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208-170
• 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. Q2®g - ~ ~Q Well History File Identifier Organizing (done) ^ Two-sided III (I'l ll 11 III (~ II) ^ Rescan Needed III II~III II II III III RE AN DIG TAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. I ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~s~ Pro-ect Proofin I g III IIIIII IIIII II III BY: Maria Date: ~s~ tannin Pre aration S g p ~_ x 30 = 3Q + ~, ~ =TOTAL PAGES ~~ (Count does not include cover sheet) iY~ Maria Date: ~, f ~ ~~ ~ ~s~ Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: V ~s~ ~, Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: Scanning is complete at this point unless rescanning is required. =IIII!IIIIIIINIIIII ReScanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III IIIIII III II'I III 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA AL ,(A OIL AND GAS CONSERVATION COMM_ ,SON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations Li Perforate U OtherU Starting Head Weld 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 Development El Exploratory ❑ 208-170-0. 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20775-03-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028305 PBU C-23C ' 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL• 11.Present Well Condition Summary: ���� Total Depth measured 12295 feet Plugs measured None feC true vertical 9020.46 feet Junk measured None feet lei l 7 9 2013 Effective Depth measured 12256 feet Packer measured See Attachment feet ®��� true vertical 9017.35 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91.5#H-40 26-106 26-106 1490 470 Surface 2663 13-3/8"72#L-80 25-2688 25-2687.91 4930 2670 Intermediate None None None None None None Production 8556 9-5/8"47#L-80 24-8580 24-7698.47 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11750-12250 feet SCANNED AN 2 7 2014 True Vertical depth 9020.17-9016.87 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 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: 319 35143 53 0 874 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorI❑ Development al ' Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 • Gas U WDSPLU 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: N/A Contact Garry Catron Email Garry.Catron(a)_BP.Corn Printed Name Garry Catron Title PDC PE Signature 2:J V e Phone 564-4424 Date 11/19/2013 0_1 /i z // 4- ii ' .11i;,:.'., NOV 2 0 1, Form 10-404 Revised 10/2012 /e• A/7 Submit Original Only Packers and SSV's Attachment ADL0028305 SW Name Type MD ND Depscription C-23C PACKER 2610 2544.32 9-5/8" DV Packer C-23C PACKER 8434 _ 7515.49 _9-5/8" Baker ZXP Packer C-23C PACKER 9110 8112.22 _4-1/2" Baker S-3 Perm Packer C-23C _ PACKER 9164 _ 8163.34 7" Baker ZXP Top Packer C-23C PACKER 9785 8731.94 3-1/2" Baker 45 KB Packer d H O O as0000 LL) 000 (000000 O Ln r N L V co 0 0 ° 0 0 0 0 0 • � 0 M CO oo t- CO r r CO LO LO CO co I- - CO O [t Ln O c Tr CA N- 0 0 r- O co co w- � ON NCA00Nr) 00000 (0 (0 N CO CA CO CA 0) f"- N CO LO CO C . CV) LoLnO CO 7 r f� r Nr co N 0 T r N N N N N- N N co O — 00 CO co 0 C O M N co CO CO CD ° O) " CO N O) QM CO CONt0000v ' Ln wr oo � (V N � � � COONNNN C p 0 3 J ~ Q o 0 000 ° o oco a°ooco coo C) YOJ � JJO3JOJ = CO J 0 * J up N N 0 N J 0 N NLO4 CO � r (V V � • CV OO C:10 , M N 'C M C'.) N (p � CO M O) ,0 T"; z; s CO CV) CC�o LoLo %- LOCO - •- J CO N 0) Z O w V• c) oc 0c cc c) u_ Z w w w w w O IX m m O Z Z Z Z Z o D D D U JJJJJd V) I- TREE= FMC 6X7 SAFE DIES: WELL ANGLE>70°@ 10120'.ORIG IWB_LHEAD= NCEVOY ACTUATOR= BAKER C C-2 3 C 9-518e "M LLOUT WINDOW.•"A" NOT SHOWN BELOW INITIAL KB.RE 71.5' BF.ELEV= 39.4' NIPPLES'" KOP= 8575' Max Angle= 96°@ 11379' I I � �H 1 2185' 4-1/2"FES X NP(9CR),D=3.813" Datum M3= 9876' Datum TVD= 8800'SS GAS LFT MANDRELS 9-5/8"DV PKR -I' 2622' ST MD TVD DEV TYPE VLV LATCH FORT DATE 6 3020 3020 1 MMG-M DMY RK 0 05/30/03 13-3/8"CSG,72#,L-80,D=12.347" H 26. 5 3992 3989 11 MMG M DM' RK 0 07/05/13 4 5788 5515 41 MMG-M DMY RK 0 07/05/13 L 3 7123 6517 39 14/MG-M DMY RK 0 05/17/03 Minimum ID =2.387" 10996' 2 8054 7267 34 MMG-M DMY RK 0 05/17/03 1 9021 8093 19 KBG-2 DMY BK 0 11/08/13 2-7/8" XO PIN 8426' H 9-5/8"X T BKR LNR TACK,D=7.500" I a I 8434' H9-5/8-X 7'BKR ZXP LTP w/LIW2 HGR,D=6.280" I 9-5/8'MLLOUT WINDOW(C-23B) 8580'-8596' 9-5/8"CSG,47#, H 8580' I- L-80,D=8.681" I I 9089' H4-1/2"HES X MP(9CR),D=3.813" CZ si--1 9110' IH 7"X 4-1/2"BKR S-3 PKR,0=3.875" I 9133' H4-1/2"HES X NP(9CR),D=3.813" I II 9154' H4-1/2"HESXNNP(9CR),PALLED TO3.80"(11/27/08) I '4-1/2"LNR,12.6#,L-80 TCI, -I 9167' _ ( 9156' H7"X 5" BKR LTP w/TIEBACK,D=4.380' .0152 bpf,D=3.958" 9167' -14-1/2"WLEfG,D=3.958" 7"LNR,26#,L-80 BTC, -I 9344' --A 9170' IH T X 5" BKR LNR HGR,ID=4.450" I .0383 bpf,D=6.276" 9177' H5"X 4-1/2"XO,D=3.958" I ► 9785' H KB LNR TOP PKR,D=2.560" I FE2FORATION SU.MARY ► REF LOG: MCNL ON 12/11/08 •► I 9791' I--I3.7'DEPLOY SLV,D=3.00" ANGLE AT TOP FERF: 92°@ 11750' ► Note:Refer to Rod uction DB for historical perf data X MLLOUT WINDOW(C-23C)10677'-10685' l SIZE 5R INTERVAL Opn/Sgz SHOT SOZ K 2" 6 11750-12250. 0 12/12/08 k • X 9642' H 3-112-X 3-3/16"XO,D=2.786" I 4-1/2"MONO-BORE WHPSTOCK(12/07/08) H 10675' I 10994'' H3-3/16"X 2-7/8"XO,D=2.387" I ihr RA TAG 10684' �.�.�. i••••• PBTD 12257' 4-1/2"LNR,12.6',L-80 BTC-M, -I 10820' .*,*,•�� .0152 bpf,D=3.958" 3-1/2"LNR,8.81 8,L-80 STL,.0087 bpf,D=2.992" H 9842' !S, I3-3/16"LAIR,6.2#,L-80 Tat.0076 bpf,D=2.80" -I 10994' 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,ID=2.441" -I 12295' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRU DHOE BAY UNIT 09/04/82 INITIAL COMPLETION 05/01/12 JMO/JMD TREE C/O(04/23/12) WELL: C-23C 10/17/96 D16 SIDETRACK(C-23A) 09/19/13 SAC/JM)SET PX PLUG(09/15/13) PEiMT No:"2181700 05/18/03 142ES SIDETRACK(C-23B) 09/19/13 BSE1JM) GLV GO(09/16/13) AR No: 50-029-20775-03 12/13/08 NORDIC 1 CTD SIDETRACK(C-23C) 11/11/13 RKT/PJC GLV CO(11/08/11) SEC 19,T11N,R14E,1316'FNL&1030'FE. 02/11/09 DBMIPJC DRLG DRAFT CORRECTIONS_11/11/13 RKT/PJC PULL PX RUG(11/09/13) - 02/17/12 SCG/JMD GLV CXRRECTION(12/17/08) BP Exploration(Alaska) • • yw �O j j�sV THE STATE Alaska Oil and Gas OfA LAsKA conservation Commission *h' GOVERNOR SEAN PARNELL 333 West Seventh Avenue °PALAS11J' Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 John McMullen same \jcI%'4' ,' " 'c 1" Engineering Team Leader BP Exploration (Alaska), Inc. OZ - 110 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-23C Sundry Number: 313-556 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, Commissioner DATED this 25 day of October, 2013. Encl. 1k STATE OF ALASKA � ∎> RECEIVED ALASPOIL AND GAS CONSERVATION COMMISSION ta'^` nrrn 1 20.E 13 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AOGCC 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. ❑Exploratory ❑Stratigraphic 208-170 . 3. Address: ®Development/0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-20775-03-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU C-23C- Will planned perforations require a Spacing Exception? ❑Yes ® No• 9. Property Designatior 10.Field/Pool(s): ADL 028305• Prudhoe Bay/Prudhoe Bay. 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): 12295' • 9020' • 12257' • 9017' • None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20"x 30" 80' 80' Surface 2694' 13-3/8" 2694' _ 2694' 4930 2670 Intermediate 8580' 9-5/8" 8580' 7698' 6870 4760 Production Liner 918' 7" 8426'-9344' 7575'-8400' 7240 5410 Liner 1521' 4-1/2" 9156'- 10677 8221'-9020' 8430 7500 Liner 2510' 3-1/2"x 3-3/16"x 2-7/8" 9785'- 12295' 8798'-9020' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11750'- 12250'• 9020'-9017' 4-1/2", 12.6# L-80 9167' Packers and SSSV Type: 7"x 4-1/2"Baker S-3 Packer Packers and SSSV 9110'/8178' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: , ®Description Summary of Proposal ®BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic/El Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: October 28,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ®Suspended 17. I hereby certify that the for-:•ing is .' ,- correct to the best of my knowledge. Contact: Ron Phillips,564-5913 Printed Name: Jo .�i h c j Title: Engineering Team Leader Em is R .Phillips@bp.com Signature: 2P' / Phone: 564-4711 Date: nn Zr �� Commission Use Only i(J Conditions of approval: Notify Commission so that a representative may witness 3�� Sundry Number: ❑Plug Integrity\ BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: &()p try f c- D O ps 1 I 1 te-y-Y4 --c 1 L )a ct�, z71 a ,-o Vt1 P tr a °AA-C Z.5^ t jz-� �•i p �� RBDMS OCT 2 9 2� Spacing Exception Required? ❑Yes No Subsequent Form Required: — ¢U ta4. APPROVED BY Approved By: f.v COMMISSIONER THE COMMISSION Date: /0 Z 5-13 Form 10-403 Revised 10/ 012 _' A ved a lica o r f i2 n om the date of approval royal p1� Submit In Duplicate 1/7 r-"- 1 / 7 / f 3P PP � �� 1 pP Joiall/5 #4 /94* . • • To: Alaska Oil& Gas Conservation Commission h From: Ron Phillips b p CTD Engineer Date: Oct. 14, 2013 Re: C-23C Sundry Approval Sundry approval is requested to plug the C-23C perforations as part of the drilling and completion of proposed C-23D coiled tubing sidetrack. History and current status: C-23 was drilled and completed in 1982. The well was sidetracked in 1996, 2003 and again in December 2008. The well was POP, and quickly shot up to HGOR in<2 months of production. Nordic set a LTP in the well since the liner lap failed on the CTD liner primary cement job. The July-2013 screening revealed that the LTP was still stung 8' into the sealbore receptical of the CTD deployment sleeve. The well was twice tried for cycle after long SI's, with no luck. Gas underruns in the parent were the reason no adperfs back uphole were attempted. A fault mid-- wellbore also took away potential perf footage. There are no remaining non-rig intervention options to return the well to competitive status. Proposed plan: Sidetrack C-23C to the C-23D location using Nordic 1 Coiled Tubing Drilling rig on or around November 12th, 2013. The C-23D sidetrack will exit the existing 4-1/2" liner and kick off in the Ivishak Zone 2,tag the HOT and invert to get back up into and stay in Zone 2 . This sidetrack will be completed with a 3-1/4" L-80 liner which will be cemented in place. This Sundry covers plugging the existing C-23C perforations via the primary cement job to top of the liner or a liner top packer if the liner lap 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. r GOA /) ,,^ �X f O l 94/ cieo cf ,19/- Ntatv at& C Owe Iv 4e Cif d L' 'r ir A FA#'r h " uP fo z. s'earl Qwfy,, ' ' H,ell i' to Ir,// (e co ve rb .Crom 1-11711 6 e fAe 610 4 0/2"y/i,1 • • f ? C' ✓/ sea Pre-Rig Work(scheduled to begin Oct 28th,2013) 1. S Dummy GLV's and Dummy WS drift to 9,785' MD (KB LTP). 2. F MIT- IA to 2,500 psi, MIT-OA to 2,000 psi. 3. E Set a 4-1/2" KB packer whipstock at 9,760' MD. (Retrieval) 4. F MIT-T 3,000 psi to check that whipstock was set as intended. LLR if fail. 5. V PT MV, SV,WV. 6. 0 Remove wellhouse and level pad. Rig Work(scheduled to begin Nov 12th,2013) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,351psi) 2. Mill 3.80"window at 9,760' and 10'of rathole. 3. Drill build: 4.125" OH, 536' (12 deg DLS planned). 4. Drill lateral: 4.125" OH, 2672' (12 deg DLS planned). 5. Run 3-1/4" liner leaving TOL at 9,460' MD. 6. Pump primary cement job: 27.8 bbls, 15.8 ppg,TOC at 9,460'.* 7. Perform liner cleanout and GR/CCL log. 8. Perform liner lap test. 9. Perforate liner based on log interpretation (^'200'). 10. Freeze protect well to 2,500' MD. 11. Set BPV; RDMO. *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* if liner lap test fails. * Approved alternate plug placement if liner lap test fails per 20 AAC 25.112(i) Ron Phillips CTD Engineer 564-5913 CC: Well File Joe Lastufka • Note: As agreed with tt—ie AOGCC via 9/26/13 correspondence, all pre-rig • work leading-up to the PTD activity must be listed in the 10-403 approval request. However, some of the activities may not be specifically related to the 10-403 plugging request. So, for those steps associated with the permanent plugging of the existing completion or for those steps which are permanent changes to the wellbore (cannot be reversed -- for example, non-retrievable whipstocks), 10-403 approval is required before proceeding. These steps are noted by "Yes" in the 10-403 column. Required eenTir Pre-Rig Work(scheduled to begin Oct 28th,2013) 10-403 PTD 1. S Dummy GLV's and Dummy WS drift to 9,785' MD(KB LTP). No No 2. F MIT- IA to 2,500 psi, MIT-OA to 2,000 psi. No No 3. E Set a 4-1/2" KB packer whipstock at 9,760' MD. (Retrieval) No No 4. F MIT-T 3,000 psi to check that whipstock was set as intended. LLR if fail. No No 5. V PT MV,SV,WV. No No 6. 0 Remove wellhouse and level pad. No No Required Permit? Rig Work(scheduled to begin Nov 12th,2013) 10-403` TD 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,351psi) Yes Yes 2. Mill 3.80"window at 9,760' and 10' of rathole. Yes Yes 3. Drill build: 4.125" OH, 536' (12 deg DLS planned). No Yes 4. Drill lateral: 4.125" OH, 2672' (12 deg DLS planned). No Yes 5. Run 3-1/4" liner leaving TOL at 9,460' MD. No Yes 6. Pump primary cement job: 27.8 bbls, 15.8 ppg,TOC at 9,460'. Yes* Yes 7. Perform liner cleanout and GR/CCL log. No Yes 8. Perform liner lap test. No Yes 9. Perforate liner based on log interpretation (-200'). No Yes 10. Freeze protect well to 2,500' MD. No Yes 11. 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* if liner lap test fails. * Approved alternate plug placement if liner lap test fails per 20 AAC 25.112(i) Ron Phillips CTD Engineer - - ---° 564-5913 CC: Well File Joe Lastufka AJirc.I I IRJ I W. Iv ELL.lY4l�G-I V e+ 1114/ILA/.VIVV 'H1 TO = BAKE W &SIDETRACK"A" NOT SHOWN BELOW CTt�ATB. BAKER.C . .2 3 9- ILLOUT WINDOW.t.:4112"CHROME TTIAL KB.ELE 71.5' NPPLES"'• ELEV= 39.4' JP= 8575' ' 2185' -I4-1/2"1-ES X MP(SCRIM D=3.813" ax Angle= 96° c�" 11379" 3tu-m ND= 9876' 3tum TVD= 8800'SS GAS LFT MANDRELS 9-5/8'DV R(R H 2622' ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3020 3020 1 MMS-M DMY FE 0 05/30/03 13-3/8"CSG,72#,L-80,D=12.347" -I 2694' 5 3992 3989 11 NAGM DMY RK 0 07/05/13 r 4 5788 5515 41 MMG-M DMY RK 0 07/05/13 3 7123 6517 39 MMG-M DMY RK 0 05/17/03 Minimum ID =2.387" @ 10996' 2 8054 7267 34 MAG-M DMY RK 0 05/17/03 1 9021 8093 19 KBG-2 OW BK 0 05/17/03 2-7/8" XO PIN 8426' H 9-5/8°X 7"BKR LNR TEBACK,D=7.500" I I 8434' 1-95/8"X 7"BKR ZXP LIP w J LNR HGR,D=6.280" 9-5/8"NFLLOIJT WPDOW(C-23B) 8580'-8596' 9-5/8"CSG,47#, -I 8580' I-- L-80,D=8.681" ' 9089' I--I4-1/2"HES X NP(9CR),D=3.813" F-� 09110' -I T X 4-1/2"BKR S-3 PKR,D=3.875" ' 9133' IH4-1/2" S x N (9CR),D=3.813" ' I`9154' 1H4-1/2"HE S XN MP(9CR),MILLED TO 3.80'(11/27/08) 4-1/2"LNR 12.6#,L-80 TCN --I 91ST I ?fis...........1 9156' H T x 5" BKR LTP w/TE BACK,D=4.380" I .0152 bpf,D=3.958" 9167' -I4-1/2"WLEG,D=3.958" T LNR 26#,L-80 BTC, --I 9344' 9170' --17'X 5" BKR LNR HGR,D=4.450" .0383 bpf,D=6.276" 9177' 1--I5"X 41/2"XO,D=3.958" • ► 9785' -1 KB KB LINER TOP PKR,D=2.560" PERFORATION SUMMARY • ' I 9791' -I3.7'DEPLOY SLV,D=3.00" I REF LOG: MC2I-ON 12/11/08 • ' ANGLE AT TOP PERF: 92°@ 11750' • ' • Note:Refer to Production DB for historical pert data • ' FALLOUT WINDOW(C-23C)10677'-10685' SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 2" 6 11750- 12250 0 12/12/08 • 1,7 9842' 1-13-1/2"X 3-3/16"XO,D=2.786" • '''Y. I 10994' -I3-3/16'X 2-7/8"XO,D=2.38T 4-1/2"MONO-BORE WM STOCK(12/07/08) 10675' I RA TAG I- 10684' rrrr PM -I 12257' 4-1/2"LNR, 12.6",L-80 BTC-M, 10820' .0152 bpf,N3=3.958" 3-1/2"LNR,8.81#,L-80 STL,.0087 bpf,D=2.992" -I 9842' I3-3/16"LNR,6.2#,L-80 TCN,.0076 bpf,D=2.80" -I 10994' 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,ID=2.441' 12295' DATE REV BY COMvENFS DATE REV BY CONVENTS PRIDHOE BAY UNIT 09/04/82 ORIGINAL COMPLETION 02/21/12 DAS/JM)SET 4-1/2"PX PLUG(02/20/12) WELL: C-23C 10/17/96 D16 SIDETRACK(C-23A) 05/01/12 JAAD/JND TREE C/O(04/23/12) PERMT No:"2181700 05/18/03 N2E S SIDETRACK(C-23B) 05/10/12 RKT7JND PULLED 4-1/2"PX PLUG(05/08/12' AR No: 50-029-20775-03 12/13/08 NORDIC 1 CTD SIDETRACK(C-23C) 07/18/13 RKT/JND GLV C/0(07/05/13) SEC 19,T11N,R14E,1316'FT"L&1030'FB_ 02/11/09 DBANPJC ORLG DRAFT CORRECTIONS 02/17/12 SCG/JM]GLV x(12/17/081 BP E3mloraion(Alaska) ' aMrC I T I'll/I CO. 1A CLL HIg7LC f V" �! I V I LU.I./mu +[iLf-EA�D= MCEVOY yy RE g SIDETRACKS NOT SHOWN BELOW C 23D CThIATOR= BAKER PROPOSE MILL WINDOWS.***4-112"CHROME NIPPLES MTIAL KB.ELE 71.5' *** 7.ELEV= 39.4' DP= 8575' ' , 2185' -I4-1/2"FES X NP(9CR),D=3.813" Angle le °@ atum MD= 3tum ND= 8800'SS GAS LFT MANDRELS 9-5/8"DV PKR H 2627 ST MD TV D DEV TYPE VLV LATCH PORT DATE 6 3020 3020 1 MMG-M DMY RK 0 05/30/03 5 3992 3989 11 MMG-M DMY RK 0 07/05/13 13-3/8"CSG,72#,L-80,ID=12-347" —I 2694' 4 5788 5515 41 MMCrM DMY RK 0 07/05/13 3 7123 6517 39 MMG-M DMY RK 0 05/17/03 2 8054 7267 34 MMG-M DMY RK 0 05/17/03 Minimum ID =2387" @ 10996' 1 9021 8093 19 KBG-2 DAY BK 0 05/17/03 2-718" XO PIN 8426' H 9-5/8"X 7"BKR LNR TEBACK,D=7.500" 1 8454' H 9-5/8"X 7"BKR ZXP LW w/LNR HGR,ID=6.280" 9-5/8"MLLOUT WNDOW(C-23B) 8580'-8596' 19-5/8"CSG,47#, — 8580' L-80,D=8.681" ' ' 9089' H4-H4-1/2"I-1S,X NP(9CR),ID=3.813" I Ip Ei--H 9110' Hr X 41/2"BKR S-3 PKR,D=3.875" ' 1 9133' H4-1/2"FESXNP(9CR),13=3.813' I I I I 9154' H4-1/2"HES XN NP(9CR),MLLED TO 3.80"(11/27/08) I 1---4 4-1/2"LNR,12.6#,L-80 Tat — 9167' I- 91556• —I 7"X 5' BKR L313 /TLBACK,D=4.380" I .0152 bpf,D=3.958" ' 9167' -I4-1J2"VVLEG,ID=3.958" HA 9170' —17"X 5' BKR LI■R HGR,D=4.450" 7"INR,26#,L-80 BTC, H 9344' r .0383 bpf,D=6.276" 9177' H5"X 4-1/2"X0,D=3.958" TOC —I 9460' I 9460' —I3.7'DEPLOY SLV,ID=3.00" 3-1/2"LNR, #, _, —I I • I---I 3-1/2"X 3-1/4"XO,D= " I . bpf,ID= 4-1/2"KB PKR WHPSTOCK(_/ /___) —I 9760' I MLLOUT WINDOW(C-230) I 41/2"LNR, 12.6#,L-80 BTC-M, —I --9760' — .0152 bpf,ID=3.958° PERFORATION SUMMARY REF LOG: ON 1_/_ ANGLE AT TOP PERF: °@ ' I'bte:Refer to Production DB for historical perf data SIZE SFF INTERVAL Opn/Sqz SHOT SQZ • PBTD I--I X414 -1/4"LNR,—#,__,- bpf,D= " --I 12968' ��1■• DATE REV BY COMVB+TfS DATE REV BY COMMENTS PRUDHOE BAY UNIT 09/04/82 ORIGINAL COMPLETION WELL: C-23D 10/17/96 016 SIDETRACK(C-23A) PERMIT No: 05/18/03 N2ES SIDETRACK(C-2313) AR No: 50-029-20775-04 12/13/08 NORDIC 1 CTD SIDETRACK(C-23C) SEC 19,T11 N,R14E, 1316'FNL&1030'Fa 08/30/13 JMD BUILT PROPOSED BP Exoloration(Alas kal ■ NORDIC-CALISTA RIG 1 CHOKE / REEL/CIRCULATION MANIFOLD DIAGRAM e 7/23/2013 V12 Udo Cassee ■■51. ~- ` V20 I I I V14 e V15 V11 Transducers 71/16"5000 psi BOP'.ID=7.06" rr j POOR BOY - V V2 V1 V/6 rlr ..8.•�+- -,DEGASSER. .ri •-. BOP 2 , 1 III I VII*" NI ii I I BOP 1 `�.. BOP 3 BOP 4 u_ ' To Poor Boy Gas Buster .i. —i V18 V19 It Ais •Ai HCR V9 ■ —• •— Check Valve BOPS Manual Choke BOP6 BOP7 Mir JOU 1`f �� FP LineDiesel FP Line CoFlex Hose 3 S3 05 51 `� _ 114 Turn Halco BOP Cellar manifold lieni 10WOG CM 1 S4 • S6 CM2 CM3 A. _ 'y CoFlex Hose Li Pre. e transducers CM 5 R13 41 To Coiled Tubing Bleed Off Inner Reel Valve ---- — Cement Line In Ground Level Tie-in I CV3 R3 T Stand Pipe R16 - - q an RIO R11 — -=∎ = C MM9 Pressure Tr•users '.� ---"- -" Manual Choke ..�.� In.111.1111 R2. ! MM8 ANIL 4111 Motion 0 R14 R6 PS 4 „ MM7 MM2 0 R1 I MP, MM5 R17 R15 R12 %110... I R5 1...!:,............. r, - Mud Pump 2 �r In From ANN Tiger Tank R7 _ - _ - MM7 • O - r: - Baker Choke MP 1&MP 2 • • CV2 PS 1 to Pits Rig Floor Mud Pump#1 „PS: NM= CV1 Tiger tank law - _ • • To Manifold PS 2 Reverse Circulating line I CT 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. - m r l' �------ T__-`-•---�. ._ T`TTI TATTUNTT DT TT!_ c DTI TIDT il/4/1(111 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ( s r; August 22, 2011 rc4° .ail Mr. Tom Maunder ` 8 & c!s. Alaska Oil and Gas Conservation Commission � Y,ic,,3.M o g Co, 333 West 7 Avenue ' Anchorage, Alaska 99501 a 00 17 0 Subject: Corrosion Inhibitor Treatments of GPB C-Pad , Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- 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, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -128 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 � C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -278 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -358 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 1 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C-42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 DATA SUBMITTAL COMPLIANCE REPORT 3/31 /2010 Permit to Drill 2081700 Well Name/No. PRUDHOE BAY UNIT C-23C Operator BP EXPLORATION (ALASKI~ INC API No. 50-029-20775-03-00 MD 12295 TVD 9020 Completion Date 12/12/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATAINFORMATpN Types Electric or Other Logs Run: MWD DIR / REbuckitS / GR, MCNL / GR /CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D C Asc Directional Survey 10647 12295 Open 1/5/2009 Rpt Directional Survey 10647 12295 Open 1/5/2009 og Neutron 25 Blu 8994 12243 Case 2/23/2009 MCNL, Mem Lee CCL, GR, CNL 11-Dec-2008 ~~ D Lis 17620 neutron 8976 12238 Case 2/23/2009 LIS Veri, GR, CNT t LIS Verification 9414 12993 Open 3/2/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS ~~~ C Lis 17634 Gfnduction/Resistivity 9414 12993 Open 3/2/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS Log Induction/Resistivity 25 Col 10675 12295 Open 3/2/2009 MD MPR, GR 9-Deb-2008 og Induction/Resistivity 5 Col 10675 12295 Open 3/2/2009 TVD MPR, GR 9-Deb-2008 og Gamma Ray 25 Col 10675 12295 Open 3/2/2009 MD GR 9-Deb-2008 og See Notes 5 Col 9410 12260 Open 3/2/2009 Depth Shift Monitor Plot Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments r1 L~ DATA SUBMITTAL COMPLIANCE REPORT 3131 /2010 Permit to Drill 2081700 Well NamelNo. PRUDHOE BAY UNIT C-23C .Operator BP EXPLORATION (ALASKA INC MD 12295 TVD 9020 Completion Date 12/12/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ADDITIONAL INFORMNATION Well Cored? Y X N~ ~ Daily History Received? //~~,, N Chips Received? ~1-RI` Formation Tops lJ/ N Analysis Y-f-N- Received? API No. 50-029-20775-03-00 Comments: Compliance Reviewed By: Date: ~ G v • • INTEQ Lod & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: C-23C '. Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) ' 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) '` 1 color print - MP1Z/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2352790 aofr- ~~ ~ ~G3~/ Sent by: Catrina Guidry Date: 02/27/09 Received by: ( Y - " ;,~ ~ ; Date: r~ ~ ~3 r ~" ~a ,~.~ ~., PLEASE ACKNOWLEDGE RECEIPT >Y~i IYI~IG & .RETURNING OR FAXING YOU OPY ~- FAX: (907) 267-6623 Baker Hughes INTEQ ~% 7260 Homer Drive ~ Anchorage, Alaska 99518 Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 • i W MYAN Y WELL NAME FIELD BAKER MVliMES Saker Atlas PRINT DISTRIBUTION LIST BP I::XPLUKA'1'lUN (ALASKA) INC CUUN'1'Y NUK'1'H SLUYE BUKUU(iH C-23C STATE ALASKA PRUDHOE BAY UNIT DATE Z/27/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: CATRINA GUIDRY SO #:2352790 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC 1 Company DNR - I)IVISTON OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE, AK 99508 ANCHORAGE, AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston. Texas 77073 This Distribution List Completed Bv: ~b~"~~ Page 1 of 1 02/18/09 r~ h l~ l~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth wou _InM ,e N0.5089 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 .....,.,.,,. ...:,. R-40 AWJI-00012 MEMORY GLS ( ~ (p 12/12/08 1 1 P2-35 AWL9-00010 BAKER IBP/CROSSFLOW DETERM - ( 01/02!09 1 1 P2-20 AYTO-00004 PRODUCTION PROFILE d L 02/05/09 1 1 4-10A/L-28 AYKP-00009 IBP/CROSSFLOW DETERMINATION U - 02/04/09 1 1 B-36 11999060 RST (~/ - _ /' 11/10/08 1 1 11-32 12071914 RST C _ 11/30/08 1 1 C-23C AXOY-00006 MCNL a 12/11/08 1 1 L2-16 12071912 _ RST ~- 11/28/08 1 1 L2-32 12113026 RST ~~ '~- 12/07/08 1 1 L2-24 12113025 RST ~ 12/06/08 1 1 «.+.a~ r+v r~,~v vr~cVVG nCVCIf 1 0 ~ AIVIIV IIrV NIYN 17C1 UISIYIIVU VIVC I.VF'T CN~.r1 1 V: BP Exploration (Alaska) Ina _ _ _ Petrotechnical Data Centel ~#ti'~ ~ _„, „ ,! ~ 900 E. Benson Blvd. ,„~.~, .~~, , Anchorage, Alaska 99508 Date Delivered: ~' ~_~~~ ,~ ~/~-~~16~~ ;, n ,. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 't Anchorage, AK 99503-28 8 ATTN: Beth ~\ t ReceivedReceived by: 1 ~~~ O9 ~~ WELL COMPLETION OR RECOMPLETION REPORT AND Lt~ska ®~J ~ has Cons. CDmmi ' sslon 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.,os zonAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban 12/'!1/2008 12. Permit to Drill Number 208-170 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/8/2008 / 13. API Number 50-029-20775-03-00 ° 4a. Location of Well (Governmental Section): Surface: ' 7. Date T.D. Reached 12/9/2008 ~ 14. Well Name and Number: PBU C-23C FEL, SEC. 19, T11N, R14E, UM 1315' FNL, 1030 Top of Productive Horizon: 4362' FNL, 1802' FEL, SEC. 19, T11 N, R14E, UM 8. KB (ft above MSL): 65.6' - Ground (ft MSL): 37' 15. Field /Pool(s): _ Prudhoe Bay Field / Prudhoe Bay Total Depth: 2953' FNL, 3243' FEL, SEC. 19, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 12257' 9017' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): x- 664349 y- 5959903 Zone- ASP4 Surface: 10. Total Depth (MD+TVD) 12295' 9020' 16. Property Designation: ADL 028305 . TPI: x- 663655 y- 5956841 Zone- ASP4 - 5958218 Zone- ASP4 th 662178 T t l D 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: : x- y o a ep 18. Directional Survey ®Yes ^ No mi el r ni rin inf rmati n 2 . 0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 2 AAC 25.071): MWD DIR / RES / GR, MCNL / GR / CCL L///t~~~/G~ /O6 ~i~l~ 9~a70 ~.S~TYd 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 11 r rf 8' rf _ ~~ ~ ~ ~~ A /" 47# L- rf rf 1- J4" 1 CI 1 I L- 4 7' 4 -/" 2 I " 1' 1/ " I ' 3-1/2" x 3-3116" x 2-7/8" a.a,a i s.z# i s.,sn 978 ' 8 7 ' ' -1 /8" C I S 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i f T & B P MD+TVD tt nterval open Si nd Number): f ti .SIZE DEPTH .SET MD PACKER SET MD om; er ora on ze a ( o op o 6 spf 2" Gun Diameter 4-1/2", 12.6#, L-80 9167' 9110' , MD TVD MD TVD 11750' - 12250' 9020' - 901 T 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC.. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected w/ McOH 26. PRODUCTION TEST Date First Production: January 10, 2009 Method of Operation (Flowing, Gas Lift, etc.): Flowi Date Of Test: 1!11/2009 HOUrS Tested: 6 PRODUCTION FOR TEST PERIOD OIL-BBL: 246 GAS-MCF: 5,428 WATER-BBL: 13 CHOKE SIZE: 96 GAS-OIL RATIO: 22,114 Flow Tubing Press. 680 Casing Press: 1,000 CALCULATED 24-HOUR RATE..' OIL-BBL: 982 GAS-MCF: 21,712 WATER-BBL: 52 OIL GRAVITY-API (CORK): 38 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None /~%7-OP' . ~ '~ JAtu ~ 9 ?009 ~, ,W-, STATE OF ALASKA /'~2~ ALASKA~L AND GAS CONSERVATION COMI'~ION `~A~320 ED Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ., . `ra ~~ 28. GEOLrJGIC MARKERS (LIST ALL FORMATIONS AND RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD WeIlTested. Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kicked off in Zone 2A (21TS) 9988' None from parent well (C-236), and stayed in that zone to TD. Formation at Total Depth (Name): Zone 2A / 21 TS 9988' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Signed Terrie Hubble Title Drilling Technologist Date PBU C-23C 208-170 Prepared ey IVameMumber. Terrie Hubble, 564-4628 Well Number r i / r Drilling Engineer: Charles Reynolds, 564-5480 INSTRUCTIONS GerreRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production ftom each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of pemtaftost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production ftom more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IrerN 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only • BP EXPLORATION Operations Summary Report Page 1 of 8 ~ Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: ' Date From - To i Hours '', Task Code !, NPT ~ Phase Description of Operations 12/5/2008 04:00 -06:00 2.00 ~ __ - I MOB P I PRE Move rig from C-30A to C-23C. 06:00 - 10:00 4.001 RIGD P I PRE 10:00 - 12:00 I 2.001 BOPSUp P I I PRE 12:00 - 13:00 1.00 BOPSU N PRE 13:00 - 19:00 6.00 BOPSU P PRE 19:00 - 21:15 2.25 RIGU P PRE 21:15 - 21:30 0.25 BOPSU P PRE 21:30 - 23:15 1.75 RIGU P PRE 23:15 - 00:00 0.75 RIGU P PRE 12/6/2008 00:00 - 01:45 1.75 RIGU P PRE 01:45 - 03:00 1.25 RIGU P PRE 03:00 - 05:00 2.00 RIGU P PRE 05:00 - 06:00 1.00 WHIP P WEXIT 06:00 - 08:00 2.00 WHIP P WEXIT 08:00 - 08:40 0.67 WHIP P WEXIT 08:40 - 09:00 0.33 WHIP P WEXIT 09:00 - 10:40 1.67 WHIP P WEXIT 10:40 - 12:15 1.58 WHIP P WEXIT ~` _ ~_ :15 - 14:00 1.75 TW IP P WEXIT 3~'T 14:00 - 14:15 0.25 STWHIP N WEXIT C23~- 14:15 - 15:10 0.92 STWHIP P WEXIT 15:10 - 15:50 0.67 STWHIP P 15:50 - 18:30 2.67 STWHIP N 18:30 - 22:50 4.33 STWHIP N MU 7-1/16" Valve to bottom of BOP stack. Spot Rig Over Well ACCEPT RIG ~ 06:00 NU BOP Test BOP. AOGCC rep John Crisp waived witnessing BOP test. Repair test pump. Continue to BOP test. RU lubricator, test to 2000 psi, Pull BPV Shut in P - 2350 psi Test inner reel valve and chart PJSM, bleed off pressure to the TT, initial shut-in pressure 2425 psi. Bleed down to 1570 psi Pump 260 bbl of KCI through kill line, pump at 3.75 bpm At 120 away Shut in - 0 psi, Continue pumping KCL Continue pumping 260 bbl KCI, pump 30 bbl pill, pump 160 bbl milling fluid pumping at 3.8 bpm Well Dead... Pump slack and cut 375' coil Install CTC, Behead eline Bring WS to rig floor, install pip tags, MU WS setting BHA RIH to 9453 Log tie-in. Correction -17'. RIH Orient WS 90 LHS. Place WS top At 10675'. Close EDC and pressure to 4350 to shear. POH LD WS BHA and PU milling BHA RIH Tag XN. ~ 9 67.5'. No GO. Check Baker job log. Check BP tubing tally to confirm tail pipe BakerLocked OK. Ream XN nioole. 2.61 bpm 2660 psi. Stall 9167.83' Ream MW 50 psi at 9167.76, MW to 9167.82 , 9168.03 MW 600 psi to 9168.07. 600 psi MW 9168.22 -9168.24. Ream w/o motor work to 9178. PU to 9130 RIH MW 9147.8 (X nipple) .Passed XN. Slight MW. RIH to window. MWD gamma failed after reaming waived tie-in. RIH Tag WS at 10674. Gas in returns. Time mill 2.57/2.54 bpm ~ 2615 psi. ECD 9.48 Time mill 2.57/2.57 bpm ~ 2590 psi, 1.63k DHWOB, 9.49 ppg ECD ~ 10676.8 CTD MD 2.55/2.54 bpm @ 2552 psi, 1.61k DHWOB, 9.48 ppg ECD ~ 10677.7 CT MD 2.55/2.55 bpm ~ 2527 psi, 1.64k DHWOB, 9.48 ppg ECD ~ 10678.5 CT MD, PVT = 298 2.55/2.55 bpm C~ 2523 psi, 1.65k DHWOB, 9.47 ppg ECD @ 10679.2 CT MD, PVT =298 2.55/2.53 bpm ~ 2520 psi, 1.63k DHWOB, 9.47 ppg ECD ~ 10679.4 CT MD, PVT = 297 2.54/2.52 bpm ~ 2490 psi, 1.63k DHWOB, 9.47 ppg ECD C~ 10680.5 CT ME, PVT = 296 WEXIT DFAL WEXIT DFAL WEXIT Printetl: 12/22/2008 1:27:56 PM C~ BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: Date ~~ From - To Hours Task ~ Code NPT Phase Description of Operations 12/6/2008 22:50 - 00:00 1.17 STWHIP N DFAL WEXIT DHWOB is not changing and there has been no motor work from 11680-11682'. PU, zero DHWOB, then RIH at 180 fpm and tag at 10694' twice. Mud samples show pipe scale and cement. With the previous -17' correction it appears that we were milling on cement at 10674' CT MD and that the TOWS is at 10694' CT MD. PU and creep in hole to TOWS. Trouble getting started with frequent stalling. 12/7/2008 00:00 - 00:30 0.50 STWHIP N DFAL WEXIT Correct TOWS depth from 10693' to 10675'. Difficulty getting started w/frequent stalling: 00:30 - 02:15 1.75 STWHIP N DFAL WEXIT Tme Mill 2.55/2.54 bpm ~ 2516 psi, 02:15 - 04:15 2.00 STWHIP N DFAL WEXIT Time Mill 2.53/2.52 bpm ~ 2495 psi, 9.46 ECD, 0.19k DHWOB, 10675.15', PVT = 295 Time Mill 2.48/2.47 bpm C~ 2424 psi, 9.44 ECD, 0.31 k DHWOB, 10675.45, PVT = 294 Frequent stalling, reduce pump rate to 2.34bpm, FS=2280psi. ~pable to aet started milling. POH to inspect mill and PU new DGS. 04:15 - 06:00 1.75 STWHIP N DFAL WEXIT POH PJSM for LD milling BHA 06:00 - 07:30 1.50 STWHIP N DFAL WEXIT L/D Milling BHA Mill measured 3.77 Go/ 3.76 No Go. PU new mills, DPS and DGS 07:30 - 09:40 2.17 STWHIP N DFAL WEXIT RIH to 9520. NO problem thru tailpipe assy. 09:40 - 10:00 0.33 STWHIP N DFAL WEXIT Lo tie - in. Correction -19'. 10:00 - 10:20 0.33 STWHIP N DFAL WEXIT RIH to at 10678 w/o um s. 10:20 - 18:00 7.67 STWHIP P WEXIT Mill window 10677 2.56/2.56 ~ 2465 psi. Time mill .05 ft / 6 min WOB 1-4K ECD 9.42 18:00 - 20:45 2.75 STWHIP P WEXIT Mill window 2.58/2.57 ~ 2633 psi, WOB 2.13K, ECD 9.42, 10683.9' 2.59/2.59 ~ 2710 psi, WOB 2.4K, ECD 9.42, 10684.6', 20-30% Sand in Sample, BOW 2.52/2.5 X2650 psi, WOB 1.79K, ECD 9.42. 10684.9' Start milling 10' of rathole, ream window 3 times 1'/min, swap wellbore over to FloPro 20:45 - 22:00 1.25 STWHIP P WEXIT POOH 22:00 - 22:15 0.25 STWHIP P WEXIT PJSM for LD BHA and PU drilling BHA 22:15 - 23:00 0.75 STWHIP P WEXIT LD window millin BHA Mill gauged 3.79", string reamer 3.8" 23:00 - 23:45 0.75 DRILL P PROD1 MU drilling BHA, HYC Bicenter bit, Xtreme motor, HOT, USMPR, DGS, DPS Sub, EDC, P&C, Sub Wear, LOC, UOC, XO, CTC Total Length - 79.02' 23:45 - 00:00 0.25 DRILL P PROD1 RIH 12/8/2008 00:00 - 02:15 2.25 DRILL P PROD1 RIH and tie-in (-15'), finish RIH 02:15 - 03:15 1.00 DRILL P PROD1 Drill sidetrack 2.42/2.39 bpm, C~ 3100 psi, FS 2870 psi, ECD 9.9, 2.2K WOB, ROP 90-100 fph, 270 TF, PVT 309 03:15 - 04:15 1.00 DRILL P PROD1 Drill Z2A sidetrack 2.42/2.40 ~ 3200 psi, FS 2880 psi, ECD 9.9, 1 K WOB, ROP 100, 280 TF, PVT 312 Drill to 1080 'wiper Continue drilling 2.47/2.46 C~ 3250 psi, FS 2900 psi, ECD 10, 1.1 K WOB, ROP 120, 280 TF, PVT 317 Drill to 10890' 04:15 - 04:25 0.17 DRILL P PROD1 Wiper trip to window Printed: ivzyzuus 1:"Ll:bti PM ! ~ BP EXPLORATION Operations Summary Report Page 3 of 8 Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2008 04:25 - 05:30 1.08 DRILL P PROD1 Drill Z2A sidetrack 2.54/2.54 ~ 3400 psi, FS 2975 psi, ECD 10, 0.84K WOB, ROP 120-170, 201 TF, 92 deg near bit, PVT 320 BOPS variable but very high 05:30 - 05:45 0.25 DRILL P PROD1 Wiper trip to window 05:45 - 06:10 0.42 DRILL P PROD1 Continue driling to 11048. Suspect HOT failure (appears to be 95 degrees out) 06:10 - 08:15 2.08 DRILL N DFAL PROD1 POH 08:15 - 10:00 1.75 DRILL N DFAL PROD1 Change out MWD BHA. 10:00 - 12:00 2.00 DRILL N DFAL PRODi RIH 12:00 - 12:40 0.67 DRILL N PRODi Log tie-in. Correction -19.5'. 12:40 - 12:50 0.17 DRILL N PRODi RIH tag at 11049. 12:50 - 14:00 1.17 DRILL P PROD1 Drill 2.52/2.51 bpm ~ 3160 psi, FS = 2900 spi, WOB 1.6K,ECD 9.91 ppg, Drill to 11200. 14:00 - 14:30 0.50 DRILL P PRODi Wiper to window. 14:30 - 16:45 2.25 DRILL P PROD1 Drill 2.55/2.54 bpm C~3 3545psi, WOB 4.6k, ECD 10.12 ROP 30-130. Drill to 11350. 16:45 - 17:15 0.50 DRILL P PROD1 Wiper to window 17:15 - 18:30 1.25 DRILL P PROD1 Drill 2.55/2.53 bpm ~ 3700 psi, FS= 3080 psi, WOB 3.1 K , ROP 55. ECD 10.14ppg. Drill to 11500 18:30 - 20:00 1.50 DRILL P PROD1 Wiper trip to 10,100', Log GR tie-in (+1), RIH 20:00 - 22:15 2.25 DRILL P PROD1 Drill 2.50/2.50 @ 3300 psi, FS - 3000 psi, WOB 1.6K, ECD 10.16 Fight hard spot at 11620' ROP - 10-30 fph 22:15 - 23:00 0.75 DRILL P PROD1 Drill 2.54/2.55 Cad 3400 psi, FS 3000 psi, WOB 2.73K, ECD 10.23, ROP 40-60 Drill to 11642' 23:00 - 23:45 0.75 DRILL P PROD1 Wiper trip to window 23:45 - 00:00 0.25 DRILL P PROD1 Dril 2.52/2.45 C~ 3500 psi, 3100 FS, ECD 10.22, ROP 80-100 Drill to 11655' 12/9/2008 00:00 - 02:00 2.00 DRILL P PROD1 Drill 2.54/2.50 @ 3700 psi, FS 3150 psi, ECD 10.3, DWOB 2.2K, ROP variable, average 100, Drill to 11,800' Start mud swap 02:00 - 03:30 1.50 DRILL P PROD1 Wiper trip to window 03:30 - 04:30 1.00 DRILL P PROD1 Drilling 2.57/2.56 ~ 3540 psi, FS 3100 psi, ECD 10.1, DWOB 2.2K, ROP 110-120, Drill to 11950' 04:30 - 06:00 1.50 DRILL P PROD1 Wiper trip to 10,100', GR tie-in (+1 correction), continue RIH 06:00 - 07:30 1.50 DRILL P PROD1 Drilling 2.4/2.3 ~ 3300 psi, FS= 2950 psi, WOB 1.1 K, ECD 10.12 ppg, ROP 150+. Drill to 12100. 07:30 - 08:50 1.33 DRILL P PROD1 Wiper to window. 08:50 - 09:30 0.67 DRILL P PROD1 Drilling 2.52/2.49 C~ 4360 psi FS =3060, WOB 1.9K, ROP 100+, ECD 10.14 09:30 - 12:30 3.00 DRILL N SFAL PROD1 Lost SLB Computer Pump one down . PU off bottom circulate across top of hole. Open EDC POH to 9900 circulate 2.4 bpm. Park coil above window while replacing SWS computer. 12:30 - 13:15 0.75 DRILL N SFAL PROD1 RIH to bottom. 13:15 - 15:00 1.75 DRILL P PROD1 Drill Z2 lateral, 2.5 bpm, 3200 psi free spin, 1-5K WOB, 86 deg incl, 9.8 ECD, Stacking wt. Drilled to 12273'. 15:00 - 16:20 1.33 DRILL P PRODi Wiper trip to window. RIH to bottom. 16:20 - 18:00 1.67 DRILL P PROD1 Drill Z2 lateral, 2.5 bpm, 3200 psi free spin, 1-4 K wob, 86 deg incl, 9.8 ecd, Stacking wt, Drilled to 12,294'. 18:00 - 19:15 1.25 DRILL P PROD1 Drill Z2, 2.51/2.47, 3200 FS, ~ 3280 psi, 1 K DWOB, 87 incl, 10.3 ECD, ROB 0-10, Drill to 11299' Printed: 12/22/2008 1:21:56 PM BP EXPLORATION Page 4 of 8 Operations Summary Report Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: i Date From - To Hours Task Code NPT 'I Phase Description of Operations 12/9/2008 19:15 - 20:00 0.75 DRILL P PROD1 Final wiper to window 20:00 - 21:00 1.00 DRILL P PROD1 Log GR tie-in (+1), RIH to TD, tag w/ pumps on, PU and tag again. TD 12.296"_ 21:00 - 23:30 2.50 DRILL P PROD1 POOH, lay in liner pill 23:30 - 23:45 0.25 DRILL P PRODi PJSM for LD drilling BHA `CH2 will not bring out fuel and water because of a concern that it will go to phase 3, fuel truck will not come until weather lets up 23:45 - 00:00 0.25 DRILL P PROD1 LD Drilling BHA 12/10/2008 00:00 - 01:00 1.00 DRILL N WAIT PROD1 Shut in well, keep coil circulating, waiting on weather conditions to continue, 30" of fuel left (1500 gal) 01:00 - 01:15 0.25 CASE P RUNPRD PJSM for loading tools up to rig floor 01:15 - 05:00 3.75 CASE P RUNPRD Load Baker tools onto rig floor, pump slack out of coil, cut 306' of eline, cut CTC off Fuel truck and convoy showed up despite weather not letting up, Phase 2. 05:00 - 07:00 2.00 CASE P RUNPRD Install Baker CTC, Pull test, prep to run 2-7/8" X 3-3/16" Liner. 07:00 - 07:15 0.25 CASE P RUNPRD SAFETY MEETING. Review procedure, hazarads and mitigation for running liner with Baker SELRT. 07:15 - 12:00 4.75 CASE P RUNPRD Run 2-7/8" liner with Turbos and Baker equipment, Adjust SWS Farr tongs to grip and release. New brake bands. M/U Indexing guide shoe, Flt Cllr, 1 jt 2-7/8" STL, Flt Cllr, Pup Jt, Landing Cllr, 40 jts, 2-7/8" STL liner with Turbos. and one 10' 2-7/8" STL pup jt, Fill liner with water. 12:00 - 15:00 3.00 CASE P RUNPRD M/U XO, 36 jts 3-3/16" TCII Liner with Turbos, XO, 1 Jt 3-1/2" STL liner, 10' pup 3-1/2" STL Liner and Baker Deployment sleeve. M/U SELRT, XO, 6 jts, 2-3/8" PH6, XO, Swivel and CTC. finer total len th = 2 503.62' Liner BHA total length = 2,705.48'. 15:00 - 16:40 1.67 CASE P RUNPRD RIH with liner on coil. circ at 0.2 bpm, 1400 psi with full returns. Up wt at 10650' = 41 K , Dwn wt = 19K 16:40 - 17:05 0.42 CASE P RUNPRD R H thru window clean. RIH at 70 fpm, circ at 0.2 bpm, 1500 psi, full returns. Lost wt at fault at 11600' and fell thru. Dwn wt at 12200' = 14K. Landed liner at 12 308' uncorrected. Set down 2 times a same depth. Up wt = 43K. To of liner at 9791'. PBTD at 12 255' 17:05 - 19:10 2.08 CASE P RUNPRD Insert 5/8" AL ball to release from liner. Displace with FloPro. Pump 1.8 bpm for 40 bbls. Slow pump to 0.7 bpm. Ball not on seat at 70 bbls. Inc to 1.2 bpm at 2100 psi. Ball not on seat at 88 bbls. Surge pump from 0-1.3 bpm. circ at 1.2 bpm to 105 bbls. Ball not on seat. Inc pump to 1.6 bpm, full returns with FloPro. Pump 130 bbls. Ball not on seat. Pick up at 43K, still have liner. 19:10 - 20:00 0.83 CASE P RUNPRD Insert second 5/8" AL ball. Displace with FloPro at 1.5 bpm, 2400 psi. Ball on seat at 52.2 bbls. Coil volume was 56.2 bbls. Sheared at 4400 si. Pick u free at 36K. Printetl: 12/22/2008 1:21:56 PM • BP EXPLORATION Operations Summary Report Page5of8~ Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: Date From - To ~ Hours ''I Task Code ~ NPT Phase Description of Operations 12/10/2008 20:00 - 20:15 0.25 CEMT P RUNPRD Circ well to 2% double slick KCL water. 20:15 - 20:30 0.251 CEMT P 20:30 - 23:15 2.751 CEMT P 23:15 - 00:00 I 0.751 CEMT ~ P 12/11/2008 100:00 - 00:45 I 0.751 CEMT I P 00:45 - 02:00 1.25 CEMT P 02:00 - 02:15 0.25 CEMT P 02:15 - 03:00 0.75 CEMT P 03:00 - 06:00 3.00 EVAL P 06:00 - 07:35 I 1.581 EVAL I P 07:35 - 08:10 I 0.58 I EVAL I P 08:10 - 09:15 1.08 EVAL P 09:15 - 12:00 2.75 EVAL P 3.01/2.97, Circ p 1545 psi 2.85/2.80, circ p 1417 psi 2.55/2.49, circ p 1200 psi 1.95/1.89, circ p 800 psi 1.51/1.44, circ p 525 psi 1.04/1.00, circ p 300 psi, 4% fluid loss with KCL on formation, RUNPRD PJSM for cement job, review procedure, hazards and mitigations RUNPRD Circ well while Batch cement Cement at weight ~ 23:00 Stage 5 bbl 2% KCI, PT to 4500 psi. RUNPRD Stage 29 bbl, 15.7 ppg, G cement. 2.0 BPM, 1200 psi Stop pump at 29 bbl cement. 2.0 bpm, 1900 psi. Close reel valve. Pump 2# Biozan to cement line, vac cement line. Stage 2# Biozan, 2.0 bpm, 1100 psi 10 bbl displ, 2.1 bpm, 1.8 bpm returns, 950 psi 20 bbl displ, 2.1 bpm, 1.9 bpm returns, 700 psi 30 bbl displ, 2.0 bpm, 1.9 bpm returns, 800 psi 40 bbl displ, 2.0 bpm, 1.9 bpm returns, 1350 psi. 43.6 bbl displ, cement at shoe, zero out totalizer. 50 bbl displ, 2.0 bpm, 1.9 bpm returns, 1550 psi 54.2 bbl displ, stop pump, 2 bbl cement left inside coil. Pick up free at 36K, Pick up 13'. Circ 5 bbl to backside. Open Baker choke. RIH to same depth and wt. Close Baker choke. Pumping ~ 2.48/2.39, Bump LWP at 75.9 bbl displ (75.7 calculated) Pressure up to 2400 psi, floats held Out totalizer indicates 30.1 bbls return (25 bbl behind pipe) RUNPRD Pressure up to 500 psi, PU out of liner, let pressure drop ai POOH replacing voidage RUNPRD POOH w/SELRT RUNPRD PJSM for LD of SELRT, discuss procedure hazards and mitigations RUNPRD LD SELRT BHA, both balls were recovered LOWERI PU mill motor dual circ sub, HYD DISC, XO, 42 stands of CSH, XO, BOT HYD disc, DBPV, XO, 4 jts of PH6, XO, XO, Lockable swivel, XO, XO, BOT CTC Total length 2751.30' LOW ERi RIH w/ cleanout BHA cement at 1000 psi at 06:45. RIH clean to 9811'. Tagged Baker AL profile in bottom of deployment sleeve. LOWERI Mill out Baker AL profile to 2.30". One stall when first tagged. Milled thru it in 25 min. Back reamed and reamed down 2 times clean. 1.5 bpm, 1850-2100 psi, full returns. Dump contaminated cement returns to cuttings tank. LOWERI RIH with mill /motor at 40 fpm, 1.5 bpm, 1880 psi LOWERI ~ POH with mill /motor, circ at 1.5 bpm, 1600 psi. Nrinted: iyzyzuue i:zi:°° rnn • BP EXPLORATION Page 6 of 8 Operations Summary Report Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: Date From - To 'i Hours Task Code NPT ~ Phase Description of Operations 12/11/2008 12:00 - 12:15 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH workstring and BHA. 12:15 - 14:30 2.25 EVAL P LOWERI Standback PH6 tubing and CSH workstring. 14:30 - 14:45 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U swizlestick to jet cement from stack. 14:45 - 15:00 0.25 BOPSU P LOWERi FUNCTION TEST BOPS for week) AOGCC required function test. All BOPE functioned OK. 15:00 - 15:45 0.75 EVAL P LOWERI M/U Swizle stick BHA and jet stack. Swab valve is closed. Circ at 3 bpm, 1200 psi. 15:45 - 16:00 0.25 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U SWS memory CNL/C.R%C~~- 16:00 - 17:45 1.75 EVAL P LOWERI M/U SWS Memory MCNL/GR/CCL logging BHA with carrier. BHA #8. with 42 stds of CSH and 4 jts PH6. BHA OAL = 2763.61'. 17:45 - 20:00 2.25 EVAL P LOWERI RIH with SWS memory CNL/GR logging BHA. Circ at 0.5 bpm, 250 psi. 20:00 - 22:15 2.25 EVAL P LOW ER1 Log down from 9000' to PBTD at 30 fpm, PBTD tagged at 12264' ncorrected 22:15 - 23:00 0.75 EVAL P LOWERI Log up from PBTD to 9000' at 60 fpm, lay in pert pill 23:00 - 00:00 1.00 EVAL P LOWERI POOH 12/12/2008 00:00 - 00:30 0.50 EVAL P LOWERI Continue POOH 00:30 - 00:45 0.25 EVAL P LOWERI PJSM for LD logging BHA, discuss procedure, hazards, and mitigation 00:45 - 02:30 1.75 EVAL P LOWERI LD PH6, and CSH workstring 02:30 - 02:45 0.25 EVAL P LOWERI PJSM for source handling 02:45 - 03:30 0.75 EVAL P LOWERI Unload source from tool, LD logging tools. Sent log information to Anc. PBTD = 12,256' from memory log. 03:30 - 05:00 1.50 CEMT P RUNPRD Test Liner lap to 2000 psi. Lost 268 psi in 30 min. Lost 143 psi in first 15 min and 125 psi in last 15. 05:00 - 05:15 0.25 PERFO P LOWERI PJSM for PU perf guns, discuss procedure, hazards and mitigations 05:15 - 06:30 1.25 PERFO P LOWERI PU 515' of perf guns 06:30 - 06:45 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for RIH with CSH workstring and rest of BHA for perforating. 06:45 - 08:00 1.25 PERFO P LOWERI RIH with 34 STDS 1-1/4" CSH and 2 jts of PH6 and MHA. Perf BHA OAL = 2698.82'. 08:00 - 09:40 1.67 PERFO P LOWERI RIH with SWS 2" PJ perf gun BHA with 500' of puns loaded at 6 SPF. Circ at 0.2 bpm, 80 psi. RIH clean to PBTD. Tag bottom at 12,266'. Correct depth to 12,256'. Up wt = 38K. Pump 7 bbl new FloPro perf pill ahead of ball. 09:40 - 10:45 1.08 PERFO P LOWERi Insert 1/2" AL ball, Pump 7 bbl FloPro behind ball. Position bottom erf ch r e at 1 Circ. 2.0 bpm, 2900 psi for 45 bbl. slow pump to 1.0 bpm 900 psi. Ball not on seat at 60 bbl, Inc pump to 1.4 bpm, 1300 psi. Inc pump to 1.6 bpm, 1600 psi at 65 bbl. Ball on seat at 78 bbl. Fired guns on depth, good shot detection. Up wt = 38K, no overpull. 10:45 - 12:45 2.00 PERFO P LOWERI POH with perf guns, circ at 0.6 bpm, 300 psi. Printed: 12/22/2008 1:21:56 PM • BP EXPLORATION Qperations Summary Report Page 7 of 8 ~ Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: Date ;From - To Hours Task !Code NPT Phase ', ...Description of Operations 12/12/2008 10:45 - 12:45 2.00 PERFO P LOW PERFORATED INTERVAL: 11,750' - 12,250'. 500' PERFS AT 6 SPF, 2" PJ POH. Flow check at surface, no flow. 12:45 - 13:00 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for Standing back 34 stds of CSH workstring. 13:00 - 14:00 1.00 PERFO P LOWERi Stand back CSH in doubles. 14:00 - 14:15 0.25 PERFO P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for Recovering SWS 2" fired pert guns. 14:15 - 16:10 1.92 PERFO P LOWERI Lay out SWS 2" fired pert guns, 500', all shots fired., Load out fired guns out of pipe shed. 16:10 - 16:20 0.17 CASE P RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U Baker 4-1/2" liner top packer BHA. 16:20 - 17:00 0.67 CASE P RUNPRD M/U Baker 45 KB Liner top Packer BHA with running tool and 2 jts PH6. BHA OAL = 83.83'. 17:00 - 19:00 2.00 CASE P RUNPRD RIH with Baker 4.5 KB Liner top packer with running tools. Circ at 0.3 BPM, 90 psi 36K up weight 19:00 - 19:45 0.75 CASE P RUNPRD 9801' ressure u ,seals in, 9808' No go PT LTP again w/ 2000 psi on backside , Lost 220 psi in the first 15 mins, failed test, bleed off pressure Circulate through coil 19:45 - 22:30 2.75 CASE P RUNPRD PU to 9785', Launch 5/8" AL ball, 1.97/1.85, 910 psi drop pump rate, 0.66 bpm, 172 psi 66 bbl away, ball not on seat, Cycle pumps to try and get ball down to seat, 85 bbls away and ball not on seat, check for ball in reel Drop 5/8" Steel ball, 1.7/1.63, 715 psi, Drop pump rate at 40 bbl, Ball on seat at 47.3 bbl Sting back in and stack out at 9801', Pressure up to 2500 psi, SO 10K on it 22:30 - 23:00 0.50 CASE P RUNPRD PT to 2000 psi, held jug tight lost 0 psi, Pressure u to 3250 si ~ to h draulicall release from acker .PU from packer 23:00 - 00:00 1.00 CASE P RUNPRD POOH to 2000' 12/13/2008 00:00 - 01:15 1.25 WHSUR P POST POOH to 2000', FP well w/ 60/40 MEOH 01:15 - 01:30 0.25 CASE P RUNPRD PJSM for LD LTP setting BHA, discuss procedure, hazards and mitigations 01:30 - 02:15 0.75 CASE P RUNPRD LD LTP setting BHA Clean pits 02:15 - 02:30 0.25 BOPSU P POST PJSM for Setting BPV, discuss procedure hazards and mitigations 02:30 - 03:30 1.00 WHSUR P POST D Rod BPV 03:30 - 03:45 0.25 RIGD P POST PJSM for reel blowdown, discuss procedure, hazards and mitigations 03:45 - 05:45 2.00 RIGD P POST Pump 35 bbl fresh water, pump MEOH, Slowdown reel w/ N2, let pressure bleed down 05:45 - 06:00 0.25 RIGD P POST Pop off and stand back injector Clean cuttings box 06:00 - 06:15 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and mitigation for N/D BOP stack and N/U Tree cap. Printed: tzrzvzous t:zt:5ti rm n BP EXPLORATION Page 8 of 8 Operations Summary Report Legal Well Name: C-23 Common Well Name: C-23 Spud Date: Event Name: REENTER+COMPLETE Start: 12/3/2008 End: 12/13/2008 Contractor Name: NORDIC CALISTA Rig Release: 12/13/2008 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Task Code' NPT Phase Description of Operations 12/13/2008 06:15 - 08:30 2.25 RIGD P POST N/D BOP stack and N/U tree cap. Press test cap with 3500 psi. RELEASED RIG AT 0830 HRS, 12/13/2008_ TOTAL OF 8 DAYS, 2-1/2 HOURS FROM RIG ACCEPT TO RELEASE. ALL FURTHER RIG /DIMS INFORMATION WILL BE UNDER WELL DS 15-15 18 MILE DERRICK UP RIG MOVE TO DS 15-15 MOVE OFF OF C PAD AT 1000 HRS Printed: 12/22/2008 1:21:56 PM . ~ BP Alaska. ~ ~~'~ Baker Hughes INTEQ Survey Report •r..i~ B ~ HEs l.A• LL' l~[ Company: BP Amoco Date: 12/10/2008 Time: 09:36:18 Page: 1 '~ Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: C-23, True North Site: PB C Pad Vertical (TVD) Reference: C-23B: 65.6 i Well: ~ C-23 Section (VS) Reference: Well (O.OON,O.OOE,233.43Azi) ~ Wellpath: C-23C 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 C Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5957218.72 ft Latitude: 70 17 22.367 N From: Map Easting: 662550.03 ft Longitude: 148 41 2.797 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: C-23 Slot Name: C-23 Well Position: +N/-S 2644.94 ft Northing: 5959903.00 ft Latitude: 70 17 48.378 N +E/-W 1856.71 ft Easting : 664349.00 ft Longitude: 148 40 8.677 W Position Uncertainty: 0.00 ft Wellpath: C-23C Drilled From: C-236 500292077503 Tie-on Depth: 10647.94 ft Current Datum: C-23B: Height 65.60 ft Above System Datum: Mean Sea Level Magnetic Data: 10/23/2008 Declination: 22.99 deg Field Strength: 57682 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 32.60 0.00 0.00 233.43 Survey Program for Definitive Wellpath Date: 12/1/2008 Validated: Yes Version: 3 Actual From To Survey Toolcode Tool Name ft ft 94.10 8494.10 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 8581.00 10647.94 C-23B (8581.00-10775.38) (1) MWD+IFR+MS MWD +IFR + Multi Station 10674.50 12295.00 MWD (10674.50-12295.00) MWD MWD -Standard Annotation _. __ _ - - !, MD T~'ll ft ft 10647.94 __ - --- 9020.43 TIP 10674.50 9020.43 KOP 12295.00 9020.47 TD Survey: MWD Start Date: 12/8/2008 Company: Baker Hughes INTEO Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path w ~~1 '~ BP Alaska BAKER NU6NES Baker Hughes INTEQ Survey Report iNTEQ Comp )na BP Amoco field: Prudhoe Bay Sile: PB C Pad ~'Vell: G23 Wellpath: G23C Survey 11D [ncl ft deg __- Azim deg D ft - Sys TVD ft - N/S ft Date: 12/10/2008 Time: 09:36:18 Pagr. 2 Co-ordinate(NE) Reference: Well: G23, True North Vertical (TVD) Reference: G23B: 65.6 Section (VS) Reference: Well (O.OON,O.OOE,233.43Azi) Survey Calculation !Method: Minimum Curvature Db: Oracle E/W MapN V1apE VS DLS Tool ft ft ft ft degl100ft 10647.94 90.43 302.50 9020.43 8954.83 -2751.29 -1329.66 5957123.48 663079.91 2707.21 0.00 MWD 10674.50 89.55 302.77 9020.43 • 8954.83 -2736.97 -1352.02 5957137.31 663057.24 2716.64 3.47 MWD 10696.91 89.91 301.62 9020.54 8954.94 -2725.03 -1370.99 5957148.83 663038.02 2724.75 5.38 MWD 10728.27 89.32 299.78 9020.75 8955.15 -2709.02 -1397.95 5957164.25 663010.71 2736.87 6.16 MWD 10760.85 87.70 297.87 9021.60 8956.00 -2693.32 -1426.48 5957179.32 662981.85 2750.42 7.69 MWD 10793.13 89.54 295.97 9022.38 8956.78 -2678.71 -1455.25 5957193.30 662952.77 2764.83 8.19 MWD 10834.39 94.12 292.09 9021.06 8955.46 -2661.92 -1492.90 5957209.26 662914.76 2785.06 14.54 MWD 10865.73 94.36 288.56 9018.74 8953.14 -2651.07 -1522.20 5957219.47 662885.23 2802.12 11.26 MWD 10897.39 93.19 285.56 9016.65 8951.05 -2641.80 -1552.40 5957228.07 662854.84 2820.85 10.15 MWD 10927.99 92.27 281.09 9015.20 8949.60 -2634.76 -1582.14 5957234.46 662824.96 2840.54 14.90 MWD 10961.57 91.29 277.51 9014.15 8948.55 -2629.33 -1615.25 5957239.16 662791.74 2863.90 11.05 MWD 10995.19 88.89 273.71 9014.10 8948.50 -2626.05 -1648.70 5957241.71 662758.22 2888.81 13.37 MWD 11026.43 86.90 271.48 9015.25 8949.65 -2624.64 -1679.89 5957242.44 662727.02 2913.01 9.56 MWD 11058.57 84.35 271.10 9017.70 8952.10 -2623.91 -1711.92 5957242.46 662694.98 2938.30 8.02 MWD 11090.53 83.96 278.06 9020.96 8955.36 -2621.38 -1743.59 5957244.31 662663.26 2962.23 21.70 MWD 11121.87 82.98 282.64 9024.52 8958.92 -2615.79 -1774.22 5957249.22 662632.53 2983.49 14.85 MWD 11157.13 83.62 288.61 9028.64 8963.04 -2606.36 -1807.92 5957257.91 662598.62 3004.94 16.91 MWD 11188.33 84.99 293.89 9031.74 8966.14 -2595.11 -1836.85 5957268.53 662569.46 3021.47 17.40 MWD 11218.91 86.32 299.44 9034.06 8968.46 -2581.43 -1864.09 5957281.61 662541.93 3035.19 18.61 MWD 11251.39 89.14 302.28 9035.35 8969.75 -2564.78 -1891.94 5957297.64 662513.72 3047.64 12.32 MWD 11284.39 92.39 306.49 9034.90 8969.30 -2546.16 -1919.16 5957315.66 662486.10 3058.40 16.11 MWD 11313.06 94.95 311.54 9033.07 8967.47 -2528.15 -1941.38 5957333.18 662463.49 3065.52 19.71 MWD 11346.40 95.25 317.43 9030.10 8964.50 -2504.89 -1965.06 5957355.91 662439.31 3070.68 17.62 MWD 11379.21 96.10 325.23 9026.85 8961.25 -2479.42 -1985.45 5957380.93 662418.38 3071.88 23.80 MWD 11412.86 93.25 329.64 9024.11 8958.51 -2451.17 -2003.49 5957408.78 662399.72 3069.53 15.57 MWD 11444.34 89.29 332.63 9023.41 8957.81 -2423.61 -2018.68 5957435.99 662383.93 3065.31 15.76 MWD 11478.48 90.34 339.78 9023.52 8957.92 -2392.40 -2032.45 5957466.90 662369.49 3057.76 21.17 MWD 11510.65 88.90 340.95 9023.73 8958.13 -2362.10 -2043.26 5957496.95 662358.02 3048.39 5.77 MWD 11542.21 90.34 336.24 9023.94 8958.34 -2332.73 -2054.77 5957526.06 662345.87 3040.14 15.61 MWD 11575.57 90.28 331.75 9023.76 8958.16 -2302.75 -2069.39 5957555.71 662330.60 3034.02 13.46 MWD 11605.52 90.71 328.04 9023.50 8957.90 -2276.85 -2084.41 5957581.28 662315.01 3030.65 12.47 MWD 11640.44 93.97 327.47 9022.08 8956.48 -2247.34 -2103.02 5957610.37 662295.76 3028.01 9.48 MWD 11671.74 89.85 321.48 9021.04 8955.44 -2221.90 -2121.19 5957635.40 662277.04 3027.44 23.22 MWD 11702.14 90.46 318.33 9020.95 8955.35 -2198.65 -2140.77 5957658.22 662256.97 3029.31 10.55 MWD 11732.92 90.98 321.61 9020.57 8954.97 -2175.08 -2160.56 5957681.34 662236.66 3031.16 10.79 MWD 11762.42 92.21 326.68 9019.74 8954.14 -2151.19 -2177.83 5957704.85 662218.88 3030.80 17.68 MWD 11802.14 90.92 332.34 9018.66 8953.06 -2116.99 -2197.96 5957738.60 662198.00 3026.59 14.61 MWD 11840.92 92.39 338.14 9017.54 8951.94 -2081.81 -2214.19 5957773.42 662181.01 3018.66 15.42 MWD 11874.16 92.27 343.05 9016.19 8950.59 -2050.49 -2225.22 5957804.48 662169.30 3008.86 14.76 MWD 11906.82 91.54 347.21 9015.10 8949.50 -2018.95 -2233.60 5957835.83 662160.23 2996.79 12.92 MWD 11935.30 91.41 350.63 9014.37 8948.77 -1991.01 -2239.07 5957863.64 662154.15 2984.53 12.01 MWD 11966.08 91.32 356.57 9013.63 8948.03 -1960.45 -2242.50 5957894.12 662150.06 2969.08 19.29 MWD 12002.88 94.74 2.99 9011.69 8946.09 -1923.72 -2242.64 5957930.83 662149.11 2947.31 19.74 MWD 12040.56 91.08 7.81 9009.77 8944.17 -1886.28 -2239.10 5957968.34 662151.83 2922.15 16.05 MWD 12075.38 89.57 13.16 9009.57 8943.97 -1852.05 -2232.77 5958002.69 662157.42 2896.67 15.96 MWD 12104.92 90.15 17.90 9009.65 8944.05 -1823.60 -2224.86 5958031.31 662164.70 2873.37 16.17 MWD 12140.12 91.08 15.96 9009.27 8943.67 -1789.93 -2214.61 5958065.20 662174.21 2845.07 6.11 MWD 12174.34 85.85 12.64 9010.19 8944.59 -1756.80 -2206.16 5958098.50 662181.93 2818.55 18.10 MWD 12206.46 84.34 4.43 9012.94 8947.34 -1725.18 -2201.42 5958130.22 662185.98 2795.90 25.90 MWD 12234.04 84.92 356.98 9015.52 8949.92 -1697.74 -2201.08 5958157.65 662185.72 2779.28 26.98 MWD 12251.94 85.42 354.33 9017.03 8951.43 -1679.96 -2202.43 5958175.40 662183.98 2769.77 15.01 MWD 12295.00 85.42 354.33 9020.47 8954.87 -1637.25 -2206.67 5958218.01 662178.81 2747.72 0.00 MWD TREE = 6" Mc EV OY WELLH~EA~D = ACTUATOR = OTIS KB. ELEV = 71.5' BF. ELEV....- 39.4' KOP = 8575' Max Angle = 96° @ 11379' Datum MD = 9876' Datum TV D = 8800' SS C -~ ~ ~ S OTES: *** 4-1 /2" CHROME NIPPLES*** 2185' - j4-1/2" HES X NIP (9CR), ID = 3.813" GAS LIFT MANDRELS 9-5/8" DV PKR 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2694' Minimum ID = 3.725" @ 9154' 4-1 /2" HES XN NIPPLE TOP OF WHIPSTOCK ~~ 8575' approx ¢sv ~ 8608~~ 9-5/8" CSG, 47#, I 9442' L-80, ID = 8.681" 4-1/2" HES X NIP (9CR), ID = 3.813" 9110' ~ 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9133' 4-1/2" HES X NIP (9CR), ID = 3.813" 9154' I--14-1/2" HES XN NIP (9CR), MILLED TO 3.80" (11/27/08) 4-1/2" LNR, 12.6#, L-80 TCII, 9167' .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 BTC, 9344' .0383 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: MCNL ON 12/11/08 ANGLE AT TOP PERF: 92° @ 11750' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11750 - 12250 O 12/12/08 ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3020 3020 1 MMG-M DMY RK 0 05/30/03 5 3992 3989 11 MMG-M DMY RK 0 04/11/08 4 5788 5515 41 MMG-M DMY RK 0 04/11/08 3 7123 6517 39 MMG-M DMY RK 0 05/17/03 2 8054 7267 34 MMG-M DMY RK 0 05/17/03 1 9021 8093 19 KBG-2 DMY BK 0 05/17/03 8426' ~ 9-5/8" X 7" BKR LNR TIEBACK, ID = 7.500" I 8434' 9-5/8" X 7" BKR ZXP LTP w /LNR HGR, ID = 6.280" MILLOUT WINDOW (C-236) 8580 ' - 8596' 9156' I-17" X 5" BKR LTP w /TIEBACK, ID = 4.380" 9167' 4-1/2" WLEG, ID=3.958" 9170' 7" X 5" BKR LNR HGR, ID = 4.450" 9177' 5" X 4-1 /2" XO, ID = 3.958" 9785' KB LNR TOP PKR, ID = 2.560" 9791' 3.7' DEPLOY SLV, ID = 3.00" MILLOUT WINDOW (C-23C) 10677' - 10685' 9842' 3-1 /2" X 3-3/16" XO, ID = 2.992" 10994' 3-3/16" X 2-7/8" XO, ID = 2.786" 4-1/2" MONO-BORE WHIPSTOCK (12/07/08) 10675' RA TAG 10684' ~ -- 4-1/2" LNR, 12.6", L-80 BTGM, 10820' .0152 bpf, ID = 3.958" 3-1/2" LNR, 8.81 #, L-80 STL, .0087 bpf, ID = 2.995" 9842' 3-3/16" LNR, 6.2 #, L-80 TCII, .0076 bpf, ID = 2.80" 10994' 2-7/8" LNR, 6.16 #, L-80 STL, .0058 bpf, ID = 2.441" PBTD I~ 12257' I 12295' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 09/04/82 ORIGINAL COMPLETION 10/17/96 D16 SIDETRACK (C-23A) 05/18/03 N2ES SIDETRACK (C-23B) 12/13/08 NORDIC 1 CTD SIDETRACK (C-23C) 12/19/08 ?/ PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: G23C PERMfT No: 2181700 API No: 50-029-20775-03 SEC 19, T11N, R14E, 1316' FNL & 1030' FEL BP Exploration (Alaska) /~~ BAKER HUGHES 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: December 18, 2008 Please find enclosed directional survey data for the following wells: G-02B Y-05B E-32B Y-OSBPBI Z-01 B Y-25 C-30A C-23C'~ Enclosed for each well is: tea copies of directional survey reports lea 3.S" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: ~ ,State of Alaska AOGCC DATE: S^ .1 ~ ~,~,~1 _~ Cc: State of Alaska, AOGCC o~,t~~'-l?d ALASSA OIL A1~TD GA,S COI~TSERQATIOrT COMI~IISSIOI~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-23C BP Exploration Alaska Inc. Permit No: 208-170 Surface Location: 1315' FNL, 1030' FEL, SEC. 19, T11N, R14E, UM Bottomhole Location: 2855' FNL, 3296' FEL, SEC. 19, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the 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, D el T. Seamount, Jr. i~ Chair DATED this Z. day of November, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '''~~~~° V ~~ M L . STATE OF ALASKA ~°'~ °~ ALA OIL AND GAS CONSERVATION COM ION ~ ~; ., ', PERMIT TO DRILL ~~ 20 AAC 25.005 , 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone c. Specify ~.we14 is: proposed for: ^ Coaltied Mefhare ^ 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 C-23C 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12300' TVD 8956'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 028305 ~,} ~\Pool 1315 FNL, 1030 FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 4370' FNL, 1636' FEL, SEC. 19, T11 N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 20, 2008 Total Depth: 2855' FNL, 3296' FEL, SEC. 19, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 26,000' 4b. Location of Well (State Base Plane Coordinates): Surface: x-664349 y-5959903 Zone-ASP4 10. KB Elevation (Height above GL): 65.6' feet 15. Distance to Nearest Well Within Pool: 800' 16. Deviated Wells: Kickoff Depth: 10790 feet Maximum Hole An le: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3237 Surface: 2357 m: . i i n in h- m u n' f m n .f. r s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4- ~-~~"x~~s" # STL/TCII 1T 1 14 Xzare° / . 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 10821' Total Depth TVD (ft): Plugs (measured): None Effective Depth MD (ft): 10736' Effective Depth TVD (ft): 9022' Junk (measured): 10723' acing Len th Size Cement Volume MD D Conductor /Structural ' Surface 1-/" 7 Ar i I 2 4' 2 ' Intermediate Ar i I 7 ' Liner 1 I 6' - 7 7 ' - r 1 4-1 2" 7 '- 1 1' - 2' Perforation Depth MD (ft): 10119' - 10730' Perforation Depth TVD (ft): 8993' - 9022' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ^ Property Plat ^ Diverter Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Printed Name John cMullen Si nature !~' Contact Charles Reynolds, 564-5480 Title Engineerin Team Leader ~1 Prepared By NameMumber: Phone 564-4711 Dat~U ~~ d~ Terre Hubble, 564-4628 Commission Use On Permit To Drill r: o~Od''»O API Number: 50-029-20775-03-00 Permit Approval See cover letter for r i t Conditions of Approval If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^,_, /Yes Q~No Mud Log Req'd: ^ Yes Q~No HZS Measures: L~ Yes ^ No Directional Survey Req'd: Yes ^ No Other: 3 ~~ Q S ~ ~~~ ~ ~C.S~. APPROVED BY THE COMMISSION Date COMMISSIONER Form 10-401' Revj$ed 12/2005 ri'~GidAL .- /~' .y Submit In Duplicate by BPXA Prudhoe Bay C-23C CTD Sidetrack October 30, 2008 CTD Sidetrack Summary Pre-Rig Work: (Scheduled to begin on November 15, 2008) 1. MIT-IA, -OA 2. Pull TTP from 4-1/2" X Nipple @ 2,185' 3. Mill XN at 9,154' to 3.80" with left handed motor, mill. 4. Tag CIBP Debris, Verify Depth and attempt to push to bottom. 5. Drift to PBTD with dummy whipstock 6. PT MV, SV, WV 7. Bleed gas lift and production flowlines down to zero and blind flange. ?J~~ ~~~ 8. Remove well house, level pad Rig P&A and Sidetrack Operations: (Scheduled to begin on December 20, 2008 using Nordic rig 1) 1. MIRU Nordic Rig 1 2. NU 7-1/16" CT Drilling BOPE and test. 3. Set Baker through tubing whipstock at 10,790' or tagged PBTD °F. IVIIII J.O WIIIUVW 1I 11VU1J. 11 `i-I/G . 5. Drill turn and lateral section to 12,300'. 6. Run and cement a 3-3/16" x 2-7/8" L-80 liner string to 9900'. This will P&A the existing perforations. 7. Make a cleanout run with mill, motor and SWS GR-CNL logging tool. 8. Perforate well. 9. FP well to 2000' with diesel. 10. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 11. RDMO Nordic 1. Post-Rig Work: ~~ ~ S 1. Re-install wellhouse and FL's. 2. Pull BPV. '~lc.,~i ~v~, 3. Run gas lift design. 1 4. POP Well Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 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: 4.125" (bi-center bits used) Casing Program: fully cemented liner • 3-1 /2", L-80 9.3# STL 9,900' - 9,930' and • 3-3/16", L-80 6.2# TCII 9,930' and - 11,200' and • 2-7/8", L-80 6.16# STL 11,200'md -12,300' and • A minimum of 25.5 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9,900' Existing casing/tubing Information 13-3/8", L-80 72#, Burst 5380, collapse 2670 psi 9-5/8", L-80, 47# Burst 6870, collapse 4750 7", L-80 26#, Burst 7240, collapse 5410 psi 4-1/2", L-80 12.6#, Burst 8430, collapse 7500 psi 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 plan. Maximum planned hole angle is 90 deg at 11,000'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line - 26,000 ft. • Distance to nearest well within pool - 800 ft. (C-09A ~ 10,790') Logging • MW D directional, Resistivity and Gamma Ray will be run over all of the open hole section. • Cased hole MCNVGR/CCL will be run. Hazards • The maximum recorded H2S level on C pad was 25 ppm on well C-39A. • Two planned fault crossings, calculated risk of lost circulation low. Reservoir Pressure • The reservoir pressure on C-23C is expected to be 3,237 psi at 8,800' TVDSS. (7.07 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 2,357 psi. C.R.Reynolds CTD Engineer CC: Well File Sondra StewmanlTerrie Hubble TREE= _, 6" ~-23B WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 61.4' BF. ELEV = 39.4' KOP = 8575' Max Angle = a0 ~ 10300' Datum MD = 9876' Datum TVD = 8800' SS s-s/8° av PKR 2622' 13-3(8" CSG, 72#, L-80, ID = 12.347" H 2694' Minimum ID = 3.725" ~ 9154' 4-1/2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: MWD GR ON 05/07/03 A NGLE A T TOP PERF: 71 ° ~ 10119' Note: Refer to Production ~ for historical perf data SQE SPF INTERVAL OpNSgz DATE 2-7/8" 6 10119 - 10127 C 05!10/07 2-7/8" 6 10124 -10130 C 02/27/04 2-1/2" 4 10330-10730 C 05/17/03 S NOTES: 2185' -~ 4-112" HES X NIP, ID = 3.813" 2185' 4-1/2" XX PLUG (04/13!08) GAS LIFT MA NDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3020 3020 1 NN1AG-M DMY RK 0 05!30/03 5 3992 3989 11 MMGM DMY RK 0 04/11/08 4 5788 5514 41 MMGM DMY RK 0 04/11/08 3 7123 6518 39 MMGM DMY RK 0 05/17/03 2 8054 7267 34 MMGM DMY RK 0 05/17/03 1 9021 8094 19 KBG2 DMY RK 0 05/17/03 8426' I-{ 9-5/8" X 7" BKR ZXP LNR TOP PKR MILLOUT WINDOW 8580' -8596' TOP OF WHIPSTOCK I~ 8575' a ¢sv I-~ 8608' I 9-5/8" CSG, 47#, L-80, ID = 8.681" I ~2-7/8" LNR, 6.4#, L-80, ID = 2.441" H 11662' 7" LNR, 26#, L-80, .0383 bpt, ID = 6.275' -r 9089' H 4-1/2" HES X NIP, ID = 3.813" 9110' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9133' 4-1/2" HES X NIP, ID = 3.813" 9154' 4-112" HES XN NIP, ID = 3.725" 9156' 7" X 5" ZXP LNR TOP PKR ~ 9167' 4-1/2" WLEG, ID - 3.958" 10358' ~- 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 9167' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.275' 9344' 4-1/2" LNR, 12.5', L-80, .0152 bpf, ID=3.958" 10820' 1072~~--~GBP MILLED 8 PUSHED TO TD PRUDHOE BAY UNfT WELL: G23B PERMIT No: 2030600 AFi No: 50-029-20775-02 SEC 19, T11 N, R14E, 1315' SNL & 1030' WEL BP Exploration (Alaska) DATE REV BY COMMENTS DATE REV BY COMMENTS 08/04/82 ORJGINAL COMPLETION 04/11/08 KSB/TLH GLV C/O 10/06/96 R1G SIDETRACK (C-23A) 04/18/08 KJB/TLH XX PLUG SET (OM13l08) 05h9/03 JDM/KK RIG SIDETRACK (C-23Bf 04/03/04 MJA/KA K SET CIBP 05/10/07 TEUPAG ADPERFS 02/13/08 SRB/TLH CIBP MILLED & PUSHED TO B TREE = 5 liVELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 61.4' BF. ELEV = 39.4' KOP = 8575' Max Angle = ~0 ~ 10300' Datum MD = 9876' Datum TVD = 8800' SS ~-23C P mposed C TD S iiei?ack S NOTES: 2185' ~--~ 4-1/2" HES X NIP, ID = 3.813" ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-{ 2694' Minimum ID = 3.725" ~ 9154' 4-1 /2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: MWD GR ON 05!07/03 A NGLE A T TOP PERF: 71 ° ~ 10119' Note: Refer to Production DB for historical perf data SQE SPF INTERVAL OpNSgz DATE 2-7/8" 6 10119 - 10127 C 05/10/07 2-7/8" 6 10124 - 10130 C 02/27/04 2-112" 4 10330 - 10730 C 05/17/03 TOP OF WHIPSTOCK 8575'approx~- s-s/8° csG, a7#, L-8o, ID = 8.68x' 9442' ~4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" H 9167' T' LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9344' 10790' Mill Window off Mechanical Whipstock 10723' CTM CIBP MILLED 8 PUSHED TO TD (02/13/08) Depth To Be Verified Pre-rig 4-1/2" LNR, 12.6", L-80, .0152 bpf, ID = 3.958" 10820' ~ GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3020 3020 1 MMG-M DMY RK 0 05!30/03 5 3992 3989 11 AI~AG-M DMY RK 0 04/11/08 4 5788 5514 41 MAAG-M DMY RK 0 04/11 /08 3 7123 6518 39 MMG-M DMY RK 0 05/17/03 2 8054 7267 34 MMGM DMY RK 0 05/17/03 ~~ ~, ,_ -- ~~9'•- - "i ! ------ K:BG-2 1 DMY RK 0 05/17/03 I 9-5/8" X 7" BKR ZXP LNR TOP PKR I 9089' 4-1 /2" HES X NIP, ID = 3.813" 9110' T' X 4-1/2" BKR S-3 PKR, ID = 3.875" 9133' 4-1/2" HES X NIP, ID = 3.813" 9154' 4-1/2" HES XN NIP, ID milled to = 3.80" 9156' 7" X 5" ZXP LNR TOP PKR 9167' 4-1/2" WLEG, ID = 3.958" 9900' -1 Top of Proposed 3-3116" Liner TOL Top of Cement 11200' 3-3/16" X 2-7 8" XO 3-3;16" x 2-7; 8" L-80 Liner, Cemented & Perf'd DATE REV BY COMMENTS DATE REV BY COMMENTS 09/04/82 ORIGINAL COMPLETION 04/11/08 KSB/TLH GLV C/O 10/06/96 RIG SIDETRACK ~C-23A) 04/18/08 KJB/TLH XX PLUG SET (04/13108) 05/19/03 JDM/KK RIG SIDETRACK ~C-236) 10/14/08 MSE CTD PROPOSED SIDETRACK 04103!04 MJA/KA K SET CIBP 05/10/07 TEUPAG ADPERFS 02/13/08 SRB/TLH CIBP MILLED 8 PUSHED TO BTM PRUDHOE BAY UNfT WELL: G23C PERMIT No: API No: 50-029-20775-03 SEC 19, T11 N, R14E, 1315' SNL & 1030' WEL BP Exploration (Alaska) by ~ BP Alaska Baker Hu hes INTEQ Plannin Report g g INTEQ Companyt BP Amoco Date: 10/23/2008 Time: i232:Ot7 Page: 1 Field: Prudhoe$ay Co-ordinate(NE) Reference:` Well; C-23, True North Site: PB C Pad Vertical.(TVD) Reference: C- 23B: 65.6 Well: C-23 Section (VS) Reference: Well (-2653.53N,-458.2 7E,320.OOAzi) Wellpath: Plan 2, C-23C Survey Calculation-Method: Mi nimum Curvature Db: Sybase Field: Prudhoe Bay - _- - - -- - _- i 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 L Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB C Pad -- -- --- - ', TR-11-14 'i UNITED STATES :North S lope 'i Site Position: Northing: 5957218.72 ft Latitude: 70 17 22.367 N ', From: Map Easting: 662550.03 ft Longitude: 148 41 2.797 W l j, Position Uncertainty: 0.00 ft North Reference: True i j Ground Level: 0.00 ft ___. - Grid Convergence: 1.24 deg - - r Well: C-23 -- - Slot Name. _ ! C-23 j ! Well Position: +N/-S 2644.94 ft Northing: 5959903.00 ft Latitude: 70 17 48.378 N ', +E/-W 1856.71 ft Easting : 664349.00 ft Longitude: 148 40 8.677 W ', Position Uncertainty: 0.00 ft Wellpath: Plan 2, C-23C Dri-led From: C-23 B 500292077503 Tie-on Depth: 10 775.38 ft Current Datum: C-236: Height 65.60 ft Above System Datum: Mean Sea Level Magnetic Data: 10/23/2008 Declination: 22.99 deg ', Field Strength: 57682 nT Mag Dip Angle: 80.92 deg i ', Vertical Section: Depth From (TVD) +N/-S +E/-W Direction I ft ft ft deg j j 32.60 -2653.53 -458.27 320.00 ! it Plan: Plan #2 Date Com osed: 10/23/2008 p ! l correct RKB height used Version: 1 i Principal: Yes Tied-to: From : Definitive Path ' Targets _ Map Map <---- Latitude -=--> <--- Longitude ---> Name Description TVD +N/-S +Ef-W Northing Easting Deg htin Sec Deg Min Sec qip. Dir. ft ft' ft ft ft j C 23C Fault 1 65.60 -2575.86 -2421.07 5957275.00 661985.00 70 17 23.041 N 148 41 19223 W ', -Polygon 1 65.60 -2575.86 -2421.07 5957275.00 661985.00 70 17 23.041 N 148 41 19.223 W j ' -Polygon 2 65.60 -2386.06 -1951.77 5957475.00 662450.00 70 17 24.909 N 148 41 5.550 W ', C-23C Polygon 65.60 -2592.73 -1421.13 5957280.00 662985.00 70 17 22.877 N 148 40 50.087 W !i -Polygon 1 65.60 -2592.73 -1421.13 5957280.00 662985.00 70 17 22.877 N 148 40 50.087 W ', -Polygon 2 65.60 -2196.53 -1927.62 5957665.00 662470.00 70 17 26.773 N 148 41 4.848 W '~ -Polygon 3 65.60 -1329.57 -2233.76 5958525.00 662145.00 70 17 35.298 N i 148 41 13.776 W -Polygon 4 65.60 -1379.97 -2444.93 5958470.00 661935.00 70 17 34.802 N 148 41 19.930 W j -Polygon 5 65.60 -2456.78 -2148.38 5957400.00 662255.00 70 17 24.213 N 148 41 11.279 W j -Polygon 6 65.60 -2696.29 -1488.41 5957175.00 662920.00 70 17 21.859 N 148 40 52.047 W I, ', C-23C Fault 2 65.60 -2414.35 -2487.56 5957435.00 661915.00 70 17 24.629 N i 148 41 21.162 W !i -Polygon 1 65.60 -2414.35 -2487.56 5957435.00 661915.00 70 17 24.629 N 148 41 21.162 W I, '~ -Polygon 2 65.60 -2187.81 -2097.48 5957670.00 662300.00 70 17 26.858 N 148 41 9.798 W ', -Polygon 3 65.60 -2081.44 -1930.11 5957780.00 662465.00 70 17 27.905 N 148 41 4.921 W '~~ -Polygon 4 65.60 -2187.81 -2097.48 5957670.00 662300.00 70 17 26.858 N 148 41 9.798 W ', j C-23C Fault 3 65.60 -1342.63 -2094.00 5958515.00 662285.00 70 17 35.170 N 148 41 9.703 W ', ~, -Polygon 1 65.60 -1342.63 -2094.00 5958515.00 662285.00 70 17 35.170 N 148 41 9.703 W -Polygon 2 65.60 -1755.43 -1742.92 5958110.00 662645.00 70 17 31.111 N 148 40 59.469 W C-23C Target 2 9021.60 -2139.50 -2202.46 5957716.00 662194.00 70 17 27.333 N 148 41 12.857 W i C-23C Target 3 9021.60 -1501.92 -2265.54 5958352.00 662117.00 70 17 33.603 N 148 41 14.701 W li C-23C Target 1 9025.60 -2411.58 -1928.33 5957450.00 662474.00 70 17 24.658 N 148 41 4.867 W ', BP Alaska by Baker Hughes INTEQ Planning Report iNTEQ Company:' BP Amoco Date: 10!23!2008 Time: 12:32:00 Page: 2 Field:. Prudhoe Bay Co-ordinate(NE) Reference: Well: C-23, True North Site: PB C Pad Vertical (TVD) Reference: C-23B: 65.6 Well: C-23 Section (VSO Reference: Well (-2653.53N,-458.27E,320.OOAzi) Wellpath: Plan 2; C-23G Survey.Calculation Method: Minimum Curvature Db: Sybase Annotatio n - -- - IVID TVD - - ft ft '10775.38 1 9023.69 TIP 10790.00 9024.25 KOP ~! 10810.00 9025.03 End of 9 Deg/100' DLS 110860.00 9026.96 4 10960.00 9029.15 5 11060.00 9028.76 6 ~! 11210.00 ~ 9026.83 7 ' 11310.00 9025.77 8 '111510.00 9022.68 9 11650.00 9021.06 10 ', 11800.00 9021.14 11 12065.00 9021.60 12 1, 12300.00 9021.96 TD -- -- - _ _ Plan Section Information MD Inc! rizim TVD - +N/-S +El-W DLS- Build Turn TFO Target ft deg deg ft ft ft deg/1QOft deg/100ft deg/100ft deg 10775.38 87.78 303.56 9023.69 -2681.71 -1436.35 0.00 0.00 0.00 0.00 10790.00 87.78 303.56 9024.25 -2673.63 -1448.52 0.00 0.00 0.00 0.00 10810.00 87.78 301.76 9025.03 -2662.85 -1465.35 9.00 0.01 -9.01 270.00 10860.00 87.79 295.75 9026.96 -2638.82 -1509.13 12.00 0.02 -12.01 270.00 10960.00 89.70 283.90 9029.15 -2604.97 -1603.01 12.00 1.91 -11.85 279.00 ', 11060.00 90.75 295.86 9028.76 -2571.03 -1696.87 12.00 1.04 11.95 85.00 111210.00 90.71 313.86 9026.83 -2485.65 -1819.44 12.00 -0.02 12.00 90.00 111310.00 90.49 301.86 9025.77 -2424.39 -1898.24 12.00 -0.22 -12.00 269.00 ~i 11510.00 91.26 325.85 9022.68 -2286.85 -2041.39 12.00 0.39 12.00 88.00 11650.00 90.05 342.61 9021.06 -2161.23 -2102.03 12.00 -0.86 11.97 94.00 11800.00 89.89 0.61 9021.14 -2013.45 -2123.83 12.00 -0.10 12.00 90.50 ~i 12065.00 89.91 328.81 9021.60 -1761.10 -2192.82 12.00 0.01 -12.00 270.00 112300.00 89.92 357.01 9021.96 -1538.74 -2261.19 12.00 0.00 12.00 90.00 Survey MD ft 10775.38 10790.00 10800.00 10810.00 10825.00 Intl Azim SS TVD N/S E/W MapN MapE DLS VS 'fF0 Too deg. deg ft' ft ft ;`ft ft deg/100ft ft deg 87 .78 303. 56 8958. 09 -2681.71 -1436.35 5957190 .71 662971 .73 0.00 607.11 0 .00 MWD, 87 .78 303. 56 8958. 65 -2673.63 -1448.52 5957198 .52 662959 .38 0.00 621.12 0 .00 MWD', 87 .78 302. 66 8959. 04 -2668.17 -1456.89 5957203 .79 662950 .90 9.00 630.69 270 .00 MWD~~ 87 .78 301. 76 8959. 43 -2662.85 -1465.35 5957208 .93 662942 .33 9.00 640.20 270 .03 MWDI 87 .78 299. 96 8960. 01 -2655.16 -1478.22 5957216 .34 662929 .30 12.00 654.36 270 .00 MWD'', 10850.00 87.79 296. 96 8960. 98 -2643.26 -1500.18 5957227 .75 662907.08 12. 00 677. 59 270 .07 MWD', 10860.00 87.79 295. 75 8961. 36 -2638. 82 -1509.13 5957231 .99 662898.03 12. 00 686. 75 270 .19 MWD', 10875.00 88.08 293. 98 8961. 90 -2632. 52 -1522.73 5957238 .00 662884.30 12. 00 700. 32 279 .00 MWD', 10900.00 88.55 291. 01 8962. 64 -2622. 96 -1545.82 5957247 .05 662861.01 12. 00 722. 48 279 .06 MWD' 10925.00 89.03 288. 05 8963. 17 -2614. 60 -1569.37 5957254 .89 662837.28 12. 00 744. 02 279 .15 MWD 10950. 00 89.51 285. 09 8963. 48 -2607 .48 -1593. 33 5957261 .49 662813.18 12.00 764.88 279 .21 MWD 10960. 00 89.70 283. 90 8963. 55 -2604 .97 -1603. 01 5957263 .78 662803.45 12.00 773.02 279 .25 MWD 10975. 00 89.86 285. 70 8963. 61 -2601 .14 -1617. 51 5957267 .29 662788.86 12.00 785.28 85 .00 MWD 11000. 00 90.12 288. 69 8963. 61 -2593 .75 -1641. 39 5957274 .15 662764.83 12.00 806.29 84 .99 MWD ', 11025. 00 90.38 291. 67 8963. 50 -2585 .13 -1664. 85 5957282 .26 662741.19 12.00 827.97 84 .99 MWD 11050. 00 90. 65 294. 66 8963. 28 -2575.30 -1687.83 5957291 .59 662718.00 12.00 850.28 85. 01 MWDI 11060. 00 90. 75 295. 86 8963. 16 -2571.03 -1696. 87 5957295 .66 662708.86 12.00 859.36 85. 03 MWD' 11075. 00 90. 75 297. 66 8962. 96 -2564.28 -1710. 27 5957302 .12 662695.33 12.00 873.14 90. 00 MWD', 11100. 00 90. 75 300. 66 8962. 63 -2552.10 -1732. 09 5957313 .81 662673.24 12.00 896.50 90. 02 MWD'. 11125. 00 90. 74 303. 66 8962. 31 -2538.79 -1753. 25 5957326 .65 662651.80 12.00 920.29 90. 06 MWD', 11150.00 90.74 306.66 8961 .99 -2524.40 -1773.69 5957340.59 662631.05 12.00 944.45 90.10 MWD'' 11175.00 90.73 309.66 8961 .67 -2508.96 -1793.34 5957355.60 662611.07 12.00 968.92 90.14 MWD'1 11200.00 90.72 312.66 8961 .35 -2492.51 -1812.16 5957371.64 662591.90 12.00 993.62 90.18 MWDI 11210.00 90.71 313.86 8961 .23 -2485.65 -1819.44 5957378.33 662584.47 12.00 1003.55 90.22 MWDI, BP Alaska by Baker Hughes INTEQ Planning Report 1NTEQ ' Company: BP Amoco Date: 10/23/2008 Timc: 12:32:00 Pale: 3 Field: Prudhoe Bay Co-ordiuate(NE) Reference: Well: C-23, True North i Site: PB C Pad Vertical ('rVD) Reference: C-23B: 65.6 Well: C-23 Section (VS) Reference: Well (-2653.53N,-458.27E,320.OOAzi) Wellpath: Plan 2, C-23C Surrey Calculation Method: Minimum Curvature Db: Sybase Survey MD Intl Azim SS TVD N!S FJW MapN iV1apE DL S VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg ', 11225.00 90.68 312. 06 8961. 04 -2475. 43 -1830.42 5957388. 31 662573.27 12. 00 1018. 43 269.00 MWD: 11250.00 90.63 309. 06 8960 .76 -2459 .18 -1849.41 5957404. 14 662553.93 12. 00 1043. 09 268.98 MWDI 11275.00 90.57 306. 06 8960 .50 -2443 .94 -1869.22 5957418. 94 662533.79 12. 00 1067. 50 268.94 MWD ~~ 11300 00 90 51 303 06 8960 .26 -2429 .76 -1889.81 5957432. 66 662512.90 12. 00 1091. 59 268.91 MWD . 11310.00 ! . 90.49 . 301. 86 8960 .17 -2424 .39 -1898.24 5957437. 84 662504.35 12. 00 1101. 13 268.88 I MWD', ~ 11325.00 90.55 303 .66 8960 .04 -2416 .28 -1910.86 5957445. 68 662491.56 12. 00 1115. 45 88.00 MWD' 11350 00 65 90 306 66 8959 78 -2401 .88 -1931.29 5957459. 63 662470.82 12. 00 1139. 61 88.02 MWD' . 11375.00 . 90.76 309 . .66 8959 . .47 -2386 .44 -1950.95 5957474. 63 662450.83 12. 00 1164. 08 88.05 MWD 11400 00 90 85 312 66 8959 .12 -2369 .99 -1969.77 5957490. 67 662431.66 12. 00 1188. 77 88.08 MWDI . 11425.00 . 90.95 315 . .65 8958 .72 -2352 .58 -1987.70 5957507. 68 662413.35 12. 00 1213 .64 88.13 MWDI, 11450.00 91.05 318 .65 8958 .29 -2334 .26 -2004.69 5957525. 63 662395.96 12. 00 1238 .60 88.17 MWD', ', 11475.00 91.14 321 .65 8957 .81 -2315 .07 -2020.71 5957544. 46 662379.53 12. 00 1263 .59 88.23 MWD II 11500 00 91 23 324 65 8957 29 -2295 .07 -2035.69 5957564. 13 662364.11 12. 00 1288 .55 88.28 MW D . 11510.00 . 91.26 325 . .85 8957 . .08 -2286 .85 -2041.39 5957572. 21 662358.24 12. 00 1298 .50 88.35 I MWD 11525.00 91.13 327 .65 8956 .76 -2274 .31 -2049.62 5957584. 57 662349.74 12. 00 1313 .39 94.00 MWDI, 11550.00 90.92 330 .64 8956 .32 -2252 .86 -2062.43 5957605. 74 662336.46 12. 00 1338 .07 94.04 MWD', I 11575.00 90.71 333 .63 8955 .96 -2230 .76 -2074.11 5957627. 57 662324.30 12 .00 1362 .51 94.09 MWDI, 11600.00 90.49 336 .63 8955 .70 -2208 .08 -2084.63 5957650. 01 662313.30 12 .00 1386 .63 94.13 MWDI, I 11625 00 27 90 339 62 8955 .53 -2184 .89 -2093.94 5957673. 00 662303.48 12 .00 1410 .39 94.16 MWD', . 11650.00 . 90.05 342 . .61 8955 .46 -2161 .23 -2102.03 5957696. 47 662294.87 12 .00 1433 .71 94.18 MWDI, 11675.00 90.02 345 .61 8955 .45 -2137 .19 -2108.88 5957720. 35 662287.50 12 .00 1456 .53 90.50 MWD 11700.00 90. 00 348.61 8955.44 -2112. 83 -2114. 45 5957744.59 662281. 40 12. 00 1478.78 90. 50 MWD 11725.00 89. 97 351. 61 8955.45 -2088. 20 -2118. 75 5957769.11 662276. 56 12. 00 1500.40 90 .50 MWD i 11750.00 89. 95 354. 61 8955.47 -2063. 38 -2121. 75 5957793.86 662273. 02 12. 00 1521.34 90 .50 MW D ~, 11775.00 89. 92 357. 61 8955.50 -2038. 44 -2123. 44 5957818.75 662270. 78 12. 00 1541.54 90 .50 MWDI, 11800.00 89. 89 0. 61 8955.54 -2013. 45 -2123. 83 5957843.73 662269. 85 12. 00 1560.93 90 .50 MWDI, 11825 00 89 89 357 61 58 8955 -1988. 46 -2124. 22 5957868.71 662268 .91 12. 00 1580.33 270 .00 MWD . 11850 00 . 89 89 . 354. 61 . 8955.63 -1963. 52 -2125. 92 5957893.60 662266 .67 12. 00 1600.52 270 .01 I MWDI . 11875.00 . 89 .90 351. 61 8955.68 -1938. 70 -2128. 91 5957918.35 662263 .13 12. 00 1621.46 270 .01 MWDI,, 11900.00 89 .90 348. 61 8955.72 -1914. 07 -2133. 21 5957942.87 662258 .30 12. 00 1643.09 270 .02 MWDI 11925.00 89 .90 345. 61 8955.77 -1889. 71 -2138. 78 5957967.11 662252 .19 12. 00 1665.34 270 .02 MWD, 11950.00 89 .90 342. 61 8955.81 -1865. 67 -2145. 63 5957990.99 662244 .82 12. 00 1688.15 270 .03 MWD', 11975.00 89 .90 339. 61 8955.85 -1842. 01 -2153. 72 5958014.46 662236 .22 12. 00 1711.47 270 .03 MWDI 12000.00 89 .90 336. 61 8955.90 -1818. 82 -2163. 04 5958037.44 662226 .39 12. 00 1735.23 270 .04 MWD 12025.00 89 .91 333. 61 8955.94 -1796. 14 -2173. 56 5958059.88 662215 .38 12. 00 1759.36 270 .04 MWD 12050.00 89 .91 330. 61 8955.98 -1774 .05 -2185. 26 5958081.71 662203 .21 12. 00 1783.81 270 .05 MWD! 12065.00 89 .91 328. 81 8956.00 -1761 .10 -2192. 82 5958094.49 662195 .36 12. 00 1798.59 270 .05 MWD, 12075.00 89 .91 330. 01 8956.02 -1752 .49 -2197. 91 5958102.99 662190 .08 12. 00 1808.46 90 .00 MWDII 12100.00 89 .91 333. 01 8956.06 -1730 .52 -2209. 84 5958124.69 662177 .68 12. 00 1832.95 90 .00 MWD', 12125.00 89 .91 336. 01 8956.10 -1707 .96 -2220. 59 5958147.01 662166 .44 12. 00 1857.15 89 .99 MWD I 12150.00 89 .91 339. 01 8956.14 -1684 .86 -2230. 16 5958169.89 662156 .37 12. 00 1880.99 89 .99 MWD' 12175.00 89 .91 342 .01 8956.17 -1661 .30 -2238. 50 5958193.27 662147 .52 12. 00 1904.40 89 .98 MWD'•, 12200.00 89 .91 345 .01 8956.21 -1637 .33 -2245. 59 5958217.07 662139 .90 12. 00 1927.32 89 .98 MWDI, 12225.00 89 .91 348 .01 8956.25 -1613 .02 -2251. 42 5958241.25 662133 .54 12. 00 1949.69 89 .97 MWDI, 12250.00 89 .92 351 .01 8956.29 -1588 .44 -2255. 97 5958265.72 662128 .45 12. 00 1971.45 89 .97 MWD', 12275.00 89 .92 354 .01 8956.32 -1563 .66 -2259. 23 5958290.42 662124 .65 12. 00 1992.53 89 .97 MWD 12300.00 89 .92 357 .01 8956.36 -1538 .74 -2261 .19 5958315.29 662122 .15 12. 00 2012.88 89 .96 2.8751 BP Alaska LEGEND _ G-23 (C-23) ~~ ~ G-23 (G-2381 23 G 439 ~ ° ".~pseztc zr `""'"" ` ° c~,a 0... ,Oanwa Om, T T IU BAKER HU6HE S ~ rrv~a ( - 1 zz - by Plan 2, G-23G Muw. Plan N2 Se~pF-si YiELV. N aE ~ I ~ o~ ~ ~ ~ I , x~xPoOe C ~B one 5993929))SO] ..,.n,..il,.,E: Ti. on a0: taTTE.]E _ 1NTEQ - ~9 ~- 190]13013510 Ema~6~m:< ~~~~1e9~ , W I. aawm: C 338. ES.E9N v.s.ouon o.i~j a~w iwlaitlnlT~ro ~. a]o eo• zeE].s] rEE.n ]:.so RMA E NFO r - - l' 3 - _ F : C-23C Fault 3 II ~ , 1 ~ ~ ~ 1 ~ ~+ L ^ CoVertca(NDIR e erer,cc C~i59 21E) sea on lvsl e e,e~~ - ( a R " ' .._I I~ J ~-l ~ A, i i ~_~ tY r~ J ~ . '. C-23C TarBef3 -1 J+ 1 . _ } ity .. 1 - . r i Mre..~ - C l0 656] ,s -~a,e Me oa ' w•- ~ ~ ~ .__ ..._ + _ _ ' ^- _ Plan 2, C-23C - r f {{ r y ~ .:.`i t eecTew errues ' .. w ..... T..r e. ew r - ]ve «w .nee vex .... Ir r ~." -. ' ' ~' 1 I t - T ~ ~t 'r ~L ~ *1- 1 i- ~ _ - 1.n e.ET. ..a•. .,e].a " . i °Y ` r -i I r 1 ~ µ .L. ..o,. ....~ e. e . _ _ . ~ 1.i .1.1 t ~~ t ~E i I 12~ ~ ~- -~> -1 =~ ly =4 - { - - F V ..,. aw..,.... ,... ».. 7,~.,. „ iiis Ee, ur Ee.e .. 4 - , r .. 7 Ir ' t t+r ~'~ F _ ir _~ r = .m..u mJee ,ar rrw .a.eaeewe r~u rw eeraae -ox1. ease .ue ,.-, ~ r ~ ' ~ : ,, ~ _~. ~ ,+- - = - ~_ - } _ _ ,-,.. f _ r r, ; L ~ ~ ..{ { ~r - i. -_. ~ i. - . T r L t F i _-F' i sa.ornr orvx - u0 ..,:,:,,.,,a, ~ ~ i- ~~ 1 _ }~r r r 7 77 ~ ~ -. g ' r~.r ~-r ~ I -1-. T i. - ' . I 1 - 'Y tr ~~tt - t f I --- ~ 99ae.. :ti a,.e.w,ee~oLe 09ae au = oea OO e _ { ~ tD 423C Tar t 2 ~ ~ 1 I j T f". '~t ~ ' , .z,e ae 1 ese0 a0 rom - ea,,.5e -,ezu:JS ,z,0 oo a c:xJC re w,l ~ _ .I 1 ~ ~- 11 j 1 G 1 4 _ { ,»o.ae r z ieuo oa tt ~ + mo-~ , , I t i t 1 F +Y } ~. -z ~ .. '" 1 C-23C Tar et1 '. 'r { ._ ~ 9 ~ ~ F • F ~r 'z eeseae iiwo oa To _ { ~.. -{..~ { _ _.. ~ _ _ ~,~ ~ La 1 -~ _{. ~ _ _ _ {_ + . I I rt-~- TriY 1 r f ~ / z awe :. i _ 1_ ~ I ~.-. -E G23C Fault 2 _ o + 11 r ~ T- t ~ 1 - 1 ~ ~ ~ ~~ I~1 E d f0 De~70O'DLS C-23C Fault 1 K 1 1 _t } + h_ T ' {-} E r ~-i { I .. ~. r 1 ~ I I T 4 _ - Ff- - + ~ 1 T r - T _ esro J ~. ~ - ~ ~ ~ I ~ _ ' -. i : - - Ti T rt TIP .... C-23 C-23B - - 11 I _ r t } f: It T' + ~} l ~ }~ If ~ f l ' i ~ + I year. ~ t ~ t~~,l~ ItIGI j rt~~fi ; , tr : ~ f ~ tk{ , ]ti~ ' .. ~. + I , i +l -t- - ~ #i ,~_ s ~ ~ ~ .. a,ao _ ~~ +i '--T F r U -- . -I ~ -~ . . I _ . r. _ + ~. r. y T +j t ~ ~ r , f .. ... + -~ + I r r : r, ~ ~. ,1 ;.Y aco ~ ],~ >~e x~9 z~ z>~ o „ 1.., i ; ~ - - a ~~, ee z~ xam .xJ~ x]., x, ,ten ,eee ,moo ,.~ ,.~ ,x .. o ma ~ ~ , e ~ eo9 ,~ e , rrr a, i- *. + ;__ .. weEry-peaEgt] ]1DDwin] . + 1 r t rt t ~ T 4 r ~j ~ I 1' _ I -r .,-~. ! { . i c~ s t+1 i _ I t F 1- 1 ; F_+ r I 1~ t I a ~ '.'i TIP KOP n g ~! q I ~ End of S Deg/100 DLS y d aye ar -_ ,'. j_ . C-23C T get 1 `C-23C TarOat 2 i I I ~ __ ... ~C-23C Ta i 'r' rget3 u I I~ ~ ©, ^7 ~ ~ 70 11 z h ~' - 72 I Plan 2, C-23C I ~ - LC-23 C-23B { _ - is ,... ... ~ ~ r {F = ~ { A~~~ r TAT ~ ( ~ ~ ~ i ,. } ~ ~ ~ i Yt-' ~ i 'f ~ t 4t f ~ i -1 1 I ~ ~~- - I t i1 - F ' t -~ '1 _ .. ~ ~~ 1 ;. ~ :-; ~ + 1. r- ,~ ~_~ r ~ . --~ .. 11 l { , ' I ~ ~ L - .- .... . -- - ~j . {+~ . '{~ ~ r t yr -1 1 I~-t i ~ ~ r - 7~~ t {` ~ ~ I 1 I } ~ F ~~L ~ r I ~ T ~-r ~' ~ tl t ~- f { ~~ - 1 1 --j r ~ T + ~ ~ ~ I- _t ~ -~ - 1~ ~ r ~ { + ' r ~~rt -r r f 1 ~ _ ;. ~ . - _ ~-. ._. _ r 1 . . ..'- - - - ~ - - - .. : .. -L} :_ I _-. - ~ .+... I ~ ~ . r± ex - ~- ,++~ ' ` ~: r - F ,, ~~ ~ : - T:# r 1}! ; ~, r t 4 r l r I--r ~± , r~ I_' H ~ 1 1 , , ~ t- ~ t ; ~ 1 ~; ;i T ~ i~ - ~i~ li i~ - t -F ~ r _ ~ i i~ ' f r r r - rr ~~ F h ' ~ 1 {' ; ~y-i ` ~ Gj ~ + ~ ~ - ~ I -- = . - : 9z I• _ t -: ~-r I - -` __: it , ~ t -r ~ , ; : _ " ~' , _' I ' 1.~_ r ~., +` ; C'- {, / 1 `? t ' '~+ I - ~+ I }1' ~ , r r 1 L. , _, . I - ., :_: 1 i ~ .r'-,-{- a~ ,ae'. .aye wa ~. sw a'---' ~-tee ~ rt .w~eoo Tew~~mroT ~ T ,moo-r ,~er~ zw w za0 ,~eo „~ ~ ~,~~ , ,.I -. ~ 1 _ aw.'~ a~ ~,~ '~0 ~~ ,s5a ~~ ,~ ,1w 1150 ~ ,aw , i ... ._ ya0 IOC0 .Ow z,0o .r.... ,fir f -- z xzw Vertkal Seetlon at 320.00' ISOwin] ~I LEGEND .~~ T M Plan: Plan N2 (G23/Plan 2, C-23CJ Gealetl By BP Date: 10/24/2008 BP Alaska B-3018-30) 8-30 B-30A ) MimulM1S YO True NUmi Magn0lic NwN'. 22 99° Checked: Dale: w6w•rx YYEwu - _. C-11 (C-11) C-11 (C-1 tA) 1lLIGN! ~1~/ by Maynel~ Fie10 svenvm. s7r~aznT c ~ ~ a mr«S,aY rl.. z, c-z]c 5003930»SOa C-22 (C-22) C-22 (C-22A) NTEQ -_.. o ie azinooe Motlel. 099m2007 w, a au Mi liWm, Ce9 1907) 301 1510 9,, a-2]x r,..„ x9 1ons as C-23 (C-23) amen eBl m. ~naeN,~"anmiwt.~.,m . . - C-23 (C-23A) x.Y. 9.1~',°.I c z]9. ss.6or1 C-23 (C-238) C-24 (C-24) 9w.Y °feiY;gll °.iLa °.~~ r,9w r"~r9 _.. C-24 (C-24A) b9 ]x9 99• acv 53 rm n u -- - Plan 2, C-230 . . . . Plan #2 REFERENCE INFORMATION Co-ortlinale (NIE) Reference: Well Cenlre: C-23, True NoM TVD R C 23B 65 60 V i l f - erence: - : . ert ca ( ) e Seclien (VS)Reterence'. Slal- (-2653.53N -056.27E) Measured Depth Reference: C-23 B: 05.60 Calculation M~lhoJ. Mini,riuni C~rva Wrc 9ECTrox OET•YL9 m Y - _._. x9 I.o rl rv9 .roe .u-w o 199.9 v9.9 9. a amsa aB.as 2 1 903035 aY.ii e].>B ] 1885.]s 9.00 3 -26al:B2 13.00 2>0.00 686.)5 5 f 89.>0 211 so 904.9> -180a.01 00 3>9.00 -2311.0] 85.00 859.]5 1 1310.00 9 t ]ta.96 13.00 0 90.aB ]01.86 -3a2a.J9 -1998.31 fi9.00 1fOt.la Be.BS ae.i0 10 ttfi50.00 90.03 ] -31613a 110203 90.00 1laa.>1 tt 11500.00 8 9a31:11 SOt].93 -213a.B] 12.00 90.50 212085.00 B o9 803196 ~ 0 ~ 1200 29000 9] t] 12]00.00 98.02 ]51.01 00 15]8.>< 2281.19 1 3013.55 r r r ~' 6000 6300 / /4800 i 1 f' -000 7 ~-F ~ r- ~ ~ i _ / , 6300 8 6 600 ~ ~ ~ ~ - _ I r 1 - t f I ~ - / ~ _' 600 5100 -fi00 r- ~ i1 Tt- T+ ~r{ . I T i ~ ' r r . /'7200 6900 9 6800 ~ 3 000 t 300 1 1. ...I - ~~ 1 ~ y ~ r + [ r t ~ r ~' } ~~00 G22 Gz2A 7200 / - "'1- r - ~ 1 ~ , 600 7 I T _ T i ~ f ~ ~ D0 500 7600 5400 t~ ~- _ _ r - ' + -- i _ - L t ~ . i ff t) ~ ~ i { ~~ 700 7900 t ~ -. aooo - 1 T - ~ 4YY C-3Z __ y' { - ~ I o00 / / +Fi 5700 ... . ~ 1 _ ~:_. - + ) , -. - .'- - ... / az oo } r+ {- - i, - r 11. .. 1 t T ~ t 100 awo - r } ( , w . + j ~ ' - ~ ' - t t - ~ + - -- f - - + ' o ~ , c-11 Sc-~_~ _ 1 t_ ~ r ' r t r t ( -7aoo .. ~ - ... .._- ~ _ T +I - ., . 1 ' .Plan 2 C-230 rr~ ~~ \ :~' aeoc ~-li_ F { - ~~ { _ i+t I ~ - ~k F )t~-~t-_ I-~~ _.1~1 _ + o p p /g eaoo _ ~, ._-7soo -r C _ ~ r '.. .t . a :.: - T t L .. - _- //51 0 0 6300 1 tt r 71 ~- h ~-F iit ~ i 1 I ; _.. - 1 __ ~ t , ' ~ . 6 r+ { ~ - ~ , 1. #" LL~ F jj ~ -16U0 F' N rf - 7 1 +~ C ~ 1 • 1 t -1' _ ~ T 1 _ 5000 5700 ~~ 1-I _ . , 8600 - ~... _ _ + .. I_+ ~'..., - ' - + ~f -t { rt - T .+,.-zooo I , ~ tr --i ~ .~ 7 - r ` -- ~ ~ ~ ~ ? '~ I { F - r 1 - ~ ~.. G241c-21A1~ .. _-_.. . ~.:, all c-11 6000 rrI I t +'~ fisoo - - i f Z - ~ i ~ ~ i r { ~ ~~ ~ ~ ~ i ~ ~ _ ~ ' r ~ - ~ ' ~ -2200 i ~ i i- ~ _ 1 , _ -, - ,_ r . !T ~ r :.. .. ~30o i ~ '~ 7soo i , # ~ ~' j - .,'- t j ,_ - _t~ "zaoo' ~ ._ 3 ;~ ~ ~ I .. ~ ~ ~ 6 ~, ~ O ,, tt'. .....a- .. ' -r- tFN .. ._ +r... r -1 ~ t ~ I..-. 1 1 «: ~ ~ + 1 r , + rl ~ /~ :: T oo I C-33 C-23B F--- 7 r ~.. _ -l ~ 598 t i t ~ + I ~ , ; . 1 ~ - .. : _ -2600 ~ l }r ~-{ .. t t r t ~ 7 i- , . I - . + _ I o f _ ._. ~ 1 ~ .-7z _. 7 ~ r. .. - + ~ - - rt - - . I / --1 _ /' 600 7 - ~ r - t ~-r . r r - i - l -2800 Yr f-I { E 1 .. y I ... 1 . . ~~~ 1 ] - ~ 0 / 6 10 0 r 6 {-7 L ~ - '- ~ r T ~ rT1 r ' - , -1 . 1 ~ I ~ + t~ 1 ~ -3000 , t ri .7 .~ i s9 .. 11 . 80 1 00 r _ 760 W f . ' { ~ .. i I tt 1 ~ + ~ . (~ l _ 64~ ~ r ~ ,t- + y ~... , -ago "` I -.. ~~ 1 + i ~ ,~ ~ + r 1 6700 _ c za c za 1. -_-_._ ~ +--r ~ ( I - ~~ Y ;, r - ~ ~ j -~ 1 00 ~~ ' T~ ~ ~ 1 ~ r~ F i ~ t -3400 - 1 i 1 r t I t ~ 1 , . , 1 _~,+- .. - 9008 _ ~ . i _ ~ -. . r tT~ ll 1 I ~ ~ ~ 4 ± " "-.._ - G-23 C-23 Y r ~ +r T ) ~ t ~ } - i :.__} I _~'„ ~ : . `: ~ 1.. f L . • ~ . -t r-' ~.~.!•_ _ .. r-f. . _ _ : ~ ~ .. - ` -3600 .... .. ~ •30 B•3 ~ 0A .... .. (. . .. I _ .. -3800 11 - + T ' - ' , r ' ` 1 T ;-;- 1 ~ 8-30 8-30 ~ -r ~~ 11 ' .r, , , .. - :9 i II -111- 17 ' -- 33 T3 ~1~ ,,Ir . - 7 1 TrT' r~ I ~ ' . . I ( .. . TT ~T ~T, it li r r{rrT r I~t t 11 r 1„~T7 i ~ 1 r t Tr r r 400 600 800 1000 1200 1400 7600 7800 2000 -000 -200 0 200 -800 600 -5800 -5600 -5400 -5200 -5000 -0800 -0600 -0400 -0200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -1000 -1800 -1600 -1400 -1200 -1000 West(-)/East(+) [200ft/in] • WILL UkTA1LS AM1TI-COLI.ISIOM1 SF.TTII:<;S I:unly ~M1'i-S 'Fi'-W NutthinK LvlinK I.wilwl.~ I.uUKiw~k Sl~n In4epul~liun Vl.~IhvWMD hi4rvul. IW IIU Dvplh R~nK. trUnl: IU]]S.lx TU: I?3W.W (: '1 '444.YJ InSfi ]1 SYSYW].W LL434Y.U11 )11`1 ]'4x 3]xA 14x"4VUx.L'!]W M1/A Vluximwn RwlK._ IJ'_4 ]4 Rvli'r~n.c: Plun: PWn R3 3es ~~ IYS - i45 - Ixx Ififi IxU 1.x0-. 1 - I]3 - lii IGS l6> Isx _ ISa Iso u~ COMI'AYl' ULI AILS UP AmmU C Wcululiwi N.IhuJ: NiUiUwnl Cwv+wn~ F.rzUr Sy~l~m: ISC' W S.4 S.an.Slvlh.nl. I inr ('ylinJ.~r YUnh Prror Surt+cc: tllipli.~+l-ln.inp W uminK S1etlnul. RW.~ buaul SURVEY YRDURAN UmUrYm U.TUI I-~~ SunvYll'luil IU]]53% I?3WLYI Ylwm.rl-Ylw„Y3 VI \ .\ \\ W LLLYA'I I I UI~T AI I.S "fwl Pl+n ~. C ?3C SW292U]]5U3 MWU Ywwr1 Wcllpnth: (-~iN I'ic Un NU. IOJ]5.1% x~,• Rn: unmm: c-21n: fis WR V.S..tiur~ Ori%iU Onxi~r SwIi~~K AUKIc -Y/-S *1/-W trum'I VU ]^_II.OIY 653.53 -43%?] 3?611 LHGGND - d-30 (d-3UA), Major Risk - C-I I (C-11), Major Rlsk - C-11 (C-1 IAI. Major Risk - C-22 (C-2?), Major Risk - C 22 (C'-~2A) M ~ r Risk - C 23 (C' 23j M j Risk - C ]3 (C .3A) M j Rlsk - C-?3 (C 230). Mayor Risk - C-24 (C-2d), Major Risk - C-?4 (C ~4A), Major Risk - Plan 2, C-23C - Plan N2 • Tr+r~11iUK (:yliUJ<r Ai-imwh ITFO A/I) I~~KI ~~ C.i~vc m Caivc S.~p:uaU~~n 1151~'ilil by INTEL SL(' l IO.V UICI dI LS Su NU Illi Aii 1VU -Y/-S -1l-W UL.~K Tt+.:< VSi~. -I:uK.I I 10]]5.1% %].]% 103.56 Y11"21 by ~fi%I.]I -141635 U UII II.UII W>.II 10]YU.W %]J% SLLi-56 WI24.25 -^_4]3.63 -149A5? U.W U.W fi?I.I~ J IU%IU UU %].]tl 301.]6 4 IU%6U,W %].]H 2Y5,]3 YUJSL3 -!662%5 -14455 9.W 3]11W YII2fi.44 X43%.%? -I SUY.13 IJ.W ?JII.W 4411.30 fi%6.]5 - I(IY411 UU %Y )U 2x1.YO W2Y.15 ~LU44J -IW3.U1 I~.110 ?]Y.W ]]3.U? IIWII.W YU.]5 295.%b W2%.]4 -25]1 US -IfiY4 A] I'_.W %5 UO %SY )fi ] II21U.W W.]I 313.%b IISIUW YSI4Y 3UI.%b YIIJfi.%} ~4%5 h5 -I%IY i4 I~UII 11W 41125]) -24'_4.3Y -I%Y%.24 I2 UU 3fiY.W II%13 i5 1101.13 Y IISIU 110 91 ~6 325 b5 W2?6% '?N4-%$ ^011.19 I~.1x1 %%00 I?4n.5U 10 11450-I1U YIrUS 143.61 II II%OU 110 xY_%Y LL61 W?I.U6 -!161:!3 -]IO~uI I~.UO 941N1 W21.19 ~IIIS.aS =!I?3-%3 I?.UU 50.50 1413 )I I>W.Y3 12 I~WSLO N4 VI 3~x%I W21 liU -1]41.111 ~IY'_N2 I~.UU ?]II.W I]4%.SY I1 121011 lXl %Y.Y2 35]111 W131.Y6 -153%.]4 ~3fi I.IY I'_UO YII IIU 'UI2.%% • .:~'•ti• ~ BP Alaska by °'}++'~ Anticollision Report ri.r BAKER HUGHES INTEQ :Company: BPAmoca Date;• 10/24l2008> Time: 09:5953 Page: 1 Fields Prudhoe Bay- j Reference S ite: PB C Pad Co-ordinate(NE) Reference: Well: C-23, True Nort h Reference WeIL• C-23' Vertical (1'VDpReference: C-23B: 65.6 Reference Wellpath:-- Plan 2, C-23G Db: Oracle' GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are'R~d~laeells in this~iahCi pal Plan & PLANNED PROGRAM ', Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse ', Depth Ran ge: 10775.38 to 12300.00 ft Scan Method: Trav Cylinder North Maximum Radius: 1426.74 ft Error Surface: Ellipse + Casing ', Survey Program for Definitive Wellpath Date: 10/23/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool N ame ', ft ft ', 94.10 8494.10 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOS S gyro multi shot 8581.00 10775.38 C-236 (8581.00-10775.38) (1) MWD+IFR+MS MWD +IFR + Multi Station 10775.38 12300.00 Planned: Plan #2 V1 MWD MWD -Standard Casing Poi nts __ MD TVD Diameter Hole. Size Name ft fY ; in in ~ 12300.00 9021.96 2.875 4.125 2.875" Summary <----- -----0ffset Wellpath:.------ -> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area veviation Warning : : ft ft - ft ft ft _ -- ', PB B Pad -- _ __- - . B-30 --- - -- B-30A V4 -- - --- __ - - _ - -- 9 - Out of ran a '~ ~I PB C Pad C-11 C-11 V1 11836.47 9975.00 239.63 770.94 -531.31 FAIL: Major Risk '~ ~, PB C Pad C-11 C-11A V4 12010.29 9500.00 823.77 498.71 325.06 Pass: Major Risk I, PB C Pad C-22 C-22 V3 Out of range ', ', PB C Pad C-22 C-22A V6 Out of range PB C Pad C-23 C-23 V3 Out of range j ', PB C Pad C-23 C-23A V1 Out of range PB C Pad C-23 C-23B V8 10820.97 10821.00 0.79 327.08 -326.30 FAIL: Major Risk ', PB C Pad C-24 C-24 V8 Out of range ~ PB C Pad C-24 C-24A V7 11750.00 11125.00 929.09 760.55 168.54 Pass: Major Risk !~ Site: PB C Pad Well: C-11 Rule Assigned: Major Risk Wellpath: C-11 V1 Inter-Site Error: 0.00 ft Reference Offset Semr-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 12036.06 9021.56 8850.00 8181.59 105.92 58.52 15.74 43.45 1157.11 370.50 786.61 Pass ~ 12033.40 9021.55 8875.00 8200.87 106.33 59.48 16.20 43.60 1133.30 374.27 759.04 Pass I i 12030.70 9021.55 8900.00 8220.20 106.75 60.45 16.69 43.76 1109.53 378.17 731.36 Pass 12025.00 9021.54 8925.00 8239.59 107.63 62.03 17.54 43.93 1085.80 384.41 701.39 Pass ', 12025.00 9021.54 8950.00 8259.03 107.63 62.45 17.72 44.11 1062.08 386.47 675.61 Pass li :12025.00 9021.54 8975.00 8278.52 107.63 62.87 17.92 44.31 1038.41 388.60 649.81 Pass 12019.46 9021.53 9000.00 8298.07 108.42 64.45 18.80 44.53 1014.77 395.00 619.77 Pass ~, 12016.53 9021.52 9025.00 8317.61 108.84 65.49 19.38 44.75 991.17 399.56 591.61 Pass ', ', 12013.54 9021.52 9050.00 8337.06 109.27 66.56 19.96 44.98 967.59 404.22 563.37 Pass ' 12010.48 9021.51 9075.00 8356.39 109.71 67.66 20.56 45.20 944.01 408.97 535.04 Pass ', 12007.34 9021.51 9100.00 8375.61 110.17 68.77 21.16 45.43 920.46 413.84 506.62 Pass 12004.14 9021.50 9125.00 8394.75 110.63 69.91 21.78 45.67 896.92 418.82 478.10 Pass !, 12000.00 9021.50 9150.00 8413.86 111.22 71.26 22.52 45.91 873.39 424.65 448.75 Pass 12000.00 9021.50 9175.00 8432.95 111.22 71.73 22.78 46.17 849.89 427.35 422.55 Pass ', 11994.24 9021.49 9200.00 8452.01 111.99 73.45 23.74 46.44 826.40 434.55 391.85 Pass ~, 11990.83 9021.48 9225.00 8471.07 112.44 74.66 24.44 46.73 802.95 440.11 362.84 Pass 11987.31 9021.47 9250.00 8490.17 112.90 75.90 25.17 47.04 779.57 445.94 333.64 Pass 11983.71 9021.47 9275.00 8509.30 113.38 77.17 25.94 47.37 756.28 452.07 304.21 Pass 'I 11980.00 9021.46 9300.00 8528.47 113.87 78.46 26.75 47.74 733.07 458.53 274.54 Pass 11975.00 9021.45 9325.00 8547.68 114.54 80.05 27.75 48.14 709.95 466.27 243.68 Pass 11972.28 9021.45 9350.00 8566.96 114.87 81.14 28.51 48.58 686.95 472.45 214.49 Pass BP CTD BOP Stackup 2 3/8" Coil by Rig Floor to Top of Bag: 9.23' 7 1/16" H drill Annular, 5000 si 9.23' 7 1/16" 5000 si, RX-46 Blind Shears TOT (12.65') 2 3/8" Combi's TOT 13.56') 7 1/16" 5000 si, RX-46 Mud Cross 14.89' 2 1116" 5000 psi, RX-24 2 318" x 3 1/2" Variable Ram 18.10' 2 3/8" Combi TOT 18.88' 7 1/16" 5000 si, RX-46 7 1/16" x 3 1/6" Flan ed Ada ter Swab valve (20.04' Flow Line SSV 22.88' Master Valve 24.88') Lock Down Screws 26.68') Ground Level 31.00') Alaska Department of Natural Resources Land Administration System Page 1 0~ -, : ~ ~ ~ - ~.: . , ~ _~tat~ ;~>-~ RA~ar~d~r`s ~~earch State Cabins ~i~tii ~5€~uC~s Alaska ~111R asp ~ummar~ File Type: ADL.._....._` File Number: 28305 ~ Printable Case File_Summary See Township, Range, Section and Acreage? ~` Yes No New Search 1_.~5 1Vlen~~ ~ Case Abstract !Case Detail ~ land Abstract .. File: a~L ?830 Search for Status i~iat Upd~+tes ~~ cif 11'(1-t X11118 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX ] 966] 2/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ~~~~'~ O1L & GAS LEASE COMP DNR Urzi1: 780 OIL AND GAS File Location: DOG DIV OIL AN D GAS Case .Status:3~ ISSUED Status Date: 08/19/1965 Total ~4cres: 2480.000 Date Initiated: OS/2S/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Ircrnsactiorr Date: 12/04/2006 Case Subtype: =~S NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APAROVED !~leridr~rj~ ~ [' l ~nvnslzrp: (I I I N Range: OI4E ~~~°c~ttur~: I ~'ec~lrun ,Ic~res: 640 Search Flats 1 /~~t-i~li~rri: l ! 7urnnsllrJ~: (11 1 V~ l~'nrr,,~r~~: 01-t1 ~: ~8~~c 1ini1.~ I ~ _ti~~cliu~t . i~~f~c~~~: ~~~~~ ,l I~~ridiun.~ lJ 7otinnslrij>: O1 I ~~ Kcrr~~~c ~ t? I -ll~, Src~iun.~ I ~> ~~,~,/ir~ir .~Icrc~~~: 6U l 11~rr~lian: U Totivnsl~ih: UI IN l~~m;~c.~ (114E .~~~'rlir~~i~ '(1 ~r~c~[iun.]cr~~y~: h-~(} Leg~il Description 0~-28-1)6~ '~ ~ ~ SALE ;~'OTIC.'E LEG,:11_, DF_SC'RIPT1O-'~'~-T+ ('1=1-1?6111~' 1-1E L~bf 1.?.1 ~Y.19,?U ?-Ib'0.00 U- .i- 7 Last updated on 11/04/2008. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28305&... 11 /4/2008 Maunder, Thomas E (DOA) From: Reynolds, Charles [Charles.Reynolds@bp.com] Sent: Thursday, November 06, 2008 5:02 PM To: Maunder, Thomas E (DOA) Subject: RE: PBU C-23C Attachments: Closest Well Analysis.doc Tom, Page 1 of 1 Please see the attached explanation regarding the wells surrounding the C-23C sidetrack which is in the permitting process. Please feet free to a-mail me with any further questions/concerns. Charles Reynolds BP Alaska Coil Tubing Drilling Ph: (907) 564-5480 Cell: (907) 575-6234 Email: Charles.Reynolds@BP.com From: McMullen, John C Sent: Wednesday, November 05, 2008 12:05 PM To: Reynolds, Charles Subject: FW: PBU C-23C Please follow-up with Tom. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, November 05, 2008 10:26 AM To: McMullen, John C Subject: PBU C-23C John, Would you please forward to Charles, I don't have his eddress. I am reviewing the permit application for this well. Looking at the well clearance/well proximity, it is stated that the closest well is C-09A at 800' distant. 1 do not find C-09A shown on the plan view of wells provided by Schlumberger. Please check the information and if necessary submit any new directional plots. Email is fine. Call or message with any questions. Tom Maunder, PE AOGCC 11 /7/2008 i by i To: Tom Maunder, PE Date: November 7, 2008 AOGCC From: Charles Reynolds 564-5480 O / 575-6234 M BP Exploration Subject: C-23C Closest Well Discrepancy In response to our previous conversation I have researched and addressed what I believe to be the two root issues behind the confusion about the closest well to the planned C-23C sidetrack. Issue 1: Why C-09A does not fail the anti-collision scan and therefore does not appear in the supplied directional data? The anti-collision scan works on the premise of the traveling cylinder to identify wells that fall within a defined perpendicular distance from the planned wellbore. Since C-09 is to the southeast of the planned northwest trending C-23C, it would not appear in any measurements taken perpendicular to the C-23C well path. Issue 2: What is the closest Zone 2A producible completion to the planned C-23C wellbore? After further review it has been determined that the 800' offset between C-09 and C-23C is actually in reference to the parent C-23B wellbore. When measurement is taken from C-09 to the new C-23C sidetrack the offset distance is actually 1200'. This finding excludes C-09 from further consideration in this matter. Based on the anti-collision scan the C-11A wellbore, is the closest well to the projected C- 23C. C-11A is currently a Zone 2A completion. Given this analysis, the closest offset within Zone 2A to the planned C-23C wellbore is C-11A at a distance of 823'. r~ TRANSMI'TT'AL LETTER CHECKLIST WELL NAME ~j~~ ~'_~3~ PTD# ~o~ f,~a ~Development~ _____ Service _ Exploratory _ S~~gra hic Test _____ Non-Conventional Weil p FIELD: _f~-.~'c/~,yDE /S~.s~y POOL: _f ~L/lac/G~' Cirde Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS \1yppT (OPTIONS) X.Z. 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 number are . AP[ No. SO- betwcen 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), alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PI-~ and APl number (50 = _) from records, data and logs acquires for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 2S.OSS. Approval to perforate and Produce // r ~ is contingept 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 Al! 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 ane fast caught and 10' sample intervals throu tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed mejhane is not allowed for jn_ame of well) until after (Comnanv Namel has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _(Comoanv Name) must contact the Commission to obtain advance approval of such water welt testing nmo~.m Rev: I111/20Q8 .WELL PERMR CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT C-23C Program DEV Well bore sag ^ PTD#:2081700 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV! PEND GeoArea 890 Unit 11650 OnlOff Share On Annular Disposal ^ Administration 1 Petmi#feeattached_-- -- ----- ---- -- ------- ------------- NA---- - - -- -- --- -- - -- -- --- --- -- - --- 2 l.easenumberapproRdate.- - - --- --- -- -- -- --- --- -Yes - -- ------ -- - ------ ---- -- --- - ---- 3 Unique well-natneandnumbet-- --------- --- -Yes----- ---- -- -- -- -- - --- -- ------- -- 4 Welllocs#edin.adefinedpool-------------------------- -------------Yes----- --P[udhoeBay Oil Pool.------------------------------- -- 5 Well located proper distance from drillingunit_boundary----------- ------____--Yes----- -----------------------------------------------.------------__ -- 6 Well locatedp[operdistan~efCOmotherwells-------------- ---------Yes----- ------------------------------------- ------------------------------ 7 Sufficientacreageavailahleind1111ingun)t___________________ _____________Yes---- --2560 acres.--_--_---___---_---____________-___--__-- -------------- 8 If deviated, iswellhoreplatiocluded______________________ _____________Yes----_ -__._ -------------------------------------------------------------- 9 Ops[atotonlyaffeotedParkY - ---------- -- -- - -- --- ---- Yes- - - ---- -- - ----- -- --- - --- - - ------ 10 Ope[atorhas_approprjatet2ondinfQroe___---_._____----- -----------_Yes_____ _-8lanketBond#6994163.-__--__-__________.__----------_---_ - -- -- 11 Pe[mitcanbeissuedwithoutoonsentationorder--------------- -------------Yes------ ------------------------------------------------------------------- Appr Date 12 Permitcan he issued wkhout edminist[ative_app[oyal _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ - - - _ - -------------------------------------------------------------------- ACS 111412008 13 CanpermkbeapRrovedbefore15-daY-wah---- - -- -- -- --- --- ----Yes - - - -- -- - ----- - - - -- -- -- -- - -------- 14 Well located within area and_sirata authorized by_ Injection Order # (put10# in_comments). (Fof_ NA_ _ _ _ _ _ _ - 15 Allwells-within 1l4_mile atfla_of review identified (For service well only) _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ . _ - - _ _ _ _ _ _ - ------------------------------------------------------------ 16 Pre-produced injector; duration of preproduction lessthan3months-(Far service well oniy)__NA__--_ ---_---___---------___________________-_--__--___-_-________ 17 Nonconven,gasconformstoA&31.05.030(1.1.A),Q.2.A-D)- -- - --------- - NA- - - --- -- - -- - ----- ------ _ --------- Engineering 18 Conductorstnng_provided-----.--------------------- ------------- NA_____ _Canductorset_inC-23~1.8~-108),-----------------------------------------_-- 19 SurfacecasingRrotectsallknownU&DWS-_--------------- --------_-- NA_-__-__ _Allaquifersexemp#ed,AE01,------------------------------------------------ 20 CMTvoladequatetocircuta#e onconductor&surf-csg----------- ------------- NA_-_-- _$urf_acecasingsetinC-23.-__---__-_-__--_--_-------_-- --------------- 21 CMT vol adequate to tie-in long s#ring fo surf csg- _ - - - - _ - - NA- - _ _ _ _ _ _ Production_casing set in C-23. _Production liner set in C•13B (203-060)__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 22 CMT will cover-ail knownptoduciiveborizons_______.__ -___._____Yes------ -----------.--------------------------------------------------_-- 23 Casing designs adequate for C, T, 6 & permafrost- - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - 24 Adequa#e tankage-or reserve pit - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - - - . _ Rig equipped with steel pits. No reserve pit plann_ed,_ AItwaste-tc approved disposalwell(s), _ - _ _ - _ _ _ _ _ _ - _ 25 Ifa_re-drill,hss_a10-403forabandonmentbeenapproved_-_____ ________-___ Yes-_____ _308.39f3----------------------------------------------------_---_---_- 26 Adequa#e wellhote seperationproposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - _ - . - Proximity analysis performed, Closest segmentis P6A portion of C-238 and paths diverge._ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 If diveder_r@quited,doesitmeetregulations_-__-___-_-__ -_-___-_____KA_______ _~OPStack_will already-be_inplace_____________________-----__----_---_---- Appr Date 28 Drilling fluid-program schematic_& equip list adequate_ Yes - _ - - - _ -Maximum expected formation pressure 7,1-EMW._ MW planned 8.6 ppg. _ - - - - - - - - - - _ _ _ _ _ _ _ _ TEM 111712008 29 BOPEs,.dotheymeetregulaiion-------------------- ------_---Yes------ ----------------------------------------------------- 30 BOPE_ptess rating appropriate; test to-(put prig in_comments)- - - - - - - - - - - - - - - - - - - - Yes - _ - . _ ---------_---- - MASP calculated at 2357psi, 3500-psi_BOP testptanned: - - _ _ _ _ _ _ - - _ - - _ _ - - _ - - - --- 31 Choke.manif0ld complies wlAPl_RP~3 (May 84) - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will occurwilhoutoperaUonshutdown----- - -- --- --- ---------Yes--- --- ---- - - -- -- ----- - ---- -- -- - - 33 IS presence of H2S gas probable - - - - - - - - - - - - - - - - - - .. - - . - . Yes - - - - - - - H2S reported at C Dad. Mud should preclude H2S cn rig. -Rig has_sensors-and alarms, - - _ _ _ _ _ _ _ . 34 Mechanicatconditiot~ofwellswithinAORyerifed(Forsetvicewellpnly~_ _____________ NA-_-_-- -__-_____-____-_,---_---_---__---_--_---_-------_ -_- - _--_- Geology 35 Permi# can be issued w!o hydrogen sulfide measures - - - - - - - - - - - - - - - - - - - - - - - - - No- _ - - Max level H2$ on C pad_was 25ppm on well C-39A, _ _ _ _ _ - -------------------- 36 Datapteser~8donpoientialovelpressurezone--------------- --------------NA------ ------------------------------------------------------------------- Appr Date 37 SeismicanalYSisofshellowgas_zones---- --------- ------ -- ------- ---NA - - - --- ---- - - -- --- ... ------- ---- - - ACS 111412008 38 Sashed corldkion survey_(if off shore) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - ------------- NA---- - - --- - ------ - - --- - --- --- ------ -- -- -- -- - --- 39 Cantaci namelphone for week~.Rrcrgtess reports_ [explotatQry only - - - - - - - - - - - - - -Yes - - - - - - -Charles R@ynolds -564-54@0- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Pub Engineering Commissioner: Date: Date C m~ssioner: omm Date er Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • i **** REEL HEADER **** MWD 09/02/20 BHI Ol LIS Customer Format Tape **** TAPE HEADER **** MWD 08/12/09 2352790 01 3" CTK *** LIS COMMENT RECORD *** !!!!~!~~!!!!~!!!!!! Remark File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 9414.0000: Starting Depth STOP.FT 12993.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: C-23C FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 17' 48.378"N 148 deg 40' 8.677"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 09 Dec 2008 API API NUMBER: 500292077503 Parameter Information Block Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 (1) All depths are Measured Depths (MD) unless otherwise noted. #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N T11N RANG. R14E PDAT. MSL EPD . F 0 LMF DF FAPD.F 65.6 DMF DF EKB .F 0 EDF .F 65.6 EGL .F 0 CASE.F N/A OS1 DIRECTIONAL Remarks (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 11 Dec 2008 per Doug Stoner with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from C-23B through a milled window in a 4 1/2 inch liner. Top of window 10677 ft.MD (8954.85 ft.TVDSS) Bottom of window 10685 ft.MD (8954.90 ft.TVDS5) (9) Tied to C-23B at 10648 feet MD (8954.8 feet TVDSS). (10) The interval from 12255 feet to 12295 feet MD (8951.7 feet to 8954.9 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) (OHMM) (OHMM) (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected TVDSS -> True Vertical Depth (Subsea) CURVE SHIF T DATA BASELINE, MEASURED, DISPLACEMENT 9416.04, 9414.8, ! -1.24316 9425.37, 9424.13, ! -1.24414 9428.27, 9427.65, ! -0.621094 9429.31, 9428.48, ! -0.829102 9431.8, 9431.17, ! -0.62207 9435.11, 9434.7, ! -0.414062 9439.47, 9439.47, ! 0 9446.51, 9446.31, ! -0.207031 9451.7, 9450.04, ! -1.6582 9457.09, 9456.05, ! -1.03613 9460.61, 9460.2, ! -0.415039 9467.45, 9466.21, ! -1.24414 9474.5, 9474.08, ! -0.415039 9481.34, 9480.72, ! -0.62207 9490.46, 9490.25, ! -0.207031 10682.6, 10681.2, ! -1.45117 10683.5, 10682.4, ! -1.03613 10685.7, 10684.5, ! -1.24316 10986.6, 10983.5, ! -3.11035 10989.9, 10987, ! -2.90234 10997.4, 10995.1, ! -2.28027 11002.4, 10999.7, ! -2.69434 11010.2, 11007.8, ! -2.4873 11040.7, 11040.3, ! -0.415039 11068, 1 1068.2, ! 0.208008 11078.5, 11079.2, ! 0.62207 11111.6, 11111, ! -0.62207 11120.1, 11119.3, ! -0.829102 11131.7, 11128.6, ! -3.10938 11133.6, 11130.5, ! -3.10938 11138, 1 1136.1, ! -1.86523 11147.7, 11145.8, ! -1.86523 11154.8, 11153.3, ! -1.4502 11187.9, 11185.2, ! -2.69434 11210, 1 1206.5, ! -3.52344 11220.4, 11217.3, ! -3.10938 11222.5, 11219, ! -3.52441 11224.6, 11220.9, ! -3.73145 11228.1, 11224.6, ! -3.52344 11228.9, 11225.8, ! -3.10938 11234.3, 11229.8, ! -4.56055 11245.5, 11241.8, ! -3.73145 11249.7, 11245.9, ! -3.73145 11251.3, 11249.5, ! -1.86621 11265.2, 11261.3, ! -3.93848 11288.4, 11285.5, ! -2.90234 11297.5, 11295.7, ! -1.86621 11303.1, 11300.9, ! -2.28027 11310.8, 11309, ! -1.86523 11334.7, 11331, ! -3.73145 11337, 11335, ! -2.07324 11341, 11337.4, ! -3.52344 11355.9, 11352.2, ! -3.73.145 11357.5, 11354.6, ! -2.90234 11360.9, 11357.5, ! -3.31641 11363.8, 11362.5, ! -1.24414 11366.5, 11364.2, ! -2.28027 11370.2, 11368.3, ! -1.86523 11373.9, 11372.1, ! -1.86523 11377.7, 11376.4, ! -1.24316 11387.4, 11386.4, ! -1.03711 11390.8, 11389.5, ! -1.24414 11419.4, 11419.8, ! 0.415039 11576.7, 11567.7, ! -8.91406 11586.6, 11579.1, ! -7.46289 11592.2, 11586.6, ! -5.59668 11597.6, 11591.2, ! -6.42676 11599.7, 11594.5, ! -5.18262 11603.6, 11597.4, ! -6.21875 11609.4, 11605.4, ! -3.93848 11612.3, 11607.9, ! -4.35352 11615, 11611, ! -3.93848 11618.1, 11616, ! -2.07227 11620.8, 11619.5, ! -1.24414 11628.4, 11625.1, ! -3.31641 11632.2, 11628, ! -4.14648 11636.3, 11633.2, ! -3.10938 11640.9, 11638, ! -2.90234 11704.9, 11702, ! -2.90137 11710.2, 11708.8, ! -1.4502 11713.1, 11711.3, ! -1.86523 11738.3, 11737.2, ! -1.03711 11766.3, 11763.6, ! -2.69434 11774.3, 11772.3, ! -2.07324 11785.1, 11781.6, ! -3.52441 11793.4, 11790.7, ! -2.69434 11796.9, 11794.4, ! -2.4873 11801.7, 11797.8, ! -3.93848 11815.2, 11812.1, ! -3.10938 11817, 11814.1, ! -2.90137 11825.1, 11824.1, ! -1.03711 11831.7, 11828.6, ! -3.10938 11834.4, 11831.5, ! -2.90234 11839.2, 11836.1, ! -3.10938 11844.6, 11841.3, ! -3.31641 12009.2, 12005.5, ! -3.73145 12018.7, 12014.6, ! -4.14648 12024.1, 12020.4, ! -3.73145 12028.7, 12024.1, ! -4.56055 12036.2, 12031.8, ! -4.35254 12100.9, 12101.3, ! 0.415039 12108, 12106.3, ! -1.6582 12114.6, 12112.7, ! -1.86523 12117.5, 12115.6, ! -1.86621 12121.6, 12119.6, ! -2.07227 12145, 12142.7, ! -2.28027 12152.5, 12151.4, ! -1.03613 12160.3, 12156.6, ! -3.73047 12163.9, 12161.4, ! -2.4873 12172.4, 12169.7, ! -2.69434 12179.4, 12179, ! -0.415039 12181.9, 12181.3, ! -0.62207 12201.6, 12200.3, ! -1.24414 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 188 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!ii!!!!!!!!!!!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDCL from Schlumberger GR CNL dated 11 Dec 2008 per Doug Stoner with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 160 Tape File Start Depth = 9414.000000 Tape File End Depth = 12293.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 173 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME _ Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 320 Tape File Start Depth = 9415.000000 Tape File End Depth = 12294.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 333 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/12/09 2352790 01 **** REEL TRAILER **** MWD 09/02/20 BHI 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • • Tape Subfile 1 is type: LIS s • Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9414.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9414.5000 84.1454 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9800.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9900.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 -999.2500 -999.2500 -999.2500 -999..2500 -999.2500 -999.2500 10300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10600.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10700.0000 23.3416 93.2778 6.1867 6.1867 5.7148 4.7306 10800.0000 24.5661 132.0052 13.6569 13.6569 19.9440 21.4500 10900.0000 21.0755 174.1063 15.0540 15.0540 20.6350 21.3711 11000.0000 105.0821 102.7182 13.3909 13.3909 14.6886 14.0210 11100.0000 25.8900 123.6200 13.8940 13.8940 18.1462 17.6254 11200.0000 49.8441 196.4123 10.7426 10.7426 11.4272 10.6970 11300.0000 65.8503 140.8196 11.1212 11.1212 10.8561 9.8811 11400.0000 30.5535 202.6771 12.3290 12.0485 11500.0000 24.1530 230.9861 16.7710 16.9070 11600.0000 172.4419 34.6127 9.6692 10.3046 11700.0000 25.7406 122.7023 9.1457 7.4879 11800.0000 45..1960 68.7211 8.4720 7.5260 11900.0000 29.4201 167.6542 11.3982 11.8280 12000.0000 34.8075 168.7496 9.7260 9.6090 12100.0000 38.0711 161.3341 9.4284 9.4955 12200.0000 36.3187 188.7519 11.6999 13.4794 12293.5000 -999.2500 68.5068 -999.2500 -999.2500 Tape File Start Depth = 9414.000000 Tape File End Depth = 12293.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet i 10.3267 12.8402 9.7538 10.6278 9.3990 9.5318 9.0795 8.7795 8.7337 -999.2500 10.3267 12.8402 9.7538 10.6278 9.3990 9.5318 9.0795 8.7795 8.7337 -999.2500 • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9415.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9415.2500 90.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9600.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9700.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9800.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9900.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10000.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10100.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10500.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10600.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10700.0000 24.0000 92.1000 5.5650 6.3250 5.9970 5.1120 10800.0000 23.8000 126.6000 13.5960 19.9010 20.1810 21.7430 10900.0000 16.8000 180.5000 14.7530 20.6330 20.6690 21.7930 11000.0000 96.8000 159.7000 13.6750 15.5440 13.3500 11.8000 11100.0000 25.8000 123.8000 13.8940 20.3050 18.1000 17.5240 11200.0000 49.4000 257.9000 11.1250 13.3020 11.9360 11.1900 11300.0000 58.3000 138.0000 11.1720 12.2540 11.1630 10.2900 11400.0000 30.2000 371.6000 12.3290 12.0160 11500.0000 24.7000 359.2000 16.9530 17.3220 11600.0000 39.3000 227.1000 11.4650 12.3450 11700.0000 23.2000 173.0000 8.8450 7.3640 11800.0000 50.9000 252.1000 8.9600 8.0680 11900.0000 27.0000 158.8000 11.3560 11.7070 12000.0000 26.5000 158.4000 9.8650 9.8600 12100.0000 39.0000 147.4000 9.4600 9.4590 12200.0000 31.3000 192.4000 11.7140 13.4990 12294.7500 -999.2500 235.2000 -999.2500 -999.2500 Tape File Start Depth = 9415.000000 Tape File End Depth = 12294.750000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet • 10.3020 ,12.9650 9.3330 10.2280 9.7120 9.6310 9.1220 8.8340 8.6720 -999.2500 13.5960 18.3770 12.8370 10.7850 9.5940 11.2190 10.0270 9.8230 10.9540 -999.2500 • Tape Subfile 4 is type: LIS
