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Home My WebLink About201-151 • • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, October 13, 2016 2:10 PM To: AK, GWO SUPT Well Integrity;AK, OPS GC2 OSM;AK,OPS GC2 Field O&M TL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;Zoesch, Eric;AK, OPS WELL PAD W; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington, Aras J;Wallace, Chris D (DOA) Subject: OPERABLE: Producer L-107 (PTD#2011510) All, Producer L-107 (PTD#2011510)was reported to have sustained OA casing pressure (1120 psi)above Normal Operating Limit on 09/30/16. Recorded wellhead pressures later that day were TBG/IA/OA=SSV/1620/440 psi. The well has been shut in since June 2015. The gas lift line is currently blinded. The well was reclassified as Under Evaluation for further diagnostics including an OA repressurization test which passed on 10/06/16 with a build-up rate of 10 psi/day. There are no indications of a loss in production casing integrity. This well is now reclassified as Operable. Thanks! Jack Lau (Alternate:Adrienne McVey) BP Alaska-Well Integrity Superintendent SCANNED FEB 2 12017, W:907.659.5102 C: 907.943.0296 H: x2376 From: AK, GWO SUPT Well Integrity Sent: W ay, October 05, 2016 4:17 PM To: AK, OPS GC2 • AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS EOC Specialists; Cismoski, Do • Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC Ops Lead; Zoesch, Eric, OPS WELL PAD W; 'Regg, James B (DOA) (jim.regg@alaska.gov)' (jim.regg@alaska.gov) Cc: AK, GWO DHD Well Integrity; AK, GWO`Projects Well Integrity; AK, GWO Completions Well Integrity; AK, GWO SUPT Well Integrity; AK, OPS FF Well Ops Comp Rep; i rt, Michael; Janowski, Carrie; Montgomery,Travis 3; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R; el,Troy; Worthington, Aras J; 'chris.wallace@alaska.gov' (ch ris.wa llace@alaska.gov) Subject: UNDER EVALUATION: Producer L-107 (PTD #2011510) S ined OA Pressure above Normal Operating Limit (formerly MOASP) All, Producer L-107 (PTD#2011510)was reported to have sustained OA pressure (1120 psi) above Nor Operating Limit on 09/30/16.Observed wellhead pressures later that day were TBG/IA/OA=SSV/1620/440 psi.The well been shut 1 i • Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Wednesday, October 05, 2016 4:17 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers;AK, OPS EOC Specialists; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS PCC Ops Lead;Zoesch, Eric;AK, OPS WELL PAD W; Regg,James B (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;Wallace, Chris D (DOA) Subject: UNDER EVALUATION: Producer L-107 (PTD#2011510) Sustained OA Pressure above Normal Operating Limit(formerly MOASP) Attachments: Producer L-107 (PTD#2011510)TIO Plot 2016-10-05.docx All, Producer L-107 (PTD#2011510)was reported to have sustained OA pressure (1120 psi) above Normal Operating Limit on 09/30/16.Observed wellhead pressures later that day were TBG/IA/OA=SSV/1620/440 psi.The well has been shut in since June 2015.The gas lift line is currently blinded.The well is reclassified as Under Evaluation for further diagnostics. Plan Forward: 1. Downhole Diagnostics: Cold OA Repressurization test—In Progress; current OA build-up rate less than 20 psi/day 2. Wellhead:Cold Positive Pressure Packoff Test—Inner Casing 3. Well Integrity Engineer:Additional diagnostics as needed A TIO plot is attached. Please reply if in conflict with proposed plan. NNED ' L 72017r; Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 Email: AKDCWeIlIntegrityCoordinator@BP.com From: AK, D&C Well Integr • =. .inator Sent: Monday, December 10, 2012 10:4. • To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; • ,, GC2 OSM; AK, OPS GC2 Field 0&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Danie, • AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt E iqr Qstiiro, Joleen Imam_. Project Well History File Covet", age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~vJ~ l- -~- ~ J-- Well History File Identifier Organizing i~o,,?.l [] RESGAN j Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: DIGITAL DATA /,~ Diskettes, No. [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL(~~INDY OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~WINDY Scanning Preparation , l x 30 = ~ + BY: BEVERLY ROBIN VINCENT SHERYL~WlNDY DATE;lei31 O~s/ /~--'"' = TOTALPAGES Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: BY~ BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAOES ) YES NO Is~ YES NO /si RESCANNEDB~'; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: Isl Quality Checked 1211 O/02Rev3NOTScanned.wpd STATE OF ALASKA A. .KA OIL AND GAS CONSERVATION COMMIooION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well LJ Plug Perforations U Perforate U OtherH Pull/Reset Patch 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: BP Exploration(Alaska),Inc Name: Development Exploratory ❑ • 201-151-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number:• Anchorage,AK 99519-6612 50-029-23036-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ' ADL0028241 - BRLS L-107 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,BOREALIS OIL 11.Present Well Condition Summary: c 51,E z Total Depth measured • 8950 feet Plugs measured None feeti i true vertical 7046.92 feet Junk measured None feet Effective Depth measured • 8834 feet Packer measured See Attachment feet '41 ("Cc("' true vertical 6931.81 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 20"91.5#H-40 22-106 22-106 1490 470 Surface 3010 7-5/8"29.7#L-80 26-3036 26-2620.46 6890 4790 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None NoneNone Perforation depth Measured depth 8394-8452 feet 8452-8482 feet scANNED JUN 1 1 2014 True Vertical depth 6499.33-6555.97 feet 6555.97-6585.29 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: li Intervals treated(measured): RBDMS___._MAY 15 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 440 1870 2344 1554 404 Subsequent to operation: 699 2464 3417 1600 418 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 .U Gas IJ WDSPLI I GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCCI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.Catron( BP.Com Printed Name Garry Catron Title PDC PE 1 Signature A.,,6_✓ `' Phone 564-4424 Date 4/10/2014 r 4- f/4z/y Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028241 SW Name Type MD TVD Depscription L-107 PACKER 6416 4795.26 2-3/8" 35 KB Packer L-107 PACKER 6448 4818.56 2-3/8" 35 KB Packer L-107 PACKER 8077 6193 3-1/2" Baker SABL-3 Packer m Q O CO O O O O O CU � � 0L0 � � o v o v o 0 U 0 0 0 0 s- rnoo (O0) CO CO CO CD O o 0 c- CID CO N LO CO CO N '- c- N CO M N CO CO N O CO N N d CO N CO CO , i , , , i i H (D N N '- 0) C O N pp N N M I� N N - CO CO C 6) M CO CO 0) 00 LC) CO Cr) M N CO (A O `- a- .0 (. 00 00 CO 00 00 v ca a , ▪ Tr 2- • N Co N d' (fl co co N C) (V N N N N '- C CO CO Q 3 J H Q OoOOo CO , CO i CO CO Cr) = J J J J J J N CD r-- N N O �C fn ()) N O O) U C - 00 CV N 00 N N p M c N N M M M t +-' Ln O Lf) V 0( Lo C 0 M 0 0 0 V d00 co 00 J O O O W Z H O O CC m O < o c D D D U 0_ CL U) H TREE . 3-1/8"5M CNV 'A LFEAD= 11"FMC L-107 SAFE. 1NOTES: ACTUATOR= NA N11AL KB.81 77.3' BF.EL1 V— 53.9' "CONDUCTOR, —1 ? KOP= 1000 D OM 1022' H 7-5/8"TAM PORT COLLAR Max Angle= 53'@ 4801' Datum MD= 8576' I I 1913' 3-t/2"FES X NP,ID=2.813" Datum 1VD= 6600'SS 7-5/8"CSG,29.7#,L-80 BTC-M,D=6.875" — 3036' ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 2116 2011 38 KBG-2 DMY NT 0 01/26/05 3-1/2"AD-2 PACK OFF PATCH, — 6416' -6451' 6 3078 2647 51 KBG-2 DOME NT 16 03/18/14 D=1.48"(03/18/14) 5 4278 3407 52 KBG-2 DMY NT 0 10/09/12 4 5378 4097 50 KBG-2 SO NT 16 03/18/14 Minimum ID = 1.48" @ 6416' 3 6424 4801 43 KBG-2 *DMY NT 0 10/09/12 2 7302 5490 32 KBG-2 DMY NT 0 10/09/12 3-1/2" AD-2 PACKOFF PATCH 1 8001 6121 19 KBG-2 DMY NT 0 10/09/12 `STA#3=DMY HAS EXTENDED PACKING-BEBN) PATCH I I 8056' —13-1/2"HES X NP,D=2.813" 8 g- 807T —15-1/2"X 3-112"SA BL PKR,ID=2.78" II i 8100' —13-112"HES BPXNP,D=2.75" 3-1/2"TBG,9.2#,L-80 BT-M,.0087 bpf,D=2.992" H 812V 3-1/2"TBG STUB(06/16/05) --{ 8124' I 1 I 8128' —{5-1/2"X 3-1/2"UNIQUE OVERSHOT 3-1/2"TBG,92#,L-80,IBT-M, .0087 bpi,D=2.992" —I 8156' 8156' —3-1/2"BKR G22 LOCATOR 15-1/2"CSG, 15.5#,L-80 BTC-M,ID=4.950" Ht. 8166' 1 .-- SEAL ASSEMBLY,ID=3.00" 816T —'5-1/2•x 5"x0 SBE 8 PBR D=4.00" 8168' —{5"X 3-1/2"XO SUB,D=2.96" pI8219' —13-1/2"FES X NP,ID=2.813" PERFORATION SUMMARY REF LOG SVS RESISTIVITY LOG ON 08/27/01 8240' —I 3-1/2"FES X NP,ID=2.813" ANGLE AT TOP F$RF 13°@ 8394' Note:Refer to Production DB for historical perf data = 8373' —110'PUP JT W/RA TAG SIZE SPF INTERVAL Opn/Sgz SHOT SO7 — 2-1/2" 6 8394-8452 0 09/17/01 2-1/2" 6 8452-8482 0 09/16/01 11 8722' —I20'PUP JT W/RA TAG PBTD H 8834' I 11111 3-1/2"CSG,9.2#,L-80,NSCT,D •11111=2.992" — 8933' ,1111111111 1.1.1.1.1. DATE REV BY COMMBJTS DATE REV BY COMVEYTS BOREALIS LW 08/31/01 N9ES INTIAL COMPLETION 03/18/14 PJC REFORMAT LIAR/CSG/TBG WELL: L-107 01/28/05 N9ES RWO 03/24/14 SWC/JM3 C/O PACKOFF/GLV C1O(3/18/14) PERMIT No:"2011510 01/18/13 NW/10.4D GLV C/O(01/04/13) API No: 50-029-23036-00 04/22/13 DBMJMD GLV C/O(04/03/13) SEC 34,T12N R11E 2397'NSL&3646'WEL 03/18/14 SWC/PJC DMY GLVS(03/14/14) 03/18/14 SWC/PJC PULU RESET PATCH(03/15/15) BP Exploration(Alaska) N N W N N -o 0 CCif) W ,r Z 0 m w z 5"' as 0 a) F- J N CC O c w n I a U) 0 Z W > - I, J Cl) F- 0 ¢ O 0 N _J 3 X d F- o o 2 0 C • o Fes- CO o MI G D v^ @jam C7gr) 2 � www o LL 6 J Cn w X U) N U) CO coO N W _ V. co ._ LL -- x M U) M 4520 Lv • W LL 0 U O 0 J cn a- co '�7' J MO --� - C J c_ Q .cuUwwO w � F- 6) Q = c/) MEc° O o C in � � o J --en,-- o Cr N moY Uw1-- a �tsinvF- X 2E 't_ � N �oMcn :(5-2 NI. N �z ,tU X00 IL „JD 1. 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C —O C co O O Ca.-0 X E Q N O u_ (D x a 0- a) ,> N m G) Q ~ In C - O /,@. • 2) -0 N Q Or a) 3 O `/ p 2 -0a Xs"BH � r -0 O C N m _ N O O iv N 2 ao cp 2 � O C H iu 4 F_- C w N ro _ . 2 uu)iN- 0U) co oJi� wc) 2 -E a) 2 o 5 _ _ _ _c O �MI = U) NN � tnN � N � O N U , pUOT "O as w a. 0 - O J U) O N U) (8_,D 17) O C - -0 2 •Nm o '7) > N 0 r -0)- c.5 J M W LC) O O N O 2 a 2 L O Q aH u) O- Q� VI' C U) � (nM m0x oo0 ^ O - X2, 0) i � F_ ra -4 a) ?:2 — N � � Ow_ v ACL ,t cc O .a N •D mLO � -0 (NI co co cc M LL o o < J LWL O N W 'O OM O (n a O 4 p p CO p J i� U � 0oO � 0 '' OO ° -Ow &3 � � o ro U E. cii Lis T.: 0 QQpp0LLOO2F- < 0 ~ H a rD QQ 0_U) ..--0 Q § Lo CO ' 0 < * U � < OHUU) 0- 02 ( T — F- -c-1---) a_ o0 ii -•-• _c C � (n ,bn � m (~i) z_ u_ o cZH o0a a'11 La- < o ° 1EN 03 > (nNCOOOWU) LL -) W (/) LLO_ ZW EoQ -C •N •N U) C .- v } � owQO = u_< 0Hwi) z HO 3 c, co � M � cn CI TYwOJ > 00UC7 0o0 (� w0 NQa o ' m -NCDM 0) c� OLL Y W a = Y W Q OOU) � of= 0) pH a 2 x as 2H 1 — 2 - N C) 2 - H2 O v) Ci — r — O cD OO_ U00QQ= NC12 ¢ W NQcCH O 5 m c) , c- 0- ° CC2z = wwoT ¢ J - OTQOw 70 *. C Ems .- C LLwaN0NLL. c5NU) Nu_ (4) NLLJ 8 O ? � OL U O 0 � mQ9r-) 0_ _jr .,j- o rod W TI Q o ° ° � -cs cp UJ0E- U) ZU) JH (oZU) -IHU) � Ow u) vJN a) > * D < wEC < Dw Q 2) W EC * in � .� in o u) N M « a- HU) J W JO_ U @) a: JO_ U) J : H an •a a_co _ - 0 > T c o N N IC) IC) .,-- c--;5 M Co 0 2 / co - \ o / \ \ \ :4- / / D { \ \ - TD Co c w \ \ ) co . a x \ w Li_ m \ e / 6 I CL- -Y $ f /\ a_ CC \ \� / o \ \ E f u o \ @e = cc o _F » . O A ' k 09 ® - u �2 x72 n a) 151 -0 / G / a I Z _1 ® � � � \ a ° \ � a E ± / \ 4 0 � 2 ?G - mss ƒ I wmm / / Z _ CM » O c E w - m o m � \ c / / 72 % % - �oo \ ƒ - © z � k . ° w O0 <E ‹ d A © 7\ \ \ 2 � � ¥ g MIgE — E w IAA \ G \ s� •,- oe - O = 0 : / ƒ � � ¢ + ± c E w u a � n\ a_ - y0I / m / / / / ® 99 ± a) < m & : 2 < O U- 5 U CC + 3 \ r n \ >. 4, U) / 0 > AA J / 2 �I / ZOT 1 G Q9 / \ 7 / $ ƒ � ƒ J /_ E / ^ / @ _� / \ � \ \ ,r CI © �md- c00J \ E / k \ o \ zz \ \ � � � z / / / / E \ D LI \ / (30 Z 20W0u 5AO / / zz / / \ 0 - � eeR32c � 2 m 20AA I- --I 1Wf / � \ \ / \ LEA \ \ � / W Z oZOOZau —I . 0E@u - ee \ 0 { \ 7 i i 7 0_ / 2 0_ \ 7 $ / 0_ o_ $ $ : # -,:i- ,--- / n # \ \ ' STATE OF ALASKA RECEIVED A•KA OIL AND GAS CONSERVATION COM•ON JAN 0 7 2013 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon L] Repair Well Lf Plug Perforations LJ Perforate LI Other AOGCC Performed: Alter Casing ❑ Pull Tubing] Stimulate - Frac ❑ Waiver ❑ Time Extension Tb Pak/4 • Change Approved Program ❑ Operat. Shutdown Stimulate - Other ❑ Re -enter Suspended WeII❑ T 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Na me: BP Exploration (Alaska), Inc Development El • Exploratory ❑ 201 -151 -0 • 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 — 50- 029- 23036 -00 -00 ' 7. Property Designation (Lease Number): _ 8. Well Name and Number: ADL0028241 • BRLS L -107 ' 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, BOREALIS OIL • 11. Present Well Condition Summary . Total Depth measured 8950 . feet Plugs measured None feet true vertical 7046.92 , feet Junk measured None feet Effective Depth measured 8834 feet Packer measured See Attachment feet true vertical 6931.81 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 20" 91.5# H-40 22 - 106 22 - 106 1490 470 Surface 3010 7 -5/8" 29.7# L -80 26 - 3036 26 - 2620.46 8890 4790 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner None None None None None None Perforation depth Measured depth 8394 - 8452 feet 8452 - 8482 feet True Vertical depth 6499.33 - 6555.97 feet 6555.97 - 6585.29 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 2013 Treatment descriptions including volumes used and final pressure: SCANNED JAN 2 5 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 875 • 4513 1966 1342 478 Subsequent to operation: 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development al - Service ❑ Stratigraphic 0 Daily Report of Well Operations X 16. Well Status after work: Oil , 0 . Gas ❑ WDSPLJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCE 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 , Phone 564 -4424 Date 1/7/2013 / /-/(i3 "--,'\- -.' " ; `-3 Form 10-404 Revised 10/2012 e-- P4,_* j Submit Original Only • • Packers and SSV's Attachment ADL0028241 SW Name Type MD TVD Depscription L -107 PACKER 6419 4720.14 2 -3/8" 35 KB Packer L -107 PACKER 6448 4741.26 2 -3/8" 35 KB Packer L -107 PACKER 8077 6115.7 3 -1/2" Baker SABL -3 Packer Casing / Tubing Attachment ADL0028241 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 20" 91.5# H -40 22 - 106 22 - 106 1490 470 PATCH 32 2 -3/8" 4.7# L -80 6419 - 6451 4797.44 - 4820.76 11200 11780 PRODUCTION 8145 5 -1/2" 15.5# L -80 24 - 8169 24 - 6281.12 7000 4990 PRODUCTION 764 3 -1/2" 9.2# L -80 8169 - 8933 6281.12 - 7030.05 10160 10530 SURFACE 3010 7 -5/8" 29.7# L -80 26 - 3036 26 - 2620.46 6890 4790 TUBING 8105 3 -1/2" 9.2# L -80 23 - 8128 23 - 6241.76 10160 10530 TUBING 45 3 -1/2" 9.2# L -80 8124 - 8169 6237.93 - 6281.12 10160 10530 • s • S Daily Report of Well Operations ADL0028241 SUMMARY * ** WELL SHUT IN ON ARRIVAL ** *(patch) PULL P -PRONG FROM 8073' SLM. 12/4/2012 * * * *CONT JOB ON 12- 5- 12 * * ** * * * *CONT JOB FROM 12-4-12**** (patch) PULL 3 -1/2" PX -PLUG BODY FROM 8078' SLM /8100' MD. DRIFT W/ 2' 1 -7/8" STEM, 2.50" CENT, 1 -3/4" S- BAILER TO TD © 8429' SLM/8451' MD * *57' OPEN PERFS /33' FILL * *(frac sand in bailer) RUN TAG & FLAG STA #7 W/ 3 -1/2" OK -1 @ 6404' SLM/6424' MD. SET 3 -1/2" AD -2 TUBING STOP © 6428' SLM/6448' MD. SET 3 1/2" AD -2 HIGH FLOW PACK OFF (bottom element at 6447' MD) SET 3 1/2" PACK OFF TEST TOOL @ 6425' SLM. 12/5/2012 PERFORM CMIT -Tx IA TO 2000 psi(PASS). PULL TEST TOOL. * * * *CONT JOB FROM 12- 5 -12 * ** *(patch) SET 3 -1/2" AD -2 HIGH FLOW PACKOFF, 10' x 2 -3/8" PUP, 10' x 2 -3/8" PUP, 4' x 2 -3/8" PUP, XO, STINGER @ 6427' SLM/6447' MD. SET 3 -1/2" PACK OFF TEST TOOL @ 6400' SLM. MIT -T TO 2000 psi (PASS), PULL TEST TOOL. SET 3 -1/2" AA TUBING STOP @ 6399' SLM/6419' MD. MIT -IA TO 3000 psi (PASS) .bottom element at 6448' MD / top element at 6421' 12/6/2012 MD ** --_ - - -.. ** *WELL SHUT IN UPON ARRIVAL * ** SET 3 1/2" WHIDDON ON PATCH © 6419' MD. 1/2/2013 ** *CONTINUED ON 1 -3 -12 WSR * ** ** *CONTINUED FROM 1 -2 -13 WSR * ** PULL STA#4 INT -DGLV @ 5360' SLM/5378' MD PULL STA #6 INT -DGLV @ 3055' SLM /3078' MD SET STA# 6 INT -LGLV @ 3055' SLM /3078' MD ATTEMPT TO SET STA #4 W /NO SUCCESS 1/3/2013 * * *CONT. ON 1 -4 -13 WSR * ** * * *CONT. FROM 1 -3 -13 WSR * ** SET STA INT -OGLV © 5360' SLM/5378' MD PULL 3 -1/2" WHIDDON CATCHER SUB @ 6390' SLM 1/4/2013 ** *WELL S/I ON DEPARTURE * ** TREE= 3118" SMCNY • SA. NOTES: WEl"HE' °_ " °RC L 107 ACTUATOR= NA KB. 9-EV = 762 BF ELEV = 539 - - - - KOP= 1000' MIX Angle = 53° 64801' L 1 022' H7-5/8" TAM PORT COLLAR I Datum ND = 8576' (Mum 7VD = 6600' SS I I I 1913' 1H3 112 NP, D= 2.813" I 17 -5/8" CSG, 29.7 #, L-80, D = 6.875" I-1 3036' I , ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 2116 2011 38 KBG-2 DMY NT 0 01/26/05 Minimum ID =1.48" @ 6419' 6 3078 2647 51 KBG-2 DMY NT 0 02/19/11 3 -1/2" AD -2 PACKOFF PATCH 5 4278 3407 52 KBG-2 DMY NT 0 10/09/12 4 5378 4097 50 KBG-2 DMY NT 0 02/19/11 3 6424 4801 43 KBG-2 'DM1' PIT 0 10/09/12 2 7302 5490 32 KBG-2 OW' NT 0 10/09/12 1 8001 6121 19 KBG-2 CON PIT 0 10/09/12 'STA #3 = MN HAS DaE DED PACKING - BEHIND PACKOFF PATCP 1 6419' - 6451' I-13-1/2' AD-2 PACK OFF PATCH, = 1.48* D (12106/12) PERFORATION SUMMARY Z, REF LOG: SWS RESISTIVITY LOG ON 08/27/01 I ' I 8066' H3-1/2" (- N D S X P, = 2,813" I ANGLE AT TOP FatF: 13° @ 8394' Note: Refer to Ftoduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE g" 8077' H5 -1/2" X 3 SABL PKR, D= 2.78' I 2 -1/2" 6 8394 - 8452 0 09/17/01 2 -1/2" 6 8452 - 8482 0 09/16/01 8100' I— j3- 1 /2' t-ESX MP, D =2.75J I3 -1/2' TBG, 9.2#, L - 80 BT - M, .0087 bpf, D= 2.992' J—I 8121' ( 8124' I— I TOP OF 3 -1/2" TBG STUB (01/16/05) I 13 -1/2" TBG, 9.2#, L -80, BT -M, .0087 bpf, D = 2.992" H 8166 I 8128' I-j OV 62SHOT I I 5 CSG, 15.5#, L - 80, BTC, D = 4.950' H 8156' I 8157 —ITOP OF BKR PBR, D = 4.00" I5 -1/2' X 3 -1/2' CSG XO, D = 2.968' H 8168' I 8169' H3 -1/2" BKR SEAL ASSY, D = 3.00" I I 8219' H 3 -1 /2" I-ES X NP, D= 2.813' I 8240' H3- 1 /2 "I-ESX MP, D= 2.813" I 8373' --110' P JT W / RA TAG I I 8722' H20' PUP JT W/ RA TAG I I PBTD - I 8834' I 1111• • • • • • 1 3-1/2' CSG, 9.2#, L -80, NSCT, D = 2.992' —I 8933' ,1,• 1.tt1 DATE REV BY COMMENTS DATE REV BY CONVENTS BOREALIS UNIT 08/31 /01 CH!KAK ORIGINAL COMPLE(101 09/28/12 CDJ/JMD 3-1/2" FES XN NP CORRECTION WELL L -107 01/28/05 AM/BB l VO 10/24/12 LBG.MD GLV CIO 8 SET PX PLUG (10/09/12) P92MT No: "'2011510 12/30 /02 DAC/KK GLV CORRECTIONS 12/13/12 SWC/JMD FULL PX PLUG/SET PATCH (12/05- 06/12) AR No: 50-029- 23036 -00 04/08/03 DRS/iP TVD/M3 CORRECTIONS SEC 34, T12N R11 E 2397' NSL & 3646' WEL 04/21/03 JCANTLH GLV UPDATE 03/02/11 MICIPJC GLV 00 (02/19/11) BP Exploration (Alaska) • • Peci - 107 Pr6 Zi9lisl0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] R1 /o/ ( z, Sent: Thursday, October 11, 2012 6:19 AM I To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Kirchner, Carolyn J Cc: AK, D &C DHD Well Integrity Engineer; Climer, Laurie A Subject: NOT OPERABLE: Producer L -107 (PTD #2011510) MIT -IA Failed All, Producer L -107 (PTD # 2011510) failed an MIT -IA after dummy gas lift valves were set indicating a lack of competent barriers in the wellbore. The well has been secured with a down hole plug and is reclassified Not Operable until integrity is restored. Thank you, SCANNED APR 0 9 2013 Mehreen Vazir BPXA Well Integrity Coordinator From: AK, D &C Well Integrity Coordinator Sent: Saturday, September 15, 2012 8:39 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Kirchner, CarolyA J Cc: AK, D &C DHD Well Integrity Engineer; Walker, Greg (D &C) / Subject: UNDER EVALUATION: Producer L -107 (PTD #2011510) Sustained IA Pressure / Over MOASP All, Producer L -107 (PTD # 2011510) has confirmed sustained casing pressure on the IA over MOASP. The tubing /IA /OA pressures were equal to 200/2200/560 psi on 09/12/.2012. The well is reclassified as Under Evaluation and may remain on production while diagnostics are •erformed. The plan forward: 1. DHD: Perform TIFL 2. WIE: Evaluate TIFL results for gas lift val a change out A TIO plot and wellbore schematic are a- ached for reference: « File: L - 107 TIO Plot 09- 15- 12.do' » « File: L- 107.pdf » Thank you, 1 • • it�. -tv -7 Regg, James B (DOA) Zv I) 51 0 From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator ©bp.com] I Sent: Saturday, September 15, 2012 8:39 PM 1 ((7f z To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Kirchner, Carolyn J Cc: AK, D &C DHD Well Integrity Engineer; Walker, Greg (D &C) Subject: UNDER EVALUATION: Producer L -107 (PTD #2011510) Sustained IA Pressure Over MOASP Attachments: L -107 TIO Plot 09- 15- 12.docx; L- 107.pdf All, Producer L -107 (PTD # 2011510) has confirmed sustained casing pressure on the IA'over�l�7l177RSF'" Ttrev tubing /IA /OA pressures were equal to 200/2200/560 psi on 09/12/2012. The well is reclassified as Under Evaluation and may remain on production while diagnostics are performed. The plan forward: SCANNED MAY 0 7 2D13 1. DHD: Perform TIFL 2. WIE: Evaluate TIFL results for gas lift valve change out v A TIO plot and wellbore schematic are attached for reference: «L - 107 TIO Plot 09 15 12.docx» «L 107.pdf» C(' Thank you, •C Z & ps ktckfr = ',s -x ,' Mehreen Vazir BP Alaska - Well Integrity Coordinator a WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinator ftBP.com 1 PBU L -107 PTD #2011510 9/15/2012 TIO Pressures Plot Well L -107 • Thu 3 OO — IA —�— 2 000 - OA • . I \ OOA — On O0- • 06+16/12 0&23+12 0&30'12 07/07112 0714+12 0727;12 0728/12 084)4712 08+11/12 08/18112 08/25212 09/311/2 09,'08+12 0921512 • TREE = 3 -1/8" 5M CMi • SAFETY NOTES: WELLHEAD = 11" FMC M .< . ACTUATOR = NA L-1 07 KB. ELEV = 76.2' BF. ELEV = 53.9' KOP = 1000' Max Angle 53 @ 4801' "' 1022' H7-5/8" TAM PORT COLLAR I Datum MD = 8576' Datum TV D = 6600' SS 1 1 I 1913' I- 13 -1/2" HES X NIP, ID = 2.813" I 17-5/8" CSG, 29.7 #, L -80, ID = 6.875" I--I 3036' I Minimum ID = 2.750" @ 8100' GAS LIFT MANDRELS 3 -1/2" BPX NIPPLE L ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 2116 2011 38 KBG -2 DMY INT 0 01/26/05 6 3078 2647 51 KBG -2 DMY INT 0 02/19/11 5 4278 3407 52 KBG -2 DOME INT 16 02/19/11 4 5378 4097 50 KBG -2 DMY INT 0 02/19/11 PERFORATION SUMMARY 3 6424 4801 43 KBG -2 DOME INT 16 02/19/11 REF LOG: SWS RESISTIVITY LOG ON 08/27/01 2 7302 5490 32 KBG -2 DOME INT 16 02/19/11 ANGLE AT TOP PERF: 13 @ 8394' 1 8001 6121 19 KBG -2 SO INT 22 _ 02/19/11 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -1/2" 6 8394 - 8452 0 09/17/01 2 -1/2" 6 8452 - 8482 0 09/16/01 1 1 I 8056' I — I3 - 1/2" HES X NIP, ID = 2.813" I 3 1 8077' H5 -1/2" X 3 -1/2" SABL PKR, ID = 2.78" I I I I 8100' I- 3 -112" HES BPX NIP, ID = 2.75" 13-1/2" TBG, 9.2 #, L -80 IBT -M, .0087 bpf, ID = 2.992" H 8121' 8124_ TOP OF 3-1/2" TBG STUB (01/16/05) $128' — UNIQUE OVERSHOT I 13-1/2" TBG, 9.2 #, L -80, IBT -M, .0087 bpf, ID = 2.992" I-I 8156' I 5-1/2" CSG, 15.5 #, L -80, BTC, ID = 4.950" H 8156' I 8157' I—I TOP OF BKR PBR, ID = 4.00" ' 5 -1/2" X 3 -1/2" CSG XO, ID = 2.968" H 8168' E--- 8169' H3-1/2" BKR SEAL ASSY, ID = 3.00" v 1 8219' H3-1/2" HES X NIP, ID = 2.813" I N = ! 6-7 Or3i I 8240' H3-1/2" HES X NIP, ID = 2.813" I 8373' H 10' PUP JT W / RA TAG I 8722' H20' PUP JT W / RA TAG I I PBTD I-{ 8834' , � �� T 1 4 r � !l 1 � �� . 13-1/2" CSG, 9.2 #, L -80, NSCT, ID = 2.992" H 8933' 14A41. DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 08/31/01 CH /KAK ORIGINAL COMPLETION 10/18/05 SRB/TLH DRLG DRAFT CORRECTIONS WELL: L -107 01/28/05 AM /BB RWO 03/02/11 MJC/PJC GLV C/O (02/19/11) PERMIT No: 2011510 12/30/02 DAC/KK GLV CORRECTIONS API No: 50- 029 - 23036 -00 04/08/03 DRS /TP TV D /MD CORRECTIONS SEC 34, T12N R11 E 2397' NSL & 3646' WEL 04/21/03 JCM/TLH GLV UPDATE 05/02/04 GJB /KAK GLV C/O BP Exploration (Alaska) ~~ BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 r~rr9 ry 4,{~pTy~° v /~} ~~ k:?~:.ei~l,A~M~t+ri4~~ : ~~~r~ ~.t S~ ;~ L:IVJ August 14, 2009 ~ bp ~~ ~~~~6~' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L-Pad Dear Mr. Maunder, 0 C T 0 5 2009 ~1ia~s~Ca ~ii ~e Gas Cons. Gommi~sion Anchora~~ ao,- ,~ 1 ~-i p/ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ! ~- BP Exploration (Alaska ) Inc. Surface Casing by Conductor Mnulus Cement, Corcosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) e~e L pad 8/13/2009 Well Name PTD # API # Initial to of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrasion mhibitod sealant date ft bbls ft na al L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L-02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 62 NA 57.8 6/29/2009 L•101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need To Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 516l2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6l2009 L-108 2021090 50029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2,9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 3162 6/29/2009 L-111 2020300 50029230690000 NA 4,7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-114A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0,5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 20t1670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 202U640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L-121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 ~-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 1-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 5~029231910000 NA 1.8 NA 13.5 6/26/2009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-270 2031990 50029231870000 NA 325 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L-214A 2060270 50029232580100 NA 025 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 late bbckin conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 50029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 500292328t0000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 50029233090000 NA 1.8 NA 17 6/27/2009 . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marl<:er.doc ) STATE OF ALASKA'\ RE'" ALASKA OIL AND GAS CONSERVATION COI\,II\11ISSION .., REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): 77.3' 8. Property Designation: ADL 028241 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): f:lve FEB I 5 2005 Alaska Oil & 0 Ot~~ptWt ~ge 0 Time Extension 181 Repair Well 0 Plug Perforations 0 Stimulate 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 4. Current Well Class: 181 Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 201-151 6. API Number: 50-029-23036-00-00 9. Well Name and Number: PBU L-107 10. Field / Pool(s): Prudhoe Bay Field / Borealis Pool 106' 3010' feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Burst Collapse 20" 106' 106' 1490 470 7-5/8" 3036' 2620' 6890 4790 5-1/2" x 3-1/2" 8933' 7030' 7000 4990 SCANNED) FES 1 8 2.005 8950 7047 8834 6932 8909' 8394' - 8482' 6499' - 6585' 3-1/2",9.2# L-80 8156' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2" x 3-1/2" 'SABL' packer; 3-1/2" HES 'X' Nipple 8077' 1913' 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS BFL FEe 1 6 2005 Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure 454 1,254 1 ,400 601 2,442 1,560 15. Well Class after proposed work: 0 Exploratory 181 Development 0 Service 16. Well Status after proposed work: 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 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: Contact Shane Gagliardi, 564-5251 N/A Oil-Bbl Prior to well operation: 943 Subsequent to operation: 1 ,307 14. Attachments: 0 Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Printed Name Terrie Hubble s¡gnature/1OAII;.L ~J!I/R Form 1 0-404 Revis~0412'004 Tubina Pressure 340 240 Title Technical Assistant DrG \ ~~t ': , ": "~I~~~" ',¡ (/¡ Date O~!''I{ OS Prepared By NameINumber: Terrie Hubble, 564-4628 Submit Original Only ') ) BP EXPLORATION Operations Summary Report Page 1 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-107 L-107 WORKOVER Start: Rig Release: Rig Number: 1/5/2005 Spud Date: 8/18/2001 End: 1/7/2005 Date Frøm".To Hours Task Code NPT Phase qesériÞti()~ofQþerØti<>ns 1/12/2005 09:00 - 12:00 3.00 MOB P PRE Blow down steam and water lines in pits, disconnect service lines, jack up and pull pits away from sub. Move sub off well L-104 12:00 - 15:00 3.00 MOB P PRE Lay mats and herculite for sub. Spot and level sub over well L-107, spot pits and cuttings tank. Hookup service lines, and power to pits. 15:00 - 17:00 2.00 RIGU P PRE R/U circulating lines to tree and cuttings tank, install secondary valve on lA, take on seawater Accept Rig @ 15:00 hrs 1/12/2005 17:00 - 19:00 2.00 RIGU P PRE Rig up and pump open SSV, Rig up lubricator and pull BPV, zero pressure on annulus and tubing. 19:00 - 21 :30 2.50 CLEAN P DECOMP Pressure test lines to 2,500 psi, pump down 5.5" X 3.5" annulus and displace 27 bbls diesel from tubing @ 2 bpm ,400 psi, taking returns to cuttings tank. 21 :30 - 00:00 2.50 CLEAN P DECOMP Switch valves and pump down tubing @ 2 bpm, 420 psi, pump 50 bbl soap sweep, increase rate to 4 bpm @ 695 psi, after recovering diesel from annulus, (recovered 30 bbls diesel). continue circulating sweep around. shut down pumps. zero pressure on annulus and tubing. 1/13/2005 00:00 - 00:30 0.50 WHSUR P DECOMP Blow down lines, Install TWC and test from below to 1,000 psi. 00:30 - 01 :30 1.00 WHSUR P DECOMP Nipple down tree and adapter flange, inspect lifting threads on tubing hanger. 01 :30 - 03:00 1.50 BOPSUP P DECOMP Nipple up BOP, riser and mouse hole. 03:00 - 03:30 0.50 BOPSUP P DECOMP Rig up BOP test equipment. 03:30 - 06:30 3.00 BOPSUR P DECOMP Test BOP and related equipment to 250 psi low, 3,500 psi high, as per Nabors testing procedure, Chuck Scheve with AOGCC waived witness of BOP test 06:30 - 07:00 0.50 BOPSUP P DECOMP Blow down choke manifold, choke and kill lines, rig down test equipment. 07:00 - 07:30 0.50 BOPSUP P DECOMP Service rig and topdrive. 07:30 - 09:30 2.00 WHSUR P DECOMP Rig up lubricator and extension, pull TWC, rig down lubricator. 09:30 - 15:00 5.50 PULL P DECOMP Make up landing joint, BOLDS, unseat hanger @ 135k, attempt to pull seal assembly out of PBR, pulled max of 195k, pumping through lower GLM @ 385 gpm, 3480 psi. working string 75k to 195K, unable to pull seals from PBR. 15:00 - 18:00 3.00 DUMRN X DPRB INTERV Land hanger, lay down landing joint, blow down top drive, Rig up Schlumberger slick line unit, trouble shoot and repair hydraulic problem with slick line unit. 18:00 - 21 :00 3.00 DUMRN C INTERV RIH with slick line, set DGLV in lower GLM @ 8,079, POH with slick line tools, hung up in SSSV work through, POH with slick line. 21 :00 - 21 :30 0.50 PULL C DECOMP Rig down slick line unit and related equipment 21 :30 - 00:00 2.50 PULL C DECOMP Make up landing joint, Pickup on tubing srting to 195K, apply 1,000 psi to tubing to assist pulling seals from PBR, work string from 75k to 195k with 1,000 psi on tubing, unable to pull free. Mobilize Schlumberger E-Line unit, for tubing cut. 1/14/2005 00:00 - 01 :30 1.50 PULL N DPRB DECOMP Continue working string from 75K to 195k, until Schlumberger arrived on location. 01 :30 - 03:00 1.50 CHEM N SFAL DECOMP Spot E-line unit, drum brake on E-line truck would not release due to cold hydraulic fluid, apply air heater to warm up fluid, brake released once fluid warmed up. 03:00 - 04:30 1.50 CHEM C DECOMP Set tubing in slips with 140k tension, PJSM Schlumberger and Printed: 1/31/2005 8:02:31 AM ) -) Page 2 of 9 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-107 L-107 WORKOVER Date From - To Hours Task Code NPT Phase 1/14/2005 1.50 CHEM C 2.00 CHEM C DECOMP DECOMP 03:00 - 04:30 04:30 - 06:30 06:30 - 08:00 1.50 CLEAN C 08:00 - 13:30 5.50 DHB C 13:30 - 16:00 2.50 DHB C 16:00 - 18:30 2.50 EV AL C 18:30 - 19:30 1.00 CLEAN C 19:30 - 21 :00 1.50 CLEAN C 21 :00 - 00:00 3.00 DHB C 1/15/2005 00:00 - 06:00 6.00 CLEAN C DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP 06:00 - 07:00 1.00 CLEAN C DECOMP 07:00 - 08:30 1.50 CLEAN C DECOMP 08:30 - 10:00 1.50 PULL C DECOMP 10:00 - 12:00 2.00 PULL C DECOMP 12:00 - 12:30 0.50 PULL C DECOMP 12:30 - 13:00 0.50 CHEM C DECOMP 13:00 - 14:30 1.50 DHEQP C DECOMP 14:30 - 19:00 4.50 DHEQP C DECOMP 19:00 - 21 :00 2.00 FISH STUC DECOMP x Start: Rig Release: Rig Number: Spud Date: 8/18/2001 End: 1/7/2005 1/5/2005 Description of Operations all rig personnel, rig up e-line unit, arm tubing punch. RI H with tubing punch wlCCL to 8,130', Locate collar on first full joint of tubing above PBR. punch 91/4" holes @ 8,130', POH with e-line. Rig down E-line and related tools. R/U and circulate bottoms up, 4 bpm @ 825 psi, (no sand at bottoms up) Pump 12 bbl high vis sweep around, 6 bpm @ 1,750 psi, (no sand several small pieces of scale) Lay down landing joint, Mobilize tools for LIB and junk catcher retrieval. Rig up e-line. RIH with 2.75" gauge ring to top of junk catcher at 8,227' (E-line measurement) POH with gauge ring and lay down same. Make up 2.750" LIB on e-line and RIH to the top of junk catcher @ 8,227', POH with LIB. Lay down and inspect. LIB showed fish neck of junk catcher Rig down Schlumberger E-line unit and related equipment. Spot and rig up Schlumberger slick line unit, make up Junk catcher retrieving tool. RIH with junk catcher retrieving tool to 8,227', engage tool, POH and lay down junk catcher and retrieving tool. Make up dump bailer, load bailer with sand approximately 15 Ibs, RIH to PX plug set in X nipple at 8,219', dump sand on top of plug, POH with bailer, and re-Ioad bailer, made 3 runs to dump 50 Ibs of sand on top of plug. Rig down slick line, Pump 10 bb113% EMI 920 lube pill around, 250 gpm @ 1590 psi. Make up landing joint and pickup string to 190k, set slips. M/U TIW valve, Schlumberger pack off and pump in sub to landing joint. Rig up Schlumberger e-line. RIH wI string shot to bottom of seal assembly @ 8,169', shoot on depth, POH with same. RID E-line, latch on to landing joint, attempt to pull seal assembly, pulled to 190k, no go. PJSM wlSchlumberger, chemical cut tubing. R/U E-line, RIH with chemical cutter, to 8,132' tie in with CCL, detonate charge cut tubing @ 8,132', no indication of cut. POH with chemical cutter at 4,000' tool hung up, anchor dogs on tool would not retracted, rig up and pump down tubing with annular shut, pressured up to 1,000 psi, dogs released, Continue POH with chemical cutter, tools started hanging up again around 200', pressured up to 2,500 psi, to try and retract anchor dogs, worked tools up slowly pulling between 2,500 to 3,500 Ibs on E-line, while doing this the E-line below the top sheave started twisting up adding to the problem. with the top of tool string at 82' line had twisted up (+1- 10 wraps) and were unable to pull any more due to the twisted line, bled off pressure, Lowered top sheave to get the twist out of the cable, slack in line, tool stuck at 82'. Break connection and raise packoff to install wire line T handle clamp on e-line. UD top sheave and packoff. Latch on to landing joint, pickup on tubing string to 190k (tubing not cut) slack off to 140k, set slips. Latch on to E-line clamp, pulled Printed: 1/31/2005 8:02:31 AM ') ) Page 3 of 9 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-107 L-107 WORKOVER FrÓm/Tø Høurs Task CÖdëNPT Phase 1/15/2005 2.00 FISH x STUC DECOMP 19:00 - 21 :00 1/16/2005 21 :00 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 00:00 - 12:00 1.00 RUNCO~ 0.50 FISH X 1.00 FISH X 0.50 FISH X 12.00 FISH X STUC RUNCMP STUC DECOMP STUC DECOMP STUC DECOMP STUC DECOMP 12:00 - 12:30 0.50 FISH X STUC DECOMP 12:30 - 14:00 1.50 FISH X STUC DECOMP 14:00 - 14:30 0.50 FISH X STUC DECOMP 14:30 - 15:00 0.50 FISH X STUC DECOMP 15:00 - 16:00 1.00 FISH X STUC DECOMP 16:00 - 19:30 3.50 DHB X STUC DECOMP 19:30 - 20:30 1.00 DHB X STUC DECOMP 20:30 - 21 :00 0.50 DHB X DFAL DECOMP 21 :00 - 22:00 1.00 CHEM X DFAL DECOMP 22:00 - 23:00 1.00 CHEM X DFAL DECOMP 23:00 - 00:00 1.00 CHEM C DECOMP 1/17/2005 00:00 - 01 :00 1.00 EVAL C DECOMP 01 :00 - 01 :30 0.50 PULL P DECOMP 01 :30 - 02:00 0.50 PULL P DECOMP 02:00 - 02:30 0.50 PULL P DECOMP 02:30 - 03:00 0.50 PULL P DECOMP 03:00 - 07:30 4.50 PULL P DECOMP 07:30 - 08:00 0.50 PULL P DECOMP 08:00 - 13:00 5.00 PULL P DECOMP 13:00 - 13:30 13:30 - 14:00 0.50 PULL P 0.50 BOPSUR P DECOMP DECOMP Start: Rig Release: Rig Number: 1/5/2005 Spud Date: 8/18/2001 End: 1/7/2005 DøsÞriþtit>nøf.. Qþ$ratiÖ~~ 4-5k on e-line, moved tools up hole approximetly 3', pulled out of rope socket with 6k. RID E-line tools. Land tubing hanger, back out and UD landing joint. PJSM wlslick line and rig crew. Rig up slick line. M/U slick line pulling tool, RIH latch onto fish at 83', jar on fish. Jar on fish @ 82', pulling tool slipping off fish neck, POH UD pulling tool and re-pin, RIH, latch onto fish, jar on fish, shear off fish, POH UD pulling tool, M/U overshot, RIH engage fish, continue jarring. Shear off fish, POH P/U accelerator jar, RIH engage fish, continue jarring on fish @ 82', no progress made jarring with slick line. Rig down slick line. Make up 3" GS spear - XO - disqonnect - Bowen jar 2.13" OD - 2,2.38" DCs - Bowen accelerator - 1,2.38" DC. Spear fish @ 82', push fish down +1- 6' with the weight of the collars. POH w/Chemical cutter to bottom of BOPs, lay down fishing assembly. Up wt = 1-1 Ok. (did not jar) PJSM, wlSchlumberger and rig personnel, handling chemicals & explosives. Lay down chemical cutter, (Explosive devise went off, one of the two chemical canisters ruptured, but did not expel any chemical) Rig up slick line, RIH with 2.750" gauge ring to 8,150', POH with gauge ring. Rig down slick line and related tools. PJSM, w/Schlumberger and rig personnel, handling chemicals & explosives. Make up landing joint, P/U on tubing string to 160k set slips, Rig up E-line, packoff and chemical cutter. RIH with chemical cutter to 8,219', correlate depth with CCL, position and cut tubing @ 8,135' (Positive indication of tubing cut) POH with chemical cutter. PJSM, wlSchlumberger and rig personnel, handling chemicals & explosives. Lay chemical cutter down beaver slide, Rig down E-line and related tools. Make up topdrive to landing joint, pull tubing hanger to floor, up wt = 97k Circulate bottoms up @ 252 gpm, 1450 psi, no indication of sand or scale at bottoms up. Lay down landing joint and tubing hanger. Rig tubing handling equipment, hydraulic spooling unit for control line. Lay down 3.5" 9.2# L-80 IBT-M tubing and single control line. to SSSV, recovered 73 SS bands. Lay down Schlumberger control line spool. Continue to lay down 3.5" 9.2# L-80 IBT-M tubing and jewelry. Recovered 259 joints tubing, 19.03' cut off joint, SSSV, 4 GLM, 1 X nipple, 1 pup joint. The tubing string will not be re-run due to pin damage. Same damage as the tubing string on L-104 Rid down tubing handling equipment, clean floor. Rig up Bop test equipment, test lower pipe rams to 250 psi low, Printed: 1/31/2005 8:02:31 AM ') ) BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-107 L-107 WORKOVER Start: Rig Release: Rig Number: 1/5/2005 Spud Date: 8/18/2001 End: 1/7/2005 Date Frorn..To Hobrs Task .cocté NPT 1/17/2005 13:30 - 14:00 0.50 BOPSUR P DECOMP 3,500 psi high, rig down test equipment, install wear ring. 14:00 - 15:00 1.00 FISH C DECOMP Bring fishing tools to rig floor. 15:00 - 15:30 0.50 FISH C DECOMP PJSM wI Baker fishing Rep and rig crew, P/U fishing assembly 15:30 - 16:00 0.50 FISH C DECOMP Rig up 2 3/8" & 2 7/8" handling equipment. 16:00 - 18:00 2.00 FISH C DECOMP Pick up 2 3/8" fishing assembly, 2 13/16" spear w/3.001" grapple - XO sub - bumper sub - oil jar - 12, 2 3/8" DC - accelerator jar - XO sub - pump out sub, per Baker fishing Rep. 18:00 - 00:00 6.00 FISH C DECOMP RIH with fishing assembly, picking up 2 7/8" DP. As a precaution circulate volume of DP at 4,000',2 bpm , 80 psi, 2 7/8" DP has a considerable amount of rust and scale falling out when picking up pipe. 1 118/2005 00:00 - 03:00 3.00 FISH C DECOMP Continue RIH with fishing assembly, picking up 2 7/8" DP, to 6,586'. 03:00 - 03: 15 0.25 FISH C DECOMP Make up Topdrive, circulate DP volume (29 bbls) at 6586' at 2 bpm, 935 psi, blow down topdrive. 03:15 - 05:30 2.25 FISH C DECaMP RIH picking up 2 7/8" DP from 6,586' to 8,107' 05:30 - 08:30 3.00 FISH C DECOMP Make up topdrive, break circulation, establish up weight = 115k, down weight = 80k, wash down to top of tubing stub @ 8,135' engage fish. Jar on tubing stub, max weight to fire jars - 200K 08:30 - 09:30 1.00 FISH C DECOMP Circulate sweep @ 2.5 bpm, 2159 psi. 09:30 - 15:00 5.50 FISH C DECOMP Continue to jar on the seal assembly. Jars failed. Total footage gained - 6.6'. Abort jarring operations. 15:00 - 15:30 0.50 FISH C DECOMP RD. Changeout handling equipment. Blow down top drive. 15:30 - 23:00 7.50 FISH C DECaMP PJSM. LD 2-7/8" DP from 8,135'. 23:00 - 00:00 1.00 FISH C DECOMP LD Jar BHA from 388'. 1/19/2005 00:00 - 01 :00 1.00 FISH C DECOMP Continue to LD Fishing BHA. 01 :00 - 02:00 1.00 FISH C DECaMP Clean and clear the rig floor. 02:00 - 03:00 1.00 PULL C DECOMP Service the top drive. 03:00 - 06:30 3.50 PULL X WAIT DECOMP Wait on Baker crossover from 3-1/2" IBT-M to Wilson Wash pipe thread. 06:30 - 14:00 7.50 PULL C DECOMP MU Mill Shoe and Washover pipe. RIH picking up 3-1/2" 9.2#, L-80, IBT-M tubing. 14:00 - 15:00 1.00 PULL C DECOMP Cease tubing trip. Install floor safety valve. Perform Derrick inspection for ice or debris - none found. 15:00 - 18:30 3.50 PULL C DECaMP Resume RIH with 3-1/2" tubing. 18:30 - 21 :30 3.00 PULL C DECaMP Tag up on the top of the fish @ 8,124'. Set down 3,000#. PU and rotate pipe one turn. RIH and swallow fish. Tag up on tubing collar of the tubing stub fish @ 8,136'. Circulate a high visc sweep around - nothing substantial in the returns. Displace the well over to 11.1 ppg brine. 21 :30 - 23:00 1.50 PULL C DECaMP RU rig floor for Slickline and E-line work. Space out with 2' of joint #266 above the floor while leaving the washpipe over the fish. RU a 3-1/2" x 4-1/2" IF xo, 4-1/2" TIW valve (from Doyon 16), Pump In Sub (from Doyon 16),4-1/2" TIW valve (from Baker), 4-1/2" IF x 7" Otis. All subs drifted to a minmum of 2.867". 23:00 - 00:00 1.00 FISH C INTERV PJSM with SLB Slickline. RU Slickline. 1/20/2005 00:00 - 03:30 3.50 FISH C INTERV RU 10' scaffold work platform. Continue to RU Slickline. Pressure test all surface valves to 3500 psi - good tests. 03:30 - 06:30 3.00 FISH C INTERV Trip #1: RIH with 2.25" Jet Bailer on Slickline to remove calcium carbonate from the top of the PX plug @ -8232' (SLM). Empty bailer - recovered -0.5 gal of calcium Printed: 1/31/2005 8:02:31 AM ) ) BP EXPLORATION Operations Summary Report Page 5 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-107 L-107 WORKOVER Start: Rig Release: Rig Number: 1/5/2005 Spud Date: 8/18/2001 End: 1/7/2005 Date From - To Hours Task Code NPT Phase Description of Operations 1/20/2005 03:30 - 06:30 3.00 FISH C INTERV carbonate. 06:30 - 10:00 3.50 FISH C INTERV Trip #2: RIH with 2.25" Jet Bailer on Slickline. Unable to get back into tubing stub. POH. 10:00 - 17:00 7.00 FISH C INTERV Change out the shoe on the bottom of the bailing tool to a mule shoe. Trip #3: RIH to bail from the top of the PX plug @ 8232'. Recovered 0.5 gal. Trip #4: RIH to bail from the top of the PX plug @ 8232'. Recovered 0.5 gal. Trip #5: RIH to bail from the top of the PX plug @ 8232'. Recovered 0.5 gal. Mule shoe showed indication of the prong fishing neck being exposed. 17:00 - 17:30 0.50 FISH C INTERV RU a 2.5" JUC( j-Iatch, shear up) tool and pressure test the Otis connection. 17:30 - 20:00 2.50 FISH C INTERV Trip #6: RIH. Latch onto the prong. Close the Hydril. Line up to the choke. Attempt to pull prong. Sheared off of the prong. POH while circulating over the top of the hole to check for losses - none. Shut down on the pumps. Bleed off pressure and check for flow - stable. 20:00 - 21 :00 1.00 FISH C INTERV Break the Otis connection and rebuild the 2.5" JUC tool. MU the Otis connection and pressure test. 21 :00 - 23:00 2.00 FISH C INTERV Trip #7: RIH. Latch onto the prong. Close the Hydril. Line up to the choke. Attempt to pull prong. Sheared off of the prong. POH while circulating over the top of the hole to check for losses - none. Shut down on the pumps. Bleed off pressure and check for flow - stable. 23:00 - 23:30 0.50 FISH C INTERV Break the Otis connection and changeout tools for a 1.25" bailer. 23:30 - 00:00 0.50 FISH C INTERV Trip #8: RIH with 1.25" bailing tool in an attempt to clean more calcium carbonate from the top of the PX plug. 1/21 12005 00:00 - 01 :30 1.50 FISH C INTERV POH with 1.25" bailer. Recovered small amount of calcium carbonate. 01 :30 - 03:30 2.00 FISH C INTERV Change out to a 2.5" JDC tool to latch onto prong. Trip #9: RIH. Latch onto the prong. Close the Hydril. Line up to the choke. Attempt to pull prong. Sheared off of the prong. POH while circulating over the top of the hole to check for losses - none. Shut down on the pumps. Bleed off pressure and check for flow - stable. 03:30 - 11 :00 7.50 FISH C INTERV Change out 1.25" wire to Braided line. Change out the Slickline BOP's. 11 :00 - 14:00 3.00 FISH C INTERV Re-pin 2.5" JDC tool. Trip #10: RIH. Slickline depth counter was off and they believed that they were not able to get down into the tubing stub. POH to check the tool. Found that the tool had sheared, indicating that they were actually latched onto the prong. 14:00 - 17:00 3.00 FISH C INTERV Re-pin 2.5" JDC tool to latch. Trip #11: RIH. Latch onto the prong. Close the Hydril. Line up to the choke. Attempt to pull prong. Sheared off of the prong. POH while circulating over the top of the hole to check for losses - none. Shut down on the pumps. Bleed off pressure and check for flow - stable. 17:00 - 20:00 3.00 FISH C INTERV Re-pin 2.5" JDC tool to latch. Trip #12: RIH. Latch onto the prong. Close the Hydril. Line Printed: 1/31/2005 8:02:31 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-107 L-107 WORKOVER Start: Rig Release: Rig Number: Spud Date: 8/18/2001 End: 1/7/2005 1/5/2005 Date From~~To . Hours Task CÒde NPT 1/21/2005 3.00 FISH C INTERV 17:00 - 20:00 20:00 - 20:30 20:30 - 00:00 0.50 FISH 3.50 FISH INTERV INTERV c C 1/22/2005 00:00 - 03:30 3.50 FISH C INTERV 03:30 - 06:30 3.00 FISH C INTERV 06:30 - 10:00 3.50 FISH C INTERV 10:00 - 11 :00 1.00 FISH C INTERV 11 :00 - 16:00 5.00 FISH X SFAL INTERV 16:00 - 17:00 1.00 FISH C INTERV 17:00 - 18:00 1.00 FISH C INTERV 18:00 - 19:00 1.00 FISH C INTERV 19:00 -00:00 5.00 BOPSUR C INTERV 1/23/2005 1.00 FISH 1.50 FISH INTERV INTERV 00:00 - 01 :00 01 :00 - 02:30 C C 02:30 - 03:00 03:00 - 06:00 06:00 - 07:00 07:00 - 10:30 0.50 FISH 3.00 FISH 1.00 FISH 3.50 FISH INTERV INTERV INTERV INTERV C x C C 10:30 - 13:30 3.00 FISH C INTERV 13:30 - 16:30 3.00 FISH C INTERV 16:30 - 18:30 2.00 FISH C INTERV up to the choke. Attempt to pull prong. Recovered prong. POH while circulating over the top of the hole to check for losses - none. Shut down on the pumps. Bleed off pressure and check for flow - stable. RU 2.25" Jet Bailer on braided line. Trip #13: RIH wI2.25" Bailer to remove calcium carbonate from the top of the PX plug. POH. Recovered - 1.0 gal. Saw marks indicating the bailer was hitting the top of the fishing neck. Trip #14: RIH wI 1.25" Bailer to remove calcium carbonate from the toplbeside the fishing neck of the PX plug. POH. No solids recovered. Trip #15: RIH wI 3.5" GS tool to latch onto the fishing neck of the PX plug. Did not see a good indication of latch. POH to look at the tool. Tool was sheared. Trip #16: RIH wI 1.25" Bailer to remove calcium carbonate from the toplbeside the fishing neck of the PX plug. POH. Recovered - 0.25 gal of solids. Trip #17: RIH wI 1.25" Bailer to remove calcium carbonate from the toplbeside the fishing neck of the PX plug. At 3700' SLM, the slickline water pump went out. RD Slickline due to water pump failure. RD scaffolding and valving on the rig floor. LD 2 joints of 3-1/2" IBT-M tubing. . MU tubing hanger and land the tubing, PU - 100K, SO - 70K. RILDS. RU BOP testing equipment. Test BOP's and Annular to 250/3500 psi. Testing of the BOP's was waived by John Crisp of the AOGCC. RD test equipment and blow down all surface lines. BOLDS. Pull tubing hanger to the rig floor. LD hanger. PU 2 joints of 3-1/2" IBT-M tubing. Wash down over the top of the tubing stub @ 8,124' - saw pressure increase slightly when swallowing the fish. Space out with 2' of joint #266 above the floor while leaving the washpipe over fish by -4'. RU a 3-1/2" x 4-1/2" IF xo, 4-1/2" TIW valve (from Doyon 16), Pump In Sub (from Doyon 16),4-1/2" TIW valve (from Baker), 4-1/2" IF x 7" Otis. All subs drifted to a minmum of 2.867". RU 10' scaffolding on the rig floor. RU Slickline. RU hoses. PU 1.5" Pump Bailer. RU and test lubricator. Trip #18: RIH wI 1.5" Pump Bailer to remove calcium carbonate from the toplbeside the fishing neck of the PX plug. POH. Recovered - 1.5 cups of solids. Possible marks on the tool indicating fishing neck exposed. Trip #19: RIH wI 3.5" GR tool to latch onto the fishing neck of the PX plug. Did not see a good indication of latch. POH to look at the tool. Tool never latched up. Trip #20: RIH wI 1.5" Hydrostatic Bailer to remove calcium carbonate from the top/beside the fishing neck of the PX plug. POH. Recovered - 0.5 cups of solids. Trip #21: RIH w/ 1.5" Hydrostatic Bailer to remove calcium carbonate from the top/beside the fishing neck of the PX plug. Printed: 1/31/2005 8:02:31 AM ) ) Legal Well Name: L-107 Common Well Name: L-107 Spud Date: 8/18/2001 Event Name: WORKOVER Start: 1/5/2005 End: 1/7/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Hours Task CÖde NPT 1/23/2005 16:30 - 18:30 2.00 FISH C INTERV POH. Recovered - 0.5 cups of solids. Possible marks on the tool indicating fishing neck exposed. 18:30 - 20:30 2.00 FISH C INTERV Trip #22: RIH wI 3.5" GR tool to latch onto the fishing neck of the PX plug. Did not see a good indication of latch. POH to look at the tool. Tool never latched up. 20:30 - 22:30 2.00 FISH C INTERV Trip #23: RIH wI 2.5" Pump Bailer to remove calcium carbonate from the top/beside the fishing neck ofthe PX plug. POH. Recovered - 4 cups of solids. 22:30 - 00:00 1.50 FISH C INTERV Trip #24: RIH wI 2.5" Pump Bailer to remove calcium carbonate from the toplbeside the fishing neck of the PX plug. POH. 1/24/2005 00:00 - 00:30 0.50 FISH C INTERV Trip #24 (continued): POH wI 2.5" Pump Bailer used to remove calcium carbonate from the toplbeside the fishing neck of the PX plug. Recovered - 3 cups of solids. 00:30 - 02:00 1.50 FISH C INTERV Trip #25: RIH w/2.5" Pump Bailer to remove calcium carbonate from the toplbeside the fishing neck of the PX plug. POH. Recovered - 3 cups of solids. 02:00 - 03:00 1.00 FISH C INTERV Trip #26: RIH wI 2.5" Pump Bailer to remove calcium carbonate from the top/beside the fishing neck of the PX plug. While bailing material, there was a tension seen on the braided line of -2500#. At that time, the extended arms used contol the spooling of the cabling bent at the weak point. The slickline tension was clamped off at the rig floor and tension removed from the spoolng arm. Schlumberger called for mechanics to troubleshoot the problem. ***Bailing tool and braided line are still in the hole*** 03:00 - 07:00 4.00 FISH X SFAL INTERV Wait on repairsltroubleshooting of Slickline unit. 07:00 - 08:30 1.50 FISH C INTERV Trip #26 (continued): POH wI 2.5" Pump Bailer used to remove calcium carbonate from the toplbeside the fishing neck of the PX plug. No solids recovered. 08:30 - 13:30 5.00 FISH C INTERV Trip #27: RIH wI 3.5" GR tool to latch onto the fishing neck of the PX plug. Latch onto the plug and work the plug free. Well started taking fluid at an initial rate of 212 bph. POH with PX plug while filling the hole with -8.5 ppg seawater. Gained returns after - 80 bbls lost to the hole, loss rate is 60 bph. Circulate over the top of the hole and down the tubing @ 1.8 bpm, 31 psi. RD slickline. 13:30 - 14:30 1.00 FISH C INTERV Circulate over the top of the hole and through the choke using the charge pump @ 42 psi and losses at 6 bph. RD scaffolding. 14:30 - 15:30 1.00 FISH C INTERV RD the two TIW valves and the Pump In Sub. Pump across the top of the hole - 6 bph losses. MU head pin. PU - 11 OK. 15:30 - 18:00 2.50 FISH C INTERV Circulate down the tubing @ 2 bpm, 366 psi with seawater. As we got close to pumping surface to surface strokes, there was an increase in flow from the well. Shut the well in. SITP - 170 psi, SICP - 160 psi. 18:00 - 21 :00 3.00 FISH C INTERV Monitor the well. Notified John Crisp with the AOGCC. Calculated KW fluid to be 9.0 ppg. Weight up fluid to 9.4 ppg for additional trip margin. 21 :00 - 23:30 2.50 FISH C INTERV Circulate 9.4 ppg fluid down the tubing and taking returns through the choke to the degasser @ 2 bpm. ICP - 260 psi. FCP - 120 psi. Lost 40 bbls while getting KW fluid to the bit. Printed: 1/31/2005 8:02:31 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-107 L-107 WORKOVER Start: Rig Release: Rig Number: 1/5/2005 Spud Date: 8/18/2001 End: 1/7/2005 From..Th-...Hours . Task.. 1/24/2005 2.50 FISH INTERV C 21 :00 - 23:30 23:30 - 00:00 0.50 FISH INTERV C Lost 30 bbls more while circulating KW fluid up the backside. When 9.4 ppg fluid was seen at surface, SI the well. SITP - 0 psi. SICP - 0 psi. Monitor the well. Fluid level dropping slowly with the pumps off at - 25 bph. Begin rigging up the floor to pull 3-1/2" tubing. 1 125/2005 1.00 FISH C ***Total Losses for the day - 488 bbls*** INTERV RU 3-1/2" tubing handling tools. LD joint #266, head pin and surface safety valve. Blow down all surface equipment. 00:00 - 01 :00 01 :00 - 12:00 11.00 FISH INTERV C 12:00 - 17:00 5.00 FISH C INTERV 17:00 - 17:30 0.50 FISH C INTERV 17:30 - 18:30 1.00 BOPSUP C INTERV 18:30 - 19:00 0.50 RUNCOMP RUNCMP 19:00 - 19:30 0.50 RUNCOMP RUNCMP 19:30 - 00:00 4.50 RUNCOMP RUNCMP 1/26/2005 00:00 - 07:00 7.00 RUNCOMP RUNCMP 07:00 - 07:30 0.50 RUNCOMP RUNCMP 07:30 - 09:00 1.50 RUNCOtvP RUNCMP 09:00 - 11 :00 2.00 RUNCOtvP RUNCMP 11 :00 - 12:00 1.00 RUNCOtvP RUNCMP 12:00 - 13:30 1.50 RUNCOtvP RUNCMP 13:30 - 14:30 14:30 - 16:30 16:30 - 20:30 20:30 - 22:30 1.00 WHSUR P 2.00 BOPSUP P 4.00 WHSUR P 2.00 WHSUR P OTHCMP OTHCMP OTHCMP OTHCMP *Estimate losses to be -25 bph* Lay down 3.5" 9.2# L-80 tubing from 8,103' to 3,255', loss rate slowed to 12 bph. inspect and replace seal rings in pipe shed as pipe is being laid down. Losses for past 12 hrs = 138 bbls Continue to lay down 3.5" tubing from 3,255', lay down Baker tools. Clear and clean floor. Rig up test equipment, test lower pipe rams to 250 psi low, 3,500 psi high, rig down test equipment. Make dummy run with tubing hanger & landing joint. Rig up to run 3.5" completion. PJSM, with Co Rep, Toolpusher, Baker and rig crew. Make up 5.5" X 3.5" Unique Machine overshot, X Nipple wI RHC plug, Baker Sabl 5.5" X 3.5" packer, X Nipple, run 3.5" 9.2# L-80 completion per running order to 2,740', make up torque = 2,400 ft/lbs. Losses for past 12 hrs = 142 bbls Continue running 3.5" 9.2# L-80 Completion per running order. Picked up joint # 258 and # 259. Up weight = 105k down weight =70k Wash over tubing stub, pumping 3 bpm, @ 305 psi, saw pressure increase as overshot went over tubing stub at 8,124' swallowd 7' of stub to 8,131' POH lay down joint # 259 - # 257, make up 5.85' space out pup, joint # 257, tubing hanger and landing joint, drain stack and land tubing hanger, RILDS. Rig up and reverse circulate 71 bbls 9.4 ppg clean brine, followed by 9.2 bbls brine treated with corrosion inhibitor, followed by 87 bbls clean 9.4 ppg brine @ 3 bpm, 500 psi Drop 1 5/16" ball and rod, back out and lay down landing joint. Pressure up to 4,500 psi to set packer. Losess for last 12 hrs = 83 bbls Test tubing to 4,500 psi for 30 min record on chart, bled tubing presure to 2,000 psi, pressure up on annulus to 3,500 psi for 30 min record on chart, bled annulus pressure to zero, bled tubing pressure to zero, pressure up to shear DCK shear valve, sheared at 2,100 psi. Drain stack, install TWC, test from below to 1,000 psi. Blow down surface lines, nipple down BOP's. Nipple up adapter flange and tree, test to 5,000 psi. PJSM, rig up Little Red, test lines to 3,500 psi, Freeze protect Printed: 1/31/2005 8:02:31 AM ') ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L-107 L-107 WORKOVER BP EXPLORATION Operations Summary Report Page 9 of 9 Start: Rig Release: Rig Number: 1/5/2005 Spud Date: 8/18/2001 End: 1/7/2005 1/26/2005 20:30 - 22:30 FtÖrrf-To HoUrs .....TasK (Code. NPT Phase OTHCMP tubing and annulus to 4,050' with 85 bbls diesel, 2 bpm @ 1400 psi. final circulating pressure 2000 psi. U-tube Diesel. Install BPV with lubricator, Install VR plugs in both IA valves, remove secondary valve on lA, Clean cellar secure well. Date 22:30 -23:30 23:30 - 00:00 2.00 WHSUR P 1.00 WHSUR P 0.50 WHSUR P OTHCMP OTHCMP Release Rig From L-107 @ 00:00 hrs 1/26/2005 Printed: 1/31/2005 8:02:31 AM TREE = , .. 3-1/8" 5M CrN WELLHEAD = 11" FMC ... , , -. . ."..w"" I ~.\ ACTUA TOR = NA , ~ .'- "" ".J..."..' \ ",,' KB. ELEV = 78.70' , ,~ " m" .,' , ...¥' . " BF. ELEV = 53.9' ,-~..~~.".""..,,~..~...~.. ,-" ~I.- ',11. '.'~"W'¥.W'. KOP= 1000' '''''''"-'''''"''''~'''''ff._". .~.,.- .-... ~'" -~x A~~~:.~..__..~~_~.~~01' Datum MD = 8576' Datum 1VD ="c.'''.'.-'66ÕÔ~'.SŠ' -) 17-5/8" CSG, 29.7#. L-80, ID = 6.875" 1-1 3036' Min ¡mum ID = 2.75" @ 8100' 3-1/2" HES 'BPX' X Nipple PERFORA~ONSUMMARY REF LOG: SWS RESIS~VITY LOG ON 08/27/01 ANGLE AT TOP PERF: 13 @ 8394' Note: Refer to Production DB for historical perf data . SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 6 8394 - 8452 0 09/17/01 2-1/2" 6 8452 - 8482 0 09/16/01 3-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, 10 = 2.992" - 8121' 3-1/2" TBG, 9.2#, L-80, IBT-M, .0087 bpf, ID = 2.992" - 8156' , 5-1/2" CSG. 15.5#, L-80, BTC, ID = 4.950" l-f 8156' 15-1/2" X 3-1/2" CSG XO, 10 = 2.968" 1-1 8168' I PBID 1-1 8834' 13-1/2" CSG. 9.2#. L-80, NSCT, 10 = 2.992" 1-1 8933' L-107 4 /i r P;~ 1 I 0 ~ . L SAFET) )OTES: FROM DRLG - DRAFT =----i 1022' 1-17-5/8" TAM PORT COLLAR I 1913' 1-I3-1/2"HESXNIP, 10=2.813" I ~ ST MO 7 2115 6 3078 5 4278 4 5378 3 6424 2 7302 1 8001 GAS LIFT MANOR8...S 1V0 DEV TYÆ VLV LATCH PORT 2010 37 KBG2-9 DMY INT 0 2646 51 KBG2-9 DOME INT 16 3407 52 KBG2-9 DOME INT 16 4097 50 KBG2-9 DOME INT 16 4803 43 KBG2-9 SO INT 24 5489 31 KBG2-9 OMY INT 0 6121 19 KBG2-9 OMY INT 0 8056' 8077' 8078' 8100' 8124' 8128' - 3.5" HES X Nipple 10=2.813" - KBH-22S Anchor Tubing Seal 10=3.00" - 5.5" x 3.5" SABL A<R 10=2.78" - 3.5" HES 'BPX' X Nipple 10=2.75" (RHCM) - Top of tubing stub - Unique Machine Overshot (ID = 3.0") j ----1 I I 1 8157' 8169' 1-1 TOP OF BKR PBR, 10 = 4.00" I 1-{3-1/2" BKR SEAL ASSY, ID = 3.00" 1 1-13-1/2" HES X NIP, 10 = 2.813" 1 8219' 8240' 1-{3-1/2" HES X NIP, 10 = 2.813" I 8373' I-{ 10' PUP JT W / RA TAG 1 8722' 1-{20' PUPJT W / RA TAG 1 DATE 01/26/05 02/04/05 02/04/05 02/04/05 02/04/05 02/04/05 01/26/05 BOREALIS UNrr WELL: L-107 ÆRMrr No: 2011510 API No: 50-029-23036 SEC 34, T12N R11 E 2397' NSL & 3646' WEL DA TE REV BY COMMENTS 02104/05 KSBITLH GL V C/O DATE 08/31/01 12/30/02 04/08/03 04/21/03 05/02104 01/26/05 REV BY COMMENTS CHlKAK ORIGINAL COM PLErION OAC/KK GL V CORRECTIONS DRS/TP 1V DIMO CORRECTIONS JCM'TLH GL V UPDATE GJB/KAK GL V C/O AM'BB Tubing swap with overshot BP Exploration (Alaska) Well Control PBU L-107 ) Subject: Well Control PBU L-107 From: John Crisp <john_crisp@admin.state.ak.us> Date: Tue, 25 Jan 2005 06:16:12 -0900 To: Jim Regg<jim_regg@admin.state.ak.us> .::201-/51-. Got a call last night from Nabors 9ES BP Rig Rep James Franks that well PBU L-107 was shut in with 165 psi on choke & work string. I traveled to 9ES to discuss situation. The estimated formation pressure for this tubing swap had the Rig using 11.1 brine for the swap. The Rig pulled the plug in the X nipple below PBR & the well started taking fluid. The Rig was using seawater to fill the hole. The well took & then gave & the shut in pressure calculated 9.4 fluid wt. & that is with 150 psi trip margin. There had been no gas to surface. The 160 psi was on work string & choke. Cased hole wi perfs from 8394" to 8452" MD. 6460' to 6585' TVD. Inspection of secondary well control equipment & Rig inspection confirmed that this Rig & equipment is one of if not the best maintained Rig on in State. The day & night BP Rig Rep's had been swapped over to this Rig recently so I did not make inquiries of previous well control problems. I will attempt to make it to the Rig for another inspection today. JC. ~C'-'.A" !i\i~iE" - '::¡, ¡:~r~ /}". 4 2005 .~i;j n~1 b;:t. bU 't ~" 1 of 1 1/25/2005 10:03 AM Permitto Drill 2011510 DATA SUBMITTAL COMPLIANCE REPORT 10~3~2003 Well Name/No. PRUDHOE BAY UN BORE L-107 Operator BP EXPLORATION (ALASKA) INC MD 8950 j TVD 7047 /" Completion Date 9/16/2001 J Completion Status 1-OIL Current Status 1-OIL UIC N APl No. 50-029-23036-00-00 REQUIRED INFORMATION Mud Log N__~o Samples N_9o Directional Survey ~ \/44., DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset ge - MedlFrmt Number ~1~ D (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Name Scale Media No Start Stop CH Received Comments .................... ~-/Resistivity _~erature Log Resistivity i [,,3~ Den/Neu -.'-.' ...................................................... ~D~en/Neu ................................................... .~i-onal Survey 2/5 1-4 110 8950 Case 10/26/2001 2/5 FINAL 50 8800 Open 9/28/2001 2/5 1-4 110 8950 Case 10/26/2001 2/5 1-4 110 8950 Case 10/26/2001 1 100 8950 Open 2/5 1-4 110 8950 Case 10/26/2001 FINAL Open 9/21/2001 FINAL Open 9/21/2001 110-8950 BL, Sepia 50-8800 BL, Sepia 110-8950 BL, Sepia 110-8950 BL, Sepia 110-8950 BL, Sepia Directional Survey Digital Data Directional Survey Well Cores/Samples Information: Name Start Interval Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? Analysis Received? Daily History Received? ~ N Formation Tops ~ N Comments: Permitto Drill 2011510 MD 8950 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 101312003 Well Name/No. PRUDHOE BAY UN BORE L-107 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23036-00-00 7047 jCompletion Date 9/16/2001 Completion Status 1-OIL Current Status 1-OIL UIC N Date: /£'? ~ ~'~-" STATE OF ALASKA ALASK ~JIL AND GAS CONSERVATION COM ,.~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 12127101, Put on Line 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-151 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23036-00 4. Location of well at surface .... 9. Unit or Lease Name 2397' NSL, 3646' WEL, SEC. 34, T12N, R11E, UM :i ...:'.7 '._.~-,,::~ . · ' ~..,~ ~.i Prudhoe Bay Unit At top of productive interval 831'SNL, 199'WEL, SEC. 03, T11N, R11E, UM ;, ~" ':~i~.~ '~ ~.," ' . ~ 10. WellNumber At total depth 895' SNL, 129' WEL, SEC. 03, T11 N, R11 E, UM ~ ....... ~ ....... ~ -~i~.?.~, ~r~,.,?.---,~.~ L-107 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease-'D~ig'~i'i0n"and Serial No. Prudhoe Bay Field / Borealis Pool KBE = 77.30' ADL 028241 (Undefined) 12. Date Spudded 8/18/2001 113' Date T'D' Reached I14' Date C°mp'' susp'' °r Aband' 8/27/2001 9/16/2001 115' Water depth' if °fish°re N/A MSL,,116' N°' °f C°mpleti°ns One 17. Total Depth (MD+TVD)'118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 8950 7047 FTI 8834 6932 FTI [] Yes [] NoI (Nipple) 2192' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, NEU, DEN, CCL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 106' 30" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 26' 3036' 9-7/8" 349 sx Arctic Set Lite~ 197 sx 'G' 5-1t2"x3-1/2" 15.5#/9.2# L'80 24' : 8933' 6'3/4" 143 SX Dowell Lite Crete ,.. 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 8156' None MD TVD MD TVD 8394' - 8452' 6499' - 6556' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 8452' - 8482' 6556' - 6585' ' I DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8394' - 8482' --rac: 200,000# 16/20 Carbolite behind pipe 2900' Freeze Protect with 60/40 MeOH '27. '' ' PRoDucTION TEST ' ' Date First Production Method of Operation (Flowing, gas lift, etc.) November 6, 2001 Gas Lift Date of Test .Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 11/26/2001 4 TEST PERIOD 5135 2122 0 176I 413 ~low Tubing iCasing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORE) Press. 24-HOUR RATE .... 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit corech,.P, ECEiVED ' DEC 7001 Alaska 0il & Gas C0~s, C0mmissi0~ ....... Form 10-407 Rev. 07-01-80 2 Submit In Duplicate J/ N oo2 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Schrader Bluff M 5238' 4009' Schrader Bluff N 5634' 4264' Schrader Bluff O 5876' 4423' Colville Mudstone 6342' 4742' CMl 7480' 5643' HRZ 8104' 6219' Kalubik 8289' 6397' Kuparuk C 8394' 6499' LCU / Kuparuk B 8560' 6662' Kuparuk A 8690' 6789' Base Kuparuk / Top Miluveach 8770' 6868' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary, Post-Rig Summary 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ,,~(~f.~ ~ Title Technical Assistant Date L- 107 201 - 151 Prepared By Narne/Numbec Terrie Hubble, 564-4628 Well Number Permit No. / Appro.va! No. , , , , , ,, , , ,,, , , ,, , 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 10/16/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Bird, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. t 535 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Aurora Well Job # Log Description Date Color Sepia BL CD S-108 <~L~-IOO 21405 SCMT ~,,,'i 09108101 L-117 ¢-~OI- Itr)"l 21407 CMR v'"' 09/25101 L-114 21374 BHC,CMR v'" 08/13/0t L-114 ~--/~0)-I~(.o 21374 BHC ~/ 08113101 L-114 21374 CMR ,~¢"' 08/13/01 L-107 21420 PP,D/N, IMPULSE (PDC) v'" 08127101 L-107 ~::~O)- 15/ 21420 MDVISION RES v" 08/27/01 L-107 21420 TVD VISION RES v"' 08127/01 L-107 21420 MDVISION D/N-QUAD V" 08/27/01 L-107 21420 TVD VISION D/N-QUAD v" 0Sl27/01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED OCT 2 2001 An~omge Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherde STATE OF ALASKA {~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 201-151 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23036-00 4. Location of well at surface ....................... ;'i,-.,--~^,~,,-~,,,""""'~ 9. Unit or Lease Name 2397' NSL, 3646' WEL, SEC. 34, T12N, R11E, UM i w... ~.. · ¥ 1' Prudhoe Bay Unit At top of productive interval jS . ~!; ~'10. Well Number 895' SNL, 129' WEL, SEC. 03, T11 N, R11 E, UM ....... '~ 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease D~signation arid Serial No. Prudhoe Bay Field / Borealis Pool KBE - 77.30' ADL 028241 (Undefined) 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 1 20. Depth where SSSV set1 21. Thickness of Permafrost 8950 7047 FTI 8834 6932 "*1 [] Yes [] NoI (Nipple) 2192' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, NEU, DEN, CCL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 106' 30" 260 sx Arctic Set (Approx.) 7-5/8" 29.7# L-80 26' 3036' 9-7/8" 349 sx Arctic Set Lite~ 197 sx 'G' 5-1/2" x 3-1/2"15.5# / 9.2# L-80 24' 8933' 6'3/4" 143 SX Dowell Lite Crete 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE ' DEPTH SET (MD) PACKER SET (MD) 2-1/2" Gun Diameter, 6 spf 3-1/2", 9.2#, L-80 8156' None MD TVD MD TVD 8394' - 8452' 6499' - 6556' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 8452' - 8482' 6556' - 6585' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8394' - 8482' Frac: 200,000# 16/20 Carbolite behind pipe 2900' Freeze Protect with 60/40 MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. R [ C [ I V E D 2 4 2001 Anchorage ,, , Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Schrader Bluff M 5238' 4009' Schrader Bluff N 5634' 4264' Schrader Bluff O 5876' 4423' Colville Mudstone 6342' 4742' CMl 7480' 5643' HRZ 8104' 6219' Kalubik 8289' 6397' Kuparuk C 8394' 6499' LCU / Kuparuk B 8560' 6662' Kuparuk A 8690' 6789' Base Kuparuk / Top Miluveach 8770' 6868' , , ~ 31. List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary, Post-Rig Summary 32.1 hereby certify that the fore[]oing is true and correct to the best of my knOwledge Signed TerrieHubble "~~'~' ' ~ Title Technical Assistant Date /0' ~.~'i~/ L- 107 201 - 151 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. 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. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM ,5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: L-107 Common Name: L-107 : Te~t ~ (~O)i SUrface Pressure Leak Off Pressure (BHP) EMW 8/21/2001 LOT (ft) (ft) (PPg) (psi) (psi) (PPg) 8/22/2001 LOT 3,087.0 (ft) 2,620.0 (ft) 9.30 (ppg) 620 (psi) 1,886 (psi) 13.86 (ppg) Printed: 9/4/2001 5:06:18 PM BP EXPLORATION Page 1 of 5 Operations Summa Report Legal Well Name: L-107 Common Well Name: L-107 Spud Date: 8/18/2001 Event Name: DRILL+COMPLETE Start: 8/16/2001 End: 8/31/2001 Contractor Name: NABORS Rig Release: 8/31/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/17/2001 09:00 - 14:00 5.00 MOB P PRE MIRU L-114 to L-107. Spot all units. Plumb and wire in. Slow going, soft location due to rains. Lay extra matting. ACCEPT NABORS RIG 9-ES, THIS DATE 1400 HRS 14:00 - 16:30 2.50 BOPSUF. P SURF Nipple up diverter system, diverter line, all related plumbing. 16:30 - 22:30 6.00 DRILL P SURF PU 4" dp in sgls, stand back in mast. 22:30 - 00:00 1.50 DRILL P SURF Make up 9 7/8 drctnl spud assy 8/18/2001 00:00 - 01:30 1.50 DRILL P SURF Complete PU 9 7/8 drctnl / spud bha, stand bk in mast. 01:30 - 02:00 0.50 DRILL P SURF Function / test diverter system ( Witness waived by Jeff Jones AOGCC ). Test good. 02:00 - 04:00 2.00 DRILL P SURF PU bha, adjust motor to 1.5 deg. Orient bend / MWD. 04:00 - 05:00 1.00 DRILL P SURF Pre spud meeting all members drill team, PJSM. 05:00 - 05:30 0.50 DRILL P SURF Fill stack / well, test lines pump to top drive 1000 psi. Test good. 05:30 - 07:00 1.50 DRILL P SURF RU slickline / gyro tools, PJSM. 07:00 - 07:30 0.50 DRILL P SURF Service top drive. 07:30 - 00:00 16.50 DRILL P SURF Commence drill ahead 9 7/8 hole drctn1106 - 1468 ft. Gyro survey at 90 ft intervals. Up 50, dn 50, Rot 50. Rpm 93, Spm 186, Gpm 495, Press 1850, Wob 5 - 15 ART 5.75 hrs, AST 4.25 hrs 8/19/2001 00:00 - 01:30 1.50 DRILL P SURF Cont drill ahead 1468 - 1746 ft. 01:30 - 02:00 0.50 DRILL P SURF Flow check, circ/ cond mud for wiper / bit trip. Sweep yields minimum cuttings return. Hole clean. 02:00 - 04:00 2.00 DRILL P SURF Flow check, poh. Slight swabbing off btm, regain proper displacement. 5- 15 drag at 1200- 1100 ft. 04:00 - 05:00 1.00 DRILL P SURF Flow check, handle bha #1. Break bit and grade. 05:00 - 06:00 1.00 DRILL P SURF Make up bit #2 on bha #2, rih same. 06:00 - 06:30 0.50 DRILL P SURF Service tp dry, crown. 06:30 - 07:00 0.50 DRILL P SURF Flow check, follow bha with 4" dp to 1650 ft. 07:00 - 07:30 0.50 DRILL P SURF Wash / ream 1650 - btm 1746 ft. No fill. 07:30 - 15:30 8.00 DRILL P SURF Resume drill ahead 9 7/8 hole drctnl, 1746 - 3067 ( TD ). Up 95, Dn 79, Rot 88 Rpm 80, Wob 18 / 35, Press 2750, SPM 186, Gpm 550 15:30 - 16:30 1.00 DRILL P SURF Circ / cond mud for csg run. Shaker clean. 16:30 - 19:00 2.50 DRILL P SURF Flow check, poh with slight swabbing off btm. Regain correct displacement. 5 - 25 drag intermittent, 1800 - 1900 ft. Work free. Resume poh to bha, no abnormalties. 19:00 - 21:00 2.00 DRILL P SURF Flow check, stand back hwdp, lay out drctnl assy. 21:00 - 22:00 1.00 DRILL P SURF Clear floor. Place hole opener on floor. 22:00 - 22:30 0.50 DRILL P SURF Service top dry. 22:30 - 00:00 1.50 DRILL P SURF Make up hole opener bha #3, flow check, rih same to hwdp. 8/20/2001 00:00 - 01:30 1.50 DRILL P SURF Cont rih, wash / ream 1820, 1875, 2070, 2130, 2550, 2620 ft. Cont rih to 2970. 01:30 - 03:00 1.50 DRILL P SURF Precautionary wash 90 ft to btm at 3067 ft. No fill. Circ / cond mud for csg run. Sweep yields no abnormal cutting return. Shaker clean. Pump wt pill. 03:00 - 05:00 2.00 DRILL P SURF Flow check, poh for csg. Slight swabbing off btm 100 ft. 05:00 - 06:30 1.50 DRILL P SURF Lay out hole opener bha. Clear floor drlg tools. 06:30 - 07:00 0.50 CASE P SURF Make dummy run with 7 5/8 hgr, record space out. 07:00 - 08:00 1.00 CASE ,P SURF PJSM ( csg run ), place csg tool run gear on floor, rig up same. Printed: 9/4/2001 5:04:41 PM BP EXPLORATION Page 2 of 5 Operations Summary Report Legal Well Name: L-107 Common Well Name: L-107 Spud Date: 8/18/2001 Event Name: DRILL+COMPLETE Start: 8/16/2001 End: 8/31/2001 Contractor Name: NABORS Rig Release: 8/31/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/20/2001 08:00 - 14:00 6.001 CASE P SURF Make up guide shoe, shoe track, float shoe, test floats. Follow with 7 5/8 csg ( 29.73, L80, BTC ) to btm. Hole free of obstruction. Flow check. 14:00 - 14:30 0.50 CASE P SURF Lay out Franks tool, make up cmt hd, PU hgr / Idg jr. 14:30 - 16:00 1.50 CASE P SURF Slowly build to 7.5 bpm, cont circ csg. Re¢ip pipe. Land hgr with 91000 lbs. Cont circ clean returns. 16:00 - 18:30 2.50; CEMT P SURF PJSM cmt job. Pump 5 bbl CW 100, test lines 3500 psi. Pump btm plug with 5 bbls CW 100. i Pump 75 bbls Mud Push spacer, 10.2 ppg Pump 283 bbls 10.7 ppg lead slurry. ~Pump 56 bbls 15.8 ppg tail slurry. I pump top plug with 10 bbls H2o, chase cmt / flush 10 bbl H2o ' Displace with rig pump 126 bbls drlg mud. Bump plug with 1200 psi / 2 bpm. Hold press 10 min. Bleed, check floats, no back flow. Note: Full returns, no losses, recover 50 bbl 100% cmt to surface. 18:30 - 20:00 1.50 CEMT P SURF Lay out all related cmt / csg equip. Clear rig floor. Release cmt unit. 20:00 - 22:00 2.00 BOPSUF.P SURF Nipple dn diverter system. 22:00 - 00:00 2.00 BOPSUF.P PROD1 Nipple up tbg hd, bop stack, bolt up / prepare for test. 8/21/2001 00:00 - 03:30 3.50 BOPSUF.P SURF Finish NU BOP, riser & flowline. Set mousehole. 03:30 - 07:30 4.00 BOPSUF.P SURF Test BOPE to 250~4000 psi-OK; Annular to 250~3500 psi-OK. Witnessing waived by Jeff Jones-AOGCC Field Inspector. Pull test plug. 07:30 - 08:00 0.50 BOPSUF. P SURF Set wear ring & RILDS. 08:00 - 14:30 6.50 BOPSUF.P SURF PU & stand back 4" DP to TD well. Rabbit all joints. D1 Drill-OS-58 secs. 14:30 - 17:30 3.00 BOPSUF P SURF PU & MU BHA #4. Orient motor & MWD. Load LWD. RIH on HWDP. 17:30- 18:00 0.50 BOPSUF P SURF RIH to 1100'. 18:00 - 18:30 0.50 BOPSUF P SURF Shallow test MWD. Test TAM collar to 1500 psi-OK. D1 Drill-OS-1:20 min. 18:30 - 19:30 1.00 BOPSUF P SURF Cut & slip 60' drlg line. 19:30 - 20:30 1.00 BOPSUF P SURF Single in DP to 2500'. 20:30 - 21:30 1.00 BOPSUF P SURF Fill pipe. Test casing to 4000 psi f/30 min-OK (Lost 125 psi). 21:30 - 22:30 1.00 BOPSUF P SURF D-5 Drill. Blow down lines. 22:30 - 23:30 1.00 BOPSUF; P SURF Service top drive & crown. 23:30 - 00:00 0.50 BOPSUF P SURF Start wash down to FC. 8/22/2001 00:00 - 00:30 0.50 DRILL P SURF Finish wash down to FC @ 2949'. 00:30 - 02:00 1.50 DRILL P SURF Drill FC, Shoe track, FS, & rathole to 3067'. 02:00 - 03:00 1.00 DRILL P SURF Drill 20' of new hole to 3087'. Monitor well. 03:00 - 04:30 1.50 DRILL P SURF Displace well over to 9.3# QuikDril system. Spill Drill-OS-67 sec. 04:30- 05:00 0.50 DRILL P SURF Perform LOT. EMW = 13.8 05:00 - 00:00 19.00 DRILL P PROD1 Directionally drill 6.75" hole f/3087'--4686'. Fire Drill-OS-l:20 min. ART: 12.25 hrs; AST: 1.5 hrs; PR erratic @ 25-400 fph. 8/23/2001 00:00 - 11:00 11.00 DRILL P PROD1 Drld f/4686' to 5243'. ART: 6.5 hfs; AST: 1.8 hrs. Bit gradually slowed down to ~8 fph. Started stalling motor. 11:00 - 12:30 1.50 DRILL P PROD1 Circ Hi-Vis, weighted fiber sweep. Monitor well-OK. 12:30 - 17:00 4.50 DRILL P PROD1 POH slow. Started swabbing 1 std off bottom. Backream &circ Printed: 9/4/2001 5:04:4'1 PM BP EXPLORATION Page 3 of 5 Operations Summary Report Legal Well Name: L-107 Common Well Name: L-107 Spud Date: 8/18/2001 Event Name: DRILL+COMPLETE Start: 8/16/2001 End: 8/31/2001 Contractor Name: NABORS Rig Release: 8/31/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/23/2001 12:30 - 17:00 4.50 DRILL P PROD1 out from 4848' to shoe. 17:00 - 17:30 0.50 DRILL P PROD1 CBU @ 285 gpm while rotating & reciprocating @ 80 rpm. 17:30 - 19:30 2.00 DRILL P PROD1 Continue POH. Still swabbing but gradually improved. 19:30 - 22:30 3.00 DRILL P PROD1 Pull & stand back BHA. Download LWD in pipe shed. BHA partially balled up around stabilizers. Bit balled in between cones. No jets in bit (??). Clear floor. 22:30 - 00:00 1.50 DRILL P PROD1 PU & MU BHA #5. Orient motor & MWD. Load sources. 8/24/2001 00:00 - 01:30 1.50 DRILL P PROD1 RIH to shoe. No problems @ TAM collar or float colar. 01:30 - 02:30 1.00 DRILL P PROD1 Service top drive, blocks, and crown. 02:30 - 04:30 2.00 DRILL P PROD1 RIH. Precautionary wash one stand to bottom 04:30 - 18:00 13.50 DRILL P PROD1 Drill f/5243' to 6510'. Control drilled @ 180 fph max from 5600' to 6510'. Lost partial returns. 180 bph dynamic; 0 bph static. ART: 9.5 hrs; AST: 1.5 hrs. Fire Drill-OS-1:30 min.; Spill Drill-OS-2:10 min. 18:00 - 18:30 0.50 DRILL N PROD1 Reciprocate & rotate pipe while stringing Barofibre into system @ 2 bpm. Dynamic losses @ 30 bph w/150 gpm pump rate. 18:30 - 23:00 4.50 DRILL P PROD1 Continue drlg @ reduced pump rate while increasing Barofiber. Pump rate back up to 285 gpm @ 2000 hrs w/30 bph losses. Drld f/6510' to 6818'. By 6818', losses down to 9 bph. Total losses while drlg: 135 bbls. ART: 2 hrs; AST: .25 hrs. 23:00 - 00:00 1.00 DRILL P PROD1 Circ Hi-Vis sweep around in preparation for scheduled wiper trip. Dynamic losses back to 34 bph. 8/25/2001 00:00 - 04:30 4.50 DRILL P PROD1 Shut down pumps & monitor well. Flowed back 26 bbls then static. Pull 5 stands & started swabbing slightly. Continue ~ pulling pipe, pumping 1.5 bpm f/6351' to 5605'. Backream fl :5605' to 5232'. Pulled to 5045'. Displacement 2 bbls under overall. Pulled tight @ 6013', 5940', 5905', 5650', & 5270'. Monitor well-OK. 04:30 - 05:30 1.00 DRILL P PROD1 RIH to 6724'. Hole appears in good shape. Ream last stand to bottom. 05:30 - 00:00 18.50 DRILL P PROD1 Drld f/6818' to 7986'. ART: 12.75 hrs; AST: 1 hr. Losses intermittent while drilling. At one point back up to 20 bph, but then stabilized. D2 Drill-OS-l:45 min; Spill Drill-OS-2 min. Total losses @ midnight= -300 bbls ( some of this was over shakers). 8/26/2001 00:00 - 00:30 0.50 DRILL P PROD1 Drilled from 7986' to 8031'. Mud Losses < 5 bbl/hr. 00:30 - 03:00 2.50 DRILL P PROD1 Pump Hi Vis sweep and weight up mud to 10.3 ppg. Losses - 90 bbl / hr @ 190 gpm. 03:00 - 06:00 3.00 DRILL N PROD1 Shut down pumps & monitor well. Slight trickle down flow line to static. POH to 6632'. Had to pump 1 1/2 bpm to get displacement. Well static at 6632' with pumps off. RIH. ream last stand to 8031' 06:00 - 07:30 1.50 DRILL P PROD1 Drill from 8031' to 8124'. Losses up to 220 bbls / hr. Slowed pumps to 228 gpm. 07:30 - 09:00 1.50 DRILL N PROD1 Shut down pumps. Monitor well. Well flowed back 20 bbls in 15 minutes- additional 15 bbls 1/2 Hr. Began circulating slowly while building volume - immediate losses. 09:00 - 00:00 15.00 DRILL P PROD1 Cont. drilling from 8124' to 8758' Losses ranged from 50 to 180 bbl/hr, pumping @ 235 gpm. ART 13.5 hrs. P/U 192K S/O 116K ROT = 144K Total losses for 24 Hrs = 1440 bbls. 8/27/2001 00:00 - 04:00 4.00 DRILL P PROD1 Drill from 8758' to 8950'. TD called by Geologist. ART = 3.5 Hrs. Printed: 9/4/2001 5:04:4'1 PM BP EXPLORATION Page 4 of 5 Operations Summa Report Legal Well Name: L-107 Common Well Name: L-107 Spud Date: 8/18/2001 Event Name: DRILL+COMPLETE Start: 8/16/2001 End: 8/31/2001 Contractor Name: NABORS Rig Release: 8/31/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/27/2001 00:00 - 04:00 4.00 DRILL I P PROD1 P/U = 198K S/O = 118K ROT = 148K 236gpm @ 1980 psi. Mud losses to hole = 60 bbl / hr 04:00 - 05:30 1.50 DRILL P PROD1 Circ. Hi - Vis Sweep. Mud losses 120 bbls. 05:30 - 09:00 3.50 DRILL N PROD1 Shut down pumps. Monitor flowback. Hole flowed back total of 296 bbls. in a continuous trend of decreasing flow rates. Flowback down to 0.2 bbl / hr.- steady for last 30 min. 09:00 - 15:30 6.50 DRILL P PROD1 POH wet to 6072'. Monitor well very closly. Hole still giving back at 0.2 bbl / hr. - Never any indication of swabbing. Run back in hole taking survey check shots @ 7282' & 7375' tO 8860'. Hole not giving any mud for displacement. No Hole drag problems. 15:30 - 19:00 3.50 DRILL P PROD1 Stage up pumps. Wash down to TD @ 8950. No Fill. Circ. Hi - Vis sweep. Mud losses up to 270 bbl/Hr, then down to 110 bbl / Hr. pumping @ 220 gpm 1400 psi. Hole began giving back fluid @ 90 BBI / Hr. 19:00 - 21:00 2.00 DRILL N PROD1 Shut down pumps and monitored flowback. Same decreasing, deflnate trend as before. Again stabilized @ 0.2 bbl/hr. Total flowback - 126 bbls. 21:00 - 22:00 1.00 DRILL N PROD1 Pump Barofiber Pill and Lubricant Pill to spot for running prod. string. Losing 150 bbl / hr while pumping. 22:00 - 00:00 2.00 DRILL N PROD1 Again, shut down pumps and monitor flowback. Same decreasing trend as before. Total 115 bbl gain. Final flow stabilized @ 0.2 bbl/hr. 8/28/2001 00:00 - 10:30 10.50 CASE P PROD1 POH wet, monitoring well closley. 20K over pull from 8730' to 8620' wipe through once - OK. Remainder of hole no problems. Pumped dry job at shoe and cont. POH,L/D DP. 10:30 - 13:30 3.00 CASE P PROD1 POH L/D BHA. Pipe displacement correct - Hole stable. 13:30 - 14:00 0.50 CASE P PROD1 Clear & clean floor of BHA & Tools. 14:00 - 21:30 7.50 CASE P PROD1 RIH w/D/P from derrick to shoe - POH L/D DP. Repeat - All D/P L/D 21:30 - 22:00 0.50 CASE P PROD1 Pull Wear Bushing - Make dummy run w/Hgr. & Landing Jt. 22:00 - 23:30 1.50 CASE P PROD1 Rig Up to run Casing - C/O Bails. 23:30 - 00:00 0.50 CASE P PROD1 P/U 3.5" Shoe Jt. & Begin RIH w/Casing 8/29/2001 00:00 - 14:00 14.00 CASE P COMP Run 3,5' X 5.5" Prod. Csg. Running @ 30' to 50' per min. to minimize mud losses. Total 151 bbls mud lost to hole. Landed as per program, with Shoe @ 8933'. 14:00 - 15:30 1.50 CASE P COMP Attempt circ - Reciprocate pipe & Stage pumps up to 5 bbls min @ 660 psi- No returns. Pumped 331 Bbls. PJU SWS. 15:30 - 17:00 1.50 CEMT P COMP SWS / Dowell pump 10 bbl 8.3 ppg CWl00. Test lines to 4000 psi 10 bbls. CWl00. Drop btm plug. Pump 40 bbls 10.8 ppg Mudpush XL followed by 61 bbls. 12.0 ppg CemCRETE Cement. Drop top plug and displace with 201 bbls filtered sea water w/cement pump. No Returns until last 41 bbls of displacement, then only 15 bbls returns. Pressures indicate pushing Cement up annulus. Bump plug w/2500 psi. Check floats - OK. 17:00 - 19:00 2.00 WHSUR P COMP PJD SWS. Back out Landing Jt. M/U running tool Install Pack Off R.I.L.D.S. Test Pack Off to 5000 psi - OK 119:00 - 20:00 1.00 RUNCOr/F' i COMP M/U 3.5" Hanger and Landing Jt.. Make Dummy run. while i waiting on SWS. 20:00 - 00:00 4.00 EV^L N COMP R/U SWS Run Temperature Log w/GR / CCL. Good indication of TOC @ 7740'. R/D SWS. 8/30/2001 00:00 - 01:30 1.50 RUNCOr/F' COMP Service Top Drive, Level Derrick Printed: 9/4/2001 5:04:41 PM BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: L-107 Common Well Name: L-107 Spud Date: 8/18/2001 Event Name: DRILL+COMPLETE Start: 8/16/2001 End: 8/31/2001 Contractor Name: NABORS Rig Release: 8/31/2001 Rig Name: NABORS 9ES Rig Number: Date From - To Hours ActivityCode NPT Phase Description of Operations 8/30/2001 01:30 - 02:00 0.50 RUNCO~ COMP R/U to run 3.5" Tubing 02:00 - 10:00 8.00 RUNCO~ COMP RIH w/3.5" Tubing Completion String 190 Jts. LOT, Injectivity test and freeze Protection on 5 1/2" X 7 5/8" ' annulus performed simultaneously. SEE REMARKS FOR DETAIL 10:00 - 11:00 1.00 RUNCO~ COMP Pressure Test 3.5" X 5.5" Csg to 4000 psi for 30 Minute Test. PJSM w/Camco 11:00 - 12:00 1.00 RUNCO~ COMP Rig up Camco to run control line 12:00 - 13:00 1.00 RUNCO~ COMP M/U SSSV. Install control line & test to 5000 psi 13:00 - 17:00 4.00 RUNCO~ COMP Run Remaining 70 Jts 3.5" tubing w/1 SS strap per Jr. 17:00 - 18:00 1.00 RUNCO~ COMP Space out Seal Assy. into PBR 18:00 - 19:30 1.50 RUNCO~ COMP M/U Hanger, Landing Jt.. M/U Control line to Hanger 19:30 - 20:30 1.00 RUNCO~ COMP Reverse circulate Corrosion Inibited sea water. 20:30 - 21:30 1.00 RUNCO~ COMP RIH & Land Hanger. R.I.L.D.S. Torque to 450 fi/lbs 21:30 - 23:00 1.50 RUNCO~ COMP Pres. test tbg to 4000 psi. / 30 min. Bleed to 2000 psi_Pres. annulus to 4000 psi / 30 min. Bleed off tubing to shear RP- OK 23:00 - 00:00 1.00 RUNCO~ COMP Set TWC pres. test to 2800 psi from below. 8/31/2001 00:00 - 03:00 3.00 RIGD P COMP N/D BOPE 03:00 - 08:00 5.00 RIGD P COMP N/U Adaptor Flange & Tree. Adaptor Flange mis-aligned. N/D Flange & Tree. Properly align Flange & Tree. Test seal to 5000 psi 08:00 - 10:00 2.00 RIGD P COMP Attempt to test tree - TWC leaking. Pull & CIO TWC. Test Tree to 5000psi Pull TWC. 10:00 - 11:30 1.50 RIGD P , COMP R/U Hot Oiler. Test lines to 3000 psi Pump 50 bbls diesel down annulus and up tubing to freeze protect.. 11:30 - 14:00 2.50 RIGD P COMP Allow diesel to U-Tube. R/U DSM. Install BPV. Test to 1000 psi. RID cellar & Floor. Suck down pits. Secure Well. RIG RELEASED 2 14:00 HRS. Printed: 9/4/2001 5:04:4'1 PM Well: L-107 Rig Accept: 08/17/01 Field: Prudhoe Bay / Borealis Rig Spud: 08/18/01 APl: 50-029-23036-00 Rig Release: 08/31/01 Permit: 201-151 Drilling Rig: Nabors 9ES POST - RIG WORK 09/03/01 Pull DSSSV, set slip stop catcher at 4500' wlmd. Pull R/P shear valve from GLM#4 at 4427'. Set DGLV in same. Pressure test tubing and IA to 4000 psi, good test. 09/04/01 Bled down IA to 0 psi. With 4000 psi on tubing, 30 minutes test, good test. Pull 3-1/2" slipstop catcher sub from 4549' wlm. Drift and tag to 8758' wlm with 11' x 2.50" dummy gun. 09/16/01 Tie into Schlumberger resistivity log (08/27/01). Complete jewelry log from PBTD of 8770' - 7900'. Perf 30'; 8452' - 8482' with Powerflow big hole charge, EHD = .66", Penetrate 4.8", 6 spf. 09/17/01 Perforate with 2.5" Powerflow at 6 spf charge; 8422' - 8452' and 8394' - 8422'. 09/20/01 Run SBHPS with tandem petradat gauges. Average pressure at 6600' ss = 3463 psi. Set 1" SPMG (bottom latch) at 8066' sim. 09/21/01 MITIA to 3500 psi, passed. Pull catcher sub. Purge control line. Pump 22 bbls Diesel down tubing. Make two runs to set 2.813" frac sleeve in SVLN. 09/22/01 Attempt to set 2.812" frac sleeve at SVLN. Brush and flush tubing 0' to 2200'. Troubleshoot frac sleeve. Needs modification. 09/23/01 Set frac sleeve at 2176' sim. Good test. Pump 50 bbl WF130 slick data frac. ISIP = 1869 psi, closure time - 3.8 min, 50% fluid efficiency. Pump second 50 bbl YF130LG data frac (pump 5 bpm till pad on perf then increased to 25 bpm). ISIP - 1867 psi. Est. closure at 34 min, 84% fluid efficiency, 253# net pressure. Closure pressure 4473 psi. Redesign frac. Pumped 30 bbl YF130LG pad. Ramped from 1 to 6 ppa sand stages. Stepped 6 to 10 ppa stages. Placed 200,000# 16/20 carbolite into formation. Left 3 bbl 10 ppa in wellbore. Top of sand at 8000' (1900#). Recovered all treesaver cups. 09/27/01 Run in hole with 2.69 centralizer. Tagged ice in tubing at surface. 09/28/01 Run in hole, jetting ice from surface to approximately 900'. Jet down to frac sleeve at 2189' ctd. Pull out of hole. Pull frac sleeve. Recovered. Cleanout frac sand to 8824' ctd. Pull out of hole laying in Diesel from TD to surface. ANADRILL SCHLUMBERGER Survey report Client ................... : BP Exploration (Alaska) Inc. Field .................... : L-Pad Well ..................... : L-107 API number ............... : 50-029-23036-00 Engineer ................. : Corriveau COUNTY: .................. : Nabors 9ES STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference ....................... Permanent datum .......... : MEAN SEA LEVEL Depth reference .......... : Driller's Pipe Tally GL above permanent ....... : 48.80 ft KB above permanent ....... : -50000.00 ft DF above permanent ....... : 77.30 ft Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 133.02 degrees 28-Aug-2001 19:00:24 Page 1 of 5 Spud date ................ : 18-Aug-01 Last survey date ......... : 28-Aug-01 Total accepted surveys...: 98 MD of first survey ....... : 0.00 ft MD of last survey ........ : 8950.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 17-Aug-2001 Magnetic field strength..: 1148.99 HCNT Magnetic dec (+E/W-) ..... : 26.26 degrees Magnetic dip ............. : 80.74 degrees MWD survey Reference Criteria Reference G .............. : 1002 68 mGal Reference H .............. : 1149 26 HCNT Reference Dip ............ : 80 75 degrees Tolerance of G ........... : (+/-) 2 50 mGal Tolerance of H ........... : (+/-) 6 00 HCNT Tolerance of Dip ......... : (+/-) 0 45 degrees Corrections Magnetic dec (+E/W-) ..... : 26.27 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.27 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [(c)2001 Anadrill iDEAL ID6_iC_i0] ~qADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 82.00 0.50 19.00 82.00 3 169.00 1.25 68.00 87.00 4 260.00 2.30 100.50 91.00 5 355.00 3.25 102.00 95.00 6 475.11 4.34 114.84 7 570.54 5.37 107.83 8 660.60 5.79 108.12 9 752.93 7.13 116.77 10 846.14 7.86 125.98 11 938.82 8.74 137.72 12 1033.37 10.59 138.86 13 1129.06 13.88 138.77 14 1224.36 15.94 137.15 15 1310.68 17.93 137.98 16 1405.39 20.44 139.06 17 1497.49 23.05 140.87 18 1590.12 23.10 138.24 19 1682.96 26.45 134.10 20 1775.72 27.61 129.73 21 1868.87 29.98 129.29 22 1961.96 32.35 131.70 23 2054.69 35.71 133.67 24 2147.46 38.63 133.07 25 2241.46 42.06 132.26 26 2334.19 45.24 133.16 27 2428.07 47,21 131.23 28 2521.55 49.45 131.32 29 2614.00 52.43 132.54 30 2707.25 52.23 131.60 120.11 95.43 90.06 92.33 93.21 92.68 94.55 95.69 95.30 86.32 94.71 92.10 92,63 92.84 92.76 93.15 93.09 92.73 92.77 94.00 92.73 93.88 93.48 92.45 93.25 28-Aug-2001 19:00:24 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 0.00 0.00 0.00 0.00 0.00 82.00 -0.15 0.34 0.12 0.36 168.99 0.10 1.05 1.12 1.54 259.95 2.06 1.09 3.84 3.99 354,83 5.97 0.18 8.34 8.35 474.68 569.77 659,40 751.14 843.56 935.28 1028.48 1121.98 1214.07 1296.64 1386.09 1471.63 1556.85 1641.14 1723.77 1805.40 1885.05 1961.89 2035.81 2107.44 13.21 -2.43 15.80 15.99 20.68 -5.32 23.33 23.93 28.62 -8.02 31.66 32.66 38.34 -12.05 41.20 42.93 50.22 -18.40 51.52 54.71 63.53 -27.33 61.39 67.20 79.33 -39.19 71.94 81.92 99.51 -54.45 85,29 101.19 123.93 -72.64 101.73 125.00 149.00 -91.21 118.68 149.68 179.97 -114.53 139.28 180.33 213.83 -140.67 161.20 213.95 249.89 -168.29 184.75 249.91 288.72 -196.28 211.74 288.72 330.84 -224.40 243.11 330.84 0.00 19.00 46.77 74.11 88.73 98.75 102.84 104.22 106.30 109.65 114.00 118.58 122.55 125.53 127.54 2174.53 2239.48 2301.62 2359.87 2416.86 129.43 131.11 132.33 132.83 132.71 375.62 -252.94 -277.73 375.64 132.33 423.73 -284.24 314.33 423.78 132.12 475.61 -319.44 352.44 475.66 132.19 531.66 -357.92 393.19 531.70 132.31 592.50 -399.14 437.94 592.54 132.35 484.95 535.18 587.65 641.04 695.83 656.54 724.31 794.12 865.90 939.71 656.49 -442.56 724.27 -488.07 794.06 -534.13 865.82 -582.11 939.62 -631.56 132.38 132.36 132.27 132.24 132.23 2 of 5 DLS (deg/ i00f) 0.00 0.61 1.15 1.56 !.00 1.15 1.24 0.47 1.79 1.51 2.06 1.97 3.44 2.21 2.32 2.68 2.93 1.11 4.06 2.48 2.55 2.88 3.81 3.17 3.69 3.49 2.57 2.40 3.38 0.83 Srvy tool type TIP GYR GYR GYR GYR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA IFR -- MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR Tool qual type [(c}2001 Anadrill IDEAL ID6_lC_10] ANADRILL SCHLUMBERGER Survey Report 28-Aug-2001 19:00:24 Page 3 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft) (ft) (ft) (ft) (ft) (deg) 31 2798.64 52.03 130.95 91.39 2472.96 32 2893.91 51.61 131.37 95.27 2531.85 33 2987.41 51.38 130.73 93.50 2590.06 34 3004.78 51.25 131.47 17.37 2600.92 35 3115.55 51.38 129.32 110.77 2670.16 36 3209.03 51.62 130.79 37 3302.14 49.51 129.69 38 3396.13 50.05 130.25 39 3489.60 48.45 129.70 40 3583.38 48.96 130.67 93.48 93.11 93.99 93.47 93.78 93.01 93.85 93.65 94.26 92.94 41 3676.39 49.41 131.76 42 3770.24 50.26 132.15 43 3863.89 51.17 131.34 44 3958.15 .52.51 130.91 45 4051.09 51.82 133.20 2728.36 2787.50 2848.19 2909.20 2971.09 3031.88 3092.42 3151.71 3209.95 3266.97 46 4144.80 52.48 134.01 93.71 3324.47 47 4238.13 51.50 135.79 93.33 3381.94 48 4333.34 52.04 137.12 95.21 3440.86 49 4427.22 50.47 136.97 93.88 3499.61 50 4521.66 51.19 135.97 94.44 3559.26 51 4613.82 50.85 136.63 92.16 3617.24 52 4707.60 50.92 136.44 93.78 3676.40 53 4801.11 52.93 135.78 93.51 3734.07 54 4893.50 51.24 138.30 92.39 3790.84 55 4987.63 49.69 138.57 94.13 3850.76 1011.73 -679.15 750.05 1086.58 -728.44 806.43 1159.70 -776.49 861.61 1173.25 -785.41 871.83 1259.62 -841.43 937.68 1011.84 1086.72 1159.88 1173.43 1259.86 132.16 132.09 132.03 132.01 131.90 1332.68 -888.51 993.67 1332.98 131.80 1404.50 -934.97 1048.55 1404.86 131.72 1476.17 -981.07 1103.55 1476.60 131.64 1546.87 -1026.57 1157.81 1547.37 131.56 1617.24 -1072.03 1211.64 1617.81 131.50 1264.58 1317.92 1372.00 1427.83 1482.33 1687.60 -1118.41 1759.31 -1166.36 1831.77 -1214.62 1905.84 -1263.36 1979.23 -1312.52 1535.91 1588.00 1639.52 1689.41 1739.84 2053.22 -1363.55 2126.71 -1415.45 2201.36 -1469.66 2274.40 -1523.25 2347.48 -1576.33 1789.33 1839.39 1890.42 1940.10 1988.27 2036.03 2083.96 2132.75 2180.84 2228.52 2419.00 -1628.12 2491.63 -1680.93 2565.13 -1733.98 2637.83 -1787.30 2710.10 -1841.61 1688.20 1759.92 1832.40 1906.51 1979.90 2053.85 2127.26 2201.80 2274.73 2347.73 2419.19 2491.76 2565.22 2637.88 2710.11 2781.98 2853.75 2926.70 2998.82 3070.25 56 5081.55 50.85 138.64 93.92 3910.79 2781.98 -1895.79 57 5174.31 51.12 137.98 92.76 3969.18 2853.75 -1949.61 58 5268.04 51.66 138.48 93.73 4027.67 2926.69 -2004.24 59 5361.27 50.24 138.27 93.23 4086.41 2998.77 -2058.36 60 5454.88 49.73 138.36 93.61 4146.60 3070.16 -2111.90 131.49 131.51 131.52 131.50 131.52 131.60 131.71 131.87 132.04 132.18 132.30 132.42 132.53 132.65 132.81 132.96 133.09 133.22 133 .35 133.46 DLS (deg i00f 0.60 0.56 O.59 3.41 1.52 1.26 2.44 0.73 1.77 0.95 1.01 0.96 1.18 1.47 2.08 0.98 1.83 ].24 1.68 1.12 0.67 0.17 2.22 2.82 1.66 1.24 0.62 0.71 1.53 0.55 Srvy Tool / tool qual ) type type MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR [(c)2001 Anadrill IDEAL ID6_iC_10] ANADRILL SCHLUMBERGER Survey Report 28-Aug-2001 19:00:24 Page 4 of 5 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5548.73 48.86 135.84 93.85 62 5642.35 49.40 132.74 93.62 63 5734.94 48.83 131.01 92.59 64 5828.64 48.80 132.97 93.70 65 5920.09 48.62 133.38 91.45 TVD depth (ft) _ 4207.81 4269.07 4329.68 4391.38 4451.73 66 6014.05 47.74 133.38 93.96 4514.38 67 6106.49 46.97 133.58 92.44 4577.00 68 6200.23 45.72 135.44 93.74 4641.72 69 6293.92 44.82 133.82 93.69 4707.65 70 6387.19 43.78 133.43 93.27 4774.41 71 6480.85 42.72 135.29 72 6574.14 41.82 133.74 73 6666.94 40.72 134.70 74 6760.71 39.59 132.24 75 6854.21 38.51 130.38 76 6947.51 37.55 129.22 77 7041.09 36.19 130.18 78 7135.28 34.83 129.58 79 7228.15 33.71 129.70 80 7320.69 31.24 131.12 93.66 93.29 92.80 93.77 93.50 93.30 93.58 94.19 92.87 92.54 95.35 92.27 93.25 92.78 93.06 81 7416.04 30.04 129.44 82 7508.31 28.33 131.73 83 7601.56 26.24 131.67 84 7694.34 23.68 131.69 85 7787.40 21.51 132.37 4842.63 4911.66 4981.41 5053.08 5125.70 5199.19 5274.05 5350.72 5427.47 5505.53 5587.57 5668.12 5750.99 5835.10 5921.01 86 7881.79 20.83 131.77 94.39 6009.03 87 7971.09 20.07 128.47 89.30 6092.71 88 8069.43 17.58 127.96 98.34 6185.78 89 8159.75 16.10 128.91 90.32 6272.22 90 8253.53 14.50 129.67 93.78 6362.68 Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (ft) 3141.11 -2164.02 2276.94 3211.87 -2213.44 2327.60 3281.85 -2260.16 2379.72 3352.35 -2307.33 2432.13 3421.07 -2354.35 2482.24 3491.09 -2402.44 3559.08 -2449.23 3626.87 -2496.76 3693.40 -2543.51 3758.54 -2588.46 2533 .13 2582 .47 2630.84 2678.21 2725.36 3822.69 -2633.31 3885.41 -2677.31 3946.61 -2719.99 4007.06 -2761.60 4065.93 -2800.49 2771.24 2815.98 2859.85 2903.72 2947.95 4123.32 -2837.28 4179.37 -2873.14 4234.00 -2908.22 4286.20 -2941.58 4335.83 -2973.7'7 2992.10 3035.31 3077.29 3117.56 3155.40 4384.36 -3005.20 4429.31 -3034.44 4472.04 -3062.88 4511.18 -3088.91 4546.92 -3112.84 3192.46 3226.64 3258.55 3287.79 3314.35 4581.01 -3135.68 4612.15 -3155.79 4643.77 -3175.43 4669.85 -3191.69 4694.55 -3207.35 3339.66 3363.49 3388.42 3408.92 3428.08 Total displ (ft) 3141.24 3212.02 3281.98 3352.47 3421.18 At Azim (deg) 133.54 133.56 133.52 133.49 133.49 3491.20 3559.20 3627.00 3693.54 3758.68 133.48 133.48 133.50 133.52 133.52 3822.84 3885.58 3946.78 4007.24 4066.10 133.54 133.55 133.56 133.56 133.53 4123.45 4179.48 4234.08 4286.27 4335.88 133.48 133.43 133.38 133.34 133.30 4384.40 4429.34 4472.07 4511.20 4546.95 133.27 133.24 133.23 133.21 133.20 4581.03 4612.17 4643.78 4669.86 4694.55 133.20 133.18 133.14 133.12 133.09 DLS (deg/ 100f) 2.24 2.57 1.54 1.57 0.39 0.94 0.85 1.95 1.55 1.15 1.77 1.48 1.37 2.08 1.70 1.28 1.58 1.49 1.21 2.79 1.55 2.21 2.24 2.76 2.35 0.76 1.55 2.54 1.67 1.72 Srvy tool type MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR Tool qual type [(c)2001Anadrill IDEAL ID6_iC_10] ANADRILL SCHLb~BERGER Survey Report Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 28-Aug-2001 19:00:24 Page TVD Vertical Displ Displ Total At depth section +N/S- +E/W- displ Azim (ft} (ft) (ft) (ft) (ft) (deg) 91 8347.18 12.89 129.76 93.65 6453.66 4716.68 -3221.51 3445.13 92 8440.09 12.31 131.05 92.91 6544.33 4736.92 -3234.65 3460.57 93 8533.37 11.99 131.91 93.28 6635.53 4756.55 -3247.65 3475.28 94 8625.88 10.40 130.92 92.51 6726.27 4774.50 -3259.54 3488.74 95 8718.53 9.17 132.43 92.65 6817.57 4790.24 -3270.00 3500.51 6910.02 6989.76 7046.92 93.48 80.40 57.59 4716.68 4736.93 4756.55 4774.50 4790.24 133.08 133.07 133.06 133.05 133.05 96 8812.01 7.84 134.07 97 8892.41 6.93 137.78 Projected to TD 98 8950.00 6.93 137.78 4804.07 -3279.46 3510.59 4804.07 133.05 4814.38 -3286.86 3517.78 4814.38 133.06 4821.31 4821.31 -3292.01 3522.45 133.06 5 of 5 DLS (deg/ 100f) 1.72 0.69 0.39 1.73 1.36 1.45 1.28 0.00 Srwf tool type MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MSA_IFR MWD Tool qual type [ (c)2001 Anadrill IDEAL ID6_IC_10] 9/19/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1463 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Well Job # Log Description Date Color Sepia BL CD :L-116 21337 AIT/PEX/DSI 07111/01 1 L-t16 21337 PEX-AIT 07/11/01 I 1 L-116 21337 PEX-NEUTRON DENSITY 07/11/01 t 1 L-116 21337 PEX & DSl SSTVD 07/11/01 1 1 L-116 21337 RFT 07112/01 1 1 L-107 TEMPERATURE LOG 08/29/01 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: RECEIVED S£P 2 8 2001 Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie b,p Date: 09-17-2001 Transmittal Number:92241 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. If you have any questions, please contact me in the PDC at 564-4091. Top SW Name Date Contractor Log Run Depth Bottom Depth Log Type L-107 08-28-2001 ANADRILL 1 0 8950.00 MWD SURVEY; HARD COPY/DISKETTE; ease Sign and Return one copy of this transmittal. Thank You, James H. Johnson Petrotechnical Data Center Attn: Lisa Weepie (AOGCC) Attn: Susan Nisbet (Exxon Mobil Production Co.) Attn: Sandy Lemke (Phillips Alaska, Inc.) RECEIVED SEP 2 1 ?.01)1 Alaslm Oil & Gas Cons. Commi~on Anchorage Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 AI,ASI~A OIL A~D GAS CONSERYA~I~iON COPl~TISSION TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Unit L-107 BP Exploration (Alaska) Inc. Permit No: 201-151 Sur Loc: 2397' NSL, 3646' WEL, SEC. 34, T12N, R11E, UM Btmhole Loc. 4340' NSL, 76' WEL, SEC. 03, T11N, R11E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt yOu from obtaining additional Permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit L- 107. Blowout prevention equipment (BOPE) must be 'tested in accordance with 20AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow, a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Julie M. Heusser Commissioner BY ORDER OF THE CO~3MMISSION DATED this ~'~ ~.-~-~' day of July, 2001 jjc/Enclosures CC: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA '( ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 [] Ddll [] Reddll I lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen [] Service [] Development Gas [] Single Zone [] Multiple Zone I 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 77.0' Prudhoe Bay Field / Borealis 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028241 4. Location of well at surface '7. Unit or Property Name 11. Type Bond (See 20 AA-C 25.025) 2397' NSL, 3646' WEL, SEC. 34, T12N, R11E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 4407' NSL, 148' WEL, SEC. 03, T11 N, R11E, UM L-107 Number 2S100302630-277 At total depth 9. Approximate spud date 4340' NSL, 76' WEL, SEC. 03, T11N, R11E, UM 08/08/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028240, 76' MDI No Close Approach 2560 9048' MD / 7116' -I-VD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' MD Maximum Hole Angle 49 * Maximum surface 2731 psig, At total depth (TVD) 6457' / 3377 p$ig 18. Casing Program Specifications Setting Depth Size To 3 Bottom Quantity,of Cement Hole Casina Weiaht Grade Couplin.q Len.qth MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 WLD 80' Surface Surface 80' 80' 260 sx Arctic Set (Approx:). 9-7/8" 7-5/8" 29.7# L-80 BTC 2877' Surface Surface 2877' 2577' 284 sx Arctic Set Litel 197 sx 'G' 6-3/4" 5-1/2. x3-1/2. 15.5#/9.2# L-80 BTC-M/IBT-M 9048' Surface Surface 9048' 7116' 108 sx Dowell Lite Crete 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented M D TVD Structural Conductor Surface Intermediate Production RECEIVED Liner JUL Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Allen Sherritt, ~64-5204 Prepared By Name/Number: $ondra Stewman, 564-4~'50 21. I hereby certify that the foregoing is true and co.r,r-e~t to the best of my knowledge _ II Signed DanStone~------~--_.'=~'-r3. ~ Title Senior Drilling Engineer Date "'7 ".' ':.'" .'ii"':':' ':." .;;" "?,"'i' i ,';,!". i:';i,,, '.::';""; i;"'i'' :..:!,,','.:;; ;:i'::"i ::,'. :: '?.'?,'::;Ii!,:,,,':';",'," '!.,!.:.';'";,,;i,::,:'i ii;':'.i'":";:;.i;,!,'?.!',ii,.:: ,.:'i:i:.;'.C~;,~:~:!!~i;~i~,!U~,'0~!.~'i'.'.:.i;'~ .."i:l,'i,:','.'i ?'l:"":;i iI .!',!:.!i'i':'..::.!il:'i .::;i!,::.';'i":;!'.:'l"i,' ;': ?,i;,,:,;.;i";il,',,;:i,'!.? ';" ii'! :::? ,! ;:,!'i .'i,::'i.,!:' i.;::' "i.~; '"i= ;:, : ,:' ..:;i~':'I ':'." '!.: Permit Number J APl Number _ J Apl~oya.~ Date J See cover letter = o/-/.¢- / I 0- ¢ - ° 3 (:=, I,2~/E~) '? 7~'? / l for other requireme, nts .. Conditions of Approval: Samples Required [] Yes [] No Mud Log RCquire~l / I-! Yes J~ No Hydrogen Sulfide Measures [] Yes [] No_..Directi°nal Survey Required ~ Yes [] No Required Working Pressure forBOPE []2K []3K ~LK []5K E]10K []15K [] 3.5K psi for CTU Other: '~' '~ by order of ~./.~/, / B' .'";~R~(~'[~I~L ~,(~D ~"*~ i ~ I ~ ~ [ Commissioner the commission Date "//;~ '?///~i / Approved y , ~ ~ ..... ~. _ Form 10-401 'rlplicate I Well Name: IL-107 I Drill and Complete Plan Summary Type of Well (service / producer / injector): I Producer Surface Location: As-Built Target Location: Top Kuparuk Bottom Hole Location: X: 583,270.56' Y = 5,978,119.56' 2396' FSL (2882' FNL), 3645' FEL (1633' FWL), Sec. 34, T12N, R11E X = 586,810' Y = 5,974,890' 4407' FSL (872' FNL), 148' FEL (5131' FWL), Sec. 03, T11 N, R11E X = 586,883' Y = 5,974,824' 4340' FSL (938) FNL), 76' FEL (5203' FWL), Sec. 03, T11N, R11E I AFENumber: 15M4019 I I Estimated Start Date: 1 8/8/2001 I Rig: I Nabors9ES I Operating days to complete: 113.0 I MD: 19048' I I TVD: 17116' I BF/MS: 148.8' I Well Design (conventional, slimhole, etc.): I Microbore (Iongstring) I RKB: 1 77.0' I Objective: I Kuparuk Formation Mud Program: 9-7/8" Surface Hole (0-2877' ~: Fresh Water Surface Hole Mud Density Viscosity Yield Point APl FL PH (ppg) (seconds) (Ib/100ft~) (mls/30min) Initial 8.5 - 8.6 300 50 - 70 15 - 20 8.5 - 9.5 below Permafrost 9.3 - 9.5 300 50 - 70 15 - 20 8.5 - 9.5 interval TD 9.6 max 300 50 - 70 15 - 20 8.5 - 9.5 6 3A" Intermediate / Production Hole (2877' - 9048'): Fresh Water LSND Interval Density Tau o ~'P PV ' pH APl HTHP (PPg) Filtrate Filtrate Upper 9.3-9.5 4-7 20-25 8-14 8.5-9.5 4-6 Interval Top of 10.6 5-8 20-25 8-14 8.5-9.5 3-5 < 10 by HRZ HRZ L-107 Permit to Drill Page 1 Directional: Ver. Sperry WP-06 KOP: 300' Maximum Hole Angle: 49° at 2544' MD Close Approach Wells: All wells pass major risk criteria. Logging Program: Surface Intermediate/Production Hole Drilling: MWD / GR Open Hole: Gas Detection Cased Hole: None Drilling: MWD / GR/Res Open Hole: GR-Res-Neu-Den-PWD, Gas Detection, Cuttings samples Cased Hole: USIT cement evaluation (contingency) Formation Markers: Formation Tops MDbkb TVDss SV5 1580' 1480' SV4 1744' 1630' Base Permafrost 1908' 1775' SV3 2131' 1970' SV2 2344' 2140' SV1 2950' 2548' UG4A 3045' 2784' UG3 3936' 3195' UG1 4619' 3643' Ma 5058' 3931' WS2 (N sands) 5509' 4227' Not hydrocarbon bearing WS1 (O sands) 5701' 4353' Not hydrocarbon bearing Obf Base 6453' 4846' CM2 (Colville) 6799' 5073' THRZ 8195' 6209' BHRZ (Kalubik) 8350' 6355' K-1 8391' 6394' TKUP 8457' 6458' Hydrocarbon Bearing 3377 psi, 10.1 ppg Kuparuk C 8464' 6465' LCU Kuparuk B Kuparuck A TM LV (Miluveach) 8898' 6890' TD Criteria 9048' 7039' 150' below Miluveach top L-107 Permit to Drill Page 2 Casin(,irrubinq Proc ram: Hole Csg/ WtJFt Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 80/80 9-7/8" 7 5/8" 29.7# L-80 BTC 2877' GL 2877'/2577' 6-3/4" 5-1/2" 15.5# L-80 BTC-m 8307' GL 8307'/6392' 6-3/4" 3-1/2" 9.2# L-80 IBT-mod 741' 8307'/6392' 9048'/7116' Tubing 3-1/2" 9.2# L-80 IBT-mod 8307' GL 8307'/6392' Integrity Testing: Test Point I Depth Surface Casing Shoe 20' min from surface shoe Test Type LOT EMW 13.5 ppg target Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not circulated to surface. Casino. Basis: Size 1 7-5/8" Surface Lead: Based on 1908' of annulus in the permafrost @ 250% excess and 260' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume' Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2168' MD (2077' TVDbkb). Lead 281 bbl / 1578ft~ / 355 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 cf/sk. Tail 41 bbl / 230 ft~ / 197 sks of Dowell Premium 'G' at 15.8 ppg and 1.17 cf/sk. Casing Size~15'l/2"x3-1/2"Longstring Production I Basis' I Lead: Based on TOC 1000' above top of Kuparuk formation & 30% excess + 80' shoe. I Lead TOC: 7457' MD, 5637' TVDbkb Total Cement Volume: I Lead 45.9 bbls/ 258 ftc/107.9 sks of Dowell LiteCrete at 12.0 I ppg and 2.39 cf/sk. L-107 Permit to Drill Page 3 Well Control: Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- , Maximum anticipated BHP: L-116) · Maximum surface pressure: 3377 psi @ 6457' TVDss - Kuparuk Sands (MDT pressure 2731 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 4000 psi (for future frac stimulation treatments) · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 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. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. L-107 Permit to Drill Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. Operations: MIRU Nabors 9ES. 2. Nipple up diverter spool and riser. Function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 9 7/8" drilling assembly with MWD/GR and directionally drill surface hole to approximately 2877' MD / 2577' TVD. The actual surface hole TD will be +/-100' TVD below the top of the SV1 sand. POH LD BHA. 4. Run and cement the 7-5/8", 29.7# surface casing back to surface. A port collar will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 6-3/4" drilling assembly with MWD/GR/NEU/DENS/RES/PWD and RIH to float collar. Test the 9- 5/8" casing to 4000 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9-5/8" shoe and perform Leak Off Test. 8. Drill to __100' above the HRZ, ensure mud is condition to 10.6 ppg and perform short trip as needed. During this time hold the 'Pre-Reservoir' meeting highlighting kick tolerance and detection. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for liner and POOH. 9. Run and cement the tapered production casing as required from TD to 1000' above the Kuparuk. Displace the casing with seawater during cementing operations and freeze protect the 5 Y2" x 7-5/8" annulus as required. (Annular Disposal Requirement - Prior to freeze protecting annulus, perform second leak off test below the 7 5/8" shoe. Record on chart and submit to town.) 10. Test the casing to 4000 psi for 30 min. 11. Run the 3-1/2", 9.2#, L-80 gas lift completion assembly. Circulate around corrosion inhibitor. Sting seal assembly into tieback receptacle and test to 4000 psi for 30 minutes both the tubing and annulus. Release tubing pressure and shear RP valve. 12. Install TWC and test from below to 2900 psi. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 13. RU hot oil truck and freeze protect the well by reverse circulating in a sufficient volume of diesel to freeze protect both the tubing and annulus to ~2200' TVD. Allow diesel to U-tube from annulus to tubing and equalize at -2000' TVD 14. Rig down and move off. Estimated Spud Date: 8-8-2001 L-107 Permit to Drill Page 5 L-107 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies > L-Pad is not designated as an H2S site. NWE1-01 and NEW 1-02 did not report H2S as being present. (Confirmed per J. Copen.) As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. The closest surface location is L-01. L-01 will be -15' wellhead to wellhead. The well is not producing and will not require a surface shut-in. Reference RPs Operational Specifics Job 2: Drillinq Surface Hole Hazards and Contingencies > No faults are expected to be penetrated by L-107 in the surface interval. There is a nudge at 300' MD to increase distance from L-01in the surface hole. A surface gyro will be required while drilling the surface hole. All wells pass major risk criteria. Gas hydrates were observed by the NWE1-01and NWE1-02 wells. These were encountered near the base of the Permafrost at 1795' and 1730' TVD. L-01 and L-116 surface intervals encountered hydrates from the base of permafrost to TD in the SV1 sand. Expect to encounter hydrates from the base of permafrost to the surface shoe setting depth. Hydrates will be treated at surface with appropriate mud products. Refer to Baroid mud recommendation Associated with the hydrates, is the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. (Milne Point has encountered stuck pipe from this situation.) Reference RPs Operational Specifics Job 3: Install surface Casinq Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 7-5/8" port collar will be positioned at ___1000'MD to allow a secondary circulation as required. Reference RPs L-107 Permit to Drill Page 6 Operational Specifics Job 7: Drillincl Production Hole Hazards and Contingencies ~ KICK TOLERANCE: In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.5 ppg at the surface casing shoe, 10.6 ppg mud in the hole, kick tolerance is 25 bbls. An accurate LOT will be required as well as heightened awareness for kick detection, Contact Drilling Superintendent if LOT is less than 13.5 ppg. A fault is expected to be penetrated by L-107 in the base of the Schrader / top of Colville transition at -5000' TVDss. The throw is ~75' down to the west. This is not considered a high risk for lost circulation while drilling, however, losses maybe encountered when running the production casing string. Reference RPs Operational Specifics Job 9: Case & Cement Production Hole Hazards and Contingencies The 5-1/2" casing will be cemented to 1000' above the Kuparuk sand, the upper most hydrocarbon bearing zone. The top of the hydrocarbon interval should be verified with LWD resistivity log. If losses are encountered while running the production casing, be prepared to treat with barafiber when circulating on bottom prior to the cement displacement. Consider increasing cement volume if 100% returns are not established. After freeze protecting the 5 Y2" x 7-5/8" casing annulus to 2200' with 36 bbls of dead crude, the hydrostatic pressure will be assuming a diesel column to surface casing point at 2104' TVD, with 1000' of 12.0 ppg cement above the top of Kuparuk at 5637' TVD and 10.6 ppg mud to 2104' TVD, the hydrostatic pressure will be equivalent to 9.7 ppg or 3288 psi. (This is below the reservoir pressure of 3377 psi at top of Kuparuk) It is essential that freeze protection of the 7" annulus be performed only after the UCA indicates 500 psi compressive strength is indicated. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits,) > Ensure a minimum hydrostatic equivalent of 10.6 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes. > The well will be under-balanced after displacing the cement with Sea Water. Verify that the floats are holding before continuing operations and hold pressure on the well if they are not holding. Reference RPs Operational Specifics L-107 Permit to Drill Page 7 Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics Job 13: ND/NU/Release Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics L-107 Permit to Drill Page 8 TREE: 3-1/8" - 5M CIW L-80 WELLHEAD: 11" - 5M Borealis L-107: Proposed Completion Cellar Elevation = 49' RKB - MSL = 77' 3-1/2" 'X' Landing Nipple with 2..75' seal bore. I 2200' 7-5/8", 29.7 #/ft, Lo80, BTC 3-1/2" x 1" Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS 1 TBD 1" DV 2 TBD 1" DV 3 TBD 1" DV 4 TBD 1" DV 3-1/2" 9.2# IBT Mod L-80, Tubing 5-1/2", 15.5 #/ft, L-80, BTC Mod 3-1/2" 'X' Landing Nipple with 2.75" seal bore 3-1/2" Seal Asembly 3-1/2" PBR 5-1/2"x3-1/2" XO Plug Back Depth 8958' 3-1/2", 9.2 #/ft, L-80, IBT Mod 3-1/2" 'X' Landing Nipple with 2.75" seal bore 3-1/2" 'X' Landing Nipple with 2.75" seal bore, placed at +/-150' above the Kuparuk Formation. Date Rev By Comments 7/17/01 JAS Proposed Seal Bore Completion - WP6 Microbore with 5-1/2"x3-1/2" tapered Iongstring Borealis WELL: L-107 APl NO: 50-029-????? BP Alaska Drilling & Wells L-107 Well Summary of Drillin_cl Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates were observed in both NWE offset wells, L-01 and L-116. These are expected to be encountered near the base of the Permafrost at 1850' and near the TD hole section as well. · Gravel beds below the Permafrost will tend to slough in when aerated (hydrate cut) mud is being circulated out. Ensure adequate mud viscosity is maintained to avoid stuck pipe situations. Production Hole Section: · The production section will be drilled with a recommended mud weight of 10.6 ppg to ensure shale stability in the HRZ shale. Read the Shale Drilling Recommended Practice. Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Pipe sticking tendency is possible if the HRZ shale gives problems. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. FAULTS: The well trajectory is expected to intersect a fault while drilling L-107, in the base of the Schrader/top of the Colville @ ~5000' TVD. The throw is estimated @ ~75' and is not considered a high risk for loss circulation. Consult Lost Circulation Decision Tree for recommended LCM treatments. KICK TOLERANCE: With 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.5 ppg at the surface casing shoe, 10.6 ppg mud in the hole, kick tolerance is 25 bbls. A majority of the L-Pad development will have "kick tolerances" in the 25 bbl range or less. At least 100' prior to entering the Kuparuk reservoir, the drill crews will hold a safety meeting to discuss steps to ensure that a heightened awareness of kick detection will be in place while drilling/tripping through the intermediate/production intervals. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent wells NWE 1-01 and NWE 1-02 did not report H2S as being present. As a precaution Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies Page ] of 1 -1500-- 300O- 4500 6000 7500 BP Amoco Calculation Metlx~: l',finimum Curvature Env.r Syslem: ISCWSA Scan Met~-d: Tray Cylin&r North Error Surface: EllipOcal - CmSng Wami~, Method: Rules Based ~000 REFERENCE INFORI~LATION Co-ordinate {NE) Referen.~: Well CenIre: L-lO7, True North Vertk-al ITVD} Reference: Temp Plan elcxat~on 7777.OO S,.~:6on O,:S) Reference: Slot - S-N (0.OON.0.OOE} Measured Depth Reference: Yemp Plan e~.'ation 77 77.00 Calculation Metlx~: Minimum C'ar~mre All TVD depths are ssTVD plus 77' for RKBE. Start Dir 1°/100': 300' MD, 300'TVD Start Dir 1.75°/100': 700' MD, 699.68'TVD Start Dir 2.5°/100': 1096.84' MD, 1093.5'TVD End Dir: 1816.84' MD, 1771.48' TVD Start Dh- 4°/100': 2019,03' MD, 1950'TVD 7 5/8" ~ End Dh': 2544.0Y MD, 2358.57' TVD UG4A SURVEY PROGRAM Depth Fm Depth 1o SurveyPlan Iool 77.OO 1100.00 Plalme~ L-107 WP06 VI CB-GYRO-SS 1100.OO 9047.81 PlanneOc L-lrft %%q~06 %'1 Plum: I.- 1117 WI'Cfi (I-107/Plan l - 107} Created By: KLm Alien Dale: 7/17~21101 Checked: Date: Reviewed: [)ale: WELl. DETAILS ,Name -N-S-E;'-W Nocthing Eas~ing I. alim&. Longitude Sha L-10/ -116:'1 272.48 597gllgJ6 583270.56 7ff'21'00.680N 149°1926.178W S-N TARGET DEIAILS ~ TVD -N:-S -E~-W Nc~ahinglasting Shape P_L 5 6535.~O -3268.87 3503.78 59748c~.13 586810.12 I'oly~tm SECTION DETAILS Sec MD Inc AvA TVD +N/-S +E/-W Dkeg TFace VSec Target I 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 700.00 4.00 165.00 699.68 -13.48 3.61 1.00 165.00 11.84 4 1096.8410.00 132.84 1093.50 -50.32 32.49 1.75 310.14 58.09 5 1816.8428.00 132.84 1771.48 -209.06 203.67 2.50 0.00 291.53 6 2019.0328.00 132.84 1950.00 -273.60 273.27 0.00 0.00 386.46 7 2544.0349.00 132.84 2358.57 -494.56 511.59 4.00 0.00 711.45 8 6783.7349.00 132.84 5140.06 -2670.08 2857.96 0.00 0.00 3911.17 9 8457.1015.53 132.84 6535.00 -3268.87 3503.78 2.00 180.00 4791.86P_L_5 10 8897.816.72 132.84 6967.00 -3326.63 3566.07 2.00 180.00 4876.81 11 9047.813.72 132.84 7116.36 -3335.90 3576.07 2.00 180.00 4890.46 Sands) 7000 Start Dir 2°/100': 6783.7Y MD, 5140.06'TVD (Colville Shales K-10) 8000 ---- /HP, Z Kalubik K-1 TKUP ! Kuparuk C TMLV (Miluveach) 9000 / 5 1/2" ~ Total Depth: 9047.81' MD, 7116.36' TVD FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1557.00 1580.01SV5 2 1707.00 1744.41SV4 3 1852.00 1908.04Base Permafrost 4 2047.00 2131.34SV3 5 2217.00 2343.68SV2 6 2625.00 2950.13SVI 7 2687.00 3044.64UG4A 8 3272.00 3936.32UG3 9 3720.00 4619.19UGI 10 4008.00 5058.17Ma I I 4304.00 5509.35WS2 (lq Sands) 12 4430.00 5701.41WSI (O Sands) 13 4923.00 6452.87Obfbase 14 5150.00 6798.82CM2 (Colville Shales) 15 5714.00 7550.37CMl (Colville Shales K-10) 16 6286.00 8194.96THRZ 17 6432.00 8349.61Kalubik 18 6471.00 8390.45K-I 19 6535.00 8457.10TKUP 20 6542.00 8464.36Kuparuk C 21 6967.00 8897.81TMLV (Miluveach) CASING DETAILS No. TVD MD Name Size I 2577.00 2876.97 7 5/8" 7.625 2 71 16.359047.80 5 I/2" 5.500 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 Vertical Section at 133.01° [1500fl/in] BP Amoco Calculati~ Mett~d: Milfimum Cur;~ture Error S.',~em: ISCWSA Scan Method: Tmv Cylinder Nc~h Erroi' Sur face: EIl~Scal - Ca~ng Wamhm Meth~k Rul~ Based REFERENCE INFORbLttTION Co-ordinate (NE) Reference: Well Cenlre: L-107, The Nocth Vertical (TVD) Reference: Yemp Plan e}evation TI 77333 Sectkm {VS) Reference: Sk~ - S-N (0.0~N.O.OOE) Mea3ured Depth Reference: Temp Plan elevation 77 77.00 Calculaffon Me~hod: Mmmaim Curvallwe SURVEY PROGRAM Depth Fm Deplh To Sunw,Phan Tool 77.001100.00 Phnm~ L-10? ~TO6 VI CB-GYRO-SS 11oo.oo 9047.81 piannecE L-lO7 ~6 vi MYVD Plan: ! -107 WP06 (I.-107tPlan 1-107! ('reared By: Ken Allen Date: 7/17/200 I ('hocked: Dale: Re~iev, ed: Dale: WElL I)EIAll S Name W-S -E..-WNcn~ F. as~lr~ I atitu~I tmg~ Skq L-I~-11621272.~597811936 583270.~ 70:21'~.(~ 149:1926.178W S-N All TVD depths are ssTVD plus 77' for IARGEI DETAILS P L_5 6535.~ -32~.~ 3~3.7859748~.13 5~10.12 Polj~on Sec ~ Inc Azi T~ +N/-S +~-W DLeg TFace VSec Target I 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 700.00 4.00 165.00 699.68 -13.48 3.61 1.00 165.00 I 1.84 4 1096.84 10.00 132.84 1093.50 -50.32 32.49 1.75 310.14 58.09 5 1816.84 28.00 132.84 1771.48 -209.06 203.67 2.50 0.00 291.53 6 2019.03 28.00 132.84 1950.00 -273.60 273.27 0.00 0.00 386.46 St~ ~ 1°/100': 300' MD, 3~'T~ 7 2544.03 49.00 132.84 2358.57 -494.56 511.59 4.00 0.00 711.45 700' 699.68'IVD ~ MD, 8 6783.73 49.00 132.84 5140.06 -2670.08 2857.96 0.00 0.00 3911.17 ~ - Sm Dk 2.5°/100': 1~6.84' ~, 1093.5WVD 9 8457.10 15.53 132.84 6535.00 -3268.87 3503.78 2.00 180.00 4791.86 P L 5 500-00 ~ E ' 10 889781 672 13284 6967.00 -3326.63 3566.07 2.00 180.00 4876.81 - 10 nd D~ : 1816.84' MD, 1771.48' T~ I 1 9047~81 3~72 132~84 7116.36 -3335.90 3576.07 2.00 180.00 4890.46 1500 ~ Stm Dk 4~/100': 2019.0Y MD, 1950'T~ :-.' ~- '2°°° ._~nd~_ Dk : 25..03' MD, 2358.57' TVD CASING DETAILS ~ 2500 ~ . 1 2577.00 2876.97 75/8" 7.625 ~ ~ 2 7116.35 9047.80 5 112" 5.500 No. TVDPath MDPath Fo~ation ~ I 1557.00 1580.01 SV5 ............. ................... 350~_ ' 2 1707.00 17~.41 SV4 3 1852.00 1908.04 Ba~ Pe~afrost 4 2047.00 2131.34 SV3 5 2217.00 2343.68 SV2 -200& 4000 ~ 6 2625.00 2950.13 SVI 7 2687.00 30~.64 UG4A 8 3272.00 3936.32 UG3 9 3720.00 4619.19 UGI ............................................ 1 I 4304.00 5509.35 WS2 ~ Sands) 13 4923.00 6452.87 Obfb~ 14 5150.00 6798.82 CM2 (Colville Shales) 5000 ~ 95% cog. 15 5714.00 7550.37 CMl (Colville Shales K-10) ~ 17 6432.00 8349.61 Kalubik ~L_5 19 6535.00 8457.10 TKUP 00 x 21 6967.00 8897.81 TMLV (Miluveach) ~ 7000~ j i Tot~Depth:9~7.81'~,7116.36'TVD -400~ 0 1000 20~ 3000 4000 5000 6000 7000 8000 West(-)/East(+) [ 1000fl/in] BP Amoco Planning Report - Geographic Company: BP Amoco Date: 7/17/2001 Time: 16:41:26 Page: 1 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: L-107, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: L-107 Section (VS) Reference: Well (0.00N,0.00E,133.01Azi) Wellpath: Plan L-107 Plan: L-107 WP06 ........... :'~- ........ ~:~' ?~':~-z:~::~-_~.:_-_- ~-~.-"-~'~ ~:.: .................................. :'.---:'-,:-_~'_~::~'~'_-_~:~"~-'~_-.'~ ~: ' -'~.':~-"-- ~'~'.- '?"' ~:~ --- ...... 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: BGGM2001 Site: UNITED STATES · North Slope Site Position: Northing: 5978232.73 ft Latitude: 70 21 1.823 N From: Map Easting: 582996.83 ft Longitude: 149 19 34.141 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.63 deg Well: L-107 Slot Name: S-N Surface Position: +N/-S -116.21 ft Northing: 5978119.56 ft Latitude: 70 21 0.680 N +E/-W 272.48 ft Easting: 583270.56 ff Longitude: 149 19 26.178 W Position Uncertainty: 0.00 ft Reference Point: +N/-S -116.21 ft Northing: 5978119.56 ft Latitude: 70 21 0.680 N +E/-W 272.48 ft Easting: 583270.56 ft Longitude: 149 19 26.178 W Measured Depth: 77.00 ft Inclination: 0.00 deg VerticaIDepth: 77.00 ft Azimuth: 0.00 deg Wellpath: Plan L-107 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: Temp Plan elevation 77 Height 77.00 ft Above System Datum: Mean Sea Level Magnetic Data: 12/26/2000 Declination: 26.47 deg Field Strength: 57446 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 133.01 Plan: Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information 77.00 0.00 0.00 77.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 700.00 4.00 165.00 699.68 -13.48 3.61 1.00 1.00 0.00 165.00 1096.84 10.00 132.84 1093.50 -50.32 32.49 1.75 1.51 -8.10 310.14 1816.84 28.00 132.84 1771.48 -209.06 203.67 2.50 2.50 0.00 0.00 2019.03 28.00 132.84 1950.00 -273.60 273.27 0.00 0.00 0.00 0.00 2544.03 49.00 132.84 2358.57 -494.56 511.59 4.00 4.00 0.00 0.00 6783.73 49.00 132.84 5140.06 -2670.08 2857.96 0.00 0.00 0.00 0.00 8457.10 15.53 132.84 6535.00 -3268.87 3503.78 2.00 -2.00 0.00 180.00 8897.81 6.72 132.84 6967.00 -3326.63 3566.07 2.00 -2.00 0.00 180.00 9047.81 3.72 132.84 7116.36 -3335.90 3576.07 2.00 -2.00 0.00 180.00 P_L_5 Section 1 : Start ...... ": ~ ~'~"~'i~ i :"~'~ ~!'i-,'~i:"'~': ~'~'! '~;i;;"!'''~'~ 7:!~:?'-T;~']~i'':i :-~:;~"':::'::'i'-1'7i~-:¥ ¥~': ~':'~'~;~-' 7'?~ ~?i~i~ ft deg deg: : "ff' :ff :': :' ideg/,100ff:deg/100ff deg/100ft := deg 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 300'00 O:°__°. .......... °'~O ........... 30?0 ......... 0'.00 ......... °_.'00 .............. °'.0O ........... ._0:0.0 ....... BP Amoco Planning Report - Geographic Company: BP Amoco Date: 711712001 Time: 16:41:26 Page: Field: Prudhoe Bay Coordinate(NE) Reference: Well: L-107, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: L-107 Section (VS) Reference: Well (0.00N,0.00E,133.01Azi) Wellpath: Plan L-107 Plan: L-107 WP06 Section 2: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/lOOff deg/lOOfl deg/lOOft deg 400.00 1.00 165.00 399.99 -0.84 0.23 0.74 1.00 1.00 0.00 0.00 500.00 2.00 165.00 499.96 -3.37 0.90 2.96 1.00 1.00 0.00 0.00 600.00 3.00 165.00 599.86 -7.58 2.03 6.66 1.00 1.00 0.00 0.00 700.00 4.00 165.00 699.68 -13.48 3.61 11.84 1.00 1.00 0.00 0.00 Section 3: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/lOOff deg/lOOft deg/lOOft deg 800.00 5.30 150.36 799.35 -20.86 6.80 19.20 1.75 1.30 -14.64 -49.86 900.00 6.80 141.80 898.79 -29.53 12.74 29.46 1.75 1.50 -8.56 -35.27 1000.00 8.40 136.40 997.91 -39.48 21.45 42.61 1.75 1.60 -5.40 -26.75 1096.84 10.00 132.84 1093.50 -50.32 32.49 58.08 1.75 1.65 -3.68 -21.39 Section 4: Start ...... '"i ft deg deg i : , ft: ' , ft : :ft ..... ~i'i ~'(~'i-(~ .................. 10'08 --"-'-" ................. i' 32.84""~-'--"= .......... 58.63 ~'0'~ o'oo 1200.00 12.58 132.84 1194.66 -64.05 47.30 78.28 2.50 2.50 0.00 0.00 1300.00 15.08 132.84 1291.75 -80.30 64.82 102.18 2.50 2.50 0.00 0.00 1400.00 17.58 132.84 1387.71 -99.42 85.44 130.29 2.50 2.50 0.00 0.00 1500.00 20.08 132.84 1482.35 -121.36 109.10 162.56 2.50 2.50 0.00 0.00 1600.00 22.58 132.84 1575.49 -146.09 135.77 198.93 2.50 2.50 0.00 0.00 1700.00 25.08 132.84 1666.96 -173.56 165.39 239.33 2.50 2.50 0.00 0.00 1800.00 27.58 132.84 1756.58 -203.71 197.91 283.68 2.50 2.50 0.00 0.00 1816.84 28.00 132.84 1771.48 -209.06 203.67 291.54 2.50 2.50 0.00 0.00 Section 5: Start Section 6: Start ' ', deg':,, = deg '~ = 'fi:,' ~:,ft ' deg/lOOffdeg/'looffdegllOOff deg= ,: 2100.00 31.24 132.84 2020.38 -300.81 302.61 426.47 4.00 4.00 0.00 0.00 2200.00 35.24 132.84 2104.00 -338.07 342.79 481.27 4.00 4.00 0.00 0.00 2300.00 39.24 132.84 2183.60 -379.21 387.16 541.77 4.00 4.00 0.00 0.00 2400.00 43.24 132.84 2258.78 -424.02 435.48 607.68 4.00 4.00 0.00 0.00 2500.00 47.24 132.84 2329.18 -472.29 487.54 678.67 4.00 4.00 0.00 0.00 2544.03 49.00 132.84 2358.57 -494.56 511.59 711.45 4.00 4.00 0.00 0.00 Section 7: Start 2600.00 49.00 132.84 2395.29 -523.28 542.56 753.69 0.00 0.00 0.00 0.00 2700.00 49.00 132.84 2460.90 -574.60 597.90 829.16 0.00 0.00 0.00 0.00 2800.00 49.00 132.84 2526.50 -625.92 653.24 904.63 0.00 0.00 0.00 0.00 2900.00 49.00 132.84 2592.11 -677.23 708.58 980.10 0.00 0.00 0.00 0.00 3000.00 49.00 132.84 2657.71 -728.55 763.92 1055.57 0.00 0.00 0.00 0.00 3100.00 49.00 132.84 2723.32 -779.87 819.26 1131.04 0.00 0.00 0.00 0.00 3200.00 49.00 132.84 2788.93 -831.18 874.60 1206.51 0.00 0.00 0.00 0.00 3300.00 49.00 132.84 2854.53 -882.50 929.94 1281.98 0.00 0.00 0.00 0.00 3400.00 49.00 132.84 2920.14 -933.82 985.28 1357.45 0.00 0.00 0.00 0.00 3500.00 49.00 132.84 2985.74 -985.13 1040.62 1432.92 0.00 0.00 0.00 0.00 3600.00 49.00 132.84 3051.35 -1036.45 1095.96 1508.39 0.00 0.00 0.00 0.00 3700.00 49.00 132.84 3116.95 -1087.77 1151.30 1583.86 0.00 0.00 0.00 0.00 3800.00 49.00 132.84 3182.56 -1139.08 1206.64 1659.33 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 7/17/2001 Time: 16:41:26 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: L-107, True North Site: PB L Pad Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Well: L-107 Section (VS) Reference: Well (0.00N,0.00E,133.01Azi) Wellpath: Plan L-107 Plan: L-107 WP06 Section 7: Start MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg de9 ft ft ft ft deg/lOOft deg/lOOft deg/lOOft deg 3900.00 49.00 132.84 3248.17 -1190.40 1261.98 1734.80 0.00 0.00 0.00 0.00 4000.00 49.00 132.84 3313.77 -1241.72 1317.32 1810.27 0.00 0.00 0.00 0.00 4100.00 49.00 132.84 3379.38 -1293.03 1372.66 1885.75 0.00 0.00 0.00 0.00 4200.00 49.00 132.84 3444.98 -1344.35 1428.00 1961.22 0.00 0.00 0.00 0.00 4300.00 49.00 132.84 3510.59 -1395.67 1483.33 2036.69 0.00 0.00 0.00 0.00 4400.00 49.00 132.84 3576.20 -1446.98 1538.67 2112.16 0.00 0.00 0.00 0.00 4500.00 49.00 132.84 3641.80 -1498.30 1594.01 2187.63 0.00 0.00 0.00 0.00 4600.00 49.00 132.84 3707.41 -1549.62 1649.35 2263.10 0.00 0.00 0.00 0.00 4700.00 49,00 132,84 3773,01 -1600.93 1704.69 2338.57 0.00 0.00 0.00 0.00 4800.00 49.00 132.84 3838.62 -1652.25 1760.03 2414.04 0.00 0.00 0.00 0.00 4900.00 49.00 132.84 3904.23 -1703,57 1815.37 2489.51 0.00 0.00 0.00 0.00 5000.00 49.00 132.84 3969.83 -1754.88 1870.71 2564.98 0.00 0.00 0.00 0.00 5100.00 49.00 132.84 4035.44 -1806.20 1926.05 2640.45 0.00 0.00 0.00 0.00 5200.00 49.00 132.84 4101.04 -1857.52 1981.39 2715.92 0.00 0.00 0.00 0.00 5300.00 49.00 132.84 4166.65 -1908.83 2036.73 2791.39 0.00 0.00 0.00 0.00 5400.00 49.00 132.84 4232.25 -1960.15 2092.07 2866,86 0.00 0.00 0.00 0.00 5500.00 49.00 132.84 4297.86 -2011.47 2147.41 2942.33 0.00 0.00 0.00 0.00 5600.00 49.00 132.84 4363.47 -2062.78 2202.75 3017.80 0.00 0.00 0.00 0.00 5700.00 49.00 132.84 4429.07 -2114.10 2258.09 3093.28 0.00 0.00 0.00 0.00 5800.00 49,00 132.84 4494.68 -2165.42 2313.43 3168.75 0.00 0.00 0.00 0.00 5900.00 49.00 132.84 4560.28 -2216.73 2368.77 3244.22 0.00 0.00 0.00 0,00 6000,00 49.00 132.84 4625.89 -2268.05 2424.11 3319.69 0.00 0.00 0.00 0.00 6100.00 49.00 132.84 4691.50 -2319.37 2479.45 3395.16 0.00 0.00 0.00 0.00 6200.00 49.00 132.84 4757.10 -2370.68 2534.78 3470.63 0.00 0.00 0.00 0,00 6300.00 49.00 132.84 4822.71 -2422.00 2590.12 3546.10 0.00 0.00 0.00 0.00 6400.00 49.00 132.84 4888.31 -2473.32 2645.46 3621.57 0.00 0.00 0.00 0.00 6500.00 49.00 132.84 4953.92 -2524.63 2700.80 3697.04 0.00 0.00 0.00 0.00 6600.00 49.00 132.84 5019.53 -2575.95 2756,14 3772.51 0.00 0.00 0.00 0.00 6700.00 49.00 132.84 5085.13 -2627.27 2811,48 3847.98 0.00 0.00 0.00 0.00 6783.73 49.00 132.84 5140.06 -2670.08 2857.96 3911.17 0.00 0.00 0.00 0.00 Section8: Start :"i;;-;;i:ii::~:: i"i~/i"~';i':?','':'~''7~)~i':'I , vs =:,~:, :' 6800.00 48.67 132.84 5150.77 -2678.41 2866.94 3923.42 2,00 -2.00 0.00 180.00 6900.00 46.67 132.84 5218.10 -2728.68 2921.15 3997.35 2.00 -2.00 0.00 180.00 7000.00 44.67 132.84 5287.97 -2777.32 2973.60 4068.88 2.00 -2.00 0.00 180.00 7100.00 42.67 132.84 5360.29 -2824.27 3024.24 4137.94 2.00 -2.00 0.00 180.00 7200.00 40.67 132.84 5434.98 -2869.48 3072.99 4204.42 2.00 -2.00 0,00 180.00 7300.00 38.67 132.84 5511.95 -2912.89 3119.80 4268,26 2.00 -2.00 0.00 180.00 7400.00 36.67 132.84 5591.09 -2954.44 3164.61 4329.37 2.00 -2,00 0.00 180.00 7500.00 34.67 132.84 5672.32 -2994.09 3207.37 4387.69 2.00 -2.00 0.00 180.00 7600.00 32.67 132.84 5755.54 -3031.79 3248.03 4443.13 2.00 -2.00 0.00 180.00 7700.00 30.67 132.84 5840.64 -3067.49 3286.53 4495.64 2.00 -2.00 0.00 180.00 7800.00 28.67 132.84 5927.52 -3101.16 3322.83 4545.15 2.00 -2.00 0.00 180.00 7900.00 26.67 132.84 6016.07 -3132.73 3356.88 4591.59 2.00 -2.00 0.00 180.00 8000.00 24.67 132.84 6106.20 -3162.19 3388.65 4634.91 2.00 -2.00 0.00 180.00 8100.00 22.67 132.84 6197.78 -3189.49 3418.09 4675.06 2.00 -2.00 0.00 180.00 8200.00 20.67 132.84 6290.70 -3214.61 3445.17 4711.99 2.00 -2.00 0.00 180.00 8300.00 18.67 132.84 6384.86 -3237.50 3469.86 4745.66 2.00 -2.00 0.00 180.00 8400.00 16.67 132.84 6480.13 -3258.14 3492,12 4776.02 2.00 -2.00 0.00 180.00 8457.10 15.53 132.84 6535,00 -3268.87 3503.78 4791.87 2.00 -2.00 0.00 180.00 Section 9: Start ft: :: deg ::i :dog ' deg/loOft deg/1,0Oft:deg/lOoft deg 8600.00 12.67 132.84 6673.58 -3292.54 3529.31 4826.68 2.00 -2.00 0.00 180.00 8700.00 10.67 132.84 6771.51 -3306.30 3544.14 4846.91 2.00 -2.00 0.00 180.00 8800.00 8.67 132.84 6870.08 -3317.72 3556.46 4863.71 2.00 -2.00 0.00 180.00 8897.81 6.72 132.84 6967.00 -3326.63 3566.07 4876.81 2.00 -2.00 0.00 180.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 7/17/2001 Time: 16:41:26 Page: 4 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: L-107, True North Site: PB L Pad Yertical (1'¥])) Reference: Temp Plan elevation 77 77.0 Well: L-107 Section CVS) Reference: Well (0.00N,0.00E,133.01Azi) Wellpath: Plan L-107 Plan: L-107 WP06 Section 10: Start ft deg deg ft ft ft ff deg/100ft deg/100ft deg/100ft deg 8900.00 6.68 132.84 6969.18 -3326.80 3566.26 4877.07 2.00 -2.00 0.00 180.00 9000.00 4.68 132.84 7068.68 -3333.53 3573.51 4886.96 2.00 -2.00 0.00 180.00 9047.81 3.72 132.84 7116.36 -3335.90 3576.07 4890.45 2.00 -2.00 0.00 180.00 Survey Map Map <m. Latitude ----> <-- Longitude ~> MD lncl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft deg deg ff ff ff ff ff 77.00 0.00 0.00 77.00 0.00 0.00 5978119.56 583270.56 70 21 0.680 N 149 19 26.178 W 100.00 0.00 0.00 100.00 0.00 0.00 5978119.56 583270.56 70 21 0.680 N 149 19 26.178 W 200.00 0.00 0.00 200.00 0.00 0.00 5978119.56 583270.56 70 21 0.680 N 149 19 26.178 W 300.00 0.00 0.00 300.00 0.00 0.00 5978119.56 583270.56 70 21 0.680 N 149 19 26.178 W 400.00 1.00 165.00 399.99 -0.84 0.23 5978118.72 583270.80 70 21 0.672 N 149 19 26.171 W 500.00 2.00 165.00 499.96 -3.37 0.90 5978116.20 583271.50 70 21 0.647 N 149 19 26.151 W 600.00 3.00 165.00 599.86 -7.58 2.03 5978112.00 583272.68 70 21 0.606 N 149 19 26.118 W 700.00 4.00 165.00 699.68 -13.48 3.61 5978106.12 583274.32 70 21 0.548 N 149 19 26.072 W 800.00 5.30 150.36 799.35 -20.86 6.80 5978098.78 583277.59 70 21 0.475 N 149 19 25.979 W 900.00 6.80 141.80 898.79 -29.53 12.74 5978090.17 583283.63 70 21 0.390 N 149 19 25.805 W 1000.00 8.40 136.40 997.91 -39.48 21.45 5978080.32 583292.44 70 21 0.292 N 149 19 25.551 W 1096.84 10.00 132.84 1093.50 -50.32 32.49 5978069.61 583303.60 70 21 0.185 N 149 19 25.228W 1100.00 10.08 132.84 1096.61 -50.69 32.89 5978069.24 583304.01 70 21 0.182 N 149 19 25.216W 1200.00 12.58 132.84 1194.66 -64.05 47.30 5978056.04 583318.56 70 21 0.050 N 149 19 24.795W 1300.00 15.08 132.84 1291.75 -80.30 64.82 5978039.99 583336.26 70 20 59.890 N 149 19 24.283W 1400.00 17.58 132.84 1387.71 -99.42 85.44 5978021.11 583357.09 70 20 59.702 N 149 19 23.681 W 1500.00 20.08 132.84 1482.35 -121.36 109.10 5977999.43 583380.99 70 20 59.487 N 149 19 22.989W 1600.00 22.58 132.84 1575.49 -146.09 135.77 5977975.00 583407.93 70 20 59.243 N 149 19 22.210W 1700.00 25.08 132.84 1666.96 -173.56 165.39 5977947.87 583437.85 70 20 58.973 N 149 19 21.344W 1800.00 27.58 132.84 1756.58 -203.71 197.91 5977918.08 583470.70 70 20 58.677 N 149 19 20.394W 1816.84 28.00 132.84 1771.48 -209.06 203.67 5977912.80 583476.52 70 20 58.624 N 149 19 20.226W 1900.00 28.00 132.84 1844.91 -235.61 232.30 5977886.57 583505.44 70 20 58.363 N 149 19 19.389W 2000.00 28.00 132.84 1933.20 -267.53 266.72 5977855.04 583540.21 70 20 58.049 N 149 19 18.383W 2019.03 28.00 132.84 1950.00 -273.60 273.27 5977849.04 583546.83 70 20 57.989 N 149 19 18.192W 2100.00 31.24 132.84 2020.38 -300.81 302.61 5977822.16 583576.47 70 20 57.722 N 149 19 17.334W 2200.00 35.24 132.84 2104.00 -338.07 342.79 5977785.35 583617.06 70 20 57.355 N 149 19 16.160W 2300.00 39.24 132.84 2183.60 -379.21 387.16 5977744.71 583661.87 70 20 56.951 N 149 19 14.864W 2400.00 43.24 132.84 2258.78 -424.02 435.48 5977700.44 583710.69 70 20 56.510 N 149 19 13.451 W 2500.00 47.24 132.84 2329.18 -472.29 487.54 5977652.76 583763.27 70 20 56.035 N 149 19 11.930W 2544.03 49.00 132.84 2358.57 -494.56 511.59 5977630.76 583787.57 70 20 55.816 N 149 19 11.228W 2600.00 49.00 132.84 2395.29 -523.28 542.56 5977602.39 583818.85 70 20 55.534 N 149 19 10.323W 2700.00 49.00 132.84 2460.90 -574.60 597.90 5977551.69 583874.76 70 20 55.029 N 149 19 8.705W 2800.00 49.00 132.84 2526.50 -625.92 653.24 5977501.00 583930.66 70 20 54.524 N 149 19 7.088W 2900.00 49.00 132.84 2592.11 -677.23 708.58 5977450.31 583986.56 70 20 54.019 N 149 19 5.471 W 3000.00 49.00 132.84 2657.71 -728.55 763.92 5977399.61 584042.46 70 20 53.515 N 149 19 3.855W 3100.00 49.00 132.84 2723.32 -779.87 819.26 5977348.92 584098.36 70 20 53.010 N 149 19 2.238W 3200.00 49.00 132.84 2788.93 -831.18 874.60 5977298.22 584154,26 70 20 52.505 N 149 19 0.621 W 3300.00 49.00 132.84 2854.53 -882.50 929.94 5977247.53 584210.16 70 20 52.000 N 149 18 59.004W 3400.00 49.00 132.84 2920.14 -933.82 985.28 5977196.84 584266,06 70 20 51.496 N 149 18 57.387W 3500.00 49.00 132.84 2985.74 -985.13 1040.62 5977146.14 584321.96 70 20 50.991 N 149 18 55.770W 3600.00 49.00 132.84 3051.35 -1036.45 1095.96 5977095.45 584377.87 70 20 50.486 N 149 18 54.153W 3700.00 49.00 132.84 3116.95 -1087.77 1151.30 5977044.75 584433.77 70 20 49.981 N 149 18 52.536W 3800.00 49.00 132.84 3182.56 -1139.08 1206.64 5976994.06 584489.67 70 20 49.476 N 149 18 50.920W 3900.00 49.00 132.84 3248.17 -1190.40 1261.98 5976943.37 584545.57 70 20 48.972 N 149 18 49.303W 4000.00 49.00 132.84 3313.77 -1241.72 1317.32 5976892.67 584601.47 70 20 48.467 N 149 18 47.686W 4100.00 49.00 132.84 3379.38 -1293.03 1372.66 5976841.98 584657.37 70 20 47.962 N 149 18 46.069W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 711712001 Time: 16:41:26 Page: $ Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: L-107, True North Site: PB L Pad Vertical (T'vl)) Reference: Temp Plan elevation 77 77.0 Well: L-107 Section O/S) Reference: Well (0.00N,0.00E,133.01Azi) Wellpath: Plan L-107 Plan: L-107 WP06 Survey Map Map MD Incl Azim TVD +N/-S +E/-W Northing Easting ff deg deg ff ff ff ff ff 4200.00 49.00 132.84 3444.98 -1344.35 1428.00 5976791.28 584713.27 4300.00 49.00 132.84 3510.59 -1395.67 1483.33 5976740.59 584769.17 4400.00 49.00 132.84 3576.20 -1446.98 1538.67 5976689.90 584825.08 4500.00 49.00 132.84 3641.80 -1498.30 1594.01 5976639.20 584880.98 <~ Latitude ----> <-- Longitude --> Deg Min Sec Deg Min Sec 70 20 47.457N 149 18 44,453W 70 20 46.952N 149 18 42.836W 70 20 46.448 N 149 18 41.219 W 70 20 45.943 N 149 18 39.603 W 4600.00 49.00 132.84 3707.41 -1549.62 1649.35 5976588.51 584936.88 70 20 45,438 N 149 18 37.986 W 4700.00 49.00 132.84 3773.01 -1600.93 1704.69 5976537.81 584992.78 70 20 44,933 N 149 18 36.369 W 4800.00 49.00 132.84 3838.62 -1652.25 1760.03 5976487.12 585048.68 70 20 44.428 N 149 18 34,753 W 4900.00 49.00 132.84 3904.23 -1703.57 1815.37 5976436.43 585104.58 70 20 43,924 N 149 18 33,136 W 5000.00 49.00 132.84 3969.83 -1754.88 1870.71 5976385.73 585160.48 70 20 43,419 N 149 18 31.520 W 5100.00 49.00 132.84 4035.44 -1806.20 1926.05 5976335.04 585216.38 70 20 42.914 N 149 18 29,903 W 5200.00 49.00 132,84 4101.04 -1857.52 1981.39 5976284.34 585272.28 70 20 42.409 N 149 18 28.287 W 5300.00 49.00 132.84 4166.65 -1908.83 2036.73 5976233.65 585328.19 70 20 41.904 N 149 18 26.670 W 5400.00 49.00 132.84 4232.25 -1960.15 2092.07 5976182.96 585384.09 70 20 41,399 N 149 18 25.054 W 5500.00 49.00 t32.84 4297.86 -2011.47 2147.41 5976132.26 585439.99 70 20 40.895 N 149 18 23,438 W 5600.00 49.00 132.84 4363.47 -2062.78 2202.75 5976081.57 585495.89 70 20 40.390 N 149 18 21.821 W 5700.00 49.00 132.84 4429.07 -2114.10 2258.09 5976030.88 585551.79 70 20 39.885 N 149 18 20.205W 5800.00 49.00 132.84 4494.68 -2165.42 2313.43 5975980.18 585607.69 70 20 39.380 N 149 18 18.588W 5900.00 49.00 132.84 4560,28 -2216.73 2368.77 5975929.49 585663.59 70 20 38.875 N 149 18 16.972W 6000.00 49,00 132.84 4625.89 -2268.05 2424.11 5975878.79 585719.49 70 20 38.370 N 149 18 15.356W 6100.00 49.00 132.84 4691.50 -2319.37 2479.45 5975828.10 585775.40 70 20 37.865 N 149 18 13,740W 6200.00 49.00 132.84 4757.10 -2370.68 2534.78 5975777.41 585831.30 70 20 37,361 N 149 18 12,123W 6300.00 49.00 132.84 4822.71 -2422.00 2590.12 5975726.71 585887.20 70 20 36.856 N 149 18 10,507W 6400.00 49.00 132.84 4888.31 -2473.32 2645,46 5975676.02 585943.10 70 20 36,351 N 149 18 8,891 W 6500.00 49.00 132.84 4953.92 -2524.63 2700.80 5975625.32 585999.00 70 20 35,846 N 149 18 7,275W 6600.00 49.00 132.84 5019.53 -2575.95 2756.14 5975574.63 586054.90 70 20 35.341 N 149 18 5,658W 6700.00 49.00 132.84 5085.13 -2627.27 2811.48 5975523.94 586110.80 70 20 34.836 N 149 18 4.042W 6783.73 49.00 132.84 5140.06 -2670.08 2857.96 5975481.65 586157.75 70 20 34,415 N 149 18 2.685W 6800.00 48.67 132.84 5150.77 -2678.41 2866.94 5975473.42 586166.82 70 20 34.333 N 149 18 2,423W 6900.00 46.67 132.84 5218.10 -2728.68 2921.15 5975423.76 586221.58 70 20 33.838 N 149 18 0,840W 7000.00 44.67 132.84 5287.97 -2777.32 2973.60 5975375.71 586274.57 70 20 33.360 N 149 17 59.308W 7100.00 42.67 132.84 5360.29 -2824.27 3024.24 5975329.33 586325.71 70 20 32.898 N 149 17 57.829W 7200.00 40.67 132.84 5434.98 -2869.48 3072.99 5975284.67 586374.96 70 20 32.453 N 149 17 56.406W 7300.00 38.67 132.84 5511.95 -2912.89 3119.80 5975241.79 586422.25 70 20 32.026 N 149 17 55.039W 7400.00 36.67 132.84 5591.09 -2954.44 3164,61 5975200.74 586467.51 70 20 31.617 N 149 17 53.730W 7500.00 34.67 132.84 5672.32 -2994.09 3207.37 5975161.57 586510.71 70 20 31,227 N 149 17 52,481 W 7600.00 32.67 132.84 5755.54 -3031.79 3248.03 5975124.32 586551.77 70 20 30.856 N 149 17 51,294W 7700.00 30.67 132.84 5840.64 -3067.49 3286.53 5975089.06 586590.67 70 20 30,505 N 149 17 50.170W 7800.00 28.67 132.84 5927.52 -3101.16 3322.83 5975055.80 586627.33 70 20 30,173 N 149 17 49,110W 7900.00 26.67 132.84 6016.07 -3132.73 3356.88 5975024.61 586661.73 70 20 29,863 N 149 17 48.116W 8000.00 24.67 132.84 6106.20 -3162.19 3388.65 5974995.51 586693.82 70 20 29.573 N 149 17 47.188W 8100.00 22.67 132.84 6197.78 -3189.49 3418.09 5974968.54 586723.56 70 20 29.304 N 149 17 46.328W 8200.00 20.67 132.84 6290.70 -3214.61 3445.17 5974943.73 586750.92 70 20 29.057 N 149 17 45.537W 8300.00 18.67 132.84 6384.86 -3237.50 3469.86 5974921.12 586775.86 70 20 28.832 N 149 17 44.817W 8400.00 16.67 132.84 6480.13 -3258.14 3492.12 5974900.72 586798.34 70 20 28.629 N 149 17 44.167W 8457.10 15.53 132.84 6535.00 -3268.87 3503.78 5974890.12 586810.12 70 20 28.523 N 149 17 43.826W 8500.00 14.67 132.84 6576.42 -3276.47 3511.98 5974882.62 586818.40 70 20 28.448 N 149 17 43.587W 8600.00 12.67 132.84 6673.58 -3292.54 3529.31 5974866.74 586835.91 70 20 28.290 N 149 17 43.081 W 8700.00 10.67 132.84 6771.51 -3306.30 3544.14 5974853.15 586850.89 70 20 28.155 N 149 17 42.648W 8800.00 8.67 132.84 6870.08 -3317.72 3556.46 5974841.87 586863.34 70 20 28.042 N 149 17 42.288W 8897.81 6.72 132.84 6967.00 -3326.63 3566.07 5974833.07 586873.04 70 20 27.955 N 149 17 42.007W 8900.00 6.68 132.84 6969.18 -3326.80 3566.26 5974832.89 586873.23 70 20 27.953 N 149 17 42.002W 9000.00 4.68 132.84 7068.68 -3333.53 3573.51 5974826.25 586880.56 70 20 27.887 N 149 17 41.790W 9047.81 3.72 132.84 7116.36 -3335.90 3576.07 5974823.91 586883.15 70 20 27.864 N 149 17 41.715W 64 --'60 -~50 ~40 i30 P-10 --20 --40 -50 ~¥,0 64 From Coloul [o MD 0 -- 300 300 '---- 600 600 '-----' 900 900 - 1200 ~ S00 ,~- .......... 2O00 " 2500 -- 3000 3500 -~---~-- 4500 -' 5500 ~0 9O 20 18( BP Amoco Anticollision Report Company: BP Amoco Date: 7/17/2001 Time: 16:18:41 Page: 1 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: L-107, True North Reference Well: L-107 Vertical (TVD) Reference: Temp Plan elevation 77 77.0 Reference Wellpath: Plan L-107 Db: Oracle ................... - ...... 7'? ...... :~';-'.:-~----?' '--~ ~- ---';;-. ....... ; ........ .~:~-'?-'-~_ '~. ~_,---- ....... ~-_~:- ~: ......... 7-~-'_~-~;~-7-~--_~.-~ . ~ GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100Il000 of reference - There ard~f6tti~mells in thiR~l~al Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Depth Range: 77.00 to 9047.81 ft Maximum Radius: 1097.08 ff Survey Program for Definitive WeilPath Date: 12/26/2000 Validated: No Planned From To Survey ff ft . . 77.00 1100.00 Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing Version: 10 Toolcode Tool Name 1100.00 Planned: L-107 WP06 V1 CB-GYRO-SS Camera based gyro single shots 9047.81 Planned: L-107 WP06 V1 MWD MWD - Standard Casing Points MD TVD Diameter Hole Size Name ft ft in in 2876.97 2577.00 7.625 8.750 7 5/8" 9047.80 7116.35 5.500 6.750 5 1/2" Summary Site Well Wellpath 'MD MD: 'Distance Area DeviatiOn warning PB L Pad L-01 L-01 V12 750.23 750.00 13.38 13.01 0.39 Pass: Major Risk PB L Pad L-02 Plan L-02 V1 Plan: L-0 348.46 350,00 222.61 7,81 214.80 Pass: Major Risk PB L Pad L-102 Plan L-102 V4 Plan: L- 375.03 375.00 150.42 8.09 142.34 Pass: Major Risk PB L Pad L-103 Plan L-103 V1 Plan: L- 574.49 575.00 137.04 11.85 125.19 Pass: Major Risk PB L Pad L-104 Plan L-104 V3 Plan: L- 1288.61 1275.00 112.73 22.57 90.25 Pass: Major Risk PB L Pad L-105 Plan L-105 V5 Plan: L- 1356,54 1350.00 64.91 26.39 38.61 Pass: Major Risk PB L Pad L-106 Plan L-106 V7 Plan: Pi 599.28 600.00 90.98 11.97 79.01 Pass: Major Risk PB L Pad L-108 Plan L-108 V3 Plan: L- 549.59 550.00 60.65 10.56 50.09 Pass: Major Risk PB L Pad L-109 Plan L-109 V3 Plan: L- 674.89 675.00 87.78 12,26 75.52 Pass: Major Risk PB L Pad L-110 Plan L-110 V5 Plan: PI 449.95 450.00 131.30 9.04 122.26 Pass: Major Risk PB L Pad L-111 Plan L-111 V11 Plan: L 699.29 700.00 71.81 13.54 58.27 Pass: Major Risk PB L Pad L-114 Plan L-114 V8 Plan: PI 723.50 725.00 206.29 13.84 192.45 Pass: Major Risk PB L Pad L-115 Plan L-115 V6 Plan: PI 624.45 625.00 161.40 17.06 144.34 Pass: Major Risk PB L Pad L-116 L-116 V7 649.75 650.00 102.21 10.00 92.22 Pass: Major Risk PB L Pad L-117 Plan L-117 V6 Plan: L- 348.46 350.00 206.48 7.93 198.55 Pass: Major Risk PB L Pad L-118 Plan L-118 V6 Plan: L- 348.46 350.00 199.60 7.84 191,76 Pass: Major Risk PB L Pad L-119 Plan L-119 V5 Plan: L- 396.96 400.00 217.15 8.80 208.35 Pass: Major Risk PB L Pad L-120 Plan L-120 V4 Plan: L- 348.49 350.00 234.73 7,67 227.06 Pass: Major Risk Site: PB L Pad Well: L-01 Rule Assigned: Major Risk Wellpath: L-01 V12 lnter-SiteError: 0.00 ft Reference Offset SemirMajor Axis Ctr-Ctr No-Go Allowable ft:: ~ ,:ft" : ':i' ' :=deg=':'i::in:,: , ::ii: :::ft,' : :; 100.30 100.30 100.00 100.00 0.05 0.04 256.96 256.96 9.625 14.98 1.29 13.69 Pass 125.30 125.30 125.00 125.00 0.16 0.07 256.88 256.88 9.625 14.96 1.93 13.03 Pass 150.30 150.30 150.00 150.00 0.26 0.10 256.78 256.78 9.625 14.94 2.57 12.37 Pass 175.30 175.30 175.00 175.00 0.37 0.12 256.64 256.64 9.625 14.91 3.20 11.71 Pass 200.30 200.30 200.00 200.00 0.47 0.14 256.38 256.38 9.625 14.90 3.84 11.06 Pass 225.30 225.30 225.00 225.00 0.52 0.17 255.97 255.97 9.625 14.89 4.32 10.58 Pass 250.30 250.30 250.00 250.00 0.58 0.19 255.42 255.42 9.625 14.90 4.81 10.09 Pass 275.30 275.30 275.00 275.00 0.64 0.22 254.67 254.67 9.625 14.87 5.30 9.57 Pass 300.30 300.30 300.00 300.00 0.69 0.24 253.71 253.71 9.625 14.81 5.79 9.02 Pass 325.30 325.30 325.00 325.00 0.69 0.26 252.75 87.75 9.625 14.72 6.11 8.61 Pass 350.30 375.30 400.31 425.31 450.31 350.30 350.00 349.99 0.69 0.29 251.97 86.97 9.625 14.60 6.45 8.15 Pass 375.30 375.00 374.99 0.69 0.32 251.34 86.34 9.625 14.46 6.79 7.68 Pass 400.30 400.00 399.98 0.69 0.35 250.86 85.86 9.625 14.32 7.12 7.20 Pass 425.30 425.00 424.98 0.72 0.37 250.54 85.54 9.625 14.16 7.52 6.64 Pass 450.30 450.00 449.97 0.74 0.40 250.34 85.34 9.625 14.01 7.92 6.08 Pass H 193323 07/06/01 00193323 VENDOR DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 070201 CEO70201d 100. OO 100. OO PYMT (;OMMENTS: Pe~it to D~ill 1 ee HANDL NQ INST: S/H - Tee~ie Hub le X4628 oe Sondea Step,man X4750 L--/0T 'HE A'rrACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~ [0] ~_~ ~ ] lOO oo 100 oo BP EXPLORATION, (ALASKA)INC. RO. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 No. H 19332 CONSOLIDATED COMMERCIAL ACCOUNT 00193323 PAY ONE::.HUNDRED & 00/100~~~~, US D~LLAR To Th e ORDER 0~ 3'33 7T:H ,.~VENUE SU I TE ANCHORAGE NOT::VALID AFTER DAYS TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~-'- \~"~ CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR D,~L( , ANNULAR DISPOSAL ( ) yES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS ( )YES+ SPACING EXCEPTION "CLUE" The permit is for a new wellbore segment of existing well ,Permit No, ~ APl No. ~. Production should continue to be reported as a function of the original APl number stated above. In accordance with 20 AAC 25.005(0, ali records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PI-I) and API number (50 -70/80) from records, data and logs acquired for wel! (name on permit). Annular disposal has not been requested Annular Disposa! of drilling wastes will not be approved... . , .. Annular Disposal of drilling wastes will not be approved... , , Please note that an disposal of fluids generated... Enclosed is the approved application for permit to drill the above referenced well. The permit is approved' subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conserVation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST FIELD & POOL COMPANY '/~.X WELL NAMEz~-'/o INIT CLASS ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from ddlling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in ddlling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING PROGRAM: exp dev '2~ redrll serv wellbore sag ann. disposal para req GEOL AREA ~' 4:3 UNIT# N 14. Conductor string provided .................... ~ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... ON/OFF SHORE CMT vol adequate to.tie-in long string to surf csg. 18. CMT will cover all known productive horizons. N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N - 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ....... ; ...... ~ ~ ~,,.~,-~ ~t-,,~<:~c~ ~ ~.. ~-~.,c.~ t. ~-~\(~- ' 23. If diverter required, does it meet regulations .......... 24. Drilling .fluid program schematic & equip list adequate ..... ~ ~,~.:~ 25. BOPEs, do they meet regulation .............. ~ . . (~ N ~ ~, ,-, ~'-~ ~ ' DATE 26. BOPE press rating appropriate; test to (/~L.~ I:)sig. '~( 27. Choke manifold complieS w/APl RP-53 (May 84) .' ........ ~ '" ' 28. Work will occur without operation shutdown ........... ~ ..~ ' _ . . ' i . .. 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. P~rmit can be issued wlo hydrogen sulfide measures ...... Y N ,/ ' ' 31. Data presented on potential overpressure zones ....... Y N 32. Seismic analysis of shallow gas zones ........ ..... /Y//N .~,,/',,~/ , AP. PR I~TE 33. Seabed condition survey (if off-shore) ............. ~Y N · ~~./"{~:2/ 34. Contact name/phone for weekly progress reports [exploratorY~O~rly] Y N ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; ' (C) will not ·impair mechanical integrity of the Well used for diSposal; Y' N (D) will not damage producing formation or impair recovery from a Y N.. pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412, Y N G EO L~?~.~Y: ENGINEERING: ' UIC/Annular COMMISSION: ~~=_.,__ I~,V~/ , _ WM ,j~SF.i ~ Comments/Instructions: O Z O c:~nsoffice\wordia n~iana\checklist (rev. 111011100)