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210-034
7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU 01-22B Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 210-034 50-029-20848-02-00 11877 Surface Intermediate Liner Liner Liner 9044 2558 9809 494 1135 1663 10150 13-3/8" 9-5/8" 7" 3-1/2" 2-3/8" 8793 35 - 2593 33 - 9842 9544 - 10038 9198 - 10333 10214 - 11877 35 - 2593 33 - 8521 8263 - 8692 7975 - 8930 8847 - 9044 10276 , 11650 2670 4760 7020 11780 10150 , 10985 , 11650 5380 6870 8160 11200 10028 - 11839 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 x L-80 31 - 9606 8683 - 9042 Conductor 80 20" 36 - 116 36 - 116 1490 470 5-1/2" HES TNT Packer , 9039 , 7849 No SSSV 9039 7847 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY, PRUDHOE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028329 31 - 8316 228 855 20797 64706 4217 22 0 0 1002 967 N/A 13b. Pools active after work:PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 1:44 pm, Jul 17, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.07.17 10:45:23 -08'00' RBDMS JSB 071823 WCB 3-4-2024 DSR-7/19/23 ACTIVITYDATE SUMMARY 6/11/2023 ****WELL LEFT S/I ON ARRIVAL**** PULLED 4.56" DREAMCATCHER FROM X-NIP @ 9,704' MD DRIFTED 36' x 2" DUMMY GUNS & 2.80" SWEDGE TO 10,221' SLM ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 6/15/2023 ***WELL SHUT IN ON ARRIVAL*** (ADPERF) MIRU HES E-LINE PT PCE 300PSI LOW, 3000PSI HIGH CORRELATE TO SLB COIL FLAG 8-AUG-11 SET 3-1/2" NORTHERN SOLUTIONS CIBP AT 10,150' AND TEST 700PSI OVER WHP LAY DOWN AND SECURE WELL ***CONTINUE ON 16-JUN-23 WSR*** 6/15/2023 T/I/O= 2560/50/40 TFS unit 4 Assist E-Line to set a CIBP. Load the Tubing with 240 BBLS of crude. Pumped 4 BBLS of Crude to pressure test CIBP. E-Line in control of well upon departure. 6/16/2023 ***CONTINUED FROM 15-JUN-23 WSR*** CORRELATE TO SLB COIL FLAG DATED 08-AUG-23 PERFORATE 10,067' - 10,094' WITH 2" 6SPF 60PHASE HSC WITH MAXFORCE CHARGES CCL-TS=11.8', CCL STOP 10055.2'. RDMO E-LINE ***JOB COMPLETE*** HAND WELL BACK TO DSO 7/4/2023 ***WELL SHUT-IN ON ARRIVAL*** JOB SCOPE (DRIFT, SET PLUG, PERFORATE) MIRU, YJ E-LINE PREPARE TO PICK UP TOOL STRING CHD 3X 1 11/16" WB GR/CCL, JUNK CATCHER, WHILE MOVING TO WELLHEAD AND PULLING TOOLS INTO LUBRICATOR THE TOOLS SNAGGED ON A TOOL AND THE STRING WAS PULLED OUT OF THE CABLEHEAD WEAK POINT DROPPING TO THE GROUND. CONTACTED COMPANY MAN DSO TO REPORT INCIDENT AFTER A STAND DOWN CONTINED WITH JOB REHEADING LINE AND CHECKING TOOLS STAB ON WELL W/CHD 3X1 11/16 WB AND GR/CCL PT PCE 300 PSI LOW/ 3000 PSI HIGH LOG CORRELATION AND DRIFT PASS POOH LAYDOWN TOOLS AND LUBRICATOR TO CONTINUE JOB IN THE MORNING ***WELL SHUT UPON LEAVING LOCATION*** ***CONTINUE ON 5 JULY 2023*** 7/4/2023 ***Assist Eline with Perforating*** Job postponed 7/5/2023 T/I/O = 2431/64/54. ***Assist Eline*** Loaded well w/ 1bbls 60/40, 265bbls crude. Pressured up well w/ 8bbls crude prior to perforating. FWHP's = 50/66/60 Daily Report of Well Operations PBU 01-22B SET 3-1/2" NORTHERN SOLUTIONS CIBP AT 10,150' PERFORATE 10,067' - 10,094' Daily Report of Well Operations PBU 01-22B 7/5/2023 ***WELL SHUT IN ON ARRIVAL*** T/I/O = 2500/63/53 NS 2.75" OD CIBP, SET IN 3.5" LINER AT 10,060 FT, 14.0 FT TO MID ELEMENT, CCL STOP 10,046.0 FT. WT 1603/1314 LB, TAGGED AFTER SETTING. PT PLUG W/ LRS TO 1000 PSI. PT GOOD. RIH W/ 20 FT 2" 6 SPF PERF GUN, SHOOT INTERVAL 10030-10050 FT CCL -TOP SHOT = 7.7', CCL STOP = 10022.3' GOOD INDICATION, WHP 1000/950, CONFIRMED ALL SHOTS FIRED AT SURFACE, ELINE JOB COMPLETE. TIE IN TO SLB COIL FLAG DATED 08-AUG-2011 FINAL T/I/O = 500/63/53 *** WELL POP BY DSO ON DEPARTURE *** SHOOT INTERVAL 10030-10050 NS 2.75" OD CIBP, SET IN 3.5" LINER AT 10,060 FT • STATE OF ALASKA y ALASKA OIL AND GAS CONSERVATION COMMISSN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other Sr! f C/BP a 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 210-034 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20848-02-00 7. Property Designation(Lease Number): ADL 0028329 8. Well Name and Number: PBU 01-22B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11877 feet Plugs measured 10985/11650 feet true vertical 9044 feet Junkmeasured 11650 feet SEP 0 5 2017 Effective Depth: measured 10985 feet Packer measured See Attachment feet true vertical 9048 feet Packer true vertical See Attachment feet AOC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 36-116 36-116 1490 470 Surface 2559 13-3/8"72#L-80 35-2593 35-2593 4930 2670 Intermediate 9810 9-5/8"47#L-80 33-9842 33-8521 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 10640-10672 feet 11105-11130feet 11130-11155 feet 11719-11839 feet True vertical depth: 9003-9013 feet feet 9041-9038 feet 9038-9035 feet 9039-9042 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): ® �p NOV0 ( (�q Treatment descriptions including volumes used and final pressure: SCANNED ON 8 2 V I7 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 261 24507 1849 220 1674 Subsequent to operation: 494 11210 3001 1450 1328 14.Attachments:(required per 20 MC 25.07025.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Oestgaard,Finn Contact Name: Oestgaard,Finn Authorized Title: Production Engineer Challen r Contact Email: Finn.Oestgaard©bp.com Authorized Signature: Date: 6/-SI /1, Contact Phone: +1 907 564 5026 Form 10-404 Revised 04/2017 yry /0/6/`9-"I°N1 RBDMS LL SEP - 6 2617 Submit Original Only • • RECEIVED SEP 052017. AOGCC Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary August 30, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Plug and Adding of Perforations for Well 01-22B, PTD # 210-034. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • Packers and SSV's Attachment PBU 01-22B SW Name Type MD TVD Depscription 01-22B TBG PACKER 9041 7848.67 5-1/2" HES TNT Packer 01-22B TBG PACKER 9494 8220.35 5-1/2" BOT 3-H Packer 01-22B PACKER 10214.1 8846.91 3-1/2" Baker KB Top Packer • • m QO O O M O �0 0 0 0 0 t0 I� CO N- u) 00 co1 O 5 N N cO I- a; CCD (NO Ns V N 0 0 0 0 0 0 0 0 0 0 i 0) M Is CD co O Tr "c1' C) 3 O) OD ` e- N N Ns Ns NI- CD O) 00 Ns Ns h CO CO Ch O N co O) N O N Ch O) r CD N Li/ C() O) CD O CY) O) N M N 00 CO CO O) N- CD OO H Ns 01 CD Cn Ch Ns CD Ns- N Ch Ch 07 CD CV OD C7 Ch O Ns CV coAllme co N CC) M N 07 lf) e- ° OOD M 00 M Li/ CD T- N O) OD �O 0) 0) 0) W ;11,71: N Co Loma) � .- - No 01 Cr) M r Li/ " 0/ M U/= r O) O) Oa O) O) _ o m O o F— o Pi � � co00 CO °DUZ CO � Jk NCq ch CD V - M CV -0\D N N N CV_ N � Och LAI) LI) 4 . COO CD' O M T- CD C00 C) Nr r- oo CC) co e- O CD r CD J N CD — O) ch W CC C0 W W .y U U ea u cZZOOZc OZZ Z W W W W pp m pp pp 0D1-" ZZZDDDD 0 Cn Z J J J I- f f- H , 0 S eN / 0 £ � ° b $ a) X2 eL a) = o 2 _ ■ 2 = » \ o • \ ® $ 7 .- .- o Q — J £ m @2 a ® 6 = ¥ kG m o = 2 r .. @ a _/ § $ 3f � � 72 \ ® I 6 a ,. 2 $ = /m r \ � �6o= L % f ` c/ / o \ o 5/ \ / a $4,. ■ 7 » o f 2 m@q a$ - O w E t & , o o o § - 2E± / c k Ln 0) 0O 5, ■ 0 • 1 / • 1 § o _ O a 2 , a o c 47, Ce 0_b / p/ G �,- / - _/ § Cu Cu < � I 2 - .2 / o 6 a E � 1- 2 o E .- £ 2 � � in = @ m O 0 e _ $ > = o Q .c t \ 2 a ■ m m u ® OCOm � � 9Erm _ / 22 3 .c 0 = , D t co 2 pc O o = o ƒ 0Cli 0 22 � % \ / / / \ &fes /D .§- ƒ p E o c £ o o o = f2U / Ia % ƒ 0) Ei � � 2 § t CO 0 s E \ 2 7 0_. 2 § 2 ' 0 = g O. & a. ¥ 2 % k c K \ 2 CC / » ! 1 2 a (13 o \ 3 k : w m 2 u) « ƒ % / � O�/ E0 � a � oau) 2 as qfa� 2 / 9- § GE � Gm $ RkEa 2 CI CU (U ¥ o0 cu $ $ o cj22Sa CD ® - .> 0- - * ± 7 m a 2 G 2 0 _ f u) U • 2 / b •/ 7 / § ? % / / w § o 0 \ ' a2 � � k0Ienk / ocu)o _c \ 2 \ m : Et ._ 2 t .- 0 4 / = I o _c ©c 2 » c .@ D m o £ ® _ @ I- .,- u) / k / 0Q (U > - * k % t > _ : 0 U % = a a> a: Q a ; m u / ¥ ¥ ¥ » \ / \ m m / 1.0 + ¥ � b & I- N- / / « •s TREE= CM''WELLHEA2 B ANTY NOTES: WELL ANGLE>70' 10678'""MAX ACTUATOR BAKER C �� W DOGLEG:42.3°(3,r 10064'***CHROME TBG'"' OKB,ELEV 74' , I L I BE REV= ( 2230' 115-1/2"HES X NP,ID=4.562 1 KOP= 3758' Max Angle 96°@ 11102 20"CONDUCTOR, --110? j GAS LIFT MANDRELS Datum MD= 10249' 91.5#,1340, ST MD TVD DEV TYPE VLV LATCH PORT DATE D-19.124" 4 3528 3528 2 MNG DMY RK 0 12/22/15 Datum ND 8800'SS 3 5824 5506 43 MMG DMY RK 0 12/22/15 13-3/8 CSG,72# L-80 BUTT,ID 12.347" 2689' _.._ __... �— 2 7754 6880 45 NM DMY RK 0 10!22/15 1 8815 7671 40 MNG DMY RK 0 10/22/15 901 5-1/ X NP D=4.56 Minimum ID =1.780" @ 10239' � 8' � 2 HES 2' 1 2.70" DEPLOYMENT SLEEVE 1..... 9039' --19-5/8"X 5-1/2 HES TNT PKR D=4.791" , ' I.. 9074' 1-15-112"HES X NP D=4 562- 1 5-1/2"TBG, 17#,13CR-80 VAM TOP HC, -J 9166' .0232 bpf,D=4.892" \ ■ ` 9146' —5-1/2"ILS XN NP MILLED TO 4.55"(12/12/15) 5-1/2"TBG STUB(LJNSMFTED DEPTH) — 9162' {. 9181' 1--19-518 X 5-1/2"MOQUE OVERSHOT 1 TOP OF 3-1/2'LNR/C..MFNTFfl H 9198' 0 r Lr ir 1'A 5-1/2"TBG-PC, 17#,L-80 8RD ABM, J 9478' ., -Y 9478' H 5-1/2"BOT PBR ASSY .0232 bpf,D=4.892" % A 9498' H9-5/8'x5-1/2'BOT 3-H PKI.D=4.00" 9509' -15-1/2*X 4-1/2"XO,ID=3.958" TOP OF 7"LM J 9544' 9593' -4-1/2"OTIS XN NP,ID=3.75" BEHIND CT LNR 9604' 14-1/2"BOT SHEAROUT SUB 4-1/2"TBG-PC,12.6#,L-80 BUTT, -J 9606' J * *�f [ 9606' J--I4-t/2 WLEG D 3.958", ' 0152 bpf,D 1=3.958" $ li 9614' -I 8_M)TT LOGGED??/??P? • 9-5/8"CSG,47#,L-80 BUTT,13=8.681" H 9839' I a % ' IL, I A 14 7"MLLOUT WINDOW(01-22A)10038'-10049' JP 7"LNR,29#,L-80 BUTT,.0371 bpf,13=6.875" —{ 10038' - 10214' —13-112"KB LTP,D=1-810" TOP OF CRENT -J -10236' 13-1/2" WHPSTOCFC(04/22/10)wf RA TAGS 10335' H 10330' 10239' 2.70 BTT DEPLOY SLV D=1.780" 3-1/2"LNR,8.7#,L-80 FL4S.0087 bpf,13=2.990 — —10333 4` MLLOUT WINDOW(01-228) 10333'-10338' FLUSH JOINT ,,,,I4%•`• 10864' H2-3/8"MARKER JOINT PERFORATION SLJMMARY REF LOG: SLB CNUCCGR on 05/19/10 :1• ** L/ [ 10986' I-12-318"WFD CBP(07/26/17) 1 ANGLE AT TOP PERF:74°@ 10640' Note:Refer to Production DB for historical pert data i --11650' j---f FISH:2-3/8 WFD CEP(07/26/17) 1 SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 1.56" 6 10640-10672 0 07/26/172... +L 11650' H2-318"VVOT CUP(08/09/11) 1.56" 6 11105-11130 C 08/09/11 1.56" 6 11130-11155 C 08/09/11 4.$1.70'16.4,;� 1.56" 6 11719- 11839 C 05/20/10 FBTD --I 11839' ' • 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf,ID=1.995" 1 11877' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 111/07/82 RWN 35 ORIGINAL COMPLETION 12/21/15 FO/JM) PULLED WRP(08/08/15) VVELL: 01-228 02/12/95 ? CTD SIDETRACK(01-22A) 12/21/15 JTMJMD WILLED XN(12/12/15) PE'2MT No:"`2100340 05/21/10 NORDIC 1 CTD SIDETRACK(01-228) 01/27/16 CJN/JMD GLV C/O(12/22/15) AR No 50-029-20848-02 10/22/15 D-16 RWO 07/27/17 JDMJMD SET CEP/FISH&ADPERFS SEC 8,T1 ON,R15E,518'FML&528'FM_ 10/30/15 SMJMD FINAL ODE APPROVAL 11/16/15 JLS/JMD GLV 00(11/13/15) — BP Exploration(Alaska) STATE OF ALASKA �LASKA OIL AND GAS CONSERVATION COMMI REPORT OF SUNDRY WELL OPEFtATAlt • 1. Operations Performed Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing H Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0// Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 210-034 3. Address: P.O.Box 196612 Anchorage, Development H Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20848-02-00 7. Property Designation(Lease Number): ADL 028329 8. Well Name and Number: PBU 01-22B 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured 11877 feet Plugs 2016 Pmeasured 11650 feet i n^' true vertical 9044 feet Junk measured None feet .1NIV Effective Depth: measured 11650 feet Packer measured 9039,9498 feet ((���.1�(�t_ true vertical 9036 feet Packer true vertical 7847,8334 feet AOGCC �7C Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 33-113 33-113 1490 470 Surface 2559 13-3/8" 32-2591 32-2591 4930 2670 Intermediate 9810 9-5/8" 31-9841 31 -8519 6870 4760 Liner 494 7" 9544-10038 8263-8692 8160 7020 Liner 1135 3-1/2" 9198-10333 7975-8930 Liner 1663 2-3/8" 10214-11877 8847-9044 11200 11780 Perforation Depth: Measured depth: 11105 11837 feet i Hk0 I� 4LL, 24 %;'01 True vertical depth: 9041-9042 feet Tubing(size,grade,measured and true vertical depth) 5-1/2",17#,13Cr80 x 4-1/2",12.6#,L-80 9606 8316 Packers and SSSV(type,measured and 5-1/2"HES TNT Packer 9039 7847 true vertical depth) 5-1/2"3H Packer 9498 8334 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 440 0 Subsequent to operation: 692 4908 3634 380 1118 14.Attachments:(required per zo AAC 25.070.25.071,&25.2831 15.Well Class after work: Daily Report of Well Operations H Exploratory ❑ Development H Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil H Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG ❑ GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Mclaughlin,Sean M Email Sean.McLaughlin@bp.com Printed Name Joe Lastufka Title Drilling Technologist Signature0\1 1 / Phone +1 907 564 4091 Date 1 I i 11s Form 10-404 Revised 5/2015 "L i/1 3,1 L A 1I/ (j RBDMS)JAN 1 1 2016 Submit Original Only • • 01-22B, Well History (Pre-Rig Workover) ACTIVITYDATE &L{, ***JOB CONTINUED FROM 11-AUG-2015***(ELINE TUBING PUNCH AND RCT) POOH AND DETERMINE RCT DID NOT FIRE RIH WITH 2ND RCT CUTTER CUT TUBING AT 9154' POOH TO VERIFY CUTTER SHOT RIG DOWN ELINE 8/12/2015 ***JOB COMPLETE*** T/I/O= 1146/739/142 Temp=Sl Cir-out well (Pre RWO) MIT-OA to 1200 psi ***PASS*** Pumped 1.15 bbl Diesel to reach test pressure, 1st 15 Min OA Lost 38 psi: 2nd 15 Min OA Lost 13 psi, For a total Loss of 51 psi over a 30 Min Test***PASS*** Bled OA to 50 psi, Bled Back 1.2 bbl. CMIT-TxIA to 3500 psi ***PASS***( 3rd Attempt) Pumped 21 bbl Diesel to reach Test Pressure, 1st 15 Min Tbg/IA Lost 24/24 psi, 2nd 15 Tbg/IA Lost 19/18 psi for a total Loss of 43/42 psi over a 30 Minute Test***PASS*** Pumped 5 bbls neat methanol and 894 bbls of 100* 1°/0 KCL down the tubing, up the IA, taking returns to 01-23 for a Circ-out. Pumped 169 bbls of diesel down the tubing for freeze protect. U-tubed tubing and IA for 1 hour. Pumped a 10 bbl neat methanol spear followed by 113 bbls of 120*crude and a 10 bbl neat methanol tail to freeze protect the flow line on 01-23. Bled down hardline. DSO notified of well status. Caution tags hung on Master/IA/OA valves. Freeze protect tags hung on Wing valve. 8/18/2015 AFE sign already on well. Final valve postions: SV/WV/SSV= Closed, MV= Open, T/I/O =SSV/0/20, Temp:SI, PPPOT-T (PASS) PPPOT-IC (PASS) Pre RWO PPPOT-T: Stung into test void, (150 psi) bled void to 0 psi. Monitored for 10 minutes, void stayed at 0 psi. Functioned LDS, all moved freely. Torqued to 350 ft/lbs. Pumped through void, good returns. Pressured test void to 5,000 psi for 30 minute test. Lost 100 psi in 15 minutes, lost 0 psi in second 15 minutes. (PASS) Bled void to 0 psi. PPPOT-IC: Hoke valves installed on test void, opened hoke valve, 0 psi. Monitored for 10 minutes, void stayed at 0 psi. Functioned LDS, all moved freely. Torqued to 350 ft/lbs. Flushed seal tite from void until clean returns achieved. Pressured test void to 8/19/2015 3,500 psi for 30 minute test. Lost 100 psi in 15 minutes. Lost 50 psi in second 15 WHP=vac/vac/5, Conduct PJSM w/Crew and OPS. Installed 3" Piggy back temp#79 on OA and 3" Piggyback temp#51 on IA. Set BPV#538. @ 120 Inches. LTTon BPV (Passed) . . PT'd tree cap to 500psi (passed) RDMO ***Job IN Progress***See Log 9/27/2015 For Details. Final T/I/O=BPV/0/5 T/I/O=BPV/300/0. Remove old 5x7 FMC 120 upper tree. Install temp FMC 120 SV#37. Torque flange to API SPECS. P/T to 300, 5000 for 5 min each. (PASSED) Charted and 9/27/2015 retained. Bleed IA to 0 PSI. RDMO ***JOB COMPLETE*** Final T/I/O=BPV/0/0. T/I/O = BPV/0/0. Temp = SI. Bleed WHPs to 0 psi (Pre RWO). No wellhouse, flowline,AL. BPV in hole. 9/29/2015 SV= C. MV = O. IA, OA= OTG. NOVP. 2130 T/I/O=BPV/0/0. RD Pad Side 3" FMC 120 IN RU VR Plug With Tapped Blind Flange and Needle Valve. Torqued Flanges to API Specs. PT'd Blind Against VR Plug. RDMO 10/5/2015 ***Job Complete***See Log For Details. Final T/I/O=BPV/0/0 T/I/O = BPV/0/8. Temp = SI. WHPs (pre RWO). No wellhouse, no well platform, no AL or flow line, no WV or SSV. 10/14/2015 SV= C. MV=O. IA, OA = OTG. 1630 • • • North America-ALASKA-BP Page 1 of 7 Operation Summary Report Common Well Name:01-22 AFE No Event Type:WORKOVER(WO) Start Date:10/17/2015 End Date:10/22/2015 X4-011FK-E:(2,525,000.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:DOYON 16 Spud Date/Time:10/21/1982 12:00:00AM Rig Release:10/22/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292084800 Active datum:35:22 12/24/1994 00:00©74.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10/17/2015 21:00 - 22:00 1.00 MOB P PRE PJSM.SECURE TREE AND CELLAR AREA. -PULL RIG OFF DS01-13,WSL AND TOURPUSHER PRESENT.PAD OPERATOR NOTIFIED. -OA=0 PSI,IA=0 PSI,TBG=0 PSI. 22:00 - 23:00 1.00 MOB P PRE MOVE RIG ON PAD. -STAGE RIG MATS AROUND 01-22. 23:00 - 00:00 1.00 MOB P PRE PULL OVER 01-22. -WSL AND TOUR PUSHER PRESENT.PAD OPERATOR NOTIFIED. -OA=0 PSI,IA=0 PSI,TBG=0 PSI. 10/18/2015 00:00 - 01:00 1.00 MOB P PRE SHIM RIG: -SPOT SLOP TANK,FUEL TRAILER AND CREW CHANGE OUT TRAILER. 01:00 - 02:00 1.00 BOPSUR P PRE R/U AND PRESSURE TEST LINES IN CELLAR. ACCEPT DOYON 16 AT 01:00 HRS ON 10/18/2015. 02:00 - 02:30 0.50 BOPSUR P PRE RIG EVACUATION DRILL: -HELD AAR WITH CREW TO DISCUSS MUSTER AREAS AND EVACUATION PROCEDURES FROM THE RIG. 02:30 - 04:00 1.50 BOPSUR N DFAL PRE PJSM.PRESSURE TEST BPV FROM BELOW: -ATTEMPT TO PRESSURE UP ON ISA BPV. UNSUCCESSFUL,LEAKING BY BPV. 04:00 - 08:00 4.00 BOPSUR N DFAL PRE PJSM.REPLACE ISA BPV: -R/U AND PRESSURE TEST DSM LUBRICATOR TO 250 PSI LOW,3,500 PSI HIGH FOR(5)MINUTES.GOOD TEST. -PULL ISA BPV. -PRESSURE TEST QUICK TEST SUB. -BREAK OFF LUBRICATOR. -CHANGED OUT 0-RING ON ISA BPV. -STAB LUBRICATOR AND P/T QUICK TEST SUB CONNECTION. -DSM SET BPV 08:00 - 09:30 1.50 BOPSUR P PRE PRESSURE TEST BPV FROM BELOW -250 LO/3500-PSI HI FOR 5/5 CHARTED MINUTES. GOOD TEST. 09:30 - 12:00 2.50 BOPSUR P PRE NIPPLE DOWN TREE AND ADAPTER FLANGE -BLEED VOID PRESSURE TO ZERO -NIPPLED DOWN TREE AND ADAPTER FLANGE. -FMC INSPECT TUBING HANGER AND MAKEUP 5-3/4"RH ACME XO. MADE UP 10 TURNS AS EXPECTED. 12:00 - 13:00 1.00 BOPSUR P PRE CONTINUE NIPPLE DOWN TREE AND ADAPTER FLANGE: -CLEAN TUBING HANGER TOP. -FMC CHECK LOCKDOWN SCREWS AND MEASURE. -2-7/8"IN AND 3-1/2"OUT Printed 11/6/2015 3:13:01PM • i • North America-ALASKA-BP Page 2 of 7 Operation Summary Report Common Well Name:01-22 AFE No Event Type:WORKOVER(WO) Start Date:10/17/2015 End Date:10/22/2015 X4-011 FK-E:(2,525,000.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:DOYON 16 Spud Daterme:10/21/1982 12:00:OOAM Rig Release:10/22/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292084800 Active datum:35:22 12/24/1994 00:00 @74.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 16:30 3.50 BOPSUR P PRE NIPPLE UP BOPE. RIG UP TEST EQUIPMENT: BOPE CONFIGURED AS FOLLOWS TOP DOWN: -13-5/8"5M HYDRIL ANNULAR. -13-5/8"5M 3-1/2"X 6"VARIABLE BORE RAMS. -13-5/8"5M BLIND/SHEAR RAMS. -13-5/8"MUD CROSS WITH MANUAL AND HCR KILL AND CHOKE VALVES. -13-5/8"5M 3-1/2"X 6"VARIABLE BORE RAMS. 16:30 - 17:30 1.00 BOPSUR N WAIT PRE WAIT ON FLANGE BOLTS.TUBING SPOOL FLANGE BOLTS ARE 13",NOT LONG ENOUGH TO MAKE UP TO BOP FLANGE,ORDER 14" BOLTS. -TUBING SPOOL BASE FLANGE WAS 3/4" THICKER 17:30 - 20:00 2.50 BOPSUR P PRE 14"BOLTS ARRIVE ON LOCATION,CONTINUE TO NU BOPS. 20:00 - 00:00 4.00 BOPSUR P DECOMP PJSM.TEST FOUR PREVENTER 13-5/8"5M BOPE AND RELATED EQUIPMENT. -TEST BOPE ACCORDING TO AOGCC REGULATIONS,DOYON AND BP PROCEDURES. -PERFORM FULL BODY BOP TEST,250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINUTES EACH -TEST ANNULAR WITH 4"TEST JOINT TO 250 PSI LOW,3,500 PSI HIGH FOR 5 CHARTED MINUTES EACH -TEST UPPER AND LOWER 3-1/2"X 6" VARIABLE RAMS WITH 4"AND 5-1/2"TEST JOINT TO 250 PSI,3,500 PSI HIGH FOR 5 CHARTED MINUTES EACH NO FAILURES NOTED 10/19/2015 00:00 - 02:00 2.00 BOPSUR P DECOMP PJSM.CONTINUE TO TEST FOUR PREVENTER 13-5/8"5M BOPE AND RELATED EQUIPMENT. -TEST BLIND RAMS,FLOOR VALVES,AND CHOKE MANIFOLD TO 250 PSI,3,500 PSI HIGH FOR 5 CHARTED MINUTES -TEST WITH FRESH WATER -PERFORM ACCUMULATOR DRAW DOWN TEST WITH WSL PRESENT NOTE: FAIL/PASS ON UPPER 3-1/2"X 6" VBR'S. VBR'S HAD NEW ELASTOMER ELEMENTS INSTALLED AND REQUIRED SEVERAL OPENS/CLOSES TO BREAK IN THEN PASSED PRESSURE TEST. NO ADDITIONAL FAILURES NOTED. *AOGCC TEST WITNESS NOTIFICATION MADE ON 10/17/2015 AT 09:52 **AOGCC INSPECTOR JEFF JONES WAIVED WITNESS BY EMAIL ON 10/17/2015 AT 10:33 02:00 - 03:00 1.00 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT AND BLOW DOWN LINES. RIG UP FOR FREEZE PROTECT CIRC OUT. Printed 11/6/2015 3:13:01PM • • • • North America-ALASKA-BP Page 3 of 7 Operation Summary Report Common Well Name:01-22 AFE No Event Type:WORKOVER(WO) Start Date:10/17/2015 End Date:10/22/2015 X4-011FK-E:(2,525,000.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:DOYON 16 Spud Date/Time:10/21/1982 12:00:00AM Rig Release:10/22/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292084800 Active datum:35:22 12/24/1994 00:00 @74.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 03:30 0.50 WHSUR P DECOMP RU DUTCH RISER AND DSM LUBRICATOR WITH QTS -PRESSURE TEST LUBRICATOR 250 PSI LOW /3500 PSI HIGH FOR 5 CHARTED MINUTES EACH TEST-GOOD TEST 03:30 - 04:00 0.50 WHSUR P DECOMP PULL FMC BLANKING PLUG -BREAK OFF VALVE SHOP LUBRICATOR -PULL BLANKING PLUG 04:00 - 05:00 1.00 WHSUR P DECOMP PULL ISA BPV -MU DSM LUBRICATOR AND QTS,PRESSURE TEST 250 PSI LOW/3500 PSI HIGH -PULL ISA BPV -RIG DOWN DSM LUBRICATOR AND DUTCH RISER 05:00 - 05:30 0.50 KILLW P DECOMP PRESSURE TEST SURFACE HARDLINE 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES EACH 05:30 - 08:30 3.00 KILLW P DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT -CIRCULATED 70-BBLS.SEAWATER DOWN INNER ANNULUS AT 6.0-BPM AT 600-PSI. -CIRCULATED 670-BBLS.SEAWATER DOWN TUBING AT 6.0-BPM AT 350-530 PSI. -MONITORED WELL FOR 10-MINUTES. WELL IS STATIC-NO FLOW. -RIG UP 5-1/2"TUBING HANDLING EQUIPMENT 08:30 - 10:00 1.50 KILLW P DECOMP RIG DOWN WELL KILL EQUIPMENT -RIG DOWN KILL MANIFOLD AND SURFACE LINES IN RIG CELLAR. -RECONNECT KILL LINE TO BOP STACK AND PRESSURE TEST TO 250-PSI LO/3500-PSI HI. -DRAIN BOP STACK. 10:00 - 11:30 1.50 PULL P DECOMP PULL COMPLETION -MADE UP 4"HT-38 LANDING JOINT TO 5-3/4" RH ACME XO. -SCREWED INTO LANDING JOINT WITH TOP DRIVE AND MADE UP TO TUBING HANGER. 10 TURNS TO MAKE UP AS REQUIRED. -FMC REP.BACKED OUT LOCKDOWN SCREWS AND CONFIRMED FULL OUT MEASUREMENT. FULL OUT MEASUREMENT =3.5" -CLEARED RIG FLOOR TO UNLAND TUBING HANGER. -TUBING HANGER CAME FREE AT 165K UPWEIGHT WITH 12K UPWEIGHT DRAG. -HOISTED HANGER TO FLOOR. -CLOSED ANNULAR PREVENTER AROUND 5-1/2"TUBING AND DUAL CONTROL LINES. 11:30 - 12:00 0.50 PULL P DECOMP CBU X 1 -CIRCULATE BOTTOMS UP(400-BBLS.)WITH 8.5-PPG SEAWATER THROUGH MUD/GAS SEPARATOR -6.0-BPM AT 150-PSI SCR'S: 60-SPM=60-PSI, 70-SPM=80-PSI Printed 11/6/2015 3:13:01PM • • • North America-ALASKA-BP Page 4 of 7 Operation Summary Report Common Well Name:01-22 AFE No Event Type:WORKOVER(WO) Start Date:10/17/2015 End Date:10/22/2015 X4011 FK-E:(2,525,000.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:DOYON 16 Spud Date/Tme:10/21/1982 12:00:00AM Rig Release:10/22/2015 Rig Contractor:DOYON DRILLING INC. UW:500292084800 Active datum:35:22 12/24/1994 00:00 @74.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 13:30 1.50 PULL P DECOMP CONTINUE CBU X 1 -CIRCULATE BOTTOMS UP(400-BBLS.)WITH 8.5-PPG SEAWATER THROUGH MUD/GAS SEPARATOR -6.0-BPM AT 180-PSI -MONITOR WELL FOR 10-MINUTES -WELL IS STATIC-NO FLOW CONFIRM 0-PSI UNDER ANNULAR PREVENTER. -OPENED ANNULAR PREVENTER 13:30 - 14:00 0.50 PULL P DECOMP BREAK OUT AND LAY DOWN LANDING JOINT AND TUBING HANGER. 14:00 - 00:00 10.00 PULL P DECOMP POH VNTH 5-1/2"TUBING AND JEWELRY COMPLETION FROM TUBING CUT AT 9,154' MD. -SPOOLING DUAL CONTROL LINE OUT AND REMOVING CLAMPS AND BANDS AS POH. -POH FROM 9,154'MD TO 2,665'MD.PUW= 80 KLBS,SOW=84 KLBS. -RECOVERED:160 JTS,29 CLAMPS,4 SSB. 10/20/2015 00:00 - 01:00 1.00 DHB P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. -CHECK CROWN-O-MATIC.GOOD. PJSM.M/U 9-5/8"HES RTTS. -RIH 87'MD AND SET RTTS AS PER HES REPRESENTATIVE. -POOH WITH SETTING TOOL AND STAND BACK(1)STAND IN DERRICK. 01:00 - 01:30 0.50 DHB P DECOMP PJSM.PRESSURE TEST 9-5/8"HES RTTS. -PRESSURE TEST TO 250 PSI LOW,3,500 PSI HIGH FOR(5)CHARTED MINUTES.PASSES BP TESTING CRITERIA. 01:30 - 06:00 4.50 BOPSUR P DECOMP PJSM.PERFORM WELLHEAD WORK. -BLOW DOWN KILL LINE AND DRAIN BOPE STACK. -N/D TUBING SPOOL. 06:00 - 08:30 2.50 i BOPSUR P DECOMP REMOVE 13-5/8"TUBING SPOOL -ATTEMPT TO PULL EXISTING TUBING SPOOL WITH SUPER TUGGER,UNSUCCESSUL -APPLY STEAM HEAT -REATTEMPT TO PULL WITH SUPER TUGGER,UNSUCCESSFUL -MU LANDING JOINT AND OLD TUBING HANGER AND RILDS -MU TOP DRIVE AND AND WORK TUBING SPOOL,INCREASE PULL -PULL SPOOL FREE AT 65K OVER -LAY DOWN LANDING JOINT AND TUBING HANGER -REMOVE TUBING SPOOL AND CLEAR CELLAR 08:30 - 14:00 5.50 BOPSUR P DECOMP PJSM,CHANGEOUT AND TEST PACKOFF, INSTALL NEW TUBING SPOOL -PULL AND INSTALL NEW IC PACKOFF -INSTALL NEW TUBING SPOOL W/2ND IA VALVE -TEST IC PACKOFF(PPPOT-IC) 250 PSI LOW /3500 PSI HIGH FOR 30 CHARTED MINUTES- GOOD TEST Printed 11/6/2015 3:13:01PM •• • North America-ALASKA-BP Page 5 of 7 Operation Summary Report Common Well Name:01-22 AFE No Event Type:WORKOVER(WO) Start Date:10/17/2015 End Date:10/22/2015 X4-011FK-E:(2,525,000.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:DOYON 16 Spud Date/Time:10/21/1982 12:00:00AM Rig Release:10/22/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292084800 Active datum:35:22 12/24/1994 00:00(g74.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 16:30 2.50 BOPSUR P DECOMP PJSM,NU 13-5/8"5M BOPS TO NEW TUBING SPOOL -PRESSURE TEST BREAK 250 PSI LOW/3500 PSI HIGH FOR 5 CHARTED MINUTES EACH -RD TEST EQUIPMENT AND BLOW DOWN LINES 16:30 - 18:30 2.00 SOPSUR P DECOMP PJSM,PULL HES STORM PACKER -RUN IN ONE STAND FROM DERRICK AND ENGAGE STORM PACKER PER HES REP -RELEASE STORM PACKER AND POH -LAY DOWN STORM PACKER,CLEAN AND CLEAR RIG FLOOR 18:30 - 22:00 3.50 PULL P DECOMP POOH WITH 5-1/2"17#L-80 8RD COMPLETION. -POOH FROM 2,665'MD TO SURFACE. -RECOVERED:(233)JOINTS,(8)GLM'S,(1) CUT JOINT=7.90' 22:00 - 23:30 1.50 PULL P DECOMP CLEAR AND CLEAN RIG FLOOR. 23:30 - 00:00 0.50 PULL P DECOMP PJSM.SLIP AND CUT 70'OF DRILLING LINE. NO SLOW CIRCULATING RATES THIS TOUR. -OA=0 PSI. 10/21/2015 00:00 - 01:30 1.50 PULL P DECOMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. -CHECK CROWN-O-MATIC.GOOD. PJSM.SLIP AND CUT 70'OF DRILLING LINE. 01:30 - 02:30 1.00 RUNCOM P RUNCMP R/U TO RUN 5-1/2"17#13CR-80 VAMTOP HC COMPLETION. 02:30 - 12:00 9.50 RUNCOM P RUNCMP PJSM.RIH WITH 5-1/2"17#13CR-80 VAMTOP HC COMPLETION. -BAKER LOK ALL CONNECTIONS BELOW PACKER. -USING TORQUE TURN SERVICES,TORQING EACH CONNECTION TO 6,580 FT-LBS. -USING JET LUBE SEAL GUARD THREAD COMPOUND. RIH FROM SURFACE TO 4,660'MD. 12:00 - 22:30 10.50 RUNCOM P RUNCMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. -CHECK CROWN-O-MATIC.GOOD. PJSM.RIH WITH 5-1/2"17#13CR-80 VAMTOP HC COMPLETION. -USING TORQUE TURN SERVICES,TORQING EACH CONNECTION TO 6,580 FT-LBS. -USING JET LUBE SEAL GUARD THREAD COMPOUND. -RIH FROM 4,660'MD TO 9,155'MD.NO-GOAT 9,155'MD.PUW=171 KLBS,SOW=150 KLBS. -NOTE FIRST SET OF SHEAR PINS AT 9,145' MD,SECOND SET OF SHEAR PINS AT 9,153' MD. Printed 11/6/2015 3:13:01PM • a • North America-ALASKA-BP Page 6 of 7 Operation Summary Report Common Well Name:01-22 AFE No Event Type:WORKOVER(WO) Start Date:10/17/2015 End Date:10/22/2015 X4-011 FK-E:(2,525,000.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:DOYON 16 Spud Date/Time:10/21/1982 12:00:00AM Rig Release:10/22/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292084800 Active datum:35:22 12/24/1994 00:00 @74.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 00:00 1.50 RUNCOM P RUNCMP PERFORM SPACE OUT CALCULATIONS. -WSLAND HES AGREE TO RUN NO SPACE OUT PUPS.TOP OF TUBING STUB 2.31'OFF OF NO-GO. FLUID LOSS TO WELL BORE PAST(24) HOURS=0 BBLS 8.5 PPG SEAWATER. -OA=0PSI. -NO SLOW CIRCULATING RATES THIS TOUR. 10/22/2015 00:00 - 01:00 1.00 RUNCOM P RUNCMP PTSM.PERFORM SPCC AND EQUIPMENT CHECKS. -CHECK CROWN-O-MATIC.GOOD. FMC RILDS ON HANGER. -L/D LANDING JOINT. 01:00 - 02:00 1.00 IRUNCOM P RUNCMP PJSM.R/U CIRCULATING MANIFOLD IN CELLAR. -LRS PRESSURE TEST SURFACE LINES TO 250 PSI LOW,3,500 PSI HIGH FOR(5) MINUTES.GOOD TEST. 02:00 - 05:30 3.50 RUNCOM P RUNCMP PJSM.FREEZE PROTECT WELL WITH LRS. -LRS PUMP 170 BBLS DIESEL FREEZE PROTECT. -PUMP AT 1.8 BPM=750 PSI. -SHUT DOWN AND ALLOW DIESEL TO U-TUBE BETWEEN IAAND TUBING. -R/D LRS LINES IN CELLAR. 05:30 - 07:30 2.00 WHSUR P RUNCMP PJSM.RIG UP DUTCH RISER AND DRILL SITE MAINTENANCE LUBRICATOR. -SET TWO WAY CHECK VALVE.PT FROM ABOVE @ 250/3500 PSI,5 MIN. -RIG DOWN DSM LUBRICATOR AND DUTCH RISER. 07:30 - 10:00 2.50 BOPSUR P RUNCMP PJSM.BLOW DOWN ALL LINES.RIG DOWN CIRC MANIFOLD. -FLUSH AND DRAIN BOP STACK. -N/D BOPE,FMC CLEAN AND INSPECT TUBING HANGER. 10:00 - 12:00 2.00 WHSUR P RUNCMP PJSM.N/U 13-5/8"X 7-1/16"5M ADAPTER FLANGE. -LOSSES TO WELLBORE LAST 12 HRS=0 BBLS. -O/A=0 PSI -NO PUMP OPERATIONS TO GET SLOW PUMP RATES. 12:00 - 13:30 1.50 WHSUR P RUNCMP PJSM.PRESSURE TEST HANGER VOID SEALS. -PRESSURE TEST TO 250 PSI LOW FOR(5) CHARTED MINUTES,5,000 PSI HIGH FOR(30) CHARTED MINUTES.GOOD TEST. 13:30 - 14:30 1.00 WHSUR P RUNCMP N/U 7-1/16"DRY HOLE TREE. -PRESSURE TEST TREE TO 250 PSI LOW, 5,000 PSI HIGH FOR(5)MINUTES.GOOD TEST. Printed 11/6/2015 3:13:01 PM • • North America-ALASKA-BP Page 7 of 7 Operation Summary Report Common Well Name:01-22 AFE No Event Type:WORKOVER(WO) Start Date:10/17/2015 End Date:10/22/2015 X4-011FK-E:(2,525,000.00) Project:Prudhoe Bay Site:PB DS 01 Rig Name/No.:DOYON 16 Spud DatefTime:10/21/1982 12:00:00AM Rig Release:10/22/2015 Rig Contractor:DOYON DRILLING INC. UWI:500292084800 Active datum:35:22 12/24/1994 00:00 @74.00usft(above Mean Sea Level) Date From-To I Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 16:00 1.50 RIGD P RUNCMP SECURE TREE AND CELLAR AREA -PULL RIG OFF DS01-22,WSLAND TOURPUSHER PRESENT.PAD OPERATOR NOTIFIED. -OA=0 PSI,IA=0 PSI,TBG=0 PSI. RELEASE DOYON 16 RIG AT 16:00 HRS ON 10/22/2015. Printed 11/6/2015 3:13:01PM • • 01-22B, Well History (Post-Rig Sidetrack) k." - Ifr T/I/O=TWC/0/0. Barriers =TWCxMV. Removed temp (SV#22). Installed upper 6"tree. Torqued to API specs. RU CIW lubricator w/6"J-plug pulling tool. Stabbed onto tree and PT'd against TWC, 300psi low and 5,000psi high for 5min. each (passed) ran down polish rod, tagging @135". Removed TWC#419. RD lubricator. Removed piggyback(IA#96) "" 4" (OA#79) . Installed tapped blind flanges and PT'd to 2500psi (passed) RDMO***Job Complete***SEE LOG FOR DETAILS. Final T/I/O= Vac/0/0. Note: TREE, WELLBORE AND 10/24/2015 ANNULUS VALVES ARE FLUID PACKED ***WELL S/I ON ARRIVAL***(rwo expense) SWCP 4522 R/U &STANDBY 11/10/2015 ***CONT ON 11/11/15 WSR*** T/I/O=8/8/0 Temp=S/I Circ well, FP, Set packer(Post rig) RU to upright and heat KCL to 11/10/2015 150* per WSL. ***Job continues 11/11/15 WSR*** ***CONT FROM 11/10/15*** (rwo expense) LRS PUMP 760 BBLS KCL& 160 BBLS DIESEL. DROP BALL& ROD (see log for details) LRS PERFORMS PASSING PRESSURE TEST FOR BALL& ROD SWCP 4522 RID FOR SCHEDULED MAINTENANCE ***JOB INCOMPLETE*** 11/11/2015 ***LRS IN CONTROL OF WELL UPON DEPARTURE*** ***Job continued from 11/10/15 WSR*** MIT-T @ 3500 ***PASS*** MIT-IA @ 3500 ***PASS***Pumped 5 bbls MEOH followed by 760 bbls 1%KCL to circ well then capped with 160 bbls 90*diesel for TBG/IA FP & U-tubed 1 hour. Then pumped 5 bbls MEOH followed by 121 bbls crude&capped w/8 bbls diesel for surface line & FL FP on return well 01-23.Tags hung. Pumped 2.99 bbls down TBG to reach test presure. 1st 15 minutes lost 25 psi, 2nd 15 minutes lost 19 psi, for a total loss of 44 psi Pumped 6.06 bbls diesel down IA to reach test pressure. 1st 15 minutes lost 47 psi, 2nd 15 minutes lost 18 psi, for a total loss of 65 psi. 11/11/2015 Bled back 9.2 bbls diesel. ***Job continues 11/12/15 WSR*** ***Job continued from 11/11/15 WSR*** Bled down WHP's. Notify DSO of well status, Hang AFE sign and caution tags, SV,WV,SSV=Closed MV=Open IA/OA=OTG. FWHP= 11/12/2015 0/0/8. Well shut in upon departure. ***WELL S/I ON ARRIVAL***(rwo expense) PULLED BALL& ROD @ 9,146' MD. 11/12/2015 ***JOB IN PROGRESS, CONTINUE ON 11/13/15 WSR*** ***JOB IN PROGRESS, CONTINUED FROM 11/12/15 WSR***(rwo expense). PULL RK-DGLV ST#3 @ 5,824'MD PULL RK-DGLV ST#4 @ 3,528' MD SET RK-LGLV ST#3 @ 3,528' MD SET RK-OGLV ST#4 @ 5,824' MD PULL 5-1/2" RHC PLUG BODY FROM 9,146' MD. ----UNABLE TO PULL JUNK CATCHER OR EVO TRIEVE DUE TO TOOL OD'S &XN ID---- 11/13/2015 ***JOB INCOMPLETE(plug lih), WELL LEFT S/I ON DEPARTURE*** CTU#3. 1.75" Coil 32 bbl CV 12/9/2015 Rig up CTU #3. 1.75" Coil 32.2 bbls CV***Continue from WSR 12/09/15*** Rig up RIH w/ BOT milling assembly w/4.55"diamond speed mill. Tagged the XN nipple at 9138' ctm. Milled through and drifted down to 9177' ctm.. POOH. 12/10/2015 ***Job in Progress*** • • 01-22B, Well History (Post-Rig Sidetrack) CTU #3. 1.75" Coil 32.2 bbls CV***Continue from WSR 12/10/15*** Rig up RIH w/BOT milling assembly w/4.55" diamond speed mill. Tagged the nipple at 9138' ctm. Milled the nipple and drifted down to 9177' ctm.. POOH. 12/10/2015 ***Job in Progress*** CTU #6. 1.75" 32 bbl CV***Continue from WSR 12/10/15*** RIH w/BOT venturi and tag the catcher sub at 9186' ctm. Venturi on top of it. Nothing recovered. Attempt to RIH w/BOT 5" G spear and fishing assembly, tagged on the P-sub to swab flange...not able to work past. Pick up a 4.45"od centralizer in the tool string...no go, move the centralizer up the tool string...no go. Close the master and SSV and deploy the tools through the swab...finally made it through the tree. ***Job in Progress*** 12/11/2015 CTU #6. 1.75" 32 bbl CV***Continue from WSR 12/10/15*** RIH w/ BOT venturi and tag the junk catcher at 9186' ctm. Venturi on top of it. Nothing recovered. Attempt to RIH w/ BOT 5" G spear and fishing assembly, tagged on the P-sub to swab flange had to troubleshoot getting through tree. Tagged junk catcher @ 9186', latched on third attempt and POOH. Standby on well due to communications outage. ***Job in Progress*** 12/11/2015 CTU #3. 1.75" Coil 32.0 bbl CV ***Continue from WSR 12/11/15*** Recovered junk catcher. Stoodby due to communications outage. Perform passing CMIT to 3000 psi (see log) RIH w/BKR fishing string, latch EVO plug @ 9200'. Jar until till Jars quit working, POOH and cut 150' pipe, make up BKR fishing string again and RIH. 12/12/2015 ***Job in Progress*** CTU#3. 1.75"Coil 32.0 bbl CV ***Continue from WSR 12/11/15*** OOH w/junk basket. Stay stabbed on well while shut in. Standby due to communications outage. Got the approval to go back to work. Junk basket recovered. RIH w/BOT fishing assembly and 2.5" GS. Tagged the EVO at 9200' ctm. Jarred until the Jar quit working, pumped off and POOH while keeping the hole full. Well head pressure rose to 525 psi and then broke back while POOH. plug is equalized. Continue out. Freeze protected the well with 50 bbls of 60/40 methanol. 12/12/2015 ***Jo in Progress*** CTU #3. 1.75" Coil 32.0 BBL CV***Continue from WSR 12/12/15*** Job Scope: Pull Plug Pulled HES Evotrieve from 9194' CTM, element intact, one garter spring missing left down hole. 12/13/2015 ***Job Complete*** S TREE= CM/ • 0 1 _z 2 B DOGLEG:2T3°° /0064'N CHROME TBG*"10678'""MAX WELLHEAD FMC ACTUATOR BAKER C OKB.ELEV 74' I I BF.ELEV= r 2230' -{5-1/2"HES X NP,D=4.562" KOP= 3758 Max Angle= 96'Ca311102 20"CONDUCTOR, - 110? GAS LFT MANDRELS Datum MD= 10249' 91.5#,t+40, ST MD TVD DEV TYPE VLV LATCH PORT DATE D-19.124" ' 4 3528 3528 2 MMG DOME RK 16 11/13/15 DratumND 8800 SS 3 5824 5506 43 MAG SO RK 20 11/13/15 13-3/8"CSG,72#,L-80 BUTT,ID=12.347" — 2589' 2 7754 6880 45 MG DMY RK 0 10/22/15 1 8815 7671 40 MMG DMY RK 0 10/22/15 Minimum ID = 1.78" @ 10239' r---- 1 9018' —15-1/2"HES X NP,D=4.562" 2.70" DEPLOYMENT SLEEVE 111'14 Z903W H9-5/8"X 5-1/2 HES TNT R<R,0=4.791" r 9074' -15-1/2"HES X MP,D=4.562' 5-1/2"TBG,17#,13CR-80 VAM TOP HC, -1 9166' .0232 bpf,D=4.892" 1`� 9146' H 5-1/2"FES XN NP PALLED TO 4.55"(12/12/15) 5-1/2"TBG STUB(UNSi6FTE0 DEPTH) —1 9162' V 1 i 9181' -I9-5/8'X 5-1/T UNIQUE OVERSHOT TOP OF 3-1/2"LNR/CEMENTED 9198' I� to 5-1/2"TBG-PC,17#,L-80 8RD ABM, H 9478' El ' 0232 bpf,D=4.892" 9478' --15-1/2"BOT PER ASSY = I= 9498' -9-5/8"X 5-1/2'BOT 3-H PKR,D=4.00" 9509' H5-1/2"X 4-1/2"XO,D=3.958" TOP OF 7"LNR 9544' ,: 9593' -14-1/2"OTIS XN NP,D=3.75" BEHIND �' CT LNR mi III 9604' H4-1/2"BOT SHEAROUT SUB 4-1/2"TBG-PC,12.6#,L-80 BUTT, -1 9606' itzr 9606' H4-1/2"WLEG,D=3.958" .0152 bpf,D=3.958' 9614' -1ELMD TT LOGGED??/??/?? 9-5/8'CSG,47#,L-80 BUTT,ID=8.681" 9839' ' SCI ay 7"MLLOUT WINDOW(01-22A)10038'-10049' 7"LNR,29#,L-80 BUTT,.0371 bpf,D=6.875" H 10038' ' " • TOP OF C811/84T ^10236' 10214' H3-1/2"KB LIP,D=1.810" I • 10239' H2.70"BTT DEPLOY SLV,D=1.780' 3-1/2" WHIPSTOCK(04/22/10)vi/RA TAG @ 10335' 10330' S 3-1/2"LNR,8.7#,L-80 FL4S.0087 bpf,D=2.990 -1 -10333 S ' MLLOUT WINDOW(01-22B)10333'-10338' FLUSH JOINT PERFORATION SUMMARY 10864' -i 2-3/8"MARKER DONT REF LOG: SLB CSL/(X L/GR on 05/19/10 4. ANGLE AT TOP FERE:96" a@ 11105' tk,`. Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqt SHOT SOZ 11650' -12-3/8"WOT CEP(08/09/11) 1.56" 6 11105-11130 0 08/09/11 '\'''•‘b 1.56" 6 11130-11155 0 08/09/11 1.56" 6 11719-11839 C 05/20/10 P1310 - 11839' 2-3/8"LNR,4.7#,L-80 STL,.0039 bpf,D=1.995" -1 11877' DATE REV BY C OMF/BYTS DATE REV BY COMMENTS PRUDHOE BAY MIT 11/07/82 RWN 35 ORIGINAL COMPLETION 11/16/15 JLS/JMD GLV C/0(11/13/15) WELL: 01-228 - 02/12/95 ? CTD SIDETRACK(01-22A) 12/21/15 FCXJMD PULLED WRP(08/08/15) PERMT No: 2100340 05/21/10 NORDIC 1 CTD SIDETRACK(01-22B) 12/21/15 JTTWJMD PALLED XN(12/12/15) AR No: 50-029-20848-02 10/22/15 D-16 RWO SEC 8,T1ON,R15E,518'FNL&528'FWL 10/29/15 TLWJMD DRLG HO CORRECTIONS 10/30/15 SM!JMD FINAL ODE APPROVAL BP Exploration(Alaska) • • Pi5 ("( o ter 'ZIO94' Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, December 23, 2015 9:10 AM J 11 /S To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; AK, OPS FS1 DS1 Operator;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric;AK, D&C Wells Slickline Coordinator; Morrison, Spencer; Regg, James B (DOA) Subject: OPERABLE: Producer 01-22B (PTD #2100340) MIT-IA Passed All, Producer 01-22B (PTD#2100340) passed a MIT-IA on December 22, 2015 following slick line work. The passing test confirms two competent barriers in the well. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed - • A SSSV is not required - Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid expansion. Thank you, Kevin Parks h tnev Pettus scant) SEP 2 0 2016 BP Alaska -Well Integrity Coordinator Iob&Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, December 18, 2015 1:11 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 Field OTL; AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; AK, OPS FS1 DS1 Operator; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers, Jessica; Dickerman, Eric; AK, D&C Wells Slickline Coordinator; Morrison, Spencer; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: UNDER EVALUATION: Producer 01-22B (PTD #2100340) Sustained Inner Annulus Casing Pressure over MOASP All, 1 uU1 -zz • PTS 2-loo' tto Regg, James B (DOA) ,! From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> `�(�I�f zifr$ Sent: Friday, December 18, 2015 1:11 PM To: AK, OPS FS1 OSM;AK, OPS FS1 Facility OTL;AK, OPS FS1 Field OTL;AK, OPS FS1 DS Ops Lead; AK, OPS PCC EOC TL;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; AK, OPS FS1 DS1 Operator;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Sayers,Jessica; Dickerman, Eric;AK, D&C Wells Slickline Coordinator; Morrison, Spencer; Regg,James B (DOA) Subject: UNDER EVALUATION: Producer 01-22B (PTD#2100340) Sustained Inner Annulus Casing Pressure over MOASP All, Producer 01-22B (PTD#2100340) underwent a rig Workover completed on October 22, 2015 to replace the tubing and repaired the tubing x inner annulus communication. A MIT-T and MIT-IA both passed to 3500 psi on November 11, 20151 A downhole plug was pulled on December 13, 2015 after a well intervention. On December 17, 2015 it was reported that the Inner Annulus casing pressure was above MOASP.The pressures were confirmed to be Tubing/Inner Annulus/Outer Annulus 2130/2150/30.The well is reclassified as Under Evaluation so the well can be brought on line for further evaluation. Plan Forward: 1. Operations: Bring well on production 2. Downhole Diagnostics: Warm TIFL 3. Slickline: Change out gas lift valves, MIT-IA (if TIFL fails) 4. Well Integrity Engineer:Additional diagnostics as needed Please use caution when placing the well on production due to fluid packed annuli and the potential for annular fluid expansion. Please call with any questions or concerns. Thank you, SCANNED Kevin Parks • BP Alaska-Well Integrity Coordinator GIoba1 Wells 1114.1 V r anizatl n Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Wednesday, September 11, 2013 9:04 PM To: AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OP S1 DS Ops Lead; AK, OPS PCC EOC TL; AK, D&C Well 1 • 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. al() - 0314 Well History File Identifier Organizing (done) ❑ Two -sided III I ❑ Rescan Needed 111 1111111111111111 RESC DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No. ❑ Maps: z' reyscale Items: viz Other, No/Type: a ND , '1 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non - Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: (aria) Date: qa 63 : i /s/ m P Project Proofin • lIJIIIJIJlIJII 11111 BY: Maria Date: a, /s/ OP Scanning Preparation / x 30 = 3 O +a / = TOTAL PAGES 5 (Count does not include cover sheet) BY: Date: �p ().. i �� /s/ Production Scanning 111 11111111111 11111 Stage 1 Page Count from Scanned File: l.(, 0 (Count does include cover sheet) Pa.e Count Matches Number in Scanning Preparation: 1. YES NO BY: Date: 42/g12// 9-- /s/ 041 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. 111 111111 1111111 111 ReScanned III IlililiM (111 BY: Maria Date: /s/ Comments about this file: Quality Checked Il1IIII1I1l1lI 10/6/2005 Well History File Cover Page.doc • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 May 11,2012 AUG 1 . �01L ficlikit4ED Mr. Jim Regg 03‘,913 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -01 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-01 01/20/12 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft NA qal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01 -08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA _ NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 1 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -17B 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -19B 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 .. 01 -22B 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA DATA SUBMITTAL COMPLIANCE REPORT 6/13/2012 Permit to Drill 2100340 Well Name /No. PRUDHOE BAY UNIT 01 -22B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20848 -02 -00 MD 11877 TVD 9044 Completion Date 5/21/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, GR / CCL / CNL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr III Data Digital Dataset Log Log Run Interval OH / Type MedlFrmt Number Name Scale Media No Start Stop CH Received Comments Log 4--- Neutron 25 Blu 9397 11824 Case 7/28/2010 MCNL, Mem Lee, CCL, TNF, TNN 1 ED C/C Lis 19909 Neutron 9395 11822 Case 7/28/2010 LIS Veri, GR, CNT RptV LIS Verification 9826 11877 Open 8/18/2010 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS ED ,VC Lis 20011 Induction /Resistivity 9826 11877 Open 8/18/2010 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS Log IX Induction /Resistivity 25 Col 10330 11877 Open 8/18/2010 MD MPR, GR I Log ✓ Induction /Resistivity 5 Col 10330 11877 Open 8/18/2010 TVD MPR, GR Log d" Gamma Ray 25 Col 10330 11877 Open 8/18/2010 MD GR Log ' Gamma Ray 5 Col 9820 11870 Open 8/18/2010 Depth Shift Monitor Plot ED C(/ Directional Survey 10307 11877 Open Rpt ' -fir Directional Survey 10307 11877 Open • Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Daily History Received? ®/ N Chips Received? "'Y-f -N-- Formation Tops �/ N Analysis Received? DATA SUBMITTAL COMPLIANCE REPORT 6/13/2012 Permit to Drill 2100340 Well Name /No. PRUDHOE BAY UNIT 01 -22B Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 20848 -02 -00 MD 11877 TVD 9044 Completion Date 5/21/2010 Completion Status 1 -OIL Current Status 1 -OIL UIC N Comments: Compliance Reviewed By: —_ Date: —� 3 �ry.� 20 • • STATE OF ALASKA ALASKAOAND GAS CONSERVATION COMMISSIA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations El Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ig Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ig Exploratory ❑ .r 210 -0340 3. Address: P.O. Box 196612 Stratigraphic Service p 6. API Number: Anchorage, AK 99519 -6612 — 50- 029 - 20848 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: • ADLO- 028329 -, PBU 01 -22B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11877 feet Plugs (measured) 11650 feet true vertical 9044.27 feet Junk (measured) None feet Effective Depth measured 11839 feet Packer (measured) 9498 10214 • feet true vertical 9042.18 feet (true vertical) 8224 8847 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 32 - 112 32 - 112 1490 470 Surface 2558' 13 -3/8" 72# L -80 31 - 2589 31 - 2589 4930 2670 Production 9809' 9 -5/8" 47# L -80 30 - 9839 30 - 8518 6870 4760 Liner 494' 7" 29# L -80 9544 - 10038 8263 - 8692 8160 7020 Liner 1140' 3 -1/2" 9.3# L -80 9198 - 10338 7975 - 8933 10160 10530 Liner 1638' 2 -3/8" 4.7# L -80 10239 - 11877 8866 - 9044 11200 11780 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# L -80 29 - 9509 29 - 8233 4 -1/2" 12.6# L -80 9509 - 9606 8233 - 8316 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" BOT 3 -H Packer 9498 8224 3 -1/2" Baker KB Top Packer 10214 8847 12. Stimulation or cement squeeze summary: RECEIVED' Intervals treated (measured): AUG 3 0 2011 Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cam 6omnissipq 13. Representative Daily Avera5ef or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 381 27,486 214 1,295 Subsequent to operation: 1,832 14,774 141 1 ,453 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development IO - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ,. Q Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG0 GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na e J Lastufka sit i Title Petrotechnical Data Technologist Signatu r j % � ` _ Phone 564 -4091 Date 8/29/2011 Form 10 -404 Revised 10/2010 RBDMS AUG 31 ZO11 Submit Original Only U 01 -22B 210 -034 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01 -22B 5/20/10 PER 11,719. 11,839. 9,039.1 9,042.18 01 -22B 7/24/11 BPS 10,214. 11,719. 8,846.83 9,039.1 01 -22B 7/30/11 BPP 10,214. 11,719. 8,846.83 9,039.1 01 -22B 8/9/11 BPS 11,650. 11,839. 9,035.57 9,042.18 01 -22B 8/9/11 APF 11,105. 11,130. 9,040.52 9,037.78 01 -22B 8/9/11 APF 11,130. 11,155. 9,037.78 9,035.27 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET • FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 • 01 -22B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/8/2011 CTU #8 w/ 1.5" CT (CTV =30.2) Scope: GSO (w/ CIBP) w/ 50' add perfs Finish RU. Prep new CT. Pump 1.0" ball. RIH w/ BHA #1 (WFT MHA + two 1.75" stingers + 1.75" nozzle, OAL= 10.42').. Tag PBTD @ 11821'. Pooh. RIH w/ 1.68" ctc, 1.69" dfcv, disco, 1.5" crossover, 1.5" KJ, 1.375" memory GR,CCL (oal= 20.09') Log at 40 fpm from 11750', flag pipe at 11,600 and 11,000' to 10,000'. pooh. RIH w/ WFT 1 2-3/8" CIBP to 11650' $ * *job in progress** 8/9/2011 CTU #8 w/ 1.5" CT (CTV =30.2) _._. Scope: GSO (w/ CIBP) w/ 50' add perfs Set WFT 2 -3/8" CIBP at 11650'. RIH w/ perf gun #1 (25'). Tag CIBP. Perforate 11130- 11155 interval. RIH w/ perf gun #2. Stopped at top flag and noted depths. RIH and tagged plug at 11650 corrected depth. (Plug is on depth) PUH and ° perforate 11105- 1113 interval. pooh. Freeze protect well w/ 58 bbls of 50/50 meth. * *job complete ** FLUIDS PUMPED BBLS 105 1% KCL 58 50/50 METH 163 TOTAL TREE = FMC W+cLLHEAD = FMC SAFETY WELL ANGLE> 70° @ 10678'."*"ORIG ACTUATOR = BAKER C 0 1 -2 2 B WELL & 0 A NOT SHOWN BELOW WHIPSTOCK" KB, ELEV = 74' BF. ELEV = KOP = 3758' 1 2215' I - 15 - 1/2" OTIS ROM NIP, ID = 4.562" I Max Angle = 96° @ 11138' Datum MD = 10249' GAS LIFT MANDRELS Datum TVD= 8800' SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2920 2920 1 OTIS DOME RM 16 05/25/10 120" CONDUCTOR, 91.5 #, H -40, ID = 19.124" 1 110' 2 4870 4775 37 OTIS SO RM 20 05/25/10 1 13 -3/8" CSG, 72 #, L -80 BUTT, ID = 12.347" I--1 2589' ' 3 6560 6042 44 OTIS DMY RA 0 06/02/96 4 7828 6933 44 OTIS DMY RA 0 03/09/97 5 8558 7473 40 OTIS DMY RA 0 11/06/82 Minimum ID = 1.780" @ 10239' 6 8630 7528 40 OTIS DMY RA 0 11/06/82 2.70" DEPLOYMENT SLEEVE 7 9010 7824 37 OTIS DMY RA 0 11/06/82 8 9085 7884 37 OTIS DMY RA 0 03/07/95 9 9374 8120 34 CMTD DMY N/A 0 01/11/95 ITOP OF 3 -1/2" LNR I I 9198' 10 9451 8184 33 CMTD DMY N/A 0 01/11/95 I 9478' H 5-1/2" BOT PBR A SSY I ►�� 9498' 1 - 19 - 5 / 8 " X 5 -1/2" BOT 3 -H PKR, ID = 4.00" I 5 -1/2" TBG -PC, 17 #, L -80 8RD ABM, — 9478' I 9509' H5 -1/2" X 4 -1/2" X0, ID = 3.958" I BEHIND .0232 bpf, ID = 4.892" CT LNR i 1 9593 H4-1/2" OTIS XN NIP, ID - 3.75" 1 I TOP OF 7" LNR H 9544' 9604' H4 -112" BOT SHEAROUT SUB I 4-1/2" TBG-PC, 12.6 #, L-80 BUTT, 9606' 1 9606' 4 -1/2" TUBING TAIL, ID = 3.958" .0152 bpf, ID = 3.958" I 9614' 11 EL MD TT LOGGED ? ?/ ? ? / ?? I ( 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9839' I 7" MILLOUT WINDOW (01 -22A) 10038' - 10049' I ( ( J 7" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.875" 10038' 1 — / I I 10214' 1-13 -1/2" KB LTP, ID = 1.810" I (TOP OF CEMENT H I - 10236' ! 1 10239' H2.70" BTT DEPLOYMENT SLV, ID = 1.780" I 1 � I3 -112" WHIPSTOCK (04/22/10) w/ RA TAG @ 10335' I 10330' 3 -1/2" LNR, 9.3 #, L -80 FL4S .0087 bpf, ID = 2.992 --I - 10333 49 MILLOUT WINDOW (01 -22B) 10333' 10338' FLUSH JOINT " ` PERFORATION SUMMARY `- REF LOG: SLB CNL /CCL /GR on 05/19/10 ` I 11650' H2-3/8" WOT CIBP (08/09/11) 1 ANGLE AT TOP PERF: 96° @ 11105' Note: Refer to Production DB for historical perf data I 10864' 1 MARKER JOINT I SIZE SPF INTERVAL Opn /Sqz DATE 1.56" 6 11105 - 11130 0 08/09/11 1/ 1.56" 6 11130 - 11155 0 08/09/11 ✓ A 1.56" 6 11719 - 11839 C 05/20/10 I PBTD 1 11839' w ilt, �Z, 12-3/8" LNR, 4.7 #, L -80 STL, .0039 bpf, ID = 1.995" (--I 11877' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/01/82 ORIGINAL COMPLETION 07/09/10 BS /JMD GLV DATE CORRECTIONS WELL: 01 -22B 01/11/95 CTD SIDETRACK (01 -22A) 08/08/11 JO/ PJC TREE C/O (07/28/11) PERMIT No: 2100340 05/21/10 NORDIC 1 CTD SIDETRACK (01 -22B) 08/14/11 RMH/ PJC CIBP/ ADPERF (8/9/11) API No: 50- 029 - 20848 -02 -00 05/25/10 PJC DRLG HO CORRECTIONS SEC 8, T1 ON, R15E, 2052.19 FEL & 2595.34 FNL 05/28/10 DAV /PJC GLV C/O (05/25/10) 07/09/10 WH/JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 01 -22B Contains the following: "- 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary i 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow) s 1 color print — MPR/Directional Measured Depth Log (to follow) i LAC Job #: 3170648 910 -034 "W// Sent by: Holly Vann Date: 08/16/2010 Received by: de A Date: i PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ Vall 7260 Homer Drive BAKER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 INTEQ FAX: (907) 267 -6623 • • M 6NES Baker At1as PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION (ALASKA) INC COUN I Y NOR 1H SLOPE BOROUGH WELL NAME 01 -22B STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 8/16/2010 THIS DISTRIBUTION LIST AUTHORIZED BY HOLLY VANN SO 4 3170648 Copes of Copes DIgttal Copies of Copes 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 CORAZON MANAOIS Address LR2 -1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 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 By: BAKER ATLAS -PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By 010 —0 3. Page 1 of 1 07/27/10 Schimberger NO. 5567 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambetl Street, Suite 400 Alaska 00 & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 71h Ave, Suite 100 Anchorage, AK 99501 Well Job 9 Log Description Date BL Color CD P2-16 BB6M -00027 LDL -Y - 1 •. - 07/20/10 1 1 F -03A AVKP -00096 SCMT i _. • ' -..: -I: ,,; II 07/22/10 1 1 V -225 BBKA -00039 LualMei �, ,ikiy _ V 07/01/10 1 1 S-100 BCZ2-00014 MINIIIIIIIIIM,, 9 PA, Z. �;. LfiZ 07/14/10 1 1 2- 58/S -09 BCZ2 -00016 LDL i y� _ t• 07/1 7/10 1 1 e ... , 1- 15/P -25 AYKP -00094 LDL �_ a� 07/11/10 1 1 W -19A BCRD -00036 USIT i 07/25/10 1 1 01 -22B AZ2F- 00042 1 /Cleri'fGZ+!alli:laal; 05/19/10 1 1 B -20 -00020 RST i Wait: 05/30/10 1 1 BCRJ-00020 eCRJ -00020 RST } ; 05/30/10 1 1 B -18 AVKP -00082 RST _ ♦ • 06/02/10 1 1 05 -32A MKS-00040 - 05/19/10 1 1 H -25 BCRD -00017 - ��, 05/10/10 1 1 P2 -34 AVYO.00063 RST / -- — OW., f / 9, ix,)-- 04/17/10 1 1 , Cilia 1111M1111=11111111111111MIAMIMIIIIMATNIX 1._____-_ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 • 900 E. Benson Blvd. Anchorage, Al( 99503 -2535 . 0... ., . ,J(JL.. 2 tl 2010 , ; a CV 8, Galx AnChMge • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ® Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 2OAAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions One ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 5/21/2010 210 - 034 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 5/15/2010 50 029 - 20848 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 5/17/2010 PBU 01 -22B 519' FNL, 528' FWL, SEC. 08, T10N, R15E, UM 8. KB (ft above MSL): 74' 15. Field / Pool(s): Top of Productive Horizon: 2514' FSL, 3422' FWL, SEC. 05, T10N, R15E, UM GL (ft above MSL): 40.5' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 1496' FSL, 3522' FWL, SEC. 05, T10N, R15E, UM 11839' 9042' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x 697854 y 5940382 Zone ASP4 11877' 9044 ADL 028329 TPI: x 700656 y 5943490 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x 700787 y 5942475 Zone ASP4 None 18. Directional Survey: ® Yes ❑ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD DIR, GR, RES, GR / CCL / CNL 10333' 8930' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 80' Surface 80' 30" 1900 # Poleset 13 -3/8" 72# L -80 Surface 2589' Surface 2589' 17 -1/2" 2000 sx Coldset 111.400 sx Coldset II 9 -5/8" 47# L -80 Surface 9839' Surface 8518' 12 -1/4" 500 sx Class 'G'. 300 sx Coldset 1 7" 29# L -80 9544' 10038' 8263' 8692' 8-1/2' 380 sx Class 'G' 3 -1/2" x 2 -7/8" 8.7# L -80 9198' 10333' 7975' 8930' 4 -1/2" 164 sx LARC 2 -3/8" 4.7# L -80 10225' 11877' 8856' 9944' 3" 41 sx Class 'G' 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 1.56" Gun Diameter, 6 spf 5 -1/2 ", 17 #, L 9509' 9498'! 8224' MD TVD MD TVD 4 - 1/2 ", 12.6#, L - 80 9509' - 9606' 11719' - 11839' 9039' - 9042' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ` DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED tr 2500' Freeze Protect w/ 65 Bbls of Diesel V 9 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 2, 2010 _ Flowing Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: G AS -OIL RATIO: 6/10/2010 8 Test Period ♦ 185 _ 8,240 9 56 44,449 Flow Tubing Casing Press: Calculated OIL -B8L: GAS-MCF: WATER -BBL: OIL G RAVITY - API (CORK): Press. 1,564 1,300 24 -Hour Rate ♦ 556 24,719 28 32 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ 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 laborato� r�Sspp�AC 250.071. None JUN 1 1 2010 RBDM$ JUN 1 ZOIJJ Alaska Oil & Gas Cons, Commission Form 10-407 Revised 12/2009 CONTI UED ON REVERSE�� Ar1C11OrageSubmit Original Only 29. GEOLOGIC MARKERS (List all formations and ma encountered): 30.MATION TESTS NAME MD TVD Well Tested? ❑ Yes 0 No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 23SB / Zone 2B 10372' 8950' None 22TS 10545' 8988' 21 TS / Zone 2A 10693' 9021' Zone 1B 10775' 9053' Zone 1B (Invert in to Base Zone 2A) 10900' 9054' Formation at Total Depth (Name): Zone 2A (Entered From Base) 10900' 9054' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,�/ Signed: Terris Hubble ONE Title: Drilling Technologist Date: 0G 7//// D PBU 01 - 22B 210 - 034 Prepared By Name/Number Terris Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Wilmer Hoffman, 564 -4592 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 la: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • North America - ALASKA - BP Page 1 of 2 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: MOBILIZATION (MOB) ' Start Date: 5/12/2010 End Date: 5/13/2010 X3- 00VM6 -C (471,525.00 ) Project: Prudhoe Bay I Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/12/2010 04:00 - 04:30 0.50 MOB P PRE PJSM REGARDING MOVING RIG OFF WELL & TO PAD ENTRANCE. _ 04:30 - 06:00 1.50 MOB P PRE BACK OFF WELL & SPOT RIG AT PAD ENTRANCE. CLEAN UP AROUND WELLHEAD. SIGN OFF PERMIT WITH DSO. 06:00 - 06:45 0.75 MOB P PRE C/O WITH NIGHT CREW. PEFORM WALK AROUNDS. WAIT FOR SECURITY TO MOVE RIG. 06:45 - 09:20 2.58 MOB P PRE MOVE RIG FROM DS 2 TO DS 1. MOVE RIG TO BACK SIDE OF PAD. S/I CASING VALVES & TREE VALVES. CHECK TREE PRESSURE = OPSI. 09:20 - 09:30 0.17 MOB P PRE PJSM REGARDING SPOTTING OVER. WELL. 09:30 - 09:50 0.33 MOB P PRE SPOT RIG OVER WELL. L/D TREE DIKE. 09:50 - 11:00 1.17 RIGU P PRE SET RIG DOWN. SPOT OFFICE CAMP. SPOT WELDING SHACK. SPOT MISC SUPPORT EQUIPMENT. ACCEPT RIG AT 10:00. APPLY TIOGA HEAT TO TREE. 11:00 - 11:15 0.25 BOPSUR P PRE PJSM REGARDING ND TREE CAP & NU BOP'S. 11:15 - 14:00 2.75 BOPSUR P PRE REMOVE TREE CAP. NU BOPE. CONTINUE TO SPOT MISC SUPPORT EQUIPMENT. SIMULTANEOUSLY RU INNER REEL HARDLINE & BULKHEAD. 14:00 - 18:00 4.00 r BOPSUR P PRE CHECK TREE STUDS FOR TIGHTNESS - TORQUED TO SPEC, SOME ARE LOOSE ON ALL FLANGES WITH TWO HANDTIGHT ON THE SWAB TO FLOW CROSS FLANGE, PAINT STUDS WITH LINE. INSTALL CATCH PAN. GREASE BOPE. FILL PITS WITH FLUID. BRING ON BOILER WATER. 18:00 - 00:00 6.00 BOPSUR P PRE TEST ALL BOP RAMS, KILL AND CHOKE VALVES. BOP TEST IS WITNESSED BY LOU GRIMALDI OF AOGCC. 5/13/2010 00:00 - 04:00 4.00 BOPSUR P PRE CONTINUE TESTING BOPS AND FLOOR VALVES. 04:00 - 10:30 6.50 BOPSUR N SFAL PRE I HCR AND BLIND SHEARS FAIL, OPEN UP AND REPLACE BLIND RAM SEALS. FIND BODY OF HCR IS BADLY PITTED, NEED TO REPLACE ENTIRE VALVE. PERFORM LOTO ON KOOMEY UNIT. REMOVE HCR VALVE FROM 13 -5/8" BOP STACK AT PERMAFROST PAD. SWAP OUT HCR VALVES. GREASE NEW HCR VALVE. CLOSE OUT LOTO ON KOOMEY UNIT. FUNCTION TEST BLIND RAMS & HCR VALVES. TEST GAS ALARMS PER AOGCC REGS. 10:30 - 11:30 1.00 BOPSUR N SFAL PRE FILL STACK. SHELL TEST BOP'S. PRESSURE TEST BLIND RAMS & HCR PER AOGCC REGS, 250PSI /3500PSI - PASS. 11:30 - 12:00 0.50 BOPSUR P PRE PJSM REGARDING DRIFTING SSV, SETTING TEST PLUG. Printed 6/10/2010 12:36:55PM • • North America - ALASKA - BP Page 2 of 2 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: MOBILIZATION (MOB) Start Date: 5/12/2010 End Date: 5/13/2010 X3- 00VM6 -C (471,525.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ j (ft) _ 12:00 - 14:00 2.00 BOPSUR P PRE OPEN WELL - OPSI. OPEN WHITEY VALVE - SLIGHT PRESSURE. RU DSM LUBRICATOR. DRIFT SSV, ADJUST SSV AS NEEDED & ATTACH FUSEABLE. L/D DRIFT. RU DSM LUBRICATOR. 14:00 - 14:15 0.25 BOPSUR P PRE PRESSURE TEST DSM LUBRICATOR - NO LEAKS. 14:15 - 15:00 0.75 BOPSUR P PRE SET TEST PLUG. GOOD INDICATION THAT PLUG IS SET. 15:00 - 15:15 0.25 BOPSUR P PRE STAB WITH PULLING TOOL. 15:15 - 16:00 0.75 BOPSUR P PRE I PRESSURE TEST TREE TO 250PSI/3500PSI, 1 CHART SAME - PASS. 16:00 - 16:50 0.83 BOPSUR P PRE PULL TEST PLUG & RD DSM LUBRICATOR. 16:50 - 17:05 0.25 RIGU P PRE PJSM REGARDING PULL COIL ACROSS & STABBING PIPE. 17:05 - 19:00 1.92 RIGU P PRE PICK UP INJECTOR. PULL TEST CT GRAPPLE. PULL COIL ACROSS & STAB INTO THE INJECTOR. 19:00 - 21:00 2.00 RIGU P PRE FILL REEL FORWARD AT 1 BPM, PUMP UNTIL RETURNS ARE CLEAN. PUMP SLACK BACKWARDS, 2.5 BPM @ 3200 PSI AGAINST CHOKE AND CT PACKOFF ELEMENT. POP OFF WELL, HOOK UP HYDRAULIC CT CUTTER. CUT 25 FT OF CT TO FIND CABLE. 21:00 - 22:30 1.50 RIGU P PRE INSTALL CT CONNECTOR. PULL TEST TO 35K. CIRCULATE TO WARM UP CT THEN INSTALL BHI CABLE HEAD. 22:30 - 00:00 1.50 RIGU P PRE PT INNER REEL VALVE AND CT CONNECTOR TO 3500 PSI. LIFT BTT WINDOW MILLING TOOLS TO RIG FLOOR. FILL WELL WITH 22 BBLS. Printed 6/10/2010 12:36:55PM 411 411 North America - ALASKA - BP Page 1 of 5 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/13/2010 End Date: X3- 0OVM6 -C (748,500.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 5/14/2010 100:00 - 01:10 1.17 STWHIP P j WEXIT 1 M/U BHA #1 - 1ST WINDOW MILLING BHA WITH 2.80 MILL AND STRING REAMER, 2 JTS 2.06 CSH AND 2.38" COILTRAK. M/U CT RISER AND PUMP SLACK FORWARD, ONE CT VOLUME THROUGH OPEN EDC. WHILE PUMPING CT PACKOFF IS SEEN TO BE LEAKING. 01:10 - 01:40 0.50 STWHIP N SFAL 100.0 WEXIT RIH 100 FT AND CLOSE ANNULAR. REPLACE CT PACKOFF ELEMENT. OLD ELEMENT LOOKS IN GOOD CONDITION. PT NEW PACKOFF ELEMENT TO 600 PSI, GOOD. 01:40 - 04:30 2.83 j STWHIP P WEXIT OPEN CHOKE AND RIH. PUMP MIN RATE. TAKE RETURNS OUT TO FLOWBACK TANK. GAS CUT RETURNS. AFTER 5600 FT HOLD 150 PSI ON CHOKE WHILE RIH. 04:30 - 08:15 3.75 STWHIP P WEXIT LOG TIE -IN FROM 9900 FT TO 10290' (PLUS 2FT CORRECTION). AT 10280FT, OPEN CHOKE & LIQUID PACK TUBING PUMPING WHILE HOLDING 15OPSI WHP. WET TAG AT 10,331FT. 08:15 - 10:15 2.00 STMILL P WEXIT TIME MILL WINDOW FROM 10,332.5FT PUMPING 1.5BPM/2480PSI HOLDING 200PSI WHP (WHILE SWAPPING WELL TO 2% SLICK KCL WITH 2PPB O ! - a BIO) WITH 0.3K STARTING WOB & 9.56PPG ECD. cJ ; TAKE RETURNS TO TIGER TANK. 10:15 - 18:30 8.25 STMILL P WEXIT CONTINUE TO MILL WINDOW FROM 10,333.1FT WITH THE WELL SWAPPED TO 2% SLICK KCL W/ 2PPB BIO. 1.5BPMIN & OUT @ 2400PSI, 100PSI MW, 1.4K WOB, 9PPG ECD. PVT = 216. 18:30 - 21:00 2.50 STMILL P j WEXIT CONTINUE MILLING WINDOW. 10337.70 FT 2660 PSI 0.55K DWOB MILL RATHOLE TO 10348 FT. 21:00 - 23:10 2.17 STMILL P WEXIT START 1ST UP PASS, REAMING 1 FT /MIN. 200 PSI MW AT BOTTOM AND TOP OF WINDOW. START MUD SWAP. SAMPLE FROM 10338 FT HAS 10% FORMATION. SECOND AND 3RD REAMING PASS HAS SLIGHT MW AT BOTTOM AND TOP OF WINDOW. 23:10 - 00:00 0.83 STMILL P WEXIT DRY RUN THROUGH WINDOW IS CLEAN TO BOTTOM. POOH. 5/15/2010 00:00 - 02:45 2.75 STMILL P WEXIT CONTINUE POOH. PERFORM JOG AT SURFACE, SMALL INCREASE IN AMOUNT OF CUTTINGS PJSM FOR CHANGE OUT BHA WHILE POOH. 02:45 - 04:00 1.25 DRILL P PROD1 TAG STRIPPER AND UD WINDOW MILL. MILL IS 2.79 NO -GO. M/U BHA #2 - NEW HYC TREX, 2.0 DEG XTREME, 2.38 COILTRAK WITH RES. M/U CT RISER, TEST TOOL AT SURFACE. Printed 6/10/2010 12:37:52PM • . North America - ALASKA - SP Page 2 of 5 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/13/2010 End Date: X3- 00VM6 -C (748,500.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 06:00 2.00 DRILL P PROD1 RIH BHA #2. 06:00 - 06:20 0.33 DRILL P PROD1 TIE -IN DEPTH FROM 9975 FT (NO CORRECTION). 06:20 - 06:25 0.08 DRILL P PROD1 RIH. WAS WAS SMOOTH. 06:25 - 07:45 1.33 DRILL P PROD1 DRILL BUILD FROM 10,347.8FT. USING NEW 8.6PPG GEO VIS PUMPING AT 1.7BPM/2875PSI FS, 100- 200PSI MW, 1 -2K WOB, 45R TF, 9.36PPG ECD, 80- 120FT /HR, PVT = 355. DRILL TO 10,450Ft. 07:45 - 08:10 0.42 DRILL P PROD1 WIPER TO THE BOTTOM OF THE WINDOW & TO TD - CLEAN BOTH WAYS. 08:10 - 10:05 1.92 j DRILL P PROD1 CONTINUE TO DRILL BUILD FROM 10,450FT. PUMP AT 1.7BPM/2875PSI FS, 100- 200PSI MW, 1 -2K WOB, 80 -110R TF, 9.45PPG ECD, 80- 120FT /HR, PVT = 355. DRILL TO 10,600FT. 10:05 - 10:50 0.75 DRILL P PROD1 WIPER TO THE BASE OF THE WINDOW - CLEAN BOTH WAYS. SLOWLY PUH & VERIFY CORRECT SURVEYS FOR LANDING POINT & NEEDED DLS. 10:50 - 11:05 0.25 DRILL P PROD1 CONTINUE TO DRILL BUILD FROM 10,620FT. PUMP AT 1.76PM/2900PSI FS, 100- 200PSI MW, 1 -2K WOB, 80 -11 OR TF, 9.45PPG ECD, 80- 120FT /HR, PVT = 355. DRILL TO 10,622FT. 11:05 - 11:45 0.67 DRILL P PROD1 SLOWLY PUH & DISCUSS WITH DD & GEO. 11:45 - 13:15 1.50 DRILL P PROD1 CONTINUE TO DRILL BUILD FROM 10,622FT. REDUCE PUMP RATE TO AID IN DLS AT 1.35BPM/2300PSI FS, 300- 400PSI MW,1 -2K WOB, 180 -110R TF, 9.45PPG ECD, 80- 120FT /HR, PVT = 355. DRILL TO 10,740FT. 13:15 - 13:35 0.33 DRILL p PROD1 WIPER TO THE WINDOW. PULL THROUGH WINDOW. OPEN EDC. BOTTOM'S UP REVEALED AN INCREASE IN AMOUNT OF CUTTINGS. 13:35 - 14:30 0.92 DRILL P PROD1 PUH JETTING 3 -1/2" LINER FROM 10,320FT TO _ 9100FT PUMPING 2.6BPM /3200PSI. 14:30 - 14:45 0.25 DRILL P PROD1 RIH JET 3 -1/2" LINER FROM 10,320FT TO PUMPING 2.6BPM /3200PSI. 14:45 - 15:35 0.83 DRILL P PROD1 CLOSE EDC. LOG DOWN FOR TIE -IN RFOM 10,300FT - PLUS 3 FT CORRECTION. 15:35 - 15:50 0.25 DRILL 1 P PROD1 WIPER TO TD. 15:50 - 16:15 0.42 DRILL P 1- PROD1 CONTINUE TO DRILL BUILD FROM 10,622FT. PUMP AT 1.71BPM/2850PSI FS, 200- 300PSI MW,1 -1.75K WOB, HS -90R TF, 9.49PPG ECD, 80- 120FT /HR, PVT = 351. _ DRILL TO 10,783FT. _ i 116:15 - 16:35 0.33 DRILL P PROD1 GEO WIPER, 14N SHALE MIGHT BE HIGHER THAN ANTICIPATED. Printed 6/10/2010 12:37:52PM • North America - ALASKA - BP Page 3 of 5 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/13/2010 End Date: X3- OOVM6 -C (748,500.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:35 - 18:05 1.50 DRILL P PROD1 CONTINUE TO DRILL BUILD FROM 10,783FT. REDUCE PUMP RATE TO AID IN DLS AT 1.35BPM/2300PSI FS, 300- 400PSI MW,1 -2K WOB, HS, 9.49PPG ECD, 80- 120FT /HR, PVT = 351. DRILL BUILD & LAND AT 10,810FT. DRILL TURN FROM 10,810FT TO 10,920FT USING REDUCE PUMP RATE TO AID IN DLS AT 1.35BPM/2300PSI FS, 300- 400PSI MW,1 -2K WOB, 90 -110R TF, 9.49PPG ECD, 80- 120FT /HR, PVT = 351. 18:05 - 18:50 0.75 DRILL P PROD1 WIPER TO THE WINDOW. 18:50 - 19:30 0.67 DRILL P PROD1 DRILL TO 11,000 FT. TD OF BUILD SECTION, 1 DIRECTIONAL OBJECTIVES HAVE BEEN MET. 19:30 - 23:00 3.50 DRILL P PROD1 1 POOH. PULL THROUGH WINDOW AND DOA 200 FT JOG, THEN OPEN EDC. PUMP 2.5 BPM OOH. PERFORM 2 PASSES ACROSS LINER LAP AREA, NOTHING SEEN. 23:00 - 23:15 0.25 DRILL P PROD1 PJSM FOR CHANGE OUT BHA. 23:15 - 00:00 0.75 DRILL P PROD1 TAG STRIPPER. L/D BHA #2. BIT HAS 2 CHIPPED TEETH AND SLIGHT RINGING ON THE NOSE, 1 -1. PICK UP BHA #3 - NEW TREX, 1.1 DEG MOTOR, 2.38 COILTRAK WITH RES. M/U CT RISER AND TEST TOOL AT SURFACE. BHA OAL = 68.03 FT. 5/16/2010 j 00:00 - 02:00 2.00 DRILL P PROD1 RIH BHA #3. PUMP 0.3 BPM / 1200 PSI WHILE RIH. 02:00 - 02:40 0.67 DRILL P PROD1 TIE -IN DEPTH FROM 10350 FT. CORRECT -2 FT. CONTINUE RIH. 02:40 - 04:50 2.17 DRILL P PROD1 DRILL FROM 11,000 FT. HOLD 120R TF FOR NOW TO CONTINUE RH TURN DOWN POLYGON. INITIAL ROP IS 120 -140 FT /HR WITH 3K DWOB. ROP SLOWS FROM 11010 -11020 FT. 1.64 / 1.65 BPM @ 2800 -3200 PSI. PVT = 328 BBLS. DRILL TO 11150 FT. 04:50 - 05:50 1.00 DRILL P PROD1 WIPER TRIP FROM 11150 FT TO WINDOW. CLEAN PASS UP AND DOWN. 05:50 - 07:35 1.75 DRILL P PROD1 DRILL FROM 11150 FT. REDUCE INC TO 92 DEG. SOME WT STACKING. CONTINUE TO DRILL LATERAL FROM 11,150FT. PUMP AT 1.7BPM /2900PS! FS, 100- 200PSI MW, 1 -2K WOB, 80 -110R TF, 9.75PPG ECD, 80- 120FT /HR, PVT = 335. DRILL TO 11,300FT. 07:35 - 09:09 1.57 DRILL P PROD1 WIPER TO THE WINDOW - CLEAN. 30K PUW OFF BOTTOM. WIPER TO TD - CLEAN. 09:09 - 11:35 2.43 DRILL P PROD1 CONTINUE TO DRILL LATERAL FROM 11,300FT. PUMP AT 1.74BPM /3000PSI FS, 100- 200PSI MW, 1 -2K WOB, 80 -110L TF, 9.72PPG ECD, 80- 110FT /HR, PVT = (CONDUCTING MUD SWAP). DRILL TO 11,408FT. STACKING, HARD TO DRILL. 11:35 - 12:15 0.67 DRILL P PROD1 WIPER TO THE WINDOW - CLEAN. PULL THROUGH WINDOW - CLEAN. OPEN EDC. Printed 6/10/2010 12:37:52PM North America - ALASKA - BP Page 4 of 5 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/13/2010 End Date: X3- 00VM6 -C (748,500.00 ) Project: Prudhoe Bay . PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (ft) 12:15 - 13:15 1.00 DRILL P PROD1 JET 3 -1/2" TUBING FROM 10,300FT & BACK DOWN TO 9100FT. CLOSE EDC. INCREASE IN AMOUNT OF CUTTINGS ON BOTTOMS UP & SIZE (PEAS SIZE GRAVEL). 13:15 - 13:30 0.25 DRILL P PROD1 LOG DOWN FOR TIE ACROSS RA TAG, PLUS 3FT CORRECTION. 13:30 - 14:10 0.67 DRILL P PROD1 WIPER TO TD. 14:10 - 17:45 3.58 DRILL P PROD1 CONTINUE TO DRILL LATERAL FROM 11,408FT. PUMP AT 1.74BPM/3234PSI FS, 100- 200PSI MW, 1 -2.5K WOB, 80 -110L TF, 9.78PPG ECD, 50- 80FT /HR, PVT = 329. DRILL TO 11,502FT. STACKING, TORQUING UP (TF ALL OVER THE PLACE). POH TO INSPECT BIT. 17:45 - 21:00 3.25 DRILL P PROD1 WIPER TO THE SHOE - CLEAN. PULL THROUGH WINDOW AND PERFORM 200 FT _ JOG, THEN OPEN EDC. 21:00 - 21:15 0.25 DRILL P PROD1 PJSM FOR CHANGE OUT BHA. 21:15 - 22:20 1.08 DRILL P PROD1 TAG STRIPPER AND UD BHA. BIT IS 4 -4, WITH RINGING ON THE NOSE. P/U BHA #4 - RE -RUN TREX BIT, NEW 1.2 DEG XTREME, 2.38 COILTRAK WITH RES. BHA OAL = 68.03 FT. 22:20 - 00:00 1.67 DRILL P PROD1 RIH BHA#4. 5/17/2010 00:00 - 01:20 1.33 DRILL P PROD1 CONTINUE RIH. TIE -IN DEPTH FROM 10350 FT. CORRECT -1.5 FT. CONTINUE RIH. 01:20 - 05:40 4.33 DRILL P PROD1 DRILL FROM 11502 FT. GRADUALLY REDUCE INC TO 88 DEG. 1.64 / 1.64 BPM @ 3200 -3500 PSI. INITIAL ROP IS 30-40 FT /HR WITH 1.5 -2K DWOB, LOTS OF CHERT IN SAMPLES. AFTER 11600 FT ROP INCREASES TO 100 FT /HR. DRILL TO 11650 FT. 05:40 - 07:20 1.67 DRILL P PROD1 WIPER TRIP FROM 11,650 FT TO WINDOW - CLEAN, 1.67BPM/315OPSI. 07:20 - 09:50 2.50 DRILL P PROD1 CONTINUE TO DRILL LATERAL FROM 11,650 FT. PUMP AT 1.67BPM /3200PSI FS, 100- 150PSI MW, 1.5 -2.5K WOB, 80 -110L TF, 9.96PPG ECD, 80- 100FT /HR, PVT = 305. DRILL TO 11,785FT. STACKING ISSUES & NO WOB 09:50 - 11:40 1.83 DRILL P PROD1 WIPER TO THE WINDOW - CLEAN, 1.7BPM /3090PSI. WIPER TO TD - CLEAN, 1.69BPM/3110PSI. 11:40 - 13:50 2.17 DRILL P PROD1 CONTINUE TO DRILL LATERAL FROM 11,785 FT. PUMP AT 1.67BPM /3200PSI FS, 100- 150PSI MW, 1.5 -2.5K WOB, 110 -90L TF, 10.05PPG ECD, 80- 60FT /HR, PVT = 290. DRILL TO TD 11,875FT. 13:50 - 15:00 1.17 DRILL P PROD1 WIPER TO THE WINDOW - CLEAN, 1.7BPM /3050PSI. Printed 6/10/2010 12:37:52PM • • North America - ALASKA - BP Page 5 of 5 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 5/13/2010 End Date: X3- 00VM6 -C (748,500.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:00 - 15:15 0.25 DRILL P PROD1 LOG DOWN FOR TIE -IN FROM 10,345FT, MINUS 4FT CORRECTION, 0.5BPM /1900PSI. 15:15 - 16:15 1.00 DRILL P PROD1 WIPER TO TD - CLEAN, 1.7BPM /3100PSI. TAG AT 11,877FT. _ 16:15 - 17:15 1.00 DRILL P PROD1 WIPER TO THE WINDOW LAYING IN LINER PILL - CLEAN, 1.7BPM/3560PSI. PULL THROUGH WINDOW - CLEAN. 17:15 - 20:30 3.25 DRILL P PROD1 ATTEMPT TO OPEN EDC - EDC FAILURE. PAINT EOP FLAG AT 10,238FT. CIRCULATE AT 1.75BPM/3380PSI WHILE CLL LOGGING FOR POSSIBLE KB PACKER PLACEMENT. PERFORM 500 FT JOG AT SURFACE. PJSM FOR UD BHA WHILE POOH. 20:30 - 21:30 1.00 DRILL P 1 PROD1 TAG STRIPPER. UD BHA, BIT IS 3 -2 WITH RINGING ON THE NOSE. REMOVE BHI UQC. INSTALL BOOT ON END OF CABLE. 21:30 - 23:30 2.00 CASING P RUNPRD M/U 2 JTS OF LINER AND M/U CT RISER. PUMP SLACK FORWARD, CYCLE PUMP 3 TIMES UP TO 3 BPM. CABLE IS HEARD MOVING. POP OFF WELL, CUT 251 FT OF CABLE, LEAVES 123 FT OF CABLE SLACK, ACCORDING TO SLB RECORDS. INSTALL CT CONNECTOR AND PULL TEST TO 35K, GOOD. PT TO 3500 PSI, GOOD. 23:30 - 00:00 0.50 CASING P RUNPRD M/U NOZZLE, PUMP 3/4 BALL FORWARD. BALL IS HEARD ROLLING. Printed 6/10/2010 12:37:52PM • North America - ALASKA - BP Page 1 of 10 Operation Summary Report Common Well Name: 01 -22 (AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: 'X3- 00VM6 -C (970,533.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 5/18/2010 00:00 - 00:20 0.33 CASING P RUNPRD CONTINUE CIRC 3/4 BALL FORWARD. 00:20 - 00:50 0.50 CASING P RUNPRD POP OFF WELL, RECOVER 3/4 BALL. STAND INJECTOR BACK, SET IT ON LEGS. PREP RIG FLOOR FOR RUNNING LINER. 00:50 - 01:10 0.33 CASING P RUNPRD PJSM FOR M/U LINER. 01:10 - 04:20 3.17 CASING P RUNPRD M/U LINER + SELBRT AS PER PROGRAM. FILL LINER WITH WATER AFTER 30 JTS. BHA OAL = 1638.49 FT. 04:20 - 07:30 3.17 CASING P RUNPRD M/U CT RISER AND PUMP 10 BBLS. RIH WITH LINER. PUMP GEOVIS AT 0.3 BPM / 1500 PSI. AT 10,300FT, DUE TO HIGH PRESSURE & VERY LITTLE PUMP RATE, SWAP COIL TO 2% DBL SLICK KCL FOR MORE PUMP RATE, 0.15BPM /1900PSI. WT CK AT 10,300FT = 34.5K, RIW= 18.8K. TAG AT 11,840FT. WORK PIPE & GET PAST LEDGE. BREAK OVER AT 43K, 13K RIW. TAG BOTTOM THREE TIMES AT 11,881.7FT (WITH 12K STACKED). 07:30 - 08:30 1.00 CASING P RUNPRD WITH LINER ON BOTTOM & 10K STACKED, PUMP 7BBLS OF 2% DBL SLICK KCL. LAUNCH 5/8" STEEL BALL WITH 3BBLS OF 8.6PPG GEO -VIS, FOLLOWED BY 2% DBL SLICK KCL, CIRCULATING AT 2.2BPM AT 3150PSI (BALL WAS HEARD GOING OVER THE GOOSENECK). WITH 25.5BBLS AWAY, REDUCE PUMP RATE TO 0.5BPM AT 1350PSI, ONE FOR ONE RETURNS. BALL LANDED AT 31.9BBLS, SHEARED AT 2300PSI. PUH TO CONFIRM RELEASED FROM LINER. 29K PUW - RELEASED FROM LINER. 08:30 - 11:15 2.75 CASING P RUNPRD FINISH SWAPPING COIL & WELL TO 2% DBL SLICK KCL. CIRCULATE AT 2.93BBLS IN AT 3600PSI, 2.48BPM OUT. REDUCE TO 2BPM IN AT 2260PSI WITH 1.97BPM OUT. WITH THE HOLE SWAPPED TO 2% DBL SLICK KCL, PUMP RATES ARE 2.08BPM IN/2175PSI WITH 1.98BPM OUT. SIMULTANEOUSLY, MIX 150BBLS OF 2% DBL SLICK KCL WITH 2PPB BIO. REDUCE PUMP RATE TO 1.5BPM = 1250PSI WITH 1.44BPM OUT. 11:15 - 11:25 0.17 CASING P RUNPRD PJSM REGARDING MIXING & PUMPING CEMENT. DISCUSSED HIGH PRESSURE PUMPING, HIGH WINDS & DOOR CLOSURES, SIM OPS AND PAD TRAFFIC. 11:25 - 11:50 0.42 CASING P RUNPRD PRIME UP & BATCH UP 15BBLS OF 15.8PPG CLASS 'G' CEMENT. CEMENT IS UP TO WEIGHT AT 11:45AM WITH 4.06HRS THICKENING TIME. Printed 6/10/2010 12:38:36PM • North America - ALASKA - BP Page 2 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: X3- 00VM6 -C (970,533.00 ) _ _ I Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) ( (ft) _ 11:50 - 12:10 0.33 CASING P RUNPRD ISOLATE COIL & SEND 5BBLS OF 2% DBL SLICK KCL TO CEMENTERS TO FLUID PACK THEIR LINE. PRESSURE TEST SLB CEMENT LINE 250PSI /3500PSI. PUMP 1.5BBLS OF 2% DBL SLICK KCL WITH 2PPB BIO TO TO THE COIL IRON. 12:10 - 12:20 0.17 CASING P RUNPRD PUMP 8.5BBLS OF 15.8PPG CLASS 'G' CEMENT INTO THE REEL. PUMPING AT 1BPM TA 670PSI. AFTER 1 BBL AWAY, INCREASE TO 1.5BPM, 1500PSI. FINAL PUMP PRESSURE 1.58PM AT 2300PSI WITH 1 FOR 1 RETURNS. 12:20 - 12:25 0.08 CASING P RUNPRD SEND 5BBLS OF 2% DBL SLICK KCL WITH 2PPB BIO TO THE CEMENTERS. CLEAN UP SLB CEMENT TRUCK. Printed 6/10/2010 12:38:36PM • • North America - ALASKA - BP Page 3 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: X3- 00VM6 -C (970,533.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (ft) 12:25 - 13:41 1 27 CASING P RUNPRD DISPLACE CEMENT WITH 2% DBL SLICK KCL WITH 2PPB BIO PUMPING AT 1.25BPM AT 2018PSI, 1 FOR 1 RETURNS. 5BBLS AWAY 1.25BPM AT 2087PSI, 1 FOR 1 RETURNS. 10BBLS AWAY 1.25BPM AT 1765PSI. INCREASE TO 1.5BPM AT 2250PSI, 1 FOR 1 RETURNS. 15BBLS AWAY 1.5BPM AT 1780PSI, 1 FOR 1 RETURNS. 20BBLS AWAY 1.5BPM AT 1571 PSI, 1 FOR 1 RETURNS. 25BBLS AWAY 1.54BPM AT 2080PSI, 1.5BPM RETURN RATE. 30BBLS AWAY 1.56BPM AT 2300PSI, 1.51BPM RETURN RATE. 132BBLS AWAY & REDUCE RATE TO 0.5BPM (TO PREVENT PREMATURE LAUNCH OF LWP). 35BBLS AWAY 0.48BPM AT 282PS1, 0.38 RETURN RATE. INCREASE PUMP RATE TO 1 1.5BPM STOP PUMPING AT 40.6BBLS AWAY. PU 13FT PAST BREAK OVER, PUW =28K. SIDE EXHAUST 5BBLS 1.5BPM AT 1800PSI (THIS BRINGS 2BBLS OF CEMENT AT 9600FT). STOP PUMPING & SET BACK DOWN WITH 10K AT 11,881 FT, HOWEVER THE BAKER CHOKE WAS LEFT CLOSED & THE CTP WENT FROM OPSI TO 280PSI. LAUNCH LWP, SHEARED AT 3600PSI.. DISPLACE LWP AT 0.62BPM/1850PSI (PER BOT REP). LWP IS PREDICTED TO LAND AT 6.2BBLS. SLOWLY PRESSURES UP. STOP AT 6.5BBLS AWAY (3000PSI CTP), 6.2BLS OF CEMENT ON THE BACKSIDE. PRESSURE BACK UP TO 3000PSI, SLOWLYS BLEEDS OFF WITH 0.1BPM RETURN RATE. PRESSURE BACK UP TO 3500PSI, SLOWLY BLEEDS OFF WITH 0.1BPM RETURN RATE. OPEN BAKER CHOKE & CHECK FLOATS - NO FLOW. PRESSURE UP LINER TO 500PSI & PUH. PRESSURE REDUCTION SEEN. PUMP RIGHT AWAY & PUMP - 2.5BBLS OF 2% DBL SLICK KCL WITH 2PPB BIO. 13:41 - 14:00 0.32 CASING P RUNPRD SLOWLY PUH AT 9FT /MIN TO 10100FT PUMPING 2% DBL SLICK KCL WITH 2PPB BIO, 0.6BPM AT 1100PSI WITH 0.52BPM RETURN RATE. 14:00 - 14:10 0.17 CASING P RUNPRD RIH AT 19FT /MIN TO 10236FT PUMPING 2% DBL SLICK KCL WITH 2PPB BIO, 0.6BPM AT 1100PSI WITH 0.65BPM RETURN RATE. 14:10 - 14:20 0.17 CASING P RUNPRD WAIT AT 10,236FT & PUMP 5BBLS OF 2% DBL SLICK KCL WITH 2PPB BIOAT 0.57BPM IN AT 1140PSI WITH 0.57BPM OUT. Printed 6/10/2010 12:38:36PM • • North America - ALASKA - BP Page 4 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 I End Date: X3- 00VM6 -C (970,533.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:20 - 16:45 2.42 CASING P RUNPRD POH AT 36FT /MIN PUMPING 0.87BPM IN AT 1337PSI WITH 0.75BPM OUT. AT 8000FT INCREASE PULLING SPEED TO 65FT /MIN, PUMPING AT 0.9BPM IN AT 840PSI WITH 0.65BPM RETURN RATE. 16:45 - 17:30 0.75 CASING P RUNPRD STOP AT 1500FT & FINISH CIRCULATING BOTTOM "S UP USING 1.57BPM AT 864PSI WITH 1 FOR 1 RETURNS. DIVERT 75BBLS OF 8.7PPG CEMENT LADEN FLUIDS TO THE TIGER TANK. 17:30 - 17:50 0.33 CASING P RUNPRD CONTINUE TO POH, CIRC 1.57BPM AT 864PSI. 17:50 - 18:20 0.50 CASING P RUNPRD TAG UP. STOP PUMPING. FLOW CHECK. AND CREW CHANGE 18:20 - 18:40 0.33 CEMT P RUNPRD PJSM FOR LD OF BHA 18:40 - 19:40 1.00 CEMT P RUNPRD LD LINER RUNNING TOOLS AND INSPECT. ONE SEAL GONE ONE ROLLED. 19:40 - 20:00 0.33 CEMT P RUNPRD PJSM FOR MU AND PU OF CLEAN OUT BHA. I MU SAFETY JOINT 20:00 - 22:25 2.42 CEMT P RUNPRD f PU CLEAN OUT BHA WITH 6 JOINT OF CSH AND 54 JOINTS OF PH6 STAB ON INJECTOR AND CIRCULATE THROUGH BHAFOR7BBLS 22:25 - 00:00 1.58 CEMT P RUNPRD RIH WITH CLEAN OUT BHA Q =0.9 BPM @ 1300 PSI 5/19/2010 00:00 - 00:10 0.17 CEMT P RUNPRD CONTINUE TO RIH FROM 9700 FT AT 10,200 FT RIH WT = 18,5 # FREE WT = 19,6 # UP WT = 30,0 # 00:10 - 01:05 0.92 CEMT P RUNPRD RIH THROUGH TOP OF LINER CLEAN FS =1600 PSI @ 0.94 BPM CONTINUE TO RIH TO PBTD AT 30 FT /MIN TAG PBTD AT 11,839 FT UNCORRECTED 01:05 - 01:35 0.50 CEMT P ■ RUNPRD POOH AT 60 FT /MIN AND 0.95 BPM TO TOP OF LINER 01:35 - 03:45 2.17 CEMT P RUNPRD POOH FROM TOL AT 0.95 BPM PJSM FOR STAND BACK OF CSH AND LD OF CLEAN OUT TOOLS. 03:45 - 04:30 0.75 CEMT P RUNPRD TAG UP FLOW CHECK WELL AND UNSTAB INJECTOR LD 6 JOINTS OF CSH DROP 1/2" BALL AND OPEN CIRC SUB AND STAND BACK 3 STANDS OF PH6 04:30 - 04:40 0.17 CEMT P RUNPRD HELD A KICK WHILE TRIPPING / FLOOR VALVE DRILL. RIG CREW PERFORMED GOOD AND WAS PREPAIRED WITH APPROPRIATE XO'S AND SAFETY JOINT MADE UP. DRILLER TOOK SOME TIME TO TEACH THE NEW ROUSTABOUT A LITTLE MORE ABOUT THE PROCESS. 04:40 - 05:30 0.83 CEMT P RUNPRD CONTINUE TO STAND BACK REMAINING 24 STANDS OF PH6 LD MILL AND MOTOR RECOVERD 1/2" BALL Printed 6/10/2010 12:38:36PM • • North America - ALASKA - BP Page 5 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: X3- 00VM6 -C (970,533.00 ) 1 Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: ' Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) 05:30 - 05:45 0.25 CEMT P RUNPRD MU SWIZZLE STICK AND STAB ON INJECTOR. - I 05:45 - 07:00 1.25 CEMT P RUNPRD JET STACK & DEAD LEGS. POP OFF WELL. LD SWIZZLE STICK BHA. PUT INJECTOR ON LEGS. 07:00 - 07:15 0.25 EVAL P OTHCMP PJSM REGARDING MU LOGGING BHA & HANDLING RA SOURCE. 07:15 - 09:00 1.75 EVAL P OTHCMP MU LOGGING BHA WITH 27 STANDS OF 1" CSH FROM THE DERRICK & 6 JTS of 2 -1/6" CSH. PU INJECTOR & MU TO LOGGING BHA. 09:00 - 10:40 1.67 EVAL P OTHCMP RIH WITH LOGGING BHA (BHA #7). CIRCULATE 2 %KCLAT0.31BPMAT187PSI. 10:40 - 12:50 2.17 EVAL P OTHCMP LOG DOWN AT 30FT /MIN. CIRCULATE 8.6PPG GEO -VIS 120K LSRV PERF PILL DOWN THE COIL AT 0.51 BPM / 1500PSI. TAG AT 11,837FT. PAUSE FOR 5MIN. LOG UP AT 60FT /MIN WHILE LAYING PERF PILL AT 0.65BPM /1500PSI. STOP ■ LOGGING AT 9400FT. 12:50 - 14:05 1.25 EVAL P ! OTHCMP POH FROM 9400FT CIRCULATING AT 1.15BPM AT 1715PSI. 14:05 - 15:15 ! 1.17 EVAL P OTHCMP FLOW CHECK - NO FLOW. POP OFF WELL. 1 STAND BACK INJECTOR. LD 6 JTS of 2- 1/16" CSH. STAND BACK 27 JTS of 1" CSH. 15:15 - 15:25 0.17 EVAL P OTHCMP PJSM REGARDING HANDLING RA SOURCE. 15:25 - 15:35 0.17 EVAL P OTHCMP LD LOGGING TOOL. 15:35 - 15:45 0.17 EVAL P OTHCMP PJSM REGARDING LINER LAP TEST. CEMENT AT 2000PSI CS AT 13:00. 15:45 - 16:00 0.25 EVAL P OTHCMP PRESSURE TEST LINER LAP TO 2000PSI - FAIL, 400PSI LEAK OFF RATE IN 1 MIN. RETEST LINER LAP THREE TIMES, SAME RESULTS. -- -- -- - - -- - -- 16:00 - 16:25 0.42 EVAL P OTHCMP PU INJECTOR & STAB ONTO WELL. PRESSURE TEST COIL TO 4000PSI - PASS. STAND BACK INJECTOR. 16:25 - 16:50 0.42 PERFOB P ! OTHCMP PREP TO RUN GUNS. 16:50 - 18:55 2.08 PERFOB N WAIT OTHCMP WAIT FOR LOGS & WAIT FOR PERF INTERVAL FROM TOWN. 18:55 - 19:15 0.33 PERFOB P OTHCMP PJSM WITH SLB PERFORATORS AND RIG CREW. 19:15 - 21:30 2.25 PERFOB P OTHCMP _ MU 6 1.56" GUNS FOR 120 FT OF 6 SPF PERFORATING GUNS. MU 27 STANDS OF PH6 AND 6 JNTS OF CSH. STAB ON INJECTOR AND CIRCULATE OUT BHA 121:30 - 00:00 2.50 PERFOB P OTHCMP RIH WITH GUNS Q =.6 BPM UPWT @10,120 FT =30K 5/20/2010 00:00 - 00:10 0.17 PERFOB P OTHCMP RIH TO PBTD AND TAG @ 11838.8 FT 00:10 - 00:30 0.33 PERFOB P OTHCMP PU TO UP WT AND STOP CORRECT DEPTH TO 11,836.3 FT AS PER PBTD FROM MCNL LOG GO THROUGH PRACTICE PUMP SEQUENCING TO GET PUMP POSITIONS DIALED IN RUN PUMP SEQUENCES TO FIRE (USED .3 AND .9 BPM ) NO INDICATION OF FIRE Printed 6/10/2010 12:38:36PM • i North America - ALASKA - BP Page 6 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: X3- 00VM6 -C (970,533.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (ft) 00:30 - 01:10 0.67 PERFOB N FLUD OTHCMP PU 20 FT TO MAKE SURE WERE FREE RIH TO TAG AND THEN PU TO UP WT. TRY CYCLE AGAIN USING HIGHER FLOW RATES. (USED .6 AND 1.2 BPM) NO INDICATION OF FIRE PU TO MAKE SURE WERE FREE - OK SLB - CONSULTING THERE TOWN GUYS WE THINK GUNS HAVE FIRED BUT WERE NOT SEEING INDICATION DUE TO LOW AMOUNT OF GUNS 01:10 - 01:50 0.67 PERFOB N FLUD OTHCMP POOH ON BOTTOM AND STOPED WE HAVE 1 FOR 1 RETURNS PVT VOL ON BOTTOM IS 341 BBLS 01:50 - 02:05 0.25 PERFOB N FLUD OTHCMP STOP AT 10,000 FT AND FLOW CHECK WELL - NO FLOW. 02:05 - 03:25 1.33 PERFOB N FLUD OTHCMP CONTINUE TO POOH 1 FOR 1 03:25 - 03:40 0.25 PERFOB N FLUD OTHCMP FLOW CHECK WELL AT 350 FT - NO FLOW 03:40 - 03:50 0.17 PERFOB N FLUD OTHCMP POOH 03:50 - 05:25 1.58 PERFOB N FLUD OTHCMP UNSTAB INJECTOR AND STAND BACK CSH BO FIRING HEAD AND GUNS DID NOT FIRE. 05:25 - 09:00 3.58 PERFOB N FLUD OTHCMP DOWN LOAD E FIR HEAD DATA AND TRY TO DETERMINE CAUSE OF MISFIRE TOP GUN WAS DRY AND NO SIGNS OF DAMAGED CONNECTION. E FIRE TOOL APPEARS TO BE WORKING RIGHT BUT DID NOT FIRE. SLB TO DOWNLOAD DATA TO HOUSTON. APPEAR THAT THE CTP WILL NOT BLEED OFF THEREBY SENDING A NO -FIRE SEQUENCE TO THE E -FIRE HEAD. IT ALSO APPEARS THAT THE PERF PILL & OTHER DOWN HOLE FLUIDS ADE TOO THICK & ACT AS A DOWN HOLE RESTRICTION THEREBY NOT ALLOWING PRESSURE TO FALL OFF FAST ENOUGH TO PROPERLY ACTIVATE THE E -FIRE HEAD. 09:00 - 09:15 0.25 PERFOB N FLUD OTHCMP SAFETY MEETING REGARDING MU PERF BHA. 09:15 - 09:40 0.42 PERFOB N FLUD OTHCMP MU PERF BHA PER PROGRAM. PU 27 STANDS OF 1" CSH FROM THE DERRICK. 09:40 - 09:55 0.25 PERFOB N FLUD OTHCMP WAIT & DISCUSS PROCEDURE WITH TOWN. 09:55 - 11:00 1.08 PERFOB N FLUD OTHCMP CONTINUE TO MU PERF BHA. MU 6JTS OF 2- 1/16" CSH. PU INJECTOR & MU TO PERF BHA. STAB ONTO WELL. 11:00 - 13:00 2.00 PERFOB N FLUD OTHCMP RIH WITH PERF BHA (BHA #9), CIRC MIN RATE AT 0.24BPM AT 223PSI. TAG & CORRECT DEPTH TO 13:00 - 14:30 1.50 PERFOB N FLUD OTHCMP WAIT FOR FLUID, CIRC MIN RATE AT 0.25BPM 223PSI WHILE WAITING FOR NEW FLUID. 14:30 - 17:15 2.75 PERFOB N FLUD OTHCMP SWAP WELL TO FRESH 2% DBL SLICK KCL AT 1.3BPM AT 4230PSI. PUMPED 190BBLS, PERF PILL WAS NOT SEEN. FINAL CIRCULATING j PRESSURE 1.34BPM AT 3750PSI. STOP PUMPING. Printed 6/10/2010 12:38:36PM • • North America - ALASKA - SP Page 7 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: X3- 00VM6 -C (970,533.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:15 - 18:00 0.75 PERFOB N FLUD OTHCMP PUH 2OF, 34K PUW. RIH & TAG TD. CORRECT DEPTH. USING PUMP #1. GO THROUGH PRACTICE PUMP SEQUENCING TO GET PUMP POSITIONS DIALED IN. PUMP SEQUENCES USED TO FIRE (USED 0.4 AND 1 BPM ). 0.4BPM = 355CTP, 1BPM = 1700PSI. SAME PRESSURE LAG /ISSUES AS BEFORE. ISSUES WITH PUMP #1 (WHEN MECHANICAL RATE IS ZERO, WE SHOW A IN MM RATE, WHEN PUMP REOSTAT IS TURNED UP PUMP GOES TO 1BPM THEN BACK TO 0.25BPM & VISA VERSA. SWITCH TO PUMP #2. SAME RESULTS (MORE PRONOUNCED & PRESSURE SPIKES AT 1000PSI). SWITCH BACK TO PUMP 1. ISOLATE & BLOCK IN PUMP #2. CHECK PULSATION DAMPENER PRE CHARGE ON BOTH PUMPS - BOTH OK — 1000PSI. ISOLATE BAKER CHOKE VIA CLOSED VALVE GO THROUGH PRACTICE PUMP SEQUENCING TO GET PUMP POSITIONS DIALED IN ON PUMP #1. OPEN BOTH REEL FILTERS. ATTEMPT TO FIRE GUNS. GOOD INDICATION OF GUN FIRING (LOSS OF RETURN RATE ON OUT MM & VIA SLB SHOT DETECTION). RECAP - SWAPPED WELL TO 2% DOUBLE SLICK KCL, ISOLATED BAKER CHOKE (CLOSED IN HARDLINE), ISOLATED PUMP #2 (CLOSED IN HARDLINE) AS THE CHECK VALVE MAY HAVE ISSUES & IS ANOTHER POSSIBLE LEAK SOURCE. WENT THROUGH BOTH REEL FILTERS. * * ** ANOTHER POSSIBLE ACTION ITEM FOR NEXT TIME WOULD BE TO BLEED OFF PRE CHARGE ON THE PULSATION DAMPENER TO REMOVE PRESSURE SPIKES. ALSO, TRY USING THE REOSTAT ON THE DRILLERS CONSOLE IF THE SLB REOSTAT IS IN QUESTION * * ** 18:00 - 18:05 0.08 PERFOB P OTHCMP PERFORATE WITH 1.56" 6SPF POWER JET PERF GUNS FROM 11,719FT TO 11,839FT. 18:05 - 18:25 0.33 PERFOB P OTHCMP POH TO TOL AT 10,200FT 18:25 - 18:45 0.33 PERFOB P OTHCMP FLOW CHECK AT TOL. 18:45 - 20:25 1.67 PERFOB P OTHCMP POH, CIRCULATE 1.22BPM AT 3000PSI. NO LOSSES ON TRIP OUT OF HOLE 20:25 - 20:40 0.25 PERFOB 1 P OTHCMP TAG UP AND FLOW CHECK WELL. RETURNS WERE 1 FOR 1 BEFORE PUMP WAS SHUT DOWN HAD PJSM DURING FLOW CHECK Printed 6/10/2010 12:38:36PM • North America - ALASKA - SP Page 8 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: X3- OOVM6 -C (970,533.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA 1 UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:40 - 22:45 2.08 PERFOB P OTHCMP UNSTAB INJECTOR AND LD CSH JOINTS AND JEWLERY. STAND BACK 27 STANDS OF PH6. HAVE PJSM WITH SLB PERFORATORS AND RIG CREW FOR LD OF GUNNS. { I _ LD GUNS, AND RD MO PERFORATORS. 22:45 - 23:45 1.00 BOPSUR P OTHCMP FUNCTION TEST BOP'S PER AOGCC REGS, PERMIT TO DRILL, AND WELL PLAN 23:45 - 00:00 0.25 ZONISO P RUNPRD PJSM FOR MU OF LTP RUNNING BHA 5/21/2010 00:00 - 01:00 1.00 ZONISO P RUNPRD MU LTP RUNNING BHA STAB ON 01:00 - 01:30 0.50 ZONISO P RUNPRD RIH WITH LTP BHA STACKED OUT AT DUMMY SSSV. PU CLEAN TRIED TO WORK BY SSSV AND CAN'T GET PASSED 2215.5 FT (UNCORRECTED) 01:30 - 01:55 0.42 ZONISO N DPRB 2,215.5 RUNPRD POOH TO EVAL BHA 01:55 - 03:10 1.25 ZONISO N DPRB 2,215.0 RUNPRD UNSTAB AND INSPECT BHA. ONLY FINDING IS SMALL INDENT ON BOTTOM OF MUEL SHOE. REDRESSED MUEL SHOE AND PU 3 MORE JOINTS OF SCH. STAB ON INJECTOR 03:10 - 03:30 0.33 ZONISO N DPRB 2,215.0 RUNPRD RIH WITH SECOND LTP RUNNING BHA TO 2215 AND PASS THROUGH DUMMY SSSV CLEAN 03:30 - 04:55 1.42 ZONISO P RUNPRD CONTINUE TO RIH WITH LTP BHA. 04:55 - 05:00 0.08 ZONISO P RUNPRD FIRE DRILL FOR ELECTRICAL FIRE IN THE AIR COMPRESSOR AREA 05:00 - 05:25 0.42 ZONISO P RUNPRD STILLRIH WITH LTP UP WT =31,7 RI WT =19,5 05:25 - 05:40 0.25 ZONISO P RUNPRD TAG TOL @ 10,236 FT STACK OUT PU TO BO +1 FT @ 10,236 FT PU 20 FT AND RE STAB IN STACK OUT AND PU TO BO + @ 10,236 FT CIRCULATE DOWN BACKSIDE & SHOWS A LOSS OF PRESSURE. PU UP HOLE FOR BALL DROP 05:40 - 06:00 0.33 ZONISO P RUNPRD LAUNCH 5/8" STEEL BALL WITH 1500 PSI HEARD THE BALL LEAVE THE REEL HOUSE. Printed 6/10/2010 12:38:36PM • • North America - ALASKA - BP Page 9 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: X3- 00VM6 -C (970,533.00 ) _ I Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (ft) 06:00 - 06:30 0.50 ZONISO N SFAL RUNPRD DURING WALK AROUNDS IN THE CELLAR, LOOSE TREE BOLTS WERE NOTICED BY NIGHT CREW (HAND TIGHT) ON THE MASTER BY HANGER FLANGE, THE LINES ON THE STUDS & NUT WERE LINED WHEN TIGHTENING. USE OPEN WRENCH TO TIGHTEN LOOSE BOLTS ON THE MASTER BY HANGER FLANGE (FLOW LINE SIDE). STOP MOVING COIL AT 10,200FT & ASSESS SITUATION. STOP PUMPING, HOWEVER BALL IS ON SEAT IN THE SETTING TOOL, BLEED OFF CTP. PUH TO HAVE THE OPTION TO CUT COIL & CLOSE MASTER SHOULD THE NEED ARISE. CIRCULATE ACROSS THE TOP TO KEEP THE HOLE FULL. MAKE NOTIFICATIONS. FINISH CHANGE OUT & WALK AROUNDS. 06:30 - 06:45 j 0.25 ZONISO N SFAL RUNPRD MOVE COIL TO KEEP IT WARM. PJSM REGARDING USING SWEENEY WRENCH & HAMMER WRENCH. 06:45 - 07:30 0.75 j ZONISO N SFAL RUNPRD TORQUE UP TREE STUDS. MASTER BY HANGER - 3 LOOSE ON FLOW LINE SIDE — 1/2 TURN EACH SSV TO FLOW CROSS - 3 LOOSE ON FLOW LINE SIDE — 1/2 TURN EACH SWAB TO FLOW CROSS - 10 LOOSE ON THE FLOW LINE SIDE — 1 -1/2 TURNS EACH SWAB TO RISER - 10 LOOSE ON THE FLOW LINE SIDE — 1 -1/2 TURNS EACH RISER TO BOB SWAB - 10 LOOSE ON THE FLOW LINE SIDE — 1 -1/2 TURNS EACH 07:30 - 07:50 0.33 ZONISO P RUNPRD RESUME KB PACKER SETTING PROCEDURE. SET DOWN AT 10,241 FT & STACK 10K. PU TO BREAK OVER. REPEAT FOR VERIFICATION. PRESSURE COIL UP TO 1590PSI TO ENGAUGE PACKER ELEMENT. STACK OUT 10K PAST RIW. PRESSURE UP BACKSIDE TO 2000PSI. 07:50 - 08:20 0.50 ZONISO P RUNPRD PRESSURE TEST BACKSIDE TO 2000PSI - PASS. 08:20 - 08:35 0.25 ZONISO P RUNPRD FINISH SETTING KB PACKER. SHEARED AT 2300PS1. TOP KB PACKER = 10,224.6FT 08:35 - 10:25 1.83 ZONISO P RUNPRD POH. 10:25 - 10:35 0.17 ZONISO P RUNPRD FLOW CHECK & PJSM REGARDING LD KB PACKER SETTING BHA. 10:35 - 11:15 0.67 ZONISO P RUNPRD LD 6 JTS of 2- 1/16" CSH. LD KB PACKER SETTING TOOL. 11:15 - 12:00 0.75 ZONISO P RUNPRD MU NOZZLE BHA. MU INJECTOR TO BHA. STAB ONTO WELL. Printed 6/10/2010 12:38:36PM • • North America - ALASKA - BP Page 10 of 10 Operation Summary Report Common Well Name: 01 -22 AFE No Event Type: COM- ONSHORE (CON) Start Date: 5/16/2010 End Date: X3- 00VM6 -C (970,533.00 ) Project: Prudhoe Bay Site: PB DS 01 Rig Name /No.: NORDIC 1 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum: 35 : 22 12/24/1994 00:00 @74.0ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ (ft) 12:00 - 13:35 1.58 ZONISO N WSEQ RUNPRD WAIT FOR DIESEL. ROAD TRAVEL IS EXTREMELY SLOW DUE TO POT HOLES & LONGER THAN NORMAL LINE UPS AT THE DIESEL DOCK. 13:35 - 14:00 0.42 RIGD P PRE SPOT & RU LITTLE RED SERVICES. 14:00 - 14:20 0.33 RIGD P PRE PJSM REGARDING PUMPING DIESEL. 14:20 - 14:33 0.22 RIGD P PRE PRESSURE TEST LITTLE RED DIESEL, 250PSI /4000PSI - PASS. 14:33 - 15:02 0.48 RIGD P PRE PUMP 65BBLS OF 6.8PPG DIESEL INTO THE COIL L AT 2BPM /1700PSI. 15:02 - 15:38 0.60 RIGD P PRE LAY IN DIESEL PUMPING AT 2BPM /1700PSI AT 80% PULLING SPEED. WITH DIESEL AT SURFACE, STOP PUMPING AT 500FT & CONTINUE TO POH DRY. 15:38 - 15:50 0.20 RIGD P PRE NO FLOW CHECK WHILE CONDUCTING PJSM REGARDING LD NOZZLE BHA. 15:50 - 16:00 0.17 RIGD P PRE POP OFF WELL. LD NOZZLE BHA. STAND BACK INJECTOR. 16:00 - 16:10 0.17 RIGD P PRE PJSM REGARDING GREASING TREE. 16:10 - 16:40 0.50 RIGD P PRE GREASE TREE VALVES. 16:40 - 17:00 0.33 RIGD P PRE DRIFT SSV. DRY ROD BPV. RD DSM EQUIPMENT. 17:00 - 18:00 1.00 RIGD P PRE ND BOP'S. 18:00 - 18:45 0.75 RIGD P PRE CREW CHANGE, WALK AROUNDS, AND PJSM FOR ND OF BOPS AND OTHER RD OPPERATIONS. 18:45 - 19:45 1.00 RIGD P PRE ND BOPS 19:45 - 21:30 1.75 RIGD P PRE NU TREE CAP AND PT WITH McOH TO 250 LOW AND 4,000 PSI RELEASE RIG FROM 01 -22B SEE 05 -25B FOR CONTINUE OPPS I Printed 6/10/2010 12:38:36PM • • � bp North America - ALASKA - BP Prudhoe Bay PB DS 01 01 -22 - Slot 22 01 -22B Survey: MWD Survey Report - Geographic 20 May, 2010 Midi BAKER HUGHES INTEQ • • M.. BAKER by Survey Report - Geographic s IINTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 01 -22 - Slot 22 Project: Prudhoe Bay TVD Reference: 35 : 22 12/24/1994 00:00 © 74.00ft (generic drillir Site: PB DS 01 MD Reference: 35 : 22 12/24/1994 00:00 c 74.00ft (generic drillir Well: 01 -22 North Reference: True Wellbore: 01 -22B Survey Calculation Method: Minimum Curvature Design: 01 -22B Database: EDM .16 - Anc Prod - WH24P Project Prudhoe Bay, GPB, PRUDHOE BAY Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 01, TR -10 -15 i Site Position: Northing: 5,941,932.14ft Latitude: 70° 14' 43.905 N From: Map Easting: 697,237.60ft Longitude: 148° 24' 24.004 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.50 ° Well 01 -22 API No 500292084800 Well Position +N / -S 0.00 ft Northing: 5,940,382.18 ft Latitude: 70° 14' 28.506 N ! +E / -W 0.00 ft Easting: 697,853.78 ft Longitude: 148° 24' 7.276 W j Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 01 -22B API No 500292084802 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) ( °) (nT) � BGGM2009 2/4/2010 22.44 80.92 57,686 Design 01 -22B Audit Notes: Version: Phase: ACTUAL Tie On Depth: 10,307.00 Vertical Section: Depth From (TVD) +NI-S +E/ -W Direction (ft) (ft) (ft) r) i 34.00 0.00 0.00 56.00 Survey Program Date: 5/20/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 10,000.00 1 : Camera based gyro multisho (01 -22) CB- GYRO -MS Camera based gyro multishot 10,050.00 10,307.00 2 : MWD - Standard (01 -22A) MWD MWD - Standard 10,330.10 11,877.00 MWD (01 -22B) MWD MWD - Standard 5/20/2010 2:07:04PM Page 2 COMPASS 2003.16 Build 71 • • 5►►.r BAINalt ` 0 bp Survey Report - Geographic HUGHES INTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well 01 -22 - Slot 22 Project: Prudhoe Bay TVD Reference: 35 : 22 12/24/1994 00:00 @ 74.00ft (generic drillir Site: PB DS 01 MD Reference: 35 : 22 12/24/1994 00:00 @ 74.00ft (generic drillir Well: 01 - 22 North Reference: True Wellbore: 01 - 22B Survey Calculation Method: Minimum Curvature Design: 01 - 22B Database: EDM .16 - Anc Prod - WH24P I Survey I Measured Vertical Map Map Depth Inclination Azimuth Depth +N / -S +E / -W Northing Easting (ft) ( °) ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 10,307.00 51.20 40.80 8,914.50 2,976.62 2,564.61 5,943,424.92 700,339.24 70° 14' 57.777 N 148° 22' 52.694 W TIP 10,330.10 55.51 40.80 8,928.28 2,990.65 2,576.72 5,943,439.26 700,350.98 70° 14' 57.915 N 148° 22' 52.341 W KOP 10,350.00 59.00 47.20 8,939.05 3,002.66 2,588.35 5,943,451.57 700,362.29 70° 14' 58.033 N 148° 22' 52.003 W I 10,375.00 62.00 50.00 8,951.36 3,017.04 2,604.67 5,943,466.38 700,378.23 70° 14' 58.175 N 148° 22' 51.528 W 10,422.05 74.42 53.38 8,968.80 3,044.02 2,638.91 5,943,494.24 700,411.75 70° 14' 58.440 N 148° 22' 50.532 W 10,435.17 76.34 57.21 8,972.11 3,051.25 2,649.35 5,943,501.74 700,421.99 70° 14' 58.511 N 148° 22' 50.229 WI 10,474.29 81.04 68.24 8,979.80 3,068.77 2,683.39 5,943,520.14 700,455.56 70° 14' 58.683 N 148° 22' 49.238 W I 10,520.93 84.72 84.37 8,985.62 3,079.66 2,728.20 5,943,532.21 700,500.06 70° 14' 58.790 N 148° 22' 47.935 W I 10,555.05 84.41 91.59 8,988.86 3,080.86 2,762.12 5,943,534.30 700,533.94 70° 14' 58.802 N 148° 22' 46.949 W 10,582.67 81.53 100.64 8,992.24 3,077.95 2,789.35 5,943,532.10 700,561.23 70° 14' 58.773 N 148° 22' 46.157 W 10,614.79 79.95 110.74 8,997.42 3,069.39 2,819.83 5,943,524.35 700,591.92 70° 14' 58.689 N 148° 22' 45.271 W 10,644.61 72.91 115.90 9,004.42 3,057.95 2,846.43 5,943,513.61 700,618.81 70° 14' 58.576 N 148° 22' 44.497 W 10,675.35 69.54 125.45 9,014.33 3,043.14 2,871.43 5,943,499.46 700,644.20 70° 14' 58.430 N 148° 22' 43.770 W 10,705.23 61.74 131.02 9,026.66 3,026.35 2,892.81 5,943,483.24 700,666.01 70° 14' 58.265 N 148° 22' 43.149 W 10,735.19 64.50 129.22 9,040.20 3,009.14 2,913.25 5,943,466.57 700,686.89 70° 14' 58.096 N 148° 22' 42.554 W 10,765.39 73.71 131.28 9,050.96 2,990.92 2,934.75 5,943,448.92 700,708.86 70° 14' 57.916 N 148° 22' 41.929 W 10,795.05 83.61 129.88 9,056.79 2,972.03 2,956.81 5,943,430.62 700,731.41 70° 14' 57.731 N 148° 22' 41.288 W 10,825.35 91.10 130.85 9,058.19 2,952.44 2,979.85 5,943,411.64 700,754.96 70° 14' 57.538 N 148° 22' 40.618 W 10,855.43 92.91 141.38 9,057.13 2,930.80 3,000.66 5,943,390.56 700,776.33 70° 14' 57.325 N 148° 22' 40.013 W 10,884.99 95.62 151.75 9,054.93 2,906.24 3,016.89 5,943,366.44 700,793.19 70° 14' 57.083 N 148° 22' 39.542 W I 10,925.49 94.30 166.48 9,051.40 2,868.65 3,031.22 5,943,329.24 700,808.51 70° 14' 56.714 N 148° 22' 39.125 W 10,952.27 93.53 175.13 9,049.57 2,842.30 3,035.49 5,943,303.01 700,813.46 70° 14' 56.454 N 148° 22' 39.001 W j 10,978.30 93.35 184.28 9,048.01 2,816.35 3,035.62 5,943,277.07 700,814.27 70° 14' 56.199 N 148° 22' 38.998 W 11,005.74 92.03 191.11 9,046.72 2,789.20 3,031.95 5,943,249.84 700,811.32 70° 14' 55.932 N 148° 22' 39.105 W 11,035.62 92.34 195.54 9,045.58 2,760.15 3,025.07 5,943,220.62 700,805.20 70° 14' 55.646 N 148° 22' 39.305 W 11,066.66 93.75 199.21 9,043.93 2,730.58 3,015.82 5,943,190.81 700,796.73 70° 14' 55.356 N 148° 22' 39.575 W 11,102.36 96.27 202.28 9,040.81 2,697.32 3,003.23 5,943,157.24 700,785.02 70° 14' 55.029 N 148° 22' 39.941 W 11,138.18 96.34 206.37 9,036.88 2,664.89 2,988.56 5,943,124.44 700,771.21 70° 14' 54.710 N 148° 22' 40.368 W 11,171.82 92.85 210.97 9,034.18 2,635.48 2,972.48 5,943,094.62 700,755.91 70° 14' 54.421 N 148° 22' 40.836 W 11,198.48 90.22 212.14 9,033.47 2,612.77 2,958.54 5,943,071.56 700,742.56 70° 14' 54.197 N 148° 22' 41.242 W 11,231.68 91.96 212.16 9,032.83 2,584.67 2,940.87 5,943,043.00 700,725.64 70° 14' 53.921 N 148° 22' 41.756 W 11,258.82 91.96 212.48 9,031.91 2,561.75 2,926.37 5,943,019.71 700,711.75 70° 14' 53.696 N 148° 22' 42.178 W 11,291.68 89.91 213.59 9,031.37 2,534.21 2,908.46 5,942,991.71 700,694.57 70° 14' 53.425 N 148° 22' 42.699 W 11,317.88 90.06 208.17 9,031.38 2,511.73 2,895.02 5,942,968.88 700,681.72 70° 14' 53.204 N 148° 22' 43.090 W 11,355.76 90.06 200.12 9,031.34 2,477.19 2,879.54 5,942,933.95 700,667.15 70° 14' 52.864 N 148° 22' 43.541 W 11,383.72 90.15 197.32 9,031.29 2,450.71 2,870.56 5,942,907.25 700,658.88 70° 14' 52.604 N 148° 22' 43.802 W 11,411.50 90.64 197.69 9,031.09 2,424.22 2,862.21 5,942,880.55 700,651.22 70° 14' 52.343 N 148° 22' 44.045 W 11,441.44 89.72 197.14 9,031.00 2,395.65 2,853.25 5,942,851.76 700,643.01 70° 14' 52.062 N 148° 22' 44.306 W 11,468.98 90.55 194.36 9,030.94 2,369.15 2,845.77 5,942,825.07 700,636.24 70° 14' 51.802 N 148° 22' 44.524 W 11,524.80 87.45 187.43 9,031.91 2,314.39 2,835.23 5,942,770.05 700,627.14 70° 14' 51.263 N 148° 22' 44.831 W 11,603.62 89.39 171.16 9,034.10 2,235.87 2,836.20 5,942,691.59 700,630.17 70° 14' 50.491 N 148° 22' 44.804 W ' 11,636.50 87.70 162.47 9,034.93 2,203.90 2,843.69 5,942,659.83 700,638.49 70° 14' 50.176 N 148° 22' 44.586 W 11,665.72 85.98 155.73 9,036.55 2,176.66 2,854.09 5,942,632.87 700,649.60 70° 14' 49.909 N 148° 22' 44.284 W 11,694.74 87.67 148.87 9,038.16 2,151.02 2,867.55 5,942,607.60 700,663.73 70° 14' 49.656 N 148° 22' 43.893 W 11,727.90 87.97 140.34 9,039.42 2,124.04 2,886.73 5,942,581.13 700,683.61 70° 14' 49.391 N 148° 22' 43.336 W 11,755.48 90.61 134.44 9,039.76 2,103.75 2,905.39 5,942,561.34 700,702.80 70° 14' 49.191 N 148° 22' 42.793 W 11,784.70 89.29 130.92 9,039.79 2,083.94 2,926.87 5,942,542.11 700,724.78 70° 14' 48.996 N 148° 22' 42.169 W 11,814.70 86.75 137.07 9,040.83 2,063.13 2,948.42 5,942,521.87 700,746.88 70° 14' 48.792 N 148° 22' 41.542 W 11,832.66 86.84 140.91 9,041.83 2,049.60 2,960.19 5,942,508.65 700,758.99 70° 14' 48.659 N 148° 22' 41.200 W 1 11,877.00 86.84 140.91 9,044.27 2,015.24 2,988.10 5,942,475.04 700,787.80 70° 14' 48.320 N 148° 22' 40.389 W TD 5/20/2010 2:07:04PM Page 3 COMPASS 2003.16 Build 71 • • wi t ' by Survey Report - Geographic HUGHES BAKER INTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well 01 -22 - Slot 22 Project: Prudhoe Bay TVD Reference: 35:22 12/24/1994 00:00 © 74.00ft (generic drillir Site: PB DS 01 MD Reference: 35 : 22 12/24/1994 00:00 © 74.00ft (generic drillir Well: 01 - 22 North Reference: True Wellbore: 01 - 22B Survey Calculation Method: Minimum Curvature Design: 01 - 22B Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N /-S +E/ -W Northing Easting - Shape (°) ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 01 -22B T1.3 0.00 0.00 9,059.00 2,042.55 2,822.95 5,942,498.00 700,622.00 70° 14' 48.590 N 148° 22' 45.191 W - survey misses target center by 103.57ft at 11744.95ft MD (9039.78 TVD, 2111.27 N, 2898.01 E) - Point 01 -22B Fault 3 0.00 0.00 74.00 1,811.64 2,739.86 5,942,265.00 700,545.00 70° 14' 46.319 N 148° 22' 47.609 W - survey misses target center by 8918.65ft at 10307.00ft MD (8914.50 TVD, 2976.62 N, 2564.61 E) j - Polygon Point 1 74.00 1,811.64 2,739.86 5,942,265.00 700,545.00 Point 2 74.00 2,069.44 2,446.51 5,942,515.00 700,245.00 01 -22B Fault 2 0.00 0.00 74.00 3,381.33 2,966.15 5,943,840.00 700,730.00 70° 15' 1.756 N 148° 22' 41.012 W - survey misses target center by 8858.86ft at 10307.00ft MD (8914.50 TVD, 2976.62 N, 2564.61 E) - Polygon Point 1 74.00 3,381.33 2,966.15 5,943,840.00 700,730.00 Point 2 74.00 2,971.20 3,155.46 5,943,435.00 700,930.00 Point 3 74.00 2,824.80 3,206.64 5,943,290.00 700,985.00 Point 4 74.00 2,971.20 3,155.46 5,943,435.00 700,930.00 01 -22B Fault 1 0.00 0.00 74.00 3,110.31 2,238.74 5,943,550.00 700,010.00 70° 14' 59.093 N 148° 23' 2.169 W - survey misses target center by 8847.51ft at 10307.00ft MD (8914.50 TVD, 2976.62 N, 2564.61 E) - Polygon Point 1 74.00 3,110.31 2,238.74 5,943,550.00 700,010.00 Point 2 74.00 2,691.24 2,577.88 5,943,140.00 700,360.00 01 -22B Polygon 0.00 0.00 74.00 2,995.39 2,996.03 5,943,455.00 700,770.00 70° 14' 57.960 N 148° 22' 40.147 W - survey misses target center by 8851.04ft at 10307.00ft MD (8914.50 TVD, 2976.62 N, 2564.61 E) - Polygon Point 1 74.00 2,995.39 2,996.03 5,943,455.00 700,770.00 Point2 74.00 2,733.23 3,074.18 5,943,195.00 700,855.00 Point 3 74.00 1,910.31 2,982.55 5,942,370.00 700,785.00 Point 4 74.00 2,133.38 2,678.28 5,942,585.00 700,475.00 Point 5 74.00 2,946.57 2,759.65 5,943,400.00 700,535.00 01 -22B T1.1 0.00 0.00 9,059.00 2,935.03 2,856.39 5,943,391.00 700,632.00 70° 14' 57.367 N 148° 22' 44.209 W - survey misses target center by 94.67ft at 10746.15ft MD (9044.63 TVD, 3002.75 N, 2920.97 E) - Point 01 -22B T1.2 0.00 0.00 9,054.00 2,775.08 2,890.21 5,943,232.00 700,670.00 70° 14' 55.794 N 148° 22' 43.227 W - survey misses target center by 133.67ft at 11061.17ft MD (9044.28 TVD, 2735.76 N, 3017.59 E) - Point Survey Annotations Measured Vertical Local Coordinates Depth Depth +N / -S +E/ -W (ft) (ft) (ft) (ft) Comment 10,307.00 8,914.50 2,976.62 2,564.61 TIP 10,330.10 8,928.28 2,990.65 2,576.72 KOP 11,877.00 9,044.27 2,015.24 2,988.10 TD Checked By: Approved By: Date: 5/20/2010 2:07:04PM Page 4 COMPASS 2003.16 Build 71 TREE= FMC GEN I • I 'WELLHEAD = FMC SAFETYOES: WELL ANGLE > 70° @ 10678' A CTUA TOR = AXELSON 01-22B KB. ELEV = 74' 8F. ELEV = 3758 DRLG D 1 i KOP = Max Angle = 0" @ 1 2215' H 5-1 /2" OTIS ROM NIP, ID = 4.562" 1 Datum MD = 10249' 'Datum TVD = R8C0' Ss GAS LIFT MANDRELS ST MD WD DEV 1Y PE VLVJ LA TCH PORT DATE 120" CONDUCTOR. 91 54, 9-40 ID = 19,124" I 110' 1 2920 2920 1 OTIS DOM RA 16 05/25/10 2 4870 4776 37 OTIS SO RA 20 05/25/10 1 11,3 i8" CSG, 724, L-80 BIG, ID 9 12 347" H 25139' 3 6560 6042 44 OTIS 1.:XvW RA 0 03/09/97 4 7828 6933 44 OTIS OrNY RA 0 11/06/82 Minimum ID = 1,810" @ 10225' 5 8558 7473 40 OTIS DMY RA 0 11/06/82 3-1/2" KB LINER TOP PACKER 6 8630 7528 40 OTIS DMY RA 0 11/06/82 7 9010 7824 37 OTIS DMY RA 0 11/06/82 'TOP OF 3-1/2" LNR H 9198' 8 9085 7884 37 OTIS DM' RA 0 11/06/82 9 9374 8120 34 CEMENTED DMY RA 0 11/06/82 10 9451 8184 33 CEMENTED DMY RA 0 11/06/82 5-1/2" TBG-PC, 17#, L-80 8RD ABM, --I 9478' I- 1 0232 bpf, ID = 4 892" '1 r 9478' H5-1/2" BOT PBR A SSY 1 XI 9498' J—I9-5/8" X 5-1/2" BOT 3-H PKR, ID= 4.00" 1 BEHIND 1 9509' 1 -15-1/2' X 4-1/2 X0, ID = 3.958' 1 CT LNR 1TOP OF 7" LNR H 9544' 1 ,,, ....„. .,..... 1 9604" H4-1/2" BOT SHEA ROUT SUB, ID= 3.958" 1 4-1/2" TBG, 12.6#, L-80 BUTT, —I 9606' .0152 bpf, ID = 3.958" I *.---------. . -...**-- 1 9606' H 4-1/2" TBG TAIL, ID = 3.958" 1 I 9614' 1ELM TT LOGGED (7??) 1 1 9-5/8" CSG, 47#, L-80 BTC, ID = 8.681 1-1 9839' I-A IL 1 7" LNR, 29#, L-80 BTC, .0371 bpf, 7" MILLOUT WINDOW (01-22A) 10038' - 10049' , ID = 6.875" 1-1 10038' H 10225' 113-1/2" KB LNR TOP PKR ID = 1.810" 1 E l 10236' 113-1/2" BTT DEPLOY SLV. ID = 1 780) 1 10236' 11 ESTIMATED TOP OF CMT 1 3-1/2" BKR WHIPSTOCK (04/22/10) 1-1 10330' \\\:\ :/8" MILLOUT WINDOW (01-22B) 10333' - 10338' 2-7/8" LNR, 6.5#, L-80, .0056 bpf. ID = 2.441" H 10335' 1„ I 10864' 1 2-3/8" MARKER JOINT I PERFORATION SUMMARY REF LOG: SLB CNUCCLIGR 05/19/10 I: I.-. L...... 1........... ANGLE AT TOP PEEP 86 @ 11719' Note: Refer to Production DB for historical perf data PS H 11839' SEE SPF . INTERVAL Opn/Sqz P DATE 1 56" 6 11719 - 11839 0 05/20/10 ] 1 2-3/8" LNR, 4 7#, L-80 STL, 0039 bpf, ID = 1 995" 1-1 11877' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/01/82 ROW 35 ORIGINAL COMPLETION WELL: 01-228 01/11/95 ? CTD SIDETFtACK (01-22A) PERMIT No: r2100340 05/21/10 NORDIC 1 CTO SIDETRACK (01-22B) API No: 50-029-20848-02 05/25110 PJC DRLG HO CORRECTIONS SEC 8, '110N, R1 5E,' 519' F'NL & 528' FWL '05/28/10 DAV/PJC GLV C/0 (05/25/10) BP Exploration (Alaska) • • sirtal arc taAsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01 -22B BP Exploration (Alaska), Inc. Permit No: 210 -034 Surface Location: 519' FNL, 528' FWL, SEC. 08, T1ON, R15E, UM Bottomhole Location: 1511' FSL, 3375' FWL, SEC. 05, T1ON, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, 0 , . eamount, Jr. Chair DATED this day of March, 2010. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e -mail) Department of Environmental Conservation w/o encl. (via e -mail) STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMON RECEIIE' . PERMIT TO DRILL AAC 25.005 .-floZSIVZ, 2 2 2010 1 a. Type of work: 1 b. Proposed Well Class: ® Development Oil ❑ Service - Winj ❑ Single Zone lc. Speci f P e l s proposed for. ❑ Drill IN Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone ❑ Coalbed Gas t ❑ Re -Entry ❑ Exploratory ❑ Service - WAG ❑ Service - Disp 4381(301I &Gas as 2. Operator Name: 5. Bond: -4 Blanket ❑ Single Well 11. Well Namlinctgalrfber: BP Exploration (Alaska) Inc. Bond No. 6194193 PBU 01 - 22B - 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 11700' TVD 8985'ss Prudhoe Bay Field / Prudhoe 4a. Location of Well (Govemmental Section): 7. Property Designation (Lease Number): Bay Oil Pool Surface: ADL 028329 519' FNL, 528' FWL, SEC. 08, T1ON, R15E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2318' FSL, 2987' FWL, SEC. 05, T1ON, R15E, UM May 20, 2010 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1511' FSL, 3375' FWL, SEC. 05, T1ON, R15E, UM 2560 26,550' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 74' feet 15. Distance to Nearest Well Open Surface: x- 697854 y- 5940382 Zone- ASP4 GL Elevation above MSL: 40.5' feet to Same Pool: 850' 16. Deviated Wells: Kickoff Depth: 10370 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 degrees Downhole: 3240 Surface: 2360 18. Casing Program: Specifications Top - Setting Depth - Bottom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2 -3/8" 4.7# L -80 STL 1450' 10250' 8801'ss 11700' 8985'ss 34 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 10612' 908Q' None 1 10595' 9071' 10567' Casing Length Size Cement Volume MD TVD Conductor / Structural 80' 20" 1900 # Poleset 80' 80' Surface 2589' 13 -3/8" 2000 sx Coldset III. 400 sx Coldset II 2589' 2589' Intermediate 9839' 9 -5/8" 500 sx Class 'G'. 300 sx Coldset I 9839' 8518' Production Liner 609' 7" 380 sx Class 'G' 10038' - 10647' 8692' - 9100' Liner 1408' 3 -1/2" x 2 -7/8" 164 sx LARC 9198' - 10606' 7975' - 9077' Perforation Depth MD (ft): 10368' - 10560' Perforation Depth TVD (ft): 8948' - 9051' 20. Attachments: ❑ Property Plat ® BOP Sketch Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report ® Drilling Fluid Program 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the fo / is true and correct. Contact Wilmer Hoffman, 564 -4592 Printed Name John , .v Ile,v / Title •ineering Team Leader prepa ey ble, 28 Signature l Phone 564 -4711 Date 3 Q /� Te rris Hubble, 5 64-46 4 -46 Commbsion Use Only Permit To Drill API Number: Permit A r val ate: See co ver le tt er for Number: / 50 - 029 - 20848 -02 - � 6 1 0 f other requirements Conditions of Approval: If box is checked, well may not be used to ex I produce coalbed metha hydrates, gas contained shales: [e p o re for, test, or p a . gas Y , or 9 e ::. ,(3 Other: 3500 s d I eS -i- Samples Req•d: ❑ es No Mud Log Req'd: 0 Yes [(i�No .- - Z SOD PSc: Annw l eSt H Measures: Yes ❑ No Directional Survey Req'd: Yes ❑ No /d '� APPROVED BY THE COMMISSION Date COMMISSIONER Form 0-401 Revi 07/2009 This permit is valid for 24 • nths • he date of approval (20 AAC 25.005(9)) Submit In Duplicate 3 -2 3. / o Q'1G1NAL , ,/e • 01 -22B — Coiled Tubing liking To: Chairperson Alaska Oil & Gas Conservation Commission From: Wilmer Hoffman by CTD Engineer Date: March 18, 2010 Re: 01 -22B Application for Permit to Drill Request CTD Drill and Complete 01 -22B program: Spud in May 20, 2010 Pre -Rig Work: (scheduled to begin May 1, 2010) 1. S Caliper tubing / drift with dummy whipstock (done on 1/26/10 - drift not deep enough) 2. F MIT -OA to 2,000 psi and MIT -IA to 3,000 psi (both passed on 2/10/10) 3. W AC -LDS; AC- PPPOT -IC, T (all passed on 2/12/10 - PPPOT-IC seal tite) 4. S Pull 5 -1/2" RQY Dummy SSSV in nipple at 2,215'. 5. S Drift with min 2.80" OD, min 15' long whipstock dummy to 10,400'. 6. E Set 3 -1/2" KB packer whipstock at 10,350' 7. 0 Bleed wellhead pressures down to zero. 8. 0 Bleed production flow lines and GL lines down to zero and blind flange 9. 0 Remove wellhouse, level pad 3/0.064 Rig Work: (scheduled to begin around May 20, 2010) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 2.74" window at 10,350' and 10' of rathole in Zone 2. 3. Drill Build: 3" OH, 600' (30 deg /100 planned) 4. Drill Lateral: 3" OH, 750' (12 deg /100 planned) with resistivity 5. Run 2 -3/8" L -80 liner leaving TOL at 10,250'. 6. Pump primary cement leaving TOC at 10,250', 7 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL/GR/CCL log 8. Test liner lap to 2,000 psi. y 9. Perforate liner per asset instructions ( -400') T��s 10. Set 3 -1/2" KB Liner Top Packer 11. Freeze protect well, set BPV, RDMO. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Generic GLV's 3/18/2010 • 01 -22B — Coiled Tubing Cling Mud Program: • Well kill: 8.6 ppg seawater / brine • Milling /drilling: 8.6 ppg Geo -vis or biozan for milling, new Geo -vis for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3" Casing Program: • 2 -3/8 ", 4.7 #, L -80, STL solid 10,250' MD — 11,700' MD • A minimum of 7 bbls of 15.8 ppg cement will be used for liner cementing (TOC at 10,250'). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi.- • The annular preventer will be tested to 250 psi and 2,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 93 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line — 26,550' Southwest • Distance to nearest well within pool — 850' (01 -16) . Anticollision Summary • No anti - collision issues Logging • MWD directional, Gamma Ray and resistivity will be run over all of the open hole section. • A cased hole GR/CCUCNL log will be run. • Hazards • The maximum recorded H2S level on Drill Site 01 is 30 ppm on well 01 -13 (11 -13- 2009). Drill Site 01 is not an H2S pad. • Lost circulation risk is low. No fault crossings are expected and the occurrence of losses in nearby wells is moderate. Reservoir Pressure • Reservoir pressure is estimated to be 3,240 psi at 8,800'ss (7.1 ppg EMW). Maximum surface pressure with gas (0.10 psi /ft) to surface is 2,360 psi. Wilmer Hoffman CTD Engineer 3/18/2010 1 0 TREE= FMC GEN I SAFETY NOTES WELLHEAD= FMC 01 -22A ACTUATOR= AXELSON KB. ELEV = 74' BF. ELEV= - KOP = 3758' Max Angle = 60 @ 10399' 1 221 H 5 -1/2" OTIS RQM NIP, ID = 4.562" Datum MD= 10249' 0 GAS LIFT MANDRES DatumTVD = 8800' SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2920 2920 1 OTIS RA I 13 -3/8" CSG, 72 #, L -80, ID= 12.347" H 2589' 1 — A 2 4870 4775 35 OTIS RA 3 6560 6042 43 OTIS RA 4 7828 6933 46 O11S RA 5 8558 7473 46 OTIS RA 6 8630 7528 45 011S RA 7 9010 7824 44 OTIS RA 8 9085 7884 44 Ol1S RA 9 9374 8120 43 CEMENTED RA I TOP OF3 -1/2" LNR W/4-1/2" TO LANDING SUB/PBR (-J 9198' I , ga 10 9451 8184 43 CBv1BVT® RA Minimum ID = 2.992" @ 9198' 1 947$' H 5 -1/2" BOTPBRASSY (BEHIND CT) 3 -1/2" LNR TOP �_ I 9498 ( — { 9 -5/8 X 5 -1/2" BOT 3-H PKR f ID= 4.000 "(BEHNDCT) I 5-1/2" TBG -FC, 17 #, L -80, .0232 bpf, ID = 4.892" 11 9509' I 9509' 11 5 -1/2" X 4-1/2" XO ( BEHND CT) ITOP OF 4 -1/2" TBG -PC 1 - 1 9509' 1 1 1 9593' ( 4 -1/2" OTIS XN NO-GO NIP (BEHIND CT), ID = 3.725" 9604' 4 -1/2" BOT SHEAROUT SUB (BEHIND CT) 1 9606' 4 -1/2" TUBING TAIL (BEHIND CT) I 9614' ELM TT - NOT LOGGED I ITOP OF 7" LNR H 9544' ... 1" --7 _? — 7" MILLOUT WINDOW @ 10038' -10049 I 9-5/8" CSG, 47 #, L -80, ID = 8.681" H 9839' 1 A ■ PERFORATION SUMMARY REF LOG: DUAL BURST TDT -P & CBT SONIC ANGLE AT TOP FERF: 59 @ 10368' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE •�•�• . 10567' H FlSH- GBP(08 /09/01) (CTM) ••••• 2 -1/8" 4 10368- 10370 0 07/06/96 ••••• 2 -1/8" 4 10395 -10408 C 03/12/96 ����������� � , 10596' H 3- 1/2 "X2- 7/8 "XO I 2-1/8" 4 10408 - 10414 0 07/06/96 01111°. 2 -1/8" 4 10414 -10415 C 03/12/96 2-1/2" 6 10474 - 10494 0 06/20/04 • 2-1/2" 6 10484 - 10494 0 02/26/03 2 -1/8" 4 10552- 10560 0 08/09/01 I 10530' H IBP ( ' ,,tp 4 i ►► i Nr•■•■• I TD I 10615' I FBTD — I 10609' I Di �i�i�i�i4 I 7" LNR, 29#, L -80, .0371 bpf, ID= 6.875" ( I 10647' I 2 -7/8" LNR CT, 6.5#, L -80, .0056 bpf, ID= 2.441" 1 10606' I DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 11/01/82 ORIGINAL COMPLETION 06/05/02 KB /KAK FlSH& FERF CORRECTION WELL: 01 -22A 01/11/35 CTDSIDETRACK 02/26/03 RL /KAK ADPERFS PERMIT No: 1941550 04/25/01 RN/TP CORRECTIONS 06 /20/04 LDK/KAK ADPBRFS APINo: 50 -029- 20848 -01 08/13/01 ATD /TP ADD 5 -1 /2" TBG SEC 8, T1 ON, R15E, 2052.19 FEL & 2595.34 FNL 05/03/02 KB/KAK CORRECTIONS 05/09/02 CMO /KK MAX ANGLE CORRECTION BP Explo ration (Alaska) 1 01 -22B - Coiled Tubing Clang TREE = FMC GEN I /� /� 1NELLHEAD= FMC 01 _2 2 B I SAFETY NOTES ACTUATOR = AXELSON KB. B E'/ = 74' Proposed CTD Sidetrack BF. ELEV = KOP = 3758' Max Angle = 10 © 10399' I 2215' H 5-1/2" OTIS ROM NIP, ID = 4.562" Datum MD = 10249' GAS L FT MANDRELS DatumTVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2920 2920 1 OTIS RA 2 4870 4775 35 OTIS RA 13 -3/8" CSG, 72#, L -80, ID = 12.347" H 2599' 6560 6042 43 OTIS RA 4 7828 6933 46 OTIS RA 5 8558 7473 46 OTIS RA 6 8630 7528 45 OTIS RA 7 9010 7824 44 OTIS RA ITOP OF 3 -112" LNR W /4- 112" TO LANDING SUBIPBR H 9198' 8 9085 7884 44 OTIS RA 9 9374 8120 43 CEMENTED RA ME' 10 9451 8184 43 CEMENTED RA Minimum ID = 1.812" II KB Packer at 10240 I 9478' H 5-1/2" BOT MR ASSY (BEHIND CT) 9499' I— 9-5/8" X 5-112" BOT 3 -H FKR, ID = 4.000" (BEHIND CT) I 5 -1/2" TBG -FC, 17 #, L -80, .0232 bpf, ID= 4.892" I—I 9509' I I 9509' H 5-1/2" X4-1/2" XO (BB-IIND CT) I ITOP OF 4 -112" TBG -PC H 9509' 1 ITOPOF7 "LNR -1 9544' 1 9604' H 4 -1/2" BOT SHEAROUT SUB (BEHIND CT) 1 9608' H 4-1/2" TUBING TAIL (BEHIND CT) 9- -m, 6t4y8.681" 9 839' ' ( 9614' I ELM TT -NOT LOGGED 1 I� �—� TSGR 9844' REF LOG: DUAL BURST TDT -P & CBT SONIC ANGLE AT TOP FERF: 59 r`ct710368' Note: Refer to Production W for historical perf data SIZE SFF NTERVAL OpnlSgz DATE 2 -1/8" 4 10368- 10370 0 07/06/96 2 -1/8" 4 10395- 10408 C 03/12/96 2 -1/8" 4 10408 - 10414 0 07/06/96 2 -1/8" 4 10414 -10415 C 03/12/96 2 -1/2" 6 10474 -10494 0 06/20/04 2 -1/2" 6 10484 - 10494 0 02/26/03 2 -1/8" 4 10552 - 10560 0 08/09/01 7 MLLOUT WNDOW @ 10038' - 10049' 0 \ 10240 I - 1 3 -1/2" Liner Top Packer 1 40 BCGL 10238' 10250' I-1_ TOL, TOC I 10350 I "I 3 -1/2" MONOBOREFKR WHIPSTOCK i e I 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.875" H 10647' I 59 - 2 -3/8" LNR -CT, 4,7 #, L -80, ID = 1 995" H 11700' I 1 10596' H 3-1/2" X 2-7/8" XO I 10567' —I FISH - CIBP (08/09/01) (CTM) J 2 -7/8" LNR -CT. 6.5 #, L -80, .0056 bpf, ID= 2.441" I—I 10606' I 1 H ' I DATE REV BY COMv1BVTS DATE REV BY COMMENTS PRUDHOE BAY UNfr 11/01/82 ORIGINAL COMPLETION 06/05/02 KB/KAK FISH & FERF CORRECTION WELL: 01 -22B 01/11/95 CTD SIDETRACK 02/26/03 RLMAK ADFERFS FERMC - No: 04/25/01 RN/TP CORRECTIONS 06/20/04 LDK/KAK ADPERFS API No: 50- 029 - 20848 -02 08/13/01 ATIYTP ADD 5-1/2" TBG 02/16/10 MSE PROPOSE) CTD SIDETRACK SEC 8, T10N, R15E 2052.19 FEL & 2595.34 FNL 05/03/02 KB /KAK CORRECTIONS 05/09/02 CMOMK MAX ANGLE CORRECTION BP Exploration (Alaska) 3/18/2010 FS MI BPPASSPORT ss BP Coil Tubing Report 0 bp 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 01 -22 - Slot 22 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 01 MD Reference: 35:22 12/24/1994 00:00 @ 74.00ft (generic drillir Well: 01 -22 North Reference: True Wellbore: Plan 1, 01 -22B Survey Calculation Method: Minimum Curvature Design: Plan 1 Database: EDM .16 - Anc Prod - WH24P Survey Tool Program Date 2/19/2010 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 10,000.00 1 : Camera based gyro multisho (01 -22) CB- GYRO -MS Camera based gyro multishot 10,050.00 10,337.00 2 : MWD - Standard (01 -22A) MWD MWD - Standard • 10,337.00 11,700.00 Plan 1 (Plan 1, 01 -22B) MWD MWD - Standard Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting DLeg V. Sec TFace (ft) ( ( (ft) (ft) (ft) (ft) (ft) 0100ft) (ft) ( °) 10,337.00 56.80 40.80 8,858.12 2,994.99 2,580.46 5,943,443.69 700,354.61 0.00 - 2,994.99 0.00 TIP 1 10,350.00 59.00 40.80 8,865.03 3,003.32 2,587.66 5,943,452.21 700,361.58 16.92 - 3,003.32 0.00 TIP 2 /KOP 10,370.00 60.28 42.27 8,875.14 3,016.24 2,599.10 5,943,465.43 700,372.68 9.00 - 3,016.24 45.00 End of 9 Deg /100' DLS 10,400.00 66.82 49.18 8,888.51 3,034.93 2,618.34 5,943,484.62 700,391.42 30.00 - 3,034.93 45.00 4 10,430.00 69.42 58.46 8,899.71 3,051.33 2,640.79 5,943,501.59 700,413.43 30.00 - 3,051.33 75.00 5 10,500.00 68.95 80.94 8,924.86 3,073.86 2,701.66 5,943,525.71 700,473.68 30.00 - 3,073.86 95.3 10,600.00 73.24 112.38 8,958.00 3,062.72 2,794.13 5,943,517.00 700,566.41 30.00 - 3,062.72 87.22 10,700.00 81.93 141.83 8,979.95 3,004.22 2,870.75 5,943,460.54 700,644.54 30.00 - 3,004.22 76.79 10,776.07 90.00 163.25 8,985.36 2,937.31 2,905.44 5,943,394.57 700,680.97 30.00 - 2,937.31 70.31 6 10,800.00 90.62 170.40 8,985.23 2,914.02 2,910.89 5,943,371.43 700,687.03 30.00 - 2,914.02 85.00 10,876.07 92.50 193.15 8,983.13 2,838.52 2,908.56 5,943,295.90 700,686.68 30.00 - 2,838.52 85.04 End of 30 Deg /100' DLS 10,900.00 91.90 195.96 8,982.21 2,815.38 2,902.55 5,943,272.61 700,681.28 12.00 - 2,815.38 102.00 10,976.07 89.97 204.89 8,980.97 2,744.18 2,876.03 5,943,200.74 700,656.64 12.00 - 2,744.18 102.11 8 11,000.00 89.93 202.02 8,980.99 2,722.23 2,866.51 5,943,178.55 700,647.70 12.00 - 2,722.23 -90.70 2/19/2010 2:47:58PM Page 3 COMPASS 2003.16 Build 71 NM BPPASSPORT BAKER HUGHES BP Coil Tubing Report 0 bp 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 01 -22 - Slot 22 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 01 MD Reference: 35 : 22 12/24/1994 00:00 @ 74.00ft (generic drillir Well: 01 -22 North Reference: True Wel!bore: Plan 1, 01 -22B Survey Calculation Method: Minimum Curvature Design: Plan 1 Database: EDM .16 - Anc Prod - WH24P Planned Survey MD Inc Azi TVDSS N/S FJW Northing Easting DLeg V. Sec TFace (ft) (°) ( °) (ft) (ft) (ft) (ft) (ft) ( ° / (ft) ( °) 11,100.00 89.79 190.02 8,981.23 2,626.29 2,838.96 5,943,081.92 700,622.68 12.00 - 2,626.29 -90.7iii 11,200.00 89.65 178.02 8,981.72 2,526.71 2,831.97 5,942,982.21 700,618.30 12.00 - 2,526.71 -90.6 11,276.07 89.56 168.89 8,982.24 2,451.22 2,840.63 5,942,906.97 700,628.94 12.00 - 2,451.22 -90.61 9 11,300.00 89.56 171.76 8,982.42 2,427.64 2,844.65 5,942,883.50 700,633.58 12.00 - 2,427.64 90.00 11,400.00 89.58 183.76 8,983.18 2,327.90 2,848.55 5,942,783.91 700,640.10 12.00 - 2,327.90 89.98 11,476.07 89.60 192.89 8,983.72 2,252.71 2,837.55 5,942,708.46 700,631.07 12.00 - 2,252.71 89.89 10 11,500.00 89.60 190.02 8,983.89 2,229.26 2,832.79 5,942,684.89 700,626.94 12.00 - 2,229.26 -90.00 11,600.00 89.61 178.02 8,984.58 2,129.69 2,825.80 5,942,585.18 700,622.56 12.00 - 2,129.69 -89.98 11,700.00 89.64 166.02 8,985.23 2,030.84 2,839.66 5,942,486.74 700,639.00 12.00 - 2,030.84 -89.90 TD at 11700.00 • 2/19/2010 2:47:58PM Page 4 COMPASS 2003.16 Build 71 s R ■ BPPASSPORT BYES BP Coil Tubing Report 0 bp 1NTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 01 -22 - Slot 22 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 01 MD Reference: 35 : 22 12/24/1994 00:00 @ 74.00ft (generic drillir Well: 01 -22 North Reference: True Wellbore: Plan 1, 01 -22B Survey Calculation Method: Minimum Curvature Design: Plan 1 Database: EDM .16 - Anc Prod - WH24P Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E / -W Northing Easting - Shape ( (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 01 -22B T1.3 0.00 0.00 8,985.00 2,042.55 2,822.95 5,942,498.00 700,622.00 70° 14' 48.590 N 148° 22' 45.191 W • - plan misses target center by 13.66ft at 11686.06ft MD (8985.14 TVD, 2044.42 N, 2836.49 E) - Point 01 -22B Fault 3 0.00 0.00 0.00 1,811.64 2,739.86 5,942,265.00 700,545.00 70° 14' 46.319 N 148° 22' 47.609 W - plan misses target center by 8938.24ft at 10337.00ft MD (8858.12 TVD, 2994.99 N, 2580.46 E) - Polygon Point 1 0.00 1,811.64 2,739.86 5,942,265.00 700,545.00 Point 2 0.00 2,069.44 2,446.51 5,942,515.00 700,245.00 01 -22B Fault 2 0.00 0.00 0.00 3,381.33 2,966.15 5,943,840.00 700,730.00 70° 15 1.756 N 148° 22' 41.012 W - plan misses target center by 8874.93ft at 10337.00ft MD (8858.12 TVD, 2994.99 N, 2580.46 E) - Polygon Point 1 0.00 3,381.33 2,966.15 5,943,840.00 700,730.00 Point 2 0.00 2,971.20 3,155.46 5,943,435.00 700,930.00 Point 3 0.00 2,824.80 3,206.64 5,943,290.00 700,985.00 Point4 0.00 2,971.20 3,155.46 5,943,435.00 700,930.00 01 -22B Fault 1 0.00 0.00 0.00 3,110.31 2,238.74 5,943,550.00 700,010.00 70° 14' 59.093 N 148° 23' 2.169 W - plan misses target center by 8865.46ft at 10337.00ft MD (8858.12 TVD, 2994.99 N, 2580.46 E) - Polygon Point 1 0.00 3,110.31 2,238.74 5,943,550.00 700,010.00 Point 2 0.00 2,691.24 2,577.88 5,943,140.00 700,360.00 IP 01 -22B Polygon 0.00 0.00 0.00 2,995.39 2,996.03 5,943,455.00 700,770.00 70° 14' 57.960 N 148° 22' 40.147 W - plan misses target center by 8867.87ft at 10337.00ft MD (8858.12 TVD, 2994.99 N, 2580.46 E) - Polygon Point 1 0.00 2,995.39 2,996.03 5,943,455.00 700,770.00 Point 2 0.00 2,733.23 3,074.18 5,943,195.00 700,855.00 Point 3 0.00 1,910.31 2,982.55 5,942,370.00 700,785.00 Point 4 0.00 2,133.38 2,678.28 5,942,585.00 700,475.00 Point 5 0.00 2,946.57 2,759.65 5,943,400.00 700,535.00 01 -22B T1.1 0.00 0.00 8,985.00 2,935.03 2,856.39 5,943,391.00 700,632.00 70° 14' 57.367 N 148° 22' 44.209 W - plan misses target center by 47.39ft at 10755.41ft MD (8984.95 TVD, 2956.76 N, 2898.50 E) - Point 01 -22B T1.2 0.00 0.00 8,980.00 2,775.08 2,890.21 5,943,232.00 700,670.00 70° 14' 55.794 N 148° 22' 43.227 W - plan misses target center by 1.59ft at 10942.15ft MD (8981.20 TVD, 2775.42 N, 2889.22 E) 2/19/2010 2:47:58PM Page 5 COMPASS 2003.16 Build 71 BAKER ■ BPPASSPORT MGM BP Coil Tubing Report 0 bp INTEQ Company: North America - ALASKA - BP Local Co -ordinate Reference: Well 01 -22 - Slot 22 Project: Prudhoe Bay TVD Reference: Mean Sea Level Site: PB DS 01 MD Reference: 35:22 12/24/1994 00:00 @ 74.00ft (generic drillir Well: 01 -22 North Reference: True Wellbore: Plan 1, 01 -22B Survey Calculation Method: Minimum Curvature Design: Plan 1 Database: EDM .16 - Anc Prod - WH24P - Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 11,700.00 8,985.23 2 -3/8" 2.375 3.000 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-5 +E/ -W (ft) (ft) (ft) (ft) Comment 10,337.00 8,858.12 2,994.99 2,580.46 TIP 1 10,350.00 8,865.03 3,003.32 2,587.66 TIP 2 /KOP 10,370.00 8,875.14 3,016.24 2,599.10 End of 9 Deg /100' DLS 10,400.00 8,888.51 3,034.93 2,618.34 4 10,430.00 8,899.71 3,051.33 2,640.79 5 10,776.07 8,985.36 2,937.31 2,905.44 6 10,876.07 8,983.13 2,838.52 2,908.56 End of 30 Deg /100' DLS 10,976.07 8,980.97 2,744.18 2,876.03 8 11,276.07 8,982.24 2,451.22 2,840.63 9 11,476.07 8,983.72 2,252.71 2,837.55 10 11,700.00 8,985.23 2,030.84 2,839.66 TD at 11700.00 I Checked By: Approved By: Date: 2/19/2010 2:47:58PM Page 6 COMPASS 2003.16 Build 71 Project: Prudhoe Bay stoTm &0° NC c WELLBORE DETAILS: Plan 1, 01 - 228 REFEREEWFORM8TION /Gtr Site: PBDS01 Co -ordinate(WE)Reference: Well 01- 22- Slot 22, True North BAKER Mawelic Fitld Parent Wellbore: 01 -22A 0 Well: 01 -22 Strength: 576.96.4.17 TeonMD: 10337.00 Vertical (TVD)Reference: Mean Sea Level NUGNE$ , Wellbore: PIan 1, 01 -22B operee Section (VS) Reference: Slot - 22(0.00N, 0.00E) Plan: Plan 1(01-22/Plan 1, 01 - 226) Sbd ro Measured Depth Reference: 35:22121241199400:00 5 74.008 (generic drgling rig) Calculation Method Minimum Curvature 1NTEQ 3145 1 a ` 01- 22101 22 01- 22/01 -2' 30.1 WELL DETAILS: 01 -22 2>/ I �dof9De 00'D /ar� 22BT1 NII,. Ground Level: 0.00 2975 0.0S +0 Northing EasBn8 La5 de Longitude 6W Slot ' .��� ■1 0.00 0 0.0 0.00 5940382.18 697853.78 70 °14'28.SO 06 N 148 °24'7..276W 22 28'1 1. •' SECTION DETAILS ANNOTATIONS I 2805 ��■,■'�L .. -_ . , . Sec MD Inc Azi ssTVD +N/-S 4E/-W DLeg TFace VSec Target Annotation 1 10337.00 56.80 40.80 8858.12 2991.99 2580.46 0.00 0.00 -2994.99 TIP 1 2721 -■■111§1 2 10350.00 59.00 40.80 8865.03 3003.32 2587.66 16.92 0.00 - 3003.32 TIP21KOP I 0 - 2213 T1.2 3 10370.00 60.28 42.27 8875.14 301624 2599.10 9.00 45.00 - 3016.24 End of 9 Deg/100' DLS .-.. 4 10400.00 66.82 49.18 8888.51 3034.93 2618.34 30.00 45.00 - 3034.93 4 . G 2635 5 10430.00 69.42 58.46 8899.71 3051.33 2640.79 30.00 75.00 - 3051.33 5 a 6 10776.07 90.00 163.25 8985.36 2937.31 2905.44 30.00 95.30 - 2937.31 6 V2550 7 10876.07 92.50 193.15 8983.13 2838.52 2908.56 30.00 85.00 - 2838.52 End of 30 Deg/100' DLS • 8 10976.07 89.97 204.89 8980.97 2744.18 2876.03 12.00 102.00 - 2744.18 8 9 11276.07 89.56 168.89 8982.24 2451.22 2840.63 12.00 269.30 -2451.22 9 x 2465 10 11476.07 89.60 192.89 8983.72 2252.71 2837.55 12.00 90.00 - 2252.71 10 t 9' 11 11700.00 89.64 166.02 8985.23 2030.84 2839.66 12.00 270.00 - 2030.84 TDat11700.00 02380 .1,2295 IS 0 02210 2125 01 -2213 T1.', _ • 2040 ' 1955' ' � ' 0 - 22/PIan1,01 -22B TD t 11711.00 1870' . 2040 2125 2210 2295 2380 2465 2550 2635 2720 2805 2890 2975 3060 3145 3230 3315 3400 3485 3570 West( - )/East( +) (85 ft/in) 8760 A 8:11 �I 8$80 I .... 1111 � Q. 8920 A 896073 900. W IiIIi I '- - - -- t 9040 9080 912 0 9160 AIIIIHIIINIIII 00 m m 9200 _, ., -3240 -3200 -31 -3120 -3080 -3040 -3000 -2960 -2920 -2880 -2840 -2800 -2760 -2720 -2680 -2640 -2600 -2560 -2520 -2480 -2440 -2400 -2360 -2320 -2280 -2240 . -2200 .. -2160 -2120 -2080 -2040 -2000 -1960 -1920 -1880 -1840 -1800 - 1760^ -1720 -1680 Vertical Section at 180.00° (40 ft /in) Project: Prudhoe Bay M M a uths. M ua ^ WELLBORE DETAILS: Plan 1, 01 -220 REFERENCE INFORMATION � Site: PBDS01 Meg,eticFied Parent Wellbore: 01 - 22A Co- rd0fe(wElRercrenne. weuof -zz - slot 22, True North BAKE 0 bp Well: 01 - Strength: 576e6e0 Tie on MD: 10337.00 Vertical ITVDI Reference. Mean Sea Level I Wellbore: Plan 1, 01 - 22B DipMe: 80.9 g� Section (VS( Reference: Slot - 22(0.00N,000E) Measured De Reference: 35 Date c P lan: Plan 1(01 22JPlan 1, 01 - 228) , a 2212241199409.00 @ 74.06it (generic ddllin s rig) Calculation Method Minimum Curvature IN TEQ 3430 - I ■ 3360- 3290 01 22/01 -2 . A 3220 01- 22/01 -22 - 3150 � : �� ' 3000---- 01 -01A/01-0l , ` 3010 /� CF�00 � • 2940 2871 �� 2800. ' 2730 2. 1 I 2590 11 1 + 2520 O� 1 p 2450 �� .. I II C I 2380 o O 2310 2240 21701 2 1. . 100 2031 R`- 01- . 6/01-16 1960 -___'-.� `� �O` 0 • � O 1890 111111116L . O 01 -22/P an 1 01-22B 1820, '-■�-'' 1751 Ol- I /01 -04B Plan 1680 0104/01 04 ' 1 P ___________\ , 1610 \ - Mean Sea Leve .0 01- 04t01 -04A 1540 1610 1680 1750 1820 1890 1960 2030 210 2170 2240 2310 2380 2450 2520 2590 2660 2730 280 2870 2940 3010 3080 3150 3220 3290 3360 3430 3500 3570 3640 3710 3780 3850 3920 3990 4060 4130 4200 West( - )/East( +) (70 ft /in) MIS • BPPASSPORT ' BAKER Travelling Cylinder Report 0 bp INTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well 01 -22 - Slot 22 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 01 MD Reference: 35 : 22 12/24/1994 00:00 @ 74.00ft (generic drilling rig; Site Error: O.00ft North Reference: True Reference Well: 01 -22 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 1, 01 -22B Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan 1 Offset TVD Reference: Offset Datum Reference Plan 1 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 10,337.00 to 11,700.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,366.60ft Error Surface: Elliptical Conic Survey Tool Program Date 2/19/2010 1 From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 10,000.00 1 : Camera based gyro multisho (01 -22) CB- GYRO -MS Camera based gyro multishot 10,050.00 10,337.00 2 : MWD - Standard (01 -22A) MWD MWD - Standard 10,337.00 11,700.00 Plan 1 (Plan 1, 01 -22B) MWD MWD - Standard Casing Points I Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 1 11,700.00 8,985.23 2 -3/8" 2.375 3.000 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) PB DS 01 01 -01A - 01 -01C - 01 -01C 11,500.00 10,125.00 756.54 685.55 85.91 Pass - Major Risk 01 -03 - 01 -03 - 01 -03 Out of range 01 -03A - 01 -03A - 01 -03A Out of range 01 -04 - 01 -04 - 01 -04 Out of range 01 -04 - 01 -04A - 01 -04A Out of range 01 -04 - 01 -04A - Plan #9 Out of range 01 -04 - 01 -04B Plan - 01 -04B Wp 2.0 11,700.00 10,750.00 1,001.20 486.66 516.17 Pass - Major Risk 01 -14 - 01 -14A - 01 -14A Out of range 01 -17 - 01 -17 - 01 -17 Out of range 01 -17 - 01 -17A - 01 -17A Out of range 01 -17 - 01 -17B - 01 -17B Out of range 01-17 - 01-17B - Plan #4 Out of range 01 -21 - 01 -21 - 01 -21 Out of range 01 -21 - 01- 21A- 01 -21A Out of range 01 -22 - 01 -22 - 01 -22 10,352.84 10,375.00 61.62 46.76 20.37 Pass - Major Risk 01 -22 - 01 -22A - 01 -22A 10,350.00 10,350.00 0.00 0.44 -0.41 FAIL - Major Risk 01 -23 - 01 -23 - 01 -23 Out of range 01 -32 - 01 -32A - 01 -32A Out of range 01 -32 - 01 -32A - 01 -32A wp05 Out of range 01 -33 - 01 -33 - 01 -33 Out of range CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 2/22/2010 1:37:33PM Page 2 of 8 COMPASS 2003.16 Build 71 1 01 -22B — Coiled Tubing Deng All Measurements are from top of Riser 3/17 /2010 L w CC 01-22B top of bag / BAG ‘44'" I 1 bttm of bag middle of blind /shears Blind /Shears TOTs middle of pipe /slips I 2" combi pipe /slips 1 .. ...... I I .--, 0 Mud Cross Mud Cross middle off low cross I middle of rams 1 2-3/8" combi pipe /slips I I TOTs middle of pipe /slips I 2" combi pipe /slips 1 I Swab Valve 1 1 Flow Tee 3/18/2010 Alaska Department of Natural Resources Land Administration System Page 1 of/ ( • Alaska Mapper Land Records /Status Plats Recorder's Search State Cabins Natural Resources 1 Alaska DNR Case Summary File Type: ADL File Number: 28329 Printable Case File SummMy See Township, Range, Section and Acreage? C New Search ) Yes 0 No LAS Menu 1 Case Abstract 1 Case Detail 1 Land Abstract File: ADL 28329 Ma V' Search for Status Plat Updates As of 03/23/2010 Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER - ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2501.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA -NRB ASSIGNMENT APPROVED Meridian: U Township: O10N Range: 015E Section: 05 Section Acres: 640 Search Plats Meridian: U Township: O10N Range: 015E Section: 06 Section Acres: 609 Meridian: U Township: O10N Range: 015E Section: 07 Section Acres: 612 Meridian: U Township: 010N Range: 015E Section: 08 Section Acres: 640 Legal Description 05 -28 -1965 ** *SALE NOTICE LEGAL DESCRIPTION * ** C14 -159 T1ON- R15E- UM 5,6,7,8 2501.00 U- 3- 7 End of Case Summary Last updated on 03/23/2010. http://dnr.alaska.gov/projects/las/Case Summary. cfm ?FileType= ADL &FileNumber = 2832... 3/23/2010 • TRANSMITTAL LETTER CHECKLIST WELL NAME , I/ O /-c !S' PTD# 42 /00doll /Development Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: �,� .i/.D,-,496'' .7.0?)/ POOL: ?:=3ere4 OE' /7,4J/Oi4 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(0, 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 through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 0 • E (0 ' CD Q co y 0 0 1 I 1 , ' of 0 0 w -C) ' DI a 5. EO a N o� V L @ o = rn, O � � � N O= co O > 1 .0 > p . > ; cc) a v, w' 0 NI @ N o) 0. co ), a a o, I ° aa) a s o m 3 -1 � N N N �O N. M , " O Z1 cV N� 3 Z a • t�� ca. a a a ( a (0 N p. all . a m 0 1!) o •zr m ' N co C co' y N M C N • CD O M N D E 0 a a 0 N E d N, co =1 CA, N D of Et D o' a) o) - L' rn a) N c a N co C' N, 0 C W > , .N C) p .N O 92 at m_( M 3 (0 0. c a E 0 CO O' N, CO N C -p 0. N, N ' (0 M, CO' 1 = CO 0 m' O U O O w a .T. 'O' E. N 0 a ) z ( 0. N � c, O 0 0 N' 6 O . _c �O. a 0 N O. 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(` (n J t J Hfflfl H fl ! ! 1 o o m' c a) m O, 3' m o 1 11 1 1 1 6 Q' o L L m o ° o o a a 3 z m3 3 a te ) a�.. o ' -O O 4 .- o co, 0 ' > • j a 0. O o) C, I 'o. 0) , o O'. o c'• P a > o' a) a - - o CO ' o c o a) o o c a o o u) -0 E a) f E' L 0 1 0 O g' c • '5 Q t a N N. a a rn N d W' o N L' C U a a al CO @ CO' o o' N' Of S' a cs p l y O' N' O a -o a1 O , m, E. o o a N N, of m c N ._ TD O'. �° c' n a 0) N > N . • 0) 3 C p o) 1' m o a a� �' co a - 0 L O . ` ° ° m • E LL J f0' .0 — D. 'O o 0, C, O L L Q - O L N • ' N . a) o >, 10 , L N "O N C N * a. C E N �� + N • , N �� p. .c a) C. . 0) 0 C O), a U O ' y _ 3 O (o 0, 0 (0, C� a) C, O CO ' X ', N' m • 3 0 V m m 0 a) a) _ 0 -o N' m = o f0 co (a O, c, c, l i.... U4 0 3 m m. m O y E 0 c a) - c p -o a d E • a) c; 0 ,.. ' v al a c ) (1) o 0 o a ) m m m c0. o o c c 0 cp o> 3 c CO m CO a � i m w w, 1) > a s o- . E 0) a) a; m E w' Q- -- p (I m a) c - 3 p ' c 2 `t H H 1- 'm a c >_ .- a a p O E m, 4, m e n3 m. L • a) a) 0) o 4 a aE ) w m= m, , I o O 2 2' 2(0 a(0 -o -= O O L O a N a) i0 a) o,, o' 0 c a, -J D �' _ cn '=• O, o a a c) Q, a z o o (n U U U 0 Q, Q a m m o N , 2 a D u), cn, U , ''1 a I E O _ r - N M V (1) (D I� a0 O O N M V I 1.0 C0 N- 00 0) co c, N l. M R V) () r °3 CA O c- N N N N N N N N N N M M co U O __— - _ - O O . N v 0 O 0) N 0) N () C N O £...,, -. V O CO M Q M CI M co .N co = N p) N CN N_ W - 0 0 CO CO ` co co ° y E „,, w 1 0 ' >, O E a. N C ` , C I O O : 0_ a • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • • tapescan.txt •• * ** REEL HEADER * * ** MWD 10/08/11 BHI 01 LIS Customer Format Tape * * ** TAPE HEADER * * ** MWD 10/05/14 3170648 01 2.375" CTK * ** LIS COMMENT RECORD * ** Remark File Version 1.000 Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 9826.0000: Starting Depth STOP.FT 11877.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 01 -22B FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 14' 28.506 "N 148 deg 24' 7.267 "W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 17 May 2010 API . API NUMBER: 500292084802 Parameter Information Block #MNEM.UNIT Value Description SECT. 08 Section TOWN.N T10N Township RANG. R15E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 74.00 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 74.00 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 C241 c9 i • tapescan.txt CASE.F N/A Casing Depth 0S1 . 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 log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by schlumberger GR CNL dated 19 May 2010 per Jennifer Flight with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 01 -22A through a milled window in a 3 1/2 inch liner. Top of window 10330 ft.MD (8854.3 ft.TVDSS) Bottom of window 10335 ft.MD (8857.2 ft.TVDSS) (9) Tied to 01 -22 and 01 -22A from 9827 feet MD to 10258 feet MD. (10) The interval from 11845 ft to 11877 ft MD (8968.5 ft. to 8970.3 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MwD -API units) ROP_AVG - Rate of Penetration, feet /hour RACLX - Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) 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 9834.04, 9832.81, ! - 1.23242 9841.63, 9841.02, ! - 0.615234 9845.54, 9844.1, ! - 1.4375 9848.2, 9847.18, ! - 1.02637 9851.08, 9850.87, ! - 0.205078 9884.83, 9885.03, ! 0.206055 9887.91, 9887.91, ! 0 9889.55, 9889.75, ! 0.205078 9895.71, 9894.27, ! - 1.43652 9899.2, 9897.96, ! - 1.23145 9902.89, 9901.25, ! - 1.6416 9908.64, 9906.79, ! - 1.84668 9911.31, 9909.87, ! - 1.4375 9914.8, 9913.15, ! - 1.64258 9923.21, 9921.57, ! - 1.6416 9931.75, 9930.11, ! - 1.64258 9936.27, 9934.83, ! - 1.4375 9940.17, 9939.14, ! - 1.02637 9947.35, 9947.14, ! - 0.205078 9953.92, 9953.71, ! - 0.205078 9956.59, 9956.38, ! - 0.206055 9960.49, 9959.66, ! - 0.821289 9965, 9964.38, ! - 0.616211 9971.69, 9971.49, ! - 0.205078 9979.29, 9980.52, ! 1.23145 9986.68, 9987.29, ! 0.616211 Page 2 • • tapescan.txt 9996.32, 9997.35, ! 1.02539 10027.7, 10028.1, ! 0.410156 10037.5, 10037.5, ! 0 10040, 10040.2, ! 0.205078 10049.8, 10050.3, ! 0.411133 10054.4, 10054.6, ! 0.206055 10058.9, 10059.5, ! 0.616211 10061.8, 10062.6, ! 0.821289 10064.4, 10064.6, ! 0.205078 10071.1, 10071.1, ! 0 10079.4, 10079.4, ! 0 10095, 10095, ! 0 10099.1, 10098.9, ! - 0.206055 10101.8, 10102.4, ! 0.615234 10110.5, 10111.5, ! 1.02637 10117.6, 10117.2, ! - 0.410156 10123, 10123, ! 0 10131, 10130.8, ! - 0.205078 10139.2, 10139.4, ! 0.205078 10143.3, 10144.1, ! 0.820312 10147.6, 10147.2, ! - 0.410156 10151.1, 10150.9, ! - 0.206055 10153.7, 10153.9, ! 0.205078 10161.9, 10161.1, ! - 0.821289 10165.2, 10165, ! - 0.205078 10167, 10167, ! 0 10168.9, 10168.9, ! 0 10173.2, 10173.2, ! 0 10175.6, 10175.2, ! - 0.410156 10177.9, 10177.3, ! - 0.615234 10181, 10180.6, ! - 0.410156 10182.8, 10182.6, ! - 0.206055 10189.4, 10189, ! - 0.410156 10194.3, 10194.1, ! - 0.206055 10207.1, 10207.1, ! 0 10222.4, 10221.5, ! - 0.820312 10252.7, 10251.5, ! - 1.23145 10257.9, 10256.8, ! - 1.02539 10259.5, 10259.5, ! 0 10262.6, 10262, ! - 0.616211 10264.6, 10265.1, ! 0.411133 10266.7, 10266.5, ! - 0.205078 10269.4, 10269.6, ! 0.205078 10290.3, 10292.4, ! 2.05176 10304.1, 10306.3, ! 2.25781 10306.9, 10310.4, ! 3.48926 10326.2, 10329.1, ! 2.87402 10333.4, 10335.7, ! 2.25781 10335.7, 10337.9, ! 2.25781 10337.1, 10340.2, ! 3.07812 10342.5, 10345.2, ! 2.66797 10355.2, 10356.5, ! 1.23145 10371.7, 10373.9, ! 2.25781 10373.1, 10375.4, ! 2.25781 10383.1, 10386.8, ! 3.69531 10389.2, 10392.9, ! 3.69434 10400.1, 10403.6, ! 3.48926 10403, 10406.5, ! 3.48926 10405.4, 10409.3, ! 3.89941 10425.6, 10428.8, ! 3.28418 10433.3, 10437.2, ! 3.89941 10444, 10447.6, ! 3.69434 10448.9, 10451.1, . 2.25781 Page 3 • • tapescan.txt 10454.6, 10456.7, ! 2.05273 10477, 10479.2, ! 2.25781 10503.7, 10504.7, ! 1.02637 10508.6, 10512.3, ! 3.69434 10513.2, 10516.7, ! 3.48926 10521.4, 10524.3, ! 2.87402 10523.3, 10526.8, ! 3.48926 10527.8, 10531.1, ! 3.2832 10534.6, 10537.6, ! 3.07812 10539.1, 10542.8, ! 3.69531 10572, 10574.7, ! 2.66797 10576.1, 10578, ! 1.84766 10601.4, 10606.3, ! 4.92676 10611.7, 10615.6, ! 3.90039 10621.3, 10625, ! 3.69434 10646.2, 10649.3, ! 3.0791 10672.5, 10675.8, ! 3.28418 10676.8, 10681.3, ! 4.51562 10683.6, 10687.9, ! 4.30957 10687.7, 10691.6, ! 3.90039 10692.2, 10695.5, ! 3.28418 10711.7, 10714, ! 2.25781 10722.2, 10724.4, ! 2.25781 10726.3, 10730, ! 3.69434 i 10740.4, 10742.7, 2.25781 10742.5, 10744.5, ! 2.05273 10745.4, 10747.8, ! 2.46387 10749.3, 10750.7, ! 1.43652 10761.5, 10762.6, ! 1.02637 10770.6, 10772, ! 1.43652 10774.1, 10775.5, ! 1.43652 10776.9, 10779.2, ! 2.25781 10781.7, 10783.7, ! 2.05273 10785.4, 10787.2, ! 1.84766 10796, 10797.1, ! 1.02637 10802.5, 10805, ! 2.46289 10829.2, 10830.8, ! 1.64258 10842.3, 10844, ! 1.6416 10879.8, 10881.7, ! 1.84668 10899.9, 10901.8, ! 1.84766 10912.1, 10914.9, ! 2.87305 10924.2, 10926, ! 1.84766 10931.3, 10932.9, ! 1.6416 10945.1, 10949.4, ! 4.31055 10983.2, 10986.9, ! 3.69434 10991.2, 10994.1, ! 2.87305 10994.7, 10997.2, ! 2.46289 11002.1, 11004.4, ! 2.25781 11004.4, 11007.1, ! 2.66895 11010.3, 11012.4, ! 2.05176 11014.6, 11016.3, ! 1.64258 11020.2, 11021, ! 0.821289 11026.3, 11028.3, ! 2.05273 11027.7, 11030.2, ! 2.46289 11042.9, 11045.1, ! 2.25781 11068.9, 11067.8, ! - 1.02637 11075, 11076.5, ! 1.43652 11119, 11121.4, ! 2.46289 11143.5, 11145.3, ! 1.84668 11417, 11419.7, ! 2.66797 11459.2, 11456.7, ! - 2.46289 11462.7, 11461, . - 1.6416 11465.6, 11463.7, . - 1.84766 Page 4 • • tapescan.txt 11475.6, 11474.8, ! - 0.820312 11482.8, 11482.4, ! - 0.411133 11493.7, 11492.9, ! - 0.821289 11504.6, 11504.4, ! - 0.205078 11533.7, 11534.7, ! 1.02637 11541.5, 11542.1, ! 0.616211 11558.3, 11557.1, ! - 1.23145 11604.7, 11603.9, ! - 0.821289 11617, 11616.6, ! - 0.410156 11622.5, 11621.3, ! - 1.23145 11630.5, 11631, ! 0.410156 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 237 records... Minimum record length: 10 bytes Maximum record length: 132 bytes * * ** FILE HEADER * ** MWD .001 1024 * ** LIS COMMENT RECORD * ** 1111111111 Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDc) log provided by schlumberger GR CNL dated 19 May 2010 per Jennifer Flight with BP Exploration (Alaska), Inc. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples units Size Length Page 5 • • tapescan.txt 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 114 Tape File Start Depth = 9826.000000 Tape File End Depth = 11877.500000 Tape File Level Spacing = 0.500000 Tape File Depth units = feet ° * ** FILE TRAILER * * ** Tape Subfile: 2 127 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD * ** 11111 1 11111111 Remark File version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) optical Log Depth scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length Page 6 + . • tapescan.txt 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 228 Tape File Start Depth = 9826.750000 Tape File End Depth = 11877.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * ** FILE TRAILER * ** Tape subfile: 3 241 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes ** TAPE TRAILER * * ** MWD 10/05/14 3170648 01 * ** REEL TRAILER * * ** MWD 10/08/11 BHI 01 Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS 0 Tape subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS Page 7 , 410 410 tapescan.txt 9826.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9826.5000 39.7745 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 11877.5000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9826.000000 Tape File End Depth = 11877.500000 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 9826.7500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 9827.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 11877.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 9826.750000 Tape File End Depth = 11877.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS 1 Page 8
