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207-098
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 05-10C Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 207-098 50-029-20263-03-00 11685 Conductor Surface Intermediate Liner Liner 8967 78 2680 5333 1562 2802 8760 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-1/16" x 2-7/8" 8451 28 - 106 28 - 2708 2358 - 7691 7518 - 9080 8880 - 11682 28 - 106 28 - 2707 2358 - 7494 7337 - 8723 8555 - 8967 none 520 2670 4760 7020 10530 8760 , 9433 1530 5380 6870 8160 10160 8678 - 11630 4-1/2" 12.6# L-80 24 - 9080 8380 - 8966 Structural 7" Baker LT , 7526 , 7344 No SSSV (TRDP-4A locked out) 7526 7344 Bo York Operations Manager Dave 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 0028326 23 - 8723 273 130 29444 28796 3664 15 0 0 1479 861 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 Samantha Coldiron at 11:14 am, Mar 08, 2024 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.03.07 21:08:43 - 09'00' Bo York (1248) RBDMS JSB 031424 WCB 2024-06-25 DSR-3/11/24 ACTIVITYDATE SUMMARY 2/14/2024 *** WELL SHUT IN ON ARRIVAL *** WELL SAFETY DRILL (MAN DOWN AT BOTTOM OF LADDER) RAN 3.68" CENTRALIZER, TAGGED LINER TOP PACKER @ 8,880' SLM (8,874' MD) RAN 33.5' X 3.66" OD DUMMY E-LINE GUNS TAGGED @ 8,880' SLM (8,874' MD) *** WELL SHUT IN ON DEPARTURE *** 2/17/2024 *** WELL SI ON ARRIVAL *** (PLUG SET/ADPERF) MIRU YJT E-LINE RU YJ ELINE AND T BIRD PUMPERS, PT 300/3000 PSI. SET PLUG AT 8760.0 FT, OFFSET = 11.6 FT, CCL STOP = 8748.4 FT, PT PLUG 500PSI OVER WHP WHP = 1000 PSI. CCL OFFSET = 9.5 FT, CCL STOP = 8668.5, INTERVAL 8678- 8708 FT OF 3.375" 6SPF 60PHASE HSC GEODYNAMICS RAZOR CHARGES GOOD INDICATION. PRESSURE DROP AFTER SHOOTING, GOT STICKY PROBABLY DIFFERENTIALLY STUCK, GOT FREE, POOH. ELINE COMPLETE. RDMO YJT E-LINE *** WELL SI ON DEPARTURE, DSO NOTIFIED *** Daily Report of Well Operations PBU 05-10C SET PLUG AT 8760.0 FT, INTERVAL 8678- 8708 FT OF 3.375" 6SPF 60PHASE HSC GEODYNAMICS RAZOR CHARGES RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION APR 2 7 2017 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed AGC Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ® 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: Z le P ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-098 3. Address: P.O.Box 196612 Anchorage, Development G3 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20263-03-00 7. Property Designation(Lease Number): ADL 0028326 8. Well Name and Number: PRUDHOE BAY UNIT 05-10C 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: Total Depth: measured 11685 feet Plugs measured 9433 feet true vertical 8967 feet Junk measured feet Effective Depth: measured 9433 feet Packer measured feet true vertical 8965 feet Packer true vertical feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20"94#H-40 28-106 28-106 1530 520 Surface 2680 13-3/8"72#MN-80 28-2708 28-2707 5380 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet KCANHM MAY j 6 Z f317 True vertical depth: See Attachment feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 24-9080 24-8723 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"Camco TRDP-4A SSV 2114 2114 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: 443 41 2 620 722 Subsequent to operation: 699 47555 0 1670 1412 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ® Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 53 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: Produc'en Engineer Challen er IN Contact Email: Finn.Oestgaard@bp.com Authorized Signature: t / o chone: +19075645026 Form 10-404 Revi , e L d f� S , 1�,t,I,Y - 3 2017 Revised 04/2017 1 T 57/ /j� Alp r7 v __. Suhmit nminai rim, • • 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 April 27, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for 05-10C, PTD # 207-098 to Set a Plug and Add Perforations. 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 • • Q,O 0 0 0 O o 0 (Nis 00 Cfl N O C (NI in d I� U 0 i 0 o o o (0 o (0 o oM coo � 6 ppN- LnC�OC CO CO CO 1-0 CO O CO O O In O) N CO CO N O Cr) d' N- In CA N- v- N N I- oo co co co F 00 N- Lo C)) CO CO In Ln CO CD O Nt N N N CO CO Lf) O N N I� CO CO C0 (1) oCOCON- 0O � o E , ooin0, co � co N- CO CO O O) O O 0mC N N N- C) CO r CA i i I i I I i i Z Q00000 co M L0 In r- CO CO �t N N N M to CO N- C N N- CO C)) W E— W o O co O O O 9) T • i 'cr Z J 00 00 00 J � J Z OO J • ind = # J M N N CV U 0. 0 -22 ( 0`0 N0\0N N M 0 6 M N r � CO CO M M CCOO O 10 L C I- CO co co 1n co CI) co J N N L0 r- s- C3) W W fr i— Q _Q C O - oUww CU 0 0u_ f � c Z Z � wwwwwpp Z_ Z_ _Z U u) Z Z J J J co 0] 0 r- LU COO _ M 000 O - CO 6a) (Y ) . d „ 6) 61 61 61 67 6) 6) O O 6) CO ti 0 • ob CD CD CD CD CD 0 CO CO CO CO CO CO CO CO CO CO CO CO F 0 F' 0 m M N- CO CO N LU 0 CO N N r- .0 N- 6) CO '- CO 00 r- N- co , U) 00 M a N- 0 N- 00 N- N- 0 O O 0 6) 4 0 ❑ o ti 6) 6) 6) 6) 6) 6) O 6) 6) 6) 0 CO N- W O d' 6) 6) 6) 6) 6) 6) O O O 6) 6) 6) a7 > p CO CO CO CO CO CO CO 0) °� CO Co 0 0 0 0 2 w ❑ ❑• ❑ w Z W w 0W O g g Y J ❑ 00 O U CO 0 0 0 0 0 0 O O U U W w W .F+ _ O. 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O LU LU o 0 C) m d a d7 CO N- 0O M 7I� 0 0 0 ' tf)ti 6) O M 0 0 N CO 0 0 0 0 0 0 0 0 0 0 0 0 c- co W w Y = H a - d 2 O cn u) cn cn LI- C‘ d a8 2• LLCCCCCCCCCl) CnWCC � aa. a � � � a. aaaaaaa d QmmCOmmmmmmmmmm a 0 t a, a d F- is N- N- N- N- N- ti N- N- ti ti N- ti N- N .- �- . . . . . r- r- r- r- ❑ 0 OO O O O o 0 0 0 0 0 0 0 0 0 W Z L W N N N N N N N N N N N N N N Zit 00 Oc Oco c 0w0 c c0 Oc c0 00 Occ 00 cO OO O W ❑ N N a N N N N N N N N N N N N N N Z a W UW y w W W W a M M M M M M cM M M- M M M M CM < ❑ - 1 _i - D -I D a a O m ❑ D W --1 -1JQ O W W a Cl) U LT4 a cn a s a, E • U U U U C) U U U U U U U U U o 0 0 0 0 0 0 0 0 0 0 0 0 0 r- i i i i i i i i i i i i a s Cl) 0 W N a' a 00Lb0000Lb00000tn m a 0 CL U -J C7 Ca W a 00000000000000 < < m m IL iL cn cn a s • • Packers and SSV's Attachment PRUDHOE BAY UNIT 05-10C SW Name Type MD TVD Depscription 05-10C SSSV 2113.92 2113.89 4-1/2" Camco TRDP-4A SSV 05-10C PACKER 7525.81 7344.15 7" Baker LT Packer 05-10C PACKER 8874 8550.2 4-1/2" Baker KB Top Packer • • p / a) & a o ƒ a) - Lu % / \ R - _/ t # w z > 0 5a O O U § \ 2 3 _j / k E ) \ / LU 0 / ._ L R O s / / / E % _0 k CU / < 0 (0 < / / 7 I ƒ A a E ƒ 6 0_ & co -\ Z 0 \ / m I u_ 2 R - - I 0 � < E = _0 LU q \ / q 0 - o \ = O �, 0 > z ■ 7 k » % £ co ƒ $ w / I co Sal 2 c * 2 2 e O O X / • / 0 / a H k © 3 a E _ < 1- L k ° / o ID � o O 6 < u ± � I I E o @o § ¥ 9 ® - = Rg ® mw LU 2 a / % Q. R % m 6 7 J O 2 < 0 u V@ m _1 p » c / < -, H _r_< x / 7 ƒ �_ m \ E O o b •7 L >" - < 0 - UJ $ - O 2 0 \ -) 2 R t IA / 25 / / cn / / < / O % I / : n < ._ • a ° / % � < \ � / � 0 R / ® 0 k / 0 = c / ° mI # C@ �� \ 0 � 0 k et� 2 / f ? ƒ / / \ < / ilk / / _Z / \ 3 _i c & E> / c < e < R ± co co@ » G 0 - e m e / - £ 0 b ® _' 11 \ \ g ~ / 2d \ D < _E EO99I ƒ \ / R > n a § 4 / z / / . 4 0 / g ® se c) y / 61 ? Co / / / / ° E % $ k # - m o , oz. -- m @ / m w a. < 0- m # O q / co , o = ? \ _c 0_ a IA u_ O o o -I 0 ± II �\ X " 2 ~ O ® O O ® C 0 O 5 O $ m ® I ® 5 $ u 0 L m L $ a as U e - 2 > � 9 � >$ / � -T1- = / b ƒ / \ \ 6 / $ t / f A o m 6 n : _ ± : 2 O < 2 CL w o- O < O 2 : 5 2 - O 2 < N- * w N. in N- ›- 3 3 % \ - / / / CO .TD *L- - ^ e 9 F- CO -CO- CO CO < TREE= 4-1/16"CIW * WELLFEAD= FMC SAFETY NOTES: WELL ANGLE>70°@ 9480'. ACTUATOR= BAKER C O 5-1 0 C KB. ELEV= 62.3' BF.ELEV= WA KOP= 5350' Max Angle= 970 @ 10181' 2116' —14-1/2"CAM-TRDP-4A TRSSSV,13=3.812" Datum MD= 9257° I Datum ND= 8800'SS 13-3/8"CSG,72#,MN-80,ID=12.347" —I 2703' GAS LFT MANDRELS I ST MD ND DEV TYPE VLV LATCH FORT DATE ' 1 3829 3829 0 TPD DOME T-2 16 08/02/15 Minimum ID = 2.377" Q@ 9767' 2 5756 5743 17 TPD DOME T-2 16 08/02/15 3-1/2" X 2-7/8" LNR XO 3 7460 7284 25 TPD DMY T-2 0 08/02/15 7521' —9-5/8"x 7"BKR LT A R w/TRACK& HMC LNR HGR,D=6.188" 9-5/8"CSG,47#,N-80,13=8.681^ H 7693' 1 9-5/8"CSG MLLOUT WINDOW(05-10A) 7693'-7743' (SECTION MLL) CALCULATED TOC N IA H 8500' - 4-1/2"TBG, 12.6#,L-80,.0152bpf,D=3.958" —{ 8874' *t - 8874' -14-1/2"BKR KB LT PKR,D=2.38" ►�I I k.1, TOC 144-1/2 TBG — 8$80• j./� t j V. 8880' J—3.70'BKR DEPLOY M3VT SLV, •// H w/3"SEAL BORE,D=2.972' r1 ;+• ►�11 i 8899' H3-1/2"HOWCO X NIP,D=2.813" 3-1/2"LNR,9.3#,L-80,SIL,.0087bpf,D=2.992" 8910' A I �.t• ►01v. ►•�► 8911' —13-1/2-x 3-31/16"X0,D=2.79" •►i1 144 ►•1 14► / • 44, 01 14, TOP OF WHIPSTOCK —{ 9077' ►i►� 1�#' P&LOUT WIDOW(06-10C): 9080'-9093' ►'► 4 7"LPL,29#,NT-80S,ID=6.182" H 9080' 0 140. 9433' H3-3/16"RIFT CSP(03/28/17) 7"LNR MILLOUT WINDOW(05-10B): ?t''k.• 9346'-9353'(BELOW 05-10C) �� I..#1. ;'''''i; �� 9767' H3-3/16"x 2-7/8'XO,13=2.377" PERFORATION SUMMARY REF LOG:SWS MCNUGR/CCL 10/04/07 ANGLE AT TOP FEW:29°@ 8790' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opr>fSgz DATE 3-1/16"LNR 6.2#,L-80,STL, 9767' 3-3/8' 6 8790-8805 0 03/28/17 0076bpf,ID=2.80' 2" 6 9560-9590 C 05/01/12 2" 6 9730-9760 C 04/30/12 PBTD H i 11650' 0410� 2" 6 9970-10025 C 10/05/07 2" 6 10050-10340 C 10/05/07 ,'�� 2" 6 10370-10510 C 10/05/07 2" 6 10535- 10585 C 10/05/07 2-7/8"LNR,6.4#,L-80,STL,.0058bpf,D=2.441' — 11682' 2" 6 10695-10725 C 10/05/07 2" 6 10770-11170 C 10/05/07 2" 6 11270-11630 C 10/05/07 DATE REV BY COMMENTS DATE REV BY COM EMS PRUDHOE BAY UNIT 09/11/77 ORIGINAL COMPLETION 05/08/12 JMD WELL FERMI',API#CORRECTION WELL: 05-10C 07/16/94 CTD SIDETRACK(05-10A) 08/28/15 DLI-VAD GLV C/O(08/02/15) PERMIT No:"1070980 09/12/96 CTD SIDETRACK(05-108) API No; 50-029-20263-03 10/06/07 NORDIC1 CTD SIDETRACK(05-10C) SEC 34,T11N,R15E,2662'FSL&5095'FEL 12/21/09 CRWSV DRLG DRAFT FNAL 05/08/12 JLS/JMD ADPERFS(04/30&05/01/12) BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, August 03, 2015 11:14 AM 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 Team Lead; 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 Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: OPERABLE: Producer 05-I0C (PTD #2070980) MIT-IA Passed All, Producer 05-10C (PTD#2070980) passed a MIT-IA on 08/02/2015 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 Please use caution while placing well on production due to fluid packed annuli and the potential for annular fluid expansion. Thank you, Kevin Parks (Alternate: Whitney Pett: BP Alaska-Well Integrity Coordinator GINGlobal Wells Organization SCANNED AUG 0 4 2015 Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, C Well Integrity Coordinator Sent: Tuesday, 30, 2015 3:23 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 Team Lead; AK, D&C Wireline Operations Team Lead; 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 Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: NOT OPERABLE: Producer 05-10C (PTD #2070980) Ined Inner Annulus Casing Pressure Above MOASP All, Producer 05-10C (PTD#2070980) was reported to have sustained inner annulus casing pressure above MOASP on 06/30/2015 after being shut in for planned facility maintenance. The pressures were reported to be inner annulus/outer annulus of 2400/450 psi. The well is reclassified as Not Operable until it can be placed online and evaluated. 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Tuesday, June 30, 2015 3:23 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 Team Lead; AK, D&C Wireline Operations Team Lead; 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 Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: NOT OPERABLE: Producer 05-I0C (PTD #2070980) Sustained Inner Annulus Casing Pressure Above MOASP Attachments: image001.png All, Producer 05-10C (PTD#2070980)was reported to have sustained inner annulus casing pressure above MOASP on 06/30/2015 after being shut in for planned facility maintenance. The pressures were reported to be inner annulus/outer annulus of 2400/450 psi. The well is reclassified as Not Operable until it can be placed online and evaluated. Tubing pressure could not be read, the surface safety valve was closed for well safe out. Plan forward: 1. APE: Evaluate plan forward for restoring tubing integrity or secure Thank you, SCANNED J U L 0 12015. Kevin Parks (Alternate: Whitney Petta BP Alaska-Well Integrity Coordinator GM A/ Global Wells Y�/ Organization Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Saturday, June 27, 2015 9:00 AM 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 Team Lead; AK, D&C Wireline Operations Team Lead; 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 Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: OPERABLE: Producer 05-I0C (PTD #2070980)TIFL Passed 1 • All, Producer 05-10C (PTD#2070980) passed a TIFL on 06/26/2015 after the well was placed on production. The passing TIFL verifies two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • A SSSV is not required Thank you, Kevin Parks (Alternate: Whitney rttt�- BP Alaska-Well Integrity Coordinator G�/r/ Global Wells �/ Organization Office: 907.659.5102 WIC Email:AKDCWelllntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, June 25, 2015 11:07 AM 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 Team Lead; AK, D&C Wireline Operations Team Lead; 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 Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.reqg@alaska.gov) Subject: UNDER EVALUATION: Producer 05-10C (PTD #2070980) Sustained Inner Annulus Casing Pressure Above MOASP All, Producer 05-10C (PTD#2070980) was reported to have sustained inner annulus casing pressure above MOASP on 06/22/2015. The pressures were reported to be tubing/inner annulus/outer annulus of 2400/2400/420 psi. The well is reclassified as Under Evaluation and is placed on a 28 day clock. Plan forward: 1. DHD: Perform TIFL 2. Wellhead: Positive Pressure Pack-off test (PPPOT-T) A copy of the TIO plot is included for reference. Thank you, Kevin Parks (Alternate Wre, -.- BP Alaska-Well Integrity Coordinator GWGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWeullntegrityCoordinator@bp.com 2 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Saturday, June 27, 2015 9:00 AM 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 Team Lead; AK, D&C Wireline Operations Team Lead; 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 Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) Subject: OPERABLE: Producer 05-10C (PTD#2070980) TIFL Passed Attachments: image001.png All, Producer 05-10C (PTD#2070980) passed a TIFL on 06/26/2015 after the well was placed on production. The passing TIFL verifies two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • A SSSV is not required Thank you, Kevin Parks {{ BP Alaska-Well Integrity CoordiGW nator ��jED JUL 0 1 Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Thursday, June 25, 2015 11:07 AM 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 Team Lead; AK, D&C Wireline Operations Team Lead; 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 Prod Controllers; G GPB FS1 Drillsites; Oestgaard, Finn; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Regg, James B (DOA) (jim.regg@alaska.gov) Subject: UNDER EVALUATION: Producer 05-10C (PTD #2070980) Sustained Inner Annulus Casing Pressure Above MOASP All, Producer 05-10C (PTD#2070980) was reported to have sustained inner annulus casing pressure above MOASP on 06/22/2015. The pressures were reported to be tubing/inner annulus/outer annulus of 2400/2400/420 psi. The well is reclassified as Under Evaluation and is placed on a 28 day clock. 1 • Plan forward: 1. DHD: Perform TIFL 2. Wellhead: Positive Pressure Pack-off test (PPPOT-T) A copy of the TIO plot is included for reference. Thank you, Kevin Parks (Alternate: Whitney Pettus) BP Alaska-Well Integrity Coordinator IwGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWelIIntegrityCoordinator{albp.com 2 Producer 05-10C(PTD#2070980)TIO Plot +n. -111-M 2004 -�Y 000 000 04 man 019116 PA. 041613 adnn par. mn,n OHw pp. avnn egp. Duron NA MS 0424. XHVZE • Image Project Well History File Cover Page This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~'~ - ~ ~ ~ Well History File Identifier Organizing (done> ^ Two-sided III (I'lll II III II III ^ Rescan Needed III IIIII II II III III RE CAN DI/GITAL DATA OVERSIZED (Scannable) Color Items: n ~XDiskettes, No. I ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: /s/ ~~l o Project Proofing Il l 11 11 it l l 111 I I III BY: Maria Date: I /s/ I Scanning Preparation L_ x 30 = 3 + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: /s/ ~ IIIIIIIIIIIIIIIIIII Production Scanning Stage 7 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scannin Preparation: __~~ES NO BY: Maria Date: ' ~., ~ ~ ~g /s/ ~M Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NYO , y BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II ~) II I II II IIIII ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III III III 10/6/2005 Well History File Cover Page.doc RECEIVED • • STATE OF ALASKA MAY 1 7 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC Ui4,_ 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U ors Other U Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Bp Exploration (Alaska) , Inc. Development © Exploratory ❑ r 207 -098 3. Address: P.0. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, Alaska 99519 -6612 50- 029- 20263 -03 -00 7. Property Designation (Lease Number): - 8. Well Name and Number: ADL- 028326 PBU 05 -10C 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11685 feet Plugs measured NONE feet true vertical 8967 feet Junk measured NONE feet Effective Depth measured 11650 feet Packer measured 7521, 8874 feet true vertical 8966 feet true vertical 7340,8550 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 94# H -40 31' -111' 31' -111' 1530 520 Surface 2673' 13 -3/8" 72# MN -80 30' -2703' 30' -2703' 538 _ 2670 Production 7664' 9 -5/8" 47# N -80 29'-7693' 29'-7496' 6870 4760 Liner 1529' 7" 29# NT -80 7521' -9050' 7340' -8699' 8160 7020 Liner 30' 3 -1/2" 9.3# L -80 8880' -8910' 8555' -8581' 10160 10530 Liner 857' 3- 1/16" 6.2# L -80 8910' -9767' 8581' -8999' Liner 1915' 2 -7/8" 6.4# L -80 9767'- 11682' 8999' -8967' Perforation depth Measured depth SEE ATTACHED feet . _ ��, ��._ ►VI II True Vertical depth feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 28'-9288' 28' -8881' 7" BKR LT PKR 7521' 7340' Packers and SSSV (type, measured and true vertical depth) 4 -1 /2" BKR KB LT PKR 8874' 8550' 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: 386 17637 46 309 Subsequent to operation: 399 17648 45 301 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development E • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil , E Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nita Summerhays Printed Name Nita Sum -rh., s Title Petrotechnical Data Technician /ice .f�g Signature ~/A WI r -- Phone 564 -4035 Date 05/16/2012 2 , ,),_ 5./8 -12- RBDMS MAY 17 2012 (4 Form 10-404 Revised 11/2011 ./4e. y% Original Only 05 -10C 207 -098 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 05 -10C 10/5/07 PER 9,970. 10,025. 9,000.75 8,999.86 05 -10C 10/5/07 PER 10,770. 11,170. 8,984.82 8,978.34 05 -10C 10/5/07 PER 10,695. 10,725. 8,989.57 8,987.94 05 -10C 10/5/07 PER 11,270. 11,630. 8,975.31 8,966.48 05 -10C 10/5/07 PER 10,370. 10,510. 8,995.55 8,995.17 05 -10C 10/5/07 PER 10,050. 10,340. 8,999.6 8,996.6 05 -10C 10/5/07 PER 10,535. 10,585. 8,994.16 8,991.38 05 -10C 4/29/12 APF 9,750. 9,760. 8,998.12 8,998.37 05 -10C 4/30/12 APF 9,730. 9,760. 8,997.66 8,998.37 05 -10C 5/1/12 APF 9,730. 9,740. 8,997.66 8,997.88 • 05 -10C 5/1/12 APF 9,560. 9,570. 8,996.98 8,997.63 05 -10C 5/1/12 APF 9,570. 9,580. 8,997.63 8,998.17 05 -10C 5/1/12 APF 9,580. 9,590. 8,998.17 8,998.56 05 -10C 5/1/12 APF 9,740. 9,750. 8,997.88 8,998.12 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 • • • 05 -10C DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/22/2012 Load meth,rig up start pressure_ test on lines (continued on 4/23/12 4/23/2012,T/I/0= 1600/2000/820 Freeze protect tbg and flowlkine pump 5 bbl neat spear and 33 bbls crude down tbg pump 5 bbl neat spear followed by 33 bbls crude in ;flowline,pressure flowline up to 1500 psi rig down FWHP= 800/2000/820 4/24/2012;T/I/O = SSV/1350/610. Temp = SI. WHPs (eval high IAP). AL SI @ lateral valve, ALP = 1350. AL open @ casing valve, no IA companion. ASV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 11:00. 4/24/2012 ;T /I /0= 500/1360/620 Temp =SI Assist SS -Line open SSSV (PERFORATING) Pumped 2 bbls of Neat Meth down Tbg, followed by 32 bbls of 70* Crude and then 'a 3 bbl Neat Meth tail to Pump Open SSSV. SS -Line in Control of Well per LRS departure. FWHP's= 1545/1360/620 CV =OTG 4/24/2012:* ** WELL SHUT IN ON ARRIVAL * ** (Perforating) TAG TRSSSV WITH 3.84" NOGO CENT. AT 2095' SLM 'RAN 3.84" NOGO WITH FLAPPER CHECKER(92" nogo to pins) TO 2091' SLM (4'' high) LRS PUMPED —35 BBLS OF CRUDE TO OPEN SSSV FLAPPER (see LRS log) IRAN 3.84" NOGO WITH FLAPPER CHECKER(92" nogo to pins) TO 2095' SLM, 'FUNCTIONED SSSV, APPEARED TO WORK PROPERLY * ** NOTE: CONTROL LINE WAS GASSED UP * ** `:. CURRENTLY RIH W/ 2.25" CENT, 10'x2" DUMMY GUN * ** CONT WSR ON 4/25/12 * ** 4/25/2012 * ** CONT WSR FROM 4/24/12 * ** (Perforating) :DRIFT WITH 2.25" CENT, 10'x2" D.GUN TO DEVIATION AT 9448' SLM ***WELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED * ** 4/27/2012`T/I/0= 1718/1400/600 ( Pre -E -Line Load and Kill ) Rig to tree cap. Pump 5 bbls ' neat meth followed by 307 bbls 1% KCL with Slickem down TBG. WSR continued on 04- 28 -12. 4/28/2012:T/I/0= 1718/1400/600 ( Load and Kill ) WSR continued from 04- 28 -12. Continue ; pumping 307 bbls 1% KCL with Slickem down TBG. Pump 5 bbls neat meth spacer ;followed by 38 bbls diesel @ 90* for freeze protect. RDMO FWHP= 0/1468/740 ' Wing =shut / swab =shut / ssv =open / master =open / IA and OA open to gauges. Operator notified. 4/28/2012' * ** WELL SHUT -IN ON ARRIVAL * ** (SLB E -LINE DRIFT TRACTOR RUN W/ DUMMY 2" GUN) `INITIAL T /I /O = 0/1450/620 PSI RIH W/ PEH- EF, ERS ,PSTE,2XPSTS,EQF- 41,EQF- 43,ATPS HOUSING,FIRING HEAD,10' X 2" DUMMY GUN; OAL = 62', MAX OD = 2.13 ", FISHING NECK = X1.38" 'REACHED TARGET DEPTH OF 9760' WITH TRACTOR, POOH !FINAL T /I /O = 0/1450/620 PSI. WELL SHUT -IN UPON DEPARTURE. ** *JOB WILL BE CONTINUED ON 29- APR - 2012 * ** • . 4/29/2012 * ** SLB E -LINE - ADPERFS W/ TRACTOR * ** (JOB CONTINUED FROM 04 -28- 2012) INITIAL T /I /O = 0/1450/620 PSI TIE-IN USING: SLB MCNL GR/CCUCNL DATED 04 OCTOBER 2007. SHOT INTERVAL: 9750' -9760' W/ 2" 2006 POWERJET HMX, 6 SPF, 60 DEG PHASING SHOTS FIRED CONFIRMED FINAL T /I /O = 0/1450/620 PSI I * ** WELL SHUT -IN UPON DEPARTURE * ** (JOB WILL CONTINUE ONTO 04-30 - !2012) 4/30/2012 * ** SLB E -LINE - ADPERFS W/ TRACTOR * ** (JOB CONTINUED FROM 04-29 - 1 2012) INITIAL TWO = 0/1450/620 PSI TIE -IN USING: SLB MCNL GR/CCUCNL LOG DATED 04 OCTOBER 2007. RUN 2 - SHOT INTERVAL: 9740' -9750' W/ 2006 POWERJET HMX, 6 SPF, 60 'DEG PHASING RUN 3 - SHOT INTERVAL: 9730' -9740' W/ 2006 POWERJET HMX, 6 SPF, 60 DEG PHASING .T /I /O = 0/1450/550 PSI ** *JOB CONTINUED ON 1- MAY -12 * ** 5/1/2012 '***JOB CONTINUED FROM 30- APRIL -12 * ** (ELINE PERFO) SLB MCNL GR/CCUCNL LOG DATED 04 OCTOBER 2007 FOR TIE -IN. RUN 4 - SHOT INTERVAL: 9580' -9590' W/ 2006 POWERJET HMX, 6 SPF, 60 (DEG PHASING :RUN 5 - SHOT INTERVAL: 9570' -9580' W/ 2006 POWERJET HMX, 6 SPF, 60 IDEG PHASING RUN 6 - SHOT INTERVAL: 9560' -9570' W/ 2006 POWERJET HMX, 6 SPF, 60 1DEG PHASING I ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 42 DIESEL 25 METH 98 CRUDE 307 1% KCL Slickem 2 TOTAL TREE' 4 -1/15' CW W • ELLHEAD = FM1C S NOTES: WELL ANGLE> 70 9480'. ACTUATOR = BAKER C 05-1 O C • KB. ELEV = 62.3' BF, ELEV = WA KOP = - -- ----- - 5350 Max Angle = 97° @ 10181' • 1 2116' H4-12" CAM-4A TRSSSV, ID = 3.817' Datum MD = _ 9257' Datum = TV D -- 8800' SS 13 -3/8" CSG, 72#, M J-80, ID = 12.34T' H 2703' 1—■ GAS LIFT MANDRELS ED ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3829 3829 0 TFO DOME T -2 16 10105/09 Minimum ID = 2.377" @ 9767' 2 5756 5743 17 TR) DOME T -2 16 10/05/09 3 -112" X 2 -7/8" LNR X0 3 7460 7284 25 TR) SO T -2 20 10/05/09 J 7621' 1— 9-5/8" x 7" BKR LT FKR w 111EBACK & HMC LNR HGR, ID = 6.188" 1 9-5/8" CSG, 47#, N-80, ID = 8.681" H 7693' 9-5/8" CSG MLLOUT WINDOW (05 -10A) 7693' - 7743' (SECTION MILL) 'CALCULATED TOC IN IA -1 8600' 1 __ ■ ■ ■ 8874' H4 -12" BKR KB LT PKR, 10 = 2.38` 14-1/2" TBG, 12.6#, L -80, .0152bpf, ID = 3.958" —1 8874' '. [IOC IN 4 -12 TBG H 8880' ►�j ►` 8880' 1 3.70" BKR DEPLOY MENr SLV, ►�'► 7 0 w /3" SEAL BORE 10 = 2.972" V '�/ ', V 8899' H3-1/2" HOWCO X NIP, ID = 2.813" ►o / r ► • 13-12" LNR, 9.3#, L -80, STL, .0087bpf, ID = 2.992" 1-1 8910' i „l Ps - 8911' H3-12" x 3- 31/15' X0,10 = 2.79" I ► 0 4 4 N ► Oy ti4 ►.4 14•, 1TOP OF WHIPSTOCK — 9077' ► ►�1 N «�i � � �� MLLOUT WINDOW (06 -10C): 9080' - 9093' � 1 7' LNR, 29#, NT -80S, ID = 6.182" 9080' ° «� ►4 •• 4 1 T' LNR MLLOUT WINDOW (05 -108): 0 - ' 4 7 4 ,11 9345 - 9353' ( BELOW 05.10C) i '4$4 4, 9767' --13 -3/15' x 2-7/8" X0, ID = 2.377' 1 PERFORATION SUMMARY FIEF LOG: SWS MCNLJGR/CCL 10/04/07 ANGLE AT TOP PERF: 92° @ 9970' Note: Refer to R oduction DB for historical perf data 3 1H5' LNR, 6.2#, L-80, STL, 9767' SIZE SR INTERVAL Opn/Sqz DATE 2" 6 9560 - 9590 0 05/01/12 ? . 0078bpf, ID = 2.80" 2' 6 9730 - 9760 0 04/30/12 2" 6 9970 - 10025 0 10/055/07 1 PBTO H 11650' I '•t� ;,♦,, 7 6 10050 - 10340 0 10/05/07 2" 6 10370 - 10510 0 10/05/07 2" 6 10535. 10585 0 10105107 2" 6 10695 - 10725 0 10/05107 1 2 -7/8" LNR, 6.4#, L -80, STL, 0058bpf, ID= 2.441" H 11682' 2' 6 10770 - 11170 0 10/05/07 7' 6 11270 - 11630 0 10/05/07 DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 09111/77 ORIGINAL COMPLETION 05/08/12 AD WELL, PERMIT, AR 4 CORRECTION WELL: 05-10C 07116/94 CTD SIDETRACK (05 -10A) PERMIT No: '070980 09112196 CTD SIDETRACK (05 -106) API ND: 50-029-20263-03 10/06/07 NORDIC1 CTD SIDETRACK (05 -10C) SEC 34, T11 N, R15E, 2662' FSL & 5095' FEL 12/21/09 CRWSV DRLG DRAFT FINAL 05/08/12 JLS/JMD ADPERFS (04/30 & 05/01/12) BP Exploration (Alaska) ~ ~ b > = a,~ ~`` ,~ ~~ ~ ,.,, ~, ~~ e ~~s ~- ~ ' "~,,~, "~ ~ ~' -~9 ~ .~~, ~~~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • '~ BAKER M~/6ME5 CUMYANY WELL NAME FIELD Baker Atlas PRINT DISTRIBUTION LIST BY EXYLURA"1"lUN (ALASKA) 1NC CUUN'1'Y NUR'1'H SLUYE BURUUGH OS-lOC STATE ALASKA PRUDHOE BAY UNIT DATE 1/28/2009 THIS DISTRIBUTION LIST AUTHORIZED BY: Terri Ttiminello SO #: 1585159 Copies of Copia Digital Copies of Copia Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKAI INC 1 Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company EXXON MOBII, PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON, TX 77002 1 Company STATE OF ALASKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv: BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed Bv: O~'• O~ Page 1 of 1 i INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 F -,-~ ,. ~, ~,r ~~r~r,~; Attention: Christine Mahnken Reference: OS-lOC Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - GR Directional TVD Log (to follow) LAC Job#: 1585159 Sent by: Terri Tuminello Date: 01/28/0 ~ . ~ :.~ ~: y Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SI ~ ~ a ~; ~''t'~NG OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ ~~'~~~f 7260 Homer Drive ~ Anchorage, Alaska 99518 ~j Direct: (907) 267-6612 ~~ ~ o INTEQ FAX: (907) 267-6623 01 /23/09 ~~,~I~m~~r~~~ Alaska Data & Consulting Services a(`' 2525 Gambell Street, Suite 400 ` a~ Anchorage, AK 99503-2838 0~ ATTN: Beth P~J Q~ ~`~~~` ~ w/ ell 1 O .I~n s N0.5047 Company: State of Alaska f .; it ° '; tom- [~ +~ '~ L~~ Alaska Oil & Gas Cons Comm i~%l.l ~..~ Li~~tcaw% 7 ~f.~ ~,.'~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ nn ns ..~:.. n_a_ H-35 11970840 PRODUCTION PROFILE 08/12/08 1~ 1 -11 12111927 IBP & CROSS-FLOW STP l 11/24/08 1 1 MPS-41 11966291 SCMT - ~ 11/24/08 1 1 K-O5C AWJB-00016 MEM PROD PROFILE CJ _ ~. ~" 12/29/08 1 1 14-17A AXOY-00010 MEM INJECTION PROFILE ~ 0 -~ 01/15/09 1 1 F-33 ALYF-00010 CEMENT IMAGE LOG (p- ~"~" 12/30/08 1 1 K-i6AL2 AXIA-00009 MEM PROD PROFILE 0 - b 01/10/09 1 1 01-29 AP30-00011 USIT - ~ ~ 01/04/09 1 1 09-30 AY1M-00007 STATIC SPINNER &IBP -. ~ L~ 01/15/09 1 1 N-18A AZCM-00005 JEWELRY LOG/PRESS/TEMP - ~ 01/06/09 1 1 R-24 AY3J-00004 USIT 01/16/09 1 1 N-18A AWLB-00002 USIT 12/26/08 1 1 V-212 AXBD-00010 MEM INJECTION PROFILE ~ 01/16/09 1 1 V-222 ALYF-00011 INJ PROFILEIWFL .c r~j'~ 01/08/09 1 1 07-OVA AYOO-00009 USIT - L 01/22109 1 1 N-12 12014053 RST ~ 09/30/08 1 1 E-32B AXOY-00005 MCNL 11/18/08 1 1 P2-15A 11594511 SCMT (PDC) (REVISION 2) i )~.~': 06/15/07 1 B-27A 11999059 RST ®D~ ~ !a~' + 11/07/08 1 1 12-37 40018138 OHM D/LWD EDIT _~ ~~- 11/07/08 2 1 N-18A 08AKA0037 OH MWD/LWD EDIT ~O~j .- '~ 12/24/08 2 1 H-38 OSAKA0031 OH MWD/LWD EDIT C 12/07/08 2 1 -I~ ~ ~ = '~- -p n~ ~wc.~ w .._....~..~~~... ~........ ~ .. ... .................v ..~. vnn.naa v~~c a.vr ~ cMa.n ~ v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 ~ /~ 900 E. Benson Blvd. 111/ IJI Anchorage, Alaska 99508 n Date Delivered Alaska Data & Consulting Services 2525 Gambell Street, Swte 400 Anchorage, AK 9 ._ . ~F~3~ ~~~'` ,~ ;; ATTN: Beth Received by: ~ ~. t... ~~ v .- .,. ... ~J • • Oilfield Services 2525 Gai»he~~ s~rreet flue Suite 400 Anchorage, Alaska 99503 (901) 273-1700 Fax (907) 561-8317 DATE: January 2, 2009 T0: State of Alaska - AOGCC DNR -Division of Oil & Gas Exxon Mobi11'roduction Co -Houston FROM: Dana Kostreba Log;Data Project Coordinator Schlumber er Data & Consulting Services RE: 05-10C MCNL logged 04-Oct-2007 The enclosed MCNL data ha$ been REVISED as follows: `Thy repeat pass has been depth-corrected to they main pass. The LDVNG edit delivered previously did not include depth-shifting the repeat pass to the main pass. The final prints did not require revising; hard copy prints-wily not be t~edelivered. Should you have questions concerning the revisions made for this edit, please do not hesitate to contact me. Best regards, ~~~ ~ ~r ,~ ZOG ~- ~~~~~~ -~ 12/18/08 ~~i~~~mU~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Woll 1..1. N N0.5011 - ~. t R , ~~ r,; , ~. __~ Company: State of Alaska ~~ ~' ~~~+~ ,,i~~ I `I ~ ~~~~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 11-34 12071901 USIT t~ _ 10/17/08 [.iL VVIVf 1 (,U 1 V-219 12103700 USIT 11/21/08 1 1 D-12 12113022 INJECTION PROFILE 'fj 12/05/08 1 1 R-t1A 12096929 USIT 12/07/08 1 1 01-34 12116292 CORRELATION/GR LOG CO - / '~- ~ a 12/06!08 1 1 F-19 AWJI-00011 MEM LDL (_ 12/08/08 1 1 18-296 AWJI-00010 MEM LDL .- (, b 12/05/08 1 1 09-41 12017504 PRODUCTION PROFILE J4~ -(S 12/04/08 1 1 18-14B 12005233 MCNL ~ -- 09/21/08 1 1 18-066 12083417 MCNL - 10/28/08 1 1 18-14C 12066551 MCNL 10/06/08 1 1 OS-10C 11649990 MCNL 10/04/08 1 1 V-219 12103700 CH EDIT (USIT) 11/21/08 f --b~' tM "f -t ~ - tt- c PI FASP ACICAIA11V1 Crl!_C no roror ov ~+u±w u~~n n BP Exploration (Alaska) Inc. _ - V 'v v •~ vv, ~^v'1 ~v• Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: • • Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2 8 ATTN: Beth Received by: --------- DATA SUBMITTAL COMPLIANCE REPORT 11 /19/2008 Permit to Drill 2070980 Well Name/No. PRUDHOE BAY UNIT 05-10C Operator BP EXPLORATION (ALASKA) INC MD 11685 TVD 8967 Completion Date 10/6/2007 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20263-03-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional S DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, MCNL / GR / CCL Well Log Information: Log/ Electr Data Digital Dataset Ty~ Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments C Las 15673 Gamma Ray D Asc Directional Survey Directional Survey 7061 11685 Open 11/9/2007 GR, ROP Field Data 8959 11685 Open 11/21/2007 8959 11685 Open 11/21/2007 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Daily History Received? N Chips Received? "'f-/-td' Formation Tops Y N Analysis Y / N Received? Comments: --- --- ---- ---------- -- ----- ---- -^^-~~-- pp \\ ~~ ~A~~ w Compliance Reviewed By: ____._.__. -_- Date: O'\- y ~ `7 dVV~ s HUGHES INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Te1907-267-6600 Fax 907-267-6623 To Whom It May Concern: November 16, 2007 Please find enclosed directional survey data for the following wells: G-09B OS-lOC OS-22C K-08B X-30APB 1 X-30APB2 X-30A X-20A Enclosed for each well is: tea copies of directional survey reports lea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration(Alaska)Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. d ~ ,~ RECEIVED BY: v ~~ ,State of Alaska AOGCC DATE: ~ ~~` ~ U Cc: State of Alaska, AOGCC ao~-~Ya Date 1 1-09-2007 Transmittal Number:92919 ~' BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Douglas Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: .. n. 17-07~..~b~_=.Q1.~~~-._ _._ C7.-046 ~(~,, _..1. ~ t r _. _. ~'-t.,t --~i;.?`s T. r_i QR ~,,-~ - sail ~ r5~5~U. G. 27A c? p'~:. ~~ 1 ~.-. i 5~ ~.~ P2-15APB2 w.i~ °~ ~ ::~ ~ Y ~ ~e~ ~ ..'~_ ~ ~ r ~ ~;°. P2 wt5AP63_._.tt ~~...~^~~ ~~~__~_.!_a~`cG, Please sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 :,, °, '~jrtl f Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 f/ STATE OF ALASKA ~ ~~~~~ Y ~~ /' S~~ ALASKA~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO~~~ ~ 2 2007 e~~E~a nil & Gas Cons. Commission 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 1 b. Well ~ raae " 20AAC 25.105 2oAAC zs.~ ~o ®Deve lopme~ft ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ^ Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or A 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10/6/2007 207-098 - 3. Address: 6. Date Spudded a(r ~ 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 9/ 007 50-029-20263-03-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: ' ' 10/2/2007 PBU 05-10C 2662 FSL, 185 FWL, SEC 32, T11 N, R15E, UM Top of Productive Horizon: 8. KB (ft above MSL): 62.3'° 15. Field /Pool(s): 1109' FSL, 873' FWL, SEC 32, T11 N, R15E, UM Ground (ft MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD) Pool 2333' FSL, 779' FEL, SEC 31, T11 N, R15E, UM 11650 8966 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 697259 y- 5948830 Zone- ASP4 11685 8967 ADL 028326 - TPI: x- 697993 y- 5947295 Zone- ASP4 11. SSSV Depth (MD+TVD) 17. Land Use Permit: Total Depth: x- 696306 y- 5948476 Zone- ASP4 2116 2116 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore 20. Thickness of Permafrost (TVD): Submit electronic and rinted information er 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): MWD DIR, GR, RES, MCNL / GR / CCL v--1•~~os SOU ' ~O~?~. ~~ ~~~ ~. 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-4 Surface 111' Surface 111' 32" 282 sx Permafrost 13-3/8" 72# MN-80 Surface 2703' Surface 2703' 17-1/2" 6620 sx Arcticset II 9-5/8" 47# N-80 Surface 7693' Surface 7497' 12-1/4" 1000 sx Class 'G' 300-sx AS I 7" 29# NT-80S 7521' 7 40' 8699' 8-1/2" 425 sx Class 'G' 3-1 /2" x 3-3/16" 9.3# / 6.2# L-80 8880' 11682' 8555' 8967' 4-1/8" 160 sx Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24;" TUBING RECORD If Yes, list each i (MD+TVD of Top 8~ Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 9288' 9240' MD TVD MD TVD 9970' - 10025' 9001' - 9000' FRACTURE DEMENT SQUEEZE ETC 25. ACID 10050' - 10340' 9000' - 8997 , , , . 10370' - 10510' 8996' - 8995' DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED 10535' - 10585' 8994' - 8991' 2200' Freeze Protect with 60/40 McOH 10695' - 10725' 8990' - 8988' 10770' - 11170' 8985' - 8978' 11270' - 11630' 8975' - 8966' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 1, 2007 Flowing Date of Test: HOUfS Tested: PRODUCTION FOR OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 11/1/2007 6 TEST PERIOD 43 11 172 128 251 Flow Tubing CaSing PfeSS: CALCULATED OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): Press. 293 1,500 24-HOUR RATE 171 43 687 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20AAC 250.071. a _ ? ~'. None ~~ : /Q ~~~ ~()1i ~! ~'~ 2~~T -- __ Form 10-407 Revised 02/2007 ~ ~ ~ ~ N A ~ NTINUED ON REVERSE SIDE '1 ~ y 28. LUEOLOGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. 23SB / 24N 9162' 8785' None 22TS 9205' 8818' 21 TS /Zone 2A 9262' 8861' Zone 1 B 9385' 8941' Zone 1A / 13N 9456' 8974' Formation at Total Depth (Name): Zone 1 A / 13 N 9456' 8974' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si d l (/~~~ gne Terrie Hubble Title Drilling Technologist Date P8U 05-1 OC 207-098 Prepared By Name/Number. Ter-ie Hubble, 564-4628 Well Number Drilling Engineer: C,arret Staudinger, 564-4242 Permit No. ! A royal No. INSTRUCTIONS GeNeRa~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this welt is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only i ~ BP EXPLORATI©N- Page 1 of 12 Opell•ations Summary Report Legal Well Name: 05-10 ~„ ~~ 1 Common Well Name; 05-10 ~~ Spud Date: 7/28/1977 ~ Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Nours Task Code NPT Phase Description of Operations 9/23/2007 00:00 - 10:00 10.00 MOB P PRE Turnkey Rig Move from G pad to DS 5, spotted rig on pad 10 to lower derrick 10:00 - 10:30 0.50 MOB P PRE PJSM on operational proceedure for lowering and LD derrick 10:30 - 16:30 6.00 RIGD P PRE Prep derrick for laying down, lower derrick cylinders, pinned in place, LD bails, hooked bridle line to wind walls, ND gas buster stack and guide line cables, LD wind walls, loosen guide Tines, RU Hydraulic hoses, filling holding tank with hydraulic fluid, scope down derrick, LD and secure traveling block on rig floor, i secure all cables on roof, open pipeshed roof, LD derrick, close roof. 16:30 - 17:00 0.50 MOB P PRE Prep rig for move, PJSM on moving proceedures. 17:00 - 18:30 1.50 MOB P PRE Move rig to DS 5, stage in front of 5-10. 18:30 - 19:00 0.50 RIGU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for raising derrick and closing windwalls. ' 19:00 - 21:00 2.00 RIGU P PRE Open pipeshed roof, raise derrick, secure, close pipeshed roof, scope derrick up. 21:00 - 23:00 2.00 RIGU P PRE Hooked bridle line to windwalls, raise and secure windwalls. Secured guide line cables, disconnected and lowered bridle line to floor. Raise and secure derrick cylinders. Prep to move rig over 05-10. Secure blocks. 23:00 - 00;00 1.00 MOB N WAIT PRE Wait on DSM to move mat boards to allow room for rig to back over well. 9/24/2007 00:00 - 00:30 0.50 MOB N WAIT PRE Wait on DSM to move mat boards to allow room for rig to back over well. 00:30 - 01:00 0.50 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. 01:00 - 03:00 2.00 MOB P PRE Lay out herculite. Back rig over 05-10C. DSM valve crew greased tree. 03:00 - 04:00 1.00 RIGU P PRE RIG ACCEPT AT 0300 HRS, 9/24/07. R/U satellite camp and cuttings box, VECO hardline crew R/U tiger tank and hardlines. PT hardlines. 04:00 - 04:30 0.50 BOPSU P PRE Begin N/U BOP stack to tree. 04:30 - 04:45 0.25 RIGU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for picking up a-coil reel into reelhouse. 04:45 - 05:30 0.75 RIGU P PRE Open bombay door. Pick E-Coil reel off of Veco trailer and set in reel stand support/drive pins. Close bombay door. 05:30 - 06:00 0.50 BOPSU P PRE N/U BOP. M/U hardline in reel. 06:00 - 07:30 1.50 RIGU P PRE Install mono rails in pipe shed 07:30 - 12:15 4.75 BOPSU P PRE install 2 2ft sections of riser, borrowed from DSM, missing two 11 3/4" x 1 3/8" studs and nuts, Hotshot to rig 12:15 - 21:00 8.75 BOPSU P PRE Installed 2 3/8" test joint, performed koomey draw down test, test BOP's, all rams, choke manifold from 250 to 3500psi, annular from 250 to 2500psi, OK, test surface valves and lines from 250 to 3500psi, change out test joint ,test VBR's Had to grease HCR and #2,# 6, and #11 choke manifold valves to get a good test. Jeff Jones with AOGCC waived witnessing BOP test 21:00 - 21:15 0.25 BOPSU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for R/U DSM tools, PT lubricator, pull BPV. 21:15 - 00:00 2.75 BOPSU P PRE P/U DSM tools through beaver slide. Nordic crew change. R/U lubricator Test 500 psi low 3000 psi hi -Okay. Pules. RD Printed: 10/23/2007 2:59:42 PM BP EXPLORATION- Page 2 of 12 Operations Summary :Report Legal Well Name: 05-10 ~ ~~1`tn Common Well Name: 05-10 ~~~b Spud Date: 7/28/1977 Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Qperations 9/24/2007 21:15 - 00:00 2.75 BOPSU P PRE Meanwhile P/U gooseneck from pipeshed floor to catwalk. Meg eline okay. 9/25/2007 00:00 - 00:15 0.25 RIGU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for R/U pipe straightener, injector, and gooseneck. 00:15 - 03:00 2.75 RIGU P PRE P/U pipe straightener and R/U to injector. P/U injector from stabbing box to rig floor. P/U gooseneck from catwalk and R/U to injector. 03:00 - 04:15 1.25 RIGU P PRE PJSM. Install internal grapple, pull test, pull coil to injecter head. 04:15 - 05:15 1.00 RIGU P PRE Cut CT. Boot end of a-line. R/U new SLB side door pack off to bottom of injector. Stab injector on weN. 05:15 - 06:30 1.25 RIGU P PRE Pump 6 bbls to fill hardline in reelhouse. Pressure test inner reel valve to 3500psi. Line up to reverse circulate. Reverse circ 115 bbls of 2% double slick KCL 2ppb biozan, filling CT. CT length 15270', E-line cable 15527' 06:30 - 07:30 1.00 RIGU P PRE Reposition electrical service loop in derrick for injector 07:30 - 08:00 0.50 BOPSU P PRE Pressure test hardline and inner reel valve 250 -3500psi 08:00 - 10:00 2.00 RIGU P PRE RU CT hydraulic cutter, Cut 135' CT, exposed 8' of a-coil, RD cutter 10:00 - 12:00 2.00 RIGU N SFAL PRE Test a-coil cable, passed insulation test, failed the continuity test, troubleshooting a-coil, found two VOM's (volt ohm meters), calibrated 090707, questionable, retested insulation and continuity test good with SLB and Baker Fluke megger 12:00 - 12:30 0.50 RIGU P PRE Install SLB dipple CTC, pull tested 40k, ok 12:30 - 16:00 3.50 RIGU P PRE Baker installing UOC, MU a-coil cable, meg line, ok, test coil CTC to 3500psi, ok, test surface lines to 4500 psi 16:00 - 18:10 2.17 STWHIP P WEXIT RIH. Pumping 2% KCL to swap well over. Taking freeze protect diesel to tiger tank. 18:10 - 18:40 0.50 STWHIP P WEXIT Shut down pump. Close EDC. Tag whipstock pinch point at 9083'. Correct depth to 9080'. Flagged coil at 9080'. 18:40 - 21:00 2.33 STWHIP P WEXIT Mill 3.80" window thru 4-1/2" tubing and 7" Liner. 2.6 bpm, 2780-3000 psi, 1-3K wob, 1 fph. Milled to 9082'. 21:00 - 00:00 3.00 STWHIP P WEXIT Mill 3.80" window thru 4-1/2" tubing and 7" Liner. 2.6 bpm, 2780-3000 psi, 2-4K wob, 1 fph. Milled to 9085' . 9/26/2007 00:00 - 02:00 2.00 STWHIP P WEXIT Mill 3.8" window thru 4-1/2 and 7" liner. 2.6 bpm, 2700-3000 psi, 2-5K wob, 1 fph, Milled to 9088'. 02:00 - 04:00 2.00 STWHIP P WEXIT Mill 3.8" window thru 7" liner, 2.6 bpm, 2700-3200 psi, 3-5K wob, 0.5 fph, Milled to 9089'. IS ~` 04:00 - 06:00 2.00 STWHIP P WEXIT Mill 3.8" window thru 7" liner, 2.6 bpm, 2700-3200 psi, 3-5K wob, 0.5 fph, Milled to 9090'. 06:00 - 08:45 2.75 STWHIP P WEXIT 9090.3' at 06:00. Milling at -1 fph. PVT=303 bbls. IAP=400 psi, OAP=62 psi. Free spin 2700 psi at 2.6 bpm. Milling at 2900 psi. DHWOB=5000 lbs. String weight 14 klbs. 08:45 - 09:45 1.00 STWHIP P WEXIT 9091.6', Slight drilling break. DHWOB change. Possible exit. Continue milling ahead @ 1 fph. Printed: 10/23/2007 2:59:42 PM ~ ~ BP EXPLORATION Page 3 of 12 Operations Summary Report Legal Well Name: 05-10 Common Well Name: 05-10 Spud Date: 7/28/1977 Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hotars Task. Code NPT Phase Description ofAperations 9/26/2007 09:45 - 13:30 3.75 STWHIP P WEXIT 9092.6' Probably in open hole. Drill 10' of rathole. 13:30 - 14:30 I 1.001 STWHIPI P 14:30 - 16:10 1.67 STWHIP P 16:10 - 16:30 0.33 STWHIP P 16:30 - 18:45 I 2.251 STWHIPI P 18:45 - 19:15 I 0.501 DRILL I P 19:15 - 20:30 I 1.251 DRILL I P WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 20:30 - 22:30 I 2.001 DRILL I P I I PROD1 22:30 - 00:00 1.50 DRILL P PROD1 9/27/2007 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 00:50 0.33 DRILL P PROD1 00:50 - 01:30 0.67 DRILL P PROD1 01:30 - 03:15 1.75 DRILL N DFAL PROD1 03:15 - 03:30 0.25 DRILL N DFAL PROD1 03:30 - 05:15 I 1.751 DRILL I N I DFAL I PROD1 Vac Trucks standing by to swap to mud. Hold unannounced spill drill at the Vac trucks. Good response by rig hands. Hold debrief in doghouse post drill. Drill to 9102.6'. Geo confirms that there are formation samples consistent with zone 3 (chert) in returned cuttings. Swap to mud. Ream/backream window. Dry drift up and down ok. POOH pumping at full rate thru the mill and motor. PJSM to discuss laying down milling BHA, and pressure testing IA. PT will not take place until after BHA is laid down. Operations will be conducted short handed. Pfdvo~~~l~~oc.,,c,,L-loin ~~Jo"M~~(to Lay down BHA #1. Mills gauged as follows; D0261 = 3.79 go/3.78 No-go, String Reamer 3.80 go/3.79 No-go. D-0261 had good swirl pattern on the face. All indications are a good window. While BHI swaps MWD tools around, hook up Little Red to PT the Inner annulus. PT to 3000 psi for 30 min, as per procedure. Bleed down IAP and Rig down Little Red. Press test lost 140 psi for first 15 min. and lost 60 psi for second 15 min. Final press after 30 min. was 2800 psi. Good IAP TEST. Held Pre-Spud Safety Meeting with all personnel. Reviewed well plan and hazards with crew. Reviewed procedure, hazards and mitigation for M/U Build Drilling BHA. M/U Coiltrak build BHA #2 with Smith BC Bit #1 and 2.4 deg motor. Surface test Coiltrak tools. BHA OAL = 66.05'. RIH with Coiltrak build BHA #2. Circ at 0.2 bpm. Tested orienter at surface, OK. Held Kick while trip drill while RIH. Log GR tie-in from 8340-8500' and 8770-8900' as per GEO. Log GR tie-in above window. Added 5.5' to CTD. RIH clean thru window. Tag bottom at 9102'. Not able to orient. Orienter locked at 60L at bottom. Work pump, spud on bottom several times to try and free up orienter. Orienter started working. Drill build section in Zone 3, 2.5 bpm, 3020-3600 psi, 10R TF, Not able to hole correct TF. Orienter is not working. Drilled to 9105'. POH to change out orienter. SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA. C/O orienter, DGS and bit. Bit was damaged near window due 'to poor TF information. TF varied all over, so bit was damaged in window and below window while trying to get orienter working. M/U Smith BC Bit #2, 2.4 deg Extreme motor, and Coiltrak tools. BHA OAL = 66.05'. Printed: 10/23/2007 2'59:42 • $P EXPLORATION Page 4 of 12 Operations Slumlmary Report Legal Well Name: 05-10 Common Well Name: 05-10 Spud Date: 7/28/1977 Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/27/2007 05:15 - 07:00 1.75 DRILL N DFAL PROD1 RIH with CoilTrak build BHA #3 with Smith BC bit and 2.4 deg 07:00 - 07:30 0.50 DRILL P PROD1 07:30 - 08:45 1.25 DRILL P PROD1 08:45 - 12:30 3.75 DRILL P PROD1 12:30 - 13:25 0.92 DRILL N DFAL PROD1 13:25 - 15:30 2.08 DRILL N DFAL PROD1 15:30 - 15:50 I 0.331 DRILL I N DFAL I PROD1 15:50 - 18:15 2.42 DRILL N DFAL PROD1 18:15 - 20:30 2.25 DRILL N DFAL PROD1 20:30 - 23:45 3.25 DRILL N WAIT PROD1 23:45 - 00:00 0.25 DRILL P PROD1 9/28/2007 00:00 - 00:15 0.25 DRILL P PROD1 00:15 - 01:30 1.25 DRILL P PROD1 01:30 - 02:45 I 1.251 DRILL I P I I PROD1 03:20 - 04:45 I 01.42 DRILL P I I PROD1 Extreme motor. Tested CoilTrak tools and Orienter near surface, OK. Circ at 0.2 bpm. Tag bottom pick up and bring pumps on. Tag bottom again at 9105' CTM. Make 0' correction. Begin drilling build section. Mud pump #1 needs service. Need to log tie in pass over RA tag at some point anyway. Make wiper trip to window and log tie in pass over RA tag and to PDC log. Window depths as follows; Top of Window = 9080.0' RA tag = 9088.5' Bottom of Window = 9092.6' Resume drilling. Slightly ratty drilling. ROP 45-65 fph. Typical for lower zone 3/upper zone 2. Free spin 3020 psi at 2.55 bpm. Drilling at 3300 psi. PVT=312 bbls. IAP=630 psi, OAP=82 psi. BHI orienter not working. Make wiper while attempting to resolve problem. Attempt to resume drilling, can't get it to work. POOH for new tool. Problem could be in other part of BHA which is causing the communications to the orienter to fail. Plan to swap out entire BHA at surface. Note -Checked previous orienter that had failed, and it checks ok on the catwalk. PJSM for laying out BHA, troubleshooting, and picking up new BHA. Lay down BHA #3. Check motor, appears good. Check Smith bit. Graded 1,1. Has 1 slightly chipped cutter on the pilot, 1 slightly chipped cutter on the wing. Troubleshoot failed MWD BHA. Pick up completly new MWD BHA. Rerun same motor and same Smith bit. MU injector and RIH with BHA #4. GEO determined there was an error in directional file. Wait for correct directional file before drilling further. Depth tie-in was from well 05-10, but actual exit was from well 05-10A. Geo and BHI got correct directional information and made the needed depth changes. Adjusted RA depth up hole 3' to 9085.5'. Adjusted all surveys as needed. Log GR tie-in at RA tag. -8' CTD. RIH clean to bottom. Tag bottom at 9290'. Drill build section. 2.5 bpm, 3200-3900 psi, 40R TF. 51 deg incl, 60 fph, 10.1 ecd. Drilled to 9370'. Drill build section. 2.6 bpm,,. 3300-3900 psi, 60R TF. 60 deg incl, 80 fph, 10.1 ecd. Drilled to 9450'. Wiper trip to window. Clean hole. RIH clean to bottom. Drill build section. 2.6 bpm, 3300-3900 psi, 60R TF. 60 deg incl, 80 fph, 10.2 ecd. Control drill trying to reduce downhole vibration. Try low pump rate and high pump rate, Ynfl[BO: lU/Z3lZUU/ Z:O~J:4Z NM ~! i BP EXPLORATION Page 5 of 12. Operations Summary Report Legal Well Name: 05-10 Common Well Name: 05-10 Spud Date: 7/28/1977 Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours. .Task .Code NPT Phase Description of Operations 9/28/2007 03:20 - 04:45 1.42 DRILL P PROD1 Drill with low WOB. Vibration running at 4-5 G. Drilled to 9480'. 04:45 - 06:00 1.25 DRILL P PROD1 Drill build section, 2.2 bpm, 2800-3400 psi, 40R TF, 65 deg incl, 10.0 ECD, 40 fph, Drilling with 2.2 bpm and 1-3K WOB, 30-40 fph to keep G totals below 4 G's. Drilled to 9514'. 06:00 - 09:40 3.67 DRILL P PROD1 Continue drilling ahead. Able to drill at normal pump rates now with no excess vibrations. ROP = 55 fph. PVT=316 bbls. IAP=380 psi, OAP=100 psi. DHWOB=2000 lbs. String wt=9500 lbs. ECD=10.16 ppg. Drilling at 2.55/2.59/3800 psi. 09:40 - 11:45 2.08 DRILL P PROD1 Well is landed. POH for lateral section BHA. Clean PU off bottom at 36klbs. Clean in open hole. Pump at full rate while POH in tubing. Jog at surface. 11:45 - 12:15 0.50 DRILL P PROD1 Tag up at surface. Flow check well. Hole PJSM Re: BHA swap. Discuss hazards, and mitigations. Discuss job assignments. Check well for flow again. No flow observed. 12:15 - 14:00 1.75 DRILL P PROD1 Stand back injector. Lay down BHA #4. Readjust and check motor. Seems good. Adjust to 1.2 deg AKO. Smith Bicenter graded at 2-2-BT-A-X-I-RO-BHA. It had 2 chipped cutters on the pilot, and 2 on the gauge. Pick up new Hughes bit. Redeploy MWD and make up BHA #5. '~, 14:00 - 15:45 1.75 DRILL P PROD1 Make up injector. Perform shallow hole test. All checks ok. RIH with BHA #5, first lateral section BHA with 1.2 deg motor and rebuilt Hughes Bicenter bit. 15:45 - 16:35 0.83 DRILL P PROD1 Begin extended logging pass down from 7100'. This is being done to remove any doubt about the depth discrepencies between the DS 05-10 and DS 05-10A laterals. No tie in pass was ever made to tie in the "A" lateral to the parent DS 05-10 well. After logging tie in pass make -22' correction. ~~ 16:35 - 17:30 0.92 DRILL P PROD1 RIH, log tie in pass over RA tag. RA tag shifted to be tied into long tie in pass made above. New RA tag depth = 9058.5'. Too of Whiostock/Window = 17:30 - 19:50 I 2.331 DRILL I N I WAIT I PROD1 19:50 - 20:10 0.33 DRILL I P 20:10 - 22:00 1.83 DRILL P 22:00 - 23:00 I 1.00 I DRILL I P PROD1 PROD1 PROD1 RA Tag = 9058.5' Bottom of Whipstock = 9062.4' Bottom of Window = 9063'. _ Wait at the window for MWD engineer to shift all surveys and data files to the new correlated depths. GEO and BHI reviewed directional information and tie-in and determined all is now correct. The above depths are correct. Re-enter all DIMS directional on todays report. Held a Rig Evacuation drill and H2S drill while waiting for directional corrections. RIH clean to bottom. Tag bottom at 9633'. Drill Zone 1A lateral, 2.5 bpm, 3300-3900 psi, 120E TF, 2-3K WOB, 60 fph, 10.2 ECD, Drilled to 9700'. Drill Zone 1A lateral, 2.5 bpm, 3300-3900 psi, 120E TF, 2-3K WOB, 40 fph, 10.2 ECD, Printed: 10/23/2007 2:59:42 PM BP EXPLORATION Page 6 of 12 Operations Summary Report Legal Well Name: 05-10 Common Well Name: 05-10 Spud Date: 7/28/1977 Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/28/2007 22:00 - 23:00 1.00 DRILL P PROD1 Drilled to 9730'. Stacking wt in shale. 23:00 - 23:45 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 23:45 - 00:00 0.25 DRILL P PROD1 Drill Zone 1A lateral, 2.6 bpm, 3350-3900 psi, 100E TF, 2-3K WOB, 50 fph, 10.3 ECD, Drilled to 9740'. 9/29/2007 00:00 - 02:15 2.25 DRILL P PROD1 Drill Z1A Lateral, 2.6 bpm, 3350-4100 psi, 1-3K WOB, 80L TF, 70 fph, 10.3 ecd, Drilled to 9840'. 02:15 - 03:20 1.08 DRILL P PROD1 Drill Z1A Lateral, 2.6 bpm, 3350-4100 psi, 1-3K WOB, 80L TF, 50 fph, 10.3 ecd, Stacking wt, several stalls, Drilled to 9857'. 03:20 - 04:10 0.83 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom. 04:10 - 06:00 1.83 DRILL P PROD1 Drill Z1A Lateral, 2.6 bpm, 3450-4100 psi, 1-3K WOB, 10L TF, 30 fph, 10.3 ecd, Drilling shale, Drilling at high side to get up out of this shale. Drilled to 9900'. 06:00 - 06:30 0.50 DRILL P PROD1 Drilling ahead in shale. 06:30 - 07:00 0.50 DRILL P PROD1 Drilling ahead. TF=O deg. PVT=283 bbls. IAP=211 psi, OAP=114 psi. Free spin 2.66 bpm @ 3540 psi. Getting lots of stalls. 07:00 - 08:30 1.50 DRILL P PROD1 Drilling ratty and slow. Try swap to new mud to see if we can improve weight transfer. 08:30 - 09:40 1.17 DRILL P PROD1 New mud around. Free spin 3140 psi at 2.65 bpm. New mud seems to help weight transfer a bit, but still slow ROP in shale. 09:40 - 10:30 0.83 DRILL P PROD1 Sloooooow drilling. Wiper trip to the window. Clean PU off bottom. Couple of bobbles during trip up. Clean back to bottom. 10:30 - 13:00 2.50 DRILL P PROD1 Resume drilling with slow ROP in shale. ROP -10 fph. Still trying to build angle to get up out of it. 13:00 - 15:00 2.00 DRILL P PROD1 Can't take it any more. We have only made 50' in last 7 hours. POH. Going to change bit and motor and possibly pick up the Agitator. Need to do something to get this to drill in shale. 15:00 - 15:20 0.33 DRILL P PROD1 PJSM Re: Swapping bit and motor, PT'ing CTC. Discuss proceedure, hazards, and mitigations to hazards. 15:20 - 17:00 1.67 DRILL P PROD1 Tag up at surface. Stand back injector. PT CTC to 3500 psi. Passed ok. Inspect BHA #5 for leaks. None observed. Break off bit and motor. Motor had 2 plugged ports (shale). Graded 1,1. Motor seemed tight. Make up new motor and hycalog bit. 17:00 - 18:45 1.75 DRILL P PROD1 RIH with BHA #6, 1.2 deg motor, Hycalog bicenter bit. 18:45 - 19:30 0.75 DRILL P PROD1 Log GR tie-in at RA tag. -26.5' CTD. 19:30 - 20:00 0.50 DRILL P PROD1 RIH clean to bottom. ~ Held Kick while trip drill 20:00 - 21:40 1.67 DRILL P PROD1 Drill Z1A shale, 2.7 bpm, 3100-3400 psi, HS TF, trying to drill up and out of shale. 92 deg incl, Slow drilling in shale with 4-6K WOB. 6 fph ROP. Drilled out of shale at 9965'. ROP increased up to 90 fph. Drilled to 10,000' 21:40 - 23:00 1.33 DRILL P PROD1 Drill Z1A lateral, 2.7 bpm, 3100-3900 psi, 80L, 90 fph. Drilled to 10093'. 23:00 - 00:00 1.00 DRILL P PROD1 Wiper trip to window. Clean hole. RIH clean to bottom.. 9/30/2007 00:00 - 00:15 0.25 DRILL P PROD1 RIH clean to bottom after wiper trip. 00:15 - 01:50 1.58 DRILL P PROD1 Drill Z1A lateral, 2.7 bpm, 3300-4000 psi, 90R TF, 1-2K wob, Printed: 10/23/2007 2:59:42 PM ~ A BP EXPLORATION Page 7 of 12- Operations Slummary Report Legal Well Name: 05-10 Common Well Name: 05-10 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Spud Date: 7/28/1977 Start: 9/23/2007 End: 10/6/2007 Rig Release: 10/6/2007 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 9/30/2007 00:15 - 01:50 1.58 DRILL P PROD1 90 fph, 10.0 ecd, 01:50 - 02:40 0.83 DRILL P PROD1 02:40 - 03:50 1.17 DRILL P PROD1 03:50 - 06:00 2.17 DRILL P PROD1 06:00 - 07:00 1.00 DRILL P PROD1 07:00 - 07:35 0.58 DRILL P PROD1 07:35 - 08:00 0.42 DRILL P PROD1 08:00 - 09:30 1.50 DRILL P PROD1 09:30 - 11:05 1.58 DRILL P PROD1 11:05 - 12:20 1.25 DRILL P PROD1 12:20 - 14:50 2.50 DRILL P PROD1 14:50 - 17:45 2.92 DRILL P PROD1 17:45 - 19:10 1.42 DRILL P PROD1 19:10 - 19:30 0.33 DRILL P PROD1 19:30 - 21:00 1.50 DRILL P PROD1 21:00 - 22:00 1.00 DRILL P PROD1 22:00 - 22:30 0.50 DRILL P PROD1 Drilled to 10,200'. Drill Z1A lateral, 2.7 bpm, 3300-4000 psi, 90R TF, 1-2K wob, 90 fph, 10.0 ecd, Drilled to 10,250'. Wiper trip to window. 2 overpulls in shales. RIH clean to bottom. Drill Z1A lateral, 2.7 bpm, 3300-4000 psi, 80R TF, 1-2K wob, 90 fph, 10.0 ecd, Drilled to 10,400'. Wiper trip to window. Overpull in shale at 9900'. Log tie-in at RA tag. Make -1' correction. Run back in hole to resume logging. PVT=264 bbls. IAP=195 bbls, OAP=115 bbls. Free spin while RIH at 2.5 bpm = 3060 psi. Call for an additional 80 bbls of mud from MI to top off the pits. Set down at 9945, had to work it to get thru. Rest of trip in hole was smooth. Tag bottom, resume drilling. ROP 90 fph. Drilling at 2.47/2.42/3340 psi. TF=330 deg. DHWOB=1700 lbs. Life is good. PVT=305 bbls after taking on new mud. Wiper trip to window. Clean PU off bottom. Bobble at 10000', overpull and motor work at 9950', 9837'. Clean the rest of the way to the window. RIH pumping at 2.35 bpm. Slight bobbles at 9850', 9950', shut down pumps and poped right thru. It looked cleaner than the last wiper trip. Resume drilling. Trying to build angle a little to get up out of the 70 api, marginal sand we are in. Free spin 3320 psi at 2.67 bpm. Drilling at 2.77/2.76/3880 psi. PVT=307 bbls. ROP=150 fph. Wiper trip to the window. Clean PU off bottom. A couple of small bobbles at 10000', 9950', 9850'. Much better than last wiper. Light bobbles at the same depth RIH. Free spin 3380 psi at 2.55 bpm. PVT=285 bbls. Slight losses of about 2 bbls/hr. Resume drilling. Trying to drill up out of 70 api poor quality pay as per Geo. Drilling at 2.56/2.52/3740 psi. ROP=115 fph. Wiper trip to the window. Clean PU off bottom. Heavy overpull at 9910'. Momentarily stuck. Dropped out of it. Pulled back thru it at maximum pump speed, and 3 fpm. Not seeing any motor work, or DHWOB, but do see increased string weight at surface. Suspect cuttings bed as top of BHA exits bad shale back into sand. Pull thru it ok. Motor work and overpull at 9495', 9265' Log tie in pass over RA tag. -4' CTD. RIH. Saw shale at 9468', Sat down in shale at 9850'. Ream shale from 9840-9960' at 10 fpm. RIH clean to bottom. Drill Z1A lateral, 2.5 bpm, 3300-3900 psi, 80R TF, 90 deg incl, 2-3K wob, 10.3 ecd. Drilling good 40-50 API sand from 10820-10950'. Drilled to 10,950'. Drill Z1A lateral, 2.6 bpm, 3500-4100 psi, 80R TF, 89 deg incl, 2-3K wob, 10.3 ecd. Drilled to 11,000'. Ptintetl: 10/23/2007 2:59:42 PM ~ ~ BP EXPLORATION Page 8 of 12 Operations Summary :Report Legal Well Name: 05-10 Common Well Name: 05-10 Spud Date: 7/28/1977 Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date f=rom - To Hours Task Code NPT Phase Description of Operations 9/30/2007 22:30 - 00:00 1.50 DRILL P PROD1 Wiper trip to window. 10/1/2007 00:00 - 00:30 0.50 DRILL P PROD1 RIH clean to bottom after wiper trip to window. 00:30 - 02:00 1.50 DRILL P PROD1 Drill Z1A lateral, 2.5 bpm, 3500-4100 psi, 90R TF, 89 deg incl, 10.4 ecd. Drilled to 11,082'. 02:00 - 03:00 1.00 DRILL P PROD1 Drill Z1A lateral, 2.5 bpm, 3500-4100 psi, 45R TF, 89 deg incl, 10.5 ecd. Swapped to new FloPro. i Drilled to 11,150'. 03:00 - 06:00 3.00 DRILL N DFAL PROD1 POH for failed orienter. Shales were clean. POH. 06:00 - 06:30 0.50 DRILL N DFAL PROD1 Crew Tour change and PJSM for BHA swap. 06:30 - 08:30 2.00 DRILL N DFAL PROD1 LD BHA #6. Change out failed orienter. Check motor, seems good. Lay down Hycalog bicenter bit. Graded 1,1 with 2 slightly chipped cutters on the wing. Pick up Hycalog DS49 bit. 08:30 - 10:00 I 1.501 DRILL I N I DFAL I PROD1 10:00 - 10:30 I 0.501 DRILL I N I DFAL I PROD1 10:30 - 11:30 J 1.00 I DRILL I N I DFAL I PROD1 11:30 - 13:45 I 2.251 DRILL I P 13:45 - 16:10 I 2.421 DRILL I P 16:10 - 17:40 I 1.501 DRILL I P 17:40 - 20:15 I 2.581 DRILL I P 20:15 - 21:45 I 1.501 DRILL 1 P 21:45 - 00:00 2.25 DRILL P 10/2/2007 00:00 - 00:30 0.50 DRILL P 00:30 - 03:15 2.75 DRILL P 03:15 - 05:15 I 2.001 DRILL I P 05:15 - 05:45 I 0.501 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Perform weekly function test of BOP stack while making BHA swap. Shallow hole test passed ok. RIH with BHA #7. 1.2 deg motor AKO and a Hycalog DS-49. Log tie in pass over RA tag in whipstock. Make -25.5' correction. RIH. Go to low pumps at 9850, slipped right thru with just a small amount of rattyness on the string weight. Back to full pumps, smooth to TD. Very low vibration when RIH with DS49 bit in open hole. Getting 0 on vib toot now, last BHA was giving 3 & 4 when RIH. Note the motor and rest of the BHA is identical, with the exception of the replaced EDC and bit. Free spin 2.4 bpm, 3130 psi. Tag bottom. Begin drilling. PVT=308 bbls. IAP=O psi, OAP=100 psi. Drilling at 90 fph, 2.48/2.43/3650 psi. Wiper trip to window. Minor overpull at 9850'. Much less than previous trips. Clean back in the hole to TD. Free spin 3303 psi at 2.45 bpm. Tag bottom. Resume drilling. PVT=290 bbls. Drilling at 2.43/2.36/3640 psi. 125 fph ROP. Back in good sand. Wiper trip to window. Clean PU off of bottom. Overpull at 9830' in shale. Ream shale and RIH clean to bottom. Drill Z1A Lateral, 2.6 bpm, 3500-4100 psi, 90L TF, 2-4K WOB, 89 deg incl, Drilling good sand with 40-50 API GR. 140 fph, Drilled to 11,600' Wiper trip to window. Motor work in shale at 9960'. Clean up to window. RIH and ream shale at 9840-9960'. RIH. RIH clean to bottom after wiper trip to window. Drill Z1A lateral, 2.5 bpm, 3600-4100 psi, 80L TF, 2-5K wob, 100 fph, 10.5 ecd, Drilled to end of polygon at 11,695'. Wiper trip up to window. Overpull and motorwork in shales at 9840-9960'. Ream shales. Log GR Tie-in at RA tag, logging down, -11' for BHI and SWS. Printed: 10/23/2007 2:59:42 PM • BP EXPLORATION. Page 9 of ~ 2 Operations Summary Report Legal Well Name: 05-10 Common Well Name: 05-10 Spud Date: 7/28/1977 'Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task. Code NPfi Phase Description of Operations 10/2/2007 05:45 - 07:20 1.58 DRILL P PROD1 RIH to tag TD. Minor bobbles at 9950'. 07:20 - 10:00 2.67 DRILL P PROD1 Ta ed bottom at 11,685'. POOH to run liner. Clean PU off bottom at 38klbs. Smoth thru the 9850'-9950' interval. Pull thru the window. Pump at full rate thru the DS49 on the way OOH. Paint EOP flags at 8800', 6200' on way OOH. (EOP, not bit depth!). 10:00 - 10:20 0.33 DRILL P PROD1 PJSM Re: Laying down last drilling BHA 10:20 - 11:30 1.17 DRILL P PROD1 Lay down BHA #7. Bit recovered graded at 1,1, with 1 small chip on 1 cutter on the shoulder. 11:30 - 12:30 1.00 CASE P RUNPRD Organize rig floor for running liner. Hold PJSM for liner running operations. Discuss hazards and mitigations. Focus on 2 "red hats" to ensure that they are aware of what is going on, and what their part in the operations is. 12:30 - 18:15 5.75 CASE P RUNPRD Run 2-7/8" x 3-3/16" x 3-1/2" liner as per proceedure. Liner as follows; BOT deployment sleeve 3-1/2" STL pup joint 3-1/2" STL pup joint HES 3-1/2" X Nipple 3-1/2" pup joint 3-1/2" STL x 3-3/16" TCII XO 30 jts 3-3/16" TCII liner (855.87') 3-3/16" TCII x 2-7/8" STL XO 59 jts of 2-7/8" STL Liner (1881.73') 2-7/8" BTT Landing collar 2-7/8" BTT Float Collar 2-7/8" Float Joint 2-7/8" BTT Float Collar BTT Unique Rotating Guide shoe. Total Liner BHA length = 2802.39' 18:15 - 19:30 1.25 CASE P RUNPRD M/U BTT pump off GS spear and CoilTrak tools. Pull test spear with liner weight. 19:30 - 21:40 2.17 CASE P RUNPRD Correct to flag -41'. Up wt 43K, Continue to RIH. Bauble at 9492, lost 4K wt 9932. Second flag -3' correction. Taq at 11,685 TD. 21:40 - 21:45 0.08 CASE P RUNPRD Circulate 1.8 bpm at 3250 psi. 1 for 1 returns. OK. PU 28K. released from liner. 21:45 - 23:00 1.25 CASE P RUNPRD POH. 23:00 - 00:00 1.00 CASE P RUNPRD LD BHA #8. RU N2 unit. 10/3/2007 00:00 - 00:30 0.50 CASE P RUNPRD RU N2 unit. 00:30 - 00:45 0.25 CASE P RUNPRD PJSM for N2 Slowdown. 00:45 - 02:30 1.75 CASE P RUNPRD Circulate 55 bl H2o, 15 bl Inhibitor, 10 bbl H2O, & 15 bbl MEOH. Chased with N2. 02:30 - 03:30 1.00 CASE N RUNPRD Equipment problem with N2 pumper. Wait on replacement N2 unit. 03:30 - 05:00 1.50 CASE P RUNPRD N2 Blow down. 05:00 - 06:00 1.00 CASE P RUNPRD LD BHA. Remove. coil connector. 06:00 - 06:50 0.83 CEMT N RREP RUNPRD Determine that driller side winch cable on reelstand bridge crane needs re-spooling. Held prejob safety meeting. Re-spool cable, OK. 06:50 - 10:00 3.17 CEMT P RUNPRD Pull test internal connecter. Pull coil to reel. Secure coil on reel. 10:00 - 10:15. 0.25 CEMT P RUNPRD SAFETY MEETING. Review procedure, hazards and Printed: 10/23/2007 2:59:42 PM • BP EXPLORATION Page 10 ofi 12 Opelrations Summary.Report Legal Well Name: 05-10 Common Well Name: 05-10 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date !From - To ~ Hours I Task ~ Code ~ NPT 10/3/2007 10:00 - 10:15 0.25 CEMT I P 10:15 - 12:30 2.25 CEMT P 12:30 - 12:45 0.25 CEMT P 12:45 - 13:45 1.00 CEMT P 13:45 - 16:00 2.25 CEMT P 16:00 - 16:15 0.25 CEMT P 16:15 - 17:30 I 1.251 CEMT I P 17:30 - 19:15 I 1.751 CEMT I P 19:15 - 19:30 I 0.251 CEMT I P 19:30 - 20:10 0.67 CEMT P 20:10 - 22:45 2.58 CEMT P 22:45 - 23:00 0.25 CEMT P 23:00 - 00:00 1.00 CEMT P 110/4/2007 100:00 - 00:45 I 0.751 CEMT I P 02:15 - 03:20 I 1.081 CEMT I P 03:20 - 03:30 0.17 CEMT P 03:30 - 05:00 1.50 CEMT P 05:00 - 09:50 4.83 CEMT P 09:50 - 10:45 0.92 CEMT P 10:45 - 13:05 2.33 EVAL P Spud Date: 7/28/1977 Start: 9/23/2007 End: 10/6/2007 Rig Release: 10/6/2007 Rig Number: N1 , Phase Description of Operations RUNPRD mitigation for swapping reels with bridgecrane, RUNPRD Take weight with crane. Pull pins from reel. Open bombay door. Lower reel. Pick up E-Free coil. Close bombay door. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for pulling coil to injecter. RUNPRD Pull coil to injecter. cut off internal connecter. RUNPRD M/U BTT CTC. Pull test. Pump dart. Dart landed at 59.2 bbl. RUNPRD SAFETY MEETING. Review procedure, hazards and mitigation for M/U BTT CTLRT BHA. RUNPRD M/U BTT CTLRT BHA with seal assy and LWP and 1 jt of 2-3/8" PH6. BHA OAL = 52.00'. RUNPRD RiH with BTT CTLRT BHA #9. Circ at min. rate. RIH to 8800'. PU 34K. RUNPRD Sting on to liner. Establish circulation..55 bpm@ 1800psi. Establish full returns. Attempt to reciprocate liner. PU 60 K Break over to 39K. PU 40' RIH to TD. PU 40' 42K break over to 39K. RIH lost 20'. PU run to TD. RUNPRD Drop 5/8" Stl ball and circulate to seat. On seat @ 47.6 bbl. Shear at 4510 psi. PU 26K. Set down stack 14K. RUNPRD Swap well to 2% KCL double slick. RUNPRD PJSM for cement job. RUNPRD Batch mix 33bb1 cement. Flood lines and PT hard line to 4000psi. Pump 33 bbl to CT 1.95 bpm1070 psi. Zero in MM on density of 15.0 ppg. Pump 2.2 bpm at 1720-2500 psi. RUNPRD Displace cement with 35 bbl bio and KCL at 2.79 bpm and 1500 psi. Took 14 bbl to catch cement due to long turnaround to vac lines to cementers. This was due to Thick Bio. We needed mud pump to assist charge pump to pump bio to cemeters. Held back cement with choke. Lauch dart with 100 psi. Displace with 35 bbl 2# bio and 2% KCL. Zero out MM at 76.8 bbl. PU liner wiper plug at92.8 bbl actual (calculated at 92.3 bbls). Shear LWP with 3430 psi. Bump plug at 110.7 bbl (caluulated 110.4bbls). OMM = 31.6 bbl, 1.5 bbl loss. Held 2900 psi for 5 min. Bleed off floats held. Pressure to 200 psi and unsting 38K up.Seals sting in at 8921'. RUNPRD POH filling metal displacement. RUNPRD LD BHA Clear floor for Memory logging /cleanout run. Pu mill and motor. RUNPRD PJSM for PU memory tools. RUNPRD Pu memory tools. First tool failed to test PU second tool OK. RUNPRD Pu 90 joints of CSH tubing and SWS MHA. BHA OAL = 2891'. RUNPRD RIH with Mill/Mtr/MCNL BHA #10. LOWER1 Log down with SWS Memory CNL/GR/CCL logging tools at 30 fph, circ 1.5 bpm at 1950 psi, full returns. RIH into too of liner with no wt loss. Did see contaminated Tagged. PBTD at 11,692' CTD. 13:05 - 14:45 1.67 EVAL ~ P LOWERI Log up to 7500' at 60 fpm. Lay in new High Vis FloPro pert pill from PBTD to top of liner. 14:45 - 17:00 2.25 EVAL P LOWER1 RIH to 9100'. Circ. 5/8" AL ball and open circ sub. circ. at 2.6 bpm while POH to clean up well. 17:00 - 17:10 0.17 EVAL P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for standing back CSH. Printed: 10/23/2007 2:59:42 PM BP EXPLORATION Page 1 ~ of 12 Operations Suimlrnary Report Legal Well Name: 05-10 Common Well Name: 05-10 Spud Date: 7/28/1977 Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/4/2007 17:10 - 19:30 2.33 EVAL P LOWER1 POH stand back CSH. 19:30 - 20:00 0.50 EVAL P LOWER1 LD Memory log tool and cleanout mill and motor. Fax log to town. 20:00 - 21:30 1.50 EVAL P LOWER1 Close master. Stab on to well and flush BOP stack. Load pipe shed with guns. 21:30 - 22:00 0.50 EVAL P LOWER1 Prep floor for liner lap test. 22:00 - 23:45 1.75 EVAL P LOWER1 Test liner lap to 2000 psi Lost 250 psi in 30 min. Failed Test. 23:45 - 00:00 0.25 PERFO P LOWER1 Prep floor for PU guns. 10/5/2007 00:00 - 00:20 0.33 PERFO P LOWER1 PJSM for PU perforating guns. 00:20 - 03:30 3.17 PERFO P LOWER1 Run 79 gun into well. 03:30 - 05:00 1.50 PERFO P LOWER1 RIH with 19 stands of 1-1/4" CSH. 05:00 - 07:00 2.00 PERFO P LOWER1 RIH with perforating assembly. Tag PBTD. Pick up at 11,685' CTD. Correct to 11,650' PBTD from MCNL/GR log. Pump 10 bbl High Vis FloPro pert pill ahead of ball. 07:00 - 08:45 1.75 PERFO P LOWER1 Insert 5/8" AL ball and displace with 8 bbl FloPro and KCL water. Position bottom shot at 11,634'. Circ ball on seat at 55.2 bbl. Fire guns on depth on the fly. 1 K overpull after guns fired. Continue POH with pert guns. Good Shot detection from SWS. Pull to 8800'. Stop and flow check well. No Flow. 08:45 - 10:00 1.25 PERFO P LOWER1 POH with pert guns. Held Kick while trip drill. Flow check with CSH at surface. No flow. 10:00 - 10:15 0.25 PERFO P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out CSH in singles. 10:15 - 12:30 2.25 PERFO P LOWER1 Lay out CSH workstring. 12:30 - 12:45 0.25 PERFO P LOWER1 SAFETY MEETING. Review procedure, hazards and mitigation for laying out SWS pert guns. 12:45 - 18:00 5.25 PERFO P LOWER1 Lay out fired pert guns. 18:00 - 19:00 1.00 PERFO P LOWER1 Load out spent guns. 19:00 - 20:00 1.00 PERFO P LOWER1 RIH with 1-1/4 "CSH and LD same (for Rig move) 20:00 - 20:20 0.33 PERFO P LOWER1 Shut down for Nordic 401 K meeting. 20:20 - 22:00 1.67 PERFO P LOWER1 POH LD 1-1/4" CSH. 22:00 - 22:40 0.67 CASE P RUNPRD PU KB packer assy and Mu BHA. 22:40 - 00:00 1.33 CASE P RUNPRD RIH with KB liner top packer assembly. 10/6/2007 00:00 - 00:45 0.75 CASE P RUNPRD RIH with liner top packer to 8500'. Wt check 33.5K up. Tag up 8926 un corrected stack out at 8930.9' PU to ball drop position. PU wt 38K. 00:45 - 02:00 1.25 CASE P RUNPRD Launch ball with 1000 psi and circulate to tool 2.5 bpm @ 1200 ' psi. To KB running tool on seat at 46.3 bbls. Sting back onto liner Stack 6K. PU to breakover 38K + 1'. Pressure to 2000 psi. SO to 15K. Bleed off pressure. PU to34K. Pressure annulus to 2000 psi. for 30 min good test. Pressure to 3700 to shear. 02:00 - 03:30 1.50 CASE P RUNPRD POH. 03:30 - 04:00 0.50 CASE P RUNPRD BHA swap. 04:00 - 05:30 1.50 WHSUR P POST RIH to 2200" Freeze protect with MEOH. 05:30 - 07:30 2.00 RIGD P POST Pump SWS pickle procedure, Blow down reel with N2. Bleed off press to tiger tank. 07:30 - 07:45 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and mitigation for setting BPV. 07:45 - 08:30 0.75 RIGD P POST Set BPV. Close master and swab valves. SIWHP = 0 psi. Printed: 10/23/2007 2:59:42 PM • BP EXPLORATION' Page 12 of 12 Operations Slummary Report Legal Well Name: 05-10 Common Well Name: 05-10 Spud Date: 7/28/1977 Event Name: REENTER+COMPLETE Start: 9/23/2007 End: 10/6/2007 Contractor Name: NORDIC CALISTA Rig Release: 10/6/2007 Rig. Name: NORDIC 1 Rig Number: N1 Date From - To Hours Task Code NPT Phase Description of Operations 10/6/2007 08:30 - 11:15 2.75 RIGD P POST Change out packoff to 2". install internal grapple. Clean rig pits. Change out rams in BOP's for 2" coil. 11:15 - 11:30 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and mitigation for setting BPV. 11:30 - 13:00 1.50 RIGD P POST Pull test internal grapple. Pull coil stub to reel. Secure coil on reel. 13:00 - 13:15 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and mitigation for swapping reels with bridgecrane. 13:15 - 15:00 1.75 RIGD P POST Lower 2-3/8" E-Free coil onto Veco trailer. Pick up 2" E-Coil reel. 15:00 - 17:30 2.50 RIGD P POST Nipple down BOP's. N/U tree cap. Press test tree cap. RELEASED RIG AT 17:30 HRS, 10/06/2007. TOTAL TIME FROM RIG ACCEPT TO RIG RELEASE WAS 12 DAYS, 14-1 /2 HOURS. ALL FURTHER DIMS INFORMATION WILL BE ON DS 05-226 REPORTS. MOVED RIG TO DS 05-328 WELL. Printed: 10/23/2007 2:59:42 PM i by BP Alaska $ Baker Hughes INTEQ Survey Report INTEQ Compauy: BP Amoco Date: 11 /5/2007 Time: 13:24:05 Page: 1 Field: Prudhoe Bay Co-ordiuate(NE) Refereuce: Well: 05-10, True North Site: PB DS 05 Vertical (TVD) Refereuce: 22:10 6!10/1994 00:00 62.3 Well: 05-10 Sectioa (VS) Refereuce: WeN (O.OON,O.OOE,251.10Azi) Wellpath: 05-10C Survey Calculation Method: Minimum Curvature Db: Orade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zoue: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5947204.70 ft Latitude: 70 15 35.696 N From: Map Easting: 697428.91 ft Longitude: 148 24 14.424 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 05-10 Slot Name: 10 05-10 Well Position: +N/-S 1628.53 ft Northing: 5948829.26 ft Latitude: 70 15 51.713 N +E/-W -126.65 ft Easting : 697259.62 ft Longitude: 148 24 18.109 W Position Uncertainty: 0.00 ft Wellpath: 05-10C Drilled From: 05-10A 500292026303 Tie-on Depth: 9054.00 ft Current Datum: 22:10 6/10/1994 00:00 Height 62.26 ft Above System Datum: Mean Sea Level Magnetic Data: 8/13/2007 Declination: 23.78 deg Field Strength: 57665 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (1'VD) +N/-S +E/_W Direction ft ft ft deg 28.26 0.00 0.00 251.10 Survey Program for Definitive Wellpath Date: 8/13/2007 Validated: Yes Version: 8 Actual From To Survey Toolcode Tool Name ft ft 625.26 7638.26 1 : Camera based mag multi sho CB-MAGMS Camera based mag multi shot 7698.00 8959.78 MWD (7698.00-10430.00) (1) MWD MWD -Standard 9050.00 11685.00 MWD (9050.00-11685.00) MWD MWD -Standard Annotation MD TVD ft ft 8959.78 8623.03 TIP 9050.00 8698.98 KOP 11685.00 8966.93 TD Survey: MWD Start Date: 10/1/2007 Compauy: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path ~~~y d~$ • • by BP Alaska Baker Hughes INTEQ Survey Report ~~~ u. _~,,~ s~n~ey MD ft Incl deg Azim deg "I'VD ft 8959.78 32.48 149.41 8623.03 9050.00 32.86 150.50 8698.98 9083.62 38.38 157.74 8726.31 9114.82 44.07 162.97 8749.78 9142.50 41.27 167.33 8770.13 9170.96 40.14 171.65 8791.71 9200.60 40.04 186.40 8814.44 9234.19 40.27 198.83 8840.15 9273.24 40.54 213.00 8869.95 9300.24 46.50 216.87 8889.53 9334.77 52.35 224.36 8911.99 9368.82 55.83 235.61 8932.00 9396.71 57.98 246.51 8947.26 9422.21 62.52 255.81 8959.94 9456.50 67.79 258.13 8974.34 9486.30 72.67 262.36 8984.42 9521.14 80.16 270.30 8992.61 9549.90 85.41 279.40 8996.23 9580.89 87.26 288.21 8998.21 9611.64 91.14 299.23 8998.64 9640.80 90.22 306.76 8998.30 9675.91 91.78 305.16 8997.68 9706.29 89.54 304.80 8997.33 9739.80 88.62 302.54 8997.87 9772.92 88.53 300.07 8998.70 9803.14 86.46 298.62 9000.02 9834.19 86.90 294.97 9001.82 9864.51 88.07 293.27 9003.15 9894.07 90.61 291.76 9003.49 9927.87 92.67 290.44 9002.52 9961.11 92.31 286.51 9001.07 9991.29 90.86 284.26 9000.24 10027.82 90.40 281.45 8999.84 10061.13 91.02 279.74 8999.43 10095.02 91.35 276.10 8998.72 10127.34 87.94 278.74 8998.92 10160.49 90.61 281.48 8999.34 10196.27 89.97 286.85 8999.16 10232.84 90.58 292.29 8998.99 10259.10 91.53 295.10 8998.50 10288.34 90.71 298.03 8997.93 10315.58 91.44 301.03 8997.42 10345.90 92.65 304.97 8996.34 10373.64 90.83 309.09 8995.50 10409.35 88.95 307.09 8995.56 10440.36 89.66 302.26 8995.94 10471.72 90.09 300.34 8996.01 10502.18 92.00 297.64 8995.45 10537.41 92.53 294.07 8994.06 10568.98 93.77 290.46 8992.33 10597.42 92.40 288.04 8990.79 10630.38 90.00 284.11 8990.10 10666.51 89.85 286.45 8990.15 Sys TVD N/S E/V1' ft ft ft 8560.77 -1297.36 781.36 8636.72 -1339.52 805.74 8664.05 -1357.14 814.20 8687.52 -1376.50 821.05 8707.87 -1394.62 825.88 8729.45 -1412.86 829.27 8752.18 -1431.83 829.59 8777.89 -1452.87 824.88 8807.69 -1475.51 813.87 8827.27 -1490.72 803.20 8849.73 -1510.55 786.10 8869.74 -1528.18 765.00 8885.00 -1539.44 744.59 8897.68 -1546.53 723.67 8912.08 -1553.53 693.36 8922.16 -1558.27 665.74 8930.35 -1560.39 631.99 8933.97 -1557.97 603.60 8935.95 -1550.60 573.60 8936.38 -1538.25 545.50 8936.04 -1522.38 521.07 8935.42 -1501.77 492.65 8935.07 -1484.35 467.76 8935.61 -1465.78 439.88 8936.44 -1448.58 411.59 8937.76 -1433.78 385.28 8939.56 -1419.81 357.61 8940.89 -1407.43 329.97 8941.23 -1396.12 302.67 8940.26 -1383.95 271.15 8938.81 -1373.43 239.66 8937.98 -1365.43 210.57 8937.58 -1357.30 174.96 8937.17 -1351.18 142.23 8936.46 -1346.51 108.67 8936.66 -1342.34 76.63 8937.08 -1336.52 44.01 8936.90 -1327.77 9.33 8936.73 -1315.52 -25.12 8936.24 -1304.97 -49.16 8935.67 -1291.90 -75.30 8935.16 -1278.48 -99.00 8934.08 -1261.98 -124.40 8933.24 -1245.29 -146.53 8933.30 -1223.26 -174.64 8933.68 -1205.62 -200.13 8933.75 -1189.33 -226.92 8933.19 -1174.57 -253.56 8931.80 -1159.23 -285.23 8930.07 -1147.28 -314.40 8928.53 -1137.92 -341.21 8927.84 -1128.80 -372.86 8927.89 -1119.28 -407.71 MapN MapE ft ft 5947552.88 698074,66 5947511.38 698100.14 5947493.99 698109.05 5947474.82 698116.41 5947456.83 698121.71 5947438.69 698125.58 5947419.73 698126.40 5947398.57 698122.23 5947375.66 698111.82 5947360.17 698101.56 5947339.91 698084.99 5947321.73 698064.36 5947309.94 698044.25 5947302.30 698023.52 5947294.51 697993.41 5947289.05 697965.92 5947286.04 697932.24 5947287.72 697903.80 5947294.31 697873.62 5947305.91 697845.21 5947321.13 697820.36 5947340.99 697791.42 5947357.75 697766.09 5947375.59 697737.73 5947392.04 697709.00 5947406.14 697682.31 5947419.38 697654.29 5947431.03 697626.33 5947441.63 697598.75 5947452.96 697566.92 5947462.65 697535,17 5947469.89 697505.88 5947477.08 697470.08 5947482.34 697437.19 5947486.13 697403.53 5947489.46 697371.39 5947494.42 697338.63 5947502.26 697303.73 5947513.60 697268.98 5947523.51 697244.67 5947535.90 697218.20 5947548.69 697194.16 5947564.52 697168.33 5947580.63 697145.77 5947601,91 697117.10 5947618.87 697091.16 5947634.45 697063.95 5947648.51 697036.94 5947663.02 697004.88 5947674.19 696975.41 5947682.85 696948.36 5947691.14 696916.48 5947699.74 696881.40 VS DLS Tool ft deg/100ft -318.90 0.00 MWD -328.30 0.78 MWD -330.59 20.64 MWD -330.81 21.31 MWD -329.50 14.70 MWD -326.80 10.66 MWD -320.96 32.00 MWD -309.68 23.85 MWD -291.93 23.50 MWD -276.91 24.17 MWD -254.31 23.61 MWD -228.64 28.62 MWD -205.68 33.62 MWD -183.58 36.30 MWD -152.65 16.55 MWD -124.98 21.13 MWD -92.36 30.86 MWD -66.29 36.30 MWD -40.30 28.99 MWD -17.71 37.98 MWD 0.26 26.01 MWD 20.47 6.36 MWD 38.37 7.47 MWD 58.73 7.28 MWD 79.92 7.46 MWD 100.02 8.36 MIND 121.67 11.82 MWD 143.81 6.80 MWD 165.98 10.00 MWD 191.85 7.24 MWD 218.24 11.86 MWD 243.16 8.87 MWD 274.22 7.79 MWD 303.20 5.46 MWD 333.44 10.78 MWD 362.40 13.34 MWD 391.38 11.54 MWD 421.35 15.11 MWD 449.97 14.97 MWD 469.30 11.29 MWD 489.79 10.40 MWD 507.86 11.33 MWD 526.55 13.59 MWD 542.08 16.23 MWD 561.53 7.69 MWD 579.94 15.74 MWD 600.01 6.27 MWD 620.42 10.86 MWD 645.42 10.24 MWD 669.14 12.07 MWD 691.47 9.77 MWD 718.46 13.97 MWD 748.35 6.49 MWD • by BP Alaska $ Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 11/5/2007 Time: 13:24:05 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: 05-10, True North Site: PB DS 05 Vertical (TVD) Reference: 22:1 0 6110/1 994 00:00 62.3 Well: 05-10 Section (VS) Reference: Well (O.OON,O.OOE,251.10Azi) R'ellpath: 05-10C Survey Calculation Method: Minimum Curvature Db: Orade Survey MD ft Ind deg Azim deg T~~ ft 10699.56 92.88 290.54 8989.36 10727.14 93.57 292.30 8987.81 10760.64 94.22 296.95 8985.54 10795.53 95.30 302.13 8982.64 10829.15 94.83 307.10 8979.67 10867.76 92.70 312.51 8977.13 10908.98 92.61 319.57 8975.22 10948.57 89.29 325.33 8974.56 10994.78 91.08 331.76 8974.41 11031.19 88.65 334.64 8974.50 11067.64 86.16 337.75 8976.15 11095.20 87.05 341.11 8977.78 11126.27 89.14 343.04 8978.81 11157.91 91.29 346.06 8978.70 11185.93 93.19 348.88 8977.60 11216.71 90.98 350.73 8976.48 11250.10 90.64 352.52 8976.01 11278.42 94.52 350.87 8974.73 11306.20 94.83 346.95 8972.47 11338.06 94.52 342.69 8969.87 11366.18 92.42 339.78 8968.17 11393.42 91.69 336.53 8967.19 11424.34 90.95 332,54 8966.48 11458.81 89.82 327,68 8966.25 11494.00 91.56 323.97 8965.82 11526.03 88.43 320,28 8965.83 11561.74 88.74 315,42 8966.71 11594.52 90.43 310.06 8966.95 11626.43 91.04 307.20 8966.54 11664.44 88.93 303.93 8966.55 11685.00 88.93 303.93 8966.93 Sys TVD N/S E/W ft ft ft 8927.10 -1108.80 -439.04 8925.55 -1098.75 -464.67 8923.28 -1084.82 -495.04 8920.38 -1067.69 -525.28 8917.41 -1048.67 -552.84 8914.87 -1024.02 -582.42 8912.96 -994.40 -610.98 8912.30 -963.03 -635.09 8912.15 -923.63 -659.19 8912.24 -891.14 -675.61 8913.89 -857.83 -690.30 8915.52 -832.08 -699.97 8916.55 -802.54 -709.52 8916.44 -772.04 -717.95 8915.34 -744.72 -724.02 8914.22 -714.45 -729.47 8913.75 -681.42 -734.33 8912.47 -653.43 -738.41 8910.21 -626.26 -743.74 8907.61 -595.62 -752.05 8905.91 -569.05 -761.08 8904.93 -543.79 -771.21 8904.22 -515.89 -784.50 8903.99 -486.01 -801.67 8903.56 -456.91 -821.43 8903.57 -431.63 -841.09 8904.45 -405.17 -865.04 8904.69 -382.93 -889.10 8904.28 -363.02 -914.03 8904.29 -340.91 -944.94 8904.67 -329.44 -962.00 MapN MapE ft ft 5947709.39 696849.81 5947718.77 696823.92 5947731.89 696793.20 5947748.23 696762.52 5947766.52 696734.48 5947790.39 696704.26 5947819.25 696674.94 5947849.97 696650.01 5947888.72 696624.89 5947920.77 696607.63 5947953.68 696592.07 5947979.17 696581.73 5948008.45 696571.41 5948038.71 696562.19 5948065.87 696555.40 5948095.98 696549.16 5948128.87 696543.44 5948156.74 696538.62 5948183.76 696532.59 5948214.17 696523.47 5948240.49 696513.75 5948265.48 696502.97 5948293.02 696488.95 5948322.44 696471.01 5948351.01 696450.49 5948375.76 696430.18 5948401.58 696405.54 5948423.18 696380.91 5948442.44 696355.47 5948463.72 696323.99 5948474.74 696306.64 V S DLS Tool ft deg/100ft 774.59 15.40 MWD 795.58 6.84 MWD 819.81 13.98 MWD 842.86 15.12 MWD 862.77 14.79 MWD 882.77 15.03 MWD 900.20 17.11 MWD 912.84 16.79 MWD 922.88 14.44 MWD 927.88 10.35 MWD 930.99 10.92 MWD 931.79 12.59 MWD 931.26 9.15 MWD 929.35 11.72 MWD 926.25 12.13 MWD 921.59 9.36 MWD 915.49 5.46 MWD 910.29 14.89 MWD 906.52 14.11 MWD 904.46 13.36 MWD 904.39 12.75 MWD 905.79 12.22 MWD 909.32 13.12 MWD 915.89 14.47 MWD 925.15 11.64 MWD 935.56 15.11 MWD 949.65 13.63 MWD 965.21 17.14 MVVD 982.34 9.16 MWD 1004.42 10.24 MWD 1016.84 0.00 MWD TREE = 41116" CNV WELLHEAD= FMC ACTUATOR = KB. ELEV = BAKER C 62.3' BF. ELEV = KOP = WA 5350' Max Angle = 95 @ 10796' Datum MD = Datum TVD = 9263' 8800' SS DRLG DRAFT 13-3/8" CSG, 72#, MN-80, ID = 12.347" 2703' Minimum ID = 2.36" ~ 8879' BTT LT PKR Seal Assy 7" BKR TIEBACK SLV, D = 7.500" 7521' 9-5/S" X 7" BKR LT PKR, ID = 6.188" 7528' 9-5/8" X 7" BKR HMC HGR, ID = 6.188" 7534' s-s/s° csG, a7u, N-so, to = 8.681 ° 7693' Top of Cement Sgg0' TOP OF 3-3/16" LNR 8880' 3.5" X Nip 2.813" ID 8899' 05-10C CTD Sidetrack I • I = 3.812" GA S LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3829 3829 0 TPD DOME T-2 16 10/19/07 2 5756 5744 18 TPD SO T-2 16 10/19/07 3 7460 7285 25 TPD DMY T-2 0 07/16/94 9-5/8" CSG M~LOUT WINDOW 7693' -7743' (SECTION MILL) 8500' Top of cement packer (cak:) 8111/07 $$74' BTT LINER TOP PACKER, 2.38" ID 13-3/16 x 2-7/8 X-over Cement Retainer 8/5/07 H 9110' ~ Tubing Punch 8/4/07 91305 3.7T' G SEA L SUB, ID = 3.Q0" 9137' 3-1/2" X 2-7/8" LNR XO, ID = 2.387" 9143' of cement behind 2-718" liner I-~ 9250' ~ 41/2" TBG, 12.6tf, L-80, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: SWS MCNUGR/CCL OF 10/04/2007 ANGLE AT TOP PERF: 92 ~ 9970' Note: Refer to Roduction DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 2" 6 9970 - 10025 OPEN 10/05/07 2" 6 10050 - 10340 OPEN 10/05!07 2" 6 10370 - 10510 OPEN 10/05/07 2" 6 10535 - t 0585 OPOV t 0/05/07 2" 6 10695 - 10725 OPEN 10/05/07 2" 6 10770 - 11170 OPEN 10/OSro7 2" 6 11270 - 11630 OPEN 10105107 T LNR, 29iF, NT-SOS, ID = 6.182" 9621' 2-7/8" LNR, 6.5#, L-80, .0058 bpf, m = 2.387" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNR 09/11/77 ORIGINAL COMPLETION 08/17!03 CMO/TLP DATUM MD / PERF A NGLE WELL: OS-10C 07/16/94 ROTARY SIDETRACK (05-10A) 05/19/07 JA/TLH 4-112" WRP PLUG SET PERMIT No: 82070980 09!12!96 CTD SIDETRACK (05-106) 10/06/07 RRW CTD HORIZONTAL SIDETRACK API No: 50-029-20263-03 01/28/02 CWKAK CORRECTIONS 10/19/07 JLJ/PJC GLV C!O SEC 34, T11 N, R15~ 2662' FSL & 5095' FB 61/09/03 SRB/TtH MILUPUSHCIBP 06/12/03 CMO/TLP KB ELEVATION CORRECTION BP 6cploration (Alaska} 3-3/16" X 2-718" cmt'ed and perfedH 11685' 9050' Mechanical Whipstock 8/26107 ~ 0~~„0' ~ C~P8/4/07 9240' 7" X 4-1/2" BAKER SABL-3 PKR ID = 3.875" (BEHIND CT LNR) 9259' 41/2" OTIS X NIP, ID = 3.813" (BEHIND CT LNR) 9276' 41 /2" OTIS XN NIP, ID = 3.725" (BEHOJD CT LNR) 9288' 41/2" WLEG (BEHIND CT LNR) 7" LNR MILLOUT WBJDOW 9346' - 9353' (OFF CMT PLUG) 10350' CM 2-7/8" CIBP MILLED & PUSHED TO PBTD 01 /09/03 PBTD 1035Z' ~ 0 d o ~ SARAH PALIN, GOVERNOR co1~TsERV~'r o rn~IISS 0 333 W. 7th AVENUE, SUITE 100 ~ii ANCHORAGE, ALASKA 89501-3539 PHONE (907) 278-1433 Garret Staudinger FAx (907) 276-7542 CT Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 05- l OC BP Exploration Alaska, Inc. Permit No: 207-098 Surface Location: 2662' FSL, 185' FWL, SEC. 32, T11N, R15E, UM Bottomhole Location: 2391' FSL, 672' FEL, SEC. 31, T11N R15E UM Dear Mr. Staudinger: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (paler). DATED this day of July, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA~ ' ALAS~IL AND GAS CONSERVATION COMMIS. ~JN PERMIT TO DRILL ~~'~~, 20 AAC 25.005 `>~~'~~ ,~ :? 1 x`07 .~_ ..a~. C~mmi~s~c~ 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is proposed for•: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 - 11. Well Name and Number: PBU 05-10C - 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD 11700 TVD 8910ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay- 4a. Location of Well (Governmental Section): Surface: 2662' FSL 185' FWL SEC 32 T11 N R15E UM - 7. Property Designation: ADL 028326 Pool , , , , , Top of Productive Horizon: 1438' FSL, 926' FWL, SEC 32, T11 N, R15E, UM ' 8. Land Use Permit: 13. Approximate Spud Date: September 25, 2007 " Total Depth: 2391' FSL, 672' FEL, SEC 31, T11N, R15E, UM 9. Acres in Property: 2560 `! 14. Distance to Nearest Property: 27,000' - 4b. Location of Well (State Base Plane Coordinates): Surface: x-697259 y-5948830 Zone-ASP4 10. KB Elevation (Height above GL): 62.3 ~ feet 15. Distance to Nearest Well Within Pool: 550' 16. Deviated Wells: Kickoff Depth: gOgS feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3220 Surface: 2340 18. C in Pr ram: S fications To - Settin De th -Bo ttom uanti of Cement c.f. or sa ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/8" 33/16" x2-7/8" 6.2# / 6.16# L-80 TCII / STL 2805' 8895' 8506' 11700' 8910 160 sx Class'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed foriRedrill and Re-entry Operations) Total Depth MD (ft): 10416 Total Depth TVD (ft): Plugs (measured): 8986 9102 Effective Depth MD (ft): 10352 Effective Depth TVD (ft): 8985 Junk (measured): 10350 Casing Length:.. Size Cement Volume MD : D Conductor /Structural 111' 20" 282 sx Permafrost 111' 111' Surface 2703' 13-3/8" 6620 sx Arctictset II 2703' 2703' Intermediate 7693' 9-518" 100 sx Class 'G' 300 sx Arcticset I 7693' 7497' Production Liner 1824' 7" 425 sx Class 'G' 7521' - 9345' 7340' - 8914' Liner 1279' 2-7/8" 46 sx Class 'G' 9137' - 10416' 8772' - 8986' Perforation Depth MD (ft): 9670' - 10310' Perforation Depth TVD (ft): 8987' - 8985' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Garret Staudinger, 564-4242 Printed Name Garret Stauding r Title CT Drilling Engineer Prepared By Name/Number: Si nature ~ Phone 564-4242 Date 7 12 0 ~ Terrie Hubble, 564-4628 Commission Use Qnl Permit To Drill Number: ~D.?0~9~D API Number: 50-029-20263-03-00 Permit Approval See cover letter for Date: other re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas rates, or gas contained shales:D~/ .~5~ ~-i ~~P ~~ ~~- Samples Req'd: ^ Yes No Mud Log Req'd: ^ Yes t~0 No HZS Measures: ' ectional Survey Req'd: Yes ^ No Other: n~/~ '_ APPROVED BY THE COMMISSION Date '' ~Q-I ,COMMISSIONER Form 10-401 Revised 12!2005 `~ Submit In Duplicate ,~RII~INAL ~~~~~ BP Prudhoe Bay OS-lOC CTD Sidetrack CTD Sidetrack Summary Pre-Rig Work: (Scheduled to begin July 20, 2007) 1) S Drifted liner to 9494' SLM May 18, 2007 2) S Passed tubing caliper inspection May 18, 2007 3) S Dummy GLV May 19, 2007 4) O Passed MIT-IA and MIT-OA. May 19 & 20, 2007 5) O AC -LDS; AC-PPPOT-IC, T May 26, 2007 6) S Pull WRP set in 4-1/2" tubing at 9102' SLM 7) S Run dummy whipstock drift 8) E Set Cast Iron Bridge Plug at 9150' in 2-7/8" liner 9) E Punch 4-1/2" tubing at 9130' 10) E Set cement retainer in 4-1/2" tubing at 9120' ~('~~ --~ 11) C Pump 16 bbls cement into annulus for cement packer 12) E Set 4-1/2" Baker Monobore WS at 9095' 13) O PT MV, SV, WV 14) O Blind and bleed lines 15) O Remove wellhouse, level pad Rig Work: (Scheduled to begin September 25, 2007) 1) MIRU Nordic 1 and test BOPE to 250psi low and 3500psi high. 2) Mi113.80" window at 9095' and 10' of rathole in Zone 3 through the 4-1/2" x 7" straddle 3) Drill Build: 4.125" OH, 605' (28 deg/100 planned) 4) Drill Lateral: 4.125" OH, 2000' (12 deg/100 planned) 5) Run 3-3/16" x 2-7/8" solid liner leaving TOL at 8895' ~~ ~ S ~ ~ pCp~C~,_ 6) Pump cement leaving TOC at 8895' 7) Cleanout liner and MCNL/GR/CCL log (' 8) Test liner lap to 2000 psi ~ S ©~ ~ l ~ ~* 9) Perforate liner per asset instructions (1200') 10) Freeze protect well with diesel, set BPV, and RDMO Post-Rig Work: 1) Install well house, flow line, and gas lift valves 2) Pull BPV 3) Test Separator (1200' of perfs) Mud Program: • Well kill: 8.6 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole Size: • 4.125" Casing Program: Fully cemented liner • 3-3/16", 6.2#, L-80, TCII 8895'MD - 9700'MD • 2-7/8", 6.5#, L-80, STL 9700' MD -11700' MD • A minimum of 33 bbls 15.8 ppg cement will be used for liner cementing. Well Control: ~ • • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Max. planned hole angle is 95 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property - 27,000 ft. West • Distance to nearest well within pool - 550 ft. (OS-04A) Anti-collision Summary • All nearby wells passed all anti-collision scan Logging • MWD directional, gamma ray, and resistivity will be run over all of the open hole section. • A cased hole MCNL/GR/CCL log will be run Hazards • The maximum recorded H2S level on Drill Site 5 is 27 ppm (OS-OSB on 11/1/1990). • Lost circulation risk is moderate. Reservoir Pressure • Res. press. is estimated to be 3220 psi at 8800'TVDss (7.0 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2340 psi. 4-1/16" WELLHEAD = FMC ACTUATOR = BAK9~ C KB. ELEV = 62.3' BF. ELEV = WA KOP = 5350' Max Angle = 97 ~ 10181' Datum MD = 9257' Datum ND = 8800' SS 13-3/8" CSG, 72A~, MV-80, ID = 12.34T' H 270$' Minimum ID = 2.387" ~ 9143' 3-1/2" X 2-7/8" LNR XO 7" BKR T~BACK SLV, ID = 7.500" 7521' 9-5/8" X 7" BKR LT PKR, ID = 8.188" 7528' 9-5/8" X 7" BKR HMC HGR, ID = 8.188" 7534' 9-5J8" CSG, 47#, N-80, ID = 8.681" 7693' 3.77" G SEAL SUB, ID = 3.00" 9137' 3-1 /2" X 2-7/8" LNR XO, O = 2.387" 9143' os-~ oe I SAFELY NOTES: W ELL ANGLE > 70° ~ 9480' 8. > 90° ~ 9550'. 2116' H4-12"CAM-TRDR4A TRSSSV, ID=3.81x' GAS LIFTMANDRELS ST MD ND DEV TYPE VLV LATCH PORT OWTE 3829 3829 0 TPD DOME T-2 16 x/14/96 2 3 5758 7460 5744 7285 18 25 TPD TPD SO DMY T-2 T-2 18 0 W/14/96 07/18/94 9-5/8" CSG MLLOUT WINDOW 7693' -7743' (SECTION MLL) 9102' SLM H4-1/2" WRP PLUG (05!19/07) 82_~ 7" X 4-1 /2" BAKER SA BL-3 PKF ID = 3.875" (BEHIND CT LNR) 9269' 4-1 /r' OTIS X NIP, ID = 3.813" (BEHIND CT LNI~ 9276' 4-112" OTIS XN NIP, ID = 3.725" (BEHIND CT LNR) II 4-112" TBG, 12.8#, L-80, .0152 bpf, ID = 3.958" I PERFORATION SUMMARY REF LOG: AWS CNL ON 06/17/94 ANGLE AT TOP PERF: 90 ~ 9670' Note: Refer to Production DB for hstorical perf data SIZE SPF INTERVAL OpNSgz DATE 7' 6 9670 -9850 C 04103/99 2-1/8" 4 9894 -10050 C 09/11/96 2-1 /8" 4 10108 - 10128 C 10101 /'~ 2-1/8" 4 10170 - 10310 C 10101/' 9288' 4-1/2" WLEG (BEHIND CT LNR) T' LNR MLLOUT WINDOW 9346' -9353' (OFF CMf PLUG) 10350'CMD 2-7/8"CIBPMLLEDBPUSHED TO PBTD 01/09/03 I 10352' ! 2-7/8" LNR, 6.5#, L-80, .0058 bpf, 10 = 2.387" I~ 10416' GATE REV BY COMNBJTS DATE REV BY COMY~ITS 09N11'77 ORIGINAL COMPLETION 08/17103 CMO/TLP DATUM ND/ PERFANGLE 07H6l94 CTDSIDETRACK(03-10A) 05/19107 JA/TLH 4-1R"WI~PPLUGSET 09M2196 CTDSIDETRACK(05-10~ 01/28/02 CHIKAK CORRECTIONS 01!09/03 SRB/TLH MLUPUSH GBP 06/12/03 CMO/TLP KB E3EVATION CORRECTION PRUDHDE BAY UNR WELL: 05-108 PERMIT No: 1961500 API No: 50-029-2026302 SEC 34, T11 N, R15E, 2662' FSL &5095' FEL BP Exploration (Alaska) = 4-1 WD_LHEAD = FMC ACTUATOR = BAK9~ C KB. ELEV = 62.3' BF. ELEV = rYA KOP = 5350' Max Angle = 97 ~ 10181' Datum MD = 9257' Datum ND = 8800' SS Q 5 ~ 1 Q ~ SAFETY NOTES: W ELL ANGLE > 70° ~ 9480' & > 90° aLD 9550'. Proposed CTD Sidetrack I O I 13-3/8" CSG, 72#, MN-80, ID = 12.347" H 2703' ~- Minimum ID = 2.387" @ 9143' 3-1 /2" X 2-7/8" LN R XO 7" BKR TEBACK SLV, ID = 7.500" 7521' _ 9-5/8" X 7" BKR LT PKR, ID = 6.188" 7528' 9-5/8" X 7" BKR HMC HGR, ID = 6.188" 7534' 9-518" CSG, 47#, N-80, ID = 8.681" 7693' ?op of Cement 8895' TOP OF 3-3/16" LN 8895' 3.5" XN Nip 2.75" ID 8905' 2116' H4-1/2" CAM-TRDP-4A TRSSSV, ID= 3.812" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 3829 3829 0 TPD DOME T-2 16 09/14/96 2 3 5756 7460 5744 7285 18 25 TPD TPD SO DMY T-2 T-2 16 0 09/14/96 07/16/94 9-5/8" CSG MILLOUT WINDOW 7693' - 7743' (SECTION MILL) 8500' "co o` cer,ient packer 9700' H3-3116 x 2-7/8 X-over Cement Retam,er I--I 9120' Tubing Punch 9130' 3.77" G SEAL SUB, ID = 3.00" 9137' 3-1 /2" X 2-7/8" LNR XO, ID = 2.387" 9143' Top of cement behind 2-7/8" liner 9250' 3-3116" X 2-716" cmt'ed and perfedH 11700' 9095' Mechanical Whipstock 9150' CIBP 9240' ~7" X 4-1/2" BAKER SABL-3 PKR ID = 3.875" (BEHIND CT LNR) 9259' 4-1/2" OTIS X NIP, ID = 3.813" (BEHIND CT LNR) 9276' 4-112" OTIS XN NIP, m = 3.725" (BEHIND CT LNR) 4-1 PERFORATION SUMMARY REF LOG: AW5 CNL ON 06/17/94 ANGLE AT TOP PERF: 90 (d3 9670' Note: Refer to Production DB for historical perf data SIZE SPF INTB~1/AL OpNSgz DOTE 2" 6 9670 - 9850 ~-..., ?~ o~.^sed 2-1/8" 4 9894 - 10050 soiated proposed 2-1/8" 4 10108 - 10128 isolated proposed 2-1/8" 4 10170 - 10310 isolated proposed 7" LNR MILLOUT WNDOW 9346' - 9353' (OFF CMT PLUG) 10350' CMD 2-7/8" CIBP MILLED & PU: TO PBTD 01 /09/03 PBTD 10352' 2-7/8" LNR, 6.5#, L-80, .0058 bpf, D = 2.387" H 10416' DATE REV BY COMMENTS DATE REV BY COMMENTS 09/11/77 ORIGINAL COMPLETION 08/17/03 CMO/TLP DATUM MD / PERF ANGLE 07/16!94 CTD SIDETRACK (05-10A) 05/19/07 JA/TLH 4-1/2" WRP PLUG SEf 09/12/96 CTD SIDETRACK (OS-10~ 01/28/02 CWKAK CORRECTIONS 01/09/03 SRB/TLH MILUPUSH CIBP 06/12/03 CMO/TLP KB ELEVATION CORRECTION 9288' 1~4-1/2" WLEG (BB-IND CT LNR) PRUDHOE BAY UNfr WELL: 05-106 PERMfr No: '1961500 AR No: 50-029-20263-02 SEC 34, T11 N, R15E, 2662' FSL & 5095' FE3 BP 6cploration (Alaska) • • by BP Alaska S Baker Hughes INTEQ Planning Report INTEQ Company: BP Rmoco Date: 7/6/2007.. Time: 15:26:32 ° Page: I Field: Prudhoe Bay Co-ordioate(NE) Reference: Well: 05-10, True North' Site: PB OS 05 Vet•tlcal (TVD) Reference; - 22 : 10 6!10/1994 00:00 62:3 Well: 05-10 Sectioe (VS) Reference: We0 (O:OON,O.OOE,330.OQAz) Wellpath: Plen 3, 05-10C Survey Cakalatioe Method: Minimum Curvature Db: grade Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datnm: Mean Sea Level Geomagnetic Model: bggm2007 Site: PB DS 05 TR-11-15 UNITED STATES :North Slope Site Position: Northing: 5947204 .70 ft Latitude: 70 15 35.696 N From: Map Easting: 697428 .91 ft Longitude: 148 24 14.424 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 05-10 Slot Name: 10 05-10 Well Position: +N/-S 1628.53 ft Northing: 5948829 .26 ft Latitude: 70 15 51.713 N +E/-W -126.65 ft Easting : 697259 .62 ft Longitude: 148 24 18.109 W Position Uncertainty: 0.00 ft Wellpath: Plan 3, 05-10C Drilled From: 05- 106 Tie-oe Depth: 9087.04 ft Current Datum: 22:10 6/10/1994 00 :00 Height 62 .26 ft Above System Datum: Mean Sea Level Magnetic Data: 7/6/2007 Declination: 24.01 deg Field Strength: 57673 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 28.26 0.00 0.00 330.00 Plan: Plan #3 Date Composed: 7/6/2007 copy Lamar's Plan 3 Version: 3 Principal: Yes Tied-to: Fro m: Definitive Path Targets Map Map G-- Latitude --> <-- Longitude --> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 05-10C Fault 3 62.26 -159.82 -744.11 5948650.00 696520.00 70 15 50.140 N 148 24 39.764 W -Polygon 1 62.26 -159.82 -744.11 5948650.00 696520.00 70 15 50.140 N 148 24 39.764 W -Polygon 2 62.26 453.12 -1038.16 5949255.00 696210.00 70 15 56.168 N 148 24 48.324 W 05-10C Fault 4 62.26 101.50 -1172.43 5948900.00 696085.00 70 15 52.710 N 148 24 52.231 W -Polygon 1 62.26 101.50 -1172.43 5948900.00 696085.00 70 15 52.710 N 148 24 52.231 W -Polygon 2 62.26 -405.32 -1110.68 5948395.00 696160.00 70 15 47.726 N 148 24 50.431 W -Polygon 3 62.26 -1648.89 -993.22 5947155.00 696310.00 70 15 35.495 N 148 24 47.008 W -Polygon 4 62.26 -405.32 -1110.68 5948395.00 696160.00 70 15 47.726 N 148 24 50.431 W 05-10C Polygon 62.26 -1678.44 706.69 5947170.00 698010.00 70 15 35.205 N 148 23 57.548 W -Polygon 1 62.26 -1678.44 706.69 5947170.00 698010.00 70 15 35.205 N 148 23 57.548 W -Polygon 2 62.26 -1457.69 -272.92 5947365.00 697025.00 70 15 37.376 N 148 24 26.051 W -Polygon 3 62.26 -1139.39 -584.71 5947675.00 696705.00 70 15 40.507 N 148 24 35.123 W -Polygon 4 62.26 -986.70 -875.82 5947820.00 696410.00 70 15 42.008 N 148 24 43.595 W -Polygon 5 62.26 -278.76 -977.31 5948525.00 696290.00 70 15 48.970 N 148 24 46.551 W -Polygon 6 62.26 -243.88 -781.32 5948565.00 696485.00 70 15 49.314 N 148 24 40.847 W -Polygon 7 62.26 -867.72 -262.46 5947955.00 697020.00 70 15 43.179 N 148 24 25.747 W -Polygon 8 62.26 -1377.74 684.56 5947470.00 697980.00 70 15 38.162 N 148 23 58.191 W 05-10C Fautt 2 62.26 -1223.71 -611.93 5947590.00 696680.00 70 15 39.677 N 148 24 35.915 W -Polygon 1 62.26 -1223.71 -611.93 5947590.00 696680.00 70 15 39.677 N 148 24 35.915 W -Polygon 2 62.26 -1422.59 -467.08 5947395.00 696830.00 70 15 37.721 N 148 24 31.700 W 05-10C Fault 1 62.26 -1290.12 776.89 5947560.00 698070.00 70 15 39.024 N 148 23 55.504 W -Polygon 1 62.26 -1290.12 776.89 5947560.00 698070.00 70 15 39.024 N 148 23 55.504 W -Polygon 2 62.26 -1502.42 861.36 5947350.00 698160.00 70 15 36.936 N 148 23 53.047 W -Polygon 3 62.26 -2106.94 1215.66 5946755.00 698530.00 70 15 30.990 N 148 23 42.741 W by BP Alaska s Baker Hughes INTEQ Planning Report iNTE Q Gompsny: BP Amoco Date; 7/6/2007 Tune: 15:26:32 ;Page: 2 Field: Prudhoe Bay Co-ordiaate(NE) Reference: Wel{`. 05-10, True North Site: PB DS 05 Vertical (TVD) Reference; 22:40 6[10/1994 00:00 62.3 Well: 05-10 Section (VS) Reference: Well (O.OON,O.OOE,330:OOAzi) Wdlpath: Plant 3, 05-10C Snrvey Calculation Method: Minimum Curvature Dh: Orate Targets Map Map. <..- .Latitude. ----~ <-. Lonzitade --a Name Description . TVD +N/-S +E/-W Northing Fasting Deg Min Sec Det Min Sec Dip.. Dir, ft ft ft ft ft -Polygon 4 62.26 -1502.42 861.36 5947350.00 698160.00 70 15 36.936 N 148 23 53.047 W 05-10C Target 5 8972.26 -287.30 -842.48 5948520.00 696425.00 70 15 48.887 N 148 24 42.627 W 05-10C Target 4 8975.26 -581.03 -819.17 5948227.00 696456.00 70 15 45.998 N 148 24 41.948 W 05-10C Target 3 8992.26 -990.67 -609.82 5947823.00 696676.00 70 15 41.969 N 148 24 35.854 W 05-10C Target 1 8996.26 -1458.51 369.31 5947381.00 697667.00 70 15 37.368 N 148 24 7.364 W 05-10C Target 2 9002.26 -1478.61 181.71 5947356.00 697480.00 70 15 37.171 N 148 24 12.822 W annotation MD TW ft ft 9087.04 8730.12 9095.00 8736.81 9115.00 8753.46 9145.00 8777.01 9539.57 8996.10 9664.57 8996.10 9814.57 8996.10 9914.57 8999.15 10014.57 9002.14 10164.57 9000.94 10414.57 8997.45 10714.57 8993.89 10914.57 8991.90 11214.57 8978.16 11364.57 8972.11 11700.00 8971.86 TIP KOP End of 9 Deg/100' DLS 4 End of 28 Deg/100' DLS 6 7 8 9 10 11 12 13 14 15 TD Plan Section Information MD ft Incl deg Azim deg TVD ft +N/-S ft +E/-W ft DLS Build Turn deg/100ft deg/100ft deg/100ft TFO Target deg 9087.04 32.70 151.20 8730.12 -1357.04 815.52 0. 00 0.00 0.00 0.00 9095.00 32.75 150.97 8736.81 -1360.81 817.60 1 .68 0.63 -2.89 291.81 9115.00 34.55 150.97 8753.46 -1370.49 822.98 9. 00 9.00 0.00 0.00 9145.00 42.01 157.24 8777.01 -1387.22 831.00 28 .00 24.86 20.89 30.00 9539.57 90.00 278.76 8996.10 -1524.29 615.93 28 .00 12.16 30.80 114.50 9664.57 90.00 293.76 8996.10 -1489.39 496.27 12 .00 0.00 12.00 90.00 9814.57 90.00 275.76 8996.10 -1451.34 351.82 12 .00 0.00 -12.00 270.00 9914.57 86.51 264.27 8999.15 -1451.31 252.05 12. 00 -3.49 -11.49 253.00 10014.57 90.07 275.74 9002.14 -1451.30 152.27 12. 00 3.55 11.47 73.00 10164.57 90.84 293.72 9000.94 -1413.32 7.80 12 .00 0.51 11.99 87.50 10414.57 90.73 323.72 8997.45 -1258.73 -185.01 12 .00 -0.04 12.00 90.00 10714.57 90.59 287.72 8993.89 -1086.46 -424.56 12 .00 -0.05 -12.00 270.00 10914.57 90.54 311.72 8991.90 -988.03 -596.97 12 .00 -0.03 12.00 90.00 11214.57 94.54 347.54 8978.16 -733.78 -746.12 12 .00 1.34 11.94 83.00 11364.57 90.05 330.09 8972.11 -594.62 -800.09 12 .00 -3.00 -11.63 256.00 11700.00 90.04 10.35 8971.86 -270.82 -855.91 12 .00 0.00 12.00 90.00 • by BP Alaska r Baker Hughes INTEQ Planning Report >~vTE Q Company: BP Amoco Date: 7/6/2007 Time: 15:26:32 Pase: 3 Fields Prudhoe Bay Co-ordinate(NE) Reference: We11: 05-10, True North Site: PB DS 05 Vertieal (TVD) Reference. 22:1 06/10/1994 00:00 62.3 We1L 05-10 Section (VS) Reference: Well (O.OON,O.QOE,330.OOAz~ Wellpatb: Plan 3, 05-10C Snrvey Caknlation Methods Minimum Curvature Db: oracle Survey MD Intl Azim SS TVb N/S FJVi' MapN MapE DLS VS ' TFO Tool tt deg. deg ft ft ft ft ft deg/100ft ft deg 9087. 04 32.70 151.20 8667.86 -1357.04 815.52 5947494.12 698110.37 0.00 -1582.99 0.00 MWD 9095. 00 32.75 150.97 8674.55 -1360.81 817.60 5947490.41 698112.55 1.68 -1587.29 291.81 MWD 9100. 00 33.20 150.97 8678.75 -1363.18 818.92 5947488.07 698113.93 9.00 -1590.01 0.00 MWD 9115. 00 34.55 150.97 8691.20 -1370.49 822.98 5947480.87 698118.18 9.00 -1598.37 0.00 MWD 9125. 00 37.00 153.30 8699.32 -1375.66 825.70 5947475.77 698121.04 28.00 -1604.21 30.00 MWD 9145. 00 42.01 157.24 8714.75 -1387.22 831.00 5947464.36 698126.64 28.00 -1616.87 28.11 MWD 9150. 00 41.44 159.16 8718.48 -1390.31 832.24 5947461.31 698127.95 28.00 -1620.16 114.50 MWD 9175. 00 39.14 169.39 8737.57 -1405.82 836.64 5947445.92 698132.76 28.00 -1635.79 113.06 MIND 9200. 00 37.81 180.45 8757.16 -1421.25 838.03 5947430.53 698134.56 28.00 -1649.86 105.25 MWD 9225. 00 37.56 191.91 8776.97 -1436.39 836.40 5947415.35 698133.32 28.00 -1662.15 96.58 MWD 9250. 00 38.41 203.21 8796.70 -1451.00 831.76 5947400.62 698129.07 28.00 -1672.48 87.50 MWD 9275. 00 40.29 213.85 8816.05 -1464.87 824.19 5947386.56 698121.86 28.00 -1680.71 78.58 MWD 9300. 00 43.07 223.53 8834.74 -1477.79 813.79 5947373.38 698111.81 28.00 -1686.70 70.34 MWD 9325. 00 46.57 232.14 8852.49 -1489.56 800.73 5947361.27 698099.06 28.00 -1690.36 63.10 MWD 9350. 00 50.64 239.73 8869.03 -1500.02 785.20 5947350.41 698083.81 28.00 -1691.65 56.99 MWD 9375. 00 55.16 246.45 8884.12 -1509.00 767.42 5947340.96 698066.27 28.00 -1690.54 51.96 MWD 9400. 00 60.00 252.44 8897.53 -1516.37 747.67 5947333.08 698046.73 28.00 -1687.05 47.90 MWD 9425. 00 65.09 257.86 8909.06 -1522.03 726.24 5947326.86 698025.45 28.00 -1681.24 44.68 MWD 9427. 25 65.55 258.33 8910.00 -1522.45 724.24 5947326.39 698023.46 28.00 -1680.60 42.18 05-10C 9434. 73 67.12 259.85 8913.00 -1523.75 717.52 5947324.92 698016.77 28.00 -1678.36 41.99 05-10C 9450. 00 70.35 262.85 8918.54 -1525.88 703.45 5947322.41 698002.77 28.00 -1673.18 41.38 MWD 9475. 00 75.75 267.51 8925.83 -1527.88 679.64 5947319.79 697979.02 28.00 -1663.00 40.29 MWD 9500. 00 81.23 271.96 8930.82 -1527.98 655.16 5947319.05 697954.55 28.00 -1650.85 38.93 MWD 9525. 00 86.76 276.27 8933.43 -1526.19 630.37 5947320.19 697929.73 28.00 -1636.91 38.04 MWD 9539. 57 90.00 278.76 8933.84 -1524.29 615.93 5947321.71 697915.24 28.00 -1628.04 37.59 MWD 9550. 00 90.00 280.01 8933.84 -1522.59 605.65 5947323.14 697904.92 12.00 -1621.42 90.00 MWD 9575. 00 90.00 283.01 8933.84 -1517.60 581.15 5947327.48 697880.30 12.00 -1604.86 90.00 MVVD 9600. 00 90.00 286.01 8933.84 -1511.34 556.95 5947333.11 697855.95 12.00 -1587.33 90.00 a MWD 9625. 00 90.00 289.01 8933.84 -1503.82 533.11 5947340.00 697831.92 12.00 -1568.90 90.00 MWD 9650. 00 90.00 292.01 8933.84 -1495.06 509.70 5947348.14 697808.29 12.00 -1549.61 90.00 MWD 9664. 57 90.00 293.76 8933.84 -1489.39 496.27 5947353.46 697794.72 12.00 -1537.99 90.00 MWD 9675. 00 90.00 292.51 8933.84 -1485.30 486.69 5947357.30 697785.03 12.00 -1529.65 270.00 MWD 9700. 00 90.00 289.51 8933.84 -1476.34 463.35 5947365.65 697761.47 12.00 -1510.22 270.00 MWD 9725. 00 90.00 286.51 8933.84 -1468.61 439.58 5947372.75 697737.50 12.00 -1491.64 270.00 MWD 9750. 00 90.00 283.51 8933.84 -1462.14 415.43 5947378.58 697713.20 12.00 -1473.97 270.00 MWD 9775. 00 90.00 280.51 8933.84 -1456.94 390.98 5947383.14 697688.62 12.00 -1457.24 270.00 MWD 9800. 00 90.00 277.51 8933.84 -1453.03 366.29 5947386.41 697663.84 12.00 -1441.50 270.00 MWD 9814. 57 90.00 275.76 8933.84 -1451.34 351.82 5947387.71 697649.32 12.00 -1432.81 270.00 MWD 9825. 00 89.63 274.56 8933.88 -1450.40 341.43 5947388.37 697638.92 12.00 -1426.80 253.00 MWD 9850. 00 88.76 271.69 8934.23 -1449.04 316.48 5947389.08 697613.94 12.00 -1413.14 253.00 MWD 9875. 00 87.89 268.82 8934.96 -1448.93 291.49 5947388.54 697588.96 12.00 -1400.56 253.04 MWD 9900. 00 87.02 265.95 8936.07 -1450.07 266.54 5947386.75 697564.05 12.00 -1389.07 253.13 MWD 9914. 57 86.51 264.27 8936.89 -1451.31 252.05 5947385.13 697549.59 12.00 -1382.90 253.26 MWD 9925. 00 86.88 265.47 8937.49 -1452.24 241.68 5947383.92 697539.25 12.00 -1378.52 73.00 MWD 9950. 00 87.77 268.34 8938.66 -1453.59 216.75 5947381.92 697514.36 12.00 -1367.22 72.93 MWD 9975 .00 88.66 271.20 8939.44 -1453.69 191.76 5947381.17 697489.39 12.00 -1354.82 72.80 MWD 10000 .00 89.55 274.07 8939.83 -1452.54 166.79 5947381.66 697464.40 12.00 -1341.34 72.71 MWD 10014 .57 90.07 275.74 8939.88 -1451.30 152.27 5947382.53 697449.86 12.00 -1333.00 72.66 MWD 10025 .00 90.12 276.99 8939.87 -1450.14 141.91 5947383.41 697439.47 12.00 -1326.82 87.50 MWD 10050 .00 90.25 279.98 8939.78 -1446.46 117.19 5947386.45 697414.66 12.00 -1311.26 87.50 MWD 10075 .00 90.38 282.98 8939.64 -1441.48 92.69 5947390.78 697390.04 12.00 -1294.70 87.51 MWD 10100 .00 90.51 285.98 8939.45 -1435.23 68.49 5947396.39 697365.69 12.00 -1277.19 87.53 MWD 10125 .00 90.64 288.98 8939.20 -1427.72 44.65 5847403.27 697341.66 12.00 -1258.77 87.55 MWD • • b BP Alaska ~t~r p Baker Hughes INTEQ Planning Report 1NTE Q Gompaoy: BP Amoco Date: .7/6/2007 Time: 15:26:32 Page: 4 Field: Prudhoe Bay Go-ordinate(NE) Reference: ` WeiC 05-10, True North Site: PB DS 05 Vertica l (TVD) Reference-. 22:1 06/10/1994 OO:OQ 82 .3 Well: 05-10 Section (VS) Refereunec Well (O.OON,O.OOE,330.OOAzi) Wellpath: Pla n 3, 05-10C Sarvey Caleulation Method: Minimum Curvature Dh: Orade Survey MD Ind Atim SS TVD N/S FJW MapN MapE I)LS VS TFO Tool -ft deg deg ft ft ft ft ft deg/100ft ft deg:. 10150. 00 90.77 291.97 8938.89 -1418.98 21.23 5947411.40 697318.02 12.00 -1239.49 87.58 MWD 10164. 57 90.84 293.72 8938.68 -1413.32 7.80 5947416.70 697304.45 12.00 -1227.88 87.62 MWD 10175. 00 90.84 294.97 8938.53 -1409.03 -1.69 5947420.75 697294.84 12.00 -1219.40 90.00 MWD 10200. 00 90.84 297.97 8938.17 -1397.88 -24.07 5947431.30 697272.19 12.00 -1198.57 90.02 MWD 10225. 00 90.83 300.97 8937.80 -1385.59 -45.83 5947443.02 697250.11 12.00 -1177.04 90.06 MWD 10250. 00 90.83 303.97 8937.44 -1372.17 -66.92 5947455.88 697228.68 12.00 -1154.87 90.11 MWD 10275. 00 90.82 306.97 8937.08 -1357.66 -87.27 5947469.85 697207.96 12.00 -1132.14 90.15 MWD 10300. 00 90.81 309.97 8936.73 -1342.11 -106.84 5947484.88 697187.99 12.00 -1108.88 90.19 MWD 10325. 00 90.79 312.97 8936.38 -1325.56 -125.57 5947500.93 697168.83 12.00 -1085.18 90.23 MWD 10350. 00 90.78 315.97 8936.04 -1308.05 -143.40 5947517.97 697150.55 12.00 -1061.10 90.28 MWD 10375. 00 90.76 318.97 8935.70 -1289.63 -160.30 5947535.94 697133.18 12.00 -1036.70 90.32 MWD 10400. 00 90.74 321.97 8935.38 -1270.35 -176.21 5947554.80 697116.77 12.00 -1012.05 90.36 MWD 10414. 57 90.73 323.72 8935.19 -1258.73 -185.01 5947566.18 697107.67 12.00 -997.59 90.40 MWD 10425. 00 90.73 322.47 8935.06 -1250.40 -191.27 5947574.35 697101.19 12.00 -987.24 270.00 MWD 10450. 00 90.72 319.47 8934.74 -1230.98 -207.01 5947593.34 697084.95 12.00 -962.56 269.98 MWD 10475. 00 90.72 316.47 8934.43 -1212.41 -223.74 5947611.46 697067.74 12.00 -938.11 269.95 MWD 10500. 00 90.71 313.47 8934.11 -1194.75 -241.42 5947628.66 697049.60 12.00 -913.97 269.91 MWD 10525. 00 90.71 310.47 8933.80 -1178.03 -260.01 5947644.88 697030.58 12.00 -890.20 269.87 MWD 10550. 00 90.70 307.47 8933.50 -1162.31 -279.44 5947660.08 697010.75 12.00 -866.87 269.83 MWD 10575. 00 90.69 304.47 8933.20 -1147.63 -299.67 5947674.23 696990.14 12.00 -844.04 269.80 MWD 10600. 00 90.67 301.47 8932.90 -1134.03 -320.64 5947687.28 696968.82 12.00 -821.78 269.76 MWD 10625. 00 90.66 298.47 8932.61 -1121.54 -342.29 5947699.19 696946.85 12.00 -800.14 269.72 MWD 10650. 00 90.64 295.47 8932.33 -1110.21 -364.57 5947709.94 696924.28 12.00 -779.18 269.69 MWD 10675. 00 90.62 292.47 8932.05 -1100.05 -387.41 5947719.49 696901.19 12.00 -758.97 269.66 MWD 10700. 00 90.60 289.47 8931.78 -1091.11 -410.75 5947727.82 696877.62 12.00 -739.55 269.62 MWD 10714. 57 90.59 287.72 8931.63 -1086.46 -424.56 5947732.11 696863.69 12.00 -728.62 269.59 MWD 10725. 00 90.59 288.97 8931.53 -1083.18 -434.46 5947735.13 696853.72 12.00 -720.83 90.00 MWD 10750. 00 90.59 291.97 8931.27 -1074.44 -457.87 5947743.25 696830.08 12.00 -701.55 90.01 MWD 10775. 00 90.58 294.97 8931.02 -1064.48 -480.80 5947752.60 696806.90 12.00 -681.47 90.04 MWD 10800. 00 90.58 297.97 8930.76 -1053.34 -503.18 5947763.15 696784.24 12.00 -660.63 90.07 MWD 10825. 00 90.57 300.97 8930.51 -1041.04 -524.94 5947774.88 696762.17 12.00 -639.10 90.10 MWD 10850. 00 90.56 303.97 8930.26 -1027.62 -546.03 5947787.74 696740.74 12.00 -616.93 90.13 MWD 10875. 00 90.55 306.97 8930.02 -1013.11 -566.38 5947801.71 696720.01 12.00 -594.19 90.16 MWD 10900. 00 90.54 309.97 8929.78 -997.56 -585.95 5947816.74 696700.04 12.00 -570.94 90.19 MWD 10914. 57 90.54 311.72 8929.64 -988.03 -596.97 5947825.98 696688.77 12.00 -557.17 90.22 MWD 10925. 00 90.69 312.96 8929.53 -981.01 -604.68 5947832.79 696680.88 12.00 -547.24 83.00 MWD 10950. 00 91.05 315.94 8929.15 -963.51 -622.52 5947849.82 696662.59 12.00 -523.16 83.01 MWD 10975 .00 91.41 318.92 8928.61 -945.10 -639.43 5947867.78 696645.21 12.00 -498.77 83.06 MWD 11000 .00 91.77 321.90 8927.92 -925.84 -655.35 5947886.61 696628.79 12.00 -474.13 83.12 MWD 11025 .00 92.12 .324.88 8927.07 -905.79 -670.25 5947906.27 696613.37 12.00 -449.31 83.21 MWD 11050 .00 92.47 327.86 8926.07 -884.99 -684.08 5947926.69 696599.00 12.00 -424.39 83.31 MWD 11075 .00 92.81 330.85 8924.91 -863.51 -696.81 5947947.83 696585.71 12.00 -399.42 83.43 MWD 11100 .00 93.14 333.83 8923.62 -841.40 -708.40 5947969.63 696573.55 12.00 -374.47 83.56 MWD 11125 .00 93.47 336.82 8922.17 -818.72 -718.82 5947992.03 696562.54 12.00 -349.63 83.72 MWD 11150 .00 93.78 339.81 8920.59 -795.54 -728.03 5948014.96 696552.72 12.00 -324.94 83.89 MWD 11175 .00 94.08 342.80 8918.88 -771.92 -736.03 5948038.36 696544.11 12.00 -300.49 84.08 MWD 11200 .00 94.38 345.80 8917.03 -747.92 -742.77 5948062.17 696536.74 12.00 -276.33 84.29 MWD 11214 .57 94.54 347.54 8915.90 -733.78 -746.12 5948076.22 696533.02 12.00 -262.41 84.51 MWD 11225 .00 94.24 346.32 8915.10 -723.66 -748.47 5948086.28 696530.41 12.00 -252.47 256.00 MWD 11250 .00 93.50 343.41 8913.41 -699.58 -754.99 5948110.17 696523.27 12.00 -228.36 255.91 MWD 11275 .00 92.76 340.50 8912.05 -675.85 -762.72 5948133.69 696514.92 12.00 -203.94 255.71 MWD 11300 .00 92.01 337.59 8911.01 -652.52 -771.65 5948156.77 696505.38 12.00 -179.28 255.55 MWD • • by BP Alaska sA ~r Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 7/6/2007 Time:. 15:26:32 Pace: 5 Field: Prudhoe :Bay. Co-ordioate(NE) Reference: Well: 05-10, Truta North Site: Pl3 DS 05 Vertical (1'VD) Reference: 22:1 0 6/10/1994 00:00 62.3 Well: 05-10 Section (VS) lietereoce: Well (O.OON,O.OOE,330.OllAzi) Wellpath: Plan 3, 05-10C Survey Calculation Method: Minimum Curvattue Db: Orade Survey MD Iacl Azim SS TVD N/S E/VV MapN MepE DLS VS TFO Tool ft deg deg ft ft ft ft ft degN00ft ft deg 11325.00 91.25 334.69 8910.30 -629.67 -781.76 5948179.35 696494.67 12.00 -154.43 255.43 MWD 11350.00 90.49 331.79 8909.92 -607.36 -793.01 5948201.37 696482.84 12.00 -129.48 255.35 MVVD 11364.57 90.05 330.09 8909.85 -594.62 -800.09 5948213.91 696475.43 12.00 -114.91 255.30 MWD 11375.00 90.05 331.35 8909.84 -585.52 -805.19 5948222.87 696470.09 12.00 -104.48 90.00 MWD 11400.00 90.05 334.35 8909.82 -563.28 -816.60 5948244.80 696458.11 12.00 -79.52 90.00 MWD 11425.00 90.05 337.35 8909.80 -540.47 -826.83 5948267.34 696447.28 12.00 -54.65 90.00 MWD 11450.00 90.05 340.35 8909.78 -517.16 -835.85 5948290.40 696437.66 12.00 -29.95 90.01 MWD 11475.00 90.05 343.35 8909.76 -493.41 -843.64 5948313.94 696429.25 12.00 -5.49 90.01 MWD 11500.00 90.04 346.35 8909.74 -469.28 -850.17 5948337.89 696422.08 12.00 18.68 90.01 MWD 11525.00 90.04 349.35 8909.72 -444.84 -855.44 5948362.18 696416.18 12.00 42.47 90.01 MWD 11550.00 90.04 352.35 8909.70 -420.16 -859.41 5948386.74 696411.56 12.00 65.83 90.02 MWD 11575.00 90.04 355.35 8909.68 -395.31 -862.09 5948411.52 696408.23 12.00 88.70 90.02 MWD 11600.00 90.04 358.35 8909.67 -370.35 -863.47 5948436.43 696406.20 12.00 111.00 90.02 MWD 11625.00 90.04 1.35 8909.65 -345.36 -863.54 5948461.41 696405.48 12.00 132.68 90.02 MWD 11650.00 90.04 4.35 8909.63 -320.39 -862.30 5948486.40 696406.06 12.00 153.68 90.02 MWD 11675.00 90.04 7.35 8909.62 -295.52 -859.75 5948511.33 696407.96 12.00 173.95 90.03 MWD 11700.00 90.04 10.35 8909.60 -270.82 -855.91 5948536.12 696411.15 12.00 193.41 90.03 2 7/8" • • a ~:t1117F11ktt~ rlc 14~ iE 1,1 ~ F~; I l II ~ rte n; ,}4~;llk ~~k ~t:,~ ~ 'r'iI_I IiIG ~lh` lfri jt~i j~tt~ ~ ~~ I {~ ii 1{1~~iiEt likl III ~a~ii i i~ 1 I~ f±~1 :° R a i~ !~ .{ _ ~ ~ : o~ ~~~~~ $ ~~ ~ { ~ ~! `-" ~ o ~ - ~~ ~ ~~ ~ ~~ ~ ~ ¢~ ~ ! : j ;~ ~ $-- `~,:. ,i i~ ~~, Iil Il~llllll ~ ~ T ~• t {i t I f. ~ -: k lid fr'~ ~Ill~llilJi ~ ~ ~S I 1 o i i C t:~ll... 8 M ~ a38~~ 4 3 ~ 00~~~6 ~ ~___`"9 $~~o'~G a 4 ~~ ~. ,/ ~~ ~ ~ q ~ ~ ~ / 4 S~/ ~ :.I~1 Ili e ~/ -~~~ ' ~~ Q 9 ~ i ~ f ,. ~~~ ~~ ~ I ~1 r`~8 t ~a iilk~,~ji ~~€~~g$vs~ ~ ~ f I ~ 1~ a= Asc^-~ C ~1{l I : I ! tgii7=s•7:ass~a ~ a ~ x39$Ro II~ I .. q ' ~SijC'~~~~A:AS" 573 R o I ~~____~__?______ 8888888p8p88yy - - '' st A ]~] ..i~i.ii S8@~B Y ~ ~€ n ~:qt::ea:c:aai: I q~ e o~ . ''dd::::"'::d: ~ i ~" ~ r x $ ~ g ~ ~:ixj~;t=#~{a e'a"_~~r~ ~~ llt: kt~c R1~ ~ Ra a ~ ~ ~ ~• i ~Ss~ssg~ss~ss ~}~* j +f• ~`T a C ° 7 A ]77699""~iC~ '~ M i ~ ]~ ~"A"'A_ 1 4 Y.1 ~~ ~~ $ $ p 3. i~F tt'atitFF79~I Ef~ R AC AF :A•C^CF7i: d C ~! • ~'1~aaaaiaaiiaa=e !~ ~~~iii;ice6~f islstt:sse~ii8~~ ' ~dvwsl aaw w•w•~ •w ~~vs by BP Alaska Anticollision Report ~~r s 11YTEQ Company: BP Amoco Date: 7/6/2007. Time: 15:30;41. Pager.. 1 Field; Prudhoe Bay Reference Site: PB DS D5 Co-ordinate(NE) Reference: Well: 05-10, True North Reference Weil 05-10 Vertical (TVD) Reference: 22 ; 10 6/10/1894 00: 0062.3 Reference.Welipath: Plan 3, 05-10C Db: Oradtt GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference - There are'Ri~aells in this8fehiiipal Plan & PLANNED PROGRAM Interpolation Method : MD Interval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 9087.04 to 11700.00 ft Scan Method: Trav Cylinder North Maximam Radius: 2500.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 7/6/2007 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 625.26 7638.26 1 : Camera based mag multi sho CB-MAG-MS Camera based mag multi shot 7700.04 9087.04 MWD (7700.04-10416.00) (2) MWD MWD - Standard 9087.04 11700.00 Planned: Plan #3 V3 MWD MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 11700.00 8971.86 2.875 4.125 2 7/8" Summary ~-- -Offset Wellpath -- ----> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Wareing ft ft ft ft ft PB DS 05 05-04 05-04 V1 11113.19 9300.00 1211.09 197.64 1013.45 Pass: Major Risk PB DS 05 05-04A 05-04A V5 10990.38 10500.00 573.56 275.29 298.27 Pass: Major Risk PB DS 05 05-10 05-10 V1 9096.41 9100.00 111.26 250.89 -139.63 FAIL: Major Risk PB DS 05 05-10 05-10A VO 9197.71 9200.00 11.94 224.50 -212.56 FAIL: Major Risk PB DS 05 05-10 05-106 VO 9197.71 9200.00 11.94 225.02 -213.08 FAIL: Major Risk PB DS 05 05-10 05-106P61 VO 9197.71 9200.00 11.94 224.47 -212.53 FAIL: Major Risk PB DS 05 05-12 05-12 V4 Out of range PB DS 05 05-12 05-12A V1 Out of range PB OS 05 05-12 05-126 V5 Out of range PB DS 05 05-17 05-17 V1 Out of range PB DS 05 05-17A 05-17A V1 Out of range PB DS 05 05-176 05-176 V5 9793.94 10200.00 706.39 148.63 557.77 Pass: Major Risk PB DS 05 05-20 05-20 V7 10022.47 9300.00 150.02 110.45 39.57 Pass: Major Risk PB DS 05 05-20 05-20A V1 10022.45 9300.00 150.06 109.87 40.19 Pass: Major Risk PB DS 05 05-20 05-20B V4 9940.64 9100.00 480.72 112.76 367.97 Pass: Major Risk PB DS 05 05-20 05-20PB1 V3 10022.47 9300.00 150.02 110.45 39.57 Pass: Major Risk PB DS 05 05-21 05-21 V1 9145.00 8800.00 732.02 157.75 574.27 Pass: Major Risk PB DS 05 05-21A 05-21A V3 9145.00 8800.00 732.02 157.75 574.27 Pass: Major Risk PB D5 05 05-22 05-22 V3 10936.94 9200.00 390.98 131.56 259.42 Pass: Major Risk PB DS 05 05-22 05-22A V10 10936.94 9200.00 390.98 131.40 259.58 Pass: Major Risk PB DS 05 05-25 05-25 V2 11561.05 8800.00 1721.33 150.67 1570.66 Pass: Major Risk PB DS 05 05-25 05-25A V1 11561.05 8800.00 1721.33 150.67 1570.66 Pass: Major Risk PB DS 05 05-25 05-25B V4 11561.05 8800.00 1721.33 150.67 1570.66 Pass: Major Risk PB DS 05 05-34 05-34 V1 Out of range PB DS 05 05-39 05-39 V3 9117.04 9300.00 946.38 157.55 788.83 Pass: Major Risk PB DS 05 05-39P61 05-39PB1 V1 9116.92 9300.00 946.37 157.72 788.65 Pass: Major Risk Site: PB DS 0 5 Well: 05-04 Rule Assigned: Major Risk Wellpath: 05-04 V7 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casia~/IfSflistance Area Deviation Warning ft ft ff ft ft ft deg deg in ft ft it 11035.65 8988.92 7000.00 6514.11 33.57 20.24 321.85 355.70 2483.76 103.97 2379.79 Pass 11046.66 8988.47 7100.00 6601.32 33.53 19.49 321.93 354.47 2400.46 105.55 2294.92 Pass 11054.79 8988.12 7200.00 6688.74 33.48 19.03 321.58 353.14 2318.21 107.21 2211.00 Pass 11061.13 8987.83 7300.00 6776.01 33.44 18.77 320.89 351.70 2237.58 109.08 2128.50 Pass 11066.66 8987.57 7400.00 6863.37 33.41 18.65 320.00 350.15 2158.40 111.23 2047.17 Pass 11071.40 8987.35 7500.00 6951.04 33.38 18.61 318.90 348.49 2080.55 113.63 1966.92 Pass 11075.14 8987.17 7600.00 7038.89 33.36 18.65 317.54 346.69 2004.43 116.29 1888.14 Pass 11078.83 8986.98 7700.00 7126.91 33.33 18.73 316.08 344.77 1930.16 119.31 1810.85 Pass r • are L of bag BAG Dowell of bag Blind/Shears TOTs 2 3/8" combi ram/slips Mud Cross I I Mud Cross cross variable bore pipe 3 1/2"-2 718" TOTs 2 3/8" combi ram/slips Swab Valve Flow Tee Alaska Department of Natural Resources Land Administration Syste~ Page 1 of 2 ~~ ~ ~s!<.~ ~.1a~:-;~~ -: ~: ~ ~ .. °: ~~=r_-,, ~ ? ~-~~or~de€'s Search State Cabins ~~u~l ~ '~rD41C€s~S Alaska DNR Case Summary File Type ADL..__.. File Number: _ ?8326 ~ printable Case File_Summary. See Township, Range, Section and Acreage? ~' Yes ~" No New. Search J LA8 Menu ~ Case Abstract i Case Detail ~ Land Abstract ._ bile: ADL 28326 ~"-'~ Search for Status Plat Updates ~s cif 0711 S%2007 Customer: 400107377 I3P EXPLORATION (ALASf~A 1 1VC PO BOX 1 966 1 2/900 E. BENSOh1 BL ATTN: LAND MANAGER- . ALASKA ANCHORAGE AK 995196612. Case Type:.78~ OIL & GAS LEASE COMP File Location: DOG DIV OIL AND GAS Case Stales: 35 ISS/APPRV/ACTV AUTH Total Acres: 2491.000 Office of Primary Responsibility: DOG L Last Transaction Date: 12/04/2006 DNR Unit: 780 OIL AND GAS Status Date: 09/14/1965 Dute b~itiated_~ 0512811965 )IV OIL AND GAS CaseSttbtvUe: 3~5 NORMI SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED ;t~Ierir~icrrl: l1 Townshi~~: OLIN Range: 015E Sccrron: 29 Section,lcres: 6=10 Plats l~el'I(/lU/!: ~ ~ ~Ul~'i1.S'{!1/): ~)~ ~ ~+~ /~CIi],LrL': O ~ J i; :~~CC'llUll: ?~) ,~~NCIIOTY _`{Cr('S': x)0=1 Me'IYC/lUI7.~ t ~ ~ UlGi1.S{71~): ~ ~ ~ N J~all CSC: ~)~ J L ,~~C'CIIU71: ~ ~ .~~NC"//UI7 : ~CrB~: 6n 1 1~E/7C/lCli7: 1~ lOlt~/]~/11~~: ~)~ IN l~U]l,~E: ~)~~i. .ti~L'Cl/1)17.' >2 ~~['Cl(07J~1Crt'.S"; 6~~) Leal Description OS-28-1965 ~` ~` *SALE NOTICE LEUAL DESCRIPTION* C14-156 TIIN-RISE-UM29,30,31,32 2491.00 U- 3- 7 End ~ Case Summary Last updated on 07118/2007. Search http://www.dnr.state. ak.us/las/Case_Summary. cfm?FileType=ADL&FileNumber=28326&... 7/18/2007 Terrie L. Hubble gp Exploration AK Inc. pp Box ~ e6AK 995196 Anchorag , ^Mastercard Check" PAY 70 THE ~Xr -~" '~` D DER OF First.Nationat Be 99501 ka Anchorage~~AK nnFMO "~ • as-s~~zs2 346 DATE $ ~~ ~'L25200060~:99L46227L556~~' 0346 • • TRANSMITTAL LETTER CHECKLIST WELL NAME P ~~ Q~ PTD# ~ ©~' ~~.~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) 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 Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well 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. SCompany Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 • ^^ ~ y , , o, o d ~ , , y N a~ ~ ` , o ~ ~ ~ ~ , , c ~ ~ ~ ~ , ~, Q ~ ~ , , O 3; ~, ` ' ' m O w ~ U: _, m f6 ~ ~ ~ ~ ~ O- O d y~ ~ ~' ~ , , ~ Q: ~ , ~ ~~ , to ~ ~ Q' c c, c • o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ . ~ c, ~ ~~ . ~ m U ~ . L. ~, ~ a~, N. ~ ~ , a ' O ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ p. O, O. Q~ ~ ~ ~ ~, ~ ~, ~ ~ ~ ~ ~ N. d ~ ~ ~ ~ ~ ~ ~; ~ ~ ~ ~ ~~ 4Y N, m ~ L' ~ y. ~~ N, ~ 'O 0, N Q ~ a. ~ O, ~ ~ ~ ~p as ~, ~, ~ ~ a, Q ~ O, ~ N. ~ U, ~ ~ Q ~ ~ ~, E N Z ~ ~ ~ ~ ~ ~ ~ i 7 ~ U ~ Y M i ~~ ~ : ~ ~ ~ : , U. ~ ~ . ~, p~ ~, ~ 4., ~ ,ul: ~ ~ ~ z ~ ~ ~ ~ ~ ~ f6. ~ ~ ~ ~ O, >, ~~ O. ~ ~ O ~ O, ~~ f0~ Q. ~ ^ N' ~ ~ ~ ~ gyp, O D ~ ~ ~ ~ :) ~ ~ ~ ~, tq, ~ ' N~ ~ ' N: y~ W~ ~ ~ ~ ' ' y~ ~ ' N: W~ ~ ~, ~ VA M: N, ~ ~ ~ W: ~ V1 ~ Q'Q' Q' Q; Q; Q; a; Q' ' N~ ~, N~ ~, W ~ ' y~ y: W~ N~ W~ N~ ~ ~ Q' ~ ~, ~, ~, ~ ~ ~ N~ W~ ~ ~ Q; ' ' o ~ Q' ~ N~ ~' Q ~,, ~ t d ; ~ ~ }; ~ } ~' , >' , ~" ~~ ~; ~; ~; ~ z; z; z~ Z Z Z Z Z ~ ~ ~ ~ ~" ~' ~' z ~ ~ ~" r Z z z z >- ~ ~` 1~ R U w. co' I , - E, ~ o , , S as : O. o, ~ T - O ~ ~, ~, o a -o ~ O. ~; rv w ~ Z' ~ i o Z, s, D. m: ~ ~ o m ~ _ ~ ~ ~, ~ ~ ~ ~ `, ~. ~ `t N O O~ ~, ~ N,~ N ~.' ~ ~ O~ 3~ •C ~ O, -', ~ `O. N ~ M ~ ~ V. N, O N. fl: C O, _ ~ p: ~ ~, ~~ 'O. N. ~ N. m ~ ~, t~ O ~ U, Z~ ~ T 3 ~ O ~ ~ O °~ M ~ o • C~ y ~ ~ ~ w z w _ . -p. o' ~ c, v' ~, ar N, .c, 0 v , ~~ 0, N, p, c, rn ~, v c, L, ar ~ m. , ~, ~ ~ : ~ ~ O. o, rn ar N a, ~~ ~ Q' t. c' N~ ~ N~ d~ N~ N OS c O ' O Q Z ~ ~ ~ ~ • ~~ , ~ N, ~ ~ ~ ~ : • V' ~ ., N Y ~ ( 7 ~ O N ~ ,~ ' O ,~ O C U~ O U ~ C ~ f0~ N ~ ~ N O~ O~ Q~ ~ 3 O ~ C "O V' . •d ~~ Q ~ U C' _~ ~ ~ O, ~, d.. ~~ . ~ O• ~ ~, 3, ~ ~ ~~ > N y, ~ N' ~' Y O N 'y , • ; r.+ C a ° ' ~ ~ ~ _ q m 4 -- 3 .m Q ~ ' m. ' ~ m' c, -o~ ~ m ~ n' `~' m. d ~ o' ai w' d w v m. ~ ~ ~, a. E~ ~ ~ ~, , a~: ~~ ~ ~~, ~ c m' a~ ui ~ , •_ a~ a, w M ~: ~~ ~ ~, ° o~ a a 3, O. ,~, o ~ ° . o >r o w o z Q ~ ~ ~, ?, ~ o: v' ~, 3, • 3, a~ ~: ~: ..: a ~ ~ 3 3 ~ o a o ai 4 ~ ~ o, i 3 ~ L, a~ o U o O o, c~ ~ v ~, > o, m m v a; v • ~ ~, o: ~' o Y o o ~ u o `* N, -°a a~, ~~ o rn c i a a ~n ~ m d ~ ~ d : ~ O ~, ~, c o: ~ ~ d c: ~: o U n. o' ~, ~ ° m' ~, m o' ~ w U' ~, ~ ' 3, c' a m o ~ t~ ~ d (6, , ~ d O, E, d O, ~ ~, ~ ~~ d y. rq, ~ 4 h~ Ul, d m ~ ~~ ~ N. M, c: ^: ~ d 01 f0 f6 - (O f0 ~ m. ~ ~~ C. U. f6' O 01 >, ~ ~~ N. ~ 2, ~ N. N, O' N~ c, L, o, d • , ~ ~ O ;a ~ ~, ~, d d ~ N, x y: o m. a~ 3. ~, v m ~' c v Q a~ c, ~ ~, ~ ~~ a ~: ~ o. ~ a o I o v ~ ~ . >, o~, ii ~ m, ~, -, a, a, v. v. ~ c' m. n, c ~~ c -Q a. w~ ;n' 'y' a~~ a~~ >, .m ~~ s, ~ ~ ~~ ~ o. ~, ~ ~~ c, a~ ~, ~, ~, c o t, ro E w' m. o ~ ~ v' m o o. , c c: m N , ~ c> c ~"" w to ~: ~: c m, m 3' v v a~, o' o' m. v o' N ~' ~, ~ `o' `o' ~' o ~ m v ui ~~ >~ o o ~ ~ ~, ~ _ - : -a a?, '' •- , ~, ~, a ~, ' ~~ - c ~ 3 ~ ~ U. ~~ ° ~' a J m ~ ~ ~ o ~, , o 3 3 ~, ~, ~' w w ~ ~ a Y ~, Q ~, N, m ui Y ~, ~ . ~, ~, ' ~ ~, v a a ~ ' ~ ' ~ ~ . ~ o' ' ' ' o; ~' ~' ~', ' ' ~; m o co ~ 'v' = O O _, ' ~ `o ' ' :°, o' c, . v ' m ~ ~ a ~~;~ , ~; cn_ OO;a a U z ,Q;a ~ Ucn U U, 0 0 0, 4 Q,_ o;m mU ~; ~? ~ a , iviU w a O N M V to GO I~ p O O N M ~ ~ O n W O O N M d' to O n p O O N M V to CO I~ N O ~- N N N N N N N N N N M M M M M M M M M M U _ _ _ r C C '4' O N O Y N O •O'' N ~ U C ~~ y O ~ ~ D O S o N a o ~ ~ •`c ~ ~ °~ ~ N !~ ~ ~ ~ C9 E U W 0 ~ Q Q c Q W * °~ Q Q a Q w t7 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 ibis category of information. **** REEL HEADER **** MWD 09/01/27 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 08/10/02 1585159 O1 3" CTK *** LIS COMMENT RECORD *** tapescan.txt ~~~`~~~~:~=' FHB ~~ ~~~` !!!!!!!!!!!!!!!!!!! Remark File version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: ldwg.las version Information VERS. 1.20: OWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame well Information Block #MNEM.UNIT Data Type Information STRT.FT 7059.0000: Starting Depth STOP.FT 11685.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: 05-lOC FLD FIELD: Prudhoe Bay Unit LOC LOCATION: 70 deg 15' 51.713"N 148 deg 24' 18.109"w CNTY. COUNTY: North slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 02 OCt 2007 API API NUMBER: 500292026303 Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 32 TOWN.N T11N RANG. R15E PDAT. MSL EPD .F 0 . LMF DF FAPD.F 62.26 . DMF DF EKB .F 0 . EDF .F 62.26 EGL .F 0 . Page 1 Description Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level ~ ~ feet tapescan.txt CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to lob this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating sub, a Drilling Performance sub (Inner and outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a PDC (Primary Depth control) lob provided by Schlumberger GR CNL dated 04 Oct 2007 per Priya Maras with BP Exploration (Alaska), Inc. (8) The sidetrack was drilled from 05-10A through a milled window in a 4 1/2 and 7 inch liner. Top of window 9050 ft.MD (8636.7 ft.TVDSS) Bottom of window 9026 ft.MD (8647.2 ft.TVDSS) (9) Tied to 05-10 at 7061 feet MD (6861 feet TvDSS) and 7744 feet MD (7481 CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 7387.82, 7385.96, ! -1.86572 7405.44, 7404.82, ! -0.62207 7424.25, 7424.04, ! -0.207031 7430.05, 7429.64, ! -0.415039 7445.03, 7445.03, ! 0 7454.51, 7455.96, ! 1.45117 7457.21, 7459.28, ! 2.07275 7461.3, 7461.92, ! 0.621582 7473.1, 7474.76, ! 1.6582 7476.42, 7480.36, ! 3.93896 7483.05, 7486.16, ! 3.10938 7522.23, 7525.34, ! 3.10938 7546.11, 7550.47, ! 4.35352 7553.78, 7557.72, ! 3.93896 7575.76, 7582.6, ! 6.84082 7581.97, 7587.98, ! 6.01172 7600.42, 7606.22, ! 5.8042 7606.22, 7611.4, ! 5.18262 7634.61, 7644.35, ! 9.74316 7640.42, 7648.09, ! 7.66992 7661.15, 7667.78, ! 6.63379 7664.46, 7671.1, ! 6.6333 7691.09, 7693.58, ! 2.48779 7703.32, 7712.02, ! 8.70654 7719.49, 7723.63, ! 4.146 7722.39, 7728.4, ! 6.01172 7724.46, 7730.89, ! 6.42627 7741.46, 7749.13, ! 7.66992 8759.13, 8762.86, ! 3.73145 8764.52, 8768.04, ! 3.52344 8770.74, 8774.47, ! 3.73145 8773.85, 8778.2, ! 4.35352 Page 2 GRAX -> Gamma Ray [MWD] (MWD-API units) ROPJ4VG -> Rate of Penetration, feet/hour TvDSS -> True vertical Depth (subsea) TvDSS). (10) The interval from 11658 feet to 11685 feet MD was not logged due to sensor to bit offset at well TD. MNEMONICS: 8776.33, 8780.69, 8778.82, 8783.17, 8785.25, 8789.6, 8792.09, 8796.23, 9057.61, 9058.65, 9061.55, 9062.8, 9064.25, 9065.08, 9067.15, 9068.39, 9075.23, 9076.68, 9078.14, 9079.59, 9095.34, 9095.96, 9109.44, 9108.82, 9112.96, 9111.72, 9135.86, 9139.17, 9146.22, 9149.54, 9160.94, 9163.22, 9163.63, 9165.71, 9167.36, 9168.61, 9168.4, 9170.89, 9171.72, 9173.58, 9173.83, 9175.91, 9176.32, 9177.98, 9180.47, 9182.95, 9187.51, 9190.42, 9190, 9192.49, 9198.92, 9200.78, 9200.37, 9201.82, 9203.06, 9205.34, 9206.58, 9209.07, 9218.24, 9220.52, 9224.45, 9225.28, 9229.43, 9231.92, 9239.59, 9240.42, 9249.33, 9250.78, 9274.5, 9275.13, 9279.69, 9281.55, 9285.08, 9286.32, 9288.19, 9289.22, 9292.95, 9294.4, 9301.45, 9302.28, 9303.32, 9305.39, 9308.5, 9310.78, 9315.76, 9318.66, 9319.28, 9322.39, 9329.23, 9330.06, 9342.49, 9344.15, 9345.18, 9346.22, 9349.95, 9351.4, 9364.46, 9366.33, 9386.11, 9387.77, 9390.05, 9391.71, 9395.86, 9397.72, 9403.94, 9405.39, 9413.48, 9412.65, 9422.39, 9420.73, 9425.29, 9424.46, 9429.64, 9430.68, 9437.73, 9439.39, 9447.1, 9448.34, 9457.88, 9459.12, 9463.68, 9464.1, 9468.04, 9469.69, 9473.22, 9472.6, tapescan.txt ! 4.35352 ! 4.35254 ! 4.35352 ! 4.14551 ! 1.03711 ! 1.24414 ! 0.829102 ! 1.24316 ! 1.45117 ! 1.45117 ! 0.621094 ! -0.62207 ! -1.24414 ! 3.31641 ! 3.31641 ! 2.28027 ! 2.07324 ! 1.24414 ! 2.4873 ! 1.86621 ! 2.07324 ! 1.6582 ! 2.4873 ! 2.90234 2.4873 ! 1.86621 ! 1.45117 ! 2.28027 ! 2.48828 ! 2.28027 ! 0.829102 ! 2.4873 ! 0.829102 ! 1.45117 ! 0.62207 ! 1.86523 ! 1.24414 ! 1.03613 ! 1.45117 ! 0.830078 ! 2.07324 ! 2.28027 ! 2.90234 ! 3.10938 ! 0.829102 ! 1.6582 ! 1.03711 ! 1.4502 ! 1.86523 ! 1.65918 ! 1.6582 ! 1.86621 ! 1.45117 ! -0.829102 ! -1.6582 ! -0.829102 ! 1.03711 ! 1.6582 ! 1.24316 ! 1.24414 ! 0.415039 ! 1.6582 -0.62207 Page 3 9481.1, 9481.92, 9488.97, 9489.18, 9497.2, 9498.65, 9504.04, 9504.25, 9506.11, 9506.32, 9520.42, 9522.07, 9528.29, 9527.67, 9540.73, 9542.39, 9551.51, 9554, 9571.77, 9570.32, 9586.58, 9584.72, 9606.43, 9607.88, 9617.83, 9619.9, 9630.89, 9633.58, 9653.06, 9653.27, 9672.34, 9671.3, 9674.83, 9675.24, 9688.96, 9688.34, 9703.48, 9702.65, 9708.04, 9707.41, 9814.77, 9813.32, 9822.44, 9819.95, 9835.5, 9835.08, 9844.71, 9846.78, 9857.15, 9858.39, 9865.65, 9863.78, 9878.92, 9875.81, 9887, 9884.51, 9901.51, 9899.23, 9904.87, 9904.45, 9916.27, 9915.23, 9919.17, 9917.93, 9934.3, 9933.06, 9941.56, 9938.66, 9951.1, 9952.55, 9955.86, 9957.73, 9966.02, 9968.3, 10008.6, 10009.2, 10023.7, 10022.6, 10026.6, 10026.2, 10032.2, 10032, 10033.8, 10034.9, 10037.4, 10038, 10043, 10043.8, 10045.2, 10046.9, 10121.1, 10118.7, 10135.2, 10133.2, 10152.4, 10147.3, 10165.8, 10164.7, 10201.3, 10202.7, 10224.9, 10224.5, 10261.7, 10260.6, 10281.8, 10281.4, 10291.3, 10291.3, 10303.1, 10300.6, 10316.3, 10317.1, 10380.7, 10382.5, 10390.4, 10391.5, 10408.7, 10408.5, 10440.5, 10440.7, 10446.5, 10447.1, 10461, 10459.3, 10464.3, 10463.7, tapescan.txt 0.829102 0.207031 1.45117 0.207031 0.208008 1.6582 -0.621094 1.6582 2.4873 -1.45117 -1.86523 1.45117 2.07324 2.69531 0.207031 -1.03613 0.415039 -0.62207 -0.829102 -0.62207 -1.45117 -2.4873 -0.415039 2.07324 1.24316 -1.86621 -3.10938 -2.4873 -2.28027 -0.415039 -1.03711 -1.24316 -1.24316 -2.90234 1.45117 1.86621 2.28027 0.621094 -1.03613 -0.414062 -0.208008 1.03613 0.62207 0.829102 1.6582 -2.4873 -2.07227 -5.18262 -1.03613 1.45117 -0.414062 -1.03711 -0.414062 -2.4873 0.829102 1.86523 1.03711 -0.207031 0.207031 0.62207 1.6582 -0.62207 Page 4 • tapescan.txt 10471.7, 10473, ! 1.24316 10475.4, 10476.5, ! 1.03613 10481.2, 10482.3, ! 1.03711 10492, 1 0492, ! 0 10495.5, 10496, ! 0.414062 10502.6, 10503.4, ! 0.829102 10511.1, 10510.5, ! -0.62207 10514.8, 10513.8, ! -1.03613 10563.2, 10561.8, ! -1.45117 10597.5, 10594.4, ! -3.10938 10619.5, 10616.6, ! -2.90234 10624.5, 10621.1, ! -3.31738 10631.1, 10629.6, ! -1.45117 10642.3, 10639.8, ! -2.48828 10661.6, 10662, ! 0.414062 10674.5, 10671.8, ! -2.69531 10726.3, 10724.9, ! -1.45117 10735.6, 10735, ! -0.62207 10751, 10746.6, ! -4.35352 10761.8, 10757.8, ! -3.93848 10766.7, 10763, ! -3.73145 10776.1, 10772.3, ! -3.73047 10799.1, 10796.6, ! -2.48828 10811.1, 10810.7, ! -0.414062 10813.2, 10812.8, ! -0.415039 10875, 10872.7, ! -2.28027 10953.7, 10954.3, ! 0.62207 10971.1, 10971.9, ! 0.829102 11001.1, 11003, ! 1.86621 11022.9, 11022.9, ! 0 11029.1, 11029.3, ! 0.207031 11034.3, 11032.9, ! -1.45117 11090.4, 11089.2, ! -1.24414 11103.9, 11102.4, ! -1.45117 11128.3, 11124.6, ! -3.73047 11132.1, 11129.2, ! -2.90234 11137.3, 11135.6, ! -1.6582 11165.7, 11163.2, ! -2.4873 11179.6, 11179.6, ! 0 11193.1, 11192.2, ! -0.829102 11238.1, 11238.3, ! 0.207031 11269.6, 11269.9, ! 0.208008 11284.9, 11284.5, ! -0.415039 11398.1, 11401.9, ! 3.73145 11409.7, 11413.7, ! 3.93848 11487.9, 11485.6, ! -2.28027 11509, 11508.2, ! -0.829102 11513.8, 11511.9, ! -1.86523 11535.5, 11537.2, ! 1.6582 11542.8, 11541.8, ! -1.03613 11560.8, 11561.9, ! 1.03613 11566, 11565.2, ! -0.829102 EOZ END BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 281 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** Page 5 • tapescan.txt MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 The data presented here is final and has been depth adjusted to a PDC (Primary Depth Control) log provided by Schlumberger GR CNL dated 04 oct 2008 per Priya Maraj with BP Exploration (Alaska), Inc. FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) opticall Lod Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool code samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 111 Tape File start De th = Tape File End Depth = Tape File Level Spacing = Tape File Depth units = **** FILE TRAILER **** Tape subfile: 2 120 Minimum record length: 54 Maximum record length: 4124 **** FILE HEADER **** 1 size Length 4 4 4 4 8 7059.000000 11684.000000 0.500000 feet records... bytes bytes Page 6 tapescan.txt MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! Remark File version 1.000 This file contains the raw-unedited field MwD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Opticall Lod Depth scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 84 one depth per frame (value= 0) Datum specification Block sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 2 curves: Name Tool Code samples units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR Total Data Records: 221 1 size Length 4 4 4 4 8 Tape File start Depth = 7061.000000 Tape File End Depth = 11685.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape 5ubfile: 3 230 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 08/10/02 1585159 Page 7 tapescan.txt O1 **** REEL TRAILER **** MWD 09/01/27 BHI Ol Tape subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS Tape subfile 2 is type: LIS DEPTH GR ROP 7059.0000 -999.2500 -999.2500 7059.5000 -999.2500 -999.2500 7100.0000 59.1000 -999.2500 7200.0000 48.3242 -999.2500 7300.0000 43.0000 -999.2500 7400.0000 47.9000 -999.2500 7500.0000 47.9000 -999.2500 7600.0000 32.9743 -999.2500 7700.0000 44.0910 -999.2500 7800.0000 -999.2500 -999.2500 7900.0000 -999.2500 -999.2500 8000.0000 -999.2500 -999.2500 8100.0000 -999.2500 -999.2500 8200.0000 -999.2500 -999.2500 8300.0000 -999.2500 -999.2500 8400.0000 -999.2500 -999.2500 8500.0000 -999.2500 -999.2500 8600.0000 -999.2500 -999.2500 8700.0000 -999.2500 -999.2500 8800.0000 19.6463 -999.2500 8900.0000 -999.2500 -999.2500 9000.0000 -999.2500 -999.2500 9100.0000 20.2667 66.4812 9200.0000 140.6233 51.7000 9300.0000 25.3534 91.6152 9400.0000 77.7520 87.8000 9500.0000 178.4267 52.9395 9600.0000 89.8357 70.7311 9700.0000 93.4429 37.5131 9800.0000 74.0922 363.8336 9900.0000 152.1135 52.3938 10000.0000 70.8878 77.2583 10100.0000 71.8761 109.0348 Page 8 tapescan.txt 10200.0000 62.8735 92.7564 10300.0000 67.6224 71.2896 10400.0000 76.7272 168.4337 10500.0000 58.6350 138.1104 10600.0000 79.1437 106.8013 10700.0000 62.0587 116.0793 10800.0000 99.6724 52.5475 10900.0000 48.3937 205.0601 11000.0000 58.9355 139.9759 11100.0000 78.6302 129.9726 11200.0000 94.2720 79.3586 11300.0000 46.1424 125.4052 11400.0000 54.0620 126.3518 11500.0000 52.1437 171.2622 11600.0000 40.3607 168.0400 11684.0000 -999.2500 42.0408 Tape File Start Depth = 7059.000000 Tape File End Depth = 11684.000000 Tape File revel Spacing = 0.500000 Tape File Depth Units = feet Tape Subfile 3 is type: LIS DEPTH GR ROP 7061.0000 -999.2500 -999.2500 7061.2500 63.2000 -999.2500 7100.0000 58.0000 -999.2500 7200.0000 50.8000 -999.2500 7300.0000 42.3000 -999.2500 7400.0000 50.7000 -999.2500 7500.0000 47.9000 -999.2500 7600.0000 35.2000 -999.2500 7700.0000 49.8000 -999.2500 7800.0000 -999.2500 -999.2500 7900.0000 -999.2500 -999.2500 8000.0000 -999.2500 -999.2500 8100.0000 -999.2500 -999.2500 8200.0000 -999.2500 -999.2500 8300.0000 -999.2500 -999.2500 8400.0000 -999.2500 -999.2500 8500.0000 -999.2500 -999.2500 8600.0000 -999.2500 -999.2500 8700.0000 -999.2500 -999.2500 8800.0000 21.5000 -999.2500 8900.0000 -999.2500 -999.2500 9000.0000 -999.2500 -999.2500 9100.0000 18.1000 50.3000 9200.0000 92.6000 54.5000 9300.0000 45.8000 91.5000 9400.0000 84.7000 88.0000 9500.0000 174.3000 53.7000 9600.0000 83.1000 62.7000 9700.0000 100.8000 44.0000 9800.0000 76.2000 1481.8000 9900.0000 156.9000 53.5000 10000.0000 62.1000 78.6000 10100.0000 77.4000 118.6000 10200.0000 62.7000 92.5000 10300.0000 72.9000 88.9000 10400.0000 72.5000 174.1000 10500.0000 64.1000 137.1000 Page 9 • i tapescan.txt 10600.0000 86.1000 94.9000 10700.0000 73.1000 522.4000 10800.0000 80.6000 83.4000 10900.0000 44.8000 136.3000 11000.0000 55.5000 120.0000 11100.0000 90.1000 120.5000 11200.0000 94.4000 78.3000 11300.0000 47.5000 126.3000 11400.0000 54.1000 127.5000 11500.0000 50.3000 173.5000 11600.0000 42.5000 171.4000 11685.0000 -999.2500 41.2000 Tape File start De th = 7061.000000 Tape File End Depth = 11685.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet 0 Tape subfile 4 is type: LIS CJ Page 10
