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207-116
Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:207-116 6.50-029-20580-03-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 12360 10210 9002 9361 11979, 11990, 120 10210, 11050 8314 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 37 - 117 37 - 117 Surface 2654 13-3/8" 36 - 2690 36 - 2689 5380 2670 Intermediate 7104 9-5/8" 34 - 7138 34 - 6309 6870 4760 Liner 2592 7" 6974 - 9566 6191 - 8507 7240 5410 Perforation Depth: Measured depth: 10144 - 11845 feet True vertical depth:8967 - 8982 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# 13Cr80 31 - 9418 31 - 8367 9361 8314Packers and SSSV (type, measured and true vertical depth) 4-1/2" Baker S-3 Perm Packer Liner 9387 4-1/2" 9408 - 12098 8359 - 8955 8430 7500 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 11026 0 41 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Stechauner, Bernhard Bernhard.Stechauner@bp.com Authorized Name:Stechauner, Bernhard Authorized Title: Authorized Signature with Date:Contact Phone:+1 907 564 4594 Treatment descriptions including volumes used and final pressure: 13. GC2 Lead PE Operations Performed1. Abandon Plug Perforations 5 Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8951 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Set Packer with XX Plug Operations shutdown Change Approved Program 5 Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7.Property Designation (Lease Number):ADL 028284 PBU H-14B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Bernhard Stechauner Digitally signed by Bernhard Stechauner Date: 2020.05.21 14:58:03 -08'00' By Samantha Carlisle at 8:39 am, May 22, 2020 DSR-5/26/2020 RBDMS HEW 5/22/2020 MGR22MAY20 ACTIVITYDATE SUMMARY 4/22/2020 ***WELL FLOWING ON ARRIVAL***(profile mod) R/U SWCP 4516 SLICKLINE UNIT ***CONT WSR ON 4/23/20*** 4/23/2020 ***CONT WSR FROM 4/22/20*** (profile modification) RAN 20' x 3.70" DUMMY WHIP STOCK, 2 1/2" SAMPLE BAILER TO 10,258' SLM (see log for issues, 68°) RAN 12' x 2 7/8" DUMMY GUN (3.16" rings),TO 10,350' SLM RAN READ CASED HOLE 40arm CALIPER FROM 10,350' SLM TO 9,200' SLM (Good data). DRIFT TO 10,319' SLM / 10,352' MD W/ 10'x 2-7/8" DUMY PERF GUN (3.16" swell rings), 4-1/2" XN LOCATOR SET BAKER 45 KB SUMP PACKER W/ 2-7/8" X-NIPPLE W/ 2-7/8" XX-PLUG INSTALLED AT ME= 10,200' MD ****WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED**** Daily Report of Well Operations PBU H-14B Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, May 29, 2018 9:33 AM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Draughon,Austin; Duong, Lea; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan;Wellman,Julie;Youngmun,Alex; Zoesch, Eric Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO W II Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismos i, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington,Aras J Subject: OPERABLE: Producer H-14B (PTD#2071160) OA repressurization fixed external-email: 0 All, Producer H-14B(PTD#2071160)was put Under Evaluation on 05/18/18 for sustained OA casing pressure above NOL. On 05/18/18 the Cameron Wellhead Technician re-energized the secondary IC seals.The Wellhead Tech.did a follow up PPPOT-IC on 05/20/18 that passed.A follow up OART indicated a 10 psi/day build up rate, but the OA pressure has since stabilized at 110 psi.The well meets operability criteria and will now be classified as OPERABLE. Please respond with any questions. Andrew Ogg sCANNED MAY 3 U 213th Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 From: AK, GWO Well Integrity Engineer Sen . 'say, May 18, 2018 4:51 PM To: 'Regg, Ja : (DOA) (jim.regg@alaska.gov)'; AK, OPS EOC Specialists; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, 0' - - OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad HUQ; AK, OPS P.• LV; AK, OPS Well Pad MN; AK, OPS Well Pad RJ; AK, OPS WELL PAD S; AK, OPS Well Pad SW; AK, OPS WELL PAD W; A', :• Well Pad Z; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK RES GPB West Wells Opt Engr; AKOpsProdEO , -r•ene, Matthew; Draughon, Austin; Frankenburg, Amy; Peru, Cale Rupert, C. Ryan; Shriver,Tyson; Wellman, Julie; Young . Alex; Zoesch, Eric Cc: 'chris.wallace@alaska.gov'; AK, GWO Completions Well Inte• '* • AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity" nformation; AK, OPS FF Well Ops Comp Res; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerm. • Eric; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; .+o, Louis A; Sternicki, Oliver R Tempel, Joshua; Worthington, Aras J Subject: UNDER EVALUATION: Producer H-14B (PTD #2071160) sustained OA pressure above N' All, 110 • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Friday, May 18, 2018 4:51 PM To: Regg,James B (DOA);AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead; AK, OPS Prod Controllers;AK, OPS Well Pad HUQ;AK, OPS Well Pad LV;AK, OPS Well' Pad MN;AK, OPS Well Pad RJ;AK, OPS WELL PAD S;AK, OPS Well Pad SW;AK, OPS WELL PAD W;AK, OPS Well Pad Z;Ak, Ops West Area TL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Bergene, Matthew; Draughon,Austin; Frankenburg,Amy; Peru, Cale; Rupert, C. Ryan; Shriver,Tyson; Wellman,Julie;Youngmun,Alex;Zoesch, Eric Cc: Wallace, Chris D (DOA);AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO WEII Integrity Well Information;AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismosli, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington, Aras J Subject: UNDER EVALUATION: Producer H-14B (PTD#2071160) sustained OA pressure above NOL All, Producer H-14B (PTD#2071160)was flagged to evaluate possible IAxOA communication. On 05/16/18 DHD bled the OA from 950 psi to 50 psi.On 05/17/18 during a follow up monitor the OA pressure was reported to be over NOL.The T/IiO pressures were 1430/1660/1010 psi.The rapid buildup rate of the OA pressures indicates a possible well barrier failure. The well is now classified as UNDER EVALUATION and is on the 28 day clock for diagnostics and repair. Plan forward: 1. Cameron: Re-energize IC secondary seals 2. DHD: Perform OART 3. Well Integrity Engineer:Additional diagnostics as needed. Please respond if in conflict. Andrew Ogg ;} MAY 2 2 nib Well Integrity Engineer BP Global Wells Organization-Alaska Office:907-659-8110 1 S OLASKA OIL AND G STCONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS NOV1. Operations Performed NO 0 2U17 Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operatio s s�• td• n 0 Suspend 0 Perforate IZ Other Stimulate 0 Alter Casing 0 Chang 21 =• - r e ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 207-116 3. Address: P.O.Box 196612 Anchorage, Development I3 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20580-03-00 7. Property Designation(Lease Number): ADL 0028284 8. Well Name and Number PBU H-14B - 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 12360 feet Plugs measured 11050 feet true vertical 8951 feet Junk measured See Attachment feet Effective Depth: measured 11050 feet Packer measured 9361 feet true vertical 9005 feet Packer true vertical 8314 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 36-116 36-116 Surface 2660 13-3/8"72#L-80 35-2695 35-2695 4930 2670 Intermediate 7105 9-5/8"47#L-80 33-7138 33-6310 6870 4760 Production Liner 2690 4-1/2"12.6#L-80 9409-12098 8359-8955 8430 7500 Liner 2592 7"26#L-80 6974-9566 9191-8507 7240 5410 Perforation Depth: Measured depth: 10144-10154 feet 10420-10480 feet 10600-10630 feet 10725-10755 feet 10875-10905 feet 11100-11660 feet 11718-11743 feet 11795-11820 feet 11820-11845 feet True vertical depth: 8967-8973 feet feet 9055-9052 feet 9037-9034 feet 9021-9017 feet 9011-9011 feet 9002-8991 feet 8990-8989 feet 8986-8984 feet 8984-8982 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 31-9418 31-8368 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED AN 0 3 2U18 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 512 35872 2388 620 1204 Subsequent to operation: 819 15669 6195 1580 718 14.Attachments:(required per 20 AAC 25.07025.071,&25.283) 15.Well Class after work: Daily Report of Well Operations [1 j Exploratory 0 Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil IBJ Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 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: Shriver,Tyson Contact Name: Shriver,Tyson Authorized Title: Well Intervention EngineerAz„...:,.."..._, Contact Email: Tyson.Shriver@bp.com Authorized Signature: Date: /I / ? Contact Phone: +1 9075644133 Form 10-404 Revised 04/2017 �-�L `z— eqS e 20� �/ �� L R B M1S \,\./ �. _ 7 Submit Original Only • • 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 October 31, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Addition of Perforations for Well H-14B, PTD # 207-116. 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 • 0 Junk Attachment PBU H-14B SW Name MD Date Comments H-14B 11979 01/06/2015 Milled CIBP H-14B 11990 10/01/2013 Milled CIBP H-14B 12012 12/03/2012 Milled 4-1/2" HES CIBP • • Packers and SSV's Attachment PBU H-14B SW Name Type MD TVD Depscription H-14B PACKER 6980.12 6195.7 7" Baker ZXP Packer H-14B TBG PACKER 9360.96 8313.91 4-1/2" Baker S-3 Perm Packer H-14B PACKER 9408.82 8358.89 5" Baker ZXP Top Packer • 0 CC o LU ai w o a, -o Jcn II M Q I I = * O CO J w W W 0 Z w 0 Y _o O d C O o d • O II _ o V Q i� W v o < 0 0F `- -a O Ua) O 0 I I CC F 0 E N N o < J a) a`) 0 u) w -0 _c Q w J z 0 O (i) o a 0 - co E C N Q Z Y d 0 N- 0 -a O -C Z 0 0 Z • E •ate Ln N � fl..o � D °6 0 oa M Eio O tJOF o Na' II > 0 n w0- Q . _o J W NC O 0 _0- a:W o wU) NQ- O _C O Cl- TS_W > F— p0 in J U) W y } E ›- 2 c`r) in o � iZ (3 = 0 wwD owm0- O `'' lc?) O a'.> C > o o El- F- F- F- cc - — co ° O O Q < _ �' E ao a0 `- Cr 22 ami cZ1- W F- 0a. s a, � E a) to i r` UOW On d c o oopJ 0w 3 0 0 Q C) N 'O WII ~ Y LL EY - U) w N o U O co O O L A a x a) z11 W W �c cv-) Jz C CL (i) u) 0 03 (f) N O = Q' O d2 O O c`�nm `- Ow • Q0 J N CO - — Nr • Cw00 wa o •LU) � I- � ( az W a) 2 Li w . � Qmz o d -3o * Oou) � Q Q) = a' oJwO � N w * „ Ex � m0 2F- ( ci ai :,=. 2 -o U) X F- F- * _c * m , W Op � D D 0 m ca U) QEF— ~ < Q m _1 2 - Co - Q = ¢ o o `.* = C/ 3 0 CJd2 = v 0 � * J co L d � � * JY0 mill c L7u- 01-- ;c1) z ~ « o a) Q C1co W Q J W w N J 0 N CC WO W N- 4- "17 d : O : a CO cJ) 0- 0D -.,, C)OW rZ 2 Q W J J . m _1 J � F- ama F- F- ? nY = 0U) W Q DJ .— _1 < . CQOw Qwcfl � o a W w > > m W o c io > Z ajQ o _ • w _ OWU) O 3 - O � � WO � 1¢ � w � LU �' >_ � a � 60 W Qui o ° 3 m z5• `nzF_ D - II 0ZZm � � ZO } � 0w ai o O w Z 0 = O z z M Z W X W Z c 0 0 _ c m U) O aai � W � E ZOOo �� O � woQ 00 E' .2 o J JJ QJUI— -6 •5U = W \ c ,_ w0 0 O C � J w F- vIiwwa •- � � ZCO a) mF- - � � 0 ~ m � tea) a) OU Y N � �-L o > > � ZU) 0000 0 0000 = w 'tOO 2, E u) Lo -a m 0 o O O O O O O s 0 Z: : Ct J J m : F— 2 J : J J C7 0,- J * * .- W o U W F- N- N- r` r` N N- 0 0 00 C) Ccn ti H N N N N N N Q N N- i-.6 O N io co Co m a) F- 4izz i i i----- 0 Q TREE= 41/16"CMV III SAFETY NOTES: WELL ANGLE >70°@ 10282'. WELLHEAD= MCEVOYLI F •"4-1/2"Cf-RONE TBG"` ACTUATOR= BAKER C 'OKB.11EV= 82.25' BF.13EV= 46.47' I I KOP= 3200' Max Angle= 98"@ 10727 U r 2190' —14-1/2"HES X NP,D=3.813" Datum MD= 10007 Datum ND= 8800'SS 0.0 — 2632' —9-518`DV PKR 20-CONDUCTOR,D=? —1 110' , GAS LFT MANDRELS 13-3/8'CSG,72#,L-80,D=12.347" H 2692' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3426 3417 16 NM DOME F ( 16 12/16/07 Minimum ID = 3.725" 9405` 3 6204 5594 41 MNG DOME RK r 16 12/05/16 2 8114 7149 19 KBG2 DMY BK r 0 11/22/07 4-1/2" HES X NIPPLE 1 9271 8229 19 KBG2 DMY BK r 0 11/22/07 9-518'X 7'BKR ZXP LTP H 6974' L 4-, w/6'T/BS,D=7.5" T / 9-5/8"MI_LOUT WOW(H 14B) 7138'-7155' 9-518'X 7'BKR HMC —1 6992' LNRHGR,D=6.28' 9-5/8"W PSTOCK(11/05/07) —1 7138' ( 9340' 1—'4_1/2-HE5 X NP,D=3.813- 1 9-5/8"EZSV(11/03/07) —{ 7150' /:1 /a • 9361' —7"X 4-1/2'BKR S-3 PKR D=3.875" 5-1/2"TBG STUB(Tagged 11/03/07) -1 7505' 93$4' I-14112"HES X NP,D=3.813" ESTIMATED TOP OF CBNBYT H 9000' j IN - ••••••••►4 1 #•••••. 9405' -4tom 112"FES XN ,D=3.725" 9-5/8"CSG,47#,L-80,0=8.681' 9981 -• ♦ • .4.•.•. ';••••44 �•• •4 •••• ' 9408' —7'X 41/2"BKR HRD • PERFORATION SUM4MARY m►•i�►•iii►•i ZXP LTP,D=4.43' ►••�•••••4• 4,-- •1 •••• • REF LOG:ROP/GR ON 11/20/07 1•0••4* I• \ 9418' —{4-to"wLEG,E)=4.00" •1 •••♦ ANGLE AT TOP FERE:56"C 10144' ►••�0••••4 111 ♦1 •••• Note:Refer to Reduction DB for historical pert data n►••�:••••4►••• 9431' —17'X5"BKRI-MC `-;:t►•"•• ►• SIZE SPF INTERVAL Opn/Sqz DATE Saz ; •� ••••4� INR HGR,D=4.45" ' a"" ••42-7/8" 6 10144-10154 0 07/16/17 - ' ••••• • 2-7/8" 6 10420-10480 0 10/03/13 .•• •• . 9437' H 5'X 41/2'XO,D=3.958' 2-7/8" 6 10600-10630 0 10/03/13 2-7/8" 6 10725-10755 0 12/05/12 111 2-7/8" 6 10875-10905 0 12/05/12 2-7/8' 6 11100-11660 C 11/22107 il 11050' —{4-1/2'wFDCUP(02/25/15) 3-3/8" 4 11718-11743 C 08/28/09 •-* 2-7/8' 6 11795- 11820 C 06/03/11 �••••! 2-7/8' 6 11820-11845 C 06/03/11 11979' HASH:M LLED CEP(01/06/15) 111 Il 11990' —iFSH:?ALLIED CEP(10/01/13) 41/2"TBG,12.6#, 13CR-80 VAM TOP,.0152 bpf,D=1958' 9418' 12012' _ FSMlH: LED CEP(12/05112) 7"LNR 26#,L-80 BT-M,.0383 bpf,D=6.276' H $566' ►••••••...• • ►••••••, FWD H 12013' ►••• 41/2"INR,12.6#,L-80 BT-M,.0152 bpf,D=3.958'—i--r-17696"— DATE .958" 12098' DATE REV BY CONVENTS DATE REV BY COMMENTS PRUDHOE BAY UNT P 1981 V3 ORIGINAL COMPLETION 03/02/15 RRW/JMC SET CEP(02/25/15) VA L: 1-1-14B 12/15/89 016 RWP 08/06/15 DGB/JMJ CORRECTED PEW REF LOG PERMIT No:"2071160 06/24/98 ? CTD SIDETRACK(H-14A) 12/07/16 CJWJM)GLV CIO(12/05/16) API No: 50-029-20580-03 11/24/07 D14 SIDETRACK(H-1413) 07/17/17 BTN+JM)ADPHZFS(07/16117) SEC 21,T11N,R13E,1547 FM.8 1265'FEL 10/10/13 ALMJMJ MILL CBP/CBP'ADFERFS(10/03/13) 01/13/15 ATO/JMD MILL CBPYSET FISH(01/06/15) BP Exploration(Alaska) 2a1-�l� BA ER . . -2_1c cc,at UGHES PRINT DISTRIBUTION LIST a GE company Please sign and return one copy of this transmittal form to: COMPANY BP Exploration Alaska II EIVE BP Exploration(Alaska) Inc. ��v Y Petrotechnical Data Center, LR2-1 DATA LOGGED WELL NAME H-14B 900 E. Benson Blvd. /14/201'7 M. K. BENDER AUG 0 3 2017 Anchorage,Alaska 99508 FIELD Prudhoe Bay Unit to acknowledge receipt of this data. COUNTY PRUDHOE BAY AOGCC LOG TYPE RPM:PNC3D-CO BHI DISTRICT Alaska LOG DATE July 15,2017 AUTHORIZED BY Paul Canizares EMAIL Paul.CanizaresCcr�bakerhughes.corn TODAYS DATE August 1,2017 Revision STATUS Final Replacement: No Details: Rev. Requested by: COMPANY FIELD/ FINAL CD/DVD FINAL PRELIM (las,dlis,PDF,META, SURVEY REPORT ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS CGM,Final Surveys) (Compass) PERSON ATTENTION #OF PRINTS #UI-PRIN IS #OF COPIES #OF COPIES #OF COPIES 1 BP North Slope. 0 1 1 EOA,PBOC,PRB-20(Office 109) 0 D&C Wells Project Aids Agatha Rutka&Barbara Glassmaker 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. 0 0 1 0 Attn:Ricky Elgarico ATO 3-344 700 G Street Anchorage,AK 99510 3 ExxonMobil,Alaska 0 0 1 0 Attn:Lynda M.Yaskell and/or Lisa Boggs 3201 C Street,Suite 505 Anchorage,AK 99503 4 State of Alaska -AOGCC 0 1 1 0 Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division ofOil&Gas *** 0 I 0 1 0 Attn:James Hyun 550 West 7th Avenue,Suite 802 Anchorage,Alaska 99501 Stamp"confential"on all material deliver to DNR 6 BP Exploration(Alaska)Inc. Petrotechnical Data Center,IR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 Attn:Dodie Stinson TOTALS FOR THIS PAGE: 0 2 5 0 0 STATE OF ALASKA • / :KA OIL AND GAS CONSERVATION COW. JION • REPORT OF SUNDRY WELL OPERATIONS / 1 Operations Abandon Li Repair Well L] Plug Perforations U Perforate Lf OtherEfk-vh C/3P Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extensions Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Weill] 2 Operator 4 Well Class Before Work 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Development Exploratory ❑ 207-116-0 3 Address P O Box 196612 Stratigraphic❑ Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-20580-03-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028284 PBU H-14B 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary RECEIVED Total Depth measured 12360 feet Plugs measured 11050 feet true vertical 8951 1 feet Junk measured See Attachment feelvIAR 2 4 2015 Effective Depth measured 11050 feet Packer measured None feet/i +, CC true vertical 9004 69 feet true vertical None fee �- Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x30" 356-1156 356-1156 0 0 Surface 2660 03 13-3/8"72#L-80 35 1 -2695 13 35 1 -2694 99 4930 2670 Intermediate 7104 7 9-5/8"47#L-80 33 3-7138 33 3-6309 3 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10420-10480 feet 10600-10630 feet 10725-10755 feet _ 10875-10905 feet 11100-11660 feet 11718-11743 feet 11795-11820 feet 11820-11845 feet True Vertical depth 9054 62-9051.54 feet 9037 12-9033 64 feet 9020 86-9016 82 feet 9011 48-9010 82 feet 9002 39-8991 05 feet 8990 25-8989.46 feet 8986 36-8984 08 feet 8984.08-8981 5 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 31 1-9418 02 31 1-8367 52 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured). Treatment descriptions including volumes used and final pressure 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 532 38226 3540 0 1089 Subsequent to operation 668 11171 2310 0 739 14 Attachments 15.Well Class after work Copies of Logs and Surveys Run Exploratory❑ Development Q Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work. Oil U Gas ❑ WDSPLJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCf 17 I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C 0 Exempt N/A Contact Nita Summerhays Email Nita.Summerhays CI_bp.com Pnnted Name Nita S mmerhays Title Petrotechnical Data Engineer l Signatu Vi.' / Phone 564-4035 Date 3/24/2015 ►' 7— 4/T/1 S RBDMS) APR - 6 2015 Form 10-404 Revised 10/2012 Submit Original Only Daily Report of Well Operations ADL0028284 n.. . � f �.,. SUMMARY Coil 3, 1.75", 14600', Job Scope: log tie-in, drift and set CIBP Wait for snow removal to spot unit. 2/23/2015 ***Continue on WSR 2-24-15 *** CTU#3 w/ 1.75" CT(CTV=31.6 bbls) Objective: Set CIBP MIRU CTU #3- Perform 7 day BOPE pressure/function Test. No failures. No flow swab and SSV. N/U BOPE. Well control drill. M/U WFD MHA. M/U PDS GR/CCL and 3.70"drift. PT lube. Bullhead 1% KCL with 86 bbl safelube, RIH clean to 11200'. Log up at 40 fpm. Flag coil at 11000'. Log up at 40 fpm to 9200'. POH. No Flow swab and SSV. Lay out PDS mem GR/CCL (0' Correction) - PT MHA- MU wfd setting tool 4-1/2" CIBP- Bullhead 1% KCL w/SL 27 bbls - RIH. 2/24/2015 *** Continue on WSR 2-24-15 *** CTU #3 w/ 1.75" CT(CTV=31.6 bbls) Objective: Set CIBP RIH w/4-1/2"Wfd CIBP- Set CIBP @ 11,050' - POOH - FP well Diesel 30 bbls- Secure well. RDMO CTU#3 2/25/2015 ***Job Complete*** FLUIDS PUMPED BBLS 110 60/40 METH 131 SLICK 1% KCL W/SAFELUBE 24 DIESEL 265 TOTAL • m a O o 0 0 0 co � o � o V CO I1) Lf) N- N N- U y 0 0 0 0 0 ►. N- V M M M 7 CO N c O 'Cr m CO I— 00 V CO (') r O N CO O) O O) L() • Cfl Ln N- O LC) O) CO co— U') O) CO CO co 00 N CO • I I H O) CO Co .C O) r r M M co CO M a) L LLL co CO 00 LU co O M CO cp r Ln CO - f* O) N d7 4-I 00 2 N CO LU co') N- O LU CO N M M O) V M M C Q CO O) #.▪7 Q � J QO co 0 � � v Q O co J J J CO d CO It J CO N *k O V NO � (NI _ w ,— C� M — d- N- 4 C)O O O) O) CO 00 C co — Ln O CO CO J N- N N N O) C O 0 LU D v U CC CC C Z U Q Z Z: D U ZH J J w H Packers and SSV's Attachment ADL0028284 SW Name Type MD TVD Depscription H-14B PACKER 6980.23 6195.78 7" Baker ZXP Packer H-14B PACKER 9360.91 8313.87 4-1/2" Baker S-3 Perm Packer H-14B PACKER 9408.93 8359 5" Baker ZXP Top Packer H-14B 207-116-0 Junk Attachment SW Name MD Date Description H-14B 11979 1/6/2015 Milled CIBP H-14B 11990 10/1/2013 Milled CIBP H-14B 12012 12/3/2012 Milled 4-1/2" HES CIBP TREE= 4-1/16' Y NOTES: WEL ANGLE >70°Q 10282'. WELLJEAD CNV H 14 B "" .-12'CHROME TBG""" ACTUATOR= BAKER C OKB. EV= 82 a. .25 BF.EIV= 46.4T I I KOP- L 2190' H4-1/2'FES X Ems,D=3.813' Aix Age= 98" ', 10727' Datum IC= 10007' Datum TVD= 8800'SS — 2632" -19-5/8'DV FKR 20"CONDUCTOR,D=? H 110' GAS LFT MANDRELS 13-3/8'CSG,72#,L-80,D=12.347' H 2692' ST MD TVD DEV_TYPE VLV LATCH FORT DATE 4 3426•3417 16 WAG DOME Fa( 16 12/16/07 L Minimum ID = 3.725" @ 9405' 3 6204 5594 41 MNG SO Fac F 20 12/16/07 2 8114 7149 19 103G2 DAY BK r 0 11/22/07 4-1/2" HES X NIPPLE 1 9271 8229 19 KBG2 DMY BK r 0 11/22/07 L 9-5/8'X 7'BKR ZXP LTP JI 6974' _- w/6'TBS,D=7.5' T f 9 5/B'X r BKR I F1AC -{ 6992' 9-5/8'MLLOUT WICOW(11-1413) 7138'-7155' ILFfiHGR,U=6.28' 9-5/8'W IPSTOCK(11/05/07) H 7138' I 9340• H4-12"FE X NP,D=3.813' 9-5/8'EZSV(11/03/07) --I 7150' 2 L9361' I-7'X4-1/Y BKR S-3 PKR,D=3.875" 5-12-TBG STUB(Tagged 11/03/07) - 7505' I 93$4' H4-12'FES XPP,D=3.813' ESTIMATE)TOP OF CEMENT -I 9000' J 11111/ •�i•i••i•44 9406' H 4-12'FES XN NP,D=3.725' I ririr[- 9-5/8'CSG,47#,L-80,D=8.681' H 9981' x-41_/•►� ►•• ►. I 41/ ♦•4•/ 9408' -7'X 4-1/2'BKR FRD ►♦►•• ►♦ •4•••�►•�4 PERFORATION SUS IAARY ►►�••1►►�•••�••O ZXP• ETP,D=4.43' • REF LOG:MCN/STP ON 08/27/09 ►iii►i�i�i►iii 9418' H4-112'WLE G,D=4.00' ♦/ ♦•••/ ANGLE AT TOP PERF:89°Q 10420' ••4••••••••o•►ii9431' I-7"X 5'BKR me♦ ♦���/ Note:Refer to Production DB for historical pert data „,,,,,,\ ,; , ►�1►� . ►�►• • LARFKD=4.45' SIZE SPF FNT6�VAL OpNSgz DATE St7Z ;i-;;• ��/•••••• — 2-78' 6 10420-10480 0 10/03/13 ►�•�•• , 9437' 5”X 4-1/2'X0,D=3.958' 2-7/8' 6 10600-10630 0 10/03/13 �•�•�i / 2-78' 6 10725-10755 0 12/05112 U 2-7/8' 6 10875- 10905 0 12(05/12 U 2-78' 6 11100-11660 C 11/22/07 I 3-3/8' 4 11718- 11743 C 08/28/09 II 11050' 14-12'WFD CSP(0225/15) 2-78' 6 11795- 11820 C 06/03/11 •VV** 2-78" 6 11820-11845 C 06/03/11 P-•-•- 11. 11979' -I FISH MILLED CEP(01/06/15) • 11990' H FISH MLLEDCEP(10/01/13) 4-12"TBG,12.6#, 13CR-80 VAN TOP,.0152 bpf,D=3.958" H 9418' I 12012' HF1S-t PALLED CBP(12/05/12) 7'LNR,26#,L-80 BT-M,.0383 bpf,D=6.276' H 9566' ��•••• MID 12013' L•-•.• x4_1/2'LNR, 12.6#.L-80 BT-M, 0152 bpf,D=3.958' j-r-12098' DATE REV BY COMMENTS DATE REV BY COMMENTS PRIDHOE BAY lt4T 1981 V3 ORIGINAL COMPLETION 10/10/13 ALIWJM IMLL CEBP/CBPADRRES(10/03/13) %MIL H-14B 12/15189 D16 IMP 01/13/15 ATO/JME1MLL CEP/SET FSH(01/06/15) FERMT No: 2071160 06/24/98 ? CTD SIDETRACK(H-14A) 03/02/15FIRWIA C SET GBP(02/25/15) AR No: 50-029-20580-03 11/24107 D14 SIDETRACK(H-14B) SEC 21,T11N,R13E,1542'FPL&1265'FB 06/13/11 RMF-'PJC CFBR REFS FS(6/3/11) 1 12/12/12 JJIJMD PALL CBRCBP/AD( S(12/05/12) BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION . .AMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate Other 0 Mill Plug Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver Time Extension❑ Change Approved Program❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2 Operator 4 Well Class Before Work. 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory 207-116-0 3.Address P O Box 196612 Stratigraphic ❑ Service❑ 6.API Number Anchorage,AK 99519-6612 50-029-20580-03-00 7 Property Designation(Lease Number) 8.Well Name and Number ADL0028284 PBU H-14B 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary' R EC E IV E D Total Depth measured 12360 feet Plugs measured None feet A N 2 a 2015 true vertical 8951 1 feet Junk measured See Attachment feet Effective Depth measured 12013 feet Packer measured See Attachment feet AOGCCj true vertical 8962.96 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x30" 356-1156 356-1156 0 0 Surface 2660 03 13-3/8"72#L-80 35.1-2695 13 35 1-2694 99 4930 2670 Intermediate 7104 7 9-5/8"47#L-80 33 3-7138 33 3-6309.3 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10420-10480 feet 10600-10630 feet 10725-10755 feet 10875-10905 feet 11100-11660 feet 11718-11743 feet 11795-11820 feet 11820-11845 feet True Vertical depth 9054 62-9051 54 feet 9037.12-9033 64 feet 9020 86-9016.82 feet 9011 48-9010 82 feet 9002 39-8991 05 feet 8990 25-8989 46 feet 8986 36-8984 08 feet 8984 08-8981.5 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 31 1-9418 02 31 1 -8367 52 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12 Stimulation or cement squeeze summary Intervals treated(measured) C , . ..F iy) Treatment descriptions including volumes used and final pressure f 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 102 305 226 1520 240 Subsequent to operation: 916 22207 3612 1640 1423 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work Oil 0 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 0 Exempt. N/A Contact Garry Catron Email Garry.Catron( BP.Com Pnnted Name Garry Catron Title PDC PE Signature _fida4 Phone 564-4424 Date 1/19/2015 ��� �Z�� RBDMSc�kk JAN 2 1 2015 A. /4-P7 Form 10-404 Revised 10/2012 Submit Original Only H-14B 207-116-0 Junk Attachment SW Name MD Date Description H-14B 11979 1/6/2015 Milled CIBP H-14B 11990 10/1/2013 Milled CIBP H-14B 12012 12/3/2012 Milled 4-1/2" HES CIBP Packers and SSV's Attachment ADL0028284 SW Name Type MD TVD Depscription H-14B PACKER 6980.23 6195.78 7" Baker ZXP Packer H-14B PACKER 9360.91 8313.87 4-1/2" Baker S-3 Perm Packer H-14B PACKER 9408.93 8359 5" Baker ZXP Top Packer a o 0 0 o O R O . o �(No- o � v �n �n V N N N- U y O O O O O i N. V CO M Cr) • CO N V O .4- 03 m CO V CO N- a— O) N CO M O) O O) Lc) O O O t[) 4 - O O O O) CO CO Cr) CO co O O O N 0) CO CO H O7 N d7 O M y) M tri M CO d7 co CO CO CO O 00 O O 00 to N O 0) - f� O) N O) C▪.) a '-• Co ▪ N (O CO N- o LC) N— CO CO CO O) v co co • N CO O) C • 9O o o O ao CO co co O J CO J • CD M * J (.0 N N r N- O -4- *k • x N - - O - (� O U "—r. to r. -N (V M V ; LO CV 0 0 L_ D)O O 0)) O) CO 00 O CO LO CO O CO 4) f� N N N O) J W Q CS) LU Q U V p CtC[ C[ L t_ Z Q LU LU LJJ H ZZj 3 U Z _ _ J J Cn I— y g £ _ m -- = a) / § I- I- U) 2 0 lba /3 0= / 0 � © 2 � ƒ g � � $ ƒ \ 2 > aF / | \ / \4- o0 � 0 / 00 $ r 0ek 2 # 6 = a) m 0 < 1--9 a '- 6 0- \ 6 „ oa cu \/ 2 ƒ f / 0 0 ca 0 / 0 / 8 - o- Til e 4, - k / - n / � \ 0 E / d 8 p E - b ° . G ® 3 f E \ 0 0 / / / / E \/ •22 \ x \ ? k d e __ 2 R 2 = 6 - ,0 I ; 0 2 2 co t / / \ \ / $ MP TRE =` 4-1/16"CNV ..NtaLHEAD= MCEVOY SAFETY NOTES: WELL ANGLE >70°@ 10282'. ACTUATOR= BAKER C H - I ••'4-1/2"CI-ROME TBG•'* 1 4B OKB.ELEV= 82.25' BF.B.EV= 46.47' I Li KOP= 3200' Max Angie= 98'©10727' Datum MD= 10007' ' ' j 2190' H4-1/2"HES X NP,ID=3.813" Datum ND= 8800'SS 20"CONDUCTOR,D=? — 110' (_,..4 GAS LFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" H 2692' ST MD ND DEV TYPE VLV LATCH FORT DATE Ld 4 3426 3417 16 P. 3 DOMFE+ ( r 16 12/16/07 Minimum ID = 3.725" @ 9405' 3 6204 5594 41 MV1G SO RK ' 20 12/16/07 2 8114 7149 19 KBG2 DMY BK ' 0 11/22/07 4-1/2" HES X NIPPLE 1 9271 8229 19 KBG2 DMY BK ' 0 11/22/07 9-5/8"X 7"BKR ZXP LTP 6974` w/6'T/BS,D=7.5" T 9-5/8"MLLOIJT WINIDOW(H-148) 7138'-7155' 9-5/8"X 7"BKR I-iAC H 6992' LNR HGR,D=6.28" 9-5/8'VVHPSTOCK(11/05/07) —{ 7138' i 9340' 1--14-1/2"HES X NP,D=3.813" 9-5/8"EZSV(11/03/07) --1 7150' L9361' —7"X 41/2"BKR S-3 i'KR D=3.875' 5-1/2"TBG STUB(Tagged 11/03/07) H 7505' I 93$4' —14-1/2"HES X NP,D=3.813" ESTIMATED TOP OF C8d8HT H 9000' .♦►♦♦•♦•O ' 9405' H4-112"HES XN NP,D=3.725' 9-5/8"CSG,47#,L-80,D=8.681' H 9981' r 1 9408' —7"X41J2"BKR Ff2D PERFORATION SUMMARYZXPLTP,D=4.43" ►�♦�►:♦:♦*♦� ►♦►♦♦•►♦ ♦1 ♦♦•♦4 REF LOG:MCNL/SW ON 08/27/09 ►♦♦1••••• •k•♦ i 9418' H4-1/2"112"Wt EG ID=4.00" ANGLE AT TOP PBZF:89' 10420' •••,I•♦� ♦♦ ♦� •1 •• ►♦ ♦� ♦♦4♦� 9431` —7"X5"BKRI-ND Note:Refer to Production OB for historical perf data •;;;%iIG,►♦►♦♦ ► ♦1 ♦♦••. SIZE SPF INTERVAL Opn/Sqz DATE SOZ - ►♦♦1►♦♦♦♦• LP112 HGR D=4.45" 2-7/8" 6 10420-10480 0 10/03/13 ' ►♦•♦•4 2-7/8" 6 10600-10630 0 10/03/13 •• 9437' N5"X 41/Y XO,D=3.958" j 2-7/8" 6 10725-10755 0 12/05/12 2-7/8" 6 10875-10905 0 12/05/12 I 2-7/8" 6 11100- 11660 0 11/22/07 II 3-3/8' 4 11718-11743 0 08/28/09 ' 2-7/8" 6 11795-11820 0 06/03/11 ,.-**-No 1 2-7/8" 6 11820-11845 0 06/03/11 11979' —{FISH:PALLED CBP(01/06/15) 11990' -FISH:MLLEDCBP(10/01/13) 4-1/2'TBG,12.6#, 13CR-80 VAM TOP,.0152 bpf,D=3.958" -I 9418' 4111 12012' --J FISH:MILLED GBP(12/05/12) 7'LNR,26#,L-80 BT-M,.0383 bpf,0=6.276' —{ 9566' ♦..,1 ••••••.♦♦♦• • FBTD 12013' ► 4-1/2'LNR,12.6#,L-80 BT-M,.0152 bpf,D=3.958" H 12098' DATE REV BY COMVFNTS DATE REV BY COMvENTS PRUDHOE BAY UNIT 1981 ? ORIGINAL COMPLETION 06/13/11 RAH PJC CIBP1 REFERFS(6/3/11) WELL: H-14B 12/15/89 D16 RWP 12/12/12 JJL/JMJ MLL COBP/gBFYADPERFS(12/05/12) PERMIT No: 2071160 06/24/98 ? CTDSIDETRACK(H-14A) 1W10/13 ALMJMtt MLL CBP/CIBP/ADPERFS(10/03/13) AFI No: 50-029-20580-03 11/24/07 D14 SIDETRACK(H-14B) 01/13/15 ATCYJM7 MLL CIBFYSET FISH(01/06/15) SIC 21,T11N,R13E,1547 FM_&1265'FEL 12/17/07 TFA/SV GLV C/O 05/12/08 PGS/PJC DRG DRAFT CORRECTIONS BP Exploration(Alaska) • linage Project Wel! Flistory File Cover Page XHVZE This page idQntifies 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. ~,Q ~ - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III IIIIIIIIIII IIIII ^ Rescan Needed III II'lllll(I 111111 RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: ,[~Greyscale Items: ~ "P ^ Other, No/Type: ^ Other Items Scannable by VV a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria ['' Date: ~ J D ^ Other.: lsl ProjectProofing III IIIIIIIIIII IIIII BY: Maria Date: '~ Q /s/ Scanning Preparation `' x 30 = ~J + ` ~ =TOTAL PAGES ~ ~ ~ ~ (Count does not i S~ude cover sheets ^ ,~ BY: Maria ' I, ~ Date: u ~/' Production Scanning Stage 1 Page Count from Scanned File: J `-~ (Count does include c er sheet) Page Count Matches Number in Scanni g Pre aration: YES NO BY: Maria Date: ~~- ~~ ~V /s/ 'n/~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO V BY: Maria Date: Scanning is complete at this point unless rescanning is required. "'iuumiuiiiuu ReScanned BY: Maria Date: /s/ Comments about this file: a~ , ~e~~ed iuuiimiiuiui 10/6/2005 Well History File Cover Page.doc RECEIVED STATE OF ALASKA ' AKA OIL AND GAS CONSERVATION COMMISSION 6 L 3 1 2.013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon Li Repair Well L] Plug Perforations U Perforate U Other Lij Mill CIBP 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 0 Exploratory ❑ 207-116-0 • 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20580-03-00 ` 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028284 ° PBU H-14B . 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL• 11.Present Well Condition Summary: Total Depth measured 12360 feet Plugs measured 11050 feet true vertical 8951.1 feet Junk measured 12014 feet Effective Depth measured 11050 feet Packer measured See Attachment feet true vertical 9004.69 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 33-113 33-113 0 0 Surface 2657 13-3/8"72#L-80 32-2689 32-2688.86 4930 2670 Intermediate None None None None None None Production 7107 9-5/8"47#L-80 31-7138 31-6309.3 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10420-10480 feet 10600-10630 feet 10725-10755 feet 10875-10905 feet 11100-11660 feet 11718-11743 feet 11795-11820 feet 11820-11845 feet True Vertical depth 9054.62-9051.54 feet 9037.12-9033.64 feet 9020.86-9016.82 feet 9011.48-9010.82 feet 9002.39-8991.05 feet 8990.25-8989.46 feet 8986.36-8984.08 feet 8984.08-8981.5 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 31-9418 31-8367.5 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: CpN � NED 'N.OV 2 7-01 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 201 140 6487 0 413 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Explorator,❑ Development 0 • Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 ' Gas ❑ WDSPL,L] GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature Cet Phone 564-4424 Date 10/29/2013 V'LP /e/. RBDMS NOV - 4 `t:; Form 10-404 Revised 10/2012 Submit Original Only 0 • Packers and SSV's Attachment ADL0028284 1 SW Name i Type MD ND Depscription H-14B PACKER 6972 6109.85 7" Baker ZXP Top Packer H-14B PACKER 6974 6111.35 7" Baker ZXP Packer H-14B PACKER 9361 8234.18 4-1/2" Baker S-3 Perm Packer H-14B PACKER 9408 8278.36 5" Baker ZXP Top Packer Casing / Tubing Attachment ADLO 028284 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20"x 30" 33 - 113 33 - 113 LINER 2592 7"26#L-80 6974 - 9566 6191.12 - 8506.55 7240 5410 LINER 2690 4-1/2" 12.6# L-80 9408 - 12098 8358.13 - 8955.04 8430 7500 PRODUCTION 7107 9-5/8"47# L-80 31 - 7138 31 - 6309.3 6870 4760 SURFACE 2657 13-3/8" 72# L-80 32 - 2689 32 - 2688.86 4930 2670 TUBING 9387 4-1/2" 12.6# 13Cr80 31 - 9418 31 - 8367.5 8430 7500 • • • • o E rn o o -a - Q.= o N ° -.(ii 0) -0 r a) 7, E o C � - -0 ao `p "= o �' C >� Q T- COO - -- E co ca o -p ca u) Q i o > -° •C 0) () a) c - E -0 O E ° C 5 ° a) Y cc o - C C D O = ° (O m (O O E N \ E .N z2 O 2 � � � N .. 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N CO r r ,- r Daily Report of Well Operations ADL0028284 ***WELL SHUT IN UPON ARRIVAL***(E-LINE PERFORATING) INITIAL T/I/0=1650/200/0 PSI RIH W/6'x2-1/8"WEIGHT BAR (x3)/JARS SET AT 500#/GR/CCL/BULLNOSE TOOLS FALL SLOWLY AT 11600', TAG SOFT/STICKY TD AT 11657' PULLED 600#OVER PICK UP WEIGHT BEFORE TENSION LEVELED OUT RIH W/20'x2-7/8" 2906 HMX PJ OMEGA PERF GUNS (14' LOADED) INTERVAL 11444'-11458', CCL TO TOP SHOT=9.3', CCL STOP DEPTH=11434.7' ATTEMPTED TO MITIGATE OVERBALANCED CONDITIONS STARTED TAGGING SCHMOO AT SHALLOWER DEPTH DECISION MADE TO POOH, NO PERFORATIONS SHOT • WELL SHUT IN ON DEPARTURE, DSO NOTIFIED FINAL T/I/0=1100/200/0 PSI 9/16/2013 ***JOB CANCELED*** ***CONT FROM WSR 9/16/13*** RAN 3.25" CENT, TEL, SAMPLE BAILER LOCATED TUBING TAIL @10728' slm(10762'md)(+34' correction) SD @11258' SLM (11292'MD) RECOVERED SAMPLE OF SCHOOM/SOME CEMENT 9/17/2013 ***WELL S/I ON DEPARTURE*** ****WELL S/I UPON ARRIVAL**** (profile modification) DRIFTED W/ 3.25" CENTRALIZER, TEL, 3" SAMPLE BAILER, S/D @ 11,371' MD (sticky) (sample of schmoo) BRUSH SVLN W/3.85" CENTRALIZER, 4-1/2" BRUSH, 3.805" GAUGE RING SET 4-1/2" MCX-SSSV(serial# M-15, 1.30" bean) IN SVLN @ 1481' SLM / 1515' MD 9/26/2013 ****CONT. JOB ON 9/27/13**** ****CONT. JOB FROM 9/26/13****(profile modification) RAN 4-1/2" CHECK SET TO MCX @ 1515' MD (indicated good set) • PERFORMED PASSING DRAW DOWN /CLOSURE TEST 9/27/2013 ****WELL LEFT S/I &WELL TENDER NOTIFIED OF STATUS UPON DEPARTURE**** LL I MEE= 4-1/16'CIW • NOTES: WELL ANGLE >70°@ 10282". WaLI-EAD MCEVOY '*"4-1/2'CHROME TBG"' ACTUATOR BAKER C H-1 9 B OKB.13 EV= 82.25' BF.ELI%= 46.47' KOP= 3200' Max Angle= 98°n 1072T Datum MD= 10007' ' ' I 2190' 1-14-1/2"HES X MP,lb=3.813" Datum TVD= 8800'SS 120'CONDUCTOR,13=? —I 110' (,) GAS LFT MAFDRB.S 13-3/8"CSG,72#,L-80,D=12.347" H 2692' ST MD TVD I DEV I'TYPE( VLV LATCH PORT DATE Ld 4 3426 3417 16 WAG DOME RK ' 16 12/16/07 Minimum ID = 3.725" 9405' 3 6204 5594 41 WC SO RK ' 20 12/16/07 2 8114 7149 19 KBG2 DMY BK r 0 11/22/07 4-1/2" HES X NIPPLE 1 9271 8229 19 KBG2 DPW BK ' 0 11/22/07 9-5/8"X 7"BKR ZXP LTP H 6974' w/6'T/BS,D=7.5' I r / 9-5/8"MLLOUT WINDOW(H-14B) 7138'-7155' 9-5/8"X 7"BKR HMC —I 6992' LNR HGR,D=6.28" 9-5/8"WHF'STOCK(11/05/07) —I 7138' 9340' —14-1/2"FDS X a',D=3.813" 9-5/8"EZSV(11/03/07) — 7150' �- �/ 9361' —7"X 4-1/2"BKR S-3 5-1/2'TBG STUB(Tagged 11/03/07) IH 7505' ( PKR D= " 938¢' 1 14-1/2'HES X8 3.875 NI?D=3113' ESTIMATED TOP OF CEMENT H 9000' I Ili ••�•�•■1 9405' --4-1/2'HES XN NP,D=3.725" l - 1► 4444•A- - p..-•-.1- 1.4.. 19-5/8"CSG,47#,L-80,D=8.681' — 9981' ..j •• � ••i•4•4••►•`■ 9408' —7'X 4-1/2"BKR I-RD ►4►44•►♦ PERFORATION SIAVIMARY ►���►����4►•� ZXP LTP,D=4.43" ■•■•••■• REF LOG:MCN..1 STP ON 08/27/09 4 ••••1• ►•�1►OOi►441 ' 9418' --14-1/2''MEG,L D=4.00" ►4►44•►4 ANGLE AT TOP PET:89°@ 10420' •.'4 ►�i�i<►�iI 4 •••• 9431' —7"X5"BKR FlIAC ►4•44 ►♦ 4/ 44�4� Pbte:Refer to Production OB for historical pert data ►♦:444►♦ HGR,D=4.45"•SIZE SPF INTERVAL Opn/Sgz ATE SQZ :`':'�►441 441 LN2• 2-7/8" 6 10420-10480 0 10/03/13 4ii i14444� 8437 �-(5"X 4-1/2"XO,D=3.958" 2-7/8" 6 10600-10630 0 10/03/13 ►4444•• 2-7/8" 6 10725-10755 C 12/05/12 , 2-7/8" 6 10875-10905 C 12/05/12 , 2-7/8" 6 11100-11660 C 11/22107 3-3/8" 4 11718-11743 C 08/28/09 1--------1 10690' 1H4-1/2"BOT C BP(10/02/13) 2-7/8" 6 11795-11820 C 06103/11 ►�4�4� , 2-7/8" 6 11820-11845 C 06/03/11 I 1 - I 11990' H FISH:MILLED COBP(10/01/13) 4-1/2'TBG,12.6#,13CR 80 VAN TOP,.0152 bpf,D=3.958' 9418' 12012• —1 FISH:MLLED CIBP(12/05/12) 7"LNR,26#,L-80 BT-M,.0383 bpf,D=6.276" --1 9566' '4r4�4�* •►444444• FBTD —j 12013' ►4_4-4� 4-1/2"LW,12.6#,L-80 BT-M,.0152 bpf,D=3.958" 1—I 12098' DATE REV BY COMMENT'S DATE REV BY COMMENTS P UDHOE BAY UNIT r 1981 ? ORIGINAL COMPLETION 06/13/11 RIAll PJC CEP/REPEFFS(6/3/11) WELL. H-14B 12/15/89 D16 MVP 12/12/12 JJUJWD MILL CBP/CBP/ADPERFS(12/05/1: PERMT No:"2071160 06/24498+ '7 CTD SIDETRACK(H-14A) 10/10/13 ALMJMDMILLCBPI CEIRADFERFS(10/03/1: API No: 50-029-20580-03 11/24/07 D14 SIDETRACK(H-14B) SEC 21,T11N,R13E,1542'FN-&1265'FEL 12/17/07 TFA/SV GLV CJO 05/12/08 PGS/PJC DRLG DRAFT CORRECTIONS BP Exploration(Alaska) t STATE OF ALASKA AAA OIL AND GAS CONSERVATION COM ON JAN 04 2013 RE OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations L✓J Perforate U Other Li Mill CIIBP Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown Stimulate - Other ❑ Re -enter Suspended WeII❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development el Exploratory ❑ -- 207 -116 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20580 -03 -00 7. Property Designation (Lease Number): 8. Well Name and Number: - , ADL0028284 PBU H -14B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 12360 feet Plugs measured 11050 feet true vertical 8951.1 feet Junk measured 12014 feet Effective Depth measured 11050 feet Packer measured See Attachment feet true vertical 9004.69 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" x 30" 33 - 113 33 - 113 0 0 Surface 2657 13 -3/8" 72# L -80 32 - 2689 32 - 2688.86 4930 2670 Intermediate None None None None None None Production 7107 9 -5/8" 47# L -80 31 - 7138 31 - 6309.3 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10725 - 10755 feet 10875 - 10905 feet 11100 - 11660 feet 11718 - 11743 feet 11795 - 11820 feet 11820 - 11845 feet True Vertical depth 9020.86 - 9016.82 feet 9011.48 - 9010.82 feet 9002.39 - 8991.05 feet 8990.25 - 8989.46 feet 8986.36 - 8984.08 feet 8984.08 - 8981.5 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 31 - 9418 31 - 8367.5 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: MAR 11J1 R 0 1 20 13 Intervals treated (measured): swam ly{ 0 GU 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: 514 34894 2404 0 1243 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorL] Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPIJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC-❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry.Catrotic BP.Com Printed Name Garry Catron Title PDC PE Signature 1 aA.41- C'ii/ Phone 564 -4424 Date 1/4/2013 RBCAS JAN 07 V I/ r' I 1 °) , 3 Form 10 -404 Revised 10/2012 / Submit Original Only / / , • • Packers and SSV's Attachment ADL0028284 SW Name Type MD TVD Depscription H -14B PACKER 6972 6109.85 7" Baker ZXP Top Packer H -14B PACKER 6974 6111.35 7" Baker ZXP Packer H -14B PACKER 9361 8234.18 4 -1/2" Baker S -3 Perm Packer H -14B PACKER 9408 8278.36 5" Baker ZXP Top Packer Casing / Tubing Attachment ADLOO28284 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20" x 30" 33 - 113 33 - 113 LINER 2592 7" 26# L -80 6974 - 9566 6191.12 - 8506.55 7240 5410 LINER 2690 4 -1/2" 12.6# L -80 9408 - 12098 8358.13 - 8955.04 8430 7500 PRODUCTION 7107 9 -5/8" 47# L -80 31 - 7138 31 - 6309.3 6870 4760 SURFACE 2657 13 -3/8" 72# L -80 32 - 2689 32 - 2688.86 4930 2670 TUBING 9387 4 -1/2" 12.6# 13Cr80 31 - 9418 31 - 8367.5 8430 7500 • • • • Daily Report of Well Operations ADL0028284 ACTIVITYDATE I SUMMARY CTU #9 w/ 1.75 "CT. Job Scope: Mill CIBP, Set CIBP, AdPerf 60'. « <Job Continued from 12/2/2012 »> RIH w/ BOT milling assembly with 3.7" Piranha mill. Tag plug at 11,700'CTM ( +60' corr to ELMD). Mill on plug for 2hrs. Initially had 200 psi of motor work. Unable to reestablish motor work or stall when setting down wt. PU above perfs. Kill well down backside w/ 110 bbls of 1% Slick KCI w/ SafeLube, followed by 40 bbls of 60/40 to allow more WOB. Mill on HES CIBP for lhrs (3 total hrs) before first stall with -200 - 350 psi constant motor work. Subsequently able to push plug down hole. Work plug thru perfs with multiple stalls and dry pushes to PBTD at 11,954'CTM (12,014'ELMD). PU clean and PUH. Pull heavy at 11,551'CTM, come online down CT and drop plug. Tag plug at 11,553'CTM. Push plug back to PBTD while spinning. PU off fish and spin. Make dry pass thru bottom set of perfs w/o issues. Hang up at 11,541'CTM. Jars fire. RBIH dry. Tag at 11,592'CTM. Push dry to PBTD and lightly tag. PU 20' and kick on pumps. PUH dry. Slight overpull at 11,560'CTM. Run up /down 2 dry passes from 11,520' - 11,620'CTM w/o issues. POOH. RIH w/ PDS Mem GR /CCL in 2.375" Carrier & 2.5" JSN. Stopped at 11350. PUH to 11300'. Logged up to 10950'. Flagged pipe. Logged up to 9300'. POOH. * **FISH: Pushed Milled 4.5" HES CIBP to PBTD 11,952'CTM (12,012'ELMD). 12/3/2012 « <Job Continued on 12/4/2012 »> CTU #9 w/ 1.75 "CT. Job Scope: Mill C IBP, Set CIBP AdPerf 60'.,, « <Job Continued from 12/3/2012 »> Continue out of hole w/ logging string. Correct depth +7.5' to Tie -In Log SLB CCL /GR dated 27- Aug -09. RIH w/ HES 4 -1/2" EZSV CIBP. Correct depth at the flag to 10958.3'ELM. Set center element of CIBP at 11,040'ELM per Tie -In Log (11,050'ELM to Ref Log), top of plug 11,039'ELM ( Plug OAL 2.09'). POOH. RIH w/ 30' x 2 -7/8" PJ 2906 HMX Perf Guns. Tag top of CIBP and correct to 11,038.4'ELM bottom shot depth. PUH to 10,895'ELM and pumped ball. Perforate 10,865 10,895'ELM per Tie -In Log (10,875- 10,905'ELM to Ref Log). Had good indication of the gun firing. POOH. 12/4/2012 « <Job continued on 12/5/2012 »> CTU #9 w/ 1.75 "CT. Job Scope: Mill CIBP, Set CIBP, AdPerf 60'. « <Job Continued from 12/4/2012 »> POOH. At surface gun was fired. Perforate interval 10,865'- 10,895'ELM Tie -In Log (10,875- 10905' ELM to Ref Log). RIH w/ 30' x 2 -7/8" PJ 2906 HMX Perf Guns. Tag plug and correct to 11,038.4'ELM at bottom shot depth. PUH to bottom shot at 10,745'ELM. Pump 1/2" ball. Perforate interval 10,715'- 10,745'ELM Tie-In Log (10,725- 10,755' ELM to Ref Log). Good shot indication. POOH. Freeze protect well with 38 bbls of 60/40 methanol. 12/5/2012 « <Job Complete »> TREE 4 * 4 -1/16" CON « W2 NOTES: WELL ANGLE > 70° @ 10282'. V,VELLHEAD = MCEVOY • TBG `"` ACTUATOR= BAKER H — 1 4 B KB. E3.EV = 79.77' BF. ELEV = 46.4T KOP= 3200' Max x Angle = 98° 1072T Datum MD= 1000T ' ' 2190' 4 -1/2" HES X NP, 0= 3.813" Datum TVD = 8800' SS 120' OOhDUCTOR, D = ?_H 110' I GAS LET MANDRELS 113 -3/8" CSG, 72#, L-80, D= 12.347" H 2692' ST M) TVD DEV TYPE VLV LATCH PORT DATE 4 3426 3417 16 G DOME W " 16 12/16/07 Minimum ID = 3.725" 9405' WIG 6204 5594 41 MD SO RK ' 20 12116/07 2 8114 7149 19 KBG2 DW BK ' 0 11/22/07 4 -112" HES X NIPPLE 1 9271 8229 19 KBG2 DMY BK ' 0 11/22/07 9-5/8" X 7" BKRZXP LW 6974' F A w /6'TBS,0 =7.5" 1 / 9-5/8" M WINDOW OW (H -14B) 7138' - 7155' I 9-5/8' X r BKR HMC —I 6992' LNR HGR, 0 = 6.28 19 -5/8" WHPSTOCK (11 /05/07) H 7138' 1 1 9340' H4 -1/2" HES X NP, 0 = 3.813' I 9-5/8" EZSV (11/03/07) H 7160' ,_ 1 9361' 1 — 7 „ X 4-1/2” BKR S-3 PKR, D = 3.875° 15 -1/2" TBG STUB (Ta9ged 11/03/07) H 7606' , 1 9384' H4 -1/2" I- ES X NP, D = 3.813' 1 ESTMATEO TOP OF OJT H 9000' f , �••�•�• 4 ' I 0405' _-14 -1/2" HES XN MP D = 3.725" 1 1 9-5/8" CSG, 47#, L-80, D= 8.681" H 9981' , : , •1 •••�•�4 �•∎ 9408" 1-7" X 4-1/2" BKR HRD ►� ►.. ZXP LTP, 0 = 4.43" PENFORATON SUMMARY ►• ■••••• /•�∎ I , FU LOG: Mat/ STPON 08/27/09 ► �• � • ► 8418' H4-1/2" wLEG, ID= 4.00" I ►♦ ►•• •►♦ • ANGLE AT TOP PERF: 98° @ 10725 ► • ■ 9431' I— 7" X 5° BKR HNC Note: Refer to Production DB for historical perf data ► ••••• LN2 HGR, ID= 4.45" ! ......SPF,� f ig AL ••• '_..■ ■4.1.- SQZ ew 2 -718" 6 1 - 0755 0 12/05/12 •� ∎ ∎•� 943T HS" X 4 1!2" XO, ID= 3.958" I 2 -7/8' 6 10875 -10965 0 12/05/12 ► ' 2- 7100166 D— 1 3-3/5" 4 11718 - 11743 C 08/28/09 1 11050' 14-1/2* HES EZSV 2 -7/8" 6 11795 - 11820 C 06/03/11 " CFBP (12!05112) 2 -7/8" 6 11820 - 11845 C 06/03/11 v*-*- 1 . _.--, I4 -1/2" 1B0, 12.6#, 13CR_80 VAM TOP, .0152 bpf, D= 3.958" H 9418' 1 ibr' ( 12012' H IRSft Mt.LED CEP (12105/12) 1 17 LM, 26#, L -80 BT -M, .0383 bpf, D = 6.276" H 9666' * •• • 4 IPBTD —1 12013' •■■■■ I4 -1/2" LNR, 12.6#, 1-80 BT -M, .0152 bpf, D= 3.958' I-1 12098' DATE REV BY CX)M U4TS DATE REV BY COM ENTS PRUDHOE BAY UNT r 1981 ? ORIGINAL COMPLETION 09/09/09 RMEYTLH ACFE F (08/28/09) WELL: H-148 12/15/89 D16 MVP 06/27/10 KJB/ PJC ADPF32F (06/21/10) PERMIT No: '2071160 06126998 ? CTD SIDETRACK (Hi-14A) 07/05/10 KJB/ PJC ADPERF (06/28/10) API No: 50-029- 20580.03 11/24/07 D14 SIDETRACK (H -148) 06/13/11 HMI PJC C23NN' FEFERFS (6/3/11) SEC 21, T11N, R13E, 1524' Rt. 81265' FEL 12/17 /07 TFA/SV GLV CIO 12/12/12 JJL/JMO WILL C2 FK3BPIADFERFS (12/05/12) 05/12/08 PGS/PJC DRLG DRAFT CORRECTIONS _ 1 1 BP Bcploration (Alaska) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ao-)--1/6 18, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission 333 West 7 Avenue S ANNED AUG 0 8 2012 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB H -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H-01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H -05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 11-06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 I 11-11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 -p H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18/2010 1415 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 11-16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 11-18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 1-1-20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 1-1-25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H -26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 1-1-31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 11-32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 1-1-33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H -34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H -35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA _ 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H -38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 Schlumberger RECEIVED No. 5769 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Mil.. 9 6 20 � 1 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 ' Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Awoke Of & Gas Cons. CDmnikeiell Anchorage, AK 99501 Well Job # Log Descript Date BL Color CD H -17A BLPO -00119 PPROF W GHOST _ 10- Jul -11 1 1 14 -04A AV1P -00093 LEAK DETECTION LOG 9- Jul -11 1 1 E -01A BLPO -00121 PPROF W GHOST 12- Jul -11 1 1 III MPB -50 BCRJ -00096 RST WFL LOG 16- Jul -11 1 1 r,7-1(( H -14B BD88 -00113 PPROF W/ DEFT & GHOST 2- Jun -11 1 -'1 1 of 84 f OWDW -SW AV1P -00091 RST WFL LOG 16- Jul -11 1 1 06 -02A BL65 -00027 LDWG EDIT OF MCNL 4- May -11 1 1 15 -02B BJOH -00016 LDWG EDIT OF RST 1- Apr -11 1 1 P2 -41 BJOH -00020 LDWG EDIT OF RST 11- Apr -11 1 1 W -223 BCRJ -00086 LDWG EDIT OF USIT 18- May -11 N/A 1 W -202 BMSA -00005 LDWG EDIT OF USIT 30- Jan -11 N/A 1 06 -08A BCRD -00089 LDWG EDIT OF RST 6- Mar -11 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Explonatirmn (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center 1.52-1 2525 Gambell Street, Suite 400 V 900 E- Benson Blvd Anchorage, AK 99503 - 2838 I. Ati STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ^~ Exploratory ^ 207-1160 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number. Anchorage, AK 99519-6612 50-029-20580-03-00 8. Property Designation (Lease Number) : ~ $ 9. Well Name and Number ~PB H 14B ADLO-0282 4 - U 10. Field/Pool(s): OO PRUDH OE BAY FIELD /PRUDHOE OIL P L 11. Present Well Condition Summary: Total Depth measured 12360 feet Plugs (measured) None feet true vertical 8951.1 feet Junk (measured) None feet Effective Depth measured 12013 feet Packer (measured) 9361 true vertical 8962.96 feet (true vertical) 8314 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURACE - 110 Surface 2692 13-3/8" 72# L-80 SURFACE - 2692 SURACE - 2692 4930 2670 Intermediate Production 7138 9-5/8" 47# L-80 SURFACE - 7138 SURFACE - 6309 6870 4760 Liner 2592 7" 26# L-80 6974 - 9566 6191 - 8507 7240 5410 liner 2690 4-1 /2" 12.6# L-80 9408 - 12098 8358 - 8955 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR-80 SURFACE - 9413 SURFACE - 8368 Packers and SSSV (type, measured and true vertical depth) 7"X4-1/2" BKR S-3 PKR .. 9361 8314 12. Stimulation or cement squeeze summary: Intervals treated (measured): ;,~., w t ~ -s ;J '1 ~}~E ~(~~ '~ ~ zQ~~l Treatment descriptions including volumes used and final pressure: `~y~k~ ~ ~ 6~ (i'~~ GQl~ltt38t4fi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 481 25757 1506 1718 Subsequent to operation: SI 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 7/13/2010 ~,,,, ,,,-~„Y,.~~„~,. „~..,,~ RBDMS .IUL 1 ~ 20~1~~~'fiv„ ~'' 7-/9-/a H-14B 207-116 DFRG ATTA(_NMFNT LJ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-14B 11/22/07 PER 11,100. 11,660. 9,002.39 8,991.05 H-14B 8/28/09 APF 11,718. 11,743. 8,990.25 8,989.46 H-14B 6/21/10 APF ,.~ 11,820. 11,845. 8,984.08 8,981.5 H-14B 6128/10 APF 11,795. 11,820. 8,986.36 8,984.08 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 • • H-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY j 6/20/2010 `**WELL SHUT IN ON ARRIVAL"""(E-LINE TRACTOR PERFORATING) ~ ~ INITIAL T/I/0= 1980/350/50 PSI l ~ INITIAL VALVE POSITIONS: SWAB/ WING/ SSV= CLOSED MASTER= OPEN ~ RUN 1: 2-7/8" DUMMY RUN WITH WELLTEC 318 XR TRACTOR REACHED 11864' ~ ""* JOB CONTINUED ON 21-JUNE-2010""" 6/21/2010 *** JOB CONTINUED FROM 20-JUNE-2010*** (ADPERF TRACTOR ) RUN 2: 25' OF 2-7/8" POWERJET. 60 DEG PHASING, 6 SPF BREACHED 11870' AFTER SUBSEQUENT RUNS TO TD WITH THE TRACTOR JEWELRY LOG PULLED FROM TD TO 9100'. GUN 1 SHOT INTERVAL: 11820'-11845'. TAGGED TD AT 11,911'. POOH NOTICED INTERVALS OF DAMAGED 0.44" SLICABLE DUE TO BEING GAS CUT. SNOT ABLE TO PROCEED WITH RUN 3 (25' OF 2-7/8" POWERJET. 60 DEG PHASING, 6 SPF FROM 11795'-11820'). TELEMETRY ISSUES AROUND 2300' IN THE HOLE. POOH TO INSPECT. ""*JOB CONTINUED ON 22-JUNE-2010*"'' 6/22/2010 "** JOB CONTINUED FROM 21-JUNE-2010*"* FINAL T/I/0= 2000/350/50 PSI FINAL VALVE POSITIONS: SWAB/WING/SSV= CLOSED MASTER= OPEN *"*JOB POSTPONED DUE TO CABLE DAMAGE AND RIG MOVE. JOB NOT COMPLETE*"* 6/26/2010 ""*WELL SHUT-IN ON ARRIVAL"**(ELINE -ADPERF) INITIAL T/I/O = 1800/350/0 RIG UP WITH CH2 60 TON CRANE, PERFORM SURFACE CHECKS, ARM GUNS, RIH. ***JOB IN PROGRESS AND CONTINUED ON 27 JUNE 2010**" . ~ • 6/27/2010***JOB CONTINUED FROM 26 JUNE 2010**" RIH WITH 25' 2-7/8" PERF GUN, UNABLE TO TIE IN WITH CCL, POOH. FIND EXCESSIVE AMOUNT OF METAL SHAVNGS AND DEBRIS ON CCL. RU ~GR/CCL WITH 25' GUN AND RIH. UNABLE TO TIE IN, POOH. *''*JOB IN PROGRESS AND CONTINUED ON 28 JUNE 2010"'** 6/28/2010''*"JOB CONTINUED FROM 27 JUNE 2010"** RIG DOWN GUNS, CHECK HEAD, NO PROBLEMS, WILL SEND GAMMA ITOOL IN FOR ET TO CHECKOUT. STAB ON AND POP WELL FOR 4.5 HRS TO FLOW DEBRIS OUT. PERFORATE INTERVAL 11795'-11 20' WITH 2-7/8" HSp POWER JET HMX 2906, 6 SPF, 60 DEG PHASING. DEPTH REFERENCED TO SLB MEMORY ~CNL DATED 27-AUG-2009. GUN API DATA: PENETRATION = 25.3", `ENTRANCE HOLE = 0.38" SSV = C, WV = C, SV = C, MV = O, IA/OA = OTG FINIAL T/I/O = 2150/380/0, ***WELL SHUT-IN ON DEPARTURE. JOB COMPLETE*** FLUIDS PUMPED BBLS 5 DIESEL 5 Total TREE= ~ ~ + 4-7/16" CMJ WELLHEAD= MCEVOY ACTUATOR = BAKER C KB. ELEV = 79.77' BF. ELEV = 46.47' KOP = 3200' Max Angle = 98° @ 10727' Datum MD = 10007' Datum TVD = 8800' SS 20" CONDUCTOR, ID = ? 110' 13-3/8" CSG, 72#, L-80, ID = 12.347" -~ 2692' Minimum iD = 3.725" @ 9405' 4-1i2" HES X NIPPLE 9-5/8" X 7" BKR ZXP LTP 6974' 9-5/8" X 7" BKR HMC~ 6992' LNR HGR, ID = 6.28" 9-518" WHIPSTOCK (11/05/07) ~9-5/8" EZSV (11/03/07) ~ 5-1/2" TBG STUB (Tagged 11/03/07) i ESTIMATED TOP OF CEMENT 4-1/2" HES X NIP, ID = 3.813" ' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" ' ~ 4-1/2" HES X NIP, ID = 3.813" 9405 i-i4-1/2" HES XN NIP, ID = 3.725" 9-5/8" CSG, 47#, L-80, ID = 8.681" PERFORATION SUMMARY REF LOG: MCNL/ STP ON 08/27/09 A NGLE AT TOP PERF: 93° @ 11100' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 2-7/8" 6 11100 - 11660 O 11!22/07 3-3/8" 4 11718 - 11743 O 08/28/09 2-7/8" 6 11795 - 11820 O 06/28/10 2-7/8" 6 11820 - 11845 O 06/21/10 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, . 152 bpf, ID = 3.958" -L 7" LNR 26#, L-$0 T-M, .0383 bpf, ID = 6.276" 1 - - 4-1/2" LNR, 12.6#, L- 0 IBT-M, .0152 bpf, ID = 3.958" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3426 3417 16 MMG DOME RK 16 12/16/07 3 6204 5594 41 MMG SO RK 20 12(16/07 2 8114 7149 19 KBG2 DMY BK 0 11!22107 1 9271 8229 19 KBG2 DMY BK 0 11/22/07 9-5/8" MILLOUT WINDOW {H-14B) 7138' - 7155' DATE REV BY COMMENTS DATE REV BY COMMENTS 1981 ? ORIGINAL COMPLETION 09!09109 RMHITLH ADPERF (08/28/09} 12/15/89 D16 RWP 06/27/10 KJB/ PJC ADPERF (06/21/10} 06/24/98 ? CTD SIDETRACK (H-14A 07/05/10 KJB/ PJC ADPERF (06!28/10) 11/24/07 D14 SIDETRACK{H-14B) 12!17107 TFA/SV GLV GO 05!12108 PGS/PJC DRLG DRAFT CORRECT NS SAFET TES: WELL ANGLE ~ 70° @ 10282'. H -14 B ~~~ 4-1/ ROMETBG "" 2190 i~4-1/2" HES X NIP, ID = 3.813" 9408 1 7" X 4-112" BKR HRD ZXP LTP, ID = 4.43" 9418' 4-1/2" WLEG, ID = 4.00" 9431 LNR HGR, DHn14.4 ' 5" 9437 5" X 4-1/2" XO, ID = 3.958" PRUDHOE BAY UNTf WELL: H-146 PERMff No: ~L071160 API No: 50-029-20580-03 SEC 21, T11 N, R13E, 1524' FNL & 1265' FEL BP Exploration (Alaska) ,~ ~~ . rd ~: . ~.~ S ~ ~;'' ~ ~ r ~~~ ~ ~ ~ ~Y x ~; g :, zeFyk.. ~~ ~~ _ ,~„ MICROFILMED 6/30/2010 DO .NOT P LAC E ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfitm_Marker.doc 10/19/09 SchhMheripp NO. 5423 �. LUvJ Alaska Data &Consulting Services Company: State of Alaska Suite 40 2526 Gambell Street, 0 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 14- 23APS1 09AKA0035 OH MWD/LWD EDIT _ 0 - 04/29/09 1 1 14- 23APB2 09AKA0035 OH MWD/LWD EDIT 05/07/09 1 1 E -12 AZCM -00041 RS7 09/07/09 1 1 15-42B 02WY -00028 JMCNL — 08/29/09 1 1 B -1 AA AXBD -00043 MCNL 09/01/09 1 1 1- 25/K•22 12086685 RST 09/21/08 1 1 12 -05 11676951 CH EDIT PDC US 06/24/07 1 07 -21 AYS4 -00098 HST _ 09/18/09 1 1 5.134 AWLS -00039 CH EDIT PDC US 09/28/09 1 • H-148 B2WY•00026 MCNL 08/27109 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETU ING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data 8 Consulting Sery„es Petrotechnical Data Center LR2 -1 2525 Gambell Street, suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • 10101!09 Schiumberger NO. 5405 Alaska Data Consulting Services Company: State of Alaska 2525 Gambol! Street, Suite 400 Alaska Oil Gas Cons Comm Anchorage, AK 99503-2838 Jjj� Attn: Christine Mahnken ATTN: Bath °,\1,, 333 West 7th Ave, Suite 100 Anchorage, Al( 99501 Well Job 8 Log Description Date BL Color CD K -11 AY1M -00033 SBHP SURVEY /�a 09/12/09 1 1 L4 -30 AWL8-00031 PRODUCTION PROFILE je O f it"3•053 08/06/09 1 1 P2 -31 AP3O -00045 LDL /glLL_ "3-u 07/11/09 1 1 01 -29 ME-00009 PRODUCTION PROFILE f r 4(� 08/11/09 1 1 J -22A B69K -00013 PRODUCTION PROFILE j 08/30/09 1 1 1 �e t W-44 B14B -00071 INJECTION PROFILE 09/06/09 1 1 12 -25 B581-00010 INJECTION PROFILE j I L5 -33 AYKP -00051 SBHP SURVEY 5 08/22/09 1 1 l 5 GG!! 09/01/09 1 1 e P2-48 B69K -00015 SBHP SURVEY a, L9(, 11-- o 09/01/09 1 1 Z -28 669K -00016 INJECTION PROFIL V 3 49 t 09/19/09 1 1 0-02A AP3O -00054 IBP /LDL (+y� �r p 1 1 N -10A AX -00040 MEM PROD PROFILE u 08/25/09 1 W -24 AWJI -00044 MEM INJECTION PROFILE I 4q)8/15/09 1 1 V -03 r 82NJ•00021 MEM PROD PROFILE 09/03/09 1 1 H -14B B2WY -00026 MEM PROD PROFILE q. ..j 1 1 Pt -Ot AY1M -00031 INJECTION PROFILE I 6 06/20/09 1 1 P1 -05 8581 -00009 PRODUCTION PROFIL 08/20/09 1 1 1 NK -10 B2WY -00023 MEM INJECTION PROFILE 1 j el je Y 08/22/09 1 1 13 -27A 82ND -00019 MEMORY SCMT 19(4 '409 08/13/09 1 1 18 -02B 92WY -00021 MEMORY SCMT at ii ..p -1--a 08/19/09 1 1 NK -38A AYKP -00049 USIT p,( 08/77/09 1 1 06.09 SWL8.00028 USIT .r(,) 07/30/09 1 1 13 -03A 09AKA0150 OH MWD /LWD EDIT ay '7 V) 07/06/09 2 1 C-18B MCNL r 08/09109 1 1 1-35/0-25 B69K-00011 B69K -00011 RST i 08/26/09 1 1 04 -35A AX80.00025 MCNL a 69 6 pli 05/13/09 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2.1 2525 Gambell Srreot, Suite 400 900 E. Benson Blvd. 2 f Anchorage. AK 99503 -2838 STATE OF ALASKA ~° ALASKA IL AND GAS CONSERVATION COMMIS~ REPORT OF SUNDRY WELL OPERATIONS , ~,~, ,v,~=~ a~M:~qg4~~~~._~' ~. _ ~ ~a ~~~~' ~~ ~~ 20C~ 1. Operations Abandon Repair Well Plug Perforations Stimulate ,,~3i~j F : ~,r~ ~~r ~ ~,~ ^ ^ ^ ^ ~ ~ ~°~ ~ ~ . ., .~ , , e~~ Performed: Alter Casing ~ Pull Tubing~ Pertorate New Pool ~ Waiver~ Time Extension ~ x; :: , Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well ~ 2. Operator BP Exploration (Aiaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~elopment r Exploratory I~ 207-1160 ~ 3. Address: P.O. Box 196612 Stratigraphic I~ Service r 6. API Number: Anchorage,AK 99519-6612 50-029-20580-03-00 / 7. KB Elevation (ft): 9. Well Name and Number: 79.77 KB PBU H-14B ,, 8. Property Designation: 10. Field/Pool(s): ADLO-028284 ti PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12360 - feet Plugs (measured) None true vertical 8951.1 ~ feet Junk (measured) None Effective Depth measured 12013 . feet true vertical 8962.96 feet Casing Length Size MD ND Burst Collapse Conductor 110 20" Surface - 110 Surface - 110 SurFace 2692 13-3/8" 72# L-80 SurFace - 2692 Surface - 2692 4930 2670 Production 7138 9-5/8" 47# L-80 Surface - 7138 Surface - 6309 6870 4760 Liner 2592 7" 26# L-80 6974 - 9566 6191 - 8507 7240 5410 Liner 2690 4-1/2" 12.6# L-80 9408 - 12098 8358 - 8955 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 9418' 0 0 - Packers and SSSV (type and measured depth) 7" X 4-1/2" BKR S-3 PKR 9361' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,. T, r ~ ,~ ~ ~° , r.. ' - u. 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: 550 21949 3057 1488 Subsequent to operation: 14. Attachments: 15. Well Class after qroposed work: Copies of Logs and Surveys Run Exploratory f Development r Service r Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas r WAG r GINJ 1- WINJ r WDSPL (~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signatur Phone 564-4944 Date 9/1/2009 ~ Form 10-404 Revised 04/2006 '~ T~~ Submit Ori mal Onl C~-''~ ~~ ~ ~~~.. :?t~` 1. i_:~ ~~~9 It3 g ~,;:Yl~ ,~J~~y H-14B 207-116 PFRF oTTOCHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-14B 11/22/07 PER 11,100. 11,660. 9,002.39 8,991.05 H-14B 8/28/09 APF 11,718. 11,743. 8,990.25 8,989.46 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED 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 STRQDDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ... ~ u H-14B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY FLUIDS PUMPED BBLS 98 1% XS KCL W/0.6% SL 27 1 % KCL 35 50/50 METH 160 TOTAL DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071160 Well Name/No. PRUDHOE BAY UNIT H-14B Operator BP EXPLORATION (ALASKA) INC MD 12360 TVD 8951 Completion Date 11/24/2007 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN / ABI Well Log Information: tog/ Electr Data Digital Dataset Log Log Run TC/~" Med/Frmt Number Name Scale Media No D Asc Directional Survey t Directional Survey D C Las 15918 Induction/Resistivity i I pt LIS Verification C Lis 16093 Induction/Resistivity ~g Induction/Resistivity 25 Col '" og Induction/Resistivity 25 Col ~rED C 17127 See Notes Well Cores/Samples Information: API No. 50-029-20580-03-00 UIC N (data taken from Logs Portion of Master Well Data Maint • Interval OH / Start Stop CH Received Comments 33 12360 Open 1/16/2008 33 12360 Open 1/16/2008 i 6803 12359 Open 2/8/2008 LAS DRHO, RPM, FCNL, GR, NCNL, NPHI, RHOB, ~ ROP, RPD, RPS, RPS in PDF and EMF graphics 6802 12274 Open 4/10/2008 LIS Veri, GR, RPX, FET, ~ RPS, RPD, ROP, DRHO, RHOB, NPHI, FCNT, NCNT 6802 12274 Open 4/10/2008 LIS Veri, GR, RPX, FET, RPS, RPD, ROP, DRHO, RHOB, NPHI, FCNT, NCNT 6800 12360 Open 11/3/2008 MD ROP, DGR, EWR, ALD, CTN 20-Nov-2007 6800 12360 Open 11/3/2008 TVD ROP, DGR, EWR, ALD, CTN 20-Nov-2007 ~ 0 0 Open 11/3/2008 PDS, EMF and CGM of EWR logs Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /24/2008 Permit to Drill 2071160 Well Name/No. PRUDHOE BAY UNIT H-146 MD 12360 TVD 8951 ADDITIONAL INFORMATION Well Cored? Y /~ Chips Received? `~/-Pd~ Analysis 1`Fid~ Received? Comments: Completion Date 11/24/2007 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20580-03-00 Completion Status 1-OIL Current Status 1-OIL UIC N Daily History Received? ~/~~/~, N Formation Tops ~' N Compliance Reviewed By: __ Date: __ ~ ~ i) ~0 O • ~~ C WELL LOG TRANSMITTAL To: State of Alaska October 30, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: H-14B AK-MW-5356206 H-14B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20580-03 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-20580-03 Digital Log Images: 1 CD Rom 50-029-20580-03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 907-273-3536 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: 2.b~-fit(, ~ 1~ t 2~ ~ • WELL LOG TRANSMITTAL To: State of Alaska March 24, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: H-14B AK-MW-5356206 1 LDWG formatted CD rom with verification listing. API#: 50-029-2058003-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage: Alaska 99;~~18 ~. Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~0~-ll to ~ l ~64,~ i • ~~ Date 02-08-2008 Transmittal Number:92927 ..~ ~.~_ ~'•_ t.. a .., , _ 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 Contents 8-13BPB1 t ~'~--IoU l5 q ~ S- 8-13BPB2 l$.~--r6o l S~il~ 8-13BPB3 l8~-lam 159i~- I-14B c)U'a-- ll Co t~ g I ~' 14A c~U~-_ I p2 ! 59otD -214 uzcao~- -~ca -59a1 ~a~,~ 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 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 Saltmarsh, Arthur C (DOA) • Page 1 of I From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Monday, January 21, 2008 3:30 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU H-14B, PTD # 207-116, 50-029-20580-03-00 H i Art, Please reference the following well: Well Name: PBU H-14B Permit #: 207-116 AP! #: 50-029-20580-03-00 Top Perf MD: 11100' Bottom Perf MD: 11660' This well began Production on January 6, 2008 Method of Operations is: Flowing Date of Test: 01114/0$ Hours Tested: 6 24-Hour Rate /Oil-Bbl: 814 24-Hour Rate /Gas-Mcf: 21,364 24-Hour Rate /Water-Bbl: 6,372 Test Rate /Oil-Bbl: 204 Test Rate /Gas-Mcf: 5,341 Test Rate /Water-Bbl: 1,593 Choke Size: 68 Gas-0il Ration: 26,247 Flow Tubing Pressure: 860 Casing Pressure: 1,560 Oil Gravity-APi: 14 1/28/2008 STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COMSION ~~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG;~s~; ~ Q 2467 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoaaczs.TOS zoaACZS.>>o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One ~ 6:' e I I s: `'` ' ®Dev~ldj~I~C~'I~°^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Ab~pd. 11/24/2007 ~ 12. Permit to Drill Number 207-116 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded ~ 11r~2007 13. API Number 50-029-20580-03-00 - 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/19/2007 14. Well Name and Number: PBU H-14B' 1542 FNL, 1265 FEL, SEC. 21, T11N, R13E, UM Top of Productive Horizon: 994' FSL, 1004' FWL, SEC. 15, T11 N, R13E, UM 8. KB (ft above MSL): 79.77' - Ground (ft MSL): 45.05' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 735' FNL, 2317 FWL, SEC. 22, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 12013 8963 - Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 643329 y- 5959246 Zone- ASP4 10. Total Depth (MD+TVD) 12360 - 8951 16. Property Designation: ADL 028284 TPI: x- 645543 y- 5961825 Zone- ASP4 Total Depth: x- 646894 y- 5960122 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted inform tion er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25. 71): DIR / GR /RES / PWD, DIR / GR /RES / NEU /DEN / ABI ~~/DOSJG-' ~f3d~'~D ~~~ ~ ~ a 22. CASING, LINER AND CEMENTING RECORD CASING SETTINGDEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM S{ZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2692' Surface 2692' 17-1/2" 3720 cu ft Permafrost II 9-5/8" 47# L-80 Surface 71 Surface 6309' 12-1/4" 1410 cu ft Class'G' 130 cu ft PF'C' 7" 26# L-80 6974' 9566' 6191' 507' 8-1/2" 561 cu ft Class'G' 4-1 /2" 12.6# L-80 9408' 12098' 8358' 8955' 6-1 /8' 453 cu ft Class 'G' 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i (MD+TVD of Top & Bottom; Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-7/8" Gun Diameter, 6 spf 4-1/2", 12.6#, 13Cr80 9418' 9361' MD TVD MD TVD 11100' - 11660' 9002' - 8991' '25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED Freeze Protect w/ 155 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.): N/A Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 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 20 AAC 250.071. Ct7Mf'in?r{IOt~t .~ None !?~,'+~ ~~~. i=E~ `~ '~ 100 J~~ D~? -+y~` FOrm 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE /_' 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME M TVD Well Tested . ^ 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. Sag River 9589' 8528' None Shublik 9628' 8564' Sadlerochit 9721' 8646' Top CGL /Zone 3 9938' 8831' Base CGL /Top Zone 2C 10029' 8895' 25N /Top Zone 2B 10154' 8973' 25P 10161' 8976' 25P 11926' 8972' Formation at Total Depth (Name): Zone 26 10154' 8973' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~/ Signed Terrie Hubble ~ Title Drilling Technologist Date ~ ~~~ PBU H-14B 207-116 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal No. Drilling Engineer: phil Smith, 564-4897 INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well. completion report and 10-404 well sundry report when the downhole well design is changed. ITEM 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). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). 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 BP EXPLORATION Page 1 of 1 Leak-Off Test Summary Legal Name: H-14 Common Name: H-14 Test Date lest Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak Off Pressure (BHP) EMW 10/6/2007 FIT 7,147.0 (ft) 6,327,0 (ft) 9.20 (ppg) 590 (psi) 3,614 (psi) 11.00 (ppg) 11/12/2007 FIT 7,147.0 (ft) 8,526.0 (ft) 8.40 (ppg) 710 (psi) 4,430 (psi) 10.00 (ppg) r 1 ~J Printed: 12/5/2007 11:05:57 AM $P EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Ph ase Description of Operatjons 10/31/2007 20:30 - 00:00 3.50 RIGD P PRE RD rig floor -Skid rig floor to moving position -Move rig off well - Install front boosters and frames. 11/1/2007 00:00 - 15:00 15.00 MOB P PRE Move rig f/ well NGI-13A to H pad 15:00 - 16:00 1.00 RIGU P PRE Remove boosters -Install mouse hole and cellar doors 16:00 - 17:30 1.50 RIGU P PRE Position rig over well H-14 and shim 17:30 - 18:30 1.00 RIGU P PRE Skid rig floor to drilling position 18:30 - 20:00 1.50 RIGU P PRE RU rig floor -Spot and berm rock washer and tiger tank Accept rig at 20:00 11/1/2007 20:00 - 21:00 1.00 WHSUR P DECOMP ,RU DSM lubricator -Pull BPV - RD lubricator Filling pits w/ seawater Note: Tubing press = 0 psi / IA press = 0 psi 21:00 - 22:00 1.00 WHSUR P DECOMP RU on well to displace out freeze protect -Cont. filling pits w/ seawater 22:00 - 00:00 2.00 WHSUR N WAIT DECOMP Waiting on hard line crew: change out day - no crew available at the time requested 11/2/2007 00:00 - 02:30 2.50 WHSUR N WAIT DECOMP Wait on hard line crew 02:30 - 04:30 2.00 WHSUR P DECOMP MU wing valve flange and double annular valve -Spot and berm tiger tank - RU hard line and choke to tiger tank. Test w/ air. Test w/ seawater to 1,000 psi 04:30 - 07:00 2.50 WHSUR P DECOMP Pump 46 bbls seawater down IA, taking returns through tubing j to tiger tank and displacing diesel, 3.5 bpm / 370 - 400 psi - Swap lines -Pump 150 bbls seawater down tubing, taking returns to tiger tank, 3.5 bpm / 230 psi -Let diesel migrate in IA x 30 min -Pump 30 bbls seawater down tubing taking returns to tiger tank -Verify well dead- Blow down and RD lines. 07:00 - 10:00 3.00 WHSUR P DECOMP Install TWC -Test from below to 1 000 six 30 min. Test from above to 3,500 six 5 min. Chart tests. 10:00 - 12:00 2.00 WHSUR P DECOMP ND tree -Separate adapter flange -Back out /run in all LDS - Remove tree from cellar -Dry run XO to tubing hanger 12:00 - 15:00 3.00 BOPSU P DECOMP NU BOP and spacer spool 15:00 - 16:00 1.00 BOPSU P DECOMP Install extension on choke hose - RU to test BOP 16:00 - 20:30 4.50 BOPSU P DECOMP Test BOP and related equipment as oer BP / AOGCC r ulations. Test to 250 psi low - 3,500 psi high (annular preventer to 250 psi low - 2,500 psi high). Test w/ 4" test joint, and 5-1/2" test joint (top rams). Perform koomey test. Chart all tests. Test witnessed by WSL and Toolpusher. John Crisp, AOGCC rep, waived witness of test. 20:30 - 21:00 0.50 BOPSU P DECOMP RD testing equipment -Blow down choke and kill lines 21:00 - 22:30 1.50 WHSUR P DECOMP Install lubricator extension and RU DSM lubricator. Test to 500 psi -Pull TWC - RD DSM lubricator and lubricator extension 22:30 - 23:00 0.50 PULL P DECOMP MU spear assembly for 5-1 /2"tubing 23:00 - 23:30 0.50 PULL P DECOMP RIH and enoaae tubing hanger -Pull 5-1/2" tubing free w/ 162k rvvv tuivcna wciym ovn~ - rwi iuuniy nanyc~ w auiiaw 23:30 - 00:00 0.50 PULL P DECOMP Pump down tubing 40 bbls "Safe Surf O" pill followed by 50 bbls hot seawater - 425 gpm / 1,020 psi 11/3/2007 00:00 - 02:00 2.00 PULL P DECOMP Pump down tubing second 40 bbl "Safe Surf O" pill. Circulate surface to surface w/ 660 bbls of seawater - 500 gpm / 1,410 psi 02:00 - 03:00 1.00 PULL P DECOMP Disengage and LD spear -Break off and LD tubing hanger and two 5-1/2" pup joints 03:00 - 05:00 2.00 PULL P DECOMP POH and LD 5-1/2" 17# L-80 tubing to SSSV nipple (46 jts to this point), recovering control lines. Recovered 22 clamps and Printed: 12/4/2007 4:29:08 PM _~ \~ BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date from - 7o Hours Task Code NPT Phase Description of Operations 11/3/2007 03:00 - 05:00 2.00 PULL P DECOMP 3 SS bands 05:00 - 05:30 0.50 PULL P DECOMP Disconnect control lines f/ SSSV - RD control line spool 05:30 - 10:00 4.50 PULL P DECOMP Cont. POH and LD 5-1/2" 17# L-80 tubing and completion equipment. Total LD: 174 jts + 21.04' cut off jt, 2 GLMs, 1 SSSV nipple 10:00 - 11:00 1.00 PULL P DECOMP RD tubing tools -Mobilize EZSV to rig floor 11:00 - 13:30 2.50 DHB P DECOMP Spot and RU Schlumberger a-line unit 13:30 - 15:00 1.50 DHB N SFAL DECOMP Schlumberger solving problems with unit computer 15:00 - 17:00 2.00 DHB P DECOMP RIH w/ 8.5" gauge ring and junk basket - CCL/GR on a-line. Tag tubing stump @ 7,505'. POH 17:00 - 20:00 3.00 DHB P DECOMP RIH w/ 9-5/8" EZSV-CCL/GR on a-line. Run tie-in log. Set EZSV 7,150'. POH 20:00 - 20:30 0.50 DHB P DECOMP RD Schlumberger a-line 20:30 - 21:30 1.00 DHB P DECOMP .Test 9-5/8" caain to 3 500 six 30 min. Chart test. Blow down lines 21:30 - 22:30 1.00 BOPSU P DECOMP ND BOP 22:30 - 00:00 1.50 WHSUR P DECOMP ND tubing spool - C/O 9-5/8" pack off and tubing spool 11/4/2007 00:00 - 04:30 4.50 WHSUR P DECOMP C/O slip body in tubing spool - C/O 9-5/8" pack off - NU tubing spool -Test pack off to 3,800 psi x 30 min. 04:30 - 06:00 1.50 BOPSU P DECOMP NU BOP, choke line, riser and flow line 06:00 - 07:30 1.50 BOPSU P DECOMP Install test plug and RU to test -Test breaks at tubing spool and choke line to 250 psi low - 3,500 psi high. Chart test - RD testing equipment, pull test plug and install wear ring 07:30 - 14:00 6.50 STWHIP P DECOMP MU mule shoe + XO - PU and RIH 4" DP 1 x 1 f/ pipe shed to +/- 6,300' -Circulate string volume 2x, 420 gpm / 1350 psi 14:00 - 16:30 2.50 STWHIP P DECOMP POH 4" DP and stand back in derrick 16:30 - 18:30 2.00 STWHIP P DECOMP PU and MU drill collars and HWDP -RIH on 4" DP 1 x 1 f/ pipe shed to ,1600' 18:30 - 20:30 2.00 STWHIP N RREP DECOMP Replace chain on high drum clutch 20:30 - 23:30 3.00 STWHIP P DECOMP Cont. PU and RIH 4" DP 1 x 1 f/ pipe shed to 4,000' -Circulate string volume 2x, 420 gpm / 1000 psi 23:30 - 00:00 0.50 STWHIP P DECOMP POH 4" DP and stand back in derrick 11/5/2007 00:00 - 02:00 2.00 STWHIP P DECOMP Cont POH and standing back in derrick 4" DP, HWDP and DCs 02:00 - 02:30 0.50 STWHIP P DECOMP Mobilize mills and BHA tools to rig floor 02:30 - 06:30 4.00 STWHIP P WEXIT MU window milling assy. and whipstock - MU BHA 06:30 - 07:00 0.50 STWHIP P WEXIT Upload MWD 07:00 - 08:00 1.00 STWHIP P WEXIT RIH on DCs and HWDP -Shallow test MWD 08:00 - 13:00 5.00 STWHIP P WEXIT RIH on 4" DP to 7,000' 13:00 - 14:30 1.50 STWHIP P WEXIT Displace well to 9.2 ppg LSND mud 14:30 - 16:00 1.50 STWHIP P WEXIT Orient whipstock 70 deg right. Set anchor and shear off. EZSV tagged @ 7,162' drill pipe measurement. Top of whipstock @ 7,138' PUW 160k /SOW 145k 16:00 - 00:00 8.00 S I i win ow an n rat o e o , @ 7,155'. 372 gpm / 1250 psi - WOB 5-12k -Torque 4-13k @ 60 RPM - ROTW 152k 11/6/2007 00:00 - 04:30 4.50 STWHIP P WEXIT Drill rat hole to 7,185' and per Baker rep and Directional Driller. -P/U= 157K, SOW= 145K, ROT wt= 151 K. -W06= 12K, Tq on= 3-8K @ 160-180 RPM. -GPM= 385 @ 1400 psi. 04:30 - 06:00 1.50 STWHIP P WEXIT Circulate and condition mud. -Rotate & reciprocate to dress window per Baker rep. -Pump Hi Vis sweep. Circulate hole clean. Printed: 12/4/2007 4:29:08 PM $P EXPLORATION: Page 3 of 10 Operations Summary Report Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date..: From - To Hours Task Code NPT Phase Description of Operations 11/6/2007 06:00 - 07:30 1.50 STWHIP P WEXIT Stand back 1 std. R/U for FIT test. 07:30 - 09:00 1.50 STWHIP P 09:00 - 14:00 5.00 STWHIP P 14:00 - 15:30 I 1.501 STWHIPI P 15:30 - 16:30 1.00 STWHIP P 16;30 - 17:00 I 0.501 STWHIPI P 17:00 - 18:00 I 1.001 STWHIPI P 18:00 - 18:30 0.50 STWHIP P 18:30 - 20:00 1.50 STWHIP P 20:00 - 23:00 I 3.00 STWHIPI P 23:00 - 00:00 1.00 STWHIP P 11/7/2007 100:00 - 02:00 I 2.001 STWHIPI P 02:00 - 02:30 I 0.501 STWHIPI P 02:30 - 12:00 1 9.501 DRILL I P 12:00 - 19:30 I 7.501 DRILL I P 19:30 - 20:30 I 1.00 I DRILL I P 20:30 - 00:00 I 3.501 DRILL I P -Perform FIT test @ 6,327' tvd. -Impose 590 psi w/ 9.2 ppg mud wt. -EMW= 11.0 ppg -PASS. -R/D test equipment. WEXIT Cut & slip drilling line. Service Top Drive. WEXIT Flow check well -static. Pump dry job. -Mud wt in= 9.2 ppg, mud wt out= 9.2 ppg. -POH for drilling BHA. WEXIT Stand back HWDP. Start to UD milling BHA. WEXIT Down load MWD. Continue to L/D BHA. -Clean & clear Rig floor. WEXIT Funtion OPs. Pull wear ring. -Flush stack. Install wear ring. WEXIT Start to M/U BHA. WEXIT Up load to MWD. WEXIT Continue to M/U BHA. -RIH w/HWDP. -Surface test MWD @ 800' md. -GPM= 402 @ 760 psi. WEXIT RIH w/ 4" DP to 6,850' md. WEXIT MWD MAD Pass per Geologist. -MAD Pass f/ 6,850' to 6,950' md. -GPM= 350 @ 1300 psi. 150 - 170 fph. -Shaker screens 170s & 200s. -Mud wt in= 9.25 ppg. WEXIT Continue MWD MAD Pass to 7,130' md. -150 - 170 fph. GPM= 355 @ 1360 psi. WEXIT Obtain parameters. Record SPRs. -Orient 70-R. -No pumps through window. -Wash to bottom @ 7,185' and INT1 Directionally Drill ahead f/ 7,185' and to 7,674' md. -P/U= 165K, SOW= 150K, ROT wt= 158K, -RPM= 70, WOB= 10-15K, -Tq on= 5-7K, Tq off= 3K, -GPM= 474, Psi on= 2730, Psi off= 2510, -ADT= 5.88, AST= 3.68, ART= 2.20. -Mud wt=9.6 ppg. INT1 Continue to Directionally Drill F/ 7,674' and to 8,114' md. -Raised mud weight to 9.7 ppg due to 9.1 ppg gas cut mud at returns. INT1 MWD Mad Pass per geologist. -Relog 8,114' and to 8,064' md. -Relog 8,020' and to 7,970' md. -MAD Pass at drilling rate. INT1 Continue to Drill f/ 8,114' and to 8,328' md. -P/U= 183K, SOW= 159K, ROT wt= 174K, -RPM= 70, WOB= 10-15K, -Tq on= 5K, Tq off= 4K, -GPM= 480, Psi on= 3150, Psi off= 3040, -ADT= 6.86, AST= 2.02, ART= 4.84. Prfn[etl: 12/4/2007 4:'19:ON PM -BP EXPLQRATION Page 4 of 10 Qperations Summary Report Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hotars Task Code NPT Phase Description of Operations 11/7/2007 20:30 - 00:00 3.50 DRILL P INT1 -Shaker screens= 170s & 200s. -Mud wt=9.65 ppg. 11/8/2007 00:00 - 20:00 20.00 DRILL P INT1 Directionally Drill ahead f/ 8,328' and to 9,545' md. -P/U= 202K, SOW= 165K, ROT wt= 182K, -RPM= 70, WOB= 5-10K, -Tq on= 6K, Tq off= 4K, -GPM= 486, Psi on= 3540, Psi off= 3340, -ADT= 13.06, AST= 1.1, ART= 11.96. -Mud wt=9.7 ppg. 20:00 - 21:30 1.50 DRILL P INT1 Pump Hi Vis Sweep & circulate. -Recover formation samples for geologist. -GPM= 478 @ 3050 psi. RPM= 70. 21:30 - 22:00 0.50 DRILL P INT1 Drill f/ 9,545' and to 9,560' md. 22:00 - 23:30 1.50 DRILL P INT1 Circulate. -Recover formation samples for geologist. -GPM= 478 @ 3250 psi. RPM= 70. 23:30 - 00:00 0.50 DRILL P INT1 Drill f/ 9,560' and to 9,563' md. -Circulate. -Recover formation samples for geologist. -GPM= 469 @ 3130 psi. RPM= 70. -Shaker screens= 170s & 200s. -Mud wt in= 9.7 ppg, Mud wt out= 9.75 ppg. 11/9/2007 00:00 - 02:30 2.50 DRILL P INT1 Continue to Circulate. -Recover formation samples for geologist. -GPM= 465 @ 3030 psi. RPM= 70. -Drill to TD la 9.566' and / 8.507' tvd. -Circulate to recover formation samples for geologist. 02:30 - 05:30 3.00 DRILL P INT1 Flow check well -static. -Mud wt in= 9.7 ppg. Mud wt out= 9.75 ppg. -Pump out f/ 9,566' and to 7,155' and (window). -Pull through window to 7,130' and with no pumps. 05:30 - 07:30 2.00 DRILL P INT1 Flow check well -static -Circulate 1 1/2 bottoms up @ 475 gpm 2850 psi, R & R 80 RPM 07:30 - 09:00 1.50 DRILL P INT1 RIH to 9566' -Wash down last stand 09:00 - 12:00 3.00 DRILL P INT1 Pump high vis sweep - Circulate 3 bottoms up @475 gpm 3290 psi, R & R 80 RPM 12:00 - 15:00 3.00 DRILL P INT1 Flow check well -Static - Pump out of hole from 9566' to 7165' - 375 gpm 15:00 - 16:30 1.50 DRILL P INT1 POOH through shoe to 7100' - CBU 1 1/2 times @ 440 gpm / 2300 psi, R & R 80 RPM -Flow check well 16:30 - 20:30 4.00 DRILL P INT1 Pump dry job -POOH F/7100' T/808' -Stand back HWDP & DC's 20:30 - 21:30 1.00 DRILL P INT1 Download MWD - L/D MWD, motor and bit 21:30 - 00:00 2.50 CASE P LNR1 Clear rig floor -R/U for 7" 26# L-80 BTC-M casing 11/10/2007 00:00 - 04:30 4.50 CASE P LNR1 MU shoe track -Check float equipment - MU total 63 jts 7" 26# L-80 BTC-M liner, hanger and packer 04:30 - 05:00 0.50 CASE P LNR1 Circulate liner volume - 3 bpm @ 210 psi 05:00 - 08:00 3.00 CASE P LNR1 RIH with liner on 4" drill pipe to 7100' -Fill pipe every 10 stands - PU = 173K, SO =145K Printed: 12/4/2007 4:29:08 PM BP EXPLQRATION' Page 5 of 10' Operations Summary Report Legal Well Name: H-14 Common Well Name: H-14 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Start: 8/29/2007 Rig Release: 11 /24/2007 Rig Number: Date From - To Hours Task Code NPT Phase 11/10/2007 08:00 - 10:00 2.00 CASE P LNR1 10:00 - 11:30 1.50 CASE P LNR1 12:30 - 15:00 2.50 CASE P I I LNR1 15:00 - 17:00 I 2.001 CEMT I P I I LNR1 17:00 - 18:00 I 1.001 CASE P I I LNR1 18:00 - 22:00 I 4,001 CASE I P I I LNR1 22:00 - 00:00 2.00 CASE P LNR1 11/11/2007 00:00 - 01:30 1.50 CASE P LNR1 01:30 - 02:00 0.50 CASE P LNR1 02:00 - 02:30 0.50 CASE P LNR1 02:30 - 04:30 2.00 CASE P LNR1 04:30 - 05:00 0.50 CASE P LNR1 05:00 - 07:00 2.00 CASE P LNR1 07:00 - 08:00 1.00 CASE P LNR1 08:00 - 10:00 2.00 CASE P LNR1 10:00 - 11:30 1.50 CASE P LNR1 11:30 - 13:00 1.50 DRILL P PROD1 13:00 - 15:30 2.50 DRILL P PROD1 15:30 - 19:30 4.00 DRILL P PROD1 19:30 - 21:00 1.50 DRILL P PROD1 21:00 - 22:30 1.50 DRILL P PROD1 22:30 -00:00 I 1.501 DRILL I P I I PROD1 111/12/2007 100:00 - 02:00 I 2.001 DRILL I P 02:00 - 03:00 I 1.001 DRILL I P 03:00 - 05:00 2.00 DRILL P 05:00 - 06:00 1.00 DRILL P 06:00 - 12:00 6.00 DRILL P 12:00 - 00:00 12.00 DRILL P PROD1 Spud Date: 5/17/1981 End: Description of Operations Circulate and condition mud @ shoe - 3 bpm / 320 psi RIH with liner from 7100' to 9566' -Fill pipe every 10 stands and wash last stand down Space out with pup jt and single - MU cement head Circulate and condition mud - PU = 225K, SO = 160K, 3 bpm @ 480 psi - 20' reciprocation PJSM -Cement per plan - 5 bbls water -test lines to 4000 psi - 30 bbls 10.5 ppg mud push - 100 bbls 15.8 class G cement -Drop dart - 10 bbls water -displace. with rig 159 bbls -Cement in place @ 1700 hours Set packer with 3000 psi -Bled off -Checked floats -Released from packer -Pressured to 1000 psi - Unsting from tie back sleeve with pressure and pumping -Weight set liner top packer with 50K down weight while pumping 30 spm Continue circulate excess cement and contaminated mud out of hole 315 gpm 870 psi - LD cement head - (appr. 5 bbls cmt Pump dry job -POOH to 2800' Continue POOH from 2800' LD packer running tool MU muleshoe &RIH with flex drill collars and HWDP from derrick RIH singles from pipeshed 72 joints Circulate pipe volume 300 gpm / 530 psi Cut and slip drill line and service top drive POOH -rack 24 stands drill pipe in derrick L/D 6 3/4" DC and 5" HWDP R/U -Test 9.625" X 7" liner to 3500 psi for 30 minutes on _Paecarl _ Rn tac# anuinman# drilling assembly to rig floor MU BHA #4 RIH from 362' to 9080' -Fill pipe every 25 stands Wash and ream from 9080' to 9469' - Taoaed cement C~ 9479' Drill cement from 9469' to 9479' -Drill shoe track from 9479' to 9561' - 245 gpm / 1830 psi, 55 RPM, 7 TO on, 5 TO off, PU 210, SO 145 PJSM -Displace well with 8.4 ppg Flo Pro mud per plan - 35 bbls H2O, 50 bbls hi-vis sweep, 35 bbls H2O, 50 bbls hi-vis sweep, new 8.4 ppg mud @ 245 gpm 1900 psi Continue displacing to 8.4 ppg Flo Pro mud - R&R - 6 bpm 1490 psi 50 RPM PROD1 Drill out shoe and 20' new hole to 9586' - PU 185, SO 112, ROT 170, 245 gpm, 1420 psi, 50 RPM, 5 TO PROD1 Circulate bottoms up - 245 gpm, 1400 psi PROD1 R/U -Perform F.I.T test t 10 EMW PROD1 Drill (/9,586' to 9,745' With Drilling Parameter of up weight=190,000#, down weight=160,000#, rotating weight=170,000#, wob=15,000#, 250 gpm, 1420 psi, off bottom, 1,680 psi on bottom, torque 2,000 ft-Ibs w/10 rpm, AST=2.68, ART=1.03, ADT=3.71 hrs. PROD1 Continue to drill from 9,745' to 1.0,185'. Drilling Parameters up weight=200,000#, down weight=155,000#, rotating weight=175,000#, torque on bottom=4,000 to 7,000 ft-Ibs, Printed: 12/4/2007 4:29:08 PM i +~ BP EXPLORATION Page'6 of 1a Opelrations Slumllnary Report. Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 11/12/2007 12:00 - 00:00 12.00 DRILL P PROD1 torque off bottom 4,000 ft-Ibs, pump pressure on bottom=2,020 psi, pressure off bottom=1,730 psi. ART=2.41, AST=3.02, ADT=5.43 hrs. 11/13/2007 00:00 - 05:00 5.00 DRILL P PROD1 Directionally Drilling 6.125" hole from 10,185' to 10,224'. Poor drilling rate, Circulated sample up. 05:00 - 06:00 1.00 DRILL P PROD1 Pump out of hole to shoe. 06:00 - 06:30 0.50 DRILL P PROD1 Monitor well 06:30 - 12:00 5.50 DRILL P PROD1 POOH to 360' standing back drill pipe. 12:00 - 14:30 2.50 DRILL P PROD1 Rack Back HWDP, NMDC, Change out elevators, break out and change bit (1/2" under gage). Down load MWD. 14:30 - 18:30 4.00 DRILL P PROD1 RIH f/362' to 9,946' with Drill Pipe. 18:30 - 19:30 1.00 DRILL P PROD1 Reaming as precaution f/9,946' to 10,224' 250 gpm, 1480 psi, 40 rpm. 19:30 - 00:00 4.50 DRILL P PROD1 Drilling from 10,224' to 10,356' Drilling rate 266 gpm, 1750 psi on bottom, 1570 psi off bottom, 40 rpm, torque off bottom 4,000 ft-Ibs, torque on bottom 4-7,000 ft-Ibs. AST= 1.57hrs, ART=O, ADT=1.57 hrs. 11/14/2007 00:00 - 16:00 16.00 DRILL P PROD1 Directional Drill f/ 10,356', U10,865', Drilling Parameters: up weight=190,000#, down weight=150,000#, 262 gpm, 1960 psi on bottom, 1740 psi off bottom, 10-15,000# wob, torque 3-4,000 ft-Ibs off bottom, 4-7,000# ft-Ibs on bottom, AST= 4.04 hrs, ART=4.04 hrs, ADT=8.08 hrs. 16:00 - 18:00 2.00 DRILL P PROD1 L/D 1jt drill pipe, circulate hole clean, P/U 1jt drill pipe, monitor well bore. 18:00 - 19:30 1.50 DRILL P PROD1 Pump out of hole to shoe, f/10,865' U9,564', 262 gpm, 1,620 psi on pumps. 19:30 - 21:00 1.50 DRILL P PROD1 Flow check well bore, CBU at 262 gpm with 1620 psi on pumps. 21:00 - 00:00 3.00 DRILL P PROD1 Blow down top drive, POOH f/9,564' U2,073'. 11/15/2007 00:00 - 01:00 1.00 DRILL P PROD1 Continue to POOH f/2,073' to BHA standing back drill pipe in derrick. 01:00 - 01:30 0.50 DRILL P PROD1 Stand back HWDP and 4 3/4" drill collars. 01:30 - 02:30 1.00 DRILL P PROD1 Down loading MWD tools. 02:30 - 03:00 0.50 DRILL P PROD1 Break out bit, UD motor and MWD. 03:00 - 03:30 0.50 DRILL P PROD1 Pull wear bushing and set test plug, R/U to test BOPE. 03:30 - 08:00 4.50 BOPSU P PROD1 PJSM -Pressure testin BOPE to 250 si low test and 3 500 si hi h test for all BOP rams and Choke Valves, 250 psi low test and 2,500 psi high test for Annular Preventer. All tests held for 5 charted minutes. Test witnessed by BP Well Site Leader, Doyon Tool Pusher, and AOGCC Representitive Lou Grimaldi. 08:00 - 09:00 1.00 BOPSU P PROD1 RD test equip. -Pull test plug -Install wear ring 09:00 - 09:30 0.50 DRILL P PROD1 PJSM -Mobilize BHA to rig floor 09:30 - 11:00 1.50 DRILL P PROD1 MU bit, motor, float sub, MWD DM, TM, Gamma, Neu 11:00 - 13:00 2.00 DRILL P PROD1 Upload MWD -PJSM -Load sources -RIH w/ Dc's, HWT, Jars 13:00 - 13:30 0.50 DRILL P PROD1 PU 12 joints 4" DP f/ shed 13:30 - 14:00 0.50 DRILL P PROD1 Shallow pulse test MWD - OK 14:00 - 15:30 1.50 DRILL P PROD1 Slip and cut drilling Tine -Service rig -Secure service loops on TD -Adjust brakes 15:30 - 20:30 5.00 DRILL P PROD1 RIH f/768' U10,425' filling drill pipe every 25 stds. 20:30 - 00:00 3.50 EVAL P PROD1 MAD PASS at 100' or less per hour, f/10,425' U10,163'. Up weight=205,000#, Down weight=150,000#, 258 gpm, 1,500 psi. 11/16/2007 00:00 - 01:30 1.50 EVAL P PROD1 Continue to MAD PASS Logging, Upweight=205,000#, Down weight=150,000#, Rotating weight=175,000#, 262 gpm, 1,490 Printed: 12/4/2007 4:29:08 PM BP EXPLORATION Page 7 of 10 'Operations. Summary Report Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task ' Code NPT Phase Description of Operations 11/16/2007 00:00 - 01:30 1.50 EVAL P PROD1 psi. 01:30 - 02:00 0.50 DRILL P PROD1 RIH f/10,069' U10/865', Washing down last stand drill pipe. 02:00 - 12:00 10.00 DRILL P PROD1 Directionally Drilling 6.125" hole f/10,865' U11,350', Up weight=195,000#, Down weight=155,000#, Rotating weight=175,000#, 262 gpm, 1,550 psi off bottom, 1,880 psi on bottom, 4,000 ft-Ibs torque off bottom, 5,000 ft-Ibs torque on bottom, 80 rpm, 5-10,000 wob. 12:00 - 00:00 12.00 DRILL P PROD1 Continue to Directionally Drill 6.125" Hole Section, f/11,350' U11,795'. Drilling Parameters: Upweight=195,000#, Down Weight=151,000#, Rotating weight=180,000#, 266 gpm, 1,900 psi on bottom, 1,580 psi off bottom, 70 rpm, Torque off bottom= 5,000 ft-Ibs, Torque on bottom=6-7,000 ft-Ibs, AST=2.63 hrs, ART=3.66 hrs, ADT=6.29 hrs . 11/17/2007 00:00 - 09:00 9.00 DRILL P PROD1 Continue to Directionally Drill 6.125" Hole Section, F/11,795' U11,974'- Drilling Parameters: Up weight=195,000#, Down Weight=151,000#, Rotating weight=180,000#, 266 gpm, 1,900 psi on bottom, 1,580 psi off bottom, 70 rpm, Torque off bottom= 5,000 ft-Ibs, Torque on bottom=6-7,000 ft-Ibs. 09:00 - 11:00 2.00 DRILL P PROD1 ROP diminishing. Pulling bit at this time to change MWD and check bit. 50% of the trip time, plus LWD handling and the MAD pass over 11,974 - 10,973' will be coded NPT. Pump sweep - 266 gpm, 1740 psi - R&R Dp 90' strokes, 80 rpm 11:00 - 14:00 3.00 DRILL N DFAL PROD1 Pump out to 7" shoe w/ full drilling rate. 14:00 - 15:00 1.00 DRILL N DFAL PROD1 CBU, at the 7" shoe, Rotating and Reciprocating drill pipe, pumping at 275 gpm and 1,500 psi. 15:00 - 19:00 4.00 DRILL N DFAL PROD1 Monitor well, blow down, POOH f/9,497' to U387'. 19:00 - 19:30 0.50 DRILL P PROD1 Rack back HWDP, Jars, and Drill collars. 19:30 - 21:30 2.00 DRILL P PROD1 PJSM with rig crew and MWD hands, Remove Source, Down load MWD. 21:30 - 22:30 1.00 DRILL N DFAL PROD1 M/U Bit, C/O LWD ADL Tool, Orient same. 22:30 - 23:00 0.50 DRILL N DFAL PROD1 Program MWD. 23:00 - 00:00 1.00 DRILL P PROD1 load Source, RIH with Drill Collars and HWDP. Shallow test MWD Tools. 11/18/2007 00:00 - 04:00 4.00 DRILL P PROD1 RIH f/387' U9,426' Filling drill pipe every 25 stands. 04:00 - 05:30 1.50 DRILL P PROD1 Slip and Cut drilling Tine, Service Top Drive. 05:30 - 07:00 1.50 DRILL P PROD1 Continue to RIH f/9,426' to 11,974' Washing last stand to bottom. 07:00 - 12:00 5.00 DRILL P PROD1 Continue to Drill f/11,974' U12,069' Parameters up weight=190,000#, down weight=150,000#, rotating weight=170,000#, 266 gpm, 2100 psi on bottom, 1750 off bottom, 7,000# wob, torque on bottom 6,000 ft-Ibs, torque off bottom 5,000 ft-Ibs. 12:00 - 00:00 12.00 DRILL P PROD1 Continue to Drill f/12,069' U12,275' Parameters up weight=192,000#, down weight=153,000#, rotating weight=170,000#, 270 gpm, 1,880 psi on bottom, 1,690 off bottom, 5-10,000# wob, torque on bottom 7- 8,000 ft-Ibs, torque off bottom 5,000 ft-Ibs. 11/19/2007 00:00 - 07:00 7.00 DRILL P PROD1 Continue to Directionally Drill f/12,275' U12,336' Parameters up weight=192,000#, down weight=153,000#, rotating weight=170,000#, 270 gpm, 1,860 psi on bottom, 1,700 off bottom, 5-10,000# wob, torque on bottom 7- 8,000 ft-Ibs, torque off bottom 5,000 ft-Ibs. 07:00 - 11:30 4.50 DRILL P PROD1 Pump Sweep, CBU 2x at 266 GPM, Rotating and Printed: 12/4/2007 4:29:08 PM BP EXPLORATION:.' Page 8 of 10 Operations SIUmIlnary Report Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING lNC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code . NPT Phase Description of Operations 11/19/2007 07:00 - 11:30 4.50 DRILL P PROD1 Reciprocating drill pipe, 80 RPM, 5,000 ft-Ibs Torque off bottom, Pumped and Spotted Lube Pill, Monitor Well Bore. AST=3.83 hrs, ART=.50 hrs, ADT=4.33 hrs. 11:30 - 12:00 0.50 DRILL P PROD1 POOH f/12,360' to 12,010' in preparation for MAD PASS l Logging. 12:00 - 13:00 1.00 DRILL P PROD1 MAD PASS Logging the 6.125" Hole Section f/12,010' to 11,875', at 300' per/hr. 13:00 - 21:00 8.00 DRILL N DFAL PROD1 MAD PASS Logging the 6.125" Hole Section f/11,875' to 11,245' at 100' per/hr. 21:00 - 23:00 2.00 DRILL N DFAL PROD1 MAD Pass Logging the 6.125" Hole Section f/11,245 to 10,973' 23:00 - 00:00 I 1.001 DRILL I P 11/20/2007 100:00 - 03:00 I 3.001 DRILL I P 03:00 - 03:30 I 0.501 DRILL I P 03:30 - 04:30 1.00 DRILL P 04:30 - 08:00 3.50 DRILL P 08:00 - 09:00 1.00 DRILL P 09:00 - 11:30 2.50 DRILL P 11:30 - 12:00 0.501 DRILL P 12:00 - 13:30 1.50 CASE P 13:30 - 17:00 3.50 CASE I P 17:00 - 18:00 1.00 CASE P 18:00 - 18:30 I 0.501 CASE I P 18:30 - 22:30 I 4.001 CASE I P 22:30 - 23:00 I 0.501 CASE I P 23:00 - 00:00 1.00 CASE P 11 /21 /2007 00:00 - 01:30 1.50 CASE P 01:30 - 02:30 I 1.001 CASE I P 02:30 - 04:30 2.00 CEMT P 04:30 - 05:00 0.50 CASE P at 300' per/hr PROD1 MAD Pass Logging the 6.125" Hole Section f/ 10,973' to 10,544' at 300' per/hr. PROD1 Continue to MAD PASS Logging f/10,544' to 9,980', 266 gpm, 1,480psi. PROD1 Continue to Pump Out of Hole to 9,566', Up Weight-185,000#, Down Weight=160,000#, at the 7" liner shoe. PROD1 CBU at the 7" Shoe, 266 gpm, 1,320 psi. Rotating and Reciprocating Drill Pipe at 40 rpms. PROD1 POOH from 9,566' - 387' PROD1 LD BHA - HWDP, jars, DC's -Flush MWD and motor w/ water PROD1 PJSM -Remove sources -Download MWD - LD MWD, motor, bit PROD1 Clear /Clean rig floor RUNPRD PJSM - RU casing equip -Tongs, elevators, slips, fill up line - Prepare pipeshed - MU safety valve -Bring centralizers and pup jt to rig floor RUNPRD MU and RIH 4-1/2" 12.6# L-80 IBT-M liner. Total jts. run: 65 RUNPRD PU and MU HMC Liner hanger - ZXP Liner Top Packer assy. Pour in polymer pill and let it set x 30 min. RUNPRD MU XO 3-1/2" IF pin x 4" HT38 box -RIH on one stand of 4" DP and circulate one liner volume, 5 bpm / 120 psi RUNPRD RIH 4-1/2" liner on 4" DP f/ 2,700' to 7" shoe @ 9,529' (7" shoe @ 9,566'). Fill pipe every 20 stands RUNPRD Circulate one DP + liner volume, 5 bpm / 660 psi. Take parameters PUW: 177k /SOW: 151k RUNPRD Cont. RIH 4-1 /2" liner on 4" DP f/ 9,529' to 10,766' RUNPRD Cont. RIH 4-1/2" liner on 4" DP f/ 10,766' to 12,100' - MU cement head and RU cement line RUNPRD Circulate and condition mud, 5 bpm / 1030 psi -Prepare perf pill. PUW: 205k /SOW: 150k RUNPRD PJSM -Schlumberger batch mix cement, cont. circulating. Give it to Schlumberger: - Pump and flush lines to floor w/ 5 bbls fresh water - Test lines to 4,000 psi - Pump 25 bbls 10.5 ppg Mudpush - Pump 81 bbls 15.8 class "G" cement slurry - Drop dart plug and switch to rig pumps RUNPRD Displace cement w/ 40 bbls 8.5 ppg perf pill and chase w/ 8.5 ppg mud. Bump plug. Total displacement: 141.6 bbls (includes pert pill used) Printed: 12/4/2007 4:29:08 PM BP EXPLORATION Page 9 of 10 Operations. Summary Report Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date I From - To I Hours I Task LCode (NPT ( Phase I Description of Operations 11/21/2007 04:30 - 05:00 0.50 CASE P RUNPRD CIP 05:00 11/21/2007 Note: reciprocate pipe 20' during displacement 05:00 - 05:30 0.50 CASE P RUNPRD Pressure up pipe to 4,000 psi and set liner hanger. Slack off 50k and confirm liner set. Shear dog sub and set ZXP Top Packer. Bleed pressure and check floats, OK. Pressure up to 500 psi and pull running tool out of assy. Liner top @ 9,408' -Top of Landing Collar @ 12,013' -Shoe @ 12,098' 05:30 - 07:00 1.50 CASE P RUNPRD Circulate out Mudpush and excess cement. Aprox. 10 bbls cement returns - LD cement head 07:00 - 10:30 3.50 CASE P RUNPRD Pump nut plug sweep and safe clean spacer -Displace well to clean seawater, 425 gpm / 2,090 psi -Blow down top drive - RU to reverse circulate -Reverse circulate surface-surface, 425 gpm / 2,220 psi -Flow check -Blow down kill line 10:30 - 16:00 5.50 CASE P RUNPRD POH 4" DP and rack back in derrick f/ 9,408' to 2,846' - LD 4" DP f/ 2,846' to Baker running tool. Total jts LD: 90 16:00 - 16:30 0.50 CASE P RUNPRD Service break running tool and LD -Clear rig floor 16:30 - 17:00 0.50 CASE P RUNPRD Load pert guns and 2-7/8 PAC DP in pipe shed 17:00 - 18:00 1.00 CASE P RUNPRD RU to test casing -Test 9-5/8" x 7" x 4-1 /2" to 3,500 psi x 30 min. Chart test - RD testing equipment and blow down kill line and choke line 18:00 - 19:00 1.00 PERFO P OTHCMP PJSM - RU pert gun handling equipment 19:00 - 20:00 1.00 PERFO P OTHCMP PU and RIH 2-7/8" pert guns assy to 608'. Total length of active guns: 560' 20:00 - 22:30 2.50 PERFO P OTHCMP PU and RIH 2-7/8" PAC DP 1 x 1 f/ 608' to 2,675' 22:30 - 00:00 1.50 PERFO P OTHCMP RIH on 4" DP f/ 2,675' to 6,472'. 11/22/2007 00:00 - 03:00 3.00 PERFO P OTHCMP Cont. RIH w/ pert guns assy on 4" DP f/ 6,472' to 11,978'. Check parameters PUW: 190k /SOW: 155k -Cont. RIH and tag landing collar @ 12,013' 03:00 - 03:30 0.50 PERFO P OTHCMP POH and osition erf uns in fr f' 1 ' 03:30 - 04:30 1.00 PERFO P OTHCMP PJSM -Fire guns as per Schlumberger procedure and perforate int. 11,100'-11,660'. Good indication of firing w/ noise detection tool. 04:30 - 06:00 1.50 PERFO P OTHCMP POH to 10,747', PUW: 190k -Blow down top drive and kill line -Cont. POH to top of 4-1/2" liner @ 9,408' 06:00 - 08:30 2.50 PERFO P OTHCMP CBU, 212 gpm / 1447 psi -Flow check -Pump dry job -Blow down top drive 08:30 - 11:30 3.00 PERFO P OTHCMP POH and LD 4" DP f/ 9,408' to 4,574' 11:30 - 12:00 0.50 PERFO P OTHCMP Lubricate rig 12:00 - 14:00 2.00 PERFO P OTHCMP Cont. POH and LD 4" DP f/ 4,574' to 2,678' 14:00 - 17:00 3.00 PERFO P OTHCMP PJSM -Change DP handling tools - MU XO to safety valve - LD 2-7/8" PAC DP 17:00 - 19:30 2.50 PERFO P OTHCMP PJSM - LD erf uns. All shots fired 19:30 - 20:00 0.50 PERFO P OTHCMP Clear rig floor of vendor tools and tubing tongs 20:00 - 22:00 2.00 PERFO P OTHCMP RIH remaining stands of 4" DP f/ derrick to 2,850' 22:00 - 23:00 1.00 PERFO P OTHCMP Cut and slip drilling line -Service top drive and blocks 23:00 - 00:00 1.00 PERFO P OTHCMP POH and LD 4" DP f/ 2,850' to 1,425' 11/23/2007 00:00 - 01:00 1.00 PERFO P OTHCMP Finish LD remaining 4" DP 01:00 - 01:30 0.50 PERFO P OTHCMP Drain stack -Pull wear ring 01:30 - 04:00 2.50 RUNCO RUNCMP PJSM - RU to run completion: c/o bales and elevators, RU compensator, stabbing board, power tongs, air slips, torque turn equipment. Note: high winds and weather conditions require extra caution Printed: 12/4/2007 4:29:08 PM $P EXPLORATION Page 10 of 10 Operatiolns 5lumllnary Report Legal Well Name: H-14 Common Well Name: H-14 Spud Date: 5/17/1981 Event Name: REENTER+COMPLETE Start: 8/29/2007 End: Contractor Name: DOYON DRILLING INC. Rig Release: 11/24/2007 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT 11/23/2007 01:30 - 04:00 2.50 RUNCO 04:00 - 20:00 16.00 RUNCO 20:00 - 21:30 1.50 RUNCO 21:30 - 22:30 1.00 RUNCO 22:30 - 00:00 1.50 RUNCO 11/24/2007 00:00 - 02:00 2.00 RUNCO 02:00 - 03:30 1.50 RUNCO 03:30 - 05:00 1.50 RUNCO 05:00 - 06:30 1.50 BOPSU P 06:30 - 10:00 3.50 WHSUR P 10:00 - 11:30 1.50 WHSUR P 11:30 - 13:00 1.50 WHSUR P 13:00 - 13:01 0.02 WHSUR N MISC 13:01 - 14:30 1.48 WHSUR P 14:30 - 16:00 1.50 WHSUR P 16:00 - 17:00 1.00 RIGD P Phase Description. of Operations RUNCMP when bringing equipment up beaver slide RUNCMP RIH 4-1/2" 12.6# 13Cr Vam Top tubing w/ completion equipment to +/- 9,400'. Bakerlok all connections below packer. Tum torque all connections. Check parameters PUW: 157k /SOW: 132k RUNCMP Tag bottom of tieback @ 9,422' -Space out - MU tubing hanger -Land tubing on tubing hanger and RILDS Bottom of WLEG @ 9,418' -Top of packer @ 9,360'. Total jts tubing run: 219 RUNCMP PJSM - RU to reverse circulate clean seawater w/ corrosion inhibitor RUNCMP Reverse circulate down IA clean seawater w/ corrosion inhibitor, 126 gpm / 300 psi RUNCMP Cont. reverse circulating clean seawater w/ corrosion inhibitor, 126 gpm / 300 psi RUNCMP Drop ball and rod -Pressure up tubing to 3,500 psi. Set packer and hold pressure x 30 min. Pressure drops 30 psi in 15 min, and total 50 si in 30 min. Chart test. MIT-T OK -Bleed tubin 10 1,500 si - Pressure u IA to 3,500 si and hold x 30 min. Pressure dro s total 20 si in 30 min no ressure dro in 15 _ min.. Chart test. MIT-IA OK -Bleed tubing pressure and shear DCR-1 valve -Bleed all pressure -Pump down IA taking returns through tubing, 126 gpm / 360 psi RUNCMP RD lines and LD landing joint -Set TWC -Test f/ below to 1,000 psi x 30 min. Chart test RUNCMP ND BOP, flowline, choke line - LD bales, etc. RUNCMP NU adapter flange -Tree -Test main body metal to metal seal to 5,000 psi f/ 30 min. -Test tree w/ diesel to 5,000 psi on chart. RUNCMP RU DSM lubricator -Test to 500 psi -Pull TWC - RD lubricator RUNCMP PJSM - RU Little Red -Test lines to 3,500 psi -Pump 155 bbls diesel freeze protect down IA taking returns out tubing - 2 bpm, 550 psi RUNCMP One Minute NPT in completion section for scorecard RUNCMP Allow diesel to U- tube into tubing RUNCMP RU and test lubricator -Install BPV -Test BPV from bottom to 1,000 psi - RD lubricator -Suck back lines - RD Little Red RUNCMP Secure tree. Rig released @ 17:00 11-24-2007 OA: 600 psi / IA: 0 psi / TBG: 0 psi Printed: 12/4/2007 4:29:08 PM Sperry Drilling Services Survey Report Company: BP AmoCO Date: 12/20/2007 Time: 11:26:15 Page: 1 Field: Prudhoe Bay Co-ordinate(NF,) Reference: Well: H-14, True No rth .:Site: PB H Pad Vertical{TVD) Reference: H-146: 79.8 Well: H-14 SeCdon (VSO Reference: Well (O.OON,O.OOE,1 50.OOAzi) Wellpath: H-14B Survey CalcuiationMethod: Minimum Curvature Db: Oracle Field: Prudhoe Bay North 51ope 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 Datmn: Mean Sea Level Geomagnetic Model: bggm2007 Well: H-14 Slot Name: 14 H-14 Well Position: +N/-S 1636.67 ft Northing: 5959246.00 ft Latitude: 70 17 46.149 N +E/-W 1994.21 ft Easting : 643329.00 ft Longitude: 148 50 21.676 W Position Uncertainty: 0.00 ft Wellpath: H-146 Drilled From: H-14 500292058003 Tie-on Depth: 7097.47 ft Current Datum: H-14B: Height 79. 77 ft Above System Datum: Mean Sea Level Magnetic Data: 11 /2/2007 Declination: 23.45 deg Field Strength: 57653 nT Mag Dip Angle: 80.89 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.30 0.00 0.00 150.00 Survey Program for Definitive Wellpath Date: 12/19/2007 Validated: Yes Version: 8 Actual From To Survey Toolcode Tool Name ft ft 97.47 7097.52 1 : Sperry-Sun BOSS gyro multi BOSS-GYRO Sperry-Sun BOSS gyro mu ltishot 7138.50 12316.51 H-14B IIFR+MS+Sag (7138.50-123 MWD+IFR+MS MWD +IFR + Multi Station Survey MD _Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool _ft deg deg ft ft ft ft ft ,ft 33.30 0.00 0.00 33.30 -46.47 0.00 0.00 5959246.00 643329.00 TIE LINE 97.47 0.65 160.81 97.47 17.70 -0.34 0.12 5959245.66 643329.13 BOSS-GYRO 197.47 0.63 157.11 197.46 117.69 -1.39 0.52 5959244.62 643329.55 BOSS-GYRO 297.47 0.57 158.50 297.46 217.69 -2.36 0.92 5959243.66 643329.96 BOSS-GYRO 397.47 0.38 165.50 397.45 317.68 -3.14 1.18 5959242.88 643330.24 BOSS-GYRO 497.47 0.50 172.11 497.45 417.68 -3.89 1.32 5959242.13 643330.40 BOSS-GYRO 597.47 0.57 160.11 597.45 517.68 -4.79 1.55 5959241.24 643330.64 BOSS-GYRO 697.47 0.58 146.31 697.44 617.67 -5.68 2.00 5959240.36 643331.11 BOSS-GYRO 797.47 0.63 120.41 797.44 717.67 -6.38 2.76 5959239.67 643331.88 BOSS-GYRO 897.47 0.80 110.00 897.43 817.66 -6.90 3.89 5959239.18 643333.02 BOSS-GYRO 997.47 0.70 108.61 997.42 917.65 -7.33 5.12 5959238.77 643334.26 BOSS-GYRO 1097.47 0.62 122.70 1097.41 1017.64 -7.82 6.16 5959238.30 643335.30 BOSS-GYRO 1197.47 0.47 131.50 1197.41 1117.64 -8.38 6.92 5959237.75 643336.08 BOSS-GYRO 1297.47 0.37 163.20 1297.41 1217.64 -8.96 7.32 5959237.18 643336.49 BOSS-GYRO 1397.47 0.37 198.69 1397.40 1317.63 -9.58 7.31 5959236.56 643336.49 BOSS-GYRO 1497.47 0.33 170.81 1497.40 1417.63 -10.17 7.25 5959235.97 643336.44 BOSS-GYRO 1597.47 0.27 184.39 1597.40 1517.63 -10.69 7.28 5959235.45 643336.48 BOSS-GYRO 1697.47 0.27 135.90 1697.40 1617.63 -11.09 7.43 5959235.05 643336.64 BOSS-GYRO 1797.47 0.43 124.50 1797.40 1717.63 -11.47 7.90 5959234.68 643337.12 BOSS-GYRO 1897.47 0.52 133.11 1897.39 1817.62 -12.00 8.54 5959234.17 643337.77 BOSS-GYRO 1997.47 0.37 130.90 1997.39 1917.62 -12.52 9.12 5959233.66 643338.35 BOSS-GYRO 2097.47 0.58 129.50 2097.39 2017.62 -13.05 9.75 5959233.14 643339.00 BOSS-GYRO 2197.47 0.52 139.90 2197.38 2117.61 -13.72 10.43 5959232.48 643339.69 BOSS-GYRO 2297.47 0.92 129.90 2297.38 2217.61 -14.58 11.34 5959231.64 643340.62 BOSS-GYRO 2397.47 0.73 132.40 2397.36 2317.59 -15.53 12.43 5959230.71 643341.72 BOSS-GYRO 2497.47 0.87 131.90 2497.35 2417.58 -16.46 13.46 5959229.80 643342.77 BOSS-GYRO 2597.47 0.87 158.90 2597.34 2517.57 -17.68 14.30 5959228.60 643343.63 BOSS-GYRO 2697.47 0.87 161.70 2697.33 2617.56 -19.11 14.81 5959227.18 643344.17 BOSS-GYRO 2797.47 0.83 82.90 2797.32 2717.55 -19.74 15.77 5959226.57 643345.14 BOSS-GYRO Sperry Drilling Services Survey Report Company: BP Amoco Date: 12/20!2007 Time: 11 :26:15 Page: 2 Field: Pru dhoe Bay Co-urilinate(NE) Reference: Well: H-14, True North Site: PB H Pad Verges ! (TVD} Refer ence: H-14B: 79.8 Nell: H-1 4 -Section (YS) Ieference: Well (O.OON,O.OOE,1 50.OOAzi) Wellpath: H-1 46 Survey Calculation Method: Minim um Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD N/S F,/W MapN MapF. 1'001 ft deg deg ' ' ft : ft ft ft _ft ft 2897.47 2.58 44.79 2897.28 2817.51 -18.05 18.08 5959228.30 643347.41 BOSS-GYRO 2997.47 4.90 32.70 2997.06 2917.29 -12.86 21.97 5959233.56 643351.21 BOSS-GYRO 3097.47 7.37 32.20 3096.48 3016.71 -3.84 27.69 5959242.69 643356.76 BOSS-GYRO 3197.47 10.32 30.00 3195.28 3115.51 9.35 35.59 5959256.03 643364.40 BOSS-GYRO 3297.47 12.87 34.40 3293.23 3213.46 26.30 46.37 5959273.18 643374.85 BOSS-GYRO 3397.47 15.23 30.10 3390.24 3310.47 46.86 59.25 5959293.97 643387.34 BOSS-GYRO 3497.47 16.77 25.00 3486.37 3406.60 71.30 71.93 5959318.65 643399.55 BOSS-GYRO 3597.47 19.42 25.00 3581.41 3501.64 99.44 85.06 5959347.04 643412.14 BOSS-GYRO 3697.47 22.73 25.10 3674.71 3594.94 132.02 100.28 5959379.89 643426.74 BOSS-GYRO 3797.47 25.72 25.70 3765.89 3686.12 169.07 117.89 5959417.28 643443.64 BOSS-GYRO 3897.47 28.62 25.70 3854.85 3775.08 210.21 137.69 5959458.78 643462.65 BOSS-GYRO 3997.47 31.32 25.70 3941.47 3861.70 255.22 159.35 5959504.19 643483.44 BOSS-GYRO 4097.47 34.08 25.60 4025.61 3945.84 303.92 182.74 5959553.32 643505.89 BOSS-GYRO 4197.47 36.85 26.00 4107.05 4027.28 356.15 207.99 5959606.02 643530.15 BOSS-GYRO 4297.47 40.40 26.00 4185.16 4105.39 412.24 235.35 5959662.62 643556.43 BOSS-GYRO 4397.47 42.08 26.20 4260.36 4180.59 471.44 264.35 5959722.36 643584.29 BOSS-GYRO 4497.47 42.27 26.50 4334.47 4254.70 531.60 294.15 5959783.07 643612.94 BOSS-GYRO 4597.47 42.55 27.29 4408.30 4328.53 591.75 324.66 5959843.79 643642.29 BOSS-GYRO 4697.47 42.77 28.50 4481.84 4402.07 651.64 356.37 5959904.26 643672.85 BOSS-GYRO 4797.47 42.65 28.79 4555.32 4475.55 711.16 388.88 5959964.40 643704.22 BOSS-GYRO 4897.47 42.48 28.60 4628.97 4549.20 770.50 421.36 5960024.33 643735.56 BOSS-GYRO 4997.47 42.35 29.20 4702.80 4623.03 829.55 453.96 5960083.99 643767.02 BOSS-GYRO 5097.47 42.22 29.39 4776.78 4697.01 888.22 486.88 5960143.28 643798.81 BOSS-GYRO 5197.47 42.42 30.10 4850.72 4770.95 946.68 520.28 5960202.36 643831.09 BOSS-GYRO 5297.47 42.82 30.50 4924.31 4844.54 1005.14 554.45 5960261.46 643864.13 BOSS-GYRO 5397.47 42.82 31.00 4997.66 4917.89 1063.56 589.20 5960320.52 643897.76 BOSS-GYRO 5497.47 42.87 31.50 5070.98 4991.21 1121.69 624.48 5960379.31 643931.92 BOSS-GYRO 5597.47 42.53 32.00 5144.47 5064.70 1179.36 660.16 5960437.64 643966.50 BOSS-GYRO 5697.47 42.55 31.70 5218.15 5138.38 1236.79 695.84 5960495.74 644001.07 BOSS-GYRO 5797.47 42.90 31.79 5291.61 5211.84 1294.49 731.54 5960554.10 644035.66 BOSS-GYRO 5897.47 42.48 31.10 5365.11 5285.34 1352.33 766.91 5960612.61 644069.92 BOSS-GYRO 5997.47 42.10 30.79 5439.09 5359.32 1410.04 801.51 5960670.96 644103.41 BOSS-GYRO 6097.47 41.95 30.70 5513.37 5433.60 1467.58 835.73 5960729.13 644136.53 BOSS-GYRO 6197.47 40.83 30.79 5588.40 5508.63 1524.40 869.53 5960786.59 644169.24 BOSS-GYRO 6297.47 40.37 31.00 5664.32 5584.55 1580.24 902.95 5960843.06 644201.58 BOSS-GYRO 6397.47 39.95 30.79 5740.75 5660.98 1635.59 936.06 5960899.01 644233.63 BOSS-GYRO 6497.47 39.07 30.79 5817.90 5738.13 1690.24 968.63 5960954.27 644265.15 BOSS-GYRO 6597.47 38.53 30.60 5895.83 5816.06 1744.12 1000.62 5961008.75 644296.10 BOSS-GYRO 6697.47 37.32 31.20 5974.71 5894.94 1796.86 1032.17 5961062.08 644326.64 BOSS-GYRO 6797.47 37.37 31.29 6054.21 5974.44 1848.72 1063.64 5961114.53 644357.11 BOSS-GYRO 6897.47 39.10 31.00 6132.76 6052.99 1901.69 1095.64 5961168.09 644388.10 BOSS-GYRO 6997.47 42.22 30.89 6208.61 6128.84 1957.57 1129.14 5961224.59 644420.52 BOSS-GYRO 7097.47 .45.12 31.39 6280.93 6201.16 2016.66 1164.85 5961284.35 644455.10 BOSS-GYRO 7138.50 46.04 31.52 6309.65 • 6229.88 2041.66 1180.15 5961309.63 644469.91 MWD+IFR+MS 7216.57 44.38 36.22 6364.66 6284.89 2087.65 1210.98 5961356.20 644499.86 MWD+IFR+MS 7313.26 40.38 42.68 6436.11 6356.34 2138.00 1252.23 5961407.32 644540.13 MWD+IFR+MS 7408.20 36.50 43.48 6510.46 6430.69 2181.11 1292.52 5961451.19 644579.59 MWD+IFR+MS 7500.87 34.11 43.37 6586.08 6506.31 2220.00 1329.33 5961490.78 644615.65 MWD+IFR+MS 7596.08 28.35 44.99 6667.46 6587.69 2255.43 1363.67 5961526.85 644649.31 MWD+IFR+MS 7691.34 25.78 46.59 6752.28 6672.51 2285.66 1394.72 5961557.67 644679.77 MWD+IFR+MS 7787.19 22.02 51.62 6839.91 6760.14 2311.15 1423.96 5961583.71 644708.52 MWD+IFR+MS 7881.85 19.14 58.72 6928.53 6848.76 2330.24 1451.14 5961603.31 644735.33 MWD+IFR+MS Sperry Drilling Services Survey Report Company: BP AmOCO Date: 12/20/2007 Time: 11:26:15 Yage: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: H-14, True North Site: PB H Pad Vertical (1'VD) Keference: H- 146: 79.8 Weli: H-14 Section (VSO Referen ce: Well (O.OON,O.OOE,150.OOAzi) Wellpath: H-14 B Survey Calculation Method: Mi nimum Curvature Db: Oracle Survey MD Incl ~zim TVD Sys TVD N/S F./W ~IapN MapE Tool ft deg deg ft ft ft ft ft ft 7976.15 17.68 58.41 7018.00 6938.23 2345.77 1476.55 5961619.32 644760.44 MWD+IFR+MS 8071.99 17.59 59.35 7109.34 7029.57 2360.77 1501.41 5961634.79 644785.00 MWD+IFR+MS 8167.40 20.75 57.42 7199.45 7119.68 2377.23 1528.06 5961651.75 644811.33 MWD+IFR+MS 8264.92 20.77 56.50 7290.64 7210.87 2396.07 1557.04 5961671.14 644839.94 MWD+IFR+MS 8358.63 23.64 60.44 7377.39 7297.62 2414.52 1587.24 5961690.16 644869.79 MWD+IFR+MS 8453.86 23.45 60.54 7464.70 7384.93 2433.26 1620.35 5961709.53 644902.53 MWD+IFR+MS 8548.46 22.98 56.62 7551.64 7471.87 2452.67 1652.16 5961729.55 644933.96 MWD+IFR+MS 8642.95 22.34 56.65 7638.84 7559.07 2472.70 1682.56 5961750.14 644963.98 MWD+IFR+MS 8739.60 21.64 56.47 7728.45 7648.68 2492.64 1712.76 5961770.65 644993.79 MWD+IFR+MS 8835.34 20.92 56.78 7817.67 7737.90 2511.75 1741.78 5961790.32 645022.43 MWD+IFR+MS 8927.80 19.97 57.14 7904.30 7824.53 2529.36 1768.85 5961808.44 645049.16 MWD+IFR+MS 9022.86 18.96 57.08 7993.93 7914.16 2546.56 1795.45 5961826.14 645075.43 MWD+IFR+MS 9118.28 17.99 57.08 8084.43 8004.66 2563.00 1820.83 5961843.06 645100.49 MWD+IFR+MS 9214.00 19.83 58.72 8174.98 8095.21 2579.46 1847.12 5961860.02 645126.45 MWD+IFR+MS 9310.76 18.32 58.62 8266.42 8186.65 2595.90 1874.13 5961876.97 645153.14 MWD+IFR+MS 9404.45 20.42 60.26 8354.81 8275.04 2611.68 1900.90 5961893.25 645179.60 MWD+IFR+MS 9495.45 19.46 60.35 8440.35 8360.58 2627.05 1927.85 5961909.14 645206.26 MWD+IFR+MS 9584.26 21.36 61.75 8523.58 8443.81 2642.03 1954.96 5961924.63 645233.07 MWD+IFR+MS 9617.72 25.52 70.77 8554.28 8474.51 2647.29 1967.14 5961930.12 645245.15 MWD+IFR+MS 9651.23 27.49 82.36 8584.29 8504.52 2650.70 1981.63 5961933.80 645259.58 MWD+IFR+MS 9682.58 28.21 90.03 8612.02 8532.25 2651.66 1996.22 5961935.04 645274.14 MWD+IFR+MS 9707.33 28.45 98.30 8633.81 8554.04 2650.80 2007.91 5961934.41 645285.84 MWD+IFR+MS 9748.64 30.58 107.85 8669.78 8590.01 2646.16 2027.66 5961930.14 645305.68 MWD+IFR+MS 9779.47 28.66 111.64 8696.58 8616.81 2641.03 2042.00 5961925.28 645320.11 MWD+IFR+MS 9804.05 28.54 110.86 8718.16 8638.39 2636.76 2052.97 5961921.23 645331.15 MWD+IFR+MS 9840.27 28.21 110.88 8750.03 8670.26 2630.63 2069.05 5961915.41 645347.35 MWD+IFR+MS 9871.89 31.76 112.68 8777.41 8697.64 2624.76 2083.72 5961909.81 645362.13 MWD+IFR+MS 9899.07 35.19 112.29 8800.08 8720.31 2619.03 2097.57 5961904.35 645376.08 MWD+IFR+MS 9936.77 41.23 111.30 8829.69 8749.92 2610.38 2119.21 5961896.12 645397.89 MWD+IFR+MS 9968.20 44.87 113.75 8852.66 8772.89 2602.15 2139.02 5961888.27 645417.85 MWD+IFR+MS 9994.74 45.74 114.89 8871.32 8791.55 2594.38 2156.21 5961880.83 645435.18 MWD+IFR+MS 10032.65 46.67 115.82 8897.56 8817.79 2582.66 2180.94 5961869.59 645460.12 MWD+IFR+MS 10064.28 48.52 117.98 8918.89 8839.12 2572.09 2201.76 5961859.41 645481.14 MWD+IFR+MS 10088.71 51.32 119.01 8934.62 8854.85 2563.17 2218.18 5961850.81 645497.73 MWD+IFR+MS 10127.98 55.55 120.87 8958.01 8878.24 2547.42 2245.50 5961835.59 645525.34 MWD+IFR+MS 10158.51 56.59 123.20 8975.05 8895.28 2533.99 2266.97 5961822.56 645547.06 MWD+IFR+MS 10180.88 58.99 123.92 8986.97 8907.20 2523.52 2282.74 5961812.40 645563.03 MWD+IFR+MS 10221.95 61.70 124.19 9007.29 8927.52 2503.54 2312.31 5961792.98 645592.97 MWD+IFR+MS 10253.26 66.31 126.35 9021.01 8941.24 2487.28 2335.27 5961777.17 645616.23 MWD+IFR+MS 10281.78 70.30 127.32 9031.55 8951.78 2471.40 2356.47 5961761.70 645637.73 MWD+IFR+MS 10316.65 76.29 130.66 9041.58 8961.81 2450.39 2382.41 5961741.18 645664.06 MWD+IFR+MS 10346.70 79.99 132.22 9047.75 8967.98 2430.92 2404.44 5961722.15 645686.47 MWD+IFR+MS 10379.42 84.19 135.46 9052.25 8972.48 2408.48 2427.81 5961700.15 645710.25 MWD+IFR+MS 10411.29 88.02 138.83 9054.42 8974.65 2385.18 2449.43 5961677.27 645732.31 MWD+IFR+MS 10442.17 92.45 142.00 9054.29 8974.52 2361.39 2469.10 5961653.86 645752.43 MWD+IFR+MS 10474.33 95.38 145.57 9052.10 8972.33 2335.51 2488.05 5961628.35 645771.87 MWD+IFR+MS 10504.24 97.24 145.01 9048.81 8969.04 2311.07 2504.98 5961604.24 645789.26 MWD+IFR+MS 10534.95 97.18 144.36 9044.95 8965.18 2286.21 2522.59 5961579.73 645807.34 MWD+IFR+MS 10570.31 96.81 144.19 9040.65 8960.88 2257.72 2543.08 5961551.63 645828.37 MWD+IFR+MS 10601.51 96.80 143.94 9036.95 8957.18 2232.64 2561.26 5961526.90 645847.03 MWD+IFR+MS 10633.39 96.50 143.76 9033.26 8953.49 2207.07 2579.94 5961501.69 645866.19 MWD+IFR+MS 10665.55 98.07 144.54 9029.18 8949.41 2181.21 2598.62 5961476.20 645885.36 MWD+IFR+MS 10696.29 97.92 145.14 9024.91 8945.14 2156.32 2616.15 5961451.65 645903.36 MWD+IFR+MS • Sperry Drilling Services Survey Report Company: BP Amoco Date: 12!20/2007 Time: 11 :26:15 Page: 4 Field: Pru dhoe Bay Ctrordinate(NE) Reference: Well: H-14, True North Site;. PB H Pad ~ Vertical (TVD) Reference: H-146: 79.8 WeN: H-1 4 Section (VS) Reference: Well ( O.OON,O.OOE,1 50.OOAzi) Wellpath; H-1 46 Survey Calctclaton Method: Minimum Curvature Db: Oracle Survey MD [ncl Azim TVD'.. Sys TVD N/S E/W IV1apN NIapE '1'001 ft deg deg ft_ ft ft ft ft ft 10727.38 98.30 145.48 9020.52 8940.75 2131.02 2633.67 5961426.69 645921.35 MWD+IFR+MS 10752.56 97.18 144.55 9017.13 8937.36 2110.57 2647.98 5961406.52 645936.05 MWD+IFR+MS 10792.10 94.08 144.99 9013.25 8933.48 2078.44 2670.67 5961374.83 645959.35 MWD+IFR+MS 10823.02 90.37 145.44 9012.05 8932.28 2053.07 2688.30 5961349.80 645977.45 MWD+IFR+MS 10879.91 90.93 145.00 9011.40 8931.63 2006.34 2720.75 5961303.71 646010.78 MWD+IFR+MS 10926.57 92.35 143.23 9010.07 8930.30 1968.56 2748.08 5961266.45 646038.83 MWD+IFR+MS 10976.74 92.29 142.09 9008.04 8928.27 1928.70 2778.49 5961227.19 646069.99 MWD+IFR+MS 11024.66 92.84 142.50 9005.89 8926.12 1890.83 2807.77 5961189.88 646099.98 MWD+IFR+MS 11066.19 92.41 142.51 9003.99 8924.22 1857.91 2833.02 5961157.46 646125.86 MWD+IFR+MS 11119.49 93.34 142.68 9001.32 8921.55 1815.63 2865.35 5961115.80 646158.99 MWD+IFR+MS 11158.61 93.15 141.72 8999.10 8919.33 1784.77 2889.29 5961085.40 646183.51 MWD+IFR+MS 11214.74 92.10 142.31 8996.53 8916.76 1740.57 2923.80 5961041.88 646218.85 MWD+IFR+MS 11258.76 91.98 142.91 8994.97 8915.20 1705.62 2950.51 5961007.44 646246.23 MWD+IFR+MS 11309.75 91.73 143.08 8993.32 8913.55 1664.92 2981.19 5960967.34 646277.67 MWD+IFR+MS 11349.94 91.17 142.45 8992.30 8912.53 1632.93 3005.50 5960935.82 646302.58 MWD+IFR+MS 11407.55 90.74 141.73 8991.34 8911.57 1587.49 3040.89 5960891.07 646338.83 MWD+IFR+MS 11452.02 89.57 141.84 8991.22 8911.45 1552.55 3068.40 5960856.66 646367.00 MWD+IFR+MS 11501.50 89.75 142.30 8991.51 8911.74 1513.52 3098.81 5960818.22 646398.15 MWD+IFR+MS 11540.43 89.57 142.04 8991.74 8911.97 1482.77 3122.69 5960787.94 646422.61 MWD+IFR+MS 11596.34 90.56 142.05 8991.68 8911.91 1438.69 3157.08 5960744.52 646457.83 MWD+IFR+MS 11641.99 90.56 141.35 8991.23 8911.46 1402.87 3185.37 5960709.25 646486.79 MWD+IFR+MS 11687.98 90.56 140.68 8990.78 8911.01 1367.12 3214.30 5960674.06 646516.40 MWD+IFR+MS 11736.06 91.98 141.52 8989.72 8909.95 1329.71 3244.48 5960637.24 646547.29 MWD+IFR+MS 11765.44 93.15 142.62 8988.40 8908.63 1306.56 3262.52 5960614.44 646565.77 MWD+IFR+MS 11797.31 94.88 144.02 8986.17 8906.40 1281.07 3281.51 5960589.31 646585.24 MWD+IFR+MS 11830.57 96.00 144.94 8983.02 8903.25 1254.12 3300.75 5960562.74 646604.98 MWD+IFR+MS 11861.82 96.12 146.77 8979.72 8899.95 1228.40 3318.19 5960537.36 646622.91 MWD+IFR+MS 11892.30 97.25 147.15 8976.17 8896.40 1203.03 3334.70 5960512.31 646639.89 MWD+IFR+MS 11924.02 96.19 146.89 8972.46 8892.69 1176.60 3351.85 5960486.21 646657.54 MWD+IFR+MS 11954.77 96.00 147.26 8969.19 8889.42 1150.94 3368.46 5960460.87 646674.65 MWD+IFR+MS 11986.14 96.06 147.06 8965.90 8886.13 1124.73 3385.38 5960434.99 646692.06 MWD+IFR+MS 12018.34 96.56 147.35 8962.36 8882.59 1097.82 3402.72 5960408.42 646709.90 MWD+IFR+MS 12049.24 95.50 147.74 8959.11 8879.34 1071.89 3419.21 5960382.82 646726.88 MWD+IFR+MS 12081.42 94.57 147.63 8956.29 8876.52 1044.80 3436.34 5960356.06 646744.53 MWD+IFR+MS 12107.56 93.71 147.88 8954.40 8874.63 1022.75 3450.25 5960334.28 646758.86 MWD+IFR+MS 12148.67 91.97 148.78 8952.37 8872.60 987.81 3471.81 5960299.76 646781.08 MWD+IFR+MS 12176.79 88.58 148.00 8952.23 8872.46 963.86 3486.55 5960276.10 646796.26 MWD+IFR+MS 12209.44 91.11 148.83 8952.32 8872.55 936.05 3503.65 5960248.62 646813.89 MWD+IFR+MS 12240.58 91.11 149.41 8951.72 8871.95 909.33 3519.62 5960222.21 646830.37 MWD+IFR+MS 12273.04 88.89 148.64 8951.72 8871.95 881.50 3536.33 5960194.71 646847.61 MWD+IFR+MS 12303.71 90.25 148.75 8951.95 8872.18 855.30 3552.26 5960168.82 646864.04 MWD+IFR+MS 12316.51 90.93 148.88 8951.81 8872.04 844.35 3558.89 5960158.00 646870.87 MWD+IFR+MS 12360.00 90.93 148.88 8951.11 8871.34 807.12 3581.37 5960121.21 646894.05 BLIND TREE= 6" MCEVOY WEiLHEAD = MCEVOY ACTUATOR = OTIS KB. ELEV = 82.25' BF. ELEV = 46.47' KOP = 3200' Max Angle = 98° @ 10666 Datum MD = 10007' Datum ND = 8800' SS DRLG DRAFT 9 5/8" DV Pkr; 9.3 Arctic pak/cmt above 2632' 13-318" CSG, 72#, L-80, ID = 12.347" 2692' Minimum ID = 3.725" @ 9405' 41/2" XN Nipple H-14B SAFETY NOTES: 4-1 /2" CHROME TBG. 700 @ 10282' 2190' - 4-1/2" X Nipple (3.813" ID) GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3426 3417 16 KGB2 DCR RK 0 11/22/07 3 6204 5594 41 KG62 DMY RK 0 11/22/07 2 8114 7149 19 MMG DMY BK 0 11/22/07 1 9271 8229 19 MMG DMY BK 0 11/22/07 6974' 9-5/8" X 7" BKR ZXP PKR/HGR 4-1/2" TBG, 12.6#, 13Cr-80, .0152 bpf, ID = 3.958" 9418' Top of Window - 7138` HES EZSV - 7174' Tubing Cut - 7500` Top of cement - 9000' 9-5/8" X 5-1/2" Baker SAB PKR - 9399' 5-1/2" X 2-7/8" HES RCP PKR -9450' PERFORATION SUMMARY REF LOG: ???? On ~rrrvdd/yy A NGLE AT TOP PERF: 930 @ 11100' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2 7!8" 6 11,100-11,660 OPEN 11/22/07 9340- - 4-1/2" X Nipple (3.813" ID) °~~~'S60`- 7" X 4-1/2" BKR S3 Packer ;384' - 4-112" X Nipple (3.813" ID) 9405 4-1/2" XN nipple (3.725" ID) 9418' 4-1/2" WLEG 9566` - 7", 26#, L-80 liner 4-1/2", 12.6#, L-80, IBT Liner - i 2,098 9981' - 9-5/8", 47# CSG 10225' - CIBP (SET 11/15/02) 12482` - PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 1981 ORIGINAL COMPLETION 06/24/98 SIDETRACK (H-14A) 08/23/07 PGS Added 9 5/8" DV Collar 11/24/07 D14 SIDETRACK (H-148) 11/30/07 /TLH CORRECTIONS 7", 29#, L-80 Liner - 10940' PRUDHOE BAY UNrf WE1L: H-148 PERMIT No: 2071160 API No: 50-029-20580-02 SEC 21, T11 N, R13E, 1524' FNL & 1265' FEL BP Exploration (Alaska) ' ~. , ~; . .. 20-Dec-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well H-14B Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 7,097.47' MD Window /Kickoff Survey: 7,138.50' MD (if applicable) Projected Survey: 12,360.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ Signed V Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) a..c~ Z -~ t.t•to r~ STATE OF ALASKA Reviewed By: OIL AND GAS CONSERVATION COMMISSION P.I. Suprv BOPE Test Report Comm 'Contractor/Rig No.: Doyon 14 PTD#: 2071160 DATE: 11/15/2007 Inspector Lou Grimaldi '• Insp Source °' Operator: BP EXPLORATION (ALASKA) INC Operator Rep: Habethur Rig Rep: Marmon Inspector Type Operation. DRILL j Rams Annular: Inspection No: bopLG07 1 1 16 104332 Valves: Type Test: BIWKLY Test Pressure: 250/3500 250/3000 250/3500 ' Related Insp No: ..m ,..n . TEST DATA ~.,. ~ .~ ,...~.. MISC. INSPECTIONS .r ,,,,, .rv ~ , .....~., ...., ~.. ~ ......., ... MUD SYSTEM. ~ ~~. _~~,Wwa. ~.ro,~ .,~.. ,v,...~.,~ ..~~~ n , _a. ~~..... ~. ACCUMULATOR SYSTEM: P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P P System Pressure __3050 P Housekeeping: P Pit Level Indicators P P .Pressure After Closure 1800 P PTD On Location P Flow Indicator P P 200 PSI Attained :33 P __ Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 2:38 P Well Sign P H2S Gas Detector P P Blind Switch Covers: -oth station, P Drl. Rig P MS Misc NA NA Nitgn. Bottles (avg): 4 x 2200 P Hazard Sec. P ACC Misc NA Misc NA ': FLOOR SAFTY VALVES: BOP STACK: ~ CHOKE MANIFOLD: Quantity P/F ~ Quantity Size P/F Quantity P/F ~ Upper Kelly 1 P ; Annular Preventer 1 13 5/8 P No. Valves 14 P Lower Kelly 1 P ~ Pipe Rams 1 3.5 X 6 _ P ~. Manual Chokes 1 P Ball Type 1 P Lower Pipe Rams 1 2 7/8 x 5 P Hydraulic Chokes __ 1 P ' Inside BOP 1 P i Blind Rams 1 Blind P CH Misc NA FSV Misc NA Choke Ln. Valves __ 1 3 1/8 P HCR Valves 2 3 1/8 P f Kill Line Valves 1 3 1/8 _. P Check Valve 0 none NA BOPS Misc 0 none NA Test Results Number of Failures: 0 Remarks• 4 hour good test, no failures observed. Good procedure documented and followed. 10K chart recorder used, 5K or 6K would be better suited. STATE OF ALASKA 1/28/04 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to:~ ~-e~~~ )~adn:in.stUte.a?~.u~~ Uc~`=,.~`~-~d~oe h<:~~.arl or~.stae.Uf:.us bclv ::eckenatp:n::~a~rr:€n.stat~.a~.~~~' Contractor: Doyon Rig No.: 14 DATE: 11/2/2007 Rig Rep.: Egholm / Gochenauer Rig Phone: 659-4507 Rig Fax: 659-4506 Operator: BP Op. Phone: 659-4503 Op. Fax: 659-4506 Rep.: Burley /Chacin Field/Unit & Well No.: PBU H-14A PTD # 198-068 Meridian: UM Location: Section: 21 Township: 11 N Range: 13E Operation: Drlg: Workover: X Explor.: Test: Initial: X Weekly: Other: Test Pressure: Rams: 250-3500 Annular: 250-2500 Valves: 250-3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Resu Location Gen.: P Well Sign P Upper Kelly 1 P Housekeeping: P Drl. Rig P Lower Kelly 1 P PTD On Location P Hazard Sec. P Ball Type 1 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result Annular Preventer 1 13 5/8 P Pipe Rams 1 3 1/2"x6" P Lower Pipe Rams 1 2 7/8"x5" P Blind Rams 1 13 5/8 P Choke Ln. Valves 1 3 1/8" P HCR Valves 2 3 1/8" P Kill Line Valves 2 3 1/8" P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Resu No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: TimelPressure Test Res System Pressure 3000 P Pressure After Closure 1800 P 200 psi Attained 37 P Full Pressure Attained 3 mins Osec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4@ psi 2200 Number of Failures: 0 Test Time: 4.5 Hours Components tested 29 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: jim ~-e~q;~;n3adn:i:~.state.ak.~~~~ Remarks: Tested rams with 4" and 5 1/2" test joints. Tested to 250 low 3500 high 5 mins each test -tested oa od. 24 HOUR NOTICE GIVEN YES X NO Date 11/01/07 Time 1300 hrs Test start Finish Waived By Witness Burl John Cris holm/Chacin BOP Test (for rigs) BFL 1/28/04 2007-1102_BOP_Doyon14_PBU_H-14A.xls • ~ o a ~ a ~ SARAH rALIN, GOVERNOR ~~ ~ ~ ~~ 333 W 1~T ~t 1v 1a~ CO„~~~s~~01s CD~IIsSI01` . 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Greg Hobbs Senior Drilling Engineer BP Exploration Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-14B BP Exploration Alaska, Inc. Permit No: 207-116 Surface Location: 1542' FNL, 1265' FEL, SEC. 21, T11N, R13E, UM Bottomhole Location: 909' FNL, 2415' FWL, SEC. 22, T11N, R13E, UM Dear Mr. Hobbs: 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 an required test, contact the Commission's petroleum field inspector at (907)~8~9 3607 (pager). G~iair: a DATED this ~ day gust, 2007 cc: Department of ish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~~~~ ~ ,A ~G ~, 7 ALAS~IL AND GAS CONSERVATION COMMI~N ~~~~ PERMIT TO DRILL ~iaska Oil & Gas Cons. Commission 20 AAC 25.005 ~ ~'~, AnchoragA .~ 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 H-14B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12557 TVD 8859 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: M ' ' FE E 7. Property Designation: ADL 028284 Pool 1542 FNL, 1265 L, SEC. 21, T11 N, R13 , U Top of Productive Horizon: 831' FSL, 1187' FWL, SEC. 15, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: September 15, 2007 Total Depth: 909' FNL, 2415' FWL, SEC. 22, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 24,480 4b. Location of Well (State Base Plane Coordinates): Surface: x-643329 y-5959246 Zone-ASP4 10. KB Elevation (Height above GL): Plan 80 feet 15. Distance to Nearest Well Within Pool: 478' 16. Deviated Wells: Kickoff Depth: 1750 feet Maximum Hole An le: 102 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3170 Surface: 2460 18. Casin Pr' ram: S cfi ' tio n To - Se 'n De th - Bo om uantit of Cement c.f. ors ks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 IBT-M 2577' 7000' 6211' 9577' 8512' 535 cu ft Class'G' 6-1/8" 4-112" 12.6# L-80 IBT-M 3130' 9427' 8371' 12557' 8742' 441 cu ft Class'G' 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrilt and Re-entry Operations) Total Depth MD (ft): 12556 Total Depth TVD (ft): 9059 Plugs (measured): 9385 & 10225 Effective Depth MD (ft): 12482 Effective Depth TVD (ft): 9039 Junk (measured): None asing Length ize Cement Volume MD D Conductor /Structural 110' 20" x 30" 8 cu ds Concr t 110' 110' Surface 2692' 13-3/8" 3720 cu ft Permafrost II 2692' 2692' Intermediate 9981' 9-5/8" 1410 cu ft Class'G' 130 cu ft Permafrost'C' 9981' 8491' Pr uc ion Liner 685' 7" 305 cu ft Class'G' 9505' - 10190' 8104' - 866T Liner 3085' 2-7/8" 124 cu ft Class'G' 9471' - 12 56' 8078' - 9059' Perforation Depth MD (ft): 10560' - 12470' Perforation Depth TVD (ft): 8927' - 9037' 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 Phil Smith, 564-4897 Printed Name Greg H Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-4191 Date ,! cs ~ ~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~D API Number: 50-029-20580- -00 Permit App oval Dat : ~ See cover letter for other re uiremen Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Samples Req'd: ^~Yes ~No Mud Log Req'd: ^ Yes ~No rr n~, ,^~ i HZS Measures: ~ Yes ^ No ire ~onal Survey Req'd: Yes ^ No ~~ V ~ i ~ Y .'[~.'~~ Other: Date i ~ 6 OVED BY THE COMMISSION COMMISSIONER Form 10-401 Revised 12/2005 RR ~-~ ~ v ~~ `,/~ Submit In Duplicate • • Well Name: H-14B Planned Well Summary Well H-14B Well Horizontal Target Zone 2 T e Sidetrack Ob'ective API Number: 50-029-20580-02 Current Status H-14 Shut-In and P&A Procedures commencing Estimated Start Date: 07-Oct-2007 Time to Com lete: 23.9 Days Surface Northin Eastin Offsets TRS Location 5,959,246 643,329 1542' FNL / 4015' FWL 11 N, 13E, 21 Northin Eastin TVDss Offsets TRS Target 5,961 666 645 730 -8,950 4449' FNL / 1187' 11 N, 13E, Locations , , FWL 15 5,960 682 646 511 -8,921 168' FNL / 1947' 11 N, 13E, , , FWL 22 B tt Northin Eastin TVDss Offsets TRS om o Location 5 959 950 646 995 -8,859 909' FNL / 2415' 11 N, 13E, , , , FWL 22 Planned KOP: 7150'MD / 6238'TVDss Planned TD: 12,557'MD / 8,859' TVDss Ri : Doyon 14 BFE: 46.5' RTE: 80.0' Directional - sperry Pos KOP: 7150' MD Maximum Hole Angle: -47° in the 8-1/2" intermediate section (@ KOP) 102° in the 6-1 /8" horizontal section Close A roach Wells: All wells pass major risk criteria for close approach. Survey Program: MWD Standard + IFR /Cassandra / MS Nearest Property Line: 24,480' to the PBU property line ' Nearest Well within Pool: H-17A is the closest well at 478' ctr-ctr with 172' of allowable deviation at tanned de th of 10,500' MD. H-14B Permit to Dritl Application Page 1 • • Formation Markers H-14B (Based on SOR) Formation Estimated Formation Tops (TVDss) (TVDbkb) (MDbkb) Estimated Pore Press. (ppg EMW / Psi) CM2 6140 6222.25 7015 Kickoff 6238 6317 7150 CM1 6600 6682.25 7614 THRZ 6890 6972.25 7933 LCU/BHRZ 7163 7245.25 8224 LCU/To Kingak 7163 7245.25 8224 LCU/TJG 7163 7245.25 8224 TJF 7518 7600.25 8602 TJE 7658 7740.25 8751 TJD 7950 8032.25 9062 TJC 8178 8260.25 9305 TJB 8302 8384.25 9438 Sag River 8433 8515.25 9577 Shublik 8464 8546.25 9610 TSAD / TZ4B 8548 8630.25 8702 3170 si @ 8800 TZ4A/42N 8660 8742.25 9834 6.9+ EMW TCGL / TZ3 8730 8812.25 9930 BCGL/TZ2 8800 8882.25 10,027 25N / T2B 8870 8952.25 10,136 PGOC 8878 8960.25 10,151 25P 8886 8968.25 10,166 POWC 8928 9010.25 10,271 22N 8948 9030.25 10,373 Casincl/Tubinq Program Hole Csg / Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg (psi) (psi) MD / MD / O.D. TVDrkb TVDrkb 8-'/z" 7" 26# L-80 IBT-M 7,240 5,410 2577' 7,000' / 9577' / 6,211' 8,512' 6-1/8" 4'/z" 12.6# L-80 IBT-M 10,160 10,530 3130' 9,427' / 12,557' / 8,371' 8,742' Tubing 4'/z" 12.6# 13Cr- Vam 10,160 10,530 9,400' 33' / 33' 9,433' / 80 To 8,376' H-14B Permit to Drill Application Page 2 • • Mud Program Whipstock Millina Mud Properties: LSND Whip Stock Window 9-5/8". 47# Densit PV YP API FL HTHP FL MBT PH 9.0 16-30 30-35 <6.0 N/C N/C 9.0-10 Intermediate Mud Properties: LSND 8-1 /2" hole section Depth Interval Density (ppg) PV YP API FL HTHP FL MBT PH 7,150'-7,800' 9.0 - 9.5 14-26 26-30 <6.0 N/C <15 9.0-10 7,800'-9,577' HRZ to Sa 9.6 15-22 26-30 4.0-6.0 <10.0 <15 9.0-10 Production Mud Properties: FLOPRr7 SF Reservoir Drill-in Fluid 6-1/8" hole section De th Interval Densit PV YP LSVR API FI H MBT 9,577'-12,557' 8.4 - 8.5 8-12 22-28 >20,000 6.0-8.0 9.0-9.5 < 3 Logging Program 8-1/2" Intermediate: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/PWD Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers - as required by Geology Drilling: Dir/GR/Res/Neu/Den/ABI Open Hole: None Cased Hole: None Cement Proaram x 4" DP excess. Tail TOC: 9,377' MD (200' above Liner Top) Total Cement Volume: Spacer 40 bbls of Viscosified Spacer weighted to 9.8 ppg (Mud Push II) Lead None Tail 78.5 bbls, 441 cuft, 377 sks 15.8 Ib/ al Class G + adds -1.17 cuft/sk Temp BHST = 217° F. BHCT TBD by Schlumberaer ~g (Mud Push II) + adds -1.16 cuft/sk Tail: 2980' of open hole with 40% excess, 80' shoe track, 150' 4-~h" x 6-1/8" liner lap, and 200' of Casin Size: 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: 2,577' of open hole with 40% excess, plus 80' shoe track Tail TOC: 7,000' MD TOL + 200' DP x 9 5/8" annulus Total Cement Volume: Spacer 40 bbls of Viscosified Spacer weighted to 12.5 Lead N/A Tail 95.2 bbls, 535 cuft, 461 sks 15.8 Ib/ al Class Tem BHST = 200° F, BHCT TBD b Schlumber er Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Lead: None H-14B Permit to Drill Application Page 3 Surface and Anti-Collision Issues C Surface Shut-in Wells: There are no wells requiring surface shut-in in order to move onto the well. At surface H-15 to the north and H-13 to the south are nearest at 112' centers. Close Approach Shut-in Wells: All wells pass major risk criteria. Hydrogen Sulfide H-Pad is not designated as an H2S site. Recent H2S data from the pad is as follows: Date of Well Name H2S Level Reading #1 Closest SHL Well H2S Level #2 Closest SHL Well H2S Level #1 Closest BHL Well H2S Level #2 Closest BHL Well H2S Level Max. Recorded H2S on Pad/Facility Other Relevant H2S Data (H2S alarms from rigs, etc.) H-13 10 m 3/19/2005 H-15 No data H-17 No data H-18 No data H-22a 220 m 10/4/1995 Most recent reading on H-22a is 85 ppm on 7/31/05. Faults The H-14B wellpath is not expected to intersect any mapped faults. Faults in the area: a small (~10 ft) down to the north fault which trends east west and tips out approximately 200 ft west of the horizontal section. Fault #2 is N of the location and is an E-W trending down to the south (~25 ft) fault. H-14B Permit to Drill Application Page 4 • Well Control • Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. BOP regular test frequency for H-14B will be 14 days during drilling phase and 7 days during decompletion and surface casing work. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP 3170psi @ 8800' TVDss (6.9 pp EMW) Maximum surface pressure 2460 psi (.10 psi/ft gas gradient to surface) Kick tolerance Infinite over 11.0 ppg FIT assumin 8.5 ppg reservoir and 4" drillpipe Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casing Test 3500 psi surface pressure Integrit Test - 8-1/2" hole 11.0 pp FIT after drilling 20' from middle of window Production Interval Maximum antici ated BHP 3170psi @ 8800' TVDss (6.9 pp EMW) Maximum surface reesure 2290 psi (.10 psi/ft gas gradient to surface) Kick tolerance Infinite with a 10.0 pp FIT Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casing/7" Liner Test 3500 psi surface pressure Integrity Test - 6-1/8" hole 10.0 ppg FIT after drilling 20' of new hole Planned com letion fluids 8.5 pp Seawater / 7.2 ppg Diesel Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. H-14B Permit to Drill Application Page 5 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE 1. Well Control A. The Ivishak in this fault block is expected to be under-pressured at 6.9 ppg EMW. This pressure is estimated based on offset well pressures. 3500 psi test pressure is in accordance with the RP for Prudhoe production well casing tests. II. Lost Circulation/Breathing A. The H-14B is not expected to intersect any mapped faults. Fault #1 is a small (-10 ft) down to the north fault which trends east west and tips out approximately 200 ft west of the horizontal section. Fault #2 is N of the location and is an E-W trending down to the south (~25 ft) fault. B. The only significant lost circulation event in the area was 275 ft NE at H-17A which lost 331 bbl into the Shublik, near Fault #2. H-17A was presumably being drilled with mudweights appropriate for the Kingak, which may have caused the Shublik to frac. WELL # Ri /Coil Barrels MD TVDSS Zone X LOC Y LOC H-17A ri 331 9953 8476 SHUBLIK 646038 5961750 H-17 rig 10 9995 8400 Above Sa /LCU 646870 5961143 III. Kick Tolerance/Integrity Testing A. The Kick Tolerance for both the intermediate and production hole sections is infinite with planned mud weights. The FIT will prove up adequate formation strength for expected ECD's. B. Integrity Testing 'l'est Point Test Depth ~I'cst h:~11'1' (ll-/~;al) ty e 9-5/8" 20-ft minimum from the 9-5/8" FIT _ 11.0 minimum window window 7" shoe 20-ft minimum from the 7" shoe FIT 10.0 minimum IV. Stuck Pipe A. Significant directional work will be required in the production hole section. Hole cleaning and differential sticking tendency will be of concern. Watch for signs of tight hole and short trip /back ream as required to avoid stuck pipe. VI. Hydrogen Sulfide A. H-PAD is not designated as an H2S site; H2S levels of potentially lethal concentrations have been recorded on this pad, however, but current levels are below the 100 ppm threshold to be considered an H2S pad. VII. Faults A. Little faulting is expected along the planned trajectory. See Section II on lost circulation for more details. VIII. Anti-Collision Issues B. All wells pass major risk criteria for close approach. H-17A is the closest well at 478' ctr-ctr with 172' of allowable deviation at planned depth of 10,500' MD. CONSULT THE H-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION H-14B Permit to Drill Application Page 6 • • Operations Summary Current Condition and history: / SCMT log 2 7/8"liner from 10730'-9300' inconclusive due to gas 10/27/02 and 10/31/02. / Set CIBP in 2 7/8" at 10,225' MD 11/15/02. / Leak detection log indicates leaking 2 7/8"liner @ 9410' , CIBP holding 11/21/02 / Attempt to fish RCP liner top packer from top 2 7/8': Packer released but unable to retrieve. l2/07/02 / Drift to 9600' MD 1/13/03 / Chemical cut RCP at 9456'MD 1/14/03 / 2.25" drift to 9530' 2/27/03 / Recovered top half of RCP, left slips and lower half in hole 3/23/03 / Video log 1/17/06 / Set 5 %2" PX plug at 9385; MITIA and OA to 3000 psi, passed 3/21/06 Scope Notify the field AOGCC representative with intent to plug and abandon Pre-Riq Work: 1. RU slickline and pull the PX plug from the tubing at 9385' MD. 2. Drift the 2 7/8" liner to CIBP @ 10,225' MD. 3. RIH with 1.5" Coiled tubing to CIBP. • If coiled tubing cannot pass through 2 7/8" liner top, skip to step 7 4. Displace the well to clean seawater and fluid pack the IA with diesel. 5. Lay cement abandonment plug from CIBP to 9500' MD (4.2 bbls glass G @ 15.8 ppg) 6. Contaminate and circulate out excess cement from 9500' MD. 7. Position CTN at 9400' and confirm infectivity into the 7" x 2 7/8" annulus. 8. Displace 25 bbls Class G cement into 7" x 2 7/8" annulus (annulus volume + 5 bbls). Hesitation squeeze last 5 bbls if necessary to achieve 500 psi squeeze pressure. 9. Contaminate /circulate out excess cement from 9400' to surface. 10. Test tubing against cement plug to 3500 psi after WOC. 11. Jet cut the tubing in the middle of a full joint at ±7500' MD. 12. Circulate the tubing and IA to seawater with 2000' TVD of diesel. 13. Perform CMITIAxT to 3500 psi. 14. Bleed casing and annulus pressures to zero. 15. Cycle the tubing hanger LDS and test the 9 5/8" packoff (set on slips) to 3500 psi. 16. Set a BPV and test to 1000 psi from tubing annulus. Remove well house and flow lines. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Doyon 14 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPV/TWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull BPV/TWC. 4. R/U. Pull 5'/z" tubing from the cut depth at -7,500' MD and above. 5. RU E-line. RIH w/ 8'h" gauge ring /junk basket to top of tubing stub. ~'a 6. RIH with HES EZSV and set the cement retainer as required to avoid cutting casing collar and place '~ top of whipstock at 7150. Test casing to 3500 psi. 7. P/U and RIH with 9 5/8" Baker bottom-trip anchor whipstock assembly. Orient whipstock, as desired, and set on bridge plug. Shear off of whip stock. 8. Displace the well to 9.0 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 9. Mill window in 9 5/8" casing at ± 7,150 ,pus approxima e y eyon mi e o win ow. Circulate well bore clean. 10. Pull up into 9 5/8" casing and conduct an FIT to 11.0 ppg EMW. POOH. 11. M/U 8'/z" BHA with GR/Res/PWD. RIH, kick off and drill the 8 1/2" intermediate section to the top of the HRZ. Weight up to 9.6 ppg prior to entering HRZ. ~~` ~ ~~~~ H-14B Permit to Drill Application Page 7 • • 12. Continue ahead, per directional proposal to base HRZ /Top Sag River. Circulate well clean, short trip to window. POOH. 13. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. Test to 3500 psi. 14. M/U 6 1/8" Dir/GR/Res/Neu/Den assembly. RIH to the landing collar. 15. Drill out the liner float equipment and cement to the shoe. 16. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 17. Drill out the 7" shoe plus drill ~20' new formation; pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to horizontal landing point. POOH for bit / BHA change. 18. RIH, drill horizontal section to planned TD, short trip as necessary. 19. Circulate, short trip, spot liner running pill, POOH. 20. Run and cement a 4'/Z", 12.6#, L-80 production liner. POOH UD all drill pipe. 21. RU SLB and RIH w/ 1000' 2-7/8" 2906 Powerjet guns set @ 6 SPF. Tag PBTD. 22. Put guns on depth and fire. POOH and verify all shots fired. 23. R/U and run 4 1/2", 12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. 24. Set a TWC and test to 1000 psi 25. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. 26. Reverse circulate inhibited seawater followed by 151 bbls of diesel. U-tube diesel to the tubing side to freeze protect the well to 2200' MD. Drop packer setting ball with rod. 27. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 28. Secure the well. Rig down and move off. Post-Rig Work: 1. Install well house and instrumentation 2. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. Estimated Pre-rig Start Date: 08/31/2007 Estimated Spud Date: 09/15/2007 H-14B Permit to Drill Application Page 8 :TREE _ ~ 6" MCEV OY WELLHEAD - MCEVOY ACTUATOR OTIS . KB. ELEV = 82.25' BF. ELEV = 46.47 KOP = 3200' Max Angle= 95 @ 12286' Datum MD = 10495' Datum TV D = 8800' SS ~ H-14 y~s~,n 2000' -j 5-1/2" OTIS ROM SSSV LAND NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3003 2920 5 OTIS DUMMY RA 06/11/02 4 5685 5127 43 OTIS DUMMY RA 06/11/02 3 8417 7180 37 OTIS DUMMY RA 06/11/02 2 9202 7784 40 OTIS DUMMY RA 06/11/02 1 9355 7903 38 OTIS DUMMY RA 06/11/02 9 5/8" DV Pkr; 9.3 Arctic pak/cmt abov 2632' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2692' Minimum ID = 2.35" @ 9450' 5-1 /2" X 2-7/8" PROD PACKER 9385' ~ 5-1/2" X NIP, ID = 4.562" 9385' S-1 /2" PX PLUG (03/21 /06) 9396' 5-1/2" BKR K-22 ANCHOR, ID = 4.875" 9399' 9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.75" "* 9450' Imo" 5-1/2" X 2-7/8" HES RCP PKR, ID = 2.35" ITOP OF 2-7/8" LNR ~ 9471' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" 9499' { 9452' 8~ 9456' ~-1 TOP OF RCP /CUT RCP 01 /14/03 9458' 5-1/2" OTIS X NIP, ID = 4.562" 9471' BAKER DEPLOYMENT SUB 9481' 5-1/2" OTIS XN NIP, ID = 4.455" 9499' 7" BKR SEAL ASSY W/O SEALS 9501' ELMD TT LOGGED 10/10/91 TOP OF 7" LNR I~ 9505' 9-5/8" CSG, 47#, L-80, ID = 8.681" I-i 9981' PERFORATION SUMMARY REF LOG: SWS CNL/GR ON 06/21/98 A NGLE AT TOP PERF: 54 @ 10560' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 10560 -10564 C 05/07/00 1-11/16" 4 11090 - 11480 C 05/01/99 1-11/16" 4 11530 - 11560 C 12/27/98 1-11/16" 4 11610 - 11640 C 12/27/98 1-11/16" 4 11790 - 11820 C 12/27/98 1-11/16" 4 11850 - 11880 C 12/27/98 1-11/16" 4 12080 - 12129 C 06/24/98 1-11/16" 4 12172 - 12370 C 06/24/98 1-11/16" 4 12420 - 12470 C 06/24/98 L TOP OF WHIPSTOCK I 10187 TOP OF CEMENT 10229' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 10940' MILLOUT WINDOW 10190' - 10196' 10196' RA MARKER 1, 0~ CIBP(SEf 11/15/02) PBTD 11 12482' 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.37" ~~ 12556' DATE REV BY COMMENTS DATE REV BY COMMENTS 1981 ORIGINAL COMPLETION 03/21/06 DRF/TLH PX PLUG SET 06/24/98 SIDETRACK (H-14A) 08/23/07 PGS Added 9 5/8" DV packer 06/15/02 RL/TP GLV DUMMYS 11/15/02 CAO/KK SETCIBP 12/07!02 SRB/KK RCP PKR SAFETY NOTE 01/14/03 CAO/TLH CUT RCP PRUDHOE BAY UNff WELL: H-14A PERMff No: 1980680 API No: 50-029-20580-01 SEC 21, 711 N, R13E, 1524' FNL & 1265' FEL BP Exploration (Alaska) ~ TREE _ = 6" MCEV OY WELLHEAD= MCEVOY ACTUATOR = OTIS KB. ELEV = 82.25' BF. ELEV - 46.47 KOP = 3200' Max Angle = Datum MD = Datum TV D = 8800' SS H -14~ Pro o s e d SAFE TES: 13-Cr Tubing p 2200 - 4-1/2" X Nipple (3.813" ID) 9 5/8" DV Pkr; 9.3 Arctic pak/cmt abov 2632' 13-3/8" CSG, 72#, L-80, ID = 12.347" 2692 Minimum ID = 3.725" @ 9407' 41/2" XN Nipple I I GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 4 3 2 1 7000` 9-5/8" X 7" BKR ZXP PKR/HGR 4-1/2" TBG, 12.6#, 13Cr-80, .0152 bpf, ID = 3.9 9427' Top of Window - 7150` HES EZSV - 7174` Tubing Cut - 7500` Top of cement - 9000` 9-5/8" X 5-1/2" Baker SAB PKR - 9399` 5-1/2" X 2-7/8" HES RCP PKR - 9450` PERFORATION SUMMARY REF LOG: A NGLE AT TOP PERF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 7", 29#, L-80 Liner - 10940` ^ 9347` - 4-1/2" X Nipple (3.813" ID) 9367` - 7" X 4-1/2" BKR S3 Packer 9387` - 4-1/2" X Nipple (3.813" ID) 9407` 4-1/2" XN nipple (3.725" ID) _ 9427` - 4-1/2" WLEG 9577` - 7", 26#, L-80 liner 4-1/2", 12.6#, L-80, IBT Liner - 12557 9981 ` - 9-5/8", 47# CSG 10225` -CIBP (SET 11/15/02) 12482` - PBTD DATE REV BY COMMENTS DATE REV BY COMMENTS 1981 ORIGINAL COMPLETION 03/21/06 DRF/TLH PX PLUG SET 06/24/98 SIDETRACK (H-14A) 08!23/07 PGS Added 9 5/8" DV Collar 06/15/02 RL/TP GLV DUMMYS 11/15/02 CAO/KK SET CIBP 12/07/02 SRB/KK RCP PKR SAFETY NOTE 01/14/03 CAO/TLH CUT RCP PRUDHOE BAY UNIT WELL: H-146 PERMrr No: 1980680 API No: 50-029-20580-02 SEC 21, T11 N, R13E, 1524' FNL & 1265' FEL BP Exploration (Alaska) ('l1MYANY Ut1A1Lti W}IIU:NI.1: W Ff11UlA 1'N IN NIIaVNY NUNiNAM PI40'. 11-1418 R$ I wp11G p1-14.1'Im 11-148) tlP Am~ae ('errNmuN•(PL 1~1 X°Inami W al avm:ll-IJ, Inw•wMk ' IhpW Pm Ih•PW Je %mavy/1'Iao Trwl (}mngI NY:INY lak4M>at1 (144:1t11(tibp.real-1 •: 4~12~.INI6 1111 ('y~,ylu MSWW'. Mmmulm(un-.eme Vrxleal l l VUI N.k 5 X i] ]%. )] 1tt'Wre1V11ILle lX IJ(U. NIN,U IlUF.1 ]ISUAXI 1!55]31 I'L J :11-14a N.ti 1"wNlfi Vll MWU (~~k~. Ualc: lino XYaxm. LY('W6A ' MaJaulnl llupW 141u~We. S!5 J4.J] ]N Y'! <: 5W 1- M (' t 1 b M ticm MM.ul. Iua ( YNWk+ww limo Ymlan• IAIgXUI ~ l'nmg W- M.'IWxI. Nu4'llar•J cu Wre u . umum mra mr 4 . Re3'ieweJ-. Wle: wFll WiIANS 4 Sb 6000 Name ~ W-N • W-W N°NNmr Picvm Iamu4e Wey4u r l \ - _ -- - 11-I4 1616.4] IYY421 SYS•1!4(.W Wily W ]U IT44.I4YN 14X SV'_1.6]4W 14 1 AW ikl' UN'fA1Lti \ ' -t?~~ ~ ~ ~ Name Jvu ~w-s •tJ-w wYmmr tinmt tihape ' \ Start D u U • Y:715(Y MD, 63I7.3fiTVD ;--~-.}_ II-IJN IV(:N x31I.Y] MSS.XII I'ISUW S'MIY7]SU 415!'_7X] Pom k"- ~ ~ --~~----- 141JN IJ %'It7 Y] W.i.W 41VSAM1 5'1611!74.!] 416]YJ ]_' Peet _ Stan ~,~ 'lr 4l IINY~7171Y MD fi331.15 D ~ ~ IFIJN IS XYt1'/] 6WNI l6NW 3Y3YYSUIm 614'143W P~ml ' ~ ~~p , - - - ~ ~ 11-IJN fIni ll,y 1414N f1 ItY]X Y7 %YYY Y7 IY6J.41 !649.14 1!73.W J!IN.W SY41 _'/XI Un WS NUAMI Peyrne SY/JIWI N6 616511 YS P~ml \tW - II-IJN I! WI..Y7 '15954 !6!!.X6 SYfi1451Am WSYIU IIU Prml IFIJtl I I W!X.)] !JT.93 !444.YI 3'161666A1U 615]III.W Poml GSOU - - ~ 32 _ ~ SECTION DETAILS CMI \\ ~ .. . ~ Sec MD Inc Azi TVD +N:-S +E--W DLeg TFace VSec Tarya \ - 1 7150.00 46.32 31.56 6317.36 2049.24 1184.78 0.00 0.00 1184.78 ~4" 2 7170 00 46.58 34.85 6331.15 2061.36 1192.72 1'_.00 85.00 1192.72 7892 4T MD fi9 E d Di LITT VD +~i ~ 3 . 7892.47 20.23 58.26 6931.17 2348.50 1454.47 4.00 163.48 1454.47 o r : . , ---- - 4 9577.23 20.23 58.26 8511.97 2615.00 1950.00 0.00 0.00 1950.00 H-146 TSGR . .. ___ _. _ 5 959713 20.23 58.26 8530.74 2658.64 1955.89 0.00 0.00 1955.89 6 9875.58 43.74 II5.55 8769.87 2641.90 2088.06 13.00 80.17 2088.06 7000 - - _ _ 7 10024.02 43.7a II5.55 8877.11 2597.64 2180.67 0.00 0.00 2180.67 X0011 ~ ~ - ~ _ 8 1041619 90.00 140.00 9028.97 2373.95 2446.91 13.00 32.19 2446.91 H-148 TI _ - - . _„ - 9 10464.44 96.24 140.51 9026.35 2337.00 2477.63 13.00 4.67 2477.63 - - - - ~ ~ - -'- '-' ~- ~ - 10 10635.60 96.24 140.51 9007.75 2205.69 2585.83 0.00 0.0 2 LCU/BHRZ - _ _ ~ _ _ ~ ~ II 10694.97 93.00 142.00 9002.97 2159.54 2622.86 6.00 155.32 2622.86 H-148 T2 12 10747.46 90.10 14312 9001.55 2117.86 2654.72 6.00 ISZIS 2654.72 - ~ ~ -- - ~ -------- - 13 11671.22 90.10 143.22 8999.98 1377.96 3207.78 0.00 0.00 3207.78 LCU?op Kingak _ , ..- - 14 11674.92 90.10 143.00 8999.97 1375.00 3210.00 6.00 -89A1 3210.00 H-148 T3 LCU/T3G - ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ - - ~ - - - - ~ IS 11885.37 102.17 146.75 8977.52 1204.25 3330.21 6.00 17.02 3330.21 c - 16 11970.77 102.17 146.75 8959.53 1134.43 3375.98 0.00 0.00 3375.98 17 12174.57 90.00 148.00 8937.97 964.06 3485.00 6.00 174.10 3485.00 H-146 T4 °o h00 _ _ -- __ _ I8 12201.31 90.00 149.60 8937.97 941.19 3498.85 6.00 90.00 3498.65 s - ~ - - - ~ ~ ~ ~ ~ ~ ~ ~ - - - 19 12557.44 90.00 149.60 8937.97 634.01 3679.04 0.00 0.00 3679.04 H-148 TS u A _. ~T { - - { - ~. - T)F ' - . ~ I _ ~ _ _ J _ _ ~ ~ T>E _ 2~ ' CASMG DETAILS '~ ~ ~ I -TTT-'-_ _ Start Dir 13/11X1 :9597.23 MD, N5311.74TVD No. TVD MD Name Sizc - -'--'- - - - - I 8511.97 9577.23 7" 7.000 I^ ~ ~ ~ - - ~ - - ~ ~ ~ ~ ~ - 2 8937.97 12557.00 4 L2" 4.500 SUUO - _-- 911011 - ST ~ ~. TJD ~ Dir :9875.5%' MD, 8769.NT D _ . tart Dir l3il(W':IW24.112'M ,8877.IITVD _ - - - - Eld INr : 10464.44' , 9026.35' TVD FORMATION TOP DETAILS I Start Dv fii I IXI' 10635.6' MD, 91W7.75TV D TIC / ,. ~ Fnd Dir : 1 1747.46' MD, 91X11. 55' TVD No. TVDPath MDPath Formation _ _ _ ~~ ; ~ / S tart Dir fi/1 1' : 11671.22' MD, RYY9.YR TV T1B - ~ ~ End Di : I I RNS.JT MD, 8977.52' TV 7 i~ ~ 2 6968.97 7932. 5 THRZ " ~1 rva - ~ ~ - Toml Dcp th 12557 .44'MD, N937.9T TVD 3 7241.97 8223.71 LCU-BHRZ 8500 ./. - ~ f 4 7241.97 8223.71 LCUTop Kingak _-- ~ / ~ . ...- ~-_ ~ ' ~ 5 7241.97 8223.71 LCUTIG Sh116Gk ' / ;- 1 y--~ ~ ~ ~ 7596 97 8602.05 T1F - - . ~. . - ,~ ~ 1 - -. .9 8751.46 TIE TS D/T24B \ ~ ' ! ! ~' r - ,--~ ~ - 7 9062.7 TJD 8 8026 ° ~ Plan H-1 4 . _ ~ 9 8256.97 9305.46 TIC Tz4A'42N J ~ i : - ~ 10 8380.97 9437.62 T16 _ ~ -- - H-HB T S I I 8511.97 9577.23 Sy; Rivtt ~ TCCJL/TZ3 . ~ 1 - - ~ 4 U2" 12 8542.97 9610.28 Shublik ~ BCGIfIZ2 I OOW~ ~P ~, j ._. _ ____ - 13 8626.97 9701.54 TSADi TZ4B 25N!T2B-- -- -'. (~ W --..-- -~-- .~ '-- ~_- "'~- - - _ ~ ~ 14 6738.97 9834.35 TZ4A'42N 9000 ~ ~_- - ----- --~~--- $ - H-14 6 T4 15 8608.97 9929.70 TCGL / TZ3 - P ~ - ~ ~ 1101X1 End Dir :12 201.31' R937. 9T TVD I6 8878.97 10026.60 BCGL'TZ2 25P - - Dir (JIIN-: I1 97U.7T M D 959.S JTVD 17 8948.97 10136.19 25N~T26 ~ WC H-146 Gco Po y , IS 8956.97 10151.03 PGOC 22N H 14BT2 H -148 T3 19 8964.97 10166.63_SP ~ - \ ~ ~ 20 9006.97 1027111 POWC H-146 TI ~ H-I4 (H-141 I ~ I 21 9026.97 10372.72 22N 10 00 LS 00 20 00 25 00 30 00 35 00 40 00 45 00 5000 5500 • • Vertical Section at 90.00° [SOOft/ink tlYAmuur 1.4) ('etukh M tIXW Muemum l meaNn 1'~iv~J (N1J 141 Waf'amR'.II IC TIU: NnM Vmt 111 VIII It~WLL 1 3 ~ Xfi.i] ]N Y7 S (Vll Nil. G - 14 (11IXIN U Wlil 1 Ny.LLm'. I\('WtiA M . WI><IN6141m.W 1 ~ J(~4] tN.n 5' M1L.iJ. IVe ('yUnkx WVlh Fn~v \mleu•. IJIi1X~el ~ l'eaeg l'-4u0We AkUX~J. Mewem(urvanm: W McUX~a Nuke tluud TARGET DETAILS Name TVD +N,'-S +Ei-W Northing Easting Shape H-14B TSGR 8511.97 2655.00 1950.00 5961937.50 645227.87 Point H-14B T4 8937.97 964.06 3485.00 5960276.27 646794.72 Point H-14B TS 8937.97 634.01 3679.04 5959950.00 646995.00 Point H-14B Geo Poly 8978.97 1963.61 2669.14 5961260.00 645960.00 Polygon H-14B T3 8999.97 1375.00 3210.00 5960681.86 646511.95 Point H-14B T2 9002.97 2159.54 2622.86 5961455.00 645910.00 Point H-14671 9026.97 2373.95 2446.91 5961666.00 645730.00 Point 3000 St Dir 13, 1 W' : 9597.23' M , 8530 4T VD _ X `o - --._.-_- 20 t O z - s ____ ! 'o __. ~' _ N ~ __ 150 _` __/ ~-. 50 500 1000 I NIIKV LY YKIxiKAM YLm. 11-14N KN I wpll(111-1 S. Yom 11-I iBl UNplh 1•m npW l'u )uny/Yhe 1'nnl ('rultUJ ny:'IroyJakalNlX\)' (iakalU(;6p.cnWle 3~1~'_UU6 tl$II IXI 1233t.M YLwWJ:II-IAtl Ktil w(XNr V31 MWU ('IUx:tcJ: Udle'. W hLl. 1N:1 wn N Nm• ~W-ti ~F%.W Wulhmr Meamr Weuk LmgGWe tibl 11-10 Ifilfi,fit IYYX21 5•ISY3Jr~.lNl (r1112')IXI )U I]'.M.IYlN 10.Y S U'_'1.fi]fiW 14 SECTION DETAILS Sec MD lnc Azi TVD +N%-S +E:-W DLeg TFace VSec Target 1 7150.00 46.32 31.56 6317.36 2049.24 1184.78 0.00 0.00 1184.78 2 7170.00 46.58 34.85 6331.15 2061.36 1192.72 IZ.00 85.00 1192.72 3 7892.47 20.23 5826 6931.17 2348.50 1454.47 4.00 163.48 1454.47 4 9577.23 20.23 58.26 8511.97 2655.00 1950.00 0.00 0.00 1950.00 H-l4B TSGR _ 5 9597.23 20.23 58.26 8530.74 2658.64 19ii.89 0.00 0.00 1955.89 6 9875.58 43.74 115.55 8769.87 2641.90 2088.06 13.00 60.17 2088.06 - ~ 1- 7 10024.02 43.74 II5.55 8877.11 2597.64 2180.67 0.00 0.00 2180.67 8 10416.29 90.00 140.00 90'_8.97 2373.95 2446.91 13.00 32.19 2446.91 H-14B T1 9 1046444 96.24 140.51 9026.35 2337.00 2477.63 13.00 4.67 2477.63 10 10635.60 96.24 140.51 9007.75 2105.69 2585.83 0.00 0.00 2585.83 11 12 10694.97 10747 46 93.00 90 10 142.00 143 22 9002.97 9001 55 2159.54 2622.66 ? 117 86 2654 72 6.00 6 00 155.32 157 15 262266 72 2654 H-14B T2 13 . 1167122 . 90.10 . 143.22 . 8999.98 . . 1377.96 3207.78 . 0.00 . 0.00 . 3207.78 14 11674.92 90.10 143.00 8999.97 1375.00 3210.00 6.00 -89.41 3210.00 H-14873 IS 1188537 102.17 146.75 8977.52 1204.25 333011 6.00 17.02 3330.21 16 11970.77 102.17 146.75 8959.53 1134.43 3375.98 0.00 0.00 3375.98 1-~- 17 12174.57 90.00 148.00 8937.97 964.06 3485.00 6.00 174.10 3485.00 H-14B T4 `-~- IS 12201.31 90.00 149.60 8937.97 941.19 3496.85 6.00 90.00 3498.65 19 12557.44 90.00 149.60 8937.97 634.01 3679.04 0.00 0.00 3679.04 H-148 TS End Dir :9875.58' MD 67 69.87' TV D - FORMATION TOP DETAILS ~`~~ Start Dir 13i 100' : 0 024.02' M D, 8877. I 1 ' - No. TVDPath MDPath Formation --- End Dir : 1 4 64.44 MD , 9026.35 ' TV 1 6678.97 7613.95 CMl ~~ Start r 6 .100' :10 635.6' M D. 9 7.75'T VD 2 6968.97 7932.75 THRZ ' E Di 10747 46' MD 9W I 5' TV D 3 7241.97 8223.71 LCU/BHRZ n ' ~, r : . , 4 7241.97 8223.71 LCU-Top Kingak ; ,. S 7241.97 8223.71 LCU~TIG - - - 6 7596.97 8602.05 TJF ' ~ - - - 7 7736.97 875116 TIE 8 8028.97 9062.47 TJD j - - 9 8'_56.97 9305.46 TJC . ! 10 8380.97 9437.62 T!B 11 8511.97 957223 Sag River Start Dir %100' : 11671.22' M D, 899 .9 6TVD 12 8542.97 9610.28 Shablik I \I ~. _ , 13 8626.97 9701.54 TSAD / TZ4B __ 14 8738.97 9834.35 TZ4A~42N -_ _ _ _. _. ,.- E Dir : 1168537 MD 89 5 2' TVD IS 8808.97 9929.70 TCGL ~ TZ3 - , . 16 8878.97 10026.60 BCGLTZ2 ' r 17 8948.97 10136.19 25N / T'_B - - - - ~ 18 19 8956.97 8964 97 10151.03 10166 63 PGOC 25P - ~ ~ ~ ~ ~ ~ - 20 . 9006.97 . 10271.21 POWC 21 9026.97 10372.72 22N • 9000 Start Dir b%100' : 1970.77 MD, 8959.53TV f3 1 3000 West(-). Easq+) [SOOkin[ CASING DETAILS No. TVD MD Name Size 4000 1 8511.97 957223 7" 7.000 2 8937.97 12557.00 4 U2" 4.500 Sperry-Sun BP Planning Report Company: BP Amoco Date:. 4/12/2006 Time: 14:55:09 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: H-14, True North Site: PB H Pad Vertical (TVD) Reference: 32.5 +46,47 79.0 Wel-: H-14 Section (VS) Reference: Well (O.OON,O.OOE,90AOAz) Wellpath: Plan H-146 Survey Calculation Method: Minimum Curvature Db: OraGe Plan: H-146 RST wp06 Date Composed: 8/13/2002 Version: 31 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB H Pad TR-11-13 UNITED STATES :North S lope Site Position: Northing: 5957572.25 ft Latitude: 70 17 30.055 N From: Map Easting: 641366.07 ft Longitude: 148 51 19.802 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.08 deg Well: H-14 Slot Name: 14 H-14 Well Position: +N/-S 1636.67 ft Northing: 5959246.00 ft Latitude: 70 17 46.149 N +E/-W 1994.21 ft Easting : 643329.00 ft Longitude: 148 50 21.676 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9577.23 8511.97 7.000 8.500 7" 12557.00 8937.97 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle .Dip Direction ft ft deg deg 7613.95 6678.97 CM1 0.00 0.00 7932.75 6968.97 THRZ 0.00 0.00 8223.71 7241.97 LCU/BHRZ 0.00 0.00 8223.71 7241.97 LCUlTop Kingak 0.00 0.00 8223.71 7241.97 LCUli'JG 0.00 0.00 8602.05 7596.97 TJF 0.00 0.00 8751.26 7736.97 TJE 0.00 0.00 9062.47 8028.97 TJD 0.00 0.00 9305.46 8256.97 TJC 0.00 0.00 9437.62 8380.97 TJ B 0.00 0.00 9577.23 8511.97 Sag River 0.00 0.00 9610.28 8542.97 Shublik 0.00 0.00 9701.54 8626.97 TSAD / TZ46 0.00 0.00 9834.35 8738.97 TZ4A/42N 0.00 0.00 9929.70 8808.97 TCGL / TZ3 0.00 0.00 10026.60 8878.97 BCGL/TZ2 0.00 0.00 10136.19 8948.97 25N / T26 0.00 0.00 10151.03 8956.97 PGOC 0.00 0.00 10166.63 8964.97 25P 0.00 0.00 10271.21 9006.97 POWC 0.00 0.00 10372.72 9026.97 22N 0.00 0.00 Targets Map Map <-- Latitude ---> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft H-146 TSGR 8511.97 2655.00 1950.00 5961937.50 645227.87 70 18 12.258 N 148 49 24.818 W H-14B T4 8937.97 964.06 3485.00 5960276.27 646794.72 70 17 55.623 N 148 48 40.084 W H-146 T5 8937.97 634.01 3679.04 5959950.00 646995.00 70 17 52.376 N 148 48 34.432 W Sperry-Sun BP Planning Report Company: BP Amoco Date: 4/12/2006 Tune: 14:55;09 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: H-14, True North Site: PB H Pad Vertical (TVD) Refetence: 32. 5 +46.47 79.0 Wep: H-14 Section (VS) leference Well (O.OON,O:OOE,90;OOAzi) Weppath: Plan H-14B Survey Calculation Method: Minimum Curvature Db: OraGe Targets Map Map ~--- .Latitude ---~ ~_ Longitude ---s Name l)escriptton TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min > 'Sec Dip.. Dir.. ft ft ft ft ft H-146 Geo Poly 8978. 97 1963.61 2669.14 5961260.00 645960.00 70 18 5.456 N 148 49 3.857 W -Polygon 1 8978. 97 1968.70 2664.23 5961265.00 645955.00 70 18 5.507 N 148 49 4.000 W -Polygon 2 8978 .97 526.69 3536.96 5959840.00 646855.00 70 17 51.321 N 148 48 38.575 W -Polygon 3 8978 .97 660.95 3839.60 5959980.00 647155.00 70 17 52.640 N 148 48 29.751 W -Polygon 4 8978 .97 1946.27 3053.91 5961250.00 646345.00 70 18 5.284 N 148 48 52.639 W -Polygon 5 8978 .97 2822.48 2215.40 5962110.00 645490.00 70 18 13.905 N 148 49 17.078 W -Polygon 6 8978 .97 2656.79 1987.18 5961940.00 645265.00 70 18 12.276 N 148 49 23.734 W H-146 T3 8999 .97 1375.00 3210.00 5960681.86 646511.95 70 17 59.665 N 148 48 48.095 W H-146 T2 9002 .97 2159.54 2622.86 5961455.00 645910.00 70 18 7.384 N 148 49 5.204 W H-14B T1 9028 .97 2373.95 2446.91 5961666.00 645730.00 70 18 9.493 N 148 49 10.332 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100FI deg/100ft deg 7150.00 46.32 31.56 6317.36 2049.24 1184.78 0.00 0.00 0.00 0.00 7170.00 46.58 34.85 6331.15 2061.36 1192.72 12.00 1.28 16.46 85.00 7892.47 20.23 58.26 6931.17 2348.50 1454.47 4.00 -3.65 3.24 163.48 9577.23 20.23 58.26 8511.97 2655.00 1950.00 0.00 0.00 0.00 0.00 H-14B TSGR 9597.23 20.23 58.26 8530.74 2658.64 1955.89 0.00 0.00 0.00 0.00 9875.58 43.74 115.55 8769.87 2641.90 2088.06 13.00 8.45 20.58 80.17 10024.02 43.74 115.55 8877.11 2597.64 2180.67 0.00 0.00 0.00 0.00 10416.29 90.00 140.00 9028.97 2373.95 2446.91 13.00 11.79 6.23 32.19 H-146 T1 10464.44 96.24 140.51 9026.35 2337.00 2477.63 13.00 12.96 1.06 4.67 10635.60 96.24 140.51 9007.75 2205.69 2585.83 0.00 0.00 0.00 0.00 10694.97 93.00 142.00 9002.97 2159.54 2622.86 6.00 -5.45 2.51 155.32 H-146 T2 10747.46 90.10 143.22 9001.55 2117.86 2654.72 6.00 -5.53 2.33 157.15 11671.22 90.10 143.22 8999.98 1377.96 3207.78 0.00 0.00 0.00 0.00 11674.92 90.10 143.00 8999.97 1375.00 3210.00 6.00 0.06 -6.00 -89.41 H-146 T3 11885.37 102.17 146.75 8977.52 1204.25 3330.21 6.00 5.73 1.78 17.02 11970.77 102.17 146.75 8959.53 1134.43 3375.98 0.00 0.00 0.00 0.00 12174.57 90.00 148.00 8937.97 964.06 3485.00 6.00 -5.97 0.61 174.10 H-14B T4 12201.31 90.00 149.60 8937.97 941.19 3498.85 6.00 0.00 6.00 90.00 12557.44 90.00 149.60 8937.97 634.01 3679.04 0.00 0.00 0.00 0.00 H-14B T5 Survey MD Incl Azim TVD Sys TVD VS N/S E/W DLS MapN MapE TooVCo ft deg deg ft ft ft ft ft deg/100ft ft ft 7150.00 46.32 31.56 6317.36 6238.39 1184.78 2049.24 1184.78 0.00 5961317.30 644474.40 Start Dir 1 7170.00 46.58 34.85 6331.15 6252.18 1192.72 2061.36 1192.72 12.00 5961329.57 644482.10 Start Dir 4/ 7200.00 45.43 35.33 6351.98 6273.01 1205.12 2079.02 1205.12 4.00 5961347.46 644494.17 MWD 7300.00 41.61 37.08 6424.49 6345.52 1245.76 2134.59 1245.76 4.00 5961403.80 644533.73 MWD 7400.00 37.83 39.10 6501.40 6422.43 1285.13 2184.90 1285.13 4.00 5961454.84 644572.13 M W D 7500.00 34.08 41.50 6582.33 6503.36 1323.05 2229.70 1323.05 4.00 5961500.35 644609.19 MWD 7600.00 30.40 44.42 6666.91 6587.94 1359.34 2268.77 1359.34 4.00 5961540.10 644644.72 M W D 7613.95 29.89 44.87 6678.97 6600.00 1364.26 2273.75 1364.26 4.00 5961545.18 644649.55 CM1 7700.00 26.79 48.04 6754.70 6675.73 1393.82 2301.92 1393.82 4.00 5961573.90 644678.56 MWD 7800.00 23.30 52.67 6845.30 6766.33 1426.31 2328.99 1426.31 4.00 5961601.59 644710.53 MWD 7892.47 20.23 58.26 6931.17 6852.20 1454.47 2348.50 1454.47 4.00 5961621.63 644738.31 End Dir 7900.00 20.23 58.26 6938.24 6859.27 1456.68 2349.87 1456.68 0.00 5961623.04 644740.49 MWD 7932.75 20.23 58.26 6968.97 6890.00 1466.31 2355.83 1466.31 0.00 5961629.18 644750.01 THRZ 8000.00 20.23 58.26 7032.07 6953.10 1486.09 2368.06 1486.09 0.00 5961641.79 644769.55 M W D 8100.00 20.23 58.26 7125.90 7046.93 1515.51 2386.25 1515.51 0.00 5961660.54 644798.61 M W D 8200.00 20.23 58.26 7219.73 7140.76 1544.92 2404.45 1544.92 0.00 5961679.29 644827.67 M W D vent Sperry-Sun BP Planning Report Company:. BP AMOCO Date: 4/12/2006 Time: 14:55:09 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) ltefereuce: WeII: H-t4, True North Site: PB H Pad Vertical (TVD) Reference: 32. 5 +46.47 79.0 Well: H-1 4 Section (VS) Reference: Well (O.OON,O.OOE,90.OOAz) Wellpath: .Pla n H-146 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD VS N/S E/1V DLS MapN MapE TooUCo ft deg deg ft ft ft ft ft deg/100ft ft ft 8223.71 20.23 58.26 7241.97 7163.00 1551.89 2408.76 1551.89 0.00 5961683.73 644834.56 LCU/TJG 8300.00 20.23 58.26 7313.55 7234.58 1574.33 2422.64 1574.33 0.00 5961698.03 644856.73 MWD 8400.00 20.23 58.26 7407.38 7328.41 1603.75 2440.83 1603.75 0.00 5961716.78 644885.79 M W D 8500.00 20.23 58.26 7501.21 7422.24 1633.16 2459.02 1633.16 0.00 5961735.53 644914.84 M W D 8600.00 20.23 58.26 7595.04 7516.07 1662.57 2477.22 1662.57 0.00 5961754.28 644943.90 MWD 8602.05 20.23 58.26 7596.97 7518.00 1663.18 2477.59 1663.18 0.00 5961754.67 644944.50 TJ F 8700.00 20.23 58.26 7688.87 7609.90 1691.98 2495.41 1691.98 0.00 5961773.03 644972.96 M W D 8751.26 20.23 58.26 7736.97 7658.00 1707.06 2504.74 1707.06 0.00 5961782.64 644987.86 TJE 8800.00 20.23 58.26 7782.70 7703.73 1721.40 2513.60 1721.40 0.00 5961791.78 645002.02 M W D 8900.00 20.23 58.26 7876.53 7797.56 1750.81 2531.79 1750.81 0.00 5961810.53 645031.08 M W D 9000.00 20.23 58.26 7970.36 7891.39 1780.22 2549.99 1780.22 0.00 5961829.28 645060.14 MWD 9062.47 20,23 58.26 8028.97 7950.00 1798.60 2561.35 1798.60 0.00 5961840.99 645078.29 TJD 9100.00 20.23 58.26 8064.19 7985.22 1809.64 2568.18 1809.64 0.00 5961848.02 645089.19 M W D 9200.00 20.23 58.26 8158.02 8079.05 1839.05 2586.37 1839.05 0.00 5961866.77 645118.25 M W D 9300.00 20.23 58.26 8251.85 8172.88 1868.46 2604.56 1868.46 0.00 5961885.52 645147.31 M W D 9305.46 20.23 58.26 8256.97 8178.00 1870.07 2605.56 1870.07 0.00 5961886.55 645148.90 TJC 9400.00 20.23 58.26 8345.68 8266.71 1897.87 2622.76 1897.87 0.00 5961904.27 645176.37 M W D 9437.62 20.23 58.26 8380.97 8302.00 1908.94 2629.60 1908.94 0.00 5961911.32 645187.30 TJB 9500.00 20.23 58.26 8439.50 8360.53 1927.29 2640.95 1927.29 0.00 5961923.02 645205.43 MWD 9577.23 20.23 58.26 8511.97 8433.00 1950.00 2655.00 1950.00 0.00 5961937.50 645227.87 H-14B TS 9597.23 20.23 58.26 8530.74 8451.77 1955.89 2658.64 1955.89 0.00 5961941.25 645233.68 Start Dir 1 9600.00 20.30 59.28 8533.33 8454.36 1956.71 2659.14 1956.71 13.00 5961941.76 645234.49 MWD 9610.28 20.59 63.02 8542.97 8464.00 1959.85 2660.87 1959.85 13.00 5961943.55 645237.60 Shublik 9700.00 25.94 89.63 8625.59 8546.62 1993.65 2668.18 1993.65 13.00 5961951.50 645271.25 MWD 9701.54 26.07 89.98 8626.97 8548.00 1994.32 2668.18 1994.32 13.00 5961951.52 645271.93 TSAD / TZ 9800.00 35.46 107.21 8711.65 8632.68 2043.44 2659.70 2043.44 13.00 5961943.98 645321.19 MWD 9834.35 39.15 111.36 8738.97 8660.00 2063.07 2652.80 2063.07 13.00 5961937.45 645340.95 TZ4A/42N 9875.58 43.74 115.55 8769.87 8690.90 2088.06 2641.90 2088.06 13.00 5961927.04 645366.14 End Dir 9900.00 43.74 115.55 8787.51 8708.54 2103.30 2634.62 2103.30 0.00 5961920.05 645381.52 M W D 9929.70 43.74 115.55 8808.97 8730.00 2121.83 2625.77 2121.83 0.00 5961911.55 645400.21 TCGL / TZ 10000.00 43.74 115.55 8859.76 8780.79 2165.68 2604.81 2165.68 0.00 5961891.43 645444.45 M W D 10024.02 43.74 115.55 8877.11 8798.14 2180.67 2597.64 2180.67 0.00 5961884.56 645459.57 Start Dir 1 10026.60 44.03 115.80 8878.97 8800.00 2182.28 2596.87 2182.28 13.00 5961883.81 645461.19 BCGUfZ2 10100.00 52.31 122.18 8927.91 8848.94 2229.93 2570.24 2229.93 13.00 5961858.10 645509.34 M W D 10136.19 56.50 124.80 8948.97 8870.00 2254.46 2553.99 2254.46 13.00 5961842.32 645534.17 25N / T26 10151.03 58.24 125.80 8956.97 8878.00 2264.66 2546.77 2264.66 13.00 5961835.30 645544.50 PGOC 10166.63 60.07 126.82 8964.97 8886.00 2275.45 2538.84 2275.45 13.00 5961827.57 645555.45 25P 10196.28 63.57 128.64 8978.97 8900.00 2296.11 2522.84 2296.11 13.00 5961811.98 645576.41 H-14B Ge 10200.00 64.01 128.87 8980.61 8901.64 2298.71 2520.75 2298.71 13.00 5961809.94 645579.05 M W D 10271.21 72.51 132.83 9006.97 8928.00 2348.65 2477.49 2348.65 13.00 5961767.64 645629.80 POWC 10300.00 75.97 134.32 9014.79 8935.82 2368.72 2458.39 2368.72 13.00 5961748.93 645650.22 MWD 10372.72 84.74 137.91 9026.97 8948.00 2418.34 2406.76 2418.34 13.00 5961698.26 645700.82 22N 10400.00 88.03 139.22 9028.69 8949.72 2436.35 2386.36 2436.35 13.00 5961678.20 645719.22 M W D 10416.29 90.00 140.00 9028.97 8950.00 2446.91 2373.95 2446.91 13.00 5961666.00 645730.00 H-146 T1 10464.44 96.24 140.51 9026.35 8947.38 2477.63 2337.00 2477.63 13.00 5961629.65 645761.42 End Dir : 1 10500.00 96.24 140.51 9022.49 8943.52 2500.11 2309.72 2500.11 0.00 5961602.80 645784.42 MWD 10600.00 96.24 140.51 9011.62 8932.65 2563.33 2233.00 2563.33 0.00 5961527.31 645849.08 MWD 10635.60 96.24 140.51 9007.75 8928.78 2585.83 2205.69 2585.83 0.00 5961500.43 645872.10 Start Dir 6/ 10694.97 93.00 142.00 9002.97 8924.00 2622.86 2159.54 2622.86 6.00 5961455.00 645910.00 H-146 T2 10700.00 92.72 142.12 9002.72 8923.75 2625.95 2155.58 2625.95 6.00 5961451.10 645913.16 M W D 10747.46 90.10 143.22 9001.55 8922.58 2654.72 2117.86 2654.72 6.00 5961413.94 645942.64 End Dir : 1 10800.00 90.10 143.22 9001.46 8922.49 2686.17 2075.78 2686.17 0.00 5961372.46 645974.90 MWD 10900.00 90.10 143.22 9001.29 8922.32 2746.04 1995.68 2746.04 0.00 5961293.53 646036.28 MWD rent oly . • • Sperry-Sun BP Planning Report Company:. BP Amoco Date: 4/12/2006 Tim er 14:55:09 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Wefl: H-14, True North Site: PB H Pad Vertical (TVl)) Reference: 32:5 +46.47 79.0 Well: H-14 Section (VS) Reference: Well (O:OON,O.OOE,90:OOAzi) Wellpath: Plan H-14B Survey Calculation Method: Minimum Curvature Db: DraGe Survey MD Incl Azim TVD ft deg deg ft 11000.00 90.10 143.22 9001.12 11100.00 90.10 143.22 9000.95 11200.00 90.10 143.22 9000.78 11300.00 90.10 143.22 9000.61 11400.00 90.10 143.22 9000.44 11500.00 90.10 143.22 9000.27 11600.00 90.10 143.22 9000.10 11671.22 90.10 143.22 8999.98 11674.92 90.10 143.00 8999.97 11700.00 91.54 143.44 8999.61 11800.00 97.27 145.21 8991.93 11885.37 102.17 146.75 8977.52 11900.00 102.17 146.75 8974.44 11970.77 102.17 146.75 8959.53 12000.00 100.42 146.94 8953.80 12100.00 94.45 147.55 8940.87 12174.57 90.00 148.00 8937.97 12200.00 90.00 149.53 8937.97 12201.31 90.00 149.60 8937.97 12300.00 90.00 149.60 8937.97 12400.00 90.00 149.60 8937.97 12500.00 90.00 149.60 8937.97 12557.00 90.00 149.60 8937.97 12557.44 90.00 149.60 8937.97 Sys TVD ft 8922.15 8921.98 8921.81 8921.64 8921.47 8921.30 8921.13 8921.01 8921.00 8920.64 8912.96 8898.55 8895.47 8880.56 8874.83 8861.90 8859.00 8859.00 8859.00 8859.00 8859.00 8859.00 8859.00 8859.00 VS N/S ft ft 2805.91 1915.58 2865.79 1835.49 2925.66 1755.39 2985.53 1675.29 3045.40 1595.20 3105.27 1515.10 3165.14 1435.01 3207.78 1377.96 3210.00 1375.00 3225.02 1354.92 3283.14 1273.96 3330.21 1204.25 3338.05 1192.29 3375.98 1134.43 3391.65 1110.43 3445.28 1027.08 3485.00 964.06 3498.19 942.32 3498.85 941.19 3548.79 856.06 3599.38 769.81 3649.98 683.55 3678.82 634.39 3679.04 634.01 E/W DLS MapN ft deg/100ft ft 2805.91 0.00 5961214.60 2865.79 0.00 5961135.66 2925.66 0.00 5961056.73 2985.53 0.00 5960977.79 3045.40 0.00 5960898.86 3105.27 0.00 5960819.92 3165.14 0.00 5960740.99 3207.78 0.00 5960684.78 3210.00 6.00 5960681.86 3225.02 6.00 5960662.06 3283.14 6.00 5960582.24 3330.21 6.00 5960513.44 3338.05 0.00 5960501.63 3375.98 0.00 5960444.51 3391.65 6.00 5960420.82 3445.28 6.00 5960338.51 3485.00 6.00 5960276.27 3498.19 6.00 5960254.78 3498.85 6.00 5960253.66 3548.79 0.00 5960169.51 3599.38 0.00 5960084.25 3649.98 0.00 5959998.98 3678.82 0.00 5959950.38 3679.04 0.00 5959950.00 MapE TooUCr ft_ 646097.66 M W D 646159.04 M W D 646220.43 MWD 646281.81 M W D 646343.19 M W D 646404.57 M W D 646465.96 M W D 646509.67 Start Dir 6 646511.95 H-14B T3 646527.34 M W D 646587.00 M W D 646635.38 End Dir 646643.45 M W D 646682.47 Start Dir 6 646698.60 MWD 646753.80 MWD 646794.72 H-14B T4 646808.32 M W D 646809.00 End Dir 646860.55 M W D 646912.77 M W D 646965.00 M W D 646994.77 41/2" 646995.00 H-146 T5 Alaska Department of Natural Resources Land Administration System Page 1 of 2 ,. ._~~, .. ar~_ ..,~ -:r. f ;r~ ~. , -~r;f~t's Search State Cabins 141~tIr~1 s~~ 5 ~.,....__.. Alaska DR Case ~urnmary File Type. ADL ~ File Number: C 2$2$4 ~ Pr~_.n..table Case F.ie. Summary. See Township, Range, Section and Acreage? New Search c'' Yes ~ No !_~~ R4~n„ I Case Abstract I Case Detail I Land Abstract ~. File: AllL ?82li-I ' "` ~ Search for Status Plat Updates 1s of Ug~?<). ~i1~7 Custuiner: 0001073'77 BP EX1'LOI:I~TION (ALASKA) IN(: PO BOA 196612/900 E. BENSON BL ATTN: L;~N~ MANAGER- ALASKA ANCHORAGE AK 99S 196612 Case Type: 7~~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Statz~s: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date bzitiated.~ 05/28/1965 Once of Primary Responsibility: DOG _'DIV AIL AND GAS Last Transaction Date: 12/04/2006 Case SuUtype: ~tS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED _llei~i~iian: ~! I otii~its{tip?: 0 I 1 N Run,~c : 0l ~ 1: ,Se c~lion: l ~ Section Acrc~.~~: (i~0 Search Plats ;llc~rr~lian.~ t_1 Tuir~ra~hri~: U 1 1N Kange: 013 L S'erlinn: I G S't~cliuj7 Arrc.~~: 6~}0 1 /~~rl~lrun: L' Tuu~rr.ehri~: 01 1N Range: 0 13 L S'ec~ion: ? I .~'<~~~tiun A~~ree: 6=~0 ~~C'77i~lan: I ~ l Olt~nS{11~~: U~ ~ ~ Rat1,~C': ~) ~ _~ E .S~NC"1lUn: ~ ~ ~~C'~ llnn : ~C7'C S': ~) ~~ Legal 1)escri~iion 0~-28-196 * * *SALE NOTICE LEGAL DESCRIPTION* * C1=1-95 TIIN-RI3E-UM15,16,21,22 2560.00 Last updated on 08/29/2007. http://www. dnr. state. ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28284&... 8/29/2007 ~ • TRANSMITTAL LETTER CHECKLIST WELL NAME ~/,~~ f/ ~~!~ PTD# o?~~I/moo 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 between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_~ from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals 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. ~Com~any Name) must contact the Commission to obtain advance approval of such water well testing ro ram. 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N ~ w N_ ~ N w N C _U w ~ O ~, O •++ r ~ O (M O i ~ ` M ~ W ~ ~ O M 00 m y O f/J ~ / J ° N J *b N ~ a ~ ~ ~ ~ ~ V Q N O ~ U 'yam``' ~ a ~ j . . a s a s W ¢~ ~ a s ~ ~ • • Weil 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 Nistory file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been. made to chronologically . organize this category of information. h-14b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 28 12:50:03 2008 Reel Header Service name .............LISTPE Date . ...................08/03/28 0ri9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/03/28 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF scientific Technical services Library. scientific Technical services Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: H-14B API NUMBER: 50029205800300 OPERATOR: BP Exploration, Alaska LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 28-MAR-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: w-0005356206 w-0005356206 w-0005356206 LOGGING ENGINEER: C. CREGLOW C. CREGLOW C. CREGLOW OPERATOR WITNESS: G. BURLEY G. BURLEY G. BURLEY MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: W-0005356206 W-0005356206 W-0005356206 LOGGING ENGINEER: C. CREGLOW C. CREGLOW A. MUNRO OPERATOR WITNESS: J. HABATHUR J. HABATHUR J. HABATHUR MAD RUN 6 JOB NUMBER: w-0005356206 LOGGING ENGINEER: A. MUNRO OPERATOR WITNESS: J. HABATHUR SURFACE LOCATION SECTION: 21 Page 1 h-14b.tapx TOWNSHIP: 11N RANGE: 13E FNL: 1542 FSL: FEL: 1265 FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: 79.77 GROUND LEVEL: 46.47 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 13.375 2692.0 2ND STRING 6.125 7.000 9566.0 3RD STRING PRODUCTION STRING REMARKS: • 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL EXITS THE H-14 WELLBORE BY MEANS OF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 7138'MD/6343'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY. THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 5. MWD RUNS 2-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUNS 3-6 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUNS 5,6 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) AND COMPENSATED THERMAL NEUTRON (CTN). 6. MAD DATA WERE ACQUIRED FROM ABOUT 12010'MD TO ABOUT 9950'MD WHILE POOH AFTER REACHING FINAL TD. BECAUSE OF AN ALD TOOL FAILURE IN MWD RUN 5, THE MAD ALD DATA WERE MERGED WITH THE RUN 6 MWD DATA. OTHER MAD DATA ARE PRESENTED SEPARATELY. 7. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE SCHLUMBERGER OPEN-HOLE GAMMA RAY LOG RUN IN H-14 ON 6 JUNE 1986. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 22 JANUARY 2008, AS AUTHORIZED BY ROGER SELS (BP). ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH Page 2 U h-14b.tapx REFERENCES. THIS SHIFTED DATASET IS THE PDCL FOR H-14B. MAD DATA WERE CORRECTED (SHIFTED) TO THE MWD DATA. 8. MWD RUNS 1-6 REPRESENT WELL H-14B WITH API#: 50-029-20580-03-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12360'MD/8951'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL RUNNING SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR DEPTHS. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: 1 6.125" BIT 8.2-9.6 PPG 1500-3200 PPM CHLORIDES 11500 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE clipped curves; all bit runs merged. .5000 Page 3 h-14b.tapx FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 6802.0 12302.0 RPX 7133.0 12309.0 FET 7133.0 12309.0 RPS 7133.0 12309.0 RPM 7133.0 12309.0 RPD 7133.0 12309.0 ROP 7142.0 12361.5 PEF 9894.0 12289.0 DRHO 9894.0 12289.0 RHOS 9894.0 12289.0 NPHI 10780.0 12274.0 FONT 10780.0 12274.0 NCNT 10780.0 12274.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUI VALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 6802.5 6803.5 6803.5 6804.5 6805.5 6806.0 6807.5 6807.5 6816.0 6817.0 6818.0 6819.0 6819.5 6820.5 6822.0 6822.5 6825.5 6826.0 6835.5 6836.5 6839.0 6840.5 6855.0 6855.5 68&0.5 6861.0 6862.5 6863.5 6868.0 6869.5 6874.0 6877.5 6881.0 6883.5 6888.5 6891.0 6896.5 6897.5 6904.5 6906.0 6912.5 6914.5 6928.0 6930.0 6936.0 6935.5 6944.5 6943.5 6960.0 6958.5 6962.5 6960.5 6964.0 6961.5 6969.0 6967.5 6980.0 6979.0 6983.5 6983.0 7001.5 7000.0 7003.5 7002.0 7009.0 7008.0 7014.0 7013.0 7020.5 7020.5 7028.0 7028.5 7043.5 7043.5 7049.0 7049.5 7053.0 7052.0 7056.0 7056.5 7059.5 7060.0 Page 4 h-14b.tapx 7063.0 7064.0 7067.0 7068.0 7071.0 7071.0 7076.5 7076.5 7081.0 7082.5 7083.0 7086.5 7092.0 7096.0 7100.0 7104.5 7102.5 7107.0 7117.0 7117.0 7126.0 7124.5 7129.0 7128.5 7135.0 7133.0 $2362.0 12360.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 7140.5 7187.0 MwD 2 7187.0 9566.0 MwD 3 9566.0 10224.0 MWD 4 10224.0 10865.0 MwD 5 10865.0 11974.0 MwD 6 11974.0 12360.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam step Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MwD API 4 1 68 40 11 PEF MWD B/E 4 1 68 44 12 ROP MWD FPH 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6802 12361.5 9581.75 11120 6802 12361.5 FCNT MWD CP30 389.71 1789.05 655.862 2989 10780 12274 Page 5 ~ r h-14b.tapx NCNT MWD CP30 20370.2 44306.5 28558.8 2989 10780 12274 RHOB MwD G/CC 2.035 3.083 2.38701 4791 9894 12289 DRHO MWD G/CC -0.16 0.712 0.103219 4791 9894 12289 RPD MWD OHMM 0.6 2000 24.0368 10353 7133 12309 RPM MWD OHMM 0.58 2000 26.3857 10353 7133 12309 RPS MWD OHMM 0.62 1916.6 9.06487 10353 7133 12309 RPX MWD OHMM 0.49 1875.41 8.03632 10353 7133 12309 FET MWD HR 0.38 83.68 3.49879 10353 7133 12309 GR MwD API 10.89 456.06 81.2797 11001 6802 12302 PEF MwD B/E 1..15 8.11 2.13731 4791 9894 12289 ROP MWD FPH 0.09 584.54 91.0679 10440 7142 12361.5 NPHI MwD PU-S 11.39 29.28 22.4689 2989 10780 12274 First Reading For Entire File..........6802 Last Reading For Entire File...........12361.5 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name. .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH DRHO 9894.0 11947.0 RHOB 9894.0 11947.0 PEF 9894.0 11947.0 NPHI 9901.5 11932.0 FONT 9901.5 11932.0 NCNT 9901.5 11932.0 GR 9906.0 11959.5 FET 9914.5 11966.5 RPx 9914.5 11966.5 RPD 9914.5 11966.5 RPS 9914.5 11966.5 RPM 9914.5 11966.5 RAT 9962.5 12020.0 Page 6 • MERGED DATA SOURCE PBU TOOL CODE MWD h-14b.tapx MAD RUN NO. MAD PASS NO. 6 1 MERGE TOP MERGE BASE 9892.5 12360.0 REMARKS: MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD CP30 4 1 68 4 2 NCNT MAD CP30 4 1 68 8 3 RHOB MAD G/CC 4 1 68 12 4 DRHO MAD G/CC 4 1 68 16 5 RPD MAD OHMM 4 1 68 20 6 RPM MAD OHMM 4 1 68 24 7 RPS MAD OHMM 4 1 68 28 8 RPX MAD OHMM 4 1 68 32 9 FET MAD HR 4 1 68 36 10 GR MAD API 4 1 68 40 11 PEF MAD B/E 4 1 68 44 12 RAT MAD FPH 4 1 68 48 13 NPHI MAD PU-S 4 1 68 52 14 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 9894 12020 10957 4253 9894 12020 FONT MAD CP30 276.73 2035.39 700.13 4062 9901.5 11932 NCNT MAD CP30 18454.5 42224.5 29619.8 4062 9901.5 11932 RHOB MAD G/CC 2.083 3.083 2.34523 4107 9894 11947 DRHO MAD G/CC -0.16 0.59 0.0888783 4107 9894 11947 RPD MAD OHMM 3.67 89.26 15.2616 4093 9914.5 11966.5 RPM MAD OHMM 3.87 87.96 14.1713 4093 9914.5 11966.5 RPS MAD OHMM 4.28 86.61 13.4985 4093 9914.5 11966.5 RPX MAD OHMM 4.79 101.75 14.0648 4093 9914.5 11966.5 FET MAD HR 52.95 179.36 109.996 4093 9914.5 11966.5 GR MAD API 11.52 130.4 29.9813 4108 9906 11959.5 PEF MAD B/E 1.15 8.11 2.03015 4107 9894 11947 RAT MAD FPH 0.02 4302.67 243.352 4103 9962.5 12020 NPHI MAD PU-S 9.01 32.99 22.4458 4062 9901.5 11932 First Reading For Entire File..........9894 Last Reading For Entire File...........12020 File Trailer Service name .............STSLIB.002 Page 7 h-14b.tapx service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 7140.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE header data for each bit run in separate files. 1 .5000 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 7187.0 06-NOV-07 Insite 74.11 Memory 7187.0 6803.0 7187.0 .0 .0 TOOL NUMBER 8.500 7138.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) Page 8 3 Polymer 9.20 58.0 9.0 950 .0 ~ ~ h-14b.tapx MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 .O MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RoP MwD010 FPH 4 1 68 4 2 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7140.5 7187 7163.75 94 7140.5 7187 ROP MWDO10 FPH 2.31 19.1 6.45149 94 7140.5 7187 First Reading For Entire File..........7140.5 Last Reading For Entire File...........7187 File Trailer service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 Page 9 • h-14b.tapx File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6803.5 FET 7132.0 RPS 7132.0 RPM 7132.0 RPX 7132.0 RPD 7132.0 $OP 7187.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9518.0 9510.5 9510.5 9510.5 9510.5 9510.5 9566.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): header data for each bit run in separate files. 2 .5000 4 09-NOV-07 Insite 74.11 Memory 9566.0 7187.0 9566.0 17.6 46.0 TOOL NUMBER 124724 228272 8.500 7138.0 Polymer 9.60 50.0 9.0 1500 4.4 1.150 100.0 .840 140.0 1.200 60.0 1.100 60.0 Page 10 ~ ~ TOOL STANDOFF (IN): EWR FREQUENCY (HZ): h-14b.tapx REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Di rection .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FPH 4 1 68 28 8 First Last. Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6803.5 9566 8184.75 5526 6803.5 9566 RPD MWD020 OHMM 0.6 1842.88 5.19219 4758 7132 9510.5 RPM MWD020 OHMM 0.58 1917.13 3.78859 4758 7132 9510.5 RPS MWD020 OHMM 0.62 1916.6 2.84045 4758 7132 9510.5 RPX MWD020 OHMM 0.62 1875.41 2.63149 4758 7132 9510.5 FET MwD020 HR 0.38 36.27 1.70405 4758 7132 9510.5 GR MwD020 API 35.05 339.73 121.08 5430 6803.5 9518 ROP MWD020 FPH 1.97 238.69 101.771 4758 7187.5 9566 First Reading For Entire File..........6803.5 Last Reading For Entire File...........9566 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 service Sub Level Name... Page 11 ~ ~ h-14b.tapx version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH RPS 9511.0 RPX 9511.0 FET 9511.0 RPD 9511.0 RPM 9511.0 GR 9518.5 ROP 9566.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10170.5 10170.5 10170.5 10170.5 10170.5 10163.5 10224.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL header data for each bit run in separate files. 3 .5000 5 13-Nov-07 Insite 74.11 Memory 10224.0 9566.0 10224.0 21.4 56.6 TOOL NUMBER 203301 130908 6.125 9566.0 Polymer 8.40 48.0 9.4 4700 8.8 .800 92.0 .430 176.0 .800 92.0 .740 92.0 Page 12 MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: h-14b.tapx Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MWD030 HR 4 1 68 20 6 GR MwD030 API 4 1 68 24 7 RoP MWD030 FPH 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9511 10224 9867.5 1427 9511 10224 RPD MWD030 OHMM 0.9 2000 99.2301 1320 9511 10170.5 RPM MWD030 OHMM 0.78 2000 130.389 1320 9511 10170.5 RPS MWD030 OHMM 0.74 665.1 22.789 1320 9511 10170.5 RPX MWD030 OHMM 0.49 1414.25 19.1495 1320 9511 10170.5 FET MwD030 HR 0.59 83.68 9.15594 1320 9511 10170.5 GR MWD030 API 11.49 456.06 56.1717 1291 9518.5 10163.5 ROP MWD030 FPH 0.81 318.89 88.2189 .1316 9566.5 10224 First Reading For Entire File..........9511 Last Reading For Entire File...........10224 File Trailer service name... .......STSLI6.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Page 13 ~ ~ h-14b.tapx File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for e ach bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10164.0 10805.0 RPM 10171.0 10812.0 RPS 10171.0 10812.0 RPD 10171.0 10812.0 FET 10171.0 10812.0 RPX 10171.0 10812.0 ROP 10224.5 10865.0 LOG HEADER DATA DATE LOGGED: 14-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10865.0 TOP LOG INTERVAL (FT): 10224.0 BOTTOM LOG INTERVAL (FT): 10865.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 59.0 MAXIMUM ANGLE: 98.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 9566.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 48.0 MUD PH: 9.0 MUD CHLORIDES (PPM): 5500 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATUR E (MT): .780 92.0 MUD AT MAX CIRCULATING TER MPERATURE: .580 125.6 MUD FILTRATE AT MT: .820 92.0 Page 14 • MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): h-14b.tapx .740 92.0 REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Redding Reading DEPT FT 10164 10865 10514.5 1403 10164 10865 RPD MWD040 OHMM 2.52 24.46 9.54902 1283 10171 10812 RPM MWD040 OHMM 2.47 21.47 9.1798 1283 10171 10812 RPS MWD040 OHMM 2.64 22.41 8.7711 1283 10171 10812 RPX MWD040 OHMM 2.89 23.25 8.52667 1283 10171 10812 FET MwD040 HR 0.8 20.23 3.19622 1283 10171 10812 GR MWD040 API 12.74 104.15 27.0047 1283 10164 10805 ROP MWD040 FPH 2.09 343.9 86.9207 1282 10224.5 10865 First Reading For Entire File..........10164 Last Reading For Entire File...........10865 File Trailer Service name... .......STSLI6.006 service sub Level Name... Version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.007 Page 15 Physical EOF File Header Service name... .......STSLIB.007 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD h-14b.tapx Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH FONT 10778.5 NPHI 10778.5 NCNT 10778.5 GR 10805.5 RPD 10812.5 FET 10812.5 RPS 10812.5 RPx 10812.5 RPM 10812.5 ROP 10865.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) STOP DEPTH 11886.5 11886.5 11886.5 11914.5 11921.5 11921.5 11921.5 11921.5 11921.5 11974.0 VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): Page 16 17-NOV-07 Insite 74.11 Memory 11974.0 10865.0 11974.0 89.6 97.3 TOOL NUMBER 232605 10603685 223565 231387 6.125 9566.0 Polymer 8.50 h-14b.tapx MUD VISCOSITY (S): 48.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 3700 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .750 90.0 MUD AT MAX CIRCULATING TERMPERATURE: .520 132.0 MUD FILTRATE AT MT: .800 90.0 MUD CAKE AT MT: .720 90.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loggin Direction .................Down Optical log .depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification slock sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FONT MWD050 CP30 4 1 68 4 2 NCNT MWD050 CP30 4 1 68 8 3 RPD MWD050 OHMM 4 1 68 12 4 RPM MWD050 OHMM 4 1 68 16 5 RPS MwD050 OHMM 4 1 68 20 6 RPX MwD050 OHMM 4 1 68 24 7 FET MWD050 HR 4 1 68 28 8 GR MWD050 API 4 1 68 32 9 ROP MWD050 FPH 4 1 68 36 10 NPHI MWD050 PU-S 4 1 68 40 11 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10778.5 11974 11376.3 2392 10778.5 11974 FCNT MWD050 CP30 458.78 1015.54 643.042 2217 10778.5 11886.5 NCNT MWD050 CP30 23545.2 35603.6 28439.5 2217 10778.5 11886.5 RPD MwD050 OHMM 3.23 67.88 17.907 2219 10812.5 11921.5 RPM MwD050 OHMM 2.97 51.46 16.3686 2219 10812.5 11921.5 RPS MWD050 OHMM 2.97 42.11 13.8084 2219 10812.5 11921.5 RPX MWD050 OHMM 2.77 38.67 12.1244 2219 10812.5 11921.5 FET MWD050 HR 0.54 36.78 3.09475 2219 10812.5 11921.5 GR MWD050 API 10.89 100.65 23.8766 2219 10805.5 11914.5 ROP MWD050 FPH 0.12 584.54 91.3114 2218 10865.5 11974 NPHI MWD050 Pu-S 16.28 27.93 22.5943 2217 10778.5 11886.5 Page 17 • h-14b.tapx First Reading For Entire File..........10778.5 Last Reading For Entire File...........11974 File Trailer Service name... .......STSLIB.007 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File TyL~e ................L0 Next Fite Name...........STSLIB.008 Physical EOF File Header service name... .......STSLIB.008 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH PEF 9892.5 12287.5 DRHO 9892.5 12287.5 RHOB 9892.5 12287.5 NCNT 11887.0 12272.5 NPHI 11887.0 12272.5 FCNT 11887.0 12272.5 GR 11915.0 12300.5 FET 11922.0 12307.5 RPD 11922.0 12307.5. RPM 11922.0 12307.5 RPS 11922.0 12307.5 RPx 11922.0 12307.5 ROP 11974.5 12360.0 LOG HEADER DATA DATE LOGGED: 19-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12360.0 TOP LOG INTERVAL (FT): 11974.0 BOTTOM LOG INTERVAL (FT): 12360.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 Page 18 • • MAXIMUM ANGLE: h-14b.tapx TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units .. .. ..... Datum specification Block sub-type...0 96.6 TOOL NUMBER 232605 1844674407370955 223565 179170 6.125 9566.0 Polymer 8.40 48.0 9.0 32000 .0 1.300 98.0 .950 136.0 2.100 98.0 1.700 98.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FONT MWD060 CP30 4 1 68 4 2 NCNT MWD060 CP30 4 1 68 8 3 RHOB MWD060 G/CC 4 1 68 12 4 DRHO MWD060 G/CC 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 RPX MWD060 OHMM 4 1 68 32 9 FET MWD060 HR 4 1 68 36 10 GR MWD060 API 4 1 68 40 11 PEF MWD060 B/E 4 1 68 44 12 Page 19 i r h-14b.tapx ROP MWD060 FPH 4 1 68 48 13 NPHI MwD060 PU-S 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9892.5 12360 11126.3 4936 9892.5 12360 FONT MWD060 cP30 389.71 1789.05 692.679 772 11887 12272.5 NCNT MWD060 CP30 20370.2 44306.5 28901.5 772 11887 12272.5 RHOB MWD060 G/CC 2.035 3.083 2.38701 4791 9892.5 12287.5 DRHO MWD060 G/CC -0.16 0.712 0.103219 4791 9892.5 12287.5 RPD MwD060 OHMM 6.13 2000 50.9515 772 11922 12307.5 RPM MwD060 OHMM 5.5 2000 44.8764 772 11922 12307.5 RPS MWD060 OHMM 5.59 71.28 10.8183 772 11922 12307.5 RPX MWD060 OHMM 5.75 41.24 9.78483 772 11922 12307.5 FET MWD060 HR 0.99 26.77 6.50977 772 11922 12307.5 GR MWD060 API 16.87 122.6 98.7017 772 11915 12300.5 PEF MwD060 B/E 1.15 8.11 2.13731 4791 9892.5 12287.5 ROP MWD060 FPH 0.09 433.99 46.45 772 11974.5 12360 NPHI MwD060 PU-S 11.39 29.28 22.1088 772 11887 12272.5 First Reading For Entire File..........9892.5 Last Reading For Entire File...........12360 File Trailer Service name... .......STSLIB.008 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.009 Physical EOF File Header Service name... .......STSLIB.009 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 6 MAD PASS NUMBER: 1 FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH RHOB 9892.5 11945.5 DRHO 9892.5 11945.5 PEF 9892.5 11945.5 Page 20 • h-14b.tapx NPHI 9900.0 11930.5 FCNT 9900.0 11930.5 NCNT 9900.0 11930.5 GR 9904.5 11958.0 RPM 9913.0 11965.0 RPx 9913.0 11965.0 RPS 9913.0 11965.0 RPD 9913.0 11965.0 FET 9913.0 11965.0 T 9961.0 12018.5 $ LOG HEADER DATA DATE LOGGED: 19-NOV-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12360.0 TOP LOG INTERVAL (FT): 9892.0 BOTTOM LOG INTERVAL (FT): 12360.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 96.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 ALD Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record TOOL NUMBER 232605 1844674407370955 223565 179170 6.125 9566.0 Polymer 8.40 48.0 9.0 32000 .0 1.300 98.0 .950 136.0 2.100 98.0 1.700 98.0 Page 21 • h-14b.tapx Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MAD061 CP30 4 1 68 4 2 NCNT MAD061 CP30 4 1 68 8 3 RHOB MAD061 G/CC 4 1 68 12 4 DRHO MAD061 G/CC 4 1 68 16 5 RPD MAD061 OHMM 4 1 68 20 6 RPM MAD061 OHMM 4 1 68 24 7 RPS MAD061 OHMM 4 1 68 28 8 RPX MAD061 OHMM 4 1 68 32 9 FET MAD061 HR 4 1 68 36 10 GR MAD061 API 4 1 68 40 11 PEF MAD061 B/E 4 1 68 44 12 RAT MAD061 FPH 4 1 68 48 13 NPHI MAD061 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9892.5 12018.5 10955.5 4253 9892.5 12018.5 FONT MAD061 CP30 276.73 2035.39 700.13 4062 9900 11930.5 NCNT MAD061 CP30 18454.5 42224.5 29619.8 4062 9900 11930.5 RHOB MAD061 G/CC 2.083 3.083 2.34523 4107 9892.5 11945.5 DRHO MAD061 G/CC -0.16 0.59 0.0888783 4107 9892.5 11945.5 RPD MAD061 OHMM 3.67 89.26 15.2616 4093 9913 11965 RPM MAD061 OHMM 3.87 87.96 14.1713 4093 9913 11965 RPS MAD061 OHMM 4.28 86.61 13.4985 4093 9913 11965 RPX MAD061 OHMM 4.79 101.75 14.0648 4093 9913 11965 FET MAD061 HR 52.95 179.36 109.996 4093 9913 11965 GR MAD061 API 11.52 130.4 29.9813 4108 9904.5 11958 PEF MAD061 B/E 1.15 8.11 2.03015 4107 9892.5 11945.5 RAT MAD061 FPH 0.02 4302.67 243.352 4103 9961 12018.5 NPHI MAD061 PU-S 9.01 32.99 22.4458 4062 9900 11930.5 First Reading For Entire File..........9892.5 Last Reading For Entire File...........12018.5 File Trailer Service name... .......STSLIB.009 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/28 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.010 Physical EOF Page 22 h-14b.tapx Tape Trailer Service name .............LISTPE gate . ...................08/03/28 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE gate . ...................08/03/28 Ori in ...................STS Ree~ Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File • scientific Technical services scientific Technical services Page 23
