 5956113.57 653244.02 N 70 17 13.422 W 148 45 34. 9066.09 25.94 158.08 8187.44 8257.12 2678.09 2752.46 2686.90 -2672.38 -279.00 1.29 5956100.68 653249.64 N 70 17 13.294 W 148 45 34 9097.96 25.14 158.96 8216.19 8285.87 2690.76 2766.20 2699.10 -2685.16 -273.96 2.78 5956088.01 653254.94 N 70 17 13.168 W 148 45 34. 9130.1 S 25.43 159.76 8245.32 8315.00 2703.52 2779.96 2711.43 -2698.04 -269.11 1.39 5956075.23 653260.05 N 70 17 13.042 W 148 45 34.133 9162.74 28.10 158.59 8274.39 8344.07 2717.10 2794.62 2724.55 -2711.74 -263.89 8.36 5956061.64 653265.54 N 70 17 12.907 W 148 45 33.981 9193.90 28.18 158.91 8301.87 8371.55 2730.67 2809.32 2737.68 -2725.44 -258.57 0.55 5956048.06 653271.15 N 70 17 12.772 W 148 45 33.825 9285.63 26.64 159.84 8383.30 8452.98 2769.83 2851.54 2775.67 -2764.95 -243.69 1.74 5956008.86 653286.83 N 70 17 12.384 W 148 45 33.392 7" ~ 9344'md 9356.77 26.93 160.71 8446.81 8516.49 2799.75 2883.60 2804.82 -2795.13 -232.87 0.69 5955978.91 653298.27 N 70 17 12.087 W 148 45 33.077 9387.48 29.11 161.05 8473.92 8543.60 2813.27 2898.03 2818.01 -2808.76 -228.14 7.12 5955965.38 653303.27 N 70 17 11.953 W 148 45 32.939 9420.01 30.52 161.69 8502.14 8571.82 2828.48 2914.20 2832.88 -2824.09 -222.98 4.44 5955950.16 653308.74 N 70 17 11.802 W 148 45 32.788 9451.99 35.21 167.47 8529.00 8598.68 2845.09 2931.54 2849.20 -2840.81 -218.42 17.63 5955933.54 653313.64 N 70 17 11.638 W 148 45 32.656 9483.91 39.51 174.37 8554.38 8624.06 2864.12 2950.89 2868.02 -2859.92 -215.43 18.79 5955914.50 653317.02 N 70 17 11.450 W 148 45 32.568 9516.75 42.98 177.15 8579.07 8648.75 2885.66 2972.54 2889.43 -2881.50 -213.85 11.95 5955892.95 653319.04 N 70 17 11.237 W 148 45 32.522 9548.30 44.40 178.02 8601.88 8671.56 2907.41 2994.33 2911.07 -2903.27 -212.93 4.89 5955871.20 653320.40 N 70 17 11.023 W 148 45 32.496 9578.53 47.79 181.71 8622.84 8692.52 2929.17 3016.10 2932.78 -2925.04 -212.90 14.25 5955849.44 653320.88 N 70 17 10.809 W 148 45 32.495 SurveyEditor Ver SP 2.1 Bld( users) D-16\D-16\D-16A\D-16A Generated 10/7/2009 10:51 AM Page 3 of 4 Measured Azimuth Vertical Along Hole NS EW Comments Inclination Sub•Sea TVD ND Closure DLS Northing Easting Latitude Longitude Depth True Section Departure True North True North ft de de ft ft ft ft ft ft ft de 700 ft ftUS ftUS yU1L.V3 X1. 44 1tf4.4L r5b44. 5D tS/14 .L3 Ly~4. b/ 3U47 .t71 1y5t1.1y -1`35U .b1 -114. 1tf 11.51 5y55tf13. y5 9643.89 54. 53 187.34 8663. 73 8733 .41 2980. 02 3067 .05 2983.71 -2975 .81 -216. 90 12.15 5955798. 60 9675.04 56. 34 189.07 8681. 40 8751 .08 3005. 48 3092 .70 3009.29 -3001 .20 -220. 56 7.39 5955773. 15 9706.86 58. 26 190.30 8698. 59 8768 .27 3031. 97 3119 .47 3035.94 -3027 .59 -225. 07 6.85 5955746. 67 9739.27 60. 78 191.40 8715. 03 8784 .71 3059. 51 3147 .40 3063.69 -3055 .02 -230. 33 8.31 5955719. 15 9770.77 64. 25 192.26 8729. 57 8799 .25 3086. 98 3175 .34 3091.39 -3082 .36 -236. 06 11.28 5955691. 69 9803.14 65. 00 192.23 8743. 44 8813 .12 3115. 70 3204 .59 3120.37 -3110 .95 -242. 26 2.32 5955662. 99 9834.51 65. 08 191.95 8756. 68 8826 .36 3143. 64 3233 .03 3148.56 -3138 .76 -248. 22 0.85 5955635. 07 9865.72 65. 64 191.30 8769. 69 8839 .37 3171. 55 3261 .40 3176.71 -3166 .54 -253. 94 2.61 5955607. 17 9898.08 62. 99 190.64 8783. 71 8853 .39 3200. 30 3290 .56 3205.69 -3195 .17 -259. 49 8.39 5955578. 44 9930.07 63. 29 190.39 8798. 17 8867 .85 3228. 47 3319 .09 3234.08 -3223 .23 -264. 70 1.17 5955550. 28 9961.20 63. 53 189.62 8812. 10 8881 .78 3255. 99 3346 .93 3261.80 -3250 .64 -269. 53 2.34 5955522. 78 9993.02 63. 54 189.75 8826. 28 8895 .96 3284. 17 3375 .42 3290.18 -3278 .72 -274. 32 0.37 5955494. 61 10024.53 63. 53 191.04 8840. 32 8910 .00 3312. 02 3403 .63 3318.25 -3306 .47 -279. 41 3.67 5955466. 77 10055.92 63. 56 190.70 8854. 31 8923 .99 3339. 74 3431 .73 3346.20 -3334 .06 -284. 71 0.97 5955439. 07 10088.83 63. 67 189.97 8868. 93 8938 .61 3368. 86 3461 .21 3375.55 -3363 .07 -290. 00 2.02 5955409. 97 10120.92 63. 70 190.10 8883. 16 8952 .84 3397. 29 3489 .97 3404.20 -3391 .39 -295. 01 0.37 5955381. 55 10152.28 63. 76 191.08 8897. 04 8966 .72 3425. 04 3518 .10 3432.19 -3419 .03 -300. 18 2.81 5955353. 81 10215.00 63. 89 190.96 8924. 71 8994 .39 3480. 52 3574 .38 3488.17 -3474 .28 -310. 94 0.27 5955298. 35 10247.44 63. 93 191.19 8938. 97 9008 .65 3509. 24 3603 .52 3517.15 -3502 .88 -316. 54 0.65 5955269. 66 10279.52 64. 19 191.13 8953. 01 9022 .69 3537. 66 3632 .37 3545.84 -3531 .18 -322. 12 0.83 5955241. 25 10310.65 62. 08 191.09 8967. 07 9036 .75 3565. 03 3660 .13 3573.46 -3558 .43 -327. 47 6.78 5955213. 90 Last Survey 10356.17 62. 34 190.87 8988. 29 9057 .97 3604. 72 3700 .40 3613.53 -3597 .96 -335. 14 0.71 5955174. 22 TD (Projected) 10410.00 62. 34 190.87 9013. 28 9082 .96 3651. 74 3748 .08 3660.99 -3644 .78 -344. 13 0.00 5955127. 23 Survey Type: Definitive Survey NOTES: BOSS Gyro - (Sperry-S un BOSS gyro multishot --Sperry Sun BOSS m ultishot surveys Inc+Trend - ( Inclinometer + known azi trend -- Inclination only surveys in near-vertical hole-where formation di p and experience enab les direction of drift to be predicted. Replaces ex-BP "Inc linometer (azimuth in known quadrant" model. ) MWD + IFR + MS - ( In-field referenced MWD with mutt-station analysis and correction applied in post-processi ng. Ass umes a BHA sag c orrection is ap plied to enhance inclination accuracy. Legal Descriation: Northin g IYI [ ftUSI Eastino 1X1 tftUSl Surface : 3069 FSL 1692 FEL S23 T11 N R13E UM 5958778 .00 653474.00 BHL : 4704 FSL 2039 FEL S26 T11 N R13E UM 5955127 .23 653204.38 1i533LU.U1 N /U 1 / 1U.55y W 14tf 45 :11.535 653317.92 N 70 17 10.310 W 148 45 32.611 653314.77 N 70 17 10.060 W 148 45 32.718 653310.81 N 70 17 9.801 W 148 45 32.849 653306.11 N 70 17 9.531 W 148 45 33.002 653300.94 N 70 17 9.262 W 148 45 33.169 653295.32 N 70 17 8.981 W 148 45 33.350 653289.93 N 70 17 8.707 W 148 45 33.524 653284.78 N 70 17 8.434 W 148 45 33.690 653279.82 N 70 17 8.152 W 148 45 33.852 653275.19 N 70 17 7.876 W 148 45 34.003 653270.91 N 70 17 7.607 W 148 45 34.144 653266.69 N 70 17 7.331 W 148 45 34.~ 653262.17 N 70 17 7.058 W 148 45 34. 653257.44 N 70 17 6.786 W 148 45 34.586 653252.74 N 70 17 6.501 W 148 45 34.740 653248.31 N 70 17 6.223 W 148 45 34.886 653243.71 N 70 17 5.951 W 148 45 35.037 653234.08 N 70 17 5.407 W 148 45 35.350 653229.07 N 70 17 5.126 W 148 45 35.513 653224.06 N 70 17 4.848 W 148 45 35.676 653219.27 N 70 17 4.580 W 148 45 35.832 653212.41 N 70 17 4.191 W 148 45 36.055 653204.38 N 70 17 3.730 W 148 45 36.317 • SurveyEditor Ver SP 2.1 Bld( users) D-16\D-16\D-16A\D-16A Generated 10/7/2009 10:51 AM Page 4 of 4 TREE _ WELLH D= ACTUATOR KB. ELEV = 78.6' BF. ELEV - 26.71' KOP = 8416' Max Angle= 66° @ 9866° Datum MD = 9934' Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID=12.347" Minimum ID = 3.725" @ 9,159' 4-1/2" HES XN NIPPLE 2184' ~ 4-1/2" HES X NIP, ID = 3.813" 2661' FOC GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3508 3508 1 MMG DOME RKP 20 09/19/09 3 5090 4997 35 MMG SO RK 22 09/19/09 2 6595 6200 39 MMG DMY RK 0 09/10/09 1 7976 7305 33 MMG DMY RK 0 09/10/09 ' ~~ 9-5/8" X 7" BKR HRD ZXP LTP, ID = 6.19" 4 1/8" 5M MCEVOY -16A Hydl TOP OF 7" LNR ~-~ 8261' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~~ 9357' 9-5/8" MILLOUT WINDOW (D-16A) 8416' - 8433' 9022' --{4-1/2" HES X NIP, ID = 3.813" 9053' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9086' 4-112" HES X NIP, ID = 3.813" PERFORATION SUMMARY REF LOG: SLB-MWD 09/07/09 ANGLE AT TOP PERF: 64° @ 9972' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE i-3/8" 6 9972 - 9982 O 09/23/09 4-1/2" TBG, 12.6# 13CR-80 Vam Top, .0152 bpf, ID = 3.958" 9172' 7" CSG, 26#, L-80, BTGM, .0383 bpf, ID = 6.276" 9344' PBTD -{ 4-1/2" LNR, 12.6#, 13CR-80 VAM TOP, .0152 bpf, ID = 3.958" 9159' --~4-1/2" HES XN NIP, ID = 3.725" 9172' 4-1/2" WLEG, ID = 4.0" \ 9191' S" x 4-1/2" xo, ID = 3.958" 10320' 10,408' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/28/81 ORIGINAL COMPLETION 09/12/09 N9ES SIDETRACK (D-16A) 09/19/09 PJC DRLG HO CORRECTIONS 10/02/09 JED/PJC PERFS (09/07/09) 10/02/09 DTR/PJC GLV C/O (09/19/09) PRUDHOE BAY UNff WELL: D-16A PERMf>• No: 2090250 API No: 50-029-20683-01-00 SEC 23, T11 N, R13E, 2211' FNL & 1692' FEL BP Exploration (Alaska) F= i ~~ p .__~ ~ ~ y~p) F t ~~~ 4 ~' 6 / ~~ ~ ~ ~ ~ ~ 4 r ~ q k ~ ~~ ~ ~:F f" ~ e '~ ~ ~ ~ t ~ ~ ~ p@p p~p ~ ~ ~ ~ ~ ~ E {{{ ~~ '~ p~p ,~!°~ ~ ~ 'g ~ SEAN PARNELL, GOVERNOR ,9g t~ ~ ~+ A~S~ OIL ~ ~ s~~ CO1~T5ERQA'1'IO1~T CO1~II-II551O~T 333 W. 7th AVENUE, SUITE 100 ~~ ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 Robert Tirpack FAX (907) 276-7542 Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-16A BP Exploration Alaska Inc. Permit No: 209-025(revised) Surface Location: 2210' FNL, 1692' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 670' FNL, 2069' FEL, SEC. 26, T11N, R13E, UM Dear Mr. Tirpack: Enclosed is the revised approved application for permit to re-drill the above referenced development well. This revision was necessary due to the rig change necessitated by changing the well design from coil to rotary drilled and a change in the bottomhole location greater than 500' laterally. This approval supersedes the original approval dated February 20, 2009. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seam uo nt, Jr. Chair DATED this~~day of July, 2009 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA -~~~;C.~ ALASl~IL AND GAS CONSERVATION COMMI~N ,~! ~~i?~ 4y' PERMIT TO DRILL /~~`~~~ 20 AAC 25.005 Revised 07/21/09: Change to Rotary SIT 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 proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU D-16A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10536' TVD 9140' 12. Field !Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2210' FNL 1692' FEL SEC 23 T11N R13E UM 7. Property Designation: ADL 028285 & 028286 Oil Pool , , . , , , Top of Productive Horizon: 5016' FNL, 1919' FEL, SEC. 23, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 20, 2009 Total Depth: 670' FNL, 2069' FEL, SEC. 26, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 25,620' 4b. Location of Well (State Base Plane Coordinates): Surface: x-653474 y-5958778 Zone-ASP4 10. KB Elevation Plan (Height above GL): 70' feet 15. Distance to Nearest well within Pool: 1,200' 16. Deviated Wells: Kickoff Depth: 8429 feet Maximum Hole An le: 65 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3135 Surface: in Pr - _ n Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 2 L- TC-M 1072' 8250' 7 7' 2' 4 2 c Class' ' 6-1/8" 4-1/2" 12.6# 13 r80 VamTo 1 64' 172' 4 ' 10 36' 914 ' u lass' ' 5 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10242' Total Depth TVD (ft): Plugs (measured): g 29' None Effective Depth MD (ft): 10183' Effective Depth TVD (ft): 9273' Junk (measured): 9895' Casin Length. Size Gement Volume. MD' TVD Conductor /Structural 11 " x n e 11 11 ' Surface 2 2' 13- /8" 8 3 c ft Permafro t II 2' 2 6' Intermediate 3 7' - / " 1 67 cu ft Class' 130 cu ft PF'C' 9 7' 2' Pr Liner 1379' 7" 407 cu ft Class'G' 8848' - 1 T 80 0' - 15' Perforation Depth MD (ft): 9855' - 9927' Perforation Depth TVD (ft): 8962 - 9030' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Ryan Ciolkosz, 564-5977 Printed Name Robert Tirpa Title Engineering Team Leader Prepared By NameMumber Si nature ,~'~ ~ Phone 564-4166 Date rl ~~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill 209-025 mb r: API Number: 50-029-20683-01-00 Permit A pr..oval a e: ; See cover letter for he re irements Conditions of Approval: ~~ZSO.d?bt-pvCtit~ ~~pQ ~ CS ~~ Gl(~~~"~~C~`O~ ~ ~ ~ If box is checked, well// ay not be used toe lore for, test, or produce ~o Ibed methane, gas hydrates, or gas contained shales: [~ 3~~ ~~ ~c~~SJt- T ` Samples Req'd: ^, ~Yes I~No Mud Log Req'd: ^ Yes ~No ~SOC~ P 5`< dpi nZ ~~~Cl~~c~v~vc~g~ HZS Measures: I]O Yes ^ No Directional Survey Req'd: Yes ^ No Other: / 2'~ ~ ~ Date APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ ~ w ~ ~ ~ ~ / Submit In Duplik:ate ~~ Maunder, TMam~s E (pQA~ ~~ From: Colkosz, Ryan R [Ryan.Ciofkosz~bp.com] Sent; Friday, July 24, 20©910:26 AM To 11Aaunder, Thomas E (f00A) Subject: RE; f~-16A (209-025) revised - AG~11N T1te Correct. !~! R >s 2259p~i ~r ain; A~~fize for the rni#e~e Th~~f~ youf R~~n l~idtk~-, GPB Rotary Operations Drilling Engine~~~ BF' Exploration Alaska Office: (907)564-5977 Gall: {907)306-5626 Pag From: Maunder, Thomas E {p0A) [mailto;tom.maunder@alaska.gov] Sent: Friday, Jufy 24, 2009 10:2#, AM To: Colfcosz, Ryan R Subjec#: RE: D-16A {209-025) revis~ci ~ AGAiN Thanks f~y~t'1, a# is tla~ M~S>~'~ ~n e 5 i# ys 2.252; hu# on page 8 i# y~ X259. The di#f~rert~ is srneil; tau# the numbers shoufd b€~ c~t~eient. Thinks in a~va. T®rrt From: Ciolkosz, Ryan R [mailto:Ryan.Cioikosz@bp.cam) Sent: Friday, July 24, 2009 10:1$ AM To: Maunder, Thomas E (QQA) Subject: RE: D-16A (209-025) revised C'iolkt~z GPB Rotary ()pcrations Drilling ~n~itteer BP F,xpforatiort Alaska Uf'fice: (907)564-5977 ~ ell: (907j306-5626 7/24/2009 • ~ Page 2 of 2 From: Maunder, Thomas E (D{?A) [mailtotam.maunder@alaska.gov] Sent#: Friday, July Z4, 2009 10:0$ AM To: Ciolkosz, Ryan R Subject: Q-i6A (2U4-02S} revised Ryan, I am reviewing the revised pemii# application for this we11. 1. Please cheek the cement calculation for the 4-1t2" liner.. to the 401 208 f#"3 is fisted, but on 3, 208 sx is listed.. 1Amich is correct?' Thanks in advance. Tom Maunder, PE A4000 7/24/2009 • Well Name: D-16A Drill and Complete Plan Summary T e of Well (service / roducer / in'ector : Producer Surface Location: As-Built X=653474 Y=5958778 3069' FSL, 1692' FEL, T11 N, R13E, Sec. 23 Tgt 1 (Ivishak) X=653306 Y=5955969 264' FSL, 1919' FEL, T11 N, R13E, Sec. 23 Tgt 2 (Ivishak) X=653316 Y=5955704 5278' FSL, 1914' FEL, T11 N, R13E Sec. 26 Bottom Hole Location: X =653176' Y =5955032' Z=9070' SSTVD 4610' FSL, 2069' FEL, T11 N, R13E, Sec. 26 Kristin Pa Geolo ist 564-5256 Chris Stone Prod. En ineer 564-5518 R an Ciolkosz Drillin En ineer 564-5977 API NUMBER: TBD Ri Nabors 9ES Estimated Start Date: 08/20/2009 Operating Days to complete: 18.5 MD: 10536' TVD: 9140' ~ RT/GL: 28.53'/41.47' RTE: 70' Well Design: Ivishak Zone 2 Producer 4 ~/z" tbq, 12.6# 13-CR-80 , 7" x 4'/2" packer, 4'h" L-80 12.6# 13-CR-80 Ob'ective: Slant Producer in Ivishak Zone 2 Directional Plan: Version: Schlumberger P2 KOP: 8429' MD, build 4/100 Maximum Hole An le: 65.0° Close Approach Wells: Nearest well within Pool: No close approach Wells 1200' to D-08A Distance to Nearest Property Line: 25,620' to Unit Boundary S Surface and Anti-collision: No Surface of Anti-collision shut-in required D-16A Permit Application Page 1 Lo in Pro ram: • Intermediate Interval Drilling, MWD: GR/Res/Directional Open Hole: None Cased Hole: None Production Interval Drilling, MWD: GR, RES, NEU, Azimuthal Density, Directional Open Hole: None Cased Hole: None Mud Program: Whipstock Milling Mud Properties D y Plastic t API Fluid MBT ~pP9) Viscosity Ylb/a Oft ) Loss pH c mis/30min 10.2 15-22 30-40 6 -8 9.0 - 9.5 < 20 8 1/2: Intermediate Hole: LSND Mud Density Plastic Y d nt API Fluid MBT ~ppg) Viscosity lb/1 Oft ~ ~ Loss pH c mis/30min 10.2 16-20 25 - 30 < 6.0 9 - 10 < 20 6 1/8" Production Hole: Flo-Pro Mud Density Plastic nt Y API ~ppg) Viscosity lb/tl Oft ~ ~ Fluid Loss pH MBT c ml/30 min 8.5-8.6 8-15 24-30 6-8 9-9.5 <6 Casin ubin Pro ram: Hole Size Csg/ Tb O.D. Type Wt/ Ft Grade Connection Length Top MDlTVD Btm MDlrVD RTE 8 1/2" 7" Solid Liner 26 L-80 BTC-M 1072' 8250'/7537' 9322' / 8480' 6 1 /8" 4 1 /2" Solid 12.6 13CR-80 VamTo 1364' 9172' / 8345' 10536' / 9140' Tubin 4'h" 12.6 13CR-80 VamTo 9170' GL 9170' / 8343' Integrit Testin Test Point Depth Test Type 9 5/ "Surface Casin 20' - 50' from window 11.5 FIT Test Point Depth Test Type 7" Intermediate Casin 20' - 50' from intermediate shoe 10.5 FIT D-16A Permit Application Page 2 Cement Calculations: Casin Size Intermediate - 7" 26 ppf L-80 BTC-M -Single Stage Basis Tail: Open hole volume + 30% excess + 150' Liner Lap + 200' MD above liner(9 5/8" x 4"). TOC at TOL. Wash None S acer 25 bbls of MudPush II wei hted to 13.0 Tail 45.5 bbls 218 sks 15.8 Class G - 1.17 cuft/sk Temp BHST = 203° F Casin Size Production Casin - 4 1/2" 12.6 f 13-CR-80 VamTo Basis Tail: O en Hole Volume + 40% excess + 150' liner la + 200' MD above liner 7"x 4" . TOC at TOL. Wash None S acer 20 bbls of MudPush II wei hted to 12.0 Tail 37.1 bbls sks 15.8 Class G w/latex - 1.17 ft /sk Temp BHST = 213° F a~~~ . D-16A Permit Application Page 3 • Formation To s(TVDss) and Esti mated Pore Pressures Est. Formation To s Commercial Hydrocarbon Bearin Est. Pore Press. Formation (TVDss) (Yes/No) (Psi) UG4 -4186 UG3 UGl -4851 WS2 WSl CM3 -5843 THRZ -7152 BHRZ/TKNG -7402 TJF -7531 Kickoff -7618 TJE -7648 TJD -7979 TJC -8125 TJB -8335 TSGR -8410 Yes TSHA -8443 Yes TSAD -8513 Yes 42N/Zn4A -8660 Yes TCGL -8755 3135 BCGL -8832 PGOC -8905 25N -8920 MHO/HOT -8970 Yes 22N/Zn2A -8991 TZ1B -9070 TDF -9140 BSAD -9180 D-16A Permit Application Page 4 Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer will be tested to 2500 psi. Rams will be tested to 3500 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Giveri.[ig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration i d to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.2 arding the initial testing of the ROPE when existing wellhead or testing equipment prevents the testing of et of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams wi at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pu rte. a well. Safety concerns and spacing limitations with the wellhead height and tubing spo I preclude us rr "n a spacer spool in the BOP stack. ~ Q. ~~ ~~a~~~ ~~ ~ ~~ Production Interval- ~~~~L~ • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • Annular Preventer • Rams • Planned completion fluid: 3135 psi ~ 8755' TVD, 6.88 ppg EMW 2252 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) 250 / 2500 psi 250 / 3500 psi 8.6 ppg seawater / 6.8 ppg diesel Kick Tolerance / Intearifir Testing Summary Table Casing and Interval Casing Test Pressure Maximum Influx Volume Mud Weight Exp Pore Press LOT / FIT 95/8" Surface 3500 psi Infinite 10.2 6.83 11.5ppg Casing (assuming FIT 10.5ppg EMV FIT 7' Production 3500 psi Infinite 8.6 6.83 10.5ppg Liner (assuming a FIT 9.Oppg EMV FIT Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. D-16A Permit Application Page 5 • • D-16A Operations Summary Current Well Conditions 1. Open Perfs from 9,855' - 9,859' MD and from 9866' - 9927' MD. PBTD ~ 10,183' MD 2. Currently shut-in due to low oil rate 3. MITOA passed to 2000 psi (1/26/2009) 4. MIT-IA passes to 2600 psi (03/30/2009) 5. MIT-T passes to 3000psi (03/08/2009) 6. PPIT passed to 5000psi (1/26/2009). 7. Drifted to 9881' MD with 2.78" swage (5/2/2009) Pre Riq Operations S 1 Drift tubin to 8700' F 3 Pump at least 18 bbls of cement from PBTD at 10,183' MD to 9698' MD in the 7" 29# liner with 15.8 ppg Class G cement. The TOC must be a minimum of 9704' MD to comply with AOGCC regulations. Volume of 7" from 10,183 to 9698': .0371 bpf, 485' = 18 bbls. The plan is to kick off above 8600', do not bring cement above this depth. This plug is for zonal isolation. Freeze protect tubin with diesel to 2200' TVD. SBHP: 3202 si SBHT: 213 °F S 4 WOC. Drift to TOC. O 7 CMIT-T x IA to 2,500 psi. Pressure tests are required for competent barrier for ri o erations. If test fails, contact ODE. Freeze Protect as necessa C 6 Cut tubing below tubing patch with 2.63" OD DB tubing cutter. (Patch Drift ID: 2.867") Bottom of patch estimated at 4924' MD. Top of next Collar at 4928'. No-Go on top of patch and make cut between patch and collar or below Collar if possible. Establish circulation from the T to the IA. If cut fails contact ODE and ossibl ri u E-line for 'et cut above tubin atch O 8 MIT-OA to 2000 si. O 9 Bleed casin and annulus ressures to zero. O 10 Function tubing and casing LDS. Repair/replace as required. Perform PPPOT-IC to 3500 si and PPPOT-T to 5000 si. O 11 Set a BPV. Remove well house and flow line. Level ad as necessa Riq Operations 1. Move in. Rig up Nabors rig 7ES. 2. Pressure test OA to 2,000 psi and IA to 2500psi. (Begin Monitoring OA) 3. RU lubricator and Pull BPV. 4. Circulate out Freeze Protect and displace with seawater. 5. Install TWC (6-3/8 Type J BPV) and test to 1000psi above and below. 6. Nipple down tree. Nipple up BOPE. 7. Test BOPE to 3500 psi high, 250 psi low. Pull TWC 8. Screw in landing joint (7" IJ4S). Unseat and pull tubing hanger to floor. 9. Lay down landing joint and hanger. 10. Pull 5 1/2" tbg to cut at 4926' MD. Spool up (2) ~/a" control lines. Count bands and clamps. (26 bands). Obtain Hot work permit and cut tubing above patch with torch. 11. Test Lower BOP rams. 12. RU E-line and jet cut tubing at 8600' MD. POOH RD E-line 13. RIH with overshot and swallow tubing stub. Pull 5'/i" tubing. 14. Clean 9 5/8" casing with full gauge mill. (FO Collar at 2661'. Do not run scraper) Circulate well, surface to surface. 15. RU E-line. Run EZSV with GR/CCL Kick off point. D-16A Permit Application Page 6 • 16. Test 9-5/8" casing above EZSV to 3500 psi. 17. Change out 9 5/8 pack-off. Pull pack-off through stack. 18. PU and RIH with whipstock on drill pipe. 19. Orient and set WS. 21. Mill window. Pump a sweep. Drill 20', perform 11.5ppg FIT. POOH, LD window milling assemt 22. PU 8-1/2" drilling BHA (GR/Resistivity/Dir). RIH. 23. Drill to TD a Top of Sag River 24. At TD, Circulate sweep and BU as necessary. Do wiper to window. POH and LD BHA. 25. Rig up liner running equipment. Run 7" 26# BTC-M L-80 liner. ''r~_ ~ 26. Circulate bottoms up at the window. Continue in to TD. ~ ~~- 27. Circulate hole prior to cement. 28. Cement liner in place. Set liner hanger/packer. ~~'~,~29. Circulate out contaminated mud and cement. POH. LD running tool. 30. Test 7" liner (After 1000psi Compressive Strength) to 3500 psi for 30 minutes. Chart same. 31. PU 6 1/8" Build BHA (GR/Resistivity/Neutron-Density). RIH 32. Drill cement and float equipment. Displace well to 8.6ppg Flo-Pro drilling fluid. 33. Drill 20' of formation. Perform 10.5ppg FIT. 34. Build Curve through Zn 4. Rotate through Zn 3 and Z2. 35. Drill to TD tripping for new bits as required. 36. Circulate sweep and BU as necessary. POOH, MAD pass as required by Geologist 37. LD BHA. Pull wear Bushing 38. RIH with 4-1/2" 12.6# VamTop 13CR-80 liner on DP. 39. RU cement equipment. Circulate liner at TD. 40. Cement liner in place. Spot pert. Pill. Set liner hanger/packer. Release off with Running tool. 41. Swap over to Seawater. POOH 42. RU to run tubing. 43. Run 4-1/2" Vamtop 13CR-80 completion. 44. Space out and land tubing. 45. Reverse in corrosion inhibited brine 46. Drop Ball and Rod. Set packer. Individually test the tubing and annulus to 3500 psi for 30 minutes. 47. Shear valve and Confirm circulation. 48. Install TWC valve and Pressure test to 1000psi. Nipple down the BOPE. Nipple up the tree and test to 5000psi. 49. Pull TWC valve. Freeze protect the well to 2200' TVD. Install BPV. 50. RDMO. Release rig. Post Rig Operations 1. Pull BPV 2. Pull the ball and rod / RHC plug. 3. Perforate on E-line 4. Install gas lift valves 5. Re-install well house and instrumentation. (S-riser Mod Required) Drilling Engineer: Ryan Ciolkosz (907)564-5977 Production Engineer: Chris Stone (907)564-5518 Geologist: Roger Sels (907)564-5303 D-16A Permit Application Page 7 ., • ! Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE • 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 D-Pad is not an H2S pad. However, Standard Operating Procedures for H2S precautions should still be followed at all times. D-17B 12 m 5/17/2009 D-18A 10 m 3/11/2009 D-12 16 m 5/13/2009 D-08A 11 m 6/7/2009 D-15A 16 m 6/25/2009 Most recent reading on D-16 is 10 ppm on 3/4/2008. • Bottom Hole Pressure 0 3135 psi (6.88 ppg) C«~ 8755'ss • Maximum anticipated wellhead pressure: 0 2259 psi C~ surface(based on BHP and a full column of gas from TD C~ 0.10 psi/ft) • Potential for loss circulation o D-16A encounters one fault above the Kingak TJB which was encountered in the original wellbore with out losses o Most losses in area are associated with major faults in the area which D-16A does not encounter o Lost circulation potential for D-16A is moderate. In the event of lost circulation follow the ADW Lost circulation decision tree. • Faults o Kingak C~3 9100' MD. Est. Throw 25ft Down to the West. • Stuck Pipe o Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ/Kingak shale give problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. o Monitor cuttings closely and adjust mud weight accordingly to avoid destabilization. o We do not expect stuck pipe if the hole is kept adequately clean. D-16A Permit Application Page 8 WELLHEAD= ACTUATOR=' KB. ELEV = BF~. ELEV = KOP __ Max Angle =- Datum MD = flafi im T/fl = 39 • D-16 2662' 4895'-4907' 4901' 4901-4924" 13-3/8" CSG, 72#, L-80, ID = 12.347" STRING SHOT (04/21/0 CHEM CUT PATCH (04/21/ 5-1/2" DWPTBG PATCH (11/08/01), ID= 2.992". Minimum ID = 2.992" @-490'1' 5-1 /2" DWP TBG PATCH I ~ I SA~NOTES: 2034' ~ 5-1/2" OTIS "ROM" SSSVLN, ID = 4.562" 2661' Foc GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 12 2983 2983 1 MMG DMY RK 0 01/22/( "'11 4912 4848 31 MMG DMY RK 0 12/28/f 10 6059 5772 35 MMG DMY RK 0 12/28/£ 9 6213 5899 35 MMG DMY RK 0 12/28/f 8 6897 6436 39 MMG DMY RK 0 12/28/E 7 7069 6570 38 MMG DMY RK 0 12/28/E 6 7447 6872 36 MMG DMY RK 0 12/28/E 5 7602 6998 35 MMG DMY RK 0 12/28!£ 4 8003 7329 33 MMG DMY RK 0 12/28/F 3 8155 7457 32 MMG DMY RK 0 12/28/f 2 8473 7727 32 MMG DMY RK 0 12/28/E 1 8623 7855 31 MMG DMY RK 0 12/28/f **GLM PATCH ON 11/08/01 ~ ~ 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 8756' TOP OF 7" LNR I-I 8848' 1-1/2"_TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 8914' 9357' PERFORATION SUMMARY REF LOG: DA-BHCA ON 12/23/81 ANGLE AT TOP PE:RF: 20 @ 9804' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/2" 4 9804 - 9859 S 12/14/90 3-3/8" 4 9855-9859 O 03/01/00 3-3/8" 6 9866 - 9876 S 12/14/90 3-3/8" 6 9866 - 9876 O 07/02/94 3-3/8" 4 9885 - 9892 O 12/20/92 3-3/8" 4 9892 - 9900 O 02/26/91 3-3/8" 4 9911 - 9927 O 02/26/91 PBTD 10183' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10227' 8689' ~ 5-1/2" BKR L SLIDING SLV, ID = 4.562" 8729' TBG SEAL ASSY 8756 5-1/2" X 4-1/2" XO 8755' 9 5/8" X 5-1/2" BOT PKR, ID = 4.75" $$29' 4-1/2" OTIS X NIP, ID = 3.813" 8872' 4-1 /2" OTIS XN NIP, ID = 3.725" . 8914' 4-1/2" TBG TAIL, ID = 3.958" 8909' ELMD TT LOGGED 07/21/83 9677' MARKERJOINT 9895' ~ FISH - (4) CAM E-LINE BOWSPRING CENTRALIZER- 10/16/92 9919' FISH -MOUSETRAP - 03/02/95 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 12/28/81 ORIGINAL COMPLETION WELL: D-16 05/27/01 RN/TP CORRECTIONS PERMff No: 1811710 11/08/01 DAV/KAK TUBING PATCH API No: 50-029-20683-00 12/25/06 RRD/PAG CORRECT REPERF (07/02/94) SEC 23, T11 N, R13E, 210' FNL & 1692' FEL 03/18/09 RMC/SV TREE C/O (03/11/09) 05/30/09 MV/TLH TBG PATCH CUT (04/21/091 BP Exoloration (Alaska) TREE _ WELLHEAD= MCEVOY ACTUATOR= KB. ELEV = 78.57' BF. ELEV = 42.97' KOP = Max Angle = Datum MD = Datum TVD = Minimum ID = 3.725" @ 9,154' 4-1 /2" XN NIPPLE D~ 6A SA OTES: 2200' -1 4 1/2" X-Nipple, ID = 3.813 I 2661' Foc 2662' 13-3/8" CSG, 72#, L-80, ID=12.347" ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3518 3500 MMG DMY BEK 0 3 5101 5000 MMG DMY BK 0 2 6601 6200 MMG DMY BK 0 1 7967 7300 MMG DMY BK 0 /I 8240' '--I Baker PBR, ID = 7.5" 8250' 9-5/8" x 7" Baker Liner Top / Packer / 9017' 4-1/2" X-NIP, ID = 3.813" 9048' 7" x 4-1/2" Packer 9081' 4-1/2" X-NIP, ID = 3.813" ~ 9154' 4-1/2" XN-NIP, ID = 3.725" r 9-518" CSG, 47#, L-80, ID = 8.681" 9357' 4-1/2" Tubing, 12.6#, 13CR VAMTOP, ID = 3.958" 9167' PBTD 10183' 4-112" Liner, ?2.6#, 13CR V~ml~~op. ID = 3.958" 10,536' PERFORATION SUMMARY REF LOG: DA-BHCA ON 12/23/81 ANGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 9165' H Baker PBR, ID = 5.25" 9167' WLEG 9172' ZXP Packer 9322' 7" CSG, 26#, BTGM, ID = 6.276" DATE REV BY COMMENTS DATE REV BY COMMENTS 12/28/81 ORIGINAL COMPLETION 05/27/01 RN/TP CORRECTIONS 11/08/01 DAV/KA TUBING PATCH 12/25/06 RRDlPAG CORRECT REPERF (07/02/94) 03/18/09 RMC/SV TREE C/O (03/11/09) 05/30/09 MV/TLH TBG PATCH CUT (04/21/09) PRUDHOE BAY UNfT WELL: D-16A PERMff No: API No: 50-029-20683-02 SEC 23, T11 N, R13E, 210' FNL & 1692' FEL BP Exploration (Alaska) by Schlumherger D-16A (P2) Proposal Survey 1 DLS Computation Method: Minimum Curvature 1 Lubinski Client: Shared Services Drilling Vertical Section Azimuth: 181.320° Field: Prudhoe Bay Unit - WOA ~~ Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure 1 Slot: D-PAD I D-16 ' I~ s ~ ND Reference Datum: Rotary Table Well: ~ ~ ~; D-16 ND Reference Elevation: 70.00 ft relative to MSL Borehole: Plan D-16A ~P/~ Sea Bed 1 Ground Level Elevation: 41.47 ft relative to MSL UWIIAPI#: 500292068301 Magnetic Declination: 22.613° Survey Name 1 Date: D-16A (P2) I July 1, 2009 Total Field Strength: 57710.641 nT Tort 1 AHD 1 DDI I ERD ratio: 133.339° 13853.25 ft 15.773 / 0.422 Magnetic Dip: 80.906° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: July 01, 2009 Location LaUlong: N 7017 39.57675646, W 148 45 26.29221794 Magnetic Declination Model: BGGM 2008 Location Grid NIE YIX: N 5958778.000 ftUS, E 653474.000 ftUS North Reference: True North Grid Convergence Angle: +1.16994167° Total Corr Mag North -> True North: +22.613° Comments ' Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Dapth True Section True North True North Tool Face Difficulty ft de de ft ft H H R de de 1100 ft Index ftUS ftUS iie-in survey nsal.4J J~.// lay.uu Top Whipstock 8400.00 31.75 188.97 Base Whipstock 8416.00 32.60 185.74 KOP Crv 4/100 8429.00 32.60 185.74 TJE 8464.50 31.79 183.56 8500.00 31.01 181.27 8600.00 29.07 174.28 8700.00 27.53 166.49 8800.00 26.47 157.99 End Crv 8817.50 26.34 156.44 TJD 8841.19 26.34 156.44 TJC 9004.10 26.34 156.44 TJB 9238.43 26.34 156.44 Target Sag 9322.10 26.34 156.44 Sag 9322.11 26.34 156.44 7" Csg 9322.12 26.34 156.44 TSHU 9358.94 26.34 156.44 9361.17 26.34 156.44 Crv 13/100 /Target 1 9428.67 26.34 156.44 TSAD 9437.07 27.04 158.30 9500.00 32.96 169.67 9600.00 43.74 181.49 WeIlDesign Ver SP 2.1 Bld( users ) / aao. 1 a 7593.46 7607.01 7617.96 7648.00 7678.30 7764.89 7852.97 7942.10 7957.77 7979.00 8125.00 8335.00 8409.99 8410.00 8410.01 8443.00 8445.00 8505.49 8513.00 /oao.lo 7663.46 7677.01 7687.96 7718.00 7748.30 7834.89 7922.97 8012.10 8027.77 8049.00 8195.00 8405.00 8479.99 8480.00 8480.01 8513.00 8515.00 8575.49 8583.00 LJ8/.UL -LJ/~./U -J~iJ.V4 14V.7LL V.VU V.LO J.7JVJ.71..7L V:7J1/.7.V'!V 1/ IV.1/1.7/ODE VYJ JV.GVVO/VGA ', 2391.49 -2384.21 -343.74 65.00E 0.29 5.28 5956387.45 653179.03 0 17 16.12816428 8 45 36.30739210 'I 2399.96 -2392.65 -344.83 --- 12.00 5.29 5956378.98 653178.11 0 17 16.04508194 8 45 36.33908279 ~ 2406.95 -2399.62 -345.53 125.85E 0.00 5.29 5956372.00 653177.56 0 17 15.97653950 8 45 36.35949565 ' 2425.83 -2418.47 -347.07 124.00E 4.00 5.30 5956353.13 653176.40 0 17 15.79116706 8 45 36.40426272 2444.32 -2436.95 -347.85 122.05E 4.00 5.31 5956334.64 2494.21 -2486.90 -346.01 116.00E 4.00 5.35 5956284.74 2540.68 -2533.56 -338.18 109.14E 4.00 5.38 5956238.25 2583.51 -2576.72 -324.42 101.56E 4.00 5.40 5956195.39 2590.61 -2583.89 -321.41 -- 4.00 5.41 5956188.28 2600.14 -2593.53 -317.21 --- 0.00 5.41 5956178.73 2665.72 -2659.78 -288.32 --- 0.00 5.42 5956113.09 2760.03 -2755.08 -246.77 --- 0.00 5.44 5956018.66 2793.71 -2789.11 -231.93 --- 0.00 5.44 5955984.94 2793.72 -2789.12 -231.93 --- 0.00 5.44 5955984.94 2793.72 -2789.12 -231.92 --- 0.00 5.44 5955984.94 2808.54 -2804.09 -225.40 --- 0.00 5.45 5955970.10 2809.44 -2805.00 -225.00 -- 0.00 5.45 5955969.20 2836.61 -2832.45 -213.03 50.57R 0.00 5.45 5955942.00 2840.06 -2835.94 -211.58 48.91R 13.00 5.46 5955938.55 8567.52 8637.52 2870.04 -2866.12 -203.20 39.05R 13.00 8645.93 8715.93 2931.51 -2927.70 -199.21 29.72R 13.00 D-16\D-16\Plan D-16A\D-16A (P2) 5.50 5955908.55 5.56 5955847.06 653176.00 0 17 15.60943759 8 45 36.42706881 653178.87 0 17 15.11818059 8 45 36.37316257 653187.64 0 17 14.65923709 8 45 36.14519003 653202.27 0 17 14.23484286 8 45 35.74426478 653205.43 0 17 14.16429907 8 45 35.65647514 653209.83 0 1714.06953952 8 45 35.530 653240.06 0 1713.41792642 9 45 34.69 3 653283.55 0 17 12.48067277 8 45 33.48152797 653299.08 D 1712.14598237 8 45 33.04918010 653299.08 D 1712.14593878 8 45 33.04912380 653299.09 0 17 12.14589520 8 45 33.04906750 653305.92 0 17 11.99865573 8 45 32.85886720 653306.33 0 17 11.98972563 8 45 32.84733154 653318.86 0 17 11.71973970 8 45 32.49857263 653320.38 0 1711.68548217 9 45 32.45628604 653329.37 0 17 11.38863207 8 45 32.21226011 653334.62 0 17 10.78299235 8 45 32.09582152 Generated 7/2/2009 10:45 AM Page 1 of 2 Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth True Section True North True North Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS 4Y/V/ IL4H `J07`J.CD 4J.yy 7UJ.L/ UOOU.VV O/JV.UU LJ4.7.71 -L`J41.0`J 9691.23 ~ 54.29 188.70 8705.73 8775.73 3000.02 -2996.08 9691.69 54.29 188.70 8706.00 8776.00 3000.40 -2996.45 9700.00 55.30 189.16 8710.79 8780.79 3007.12 -3003.16 End Crv /Target 2 9778.86 65.00 193.00 8750.00 8820.00 3074.41 -3070.16 TCGL 9790.69 65.00 193.00 8755.00 8825.00 3084.91 -3080.61 BCGL 9972.88 65.00 193.00 8832.00 8902.00 3246.62 -3241.50 PGOC 9979.98 65.00 193.00 8835.00 8905.00 3252.92 -3247.77 POWC 10145.62 65.00 193.00 8905.00 8975.00 3399.93 -3394.04 25N 10181.11 65.00 193.00 8920.00 8990.00 3431.43 -3425.38 MHO /HOT 10299.42 65.00 193.00 8970.00 9040.00 3536.43 -3529.86 22N / TZ2A 10349.11 65.00 193.00 8991.00 9061.00 3580.54 -3573.74 TZ16 10536.02 65.00 193.00 9069.99 9139.99 3746.42 -3738.79 TD 10536.04 65.00 193.00 9070.00 9140.00 3746.45 -3738.81 Legal Description: Northing IYI fftUSl Surface : 3069 FSL 1692 FEL S23 T11 N R13E UM 5958778.00 Target Sag : 280 FSL 1926 FEL S23 T11 N R13E UM 5955984.94 Target 1 : 264 FSL 1919 FEL S23 T11 N R13E UM 5955969.20 Target 2 : 5278 FSL 1914 FEL S26 T11 N R13E UM 5955704.22 BHL : 4610 FSL 2069 FEL S26 T11 N R13E UM 5955032.60 -I`J`J./`/ L0.40K IJ.UU .7..70 .7y.7VOJJ.U/ 0.73JJ4.JL 'J // IU. U4.74344V 74.7 JL. I ILO.Y4VL -205.66 --- 13.00 5.62 5955778.57 653329.57 0 17 10 .11048987 8 45 32 .28363463 -205.71 20.23R 0.00 5.62 5955778.20 653329.52 0 17 10 .10680477 8 45 32 .28530503 -206.77 19.96R 13.00 5.62 5955771.47 653328.60 0 17 10 .04085997 8 45 32 .31599429 -220.00 --- 13.00 5.67 5955704.22 653316.74 70 17 9 .38189537 8 45 32 .70142761 -222.41 --- 0.00 5.67 5955693.73 653314.55 70 17 9. 27915974 9 45 32. 77167621 -259.56 --- 0.00 5.70 5955532.12 653280.70 70 17 7. 69675647 9 45 33. 85366684 -261.00 --- 0.00 5.70 5955525.82 653279.38 70 17 7. 63510436 9 45 33. 89582138 -294.77 --- 0.00 5.72 5955378.91 653248.60 70 17 6. 19655420 9 45 34. I 87940719 -302.01 --- 0.00 5.73 5955347.42 653242.01 70 17 5. 88829325 3 45 35. 09017057 -326.13 --- 0.00 5.74 5955242.48 653220.03 70 17 4. 86075621 4 45 35. 79 3 ' -336.26 --- 0.00 5.75 5955198.41 653210.80 70 17 4. 42919041 R 45 36. 086 -374.37 --- 0.00 5.77 5955032.63 653176.07 70 17 2. 80588038 9 45 37. 19757008 -374.37 -- 0.00 5.77 5955032.60 653176.07 70 17 2 .80566193 8 45 37 .19771942 Easting (XI fftUSl 653474.00 653299.08 653306.33 653316.74 653176.07 ~! • WeIlDesign Ver SP 2.1 Bld( users) D-16\D-16\Plan D-16A\D-16A (P2) Generated 7/2/2009 10:45 AM Page 2 of 2 by . i • Schlumherger ALL D-16A (P2) FIELD Prudhoe Bay Unit - WOA STRDDTURE D-PAD Magrelk Paramelen MoEel: aGGM 2008 Oq: 80.906° Date: JuM Ot, Z009 Surtaw L Lat: oralion NAD2] Alaska Stale PUnes. Zone Od. US Faet N]0 t]395]] Ming 5958]]8 OO 6U5 Gntl Delly: .11699d18]° Miscellan Slq-. eous D-t6 NO ReI Rotary Tapie l/C 00 !~apova MSL) Mag Dec: X22813° FS'. 5])10fi nT Lon. W1d8652fi.292 Easlieg: 65J6]400 fiUS Scale Fact: D999926]5]J Plan: D-tfiA (P2( Srvy Dade: July O'. '?009 2400 2700 3000 3300 3600 7800 8100 3= O O M 8400 C 0) 03 U 8700 9000 9300 i6 Tie-In Survey Top Whipstock 8asa Whipstock KOP Crv 61100 ..._.. _.._.._. _ .~. _.. _.. _.._.. _.. _. _.._.._.._..-..-..-..-..r...-..-..-.. _..~..-..-..- .-..-..-..-.._.._..-....i. .....................:.................................1...................................:..................................:..................................:. End Crv .....................i......................... ......;...................................~..................................i.................................. t. at6n ~PZ~ .............:..................................:.................... s 7800 8100 8400 8700 9000 9300 2400 2700 3000 3300 3600 Vertical Section (ft) Azim = 181.32°, Scale = 1(in):300(ft) Origin = 0 N/-S, 0 E/-V • by • Schlumherger WELL FIELD STRUCTURE D-16A (P2) Prudhoe Bay Unit - WOA D-PAD Ma9ne0c Parameters Sunace Location NAD21 Alaska Slate PWnes. Zone Od. VS Fea+ svaNaneous MoCel'. BGGM 2008 Dip'. 80906' Date'. Jury 01.2009 Lal: N]0 1139.5]] n6ing 5956]]8001iDS GM COnv. •+16994162` Sld: D-i6 ND ReI: Rotary Table (TO 00habove MSL) Mag Dec: ~226t 3° FS. 5l110fi ni Lon. Wt404526.292 Easlinq: 653414.001tU5 Scale FacL.09999261513 PWn'. D-16A (P2~ Srvy Dale. July 01, 2009 -600 -400 -200 0 -2400 -2600 Tie-In Survey Top Whipstod ............................................ Base WhipstocK KOP Crv dI100} -2400 -2600 -2800 n n -3000 Z 0 0 N C I I a~ -3200 m U Cn V V V -3400 -3600 3800 ....................:.............................. ..:..........................A......:..................................:.............................. J crv~~too ....................:.................................:................................. i..................................i.............................. End Crv I Target ....................:.................................i......... ........................; ................................;.............................. TD -2800 -3000 -3200 -3400 -3600 -3800 -600 -400 -200 0 «< W Scale = 1(in):200(ft) E »> • • - -- - -- - -~ntfc~~sion Report Company: North America -ALASKA- BP LocakCo-ordinate Reference: Well D-16 -Slot 16' Project: Prudhoe Bay TVD Reference: Mean Sea Level - Reference Site: PB D Pad MD Reference: D-16A Plan @ 70:OOft (Nabors XES) Site Error: O.OOft North Reference: True Reference Well: D-16 Survey Calculation Methods Minimum Cu+vature Well Error: O.OOft Output errors are at 1.00 sigma Reference Wellbore Plan D-16A _ Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan #2 D-16A Offset TVD Reference: Offset Datum Reference Plan #2 D-16A Filter type: GLOBAL FILTER APPLIED: All welfpaths within 200'+ 100/1000 of refer Interpolationlllfefhod: ~VI6~fervaTb~OfE ErrorNlodel: fSC1N5A Depth Range: 8,400.00 to 10,536.04ft Scan Method: Trav. Cylinder North -Results L-invited by: - --Ma~inwm center-centerdistanse o~'~~5E~75f~- Erra~ ~~;rfac~ --~~liptical-Genie _ - Survey Tool Program Date 7/2/2009 From To (ft) (ft) Survey (Wellbore) Tool Name - Description - -- - 91.43 8,391.43 D-16 Srvy 1 BOSS Gyro (D-16) BOSS-GYRO Sperry-Sun BOSS gyro multishot 8,391.43 8,700.00 Plan #2 D-16A (Plan D-16A) INC+TREND Inclinometer + known azi trend 8,700.00 9,361.00 Plan #2 D-16A (Plan D-16A) MWD MWD -Standard ~- 8~00~- ~,361:O~Plerr #2-D=t6A (PlarfD~ 6f~r - - - MWf7+tFR}IGTS- -- - IGtWD_+ 1FR +1VTUtti Statiorf --_ --- 9,361.00 10,536.04 Plan #2 D-16A (Plan D-16A) MWD MWD -Standard __ -9.36T.OIl 1II,53fiAA._P_lan #2 D=-16A (Plan-D--16A)--- - ---- --AQWD}11=R+1+AS-_ _- ___ MWD + iFR ±alrtultiStation -__---- - Summary -- - -= Site Name Offset Well -Wellbore -Design PB ~ Pad _D-Oa-_D-01---D-01- ---- - D-01 A- D-01 A- D-01 A D-08 - D-08A - D-08A _~175~=08/~D=08A WP05 D-10 - D-10 - D-10 ~-16 - D-16 -_D-16 _ - . __ - D-16 -Plan 2, D-16AP61 -Plan 2 D-16 -Plan 3, D-16A -Plan 3 D-17 - D-17 - D-17 D-17 - D-17A - D-17A - D-17 - D-17B -_D-17B_ ______ D-17 - D-17B - D-17B wp05 D-18 - D-18 - D-18 ---~1$$1$A = B==fBAc - -- D-18 - D-18A - D-18A wp4 D-19 - D-19A - D-19A - - - _ D-20 - D-20 - D-20 D-31 - D-31 - D-31 - -r 31A_~r_L.'~ia__R.'31d _.-_-_ _. Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) Outoffaage -___-___ Out of range 8,784.85 9,070.00 770.67 622.81 155.37 Pass -Major Risk ~;74~T~- -~T~Ot3 _ 734.47 - ~3~21 1T0.7~ asP s - Malo~ Risk Out of range ____8,5fi0.81 8,57D.00-- -~1-9 _-__ -_322.88_ ~60.9Z_- EAIL--MajoxBisk _-_ 8,560.78 8,570.00 9.19 372.87 -360.97 FAIL -Major Risk 10,182.97 10,295.00 83.52 489.23 -395.32 FAIL -Major Risk Out of range Out of range -_ - _ _ --- _ _ - Out of range Out of range Out of range Out of range Out of range - Out of range 8,630.53 8,245.00 391.56 462.23 99.75 Pass -Major Risk __- _ - 8,400-04 -835,©~ 701:48-- 415:78 - 3813 amass--Major Risl~ I 7/2/~Oa9 f238:~9P1Gf -- - Page 2 of 3- _-_ - - -- -- COMPASS 2003.16 Build 70- _ ' Project: - -- Prudhoe Bay -- -_ -_ __ _ _ _ _- _- - --mite. PB-Dad - -- Well: D-16 Wellbore: Plan D-16A Design: __ _ __ -- Plan #2 D-16A ---------- __ _ _ -- -- -_ From KOP to TD can interval 1.00 ft_____ _ - -- - -- ---- Scale 1:100 a moo 180 Travelling Cylinder Azimuth (TFO+AZI) [°] vs Centre to Centre Separation [200 ft/in] revised PTD 209025 • • Page 1 of 1 Saltmarsh, Arthur C (DOA) From: McMullen, John C [McMuIIJC@BP.com] Sent: Thursday, July 23, 2009 3:20 PM To: Saltmarsh, Arthur C (DOA) Cc: Hubble, Terrie L Subject: revised PTD 209025 Art - The reason for requesting a revision to PTD 209025 (D-16a sidetrack) is because the scope has changed from a coiled tubing sidetrack to a rotary sidetrack. In the prep work, we were unable to remove a tubing patch to be able to sidetrack the well through tubing via coil. Thanks, John McMullen Engineering Team Leader Coiled Tubing Drilling 564-4711 7/23/2009 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME /~~~ ,~ - ~~ /9 PTD# coq pis ~,G°~ /~S~Sl~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: f,G°!./Q~l~~ ,~~j~ POOL: ~~-',L°~;/Q~/yE „J ~l~ o/L Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / ilect is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and ] 0' sample intervals through tar et 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. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1 / 11 /2008 WELL PERA PTD#:2090250 Admin~- Appr Date ACS 7124!2009 Engineering ~HEGKLIST' field & Pool PRUDHOE BAY, PRUDHOE OIL •640150 WeN Name: PRUDHOE BAY UNIT D-16A - Program DEV Well bore sag ompanv BP EXPLORATIONIALASKAI INC Inkial Classffype DEV! 1-OIL GeoArea $90 Unit 11650 On/Off Shore On Annular Disposal 1 PS'rmN-fee-algched---- ------ ----- ----------------- ----------- 2 l~senumberappropriate_..------------------------------- - ----Yes---- --- ---- -- - --- -----•- - 3 Uniqua well name artd number . . ... . . . .. . .. . ... . --------•- ------ --.. Yes---- --- --- ---------------•-------- -------------------- --- -- --- --- - 4 )NallJocatedN~adefinedRo91------------------------ ----------- - --Yes---- -- ---- ----- -- ---------- ----------- ----------------------------- 5 -Vt1eJl located prcpet distance Uom drilling unN.bpundary _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ --Y~ ---- -- ---- ----------------•-- ------------------------------ -- --- -- 6 WeJI)o9atedR<ope[distancefJ4m4therwells--------------------------- ----Y~-- - -- ------- --- ---------------------------._..-----_-.. 7 SuffiCientaCreageavailable)RdriUin9unit.._--------•--------------- ....Yes .... .............. . ------------------------------------ -- --- ------------ 8 Ifdeviatsd, iswellbpreptatinc)uded ... . . . ...... . . . . . .... . ---------- ----Yes.... ..-- ----...-----.....-...... ----------------------------- .....------ 9 Operator.onlyatfectedpedY-------------------•---------------- ----Yes-•-- --- --------- -- -----•--------------------------------------- 10 Operato[hasaPprop[iatebondtn.force.-•---------------------------- ----Yes.... ------ ...@lanket_Bo0d~8t94193._..........,.---•-------------------------•--~~- 11 Pemlg-can be.issuedwitr4uts~or>serYati4norder------------------------- -...Yes-•-- ------------...........----------•----•-------------------------------- 12 ' Permitcan ke. issued without administrative approval . . . .. . ........... . . . . . . . . .Yes _ ... . _ ............. _ .. - . - - - - - - - - - 13 Canpermifbflapprovedbefprel5•daY-vrait-----•---------------------- ----Yes.... -- -------........-----------....---------------------------......----- 14 Well l~ated within area and strata authorfzad.bylnj~tion order # (psA 10# in-comments) For sane .NA . _ - . . - - _ - ~ ~ - 15 A11 walls within 11.4 mhe area of review identlnad-(Foraervicaweh surly) ..... . ....... . ....NA... - - - - - - ~ - - - - - • - - ~ ~ ~ - - - - - - - - - ~ - 16 Prs•produced-injector:. durationof pra~production less than 3months (F9r service wellonly) .....NA _ .. - - - - - • - - • - - - - • - - - - - - - - - - - - - - - - - - - - - - • - - - - - - - - - • • - - - - - - - - - - - - - - - ---- 17 N.onconven..garcon(atmstoAS31.05.OSQ~,11A),G.2A•D)-------------------- -~...NA..--- --- ...-------------------•---------------- ---- 18 Condos't9r-stringptovlded.....---•------------------ - .....NA..... ._.GonductorsetirtR-16(.181.171),_:.......--------•-------------------------- ---- 19 SudacasasingptotectsaUkn9wnUSDWS.----------•------•--------- -----NA----- ---AltaquiteCS-e~emptadA~O-1:........-.--.-.--•------•----------- -------------- 20 CMTvoI-adequate to-cjrculateon conducter.&suCf-csg--------------------- -----NA----- ---SUrfacscasingsetin A-16.------------------------------------- ------------- 21 CMT-vs>I-aslequatetotfp•)rllong-string to surf cs9--------•---------- ----- -----NA-.-.. .._Pr9ductioncaslrgasat.inD-18•--......_......-------------------....-..---------- 22 CMT.vdllcoverallkn9.nRroducflvel~riZRns---------------•----- ----- --- Y~---- ------------....._. ....----•--.... 23 Casipgdesigns.adequateforC.T,)3.&Rermafroat-------------•---------- --..Yes..-. Yes .........---• ---------.......--------------•------------..........._._ Rlg equipped with steel_pBs..No_resetve Pit planned, All yvaste toapproveddisposalwell(s).- - .. - - - - - - - - - - - - 24 Adequate tankage or.reserve Pit --- - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - .. 25 Ifa.re•driN,hasat0.4Q$fqr_abandonmentbeenapproysd .................... .:..Yes---- Yes --~---...•.... ....-------------•----- Preximity ana~sispertormad, Traveling cylinder-path-calculated, Nearestsegment, P8A poltion of-R•1ti. - . , .... _ 26 Adequate y+eRbora separekion-proposed ....... . . .............. . ..... . ... - . . . . - . - 27 Jf-dlvertertequired,ds>es-ikroeetragulatior~..--•------------------ --- -----~---. - Yas ...BOPSta~Cw)ILalreadYbainplace,.........--------------------------- ......---.. Ma>umum axpacted tormatipn pressure ^~ 6 9 EMW MW Rlannedup to 1D 2 RP9 in&5"hole & )3 6ppg in zona.... - 26 D11Uing ftuidprogram scbemakic & equlpJist adequate ------ - - ----- - - - - - - - - - _ ... - - - . _ . ---- 29 30 )30PEs,.dotheymestregulatipn-------------•-------------------- 139P~press rating_approRriate;-test to-(Put prig In swromants) - - - - - - - - - - - - - - • - - -- ~ Yes.--- - - - -Yes .... --------------------------------•----------•----------------------- ... MASP calculated at2259 Rsi 3500 psi 9QP testplanned... - ...... - _ - - - - - - - - - - - - - ...... - .. - - .. 31 Chokemanifoldc9mplies wIAPI RP-58 (May $4) .... . . .. . . . ..... . . . . ..... .... . Yas---- -------------------------------- ---------------------------- --•---- 32 WorkwiUcccur.~tbou3cpetatiQn-shutdo_wn--------------------- ----- ----Y~---- Yes - --------.........----------- -------------------------•---.....------ is Presets at D.pad• .Mud-should preclude H2& on-rig. Rig-has sensor's artd ala[ms, - - - - - - - - - - • - - - - - - H2S 33 Js presenee-of H2$ gas propable- - - - - --- - - - --- - - - - - - - - - - - - - - - - - - - - - - - - - - - . - ... 34 MecharUS~ICOrtditiQrtofytellswithinA9Byerif~d(Foi'aervic?we)Ionly)------------ ----NA-... .._..--- ------------- -...---------------------------..._.. ----•------ 35 Permit can be issuedwlobYdrogensulfidemeasures-------------------- - - ---N-O-•-- ----MaxlaveLH2Sinwe11A-15Awas16pPm(6125f09)..---.------------------------ -- ----- 36 Datap[eserttedoppotenlialoverpresaurezcnes-------------------- NA---- -- ---------------------... -- .....---------------------- ---•---- - 37 Seiamic anatysis of shallow gas zonas- - - - - - - - - - - -- - - - -- - - - - - -- - - ---- ---. NA---- -------------------------------- ------------------------ -------------- 38 5~t~edcpndUiRnsurvey(ifpff-shore)------------------- -- -- ---- ---- NA---- ---------- ------•---• --•--------------------------------------- --.... 39 CoDtaot namelphone for.weekty.progress [eports~exPloratgry only) - - - ---- - - - - - - - - - - --Yes . - - . _ _ .Greg Barbary 564-43~.. - - - - - - ..... - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date TEM 7124/2009 Geology Appr Date ACS 7/2412009 Geologic Commissioner: DT5 Engineering Public W10 Operator to confirm Location and lease numbers (2116109). Info confirmed 2:40p 2118109. AdditianaNy, Permit has been re-issued Date: Co pC9~'' loner: Date Commissioner Date due to change from coil tubing dell to rotary SIT (7/24!09 -ACS) 2123/2009 c~~~~~ 2123!2009 JKN 212312009 \J ~~~~ Q d SARAH PALIN, GOVERNOR CO1~SE8~A ATIOH ~ ~~+~ 333 W 7th AVENUE, SUITE 100 •~-7 1.~~~j~~•~~=~llliii---iii1----777 0l` ANCHORAGE, ALASKA. 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-16A BP Exploration Alaska Inc. Permit No: 209-025 Surface Location: 2210' FNL, 1692' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 4733' FNL, 1452' FEL, SEC. 23, T11N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. In accordance with 20 AAC 25.005(fl, all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (D-16A PB 1 PH) and API number 50-029-20683-70 from records, data and logs acquired for well D-16A. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). incerely, Daniel T. Seamount, Jr. Chair DATED this ~ day of February, 2009 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 N a ~l-d9 ~y 1~ ~ PERMIT TO DRILL ~ ~~~ ~ ~~~~ 20 AAC 25.005 AI811;k~ ~iI ~ Gas Cans. iabmmisSlO~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Service ^ Stratigraphic Test ®Development Oil Development Gas MuRiple Zone Single Zone 1 c. Specify if wed' for: ^ Coalbed Methane Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU D-16A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11912' TVD 8893'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028285~8r02t3288- Oil Pool FEL, SEC. 23, T11 N, R13E, UM 2210 FNL, 1692 Top of Productive Horizon: 5103' FNL 2137' FEL SEC. 23 T11 N R13E UM 8. Land Use Permit: 13. Approximate Spud Date: April 15, 2009 , , , , , Total Depth: 4733' FNL, 1452' FEL, SEC. 23, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,928' 4b. Location of Well (State Base Plane Coordinates): Surface: x-653474 y-5958778 Zone-ASP4 10. KB Elevation (Hei ht above GL): 78.60' feet 15. Distance to Nearest well Within Pool: 1,414' 16. Deviated Wells: Kickoff Depth: g7gg feet Maximum Hole An le: 102 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3222 Surface: 2342 1 in Pr ram: ifi i n T- etti - m em r a Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 / " a-~,z,, x zaia" 9.3# / 6.16# 1 r 7 7 ' 11 12' 174 I ' 1 g_ PRESE NT WELL CONDITION. S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10242' Total Depth TVD (ft): 2 ' Plugs (measured): None Effective Depth MD (ft): 10183' Effective Depth TVD (ft): 9273' Junk (measured): 9895' :Casin Len th Size Cement Volume MD Conductor l Structural 1 1 ' Surface 1 3/ " P rm fr II 2 ' Intermediate 9 57' /" 1 I 1 PF' 5 Pr i n Liner 1 7' 7" 4 7 I 'G' - 0'- 1' Perforation Depth MD (ft): 9855' - 9927' Perforation Depth TVD (ft): 8962' -9030' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Ptat ^ 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 Gres Sarber, 564-4330 Printed Name Joh c ull Title En ineerin Team Leader Prepared By NameMumber: Si nature Phone 564-4711 Date ~ / 7 ® Terrie Hubble, 564-4628 Commission Use Oni Permit To D m o?O API Number: 50-029-20683-01-00 Permit Approval See cover letter for Conditions of Approval If box is checked, well may not be used to explore for, test, or produce coalbed me_th/ane, gas hydrates, or gas contained shales: [/~ 3Sb~~1 cae-..~5~ Samples Req'd: ^ Yes 11e7 No Mud Log Req'd: ^ Yes CI~No ~~~.~ ~ ~.,^ti ~..~,v..`Grn~~-~{~T HZS Measures: Yes ^ No Directional Survey Req'd: (Yes ^ No Other: n APPROVED BY THE COMMISSION ~,~/ Date ,COMMISSIONER Form 10.401 Revised 12/2605 Submit In Duplicate L r ~ BP Prudhoe Bay D-16A CTD Sidetrack February 12, 2009 by Permit to Drill approval is requested to drill a coiled tubing sidetrack from well D-16 starting on April 15, 2009. D-16 is currently shut in for high gas production. D-16 has had a long history of squeezes and reperfs to shut-off gas. The liner is known to have damage from 9,815' - 9,856' MD, this damaged liner was identified as a major source of gas entry into the well. Being as the liner is damaged, it would make a gas shut-off with a cement squeeze difficult, with a low chance of success. Due to the high gas rates from this well it struggles to compete for on time. In the past year the well has seen a 38% on time making it a great candidate to relocate into a more prolific area of the D-pad GDWFI block. The plan calls for a big hole lateral with a solid and cemented liner in Zone 2B. Due to uncertainty about the oil/water contact in the parent well, and possible stranded oil lens's due to water over runs on shale stringers, this plan includes a planned pilot hole. The pilot hole will be drilled down until the heavy oil/tar is encountered. The pilot hole will be exited by sidetracking off of an open hole whipstock @ 9,860'. The horizontal sidetrack lateral will then be geo-steered to remain in lens's of good oil saturation within zone 2. The CTD liner will be solid, cemented and perforated. Liner cement will only be brought up to 9,580' in the parent well to provide a possible future cut and pull and re-sidetrack option. CTD Sidetrack Summary Pre-Rig Work Summary: 1. O MIT-IA - to 3000psi 2. O MIT-OA - to 2000 psi 3. O PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi 4. O Function LDS 5. O PPPOT-T 6. S Pull Patch from 5-1/2" tubing @4900'. 7. S Dummy all GLM's 8. C Mill XN nipple to 3.80" using Left Handed Motor. 9. S Drift well for whipstock to 9,815' which is top of damaged 7" casing. 10. E Set Whipstock with top at 9,786'. 11. C Downsqueeze cement past whipstock to P&A parent well perforations. 12. O Bleed IA, gas lift and production flowlines down to zero and blind flange. 13. O Remove S-Riser, Remove wellhouse, level pad. Rig Sidetrack Operations: (Scheduled to begin on April 15, 2009) 30~-0~~ 3. Drill 279' pilot hole section to 10,065' in order to determine the gas/oil contact. Q(~~,,, 4. Set open hole whipstock at 9,860'. 5. Drill build/turn section with 3.75" x 4.125" bicenter bit, and land well @ 10,002'. 6. Drill horizontal lateral section to 11,912'. 7. Run and cement a 3-1/2" x 2-7/8" Tapered 13Cr80 liner string. 8. Make a cleanout run with mill and motor 9. Make a logging run with a SWS CNL logging tool. 10. Perforate well 11. Circulate well to KWF brine. FP well to 2000' with diesel. 12. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 13. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design. 4. Run patch over leaking GLM at 4,900' 5. Test separator (600' of prefs) ~~~~f~t Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.7 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.75"x4-1/8" (bi-center bits used) Casing Program: fully cemented liner • 3-1/2", 13Cr80 9.3# STL 8,850' and - 9,786" and • 2-7/8", 13Cr80 6.16# STL 9,786'md -11,912'md • A minimum of 31 bbls 15.8 ppg cement will be used for liner cementing. (Assuming TD @ 11,912', a bit size of 4.125" and planning on 40% excess in the open hole interval) • TOC planned at 9,580'. Note -Leaving the cement top at this depth will preserve sidetrack options at a future date. If the cement in the liner lap should fail to provide hydraulic isolation, a liner top packer will be set. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plans. There are 2 directional plans attached. One for D-16APB1 which is the planned pilot hole, and one for the D-16A sidetrack. Max. planned hole angle in D-16A is 101 deg. @ 10,100'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 24,928 ft. • Distance to nearest well within pool -1,414 ft. (D-20 East to open perfs) Logging • MWD directional, Gamma Ray, Resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on D Pad is 50 ppm on well D-15A. • The maximum recorded H2S level on D-16 was 10 ppm on 10/26/2008. • Lost circulation risk is medium. • Leak at GLM #11 @ 4,900' -monitor IA throughout job. Reservoir Pressure • The max reservoir pressure was measured at 3,222 psi at 8800'ss in October 2007. (7.04 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2,342 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble 6" MCEVOY D -16 SAFETY NOTES: W~LhIEAD= MC~VOY ACTUATOR= OTIS KB. REV = 78.57' BF. ELEV = 4297' KOP= 4000' Max Angte = 39 ~ 6800' Datum MD = 9766' DatumTVD= 8800' SS 13-3/8" CSG, 72#, L-80, D = 12.34T DWP TBG PATCH (11!08!01), D = 2~ 112' OTIS SSSV LANDING NP, D = f:AC I IFT AdANrN2Fl S Minimum ID = 2.992" @ 4900' 5-1/2" DWP TBG PATCH °cir_a~ ria ~ i,n awa ~ uvorvi ~ 5-1/r BKR L SLDRJG SLV, D = 4.562" ~ 1 5-112' TBG, 17#, L-80, .0232 bpf, D= 4.89r ~ iTOP OF 7" LNR t 4-112" TBG, 12.6#, L-80, .0152 bpf, D = 3.958" 9-518" CSG, 47#, L-80, D = 8.681" 8756' 87~ 5-1/r x 4-112" XO --~--C55' 9 5/8'X5-11r BOT PKR D = $$29' 41 tr OTLS X N~ D = 3.813" 8848' 8872' 4-1Jr OTLS XN N~? D = 3.72: 8914' $914' 411r TBG TAL, D = 3.958° ~~ 8909' H.fLD TT LOGGED OTY11 /83 P9iFORATION SUMM4 RY REF LOG: DA-BHCA ON 12/23/81 ANGLE AT TOP PffiF: 20 Q 9804' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/r a saoa -sass s 1u14/so 3-318' 4 9855-9859 O 03101/00 3-318" 6 9866 -9876 S 12/14/90 3-378" 6 9868 -9878 O 07/02/94 3-318" 4 9865 - 9892 O 12/20/92 3-318" 4 9892 - 9900 O 02/26/91 3-318" 4 9911 - 9927 O 02126/91 u 7" LNR 29#, L-80, .0371 bpf, D = 6.184' 12 2983 2983 t MMG DMY RK 0 01122/09 "'11 4912 4848 31 MMG DMY RK 0 12/28181 10 6059 5772 35 MMG DMY Pot 0 12!28181 9 6213 5899. 35 MMG DMY RK 0 12/28/81 8 6897 8436 39 MMG DMY RK 0 12/28181 7 7069 6570 38 MMG DMY RK 0 12/2881 8 7447 6872 36 MMG DMY RK 0 12I28r81 5 7602 6996 35 MMG DMY RK 0 12128/81 4 8003 7329 33 MMG DMY RK 0 12128x81 3 8155 7457 32 MMG DMY RK 0 12/28!81 2 8473 7727 32 MMG DMY RK 0 12/2&81 1 8623 7855 31 MMG DMY RK 0 12/28781 9895' FISH- (4j CAME-LOBO CBJTRAL2ER-10116192 9919' FISH - MOISETRAP - 03tt DATE 12128181 REV BY COMMENTS OitIpNAL COMPLt_TION DATE 01/12/07 REV BY DAV/PA COMMENTS CORRECT REPERF #2 1 1 12/04/01 DCR/TLH BP REM D 10/30701 09117/03 CMQI7LP PERF ANGLE 8 LOCATION 12/25/06 RFmlPAG OORRECTREPERF(07/0?J94) PRUDHOE BAY UNti WELL: D•16 PERMIT No:'1811710 API No: 50-029.20693-00 T11N, R13E, 210' FNL & 1692' BP bcploration (Alaska) 3tZ/ _ iEV D - ~ s ~ SAFETY NOTES: Proposed CTD Sidetrack IS-112" OTIS SSSV LANDING NP. ID = 4.562" 1 U = 8800' 551 13-3/8" CSG, 72#, L-80, D = 12.347" Minimum ID = 2.992" @ 4900' 5-112" DWP TBG PATCH TOP OF 7" LNR I--I $$4$' OP OF CT LNR 8850' 19-5/8" CSG, 47#, L-80, O = 8.681" H 9357' I--~ ' 9786 PERFORATION S REF LOG: DA-BHCA ON 12/23/81 ANGLE AT TOP PERF: 20 ~ 9E04' 20= Note: lister to Productbn DB for historical pert data IQE SPF MERVAL OpNSgz !]ATE ' 1n° a s6o4 - s65s s 12114/so 9815 Dan 3l8" 4 9855 - 9859 O 03/01100 3l8" 6 9866-9876 S 12/14/90 3/8" 8 9888 -9878 O 07!02/94 3/8" 4 9885 -9892 O 12/20192 318" 4 9892 -9900 O 02/28/91 318" 4 9911 -9927 O 02/26/91 101$3' 7" ST MD ND DEV TYPE VLV LATCH PDFYi DATE 2983 2904 1 NtiAG DOME RK 16 02/18!07 "11 4912 4770 31 NMG DRAY RK 0 10 8059 5694 35 hAMG DRAY RK 0 9 8213 5820 35 NNK, DMY RK 0 8 6897 6357 39 NMG DMY RK 0 7 7069 6492 38 NtiAG DNIY RK 0 8 7447 8793 38 MI11K' DNIY RK 0 5 7802 6919 35 NtiAG DNIY RK 0 4 8003 7250 33 NMG DMY RK 0 3 8155 7378 32 MtrK' OMIY RK 0 2 8473 7648 32 MNIG DAAY RK 0 1 8823 7778 31 NMG DMY RK 0 "GLM PATGM Q~111NNU7 ' 5-1/2" DVIIPTBG PATCH (11/08/01), D= 4900 2.992" to oe pulsed 8689' 5-12" BKR L SLt]NG SLV, ID = 4.582" $729' TBG SEAL ASSY 875$' 5-1l2" X 4-1l2" XO 8755' 9 5/8" X 5-1/2" BOT PKR, D = 4.75" $$29' 4-112" OTIS X NIP, ID = 3.813" $$72' 4-112" OTLS XN NP, ID mlled to = 3.80' 8914' 4-112" TBG TA 1_, ID = 3.958" 8909' ELNID TT LOGG®07/21!83 ~ billet 9850 rt to 10065" 3-112" X 2-718" 13Cr cmtd & perfd 11912' 9896' FISH-(4)CAM6LME BOW^PRNG CENTRALIZER- 10116/92 FISH- MC)LLSETRAP- 03!02195 !]ATE REV BY COMuBJTS DATE REV BY COMMENTS 1212x181 ORIGINAL COMPLETION 01/12/07 DAV/PAG CORRECT REPD2F #2 05/27!01 RNITP OORRECTIDNS 02!27!07 DAVlTLH GLV CIO (02118/07) 11/08/01 D4V/KA TUBING PATCH 02/03109 NISE PROP'OSEDCTDStDETRACK 12104!01 DCWTLH EP RE11A04/ED 10/30/01 09/17103 CNIOVTLP PERFANGLEBLOCATION 12/25/06 RRD!PAG CORRECT REP3tF (07/02/94) PRUDtiOE BAY UNT 1NELL: D-16A PERMIT No: API No: 50.029-20683-Ot T71 K R13E 210' FNL 8 1692' FEL BP Elcpbration (Alaska) Welll D-16A 2.25 9.23 5.00 •- 12.65 ~'~ 13.56 ~`_ 2 1116" 5000 psi . R-24 Mud Cross 14.89 HCR M Hydril Annular 7 ii 16" Annular x 5000 psi 7 1 i 16" 5000 psi, FUC-46 TOT I IMud Cross I I Choke Line 16.~~ ~- 23.'8"x31 Variable R. 16.66 f- 2-3:8' Cort TOT 20.04 ~ Tree Size ,, ~, O 24.86 --=~ 26.68 _~ SSV Master Valve Lock Down Screws Ground Level -- ~ v1s" sooo ~ Kill Line 1L 2 1!16" 5000 psi , RX-24 1~1 ~- 7 1/16" X 3 1!8" Flanged Adapter Swab Valve by ~ BP Alaska `'~i` Baker Hughes INTEQ Planning Report r~~~ s wtc ins INTEQ Company: BP Amoco Date: 2/6!2009 Time: 10:54:12 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-16, True North Site: PB D Pad Vertical (TVD) Reference: 29 : i6 12/7/1981 00:00 78.6 Weli: D-16 - - „ .,.. Section(VS) Reference: Well (O.OON,O.OOE,170.OOAzi) Wellpath: Plan i ' - Survey Calculation Method: __ - Minimum Curvature 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 System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB D Pad TR-11-13 UNITED STATES :North Slope ~ Site Position: Northing: 5955590.34 ft Latitude: 70 From: Map EasHng: 652165.06 ft Longitude: 148 Position Uncertainty: 0.00 ft North Reference: 17 8.492 N 46 6.316 W True ~~ j Ground Level: 0.00 ft Grid Convergence: 1.16 deg _~ Well: D-16 Slot Name: 16 D-16 Well Position: +N/-S 3160.75 ft Northing: 5958778.00 ft Latitude: 70 17 39.577 N +E/-W 1373.27 ft Easting : 6534 74.00 ft Longitude: 148 45 26.292 W i ~ Position Uncertainty_ 0.00 ft _ _ ~ __ - '! Wellpath: Plan 2, D-16APB1 Drilled From: D-16 ' ~ 500292068370 Tie-on Depth: 9700.00 ft Current Datum: 29:16 12/7/1981 00:00 Height 78.60 ft Above System Datum: Mean Sea Level Magnetic Data: 4/9/2009 Declination: 22.73 deg Field Strength: 57703 nT Vertical Section: Depth From (TVD) +N/-S Mag Dip Angle: +E/-W 80.90 deg Direction ft ft ft deg 38.10 0.00 0.00 170.00 Plan Plan 2 Date Composed: 2/5/2009 Client's; Pilot Hole Version: 1 Principal: Yes Tied-to: _ From: Definitive Path _~ _ _ Targets - Map Map <- Latitude ---> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft D-16AP61 Target 9098.60 -3173.95 -437.92 5955596.00 653101.00 70 17 8.361 N 148 45 39.050 W -Plan hit target Annotation - - _ _ - __ _ _ - - MD TVD -- -- ft ft 9700.00 8817.06 TIP 9786.00 8897.56 KOP 9806.00 8916.22 3 10065.93 9099.00 TD -- - Plan Section Information MD Inci Azim TVD +N!-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft d eg/100ft deg ', 9700.00 20.87 191.50 8817.06 -2965.84 -458.56 0.00 0.00 0.00 0.00 9786.00 20.34 190.12 8897.56 -2995.57 -464.24 0.84 -0.62 -1.60 221.86 9806.00 21.92 187.71 8916.22 -3002.69 -465.35 9.00 7.88 - 12.06 330.00 10065.93 66.45 164.28 9099.00 -3175.14 -438.05 18.00 17.13 -9.01 330.00 ~R>~ bP ~ BP Alaska ~ B ~ '~~' Baker Hughes INTEQ Planning Report INTEQ Company: BP Amoco Date: 2/6/2009 Time: 10:54:12 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-16, True North Site: PB D Pad Vertical (TVD) Reference: 29:16 12/7/1981 00:00 78.6 ~ Well: D-16 Section (VS) Reference: Well (O.OON,O.OOE,170.OOAzi) I Wellpath: Plan 2, D-16APB1 Survey Calculation Method: Minimum Curvature Db: Oracle Survev MD Incl Azim SS TVD N/S E/W ft deg deg ft ft ft 9700.00 20.87 191.50 8738.46 -2965.84 -458.56 '. 9786.00 20.34 190.12 8818.96 -2995.57 -464.24 ~ 9800.00 21.44 188.40 8832.04 -3000.49 -465.04 9806.00 21.92 187.71 8837.62 -3002.69 -465.35 9825.00 24.93 183.65 8855.05 -3010.20 -466.08 9850.00 29.03 179.55 8877.32 -3021.53 -466.37 9875.00 33.23 176.39 8898.72 -3034.44 -465.89 9900.00 37.49 173.87 8919.11 -3048.85 -464.65 9925.00 41.79 171.81 8938.35 -3064.67 -462.65 i 9950.00 46.12 170.06 8956.35 -3081.79 -459.90 ~ 9975.00 50.48 168.55 8972.97 -3100.13 -456.43 10000.00 54.85 167.22 8988.13 -3119.56 -452.25 10025.00 59.24 166.03 9001.73 -3139.96 -447.40 10050.00 63.64 164.94 9013.68 -3161.21 -441.89 10064.94 66.27 164.32 9020.00 -3174.26 -438.30 10065.93 66.45 164.28 9020.40 -3175.14 -438.05 __ MapN MapE __ DLS VS TFO Tool ft ft deg/100ft ft deg -- 5955803.63 - _- _ 653076.12 0.00 __ 2841.16 0.00 MWD 5955773.80 653071.05 0.84 2869.44 221.86 MWD 5955768.86 653070.35 9.00 2874.16 330.00 MWD 5955766.66 653070.08 9.00 2876.26 331.61 MWD 5955759.13 653069.51 18.00 2883.54 330.00 MWD 5955747.80 653069.45 18.00 2894.64 333.72 MWD 5955734.90 653070.19 18.00 2907.44 337.38 MWD 5955720.52 653071.73 18.00 2921.84 340.09 MWD 5955704.75 653074.05 18.00 2937.77 342.14 MWD 5955687.68 653077.15 18.00 2955.11 343.74 MWD 5955669.42 653080.99 18.00 2973.77 344.99 MWD 5955650.09 653085.56 18.00 2993.63 346.00 MWD 5955629.79 653090.84 18.00 3014.57 346.81 MWD 5955608.66 653096.78 18.00 3036.45 347.46 MWD 5955595.69 653100.63 18.00 3049.92 347.98 D-16A 5955594.81 653100.89 18.00 3050.83 348.24 MWD LEGEND w, or,a ln,ww, uw,l BP Alaska I/.~ D.,61D-,6) „rr~~~,~ ~ ao p~~„°°Y-- ~~l~~,. - Plan 2, D-16APB1 wee .rn neruu ~ 1ARKlEGI! b Plan 2 uaP ~ Nonn: p ]~ n~, ~w.,, •"a~sp6.,~< NTEQ ~,,,] Fn,a.a,.mmaa, .. o-,. ,o`~,~,ape~n, ,.. o. aa. .,a~.~ ..r.a.,.'~: p.~6,~Tr,..,6a:aa ,..w, M;~ ^ a': ^~;: :~ ~,a REFERENCE NFORlMT ON I +~- ~ 1 rr {~ *'1-t. _l~~ y ~, r` '+ ~_ •1 !~:: ~~-~-~ J1 Pr{ rl t}~ t# ~~+ -1} r,.I. 4 1 +.:i (. 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T7 I 7' r+ I 1 +- r { ~ ~ f C ~~ ~+i-r l,i I -+I ~ i~:i ~ ~t. I J7r: L~ 'E.1 I fl rfi T'{ r~ ~tI:I i4 I sago I 1~ ~ r -__.I ~ I F r ~ ~ r 1 i , f ~ . } ~ tT iT i r.. II I~_ '. ., -i ~I-- -1 f i II rt"~ il.r:~ ++1 r~ 71 j_~- tii t~i- iL.l .:'l~1.~...~1 ,? _.,t 1 - } ~.~` ~....-:.a 4,~-i. 1 I, -,.r I~I:- i~- I.. ,...I .,. .IY Ir-t. 1'.k r ~'1. .. 1, .1... rr _, -r;-:. -~ ~k ~ , ±r. - I k r~ r + t r , ~ i.~1t7 Ir{ _.. o-te o-te \ irl i. f P~anz,o-teavet T-+_;-,~ 1 i ~_T f rit} 't t 1 t.i { Fjf~i +~ }!t ilii ~l:}1 +~ {!~i 1 yl} :_:. i_. + I ~w ~a ap n~ ~6 ~ a6d z~ ~p6 ]9p ~.p z~ ~6 ~ ~a ap,a ~ ~ ~p s ~ ~ ,~ ~ fi.d ~ ~ ~~ ~ >.,o~ ;.® ~60 o ~ap a~,p VeRbal eeetbn at 170.00' [20WIn] I ~~ LEGEND _ T Pia Puy z tD-+~ne~ z. D-terwell BP Alaska - D_oa (D_o8) ~l~ M Azimuths to True NOM Crear•e By BP - Date. 2Ifi2009 D-08 (D-08A) BAKiR Ma9rerK Nann: 22'3° D"~Me° 0a1a -_- D-1s (D-1s) Ma9retrFreM ~ Dele YFLVBTX DETAILL Srrarg8~ 57)03nT -- - D31A (D31A) ~6~ Dip Mgye: BD.90° 'eooii'3o:.3°~io°+ 031 (031) Mode a O+wzpaa `""" ~"~~~"~ ae~ M~••i~ - Plan 2, D-16AP81 NTEQ ~99m2°°' •,,., ~»3~ur9 °i Tr.-rD. iioo.oo PIan2 em°~- "'"1B~'~'""°mm !w. o-m~~°9 x9 . u +3nn-1 ooso 19aoD v. ~np. ~ Wi ~E~ar" Fn~MTED no.-• Dm 9.oD as.+o REFERENCE INFORMATION Corordinate (N/E Reference: Well Centre: D-1fi, True North Vertical ( D Reference: 29:16 12/7/1981 00:00 78 60 Section (VS Reference: Slot - 1fi (O.OON,O.OOE) Measured Depth Reference'. 29: ifi 12/7/1981 00:00 78.fi0 Calculation Methotl: Minimum Curvature flOTIOY DlTAIU YD IM AJ ND +WJ +G~W 049 TF9u VLC T9g91 9]00.00 20JT +91.50 881].08 3986.H A58.68 0.00 0.00 3M+.18 p188.00 30.)0 +80.+3 9891.58 3996.5] -080.20 O.M 331.88 2889A4 9808.00 21.92 +8].]1 8918.32 .]003.69 J65.3S 8.00 330.00 291856 10085.93 BBA3 +8038 9089.00 31)5.19 x]8.03 +8.00 330.00 ]050.83 D-OS ~ / D-08A) ~ 7200~ ( ~o "soo i i ~ i -,_ , 7eoo 8aoo . _ ~~ _ } ~l ~~ ~ ~ i~ ::a - - , i- -2800 - - - _ ~ __ - _ - - + _ _ _ ~_ _ - ~-- + ~t 6600 r ~ $ _. 1_ _ - n ? - }- -- ~ ... fi ~ - ~ T +-r ~- ~ --- ~ _ -2900 ' t 8700 - i 8100 , _ - a-- _ I -'_ ~ ( _~ ~ ~ _ __ y+ 1 i N -3000 6900 ~- ~-- ~ ~ ~ ~ I r ii - ,_- i - + ~ 1 ~ ~_ + L 8400 i- .. _ -~ - - ~ ~... ... -3100 ~ - 7--- - - S i , _ 9 00 ii ~ r~ ~ -r __ _ ~_ , ~_ ~, 1_ ~ } _ O ( ) 1 t -i ~ - -i 9600 Plan 2 D-16AP67 i-- -'-1~ ~ - __ _ Z -3200 D-08 D-08 ~ I I -~ ~ ~_ v r. T 7 ~ ~ ~- ~ 8700 ' ~ I ~ ~ - r r J ~ 3300...- _ -, . 1 ~- _ ~ _ , _t -- ~~ fi ~ 4- - - - ~ I+ ~ ~ + -3400 ~ _ _' ~.. i~ r ~ -3500 ', _ -- --. - ---- - -_ 0-31 (0-31) _ ~ ~ ~_ -- --~~--r-r~--C-~-: F-r--- -1500 -1400 -1300 -1200 -1100 -1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100 200 300 West(-)/East(+) [50ft/in] i WELL DETAILS Nwnc /N/-S AEI-W NoMing F'Ong Latitude Longitude Slat D-1611 W.]5 13]J.2] SYStl]]RW 6534]4W ]0°I ]'19.5]]N 148°45'26.2Y2W 16 ANTI-COLLISION SETTINGS Inmryalalien VlethuLMD InR:rval: SO.W Depth Range t'runt: Y]W.W To: IW65.93 Maximm~i Range: I20?.]X Rufcrcnce: Plan: Plan'_ COMPANY UI "PAILS RP Amucu CWculatiuv Method: Minimum Cwvanuc tirar Sysu:m: ISCWSA Seen Medial: 'fray Cylinder Nanh Ertnr Surface.- Elliptical - Coning Warning Mmhral: RWea Uas.d SURVEY PROGRAM U.ylh Pm U plh Tu Survey/Plwt 9]WW IWfi5.91 Plwmed: Plant Vl W ELI.PA TIi DE'fA1LS TwI Plav 2. U-16APRI SW292W83]0 MWU Puenl We11PaN: DI6 Tie un MU- 9]W.W gig. Ref Uatum: ?9: 161?/]/1981 W:W ]B.Wti V.gection Ongiv Origin Salting atye -w-s -Ir-w hmm TvD I]O.W' O.W O.ql 18.10 LEGEND D-U8 (D-OSA), Major Risk D-16 (D-16), Major Risk ---- D-31A (D31A1, Major Risk D-31 (D31), Major Risk Plan 2, D-16APB1 Plan ? i -113 _120 -128 ..133 14J 150 -15% -165 -1]3 -Itl0 IBtl Travelling Cylinder Auntmh fTtG ~ NI) ldegl vs Centre to CenOe Scpamuon 115[VinJ .W, e~,t~ t4~~.t rvt~Pa~, by r~~r BAKER Nu~NE VTE~ SECT ION UE'rA1LS Svr MU Inc Aii TVU -N/-S *F/-W ULag 'Race VSec Target I 9)WW 20.8] IYI.50 X81].06?965.X4 -05X56 OW OW 2X41.16 9]86.W 20.34 IW.12 88Yt.56 -?9Y5.5] -46424 0.X4 221.tl6 2XfiY.44 3 9%WW 21.Y2 IN].)1 8916.22 -3W2.L9 -465.35 Y00 3lUW 28]6'_6 4 10065 Y3 6fi.45 164.28 YW9W -31]5.14 -43X115 IX.W 3IO.W ]0511.X1 {*~ by ~ BP Alaska +~'' Anticollision Report ~L~ BAKER NLl~iMEB 1NTEQ r - Company: BP Amoco Date: 2/6/2009 Time: 11:31:54 Page: 1 Field: Prudhoe Bay Reference Site: PB D Pad Co-ordinat e(NE) Refe rence: Well: D-16, True North Reference We11: D-16 Ve~ical (T VD) Reference: 29:16 12/7/1981 00: 00 78.6 Reference Wellpath: Plan 2, D-16APB1 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'aeells in thisffluhl~ pal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9700.00 to 10065.9 3 ft Scan Method: Trav Cylinder North Maximum Radius: 1202.78 ft - Error Surface: - Ellipse + Casing -- - Survey Program for Definitive Wellpath Date: 2/5/2009 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 100.00 9700.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multi shot 9700.00 10065.93 Planned: Plan 2 V1 MWD MWD -Standard Casing Points MD TVD Diameter Ho le Size Name ft ft in in 10065.93 9099.00 i 2.875 4.125 2 7/8" 1 _. Summary <----------- Offset Wellpath ---- ------> Reference Offset Ctr-Ctr No-Go Allowable Sate Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB D Pad D-08 D-08A V27 9704.51 10150.00 1037.32 466.31 571.01 Pass: Major Risk PB D Pad D-16 D-16 V4 9775.00 9775.00 0.00 514.89 -514.89 FAIL: Major Risk PB D Pad D-16 Plan 3, D-16A VO Plan: 9850.00 9850.00 0.00 547.85 -547.85 FAIL: Major Risk PB D Pad D-31A D-31A V1 Out of range PB D Pad D-31 D-31 V1 52769.77 9350.00 619.65 1483.62 -863.96 FAIL: Major Risk Site: PB D Pad Well: D-08 Rule Assigned: Major Risk Wellpath: D-08A V27 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Co Allowable MD TVD MD TVD Ref Offset TFO+A ZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9704.51 8821.28 10150.00 9145.89 144.83 92.21 ___ 344.37 , 152.94 - -- 1037.32 466.31 571.01 Pass ~~ 9720.68 8836.39 10175.00 9167.02 144.98 92.21 345.05 153.87 1052.57 463.72 588.85 Pass 9723.93 8839.43 10180.00 9171.24 145.01 92.21 345.18 154.06 1055.63 463.22 592.41 Pass Site: PB D Pad Well: D-16 Rule Assigned: Major Risk Wellpath: D-16 V4 T Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+A ZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft ~~ 9700.00 8817.06 9700.00 8817.06 144.79 144.79 191.50 0.00 7.000 0.00 514.14 -514.14 FAIL !, 9725.00 8840.43 9725.00 8840.43 145.02 145.25 191.11 0.00 7.000 0.00 514.26 -514.26 FAIL 9750.00 8863.83 9750.00 8863.83 145.26 145.70 190.71 0.00 7.000 0.00 514.48 -514.48 FAIL 9775.00 8887.25 9775.00 8887.25 145.49 146.16 190.30 0.00 7.000 0.00 514.89 -514.89 FAIL 9800.00 8910.64 9800.00 8910.69 145.59 146.61 345.46 157.06 7.000 0.16 400.33 -400.17 FAIL ~ 9824.90 8933.56 9825.00 8934.17 145.46 146.91 342.50 158.83 7.000 1.57 434.88 -433.31 FAIL ', 9849.42 8955.41 9850.00 8957.70 145.08 146.96 340.78 161.15 7.000 5.00 449.16 -444.16 FAIL 9873.25 8975.85 9875.00 8981.29 144.50 146.80 339.84 163.25 7.000 10.44 450.63 -440.19 FAIL 9896.14 8994.63 9900.00 9004.92 143.74 146.46 339.16 164.93 7.000 17.77 446.53 -428.76 FAIL 9917.93 9011.64 9925.00 9028.57 142.86 145.98 338.52 166.17 7.000 26.81 440.34 -413.53 FAIL 9938.53 9026.86 9950.00 9052.21 141.89 145.40 337.87 167.05 7.000 37.35 433.06 -395.71 FAIL 9957.88 9040.34 9975.00 9075.84 140.88 144.76 337.26 167.70 7.000 49.27 424.60 -375.33 FAIL 9975.97 9052.19 10000.00 9099.45 139.87 144.11 336.69 168.20 7.000 62.44 415.28 -352.84 FAIL 9992.79 9062.52 10025.00 9123.08 138.84 143.46 336.20 168.61 7.000 76.76 404.46 -327.70 FAIL 10008.38 9071.47 10050.00 9146.72 137.86 142.83 335.78 168.97 7.000 92.13 393.03 -300.90 FAIL ~ 10022.79 9079.19 10075.00 9170.39 136.93 142.25 335.42 169.29 7.000 108.44 381.38 -272.94 FAIL 10036.10 9085.84 10100.00 9194.07 136.04 141.72 335.10 169.57 7.000 125.60 369.39 -243.79 FAIL b BP Alaska ~ ~ ~~'~ MUGF~S y '~'~ Antlcollision Report INTE Q Company: BP Amoco ~ pate: 2/6/2009 Time: 11:31:54 Page: 2 Field: Prudhoe Bay Reference Site: PB D Pad Co-ordinate(NE) Reference: Well: D-16, True North Reference Well: D-16 Vertical (1'VD) Reference: 29:16 12/7!1981 00:00 78.6 Reference Wellpath: Plan 2 D-16AP61 Db: OraGe Site: PB D Pad Well: D-16 Rule Assigned: Major Risk Wellpath: D-16 V4 -- - Inter-Site Error: - 0.00 ft i Reference Offset Semi-1kIajor Ads Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft j 10048.32 9091.53 10125.00 9217.81 135.22 141.23 334.82 169.81 7.000 143.56 357.85 -214.28 FAIL 10059.48 9096.36 10150.00 9241.63 134.47 140.81 334.58 170.04 7.000 162.33 346.41 -184.08 FAIL Site: PB D Pad Well: D-16 Rule Assigned: Major Risk Wellpath: Plan 3, D- 16A VO Plan: Plan 3 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Avis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9700.00 8817.06 9700.00 8817.06 144.79 143.87 191.50 0.00 4.125 0.00 513.75 -513.75 FAIL 9725.00 8840.43 9725.00 8840.43 145.02 143.88 191.11 0.00 4.125 0.00 513.71 -513.71 FAIL 9750.00 8863.83 9750.00 8863.83 145.26 143.88 190.71 0.00 4.125 0.00 513.82 -513.82 FAIL 9775.00 8887.25 9775.00 8887.25 145.49 143.88 190.30 0.00 4.125 0.00 514.09 -514.09 FAIL 9800.00 8910.64 9800.00 8910.64 145.59 143.88 188.40 0.00 4.125 0.00 515.01 -515.01 FAIL 9825.00 8933.65 9825.00 8933.65 145.46 143.75 183.65 0.00 4.125 0.00 529.77 -529.77 FAIL 9850.00 8955.92 9850.00 8955.93 145.07 143.38 179.55 0.00 4.125 0.00 547.85 -547.85 FAIL 9874.98 8977.30 9875.00 8976.62 144.46 142.77 195.59 19.20 4.125 1.33 183.74 -182.42 FAIL 9899.84 8997.58 9900.00 8994.57 143.62 141.95 194.86 20.97 4.125 5.30 186.48 -181.18 FAIL 9924.45 9016.55 9925.00 9009.23 142.58 140.93 194.00 22.16 4.125 11.87 189.39 -177.52 FAIL 9948.69 9034.04 9950.00 9020.17 141.39 139.75 193.01 22.87 4.125 20.97 192.11 -171.14 FAIL 9972.43 9049.93 9975.00 9027.04 140.07 138.46 191.87 23.18 4.125 32.49 194.55 -162.06 FAIL 9995.51 9064.12 10000.00 9029.63 138.67 137.08 190.61 23.16 4.125 46.32 196.62 -150.30 FAIL 10018.66 9077.03 10025.00 9029.08 137.19 135.62 189.27 22.96 4.125 61.33 199.65 -138.32 FAIL 10043.24 9089.21 10050.00 9027.09 135.56 134.01 187.94 22.72 4.125 75.96 205.79 -129.83 FAIL 10043.27 9089.23 11400.00 8975.71 135.56 134.21 85.24 280.02 4.125 735.86 843.68 -107.83 FAIL 9924.54 9016.62 11425.00 8977.69 142.58 141.11 86.43 274.59 4.125 730.40 875.98 -145.57 FAIL 9863.69 8967.76 11450.00 8979.53 144.74 143.25 85.93 268.21 4.125 725.18 880.58 -155.40 FAIL 9828.36 8936.69 11475.00 8981.23 145.40 143.89 84.78 261.75 4.125 721.32 877.03 -155.71 FAIL 9805.62 8915.86 11500.00 8982.77 145.58 144.05 83.30 255.55 4.125 719.24 870.28 -151.05 FAIL 9795.69 8906.62 11525.00 8984.16 145.59 144.06 81.48 252.57 4.125 719.12 862.15 -143.03 FAIL 9786.32 8897.86 11550.00 8985.39 145.59 144.06 79.66 249.58 4.125 721.05 853.04 -131.99 FAIL 9777.97 8890.04 11575.00 8986.45 145.52 144.07 77.81 247.56 4.125 725.00 843.03 -118.03 FAIL 9769.36 8881.97 11600.00 8987.35 145.44 144.07 76.01 245.62 4.125 730.93 832.47 -101.53 FAIL 9760.47 8873.64 11625.00 8988.09 145.35 144.07 74.28 243.74 4.125 738.77 821.54 -82.77 FAIL 9751.32 8865.06 11650.00 8988.65 145.27 144.07 72.63 241.94 4.125 748.43 810.45 -62.02 FAIL 9741.68 8856.04 11675.00 8988.81 145.18 144.08 71.04 240.20 4.125 758.91 799.18 -40.27 FAIL 9731.23 8846.26 11700.00 8988.22 145.08 144.10 69.48 238.47 4.125 768.87 787.53 -18.66 FAIL 9720.00 8835.76 11725.00 8986.87 144.98 144.12 67.94 236.76 4.125 778.28 775.51 2.77 Pass 9708.02 8824.56 11750.00 8984.79 144.87 144.14 66.43 235.06 4.125 787.09 763.15 23.94 Pass Site: PB D Pad Well: D-31 Rule Assigned: Major Risk Wellpath: D-31 V1 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZ I TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 52769.77 8816.73 9350.00 8674.92 544.96 32.53 240.86 49.35 7.000 619.651483.62 -863.96 FAIL 9719.31 8835.11 9375.00 8691.26 144.97 32.77 240.56 49.36 7.000 632.14 420.17 211.97 Pass 9738.85 8853.40 9400.00 8707.50 145.15 33.01 240.26 49.38 7.000 644.78 419.24 225.53 Pass 9758.19 8871.50 9425.00 8723.49 145.33 33.25 239.96 49.38 7.000 657.68 418.26 239.42 Pass 9777.18 8889.29 9450.00 8739.03 145.51 33.50 239.64 49.37 7.000 671.08 417.21 253.88 Pass 9799.34 8910.02 9475.00 8753.93 145.59 33.66 239.22 50.75 7.000 685.14 416.03 269.11 Pass 9828.07 8936.42 9500.00 8768.08 145.41 33.45 238.55 55.46 7.000 699.73 415.71 284.02 Pass -r..r ~' BP Alaska ~-~ER ~ by Anticollision Re ort it~u~~s P INTEQ - Company: BP Amoco ---- Date: 2/6/2009 Time: 11:31:54 Page: 3 Field: Prudhoe Bay ~ Reference S ite: PB D Pad Go-ordinate(NE) Refe rence: Well: D-1 6, True North Reference Well: D-16 Vertical (1'VD) Reference: 29:16 12/7/1981 00 :00 78.6 ~ Reference Wellpath: Plan 2, D-16APB1 Db: Oracle Site: PB D Pad Well: D-31 Rule Assigned: Major Risk Wellpath: D-31 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Albwable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg' deg in ft ft ft 9858.25 8963.09 9525.00 8781.38 144.87 32.96 237.91 59.49 7.000 714.83 416.45 298.38 Pass 9888.30 8988.30 9550.00 8793.83 144.01 32.28 237.38 62.40 7.000 730.43 418.15 312.28 Pass '~ 9917.88 9011.60 9575.00 8805.49 142.86 31.42 236.97 64.61 7.000 746.45 420.81 325.64 Pass 9946.68 9032.63 9600.00 8816.42 141.49 30.44 236.65 66.38 7.000 762.85 424.30 338.55 Pass ~ 9974.79 9051.44 9625.00 8826.99 139.94 29.36 236.42 67.86 7.000 779.31 428.48 350.83 Pass ~, 10001.99 9067.88 9650.00 8837.31 138.27 28.23 236.27 69.15 7.000 795.75 433.23 362.52 Pass 10028.04 9081.87 9675.00 8847.39 136.58 27.12 236.20 70.31 7.000 812.21 438.20 374.01 Pass 10052.73 9093.48 9700.00 8857.21 134.93 26.06 236.19 71.36 7.000 828.73 443.16 385.57 Pass L~'~- ~ BP Alaska by `'~+~' Baker Hughes INTEQ Planning Report r~~~ BAKER Nut~~s INTEQ Company: BP Amoco Date: 2/6/2009 Time: 10:46:32 Page: 1 Field: Prudhoe Bay Co-ordioate(NE) Reference: Well: D-16, True North Site: PB D Pad Vertical (T'VD) Reference: 29 :16 12!7/1981 00:00 78.6 Well: D-16 ,., ,q LY., Section(VS}Reference: Well (O.OON,O.OOE,45.OOAzi) Wellpath: Plan v- ° ~'~ Survey Calculation Method: Mi nimum Curvature - _ Db: Oracle - - -- Field: -- _ _ _ ---- ~ North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level _ Geomagnetic Model: bggm2007 _ _ _ Srte: PB D Pad TR-11-13 UNITED STATES :North Sl ope Site Position: Northing: 5955590. 34 ft Latitude: 70 17 8.492 N From: Map Easting: 652165. 06 ft Longitude: 148 46 6.316 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.16 deg !r Well: D-16 Slot Name: 16 D-16 Well Position: +N/-S 3160.75 ft Northing: 5958778. 00 ft Latitude: 70 17 39.577 N +E/-W 1373.27 ft Easting : 653474. 00 ft Longitude: 148 45 26.292 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, D-16A Drilled From: Plan 2, D-16AP61 1 500292068301 Tie-on Depth: 9806.00 ft Current Datum: 29:16 12/7/1981 00:00 Height 78. 60 ft Above System Datum: Mean Sea Level Magnetic Data: 4/9/2009 Declination: 22.73 deg Field Strength: 57703 nT Mag Dip Angle: 80.90 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 38.10 0.00 0.00 45.00 Plan: Plan 3 Date Composed: 2/5/2009 ~ Client's Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <-- Latitude -> <--- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft D-16A Ploygon 78.60 -3767.81 -551.08 5955000.00 653000.00 70 17 2.520 N 148 45 42.345 W -Polygon 1 78.60 -3767.81 -551.08 5955000.00 653000.00 70 17 2.520 N 148 45 42.345 W -Polygon 2 78.60 -3791.30 598.76 5955000.00 654150.00 70 17 2.289 N 148 45 8.850 W -Polygon 3 78.60 -2491.47 625.31 5956300.00 654150.00 70 17 15.073 N 148 45 8:074 W -Polygon 4 78.60 -2475.65 -149.59 5956300.00 653375.00 70 17 15.229 N 148 45 30.650 W -Polygon 5 78.60 -2883.96 -237.95 5955890.00 653295.00 70 17 11.213 N 148 45 33.224 W -Polygon 6 78.60 -3328.48 -512.10 5955440.00 653030.00 70 17 6.841 N 148 45 41.211 W D-16A Fault 1 78.60 -3428.07 -44.00 5955350.00 653500.00 70 17 5.862 N 148 45 27.574 W -Polygon 1 78.60 -3428.07 -44.00 5955350.00 653500.00 70 17 5.862 N 148 45 27.574 W -Polygon 2 78.60 -3648.04 -48.49 5955130.00 653500.00 70 17 3.698 N 148 45 27.705 W -Polygon 3 78.60 -3864.54 22.11 5954915.00 653575.00 70 17 1.569 N 148 45 25.648 W -Polygon 4 78.60 -3648.04 -48.49 5955130.00 653500.00 70 17 3.698 N 148 45 27.705 W i D-16A Fault 2 78.60 -3291.22 -671.38 5955474.00 652870.00 70 17 7.207 N 148 45 45.851 W -Polygon 1 78.60 -3291.22 -671.38 5955474.00 652870.00 70 17 7.207 N 148 45 45.851 W -Polygon 2 78.60 -2397.94 -183.01 5956377.00 653340.00 70 17 15.993 N 148 45 31.624 W -Polygon 3 78.60 -2065.19 -166.21 5956710.00 653350.00 70 17 19.266 N 148 45 31.135 W -Polygon 4 78.60 -2397.94 -183.01 5956377.00 653340.00 70 17 15.993 N 148 45 31.624 W D-16A Fault 3 78.60 -2065.19 -166.21 5956710.00 653350.00 70 17 19.266 N 148 45 31.135 W -Polygon 1 78.60 -2065.19 -166.21 5956710.00 653350.00 70 17 19.266 N 148 45 31.135 W -Polygon 2 78.60 -2049.38 284.24 5956735.00 653800.00 70 17 19.421 N 148 45 18.010 W -Polygon 3 78.60 -1877.70 693.86 5956915.00 654206.00 70 17 21.109 N 148 45 6.075 W -Polygon 4 78.60 -2049.38 284.24 5956735.00 653800.00 70 17 19.421 N 148 45 18.010 W ~ D-16A Target 3 8942.60 -3556.15 -139.64 5955220.00 653407.00 70 17 4.602 N 148 45 30.360 W ,,.•.-:. by ~ BP Alaska ~'*+~ Baker Hughes INTEQ Planning Report rr.~~ BANV R~iNES 1NTEQ Company: BP Amoco Date: 2/6!2009 Time: 10:46:32 Page: 2 Field: Prudhoe Bay Co-or dinate(NE)Reference: Well: D-16, True North Site: PB D Pad Vertical (TVD) Reference: 29 :16 12/7/1981 00:00 78.6 Well: D-16 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Wellpath: Plan 3, D-1 6A Survey Calculation Method: Min imum Curvature Db: Oracle Targets -- Map Map <_-_ Latitude ---> <-- Longitude --> , Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ', Dip. Dir. ft ft ft ft ft - - ' -- ~ D-16A Target 4 i 8949.60 -3450.62 178.60 _ 5955332.00 653723.00 70 17 5.640 N 148 45 21.089 W D-16A Target 5 i 8968.60 -3121.99 299.35 5955663.00 653837.00 70 17 8.872 N 148 45 17.571 W D-16A Target 7 8972.60 -2522.68 243.57 5956261.00 653769.00 70 17 14.766 N 148 45 19.196 W ~,~ D-16A Target 6 8987.60 -2769.77 244.52 5956014.00 653775.00 70 17 12.336 N 148 45 19.168 W ~, D-16A Target 2 8988.60 -3380.70 -404.14 5955390.00 653139.00 70 17 6.328 N 148 45 38.065 W D-16A Target 1 9027.60 -3151.35 -467.47 5955618.00 653071.00 70 17 8.583 N 148 45 39.911 W I~ 1 Annotation MD TVD ft ft 9806.00 8916.22 TIP 9850.00 8955.93 KOP 10002.42 9029.66 End of 40 deg / 100 ft DLS 10092.42 9020.52 4 10492.42 8953.64 5 10692.42 8943.17 6 10992.42 8952.61 7 i 11292.42 8969.03 End of 15 deg / 100 ft DLS 11402.42 8975.91 9 11652.42 8988.70 10 111802.42 8978.02 11 11872.42 8971.94 12 ' 11912.00 8971.40 TD _____ __~ Plan Section Information _ _ _ _ ____ __ _ ____ - -- MD Inc! Azim - TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft degl100ft deg/100ft deg ' I 9806.00 21.92 187.71 8916.22 -3002.69 -465.35 0.00 0.00 0.00 0.00 ~ 9850.00 29.03 179.55 8955.93 -3021.53 -466.37 17.99 16.17 -18.54 330.00 10002.42 90.00 179.55 9029.66 -3146.77 -465.39 40.00 40.00 0.00 0.00 110092.42 101.66 172.71 9020.52 -3235.90 -459.41 15.00 12.96 -7.61 330.00 10492.42 95.80 112.19 8953.64 -3532.99 -228.83 15.00 -1.47 -15.13 270.00 10692.42 90.07 82.69 8943.17 -3558.43 -33.03 15.00 -2.87 -14.75 260.00 10992.42 86.51 37.80 8952.61 -3413.52 220.70 15.00 -1.18 -14.96 265.00 11292.42 87.54 352.75 8969.03 -3131.93 297.55 15.00 0.34 -15.02 270.00 11402.42 85.33 339.71 8975.91 -3025.54 271.49 12.00 -2.01 -11.85 260.00 11652.42 88.94 9.53 8988.70 -2779.79 248.47 12.00 1.45 11.93 84.00 ~ 11802.42 99.19 354.68 8978.02 -2630.89 254.07 12.00 6.83 -9.91 305.00 11872.42 90.79 354.68 8971.94 -2561.52 247.60 12.00 -12.00 0.00 180.00 11912.00 90.78 349.93 8971.40 -2522.31 242.30 12.00 -0.01 -12.00 270.00 ; by ~ BP Alaska ~ ~ '~*~` Baker Hughes INTEQ Planning Report 1NTEQ ~:_- Company: BP Amoco - __ - -- -- Date::. _-_ 2/6!2009 __ Time: 10:46:32 ,_ _ -_ Page: T - 3 Field: Prudhoe Bay Co-ordinsfe(NE) Reference: Well: D-16, True North Site: PB D Pad Verticai (TVD) Reference: 29:1 6 12/7/1981 00:00 78.6 ' Well: D-16 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Weilpath: Plan 3, D-16A Survey Calculation Method: Minimum Curva ture Db: Oracle Survey _ _ - MD Inc! Azim SS TVD N/S -_ E/W MapN MapE DLS VS TFO Tool ~ ft deg deg ft ft ft ft ft deg/100ft ft deg 9806 .00 21.92 187.71 8837.62 -3002.69 -465.35 5955766.66 653070.08 0.00 -2452.28 0.00 MWD 9825 .00 24.93 183.65 8855.05 -3010.20 -466.08 5955759.13 653069.51 17.99 -2458.10 330.00 MWD 9834 .94 26.55 181.88 8864.00 -3014.51 -466.29 5955754.82 653069.39 17.99 -2461.30 333.72 D-16A 9842 .81 27.84 180.62 8871.00 -3018.11 -466.37 5955751.22 653069.38 17.99 -2463.90 335.32 D-16A 9850 .00 29.03 179.55 8877.33 -3021.53 -466.37 5955747.80 653069.45 17.99 -2466.32 336.44 MWD 9860 .00 33.03 179.55 8885.89 -3026.69 -466.33 5955742.65 653069.59 40.00 -2469.94 0.00 MWD 9864 .96 35.01 179.55 8890.00 -3029.46 -466.31 5955739.88 653069.67 40.00 -2471.88 0.00 D-16A T 9869 .90 36.99 179.55 8894.00 -3032.36 -466.29 5955736.97 653069.76 40.00 -2473.92 360.00 D-16A 9870 .00 37.03 179.55 8894.08 -3032.42 -466.29 5955736.91 653069.76 40.00 -2473.96 0.00 MWD 9880 .00 41.03 179.55 8901.85 -3038.72 X66.24 5955730.62 653069.93 40.00 -2478.38 0.00 MWD 9889 .78 44.94 179.55 8909.00 -3045.39 -466.18 5955723.95 653070.12 40.00 -2483.06 0.00 D-16A 9890 .00 45.03 179.55 8909.15 -3045.54 -466.18 5955723.80 653070.13 40.00 -2483.16 360.00 MWD 9891 .20 45.51 179.55 8910.00 -3046.40 -466.18 5955722.95 653070.15 40.00 -2483.76 360.00 0-16A 9900 .00 49.03 179.55 8915.97 -3052.86 -466.13 5955716.49 653070.33 40.00 -2488.30 0.00 MWD 9910 .00 53.03 179.55 8922.26 -3060.63 -466.06 5955708.72 653070.55 40.00 -2493.75 0.00 MWD 9920 .00 57.03 179.55 8927.99 -3068.82 -466.00 5955700.53 653070.79 40.00 -2499.50 0.00 MWD 9930 .00 61.03 179.55 8933.13 -3077.40 -465.93 5955691.96 653071.03 40.00 -2505.51 0.00 MWD 9940 .00 65.03 179.55 8937.67 -3086.31 -465.86 5955683.05 653071.28 40.00 -2511.76 0.00 MWD ~i 9950 .00 69.03 179.55 8941.57 -3095.51 -465.79 5955673.85 653071.54 40.00 -2518.22 0.00 MWD 9960 .00 73.03 179.55 8944.82 -3104.97 -465.72 5955664.40 653071.81 40.00 -2524.85 0.00 MWD I 9970 .00 77.03 179.55 8947.40 -3114.62 -465.64 5955654.75 653072.08 40.00 -2531.63 0.00 MWD 9980 .00 81.03 179.55 8949.30 -3124.44 -465.56 5955644.94 653072.36 40.00 -2538.51 0.00 MWD I 9990 .00 85.03 179.55 8950.52 -3134.36 -465.49 5955635.02 653072.64 40.00 -2545.48 0.00 MWD ~I 10000 .00 89.03 179.55 8951.03 -3144.35 -465.41 5955625.04 653072.92 40.00 -2552.48 0.00 MWD ', 10002 .42 90.00 179.55 8951.06 -3146.77 -465.39 5955622.61 653072.99 40.00 -2554.18 0.00 MWD 10025 .00 92.93 177.86 8950.48 -3169.33 -464.88 5955600.07 653073.96 15.00 -2569.77 330.00 MWD i 10050 .00 96.18 175.97 8948.49 -3194.21 -463.54 5955575.23 653075.81 15.00 -2586.42 329.96 MWD ' 10075 .00 99.41 174.06 8945.10 -3218.88 -461.38 5955550.61 653078.46 15.00 -2602.34 329.81 MWD 10092 .42 101.66 172.71 8941.92 -3235.90 -459.41 5955533.64 653080.78 15.00 -2612.98 329.55 MWD 10100 I .00 101.66 171.54 8940.38 -3243.25 -458.39 5955526.31 653081.95 15.00 -2617.45 270.00 I MWD 10125 .00 101.62 167.72 8935.34 -3267.33 -453.99 5955502.33 653086.85 15.00 -2631.37 269.77 MWD ~ 10150 .00 101.53 163.89 8930.32 -3291.06 -447.98 5955478.72 653093.34 15.00 -2643.91 268.99 MWD 10175 .00 101.39 160.07 8925.35 -3314.36 -440.40 5955455.58 653101.39 15.00 -2655.02 268.22. MWD 10200 .00 101.20 156.25 8920.45 -3337.11 -431.28 5955433.02 653110.97 15.00 -2664.66 267.46 MWD 10225 .00 100.96 152.43 8915.65 -3359.22 -420.66 5955411.14 653122.04 15.00 -2672.78 266.72 MWD 10250. 00 100.67 148.63 8910.95 -3380.59 -408.58 5955390.02 653134.55 15.00 -2679.35 265.98 MWD 10275. 00 100.34 144.83 8906.39 -3401.14 -395.10 5955369.75 653148.45 15.00 -2684.35 265.27 MWD '. 10300. 00 99.96 141.04 8901.99 -3420.77 -380.27 5955350.43 653163.68 15.00 -2687.74 264.58 MWD 10325. 00 99.55 137.26 8897.75 -3439.41 -364.15 5955332.13 653180.17 15.00 -2689.52 263.91 MWD 10350. 00 99.09 133.48 8893.70 -3456.96 -346.83 5955314.93 653197.85 15.00 -2689.68 263.27 MWD 10375. 00 98.59 129.72 8889.86 -3473.36 -328.36 5955298.92 653216.65 15.00 -2688.22 262.66 MWD 10400. 00 98.05 125.97 8886.24 -3488.53 -308.83 5955284.15 653236.48 15.00 -2685.14 262.08 MWD 10425. 00 97.48 122.23 8882.86 -3502.42 -288.32 5955270.68 653257.27 15.00 -2680.45 261.53 MWD i i 10450. 00 96.88 118.50 8879.73 -3514.95 -266.92 5955258.59 653278.92 15.00 -2674.19 261.03 MWD 10475. 00 96.26 114.78 8876.87 -3526.09 -244.73 5955247.91 653301.33 15.00 -2666.37 260.56 MWD ! ~~ 10492. 42 95.80 112.19 8875.04 -3532.99 -228.83 5955241.33 653317.36 15.00 -2660.01 260.14 , MWD ~ 10500. 00 95.60 111.07 8874.29 -3535.77 -221.83 5955238.70 653324.42 15.00 -2657.02 260.00 MWD ~ 10525. 00 94.93 107.36 8871.99 -3543.96 -198.32 5955230.99 653348.09 15.00 -2646.19 259.89 MWD 10550. 00 94.24 103.66 8869.99 -3550.62 -174.32 5955224.82 653372.22 15.00 -2633.93 259.55 MWD I 10575. i 00 93.54 99.97 8868.29 -3555.73 -149.91 5955220.21 653396.73 15.00 -2620.28 259.25 MWD 10600. 00 92.81 96.29 8866.91 -3559.26 -125.20 5955217.19 653421.50 15.00 -2605.30 259.00 MWD 10625. 00 92.08 92.60 8865.84 -3561.19 -100.30 5955215.76 653446.43 15.00 -2589.07 258.80 MWD 10650. 00 91.34 88.93 8865.09 -3561.53 -75.32 5955215.94 653471.42 15.00 -2571.64 258.64 MWD ~,, Ott by ~ BP Alaska sN~~Es +~~` Baker Hughes INTEQ Planning Report INTE Q Company: BP Amoco Date: 2/6/2009 Time: 10:46:32 Page: 4 Field: Pru dhoe Bay ~ Co-ord inate(NE) Reference: Well: D-16, True North ~ Site: PB D Pad Vertical (TVD) Reference: 29: 16 12/711981 00:00 78.6 Well: D-1 6 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Wellpath: Pla n 3, D-16A Survey Calculation Metho d: Minimum Curva ture Db: OraGe i Survev -_ _ MD __ Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Toot ft deg deg ft ft ft ft ft deg/100ft ft deg 10675.00 90.59 85.25 8864.67 -3560.26 -50.36 5955217.72 653496.34 15.00 -2553.09 258.53 MWD ~ 10692.42 90.07 82.69 8864.57 -3558.43 -33.03 5955219.90 653513.63 15.00 -2539.55 258.47 MWD ~ 10700.00 89.97 81.56 8864.57 -3557.39 -25.53 5955221.09 653521.11 15.00 -2533.51 265.00 MWD ' 10725.00 89.64 77.82 8864.66 -3552.92 -0.94 5955226.07 653545.60 15.00 -2512.95 265.00 MWD 10750.00 89.32 74.09 8864.88 -3546.85 23.31 5955232.62 653569.72 15.00 -2491.52 265.01 MWD 10775.00 88.99 70.35 8865.25 -3539.22 47.11 5955240.74 653593.35 15.00 -2469.29 265.05 MWD 10800.00 88.68 66.61 8865.76 -3530.05 70.36 5955250.38 653616.41 15.00 -2446.37 265.10 MWD 10825.00 88.36 62.88 8866.41 -3519.39 92.96 5955261.50 653638.78 15.00 -2422.86 265.18 MWD 10850.00 88.06 59.14 8867.19 -3507.28 114.81 5955274.05 653660.38 15.00 -2398.84 265.27 MWD 10875.00 87.76 55.40 8868.10 -3493.77 135.82 5955287.98 653681.11 15.00 -2374.43 265.39 MWD 10900.00 87.47 51.65 8869.14 -3478.93 155.90 5955303.24 653700.89 15.00 -2349.73 265.53 MWD 10925.00 87.20 47.91 8870.30 -3462.81 174.97 5955319.74 653719.62 15.00 -2324.85 265.68 MWD 10950.00 86.93 44.16 8871.58 -3445.48 192.94 5955337.43 653737.23 15.00 -2299.89 265.86 MWD 10975.00 86.68 40.42 8872.98 -3427.02 209.73 5955356.23 653753.64 15.00 -2274.97 266.05 MWD 10992.42 86.51 37.80 8874.01 -3413.52 220.70 5955369.95 653764.33 15.00 -2257.66 266.26 MWD 11000.00 86.51 36.67 8874.47 -3407.50 225.27 5955376.06 653768.78 15.00 -2250.17 270.00 MWD 11025.00 86.53 32.91 8875.99 -3387.01 239.51 5955396.84 653782.59 15.00 -2225.62 270.07 MWD j 11050.00 86.55 29.15 8877.50 -3365.63 252.37 5955418.47 653795.01 15.00 -2201.41 270.30 MWD 11075.00 86.60 25.39 8878.99 -3343.45 263.80 5955440.88 653805.99 15.00 -2177.64 270.52 MWD 11100.00 86.65 21.64 8880.47 -3320.57 273.76 5955463.95 653815.48 15.00 -2154.42 270.75 MWD i 11125.00 86.72 17.88 8881.91 -3297.09 282.20 5955487.60 653823.43 15.00 -2131.85 270.97 MWD 11150.00 86.81 14.13 8883.32 -3273.10 289.08 5955511.72 653829.82 15.00 -2110.02 271.19 MWD 11175.00 86.91 10.37 8884.69 -3248.71 294.37 5955536.21 653834.62 15.00 -2089.03 271.40 MWD I 11200.00 87.02 6.62 8886.02 -3224.02 298.06 5955560.97 653837.80 15.00 -2068.97 271.61 MWD 11225.00 87.14 2.87 8887.29 -3199.15 300.13 5955585.88 653839.36 15.00 -2049.92 271.80 MWD i ~ 11250.00 87.28 359.12 8888.51 -3174.18 300.56 5955610.85 653839.28 15.00 -2031.96 272.00 MWD i ' 11275.00 87.43 355.36 8889.67 -3149.24 299.36 5955635.75 653837.57 15.00 -2015.18 272.18 MWD , i 11292.42 87.54 352.75 8890.43 -3131.93 297.55 5955653.03 653835.41 15.00 -2004.21 272.35 MWD '~i 11300.00 87.38 351.85 8890.77 -3124.43 296.54 5955660.50 653834.25 12.00 -1999.62 260.00 MWD j 11325.00 86.86 348.90 8892.03 -3099.82 292.37 5955685.02 653829.57 12.00 -1985.17 260.04 MWD ~, 11350.00 86.36 345.93 8893.50 -3075.46 286.93 5955709.26 653823.64 12.00 -197:1.79 260.19 MWD 11375.00 85.86 342.97 8895.20 -3051.44 280.24 5955733.14 653816.46 12.00 -1959.53 260.36 MWD 11402.42 85.33 339.71 8897.31 -3025.54 271.49 5955758.86 653807.19 12.00 -1947.40 260.57 MWD 11425.00 85.61 342.41 8899.09 -3004.25 264.19 5955779.99 653799.45 12.00 -1937.51 84.00 MWD 11450.00 85.95 345.40 8900.93 -2980.30 257.28 5955803.79 653792.06 12.00 -1925.46 83.79 MWD 11475.00 86.29 348.39 8902.63 -2956.01 251.63 5955827.96 653785.91 12.00 -1912.29 83.57 MWD 11500.00 86.64 351.37 8904.17 -2931.45 247.24 5955852.43 653781.02 12.00 -1898.02 83.36 MWD 11525.00 87.00 354.36 8905.56 -2906.68 244.15 5955877.12 653777.42 12.00 -1882.70 83.18 MWD j 11550.00 87.37 357.34 8906.79 -2881.78 242.34 5955901.98 653775.11 12.00 -1866.37 83.01 MWD 11575.00 87.74 0.32 8907.85 -2856.81 241.83 5955926.93 653774.08 12.00 -1849.07 82.87 MWD I 11600.00 88.13 3.29 8908.75 -2831.84 242.61 5955951.91 653774.36 12.00 -1830.86 82.74 MWD i 11625.00 88.51 6.27 8909.49 -2806.94 244.70 5955976.84 653775.94 12.00 -1811.78 82.63 MWD 11652.42 88.94 9.53 8910.10 -2779.79 248.47 5956004.07 653779.15 12.00 -1789.91 82.55 MWD 11675.00 90.50 7.32 8910.21 -2757.46 251.77 5956026.46 653782.00 12.00 -1771.79 305.00 MWD 11700.00 92.22 4.86 8909.62 -2732.61 254.42 5956051.35 653784.14 12.00 -1752.34 305.01 MWD ': 11725.00 93.93 2.39 8908.27 -2707.70 256.00 5956076.29 653785.21 12.00 -1733.61 304.95 MWD i I 11750.00 95.64 359.92 8906.19 -2682.79 256.51 5956101.20 653785.21 12.00 -1715.64 304.82 MWD 11775.00 97.34 357.43 8903.36 -2657.96 255.93 5956126.01 653784.13 12.00 -1698.49 304.61 MWD !, 11802.42 99.19 354.68 8899.42 -2630.89 254.07 5956153.04 653781.71 12.00 -1680.67 304.33 MWD ~ 11825.00 96.48 354.68 8896.34 -2608.63 251.99 5956175.25 653779.18 12.00 -1666.39 180.00 MWD 11850.00 93.48 354.68 8894.18 -2583.83 249.68 5956200.00 653776.36 12.00 -1650.49 180.00 MWD ' 11872.42 ~_ 90.79 354.68 8893.34 -2561.52 247.60 5956222.26 653773.83 12.00 -1636.19 180.00 MWD "~ by ~' BP Alaska ~"#*~' Baker Hughes INTEQ Planning Report 1NTEQ `Company: BP Amoco Date: 2!6!2009 Timc: 10:46:32 Page: 5 Field: Prudhoe Bay Corordinate(NE) Reference: Well: D-16, True North Site: PB D Pad Vertical (TVD) Reference: 29:16 12/7/1981 00:00 78.6 Well: D-16 Section (VS) Reference: Well (O.OON,O.OOE,45.OOAzi) Wetlpath: Plan 3, D-16A Survey Calculation Method: Minimum Curvature _ __ - Db: Oracle -_ Survey MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft degl100ft ft deg ~ 11875.00 90.79 354.37 8893.31 -2558.96 247.36 5956224.81 653773.53 12.00 -1634.55 270.00 MWD 11900.00 90.79 351.37 8892.96 -2534.16 244.25 5956249.55 653769.92 12.00 -1619.20 270.00 MWD 11912.00 90.78 349.93 8892.80 -2522.31 242.30 5956261.35 653767.73 12.00 -1612.21 269.95 MWD BP Alaska sooip'ze'snm ~., o-tppnt n~ ~~io: iue.oo IIIp: MI. O~Wn: 3p:1p1NHpIt W:W ]p.pON LEGEND - D-ifi (D-16) -- D-ifi (Plan 2, D-i6APB1) p.~ Plan 3, D-16A Plan 3 ~ o ~ ~'ar Umaq inlamalwn. e m.o. nn.~.e~i.~~~en.~ ~_ 'E 6 Y O S~ L; p7 Y 2 LEGEND _ T qa~. v;~~ a 1o-16m;fi~ 3, o-15n1 B P A I a s ka - A_O6 (A_O6) ~' ~ M nzmmrs W T,u6 Nonn c ~'m~ee BP om. z s~z9o9 - o-oa (D-oa) BAKER Ma9reik NOM 23]3° - D-08 (D-08A) u M.9~xr F~91a x°~'e...^. oa~e. w6w6rx D6ruu D-12 D-12) ^~~~ ~ 5oq~ge~eo so c ~ So9'ie2zoolsio+ D-16 (D-16) N ~°~ ~~~] ~~ ~~ wm PNOB OOD-18Y81 D-16 (Plan 2, D-16AP8 NTE-•Cl ,,,~ - - D31A (D-31A) xw. D.19~.: 29.1fi 12nn991 aaAO 7e.9on D31 (D-31) - A~fa~ od~~ or1~~ '9~e~lieo Plan 3, D-16A - Plan 3 65AO• o.m D.oo aa.1o REFERENCE INFORMATION Co-ordinate N/E)) Reference: Well CenVe: D-1 fi, True North Vexical (4VD) Reference: 29:16 12/7/1981 00:00 76.60 Section (VS) Reference: Slot - 16 (O.OON O.OOE) Measured Depth Reference: 29: i6 12/7/1981 00.00 78.60 Calculation Method: Minimum Curvature secnox Dcruu ro me w rw 1w.9 .Fi.w D~.9 n6~. vs6o >.r9.1 980fi.00 0].92 187.T1 891633 - 2.89 -.BS.aS a.00 0.00 316225 9850.00 29.0] 1 0955.9) ~3021.Sa efie.a7 17.98 230.00 -2188.]3 10003.12 BOAO 179.55 9039.66 ~]t6fi.17 M5.]9 10.00 OAO 3551.18 10093.13 101.88 172.)'1 32]5.90 -669A1 15.00 ]]0.00 -3612.98 10692.12 BSAO 112.19 S].fi6 -a3]3.99 -328A] 15.00 2]0.00 3880.01 10892.1] 80.07 83.68 963.1) .]SSB.II 3].0] 18.00 280.00 3539.55 1089112 88.81 ]].80 8952.81 -]611.82 320.70 15.00 385.00 328).88 t 1393.13 8).54 ]53.75 ~3131.9a 387.88 15.00 2]0.00 11102.13 85.]] ]39.]1 89>S.B1 -3035.51 3r1 A8 110D 380.00 -1517.b 0 1185113 Y.96 9.5] 8988.70 -27rf.r8 3N.47 13.00 01.00 -1789.91 1 1180212 98.19 151.88 8978.03 -3820.89 358.07 12.00 305.00 -1880.87 2 11813.43 80.78 ]51.88 89]1.94 3581.53 317.60 ;2.00 180.00 -18]0.19 2 11913.00 90.]8 ]19.9] 89)1.60 -2522.21 243.20 2.00 270.00 -161131 -'~ 8700 50 1- D-08 (D-OSA~ 8400 5700 690 Plan 3, D-16A '-t 7800 -2400... ~_ 1 ~ _~_ , ^ 8100 7 ~~ ~ - ~~ ~ , 6000 C ~I ! _ , ~.... -- -- --~ _ 8100 ~ -2600 __~ - 7800 750 8 00 Y i I =- - , _ 1 i - ,i_ I +_i-I t ~ _ {- -~- 8400 O , -rt . g i t' I fi I 1-' ~ 1 ~. 2800 ~ ~..~ ~ ~ X6600 7800 87000 ~ _ r ~ ~ : ~ ~ i __ - _ ~ _~._ N ~ ~~ -- '-~ --- I" 1 .. _ ~ , I r rt-) 6900 - - 8700 -._ S -3000 8100 90 ~ -.._ )_ 7200 8400 r , a - - fi - - I- - _ _ 9000 9 0 _ Z -3200 -_ 7500 _ , 00 i i . .^i D-16 (Plan 2, D-16APB1 ~ 9000 ~ ~ I 1-~ D-20 (D-20) - - ' 7800 III _- ~ -3400 ~ © f I ~ '- 3 ~ ' __ -- D-16 D-16) __ - I-_ - _-- l ~ ' ~ - ~ -3600 ', _ - ~ ~ *~ ~ -1 _~ l _ l ~~ -~ Ir+ r ~ - I ~ -~-, , '~~;- ~ .- ~ r tit _. ~_-, ~.- - - _ -;-T T-- ~- _ . ~~~ ~--; ~T', -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 200 400 600 800 1000 1200 1400 1600 1800 West(-)/East(+) [200ft/in] u WELL DETAILS Name ~N/-S .F/-W NoMing EaxOng Latitude Loneitudc Slot D-1631X1.]5 13]1 ~] 5958]]8.W 6514]4.OU ]0"1 ]'3Y.5]'R: 148"95'26.292W Ifi l4J 12x u3 ANTI~('OLLISIOI: SETTR.'[i5 InmrpulaOunMMaN1D Inmrval: 511W Depth Range Pront-9%OL_Iq Tug 11912.00 Maximum Range: I}N].39 Reference: Plan: Plan) COMPANY DETAILS dP Amoa~ Calculatim Nethud: Minimum Cwvawrc Ertor Syxwm: ISC W SA Scan Me1hW: Truv Cylind<r Nunh Pirur Surface: Elliptical * Caxiug WaminB MethotL RWex dv. vl 1 Colour To MD 10103 - 10139 I 11912 WELI.P.4"ffl DE'1 AILS - "Puol Plan 3. U-IfiA SW?9206%301 MWD Parent WWlpath: Plan?, PI6AP111 Tie un MU: Y806.W Wig. 141: Datum: 29:1612/]/IH8I IXI:W ]%.WR V Sewiun Origin Origin Swning a,g4 +w-s +ri_w rmm Tw 45.W' O.W QW itl.10 LEGEND A-06 (A-06), Major Risk D-OS (D-ORA). Major Risk - D-12 (0.12), Major Risk - D-16 (D-Ifi), NOHRRORS - D-IG (Plao 2, D-16APB1), NOLRKORS - D-20 (D-211), Major Risk - D-31A (D-31 A), Major Rick - D-3I (D-31). Major Risk ~~ - Plan 3 D-16A Ixn Tmv<IlinB Cylinder Azimuth ITEO ~ All) IdcgJ va Cwnrc u+CCnve S<ParaOon 11 SIVinJ by ^~~ INTEL SF.I "LION UEfAILS Scc MU Inc Aei TVD +Nr-S -II-W UL<g TPaz~e VSec 4:vgct I 98W 00 21.9? I8).]I %Y1fi 22 -JW2.fi9 -46535 O.W O.W -!45=2% 9850.W ?9.01 1]9.55 %9559] -}0?1.53 -46fi1] 1].Y9 3JdW -24fifi.12 1 IOW24? W.W I]Y.55 9029.66 -1146]] -46519 411.W OW -2554.1% 4 IOIIY2.42 IUI 6fi I]2 ]I 9U20.5? -1235.90 -45941 IS.W 110W -2612.Ytl 5 104Y2A2 95.tl0 II?.IY %95].69 -IS.J~49 -22%.%3 IS.W ?]OW X66001 6 10692 d2 90.0] %?.69 tlY93.1] -]558.43 -3303 IS.UO 2XI.W -251Y.55 ] IOYY242 tlb.51 3].80 895'_.fil -141 J.52 ?20.]U IS.W 265W '?5].66 tl 1129242 N].54 35?.]5 %9690} -llil9l 2Y].55 ISW 2]II.W -2W421 9 11402.4? X5.11 33Y ]I %9]5.91 -]025.54 2]I.4Y 12.W 260.W -194].411 10 1165292 8%.99 95] %9%N ]0 -?]]Y.]Y 24%.4] 12.00 %400 -I]%Y.91 II 11811?i2 9Y.IY 354.68 tl9]%02 -?61089 254.U] 12.00 305.W -Ifi806] 12 118]2.4? Y0.]Y I54.fi8 89]194 -?561.52 24].60 12 U0 1tlOW -1636.19 13 11912.W 90.]N 14Y.91 %Y]I.40 -2522.31 24210 12.W 2]0.(X1 -1612.21 SURVEY PROCiR.4M Uapdr t'm IhptO'1< SurvcylPlwt 9%O6.W 1191200 Plmw d: Plmt3 V2 u "ti ~ BP Alaska ~„~; by Anticollision Report ~ rr.~r ~~~x INTEQ r- - --- ___~ _ Company: BP Amoco Date: 2/6/2009 Time: 09:43: 36 Page: 1 , Field: Prudhoe Bay Reference Site: PB D Pad Co-ordinate(NE) Reference: Well: D-1 6, True North Reference Weli: D-16 Vertical (TVD) Reference: 29; 16 42/7/1981 00 :00 78.6 L Reference Wellpath: Plan 3, D-16A Dbi Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'R»d~laeells in this~iehtllpal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 9806.00 to 11912.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1387.39 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 2/5/2009 Validated: No Version: 0 ~~ Planned From To Survey Toolcode Tool Name ft ft _ 100.00 9700.00 1 : Sperry-Sun B OSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot ~ 9700.00 9806.00 Planned: Plan 2 V1 (1) MWD MWD -Standard 9806.00 11912.00 Planned: Plan 3 V1 MWD MWD -Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 11912.00 8971.40 2.875 4.125 2 7/8" Summary - - _ __ ~ ~___ , <--_-~_-- Offset Wellpath ----- -----> Reference Offset Ctr-Ctr No-Go Allowable T Site Well We0path MD MD Distance Area Deviation Warning ft ft ft ft ft PB A Pad A-06 A-06 V1 1 0736.34 11411.00 1154.81 359.30 795.50 Pass: Major Risk PB D Pad D-08 D-08A V27 Out of range PB D Pad D-12 D-12 V1 Out of range PB D Pad D-16 D-16 V4 9849.42 9850.00 5.00 449.15 -444.15 FAIL: Major Risk PB D Pad D-16 Plan 2, D-16APB1 VO PI 9850.00 9850.00 0.00 547.74 -547.74 FAIL: Major Risk PB D Pad D-20 D-20 V1 Out of range PB D Pad D-31A D-31A V1 Out of range PB D Pad D-31 D-31 V1 1 0113.12 9450.00 647.02 486.60 160.43 Pass: Major Risk Site: PB A Pad _ Well: A-06 Rule Assigned: Major Risk Wellpath: A-O6 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+A ZI TFO-H S Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft j 10717.07 8943.21 10850.00 8828.54 53.02 35.24 164.81 85.80 1385.46 302.65 1082.81 Pass 110725.00 8943.26 10875.00 8849.83 55.72 40.07 164.48 86.65 1371.41 325.98 1045.43 Pass 10725.00 8943.26 10900.00 8871.09 55.72 40.26 165.34 87.52 1357.52 326.83 1030.68 Pass ~ 10725.00 8943.26 10925.00 8892.32 55.72 40.46 166.22 88.40 1343.91 327.66 1016.24 Pass 10725.00 8943.26 10950.00 8913.53 55.72 40.66 167.12 89.29 1330.61 328.44 1002.18 Pass 10725.00 8943.26 10975.00 8934.72 55.72 40.86 168.03 90.21 1317.64 329.15 988.49 Pass I, 10725.00 8943.26 11000.00 8955.90 55.72 41.05 168.96 91.14 1305.00 329.80 975.21 Pass 10725.00 8943.26 11025.00 8977.05 55.72 41.26 169.91 92.09 1292.71 330.41 962.30 Pass 10725.00 8943.26 11050.00 8998.20 55.72 41.47 170.88 93.05 1280.77 330.95 949.82 Pass 10725.00 8943.26 11075.00 9019.34 55.72 41.68 171.86 94.04 1269.20 331.41 937.79 Pass 10725.00 8943.26 11100.00 9040.47 55.72 41.88 172.86 95.04 1258.00 331.79 926.21 Pass 10725.00 8943.26 11125.00 9061.59 55.72 42.09 173.88 96.05 1247.19 332.21 914.98 Pass 10725.00 8943.26 11150.00 9082.70 55.72 42.30 174.91 97.09 1236.77 332.42 904.35 Pass 10725.00 8943.26 11175.00 9103.80 55.72 42.51 175.96 98.14 1226.76 332.53 894.22 Pass i 10725.00 8943.26 I 11200.00 9124.89 55.72 42.72 177.03 99.21 1217.16 332.55 884.61 Pass 10725.00 8943.26 11225.00 9145.98 55.72 42.93 178.12 100.29 1208.00 332.46 875.54 Pass I. 10725.00 8943.26 11250.00 9167.08 55.72 43.13 179.22 101.39 1199.28 332.25 867.03 Pass 10725.00 8943.26 11275.00 9188.19 55.72 43.34 180.34 102.51 1191.03 331.94 859.09 Pass 10731.89 8943.30 11300.00 9209.31 58.04 48.12 180.44 103.65 1183.18 350.95 832.22 Pass 10732.84 8943.31 11325.00 9230.44 58.36 48.99 181.45 104.80 1175.88 352.98 822.90 Pass 10733.82 8943.32 11350.00 9251.58 58.69 49.88 182.47 105.96 1169.10 354.93 814.17 Pass 10734.83 8943.33 11375.00 9272.74 59.03 50.80 183.49 107.14 1162.85 356.79 806.06 Pass 10735.87 8943.34 11400A0 9293.91 59.38 51.75 184.52 108.32 1157.14 358.55 798.59 Pass ~ ~L~ by r BP Alaska ~ s~~s `~;' Anticollision Report INTEQ Company: BP Amoco - - Date: 2/6/2009 Time: 09:43:36 Page: 2 Field: Prudhoe Bay ~ Reference Site: PB D Pad Co-ordinate(NE) Reference: Well: D-16, True North ~ Reference Well: D-16 VerticaF(TVD) Reference: 29:16 12/7/1981 00:00 78.6 Reference Wellpath: Plan 3, D-16A Db: OraGle Site: PB A Pad Well: A-06 Rule Assigned: Major Risk Wellpath: A-06 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Co Allowable MD TVD MD TVD Ref Offset TFO+AZL TFO-HS Casing/HSflistance Area Deviation Warning '; ft ft ft ft ft ft ,deg deg in ft ft ft 10736.34 8943.34 11411.00 9303.23 59.53 52.18 184.98 108.85 1154.81 359.30 795.50 Pass Site: PB D Pad Well: D-16 Rule Assigned: Major Risk Wellpath: D-16 V4 - Inter-Site Error: - - 0.00 - ft -_ i Refe rence Offset Semi-MajorAxis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9824.90 8933.56 9825.00 8934.17 145.46 146.91 342.50 158.83 7.000 1.57 434.87 -433.30 FAIL 9849.42 8955.41 9850.00 8957.70 145.08 146.96 340.78 161.15 7.000 5.00 449.15 -444.15 FAIL ~'i 9872.38 8974.57 9875.00 8981.29 144.76 147.06 343.65 164.10 7.000 11.35 400.70 -389.35 FAIL 'I 9893.02 8989.87 9900.00 9004.92 144.44 147.16 347.13 167.58 7.000 21.33 341.03 -319.69 FAIL 9910.96 9001.43 9925.00 9028.57 144.17 147.30 349.39 169.84 7.000 34.33 297.10 -262.78 FAIL 9926.27 9009.88 9950.00 9052.21 143.95 147.49 350.83 171.28 7.000 49.68 264.72 -215.04 FAIL 9939.21 9015.93 9975.00 9075.84 143.79 147.73 351.80 172.25 7.000 66.86 239.84 -172.98 FAIL 9950.13 9020.22 10000.00 9099.45 143.67 148.02 352.49 172.94 7.000 85.48 220.18 -134.70 FAIL 9959.36 9023.23 10025.00 9123.08 143.58 148.34 353.02 173.47 7.000 105.22 203.94 -98.72 FAIL 9967.18 9025.34 10050.00 9146.72 143.52 148.69 353.44 173.89 7.000 125.87 190.39 -64.52 FAIL 9973.84 9026.81 10075.00 9170.39 143.48 149.06 353.78 174.23 7.000 147.23 178.95 -31.72 FAIL 9979.55 9027.83 10100.00 9194.07 143.45 149.44 354.07 174.52 7.000 169.15 169.20 -0.05 FAIL 9984.44 9028.53 10125.00 9217.81 143.43 149.81 354.31 174.76 7.000 191.58 160.94 30.64 Pass 9988.62 9028.99 10150.00 9241.63 143.41 150.19 354.51 174.96 7.000 214.46 154.04 60.42 Pass 9992.24 9029.29 10175.00 9265.48 143.41 150.56 354.67 175.12 7.000 237.65 148.16 89.49 Pass 9995.44 9029.48 10200.00 9289.34 143.40 150.93 354.81 175.26 7.000 261.06 143.07 117.99 Pass 9998.29 9029.60 10225.00 9313.20 143.40 151.31 354.92 175.37 7.000 284.65 138.61 146.04 Pass 10000.84 9029.65 10250.00 9337.06 143.40 151.69 355.03 175.48 7.000 308.39 134.70 173.70 Pass 10003.75 9029.65 10275.00 9360.92 143.35 152.02 355.02 175.57 7.000 332.26 131.50 200.77 Pass 10007.69 9029.62 10300.00 9384.78 143.21 152.26 354.79 175.64 7.000 356.21 129.19 227.03 Pass 10011.41 9029.56 10325.00 9408.64 143.08 152.51 354.57 175.69 7.000 380.23 127.15 253.08 Pass 10014.91 9029.48 10350.00 9432.49 142.96 152.76 354.35 175.73 7.000 404.30 125.33 278.97 Pass 10018.21 9029.37 10375.00 9456.35 142.84 153.01 354.13 175.76 7.000 428.42 123.70 304.73 Pass 10021.33 9029.25 10400.00 9480.21 142.73 153.27 353.92 175.79 7.000 452.60 122.22 330.38 Pass 10025.00 9029.08 10425.00 9504.07 142.60 153.50 353.66 175.80 7.000 476.82 120.60 356.22 Pass 10025.00 9029.08 10450.00 9527.93 142.60 153.89 353.68 175.82 7.000 501.09 120.51 380.59 Pass 10029.75 9028.81 10475.00 9551.79 142.41 154.07 353.32 175.82 7.000 525.38 118.34 407.04 Pass 10032.28 9028.65 10500.00 9575.65 142.31 154.34 353.13 175.82 7.000 549.72 117.20 432.52 Pass 10034.68 9028.48 10525.00 9599.51 142.22 154.62 352.95 175.82 7.000 574.09 116.15 457.94 Pass 10036.25 9028.36 10542.00 9615.73 142.15 154.81 352.83 175.82 7.000 590.67 115.48 475.19 Pass Site: PB D Pad Well: D-16 Rule Assigned: Major Risk Wellpath: Plan 2, D-16APB1 VO Plan: Plan 2 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9825.00 8933.65 9825.00 8933.65 145.46 143.75 183.65 0.00 4.125 0.00 529.66 -529.66 FAIL 9850.00 8955.93 9850.00 8955.92 145.07 143.38 179.55 0.00 4.125 0.00 547.74 -547.74 FAIL j 9874.88 8976.52 9875.00 8977.32 144.72 143.03 16.19 196.64 4.125 1.32 192.27 -190.95 FAIL 9899.07 8993.96 9900.00 8997.71 144.35 142.67 16.37 196.82 4.125 5.22 207.21 -201.99 FAIL 9922.02 9007.68 9925.00 9016.95 144.01 142.33 16.71 197.16 4.125 11.47 225.95 -214.47 FAIL 9943.39 9017.66 9950.00 9034.95 143.74 142.07 17.18 197.63 4.125 19.79 247.40 -227.61 FAIL 9963.06 9024.28 9975.00 9051.57 143.55 141.88 17.75 198.20 4.125 29.85 270.62 -240.76 FAIL 9981.05 9028.06 10000.00 9066.73 143.44 141.77 18.40 198.85 4.125 41.32 294.73 -253.41 FAIL ' ~'~: ~ r BP Alaska ~ ,~`~ ~~a~r'" P Antlcollision Report 1NTEQ Company: BP Amoco Date: 2/6/2009 Time: 09:43:36 Page: 3 Field: Prudhoe Bay Reference S ite: PB D Pad C o-ordiuatas(NE) Reference: Well: D-16, True North Reference Well: D-16 V ertical (TVD} Reference: 29:16 1 2/711981 OO: pO 78.6 Reference WeNpath: Plan 3, D-16A ' Db: Oracle Site: PB D Pad Well: D-16 Rule Assigned: Major Risk Wellpath: - Plan 2, D-16APB1 VO - Plan: Plan 2 V1 - Inter-Site Error: 0.00 _ ft - -- Refe rence Offset Semi-Major Axis Ctr-Ctr No-Co Allowable ~ MD TVD MD TVD Ref .Offset TFO+AZI TFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9997.50 9029.57 10025.00 9080.33 143.40 141.73 19.11 199.56 4.125 53.90 319.10 -265.20 FAIL 110015.58 9029.46 1.0050.00 9092.28 142.93 141.29 18.86 200.30 4.125 67.01 337.24 -270.23 FAIL '~ 10027.87 9028.92 10065.93 9099.00 142.49 140.85 18.37 200.73 4.125 75.05 346.93 -271.88 FAIL Site: PB D Pad Well: D-31 Rule Assigned: Major Risk Wellpath: D-31 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVll MD TVD Ref :Offset TFO+AZI TFO-HS CasinglliSDistance Area. Deviation Warning ft ft ft ft ff ft' deg deg in ft ft ft 10104.73 9018.03 9400.00 8707.50 138.25 24.48 230.93 60.11 640.34 476.60 163.74 Pass 10108.91 9017.18 9425.00 8723.49 137.72 24.44 232.18 62.00 643.04 481.96 161.07 Pass 10113.12 9016.33 9450.00 8739.03 137.19 24.41 233.38 63.85 647.02 486.60 160.43 Pass 10117.37 9015.48 9475.00 8753.93 136.66 24.37 234.53 65.64 652.49 490.47 162.02 Pass ~ 10125.00 9013.94 9500.00 8768.08 135.70 24.13 234.98 67.27 659.50 491.86 167.63 Pass 10125.00 9013.94 9525.00 8781.38 135.70 24.34 236.76 69.04 668.06 496.46 171.60 Pass 10130.28 9012.88 9550.00 8793.83 134.92 24.23 237.47 70.56 678.19 497.33 180.86 Pass 10134.51 9012.02 9575.00 8805.49 134.29 24.19 238.28 72.02 689.73 498.18 191.55 Pass 10138.69 9011.18 9600.00 8816.42 133.67 24.14 239.01 73.39 702.54 498.52 204.01 Pass 10142.78 9010.37 9625.00 8826.99 133.06 24.09 239.68 74.68 716.18 498.46 217.72 Pass I, 10150.00 9008.92 9650.00 8837.31 131.99 23.84 239.70 75.81 730.53 496.03 234.50 Pass 10150.00 9008.92 9675.00 8847.39 131.99 24.03 240.98 77.09 745.49 497.75 247.73 Pass ', 10150.00 9008.92 9700.00 8857.21 131.99 24.23 242.20 78.31 761.11 499.20 261.91 Pass i 10158.20 9007.28 9725.00 8866.84 130.60 23.89 241.85 79.22 777.18 494.62 282.56 Pass ~~, 10161.85 9006.56 9750.00 8876.26 129.97 23.85 242.29 80.21 793.78 492.99 300.79 Pass i, i 10165.42 9005.85 9775.00 8885.49 129.37 23.80 242.67 81.14 810.82 491.20 319.63 Pass 10168.90 9005.16 9800.00 8894.54 128.77 23.75 243.02 82.03 828.31 489.29 339.01 Pass 10175.00 9003.95 9825.00 8903.44 127.73 23.52 242.85 82.78 846.25 485.33 360.92 Pass 10175.00 9003.95 9850.00 8912.24 127.73 23.70 243.74 83.68 864.45 485.63 378.82 Pass 10175.00 9003.95 9875.00 8920.72 127.73 23.87 244.58 84.52 883.06 485.84 397.22 Pass 10182.12 9002.55 9900.00 8928.59 126.37 23.56 244.05 85.07 902.08 480.34 421.75 Pass 10185.37 9001.91 9925.00 8935.53 125.75 23.52 244.14 85.66 921.71 477.86 443.84 Pass 10188.57 9001.28 9950.00 8941.40 125.13 23.47 244.15 86.16 941.97 475.41 466.56 Pass 10191.66 9000.68 9975.00 8946.28 124.54 23.43 244.10 86.58 962.85 473.04 489.81 Pass i 10200.00 8999.05 10000.00 8950.12 122.94 23.00 243.00 86.76 984.24 466.41 517.83 Pass 1 10200.00 8999.05 10025.00 8952.80 122.94 23.17 243.35 87.10 1005.88 466.56 539.31 Pass ~ ' 10200.00 8999.05 10050.00 8954.21 122.94 23.34 243.61 87.37 1027.85 466.78 561.08 Pass 10200.00 8999.05 10075.00 8954.71 122.94 23.50 243.81 87.57 1050.21 467.01 583.20 Pass 10200.00 8999.05 10100.00 8955.10 122.94 23.65 243.99 87.75 1073.04 467.24 605.80 Pass 10208.50 8997.41 10125.00 8955.91 121.14 23.13 242.63 87.68 1096.01 459.85 636.16 Pass 10210.71 8996.98 10150.00 8957.59 120.67 23.08 242.45 87.84 1119.08 457.94 661.14 Pass 10212.83 8996.57 10175.00 8960:21 120.22 23.03 242.33 88.04 1142.06 456.06 686.00 Pass 10214.90 8996.18 10200.00 8963.78 119.78 22.98 242.25 88.28 1164.85 454.17 710.68 Pass 10216.95 8995.78 10225.00 8968.29 119.35 22.93 242.21 88.55 1187.41 452.25 735.16 Pass j 10225.00 8994.25 10250.00 8973.50 117.64 22.42 241.10 88.67 1209.90 444.90 765.00 Pass 10225.00 8994.25 10275.00 8979.26 117.64 22.54 241.47 89.04 1232.25 444.73 787.53 Pass 10225.00 8994.25 10300.00 8985.47 117.64 22.65 241.84 89.41 1254.63 444.53 810.10 Pass 10225.00 8994.25 10325.00 8992.05 117.64 22.77 242.22 89.78 1277.04 444.31 832.74 Pass 10225.00 8994.25 10350.00 8999.02 117.64 22.88 242.59 90.16 1299.42 444.06 855.35 Pass 10225.00 ~ 8994.25 10375.00 9006.37 117.64 23.00 242.98 90.54 1321.77 443.79 877.98 Pass ~ 10225.00 8994.25 10400.00 9014.11 117.64 23.11 243.36 90.93 1344.13 443.50 900.63 Pass ~L~ - ~ by ~ BP Alaska '~ ~~~ '*+~` Anticollision Report INTEQ -_- -- Company: BP Amoco --- Date: 2/6/2009 Time: 09:43:36 Page: 4 Field: Prudhoe Bay Reference Site: PB D Pad Co-ordinate(NE) Reference: Well: D-16, True North Reference Well: D-16 Vertical (TVD) Reference: 29:16 12R/1981 00:00 78.6 ~i Reference Wellpath: Plan 3, D-16A Db: Oracle Site: PB D Pad Well: D-31 Rule Assigned: Major Risk Wellpath: D-31 V1 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable NID TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10225.00 8994.25 10425.00 9022.22 117.64 23.23 243.75 91.31 1366.49 443.18 923.31 Pass Alaska Department of Natural Resources Land Administration System Page 1 of,~ t -. ~, . . ,cc~ _~.. ... _ -_~ . - =~carder's Search State Catains 1'~~#ur~1 ls~urc+es S a ~ C File Type: ADL File Number: 28285 ~ Pri_n..table_C.. ase File_Summary See Township, Range, Section and Acreage? ~' Yes No Mew Search ~ LAS MPn,~ i Case Abstract i Case Detail i Land Abstract F[Ie: AUI. ?8285 °'~'~'~~ Search for Status Plat Updates -1, c~- OZ 1 ~, X009 Customer: 000107377 BP EXPLORATION (ALASKA)1NC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 99519661 ~', Cuse Tyne: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DN OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated. 05/28/1965 Office of Priryzary Responsibility.' DOG DN OIL AND GAS Lust Transaction Date: 12/04/2006 Case Subtype: YyS NORTH SLOPE Last Ti~ansc~ction: AA-NRB ASSIGNMENT APPROVED Mc~ri~licaj~: ~,' 7rnrn.~~hip: O11N K~r~rge: 013E Scc~liorz: ~3 ~ Section~9c°rc~.~: 64U ~ Search Plats alc~~~i~li~nr.~ l' Z~~~~in~~lrri~: O1 I~' Rrrf~L~~~: Olil, S"<~c~1ru~~.~ I ~ Section.I~~rc~.~~: 641) 1 /eridr~r~r.~ l' l~nrn.~~hi~~: 0l I \ Ran,<_.c ~ O I3L ,ti'c~cJr„».~ `' ~ .S'ection, lc~rc~,~: 6 1O llferidiur~: L!' Totir~t.~~hi~~: 01IN Ra~t~r: (113L ,~'c>~~~ic~n: ~~ .5'ccrinn.lcre~s: 641) Legal Descriptiuu 0~ -28-196 * * *SALE NOTICE LEGAL DESCRIPTION* C1~-96 TIIN-RISE-UM13,Id,?3,2-~ 2,60.00 LISBURNE PARTICIPATING AREA DESCRIPTION T. 11., R. 13 E., U.M. SECTION 13: ALL 6~0 ACRES CONTAINING 6~0 ACRES, MORE OR I ESS. http://dnr.alaska.gov/proj ects/las/Case_Summary.cfm?FileType=ADL&FileNumber=2828... 2/18/2009 TRANSMITTAL LETTER CHECKLIST WELL NAME ~'~'L/ /.> • I~ PTD# 0?09 O~?S Development Service Exploratory Stratigraphic Test Non-Conventional Welt FIELD: ~.~~,Dyo~- ~,g y POOL: ~,~G/D,S/06' 1~~Y O/G Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name (~j- ~(~,p,Q ~, PH) and API number (50-~5 -aO6TS~_-'1D) from records, data and logs acquired for well b- ~ fo P~ SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et 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. (Company NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: I / 11 /2008 WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT D-16A Program DEV _ _ Well bore seg ^ PTD#:2090250 Company BP EXPLORATION (ALASKA) INC Initial Class/Type DEV / PEND GeoArea 890 Unit 11650 On/Off Shore On Annular Disposal ^ Administration 1 Permit fee attached_ NA_ 2 Lease number appropriate______________________ Yes_ _-______ 3 Uniquewell_n_ameandnlamber______________________________ Yes- _--_____ -_-._ 4 Well located in_a_defned-pool__ ______________ Yes- ---_-_______ __--__---.-_-______ 5 Well locatedproperdistancefromdrillingunit_boundary__ ________________ ____ Yes_ _______________________ 6 Well located proper distance from other wells_ Yes - - 7 Sufficient acreage available in-drilling unit_ Yes . - - .. - - .. - S If deviated, is_wellbore plat.included Yes- ------- ----- 9 Ope[ator only affected party Yes - - ( 10 Ope[atorhas_appr_opriate_bondinforce.___-_____-___ Yes. .....-BlanketBond#6194193.--- .___-_-_______________________________________ ( 11 Pe[mitcanbeissuedwithoutconservationorder__________ Yes- ---------------------------------------------------------------------- --- Appr Date ( 12 Pe[mitcanbeissuedwithoutadministralive_approyal_______ _________________ Yes- __--_-_-_--__-_--._-----.-_______________ 13 Can permit be approved before 15-day wait Yes AC5 2/18!2009 i 14 Well.locatedwithinareaand_strataauthorizedby_InjectionOrder#(put_10#in-comments)_(For_ N_A__ __________________________________________________________________________ ( 15 All wells_within 1!4_mile area-of review identified (For service well only) NA_ - _ _ _ - - - - 16 Pre-produced injector. duration_ofgre-production Less than 3 months (For_service well only) NA- - - - - - - - - - - - - - - - - - - - - - - - - - 17 Nonconyen, gas conforms to AS31,05,030((.1.A),Q.2.A-D) - , - NA_ 18 C_ondu_ctorstring provided _ - _ _ _ _ - _ . _ _ - - NA _ _ _ _ _ _ Con_ductorset_in D-16_(1.81-171). _ _ _ _ _ _ _ _ _ _ -------- Engineering X 19 Surface casingprotects all_known USDWS NA All aquifers exem ted AE01, p 20 _C_MT.v_ol_adequate_tocirculate.onconductor&surf_csg___ ______ ._. NA .--_._SurfacecasingsetinD-16______________________________________ _______ __ ___ ~ 21 CMTVOIadequate_totie-inlongstringto_surfcsg _-_-- _-____________ ____ NA__ ____ _Production_casingsetin_D-16._____________-------...-_._--_-_______ 22 CMT.will coyer all known_producti_ve horizons_ Yes ! 23 _C_asingdesgnsadequateforC,T,B&permafrost______ ___ _____ ___ _ ____ Yes_ _-__ ____________._ x, 24 Adequate tankage-or reserve pit Yes Rig equipped with steel pits. No reserve pit planned._ All waste_to approved disposal well(s), 25 If_a_ re-drill, has_a 10.403 for abandonment been approved Yes _ - - 309-066 26 Adequate wellbore separation proposed- . - - _ - Yes Proximity analysis performed, T[ayeling cylinder path calculated, Nearest segment, P8A portion of D-16, - 27 If_diverterrequired,dnes it meet regulations_ NA_ - - _ - . -BOP stack will already-be-in place, - _ - _ - . _ Appr Date 28 Drilling fluid_program schematic_& equip)istadequate- - - Yes Maximum expected formation pressure x_7.0 EMW, MW planned 8,6_ppg.- TEM 2!20!2009 29 BOPEs,_do they meet regulatipn . Yes - - . - .. - - - - - - 30 B_OPE_press rating appropriate; test to-(put prig in comments)_ - - - Yes MASP calculated-at 2342psi, 3500-psi-BOP test-planned- -- - - - - - -- - - - - - ~ 31 Choke_manifoldcomplieswlAPIRP-53 (May 84) ______ _______________ ____ Yes_ ____--_----.__ 32 Work will occur without operation shutdown__________________________ Yes_ --_---.--- 33 Is presence of H2S gas probable Yes H2S is present at_D pad. Mud should_preclude H2S on ri . _Ri has sensors_andalarms, - - - - - - 9 9- j 34 Mechanical_condition of wells within AOR verified (For service well only) _ - - - NA . . .... . .. . . . . . . . . . . . . .... . ... . ... . . _ _ - - - .. _ - . - - - - _ _ - - _ - - 35 - ----- --- Permit can be issued wlo hydrogen_ sulfide measures No_ - - Geology 36 _Data_p_resented on potential overpressure zones NA_ _ - Appr Date 37 Seismic analysis of shallow gas_zones- - . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA - _ _ . - . - .. - ACS 2118/2009 X38 Seabed conditionsurvey_(ifoff-shore)----- ---------- ---------- NA_- ----.--.-.-..----- -,-. - -.--. ._---- ----. .... _. -- 39 C_ontactnamelphoneforweekly_progressreports[exploratoryonly]_________________ Yes_ ____ _GregSarber_-564.4330,___________-__-_--__--_____--___-______-__. Geologic Engineering Public WIO Operator to confirm Location and Lease numbers (2118!09). Info confirmed 2:40p 2118/09. Commissioner: C inner Date Date: Commissioner: Date c) /wf ~%~~ ~I~'O/ ~~~Y ^ ~~
