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• • 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. ~g - ~ ~ ~ Well History File Identifier Organizing (done) RESC N Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: o.~.~, iuuiiimiuum DIGITAL DATA ~skettes, No. 1 ^ Other, No/Type: ~, a.~,~~,~~ iuuiuuuiiui OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: BY Date: ~ ~,~ f~ Project Proofing BY: Maria Date: Scanning Preparation ~ x 30 = BY: Maria Date: ~ l Production Scanning ^ Other:: /s/ iuuiuuiiwiimmP + ~ =TOTAL PAGES (Count does not include cover sheet) /s! Stage 1 Page Count from Scanned File: ~ (Count does include cov sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ f / //d ~s~ I Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~s~ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: ~s~ Comments about this file: Quality Checked III IIIIII III IIII III 10/6/2005 Well History File Cover Page.doc • STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMM. .ON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Repair Well U Plug Perforations Li Perforate Li OtherU Mill CIBP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdowns Stimulate-Other ❑ Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc y Development Exploratory ❑ 208-080-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20594-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028282 ` PBU N-14B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOF L 11.Present Well Condition Summary: RECEIVE ()CEIV ( Total Depth measured . 10123 feet Plugs measured None feet APR 0 3 2 G.i,, true vertical 8770.42 feet Junk measured 10010 feet (+,► AOGC Effective Depth measured . 10085 feet Packer measured See Attachment feet ^"' true vertical 8795.23 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 29-109 29-109 0 0 Surface 2646 13-3/8"72#L-80 28-2674 28-2673.95 4930 2670 Intermediate None None None None None None Production 8250 9-5/8"47#L-80 27-8277 27-7628.91 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9640-9665 feet 9940-9950 feet 9965-9995 feet 10006-10026 feet True Vertical depth 8849.43-8865.74 feet 8874.75-8870.44 feet 8863.67-8848.85 feet 8842.99-8831.79 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 27-9159 27-8418.99 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): SCANNED MAY 2 9 2014 SCANNED RBDMS MAY 14 2014 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: 57 1587 3770 2056 633 Subsequent to operation: 423 4702 624 1341 284 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑✓ Gas U WDSPLLI GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCI 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 Analisa Steger Email Analisa.Ste•er• BP.Com Printed Name Analisaa)A4j. Steger � Title DC Data Manager Signature Phone 564-5439 Date 4/3/2014 VL4 3-/2Z/jj Form 10-404 Revised 10/2012 Submit Original Only • Daily Report of Well Operations ADL0028282 TE CTU 3 w/ 1.75" 0.134"wall CT-32.9 bbl Vol Job Scope: Mill CIBP MIRU - MU BHA to mill CIBP- 3/3/2014 *** Job Still in Progress *** CTU 3 w/ 1.75" 0.134" wall CT- 32.9 bbl Vol Job Scope: Mill CIBP MIRU - MU BHA to mill CIBP - Tag high/stringers @ 9660'. Mill to 9742'with 1 stall. Dry tag @ 9737'. FP coil POOH for safety standdown. Cap well with 20.5 bbl meth/wtr. Stand tools on back deck and secure well for SWS safety standdown. RU on WH. 3/3/2014 *** Job Continued on WSR 3-4-14 *** CTU 3w/ 1.75" 0.134"wall CT- 32.9bbl Vol Job Scope: Mill CIBP 3/3/2014 *** Job Still in Progress *** CTU 3w/ 1.75" 0.134"wall CT- 32.9bbl Vol Job Scope: Mill CIBP RU to RIH to Mill - Gas Monitor Not working -Waiting to fix Gas Monitor(SCE). Replace power supply. RIH w/2.3"junk mill on 1 11/16" motor. Dry tag @ 9731'. Mill to 9746' with 1 stall. Jet gel pill above CIBP. Chase out of 2 7/8" liner while ciruclating bottoms up. POOH -Stop @ 2500' Circ 60/40 Meth FP Well - Pop off WH RD. 3/4/2014 ***Job Continued on WSR 3-5-14 *** CTU 3 w/ 1.75" 0.134"wall CT- 32.9 bbl Vol Job Scope: Mill CIBP RU to RIH to Mill -Gas Monitor Not working -Waiting to fix Gas Monitor(SCE). Replace power supply. RIH w/2.3"junk mill on 1 11/16" motor. Dry tag @ 9731'. Mill to 9746'with 1 stall. Jet gel pill above CIBP. Chase out of 2 7/8" liner while ciruclating bottoms up. 3/4/2014 ***Job Still In Progress *** CTU 3 w/ 1.75" 0.134" wall CT- 32.9 bbl Vol Job Scope: Mill CIBP RDMO CTU 3 3/5/2014 ***Job on Hold / Moving to 09-47 *** CTU#3 w/ 1.75" (CTV=31.9 bbls) Job Scope: Mill CIBP and Push to Btm MIRU. Double barrier test. NU BOPE. M/U WFD 2.30 milling BHA with up/dwn jars. PT Lube. RIH. Swap out meth in coil to slick KCL while RIH. RIH to 9700'. Circ 15 bbl Powervis sweep to mill. Dry tag at 9756'. Chase sweep to surface to clean hole. Attempt to time mill CIBP. Appears plug moved -1', lost returns to surface. Attempted to mill/push plug with no luck. Unable to see motor work or able to stall, pooh to inspect BHA. 3/13/2014 ***Job In Progress*** CTU 3 w/ 1.75" 0.134"wall CT- 32.1 bbl Vol Job Scope: Mill CIBP and Push to Btm MIRU. Double barrier test. NU BOPE. M/U WFD 2.30 milling BHA with up/dwn jars. PT Lube. RIH. Swap out meth in coil to slick KCL while RIH. RIH to 9700'. Circ 15 bbl Powervis sweep to mill. Dry tag at 9756'. Chase sweep to surface to clean hole. Tag CIBP at 9756'with motor. Stall 1. Pick up 100'. Time Mill with 3 more stalls. 3/13/2014 ***Job Still in Progress *** CTU 3 w/ 1.75" 0.134"wall CT- 32.1 bbl Vol Job Scope: Mill CIBP and Push to Btm MIRU 3/13/2014 *** Job Still in Progress *** Daily Report of Well Operations ADL0028282 CTU#3 w/ 1.75" (CTV=31.9 bbls) Job Scope: Mill CIBP and Push to Btm MIRU. Double barrier test. NU BOPE. M/U WFD 2.30 milling BHA with up/dwn jars. PT Lube. RIH. Swap out meth in coil to slick KCL while RIH. RIH to 9700'. Circ 15 bbl Powervis sweep to mill. Dry tag at 9756'. Chase sweep to surface to clean hole. Attempt to time mill CIBP. Appears plug moved —1', lost returns to surface. Attempted to mill/push plug with no luck. Quit seeing motor work or able to stall motor, pooh to inspect BHA. 3/13/2014 ***Job In Progress*** CTU#3 w/ 1.75" CT (CTV=31.9 bbls) Job Scope: Mill CIBP and Push to Btm. Re-run WFD 2.30" milling BHA w/agitator in progress. Sat down on 3.5" liner top. Work thru. RIH. Sat down at 9408'. Mill thru. RIH and mill on CIBP at 9760'. Mill thru and pushed CIBP to 10005'. Wiper trip up to 9300' to check liner. RIH and pushed plug to 10010'. Pick up to 9900', RIH and tag plug at 9950'. Inclination in liner at 9950' = 117 deg. 9990' = 121 deg inclination. Inverted hole, plug sliding down hill when pushed to bottom. Talked to town eng. Pushed plug to 10010' again and POH. Slickline to run catcher sub in 4.5"tailpipe to catch plug if it flows up well. Freeze protect tubing to 2500'with 60/40 meth. FP coil. PJSM. Lay out milling BHA. Mill gauged at 2.25". Perform weekly BOPE pressure/function test. 3/14/2014 ***Job In Progress** ***COST PLACEHOLDER*** 3/16/2014 PURCHASE FINGER CAGES TO MAKE DREAMCATCHER ****WELL S/I UPON ARRIVAL**** (profile modification) RIG UP SLICKLINE UNIT SWCP#4517 3/17/2014 ****CONT. JOB ON 3/18/14**** ****CONT. JOB FROM 3/17/14**** (profile modification) DRIFTED W/4-1/2" BRUSH, 3.805" G-RING TO DEPLOYMENT SLEEVE @ 9078' SLM (brushed nipples) MADE 3 ATTEMPTS TO SET 4-1/2" DREAM CATCHER @ 9081' MD/9036' MD (returned w/metal shavings), DRIFTED W/ KJ, 4-1/2" BRUSH, 3.80" G-RING TO X-NIPPLES @ 9081' MD/9036' MD (brushed profiles for—30 min) MADE 4TH ATTEMPT TO SET 4-1/2" DREAM CATCHER @ 9081' MD/9036' MD (same results) SET 4-1/2" SLIP STOP CATCHER @ 4136' SLM,PUMPED —14 BBL DIESEL DOWN TUBING W/ TRIPLEX FOR GASLIFT UNDERBALANCE PULLED STA#5 RK-DGLV FROM 4005' SLM/4028' MD &STA#6 RK-DGLV FROM 3265' SLM / 3286' MD SET STA#6 RK-LGLV & STA#5 RK-OGLV 3/18/2014 ****CONT. JOB ON 3/19/14**** ****CONT. JOB FROM 3/18/14****(profile modification) PULLED 4-1/2" SLIP STOP CATCHER FROM 4136' SLM (empty) BRUSH & FLUSH /4-1/2" BRUSH, 3.80 GAUGE RING TO DEPLOYMENT SLEEVE LRS PUMPED 5 BBL METH, 112 BBL 180* CRUDE DOWN TUBING SET 4-1/2" DREAM CATCHER @ 9051' SLM/9081' MD RAN CHECK SET TO DREAM CATCHER @ 9081' MD (good set) 3/19/2014 ****WELL LEFT S/I & PAD-OP NOTIFIED OF STATUS UPON DEPARTURE**** T/I/O =0/0/280 Temp = S/I Assist SSL with brush and flush. Pumped 5 bbls neat methanol,followed by 112 bbls of 180*crude down tbg while SSL worked brush. SSL still on well at LRS departure. FWHP= 650/0/319 3/19/2014 � Cn -0rrrrO C C o Z Z Z Z O CO ThOrnrnrrIMZ0 z D 0717:13:1730w 0 C C) 5 m -I CC O O z 1 r N OoJ N N CD - W N O W (O W CO CO N 0) O O(Q A A N - G.3 N - N - N ^ pp cc-) 0 Oo _ N O p N O) v N O �# x N' 060o & o (C Fo Oo0 D o CO CO CO CO N N N A N O N N CO CO W N CO CO CO - v CJl IV > E CO rF 1111111 CO N CO - CO CO CO - N CD A A A cn v N O) CA (O A �l W v v v CD OD CO CO �l 0) A W A N N N N CO co 0) N) v ▪ co -.4 W N Cn N A W C7) —1 I I I I 1 1 I v CO N v 00 0) CO co C) O) - 0) 0) 0) N v CO 01 CO CO W CO O --AN J O CO CO co A CIi O CIl O CO 01 N W N W CO A co c CO A CO CO O A O N C W W CP W 0 0 0 0) 0 p C) N A J O 01 C 01 0) v - CDA O �I - O c 0 0 0cr, O co O N CD Packers and SSV's Attachment ADL0028282 SW Name _ Type MD TVD Depscription N-14B PACKER 8091 7391.09 7" Baker HMC Packer N-14B PACKER 9058 8253.16 4-1/2" Baker S-3 Hydro Set Packer N-14B PACKER 9237 8414.87 5" Baker ZXP Top Packer a) N ld m .4 LC) 0) CO N- S COO CO CO a) N- V M ❑ CO CO CO CO ❑ CO CO CO CO Q 0 CO Lf) f— O) N- CO O) °. O) 4 cei N d N- CO ❑ co 00 co 00 ❑ CO CO CO CO F a) N ca y• LC) O LX) N ++ °_ CO LO O O = a) CO O O) 4 ❑ O) O) (3) N a) V N 03 - a Q N 03 F = C « O O in (O O Q13 0) O) O) O 03 R L a) 0 L a) a O U c .2 N d a d a U' 0- a- d y () m m CO a 0 0 C) a a) c• O O O O o N N N N V v- 0 0 a) E m Z CO C0 00 0. v v v zzzz TREE= 4-1/16'CNV SA .'NOTES: '"4-1/2"CHROME TBG"'WELL �Wt1LHEAD= FMC ANGLE>70°(ED 9727'. ACTUATOR= BAKER C OKE.ELEV= 78.67' BF ELEV= 45.07' I I 2012' 1-1/2"IES NP,D=3.813" KOP= 3196' Max Angle= 131°@ 10776' �{ 2593' —9-5/8"DV RCR Datum Mn= 9679' = GAS LFT MANDRELS Datum ND= 8800'SS IL ST MD IVO DEV TYPE VLV LATCH FORT DATE 13-3/8'CSG,72#,L-80 BTS,D=12.347' -1-- 2678' 6 3286 3282 13 MMG DOME RK ' 16-03/18/14 5 4028 3977 26 MMS SO RK ' 20 03/18/14 4 5778 5508 34 I? DM' RK ' 0 09/13/13 3 7317 6794 31 MMG DMY RK ' 0 01/25/10 TOP OF 7"LNR -{ 8091' 2 8144 7512 29 KBG DMY BK ' 0 09/06/08 1 8969 8247 25 KBG DMY BK ' 0 01/25/10 Minimum ID = 2.25" @ 9420' LINER RESTRICTION 8091' —19-5/8"X 7"BKR ZXP PKR/HGR,D=6.331" 9-5/8'CSG,47#,L-80,D=8.681' H 8277' 9-5/8"MIL.LOUT WINDOW(N-14A) 8277'-8293' 1 ' 9036' —14-1/2"HES NIP,D=3.813" g9058' --1 7"X 4-1/2"BKR S-3 PKR D=3.875" DREAM CATCHER(03/19/14) —{ 9081' N 9081' —14-112"FES NIP,D=3.813" r 9115' --{3-1/2'DEPLOY SLV,D=3.00" 4-1/2"TBG, 12.6#,13CR-80 VAM TOP, H 9144' 0152 bpf,D=3.958" V 9159' —I 7"X 4-1/2"BKR UNIQUE OVERSHOT 4-1/2"TUBING STUB(09/04/08) —I 9140' ' ' 9175' H4-112"FES X NP,D=3.813" BEHIND zr9186' —{7"X 4-1/2"BKR S-3 PKR,D=3.875" LNR 1 1 ' 9209' —14-1/2"FES X NIP,ID=3.813' 4-1/2"TBG, 12.6#,L-80, .0152 bpf,D=3.958' —{ 9242' .c 9230'Ia 9230' 1-14-1/7 1-ES XN NP,MLL®TO 3.80(09/11/08) 9237' —7"X 5"BKR ZXP LTP w/HGF.D=4.375" TOP OF 4-1/2'LNR --I 9237' 9242' —14-1/2'WLEG, D=3.958" BEHIND LNR 7"LNR,26#,L-80 BUTT, .0383 bpf,ID=6.276" H 9405'1 k - 9263' --I5"X 4-1/2"XO,D=3.958" 3-1/2"LNR 9.2#,L-80 STL,.0087 bpf,D=2.992" H 9417' 9417' F-31/2"X 2-7/8"XO,D=2.387" 4-1/2"WFPSTOCK(0X/XX/08) H{ 9467' 9420' —LNR RESTRICTION,D=2.25"(MLLED 03/14/14) 4-1/2"FES BKR CBP(06/09/08) —{ 9500' 4-1/2"MLLOIJT WIDOW(N-148) 9467'-9476' PERFORATION SUv*hARY REF LOG:SV\S-MCNIJGR/CCL run 09/20/2008 9688' }--OV A L DEFORMATION,D=2.29" ANGLE AT TOP PERF: 47°@ 9640' (CALIPER 5/17/13) Note:Refer to Production DB for historical pert data `4 .............49699'&9732'1—LNR HOLES(SQZ'D 2/11114) SCE SPF INTERVAL Opn/Sqz SHOT SQZ I ? FISH:2-7/8'CEP 2" 6 9640-9665 S 09/21/08 02/11/14 I ` MILLED/PUSHED 7 6 9940-9950 0 09/21/08 TO BTM(3/14/14) 2' 4 9965 9995 0 09/21/08 ••�•�•* 2" 6 10006- 10026 0 07/01/10 1 MID —{ 10085' 1 2-7/8"LNR,6.4#,L-80 STL, H 10123' ��s. 4-1/2"LNR,12.6#,L-80 BTC-M,.0152 bpf,ID=3.958' H 9959' .0058 bpf,ID=2.441" �At DATE REV BY COMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT 07/26/81 INITIAL COMPLETION 02/20/14 TQ/PJC RESTRICTIONS(5/17/13 CALIPER) WELL: N-14B 07/09/98 SIDETRACK COMPLETION 03/20/14 TFA/JMD MLLED/PUSFED CIBP(03/14/14) PERMIT No:'2080800 09/21/08 NORDIC2 RWO+CTD STRACK(N-14B) 03/27/14 DGB/PJC MILL RESTRICTION(03/14/14) AR No: 50-029-20594-02 09/17/13 SWGJMD GLV GO(09/13/13) 03/27/14 DGB/PJC SET DREAM CATCHER(3/19/14) SEC 8,T11 Nl R13E, 1363'FSL&548'FW_ 11/24/13 JLF/PJC CBP SET(09/24/13) 03/27/14 WEG PJC GLV GO(03/18/14) 02/20/14 TQ/PJC CMT SQZ(02/11/14) BP Exploration(Alaska) A E A KA OIL AND G STCONSERVAT ON COMA. iON RECEIVED REPORT OF SUNDRY WELL OPERATIONS MAR 0 4 2014 1.Operations Abandon ❑ Repair Well Lif Plug Perforations U Perforate ❑ Other Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions OG VG Change Approved Program ❑ Operat.Shutdowns Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: I Name: BP Exploration(Alaska),Inc Developments Exploratory ❑ . 208-080-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 „ ' 50-029-20594-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028282 . PBU N-14B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • 1 PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured • 10123 feet Plugs measured 9770 feet true vertical 8770.42 feet Junk measured None feet Effective Depth measured 9770 feet Packer measured See Attachment feet true vertical 8908.94 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 29-109 29-109 0 0 Surface 2646 13-3/8"72#L-80 28-2674 28-2673.95 4930 2670 Intermediate None None None None None None Production 8249 9-5/8"47#L-80 28-8277 28-7628.91 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 9640-9665 feet 9940-9950 feet 9965-9995 feet 10006-10026 feet True Vertical depth 8849.43-8865.74 feet 8874.75-8870.44 feet 8863.67-8848.85 feet 8842.99-8831.79 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 27-9159 27-8418.99 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): 9640'-9665',9699',9732' Treatment descriptions including volumes used and final pressure: swap AUG 1 4 2014 RBDM MAY 13 2014 09/25/13 Organoseal 121.6 bbls;11/25/13 Organoseal 210 bbls;02/11/14 SqueezeCrete 35 bbls.Final Pressure 1500psi 02/14/2014 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 57 1587 3770 2056 633 Subsequent to operation: 0 0 0 0 0 - 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑, . Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil , E Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Analisa Steger Email Analisa.Steger(caBP.Com Printed Name Analisa Steger Title PDC Data Manager cl Signature rA__, Phone 564-5439 Date 3/4/2014 Form 10-404 Revised 10/2012 A 6X6/1 y Submit Original Only Daily Report of Well Operations ADL0028282 ACTI SATE 111111.1111F SUMMARY T/I/0=330/410/300. (Load&test) Spear into IA w/5 bbls neat meth followed by 428 bbls crude to 9/13/2013 load IA. MIT-IA to 2500 PSI, ****PASSED""""(see log and data tab for details) —"WELL S/I ON ARRIVAL"""(Organoseal) RAN 2.25"CENT., 1-1/2"SAMPLE BAILER, DEV. OUT @ 9,731'SLM(no sample recovered) SET WHIDDON CATCHER SUB @ 9,085'SLM PULLED STA.#4 RK-OGLV @ 5,763'SLM(5,778'MD) PULLED STA.#5 RK-LGLV @ 4,011'SLM(4,028'MD) SET STA.#5 RK-DGLV @ 4,011'SLM(4,028'MD) SET STA.#4 RK-DGLV @ 5763'SLM(5778'MD) LRS PERFORM PASSING MIT-IA TO 2500 PSI (see Irs log) LRS FREEZE PROTECT FLOWLINE 9/13/2013 "`CONT. ON 9/14/13 WSR*** ""CONT. FROM 9/13/13 WSR"""(Organoseal) LRS FREEZE PROTECT FLOWLINE PULLED 4-1/2"WHIDDON CATCHER SUB @ 9,085'SLM 9/14/2013 """WELL S/I ON DEPARTURE""" T/I/0=440 Assist SL as directed (PROFILE MODIFICATION) Pump 5 bbls meth, 37 bbls 70* crude down TBG to free up SL tools. 9/14/2013 FWHP=0/700/300 Slickline in control of well upon departure CV's=OTG WSR continues from 9-13-2013. Freeze Protect Flowline. Pumped 5 bbls meth spear,followed by 37 bbls crude, 5 bbls meth pill,then an additional 57 bbls crude,capped off with 3.5 bbls 9/14/2013 methanol. FWHP=461/0/380 SSL still on well at LRS departure. IA/OA=OTG T/I/O-20/580/300 Temp.-SI Freeze Protect Tubing with 5 bbls of meth and 40 bbls of crude. 9/15/2013 Final WHP- 120/400/300. SV,WV-closed SSV,MV,IA,OA-open AL-SI CTU#3-1.75"Coil Job Objective: GSO with Organoseal/Squeezecrete Road unit from DS2. Standby for WS Rig up.WS finished, MIRU CTU. 9/22/2013 ...Continued on WSR 9-23-13... CTU#3- 1.75"Coil Job Objective: GSO with Organoseal/Squeezecrete Road unit from DS2. Standby for WS Rig up. 9/22/2013 ...Job in Progress... CTU#3- 1.75"Coil""Continued from WSR 9-22-13"* Job Objective: GSO with Organoseal/Sqeezecrete Finish rig up CTU. Make up 1 11/16"motor with a 2.30"mill and RIH. Drift through obstructions and tubing damage clean,tag bottom at 10071, POOH. FP CT-RD motor/mill-RU 2.25"Jet Nozzle- Kill well w/220 bbls 1%KCL-Step Rate Test-RIH-Btm Perf 10000'-Jet 12%HCL across perfs up to 9640'-POOH while pumping 200 bbls 1%KCL down backside-Step Rate Test -251 bbls- 10 bbls Cap Meth backside-Test MicroMotion Backside-1:1 Ratio- 9/23/2013 ,,,Job in progress CTU#3- 1.75"Coil"""Continued from WSR 9-22-13""" Job Objective: GSO with Organoseal/Sqeezecrete Finish rig up CTU. Make up 1 11/16"motor with a 2.30"mill and RIH. Drift through obstructions and tubing damage clean,tag bottom at 10071, POOH. FP CT-RD motor/mill-RU 2.25"Jet Nozzle- Kill well w/220 bbls 1%KCL-Step Rate Test-RIH-Btm Perf 10000'-Jet 12%HCL across perfs up to 9640'-POOH while pumping 200 bbls 1% KCL down backside-Step Rate Test -251 bbls- 10 bbls Cap Meth backside-Test MicroMotion Backside-1:1 Ratio. Make up GR/CCL with 2.2" carrier and 2.25"DJN, RIH. Log from 10000'-9000'with tie in flag painted at 9700'. Saw overpull at 9413', RBIH and re-drift clean. POOH 9/23/2013 ....Continued on WSR 9-24-13 CTU#3-1.75"Coil"""Continued from WSR 9-22-13""" Job Objective:GSO with Organoseal/Sqeezecrete Finish rig up CTU. Make up 1 11/16"motor with a 2.30"mill and RIH. Drift through obstructions and tubing damage clean,tag bottom at 10071, POOH. 9/23/2013 ,,,Job in progress Daily Report of Well Operations ADL0028282 CTU#3- 1.75"Coil***Continued from WSR 9-22-13*** Job Objective: GSO with Organoseal/Sqeezecrete Finish rig up CTU. Make up 1 11/16"motor with a 2.30"mill and RIH. Drift through obstructions and tubing damage clean,tag bottom at 10071, POOH. FP CT-RD motor/mill-RU 2.25"Jet Nozzle- Kill well w/220 bbls I% KCL-Step Rate Test-RIH-Btm Perf 10000'-Jet 12% HCL across perfs up to 9640'-POOH while pumping 200 bbls I%KCL down backside-Step Rate Test -251 bbls- 10 bbls Cap Meth backside-Test MicroMotion Backside- 1:1 Ratio. Make up GR/CCL with 2.2" carrier and 2.25"DJN, RIH. Log from 10000'-9000'with tie in flag painted at 9700'. Saw overpull at 9413', RBIH and re-drift clean. POOH 9/23/2013 ....Continued on WSR 9-24-13 CTU#3-1.75"Coil***Continued from WSR 9-22-13*** Job Objective: GSO with Organoseal/Sqeezecrete Finish rig up CTU. Make up 1 11/16"motor with a 2.30"mill and RIH. Drift through obstructions and tubing damage clean,tag bottom at 10071, POOH. FP CT-RD motor/mill-RU 2.25"Jet Nozzle- Kill well w/220 bbls 1%KCL-Step Rate Test-RIH-Btm Perf 10000'-Jet 12%HCL across perfs up to 9640'-POOH while pumping 200 bbls 1%KCL down backside-Step Rate Test -251 bbls- 10 bbls Cap Meth backside-Test MicroMotion Backside- 1:1 Ratio. Make up GR/CCL with 2.2" carrier and 2.25"DJN, RIH. Log from 10000'-9000'with tie in flag painted at 9700'.Saw overpull at 9413', RBIH and re-drift clean. POOH 9/23/2013 ....Continued on WSR 9-24-13 CTU#3-1.75"Coil***Continued from WSR 9-22-13*** Job Objective: GSO with Organoseal/Sqeezecrete Finish rig up CTU. Make up 1 11/16"motor with a 2.30"mill and RIH. 9/23/2013 ,,,Job in progress... CTU#3-1.75"Coil ***Continued from WSR 9-23-13*** Job Objective: GSO with Organoseal/Squeezecrete POOH with GR/CCL for tie in log. Confirm good data and+12.0'correction. Make up 2 7/8"CIBP and RIH. Correct depth at flag to 9712.7'mid element of CIBP. CIBP set at 9770'mid element due to collar location,sheared at 3250 psi.Tag plug to confirm and POOH. 7 day BOP Test-Top Blind Shear Failed-Rest of BOP Test good-SCE to re-build Top Blind Shear. 9/24/2013 ...Job in Progress... CTU#3- 1.75"Coil ***Continued from WSR 9-23-13*** Job Objective: GSO with Organoseal/Squeezecrete POOH with GR/CCL for tie in log.Confirm good data and+12.0'correction. Make up 2 7/8"CIBP and RIH. Correct depth at flag to 9712.7'mid element of CIBP.CIBP set at 9770'mid element due to collar location,sheared at 3250 psi.Tag plug to confirm and POOH. 9/24/2013 ...Job in Progress... CTU#3-1.75"Coil ***Continued from WSR 9-23-13*** Job Objective: GSO with Organoseal/Squeezecrete POOH with GR/CCL for tie in log. Confirm good data and+12.0'correction. Make up 2 7/8"CIBP and RIH. Correct depth at flag to 9712.7'mid element of CIBP.CIBP set at 9770'mid element due to collar location, sheared at 3250 psi.Tag plug to confirm and POOH. 9/24/2013 ...Job in Progress... CTU#3- 1.75"Coil ***Continued from WSR 9-23-13*** Job Objective: GSO with Organoseal/Squeezecrete POOH with GR/CCL for tie in log. Confirm good data and+12.0'correction. Make up 2 7/8"CIBP and RIH. Correct depth at flag to 9712.7'mid element of CIBP. CIBP set at 9770'mid element due to collar location,sheared at 3250 psi.Tag plug to confirm and POOH. Standby for Cementers and fluids. Perform 7 day BOP Test-Top Blind Shear Failed-Rest of BOP Test good , SCE discovered equalizing port leak, repaired. Re-test Full Body and Upper Blind Shear. BOP Test complete, Make up Cementing BHA with 2.0"BD-JSN with down jets, RIH.Cementers on location and begin riging up. 9/24/2013 ...Continued on WSR 9-25-13... Daily Report of Well Operations ADL0028282 CTU#3-1.75"Coil ***Continued from WSR 9-23-13*** Job Objective:GSO with Organoseal/Squeezecrete POOH with GR/CCL for tie in log. Confirm good data and+12.0'correction. Make up 2 7/8"CIBP and RIH.Correct depth at flag to 9712.7'mid element of CIBP.CIBP set at 9770'mid element due to collar location, sheared at 3250 psi.Tag plug to confirm and POOH. Standby for Cementers and fluids. Perform 7 day BOP Test-Top Blind Shear Failed-Rest of BOP Test good , SCE discovered equalizing port leak, repaired. Re-test Full Body and Upper Blind Shear. BOP Test complete, Make up Cementing BHA with 2.0"BD-JSN with down jets, RIH. Cementers on location and begin riging up. 9/24/2013 ...Continued on WSR 9-25-13... CTU#3-1.75"Coil ***Continued from WSR 9-23-13*** Job Objective:GSO with Organoseal/Squeezecrete RIH with cementing BHA with 2.0"BD-JSN with down jets. Cementers finished rigging up and primed pumps. Clean drift down to CIBP. Swapped coil over to diesel and pulled up to 8460'(10 bbls above liner top). Cementers pumped down the backside: 10 bbl FW, 92.5 bbl Organoseal, followed by 10 bbl FW. Pumped 5 bbl meth spear,followed by 98.5 bbl diesel to place leading edge of FW at liner top. Circulated 5 bbls 50/50 meth spear,20 bbls Freshwater to nozzle. Getting 1:1 returns. Close choke, Jet organoseal from liner top to CBP at 9760'ctm. Pull back up to 9050' ctm when Squeezecrete is exiting nozzle. Bull head 28.6 bbls of squeezecrete behind pipe. Hesitated for 2 hours. Injection was.5bpm at 250#, Discuss with CT scheduler, and the Well Intervention Engineer. Decide to push remaining 2.6 bbls Squeezecrete away. Flushed liner with 1%KCL to CIBP. Layed 1.25 ppg Powervis from CIBP to 8645' Pull out of hole while pumping 50/50 to replace pipe displacement. 9/25/2013 ***Job complete*** CTU#3-1.75"Coil ***Continued from WSR 9-23-13*** Job Objective:GSO with Organoseal/Squeezecrete RIH with cementing BHA with 2.0"BD-JSN with down jets. Cementers finished rigging up and primed pumps.Clean drift down to CIBP. Swapped coil over to diesel and pulled up to 8460'(10 bbls above liner top). Cementers pumped down the backside: 10 bbl FW,92.5 bbl Organoseal, followed by 10 bbl FW. Pumped 5 bbl meth spear,followed by 98.5 bbl diesel to place leading edge of FW at liner top. 9/25/2013 ....Job in Progress.... T/I/O=0/646/290 Temp=S/I (MITx T to1500 psi Failed/Post OrganoSeal/Squeeze Crete)Rig to TBG. Pump 34 bbls neat meth down TBG. Could not catch pressure. (LLR of 4.5 bpm) Bleed TBG presswure to 0 psi. RDMO/FWHP=0/500/300 Wing=shut/Swab=shut/SSV=shut/Master= 9/30/2013 open/IA and OA open to gauges. Operator notified of departure. T/I/0=180/700/290 Temp=SI Assist Schlumberger Pump crew(Organoseal Treatment) Pumped 10 bbls neat methanol, 11 bbls 60/40 methanol& 120 bbls diesel down Tbg to assist Schlumberger Pump crew. Pumped 3 bbls diesel down hardline to open top tank to freeze protect. 11/25/2013 FWHP's=800/120/320 Schlumberger in control of well upon departure. ***Fullbore OrganoSEAL Treament***Initial T/I/O=25/700/300. Mix and pump OrganoSEAL treatment on previously OrganoSEAL/Squeezecrete perfs above bridge plug set at 9770'MD. Loaded well with 10 bbls Neat Meth Spear,215 bbls of 1% KCI, 5 bbls 60/40 Meth, 10 bbls Fresh Water,210 bbls of OrganoSEAL,displacement consist 10 bbls Fresh Water, 5 bbls 60/40,and 120 bbls Diesel. Samples of OrganoSEAL were obtained and sent to SLB lab for observation. Final 11/25/2013 T/I/O= 1230/81/325.SV,WV, SSV=C. MV=0. IA,OA, =OTG. ****WELL S/I ON ARRIVAL****(profile modification) DRIFTED WITH 3.50"CENT,2-1/2"SAMPLE BAILER TO 8945'SLM(see log) ATTEMPTED MIT-T TO 1500psi, ESTABLISHED LLR OF 1 GALLON PER MIN @ 1000psi 11/28/2013 ****WELL LEFT S/I ON DEPARTURE**** T/I/0=129/661/311,Temp=S/I, MIT-T to 1500 psi(Post Organoseal) Pumped 10 bbls diesel, could not reach test pressure. At 1 pbm pressure reached 1219 psi then started falling off. PE confirmed 11/29/2013 not to get LLR over 1 bpm. FWHP 175/609/266 SV,WV,SSV=closed, MV=open, IA and OA=OTG 2/10/2014 LRS 46 heat diesel in transport to 90*for CTU. CTU#9 w/1.75"CT(CTV=33.5) Job Objective: Clean out Organoseal and pump SqueezeCRETE MIRU. 2/10/2014 *** Job Continued *** CTU#9 w/1.75"CT(CTV=33.5) Job Objective: Clean out Organoseal and pump SqueezeCRETE Travel from DS11 and rig up. Make up cementing BHA w/2"Crayola BDJSN and start RIH. 2/10/2014 *** Job Continued *** Daily Report of Well Operations ADL0028282 CTU#9 w/1.75"CT(CTV=33.5) Job Objective: Clean out Organoseal and pump SqueezeCRETE Travel from DS11 and rig up. Make up cementing BHA w/2"Crayola BDJSN and start RIH. 2/10/2014 *** Job Continued *** CTU#9 w/1.75"CT(CTV=33.3 bbls) Job Objective: Clean out Organoseal and pump SqueezeCRETE Continue RIH to 8900'w/cementing BHA w/2"Crayola BDJSN. Tagged plug @ 9746'ctm. PUH and painted flag @ 9735'e/9703'm. Circulate around warm 1%KCI to clean out Organoseal and warm wellbore. Redisplace well with warm diesel. Perform injectivity test w/FW at 1.0/1100 psi. Bullhead 35 bbls of Squeezecrete cement from 9050'and got 500 psi bump to 1600 psi after cement covered perfs. Layed in the rest getting 1/1 until almost at safety when pressure broke back to 1400 psi and kept falling. Waited for 2 hrs watching it fall to 374 psi. Worked it up in stages to 1400 psi where it broke back again. Got to 900 psi and called it good. Diluted w/PV to 9150'holding 300 psi on choke and CBU to get most of cement back and lower the HP. RBIH contaminating cement to plug(tagged @ 9725'down). PUH at 80%cleaning out cement to surface and washing over jewelry. RBIH to FP to 2500'. 2/11/2014 *** Job Continued *** CTU#9 w/1.75"CT(CTV=33.3 bbls) Job Objective:Clean out Organoseal and pump SqueezeCRETE Continue RIH to 8900'w/cementing BHA w/2"Crayola BDJSN. Tagged plug @ 9746'ctm. PUH and painted flag @ 9735'e/9703'm. Circulate around warm 1%KCI to clean out Organoseal and warm wellbore. Redisplace well with warm diesel and perform injectivity test. 2/11/2014 *** Job Continued *** CTU#9 w/1.75"CT(CTV=33.3 bbls) Job Objective: Clean out Organoseal and pump SqueezeCRETE Continue RIH to 8900'w/cementing BHA w/2"Crayola BDJSN. Tagged plug @ 9746'ctm. PUH and painted flag©9735'e/9703'm. Circulate around warm 1%KCI to clean out Organoseal and warm wellbore. Redisplace well with warm diesel. Perform injectivity test w/FW at 1.0/1100 psi. Bullhead 35 bbls of Squeezecrete cement from 9050'and got 500 psi bump to 1600 psi after cement covered perfs. Layed in the rest getting 1/1 until almost at safety when pressure broke back to 1400 psi and kept falling. Waited for 2 hrs watching it fall to 374 psi. Worked it up in stages to 1400 psi where it broke back again. Got to 900 psi and called it good. Diluted w/PV to 9150'holding 300 psi on choke and CBU to get most of cement back and lower the HP. 2/11/2014 *** Job Continued *** CTU#9 w/1.75"CT(CTV=33.3 bbls) Job Objective: Clean out Organoseal and pump SqueezeCRETE FP well with 60/40 to 2500'. Left 500 psi WHP on the well. RDMO to 07-02. 2/12/2014 *** Job Complete *** CTU#9 w/1.75"CT(CTV=33.3 bbls) Job Objective:Clean out Organoseal and pump SqueezeCRETE FP well with 60/40 to 2500'. Left 500 psi WHP on the well. RDMO to 07-02. 2/12/2014 *** Job Complete "— CTU#9 w/1.75"CT(CTV=33.3 bbls) Job Objective: Clean out Organoseal and pump SqueezeCRETE FP well with 60/40 to 2500'. Left 500 psi WHP on the well. RDMO to 07-02. 2/12/2014 *** Job Complete *** T/I/O=0/10/300 Temp=SI MIT-T to 1500 psi ***PASSED*** (Profile Modification) Pumped 1 bbl of diesel to pressure TBG up to 1500 psi, 15 min Tbg lost 88 psi, 30 min Tbg lost 31 psi for a total of 119 psi on 2nd test. bled back—.5 bbl of diesel. Pad op notified of well status per LRS departure 2/14/2014 WV,SV,SSV=Closed MV=Open IA/OA=OTG T/I/O=SSV/0/300. Temp=SI. OA FL Campaign. AL SI©casing valve,ALP=300 psi. OA FL near surface. 2/17/2014 SV,WV, SSV=C. MV=O. IA,OA=OTG. 1125. CTU 3 w/1.75"0.134"wall CT-32.9 bbl Vol Job Scope: Mill CIBP 3/3/2014 ***Job Still in Progress*** CTU 3 w/1.75"0.134"wall CT-32.9 bbl Vol Job Scope: Mill CIBP MIRU-MU BHA to mill CIBP- Tag high/stringers @ 9660'. Mill to 9742'with 1 stall. Dry tag @ 9737'. FP coil POOH for safety standdown. Cap well with 20.5 bbl meth/wtr. Stand tools on back deck and secure well for SWS safety standdown. 3/3/2014 ***Job Still in Progress**' Daily Report of Well Operations ADL0028282 CTU 3 w/1.75"0.134"wall CT-32.9 bbl Vol Job Scope: Mill CIBP MIRU-MU BHA to mill CIBP- 3/3/2014 """Job Still in Progress""" CTU 3 w/1.75"0.134"wall CT-32.9 bbl Vol Job Scope: Mill CIBP MIRU-MU BHA to mill CIBP- Tag high/stringers @ 9660'. Mill to 9742'with 1 stall. Dry tag© 9737'. FP coil POOH for safety standdown. Cap well with 20.5 bbl meth/wtr. Stand tools on back deck and secure well for SWS safety standdown. RU on WH. 3/3/2014 """Job Continued on WSR 3-4-14""" CTU 3w/1.75"0.134"wall CT-32.9bbl Vol Job Scope: Mill CIBP RU to RIH to Mill-Gas Monitor Not working-Waiting to fix Gas Monitor(SCE) 3/4/2014 """Job Still In Progress""" N-14B 208-080-0 Plugs Attachement SW Name Date MD Description N-14B 9/25/2013 9770 2-7/8" CIBP —I (p -0rrrrn C C 3 Z Z Z Z O 03730MMMMZ0 z7107:173Xu 0C C N m -I co 0 z IQ OD O) COOONO N A W wG77 N v � - N n N ,p • IQ • 4t X F CO co -3 c) c, v —I r = o N N co N - co NN IJ to CO O W N CO CO 03 �I �l C31 N > N 0 co N co Bs co co co O) N A A O CSO A v co O CD OD OD OD --1 rh (3) A W A N N N OD OD O) �l co co N CO OD CT Cp O W N CJ1 A W (3) CO N -.1 00 OD OD OD A (3) O) O) (3) O) N J CO o1 co -` co co OD O -.1 N v O CO CO COAcnOCnCO CO CJl N W N W OAO) 01OD v w ACO CO 0, C 0 0 0 0) 0 0 0 N A -s J CT C CT O) -.1 CJI 0.1 A O O O W O C') O CJl O co Packers and SSV's Attachment ADL0028282 SW Name Type MD ND Depscription N-14B PACKER 8091 7391.09 7" Baker HMC Packer N-14B PACKER 9058 8253.16 4-1/2" Baker S-3 Hydro Set Packer N-14B PACKER 9237 8414.87 5" Baker ZXP Top Packer • Perforation Attachment ADL0028282 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TW Depth Base N-14B 2/11/2014 SQZ 9640 9665 8849.43 8865.74 N-14B 9/24/2013 _ BPS 9940 9950 8874.75 8870.44 N-14B 9/24/2013 _ BPS 9965 _ 9995 8863.67 8848.85 N-14B 9/24/2013 BPS 10006 10026 8842.99 8831.79 MEE ELL CNVV1�L4-1/16"CN —I B � FEAD- FMC A S .Y NOTES: ""'4-1/2"CHROME TBG""WELL ANGLE>70°(tD 9727'. ACTUATOR= BAKER C OKB.R.EV= 78.6T - - BF.aEV= -- 45 07' ' ' 2012' —14-1/7 HES NP,D=3.813" KOP= 3196' Max Angle= 131°@ 10776' / 2593' H9-5/8"DV PKR Datum MD= 9679' ...... = GAS LFT MANDRELS Datum TVD= 8800'SS , ST MD I VI) DEV TY PE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTS,D=12.347' — 2678' I)I 6 3286 3282 13 MAG DMY RK ir 0 01/09/10 5 4028 3977 26 Mv+G DMY IRK r 0 09/13/13 4 5778 5508 34 MAG DMY RK r 0 09/13/13 4l 3 7317 6794 31 MAC DMY RK r 0 01/25/10 TOP OF 7"LNR — 8091' 2 8144 7512 29 KBG DMY BK r 0 09/06/08 "`���� 1 8969 8247 25 KBG DMY BK r 0 01/25/10 Minimum ID =2.14" @ 9420' LINER RESTRICTION 8091• H9-5/8"X 7'BKR ZXPPKR/HGR,D=6.331' 9-5/8"CSG,47#,L-80,ID=8.681" H I 8277' 9-5/8"MLLOUT WINDOW(N-14A) 827T-8293' M M 9036' —+4-1/2"HES NP,ID=3.813" Z9058' —17"X 4-1/2"BKR S-3 R(R,D=3.875" ■ I 9081' —14-1/2"HES NP,ID=3.813" H I 9115' H3-1/2"DEPLOY SLV,D=3.00' 4-1/2"TBG, 12.6#,13CR-80 VA M TOP, 9144' .0152 bpf,D=3.958" V 9159' H 7'X 4-1/2"BKR UNIQUE OVERSHOT 4-1/2"TUBING STUB(09/04/08) H 9140' , 9175' --I4-1/2"HES X NIP,D=3.813' BEHIND 9186' --17"X 4-1/2"BKR S-3 PKR D=3.875' LNR 9209' H 4-1/2"HES X NP,D=3.813" 4-1/2"TBG, 12.6#, L-80,.0152 bpf,ID=3.958' —1 9242' I , 9230' H4-1/2'HES XN NP,MILLED TO 3.80(09/11/08) TOP OF 4-1/2"LNR —{ 923T 9237' H7"X 5"BKR ZXP LTP w/HGR,ID=4.375' 9242' H4-1/2'WLEG, D=3.958' BEHIND 9263' —5"X 4-1/2"XO,D=3.958" LNR 7"LNR 26#,L-80 BUTT,.0383 bpf,D=6.276' H 9405' 3-1/2"LNR 9.2#,L-80 STL,.0087 bpf,I)=2.992" H 9417' 9417' 1—3-1/2"X 2-7/8"XO,ID=2.387" 4-1/2'WHPSTOCK(0X/XX/08) --1 9467' 9420' I--LNR RESTRICTION,ID=2.14"(CALIPER 05/17/13) 4-1/7 HES BKR CIBP(06/09/08) H 9500' 4-1/7 MLLOUT WINDOW(N-14B) 9467-9476' PERFORATION SUMMARY REF LOG SWS-MCNL/GR/CCL run 09/20/2008 9688' �—OVAL DEFORMATION,D=2.29' ANGLE AT TOP PERF. 470 @ 9640' ` (CALIPER 5/17/13) Note:Refer to Production DB for historical pert data `� .........--I9699'&9732'�—LNR HOLES(SQZ'D 2/11/14) SEE SPF INTERVAL Opn/Sqz SHOT SQL 7 6 9640-9665 S 09/21/08 02/11/14 I 9770' —�2-7/8'CBP(09/24/13) I i 2" 6 9940-9950 C: 09/21/08 ,/ Ni, 7 4 9965-9995 C 09/21/08 'j"j".�� ` PBTD — 10085' i i 2" 6 10006- 10026 C 07/01/10 2-7/8"LNR 6.4#,L-80 STL, — 10123' ,;��. 4-1/2"LNR 12.6#,L-80 BTC-M,.0152 bpf,ID=3.958" —{ 9959' .0058 bpf,ID=2.441" DATE REV BY_ COMVB'(TS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/26/81 INITIAL COMPLETION 09/17/13 SWC/JMD GLV C/0(09/13/13) WELL. N-14B 07/09/98 SIDETRACK COMPLETION 11/24/13 JLF/PJC CBPSET(09/24/13) PERMIT No 82080800 09/21/08 NORDIC2 RWO+CTD STRACK(N-14B) 02/20/14 TQ/PJC CMT SQZ(02/11/14) AR Na: 50-029-20594-02 02/03/10 RCT/PJC GLV C/0(01/25/10) 02/20/14 TQ/PJC RESTRICTIONS(5/17/13 CAUPER) SEC 8,T11N,R13E,1363'FSL&548'FWL 07/05/10 PBS/SV ADFEIF(07/01/10) 08/08/10 PJC FINAL ODE APPROVAL BP Exploration(Alaska) OPERABLE: Producer N -14B (PTD # 80800) OART Confirms OA Pressure enageable By ... Page 1,e€-2' Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] 61 1( )c/ei It Sent: Saturday, April 16, 2011 3:59 PM To: AK, D &C Well Integrity Coordinator; Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Phillips, Patti J Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C) Subject: OPERABLE: Producer N -14B (PTD #2080800) OART Confirms OA Pressure Manageable By Bleeds All, Producer N -14B (PTD #2080800) passed an OA repressurization test conducted between 4/10 - 4/15. The OA pressure increased —10 psi per /day making it manageable by bleeds. The well has been reclassified as Operable and may continue on production. Please call if you have any questions. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 p,pR 0 01 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Friday, April 08, 2011 1:46 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 d O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D: ireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB Eas ' ells Opt Engr; Phillips, Patti J Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany Subject: UNDER EVALUATION: Producer N -14B (PTD #2080800) Sustained Casing OA Pr- sure Over MOASP All, Producer N -14B (PTD #2080800) has been found to have stained OA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 350 40/1040 psi on 4/6/2011. The well has been reclassified as Under Evaluation. The well may remai r online while work is conducted to attempt to confirm integrity. Plan forward: 1. DHD: Outer Annulus Repressurization -st (OART) 2. Wellhead: PPPOT -IC A TIO plot and wellbore schematic/have been included for reference. r Please call if you have an questions or concerns. 4/18/2011 UNDER EVALUATION: Producer N14 (PTD #2080800) Sustained Casing • Pressure Over... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWelIIntegrityCoordinator @bp.com] Sent: Friday, April 08, 2011 1:46 PM ' l j 4-1811( To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS 3C2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Phillips, Patti J Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany Subject: UNDER EVALUATION: Producer N -14B (PTD #2080800) Sustained Casing OA Pressure Over MOASP Attachments: Producer N -14B (PTD #2080800) TIO Plot.doc; Producer N -14B (PTD #2080800) wellbore schematic.pdf All, Producer N -14B (PTD #2080800) has been found to have sustained OA casing pressure above MOASP. The wellhead pressures were tubing /IA/OA equal to 350/1740/1040 psi on 4/6/2011. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to confirm integrity. Plan forward: 1. DHD: Outer Annulus Repressurization Test (DART) i 2. Wellhead: PPPOT -IC A TIO plot and wellbore schematic have been included for reference. «Producer N -14B (PTD #2080800) TIO Plot.doc» «Producer N -14B (PTD #2080800) wellbore schematic.pdf» Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 4/8/2011 PBU N -14B PTD #2080800 4/8/2011 TIO Pressures Plot Well: N - 14 4,i 000 • ,.000 Tbg —I IA 2,000 00A / 111\:........1F-OillM -�- 000A On V i l owed.644.1.4c A- 4 . 644, - , Le ar " S"*""1"4"dek 1,000 • 0111 5/11 01129/11 02/12111 02129111 03112111 03/28111 TREE = 6" CM/ - /� 4 WELLHEAD = FMC SAFETY OES: * ** 4-1/2" CHROME TBG* ** ACTUATOR OTIS KB ELEV = 74.47° BF. ELEV = 45.07° ` 2012' I- 14-1/2" HES NIP, ID = 3.813" KOP = _ 3196' Max Angle 35 @ 5896' 2593' H 9 -5/8" DV PKR Datum MD = 9660' GAS LIFT MANDRELS Datum TVD = 8800' SS ® ST MD TV D DEV TYPE VLV LATCH PORT DATE 13 -3/8" CSG, 72 #, L -80 BTS, ID = 12.347" I 2678' 6 3286 3282 13 MMG DMY RK ® 0 01/09/10 5 4028 3977 26 MMG DOME RK 7. 16 01/25/10 4 5778 5508 34 MMG SO RK ' 24 01/25/10 3 7317 6794 31 MMG DMY RK ' 0 01/25/10 TOP OF 7" LNR I-f 8091' 2 8144 7512 29 KBG DMY BK ' 0 09/06/08 1 8969 8247 _ 25 KBG DMY BK _ 0 01/25/10 Minimum ID = 3.725" @ 9230' 4 -1/2" HES XN NIPPLE 091' H9 -5/8" X 7" BKRZXPPKR/HGR, ID= 6.331" 1 9 -5 /8" CSG, 47 #, L -80, ID = 8.681" H 8277' 9 -5/8" MILLOUT WINDOW (N -14A) 8277' - 8293' I I 1 9036' 1- 14 -1/2" HES NIP, ID = 3.813" 1 Ci g- 9058' H7" X 4-1/2" BKR S -3 PKR, ID = 3.875" I i ( 9081' I- I4 -1/2" HES NIP, ID = 3.813" I 9115' H3 -1/2 DEPLOY SLEEVE, ID= 3.00" I � 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, -) 9144' � .0152 bpf, ID = 3.958" 9159' (-� 7" X 4-1/2" BKR UNIQUE OVERSHOT , 1 9175' J-14 -1/2" HES X NIP, ID= 3.813" I BEHIND 4-1/2" TUBING STUB (09(04/08) H 9140' ,-, 9186' H7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" I LNR ■ 9209' 1- -I4 -1/2" HES X NIP, ID = 3.813" I ' 9230' 1-14-1/2" HES XN NIP, MILLED TO 3.80 (0911/08) I 4-1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" 1-± 9242' I I ( 9237' 1-17" X 5" BKR ZXP LTP w / HGR, ID = 4.375" 1 9242' H4 -1/2" WLEG, ID = 3.958" 1 BEHIND 17" LNR, 26 #, L -80 BUTT, .0383 bpf, ID = 6.276" H 9405' 9263' H5- X 4 -1/2" XO, ID = 3.958" I LNR I3 -1/2" LNR, 9.2 #, L -80 STL, .0087 bpf, ID = 2.992" H 9417' 1- - . I I 9417' 1-13-1/2" X 2 -7/8" XO, ID = 2.387" I 14-1/2" WHIPSTOCK (0 / /08) H 9467' 4 -1/2" MILLOUT WINDOW (N -14B) 9467' -9476' 4 -1/2" HES BKR CIBP (06/09/08) H 9500' PERFORATION SUMMARY ` REF LOG: SWS- MCNL/GR/CCL run 09/20/2008 ' ANGLE AT TOP PERF: 47° @ 9640' I Note: Refer to Production DB for historical perf data I 41111 SIZE SPF INTERVAL Opn/Sqz DATE vivilvv., 4414% 1 PBTD I 10085' 2" 6 9640 - 9665 0 09/21/08 . A , 2" 6 9940 - 9950 O 09/21/08 2" 4 9965 - 9995 O 09/21/08 2 -7/8" LNR, 6.4 #, L -80 STL, -1 10123' ` * . M 2" 6 10006 - 10026 0 07/01/10 .0058 bpf, ID = 2.441" 4' DATE REV BY COMMENTS 1 DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/26/81 ORIGINAL COMPLETION 01/04/11 JKC/PJC FINAL DRLG CORRECTIONS WELL: N -148 07/09/98 SIDETRACK COM PLETION 01/12/11 PJP /PJC MILLOUT WINDOW UPDATE PERIM No: '1972110 09/21/08 NORDIC2 RWO + CTD SIDETRACK (N -14B) API No: 50- 029 - 20594 -01 -02 02/03/10 RCT /PJC GLV C/O (01/25/10) SEC 8, T11 N, R13E, 3917' SNL & 4731' WEL 07/05/10 PBS /SV ADPERF (07/01/10) 08/08/10 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) OPERABLE: Producer N-148(PTD #0800) Stable OAP • Page 1 of 2 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] 7 /~~-I/~ Sent: Sunday, July 11, 2010 7:54 PM ~~~ To: AK, D&C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, OPS Well Pad MN Cc: King, Whitney Subject: OPERABLE: Producer N-14~PTD #2080800) Stable OAP All, Producer N-14~PTD #2080800) OAP was bled from 670 to 60 psi 7/5/10 and has stabilized 100 psi for 5 des. The initial high OAP appears to be a thermal event from the well being brough ack on line. The well Is reclassified to Operable. No further action is planned at this time. Please let us know if you have any questions or concerns. Thank you, Tiffany Quy (for the Well Integrity Coordinator Gerald Murphy/Torin Roschinger) Projects Well Integrity Engineer phone: (907) 659-5102 P~~N~~~ ~~~ ~ r~ ~a~~i cell: (253) 576-6153 tiffg0@bp.com From: AK, D&C Well Integrity Coordinator Sent: Monday, July 05, 2010 10:42 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; "Schwartz, Guy (DOA'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field 0&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Well Integrity Coordinator; AK, OPS Well Pad MN Cc: Janowski, Carrie; King, Whitney; Quy, Tiffany Subject: UNDER EVALUATION: Producer N-14 (PTD #2080800) Confirmed Pressure Above MOASP All, Producer N-14 (PTD #2080800) has confirmed sustained in ressure above MOASP. The wellhead pressures were tubing/IA/OA equa to 200/105Q/1200 psi on 07/03/2010. The well is reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. DHD: Outer annulus repressurization test 2. Wellhead: PPPOT-IC (pending DART results) 3. Fullbore pumping: MITOA (pending DART results) A TIO plot and schematic have been included for reference. File: Producer N-14 7-5-2010 TIO Plot.doc » « File: Producer N-14B (PTD #2080800) schematic.pdf» 7/15/2010 OPERABLE: Producer N-14 (PTD #0800) Stable OAP • Page 2 of 2 Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 7/15/2010 PBU N-14B PTD # 2080800 7/5/2010 TIO Pressures Plot. 4,000 4~fe11: N-14 ~,aoo 2,000 1,o0a -~- Tbg ~- IA ~- OA OOA -•~- OOOA On 04'10110 04124110 05108!10 05122110 06105110 06119110 07100110 TREE = 4-1116" 'WELLHEAD = FMC ..ACTUATOR= OTIS KB. ELEV = 74.47 BF. ELEV = 45.0T KOP = 3196' Max Angle = 130 c~r7 R 3.076' Datum MD = Datum TV D = 9660' 8800' SS e i 13-318" CSG, 72#, L-80, ID = 12.347" IC1ppi++zf,,YY1rr'~EI;~a1ga~T1 //pp~~pp4= a~~) ~" I ~~' °id~a ~9 /'~ °1~d98 aa/ PERFORATION SUMMARY REF LOG: SWS-MCNL/GR/CCL run 09/20/ 2008 ANGLE AT TOP PERF: 46 @ 9640' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2" 6 9640 - 9665 O 09/21/08 2" 6 9940 - 9950 O 09(21!08 2" 4 9965 - 9995 O 09!21/08 2" 6 10006 - 10026 O 07!01/10 TOP OF 7" LNR $091' S ES:*** Oh~cante Tubing *** 4-1i2'" HES SSSV NIP, ID = 3.813" C;A.r, I IFT MANDREI S ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3286 3282 13 MMG DMY RK 0 01!09110 5 4028 3977 26 MMG DOME RK 16 01/25/10 4 5778 5508 34 MMG SO RK 24 01(25!10 3 7317 6794 31 MMG DMY RK 0 01!25/10 2 8144 7512 29 KBG DMY BK 0 09106108 1 8969 8247 25 KBG DMY BK 0 01/25/10 $Og~' ~-) 9-5/8" X 7" BKR ZXP PKR/HGR, ID = 6.331" ~TOPOFWHIPSTOCK ~ 8277' 9-5l8" CSG, 47#, L-80, ID = 8.681" $277' ~"" MILLOUT WINDOW 8277 - 8293' ~ 8037° 4-112" HES X NIP, ID = 3.813" ! g057' 7" X 4-1!2" BKR 9Cr PKR, ID = 3.875„ ~ g081' 4-112" HES X NiP, ID = 3.813" 4' ' E g1 ~ 5' TOP 3-1l2" x 2-7;`8" LNR. ID = 2.992" 91$6' 7" X 4-112" BKR S-3 PKR, ID = 3.875" i ~ 9209' 4-1(2" HES X NIP, ID = 3.813" " ' i ' g23p' 4-1/2" HES XN NIP, ID = 3.75" 4-1'2" TBG: 12.6#: 13Cr, .0152 bpf, 1D = 3.958 915$ 9242' 4-1/2" WLEG, ID = 3.958" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9242' 9247' ELMD TT LOGGED 07/08/98 g237' 7" X 5" BKR ZXP PKR HGR, 1D = 4.375" 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9405' 4 1;2" rr3onabare vu hipstc~ck 84,8,7' ~~ 946` 3-1t2" x 2-718" XO, ID = 2.441" ~ FisTD 104$5' 4 1/2" CIBP --~~ 9500' ~ ~ ~ ~ , ~~.._ .,,_ PBTD 9875' _ - 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 9959' 3-1i2" 13Gr x 2-7%8" 13Cr Liner, Cen~nted & Perf'~ 10123' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/26!81 ORIGINAL COMPLETION 02/03/10 JLJ(PJC GLV C/O (01/09/10) 07!09198 SIDETRAGKCOMPLEf1ON 02/03/10 RCTiPJC GLV G/O(01l25/10) 09/21/08 NORDIC2 RWO + CTD SIDETRACK (N-14B 07/05/10 PBS/SV ADPERF (07101/10} 09/08108 DTRlTLH GLV ClO (ON RIG} 09/28/08 TLH CORRECTIONS 10/17!08 DAVlPJC GLV C/O (10/1/08} PRUDHOE BAY UNIT WELL: N-14B PERMIT No: 1972110 API No: 50-029-20594-01-02 SEC 8, T11 N, R13E, 391 T SNL & 4731' WEL BP Exploration (Alaska} STATE OF ALASKA " ALASKA AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Pertormed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate Q Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ^ 208-0800 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-20594-02-00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028282 PBU N-14B 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10123 feet Plugs (measured) None feet true vertical 8770.42 feet Junk (measured) None feet Effective Depth measured 10085 feet Packer (measured) 8091 9057 9186 true vertical 8795.23 feet (true vertical) 7466 8327 8443 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface 2678 13-3/8" 72# L-80 SURFACE - 2678 SURFACE - 2678 4930 2670 Production 8277 9-5/8" 47# L-80 SURFACE - 8277 SURFACE - 7629 6870 4760 Liner 1315 7" 26# L-80 8091 - 9406 7466 - 8642 7240 5410 Liner 230 4-1/2" 12.6# L-80 9237 - 9467 8489 - 8698 8430 7500 Liner 1007 3-1/2"X2-7/8" 9116 - 10123 8380 - 8770 9.2#/6.4# L-80 Perforation depth: Measured depth: O 9640 - 9665 O 9940 - 9950 O 9965 - 9995 O 10006 - 10026 True Vertical depth: 8849.43 - 8865.74 8874.75 - 8870.44 8863.67 - 8848.85 8843 - 8834 Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR SURFACE - 9159 SURFACE -8419 4-1 /2" 12.6# L-80 9159 - 9242 8419 -8494 Packers and SSSV (type, measured and true vertical depth) 9-5/8" X 7" BKR ZXP PKR 8091 7466 7"X4-1/2" BKR 9CRPKR--- 9057 8327 7"X4-1/2" BKR S-3 PKR 9186 8443 7"X5" BKR ZXP PKR 9237 8489 12. Stimulation or cement squeeze summary: Intervals treated (measured): (~ ~y (~ q Treatment descriptions including volumes used and final pressure +~. - s teaks qii $t 6ae Cap" ~priltnission 13. Representative Daily Average Production or Injection D~0 OrAQB Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 245 4561 5493 264 Subsequent to operation: 264 5419 6277 229 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil r Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pr ble Title Data Management Engineer Signature Phone 564-4944 Date 7/9/2010 Form 1 ~ . suu~v~~7 JUL 1 ~ [UNl ~~ ~,~-7_ZS-/o • • N-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/30/2010 i CTU #9 w/ 1.75" CT: Job Scope: MCNL / Pertorate: MIRU coiled tubing unit. ' MU and RIH with SLB memory compensated neutron logging tool. ***Continued ion 01 July 10*"* ~ I ~CTU #9 w/ 1.75" CT: Job Scope: MCNL /Perforate: Continue RIH with logging ;tools. Log two up /down passes from 10069' to 9550' while pumping 1 bpm. Download data and correlate coil flag to Baker Inteq Multiple Propagation j Resistivity / GR log dated Sept 14 - 18 2008. Perforate interval 10006' to 10026' corr with 2" Gun, PJ2006 charges loaded 6 spf. Freeze protect well to 2500' with 50/50 McOH. RDMO. ""*Job Complete**" FLUIDS PUMPED BBLS 18 MEOH 321 KCL W/SL 339 Total TREE _ ~ 4-1116" WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 74.47' BF. ELEV = 45.07' KOP = 3196' Max Angle = 130 @ 10,076' Datum MD = 9660' Datum ND = 8800' SS ~~~ FT N -14 B 13-318" CSG, 72#, L-80, ID = 12.347" ~ 2678' P1~inimum ID = 2.441" @ 941T 3-112"' X 2-7/8" XC} PERFORATION SUMMARY .REF LOG: SWS-MCNL/GR/CCL run 09/20/2008 ANGLE AT TOP PERF: 46 @ 9640' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9640 - 9665 O 09121 /08 2" 6 9940 - 9950 O 09121 /08 2" 4 9965 - 9995 O 09/21!08 2" 6 10006 - 10026 O 07/01/10 TOP OF 7" LNR ~-) $091 ` ~TOPOFWHIPSTOCK ( 8277 9-5/8" CSG, 47#, L-80, ID = 8.681" 8277' MILLOUT WINDOW 8277' - 8293' 4-1J2" TBG, 12.6#, 13Cr, .0152 bpf, ID = 3.958" ~-1 9158` 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9242' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ 9405' 4 1/2" monobore w hipstock 9467' 4 1/2" CIBP -9500' ~~ ~:: . ~•. ~_.. PBTD -~ 9875',,,,,,,,,,,,,, _ 4-112" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 9959' S ES:*** Chrome Tubing *** 2012` (-,14-112" HES SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 6 3286 3282 13 MMG DMY RK 0 01/09/10 5 4028 3977 26 MMG DOME RK 16 01/25/10 4 5778 5508 34 MMG SO RK 24 01/25/10 3 7317 6794 31 MMG DMY RK 0 01/25(10 2 8144 7512 29 KBG DMY BK 0 09/06108 1 8969 8247 25 KBG DMY BK 0 01!25110 8091' I--~ 9-518" X 7" BKR ZXP PKRJHGR, ID = 6.331" 9037' -~ 4-i12" HES X NIP, ID = 3.813" 9057' 7" X 4-112" BKR 9Cr PKR, 1D = 3.875" 9081' 4-112" HES X NIP; iD = 3.813" 9115' TOP 3-112" x 2-718" LNR, ID = 2.992" 9186` -°-- ~- 7 X 4i 11®BKR S-3 PKR, ID = 3.875" 9209` llll u~ 4-112" HES X NIP, ID = 3.813" 9230' 4-1 /2" HES XN NIP, ID = 3.75"' 9242' 4-1/2"WLEG, ID=3.958" 9247' ELMD TT LOGGED 07/08/98 923T 7" X 5" BKR ZXP PKR ,HGR, ID = 4.375" 9416` 3-1/2" x 2-718" XO, ID = 2.441" PBTD 1 oa85' 3-1/2" 13Cr x 2-718" 13Cr Liner, Cemented & Perf'd ~-~ 10123' DATE REV BY COMMENTS DATE REV BY COMMEMS 07/26/81 ORIGINAL COMPLETION 02/03/10 JLJlPJC GLV Cl0 (01109/10} 07/09/98 SIDETRACK COM PLEI'ION 02/03/10 RGT/PJC GLV CJO (01125/10} 09/21108 NORDIC2 RWO + CTD SIDETRACK (N-14B 07/05/10 PBS/SV ADPERF (07/01!10) 09/08/08 DTR/TLH GLV C/O (ON RIG) 09/28/08 TLH CORRECTIONS 10/17/08 DAV/PJC GLV C/O (10/1/08} PRUDHOE BAY UNIT WELL: r 146 ~Q~_a API No: 50-029-20594-01-02 SEC 8, T11 N, R13E, 3917' SNL & 4731' WEL BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 2/11/2010 Permit to Drill 2080800 Well Name/No. PRUDHOE BAY UNIT N-146 Operator BP EXPLORATION (ALAStCIy INC API No. 50-029-20594-02-00 MD 10123 TVD 8770 Completion Date 9/22/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other logs Run: MWD, DIR, GR, RES, 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 Asc Directional Survey Directional Survey D Asc Directional Survey irectional Survey D C Lis •• // 17245~Neutron Neutron C Las 1747~nduction/Resistivity C Las 17471~duction/Resistivity LIS Verification C Lis 17539~nduction/Resistivity Induction/Resistivity 1 nduction/Resistivity Gamma Ray LIS Verification 9456 10123 Open 11/14/2008 9456 10123 Open 11/14/2008 9456 9619 Open 11/14/2008 PB 1 9456 9619 Open 11/14/2008 PB 1 8725 9991 Case 12/10/2008 LIS Veri, GR CNT 2 Blu 8742 9998 Case 12/10/2008 MCNL, Mem Lee, CCL, GR, CNL 20-Sep-2008 9467 11012 Open RPM, GR< RAD, RAM, ROP, RPD 9445 9619 Open P61 RPM, GR, RAD, RAM, ROP, RPD 9462 10117 Open 1/28/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 9462 10117 Open 1/28/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS 25 Col 9467 10123 Open 1/28/2009 MD MPR, GR 18-Sep-2009 25 Col 9467 10123 Open 1/28/2009 TVD GR 18-Sep-2009 5 Col 9460 10010 Open 1/28/2009 Depth Shift Monitor Plot 9446 9619 Open 2/12/2009 P61 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS -~J DATA SUBMITTAL COMPLIANCE REPORT 2/11/2010 Permit to Drill 2080800 Well Name/No. PRUDHOE BAY UNIT N-146 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-20594-02-00 MD 10123 ND 8770 Completion Date 9/22/2008 Completion Status 1-OIL Current Status 1-OIL UIC N ~C Lis 17576~'Induction/Resistivity 9446 9619 Open 2/12/2009 PB1 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 9467 9619 Open 2/12/2009 PB1 MD MPR, GR 14-Sep- 2009 ~g __ _ _ G ~ _ 25 Col 9467 9619 Open 2/12/2009 P61 MD GR 14-Sep-2009 ff J Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Daily History Received? V N Chips Received? ~'-t'1~( Formation Tops ~/ N Analysis `t`t'N- Received? Comments: Compliance Reviewed By: _~ __ Date: __~_~l ~;~~L l s INTEQ Log & Data Transmittal Form To: State of Alaska -A®GCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: N-14BPB1 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 - GR Directional TVD Log (to follow) LAC Job#: 2165765 Sent by: Terri Tumine o Date: 02/09/2009 _* % i Received by: ~ Date: ~. ~ •~ _ ` l~ ~ ~-' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & R~~1113~1ING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~~~ ~ ~~d ~~~ 7260 Homer Drive ~ J- ~tO B~ Anchorage, Alaska 99518 Direct: (907) 267-6612 YNT~'.Q FAX: (907) 267-6623 ~ ~ CUMYANY WELL NAME ,, Mu~~s Baker Atlas PRINT DISTRIBUTION LIST BY EXYLURA'I'IUN (ALASKA) INC C;UUN'1'Y NUR1'H SLUYE BUKUU(iH N-14BPB1 STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 2/9/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Tem Tuminelio SO #:2165765 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 -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LRZ-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~~C~ ~~ Page 1 of 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7t" Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: N-14B '~ Contains the following: '~ 1 LDWG Compact Disc ~'I ~ (Includes Graphic Image files) ~ 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) .a 1 color print - GR Directional TVD Log (to follow) LAC Job#: 2165765 Sent by: Terri Tuminell Date: 01/28/09 Received by: _- Date ~, PLEASE ACKNOWLEDGE RECEIPT B; ~ ~ N RNING OR FAXING YOUR COPY°~ -~ -° FAX: (907) 267-6623 Baker Hughes INTEQ ~~~0~~ ~~% 7260 Homer Drive ~ Anchorage, Alaska 99518 1 ~~~~ Direct: (907) 267-6612 INTEQ FAX: (907) 267-6623 ~~~~ BAKER NYtsNES Baker Atlas PRINT DISTRIBUTION LIST CUMYANY BY EXYLURA'1'lUN (ALASKA) INC CUUN 1'Y NUR'1'H SLUYE BURUUGH WELL NAME N-14B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 1/28/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Tuminello SO #:2165765 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-i 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: ~p~~~ Page 1 of 1 • - Date 12-12-2008 Transmittal Number:93025 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 ~~- Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 01-21 A t 18-24B N-14B N-14BP61 Y-05BP61 Y-09AL1 Y-09AL1-01 ~ - ,l i ~; Please sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~~~"_- iii i ~~!'-- ~~4-1~1~~ i~~i~- f ~~`S=a~G t _~~-i~- ~ ~~.~~; ors ~. J r/ ~ -c ~ ~ ~ ~- ~~ ~- JL~~- ~~~ I~L~~~i Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 i 12/08/08 • ~` `_ Schiumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Jnh !k NO.4995 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1_nn nesr_rinfinn nafw RI Cnlnr en R-03A 4994 INJECTION PROFILE (REVISED) 10/08/08 1 1 13-23A 4994 INJECTION PROFILE 10/21/08 1 1 01-26A 4994 SCMT 11/13/08 1 1 D-29 4994 USIT 10/19!08 1 1 15-028 4994 MEM PROD PROFILE - 11/25/08 1 1 H-OSA 4994 MEM PROD & INJ PROFILE 11/20/08 1 1 E-32A 4994 SCMT ( 11/04/08 1 1 12-17 4994 PRODUCTION LOG Q C-/ 11/04/08 1 1 P2-41 4994 PRODUCTION LOG 11/07/08 1 1 1•-29/M-25 4994 PRODUCTION LOG (p - 11/04/08 1 1 MPC-OSA 4994 MEM LDL r 11/15/08 1 1 L-114A 4994 USIT ~- ~- ( ~ 11/03/08 1 1 A-07 4994 PRODUCTION PROFILE ~ - ( ~} 11/27/08 1 1 07-18 4994 INJECTION PROFILE ~ - - 12/02/08 1 1 15-126 4994 MEM PROD PROFILE ~ ~-- ~ 11/27/08 1 1 4-40/P-43 4994 _ MEM LDL (~j - ` - `~' .C;Y 11/26!08 1 1 N-146 4994 MCNL ~ ~ ' 09/20/08 1 1 01-21A 4994 MCNL 09/29/08 1 1 E-29A 4994 MCNL 09/01/08 1 1 • -.-r.v~ r+......v ..rrv.wr •.w~u . ~. .a.u.YUYU n1YV flGl Vlll\il\V VIYG l.Vr'i CN{.r rl 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 I ;_ ':~; Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 8 8 ATTN: Beth Received by: ~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: November 14, 2008 Please find enclosed directional survey data for the following wells: N-14BPB1 ~ N-14B ~ Ol-21A Y-09AL1 Y-09AL1-Ol Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" 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: ~ ~ Cc: State of Alaska, AOGCC ~c~~^o~o STATE OF ALASKA ~J~ ~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC 2s.,o5 zoAAC z5.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Ex loration (Alaska) Inc. 5. Date Comp., Susp., or Aban~d~,/ 9/22/2008 dui ~ 12. Permit to Drill Number 208-080 - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/14/2008 ' 13. API Number 50-029-20594-02-00 4a. Location of Well (Governmental Section): Surface: ' 7. Date T.D. Reached 9/18/2008 ' 14. Well Name and Number: PBU N-14B' FEL, SEC. 08, T11 N, R13E, UM 3917' FNL, 4731 Top of Productive Horizon: 1481' FNL, 3377' FEL, SEC. 08, T11 N, R13E, UM 8. KB (ft above MSL): 74.4T Ground (ft MSL): 43.5T 15. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Bay Total Depth: 1796' FNL, 3096' FEL, SEC. 08, T11 N, R13E, UM 9. Ptug Back Depth (MD+TVD) 10085' 8795' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 634410 y- 5967267 Zone- ASP4 10. Total Depth (MD+TVD) 10123' 8770' 16. Property Designation: ADL 028282 TPI: x- 635712 y- 5969727 Zone- ASP4 - 5969417 Zone- ASP4 l D th: x 636000 T t 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: - y o a ep 18. Directional Survey ®Yes ^ No bmit I r ni n rin d inf rm i r 2 AA 25. 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 20 C 25.071): MWD DIR, GR, RES, MCNL / GR / CCL J,//yDOS/ ~ 9'~6 ~ s i~D 1~~ 9z?S~yD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD f jOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SRE CEMENTING RECORD PULLED "x3" In I r rf 1 rf 11 nr 5/8" 47# rface 77' rfa 7 1 -1/4" 1 0 u 1 PF' ' 7" L-8 1' 74 8 -1 1 u I s' ~~ 1 I ~-,rr~ X za~s~ .4# -8 1 87 4-1 / " 7 I ' 23. Open to production or inject ion? ®Yes ^ No 24. TuewG RECORD If Yes, list each i MD+TVD f T 8 B tt P nterval open n Size and Number): rf r ti SIZE DEPTH SET MD PACKER SET MD op ~ o om; e o a o ( o 6 spf 2" Gun Diameter 4-1/2", 12.6#, 13Cr 9159' 9058' , MD TVD MD TVD 4-1/2", 12.6#, L-80 9159' - 9242' 9186' 9640' - 9665' 8849' - 8866' 9950' 8875' 8870' 9940' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - - 9965' - 9995' 8864' - 8549' DEPTH INTERVAL MD AMOUNT Si KIND OF MATERIAL USED 2000' Freeze Protected I ~ ~~Q~ 26. PRODUCTION TEST ~~ a~" ~ I ~~ ~ Zn~n ~ ~ft'IRIISSIQFi Date First Production: October 3, 2008 Method of Operation (Flowing, Gas Lift, etc.): AnChl~ragl; Gas Lift Date Of Test: 10/5/2008 HOUfS Tested: 6 PRODUCTION FOR TEST PERIOD OIL-BBL: 270 GAS-MCF: 778 WATER-BBL: 310 CHOKE SIZE: 95 GAS-OIL RATIO: 2,885 Flow Tubing Press. 200 Casing Press: 1,100 CALCULATED 24-HOUR RATE• OIL-BBL: 1,078 GAS-MCF: 3,111 WATER-BBL: 1,240 OIL GRAVITY-API (CORK): 25 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A uired? ^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 ~ :.+A ~~: ~ CT ~ ~ 2008 ; -_~-___~, Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~ a j ~~ ~~ ~ ~ 1~ f-"l I~ ~-`~1a-~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit /Zone 46 9524' 8752' None 42N /Zone 4A 9619' 8834' 42N /Zone 4A 10000' 8846' Base Zone 46 10000' 8846' Formation at Total Depth (Name): Base Zone 4B 10000' 8846' 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. ~ / ~~~/D~ Signed Terrie Hubble Title Drilling Technologist Date ' PBU N-146 208-080 Prepared ey NameMumber. Terrie Hubble, 564-4628 Well Number P r i . / r I N Drilling Engineer. Sean McLaughlin, 564-4387 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.07E IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 of 20 Operations Summary Report Legal Well Name: N -14 Common W ell Name: N -14 Spud Date: 8/27/2008 Event Name : R EENTE R+COM PLET E Start : 8/27/2008 End: 9/22/2008 Contractor Name: N ORDIC CALIST A Rig R elease: 9/22/2008 Rig Name: N ORDIC 2 Rig N umber: Date ' From - To ! Hours Task Code NPT Phase Description of Operations 8/26/2008 06:00 - 07:00 1.00 MOB P PRE Hold PJSM with all crew. Perform final walk around. Back rig off well. Spot on pad. 07:00 - 15:30 8.50 MOB P PRE Standby for rig mats to be spotted on access road. Remove CT 7-1/16" BOPS from cellar. Load out rig mats. Clean up around wellhead. Complete post pad inspection on V-115 with DSO. Lay herculite and set 13-5/8" BOPE on skid behind N-14. Set a few rig mats Move office trailer to N Pad 15:30 - 16:45 1.25 MOB P PRE Rig mats are spotted on access road. Move rig down V Pad and onto access road and head to the Spine 16:45 - 18:00 1.25 MOB P PRE Head east down the Spine Road 18:00 - 18:45 0.75 MOB P PRE C/O at Z pad entrance. 18:45 - 23:15 4.50 MOB P PRE Head east down the Spine Road 1 23:15 - 00:00 0.75 MOB P PRE Turn onto N pad access road. Spot rest of rig mats & dunnage. 8/27/2008 00:00 - 02:30 2.50 RIGU P PRE Inspect wellhead/tree & area, T/I/O = na/0/0, SI all tree valves & whitey valves. PJSM regarding backing onto rig mats & spotting over well. Review ADW SOP for moving over well with crew. Spot rig over well & set rig down. Rig accepted at 02:30hrs. 02:30 - 03:30 1.00 BOPSU P PRE RU handy berm. ND tree scaffolding. ND tree cap. Spot tiger tank, welding shop, cuttings box & spill shack. DSM RU hardline to tiger tank. Order rig fuel & rig water for BOPE testing. 03:30 - 03:40 0.17 BOPSU P PRE PJSM regarding pulling BPV & setting TWC. 03:40 - 10:15 6.58 BOPSU P PRE RU DSM lubricator. Test tiger tank line to 500psi. Pull 6-3/8" CIW "J" BPV. Set 6-3/8" CIW TWC. PT above to 3500 psi, below to 1000 psi. RDMO DSM 10:15 - 14:30 4.25 BOPSU P PRE ND 6" CIW tree and adaptor flange and load out Chk 7" NSCC threads in hanger w/ 8-1/2 RH turns 14:30 - 14:45 0.25 BOPSU P PRE Safety mtg re: skid in/NU BOPE 14:45 - 17:45 3.00 BOPSU P PRE Skid in 13-5/8" stack. Lift w/ bridge crane and NU. NU CIW/Barber spool 17:45 - 00:00 6.25 BOPSU P PRE NU choke and kill lines. Pick up CIW mandrel w/ 10ft of lubricator & test fit in CIW spool piece -very tight fit & stuck for 30 min, work it loose & lay it down. C/O air boots & RU riser. Get BOP measurements. Label BOP panels. Function test BOP's. Grease mud cross valves. 8/28/2008 00:00 - 01:00 1.00 BOPSU P PRE MU & torque test joint & place in well. Fill stack, lower boot on riser has slight leak, will fix after BOP test. RU IA & OA SLB gauges. 01:00 - 01:30 0.50 BOPSU P PRE Shell test BOPE 250psi/3500psi. Fix choke line leak. Shell test BOPE 250psi/3500psi -good test. 01:30 - 09:30 8.00 BOPSU P PRE Perform weekly BOPE test per AOGCC regs. Chuck Scheve waived witnessing BOP test. Test VBR's w/ 4-1/2" test joint. Fix lower boot on riser 09:30 - 12:30 3.00 BOPSU N RREP PRE Have trouble getting test on valve #3. Rebuild and no go. Replace valve and retest, okay 12:30 - 15:15 2.75 BOPSU P PRE RU and install new CIW mandrel in CIW/Barber spool w/ 14' of 7" lub to RF. Took a couple tries to get fully seated. RILDS and BOLDS. Pull back out w/ no problem using Coppertone pipedope and WD40. Reset and RILDS. PT 250/3500 15:15 - 16:30 1.25 BOPSU P PRE Bring DSM lubricator to the floor. PT ~ 600 psi. RIH and latch Nrintea: aisuizuus 11:55:50 HM BP EXPLORATION Page 2 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 8/28/2008 15:15 - 16:30 1.25 BOPSU P PRE TWC and well has 40 psi SITP, 10 psi IAP. Attempt to bleed down WHP in 3 stages and took 12 bbls plus a fair amount of gas to the TT. SITP 100 psi. Bled IA quickly to zero. Don't have enough lubricator pull TWC above blind rams 16:30 - 18:00 1.50 BOPSU P PRE Discuss w/ Sean McLaughlin. Add second valve to IA and RU to rev. Order more fluids Ken Miller on location. Notify Chuck Scheve w/ AOGCC 18:00 - 21:00 3.00 BOPSU P PRE C/O w/day crew. PJSM & walk walk around. RU hose & choke from IA to Tiger tank line to take ruturns from IA while pumping down tubing. 21:00 - 22:10 1.17 BOPSU P PRE Reverse circulate 100bb1s C~3 180 stks/min. 22:10 - 23:50 1.67 BOPSU P PRE Circulate 500bb1s down the tubing ~ 180stks/min. Bleed down OA to slop trailer. 23:50 - 00:00 0.17 BOPSU P PRE Stop pumping & bleed off pressure. 130psi on the tubing & 100psi on the IA -holing steady & not dropping. 8/29/2008 00:00 - 00:40 0.67 BOPSU P PRE Circulate 175bb1s down the tubing & up the IA. Bleed down OA to slop trailer. Total of 675bb1s pumped down the tubing ~ 180stks/min. 00:40 - 00:50 0.17 BOPSU P PRE Pits are MT. Stop pumping. Bleed off IA & tubing to TT. Crude returns from IA. Gas on the tubing. 00:50 - 02:15 1.42 BOPSU P PRE WHP = 4psi. IA = 8psi. SI & monitor pressure. STP in GPB is broken, traffic jam at the hot water plant. G&I is down, traffic jam at Pad 3. Wait on fluid from hot water plant & dirty vac truck. RU 4-1/2" handling equipment. 02:15 - 04:00 1.75 BOPSU P PRE WHP = 15psi. IA = 83psi. Load 290bb1s into the pits. Load some drill pipe into the pipeshed. 04:00 - 05:35 1.58 BOPSU P PRE WHP = 15psi. IA = 94psi. Load 200bb1s into the pits. Bleed off gas in the tubing & fill up tubing with C-pump - 19bbls. Having vac truck problems -won't build a vac, this really sucks. 05:35 - 08:00 2.42 BOPSU P PRE Circulate down the tubing, taking returns up the IA ~ 130 stks/min. After 100 bbls, continue to circ 4.4/360 w/ 310 IAP, 70 OAP w/ open choke After 500 bbls 4.4/360 w/ 290 IAP, 290 OAP 08:00 - 10:30 2.50 BOPSU P PRE After 605 bbls (2nd circ) take returns to pits at red rate of 2.44/120 w/ 105 IAP and 322 OAP After -10 bbls, gas alarms went off and had max 22% LEL. Resume taking returns to TT. Due to truck shortage and assuming most of diesel is out of wellbore, start recycling fluid 10:30 - 12:45 2.25 BOPSU P PRE After additional 150 bbls, take fluid back to pits and monitor 4-8% LEL. Bleed OA from 250 psi to zero. Continue to circ recycled 1% KCI 2.3/114 w/ 107 IAP, 10 OAP and have short durations of 10-20% LEL 12:45 - 15:30 2.75 BOPSU P PRE After 575 bbls (3rd circ) LEL was at 3-8%. Circ 2.35/110 w/ 103 psi IAP, 10 OAP 15:30 - 17:00 1.50 BOPSU P PRE After 365 bbls LEL was 0-8%, with avg <3%. SD pump and monitor for flow from the IA. PVT 363 Bleed OAP to zero No flow from IA 17:00 - 19:05 2.08 BOPSU P PRE Resume circ 2.44/125 w/ 96 IAP during crew changes. LEL = Printed: ei~uizuus l l:bb:b6 AM BP EXPLORATION Operations Summary Report Legal Well Name: N-14 Page 3 of 20 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours- Task I Code NPT ~ Phase ~ Description of Operations 8/29/2008 17:00 - 19:05 2.08 BOPSU~ P 19:05 - 19:30 0.42 BOPSU P 19:30 - 21:30 2.00 BOPSU P 21:30 - 22:30 I 1.001 FISH I P 22:30 - 23:00 0.50 FISH P 23:00 - 00:00 1.00 FISH P 8/30/2008 00:00 - 03:15 3.25 FISH P 03:15 - 03:40 I 0.421 FISH I P 03:40 - 04:10 0.50 FISH P 04:10 - 04:30 0.33 FISH P 04:30 - 04:55 0.42 FISH P 04:55 - 05:10 0.25 FISH P 05:10 - 06:45 1.58 FISH P 06:45 - 07:45 1.00 FISH P 07:45 - 09:30 I 1.751 FISH I P 09:30 - 11:00 1.501 FISH ~ P 11:00 - 13:00 2.00 FISH P 13:00 - 13:15 0.25 PERF P 13:15 - 14:15 1.00 PERF P 14:15 - 17:30 3.25 PERF P 17:30 - 18:00 0.50 PERF P 18:00 - 20:15 2.25 PULL P 20:15 - 20:45 0.50 PULL P 20:45 - 22:40 1.92 PULL P 22:40 - 22:50 0.17 PULL P 22:50 - 00:00 1.17 PULL P 18/31/2008 100:00 - 04:30 I 4.501 PULL I P PRE 0. Stop pumping. PRE Flow check. PJSM. PRE Attempt to pull CIW mandrel with tuggers - no go. Pop off DSM lubricator & disconnect from pulling tools. Install lifting cap & hook up to the blocks. Pull - 12k to get CIW mandrel free. Mandrel is scarred with mushrooming from lockdown screws & upward force from pumping, upper o-ring on mandrel was tore up. RD & LD DSM lubricator & pulling tools. Call for slickline unit. DECOMP Run mandrel back into spool piece with great difficulties. Removed upper o-ring on mandrel. DECOMP Wait on slick line. Empty & clean pits. Bring on new KCL water. DECOMP PJSM regarding RU slickline. RU slickline. DECOMP Continue to RU slickline. Stab onto well w/ slickline w/ equalizing tool & 1 tattle tail pin. P.T. 250/500 -good. Bleed off. DECOMP RIH w/ slickline. Shut in choke & jar down 5 times, no increase in WHP. DECOMP Pump across the top & POH. Tag up. Flow check. Pop off. DECOMP Break off equalizing tool -tattle tail pin was bent over. MU pulling tool. stab onto well. DECOMP RIH w/slickline. DECOMP Latch fish & jar up 11 times. Move fish up hole 20ft, let IBP relax for 15 min. DECOMP POH w/fish on. DECOMP Recovered IBP w/ upper rubber element. Missing lower element and stiffener ring SWS crew change DECOMP RIH w/ 3 prong grab and found element at 8570'. RIH to tag at 9150'. POH and recovered the lower element. Still missing the stiffener ring PVT 444 DECOMP RIH w/ 3.75" GR to tag. POOH w/ slickline Will mill up stiffener ring during millout of Fas-dril plug DECOMP RD SWS lubricator and BOP's. RDMO SWS DECOMP Safety mtg re: RU SWS a-line DECOMP MIRU SWS w/ WL packoff assy DECOMP RIH w/ GR/CCUJet cutter for 4-1/2". Log tie-in. Jet cut tubing at 9154' ELMD. POOH w/ a-line DECOMP RDMO SWS DECOMP Pull bushings, BOLDS on CIW spool & pull mandrel out with tugger. LD lubricator. RU floor tools for handling DP. MU 3-1/2" DP landing joint w/ XO's & stab into hanger w/ 8-1/2 turns. RU circulating hose. Open IA to tiger tank -vac. BOLDS on hanger. DECOMP Pull hanger to the RF, 104k break over point. Line up to CBU. DECOMP CBU ~ 180stks/min. Soapy returns C~ 9000stks away _ 2nd GLM. RU SLB control line spooler. PJSM while CBU regarding LD 4-1/2" completion. DECOMP Flow check - no flow. DECOMP Hook up control & balance lines to SLB spooler. Pull 4-1/2" completion from well bore, fill hole every 10 jts. DECOMP Continue to pull 4-1/2" completion. 51 of 56 control line bands recovered. Fill hole every 10 jts. Unload tubing from the pipeshed. rrinteo: aisurzuuu 1 CDJ:DO HM BP EXPLORATION Page 4 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations - - - 8/31/2008 04:30 - 12:00 7.50 PULL P DECOMP 12:00 - 15:15 ~ 3.25 ~ PULL ~ P ~ ~ DECOMP 15:15 - 16:00 0.75 PULL ~ P DECOMP 16:00 - 16:45 0.75 RIGU P DECOMP 16:45 - 18:40 1.92 BOPSU P DECOMP 18:40 - 00:00 ~ 5.33 ~ CLEAN ~ P ~ ~ DECOMP 19/1/2008 ~ 00:00 - 06:00 ~ 6.00 ~ RIGU ~ P ~ ~ DECOMP 06:00 - 07:00 1.00 CLEAN P DECOMP 07:00 - 07:15 0.25 CLEAN P DECOMP 07:15 - 08:30 1.25 CLEAN P DECOMP 08:30 - 10:30 2.00 CLEAN P DECOMP 10:30 - 11:00 0.50 CLEAN P DECOMP 11:00 - 11:30 0.50 CLEAN P DECOMP 11:30 - 16:00 4.50 CLEAN P DECOMP 16:00 - 16:45 0.75 CLEAN P DECOMP 16:45 - 18:00 1.25 CLEAN P DECOMP 18:00 - 18:45 0.75 CLEAN P DECOMP 18:45 - 22:30 3.75 CLEAN P DECOMP 22:30 - 00:00 1.50 CLEAN P DECOMP 19/2/2008 ~ 00:00 - 00:45 ~ 0.75 ~ CLEAN ~ P ~ ~ DECOMP Continue to pull 4-1/2" completion. Fill hole every 10 jts. Jts 50-70 have heavy corrosion & thickness loss. Found the first holes in jts 120 and 123 (+/-4800'). Had 170 total joints OOH at noon. Unload pipeshed. Wellbore is taking +/-2 bph Nordic crew change. PJSM Finish LD a total of 217 jts of 4-1/2" tubing w/ 6 GLM's. The jet cut joint measured 18.87' and was flared to 4-13/16" max (good cut). There were numerous 1/2" to 1" holes in the last 17 joints generally in the LS groove. The whole string had a very evident LS groove with fair internal pitting and heavy external pitting. Nearly every pin conection in the lower half was eroded to paper thin at the bottom. Several of the last joints bodys were deformed (crushed) while being held by the tongs during breakout. See photos on server Unload pipeshed of recovered completion tubing and jewelry Load Kelly, shuck and swivel into pipeshed Install test plug. PT 3-1/2 DP 3500/250 in the VBR's and 2500/250 in the annular. Remove test joint, pull test plug. Set wear ring in tubing hanger 13-5/8"x9-1/16" w/ 2 LDS to hold in place, labeled same. Set wear ring in CIW spool 13-5/8"x13-7/16" w/ 4 lower & 4 upper LDS to hold in place, labeled same. Load used 2-3/8" E-CT reel 15450E into reelhouse. NORM test tubing & GLM's -over limits. Test CL spool, RF & handling equipment -all within limits. PJSM for RU the Kelly. RU the Kelly. Put shuck in the rat hole. Simultaneously load pipeshed with 3-1/2" DP, tally same. Well is static. Continue to RU the Kelly, Kelly bushing, Kelly hose & Kelly swivel hoses. Service the Kelly. Test rotary table. MU saver sub. Torque all Kelly connections. Continue to load pipeshed w/ 3-1/2" DP. Bleed down OA from 4 psi to slop oil trailer (gas) & monitor for 3 hrs, remove hose after 3hrs - no flow, SI & monitor OA, wrap OA & apply heat. RU spinners & test same. RU 3-1/2" DP handling equipment. Clean RF. Bring BOT BHA to floor Safety mtg re: MU BHA MU washover BHA #1 MU 14 4-3/4" DC's MU 20 jts 3-1/2 DP MU 9-5/8" casing scraper Single in w/ 3-1/2 DP to 4290' Adjust tong counterweights 1/2 hr RBUx2 2.4/300 to clean scale out of DP Continue single in w/ 3-1/2 DP Stop at jt 160. C/O w/ day crew. Perform walk around/spill champion. Service rig. PJSM regarding tripping pipe. Single in with 3-1/2" DP. PU Kelly at 21:50. Reconfigue kelly spinner hoses. Test upper & lower Kelly valves per AOGCC regs 250psi/3500psi -good. Shell test Kelly hose & mud manifold - tighten 4" greylock on mud manifold. Continue to pressure test Kelly hose. R/D test equipment. rnnre¢ aiowcvuo i i.oa.ao n~~~ ~ ~ BP EXPLORATION Page 5 of 20 ', Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 L Date From - To Hours Task I Code NPT 9/2/2008 00:00 - 00:45 0.75 CLEAN P 00:45 - 01:30 0.75 CLEAN P 01:30 - 02:30 1.00 CLEAN P 02:30 - 02:40 0.17 CLEAN P 02:40 - 04:40 2.00 CLEAN P 04:40 - 05:15 I 0.581 CLEAN I P 05:15 - 07:30 I 2.251 CLEAN I P 07:30 - 08:20 0.83 CLEAN P 08:20 - 18:00 9.67 CLEAN P 18:00 - 20:15 I 2.25 I CLEAN I P 20:15 - 20:40 0.42 CASE P 20:40 - 21:00 0.33 CASE P 21:00 - 21:30 0.50 CASE P 21:30 - 00:00 2.50 CASE P 9/3/2008 00:00 - 04:40 4.67 CASE P 04:40 - 05:10 0.50 CASE P 05:10 - 07:30 2.331 WHSUR P 07:30 - 09:00 ~ 1.50 ~ WHSUR ~ P 09:00-13:00 ~ 4.OO~WHSUR~P 13:00 - 16:25 3.42 ~ W HSU R P Spud Date: 8/27/2008 Start: 8/27/2008 End: 9/22/2008 Rig Release: 9/22/2008 Rig Number: Phase ~ Description of Operations DECOMP Remove & send out CL spooler from RF. DECOMP RBU at 90 sks/min ~ 700psi. DECOMP Single in the hole with the Kelly from jt # 238 to jt # 243. No issues with top of 7" liner. Circulate & rotate pipe, 180 Amps or 3800ft/Ibs, 88k up & 82k down. DECOMP Blow down the Kelly & rack back in the shuck. DECOMP Continue to single in with 3-1/2" DP. Mix 40bb1 hi-vis pill. 84k RIW, 98k up weight. Tag (2k) at 9140ft on jt # 274. LD jt # 274. PU the Kelly, 102k up weight. Circualte at 120 stk/min C~ 1000psi, rotate ~ 200 Amps = 4000ft/Ibs. Tag at 9140ft. DECOMP Mill on 4-1/2" stub at 9140ft mill for 10min, swallow tubing & work down 16ft & tag (9156ft)- mill with upper mill made -2", mill for 15min. Stop rotating. PU, 10k drop in weight above 9140ft & lost 300psi in pump pressure. Pump hi vis pill. Work up & down on stub -clean. Tag at 9156ft. PU. DECOMP CBU ~ 120 stk/min. Fin CBU ~ 4.95/1000 No metal or foreign objects noted. DECOMP Blow down and set back kelly. DECOMP TOH standing back DP. LD 9-5/8" casing scaper -good condition. Continue to TOH standing back DP. LD DC's sideways. Break apart lower mill (good indicaton inside of lower mill). Break apart upper mill (good indicaton on upper mill). DECOMP Crew change, Spill champion inspection, and PJSM. Finish LD of BHA. Unload DC's out of pipe shed. DECOMP Bring in HAL tools. DECOMP PJSM on PU of RBP packer and running procedures. DECOMP PU RBP packer and MU to DP DECOMP TIH with RBP. DECOMP continue to TIH with RBP paker. DECOMP DWN WT = 78 K UP WT=82K Space out to set packer 15 ft in on jnt # 289. Taged top of tubing stub at 20 ft in on jnt # 289. Set down 8 K lbs. PU and set packer 10 ft in ~ 9133.34 ft top of packer C~ 9124.6 ft. DECOMP RU and pressure test 7" casing. Time IAP OAP 06:30 3500psi Opsi 06:45 3454psi Opsi 07:00 3450psi Opsi Casing pressure test to 3500psi =PASS. RD test equipment. DECOMP LD 4 jts of 3-1/2" DP. Set RTTS packer 33ft from RF & test to 500psi for 10 min -pass. DECOMP Remove OA bleed hose & check for flow/pressure - no flow. RU to IA & suck down stack. Pull upper & lower wear rings. RU 4-1/4" DC & casing packoff pulling tool. Bleed casing packoff pressure to Opsi. Pull casing packoff - 30k. RU 1/2" conduit w/ chugger pump to suck out neck seal cavity. Run new casing packoff. Perform ICPPOT - 3800psi -PASS. DECOMP LD 4-1/4" DC. Set wear rings. RBIH with 4 jts. Latch RBP w/ Printed: eisuieuua ii:oo:oeHm BP EXPLORATION Page 6 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To 'Hours Task ~ Code NPT Phase Description of Operations 9/3/2008 13:00 - 16:25 3.42 WHSUR P DECOMP 15k below string wt. PU 5k over string wt -latched. Turn string to the right while PU & wt fell back to normal string wt. Let RBP rubber relax. Turn string to the right to let torque out. PU 20ff & 15tt below setting depth to confirm RBP is upset. 16:25 - 17:20 0.92 WHSUR P DECOMP RBU ~ 90stks/min for 2 times the DP volume. 17:20 - 00:00 6.67 CLEAN P DECOMP Slowly TOH in the 7" standing back DP. 9/4/2008 00:00 - 00:40 0.67 CLEAN P DECOMP Continue TOH with RBP 00:40 - 00:45 0.08 CLEAN P DECOMP PJSM on LD and unloading of RBP Paker. 00:45 - 01:30 0.75 CLEAN P DECOMP LD packer and set outside. No damage to packer observed, very light marking on bottom of RBP bull noze, assumingly from top of tubing stub. Not dented, not scrached. 01:30 - 03:30 2.00 BOPSU P DECOMP Rig up for weekly BOPE Test. 03:30 - 13:30 10.00 BOPSU P DECOMP Perform weekly BOPE Test as per AOGCC Regulations, Well permit, and well plan. Test witness waived by AOGCC Inspector, Lou Grimaldi. Having difficulties with the blinds. Regrease valves, cycle blinds, flush with water, troubleshoot. RILDS to energize seal on test plug -blinds passed. 13:30 - 14:50 1.33 CLEAN P DECOMP Set lower & upper wear rings. 14:50 - 15:55 1.08 CLEAN P DECOMP PJSM regarding MU BHA. Hoist BOT BHA components to the RF. MU lower dress over shoe, 16ft of wash pipe, inner dressing mill + boot basket, jars & bumper sub. 15:55 - 23:00 7.08 CLEAN P DECOMP TIH w/ DP. 23:00 - 23:40 0.67 CLEAN P DECOMP PU Kelly, obtain parameters. 100K UW, 88K DW, & 98K RW. Did not see any indication of top of tubing and bottom of wash pipe tag. Tagged Top of tubing with inner mill at 9140' (bottom of wash pipe Cam? 9156'). PU off of TT and repeated, again no indication of TT and bottom of wash pipe tag. No milling was done to prevent damaging tubing stub. Saw increase in pump pressure both times the mill shoe went over the tubing stub. The upper mill goes into the 4-1/2" stub 9" & an increase in pump pressure was noted. 23:40 - 00:00 0.33 CLEAN P DECOMP Continue to pump biozan sweep out. 9/5/2008 00:00 - 00:50 0.83 CLEAN P DECOMP Continue to pump sweep to top of 7" then reverse circulate it out. 00:50 - 01:20 0.50 CLEAN P DECOMP Blow down and stand back Kelly 01:20 - 01:35 0.25 CLEAN P DECOMP PJSM on LD & wash of Drill pipe for long term storage. 01:35 - 06:00 4.42 CLEAN P DECOMP TOH and LD drill pipe. 06:00 - 06:45 0.75 CLEAN P DECOMP C/O w/night crew. Spill champion. Service the rig. PJSM regarding TOH w/ DP. 06:45 - 06:50 0.08 CLEAN P DECOMP Noticed slight gas bubbling in the reserve pit out behind the rig. Make a series of phone calls. 06:50 - 12:30 5.67 CLEAN P DECOMP Continue to TOH sideways, fill hole every 5 stds. 12:30 - 14:00 1.50 CLEAN P DECOMP With - 20k hanging weight, break apart the Kelly. 14:00 - 17:00 3.00 CLEAN P DECOMP Continue to TOH sideways, fill hole every 5 stds. 17:00 - 18:00 1.00 CLEAN P DECOMP LD BOT BHA. 18:00 - 18:30 0.50 CLEAN P DECOMP Crew change and PJSM on LD of BHA 18:30 - 19:30 1.00 CLEAN P DECOMP Continue to LD BHA, and send out BOT tools. RIH with remaining stands in derick, and POOH laying down sideways. 19:30 - 20:00 0.50 CLEAN P DECOMP Pull upper and lower wear rings, LD and send out. 20:00 - 20:15 0.25 CLEAN P DECOMP PJSM on LD of Kelly, Schuck, and swivel. rrirneo: aisuizuuu i i:oaao r{m BP EXPLORATION Page 7 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To 'i Hours Task 'Code NPT ~ Phase Description of Operations 9/5/2008 20:15 - 00:00 3.75 CLEAN P DECOMP LD Kelly, Schuck, Swivel, and send out. RD and put away 3.5" DP handling tools. 9/6/2008 00:00 - 00:20 0.33 BUNCO RUNCMP PJSM on loading pipe shed with 4.5" Completion 00:20 - 11:30 11.17 BUNCO RUNCMP Load pipe shed with 4.5" completion. Strap and Drift completion. RU 4-1/2" handling equipment. RU Doyon torque turn services. 11:30 - 18:00 6.50 BUNCO RUNCMP Running 13Cr 4-1/2" tubing with Doyon Torque Turn (Torque = 4450 ft-Ib). All connections below the packer were Bakerlock'd. Stop on jt # 67. 18:00 - 18:45 0.75 BUNCO RUNCMP Crew change and PJSM on running completion. 18:45 - 00:00 5.25 BUNCO RUNCMP Continue 13Cr 4.5" tubing from Jnt # 72 with Doyon Torque Turn services. Target torque = 4450 ft/Ibs. Kick out Jnt 145 and replace with Jnt 216. 9/7/2008 00:00 - 07:00 7.00 BUNCO RUNCMP Continue to run 4.5" completion. Tag top of stump on jnt # 212, 1st shear pins ~ 9152ft, 2nd shear pins ~ 9160ft, and no go ~ 9164 ft. LD jt # 212. Space out and land hanger in the tubing spool on jnt # 211 with 8 ft over the existing tubing stub. RILDS on hanger. 07:00 - 09:20 2.33 BUNCO RUNCMP PJSM regarding RU slickline. LD landing joint. RU CIW mandrel in spool. RU slickline. RD 4-1/2" handling equipment. 09:20 - 10:25 1.08 BUNCO RUNCMP RIH w/ 3.70"x21ft dummy whipstock drift via slickline. Tag at 9195ft 3 times. 10:25 - 10:45 0.33 BUNCO RUNCMP POH. 10:45 - 11:00 0.25 BUNCO RUNCMP Tag up. Flow check. LD dummy whipstock. RU RHC plug & x-line. 11:00 - 12:30 1.50 BUNCO RUNCMP RIH w/ RHC plug. Set RHC in profile at 9080ft. 12:30 - 12:50 0.33 BUNCO RUNCMP POH. 12:50 - 13:15 0.42 BUNCO RUNCMP Tag up. Flow check. Stand back slickline. RU landing joint. RU 2" circulating hose. 13:15 - 17:30 4.25 BUNCO RUNCMP Reverse circulate 140bb1s of 140 deg F 1 %KCL ~ 3bpm/286psi, followed by 345bb1s of corrosion inhibited 140 deg F 1%KCL @ 3bpm/300psi, followed by 120bb1s of SW from the pits. 17:30 - 18:40 1.17 BUNCO RUNCMP Drop ball and rod to set packer. Bring tubing pressure up to 1700 psi saw pressure bobble. Continue to bring pressure up to 3500 psi. 18:40 - 20:05 1.42 BUNCO RUNCMP Pressure test tubing for 30 min with 3500 psi. Lost 50 psi over 30 min-Pass. Bleed tubing down to 1500 psi. Pressure up IA to 3500 psi. and test 30 min. Test pass with no noticeable loss in 30 min. 20:05 - 20:30 0.42 BUNCO RUNCMP Bleed down leaving pressure on the IA to shear DCR valve in GLM # 6. DCR sheared at about 2000 psi. Let IA and tubing pressure bleed down to zero. 20:30 - 20:45 0.25 BUNCO RUNCMP PJSM on RD of test equipment, RU of LRHOS, and FP opps. 20:45 - 21:00 0.25 BUNCO RUNCMP RU LRHOS and PT lines. 21:00 - 22:20 1.33 BUNCO RUNCMP Pump 110 bbls of diesel at 1.5 bpm down IA taking returns through tubing to freeze protect IA to 2000 ft. 22:20 - 23:00 0.67 BUNCO RUNCMP RD LRHOS. RD Kelly line 23:00 - 23:15 0.25 BUNCO RUNCMP PJSM with SLB SL crew for RU and SL opps Pnntetl: eisuizoutt n:oxaenm ~ ~ BP EXPLORATION Page 8 of 20 Operations .Summary Report Legal Well Name: N-14 Common Well Name: N-14 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date I From - To I Hours ' Task Code NPT 9/7/2008 23:15 - 23:30 0.25 RU 23:30 - 00:00 0.50 RU 9/8/2008 00:00 - 00:15 0.25 RU 00:15 - 00:45 0.50 RU 00:45 - 01:10 0.42 RU 01:10 - 01:50 0.67 RU 01:50 - 02:30 0.67 RU 02:30 - 03:00 0.50 RU 03:00 - 03:30 0.50 RU 03:30 - 04:15 0.75 RU 04:15 - 04:35 0.33 RUN 04:35 - 06:00 1.42 RUN 06:00 - 06:45 0.75 BOPSU P 06:45 - 15:00 8.25 BOPSU P 15:00 - 17:00 2.00 ~ BOPSU ~ P 17:00 - 17:30 0.50 BOPSUF{ P 17:30 - 20:20 2.83 BOPSU~dj P 20:20 - 20:50 0.50 BOPSU P 20:50 - 00:00 I 3.171 BOPSUR P 9/9/2008 00:00 - 07:00 7.00 BOPSUFj P 07:00 - 07:30 0.50 BOPSUq P 07:30 - 13:45 6.251 BOPSUFi P 13:45 - 14:30 0.75 BOPSU~ P 14:30 - 14:45 0.25 RIGU P 14:45 - 16:30 1.75 RIGU P 16:30 - 16:45 0.25 RIGU P 16:45 - 18:20 1.58 RIGU P 18:20 - 18:30 0.17 RIGU P 18:30 - 20:30 2.00 RIGU P 20:30 - 20:40 I 0.171 RIGU I P 20:40 - 22:00 I 1.331 RIGU I P Spud Date: 8/27/2008 Start: 8/27/2008 End: 9/22/2008 Rig Release: 9/22/2008 Rig Number: Phase Description of Operations RUNCMP RU SLB SL RUNCMP RIH with SL to retrieve ball and rod. RUNCMP RIH and latch ball and rod. RUNCMP POOH with ball and rod. RUNCMP change out SL tools for DCR pull run. RUNCMP RIH and pull DCR valve. RUNCMP POOH with DCR valve. RUNCMP RIH and set dummy valve in GLM #6 RUNCMP POOH after setting valve RUNCMP RU triplex pump to IA and start to PT IA to 500 psi. Triplex wont stay running, Call for new one. RU second Triplex. RUNCMP PT IA to 500 psi for 10 min. RUNCMP RD from IA test while SL RIH to pull RHC. Pop off well, RHC plug was recovered. RUNCMP Set 4" 'H' TWC & test to 3500psi -Pass. RUNCMP Blow down kill line, choke line, cellar cement line & stack. RD BOP riser. RD CIW spool piece. Open ram doors & remove ram components for long term storage. ND choke & kill lines. RU BOP lifting plate. Un chain BOP stack. Un hook BOP hoses. ND BOP flange at tubing spool. Hoist 13-5/8" BOP onto BOP skid. PRE NU 13-5/8" x 4-1/6" adapter flange, torque up w/ Sweeney wrench. PRE PPPOT-T to 5000psi, 30min test -PASS. PRE NU 4-1/16" tree & jewellery. PRE Pressure test tree. Low pressure test to 250 psi, then High pressure to 5000 psi. - no leaks PRE Pull rig back off well. Spot in 7 1/16" BOP skid, lift BOP'S with blocks and secure. Install Koomey lines. Spot rig back over well head. NU BOP's. PRE Continue to NU 7 1/16" BOP's. RU Choke and Kill lines. Grease mud cross valves & choke valves. PRE Shell test to 3500psi. Slight leak on gey lock fitting, bleed off & tighten. Repeat shell test -pass. PRE Pressure test BOPE per AOGCC regs to 250psi/3500psi. Bob Noble waived witness of test. PRE RD from BOP test. PRE PJSM on RU Injector Head and Pac-off PRE RU injector head, and pack off. Make ready to stab coil PRE PJSM on stabing coil PRE Stab Coil into injector. PRE PJSM for cutting coil. PRE Cut 550 ft of coil. Clear rig floor of tools and cut pipe. Install SLB CTC. PRE PJSM on CTC pull test and PU of Jnt of PH6 for pumping slack. PRE Pull test CTC. PU 1 jnt of PH6 and stab on well. Pumped 110 bbls 2 ppb Biozan at 3 bpm. Unstab from well and no E line sticking out of CTC. Printed: 9/30/2008 11:55:56 AM i BP EXPLORATION Page 9 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: .Date From- To '~, Hours. Task Code NPT Phase Description of Operations 9/9/2008 22:00 - 22:40 0.67 FISH P WEXIT MU BTT CTC. 22:40 - 00:00 1.331 BOPSUp P ~ WEXIT 9/10/2008 00:00 - 00:15 0.25 FISH P WEXIT 00:15 - 01:10 0.92 FISH P WEXIT 01:10 - 03:05 1.921 FISH P WEXIT 03:05 - 08:00 ~ 4.92 ~ FISH ~ P ~ W EXIT 08:00 - 10:00 2.00 FISH N DPRB WEXIT 10:00 - 10:30 0.50 FISH N DPRB WEXIT 10:30 - 12:30 2.00 FISH P WEXIT 12:30 - 15:30 3.00 FISH N DPRB WEXIT 15:30 - 17:30 2.00 FISH N DPRB WEXIT 17:30 - 18:00 0.50 FISH N DPRB WEXIT 18:00 - 18:30 0.50 FISH N DPRB WEXIT 18:30 - 19:30 1.00 FISH N DPRB WEXIT 19:30 - 21:25 1.92 FISH N DPRB WEXIT 21:25 - 22:00 ~ 0.58 ~ FISH ~ N ~ DPRB ~ W EXIT BTT missing cross over needed from LH threads to RH threads to PT and Pull test. While waiting on BTT hot shot. Pressure test inner reel valve and pack off. BTT cross over here by 23:40 -still testing though. PJSM on PU of Milling BHA and stabbing on the injector. PU - LH Milling BHA with 3.70 piranha mill and 3.80 diamond string mill. Stab on injector RIH with Milling BHA. at 9100 ft. 2.5 bpm ~ 1820 psi Up WT=32K Dn WT=23K continue RIH to Fast drill. Tag top of fast drill ~ 9215.8 ft. Stalled twice while RIH 0.4 fpm Time mill ahead on top of wear ring and fast plug stopping every 0.1 ft to allow time to mill off starting ~ 9215.5 Op=2.56/2.56 bpm @ 2000psi. Stalled again @ 915.9 ft. - PU and start again from 9215.7 ft Repeat Eventually mill to 9217.5'. Unable to make any additional progress for several hours. Frequent stalls. Pick up after stalls initially smooth, then began to get overpulls. CT up wt: 27k#. Overpulls up to 46k#. Discuss options with town. Decide to rig up slickline. Circulate out of hole. Had a few overpulls. Lay down milling BHA. Piranha mill and string reamer showed significant junk wear on gauge areas. Face of piranha mill showed little wear. Looks like hard junk was up along side mills. Cut and slip drilling line while waiting on slickline. Spot slickline unit. Hold PJSM with all crews. RU wireline pressure control equipment. Bring tools to floor. Complete rig up with SLB slickline crew. Some SLB hands new to rig. Run in hole with 3.0" x 10' flat bottom pump bailer BHA. Recovered half a cup of large steel and brass pieces. These were up to +/- 1" x 1" x 3/8" thick. Very substantial junk. Crew changes and PJSM on slick line operations. RU Second pump bailer run with 3.0" x 10 ft' double mule shoe bottom. RIH with second pump bailer worked bailer, POOH Recovered less junk but still some large brass peices, and some steel peices as well. 'Change out 3" pump out bailer, to a 3.5" X 10' bailer with a single sided mule shoe Printetl: 9/30/2008 11:55:56 AM BP EXPLORATION Page 10 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ,Hours Task ~ Code NPT Phase Description of Operations 9/10/2008 22:00 - 00:00 2.00 FISH N DPRB WEXIT Make third bailer run with larger bailer. Work bailer, POOH 9/11/2008 00:00 - 00:30 0.50 FISH N DPRB WEXIT SL #3 Recovered more large brass pieces, and some steel 00:30 - 01:15 0.75 FISH N DPRB WEXIT 01:15 - 03:05 1.83 FISH N DPRB WEXIT 03:05 - 03:40 0.58 FISH N DPRB WEXIT 03:40 - 07:00 3.33 FISH N DPRB WEXIT 07:00 - 09:00 2.00 FISH N DPRB WEXIT 09:00 - 10:30 1.50 FISH N DPRB WEXIT 10:30 - 11:15 0.75 FISH N DPRB WEXIT 11:15 - 13:00 1.75 FISH N DPRB WEXIT 13:00 - 14:30 1.50 FISH N DPRB WEXIT 14:30 - 16:00 1.50 FISH P WEXIT 16:00 - 16:45 0.75 FISH P WEXIT 16:45 - 18:50 2.08 FISH P WEXIT 18:50 - 21:45 2.921 FISH P W EXIT 21:45 - 23:50 2.08 FISH P WEXIT 23:50 - 00:00 0.17 FISH P WEXIT 9/12/2008 00:00 - 01:50 1.83 FISH P WEXIT pieces. Also recovered one large round steel chunk about 2" in diameter with small threaded tap on one side with "WS" and "1270" engraved on surface. Changed tool configuration from 3.5" X 10 ft to 3.5" X 5 ft. This should give us a little more suction power. SL run #4. Recovered very little. Few small metallic peices. Most stayed suspended in the 2 ppb biozan. RD pump bailer and RU a LIB to run while waiting on Baker Thru Tubing. Run 3.75" LIB on slickline. Tag fish at +/- 9217'. Pull out of hole. Good impression of what looks like the top of the easidrill plug. Slight evidence of additional small junk. Rig down SLB slickline equipment. MIRU DHD pressure test equipment. Hold PJSM with crew to discuss OA MIT test. Pressure OA to 1000 psi w/diesel. Hold and record for 30 minutes. MU milling BHA with piranah mill and no string reamer. All left hand threads. Run in hole. Tag fasdril at 9222'. 1900 psi fs at 2.57 bpm in/out. Mill plug. Push remains to 9505'. Circulate hi vis sweep. Circulate out of hole. At surface. Get off well. LD piranah mill. MU 3.79" parabolic 331 with 3.80" string reamer. Stab coil. Get on well. RIH To mill XN nipple. Wt check @ 9200 ft Up WT=37K dry Tag ~ 9253 ft. PU to nutral wt. ~ 9250 and get parameters Op=2.5 bpm @ 2050 psi. Time mill XN nipple from 9250 ft. .01 ft / 3 min. Pumped 5 bbl sweep C~ 9252 ft. Stalled Cad 9253 ft. ~ 9253.2 Cp=2200 psi. Milled through ~ 9254.8 ft. Pass through slowly twice while pumping. PU to 9247 ft SD MP's and RIH dry to 9256.5 ft Turn MP's on to 2.5 bpm and continue to 9490 ft. POOH chassing last pill to surface. Pull through milled XN nipple was clean. PJSM while POOH on standing back injector and LD of BHA. Stand back injector and LD (LH) milling BHA. Rehead with (RH) BTT CTC. Pull test to 20K and PT to 3500 psi. PJSM on MU & PU of BHA. PU dummy whipstock BHA. Stab on injector. Pnntetl: 9/30/2008 11:5S:Sti Ann BP EXPLORATION Page 11 of 20 ~ Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date ' From - To Hours Task Code NPT Phase. 9/12/2008 00:00 - 01:50 1.83 FISH P WEXIT 01:50 - 04:15 2.42 EVAL P WEXIT 04:15 - 06:15 2.00 EVAL P 06:15 - 06:45 0.50 STWHIP P 06:45 - 09:30 2.75 STWHIP P 09:30 - 10:45 1.25 STWHIP P 10:45 - 13:00 2.25 STWHIP P 13:00 - 15:00 2.00 STWHIP P 15:00 - 16:00 1.00 STWHIP P 16:00 - 16:30 0.50 STWHIP P 16:30 - 17:30 1.00 STWHIP P 17:30 - 19:20 I 1.831 STWHIPI P 19:20 - 19:30 0.17 STWHIP P 19:30 - 19:40 0.17 STWHIP P 19:40 - 20:20 0.67 STWHIP P 20:20 - 20:25 0.08 STWHIP P 20:25 - 20:50 0.42 STWHIP P 20:50 - 23:05 2.25 STWHIP P 23:05 - 23:20 0.25 STWHIP P 23:20 - 00:00 0.67 STWHIP P 9/13/2008 ~ 00:00 - 02:20 ~ 2.33 ~ STW H I P ~ P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Description of Operations RIH with dummy whipstock to 9495 ft. Dn WT @ 9050 ft = 19,700 #'s C~ 22 fpm. Drift was clean down and up. POOH pumping 2.5 bpm. At surface. Get off well. LD dummy WS BHA. RU and reverse circulate slack into reel. Cut 340' of coil. Test a-line. MU dimple connector. Pull, pressure, and continuity test connector. Install 2 PIP tags in tray. MU Baker 4-1/2" mono-bore retr whipstock on Inteq BHA tools. Scribe tray face to HS on orienter. Stab coil. Test tools. Get on well. Run in hole at 60 fpm. Log initial GR tie in from 9410'. Displace coil and well to seawater. GR too hot for Inteq tools in area of interest. Round up more logs from PBOC. log CCL tie in from 9150 to 9480'. Subtract 12' correction. Set whipstock top at 9467'. TF to 150R. Close EDC. Pressure up coil and set whipstock. Sheared at 3400 psi. Set 31# dn. WS taking weight. PU. Off whipstock. Pull out of hole. Paint EOP flag at 9200'. (BOP excluded) PJSM while POOH on unstabbing and LD of BHA. POOH Stand back injector and LD Inteq tools. LD whipstock setting tool. Tool had indication of good clean set. Change injector pack offs. PJSM on MU of cement nozzle and stabbing injector MU cement Nozzle BHA, stab on injector. RIH PJSM with cementers, Spot in cement trucks, RU hard line, load water, While RIH. Stop at EOP mark C~ 9200 ft for correction of -14 ft. Nozzle depth ~ EOP 9221.26 ft PJSM with SLB & Nordic crews for cement job. By pass "rock catcher" Pump 5 bbls fresh water. PT cement lines to 4500 psi. Pump 8 bbls 15.8 ppg class G cement Pump 5 bbls fresh water. Pump 7 bbls KCL water switch to 2ppb biozan. while RIH to 9457 ft. from 9457 ft. pump 1 bbl cement out nozzle then POOH 1 for 1 at 1 bpm & 66 fpm. POOH to saftey. POOH to safety ~ 8300 psi. Wait for 30 min for cement to settle. Slowly pressure up to 1000 psi for 30 min. Slowly open Printed: 9/30/2008 11:55:56 AM BP EXPLORATION Page 12 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date '~ From - To ,Hours Task Code ~ NPT Phase Description of Operations 9/13/2008 00:00 - 02:20 2.33 STWHIP P WEXIT choke up to bleed off wellhead press. RIH to 9457 ~ 40 FPM with Op=3 bpm ~ 2100 psi. POOH to 8900 ft still pumping 3.0 bpm. RIH to 9457 @ 3 bpm. 02:20 - 04:55 2.58 STWHIP P WEXIT POOH pumping 3 bpm. Slowly reciprocate across jewelry. 04:55 - 05:10 0.25 STWHIP P WEXIT Unstab injector, LD cement nozzle, PU swizzle stick, Stab on injector. 05:10 - 05:40 0.50 STWHIP P WEXIT Wash out stack with swizzle stick. 05:40 - 05:55 0.25 STWHIP P WEXIT Unstab injector, LD swizzle stick. 05:55 - 07:00 1.08 STWHIP P WEXIT MU window milling BHA on Inteq tools. (3.8" speed mill and 3.8" string mill). Stab coil. Test tools. Get on well. 07:00 - 11:00 4.00 STWHIP P WEXIT Run in hole slow while waiting on cement. 11:00 - 11:30 0.50 STWHIP P WEXIT Lo CCL tie in from 9150'. Subtract 16' correction. S 11:30 - 15:00 3.50 STWHIP P WEXIT 2020 psi fs at 2.53 bpm in/out. ' ' ~f . Tag TOW at 9467.5 Tag cement at 9465 ~ 1, ~l.`~j Begin time milling from 9467.5'. N DHWOB: 1.0-2.Ok# Mill at 12 minutes per 1/10th initially, then increase to 6 minutes per 1/10th ft. Mill to 9469'. 15:00 - 17:00 2.00 STWHIP P WEXIT Mill ahead from 9469'. Mill at 6 minutes per one-tenth ft. 2010 psi fs at 2.52 bpm in/out. 100-200 psi mtr work. DH W OB: 1-2k#. Metal on magnets. 17:00 - 00:00 7.00 STWHIP P WEXIT Showing lighter WOB for same travel and pump pressures. ~ 9470.5 Mill to 9474.2 ft with DH WOB = 0.08-1.2k# 0=2.53/2.56 bpm p=2050 - 2150 psi 9/14/2008 00:00 - 04:25 4.42 STWHIP P WEXIT Continue to mill window. ~ 9474 ft change to .5 ft / 6 min. ~ 9474.6 ft 0=2.52/2.55 bpm P=2110 psi DH WOB=710# Getting P=2150psi when pipe is advanced 0.5 ft ~ 9476.3 ft motor work and DHWOB started to fall off much faster. Expected BOW ~ 9476.3 Continue to mill ahead at 0.1 ft / 6 min. GEO confirmed formation cuttings in bottoms up sample from 9476.4 ft 04:25 - 05:30 1.08 STWHIP P WEXIT From 9467.3 ft drill ahead 10 ft of formation. l~ 9478.5 ft. QP=2.53/2.59 bpm ~ 2175 psi. DH WOB=1840# Delta-P=504 psi. ~ 9481.5 ft DHWOB=2400#'s P=2190 psi. drilled to 9486 ft rrinteo: aiwizv~a i i.oo.oo Nm ~ ~ BP EXPLORATION Page 13 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase I Description of Operations 9/14/2008 04:25 - 05:30 1.08 STWHIP P WEXIT 05:30 - 06:30 1.00 STWHIP P WEXIT 06:30-08:30 2.00 STWHIP P WEXIT 08:30 - 09:30 1.00 STWHIP P WEXIT 09:30 - 10:30 1.00 DRILL P PROD1 10:30 - 12:15 1.75 DRILL P PROD1 12:15 - 12:30 0.25 DRILL P PRODi 12:30 - 12:45 0.25 DRILL P PROD1 12:45 - 18:50 6.08 DRILL P PROD1 18:50 - 21:10 2.33 DRILL N DFAL PROD1 21:10 - 21:20 0.17 DRILL N DFAL PROD1 21:20 - 22:00 0.67 DRILL N DFAL PROD1 22:00 - 23:30 1.50 DRILL N DFAL PROD1 23:30 - 00:00 0.50 DRILL N DFAL PROD1 9/15/2008 00:00 - 04:30 4.50 DRILL N DFAL PROD1 04:30 - 04:50 0.33 DRILL N DFAL PROD1 04:50 - 05:00 0.17 DRILL N DFAL PROD1 05:00 - 05:45 0.75 DRILL N DFAL PROD1 05:45- 08:00 2.25 DRILL N DFAL PROD1 08:00 - 10:00 2.00 DRILL N DFAL PROD1 10:00 - 10:30 0.50 DRILL N DFAL PROD1 10:30 - 11:30 1.00 DRILL N DFAL PROD1 PU and pull through window to 9400-up pass clean RIH down pass through window-clean. Dry drift window. Smooth. Pull out of hole. SLB mechanics checking out injector noises. Hold BHA PJSM. LD milling BHA. Gauge mills. MU drilling build assembly (BHA run #10). 3.55 deg AKO with HTC 4.125" bicenter. Stab coil. Test tools. Get on well. Run in hole. Log CCL tie in from 9150'. Subtract 12' correction. RIH. Pass through window ok. Begin displacement to flo-pro mud. Drill ahead from 9487' 2200 psi fs at 2.23 bpm in/out. Pressures changing during displacement. Drill ahead to 9616'. MWD data shows hole azimuth +/-120 deg off plan. Other data indicates major directional problem. POOH to check tools. PJSM - LD of Inteq tools. Unstab injector and LD Inteq tools for diagnosis. Test and evaluate problems with Inteq tools High Side calibration or HOT mechanical problems. Waiting on cement pilot testing /loading /and batch testing. Continue to wait for cement Prep pits for cement job. Spot vac trucks. Off load FloPro, bring in sea water. PJSM for MU of cementing BHA and PU injector. PU cementing BHA while prepping pits. (connector, 15 jts 1.25" CSH, nozzle) E-line is anchored. RIH. Tag TD at 9630'. Subtract typical correction off -14' to correct to known TD of 9616'. Circulate above window while waiting on SLB cementers. Displace well to seawater. Hold PJSM with all crew in Ops cab. Discuss HSE issues, pump schedule, and clean up. Mix 8 bbls 17 opo Class G cement. Up to weight at 1050 hrs. Pump 2 bbls fresh Ovate. Test lines to 4000 psi. Pump 8 bbls cement into reel. 950 psi at 1.5 bpm in/out. Chase with 5 bbls seawater. Displace cement down coil with seawater. Lay in cmt at 0.5 bpm while POH at 30 fpm._ POOH to safety at 8500'. Continue to circ at 0.5 bpm and move pipe up hole. CIP at 1130 hrs. Release cementers. Transport live cement sample to SLB shop for UCA test. Printed: 9/30/2008 11:55:56 AM ~ ~ BP EXPLORATION Page 14 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 9/15/2008 11:30 - 12:30 1.00 DRILL N DFAL PROD1 Circulate while waiting on cement to swap and settle. 12:30 - 15:00 2.50 DRILL N DFAL PROD1 Wash down to 9447' with biozan. 15:00 - 19:30 ~ 4.501 DRILL ~ N ~ DFAL ~ PROD1 19:30 - 19:50 0.33 DRILL N DFAL PROD1 19:50 - 20:30 0.67 DRILL N DFAL PROD1 20:30 - 23:35 3.08 DRILL N DFAL PROD1 23:35 - 00:00 0.42 DRILL N DFAL PROD1 9/16/2008 00:00 - 01:15 1.25 DRILL N DFAL PROD1 01:15 - 02:30 I 1.251 DRILL I N I DFAL I PROD1 02:30 - 07:30 5.00 DRILL N DFAL PRODi 07:30 - 08:00 0.50 DRILL N DFAL PROD1 08:00 - 09:00 1.00 DRILL N DFAL PROD1 09:00 - 10:30 1.50 DRILL N DFAL PROD1 10:30 - 12:00 1.50 DRILL N DFAL PROD1 12:00 - 14:00 2.00 DRILL N DFAL PROD1 14:00 - 14:15 0.25 DRILL N DFAL PROD1 14:15 - 18:00 3.75 DRILL P PROD1 18:00 - 19:00 I 1.001 DRILL I P I I PROD1 Circulate out of hole. Wash GLMs on the way out. Several bbls of cement was returned, treated, and disposed of. Cut 100' of coil and wire for chrome management. Re-head a-coil. Pull test to 35K -good PT to 3800 psi -good PJSM - PU of cement milling BHA and PU / stab on injector PU cement milling BHA with 3.77" Parabolic mill and 3.79 string mill. Stab on injector. RIH slowly waiting for cement compressibility test to indicate 500 psi. Receive report from SLB for cement compressibility of 500 psi ~ 9:30 min after CIP time. Increase RIH speed. Log from 9,000 ft to 9380 ft for CCL tie in. -12 ft correction RIH from 9380 with correction Slowlv RIH all the way to 9476 ft. NO -significant WOB only got 500#'s NO motor work. PU to 9150 and RIH back to 9450 waiting on BU sample. BU sample had uncured cement in it. Consult with town. ` POOH to 8500 to WOC. 0=2.23 bpm Wait on cement, ~ Run in hole to test cement. Cement has been in place for 19 hrs. UCA test at SLB shows 5000+ psi comp strength at 16 hrs on field sample. 612 psi fs at 0.77 bpm in/out. Tap hard cement at 9476'. 1450 psi fs at 2.07 bpm in/2.08 out. DHWOB: 1-2k# Mill ahead to 9482'. Circulate out of hole. Hold BHA PJSM near surface. AT surface. Get off well. LD milling BHA. MU 3.55 deg AKO build assy w/ 4.125" HTC bi-center and resistivity tool. Stab coil. Test tools. Get on well. Run in hole. Line up vac trucks for mud displacement. Log CCL tie in from 9150'. Subtract 8' correction. Run through window ok. Drill ahead with 0.5 to 1.0 k# dhwob. TF: 155R. 1950 psi fs at 2.02 bpm in/out. ROP 13fph Continue to displace CT annulus to flo-pro mud. Drill to 9535' with 0.5 to 1.0 k#dhwob. TF: 112 - 76R. 2800 psi at 2.28 bpm in/out. ROP 24 fph, ECD 9.75ppg Printed: 9/30/2008 11:55:56 AM BP EXPLORATION Page 15 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~~ Code I NPT 'I Phase ~ Description of Operations 9/16/2008 19:00 - 21:30 2.50 DRILL P PROD1 Drill to 9650' with 1.5 k# dhwob. TF: 105 - 84R. 2800 psi at 2.28 bpm in/out. ROP 42 - 80fph, ECD 9.75ppg 21:30 - 21:45 0.25 DRILL P PROD1 Wiper trip to window, Up Wt 33k, Dn Wt 21 k, PVT 437bb1s, IA 94psi, OA 205psi, hole clean 21:45 - 22:30 0.75 DRILL P PROD1 Drill to 9680'with 1.8 k# dhwob. TF: 92 R. 2725 psi at 2.23 bpm in/out. ROP 36 - 81fph, ECD 9.78ppg 22:30 - 00:00 1.50 DRILL P PROD1 Drill to 9766' with 1.1- 1.6 k# dhwob. TF: 40 - 92 R. 2825 psi at 2.38 bpm in/out. ROP 77fph, ECD 9.81 ppg 9/17/2008 00:00 - 02:10 2.17 DRILL P PROD1 Drill to 9850' with 1.1- 2.4 k# dhwob. TF: 61-53 R. 2725 psi at 2.2 bpm in/out. ROP 113 - 82fph, ECD 9.70ppg 02:10 - 02:50 0.67 DRILL P PROD1 'holed 2 3/8" Coil Tb 02:50 - 04:30 1.67 DRILL N DFAL PRODi PJSM on clean u o erations, dressed out pin hole with duck to nd absorbent, Re orted Pin hoe ea o o ro r g Mud in coil tubing to X-5700 and pad operator erry 0, leak was contained to roof and reel house, cleaned up with absorb, placed in oily waste bag for disposal ,Leak was less than one gallon, all material leaked was contained on rig 04:30 - 06:00 1.50 DRILL N DFAL PROD1 POH to BHA #13 06:00 - 07:15 1.25 DRILL N DFAL PROD1 Get off well. LD build BHA. Bit was 1-1-I. A few small chips on pilot cutters. Remove tool from catwalk. 07:15 - 08:30 1.25 DRILL N DFAL PROD1 RU SLB nitrogen pumpers. Hold PJSM in Ops cab with all hands. Flush coil with 25 bbls water. Displace reel with N2. RD N2 unit. 08:30 - 10:30 2.00 DRILL N DFAL PROD1 Hold PJSM. RU to unstab coil. Install grapple. Pull test same. Spool coil onto reel. Secure same. 10:30 - 11:30 1.00 DRILL N DFAL PROD1 Hold detailed safety discussion w/ H. Williams, K. Miller and entire crew. Discussed unstab procedure in detail, lock out/tag out in general. Also discussed lifting operations in windy conditions. 11:30 - 13:00 1.50 DRILL N DFAL PROD1 Cut extra bolts from drive plate. Free reel from drive mechanism. Suspend reel. 13:00 - 15:30 2.50 DRILL N DFAL PROD1 Hold PJSM with CHILL. SLB crew change. Lower used reel to low boy trailer. Secure used reel on trailer. Spot lowboy with replacement reel. Attach slings and lift into reel house. 15:30 - 17:15 1.75 DRILL N DFAL PROD1 MU hardline and bulkhead assemblies inside reel. 17:15 - 18:00 0.75 DRILL N DFAL PROD1 Hold PJSM with crew. Install grapple in coil. Pull test same. 18:00 - 18:45 0.75 DRILL N DFAL PROD1 PJSM with change out crew on pulling across CT 18:45 - 22:15 3.50 DRILL N DFAL PROD1 Pull CT across, stab injector, Cut off CT grapple, meg a-line, boot a-line, stab injector, displace CT with FW, test surface lines back to inner reel valve to 250 - 3500psi 22:15 - 23:00 0.75 DRILL N DFAL PROD1 Reverse circ for slack management several times with FW at 3.5 - 4 bpm, cut 10' of CT found 5' a-line 23:00 - 00:00 1.00 DRILL N DFAL PROD1 Install SLB dipple CTC 9/18/2008 00:00 - 00:30 0.50 DRILL N DFAL PROD1 Finished installing SLB dipple CTC, Pull test to 35k, ok 00:30 - 02:00 1.50 DRILL N DFAL PROD1 Install UOC, Behead a-line, pressure test CTC to 4000 psi 02:00 - 02:30 0.50 DRILL P PROD1 Displace CT to Flo Pro mud, PJSM on handling and MU BHA 02:30 - 03:20 0.83 DRILL P PROD1 MU Drlg BHA #14 with 1.2 deg motor 03:20 - 05:10 1.83 DRILL P PROD1 RIH with Drlg BHA #14 to 9290' Printed: 9/30/2008 11:55:56 AM B'P EXPLORATION Page 16 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number:. Date From - To ~ Hours Task Code NPT Phase 9/18/2008 05:10 - 05:25 0.25 DRILL P PROD1 05:25 - 05:45 0.33 DRILL P PROD1 05:45 - 06:45 1.00 DRILL P PROD1 06:45 - 07:30 0.75 DRILL P PROD1 07:30 - 11:00 3.50 DRILL P PROD1 11:00 - 12:00 1.00 DRILL P PROD1 12:00 - 14:00 2.00 DRILL P PROD1 POOH and lay in hi vis flo pro pill. PRODi Circulate at max rate while POOH. Hold PJSM near surface, PROD1 LD lateral BHA tools. PROD1 PJSM on slack mgnt and handling a-line PROD1 RU, set injector over rig floor circ hole, pumped at 3bpm, recovered 330' of 5/16" EL, total CT length 15523', boot a-line RUNPRD PJSM, RU handling tools and tongs RUNPRD PJSM on running liner -Discuss hazard, crew assignments and hand and body placement RUNPRD P~ 1 M 7/ " x 3 1/ " lin .r Ac y as follow$ 2-7/8" Unique Biased Edge Guide Shoe, Float Collar, 2 7/8" joint with turbo, Float Collar, Pup Jt, Landing Collar, 22 jts 2-7/8 6.4# L-80 STL Liner with turbos, XO, 9 jts 3-1/2" 9.2# STL liner, 3-1/2" Pup Jt, BTT Deployment Sleeve with 4" GS profile, SELRT running tool, 3/4" disconnect, 4 jts PH6 tubing, Lockable swivel RUNPRD Change out to BTT Slip-on CTC with 1.5" ID, pull test to 40k, pressure test to 4000 psi, MU to BHA, stab injector RUNPRD in r Ass it SELRT runnin tool. 2550 psi fs at 2.20 bpm in/out. TD called at 10,120'. 14:00 - 14:30 0.50 DRILL P PROD1 Wlper trip to window. Log CCL tie in. Add 3' correction. 14:30 - 15:30 1.00 DRILL P PROD1 back to bottom. Offical TD is 10 123'. 15:30 - 17:00 1.50 DRILL P 17:00 - 18:15 1.25 DRILL P 18:15 - 18:30 0.25 DRILL P 18:30 - 20:30 2.00 DRILL P 20:30 - 21:00 0.50 CASE P 21:00 - 21:15 0.25 CASE P 21:15 - 00:00 2.75 CASE P 19/19/2008 100:00 - 01:15 1.251 CASE P 01:15 - 03:00 1.751 CASE P 03:00 - 03:35 0.581 CASE ~ P 03:35 - 04:15 I 0.671 CASE I P 04:15 - 06:00 I 1.75 I CASE I P Description of Operations Run tie-in pass from 9290' - 9390', -10' correction, close EDC RIH to Btm, PVT 393 bbls Drill with 2.4 k# dhwob. TF: 18 R, FS 2575psi at 2.38bpm, 2825 psi at 2.38 bpm in/out. ROP 43 fph, ECD 9.80ppg Make wiper trip to window. Hole smooth. Drill ahead from 9914'.,s 2445 psi fs at 2.28 bpm in/out. 100-300 psi mtr work. DH W OB: 3-4k#. Frequent stalling. Problems with wt xfer. Make frequent short wipers. ROP: 80-10 fph when drilling. Make wiper trip to window. Hole smooth. Wt check at window, broke over at 41.3k, Up Wt 39.5k, slacked off thru window with slight bobble of 1 k, Dn wt 24k RIH to bottom at 10,123' Cleaning pits, loading with 2% double slick KCL, built 45bbls of 2ppb biozan RUNPRD RIH to bottom at 10,132', correct depth back to 10123', Up Wt 42.5k at 15fpm, Dn Wt 23k, Paint EOP flag at 8978', slacked off with 10k to 10124.5 without pumps RUNPRD PU to 10117.8 w/ 42.5 k Up Wt, Est Circ at .2 - .5 bpm, 927 - 1183 psi for 5 bbls, increase rate to 1 bpm at 1454 psi for 5 bbls, increase rate 1.5 bpm at 1772 psi for 5 bbls, Slack off with 10k to 10124.1, Pick Up to 10118' with 32.5k Up wt, position reel for ball drop at 10130' with 20 k. RUNPRD Drop 5/8" steel ball with 500 psi, chase with flo-pro, Move CT back to 10K compression, never heard ball move, pumped 35 Nnnteo: ai~uiluub 11:°b:bb HM • BP EXPLORATION Page 17 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 ,Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ' Task Code NPT Phase Description of Operations 9/19/2008 04:15 - 06:00 1.75 CASE P RUNPRD bbl 2 bpm, 2020 psi, slowed rate to .5 bpm at 1100psi, pumped 69 bbls, ball did not land on seat 06:00 - 07:00 1.00 CASE P RUNPRD Check ball drop, slacked off to 10131' w/ 25k, heard possible ball move at ball drop, applied 1000psi, open ball drop valve, chase with flo-pro at 2.05bpm, 2225 psi. Increase rate to 2.99 bpm in w/ 3200 psi, then 3.44 bpm in at 3735 psi. No indication at all of ball on seat. 07:00 - 07:30 0.50 CASE P RUNPRD Make weight check. 36k# up wt with no pump. No indication coil is released from liner. (Lateral drilling BHA showed an up wt o stimated liner wt is 4.5k#) 07:30 - 08:00 0.50 CASE P RUNPRD Pump 10 bbls slick KCL. Blow out uphole end of coil inside reel. Drop 5/8" steel ball #2. Circ at 2.06 bpm in/out at 2015 psi. The ball drop team hears ball moving. Heard one or maybe both go over the gooseneck. Slow rate to 0.75 bpm. Ball on seat at 47 bbls. Pressure to 4050 psi. Continue to circ. wt k#. A 08:00 - 09:15 1.25 CASE P RUNPRD Displace well to 2% slick KCL. 2250 psi at 2.55 bpm in out. Hold PJSM with crew. 09:15 - 10:30 1.25 CASE P RUNPRD Batch mix 12 bbls Class G 15.8 as block cement. Cement up to weight. 10:30 - 12:00 1.50 CASE P RUNPRD Pump 3 bbls KCL. Pressure test lines to 4000 psi. Pump 12 bbls cmt into reel. Shut down and circ biozan back through cement line. Displace cement with 41 bbls biozan followed by KCL water. 1380 psi 2.06 bpm in/out. Maintain 10k# positive down on coil. Zero the M out at 65 bbls away (cmt at shoe). Shut do pump at 69.1 bbls total pumped (cmt/bio/kcl). PU to up wt of 33K# at 10,121'. Continue to PU 13' to 10,108'. Pump 2 bbls cmt followed by 5 bbls biozan. Shut do pump. Open Baker choke. RIH to 10,126'. MM out: 11.3 bbls. Pressure CT to shear liner wiper plug at 1500 psi. 0.3 bbls additional to shear. Pump cement through liner at 2.0 bpm w/ 1300 psi. Bumo plug 6 I backflow. Floats holdin . Pressure up to 500 psi. Unsling. CIP at 1200 hrs. 12:00 - 14:00 2.00 CASE P RUNPRD POOH replacing voidage. Lay in remianing 30 bbls of bio while pulling through cement. 14:00 - 15:45 1.75 CASE P RUNPRD LD liner runnin BHA. Found 26' of a-line extended from coil end. Found one 5/8" ball, the 2nd ball is missing. 15:45 - 17:15 1.50 CASE N SFAL RUNPRD MU nozzle on coil. Verify 5/8" ball will not go through nozzle. Get on well. Slowly RIH and circ at 3950 psi at 5.45 bpm in/out. Circ 180 bbls or three coil volumes. Get off well. No ball found. 17:15 - 17:30 0.25 CASE N SFAL RUNPRD Vacuum out bung hole on rig floor. Found 5/8" ball. 17:30 - 18:00 0.50 EVAL P LOWERi PU logging tools to pipeshed 18:00 - 18:30 0.50 EVAL P LOWERI SAFETY MEETING. Review procedure, hazards and mitigation for M/U mill, motor and SWS Memory CNL/GR logging tools. Printetl: y/3U/'LUUti 11:~~:5ti HM BP EXPLORATION Page 18 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code ~I NPT 9/19/2008 ~ 18:30 - 21:30 ~ 3.00 ~ EVAL ~ P 21:30 - 23:40 2.171 EVAL ~ P 23:40 - 00:00 0.331 FISH P Spud Date: 8/27/2008 Start: 8/27/2008 End: 9/22/2008 Rig Release: 9/22/2008 Rig Number: Phase Description of Operations LOWERI M/U Memory logging / Cleanout BHA #16 with 2.30" diamond mill, motor, 2 jts CSH, SWS Carrier, Circ sub, Hyd disc, 30 jts CSH, Hyd Disc, 2 jts PH6, locking swivel and CTC. BHA OAL = 1100.1'. LOWERI RIH with cleanout and memory logging BHA #16, Circ at 0.40 bpm at 430psi Tag AI profile at 9134', Up wt 32k Bring pump to drilling rate of 1.30 bpm at 1530 psi. LOWERI Mill out profile in deployment sleeve at 9134' (uncorrected), 1.3bpm, 1700psi 9/20/2008 00:00 - 02:45 2.75 FISH P LOW ER1 Mill out profile in deployment sleeve from 9134' to 9134.8' (uncorrected), 1.3bpm, 1700 - 952psi, made several pass with and without pumps, hole clean, cement contamination in returns, strung out over 60 bbls, weighing 8.6 to 9.0 ppg 02:45 - 03:30 0.75 EVAL P LOWERI Pull up to start of logging depth at 8930', Log down at 30 fUmin, 1.45bpm, 1545psi, No cement stringers seen, Tap PBTD at 10094' twice Uncorrected 03:30 - 03:55 0.42 EVAL P LOWERI Log upwards at 60 ft/min to 8930', start pert pill down CT 03:55 - 04:20 0.42 EVAL P LOWERI RIH to Btm at 10094', Flagged EOP at 8994' 04:20 - 06:15 1.92 EVAL P LOW ER1 POH, Layed in pert pill from bottom across liner 06:15 - 08:30 2.25 EVAL P LOW ER1 At surface. Unstab coil. Stand back CSH. Remove logging source. LD logging tools and motor assy. 08:30 - 09:00 0.50 EVAL N DFAL LOWERi Down load logging tool data. GR/CCL/CNL tool failed in the middle of milling aluminum sleeve. Tool will have to be re-run. 09:00 - 10:00 1.00 EVAL N DFAL LOWERI Pressure test liner lap to 2000 psi for 30 minutes. Chart same. ISITP: 2055 psi. FSITP: 2036 psi. 10:00 - 12:00 2.00 EVAL N DFAL LOWERI MU repaired set of logging tools and a replacement motor. Run 32 'ts of 1-1/4" CSH from derrick. Stab coil. Get on well. 12:00 - 14:00 2.00 EVAL N DFAL LOWERI Run in hole. 14:00 - 15:00 1.00 EVAL N DFAL LOWERI Make GR/CCL/CNL down and up pass through liner. Tag TD at 10.096'. 15:00 - 17:00 2.00 EVAL N DFAL LOWERI Pull out of hole to logging BHA. Stand back injector. 17:00 - 19:15 2.25 EVAL N DFAL LOWERI SAFETY MEETING. Discuss hazards and procedure for pulling CSH. Stand back CSH, L/D BHA #16 19:15 - 19:40 0.42 EVAL P LOWERI SAFETY MEETING. Discuss crew positions and hazards for removing radioactive source from logging tools, Remove source, lay down and offload logging tools. 19:40 - 21:00 1.33 EVAL P LOWERI Rig up swizzle stick, Jet stack and surface lines with 3 bpm, 2150psi to clean out any cement, POH LD nozzle 21:00 - 22:00 1.00 PERFO P LOWERI SAFETY MEETING. Discuss hazards and mitigations for running pert guns, Keep cellar clear, minimize people on the rig floor. Run erf uns on efire-CT firin s stem with 370' of 2" 6SP uns and blanks, 5/8" disconnect 22:00 - 23:40 1.67 PERFO P LOWERI Run 11 stds 1 1/4" CSH, 3/4" disconnect, check valve, 2 jts PH6 tbg, Lockable swivel and CTC, stab injector 23:40 - 00:00 0.33 PERFO P LOWERI RIH with Perf Gun BHA #17, present depth at 2520' 9/21/2008 00:00 - 01:50 1.83 PERFO P LOWERI RIH with Perf Gun BHA #17, tagged btm at 10101' uncorrected, twice, corrected PBTD to 10081', MCNL dated 09-20/08, Dn wt Printed: 9/30/2008 11:55:56 AM ! • BP EXPLORATION Page 19 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To 'Hours Task ~ Code NPT Phase Description of Operations 9/21/2008 00:00 - 01:50 1.83 PERFO P LOWERI 23k, Up wt 38k, RU shot detection 01:50 - 04:00 2.17 PERFO P LOWERI PU, spot guns on depth with btm shot at 9995' and top shot at 9640', perform practice run on cycling pump, start circulation sequence to fire guns. Shut down pump for 2 min. Pump 0.3 bpm for 1 min, then 1.5 bpm for 1 min. Repeat twice Pump 0.3 bpm for 1 min, 1.5 bpm for 2.5 min. Reduce pump to 0.3 bpm, wait +75 seconds for firing head to activate. No indication of uns firin . Repeat pump sequence, no indication of guns firing. Bleed down pulsation dampener to 0 psi, attempt to cycle pump, pump reostat not responding fast enough, pressured up pulsation damper to 1000psi, Circulate at 1.75bpm, 2025psi for 10 minutes repeat pump sequence a third time, no indication of guns firing. Circ at 1. bpm, 1470psi, while consulting with SLB Feild Supv, Fourth time repeating pump sequence, no indication of guns firing. 04:00 - 06:00 2.00 PERFO P LOW ER1 POH to Perf Gun BHA #17 while circ across the top of hole. 06:00 - 07:45 1.75 PERFO P LOWERI Crew change. Hold PJSM. LD PH6. Stand back 1-1/4" CSH in derrick. 07:45 - 09:45 2.00 PERFO N DFAL LOWERI Guns did not fire. Check top gun for "wet connect". Change E-fire head for Ball drop firing head. Run CSH and PH6 from derrick. 09:45 - 12:30 2.75 PERFO N DFAL LOWERI Run in hole. Tag btm at 10,100'. Subtract 19' correction to btm shot. PU to good ball drop depth. Drop ball. Displace ball with KCL. Call hear ball rolling 1500 psi at 2.04 bpm in/out. RU shot detector on tree in cellar. Slow rate to 1.1 bpm ~ 490 psi with 50 bbls away. On seat at 53 bbls. Seat sheared at 3020 psi. Good shot indication in cellar. Move BHA immediately. 12:30 - 14:30 2.00 PERFO N DFAL LOWERI Pull out of hole. Fill across the top. Lost 2 bbls fluid while POH. 14:30 - 19:30 5.00 PERFO P LOWERI Get off well. LD PH6 and CSH in singles. LD guns. All shots fired. Perf interval: 9640' to 9665', 9940' to 9950', 9965' to 9995'. Offload from pipeshed to SLB trk 19:30 - 20:40 1.17 PERFO P LOWERI PJSM on handling CSH, RIH with stds of CSH, POH, LD same, simops- RU pump trk to cement line, pressure test lines, pumped 35 bbls of diesel down CT, RD pump trk, 20:40 - 23:00 2.33 WHSUR P POST M/U nozzle, check valves, CTC, stab injector, RIH to 2,000 ft, POH, lay in diesel to surface, freeze protect well, Std Back Injector, LD nozzle BHA, 23:00 - 23:35 0.58 WHSUR P POST PJSM with valve crew on BPV setting operations, Dry rod and set 4" Cameron "H" Plug, LD dry rod and running tool 23:35 - 00:00 0.42 WHSUR P POST PJSM for N2 blowdown and pickle job. 9/22/2008 00:00 - 01:45 1.75 WHSUR P POST Pickle CT with corrision inhibited pill, MEOH followed with N2 01:45 - 05:30 3.75 WHSUR P POST Install internal grapple in CT, PJSM for pulling back CT, Pull Printed: 9/30/2006 11:55:56 AM • BP EXPLORATION Page 20 of 20 Operations Summary Report Legal Well Name: N-14 Common Well Name: N-14 Spud Date: 8/27/2008 Event Name: REENTER+COMPLETE Start: 8/27/2008 End: 9/22/2008 Contractor Name: NORDIC CALISTA Rig Release: 9/22/2008 Rig Name: NORDIC 2 Rig Number: Date From - To I Hours Task ' Code ~ NPT ! Phase Description of Operations 9/22/2008 01:45 - 05:30 3.75 WHSUR P POST bacik CT to reel, secure, RD hard line and tiger tank 05:30 - 09:15 3.75 DEMOB P POST ND BOP, cleaning pits rig released at 0800 hrs on 9-22-08 09:15 - 10:00 0.75 DEMOB P POST Back off well. Prep to lower derrick. Printed: 9/30/2008 11:55:56 AM `x,, ~, ~~ ~ BP Alaska `~~~~~° Baker Hughes INTEQ Survey Report BAKER HUGHES INTEQ Cumpany: BP Amoco ~ Field: Prudhoe Bay Site: PB N Pad Well: N-14 Wellpath: N-14BPB1 Date: 9/19/2008 'l'ime: 09:04:07 Page: 1 Co-ordinate(NE) Reference: Well: N-14, True North Vertical (TVD) Reference: 74.47 74.5 Section (VS) Reference: Well (O.OON,O.OOE,27.92Azi) 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 N Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5965420.89 ft Latitude: 70 18 48.671 N From: Map Easting: 633404.63 ft Longitude: 148 55 7.726 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.02 deg Well: N-14 Slot Name: 14 N-14 Well Position: +N/-S 1828.10 ft Northing: 5967267.00 ft Latitude: 70 19 6.650 N +E/-W 1038.09 ft Easting : 634409.99 ft Longitude: 148 54 37.435 W Position Uncertainty: 0.00 ft Wellpath: N-146PB1 Drilled From: N-14A 500292059470 Tie-on Depth: 9456.98 ft Current Datum: 74.47 Height 74.47 ft Above System Datum: Mean Sea Level Magnetic Data: 9/17/2008 Declination: 22.94 deg Field Strength: 57672 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.97 0.00 0.00 27.92 Survey Program for Definitive Wellpath Date: 9/17/2008 Validated: Yes Version: 4 Actual From To Survey Toolcode Tool Name ft ft -4.20 8200.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 8290.00 9456.98 2 : MWD -Standard (8290.00-99 MWD MWD -Standard 9467.00 9619.00 MWD (9467.00-9619.00) MWD MWD -Standard Annotation NID T~'D ft ft 9456.98 8688.40 TIP 9467.00 8697.53 KOP 9619.00 8834.32 TD Survey: MWD Start Date: 9/17/2008 Company: Baker Hughes INTEO Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path -~ ~ BP Alaska ~ sNU~~s '' Baker Hughes INTEQ Survey Report 1NTEQ ~ ~ ~: BP C Amoco Date: B/19/2008 Tim e: 09:04:07 Page: ~ Field: Pru dhoe Bay eo-ordinate(NE) Reference: Well: N-14, Tr ue North Sife: PB N Pad Vertical (TVD) Reference: 74.47 74.5 ~ Nell: N-1 4 Section (VS) Reference: Well (O.OON,O. OOE,27.92 Azi) i ~Vellpath: N-1 4BPB1 Sur~ey Calculation ~1ethod: Minimum Curvature Db: Orade Sur~~cv J1D Incl Azim TVD Sys TVD NIS E/~'~' MapN ~~iapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100 ft 9456.98 24.39 327.70 8688.40 8613.93 2416.99 1354.58 5969707.66 635720.98 2769.93 0.00 MWD 9467.00 24.23 327.70 8697.53 8623.06 2420.47 1352.38 5969711.11 635718.71 2771.98 1.60 MWD 9486.25 21.34 330.00 8715.27 8640.80 2426.85 1348.51 5969717.41 635714.73 2775.80 15.71 MWD 9515.65 13.83 310.00 8743.30 8668.83 2433.75 1343.14 5969724.22 635709.23 2779.38 32.44 MWD 9542.25 20.26 290.05 8768.74 8694.27 2437.38 1336.36 5969727.73 635702.40 2779.42 32.35 MWD 9568.96 31.79 292.45 8792.71 8718.24 2441.67 1325.48 5969731.82 635691.44 2778.11 43.34 MWD 9574.22 33.83 293.29 8797.13 8722.66 2442.78 1322.85 5969732.88 635688.79 2777.86 39.74 MWD 9619.00 33.83 293.29 8834.32 8759.85 2452.64 1299.95 5969742.32 635665.72 2775.84 0.00 MWD P AJ .~ '}~~~- BP Alaska BAKER HUGNE9 Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 9/19/2008 Time: 08:58:14 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference. Well: N-14, True North Site: PB N Pad Vertical (TVD) Reference: 74.47 74.5 ~Vcll: N-14 Section (VS) Neference: Well (O.OON,O.OOE,37.50Azi) Wellpath: N-14B Survey Calculation Method: Minimum Curvature llb: 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 N Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5965420.89 ft Latitude: 70 18 48.671 N From: Map Easting: 633404.63 ft Longitude: 148 55 7.726 W Position Uncertainty: 0.00 ft Ground Level: 0.00 ft North Reference: Grid Convergence: True 1.02 deg Well: N-14 Slot Name: 14 N-14 Well Position: +N/-S 1828.10 ft Northing: 5967267.00 ft Latitude: 70 19 6.650 N +E/-W 1038.09 ft Easting : 634409.99 ft Longitude: 148 54 37.435 W Position Uncertainty: 0.00 ft Wellpath: N-14B 500292059402 Drilled From: Tie-on Depth: N-14A 9456.98 ft Current Datum: 74.47 Height 74.47 ft Above System Datum: Mean Sea Level Magnetic Data: 5/9/2008 Field Strength: 57664 nT Declination: Mag Dip Angle: 23.14 deg 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.97 0.00 0.00 37.50 Survey Program for Definitive Wellpath Date: 5/9/2008 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft -4.20 8200.00 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO -Sperry-Sun BOSS gyro multishot 8290.00 9456.98 2 : MWD -Standard (8290.00-99 MWD MWD -Standard 9467.00 10123.00 MWD (9467.00-10123.00) MWD MWD -Standard Annotation ~- - NID T~'D ft ft __ --- _ 9456.98 8688.40 TIP 9467.00 8697.53 KOP 10123.00 8770.42 TD Survey: MWD Start Date: 9/17/2008 Company: Baker Hughes INTEQ Tool: MWD;MWD -Standard Engineer: Tied-to: From: Definitive Path ~~~ , ~ BP Alaska ~ ~N~6 ES ~` Baker Hughes INTEQ Survey Report 1NTEQ Company: BP Amoco Date: 9/19/2008 Time: 08:58:14 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: N-14, True North Site: PB N Pad Vertical (TVD) Reference: 74.47 74.5 Well: N-14 Section (VS) Reference: Well (O.OON,O.OOE,37.50Azi) Wcllpath: N-14B Survcv Calculation Jlethod: Minimum Curvature Db: Oracle Survcs blll incl Azim TVD Sys TVD N/S E/W J1apN i~1apE VS DLS Tuol ~' ft deg deg ft ft ft ft ft ft ft deg/100ft 9456.98 24.39 327.70 8688.40 8613.93 2416.99 1354.58 5969707.66 635720.98 2742.12 0.00 MWD 9467.00 24.23 327.70 8697.53 8623.06 2420.47 1352.38 5969711.11 635718.71 2743.55 1.60 MWD 9480.82 21.49 328.00 8710.26 8635.79 2425.02 1349.52 5969715.60 635715.77 2745.41 19.84 MWD 9496.22 17.41 330.00 8724.78 8650.31 2429.41 1346.87 5969719.94 635713.05 2747.28 26.84 MWD 9510.21 14.55 350.00 8738.24 8663.77 2432.95 1345.52 5969723.46 635711.63 2749.27 44.05 MWD 9525.34 14.60 17.74 8752.90 8678.43 2436.65 1345.77 5969727.16 635711.82 2752.36 45.72 MWD 9530.14 15.68 25.34 8757.53 8683.06 2437.81 1346.23 5969728.33 635712.26 2753.56 47.03 MWD 9545.31 20.77 42.10 8771.95 8697.48 2441.66 1348.92 5969732.23 635714.87 2758.25 47.85 MWD 9560.45 25.31 54.08 8785.88 8711.41 2445.56 1353.34 5969736.20 635719.23 2764.04 42.97 MWD 9590.57 34.45 67.93 8812.00 8737.53 2452.56 1366.49 5969743.44 635732.25 2777.60 37.85 MWD 9619.77 42.12 84.08 8834.96 8760.49 2456.69 1383.96 5969747.88 635749.64 2791.51 43.00 MWD 9650.24 49.12 96.00 8856.30 8781.83 2456.54 1405.64 5969748.12 635771.32 2804.59 36.12 MWD 9686.16 55.67 114.89 8878.33 8803.86 2448.82 1432.79 5969740.89 635798.59 2814.99 45.36 MWD 9714.41 62.81 125.28 8892.80 8818.33 2436.62 1453.69 5969729.06 635819.71 2818.04 40.43 MWD 9739.19 71.60 130.31 8902.40 8827.93 2422.61 1471.70 5969715.38 635837.97 2817.89 40.09 MWD 9770.12 83.91 135.13 8908.95 8834.48 2402.13 1493.84 5969695.30 635860.46 2815.12 42.60 MWD 9800.94 90.28 147.32 8910.51 8836.04 2378.18 1513.06 5969671.71 635880.11 2807.82 44.56 MWD 9834.94 99.07 159.67 8907.73 8833.26 2347.96 1528.16 5969641.76 635895.75 2793.04 44.46 MWD 9851.79 103.40 163.66 8904.45 8829.98 2332.28 1533.36 5969626.17 635901.23 2783.76 34.63 MWD 9870.82 106.34 164.05 8899.57 8825.10 2314.61 1538.47 5969608.61 635906.66 2772.86 15.58 MWD 9900.34 110.80 162.20 8890.17 8815.70 2287.84 1546.59 5969581.99 635915.25 2756.56 16.23 MWD 9930.83 114.02 159.94 8878.55 8804.08 2261.18 1555.72 5969555.50 635924.86 2740.98 12.59 MWD 9960.35 117.11 158.16 8865.81 8791.34 2236.32 1565.24 5969530.81 635934.82 2727.04 11.80 MWD 9990.27 120.92 155.91 8851.30 8776.83 2212.23 1575.44 5969506.91 635945.44 2714.14 14.33 MWD 10020.04 124.55 153.35 8835.20 8760.73 2189.60 1586.15 5969484.48 635956.56 2702.71 14.18 MWD 10050.15 127.71 149.38 8817.44 8742.97 2168.26 1597.79 5969463.35 635968.58 2692.87 14.95 MWD 10076.84 130.76 146.35 8800.56 8726.09 2150.75 1608.77 5969446.04 635979.87 2685.66 14.42 MWD 10123.00 130.76 146.35 8770.42 8695.95 2121.65 1628.14 5969417.29 635999.76 2674.37 0.00 MWD NELLHEAO = FMC >CTUATOR= OTIS <B. ELEV = 74.47' 3F. ELEV = 45.07' <OP = 3196' Flax Angle = 130 @ 10,076' )atum MD = 9660' )atum TV D = 8800' SS DRL~ ~ r=T 13-3/8" CSG, 72#, L-80, ID = 12.347" I 2678' Minimum ID = 2.441" @ 9417' 3-1 /2" X 2-718" XO PERFORATION SUMMARY REF LOG: SWS-MCNL/GR/CCL run 09/20/2008 ANGLE AT TOP PERF: 46 @ 9640' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9640 - 9665 O 09/21 /08 2" 6 9940 - 9950 O 09/21/08 2" 4 9965 - 9995 O 09!21 /08 TOP OF 7" LNR ~-{ 8091' ITOPOF WHIPSTOCK ~ 8277' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8277' MILLOUT WINDOW 8277' - 8293' ' 4-1/2" TBG, 12.6#, 13Cr, .0152 bpf, ID = 3.958" I-~ 91 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~~ 9242' N-14B 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" I--I 9405' ~ 4 1/2" monobore w hipstock 9467' 4 1/2" CIBP l 9500' PBTD 9875' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.953" 9959' S~ NOTES:*'`'` Chrome Tubing *** 2012' ~~ 4-1 /2" HES SSSV NIP, ID = 3.813" (;AS I IFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3286 3282 13 MMG DMY RK 0 09/08/08 5 4028 3977 26 MMG DMY RK 0 09/06/08 4 5778 5508 34 MMG DMY RK 0 09/06/08 3 7317 6794 31 MMG DMY RK 0 09/06/08 2 8144 7512 29 KBG DMY BK 0 09/06/08 1 8969 8247 25 KBG DMY BK 0 09/06/08 8091' ~ 9-5/8" X 7" BKR ZXP PKR/HGR, ID = 6.331" I 9037' -14-1/2" HES X NIP, ID = 3.813" 9057' 7" X 4-1 /2" BKR 9Cr PKR, ID = 3.875" 9081' 4-1/2" HES X NIP, ID = 3.813" 9115' TOP 3-1/2" x 2-7/8" LNR, ID = 2.992" 9186' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9209' 4-1/2" HES X NIP, ID = 3.813" 9230' 4-1/2" HES XN NIP, ID = 3.75" 9242' 4-1/2"WLEG, ID=3.958" 9247' ELMD TT LOGGED 07/08/98 923T 7" X 5" BKR ZXP PKR HGR, ID = 4.375" 9416' 3-1/2" x 2-7/8" XO, ID = 2.441" PBTD 10085 I 3-1/2" 13Cr x 2-7/8" 13Cr Liner, Cemented ~ Perf'd ~~ 10123' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/26/81 ORIGINAL COMPLETION 09/28/08 TLH CORRECTIONS 07/09/98 SIDETRACKCOMPLETION 03/08/02 RN/TP CORRECTIONS 11/10/02 CAO/KK SET WRP 09121/08 NORDIC2 RWO + CTD SIDETRACK (N-14B PRUDHOE BAY UNfT WELL: N-14B PERMIT No: 1972110 API No: 50-029-20594-01-02 SEC 8, T11 N, R13E, 3917' SNL & 4731' WEL '~-`~ SARAH PALIN, GOVERNOR CO1~SL8Q~ A,lIOH ^ ~~a *~ 333 W 7th AVENUE, SUITE 100 i`-7 i ii t.,.~~~`~~.~~iiil~~'iiliii----777 iol` ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sean McLaughlin CT Drilling Engineer BP Exploration Alaska Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU N-14B BP Exploration Alaska Inc. Permit No: 208-080 Surface Location: 3917' FNL, 4731' FEL, SEC. 08, T11N, R13E, UM Bottomhole Location: 1774' FNL, 3036' FEL, SEC. 08, T11N, R13E, UM Dear Mr. McLaughlin: 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 iri accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. f Chair S DATED this ~ ~ day of May, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N PERMIT TO DRILL 20 AAC 25.005 ~~~~ MAY 1 6 2008 nla~ka ®if & Gas Cans. Commission 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pro~kls3bage ^ Coatbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU N-14B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10131' TVD 8675'ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 3917' FNL 4731' FEL SEC 08 T11 N R13E UM 7. Property Designation: ADL 028282 Pool , , . , , , Top of Productive Horizon: 1478' FNL, 3383' FEL, SEC. 08, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 15, 2008 Total Depth: 1774' FNL, 3036' FEL, SEC. 08, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 22,600' 4b. Location of Well (State Base Plane Coordinates): Surface: x-634410 y-5967267 Zone-ASP4 10. KB Elevation (Height above GL): 74.47' feet 15. Distance to Nearest Well Within Pool: 1,235' 16. Deviated Wells: Kickoff Depth: g470~ feet Maximum Hole An le: 139 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3220 Surface: 2340 18. Casin P " ram: S ecifi lion To -' ttn D th -Bo ttom n i of G m nt c.f. r sa k Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" s-vz° Xza,e° 9,3/# / 6.5# 13Cr80 STL 1010' 9120' 8309'ss 10131' 8675'ss 56 cu ft Class'G' 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Reentry Operations) Total Depth MD (ft): 9960' Total Depth TVD (ft): 9151' Plugs (measured): 9320' Effective Depth MD (ft): 9875' Effective Depth TVD (ft): 9073' Junk (measured): None asing Length ; ize Cement Volume M D Conductor /Structural 11 2 " x 30" 8 cu ds C ncre 110' 110' Surface 2678' 13-3/8" 3720 cu ft Permafrost II 2678' 2678' Intermediate 8277' 9-5/8" 1300 cu ft Class'G' 130 cu ft PF'C' 8277' 7629' Pro i n Liner 1315' 7" 331 cu ft Class 'G' 8091' - 9406' 7466' - 8642' Liner 722' 4-1/2" 101 cu ft Class'G' 9237' - 9959' 8489' - 9150' Perforation Depth MD (ft): 9598' - 9652' Perforation Depth TVD (ft): 8818' - 8868' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Sean McLaughlin, 564-4387 Printed Name Sean McLaughlin Title CT Drilling Engineer Preparetl By Name/Number: Si nature ~ Phone 564-4387 Date S~I S p ~ Terrie Hubble, 564-4628 Commission Uae Onl Permit To Drill Number: 0?08~~ API Number: 50-029-20594-02-00 Permit Approv I Date: See cover letter for other re uirements 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: 1 Samples Req'd: ~ Yes ~ No Mud Log Req'd: Yes LU No ~~ ®^ ,~ ~S HZS Measures: Yes ^ No Directional Survey Req'd: Yes ^ No Other: U f~S ~ ~Q ~ ~~ f ~ Date APPROVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate BP Prudhoe Bay N-14B CTD Sidetrac CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin on June 15, 2008) 1. O CMIT-TxIA Passed 03/01/08 2. O Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC. 3. S Pull IBP from 9320' 4. S Run Dummy whipstock drift to 9550' . 5. E Set 4-1/2" CIBP at 9500'; CMIT TxIA 3500 psi 6. E Jet cut @ 9145', in the middle of lst full joint above the packer (Ref: 23-JUN-98 tubing summary). 7. F Circulate bullhead seawater thru the cut. Bleed WHP's to 0 psi. 8. W PT MV, SV, WV 9. O Blind and bleed lines, remove well house, level pad Rig Work: (scheduled to begin on August 15, 2008) 1. MIRU, Set TWC, ND Tree, NU BOPE and test BOPE to 250 psi low and 3500 psi high. 2. Pu114-1/2" L-80 tubing 3. Replace 9-5/8" packoffs ~~ C 4. Run 4-1/2" Chrome completion ~~~ \ 5. Pull ball and rod and RHC plug 6. Dummy whipstock drift 7. Set Baker 4.5" monobore WS w LS orientation @ 9467' 8. Mi113.80" window with KOP at 9467' and 10' of rathole. Swap the well to Flo-Pro. 9. Drill Build: 4.125" OH, 343' (42 deg/100 planned) to a depth of 9810' MD. 10. Drill Lateral: 4.125" OH, 320' (12 deg/100 planned) to a depth of 10130' MD. 11. Run 3-1/2" x 2-7/8" chrome solid liner leaving TOL at 9120' 12. Pump primary cement leaving TOC at 9120', 10 bbls of 15.8 ppg liner cmt planned 13. Cleanout liner and MCNL/GR/CCL log 14. Test liner lap to 2000 psi, run LTP if needed. 15. Perforate liner per asset instructions 0300') 16. Freeze protect well, install BPV, and RDMO Post-Rig Work: 1. Remove BPV. 2. Re-install wellhouse and FL's. 3. Test separator 0300' of perfs) Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 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: 4-1/8" Casing Program: fully cemented liner • 3-1/2", 13CR-80 9.3# STL 9120' and - 9467' and • 2-7/8", 13CR-80 6.5# ~ 9467'md - 10130'md i • A minimum of 10 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9120' 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. Max. planned hole angle is 139 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 22600 ft. • Distance to nearest well within pool - 1235 ft. (N-OlA) Anti-Collision • No issues Logging • MWD directional, Gamma Ray, and Resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on N Pad is 220 ppm. • Lost circulation risk is low. Reservoir Pressure • The max res. press. is estimated to be 3220 psi at 8800'ss (7.1 ppg EMW). • Max. surface pressure with gas (0.10 psi/ft) to surface is 2340 psi. TREE = 6" CNV WELLHEA©= FMC ACTUATOR = OTIS KB. ELEV = 74.47' BF. ELEV = 45.07' KOP = 3196' Max Angle = 35 @ 5896' Datum MD = 9660' Datum TV D = 8800' SS S NOTES:*** LOST WRP SLIP & 2" X 1" X • N -14A ENT (9,4,05,*** 4-1/2" HES SSSV NIP, ID = 3.813" 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2678' Minimum ID = 3.725" @ 9230' 4-112" HES XN NIPPLE TOP OF 7" LNR 8091' PERFORATION SUMMARY REF LOG: SWS-BRCS ON 06/18/81 ANGLE AT TOP PERF: 23 @ 9598' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9598 - 9602 C 07/25/00 2-7/8" 6 9604 - 9613 C 07/25/00 2-7/8" 4 9616 - 9629 C 06/12/00 2-7/8" 4 9632 - 9652 C 06/12/00 9-5/8" CSG, 47#, L-80, ID = 8.681" ~ 8277' TOP OF WHIPSTOCK ~BRIDGEPLUG H 8308' TOP OF CEMENT 9509' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT GATE 6 3265 3187 13 CAMCO RK 5 4034 3907 26 CAMCO RK 4 5799 5451 34 CAMCO RK 3 7311 6714 31 CAMCO RK 2 8146 7439 29 CAMCO BTM 1 8987 8189 25 CAMCO BTM 8091' 9-5/8" X 7" BKR ZXP PKR/HGR ID = 6.331" MILLOUT WINDOW 8277' - 8293' 9175' -~4-1/2" HES X NIP, ID = 3.813" i 9186' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" 9209' 4-1/2" HES X NIP, ID = 3.813" 9230' '-~4-1/2" HES XN NIP, ID = 3.72 9242' 4-1/2" WLEG, ID = 3.958 9247' -~MD TT LOGGED 07/08/98 9237' 7" X 5" BKR ZXP PKR HGR ID = 4.375" 9320' BKR IBP (09/06/05) 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~-j 9242' ~ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9405' PBTD 9875' 4-1/2" LNR 12.6#, L-80, .0152 bpf, ID = 3.953" I 9959' I DATE REV BY COMMENTS DATE REV BY COMMENTS 07/26181 OWGINAL COMPLETION 09/06/05 GJB/TLH WRP PULL®/IBP SET 07/09/98 SIDETRACKCOMPLETION 03/08/02 RN/TP CORRECTIONS 11/10/02 CAO/KK SET WRP 08/16/03 CMO/TLP KB ELEVATION 1£ MAX ANGLE 09/04/05 DAV/PJC SAFETY NOTE PRUDHOE BAY UNfT WELL: N-14A PERMfT No: 1972110 API No: 50-029-20594-01 SEC 8, T11 N, R13E, 3917' SNL & 4731' WEL BP Exploration (Alaska) TREE = 6" CNV WELLHEAD = FMC ACTUATOR = OTIS KB. ELEV = 74.47' BF. ELEV = 45.07' KOP = 3196' Max Angle = 35 @ 5896' Datum MD = 9660' Datum TVD = 8800' SS -14 B S/42~EMENT (9/4/OOST WRP SLIP & 2" X 1" X Proposed RWO/CTD Sidetrack O 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 2678• Minimum ID = 3.725" @ 9230' 4-112" HES XN NIPPLE PERFORATION SUMMARY REF LOG: SWS-BHCS ON 06/18/81 ANGLE AT TOP PERF: 23 @ 9598' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 9598 - 9602 C 07/25/00 2-7/8" 6 9604 - 9613 C 07/25/00 2-7/8" 4 9616 - 9629 C 06/12/00 2-7/8" 4 9632 - 9652 C 06/12/00 OF 7" LNR ~~ 8091' 2001' ~~4-1/2" X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3265 3187 13 CAMCO RK 5 4034 3907 26 CAMCO RK 4 5799 5451 34 CAMCO RK 3 7311 6714 31 CAMCO RK 2 8146 7439 29 CAMCO BTM 1 8987 8189 25 CAMCO BTM 8091' ~~ 9-5/8" X 7" BKR ZXP PKR/HGR, ID = 6.331" ITOPOF WHIPSTOCK I 8277' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8277' MILLOUT WINDOW 8277' - 8293' 9035' 4-1/2" HES X NIP, ID = 3.813" 9065' 7" )< 4-1/2" BKR S-3 PKR, ID = 3.875" 9095' 4-1/2" HES X NIP, ID = 3.813" 9120' I~TOP3-1/2" x 2-7/8" LINE 4-1/2" TBG, 12.6#, 13Cr, .0152 bpf, ID = 3.958" ~--~ 9145' I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9242' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" ~ 9405' 4 1/2" monobore w hipstock 9467' 4 1/2" CIBP 9500' PBTD 9875' 4-1 /2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.953" 9959' 9186' ~- 9209' -~ 7" X 4-1 /2" BKR S-3 PKR, ID = 3.875" I 4-1/2" HES X NIP, ID = 3.813" 9230' 4-1/2" HES XN NIP, ID milled to = 3.80" 9242' 4-1/2" WLEG, ID = 3.958" 9247' ELMD TT LOGGED 07/08/98 9237' 7" X 5" BKR ZXP PKR HGR, ID = 4.375" 9440' 3-1/2"' x 2-7/8" crossover ~~ ,_ 3-1/2" 13Cr x DATE REV BY COMMENTS DATE REV BY COMMENTS 07/26/81 ORIGINAL COMPLETION 09/06/05 GJB/TLH WRP PULLED / IBP SET 07/09/98 SIDETRACK COM PLETION 04/23/08 MSE PROPOSED CTD ST 03/08/02 RN/TP CORRECTIONS 11/10/02 CAO/KK SET WRP 08/16/03 CMO/TLP KB ELEVATION 8 MAX ANGLE 09/04/05 DAV/PJC SAFETY NOTE Cemented 8 P~erf'd ~-{ 10130' PRUDHOE BAY UNfr WELL: N-146 PERMIT No: API No: 50-029-20594-02 SEC 8, T11 N, R13E, 3917' SNL & 4731' WEL BP Exploration (Alaska) by ~ BP Alaska Baker Hughes INTEQ Planning Report INTEQ Company: $P Amoco Date: 5/9/2008 Time: 13:35:19 Page: 1 Field: Prudhoe Bay Co-ordinate(NE} Reference: Well: N-14, True North Site: PB N Pad Vertical (TVD) Reference: 74.47 74.5 Well: N-14 Section (VS}Reference: Well (O.OON,O.OOE,120. OOAzi) Wellpath: Plan 3, N-14B Survey Calculation Method! Minimum Curvature Db: Sybase 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 N Pad -_-- TR-11-13 ~ ~ UNITED STATES :North Sl ope ! Site Position: Northing: 5965420. 89 ft Latitude: 70 18 48.671 N From: Map Easting: 633404. 63 ft Longitude: 148 55 7.726 W ~ Position Uncertainty: 0.00 ft North Reference: True I Ground Level: 0.00 ft Grid Convergence: 1.02 deg Well: N-14 Slot Name: 14 N-14 ~ I Well Position: +N/-S 1828.10 ft Northing: 5967267. 00 ft Latitude: 70 19 6.650 N C +E/•W 1038.09 ft Easting : 634409. 99 ft Longitude: 148 54 37.435 W I Position Uncertainty: 0.00 ft Wellpath: Plan 3, N-14B Drilled From: N-14A 500292059402 Tie-on Depth: 9456.98 ft Current Datum: 74.47 Height 74. 47 ft Above System Datum: Mean Sea Level Magnetic Data: 5/9/2008 Field Strength: 57664 nT Declination: 23.14 deg Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 35.97 0.00 0.00 120.00 Plan: Plan #3 Date Composed: 5/9/2008 copy Mary's plan 3 Version: 3 Principal: Yes Tied-to: From: Definitive Path Targets Map' Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir- ft ft ft ft ft N-146 Polygon 74.47 2143.11 1418.72 5969435.00 635790.00 70 19 27.726 N 148 53 56.026 W -Polygon 1 74.47 2143.11 1418.72 5969435.00 635790.00 70 19 27.726 N 148 53 56.026 W -Polygon 2 74.47 2048..64 1667.09 5969345.00 636040.00 70 19 26.796 N 148 53 48.778 W -Polygon 3 74.47 2272.73 1721.11 5969570.00 636090.00 70 19 29.000 N 148 53 47.199 W -Polygon 4 74.47 2367.83 1437.75 5969660.00 635805.00 70 19 29.936 N 148 53 55.470 W ! N-146 Fault 1 74.47 2976.96 1103.57 5970263.00 635460.00 70 19 35.927 N 148 54 5.221 W j -Polygon 1 74.47 2976.96 1103.57 5970263.00 635460.00 70 19 35.927 N 148 54 5.221 W ! -Polygon 2 74.47 2564.81 2390.50 5969874.00 636754.00 70 19 31.871 N 148 53 27.658 W j N-14B Target 2 8749.47 2153.28 1688.96 5969450.00 636060.00 70 19 27.825 N 148 53 48.138 W !~ N-14B Target 1 8909.47 2303.01 1426.58 5969595.00 635795.00 70 19 29.298 N 148 53 55.796 W Annotation MD TVD ft ft_ ... _ - - - _ - _ __ _ 9456.98 8688.40 TIP - 9470.00 8700.26 KOP 9490.00 8718.63 End of 9 Deg/ 100' DLS 9730.00 8904.23 4 9810.00 8905.05 End of 42 Deg/100' DLS ~ 10131.01 0.00 TD _ _ ~ by ~ BP Alaska Baker Hu hes INTE Plannin Re ort g Q g P 1r-TEQ _Company: BP Amoco Field: Prudhoe Bay ,Site: PB N Pad We1L• N-14 Wel{path: Plan 3, N-146 Plan Section Information MD' Iucl Azim ft deg deg 9456.98 24.39 327.70 9470.00 24.19 327.70 9490.00 22.39 327.70 9730.00 78.41 147.70 9810.00 100.44 122.17 10131.01 138.96 122.17 VD ft 8688.40 8700.26 8718.63 8904.23 8905.05 8749.00 N/-S ft 2416.99 2421.51 2428.20 2344.75 2289.08 2143.41 Date: 5/9/2008 Time. - 13:35:19 Page: 2 Co-ordinate(NE) Reference: Well: N-14, True North Vertical (TVI)1Reference: 74.47 74.5 Section (VS}:Reference: Well (O.OON,O.OOE,120.OOAzi) Survey Calculation Niethodc Minimum Curvature Db: Sybase +FJ-W DLS Build Turn TFO Target ft degl100ft deg(100ft deg/100ft deg 1354.58 0.00 0.00 0.00 0.00 1351.72 1.54 -1.54 0.00 180.00 1347.49 9.00 -9.00 0.00 180.00 1400.25 42.00 23.34 75.00 180.00 1456.10 42.00 27.53 -31.92 310.00 1687.73 12.00 12.00 0.00 0.00 Survey MD Incl Aztm SS TVD N!S E!W MapN MapE DLS VS TFO Tool ft deg deg ft ft h ft ft deg/1,t10ft ft deg 9456.98 24.39 327.70 8613.93 2416.99 1354.58 5969707.66 635720.98 0.00 -35.39 0.00 MWD 9470.00 24.19 327.70 8625.79 2421.51 1351.72 5969712.14 635718.03 1.54 -40.13 180.00 MWD 9475.00 23.74 327.70 8630.36 2423.23 1350.63 5969713.83 635716.92 9.00 -41.93 180.00 MWD i 9490.00 22.39 327.70 8644.16 2428.20 1347.49 5969718.74 635713.69 9.00 -47.13 180.00 MWD 9500.00 18.19 327.70 8653.54 2431.13 1345.64 5969721.64 635711.79 42.00 -50.20 180.00 MWD ~ 9522.10 8.91 327.70 8675.00 2435.50 1342.88 5969725.96 635708.94 42.00 -54.78 180.00 N-14 a 9525.00 7.69 327.70 8677.87 2435.85 1342.65 5969726.31 635708.71 42.00 -55.15 180.00 MWD 9550.00 2.81 147.70 8702.81 2436.75 1342.09 5969727.20 635708.13 42.00 -56.09 180.00 MWD 9575.00 13.31 147.70 8727.53 2433.79 1343.96 5969724.27 635710.05 42.00 -53.00 0.00 MWD 9600.00 23.81 147.70 8751.20 2427.08 1348.20 5969717.63 635714.42 42.00 -45.96 0.00 MWD 9625.00 34.31 147.70 8773.02 2416.83 1354.68 5969707.50 635721.08 42.00 -35.22 0.00 MWD 9650.00 44.81 147.70 8792.27 2403.39 1363.18 5969694.22 635729.82 42.00 -21.15 0.00 MWD 9675.00 55.31 147.70 8808.29 2387.21 1373.41 5969678.23 635740.33 42.00 -4.20 0.00 MWD 9700.00 65.81 147.70 8820.57 2368.83 1385.02 5969660.06 635752.27 42.00 15.05 0.00 MWD i 9725.00 76.31 147.70 8828.67 2348.87 1397.64 5969640.33 635765.25 42.00 35.96 0.00 MWD 9730.00 78.41 147.70 8829.76 2344.75 1400.25 5969636.26 635767.93 42.00 40.28 0.00 MWD I 9750.00 83.87 141.24 8832.84 2328.69 1411.73 5969620.40 635779.69 42.00 58.25 310.00 MWD ~ 9775.00 90.80 133.33 8834.01 2310.37 1428.65 5969602.39 635796.94 42.00 82.06 311.00 MWD 9800.00 97.71 125.40 8832.15 2294.57 1447.89 5969586.94 635816.46 42.00 106.63 311.37 MWD! 9810.00 100.44 122.17 8830.58 2289.08 1456.10 5969581.60 635824.76 42.00 116.48 310.78 MWD 9825.00 102.24 122.17 8827.63 2281.25 1468.55 5969574.00 635837.35 12.00 131.17 0.00 MWD 9850.00 105.24 122.17 8821.69 2268.32 1489.10 5969561.44 635858.13 12.00 155.44 0.00 MWD 9875.00 108.24 122.17 8814.50 2255.58 1509.37 5969549.06 635878.61 12.00 179.36 0.00 MWD 9900.00 111.24 122.17 8806.06 2243.05 1529.28 5969536.90 635898.75 12.00 202.87 0.00 MWD 9925.00 114.24 122.17 8796.40 2230.78 1548.80 5969524.98 635918.48 12.00 225.91 0.00 MWD 9950.00 117.24 122.17 8785.54 2218.79 1567.86 5969513.33 635937.75 12.00 248.41 0.00 MWD 9975.00 120.24 122.17 8773.52 2207.12 1586.42 5969502.00 635956.51 12.00 270.32 0.00 MWD 10000.00 123.24 122.17 8760.38 2195.80 1604.41 5969491.00 635974.71 12.00 291.56 0.00 MWD 10025.00 126.24 122.17 8746.13 2184.87 1621.80 5969480.38 635992.29 12.00 312.09 0.00 MWD 10050.00 129.24 122.17 8730.83 2174.34 1638.54 5969470.16 636009.21 12.00 331.84 0.00 MWD 10075.00 132.24 122.17 8714.52 2164.26 1654.57 5969460.37 636025.42 12.00 350.77 0.00 MWD ; 10100.00 135.24 122.17 8697.24 2154.64 1669.86 5969451.03 636040.88 12.00 368.82 0.00 MWD 10125.00 138.24 122.17 8679.04 2145.52 1684.36 5969442.17 636055.54 12.00 385.94 0.00 MWD 10131.01 138.96 122.17 8674.53 2143.41 1687.73 5969440.11 636058.94 12.00 389.91 0.00 3.5" ' - - LEGEND N-141`N-14) c na , n"u`N'«nn''r~,• a1 BP Alaska ~~~ - - N-14 (N-/4A) c ~u _ - o.. BAK lR - PIaD3 N-14B M ~xtiann ~ WEWATM DETAILS FI4n 1, N-1N H~ ~~ (`1 by Plan q3 /cesa An~.: S Sbe l~ i i omen mlo C rm alsoBn MCnaelw ~ 300333053403 .a N-,.. Tb MD WSS W 4 I N"f l:(~ e W ~Bm E 1~. 198)1 Y 11 m lf~OS]0®ww wm ~ on : . RI3: MerMC 3 M,. Dv,m: )4.11 T4.4TR VA4c,l a OrI313n dlyln Slvrli~rp Arp IUU ~E(-W From TVD ]eau M1F,4 14,M. ~. .. . ;_ _ ~' 1~T 1 _ - .._ _ ~ I T f ~ I I I -. _+ .. I ,30.00' 33s] - I I I~ I I \~~ ,, ~~pp pp~~~~,, ~DDD. ppII ,, _ __ .. _ , 1 I ' T• ' ~..1 f 1 1 ~ f I 1 ~ I. • REFERENCE NFORMR OH za ~ _.. ~ ~ -i ~ {- - - - -• T 1 l . _. _ ~ i ~ _ . LOON rwte N/E Refe W C N 14, True Norm ~ ~ _ ' l- Varuca ( D Reler S - nSea LavN ( O63E1 ~ 0 l 1 ~ ~ 1 _ _ _ f_ ._ ~_ i _ _ - Meas 0 ep l i Refer M T umLa ~~ a oe M nm ,,m anawre ~ _I- ~ f - ~ T ~ t - - I, I + I - i _ ~ I I I : i f i # i f fI C T T ~~ ~ SFeneN INrtARS Ss r r Ar 'tvD .sR wa oy n, M3. *~ I I { -. ~. 'i 1 . I :. .. 1 _ '~ _ ,._ '~ . ~- .. t ... ~ ~. ~ _ _ ~ I . I , FnW".aFF ia,i mn sw°aia,: s ma3 SwY14N i n'i W i3a~i3 i was >o _ _. f _ I ~ .. ; .. ~ . 4 r,~a33,3w ,nn ,43x,3 i,ssi, .aas ,a,T Fnut M4~aA1 ,RRr.n ,R~i3 r' a „w Aw i / :. . . y y F ii ~ ~ ~ _ •.. ' .. ~ + _ . . T - . . ~ ~ . 5 - f i-- .. N-, w r. ~ .1 . _ - - . . f ANNOUnowa rnlacET DETn is ado- ' ~ i . \ ~- - . . -i .. Tv0 N0 A.rw/.rwr, e3,a e3 vase ve TP Name VD N S C 5 ~~ ~ • __ r . \ ~ ~ e335.)9 w]000 BE•ONPOIV OeV,OD DLi 30aa.,e O 0 00 N148 Pd 008 2 3. 8.2 v~ NIaB Fau 11 0.00 29]698 03.5] Pd N14B TaryH2 SB 500 2 8328 168098 Pant ~vw~ 7 1 - i + i + ..._.._ ~. .. \ ~ 1 .\ \ - 1 ~ r' i -. . ~ - T . 4 et 430+ytar 0Y !0063 SN000 7 rgelt 8835011 2303.01 1428.50 Panl N14B Ta .. ~. ~ I \ .. 0 lM],Otlt O, 1 . I' I _ I I .... w I - + + ~- , f F } t~ 1 1 t t ... I .. ._ t t qq I •_~ '. I" _. I I I{ I I ~ I i f ! a5] _... .. .. , __ _ f ~ t t ~ .. !: r I t it _ _ _ _. ~ ~ i L ~ ~. - x, _ ,. _ . ~. (~. seu , '. f it f 1 N..3r 7.. ,.1 I T I i __ _ ~ I \ r I ~' ' a3aa .. . '~ I y. . 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SO S oo 6zo 3.3 SSO .aa by ~ BP Alaska Anticollision Re ort P 1NTEQ Company: BP Amoco Date: 5/9!2008 Time: 14:18:06 _ Page: 1 Field: Prudhoe Bay Reference Site: PB N Pad Co-ordinate(NE) Reference: Well: N-1 4, True North Reference Well: N-14 Vertical (TVD) Reference: 74.47 74. 5 Reference Wellpath: P{an 3, N-14B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are 1)ndls in this fiBh7lCi pal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSAEIIipse Depth Range: 9456.98 to 10131.0 1 ft Scan Method: Trav Cylinder North Ma:dmum Radius: 1209.50 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 5/9/2008 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 90.07 8195.80 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro multishot 8290.00 9456.98 2 : MW D -Standard (8290.00-99 MWD MWD -Standard 9456.98 10131.01 Planned: Plan #3 V3 MWD MWD - Standard Casing Points MD TVD .Diameter Hole Size Name ft ft in in 10131.01 8749.00 3.500 4.125 3.5" - -- Summary _ <------------- ------ Offset Wellpath ----------------------> Reference Offset Ctr-Ctr No-Go Allowable - -- -- -- Site Well Wellpath MD MD Distance Area Deviation Warning i~ - _ ft ft ft ft ft PB NPad . _ N-01 N-O1A V4 _.. 9743.58 9750.59 1127.37 151.94 .. _i 975.42 ..- Pass Major Risk PB N Pad N-04A N-04A V1 Out of range PB N Pad N-14 N-14 V4 10067.64 9650.00 284.70 206.04 78.66 Pass: Major Risk PB N Pad N-14 N-14A V1 9524.01 9525.00 5.38 624.14 -618.75 FAIL: Major Risk PB N Pad N-17 N-17 V1 9550.00 9025.00 1060.96 466.26 594.70 Pass: Major Risk PB N Pad N-20A N-20A V7 Out of range PB N Pad N-20 N-20 Vi Out of range PB N Pad Plan UZI#1 Plan UZI# 1 VO Plan: UZ Out of range Site: PB N Pad Well: N-01 Rule Assigned: Major Risk Wellpath: N-01 A V4 Inter-Site Error: 0.00 ft ', Reference Offset Semi-Major Aaris Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9750.00 8907.31 9650.00 8939.21 29.88 7.71 232.81 91.57 4.500 1204.56 139.26 1065.30 Pass 9750.00 8907.31 9675.00 8949.41 29.88 7.73 233.38 92.15 4.500 1185.11 139.64 1045.48 Pass 9746.26 8906.88 9700.00 8959.60 32.32 7.81 235.04 92.61 4.500 1165.79 146.33 1019.47 Pass 9744.95 8906.71 9725.00 8969.80 33.19 7.88 236.03 93.18 4.500 1146.69 149.06 997.63 Pass 9743.61 8906.54 9750.00 8980.00 34.06 7.96 237.05 93.77 4.500 1127.81 151.88 975.93 Pass 9743.58 8906.53 9750.59 8980.24 34.08 7.97 237.08 93.78 4.500 1127.37 151.94 975.42 Pass Site: PB N Pad Well: N-14 Rule Assigned: Major Risk Wellpath: N-14 V4 Inter-Site Error: 0.00 ft Reference Offset' Semi-Major Axis Ctr-Gtr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warnfng ft ft ft ft - ft ft deg deg in ft ft ft - 10118.28 8758.48 9550.00 8800.09 78.36 97.32 16.77 254.61 231.70 __ 132.13 _ -- 99.57 Pass 10104.37 8768.59 9575.00 8824.09 76.29 95.02 13.10 250.93 243.43 152.45 90.98 Pass 10091.34 8777.80 9600.00 8848.08 74.28 92.80 9.68 247.51 256.25 172.39 83.86 Pass 10079.12 8786.21 9625.00 8872.09 72.37 90.67 6.51 244.35 270.03 190.38 79.66 Pass 10067.64 8793.89 9650.00 8896.10 70.52 88.62 3.59 241.43 284.70 206.04 78.66 Pass 10056.86 8800.93 9675.00 8920.13 68.75 86.65 0.91 238.74 300.16 219.28 80.88 Pass 10046.70 8807.38 9700.00 8944.18 67.07 84.77 358.44 236.28 316.36 230.40 85.96 Pass 10037.13 8813.31 9725.00 8968.24 65.44 82.97 356.18 234.01 333.19 239.39 93.80 Pass 10028.07 8818.78 9750.00 8992.32 63.89 81.24 354.10 231.93 350.59 246.72 103.88 Pass 10019.50 8823.83 9775.00 9016.42 62.40 79.58 352.18 230.02 368.51 252.53 115.98 Pass easurements are i Cn of bag Dowel I bttm of bag BAG H-14B middle of slips Blind/Shears TOTs middle of pipes 2 3/8" combi ram/slips ~ ~ Mud Cross I I Mud Cross of flow cross of blind/shears variable bore wipe 3 1/2"-2 7/8" TOTs of pipe/slips 2 3/8" combi ram/slips wab Valve Flow Tee 6050000 6000000 5950000 5900000 5850000 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 400000 500000 600000 700000 800000 ~~ Alaska Department of Natural Resources Land Administration System Page 1 of~12 .z ry~~ ' ~':' ~?r'_C ''.~ .. ~ 3`U. F'2f5 RECttrd@€'`~ .~i°t~tt,il ~~i~r'~te ~8E7if1S ~~~ "~lIC€~S ..... Alaska DNR Cas+~ Summary File Type: ADL File Number: 28282 ', ~ Printable Case File_Surnmary See Township, Range, Section and Acreage? ~f ~~' Yes ~`'' No y New Search I_ AS Menu ~ Case Abstract ~ Case Detail ~ Land Abstract Filc: AUL 282H2 '~``'-'~' Search fir Status Plat Updates 1s „I (l~ 1 ~N~O(lti Cus7orner: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case type: °~~4 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Statars: 35 ISSUED Statass Date: 08/19/1965 Total Acres: 2469.000 Date Initiated: 05/28/1965 Office of Prinurrv Respotrsibility: DOG DIV OIL AND GAS bust Transaction Date: 12/04/2006 Case Subtype: NORTH SLOPE Las? Transaction: AA-NRB ASSIGNMENT APPROVED Nfe~•iclian: U 7n tirn ~~~zip: (1 I l N Range: 013 } ,~'~>c~rion: 0'S Seet'ion ,1 ~ r~~s: 6~0 Search i~lat~ Nleridiar~: U Iuli n~/rip: (11 I N Runge: (1(3E S~~cliurr ~ 06 Sec~tiujr .1 c~re~~: ~9 Meric~ian.~ l_I Iutiti~~~sl~~ij~: 01 1 N Run,~cr.~ OI3E Sc'c~iwr.~ 07 Section :Icre~~: 596 Meridian: L! 7~~~rns{~r~~: OIIN Rune-: 01.3E Sc'~~tiu~t_ 08 Secunn:]cre~s: 6~C1 Legal Description 05-28-196 * * *SALE NOTICE LEGAL DE.SCRIPTION~ * ~` C1~-93TIIN-RISE-UM~,6,7,82~169.00 0-?-01-197? * * * * * ~ UNITIZED AND LEASE L EGAL DESCRIPTION * * * * * * * * * * ~` ENTIRE LE~~ISF COIti1NtITTEI) TO.~'RUDIIOE BAY UNIT PRUDHOE SAY UNIT http://www. dnr. state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=282 82&... 5/ 19/2008 Alaska Department of Natural Resources Land Administration System Page 2 of~ a. • TRACT 4h T. 11 N., R. 13 E., UMIAT MERIDIAN, ALASKA SECTION ~: ALL, 640 ACRES; SECTION 6: ALL, 593 ACRES; SECTION 7.~ ALL, 596 ACRES; SECTION 8: AI,L, 640 _ACRES; CONTAINING ?, 469.00 ACRES MORE OR LESS. 0=1-01-19?7 ****PARTICIPATINGAREA LEASE LEGAL DECRIPTION ~*****~~*** ENTIRE LF,ASE COMMITTED TO OIL RIMAND GAS C'AP PA'S PRUDHOE BAY UNIT OIL RIMAND GAS CAP PARTICIPATING AREAS TRACT 46 T. 11 N., R. 13 E., UMIAT MERIDIAN, ALASKA SECTION ~: ALL, 640 ACRES, SECTION 6: ALL, X93 ACRES; SECTION 7: ALL, 596 ACRF,S: SECTION 8: ALL, 640 ACRES; CONTAINING 2, 469.00 ACRES MORE OR LESS. II-01-1999 ****PARTICIPATINGAREA LEASE LEGAL DECRIPTION ********* LEASE INCORPORATED IN PART INTO INITIAL POLARIS PA PR UDIIOE BA Y UNIT POLARISPAXTICIPATING AREA TRACT 46 T. 11 ~?, R 13 E., £IMIAT MERIL~E~tN, ALASKA SECTION 6:• FRACT~ONAG, W~2, .SE;'-~, S/2NE;'4, NW/4NE/4, AS PROTRACTED http: //www. dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28282&... 5/ 19/2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~u i/ /~~ PTD# a?O~O~Oo / Developmen~t~ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: f ~~/~od- /~A y POOL: f ~d~i~,~oE' ~AY ~ p~_ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well - -~ (If last two digits in permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed mejhane is not allowed for (name of weU) until after (Company Narae) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. !Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 / 112008 WELL PERMIT CHECKLIST Field 8 Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT N-146 Program DEV Well bare seg ^ PTD#:2080800 Company BP EXPLORATION (ALASiCP) INC Initial ClassiType DEV I PEND GeoArea 890 Unit 11650 On1Off Shore Qn Annular Disposal ^ Administration 1 Petmitfeeaitached ------ -- - -- -- -- -- - - NA - - - -- -- ------ - ------ - ---- - -------- 2 Lease numberappropnate- -------- -- ---- --------Yes- ----- -- -- - -- -- - ------------------------------------ 3 Unique well4ameandnumber_-------------------------- __- -Yes- -------------------------_-- -- 4 Well located in a_definedpool__________________-______-__ --________Yes_ _____-PrudhoeBaylPrudhoe Bay lvishak._______-_-_-_----_---__--_-_----------___ 5 Well located proper distance from drilling unitboundsry- - - - - - - - - - - - - - - - - - - - _ Yes _ - _ - - - _ - - _ --------------------------------------------------------------- 6 Well locatedpcoperdistancef[omotherwells___-__-________._ ___-____Yes_ --__-_________.__----_ 7 Sufficient acreageayaileblein_dtiUinqun)t_____________________ __________Yes_ ______2560ACres._--__-__.---_______- 8 If deviated,is_wellboreplat_included_--------------------- ----------Yes- ----------------------- --------------------------------------------- 9 Ope[atotonlyaffeotedperb'-- ------ - - - ----- ------ -Yes- --------- -- - ------- - ----- - - ---- -- ---- - 10 Operaiotbas_appr_opriaiebondinforce_---_----------------- ------___Yes __-_-_BlanketBOnd#6194193.-_____--_--_---_---__-_- --------------------------- 11 PetmitcaDbeissuedwlthoutconservationprder_--_.------------ ------- --Yes- ---------------------------------------------------------------_-.---- Appr Date 12 Pe[mitcat~beissuedwitbouiadminisi[atiue_apP[oval--------------- ----------Yes- -------------------------..---.----------.------------.----..------------ ACS 5119!2008 13 Canpermdbeapprovedbefore15-day wait__.________________ __________Yes- ------------------------------------.--------------,-----------____-- 14 Well located within areaand_strataauthortzedby-InjectionO[de[#(put_1O#in_ comments)(For-_KA_ _-___________________________---------_--_-------------___-_------_-_ 15 AJlwells_withinll4_mileatea_ofteyiewidentified(Fo[sen!icewellonly)_____ __________ Nq _-____---__-___-__----------_--_---_---_-___-----_----.-_----_.___-- 16 Pte-produced injector; duration of preproduction less than3months-(Forserviceweltonly)-_NA_ _____---_----------------_--__---_---__-__--__--_____---_.._--_______ 17 Nonconven,gasconformstoA$31.05,03QQ.1.A),Q.2.A-D) ------ -- -------- NO-- - ------- -- ---- - - -- ------ - ------ --- - ----- Engineering 18 Conductor string-provided----------------___-_----.---- ------_---- -- _--_-- ortuctorsetmN-14(181.0$4),______-_,___---_-_-__-_- ---------------------- 19 Surfacecagingprotectsall_knownlJSDWS_.__________________ ___________NA-- ------Allaqurfersexempted,-AEO1.------------------------------------------------ 20 CM-T vol adequate tg circulate on conductor & surf-csg - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ _ _ _ _ _ -Surface casing set in N-14.- - _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - 21 CMTvoladequate_totie-iniQngstripgtosurfcsg------------------ -----------NA__ __-___Productian_casingsetin_N-14._-_.,.______--___--_---_------_------__-------___ 22 CMTwiIIGOyer_ailk~ownproduciivehorizons-------------------- ---- - ---Yes- ----.--------------------------------------------------------------____-- 23 Casingdes~nsadequatefarG,T,13&-patina!cost----------------- ---___---Yes- ------.-.---------------------------------,-----------------------_----- 24 Adequ2te fiankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - - - _ Rig equipped with steel pits. Noteserve pit planned.- All waste_to approved disposalwell(s)! - - - - - - - - _ - - . _ 25 Ifa_re-dtill,has_a10-403 for abandonroentl~eenappraved------------ ----------Yes- ------308-184-------------------------------------------------------------- 26 Adequate welliZOre separationproposed - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - _ _ - _ Proximity analysis performed, Nearest segment is Ps;<Aportion Qf N-1.4A and paths-diverge,- _ _ - _ _ _ _ _ , - _ - 27 If dive[tertequir$d,dtZesitmeetregulati9ns_.__-._------------- -_--_---_ NA__ ______BQPStaok-willal[eady_beinplace,______-______---_---_------.-__-----------_--_- pppr Date 28 Drilling ilujd-program schemattc_$ equip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes Maximum expected formation pressure 7,1_EMW, Planned MW 6.6-ppg.- _ _ - - _ _ _ _ _ - - - - - - - - - - _ - - _ - TEM 5/2012008 29 BOPEs,-dotheymeetregulation- -- -- --- ------ - -- -- Yes- -- --- --- -- -- ---- --- ---- -- - - ----- ~ 30 BOPE_press rating app[opriate; test to_(put psig in comments)- - - - - Yes - - MASP calculated x12340 psi. 3500_psi-6OP testplanned- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - , 31 Choke_manifokicomplieswlAPl_RP-53(May$4)__________________ __________Yes_ ________--___-__--_.-____-____--_____ 32 Work will occurwkhoutoperaiionshutdown_________________ __________Yes- -------------------------------------------------------------_ __-- 33 Is presence of H2S gas probable- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes - - _ _ - - _ H2S is teported_at N_pad._Mud-should preclude_H2S on rig._ Rig has sensors and_alarms._ - - - - _ - - 34 -NtechanicalcondiiionofwellswithinAQRyerified(Fgrservicewellonly}_-_- _-______ NA__ --.___---_------------------_.__---_---____--------------_-_ Geology 35 Petm$can be issued w!o hydrogen_sulfideineasures _ - - _ _ - - - _ - - -No_ _ _ - - - - _ Max H2S_Qn_N pad-is 220_ppm, _ _ _ _ _ _ _ - 36 Data-presented onpoterrtialcverpressurezones----------------- ---_---_--Yes- -------------------------------------- -- ----------------------------- Appr Date 37 Seismic analysis 4f shallowgas_zones---------------------_ _-____-_-_ NA-_ __--___-_ ---------------------------------------------------------------- ACS 5119!2008 38 Seattedconditionsurvey_(ffoff_-shore)____.__.___---_--_--- ----------- NA__ _______--_ 39 Contact name/phone for weekly_progress reports [exploratory onlyj _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ _ Sean McLaughlin--_5$4.4387._ - _ _ _ _ - - - _ - - - _ - - - - _ - - - - - - - - - - - - - - _ - - _ - - - - _ Geologic Engineering Public Commissioner: Date: Coin issionef : Date Co Daie `/ '~V ~ f% i • Welt 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. r: tapescan.txt **** REEL HEADER **** MWD 09/01/27 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/09/18 2165765 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. N0: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9462.0000: Starting De th STOP.FT 10117.5000: Ending Dept h STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: N-14B FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 6.650"N 148 deg 54' 37.435"w CNTY. COUNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 18 Sep 2008 API API NUMBER: 500292059402 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 08 TOWN.N T11N . RANG. R13E , PDAT. MSL EPD .F 0 LMF DF FAPD.F 74.47 . DMF DF EKB .F 0 EDF .F 74.47 EGL .F 0 Page 1 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 BUU~~'~ C~~' ~ ~~~i C~ tapescan.txt CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVD55) 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 lob 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 20 Sep 2008 per Roger Sels with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from N-14A through a milled window in a 4 1/2 inch liner. Top of window 9467 ft.MD (8623.1 ft.TVDSS) Bottom of window 8476 ft.MD (8631.3 ft.TVDSS) (9) Tied to N-14A at 9457 feet MD (8613.9 feet TVDSS). (10) Run 3 was used to drill N-146P61. (11) The interval from 10082 feet to 10123 feet MD (8722.8 feet to 8696.0 feet TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROPJ4VG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (subsea). CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 9466.95, 9461.35, ! -5.59766 9471.93, 9467.16, ! -4.76758 9478.35, 9476.28, ! -2.07324 9486.64, 9484.36, ! -2.28027 9489.55, 9486.85, ! -2.69434 9499.7, 9497.21, ! -2.4873 9501.56, 9500.11, ! -1.45117 9507.16, 9504.67, ! -2.4873 9514.41, 9512.13, ! -2.28027 9517.73, 9514.41, ! -3.31738 9518.56, 9516.07, ! -2.4873 9519.6, 9517.11, ! -2.4873 9526.02, 9523.33, ! -2.69531 9527.68, 9524.99, ! -2.69531 9528.3, 9526.85, ! -1.45117 9534.31, 9531.41, ! -2.90137 9536.59, 9533.69, ! -2.90137 9540, 95 38.55, ! -1.45117 9545.81, 9543.53, ! -2.28027 9548.5, 9545.81, ! -2.69434 9550.58, 9547.88, ! -2.69434 9556.79, 9553.27, ! -3.52344 9562.18, 9559.7, ! -2.4873 9564.67, 9562.18, ! -2.48828 9567.37, 9564.05, ! -3.31641 Page 2 n 9569.23, 9566.54, 9572.34, 9569.23, 9573.79, 9571.1, 9575.04, 9572.34, 9578.15, 9575.45, 9580.22, 9577.11, 9584.15, 9581.04, 9587.05, 9584.98, 9590.58, 9587.47, 9592.86, 9590.16, 9599.9, 9597.21, 9603.01, 9600.53, 9605.09, 9602.39, 9609.02, 9606.12, 9612.34, 9610.48, 9620.05, 9617.77, 9622.33, 9620.47, 9625.03, 9622.54, 9629.59, 9626.89, 9632.7, 9630.42, 9636.43, 9633.53, 9649.9, 9647.62, 9653.63, 9650.94, 9657.37, 9654.67, 9672.29, 9669.8, 9696.59, 9693.27, 9708.4, 9706.33, 9719.39, 9716.9, 9737.83, 9735.96, 9741.35, 9739.28, 9754, 9751.51, 9758.15, 9756.07, 9761.05, 9758.56, 9766.23, 9763.74, 9810.32, 9805.96, 9814.88, 9811.77, 9819.44, 9815.5, 9827.94, 9824, 9832.08, 9828.35, 9863.48, 9861.2, 9875.71, 9872.18, 9897.67, 9894.77, 9911.98, 9909.07, 9920.48, 9915.5, 9928.56, 9924.41, 9932.91, 9930.63, 9934.99, 9932.91, 9938.92, 9936.85, 9944.56, 9942.08, 9947.47, 9944.36, 9949.95, 9947.88, 9956.59, 9953.68, 9959.7, 9956.79, 9961.35, 9958.87, 9964.88, 9961.77, 9972.96, 9969.02, 9977.73, 9972.34, tapescan.txt ! -2.69531 ! -3.10938 ! -2.69531 ! -2.69434 ! -2.69434 ! -3.10938 ! -3.10938 ! -2.07324 ! -3.10938 ! -2.69434 ! -2.69434 ! -2.4873 ! -2.69434 ! -2.90137 ! -1.86621 ! -2.28027 ! -1.86523 ! -2.4873 ! -2.69531 ! -2.28027 ! -2.90234 ! -2.28027 ! -2.69434 ! -2.69434 ! -2.48828 ! -3.31641 ! -2.07227 ! -2.4873 ! -1.86621 ! -2.07227 -2.4873 ! -2.07227 ! -2.4873 ! -2.4873 ! -4.35352 ! -3.10938 ! -3.93848 -3.93848 ! -3.73047 ! -2.28027 ! -3.52441 ! -2.90137 ! -2.90234 ! -4.97461 ! -4.14648 ! -2.28027 ! -2.07324 ! -2.07227 ! -2.4873 ! -3.10938 ! -2.07227 ! -2.90234 -2.90234 ! -2.4873 ! -3.10938 ! -3.93848 ! -5.38965 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 158 records... Page 3 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 tapescan.txt 10 bytes 132 bytes *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 20 Sep 2008 per Roger sels 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) Opticall Lod 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: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 37 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start De th = 9462.000000 Tape File End Depth = 10117.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet Page 4 • **** FILE TRAILER **** Tape Subfile: 2 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 tapescan.txt 50 records... 54 bytes 4124 bytes *** 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 Lod 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: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 73 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start De th = 9466.750000 Tape File End Depth = 10123.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet Page 5 • tapescan.txt **** FILE TRAILER **** Tape Subfile: 3 86 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/09/18 2165765 O1 **** REEL TRAILER **** MWD 09/01/27 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS D Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9462.0000 287.6000 -999.2500 0.0240 0.0840 0.1730 0.1840 9462.5000 287.4089 -999.2500 0.0326 0.0878 0.2284 0.2031 9500.0000 115.0291 13.0911 45.9221 86.5017 71.4659 63.9296 9600.0000 140.9722 69.6265 15.3883 18.3492 15.6868 13.8837 9700.0000 33.3398 83.8398 4.7747 5.2400 5.0922 5.1358 9800.0000 29.6771 45.6964 3.8953 4.7617 5.0091 5.9872 Page 6 tapescan.txt 9900.0000 41.3418 99.8667 13.6562 13.8371 10000.0000 36.0437 73.7000 31.1065 27.6628 10100.0000 -999.2500 96.6937 -999.2500 -999.2500 10117.5000 -999.2500 1428.0342 -999.2500 -999.2500 Tape File Start Depth = 9462.000000 Tape File End Dept h = 10117.500000 Tape File Level spacing = 0.500000 Tape File Depth units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RPD RPS 9466.7500 -999.2500 -999.2500 -999.2500 -999.2500 9467.0000 287.6000 -999.2500 0.1730 0.1840 9500.0000 205.5000 12.6000 57.0800 48.3090 9600.0000 52.5000 71.0000 18.1350 16.7260 9700.0000 34.4000 77.2000 5.3100 5.5460 9800.0000 25.5000 48.7000 5.5220 6.8770 9900.0000 38.8000 85.0000 11.8430 12.4450 10000.0000 44.9000 86.7000 32.1700 28.9530 10100.0000 -999.2500 92.1000 -999.2500 -999.2500 10123.0000 -999.2500 1423.2000 -999.2500 -999.2500 Tape File Start De th = 9466.750000 Tape File End Dept h = 10123.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet 0 Tape Subfile 4 is type: LIS 9.8793 27.1017 -999.2500 -999.2500 RAD -999.2500 0.0240 52.9960 16.2840 4.8290 4.0360 8.8560 27.2650 -999.2500 -999.2500 14.0841 40.3584 -999.2500 -999.2500 RAS -999.2500 0.0840 73.6690 20.2520 5.3370 5.1470 11.6180 39.1900 -999.2500 -999.2500 Page 7 CJ tapescan.txt **** REEL HEADER **** MWD 09/01/28 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/09/17 2165765 O1 3.0" CTK *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las n U version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: one line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 9446.0000: Starting De th STOP.FT 9619.0000: Ending Dept h STEP.FT 0.5000: Level spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: N-146PB1 FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 19' 6.650"N 148 deg 54' 37.435"w CNTY. COUNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 17 Sep 2008 API API NUMBER: 500292059470 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 08 TOWN.N T11N RANG. R13E PDAT. MSL EPD .F 0 LMF DF FAPD.F 74.47 DMF DF EKB .F 0 . EDF .F 74.47 EGL .F 0 . Page 1 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 • tapescan.txt CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (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 lob this well.. (6) Tools ran ~n 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 any depth shifting has been waived by Roger sels with BP Exploration (Alaska), Inc. (8) Tied to N-14A at 9457 feet MD (8613.9 feet TVDSS). (9) The sidetrack was drilled from N-14A through a milled window in a 4 1/2 inch liner. Top of window 9467 ft.MD (8623.1 ft.TVDSS) Bottom of window 9476 ft.MD (8631.3 ft.TVDSS) (10) The interval from 9579 feet to 19619 feet MD (8726.63 feet to 8759.85 feet TvDSS) was not logged due MNEMONICS GRAX ROP~VG RACHX RACLX ohm.m to sensor to bit offset -> Gamma Ray [MWD] (MWD -> Rate of Penetration, -> Resistivity (AT)(LS) -> Resistivity (AT)(LS) at well TD. -API units) feet/hour 2MHz-Compensated Borehole Corrected, ohm.m 400kHz-compensated Borehole corrected, RPCLX -> Resistivity (PD)(LS) 400kHz-Compensated Borehole Corrected, ohm.m RPCHX -> Resistivity (PD)(LS) 2MHz-Compensated Borehole Corrected, ohm.m TVD -> True vertical Depth (subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 Minimum record length: Maximum record length: **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and any depth shifting has been waived by Roger sels with BP Exploration (Alaska), Inc. 72 records... 14 bytes 132 bytes * FORMAT RECORD (TYPE# 64) Page 2 • tapescan.txt Data record type is: 0 Datum Frame Size is: 28 bytes Loging direction is down (value= 255) Optical Lod 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: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD Code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 10 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9446.000000 Tape File End Depth = 9619.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 2 23 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) Page 3 tapescan.txt Data record type is: 0 Datum Frame size is: 28 bytes Loggin 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: FRAME SPACE 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool 1 GR MWD 2 ROP MWD 3 RAD MWD 4 RAS MWD 5 RPD MWD 6 RPS MWD code samples units 68 1 AAPI 68 1 F/HR 68 1 OHMM 68 1 OHMM 68 1 OHMM 68 1 OHMM Total Data Records: 20 1 size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start De th = 9446.000000 Tape File End Depth = 9619.000000 Tape File Level spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape subfile: 3 33 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/09/17 2165765 O1 **** REEL TRAILER **** MWD 09/01/28 BHI • Page 4 tapescan.txt 01 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9446.0000 300.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9446.5000 298.7000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 221.2000 8.6000 3.5520 4.0890 4.6580 4.0720 9600.0000 -999.2500 66.8000 15.1410 25.6680 24.6750 25.5470 9619.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 9446.000000 Tape File End Depth = 9619.000000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet 0 Tape subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 9446.0000 300.6000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9446.2500 299.7000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 9500.0000 221.2000 8.6000 3.5520 4.0890 4.6580 4.0720 9600.0000 -999.2500 66.8000 15.1410 25.6680 24.6750 25.5470 9619.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 Page 5 U Tape File start Deppth Tape File End Depth Tape File Level Spacing Tape File Depth Units Tape Subfile 4 is type: LIS tapescan.txt = 9446.000000 = 9619.000000 = 0.250000 = feet Page 6 C~
