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203-128
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, October 15, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC W-209 PRUDHOE BAY UN POL W-209 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/15/2024 W-209 50-029-23170-00-00 203-128-0 G SPT 5068 2031280 1500 2936 2947 2932 2926 132 141 144 145 4YRTST P Austin McLeod 8/12/2024 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN POL W-209 Inspection Date: Tubing OA Packer Depth 23 1712 1658 1644IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM240812202105 BBL Pumped:2.4 BBL Returned:1.5 Tuesday, October 15, 2024 Page 1 of 1 9 9 9 9 99 999 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2024.10.15 12:17:54 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-21 50029215350000 186023 5/8/2023 HALLIBURTON Jewelry Log MPU B-21 50029215350000 186023 5/12/2023 HALLIBURTON Leak Detection Log MPU B-21 50029215350000 186023 5/13/2023 HALLIBURTON Multi Finger Caliper Report MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT PBU 09-24A 50029214280100 223003 4/9/2023 HALLIBURTON RBT-Coilflag PBU C-26A 50029208340100 198145 3/17/2023 HALLIBURTON Production Profile PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile PBU S-32A 50029220990100 212082 5/23/2023 HALLIBURTON CAST CBL PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile PBU W-04 50029219070000 189008 3/8/2023 HALLIBURTON CAST CBL PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile PBU W-219 50029234290000 210105 4/16/2023 HALLIBURTON Inj. Profile PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile SRU 213B-15 50133206540000 215130 4/28/2023 HALLIBURTON Perf Please include current contact information if different from above. T37729 T37729 T37729 T37730 T37731 T37732 T37733 T37734 T37735 T37736 T37737 T37738 T37739 T37740 T37741 T37742T37743 PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.13 13:09:15 -08'00' MEMORANDUM State of Alaska Depth Alaska Oil and Cas Conservation Commission IT aJ In DATE: Monday, August 31, 2020 TO: Jim Regg C� P.I. Supervisor ,��j (l1 (7C SUBJECT: Mechanical Integrity Tests t BP Exploration (Alaska) [Tic. SPT W-209 FROM: Jeff Jones PRUDHOE BAY UN POL W-209 Petroleum Inspector 16 - IBBL Returned: % Src: Inspector OA Reviewed By: 1 - 1- P. 1. Supry J1912— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-209 API Well Number 50-029-23170-00-00 Inspector Name: JeffJones Permit Number: 203-128-0 Inspection Date: 8/14/2020 Insp Num: mitJJ200828144114 Rel Insp Num: Pretest Initial 15 Min 30 Min 45 Min 60 Min 1267 1273 1271 1272 467 2253 2203 2199 -- ; -- 132 I68 - i 170 - 170 Monday, August 31, 2020 Page 1 of 1 Packer Depth Well ' W-209 � IT aJ In W 'T VD 5068 Tubing PTD 2031280 'Type Testli SPT (Test psi' 1500 IA BBL Pumped: 16 - IBBL Returned: % 1-6 OA Interval 1 - 1- -— 4YRTST F P - ---� - Notes: I well inspected, no exceptions noted. Pretest Initial 15 Min 30 Min 45 Min 60 Min 1267 1273 1271 1272 467 2253 2203 2199 -- ; -- 132 I68 - i 170 - 170 Monday, August 31, 2020 Page 1 of 1 nno X0312- 51 Loe• •, Victoria T (DOA) From: Regg,James B (DOA) Sent: Monday,April 30, 2018 1:37 PM To: Loepp,Victoria T(DOA) Subject: FW: Producer 1-01B (PTD#2022010)Similar Construction Geometry to 02-03 Follow Up Flag: Follow up Flag Status: Flagged Jim Regg SCANNED Supervisor, Inspections r f AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged informati.n. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 90 793-1236 or jim.regg@alaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com> Sent: Monday,April 30,2018 1:35 PM To: Regg,James B(DOA)<jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>; Foerster,Catherine P(DOA)<cathy.foerster@alaska.gov>; Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov>; Rixse, Melvin G (DOA)<melvin.rixse@alaska.gov>; Daniel, Ryan <Ryan.Daniel@bp.com>; Cismoski, Doug A<CismosDA@BP.com>; Romo, Louis A<Louis.Romo@bp.com>;AK,GWO ell Integrity Engineer<AKGWOWellSiteEnginee@bp.com> Subject: RE: Producer J-01B (PTD#2022010)Similar Construction Geometry to 02-03 Jim, Per my voicemail,we will reclassify the wells with gravel protection strings Not Operable: • Prod S-122(PTD 2050810) Injector W-209(PTD 203128 • Injector W-214(PTD 2071420) • Injector W-216(PTD 2071680) Our surface casing depth verification project identified 2 other wells with surface casing set in the permafrost(both L.ng Term Shut Ins): • Producer E-28A(PTD 1990610)—will reclassify Not Operable • Injector M-01(PTD 1690780)—already Not Operable due to remaining shut in past its 4-year witnessed test d.to BPXA's Tubular Design Advisor will review all of these wells. Upon completion,we'll present the findings to the AOGCI. In the meantime,all will remain Not Operable and shut in. 1 Thanks, • • Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 From: Regg, James B (DOA) [mailto:jim.reggOalaska.gov] Sent: Friday, April 27, 2018 2:18 PM To: AK, GWO SUPT Well Integrity Cc: Loepp, Victoria T(DOA); Foerster, Catherine P(DOA); Schwartz, Guy L(DOA); Rixse, Melvin G (DOA) Subject: RE: Producer J-01B (PTD #2022010) Similar Construction Geometry to 02-03 Thank you for the follow-up email. Just to be clear,are the S-pad and W-pad wells with gravel protection strings also going to be reclassified as"not operable"to verify they are not at risk for failure like PBU 02-03B? When BP is finished with the reviews of the wells, please arrange for a meeting to present your findings to the AOGCC. That can be coordinated with Victoria. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged informati n. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this a-mai, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 90'- 793-1236 or iim.regg@alaska.gov. From:AK,GWO SUPT Well Integrity<AKDCWelllntegrityCoordinator@bp.com> Sent: Friday,April 27, 2018 1:51 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Cc: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov>;Cismoski, Doug A<CismosDA@BP.com>; Daniel, Ryan <Ryan.Daniel@bp.com>;AK,GWO Well Integrity Engineer<AKGWOWellSiteEnginee@bp.com> Subject: Producer J-01B(PTD#2022010)Similar Construction Geometry to 02-03 Jim, To summarize our phone conversation today: • After the 02-03 incident,we reported to the AOGCC 14 wells with similar construction geometry; i.e.a 3-strin: casing design,and the surface casing shoe set in the permafrost. • Yesterday,we identified one additional well with similar construction geometry:J-01. • We do not believe that J-01 is at risk of an event similar to 02-03, because, unlike 02-03,all three strings of casing are anchored together with cement.We believe this eliminates the potential for differential force load ng at the wellhead. 2 • However,we are goingeclassify J-01 Not Operable,shut it in,ancure it, until we can perform modeling to verify. • We also identified 4 wells on S-Pad and W-Pad that have 13-3/8"gravel protection strings set in the permafro.t, and 2 casing strings within. I'm investigating the details now, but I do not believe these wells present a risk.Th- 13-3/8" is a second conductor,and not coupled to the inner casing strings at the wellhead. In the event the 13 3/8"were to subside, it would not impart a load to the inner casing strings via the wellhead. I will follow up o these wells as soon as possible. Thanks, Adrienne McVey Well Integrity Superintendent—GWO Alaska (Alternate:Jack Lau) 0:(907)659-5102 C:(907)943-0296 H:2376 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,November 01,2016 P.I.Supervisor 1` t i/011 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. W-209 FROM: Chuck Scheve PRUDHOE BAY UN POL W-209 Petroleum Inspector Src: Inspector Reviewed By: P.I.SuprvJIS -- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN POL W-209 API Well Number 50-029-23170-00-00 Inspector Name: Chuck Scheve Permit Number: 203-128-0 Inspection Date: 10/15/2016 Insp Num: mitCS161016154911 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well W-209 'Type Inj WTVD j 5068 - Tubing 1508 - 1511- 1519 1515. PTD 2031280 - Type Test SPT Test psi 1500 - IA 315 2300 2263 - 2254 . Interval 4YRTST P/F P / OA 179 286 280 276. —I Notes: scAtiteP 4') Tuesday,November 01,2016 Page 1 of 1 STATE OF ALASKA ` •ALASKA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well RI Re-enter Susp Well 0 Other:Set Patch Q 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-128 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service RI 6. API Number: 50-029-23170-00-00 7. Property Designation(Lease Number): ADL 0047451 8. Well Name and Number: PLRS W-209 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,POLARIS OIL 11.Present Well Condition Summary: Total Depth: measured 10545 feet Plugs measured feet true vertical 5554 feet Junk 10300 feet JUN n V 2 9 2 o 1 6 measured Effective Depth: measured 10446 feet Packer measured See Attachment feet / (� true vertical 5506 feet Packer true vertical See Attachment feet 1\O0CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"166.4#X-56 29-109 29-109 Surface 1850 13-3/8"68#L-80 29-1879 29-1630 5020 2260 Intermediate 4149 9-5/8"40#L-80 28-4177 28-2696 5750 3090 Production 10506 7"26#L-80 26-10532 26-5547 7240 5410 Liner 13 2-7/8"6.16#L-80 9866-9879 5229-5235 13450 13890 Perforation Depth: Measured depth: 9675-9705 feet feet 9828-9848 feet 9860-9880 feet 9954-10054 feet True vertical depth: 5137-5152 feet feet 5211-5221 feet 5226-5236 feet 5271-5319 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED JAN 2 ? n17, 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: 1006 860 1481 Subsequent to operation: 744 220 1262 14.Attachments:(required per 20 AAC 25.070.25.071,s 25.283) 15.Well Class after work: Daily Report of Well Operations 6r7 Exploratory ❑ Development 0 Service H Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ IL WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-053 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature �� Phone +1 907 564 4424 Date 6/29/16 Form 10-404 Revised 5/2015 V f Z 47 Z/1L, Submit Original Only S4 RBDMS JUN 3 0 2016 • • Packers and SSV's Attachment PLRS W-209 SW Name Type MD TVD Depscription W-209 TBG PACKER 9529.35 5068.44 4-1/2" Baker Premier Packer W-209 TBG PACKER 9731.85 5164.61 3-1/2" Baker Premier TCII Packer W-209 PACKER 9862 5227.36 3-1/2" Baker 45 KB Packer W-209 PACKER 9879 5235.49 3-1/2" Baker 45 KB Packer W-209 TBG PACKER 9898.34 5244.71 4-1/2" Baker S-3 Perm Packer m Q. 000802 ca zorn7rnOM — N OM - 0 0 0 0 S 0 S i N LO 3 M inLn f� M M OD O O M N- Ln N CO O M O LO M C CO Cfl (fl Ln N O N X- N LL') Ln l!') 11) l i i i l II H CA N O O 00 CO N LO I- N N N N N N O l!) 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O -O co p QNN ` W p J Lp � c I- 0o - FO- aa)) coo O 0 E - N c c Z w o z o � � \ L v o Q� v � Q 4.71 N C CDN c4 J0 W W a) ° 0 d m o C) - ° c CD o L. J X02 W � a p °o o � a) -° � cmw > mm@O _ c (n a. _ Q Z j io UJN c c° O a) HO O 0 U (n a Z0 N 0 w O a a L 0 o -- -- -- E '- L N Z Q U) co Z j j W 5 5i I coLU F- E Q2 co- ~ cn O E E° c co O cdXZCC w (q : ~ `- - J (= ate a a -•- ° O � � � rn o � F * 0 o Q a) G wJ ONw � J * � � a) a) T- a. � "If- Ua2X *k O �� OE >> � r J Q Z C° (n LL p ° J CNO O a) c1 a Q ' N fx * > 6 LL > Q c) a• dE p rntE W J a) ° LLI CO>'a � 25 .13 Qm o up2! 2 , 21- gR -- £ 2up > 3p Q Z Q u) O- J J * �� O J Z Z o 7,-.! Z Z HI- - w >, za. - wz ¢ a � '-'-I 3 � � QUzO � J . o (octocn0cn JgozZQZ - p0 0oO W DN * W '. D > H QOM l_ QwQ OOiLOiLOa - O pow _ QO92ow V) N o � aW W � cn22LI]0) D 4t LF- � pp - p2X � ZI� (n (Q � a � � �j < O11 aQ W D2 W � � � p W pFpr � Jpp = pQ22 Wa. 0OQ0JCD 02 OZOZZ0, ON- ZZI- WJ 2 F-WJ _Zp _ZZ_ � Z_ 0- QM D �� p0 12 ‹C u wv . � 051, - RV) gLU0 aCCN (XZ O I- C - coOaNQ2p0Oo ° w c � F- 00a ° ° pwOJ � TOHC� OQ0c0 " J J H2NZ ( C) Zro J0UU * co � pUNCCMCC0QE 0071) 0 p J JDF- } 0UF- N- N D U) JwXX ° a ? 0 iu0 WYa0[ [tdct00 -I W ¢ 0- QOILYJm ii _CI �, w0U) (n 0-- I- (nchww0_ > EtEl (A (nI (nw2In � cn2CDOCQZOocn Q (ni> O g > Z �- (n -JI (npl- F- � I- 3> +*� _ J a. J LL * H I -0 < : I-- * + N 75 > 0 U) � a. � ? (n < : 1 LL « a. co O O O O O 0 O CQ 0 0 0 0 0 0 0 0 N N N N N N CNI N CO CO CACD O O Ch V LO 10 ii in C 7 to • Cl) c � 0 ▪ E L Cl- CD CO c 5 L "- O ft � J o a a m 0 0 C 0 (13 a) a� 0 TD N I)) m a TREE= 4-1/16"CWI y NOTES: INJECTION MANDRELS ARE MMG WELLAAR= 11"FMC ACTUATOR= BAKER W-209 (NOT MMGW) KB.ELEV= 80.4' BF ELEV= 51,9' KOP= 300' — 511' --13-3/8"TAM PORT COLLAR Max Angle= 66°@ 3030' Datum MD= 9555' 1896' 9-5/8"TAM PORT COLLAR 1 Datum TVD= 5000'SSi — 13-3/8"CSG,68#,L-80,D=12.415" —1 1879' 3769' H4-1/2"HES X NP,D=3.813" 9-5/8"CSG,40#,L-80,D=8.75" H 4176' GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 7"MARKER Jr W/RA TAG --1 9465' 5 5174 3122 64 KBG2 DMY BEK 0 11!16/03 Minimum ID = 1.830" @ 9862' -9883' 9508' -14-172"HES X NP,D=3.813" 35 KB BKR PATCH -, �� 9528' 7"X 4-1/2"BKR PREM PKR,D=3.875" 1 4-1/2"TBG,12.6#,L-80 TCI,.0152 bpf,D=3.958" H 9536' 9536' H4-112"X 3-1/2"XO,D=2.930" 3-1/2"MARKER JT WI RA TAG H 9538' 9558' H3-1/2"HES X NP,D=2.813" WATERFLOOD MANDRELS IM [il ST MD ND DEV TYPE VLV LATCH PORT DATE 4 9642 5122 62 MMG DMY RK 0 10/20/03 IV 3 9671 5135 62 MMG RWF-B RK 12 06/04/16 2 9819 5207 61 MMG RWF-B RK 12 06/04/16 1 9847 5220 61 MMG DMY RK 9 01/07/16 _, F. 9731' H 7"X 3-1/2"BKR PREM PKR,ID=2.870" 7"MARKER JT W/RA TAG H 9768• ,-11 9778' —13-1/2"HES X NP,D=2.813" Mr ' 9862'-9883' —135 KB BKR PATCH,D=1.830"(03/03/16) PERFORATION Sl1MIVARY lir . REF LOG: SWS CDR ON 10/14/03 ' 9896' H3-1/2"X 4-1/2"XO,D=2.910" ANGLE AT TOP FEW 62'@ 9675' C. ..),,,,,,---. Note:Refer to Production DB for historical pert data SIZE SEE ZONE INTERVAL Opn/Sgz DATE Z4 C989E 7"X 4-1J2'BKR S 3 PKR D=3.875" 4-1/2" r 5 OBa 9675-9705 O 10!18/03 ` 9902' H4-1/2"X 3-1/2"XO,D=2.910" 4-1/2" r 5 OBc 9828-9848 O 10/18/03 4-1/2" ' 5 9860-9880 0 10/18/03 9913' H3-1/2"HES X NP,D=2.813" 4-1/2" r 5 OBd 9954- 10054 0 11/14/03 I 9924' H 3-1/2"HES X NP,D=2.813" 9924' H3-1/2"RMX PLUG (06/03/16) 3-1/2"TBG,9.2#&9.3#,L-80,,0087 bpf,ID=2.992" — 9943' \ U9943' --13-1/2"WLEG,ID=2.992" H E_MD NOT LOGGED lir 10300' —5'X 1-1/2'STEM w/5'SWS FRNG HEAD PBTD —1 10446• &90'OF PERF GUNS(100'OAL) 111111111111111111111 7"CSG,264,L-80.0383 bpf,D=6.276" --1 10531' 4.4.4.4.4.4.4.4.4.4.1 DATE REV BY COMMENTS DATE REV BY COMMENTS POLARIS LINT 10/20/03 N9ES ORIGINAL COMPLETION 03/15/16 GJB/JMD RLL RMX LOCK&SET PLUG WELL: W-209 11/16/03 MWTLH SWS GUNS FRED&GLV GO 03/15/16 LACJJMD SET 35 KB PATCH(03/03/16) PERMIT No:"2031280 02/17/08 TW/PJC DRAWING CORRECTIONS 06/15/16 JMG/JMD WFR GO&RESET RMX PLUG API No: 50-029-23170-00 12/01/15 DLWJMD WFR GO(11/15/15) SEC 21,T11N,R12E, 1127'FNL&1189'FEL 02/03/16 GJB/TLH WFR&RMX GO(1/7&1/9/16) 02/29/16 JLS/JMD VVFR&RMX GO(02/23-24/16) BP Exploration(Alaska) RECEIVED2-t -LT/ JUN 08 201b WELL LOG TRANSMITTAL#903262144 AOGCC To: Alaska Oil and Gas Conservation Comm. June 9, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED AnchorageAlaska 99501 M K 9 C g , fVl.K.BENDER RE: Leak Detect Log: W-209 Run Date: 4/23/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 W-209 Digital Log Image files 1 CD Rom 50-029-23170-00 Leak Detection Log SCANNED JAN 0 6 2op 1 Color Log 50-029-23170-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS ANC@halliburton.com Date: Signed: MAugtz,..0.40,..,(/) /J ci (row J w i tp cfl _ C7 N Z Q a1 ,„ .r 2, Yr.d >ro3 O4 LA aNg o a a c.1 N oma: 1) L ..L Z ao F- > o ° o ro > a o o 7 Lu _0O = F- Ci ro Y r6 >• a Q Q _, Ua In O CD CO r0 O r0 1A co 0 a) E 'N m ❑ V.. . . r .- L v Y L J '.1 F- RI, > C C C C 7 C > a"' a1 O Y Y to 1a- F- dy 0 t0 ra ro ra - ry 0 0 L C C N t^. 2 i z -) -) ' -) z ''' ro v) I.W. 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Q W H U U _ _ a o p N O LI30 M O O o m ir lD O O O O O O O O C co ao C 1.101 O O O M r ++ L Q 0 r of 10 r M M O t0 0 t-- N N to -6 N N N 0 0 M M 0 N > ry l.:71) N N N N N N N m O O) al 07 O T 0) O E 0000111 N N N N N N N N 1n C 0 0 0 0 0 0 0 0 c 0 N `• O o 0 0 0 0 0 0 fv C U) N 1!) 1A N U) N 1A . a) + Co'IS Com CO 46.'t1 w co rg Lel fe LL= E 3./ - 0 o z 11�� � N V 8 e ` 1 6 ,7 a V' 0 0 r 0 N 0 ri N Z M M M O N ++ f Olcc 2 a Q N W Y 'S a o E Z y -0 0 •W = 1 N V ry A c R3 C tl 8 y L cS d` it a` a r° Co ti of T�� S • •��\I y , THE STATE Alaska Oil and Gas w of T Conservation Commission — �a 1 z__ A s KA 333 West Seventh Avenue -•= - GOVERNOR BILL WALKER, Anchorage, Alaska 99501-3572 *,R ®F • , Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Eric Zoesch1 ` tI lt� Production Engineer b 3 --� BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Polaris Oil Pool, PLRS W-209 Permit to Drill Number: 203-128 Sundry Number: 316-053 Dear Mr. Zoesch: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Asrovided in AS 31.05.080 within, w thin 20 days after written notice of this decision,Y son, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 3 day of February, 2016. RBDMS LL FEB0 4 2016 STATE OF ALASKA 2© 3 — ‘.'2...• �b • ALASKA OIL AND GAS CONSERVATION COMMIDON APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well H- Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tabing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 Alter Casing 0 Other Set Pht h in Straddle Z H 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 203-128 " 3. Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development ❑ 99519-6612 Stratigraphic ❑ Service H" 6. API Number: 50-029-23170-00-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No H PLRS W-209 q F°V E I 9. Property Designation(Lease Number): 10. Field/Pools: *tea JANZ016 ADL 0047451 . PRUDHOE BAY,POLARIS OIL . 11. PRESENT WELL CONDITION SUMMARY 07f /? /A' Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10545 • 5554 - 9924 5257 99P4 10300 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"166.4#X-56 29-109 29-109 Surface 1850 13-3/8"68#L-80 29-1879 29-1630 5020 2260 Intermediate 4149 9-5/8"40#L-80 28-4177 28-2696 5750 3090 Production 10506 7"26#L-80 26-10532 26-5547 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program H BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service H- 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG H • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Zoesch,Eric be deviated from without prior written approval. Email zoeseO@BP.com Printed Name Zoesch,Eric Title Production Engineer Signature i /a4 \____ Phone +1 907 564 4695 Date I /..'_ j/ COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness SundryNumber: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test CJ Location Clearance 0 Other: ! -4., j--,.- W! l Yr f S—� rf----1---r OP 1 J i r-c Iv d ci �1LC I " f Post Initial Injection MIT Req'd? Yes❑ No ❑ - Spacing Exception Required? Yes❑ No l Subsequent Form Required: /U —40 ¢ 01 APPROVED BYTHE Approved by: 647 COMMISSIONER COMMISSION Date: 2 • 3 it ORIGINAL Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate RBDMS LI, Fop n 4 2016.. /z7-/6, • i oN C6 m N- CO C7) CV • m LC) N M C.,) LCA LN LN > F- a 0 H CO NCO .c CO O ' N O. N- - 0 - 0 N ❑ LO Lu � 0 LO 0 > 2 F- W cc 0 ❑ ❑ W Z WW w p W ❑ H H J O W g Y U > cti O O < m co _ J U U W W W t 4 a0v0000 Q Q Q w f1 a N _Z /C 0rnrnrno 00 0 J J J O J C7 W O J ❑ _ E a) Q Q < 2 ❑ ❑ a LLQ d t p) 0w w W 0 a zQ J pzQ o c 2 2 2 O co co cn cn co CO CNI Q ' 0. rj o C 0 L Ln a) O v- ... N Q N- N CO Cf) O I.L ❑CD 60) O O 0) as J Ca Baa, O 2 a! v) = U O u) cc It 2 2 O c i co co co coa O a. a, a 0 0 c ° U o o o ifi H H H H aa) (nU) U) U) 0 t a) a w H O • ,7 0 co co 0 :7 O O .- .- c W -J - • N 0 0 0 Z U- 1 1 Q W i17 10 � O W N W iii .- LC) LC) I- ❑ LL/ JJ ❑ 11 J ❑ W CC Cl :7 W "J 0 W W W W a Q ❑ - J _ F- J J J D a a 0 m ❑ Y D X W -1 -1 .7t 0 W w < < T) a T) co U LL Lc. co Cl cc 1 a E co z 0) o) rna) o O O o • N N N N a N rY W i �j > - Q Q m m O LL co co a. a' • • a 000oo coN O ct N CO CO U w 0 0 0 0 0 N M 3 O f- N m to L() r- co OT O O CO I"- N CO O M O) N- CO CO CO LO O N N In (0 IC) H N O 0) CO CO to I"- N N N N N O t1) 00M V- CO LC) O) r O O C.) ++ Q N O) O) CO CO LO Cr) 0 N N N N N t[) = O7 CL 000 00 J � � co � = y *k0# 4* J *k N V' O *k N _ c0 N = N o M N O v M D)o tor) CZ N C (0 (0 - `nIC) J v o 0 iQz O En c OH w a l U O u. c O Z Z z a w O m m OU) ZdF- F- • Packers and SSV's Attachment PLRS W-209 SW Name Type MD TVD Depscription W-209 TBG PACKER 9529.35 5068.44 4-1/2" Baker Premier Packer W-209 TBG PACKER 9731.85 5164.61 3-1/2" Baker Premier TCII Packer W-209 TBG PACKER 9898.34 5244.71 4-1/2" Baker S-3 Perm Packer • 0 • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: W-209 Well Type: WAG Injection Well API Number: 50-029-23170-00 Well Activity Conventional 4 Classification: Activity Description: Set TBG Patch&Install WFRV's Cost Code/AFE: APBINJEC Field/Reservoir: POLARIS 12 Month Avg IOR, bopd: Job Type: Mech-Patch Estimated Cost, $K: AWGRS Job Scope: PATCH TUBING/LINER Other regulatory • Sundry Form 10-403 requirements? Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Eric Zoesch Contact numbers: (907)564-4695 (406)270-9837 Well Intervention Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 Lead Engineer: Dan Robertson Contact numbers: (907)564-5546 (907)529-5818 Date Created: January 19,2016 Revisions(date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Oil Rate Inj Rate Gas Injection GOR FTP or Injection g Gas Lift Rate Date Choke SettinPressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 1/17/2016 0 0 1,800 Current Status: Operable Shut In Inclination>70°at Depth(ft) N/A Recent H2S (date,ppm) NA 0 ppm Maximum Deviation(Angle and Depth) 66° 3,030' MD Datum depth,ft TVDss 5,000'TVDss Dogleg Severity(Angle and Depth) 7° 2,181' MD Reservoir pressure(date, psig) 10/21/2008 2,464 psi Minimum ID and Depth 2.813" 9,558' MD Reservoir Temp,F 93°F Shut-in Wellhead Pressure 200 psi Known mech. integrity problems(specifics) Hole in tbg below ST#1 &above bottom packer Last downhole operation(date, operation) 1/9/2016 SL attempted WFRV C/O Most recent TD tag(date,depth, toolstring OD) 9/15/2012 10,042' MD 2.74"GR If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Kit Fit-for-Service? YES If No,Why? • Surface Equipment Checklist. Comments,well history, W-209 is a regulated Polaris injector that injects into three distinct zones—OBa, OBc,&OBd.Slickline background information, attempted a WFRV C/O in November 2015 but was only able to dummy off the top zone due to excessive etc: schmoo in the well.A CTCO was performed early January 2016 and slickline followed immediately to finish the valve changeout. During this intervention,slickline was unable to obtain a passing MIT-T with all zones dummied.A follow-up LDL found a leak of approximately 1 bpm at 1800 psi at a depth of 9872' MD. Prior to setting the patch,the current dummy will be pulled and a dummy with a custom down-sized fishing neck will be run to allow for pulling/running through the 1.81"ID of the patch to be installed. EL will then come and set the patch and pressure test against it&the three dummy valves. Slickline will finish the routine WFRV C/O after the patch is installed and tested. • • Well Intervention Details Suspected Well Problem: Tubing leak in OBc Zone Specific Intervention or Well Objectives: 1 Set 1-run WFD patch across leak 2 Install live WFRV design 3 Key risks,critical issues: Mitigation plan: Set well up for MIT-T post-patch to confirm integrity; 1 Leak persists after patch is set establish LLR&perform LDL if MIT-T fails 2 WFRV doesn't fully set Perform SRT's after each valve is installed 3 Zones crossflow/sand comes into tubing Hold appropriate backpressure when zones are open Summary Step# Service Line Activity Pull both the RMX prong w/dummy&the RMX plug body itself,then drift for WFD 3-1/2"Widepak patch. 1 S Set new RMX body,then set dummy with custom NS 1-3/16"fishing neck in RMX body. (Smaller fishing neck allows for smaller running/pulling tools,facilitating valve replacement through the 1.81"patch ID.) 2 F Set 20'WFD 1-Trip 3-1/2"WidePak patch across leak at 9872' MD.To avoid collars, set top element at 9863' MD. 3 F A/EL by performing MIT-T to 1500 psi with Diesel after patch is set. 4 S Perform WFRV C/0&Step Rate Tests 5 F A/SL with Step Rate Tests by pumping Diesel as needed during WFRV C/0 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 See Detailed Procedure tab for specifics on WFRV Changeout. Smaller 1-3/16"fishing neck is to be machined by Northern Solutions. Contact Bob Harris, Carl Diller,or 2 John Milne with questions. Exact size of fishing neck may be adjusted at their discretion but the pulling tool must be able to pass through the 1.81"ID of the WFD patch. 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: MMSCFD: BWPD: 1200 Expected Production Rates: FTP(psi): 1500 Choke setting: PI(bfpd/psi dp) Post job POP instructions: P01 well after SL RDMO post-WFRV C/0 Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed:Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: III ... 4111 _ TREE= 4-1116-CM/ SAFETY NOTES; INJECTION MANDRELS ARE MMG :WELLHEAD= 11-Fkle . (NOT MAGNI) ACRATOR= BAKER W-209 , KB.B_EV= 80.4' BF REV-- 51.9' KOP= 300' 511. H13-3/8"TAM PORT COLLAR 1 Max Angle= 66-,'Z 303(7 Datum AID= 9555' .. m N. i 189V —I 9-5/8"TAM PORT COLLAR Daturn TVD= 5000'SS 13 3r8r csG,158/$.I 80,i)-.=1?415" H 187W t 3769 —1471/2"1—:—ES X NP.D=3.81 r1 II-5/8'CSC.,ACV,t-80,1)-6Th" --1 41 76 -4 i GAS LET MANDRELS ---- ST; NC ND DB/ TYPE VLV LATCH PORT DATE WI 7MARKJT W/RA TAG —I— 5 i 5174 3122 64 KBG2 MY BB( 0 11/16/03 " ER 9465 1 i 9506' , = * I Minimum ID =2.813" @ 9558' 1 I I H4-1/7 NM X MPID3.813 [3-1/2" HES X NIPPLE J ....:1 x:- I 9528' ._[F-x74-1/2"BKR PREM PKR,ID-3815-1 4-1r7 TBG,12 se,L-80 TO,.0152 bpf,,D=3.95r H 9536' : 1 953V j—4-1/2'X 3-1/7 X0,ID=2.93o- 3-1/7 MARKER JT WI RA TAG H 953)3' rig1118' --13-1/2-HEs X NIP,I)-2 813" WATERFLOOD MAICRELS IV — FST M) ND EEV 1 TYPE VLV LATCH PORT DATE 4 9642 5122 62 1.043 DAY PK 0 10(20/03 1111 — 3 9671 5135 62 NAG OW RK 0 11/17/15 2 9819 5207 61 LOAG [MAY RK 0 10/20/03 1 9847 5220 61 19A3 RWF-B RK 9 09/17/12 Ilr'' '16 9924 5257 52 P-15)(JR RMX 18 0917/12 ir MARKER JT VW RA TAG H 9768* —ft 9731' H X 3-1/2"BKR PREM PKR,iD=2 870" 9778' —13-1/2-HES X MP,13=2.813- I FERFORA T1ON SUlif48,RY REF LOG: SWS CCR ON 10/14/03 Illr ANGLE Al TOP FEW- 67(4)9675' IV ND*:Refer to Production OB for historical pert data : ..........,,,............1 9896" I—3-1/7 x 4-117 XO,0=2.910- I SVE SFf ,ZONE NTERVAL °pit/S/4z DATE 4-1/7 P. 5 OBa 9675 9705 0 10/18/03 4-10 ' 5 043c 9628-9848 0 10/18/03 24 OBIT Hr x 4-1/2'BKR 5-3 FKR D,.3./W1 4-10 ' 5 ' 9860-9880 0 10/18433 4-1/7 ' 5 OM 9954-10054 0 11/14/03 I 99W 1-4-1/7 X 3-1/7 XQ D=2.910-- I 9913' 1-13-1/714M X RP,D=2,817 , 1 1 I 9924* 1--L-3- 2-ms X NP.D.2.813' I 1111124* i—RMX LOCK riv/P-15XJR VLV on MIR SUB BELOW LOO((09715/12) 3 yr FU(,,9,21/&9.311,L 80,.oiatsr bpf,L)...1992" 3— 9943' --- _......,_. 1 1043* I 13 im•141.6c,I)-2.000" - I -1 a mo NOT Lams) I Ilk I 10300' F 5 x i-hr sTsvirils'sibs FIRING I-EAD I PEH &90'OF PERE GUNS(100'OAL)= 10446' ' 9 $4.4114•••• ••••• • [r CZG,20#,L-80.0383 bpf,ID.8.278- H 1063i. 1 °•.•41•41.44.4.614. DATE REV BY COMMENTS MIT RN BY COMENTS POtARLS UHT 10/20/03 M9 ORIGINAL COMPLETION 09118/12 PJC WFR CORFECTIONS WR L: W-209 11/16/03 0.4-111_11 SAG GUNS FRED 8 GLV ao 11/10/12 PJC WFR CORRECTIONS(9/17/12) FERMI-No:2031280 _ 02/17/08 TWPJC DRAWNG CORRECTIONS 12/01/15 C1I-1.11.°WFR 00(11/15/15) AFINa. 50029-23170-00 12/13/09 IW/SV WNEREL TY PE CORRECTION SEC 21,T11N R12E 1127 FM-&1189'Fa 03/20/10 CJWSV WFR C/O(03/18/10) _ 04/30/12 LiK) SET MIX LOCK(04/25/12) BP Exploration(Alaska) • • I . imEgiii 1 1 •■M I�_MM. f ; MI ..�MIMMM. I t k MI .rte MM_M! = rt.=�1��M ' r MilIM MM_M. I PUP ll 1111111 111Mil P K Ri i NM .,,__MMM. imm .ri__MMM. r■MIIMI I=iii ni_MMM! PUP ; _.._M__M. f MI M MI•EIMMIE IIIiiIIIIIuP �1 -r M MIME M_MM. ' _ . IMI . 7 =_7E 1 . I 1!1i111 PUP•E■i� X N i p IL I 1111 PUP _ `r---s IM ■■MJMMMMi L MI rim=����M C MI MOM M_MM! ' M IS rag!M__M. _ . t L -- ----s iii_ - _.■ronM_MM. PUP MINIM_MM_! .. M ■■s___MM. , M MEM_MM . MI Mr1.41111MMMIIIIMINIIINL M MILIIM MMMM. ' I t MI .Ma MMMM. M .■.....�... PUP ,, e II= .P:.MIMIIMIIIM■C- ^a -.-_,..%�RI.__MMI IM hi ;MN .��MMM` — r irm * l=M��____r .. � ME MIM+_MM_! PUP ��� IIIM .f 1 ��MM_E ___.._�---.IN HO EIMIENF t M■■MIMMMM. ► NM MEM w.MMM.mi NIPM1111MIIMIIMMIIIPUP ; MS M►2.M M77r -----rs M . ■:■M_MM■r■ GLM �` M MOWNM_Mc` - MN ■. M_MM. 11111111P- �. NM - EMI:____E PUP - �} M .._�___! p L i --Lam_____ f. .� .■MraMMMs .. ; MI11•.�a_MM! .. .■r-M_MM. ' - - ....•■i1 M_MM! -. k .■�����. PUP K •. — •■M►RIMMM! '• } Mill .■MMI__M■ NM ■■IE�I•_�! '11..N. • .IMP;IIIMIMM_la - 20'Patch,top element @ 9863'MD I. ism =mini immummumNM : MI M . P U P: __ M _ MAIM_MMM! MI MEM MMIMIIMnr in Elm MMMMta. _ r t M ■.■M_MMMT - - WFRV CHANGEOUT Pull dummy & set live valve with port size 18 (445 bwpd) in RMX body at 9924' MD. 1 Note the size of the fishing neck on the dummy valve is NOT standard. Ensure the live valve is also run with the smaller fishing neck provided by Northern Solutions in order to pass through the WFD patch. Perform a step rate test at 1200, 1400, 1600, and 600 psi. 2 * Record injection rate and pressure at 5 and 10 minutes for each pressure cycle. * Expected injection rate w/ Diesel is 0.34 bpm +/- 20%. Test fails if it is outside this range; please re-run WFRV and re-test. 3 Once a passing test is obtained in previous step, pull dummy in ST#2 &set live RWF-B valve with orifice size 0.187"/4.75 mm (378 bwpd). Perform a step rate test at 1200, 1400, 1600, and 1800 psi. 4 * Record injection rate and pressure at 5 and 10 minutes for each pressure cycle. * Expected injection rate w/ Diesel is 0.63 bpm +/-20%. Test fails if it is outside this range; please re-run WFRV and re-test. 5 Once a passing test is obtained in previous step, pull dummy in ST#3 &set live RWF-B valve with orifice size 0.187"/4.75 mm (378 bwpd). Perform a step rate test at 1200, 1400, 1600, and 1800 psi. 6 * Record injection rate and pressure at 5 and 10 minutes for each pressure cycle. * Expected injection rate w/ Diesel is 0.93 bpm +/- 20%. Test fails if it is outside this range; please re-run WFRV and re-test. 7 Once a passing final SRT is obtained, RDMO ) ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable ~ direct inspection of the file. Q¿O;;? - J~ 3 Well History File Identifier Page Count from Scanned File: g I (Count does include cover sheet) Page Count Matches Number in Scanning P¡reparation: V YES ~ Date: I J:J-1 ob If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided 1111111111111111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. ¿;L o Other, NolType: o Poor Quality Originals: o Other: NOTES: t I I Date: 1 :¡.I-A Ole> BY: (Ma~ Project Proofing BY: CMaria J I Date: ;)1 Dc::' ~ X 30 = /oD Date: 118-770 t, Scanning Preparation BY: ç..Maria )_ Production Scanning Stage 1 BY: Stage 1 BY: Date: Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: ~ 1111111111111111111 151 151 m¿) + d-.O = TOTAL PAGES ~ () (Count does not include cover sheet) 1M. P 151 r 'f 1111111111111111111 151 NO of NO 151 111111111111111111 111111111111111111I 151 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc 1 tic Schlumberger NO. 5436 fp s✓ TJluNED `' C' t' 2 20H Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD i MPC -04 AXED -00061 MEMORY =GLS 11117/09 1 1 NK -38A AWJI -00057 MEM PROD PROFILE (r - 11/04/09 1 1 14 -12 83SQ -00033 PRODUCTION PROFILE 11/13/09 1 1 13 -35 B14B -00084 INJECTION PROFILE V 11/10/09 1 1 06 -08A B14B -00082 PLUGBACK SET WIN-FLOW CHECK — 11/08/09 1 1 H -30 AVII H -00031 PRODUCTION PROFILE 11/14/09 1 1 18 -11 A B2NJ -00038 MEM CNL & SCMT G 111/06/09 1 1 1 Y -23B AYKP -00055 GLS — G g 11/22/09 1 1 N -24 AYS4 -00109 PRODUCTION PROFILE — 11/08/09 1 1 02 -31A AYKP -00053 PRODUCTION PROFILE 11/15/09 1 1 03 -01 BBK5 -00014 PRODUCTION PROFILE 11/24/09 1 1 L -213 8581 -00017 1NJ PROFILE W/WFL 11/19/09 1 1 W -209 AYKP -00054 INJ PROFILE W/WFL - 11/17/09 1 1 X -05 AP30 -00072 PRODUCTION PROFILE - 11/29/09 1 1 X -07 AYS4 -00111 PRODUCTION PROFILE Ito -nn 11/27/09 1 1 s PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 OPERABLE: W-209 (PTD #2031280) To place on injection and obtain AOGCC MITIA for com... Page 1 ~' ~ ~ k- Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ~l(ZY3~zek.~ Sent: Saturday, November 01, 2008 9:18 PM ~~7`~_ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Townsend, S. Eliot; Makarov, Egor; NSU, ADW Well Integrity Engineer Subject: OPERABLE: W-209 (PTD #2031280) To place on injection and obtain AOGCC MITIA for compliance Hi all, Wel! W-209 {PTD #2031280) passed an AOGCC witnessed MITIA for UIC compliance on 10131/08. The well has been reclassified as Operable. Please le# us know if you have any questions. Thank you, Anna ~Du6e, ~? ~ Well Integrity Coordinator GPB Wells Group Phone: {907} 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Thursday, October 23, 2008 7:42 PM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; GPB, GC2 Wellpad Lead; GPB, GC2 OTL; GPB, Area Mgr West (GC2/WRD); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, Prod Controllers; GPB, Optimization Engr Cc: Holt, Ryan P (ASRC); NSU, ADW Well Integrity Engineer; Makarov, Egor Subject: UNDER EVALUATION: W-209 (PTD #2031280) To place on injection and obtain AOGCC MITIA for compliance Hi all, Well W-209 (PTD #2031280) has been reclassified as Under Evaluation so that it may be placed on injection and an AOGCC witnessed MITIA can be obtained for UIC compliance. Please place the well on injection watching for an increase in IA pressure as the well reaches temperature. Well Integrity will schedule an AOGCC witnessed MITIA once the well has stabilized. The plan forward for the well is as follows: 1. Operations: Place well on injection 2. Fullbore: AOGCC MITIA Please call with any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group phone: (907) 659-5102 Lager: (907} 659-5100 x1154 11/28/2008 MEMORANDUM To: Jim Regg ~~~ ~ Il~ ~ ~ u~ P.I. Supervisor I+xoN1: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, November O5, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC W-209 PRUDHOE BAY UN POL W-209 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~ Comm Well Name: PRUDHOE BAY UN POL W-209 Insp Num: mitCS08ll021 t 141 I Rel Insp Num: API Well Number: 50-029-23170-00-00 Permit Number: 203-128-0 ~ Inspector Name• Chuck Scheve Inspection Date: 10/3 i/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v'-209 p T zosliso Type Inj. TypeTest W SPT TVD Test psi 5068 Isoo % IA OA 1510 zto - - 2490 ~~ 2460 2460 zso ~ zso 2so - Interval INITAL P/F P ''~ Tubing Iaoo Iaoo ~ ----- - Iaoo I I4oo Notes: _ _ Wednesday, November O5, 2008 Page I of 1 • MICROFILMED 03/01/2008 DO NOT PLACE ~~~ .~ ~~ ~y,. tom.. ~ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm Marker.doc Scblumllergep % ,'2 - \ d ....... c., rl 0 ,"") \ ).... ./ 06/21/06 NO. 3862 Schlumberger-DCS 2525 Gambell SI, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Well Job# Log Description Date BL Color CD S-111 11216189 MEMORY INJECTION PROFILE 04/15/06 1 S-114A 10572082 RST UPFLOW WFL 03101/03 1 V-105 10663005 INJECTION PROFILE 03112/04 1 E-103 10560276 TEMPERATURE WARM BACK 06/22/03 1 V-214 11162720 UBI 11/24/05 1 V-213 11076450 INJECTION PROFILE 07/01/05 1 V-216 11076451 INJECTION PROFILE 07102/05 1 V-221 11058523 INJECTION PROFILE 07103/05 1 L-103 NlA INJECTION PROFILE 07118/09 1 W-209 11078461 INJECTION PROFILE 08/20105 1 W-207 10980589 INJECTION PROFILE 07/20/05 1 W-212 N/A INJECTION PROFILE 07119105 1 e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: c.Li Schlumberger-DCS 2525 Gambeil SI. Suite 400 Anchorage, AK 99503-2838 A TTN: Beth BP Expioration (Alaska) inc. Petrotechnicai Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Received by: e RECEIVED JUN 23 2006 .~ Cil & Gæ Cons. Ccmmissicn .A.ncho!'2ge Id- Permit to Drill 2031280 ~ MD 10545 --- -~--------- ---~---- REQUIRED INFORMATION -----~----- ---- ---------- ~ W ~ i4 o Asc o Asc ~ W"C Lis ~ ~ : Log DATA SUBMITTAL COMPLIANCE REPORT 12/13/2005 Well Name/No. PRUDHOE BAY UN POL W-209 Operator BP EXPLORATION (ALASKA) INC TVD 5554 ;' Completion Status Completion Date 10/20/2003 ",-- Mud Log No Samples No Name Pressure Log Log Scale Media 15 Blu Run No Directional Survey Directional Survey Directional Survey Directional Survey See Notes 5 Col 13387 Gamma Ray 13387 Gamma Ray 13387 Gamma Ray Induction/Resistivity ~/ð 5 Blu compo 5 Blu compo 25 Blu 1-9 I ~g ~ '- ----- ----------- I nd uction/Resistivity rV1) 25 Blu 1-9 I nd uctio n/Res istivity 25 Blu 1-9 ý,~ 1WINJ Current Status 1WINJ 5pul ~) ~~ API No. 50-029-23170-00-00 ~(UIC v) Directional sur£ ve~ ) (data taken from Logs Portion of Master Well Data Maint Received Comments 10/17/2005 Static Bottom Hole Pressure Survey (Press- Temp-CCL-GR) 14 Aug 2005 10/27/2003 PB1 10/27/2003 Schlumberger & Anadrill reports - PB1 10/27/2003 Schlumberger & Anadrill reports 10/27/2003 Schfumberger & Anadrill reports ULTRASONIC IMAGING TOOL, USIT/AMS/GRlCCL TVD/MD Gamma Ray MD PowerPulse Gamma Ray TVD PowerPulse Gamma Ray VISION Service MD Composite GR Rap RES RHOB DENS PORO FINAL PRINT 09-12-03 11/29/2005 VISION Service TVD Composite GR Rap RES RHOB DENS paRa FINAL PRINT 09-12-03 11/29/2005 COR-Resistivity TVD Composite FINAL PRINT 09-23-03 Interval Start Stop o 10230 OH/ CH Case DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number ~--- o 0 o 0 o 1 0545 o 10545 6800 10420 Case 5/3/2004 103 42660 Case 11/29/2005 108 4270 Case 11/29/2005 108 4270 Case 11/29/2005 108 10505 11/29/2005 108 10505 108 10505 .~ -' DATA SUBMITTAL COMPLIANCE REPORT 12/13/2005 Permit to Drill 2031280 Well Name/No. PRUDHOE BAY UN POL W-209 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23170-00-00 MD 10545 TVD F. -.--- --------~~ {. Log 5554 Completion Date I nd uction/Resistivity :¿ ~g x: Neutron Neutron C Lis 13388 See Notes ~------------ Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ,.. Y / N Analysis Received? .::I-I-H- ---_._~--- -- ---------- ---------- Comments: --- -------- -._-- ----------~-- Compliance Reviewed By: 1 0/20/2003 f"D /VI 0 "tv h Interval Start Stop Completion Status 1WINJ 25 Blu 1-9 108 Current Status 1WINJ UIC Y 10505 11/29/2005 COR-Resistivity MD Composite FINAL PRINT 09-23-03 11/29/2005 VISION Density Neutron TVD Composite FINAL PRINT 09-23-03 11/29/2005 VISION Density Neutron MD Composite FINAL PRINT 09-23-03 11/29/2005 GRlRES/DENSITY 10-14- 03 + PDS Graphics 25 Blu 1-9 108 1 0505 25 Blu 1-9 108 10505 1-9 103 1 0545 ---' Sent Received Sample Set Number Comments Daily History Received? ~N ~N ( -rOof' ""- 0<0"" @ Q.I, c.-....1 ~"""t tt : 11 .~ Ò p {fr\. t::J#~ ~~ r ..g, ~ tI' V J.~ cf\,/~kJ, Ià b-t.c.- t \ lD ()... 't ~ t1\\lS"~\ \0 h 6. ,G \,t ~ "- \) c.l() I p~ J l.... ~~\è ~ (\ t" t: Vf.j. À})o.,- Jj) ( l ~ ~ D ~~ . (r ~..; "t.. ~ ( (" V\. " \J l þJ'" E ¡M.-~r1-1.¿ (1..~cL¡ F-~V"~-4. v Þ ~ ~,\i,,\ ~ (~Vy~Q- ~ Formation Tops -'" Date: I) 1'. t--Æ. t'}.AJ r Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838" ATTN: Beth "'.:~.>' Well W-209 ';':C3 i :) Hì (;)j3 - / Q 8' ::~~: W-209 W-209 W-209 W-209 W-209 W-209PB1 W-209PB1 W-209PB1 ;.:~< £.::~ L _~ E 1 '\/ t: L) Job# Log Description 10687651 USIT (PDC) 40009639 OH LDWG EDIT OF MWD/LWD 40009639 MD CDR RESISTIVITY 40009639 TVD CDR RESISTIVITY 40009639 MD VISION DENINEUTRON 40009639 TVD VISION DEN/NEUTRON 40009639 MD VISION SERVICE 40009639 TVD VISION SERVICE 40009639 OH LDWG EDIT OF MWD/LWD 40009639 MD POWERPULSE GR 40009639 TVD POWERPULSE GR 10/18/03 10/14/03 10/14/03 10/14/03 10/14/03 10/14/03 10/14/03 10/14/03 09/28/03 09/28/03 09/28/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd. Anchorage AK 99508-4254 Date Delivered: 11/{)C)!05 11/28/05 NO. 3608 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Date Color CD BL Schlumberger-DCS 2525 Gambell St. Suile 400 Anchorage. AK 99503-2838 ATTN: Belhr.~' ! r.. ~r_: I." '. : -. '- '- J R,eo'"," é'l'0' ~ ~ é In Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job# Log Description W-205L 1 40009936 OH LDWG EDIT OF LWD ADN & IMP W-205L 1 40009936 MD VISION SERVICE W-205L 1 40009936 TVD VISION SERVICE W-205L 1 PB1 40009936 OH LDWG EDIT OF LWD ADN & IMP W-205L1PB1 40009936 MD VISION SERVICE W-205L 1 PB1 40009936 TVD VISION SERVICE W-205L2 40009937 OH LDWG EDIT OF LWD ADN & IMP W-205L2 40009937 MD VISION SERVICE W-205L2 40009937 TVD VISION SERVICE W-209 10980560 SSHP SURVEY 12/14/03 12/14/03 12/14/03 12/14/03 12/14/03 12/14/03 12/21/03 12/21/03 12/21/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center lR2-1 900 E Benson Blvd. Anchorage AK 99506-4254 Date Delivered: /7 0 Jt-- ~ ,-- 10/13/05 NO. 3498 Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Polaris Date Color CD Bl ,-,. 8/14/05 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, A~995 2838 I ATTN: Beth ' 0 ' . . , Received by: 'AJ ^""-- .---- '2 t \ '\ - :l .9 F...(~ · ) STATE OF ALASKA ALASKÞ! .:.. AND GAS CONSERVATION COMI\~ )ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ iii WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4153' NSL, 1189' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 3765' NSL, 1215' EWL, SEC. 23, T11N, R12E, UM Total Depth: 3775' NSL, 1994' EWL, SEC. 23, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 612049 y- 5959130 Zone- ASP4 TPI: x- 619738 y- 5958861 Zone- ASP4 Total Depth: x- 620517 y- 5958884 Zone- ASP4 18. Directional Survey III Yes 0 No 21. Logs Run: MWD, GR, RES, DEN, NEU, PWD, USIT One Other 5. Date Comp., Susp., or Aband. 10/20/2003 6. Date Spudded 9/23/2003 7. Date T.D. Reached 10/14/2003 8. Elevation in feet (indicate KB, OF, etc.) KBE = 80.4' 9. Plug Back Depth (MD+ TVD) 10446 + 5506 Ft 10. Total Depth (MD+TVD) 10545 + 5554 Ft 11. Depth where SSSV set (Nipple) 3769' MD 19. Water depth, if offshore N/A MSL 1b. Well Class: o Development 0 Exploratory o Stratigraphic III Service 12. Permit Number 203-128 303-304 13. API Number 50- 029-23170-00-00 14. Well Number PBU W-209i 15. Field and Pool Prudhoe Bay Field / Polaris Pool 16. Lease Designation and Serial No. ADL 047451 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 22. CASING II SIZ~:. I' 20" x 34" 13-3/8" 9-5/8" 7" II,':, "1',:.:1.', '1.1" ,,,:'..,1'::"'1<',1"1:;,,, ',, " GRAiDE.. I;,:.,: .'. A53 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD I.,. $1;.Tl:ING.:Ðs. Þtr8. I '·1,.14ci~E.' 1'::".';:'.1. 'I "'".''' ",' ""II~"'CIII'::II':,"11 ':,(IOR,,',":', '·'··Ho1TrrOI'lll.',lii " ,,:··.'It"I~H'!(' Surface 108' 48" 260 sx Arctic Set (Approx.) 28' 1879' 16" 460 sx Class 'G', 163 sx Class 'G' 27' 4176' 12-114" 543 sx AS Lite, 288 sx Class 'G' 25' 10531' 8-3/4" 365 sx Class 'G' ':"'~""':,' < ,I :<\ ',', :': ;i',,:,:, ~':': :,: ,I' ::,',.:I,'¡,' ,:;( 1 VV'r;:' PE~,,pr.).. 1,1 215.5# 68# 40# 26# 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5 spf 4-1/2" Gun Diameter, 5 spf MD TVD MD TVD 9675' - 9705' 5137' - 5152' 9954' - 10054' 5271' - 5319' 9828' - 9848' 5211' - 5221' 9860' - 9880' 5226' - 5236' 26. Date First Production: '!.i\~:~~~TI:~¿'~~~611'..,i:'·.·'·.!· II,... .1: SIZE DEPTH SET (MD) 4-1/2", 12.6#, L-80 9536' 3-1/2",9.3#, L-80 ,9536' - 9943 . , , ", ':1:>::,"" ':,:,,' ':,' ,;:":,;":,,,, ,,: .':",,:1",:': ",;1, <"",,"'" ,~.,:.:, '!,':' : '.:,'1':":"": "',,'1 'I:: . ,; ., ,::"" , ?5. .,.., .... ..\I!~ ,:I.·...·......·...·.~8Igr~MgmY~~,.~.~~~~.~.'~P9~!¥~~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 105 Bbls of Diesel November 18, 2003 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection Oll-Bsl GAs-McF PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oll-Bsl Press. 24-HoUR RATE 27. Brief description of lithology, porosity, fractures, apparent~~;: ~~T~resence of oil, gas or water (attaßt;~J;l~{l~lc~ssary). Sub~ft~co~echips;if none, state "none". DEC - 2 2003 None '~j2IJ¡'3 __BFl DEe 9 JlO~ Alaska Oil & Gas Cons. Cotm1Îmon -1!é..- _. Anchorage coQE tGl1~L- Form 10-407 Revised 2/2003 W A TER-Bsl GAs-McF W A TER-Bsl ~(~ PACKER SET (MD) 9528' 9731' & 9897' CHOKE SIZE GAS-Oil RATIO Oil GRAVITY-API (CORR) G 28. r ) GEOLOGIC MARKERS NAME MD TVD Ugnu 6033' 3491' Ugnu M Sandstones 8682' 4669' Schrader Bluff N Sandstones 9185' 4906' Schrader Bluff 0 Sandstones 9541' 5074' OBa 9658' 5129' OBb 9718' 5158' OBc 9825' 5210' OBd 9950' 5269' OBe 10105' 5344' OBf 10210' 5394' Base Schrader I Top Colville 10332' 5452' ÀMA TION TESTS Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted. state "None". 29. None RECE\VEO DEe ' 2, 1.003 Comm\SS\on 0'\ & Gas Cons. A\as~a' Anchorage 30. List of Attachments: Summary of Daily Drilling Reports and Post Rig Work, Surveys Title 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble /fOJ1/\.Ì.t. ~ 203-128 303-304 Date 1~/OPt/oL~ Technical Assistant Permit No.1 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. PBU W-209i Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Jim Smith, 564-5773 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 Legal Name: Common Name: Test Date 10/11/2003 LOT W-209i W-209i Test Type Test Depth (TMD) 4,188.0 (ft) Test Depth (TVD) 2,696.0 (ft) AMW 8.90 (ppg) Surface Pressure Leak Off Pressure (BHP) 597 (psi) 1,843 (psi) EMW 13.16 (ppg) '- <- Printed: 10/27/2003 11 :35:29 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 D$$criþtion of Opßråtions' 9/23/2003 05:00 - 07:00 Dat$ '. Fr()m~To Hòurs Task Gode 'NPT Phase 07:00 - 09:00 09:00 - 15:00 15:00 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 19:30 19:30 - 23:00 23:00 - 23:30 23:30 - 00:00 9/24/2003 00:00 - 02:00 02:00 - 02:30 02:30 - 16:30 16:30 - 17:30 17:30 - 20:30 2.00 MOB P PRE 2.00 MOB P PRE 6.00 OIVRTR P SURF 2.00 DIVRTR P SURF 1.00 DIVRTR P SURF 1.00 DRILL P SURF 0.50 DRILL P SURF 3.50 DRILL P SURF 0.50 DRILL P SURF 0.50 DRILL P SURF 2.00 DRILL N 0.50 DRILL P RREP SURF SURF 14.00 DRILL P SURF 1.00 DRILL P SURF 3.00 DRILL P SURF Held PJSM, Load and move work shop. Move Rig Camp. Load and move pit module away from rig. Move rig from W-215i & into position over well W-209i. Spot pit module & Rig Camp. Accept rig @ 09:00 Hrs 9-23-2003. N/U 21-1/4" 2M Diverter on pre-installed 20" Conductor. Install diverter line & related equipment. Start taking on drill water & mix spud mud in pits. Load pipe shed with Schlumberger drilling tools. Strap & caliper same. P/U Jars & two jts of 5" HWDP. Hit ice @ 65' RKB. Function test 21-1/4" Diverter system (18 seconds to close element) ** Chuck Scheve with the AOGCC wavied witnessing the 21-1/4" Diverter test **. After function testing filled up Oiverter with water & check for leaks-OK. M/U 12-1/4" Drilling assembly. Orient MWO/Mud-motor. Perform surface test on same. Held Pre-Spud meeting with Rig Crew & service company personnel associated with drilling operations. Spud well @ 19:30 hrs. Start drilling ice F/ 65'. Clean out 20" conductor pipe to 108". OriIl12-1/4" hole from 108' to 349'. WOB = 5K RPM = 50 + Mud-motor (Motor factor = 0.2216 rpm/gal) GPM = 670 w/ 1100 psi Torque off Btm = 1100 FtLb. Torque on Btm = 2500 FtLb P/U 53K S/O 53K ROT 53K AST = 0.6 hrs ART = 0.95 hrs Total Drilling Time = 1.55 hrs Circulate hole clean from 349' with 650 gpm. Lots of gravel coming over shale shakers. NOTE: Drag chain on cutting chute broke while circulating. POOH to 20" casing shoe @ 108'. Note: The original plan was to POOH at this depth & P/U drilling jars. Repair drag chain & sprocket on cutting dump chute. TIH to 256'. Establish circulation. Wash to bottom @ 349'. Note: P/U drilling jars on trip back to bottom. Drill 12-1/4" directional hole from 349' to 1651'. Slide as required to build angle & maintain azimuth. WOB = 15-35K RPM = 50 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 3200 FtLb Torque on Btm = 7500 FtLb GPM = 670 @ 2400 psi w/ 120 psi Diff. P/U 79K S/O 63K ROT 69K AST = 6.61 hrs ART = 3.01 hrs Total Drilling Time = 9.62 hrs Circulate to clean hole prior to bit trip. Circulated 3 x bottoms-up @ 670 gpm. Reciprocate & rotate drill string while circulating. POOH for bit change. Encountered tight hole @ 1300'. Pull & work drill string up to 1215', Attempt to work past tight spot @ 1215' with no success. M/U TDS & establish circulation. Backream from 1215' to 1150'. Pump & pull from 1150' to 300' with tight spots @ 1082',910',820',620' & 400'. Appeared to be dragging something up the hole. POOH from 300' with no Printed: 10/27/2003 11 :35:38 AM ) SF> Op~"ätiøn$ßdmmaryRepórf P~~~2of '1a Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES [)at~ Frohl- To · Hours' · Täsk Codè NPT 9/24/2003 17:30 - 20:30 3.00 DRILL P 20:30 - 21 :30 1.00 DRILL P 21 :30 - 22:30 1.00 DRILL P 22:30 - 23:00 0.50 DRILL P 23:00 - 00:00 1.00 DRILL P 9/25/2003 00:00 - 01 :00 1.00 DRILL P Ph$se SURF SURF SURF SURF SURF SURF 01 :00 - 02:00 1.00 DRILL P SURF 02:00 - 08:00 6.00 DRILL P SURF 08:00 - 09:30 1.50 DRILL P SURF 09:30 - 23:00 13.50 DRILL P SURF 23:00 - 00:00 1.00 DRILL P SURF 9/26/2003 00:00 - 02:00 2.00 DRILL P SURF Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 other hole problems encountered. Break off bit. M/U new Hughes MXC1. Adjust mud-motor to 1.5 deg bend. TIH to 65'. Clean rig floor & service TOS. Note: Replace cuttings shute drag chain with a new one while servicing TOS. TIH with 12-1/4" drilling assembly. Tag up on obstruction @ 535'. Attempt to work past same with no success. Establish circulation. Orient mud-motor to High Side. Stop pumps. Work bit past obstruction @ 535'. Continue TIH. Tag up on obstruction @ 1184'. Tag up on obstruction @ 1184' while TIH. M/U TDS into 4" DP. Establish circulation. Orient mud-motor to High Side. Stop pumps & attempt to work bit past 1184' with no success. Intermittently throttle up mud pumps to 540 gpm & apply 50 RPM to drill string. Work bit past obstruction @ 1184' & work bit down hole to 1296'. Continue TIH from 1296' to bottom @ 1651' with no other problems. Once on bottom, establish circulation. Reciprocate & rotate drill string while circulating to clean hole. Hole unloading an excessive amount of cuttings. Initial circulating rate = 452 gpm w/ 1275 psi & 80 RPM. Gradually increase circulating rate to 670 gpm once hole cleaned up. Drill 12-1 /4" directional hole from 1651' to 2170' MD. Slide as required to build angle & maintain azimuth. WOB = 30-35K RPM = 80 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 3000 FtLb Torque on Btm = 8000 FtLb GPM = 670 @ 2830 psi w/ 120 psi Diff. P/U 85K S/O 56K ROT 69K Circulate & condition mud @ 2170'. Reciprocate & rotate drill string while circulating. Add 200 bbl of fresh mud to system. Drill 12-1/4" directional hole from 2170' to 4267'MD /2690' TVD (4267' MD is TO for this hole section). Slide as required to build angle & maintain azimuth. Increase mud wt to 9.7+ while drilling @ 4100' due to excess gravel unloading from well. Also have recovered several fairly large pieces of wood. Gravels appear to have started running and increasing at -3900'. Having to jet flowline on every stand to clear gravel and wood. WOB = 30-35K RPM = 80 + Mud-motor (Motor factor = 0.2216 rpm/gal) Torque off Btm = 7000 FtLb Torque on Btm = 9500 FtLb GPM = 640 @ 3550 psi w/ 120 psi o iff. P/U 108K S/O 52K ROT 80K AST last 24 hrs = 5.15 hr ART last 24 hrs = 6.06 Total drill time today = 11.21 hrs. Circulate & condition mud. Adding fresh gel & finish increasing mud wt to 9.7 ppg. Preparing a 40 bbl Super-Sweep pill (Synthetic monofilament fiber). Pump rate = 640 gpm w/3550 psi. Reciprocate & rotate (80+ rpm) drill string while circulating. Circulate & condition mud @ 4267'. Pump a 40 bbl Super-Sweep & circulate hole clean. Pump rate = 640 gpm w/ 3550 psi. Reciprocate & rotate (initial 80 up to 100 rpm) drill string while circulating. NOTE: The Super-Sweep pill brought Printed: 10/27/2003 11 :35:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 · DSte Frdm..;To PlþUts> ' Task Code NPT Ph~Sé DescriþtiondtOþeratiohs 9/26/2003 00:00 - 02:00 2.00 DRILL P SURF up a fair amount of fine drill cuttings & small gravel. 02:00 - 02:30 0.50 DRILL P SURF POOH for wiper trip. Pull 6 stands up to 3700'. Hole started pulling tight from 4080' with 50K-60K drag (P/U off btm w/ no pump = 125K). Attempt to work pipe down on each stand. Pipe standing up. Hole not taking the proper amount of mud & trying to swab. 02:30 - 11 :30 9.00 DRILL P SURF M/U TDS. Establish circulation. Backream from 3700' to 300'. Hole trying to pack off at several depths from 3700' to 535'. Backreaming with 500-550 gpm w/ 2150 psi + 100 rpm. Shakers won't handle any more flow than this without running over due to excessive amounts of gravel unloading from well. 11:30-12:30 1.00 ORILL P SURF Circulate @ 300' while changing shaker screens & building mud volume. 12:30 - 16:30 4.00 ORILL P SURF TIH from 300'. Tag up on obstruction @ 1040'. M/U TOS. Establish circulation. Ream down to 1300'. TIH to 2350', tag up. Pull back to 2304'. M/U TDS. Ream down from 2304' to 2397'. TIH to 3706', tag up. M/U TDS. Ream from 3706' to bottom @ 4267'. 16:30 - 19:00 2.50 DRILL P SURF Circulate & condition mud @ 4267' (2 x Btm-up). Then pumped a 30 bbl Weighted Sweep (12.7 ppg) & circulate hole clean. Pump rate = 640 gpm w/ 3500 psi. Reciprocate & rotate (100 rpm) drill string while circulating. NOTE: Very little increase in cutting observed when the Weighted Sweep came across shale shakers. P/U 115K S/O 56K. 19:00 - 19:30 0.50 DRILL P SURF Attempt to POOH without pumping or backreaming. Pulled one stand. Hole swabbing. TIH to bottom @ 4267'. 19:30 - 00:00 4.50 DRILL P SURF M/U TOS & establish circulation. Backream from 4267' to 1931'. Backreaming with 630 gpm with 3300 psi + 100 RPM. At 2400' attempted to POOH without backreaming or pumping. Hole pulling tight & swabbing. Continued backreaming out. 9/27/2003 00:00 - 01 :30 1.50 DRILL P SURF Continue backreaming out of hole from 1931' to 903'. Backreaming with 630 gpm with 2200 psi + 80-100 RPM. At 1400' attempted to POOH without backreaming or pumping. Hole swabbing. Continued backreaming out to 903'. Reduce pump rate to 400 gpm from 1300'. Note: After backreaming through & above each of the following hole problem depths 1275'-1260',1200',1040',860' & 470' the drill string was ran back down with no problems. 01 :30 - 02:30 1.00 DRILL P SURF POOH from 903' with no problems. 02:30 - 04:00 1.50 DRILL P SURF UD 12-1/4" BHA. Clear Rig Floor of excess drilling tools & equipment. 04:00 - 04:30 0.50 CASE P SURF Make a dummy run with 9-5/8" casing hanger. UD same. 04:30 - 06:00 1.50 CASE P SURF R/U to run 9-5/8" casing. 06:00 - 06:15 0.25 CASE P SURF PJSM for running casing. 06: 15 - 06:30 0.25 CASE P SURF MU shoe track and test floats - OK. 06:30 - 09:30 3.00 CASE P SURF Run 9-5/8" casing. Torque to mark. Fill each joint. Circ pipe volume every 10 jts while running. 09:30 - 11 :00 1.50 CASE P SURF Took weight at 1120' - work thru same. Took wt again at 1185'. Break circ and work down to 1220'. Continue to spud and work pipe. Finally broke through and circ down to 1255'. 11 :00 - 13:30 2.50 CASE P SURF Work pipe down to 1275' and circ down to 1325'. Work pipe down to 1340' - hit hard spot and only make 2' progress in 30 Printed: 10/27/2003 11 :35:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES , Däte !From- TÓHours' Ta$k,' Gpde N PT Phase 9/27/2003 2,50 CASE P 0.50 CASE P 11 :00 - 13:30 13:30 - 14:00 14:00 - 14:45 0.75 CASE P 14:45 - 15:45 1,00 CASE N 15:45 - 17:00 1.25 CASE P 17:00 - 00:00 7.00 CASE N 9/28/2003 00:00 - 01 :30 1.50 CASE N 01 :30 - 03:00 1.50 CASE N 03:00 - 04:00 1.00 CASE P 04:00 - 04:30 0.50 CASE P 04:30 - 07:30 3.00 CASE N 07:30 - 08:00 0.50 CASE N 08:00 - 13:30 5.50 CASE N 13:30 - 15:00 15:00 - 15:30 1.50 CASE N 0.50 CASE N 15:30 - 18:30 3,00 CASE N 18:30 - 19:00 0.50 CASE N 19:00 - 00:00 5.00 CASE N SURF SURF SURF DPRB SURF SURF DPRB SURF DPRB SURF DPRB SURF SURF SURF DPRB SURF DPRB SURF DPRB SURF OPRB SURF DPRB SURF DPRB SURF STUC SURF STUC SURF Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 .. Descriþtion of 0 þetâti dhS min. Continue spudding casing and work down to 1405' (34 Jts csg in hole), Pump 50 bbl nut plug pill to attempt to improve hole conditions for running casing. When pill was 1/2 out of shoe, the hole packed off and no pipe movement. Work pipe and regain circulation. Establish full returns and work pipe to get free travel - OK. Try washing down again but no further progress. Work pipe and keep free travel while developing plan to pull and lay down casing safely. Pump slug. POOH laying down 9-5/8" surface casing from 1405' to 251' (28 Jts). Fill up hole continuously with trip tank. Hole taking the proper amount of mud while POOH. POH laying down 9-5/8" surface casing from 251' (34 Jts total). Fill up hole continuously with trip tank. Hole taking the proper amount of mud while POOH. Clear & clean rig floor. R/D 9-5/8" casing equipment. Slip & cut 78' of drill line. Reset & check C-O-M. Service TDS & Rig. M/U 12-1/4" Steerable Drilling Assembly. Change out jars. Test MWD. TIH with 12-1/4" BHA. Tag up @ 760'. M/U TDS. Wash thru tight spot & continue TIH. Tag up agian @ 1088'. M/U TDS. Establish circulation. Ream down from 1088' to 1930'. Work spots 1088',1120',1180-1190',1290',1295', 1445-1460'. Act like ledges? Ream down with 35 RPM, 300 gpm. Backream with 80 RPM, 600 gpm. Continue TIH from 1930' to 4172' with no problems, M/U TDS. Establish circulation. Wash to bottom @ 4267'. Drill 3' of 12-1/4" hole to 4270' to compensate for longer shoe track. Pump a 40 bbl Super-Sweep & circulate surface to surface. Next pumped a 40 bbl weighted sweep & circulate surface to surface. Hole appeared to be clean. Very little cuttings coming over shakers. Reciprocate (93') & rotate drill string (110 RPM) while circulating (600 GPM @ 3470 PSI). No excessive drag observed while circulating. P/U 118K, S/O 56K, ROT 80K. Orient MWO Tool Face to HS. Shut down pumps. Attempt to POOH with no pumps. Hole swabbing. Run back down to bottom. P/U Wt no pump = 128k. Establish circulation. POOH with pump (450 gpm) from 4270' to 4168' with no problems, hole slick. Break-off & rack back the 1 st stand of drill pipe. Next step latched on to the 4" DP in rotary table. Attempt to pull. Drill String was stuck @ 4168'. Set slips & M/U the stand of 4" DP from derrick & install TDS into same. Establish circulation. Torque up drill string to 19k FtLb. Slack off on drill string with maximum string wt & continue this process for several minutes with no success. No room to work pipe. Rack back one stand of 4" DP. M/U a single of 4" DP & install TDS. Attempt to jar down, unable to cock jars in down stroke. Jar up with 250k & pulling to 350k max. Jarred up for 30 minutes with no success. Attempt to free drill string by torquing up drill string to 22k & applying max wt down, jariing Printed: 10/27/2003 11 :35:38 AM BF> Oipéräti:øhŠ$µ mrniary., Report·.·· Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 Date From ..;To ' Hours ' Task Code NPT · Phase Description .OfOþerations 9/28/2003 19:00 - 00:00 5.00 CASE N STUC SURF up every 30 minutes to confirm that the jars are free. Circulating with no restrictions. Starting to reducing mud wt from 10 ppg ( The plan is to reduce the mud wt to below 9.5 ppg & spot SFT around BHA). 9/29/2003 00:00 - 06:00 6.00 CASE N STUC SURF Drill string stuck @ 4168'. Attempt to free drill string by torquing up drill string to 22k & applying max wt down, jariing up every 30 minutes to confirm that the jars are free. Circulating with no restrictions. Reducing mud wt from 10 ppg to below 9.5 ppg ( The plan is to reduce the mud wt to below 9.5 ppg & spot SFT around BHA). Vac truck arrived on location with 290 bbl of fresh mud. Feed fresh mud into system & decrease mud wt to 9.5+. Clean slug pit & flush lines in preparation to mix SFT spotting fluid concentrate. Mix 70 bbl SFT. Continue working pipe as above - zero pipe movement seen. 06:00 - 06:30 0.50 CASE N STUC SURF Pump 69 bbl SFT down drill string. Spot 33 bbl around BHA. Pump @ 150 gpm w/ 555 psi. 06:30 - 11 :00 4.50 CASE N STUC SURF SFT in place. Let soak for 30 minutes. Continue attempting to free drill string by torquing up drill string to 23k & applying max wt down, jariing up every hour to confirm that the jars are free. Pump 1 bbl every 30 minutes for 3 hrs, then pump 0.5 bbl every 30 minutes. Circulating with no restrictions. 11 :00 - 12:00 1.00 CASE N STUC SURF LID one joint of 4" DP. M/U BOT Surface jars & Bumper sub. 12:00 - 12:30 0.50 CASE N STUC SURF SAFETY --- Held PJSM with Drill Crew & BOT Fishing Supervisor regarding the operation of Surface Jars & hazards associated with same. 12:30 - 15:30 3.00 CASE N STUC SURF Adjust BOT Surface jars to trip at 100k over pull. Began jarring. Adjust jars to a max of 150k. Jar for 2 hrs with no pipe movement observed. LID Surface Jars & M/U one joint of 4" DP into string & install TDS. 15:30 - 00:00 8.50 CASE N STUC SURF Continue jarring & attempting to free drill string by torquing up drill string to 23k & applying max wt down. Jarring up every hour to confirm that the jars are free. Zero pipe movement observed. Pump 2 bbl every 30 minutes. NOTE: starting around 21 :00 hrs observed that when breaking circulation & pumping the SFT it is taking more pump pressure to establish circulation & also having to apply torque in drill string to get the jars to cock. Possible indication of cuttings build up around jars or string getting partly stuck above jars. 9/30/2003 00:00 - 00:30 0.50 FISH N STUC SURF Continue jarring & attempting to free drill string by torquing up drill string to 23k & applying max wt down. Jarring up every hour to confirm that the jars are free. Pump 2 bbl every 30 minutes. Circulating with no restrictions. 00:30 - 01 :30 1.00 FISH N STUC SURF Circulate & displace SFT from drill string & well. Pump rate = 560 gpm with 2640 psi. Dumped SFT pill + 20 bbl of contaminated mud to cutting tank. Had a fair amount of pea gravel & sand come across shakers on bottoms-up. 01 :30 - 03:30 2.00 FISH N STUC SURF Continue jarring & working drill string. Circulating with 560 gpm @ 2640 psi. Feed in 290 bbl of fresh mud (8.8 ppg) & reduce the mud wt from 9.5 ppg to 9.4 ppg with 326 vis mud. At 03:30 observed lots of gravel coming over shakers. 03:30 - 05:00 1.50 FISH N STUC SURF Reduce circulating rate to 200 gpm w/ 975 psi. Tripping jars one time every hour while wait on Schlumberger Pipe Recovery crew to arrive on location. Printed: 10/27/2003 11 :35:38 AM ) ) . 'BP ............. ... . .. . . ·Øþ~råti()nsSummaryRèp()l1t: .' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date ;FrÔntL To Hours Task Code NPT phase 9/30/2003 05:00 - 07:30 2.50 FISH N STUC SURF 07:30 - 09:00 1.50 FISH N STUC SURF 09:00 - 12:00 3.00 FISH N STUC SURF 12:00 - 12:30 0.50 FISH N STUC SURF 12:30 - 13:30 1.00 FISH N STUC SURF 13:30 - 17:00 3.50 FISH N STUC SURF 17:00 - 18:30 1.50 FISH N STUC SURF 18:30 - 19:00 0.50 FISH N STUC SURF 19:00 - 22:00 3.00 FISH N STUC SURF 10/1/2003 22:00 - 00:00 00:00 - 00:30 STUC SURF STUC SURF 2.00 FISH 0.50 FISH N N 00:30 - 01 :00 0.50 FISH N STUC SURF 01 :00 - 02:00 1.00 FISH N STUC SURF 02:00 - 03:00 1.00 FISH N STUC SURF 03:00 - 05:00 2.00 FISH N STUC SURF 05:00 - 06:00 1.00 FISH N STUC SURF 06:00 - 07:00 1.00 FISH N STUC SURF 07:00 - 09:30 2.50 FISH N STUC SURF 09:30 - 12:00 2.50 FISH N STUC SURF 12:00 - 13:00 1.00 FISH N STUC SURF 13:00 - 15:30 2.50 FISH N STUC SURF 15:30 -17:00 1.50 FISH N STUC SURF 17:00-17:15 0.25 FISH N STUC SURF 17:15 - 18:00 0.75 FISH N STUC SURF 18:00 - 19:30 1.50 FISH N STUC SURF 19:30 - 20:00 0.50 FISH N STUC SURF Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 DescriptiOn of Öper~tions · Increase pump rate to 370 gpm and 1270 psi to clean hole while tripping jars every hour. LD single joint of DP. Chnage top drive quill to 4-1/2" IF RU SWS pup joint, side door entry sub, joint of 5" DP and TIW valve. RU wireline. PJSM with SWS and all rig personnel. Covered wireline operations and explosives safety. MU SWS string shot RIH with string shot. Pump down at 2 bpm and 420 psi. Log string shot on depth between first and seconf monel DC at 4037. Work 4-1/2 rounds of left hand torque into drill string. Position string shot and fire. POH with wireline, verify shot fired. Work 4 turns of left hand torque into drill dtring, work pipe. Work another turn left hand torque into string. Work another turn left hand torque into string, no backoff. Pump at 5 bpm and 720 psi while working pipe and jarring up. SWS makingup second string shot to attempt to back off below jars. MU string shot. RIH, pump down 2 bpm at 450 psi. Log string shot on depth at 3974'. Work 5 turns left hand torque into drill string. Position string shot and fire. POH with string shot and verify fired. PU drill string break over at 108 klbs, backed off. RD SWS POH with 35 stands DP, 21 stands HWDP, 1 joint 5" HWDP and jars. POH to 2948' 110 klbs up, 50 klbs down. Start pulling 25 klbs, MU top drive, stage pumps to 600 gpm, 1970 psi. Circ 1-1/2 bottoms up to clean up hole while reciprocating pipe 88 klbs up, 50 klbs down. Heavy sand and gravel returns while circulating. Start POH, swabbing. Change out top drive quill from 4-1/2" IF to 4" HT-40 to allow pipe to be pumped out. POH pumping 200 gpm at 235 psi. 85 klbs up, 50 klbs down Continue POH with HWOP, no pumps. Verify drill string backed off below jars. Change out top drive quill from 4" HT-40 to 4-1/2" IF PU 5" DP from pipe shed and MU 25 stands. Stand back in derrick. MU fishing BHA #1,4-1/2" IF screw in sub RIH from 590' to 1310' picking up singles from pipe shed. 75 klbs up, 74 klbs down. 30 klbs drag at 1310',1387' and 1417'. Made up top drive and pumped down, 300 gpm at 200 psi. Stacked out at 1527', pump and rotate unable to work through. Losing footage while working pipe. Stand back 1 stand. Circulate 500 gpm at 980 psi while increasing mud weight to 9.6 ppg and 325 viscosity. Monitor well at 1438' - static Pump out 1 stand 92 klbs up, 62 klbs down with pumps. POH from 1344' with no pumps 98 klbs up, 62 klbs down. Stand back HWDP and Collars. LD BHA. Clean clear rig floor Printed: 10/27/2003 11 :35:38 AM Legal Well Name: W-209i Common Well Name: W-209i Spud Date: 9/22/2003 Event Name: DRILL +COMPLETE Start: 9/23/2003 End: 10/20/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/20/2003 Rig Name: NABORS 9ES Rig Number: 9 bate From'· To Hours ' Task CÖde', NPT 10/1/2003 20:00 - 22:30 2.50 FISH N STUC SURF MU BHA #5 for clean out run, shallow test MWO tool 22:30 - 00:00 1.50 FISH N STUC SURF RIH, PU remaining singles from pipe shed and stands from derrick. Taking weight at 1269'. MU top drive wash and ream down from 1269' to 1376' 10/2/2003 00:00 - 02:30 2.50 FISH N STUC SURF Continue washing and reaming down with 12-1/4" cleanout assembly to 1470'. 600 gpm @ 1020 psi and 110-120 rpm. 110 klbs up, 60 klbs down. Backream each stand. Work bad spots in an attempt to clean up hole. Heavy sand and gravel returns. Particularly difficult to work through at 1460'. 02:30 - 04:00 1.50 FISH N STUC SURF Continue wash and ream down from 1470' to 1755'. 600 gpm @ 1020 psi. Backream each stand. Able to TIH after backreaming each stand. Work bad spot at 1527' the point at which the fishing assy. was stopped on previous run. 04:00 - 04:30 0.50 FISH N STUC SURF RIH from 1755' to 2320', no pumps. At 2320' started taking weight. 04:30 - 07:30 3.00 FISH N STUC SURF Wash and ream down from 2320' to 3500'.600 gpm @ 1450 psi and 120 rpm 07:30 - 08:30 1.00 FISH N STUC SURF Circulate 2 X BU at 3500'.600 gpm @ 1450 psi, 125 rpm. 90 klbs rotate, 12 klbs torque 08:30 - 10:00 1.50 FISH N STUC SURF Continue wash and ream in to 3965'. Wash down from 3965' to tag top of fish. Tag top of fish at 3977'. 600 gpm @ 1535 psi. 120 rpm, 12 klbs torque. 10:00 - 11 :30 1.50 FISH N STUC SURF Circulate 2 X BU at 3967'.650 gpm @ 1750 psi, 125 rpm. 150 klbs up, 60 klbs down 94 klbs rotate. 11 :30 - 12:00 0.50 FISH N STUC SURF Monitor well - static. Start POH pumping 200 gpm @ 460 psi. 150 klbs up, 60 klbs down. 12:00 - 15:30 3.50 FISH N STUC SURF Pick up out of slips at 3930', differentially stuck. Roll pump slowly and apply torque on the down stroke to break free - OK. Backream each stand out at 500 gpm @ 1100 psi, 120 rpm. 94 klbs rotate, 7-15 klbs torque. 15:30 - 18:30 3.00 FISH N STUC SURF Pump out from 2510' to 1650', 200 gpm @ 270 psi. 120 klbs up, 55 klbs down. At 1650' started pulling 10-20 klbs over. Worked stand down and started backreaming out to 1180', 500 gpm and 120 rpm. Pump out from 1180' to 500', 200 gpm @ 200 psi. 18:30 - 21 :30 3.00 FISH N STUC SURF Monitor well - static. 76 klbs up, 74 klbs down. RIH to 1375' with no pumps. From 1372' to 1755' taking weight ream through and back ream up through tight spots able to pump down through all tight spots without rotating. Continue RIH without pumps from 1755' to 2605',53 klbs down. 21 :30 - 22:30 1.00 FISH N STUC SURF MU top drive, fill pipe and RIH to 2700'. Circulate BU X 2,650 gpm @ 1460 psi, 120 rpm. 86 klbs rotate, 5-10 klbs torque. 22:30 - 00:00 1.50 FISH N STUC SURF POH to 1850' pumping out, 200 gpm @ 250 psi. 128 klbs up, 62 klbs down 10/3/2003 00:00 - 02:30 2.50 FISH N STUC SURF Continue pumping out of hole from 1850',200 gpm @ 200 psi. 115 klbs up, 60 klbs down. Pulled 25 klbs over intermittently from 1658' to 1370'. Able work through without backreaming. 02:30 - 04:00 1.50 FISH N STUC SURF LD jars, stand back DC's. 04:00 - 04:30 0.50 FISH N STUC SURF LD BHA #5 04:30 - 05:00 0.50 FISH N RREP SURF Repair pipe skate. 05:00 - 05:30 0.50 FISH N STUC SURF Finish laying down BHA #5. 05:30 - 06:00 0.50 FISH N STUC SURF Clean and clear rig floor. 06:00 - 07:30 1.50 CASE N STUC SURF RU to run 9-5/8" 40# casing. Printed: 10/27/2003 11:35:38AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From ~Tö 'HoUrs Task Goder ' NÞr Phase 1 0/3/2003 07:30 ~ 08:00 0.50 CASE N 08:00 ~ 12:00 4.00 CASE N 12:00 ~ 13:30 1.50 CASE N 13:30 ~ 14:00 0.50 CASE N 14:00 - 15:00 1.00 CASE N 15:00 ~ 20:30 5.50 CASE N 20:30 ~ 21 :00 0.50 CASE N 21 :00 - 21 :30 0.50 CASE N 21 :30 ~ 22:00 0.50 CASE N 22:00 ~ 00:00 2.00 CASE N 10/4/2003 00:00 - 02:00 2.00 CASE N 02:00 - 03:00 1.00 STKOH N 03:00 ~ 04:00 1.00 STKOH N 04:00 - 06:30 2.50 STKOH N 06:30 - 09:30 3.00 STKOH N 09:30 ~ 18:30 9.00 STKOH N STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF STUC SURF 18:30 ~ 19:00 0.50 STKOH N STUC SURF 19:00 - 20:30 1.50 STKOH N STUC SURF 20:30 ~ 21 :00 0.50 STKOH N STUC SURF 21 :00 - 21 :30 0.50 STKOH N STUC SURF 21 :30 ~ 00:00 2.50 STKOH N STUC SURF 10/5/2003 00:00 ~ 00:30 0.50 STKOH N STUC SURF 00:30 ~ 02:30 2.00 STKOH N STUC SURF 02:30 - 04:00 1.50 CASE N STUC SURF 04:00 - 04:30 0.50 CASE N STUC SURF 04:30 ~ 07:45 3.25 CASE N STUC SURF Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 Description o.f 'Oþér~ti()hs ' PJSM with Nabors Casing and all rig personnel on running 9-5/8" csg. MU float equipment and check floats. Run 9~5/8" 40# L-80 csg. Fill each joint, break circulation on jt #20. Taking weight at 1375 and again at 1390'. Work pipe at 1393' Work pipe at 1393', pump 450 gpm @ 630 psi. Unable to work csg through, start losing footage. Pipe at 1375', unable to work past this point. PJSM with Nabors casing and all rig personnel on POH and LD 9-5/8" csg. RU to LD 9~5/8" csg. Mix and pumpd dry job. POH laying down 9-5/8" csg. LO fill~up tool. Blow down top drive. Evacuate float equipment. PJSM with Nabors Casing, rig welder and all rig personnel on cutting and laying down float equipment. Cut and LD float equipment. RD csg equipment. Clean and clear rig floor. LO 6-1/2" DC's. Clean and clear rig floor Load BHA #6 and 5" HWDP into pipe shed PU HWDP, Jars and DC's. Stand back in derrick PU motor, MU bit. PU MWD tools. Orient. RIH with BHA and shallow test MWD. Wash down from 350' to 1030', 300 gpm @ 580 psi. At 1030' hit a tight spot and reamed through to 1040', 300 gpm and 30 rpm. Continued washing down from 1040' through intermintent tight spots to tag up on obstruction at 1379' OH sidetrack from 1379' to 1891'. 700 gpm @ 2121 psi, 50 rpm when rotating. 105 klbs up, 70 klbs down, 80 klbs rotate. AST last 24 hrs. = 3.98 hrs. ART last 24 hrs. = 1.65 hrs. Circulate 1-1/2 BU, 700 gpm @ 1893 psi. Reciprocate DP 10' and rotate at 80 rpms while circulating. POH to 1017, pumping 200 gpm @ 400 psi. 105 klbs up, 70 klbs down. Intermintent drag of 15-20 klbs throughout short trip RIH with no pumps to 1891'. Taking weight at 1286', 1415-1420' and 1615-1640. Able to work through with no problems. Circulate 1-1/2 BU, 700 gpm @ 1495 psi. Reciprocate DP 10' and rotate at 80 rpms while circulating. POH pumping 200 gpm @ 400 psi. 105 klbs up, 70 klbs down. Intermintent drag of 5~ 15 klbs throughout trip. Continue POH pumping 200 gpm @ 400 psi Stand back HWDP, jars and collars. LD MWD, motor and jewelry. Clean and clear rig floor. CO bails. RU 13-3/8" casing equipment. MU fill-up tool PJSM with Nabors Casing and all rig personnel on running 13-3/8" 68# casing. Baker-Iok float equipment. Check floats. Run 13-3/8" #68 casing. Doyon 141 surface cement job currently ongoing. Will have to wait on equipment to free up from this job; vac trucks, supersuckers and a cement head before the 13-3/8" csg can be cemented. Continue running 133/8" casing to 1420'. Printed: 10/27/2003 11 :35:38 AM ) BP Oiperatiøns",SUI11nlélry !Rê.þort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From..; To Höurs Task Code NPT Phase 10/5/2003 4.75 CASE N STUC SURF 07:45 - 12:30 12:30 - 13:30 1.00 CEMT N STUC SURF 13:30 - 18:00 4.50 CEMT N STUC SURF 18:00 - 18:30 0.50 CEMT N STUC SURF 18:30 - 18:55 0.42 CEMT N STUC SURF 18:55 - 19:25 0.50 CEMT N STUC SURF 19:25 - 20:20 0.92 CEMT N STUC SURF 20:20 - 20:45 0.42 CEMT N STUC SURF 20:45 - 21 :30 0.75 CEMT N STUC SURF 21 :30 - 00:00 2.50 CEMT N STUC SURF 10/6/2003 00:00 - 01 :30 1.50 BOPSUR N STUC SURF 01 :30 - 01 :45 0.25 WHSUR N STUC SURF 01 :45 - 04:00 2.25 WHSUR N STUC SURF 04:00 - 07:00 3.00 WHSUR N STUC SURF 07:00 - 09:00 2.00 BOPSURN STUC SURF 09:00 - 13:00 4.00 DRILL N STUC SURF 13:00 - 14:00 1.00 DRILL N STUC SURF 14:00 - 15:30 1.50 DRILL N STUC SURF 15:30 - 17:30 2.00 DRILL N STUC SURF 17:30 - 18:30 1.00 DRILL N STUC SURF 18:30 - 19:30 1.00 DRILL N STUC SURF 19:30 - 00:00 4.50 DRILL N STUC SURF Päg~'~()f 1.9 '. Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 De$Cri ptionof OperatiOns Casing stopped at 1420'. Circ down with Franks tool and work pipe in ground slowly, but always making progress. Continue washing down. MU hanger and landing joint and land hanger on ring. Land casing with shoe at 1879' MO. PSI cement job has finished and equipment is becoming available. LD Franks tool. Blow down top drive. RU cement head and lines Stage pumps to 8 bpm @ 430 psi. Ciculate and condition mud to reduce visc to 110 sec/qt and stage trucks PJSM with Schlumberger, PES and all rig personnel on cement job. Air and batch up cement trucks. Pump 5 bbl1 0.5 ppg spacer. Test lines to 3500 psi. Contine pumping 125 bbls 10.5 ppg spacer. 2 gallons of red dye mixed with first tub of spacer Orop bottom plug. Pump 364.4 bbls (460 sxs) 10.7 ppg lead cement. 7 bpm @ 200 psi. Red dyed spacer at surface. Pump 105.7 bbls (167 sxs) 11.0 ppg Arctic LiteCrete tail cement. 5 bpm @ 170 psi. Drop top plug and kick out with 10 bbl of water from cementers. Switch to rig pumps and displace with mud. 8 bpm @ 440 psi for first 187 bbls. 48 bbls into displacement cement returns to surface. Reduce rate to 6 bpm @ 400 psi for the next 61 bbls of displacement. Reduce rate to 2 bpm to bump, FCP 500 psi. 300 strokes prior to bumping cement packed off below the hanger, continue displacement. Bump plugs with 1000 psi on calculated strokes. 100 bbls contaminated mud and 230 bbls cement returns. Bleed pressure check floats - holding. CIP @ 21 :30 Flush flow line and surface stack with retarder. RD cement head. LO landing joint. Rig down casing equipment. Clean and clear rig floor NO riser and Hydril. Remove diverter line PJSM with FMC, GBR and rig personnel on cutting 13-3/8" hanger and welding 9-5/8" landing ring Cut 13-3/8" casing hanger and weld on Kuparuk style 9-5/8" landing ring. Service top drive, blocks and crown. Cut and slip 54' of drilling line. Change to 5-1/2" liners. Wait for wellhead to cool after cutting and welding. NU riser and diverter PU and MU BHA #7 12-1/4" drilling assy. Shallow test MWD, RIH to float collar Wash down to plugs at 1832'. Drill cement, rat hole and 10' of new hole to 1900'. 500 gpm @ 1130 psi and 40 rpm. 104 klbs up, 73 klbs down, 87 klbs rotate. Displace hole to new 8.8 ppg, 300+ vis spud mud. 250 gpm @ 240 psi. Clean contaminated mud from pits. Build 80 bbls 8.8 ppg, 300+ vis spud mud Directional drill from 1900' to 2275'. 650 gpm @ 1610 psi, 50 rpm. 105 klbs up, 65 klbs down, 87 klbs rotate. Torque 7.5-8 Printed: 10/27/2003 11 :35:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 ·>Date From ~ To Hours Ta$k·, Code NPT Descriþtiöhöf qper~tiohs 1 0/6/2003 19:30 - 00:00 4.50 DRILL N STUC SURF 1 0/7/2003 00:00 - 00:30 0.50 DRILL N STUC SURF 00:30 - 01 :00 0.50 ORILL N STUC SURF 01 :00 - 03:30 2.50 DRILL N STUC SURF 03:30 - 04:30 1.00 DRILL N STUC SURF 04:30 - 08:00 3.50 DRILL N STUC SURF 08:00 - 09:00 09:00 - 10:30 1.00 DRILL N 1.50 DRILL N STUC SURF STUC SURF 10:30 - 13:00 2.50 DRILL N STUC SURF 13:00 - 13:30 0.50 DRILL N STUC SURF 13:30 - 14:00 0.50 ORILL N STUC SURF 14:00 - 14:30 0.50 DRILL N STUC SURF 14:30 - 15:00 0.50 ORILL N STUC SURF 15:00 - 15:30 0.50 DRILL N STUC SURF 15:30 - 16:00 0.50 DRILL N STUC SURF 16:00 - 16:30 0.50 DRILL N STUC SURF 16:30 - 18:00 1.50 DRILL N STUC SURF 18:00 - 19:00 1.00 DRILL N STUC SURF 19:00 - 00:00 5.00 ORILL N STUC SURF 10/8/2003 00:00 - 01 :30 1.50 DRILL N STUC SURF 01 :30 - 02:00 02:00 - 03:00 0.50 DRILL N 1.00 DRILL N STUC SURF STUC SURF klbs. waB 25-30 klbs. Sliding to build angle to 65 degrees. AST last 24 hrs. = 2.64 hrs. ART last 24 hrs. = 0.32 hrs. Directional drill from 2275' to 2390'.650 gpm @ 1610 psi, 50 rpm. 105 klbs up, 65 klbs down, 87 klbs rotate. Torque 7.5-8 klbs. WaB 25-30 klbs. Sliding to build angle to 65 degrees. Ciculate hole clean. 650 gpm @ 1538 psi. Rotate 60 rpm keeping the bit within 10' of the bottom of the hole. Directional drill from 2390' to 2782'.650 gpm @ 1730 psi, 50 rpm. 108 klbs up,70 klbs down, 84 klbs rotate. Torque 7.5-8 klbs. WaB 25-30 klbs. Rotating and sliding as needed to maintain angle at 65 degrees. Circulate hole clean. 650 gpm @ 1580 psi. Rotate 80 rpm keeping the bit within 10' of the bottom of the hole. Large quantities of clay returns. Start stringing in nutplug at 1 sx/15min to help cut and transport clays. Oirectional drill from 2782' to 3495'.650 gpm @ 1978 psi, 60 rpm. 119 klbs up, 58 klbs down, 83 klbs rotate. Torque 7.5-8 klbs. WaB 25-30 klbs. Rotating and sliding as needed to maintain angleat 65 degrees. * Ordered 200 bbl new 8.8 ppg, 250 vis mud pre-mixed with 10#/bbl MIX II medium, 1.5#/bbl PolyPac and 1/2% Drillzone. Flow Line & Possum Belly packing off. Circulate & clean same. Backream slowly from 3495' to 3370' while conditioning mud. Ream back to bottom @ 3495'. Directional drill from 3495' to 3814'. 660 GPM @ 2055 psi. RPM = 60 P/U = 125K, ON = 70K, ROT = 88K. TO = 7.5K to 8.5K Rap Limit 250 ft / Hr. Backream every stand Large balls of clay plugging Flow Line & Possum Belly. Reduce circ. rate, work pipe & clean out same. Directional drill from 3814' to 3862' @ above parameters. Remove clay from Flow Line & Possum Belly as above. Directional drill from 3862' to 3876' @ above parameters. Remove clay from Flow Line & Possum Belly as above. Oirectional drill from 3876' to 4035'.650 GPM @ 2058 psi. Remove clay from Flow Line & Possum Belly as above. Directional drill from 4035' to 4188' - TO per Geologist. 650 GPM @ 2120 psi. P/U = 135K, ON = 75K, ROT = 91 K. TO = 7.5K to 8.5K AST = 2.55 Hrs. ART = 5.86 Hrs. for Day. CBU X 3, 710 GPM @ 2230 psi. 80 to 100 RPM. Reciprocate pipe 10ft off bottom. Backream out of hole to 13 3/8" shoe @ 1879' w/ 650 GPM @ 1840 psi. & 100 RPM. Flow Line & possum belly plugging often with clay balls the size of basketballs. Slowed rate to clean out & continued backreaming. CBU X3 @ Shoe, 1879'.700 GPM @ 1750 psi. Adjust flow rate as needed as large clay balls plugged possum belly. Service Top Drive & Blocks. RIH, Precautionary wash last two stands to bottom @ 4188'. Printed: 10/27/2003 11:35:38AM Päge 11,.of 19 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 '.·Date 'From "' To Höurs Tâsk' CodeNPT Phase Desbr.iþtiönof Operations 1 0/8/2003 02:00 - 03:00 1.00 DRILL N STUC SURF No Fill. Hole Slick 03:00 - 04:00 1.00 DRILL N STUC SURF CBU X 2, 100 RPM, 710 GPM 2070 psi. Very little over Shaker 04:00 - 07:30 3.50 DRILL N STUC SURF Monitor well - Static. POH 1 stand - swabbing. Run back to bottom & pump out of hole @ 650 GPM 1750 psi. to 1994' - 30K overpull ( top stab. entering shoe) Backream up into shoe. 07:30 - 08:30 1.00 ORILL N STUK SURF CBU @ Shoe, 700 GPM @ 1664 psi. 08:30 - 10:00 1.50 DRILL N STUS SURF Monitor well - Static. Blow down TO. POH dry from shoe. Stand back HWDP. 10:00 - 12:30 2.50 DRILL N STUC SURF LID DC's, Stabs, MWD, Motor & Bit 12:30 - 14:00 1.50 CASE N STUC SURF Make dummy run w/ hanger & landing jt. R/U to run csg. 14:00 - 0.00 SURF 14:00 - 14:30 0.50 CASE N STUC SURF PJSM w/ Co. Rep, Tool Pusher, Casing Hand & Crew. 14:30 - 15:30 1.00 CASE N STUC SURF M/U Shoe Track & check floats. RIH w/ 9 5/8", 40#, L-80, BTC Casing as per program, filling every Jt. w/ Franks tool.- 15:30 - 16:00 0.50 CASE N STUC SURF Check valve in Franks Tool stuck open. LID Franks tool & R/U Fill- Up Line. 16:00 - 16:30 0.50 CASE N STUC SURF Cont. RIH w/ Casing. 16:30 - 17:00 0.50 CASE N STUC SURF P/U & M/U repaired Franks Tool 17:00 - 18:00 1.00 CASE N STUC SURF Cont. RI H w/ Casing to 1500'. 18:00 - 19:00 1.00 CASE P SURF RIH w/ Casing to Shoe @ 1879'. 19:00 - 19:30 0.50 CASE P SURF Circ. Casing volume. 19:30 - 23:00 3.50 CASE P SURF Cont. RIH w/ 9 5/8" Csg. Fill every Jt, break circ every 15 Jts. Total 100 Jts ran. Shoe @ 4176'. F/C @ 4086', Tam Port Collar @ 1895'.Circulated Last jt down. No Hole problems throughout run. 23:00 - 23:30 0.50 CEMT P SURF R/D Franks Tool, R/U Cement Head. 23:30 - 00:00 0.50 CEMT P SURF Break circ. Stage pumps up to 8 BPM @ 500 psi. Reciprocate pipe 15' Up Wt = 160K On Wt = 90K 1 0/9/2003 00:00 - 01 :30 1.50 CEMT P SURF Circ. & Condo mud for Cement Job. Stage up to 10 BPM @ 600 psi. Wt = 9.3 ppg, Vis = 66, YP = 17 Reciprocate, Up Wt = 156K On Wt = 88K 01 :30 - 04:30 3.00 CEMT P SURF Turn over to Oowell / Schlumberger & Cement as follows: Pump 5 Bbls CW-100 @ 8.34 ppg. & 5 BPM Test Lines to 3500 psi. Pump 15 Bbls CW-100 @ 8.34 ppg. & 5 BPM Mix & pump 80 Bbls Mud Push @ 10.5 ppg & 4 BPM Drop bottom plug Mix & Pump 430 BBls(543 sX), 10.7 ppg, Arctic Set Lite Lead Slurry @ 8 BPM. Yield: 4.45 ft3/sk. Mix & Pump 60 Bbls. ( 287 sX), 15.8 ppg, Class G Tail Slurry.@ 6 BPM Yield : 1.17 ft3/sk Drop Top Plug Chase w/ 10 Bbls water from OS. Switch to rig & displace w/ 301 Bbls 9.3 ppg. Mud. Bumped Plug w/ 1200 psi. Reciprocated until Mud push @ surface. 200 Bbls of good 10.7 ppg cement to surface. 04:30 - 06:00 1.50 CASE P SURF RID cement head, break out landing jt. N/D Riser 06:00 - 06:30 0.50 CASE P SURF RID Casing equip from floor. 06:30 - 07:30 1.00 DRILL P INT1 Cleanout under rotary Table w/ Super sucker Printed: 10/27/2003 11 :35:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Þrbm'"To< Hours Task Code NPT 10/9/2003 07:30 - 08:30 08:30 - 13:30 13:30 - 14:00 14:00 - 17:30 17:30 - 18:00 18:00 - 19:30 19:30 - 22:30 22:30 - 00:00 10/10/2003 00:00 - 01 :00 01 :00 - 04:30 04:30 - 05:30 05:30 - 07:00 07:00 - 12:00 12:00 - 14:00 14:00 - 15:00 15:00 - 16:30 16:30 - 17:30 17:30 - 18:30 18:30 - 20:00 20:00 - 20:30 20:30 - 00:00 10/11/2003 00:00 - 00:30 00:30 - 02:00 02:00 - 04:00 04:00 - 04:30 04:30 - 06:30 06:30 - 07:30 07:30 - 09:00 1.00 DRILL P 5.00 BOPSUR P 0.50 BOPSUR P 3.50 BOPSUR P 0.50 DRILL P 1.50 ORILL P 3.00 DRILL P 1.50 DRILL P 1.00 ORILL P 3.50 DRILL P 1.00 DRILL P 1.50 DRILL P 5.00 DRILL N 2.00 DRILL P 1.00 DRILL P 1.50 DRILL P 1.00 DRILL P 1.00 DRILL P 1.50 DRILL P 0.50 DRILL P 3.50 CASE N 0.50 CASE N 1.50 CASE N 2.00 CASE N 0.50 CASE N 2.00 CASE N 1.00 CASE N 1.50 CASE N INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 DPRB INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 DFAL SURF DFAL SURF DFAL SURF DFAL SURF DFAL SURF DFAL SURF DFAL SURF DFAL SURF Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 " , DescriþtìonofOþerations N/D Diverter & Line. Remove Hydrill from cellar. N/U Casing Head & Tubing spool. Test head seal to 1000 psi for 10 minutes. N/U 135/8", 5000 psi BOP. M/U Test Jt., Test plug, TIW & Dart valve. Test BOPE to 250 psi Low I 4000 psi High, Annular 250 psi Low I 3500 psi High. Test witnessed by Chuck Scheve, AOGCC. MIU & Install Wear Bushing. Install Mouse Hole. RIH with 5" DP out of Derrick. POH LID 5" Orill Pipe. Clean Rig Clean Rig P/U & RIH wI 120 Jts 4" DP. Move 4" HWDP to OS. POH wI 40 stands of 4" DP. PJSM, P/U & M/U Bit, Motor, LWD - Bit would not pass through Hanger. Pull up & take 1.15 Deg bend out of motor. Re-try no-go. Change out bit to 8 1/2" - Passes through OK. Break out 8 3/4" Stabilizers while waiting on new 8 1 12" bit and stabilizers. M/U New 8 1/2" Bit & sleeve Stabilizers surface test MWD - OK. RIH to 2400' P/U 4" DP from Shed. POH, standing back 4" DP. Service Top Drive, Blocks & Crown. Slip & Cut Drilling Line. MIU 8 1/2" Ghost Reamer, RIH to 2000'. Test Csg (Tam Clr) to 1000 psi. RIH, P/U 15 Jts 4" DP from Shed to put 8 1/2" Ghost Reamer past Tam elr. Test Csg again to 1000 psi - OK RIH to 3800' ( Hold Kick while Tripping Drill) Precautionary wash to 3906' Attempt to test 9 5/8" Surface Casing. Pressure to 3500 psi. Bled off to 2800 psi in 8 min. Check surface equipment. Re- Test to 3500 psi. Bled off to 1200 psi in 35 min. Called ODE, Neil Magee. Double Checked all surface equipment & CBU. Re - pressured Casing to 3500 psi. Pressure dropping at similar rate. After 20 min. pressure = 1300 psi. After 40 min. pressure = 800 psi. After 60 min = 680 psi RID from casing test. Prepare to POH. Pump slug, POH wI 4" DP. PJSM, Unload Nuke Source, break down & stand back BHA Re - test Casing under blind rams for final surface check - same bleed off. M/U Halliburton 9 5/8" RTTS Tool & RIH to 1915' - just below Tam Port Clr. Break Circ. Set RTTS. Pressure down DP, below RTTS. Pres. up to 3500 psi. Leak off same as previous tests. Bleed pres. at surface. Then, pressure down annulus; testing Tam Clr and Casing above RTTS. Pressure to 3500 psi. Held steady for 10 minutes. Good Test. Bleed pressure at Surface. Release RTTS. RIH wI RTTS to 3906' Printed: 10/27/2003 11 :35:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 , Date From .;To< Ho Li rs Task ÇÖde NPT Phase ' Dès¢riþtion ()fOþeratiÖhs 10/11/2003 09:00 - 10:30 1.50 CASE N DFAL SURF Break Circ. Set RTTS. Pressure up annulus to 3500 psi, hold & chart for 30 minute Casing Test. No Bleed Off - Good Test. Bleed pres. at surface. Release RTTS. Wet Shoe Confirmed. 10:30 - 13:30 3.00 CASE N DFAL SURF Pump slug & POH wI RTTS. Stand back DC's, LID RTTS. 13:30 - 16:00 2.50 CASE N DFAL SURF MIU BHA, Load Nuke source, RIH wI DC's, HWDP & Ghost Reamer. Shallow Test Anadrill Tools. 16:00 - 17:00 1.00 CASE N OFAL SURF RIH to 3906'. 17:00 - 17:30 0.50 DRILL P INT1 Wash down to 4068', tagged soft cement. 17:30 - 20:00 2.50 DRILL P INT1 Orill soft cement, Plugs, Float Collar & Shoe. Clean out rat hole to TO of4188'. Circulate up contaminated mud. 20:00 - 20:30 0.50 DRILL P INT1 Drill 20' of new hole to 4208', 20:30 - 21 :30 1.00 DRILL P INT1 Oisplace to New, 8.9 ppg. I LSND Mud. 21 :30 - 22:00 0.50 ORILL P INT1 Perform LOT. Shoe TVD of 2696',8.9 ppg Mud, Surface Leak-Off pressure of 597 psi. = 13.61 ppg, EMW, LOT. Take ECD Benchmark readings - Calculated Clean Hole ECD = 9.85 ppg. 22:00 - 00:00 2.00 ORILL P INT1 Directional Drill from 4208' to 4405'.600 GPM @ 2250 psi. UW = 100K, OW = 65K, RW = 79K. TO On = 5K, TO Off = 3K ECD = 9.98 ppg. 10/12/2003 00:00 - 10:30 10.50 DRILL P INT1 Directional Drill from 4405' to 6148' with 600GPM @ 2950 psi UW = 108K, OW = 75K, RW = 91K. Tq On = 7K, TO Off = 4.1K Calc. ECD = 10.42 ppg. Actual ECD = 10.81 ppg Sweeping Hole every 300' to contol ECD. Stopping & Circulating when 1.0 ppg over calculated. LWD Tools Failed. 10:30 - 11 :30 1.00 DRILL N DFAL INT1 Circulate LO - Hi Vis Sweep @ 600 GPM, Rotating @ 140 RPM. 11 :30 - 12:00 0.50 DRILL P INT1 Anadrill tools now working. Resume drilling & drill from 6148' to 6241'. Same parameters. Tools again failed. Total daily AST = 1.30 Hrs. Total daily ART = 3.35 Hrs. 12:00 - 13:00 1.00 DRILL N DFAL INT1 Circulate bottoms up. 600 GPM, 140 RPM. ECD = 10.57, Calc ECO = 10.42 13:00 - 14:00 1.00 DRILL N OFAL INT1 POH to 5948'. Pulling 20K Over. Backream from 5948' to 5160' - 100' above Ghost Reamer depth @ TO. 14:00 - 16:30 2.50 DRILL N DFAL INT1 POH without pumps. No excess drag nor swabbing. Monitor well @ Shoe. Continue POH to HWDP. 16:30 - 17:30 1.00 DRILL N DFAL INT1 Stand back HWDP. PJSM for source & BHA. 17:30 - 19:30 2.00 DRILL N DFAL INT1 Stand back Jars, DC's. Remove source & LID all Anadrill Tools. 19:30 - 21 :00 1.50 DRILL N DFAL INT1 P/U COR, MWD & Orient. PIU ADN & load source. RIH wI DC's, HWDP. Shallow test Tools - OK. 21 :00 - 21 :30 0.50 DRILL N DFAL INT1 Service Top Drive, Blocks & Crown. 21 :30 - 00:00 2.50 DRILL N DFAL INT1 RIH To Shoe @ 4188'. Break circulation. Cont. RIH to 6150'. 10/13/2003 00:00 - 00:30 0.50 DRILL N DFAL INT1 Wash from 6150' to 6241'. Hole in great shape. 00:30 - 00:00 23.50 DRILL P INT1 Directional Drill from 6241' to 9250'. 600 GPM @ 3460 psi., 100 RPM UW = 165K, OW = 82K, RW = 113K WOB = 15K to 25K AST = 2.85 Hrs. ART = 9.93 Hrs. Torque was climbing up to 13K @ +1- 9000'. Treated wI FloLube and saw a reduction of 500 to 1000 ftllbs. for 30 min.; Printed: 10/27/2003 11 :35:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 ····Date Fror'n·~ To Hours Task Code NPT Phase Dèscriþtiqn of Operations 10/13/2003 00:30 - 00:00 23.50 DRILL P INT1 then back up to 12.5 to 13K. Added 2 drums of EP Mud Lube & the torque dropped off 3000 ftllbs & remained workable. Backreaming every stand. Sweeps every 400'. Cleaning Hole Nicely. ECD is staying within 0.3 ppg. to 0.4 ppg. of Calculated 10/14/2003 00:00 - 09:00 9.00 DRILL P INT1 Directional Drill 8-1/2" hole from 9,250' to 1 O,545'MD I 5553' TVD. WOB = 25K RPM 100 + Mud-Motor (Motor factor = 0.481 rpm/gal) Torque off Btm = 11300 FtLb Torque on Btm = 12000 FtLb GPM= 600 GPM @ 3985 psi WI 300 psi Diff. Backreaming every stand. Pump HV Sweeps every 400'. Managing Torque wI EP Lube Calculated ECD = 10.22 ppg, Actual ECD = 10.52 ppg. AST = 0 hrs ART = 5.35 hrs. 09:00 - 11 :30 2.50 DRILL P INT1 Pump a 35 bbl HV Sweep & circulate hole clean (3 x Btm-up vol) with 600 gpm @ 3985 psi. Reciprocate & rotate drill string (140 RPM) while circulating. 11 :30 - 12:00 0.50 DRILL P INT1 POOH for wiper trip. Pull 3 stands up to 10261 '. Hole started pulling tight from 10237' with 20K drag. 12:00 - 12:30 0.50 ORILL P INT1 M/U TDS. Establish circulation. Sackream from 10237' to 9485' with no problems. Sackreaming with 570 gpm wI 3210 psi + 100 RPM. 12:30 - 15:30 3.00 DRILL P INT1 POOH from 9485' with 10k-15k over pull @ 7834' & 7355'. At 6960' encountered tight hole (20k over pull). 15:30 -16:30 1.00 DRILL P INT1 TIH with one stand 4" DP to 7050'. M/U TDS. Establish circulation. Sackream up to 6930'. Hole trying to pack-off. Circulate & condition mud/hole from 6930'. Circulate 2 x Btm-up @ 600 gpm wI 2800 psi. Reciprocate & rotate drill string (140 RPM) while circulating. Initial ECO = 10.55 ppg. Final ECD = 10.22 ppg. No excess cuttings observed at shakers while circulating. 16:30 - 17:30 1.00 ORILL P INT1 POOH from 6930' to 6076' with no problems. Encountered tight hole @ 6076'. 17:30 - 19:00 1.50 DRILL P INT1 M/U TDS. Establish circulation. Sackream from 6076 to 5145' with no problems. Sackreaming with 580 gpm wI 2420 psi + 100 RPM. 19:00 - 19:30 0.50 DRILL P INT1 POOH from 5145' to inside the 9-5/8" casing shoe @ 4176' with no other hole problems encountered. 19:30 - 20:00 0.50 DRILL P INT1 Circulate hole clean from 4176' with 600 gpm wI 2025 psi. Reciprocate & rotate drill string (80 rpm) while circulating. 20:00 - 21 :30 1.50 DRILL P INT1 Slip & cut 80' drill line. Reset & test C-O-M. Service TDS & Rig. 21 :30 - 00:00 2.50 DRILL P INT1 TIH with 8-1/2" Steerable Drilling assembly on 4" DP to 8500' (Midnight depth) with no problems. 10/15/2003 00:00 - 00:30 0.50 DRILL P INT1 Continue TIH from 8500' to 10443' with no hole problems encountered. Hole in good shape. 00:30 - 03:00 2.50 DRILL P INT1 M/U TDS. Establish circulation. Precautionary wash & ream to bottom @ 10545' TO. Pump a 35 bbl HV sweep. Circulate hole clean (2 x Btms-up) with 600 gpm @ 3800 psi. Reciprocate & rotate drill string (140 rpm) while circulating. Torque = 11 000 FtLb. Had a fair amount of fine cuttings on bottoms-up. Hole Printed: 10/27/2003 11 :35:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 Date From- To Höurs Task CQcJé NPT. Phase 10/15/2003 00:30 - 03:00 2.50 DRILL P INT1 cleaned up real fast. Spot 447 bbl of 9.2 ppg mud mixed with 10 ppb G-Seal in open hole. 03:00 - 08:00 5.00 ORILL P INT1 Flow check well. Well static. POOH 10 std with no problems. M/U TDS & pump slug. Continue POOH to BHA with no hole problems encountered. PIU Wt off bottom with no pump = 180k 08:00 - 11 :30 3.50 DRILL P INT1 POOH with BHA. Stand bach 4" HWDP. Flush MWD & Mud-motor with water. Held PJSM. Remove nuclear source from COR. LID all MWD & directional drilling related equipment. Clean Rig Floor. 11 :30 - 12:00 0.50 BOPSUR P PROD1 M/U 4" DP with ported sub & wear bushing retrieving tool. Flush BOP. Pull wear bushing. LID same. 12:00 - 13:30 1.50 BOPSUR P PROD1 Held PJSM. Change out upper pipe rams from 3.5" x 6" VBR to 7" casing rams. Test bonnet seals to 1000 psi. 13:30 - 14:00 0.50 WHSUR P PROD1 PIU 7" casing landing joint with casing hanger assembly. Make dummy run. LID same. 14:00 - 15:00 1.00 CASE P PROO1 R/U 7" casing running equipment. M/U Franks Fill-up tool to TDS. 15:00 - 15:30 0.50 CASE P PROD1 Held PJSM with crew on running 7" casing. 15:30 - 21 :00 5.50 CASE P PROD1 M/U 7" shoe track. Check floats-OK. RIH with 7" 26# L-80 BTCM casing to 9-5/8" casing shoe @ 4176'. Fill every joint. Circulate 10 minutes @ 2088'. 21 :00 - 22:00 1.00 CASE P PROD1 Establish circulation. Stage pumps up slowly to 7 bpm wI 460 psi. Circulate 1.5 BU. No losses observed. 22:00 - 00:00 2.00 CASE P PROD1 Continue RIH with 7" casing @ 1 min I joint filling every joint. Break circulation every 20 jts. Total joints ran as of midnight = 117 Jts @ 5758'. 10/16/2003 00:00 - 07:30 7.50 CASE P PROD1 RIH with 7" casing from 5758' @ 1 min I joint, filling every joint. Break circ every 20 joints. CBU while running in slowly F/6000' to 6700'. CBU while running in slowly FI 8000' to 8900'. Continue RIH filling every joint to 10530' (256 Jts total of 7" 26# L-80 BTCM csg) with no problems. Average casing make-up torque = 9000 FtLb. 07:30 - 08:00 0.50 CASE P PROD1 RD Frank's tool. MU cement head & related equipment. Blow down top drive. 08:00 - 10:30 2.50 CASE P PROD1 Break circulation slowly and stage pumps up to 7 bpm @ 860 psi. Reciprocate casing with 243K PIU Wt & 88K S/O Wt. Circulate hole clean. Batch mix cement while circulating. 10:30 - 14:00 3.50 CEMT P PROD1 Held PJSM. Line up Dowell & pump 5 bbl CW 100. Test cement line to 3500 psi. Pump another 5 bbl CW 100 + 30 bbls MudPush II @ 10.3 ppg Drop bottom plug. Follow with 78 bbls (364 sxs) Premium 'G' @ 15.8 ppg (Yield = 1.200 ft3/sk). Pumped cement @ 6 bpm. Flush cement lines. Drop Top plug & displace wI seawater @ 6 bpm. Displaced cement with 399 bbl total fluid. FCP = 510 psi. Bumped plug with 3500 psi. CIP @ 13:23 hrs. Bled off surface pressure. Floats held. Monitor well while preparing to RD cement related equipment. Well static. 14:00 - 15:30 1.50 CEMT P PROD1 RID cement head & related equipment. LID 7" Landing Jt wI RT. Blow down surface lines. RID casing equipment. Change elevator bails & install drill pipe elevators. Clear rig floor of excess equipment. 15:30 - 16:30 1.00 WHSUR P PROD1 M/U 7" packoff seals. RIH & set packoff. Test packoff to 5000 Printed: 10/27/2003 11:35:38AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 D~tèFrom"" To Hours Task Gode NPT D~sbriþtion of Oþeratidns 10/16/2003 15:30 - 16:30 16:30 - 17:30 1.00 WHSUR P 1.00 BOPSUR P PROD1 PROD1 17:30 - 21 :00 3.50 BOPSUR P PROD1 21 :00 - 21 :30 0.50 BOPSUR P PROD1 21 :30 - 23:00 COMP 1.50 CLEAN P 23:00 - 00:00 10/17/2003 00:00 - 03:00 03:00 - 04:30 1.00 CLEAN P 3.00 CLEAN P 1.50 CLEAN P COMP COMP COMP 04:30 - 13:30 9.00 CLEAN P COMP 13:30 - 15:00 1.50 BOPSURP COMP 15:00 - 15:30 0.50 EVAL P COMP 15:30 - 16:30 1.00 EVAL P COMP 16:30 - 18:30 2.00 EVAL P COMP 18:30 - 20:30 2.00 EVAL N DFAL COMP 20:30 - 23:30 DFAL COMP 3.00 EVAL N 23:30 - 00:00 10/18/2003 00:00 - 01 :00 DFAL COMP DFAL COMP 0.50 EVAL N 1.00 EVAL N 01 :00 - 02:00 1.00 EVAL N DFAL COMP psi. LlO setting tool. Held PJSM. Change upper rams in BOP from 7" to 3.5" X 6" VBR. MU test plug on 4" DP & land in wellhead. Test BOP's: Test Annular BOP to 250/3500 psi. Test all pipe rams, BlindlShear rams + all surface related equipment to 250/4000 psi. All test were API. Witness of BOP test waived by John Crisp -AOGCC. Pull test plug. Install wear bushing (7" 10). Blow down surface lines. MIU BHA consisting of a 6-1/8" Bit + float sub + XO sub + 12 x 4" HWDP + Jar + 9 x 4" HWDP. Total length = 678.56'. Note: Performed the following while M/U BHA: R/U 9ES mud pump on 9 5/8 X 7' annulus. Test lines to 3500 psi. Bullhead 175 bbls of 9.3 ppg mud down annulus. Start at 1 bbl/min @ 750 psi. - complete at 4 bbl./ min @ 975 psi. R/U hot oiler and test lines to 3500 psi. Bullhead 85 bbls of dead crude down annulus. Max rate 3 bbl/min, max pressure 1000 psi S/I with 850 psi. RID hot oiler & secure wellhead wing valves. TIH with 6-1/8" BHA on 4" drill pipe to 1618'. Continue TIH with 6-1/8" BHA on 4" DP to 10420'. Establish circulation. Pump a 46 bbl HV Seawater sweep. Oisplace well with clean 9.3 ppg brine water. Pump rate 12 bpm with 3530 psi. Rotate & reciprocate drill string while displacing well with 9.3 ppg brine. P/U 200K S/O 86K Rot Wt 117K. Drill string torque = 11000-13000 FtLb. POOH from 10420'. LID all 4" DP, HWOP & Bit. Held PJSM. Pull wearbushing, run test plug. Change upper rams in BOP from 3.5" x 6" VBR to 7" casing rams. Test bonnet seals to 3000 psi. Pull test plug & install wearbushing. SAFETY ---. Held PJSM with Rig Crew & Schlumberger E-line crew regarding rigging up e-line logging equipment, lubricator & the pressure testing of lubricator. R/U Schlumberger e-line sheaves & related equipment. Install 7" lubricator & test to 1 000 psi. RIH with USIT logging tool to 10420'. Attempt to log. No response from USIT tool. POOH. Tool at surface @ 19:30 hrs. Trouble shoot electrical problem. Found that e-line had shorted out inside LEHQ head connector. Cut off 20' of e-line & re-head. Perform surface checks on same-OK. RIH with USIT logging tool to 6000'. No response from tool @ this depth. POOH. Change out USIT tool. Trouble shoot problem with e-line. Found that the e-line had once again shorted out inside the LEHQ Head Connector. Cut off 200' of e-line & re-head same. Perform surface checks on e-line-OK. Connect e-line to USIT tool & power up. USIT tool working at surface. RIH with USIT logging tool (Run #3). SWS continue RIH with USIT log (Run #3) to 10420'. When starting to log up with the USIT, the tool failed. POOH with e-line. LID USIT tool. Printed: 10/27/2003 11 :35:38 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES pate Fr()h1.-",.To, Hours'· Task Code NPT >Phase 10/18/2003 02:00 - 02:30 0.50 EVAL N DFAL COMP 02:30 - 03:30 1.00 EVAL P COMP 03:30 - 04:00 0.50 EVAL N DFAL COMP 04:00 - 06:30 2.50 EVAL N DFAL COMP 06:30 - 08:00 1.50 EVAL N DFAL COMP 08:00 - 10:30 2.50 EVAL P COMP 10:30 - 11 :30 1.00 EVAL P COMP 11 :30 - 12:00 0.50 EVAL P COMP 12:00 - 20:30 8.50 EVAL P COMP 20:30 - 00:00 3.50 EVAL P COMP 10/19/2003 00:00 - 03:30 3.50 EVAL P COMP 03:30 - 05:00 1.50 BOPSUR P COMP 05:00 - 06:30 1.50 RUNCOMP COMP 06:30 - 07:00 0.50 RUNCOMP COMP 07:00 - 08:00 1.00 RUNCOMP COMP Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 , DèsctiptiQP· ë>fOþeratidns RIO SWS e-line equipment & lubricator (The plan is to swap out e-line units). R/U & test 7" casing to 4000 psi for 30 minutes while waiting on another Schlumberger e-line truck. Casing test was API. Spot another e-line truck & related equipment in front of Beaver Slide. R/U e-line through sheaves. R/U lubricator. SWS re-head LEHQ logging head & rope socket on e-line. Perform surface checks on equipment. Test lubricator to 1 000 psi. RIH with USIT logging tool to 10420'. Log up with USIT from 10420' to 6800' (TOC @ 6850'). POOH. LID US IT logging tool. Crew change SWS e-line crew. Re-head LEHQ logging head rope socket. SAFETY ---. Held PJSM with Rig Crew & SWS E-line crew regarding perforating operations. M/U Perf Guns for run #1. (20' of 4-1/2" HSD PowerJet charge guns @ 5 spf). RIH. Log on depth. Perforate 7" casing (Obc sand zone) FI 9880'-9860'. Monitor well after firing guns. Well static. POOH. Had 100% detonation on perf guns. LID spent perf guns. MIU Perf Guns (20' Perf Guns) for run #2. RIH. Log on depth. Peforate 7" casing (Obc sand zone) FI 9848'-9828'. Monitor well after firing guns. Well static. POOH. Had 100% detonation. LID spent guns. M/U Perf Guns for run #3. (30' perf guns). RIH. Log on depth. Perforate 7" casing (Oba sand zone) FI 9?05'-9675'. Monitor well after firing guns. Well static. POOH. Had 100% detonation on perf guns. LID spent perf guns. SWS M/U Junk Basket with 6.100" gauge ring. RIH to 10200' with no problems. POOH. Recovered a significant amount (about one gallon) of debris from Junk Basket. RIH with Junk Basket (Run #2) to 10200'. POOH. POOH from 10200' with Junk Basket (Run #2). Recovered a substantial amount of debris from Junk Basket. RIH with Junk Basket (Run #3) to 10200'. POOH. RIO SWS e-line & related equipment. Held PJSM. Pull wearbushing. Run & set BOP test plug. Change out upper rams from 7" casing rams to 3.5" x 6" VBR. Test bonnet seals to 3500 psi. Pull test plug. Make dummy run with tubing hanger. R/U to run 3.5" x 4.5" completion string. Change out elevator bails. R/U Nabors tubing running & Torque-Turn equipment. Held PJSM with Rig Crew, Schlumberger TCP & Nabors Tubing Tong Service Rep regarding picking up TCP guns & tubing running operations. MIU Schlumberger SXAR Gun Drop assembly consisting of 5 each 4-1/2" HSD PowerJet 4505 HMX 38.8 5 spf @ 72 deg phasing + 1 each Blank Gun (Safety Spacer) + Auto-release SXAR + TCF Firing Head + Debris Sub. Total length = 127.91'. Printed: 10/27/2003 11:35:38 AM COMP Change over to run 3.5" tubing. RIH with 3.5" Tail-pipe & X-nipple assembly + 3.5" 9.3# L-80 TCII tubing with Baker 7" Stratle Packers & GLM (4each) assemblies (Packers spaced out to be set @ 9889' & 9723').Totallength = 398.71'. COMP Change over to run 4.5" tubing. Continue RIH to 10054' with the SXAR Gun Drop assembly + 3.5" tubing wI 7" Stradle Packer assemblies (Packers spaced out to be set @ 9889',9723' & Top Packer @ 9520') on 4.5" 12.6# L-80 TC-II production tubing @ 1 minute/Jt. Avg M/U torque on 4.5" tubing = 2700 FtlLb using Jet-Lube Seal Guard pipe dope. COMP Tubing hanger landed placing bottom of production string assembly @ 10054.86' DPM. NOTE: Top connection on tubing hager is 4-1/2" TCII. Held PJSM with Drill Crew & SWS e-line crew. COMP R/U e-line equipment & lubricator. COMP SWS RIH with PBMS (GR-CCL) tool to 9820'. Run correlation pass from 9820' to 9300'. POOH. Correlation log indicates that the tubing string needs to be moved down +1- 8' to place TCP guns on depth for perforating 7" casing @ 9954'-10054'. COMP POOH. RID Lubricator & e-line equipment. COMP Pull tubing hanger to rig floor. Install a 4.5" 12.6# L-80 TCII x 7.80' pup joint in string. Land tubing hanger in wellhead. Run in Lock Down screws. Note: Bottom of production string assembly @ 10062.66' DPM. COMP Rig up to reverse circulate. Reverse circulate down 7" annulus & up tubing string with 160 bbl of clean 9.3 ppg NaCI followed by 176 bbls of 9.3 ppg corrosion inhibited brine @ 3 bpm wI 350 psi. COMP RID tubing pump-in sub. Drop Ball-rod wI rollers & allow to gravitate on seat while LID the Tubing Landing Jt. COMP Pressure up on tubing to 2800 psi to set lower "S-3" packer. Continue pressuring tubing to 4200 psi to set the two "Premier" packers. Hold test for 30 minutes. Test was API. Manually bled off tubing pressure to 2500 psi. Pressure up 4.5 x 7" annulus to 4000 psi. Hold test for 30 minutes. Test was API. Manually bled off pressure on both tubing & annulus to 0 psi. Pressure up 4.5" x 7" annulus to 3000 psi & sheared DCK valve in the GLM @ 5174'. Manually bled off pressure to 0 psi on tubing & annulus. Pump out BOP. FMC install TWCV. Test TWCV from below to 1000 psi-OK. PJSM. NID BOP's. Set back & secure. N/U FMC 11" 5K x 4-1/16" 5K Tubing head adapter & 4-1/16" 5K Production Tree. Test tubing head adapter & tree to 5000 psi. R/U DSM lubricator & pull TWCV. Held PJSM with Rig Crew & Little Red Hot Oil Service rep regarding freeze protecting operations. R/U Hot Oil & test lines to 3000 psi. Freeze protect 4.5" x 7" annulus. Reverse circulate 105 bbl of diesel down 4.5" x 7" annulus @ 3.5 bpm with 2300 psi. Let well U-Tube & equalize. COMP DSM install BPV in Tubing Hanger. Test to 1000 psi. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Date From-TÖHours, T~.$k Code NPT Phase 10/19/2003 08:00 - 09:00 1.00 RUNCOrvP 09:00 - 00:00 15.00 RUNCOrvP 10/20/2003 00:00 - 00:30 0.50 RUNCOrvP 00:30 - 01 :00 01 :00 - 02:30 0.50 RUNCOrvP 1.50 RUNCOrvP 02:30 - 04:00 04:00 - 05:00 1.50 RUNCOrvP 1.00 RUNCOrvP 05:00 - 07:00 2.00 RUNCOrvP 07:00 - 07:30 0.50 RUNCOrvP 07:30 - 09:30 2.00 RUNCOrvP 09:30 - 10:00 0.50 WHSUR P COMP 10:00 - 11 :30 1.50 BOPSUR P COMP 11:30-13:00 1.50 WHSUR P COMP 13:00 - 14:00 1.00 WHSUR P COMP 14:00 - 16:30 2.50 WHSUR P COMP 16:30 - 17:30 1.00 WHSUR P Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 Descriptioh ófOpëré!tións Printed: 10/27/2003 11 :35:38 AM B'þ Qperatiøl'1$·. ,Surtlrnélry.. '~eport, Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-209i W-209i DRILL +COMPLETE NABORS ALASKA DRILLING I NABORS 9ES Start: 9/23/2003 Rig Release: 10/20/2003 Rig Number: 9 Spud Date: 9/22/2003 End: 10/20/2003 Date From -1"0 ,Hours Task ",CodEr 1 0/20/2003 17:30 - 19:00 1.50 WHSUR P COMP RID Hoil Oil line & DSM. Secure well & clean up cellar area. Release Rig 9ES from W-209i @ 19:00 Hrs on October 20, 2003. Printed: 10/27/2003 11.35:38 AM ) ) Well: Field: API: Permit: Date W -209i Prudhoe Bay Unit 50-029-23170-00 203-128 Accept: Spud: Release: Rig: 09/23/03 09/23/03 1 0120103 Nabors 9ES POST RIG WORK 11/13/03 SPOT EQUIP. TGSM. START RIH WI 2.63 CENT & 2" RB TO PULL B & R. JOB IN PROGRESS. 11/14/03 PULLED B & R FROM RHC PLUG BODY @ 99011 SLM PULLED ST A #5 (BEK- DCK SHEAR VL V) SET STA #5 (BK-DGLV) PULLED RHC PLUG BODY DRIFTED TO FIRING HEAD WI 2.25 LIB RAN FIRING HEAD ASSEMBLY (2.7 CENT, 2" SS, 1.5" X 51 STEM, SWS FIRING HEAD) GOOD INDICATION FIRING TEST BOTTOM PACKER TO 2000# (GOOD TEST). MAKE DRIFT RUN WI LIB, SD @ 98101 SLM (STA#2) RECONFIGURED LIB, FOUND GUNS FELL DOWN HOLE TO 10,3001 SLM RUNNING SBHP @ TIME OF REPORT SET SWS FIRING HEAD WI 511 1/2" STEM (122" OAL 1 3/8" FN). FISH LEFT IN HOLE (511 1/2" STEM, SWS FIRING HEAD & 901 OF PERF GUNS OAL 1001). JOB IN PROGRESS. 11/15/03 PERFORM SBHP WI TANDEM PETRADAT GAUGES. PUMP TRUCK UNAVAILABLE TO COMPLETE JOB, RDMO. (LEFT WELL SI) T 11/0= 250/220/80. INJECTIVITY TEST = 5.5 BPM @ 2450 PSI. PUMPED 40 BBLS OF 50/50 MEOH, 291 BBLS OF SEA WATER AND 40 BBLS OF 50/50 MEOH FREEZE PROTECTION DOWN THE TUBING. STANDBY WHILE SLICK-LINE PULLS VALVES. RIG UP SLU, ATTEMPT TO SET CATCHER SUB. 11/16/03 SET CATCHER SUB PULLED DGLV'S FROM STA #1 & #3 SET RKFS IN STA #1 & #3 PULL CATCHER TURN WELL OVER TO DSO. T/I/O= 175/400/100, SLICK-LINE ENCOUNTERING POSSIBLE ICE PLUG, PUMP 65 BBLS 50/50 MEOH DOWN TBG, RIG DOWN TO RELOAD WI 150 BBLS NEAT. RIG UP STANDBY FOR SLlCKLlNE. PUMP AS INSTRUCTED TON ASSIST SLlCKLlNE. FINAL T/I/O= 420/160/80. 11/22/03 TIIIO = 1120/160/180. TEMP = 100*. IA FL @ SURFACE. (PRE AOGCC MIT - IA). 11/24/03 TIIIO = 178011810/320. MIT - IA TO 2500 PSI PASSED. (AOGCC STATE WITNESS, CHUCK SCHEVE). PRESSURED IA TO 2500 PSI WITH 2.5 BBLS OF METHANOL. STARTED 30 MIN TEST. IA LOST 0 PSI IN 30 MIN. lAP INCREASED 80 PSI IN THE 1 ST 15 MIN AND INCREASED ANOTHER 60 PSI IN THE 2ND 15 MIN. BLED IA TO 300 PSI. FINAL WHplS = 1780/3001200. 11/25/03 T/I/O=510NAC/130. TEMP=SI. MONITOR WHP'S (POST MITIA). lAP WENT TO A VAC DUE TO WELL BEING SHUT IN. SCHLUMBERGER Survey report Client...................: BP Exploration (AK) Inc. Field. . . . . . . . . . . . . . . . . . . .: Polaris Well. . . . . . . . . . . . . . . . . . . . .: W-209i API number...............: 50-029-23170-00 Engineer. . . . . . . . . . . . . . . . .: Silvia Roblero Rig: . . . . . . . . . . . . . . . . . . . . .: 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.......: 51.90 ft KB above permanent.......: N/A - Top Drive DF above permanent.......: 80.40 ft ----- Vertical section origin---------------- La tit ude ( + N / S -) . . . . . . . . . : 0 . 00 f t Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- La tit ude ( + N / S -) . . . . . . . . . : - 999 . 25 f t Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 92.80 degrees [(c)2003 IDEAL ID8 1C_01J 14-0ct-2003 19:34:05 Spud date................: Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 23-Sept-2003 14-0ct-03 116 0.00 ft 10545.00 ft ~ ----- Geomagnetic data ---------------------- Magnetic model.. .........: BGGM version 2002 Magnetic date............: 23-Sep-2003 Magnetic field strength..: 1150.56 HCNT Magnetic dec (+E/W-).....: 25.32 degrees Magnetic dip.............: 80.78 degrees ----- MWD survey Reference Reference G..............: Reference H. . . . . . . . . . . . . . : Reference Dip............: Tolerance of G...........: Tolerance of H... ........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1150.56 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-) .....: 25.32 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-).. ..: 25.32 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction '~ SCHLUMBERGER Survey Report 14-0ct-2003 19:34:05 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- Seq Measured # depth (ft) Incl angle (deg) Azimuth angle (deg) Course length (ft) TVD depth (ft) Vertical section (ft) Displ +N/S- (ft) Disp1 +E/W- (ft) Total displ (ft) At Azim (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- -------- ------ ------- ------ -------- -------- ---------------- --------------- 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 1 2 3 4 5 0.00 197.46 291.79 383.29 475.20 0.00 0.70 2.23 5.32 8.95 13.07 17.40 21.89 25.05 28.12 30.70 32.97 37.21 40.21 39.93 40.21 43.23 45.87 45.83 45.46 45.26 44.42 47.22 50.45 56.69 59.75 62.46 63.03 63.15 65.28 0.00 46.02 77.52 87.95 88.38 89.55 90.42 92.46 94.25 96.53 97.00 96.66 94.65 93.92 93.52 97.34 100.19 99.33 98.90 99.46 99.29 99.89 100.91 101.68 100.59 98.80 95.51 96.13 95.60 95.54 [(c)2003 IDEAL ID8 1C_01J 567.66 659.85 752.41 845.02 939.08 1032.45 1126.09 1220.13 1313.07 1331.48 1425.91 1519.52 1612.72 1708.40 1804.09 1826.34 1895.55 1991.11 2086.28 2180.75 2275.56 2370.73 2465.48 2558.69 2653.51 0.00 197.46 94.33 91.50 91.91 92.46 92.19 92.56 92.61 94.06 93.37 93.64 94.04 92.94 18.41 94.43 93.61 93.20 95.68 95.69 22.25 69.21 95.56 95.17 94.47 94.81 95.17 94.75 93.21 94.82 0.00 197.46 291.75 383.04 474.23 564.97 653.89 741.05 825.98 910.09 991.42 1070.97 1147.90 1220.42 1234.51 1306.78 1376.65 1443.06 1509.71 1576.61 1592.24 1641.32 1707.91 1770.54 1826.62 1876.55 1922.54 1965.93 2008.12 2049.36 0.00 0.83 2.99 8.94 20.31 37.93 62.12 93.22 130.09 172.13 217.86 267.13 321.11 379.20 391.05 451.75 513.69 578.58 646.82 714.81 730.54 779.00 846.92 917.77 992.94 1072.94 1156.00 1240.11 1323.11 1408.38 0.00 0.84 1.63 2.17 2.53 2.81 2.79 1.95 -0.25 -4.24 -9.65 -15.52 -20.79 -25.13 -25.89 -31.65 -41.18 -52.26 -63.13 -74.05 -76.63 -84.75 -97.14 -111.18 -125.82 -139.37 -149.72 -158.26 -166.75 -175.04 0.00 0.87 3.07 9.05 20.46 38.11 62.33 93.43 130.24 172.13 217.65 266.69 320.48 378.43 390.26 450.74 512.29 576.72 644.50 712.05 727.67 775.79 843.18 913.42 ·987.97 1067.40 1150.06 1233.85 1316.53 1401.50 0.00 1.21 3.48 9.31 20.62 38.22 62.39 93.45 130.24 172.18 217.87 267.14 321.15 379.26 391.11 451.85 513.94 579.08 647.59 715.89 731.69 780.40 848.76 920.17 995.95 1076.46 1159.76 1243.96 1327.05 1412.39 0.00 46.02 62.01 76.52 82.96 85.78 87.44 88.80 90.11 91.41 92.54 93.33 93.71 93.80 93.80 94.02 94.60 95.18 95.59 95.94 96.01 96.23 96.57 96.94 97.26 97.44 97.42 97.31 97.22 97.12 DLS (deg/ 100f) 0.00 0.35 1.77 3.45 3.95 4.46 4.70 4.91 3.50 3.44 2.77 2.43 4.67 3.27 2.07 2.62 3.81 2.91 0.33 0.57 1.05 1.36 3.03 3.45 6.67 3.60 4.16 0.84 0.52 2.25 ------ ------ Srvy Tool tool Corr type (deg) ------ ------ TIP None MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA - MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD I FR MSA MWD IFR MSA MWD IFR MSA INC TREND MWD IFR MSA MWD I FR MSA MWD IFR MSA -~ MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA MWD IFR MSA SCHLUMBERGER Survey Report 14-0ct-2003 19:34:05 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2747.55 63.42 95.67 94.04 2090.06 1493.05 -183.32 1485.87 1497.13 97.03 1.98 MWD IFR MSA - 32 2843.23 65.14 96.11 95.68 2131.59 1579.12 -192.16 1571.61 1583.31 96.97 1.84 MWD IFR MSA 33 2937.98 64.75 95.66 94.75 2171.71 1664.83 -200.97 1656.99 1669.13 96.92 0.60 MWD IFR MSA - 34 3030.30 65.75 95.10 92.32 2210.36 1748.58 -208.82 1740.46 1752.94 96.84 1.22 MWD IFR MSA - 35 3123.88 65.32 91.46 93.58 2249.13 1833.74 -213.70 1825.48 1837.94 96.68 3.57 MWD IFR MSA 36 3218.52 65.19 90.86 94.64 2288.74 1919.65 -215.44 1911.41 1923.51 96.43 0.59 MWD IFR MSA - 37 3312.29 65.22 91.03 93.77 2328.07 2004.73 -216.85 1996.52 2008.27 96.20 0.17 MWD IFR MSA - .~ 38 3407.87 65.19 90.68 95.58 2368.15 2091.45 -218.14 2083.28 2094.67 95.98 0.33 MWD IFR MSA 39 3502.10 65.41 90.42 94.23 2407.53 2177.00 -218.96 2168.89 2179.91 95.76 0.34 MWD IFR MSA - 40 3596.32 64.84 90.10 94.22 2447.16 2262.39 -219.35 2254.37 2265.01 95.56 0.68 MWD IFR MSA 41 3691.75 65.70 90.35 95.43 2487.08 2348.98 -219.69 2341.04 2351.33 95.36 0.93 MWD IFR MSA - 42 3787.56 65.81 90.14 95.81 2526.42 2436.25 -220.06 2428.40 2438.35 95.18 0.23 MWD IFR MSA - 43 3881.59 64.36 90.58 94.03 2566.04 2521.45 -220.60 2513.68 2523.34 95.02 1.60 MWD IFR MSA - 44 3975.53 63.93 90.52 93.94 2607.00 2605.92 -221.41 2598.21 2607.63 94.87 0.46 MWD IFR MSA - 45 4070.09 63.54 90.37 94.56 2648.85 2690.65 -222.07 2683.00 2692.18 94.73 0.44 MWD IFR MSA 46 4126.34 64.11 90.75 56.25 2673.66 2741.09 -222.56 2733.48 2742.53 94.65 1.18 MWD IFR MSA - 47 4205.00 64.53 91.10 78.66 2707.75 2811.94 -223.71 2804.36 2813.27 94.56 0.67 INC TREND 48 4298.97 63.88 91.51 93.97 2748.64 2896.52 -225.63 2888.95 2897.74 94.47 0.80 MWD IFR MSA - 49 4394.06 65.21 91.64 95.09 2789.51 2982.36 -227.99 2974.77 2983.50 94.38 1.40 MWD IFR MSA - 50 4487.26 66.01 90.89 93.20 2827.99 3067.21 -229.87 3059.63 3068.25 94.30 1.13 MWD IFR MSA 51 4582.00 65.98 90.78 94.74 2866.54 3153.70 -231.13 3146.17 3154.65 94.20 0.11 MWD IFR MSA - 52 4675.61 64.28 90.27 93.61 2905.90 3238.56 -231.91 3231.09 3239.40 94.11 1.88 MWD IFR MSA ~ - 53 4769.08 64.80 90.92 93.47 2946.08 3322.89 -232.79 3315.48 3323.64 94.02 0.84 MWD IFR MSA - 54 4862.93 64.42 90.20 93.85 2986.33 3407.61 -233.62 3400.26 3408.27 93.93 0.80 MWD IFR MSA - 55 4956.45 63.63 90.58 93.52 3027.28 3491.61 -234.19 3484.33 3492.19 93.85 0.92 MWD IFR MSA 56 5049.52 64.23 91.94 93.07 3068.19 3575.18 -236.03 3567.91 3575.70 93.78 1.46 MWD IFR MSA 57 5141.65 63.96 91.06 92.13 3108.44 3658.03 -238.20 3650.75 3658.51 93.73 0.91 MWD IFR MSA - 58 5235.07 65.05 92.29 93.42 3148.65 3742.33 -240.67 3735.03 3742.78 93.69 1.67 MWD IFR MSA - 59 5326.72 65.27 92.21 91.65 3187.15 3825.50 -243.93 3818.14 3825.92 93.66 0.25 MWD IFR MSA - 60 5420.03 64.64 92.00 93.31 3226.65 3910.03 -247.04 3902.62 3910.43 93.62 0.71 MWD IFR MSA [(c)2003 IDEAL ID8 1C_01] SCHLUMBERGER Survey Report 14-0ct-2003 19:34:05 Page 4 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 61 5512.91 63.49 91.35 92.88 3267.27 3993.53 -249.48 3986.11 3993.91 93.58 1.39 MWD IFR MSA 62 5607.35 63.44 93.11 94.44 3309.46 4078.02 -252.77 4070.53 4078.37 93.55 1.67 MWD IFR MSA - 63 5701.10 64.01 93.61 93.75 3350.97 4162.08 -257.70 4154.45 4162.43 93.55 0.77 MWD IFR MSA - 64 5793.29 64.20 94.17 92.19 3391.23 4244.99 -263.32 4237.19 4245.36 93.56 0.58 MWD IFR MSA - 65 5887.42 65.57 94.36 94.13 3431.18 4330.20 -269.66 4322.18 4330.59 93.57 1.47 MWD IFR MSA 66 5980.99 65.70 93.46 93.57 3469.78 4415.41 -275.47 4407.22 4415.82 93.58 0.89 MWD IFR MSA - 67 6074.53 65.15 93.73 93.54 3508.68 4500.47 -280.81 4492.12 4500.89 93.58 0.64 MWD IFR MSA - .~ 68 6167.92 64.56 95.13 93.39 3548.37 4584.98 -287.33 4576.40 4585.41 93.59 1.50 MWD IFR MSA - 69 6261.23 64.23 95.01 93.31 3588.69 4669.06 -294.77 4660.22 4669.53 93.62 0.37 MWD IFR MSA - 70 6353.36 64.52 94.56 92.13 3628.54 4752.07 -301.70 4743.00 4752.58 93.64 0.54 MWD IFR MSA 71 6446.56 63.95 94.41 93.20 3669.05 4835.97 -308.26 4826.68 4836.51 93.65 0.63 MWD IFR MSA - 72 6539.64 64.20 93.84 93.08 3709.74 4919.66 -314.28 4910.17 4920.22 93.66 0.61 MWD IFR MSA - 73 6633.83 65.37 93.80 94.19 3749.87 5004.86 -319.96 4995.20 5005.43 93.67 1.24 MWD IFR MSA - 74 6728.04 65.05 93.02 94.21 3789.37 5090.39 -325.05 5080.57 5090.96 93.66 0.82 MWD IFR MSA 75 6822.67 64.16 93.41 94.63 3829.95 5175.87 -329.84 5165.92 5176.44 93.65 1.01 MWD IFR MSA - 76 6915.40 64.99 91.66 92.73 3869.77 5259.61 -333.54 5249.58 5260.17 93.64 1.93 MWD IFR MSA - 77 7006.39 64.80 90.61 90.99 3908.37 5341.97 -335.17 5331.96 5342.49 93.60 1.07 MWD IFR MSA - 78 7100.35 64.73 90.43 93.96 3948.43 5426.90 -335.95 5416.95 5427.36 93.55 0.19 MWD IFR MSA - 79 7192.51 64.77 90.31 92.16 3987.74 5510.17 -336.48 5500.30 5510.59 93.50 0.13 MWD IFR MSA - 80 7285.30 64.20 90.05 92.79 4027.71 5593.83 -336.75 5584.04 5594.19 93.45 0.66 MWD IFR MSA 81 7380.02 63.50 89.44 94.72 4069.46 5678.73 -336.37 5669.07 5679.04 93.40 0.94 MWD IFR MSA - 82 7473.08 63.66 89.94 93.06 4110.87 5761.95 -335.92 5752.41 5762.21 93.34 0.51 MWD IFR MSA ~.-- - 83 7566.49 63.51 90.51 93.41 4152.42 5845.52 -336.25 5836.06 5845.74 93.30 0.57 MWD IFR MSA - 84 7659.99 63.04 92.01 93.50 4194.47 5929.00 -338.08 5919.55 5929.20 93.27 1.52 MWD IFR MSA - 85 7753.29 63.15 91.36 93.30 4236.69 6012.18 -340.53 6002.71 6012.37 93.25 0.63 MWD IFR MSA 86 7847.15 62.55 91.06 93.86 4279.52 6095.67 -342.29 6086.21 6095.83 93.22 0.70 MWD IFR MSA 87 7940.98 62.09 90.40 93.83 4323.11 6178.70 -343.35 6169.30 6178.84 93.19 0.79 MWD IFR MSA - 88 8032.93 61.86 91.47 91.95 4366.31 6259.83 -344.68 6250.45 6259.95 93.16 1.06 MWD IFR MSA - 89 8125.52 62.29 92.96 92.59 4409.68 6341.63 -347.84 6332.20 6341.74 93.14 1.50 MWD IFR MSA - 90 8218.88 62.22 92.14 93.36 4453.14 6424.25 -351.52 6414.74 6424.36 93.14 0.78 MWD IFR MSA [(c)2003 IDEAL ID8 1C_01] SCHLUMBERGER Survey Report 14-0ct-2003 19:34:05 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8312.62 61.76 91.31 93.74 4497.16 6507.00 -354.01 6497.46 6507.10 93.12 0.92 MWD IFR MSA 92 8405.17 62.52 91.56 92.55 4540.41 6588.80 -356.06 6579.26 6588.89 93.10 0.86 MWD IFR MSA - 93 8498.21 62.03 90.43 93.04 4583.70 6671.11 -357.49 6661.60 6671.19 93.07 1.20 MWD IFR MSA - 94 8592.13 62.39 91.34 93.92 4627.49 6754.15 -358.77 6744.68 6754.21 93.04 0.94 MWD IFR MSA 95 8686.01 62.35 92.69 93.88 4671.03 6837.31 -361.70 6827.80 6837.37 93.03 1.27 MWD IFR MSA - 96 8779.00 62.17 92.35 92.99 4714.31 6919.62 -365.32 6910.02 6919.67 93.03 0.38 MWD IFR MSA - 97 8872.69 62.13 91.72 93.69 4758.08 7002.45 -368.26 6992.81 7002.50 93.01 0.60 MWD IFR MSA 8966.39 62.28 91.14 93.70 4801.77 7085.31 -370.33 7075.67 7085.35 93.00 0.57 MWD IFR MSA .~ 98 - 99 9059.84 61.56 92.27 93.45 4845.76 7167.74 -372.78 7158.08 7167.78 92.98 1.32 MWD IFR MSA - 100 9153.95 61.09 91.97 94.11 4890.92 7250.31 -375.83 7240.59 7250.34 92.97 0.57 MWD IFR MSA 101 9248.35 61.39 91.69 94.40 4936.34 7333.05 -378.48 7323.30 7333.08 92.96 0.41 MWD IFR MSA - 102 9341.22 61.98 90.58 92.87 4980.39 7414.77 -380.09 7405.04 7414.79 92.94 1.23 MWD IFR MSA - 103 9433.83 62.26 90.66 92.61 5023.69 7496.57 -380.98 7486.90 7496.59 92.91 0.31 MWD IFR MSA - 104 9526.97 61.88 90.36 93.14 5067.32 7578.80 -381.71 7569.19 7578.80 92.89 0.50 MWD IFR MSA 105 9620.28 61.78 89.77 93.31 5111.37 7660.96 -381.80 7651.44 7660.96 92.86 0.57 MWD IFR MSA 106 9714.99 61.29 88.69 94.71 5156.51 7744.06 -380.69 7734.69 7744.06 92.82 1.13 MWD IFR MSA - 107 9808.04 61.06 88.80 93.05 5201.38 7825.37 -378.90 7816.20 7825.37 92.78 0.27 MWD IFR MSA 108 9902.34 61.62 88.90 94.30 5246.60 7907.92 -377.24 7898.92 7907.93 92.73 0.60 MWD IFR MSA - 109 9995.26 61.29 89.11 92.92 5291.00 7989.37 -375.82 7980.54 7989.38 92.70 0.41 MWD IFR MSA 110 10089.29 61.39 89.06 94.03 5336.10 8071.70 -374.51 8063.04 8071.73 92.66 0.12 MWD IFR MSA 111 10182.63 61.47 89.66 93.34 5380.74 8153.53 -373.59 8145.00 8153.57 92.63 0.57 MWD IFR MSA - 112 10276.78 61.62 89.60 94.15 5425.60 8236.18 -373.06 8227.78 8236.23 92.60 0.17 MWD IFR MSA ..~ - 113 10369.25 61.53 89.52 92.47 5469.62 8317.37 -372.43 8309.10 8317.44 92.57 0.12 MWD IFR MSA - 114 10462.01 61.46 88.96 92.76 5513.89 8398.73 -371.35 8390.61 8398.82 92.53 0.54 MWD IFR MSA - 115 10472.41 61.45 89.04 10.40 5518.85 8407.85 -371.19 8399.74 8407.94 92.53 0.68 MWD IFR MSA - 116 10545.00 61.45 89.04 72.59 5553.55 8471.47 -370.12 8463.50 8471.58 92.50 0.00 Projected to TD [(c)2003 IDEAL ID8 1C 01] - bp W-209 Survey Report Sch- Umb8PD8P Report Date: 14-0ct-03 Survey I OLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 92.800" Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: W·PAD 1 W-209 TVO Reference Datum: KB Well: W-209 TVO Reference Elevation: 80.40 It relative to MSL Borehole: W-209 Sea Bed I Ground Level Elevation: 51.90 ft relative to MSL UWI/API#: 500292317000 Magnetic Declination: 25.312° Survey Name I Date: W-2091 October 14, 2003 Total Field Strength: 57553.547 nT Tort I AHO I 0011 ERO ratio: 142.617° 18483.05 It 16.361/1.528 Magnetic Dip: 80.807° Grid Coordinate System: NA027 Alaska State Planes, Zone 04, US Feet Declination Date: October 09, 2003 Location LaULong: N 70.29728775, W 149.09262235 Magnetic Declination Model: BGGM 2003 Location Grid N/E YIX: N 5959130.050 ftUS, E 612048.860 flUS North Reference: True North Grid Convergence Angle: +0.85426299° Total Carr Mag North -> True North: +25.312° Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head ,.~ Measured Course TVD Sub-Sea TVD Vertical NS EW Closure Closure DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Inclination Azimuth Length Section Azimuth (II) (deg) (deg) ( II) ( ft ) ( ft) ( ft) ( ft) ( ft) (ft ) (deg) ( deg/100 ft) ( deg/l 00 ft ) ( deg/1 00 ft ) (flUS) ( ftUS ) 0.00 0.00 0.00 0.00 0.00 -80.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5959130.05 612048.86 N 70.29728775 W 149.09262235 197.46 0.70 46.02 197.46 197.46 117.06 0.83 0.84 0.87 1.21 46.02 0.35 0.35 0.00 5959130.90 612049.72 N 70.29729004 W 149.09261532 291 .79 2.23 77.52 94.33 291.75 211.35 2.99 1.63 3.07 3.48 62.01 1.77 1.62 33.39 5959131.73 612051.91 N 70.29729222 W 149.09259745 383.29 5.32 87.95 91.50 383.04 302.64 8.94 2.17 9.05 9.31 76.52 3.45 3.38 11.40 5959132.36 612057.88 N 70.29729368 W 149.09254904 475.20 8.95 88.38 91.91 474.23 393.83 20.31 2.53 20.46 20.62 82.96 3.95 3.95 0.47 5959132.88 612069.28 N 70.29729465 W 149.09245667 567.66 13.07 89.55 92.46 564.97 484.57 37.93 2.81 38.11 38.22 85.78 4.46 4.46 1.27 5959133.43 612086.92 N 70.29729543 W 149.09231375 659.85 17.40 90.42 92.19 653.89 573.49 62.12 2.79 62.33 62.39 87.44 4.70 4.70 0.94 5959133.77 612111.14 N 70.29729538 W 149.09211764 752.41 21.89 92.46 92.56 741.05 660.65 93.22 1.95 93.43 93.45 88.80 4.91 4.85 2.20 5959133.39 612142.24 N 70.29729308 W 149.09186588 845.02 25.05 94.25 92.61 825.98 745.58 130.09 -0.25 130.24 130.24 90.11 3.50 3.41 1.93 5959131.75 612179.07 N 70.29728708 W 149.09156783 939.08 28.12 96.53 94.06 910.09 829.69 172.1 ~ -4.24 172.13 172.18 91.41 3.44 3.26 2.42 5959128.37 612221.02 N 70.29727616 W 149.09122864 1032.45 30.70 97.00 93.37 991.42 911.02 217.86 -9.65 217.65 217.87 92.54 2.77 2.76 0.50 5959123.65 612266.61 N 70.29726138 W 149.09086002 1126.09 32.97 96.66 93.64 1070.97 990.57 267.13 -15.52 266.69 267.14 93.33 2.43 2.42 -0.36 5959118.51 612315.73 N 70.29724534 W 149.09046295 1220.13 37.21 94.65 94.04 1147.90 1067.50 321.11 -20.79 320.48 321 .15 93.71 4.67 4.51 -2.14 5959114.04 612369.58 N 70.29723092 W 149.\ '747 1313.07 40.21 93.92 92.94 1220.42 1140.02 379.20 -25.13 378.43 379.26 93.80 3.27 3.23 -0.79 5959110.57 612427.59 N 70.29721909 W 149.L,_,J823 1331.48 39.93 93.52 18.41 1234.51 1154.11 391.05 -25.89 390.26 391.11 93.80 2.07 -1.52 -2.17 5959109.98 612439.42 N 70.29721698 W 149.08946247 1425.91 40.21 97.34 94.43 1306.78 1226.38 451.75 -31.65 450.74 451.85 94.02 2.62 0.30 4.05 5959105.13 612499.99 N 70.29720125 W 149.08897270 1519.52 43.23 100.19 93.61 1376.65 1296.25 513.69 -41 . 1 8 512.29 513.94 94.60 3.81 3.23 3.04 5959096.51 612561.66 N 70.29717519 W 149.08847441 1612.72 45.87 99.33 93.20 1443.06 1362.66 578.58 -52.26 576.72 579.08 95.18 2.91 2.83 -0.92 5959086.40 612626.24 N 70.29714493 W 149.08795272 1708.40 45.83 98.90 95.68 1509.71 1429.31 646.82 -63.13 644.50 647.59 95.59 0.33 -0.04 -0.45 5959076.54 612694.18 N 70.29711520 W 149.08740388 1804.09 45.46 99.46 95.69 1576.61 1496.21 714.81 -74.05 712.05 715.89 95.94 0.57 -0.39 0.59 5959066.63 612761.87 N 70.29708537 W 149.08685699 1826.34 45.26 99.29 22.25 1592.24 1511.84 730.54 -76.63 727.67 731.69 96.01 1.05 -0.90 -0.76 5959064.29 612777.52 N 70.29707832 W 149.08673052 1895.55 44.42 99,89 69.21 1641,32 1560.92 779.00 -84,75 775.79 780.40 96.23 1.36 -1.21 0.87 5959056.88 612825.75 N 70.29705610 W 149.08634091 1991 .11 47.22 1 00.91 95.56 1707.91 1627.51 846.92 -97.14 843.18 848.76 96.57 3.03 2.93 1.07 5959045.50 612893.32 N 70.29702225 W 149.08579524 2086.28 50.45 101.68 95.17 1770.54 1690.14 917.77 -111.18 913.42 920.17 96.94 3.45 3.39 0.81 5959032.51 612963.76 N 70.29698387 W 149.08522649 2180.75 56.69 100.59 94.47 1826.62 1746.22 992.94 -125.82 987.97 995.95 97.26 6.67 6.61 -1.15 5959018.98 613038.51 N 70.29694384 W 149.08462292 SurveyEditor Ver 3.1 RT-SP3.03-HF1.2 Bld( do31 rt-546 ) W -209\W -209\W -209\W -209 Generated 10/24/2003 4: 19 PM Page 1 of 4 2275.56 59.75 98.80 94.81 1876.55 1796.15 1072.94 -139.37 1067.40 1076.46 97.44 3.60 3.23 -1.89 5959006.62 613118.13 N 70.29690679 W 149.08397978 2370.73 62.46 95.51 95.17 1922.54 1842.14 1156.00 -149.72 1150.06 1159.76 97.42 4.16 2.85 -3.46 5958997.51 613200.92 N 70.29687850 W 149.0B331057 2465.48 63.03 96.13 94.75 1965.93 1885.53 1240.11 -158.26 1 233.85 1243.96 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62.29 92.96 92.59 4409.68 4329.28 6341.63 -347.84 6332.20 6341.74 93.14 1.50 0.46 1.61 5958876.68 618384.98 N 70.29633019 W 149.04135320 8218.88 62.22 92.14 93.36 4453.14 4372.74 6424.25 -351.52 6414.74 6424.36 93.14 0.78 -0.07 -0.88 5958874.23 618467.56 N 70.29631996 W 149.04068490 8312.62 61.76 91.31 93.74 4497.16 4416.76 6507.00 -354.01 6497.46 6507.10 93.12 0.92 -0.49 -0.89 5958872.98 618550.31 N 70.29631296 W 149.04001516 8405.17 62.52 91.56 92.55 4540.41 4460.01 6588.80 -356.06 6579.26 6588.88 93.10 0.86 0.82 0.27 5958872.15 618632.12 N 70.29630716 W 149.03935291 8498.21 62.03 90.43 93.04 4583.70 4503.30 6671.11 -357.49 6661.60 6671.19 93.07 1.20 -0.53 -1.21 5958871.94 618714.47 N 70.29630305 W 149.03868622 8592.13 62.39 91.34 93.92 4627.49 4547.09 6754.15 -358.77 6744.68 6754.21 93.04 0.94 0.38 0.97 5958871.90 618797.54 N 70.29629934 W 149.03801360 8686.01 62.35 92.69 93.88 4671.03 4590.63 6837.31 -361.70 6827.80 6837.37 93.03 1.27 -0.04 1.44 5958870.21 618880.69 N 70.29629115 W 149.03734064 8779.00 62.17 92.35 92.99 4714.31 4633.91 6919.62 -365.32 6910.02 6919.67 93.03 0.38 -0.19 -0.37 5958867.82 618962.95 N 70.29628106 W 149.03667494 8872.69 62.13 91.72 93.69 4758.08 4677.68 7002.45 -368.26 6992.80 7002.50 93.01 0.60 -0.04 -0.67 5958866.11 619045.76 N 70.29627281 W 149.03600468 8966.39 62.28 91.14 93.70 4801.77 4721.37 7085.31 -370.33 7075.67 7085.35 93.00 0.57 0.16 -0.62 5958865.28 619128.64 N 70.29626695 W 149.03533380 9059.84 61.56 92.27 93.45 4845.76 4765.36 7167.74 -372.78 7158.08 7167.78 92.98 1.32 -0.77 1.21 5958864.06 619211.07 N 70.29626004 W 149.03466657 9153.95 61.09 91.97 94.11 4890.92 4810.52 7250.30 -375.83 7240.59 7250.34 92.97 0.57 -0.50 -0.32 5958862.23 619293.61 N 70.29625148 W 149.03399854 9248.35 61.39 91.69 94.40 4936.34 4855.94 7333.05 -378.48 7323.30 7333.08 92.96 0.41 0.32 -0.30 5958860.82 619376.35 N 70.29624404 W 149.0 '388 9341.22 61.98 90.58 92.87 4980.39 4899.99 7414.77 -380.09 7405.04 7414.79 92.94 1.23 0.64 -1.20 5958860.43 619458.10 N 70.29623940 W 149.(¡c____-'708 9433.83 62.26 90.66 92.61 5023.69 4943.29 7496.57 -380.98 7486.90 7496.59 92.91 0.31 0.30 0.09 5958860.76 619539.95 N 70.29623676 W 149.03200434 9526.97 61.88 90.36 93.14 5067.32 4986.92 7578.80 -381.71 7569.19 7578.80 92.89 0.50 -0.41 -0.32 5958861.25 619622.23 N 70.29623454 W 149.03133810 9620.28 61.78 89.77 93.31 5111.37 5030.97 7660.96 -381.80 7651.44 7660.96 92.86 0.57 -0.11 -0.63 5958862.39 619704.47 N 70.29623405 W 149.03067210 9714.99 61.29 88.69 94.71 5156.51 5076.11 7744.06 -380.69 7734.69 7744.06 92.82 1.13 -0.52 -1.14 5958864.75 619787.69 N 70.29623687 W 149.02999805 9808.04 61.06 88.80 93.05 5201.38 5120.98 7825.37 -378.90 7816.19 7825.37 92.78 0.27 -0.25 0.12 5958867. 75 619869.15 N 70.29624152 W 149.02933816 9902.34 61.62 88.90 94.30 5246.60 5166.20 7907.92 -377.24 7898.92 7907.93 92.73 0.60 0.59 0.11 5958870.64 619951.84 N 70.29624582 W 149.02866833 9995.26 61.29 89.11 92.92 5291.00 5210.60 7989.37 -375.82 7980.54 7989.38 92.70 0.41 -0.36 0.23 5958873.27 620033.41 N 70.29624946 W 149.02800754 10089.29 61.39 89.06 94.03 5336.10 5255.70 8071.70 -374.51 8063.04 8071.73 92.66 0.12 0.11 -0.05 5958875.82 620115.88 N 70.29625282 W 149.02733957 10182.63 61.47 89.66 93.34 5380.74 5300.34 8153.53 -373.59 8145.00 8153.57 92.63 0.57 0.09 0.64 5958877.96 620197.81 N 70.29625508 W 149.02667590 10276.78 61.62 89.60 94.15 5425.60 5345.20 8236.18 -373.06 8227.78 8236.23 92.60 0.17 0.16 -0.06 5958879.73 620280.56 N 70.29625629 W 149.02600571 10369.25 61.53 89.52 92.47 5469.62 5389.22 8317.37 -372.43 8309.10 8317.44 92.57 0.12 -0.10 -0.09 5958881.56 620361.86 N 70.29625775 W 149.02534730 SurveyEdltor Ver 3.1 RT-SP3.03·HF1.2 Bld( do31 rt-548 ) W -209\ W ·209\ W -209\ W·209 Generated 10/24/20034:19 PM Page 3 of 4 10462.01 10472.41 10545.00 61 .46 61.45 Leqal Description: 61.45 88.96 89.04 89.04 92.76 10.40 5513.89 5518.86 72.59 5553.55 Surface: 4153 FSL 1189 FEL S21 T11 N R12E UM BHL: 3778 FSL 3286 FEL S23 T11 N R12E UM 5433.49 5438.46 5473.15 SurveyEditor Ver 3.1 RT -SP3.03-HF1.2 Bld( d031 11-546 ) 8398.73 8407.84 8471.47 Northinq (Y) fftUSl 5959130.05 5958886.17 -371.35 -371.19 8390.61 8399.74 8398.82 8407.94 -370.12 8463.49 8471.58 EastinQ (X) fftUSl 612048.86 620516.19 92.53 92.53 92.50 W-209\W -209\W-209\W -209 0.54 0.68 0.00 -0.08 -0.10 0.00 -0.60 0.77 5958883.86 5958884.15 0.00 5958886.17 620443.33 620452.46 620516.19 N 70.29626046 W 149.02468736 . N 70.29626087 W 149.02461340 N 70.29626359 W 149.02409720 .~ ~ Generated 10/24/2003 4: 19 PM Page 4 of 4 SCHLUMBERGER Survey report Client...................: BP Exploration (AK) Inc. Fie111. . . . . . . . . . . . . . . . . . . .: Polaris Well T . . . . . . . . . . . . . . . . . . .: W-209i PB1 API.~umber............ ...: 50-029-23170-70 Engl~eer.................: Mark St. Amour I I COUNT¡Y: . . . . . . . . . . . . . . . . . .: Nabors 9ES STATi: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Methqd for DLS...........: Mason & Taylor ! ----- Depth reference ----------------------- ,Permanent datum. ...... ...: Mean Sea Level 'Dept~ reference..........: Driller's Pipe Tally GL a~ove permanent.......: 51.90 ft KB a~ove permanent.......: Top Drive DF a~ove permanent... ....: 80.40 ft : ----- Vertical section origin---------------- ¡Latitude (+N/S-) .........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: Depa~ture (+E/W-)........: I Azim~th from rotary table to ¡ I -999.25 ft -999.25 ft target: 92.80 degrees [(c)2003 IDEAL ID8_1C_01] I 1-0ct-2003 04:58:20 Spud date... .... .... .....: Last survey date..... ....: Total accepted surveys...: MD of first survey.. .....: MD of last survey...... ..: Page 1 of 3 23-Sept-2003 01-Oct-03 46 0.00 ft 4270.00 ft .~/ ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2002 Magnetic date....... .....: 23-Sep-2003 Magnetic field strength..: 1150.56 RCNT Magnetic dec (+E/W-) .....: 25.51 degrees Magnetic dip.... .........: 80.78 degrees ----- MWD survey Reference Reference G.... ...... ....: Reference H.... ... ... ....: Reference Dip............: Tolerance of G....... ....: Tolerance of R.. ..... ....: Tolerance of Dip..... ....: Criteria --------- 1002.68 mGal 1150.56 RCNT 80.78 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).. ...: 25.51 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) ....: 25.51 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction .~ [(c)2003 IDEAL ID8 1C_01] SCHLl~BERGER Survey Report 1-0ct-2003 04:58:20 Page 2 of 3 --- -------- ------ ------- ------ -------- -------- ---------------- --------------- ===== ====== -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Carr (ft) ( deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 197.46 0.70 46.02 197.46 197.46 0.83 0.84 0.87 1.21 46.02 0.35 MWD IFR MSA 3 291.79 2.23 77.52 94.33 291.75 2.99 1.63 3.07 3.48 62.01 1.77 MWD IFR MSA 4 383.29 5.32 87.95 91.50 383.04 8.94 2.17 9.05 9.31 76.52 3.45 MWD IFR MSA 5 475.20 8.95 88.38 91.91 474.23 20.31 2.53 20.46 20.62 82.96 3.95 MWD IFR MSA 6 567.66 13.07 89.55 92.46 564.97 37.93 2.81 38.11 38.22 85.78 4.46 MWD IFR MSA 7 659.85 17.40 90.42 92.19 653.89 62.12 2.79 62.33 62.39 87.44 4.70 MWD IFR MSA 8 752.41 21.89 92.46 92.56 741.05 93.22 1.95 93.43 93.45 88.80 4.91 MWD IFR MSA ,-/ 9 845.02 25.05 94.25 92.61 825.98 130.09 -0.25 130.24 130.24 90.11 3.50 MWD IFR MSA 10 939.08 28.12 96.53 94.06 910.09 172.13 -4.24 172.13 172.18 91.41 3.44 MWD IFR MSA 11 1032.45 30.70 97.00 93.37 991.42 217.86 -9.65 217.65 217.87 92.54 2.77 MWD IFR MSA 12 1126.09 32.97 96.66 93.64 1070.97 267.13 -15.52 266.69 267.14 93.33 2.43 MWD IFR MSA 13 1220.13 37.21 94.65 94.04 1147.90 321.11 -20.79 320.48 321.15 93.71 4.67 MWD IFR MSA 14 1313.07 40.21 93.92 92.94 1220.42 379.20 -25.13 378.43 379.26 93.80 3.27 MWD IFR MSA 15 1406.06 42.54 92.63 92.99 1290.20 440.66 -28.62 439.79 440.72 93.72 2.67 MWD IFR MSA 16 1500.06 45.93 90.72 94.00 1357.54 506.21 -30.50 505.32 506.24 93.45 3.87 MWD IFR MSA 17 1592.32 49.68 90.86 92.26 1419.49 574.50 -31.45 573.65 574.51 93.14 4.07 MWD IFR MSA 18 1685.34 53.16 91.67 93.02 1477.49 647.18 -33.07 646.34 647.19 92.93 3.80 MWD IFR MSA 19 1778.47 53.70 92.06 93.13 1532.98 721.97 -35.50 721.10 721.97 92.82 0.67 MWD IFR MSA 20 1872.86 55.79 93.65 94.39 1587.46 799.04 -39.35 798.07 799.04 92.82 2.61 MWD IFR MSA 21 1964.64 58.00 93.53 91.78 1637.59 875.91 -44.17 874.79 875.91 92.89 2.41 MWD IFR MSA 22 2057.69 58.67 94.29 93.05 1686.44 955.09 -49.57 953.81 955.09 92.97 1.00 MWD IFR MSA ..-- 23 2152.26 59.64 93.56 94.57 1734.92 1036.27 -55.12 1034.81 1036.28 93.05 1.22 MWD IFR MSA 24 2246.06 60.92 93.73 93.80 1781.42 1117.72 -60.30 1116.10 1117.73 93.09 1.37 MWD IFR MSA 25 2339.90 63.62 94.12 93.84 1825.08 1200.75 -65.99 1198.96 1200.78 93.15 2.90 MWD IFR MSA 26 2433.70 64.11 93.73 93.80 1866.40 1284.95 -71.75 1282.97 1284.98 93.20 0.64 MWD IFR MSA 27 2527.15 63.18 92.56 93.45 1907.89 1368.68 -76.35 1366.58 1368.71 93.20 1.50 MWD IFR MSA 28 2620.38 61.60 93.02 93.23 1951.10 1451.29 -80.37 1449.09 1451.32 93.17 1.75 MWD IFR MSA 29 2713.60 63.44 92.56 93.22 1994.11 1533.99 -84.39 1531.69 1534.02 93.15 2.02 MWD IFR MSA 30 2806.18 63.02 92.41 92.58 2035.81 1616.64 -87.98 1614.27 1616.67 93.12 0.48 MWD IFR MSA SCHLl~BERGER Survey Report 1-0ct-2003 04:58:20 Page 3 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - I (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) I -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ----- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ----- ------ 31 2900.11 62.41 92.30 93.93 2078.87 1700.12 -91.41 1697.68 1700.14 93.08 0.66 MWD IFR MSA 32 2993.48 63.15 94.53 93.37 2121.58 1783.14 -96.36 1780.56 1783.16 93.10 2.27 MWD IFR MSA 33 3086.47 62.73 94.44 92.99 2163.88 1865.91 -102.83 1863.11 1865.95 93.16 0.46 MWD IFR MSA 34 3180.29 64.22 93.33 93.82 2205.78 1949.84 -108.52 1946.86 1949.88 93.19 1.91 MWD IFR MSA 35 3274.04 63.59 93.13 93.75 2247.02 2034.03 -113.26 2030.92 2034.08 93.19 0.70 MWD IFR MSA 36 3366.64 63.05 93.19 92.60 2288.60 2116.77 -117.82 2113.53 2116.82 93.19 0.59 MWD IFR MSA 37 3460.41 62.25 93.72 93.77 2331.68 2200.05 -122.84 2196.67 2200.10 93.20 0.99 MWD IFR MSA - - ~ 38 3554.75 63.40 93.05 94.34 2374.76 2283.97 -127.79 2280.45 2284.03 93.21 1.37 MWD IFR MSA 39 3647.94 63.05 92.86 93.19 2416.74 2367.17 -132.08 2363.54 2367.22 93.20 0.42 MWD IFR MSA 40 3740.92 64.45 92.33 92.9.8 2457.87 2450.55 -135.85 2446.84 2450.61 93.18 1.59 MWD IFR MSA 41 3835.27 64.39 91.93 94.35 2498.60 2535.65 -139.02 2531.88 2535.70 93.14 0.39 MWD IFR MSA 42 3929.17 63.85 91.73 93.90 2539.59 2620.12 -141.72 2616.32 2620.16 93.10 0.61 MWD IFR MSA 43 4023.29 63.37 92.43 94.12 2581.42 2704.43 -144.77 2700.58 2704.46 93.07 0.84 MWD IFR MSA 44 4115.18 62.92 91.98 91.89 2622.93 2786.40 -147.93 2782.50 2786.43 93.04 0.66 MWD IFR MSA 45 I 4209.10 63.98 91.85 93.92 2664.91 2870.41 -150.74 2866.46 2870.42 93.01 1.14 MWD IFR MSA I 46 I 4270.00 63.98 91.85 60.90 2691.63 2925.12 -152.50 2921.16 2925.14 92.99 0.00 Projected to TD I [(c)2003 IDEAL ID8 lC 01] ¡ - - I '~ bp 2£", W-209PB1 Survey Report Schlumberger .",...,... ~.¡;,::'-¡_:--_..:.- Report Date: 1·0ct-03 Survey 1 DLS Computation Method: Minimum Curvature { Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 92.800° Field: Prudhoe Bay Unit· WOA Vertical Section Origin: N 0.000 ft. E 0.000 It Structure / Slot: W-PAD 1 W·209 TVD Reference Datum: KB Well: W-209 TVD Reference Elevation: 80.40 It relative to MSL Borehole: W·209PB1 Sea Bed 1 Ground Level Elevation: 51.90 ft relative to MSL UWI/API#: 500292317070 Magnetic Declination: 25.325° Survey Name 1 Date: W-209PB 11 October 1, 2003 Total Field Strength: 57552.646 nT Tort 1 AHD 1 DDII ERD ratio: 85.331 ° {2926.56 It { 5.598 { 1.087 Magnetic Dip: 80.806' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: September 28, 2003 Location LatlLong: N 70.29728775, W 149.09262235 Magnetic Declination Model: BGGM 2003 Location Grid N/E YfX: N 5959130.050 ftUS, E 612048.860 ftUS North Reference: True North Grid Convergence Angle: +0.85426299° Total Corr Mag North -> True North: +25.325' .'-"" Grid Scale Factor: 0.99991426 Local Coordinates Referenced To: Well Head Measured Inclination Azimuth Course TVD Sub-Sea TVD Vertical NS EW Closure Closure DLS Build Rate Walk Rate Northing Easting Latitude Longitude Depth Length Section Azimuth ( It ) (deg) (deg) ( It ) ( It) ( It) (It ) ( It ) (It ) ( ft) (deg) ( deg/100 It) ( deg/1 00 It ) ( deg/100 It) (ltUS) (ltUS) 0.00 0.00 0.00 0.00 0.00 -80.40 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5959130.05 612048.86 N 70.29728775 W 149.09262235 197.46 0.70 46.02 197.46 197.46 117.06 0.83 0.84 0.87 1.21 46.02 0.35 0.35 0.00 5959130.90 612049.72 N 70.29729004 W 149.09261532 291.79 2.23 77.52 94.33 291.75 211.35 2.99 1.63 3.07 3.48 62.01 1.77 1.62 33.39 5959131.73 612051.91 N 70.29729222 W 149.09259745 383.29 5.32 87.95 91.50 383.04 302.64 8.94 2.17 9.05 9.31 76.52 3.45 3.38 11 .40 5959132.36 612057.88 N 70.29729368 W 149.09254904 475.20 8.95 88.38 91.91 474.23 393.83 20.31 2.53 20.46 20.62 82.96 3.95 3.95 0.47 5959132.88 612069.28 N 70.29729465 W 149.09245667 567.66 13.07 89.55 92.46 564.97 484.57 37.93 2.81 38.11 38.22 85.78 4.46 4.46 1.27 5959133.43 612086.92 N 70.29729543 W 149.09231375 659.85 17.40 90.42 92.19 653.89 573.49 62.12 2.79 62.33 62.39 87.44 4.70 4.70 0.94 5959133.77 612111.14 N 70.29729538 W 149.09211764 752.41 21.89 92.46 92.56 741.05 660.65 93.22 1.95 93.43 93.45 88.80 4.91 4.85 2.20 5959133.39 612142.24 N 70.29729308 W 149.09186588 845.02 25.05 94.25 92.61 825.98 745.58 130.09 -0.25 130.24 130.24 90.11 3.50 3.41 1.93 5959131.75 612179.07 N 70.29728708 W 149.09156783 939.08 28.12 96.53 94.06 910.09 829.69 172.13 -4.24 172.13 172.18 91.41 3.44 3.26 2.42 5959128.37 612221.02 N 70.29727616 W 149.09122864 1032.45 30.70 97.00 93.37 991.42 911.02 217.86 -9.65 217.65 217.87 92.54 2.77 2.76 0.50 5959123.65 612266.61 N 70.29726138 W 149.09086002 1126.09 32.97 96.66 93.64 1070.97 990.57 267.13 -15.52 266.69 267.14 93.33 2.43 2.42 -0.36 5959118.51 612315.73 N 70.29724534 W 149.090d6295 1220.13 37.21 94.65 94.04 1147.90 1067.50 321.11 -20.79 320.48 321.15 93.71 4.67 4.51 -2.14 5959114.04 612369.58 N 70.29723092 W 149.0 '47 1313.07 40.21 93.92 92.94 1220.42 1140.02 379.20 -25.13 378.43 379.26 93.80 3.27 3.23 -0.79 5959110.57 612427.59 N 70.29721909 W 149.0~23 1406.06 42.54 92.63 92.99 1290.20 1209.80 440.66 -28.62 439.79 440.72 93.72 2.67 2.51 -1.39 5959107.99 612488.99 N 70.29720953 W 149.08906141 1500.06 45.93 90.72 94.00 1357.54 1277.14 506.21 -30.50 505.32 506.24 93.45 3.87 3.61 -2.03 5959107.09 612554.53 N 70.29720437 W 149.08853081 1592.32 49.68 90.86 92.26 1419.49 1339.09 574.50 -31.45 573.65 574.51 93.14 4.07 4.06 0.15 5959107.16 612622.87 N 70.29720178 W 149.08797752 1685.34 53.16 91.67 93.02 1477.49 1397.09 647.18 -33.07 646.34 647.19 92.93 3.80 3.74 0.87 5959106.63 612695.56 N 70.29719734 W 149.08738898 1778.47 53.70 92.06 93.13 1532.98 1452.58 721.97 -35.50 721.10 721.97 92.82 0.67 0.58 0.42 5959105.31 612770.34 N 70.29719067 W 149.08678369 1872.86 55.79 93.65 94.39 1587.46 1507.06 799.04 -39.35 798.07 799.04 92.82 2.61 2.21 1.68 5959102.60 612847.36 N 70.29718013 W 149.08616045 1964.64 58.00 93.53 91.78 1637.59 1557.19 875.91 -44.17 874.79 875.91 92.89 2.41 2.41 -0.13 5959098.93 612924.14 N 70.29716695 W 149.08553921 2057.69 58.67 94.29 93.05 1686.44 1606.04 955.09 -49.57 953.81 955.09 92.97 1.00 0.72 0.82 5959094.71 613003.22 N 70.29715217 W 149.08489946 2152.26 59.64 93.56 94.57 1734.92 1654.52 1036.27 -55.12 1034.81 1036.28 93.05 1.22 1.03 -0.77 5959090.36 613084.28 N 70.29713696 W 149.08424360 2246.06 60.92 93.73 93.80 1781.42 1701.02 1117.72 -60.30 1116.1 0 1117.73 93.09 1.37 1.36 0.18 5959086.40 613165.64 N 70.29712278 W 149.08358537 2339.90 63.62 94.12 93.84 1825.08 1744.68 1200.75 -65.99 1198:96 1200.78 93.15 2.90 2.88 0.42 5959081.95 613248.57 N 70.29710721 W 149.08291448 SurveyEditor Ver 3.1 RT-SP3.03-HF1.2 Bld( do31 rt-546 ) W -209\ W -209\ W -209PB 1 \ W -209PB 1 Generated 10/24/2003 4:26 PM Page 1 of 2 2433.70 64.11 93.73 93.80 1866.40 1786.00 1284.95 -71.75 1282.97 1284.98 93.20 0.64 0.52 -0.42 5959077.44 613332.65 N 70.29709142 W 149.08223425 2527.15 63.18 92.56 93.45 1907.89 1827.49 1368.68 -76.35 1366.58 1368.71 93.20 1.50 -1.00 -1.25 5959074.09 613416.31 N 70.29707882 W 149.08155729 2620.38 61.60 93.02 93.23 1951.10 1870.70 1451.29 -80.37 1449.09 1451.32 93.17 1.75 -1.69 0.49 5959071.30 613498.86 N 70.29706780 W 149.08088921 2713.60 63.44 92.56 93.22 1994.11 1913.71 1533.99 -84.39 1531.69 1534.02 93.15 2.02 1.97 -0.49 5959068.51 613581.51 N 70.29705677 W 149.08022041 2806.18 63.02 92.41 92.58 2035.81 1955.41 1616.64 -87.98 1614.27 1616.67 93.12 0.48 -0.45 -0.16 5959066.16 613664.12 N 70.29704693 W 149.07955178 2900.11 62.41 92.30 93.93 2078.87 1998.47 1700.12 -91 .41 1697.68 1700.14 93.08 0.66 -0.65 -0.12 5959063.97 613747.57 N 70.29703751 W 149.07887644 2993.48 63.15 94.53 93.37 2121.58 2041.1 8 1783.14 -96.36 1780.56 1783.16 93.10 2.27 0.79 2.39 5959060.25 613830.50 N 70.29702393 W 149.07820543 3086.47 62.73 94.44 92.99 2163.88 2083.48 1865.91 -102.83 1863.11 1865.95 93.16 0.46 -0.45 -0.10 5959055.01 613913.14 N 70.29700618 W 149.07753699 3180.29 64.22 93.33 93.82 2205.78 2125.38 1949.84 -108.52 1946.86 1949.88 93.19 1.91 1.59 -1.18 5959050.58 613996.95 N 70.29699060 W 149.07685891 3274.04 63.59 93.13 93.75 2247.02 2166.62 2034.03 -113.26 2030.92 2034.08 93.19 0.70 -0.67 -0.21 5959047.09 614081.06 N 70.29697758 W 149.07617830 3366.64 63.05 93.19 92.60 2288.60 2208.20 2116.77 -117.82 2113.53 2116.82 93.19 0.59 -0.58 0.06 5959043.76 614163.73 N 70.29696506 W 149.07550940 3460.41 62.25 93.72 93.77 2331.68 2251.28 2200.05 -122.84 2196.67 2200.10 93.20 0.99 -0.85 0.57 5959039.98 614246.92 N 70.29695129 W 149.07483628 3554.75 63.40 93.05 94.34 2374.76 2294.36 2283.97 -127.79 2280.45 2284.03 93.21 1.37 1.22 -0.71 5959036.28 614330.76 N 70.29693769 W 149.07415795 3647.94 63.05 92.86 93.19 2416.74 2336.34 2367.17 -132..08 2363.54 2367.22 93.20 0.42 -0.38 -0.20 5959033.23 614413.90 N 70.29692590 W 149.072' - -?2 3740.92 64.45 92.33 92.98 2457.87 2377.47 2450.55 -135.85 2446.84 '. 2450.61 93.18 1.59 1.51 -0.57 5959030.70 614497.24 N 70.29691552 W 149.07. ß ---- 3835.27 64.39 91.93 94.35 2498.60 2418.20 2535.65 -139.02 2531.88 2535.70 93.14 0.39 -0.06 -0.42 5959028.80 614582.31 N 70.29690680 W 149.07212216 3929.17 63.85 91.73 93.90 2539.59 2459.19 2620.12 -141.72 2616.32 2620.16 93.10 0.61 -0.58 -0.21 5959027.37 614666.77 N 70.29689935 W 149.07143848 4023.29 63.37 92.43 94.12 2581.42 2501.02 2704.43 -144.77 2700.58 2704.45 93.07 0.84 -0.51 0.74 5959025.56 614751.06 N 70.29689091 W 149.07075629 4115.18 62.92 91.98 91.89 2622.93 2542.53 2786.40 -147.93 2782.50 2786.43 93.04 0.66 -0.49 -0.49 5959023.63 614833.01 N 70.29688221 W 149.07009302 4209.10 63.98 91.85 93.92 2664.91 2584.51 2870.40 -150.74 2866.46 2870.42 93.01 1.14 1.13 -0.14 5959022.08 614917.00 N 70.29687446 W 149.06941316 4270.00 63.98 91.85 60.90 2691.63 2611.23 2925.12 -152.50 2921.16 2925.14 92.99 0.00 0.00 0.00 5959021.13 614971.71 N 70.29686957 W 149.06897029 Leqal Description: NorthinQ (y) rftUSl EastinQ (X) rftUSl Surface: 4153 FSL 1189 FEL S21 T11N R12E UM 5959130.05 612048.86 BHL: 3999 FSL 3548 FEL S22 T11N R12E UM 5959021.13 614971.71 .---- SurveyEditor Ver 3.1 RT -SP3.03-H F1.2 Bld( do31 rt-546 ) W-209\W -209\W-209PB 1 \W-209PB 1 Generated 10/24/20034:26 PM Page 2 of 2 ') ) STATE OF ALASKA :¡ ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU I W-209i 11/24/03 Mellveson Chuck Scheve ~, l(z6 03 Vf'l Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us Packer Oepth Pretest Initial 15 Min. 30 Min. Well W-209i Type Inj. S TVO 5,068' Tubing 1 ,780 1,780 1 ,780 1,780 Interval I v'''' P.T.D. 2031280 Type test P Test psi 1500 Casing 1,810 2,500 2,580 2,640 PIF P Notes: Initial 4 year MITIA. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing PIF Notes: Well Type Inj. TVO Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVO Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVO Tubing Interval P.T.D. Type test Test psi Casing PIF Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU W-209i 11-24-03.xls ) ) ðð3-/t9'ii MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W -209i Date Dispatched: 9-Sep~03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 ': ' n -1 Lt Received BY~~~~ \ ~ ",' Please sign and return to: James H. Johnson 'Y\ ~~, c.\ ~ ~/~,,,,- BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 ~~~ \\\ ~~ .) ) ff(')ô - J /9 ~ MWD/LWD Log Product Delivery Custom er BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W-209PB1 Date Dispatched: 9-Sep-03 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 Received BY~~'::' N\ D '- ~" ¿(E,,"':'::'D'¡~' to"",,, I' .,_.., 'J ~._'-" I: ~ "1"= ; ~~ l\. :¡~~I''T" ~ .\~~~ Jt»õ:.,~ § I{# ¡;; . I' Or-or r: --,. ""'J:""\.7 \..- I c.,. i 1.\ \i J Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1 Dec '97 .t:.~~~s~.a v;; c, ;~1:}:~,:",·u: ;:::, C-(;dîm)ssion /-\!1cnorage ~, ·¡,.wC-;J\ iO'I112-0o·~ ) STATE OF ALASKA ') ALASKA 01L AND GAS CONSERVATION COrvllvilSSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 1. Type of Request: o Abandon o Alter Casing /' 1m Chanç e Approved ProQram 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska T. KB Elevation (ft): o Suspend 0 Operation Shutdown 0 Perforate o Repair Well 0 Plug Perforations 0 Stimulate o Pull TubinQ 0 Perforate New Pool 0 Re-Enter Suspended Well 4. Current Well Class: o Development 0 Exploratory o Stratigraphic III Service 99519-6612 o Variance o Time Extension o Annular Disposal 5. Permit To Drill Number 203-128 /' 6. API Number: , 50- 029-23170-00 /' o Other Plan KBE = 80.4' 9. Well Name and Number: ./ PBU W-209i 8. Property Designation: 10. Field / Pool(s): .':.'1.,,::;, ¡;·.·.··:·:"i,.'!.' "i,.(,i:.I.'1 ',; ': ADL 047451 Prudhoe Bay Field / Polaris Pool '..". h " .. . .. .../1"···· , .... . ...'~' . . ,. ,.. 'nm .... "1' "r\IKlIS·I:I,I".;··..·,···R...v¡"····, .,0',. """"';11' ,. " "I:' ." . I ., . ",. . li",I,,:' ".::', I ',: I, ",I "i":,,,',';:'!:, :,·I.':'.;!',:! ?R~~:~N).:WiE:~~I*~N'ª',ry¡I,~,IIè1·· ~M,Y,'~. :111::I:""I"'(::!li:,::'¡:,' '.:.i::::I;'!""·.III,':I',.,,::,:,:,,':·,..:il;I¡':1 :.1;"'.. ;.:":,:.,:,' Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 2691 4270 2691 None 3977 L.ength . Size'. MD, .' TVD' Bu~st Cóllapse Total Depth MD (ft): 4270 C~sing Structural Conductor Surface Intermediate Production Liner Extended Conductor 108' 20" 108' 108' 1850' 13-3/8" 1879' .r /' 1635 HECf'Vr"'~'n (JCT 0 62003 ~AIkoOi'&Gœ nl'\n..~()un~ Tubing Grade: Anch vrgmrrg'rt1t!1I~,n None . oragSNone Packers and SSSV MD (ft): None Perforation Depth MD (ft): None Packers and SSSV Type: None Perforation Depth TVD (ft): None Tubing Size: None 12. Attachments: 181 Description Summary of Proposal 0 BOP Sketch o Detailed Operations Program 14. Estimated Date for Commencing Operations: October 3,2003 16. Verbal Approval: ~ate: /tJ;f7J10';'~ Commission Representative: Winton Aubert 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bi I Isaacson Title Senior Drilling Engineer Signature I l' ~''\; 1. , ... ____ Phone 564-5521 Date ¡ 0/ " I ú 3 Commission Use Only 13. Well Class after proposed work: o Exploratory 0 Development III Service 15. Well Status after proposed work: o Oil 0 Gas o WAG DGINJ o Plugged III WINJ o Abandoned o WDSPL Contact Jim Smith, 564-5773 Michael Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 Conditions of approval: Notify Commission so that a representative may witness I Sundry Number:~O:]_ 1; ó tf o Plug Integrity o BOP Test o Mechanical Integrity Test o Location Clearance Other: Subsequent form required 10- '-/01 Approved By: ~ A Form 10-403 Revised 2/2'3 {;J ,J\I ! \ J'"\...:.:. :. ,; lX\2 LL \: h~ ¡"ì' ~!~ OCTO,'120030¡\lG!NAI COMMISSIONER BY ORDER OF THE COMMISSION /0107!¿;:? Date ¡CJ Submit In Duplicate ) ') Well W - 209i, extended conductor setting Drilling of the surface interval on W -209i was problematic due to severe ledge problems /" in the interval from 1400' to 1800'MD. The 12-1/4" hole had been drilled to TD for the 9-5/8" surface casing at 4270'MD/2691 'TVD. The final angle at 4270'MD of slightly more than 64 degrees had been increased from the initial kick off depth of 300'. At TD the BHA became differentially stuck and could not be jarred loose. The assembly was backed off and BHA recovery efforts initiated. Fishing for the BHA was abandoned when it was not possible to reach the BHA with fishing tools due to the ledge interval between 1400' and 1800'MD which prevented tool passage. The decision was reached to abandon the BHA and set surface casing just above the fish so that further well advancement could be accomplished. The hole was cleaned out and 9- /',. 5/8" casing was run into the hole. The casing could not pass the first severe ledge at 1400' and was removed from the hole. Further clean out operations were conducted and the 9-5/8" again run but with the same difficulty passing the ledge at 1400'. Due to the inability to pass the ledge at 1400' it was decided to open the hole to 16" and run an extended conductor of 13-3/8" casing across the ledge interval. Phone contact with Winton Aubert of the AOGCC was made on Friday, October 3, 2003. Winton was unavailable and a phone message was left on his recorder to which he replied agreement ..--' and request for a follow-up Sundry application this week. The well was sidetracked at the 1400' ledge and re-drilled to 1891 'MDI1638'TVD which lies just below the interval of ledge building and still within the permafrost interval. The additional extended conductor (13-3/8", 68#, L-80, BTC) casing was run to 1879' and cemented to surface with 470 bbl of cement and full returns. There were 230 bbls of cement circulated to surface. Drilling will continue in 12-1/4" hole size to again reach the planned surface casing point /" which will be near 4300'MD/2691 'TVD. At that depth 9-5/8" surface casing will be run and cemented to surface. ') W-209i Proposed Completion ¡ ~ 1~ 13-3/8", 68#/ft, , BTC j ) 11,879' l-l~ TAM Port Collar 11,800' r1 9-518", 40#/ft, L-BO, BTG~ 14,162' I Cellar Elevation = 51.9' Nabors 9ES RKB = 80.4' 4-1/2" X 3-1/2" TCII XO- 7" Short Joint & RA Tag -TBD' TVDss -TBD' TVDss Date 9/16/03 10106/03 Rev By MikT JES TREL.-ìMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head wI 7" mandrel hanger & packoff 11" x 11", 5M, tbg spool wI 11" x 4-1/2" tubing hanger 11" X4-1/16" Adaptor Flange ~ 20" X 34" 215.5 Ibltt, A53 ERW Insulated 114' ~~ /~ 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 2,500' TVD I Camco gas lift mandrel 4-1/2" x 1" KBG2 - With OCR Shear Valve pinned to 2,500 I 3,100' TVD I ~ 4-1/2", 12.75Ib/ft, L-80, TCII Drift 110: 3.833"/3.958" 3-1/2", 9.3 Ib/ft, L-80, TCII Drift 110: 2.867"/2.992" 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 7" x 4-1/2" Baker 'PRM' Production Packer 200' MO above the top OBa perf 3-1/2" 'X' Landing Nipple with 2.813" seal bore. 7" x 3-1/2" Baker 'PRM' Production Packer 3-1/2" 'X' Landing Nipple with 2.813" seal bore. Camco 3-1/2" x 1-1/2" Injection Mandrel ~ OBc sand Perfs: TBD ...........,.....,..'.......'I:.!..,..·...,.···.·...·,·..,·..~...... ..,:,;.,:.:.:,::.:':,.:;,~ . :~ 7" x 3-1/2" Baker 'S-3' Production Packer :::::::==- 3-1/2" 'X' Landing Nipple with 2.813" seal bore. ~ 3-1/2" WireLine Entry Guide (-50' above the top OEkJ perf) 55 - æ ~Bd sand Perfs: TBD l~ 7", PBTO ~ 7",26 #Ift, L80, BTC-Mod 10,500' MD 10,580' MD Comments G~/QJ7ltgm¡fBgp ./ Proposed Completion Revision for addn'l conductor WELL: W-209i API NO: 50-029-23170 ri,' ·-r·:~ ! r, J ¡ ¡ L;} tJ th~ ) [ill,.· f?L' ~r @1 fK\ ~ ~ 1 Œ\ __' lr l\ .._.:~ Lr\~ \,-~" ,J~~. U \\ AT/ASIiA OIL AND GAS CONSERVATION COMMISSION ) FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. AIO 25.01 Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage Alaska 99519 Dear Mr. Crane: Area Injection Order No. 25 ("Ala No. 25"), dated February 4, 2003, au- thorizes underground injection of fluids for enhanced oil recovery in the Polaris Oil Pool, Prudhoe Bay Field, North Slope, Alaska. Rule 2 of Ala No. 25 author- izes underground fluid injection in specific wells enumerated in the Order. Subject Rule 2 also allows the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") administrative approval of additional Polaris injec- tion wells. Proposed well W-209i is permitted for drilling as a service well for injec- tion in conformance with 20 AAC 25.005. AOGCC has verified the mechanical condition of wells within a one-quarter mile radius of the proposed injection zone. AOGCC has determined that fluids injected into proposed well W-209i will enter permeable strata which can reasonably be expected to accept injected fluids at pressures less than the fracture pressure of confining strata. The Commission has further determined that injected fluids will be confined within the appropriate receiving intervals by impermeable lithology, cement isolation of the well bore and appropriate operating conditions. Accordingly, Area Injection Order No. 25 is amended ,to authorize drilling and construction of Prudhoe Bay Field, Polaris Oil Pool welr-.W-209i. DONE~~~ AnChOr,i~, ' Al7s~a this 25th of July 200,3. ~C{A-"A· .)JL- ~ ~, fuah,K. Palin \) Daniel T. Seamount, Jr. .~ \ Commissioner BY ORDER OF THE COMMISSION ) ) r~'~::::J I I.....,. . r··.. , r L." ,,'·,.1..1' I ;' l \. _I\:ì FRANK H. MURKOWSKI, GOVERNOR AI1A.SIiA OIL AND GAS CONSERVATION COMMISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage Alaska 99519 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Unit W-209i BP Exploration (Alaska), Inc. Permit No: 203-128 Surface Location: 4153' NSL, 1189' WEL, Sec. 21, T11N, R12E, UM Bottomhole Location: 3734' NSL, 1991' EWL, Sec. 23, T11N, R12E, UM Dear Mr. Crane: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required penTIits and approvals have been issued. In addition, the Commission reserves the right to withdraw the penTIit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenTIS and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, /"'-l ~. I L__-_~ "I fL7" C......-·-- )...'\_ú~·// ~-t).¡~/L-- - Sarah Pa 'n \j - Chair BY ORDER 9l THE COMMISSION DATED thisJ;1 day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section L^Jú!\- 1/2-~/z-oo~ 12. Distance to nearest property line 13. Distance to nearest well / ADL 028263,1991' MD W-01 is 33' away at 54T MD 16. To be completed for deviated wells Kick Off Depth 300' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Casing WeiCJht Grade CouDlina 20" x 34" 215.5# A53 Welded 9-5/8" 40# L-80 BTC T' 26# L-80 BTC-M Hole 48" 12-1/4" 8-314" , STATE OF ALASKA ALASKA ,-..l AND GAS CONSERVATION cOMrv..,110N PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 0 Oevelopment Oil iii Service 0 Oevelopment Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 80.4' Prudhoe Bay Field / Polaris 6. Property Designation Pool ADL 047451 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number W-209i 9. Approximate spud date 09/05/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 -10580' MD / 5521' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 630 Maximum surface 1786 psig, At total depth (TVO) 4990' / 2285 psig Setting Depth Top Bottom MD TVD MD TVD 291 29' 109' 109' 29' 29' 4162' / 2660' 29' 29' 10580'/ 5527' 11. Type Bond (See 20 AAC 25.025) 1 a. Type of work II Orill 0 Redrill ORe-Entry 0 Oeepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 612049, Y = 5959130 4153' NSL, 1189' WEL, SEC. 21, T11 N, R12E, UM At top of productive interval x = 620000, Y = 5958860 3760' NSL, 147T EWL, SEC. 23, T11 N, R12E, UM At total depth x = 620514, Y = 5958843 3734' NSL, 1991' EWL, SEC. 23, T11N, R12E, UM / Number 2S 100302630-277 Lenath 80' 4133' 1 0551' Quantity of Cement (include stage data) 260 sx Arctic Set (Approx.) 725 sx PF 'L', 428 sx Class 'G' 427 sx Class 'G' "~ 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 MD TVD Structural Conductor Su rface Intermediate Production Liner JUL 2, ,;3 ?ODj 22 Perforation depth: measured true vertical 20. Attachments iii Filing Fee 0 Property Plat 0 BOP Sketch 0 Oiverter Sketch iii Drilling Program iii Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report iii 20 AAC 25.050 Requirements Contact Engineer Name/Number: Michael Triolo, 564-5774 Prepared By Name/Number: Terrie Hubble, 564-4628 ?1. I hereby certify that~he. fO.. g. oing is tru; a~J correct to th.....e b.' e. st.. O. ..f.. .m..... Y.. .~,n. .0. W. I..~, .~. g. e . Signed Lowell Cran ~ ~ _ Title Senior Dnlllng Engineer Date "7 -' .73- Ð3 . .' . .....'. . . ,CommisSion USe.,pn~y , Permit Number API Number / '"? APPJP~al 00}e-1, See cover letter ;¿ð,.3 - /:z 9? 50- 02..? - Z 3 r ð '{ J ,:j¡f¡ '0'/ for other requirements Conditions of Approval: Samples Required DYes Qf No Mud Log R quir DYes )'tNo Hydrogen Sulfide Measures D Yes (Sa No Directional Survey Required ~ Yes DNa ReqUir~ W~rking Pressure for BOPE D..2K D 3K D 4K D 5K . ÇJ 10K D 15~ f' D ~.5K psi for CTU Other: JeSt gOJ?"'='nÞfð~)s::¿. MrT é.-Wt.-t '/¡u...~J.¡'[:v¡lIOj 'r-t!1/U.Y'-€.d~. ~ .. . cmg h paUn ffy order of ..r1 . ¡; ~ Approved By . Sara C01fJ3~r'" ^ 'tcommission Date! I ~ ~!jJ I. Form 10-401 Rev. 12-01-85 0 ~ ,\J \ \" t'\ S bmit In Triplicate ) Greater Prudhoe Bay Polaris W-209i Permit " ~) Well Plan SUmmary I Well Name: I W-209i 1 Type of Well (producer or injector): I USH Injector 1/ Surface Location: 4,153' FSL, 1,189' FEL, Sec. 21, T11 N, R12E X = 612,048.86 Y = 5,959,130.05 3,7601 FSL, 3,803' FEL, Sec. 23, T11N, R12E X = 620,000 Y = 5,958,860 Z = 5,190' TVDss ./ 3,734' FSL, 3,289' FEL, Sec. 23, T11 N, R12E X = 620,514.33 Y = 5,958,842.53 Z = 5,447' TVDss /" W-209i Target Start: W-209i Target End: -,,,./ 1 AFE Number: I PLD5M 1067 1 Rig: I Nabors 9ES / 1 Estimated Start Date: I Sept 5tn 2003 1/ 1 Operating days to complete: 116.08 MD 110,580' I I TVDrkb: TD 1 5,527' I I Max Inc. I 63° I I KBE I 80.40' Well Design: USH Grassroots Schrader Injector. 4-%" X 3-%" TCII Completion. Current Well Information General Well Name: API Number: Well Type: Current Status: BHP: BHT: W -209i 50-029- ????? Development - Polaris Schrader Injector New well, 20" X 34" insulated conductor 2,335 psi @ 5,045' TVDss (8.9 ppg EMW). Normal pressure gradient. 100°F @ 5,045' TVDss Estimated Mechanical Condition W-209i: Nabors 9ES: Conductor: Cellar Box above MSL = 51.9' KB / MSL = 28.5' 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB % Mile WeH~e Near Wellbore Mechanical Integrity Summary: \ 10 -o(7¡t41112j~ithin 14 mile of this injector penetration at the Top OA structure. The mechanical integrity of this well was '-fevie.Weá and approved by the AOGCC during the initial Area Injection Order application in conjunction with approval for injection into W -207i. \¡-J - r- I I,J - 17 rqeJ -l7')") I{~- O'î5 Target Estimates Pt It- Estimated Reserves: 1,485 mstb Expected 12 month avg: 65 bopd (from W -205 ML) Final Approved 7/23/03 Materials Needed Surface Casing: Intermediate Casing: L-80 Completion: ) Greater Prudhoe E/y Polaris W-209i Permit 4,162' 1 each 1 each 25 each 1 assembly 1 lot 9-%", 40#, L-80 BTC Casing 9-%", BTC Float Shoe and Float Collar 9-%", 40#, BTC Type TAM Port Collar 9-%" x 12 1,4" Bow Spring Centralizers FMC 11" 5m Gen 5 Wellhead System 9-%" casing pups 5', 10', 20'. 10,600' 1 each 65 each 2 lots 2 each 2 each 7" 26# L-80 BTC-M Casing 7" BTC-M Float Shoe and Float Collar 7" x 8 1,4" Rigid Straight Blade Centralizers 7" casing pups 5', 10', 20' 7" RA Tag 7" 26# L-80 BTC-M Casing Short Joint 9,500' 500' 2 each 1 each 2 each 4 each 1 each 1 each 1 each 4 each 1 each 4 Y2" 12.60 Ib/ft, L-80, TCII tubing 3 %" 9.20 I blft , L-80, TCII tubing Baker PRM Production Packer 7" X 3-%" Baker S-3 Production Packer 7" X 3-Y2" Halliburton 4-%" X-Nipple (3.813" ID) Halliburton 3-%" X-Nipple (2.813" 10) 11" X 4-%" FMC tubing hanger 4-1/16", 5m Cameron Tree 4-%" x 1" KBG-2 GLM 3-%" x 1-%" MMG GLM 3-Y2" WLEG Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off W -209i. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. ?I..o~..~...~.ee.~.~.~~..~. ..."'!.el.I....~ist:. .............................. ·W~II·Nªm~.;Q~Î'~·ØtrPf$tänø~:· _. W-01 32.74-ft W-02 64.90-ft W-03 100.55-ft W-207i 110.07-ft .. . . .. .. .... ..' :····;:·a~.ør~ijç'·IVIO: 546.86-ft 547.32-ft 589.29-ft 943.41-ft :·:··'..··...iÀlíÔW~I)Jø:.þij~iati~ii¡ 22.63-ft 56.92-ft 90.32-ft 93.92-ft '_)··.:···:.·..e(èc:~LdfOijªry.C~rom~lÎt·':!:··.········ Use Traveling Cylinder (Gyro) Use Traveling Cylinder (Gyro) Use Traveling Cylinder Use Traveling Cylinder // Survey and Logging Program 12-%" Hole Section: Surface Gyro if needed (have discussion with ODE on photo or E-line Gyro) Open Hole: MWD I GR Cased hole: None 8-3,4" Hole Section: MWD I GR I Res I Den I Neu I PWD (Den Neu recorded only) Cased Hole: USIT Bond Log 2 Approved Mud Program 12"IA" Surface Hole Mud Properties: Interval I Density (ppg) Funnel vis Initial 8.6 - 8.8 300 Base Perm 8.8 - 9. 200 - 300 Interval TD 9.3 - .6 200 8 %" Intermediate Holè Mud Properties: Interval I Density (ppg) Funnel vis Initial 8.6 - 9.0 45 - 55 Ugnu / Schrader 9.5 45 - 55 ) YP 50 - 70 30 - 60 25 - 48 YP 21 - 28 21 - 28 Greater Prudhoe êay Polaris W-209i Permit ) I Spud - Freshwater Mud Tauo PH Plastic Vis FL 10 - 18 8.5 - 9.5 20 - 45 15 - 20 8 - 16 8.5 - 9.5 20 - 40 < 15 9 - 14 8.5 - 9.5 14 - 20 < 10 I Freshwater Mud (LSND) PH: 8.5 - 9.5 Tauo PV API Filtrate MBT 3 - 6 9 - 14 < 5 < 20 3 - 6 11 - 15 < 5 < 20 Formation Markers (Based on Schlumberger WP6) ·.:::..¡:!¡!':<1J::¡!~(i~fñät.ø~:,møp$I ...... ......,. SV5 Base Permafrost SV4 SV3 SV2 SVl UG4 UG4A UG3 UGl Top Schrader Bluff/Ma Sand Mbl Mb2 Mc Na Nb Nc OA OBa OBb OBc OBd OBe - Base injection interval OBf OBf_Base TD :,:::!:,;:'::Fîi~Þ$$':.!;' . - 1,835 1,850 1,980 2,490 2,690 3,015 3,395 3,435 3,760 4,245 4,565 4,610 4,670 4,740 4,805 4,840 4,885 4,990 5,045 5,080 5,130 5,190 5,270 5,325 5,380 5,447 2,495 2,528 2,819 3,961 4,408 5,135 5,987 6,076 6,803 7,889 8,605 8,706 8,840 8,997 9,142 9,221 9,322 9,557 9,680 9,758 9,870 10,004 10,183 10,306 1 0,430 10,580 ·.::,;,.'·'~t{tt~·ø:·::;.::· 1,915 1,930 2,060 2,570 2,770 3,095 3,475 3,515 3,840 4,325 4,645 4,690 4,750 4,820 4,885 4,920 4,965 5,070 5,125 5,160 5,210 5,270 5,350 5,405 5,460 5,527 (')::ïS"···..'· ....,....::,...,...."....,....,.." J:::f')Or~:..p.$~;;/. 826 833 891 1,121 1,211 1,357 1,528 1,546 1,692 1,910 2,105 2,120 2,145 2,180 2,215 2,220 2,235 2,285 2,335 2,345 2,365 2,385 2,410 2,430 2,445 ,¡:' I;MW!· (pP'Q):': 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.7 8.9 8.8 8.8 8.8 8.9 8.8 8.8 8.8 8.9 8.9 8.9 8.8 8.8 8.8 8.7 ·:'..!!i::HY~tQç¡r~øij$::,,:·: No No Pass. Gas Hydrates Pass. Gas Hydrates Pass. Gas Hydrates No Heavy Oil Maybe - Heavy Oil No Maybe - Heavy Oil No No No No No No No Yes Yes Yes Yes Yes Yes Yes 1/~ CasinglTubing Program HòleSize Csgl'" WtlFt Gr~ Co~., Length Top Bottom Tbg O.D. MD I TVDrkb MD I TVDrkb 48" 20" X 34" 215.5# A53 Welded 80' 29' / 29' 109' /109' ./ 12-%" 9-%" 40# L-80 BTC 4,133' 29' / 29' 4,162' /2,660' ,/ 8-%" 7" 26# L-80 BTC-M 10,551 ' 29' / 29' 10,580' / 5,527' ,/ Tubing 4 Y2" 12.60# L-80 TCII 9,471 ' 29' / 29' 9,500' / 5,068' Tubing 3 Y2" 9.20# L-80 TCII 500' 9,500' / 5,068 10,000' / 5,270 3 Approved Cement Calculations ) Greater Prudhoe i;Jay Polaris W-209i Permit ) Casin~ Size 9-%-in 40-lb/tt L-80 BTC - Single Stage Basis I 250% excess over gauge hole in permafrost interval, 30% excess over gauge hole below permafrost Total Cement Volume: Tam Port collar located at 1,000' as a contingency for cement to surface Wash 20 bbls CW1 00 Spacer .,...,7.., ,,5........b,.,..b...IS ,.0. .,~f.......y.,... i.'.S...,.,. s,.....i.f..i..e.. .d..., spacer,...,w..,...e..., i.9..,.,h,.,.t..,e.. d to 1 0.,2....,0........p..,..p..~... .'.' ,'..,..,.. ,...,......,...,. Lead 536 bbls 7~) 10.7 Ib/gal Permafrost L cement . U...f,..tI"..,s,. k Tail 87.60 bb s &~k~) 15.8lb/gal Class G + adds- ~1 -uft/sk Temp 1 BHST ==60° F fromSOR, BHCT 70° F estimated by Halliburton In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. CasinQ Size 17" 26 Ib/tt L-80 BTC-M - Single Stage Basis I 30% excess - TOC: 600' MD above the Ma sands (planned Top Ma: 8,605' MD) => 8,005' MD Total Cement Volume: Wash 5 bbls CW100 Spacer 35 bbIS.,...,...o,..,..,.f,.,. .V)S..·...se9". ...e..,..." .,....s..,....i,.f."ie,..,..d".., ".S,..,...,..,..p,....,.,.a.."....c......".e...,..,r........(,..M,.,.,..."....u".,.,.d,'",..p.....u,....s... 'h.... XL De....,s"".:·.'...g.,. n}JN.n"..:.,.... ..If'e-r~.. .'e-, ,.,...,.i. '." ,...h",.,.t,.e,...,d.,.."..,.,.t.. o. 10.2 ppg Tail 92.7 bbls~,??ks) 15.6 I big é;1 I Premium G + LXT~~kS2'cuftlsk Temp BHST == 100° F from SOR, BHCT 80° F estimated by Halliburton 9-0/8" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 3,162' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar. c) This centralizer program is subject to change pending actual hole conditions. 7" String Centralizer Placement a) Place 2 centralizers rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 8,005' MD (600' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. Bit Recommendations BHA<,;;: Hole.Size,: .,:"/'D~pthslMD) :: NÚrribêrårid .Sectiòn Surface 12- %" 0' - 2,528' Nozzles' :'K~Revs ::HoUrs Hughes MXC-1 2x20 1x14 1x12 2x20 1 x 14 1x12 6x14 Surface 12-%" 2,528' - 4,162' Hughes MXC-1 Interm. 8-3,4 4,162' - 10,580' Hycalog DS70NPV Motors and Required Doglegs BHA N()~ 1&2 Motor Size and Motor Required 9-%" Anadrill A962M3445SP Mud Motor, 1.5° ABH with 12-%" string stabilizer 6-3,4" Anadrill A675M4570XP Mud motor, with 1.15° ABH with 7.0" string stabilizer Flow Rate 400 - 650 gpm 500 - 600 gpm RPMs 40-60 "'Required Doglegs 1.5°/100' initial build 4°/100' final build Hold 63° Tangent 3 60-120 4 Approved Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. ./ Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. /' ) Greater Prudhoe êay Polaris W-209i Permit ') Production Section- · Maximum anticipated BHP: 2,285 psi @ 4,990' TVDss - Schrader · Maximum surface pressure: 1,786 psi @ surface (based on BHP and a full column of gas from TO @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4,000 psi (the 7" casing will be tested to 4,000 psi) Estimated 9.2 ppg Brine /6.8 ppg Diesel 4,000/250 psi Rams & Valves / 3,500/250 psi Annular Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. 5 Approved Greater Prudhoe Bay Polaris W-209i Permit ) . -) DrillinQ Hazards and· Continaencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in this fault block is expected to be normal pressured at 8.8 ppg EMW. This pressure is estimated based on offset well pressures and material balance. II. Hyd rates and Shallow gas A. Hydrates have not been a significant issue thus far on W-Pad during the recent drilling of W-203, W-211, W-212i, and W -207i however there is always a potential. III. Lost Circulation/Breathing A. Lost circulation is unlikely. B. We do not expect breathing on this well. IV. Kick Tolerancellntegrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.6~b/9~1 :aii- ement to 600' MD above the Ma sand -8,005' MD. C. The Kick Tolerance for the surface casin 's 52. bls with 9.2 ppg mud, 11.5 ppg LOT, and an 8.9 ppg pore pressure. If the LOT is less then 11.5 .,. W, then the kick tolerance will be < 50 bbls. D. Integrity Testing ··..'Tê$tPôiijj,:: 9-%-in shoe 'Ÿesttype 'l:fJlW(It)Zgál):' LOT 11.5 minimum 20-ft minimum from 9-%--in shoe V. Stuck Pipe A. We do not expect stuck pipe. B. There could be slight differential sticking issues across the Ugnu. Centralizers will be run to mitigate. VI. Hydrogen Sulfide A. W Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. Waterflood on W-Pad was just initiated into the Ivishak in October 2001 and the Schrader Bluff in April 2003, and H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: B. Adjacent producers at Surface: a. W-1 0 ppm b. W -207i 0 ppm C. Adjacent producers at TO: a. W -203 0 ppm b. W -200 0 ppm D. The maximum level of H2S recently recorded on the pad was under -10 ppm. VII. Faults A. Two faults are planned to be crossed up in the UGNU after the surface casing shoe. These faults have been crossed on numerous wells and are not expected to cause any drilling problems. The fault details are listed below for reference: Fault #1: 6,050' MD Fault #1: 8,400' MD 3,504' TVO 4,553' TVD 3,424' TVOss 4,473' TVDss Throw: 40' West Throw: 30' South CONSULT THE W PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Approved · Greater Prudhoe .Bay Polaris W-209i Permit ) ) Drill and Complete Procedure Summary Pre-Rig Work: 1. A conductor has already been set for W-209i. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. ***AII pre-rig work should be charged off against the predrill AFE # PLD5M1067*** Rig Operations: / 1. MIRU Nabors 9ES. / 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-%" drilling assembly with MWD/GR and directionally drill surface hole to approximately 4,162' MD. The actual surface hole TD will be +/-90' TVD below the top of the SV3 sands. .../'. /. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing .bac't<fo surface. A TAM Port collar or stage tool will be run in the casing string to allow secondary cementing, in the event cement is not circulated to surface during primary cementing operations. / 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4,000 psi. 6. MU 8-%" drilling assembly with MWD/GR/Res/Den/Neu(recorded)/PWD and RIH to float collar. Test the 9-%" casing to 3,500 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.0 ppg mud /' 8. Drill new formation to 20' below 9-%" shoe and perform LOT (minimum 11.5 ppg EMW). 9. Drill ahead to TD at 10,580' MD, the base of Schrader formation. 10. Perform wiper trip and condition the hole for casing. POOH standing back the 4" DP. // 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace the casing with 9.2 ppg mud or seawater during cementing operations and freeze protect the 7" x 9-%" annulus. 12. PU used bit/scraper/GR and RIH with 4" DP while waiting on cement. Position GR sensor in MWD tool at ±9,820' or as near to it as possible. Log up one full stand to find the top of the OBa sand a~RA tag if possible. Continue in the hole to PBTD ±10,500' MD. Displace out the mud / seawater with 9.2 ppg brine. Spot 20,000 LSRV perf pill from PBTD to 200' MD above OBa. POOH and LD BHA. ,,- 13. RU Schlumberger E-line and run a USIT log. / 14. RU Halliburton and PU 140' of 4-%" Millenium 5 ~pf perforation assembly with -294' of spacer pups. RIH to perforation depth based on previous logging run, space out and perforate. 15. PU to above top perf and circulate wellbore, monitor for losses. POOH, LD perforation assembly. 16. MU cleanout assembly with bit and 7" casing scraper, run to bottom and circulate and cleanup any perf debris and perf pill. Design assembly for rotation. POOH and LD 4" DP and cleanout assembly. /' 17. Run the 4-%" X 3-%", L-80 TCII completion with a 7" x 3-Y2" straddle packer assembly and GLM's for injection. /" 18. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to 4,000 psi each. Run in a positive plug in the XN-nipple with Slickline. Shear the DCK shear valve. 19. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 20. Freeze protect the well to -2,200' TVD. Install a VR plug in the 7"x 4-Y2" annulus valve and secure the well. 21. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCK shear valve with a dummy GL V. 3. Tag TD with slickline 4. Pull dummy valves in injection mandrels and replace with injection valves I T T ,...............:;* 'III. ! ,_, H 1-1','-:--:'-- I" 7 Approved Job 1: MIRU ) Greater Prudhoe B1I) Polaris W-209i Permit Hazards and Contingencies: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ No wells are required to be shut in. ~;'~:'IJ;'''I,'-:Io,:~,HU,;:<,:<,~{.~,~,~~t;,I.;.I,:..,;I,:,I¡,I'1,1,lll,m:,::.':,',';:,':,:I;:,;:,'.,:,:':,-,-,!,IH.:,:,!~,:,~i':'~,W,:,!;I,m.a,IIJI,;,:':'I,I,111,~.:I,;;¡:"-,;I.":,-,:,I":J ,IU-.:,I.ID1u..TA)I,-¡,;~;:,'-,:,-,I.-;,:'.,:>,I_I,1,1,!.I,!.~,;, ,I,:,I,!,IAI.:I.c.-,-,-~~:,I,I,",:'I,(llHlllJ,-,:,:,~,-,JIl'll;,~lH-l ,I,lll,I,-J.I,I,I,II,~:,I,:l ,:H',:,:,:,a:,'-ioI.H'-,lI,;,<',-ll,:l:,:,m,ll<I,:":,:I.I,U:,:,'U,lm,I,-,-.I,:,1;,llIH;,a,-,m-,:,-:I,'IA:J.t:,-,':,:,I,\I,;n:,;:n_-;.I.;I,:,:,OI,Ull,:I,:,a~~,;:,:,:,:,~,lm,;'-,;-J.I¡.I¡,IJ,I,a:U~II,:':,-,-M.I I~, 'I,I,~,.,."".,:,:.,~ Job 2: Dril/12%" Surface Hole Hazards and Contingencies: ~ At W-Pad, no significant surface hole drilling problems have been identified. Minor tight hole has been encountered in the clay sections below the permafrost, some lost circulation thought to be in conjunction with the tight hole, possible packing off has been encountered. ~ Close Approach: No wells are required to be shut in. There are several close tolerance wells in the surface interval. Follow the traveling cylinder / no-go plot per established procedures. Should not need to run a gyro. Magnetic interference is expected to be minimal. '" Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Obiective is to keep DLS ~1 0 over planned. ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.50 motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TO to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. ~ Drill Pipe specs: from Premium classification, not New. 5",19.5#,4-%" IF, IG1 ID Collapse 100% 4.276 8,765 psi 80% 3.250(tool joint) 7,012 psi ***Max Recommended MU Torque: 26,800 ft-Ibs ***Min Recommended MU Torque: 25,900 ft-Ibs ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. Burst 12,526 psi 10,021 psi Torsional 45,200 Ibs 36,200 Ibs Tensile 436,100 Ibs 348,880 Ibs ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. IN! ..................;;·;;^;~W-;·:;I-;- -1I11::cw.:wv.;:O¡:¡ ,: I:mlllllmlu;~;;;:_I'.'Ot'1'__II:III,II' ,::,I"-I;~"";-:;11;--;': '01-"""'" "l al:I'-,.¡;¡-;-,T'-I~ _ +:::II,:1 - -........-..T\-T,IlTn ,- --'-WYI;I- -1:1,:w........:HI,I:,:I¡:I-;IWlIMI·I.;·...··1 .;--;; ';;lm~II:-"-I-' --""'.....,.............;wu:; -11.'1-' -II Job3: Install Surface Casing Hazards and Contingencies: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV3 sands to ensure wellbore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to insure circulation is attained at TO at the desired cementing rates without losses. ~ Casing drift: 9-%" special drift casing is being used (8.835" drift required). Ensure that casing equipment is properly drifted to ensure adequate ID for the 8-3,4" bit, i.e. float equipment, casing hanger, etc. ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. As we will be downsizing the nozzles on the bit this may increase hole erosion slightly due to the extra nozzle velocity. A TAM Port collar will be placed at 1 ,OOO-ft MD. 8 Approved Greater Prudhoe B~y Polaris W-209i Permit ~ Losses during cement job: p) W-Pad lost circulation has been experiell~ed while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV3 sands is 12.5-lb/gal EMW. Follow the Halliburton recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. ~,;,~".,;.;,w..II,I,¡;I, ,~,:.;,-,:,:,:, ,a,WI;,;I,~ ,1!,1, -.-,1,-~~1111,1;1,;,11,1:,:,\~1,1,; ,~,.,.:,1O:I,.,:1,;,:,:,::,:':,::,::,~,:,I,I,':,;I,I,;;,I,\!.I,:.I,!1 ,:,;"r,~I,I,:;~.I,l,\\I,I,I,I,I_I,~;,~I,W, W,I,I ,:,1.111, ,I,I,I,I,\r,I,1,'I:,:,I,II:,II¡,1,11,~I_II,:,I,1,·;,.,:,:,;;,;I;,-,I,t<I,;,I:,~,I,I;,I,r,I,:,11,~I,.,'..,.,~,IIIIII,I,r,I~~I:W,I,rl,I,II, ,:.I.I,-,X,~,:,I,II,r,11~,I,I:I"I~IIII,III,I,r,~,I,~II,I,;_,,) ,I-,;-,;~I,1,1,~,r,I ,II ,I,:,I,_,,_I,),~,I,I :,,-¡,:,I,;,I,r,;I,1,11-,:,111,1,.,:,1:,:,~:~,¡,¡ Job 4: Drill 8%" Production Hole Hazards and Contingencies: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.5 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based upon the max expected Schrader reservoir pressure of 8.9 ppg and a 9.2 ppg mud, an 11.5 ppg leak-off will provide just over 50 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.5 ppg. Based upon off- set drilling data on W -Pad, a minimum leak-off of 12.5 ppg is expected at the 9-%" shoe. ~ 711 casing landing point: The landing point for the 7" casing will be determined by depth based on changes in GR/Res curves associated with the base OBf sand. After seeing the base OBf, TD will be picked based on drilling 150' MD past this base. This footage is critical for future wellwork. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. ~ Torqüe: Modeling indicates that high torque values, in the 12,000 to 13,500-ftlb range can be expected by section TD. Use lubricants as per the MI program. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 BU to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing point for this hole section. As mentioned above in the landing point discussion, the landing of this well will depend on picking the base OBf sand which will be picked by Gamma Ray. Therefore if we loose the GR tool, we will need to trip for it. ~ Faults: Two faults are planned to be crossed up in the UGNU after the surface casing shoe. These faults have been crossed on numerous wells and are not expected to cause any drilling problems. The fault details are listed below for reference: Fault #1: 6,050' MD Fault #1: 8,400' MD 3,504' TVD 4,553' TVD 3,424' TVDss 4,473' TVDss Throw: 40' West Throw: 30' South ~ Directional Constraints: It is critical to not let the angle get any higher then planned, due to slickline access requirements. It is critical to design a BHA to minimize inclination walking tendencies to minimize wellbore tortuousity. DLS should be kept ~1 0 over planned. 'A.,~:':_~.()j':I:""":I..:l~¡';;');"':+'w~, 'It,'( -~1~:-"~~w,."",,.,..,I,.'/I:-».--mnX,\_\, " ,"~¢I:' I.;~,;AI;'¡';:~,j:iolll!:<,:-~)~ .,:"".,:.¡.(:I,.,.*,t1'õ~"":II'l'IM,~\4,r¡;.,I,"-"~~"\)':':io,:<':iI''':;,1''''':I I>I:~''''-''<-,,,,",*»¡,.;,.~tõ:':,\':I O'~,),L;,,~'¡;r..-..,,.) O,1M>':1>.1,;r~""~I,o,;~~~'¡;'¡:'I\A,.,.J..""'!'I:+;M~_M.I.I.~*:",~>,,.M'-..),','c:l;"'+'~¡":';¡(~"":S!!,!,1~1'!, frr*,....n,,,~. .~.,\...')*~,'~~~~~,~",n:O::;:<"~'*'''':I.'r~.',....';~,.:\,,ÕIo>,.:l: Job 6: Install 7" Production Casinq Hazards and Contingencies: » Tight hole, packing off and lost circulation have been experienced while running casing though this interval. Good hole cleaning and mud conditioning are required for running this string. » Centralization/Differential Sticking: See centralizer strategy under Section 3: Drilling Program Overview. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement strategy is: Pip # 1: TBD, Pip #2: TBD ~ Cement Job: It is imperative to achieve a good cement job on this well due to the water wet OA sands. Good zonal isolation of this sand is imperative to the production success of this well. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job above the Ma sand. Keep cementing ECD's below 12.5 ppg EMW during the displacement. » Mud Requirements: Thin the mud as per Ml's Mud Program. The thinner the mud the better displacement is 9 Approved Greater Prudhoe Bay Polaris W-209i Permit achieved and the better the cernlnt job will be. Extra time spent Circulating,) warranted to ensure optimum mud properties and hole cleaning prior to the cement job. ~ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 1" casing. ~ 7" Casing Specifications: 7", 26#, L-80 BTC 100% 800/0 ID 6.276 6.151 (drift) Collapse 5,410psi 4,328psi Bu rst 7,240psi 5,792psi Tensile 667,0001bs 533,6001bs ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor _·__~_~·,--I-I·,::tll::11::I:_- :II;:::;I::::_.~.",:.,..Mo_1.111111" ;.II1:1:lnl:I":"I~IIT~ml:I:~~!!I ". '-IIU_~TlIW ,.mm:I,~:m~:_ -; .m~~H'11 Job 10: DPC Perforate Well Hazards and Contingencies ~ The well will be perforated ±105 psi over-balanced. Ensure all personnel are well briefed on Halliburton's perforating procedures and that all responsibilities are understood. ~ It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, perforating crew and the Halliburton hand. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. » Contact Halliburton to prepare for approximately 140' of 4-%" Millennium charge guns at 6 spf. Exact perforation depths will be provided after reviewing the LWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. Follow the LCM decision tree for "After Perforating". Position guns either by DP measurement based on previous logging I cleanout trip or by utilizing the Schlumberger GR tool in the string. Reference RP: .:. 'Halliburton DPC Procedure' ~~:1" W,W\<l $l;~;,i \(~~~,'I4:n~II:(}~J:':~ ~' 'I',~;~~~~~ð:;')'~~~'~:t:';~I:".;Ij¡,~~~~~~~~,':, ':I.~;¡t):~~~*~·:li~;I!I;~~::<I:"-\")f'r~':'!~":«-.¡;'I,,¡¡¡'"':'¡~~ ,;:~~"':¡J~~;:'1'~:f~·,' " """"""':t':t'·"''I':'-''~-':W.~~I:''''''''~~;~~':I.¡:<,,,iIt;;J I;·':''~~;~~ó\'',·~.¡I,~1!.I:'.I:;~m*'''''M~~~@'~"'I"¡~I"~;~~I I,'Ì!(~-¡\;~~~~;(I:Õ!I'~I:I;t:I.~~,\~~~~I:'I~<IKó!i.~~t~~~~i:.I:I:I;':"~':'~:I:>¥"~.(!'.(1I,'I\(,"'I:'I,':~, ~,~,\I..~~\/),~«-t;w:;,ql1:l:'~'~I,~~':',;:<1¡I,1;I Job 12: Run Completion Hazards and Contingencies: ~ Dirty Hole: It is critical to have a clean hole to run this completion in due to the production packer. Take time if deemed necessary to run a GR/JB. If the packer partially prematurely sets, set it all the way and run in and chemical cut and remove the completion. Reference RP: .:. 'Completion Design and Running' RP Job 13: ND/NU/Release RiQ Hazards and Contingencies: ~ Diesel will be used to freeze protect the well. The diesel flash point Is 100° F. Diesel vapor pressure is - 0.1 psia at 1000 F. 10 Approved TAM , 40 11ft, BTC x RA -TBD' TVDss TVDss MikT ... ... .... ... ... ... :: TREE: 4-1/16" 5M WELLHEAD: FMC 11",5M 1 1 1 1 ì. X 34" 215.5 ¡bitt, A53 114' !nsulated 4-1/2" 'X' TVD I with 3.813" seal bore, Cameo gas lift mandrel 4-1/2" xi" KBG2 With DCR Shear Valve pinned to 2,500 TVD .. 'X' 4-1/2", 12.75Ib/ft, l-80, TCII Drift 1 10: 3.833"13.958" 3-1/2", 9.3 Iblft, l-80, TCII Drift 110: 2.867"/2.992" 3.813" bore. Baker 'PRM' Production Packer 200' MD above the top OBa per! 'X· with 2.813" seal bore. TBD Cameo 3-1/2" x 1-1/2" Injection Mandrel x Baker 'PRM' Production Packer 'X' with 2.813" seal Baker 'S-3' Production Packer 2.813" seal bore. 3-1/2" WireUne Guide above the top ~Bd sand Perfs: .... , PBTD TBD MD MD 1 7". 26 L80, BTC-Mod '--' 4000 10ú_ 9000 3000 4000 5000 6000 Vertical Section (ft) Azim = 92.8°, Scale = 1:1000 Origin = 0 N/-S, 0 EJ-W 1000 8000 7000 2000 5000 . . . . . . 3000 2000 ... {................................................... t·"........·· .".. .......,.. ................0:,..................................................... -.. ~....................... .".................. ....... ...0;........ .......... ...................... ............. ..]:................................... ........... ......~...................... ... ....... ........ ........... O¡.,. .................................. ....... ..............~....... ....................................................; -. or'" -.. -" -.... _.. -..-.... - .. - "1'· -.. -... -.. -. -.. -.." -. ._.~ -ŠV4 .-..- ...-... -..-..-... -. 't,· -... -...-..-.. - ..-..-..-... -f'- c. -. .-..- ..-. ._..._c. -.. -:>1-" -... - ..-..-", -. .-....-., -. '1"-"'-" - ..-. ._c._. .-..-.. - ~._.._.c -. .-..-..-... _.._c._~ ~r··_c._. .-.. _c. -.. _..._c._.. ~ . . .. .. .. . .. . ~ .. c .. c .. . . . .. ~ .. .. .. .. ... ... .. ... .. . ~ .. ... ... ~ ... ... ~ . ... ... .. ... ... ... to .. -........ c ~ ~ 9.5~" Csg pt ~ ~ ~ ~ i ... to ... ~ ~ I ~ ..... ........... ..... ......... ~ .... ............. " .. '" .. .. ... .. -"i""" -. .-.. -.. -.. -,,-., -.. -.. ~.. -..-.. -.. -. .-. '-"-'. - "-'i švj"- ..-.. ..- ··t· '_n_ "-" _.._.._.._.._.._~._.._.._.._.._.._.._..- .._.~_.._.._.._.._. ._.._u -.. -"1"-"-"-"-' ._.._.._.._.._~._.._.._.._.._. .-..-..-.. -"r "-"-"-" -..- ..-..-..-....; __KOP Bid 11100 _Bid 2.5/100 _Bid 4/100 o 9000 8000 tvD Ref: KB (80.40 It atxw. MSL) SIvy Dats: July 07. 2003 7000 Miscellaneous Slot: W-209 W-209 (P6) 6000 NAD27 AIasI<a State Planes. Zooe 04. us Feet NorIhò1g: 5959130.05 nus Grid Com: +0.85426299' Easting: 612048.86 flUS Scale Fad: 0.9999142622 4000 5000 I FIELD I Swfaœ l.oc<fi>o ~17.2003 Lat 1'101750.236 fil527.6 nT Lon: W149 5 33.440 3000 Das: FS: 2000 I VÆ~ I Magnetic p~ Model: BGGM 2002 1000 [);po 80.782' Mag Dee: <25.514' STRUCTURE W-PAD Prudhoe Bay Unit - WOA Plan W-209 Schlumberger o 5000 4000 2000 e- O' 0 0 ~ .- II Q) (5 3000 u Cf) 0 > I- 1000 o o '-/ 8000 4000 5000 «< W Scale = 1:1 OOO(ft) E >>> 1000 7000 6000 3000 2000 -2000 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . ; : : : : : '..HHUU.HUHU.HJ.U.U..HU.UHH...HH.....HHH.....H.J....HHUU.HHUUUH.U....U....HU.HHU'.U.H...H....HH.....H. U.HHUU.H..H......~ · . . . . . . . · . . . . . . . · . . . . . . . · . . . . . . . · . . . . . . . · . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . · . . . . . . . . ¡ KOP ~~d ~~:" ¡ ¡ ~5~. c"" ¡ .uuuHLHHHHU.H_HU....¡U...HHHU......HUUH+HHHHH.UH.H.U...~~;. ....~~~~~~~~).. · / Bid ~1" . ',j . . "HHHHHHHH. . .. ........ .. '.. ... .................-1 ; / -::::-.:.UHU:UHHU.HUU.....~HHUU.HH:;¡¡TH¡UHH..U.HH.U.H·T... ¡ . ¡ ¡ ('!\ ..... I ..'" .... " ' '- , , , , , , , · . . ,. . . . '. . · . . . . . . . " . · . . . . . . .... i KBE E,dBId : i : : : ¡ ibI7Hc" · . . . . . . . · . . . . . . . ¡ ¡ ¡ ¡ ¡ w·",,,,. ¡ ¡ · . . . . . . . -1 000 o 1000 2000 8000 7000 6000 5000 4000 3000 2000 1000 MisœIaneous Slot: W-209 TVD REI: KB (80.40 ft ¡j oyeldSl) W-209 (P6) S<vy Dale: Jùy 07. 2003 I Suface localioo Sep<ember 17,2003 [at N70 17 50236 575ZT.6 nT Lon: Date; FS; ~; 80.782' Mag Dee: +25.514" I ~l I MagneIic- Model; BGGM 2002 NAD27 Alaska Stale --.... Zone 04, US Feet Nailing; 5959130.05ftUS GridConv: -+0.85426299" Easting: 612048.86ftO$ ScaSeFacI: OjJ999142622 STRUCTURE W-PAD I FIELD Prudhoe Bay Unit - WOA Plan W-209 Schlumberuer o -2000 1000 ^ ^ ^ z 4? Õ 0 0 T"" T"" 0 " Q) ro u Cf) Cf) v v v -1 000 2000 o KBE KOP Bid 1/100 Bid 2.5/100 Bid 4/100 End Bid SV5 bp W-209 (P6) Proposal Schlumberuer Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPI#: Survey Name I Date: Tort I AHD I DOlI ERD ratio: Grid Coordinate System: Location latlLong: Location Grid NJE Y/X: Grid Convergence Angle: Grid Scale Factor: July 7, 2003 Survey I DLS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA t" I Y Vertical Section Origin: W-PAD I W-209 ØlllØty 5 ötJ TVD Reference Datum: Plan W-209 F as 111I b I I TVD Reference Elevation: W-209 e Sea Bed / Ground Level Elevation: 50029 Magnetic Declination: W-209 (P6) I July 7, 2003 Total Field Strength: 63.464 ° 18471.10 ft 16.012 11.533 Magnetic Dip: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: N 70.29728775, W 149.09262235 Magnetic Declination Model: N 5959130.050 ftUS, E 612048.860 ftUS North Reference: +0.85426299° Total Corr Mag North -> True North: 0.99991426 Local Coordinates Referenced To: Minimum Curvature I Lubinski 92.800° N 0.000 ft, E 0.000 ft KB 80.40 ft relative to MSL 51.90 ft relative to MSL 25.514° 57527.616 nT 80.782° September 17, 2003 BGGM 2002 True North +25.514° Well Head Comments Measured Depth (ft) 0.00 300.00 400.00 500.00 600.00 Inclination ( deg ) 0.00 0.00 1.00 3.50 7.50 11.50 15.50 19.50 23.50 27.50 31.50 35.50 39.50 43.50 47.50 51.50 55.50 59.50 63.46 63.46 Azimuth ( deg ) 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 92.80 TVD (ft) 0.00 300.00 399.99 499.91 599.43 698.04 795.26 890.61 983.63 1073.87 1160.89 1244.26 1323.58 1398.46 1468.54 1533.47 1592.94 1646.66 1693.96 1915.40 Version DO 3.1 RT ( do31 rC399 ) 3.1 RT Service Pack 2.03 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1900.00 1999.09 2494.75 Sub-Sea TVD (ft ) -80.40 219.60 319.59 419.51 519.03 617.64 714.86 810.21 903.23 993.47 1080.49 1163.86 1243.18 1318.06 1388.14 1453.07 1512.54 1566.26 1613.56 1835.00 Vertical Section (ft) 0.00 0.00 0.87 4.80 14.38 30.88 54.22 84.29 120.93 163.97 213.20 268.39 329.25 395.50 466.81 542.83 623.20 707.53 794.58 1238.02 NS (ft) 0.00 0.00 -0.04 -0.23 -0.70 -1.51 -2.65 -4.12 -5.91 -8.01 -10.41 -13.11 -16.08 -19.32 -22.80 -26.51 -30.44 -34.56 -38.81 -60.47 EW (ft ) 0.00 0.00 0.87 4.79 14.36 30.85 54.16 84.19 120.78 163.78 212.95 268.07 328.86 395.03 466.25 542.19 622.46 706.68 793.63 1236.54 DLS ( degJ100 ft ) 0.00 0.00 1.00 2.50 4.00 .;/ 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 4.00 0.00 W-209\Plan W-209\W-209\W-209 (P6) Tool Face ( deg ) 92.80M 92.80M 92.80M 92.80M O.OOG O.OOG O.OOG O.OOG O.OOG O.OOG 4.00 4.00 4.00 4.00 4.00 O.OOG O.OOG O.OOG O.OOG O.OOG O.OOG O.OOG O.OOG O.OOG O.OOG Northing ( ftUS ) 5959130.05 5959130.05 5959130.02 5959129.89 5959129.56 5959129.00 5959128.21 5959127.19 5959125.95 5959124.48 5959122.81 5959120.94 5959118.87 5959116.63 5959114.21 5959111.63 5959108.90 5959106.04 5959103.08 5959088.03 Easting ( ftUS ) 612048.86 612048.86 612049.73 612053.66 612063.23 612079.72 612103.05 612133.09 612169.71 612212.72 612261.92 612317.07 612377.89 612444.10 612515.36 612591.33 612671.65 612755.92 612842.91 613286.05 -- latitude Longitude N 70.29728775 W 149.09262235 N 70.29728775 W 149.09262235 N 70.29728764 W 149.09261529 N 70.29728711 W 149.09258354 N 70.29728583 W 149.09250604 N 70.29728363 W 149.09237259 N 70.29728052 W 149.09218383 N 70.29727650 W 149.09194069 N 70.29727161 W 149.09164435 N 70.29726587 W 149.091? <J - N 70.29725930 W 149.09089810 N 70.29725193 W 149.09045183 N 70.29724380 W 149.08995960 N 70.29723495 W 149.08942383 N 70.29722543 W 149.08884713 N 70.29721527 W 149.08823229 N 70.29720453 W 149.08758233 N 70.29719326 W 149.08690040 N 70.29718162 W 149.08619640 N 70.29712229 W 149.08261021 Generated 7 f7 12003 10:25 AM Page 1 of 2 Comments Measured Inclination Azimuth TVD Sub·Sea TVD Vertical NS EW DLS Tool Face Northing fasting Latitude Longitude Depth Section (ft) ( deg ) ( deg ) (ft) (ft) (ft ) (ft) (ft) ( degl100 ft ) ( deg ) ( ftUS ) (ftUS) Base Perm 2528.32 63.46 92.80 1930.40 1850.00 1268.05 -61.93 1266.54 0.00 O.OOG 5959087.01 613316.07 N 70.29711826 W 149.08236729 SV4 2819.30 63.46 92.80 2060.40 1980.00 1528.38 -74.65 1526.56 0.00 O.OOG 5959078.18 613576.23 N 70.29708340 W 149.08026200 SV3 3960.84 63.46 92.80 2570.40 2490.00 2549.66 -124.53 2546.62 0.00 O.OOG 5959043.51 614596.83 N 70.29694638 W 149.07200284 9-5/8" Csg Pt 4162.29 63.46 92.80 2660.40 2580.00 2729.88 -133.33 2726.63 0.00 O.OOG 5959037.40 614776.93 N 70.29692216 W 149.07054535 SV2 4408.50 63.46 92.80 2770.40 2690.00 2950.16 -144.09 2946.64 0.00 O.OOG 5959029.92 614997.06 N 70.29689254 W 149.06876398 SV1 5135.95 63.46 92.80 3095.40 3015.00 3600.97 -175.87 3596.68 0.00 O.OOG 5959007.83 615647.44 N 70.29680493 W 149.06350088 UG4 5986.51 63.46 92.80 3475.40 3395.00 4361.93 -213.04 4356.72 0.00 O.OOG 5958982.00 616407.89 N 70.29670230 W 149.05734715 UG4A 6076.04 63.46 92.80 3515.40 3435.00 4442.03 -216.95 4436.73 0.00 O.OOG 5958979.28 616487.94 N 70.29669148 W 149.05669939 UG3 6803.49 63.46 92.80 3840.40 3760.00 5092.84 -248.74 5086.76 0.00 O.OOG 5958957.19 617138.32 N 70.29660352 W 149.05143639 UG1 7889.08 63.46 92.80 4325.40 4245.00 6064.06 -296.17 6056.82 0.00 O.OOG 5958924.23 618108.89 N 70.29647197 W 149.04358246 Ma 8605.33 63.46 92.80 4645.40 4565.00 6704.86 -327.47 6696.86 0.00 O.OOG 5958902.48 618749.27 N 70.29638498 W 149.0384bw4 Mb1 8706.06 63.46 92.80 4690.40 4610.00 6794.97 -331.87 6786.86 0.00 O.OOG 5958899.42 618839.32 N 70.29637274 W 149.03767184 Mb2 8840.36 63.46 92.80 4750.40 4670.00 6915.12 -337.74 6906.87 0.00 O.OOG 5958895.35 618959.39 N 70.29635641 W 149.03670024 Me 8997.04 63.46 92.80 4820.40 4740.00 7055.30 -344.58 7046.88 0.00 O.OOG 5958890.59 619099.47 N 70.29633735 W 149.03556670 Na 9142.53 63.46 92.80 4885.40 4805.00 7185.46 -350.94 7176.89 0.00 O.OOG 5958886.17 619229.55 N 70.29631965 W 149.03451414 Nb 9220.87 63.46 92.80 4920.40 4840.00 7255.55 -354.37 7246.89 0.00 O.OOG 5958883.79 619299.59 N 70.29631011 W 149.03394737 Ne 9321.59 63.46 92.80 4965.40 4885.00 7345.66 -358.77 7336.89 0.00 O.OOG 5958880.73 619389.64 N 70.29629785 W 149.03321867 OA 9556.62 63.46 92.80 5070.40 4990.00 7555.92 -369.04 7546.91 0.00 O.OOG 5958873.60 619599.77 N 70.29626923 W 149.03151838 OBa 9679.72 63.46 92.80 5125.40 5045.00 7666.06 -374.41 7656.91 0.00 O.OOG 5958869.86 619709.83 N 70.29625423 W 149.03062775 OBb 9758.06 63.46 92.80 5160.40 5080.00 7736.15 -377.84 7726.92 0.00 O.OOG 5958867.48 619779.87 N 70.29624468 W 149.03006099 OBe 9869.98 63.46 92.80 5210.40 5130.00 7836.27 -382.73 7826.92 0.00 O.OOG 5958864.08 619879.93 N 70.29623104 W 149.02925133 Target 10004.28 63.46 92.80 5270.40 5190.00 7956.43 -388.60 7946.93 0.00 O.OOG 5958860.00 620000.00 N 70.29621466 W 149.02827974 OBd 10004.30 63.46 92.80 5270.41 5190.01 7956.45 -388.60 7946.95 0.00 O.OOG 5958860.00 620000.02 N 70.29621466 W 149.02827958 OBe 10183.34 63.46 92.80 5350.40 5270.00 8116.63 -396.42 8106.94 0.00 O.OOG 5958854.57 620160.10 N 70.29619282 W 149.02698429 OBf 10306.45 63.46 92.80 5405.40 5325.00 8226.76 -401.80 8216.95 0.00 O.OOG 5958850.83 620270.16 N 70.29617780 W 149.02609367 10429.56 63.46 92.80 5460.40 5380.00 8336.90 -407.18 8326.95 0.00 O.OOG 5958847.09 620380.23 N 70.29616277 W 149.02520305 OBf Base 10429.58 63.46 92.80 5460.41 5380.01 8336.92 -407.18 8326.97 0.00 O.OOG 5958847.09 620380.25 N 70.29616277 W 149.0252r .....q TD / 7" Csg 10579.56 63.46 92.80 5527.41 5447.01 8471.10 -413.73 8460.99 0.00 O.OOG 5958842.53 620514.33 N 70.29614446 W 149.024t_~ Leqal Description: Northinq (Y) rftUSl Eastinq (X) rftUSl Surface: 4153 FSL 1189 FEL S21 T11N R12E UM 5959130.05 612048.86 Target: 3760 FSL 3803 FEL S23 T11N R12E UM 5958860.00 620000.00 BHL: 3734 FSL 3289 FEL S23 T11N R12E UM 5958842.53 620514.33 Version DO 3.1 RT ( do31 rL399 ) 3.1 RT Service Pack 2.03 W-209\Plan W-209\W-209\W-209 (P6) Generated 7/7/2003 10:25 AM Page 2 of 2 (:9I1Ì,pJny: i': ". . Fielð: ."" .. ........ . '.. ···~~f~r~J1t~'$he,:, ....... '. "Rèfêreo¢êWell:' . '. ..·.Ï{ë¡~'r~o£é·"'.~lIp~th; SUQ1mary ) BPX AK Anticollision Report ) Re:~nçe:Q[{l~t>:...n.c.... :.~;~~el,~...,...~..;G.a..... ~:; ft .. 'if y.:1(, '.ft. 691.30 700.00 643.07 11.38 691.33 700.00 643.03 11.31 644.59 650.00 674.30 10.04 643.95 650.00 487.63 9.40 643.95 650.00 487.63 9.19 643.95 650.00 487.63 9.19 943.41 950.00 110.07 16.35 943.41 950.00 110.07 16.35 691.44 700.00 467.19 10.99 567.08 600.00 352.96 9.19 493.77 500.00 222.79 7.34 730.66 750.00 504.22 16.84 691.88 700.00 503.17 15.75 737.64 750.00 535.53 13.28 634.84 650.00 570.69 9.86 642.76 650.00 570.78 9.97 594.75 600.00 606.35 10.10 337.66 350.00 296.60 7.15 373.96 350.00 315.50 7.31 346.39 350.00 315.25 6.97 385.50 400.00 336.03 6.81 430.14 450.00 384.84 8.81 431.45 450.00 410.94 7.65 431.03 450.00 437.44 8.46 385.45 400.00 467.37 8.74 388.12 400.00 467.39 8.52 388.12 400.00 467.39 8.78 337.71 350.00 276.06 5.99 337.71 350.00 276.06 5.99 431.56 450.00 291.81 9.21 385.40 400.00 307.99 6.32 431.48 450.00 328.44 8.04 431.48 450.00 328.44 8.04 385.85 400.00 351.41 6.92 388.39 400.00 351.45 6.85 431.40 450.00 375.22 9.15 431.40 450.00 375.22 8.99 384.41 400.00 400.15 7.83 393.61 400.00 455.91 6.79 431.96 450.00 513.00 6.46 PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad PB W Pad W-200PB1 W-200 W-201 W-203 W-203 W-203 W-207 W-207 W-20 W-211 W-212 W-21 W-21 W-22 W-23 W-23 W-24 W-25 W-26A W-26 W-27 W-29 W-30 W-31 W-32 W-32 W-32 W-34 W-34 W-35 W-36 W-37 W-37 W-38 W-38 W-39 W-39 W-40 W-42 W-44 W-200PB1 V7 W-200 V4 Plan: Undefin W-201 V4 W-203 V9 W-203L 1 V7 W-203L2 V3 W-207 V10 W-207PB1 V2 W-20 V1 W-211 V8 W-212 V12 W-21 V3 W-21A V12 W-22 V1 W-23 V3 W-23A V5 W-24 V1 W-25 V1 W-26A V3 W-26 V1 W-27 V1 W-29 V1 W-30 V1 W-31 V1 W-32 V5 W-32A PB 1 V12 W-32A V3 W-34 V1 W-34A V1 W-35 V1 W-36 V1 W-37 V3 W-37 A V3 W-38 V2 W-38A V10 Plan#4 W-39A VO Plan: W-39 V1 W-40 V1 W-42 V1 W-44 V1 631.71 631.75 664.32 478.44 478.66 478.66 93.92 93.92 456.21 343.95 215.51 487.38 487.42 522.26 560.85 560.84 596.25 289.45 308.20 308.28 329.23 376.03 403.29 428.98 458.63 458.87 458.61 270.07 270.07 282.60 301.67 320.40 320.40 344.49 344.60 366.07 366.23 392.32 449.12 506.54 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk ) BPX AK Anticollision Report ) i . çQmpa~y;··· '.' ···BPArnoco .. · ...: ..: .. Fi~I~;i ..... .. ...:i '. ·í?rLJøhg~iBåY .. .. ... .. .. ... ª~t~r~~~e$if¢;i·...jPp·. ......· B.·a··.i..·...n·.w.... ......·..w.....···.:.·.p.·..··.JS2.. :d.o··.··g·. i.... ........... .... .~!f~re~ce.*~II:: . . ·.··~~t~reiic~W~llpat~h PJânW~2Ø9····· '.' NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 50.00 ft Depth Range: 28.50 to 10579.56 ft Maximum Radius: 3000.00 ft 'Date: #7í2()Ò3 ··tiriu~: '.. '·10:39:43; Reference: Error Model: Scan Method: Error Surface: . .. .... ... . ... 0"".. ::: :." ..".. '. . ...... .. ..... . ....... ...... . ...... . .,... . . . .. .. .... .... . ..'........... . .. .. .._.. . . .. ... . .... .. .' .. . . ':".:":. "."". .... ...... ........ ..... ......... ..W~n:PI~11Wf20~,Tr()~Nbrth . W~209pl~r1ßOA ... ........ . .. ..... . ·········i)bi 'Syb¡¡¡se Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Pagerl . .. ..... ...... ....... . ...... .... .. ........... ..". ...... ... '. :..... '.' . :. ":..: ...:"' ..' ..::":.., . ...... .:.....: ....:....... . . ... . ... ....",.... ... ........:. "::." :.......... ...... ." ..... . .. ... .... ". ..... çOnþr~~~a~~(NF,i)·Í{~~~~e~f~: . ". Ve~~~ëa~(TYDlR~fel:~~ëë:' . Survey Program for Definitive Wellpath Date: 2/27/2002 Validated: No Planned From To Survey ft ft 28.50 1000.00 Planned: Plan #6 V1 1000.00 10579.56 Planned: Plan #6 V1 Version: 4 Toolcode Tool Name GYD-GC-SS MWO+IFR+MS Gyrodata gyro single shots MWO + IFR + Multi Station Casing Points TVD ··ft . 4162.29 2660.40 10579.56 5527.42 Diameter . .. HölêSize.· . ;in ". ······ih 9.625 12.250 95/8" 7.000 8.750 7" Summary Reference '. Offset Ctr-ÇtrNö~Go ¡Allowable '. MD . Mil ;DistanceÁr.ea i)eviation .. .<ft ·ft ft . ft ft PB W Pad Plan W-202 Plan W-202 V3 Plan: W- 346.93 350.00 746.31 7.66 738.65 Pass: Major Risk PB W Pad Plan W-204 Plan W-204 V3 Plan: W- 544.37 550.00 711.56 11.18 700.38 Pass: Major Risk PB W Pad Plan W-205 Plan W-205 OBd V6 Plan 1986.62 2000.00 425.74 49.15 377.07 Pass: Major Risk PB W Pad Plan W-206 Plan W-206 V3 Plan: W- 750.22 750.00 521.38 14.47 506.91 Pass: Major Risk PB W Pad Plan W-208 Plan W-208 V2 Plan: W- 346.91 350.00 816.35 7.67 808.68 Pass: Major Risk PB W Pad Plan W-21 0 Plan W-210 V3 Plan: W- 523.77 550.00 1153.04 10.37 1142.67 Pass: Major Risk PB W Pad Plan W-213 Plan W-213 V3 Plan: W- 546.28 550.00 257.55 10.69 246.86 Pass: Major Risk PB W Pad Plan W-214 Plan W-214i V4 Plan: W 546.23 550.00 183.43 10.90 172.53 Pass: Major Risk PB W Pad Plan W-215 Plan W-215 V4 Plan: PI 449.38 450.00 161.67 8.00 153.67 Pass: Major Risk PB W Pad Plan W-216 Plan W-216 V11 Plan: W 481.93 500.00 749.87 9.82 740.05 Pass: Major Risk PB W Pad Plan W-217 Plan W-217 V3 Plan: W- 346.92 350.00 781.31 7.77 773.55 Pass: Major Risk PB W Pad Plan W-218 Plan W-218 V3 Out of range PB W Pad Plan W-219 Plan W-219 V4 Out of range PB W Pad Plan W-220 Plan W-220 V1 Out of range PB W Pad Plan W-221 Plan W-221 V4 Out of range PB W Pad W-01 W-01 V1 546.86 550.00 32.74 10.11 22.63 Pass: Major Risk PB W Pad W-02 W-02 V4 547.32 550.00 64.90 8.16 56.92 Pass: Major Risk PB W Pad W-02 W-02A V20 548.51 550.00 64.91 8.18 56.92 Pass: Major Risk PB W Pad W-03 W-03 V4 589.29 600.00 100.55 10.23 90.32 Pass: Major Risk PB W Pad W-03 W-03A V1 596.97 600.00 100.67 10.33 90.35 Pass: Major Risk PB W Pad W-04 W-04 V1 638.00 650.00 136.22 10.33 125.90 Pass: Major Risk PB W Pad W-05 W-05 V1 638.25 650.00 171.52 10.39 161.13 Pass: Major Risk PB W Pad W-06A W-06A V2 695.76 700.00 241.63 11.84 229.79 Pass: Major Risk PB W Pad W-06 W-06 V1 695.76 700.00 241.63 11.84 229.79 Pass: Major Risk PB W Pad W-07 W-07 V1 589.85 600.00 208.53 13.15 195.38 Pass: Major Risk PB W Pad W-08 W-08 V1 687.67 700.00 275.48 11.17 264.32 Pass: Major Risk PB W Pad W-08 W-08A V11 693.40 700.00 275.55 10.95 264.60 Pass: Major Risk PB W Pad W-09 W-09 V1 540.21 550.00 311.96 9.54 302.43 Pass: Major Risk PB W Pad W-10 W-10 V3 548.90 550.00 346.85 10.93 335.92 Pass: Major Risk PB W Pad W-10 W-10A V4 548.90 550.00 346.85 10.93 335.92 Pass: Major Risk PB W Pad W-11 W-11 V1 638.84 650.00 381.00 9.87 371.16 Pass: Major Risk PB W Pad W-12A W-12A V3 498.32 500.00 417.92 10.10 407.82 Pass: Major Risk PB W Pad W-12 W-12 V1 498.32 500.00 417.92 10.10 407.82 Pass: Major Risk PB W Pad W-15 W-15 V1 587.50 600.00 291.98 9.70 282.28 Pass: Major Risk PB W Pad W-15 W-15A V10 587.50 600.00 291.98 9.70 282.28 Pass: Major Risk PB W Pad W-15 W-15PB1 V6 587.50 600.00 291.98 9.70 282.28 Pass: Major Risk PB W Pad W-15 W-15PB2 V1 587.50 600.00 291.98 9.70 282.28 Pass: Major Risk PB W Pad W-16 W-16 V3 636.16 650.00 326.38 10.65 315.74 Pass: Major Risk PB W Pad W-17 W-17 V1 692.59 700.00 360.39 11.66 348.73 Pass: Major Risk PB W Pad W-18 W-18 V1 691.99 700.00 395.96 12.23 383.74 Pass: Major Risk PB W Pad W-19 Plan#11 W-19AL 1 V1 Pia 642.64 650.00 429.57 10.65 418.93 Pass: Major Risk PB W Pad W-19 W-19 V2 635.79 650.00 429.49 10.40 419.09 Pass: Major Risk PB W Pad W-19 W-19A V1 642.64 650.00 429.57 10.48 419.10 Pass: Major Risk STATE OF ALASKA http://www.state.ak.us/local/akpages/ ADMIN/ ogc/ orders/aio/ai025 ) ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: THE APPLICATION OF BP EXPLORATION (ALASKA) INC. for an order authorizing underground injection of fluids for enhanced oil recovery in Polaris Oil Pool, Prudhoe Bay Field, North Slope, Alaska ) Area Injection Order No. 25 ) ) Prudhoe Bay Field ) ) Polaris Oil Pool ) February 4, 2003 IT APPEARING THAT: 1. By letter and application dated September 12, 2002, BP Exploration (Alaska) Inc. ("BPXA") in its capacity as Polaris Operator and Unit Operator of the Prudhoe Bay Unit ("PBU") requested an order from the Alaska Oil and Gas Conservation Commission ("Commission") authorizing the injection of fluids for enhanced oil recovery in the Polaris Oil Pool within the PBU. 2. By letter dated October 31, 2002, BPXA amended its Polaris Pool Rules and Area Injection Order ("AIO") Application and withdrew its request for approval of injection of miscible injectant ("MI") as part of the current Enhanced Oil Recovery proj ect. 3. Notice of a public hearing was published in the Anchorage Daily News on November 8, 2002. 4. The Commission held a public hearing December 9, 2002 at 9:00 AM at the Alaska Oil and Gas Conservation Commission at 333 West 7th Avenue, Suite 100, Anchorage, Alaska 99501. 5. On December 18, 2002 and January 22, 2003, BPXA submitted for the public record exhibits containing infonnation previously submitted within confidential exhibits. 6. The Commission may issue an order pennitting underground injection of fluids on an area basis for wells within the same reservoir and operated by a single operator. FINDINGS: STATE OF ALASKA http://www.state.ak.us/local/akpages/ ADMINI ogcl orders/aio/ai025 ) ) 1. Operator: BPXA is operator of the Polaris Oil Pool in the Prudhoe Bay Field, North Slope, Alaska. 2. Project Area Pool and Formations Authorized for Enhanced Recovery:_ Strata proposed for enhanced recovery injection are a subset of the Polaris Oil Pool defined in Conservation Order 484. The target injection zones are correlative to Prudhoe Bay Unit well S-200PB 1 between the measured depths ("MD") of 5,603 feet and 6,012 feet (Schrader Bluff Formation). Development plans for the upper portion of the Polaris Oil Pool (Ugnu Formation) have not been detennined and BPXA has not requested authorization to inject fluids into the Ugnu Formation. 3. Proposed Injection Area: BPXA requested authorization to inject fluids for the purpose of enhanced recovery operations on lands within Umiat Meridian TIIN-RI2E, TIIN-RI3E, TI2N-RI2E, and TI2N-RI3E in the Prudhoe Bay Unit. The application for an Area Injection Order provides information surrounding five discrete, widely spaced injections wells. These proposed injectors are wells S-104i, proposed redrill S-200Ai, S-215Ai, W-207i, and W-212i. 4. Operators/Surface Owners Notification: BPXA provided operators and surface owners within one-quarter mile of the proposed area with a copy of the application for injection. The only affected operator is BPXA, operator of Prudhoe Bay Unit. The State of Alaska, Department of Natural Resources is the only affected surface owner. 5. Existing Orders: a. Aquifer Exemption: Aquifer Exemption Order No.1, dated July 11, 1986, exempts freshwater aquifers lying directly below the Western Operating and K-Pad Areas of the Prudhoe Bay Unit. b. Area Injection Order: AIO No.3, dated July 11, 1986, authorizes underground injection of fluids within specified strata lying directly below the Western Operating Area and K-Pad Area of the Prudhoe Bay Unit for the purposes of enhanced recovery and the disposal of non-hazardous oil field waste fluids. AlO No.3, Rule 2 authorizes injection for disposal purposes in strata that correlates with the strata found in PBU Well C-ll between 3,990 feet and 6,293 feet MD. 6. Description of Operation: The Polaris Oil Pool will be developed in phases, beginning at the crests of the accumulations near the S-, M-, and W- Pads, and progressively working towards the outer margins of the pool. Peak production rates are expected to be between 12,000 and 15,000 barrels of oil per day ("BOPD"). Waterflood STATE OF ALASKA http://www.state.aleus/locallakpages/AD MINI ogc/orders/aio/ai025 ) ) injection rates are estimated to peak between 20,000 and 25,000 barrels of water per day ("BWPD"). 7. Hydrocarbon Recovery: The Polaris Oil Pool is estimated to contain 350 to 750 million barrels of original oil in place ("OOIP") based on exploratory drilling and seismic mapping. Computer simulation results indicate primary recovery within the target sands of the development area is expected to be 5 to 10% of the OOIP, and implementing a waterflood will recover an additional 10 to 20% of the OOIP._ 8. Geologic Infonnation: a. Stratigraphy: The Polaris Oil Pool encompasses reservoirs assigned to the Late Cretaceous-aged Schrader Bluff Fonnation ("Schrader Bluff') and the Early Tertiary-aged Ugnu Fonnation ("Ugnu"). The Schrader Bluff is divided into two stratigraphic intervals that are designated, ITom deepest to shallowest, the "a-sands" and the "N-Sands." The overlying U gnu reservoir intervals of the Polaris Oil Pool are infonnally tenned the "M -Sands." The 0- and N-Sand intervals were deposited in marine shoreface and shallow shelf environments. The M -Sands were deposited in deltaic and fluvial environments. b. The Schrader Bluff a-Sands are divided into seven separate reservoir intervals that are named, from deepest to shallowest, OBf, OBe, Obd, aBc, OBb, aBa, and OA. Each of these intervals coarsens upward from non-reservoir, laminated muddy siltstone at the base to reservoir-quality, thinly bedded sandstone at the top. c. The lower portion of the Schrader Bluff N-Sands is dominated by mudstone and siltstone. However, the sediments coarsen upward, and fine- to medium-grained sandstone is prevalent in the upper part of the N-Sands. Three reservoir intervals are recognized within the N-Sands. They are, ITom oldest to youngest, NC, NB, and NA. d. The Ugnu M-Sands are divided into four reservoir intervals named, ITom deepest to shallowest, MC, MB2, MB 1, and MA. These intervals consist of unconsolidated, clean sands that are separated by thin, but extensive, intervals of non-reservoir silty mudstone. e. Structure Overview: The Polaris Oil Pool structure lies between approximately 4,800 feet and 5,300 feet true vertical depth subsea ("TVDss") within the affected area. The structural dip ranges up to 4 degrees to the east and northeast, and it is broken by three sets of faults: one trending northwest, the second trending north, and the third trending west. These faults are nonnal, and they divide the structure into a series of reservoir compartments. Northwest- and north-trending faults are the primary controls for oil distribution in the W-Pad, S-Pad and M-Pad areas. The west-trending faults occur most commonly in the down-dip portions of the pool to the east and northeast. They trap oil in the center of the pool: near the Tenn Well C, near N-Pad, and along the southern margin of the pool. f. Confining Intervals: Lower confinement for the Polaris Oil Pool is provided by the non-reservoir, laminated muddy siltstone that constitutes the base of the OBf interval and 1,100 feet of mudstone and silty mudstone assigned to the upper Colville Group. g. The basal portion of the Schrader Bluff N-Sands interval consists of non-reservoir mudstone and siltstone that fonns a regionally extensive hydraulic barrier. This barrier separates lighter, higher quality oil in the a-Sands ITom the heavier oil accumulations in the overlying N- and M-Sand intervals. The MC Sand is separated ITom the underlying N-Sands STATE OF ALASKA http://www.state.ak.us/local/akpages/ ADMIN/ ogc/ orders/aio/ai025 \ " ) by a silty mudstone that ranges in thickness from 15 to 25 feet. h. Upper confinement is provided by a 14- to 25- foot thick mudstone that lies at the base of the MB2 interval and forms a regionally continuous hydraulic barrier. This mudstone layer separates oil-bearing MC Sand from overlying, water-bearing MB2 Sand within the pool. A 9- to 15-foot thick silty mudstone overlies the uppermost MA sand and provides a regionally extensive barrier. 9. Well Logs: The logs of existing injection wells are on file with the Commission. 10. Mechanical Integrity and Well Design of Injection Wells: BPXA is requesting approval to inject water simultaneously into the Aurora (Kuparuk Formation) and Polaris Oil Pools within well S-104i. Water is currently being injected into the Aurora Oil Pool within this well. This well is designed to allow dual inj ection with packers installed for zonal isolation. Injection valves will be sized for water injection rate control and will be run within mandrels between the packers. Spinner logs will be run to verify injection rates to the separate formations. 11. Type of Fluid / Source: Water for injection will be supplied from Gathering Center 2 and from the Seawater Treatment Plant. In addition, tracer survey fluids and well stimulation fluids will be injected periodically to ensure efficient operation of the water flood. Non-hazardous filtered water collected from Polaris Oil Pool well house cellars and well pads may also be injected. 12. Water Composition and Compatibility with Formation: BPXA provided laboratory analysis of the injection and produced waters. No significant compatibility problems are evident from these analyses. Disposal of PBU produced water within the U gnu sands has successfully occurred in other parts of the field. 13. Area of Injection Influence: The area of injection influence lies within 14 mile radial distance of the point of injection, assuming radial flow of the injected water. Reservoir simulation suggests that within 1,000 feet to 1,500 feet of the injector, the reservoir pressure dissipates to near reservoir pressure. 14. Injection Rates and Pressures, Fracture Information: The requested maximum water injection rate is 25,000 barrels of water per day ("bwpd") in the project area. The individual well injection rates will range ftom 1000 to 5000 bwpd. STATE OF ALASKA http://www.state.ak.us/local/akpagesl AD MIN/ogc/ orders/aio/ai025 ) ') BPXA requested a maXImum surface injection pressure of 2800 psi with an average surface operating pressure of 2300 psi. Step rate tests indicate fractures initiate at about 1000 psi surface injection pressure while injecting at 1 Yí to 2 barrels per minute. A stress test performed in well 8-213 indicates a fracture gradient of 0.66 psi/ft for the basal mudstone of the OBa interval. This is a typical silty mudstone within the Polaris Oil Pool. Minimum stress values for the sandstones show an average fracture gradient of 0.61 psi/ft, indicating a stress contrast of approximately 255 psi between reservoir sandstone and confining mudstone. This agrees with the stress contrast of 300 psi estimated using the dipole sonic log from well W -200. 15. Mechanical Condition of Adjacent Wells: Wells recently drilled into the Polaris Oil Pool have been constructed in conformance with Commission regulations. Many pre-existing exploratory and development wells in this area were drilled to deeper targets. The mechanical isolation of some wells in the Polaris Oil Pool has not been demonstrated. Ivishak producing well W-17 is within 255 feet of proposed injector W-212i at the level of MB2 mudstone. Information supplied does not demonstrate cement confinement across the Polaris Oil Pool in well W-17. BPXA's proposed surveillance program includes a pre-injection baseline temperature survey within well W -17 and additional temperature surveys at 2, 5, and 8 months after initiating water inj ection. CONCLUSIONS: 1. The application requirements of20 AAC 25.402 have been met. 2. Water injection will significantly improve recovery. 3. Dual injection within well S-104i is appropriate so long as mechanical isolation of the pools within the wellbore is assured and water injection is allocated between the pools. 4. Sufficient information has been provided to authorize five (5) wells to inject water into the Polaris Oil Pool for the purposes of pressure maintenance and enhanced oil recovery. 5. The proposed injection operations will be conducted in permeable strata, which can reasonably be expected to accept inj ected fluids at pressures less than the fracture pressure of the confining strata. 6. Injected fluids will be confined within the appropriate receiving intervals by impermeable lithology, cement isolation of the wellbore and appropriate operating conditions. 7. Reservoir and well surveillance, coupled with regularly scheduled mechanical integrity tests will demonstrate appropriate performance of the enhanced oil recovery project or disclose possible abnormalities. 8. Disposal injection in hydrocarbon bearing strata may harm resource development. NOW, THEREFORE, IT IS ORDERED that: 1. Within the affected area, this order supersedes Rule 2 of Area Injection Order No.3, dated July 11,1986 and Administrative Approval No. 3.1, dated August 15,1986. 2. The underground injection of fluids for enhanced oil recovery is authorized, subject to the following rules and the statewide requirements under 20 AAC 25 (to the extent not superseded by STATE OF ALASKA ) these rules) in the following affected area. Umiat Meridian http://www.state.ak.us/local/akpages/ AD MINI ogcl orders/aio/ai025 ) To~nship iRa~g'e 'r'--" Lease S;ctio~s TI2N-RI2E "T" ADL2'S256 . See 22 S/2 S/2 and NE/4 SE/4 r-'---'-- 1'-~~~7448-'~=[~ee' 23 S/2 N\V/4 and S~'/4 ____._._______ ADL 28257 See 25 SW/4 NW/4 and S\V/4 and SW/4 SE/4,; ¡ 26, 35, 36 : r--"- ------- ------ ----.--..----.--------.-.----.-- r---'-- -..-.--.---.-------.-. ------ .---- L.----------- ----------- . --- ---.---.----- -- - -- ., - "'.. -.- ------ --------------"! I ADL 18258 j See 27,33 S£/4 S£/4, 34 E/2 \V/2 and SW/4 ¡ I ¡ SW/4 and E/2 [~,-.-·--~·-~-ì~~~~·R·ï:.3E-,----·- -·--·:-·J----·~.'--AD-L, i~82-7?--·-·-~.-----r- s~c--jl--~:w~~··-N~/~-~~~·-S-\~~ï4.-.--~------~--~-- --.--~-~~~-.,-~- -,I : T11N-R13E ADL 28282 See 6 W/2 and SE/4 and S/2 NE/4 and NW/4 NE/4, Tl ADL 28260 ADL 28261 ADL 28263-1 ADL 28263-2 ADL 47451 ADL 28264 .. ADL 47452 Rule 1 See 7 N/2 and N/2 SW/4 and SE/4 SW/4 and SE/4, See 8 W/2 SW/4 See 1,2, 11 W/2 and NW/4 NE/4, 12 N/2 N/2 and SE/4 NE/4 See 3, 4 E/2 E/2, 9 NE/4 NE/4 and S/2 NE/4 and SE/4, 10 See 15, 16 E/2 See 21 NE/4 NW/4 and NE/4 SE/4 and NE/4, 22 N/2 and N/2 SW/4 and SE/4 SW/4 and SE/4 See 14 W/2 and W/2 SE/4, 23 W/2 and W/2 E/2 and SE/4 SE/4 and SE/4 NE/4 See 26 N/2 N/2 . . .' .. . See 27 NE/4 NE/4 Authorized Injection Strata for Enhanced Recovery Authorized fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata that are common to, and correlate with the N and a-Sand interval between 5,603 feet and 6,012 feet MD in Prudhoe Bay Unit well S-200PB 1._ STATE OF ALASKA http://www.state.ak.us/locallakpages/ ADMINI ogcl orders/aio/ai025 " II ) Rule 2 Fluid In.iection Wells The underground injection of fluids for enhanced oil recovery is authorized in the following wells: --_._, r-:;: '- . l' . ... .... -----..- -- 1·_·"I~!~~~·~~4~:':!':"~-'r:'~~~~:~9~~~~ts~~r;'~~~~;iN~~i;~~~~"~~'~~~·'·j . ~ ~.~~~OAi ..1·· 1?:-~~~ ...1 S~c ~7, ·~12~',.~~w~:..:~~r~p~.~.~d) S-215i 202-154 Sec 34, TI2N, R12E ,r'··· [~:.._- W-212i ..J Pr~p~~<~'d ~~ïi" ,. . r·S~·~··2'3:' TiiN: 'Ri2·E·-ëpr~Ï;~~~d)<' .,........" ", ~_]~=_.__=~~_~,~~-~~..--I See 22, TIIN, ~i2E . ..... .~,; _"iI'_ ".'um". ,t· _, ,_,., W-207i Upon proper application, the Commission may administratively approve additional wells for injection of fluids in the Polaris Oil Pool. The underground injection of fluids must be through a well that is permitted for drilling as a service well for injection in conformance with 20 AAC 25.005, or through a well approved for conversion to a service well for injection in conformance with 20 AAC 25.280 and 20 AAC 25.412. The application to drill or convert a well for injection must also include a report on the mechanical condition of each well that has penetrated the injection zone within a one-quarter mile radius of the proposed injection well. The information must include cementing records, cement quality log or fonnation integrity test records. Rule 3 Authorized Fluids for Enhanced Recoverv Fluids authorized for injection include: a. Produced water from the Polaris Oil Pool or Prudhoe Bay Unit production facilities for the purposes of pressure maintenance and enhanced recovery; b. tracer survey fluid to monitor reservoir performance; c. source water from a sea water treatment plant; and d. non-hazardous filtered water collected from Polaris Oil Pool well house cellars and well pads. STATE OF ALASKA Rule 4 Rule 5 http://www.state.ak.us/local/akpages/ ADMIN/ogc/orders/aio/ai025 ). Authorized Injection Pressure for Enhanced Recovery a. Normal injection pressures must be maintained below the parting pressure of the confining mudstone (approximately 0.67 psi/ft). b. Operating pressure within well W-212i must be maintained below parting pressure of the reservoir sandstone, until offset well W -1 7 is proven to provide sufficient mechanical isolation to prevent migration of water out of the approved injection stratum. Monitoring Tubing-Casing Annulus Pressure Tubing-casing annulus pressures within each inj ection well must be checked and recorded weekly to ensure there is no pressure communication or leakage in any casing, tubing or packer. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission that ensures that the tubing-casing annulus for each injection well is pressure tested prior to initiating injection, following well workovers affecting mechanical integrity, and at least once every four years thereafter. Rule 7 Rule 8 Multiple Completion of Water In.jection Wells a. Water injectors may be completed to allow for injection in multiple pools within the same wellbore so long as mechanical isolation between pools is demonstrated and approved by the Commission. b. Prior to initiation of co-mingled injection, the Commission must approve methods for allocation of inj ection to the separate pools. c. Results of logs or surveys used for determining the allocation of water injection between pools, if applicable, must be supplied in the annual reservoir surveillance report. d. An approved inj ection order is required prior to commencement of inj ection in each pool. Well Integritv Failure Whenever operating pressure or pressure tests indicate communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation and obtain Commission approval to continue injection. Commission approval of an Application for Sundry Approval (Form 10-403) is required before initiating corrective action. STATE OF ALASKA http://www.state.ak.us/local/akpages/ ADMIN/ ogc/orders/aio/ai025 Rule 9 ) Notification of Improper Class II In.iection ,) Injection of fluids other than those listed in Rule 2 without prior authorization is considered improper Class II inj ection. Upon discovery of such an event, the operator must immediately notify the Commission, provide details of the operation, and propose actions to prevent recurrence. Additionally, notification requirements of any other State or Federal agency remain the operator's responsibility. Rule 10 W-17 Surveillance Prior initiating injection within well W-212i, a baseline temperature survey within W-17 is required. Additional temperature surveys within well W-17 are required at 2, 5, and 8 months after initiating water injection to verify the W-17 wellbore is not serving as a fluid migration path. Results and interpretation of these surveys shall be supplied to the Commission within 30 days of completing the survey. Injection must be terminated in well W-212i if there is any indication of pressure communication or leakage within well W-17 attributed to injection in well W-212i. Rule 11 Plueeine and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25. Rule 12 Other conditions a. It is a condition of this authorization that the operator complies with all applicable Commission regulations. b. The Commission may suspend, revoke, or modify this authorization if injected fluids fail to be confined within the designated inj ection strata. Rule 13 Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive the requirements of any rule stated above or administratively amend any rule as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in an increased risk of fluid movement into freshwater. DONE at Anchorage, Alaska and dated February 4,2003. Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission Daniel T. Seamount, Jr., Commissioner Alaska Oil and Gas Conservation Commission STATE OF ALASKA http://www.state.ak.us/local/akpages/ ADMIN/ ogc/ orders/aio/ai025 " . ) ) Michael L. Bill, P .E., Commissioner Alaska Oil and Gas Conservation Commission AS 31.05.080 provides that within 20 days after receipt of written notice of the entry of an order, a person affected by it Month file with the Commission an P 055091 DATE ö/9/LUU3 CHECK NO, 0:,5U91 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 6/9/2003 INV# CK060403K PERMIT TO DRILL FEE W !1 ~ /);' \--{ ({,'j \l THE ATTACHED CHECK is IN PAYMENT FOR ITEMS DESCRIBED ABOVE. _,"!:o~ 1:', ..... c; . ',_,- _ L ." __~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 NATiONAL CITY BANK Ashland, Ohio 56-389 412 NosP 055091 CONSOLIDATED COMMERCIAL ACCOUNT PAY: B P t;," "/" (II) . . ~ ~ ..II,. "HI () () IJ: DATE June 9, 2003 AMOUNT *******$100.00******* TO THE ORDER OF: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 NOT VALl1«&~~~~:~>7~;::«:\?~:~<~0}:¡'. ~-':':"" -:.... -- IlIi 0 5 5 0 g . III ~: 0 t. . 2 0 ~ a g 5 i: o. 2 7 a g b II£! ) ) TRANSMITAL LETTER CHECK'LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new well bore segment of existing well Permit No, API No. Production, should continue to be reported as a function· of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name OD permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 Ojody\templates The permit is approved subject ,to fuD compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing ,exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. "vv.~~~~!;~M~r:ê~.~9ISL~,~J\ Company _.~~EXELQMIJQNJ8J.8.SKð)JN_C_ ..___.______.__._____.. . ..__ ______ Well Name: P.RUDJ:1QE...ßAY..UNYQL____W-:20.9.L. ...___.____ Program .S,ER Well bore seg PTD#: 2031280 Field & Pool J?,RU.QttQE_8.8Y,J:>.QlAHI.s_OJL.::..6.~tQ16.0_..___...___... Initial Class/Type ,__S.EBLL1WlN_J___. GeoArea Unit Jj_6..5_0_.. On/Off Shore _Qo_.___ Annular Disposal Administration 1 P~rrnitfee attached. . . . _ . _ . Y~s 2Le~s~numberaPRropriate. . . . . Y~s 3 ..U..niqu~ w~lI.. n.arn~ _aDd ournb.er . . . . . . . . . . . . . . . . .. _ .. . . . . _ _ _ _ . _ .. _ _ . . _ . . _ Y..e$ _ .. _ _ _ _ . . _ _ _ _ .. . . _ . _ _ _ .. _ . _ . . _ _ _ _ _ . .. _ .. . . _ . _ .. .. _ _ .. _ . _ _ . . _ _ . _ . .. _ , . . . .. _ _ _ .. _ . _ . . .. .. .. 14 ,W~II.lQcat~d in.a.d,efined.pool. . Y~$ . . . . . . . . . _ _ _ _ , _ . 5 .W~IIIQcat~d pr.op~r .distance. from dri.lling unit.b.ound.ary . Yes. _ . 6 .W~II.lQcat~d propE!r .distance_ from other wells_ . . . _ _ . . . _ . Yes. . . . . , , . 7 .S.ufficient ,acr~~ge ,ayailable iR dJilJiog unjt. . . . Y ~s 8 Jf.d~viatec!. .,is. weJlbQrE! plat,includec! . Yes. 9 .oper.ator only ~ft'eçt~d party. . . . . . . _ . _ . _ _ _ . . Y~$ . . . _ . . _. . _. _ . . . _ . . _ . . . . , . . , . , . 10 _Qpßr..atof bas.appropriate. Qond in JQrc~ .. . _ _ .. _ .. . _ .. . . . _ . . .. .. . .. .. .. .. _ .. _ , , , .. .. .. .. Ye$ _ _ _ _ _ _ _ . . _ .. , .. . _ _ . _ . . _ .. _ _ . , _ _ _ _ _ _ .. .. _ .. _ . . _ _ _ _ _ , _ _ .. .. .. .. _ _ _ _ . _ _ . . _ _ _ _ .. _ _ _ . _ _ _ . . . 11 p~rmit c.aD be i.ssued w.ithQut co_nsE!rvation order Y~s Appr Date 12 P~rmit c.aD Þe issued w.itbQut administrati\(e. approval. No. RPC 7/23/2003 13 Can permit be approved before 15-daywait Yes 14 _W~II JQcated within ar~~ and.strata .authorized by.lnjectioo Ord.er # (put 10# in. cor:nm~(lts) (For Yes ,. _ _ _ . AIO.2.5copy. attach.ed ,. 15 _AJlwßl]s..wit¡'i.n_1l4_l1JiI_e_af~a.ofreyißwid~otifißd(Fo(~erv,ic_e.w.etlonly). _ _ _.. _..... _., .Y~$_ _. _ _ _ .l?eUVV.-1.5~~PßW_W-J7..<-Tb~s~..noUde_ntified.byppeJatQr-a?jnj\.QR,)c.... _..... _ _. _ _ _. _. _. _... _. 16 pr~-prpduçed inj~çtor: dur.atio.n.of pr~-produc.tioo I~s$ t!1é:1n 3 months. (For_s~r::vice WE!ll o.n.!y) . . No., _ _ . _ _ _ _ _ _ . . . . . . . _ . . . . . . . 17 ACMP. Finding ,of Co.n_si.stenGY- h.a$ bee.n .i$sued_ for. tbis pr.olect. _ _ _ . _ _ _ _ _ _ _ _ _ . . . . _ . NA . . . . . . . . , . , _ . . . . ----~---,----- Engineering Appr Date WGA 7/24/2003 _.._'.'--~..... .,,,-,...-.-... ,-,---- -._,- Geology Appr RPC Date 7/23/2003 Geologic Commissioner: 4)~ [] [] - - - - - - - . All injectipn well.s .drilled.in the AIQ No.. 25 arßa r:n1J$tb~ .admini?tratively ~pproYed. per rule 2 . - - - - - - ( ._------------_._-_.,--_._------_..~_.._--- ---_."-~._-_._---_. ---..--.- --... -----_._,--~-,.,-_._"---_._-----"._._----- -------..---- 18 .C.ondu,cto[!~t(ing.PJo.vid~d _ . . . . . . . . . . . ., , . . . . . . _ _ . . . . . . . . Yes 19 ..s,ud'ac~.casing.PJQtec.t~ all_known. USDWs _ _ . . _ _ _ _ _ . . _ . _ , _ . _ _ . . . . Yes _ . . _ . _ _ _ _ _ _ . . . . _ _ . _. ".. _ . 20 _CMTv.ota.d~qu_ateJo circ.utate_o.n.cond.uçtor.& SUJfc?g . _ , _ , , . . . _ . . . _ _ . Yes , _ _ . _ . . Ade.quate ex.ce$S, , . . _ _ . . 21 ,CMT. v_ot adßqu_ateJ9 tiE!-inJo.ng .string to.sud' ç~g. . . . . . , . _ . _ . ,. . No. , _ . . _ . .. . _ . . . ,. . _ _ _ _ _ , . . . . . 22 ,CMTw.ill çoyer..aJll<lJo.w.n.pro.duçtiye bQri~Qn_s, , _ . . . . . . . _ . _ _ _ . . . .Y~$ _ _ . _ _ _ _ .. _ _ _ _ _ _ _ _ _ . . . . , . . " 23 .C.asing d~sign$ ad.equatE! fOr. C.T. B.K perrna.fr.ost. . . . .Y~$. _ . . _ . . _ _ ., ,. . . . . _ _ . _ _ . . . 24 Adequ.ate.tan.kage.oJ re_serve pit . , _ . . .. _ . . . . ,. . . Yes ., . . .. . . . Nab.ors.9.ES, . .. . , . . . _ . , .. . . . . . _ . . . , _ _ . _ _ . . . . 25 Jta.re-drill.. bas.a. 1.0A03 fQr .abandQn.me.nt beßO apPJo.vßd . . . _ . .. . _ . _ . . . _ _ . NA . . _ . . _ . . . . _ , . . . . , _ _ . _ _ _ .. .. _ . . _ _ . _ _ _ _ _ . . . _ 26 Adequ.ate,VI(eIlQOfE!. ~epªr¡:!tjo_n..Pfop9sed _ _ _ _ . _ _ _ _ _ _ .. . .. .. .. .. .. .. _ .. _ _ _ .. _ _ _ _ _ _ _ . Ye$ _ .. _ _ _ .. .. , , .. _ _ _ . _ _ _ _ . _ .. .. .. _ .. _ _ . _ _ _ _ .. .. .. _ _ _ _ _ _ .. _ , _ _ _ _ .. _ .. _ _ _ _ . _ . . . . , _ , _ _ .. .. .. .. _ _ _ . _ 27 Jf.djv~r:tE!r.re.q.uiJE!d, do.e? .it me~trßguJations, . . _ _ ., . . ,. . . _ . . . . .Y~s . . . , . , . _ . . . ... ..........,.. _ _ . . . . . 28 .OrillilJg fluid. pSQgram sc.hßmatic.&. e.q_uip -'ist.adequat~. . . . _ , , ' _ , . . _ _ _ .' . . . ,. . _ .Yßs _ ... . _ ,. Max. MW.9JQ RPgc . . . . _ . ,. ., .. ' _ . .. _ . . . ,. . . ., . . _ _ _ . _ . 29 .BOPEs..d.o.they me~treguJati9n _ " , . . _ . ,. .. . . . . . .Y~$ . , _ _ . _ . . . ,. .. _ , . . _ . . 30 .B_OPJ=_pr~ss ratiog appropriate;.te.stto_(pu.t psig in_comr::nel1tsL _ . . . _ _ . _ _ _ .. _ . _ . . . . . .Y~$. . . _ _ . . Te.stt..o..4000.RSi..MS~ 17.86 ppg., , . . , . . . . . . . . . _ . . . . . . _ . _ . ., _ . . ., , . . . . ., ,. 31 ,C_hoke.rnanjfQld co.mpJies. w/APtR~-53 (May ß4L . . , , . . . . .. _ .. . . . . .Y~s . . . . .. . . . . . . . . , . . , . . , , _ _ . . . .. . . . . , , . . . . . , _ _ . _ ,. , . 32 _Wo.rk will oçc.U( withpyt.operation .sbutdown,. _ _ , _ . _ . . . . _ . _ . _ _ . . . _ . . , _ , yes _ _ , _ . . . _ . , . . . _ _ . . . . _ .. _ . _ . _ . . . . ., . 33 J~ Rre~e[1ce, Qf H2S gas. probaþle _ .. . .. _ . _ , . . , _ . . . . _ . No_ _ . .. . _ .. _ , _ _ . . _ . . _ . _ . . ., . . , _ , _. _ _ . .. _ . , . ,. ., . , , _ ., . . . . , , . . 34 Meçha.nical.cood.iti.onof WE!.II$ within AOß yE!riJieq (For.s.ervic~ w~1J QnJy) , . . , .. ., . , , . ' . .. . .Yßs .. , .. '. W:-1.5..P.&AW-H i.s.uIJder a WßI!ter:np .sl)rve.illançe. prQgsaro.. ~uP.$t 24-.1 1<1~ I?&A.. - - - - - - - - - _ _ _ _ _ R - - - - - - - - - - - - - - - - - - - - - - - - ( - - - - - - - -_._----~_.,---_._..._-,..-._--- -_...."._--_._-----_.,.~..._---,._.~._,.._. ----..__.._-'"...~...,,-_.__._._---- -----.----.....-.----.. ---,-------- ._,-"._--_._-----""--_.._._-----~.-._"..,---,,_.__.~------_..._---------_._.._._-----..-.__.._~.._.- 35 P~(mit. c,an be i.ssueçl w!o. hyd(ogen, s.uIJioE! r::neas.u(e$ 36 _D..ata.pJE!s~lJteq Qn. Rote_ntial PveJRre$.Sl,Jr~ .ZOl1e$ 37 _S~isr::nic,a.nalys.is. o.f sbaJlow gas.zolJE!s.. 38 _S~ªQed ,.cond.itiolJ $lJrvey _(if Qff-$h.ore) _ . . 39 . GQnta.ct narnelphQn.e_ fQr.we~lsly progr~~s.reports [e?<pIQratory .only). . . . . , , . - . - , Y~$ - - - - - .. .. .. - - - ~ - - - - - - - - .. .. - - ~ ~ - - - - NA ,.'... NA . NA.. ., . . NA.. _ . , - ~ ~ - - .. -. ~ - - ~ - - . - - - .. - - .' - - - - ~ - - - ~ ~ - - - - - - ~ ~ ~ .. - - ~ - - - - -.- ~ - .. '. - - .. ~ ~ - - - - - - - - .. - - - - - - - - - " - .. - .. ., ~ - .. - - ~ - - - ~ - ,. . -. - - - ~ . Date: ì Irz cfr fJ Engineering Commissioner: Public vÞ Commissioner U ¡:'/~te /" < //2-5 #) / Date
