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210-060
Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Tuesday, July 28, 2020 10:25 AM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Alaska NS - PB - Field Well Integrity; Aras Worthington; Bo York, Oliver Sternicki; Stan Golis; Travis Smith - (C) Subject: NOT OPERABLE: Injector 13-21 (PTD #2100600) failed MIT -IA Mr. Wallace, Injector 13-21 (PTD # 2100600) was made Under Evaluation on 07/17/20 for anomalous IA casing re -pressurization after a bleed was performed. On 07/28/20 Fullbore performed a failing MIT -IA. The failing MIT -IA indicates a failure in one or more well barriers and the well is now classified as Not Operable. The well has been shut in and freeze protected. The Operations Engineer will evaluate repair options. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P:(907)659-5102 M: (307)399-3816 From: Alhka NS - PB - Field Well Integrity Sent: Friday, J .17, 2020 6:49 PM To: chris.wallaceO' ska.eov Cc: jim.regg@alaska.go , tan Golis <sgolis@hilcorp.com>; Bo York <byork@hilcorp.com>; Oliver Sternicki <Oliver.Sternicki@hilcorp.co Aras Worthington <Aras.Worthington@hilcorp.com> Subject: UNDER EVALUATION: lnj<or 13-21 (PTD #2100600) anomalous IA casing re pressurization Mr. Wallace, On 07/17/20, DHD bled the IA pressure on WAG Inject 3-21 (PTD # 2100600) from 780 psi to 230 psi. In the subsequent monitoring period, the IAP climbed 540 psi in 3 mutes which was not due to thermal effects. The anomalous IA casing repressurization indicates TxIA communica The well will now be classified as Under Evaluation and is on the 28 day clock for diagnostics. Plan Forward: 1. Wellhead Technician: PPPOT-T 2. DHD: Monitor IAP for Build Up Rate 3. Field Well Integrity: Additional diagnostics as needed. Please respond with any questions. Wallace, Chris D (CED) From: Alaska NS - PB - Field Well Integrity <PBFieldWelllntegrity@hilcorp.com> Sent: Friday, July 17, 2020 6:49 PM To: Wallace, Chris D (CED) Cc: Regg, James B (CED); Stan Golis; Bo York, Oliver Sternicki; Aras Worthington Subject: UNDER EVALUATION: Injector 13-21 (PTD #2100600) anomalous IA casing repressurization Mr. Wallace, On 07/17/20, DHD bled the IA pressure on WAG Injector 13-21 (PTD # 2100600) from 780 psi to 230 psi. In the subsequent monitoring period, the IAP climbed 540 psi in 30 minutes which was not due to thermal effects. The anomalous IA casing repressurization indicates TxIA communication. The well will now be classified as Under Evaluation and is on the 28 day clock for diagnostics. Plan Forward: 1. Wellhead Technician: PPPOT-T 2. DHD: Monitor IAP for Build Up Rate 3. Field Well Integrity: Additional diagnostics as needed. Please respond with any questions Andy Ogg Hilcorp Alaska LLC Field Well Integrity/ Compliance andrew.ogg@hilcorp.com P:(907)659-5102 M: (307)399-3816 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim DATE: Wednesday,December 21,2016 Regg }�ec< 1Zf lc, P.I.Supervisor `I SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 13-21A FROM: Chuck Scheve PRUDHOE BAY UNIT 13-21A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J-' NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-21A API Well Number 50-029-20789-01-00 Inspector Name: Chuck Scheve Permit Number: 210-060-0 Inspection Date: 12/17/2016 Insp Num: mitCS161218091236 Rel InsP Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-21A Type Inj I W 'TVD 8548 - Tubing 800 801 ' 801 801 - ' PTD 2100600 " Type Test SPT Test psi 2137 IA 223 2300 - 2301 2301 Interval 4YRTST P/F P 'T OA 33 197 195 - 197 Notes: SCANNED APR 0 52017, Wednesday,December 21,2016 Page 1 of 1 Wallace, Chris D (DOA) From: AK, GWO SUPT Well Integrity <AKDCWellIntegrityCoordinator@bp.com> Sent: Saturday, December 17, 2016 12:38 PM To: AK, GWO Projects Well Integrity;AK, OPS FS3 OSM;AK, OPS FS3 Field OTL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites;Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Hibbert, Michael;Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus,Whitney; Sternicki, Oliver R;Tempel, Troy;Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: OPERABLE:Injector 13-21A(PTD#2100600) Passing AOGCC MIT-IA All, Injector 13-21A(PTD#2100600) passed a 48 month AOGCC MIT-IA on 12/17/16.The well is now classified as Operable and will remain on produced water injection. Please call with questions or concerns. Thanks, Ryan Holt Well Integrity —GWO Alaska 0y (Alternate:Lee Grey) Office: ic7 Office: (907)659-5297 Fiom AK, GWO Projects Well Integrity Sent: - day, November 22, 2016 6:51 AM To: AK, GW• PT Well Integrity; AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; G GPB Drillsites; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OP - •C Specialists; AK, OPS Prod Controllers; Odom, Kristine; 'chris.wallace@alaska.gov' Cc: AK, GWO DHD Well Inte• '. • AK, GWO Projects Well Integrity; AK, GWO Completions Well Integrity; AK, OPS FF Well Ops Comp Rep; AKIMS App User; Bert, Michael; Janowski, Carrie; Montgomery, Travis 3; Munk, Corey; Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver -• Tempel, Troy; Worthington, Aras 3; AK, GWO Well Integrity Well Information Subject: Under Evaluation: Injector 13-21A •TD #2100600) Well passed MIT-T&CMIT-TxIA All, WAG Injector 13-21A(PTD#2100600) passed a CMIT-TxIA to 2, - /2488 psi and a MIT-T to 2472 psi on 11/13/16 proving tubing integrity despite the high wall loss. On 11/16/16 the downh. - plug was pulled and the well unsecured.At this time the well is reclassified Under Evaluation and placed on a 28 day cl. to perform the regulatory compliance testing. Plan forward: 1. Operations: put well on injection as soon as operationally feasible 2. DHD: perform AOGCC witnessed MIT-IA Thank you Js//flop BP Well Integrity Specialist 1 • • • • Wallace, Chris D (DOA) From: AK, GWO Projects Well Integrity <AKDCProjectsWelllntegrityEngineer@bp.com> Sent: Tuesday, November 22, 2016 6:51 AM To: AK, GWO SUPT Well Integrity;AK, OPS FS3 OSM;AK, OPS FS3 Field OIL;AK, OPS FS3 Facility OTL;AK, OPS FS3 DS Ops Lead; G GPB FS3 Drillsites; Cismoski, Doug A; Daniel, Ryan;AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS EOC Specialists;AK, OPS Prod Controllers; Odom, Kristine;Wallace, Chris D (DOA) Cc: AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO Completions Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey;Obrigewitch, Beau; Pettus, Whitney; Sternicki, Oliver R;Tempel,Troy;Worthington,Aras J;AK, GWO Well Integrity Well Information Subject: Under Evaluation:Injector 13-21A(PTD#2100600)Well passed MIT-T&CMIT-TxIA All, WAG Injector 13-21A(PTD#2100600) passed a CMIT-TxIA to 2455/2488 psi and a MIT-T to 2472 psi on 11/13/16 proving tubing integrity despite the high wall loss.On 11/16/16 the downhole plug was pulled and the well unsecured.At this time the well is reclassified Under Evaluation and placed on a 28 day clock to perform the regulatory compliance testing. Plan forward: 1. Operations: put well on injection as soon as operationally feasible 2. DHD: perform AOGCC witnessed MIT-IA Thank you je4/ffaeidg BP Well Integrity Specialist Office:907-659-5766 Harmony-2377 �� � ��� Alternate: Joss s Stephen GwGk bat Welts Orcanizatior 1 • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Thursday, October 29, 2015 7:40 AM To: AK, OPS FS3 OSM;AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL;AK, OPS PCC Ops Lead; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Pettus, Whitney; Regg, James B (DOA); Sayers, Jessica; Dickerman, Eric Subject: NOT OPERABLE:Injector 13-21A (PTD #2100600) Well Secured with Downhole Plug All, WAG Injector 13-21A(PTD#2100600) had a downhole plug set on October 28, 2015. A low pressure MIT-T passed to 1000 psi on October 28, 2015 indicating the well is secure. The well has been reclassified as Not Operable and is to remain shut in until tubing integrity can be restored. Please call with any questions or concerns. Thank you, Whitney Pettus (Alternate:Kevin Parks) SCANNED AUG 1 1 2016 BPP Alaska-Well Integrity Coordinator WIC Office: 907.659.5102 WIC Email: AKDCWeIlIntegrityCoordinatorPBP.com From: AK, D&C Well Integrity Coordinator Sent: Monday, October 05, 2015 2:39 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt EngrK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Mison, Spencer; Pettus, Whitney; 'Regg, James B (DOA) (jim.reggOalaska.gov)' o�P~�e� Subject: UNDER EVALUATION: Injector 13-21A (PTD #2100600) Tubing Quality - Discontinue Injection Service All, WAG Injector 13-21A(PTD#2100600) will be due for an AOGCC MIT-IA by the end of November 2015. A caliper obtained on August 18, 2015 indicates that the tubing is in poor condition with a maximum wall penetration of 81%. Fifty one joints of tubing display between 40-80%wall loss. Due to de-rated tubing quality, this wellilu� l be taken 1 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Monday, October 05, 2015 2:39 PM To: AK, OPS FS3 OSM; AK, OPS FS3 Field OTL; AK, OPS FS3 Facility OTL; AK, OPS FS3 DS Ops Lead;AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Chou, Irwin; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R; Morrison, Spencer; Pettus, Whitney; Regg,James B (DOA) Subject: UNDER EVALUATION:Injector 13-21A (PTD #2100600) Poor Tubing Quality - Discontinue Injection Service All, WAG Injector 13-21A (PTD#2100600) will be due for an AOGCC MIT-IA by the end of November 2015. A caliper obtained on August 18, 2015 indicates that the tubing is in poor condition with a maximum wall penetration of 81%. Fifty one joints of tubing display between 40-80%wall loss. Due to de-rated tubing quality,this well will be taken out of injection service as soon as operationally feasible until tubing integrity can be restored. At this time,the well is reclassified as Under Evaluation and placed on a 28 day clock in order to secure the well with a downhole plug. Plan Forward: 1. Operations: shut in well as soon as operationally feasible 2. Slickline: secure well with downhole plug 3. Fullbore: MIT-T to 1000 psi Please call with any questions or concerns. s ��ED AU 0 2MThank you, Whitney Pettus (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator GING1oba14',. . Oroartitat,n+, WIC Office: 907.659.5102 WIC Email: AKDCWellIntegrityCoordinator@BP.com 1 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c: 1 p 0 - ©10 O Well History File Identifier Organizing(done) ❑ Two-sided I I II II II II I1111 ❑ Rescan Needed I I 1E11 II I I I III RES AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: reyscale Items: Other, No/Type: cP X10. 2 ❑ Other Items Scannable by a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: cMaria„) Date: 1130/11.1 /s/ Illf) Project Proofing I I BY: Date: QJ9 t 3 d ! /s/ Scanning Preparation a x 30 = 1 0 + ,a6 = TOTAL PAGES 3 l2 (Count does not include cover sheet) ryi r BY: Maria Date: t 3c)//q. lsl Production Scanning I Stage 1 Page Count from Scanned File: g 7 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: 1/Y'ES NO BY: MEV Date: ' 3 0 1/(. . /s/ 01 F y A Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1111111111111 ReScanned 111111111 IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked I 19/99/9(111 Wall Hietnn,Filt.Rnwar Pant.rinr 0 I 4 2 o °ate o F? as a -J a a 3 0 o a 0 0� 0� C 0 CC 0_ CY a o a0i O Ce Op Op E = ce =a =a y L °o 0 ' m o > O >- >� o 0 co 0 l 1 Z Z 1 V (n o co CO In<a' ❑ y ❑ a j = CL =CC �CLO 2 2 Q co D , C 0 0 Z o o CL 0 0 0 0 0 0 0 0 N N O N N N N N N N 0 >Q OOOg a' a O OD CO CO CO 00 ? > ❑ J ,- N N N N N .4 C CI) O _ = C C C C C C C C d '." N a)c c a) a) a) a) a) E to O U U 0 O O O 0 O O O O J t CL Q E 1 y a)a) a) o o o o o o o o U O Z O g 0 a _ _ °+ M O O O O O y N _ _ _ N N E C Z Z CL C) C) C) c (f) E W °' �nZ IX 0 C Off) Iof) lam() co M La co N. � N. d y N N N N N N N N Cs- W w z 0 > V 0. a O > Z z c d o ° U ZZ CY 2 F- 1 Q 0 0 0 1 O 65 a) c . E A L N c ZI z U U U ( m O • N N J . Z 0 O a a) a)�v ,n 10 10 E a o 0 N IA N ✓ � 0 E -1 (I) (.1) U) CO Q 0 N a a c I— `_ 0 E co 2 cc W m O 1 cc Cl) cli a) p O a) FY - V (n cn DCI ifi ❑ Q O W I— a 0_ 21 w . w Q a a o >. >.ai > > Q d U o 1 CC 2 2 ,w c f) - 3 y 0 y 5 us IEz .0 1 0 C — ci) — x 'al N CO cc fx z 7 U a) I'I 0) .5 0 0 ° w ° E E o C m 1 rn a m .- aa) ` > > E E D c co I y z a) E p o i va n ° n c) N N 2 Z N N ¢ } )c" —CD O Z 0 O O `1=! 0 z ° E E E E ? V 0 a- 0 y 0 ea co a� w O)�' J co J CO Z Q �. .� O M 1 W a) C O d l d Z N '° C 11 X Z uj o U U U � j `o 0 N > E E ❑ Q '1 U a — a 2-'0 1 F. p C'I H fl d rn.c4 a ❑ a ❑� a ❑ 0 0 o m ❑ 0 s c aUi o a. o 3 .61,, 2_ w w w J J J 3 Q 0 Qa U O 9 O CI 0o co N N > QII O 51 O N .L1 G J 2 ii Q r z �/ � U' Q Z c ui m a J U) 0 Ce Q N a w g IX ° J O. W w z U m Z y Q = J o cn aN C � o G• N a) a U N co a a N E a N CO ■ CO cn 1 I Cn o o ! H • `= ' C a a) a o z E z N O co 1 c m o 0 3 N a) N _ O re y O w M Ea m` C o a 2 , U MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday,December 15,2011 TO: Jim Regg Q P.I.Supervisor (Z��I �f SUBJECT:Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 13-2IA FROM: Lou Grimaldi PRUDHOE BAY UNIT 13-21A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry Comm Well Name: PRUDHOE BAY UNIT 13-21A API Well Number: 50-029-20789-01-00 Inspector Name: Lou Grimaldi Insp Num: mitLG111130123506 Permit Number: 210-060-0 Inspection Date: 11/29/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-21A' Type Inj. W' TVD 8548 - IA 505 2535 • 2535 • 2535 • P.T.D 2100600•TypeTest SPT Test psi 2137 - OA 109 171 164 164 Interval 4YRTST p/, P - Tubing 995 • 1033 1070 1070 • Notes: 3.9 Bbls pumped,3.7 back.Good solid test. . Thursday,December 15,2011 Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble @bp.com] Sent: Wednesday, February 23, 2011 11:33 AM To: Saltmarsh, Arthur C(DOA) Subject: PBU 13-21A/PTD#210-060 Hi Art, • Please reference the following well: Well Name: PBU 13-21A Permit #: 210-060 API #: 50-029-20789-01-00 Top Perf MD: 12750' Bottom Perf MD: 12905' This well began Injection on February 5, 2011 g Injection Y Method of Operations is: Water Injector No Test Data for Service Wells 1 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7`h Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: 13-21A Contains the following: 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 color print—GR Directional Measured Depth Log (to follow) LAC Job#: 3352669 Sent by: Debbie Hoke Date: 2/1 rfAr,I . CEVED Received by: e, Date: FEB 3 it tJ i PLEASE ACKNOWLEDGE RECEIPT S∎74. .n G OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ gig 7260 Homer Drive j({j 060 OMER Anchorage,Alaska 99518 HUGHES Direct:(907)267-6612 INTEQ FAX: (907)267-6623 i" W/liti BALKIER 1411JCDNIES Baker Atlas PRINT DISTRIBUTION LIST COMPANY BP EXPLORATION(ALASKA)INC. COUN'1 Y NORTH SLOPE BOROUGH WELL NAME 13-21A STATE ALASKA FIELD PRUDHOE BAY UNIT DATE 2/16/2011 THIS DISTRIBUTION LIST AUTHORIZED BY: DEBBIE HOKE SO#:3352669 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION(ALASKA)INC 1 Company DNR-DIVISION OF OIL&GAS Person PETROTECHNICAL DATA CENTER Person CORAZON.MANAOIS Address LR2-1 Address 550 WEST 7TH AVE 900 E BENSON BLVD. SUITE 800 ANCHORAGE,AK 99508 ANCHORAGE,AK 99501 1 Company EXXON MOBIL PRODUCTION CO Company Person FILE ROOM Person Address 800 BELL STREET Address EMB GSC 3082A HOUSTON,TX 77002 1 Company STATE OF ALASKA-AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W.7TH AVE Address SUITE 100 • ANCHORAGE.AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated Bv:BAKER ATLAS-PDC 17015 Aldine Westfield,Houston,Texas 77073 This Distribution List Completed Bv: g-l0 -0600 2(5-‘.-f3 Page 1 of 1 bp Date 01-08-2011 0 Transmittal Number:93175 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 13-21A ,::?a.) -04.0 (oa' 05-08A 9t0I01/45-3— c9O C-37B atO-COO 00(02 18-10CPB1 aiO-1(0 2o(0o-J 18-10C a 1O-ti ' o 6° � X-19BL2PB1 9 . )`10a3 co" as G-29B a/U- /q// c9O(oa:/ X-19BL2 . 1 w- 103 2o(oa X-19BL2-01 asv-10' 0642Q K-11A aio-i 3 00003 B-04APB 1 )U.)—095_ a O(°t 9 04-22AL1 ,,9/O- t5-f ao oOD B-04A 9IO-0'6- Q0(01' Please S.tt• d Return one copy of this transmittal. Thank You, Doug Dortch Petrotechnical Data Center s 40C—cg. Attn: Cetheen-Maraeis 550 West 7th Avenue, Suite 802 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E.Benson Blvd. PO Box 196612 Anchorage,AK 99519-6612 STATE OF ALASKA ALASr.,,OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other isi ACID WASH Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ Waiver Time Extension ❑ Change Approved Program ❑ Operat.Shutdown❑ Perforate 0 Re-enter Suspended Well ❑ 2.Operator BP Exploration(Alaska),Inc. Well Well Class Before Work: 5.Permit to Drill Number: Name: Development❑ Exploratory ❑ - 210-0600 3.Address: P.O.Box 196612 Stratigraphic Service 0 6.API Number: Anchorage,AK 99519-6612 - 50-029-20789-01-00 8.Property Designation(Lease Number): j i 9.Well Name and Number: ADLO-028330/028315 - PBU 13-21A 10.Field/Pool(s): , PRUDHOE BAY FIELD/PRUDHOE BAY POOL 11.Present Well Condition Summary: Total Depth measured 13010 feet Plugs(measured) None feet true vertical 8992.24 feet Junk(measured) None feet Effective Depth measured 12969 feet Packer(measured) 12204 feet true vertical 8970.55 feet (true vertical) 8548 feet Casing Length Size MD ND Burst Collapse Structural Conductor 75' 20" SURFACE - 75 SURFACE - 75 Surface 2513' 13-3/8"72#L-80 SURFACE - 2513 SURFACE - 2485 4930 2670 Intermediate 12579' 9-5/8"47#L-80 SURFACE - 12579 SURFACE - 8774 6870 4760 Liner 410' 3-1/2"9.2#L-80 12417 - 12557 8505 - 8761 Liner 98' 3-1/16"6.2#L-80 12557 - 12655 8761 - 8813 Liner 53' 2-7/8"6.16#L-80 12655 - 13008 8813 - 8991 13450 13890 Perforation depth: Measured depth: SEE ATTACHED- _ - - True Vertical depth: _ - _ Tubing:(size,grade,measured and true vertical depth) 5-1/2"17# L-80 SURFACE-12215 SURFACE-8555 4-1/2"12.6# N-80 12215-12320 8555-8620 Packers and SSSV(type,measured and true vertical depth) 9-5/8"X 5-1/2"BOT PKR 12204 8548 !RECEIVE* 12.Stimulation or cement squeeze summary: NOV 1 2 201u N Ur &Sas CMS.cU i�n Intervals treated(measured): Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14.Attachments: 15.Well Class after work: s Copies of Logs and Surveys Run Exploratory 0 Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 310-342 Contact Joe Lastufka Printed Na •e Lastuli Title Data Manager Signatu _ N�� ,�. Phone 564-4091 Date 11/12/2010 77 RBDMS Novi 5 Zpm Wil Form 10-404 Revised 10/2010 /1.is-./p Sub/mit Original Only �//Ai 0N• OCcoNa000N m co M lei co ti co tCaOaNapa0CC. Qao00aoao" aooco o a > I- C N in O I- O N N � N CO co O *3 of Oetet cc; oir` Q ao� a� o» aoo co Co a D aocoaoaococo WZ 0 O W > > J a0 1- O U 0 Y Y ( oNa0oaatNN Co Z � y J UU S• NNNNNNN JC7Cia as a 0 J J W W J J ce 1- w w 0 2 . U. ILI I- 0 I=1 LLI MI 4 I- d WW -JdQVC 1-1. Z2 a O' NV) V) UV) V) V) zoi° coocoyCoIOtivo No =H r` co. co. 0o N- r` r• Q 0 s N N N N N N M o r o e- N Q 0 U. IX LL WV) LL 0O W dJddaLI- H wg a MV) V) V) V) V) (/) V) a d 0 o w 0 0 _ 2 o Lu a fY C 0 0 0 �\ 0 IL tcemu. OLy. IOL, IQLLQL JF„ Y� aaaQQQQQ ay =—yyLL_JJ- CD 0000000 = = 0 4 4 4 tcl CI 0NN � � e- e- ee- ZLL. JJ � 0Vz0J ILI 13. EL 000 e- e- e- CW - W J QQ = L zo. (! O0 xxxz a. m ° r7R -1 -Iwwwa O QOmmu. ri2220 co ea• QQQQQQQ ZNNNNNN% N L. aV0 aV) el cvy a acou. u. 222Y 0 13-21A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 10/22/2010,CTU #8 w/ 1.75" CT: Job scope: FCO &Acid treatment. MIRU CT unit. Wittiness BOP test. MU and RIH with 2.25"JSN. Cleanout with gel sweeps starting at 12700' ctmd. Tagged PBTD @ 12957 ctm. Circulate 1.5 time bottoms up. Preform injection !test 0.4 bpm @ 1850 psi. <<< continue WSR on 10/23/10 >>>***Job in Progress*** 10/23/2010 CTU#8 w/ 1.75" CT: Job scope: FCO &Acid treatment. <<< Continue WSR from 10/22/10 »fined 10.5 bbls of 12� DAD acid.Preform injection test{ 1 bpm 1095 psi } { 1.5 bpm 2000 psi} Injected 150 bbls of KCL. Freeze protect well w/ 58 bbls of 60/40 Methanol. POOH <<< Job complete >>> 10/27/2010;***WELL SHUT IN ON ARRIVAL*** (pre-adperf) DRIFTED W/2.125" CENT, 2" DUMMY GUN, & SAMPLE BAILER TO 12800' SLM (UNABLE TO WORK PAST) ,DRIFTED W/2.14"CENT, 5 x 2 DRIVE DOWN BAILER TO TD @ 12915 SLM ((UNABLE TO WORK PAST- SAMPLE OF SCHMOO) !DRIFTED W/2.125" CENT, 2" DUMMY GUN, & SAMPLE BAILER TO TD @ 12920'1 1SLM -11' = 12909' CORRECTED MD (TARGET DEPTH FOR BTM SHOT @ 12905') ' NAGGED DEPLOYMENT SLEEVE W/3.50" CENT © 12137' SLM -11' = 12126' MD *****TURN WELL OVER TO DSO***** 11/9/2010 ***WELL SHUT IN ON ARRIVAL***(E-LINE PERF) INITIAL T/I/O= 0/0/0 PSI INITIAL VALVE POSITION= M/VALVES TO GAUGES= OPEN, S/W/SSV= CLOSED PERFORATED 12860'-12902'WITH 2' HSD PJO 2006 HMX, 6 SPF, 60 DEG PHASE GUN FINAL T/I/O= 0/0/0 PSI • FINAL VALVE POSITION= M/VALVES TO GAUGES= OPEN, S/W/SSV= CLOSED ***JOB IN PROGRESS*** (SHUT DOWN, WILL RESUME JOB ON 11-NOV-2010) 11/11/2010'***WELL SHUT IN ON ARRIVAL, JOB CONTINUED FROM 9-NOV-2010***(E-LINE PERF) INITIAL T/I/O=0/0/0 PSI 1PERFORATED 12750'-12810'WITH 2' HSD PJO 2006 HMX, 6 SPF, 60 DEG PHASE GUN FINAL T/1/0= 0/0/0 PSI !DSO NOTIFIED OF VALVE POSITIONS: M = OPEN, SV,WV,SSV= CLOSED, IA/OA= OTG WELL LEFT SHUT IN ***JOB COMPLETE*** FLUIDS PUMPED BBLS 687 1%XS KCL 290 1%KCL 110 60/40 METH 25 GEOVIS 10 12% DAD ACID 3 DIESEL 1125 TOTAL • TREE= FMC WELLHEAD= GRAY 1 3-21 A SAFETY NOTES: ACTUATOR= BAKER C JMD DRAFT KB.ELEV= 84' BF.ELEV= ? I 1 KOP= 2100' I 2024' I w/�5-1/5-2 1/2"OTIS RQY RQM DSSSV SSSV(07/26/08).562" Max Angle= 62°@ 12652' • Datum MD= 12799' Datum TV D= 8800'SS 13-3/8"CSG,72#,L-80,ID=12.347" H 2513' I I I 12123' H5-1/2"OTIS XA SLIDING SLV,ID-4.562" I Minimum ID = 2.377" @ 12655' 3-3116" X 2-7/8" XO 12126' H3.70"DEPLOYMENT SLV,ID=3.00" I II II 12147' H3-1/2"OTIS X NIP,ID= 2.812" I I I 12184' H5-1/2"BOT PBRASSY I Z 12204' —19-5/8"X 5-1/2"BOT PKR w/7"MOE I 5-1/2"TBG-IPC, 17#,L-80 LT&C 8RD AB MOD, H 12215'] - , I 12215' I-15-1/2"X 4-1/2"XO,ID=3.958" I .0232 bpf,ID=4.892" TOP OF 7"LNR H 12295' }---' i.. I 12308' I-14-1/2"OTIS XN NIP,MILLED TO 3.80"(06/17/10) I o• e1 4-1/2"TBG-IPC, 12.6#,N-80 BTC, —I 12320' -e∎ Ns 12320' H4-1/2"SHEAR OUT SUB,ID=3.958" I .0152 bpf,ID=3.958" •••■ ■•••■ 12261' —I ELMD TT LOGGED 12/20/85 I ...1 M 3-1/2"LNR,9.2#,L-80 STL —I 12557' O. ,a,•, 12557' H3-1/2"X 3-3/16"XO,ID=2.786" •'' 14.1 I I I .0087 bpf,ID=2.992" V* �����1 4.1.1 1.4.14 7"WHIPSTOCK(08/28/10) —1 12565' 1���1 1����� MILLOUT WINDOW(13-21A) 12570'-12578' PIP TAG(08/28/10) 12575' O.■ ■•9-5/8"CSG,47#,L-80&S00-95,ID=8.681" H 12579' I--41 .4 12655' —I 3-3/16"X 2-7/8"XO,ID=2.377" I 7"LNR,29#,L-80, .0371 bpf,ID=6.184" H 13404' I PERFORATION SUMMARY N/REF LOG:SLB MEM GR/CCL ON 08/31/10 3-3/16"LNR,6.2#,L-80 TCII, 12655' ANGLE AT TOP PERF:60°@ 12750' .0076 bpf,ID=2.80" Note:Refer to Production DB for historical perf data SIZE SFF INTERVAL Opn/Sqz DATE 2 6 12750-12810 0 08/31/10 PBTD —I 12969' I .44'v, 2 6 12860-12905 0 08/31/10 44 44.�•4∎ 2-7/8"LNR,6.16#,L-80 STL, .0058 bpf,ID=2.441" —{ 13008' I DATE REV BY COMMENTS DATE REV BY_ COMMENTS PRUDHOE BAY UNIT 01/25/83 ORIGINAL COMPLETION WELL: 13-21A 09/01/10 NORDIC2 CTD SIDETRACK(13-21A) PERMIT No: 2100600 09/05/10 SV DRLG HO CORRECTIONS API No: 50-029-20789-01-00 09/14/10 ?/JMD DRGL DRAFT CORRECTIONS SEC 14,TION,R14E, 1898.51 FEL&3095.2 FNL BP Exploration(Alaska) t ^ ]|B! CIS K E§ :jf ■- - 2°q .. , g -/\k __ , ). — _§ a ock- $\) !\/ r xi j- s;>oo § • \\\ M 4004 \ \/�k/kk: d 7 \� k mu l 0 Dp < e ri§ t.:A , §»■$§i$: eeoeo o. co r _ a. . _i! 0 z {(\ �l � � , : < 0. 2 ■!..■ % - o }*�E; ¥( `g\ 2£ a \� }ƒ�! f x:! \ _ ' \ . k-& { . - j \ ; j y 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑Oil ❑Gas ❑SPLUG ❑Other ❑Abandoned ❑Suspended lb. Well Class: 20AAC 25.105 2OAAC 25.110 ❑ Development ❑Exploratory ❑GINJ ❑WINJ ®WAG ❑WDSPL ❑Other No.of Completions One ®Service ❑Stratigraphic 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska)Inc. 9/1/2010 210-060 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 8/27/2010 50-029-20789-01-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number. Surface: 8/29/2010 PBU 13-21A 2523'FSL, 106'FEL,SEC. 14,T1ON, R14E, UM 8. KB(ft above MSL): 84' 15.Field/Pool(s): Top of Productive Horizon: 2019'FSL,2571'FWL, SEC. 18,T1ON, R15E, UM GL(ft above MSL): 45.53' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD): Oil Pool 2052'FSL,2799'FWL, SEC. 18,T1ON,R15E, UM 12969' 8971' 4b. Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 687095 y- 5932587 Zone- ASP4 13010' 8992' ADL 028315&028330 TPI: x- 695062 y- 5932285 Zone- ASP4 11.SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth:x- 695289 y- 5932324 Zone- ASP4 N/A 18.Directional Survey: 12I Yes ❑No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: GR, ROP, Press/Res,GR/ROP/Press(Ran Liner), MCNL/GR/CCL 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE ToP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 75' Surface 75' 30" 360 sx Arctic Set H 13-3/8" 72# L-80 Surface 2513' Surface 2485' 17-1/2" 2500 sx Fondu.400 sx Permafrost'C' 9-5/8" 47# "43/S°"6 Surface 12570' Surface 8769' 12-1/4" 500 sx Class'G'.300 sx Permafrost'C' 7" 29# L-80 12295 12570' 8604' 8769' 8-1/2" 350 sx Class'G' 3-1/2'x3-3/18'x2-7Ir 9.2#/820/8.41 L-80 12126' 13008' 8500' 8991' 4-1/8" 92 sx Class'G' 24. Open to production or injection? ®Yes ❑No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom;Perforation Size and Number): 2"Gun Diameter,6 SPF 5-12"x 4-1/7',17#/12.6#,L-80/N-80 12320' 12204'/8548' MD TVD MD TVD 12750'-12810' 8860'-8889' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 12860'-12905' 8914'-8938' _ I COM LEflON ;DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I' E t' Freeze Protect with 60 Bbls of Diesel I ' '' 1 • 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,Gas Lift,etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? ❑Yes ®No Sidewall CoreAcquired? ❑Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology a ter taste 0(submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytica t 0.071. None 1(TT Z 4 2 i0 RBDMS OCT 14 20 tteafew Form 10-407 Revised 12/2009 CONTINUE ON REVERSE Submit Original Only ,p•/S•/iJ A��y ,,,,,, '` 29. GEOLOGIC MARKERS(List all formations and n .rs encountered): 30. ORMATION TESTS NAME MD TVD Well Tested? ❑Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 MC 25.071. Shublik A 12592' 8782' None Shublik B 12632' 8802' Shublik C 12670' 8821' TSAD/46P/Top Zone 4B 12739' 8855' 45P 12822' 8895' 44P 12854' 8911' 43P 12911' 8941' 42P 12965' 8968' Formation at Total Depth(Name): Top Sadlerochit/Top Zone 4B 13010' 8992' 31.List of Attachments: Summary of Well Work and a Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Sondra StPran Title: Drilling Technologist Date: [ L ) 3 C) PBU 13-21A 210-060 Prepared By Name/Number Sondra Stewman,564-4750 Well Number Permit No./Approval No. Drilling Engineer: Amanda Suddreth, 564-5543 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the down hole well design is changed. Item la: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only North America -ALASKA- BP Page 1 of 2 Operation Summary Report Common Well Name: 13-21 AFE No Event Type:MOBILIZATION (MOB) Start Date:8/25/2010 End Date: X3-000V5D-C(965,808.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.:NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/25/2010 15:00 - 15:15 0.25 MOB P PRE PJSM FOR MOVING OFF WELL. DISCUSS HAZARDS AND MITIGATIONS,CLEAR COMMUNICATIONS FOR RIG MOVE. 15:15 - 15:45 0.50 MOB P PRE JACK UP RIG AND MOVE OFF WELL 14-11AL1. PICK UP HERCULITE AND BERMS FROM AROUND CELLAR. CLEAN UP LOCATION,PICK UP MATTING _ BOARDS. 15:45 - 16:00 0.25 MOB P PRE PJSM FOR INSTALLING WALL ON PUMP ROOM. 16:00 - 18:00 2.00 MOB P PRE INSTALL WALL ON PUMP ROOM. CONTINUE CLEAN UP LOCATION. 18:00 - 19:15 1.25 MOB P PRE SPOT RIG MATS ON PAD TO MOVE RIG TO FRONT OF PAD 19:15 - 19:30 0.25 MOB P PRE PJSM TO MOVE RIG TO FRONT OF PAD 19:30 - 20:30 1.00 MOB P PRE RIG MOVED TO FR O NT OF PAD WO T RUCKS TO MOVE TRAILERS&RIG MATS 20:30 - 00:00 3.50 MOB P PRE CONTINUE WO TRUCKS(ALL DRIVERS TIED UP ON 141 CMT JOB) 8/26/2010 00:00 - 04:00 4.00 MOB P PRE - CONTINUE WO DRIVERS FOR TRUCKS TO MOVE TRAILERS AND RIG MATS TO MOVE TO DS13 04:00 - 04:20 0.33 MOB P PRE PJSM TO MOVE RIG TO DS 13 04:20 - 04:45 0.42 MOB P PRE MAKE A LAP AROUND RIG TO MAKE SURE EVERYTHING IS READY TO MOVE 04:45 - 07:30 2.75 MOB P PRE MOVE RIG FROM DS14 RIGHT ONTO SPINE RD, PAST WEST CHECK POINT TO DS 13. _ 07:30 - 09:20 1.83 MOB P PRE RIG ARRIVES ON DS13. LEAVE PHONE MESSAGE AT AOGCC NORTH SLOPE OFFICE INFORMING THEM OF BOP TEST TIMING. 07:50-RECEIVE MESSAGE BACK FROM BOB NOBLE,AOGCC,WAIVING THE RIGHT TO WITNESS THE BOP TEST. PUT RIG MATS DOWN AND HERCULITE AROUND TREE. MOVE RIG ONTO MATS. 09:20 - 10:30 1.17 MOB P PRE SURVEY SITE WITH DSO,DOYON 141 WSL AND NORDIC TP. DECIDE TO ANGLE RIG A BIT MORE TO OPEN THE SPACE FOR VAC TRUCKS. BACK RIG OFF MATS AND SLIDE THEM INTO NEW POSITION. 10:30 - 12:00 1.50 MOB P PRE MOVE RIG ONTO MATS AND OVER WELL. ACCEPT RIG AT 11:00. SET RIG DOWN. 112:00 - 18:00 6.00 RIGU P PRE START N/U STACK. 18:00 - 18:20 0.33 RIGU P PRE PJSM TO CONTINUE OPS ,18:20 - 20:00 1.67 RIGU P PRE INSTALL CHINA CAP ON LUBRICATOR REPLACED THREADED PLUG ON COMPANION WITH A GATE VALVE AND STUDS ARE TO SHORT,CALL OUT FOR LONGER STUDS REPLACED STUDS ON GATE VALVE SHELL TEST STACK Printed 10/13/2010 12:42:22PM North America -ALASKA- BP Page 2 of 2 Operation Summary Report Common Well Name: 13-21 AFE No Event Type: MOBILIZATION(MOB) Start Date:8/25/2010 End Date: X3-000V5D-C(965,808.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.:NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 BOPSUR P -_ PRE START TESTING BOPS,250/3500PS1 TESTS l (r, CONTINUE TEST ON REPORT 8/27/2010 L' 8/27/2010 00:00 - 01:00 1.00 BOPSUR P ._ PRE CONTINUE BOP TEST FROM 8/26/2010 6� BOP TEST COMPLETED, '✓ 01:00 - 01:15 0.25 BOPSUR P ■- PRE PJSM CREW VALVE CREWE THE V TOK, VALVE CREW NEEDS TO SEE THE BPV TO SET THE DART - 01:15 - 04:00 2.75 BOPSUR P PRE MU NIGHT CAP AND BLOW DOWN STACK CLOSE CHOKE AND OPEN MASTER, NO PRESSURE REMOVE NIGHT CAP AND SUCK OUT STACK TO BPV SO VC CAN SEE PLUG TO SET DART 04:00 - 05:15 1.25 BOPSUR P PRE PRESSURE TEST FLANGES BELOW THE MASTER GOOD TEST,BLEED OFF,BLOW DOWN AND SUCK OUT STACK PJSM TO BRING VALVE CREW LUBRICATOR TO FLOOR TO PULL PLUG AND BPV 05:15 - 06:00 0.75 BOPSUR P -_ PRE LOAD VALVE CREW LUBRICATOR ON THE RIG TO PULL BPV. 06:00 - 06:15 0.25 BOPSUR P - PRE PJSM TO PULL BPV. WELL CONTROL AND COMMUNICATIONS WERE DISCUSSED. 06:15 - 07:30 1.25 BOPSUR P PRE PULL BPV WITH LUBRICATOR. WELL IS ON ■- SLIGHT VAC. OFFLOAD BPV AND PULLING TOOLS. 07:30 - 08:00 0.50 BOPSUR P PRE M/U CT RISER TO WELL. FILL CT WITH FLO-VIS. PRESSURE TEST INNER REEL VALVE AND CT STRIPPER,GOOD. CONTINUE REPORT ON 13-21A 08-27-2010 RON Printed 10/13/2010 12:42:22PM North America -ALASKA- BP Page 1 of 5 Operation Summary Report Common Well Name: 13-21 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/27/2010 End Date: X3-000V5D-C(832,266.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.: NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/27/2010 08:00 - 08:15 0.25 STWHIP P WEXIT PJSM FOR RIGGING UP HYDRAULIC CUTTER AND CUTTING CABLE. HAND TRAPS AND KEEPING HOLD OF THE CT AFTER ITS CUT WAS DISCUSSED. 08:15 - 10:15 2.00 STWHIP P WEXIT RIG UP HYDRAULIC CUTTER,CUT OFF 237 FT OF CT. 10:15 - 11:00 0.75 STWHIP P WEXIT INSTALL CT CONNECTOR. 11:00 - 11:30 0.50 STWHIP P WEXIT PULL TEST TO 36K AND PRESSURE TEST CT CONNECTOR TO 4000 PSI,GOOD. 11:30 - 12:00 0.50 STWHIP P WEXIT INSTALL BHI CABLE HEAD. 12:00 - 12:30 0.50 STWHIP P WEXIT PULL INJECTOR OVER TO CIRC HOLE, PUMP SLACK FORWARD. OPEN WELL AND FILL IT WITH 0.5 BBLS. MONITOR WELL. - 12:30 - 12:45 0.25 STWHIP P WEXIT PJSM TO DISCUSS HAZARDS AND MITIGATIONS FOR P/U BHA. 12:45 - 13:30 0.75 STWHIP P WEXIT P/U BHA#1 -3.80 MILL AND STRING REAMER, STRAIGHT MOTOR,2 JTS PH6,3"COILTRAK. BHA OAL=120.96 FT. 13:30 - 15:50 2.33 STWHIP P WEXIT RIH, PUMP 0.24 BPM/690 PSI THROUGH THE MILL. 15:50 - 17:30 1.67 STWHIP P WEXIT LOG GR DOWN FROM 12,390 FT. AFTER 12500 FT APPEAR TO BE PUSHING THROUGH DEBRIS,GO TO 2.1 BPM. LOG DOWN TO TAG DEPTH OF 12,594 FT. PICK UP AND CORRECT-30 FT BASED ON GR. BHI GR LOG HAS MUTED PEAKS COMPARED TO THE PDC LOG. 17:30 - 18:30 1.00 STWHIP P WEXIT LOG CCL UP FROM 12,500 FT. 18:30 - 18:45 0.25 STWHIP P WEXIT CCL COMPLETE, RIH TO START MILLING WINDOW CHECK RETURNS FOR BOTTOMS UP AND WE HAVE A LOT OF MILLED CMT IN THE MUD, SWAP RETURNS TO TT UNTIL THET CLEAN UP 18:45 - 19:00 0.25 STWHIP P WEXIT TAG TOC @ 12567.5'AND START MILLING DOWN TILL WE SEE CSG CONTACT TAKING RETURNS TO PITS INCREASE ROP UNTIL WE SEE A GOOD INDICATION WE ARE ON THE CASING WITH THE MILL ( l 3_a I 1 19:00 - 20:40 1.67 STWHIP P WEXIT WINDOW @ 12570.4', START TIME MILLING 2.58/2.64 BPM 2610 PSI FS, WHP/IAP/OAP= 55/2/48 PSI PVT=449 BBLS DHWOB=2.45K ECD=9.46 U j PPG 20:40 - 21:30 0.83 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW @12571.7' j1 2.58/2.61 BPM 2610 PSI FS, WHP/IAP/OAP= �� 55/2/48 PSI PVT=447 BBLS DHWOB=3.62K ECD=9.43 PPG 21:30 - 22:30 1.00 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW(a7 12572.5' 2.58/2.61 BPM 2610 PSI FS, WHP/IAP/OAP= 55/0/133 PSI PVT=447 BBLS DHWOB=2.91K ECD=9.45 PPG Printed 10/13/2010 12:42.32PM North America -ALASKA- BP Page 2 of 5 Operation Summary Report Common Wet Name: 13-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date: 8/27/2010 End Date: X3-000V5D-C(832,266.00) Project:Prudhoe Bay Site: PB DS 13 Rig Name/No.: NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00©84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 22:45 0.25 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW @ 12573.6' 2.58/2.61 BPM 2610 PSI FS, WHP/IAP/OAP= 38/0/156 PSI PVT=447 BBLS DHWOB=3.02K ECD=9.39 PPG 22:45 - 23:00 0.25 STWHIP P WEXIT AFTER OUR TIE IN CORRECTION OF 30'AND TAGGING 12"DEEPER THAN THE PROPOSED TOW,THE GEO PICKED UP SOME LOGS FROM PBOC TO DOUBLE CHECK OUR DEPTH.AS IT TURNS OUT WE ARE ON DEPTH AND THE WS WAS SET 8-10'DEEP 23:00 - 23:45 0.75 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW an.12574.5' 2.58/2.61 BPM 2610 PSI FS, WHP/IAP/OAP= 33/0/177 PSI PVT=447 BBLS DHWOB=3.01K ECD=9.39 PPG 23:45 - 00:00 0.25 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW 12575.5' 2.58/2.61 BPM 2580 PSI FS, WHP/IAP/OAP= 33/0/189 PSI PVT=447 BBLS DHWOB=3.16K ECD=9.38 PPG 12576.0'CONTINUE REPORT ON 8/28/2010 8/28/2010 00:00 - 00:15 0.25 STWHIP P WEXIT CONTINUE FROM REPORT 8/27/2010 CONTINUE TIME MILLING WINDOW @ 12576' GETTING LOTS OF METAL ACROSS THE SHACKER 2.58/2.61 BPM 2580 PSI FS, WHP/IAP/OAP= 33/0/197 PSI • PVT=447 BBLS DHWOB=2.97K ECD=9.39 • PPG 00:15 - 00:40 0.42 STWHIP P WEXIT 12576.7'FIRST 300+PSI SPIKE IN PRESSURE FLATLINED THEN DRILLED OFF 00:40 - 01:00 0.33 STWHIP P WEXIT 12577.0'PRESSURE DROPPED OFF--200PSI AND WOB DROPPED-200# RIH AND STACKED WT AGAIN,COMTINUE MILLING 01:00 - 01:40 0.67 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW @ 12577.4' 2.58/2.61 BPM 2580 PSI FS, WHP/IAP/OAP= 40/5/203 PSI PVT=447 BBLS DHWOB=1.01K ECD=9.38 PPG 12577.6'LOOKS LIKE WE POPPED OUT HERE, CONTINUE TIME MILLING TO DRESS BOTTOM OF WINDOW WITH STRING MILL STILL GETTING A LOT OF METAL BACK 01:40 - 02:00 0.33 STWHIP P WEXIT CONTINUE TIME MILLING @ 12578.0' 2.58/2.61 BPM 2580 PSI FS, WHP/IAP/OAP= • 40/5/200 PSI PVT=447 BBLS DHWOB=0.4K ECD=9.38 PPG *****FIRE DRILL IN THE SCR ROOM***** 02:00 - 02:45 0.75 STWHIP P WEXIT 12579.0'START APPLYING WT MILLING FORMATION 2.58/2.61 BPM 2580 PSI FS, WHP/IAP/OAP= 40/4/188 PSI PVT=447 BBLS DHWOB=0.3K ECD=9.37 PPG DRILLING AHEAD @ 23 FPH 4.5K WOB 12581.5'STOP AND ALLOW WOB TO DRILL OFF THEN CONTINUE MILLING FORMATION Printed 10/13/2010 12:42:32PM North America -ALASKA- BP Page 3 of 5 Operation Summary Report Common Well Name: 13-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:8/27/2010 End Date: X3-000V5D-C(832,266.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.: NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:45 - 02:50 0.08 STWHIP P WEXIT AT 12588'WE HAVE 10'OF FORMATION, STOP AND ALLOW WT TO DRILL OFF 02:50 - 04:00 1.17 STWHIP P WEXIT BACKREAM PUH SLOW AT 1 FPM BACKREAMING TO 12560'CLEAN RIH AT 1 FPM TO 12588'CLEAN 04:00 - 04:15 0.25 STWHIP P WEXIT MADE 3 PASSES AT 1 FPM CLEAN IN EACH DIRECTION,SHUT DOWN PUMP TO DRY DRIFT BOTH DIRECTIONS 04:15 - 06:15 2.00 STWHIP P WEXIT DRY DRIFTS WERE CLEAN RIH TO TOWS AND OPEN EDC TO CIRC HOLE CLEAN AT 3+ BPM WHILE POOH. 06:15 - 06:30 0.25 STWHIP P WEXIT PJSM FOR CHANGE OUT BHA. OVERHEAD LOADS AND WELL CONTROL WERE DISCUSSED. 06:30 - 07:30 1.00 STWHIP P WEXIT TAG STRIPPER,L/D WINDOW MILL AND 2 JTS PH6. MILL IS 3.80 GO,3.79 NO-GO 07:30 - 08:00 0.50 STWHIP N RREP WEXIT CLOSE MASTER VALVE. BLEED OFF ACCUMULATOR AND BOP SYSTEM PRESSURE. REPAIR A LEAKING FITTING ON THE UPPER 2-3/8"COMBI RAM OPENING HOSE,AT THE BOPS. 08:00 - 08:15 0.25 DRILL P PROD1 PJCK UP BHA#2-RE-RUN HYC BIT,1.2 DEG MOTOR,3"COILTRAK WITH RES. BHA OAL=78.76 FT. 08:15 - 08:30 0.25 DRILL P PROD1 CONDUCT UNANNOUNCED KICK DRILL WHILE CHANGING BHA. HALF THE BHA WAS IN THE WELL AT THE TIME. DRILLER RESPONDED APPROPRIATELY BY PULLING THE ENTIRE TOOL STRING OUT OF THE STACK,SO THE BLINDS OR MASTER VALVE COULD THEN BE SHUT. DRILL ENDED AT THIS POINT,AAR WAS HELD AND LESSONS LEARNED WERE DISCUSSED WITH CREW. 08:30 - 09:00 0.50 DRILL P PROD1 CONTINUE M/U BHA. 09:00 - 09:50 0.83 DRILL N DFAL PROD1 TEST TOOL AT SURFACE,ORIENTER FAILS. PULL ENTIRE BHA OUT OF STACK AND REPLACE ORIENTER. M/U BHA#2 AGAIN AND RE-TEST.DGS FAIL$ THIS TIMF _. 09:50 - 13:20 3.50 DRILL N DFAL PROD1 PULL OUT ENTIRE TOOLSTRING AND STAND IT BACK. TEST OUT NEW DGS IN THE MOUSEHOLE FIRST THEN REPLACE IT AND THE ORIENTER IN BHA#2. TOOL FAILS AGAIN. TESTED OK IN THE HORIZONTAL POSITION,AS DID THE OTHERS. REPLACE P&C.FINALLY GETA WORKING BHA. 13:20 - 16:00 2.67 DRILL P PROD1 TEST TOOL AT SURFACE,GOOD. RIH,PUMP 0.25 BPM/700 PSI. 16:00 - 17:10 1.17 DRILL P PROD1 LOG GR DOWN FROM 12,400 FT,CORRECT -31.5 FT. PASS THROUGH WINDOW,TAG BOTTOM AT 12,589 FT. Printed 10/13/2010 12.42.32PM North America -ALASKA- BP Page 4 of 5 Operation Summary Report Common Well Name: 13-21 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:8/27/2010 End Date: X3-000V5D-C(832,266.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.: NORDIC 2 1 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:10 - 18:30 1.33 DRILL P PROD1 DRILL FROM 12,589 FT. HOLD 30L TF INITIALLY TO BUILD ANGLE TO AROUND 60 DEG AND GAIN SEPARATION FROM THE OLD WELL. 2.42/2.48 BPM @ 2300-2700 PSI. ROP IS 80-100 FT/HR GETTING STARTED. 18:30 - 19:30 1.00 DRILL P PROD1 12,618'CONTINUE DRILLING AHEAD 2.56/2.61 BPM 2580 PSI FS, WHP/IAP/OAP= 40/5/89 PSI PVT=445 BBLS DHWOB=1.07K ECD=9.39 PPG 19:30 - 21:00 1.50 DRILL P PROD1 12,637'3 STALLS AT THIS DEPTH 2.57/2.62 BPM 2585 PSI FS, WHP/IAP/OAP= 44/6/90 PSI PVT=445 BBLS DHWOB=1.10K ECD=9.41 PPG LOOKS LIKE OUR PIP TAG CAME IN AT 12574' TOWS=12564' 21:00 - 22:00 1.00 DRILL P PROD1 12,667'_DRILLING AHEAD SLOW RATTY DRILLING 2.56/2.66 BPM 2468 PSI FS, WHP/IAP/OAP= 40/5/140 PSI ROP=27 FPH PVT=446 BBLS DHWOB=2.55K ECD=9.39 PPG 22:00 - 00:00 2.00 DRILL P PROD1 12,680'DRILLING AHEAD SLOW RATTY DRILLING 2.56/2.61 BPM 2468 PSI FS, WHP/IAP/OAP= 37/4/167 PSI ROP=30 FPH PVT=446 BBLS DHWOB=3.01K ECD=9.42 PPG 12714'MIDNIGHT DEPTH CONTINUE REPORT ON 8/29/2010 8/29/2010 00:00 - 02:05 2.08 DRILL P PROD1 CONTINNUE FROM REPORT 8/28/2010 CONTINUE DRILLING AHEAD @ 12714'WITH SLOW RATTY ROP 2.56/2.61 BPM 2468 PSI FS, WHP/IAP/OAP= 40/5/178 PSI ROP=36 FPH PVT=446 BBLS DHWOB=1.45K ECD=9.41 PPG '02:05 - 02:35 0.50 DRILL P PROD1 SHORT TRIP AND TIE IN CALL IN BHCT 136°F TO SLB CMT SUPERVISOR CHARLES HACKER 2.56/2.44 BPM 2768 PSI FS, WHP/IAP/OAP= 33/5/172 PSI PVT=445 BBLS ECD=9.44 PPG ABOVE WINDOW OPEN EDC TO CIRC WHILE TIE IN(CMT SHEATH) 02:35 - 02:45 0.17 DRILL P PROD1 SLB MECHANICS HERE TO AJUST PILOT CONTROL VALVE FOR INJECTOR 02:45 - 04:00 1.25 DRILL P PROD1 LOG DOWN FROM 12400'@ 300 FPH STOP AT 12550'AND CLOSE EDC STOP AT 12600'AND ADD 2.5'(TIED IN TO SAG ON PDC LOG) PIP TAG IS AT 12575 AND THAT PUTS THE TOWS AT 12565' _ CONTINUE RIH LOGGING TO 12750' 04:00 - 05:30 1.50 DRILL P PROD1 CONTINUE DRILLING AHEAD @ 12752' 2.50/2.55 BPM 2600 PSI FS, WHP/IAP/OAP= 40/5/156 PSI ROP=44 FPH PVT=444 BBLS DHWOB=0.56K ECD=9.43 PPG Printed 10/13/2010 12:42:32PM North America -ALASKA- BP Page 5 of 5 Operation Summary Report Common Well Name: 13-21 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:8/27/2010 End Date: X3-000V5D-C(832,266.00) Project:Prudhoe Bay Site: PB DS 13 Rig Name/No.: NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:30 - 09:20 3.83 DRILL P PROD1 CONTINUE DRILLING AHEAD @ 12790' 2.52/2.56 BPM 2600 PSI FS, WHP/IAP/OAP= 37/6/161 PSI ROP=43 FPH PVT=444 BBLS DHWOB=0.40K ECD=9.46 PPG DRILL TO 12,900 FT. 09:20 - 09:50 0.50 DRILL P PROD1 WIPER TRIP FROM 12,900 FT TO WINDOW. CLEAN PASS UP AND DOWN. 09:50 - 14:00 4.17 DRILL P PROD1 DRILL FROM 12,900 FT. CONTINUE HOLDING AROUND 60 DEG INC,CUTTING DOWN THROUGH ZONE 4 LAYERS. ROP IS AROUND 40 FT/HR WITH 1-2K DWOB. OCCASIONAL STALLS AS SHALE LAYERS ARE ENCOUNTERED. DRILL TO 13008 FT. 14:00 - 15:20 1.33 DRILL P PROD1 AT 18008 FT f R MARKS COME IN THAT LOOKS MORE LIKE 13-18 TO THE NORTH WHICH WE ARE DRILLING TOWARDS. IN tr THAT WELL THE CONGLOMERATE IS NOT AS DEEP SO TD IS CALLED AT 13008 FT. PULL WIPER TRIP BACK TO 12,000 FT. PULL THROUGH WINDOW AND OPEN EDC,PUMP 3.0 BPM. LOG ACROSS RA TO TIE-IN DEPTH. RIH AND TAG BOTTOM AT 13,010 FT, OFFICIAL TD FOR THE WELL. 15:20 - 16:30 1.17 DRILL P PROD1 WIPER TRIP BACK TO WINDOW. CLEAN PASS UP AND DOWN. 16:30 - 19:30 3.00 DRILL P PROD1 POOH LAY IN LINER PILL FROM TD. PULL THROUGH WINDOW AND OPEN EDC, PUMP 3 BPM WHILE POOH. LOG CCL ACROSS LINER TOP AREA WHILE POOH. FLAG PIPE AT WINDOW AND TD DEPTH FOR NEXT RUN. 19:30 - 19:50 0.33 DRILL P l PROD1 PJSM TO LD DRILLING BHA 19:50 - 20:30 0.67 DRILL P PROD1 CHECK FOR FLOW,NO FLOW PU INJECTOR LD BHA BHA OOH BIT CAME OUT WITH 2 CHIPPED CUTTERS ON THE NOSE GRADE=3-1 20:30 - 20:45 0.25 DRILL P PROD1 PJSM TO PUMP SLACK OUT OF COIL 20:45 - 21:30 0.75 DRILL P PROD1 PUMP SLACK OUT OF COIL,LOOKING FOR JUST OVER 200' PUMPED OUT 180',—40'OF SLACK STILL IN COIL SEAL END OF WIRE AND PREP COIL FOR BTT CTC 21:30 - 00:00 2.50 DRILL P PROD1 PULL TEST CTC TO 35K PRESSURE TEST CTC TO 3500 PSI PREP TO PUMP DRIFT BALL,LOAD 3/4"BALL IN REEL PUMP BALL AND LANDED ON SEAT @ 50 BBLS,CALC VOL=58 BBLS SET INJECTOR ON THE FLOOR TO PREP FOR LINER MU Printed 10/13/2010 12:42:32PM North America -ALASKA- BP Page 1 of 5 Operation Summary Report Common Well Name: 13-21 AFE No Event Type: COM-ONSHORE(CON) Start Date:8/29/2010 End Date: X3-000V5D-C(752,283.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.:NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft 8/30/2010 00:00 - 00:15 0.25 CASING P -_ RUNPRD CONTINUE REPORT FROM 08/29/2010 PREP FLOOR TO RUN LINER 00:15 - 00:40 0.42 CASING P RUNPRD PJSM TO MU LINER 00:40 - 03:30 2.83 CASING P RUNPRD MU LINER,_ FILL LINER AT END OF 2-7/8" M`A- (' � MU 3-3/16"LINER Vl MU 3-1/2"LINER JJJ 03:30 - 03:45 0.25 CASING P -_ RUNPRD MU SELRT RUNNING TOOL PULL SELRT AND INSTALL X-NIPPLE 03:45 - 04:00 0.25 CASING P RUNPRD MU SELRT AND PH6 TUBING 04:00 - 04:15 0.25 CASING P RUNPRD PU INJECTOR AND MU TO LINER 04:15 - 04:30 0.25 CASING P - RUNPRD CIRC TO FILL LINER AND UNTIL RETURNS ARE CLEAN 04:30 - 07:00 2.50 CASING P RUNPRD RIH CIRC AT MIN RATE,TRIPS SET AT 1700 PSI 330 BBLS ON PITS 2,3&5. STOP AT FIRST FLAG AND CORRECT-26 FT, CONSISTENT WITH CORRECTIONS ON PREVIOUS RUNS. 07:00 - 08:30 1.50 CASING P RUNPRD LAND LINER ON BOTTOM,CIRCULATE. UP WT IS 52K. GET TO A BALL DROP POSITION AND DROP 5/8"STEEL BALL. LAUNCH WITH 900 PSI. • BALL IS HEARD ROLLING IN REEL HOUSE. AFTER 1 CT VOLUME+5 BBLS BALL IS NOT ON SEAT. RE-LAUNCH WITH SURFACE PRESSURE AND SURGE PUMP SEVERAL TIMES. BALL IS ON SEAT AT 68.9 BBLS. SHEAR OUT SEAT AT 4500 PSI. 08:30 - 11:50 3.33 CASING P RUNPRD PICK UP TO BREAKOVER WT+2 FT. NEW UP WT IS 43K. STACK 10K DOWN AND CIRC WELL OVER TO KCL. SPOT CEMENT VAN THEN RE-SPOT IT TO GAIN MORE ROOM IN FRONT OF THE RIG. SPOT CONTAM PILL TRUCK. WITH KCL ALL THE WAY AROUND PUMP 1.5 BPM/520 PSI. 11:50 - 12:15 0.42 CASING P RUNPRD SEND KCL WATER DOWN TO CEMENT VAN FOR PT AND FLUID PACK LINE. CONTINUE CIRC KCL WATER AROUND WELLBORE. 12:15 - 12:30 0.25 CASING P ■ RUNPRD PJSM FOR PUMPING CEMENT. MUSTER AREAS,PUMPING,GOOD COMS WERE DISCUSSED. 12:30 13:05 0.58 CASING P ■- RUNPRD CEMENT LINE TO GOOD. RESTART CIRC THE C CIRC DOWN THE CT,START BATCHING UP CEMENT. Printed 10/13/2010 12:42:12PM North America -ALASKA- BP Page 2 of 5 Operation Summary Report Common Well Name: 13-21 AFE No Event Type:COM-ONSHORE(CON) Start Date:8/29/2010 End Date: X3-000V5D-C(752,283.00) Project:Prudhoe Bay Site: PB DS 13 Rig Name/No.: NORDIC 2 Spud Date/Time. Rig Release: Rig Contractor:NORDIC CALISTA _ UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:05 - 14:30 1.42 CASING P RUNPRD CEMENT IS UP TO WEIGHT. START CEMENT DOWN CT. ZERO IN MM ON DENSITY CHANGE. PUMP 18.5 BBLS CMT THEN SHUT DOWN, CLEAN UP LINE GOING TO CEMENT UNIT. ZERO IN MM ON DISPLACEMENT, DISPLACE CMT FROM COIL AT 2.0 BPM. SLOW TO 1.5 WHEN LEADING EDGE IS AT THE LWP. ZERO OUT MM WHEN CMT IS AT SHOE. WITH 2 BBLS CMT ABOVE SELRT,STOP PUMP,PICK UP CT WT+13 FT. SET BACK DOWN 10K WT,NOW 10 FT HIGHER DEPTH. PUMP 0.3 BBLS TO PUSH PEE WEE DART INTO LWP,THEN PICK UP CT WT+1 FT. EXHAUST REMAINING 2 BBLS CMT AND 3 BBLS BIOZAN. OPEN BAKER CHOKE AND STACK 10K DOWN, CLOSE CHOKE AND PRESSURE UP TO 3700 PSI TO SHEAR OUT LWP. BUMP WITH 6.5 BBLS(6.2 CALCULATED). HOLD 2800 PSI FOR 5 MIN. OPEN CHOKE AND CHECK FLOATS, HOLDING. CLOSE CHOKE THEN PULL OUT OF SLEEVE,PUMP 3 BBLS THEN POOH. ALL PARAMETERS OF CEMENT JOB WERE NORMAL. 18.5 BBLS CMT PUMPED,17.4 BBLS BEHIND PIPE. 14:30 - 16:45 2.25 CASING P RUNPRD POOH, PUMP CT VOIDAGE+0.6 BPM. 16:45 - 17:00 0.25 CASING P - RUNPRD SAFETY MEETING. PJSM FOR UD LINER RUNNING TOOLS. 17:00 - 18:00 1.00 CASING P RUNPRD TAG STRIPPER. L/D LINER RUNNING TOOLS AND RECOVER 5/8"STEEL BALL. TOOLS HAVE FUNCTIONED NORMALLY. OFFLOAD BTT TOOLS AND PREP RIG FLOOR FOR RUNNING CSH AND MGR-CCL. 18:00 - 19:00 1.00 CASING P -_ RUNPRD TOOLS OFF LOADED WAIT ON SWS TO SHOW UP WITH MEM LOG TOOLS , 19:00 - 19:20 0.33 CASING P RUNPRD PJSM TO MU CLEAN OUT&LOGGING BHA 19:20 19:45 0.42 CASING P ■- RUNPRD MU 2. MILL TR MOTOR JTS OF FOR 2 JTS OF CSH FOR SPACE OUT BETWEEN MOTOR&LOGGING TOOLS 19:45 - 20:15 0.50 CASING N WSEQ RUNPRD WHILE MAKING UP THE LIFT SUB TO PU THE SWS CARRIER THE MOTOR MAN SPOTTED A DEFECT AT A CONNECTION ON THE CARRIER THAT LOOKS LIKE IT IT FLOW CUT. ASKED SWS ENGINEER TO HAVE ANOTHER SUB BROUGHT OUT TO REPLACE THE DAMAGED ONE 20:15 - 21:45 1.50 CASING P ■ RUNPRD DAMAGED SUB REPLACED,CONTINUE MU BHA 21:20 CMT UCA AT 500 PSI 21:45 - 22:00 0.25 CASING P RUNPRD PU INJECTOR AND STAB ONTO BHA 22:00 - 23:35 1.58 CASING P RUNPRD STABBED ON CIRC AT MAX RATE FOR 10 BBLS TO ENSURE BHA IS CLEAR SET DEPTHS WITH SWS MEM LOGGER AND RIH 22:45 CMT UCA AT 1000 PSI Printed 10/13/2010 12:42:12PM North America -ALASKA- BP Page 3 of 5 Operation Summary Report Common Well Name: 13-21 AFE No Event Type:COM-ONSHORE(CON) Start Date:8/29/2010 End Date: X3-000V5D-C(752,283.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.:NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations hr) (ft) 23:35 - 00:00 0.42 CASING P ■- RUNPRD SWAP TO PERF PILL 00:00 DEPTH 11,150' CONTINUE REPORT ON 8/31/2010 8/31/2010 00:00 - 00:15 0.25 CASING P .- RUNPRD CONTINUE FROM REPORT 8/30/2010 CONTINUE RIH • 11150' 00:15 - 00:30 0.25 CASING P RUNPRD RIH THROUGH TOL CLEAN UCrA WAS 1000 PSI @ 22:45 BRING PUMP ONLINE AT FULL RATE 1.5 BPM AND RIH @ 50 FPM 1.55/1.82 1718 PSI WH/IA/OA=22/0/20 PSI PVT=195 BBLS 00:30 - 00:35 0.08 CASING P RUNPRD REDUCE RATE FOR TAG TAG 13000'PU WT 47K TAG AGAIN SAME DEPTH,PU TO UP WT AND PAUSE TO START LOGGING 00:35 - 01:00 0.42 CASING P RUNPRD START LOGGING UP @ 45 FPM LAYING IN PERF PILL STOP AT 12865'AND PAINT YELLOW&WHITE FLAG(EOP DEPTH 11700') CONTINUE POOH LOGGING UP TO 12000'AS PER PROGRAM 01:00 - 02:30 1.50 CASING P RUNPRD 12000'END OF LOGGING,PAUSE FORA FEW ■- MINUTES POOH CIRCULATING TO SURFACE 02:30 - 03:45 1.25 CASING P RUNPRD GETTING CONTAMINATED CEMENT BACK • 03:45 - 04:30 0.75 CASING P - RUNPRD RETURNS CLEANING UP,CONTINUE POOH FROM 2900' 04:30 - 04:50 0.33 CASING P RUNPRD OOH,PJSM TO LD CLEAN OUT BHA 04:50 - 05:10 0.33 CASING P ® RUNPRD PU INJECTOR AND SET INJECTOR ON ITS LEGS 05:10 - 05:30 0.33 CASING P RUNPRD LD PH6&DROP 1/2"BALL TO OPEN CIRC SUB 05:30 - 06:15 0.75 CASING P RUNPRD PULL CSH 06:15 - 06:30 0.25 CASING P RUNPRD LD MEM LOG TOOLS AND DOWNLOAD DATA 06:30 - 08:55 2.42 CASING P RUNPRD DOWNLOADING DATA AND WAITING FOR CMT TO REACH 2000PSI COMPRESSIVE STRENGTH. LOAD PERF GUNS INTO PIPE SHED. 08:55 - 10:00 1.08 CASING P RUNPRD PERFORM LINER LAP TEST,GOOD TEST. 08:55 2371 PSI 09:00 2354 09:10 2331 09:15 2336 09:27 2315 09:30 2314 LINER LAP TEST RESULTS SATISFY ALL 3 CRITERIA IN 2010 ADWOP: 1. OVERALL PRESSURE LOSS<10%OF MAX TEST PRESSURE 2. PRESSURE LOSS SECOND 15 MIN<=HALF PRESSURE LOSS IN FIRST 15 MIN 3. LOSS RATE<5 PSVMIN FOR FINAL 15 MIN 10:00 - 10:15 0.25 PERFOB P ■- OTHCMP PJSM WITH SLB TCP AND RIG CREW FOR P/U PERF GUNS. WELL CONTROL AND DROPPED OBJECTS WERE DISCUSSED. 10:15 - 12:15 2.00 PERFOB P OTHCMP PICK 11P PFRF RHA S5 R PERF GUNS,5/8 DISCONNECT,15 STDS 1.25"CSH,3/4 DISCONNECT, DBPV,2 JTS PH6. BHA OAL=1192.74 FT. Printed 10/13/2010 12:42:12PM North America -ALASKA- BP Page 4 of 5 Operation Summary Report Common Well Name: 13-21 AFE No Event Type:COM-ONSHORE(CON) Start Date:8/29/2010 End Date: X3-000V5D-C(752,283.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.: NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor:NORD I C CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:15 - 15:15 3.00 PERFOB P OTHCMP RIH WITH PERF ASSY CIRCULATING @ MIN RATE TIE IN TO EOP FLAG UNCORRECTED @ 11,700 WITH-31'CORRECTION RIH&TAG PBTD UNCORRECTED @ 13,001' PU TO BO WT @ 51K @ 12,996' RESET DEPTH TO 12,969'AS PER SWS MEMORY LOGS PU TO 12,907' 15:15 - 15:55 0.67 PERFOB P OTHCMP CALIBRATE PR AS PER SLP TCP TO FIRE GUNS FIRE GUNS AS PER SLB E-FIRE PROCEDURE FIRE GUNS ON THE FLY SHOTS FIRED WITH GOOD INDICATION @ 12,905 ****PERF INTERVALS 12750'-12810'AND �� 12860'-12905'W/2"6SPF 2006PJ PERF GUNS**** 15:55 - 19:20 3.42 PERFOB P OTHCMP PJSM TO POH WITH SLB&NORDIC DRILLER HOLD 400 PSI ON BACKSIDE AS PER RP& TOWN WHILE POH TO TOL @ 12,100' 16:15=FLOW CHECK FOR 30 MIN NO FLOW POH WHILE CONTINUEING TO HOLD 400 PSI AS PER RP&TOWN - 19:20 - 19:30 0.17 PERFOB P OTHCMP OOH,BLEED OFF WHP 19:30 - 19:50 0.33 PERFOB P OTHCMP 30 MIN NO FLOW CHECK PVT 352 BBL 19:50 - 20:10 0.33 PERFOB P OTHCMP PJSM TO PU INJECTOR AND LD PERF BHA 20:10 - 21:40 1.50 PERFOB P OTHCMP NO FLOW,PU INJECTOR LD PH6 TUBING PULL CSH 21:40 - 22:00 0.33 PERFOB P OTHCMP PJSM TO LD PERF GUNS 22:00 - 22:45 0.75 PERFOB P OTHCMP LD SPENT PERF GUNS 22:45 - 23:05 0.33 PERFOB P OTHCMP PERF GUNS QOH.ALL SHOTS FIRED LO PERF GUNS 23:05 - 23:20 0.25 CONDHL P OTHCMP PJSM TO PU INJECTOR TO FREEZE PROTECT WELL 23:20 - 23:40 0.33 CONDHL P OTHCMP PU INJECTOR&MU NOZZLE BHA 23:40 - 00:00 0.33 CONDHL P OTHCMP RIH TO FREEZE PROTECT WELL 9/1/2010 00:00 - 00:40 0.67 CONDHL P OTHCMP CONTINUE FROM REPORT 8/31/2010 CONTINUE RIH @ 1000' RETURNS SMELL LIKE THEY HAVE A LITTLE CMT IN THEM.WE STILL HAVE 50 BBLS OF NEW KCL, RIH TO 5000'AND PUMP 50 BBLS OF NEW KCL FROM PITS THEN FINISH OFF THE FINAL 2500'WITH DIESEL.LRS ON LOCATION SWAPPING FLUIDS FROM TRANSPORT TO HIS UNIT BECAUSE WE ARE TIGHT ON SPACE. 00:40 - 01:00 0.33 CONDHL P OTHCMP POOH LAYING IN NEW KCL 01:00 - 01:15 0.25 CONDHL P OTHCMP AT 2500'WO LRS TO COMPLETE FLUID TRANSFER 01:15 - 01:20 0.08 CONDHL P OTHCMP PJSM WITH LRS TO FREEZE PROTECT WELL 01:20 - 01:45 0.42 CONDHL P OTHCMP PT LRS TO 4500PSI ONLINE WITH DIESEL DOWN COIL Printed 10/13/2010 12:42:12PM North America -ALASKA- BP Page 5 of 5 Operation Summary Report Common Well Name: 13-21 1 AFE No Event Type:COM-ONSHORE(CON) Start Date: 8/29/2010 End Date: X3-000V5D-C(752,283.00) Project:Prudhoe Bay Site:PB DS 13 Rig Name/No.: NORDIC 2 Spud Date/Time: Rig Release: Rig Contractor: NORDIC CALISTA UWI: Active Datum:35:21 4/25/1982 00:00 @84.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft 01:45 - 02:15 0.50 CONDHL P OTHCMP POOH LAYING IN DIESEL GOOD DIESEL TO SURFACE,SHUT DOWN PUMP • GREASE CREW ON LOCATION TO SERVICE TREE TAG UP,CLOSE MASTER&PUMP 1 BBL TO CLEAN FRESH WATER AND SHUT DOWN 02:15 - 02:30 0.25 RIGD P OTHCMP PJSM WITH GREASE CREW TO SERVICE ■ TREE PJSM WITH SLB N2 TO RU N2 PUMPER 02:30 - 03:00 0.50 WHSUR P OTHCMP SERVICE TREE 03:00 - 03:20 0.33 WHSUR P OTHCMP PJSM TO LOAD VALVE CREW LUBRICATOR ON RIG TO INSTALL BPV PJSM WITH SLB TO COOL DOWN AND PUMP N2 03:20 - 04:40 1.33 WHSUR P OTHCMP LOAD LUB ON RIG ■ PT LUBRICATOR TO 300&3500 PSI SET BPV AND OFF LOAD LUBRICATOR 04:40 - 05:00 0.33 RIGU P - OTHCMP PU INJECTOR AND STAB ON WELL PT N2 LINE TO 4000 PSI 05:00 - 06:00 1.00 RIGU P OTHCMP RIH AND TAG THE SWAB BLOW DOWN REEL AT 1500 SCFM BLEED OFF 06:00 - 06:30 0.50 RIGU P OTHCMP CREW CHANGE OUT 06:30 - 06:45 0.25 RIGU P ® OTHCMP PJSM TO UNSTAB COIL&RU TO PULL COIL ACROSS } 06:45 - 07:15 0.50 RIGU P ® OTHCMP UNSTAB COIL&RU TO PULL COIL ACROSS TO REEL 07:15 07:30 0.25 RIGU P ■ OTHCMP AAR FOR UNSTAB&RU PJSM TO PULL COIL ACROSS&SECURE IT TO THE REEL 07:30 - 08:45 1.25 RIGD P OTHCMP PULL COIL ACROSS&SECURE IT TO THE REEL 08:45 - 09:00 0.25 RIGD P OTHCMP AAR FOR PULLING COIL ACROSS& SECURING IT TO REEL PJSM TO LOWER REEL FROM REELHOUSE& SECURE TO TRUCK PJSM TO ND BOPE WHILE LOWERING REEL 09:00 11:30 2.50 RIGD P ■- OTHCMP LOWER L FROM REELHOUSE&SECURE TO TRUCK COMPLETED @ 10:00 ND BOPE 11:30 - 12:15 0.75 RIGD P OTHCMP AAR FOR ND OF BOPE PJSM TO PT TREE CAP 12:15 - 13:00 0.75 RIGD P OTHCMP PT TREE CAP WITH DIESEL PT GOOD 13:00 - 13:30 0.50 RIGD P OTHCMP PJSM TO BACK RIG OFF WELL 13:30 - 14:00 0.50 RIGD P ■- OTHCMP C LOCATION LOCC ATION RIG RELEASED •P 14:00 Printed 10/13/2010 12:42:12PM 13-21 A, Well History (Pre & Post Rig Sidetrack) Date Summary 05/13/10 T/I/0=1050/220/0 Temp=Hot MIT IA PASSED to 3000 psi. (Prep for CTD) MIT IA pressured up to 3000 psi with 5 bbls neat methanol. IA lost 20 psi in first 15 minutes and 0 psi in second 15 minutes. For a total of 20 psi in 30 minutes. Bled pressure down. FWHP's=1050/400/0 VALVES in following positions-and operator notified of positions and result of job: Wing open, Swab closed, SSV open, Master open, IA open, OA open-Well on injection 05/24/10 RIG UP SWCP#4515 TO DRIFT TUBING W/3.70" x 20 DMY WHIPSTOCK. 05/25/10 RAN 3.70"x 20' DMY WHIPSTOCK UNABLE TO PASS 12156'SLM. RAN 3.625" CENT, 3.00" S.BAILER, DRIFT TO 12650' SLM RAN 4-1/2"TEL, 5'x 3.00" DRIVE DOWN BAILER TO 12600' SLM, NO PROBLEMS.(unable to loc tt) RAN 4-1/2"TEL, KJ, 3.70" CENT,2'x 1-7/8" STEM, 3.64 G-RING, LOC.TT&TAG BTM. @ 13016' ELMD. 68'OF FILL ABOVE BTM. OF LOWEST PERF. RAN 3.70"x 20' DMY WHIPSTOCK TO 13016' ELMD, NO PROBLEMS. 06/03/10 T/I/0=180/0/0 Freeze protect flow line with 82 bbls 60/40 methanol. (Prep for CTD) FWHP's=180/0/0 VALVES in following positions-and operator notified of positions and result of job: Wing closed, Swab closed, SSV open, Master open, IA open, OA open-Well SI 06/06/10 ***WELL INJECTING ON ARRIVAL*** (ELINE-WHIPSTOCK) **WIRELINE VALVE TESTED IN SHOP AND WITNESSED BY KEVIN BRACKETT** SHUT-IN WELL AT WING DURING RIG UP.T/I/O=0/140/0 PSI TOP OF WHIPSTOCK SET AT 12558.5', 10 DEG RIGHT OF HIGH SIDE, BOWS SET AT 12576',2 PIP TAGS AT 12568.5' FINAL T/I/O=0/0/0 PSI. 06/12/10 T/1/0=500/240/100,Temp=Hot. PPPOT-T(PASS), pre CTD. PPPOT-T: Stung into test port(0 psi). Functioned LDS, all moved freely(1"). Unable to pump through void, single port. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 06/15/10 CTU 8 . 1.75" CT Job Scope: P&A perfs, Mill XN. Move from K pad to DS 13. Wait on Wind before MIRU. 06/16/10 CTU 8; 1.75" 0.116 wall CT.Job Scope: P&A, Mill XN. MIRU on DS 13-21.Wait on LRS to freeze protect flow line. Fluid pack wellbore, perform injectivity test. Pump 46 bbls cement , obtain 1000 psi squeeze pressure.Wash down with biozan, pooh.** 06/16/10 Freeze protect FL from manifold building to wellhead. (CTD) Freeze protect FL w/95 bbls 60/40. pumping from manifold building to FL. Coil on wellhead upon departure 06/17/10 CTU 8. 1.75" CT.Job Scope: P&A perfs, Mill XN. Make up 3.80 LH motor and mill. RIH to XN at 12177 MD. Mill XN then have frequent stalls while getting to 12326'. Lost 350 psi CTP. POOH and found that motor bearing section had backed off leaving the mill, SR, motor housing and rotor in the hole. Make nozzle run to clean top of fish for fishing operations.POOH.** 06/18/10 CTU 8 1.75" CT, JOB SCOPE: Mill XN, P&A perfs. M/U BOT fishing assembly. RIH to top of fish.Attempt to latch 3x. POOH. Grapple had swallowed rotor to stop, but had no recovery. MU same assy w/smaller grapple. Had no indication of engagement. POOH. Found OS body packed full of injection solids mixed w/a little cement. Found leak in main injector hydraulic hose when under pressure. SD operations to replace hose. Hose replaced at 8pm.RIH w/fishing BHA. Page 1 of 4 13-21 A, Well History (Pre & Post Rig Sidetrack) Date Summary 06/19/10 CTU 8, 1.75 CT:Job Scope: P&A , Mill XN: RIH w/fishing BHA. Engage fish at 12323 ft.Attempt multiple times to set down on fish. POOH- no fish. Cut 100 ft of CT. Make up fishing BHA w/roller dog OS in washpipe and RIH. Good indication of going over fish and got to 12331'. Had good overpulls when start POOH, but did not recover fish. Rerun same assy and get over fish while getting deeper to 12335'. Lots of good indications, but had only minor overpull when start OOH to check tools.Fish on bank. Make up milling assembly. RIH to 12326 begin milling 06/20/10 CTU 8 1.75"CT.Job Scope: P&A perfs. Mill XN. Mill from 12330 to 12493. Minimal motor work noticed from 12330 to 12460. Consistent motor work from 12460 to 12493. Mill hard cement w/o stalls to pinch point of WS at 12589' CTD. FP wellbore to 2500'w/ diesel.Weekly BOPE Test RDMO Job Complete. 06/22/10 T/I/O=0/20/0.Temp.=SI MITT PASSED to 1000 psi. ( Post Coil P&A). Pumped 2 bbls of 50* F diesel to reach test pressure.Tubing lost 40 psi. in the 1st 15 min. and 20 psi. in the 2nd 15 min.for a total loss of 60 psi. in a 30 min.test. Bled back to Final WHP=0/20/0. SV,WV,SSV-closed/MV-open/IA,OA-OTG 06/24/10 T/I/O=Vac/ONac.Temp=SI. Bleed WHP's to 0 psi (Pre CTD).WAG (water). No need to bleed. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 06/27/10 T/1/O=0/0/0 Set 5" Gray"K" BPV#613 @ 108", 1-2'ext. used; Set 5"Test Dart;Torqued tree flange studs to API specifications; Pressure tested (shell tested)tree too 5000 PSI w/no loss; Pulled Test Dart; Pulled BPV;Tested down on Swab valve with 5000 PSI, lost 200 psi in 5 min.test;Tested down on Master valve with 5000 psi, lost 175 psi in 5 min.test; Pre Nordic 2. 07/04/10 DRIFT W/2.75" CENT., 4-1/2"TEL,2-1/2" S-BAILER, S/D @ 11,978' SLM (CANNOT WORK PAST) RAN 9'x 2.25" P. BAILER, WORK PAST RESTRICTIONS,TAG TD @ 12538' SLM(RECOVERED CEMENT) 07/05/10 RAN 9'x 2.25" P. BAILER W/MULE SHOE FLAPPER, SD @ 12550' SLM(RECOVERED 3/4 GAL CEMENT) DRIFT W/KJ,2.50"CENT.,TEL, 2.50" S. BAILER, SD @ 12543' SLM/12484' ELM LOC.TT @ 12320' SLM=-59'TO ELM @ 12261' RUN PDS LOGGING TOOL FROM 12,535'SLM TO 10,000' SLM(GOOD DATA) ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 07/06/10 TAGGED DEPTH OF --12417' CORRECTED TO PDS JEWELRY LOG DATED 5-JULY-2010 LOGGED GYRO 12417'TO SURFACE FINAL VALVE POSITIONS: SWAB:CLOSED, MASTER:OPEN, WING: CLOSED, SSV: CLOSED. ***JOB COMPLETE, DSO NOTIFIED OF DEPARTURE*** 07/07/10 T/I/O=?/Vac/Vac.Temp=SI. Bleed WHPs to 0 psi (pre CTD).AL and flow line are disconnected and blinded.Well house is removed. Unable to read TGB pressure, Need scaffolding.there is no control line connected to SSV. Unable to verify SV,WV position. 07/10/10 T/I/O= 130/Vac/Vac.Temp=SI.WHPs(pre-CTD). Used manlift on location to access well. Pumped open SSV,closed after reading TP.Changed out incorrect jewelry on bonnet. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 07/27/10 T/I/O=600/vac/vac.Temp=SI. Bleed WHPs to 0 psi (pre CTD). Flow line and AL disconnected.Well house removed.TBG FL near surface. Bled TBG pressure to 0 psi in 30 min (all gas). SI, monitored for 30 min. No change in TBG pressure.Job complete. Final WHPs=0/vac/vac. SV=C. SSV, MV=O. IA, OA=OTG. NOVP. 08/02/10 T/1/O=?/0/VAC.Temp=SI.WHPs (pre-CTD). No welhouse, Flowline, AL line or scaffolding on well. Unable to obtain TP due to no scaffolding. No change in lAp or OAp since 7/27/10. SV,WV=?. SSV, MV=Open. IA, OA=OTG. Page 2 of 4 13-21 A, Well History (Pre & Post Rig Sidetrack) Date Summary 08/24/10 T/1/O=Vac/0/0 Pressure tested barriers: Master valve- Low: 300 PSI- 11:46- 11:51/20 PSI Loss 5 min. High: 3500 PSI : 11:56-00:01- 150 psi Loss . 00:06-00:11- 150 psi loss. 00:12-00:17- 150 psi loss. 00:19• 00:24 150 psi loss. 00:31-00:36 0 psi loss. 00:41-00:46 0 psi loss. SSV- Low: 300 psi-01:00-01:05 0 psi loss High: 3500 psi -01:09-01:14 150 psi loss. 01:19-01:24 25 psi loss. Rig up lubricator and tool string, pressure tested Lubricator- Low: 300 psi-02:52-02:57 0 psi loss High: 3500 psi-02:59-03:04 50 psi loss. 03:06-03:11 50 psi loss . Set 5-1/8" Gray"K" BPV#613 , 1-1/2'ext. used,tag @ 111". Pressure tested tree cap : Low: 300 psi -03:55-04:00 0 psi loss High: 3500 psi-04:01-04:06 50 psi loss....Pre- Nordic 2. 08/24/10 T/1/0=Bpv/0/0 Pressure tested SN(barrier)for 5 min. (1208-1213) low test w/20 psi loss-3500 psi for 5 min. (1231-1236) high test w/40 psi loss, Note:2 failed p/t in between, air in valve?; Pressure tested M/V (barrier)for 5 min. (1243-1248) low test w/20 psi loss-3500 psi for 5 min. (1321-1326) high test w/50 psi loss, Note: multiple failures in between low&high test on M/V, do to valves not being fluid packed& possible leakage; Set 5" Gray test dart w/t-bar into existing bpv for p/t; Pressure tested Bpv/Test Dart For 5 min. (1416-1421) low/test w/5 psi loss-5000 psi for 5 min. (1451-1456) high test w/10 psi loss, Note:2 failures on high test do valves still not being fluid packed; Pre Nordic 2 08/27/10 T/I/O=Vac/0/0 Set 5-1/8" Gray"K"test dart thru stack RKB=25.12+0.07... pressure tested THA x Master (Pass) ..Pressure tested Lubricator- Low: 300 PSI 06:08-06:13 ( PASS) High: 3500 PSI 06:15-06:20 (PASS) . Pulled 5-1/8" Gray"K" BPV#613....Nordic 2 moved over well....no problems. 09/01/10 T/1/O=0/0/0 Pressure tested lubricator Low: 300 PSI -5 Min./Pass High: 3500 PSI -5 Min./Pass Set 5- 1/8" Gray"K" BPV#613 thru stack, RKB=25.12+0.07, 3-5' 1-2'ext. used....tag 102"....Nordic 2 to move off well....no problems. 09/07/10 T/I/O=0/0/0;Test SSV to 500 psi.-passed;Test MV to 500 psi.- passed;Test Lubricator 83052 Low 300 psi High 3500 passed. Pulled 5 1/8" Gray K BPV#613 through tree for Nordic 1 post rig: 1-2' EXT used tagged @ 102";Tested Tree cap to 5000 psi.; No problems 09/08/10 DRIFT W/1.75" CENT. &SMPL BLR, UNABLE TO PASS MUD @ 11,958' SLM. 09/09/10 BAIL W/3-1/2" PUMP BAILER FROM 11,934' SLM TO 3-1/2" DEPLOYMENT SLV ( 12124' SLM. BAIL W/2-1/4" PUMP BAILER FROM 12,130' SLM TO 12,140' SLM. RAN THIRD RUN W/2-1/4" PUMP BAILER AND UNABLE TO PASS 12,137' SLM. 09/10/10 MULTIPLE RUNS W/2.25" PUMP BAILER BAILING CEMENT FROM 12137' SLM TO 12,142' SLM. RAN 3.50" LIB AND UNABLE TO PASS 12068' SLM. ATTEMPT TO BAIL W/2.25" PUMP BAILER WITH SERRATED BTM, UNABLE TO PASS 12081'SLM. 09/11/10 BAIL FROM 12074' SLM TO 12,082 SLM W/3.5" PUMP BAILER. UNABLE TO REACH TARGET DEPTH. 09/14/10 CTU #8 w/1.75"ct Job scope: Fill clean out. RIH w/2"JSN.Tagged hard at 12319' unable to jet thru POOH for motor& mill. RIH w/BOT Drillex motor an 2.30" HCC parabolic mill. Begin milling at 12319 ft. 09/15/10 CTU 8, 1.75"CT,Job Scope: Mill/Clean out. ***Job Continued from 9-14-10"". Continue milling from 12319 ft to 12955 ft. POOH,freeze protect w/McOH. 10/03/10 """WELL SHUT IN ON ARRIVAL"""(E-LINE PERFORATION) INITIAL T/I/O=0/0/0 CORRELATED TO SWS MEMORY LOG DATED 31-AUG-2010. TAGGED AT 12740'TWICE WITH 150#OVERPULL,TOOL STRING 20'X 2" PERF GUN. TOOL CONNECTIONS OOH HAD HARD PACKED WAXY SCHMOO/MUD/CEMENT?/METAL PCS, SAMPLE GIVEN TO PE. VALVES LEFT PER DSO. FINAL T/I/O=0/0/0 """PERFORATION NOT PERFORMED,WELL LEFT SHUT IN""" Page 3 of 4 13-21 A, Well History (Pre & Post Rig Sidetrack) Date Summary 10/04/10 ***WELL SHUT IN ON ARRIVAL***(pre eline pref.) DRIFTED WITH 2.25"GAUGE RING&SD @12,664' SLM,WORKED TOOLS TO 12,672' SLM. TOOLS CAME BACK COVERED IN HARD PARRAFIN. ****LEFT WELL SHUT IN, SSV NORMALED UP TO PANEL AND LEFT OPEN**** Page 4 of 4 F BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 13 13-21 - Slot 21 13-21A Survey: MWD Survey Report - Geographic 30 August, 2010 s Il ilk 00#.#BHUGHES Survey Report- Geographic i by INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 13-21 -Slot 21 Project: Prudhoe Bay TVD Reference: 35:21 4/25/1982 00:00 @ 84.00ft(generic drillinc Site: PB DS 13 MD Reference: 35:21 4/25/1982 00:00 @ 84.00ft(generic drillinc Well: 13-21 North Reference: True Wellbore: 13-21A Survey Calculation Method: Minimum Curvature Design: 13-21A Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 13,TR-10-14 Site Position: Northing: 5,932,645.45ft Latitude: 70°13'15.444 N From: Map Easting: 685,828.44ft Longitude: 148°30'2.303 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.41 ° 'Well 13-21 API No 500292078900 Well Position +N/-S 0.00 ft Northing: 5,932,586.81 ft Latitude: 70°13'14.560 N +E/-W 0.00 ft Easting: 687,095.40 ft Longitude: 148°29'25.561 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 13-21A API No 500292078901 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 11/18/2009 22.49 80.90 57,676 Design 13-21A Audit Notes: Version: Phase: ACTUAL Tie On Depth: 12,500.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 38.00 0.00 0.00 93.26 1 Survey Program Date: 8/30/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 12,421.80 GyroData(13-21) GYD-CT-CMS Gyrodata cont.casing m/s 12,500.00 12,500.00 1 :Sperry-Sun BOSS gyro multi(13-21) BOSS-GYRO Sperry-Sun BOSS gyro multishot 12,565.00 13,010.00 MWD(13-21A) MWD MWD-Standard 8/30/2010 9:27:49AM Page 2 COMPASS 2003.16 Build 71 Mt VI BAKER HUGHES Survey Report-Geographic by 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 13-21 -Slot 21 Project: Prudhoe Bay TVD Reference: 35:21 4/25/1982 00:00 @ 84.00ft(generic drillinc Site: PB DS 13 MD Reference: 35:21 4/25/1982 00:00 @ 84.00ft(generic drillinc Well: 13-21 North Reference: True Wellbore: 13-21A Survey Calculation Method: Minimum Curvature Design: 13-21A Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 12,500.00 53.57 98.70 8,727.83 -494.37 7,756.34 5,932,284.90 694,861.14 70°13'9.658 N 148°25'40.325 W TIP 12,565.00 53.90 98.45 8,766.28 -502.19 7,808.17 5,932,278.38 694,913.14 70° 13'9.581 N 148°25'38.820 W KOP 12,591.62 56.55 98.45 8,781.46 -505.40 7,829.79 5,932,275.70 694,934.84 70°13'9.549 N 148°25'38.193 W 12,624.16 60.05 95.50 8,798.56 -508.75 7,857.26 5,932,273.03 694,962.38 70°13'9.516 N 148°25'37.395 W 12,651.58 61.72 91.75 8,811.91 -510.25 7,881.17 5,932,272.12 694,986.31 70°13'9.501 N 148°25'36.701 W 12,680.46 61.35 87.25 8,825.68 -510.03 7,906.54 5,932,272.97 695,011.68 70° 13'9.503 N 148°25'35.964 W 12,713.39 60.27 82.50 8,841.74 -507.47 7,935.16 5,932,276.24 695,040.22 70° 13'9.528 N 148°25'35.133 W 12,740.71 59.85 78.62 8,855.38 -503.59 7,958.51 5,932,280.69 695,063.47 70°13'9.565 N 148°25'34.455 W 12,770.67 60.83 75.63 8,870.21 -497.79 7,983.89 5,932,287.12 695,088.69 70°13'9.622 N 148°25'33.718 W 12,799.57 61.14 72.47 8,884.23 -490.85 8,008.18 5,932,294.67 695,112.80 70° 13'9.690 N 148°25'33.012 W 12,830.84 60.40 70.66 8,899.50 -482.22 8,034.07 5,932,303.93 695,138.46 70° 13'9.775 N 148°25'32.260 W 12,859.96 58.84 74.91 8,914.23 -474.78 8,058.05 5,932,311.97 695,162.26 70° 13'9.848 N 148°25'31.563 W 12,889.68 58.81 80.52 8,929.63 -469.37 8,082.88 5,932,317.99 695,186.94 70°13'9.901 N 148°25'30.842 W 12,919.61 59.80 85.31 8,944.91 -466.20 8,108.41 5,932,321.79 695,212.39 70°13'9.932 N 148°25'30.100 W 12,949.83 58.36 90.00 8,960.45 -465.14 8,134.30 5,932,323.50 695,238.24 70° 13'9.942 N 148°25'29.349 W 12,965.74 58.06 91.38 8,968.83 -465.30 8,147.83 5,932,323.67 695,251.76 70° 13'9.940 N 148°25'28.956 W 13,010.00 58.06 91.38 8,992.24 -466.20 8,185.37 5,932,323.70 695,289.32 70° 13'9.931 N 148°25'27.866 W TD-2 7/8" 8/30/2010 9:27:49AM Page 3 COMPASS 2003.16 Build 71 TREE= FMC WELLHEAD= GRAY SAFE, _)TES: ACTUATOR= BAKER C DRAFT 13-21 A KB. ELEV = 84' BF.ELEV = ? ' - - ' KOP= 2100' Max Angle= 62°@ 12652' Datum MD= 12799' :-/-1/52:1'2024' 1 - TIP, = " /2O"RQY S RQMD SS5V SSSV(NI07/26/08)ID 4.562 Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80, ID= 12.347" -1 2513' II I 12123' H5-1/2"OTIS XA SLIDING SLV, ID-4.562" I Minimum ID = 2.377" @ 12655' 3-3/16" X 2-7/8" XO 12126' 1-13.70"DEPLOYMENT SLV,ID=3.00" 1 12147' (H 3-1/2"OTIS X NIP, ID= 2.812" I II 1 12184' H5-1/2"BOTPBRASSY — 12204' —19-5/8"X 5-1/2"BOT PKR w/7"MOE I 5-1/2"TBG-IPC, 17#, L-80 LT&C 8RD AB MOD, -1 12215' 1- 12215' —15-1/2"X 4-1/2"XO, ID=3.958" I .0232 bpf, ID=4.892" TOP OF 7"LNR H 12295' 12308' 1-14-1/2"OTIS XN NIP,MILLED TO 3.80"(06/17/10) I n 1 11 r, 4-1/2"TBG-IPC, 12.6#, N-80 BTC, H 12320' ��.4 • • 12320' H4-1/2"SHEAR OUT SUB, ID=3.958" I .0152 bpf, ID=3.958" ►���: S$I 12261' H ELMD TT LOGGED 12/20/85 I 1.44 04 1:44: 0 1tti .4 12557' —13-1/2"X 3-3/16"XO, ID=2.786" I 3-1/2"LNR,9.21x`,L-80 STL 12557' ►��� ���� .0087 bpf, ID=2.992" )$$1 1����� W4 1.0 7"WHIPSTOCK(08/28/10) 12565' $4•4.44 1$44:•$ MILLOUT WINDOW(13-21A) 12570'- 12578' PIP TAG(08/28/10) H 12575' 4���� 9-5/8"CSG,47#, L-80&S00-95, ID=8.681" H 12579' I ,'4% 12655' H 3-3/16"X 2-7/8"X0, ID=2.377" I 7"LNR,29#, L-80, .0371 bpf, ID=6.184" H 13404' PERFORATION SUMMARY REF LOG: SLB MEM GR/CCL ON 08/31/10 3-3/16"LNR,6.2#, L-80 TCII, 12655' ANGLE AT TOP PERF:60°@ 12750' .0076 bpf, ID=2.80" Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 6 12750- 12810 0 08/31/10 PBTD H 12969' I ,SQ,*, 2 6 12860- 12905 0 08/31/10 ,Vet∎ 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf, ID=2.441" -1 13008' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/25/83 ORIGINAL COMPLETION WELL: 13-21A 09/01/10 NORDIC2 CTD SIDETRACK(13-21A) PERMIT No: 2100600 09/05/10 SV DRLG HO CORRECTIONS API No: 50-029-20789-01-00 09/14/10 ?/JMD DRGL DRAFT CORRECTIONS SEC 14,TION,R14E, 1898.51 FEL&3095.2[NE. _ - BP Exploration (Alaska) C - SUAIrE ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Matt Brown Well Intervention Engineer BP Exploration (Alaska), Inc. �� ✓ 0 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-21A Sundry Number: 310-342 Dear Mr. Brown: 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. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission 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, ti Daniel T. Seamount, Jr. / Chair DATED this I I day of October, 2010. Encl. • STATE OF ALASKA ALASK, L AND GAS CONSERVATION COMMISSIL Io-I`�,1� a�,0� ,� APPLICATION FOR SUNDRY APPROVALS C�,K ''�� 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool Repair Weill] Change Approved Program❑ Suspend❑ Plug Perforations ❑ Perforate J Pull Tubing❑ Time Extension❑ Operation Shutdown❑ Re-enter Susp.Well ❑ Stimulate❑ Alter Casing ❑ Other:ACID WASH El 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 210-0600- 3.Address: P.O.Box 196612 Stratigraphic ❑ Service III 6.API Number: Anchorage,AK 99519-6612 50-029-20789-01-00 7.If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ PBU 13-21A 9.Property Designation(Lease Number): die(10.Field/Pool(s): ADLO-02833 oers/5 - PRUDHOE BAY Field/PRUDHOE BAY Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 13008 - 8991.18 - 13000 8986.95 - NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 20" SURFACE 75 SURFACE 75 Surface 2513' 13-3/8"72#L-80 SURFACE 2513 SURFACE 2485 4930 2670 Intermediate 12579' 9-5/8"47#L-80 SURFACE 12579 SURFACE 8774 6870 4760 Liner 410' 3-1/2"9.2#L-80 12417 12557 8505 8761 Liner 98' 3-1/16"6.2#L-80 12557 12655 8761 8813 Liner 53' 2-7/8"6.16#L-80 12655 13008 8813 8991 13450 13890 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): O 12750-12810 8860.02-8889.28 5-1/2"17# L-80 SURFACE 12215 O 12860-12905 8914.25-8937.5 4-1/2"12.6# N-80 12215 12320 Packers and SSSV Tvoe: 9-5/8"X 5-1/2"BOT PKR Packers and SSSV MD and TVD(ft): 12204 8548 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program p BOP Sketch ❑ Exploratory ❑ Development ❑ Service IS- 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/19/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Brown Printed Name k,a' :oY Title WIE Signature Phone Date 564-5874 10/12/2010 Prepared by Joe Lastufka 564-4091 I/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 i 0 -3 Q� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RECEIVED HIT 1 22010 Subsequent Form Required: ld' ,O f` q q I"118Sn8 Uf♦�t Jai 415. 1 Anchorage APPROVED BY Approved by:,I r COMMISSIONER THE COMMISSION Date: )(0`I� 1 0 RBDAAS OCT 14 ale Form 10-403 Revised 1/201Q RIGINAL Submit' is 9-s/ bp WM. ,rip ����11;`•= Memorandum To: C. Olsen/T. Norene Date: October 11, 2010 J. Bixby/R. Liddelow AFE: X3-00V5D-C:SPENDI From: Paulina Meixueiro/Matt Brown Production Engineer/Wells Group Est. IOR 200 Subject: 13-21A FCO/Acid Wash/Rperf 1 C FCO/Acid Wash 2 CP Reperforate pending injectivity post-acid job Current Status New Injector Last Inj: New Well- no inj history Max Deviation 62° at 12652 ft Min ID 2.37" at 12655' 3-3/16 x 2-7/8 XO Last Tag: 12672' SLM during SL tag 04-Oct-10 Last Downhole Op: SL drift 4-Oct-10 Latest H2S value: No data available for well SBHP/T @8800 SS 3310 psi / 176° ave for 13 Pad from recent statics SBHP/T: 3758 psi /153° on 09/22/10 most recent for 13-21A NOTE: Sundry Required Objective: Cleanout fill & establish communication with the reservoir. Background Information: i Well 13-21A is a Zone 4 injector sidetracked on 9/10 to replace parent well 13-21. The well has a 2-7/8" liner with perf intervals from 12,750' to 12,810 and from 12,860' to12,905'MD, targeting 46P and 44P. During the completion phase of the sidetrack 18.5 bbl cement were pumped and the cement job seemed to have gone well (see 8/30 Open Wells Report for details). A cleanout/logging run and the perf run were both made with no problems, no obstructions were seen. The liner lap clearly passed a pressure test, indicating that the cement was holding. On 9/9/10 SL attempted to obtain a SBHP. SL sat down at 11,945' SLM and made very slow hole to 11,958', recovering "tan, soft mud." With numerous bailer trips they were able to break through multiple fill bridges and make their way down to 12,142'. However, on subsequent bailer runs they kept tagging at -12,045' and making hole to about 12,081'. Overall SL recovered about 27 gallons of drilling mud and cement (both dry and watery). CTU initially tagged up at 12,067' and was able to make it down to 12,329' by pumping biozan. Starting at 12,319' they had to mill cement, and milled intermittently to12,444' and were then able to tag TD with no more noticeable motor work. On 9/22/10 S/L successfully tagged 12,948'SLM and run a SBHP survey (3,785 psi at 8,800' SS TVD @ 152 F). The measured pressure is -400 psi higher than offset pressures, indicating that the perfs are not in communication with the reservoir and the SBHP was just measuring hydrostatic pressure. The well was programmed to be put into injection on 9/28/10 by a controlled start-up procedure using fullbore, but the reservoir was not taking any fluid. The WHP was 460 psi before fullbore started displacing the fluid in the tubing. A total of 15 bbls of diesel and neat McOH were pumped at 0.35 bpm and the WHP increased up to 2,100 psi. The start-up failed because there was little/no communication with the reservoir. On 10/03/10 e-line attempted to re-perforate the original interval, however it was not able to make it below 12,740'SLM despite 150 lb overpull. SL recovered 'hard packed waxy mud/cement/metal pieces that were sent to the lab. Lab analysis revealed that the sample was primarily sand and iron and soluble in HCI. The objective is to fill clean-out and establish injectivity in the well. If insufficient injectivity exists after the FCO/acid wash, the perfs will be reshot with CT on location. For questions or comments: Contact Office Cellular Home Matt Brown 907 564-5874 907 223-7072 907 344-1130 Paulina Meixueiro 907 564-5971 cc: w/a: Well File 13-21A Service CT Well Work Program Job Summary: 1. FCO to TD (12950') 2. Acid wash perfs 3. Injectivity test below frac gradient 4. Pending work: a. If injection rate following the acid job'is less than 4 bpm at 2000 psi (5760 bpd) refperforate 12750-12810 (60') and 12860-12905 (45'). Rperf will be done with CT unit. JOB PLANNING DETAILS Slope PE should communicate with APE prior to the job to review program. Slope PE should communicate with APE in the event problems are encountered or if scope changes are necessary based on well conditions. Well Status New Well currently Shut in Perforations: 105' shot in 2-7/8" liner Perf Deviation: 60 deg Schematic Note: Schematic diagram is misleading- deployment sleeve (12125') is actually right below 5-1/2 Sliding sleeve (12123'). Schematic diagram shows deployment sleeve/liner down in 4-1/2" tub. Schematic depths are correct. Coil Work Mill cement/FCO History Wellbore top Volumes Tubing MD bot MD Size ID bbl/ft ft vol, bbls 5-1/2"tub 0 12123 4-1/2"12.6# 3.958 0.0152 12123 184.5 4-1/2"tub 184.48 Casing 3-1/2"liner 12123 12557 3-1/2"9.2# 2.992 0.0087 434 3.8 3-3/16"liner 12557 12655 3-3/16"6.2# 2.8 0.0076 98 0.7 2-7/8"liner to perfs 12655 12750 2-7/8"6.5# 2.441 0.0058 95 0.5 2-7/8"liner across perfs 12750 12905 2-7/8"6.5# 2.441 0.0058 155 0.9 2-7/8"liner rathole 12905 12948 2-7/8"6.5# 2.441 0.0058 43 0.2 6.2 Total 190.7 CT x Tub inside outside bbl/ft ft vol Annular 1-3/4"1.91# 5-1/2"17# 0.0203 12125 245.8 Volumes- CT at 1-3/4"1.91# 3-1/2"9.2# 0.0057 432 2.5 12650' 1-3/4"1.91# 3-3/16"6.2# 0.0046 93 0.4 249 PRELIMINARY WORK 1. Grease and service the tree if not done recently 2. Perform job with diesel and slickwater. FCO/Fluff-n-Stuff 3. RIH with 2.25" JSN to top of liner at 12125' MD making weight checks as appropriate. Take returns up backside as needed to keep WHP <500 psi. 4. Line out well to tanks and start pumping slickwater at max CT pres down the coil, taking returns up backside. 5. Jet across perforations with slickwater to -12950' MD. If still getting returns, circulate_„ bottoms up. Vol of CT x Tub annulus from 12650=249 bbls. a. If losing more than 50% returns, PUH to above perfs, shut in choke, and SD pumping. Swap to pumping Slickwater down backside. Push fluids into formation. Max WHP is 2000 psi. b. Once CT x Tub annulus vol has been pushed away, swap to pumping down CT. 6. RIH to -12950' jetting with backside SI. Max WHP is 2000. 7. PUH to 12650'. SD pump. 8. Pump acid job down CT per schedule below while reciprocating across perfs (12750'- 12905') with returns SI. a. 20 bbls 1% KCI preflush b. 10 bbls 12% HCI DAD acid c. 20 bbls 1% KCI overflush 9. After acid is flushed away, perform injectivity test as follows: a. Line up to pump down backside. b. Pump 1% KCI down backside at max WHP of 2000. Establish stable injection rate & pressure. c. SD pumps. POOH. d. FP top 2500' of well with 60/40. 10. RDMO if no reperfs are necessary. CONTINGENCY REPERF-to be performed if stabilized injection rate is less than bpm at 2000 psi ( bpd). Note: Contact the Pad Engineer Paulina Meixueiro at 564-5971 (907-306- 6173 cell) before reperforating 11. Discuss results of injectivity test with Pad Engineer. 12. Reperforate 12750-12810 and 12860-12905 MD per perforating form. Tie in log is SLB Memory Correlation Log GR/CCL 31-Aug-2010 13. RDMO. DAD Acid System 12% 90:10 DAD Acid 8.0 ppt A153 Inhibitor Aid 4.0 ppt A179 Inhibitor Aid 0.6 % A261 Inhibitor 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 10% AO26 Xylene 0.5 % W054 Non-Emulsifying Agent • 0.5 % W060 Sludge and Emulsion Preventer 1.5 % U074 Dispersing Agent/Emulsifier PERFORATING PROCEDURE Ver1.2,Rev 10/21/01 Well: 13-21A API#: 50-029-20789-01 Date: 09/30/2010 Prod Engr P Meixueiro Office Ph: 564-5971 I H2S Level: Home Ph: 60ppm 5/29/10 on 13-26 Cost Est: 5100 Cell/Pager: 907-306-6173 C.C.or AFE: AFE:X3-00V5D-C:SPENDI WBL Entries IOR Type Work Desciption 100 C Re-shoot perforations Well Objectives and Perforating Notes: Attachment: Tie-in log with proposed perfs annotated Reference Log Tie in Log Add/Subtract feet Log: NA Memory correlation Log LEE from the tie-in log to be on Date: NA 8/31/2010 depth with the reference log. Company: NA SLB Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Rellperf 12,750' - 12,810' 60 6 60° 12,860' - 12,905' 45 6 60° Requested Gun Size: 2" Charge: PJ Omegas Is Drawdown Necessary/Desired/Unnecessary During Perforating Preferred Amount of DrawdownlSuggestions to Achieve Drawdown Last Tag: 12,948 ft SLM on 9/22/2010 Est Res.Pres.@ 12,769 MD is 3758 psi Perforation Summary Summary Dist Well: 13-21A Town: Date: API#: 50-029-20789-01 Prod Engr: Anch Prod Engr P.D.Center PBTD General Comments: Depths Balance Based on Ref Log Gun Dia. Orient. 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FMC SAFETY NOTES: ACTUATOR• Y 13-21A AC'(UATOR- BAKER C KB.ELEV= 84' BF.ELEV- 7 I [ KOP= 2100' Max Arx,Me= 60 13300 2024' S-t/2'OTIS ROM SSSV NP,0=4.562' Daum Mt1= ,2799 DRLG DRAFT n^ �w 15-12"ROY OSSSV(072608) � Daum TVD= 880nss 1 13-018"CSG,72*,L-80,ID=12.347' H 2513' Minimum ID= 2.37"@ 12655' ---- m 1 12123' H5-112"©TISXA SLDt�4G SLV 3-3/16"X 2-718" XO 12184' I—I5-1'2'BOTPBRASSY I � 12046' ELM D:9 58"X 5-12"BOT PKR W1 r MOE I (ELMD: 5-12"TBG-PC,171,L-80,LT&C8RD AB 12056' 1 MOD.R.0.0232 Opt,0=4.892 1 -- I 12060' HELM D:5-12"X 4-112'XO I I 12125' H3-12"DEPLOYMENT SLV,D=3.00" I IELM D:4-1/t'TBG-FC,12-6&.N-80, --I 12168' f I 12154' ELMD:4-12"OT1S6 1 NIP, BTC,OAt52 bpi,ID=3.958' y �IMILLED TO3.BfY(06117h0) I 4 I 1 21 66' HELM D:4.1'2"SHEAROUT SUB I II •-r' �Oi.�.� I 12168' HELMDTT Loose)1:&85(^on) I ITOPOF7'LNRwmd logged 11!23 1 H 12243' 1••4 044!4 '• 004 1 9-518"CSG,475,L-80&sa0- ,. � 12546' �4 114:4 ID=8.681"Mind BI-CS •••• 1+••4 :•i ii 12557' 3-1,�X �s16"XO 13-U2°LNR,9.21,L-80 STL,.00e7 bpA,b=2.992" 12557' ■••4 1.4.4 � � ' 1• 0•4 14 1:2"x 7'whps oc• I--� 12565' I '•44 ,•,5�, ►ALLOUT WP400W 113-21A) 12570'-12578' r LNR,2944,1.-80,.0371 topf,D=6.184" I•--{ 12 56 5' I ~•1#0 •4�'4• •'••4`�, ,••. •,'•■ %, 12655' 3-3'16"X2-718"XO ID=2.37" 13-3116"LNR,6.26,L-80 TCI,.0076 bpt.0=2.80" 12655' •4.:. 940. ••♦ • ,0.4I. ,0 PERFORATION SUMMARY '�•••4�41 ' •4∎' REF LOG SLB MEM GRCCL ON 8/31110 ,`• 4. ANGLE AT TOPF :60' 12750 44`�•1.4 PBTD 1296$' I Nate:Refer to Roducton DB fn ir`atmical peA data , S&ZE SPF INTERVAL DATE •,• 2 6 12750-12810 0 C&31;13 ' 4 .4'•04` ,44, 2 6 12060-12905 0 331.1? 4�„ ".+4. •i. o ' 60 I2-7'8"LNR,6.16*,L-80 STL,.3058 tpf,ID=2.4.41'H 13008' DATE RBI BY C06& 1tS 1 DATE REV BY 1 COMMENTS PRLDHOE BAY UNIT 01125183 ORIGINAL COM PLETION WELL: 13-21A 09/01110 NORIfl1C2 CT SIDETRACK 413-21AI PERMIT No:12100600 09,06/10 SV DRLG HO CORRECTIONS API No: 50-029-20789-01 SEC 14,TON.R14E 1898.51 Fe.30952 Ft4L 13-21A Service Coil FCO 7 of 7 1., STUE OT ALASEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-21A BP Exploration (Alaska), Inc, Permit No: 210-060 (revised) Surface Location: 2523' FSL, 106' FEL, SEC. 14, T1ON, R14E, UM Bottomhole Location: 2084' FSL, 2915' FWL, SEC. 18, T1ON, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and condi 'in of this permit may result in the revocation or suspension of the permit. i fr; ► . Nor an . is Toner DATED this ay of July, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASK 'L AND GAS CONSERVATION COMMIS N P..?S-A2 JUL 2 3 2010 PERMIT TO DRILL —`-_____„ 20 AAC 25.005 7/20/10 REVISED: Change BHL 1 a.Type of work:AIaSk8 CRAWRIMMRSSITDevelopment Oil ❑Service-Winj ❑Single Zone ❑ Drill 0 Redrill Delleragethic Test ❑Development Gas ❑Service-Supply ❑Multiple Zone ❑Coalbed Gas ❑Gas Hydrates ❑ Re-Entry ❑ Exploratory ®Service-WAG ❑Service-Disp ❑Shale Gas 2. Operator Name: 5.Bond: 0 Blanket ❑Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 PBU 13-21A 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 13146' TVD 8975'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028315&028330 2523'FSL, 106'FEL, SEC. 14,T1ON, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2269'FSL,2580'FWL,SEC. 18,T1ON, R15E, UM June 28,2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2084'FSL,2915'FWL, SEC. 18,T1ON, R15E, UM 2560 11,220' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 84' feet 15.Distance to Nearest Well Open Surface: x- 687095 y-5932587 Zone- ASP4 GL Elevation above MSL: 45.53' feet to Same Pool: 151' 16.Deviated Wells: Kickoff Depth: 12579 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 60 degrees Downhole: 3300 Surface: 2420 18. Casing P rogram: _ Specifications Top-Setting D epth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 4-1/8" -3-1/2"x 3-3/16" 9.2#/6.2# L-80 STL 1046' 12100' 8391'ss 13146' 8975'ss 92 sx Class'G' x 2-7/8" /6.4# , 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 13420' 9212' None 13323' 916.4' 13309' Casing Length Size Cement Volume MD ND Conductor/Structural 75' 20" .360 sx Arcticset I I 75' 75' Surface 2513' 13-3/8" 2500 sx Fondu.400 sx Permafrost'C' 2513' 2483' Intermediate 12579' . 9-5/8" 500 sx Class'G'. 300 sx Permafrost'C' 12579' 8766' Production Liner 1109' 7" 350 sx Class'G' 12295'- 13404' 8596'-9204' Perforation Depth MD(ft): 12559'-13084' Perforation Depth ND(ft): 8754'-9043' 20.Attachments: ❑ Property Plat 0 BOP Sketch 0 Drilling Program ❑Time vs Depth Plot ❑Shallow Hazard Analysis ❑Diverter Sketch ❑Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the/l e•• r! is true -nd correct. Contact Amanda Suddreth,564-5543 Printed Name Jo• IL:j' Title Engineering Team Leader / Prepared By Name/Number Signature �/ Phone 564-4711 Date 1 1 1 16 Terrie Hubble,564-4628 Commission Use Only Permit To • ill API Number: Permit a D te:S/ See cover letter for Number: 210-060 50-029-20789-01-00 I() other requirements Conditions of Approval: If box is checqfp ed,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: Q' Other: '4 35M ri' is -- — Samples Req'd: ❑Yes ErNo Mud Log Req'd: ❑Yes E"I'lo i-2 5e:6/2 3G / �l 1 c S + h`'`I)H2S Measures: "Yes ❑No Directional Survey Req'd: Yes ❑No W l--ice,44, v ia� :o L ,. nr c�rte+' c.�� l U y �E- MIT i�'e.s��c���� p D 0 APPROVED BY THE COMMISSION Date ( ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the •: _ • ap• oval( • AAC 2 .•,- • ) Submit In Duplicate ORIG1AL 7o6,-/za/o Vi�4- /1�7 13-21A - Coiled Tubing Dr. ig To: Alaska Oil & Gas Conservation Commission From: Amanda Suddreth bp CTD Engineer Date: July 15, 2010 Re: 13-21A Permit to Drill Application Coil Tubing Sidetrack: Drill and Complete Summary Pre-Rig Work: (scheduled to begin May 1, 2010) 1. S Caliper tubing from 13,036' (DONE 11/23/2009) 2. S Drift well and tag top of fill (DONE 11/23/2009) 3. 0 MIT-IA to 3000psi (PASS 5/14/2010) 4. 0 MIT-OA to 2000psi (FAIL 5/14/2010) 5. 0 PPOT-T, function LDS (DONE 6/12/2010) 6. S Drift well with dummy whipstock (DONE 5/25/2010) 7. E RIH w/through-tubing whipstock (4.5"x 7"); set TOWS @ 12,558'MD (DONE 6/6/2010) 8. C Squeeze cement past whipstock to isolate perforations (DONE 6/16/2010) 9. C Mill out XN Nipple @ 12,154' (ELMD) (DONE 6/20/2010) 10. C Freeze protect well and thoroughly wash the tree (DONE 6/27/2010) 11. 0 Post-cement job MIT-T to 1000psi for 30 minutes (PASSED 6/22/2010) 12. E Re-gyro wellbore (DONE 7/6/2010) 13. 0 Bleed wellhead pressures down to zero 14. 0 O Bleed production flow lines and GL lines down to zero and blind flange 15. 0 Remove wellhouse, level pad Rig Work: (scheduled to begin on August 8th, 2010) of 1. MIRU Nordic Rig 2 2. NU 7-1/16" BOPE;test to 250 psi low and 3500 psi high. 3. Mill 3.8"window at 12,558'and 10' of rathole. Swap the well to Power-VIS. 4. Drill Build/Lateral: 4.125"OH, 587' (12 deg/100 planned) with resistivity 5. Run 3-1/2"x 3-3/16 x 2-7/8" solid L-80 liner leaving TOL at 12,100' 6. Pump primary cement leaving TOC at 12,100', 19 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNUGR/CCL log 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions (-150') 10. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's 7/16/2010 13-21A — Coiled Tubing Dr. ,g Mud Program: • Well kill: 8.6 ppg seawater/brine • Milling/drilling: 8.6 ppg Geo-vis or biozan for milling, new Geo-vis for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.25", 12,558'-13,145' Casing Program: • 3-1/2" 9.2#, L-80, STL solid liner 12,100' MD— 12,535' MD • 3-3/16" 6.2#, L-80, STL solid liner 12,535' MD—12,785' MD • 2-7/8" 6.4#, L-80, STL solid liner 12,785' MD— 13,145; MD • A minimum of 19 bbls of 15.8 ppg cement will be to cement the solid liner(TOC at 12,100'; TOC =TOL). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 2,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 60 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line— 11,220'to the South • Distance to nearest well within pool—151' (13-21, original weilbore) Anticollision Summary • No anti-collision issues Logging • MWD directional, GR and Resistivity will be run over all of the open hole section. • A cased hole GR/CCL/CNL log will be run. Hazards • DS13 is considered a high H2S pad. The maximum recorded H2S level on Drill Site 13 is 300 ppm on well 13-02A (9/24/1994). Be aware and take proper precautions when working around high-risk H25 sites. • Lost circulation risk is moderate. The directional plan will avoid the regional fault that is currently taking 100% injection from 13-21. If losses are encountered (fault is crossed),the wellplan and/or completion strategy(cementing requirements) will be reconsidered. Reservoir Pressure • Reservoir pressure is estimated to be 3,300 psi at 8,800'TVDss (7.2 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft) to surface is 2,420 psi. Amanda Suddreth CTD Engineer 7/16/2010 13-21A — Coiled Tubing Dr, ,g TREE= FMC SAFETY NOTES: J WELLHEAD= GRAY 13-21 - ACTUATOR= BAKER C KB.ELEV= 84' BF.ELEV= ? KOP= 2100' Max Angle= 60 13300' t 2024' I--5-1/2°OTIS RQM SSSV NIP,ID=4.562" Datum MD= 12784' w/5-1/2"RQY DSSSV(07/26/08) Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,ID=12.347" H 2513' I--4 I Minimum ID = 3.725" @ 12308' I I I I 1 12123' H5-1/2"OTIS XA SLIDING SLV I 4-1/2" OTIS XN NIPPLE ` I 12184' H5-1/2"BOTPBRASSYI Z Z l —9-5/8"X 5-1/2"BOT PKR 5-1/2"TBG-PC,17#,L-80,LT&C 8RD AB MOD, 12204 WITH 7"MOE IPC,0.0232 bpf,ID=4.892" 12215' \ / 12215' I-15-1/2"X 4-1/2"xo I TOP OF 4-1/2"TBG-PC —1 12215' I 4-1/2"TBG-PC,12.6#,N-80, 12320' I 11 12308' H4-1/2"OTIS XN NIP,ID=3.725" I BTC,0.0152 bpf,ID=3.958" - / 12162' H ELMD TT LOGGED 1/6/85 I TOP OF 7"LNR elmd logged 11/23/09 H 12235' I—vi 9-5/8"CSG,47#,L-80&S00-95, — 12546' ID=8.681"elmd BHCS I PERFORATION SUMMARY REF LOG:BHCS ON 05/18/82 ANGLE AT TOP PERF:54 @ 12559' Note:Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12559-12590 0 12/27/91 I 3-3/8" 4 12720-12738 0 12/20/85 3-3/8" 4 12744-12764 0 12/20/85 3-3/8" 4 12774-12784 0 12/20/85 I 3-3/8" 4 12796-12806 0 12/20/85 3-3/8" 4 12815-12835 0 12/20/85 3-3/8" 4 12846-12866 0 12/20/85 I 3-1/8" 4 12882-12922 0 04/20/83 3-1/8" 4 12928-12958 0 04/20/83 3-1/8" 4 12974-13004 0 04/20/83 3-1/8" 4 13028-13048 0 11/18/82 3-1/8" 3 13064-13084 0 11/18/82 . 13309' H FISH-20'MAGNETIC DECBdTRALIZER I MID 13360' feee f f•T 7"LNR,29#,L-80,.0371 bpf,ID=6.184" 13404' /••••••••••••••••: TD 13420' .0.0.0.0.• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/25/83 ORIGINAL COMPLETION 08/05/08 RWJ/PJC TREE REPLACEMENT(07/29/08) WELL: 13-21 01/03/01 SIS-SLT CONVERTED TO CANVAS 12/11/09 MSE DRLG CORRECTIONS PERMIT No: 82-053 01/30/01 SIS-LG REVISION API No: 50-029-20789-00 10/27/01 RN/TP CORRECTIONS SEC 14,TION,R14E 1898.51 FEL 3095.2 FNL 08/05/08 BSE/JPJC SET DSSSV(07/26/08) BP Exploration(Alaska) 7/16/2010 13-21A - Coiled Tubing Dr. ,g TREE= FMC 13-21 A i SAFETY NOTES: WELLI•£AD= GRAY ACTUATOR= BAKER C Pronnsed CTD Sidetrack KB.ELEV= 84' BF.ELEV= ? KOP= 2100 Max Angle= 60 d 13 300 O I 2024' 15-1/5.2",.OT 5 RO RY O M DS SSSSSV V(N07P/.2 6D/0=8 4).567 Datum MD= 12784' Datum TVD- 8800'SSl 13.318'CSG.72#.L 80.ID=12.347' - 2513' Minimum ID = 2.3" 121U, I 12123' H5 112'OTIS Xn SLUNG SLV I �)L 3-1/2" I 12184' H5-1/r BOT FBRASSY 12046e -9.5/8X51/7 BOT PKR 5-1/2'TBGPC,17#,L-80,LTSCBRD AB MOD, WCf}17'MOE IFC,0.0232 bpf,D-4.892' 12056e 1 H5-1n'x4•1rz'xOI • 500 I 12100e I I =2.99' I 121540 �4 1rz'OTI5 XN NP,D cNUed to 3.80' a-t/r TsG PC 12.6#,N•80, - 12168e 12166e �4.1i2'SHEAROUT SUB JTC,0.0152 bpf,D=3.958' I F-IELM)TT LOGGED :,/85(corn) I roP OF 7-LNRelmd logged 11/23'Ci -I 12243' ljp . 13.1/7 LNR,92#.L-.0 STL,.0087 bpf,D•2.99" I L 12554' I 9-58'CS°,47#,L-80&S00-95, - D=8.881'elmdBHCS 12546' ' I 12528' H3-1/2'X 3.3/16"XO 14 1/2.x 7'whpstock 1?558' I3-3/16'LNR 6.2#.L-80 XI,.0078 bpf,D.2.80" H 12647' I 54 \\ lH33/1X2.7 .2647. X0 PERFORATION SUMMARY REF LOG:BHCS ON 05/18+82 A T ANGLE TOP FERF:54 @ 12559• Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz CATE %,% IF13TDH I 4. rA . wore '4 4 4 4 4,4 4 4 4 4'4.0 I LNR,6.4#,L.Bp STL,.0058 bpf,ID=2.44' H 13145' 7'LNR 29#.L-80..0371 Opt D'6.184" - 13404' 111441444141••••■ DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHDEBAY UNIT 01./25/8 3 ORIGINAL COMPLETION 08/05/08 RWJiPJC TREE REPLACBIENT(07;29/08) 'NELL: 1121 01/03/01 SIS-SLT CONVERTED TO CANVAS 12/16+09 MSE PROPOSED CID SCETRACK FERMTNo: 01/30/01 SIS-LG REVISION API No: 50.029.20789.0 10/27/01 RNTTP CORRECTIONS SEC 14.TION R14E 1898.51 FEL 3095.2 FNL 08/05/08 BSE/JPJC SETDSSSV(07.+26/08) BP Exploration(Alaska) 7/16/2010 a ID 0 a. co 1 co t Q 0 J 0' Q 0 w I co c') ✓ c •_ ■- i C = E H • >. 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" ! § ¥ 9 ! § 7 a § f 9 f e f ^ ! { 0 , , , , , , (q cz)( oJ(q no ` ` a o oo co BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 13 13-21 Plan 7, 13-21A Plan 7 Travelling Cylinder Report 15 July, 2010 X10.'00 sR■ BPPASSPORT h HUGHES Travelling Cylinder Report U I) 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 13-21 -Slot 21 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB DS 13 MD Reference: 35:21 4/25/1982 00:00 @ 84.00ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: 13-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 7, 13-21A Database: EDM.16-Anc Prod-WH24P Reference Design: Plan 7 Offset TVD Reference: Offset Datum Reference Plan 7 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 12,500.00 to 13,145.50ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,510.75ft Error Surface: Elliptical Conic Survey Tool Program Date 7/15/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 12,414.20 GyroData(13-21) GYD-CT-CMS Gyrodata cont.casing m/s 12,500.00 12,500.00 1 :Sperry-Sun BOSS gyro multi(13-21) BOSS-GYRO Sperry-Sun BOSS gyro multishot 12,500.00 13,145.50 Plan 7(Plan 7, 13-21A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 13,145.50 8,974.74 3 3/16" 3.188 4.250 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB DS 12 12-09-12-09-12-09 Out of range PB DS 13 13-03-13-03A-13-03A Out of range 13-20_DIMS-13-20-13-20 Out of range 13-21 -13-21 -13-21 12,575.00 12,575.00 0.20 2.23 -1.24 FAIL-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 7/15/2010 10:34:03AM Page 2 of 4 COMPASS 2003.16 Build 71 13-21A — Coiled Tubing Dr. .ig All Measurements are from top of Riser 5'3.'2x10 p (!) 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CE U U ° o o p c — Z p E 3 a> o a) L m 3 w 0 a_ Q p 7 a @ @ L m N a) L L L m m 7 N -° m i C a) N 2 '- L m Oa N Oa a 3 0 'C O T 3 m E o z o C c N _CO -° n a m 3 3 0 Q) a) a o .� °: 3 m CI m C) c a m m ° 3 o r Z ° w U O Q •� 'DC E a > 3 N •o• "O "O >O (0 E o c .2 N O O c 6 o V '°O N N n o ° C "O N 0 Q. 0 m a) m 0 0 p _ ° o N E p E L 0 ° CO N c H ° a p v N N 0 12 N 7 7 a c c O° a o ,D Q) - O a) N 'O N E m O - 7 CO C t ot$ Q L m Oa Oa m N Q U N a L •- N m a m m (0 m m a) `° ) o) C U 3 N 'p co N a U E (6 3 (0 m m C m C 7 7 N CO _0 O T -O = C .N - .N O a N Q N C a a d u) T N 3 L ° °1 ` N N > C L Q a N ° U O OU d >. N LL a- a) E a) N N 1U6 .0 0 .0 C C '-' aai 0 • N N -0 -p O 'N -6 - 3 N ._ 0 u) C O ° m C CO c C C E {+a, x 7. m m (6 a) m m E m 3 7 N o 0 m m 0 O W _ a) 2 -0 2 m = C U m N m °U c �5lrJ w c a) 0 0 0 .p m ° ° •0 0 m o ci' ° 0 W ° °> 3 m m -° m t m N a m 3 C. m ° a — CD 0 m Eup Q — — — ° a>> <` m E a — ° n 0 o m F F F o o > c d - - ° c E y . m .i a) 0 'C a a) a) = a 0a n a) n) m ° 3 m o o c 2 2 2 m -o m -o f = 0 0 0 0 ° Cl) a) co .° a) o m co_ _I n � � � (n o o a LL U � Q a_ z U u) o o o o a a O m coo A g a ° (n co o 0 W Err m a O N M V 1O O r W m O N M V l() (0 1� W m cc o' M V 1f) (0 I� W m = p - N M V 1f) (o r W m N N N N N N N N N N (`•) (`•) C) C) M M C) M M C) V U o 0 0 Cl) o W o d o ° O c (6 N 10 N 16 N U O (p 0 N N N O N a O 1112 r c r r 0. a)- N ° >` 0 E W- O •E `0.. c0 0) `0.. -1 0 `ca. C0 0 m? ala a Q LU a a s SIATE o SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMIIHSSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13-21A BP Exploration (Alaska), Inc, Permit No: 210-060 Surface Location: 2523' FSL, 106' FEL, SEC. 14, T1ON, R14E, UM Bottomhole Location: 1779' FSL, 2575' FWL, SEC. 18, T1ON, R15E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. AO �J,011r ''orman Co ,mi .ioner DATED this 74 day of May, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ,I STATE OF ALASKA RECEIVED ALAS' )IL AND GAS CONSERVATION COMM' ON ./i� PERMIT TO DRILL MAY 1 0 20105VAA9 20 AAC 25.005 la.Type of work: lb.Proposed Well Class: ❑Development Oil ❑Service-Willi ❑Single Zone liAllakftiGOBICOSQUIONO ❑ Drill ®Redrill ❑ Stratigraphic Test ❑Development Gas ❑Service-Supply ❑Multiple Zone ❑ Coalbed,htas Hydrates ❑ Re-Entry ❑ Exploratory 0 Service-WAG ❑Service-Disp ❑Shale Gas 2. Operator Name: 5.Bond: ® Blanket ❑Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 PBU 13-21A 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 13242' ND 8969'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028315&028330 2523'FSL, 106'FEL, SEC. 14,T10N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 2269'FSL,2580'FWL, SEC. 18,T10N,R15E, UM June 28,2010 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1779'FSL,2575'FWL, SEC. 18,T10N, R15E, UM 2560 11,095' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 84' feet 15.Distance to Nearest Well Open Surface: x- 687095 y-5932587 Zone- ASP4 GL Elevation above MSL: 45.53' feet to Same Pool: 151' 16.Deviated Wells: Kickoff Depth: 12600 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 65 degrees Downhole: 3300 Surface: 2420 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 4-1/8" 3-1/2"x 3-3/16" 9.2#/6.2# L-80 STL 1140' 12100' 8391'ss 13240' 8968'ss 97 sx Class'G' x 2-7/8" /6.4# 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 13420' 9212' None 13323' 9164' 13309' Casing Length Size Cement Volume MD ND Conductor/Structural 75' 20" 360 sx Arcticset II 75' 75' Surface 2513' 13-3/8" 2500 sx Fondu.400 sx Permafrost'C' 2513' 2483' ' Intermediate 12579' 9-5/8" 500 sx Class'G'. 300 sx Permafrost'C' 12579' 8766' • Production Liner 1109' 7" 350 sx Class'G' 12295'- 13404' 8596'-9204' Perforation Depth MD(ft): 12559'-13084' Perforation Depth ND(ft): 8754'-9043' 20.Attachments: ❑ Property Plat 0 BOP Sketch ®Drilling Program ❑Time vs Depth Plot ❑Shallow Hazard Analysis ❑ Diverter Sketch ❑Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Amanda Suddreth,564-5543 Printed Name ,J. c ;yr Title Engineering Team Leader A Prepared By Name/Number. Signature.--" ,/ / Phone 564-4711 Date ? /d Teme Hubble,564-4628 e Commission Use Only Permit To Drill API Number: Permit rgval Date See cover letter for Number,/,=„7/04e76. ? 50-029-20789-01-00 � h(,PI) C) other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained shales: (f Other: * 35610 p 5.4-' a"'' 1 uT Samples Req'd: Oyes NNo Mud Log Req'd: ❑Yes a No 2pre:, Ahn 44,...ti 'T —Cs..:.,) H2S Measures: Ye • No Directinal Survey Req'd: 'Yes ❑No - Le(4-itx.,.f&- 0.10..gI`�+ ` c.�, Gi.CC c,rat ,/ 4/ -* Mir C Q.1 "'0�. I APPROVED BY THE COMMISSION Date 6=2 4.-/6 ' ,COMMISSIONER Form 10-401 Revised 07/2009 This permit is valid for 24 months from the .. o :pprova 0 AAC .005(g)) Submit In Duplicate ORIGLA A Cie- b 49AI° 13-21A - Coiled Tubing Drilling To: Alaska Oil & Gas Conservation Commission From: Amanda Suddreth bP CTD Engineer Date: April 25, 2010 Re: 13-21A Permit to Drill Application Coil Tubing Sidetrack: Drill and Complete Summary Pre-Rig Work: (scheduled to begin May 1, 2010) 1. S Caliper tubing from 13,036' (DONE on 11/23/2009) 2. S Drift well and tag top of fill (DONE on 11/23/2009) 3. 0 MIT-IA to 3000psi 4. 0 MIT-OA to 2000psi 5. 0 PPOT-T, function LDS 6. S Drift well with dummy whipstock 7. E RIH w/through-tubing whipstock(4.5"x 7"); set BOWS @ 12,590'MD 8. C Squeeze cement past whipstock to isolate perforations 9. C Mill out XN Nipple @ 12,154' (ELMD) 10. C Freeze protect well and thoroughly wash the tree 11. 0 Post-cement job MIT-T to 1000psi for 30 minutes 12. 0 Bleed wellhead pressures down to zero 13. 0 Bleed production flow lines and GL lines down to zero and blind flange 14. 0 Remove wellhouse, level pad ( Rig Work: (scheduled to begin on June 28th, 2010) 1. MIRU Nordic Rig 2 2. NU 7-1/16" BOPE; test to 250 psi low and 3500 psi high. 3. Mill 3.8"window at 12,585' and 10' of rathole. Swap the well to Geo-VIS. 4. Drill Build: 4.25"OH, 200' (35 deg/100 planned)with resistivity 5. Drill Lateral: 4.25"OH, 457' (12 deg/100 planned) with resistivity 6. Run 3-1/2"x 3-3/16 x 2-7/8"solid L-80 liner leaving TOL at 12,100' V 7. Pump primary cement leaving TOC at 12,100', 21 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNUGR/CCL log 1ni5 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (-150') 11. Freeze protect well, RDMO Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Generic GLV's 5/4/2010 13-21A — Coiled Tubing Di wing Mud Program: • Well kill: 8.6 ppg seawater/brine • Milling/drilling: 8.6 ppg Geo-vis or biozan for milling, new Geo-vis for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.25", 12,585'-13,242' Casing Program: • 3-1/2" 9.2#, L-80, STL solid liner 12,100' MD— 12,535' MD • 3-3/16" 6.2#, L-80, STL solid liner 12,535' MD— 12,785' MD • 2-7/8" 6.4#, L-80, STL solid liner 12,785' MD— 13,240; MD • A minimum of 20 bbls of 15.8 ppg cement will be to cement the solid liner(TOC at 12,100';TOC=TOL). Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 2,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 65 deg. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line— 11,095'to the South • Distance to nearest well within pool— 151' (13-21, original weilbore) Anticollision Summary • No anti-collision issues Logging • MWD directional, GR and Resistivity will be run over all of the open hole section. • A cased hole GR/CCUCNL log will be run. Hazards • DS13 is considered a high H2S pad. The maximum recorded H25 level on Drill Site 13 is 300 ppm on well 13-02A(9/24/1994). Be aware and take proper precautions when working around high-risk H2S sites. • Lost circulation risk is moderate. The directional plan will avoid the regional fault that is currently taking 100% injection from 13-21. If losses are encountered (fault is crossed),the weliplan and/or completion strategy(cementing requirements) will be reconsidered. Reservoir Pressure • Reservoir pressure is estimated to be 3,300 psi at 8,800'TVDss (7.2 ppg EMW). Maximum surface pressure with gas (0.10 psi/ft)to surface is 2,420 psi. Amanda Suddreth CTD Engineer 5/4/2010 13-21A — Coiled Tubing Drilling TREE= FMC SAFETY NOTES: WELLHEAD= GRAY 13 21 ACTUATOR= BAKER C KB.B EV= 84' BF.ELEV= ? KOP= 2100' Max Angle= 60 @ 13300' 2024' H 5-1/2"OTIS RQM SSSV NIP,ID=4.562" Datum MD= 12784' w/5-1/2"ROY DSSSV(07/26/08) Datum TV D= 8800'SS 13-3/8"CSG,72#,L-80,ID=12.347° H 2513' Minimum ID= 3°725" @ 12308' I I 12123' 1-I5-1/2"OTIS XA SLIDING SLV 4-1/2"OTISXN NIPPLE 12184' H5-1/2"BOT PBR ASSY I . . 12204' —9-5/8"X 5-1/2"BOT PKR 5-1/2"TBG-PC,17#,L-80,LT&C8RDAB MOD, — 12215 WITH 7'MOE IPC,0.0232 bpf,ID=4.892" ■I / I 12215' I-15-1/2"X 4-1/2"XO I TOP OF 4-1/2'TBG-PC I-{ 12215' 4-1/2"TBG-PC,12.6#,N-80, — 12320' I I I 12308' I-14-1/2"OTIS XN NIP,ID=3.725" I BTC,0.0152 bpf,ID=3.958" / \ I 12162' HELMDTT LOGGED 1/6/85 I TOP OF 7'LNR elmd logged 11/23/09 H 12235' 9-5/8"CSG,47#,L-80&S00-95, -- 12546' ID=8.681'elmd BHCS PERFORATION SUMMARY I REF LOG:BHCS ON 05/18/82 ANGLE AT TOP PERF:54 @ 12559' Note:Refer to Production DB for historical perf data I _SCE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12559-12590 0 12/27/91 3-3/8" 4 12720-12738 0 12/20/85 I 3-3/8" 4 12744-12764 0 12/20/85 3-3/8" 4 12774-12784 0 12/20/85 3-3/8" 4 12796-12806 0 12/20/85 I 3-3/8" 4 12815-12835 0 12/20/85 3-3/8" 4 12846-12866 0 12/20/85 3-1/8" 4 12882-12922 0 04/20/83 I 3-1/8" 4 12928-12958 0 04/20/83 3-1/8' 4 12974-13004 0 04/20/83 3-1/8" 4 13028-13048 0 11/18/82 3-1/8" 3 13064-13084 0 11/18/82 13309' H FISH-20'MAGNETIC DECENTRALCER 1 PBTD 13360' feef fe•ve4 1•1•••••••1•1••t 7"LNR,29#,L-80,.0371 bpf,ID=6.184" 13404' 1.0400 • **MOO TD 13420' .0.0.0.0 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/25/83 ORIGINAL COMPLETION 08/05/08 RWJ/PJC TREE REPLACEMENT(07/29/08) WELL: 13-21 01/03/01 SIS-SLT CONVERTED TO CANVAS 12/11/09 MSE DRLG CORRECTIONS PERMIT No: 82-053 01/30/01 S IS-LG REV ISION API No: 50-029-20789-00 10/27/01 RN/TP °CORRECTIONS SEC 14,TION,R14E 1898.51 FEL 3095.2 FNL 08/05/08_BSE/JPJC_SET DSSSV(07/26/08) BP Exploration(Alaska) 5/4/2010 13-21A — Coiled Tubing Drilling TREE= FMC 1 3 21 A i SAFETY NOTES: WELLHEAD= GRAY ACTUATOR= BAKER C Proposed CTD Sidetrack KB.ELEV= 84' BF.ELEV= ? KOP= 2100' I 2024' H5-1/2'OTIS ROMSSSV NIP,ID=4.562' Max Angle= 60 @ 13300' ® w/5-1/2'ROY DSSSV(07/26/08) Datum MD= 12784' Datum ND= 8800'SS 113-3/8'CSG,72#,L-80,ID=12.347" H 2513' Minimum ID= 2.3" @ 12100' I I t 12123' H5-1/2'OTIS XA SLIDING SLV I TOL 3-1/2" JI 12184' H5-1/2'BOT PBR ASSY I 12046e I-19-5/8"X 5-1/2'BOT PKR 5-1/2'TBG-PC,17#,L-80,LT&C 8RD AB MOD, — I I WITH 7"MOE IPC,0.0232 bpf,ID=4.892" 12056e 12060e H5-1/2"X 4-1/2"XO I 50 121e H113-112'1:=297 II 1 12154e H4-1/2"OTIS XN NIP,ID milled to 3.80"" 4-1/2'TBG PC,12.6#,N-80, —N 12168e 12166e H4-1/2'SHEA ROUT SUB I BTC,0.0152 bpf,ID=3.958' I I 12168' H ELMD TT LOGGED 1/6/85(corr) I I TOP OF 7"LNR elmd logged 11/23/09 H 12243' -I I3-1/2'LNR,9.2#,L-80 STL,.0087 bpf,O=2.99' H 12535' I 9-5/8'CSG,47#,L-80&S00-95, — 12546' ID=8.681"elmd BHCS I 12535' H3-1/2"X 3-3/16"XO I4 1/2"x 7'whipstock j--I 12585' I I I3-3116"LNR,6.2#,L-80 TCN,.0076 bpf,ID=2.80" H 12785' I 54 12785' H3-3/16"X 2-7/8"XO PERFORATION SUMMARY REF LOG:BHCS ON 05/18/82 ANGLE AT TOP PERF:54 @ 12559' Note:Refer to Production DB for historical pert data SEE SPF INTERVAL Opn/Sqz DATE ,4` PBTD ?? 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N e t` O .8 7 .o g . 53 0 9, N N C T q q b 8 obi P F O — _ (ui/J OL)(+)41.oN/(-)4;nos �. ei' BPPASSPORT BAKER Travelling Cylinder Report 0 bp HUGHES Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 13-21 -Slot 21 Project: Prudhoe Bay TVD Reference: 35:21 4/25/1982 00:00 @ 84.00ft(generic drilling rig) Reference Site: PB DS 13 MD Reference: 35:21 4/25/1982 00:00 @ 84.00ft(generic drilling rig) Site Error: 0.00ft North Reference: True Reference Well: 13-21 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan 4, 13-21A Database: EDM.16-Anc Prod-WH24P Reference Design: Plan 4 Offset TVD Reference: Offset Datum Reference Plan 4 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 12,500.00 to 13,242.13ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,520.41ft Error Surface: Elliptical Conic Survey Tool Program Date 1/15/2010 From To (ft) (ft) Survey(Wellbore) Tool Name Description 100.00 12,500.00 1 :Sperry-Sun BOSS gyro multi(13-21) BOSS-GYRO Sperry-Sun BOSS gyro multishot 12,500.00 13,242.13 Plan 4(Plan 4, 13-21A) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 13,242.13 9,053.00 3 3/16" 3.188 4.250 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB DS 12 12-09-12-09-12-09 13,242.13 9,200.00 1,304.73 973.53 563.35 Pass-Major Risk PB DS 13 13-21 -13-21 -13-21 12,671.73 12,675.00 14.71 53.24 -25.62 FAIL-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/15/2010 10:29:52AM Page 2 of 5 COMPASS 2003.16 Build 71 13-21A — Coiled Tubing Drilling All Measurements are from top of Riser 512010 ■•■•■ (1) CO CC 13-21A BAG ID:tm )f ciag r :01+of ol r Blind.:Shears TOTs I • 2 18" combi ramslips radile f pips,'sl Mud Cross Mud Cross puddle of flow co 38 I 2 3/8" x 3 -1:•2" VBR's middle of rams TOTs 2 3:8" combi rarnslips I I micklle of pipe,'slips Swab Valve ___ Flow Too 5/4/2010 FW: 13-21A Page 1 of 2 Schwartz, Guy L (DOA) From: Rebol, Amanda [reboa2 @BP.com] Sent: Monday, May 17, 2010 3:23 PM P-rD 1 v-06D To: Schwartz, Guy L (DOA) Subject: FW: 13-21A Guv- See below for the 1/4 mile radius for 13-21A. Let me know if this doesn't quite fit the bill. Thanks! -Amanda From: McTeague,Mike Sent: Monday,May 17,2010 3:12 PM To: Rebol,Amanda Subject: RE: 13-21A Amanda, I think this map should do the trick. The circle is centered on the TD location of the 13-21A and has 1320' radius. The only wells in the Ivishak that are within the circle are 13-21 (parent), 12-04A and 12-09. If you need anything else let me know. Mike McTeague 91).0 F a,F.,' nn F!vci Ar∎nhnrr i■,r d k 09 (15, 5/18/2010 FW: 13-21A Page 2 of 2 ,-1.4.-- *I 0A ,i0A7011- "'P�� 0�►94r ," 101-10 / I )., 0: kl 0b-10 rl* Ni-„ �„,,, ��ff•3`•, -20 —.12*i. -12 _ ,,_ • �`` ~-- i { l 1 _'k: ..y., --etij, '..,;4 , ,• a_ _ fir_/•� •;' rre � = G] _ \ c _41404pt - t illesr7 .. .440 .. .,� =! 2 r '' � X1� _ ! 2 27 `').. ' • in, _ - , ,-,=::, f. `+ _ • is ,.. 1/4 l�40,r..-0-+4-11-w-n-4 1, .-'w . 4 ' . # J r rs-off_ �= ' " r ; --AIM 1 '''''W---..--. ..' . No 'AN � > - 6- _,- '*-:-‘41\ ,,- -14111114‘ W. , 1.1 . �% - , ,, j as '- -,3. 12 8 _ + r 3 f�-. 7 4,',, -7-07 ` --\ 1 -31 �I, �rt ; -,e — .a__.R 12-83 —y `' .,d ,- From: Rebol,Amanda Sent: Friday, May 14,2010 3:55 PM To: McTeague, Mike Cc: guy.schwartz @alask.gov Subject: 13-21A Mike- Was wondering if I could get a map view of the wells within a quarter-mile of 13-21A; basically just need to confirm the status of these wells for the upcoming injector. I spoke with Guy at AOGCC, and he said he's got the East-West view, but I believe that view is missing the nearest wellbore, 12-09. Thank you -Amanda Amanda E Suddreth (Rebol) Drilling Engineer, Coil Tubing Drilling Alaska Drilling &Wells 907.564.5543 720.308.7188 5/18/2010 Alaska Department of Natural Resources Land Administration System Page 1 of/( Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources Alaska DNR Case Summary File Type: ADL File Number: 28330 al Printable Case File Summary See Township,Range, Section and Acreage? New Search 0 Yes 0 No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28330 +'aP_ Search for Status Plat Updates As of 05/11/2010 Customer: 000107377 BP EXPLORATION(ALASKA)1NC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2512.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction:AA-NRB ASSIGNMENT APPROVED Meridian: U Township: O10N Range: 015E Section: 17 Section Acres: 640 Search Plats. Meridian: U Township: O10N Range: 015E Section: 18 Section Acres: 615 Meridian: U Township: 01 ON Range: 015E Section: 19 Section Acres: 617 Meridian: U Township: O10N Range: 015E Section: 20 Section Acres: 640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION*** C14-160 T1ON-R1 5E-UM 17,18,19,20 2512.00 U-3- 7 End of Case Summary Last updated on 05/11/2010. http://dnr.alaska.gov/proj ects/las/Case_Summary.cfm?FileType=ADL&FileNumber=2833... 5/11/2010 Alaska Department of Natural r''sources Land Administration System Page 1 of,2'/ Alaska Mapper Land Records/Status Plats Recorder's Search State Cabins Natural Resources [- - Alaska DNR Case Summary File Type: ADL File Number: 28315 Printable Case File Summary See Township, Range, Section and Acreage? I New Search Yes O No LAS Menu I Case Abstract I Case Detail I Land Abstract File: ADL 28315 map for Status Plat Updates As of 05/11/2010 Customer: 000107377 BP EXPLORATION(ALASKA)INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784. OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location:DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 08/19/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of Primary Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 010N Range: 014E Section: 13 Section Acres: 640 Search Plats Meridian: U Township: 010N Range: 014E Section: 14 Section Acres: 640 Meridian: U Township: 010N Range: 014E Section: 23 Section Acres: 640 Meridian: U Township: 010N Range: 014E Section: 24 Section Acres: 640 Legal Description 05-28-1965 ***SALE NOTICE LEGAL DESCRIPTION *** C14-137 T10N, R14E, UM 13, 14, 23, 24 2560.00 End of Case Summary Last updated on 05/11/2010. http://dnr.alaska.gov/projects/las/C ase_Summary.cfm?FileType=ADL&FileNumber=2831... 5/11/2010 TRANSMITTAL LETTER CHECKLIST WELL NAME 7'& ' PTD# c.2/006C7 Development t/ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: .a.El/D,1-474' !?A/ POOL: ?',47/D,/-,04-_4fly O/Z Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the - original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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E a) is m as a-°�) 0 s m (ca 2 a) 3 7 a) 0 0 m m 0 a) a) E , 5 -°a 2 o ° c 0 m 0 0 0 co•F- W c 3 0 0 0 0 N 0 �O .0 .0 N 0 0 O C 0 0 O O - a (6 D a) ui 0- E '3 a) C .0 2 0 -p U tl1 m . a) = 0 0 0 .� .5 as as . . 0. —° a) n 0 m F F F c a) > m a Ill Y a) 2 '0 m . m 6 -3 a) m .- a) a) a) -o n n a) a) 0 m 3 2 o o o 2 2 2 m -a 0 -oo = O O t o a a) m m 'a) as o as 0 c a _1 D co X 0 0 a a 0 Q a` z 0 cn 0 0 0 0 < � < � 0 co m 0 _) 2 a ° co co 0 ° W O. p N M V lf) (O N- CO O) O N M V (f) O r 00 Cn O N M V (O (0 n CO CA V <- N M V (O (0 (- W O N N N N N N N N N N M M a') C) A C) C) (`•) c`•) (°) ,s' 0 0 0 •• �* a1 O a) O 0 O a) i O c /6 N fa N la N 'I V O aO« c I a) E J N N a a O o c L ., a I Q Q Q w Q C(1) Q 0 0 1. 'Nell History File APPENDIX Infoimation of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simpi(fy finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. tapescan.txt **** REEL HEADER **** MWD 11/01/27 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 10/08/29 3352669 01 3" CTK *** LIS COMMENT RECORD *** 1111111111111111111 Remark File Version 1.000 IIIIIIIIIIIIIIIIIII Extract File: ldwg.las version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information # STRT.FT 12359.0000: Starting Depth STOP.FT 13010.0000: Ending Depth STEP.FT 0. 5000: Level Spacing NULL. -999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska) , Inc. WELL. WELL: 13-21A FLD . FIELD: Prudhoe Bay Unit LOC . LOCATION: 70 deg 13' 13.56"N 148 deg 29' 25.561"w CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 29 Aug 2010 API . API NUMBER: 500292078901 -Parameter Information Block #MNEM.UNIT Value Description # SECT. 14 Section TOWN.N T1ON Township RANG. R14E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 84.00 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 84.00 Elevation of Kelly Bushing EDF .F 0 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 010-06,6 0-094/3 tapescan.txt CASE.F N/A Casing Depth 0S1 . DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths (TVDSS) are subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well . (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit) , a Directional and Gamma Sub, and a Hydraulic orienting Sub with a Near Bit Inclination Sensor amd an Ultra Slim Resistivity Sub. (7) Data presented here is final and has been depth shifted to a Primary Depth Control (PDC) log provided by Schlumberger GR CNL dated 31 Aug 2010 per Doug Stoner with BP Exploration (Alaska) , Inc. (8) The sidetrack was drilled from 13-21 through a milled window in a 7 inch liner. Top of window 12570 ft.MD (8685.4 ft.TVDss) Bottom of window 12577 ft.MD (8689.3 ft.TVDSS) (9) Tied to 13-21 at 12500 feet MD (8643.8 feet TVDSS) . (10) Baker Hughes INTEQ runs 2 through 4 experienced tool failures; therefore, no logging data was acquired for these runs. (11) The interval from 12980 ft to 13010 ft MD (8892.4 ft. to 8908.2 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP. AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 12367.6, 12370.5, ! 2.87402 12371.9, 12374.6, ! 2.66895 12386.5, 12390.6, ! 4.10547 12389.8, 12392.8, ! 3.0791 12403.7, 12405.4, ! 1.6416 12405.6, 12407.4, ! 1.84668 12427.1, 12427.1, ! 0 12428.5, 12428.8, ! 0.205078 12444.5, 12445.1, ! 0.615234 12456.6, 12457.6, ! 1.02539 12462.1, 12462.9, ! 0.821289 12503.9, 12507, ! 3.0791 12508.8, 12513.2, ! 4.30957 12545.1, 12545.6, ! 0.411133 12548.2, 12548.8, ! 0.615234 12550.3, 12551.9, ! 1.6416 12554.6, 12556.6, ! 2.05176 12560.1, 12559.7, ! -0.410156 12562, 12562, ! 0 12570.8, 12570.6, ! -0.205078 12573.4, 12574.5, ! 1.02637 12574.9, 12576.1, ! 1.23145 Page 2 tapescan.txt 12576.7, 12578.2, ! 1.43652 12580.4, 12582.9, ! 2.46289 12583.9, 12587.6, ! 3.69434 12589.7, 12590.9, ! 1.23145 12591.1, 12592.5, ! 1.43652 12593.4, 12594.4, ! 1.02637 12596, 12597.7, ! 1.6416 12598.5, 12601, ! 2.46289 12600.3, 12602.2, ! 1.84668 12605.9, 12605.5, ! -0.410156 12608.4, 12609.6, ! 1.23145 12609.8, 12611.4, ! 1.6416 12616.2, 12618.4, ! 2.25781 12619, 12621.1, ! 2.05176 12622.9, 12624, ! 1.02637 12625.8, 12627.2, ! 1.43652 12627.7, 12628.9, ! 1.23145 12629.7, 12631.1, ! 1.43652 12641, 12642.9, ! 1.84668 12650.1, 12651.3, ! 1.23145 12652.9, 12654.4, ! 1.43652 12655.4, 12657.9, ! 2.46289 12659.7, 12661.1, ! 1.43652 12661.6, 12663.2, ! 1.6416 12662.8, 12665, ! 2.25781 12666.5, 12668.3, ! 1.84766 12670.2, 12671.8, ! 1.64258 12674.1, 12674.9, ! 0.820312 12677.2, 12678, ! 0.821289 12681.5, 12682.3, ! 0.821289 12683.1, 12684.8, ! 1.6416 12689.1, 12690.5, ! 1.4375 12691.9, 12693, ! 1.02637 12694.6, 12695.8, ! 1.23145 12698.7, 12699.7, ! 1.02637 12701.2, 12703.2, ! 2.05273 12703.4, 12704.9, ! 1.43652 12711.6, 12712.7, ! 1.02637 12712.9, 12714.1, ! 1.23145 12719.1, 12720.9, ! 1.84766 12722.2, 12723.8, ! 1.64258 12725.2, 12726.9, ! 1.6416 12729.3, 12731, ! 1.64258 12734.5, 12736.5, ! 2.05273 12743.5, 12745.3, ! 1.84668 12747.2, 12748.4, ! 1.23145 12752.3, 12754.4, ! 2.05176 12759.7, 12760.9, ! 1.23145 12767.5, 12767.5, ! 0 12768.9, 12770.8, ! 1.84766 12773.3, 12774.5, ! 1.23145 12780, 12781.5, ! 1.43652 12784.1, 12785.3, ! 1.23145 12796.2, 12797.2, ! 1.02637 12801.1, 12802.8, ! 1.64258 12804.4, 12806.1, ! 1.64258 12812, 12814.3, ! 2.25781 12821.7, 12823.5, ! 1.84766 12825.7, 12828.2, ! 2.46289 12834.9, 12836.4, ! 1.43652 12846.8, 12848.9, ! 2.05176 12852.2, 12854, ! 1.84766 12860.8, 12862.9, ! 2.05273 Page 3 tapescan.txt 12868.8, 12871.7, ! 2.87305 12871.3, 12873.8, ! 2.46289 12878.5, 12880.7, ! 2.25781 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape subfile: 1 164 records. . . Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** 1111111111111111111 Remark File Version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Schlumberger GR CSG dated 31 Aug 2010 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 one depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 37 Page 4 tapescan.txt Tape File Start Depth = 12359.000000 Tape File End Depth = 13012.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 50 records. . . Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .002 1024 *** LIS COMMENT RECORD *** IIIIIIMMIMMIIIIIIII Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 73 Page 5 tapescan.txt Tape File Start Depth = 12355.750000 Tape File End Depth = 13010.000000 Tape File Level Spacing = 0.250000 Tape File Depth units = feet **** FILE TRAILER **** Tape Subfile: 3 86 records. . . Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 10/08/29 3352669 01 **** REEL TRAILER **** MWD 11/01/27 BHI 01 Tape Subfile: 4 2 records. . . Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 12359.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12359.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13012.0000 -999.2500 272.0566 -999.2500 -999.2500 -999.2500 -999.2500 Page 6 tapescan.txt Tape File Start Depth = 12359.000000 Tape File End Depth = 13012.000000 Tape File Level Spacing = 0. 500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 12355.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 12356.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13010.0000 -999.2500 398. 5000 -999.2500 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 12355.750000 Tape File End Depth = 13010.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS Page 7
