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208-093
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: UPDATE NOT OPERABLE: WAG Injector V-05 (PTD #2080930) Suspected SC leak Date:Friday, September 26, 2025 1:20:06 PM Attachments:V-05.docx From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, September 26, 2025 11:42 AM To: PB Wells Integrity <PBWellsIntegrity@hilcorp.com>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com> Subject: UPDATE NOT OPERABLE: WAG Injector V-05 (PTD #2080930) Suspected SC leak Mr. Wallace, WAG Injector V-05 (PTD# 2080930) was made Not Operable due to not being on injection for 2 year required AOGCC MIT-IA on 03/01/24 and has remained shut in. DHD has confirmed slight bubbling in the well conductor with 0% LEL is a probable surface casing leak. The well will remain shut in and NOT OPERABLE. Plan Forward: 1. Slickline: Set TTP 2. Fullbore: CMIT-TxIA 3. Downhole Diagnostics / Well Integrity: Further action as needed Please call with any questions or concerns. Ryan Holt Hilcorp Alaska LLC Field Well Integrity / Compliance Ryan.Holt@Hilcorp.com P: (907) 659-5102 M: (907) 232-1005 From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 1, 2024 2:56 PM To: chris.wallace@alaska.gov Cc: Regg, James B (CED) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector V-05 (PTD #2080930) will lapse on 2-year AOGCC MIT-IA Mr. Wallace, WAG Injector V-05 (PTD# 2080930) is due for its 2-year MIT-IA per AIO 3B.009 in March 2024. There are no plans to put it on injection during the month, it will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: WAG Injector V-05 (PTD #2080930) will lapse on 2-year AOGCC MIT-IA Date:Friday, March 1, 2024 3:07:15 PM From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Friday, March 1, 2024 2:56 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Regg, James B (OGC) <jim.regg@alaska.gov>; Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; Torin Roschinger <Torin.Roschinger@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: NOT OPERABLE: WAG Injector V-05 (PTD #2080930) will lapse on 2-year AOGCC MIT-IA Mr. Wallace, WAG Injector V-05 (PTD# 2080930) is due for its 2-year MIT-IA per AIO 3B.009 in March 2024. There are no plans to put it on injection during the month, it will now be classified as NOT OPERABLE for tracking purposes. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM TO: Jim Regg 'Klel 1 P.I.Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, April 2, 2020 SUBJECT: Mechanical Integrity Tests BP Explonmon (Alaska) Inc. V-05 PRUDHOE BAY UNIT V-05 Ste: Inspector Reviewed By: P.I. SupryJ P-- Comm Well Name PRUDHOE BAY UNIT V-05 API Well Number 50-029-23391-00-00 Inspector Name: Lou Laubenstein Insp Num: mitLot.200331tzza25 Permit Number: 208-093-0 Inspection Date: 3/29/2020 . Rel Insp Num: Well V-05 Packer Type Inj l]' TVD Depth 8539 Tubing IA OA Pretest 1310 814 322 Initial 15 Min 1308 1306' 3398. 3348 ' 392 402 - 30 Min 45 Min 60 Min F1305 ' 3334 401 PTD 2080930 Type Test SP1' Test llSi l 3200 BBL Pumped: 3.1 BBL Returned: 2.8 Interval REQVAR Notes: MIT -IA to maximum anticipated Injection pressure per AID 3B.009 Thursday, April 2, 2020 Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,March 29,2018 TO: Jim Regg ,-r Si 3L 1 S P.I.SupervisoSUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-05 FROM: Jeff Jones PRUDHOE BAY UNIT V-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT V-05 API Well Number 50-029-23391-00-00 Inspector Name: Jeff Jones Permit Number: 208-093-0 Inspection Date: 3/19/2018 Insp Num: mitJJ180329123250 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ' V-05Type Inj O 'TVD 8539 - Tubing 2688- 2688` 2687 - 2687 PTD 2080930 (Type Tests SPT Test psi 2135 IA 982 3496 • 3438 ' 3421 BBL Pumped: I 2 - BBL Returned: 2 . OA 132 143 " 147' 148 - Interval OTHER ' P/F P Notes: Pre AA application. iy SCANNEk Thursday,March 29,2018 Page 1 of 1 Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, March 20, 2018 4:40 PM To: AK, GWO Well Integrity Engineer;AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M IL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad LV;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Peru, Cale;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, OPS FF Well Ops Comp Rep;AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael; Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R;Tempel,Joshua;Worthington, Aras J; Regg, James B (DOA);AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Injector V-05 (PTD#2080930) Slow IA repressurization while on MI All, Injector V-05 (PTD#2080930)was made under evaluation on 2/20/2018 for having an anomalous inner annulus pressure trend. Diagnostics performed during the 28 day UE period confirm a slow IA repressurization rate that stabilizes at 1,250psi. At this time the well is reclassified as Not Operable and will remain shut in. The well will be evaluated for an AOGCC administrative approval for continued operation. Work Completed: 1. DHD–Bleed IA–Done 2/22, 2/27, 2. DHD- Daily monitor T/I/O,and wellhead temperature–Done- IA repressurization '176psi/day and stabilized at 1,250psi 3. AOGCC Witnessed MIT-IA–Done 3/19- Passed to 3421psi Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 SCANS Cell: 907-341-9068 wo —..w..r•.«.. From: AK, GWO Well Integrity Engineer Sent: Tuesday, February 20, 2018 10:22 AM 1 • • Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, February 20, 2018 10:22 AM To: AK, OPS EOC Specialists;AK, OPS GC2 Facility OTL;AK, OPS GC2 Field O&M TL;AK, OPS GC2 OSM;AK, OPS GC2 Wellpad Lead;AK, OPS PCC Ops Lead;AK, OPS Prod Controllers;AK, OPS Well Pad LV;Ak, Ops West Area IL;AK, RES GPB East Wells Opt Engr;AK, RES GPB West Wells Opt Engr;AKOpsProdEOCTL; Peru, Cale;Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity;AK, GWO DHD Well Integrity;AK, GWO Projects Well Integrity;AK, GWO SUPT Well Integrity;AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep;AKIMS App User;Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Hibbert, Michael;Janowski, Carrie; Montgomery,Travis J; Munk, Corey; Obrigewitch, Beau;O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel,Joshua;Worthington, Aras J; Regg,James B (DOA) Subject: UNDER EVALUATION: Injector V-05 (PID#2080930)Anomalous IA repressurization after UIC bleed Attachments: V-105.pdf All, Injector V-05 (PTD#2080930)was identified as having anomalous IA repressurization following a UIC bleed that was conducted on 2/12/2018. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan forward: 1. DHD—MIT-IA, Bleed IA 2. DHD-Daily monitor T/I/O,and wellhead temperature 3. Well Integrity Engineer—Additional diagnostics as needed Please reply with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCO*13 WO 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,April 10,2017 TO: Jim Regg aV' P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. �` ‘‘ \ ' V-05 FROM: Guy Cook �\ PRUDHOE BAY UNIT V-05 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Ml NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT V-05 API Well Number 50-029-23391-00-00 Inspector Name: Guy Cook Permit Number: 208-093-0 Inspection Date: 3/28/2017 Insp Num: mitGDC170328154115 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min I_-- T — 8539 Tubing1256 1279 1255 1256 Well , V-05 Type InJ w TVD PTD 2080930 Type Test SPT Test psi 2135 IA 526 2405 2365 2359 ,.....- BBL -BBL Pumped: I 22 BBL Returned: 1.6 OA 189 221 227 228 Interval 4YRTST P/F P L....— Notes: Notes: All went well with no issues. Lou Grimaldi was on site with me. SCANNED .') CANNED 'i G 1 5 ?0 7 Monday,April 10,2017 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown ❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other Convert to WAG Id 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 208-093 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service I3 6. API Number: 50-029-23391-00-00 7. Property Designation(Lease Number): ADL 0028240 8. Well Name and Number PRUDHOE BAY UNIT V-05 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: REE' E D Total Depth: measured 12962 feet Plugs measured feet C Y true vertical 9135 feet Junk measured 12861 feet MAR 2 8 2017 Effective Depth: measured 12877 feet Packer measured 10146 feet true vertical 9118 feet Packer true vertical 8539.94 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 3132 9-5/8"40#L-80 30-3162 30-2891 5750 3090 Intermediate 10318 7"26#L-80 28-10346 28-8710 7240 5410 Production Liner 2756 4-1/2"12.6#L-80 10208-12964 8592-9136 8430 7500 Perforation Depth: Measured depth: 10577-10655 feet 10675-10720 feet 10720-10730 feet 11450-11474 feet 11489-11504 feet 11524-11594 feet 11607-11657 feet 11670-11700 feet 11711-11901 feet 12180-12310 feet True vertical depth: 8895-8948 feet feet 8960-8983 feet 8983-8987 feet 8995-8989 feet 8986-8983 feet 8980-8971 feet 8970-8966 feet 8964-8962 feet 8962-8949 feet 8965-8992 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 25-10213 25-8597 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNEDMAY 1 5 202,Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 623 380 946 Subsequent to operation: 536 600 969 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development 0 Service Ed Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG fff GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-674 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer ifif„t„,„„\r,Signatures Phone +1 907 564 4424 Date 3/28/17 Form 10-404 Revised 5/2015 VrL 5-/jb/ '774 . , /0 BDMMMS \vAPR _ 3 2017 `7Submit Original Only • • Packers and SSV's Attachment PRUDHOE BAY UNIT V-05 SW Name Type MD TVD Depscription V-05 TBG PACKER 10146.41 8539.94 4-1/2" Baker S-3 Prod Packer V-05 PACKER 10219.01 8601.84 5" Baker ZXP Top Packer 0 i N C O 0 O -o u) O O u) Lr) D Q 0U) 2 a) in w rn U) I- v Q- , O fl- C -c, N 0 a) �t t c c - cu v) a E D 0 � () a0) O u) a)� _1 c L` a Q °' ami 0 ao_ .- D o -o c O c } m O o w m _ (o . o p E ~ O a o `) o o L o o c Q_ O 0 c M (� O J Q Q (0 C ,- > a)c o 11.1 � c O O Q O w 0 O Q (B L eL 'L O OZ a U) ap 75 Nr O CO Q L_ (A L ch O O� L O O W L 0- O _v) CL 4- p M (n W (� O (n Q O o co O a p �_ o O Cl. , C CD N C _> U N p 0 0 (n ..... Q p a (n Y O Q O Q 0) E O p p .0 L.L U) 0 ca o > 73 C OJ v0) (,) <- w o W � � o � � of (n (a — in O > W o c 2 J U c •c -, O co7c) Qa N 0 Qw a.) D a co oa C� o E o0 L > � � Q� Q Om (0 (a Oma: a) In a) d M c -0 � � II G1 (n O O O O LCr) * O O W N (n > a L * V V N N Y O O -0 O da U) O O O r LL CO O 0 (6 C O > O Z0) f- ami a) O 13 cm o C c 0 (fl - = 0 � M2c rt .c E > O w_ N C J _1 � 6) ,- O . „ CD } > a o II O F- 0) (n U) N N N O E Q 2 E" Q 0 �: O -ED .� a) C \ N - Oc 0 .o c *m a) b) 00 Co 10 O - . . - (n `�- CO Qa CO 0 o E 3 c H (Ea o v Lc) cs) cocc) Q 0_U 0 W a o ui . oo pcn c * U) o � -a - r) coco (+� � � � � o � * * -p * J J J O p `r' E (n � 0) J cnQ m � F ioCD U�3U�3U�3 (n (n (n in E ° � O * * Q > O CO U) TO C *k Q _ N _Z C•2 CO O (0 CI � � a > .z.: � � � (n � � � • � m k *k *k � 0 � � co (n cY ,- II 0_0 O O (� W' \O I I O O (n 2 F- Q Q Q _� U >, Cl. E mw E m o .c o z z Eet - E ' o O I- - cn () w g©g= D `�) ,r 0) HCIS In a � Li CO o 0 ~ QJ � 0 COoQ ? oHOOOo 2No ' _ E U) o O W _c ~ ° O a) � � °)cn 4- 0 -' 0D - @)000-1 -1 -1030003 - '4- --J •- o , (o O L .� a X C J O z \ > W C .0N M N W C Q (n C 0 O I- U E \ p LL --1 O C � O Z Wk *k *k p Y c'') � -0 �)5 ai10 XUJJ1 ,r > UZ - � F WUYYY000H W C E U 101 0 0-o 00 W II -CD II o , CD a) 0ZL-L > mmmWU " 0 (� c<n (13c, - a D o a s .( - )7 � U - D * � � � U (Xw » > wwwv 4a > Z aa — a_ 0_ aF- * * U * - -0 * Jnm * Jura. a. a. (n U) U) : . . aOLT_ U-! H >-0 0 0 0 0 0 o O N (N N N N N N 10 co O Er)co ti O O O O O O 0 Q S S a c_ o u 0 W m o a z a �0 70 Opp / / E . 9 $p m _ -Lcts > 5 � O / / E / 2UiQ) 7 u G < / / / 1 « n „ , 0 -k ƒ w2 - o � � R - / / » 2 @ + 2 $ ¢ f / . ± # 2 ■ c °- N- mQ $ / \ \ / ± A ± 0 2 » 0 ± � � Z4 ± £ Q 2 ± G / e 0 Z \ H W 3 om@ / ? a i a \ a i / r d ® CO 6 0 It TREE= 4-1/16"CM/ W13LHEAD= FMC SAFETY NOTES: WELL ANGLE>700 t 10855'. ACTUATOR= ELECTRIC -O KB.ELEV= 81.2' BF.H-EV= 55.6' KOP= 100' ( 2204' . [4-1/2'HES X NIP,ID=3.813 Max Angle= 106"@ 11332' Datum MD= 10557' Datum TVD= 8800'SS 9-5/8"CSG,40#,L-80,BTC, ID=8.835' 1-- 3160' GAS UFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORI DATE 7'CSG,26#,1-80,TCII,IO=6 276' 4 3623 3212 45 KBG-2 DMY BK 0 10/16/15 3 6524 5419 30 K8G-2 DAV BK 0 10/16/15 ��� %i 2• 8429 7061 29 KBG-2 DMY BK 0 10/16/15 ••• ••• 1 10097 8498 32 KBG-2 DMY BK 0 10/08/10 'Minimum ID = 3.725" @ 10189' •;• ;•; HES XN NIPPLE •• • • ;�; ••. • • •�• ••• ••• ••� •�• i•i •i• •i•4 ►..... 10123' , 4-1/2"HES X NIP,ID=3.813" •�• ••i 10144' '� • } 7 x 4-1/2'BKR S-3 PKR,ID=3.875' -.. 4....'..: ••• •I'• ••• ►�•� 10168' -14-1/2"HES X NIP ID=3.813"l • ••• ►•••� ••�• ►..4 ►i.•• [ 10189' 14-1/2'HES XN NIP ID=3.725'1 4-112'TBG. 12.6#,L-80,TCII, .0152 bpf, ID=3.958" 10211' ��" •�•, 10206' —J TOP OF 11'TRACK SLEEVE,D=5.25" .41 10217' 7"x 5"BKR HRD ZXP LT PKR �w/BKR HMC LNR HGR ID=4.43" 7 CSG,26# L-80.BTC-M,ID=6276"J 10 ._A k 10211' H 4-112"W1EG,D=4.00" FERFORAT1ON SUMMARY REF LOG:SWS VISION ON 10/13/08 ANGLE AT TOP PERE: 44°@ 1057T +Iote:Refer to Production DB for historical perf dat SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10577- 10655 0 10/16/08 12861' —FISH-4-1/2"CIBP MILLED 8 2-7/8" 4 10675- 10720 0 10/16/08 PUSH TO BTM(10/11/10) 2-7/8" 6 10720- 10730 0 05/30/10 2-7/8" 6 11450-11474 0 05/25/10 2-7/8" 6 11489- 11504 0 05/25/10 2-7/8" 4 11524-11594 0 10/16/08 2-7/8" 4 11607-11657 0 10/16/08 IIPP4.e%N.. 2-7/8" 4 11670- 11700 0 10/16/08 V 2-7/8" 4 11711-11901 0 10/16/08 Wi` 2-7/8" 4 12180- 12310 0 10/16/08 PBTD , ' 12877' 4-1/2"LNR, 12.6#,L-80,IBT-M,.0152 bpf,D=3.958" 12962' DATE REV BY COMMENTS DATE REV BY COMMBVTS PRUDHOE BAY UNIT 10/19/08 N9ES OIIIG HORIZ COMPLETION 07/29/11 CJKJ PJC LOG REF LOG UPDATE WELL: V-05 06/14/10 SEW/SV GLV CIO(06/07/10) 04/02/12 PJC—PERF CORRECTION PERMT No: 2080930 09/26/10 SPB/PJC SET COIV OSIT PLUG(09/20/1 08/15/12 RCT/JMD GLV C/O(08/11/12) API ND: 50-029-23391-00 10/23/10 ?/AGR GLV C/O(10/08/10) 11/03/15 JLS/JM) GLV CIO(10/16/15) SEC 11,T11N,R11E, 649'FNL,1861'FEL 10/28/10 MRHIPJC MILL RUG/CMT SOZ(10/11/10) 10/29/10 BSEIBJC GLV CIO(10/26/10) BP Exploration(Alaska) 410 P6iit V-05 PrN 000 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Thursday, November 05, 2015 11:01 AM To: Regg, James B (DOA);Wallace, Chris D (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe BaykliC Cc: AK, D&C Well Integrity Coordinator Subject: October 2015 AOGCC MIT forms Attachments: October 2015 MIT Forms.zip All, Please find the attached MIT forms for October 2015: Well: PTD#: 04-06 1760830 04-09 1760300 09-08 1760700 B-22A 2001570 L-215 2051270 JUL 0 5 2016 SC R-34 1931530 //-05 2080930 V-114A 2031850 Thank you, Whitney Pettus (4/lernate: Kevin Parks) BP Alaska-Well Integrity Coordinator en 4 G ‘,3 V' Otweatton WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator@BP.com 1 • S STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regg(aalaska.gov AOGCC.Inspectors(rDalaska.gov; phoebe.brooks@alaska.gov chris.wallace0alaska.aov e )1151K( OPERATOR: BP Exploration(Alaska),Inc. �, FIELD/UNIT/PAD: Prudhoe/GPB/V DATE: 10/17/15 OPERATOR REP: Kevin Parks AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-05 Type Inj. N - TVD -8,538' Tubing 334 - 351 '338 ' 337 Interval 0 P.T.D. 2080930 - Type test P ' Test psi 2134.5 Casing 374 "4,029 " 3,928 3,905 P/F P Notes: BP Internal diagnostic work OA 138 163 163 . 163 - Pumped 4 bbls of methanol Well Type IN. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval - P.T.D. Type test Test psi Casing P/F - Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT PBU V-05 MIT-IA 10-17-15Non witnessed.xls Pl OF 7y� • • Alaska Oil and Gas ew�\11/j; THE STATE ,:z.owr.....w.... -__„„41,,,, AT A s KA 9 J Conservation Commission ,,c:____:_,___:_,__, ���.it,x114= 333 West Seventh Avenue k` GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wMain: 907.279.1433 0F4LAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Kaity Burton s . kp J AN 1 ) ji l b 3 Pad Engineer Qos. , a BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU V-05 Sundry Number: 315-674 Dear Mr. Burton: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, t.-4 Cathy P. oerster Chair DATED this 3'`'c�ay of November, 2015 Encl. RBDMS NOV 0 9 2015 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI APPLICATION FOR SUNDRY APPROV Ilt . 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other Convert Back to WAG m 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 208-093• 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service O. 6. API Number: 50-029-23391-00-00 ■■ ■�s� ECE7. If perforating: 8. Well Name and Number: -- ■V lE V What Regulation or Conservation Order governs well spacing in this pool? Yes 0 No 0 Will planned perforations require a spacing exception? PBU V-05. OCT 2 8 2C15, 9. Property Designation(Lease Number): 10. Field/Pools: if 1 i LS ADL 0028240 ' PRUDHOE BAY,PRUDHOE OIL • AUG 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): 12962 ' 9135 , 12877 9118 12861 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"91.5#H-40 30-110 30-110 1490 470 Surface 3132 9-5/8"40#L-80 30-3162 30-2891 5750 3090 Intermediate 10318 7"26#L-80 28-10346 28-8710 7240 5410 Production Liner 2756 4-1/2"12.6#L-80 10208-12964 8592-9136 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 25-10213 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal RI 13.Well Class after proposed work: • BOP Sketch ❑ Detailed Operations Program ❑ Exploratory 0 Stratigraphic 0 Development ❑ Service 10 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ 0 GINJ 0 WAG liff - Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR ❑ SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Burton,Kaity Email Kaity.Burton@bp.com Printed Name Burton,Kaity Title Pad Engineer Signature ‘ t1 Phone +1 907 564 5554 Date /b/27/20 110— (J COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 ._..., i 77 Lif Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance 0 Other: Spacing Exception Required? Yes 0 No I Subsequent Form Required: /o} 4 0 APPROVED BYTHE Approved by: /2)0.4,,,,,t./...„,....., COMMISSIONER COMMISSION Date:/f_ 3_/S"' `/ ORIGINAL RBDMS4 Nu v 0 9 2015 ,71/ Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate al 4.l 11/2/20ar ,fl44to,2''-' • • a' N la CO CO r` LC) 00 CO M M LC) LC) CO L CO CO O Nr co LC) N N M p, r` (Ni 0 6 M Ln N W N a' V o0 oo op o0 O CO 0 'Cr 0) CI CD CA O CA 0) 00 C D o) o) o) 00 00 00 CO 00 00 C0 00 00 CI> I- 0.Q 0 F' Lnr` 00 00 CO CO CC) t 00 CO O M O c- M r` CO G. Ln O N 4 0 0 0 4 . 4 0 0 00 C] oo a) 0) o) O O 0) 00) 00) 00) > 0 00 O 00 0 C0 C0 00 00 CO CO 0 > 2 I- W CL' 0 W z Lu• LLi W I- H OJ 0_ W w g g Y U O O m O 0 < Y Y H w g uj t 141 N C) N- O 0�) Lt 0 0 c- J J J d d to Z — 0. CO r` r` 0 CC) 0 N- 0) M < < Q W 0 - 0 C 0 0 0 0 N U_ U_ Z U_ J W W J Z Z O J J a p a E 03tn Q Q Q = 0 0 2 W d Z 0 0 0 OO Z .0 W W W a I_ H < J CIii) 2220 cncnLi) cnLi) CO +41 > 0 0 I- . N- IC) COrnvr- oc- o p_ N- N- N 10 00 N o N- '- CO Q co 0 IC) CO r- V �7' IC) CO CO N- o 0 0 0 c- c- c- s c- - N :N Cl. y r- ,- V- v- r- r- c- L 0 O J = 1- O a J a TL t- -f i O u) u) u) u) cn CD o. 0 0 c 0 CY d' LL_ LL_ Li- f CY CY CC coWWaaaWWEn WWW dWW <C <CaWWWCLW 0. 0 t a' 0 H M C000noo D co CD 0 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 w z 0 N N N N N N N N N N Z W W N W C�OCCOOOu, � c00000COCO O w 0 J a. M N N Z 0_ 0 wW W W W CLO 0 0 0 0 0 0 0 0 0 Q a J H J J J D 0_' 0_ J J a' E m z in in Ln in in Ln in Ln in Ln u) 0 0 0 0 0 0 0 0 0 O LL 0_ CO O L- N OC LL i i i i i I i i i Carla- 0- o J O U' W 0_ < < m m W U co cn 0_ 0_ • Packers and SSV's Attachment PBU V-05 SW Name Type MD TVD Depscription V-05 TBG PACKER 10146.41 8539.94 4-1/2" Baker S-3 Prod Packer V-05 PACKER 10219.01 8601.84 5" Baker ZXP Top Packer • • 0440 „„. BP Exploration (Alaska) Inc. ps b 900 East Benson Boulevard 104 les P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 23, 2015 Alaska Oil &Gas Conservation Commission 333 West 7Th Avenue Suite 100 Anchorage, AK. 99501 During the course of conversion to WAG injection in 2013 V-05 failed to meet the BPXA MITIA for WAG • service. At the time, it was decided to classify the well for water injection only (WIN) to validate communication with the offset producers through pressure support. At this time, it is desired to reclassify V-05 for WAG service as it has shown communication to offsets and we feel MI injection • would be of value. Therefore, on October 16, 2015 slickline work to change out old dummy gas lift valves and re-MITIA the well began. The well passed a 4000psi MITIA on October 17, 2015 and now meets BPXA's MITIA criteria for WAG injection. Kaity Burton BPXA Base Management Production Engineer 907-564-5554 Page 1 of 1 TREE_ 41/16"CNI/ IP SAOTES: WELL ANGLE>70°@ 10855'. WEU_HEAD=._ FIC V-05 ACTUATOR= ELECTRIC KB.ELEV= 81.2' BF.ELEV= 55.6' Kms= 100', 2204" —[41/2"HES X NIP,ID=3.813' Max Angle= 106°@ 11332' • I* . �— — Dation MD= _ 10557', Datum TVD= 8800'SS' 9-5/8°CSG.40#,L-80,BTC,ID=8.835" 1-- 3160' A GAS LFT MANDRELS _ __ ST MD TVD DEV TYPE VLV LATCH' FORT ' DATE 17'CSG,26#,L-80,TCII, D=6.276" l'---17 4604' X X 4 3623 3212 45 KBG-2 DMY BK 0 08/11/12 3 6524 5419 30 KBG-2 DMY BK 0 08/11/12 ••• ••• 2 8429 7061 29 KBG-2 DMY BK 0 06/07/10 • •• �• 1 10097 8498 32 KBG-2 MY BK 0 10/08/101 Minimum ID = 3.725" 10189' �.� •�• HES XN NIPPLE •• �•� Ii!. •••••••••••••• ••• 4... • 10123' H4-1/2"HES X NIP,ID=3.813' ••• ••• Wri •�• 10144• }H7'x 4-1/2"BKR S-3 PKR,ID=3.875" 1 v.. •v •• � •� r•- 10168' 4112"HES X NIP�D'3.813° ••• ••• •• • � • •� •. 10189° 4172'HES AN NIP,ID=3.725" 41/2"TBG, 12.6#,L-80,TCU, .0152 bpf,D=3.958" 10211' r• �!i, 102 ' -{TOPOF 11'TACK SLEEVE D=525" - - - 10217' —7"x 5"BKR I-H)ZXP LT PKR, w/SKR HNC LNR HGR,D=4.43" 7'CSG,26#,L-80,BTC-M, D=6.276" -1— 10344' I k 10211' 41/2"MEG,D=4.00" PERFORATION SUIVIMARY RIF LOG:SWS VISION ON 10/13/08 ANGLE AT TOP PERF: 44°@ 1057T Vote:Refer to Production D8 for historical perf dat SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10577-10655 0 10/16/08 { 12861' 1—ASH-4-1/2"C16P PALLID 8 2-7/8" 4 10675-10720 0 10/16/08 % ,, PUSH TO BTM(10/11/10) 2-7/8" 6 10720-10730 0 05/30/10 2-7/8" 6 11450-11474 0 05/25/10 i 2-7/8" 6 11489-11504 0 05/25/10 2-7/8" 4 11524-11594 0 10/16/08 2-7/8" 4 11607-11657 0 10/16/08iiiipt ��_ 2-7/8" 4 11670-11700 0 10/16/08 �fk. 2-7/8" 4 11711-11901 0 10/16/08 __ _ `tea 2-7/8" 4 12180-12310 0 10/16/08 I PBTD — 12877' 4-112"LNR, 12.6#,L-80,IBT-M,.0152 bpf,D=3.9581--{ 12962' DATE REV BY COPAMENTS DATE REV BY COMMENTS PRIDHOE BAY MAT 10/19/08 N9M OCG HORIZ COMPLETION 07/29/11 CJKJ PJC LOG REF LOG UPDATE WELL: V-05 06/14/10 SEW/SV GLV C/O(06/07/10) 04/02/12 PJC PBS CORRECTION PHZMT Nb: 2080930 09/26/10 SFB/PJC SET COIVFOSFT PLUG(09/20/1 08/15/12 RCT/A/D GLV C/O(08/11/12) AR No: 50-029-23391-00 10/23/10 ?/AGR GLV C/O(10/08/10) SEC 11,T11N,R11E 649'FNL,1861'FB 10/28/10 MRFYPJC PALL R.UG/CMT SO7(10/11/10) 10/29/10 BSEBJC GLV C/O(10/26/10) BP Exploration(Alaska) 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. ~~ ~ - Q f~, j Well History File Identifier ,~ „~,,,~., ,~ ..,ems IIIIIIIIIIIIIIIIIII o R~~,.~„~,a IIIIIIIIIIiIIIIIII RE AN DIGITAL DATA N I Di k tt OVERSIZED (Scannable) s: ^ Ma Color Items: o. e es, s p ^ Greyscale Items: Other, No/Type: G~ , "~~ ( ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria n Date: p,L, O /s/ Pro "ect Proofin J 9 I I I I I II II I I I II I I II I BY: Maria Date: a /O /s/ ti P ~ x 30 + = 5 =TOTAL PAGES~~ on re ara Scannin g p ~=- (Count does not include cover sheet) BY: Maria Date: pl O D lsl I II I III II III II I III I Production Scanning Sta e 1 Pa a Count from Scanned File: ~ (Count does include cover sheet) g 9 Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: `~ / D/ /Q /s/ I ~ 1 It 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. III II'I II I (III IIIII ReScanned III 111111 IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III !IIIII III II'I III 10!6/2005 Well History File Cover Page.doc OF T� � ID 4"� \ \I1/77 THE STATE Al Oil and Gas �® of l lLl S Commission Conservation l Witt , GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 OR 2p13 Kaity Longden SC O3 /45) {� 3 Petroleum Engineer �� _ V BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU V -05 Sundry Number: 313 -094 Dear Ms. Longden: 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, Cathy P oerster 4 ( lay DATED this '7 day of March, 2013. Encl. RECEIVED STATE OF ALASKA 'S ?.1.91(- , A OIL AND GAS CONSERVATION COMAION r r, 2 1. 13 APPLICATION FOR SUNDRY APPROVALS ��w. - 20 AAC 25.280 A t,,, 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program V Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ � Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ W4 b t W I NT E ' Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. v� BP Exploration (Alaska), Inc. Development 0 , Exploratory ❑ 208 -0930 j t. )' 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number. 3 Anchorage, AK 99519 -6612 50- 029 - 23391 -00 -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: PBU V -05 Spacing Exception Required? Yes ❑ No 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 028240 . PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12962 ' 9135 ' 12877 9117 NONE 12861 Casing Length Size MD TVD Burst Collapse Structural Conductor 83' 20" 91.5# H -40 25 108 25 108 1490 470 Surface 3136' 9 -5/8" 40# L -80 24 3160 24 2890 5750 3090 Production 10321' 7" 26# L -80 23 10344 23 8709 7240 5410 I Liner 2756' 4 -1/2" 12.6# L -80 10206 12962 8591 9054 8430 7500 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 22 10211 Packers and SSSV Tvoe: 4 -1/2" BKR S -3 PKR Packers and SSSV MD and ND (ft): 10144 8538 5" BKR HRD ZXP LT PKR 10206 8591 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El . 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/7/2013 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ El . GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kaity Longden Printed Name Kaity Longden Title PE Signature Phone Date CA/ /Y-Th 564 -5554 2/21/2013 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31.5 ^ f� V9 y Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: j tat t-r W r t/s') t- 55 rd 44 I ?— - I A ' , RSD MAR 0 5 . 1 . r'l Al d � u��1� X10 lvt fa v � qs l .-� J �' �� �01� Subsequent Form Required: R2 — 4 4- APPROVED BY Approved by: a 4 9 COMMISSIONER THE COMMISSION Date: 3 - // VLF e rRio is / 0L 3d ) 3 /-3/z7%) Submit in Duplicate b • • Noir BP Exploration, Alaska 21 February 2013 Guy Schwartz Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, Alaska 99501 J During the course of converting well V -05 to WAG it failed to meet BPXA's MITIA for WAG service. It has been decided that we should reclassify this well as WIN until such time as we would like to pursue WAG injection. 14.7 Kaity Longden Base Management EWE /NWE PE BP Alaska 907 - 564 -5554 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reoaCdlalaska.aov; doa .aoocc.prudhoe.bav()alaska.gov; phoebe,brooks(d)alaska.nov; tom.maunder(dlalaska.00v OPERATOR: BP Exploration (Alaska), inc. FIELD ! UNIT / PAD: Prudhoe Bay/PBUN -Pad DATE: 12/09/12 OPERATOR REP: Mehreen Vazir AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V -05 Type Inj. W TVD 8,457' Tubing 1533 1534 1532 1511 1508 Interval I P.T.D._2080930 Type test P Test psi 2114.25 Casing 795 3980 3838 3758 3692 P/F F Notes: Initial MIT -IA for WAG conversion OA 293 606 582 564 549 First test (extended) IA took 3.5 bbls to pressure up Well V -05 Type Inj. W TVD 8,457', Tubing 1,507 1,510 1,511 1,510 Interval P.T.D. 2080930 Type test P Test psi 2114.25 Casing 2,874 4,035 3,926 3,845 P/F F Notes: OA 449 574 564 554 Second test, IA took .8 bbls to pressure up Well V -05 Type Inj. W TVD 8,457' Tubing 1,507 1,508 1,509 1,502 Interval P.T.D. 2080930 Type test P Test psi 2114.25 Casing 242 4,000 3,849 3,766 P/F F Notes: OA 190 566 556 544 Third test, IA took 3.8 bbls to pressure up Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F, Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cyde I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) Form 10-426 (Revised 06/2010) MIT PBU V-0512- 09- 12.xds • . A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaatebalaska.00v; AOGCC.InsoectorsAalaska.00v; phoebe.brooks(8)alaska.aov chris.wallacelr)alaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD ! UNIT ! PAD: Prudhoe Bay/PBU/L -Pad DATE: 01/21/13 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V -05 Type lnj. N ND 8,538' Tubing 60 6 6 6, Interval O P.T.D. 2080930 Type test P Test psi 2134.5 Casing 430 3,516 3,418 3,367 P/F P Notes: Pre - injection pressure test to confirm barriers OA 160 204 204 204 4 bbls to reach test pressure Well V -05 Type lnj. TVD Tubing 2 10 9 9 Interval O P.T.D. 2080930 Type test Test psi Casing , 67 3,002 2,926 2,895 P/F P Notes: Pre - injection pressure test to confirm barriers OA 169 198 197 197 2.6 bbls to reach test pressure Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Weit Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test_ _ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Fax Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey 0 = Other (describe in notes) W = Water D = Differential Temperature Test Form 10-426 (Revised 11/2012) MIT PBU V-05 01- 21- 13.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa @alaska.00v; AOGCC.Inspectors(a)alaska.gov; phoebe.brooksttialaska.aov chris.wallace(BDalaska.00v OPERATOR: BP Exploration (Alaska), Inc. FIELD I UNIT I PAD: Prudhoe Bay/PBU/L -Pad DATE: 02/10/13 OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well V-05 Type Inj. N ND 8,538' Tubing 2 8 5 5 4 Interval 0 P.T.D. 2080930 Type test P Test psi 2134.5 Casing 397 2,505 2,443 2,419 2,403 P/F_ P Notes: Pre - injection pressure test to confirm barriers OA 194 198 197 196 196_ 2 bbls to reach test pressure Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P /F_ Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi , Casing P/F Notes: OA . Well Type Inj. ND Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA - TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey O = Other (describe in notes) W = Water D = Differential Temperature Test I Form 10-426 (Revised 11/2012) MIT PBU V-05 02- 10 -13.xls e RECEIVED STATE OF ALASKA A OIL AND GAS CONSERVATION COMMON JAN 3 Q 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other(✓) WAG Conversion Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development el Exploratory ❑ 208-093-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-23391-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028240 PBU V-05 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): - To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12962 feet Plugs measured None feet true vertical 9135.2 feet Junk measured 12870 feet Effective Depth measured 12877 feet Packer measured See Attachment feet true vertical 9117.51 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 83 20"91.5#H-40 25-108 25-108 1490 470 Surface 3136 9-5/8"40#L-80 24-3160 24-2889.86 5750 3090 Intermediate None None None None None None Production 10321 7"26#L-80 23-10344 23-8708.75 7240 5410 Liner 2756 4-1/2"12.6#L-80 10206-12962 8590.72-9135.2 8430 7500 Perforation depth Measured depth See Attachment feet 10675-10720 feet 10720-10730 feet 11450-11474 feet 11489-11504 feet 11524-11594 feet 11607-11657 feet 11670-11700 feet 11711-11901 _feet 12180-12310 feet True Vertical depth See Attachment feet 8959.8-8982.67 feet 8982.67-8986.95 feet 8994.98-8989.48 feet 8986.3-8983.36 feet 8979.9-8971.3 feet 8970.18-8965.53 feet 8964.36-8962.25 feet 8961.78-8949.25 feet 8964.65-8992.36 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 22-10211 22-8594.99 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): a�,f 4 0 13 SCANNED Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorE❑ Development❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: - Oil ❑ Gas U WDSPLJ_J GSTOR ❑ WINJ ❑ WAG o GINJ ❑ SUSP ❑ SPLUC-❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 312-128 Contact Nita Summerhays Email Nita.SummerhayS(c7bp.com Printed Name Nita Summerh4k Title Petrotechnical Data Technician �s Si. �, �������� .�►■_ Phone 564-4035 Date 1/30/2013 �BDI�IS JAN 31 I�L� l ° ��� � l� iO�v 7 Form 10-404 Revised 10/2012 Submit Original Only • Daily Report of Well Operations ADL0028240 .-mo SUMMARY ***WELL • 1 • I• - pre injec ion conversion SET 4 1/2"WHIDDON C-SUB. LEFT IN X-NIP @ 10,156' SLM/10,168' MD PULLED BK-S/O GLV FROM ST#3 @ 6,508' SLM/6,524' MD PULLED BK-DOME GLV FROM ST#4 @ 3,605' SLM/3,625' MD SET BK-DGLV IN ST#4 @ 3,605' SLM/3,625' MD 8/10/2012 ***WSR CONT. ON 8-11-12*** T/1/0=1700/1700/190 Assist s-line (INJEC I ION CONVERSION) Pumped 5 bbls meth followed by 135 bbls crude down IA to load. SL set DMY valve. Pumped 1.1 bbls crude Y P 8/11/2012 down IA to pressure up to 2500 psi. ***Job continued on 8-12-12 WSR*** ***WSR CONT. FROM 840-12***(pre-injection conversion) LRS LOADED IA W/135 BBLS OF CRUDE SET BK-DGLV IN ST#3 @ 6,508' SLM/6,525' MD LRS BEGINS MIT-IA 8/11/2012 ***WSR CONT. ON 8-12-12*** ***Job continued from 8-11-12 WSR*** MIT IA 2500 psi FAILED 15 min loss of 34 psi, 30 min loss of 29 psi, for a total loss of 63 psi. Bled IAP to 500 psi. Pad Op/PE notified Hang 8/12/2012 Tags SL on well upon departure CVs OTG FWHP=2250/500/220 ***WSR CONT-FROM 8-11-12***(pre-injection conversion) LRS PERFORMS MIT-IA. INCONCLUSIVE. PULLED WHIDDON C-SUB FROM 10,156' SLM -EMPTY 8/12/2012 ***WELL LEFT S/I ON DEPARTURE*** PAD-OP NOTIFIED T/I/O = 2142/386/189. Temp = Si. MiT-IA to 2000 psi PASSED (pre injector conversion). Pressured up IAP to 2510 psi using 2.3 bbls of diesel. Monitored for 30 min. IAP decreased 89 psi in the first 15 min and 36 psi in the second 15 min. Bled IAP to 320 psi (98 gal). Job complete. Final WHPs = 2140/320/200. 8/13/2012 SV, WV= C. SSV, MV= 0. IA, OA= OTG. NOVP. 1300. ?/I/0=2140/346/185 Temp=S/I Injectivity test(Prepare for inj conversion of well) Speared into TBG w/5 bbls MEOH followed by 75 bbls diesel &then 5 bbls MEOH to load TBG. Pumped 94 bbls 1%KCL for step rate injectivity test 1, Wait 30 min. pumped 93 bbbls 1% KCL down tbg for injectivity test 2, and pumped remaining 37 bbls water(see log for details) Then capped w/3 bbls MEOH &40 bbls diesel for FP. Fimal WHP's 800/420/440 8/15/2012 SV,WV=CLOSED SSV,MV,IA,OA=OPEN PAD op notified on departure • S Daily Report of Well Operations ADL0028240 T/I/0=300/500/200. Temp= Si Step rate test( Injection conversion ) Spear into tbg w/5 bbls 60/40 meth followed by 38 bbls diesel. Spear into tbg w15 bbls 60/40 meth followed by 825 bbls 1% KCL for step rate test. Rate= 5 minutes/10 minutes/15 minute pressures. .5 bpm= 736/792/791. .75 bpm= 904/926/963. 1 bpm= 1061/1181/1154. 1.25 bpm= 1341/1296/1405. 1.5 bpm= 1518/1466/1501. 1.75 bpm= 1575/1639/1842. 2 bpm= 1767/1836/1994. 2.25 bpm= 2047/2131/2123. 2.5 bpm= 2146/2217/2296. 2.75 bpm= 2304/2310/2262. 3 bpm= 2307/2353/2244. 3.25 bpm= 2340/2537/2226. 3.5 bpm= 2532/2424/2445. 3.75 bpm= 2486/2336/2374. 4 bpm= 2540/2531/2374. 4.25 bpm= 2461/2501/2613. Freeze protect tbg w/5 bbls 60/40 meth &40 bbls diesel. FWHP's=1160/700/380 SV, WV, 10/12/2012 SSV= SI MV= O IA&OA= OTG. T/I/O= 270/450/180. Temp= Sl. WHPs &T FL (injection conversion prep) Ind. T FL @ surface. 10/12/2012 SV, WV&SSV=C. MV=O. IA& OA=OTG. NOVP. 0300 hrs. surface. 11/19/2012 SV, WV, SSV= C. MV= O. IA, OA= OTG. NOVP. 0100 hrs ***Job continued from 11-19-12 WSR***Pump 5 bbls neat meth followed by 1082 bbls 1% kcl for injectivity test(see log)freeze protect tbg with 5 bbls neat meth, 35 bbls diesel, 3 bbls 11/20/2012 neat meth FWHP's=1200/1025/399 SV, WV=S/I SSV, MV=O IA, OA=OTG Pad Op notified FLUIDS PUMPED BBLS 191 DIESEL 26 METH 136.6 CRUDE 1306 1%KCL 1659.6 TOTAL ■ Perforation Attachment ADL0028240 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base V-05 10/11/2010 BPP 10577 10655 8895.45 8947.86 V-05 10/11/2010 BPP 10675 10720 8959.8 8982.67 V-05 10/11/2010 BPP 10720 10730 8982.67 8986.95 V-05 10/11/2010 BPP 11450 11474 8994.98 8989.48 V-05 10/11/2010 BPP 11489 11504 8986.3 8983.36 V-05 10/11/2010 BPP 11524 11594 8979.9 8971.3 V-05 10/11/2010 BPP 11607 11657 8970.18 8965.53 • V-05 10/11/2010 BPP 11670 11700 8964.36 8962.25 V-05 10/11/2010 BPP 11711 11901 8961.78 8949.25 V-05 10/11/2010 BPP 12180 12310 8964.65 8992.36 BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • ■ . • • Packers and SSV's Attachment ADL0028240 SW Name Type MD TVD Depscription V-05 PACKER 10144 8456.69 4-1/2" Baker S-3 Prod Packer V-05 PACKER 10206 8509.52 5" Baker ZXP Top Packer r THEE- 4-1/16"CJW i SAF TOTES: WELL ANGLE>70°(§10855'. WELLHEAD= FMC) V-0 ACTUATOR= ELECTRIC KB.B.EV= 812 BF.EI.EV= 55.6'; KO_P= 100': I 2204• I--4-1/2'HES X NIP,D=3.813" M9x Angle= 106°.., 11332'' Datum MD= 10557' Datum TVD= 8800'SS 9-5/8'CSG,40#,L-80,BTC,ID=8.835' -I 31`0' i GAS LFT MANDRELS ST MD 1VD DEV TYPE VLV LATCH PORT DATE 17'CSG,26#,L-80,TC9,D=6.276' 4604' X X 4 3623 3212 45 KBG-2 DMY BK 0 08/11/12 3 6524 5419 30 KBG-2 DMY BK 0 08/11/12 •• %i s • • SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMIIIISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Kaity Longden Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 DAPR 1 8 202 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU V -05 Sundry Number: 312 -128 40S-QC/3 Dear Mr. Longden: 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, Cathy . Foerster Chair DATED this 17 day of April, 2012. Encl. , STATE OF ALASKA ✓ `r sY `o p ALA. OIL AND GAS CONSERVATION COMMIS N ' APPLICATION FOR SUNDRY APPROVALS • 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ StimulateD Alter Casing ❑ Other: Producer to Infector 0' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development is • Exploratory ❑ 208 -0930 • 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23391 -00 -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: PBU V -05 Spacing Exception Required? Yes ❑ No 0 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 028240 - PRUDHOE BAY Field / PRUDHOE OIL Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12962 ' 9135 • 12877 9117 • NONE 12861 Casing Length Size MD ND Burst Collapse Structural Conductor 83' 20" 91.5# H-40 25 108 25 108 1490 470 Surface 3136' 9 -5/8" 40# L -80 24 3160 24 2890 5750 3090 Production 10321' 7" 26# L -80 23 10344 23 8709 7240 5410 Liner 2756' 4 -1/2" 12.6# L -80 10206 12962 8591 9054 8430 7500 Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: T MD (ft): a SEE ATTACHED - - 4 -1/2" 12.6# L -SO @. , y 1 10211 i - a P�?; Packers and SSSV Tvoe: 4 -1/2" BKR S -3 PKR Packers and SSSV MD and ND (ft): 16.144 ', 8538 5" BKR HRD ZXP LT PKR GIN # � I� ( 10206 Ap § 8591 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El • 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 4/16/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kaity Longden Printed Name Kaity Longden Title PE Signature Phone Date -A� 564 -5554 4/2/2012 Prepared by Nita Summerhays 564 -4035 (11 -/LA/V —' % COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' ) _- ' 1 g Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test g Location Clearance ❑ Other: 4 Vil i ÷itec; self f4 rr ` l A ar- ` s 1 b vt-j cz t- "'i &x7 .. 4 A (1Z-r it-4;4- p c- (-am. -L e 4. t e- 0.-- I G:. /7fird ite-t z o ,,44. j I Z c 6) Subsequent Form Required: / c)a— 11699 APPROVED BY Approved by: /2 COMMISSIONER THE COMMISSION Date: 4- -I 7 - (Z - 1 -403 Revised 1/ 2 010 a y 5 /Z 0 ` I G I'4I OR 18 2 �� �mit n Duplicate .1v Form 0 e p V -05 208 -093 - PERF ATTACHMENT A Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -05 10/16/08 PER 10,577. 10,655. 8,895.45 8,947.86 V-05 10/16/08 PER 10,675. 10,720. 8,959.8 8,982.67 V-05 10/16/08 PER 11,524. 11,594. 8,979.9 8,971.3 V-05 10/16/08 PER 11,607. 11,657. 8,970.18 8,965.53 V-05 10/16/08 PER 11,670. 11,700. 8,964.36 8,962.25 V -05 10/16/08 PER 11,711. 11,901. 8,961.78 8,949.25 V -05 10/16/08 PER 12,180. 12,310. 8,964.65 8,992.36 V-05 5/25/10 APF 11,489. 11,504. 8,986.3 8,983.36 V-05 5/25/10 APF 11,450. 11,474. 8,994.98 8,989.48 V -05 5/30/10 APF 10,720. 10,730. 8,982.67 8,986.95 • V -05 6/8/10 BPS 10,189. 12,310. 8,576.21 8,992.36 V-05 7/25/10 BPP 10,189. 12,310. 8,576.21 8,992.36 V -05 7/26/10 BPS 10,189. 12,310. 8,576.21 8,992.36 V -05 9/15/10 BPP 10,189. 12,310. 8,576.21 8,992.36 V -05 9/20/10 BPS 10,246. 12,310. 8,624.92 8,992.36 V -05 10/11/10 BPP 10,246. 12,871. 8,624.92 9,116.26 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE I • • • bp Ott ,fir, BP Exploration (Alaska) Inc 900 East Benson Boulevard P. 0. Box 196612 Anchorage, Alaska 99519 -6612 (907) 561 -5111 March 30, 2012 Guy Schwartz Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, AK 99501 Sund ry Notice for V -05 Conversion from Producer to Injector BP Exploration Alaska, Inc. proposes to convert well V -05 from a long -term shut -in pre - produced injector to a WAG injector well as part of the Northwest Eileen Pattern Flood Development project. Well V -05 was drilled and completed as a long horizontal well in upper zone 4 with the original objective of converting the well to WAG injection once it became uncompetitive. The well was pre - produced intermittently for 2 -1/2 years until it was no • longer competitive relative to other wells due to low oil rates and low gross fluid rates. It has been shut in since May 2011 following a packer leak and repair. It is now V planned to proceed with conversion to injection to provide pressure support, waterflood, and miscible gas injection sweep for the area. The forward plan for conversion of well V -05 is attached along with an area of review for offset wells. Please contact Kaity Longden at 564 -5554 with any questions or comments. Sincerely, Kaity Longden, PE Longk4abp.com (k ecey � ` r r� e�tiey ,�ev � e � �y, wel l Wa, ?elfin rre� �p �l i,� ,Cc � ©� 4 - 'VI/42-- • • Current Well Status V -05 is currently an operable Producer. The last well test on 05 -09 -11 indicated 584 bfpd, 32 bopd, 94% watercut, and 8987 scf /bbl GOR. At these rates, the well is uncompetitive due to low productivity, low formation gas rate resulting in the need for gas lift gas, and high water cut. As the gross fluid rate has declined, this well has developed hydrates which need to be thawed. A methanol drip down the IA was considered but ultimately rejected as the well has exceeded both the expected production time and reserves recovery and it was decided to move forward with conversion to injection. In 2010, add pelf's were added for increased fluid production and heat. This was to be followed by an acid stim, but while preparing for the acid stimulation, the well developed a packer leak. A cement packer squeeze was pumped to remediate the problem and the well was returned to production. An acid stimulation was later pumped in March of 2011 as a last resort to improve well productivity. There was an initial benefit, but this was short lived. Additionally, when the scale inhibition treatment was pumped, the well hydrated off and had to be thawed. In order to be converted to injection, V -05 must demonstrate (1) competent cement across upper reservoirs and (2) pass a pressure test to 4000 psi to operate as a WAG injector. A USIT cement log was run in 2008 to determine the cement quality behind the production casing. The log was run from 10350 ft up to 200 ft MD. Additionally, a cement bond log was run across the producing interval from TD up to 9995 ft MD. This log shows good cement bond from 10344' MD (production casing shoe) to TD. The top of the Ivishak is at 10577 ft MD / -8800 ft TVDss. Therefore there is sufficient cement for isolation be hind pipe. On October 25, 2010 V -05 passed an MIT -IA to 4000 psi sl demonstrating integrity. A state witnessed pressure test will still need to be performe for the AOGCC. Facilities V -05 was designed and installed as a pre - produced injector in 2008. The engineering and materials needed to convert V -05 from producer to injector were completed and procured in 2008 within the original installation package, with the exception of minor changes to design and little additional materials needed. V -05i will be configured with water and gas metering in similar fashion to other westside wells. Metering equipment includes an Endress- Hauser flow meter for water measurements and a DP style of flow metering for gas. The conversion of producer to injector is estimated to take 5 -6 weeks after funding is approved given no outstanding delays. • • Plan Forward 1. Install dummy gas lift valves. 2. MITIA at 2500 psi, step rate injection test. 3. Place well on water injection (confirm AOGCC approval prior to injection, target and maximum injection rates TBD by step rate test) 4. AOGCC witnessed MITIA at 4000 psi (WAG injection) after injection stabilized. • • Area of Review — V -05 Revised March 30, 2012 This Area of Review for V -05 will discuss the wells that are within '/ mile of this injection well BHL (see figure 1 below). V -05 is proposed as a WAG injection well in the Ivishak reservoir. There are two wells that come within 1 /4 mile of V -05 bottomhole location at the top Ivishak. The following table displays the 2 wells within 1 /4 mile, their distance from V- 05, and any annulus integrity comments based on an in depth analysis of each well: Well Name Dist, Ft. Annulus Integrity Comments 1169' (top TOC calculated to be above injection zone. ,/ perfs L -03 to Cementing records indicate good job with no cloy closest offset losses. perfs) 625' (closest TOC calculated to be above injection zone. open perfs V -03 closest peno Cementing records indicate good job with no perfs) losses. A USIT cement log was run on V -05 in 2008 to determine the cement quality behind the production casing. The log was run from 10,350 ft up to 200 ft MD. Additionally, a ®�� cement bond log was run across the producing interval from TD up to 9995 ft MD. This log shows good cement bond from 10,344' MD (production casing shoe) to TD. The top of the lvishak is at 10577 ft MD I -8800 ft TVDss. Therefore there is sufficient C cement for isolation behind pipe. td L� Cement bond logs are not available for L -03 and V -03 so cementing records were j . ` '~ reviewed for these wells. es-4 e s". t In well L -03, a 4 -1/2" liner was run to 15370' and hung off at 11729'. The TOC was calculated based on the cement volumes pumped with 30% excess in the annular v' space. It was cemented with 95 barrels of cement. Annular capacity was calculated to be 6lbbls between 4 -1/2" liner and 6 -1/8" hole. No losses were noted. In well V -03, the 4 -1/2" liner was run to 12589' and hung off at 9619'. The TOC was calculated based on the cement volumes pumped with 30% excess in the annular space. It was cemented with 82 barrels of cement. Annular capacity was calculated to be 50bbls between the 4 -1/2" liner and 6 -1/8" hole. No losses were noted. II • • TSAD structure map __ k \ , A li o ‘ i \qe i ,J l • •.. «... _s'.. r...r a.r '.4 mile •ra 1 rte. \,.. 4!_____ 5 \t "'" t • _ . b �'\ Perforated Zones iv"-----, : ,l , -- °a' f f x" 45P 44P �', • k j ° r `' 43P imai 7 III 42P `. _ \N.. Large Fault l - > 60' throw (,, 1 _ / _ N. Moderate Fault ~• 30' - 60' throw Vpad a t i • f t ••..• Small Fault _.,,\ , • 15' - 30' throw Figure 1: V -05 Area Bottomhole Location Area Map, 1 /4 mile radius circle centered around V -05A Ivishak perforations Wells L -03 and V -03 are within 'A mile of V -05 at the heel of V -05. mm. TREE = 4-1/18° CIW e WELLHEAD = FMC SAFETY NOTES: WELL ANGLE >70" ACTUATOR - — ELECTRIC V KB.',ELEV = 81.7 'BF.ELEV.= 55.6' KOP -; 10a Max Angler 106* fi: 11332' 1 2204' — [4-1/2" HES X NIP, ID = 3.813' Datum MD= 10567' • Datum TVD = 880C/ SS 19-518' CSG, 401, L-80, BTC, ID = 8.835" —1 3160' -A GAS LIFT MANDRELS ST IVO ND DEV TYPE VLV LATCH PORT DATE 4 3623 3212 45 KBG-2 IX)ME BK 16 10126/10 17' CSG, 261, L TCII, ID .2 6.276" — 4604 X ... •-• 3 6524 5419 30 KBG-2 SO BK 20 10126/10 ( 'VI • •-*. 2 8429 7061 29 KBG-2 DMY BK 0 06107/10 • • • • • 1 10097 8498 32 KBG-2 DAY BK 0 10/08/10 • 1 1 . - ) (..-, • •to, •• • 1 Minimum ID = 3.725" @ 10189' * • • • to e * A • HES XN NIPPLE •• •I •• •• • C ,'"( 2 3 ' /6 '''. a•- ' •I •• •• . • ii-c Ve+ •+ S 1 0124i- ,§4 ct. , ..-- -- "*A , • - • • • 4■4 *. •• I 10123' —1[1 HES X NIP, ID = 3.813' •1 '• P • •• ■• •1 • •• •, 10144' 1-- 7 x 4-1/2" BKR S-3 PKR, ID = 3.875" ...; v•vl _;t •• •4 10168' —14-1/2" HES X NIP, ID = 3.813" I • • 7. 1 ( 3(c( 3 61 W • • "--'` **0 • •41 of •• •Il I 10189' ,—f4:1/2"1- JON NIP, ID = 3.725" •• 7.■ •1 •• +A • • • . I I 14-1/2" TBG, 12 61, L-80, TCII, .0152 bpf, ID.. 3.958' 1-- 1 10211' I -- 10206• H TOP OF 11' TIEBACK SLEEVE, ID = 5.25" i:t .... 10217' — 7" x 5" BKR HRD ZXP LT PKR, w /BKR HMC LNR HGR, ID = 443 • • 7" DSC, 26*, L-80, BTC-M, ID = 6.276" --t 10344' l • 10211' H4-1/7' WLEG, ID = 4.00" 2 PERFORATION SUMMARY / (.) . — S( REF LOG: SWS VISION ON 10/13108 ANGLE AT TOP PERF: 44' (fg 10577' 111 ,lote: Refer to Production DB for historical perf dati SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10577- 10655 0 10/16/08 2-7/8" 4 10675 - 10720 0 10/16/08 I 12861' I— FISH - 4-1/2" CIBP WILLED & 2-7/8" 6 10720 - 10730 0 05/30/10 PUSH TO BTM (10/11/10) 2-7/8" 6 11450 - 11474 0 05125/10 2-7/8" 6 11489 - 11504 0 05/25/10 2-7/8" 4 11524 - 11594 0 10/16/08 2-7/8" 4 11607 - 11657 0 10/16/08 2-7/8" 4 11670 - 11700 0 10116408 ....... am... 2-7/8" 4 11711 - 11901 0 10/16/08 am• 2-7/8" 4 12180 - 12310 0 10/16/08 ...my ...• PBTD — 12877' 14 LNR, 12.6#, L-80, IBT .0152 bpf, ID = 3.958" H 12962' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10119/08 N9ES °RIG HOW COMPLETION 10/23/10 ?/ AGR GLV C/0 (10/08/10) WELL: V-05 06/14/10 SEW/SV GLV C/O (06/07/10) 10/28/10 MRH/PJC KILL PLUG/ CMT SQZ (10/11/10) PERMIT No: 2080930 06/18/10 SVVC/SV SET TTP (C6/08/10) 1029/1C E3SE/BJC GLV CIO (10/26/10) AR No: 50-029-23391-00 07/30/10 JONPJC PULU RESET XXN (07126/10) 07/29/11 CJK/ PJC LOG REF LOG UPDATE SEC 11, T11N, R11E, 649' FNL, 1861' FEL 09/26/10 MSS/PJC PULL XXN (09/15/10) 04A32/12 PJC PERF CORRECTION 09/26/10 _ SPB/PJC SET convosrr PLUS (09/20/10) BP Exploration (Alaska) Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Saturday, April 14, 2012 9:19 AM To: 'Kirchner, Carolyn J' Cc: Longden, Kaity Subject: RE: V -05 Variance Request: packer depth (PTD 208 -093) Carolyn, Your request is approved for the packer variance. The conditions set forth on the sundry application will also state that "Alternate Packer placement is approved" . Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Kirchner, Carolyn .3 [ mailto:Carolyn.Kirchner @bp.comi Sent: Friday, April 13, 2012 8:47 PM To: Schwartz, Guy L (DOA) Cc: Longden, Kaity Subject: V -05 Variance Request: packer depth Hello Guy, I would like to request a variance for V -05 packer depth per the 20 AAC 25.412(b) as it is greater than 200 ft about the producing interval. A cement squeeze was performed to repair a leaking packer. A passing MIT -IA to 4000 psi on 10/15/10 showed the new packer to be competent. Effective packer depth is 10,000ft MD due to the cement squeeze. 20 AAC 25.412. Casing, cementing, and tubing of injection wells for enhanced recovery, disposal, and storage (b) A well used for injection must be equipped with tubing and a packer, or with other equipment that isolates pressure to the injection interval, unless the commission approves the operator's use of alternate means to ensure that injection of fluid is limited to the injection zone. The minimum burst pressure of the tubing must exceed the maximum surface injection pressure by at least 25 percent. The packer must be placed within 200 feet measured depth above the top of the perforations, unless the commission approves a different placement depth as the commission considers appropriate given the thickness and depth of the confining zone. http: / /www.legis. state.ak.us/ basis /folioproxy. asp? url= http:// wwwjnu01.legis.state.ak.us /cgi- bin/folioisa.dll/aac/ query= [JUMP:'20 +aac +25!2E412]/docl, r.1 } ?firsthit Please let me know if you require anything further. Thank you, Carolyn Kirchner 564 -4190 4/14/2012 STATE OF ALASKA • • ALA* OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 Other ❑ 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. 4. Well Class Before Work: \Permit to Drill Number: Name: Development 0 Exploratory ❑ 208 -0930 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ API Number: Anchorage, AK 99519 -6612 50- 029 - 23391 -00 -00 8. Property Designation (Lease Number) 9. Well Name and Number• N N ADLO- 028240 PBU V -05 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12962 feet Plugs (measured) 10189' 6/8/10 feet true vertical 9135.2 feet Junk (measured) None feet Effective Depth measured 12877 feet Packer (measured) 10144 true vertical 9117.51 feet (true vertical) 8538 Casing Length Size MD TVD Burst Collapse Structural Conductor 108 20" 215.5# A -53 SURFACE - 108 SURFACE - 108 Surface 3160 9 -5/8" 40# L -80 28 - 3160 28 - 2890 5750 3090 Intermediate Production 10344 7" 26# L -80 26 - 10344 26 - 8709 7240 5410 Liner 2756 4 -1/2" 12.6# L -80 10206 - 12962 8591 - 9135 8430 7500 Liner Perforation depth: Measured depth: SEE ATTACHED - _ - _ ..a. True Vertical depth: _ - _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 SURFACE - 10211 SURFACE - 8595 Packers and SSSV (type, measured and true vertical depth) 7 "X4 -1/2" BKR S -3 PKR 10144 8538 APR 2 7 241 RECEIVED 12. Stimulation or cement squeeze summary: Z O'O Intervals treated (measured): JUL Treatment descriptions including volumes used and final pressure: Alaska Oil Folio C+m. Commission 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: 'i� Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development j0 Service ❑ Daily Report of Well Operations X N.C2 Status after work: Oil ID Gas ❑ WDSPL ❑ GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pr le Title Data Management Engineer Signature ./.-- " / � Phone 564-4944 Date 7/8/2010 _` Fui i t i 10 -404,t viaed 7 /2009 RBDMS JUL 0 9 — {/nom 7y J � sub, nil Ol iyinai Only �+ i�+ 41"x` /a /,0 V -05 208 -093 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base V -05 10/16/08 PER 10,577. 10,655. 8,895.45 8,947.86 V -05 10/16/08 PER 12,180. 12,310. 8,964.65 8,992.36 V -05 10/16/08 PER 11,670. 11,700. 8,964.36 8,962.25 V -05 10/16/08 PER 11,711. 11,901. 8,961.78 8,949.25 V -05 10/16/08 PER 11,524. 11,594. 8,979.9 8,971.3 V -05 10/16/08 PER 10,675. 10,720. 8,959.8 8,982.67 V -05 10/16/08 PER 11,607. 11,657. 8,970.18 8,965.53 V -05 5/25/10 APF 11,450. 11,474. 8,994.98 8,989.48 V -05 5/25/10 APF 11,489. 11,504. 8,986.3 8,983.36 ill V-05 5/30/10 APF 10,720. 10,730. 8,982.67 8,986.95 V-05 6/8/10 BPS 10,189. 12,310. 8,552.35 8,992.36 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • V -05 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/23/2010 CTU 5 1.74" CT, JOB SCOPE: Remove ice plug, SCMT/ GR ?CCL log, Adperf, Mud acid Move from G pad to V pad. i —ti. _�_ 5/23/2010 T /I /0= 1830/490/170. Temp =SI. Increase TP w /AL line, monitor FL's pre & post (pre acid). AL SI @ casing valve, ALP =1660 psi ASRC rigged up to tree w/ 0 psi on their equipment. TBG FL @ 1788', IA FL @ 8098' (between sta #2 & #3). 1M onitor 1 hr, TBG & IA FL unchanged. Final WHPs= 1830/490/170. ASRC in control of well. *Note V -05 is a PAL well, TP is above AL line pressure, ;possible ice plug in tubing* 5/24/2010,CTU 5. 1.75" CT ,Job Scope: Thaw ice plug, SCMT, Adperf, Mud Acid. Move to V !pad. MIRU on V -05. RIH w/ 3.00" DJN Drift to PBTD. RIH w /SLB GR/CCL & ISCMT. Log from PBTD to 10000'. POOH. 5/24/2�SRC Test unit #2, assist CTU **job in progress ** * *inlet well V -05, outlet V -204 ** 5/25/2010CTU 5 , 1.75 CT. Job Scope: e: H drate plug, p y p g SCMT /Jewelry log, Adperf, Mud Acid. ,Continued from 5/24/10. Wait for town approval to run adperfs. RIH with Perf Gun 1 #1 (15' of 2 7/8" PJ2906 6 spf 60 degree phasing) PezinratP From 11489' top 'shot to 11504' bottom shot RIH with Pen` Gun #2 (24' of 2 7/8" PJ2906 6 spf 60 degree phasing) Perforate 11450' top shot 11474' bottom shot. 5/25/2010ASRC Test unit #2, assist CTU * *job in progress ** '* *inlet well V -05, outlet V -204 ** 5/26/2010 ASRC Test Unit #2, Assisting CTU, Stand by for Reel Swap, ***Job in Progress * ** Inlet V -05, Outlet V -204 5/27/2010 ASRC Test Unit #2, Stand by for proration, ** *Job in Progress * ** Inlet V -05, Outlet V -204 5/28/2010 ASRC Test Unit #2, Stand by for proration, ** *Job in Progress * ** Inlet V -05, Outlet V -204 5/29/2010 1 CTU #5 Road from shop MIRU * * ** Job Continued on 5/30/10 **** 5/29/2010 ASRC Test Unit #2, Stand by for proration, Attend Check Six training, Assist CTU. v ' ** *Job in Progress * ** Inlet V -05, Outlet V -204 1 s 5/30/2010 #5 Job Scope: Log /Adperf /Acid treatment MU CTC and 2.25" JSN to pump 1.25" ball to drift new pipe. * * * * ** Witness weekly BOP test went good * * * * ** MU MHA and carrier with memory GR/CCL. Test coil checks, good. At 8000' PERFORM WELL CONTROL DRILL. Log 11800' - 10100'. Flag @ 10650'. ! Depth correction is -14' @ flag. RIH with Perf Gun #3 (10' of 2 7/8" PJ2906 6 spf 1 60 degree phasing) Perforate 10720' top shot 10730' bottom shot. POOH Job Continued on 5/31/10 5/30/2010 ASRC Test Unit #2, Assist CTU, ** *Job in Progress * ** Inlet V -05, Outlet V -204 5/31/2010 CTU #5 Acid Treatment * * ** Continued from 5/30/10 * * ** POOH. At surface ;confirmed shots fired B/D spent gun recover 1/2" aluminum ball from firing head. MU 2.25" JSN for acid treatment. Called Kevin IA and Tbg tracking POOH. Line ;up AL gas down backside /circ returns up IA to determine depth of leak. Job incomplete. Move to Z -46. { 1 5/31/2010 ** *WELL S/I ON ARRIVAL * ** !RIG UP SLICKLINE UNIT 4518 CURRENTLY RUNNING CAT STANDING VALVE ** *CONT ON 6 -1 -10 WSR * ** 5/31 /201 0 1ASRC Test Unit #2, Assist CTU Ops., stand by for Slickline operations, ** *Job in Progress * ** Inlet V -05, Outlet V -204 61112010:T11/O= 1600/80/220 Assist Slickline Pumped 72 bbls diesel down tubing to l assist slickline in setting valves and pressure testing valves. 1 FWHP= 1900/200/220 Slickline in control of well upon departure. 3 ( { j 3 E F 3 i 1 7 1 • 6/1/2010 Test Unit #2, Stand by for slickline operations, * **Job in Progress * ** ' Inlet V -05, Outlet V -204 I 1 i i 6/1/20101 * * *CONT FROM 5 -31 -10 WSR ** *(assist coil) MADE MULTPLE ATTEMPTS TO SET 4 1/2" CAT, TOOLS COMING BACK WITH METAL SHAVING IN THEM SET 4 1/2" CAT STANDING VALVE IN XN @ 10161' SLM, 10189' MD PULLED BK -OGLV FROM STA #1 @ 10075' SLM, 10097' MD PIECE OF ,RUBBER IN CHECK VALVE NOT ALLOWING IT TO CLOSE 1SET BK -OGLV (22/64" PORTS) IN STA #1 LRS PRESSURED UP TBG TO 2500# IA NOT TRACKING MADE MULTIPLE ATTEMPS TO PULL 4 1/2" CAT STANDING VALVE 1 * * *CONT ON 6 -2 -10 WSR * ** 6/2/2010 ASRC Test Unit #2, CTU on Location, Communication issue still exists, Stand by for decision, ** *Job in Progress * ** Inlet V -05, Outlet V -204 1 1 6/2/2010 * * *CONT FROM 6 -1 -10 WSR ** *(assist coil) PULLED 4 1/2" CAT STANDING VALVE FROM 10161' SLM, 10189' MD ** *WELL S/I ON DEPARTURE, DSO NOTIFIED * ** € � f 6/2/2010CTU #5 Acid Treatment MIRU PJSM Function test BOP's. Online to knock well down IA still tracking tubing. Check IA fluid at surface. Tubing mostly gas.Made a call decision made to move on.Freeze protect well with 38 bbls 50/50 meth. * * * * ** Job Continued on 6/3/10 * * * * ** I • 6/3/2010 Test Unit #2, Job Aborted, Begin rig down, Stand by due to high winds, in Progress* ** Ilnlet V -05, Outlet V -204 6/3/2010 CTU #5 Finish freeze protecting well. Pump 20 50/50 meth down IA. RDMO. * * ** Job Incomplete * * * * * ** 6/4/2010 ASRC Test Unit #2, Stand by for Well Support to move tank farm to continue rig down. Inlet V -05, Outlet V -204 6/5/2010 ASRC test Unit #2, Stand by for Well Support to move Tank Farm to continue Rig down, ** *Job in Progress * ** 'Inlet V -05, Outlet V -204 6/5/2010 T /I /0= 320/150/120. Temp =SI. WHP's & IA FL. (pre MITIA). AL SI @ IA casing valve with 1780 psi. IA FL © surface. There is an integral installed, and hard line rigged up to the IA, and a P -Sub, and well test flow cross on the Swab valve. SV, WV- SSV, MV =O. IA, & OA =OTG. NOVP. 6/6/2010 ASRC Test Unit #2, Complete Rig down, ** *Job Complete * ** Inlet V -05, Outlet V -204 6/6/20100 ** *WELL S/I ON ARRIVAL ** *(gas lift integrity) SET 4 -1/2" WHIDDON C -SUB AT 10,168'SLM. PULL BK -S /O FROM STA# 1 AT 10,085'SLM PULL BK -LGLV FROM STA#2(8,418'SLM), STA# 3(6,509'SLM), STA# 4(3,612'SLM). I BK -DGLV IN STA# 4(3,612'SLM). CURRENTLY RIH W/ BK -DGLV FOR STA# 3. * * *CONT WSR ON 6/7/10 * ** 6/7/2010 T /I /O= Assist S -Line MIT -IA FAILED to 3000 (Eval TxIA Comm) Loaded IA w/ 240 i bbls crude. S -Line set DGLV. Pumped 10.5 bbls crude down IA to Pressure IA to 2000 psi. Tbg tracked IAP. Opened wing. Established LLR of 3.5 BPM @ 3000 psi pumping down IA taking returns up Tbg to FL. CaII PDS for LDL. Continued on 06- 08 -10 * *Safety drill conducted ** 6/7/2010 ***CONT WSR FROM 6/6/10 ** *(gas lift integrity) SET BK -DGLV IN STA# 3(6,509'SLM), AND STA# 2 AT8,418'SLM. LRS LOADED IA WITH 250 BBLS OF CRUDE. 1 SET BK -DGLV IN STA# 1 AT 10,085'SLM / 10,097' MD LRS ATTEMPT MIT -IA. MIT -IA FAILED. TBG. TRACKED IA. 'RUN JK WITH T.T. PINS TO STATIONS 1,2,3,4, VERIFIED ALL VALVES IN POCKET. LRS PERFORMED LLR OF 3.5 BPM AT 3000 #. CURRENTLY RIH W/ 4 -1/2" GS * * *CONT WSR ON 6/8/10 * ** • 6/8/2010 ***CONT WSR FROM 6/7/10***(gas lift integrity) !PULL 4-1/2" WHIDDON C-SUB FROM 10,168'SLM. RUN SLB LEAK DETECT LOG FROM SURFACE TO 10,300' SLM. (LEAKS APPEAR TO BE AT 2,650'SLM/4,170'SLM/10,217'SLM.) !SET 4.5 X-XN AT 10,172' SLM / 10,189' MD. 1MIT-T TO 3000#.(failed tbg x ia communication) ***RDMO,LEFT WELL SHUT IN, PAD OP NOTIFIED*** 6/8/2010 Continued from 06-07-10 Assist S-Line with LDL. Pumped into the IA with 217 bbls of crude at 2 BPM while Slickline logged. Good Data Final WHP's = 1 1600/520/340 1Slickline in control of well at the time of departure. 6/11/2010 T/I/0=520/520/130. Temp=SI. T & IA FL (pre CMIT-Tx IA). TBG & AI FL @ :Surface. ISV,WV,SSV=C. MV=O. IA,OA=OTG. 6/11/2010iT/I/0=500/500/220 Temp=SI MIT TBG 3000 FAIL Est. LLR .9 BPM@ 2800 psi I 'down IA (Diagnose TxIA comm) Pumped 2.3 bbls of 40* meth down TBG to !reach 3000 psi. IA press gained 320 psi. in 15 min's TBG lost 1970 psi/ IA gained 20 psi . Attempted to establish LLR at 3000 psi while pumping down Tubing. T/IA= 2900/1070 pumped minimum rate for +/- 4 minutes- Tank level ,dropped 1 bbl and T/IA increased to 3000/1180. Attempted CMIT TxIA - Pumped 12 bbls meth down Tubing then U-tube from Tubing to IA. T/ IA pressured up to 1500 psi- monitor for 5 minutes and T/IA fell to 1000/1000. Rigged up to IA and 1pumped 7 bbls neat meth, 26 bbls crude down IA to establish LLR of .9 bpm at 12800 psi **Swab, Wing, SSV closed- Master, IA, OA open on departure** FWHP's= 800/780/300 6/16/20101T/1/0=500/500/220 Assist E-Line w/ LDL (Eval TxIA comm) Pumped 9 bbls crude 'down IA to pressure la to 3000 psi. E-Line pressured Tbg to 2700 w/ Triplex. 'Established LLR of 1 BPM down IA @ 3000 psi. Mantained 3000 psi on IA while E-Line ran LDL. Continued on 06-17-10 1 1 I - 6/16/2010 ***WELL SHUT-IN ON ARRIVAL*** (E-LINE: LEAK DETECT WITH PDS) INITIAL TWO: 600/570/200 PSI. LOGGED BASELINE TEMPERATURE PASS DOWN AT 100 FPM. STOP COUNT AT PACKER DEPTH CONFIRMED LEAK AT PACKER. *** JOB CONTINUED ON 17-JUNE-2010*** • 6/17/20101*** JOB CONTINUED FROM 16- JUNE - 2010" ** (E -LINE LEAK DETECT LOG) IT/I/0 = 2670/3000/650 PSI LOGGED PASS WITH IA AT 3000 PSI AND TUBING AT 2690 PSI AT 100 FPM iTO CHECK NOISE SIGNATURE AROUND 6362' SWAP CONFIGURATION TO PUMP DOWN TUBING AND TAKE RETURNS THROUGH IA. TUBING PRESSURE HELD AROUND 3000 PSI. LOGGED FROM SURFACE DOWN TO TTP WHILE MONITORING FOR LEAKS. PUMPING RATE DOWN TUBING VARIED FROM 0.1 TO 0.7 BPM, BUT !MOSTLY HELD ABOUT 0.45 BPM WHILE LOGGING DURING POOH. NO LEAK FOUND DESPITE —0.5 BPM PUMPING RATE. RE -LOG SLOWER AND WITH IA FULLY OPEN TO FLOWLINE FOR MAXIMUM PRESSURE DIFFERENTIAL. 1STOP COUNT CONFIRMED LEAK AT PACKER WITH DIFFERENT LEAK SIGNATURES WHILE PUMPING DOWN TUBING VS IA. ** JOB CONTINUED ON 18 -JUNE -2010 * ** 6/17 /2010 €Continued from 06 -16 -10 Assist E -Line w/ LDL Pumped total of 266 bbls crude !down IA while E -Line ran LDL. Pump 121 bbls crude & 10 bbls diesel down tbg while maintaining 3000 psi for E -line to LDL. Pump 10 bbls diesel to establish LLR of 1 bpm @ 2950 psi down tbg. Pumped an additional 212 bbls crude down Tbg at average rate of .66 BPM while E -Line Ran LDL.Continued on 06 -18 -10 WSR 6/18/2010 Continued from 06 -17 -10 Assist E -Line w/ LDL. Pumped an additional 60 bbls crude down tbg while E -Line ran LDL. FWHP= 200/350/300 Casing valves open to gauges. E -Line on location upon departure 6/18/2010 * ** JOB CONTINUED FROM 17- JUNE - 2010 * ** (E -LINE LDL) LOG OVER LEAKS FOUND IN SLICKLINE LDL TO CONFIRM OR DENY 1 EXISTANCE. OTHER THAN THE EXISTING PACKER LEAK IDENTIFIED ON RUN #1 NO ADDITIONAL LEAKS SEEN DURING LOGGING PASS. FINAL T /I /O = 280/340/220 1**** JOB COMPLETED * ** FLUIDS PUMPED B BLS 350 50/50 METH 98 diesel 49 1% KCL 497 Total TREE = 4- 1/16" CIW WELLHEAD = FMC SPF NOTES: WELL ANGLE >70° ACTUATOR = ELECTRIC V -0 5 KB. ELEV = 81.2' BF. ELEV= 55.6' KOP = 100' Max Angle = 106° @ 11332' Datum MD = 10557' I 2204' 1— I4 -1/2" HES X NIP, ID = 3.813" I Datum 1VD = 8800' SS 9 -5/8" CSG, 40 #, L-80, BTC, ID = 8.835" H 3160' 1 — , GAS LIFT MANDRELS ST 36 T MD 2 KB G-2 DEV 'TYPE DOME LATCH B 08! 8 09 C PORT 17" CSG, 26#, L -80, TCII, ID = 6.276" H 4604' I — X � J j x 3 6524 5419 30 KBG -2 DOME BK 16 08/18/09 L 2 8429 7061 29 KBG -2 DOME BK 16 08/18/09 1 10097 8498 32 KBG -2 SO _ BK _ 22 06/04/10 Minimum ID = 3.725" @ 10189' HES XN NIPPLE ' ' 10123' ,--- 14 -1/2" HES X NIP, ID = 3.813 " g 10144' 1 x 4-1/2" BKR S -3 PKR, ID = 3.875" 1 ' 10168' 4-1/2" HES X NIP, ID = 3.813" 1 10189' 4 -1/2" XXN PLUG (06/08/10) 10189' 1-14-1/2" HES XN NIP, ID = 3.725" 1 4-1/2" TBG, 12.6#, L -80, TCII, .0152 bpf, ID = 3.958" I-1 10211' 1 I 10206' 1-1TOP OF 11' TIEBACK SLEEVE, ID = 5.25" 10217' I - 7 "x5 " BKR HRDZ>PLTPKR, w /BKR HMC LNR HGR, ID = 4.43" • 7" CSG, 26#, L-80, BTC -M, ID = 6.276" H 10344' I 10211' 1-14 112" WLEG, ID = 4.00 " — PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 44° @ 10577' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 4 10577 - 10655 0 10/16/08 2 -7/8" 4 10675 - 10720 0 10/16/08 2 -7/8" 6 10720 - 10730 0 05/30/10 2 -7/8" 6 11450 - 11474 0 05/25/10 2 -7/8" 6 11489 - 11504 0 05/25/10 2 -7/8" 4 11524 - 11594 0 10/16/08 2 -7/8" 4 11607 - 11657 0 10/16/08 2 -7/8" 4 11670 - 11700 0 10/16/08 � NI. 2 -7/8" 4 11711 - 11901 0 10/16/08 Way i� 2 -7/8" 4 12180 - 12310 0 10/16/08 ' =� PBTD 1-1 12877' 14 -1/2" LNR, 12,6 #, L -80, IBT -M, .0152 bpf, ID = 3.958" 1--1 12962' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/19/08 N9ES ORIG HORIZ COMPLETION 06/14/10 SEW /SV GLV C/O (06/07/10) WELL: V -05 03/05/09 GS /SV DRLG DRAFT CORRECTIONS 06/18/10 SWC/SV SET TTP (06/08/10) PERMIT No: 2080930 03/05/09 SWC/SV GLV C/0 (02/19/09) API No: 50- 029 - 23391 -00 09/30/09 SEW /SV GLV C/O (08/18/09) SEC 11, T11 N, R11 E, 649' FNL, 1861' FEL 06/03/10 JKC/PJC PERFS (05/25- 30/10) 06/04/10 JLJ /PJC _GLV C/0 (06/01/10) _ BP Exploration (Alaska) Wells with ice plugs during to shut -dove Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, January 15, 2011 1:40 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: AK, D &C Well Integrity Coordinator `( 1 I � Subject: Wells with ice plugs during to shut -down Jim, The following wells were found to have ice plugs in the tubing. They are all artificially lifted producers that are stacked out with gas lift on the IA. The plan forward is to have a pumping unit thaw the ice plugs by pumping down the backside. We will keep you informed of the progress and any other wells with ice plugs as they are discovered. V -05 (PTD # 2080930) V -205 (PTD #2061800) Z -46A (PTD #2052030) Thank you, MaNNED FEB i 7 2011 Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907)659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 1/24/2011 osn an o • /~ l ~chtumber~r Alaska Data & Consulting Services 2525 Gambeli Street, SuOe 400 Anchorage, AK 99503-2938 ATTN: Beth Weil Job H N0.5545 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken - 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD E-198 BBUO-00015 STATIC BOTTOM & TEMP SURVEY 04/03/10 1 1 H-30 BCRD-00020 PRODUCTION PROFILE 05/10/10 1 1 P2-34 83SQ-00071 STATIC PRESSURE SURVEY 05/15/10 1 1 P2-34 83S0.00073 (PROF WITH STATIC SURVEY 05/19/10 1 1 V-OS AWJFD0090 MEM CBL 05/24/10 1 1 P2-17 BCRC-00017 PRODUCTION PRO ICE 06!01/10 1 1 16-066 BBUO.00023 PRODUCTION PROFILE 06/08/10 1 1 S-21 Z-46A BBSK-00019 BAUJ-00027 PROOUCTION PROFILE MEM CBL 06/03/10 06/01/10 1 1 1 i V-OS BD88-00018 MEM LOL .06/08/10 1 1 01-26A 13148-00106 SCMT 06/10!10 1 1 B-13A 1-27/P-20 1-27/P-20 MPF-82A BBUO-00019 AYKP-00085 AYKP-00085 BAUJ-00010 USR RST & FL RECOR PRODUCTION PROFILE MCNL 05/28/10 06/06/10 06/06/10 04/06/10 1 1 / 1 1 1 1 1 Z-16A BCUE-00005 CH EDIT PDC MEM CORR CATION 04/06!10 1 E-150 AWJI.00081 MCNL - 04/03/10 1 1 05-19 F-27A BBKA-00013 AYKP-00078 RST RST 03!14/10 03/17/10 1 1 1 1 J-18A BD88-00010 MCNL 04/18/10 1 1 BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnicai Data Center LR2-1 2525 Gambell Street, Sure 400 900 E. eanson BIVd. Anchorage, AK 99503-2838 ~ rm~~ ~~ <<'s ,1lJf~ 6G ~~ ?..(~1~) osn en o • ~J I~ l ~chlam6erger Aieska Data & Consulting Services 2525 Gambell Street, Su0e 400 Anchorage, AK 99503.2839 ATTN: Beth Well Job & N0.5545 Company: State of Alaska Alaska Oil & GasCons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anehorage,AK 99501 Log Description Date BL Color CD E-19B BBUO-00015 STATIC BOTTOM & TEMP SURVEY ~ 04/03/10 1 1 H-30 BCRD-00020 PRODUCTION PROFILE 05/10/10 1 1 P2-34 B3SQ-00071 STATIC PRESSURE SURVEY 05/15/10 1 1 P2.34 B3S0.00073 (PROF WITH STATIC SURVEY 05/19/10 1 1 V-OS AWJI-00090 MEM CBL ~ 05/24/10 1 1 P2-17 BCRC-00017 PRODUCTION PRO ICE 06/01!10 1 1 16-O6B BBUO-00023 PRODUCTION PROFILE 06/08/10 1 1 S-21 Z-46A BBSK-00019 BAUJ-00027 PRODUCTION PROFILE MEM CBL 06/03/10 06/01/10 1 1 1 1 V-OS BD88.00018 MEM LDL .06108/10 1 1 01-26A B14B-00106 SCMT 06/10/10 1 1 B-13A /-27/P-20 BBUO-00019 AYKP-00085 USR RST & FL RECOR 05/28/10 06!06/10 1 1 1 1 1-27/P-20 AYKP-00085 PRODUCTION PROFILE 06/06/10 1 1 MPF-82A BAUJ-00010 MCNL 04/06/10 1 1 Z-16A BCUE-00005 CH EDIT PDC MEM CORR CATION 04/06/10 1 E-150 AWJI.00081 MCNL 04/03/10 1 1 OS-19 F•27A BBKA-00013 AYKP-00078 RST RST 03/14/10 03/17!10 1 1 1 1 J-18A BD88-00010 MCNL 04/18/10 1 1 BP Exploration (Alaska) Inc.^w"r, 4, ~,~,~,"~ ~"V ~G, Vn1Yr1•v V"c ...,r. r:..a.n .v: Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ~(t.: s ``+ t . . Alaska Data 8 Consulting Services 2525 Gambell Street, SuBe 400 Anchorage, AK 99503-2938 tZ1~(~f DATA SUBMITTAL COMPLIANCE REPORT 2/9/2010 Permit to Drill 2080930 Well Name/No. PRUDHOE BAY UNIT V-05 Operator BP EXPLORATION (ALASKA INC API No. 50-029-23391-00-00 MD 12962 TVD 9135 Completion Date 10/16/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: Gyro, MWD, DIR, GR / RES / PWD, NEU / AZM-DENS (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Iy mearrrme rvumoer Name scare meaia No start slop cn rceceroea comments D~ C Exc Directional Survey 0 732 Open 10/8/2008 pt Directional Survey 0 732 Open 10/8/2008 ED D Asc Directional Survey 0 12962 Open 11/10/2008 Rpt Directional Survey 0 12962 Open 11/10/2008 GTED C Las 17458~induction/Resistivity 10233 12962 Open 1/14/2009 Dens, RPM, GR, RHOB, j RPD, RPM, RPS, RPX 'i~6g Cement Evaluation 5 Cof 200 10350 Case 7/20/2009 USIT, CCL, GR, GPIT, CBL-VDL 12-Oct-2009 C Pds 18296~ment Evaluation 200 10350 Case 7/20/2009 USIT, CCL, GR, GPIT, CBL-VDL 12-Oct-2009 D C Lis 18468 duction/Resistivity 44 12961 Open 9/1/2009 L1S Veri, GR, ROP, FET, RPX, RPS, RPM, RPD, DRHO, NPHI ,Log Induction/Resistivity 25 Blu 80 12920 Open 9/1/2009 MD Vision Service 13-Oct- 2009 og Induction/Resistivity 25 Blu 80 12920 Open 9/1/2009 TVD Vision Service 13-Oct- 2009 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments • ! DATA SUBMITTAL COMPLIANCE REPORT 2/912010 Permit to Drill 2080930 Well Name/No. PRUDHOE BAY UNIT V-05 Operator BP EXPLORATION (ALASYCA) INC Completion Status 1-OIL Current Status 1-OIL API No. 50-029-23391-00-00 MD 12962 TVD 9135 ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y-7N- Analysis Y`!'f~ Received? Completion Date 10/16/2008 Daily History Received? ~'-'-" Formation Tops ~'" UIC N Comments: Compliance Reviewed By: _. ~~ Date: ~~ ~ ~ '?. ~--U Z V BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 • by ~~CEI V ~1~ OCT 0 5 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB V-Pad Dear Mr. Maunder, ~i'eslcs Oil & Gas Cons. Cpmmif~>rlion Anchorage ~.~ - 0~3 ~^ ©~' Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB V- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator ~ ~ BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~~ Data V-pad 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al V-01 2040900 50029232100000 NA 2 NA 17 6/30/2009 V-02 2040770 50029232090000 NA 3 NA 43.4 7/11/2009 V-03 2022150 50029231240000 surface NA NA NA NA V-04 2061340 50029233220000 NA 1.5 NA 20.4 6/29/2009 V-05 2080930 50029233910000 NA 1.75 NA 20.4 5/10/2009 V-07 2071410 50029233720000 NA 0.25 NA 1.7 6/29/2009 V-100 2010590 50029230080000 NA 1.5 NA 20.4 5/9/2009 V-101 2020560 50029230740000 NA 3.75 NA 32.3 7/10/2009 V-102 2020330 50029230700000 NA 7.75 NA 98.2 8/7/2009 V-103 2021860 50029231170000 NA 0.5 NA 9.4 7/12/2009 V-104 2021420 50029231030000 NA 1.5 NA 21.3 7/11/2009 V-105 2021310 50029230970000 NA 2.25 NA 23.8 6/29/2009 V-106A 2041850 50029230830100 NA 1.75 NA 17 6/29/2009 V-107 2021550 50029231080000 NA 1.75 NA 13.6 7/11/2009 V-108 2021660 50029231120000 NA 1.5 NA 14.5 7/10/2009 V-109 2022020 50029231200000 NA 1.2 NA 10.2 6/30/2009 V-111 2031030 50029231610000 NA 1.5 NA 11.9 7/12/2009 V-112 2060200 50029233000000 NA 1.5 NA 15.3 5/10/2009 V-113 2022160 50029231250000 NA 2.5 NA 37.4 5/10/2009 V-114A 2031850 50029231780100 NA 2.5 NA 34 6/30/2009 V-115 2040270 50029231950000 NA 1.5 NA 13.1 5/9/2009 V-117 2030900 50029231560000 NA 1.25 NA 22.1 5/10/2009 V-119 2040410 50029232010000 NA 2 NA 18.7 6!30/2009 V-120 2041790 50029232250000 NA 1.5 NA 8.5 7/12/2009 V-121 2070360 50029233480000 NA 1.9 NA 17 6/30/2009 V-122 2061470 50029233280000 NA 1.5 NA 6.8 5/10/2009 V-tot 2012220 50029230540000 SC leak NA 4 NA 90.6 8/7/2009 V-202 2030770 50029231530000 NA 1.75 NA 12.8 7/11/2009 V-203 2051680 50029232850000 NA 2 NA 12.8 7/10/2009 V-204 2041310 50029232170000 NA 2 NA 22.1 6/30/2009 V-205 2061800 50029233380000 NA 1.8 NA 13.6 6/30/2009 V-207 2080660 50029233900000 NA 1.75 NA 18.28 1/9/2009 V-210 2042100 50029232310000 NA 2 NA 18.7 7/11/2009 V-211 2042200 50029232320000 NA 1.5 NA 13.6 7/10/2009 V-212 2051500 50029232790000 NA 1.2 NA 11.9 6/29/2009 V-213 2041160 50029232130000 NA 1.75 NA 6.3 5/9/2009 V-214 2051340 50029232750000 NA 0.5 NA 9.4 7/11/2009 V-215 2070410 50029233510000 NA 2.8 NA 30.6 6/30/2009 V-216 2041300 50029232160000 NA 1.5 NA 13.6 6/29/2009 V-217 2061620 50029233340000 NA 2.3 NA 25.5 6/30/2009 V-218 2070400 50029233500000 NA 2 NA 17.9 7/12/2009 V-219 2081420 50029233970000 NA 1 NA 16.2 7/12!2009 2080200 50029233830000 NA 1.75 NA 4b 3/9/2008 V-221 2050130 50029232460000 NA 0.8 NA 8.5 6/29/2009 V-222 2070590 50029233570000 NA 2.5 NA 21.3 7/11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 ...~~ ~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date 08/27/09 NO. 5336 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Color CD 14-12 AYTU-00048 USIT L 07/26/09 1 1 L2-06 ANHY-00101 PRODUCTION PROFILE 4 C G 07/23/09 1 1 03-20A AYKP-00034 CROSSFLOW CHECK IC 07/16/09 1 1 M-O6A AZCM-00034 PRODUCTION LOG - 07/13/09 1 1 P1-11 AYS4-00086 PRODUCTION PROFILE (p 07/21/09 1 1 02-11A AYS4-00084 LDL j 07/20/09 1 1 W-212 B3S0-00011 INJ PROFILE WNVFL - 07/20/09 1 1 W-215 AYKP-00036 INJ PROFILE W/RST-WFL ~ p- 07/25/09 1 1 W-207 AYKP-00035 INJ PROFILE W/RST-WFL ' -6C L 07/24/09 1 1 H-29A AYOO-00027 RST 'b 05/19/09 1 03-28 B14B-00067 RST % - ' L•.( 07/17/09 1 1 B-27A AXBD-00029 MCNL 06/12/09 1 1 C-15A AWJI-00038 MCNL - 06/25/09 1 1 O-04A V-05 B1JJ-00023 08AKA0024 MCNL ~ OH MWD/LWD T 05/28/09 10/13/08 1 1 1 1 07-O6B AWJI-00042 MCNL - 07/21/09 1 1 02-336 09AKA0149 OH MWD/LWD EDIT ~ 06/03/09 1 1 14-23A 09AKA0035 OH MWD/LWD EDIT 05/12/09 1 1 H-19B B2WY-00004 MCNL (REPLACEMENT) - L 05/07/09 1 PLtASt AGKNUWLtUIat FitGt1Y1 tST ,Il91VIIVU Hrvu tiCl VFIIVInll7 VIYC ~.Vri cNa.n rv: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~~ +~~~NILI~~~~~ N0.5310 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, Alt 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suites 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 07/14/09 Z-20 AP3O-00043 _ SBHP SURVEY 06!17/09 1 1 P2-31 AZCM-00029 LDL L(~ 06/17/09 1 1 12-03 AY1M-00022 SBHP SURVEY 06/15/09 1 1 Z-14B AYOO-00036 TEMP SURVEY & BHP 06/23/09 1 1 N-16 AP3O-00042 SBHP SURVEY 6 06/16/09 1 1 V~Q5,.;,,, 11999053 USIT 10/12/08 1 1 v'' N-11C _ AP3O-00042 SBHP SURVEY 06/16/09 1 1 °`-Y3-12 AY3J-00030 LDL _ 06/12/09 1 1 L1-30 AVY5-00049 PRODUCTION PROFILE~j bd 06/22/09 1 1 17-07B AYOO-00031 SBHP SURVEY / CS 06/11/09 1 1 05-258 AP3O-00040 SBHP SURVEY ~ 06/11/09 1 1 B-27A AXED-00028 MEM INJ PROFILE 06/12/09 1 1 11-36 B14B-00066 CROSSFLOW & IBP C 06/23/09 1 1 ~-21A B14B-00065 SBHP SURVEY "" 06/21/09 1 1 X-17 AYTU-00043 PROD PROFILE .- / 06/08/09 1 1 ~-25 AWLB-00018 LDL !»~ ~Q`j} - 05/28/09 1 1 02-33B AYTU-00033 USIT ! 05/19/09 1 1 P2-07 AVY5-00051 PRODUCTION PROFILE ~ ~ 06/25/09 1 1 13-03 AWLS-00020 LDL 06/01/09 1 1 3-17F/I(-30 B2NJ-00008 MEM INJ PROFILE 06/15/09 1 1 MPS-08 AYS4-00080 LDL 06/15/09 1 1 13-12 AV1H-00019 LDL ( 07/05/09 1 1 01-25 AYTU-00046 USIT ~kj 06/28/09 1 1 W-39A AWLB-00023 STATIC TEMP SURVEY ~- 06/26/09 1 1 Z-35 AYTO-00022 SBHP SURVEY ~ 06/29/09 1 1 Z-16 AV1H-00017 SBHP SURVEY ( ()~j 06/29/09 1 1 18-20 8581-00004 LDL - v ~ 06/27/09 1 1 Z-29 AVY5-00053 SBHP SURVEY ~~~ r ~)4~~ ~ ~~ ~ 07/03/09 1 1 L5-09 AYOO-00032 _ RST - j L ('~ 06/13!09 1 1 07-10A BiJJ-00022 MCNL -- d( 05/26/09 1 _-~~..r r.......v ..~rvv~ ..~v ~~r , v ~ vlaa l~lla~a Mlev nGl Vn1911Y1i VIYL VVri CNVfI 1 V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 II. 4 ~ `~, Page 1 of 1 Saltmarsh, Arthur C (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, February 17, 2009 1:42 PM To: Saltmarsh, Arthur C (DOA) Subject: PBU V-05 / PTD # 208-093 H i Art, Please reference the following well: Well Name: PBU V-05 Permit #: 208-093 API #: 50-029-23391-00-00 Top Perf MD: 10577' Bottom Perf MD: 12310' This well began Production on February 7, 2009 Method of Operations is: Pre-Produced Injector Date of Test: 02/12/09 Hours Tested: 12 24-Hour Rate /Oil-Bbl: 1,060 24-Hour Rate /Gas-Mcf: 606 24-Hour Rate 1 Water-Bbl: 169 Test Rate /Oil-Bbl: 530 Test Rate /Gas-Mcf: 303 Test Rate /Water-Bbl: 85 Choke Size: 128 Gas-Oil Ration: 572 Flow Tubing Pressure: 360 Casing Pressure: 1,440 Oil Gravity-API: Unavailable 2/17/2009 Date 01-09-2009 ;~~ Transmittal Number:93031 `~_ : ' .,~ ~' ~. ti r~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) .f you have any uestions, lease contact Dou las Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: V-05 Please Sign ancJ.l~eturn one copy of this transmittal. Thank Yc~a; i Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~, , "_~ ,:_~. ., ~,~_ ~,~, ~~ : ~va ~~~~ ; t ,tee~~~~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 9951.9-6612 V-OS Cement Slurry Yields ~ • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, February 26, 2009 12:43 PM To: 'Staudinger, Garret'; 'mtorrie@slb.com' Cc: Hobbs, Greg S (ANC); 'Tirpack, Robert B'; 'Hubble, Terrie L'; Stewman, Sondra D Subject: RE: V-05 Cement Slurry Yields ~~~ ^~~~ Garret and Maureen, Thanks for your assistance in resolving the numbers. It can be more than a little confusing at times. When a completion report {407) is filed, part of my review includes a comparison of the planned cementing operations versus the accomplished cementing operations. The basis of my comparison is the information filed with the permit application. If the sack count and yield supplied with the permit application is what is actually pumped, then reconciliation is not difficult. But when there are recipe differenceslchanges between what is contained in the permit and what actually goes down hole and the only information in the operations report is the slurry volume pumped, it makes reconciliation nearly impossible. As I indicated earlier, in order to avoid my sending a message for cementing information, I need 2 of the 3 parameters regarding what is actually pumped downhole; sack count, yield and total slurry volume. Keep me advised as to the resolution of this matter. Call or message with any questions. Tom Maunder, PE AOGCC `\z ~ From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] ~Z2 Q ~ W r ~~ 1,.~~~ Sent: Wednesday, February 25, 2009 11:00 AM ,.-A To: Maunder, Thomas E (DOA) ~~ a~_pq Subject: FW: V-05 Cement Slurry Yields Tom, Below is the response from Schlumberger on how the yield can vary on a certain cement blend. We are working with them to try and make this more consistent. Also, attached is the information on the V-05 cement jab on what what on the permit to what was actually pumped. As you can see, the volumes of cement pumped were the same on all intervals except the production hole. We wil! discuss solutions to this problem within our group to try and avoid this confusion in the future. I will keep you informed as to how we decide to go forward with this issue. Thanks, Garret From: Maureen Torrie [mailto:mtorrie@slb.com] Sent: Tuesday, February 24, 2009 1:47 PM To: Staudinger, Garret Cc: Tirpack, Robert B; 'Richard van der Tuin' Subject: RE: V-05 Cement Slurry Yields Hi Garret. As I mentioned, this has to due with whether we define a '"sack" as a sack of G cement, or a sack of blended CemCRETE cement {CemCRETE consists of G and two other particles}. This definition has a huge impact on the yield, which is measured in cuftlsack, but the actual total cement that we use is the same. This chart (based on V-05) shows that although the yields are different, the actual amount (in pounds and barrels} of cement is the same. CRETE field 2/26/2009 V-OS Cement Slurry Yields . • Page 2 of 2 sack of G sack of CemCRETE ppg 3/sk Ib G !sk Ib blend /sk 10.7 3.86 94 199.186 10.7 1.94 100 bbls slurry cult slurry "sacks" 388 2178.5 564 388 2178.5 1122 VEte used "sack of G" for the lab report, while the CemCAI~E used a '"sack of CemCRETE."' We know that this is a problem and have been working to make it mare consistent. I'm sorry that this problem affected you; but thanks for letting me know. I hope this explanation helps. Please let me know if you need more clarification. Maureen Maureen Torrie cta~~-i- ~ s:~.i Sep°~~~°~~ '"~;ct~~tis:: Work: 1-907-273-1765 Cell: 1-907-952-0445 2/26/2009 V-05i Cementing • Surface Hole Surface Hole Tail Intermediate Hole Intermediate Hole Production Hole Tail Lead Lead Tail Permit 388 bbls 85 bbls 180 bbls 38 bbls 56 bbls 491 sks 411 sks 426 sks 184 sks 262 sks 4.44 cf/sk 1.15 cf/sk 2.36 cf/sk 1.16 cf/sk 1.2 cf/sk Wellplan 388 bbls 85 bbls 183 bbls 38 bbls 56 bbls 491 sks 411 sks 426 sks 184 sks 262 sks 4.44 cf/sk 1.15 cf/sk 2.36 cf/sk 1.16 cf/sk 1.2 cf/sk CADS 388 bbls 84.2 bbls 183 bbls 38 bbls 56 bbls 1122 sks 408 sks 433 sks 183 sks 205 sks 1.94 cf/sk 1.16 cf/sk 2.36 cf/sk 1.16 cf/sk 1.53 cf/sk Field Blend 387 bbls 85 bbls 183 bbls 38.5 bbls 72 bbls 577 sks 408 sks 401 sks 186.4 sks 264 sks 3.86 cf/sk 1.17 cf/sk 2.56 cf/sk 1.16 cf/sk 1.53 cf/sk Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, February 25, 2009 9:13 AM To: 'Staudinger, Garret' Cc: 'Tirpack, Robert B'; 'Hubble, Terrie L' Subject: RE: V-05 (208-093) Garret, To follow-upon our discussion, in order to properly do my review I need two of the following 3 parameters concerning cementing operations, sack count, yield or total slurry volume. Thanks for calling, I look forward to your reply. Tom Maunder, PE AOGCC From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Tuesday, February 24, 2009 1:45 PM To: Maunder, Thomas E (DOA) Subject: RE: V-05 (208-093) Tom, ( just wanted to let you know that I am currently looking into this and am waiting to get some information back from Schlumberger. I should have an answer from you in a day or two. Thanks; Garret From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, February 23, 2009 9:03 AM To: Staudinger, Garret Cc: Tirpack, Robert B; Hubble, Terrie L Subject: V-05 (208-093) Garret, I am belatedly reviewing the completion report for this well. In the table below are listed the casing and cementing specifics for this well as listed on the permit application. There are differences in the as drilled versus as planned depths which are not of consequence, however using the cement yields provided in the permit application I cannot reconcile the sack count or volumes as provided in the 407/operations report. Thanks in advance. Tom Maunder, PE AOGCC Hole Pipe Top Bottom Lead Yield Tail Yield Surface 12.250 9.625 0 3125 491 4.44 411 1.15 Intermediate 8.750 7.000 0 10369 426 2.36 184 1.16 Liner 6.125 4.500 10219 12544 262 1.20 2/25/2009 _ ~,t~ STATE OF ALASKA "~'~ ALASK~IL AND GAS CONSERVATION'COM~iSSIC3-PJ /~~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG Pn Produced WAG Injector 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC zs.~os zoAAC zs.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Strati raphic 2. Operator Name: BP Exploration Alaska) Inc. 5. Date Comp., Susp., or Aba 10/ 008 .~~ 12. Permit to Drill Number 208-093 3. Address: P.O. Box 196612, Anchora e, Alaska 99519-6612 6. Date Spudded 9/22/2008 ~ 13. API Number 50-029-23391-00-00 " 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 10/13/2008 - 14. Well Name and Number: PBU V-05 4831' FSL, 1861' FEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: 4010' FSL, 680' FEL, SEC. 02, T11 N, R11 E, UM 8. KB (ft above MSL): 81..20' • Ground (ft MSL): 52.8' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Total Depth: 4325' FSL, 1611' FWL, SEC. 01, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 1287T 9118' Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 590442 y- 5969877 Zone- ASP4 10. Total Depth (MD+TVD) 12962' 9135' 16. Property Designation: ADL 028240 - TPI: x- 591563 y- 5974549 Zone- ASP4 ASP4 5974893 Z 593849 T D h 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: one- : x- y- otal ept TVD 18. Directional Survey ®Yes ^ No r n 19. Water depth, if offshore N/A ft MSL ): 20. Thickness of Permafrost ( 1737' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): G ro, MWD, DIR, GR / RES / PWD, NEU / AZM-DENS 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 11 1 I 1 " „ 1 1 1 x 1 1 7p - I I 1 1 - II ~ 11 1 1 " I 23. Open to production or inject ion? ®Yes ^ No 24. TueING RecoRD If Ye$, Ilst each I ntetVal Open d N i Si b SIZE DEPTH SET MD PACKER SET MD um er): on ze an (MD+TVD of Top 8 Bottom; Perforat 4 SPF Diameter 7/8" G 2 4-1/2", 12.61~f, L-80 10211' 10144' , un - MD TVD MD TVD 10577' - 10655' 8695' - 8948' ' ' ' ' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC.: 8980 - 8983 10675 - 10720 11524' - 11894' 8980' - 8971' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 11607' -11657' 8970' - 8966' ' ' ' ' Freeze Protect with 90 Bbls of Diesel 8964 - 8962 11670 - 11700 11711' -11901' 8962' - 8949' 12180' -12310' 8965' - 8992' 26. PRODUCTION TEST Date First Production: Not on Production Yet (Pre-Produced WAG Injector Method of Operation (Flowing, Gas Lift, etc.): WA Date of Test: Hours Tested: PRODUCTION FDR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Pf@SS. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core s A uired? Yes No Sidewall Core s A uired? Yes No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, 'rf needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~ is:, , rut+i:..~ None ~ ~~i16-D~ Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SI E ~'' t~* C[ ~` 44 6 ., ~L..f ~ 1 2008 ~~~a~- 28. GEOLOGIC MARKERS (LIST All FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top 28 5' 28 5' If yes, list intervals and formations tested, briefly summarizing test ' . . rf needed, and submit results. Attach separate sheets to this form, Permafrost Base 1808' 1765' detailed test information per 20 AAC 25.071. Ugnu 3217' 2930' Ugnu M 4714' 3984' None Schrader Bluff'N' 5071' 4233' Schrader Bluff'O' 5299' 4395' Base of Schrader Bluff 5760' 4765' HRZ 7545' 6298' Kalubik 7782' 6505' Kuparuk'D' 7882' 6590' Kuparuk 'C' 7891' 6597 Kuparuk 'B' 8044' 6727 Kuparuk 'A' 8182' 6845' Miluveach 8272' 6923' Kingak 9122' 7661' Sag River 10341' 8706' Shublik 10384' 8743' Eileen 10534' 8864' Sadlerochit 10571' 8891' Sadlerochit 11904' 8949' Sadlerochit 12177' 8964' Formation at Total Depth (Name): Sadlerochit 12177 8964' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys and aLeak-Off Test Summary 31. I hereby certify that the fore 'ng is true an correct to the best of my knowledge. ~1/~'~ t D e a Signed Sondra Stewman Title Drilling Technologist PBU V-0S 208-093 Prepared By NameMumber. Sondra Stewman, 564-4750 Well Number P Drilling Engineer: Garret Staudinger, 5644242 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 nsport when the downhole well design is changed. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, SaR 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 TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: 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 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Sutund Original Only BP EXPLORATION Page 1 of 1 .Leak-Off Test Summary Legal Name: V-05 Common Name: V-05 _ - ~ _ ~ _ -_ _ p ~ _ _ _ -- Test Date ~ Test T e Test De th MD Test De th VD AMW Surface Pressure Leak Off Pressure BHP EMW 9/27/2008 LOT 3,160.0 (ft) 2,890.0 (ft) 8.90 (ppg) 1,144 (psi) 2,480 (psi) 16.52 (ppg) 10/8/2008 LOT 10,344.0 (ft) 8,714.0 (ft) 8.50 (ppg) 1,133 (psi) 4,981 (psi) 11.00 (ppg) •i • Printed: 10/30/2008 11:28:19 AM • • BP EXPLORATION Page 1 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABORS 9ES Rig Number: Date 'From - To Hours Task Code NPT ',~ Phase Description of Operations 9/20/2008 15:00 - 16:00 1.00 MOB P PRE 16:00 - 19:00 3.00 MOB P PRE 19:00 - 22:30 3.50 MOB P PRE 22:30 - 00:00 1.50 MOB P PRE 19/21/2008 00:00 - 01:30 1.50 RIGU P PRE 01:30 - 03:00 1.50 RIGU P PRE 03:00 - 05:00 2.00 RIGU P PRE 05:00 - 09:30 4.501 RIGU P PRE 09:30 - 12:00 ~ 2.50 ~ RIGU ~ P ~ ~ PRE 12:00 - 15:30 3.50 RIGU P PRE 15:30 - 19:30 4.00 RIGU P PRE 19:30 - 20:00 0.50 RIGU P PRE 20:00 - 21:00 1.00 RIGU P PRE 21:00 - 22:00 1.00 RIGU P PRE 22:00 - 00:00 2.00 RIGU P PRE 9/22/2008 00:00 - 01:00 1.00 RIGU P PRE 01:00 - 01:30 0.50 RIGU P PRE 01:30 - 02:00 0.50 RIGU P PRE 02:00 - 02:30 0.50 RIGU P PRE 02:30 - 05:00 2.50 DRILL P SURF 05:00 - 06:30 ~ 1.50 ~ DRILL P ~ ~ SURF 06:30 - 12:00 ~ 5.50 ~ DRILL ~ P ~ ~ SURF PJSM with Peak Truck Drivers and NAD Toolpusher. -Move Pit Complex out from Rig. Move Rig off of well V-207. -Move camps and shops. Nipple Up Hydril and Diverter Line. -Level and place mats around well V-05. -Stage wellhead equipment and riser behind cellar on V-05. Move rig around pad from V-207 to V-05. Set Rig mats, Herculite, spot and level sub over V-05. Rig Accept for Operations on V-05 ~ 00:00 hrs on 9/21/08 ove in an spot it omplex. -Set mats and level. Finish nippling up diverter line. -Secure cellar -Hook up Interconnect Lines. -Take on water ~ 03:30 hrs. Install Riser and Flowline. -Mix Spud Mud -Load shed with drillpipe -Prep rig floor Spot MWD, Geologist, and Mud Shacks. -Set Geronimo Line -Trim and berm herculite Continue rigging up in cellar, mixing spud mud, and preping rig for spud. Pick up 4" DP and HWDP, and stand back in derrick. Function test Diverter Knife Valve and 20" Hydril -good test. -Witness of test waived by AOGCC Rep Chuck Sheve. Test witnessed by BP WSL Mark Staudinger and NAD TP Roy Hunt. Pick up BHA #1 components to rig floor from beaver slide. Hold Diverter and Rig Evacuation Drill with rig crew, WSL, NAD TP, and all third party personnel. PJSM. Make up BHA #1 as per Directional Driller. Continue to make up BHA #1 as per Directional Driller. PJSM. Rig up Sperry E-Line and Gyrodata. Hold Pre-Spud Meeting with Rig Crew, BP WSL, NAD TP, and all third party personnel. Fill hole and check for leaks -good. Pressure test surface equipment to 3000 psi -good. Spud V-05 and drill ahead from 108' to 270'. -475 gpm C~3 980 psi -45 rpm with 1 k TO and 50k Rot Wt. POH and stand back 2 stands 4" HWDP. -Make up 7" Drill Collars, Stabilizer, and Jars -RIH to 270' Drill ahead from 270' to 525'. -551 gpm C~ 1250 psi -45 rpm ~ 1.3k TO -25k WOB and 65k Rot Wt -30' wipes on connections -Run Gyro every 90' before connection - ost -150 bbls rom 270' to 330' Printetl: 10/30/2008 11:28:Lb AM • BP EXPLORATION Page 2 of 21 ...Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 9/22/2008 06:30 - 12:00 5.50 DRILL P SURF -Pre-Spud Meeting held with Sullivan's Crew during Pre-Tour Meeting. 12:00 - 13:00 1.00 DRILL P SURF Continue to directionally drill ahead from 525' to 678'. -551 gpm C~3 1250 psi -45 rpm ~ 1.3k TO -25k WOB and 65k Rot Wt -69k Up Wt, 62k Dn Wt -30' wipes on connections -Run Gyro every 90' before connection 13:00 - 14:00 1.00 DRILL P SURF CBU x3 C~ 550 gpm, 895 psi -45 rpm @ 1.8k TO -MW = 9.0 ppg, Viscosity = 350+ 14:00 - 15:30 1.50 DRILL P SURF POH from 678' to 270' -Pull from 678' to 581' and taking 25k overpull. -Pump out of hole from 581' to 270' ~ 200 gpm, 230 psi initial and increase to 500 gpm, 780 psi 15:30 - 17:30 2.00 DRILL P SURF Lay down BHA #1 as per Directional Driller 17:30 - 18:30 1.00 DRILL P SURF Clean and clear rig floor. 18:30 - 20:00 1.50 DRILL P SURF PJSM. Make up BHA #2 as per Directional Driller. -BHA #2 has PowerDrive Xceed Rota Steerable S stem 20:00 - 21:30 1.50 DRILL P SURF wit #2 rom 195' to 678' -RIH slick from 195' to 525' and tag obstruction. -Wash down from 525' to 642' @ 250 gpm, 230 psi initial and increase to 350 gpm, 388 psi. Unable to wash oast 642'. -Ream down from 642' to 678' ~ 375 gpm, 530 psi and 30 rpm with 2k-3.2k TO. 65k Rot Wt. 21:30 - 00:00 2.50 DRILL P SURF Drill ahead with BHA #2 from 678' to 820' -500 gpm C~3 950 psi on, 910 psi off -40 rpm ~ 3.4k TO on, 1.9k TO off -25k WOB -70k Up Wt, 60k Dn Wt -30' W ipes on Connections -Unable to achieve build with BSS. Adjust drilling parameters from 726' to 820' attem tin to achi v buil . 9/23/2008 00:00 - 01:00 1.00 DRILL P SURF Decision made to pull BHA #2 because unable to build angle. -Run Gyro and Rig Down Gyro and E-Line -CBU C~ 130 gpm, 150 psi 01:00 - 01:30 0.50 DRILL P SURF POH from 820' to top of BHA #2. -Pumped out of hole from 820' to 562' due to tight hole conditions C~ 300 gpm, 375 psi. -Continue to POH on elevators from 562' to top of BHA #2 01:30 - 02:30 1.00 DRILL P SURF Lay down BHA #2 as per Directional Driller. 02:30 - 03:00 0.50 DRILL P SURF Clean and clear rig floor. 03:00 - 04:30 1.50 DRILL P SURF Make u BHA #3 as er Directional Driller. 04:30 - 05:30 1.00 DRILL P SURF RIH from 220' to 820'. -Ream down from 760' to 820' ~ 307 gpm, 700 psi, 35 rpm, 1 k TO. 05:30 - 12:00 6.50 DRILL P SURF Directionally drill ahead from 820' to 1335' -587 gpm C~? 1846 psi off, 2050 psi on -45 rpm ~ 1.8k TQ off, 4.4k TO on with 25k WOB -30' wipes on connections 12:00 - 15:00 3.00 DRILL P SURF Continue to drill ahead from 1335' to 1780' -560 gpm C~ 1870 psi off, 1980 psi on rnntea: ivi~urmuo 11:ZC:LO HM BP EXPLORATION Page 3 of 21 Operations_Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABORS 9ES Rig Number: Date I From - To Hours ' Task Code NPT Phase Description of Operations 9/23/2008 12:00 - 15:00 3.00 DRILL P SURF -45 rpm C~? 1.9k TO off, 4.5k TQ on -25k WOB -88k Up Wt, 75k Dn Wt, 85k Rot Wt -30' wipes on connections 15:00 - 16:30 1.50 DRILL P SURF CBU 4x C~3 560 gpm, 1895 psi -40 rpm ~ 1.5k-1.8k TO -MW = 9.2 ppg, Viscosity = 350 16:30 - 18:30 2.00 DRILL P SURF POH from 1780' to top of BHA #3. -Encounter 15-20k overpull ~ 1090'. Pump out of hole from 1090' to 670' ~ 550 gpm, 1480 psi. -Pull slick from 670' to top of BHA #3. 18:30 - 21:00 2.50 DRILL P SURF Lay down BHA #3 as per Directional Driller. 21:00 - 21:30 0.50 DRILL P SURF Clean and clear rig floor. 21:30 - 22:30 1.00 DRILL P SURF Service Drawworks, Top Drive, and Crown. 22:30 - 00:00 1.50 DRILL P SURF Make up BHA #4 as per Directional Driller. -BHA #4 has PowerDrive Xceed Rotary Steerable System 9/24/2008 00:00 - 01:30 1.50 DRILL P SURF Continue to make u BHA #4 as per Directional Driller. -BHA #4 has PowerDrive Xceed Rotary Steerable System 01:30 - 02:00 0.50 DRILL P SURF RIH from 195' to 1780' -Shallow hole test MWD C~ 500 gpm, 1070 psi -good -Tag obstruction ~ 1058' and wash and ream down to 1275' ~ 325 apm, 515 psi and 60 rpm ~ 2k-4k TO -RIH slick from 1275' to 1532' and tag obstruction -Wash and ream down with same parameters from 1532' to 1560' -RIH slick from 1560' to bottom @ 1780' 02:00 - 12:00 10.00 DRILL P SURF Directionally drill ahead from 1780' to 2905' -653 gpm C~? 2656 psi -80 rpm ~ 4.6k TO on -30k WOB -98k Up Wt, 84k Dn Wt, 92k Rot Wt -30' wipes on connections -Intermittent Hydrates encountered from 2132' 12:00 - 14:00 2.00 DRILL P SURF Continue to drill ahead from 2905' to TD C~3 3170' -653 gpm ~ 2720 psi on -80 rpm @ 5.2k TO on, 2.9k TO off -28k WOB -101 k Up Wt, 85k Dn Wt, 92k Rot Wt -30' wipes on connections 14:00 - 16:00 2.00 DRILL P SURF CBU x3 C~3 650 gpm, 2695 psi -80 rpm ~ 2.8k TQ -MW in = 9.3+, MW out = 9.4, Viscosity in = 225, Viscosity out = 350 -Monitor Well -static 16:00 - 20:30 4.50 DRILL P SURF POH from 3170' to 1050' -Pull dry from 3170' to 2714' -pulling 15-20k over and hole swabbing -Pump out from 2714' to 1758' C~ 650 gpm, 2460 psi -Attempt to pull 1 stand dry, but pulling 25k over -Continue to pump out to 1280' -Backream from 1280' to 1050' ~ 650 gpm, 1750 psi and 80 rpm, 2.5k TO, 70k Rot Wt. 20:30 - 21:00 0.50 DRILL P SURF CBU x2 @ 650 pgm, 1750 psi and 80 rpm, 2.5k TO Printetl: 10/30/2008 17:18:"L5 AM • BP EXPLORATION Page 4 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task ~ Code NPT Phase Description of Operations 9/24/2008 20:30 - 21:00 0.50 DRILL P SURF -Reciprocate pipe from 1050' to 993' -Lots of clay and sand unloading over shakers. 21:00 - 22:00 1.00 DRILL P SURF RIH from 1050' to 3096' -RIH dry from 1050' to 1372' and tag obstruction -Wash and ream down from 1372' to 1471' ~ 350 gpm, 660 psi and 40 rpm, 2.5k TO -Continue to RIH slick from 1471' to 3096' 22:00 - 00:00 2.00 DRILL P SURF Wash down to TD @ 3170' and CBU x3 -654 gpm ~ 2810 psi -80 rpm C~ 3k TO -90k Rot Wt -Condition mud to 9.3 ppg and 250 viscosity -Clay coming back over shakers, but cleaned up after 2nd Bottoms Up 9/25/2008 00:00 - 02:00 2.00 DRILL P SURF POH from 3170' to top of BHA #4. -Encountered tight spots from 1940' to 1730' but able to work through. -112k Up Wt, 85k Dn Wt 02:00 - 04:00 2.00 DRILL P SURF Lay down BHA #4 as per Directional Driller. 04:00 - 04:30 0.50 DRILL P SURF Clean and clear rig floor. 04:30 - 06:00 1.50 CASE P SURF Rig up to run 9-5/8" 40# L-80 BTC casing. -Make dummy run with hanger -Make up Franks Fillup Tool -Rig up power tongs and scaffolding 06:00 - 13:00 7.00 CASE P SURF Run 9-5/8" 40# L-80 BTC Surface Casing as per running detail to 3129'. -Baker Lock Shoe Track Jts #1-3 -Dope BTC threads with BOL 2000 -Ave TQ = 9000 ft-Ibs -Ran 50 Bowspring Centralizers as per running detail. -138k Up Wt, 99k Dn Wt -Encountered tight spot ~ 1850', but worked through with no robp lams -Wash down from 3091' to 3129' C~ 160 gpm, 470 psi -Rig down Franks Tool 13:00 - 13:30 0.50 CASE P SURF Make up Casing Hanger and Landing Joint. -Set down on Landing Ring and make up Cement Head and equipment. 13:30 - 15:30 2.00 CEMT P SURF Circulate and condition mud C~1 224 gpm, 250 psi. -Condition mud to 9.4 ppg, PV = 84, YP = 18 -Reciprocate Pipe 10' Strokes 15:30 - 18:00 2.50 CEMT P SURF PJSM with SLB Cementers. Switch over to Schlumberger. -Pump 5 bbls of water. Pressure test lines to 3500 psi - OK. -Pump 50 bbls of 10.5 ppg of MudPush II @ 5 bpm, 200 psi. -Shut down and release bottom plug, positive indication plug left head. -Pump 387 bbls of 10.7 ppg DeepCrete lead cement ~ 6 bpm, 250 psi. -Pump 85 bbls of 15.8 ppg Class "G" tail cement @ 5-bpm, 260 psi. -Drop top plug, positive indication plug left head, and chase with 5 bbls H2O. Full returns throughout cement pumping. *Reciprocated pipe in 10' strokes PflfltBtl: 10/30/2008 11:Y8:'LS AM • • BP EXPLORATION Page 5 of 21 ..Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date ~ From - To ~ Hours Task Code NPT Phase Description of Operations 9/25/2008 18:00 - 19:30 1.50 CEMT P SURF Switch over to rig pumps and displace cement with total of 228 bbls 9.4 ppg Spud Mud (~ 5 bpm, 330 psi ICP, 780 psi FCP. -Slow pump to 2 bpm, 675 psi prior to bumping plug. -Bumped plug ~ 3285 strokes with 1210 psi and hold for 2 minutes. -Continue to pressure uq to 3500 psi for 30 minutes to test casing -good. -Bled off and checked floats -good. 'Reciprocated pipe 10' strokes while displacing. Landed casing on landing ring 200 bbls into displacement due to low slack off weight. 19:30 - 22:00 I 2.501 CEMT I P 22:00 - 00:00 I 2.001 DIVRTR I P 9/26/2008 ~ 00:00 - 01:30 ~ 1.50 ~ WHSUR P 01:30 - 03:30 2.00 BOPSU~ P 03:30 - 04:00 0.50 BOPSU P 04:00 - 06:00 2.00 BOPSU P 06:00 - 07:00 1.00 BOPSU~ P 07:00 - 08:00 1.00 BOPSU P 08:00 - 12:30 I 4.501 BOPSURP 12:30 - 13:30 I 1.001 BOPSUR P 13:30 - 15:30 ~ 2.00 ~ BOPSUp P 15:30 - 17:00 I 1.501 BOPSURP 17:00 - 20:00 3.00 BOPSU P 20:00 - 21:00 1.00 BOPSU P 21:00 - 22:00 1.00 BOPSU P 22:00 - 00:00 2.00 BOPSU P 9/27/2008 00:00 - 01:00 1.00 BOPSU P 9-5/8" casing shoe ~ 3160'. CIP C~ 18:40 hrs. Returned 10 bbls of cement. Full returns throughout job. SURF Rig down Cement Head and Casing Equipment -Flush Riser, Knife Valve, and Hydril SURF Nipple Down Diverter System -Nipple down riser and remove from cellar -Pick up and secure Hydril in cellar -Change out 20" flange to 16" flange SURF Bring wellhead equipment into cellar and install casing head. -Nipple Up Tubing Spool -Test void to 1000 psi for 10 minutes -good SURF Nipple up BOP stack. SURF Re-level sub and pits. SURF Install riser, mousehole, and double annulus valves. -Change out air boot and make up turnbuckles SURF Flush stack and flowline with ported sub. SURF Install test plug and rig up to test BOPE. -Fill stack and choke SURF Test BOPE to 4000 psi high, 250 psi low. -Test upper 3-1/2" x 6" and lower 2-7/8" x 5" VBR's with 4" test joint to 4000 psi high / 250 psi low -Test Annular Preventer with 4" test joint to 3500 psi high / 250 psi low -Witness of test waived by AOGCC rep Lou Grimaldi -Test witnessed by BP WSL Brian Buzby and NAD TP Kelly Cozby SURF Rig down and blow down all BOP testing equipment -Pull test plug and install wear ring SURF Service Top Drive -Adjust block height and check brake system -Replace broken stud on Iron Roughneck SURF Slip and cut 75' of drilling line. -Service blocks and crown SURF Single in Hole with 4" drill pipe to 2868' SURF CBU x1 C~ 465 gpm, 880 psi -Clabbered-up mud coming back over shakers. Cleaned up after bottoms up. SURF POH from 2868' and stand DP back in derrick. SURF Single in Hole with 4" drill pipe to 2400' SURF Continue to single in hole with 4" drill pipe from 2400' to 2900' Printetl: 10/30/2QV8 11:28:YS AM BP EXPLORATION Page 6 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABORS 9ES Rig Number: Date I From - To Hours Task Code NPT ~i Phase Description of Operations 9/27/2008 01:00 - 01:30 0.50 BOPSU P 01:30 - 02:30 1.00 BOPSU P 02:30 - 03:00 0.50 BOPSU P 03:00 - 07:30 4.50 DRILL P 07:30 - 08:00 0.50 DRILL P 08:00 - 10:00 2.00 DRILL P 10:00 - 12:30 2.50 DRILL P 12:30 - 13:00 I 0.501 DRILL I P 13:00 - 13:30 I 0.501 DRILL I P 13:30 - 00:00 I 10.501 DRILL I P 19/28/2008 100:00 - 12:00 12.00 DRILL P 12:00 - 19:30 7.501 DRILL P SURF CBU x1 C~ 600 gpm, 1100 psi. SURF POH from 2900' and stand back in derrick. SURF Clean and clear rig floor. INTi PJSM. Make up 8-3/4" Drilling BHA #5 as per Directional Driller. -Test communication between Ecoscope and Telescope tools ~ 500 gpm, 950 psi -good. POH and install source in Ecoscope. -Shallow hole test BHA l~ 320' with 500 gpm, 945 psi -good. INTi RIH with BHA #5 on 7 stands of 4" HWDP. INT1 Single in hole with BHA #5 on 4" Drill Pipe. INT1 Drill out shoe track and 20' of new hole from 3037' to 3190'. -Tagged cement stringers ~ 3037' and drilled to float collar ~ 3076'. -Drill out shoe track @ 516 gpm, 1097 psi, 60 rpm, 3.8k TO, 5k WOB. -Displace mud system to 8.8 ppg LSND while drilling out. -CBU ~ 3190' with same parameters. INTi Perform LOT -Leakoff ressure = 1144 si. EMW = 16.51 INT1 Establish initial benchmark ECD with PWD. INT1 INTi INTi 19:30 - 21:00 1.501 DRILL N RREP INT1 -Obtain initial drilling parameters and SPR's. Directionally drill from 3190' to 5050' -587 gpm ~ 1944 psi off, 2305 psi on -80 rpm ~ 4.7k TO off, 6.8k TO on -5-10k WOB -130k Up Wt, 95k Dn Wt, 114k Rot Wt -Backream 1 stand ~ drilling rate and ream down ~ 75% drilling rate on connections -Pumped high vis sweeps ~ 3615', 4286', and 4961'. Saw 30-40% increase in cuttings with each sweep Continue to drill ahead from 5050' to 6281' -587 gpm ~ 2510 psi off, 2700 psi on -80 rpm ~ 6.3k TO off, 7.9k TO on -5-10k WOB -162k Up Wt, 110k Dn Wt, 123k Rot Wt -Backream 1 stand ~ drilling rate and ream down ~ 75% drilling rate on connections -Pumped 40 bbl hi-vis sweep ~ 5565' and saw 40% increase in cuttings with sweep -Pump hi-vis sweep C~? 6187' and saw no increase in cuttings. -Calc ECD = 9.5 ppg, Act ECD = 10.2 ppg Continue to drill ahead from 6281' to 6956' -587 gpm ~ 2791 psi off, 3150 psi on -80 rpm ~ 6.9k TO off, 9.4k TO on -15k WOB -172k Up Wt, 112k Dn Wt, 138k Rot Wt -Pump hi-vis sweep C~ 6620' and saw 30% increase in cuttings -Begin spiking up mud weight to 9.6 ppg. Found pinhole leak in 4"mud line above Mud Pump #2. -Repair mud line leak with welder -Reciprocate pipe during repair -177k Up Wt, 118k Dn wt rnncea: wi~urzuu° i i:c°:c° nm BP EXPLORATION Page 7 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date I From - To Hours ' Task Code NPT Phase ', Description of Operations 9/28/2008 21:00 - 00:00 3.00 DRILL P INT1 Continue to drill ahead form 6956' to 7001' -587 gpm ~ 2960 psi off, 3348 psi on -80 rpm C~3 6.9k TO off, 9.5k TO on -15k WOB -177k Up Wt, 112k Dn Wt, 139k Rot Wt -Backream 1 stand C~3 drilling rate and ream down ~ 75% drilling rate on connections -Spike mud weight up to 9.8 ppg on the fly. -CECD = 10.27 ppg, AECD = 10.75 ppg 9/29/2008 00:00 - 12:00 12.00 DRILL P INT1 Continue to drill ahead from 7001' to 7786' -587 gpm ~ 3168 psi off, 3500 psi on -80 rpm C~ 7k TO off, 8.3k TO on -5-10k WOB -175k Up Wt, 125k Dn Wt, 145k Rot Wt -Backream 1 stand C~ drilling rate and ream down ~ 75% drilling rate on connections -Spike mud weight up to 10.2 ppg on the fly C~ 7200'. -CECD = 10.66 ppg, AECD = 11.29 ppg 12:00 - 17:00 5.00 DRILL P INTi Continue to drill ahead from 7786' to 8334' -524 gpm ~ 3452 psi off, 3748 psi on -80 rpm ~ 8.6k TO off, 10.3k TO on -5-15k WOB -180k Up Wt, 126k Dn Wt, 151 k Rot Wt -Backream 1 stand ~ drilling rate and ream down C~ 75% drilling rate on connections 17:00 - 18:30 1.50 DRILL N RREP INT1 Pulsation Dampener fitting on mud pump #2 washed out. -Repair fitting while reciprocating pipe with 252 gpm C~ 1046 psi. 18:30 - 00:00 5.50 DRILL P INTi Continue to drill ahead from 8334' to 8612' -524 gpm C~ 3369 psi off, 3680 psi on -80 rpm ~ 8.6k TO off, 10.4k TO on -5-15k WOB -191 k Up Wt, 125k Dn Wt, 154k Rot Wt -Backream 1 stand @ drilling rate and ream down C~1 75% drilling rate on connections -CECD = 10.65 ppg, AECD = 10.95 ppg 9/30/2008 00:00 - 03:00 3.00 DRILL P INT1 Continue to drill ahead from 8612' to 8857' -524 gpm @ 3733 psi off, 3950 psi on -80 rpm C~1 10.8k TO off, 11.3k TO on -5-15k WOB -210k Up Wt, 135k Dn Wt, 155k Rot Wt -Backream 1 stand ~ drilling rate and ream down @ 75% drilling rate on connections -CECD = 10.56 ppg, AECD = 11.16 ppg 03:00 - 11:00 8.00 DRILL N RREP INT1 Re lace cracked Fluid End #2 on Mud Pum # -Begin pumping out of hole from 8857' to 6199' ~ 280 gpm, 1050 psi -210k Up Wt, 135k Dn Wt 11:00 - 12:30 1.50 DRILL P INTi RIH from 6199' to 8760' 12:30 - 14:00 1.50 DRILL P INTi Wash down to 8857' and CBU x1 ~ 516 gpm, 3658 psi -80 rpm ~ 11.5k TO -Pump weighted sweep and saw 35% increase in cuttings 14:00 - 00:00 10.00 DRILL P INTi Continue to drill ahead from 8857' to 9334' Printed: 10/30/2008 11:28:25 AM A i BP EXPLORATION Page 8 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code' NPT ' Phase Description of Operations 9/30/2008 14:00 - 00:00 10.00 DRILL P INT1 -489 gpm ~ 3717 psi off, 3990 psi on 10/1/2008 00:00 - 00:30 0.50 DRILL N SFAL INT1 00:30 - 03:30 3.00 DRILL N SFAL INT1 03:30 - 08:30 5.00 DRILL N DFAL INT1 08:30 - 13:30 5.00 DRILL N DFAL INT1 13:30 - 14:00 I 0.501 DRILL I N I DFAL I INT1 14:00 - 16:00 2.00 DRILL N DFAL INT1 16:00 - 17:30 1.50 DRILL N DFAL INTi 17:30 - 18:00 0.50 DRILL N DFAL INT1 18:00 - 19:00 1.00 DRILL N DFAL INT1 19:00 - 21:00 2.00 DRILL N DFAL INT1 21:00 - 22:00 1.00 DRILL P INT1 22:00 - 22:30 0.50 DRILL P INT1 22:30 - 23:30 1.00 DRILL N DFAL INT1 23:30 - 00:00 0.50 DRILL N DFAL INT1 10/2/2008 00:00 - 02:30 2.50 DRILL N DFAL INTi 02:30 - 03:30 1.00 DRILL N DFAL INTi 03:30 - 04:30 1.00 DRILL N DFAL INT1 04:30 - 07:00 2.50 DRILL P INTi -80 rpm ~ 8.6k TO off, 9.8k TO on -5-10k WOB -217k Up Wt, 127k Dn Wt, 164k Rot Wt -Backream 1 stand @ drilling rate and ream down ~ 75% drilling rate on connections -CECD = 10.56 ppg, AECD = 10.84 ppg 'Increased LoTorq concentration to -2.25% and saw -2k ft-Ib TO reduction. Troubleshoot MWD tool. -Unable to get survey -too much interference. Replace Pulsation Dampener on Mud Pump #2 Troubleshoot high pump pressure. -While sending up survey, pump pressure spiked up. -Pump pressure spiking up while staging pumps up ~ 275 gpm. -Slowly stage pumps to 450 gpm, but pressure still spiking up. -Surface equipment seemed good. -Decision made to POH for BHA inspection. POH on elevators from 9334' to 9-5/8" shoe ~ 3160' with no problems. -155k Up Wt, 95k Dn Wt -MW in = 10.2 ppg, MW out = 10.2 ppg. Break circulation C~ 430 gpm, 2402 psi -feel vibration on drill pipe. -Drop dart and open circ sub. Circulate ~ 530 gpm, 1430 psi - no vibration in drill pipe. Continue to POH from 3160' to top of BHA #5. Lay down BHA #5 as per Directional Driller. -Found bad bearings in mud motor. Clean and clear rig floor. Pick up 8-3/4" Drilling BHA #6 as per Directional Driller RIH to 3125' -Shallow hole test MWD (~ 926' at 546 gpm, 1604 psi -good. Slip and cut 68' of drilling line. Service Top Drive, Blocks, Crown, and Drawworks. CBU x1 at shoe C~ 501 gpm, 1920 psi. -107k Up Wt, 82k Dn Wt. RIH from 3158' to 3801'. Continue to RIH from 3801' to 8944' -Break circulation at 5235' ~ 200 gpm, 700 psi -Break circulation at 7128' C~ 200 gpm, 1050 psi -Tight spot encountered C~3 8480'. Worked through with no robp lems; CBU x1 ~ 470 gpm, 3500 psi -80 rpm ~ 10-11 k TO -Mainly sand and some coal chunks comino over shakers. Wash down from 8944' to 9334' C~ 470 gpm, 3540 psi Drill ahead from 9334' to 9431' -525 gpm C~3 3900 psi on, 3750 psi off -80 rpm C~3 14k TO on, 12.8k TO off -5-10k WOB -240k Up Wt, 125k Dn Wt, 165k Rot Wt Printed: 10/30/2008 11:28:25 AM r BP EXPLORATION Operations Summary Report Page 9 of 21 Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task 'Code' NPT Phase Description of Operations .10/2/2008 04:30 - 07:00 2.50 DRILL P INT1 -CECD = 10.56 ppg, AECD = 10.7 ppg 07:00 - 10:30 3.50 DRILL N SFAL INT1 Change out Pop-off Valve on Mud Pump #1 -Valve malfunctioning and opening below set pop-off pressure 10:30 - 00:00 13.50 DRILL P INT1 Continue to drill ahead from 9431' to 10330' -508 gpm ~ 3690 psi off, 4000 psi on -80 rpm C~ 13k TO off, 13.5k TO on -5-10k WOB -230k Up Wt, 140k Dn Wt, 173k Rot Wt -Backream 1 stand ~ drilling rate and ream down C~ 75% drilling rate on connections -CECD = 10.55 ppg, AECD = 11.02 ppg 10/3/2008 00:00 - 01:00 1.00 DRILL P INT1 CBU x1 for sample ~ 10330' -506 gpm ~ 3760 psi -80 rpm ~ 14.5k TO -Drill 10' from 10330' to 10340' 01:00 - 02:00 1.00 DRILL P INT1 CBU x1 for sample ~ 10340' -506 gpm @ 3760 psi -80 rpm ~ 14.5k TO -Drill 10' from 10340' to 10350' 02:00 - 04:30 2.50 DRILL P INTi CBU x2 for samples @ 10350'. Call TD @ 10350' as per Geo. -506 gpm ~ 3760 psi -80 rpm C~3 14.5k TO -Clean returns over shakers. Very few 1"shale pieces seen over shakers. -Take last survey @ 10350' and establish SPR's -CECD = 10.49 ppg, AECD = 10.66 ppg. 04:30 - 06:00 1.50 DRILL P INTi Monitor well -static. POH from 10350' to 9025' (above Kingak) without problems. -MW in and out = 10.2 ppg. -255k Up Wt, 145k Dn Wt 06:00 - 12:00 6.00 DRILL P INTi Backream from 9025' to 8466', -While backreamina Cad 8555' drillstrina torqued ua and packed -RIH with 2 stands and stage pumps and rotary up to 489 gpm, 3200 psi and 80 rpm, 11.2k TQ, 160k Rot Wt -Slowly backream and work up with no problems to 8466' -Significant amounts of sand, clay, and small shale coming over shakers. 12:00 - 00:00 12.00 DRILL P INT1 Continue to backream out from 8466' to 7128' -500 gpm C~ 3060 psi -100 rpm C~ 10-12k TO -165k Up Wt, 120k Dn Wt, 135k Rot Wt -While backreaming ~ 7367', saw 3k ft-Ib TO increase and momentary reduction in return flow. RIH 30' and regained returns. Continue backreaming without further incidents. Saw no static losses. 'No recorded mud losses for day 10/4/2008 00:00 - 09:30 9.50 DRILL P INT1 Continue to backream out from 7128' to 6385' -500 gpm C~3 2809 psi -100 rpm ~ 6-7k TO -Adjust backream speed from 50-250 fph due to packoff -Ghost reamer in shoe ~ 6385' 09:30 - 10:00 0.50 DRILL P INT1 Continue to backream from 6385' to 6274' and CBU x1 Printetl: 10/302008 11:'LB:Yb AM ~ ~ BP EXPLORATION Page 10 of 21 Operations Summary Report Legal Well Name: V-05 Common W ell Name: V -05 Spud Date: 9/22/2008 Event Nam e: DRILL+C OMPLE TE Start : 9/20/2008 End: Contractor Name: N ABOBS ALASK A DRI LLING I Rig Release: 10/19/2008 Rig Name: N ABOBS 9ES Rig N umber: ~ Date From - To Hours Task Code N'PT Phase Description of Operations 10/4/2008 09:30 - 10:00 0.50 DRILL P INT1 6274'. -502 gpm ~ 2614 psi -100 rpm (~ 5.7k TO 10:00 - 11:00 1.00 DRILL P INT1 Service Top Drive, Crown, and Drawworks 11:00 - 13:00 2.00 DRILL P INT1 RIH from 6274' to 10282' with no problems -Make up Top Drive and wash down from 10282' to bottom ~ 10350' -500 gpm @ 3680 psi -80 rpm C~? 13k TO -240k Up Wt, 150k Dn Wt, 175k Rot Wt 13:00 - 16:00 3.00 DRILL P INT1 CBU x1 ~ 500 gpm, 3900 psi, 80 rpm, 13k TO -Pump 25 bbl hi-vis sweep -Monitor Well -Static 16:00 - 17:00 1.00 DRILL P INT1 POH from 10350' to 9040' (above Kingak) without problems. -MW in and out = 10.2 ppg 17:00 - 22:00 5.00 DRILL P INTi Pump dry job and continue to POH from 9040' to 3158' (bit inside shoe) 22:00 - 22:30 0.50 DRILL P INT1 Drop ball and rod, open circ sub, and CBU x2 -580 gpm @ 1550 psi -100 rpm ~ 2.6k TO -Sand and clay coming over shakers -cleaned up after x1.5 bottoms u 22:30 - 00:00 1.50 DRILL P INTi Continue to POH from 3158' to top of BHA #6. .10/5/2008 00:00 - 02:30 2.50 DRILL P INT1 Lay down BHA #6 as per Directional Driller 02:30 - 03:00 0.50 DRILL P INT1 Clean and clear rig floor 03:00 - 03:30 0.50 BOPSU P INT1 Flush BOP stack. 03:30 - 04:30 1.00 BOPSU P INT1 h n e out u er rams from 3-1/2" x 6" VBR to 7" Rams. -Pull wear ring and install test plug and 7" test joint. -Rig up to test rams 04:30 - 05:00 0.50 BOPSU P INTi Test Upper 7" Rams to 250 psi low/4000 psi high -good. -Test witnessed by BP WSL Mark Staudinger and NAD TP Brian Tiedemann. 05:00 - 06:00 1.00 BOPSU P INT1 Rig down testing equipment. 06:00 - 07:30 1.50 CASE P INT1 Rig up to run 7" 26# L-80 BTC-M x TCII Casing. 07:30 - 15:30 8.00 CASE P INT1 Run 7" 26# L-80 BTC-M Casing as per running order to 3165' -Dope BTC-M connections with Best of Life 2000 and TO to 8600 ft-Ibs -Fill pipe every joint with Franks Tool -Circulate down 3 minutes every 10 jts in cased hole. -RIH ~ 1.5 min per joint in cased hole. -Obtain Up and Dn Wts every 10 jts. 15:30 - 16:00 0.50 CASE P INT1 CBU x1.5 C~? 210 gpm, 380 psi. 16:00 - 22:30 6.50 CASE P INTi Continue to run 7" 26# L-80 BTC-M Casing as per running order from 3165' to 5739' -Dope BTC-M connections with Best of Life 2000 and TQ to 8600 ft-Ibs -Fill pipe every joint with Franks Tool -Circulate down for 3 minutes every 5 joints in open hole. -RIH (~ 2 min per joint in open hole. -Obtain Up and Dn Wts every 10 jts. 22:30 - 23:00 0.50 CASE P INT1 Rig up 7" TCII Torque Turn Equipment. 23:00 - 00:00 1.00 CASE P INT1 Run 7" 26# L-80 TCIIC_asing as per running order from 5739' F'(If1tBtl: lU/:3U/LUUtf 11:Lt1:L~HM BP EXPLORATION Page 11 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABORS 9ES Rig Number: Date .From - To Hours i Task Code ~I NPT Phase Description of Operations 10/5/2008 23:00 - 00:00 1.00 CASE P INTi -Dope TCII connections with Jet Lube Seal Gaurd and TO to 10,100 ft-Ibs -Fill pipe every joint with Franks Tool -Circulate down for 3 minutes every 5 joints -RIH ~ 2 min per joint -Obtain Up and Dn Wts every 10 jts 10/6/2008 00:00 - 09:00 9.00 CASE P INTi Continue to run 7" 26# L-80 TCII Casing as per running order from 5818' to 8927' -Dope TCII connections with Jet Lube Seal Gaurd and TO to 10,100 ft-Ibs -Fill pipe every joint with Franks Tool -Circulate down for 3 minutes every 5 joints ~ 4 bpm -RIH ~ 2 min per joint -Obtain Up and Dn Wts every 10 jts 09:00 - 10:00 1.00 CASE P INT1 CBU x1 while running 7" 26# L-80 TCII Casing from 8927' to 9087' -Circulate each joint down for 10 minutes. 10:00 - 13:30 3.50 CASE P INT1 Run 7" 26# L-80 TCII Casing through Kingak from 9087' to 10344'. -Took weight C~3 9185' and worked pipe down to 9725' -Ran casmq from 9725 to 10344' with no problems -275k Up Wt, 150k Dn Wt 13:30 - 14:00 0.50 CEMT P INT1 Rig down Frank's Fillup Tool and rig up Cement Head and circulation lines. 14:00 - 18:00 4.00 CEMT P INT1 Circulate and condition mud C~ 5 bpm, 1030 psi initial, 740 psi final. -PJSM with SLB Cementers while circulating. 18:00 - 19:30 1.50 CEMT P INT1 Switch over to Schlumberger Pumps. -Pump 5 bbls of 11.0 ppg Mud Push II. Pressure test lines to 4000 psi - OK. -Pump 35 bbls of 11.0 ppg of MudPush II C 5 bpm, 880 psi. -Shut down and release bottom plug, positive indication plug left head. -Pump 183 bbls of 12.0 ppg LiteCrete lead cement @ 5 bpm, 1600 psi. -Pump 38.5 bbls of 15.8 ppg Class "G" tail cement ~ 4 bpm, 1200 psi. -Drop top plug, positive indication plug left head, and chase with 5 bbls H2O. Full returns while pumping cement. 'Reciprocate pipe 3' strokes ~ surface. 19:30 - 21:30 2.00 CEMT P INT1 Switch over to rig pumps and displace cement with total of 388 bbls 10.2 ppg LSND. -Chase top plug C~ 247 gpm, 164 psi. Catch top plug ~ 2870 stks. -Slow pumps and displace @ 5 bpm, 790 psi initial, 450 psi final. -Bottom plug landed and sheared with 1400 psi ~ 3740 stks. -Resume displacement C~ 5 bpm, 790 psi initial, 1295 psi final. -Slow pumps C~ 5100 stks to 3 bpm, 1000 psi initial, 1550 final. -Slow pumps C~3 6010 stks to 2 bpm, 1400 psi initial, 1620 psi final. -Slow pumps ~ 6410 stks to 1 bpm, 1440 psi initial, 1500 psi final. Printed: 10/302008 11:2825 AM C~ BP EXPLORATION Page 12 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To i Hours Task Code NPT Phase Description of Operations 10/6/2008 19:30 - 21:30 2.00 CEMT P INT1 -Bumped plug @ 6690 strokes and pressure up to 2000 psi. Hold for 2 minutes. -Bleed off and checked floats -good. *Reciprocated pipe 3' strokes at surface while dis lacing. Lande casing in hanger 374 bl 6410 stks) into displacement. 7" casing shoe @ 10344'. CIP @ 21:10 hrs. Full returns throughout iob. 21:30 - 22:30 1.00 CEMT P INT1 Pressure test 7" casin to 4000 si for - d. 22:30 - 23:00 0.50 CEMT P INT1 Pump 3 bbls cement in 9-5/8" x Conductor Annulus to top off surface cement. -Cement top now 4" below 4" outlets on Conductor. 23:00 - 00:00 1.00 CEMT P INT1 Rig down cement head, landing joint and circulation lines. 10/7/2008 00:00 - 01:00 1.00 CEMT P INT1 Rig down 350 Ton Elevators and change out bails. 01:00 - 02:00 1.00 WHSUR P INT1 Install 7"x 9-5/8" packoff. -RILDS and Gland Packing Nuts. TO to 450 ft-Ibs. -Test Packoff to 5000 psi for 10 minutes -good. 02:00 - 02:30 0.50 CEMT P INT1 Freeze rotect the OA. -Perform Infectivity Test Down OA. -Pumped 90 bbls of mud followed by 75 bbls of dead crude. 02:30 - 05:00 2.50 BOPSU P INT1 Rig up to Test ROPE. -Flush BOP Stack -Install test plug and 4" test joint. -Change out Upper Rams from 7" Rams to 3-1/2" x 6" VBR. - i s ac an c o e wi res wa er. 05:00 - 10:00 5.00 BOPSU P INTi Test BOPE to 250 psi low / 4000 psi high. -Test Lower 2-7/8" x 5" VBR and Upper 3-1/2" x 6" VBR with 4" and 4.5" test Joint to 250 psi low / 4000 psi high. -Test Annular Preventer with 4" Test Joint to 250 psi low / 3500 psi high. -Test witnessed by AOGCC Rep John Crisp, BP WSL Blair Neufeld, NAP TP Kelly Cozby. 10:00 - 10:30 0.50 BOPSU P INT1 Lay down test joint. Install wear ring. Blow down lines. 10:30 - 14:00 3.50 DRILL P PROD1 PJSM prior to MU BHA and PJSM prior to loading ADN source. Bring drilling BHA components to rig floor. Make u 6-1/8" drillin BHA with: 6-1/8" insert bit, 1.5 degree bent housing motor, by pass sub, flex drill collar, stabilizer, DIR/GR/RES/DEN/NEU, flex collars, circ sub, jars, and HWDP. 14:00 - 15:30 1.50 DRILL P PROD1 Pick up 51 joints of 4" drill pipe singles. Shallow hole test the MWD tools at 1875' MD. -300 gpm, 1270 psi. Good test. 15:30 - 19:30 4.00 DRILL P PRODi RIH on 4" drill pipe out of the derrick to 9573' MD. -Fill pipe every 3000'. 19:30 - 21:30 2.00 DRILL P PROD1 Slip and cut 78' of drilling line at 9573' MD. -Clean and inspect drawworks. Service the top drive and crown. 21:30 - 23:00 1.50 DRILL P PROD1 PJSM with rig crew, WSL, and Tool Pusher for Stripping Drill. -Rig up TIW with IBOP. -Close bag and bring casing pressure to 200 psi. -Strip into well and bleed pressure through choke. Printed: 10/30/2008 11:28:25 AM BP EXPLORATION Page 13 of 21 .Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hotars Task ~I Code NPT ~ Phase Description of Operations 10/7/2008 21:30 - 23:00 1.50 DRILL P PROD1 -Test witnessed by BP WSL Kris Honas and Nabors Tool Pusher Brian Tiedemann. 23:00 - 00:00 1.00 DRILL P PROD1 Continue to RIH to 10,147' MD. 10/8/2008 00:00 - 02:30 2.50 DRILL P PROD1 Wash down to landing collar at 10,262' MD. -Tagged up on cement stringers at 10,248' MD. Drill out landin collar and cement down to 10,334' MD. -PU 198K, SO 120K, ROT 157K. -275 GPM, 50 RPM, 12K-13K TO. -Pump 1 bbl Lo-Torque and one bbl Lube 776 to reduce torque. 02:30 - 03:30 1.00 DRILL P PROD1 Displace well to 8.5 ppg FloPro SF. -Pump a 50 bbl high vis spacer with 20 gallons of Lo-Torque and 1 bbl of tube 776 followed by 8.5 ppg FloPro. -284 gpm, 2036 psi. -10k TO, 50 RPM Torque dropped down to 3.5K once new FloPro reached surface. -Obtain slow pump rates. 03:30 - 04:30 1.00 DRILL P PROD1 Drill out remaining cement and float shoe plus 20 tt of new formation to 10,364' MD. -PU 180K, SO 145K, ROT 167K. -275 GPM, 1824 psi off, 1860 psi on. -60 RPM, 4K TO off, 5K TQ on. 04:30 - 05:30 1.00 DRILL P PROD1 Circulate for 15 minutes. Perform FIT to 11.0 ppg EMW with 1133 psi surface pressure. -Chart test: Good FIT. -Bleed pressure and blow down lines. 05:30 - 17:00 11.50 DRILL P PROD1 Drill 6-1/8" production hole from 10,364'to 10,658' MD. -300 GPM, 1990 psi on 1930 psi off. -PU 190K, SO 145K. -20-30K WOB. -Actual Slide Time = 8.11 hrs. -Actual Rotate Time = 0.30 hrs. -Mud weight in/out = 8.5 ppg. Decide to POH for new bit and motor due to inability to obtain required dog legs for build interval. 17:00 - 18:00 1.00 DRILL P PROD1 Circulate bottoms up. -300 GPM, 1930 psi. -60 RPM, 3-4K TQ, -PU 190K, SO 145K, ROT 165K. 18:00 - 00:00 6.00 DRILL P PROD1 Monitor well for 10 minutes: Static. Mud weight in/out 8.5 ppg POH from 10,658' to 10,300' MD. Pump a dry job and blow down lines. Continue out of hole to 196' MD. 10/9/2008 00:00 - 02:30 2.50 DRILL P PROD1 Lay down 6-1/8" insert bit, 1.5 degree AIM motor, by pass sub, and M/LWD. Bit in poor condition with missing and broken buttons. Some of the undamaged buttons had rotated up to 90 degrees. -Bit grade: 4-5-BT-A-E-I-LT-BHA. Pick up a new 6-1/8" MX-R18DX bit, 1.83 degree bent housing motor with no inclination at bit or by pass sub, and a new Printed: 10/30/2008 11:28:25 AM BP EXPLORATION Page 14 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task 'Code NPT Phase 10/9/2008 00:00 - 02:30 2.50 DRILL P PROD1 02:30 - 03:00 0.50 DRILL P PROD1 03:00 - 03:30 0.50 DRILL P 03:30 - 08:30 5.00 DRILL P 08:30 - 12:00 I 3.501 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 10/10/2008 100:00 - 12:00 I 12.001 DRILL I P 12:00 - 00:00 I 12.001 DRILL I P 10/11/2008 100:00 - 13:00 I 13.001 DRILL I P 13:00 - 14:00 I 1.001 DRILL I P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Description of Operations M/LWD tool. RIH with 6-1/8" drilling BHA from 279' MD to 1211' MD. -Shallow hole test the MWD tools at 1211' MD. Service top drive, crown and drawworks. RIH with 6-1/8" drilling BHA from 1211' to 10,618' MD. -Wash down to bottom at 10,658' MD. Drill 6-1/8" production hole from 10,658' to 10,797' MD. -PU 190K, SO 145K, ROT 178K. -250 GPM, 1802 psi off, 2047 psi on. -20K WOB, 40 RPM, 4.5K TO off, 6.1 K TO on. -Survey every 30'. -Actual Rotate Time = 0.54 hrs. -Actual Slide Time = 0.95 hrs. Drill 6-1/8" production hole from 10,797'to 11,424' MD. -PU 210K, SO 148K, ROT 160K. -250 GPM, 1820 psi off, 2020 psi on. -10-20K WOB, 40 RPM, 5K TO off, 7K TO on. -Survey every 30'. -Backream 30' prior to connections. -Actual Rotate Time = 5.37 hrs. -Actual Slide Time = 2.97 hrs. -Mud weight in/out 8.6 ppg. Drill 6-1/8" production hole from 11,424'to 11,864' MD. -PU 195K, SO 135K, ROT 165K -250 GPM, 1820 psi off, 1954 psi on. -10-20K WOB, 40 RPM, 5K TO off, 7K TO on. -Survey every 30'. -Backream 30' prior to connections. -Actual Slide Time = 1.98 hrs. -Actual Rotate Time = 5.92 hrs. Drill 6-1/8" production hole from 11,864'to 12,146' MD. -PU 198K, SO 137K, ROT 165K -250 GPM, 1597 psi off, 1700 psi on. -20K WOB, 40 RPM, 6.3K TO off, 7K TO on. -Survey every 30'. -Backream 30' prior to connections. -Actual Slide Time = 3.28 hrs. -Actual Rotate Time = 4.27 hrs. -Mud weight in/out 8.6 ppg. Drill 6-1/8" production hole from 12,146'to 12,608' MD. -PU 201 K, SO 138K, ROT 165K -250 GPM, 1730 psi off, 1890 psi on. -15-20K WOB, 40 RPM, 6.5K TO off, 8-12K TO on. -Survey every 30'. -Backream 30' prior to connections. -Actual Slide Time = 1.13 hrs -Actual Rotate Time = 9.31 Unable to maintain weight on bit, increasing torque, and overpulls while picking up off bottom indicate bit is out of gauge. Prepare to POH for new bit. PROD1 Circulate 1.5x bottoms up. -252 GPM, 1750 psi. Printed: 10/30/2008 11:28:25 AM ~ ~ BP EXPLORATION Page 15 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours .Task Code NPT Phase Description of Operations 10/11/2008 13:00 - 14:00 1.00 DRILL P 14:00 - 17:00 3.00 DRILL P 17:00 - 21:00 I 4.001 DRILL I P 21:00 - 23:00 I 2.001 DRILL I P 23:00 - 23:30 23:30 - 00:00 10/12/2008 00:00 - 01:30 01:30 - 08:30 0.50 DRILL P 0.50 EVAL P 1.50 EVAL P 7.00 EVAL P 08:30 - 09:30 I 1.001 EVAL I P 09:30 - 11:00 I 1.501 DRILL I P 11:00 - 12:00 1.00 DRILL P 12:00 - 16:30 4.50 DRILL P 16:30 - 17:00 0.50 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 19:30 1.50 DRILL P 19:30 - 20:30 ~ 1.001 DRILL P 20:30 - 00:00 I 3.501 DRILL I P PROD1 -40 RPM, 6.5K TO. PROD1 Mud weight in/out 8.5 ppg. Monitor well for 15 minutes: Static. POH from 12,608' to 11,920' MD. -Overpull of 20-30K. -PU 217K, SO 150K. Backream from 11,910'to 11,854' MD. -235 GPM, 1550 psi, 40 RPM, 6-12K TO. Continue to pull out of hole to 10,331' MD on elevators. PRODi Monitor well at 7" shoe: Static. Mud weight 8.5 ppg. Pull out of hole to 279' MD. PROD1 PJSM. Stand jars and flex collars back in the derrick. Lay down MWD, motor, and 6-1/8" bit. Bit 1/2" under gauge. All outside cutters broken off. -Graded: 4-8-BT-G-E-4-W T-P R. PROD1 Clean and clear the rig floor. OTHCMP PJSM with rig crew and SLB E-line crew. Bring SLB tools to rig floor. OTHCMP PJSM Rig up SLB E-line. OTHCMP Make up USIT/CBL tools. RIH with logging tools to 7" casing shoe. Log 7" casing in cement evaluation mode from 10,330' MD to Top of Cement at 3300' with stringers to 2650' MD. OTHCMP ay own ogging too s. Rig down the E-line unit. Clear and clean the rig floor. PROD1 PJSM. Make up 6-1/8" drilling BHA with 6-1/8" insert bit, 1.15 degree bent housing motor, DIR/GR/RES/DEN/NEU M/LWD tools, Baker circ sub, and Jars. PROD1 Pick up 12 joints of 4" drill pipe to reach TD. PROD1 RIH with 6-1/8" drilling BHA from 651'to 1119' MD. Shallow hole test the MWD tools. -249 GPM, 823 psi: Good test. Continue to RIH to 10,321' MD. -Fill pipe every 3000'. PROD1 Service the top drive, crown and drawworks. PROD1 Slip and cut 57' of drilling line. PROD1 Run in open hole from 10,321'to 12,136' MD. -Took 10-20K periodically while running in from 11,500' to 11,900' (did not have to work pipe to get by). PROD1 Make up to top drive and Wash down from 12,136'to 12,608' MD. -250 GPM, 1919 psi, 60 RPM, 6.6K TO. PROD1 Drill 6-1/8" production hole from 12,608' to 12,725' MD. Printed: 10/30/2008 11:28:25 AM ~ ~ BP EXPLORATION Page 16 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date ;From - To Hours ' Task Code ! NPT Phase bescription of Operations 10/12/2008 20:30 - 00:00 3.50 DRILL P PROD1 -PU 199K, SO 140K, ROT 166K. 110/13/2008 100:00 - 04:30 I 4.501 DRILL I P 04:30 - 05:00 0.50 DRILL P 05:00 - 17:00 12.00 DRILL P 17:00 - 18:30 ~ 1.50 ~ DRILL ~ P 18:30 - 19:30 ~ 1.00 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 19:30 - 00:00 I 4.501 DRILL I N I RREP I PROD1 10/14/2008 100:00 - 04:30 I 4.501 DRILL I N I RREP I PROD1 04:30 - 08:30 4.00 DRILL P PROD1 08:30 - 11:00 2.50 DRILL P PROD1 -250 GPM, 1925 psi on, 1818 psi off. -15-20K WOB, 60-80 RPM, 7K TO on, 6K TO off. -Survey every 30'. -Backream 30' prior to connections. -Actual Slide Time = 0.33 hrs. -Actual Rotate Time = 1.48 hrs. -Mud weight in/out = 8.6 ppg. Drill 6-1/8" production hole to 12,950' MD. -TD called by geologist at 12,950' MD, 9131' TVD. - 201 K, SO 138K, ROT 165K. -250 GPM, 2045 psi on 1929 psi off. -10-20K WOB, 80 RPM, 5.5K TO off, 7.8K TO on. -Survey every 30'. -Backream 30' prior to connections. -Actual Slide Time = 0 hrs. -Actual Rotate Time = 4.26 hrs. -Mud weight 8.6 ppg in/out. Circulate one open hole annular volume. -250 GPM, 1850 psi. Backream /MAD pass out of the hole from 12,950' to 10,344' MD. -600 ft/hr, 80 RPM, 5.3K TO. -250 GPM, 1810 psi. -Reduce speed to 300 fUhr from 12,740' to 12,600' due to failed logs while drilling. -No rotation from10,845' to 10,680' due to high doglegs. Drop ball and open circulation sub inside 7" shoe. Circulate 1.5x bottoms up. -404 GPM, 1515 psi, 70 RPM, 5.2K TO. -Reciprocate pipe 90' while circulating. Monitor well: Static. Mud weight in/out 8.5 ppg. Pump a dry job and blow down lines. POH from 10,321' MD to 9154' MD. -PU 200K, SO 150K. Excessive noise heard in drawworks. -Trouble shoot problem. -Replace clutch handle and air couplings due to air leaking by believed to be keeping clutch partially engaged. Did not solve the drawworks had extensive wear. onUnue to work on drawworks. -Discover a blockage in the line supplying lubrication to the worn brass ring in the drawworks. -Change oil in drawworks to remove brass pieces off damaged ring. -Replace the blocked lubrication line. -Install a new brass ring. Continue to POH from 9154' to 280' MD with 6-1/8" drilling BHA. PJSM with SLB and rig crew. Printed: 10/30/2008 11:28:25 AM i • BP EXPLORATION Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date From - To Hours Task Code ~` NPT Start: 9/20/2008 Rig Release: 10/19/2008 Rig Number: Page 17 of 21 ~ Spud Date: 9/22/2008 End: Phase Description of Operations 10/14/2008 08:30 - 11:00 2.50 DRILL P PROD1 Lay down 6-1/8" drilling BHA bit graded: 1-2-WT-A-E-I-ER-TD. Clean and clear the rig floor. 11:00 - 12:00 1.00 CASE P RUNPRD Rig up 4.5", IBT-M liner running equipment. 12:00 - 17:30 5.50 CASE P RUNPRD Run in hole with 4.5", 12.6#, L-80, IBT-M liner to 2875' MD. -Bakerlok shoe joints. -Check that floats are holding. -Use Best-O-Life 2000 pipe dope. -Average make-up torque 3400 ft-Ibs. -run 3 centralizers every 2 joints. -Make up Baker 5"x7" HMC liner hanger and ZXP packer. 17:30 - 18:00 0.50 CASE P RUNPRD Circulate 1.5x liner volume. -208 gpm, 239 psi. -PU 69K, SO 67K. 18:00 - 00:00 6.00 CASE P RUNPRD Continue to RIH with 4.5", 12.6#, L-80, IBT-M liner on 4" drillpipe. -RIH to 10,258' MD. -Break circulation every 1000' at 5 bpm. 10/15/2008 00:00 - 00:30 0.50 CASE P RUNPRD Make up a swivel valve with 1502 connection, cement head, and two TIW valves to a drill pipe pup and set back on the pipe skate for later use. 00:30 - 01:00 0.50 CASE P RUNPRD Circulate bottoms up at the 7" casing shoe prior to entering open hole. -208 GPM, 725 psi. -PU 188K, SO 142K. 01:00 - 03:30 2.50 CASE P RUNPRD Run into open hole with the 4.5", 12.6#, L-80, IBT-M liner to 12,928' MD. -took 35K at 11,687' MD, work pipe three times to get by. -Broke circulation and continued in hole with normal SO weight of 135K. 03:30 - 04:30 1.00 CASE P RUNPRD Make up cement head with TIW valves and swivel to drill pipe and top drive. -Rig up cementing lines from rig pumps and Dowel to 1502 swivel. -Wash down to 12,950' at 2 bpm, 700 psi. -Tagged up on bottom 11 feet dee . 04:30 - 12:00 7.50 CEMT P RUNPRD Stage up to cementing rate with rig pumps over -30 minutes. -2 bpm, 644 psi. -3 bpm, 750 psi. -4 bpm, 900 psi. -5 bpm, 1225 psi. -Pressure increased to 1400 psi after circulating at 5 bpm, reduced rate and worked i e. Taking weight on up and down stroke. Continue to partially pack off. PU to as much as 350K, SO to as little as 50K. Circulate at 93 gpm, 1090 psi for -6 hrs bring rate up as packoffs allowed. Injected 162 bbls into formation over 6 hrs. -Changed cementing line to a longer hose to allow pipe to be reci rocated more than 2 ee . 12:00 - 14:00 2.00 CEMT P RUNPRD Continue work pipe with improved pick up and slackoff weights. Brought circulating rates up to 4 bpm, 892 psi without packing off. Printed: 10/30/2008 11:28:25 AM ~ ~ BP EXPLORATION Page 18 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date I From - To '. Hours ! Task I Code I NPT 10/15/2008 12:00 - 14:00 2.00 CEMT P 14:00 - 15:00 1.00 CEMT P 15:00 - 16:30 1.501 CEMT P Phase ! Description of Operations RUNPRD -Began batch mixing cement at 12:30. RUNPRD Swap to Schlumberger's pumps. -Pump 5 bbls of mud push and test lines to 4500 psi for 5 min. -Bled pressure and pumped total of 30 bbls of 10.2 ooa mud _ push at 3 bpm, 686 psi. -Pumped 72 bbls of 15.8 ppg class G cement at 3 bpm, 700 psi. RUNPRD Flushed cementing lines by pumping down top drive through cement lines, then flushed SLB lines. Removed cementing line and connected a blanking plug to the 1502 connection on the swivel. Opened TIW valves and kicked out the drill pipe dart with 45 bbl pert pill plus 90.5 bbls of 8.5 ppg drilling mud. -Displaced cement at 4 bpm. -Reciprocate pipe during displacement. -Drill pipe dart latched after 95.6 bbls and sheared with 2100 psi. Continued displacing at 3 bpm reducing rate to 2 bpm prior to bumping the plug. -Bumped plug after 136.5 bbls displaced -Full returns durino cement iob. -Increased pressure to 3500 psi, setting the liner hanger. -Slack off 50K to verify hanger erigaged. -Rotate 15 turns to the right to release C-2 running tool. -Bring pump pressure up to 1000 psi and pick up to expose the dogs on the C-2 tool. -Note a pressure drop and circulate 20 bbls to move excess cement off the liner top. -Slack off 50K on the liner top to set ZXP packer. Good indication the packer set. -Rotate pipe at 23 RPM and set down 50K on liner top to ensure weight transfer. -PU 35' pulling C-2 tool out of Liner Tieback. 16:30 - 18:00 1.501 CASE P Top of 4.5" liner tieback sleeve at 10,194' MD. RUNPRD Circulate bottoms up. -504 gpm, 2242 psi. 20 bbls of good cement in returns. 18:00 - 00:00 I 6.001 CASE I P 10/16/2008 100:00 - 01:00 I 1.00 I CASE I P Swap the well over to clean 8.5 ppg brine. 364 gpm, 1353 psi. RUNPRD Lay down cement head with swivel and TIW's. Monitor well: Static. Brine weight 8.5 ppg. POH with C-2 running tool and lay down. -Dogs sheared on running tool indicating weight reached liner top packer. RUNPRD Clean and clear the rig floor. Bring SLB pert running equipment to rig floor. Rig up pressure testing equiment. Pressure test the 4.5", 12.6#, L-80, IBT-M liner to 4000 psi for Printed: 10/30/2008 11:28:25 AM ~ ~ BP EXPLORATION From - To Hours Legal Well Name: V-05 Common Well Name: V-05 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date 10/16/2008 Task ;Code NPT Phase 00:00 - 01:00 1.001 CASE I P 01:00 - 02:00 I 1.00 02:00 - 06:00 I 4.00 06:00 - 17:30 I 11.50 17:30 - 18:30 I 1.00 18:30 - 19:30 1.00 19:30 - 00:00 4.50 10/17/2008 00:00 - 02:00 2.00 P 02:00 - 04:00 2.00 P 04:00 - 06:00 I 2.00 I P P P P P P P P P P 06:00 - 07:30 1.50 P 07:30 - 10:30 3.00 P Operations Summary Report P P Page 19 of 21 Spud Date: 9/22/2008 End: Description of Operations RUNPRD 30 minutes and chart. -Pressure bled off 25 psi in the first 15 minutes, 0 psi in the second 15 minutes. -Good test. OTHCMP Rig up to run 2-7/8" perforation guns, PAC drill pipe, and 2-7/8" FOX pipe. PJSM with SLB Perf hands and rig crew on making up guns. OTHCMP Make up 2-7/8" perforation guns, 2-7/8" PAC drill pipe, and 2-7/8" FOX pipe. -Use dog collars at each connection. Continue in hole on 4" drill pipe to 12.865' MD and tag PBTD. OTHCMP POH to place guns on depth at 12311' MD. PJSM with SLB pert hands. Initiate firing sequence. Perforate 593 feet with 2-7/8", 4 spf, 2906 PowerJet Omega ~ guns over the following intervals: 10,577' to 10,655' MD: Zone 46P-45P 10,675' to 10,720' MD: Zone 44P 11,524'to 11,594' MD: Zone 45P 11,607'to 11,657' MD: Zone 45P 11,670' to 11,700' MD: Zone 45P 11,711'to 11,901' MD: Zone 46P ~ 12,180'to 12,310' MD: Zone 46P-45P Felt a good indication that guns fired on the rig floor. i 2-1/2 bbl loss just after guns fired. OTHCMP POOH from 12,310 to 10,500 MD putting guns above top pert. No losses noted, correct displacement. OTHCMP CBU, 208 GPM, 85 SPM, 650 psi, no losses. OTHCMP Monitor well, static. Brine weight in/out 8.5 ppg. LDDP from 10,500 to 7086. Displacement correct. OTHCMP POH laying down 4" drill pipe from 7086' to 2789' MD. OTHCMP Change out elevators and make up a floor safety valve. POH laying down 2-7/8" FOX pipe to 1768'. OTHCMP Change out elevators. PJSM for laying down perforating guns. Lay down pert guns to 1580'. OTHCMP Lay down 2-7/8" PAC drill pipe to 815' MD. OTHCMP Lay down 2-7/8" perforation guns to surface. -Verified all nuns fired orooerly. 10:30 - 11:30 1.00 PERFO P OTHCMP Lay own running too s an c ear and clean the rig floor. 11:30 - 12:30 1.00 PERFO P OTHCMP Bring completion running tools to rig floor. 12:30 - 14:00 1.50 PERFO P OTHCMP RIH with 47 stands of 4" drill pipe out of the derrick. 14:00 - 17:00 3.00 PERFO P OTHCMP POH laying down 141 joints of 4" drill pipe. 17:00 - 17:30 0.50 PERFO P OTHCMP Pick up a test joint and retrieving tool. RIH and pull wear ring. 17:30 - 18:00 0.50 PERFO P OTHCMP Flush the stack with a jetting tool. Function rams and annular. Re-flush stack. 18:00 - 18:30 0.50 BUNCO RUNCMP Rig up to run 4.5", 12.6#, L-80, TCII tubing. a e a ummy run wit t o to mg anger. 18:30 - 20:30 2.00 BUNCO RUNCMP Rlg up Torque turn tools. 20:30 - 00:00 3.50 BUNCO RUNCMP PJSM with nabors casing hand, Baker hand and rig hands. RIH with 4.5", 12.6#, L-80, TCII completion including: Start: 9/20/2008 Rig Release: 10/19/2008 Rig Number: Printed: 10/30/2008 11:28:25 AM ~ ~ BP EXPLORATION Page 20 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code I NPT I! Phase Description of Operations 10/17/2008 20:30 - 00:00 3.50 BUNCO RUNCMP WLEG XN nipple X nipple with RHC-M plug Baker S-3 packer X nipple 4.5"x1"GLM 24 joints of 4.5" tubing at end of tour. ~ 10/18/2008 ~ 00:00 - 13:30 ~ 13.501 BUNCO 13:30 - 15:00 I 1.501 RU -Bakerlok all connections below the packer. -Make up each connection to 3850 ft-Ibs (optimal torque). -Verify running order of X and XN nipples. -Verify location of RHC-M plug. -Use Jet Lube Seal Guard on all connections. RUNCMP Continue to RIH with 4.5", 12.6#, L-80, TCII completion. -Use Jet Lube eal uar on a connections. l -Torque each connection to 2850 ft-Ibs. -Run GLM #2 after joint 41 -Run GLM #3 after joint 88 with DCK-2 shear valve. -Run GLM #4 after joint 159. -Run X landing nipple after joint 193. PU 155K SO 110K ~ 10,172' MD. RUNCMP RIH and tag the No-Go at 10,217' MD, _11.4' inside the liner top tieback receptacle. - pace ou u ing with three pup joints (19.74', 2.00', 9.75'). -Land tubing and run in lock down screws with 450 ft-Ibs of torque. Bottom of tubing WLEG at 10,211' MD (5-1/2 feet inside 15:00 - 17:00 2.00 17:00 - 17:30 0.50 17:30 - 19:30 2.00 19:30 - 21:00 I 1.50 P P RUNCMP UNCMP Reverse circulate 154 bbls of clean 8.5 ppg seawater. Reverse 67 bbls of corrosion inhibited 8.5 ppg seawater. Reverse 121 bbls of clean 8.5 ppg seawater to spot the corrosion inhibitor from the packer to the DCK-2 shear valve. -3 bpm, 275 psi. Rig down the circulating lines and drop the 1-5/16" ball and rod. Back out the landing joint and lay down. P RUNCMP Bring tubing pressure up to 4000 psi to set the Baker S-3 production packer. -Hold pressure at 4000 psi for 30 minutes and chart. -Pressure e o 100 psi in the first 15 minutes, 50 psi in the second 15 minutes: Good test. -Reduce the tubing pressure to 2500 psi and hold. -Brin the tubing x 7" annulus ressure u to 4000 si. -Hold annulus pressure at 4000 psi and chart for 30 minutes. -Annulus bled off 100 psi in the first 15 minutes, 50 psi in the second 15 minutes: Good test. -Bled annulus pressure to zero followed by the tubing pressure. -Increased the annulus pressure to 2100 psi to shear the DCK-2 valve. -Pumped 3 bbls down the annulus side at 3 bpm, 1350 psi. -Pumped 3 bbls down the tubing side at 3 bpm, 1250 psi. P RUNCMP Drain the stack. Printed: 10/30/2008 11:28:25 AM • BP EXPLORATION Page 21 of 21 Operations Summary Report Legal Well Name: V-05 Common Well Name: V-05 Spud Date: 9/22/2008 Event Name: DRILL+COMPLETE Start: 9/20/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/19/2008 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task I' Code ~' NPT Phase Description of Operations 10/18/2008 19:30 - 21:00 1.50 BOPSU P RUNCMP Blow down all lines. 21:00 - 00:00 3.00 BOPSU P 10/19/2008 00:00 - 02:00 2.00 WHSUR P 02:00 - 04:00 2.00 WHSUR P 04:00 - 05:00 1.00 WHSUR P 05:00 - 05:30 0.50 BUNCO 05:30 - 06:30 1.00 BUNCO 06:30 - 08:00 1.50 WHSUR P 08:00 - 09:00 1.00 WHSUR P 09:00 - 10:00 1.00 WHSUR P 10:00 - 11:00 1.00 WHSUR P 11:00 - 12:00 I 1.001 WHSUR I P Dry rod a TWC with FMC. - est rom below to 1000 psi for 5 minutes: Good test. RUNCMP Remove all rams from stack. RUNCMP Finish removing rams from stack. Nipple down riser and air boots. Nipple down BOP stack and set back on stump. RUNCMP Nipple up adaptor flange and double master valves (Tree to be installed post rig). -Test metal to metal seal on adaptor to 5000 psi for 10 minutes. RUNCMP Rig up Drill Site Maintenance lubricator and test to 1,000 psi u t e RUNCMP PJSM with Little Red and rig crew. Rig up Little Red Hot Oil and test lines to 2500 psi RUNCMP Freeze protect IA to 2500' tvd. with 90 bbls of 80 deg diesel ~ 2 bpm initial circu ating pressure 900 psi final circulating pressure 1200 psi. RUNCMP U-tube diesel. Prep floor for move. RUNCMP Rig up DSM lubricator and test to 1000 psi. Install BPV and test from below to 1,000 psi. Ri down Little Red. RUNCMP Install V/R plugs and secure the tree. RUNCMP Set top drive down on rig floor with brake set. Clean under pipe racks. RUNCMP Bridle up and continue to prep rig floor. Release rig from V-05i @ 12:00 on 10/19/2008 Printed: 10/30/2008 11:28:25 AM k~~ A~~~ ~~ ~..:~ V-05 S u Report Date: November 3, 2008 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure /Slot: V-Pad / Plan V Slot (S-B) Well: V-05 Borehole: V-05 UWI/APlfi: 500292339100 Survey Name /Date: V-05 /September 23, 2008 Tort /AHD / DDI / ERD ratio: 309.092° / 7635.86 ft / 6.525 / 0.836 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LaULong: N 70.32744209, W 149.26652438 Location Grid NIE Y/X: N 5969876.510 ftUS, E 590442.300 ftUS Grid Convergence Angle: +0.69066832° r Report Survey /DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 10.000° Vertical Section Origin: N 0.000 ft, E 0.000 ft TVD Reference Datum: Rotary Table TVD Reference Elevation: 61.20 ft relative to MSL Sea Bed /Ground Level Elevation: 52.70 ft relative to MSL Magnetic Declination: 22.771 ° Total Field Strength: 57665.315 nT Magnetic Dip: 80.869° Declination Date: September 23, 2008 Magnetic Declination Model: BGGM 2008 North Reference: True North Total Corr Mag North -> True North: +22.771 ° Comments Measured Inclination Azimuth Sub-Sea TVD Typ Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft n ft ft n n ft de loon ftUS ftUS Fi I t U.UU V.VV U.W -t51. ZU U. UU U. UU U. UU U.UU U.UU U.W U.W b9898/6. b1 S9U44L.3U N /U.32744209 W 149. 26652438 Gryo SS 100.00 0.42 259.28 18. 80 100. 00 -0. 13 0. 37 0.37 -0.07 -0.36 0.42 5969876. 44 590441.94 N 70.32744191 W 149. 26652730 172.00 0.71 252.77 90. 80 172. 00 -0. 43 1. 08 1.07 -0.25 -1.05 0.41 5969876. 25 590441.26 N 70.32744141 W 149 .26653286 215.00 1.09 233.18 133. 79 214. 99 -0. 85 1. 74 1.73 -0.57 -1.63 1.12 5969875. 92 590440.68 N 70.32744053 W 149 .26653758 307.00 1.67 257.86 225. 76 306. 96 -1. 99 3. 93 3.89 -1.38 -3.64 0.89 5969875. 09 590438.68 N 70.32743832 W 149 .26655388 399.00 2.85 299.31 317. 70 398. 90 -1. 74 7. 41 6.96 -0.54 -6.94 2.11 5969875. 88 590435.36 N 70.32744061 W 149 .26658069 491.00 4.85 314.38 409. 49 490. 69 1. 21 13. 55 12.17 3.30 -11.72 2.42 5969879 .67 590430.54 N 70.32745110 W 149 .26661940 582.00 6.06 322.14 500. 07 581. 27 6. 61 22. 19 19.98 9.78 -17.42 1.55 5969886 .08 590424.77 N 70.32746882 W 149 .26666560 657.00 6.92 328.94 574. 59 655. 79 12. 67 30. 66 27.81 16.78 -22.18 1.54 5969893 .02 590419.92 N 70.32748793 W 149 .26670421 732.00 7.34 330.98 649. 01 730. 21 19. 80 39. 97 36.56 24.84 -26.83 0.65 5969901 .02 590415.17 N 70.32750995 W 149 .26674196 MWD+IFR+MS 771.45 6.99 331.59 688. 16 769. 36 23. 64 44. 89 41.26 29.15 -29.20 0.91 5969905 .31 590412.76 N 70.32752174 W 149 .2667 791.19 6.95 332.90 707. 75 788. 95 25. 53 47. 28 43.55 31.27 -30.31 0.83 5969907 .41 590411.62 N 70.32752753 W 149 6 .26677 820.00 7.49 332.13 736. 33 817. 53 28. 41 50. 90 47.03 34.48 -31.98 1.90 5969910 .60 590409.91 N 70.32753630 W 149 .26678374 883.12 9.47 328.17 798. 76 879. 96 35. 52 60. 21 56.14 42.53 -36.65 3.27 5969918 .59 590405.15 N 70.32755829 W 149 .26682154 977.58 11.59 327.08 891. 62 972. 82 48. 26 77. 47 73.26 57.10 -45.90 2.25 5969933 .05 590395.72 N 70.32759809 W 149 .26689660 1073.12 13.62 325.50 984. 85 1066. 05 63. 32 98. 31 94.05 74.43 -57.49 2.16 5969950 .24 590383.92 N 70.32764543 W 149 .26699057 1169.24 16.26 324.67 1077. 72 1158. 92 80. 85 123 .09 118.80 94.74 -71.69 2.76 5969970 .37 590369.48 N 70.32770091 W 149 .26710568 1264.11 15.99 328.73 1168. 86 1250. 06 100 .01 149 .43 145.09 116.74 -86.15 1.22 5969992 .20 590354.76 N 70.32776103 W 149 .26722297 1359.76 16.07 327.97 1260. 79 1341. 99 119 .75 175 .84 171.42 139.23 -100.01 0.23 5970014 .51 590340.63 N 70.32782245 W 149 .26733536 1455.18 15.93 328.43 1352. 51 1433. 71 139 .35 202 .14 197.67 161.58 -113.87 0.20 5970036 .69 590326.50 N 70.32788352 W 149 .26744775 1550.78 18.08 330.18 1443. 93 1525. 13 160 .57 230 .10 225.55 185.63 -128.12 2.31 5970060 .57 590311.97 N 70.32794922 W 149 .26756328 1646.58 19.98 329.85 1534. 49 1615. 69 184 .50 261 .33 256.70 212.68 -143.73 1.99 5970087 .43 590296.03 N 70.32802313 W 149 .26768990 1710.54 21.32 329.96 1594. 34 1675. 54 201 .75 283 .89 279.20 232.20 -155.04 2.10 5970106 .80 590284.49 N 70.32807644 W 149 .26778162 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\V-05\V-05\V-05 Generated 1 1/1 4/2008 7:59 AM Page 1 of 6 Measured Vertical Along Hole Comments Depth inclination Azimuth Sub-Sea ND ND Section Departure Closure NS EW DLS Northing Easting Latitude Longitude ft de de ft ft ft ft ft ft ft de 100 ft ftUS ftUS 1807.47 24.97 330.83 1683. 45 1764. 65 231. 11 321. 98 317. 21 265.33 -173 .84 3.78 5970139.70 590265.29 N 70. 32816695 W 149 .26793407 1903.90 26.87 330.28 1770. 18 1851. 38 263. 66 364. 13 359. 27 302.03 -194 .57 1.99 5970176 .15 590244.13 N 70. 32826721 W 149 .26810215 1998.62 28.43 331.55 1854. 08 1935. 28 297. 78 408. 09 403. 14 340.45 -215. 92 1.76 5970214 .30 590222.31 N 70. 32837216 W 149 .26827533 2095.00 29.12 332.36 1938. 56 2019. 76 334. 32 454. 48 449. 42 381.39 -237 .73 0.82 5970254 .98 590200.01 N 70. 32848402 W 149 .26845219 2191.35 30.27 331.88 2022. 25 2103. 45 371. 99 502. 21 497. 04 423.58 -260 .05 1.22 5970296 .89 590177.19 N 70. 32859927 W 149 .26863322 2286.65 30.80 332.83 2104. 34 2185. 54 410. 33 550. 63 545. 35 466.47 -282 .51 0.75 5970339 .50 590154.21 N 70. 32871644 W 149 .26881539 2381.01 30.81 335.33 2185. 39 2266. 59 449. 46 598. 94 593. 48 509.93 -303 .63 1.36 5970382 .69 590132.57 N 70. 32883515 W 149. 26898666 2477.19 31.20 339.07 2267. 83 2349. 03 491. 09 648. 47 642. 56 555.58 -322 .81 2.04 5970428 .11 590112.84 N 70. 32895988 W 149. 26914223 2573.08 32.05 345.93 2349. 51 2430. 71 535. 64 698. 71 691. 63 603.48 -337 .88 3.85 5970475 .81 590097.20 N 70. 32909072 W 149 .26926440 2668.61 33.43 351.76 2429. 88 2511. 08 583. 79 750. 34 740. 84 654.12 -347 .81 3.60 5970526 .33 590086.66 N 70. 32922908 W 149. 26934500 2763.61 36.16 356.33 2507. 90 2589. 10 635. 89 804. 53 791. 29 708.01 -353 .36 3.97 5970580 .14 590080.46 N 70. 32937629 W 149 .2693 2858.64 38.51 359.35 2583. 46 2664. 66 692. 22 862. 15 844. 09 765.58 -355 .49 3.13 5970637 .68 590077.64 N 70. 32953358 W 149 9 .26940 2953.64 40.39 1.88 2656. 82 2738. 02 751. 77 922. 51 898 .92 825.93 -354 .82 2.60 5970698 .03 590077.59 N 70. 32969844 W 149 .26940186 3049.47 42.19 3.38 2728. 82 2810. 02 814. 48 985. 74 956 .20 889.09 -351 .90 2.14 5970761 .21 590079.74 N 70. 32987099 W 149. 26937823 3123.52 44.38 5.44 2782. 73 2863. 93 865. 00 1036. 50 1002 .06 939.70 -347 .98 3.52 5970811 .86 590083.05 N 70. 33000926 W 149 .26934645 9-5/8" @ 3160'md 3242.50 46.36 6.57 2866. 31 2947. 51 949. 46 1121. 17 1078 .60 1023.90 -339 .11 1.80 5970896 .16 590090.91 N 70. 33023929 W 149 .26927453 3339.64 46.94 6.08 2932. 99 3014. 19 1019. 95 1191. 81 1143 .18 1094.11 -331 .33 0.70 5970966 .44 590097.84 N 70. 33043109 W 149 .26921146 3435.27 46.03 7.37 2998. 84 3080. 04 1089. 19 1261. 15 1207 .06 1162.98 -323 .21 1.36 5971035 .40 590105.12 N 70. 33061923 W 149. 26914567 3530.89 45.72 7.36 3065. 41 3146. 61 1157. 75 1329. 79 1270 .57 1231.05 -314 .41 0.32 5971103 .57 590113.10 N 70. 33080520 W 149. 26907433 3626.96 45.28 7.75 3132. 75 3213. 95 1226. 21 1398. 31 1334 .40 1298.98 -305 .40 0.54 5971171 .59 590121.29 N 70. 33099077 W 149 .26900130 3721.34 44.68 8.15 3199. 51 3280. 71 1292. 88 1465. 03 1396 .81 1365.05 -296 .18 0.70 5971237 .76 590129.72 N 70. 33117128 W 149 .26892649 3816.77 44.11 7.74 3267. 70 3348. 90 1359. 60 1531. 79 1459 .65 1431.17 -286 .95 0.67 5971303 .99 590138.15 N 70. 33135192 W 149 .26885166 3913.14 44.72 8.01 3336. 53 3417. 73 1427. 00 1599. 23 1523 .50 1497.98 -277 .71 0.66 5971370 .89 590146.58 N 70. 33153443 W 149 .26877673 4008.83 45.14 9.21 3404. 28 3485. 48 1494. 56 1666. 81 1587 .51 1564.79 -267 .59 0.99 5971437 .82 590155.90 N 70. 33171697 W 149 .26869467 4103.57 44.26 9.57 3471. 62 3552. 82 1561. 19 1733. 45 1650 .63 1630.54 -256 .72 0.97 5971503 .69 590165.97 N 70. 33189658 W 149 .26860652 4199.45 43.77 9.30 3540. 57 3621. 77 1627. 81 1800. 07 1713 .98 1696.26 -245 .80 0.55 5971569 .53 590176.10 N 70. 33207612 W 149 .26851796 4296.18 44.56 8.03 3609. 96 3691. 16 1695. 18 1867. 46 1778 .56 1762.88 -235 .65 1.23 5971636 .26 590185.44 N 70. 33225813 W 149 .26843567 4391.34 45.90 9.31 3676. 98 3758. 18 1762. 72 1935 .02 1843 .50 1829.66 -225 .46 1.70 5971703 .15 590194.83 N 70. 33244057 W 149 .2683530 4486.99 45.89 9.39 3743. 55 3824. 75 1831. 40 2003 .70 1909 .50 1897.43 -214 .30 0.06 5971771 .05 590205.17 N 70. 33262571 W 149 .26826 4581.35 45.44 9.61 3809. 49 3890. 69 1898. 89 2071 .20 1974 .48 1964.00 -203 .16 0.51 5971837 .74 590215.50 N 70. 33280757 W 149 .268172 4677.61 45.58 9.83 3876. 95 3958. 15 1967. 55 2139 .86 2040 .70 2031.68 -191 .57 0.22 5971905 .55 590226.28 N 70. 33299247 W 149 .26807817 4773.75 45.52 10.72 3944. 28 4025. 48 2036. 18 2208 .49 2106 .86 2099.21 -179 .32 0.66 5971973 .21 590237.70 N 70. 33317696 W 149 .26797890 4869.29 45.60 10.59 4011. 17 4092 .37 2104 .39 2276 .71 2172 .66 2166.25 -166 .71 0.13 5972040 .39 590249.51 N 70. 33336010 W 149 .26787661 4963.75 45.75 10.90 4077. 17 4158 .37 2171 .96 2344 .28 2237 .95 2232.64 -154 .11 0.28 5972106 .93 590261.30 N 70. 33354147 W 149 .26777443 5059.37 45.76 11.04 4143. 89 4225 .09 2240 .45 2412 .78 2304 .21 2299.89 -141 .08 0.11 5972174 .32 590273.53 N 70. 33372519 W 149 .26766871 5155.28 45.21 10.92 4211. 13 4292 .33 2308 .83 2481 .17 2370 .49 2367.03 -128 .05 0.58 5972241 .60 590285.74 N 70. 33390860 W 149 .26756305 5250.81 44.61 10.42 4278 .79 4359 .99 2376 .27 2548 .62 2436 .05 2433.30 -115 .56 0.73 5972308 .02 590297.43 N 70. 33408967 W 149 .26746176 5347.02 42.68 9.48 4348. 40 4429 .60 2442 .67 2615 .01 2500 .87 2498.70 -104 .08 2.12 5972373 .54 590308.12 N 70. 33426833 W 149 .26736863 5441.38 38.26 10.07 4420 .17 4501 .37 2503 .90 2676 .24 2560 .76 2559.04 -93 .70 4.70 5972434 .00 590317.77 N 70. 33443318 W 149 .26728443 5537.43 35.38 12.37 4497 .06 4578 .26 2561 .43 2733 .80 2616 .80 2615.50 -82 .54 3.32 5972490 .58 590328.25 N 70. 33458741 W 149 .26719391 5633.29 32.73 10.28 4576 .47 4657 .67 2615 .08 2787 .47 2669 .09 2668.12 -71 .97 3.02 5972543 .32 590338.19 N 70. 33473116 W 149 .26710816 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\V-05\V-05\V-05 Generated 11 /14/2008 7:59 AM Page 2 of 6 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft tt de 100 ft ftUS ftUS 5/Z6.5U 32.78 10.99 4655.72 4/36.32 2665.70 L83/.49 2/18. UU L/7 /.28 -62. 74 0.72 5972592.58 590346.82 N 70 .33486546 W 149.26703330 5819. 34 31.82 10.33 4733. 86 4815.06 2714.29 2886.68 2766. 14 2765.62 -53. 64 0.54 5972641. 03 590355.34 N 70 .33499754 W 149. 26695947 5912. 74 30.93 12.20 4813. 60 4894.80 2762.90 2935.31 2813. 66 2813.31 -44. 15 1.41 5972688. 82 590364.25 N 70 .33512782 W 149. 26688250 6006. 05 30.48 12.37 4893. 83 4975.03 2810.51 2982.95 2860. 07 2859.87 -34. 01 0.49 5972735. 49 590373.82 N 70 .33525500 W 149. 26680027 6099. 05 30.78 12.62 4973. 85 5055.05 2857.85 3030.34 2906. 22 2906.13 -23. 76 0.35 5972781. 87 590383.52 N 70 .33538138 W 149. 26671711 6193. 94 32.45 15.50 5054. 66 5135.86 2907.45 3080.07 2954. 38 2954.36 -11. 65 2.37 5972830. 24 590395.04 N 70 .33551314 W 149. 26661888 6288. 11 31.78 15.18 5134. 42 5215.62 2957.30 3130.13 3002. 64 3002.63 1. 60 0.73 5972878. 67 590407.70 N 70 .33564503 W 149. 26651143 6382. 38 31.04 14.65 5214. 88 5296.08 3006.24 3179.26 3050. 14 3050.11 14. 24 0.84 5972926. 29 590419.78 N 70 .33577472 W 149. 26640883 6475. 67 29.99 13.87 5295. 24 5376.44 3053.48 3226.63 3096. 12 3096.01 25. 92 1.20 5972972. 33 590430.89 N 70 .33590014 W 149. 26631414 6570. 06 30.03 14.20 5376. 98 5458.18 3100.57 3273.84 3142. 04 3141.81 37. 36 0.18 5973018. 26 590441.79 N 70 .33602526 W 149. 26622126 6665. 97 30.73 15.04 5459. 72 5540.92 3148.92 3322.34 3189. 13 3188.75 49. 61 0.85 5973065. 33 590453.47 N 70 .33615347 W 149. 2661 6762. 39 30.92 15.79 5542. 52 5623.72 3198.10 3371.75 3236. 98 3236.38 62. 74 0.44 5973113. 11 590466.03 N 70 .33628359 W 149. 2 26601 6856. 54 30.40 15.54 5623. 51 5704.71 3245.88 3419.76 3283. 48 3282.60 75. 71 0.57 5973159. 48 590478.43 N 70 .33640988 W 149. 26591019 6952. 44 29.31 14.84 5706. 68 5787.88 3293.42 3467.50 3329. 84 3328.67 88. 22 1.19 5973205. 69 590490.39 N 70 .33653574 W 149. 26580868 7048. 65 30.39 15.33 5790. 13 5871.33 3341.12 3515.38 3376. 41 3374.91 100. 69 1.15 5973252. 07 590502.29 N 70 .33666204 W 149. 26570755 7144. 18 30.41 15.41 5872 .52 5953.72 3389.25 3563.72 3423. 40 3421.52 113. 50 0.05 5973298. 83 590514.54 N 70 .33678938 W 149. 26560360 7239. 84 32.12 14.97 5954 .29 6035.49 3438.69 3613.37 3471. 74 3469.43 126. 50 1.80 5973346. 89 590526.97 N 70 .33692028 W 149. 26549810 7334. 93 31.16 13.22 6035 .24 6116.44 3488.44 3663.25 3520. 54 3517.80 138. 66 1.40 5973395. 40 590538.54 N 70 .33705242 W 149. 26539947 7430. 59 30.26 13.84 6117 .49 6198.69 3537.20 3712.10 3568. 46 3565.30 150. 09 1.00 5973443. 03 590549.39 N 70 .33718218 W 149. 26530677 7526. 45 28.93 14.14 6200 .84 6282.04 3584.42 3759.44 3614. 85 3611.24 161. 53 1.40 5973489. 10 590560.27 N 70 .33730768 W 149. 26521393 7621. 74 28.54 13.49 6284 .40 6365.60 3630.13 3805.25 3659. 79 3655.72 172. 47 0.52 5973533. 71 590570.68 N 70 .33742921 W 149. 26512516 7718. 55 29.78 13.52 6368 .93 6450.13 3677.21 3852.42 3706. 13 3701.59 183. 48 1.28 5973579. 70 590581.14 N 70 .33755451 W 149. 26503578 7813. 26 32.17 14.59 6450 .13 6531.33 3725.83 3901.16 3753. 95 3748.86 195. 34 2.59 5973627. 11 590592.42 N 70 .33768366 W 149. 26493962 7909. 74 31.41 14.15 6532 .14 6613.34 3776.51 3951.99 3803. 79 3798.10 207. 95 0.82 5973676. 49 590604.44 N 70 .33781816 W 149. 26483726 8005 .85 32.06 14.04 6613 .88 6695.08 3826.93 4002.54 3853. 43 3847.13 220. 26 0.68 5973725. 66 590616.16 N 70 .33795211 W 149. 26473737 8101 .02 31.59 14.54 6694 .74 6775.94 3876.98 4052.73 3902. 70 3895.76 232. 65 0.57 5973774. 43 590627.95 N 70 .33808497 W 149. 26463687 8196 .84 30.26 13.70 6776 .94 6858.14 3926.09 4101.97 3951. 10 3943.51 244. 67 1.46 5973822. 32 590639.40 N 70 .33821542 W 149. 26453934 8292 .11 29.02 15.82 6859 .74 6940.94 3973.04 4149.08 3997. 32 3989.07 256 .65 1.70 5973868. 02 590650.83 N 70 .33833988 W 149. 2644420 8387 .41 29.06 20.48 6943 .07 7024.27 4018.80 4195.32 4042. 10 4033.00 271. 05 2.37 5973912. 11 590664.70 N 70 .33845989 W 149. 26432 8482 .39 28.48 27.43 7026 .35 7107.55 4063.10 4240.99 4085. 00 4074.72 289 .56 3.57 5973954. 05 590682.70 N 70 .33857386 W 149. 26417 8577 .56 28.91 33.16 7109 .85 7191.05 4105.91 4286.66 4125. 99 4114.13 312 .60 2.92 5973993. 72 590705.26 N 70 .33868151 W 149. 26398811 8674 .14 30.61 35.35 7193 .69 7274.89 4149.60 4334.59 4167. 59 4153.73 339 .60 2.09 5974033. 65 590731.78 N 70 .33878970 W 149. 26376905 8769 .47 30.30 41.27 7275 .89 7357.09 4192.09 4382.88 4207. 86 4191.61 369 .51 3.16 5974071. 88 590761.23 N 70 .33889318 W 149. 26352635 8866 .18 30.14 47.71 7359 .48 7440.68 4232.17 4431.51 4245. 52 4226.29 403 .58 3.35 5974106. 97 590794.87 N 70 .33898793 W 149. 26324998 8961 .90 30.97 51.91 7441 .91 7523.11 4269.51 4480.16 4280. 41 4257.66 440 .74 2.39 5974138. 78 590831.65 N 70 .33907361 W 149. 26294842 9056 .71 30.80 53.40 7523 .28 7604.48 4305.30 4528.82 4313 .90 4287.18 479 .43 0.83 5974168. 76 590869.98 N 70 .33915426 W 149. 26263452 9152 .46 31.13 56.28 7605 .39 7686.59 4340.22 4578.08 4346 .72 4315.54 519 .70 1.59 5974197. 60 590909.90 N 70 .33923172 W 149. 26230778 9247 .66 30.92 64.45 7687 .01 7768.21 4371.46 4627.09 4376 .03 4339.76 562 .25 4.43 5974222. 33 590952.15 N 70 .33929788 W 149. 26196250 9342 .54 30.22 63.98 7768 .70 7849.90 4399.68 4675.34 4402 .61 4360.75 605 .70 0.78 5974243. 84 590995.34 N 70 .33935521 W 149. 26160994 9437 .20 31.51 63.45 7849 .95 7931.15 4428.42 4723.90 4430 .09 4382.26 649 .24 1.39 5974265. 87 591038.61 N 70 .33941396 W 149. 26125668 9535 .11 31.11 61.58 7933 .60 8014.80 4459.38 4774.78 4460 .12 4405.73 694 .38 1.07 5974289. 88 591083.46 N 70 .33947808 W 149. 26089045 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\V-05\V-05\V-05 Generated 11/14/2008 7:59 AM Page 3 of 6 Measured Vertical Along Hale Comments Inclination Azimuth Sub-Sea TVD TVD Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft tt ft tt de 100 tt ftUS ftUS 9630.10 30. 53 59.70 8015.18 8096 .38 4490.23 4823.44 4490.44 4429.58 736.79 1.18 5974314. 24 591125.58 N 70. 33954323 W 149. 26054630 9726. 15 29. 43 59.31 8098.38 8179 .58 4521.40 4871.44 4521.40 4453. 94 778.15 1.16 5974339. 09 591166.64 N 70. 33960975 W 149. 26021072 9821. 24 29. 56 59.69 8181.14 8262 .34 4551.80 4918.26 4551.89 4477. 70 818.49 0.24 5974363. 33 591206.68 N 70. 33967465 W 149. 25988339 9916. 81 31. 59 58.26 8263.42 8344. 62 4583.72 4966.86 4584.18 4502. 77 860.13 2.26 5974388. 90 591248.02 N 70. 33974313 W 149. 25954548 10009. 59 31. 47 58.27 8342.51 8423. 71 4616.02 5015.38 4617.13 4528. 29 901.40 0.13 5974414. 91 591288.97 N 70. 33981283 W 149. 25921064 10108. 00 32. 11 58.12 8426.15 8507. 35 4650.58 5067.23 4652.69 4555. 61 945.45 0.66 5974442. 76 591332.69 N 70. 33988746 W 149. 25885314 10202. 85 31. 34 58.30 8506.83 8588. 03 4683.82 5117.10 4687.17 4581. 89 987.85 0.82 5974469. 55 591374.76 N 70. 33995923 W 149. 25850914 10270. 63 31. 02 58.80 8564.82 8646. 02 4707.05 5152.19 4711.44 4600. 20 1017.78 0.61 5974488. 21 591404.47 N 70. 34000924 W 149. 25826622 7" @ 10344'md 10376. 28 31. 68 61.66 8655.05 8736. 25 4742.19 5207.15 4748.55 4627. 47 1065.49 1.54 5974516. 06 591451.84 N 70. 34008373 W 149. 25787911 10407. 18 33. 80 65.96 8681.04 8762. 24 4752.04 5223.86 4759.10 4634. 83 1080.48 10.18 5974523. 59 591466.74 N 70. 34010382 W 149. 25775744 10439. 23 34. 91 70.89 8707.51 8788. 71 4761.49 5241.93 4769.40 4641. 46 1097.29 9.34 5974530. 43 591483.47 N 70. 34012194 W 149. 2576 10471. 57 37. 24 75.92 8733.65 8814. 85 4769.99 5260.97 4778.90 4646. 87 1115.54 11.65 5974536. 06 591501.64 N 70. 34013672 W 149. 25747 10502. 95 38. 26 79.27 8758.46 8839. 66 4777.30 5280.18 4787.31 4650. 99 1134.29 7.30 5974540. 40 591520.35 N 70. 34014796 W 149. 25732081 10534. 65 40. 57 80.83 8782.95 8864. 15 4784.16 5300.30 4795.42 4654. 46 1154.12 7.93 5974544. 11 591540.13 N 70. 34015743 W 149. 25715996 10567. 52 43. 31 80.95 8807.40 8888 .60 4791.35 5322.27 4804.05 4657. 94 1175.81 8.34 5974547. 85 591561.77 N 70. 34016692 W 149. 25698397 10598. 83 46. 06 81.84 8829.66 8910. 86 4798.37 5344.28 4812.61 4661. 23 1197.57 9.01 5974551. 40 591583.49 N 70. 34017590 W 149. 25680734 10631. 31 49. 03 80.53 8851.58 8932 .78 4806.11 5368.24 4822.12 4664. 91 1221.25 9.62 5974555. 37 591607.12 N 70. 34018594 W 149. 25661523 10663. 69 52. 95 81.04 8871.96 8953. 16 4814.38 5393.40 4832.36 4668. 93 1246.08 12.17 5974559. 69 591631.90 N 70. 34019693 W 149. 25641375 10694. 97 58. 93 81.60 8889.47 8970. 67 4822.67 5419.30 4842.79 4672. 84 1271.69 19.17 5974563. 90 591657.46 N 70. 34020758 W 149. 25620598 10726. 89 65. 09 84.50 8904.45 8985. 65 4830.87 5447.47 4853.47 4676. 23 1299.65 20.90 5974567. 63 591685.37 N 70. 34021682 W 149. 25597908 10758. 74 67. 26 82.91 8917.31 8998. 51 4839.04 5476.61 4864.38 4679. 42 1328.61 8.20 5974571. 17 591714.29 N 70. 34022555 W 149. 25574412 10790. 27 67. 91 82.96 8929.33 9010 .53 4847.60 5505.75 4875.80 4683. 01 1357.54 2.07 5974575. 11 591743.17 N 70. 34023533 W 149. 25550941 10854. 60 69. 31 82.81 8952.80 9034 .00 4865.22 5565.65 4899.79 4690. 43 1416.97 2.19 5974583. 24 591802.50 N 70. 34025557 W 149. 25502713 10886. 52 72. 70 81.55 8963.18 9044 .38 4874.46 5595.83 4912.44 4694. 54 1446.87 11.26 5974587. 71 591832.34 N 70. 34026678 W 149. 25478456 10917. 26 76. 16 81.29 8971.43 9052 .63 4883.90 5625.44 4925.36 4698. 96 1476.14 11.29 5974592. 48 591861.56 N 70. 34027883 W 149. 25454700 10950. 27 79. 60 82.32 8978.36 9059 .56 4893.97 5657.71 4939.41 4703. 55 1508.08 10.86 5974597. 46 591893.44 N 70. 34029137 W 149. 25428784 10981. 69 81. 24 80.61 8983.59 9064 .79 4903.82 5688.69 4953.22 4708. 15 1538.72 7.49 5974602. 43 591924.02 N 70. 34030392 W 149. 25403925 11013. 38 83. 69 80.37 8987.75 9068 .95 4914.31 5720.10 4967.85 4713. 34 1569.70 7.77 5974607. 99 591954.93 N 70. 34031808 W 149. 2537878 11045. 31 86. 79 81.83 8990.40 9071 .60 4924.62 5751.92 4982.53 4718. 26 1601.13 10.72 5974613. 29 591986.30 N 70. 34033151 W 149. 25353 11077. 38 90. 50 81.42 8991.16 9072 .36 4934.72 5783.97 4997.23 4722. 93 1632.85 11.64 5974618. 34 592017.95 N 70. 34034424 W 149. 25327 11108. 75 94. 35 82.25 8989.83 9071 .03 4944.49 5815.31 5011.65 4727. 38 1663.86 12.55 5974623. 17 592048.91 N 70. 34035638 W 149. 25302379 11141. 17 98. 36 82.09 8986.24 9067 .44 4954.35 5847.52 5026.46 4731. 77 1695.78 12.38 5974627. 94 592080.77 N 70. 34036835 W 149. 25276483 11172. 82 101. 32 82.79 8980.83 9062 .03 4963.76 5878.70 5040.83 4735. 87 1726.69 9.60 5974632. 41 592111.62 N 70. 34037954 W 149. 25251402 11204. 32 103. 70 83.57 8974.01 9055 .21 4972.66 5909.45 5054.79 4739. 53 1757.22 7.93 5974636. 43 592142.10 N 70. 34038950 W 149. 25226628 11236. 64 104. 46 83.65 8966.15 9047 .35 4981.51 5940.80 5068.97 4743. 02 1788.37 2.36 5974640. 30 592173.21 N 70. 34039901 W 149. 25201349 11268. 33 105. 36 82.98 8957.99 9039 .19 4990.30 5971.42 5083.11 4746. 58 1818.79 3.50 5974644. 23 592203.58 N 70. 34040873 W 149. 25176670 11300. 49 104. 73 82.49 8949.65 9030 .85 4999.52 6002.48 5097.88 4750. 51 1849.60 2.45 5974648. 53 592234.33 N 70. 34041944 W 149. 25151672 11332. 13 105. 79 80.52 8941.32 9022 .52 5009.20 6033.00 5113.10 4755. 02 1879.78 6.88 5974653. 40 592264.46 N 70. 34043173 W 149. 25127176 11363. 74 104. 52 80.15 8933.05 9014 .25 5019.47 6063.51 5128.99 4760. 14 1909.86 4.17 5974658. 88 592294.47 N 70. 34044571 W 149. 25102771 11394. 85 102. 29 79.65 8925.84 9007 .04 5029.87 6093.78 5145.07 4765. 45 1939.65 7.34 5974664. 55 592324.19 N 70. 34046019 W 149. 25078597 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\V-05\V-05\V-05 Generated 11/14/2008 7:59 AM Page 4 of 6 Measured Vertical Along Hole Comments Inclination Azimuth Sub-Sea ND ND Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 100 ft ttUS ftUS ll4L/.by IVC .btS iSV.[J t5yli5 .// i5yyy.y/ 5U4U. if/ b1G5. if5 51 bL.LJ 4//1. U5 ly/1.2J 1.`J~4 11458.65 103 .56 79.68 8911 .77 8992 .97 5051. 20 6156. 00 5178.50 4776. 31 2000.92 3.61 11490.22 101. 77 79.68 8904 .85 8986 .05 5061. 90 6186. 80 5195.36 4781. 83 2031.23 5.67 11522.51 99. 30 80.19 8898 .94 8980 .14 5072. 79 6218. 55 5212.75 4787. 37 2062.48 7.81 11554.68 97. 66 79.24 8894 .20 8975 .40 5083. 82 6250. 36 5230.42 4793. 05 2093.79 5.88 11586.77 94. 83 79.31 8890 .71 8971 .91 5095. 11 6282. 26 5248.47 4798. 99 2125.13 8.82 11618.12 95. 07 80.67 8888 .00 8969 .20 5105. 79 6313. 49 5265.95 4804. 42 2155.88 4.39 11649.81 95. 71 81.28 8885 .03 8966 .23 5116. 08 6345. 04 5283.29 4809. 37 2187.04 2.78 11682.18 94. 39 80.83 8882 .18 8963 .38 5126. 55 6377. 29 5301.11 4814. 38 2218.89 4.31 11714.29 91. 67 82.73 8880 .48 8961 .68 5136. 57 6409. 35 5318.62 4818. 96 2250.62 10.33 11745.15 91. 38 82.81 8879 .66 8960 .86 5145. 71 6440. 20 5335.15 4822. 85 2281.23 0.97 11777.73 91. 90 83.27 8878 .73 8959 .93 5155. 21 6472. 76 5352.61 4826. 79 2313.55 2.13 11809.32 94. 66 83.58 8876 .92 8958 .12 5164. 20 6504. 30 5369.48 4830. 40 2344.88 8.79 11841.21 95. 59 82.95 8874 .07 8955 .27 5173. 35 6536. 06 5386.67 4834. 13 2376.42 3.52 11873.01 96. 34 83.39 8870 .77 8951 .97 5182. 51 6567. 69 5403.96 4837. 89 2407.83 2.73 11905.42 94.57 82.70 8867.69 11936.10 94.93 83.98 8865.14 11968.73 93.25 83.35 8862.82 12000.26 89.40 83.26 8862.09 12031.46 87.86 84.56 8862.83 12063.71 85.14 83.39 8864.80 12095.57 80.09 83.14 8868.90 12160.32 80.40 81.71 8879.87 12191.65 77.61 81.42 8885.84 12223.52 77.06 80.13 8892.83 12255.42 77.81 82.35 8899.77 12286.90 78.31 82.18 8906.28 12319.23 76.95 82.52 8913.21 12351.25 77.18 83.15 8920.38 12382.37 77.71 82.51 8927.14 12415.17 78.08 83.20 8934.02 12447.18 76.15 81.64 8941.16 12478.96 76.19 82.37 8948.76 12510.09 76.52 82.44 8956.10 12541.98 76.79 83.05 8963.46 12563.26 76.96 81.50 8968.29 12595.29 77.31 81.48 8975.42 12627.24 77.84 81.29 8982.30 12659.33 78.05 81.37 8989.00 12691.05 77.00 81.03 8995.85 12722.95 77.38 8948.89 5191. 92 6599.95 5421. 80 4841. 80 2439.85 5.86 8946.34 5200. 68 6630. 53 5438. 69 4845. 34 2470.22 4.32 8944.02 5209. 83 6663. 07 5456. 65 4848. 93 2502.57 5.50 8943.29 5218. 89 6694. 59 5474. 33 4852. 61 2533.87 12.21 8944.03 5227. 53 6725. 78 5491. 68 4855. 92 2564.88 6.46 8946.00 8950.10 8961.07 8967.04 8974.03 8980.97 8987.48 8994.41 9001.58 9008.34 9015.22 9022.36 9029.96 9037.30 9044.66 9049.49 9056.62 9063.50 9070.20 9077.05 82.41 9002.93 9084.13 59 / 4(i /U.53 5974676.14 5974682.03 5974687.95 5974694.01 5974700.32 5974706.12 5974711.44 5974716.84 5974721.80 5974726.05 5974730.39 5974734.38 5974738.48 5974742.62 5974746.91 5974750.83 5974754.81 5974758.86 5974762.54 5236.42 6757. 96 5509. 68 4859. 30 2596.89 9.18 5974766. 30 5245.51 6789. 55 5527. 79 4863. 00 2628.26 15.87 5974770. 38 5264.78 6853. 36 5565. 51 4871. 41 2691.51 2.23 5974779. 56 5274.50 6884. 11 5584. 22 4875. 92 2721.93 8.95 5974784. 43 5284.74 6915. 21 5603. 59 4880. 91 2752.62 4.31 5974789. 79 5294.75 6946. 34 5622. 88 4885 .65 2783.39 7.19 5974794. 90 5304.14 6977. 14 5641. 65 4889 .79 2813.91 1.67 5974799. 41 5313.71 7008. 72 5660. 96 4894 .00 2845.21 4.33 5974803. 99 5322.92 7039. 93 5679. 94 4897 .89 2876.17 2.05 5974808. 26 5331.89 7070. 31 5698. 52 4901 .68 2906.31 2.63 5974812. 41 5341.34 7102. 38 5718. 23 4905 .67 2938.13 2.35 5974816. 78 5350.76 7133. 58 5737. 71 4909 .78 2969.06 7.68 5974821. 27 5360.30 7164. 44 5757. 24 4914 .08 2999.62 2.23 5974825. 93 5369.44 7194. 69 5776. 33 4918 .07 3029.61 1.08 5974830. 29 5378.65 7225. 72 5795. 86 4921 .99 3060.39 2.04 5974834. 57 5384.96 7246. 44 5809. 09 4924 .78 3080.92 7.14 5974837. 61 5394.87 7277. 67 5829 .43 4929 .40 3111.80 1.09 5974842. 60 5404.83 7308. 87 5849. 90 4934 .07 3142.65 1.76 5974847. 64 5414.87 7340. 25 5870. 60 4938 .80 3173.68 0.70 5974852. 75 5424.86 7371. 22 5891. 18 4943 .54 3204.28 3.47 5974857. 85 5434.61 7402. 33 5911 .73 4948 .02 3235.06 4.38 5974862. 70 59L;i55./U N /U.:i4U4/54/ W 149.25052975 592385.32 N 70.34048981 W 149.25028879 592415.55 N 70.34050487 W 149.25004290 592446.74 N 70.34052000 W 149.24978929 592477.97 N 70.34053549 W 149.24953526 592509.23 N 70.34055169 W 149.24928096 592539.92 N 70.34056649 W 149.24903138 592571.01 N 70.34057999 W 149.24877854 592602.80 N 70.34059366 W 149.24852009 592634.47 N 70.34060615 W 149.24826261 592665.02 N 70.34061674 W 149.24801 592697.29 N 70.34062749 W 149.2477 592728.57 N 70.34063733 W 149.24749 592760.07 N 70.34064748 W 149.24724181 592791.42 N 70.34065772 W 149.24698699 592823.39 N 70.34066837 W 149.24672713 592853.71 N 70.34067803 W 149.24648072 592886.01 N 70.34068781 W 149.24621824 592917.26 N 70.34069782 W 149.24596425 592948.23 N 70.34070683 W 149.24571260 592980.19 N 70.34071603 W 149.24545287 593011.51 N 70.34072612 W 149.24519834 593074.65 N 70.34074904 W 149.24468505 593105.01 N 70.34076133 W 149.24443821 593135.64 N 70.34077492 W 149.24418916 593166.35 N 70.34078784 W 149.24393947 593196.81 N 70.34079913 W 149.24369183 593228.05 N 70.34081058 W 149.24343786 593258.96 N 70.34082118 W 149.2431866 593289.05 N 70.34083151 W 149.24294 593320.82 N 70.34084237 W 149.24268383 593351.69 N 70.34085358 W 149.24243285 593382.19 N 70.34086527 W 149.24218488 593412.13 N 70.34087616 W 149.24194156 593442.86 N 70.34088683 W 149.24169179 593463.35 N 70.34089442 W 149.24152515 593494.18 N 70.34090701 W 149.24127455 593524.96 N 70.34091974 W 149.24102422 593555.92 N 70.34093263 W 149.24077247 593586.47 N 70.34094554 W 149.24052411 593617.19 N 70.34095774 W 149.24027433 SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\V-05\V-05\V-05 Generated 1 1/1 4/2008 7:59 AM Page 5 of 6 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 00 ft ftUS ftUS i i../.~ v I.VV av Iv. I V ava I.JV J4Y'i.J I /4J4.01 Jy3G.~8 4ybL.44 3Lb/.V4 I./U by/42511/.Sl 12785.98 77.28 81.83 9016.63 9097.83 5453.63 7463.85 5952.42 4956.59 3295.99 0.91 5974872. 00 12819.15 77.31 83.68 9023.93 9105.13 5463.22 7496.21 5973.64 4960.67 3328.08 5.44 5974876. 47 12850.36 77.66 84.23 9030.69 9111.89 5471.64 7526.68 5993.23 4963.87 3358.38 2.05 5974880. 04 12882.38 78.05 83.59 9037.43 9118.63 5480.31 7557.98 6013.47 4967.20 3389.51 2.30 5974883. 74 Last Survey 12900.01 77.98 83.57 9041.09 9122.29 5485.19 7575.22 6024.74 4969.12 3406.65 0.41 5974885. 87 TD (Projected) 12962.00 77.98 83.57 9054.00 9135.20 5502.34 7635.86 6064.58 4975.91 3466.90 0.00 5974893. 39 Survey Type: Definitive Survey NOTES: GYD GC SS - ( Gyrodata -gyro single shots -- Gyrodata gyro orientati on surveys. Not to be run above 70 degrees inclination. ) MWD + IFR + MS - (In-field referenced MWD with mull-station analysis and correction applied in post-processing. Assumes a BHA sag correction is applied to enh2~nce inclination accuracy. ) Legal Description: Northina (Y) fftUSl Easting (X) fftUSl Surface : 4630 FSL 1861 FEL Si 1 T11 N R11 E UM 5969876.51 590442.30 BHL : 4325 FSL 3670 FEL S1 T11 N R11 E UM 5974893.39 593848.65 b9J649.11 N /0. 340969 // W 149.24001484 593678.00 N 70.34098106 W 149.23977996 593710.04 N 70.34099217 W 149.23951950 593740.30 N 70.34100090 W 149.23927363 593771.38 N 70.34100994 W 149.23902105 593788.49 N 70.34101518 W 149.23888199 593848.65 N 70.34103366 W 149.23839308 • SurveyEditor Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\V-05\V-05\V-O5 Generated 1 1/1 4/2008 7:59 AM Page 6 of 6 Ti'tFJ=° WELLHFI~ D = ACTUATOR KB. FJ..EV = BF. ELEV = --- 81.2 55.f~' KC?P = _ 100' NL3x Angle = 105 Datum MD = 10557.A2 9-518" CSG, 40#, L 80, ID= 8.835" ...3160'_ Minimum ID = 3.725" @ 10189' JEWELRY TYPE "XN" Nipple 7", 261ti. L-80, (L~ 6.276", TGII fa surface ~--{ x36$34' V-OS NUTS: I 2204" ~ ~a-ir2•` s X ~ip~p~e , u~ ~.s13,, ~ GAS LIFT MANQRF_I.S ST MD TVD [)EV TYF~E ULV LATCH PC3RT DATE 4 3a23 3212 45 KBr Z DfVfl' BK-5 0 10/17!48 3 6624 5419 30 FCBG-2 QCK-2 BEK t3 iti/17/{l$ 2 8429 7061 29 KBG-2 CHuIY BK-tea 0 101171fl$ 1 10097 8498 32 KBr-"? tIM1AY BK 5 0 1(1117/0$ 10123' ]-14-112" X t~&ppEe (3,813" ID} 10144' ~--~ BaKer S-3 Packer, T' x 4.5" 1016$' 4112" X Nipple {3.813" ID) 4112" 12.6# L-80, .0152 bpf, ID = 3.858" ~ 1 Q29'1' 4.5" WLE=G. I~ 3.958"` 1021 "~ ` 41116" CNV FJectriG 7" CSG, 26#, L-80, X6.276"'~ 1U344' PERFORATION SUN[~3A RY RFF LtOC: ANGLE AT T©P PERF: 44" 111577" .......... SIZE SPF INTE~tVAL OpnlSgz DATE 2-718" 4 10577 - 10655 O 10116108 2-718" 4 10675 - 10720 O 10116108 2-7i$" 4 11524 - 11594 O 101'3 6108 2-718" 4 11607 - 11657, O 1011610$ 2-718" 4 1167(# - 117(30 O 10116/08 2-718" 4 11711 -11901 O 10116108 2-718" 4 12180-12310 O 1411610$ 4-112°, L-$13,..12.6#, 3BT-M, .0152 bpf, ID = 3.96'°? "12962' DATE REV BY Ct7fulAAE1~1'S DATE 12EV BY C.OMMF~1'CS 141191118 t~ES UI~IGINAL CUMPLET~ON 10125/08 1TLI1 CORRECT3ONS t~BTD ~--~ 12877' PRUDHOE BAY UNIT WELL: V-05 PI~iMIT No: 2080930 APi No: 50.429-233910400. Secii,Ti1N,R11E BP F.1rplpraEidn 4AlaskaJ 10169'........1--j 41/2" XN tipple (3.725"' 1[3) '1fl2t16' S" x 7" Liner tap Packer w! Tieback S~eue i ~. ~C7 .~ SCHLUMBERGER Survey report Client.. ................... Field ....................: Well .....................: API number ...............: Engineer .................. RIG :...................... STATE :...................: ----- Survey calculation m Method for positions.....: Method for DLS...........: BP Exploration (Alaska) Inc Prudhoe Bay V-05 50-029-23391-00 Kallestad Nabors 9ES Alaska ethods------------- Minimum curvature Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 52.70 ft KB above permanent.......: N/A Top Drive DF above permanent.......: 81.20 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft Azimuth from Vsect Origin to target: 10.00 degrees 3-Nov-2008 08:14:53 Page 1 of 8 Spud date ................: 21-Sep-08 Last survey date.........: 03-Nov-08 Total accepted surveys...: 193 MD of first survey.......: 0.00 ft MD of last survey........: 12962.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2008 Magnetic date ............: 22-Sep-2008 Magnetic field strength..: 1153.33 HCNT Magnetic dec (+E/W-)...... 22.77 degrees Magnetic dip .............: 80.87 degrees ----- MWD survey Reference Reference G ..............: Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --- 1002.00 meal 1153.33 HCNT 80.87 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)...... 22.77 degrees Grid convergence (+E/W-).. 0.00 degrees Total az corr (+E/W-)..... 22.77 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction U • i -. [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 3-Nov-2008 08:14:53 Page 2 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP 2 100.00 0.42 259.28 100.00 100.00 -0.13 -0.07 -0.36 0.37 259.28 0.42 BP _GYR SS 3 172.00 0.71 252.77 72.00 172.00 -0.43 -0.25 -1.05 1.07 256.58 0.41 BP _GYR SS 4 215.00 1.09 233.18 43.00 214.99 -0.85 -0.57 -1.63 1.73 250.59 1.12 BP _GYR SS 5 307.00 1.67 257.86 92.00 306.96 -1.99 -1.38 -3.64 3.89 249.23 0.89 BP GYR SS 6 399.00 2.85 299.31 92.00 398.90 -1.74 -0.54 -6.94 6.96 265.54 2.11 BP _GYR SS 7 491.00 4.85 314.38 92.00 490.69 1.21 3.30 -11.72 12.17 285.72 2.42 BP _GYR SS 8 582.00 6.06 322.14 91.00 581.27 6.61 9.78 -17.42 19.98 299.32 1.55 BP _GYR SS 9 657.00 6.92 328.94 75.00 655.79 12.67 16.78 -22.18 27.81 307.11 1.54 BP _GYR SS 10 732.00 7.34 330.98 75.00 730.21 19.80 24.84 -26.83 36.56 312.79 0.65 BP GYR SS 11 771.45 6.99 331.59 39.45 769.36 23.64 29.15 -29.20 41.26 314.96 0.91 BP _MWD+IFR+MS 12 791.19 6.95 332.90 19.74 788.95 25.53 31.27 -30.31 43.55 315.89 0.83 BP _MWD+IFR+MS 13 820.00 7.49 332.13 28.81 817.53 28.41 34.48 -31.98 47.03 317.15 1.90 BP _MWD+IFR+MS 14 883.12 9.47 328.17 63.12 879.96 35.52 42.53 -36.65 56.14 319.25 3.27 BP _MWD+IFR+MS 15 977.58 11.59 327.08 94.46 972.82 48.26 57.10 -45.90 73.26 321.21 2.25 BP MWD+IFR+MS 16 1073.12 13.62 325.50 95.54 1066.06 63.32 74.43 -57.49 94.05 322.32 2.16 BP _MWD+IFR+MS 17 1169.24 16.26 324.67 96.12 1158.92 80.85 94.74 -71.69 118.80 322.89 2.76 BP _MWD+IFR+MS 18 1264.11 15.99 328.73 94.87 1250.06 100.01 116.74 -86.15 145.09 323.58 1.22 BP _MWD+IFR+MS 19 1359.76 16.07 327.97 95.65 1341.99 119.75 139.23 -100.01 171.42 324.31 0.23 BP _MWD+IFR+MS 20 1455.18 15.93 328.43 95.42 1433.71 139.35 161.58 -113.87 197.67 324.83 0.20 BP MWD+IFR+MS 21 1550.78 18.08 330.18 95.60 1525.13 160.57 185.63 -128.12 225.55 325.39 2.31 BP _MWD+IFR+MS 22 1646.58 19.98 329.85 95.80 1615.69 184.50 212.68 -143.73 256.70 325.95 1.99 BP _MWD+IFR+MS 23 1710.54 21.32 329.96 63.96 1675.54 201.75 232.20 -155.04 279.20 326.27 2.10 BP _MWD+IFR+MS 24 1807.47 24.97 330.83 96.93 1764.65 231.11 265.33 -173.84 317.21 326.77 3.78 BP _MWD+IFR+MS 25 1903.90 26.87 330.28 96.43 1851.38 263.66 302.03 -194.57 359.27 327.21 1.99 BP MWD+IFR+MS 26 1998.62 28.43 331.55 94.72 1935.28 297.78 340.45 -215.92 403.14 327.62 1.76 BP _MWD+IFR+MS 27 2095.00 29.12 332.36 96.38 2019.76 334.32 381.39 -237.73 449.42 328.06 0.82 BP _MWD+IFR+MS 28 2191.35 30.27 331.88 96.35 2103.45 371.99 423.58 -260.05 497.04 328.45 1.22 BP _MWD+IFR+MS 29 2286.65 30.80 332.83 95.30 2185.54 410.33 466.47 -282.51 545.35 328.80 0.75 BP _MWD+IFR+MS 30 2381.01 30.81 335.33 94.36 2266.59 449.46 509.93 -303.63 593.48 329.23 1.36 BP MWD+IFR+MS [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 3-Nov-2008 08:14:53 Page 3 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 31 2477.19 31.20 339.07 96.18 2349.03 491.09 555.58 -322.81 642.56 329.84 2.04 BP _MWD+IFR+MS 32 2573.08 32.05 345.93 95.89 2430.71 535.64 603.48 -337.88 691.63 330.76 3.85 BP _MWD+IFR+MS 33 2668.61 33.43 351.76 95.53 2511.08 583.79 654.12 -347.81 740.84 332.00 3.60 BP _MWD+IFR+MS 34 2763.61 36.16 356.33 95.00 2589.10 635.89 708.01 -353.36 791.29 333.48 3.97 BP _MWD+IFR+MS 35 2858.64 38.51 359.35 95.03 2664.66 692.22 765.58 -355.49 844.09 335.09 3.13 BP MWD+IFR+MS 36 2953.64 40.39 1.88 95.00 2738.02 751.77 825.93 -354.82 898.92 336.75 2.60 BP _MWD+IFR+MS 37 3049.47 42.19 3.38 95.83 2810.02 814.48 889.09 -351.90 956.20 338.41 2.14 BP _MWD+IFR+MS 38 3123.52 44.38 5.44 74.05 2863.93 865.00 939.70 -347.98 1002.06 339.68 3.52 BP _MWD+IFR+MS 39 3242.50 46.36 6.57 118.98 2947.51 949.46 1023.90 -339.11 1078.60 341.68 1.80 BP _MWD+IFR+MS 40 3339.64 46.94 6.08 97.14 3014.19 1019.95 1094.11 -331.33 1143.18 343.15 0.70 BP MWD+IFR+MS 41 3435.27 46.03 7.37 95.63 3080.04 1089.19 1162.98 -323.21 1207.06 344.47 1.36 BP _MWD+IFR+MS 42 3530.89 45.72 7.36 95.62 3146.61 1157.75 1231.05 -314.41 1270.57 345.67 0.32 BP _MWD+IFR+MS 43 3626.96 45.28 7.75 96.07 3213.95 1226.21 1298.98 -305.40 1334.40 346.77 0.54 BP _MWD+IFR+MS 44 3721.34 44.68 8.15 94.38 3280.71 1292.88 1365.05 -296.18 1396.81 347.76 0.70 BP _MWD+IFR+MS 45 3816.77 44.11 7.74 95.43 3348.90 1359.60 1431.17 -286.95 1459.65 348.66 0.67 BP MWD+IFR+MS 46 3913.14 44.72 8.01 96.37 3417.73 1427.00 1497.98 -277.71 1523.50 349.50 0.66 BP _MWD+IFR+MS 47 4008.83 45.14 9.21 95.69 3485.48 1494.56 1564.79 -267.59 1587.51 350.30 0.99 BP _MWD+IFR+MS 48 4103.57 44.26 9.57 94.74 3552.82 1561.19 1630.54 -256.72 1650.63 351.05 0.97 BP _MWD+IFR+MS 49 4199.45 43.77 9.30 95.88 3621.77 1627.81 1696.26 -245.80 1713.98 351.76 0.55 BP _MWD+IFR+MS 50 4296.18 44.56 8.03 96.73 3691.16 1695.18 1762.88 -235.65 1778.56 352.39 1.23 BP MWD+IFR+MS 51 4391.34 45.90 9.31 95.16 3758.18 1762.72 1829.66 -225.46 1843.50 352.98 1.70 BP _MWD+IFR+MS 52 4486.99 45.89 9.39 95.65 3824.75 1831.40 1897.43 -214.30 1909.50 353.56 0.06 BP _MWD+IFR+MS 53 4581.35 45.44 9.61 94.36 3890.69 1898.89 1964.00 -203.16 1974.48 354.09 0.51 BP _MWD+IFR+MS 54 4677.61 45.58 9.83 96.26 3958.15 1967.55 2031.68 -191.57 2040.70 354.61 0.22 BP _MWD+IFR+MS 55 4773.75 45.52 10.72 96.14 4025.48 2036.18 2099.21 -179.32 2106.86 355.12 0.66 BP MWD+IFR+MS 56 4869.29 45.60 10.59 95.54 4092.37 2104.39 2166.25 -166.71 2172.66 355.60 0.13 BP _MWD+IFR+MS 57 4963.75 45.75 10.90 94.46 4158.37 2171.96 2232.64 -154.11 2237.95 356.05 0.28 BP _MWD+IFR+MS 58 5059.37 45.76 11.04 95.62 4225.09 2240.45 2299.89 -141.08 2304.21 356.49 0.11 BP _MWD+IFR+MS 59 5155.28 45.21 10.92 95.91 4292.33 2308.83 2367.03 -128.05 2370.49 356.90 0.58 BP _MWD+IFR+MS 60 5250.81 44.61 10.42 95.53 4359.99 2376.27 2433.30 -115.56 2436.05 357.28 0.73 BP MWD+IFR+MS • u [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 3-Nov-2008 08:14:53 Page 4 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 61 5347.02 42.68 9.48 96.21 4429.60 2442.67 2498.70 -104.08 2500.87 357.61 2.12 BP _MWD+IFR+MS 62 5441.38 38.26 10.07 94.36 4501.37 2503.90 2559.04 -93.70 2560.76 357.90 4.70 BP _MWD+IFR+MS 63 5537.43 35.38 12.37 96.05 4578.26 2561.43 2615.50 -82.54 2616.80 358.19 3.32 BP _MWD+IFR+MS 64 5633.29 32.73 10.28 95.86 4657.67 2615.08 2668.12 -71.97 2669.09 358.45 3.02 BP _MWD+IFR+MS 65 5726.50 32.18 10.99 93.21 4736.32 2665.10 2717.28 -62.74 2718.00 358.68 0.72 BP MWD+IFR+MS 66 5819.34 31.82 10.33 92.84 4815.06 2714.29 2765.62 -53.64 2766.14 358.89 0.54 BP _MWD+IFR+MS 67 5912.74 30.93 12.20 93.40 4894.80 2762.90 2813.31 -44.15 2813.66 359.10 1.41 BP _MWD+IFR+MS 68 6006.05 30.48 12.37 93.31 4975.03 2810.51 2859.87 -34.01 2860.07 359.32 0.49 BP _MWD+IFR+MS 69 6099.05 30.78 12.62 93.00 5055.05 2857.85 2906.13 -23.76 2906.22 359.53 0.35 BP _MWD+IFR+MS 70 6193.94 32.45 15.50 94.89 5135.86 2907.45 2954.36 -11.65 2954.38 359.77 2.37 BP MWD+IFR+MS 71 6288.11 31.78 15.18 94.17 5215.62 2957.30 3002.64 1.60 3002.64 0.03 0.73 BP _MWD+IFR+MS 72 6382.38 31.04 14.65 94.27 5296.08 3006.24 3050.11 14.24 3050.14 0.27 0.84 BP _MWD+IFR+MS 73 6475.67 29.99 13.87 93.29 5376.44 3053.48 3096.02 25.92 3096.12 0.48 1.20 BP _MWD+IFR+MS 74 6570.06 30.03 14.20 94.39 5458.18 3100.57 3141.81 37.36 3142.04 0.68 0.18 BP _MWD+IFR+MS 75 6665.97 30.73 15.04 95.91 5540.92 3148.92 3188.75 49.61 3189.13 0.89 0.85 BP MWD+IFR+MS 76 6762.39 30.92 15.79 96.42 5623.72 3198.10 3236.38 62.74 3236.98 1.11 0.44 BP _MWD+IFR+MS 77 6856.54 30.40 15.54 94.15 5704.71 3245.88 3282.60 75.71 3283.48 1.32 0.57 BP _MWD+IFR+MS 78 6952.44 29.31 14.84 95.90 5787.88 3293.42 3328.67 88.22 3329.84 1.52 1.19 BP _MWD+IFR+MS 79 7048.65 30.39 15.33 96.21 5871.33 3341.12 3374.91 100.69 3376.41 1.71 1.15 BP _MWD+IFR+MS 80 7144.18 30.41 15.41 95.53 5953.72 3389.25 3421.52 113.50 3423.40 1.90 0.05 BP MWD+IFR+MS 81 7239.84 32.12 14.97 95.66 6035.49 3438.69 3469.43 126.50 3471.74 2.09 1.80 BP _MWD+IFR+MS 82 7334.93 31.16 13.22 95.09 6116.44 3488.44 3517.80 138.66 3520.54 2.26 1.40 BP _MWD+IFR+MS 83 7430.59 30.26 13.84 95.66 6198.69 3537.20 3565.30 150.09 3568.46 2.41 1.00 BP _MWD+IFR+MS 84 7526.45 28.93 14.14 95.86 6282.04 3584.42 3611.24 161.53 3614.85 2.56 1.40 BP _MWD+IFR+MS 85 7621.74 28.54 13.49 95.29 6365.59 3630.13 3655.72 172.47 3659.79 2.70 0.52 BP MWD+IFR+MS 86 7718.55 29.78 13.52 96.81 6450.13 3677.21 3701.59 183.48 3706.13 2.84 1.28 BP _MWD+IFR+MS 87 7813.26 32.17 14.59 94.71 6531.33 3725.83 3748.86 195.34 3753.95 2.98 2.59 BP _MWD+IFR+MS 88 7909.74 31.41 14.15 96.48 6613.34 3776.51 3798.10 207.95 3803.79 3.13 0.82 BP _MWD+IFR+MS 89 8005.85 32.06 14.04 96.11 6695.08 3826.93 3847.13 220.26 3853.43 3.28 0.68 BP _MWD+IFR+MS 90 8101.02 31.59 14.54 95.17 6775.94 3876.98 3895.76 232.65 3902.70 3.42 0.57 BP MWD+IFR+MS r ~ ~J [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 3-Nov-2008 08:14:53 Page 5 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total ------- At ----- DLS - ---- Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 91 8196.84 30.26 13.70 95.82 6858.14 3926.09 3943.51 244.67 3951.10 3.55 1.46 BP _MWD+IFR+MS 92 8292.11 29.02 15.82 95.27 6940.94 3973.04 3989.07 256.65 3997.32 3.68 1.70 BP _MWD+IFR+MS 93 8387.41 29.06 20.48 95.30 7024.27 4018.80 4033.00 271.05 4042.10 3.85 2.37 BP _MWD+IFR+MS 94 8482.39 28.48 27.43 94.98 7107.55 4063.10 4074.72 289.56 4085.00 4.06 3.57 BP _MWD+IFR+MS 95 8577.56 28.91 33.16 95.17 7191.05 4105.91 4114.13 312.60 4125.99 4.35 2.92 BP MWD+IFR+MS 96 8674.14 30.61 35.35 96.58 7274.89 4149.60 4153.73 339.60 4167.59 4.67 2.09 BP _MWD+IFR+MS 97 8769.47 30.30 41.27 95.33 7357.09 4192.09 4191.61 369.51 4207.86 5.04 3.16 BP _MWD+IFR+MS 98 8866.18 30.14 47.71 96.71 7440.67 4232.17 4226.29 403.58 4245.52 5.45 3.35 BP _MWD+IFR+MS 99 8961.90 30.97 51.91 95.72 7523.11 4269.51 4257.66 440.74 4280.41 5.91 2.39 BP _MWD+IFR+MS 100 9056.71 30.80 53.40 94.81 7604.48 4305.30 4287.18 479.43 4313.90 6.38 0.83 BP MWD+IFR+MS 101 9152.46 31.13 56.28 95.75 7686.59 4340.22 4315.54 519.70 4346.72 6.87 1.59 BP _MWD+IFR+MS 102 9247.66 30.92 64.45 95.20 7768.21 4371.46 4339.76 562.25 4376.03 7.38 4.43 BP _MWD+IFR+MS 103 9342.54 30.22 63.98 94.88 7849.90 4399.68 4360.75 605.70 4402.61 7.91 0.78 BP _MWD+IFR+MS 104 9437.20 31.51 63.45 94.66 7931.15 4428.42 4382.26 649.24 4430.09 8.43 1.39 BP _MWD+IFR+MS 105 9535.11 31.11 61.58 97.91 8014.80 4459.38 4405.73 694.38 4460.12 8.96 1.07 BP MWD+IFR+MS 106 9630.10 30.53 59.70 94.99 8096.38 4490.23 4429.58 736.79 4490.44 9.44 1.18 BP _MWD+IFR+MS 107 9726.15 29.43 59.31 96.05 8179.58 4521.40 4453.94 778.15 4521.40 9.91 1.16 BP _MWD+IFR+MS 108 9821.24 29.56 59.69 95.09 8262.34 4551.80 4477.70 818.49 4551.89 10.36 0.24 BP _MWD+IFR+MS 109 9916.81 31.59 58.26 95.57 8344.62 4583.72 4502.77 860.13 4584.18 10.81 2.26 BP _MWD+IFR+MS 110 10009.59 31.47 58.27 92.78 8423.71 4616.02 4528.29 901.40 4617.13 11.26 0.13 BP MWD+IFR+MS 111 10108.00 32.11 58.12 98.41 8507.35 4650.58 4555.61 945.45 4652.69 11.72 0.66 BP _MWD+IFR+MS 112 10202.85 31.34 58.30 94.85 8588.03 4683.82 4581.89 987.85 4687.17 12.17 0.82 BP _MWD+IFR+MS 113 10270.63 31.02 58.80 67.78 8646.02 4707.05 4600.20 1017.78 4711.44 12.48 0.61 BP _MWD+IFR+MS 114 10376.28 31.68 61.66 105.65 8736.25 4742.19 4627.47 1065.49 4748.55 12.97 1.54 BP _MWD+IFR+MS 115 10407.18 33.80 65.96 30.90 8762.24 4752.04 4634.82 1080.48 4759.10 13.12 10.18 BP MWD+IFR+MS 116 10439.23 34.91 70.89 32.05 8788.71 4761.49 4641.46 1097.29 4769.40 13.30 9.34 BP _MWD+IFR+MS 117 10471.57 37.24 75.92 32.34 8814.85 4769.99 4646.87 1115.54 4778.90 13.50 11.65 BP _MWD+IFR+MS 118 10502.95 38.26 79.27 31.38 8839.66 4777.30 4650.99 1134.29 4787.31 13.71 7.30 BP _MWD+IFR+MS 119 10534.65 40.57 80.83 31.70 8864.15 4784.16 4654.46 1154.12 4795.42 13.93 7.93 BP _MWD+IFR+MS 120 10567.52 43.31 80.95 32.87 8888.60 4791.35 4657.94 1175.81 4804.05 14.17 8.34 BP MWD+IFR+MS • • [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 3-Nov-2008 08:14:53 Page 6 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 121 10598.83 46.06 81.84 31.31 8910.86 4798.37 4661.23 1197.57 4812.61 14.41 9.01 BP _MWD+IFR+MS 122 10631.31 49.03 80.53 32.48 8932.78 4806.10 4664.91 1221.25 4822.12 14.67 9.62 BP _MWD+IFR+MS 123 10663.69 52.95 81.04 32.38 8953.16 4814.38 4668.93 1246.08 4832.36 14.94 12.17 BP _MWD+IFR+MS 124 10694.97 58.93 81.60 31.28 8970.67 4822.67 4672.84 1271.69 4842.79 15.22 19.18 BP _MWD+IFR+MS 125 10726.89 65.09 84.50 31.92 8985.65 4830.87 4676.23 1299.65 4853.47 15.53 20.90 BP MWD+IFR+MS 126 10758.74 67.26 82.91 31.85 8998.51 4839.04 4679.42 1328.61 4864.38 15.85 8.20 BP _MWD+IFR+MS 127 10790.27 67.91 82.96 31.53 9010.53 4847.60 4683.01 1357.53 4875.80 16.17 2.07 BP _MWD+IFR+MS 128 10854.60 69.31 82.81 64.33 9034.00 4865.22 4690.43 1416.97 4899.79 16.81 2.19 BP _MWD+IFR+MS 129 10886.52 72.70 81.55 31.92 9044.38 4874.46 4694.54 1446.87 4912.44 17.13 11.26 BP _MWD+IFR+MS 130 10917.26 76.16 81.29 30.74 9052.63 4883.90 4698.96 1476.14 4925.36 17.44 11.29 BP MWD+IFR+MS 131 10950.27 79.60 82.32 33.01 9059.56 4893.97 4703.55 1508.08 4939.40 17.78 10.86 BP _MWD+IFR+MS 132 10981.69 81.24 80.61 31.42 9064.79 4903.82 4708.15 1538.72 4953.22 18.10 7.49 BP _MWD+IFR+MS 133 11013.38 83.69 80.37 31.69 9068.95 4914.31 4713.34 1569.70 4967.85 18.42 7.77 BP _MWD+IFR+MS 134 11045.31 86.79 81.83 31.93 9071.60 4924.62 4718.26 1601.13 4982.53 18.74 10.72 BP _MWD+IFR+MS 135 11077.38 90.50 81.42 32.07 9072.36 4934.72 4722.93 1632.85 4997.23 19.07 11.64 BP MWD+IFR+MS 136 11108.75 94.35 82.25 31.37 9071.03 4944.49 4727.38 1663.86 5011.65 19.39 12.55 BP _MWD+IFR+MS 137 11141.17 98.36 82.09 32.42 9067.44 4954.35 4731.77 1695.78 5026.46 19.72 12.38 BP _MWD+IFR+MS 138 11172.82 101.32 82.79 31.65 9062.03 4963.76 4735.88 1726.69 5040.83 20.03 9.60 BP _MWD+IFR+MS 139 11204.32 103.70 83.57 31.50 9055.21 4972.66 4739.53 1757.22 5054.79 20.34 7.93 BP _MWD+IFR+MS 140 11236.64 104.46 83.65 32.32 9047.35 4981.51 4743.02 1788.37 5068.97 20.66 2.36 BP MWD+IFR+MS 141 11268.33 105.36 82.98 31.69 9039.19 4990.30 4746.58 1818.79 5083.11 20.97 3.50 BP _MWD+IFR+MS 142 11300.49 104.73 82.49 32.16 9030.85 4999.52 4750.51 1849.60 5097.88 21.27 2.45 BP _MWD+IFR+MS 143 11332.13 105.79 80.52 31.64 9022.52 5009.20 4755.02 1879.78 5113.10 21.57 6.88 BP _MWD+IFR+MS 144 11363.74 104.52 80.15 31.61 9014.25 5019.46 4760.14 1909.86 5128.98 21.86 4.17 BP _MWD+IFR+MS 145 11394.85 102.29 79.65 31.11 9007.04 5029.86 4765.45 1939.65 5145.07 22.15 7.34 BP MWD+IFR+MS 146 11427.69 102.58 80.23 32.84 8999.97 5040.86 4771.05 1971.23 5162.23 22.45 1.94 BP _MWD+IFR+MS 147 11458.65 103.56 79.68 30.96 8992.97 5051.20 4776.31 2000.92 5178.49 22.73 3.61 BP _MWD+IFR+MS 148 11490.22 101.77 79.68 31.57 8986.05 5061.90 4781.82 2031.23 5195.36 23.01 5.67 BP _MWD+IFR+MS 149 11522.51 99.30 80.19 32.29 8980.15 5072.79 4787.37 2062.48 5212.75 23.31 7.81 BP _MWD+IFR+MS 150 11554.68 97.66 79.24 32.17 8975.40 5083.82 4793.05 2093.79 5230.42 23.60 5.88 BP MWD+IFR+MS [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 3-Nov-2008 08:14:53 Page 7 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 151 11586.77 94.83 79.31 32.09 8971.91 5095.10 4798.99 2125.13 5248.47 23.89 8.82 BP _MWD+IFR+MS 152 11618.12 95.07 80.67 31.35 8969.21 5105.79 4804.42 2155.88 5265.95 24.17 4.39 BP _MWD+IFR+MS 153 11649.81 95.71 81.28 31.69 8966.23 5116.08 4809.37 2187.04 5283.29 24.45 2.78 BP _MWD+IFR+MS 154 11682.18 94.39 80.83 32.37 8963.38 5126.55 4814.38 2218.89 5301.11 24.74 4.31 BP _MWD+IFR+MS 155 11714.29 91.67 82.73 32.11 8961.68 5136.57 4818.96 2250.62 5318.62 25.03 10.33 BP MWD+IFR+MS 156 11745.15 91.38 82.81 30.86 8960.86 5145.71 4822.85 2281.23 5335.15 25.31 0.97 BP _MWD+IFR+MS 157 11777.73 91.90 83.27 32.58 8959.93 5155.21 4826.79 2313.55 5352.61 25.61 2.13 BP _MWD+IFR+MS 158 11809.32 94.66 83.58 31.59 8958.12 5164.20 4830.40 2344.88 5369.48 25.89 8.79 BP _MWD+IFR+MS 159 11841.21 95.59 82.95 31.89 8955.27 5173.35 4834.13 2376.43 5386.67 26.18 3.52 BP _MWD+IFR+MS 160 11873.01 96.34 83.39 31.80 8951.97 5182.51 4837.89 2407.83 5403.96 26.46 2.73 BP MWD+IFR+MS 161 11905.42 94.57 82.70 32.41 8948.89 5191.91 4841.80 2439.85 5421.79 26.74 5.86 BP _MWD+IFR+MS 162 11936.10 94.93 83.98 30.68 8946.35 5200.68 4845.34 2470.22 5438.69 27.01 4.32 BP _MWD+IFR+MS 163 11968.73 93.25 83.35 32.63 8944.02 5209.83 4848.93 2502.57 5456.65 27.30 5.50 BP _MWD+IFR+MS 164 12000.26 89.40 83.26 31.53 8943.29 5218.89 4852.61 2533.87 5474.33 27.57 12.21 BP _MWD+IFR+MS 165 12031.46 87.86 84.56 31.20 8944.04 5227.53 4855.92 2564.88 5491.68 27.84 6.46 BP MWD+IFR+MS 166 12063.71 85.14 83.39 32.25 8946.00 5236.42 4859.29 2596.89 5509.68 28.12 9.18 BP _MWD+IFR+MS 167 12095.57 80.09 83.14 31.86 8950.10 5245.51 4863.00 2628.26 5527.79 28.39 15.87 BP _MWD+IFR+MS 168 12160.32 80.40 81.71 64.75 8961.07 5264.78 4871.41 2691.51 5565.51 28.92 2.23 BP _MWD+IFR+MS 169 12191.65 77.61 81.42 31.33 8967.04 5274.50 4875.92 2721.93 5584.22 29.17 8.95 BP _MWD+IFR+MS 170 12223.52 77.06 80.13 31.87 8974.03 5284.74 4880.91 2752.62 5603.59 29.42 4.31 BP MWD+IFR+MS 171 12255.42 77.81 82.35 31.90 8980.97 5294.75 4885.65 2783.39 5622.88 29.67 7.19 BP _MWD+IFR+MS 172 12286.90 78.31 82.18 31.48 8987.49 5304.14 4889.79 2813.91 5641.65 29.92 1.67 BP _MWD+IFR+MS 173 12319.23 76.95 82.52 32.33 8994.41 5313.71 4894.00 2845.21 5660.96 30.17 4.33 BP _MWD+IFR+MS 174 12351.25 77.18 83.15 32.02 9001.58 5322.92 4897.89 2876.17 5679.94 30.42 2.05 BP _MWD+IFR+MS 175 12382.37 77.71 82.51 31.12 9008.34 5331.89 4901.68 2906.31 5698.52 30.66 2.63 BP MWD+IFR+MS 176 12415.17 78.08 83.20 32.80 9015.22 5341.34 4905.67 2938.13 5718.23 30.92 2.35 BP _MWD+IFR+MS 177 12447.18 76.15 81.64 32.01 9022.36 5350.76 4909.78 2969.06 5737.71 31.16 7.68 BP _MWD+IFR+MS 178 12478.96 76.19 82.37 31.78 9029.96 5360.30 4914.07 2999.62 5757.24 31.40 2.23 BP _MWD+IFR+MS 179 12510.09 76.52 82.44 31.13 9037.30 5369.44 4918.07 3029.61 5776.33 31.63 1.08 BP _MWD+IFR+MS 180 12541.98 76.79 83.05 31.89 9044.66 5378.65 4921.99 3060.39 5795.86 31.87 2.04 BP MWD+IFR+MS C • .- I' [(c)2008 IDEAL ID13_OC_13] SCHLUMBERGER Survey Report 3-Nov-2008 08:14:53 Page 8 of 8 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type 181 12563.26 76.96 81.50 21.28 9049.49 5384.95 4924.78 3080.92 5809.09 32.03 7.14 BP _MWD+IFR+MS 182 12595.29 77.31 81.48 32.03 9056.63 5394.87 4929.40 3111.80 5829.43 32.26 1.09 BP _MWD+IFR+MS 183 12627.24 77.84 81.29 31.95 9063.50 5404.83 4934.07 3142.65 5849.90 32.49 1.76 BP _MWD+IFR+MS 184 12659.33 78.05 81.37 32.09 9070.20 5414.87 4938.80 3173.68 5870.60 32.72 0.70 BP _MWD+IFR+MS 185 12691.05 77.00 81.03 31.72 9077.05 5424.85 4943.54 3204.28 5891.18 32.95 3.47 BP _MWD+IFR+MS 186 12722.95 77.38 82.41 31.90 9084.13 5434.61 4948.02 3235.06 5911.73 33.18 4.38 BP _MWD+IFR+MS 187 12756.02 77.55 81.86 33.07 9091.30 5444.51 4952.44 3267.04 5932.97 33.41 1.70 BP _MWD+IFR+MS 188 12785.98 77.28 81.83 29.96 9097.83 5453.63 4956.58 3295.99 5952.42 33.62 0.91 BP _MWD+IFR+MS 189 12819.15 77.31 83.68 33.17 9105.13 5463.22 4960.67 3328.08 5973.64 33.86 5.44 BP _MWD+IFR+MS 190 12850.36 77.66 84.23 31.21 9111.89 5471.64 4963.87 3358.38 5993.23 34.08 2.05 BP _MWD+IFR+MS 191 12882.38 78.05 83.59 32.02 9118.63 5480.31 4967.19 3389.51 6013.47 34.31 2.30 BP _MWD+IFR+MS 192 12900.01 77.98 83.57 17.63 9122.29 5485.19 4969.12 3406.65 6024.73 34.43 0.41 BP _MWD+IFR+MS 193 12962.00 77.98 83.57 61.99 9135.20 5502.34 4975.91 3466.90 6064.58 34.87 0.00 Pr ojected to TD [(c)2008 IDEAL ID13_OC_13] CJ • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc Well No V-05 Installation/Rig 9ES Dispatched To: Christine Mahnken (AOGCC) Date Dispatched: 17-Oct-08 Dispatched By: Paul Wyman Data No Of Prints No of Floppies Surveys 2 1 Please sign and return to: ,lames FI. Johnson Received By: ~~ ~ BP Exploration (Alaska) Inc. ~~~FFF Petrotechnical Data Center(LR2-1) g N V V ~v $ 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax:907-564-4005 e-mail address: johnsojhCbp.com LVVU Log Uelwery VL.1, U3-U6-U6 ~~~- oq3 • r0da gY Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 October 2, 2008 State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: V Pad, Well #V-05 Prudhoe Bay, Alaska Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, -,~.~. Rob Shoup North American Regional Manager RS:tf Serving the Worldwide Cnergy Industry ~~vith Precision uurvey InstrumenP~ti~;~7 Gyrodata Incorporated 1682 W. Sam Houston Pkwy. N. Houston, Texas 77043 713/461-3146 Fax: 713/461-0920 SURVEY REPORT BP V Pad #V-05 Nabors #9ES Prudhoe Bay, AK AK0908G_158 22 Sep 2008 ~~ ~~~~~ • Serving the Worldwide Energy Industry with Precision Survey Instrtimerztation ~,e~-~43 A Gyrodata Directional Survey for BP EXPLORATION (ALASKA) Lease: V-Pad Well: V-O5, 4" Drillpipe Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK0908G 158 Run Date: 22 Sep 2008 Surveyor: Michael Villarreal Calculation Method: MINIMUM CURVATURE Survey surface coordinates obtained from: Directional Drilling Company Survey Latitude: 70.327442 deg. N Longitude: 149.266524 deg. W Azimuth Correction: Gyro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Well Head Location • i BP Exploration (Alaska) Lease: V-Pad Well: V-O5, 4" Drillpipe Location: Nabors #9ES, Prudhoe Bay, Alaska Job Number: AK0908G 158 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. A Gyrodata Directional Survey BORE HOLE DOGLEG VERTICAL CLOSURE HORIZONTAL BEARING SEVERITY DEPTH DIST. AZIMUTH COORDINATES deg. min. deg./ feet feet deg. feet 100 ft. 0.00 0.00 0.00 N 0 0 E 0.00 0.00 ------------------------------------------------------------------------------------------------------------------------ 0 - 732 FT. RATE GYROSCOPIC MULTISHOT SURVEY RUN INSIDE 4" DRILLPIPE ALL MEASURED DEPTHS AND COORDINATES REFERENCED TO NABORS #9ES R.K.B. 100.00 0.42 259.28 S 79 17 W 172.00 0.71 252.77 S 72 46 W 215.00 1.09 233.18 S 53 11 W 307.00 1.67 257.86 S 77 52 W 399.00 2.85 299.31 N 60 41 W 491.00 4.85 314.38 N 45 37 W 582.00 6.06 322.14 N 37 52 W 657.00 6.92 328.94 N 31 4 W 732.00 7.34 330.98 N 29 1 W Final Station Closure: Distance: 36.55 ft Az: 312.78 deg. 0.0 0.0 0.00 N 0.00 E 0.42 100.00 0.4 259.3 0.07 S 0.36 W 0.42 172.00 1.1 256.6 0.25 ' S 1.05 W 1.12 214.99 1.7 250.6 0.57 S 1.63 W 0.89 306.96 3.9 249.2 1.38 S 3.64 W 2.11 398.90 7.0 265.5 0.54 S 6.94 W 2.42 490.69 12.2 285.7 3.29 N 11.71 W 1.56 581.27 20.0 299.3 9.77 N 17.41 W 1.53 655.79 27.8 307.1 16.77 N 22.17 W 0.65 730.21 36.6 312.8 24.83 N 26.83 W • 2 BP Exploration (Alaska) Well: V-Pad V-05 4" Drill pipe Location: Nabors #9ES, Prudhoe Bay, Alaska In run Gyrodata AK0908G_158 DEFINITIVE 25 20 HOLE Mm: 732.00 15 w C7 z Z10 5 0 -25 -20 -15 -10 FASTING (ft) -5 u BP Exploration (Alaska) _Well: V-Pad V-05 4" Drillpipe Location: Nabors #9ES, Prudhoe Bay, Alaska 10 9 8 7 ~-. 0 0 6 rn a~ .o ~ 5 w w 4 C7 O 3 2 1 0 In run Gyrodata AK0908G_158 DEFINITIVE BOTTOM LOCATED MD: 732. s 100 200 300 400 500 600 7UU ~3UU MEASURED DEPTH (ft) BP Exploration (Alaska) -Well: V-Pad V-05 4" Drillpipe LOCatinn~ Nahors #9ES. Prudhoe Bav, Alaska 65 64 63 62 w o, 61 a~ a w ~ 60 w a w5 5 5 5 5 Inrun Gyrodata ; AK0908G 158 DEFINITIVE BOTTOM H LE MD: 732.00 9 8 7 6 5 ~..., nnn 100 200 3U0 4UU 5uu ouv ~vv ~~~ MEASURED DEPTH (ft) • ~5~ OIIr ~ ~ 333 W 7th AVENUE S IT C011T5ERQATIOAT COMA'IIS5IOIQ . , U E 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Tirpack Engineer Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU V-05 BP Exploration Alaska Inc. Permit No: 208-093 Surface Location: 4630' FSL, 1861' FEL, SEC. 11, T11N, R11E, UM Bottomhole Location: 4262' FSL, 1171' FWL, SEC. O 1, Tl l N, R 11 E, UM Dear Mr. Tirpack: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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 speci$cally authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum $eld inspector at (907) 659-3607 (pager). Sincerely, Cathy . Foerster Commissioner DATED this ~,~C ay of September, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA q~. O-O~ K~~~~ ALAS~IL AND GAS CONSERVATION COMMIN ~`~ SUN ®3 ZOO$ PERMIT TO DRILL Alaska Oi! & Gas Cans, Cnmrnissi0 20 AAC 25.005 1 a. Type of work ® Drill ^ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ®Service ^ Multiple Zone ^ Stratigraphic Test ^ Development Oil ^ Single Zone 1 c. Specify if well is prop r: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU V-05 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12544' TVD 9133' 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 4630' FSL 1861' FEL SEC 11 T11N R11E UM Pl 7. Property Designation: ADL 028240 Pool , , . , , , ( an) Top of Productive Horizon: 4035' FSL, 671' FEL, SEC. 02, T11 N, R11 E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 10, 2008 Total Depth: 4262' FSL, 1171' FWL, SEC. 01, T11N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 11,579' 4b. Location of Well (State Base Plane Coordinates): Surface: x-590442 y-5969877 Zone-ASP4 10. KB Elevation Plan (Height above GL): 82.5 feet 15. Distance to Nearest Well Within Pool: 613' 16. Deviated Wells: Kickoff Depth: 300 feet Maximum Hole An le: 104 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3700 Surface: 2835 18. a in P ram: S cificatio n To - ttin h -Bo ttom u nt' f nt c.f. ors cks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 42" 20" 215.5# A-53 Weld 80' Surface Surface 10 ' 108' 260 sx Arctic Set A rox. 12-1/4" 9-5/8" 40# L-80 BTC 3097' Surface Surface 3125' 2862' 491 sx Class'G' 411 sx Class 'G' 8-3/4" 7" 26# L- 0 T II 4597' urf rf 462 ' 39 2' ee B I w 8-3/4" 7" 26# L-80 BTC-M 5744' 4625' 3992' 10369' 8732' 426 sx LiteCrete 184 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2325' 10219' 8582' 12544' 9133' 262 sx Class 'G' 1 g. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill'i#nd Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): asing _. ' `Length ize Cement Volume MD l) Conductor /Structural Surface Intermediate Produ ion Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Garret Staudinger, 564-4242 Printed Name Robert Tirpack Title Engineering Team Leader Prepared By Name/Number: Si nature Phone 564-4166 Date s ,~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: o~D~09-3~ API Number: 50-oa9~ f 004 Permit Approval Date: See cover letter for oth r r irem nts 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: ~~, ~ ~ ~ CSLV~Ccr~v0~ `~~ ` f`t~ Samples Req'd: ^ Yes ~No Mud Log Req'd: ^ Yes ~No hQO~ eSt ~®~ '~S~GS ~~ ~. HZS Measures: ~ Yes ^ No Directional Survey Req'd: Yes ^ No Ot er.~`~-lv..G~©Q~crU-~vr~~+~GCCfl~ ~~ ~~~ APPROVED BY THE COMMISSION Date - -Q ,COMMISSIONER Form 10-401 Revised 12/2005 , ~..~ ~ ~ ~ ~ Submit In Duplicate Well Name• V-05 ~~ ~S ~~ ti~p~ ~~~5 Drill and Complete Plan Summary Name Position Office Home Cell Other Garret Staudin er Drillin En ineer 4242 440-6892 440-6892 Jennifer Flight Geologist 4144 644-4165 952-1018 Dan Robertson Pad Engineer 5546 346-3714 529-5818 T e of Well service / roducer / injector : In'ector Tar et X Y Z TVDss Townshi Ran a Section FSL FEL Surface As-built 590442 5969877 0 11N 11E 11 4631 1861 Start: TSAD 591571 5974575 8846 11N 11E 2 4035 671 BHL 593410 5974824 9051 11 11 1 4262 4109 AFE Number: PBDxxxxxx API Number: TBD Estimated Start Date: October 10, 2008 Operating days: 29 Ri Nabors 9ES TMD 12544' ~ TVD rkb: 9133 RKB/GL 28.5'/54' RTE 82.5' Well Design: USH Grassroots Ivishak Zone 4 Horizontal injector. 4-'/z" L-80 TCII com letion. Current Status: New drill, conductor will be set Formation De the and Pressures: Est. Formation To s PIO Est. Formation To s Uncertain Commercial Hydrocarbon Bearin Est. Pore Press. Est. Pore Press. Formation MD TVDss eet es/No Psi) EMW) G1 332 -250 +/- 50' No 113 8.7 SV6 968 -880 +/- 50' No 396 8.7 EOCU 1560 -1450 +/- 50' No 653 8.7 SV5 1648 -1535 +/- 50' No 691 8.7 SV4 1780 -1660 +/- 50' No 747 8.7 BPRF 1830 -1705 +/- 50' Gas H drates 767 8.7 SV3 2213 -2050 +/- 50' Gas H drates 923 8.7 SV2 2417 -2225 +/- 50' Gas H drates 1001 8.7 SV1 2816 -2550 +/- 50' Gas H drates 1148 8.7 UG4 3238 -2860 +/- 50' Thin coal 1287 8.7 UG4A 3280 -2890 +/- 50' Hea oil 1301 8.7 FAULT #1 "V Pad" Fault 3379 -2960 +/-100' M.D. UG3 3605 -3120 +/- 50' Thin coals 1404 8.7 UG1 4298 -3610 +/- 50' Hea oil 1625 8.7 UG Ma 4721 -3910 +/-25' Hea oil 1760 8.7 SB Na 5060 -4150 +/-25' No, wet 1868 8.7 SB OA 5294 -4315 +/-25' Yes 1300 5.8 SB OBa 5385 -4380 +/-25' Yes 1500 6.6 V-05 Permit to Drill Page 1 SB_OBb 5448 -4425 +/-25' Yes 1800 7.8 SB_OBc 5521 -4480 +/-25' Yes 1800 7.7 SB_OBd 5585 -4530 +/-25' Yes 1300 5.5 SB OBf 5720 -4640 +/-25' No 2070 8.6 OBf-Base 5780 -4690 +/-25' No 2090 8.6 CM-2 6133 -4995 +/-20' No 2230 8.6 CM-1 6922 -5675 +/-20' No 2540 8.6 TLBK 7322 -6020 +/-20' No 2690 8.6 THRZ 7548 -621.5 +/-20' No 2780 8.6 TKLB 7780 -6415 +/-20' No 2870 8.6 TKC4 7792 -6525 +/-20' Yes 3220 9.50 TKC2E 7931 -6545 +/-20' Yes 3230 9.50 TKC1C 8006 -6610 +/-20' Yes 3270. 9.50 TKB LCU 8047 -6645 +/-20' No 3390 9.80 TMLV 8273 -6840 +/-20' No 3060 8.6 TKNG 9188 -7634 +/-25' No TJF 9352 -7775 +/-25' No TJE 9704 -8078 +/-25' No TJD (partially faulted out 9890 -8238 +/-25' No Fault#2 9898 -8245 +/-150' MD No TJC (partially faulted out 10078 -8400 +/-25' No Fault#3 10194 -8500 +/-150' MD No TJB (partially faulted out 10194 -8500 +/-25' No TJA 10252 -8550 +/-25' No TSGR 10369 -8650 +/-25' Yes .3700 8.2 TSHA 10407 -8683 +/-25' No TSHB 10505 -8763 +/-25' No TSHC 10531 -8783 +/-25' No TSHD 10564 -8807 +/-25' No TEIL 10583 -8820 +/-25' No TSAD 10622 -8846 +/-25' Yes 3480 7.6 45P 10678 -8880 Yes 3495 7.6 44P 10765 -8925 Yes 3513 7.6 43P 10872 -8956 Yes 3526 7.6 42P 11030 -8997 42P /INVERT 11090 -9000 Yes 3543 7.6 43P -8978 Yes 3535. 7.6 44P -8954 Yes 3525 7.6 45P -8916 Yes 3510 7.6 REVERT (in 46P sand 11886 -8900 Yes 3503 7.6 45P -8920 Yes 3511 7.6 44P -8961 Yes 3528 7.6 43P -8988 Yes 3539 7.6 42P -9020 Yes 3551 7.6 TD 12544 -9050 Yes 3563 7.6 V-05 Permit to Drill Page 2 • Wells within a 1/a mile of this infection well: Well Name Dist, Ft. Annulus Inte ri Comments Offset producer, 613' at closest approach in pool, 3144'. No USIT. Good V-03 613' cement ~ob; um ed 82 bbls, circ 25 bbls excess cement back to surface. Offset producer, 1130' at closest approach in pool, 2103'. No USIT. Good cement job; pumped 95 bbls, circ out 30 bbls excess cement returns, L-03 ll30' no losses. Casing/Tubing Program: Hole Size Csg/ Tbg O.D. Wt/Ft Grade Connection Length (ft) Top MD/TVD RTE (ft) Btm MD/TVD .RTE (ft) 42" Insulated 20" 215.5 A-53 WLD 80 GL 108/108 12-1/a" 9-5/s" 40 L-80 BTC 3096.5 GL 3125/2862 8 3/a" 7" 26 L-80 TC-II 4596.5 GL 4625/3992 8 3/a" 7" 26 L-80 BTC-M 5744 4625/3992 10369/8732 6-'Y8" 4-1/z" 12.6 L-80 IBT-M 2325 10219/8582 12544/9133 Tubin 4-~/z" 12.6 L-80 TC-II 10190.5 GL 10219/8582 Directional• Directional Plan: Schlumber er P10 Close A roach Wells: All Wells ass Ma~or Risk Scan, reference anti-collision re ort Surve Pro ram: MWD + IFR + MS Distance to Neazest Pro ert Liner 11,579' from northern most excursion of well to the PBU Bound Distance to Neazest Well in Pool: 613' from V-03 in NWE Ivishak ool (closest a roach) Mud Program: 12-1/a" Surface Hole Mud Pro erties S ud Mud- Freshwater Mud Interval Densit PV YP PH Funn Vis FL 0-1827' (BPRF) 8.8-9.2 20-45 50 - 70 9.0 - 9.5 300-400 NC - 8 1827'-3117' (SV 1) 9.0-9.5 20-45 45 - 60 9.0 - 9.5 200-300 < 7.5 8-3/a" Intermediate Hole Mud Pro erties Freshwater Mud (LSND) Interval Densit PV YP PH API Filtrate MBT 3117'-7548' (THRZ) 8.8-9.2 12-18 20 - 26 9.0-9.5 4 - 7 < 15 7548'-9188' (TKNG) 10.1 14-22 18 - 25 9.0-9.5 HTHP < 10 < 20 9188'-10369' (TSGR) 10.1 14-22 18 - 25 9.0-9.5 HTHP < 10 < 20 6-%" Production Hole Mud Pro erties F1oPro-NT Interval Density PV YP PH HTHP @235° LG Solids 10369'-12544'(TSAD) 8.5 5-8 22-32 8.5-9.0 < 8 <3 V-05 Permit to Drill Page 3 Survey and T.nuuinu Prnuram~ 12-1/a" Hole Section: Surface G ro until MWD surve s are clean. MWD /LWD: Dir/GR O en Hole: None .Cased hole: None 8-3/a" Hole Section: Sam le as re uired b well site Geolo ist MWD /LWD: GR/RES/PWD real time and NEU/AZM-DENS recorded O en Hole: None Cased Hole: USIT 6-'/8" Hole Section: Sam le as re uired b well site Geolo ist MWD /LWD: GR/RES real time and NEU/AZM-DENS recorded O en Hole: None Cased Hole: SCMT if re uired Cement Calculations: Casin Size Surface Casin - 9-5/8", 401b/ft, L-80, BTC -Sin le Sta e Basis Lead: Open hole volume + 250% excess in permafrost and 40% excess below permafrost. TOC at surface Tail: O en hole volume + 40% excess + 80' shoe track. To of tail 1000' MD above shoe (2125' MD) Fluid Sequence and Tam Port collar located at 1,000' as a contingency for cement to surface (run if necessary) Volume: Wash None S acer 45 bbls of MudPush II wei hted to 10.5 Lead 388 bbls, 491 sks, 10.7 lb/ al Dee Crete cement - 4.44 cuft/sk Tail 85 bbls, 411 sks, 15.81b/ al Class G - 1.15 cufbsk Temp BHST ~ 50° F from SOR Casin Size Intermediate Casin - 7", 261b/ft, L-80, BTC-M x TC-II -One Sta e Basis Lead: Open hole volume + 30% excess. TOC at 4125' MD (1000' MD below the surface shoe) Tail: O en hole volume + 30% excess + 80' shoe track. To of tail at 9369' MD (1000' MD above the shoe) Fluid Sequence and Volume: Wash None S acer 40 bbl of MUDPUSH XL S acer wei hted to 11.0-1b/ al Lead 180 bbl, 426 sks, 12.0 LiteCRETE - 2.36 cuft/sk Tail 38 bbl, 184 sks, 15.8 Class G cement + Silica - 1.16 cuft/sk Temp BHST ~ 230° F Casin Size Production Liner - 4 1/z" 12.61b/ft, L-80, IBT-M -Sin le Sta e Basis Tail: Open hole volume + 30% excess + 150' of liner lap + 80' shoe track + 200' of 7" x 4" DP annulus volume. TOC at liner to (10219' MD) Total Cement Volume: Wash None S acer 25 bbls of Mud ush II Wei hted to 10 Tail 56 bbls, 262 sks, 15.8 lb/ al Class G Cement + Silica + Latex - 1.2 cuft/sk Temp BHST ~ 234° F V-05 Permit to Drill Page 4 • Surface and Anti-Collision Issues: • Surface Shut-in Wells: V-113, V-112 will need to have well houses removed and may need to be shut-in for the rig move on and off V-O5. • Close Approach Shut-in Wells: All wells have passed the major risk scan. Reference the Anti-collision report in the directional plan for a full list of offset well paths. V-202 will require surface shut-in prior to spud, and will stay shut-in until the intermediate casing is cemented. This will decrease the chances of lost circulation and/or differential sticking while drilling the Schrader. V-05 Permit to Drill Page 5 Well Control Surface hole will be drilled with a diverter. The intermediate and production hole sections will be drilled with well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer. This equipment is capable of handling maximum potential surface pressures. This being an injection well, BOP equipment will be tested to 4,000 psi. Anticipated surface pressures will not exceed 3,000 psi, therefore it will not be necessary to have two sets of pipe rams installed at all times. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Variance Request ~ To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line. To mitigate any risk involved with no flow paddle, the following steps will be taken while the flow paddle is removed from the flow line. Ensure PVT alarms are used and the pit levels are accurately monitored for any pit gain. Visually look down the riser during connections to ensure the well is not flowing. Surface Section • BOPE: • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 9 5/s" Casing Test: • Kick Tolerance: Hydril GK, 21-1/4", 2000 psi 1,148 psi - SV 1 (8.7 ppg EMW @ 2550' TVD) 893 psi -Based on a full column of gas @ 0.10 psi/ft Function Test 3,500 psi surface pressure test NA Intermediate Section Kick Tolerance and Integrity Testin • BOPE: Hydril, 13-5/8", 5000 psi • Maadmum anticipated BHP: 3,700 psi -Top Sag River (8.2 ppg EMW @ 8650' TVD) • Maximum surface pressure: 2,835 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular • 7" Casing Test: 4,000 psi surface pressure test • Integrity Test - 8-3/a" hole: LOT 20' - 50' from 9 5/8" shoe • Kick Tolerance: 25.1 bbl KT with a 10.1 ppg mud and a 11.4 ppg LOT (kick zone is Kup B) Production Section Kick Tolerance and Integrity Testin • BOPE: Hydril, 13-5/8", 5000 psi • Maximum anticipated BHP: 3,543 psi - Ivishak 42P (7.6 ppg @ 9000' TVD) • Maximum surface pressure: 2,643 psi -Based on a full column of gas @ 0.10 psi/ft • Planned BOP test pressure: 4,000 psi/250 psi Rams and 2,500 psi/250 psi Annular • 4-1/a" Liner Test: 4,000 psi surface pressure test • Integrity Test - 6-'/s" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with 11.0 ppg FIT • Planned completion fluid: Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul. all drilling and completion fluids and other Class II wastes to DS-04 for disposal. Haul all Class I wastes to Pad 3 for disposal. V-05 Permit to Drill Page 6 Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control /Reservoir Pressures: The Schrader Bluff sands are expected to be pressured at 5.8-8.6 ppg EMW, V-202 will be shut-in prior to spud and remain shut-in until the intermediate casing is cemented. The Kuparuk is expected to be pressured at 8.6-9.8 ppg EMW. The Ivishak is expected to be pressured at 7.6-8.2 ppg EMW. II. Hydrates and Shallow gas: Gas. Hydrates are expected at V-pad near the base of the permafrost. Setting casing through the SV 1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV 1. III. Lost Circulation /Breathing: Lost circulation is considered moderate at the fault crossings and unexpected fracture zones. The Shublik breathing phenomenon could occur on this well, however all lessons learned have been applied within the plan to mitigate this potential. Follow the RP guidelines for dealing with it if it occurs. IV. Kick Tolerance /Integrity Testing: Intermediate Section Kick Tolerance and Integrity Testing • Integrity Test - 8-3/a" hole: LOT 20' - 50' from 9 5/8" shoe • Kick Tolerance: 25.1 bbl KT with a 10.1 ppg mud and a 11.4 ppg LOT (kick zone is Kup B) Production Section Kick Tolerance and Integrity Testing • Integrity Test - 6-'/g" hole: FIT 20' - 50' from 7" shoe • Kick Tolerance: Calculated an Infinite KT with a 8.5 ppg mud with 11.0 ppg FIT V. Stuck Pipe There could be slight differential sticking across the open hole while running the 7" casing. Keep the casing moving as much as possible and follow the centralizer program to help with standoff. VI. Hydrogen Sulfide V Pad is not designated as an HZS site, however Standard Operating Procedures for HZS precautions should be followed at all times. H2S levels across the pad are typically in the 10-30 ppm range based on the latest samples taken. The highest reading was 300 ppm of V-117 on 4/3/07. ~ VII. Faults There is a moderate risk of losses incurred when crossing the faults. Formation Where Encounter Fault MD Intersect TVDSS Intersect Est. Throw Throw Direction .Uncertain Fault #1 in UG4A 3379 -2960 -100' to -140' SW +/-100' M.D. Fault #2 in JD 9899 -8245 110' to 140' S +/-.100' Fault #3 in JC 10195 -8500 20' to 40' W +/-100' CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-05 Permit to Drill Page 7 • V-05 Drill and Complete Procedure Summary Pre-Rig Work• 1. Install conductor and landing ring. 2. If necessary, level the pad and prepare location for rig move. Move well houses as necessary. 3. Shut-in V-202. Rig Operations• 1. MIRU Nabors 9ES. NU diverter spool & riser and function test. PU 4" DP as required and stand back in derrick. 2. MU 12 1/a" drilling assembly with MWD/GR and directionally drill surface hole to TD with one BHA. The TD will be below the top of the SV 1 sand. There is a planned short trip below the BPRF. 3. Run and cement the 9 5/8", 40#, L-80, BTC surface casing back to surface. Have a TAM collar on location if hole conditions warrant. At plug bump, test the 9-5/s" casing to 3,500 psi for 30 minutes. 4. ND diverter and riser. NU casing head and test. NU BOPE and test to 4,000 psi. PU 4" DP as needed. 5. MU 8 3/a" drilling BHA with MWD / GR / RES / NEU / AZM DENS / PWD and RIH to float collar. 6. Drill out shoe track. Circulate and condition mud. Displace well to new 8.8 ppg LSND drilling fluid. Drill 20' of new formation below rat-hole and perform a LOT. 7. Drill to +/-200' and above the HRZ, ensure mud is in condition to 10.1 ppg. During this time hold the pre-reservoir meeting highlighting kick tolerance and detection. 8. Directionally drill ahead to +/-200' and above the Kingak and ensure mud weight is at 10.1 ppg and continue drilling to TD maintaining sail angle & direction to the Top SAG. Short trip to the shoe and RBIH to TD. Circulate to ensure hole is clean. POOH. Stand back DP. 9. MU and run 7" 26# L-80 BTC-m x TC-II long string casing to TD. Cement in one stage to 500' MD above the Ma. Test the 7" casing to 4000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-5/8" annulus w/ diesel to 2,200' TVD. 10. PU 6-'/g" build BHA with MWD / GR / RES / NEU / AZM DENS /CCV and RIH to bottom. Drill out shoe track. Circulate and condition mud. Displace well to new 8.5 ppg Flo-Pro SF fluid. Dri1120' of new formation below rat hole and perform an FIT. Drill the build section, and POOH. 11. PU 6-'/8" drilling BHA with MWD / GR / RES / NEU / AZM DENS /CCV and continue geo-steering through Zone 4 to TD. Circulate and condition mud, back ream as necessary. At the shoe, open CCV and circulate at high rates. POOH. Lay down excess drill pipe. 12. RU E-line and run USIT log across cased hole to surface to prove isolation. 13. MU and run 4-1/z" 12.6#, L-80, IBT-M solid liner to TD and cement (ensure 150' overlap). Bump plug with perf pill. PU off liner hanger and circulate and condition mud. Displace over to 8.5 ppg brine. Test the 4-1/2" liner to 4,000 psi for 30 minutes. 14. PU 2.875" PAC and 2-7/8" 4 spf PJ Omega tapered perforation assembly and perf 600' of liner in overbalance. POH, LD perf guns. 15. MU and run the 4-'/z" 12.6#, L-80, TCII completion (run 4 GLMs if well is pre-produced). Land tubing hanger and test hanger pack-off to 5,000 psi. 16. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 4000 psi and annulus to 4,000 psi. Shear DCK valve. 17. Reverse in brine with corrosion inhibitor to protect the annulus. Reverse in diesel freeze protect to 2200' md, allow to u- tube. 18. Install TWC and test from below to 1,000 psi. ND the BOPE. NU and test the double master to 5,000 psi. 19. Pull TWC then install BPV. Secure the well and rig down /move off Nabors 9ES. Post-Rie Work• 1. Install the Tree with Electric Surface Safety valve. 2. MIRU slickline. Pull the ball and rod /RHC plug. Install gas lift valves in mandrels. 3. Replace well houses as necessary. V-05 Permit to Drill Page 8 41 /16" CAN ' D * FMC CTUATOR: Electric . ELEV = 28.5 F. ELEV = XXX OP a 300' Angle = 104 um MD= xxxx' um ND g xxxx' Prop~d Compl®tion V-06 I 19-5/8" CSG. 40M, L-80, ~ 8.835" I Minim~n ID = 3.725" XN Nipple GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE a I®G-2 oac-2 s l<BG-a 2 KBG-2 1 KBG-2 10139' H4-1/2" X Nipple (3.813" ~) 10158' H Baker S-3 Packer, T' x 4.5" a-1/2" L-80, 12.6 Ib/ft, TCII, 113= 3.958" ~• 4.5" WLEG, ID= 3.958" ~ 10219' ~ 10~8~ T' CSG, 26#, L-80, 0.0383 bpf, ID~6.276"~-i 1 PERFORATION SUMIAARY REl' LOG: ANGLE AT TOP PE}ZF: xx° SIZE SPF gVTER\/AL OpNSgz DATE 2-7/8" 4 Opn ~ 41/2", L-80, 12.6X, ~T M ~ PBTD H 12484' TE REV BY COMMENTS PRUDHOE BAY UN(T WELL: V-05 PERMT No: xxxxx API No: 50-029-xxxxx {9-518" TAM pbrt Copar - ~ RUN ~ 41/2" HES X Nlpppk . ~ 3.813" 10179' 4-1/2" X Nipple (3.813" ~ 10199' 41/2" XN Nipple (3.725" ~ 10219' 5" x 7" L'mer top Packer w/ Tieback Sleeve ARID - I 15°00'00" PLAN~Z - v-2zai v-zo7 V-120 ^ ^ V-115 V-03 ^ ^ V-2131 V-218i ^ ^ V-100 V-111 ^ ^ V-122 V-2161 ^ ^ V-117 V-103 ^ V-212 ^ ^ V-121 v-1os ^ ^ v-2ni ^ V-205 V-04 ^ V-105i ^ ^ V-01 V-2211 ^ ^ V-223i V-07 ^ V-222i ^ V-102 ^ ^ V-SPARE (s~or s-L) v-zo1 ^ V-107 ^ ^ SLOT 5-J V-02 ^ ^ V-2151 V-104i ^ ^ V-204 V-210i ^ ^ V-114 V-202 ^ ^ V-119 V-2141 ^ ^ V-109 V-101 ^ V-211i ^ V-113 v-1o6 ^ ~V-05 ~ V-203 ^ V-112 V-PAD TO SPINE ROAD - ~ P p,0 ~ wDp SO / NOTES 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD-27. 2. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 3. BASIS OF ELEVATION IS V-PAD OPERATOR MONUMENTATION. ELEVATIONS ARE BP MEAN SEA LEVEL DATUM. 4. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. 5. REFERENCE FIELD BOOK: W008-07 PGS. 37 & 38. 6. DATE OF SURVEY: MAY 18, 2008. o ~ "J rr ,n J l PADS ,f I ~ ;~ ~ ' ~ i ~~_ ~ I) ~ ~:~3fi r d tt Cep ~~- ~ ~v D ) ~ 51~ ry ;p o,Q ~~ ~ ~•~ ~°~ , ~ ~ T UW(~EST ~~ KSTATE K 1 J ~~ b I f'r D .l ; ~~, p S y 110` (`~1;~ Y`V~ S ; \i. L ~1 1 d 11 ;~ ~ o° ~ -0 01 I:j'~ VICINITY MAP N.T.S. LEGEND -~ AS-STAKED CONDUCTOR ^ EXISTING CONDUCTOR LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC PAD SECTION N0. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS Y= 5,969,876.51 N 10,000.00 70°19'38.792" 70.3274422° 52 8 4,630' FSL V-05 X= 590,442.11 E 4,645.00 149'15'59.493" 149.2665258' ' 1,861'FEL - - - - -- - CHECKED: on,~nnnn, ~~ SPRINGBER DATE: S/20/08 ~~` DRAWING: _ EReo6 wov o3-0o GREATER PRUDHOE BAY V-PAD SHEET: ~ ~~e~O~o Da ND AS-STAKED CONDUCTOR SCALE: 1 OF 1 1„=tso• WELL V-05 ~~ V-05 (P10) Pro Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA structure 1 slot: V-Pad I Plan V Slot (S-B) ' ~~ Well: ~~ ~~ Plan V-05 (SB) ~ Borehole: ~~ Plan V-05 UWIIAPIff: 50029 Survey Name 1 Date: V-05 (P10)1 April 15, 2008 Tort 1 AHD I DDI 1 ERD ratio: 205.089° 17198.55 ft / 6.307 10.788 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location LatlLong: N 70.32744235, W 149.26652599 Location Grid WE YIX: N 5969876.600 ftUS, E 590442.100 ftUS Grid Convergence Angle: +0.69066680° Grid Scale Factor: 0.99990929 Say Schlumberger Survey 1 DLS Computation Method: Minimum Curvature / Lubinski Vertical Section Azimuth: 10.000° Vertical Section Origin: N 0.000 ft, E 0.000 ft ND Reference Datum: Rotary Table ND Reference Elevation: 82.50 ft relative to MSL Sea Bed 1 Ground Level Elevation: 54.00 ft relahve to MSL Magnetic Declination: 22.639° Total Field Strength: 57664.215 nT Magnetic Dip: 80.882° Declination Date: December 14, 2008 Magnetic Declination Model: BGGM 2007 North Reference: True North Total Corr Mag North a True North: +22.639° C~ Comments Measured Inclination Azimuth Subsea ND ND Vertical NS ~ Mag I Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft fi fi ft ft de de 100 ft Index ftUS ftUS l~tt U.UU U.UU 33U.UU -tSZ.bU U.UU U.UU U.UU U.UU - U.VV U.UU O`Jb`Jtf/O.OU OJU44L.IU IV /U.3L/44L3D VV 14y.LO0ULU`J`J KOP Bld 1.5/100 300.00 0.00 330.00 217.50 300.00 0.00 0.00 0.00 330.OOM 0.00 0.00 5969876.60 590442.10 N 70.32744235 W 149.26652599 G1 332.50 0.49 330.00 250.00 332.50 0.11 0.12 -0.07 330.OOM 1.50 0.00 5969876.72 590442.03 N 70.32744267 W 149.26652655 Bld 2/100 400.00 1.50 330.00 317.49 399.99 1.00 1.13 -0.65 326.85M 1.50 0.29 5969877.73 590441.43 N 70.32744544 W 149.26653130 500.00 3.50 326.85 417.39 499.89 4.23 4.82 -2.98 325.99M 2.00 1.30 5969881.38 590439.07 N 70.32745552 W 149.26655013 600.00 5.50 325.99 517.08 599.58 9.90 11.35 -7.32 1.50E 2.00 1.87 5969887.86 590434.64 N 70.32747334 W 149.26658538 700.00 7.50 325.59 616.43 698.93 18.01 20.70 -13.69 1.10E 2.00 2.27 5969897.13 590428.16 N 70.32749889 W 149.26663700 800.00 9.50 325.36 715.33 797.83 28.54 32.87 -22.07 0.87E 2.00 2.58 5969909.20 590419.64 N 70.32753214 W 149.26670493 900.00 11.50 325.21 813.65 896.15 41.48 47.84 -32.44 0.72E 2.00 2.82 5969924.05 590409.08 N 70.32757305 W 149.26678908 SV6 967.88 12.86 325.13 880.00 962.50 51.64 59.60 -40.62 0.65E 2.00 2.97 5969935.70 590400.76 N 70.32760516 W 149.26685541 1000.00 13.50 325.10 911.27 993.77 56.82 65.60 -44.81 0.62E 2.00 3.03 5969941.65 590396.50 N 70.32762157 W 149.2668 1100.00 15.50 325.02 1008.08 1090.58 74.54 86.12 -59.15 0.54E 2.00 3.21 5969962.00 590381.92 N 70.32767763 W 149.2670 End Bld 1125.00 16.00 325.00 1032.14 1114.64 79.34 91.68 -63.04 -- 2.00 3.25 5969967.51 590377.96 N 70.32769282 W 149.26703721 EOCU 1559.70 16:00 325.00 1450.00 1532.50 164.07 189.83 -131.77 --- 0.00 3.58 5970064.81 590308.07 N 70.32796095 W 149.26759451 Bld 3/100 1640.00 16.00 325.00 1527.19 1609.69 179.72 207.97 -144.46 HS 0.00 3.62 5970082.79 590295.15 N 70.32801049 W 149.26769747 SV5 1648.13 16.24 325.00 1535.00 1617.50 181.32 209.81 -145.76 HS 3.00 3.63 5970084.62 590293.84 N 70.32801554 W 149.26770797 1700.00 17.80 325.00 1584.60 1667.10 192.05 222.25 -154.47 HS 3.00 3.69 5970096.95 590284.98 N 70.32804952 W 149.26777860 SV4 1779.75 20.19 325.00 1660.00 1742.50 210.41 243.52 -169.36 HS 3.00 3.79 5970118.03 590269.84 N 70.32810760 W 149.26789933 1800.00 20.80 325.00 1678.97 1761.47 215.42 249.32 -173.42 HS 3.00 3.81 5970123.79 590265.70 N 70.32812347 W 149.26793231 End Bld 1811.81 21.15 325.00 1690.00 1772.50 218.41 252.79 -175.85 -- 3.00 3.82 5970127.23 590263.23 N 70.32813294 W 149.26795198 Base Perm 1827.90 21.15 325.00 1705.00 1787.50 222.52 257.54 -179.18 --- 0.00 3.83 5970131.94 590259.85 N 70.32814593 W 149.26797898 Crv 3/100 1843.98 21.15 325.00 1720.00 1802.50 226.62 262.30 -182.51 HS 0.00 3.84 5970136.65 590256.46 N 70.32815891 W 149.26800598 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\Plan V-05 (SB)\Plan V-05\V-05 (P10) Generated 4/15/2008 8:22 AM Page 1 of 4 Comments Measured Inclination Azimuth SutrSea ND ND Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS 1yUU.UU ZZ.253 3L5.UU 1//1.y4 12554.44 241.45 Z/y.4i5 -1y4.54 fiJ 3.UU 3.yU 5y/U153.tly 5yUZ44.ZZ N /U.3L25ZU52517 W 14y.Z6i51U35ti 2000.00 25.83 325.00 1863.04 1945.54 270.59 313.23 -218.17 HS 3.00 4.01 5970187.15 590220.19 N 70.32829806 W 149.26829521 2100.00 28.83 325.00 1951.87 2034.37 303.06 350.84 -244.51 HS 3.00 4.10 5970224.44 590193.40 N 70.32840081 W 149.26850878 Crv 3/100 2123.98 29.55 325.00 1972.80 2055.30 311.33 360.43 -251.22 78.93R 3.00 4.13 5970233.94 590186.58 N 70.32842699 W 149.26856319 2200.00 30.07 329.47 2038.77 2121.27 339.06 392.19 -271.65 75.05R 3.00 4.20 5970265.45 590165.77 N 70.32851377 W 149.26872887 SV3 2212.98 30.17 330.22 2050.00 2132.50 344.04 397.83 -274.92 74.41R 3.00 4.21 5970271.05 590162.43 N 70.32852916 W 149.26875542 2300.00 30.96 335.11 2124.93 2207.43 379.21 437.12 -295.21 70.19R 3.00 4.28 5970310.09 590141.67 N 70.32863650 W 149.26891993 2400.00 32.09 340.43 2210.19 2292.69 423.43 485.49 -314.94 65.66R 3.00 4.36 5970358.22 590121.36 N 70.32876866 W 149.26907995 SV2 2417.51 32.31 341.32 2225.00 2307.50 431.58 494.31 -317.99 64.90R 3.00 4.37 5970366.99 590118.20 N 70.32879274 W 149.26910474 2500.00 33.43 345.39 2294.29 2376.79 471.59 537.19 -330.79 61.48R 3.00 4.44 5970409.72 590104.89 N 70.32890989 W 149.269 2600.00 34.95 350.00 2377.02 2459.52 523.56 592.07 -342.71 57.67R 3.00 4.51 5970464.44 590092.31 2 N 70.32905980 W 149.269 2700.00 36.63 354.25 2458.15 2540.65 579.20 649.97 -350.68 54.22R 3.00 4.57 5970522.24 590083.65 N 70.32921799 W 149.269 2800.00 38.45 358.16 2537.45 2619.95 638.36 710.74 -354.66 51.12R 3.00 4.63 5970582.95 590078.93 N 70.32938401 W 149.26940219 SV1 2816.06 38.75 358.76 2550.00 2632.50 648.18 720.76 -354.93 50.65R 3.00 4.64 5970592.96 590078.54 N 70.32941138 W 149.26940437 2900.00 40.39 1.77 2614.71 2697.21 700.87 774.22 -354.66 48.33R 3.00 4.70 5970646.42 590078.17 N 70.32955742 W 149.26940218 3000.00 42.43 5.09 2689.71 2772.21 766.57 840.22 -350.67 45.84R 3.00 4.75 5970712.46 590081.37 N 70.32973774 W 149.26936981 3100.00 44.57 8.16 2762.25 2844.75 835.26 908.57 -342.69 43.62R 3.00 4.81 5970780.89 590088.51 N 70.32992447 W 149.26930517 End Crv 3117.59 44.95 8.67 2774.74 2857.24 847.64 920.82 -340.88 -- 3.00 4.82 5970793.16 590090.18 N 70.32995794 W 149.26929048 9-5/8" Csg 3125.02 44.95 8.67 2780.00 2862.50 852.89 926.02 -340.09 --- 0.00 4.82 5970798.37 590090.91 N 70.32997213 W 149.26928406 UG4 3238.06 44.95 8.67 2860.00 2942.50 932.73 1004.96 -328.05 -- 0.00 4.86 5970877.44 590102.00 N 70.33018780 W 149.26918643 UG4A 3280.45 44.95 8.67 2890.00 2972.50 962.67 1034.57 -323.53 --- 0.00 4.87 5970907.10 590106.15 N 70.33026868 W 149.26914981 Fault 1 Crossing 3379.36 44.95 8.67 2960.00 3042.50 1032.53 1103.65 -312.99 -- 0.00 4.90 5970976.29 590115.86 N 70.33045739 W 149.26906438 UG3 3605.43 44.95 8.67 3120.00 3202.50 1192.20 1261.54 -288.91 --- 0.00 4.96 5971134.45 590138.03 N 70.33088874 W 149.26886911 UG1 4297.79 44.95 8.67 3610.00 3692.50 1681.21 1745.08 -215.15 --- 0.00 5.11 5971618.80 590205.95 N 70.33220975 W 149.26827103 Ma 4721.68 44.95 8.67 3910.00 3992.50 1980.60 2041.13 -169.99 --- 0.00 5.18 5971915.34 590247.53 N 70.33301853 W 149.26790482 Na 5060.79 44.95 8.67 4150.00 4232.50 2220.11 2277.96 -133.87 --- 0.00 5.23 5972152.57 590280.80 N 70.33366555 W 149.26761184 OA 5293.93 44.95 8.67 4315.00 4397.50 2384.78 2440.79 -109.03 -- 0.00 5.26 5972315.67 590303.67 N 70.33411037 W 149.26741040 Crv 3.5/100 5378.71 44.95 8.67 4375.00 4457.50 2444.65 2500.00 -100.00 168.73R 0.00 5.27 5972374.98 590311.98 N 70.33427213 W 149.26733714 OBa 5385.76 44.71 8.74 4380.00 4462.50 2449.62 2504.91 -99.25 168.68R 3.50 5.28 5972379.90 590312.68 N 70.33428555 W 149.267 5400.00 44.22 8.88 4390.17 4472.67 2459.60 2514.77 -97.72 168.58R 3.50 5.28 5972389.78 590314.09 N 70.33431248 W 149.26731865 OBb 5447.94 42.58 9.37 4425.00 4507.50 2492.53 2547.29 -92.50 168.22R 3.50 5.30 5972422.36 590318.92 N 70.33440133 W 149.26727629 5500.00 40.79 9.94 4463.88 4546.38 2527.15 2581.42 -86.69 167.80R 3.50 5.32 5972456.55 590324.31 N 70.33449456 W 149.26722921 OBc 5521.18 40.07 10.19 4480.00 4562.50 2540.89 2594.95 -84.29 167.61 R 3.50 5.33 5972470.10 590326:54 N 70.33453151 W 149.26720974 OBd 5585.50 37.87 10.97 4530.00 4612.50 2581.33 2634.71 -76.87 167.OOR 3.50 5.35 5972509.94 590333.48 N 70.33464013 W 149.26714956 5600.00 37.38 11.16 4541.49 4623.99 2590.18 2643.39 -75.17 166.85R 3.50 5.35 5972518.65 590335.08 N 70.33466387 W 149.26713578 5700.00 33.98 12.58 4622.71 4705.21 2648.46 2700.46 -63.21 165.69R 3.50 5.38 5972575.86 590346.35 N 70.33481978 W 149.26703871 Oef 5720.77 33.27 12.91 4640.00 4722.50 2659.95 2711.68 -60.67 165.42R 3.50 5.39 5972587.10 590348.76 N 70.33485042 W 149.26701813 OBf Base 5779.91 31.27 13.91 4690.00 4772.50 2691.47 2742.40 -53.35 164.57R 3.50 5.41 5972617.90 590355.70 N 70.33493434 W 149.26695878 5800.00 30.60 14.28 4707.24 4789.74 2701.77 2752.42 -50.84 164.26R 3.50 5.41 5972627.95 590358.10 N 70.33496171 W 149.26693837 End Crv 5804.71 30.44 14.37 4711.29 4793.79 2704.16 2754.73 -50.25 -- 3.50 5.41 5972630.27 590358.66 N 70.33496804 W 149.26693357 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\Plan V-05 (SB)\Plan V-05\V-05 (P10) Generated 4/15/2008 8:22 AM Page 2 of 4 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical NS EW Mag 1 Grev DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty fi de de ft ft ft K fi de de 100 ft Index ftUS fiUS I.MZ 07JJ.// JV.44 74.J/ 4`J`JAUU DV//.DU Lrf/U.Ji3 LYIO.LL -tl.U/ CM1 6922.47 30.44 14. 37 5675.00 5757.50 3268.78 3303.29 90.30 TLBK 7322.62 30.44 14 .37 6020.00 6102.50 3470.91 3499.66 140.61 THRZ 7548.80 30.44 14. 37 6215.00 6297.50 3585.16 3610.66 169.05 TKLB 7780.77 30.44 14. 37 6415.00 6497.50 3702.34 3724.50 198.21 TKC4 7792.37 30.44 14. 37 6425.00 6507.50 3708.20 3730.19 199.67 TKC2E 7931.55 30.44 14. 37 6545.00 6627.50 3778.50 3798.50 217.17 TKC1C 8006.94 30.44 14. 37 6610.00 6692.50 3816.59 3835.50 226.65 TKB / LCU 8047.53 30.44 14.37 6645.00 6727.50 3837.09 3855.42 TMLV 8273.71 30.44 14.37 6840.00 6922.50 3951.34 3966.42 Crv 4/100 8415.28 30.44 14.37 6962.06 7044.56 4022.85 4035.89 8500.00 29.51 20.90 7035.47 7117.97 4064.76 4076.19 8600.00 28.86 29.00 7122.81 7205.31 4111.78 4120.32 8700.00 28.70 37.30 7210.49 7292.99 4155.95 4160.54 8800.00 29.05 45.56 7298.10 7380.60 4197.04 4196.65 8900.00 29.88 53.52 7385.20 7467.70 4234.87 4228.47 End Crv 8959.13 30.59 58.00 7436.29 7518.79 4255.63 4245.21 TKNG 9188.82 30.59 58.00 7634.00 7716.50 4333.85 4307.16 TJF 9352.62 30.59 58.00 7775.00 7857.50 4389.63 4351.34 TJE 9704.62 30.59 58.00 8078.00 8160.50 4509.51 4446.27 TJD 9890.50 30.59 58.00 8238.00 8320.50 4572.82 4496.41 Fault 2 Crossing 9898.63 30.59 58.00 8245.00 8327.50 4575.59 4498.60 TJC 10078.70 30.59 58.00 8400.00 8482.50 4636.91 4547.17 Fault 3 Crossing 10194.87 30.59 58.00 8500.00 8582.50 4676.48 4578.50 TJB 10194.89 30.59 58.00 8500.01 8582.51 4676.48 4578.50 TJA 10252.96 30.59 58.00 8550.00 8632.50 4696.26 4594.17 TSAG 10369.12 30.59 58.00 8649.99 8732.49 4735.82 4625.50 V-05 Tgt 1 Sag 10369.13 30.59 58.00 8650.00 8732.50 4735.82 4625.50 7" Csg 10369.14 30.59 58.00 8650.01 8732.51 4735.83 4625.50 Crv 10/100 10399.13 30.59 58.00 8675.82 8758.32 4746.04 4633.59 10400.00 30.66 58.11 8676.57 8759.07 4746.33 4633.83 TSHA 10407.50 31.25 59.00 8683.00 8765.50 4748.89 4635.84 10500.00 38.95 67.99 8758.67 8841.17 4780.11 4659.14 TSHB 10505.58 39.43 68.43 8763.00 8845.50 4781.97 4660.45 TSHC 10531.92 41.73 70.40 8783.00 8865.50 4790.68 4666.47 TSHD 10564.84 44.65 72.63 8807.00 8889.50 4801.41 4673.60 TE/L 10583.38 46.31 73.78 8820.00 8902.50 4807.37 .4677.42 10600.00 47.81 74.77 8831.32 8913.82 4812.65 4680.71 TSAD 10622.29 49.83 76.01 8846.00 8928.50 4819.63 4684.94 45P 10678.01 54.94 78.83 8880.00 8962.50 4836.53 4694.51 --- uvu o.4w ~`J/L/`JL.LJ D`JUJ`J6.U0 IV /V.JJ04U`JCI vv /4y.mo~y/ao --- 0.00 5.49 5973180.43 590492.57 N 70.33646663 W 149.26579346 --- 0.00 5.51 5973377.38 590540.51 N 70.33700312 W 149.26538526 -- 0.00 5.52 5973488. 70 -- 0.00 5.54 5973602. 87 --- 0.00 5.54 5973608. 58 --- 0.00 5.55 5973677. 09 --- 0.00 5.55 5973714. 20 590567.60 590595.39 590596.78 590613.45 590622.49 590627.35 590654.44 590671.40 590683.69 590703.65 590729.42 590760.87 590797.86 590822.27 590920.64 N 70.33730635 W 149.26515454 N 70.33761735 W 149.26491788 N 70.33763290 W 149.26490605 N 70.33781951 W 149.26476406 N 70.33792058 W 149.26468714 N 70.33797501 W 149.26464573 N 70.33827824 W 149.2644 N 70.33846804 W 149.264 N 70.33857813 W 149.2641 N 70.33869870 W 149.26400061 N 70.33880857 W 149.26378756 N 70.33890721 W 149.26352876 N 70.33899413 W 149.26322547 N 70.33903985 W 149.26302579 N 70.33920907 W 149.26222140 231.76 --- 0.00 5.55 5973734.18 260.19 -- 0.00 5.56 5973845.50 278.00 108. 64R 0.00 5.57 5973915.18 290.77 102. 98R 4.00 5.59 5973955.62 311.26 95. 91 R 4.00 5.62 5973999.99 337.52 88. 63R 4.00 5.65 5974040.52 369.42 81. 39R 4.00 5.67 5974077.01 406.79 74. 46R 4.00 5.69 5974109.28 431.40 --- 4.00 5.71 5974126.31 530.54 --- 0.00 5.72 5974189.44 601.24 --- 0.00 5.73 5974234.46 590990.80 N 70.33932975 W 149.26164773 753.18 --- 0.00 5.74 5974331.22 591141.56 N 70.33958908 W 149.26041492 833.41 --- 0.00 5.75 5974382.31 591221.18 N 70.33972601 W 149.25976391 836.92 --- 0.00 5.75 5974384.54 591224.66 N 70.33973200 W 149.25973543 914.64 --- 0.00 5.76 5974434.04 591301.78 N 70.33986466 W 149.25910477 964.78 --- 0.00 5.76 5974465.97 591351.54 N 70.33995024 W 149.25869788 964.79 -- 0.00 5.76 5974465.98 591351.55 N 70.33995025 W 149.25869784 989.86 -- 0.00 5.77 5974481.94 591376.42 N 70.33999303 W 149.25849443 1040.00 --- 0.00 5.77 5974513.87 591426.17 N 70.34007860 W 149.25808758 1040.00 -- 0.00 5.77 5974513.87 591426.18 N 70.34007861 W 149.25808754 1040.00 --- 0.00 5.77 5974513.87 591426.18 N 70.34007862 W 149.258 1052.95 38.49R 0.00 5.77 5974522.12 591439.03 N 70.34010071 W 149.25798247 1053.32 38.40R 10.00 5.77 5974522.35 591439.40 N 70.34010135 W 149.25797943 1056.61 37.63R 10.00 5.78 5974524.41 591442.66 N 70.34010684 W 149.25795272 1104.24 30.26R 10.00 5.82 5974548.28 591490.00 N 70.34017050 W 149.25756625 1107.52 29.91R 10.00 5.82 5974549.63 591493.26 N 70.34017407 W 149.25753967 1123.55 28.42R 10.00 5.84 5974555.84 591509.22 N 70.34019050 W 149.25740954 1144.92 26.79R 10.00 5.85 5974563.23 591530.50 N 70.34020997 W 149.25723616 1157.58 25.98R 10.00 5.86 5974567.20 591543.11 N 70.34022040 W 149.25713346 1169.29 25.31 R 10.00 5.87 5974570.63 591554.78 N 70.34022940 W 149.25703843 1185.52 24.49R 10.00 5.88 5974575.06 591570.96 N 70.34024094 W 149.25690670 1228.59 22.77R 10.00 5.90 5974585.14 591613.90 N 70.34026706 W 149.25655729 WeIlDesign Ver SP 2.1 Bld( doc40x_100) Plan V Slot (S-B)\Plan V-05 (SB)\Plan V-OS\V-05 (P10) Generated 4/15/2008 8:22 AM Page 3 of 4 Comments Measured Inclination Azimuth Sub-Sea TVD TyD Vertical NS EW Mag 1 Grav DLS Directional Northing Easting Latitude Longitude Depth Section Tool Face Difficulty ft de de ft ft ft ft ft de de 100 ft Index ftUS ftUS 1U/UU. UU bti.y/ /y. 2S5 titsy"L. JI by/4. tf1 4iS4L.yti 4tiy/.tStf 114ti.4y LL.LUK IU .UU 5.`Jl 5y/4bCt5 ./S Oy1bJ1./U N /U.J4UL/bLb VV 14`J.LOti417`J`9 44P 10765. 42 63.06 82. 62 8925. 00 9007. 50 4861.14 4706.47 1302.47 20.81R 10. 00 5.94 5974597. 99 591687.62 N 70.34029970 W 149.25595782 10800. 00 66.30 83. 96 8939. 79 9022. 29 4870.12 4710.12 1333.50 20.24R 10 .00 5.95 5974602 .01 591718.61 N 70.34030965 W 149.25570597 43P 10872. 76 73.14 86. 58 8965. 00 9047. 50 4887.43 4715.71 1401.48 19.33R 10. 00 5.98 5974608. 42 591786.51 N 70.34032489 W 149.25515441 10900. 00 75.72 87. 51 8972. 31 9054. 81 4893.31 4717.06 1427.68 19.OSR 10 .00 5.99 5974610 .09 591812.69 N 70.34032857 W 149.25494183 End Crv 10910. 70 76.73 87. 87 8974. 86 9057. 36 4895.53 4717.48 1438.06 --- 10 .00 6.00 5974610 .63 591823.06 N 70.34032971 W 149.25485758 Crv 10/100 10948. 88 76.73 87. 87 8983. 62 9066. 12 4903.34 4718.86 1475.19 21.13E 0. 00 6.00 5974612 .46 591860.17 N 70.34033346 W 149.25455628 11000. 00 81.50 86. 01 8993. 28 9075. 78 4914.68 4721.55 1525.31 20.78E 10 .00 6.02 5974615 .75 591910.25 N 70.34034077 W 149.25414966 42P 11030. 18 84.32 84. 93 8997. 00 9079. 50 4922.20 4723.91 1555.16 20.64E 10. 00 6.03 5974618. 47 591940.07 N 70.34034722 W 149.25390742 V-05 Tgt 3 Invert 11090. 80 90.00 82. 80 9000. 00 9082. 50 4939.01 4730.38 1615.33 0.44E 10 .00 6.06 5974625 .67 592000.15 N 70.34036485 W 149.253 11100. 00 90.92 82. 79 8999. 93 9082. 43 4941.73 4731.53 1624.46 0.44E 10 .00 6.06 5974626 .93 592009.26 4 N 70.34036800 W 149.253 11200. 00 100.92 82. 72 8989. 63 9072. 13 4971.19 4744.06 1723.00 0.45E 10 .00 6.10 5974640 .65 592107.64 N 70.34040216 W 149.252 End Crv 11234. 34 104.35 82. 69 8982. 12 9064. 62 4981.15 4748.32 1756.23 --- 10 .00 6.11 5974645 .30 592140.81 N 70.34041377 W 149.25227590 Crv 10/100 11493. 44 104.35 82. 69 8917. 88 9000. 38 5055.84 4780.26 2005.21 LS 0 .00 6.14 5974680 .24 592389.36 N 70.34050087 W 149.25025563 11500. 00 103.70 82. 69 8916. 29 8998. 79 5057.74 4781.07 2011.52 LS 10 .00 6.14 5974681 .13 592395.66 N 70.34050308 W 149.25020441 11600. 00 93.70 82. 70 8901. 19 8983. 69 5087.11 4793.63 2109.44 LS 10 .00 6.18 5974694 .86 592493.42 N 70.34053731 W 149.24940983 V-05 Tgt 4 11636. 97 90.00 82. 70 8900. 00 8982. 50 5098.09 4798.33 2146.09 --- 10 .00 6.19 5974700 .00 592530.00 N 70.34055011 W 149.24911247 Drp 10/100 11886. 97 90.00 82. 70 8900. 00 8982. 50 5172.44 4830.09 2394.06 LS 0 .00 6.22 5974734 .75 592777.55 N 70.34063669 W 149.24710032 11900. 00 88.70 82. 70 8900. 15 8982. 65 5176.31 4831.75 2406.98 LS 10 .00 6.22 5974736 .56 592790.45 N 70.34064120 W 149.24699546 12000. 00 78.70 82. 70 8911. 11 8993. 61 5205.83 4844.36 2505.45 LS 10 .00 6.25 5974750 .36 592888.75 N 70.34067557 W 149.24619648 End Drp 12036. 97 75.00 82. 70 8919. 52 9002. 02 5216.54 4848.94 2541.15 --- 10 .00 6.26 5974755 .36 592924.39 N 70.34068803 W 149.24590676 12444. 50 75.00 82. 70 9025. 00 9107. 50 5333.60 4898.95 2931.61 --- 0 .00 6.30 5974810 .08 593314.18 N 70.34082429 W 149.24273841 TD / 4-1 /2" Lnr 12544. 50 75.00 82. 70 9050. 88 9133. 38 5362.32 4911.23 3027.42 -- 0 .00 6.31 5974823 .50 593409.82 N 70.34085771 W 149.24196095 Legal Description: Northing fYl fftUSl Easting (X) fftUSl Surface : 4630 FS L 1861 FEL S11 T11 N R 11 E UM 5969876.60 590442.10 V-05 Tgt : 3976 FS L 817 FEL S2 T11 N R11 E UM 5974513.87 591426.18 BHL : 4261 FS L 4109 FEL S1 T11 N R1 1 E UM 5974823.50 593409.82 r~ ~J WeIlDesign Ver SP 2.1 Bld(doc40x_100) Plan V Slot (S-B)\Plan V-05 (SB)\Plan V-05\V-05 (P10) Generated 4/15/2008 8:22 AM Page 4 of 4 • by Schlumherger WELL FIELD STRUCTURE V-05 (P10) Prudhoe Bay Unit - WOA V-Pad Ma9nalic Parameters Surlaca Lxaiion NA02] Alaska Slate Planas, Zone Od, US Feel Miscellaneous Motlel: BGGM 200] Dip: BO 8B2° Dala: December id, 2068 Lar. N]019 38 >92 NorlM1ing: 6969B)fi 6011US Gntl Conv: X069668660° Slor. Plan V Sb115~6) ND Rel. Rotary Table 182 50 N above MSL) Mag Dec: .22.639° FS: Sifi662nT Lon: Wt49 15 59 496 Easeng: 5906d2.101tt1S Srale Fact: 0.999999292 Plan: V-651P101 Srvy Dale: Apn115. 2008 1800 2400 3000 3600 0 8400 .............. RTE ~ ....... ......... ~ O ca OP Bld 1.51100 :-: . _.. _.._.._.._.._. ._.. _.._.. C ~ Bld 21100 _ _ I I m (6 .._.._.._.._.._. _. .. • v8.. ~ 9000 _.._.. End Bld c 1200 .....:....... Q ......... ~ End Crv; 2400 ............ ~ 3600 0 0 c 0) U ~ 4800 H 6000 End Crv 9.518" Csg A Fault 1 Crossing .............................................: Fault 2 Crossing -OS .._ ._i._.._.._.._.._.._.._.._..y.._.._.._.._.._.._.._.._..~.._.._.._..-.._.._.._.._..i.._.._.. _. .. _.._ Fault 3 Crossing ._. ~C ' V-05 Tgt 1 Sag ._.._.._ ._..fl.._. .._.._.._.._.._.._.._ _.._.._.._..-..-.._.. ._.._.._.._.._.._.._.. 1.•- - - crvtoltoo._ _ ... _..... _ .....::..:~. A ._:: _::_::_::_: _.._.._. _.._.._......::a::.................:_.:_ ~..~. _. _.._..~.._:._ .. .. .. . .. . .. .. .. .. ::z::z::z::x::z::_ ::e::e::.::z::z::z::z::z::z::z:::::z::s::s::z::z::z::s::a::s::z::z::~:: z::z::s::z::a::z:: z::z End Crv ~ End Drp -O5 (P10) ' VJ15 Tgt 4 : Crv 10/100 End Crv ~ Drp 10/100 Crv 101100 TD I:Ltl2" Lnr V-05 Tgt 3 Inve4 1800 2400 3000 3600 Vertical Section (ft) Azim = 80°, Scale = 1(in):600(ft) Origin = 0 N/-S, 0 E/-V ....................: .................................. :...................................:..... -.._..-.. _.._. _..-..-..-..-.._.._.._ .y. _.._.._.._..-.._.._.._.. j..._.._.._.._.._ 2400 .................. °.. f .................................. E.................................. <........................ 3600 Crv 3.5/100 4800 ._.._ _.._.._.._.._.._.._.._.._ _.._.._.._.._.._.._.._. _.._..-.._.._.._ ..{..t.._.. 7200 ......................................................................................i........................................ 8400 ~ ............................................................;..................................:........................ 0 1200 2400 3600 4800 Vertical Section (ft) Azim = 10°, Scale = 1(in):1200(ft) Origin = 0 N/-S, 0 E/-V .....: ........................{ 6000 n, atoa .................................. 7200 ~ nd Cr% 8400 8400 9000 by Schlumberger WELL V-05 (P10) FIELD Prudhoe Bay Unit - WOA STRUCTURE V-Pad Magnetlc Parame~ers Surtace Loca~wn NAD2) Alaska Stale Planes. ZOne 04, US Fael Miscellane ous Model: BGGM 20D> DIO. 80882' Dale December id, 2008 Lal. N'l01938.)92 M1inq. 59698]6.60 flU5 Grltl DOnV: ~06906fi680° Slol'. Plan V SbI IS-B) NO ReI' RoUry Table (82.50 Xabove MSLI Mag pec'. ~22.fi]9° FS. 5)686.2 nT Lon: W1691559 d96 Easiing'. 590442.10flUS Stale Facl'.0999909292 Plan: V-0SIP!DI Srvy Dale. Apn115. 2008 -600 0 600 1200 1800 2400 3000 4800 4200 3600 n n 3000 Z 0 0 c 2400 m U V V v 1800 1200 600 0 V-05 gt 1 Sa Crv 101100 _ - ~ ~-` ~ -- -!"-'"'-'-"~--' End Crv -OS ~P10; Fault 3:Crossin Fault 2 Crossin Entl Drp TD I A-1IZ' Lnr End Crv V-05Tgt 4; Drp tON 00 V-OS Flt 2 6300ss ~• Csg V-05 Sag HL 8650ss V-05 79t 3 Invert Crv t0/100 Crv 10/10U End Crv V-05 FII 5 8900ss civ atoo V-O5 Flt 3 B650ss -OS FI 1 2960ss 'a t 1 Crossin 9-518" Cs End Crv p 1 .....:......... ........................:..................................:..................................:..................................:..................................:..................................:.......... crv r/too :Crv 31100 End Bld Bld 31100 End Bld Bld 2700 KOP Bld 1.5]100 RTE 500 0 600 1200 1800 2400 3000 «< W Scale = 1(in):600(ft) E »> 4800 4200 3600 3000 2400 1800 1200 600 0 BP Alaska Anticollision Report Company: BP Amoco --_ - Date: 4/15/2008 Time: 08:21:48 Page: 1 Field: Prudhoe Bay Reference Site: PB V Pad Co-ordinat e(NE) Reference: Well: Plan V-05 (SB), True North Reference Well: Plan V-05 (SB) Vertical (T VD) Reference: V-07 Plan SB 82.5 Reference Wellpath: Plan V-05 Dh: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are L~QIicHaeells in thisf3tetdi pal Plan & PLANNED PROGRAM ~ Interpolation Method: MD Interval: 5.00 ft Error Model: ISCWSA Ellipse Depth Ran ge: 28.50 to 12544.50 ft Scan Method: Trav Cylinder North Maximum Radius: 1451.60 ft Error Surface: Ellipse + Casing I '~ Survey Program for Definitive Wellpath Date: 3/12/2008 Validated: No Version: 8 Planned From To Survey Toolcode Tool Name ii ft ft ~ i 28.50 800.00 Planned: Pla n #10 V-05 V2 GYD-GC-SS Gyrodata gyro single shots l 800.00 2200.00 Planned: Pla n #10 V-05 V2 MWD MWD - Standard i 800.00 3070.00 Planned: Pla n #10 V-05 V2 MWD+IFR+MS MWD +IFR + Multi Station i ;, 3070.00 10310.00 Planned: Pla n #10 V-05 V2 MWD+IFR+MS MWD +IFR + Multi Station 10310.00 12544.50 Planned: Pla n #10 V-05 V2 MWD+IFR+MS MWD +IFR + Multi Station Casing Points MD TVD Diameter Hole Site Name ft ft in in 3125.02 2862.50 9.625 12.250 9 5/8" 10369.13 8732.50 7.000 8.750 7" i 12544.50 9133.38 4.500 6.125 4-1/2" Summary <--------------- Offset W'ellpath - -_-____> - _ Reference Offset Ctr-Ctr No-Go .411owahle Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft PB L Pad L-03 L-03 VS 10901.90 13935.00 1125.66 236.37 889.29 Pass: Major Risk ~ PB V Pad Plan V-206 (S-K) Plan V-206 V3 Plan: PI 496.67 500.00 135.89 9.43 126.46 Pass: Major Risk !, PB V Pad Plan V-225 (S-D) Plan V-225 V3 Plan: PI 454.98 455.00 31.13 8.74 22.38 Pass: Major Risk j PB V Pad Plan V-226 (S-L) Plan V-226 V3 Plan: PI 437.80 440.00 151.04 8.38 142.66 Pass: Major Risk PB V Pad V-01 V-01 V15 446.55 450.00 221.16 8.06 213.10 Pass: Major Risk ', PB V Pad V-02 V-02 V12 1096.57 1095.00 123.70 18.39 105.31 Pass: Major Risk PB V Pad V-03 V-03 V7 868.44 785.00 403.35 13.96 389.40 Pass: Major Risk ', PB V Pad V-04 V-04 V7 1836.21 1820.00 252.82 37.12 215.69 Pass: Major Risk I PB V Pad V-07 V-07 V15 7013.67 6835.00 269.09 114.71 154.38 Pass: Major Risk PB V Pad V-101 V-101 V7 1866.38 1835.00 54.94 29.20 25.74 Pass: Major Risk i PB V Pad V-102 V-102 V5 710.01 695.00 230.10 13.40 216.70 Pass: Major Risk '~ PB V Pad V-104 V-104 V13 2204.09 2175.00 111.63 45.26 66.36 Pass: Major Risk PB V Pad V-105 V-105 V13 1024.31 1025.00 257.48 16.75 240.74 Pass: Major Risk PB V Pad V-106 V-106A V9 134.69 135.00 320.78 2.85 317.94 Pass: Major Risk PB V Pad V-106 V-106AP61 V7 134.69 135.00 320.78 2.85 317.94 Pass: Major Risk PB V Pad V-106 V-106AP62 V2 134.69 135.00 320.78 2.85 317.94 Pass: Major Risk ', PB V Pad V-106 V-106AP63 V2 134.69 135.00 320.78 2.85 317.94 Pass: Major Risk PB V Pad V-107 V-107 V5 1177.63 1175.00 162.39 19.34 143.04 Pass: Major Risk I PB V Pad V-108 V-108 V7 1232.11 1200.00 115.74 20.90 94.84 Pass: Major Risk ', PB V Pad V-109 V-109 V2 495.26 495.00 44.71 8.45 36.26 Pass: Major Risk ~ PB V Pad V-109 V-109P61 V5 495.26 495.00 44.71 8.45 36.26 Pass: Major Risk PB V Pad V-109 V-109P62 V2 495.26 495.00 44.71 8.45 36.26 Pass: Major Risk ~I PB V Pad V-111 V-111 V25 788.85 785.00 377.31 14.60 362.71 Pass: Major Risk I PB V Pad V-111 V-111 PB1 V9 798.67 795.00 377.49 17.07 360.41 Pass: Major Risk PB V Pad V-111 V-111 P62 V2 798.67 795.00 377.49 17.07 360.41 Pass: Major Risk PB V Pad V-111 V-111 P63 V6 788.85 785.00 377.31 14.60 362.71 Pass: Major Risk PB V Pad V-112 V-112 V8 341.00 340.00 16.73 7.51 9.22 Pass: Major Risk ~i, PB V Pad V-113 V-113 V6 475.14 475.00 14.70 7.54 7.16 Pass: Major Risk PB V Pad V-114 V-114 V5 609.62 615.00 69.80 10.77 59.03 Pass: Major Risk ~ PB V Pad V-114 V-114A V4 609.62 615.00 69.80 10.77 59.03 Pass: Major Risk '~ PB V Pad V-114 V-114APB1 V4 609.62 615.00 69.80 10.77 59.03 Pass: Major Risk PB V Pad V-114 V-114AP62 V2 609.62 615.00 69.80 10.77 59.03 Pass: Major Risk PB V Pad V-119 V-119 V15 474.77 475.00 60.72 8.48 52.23 Pass: Major Risk PB V Pad V-201 V-201 V10 2245.34 2180.00 191.56 38.71 152.85 Pass: Major Risk PB V Pad V-202 V-202 V10 1184.64 1170.00 113.77 19.54 94.23 Pass: Major Risk PB V Pad V-202 V-202L1 V5 1184.64 1170.00 113.77 19.49 94.27 Pass: Major Risk PB V Pad V-202 V-202L2 V5 1179.79 1165.00 113.67 18.75 94.92 Pass: Major Risk PB V Pad V-203 V-203 V18 1318.95 1290.00 67.35 21.33 46.02 Pass: Major Risk PB V Pad V-203 V-203L1 V6 1318.95 1290.00 67.35 21.33 46.02 Pass: Major Risk BP Alaska , Anticollision Report Company: BP Amoco Field: Prudhoe Bay Reference Site: PB V Pad Reference Well: Plan V-05 (SB) Reference Wellpath: Plan V-05 Summary r <--------- - Offset Wellpath ---------> Site Well Wellpath PB V Pad V-203 V-203L2 V4 PB V Pad V-203 V-203L3 V3 PB V Pad V-203 V-203L4 V3 'i PB V Pad V-204 V-204 V2 i PB V Pad V-204 V-204L1 V2 PB V Pad V-204 V-204L1 PB1 V6 PB V Pad V-204 V-204L2 V2 PB V Pad V-204 V-204L2P61 V6 I~ PB V Pad V-204 V-204L3 V4 PB V Pad V-204 V-204PB1 V9 PB V Pad V-204 V-204PB2 V2 PB V Pad V-205 V-205 V14 PB V Pad V-205 V-205L1 V9 PB V Pad V-205 V-205L2 V8 PB V Pad V-210 V-210 V9 PB V Pad V-211 V-211 V5 PB V Pad V-214 V-214 V3 PB V Pad V-214 V-214P61 V2 PB V Pad V-214 V-214P62 V3 i PB V Pad I V-214 V-214PB3 V5 PB V Pad V-214 V-214PB4 V2 PB V Pad V-215 V-215 V7 PB V Pad V-221 V-221 V8 I PB V Pad V-222 V-222 V6 ', PB V Pad V-223 V-223 V8 Date: 4/15!2008 Time: 08:21:48 Pagc: 2 Co-ordinate(NF.) Reference: Well: Plan V-05 (SB), True North Vertical ('fVD) Reference: V-07 Plan SB 82.5 Db: Orade Reference Offset Ctr-Ctr No-Co Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft -- 1318.95 _ 1290.00 67.35 21.33 46.02 Pass: Major Risk 1318.95 1290.00 67.35 21.33 46.02 Pass: Major Risk 1318.95 1290.00 67.35 21.33 46.02 Pass: Major Risk 1408.60 1425.00 56.80 22.17 34.63 Pass: Major Risk 1408.60 1425.00 56.80 22.17 34.63 Pass: Major Risk 1408.60 1425.00 56.80 22.17 34.63 Pass: Major Risk 4265.54 5270.00 1368.62 No Offset Errors 4265.54 5270.00 1368.62 No Offset Errors 1408.60 1425.00 56.80 22.17 34.63 Pass: Major Risk 1408.60 1425.00 56.80 22.17 34.63 Pass: Major Risk 1408.60 1425.00 56.80 22.17 34.63 Pass: Major Risk 485.01 490.00 250.89 8.60 242.28 Pass: Major Risk 485.01 490.00 250.89 8.60 242.28 Pass: Major Risk 485.01 490.00 250.89 8.60 242.28 Pass: Major Risk 211.40 210.00 195.32 3.78 191.54 Pass: Major Risk 231.59 230.00 181.83 4.05 177.79 Pass: Major Risk 270.90 270.00 186.03 5.57 180.45 Pass: Major Risk 885.81 855.00 188.49 19.09 169.39 Pass: Major Risk 263.69 260.00 186.37 5.25 181.13 Pass: Major Risk 263.69 260.00 186.37 5.25 181.13 Pass: Major Risk 263.69 260.00 186.37 5.25 181.13 Pass: Major Risk 385.38 385.00 108.32 8.19 100.13 Pass: Major Risk 280.86 280.00 273.97 5.17 268.80 Pass: Major Risk 281.49 280.00 245.44 5.27 240.17 Pass: Major Risk 482.05 485.00 207.48 10.49 196.99 Pass: Major Risk i FieldPrudhoe Bay SitePB V Pad We11:Plan V-05 (SB) WellpathPlan V-05 From Surface to TD Scan interval 100 f t Scale 1:100 -313 0 V-~/~Q1~Vja1Q~41JBi) 300 V-211 ~~ V 4 ~ 300 i;'b' 3 ,`\ 2 1 3 ~ 3 0 ~~' 4 1 ~ 2 VOV1- 222 2( V( V1-02 2)2 ) ~64 13 -5_ 1 ~§. 1 ~" ag V-H21 (~IVB2$1 ) ~ 3 % ~6 5 1 ,~ 9 1 7 8 9 0 1%~~7 1~ .. 0 ;'6 6 9' 87 1 9 r 5 ~~ ~ 1~ 0 2 0 0 ~ /g7 ..1 6 ~ l+~~ . 4 (V-214 ~1 ) ~ 1 ~~68 24 ? t 8g 56 7g -~ 11JR 7 8 3 0 2 6 1 5 5 ~g 27 8 6 1 q7 g~ g 0 11g ~ 8 1 ~ ;~70 27 9 8 titi ~ ~ ~ - g 10 VR@H03 V ~ (1~fl1~~ 28 1 0 ~3. 2 Tj~b3 01`,~ y-, ~~ ~ 1 0 1 11 2 ~' " 2 1 4 1 0 ' 20"19 ,/ 1 4 ~ " 1 1 1 0 1 1 13 ~ % ~~ 18 17i ~ 11 ~ ,~ 16'215 1 '15 1:.2 V-117 V- 1 6 12 ~~ ~ ~=;~~ ~~= 7 3 g 41 1 ~1 /~~" 1 3 1 g 7 ;1131. 7 6 ; 1 4 \1 3 ~~ V - 2 0 1 ~`2 ~'~4 2 01) 7 1 4 1 9 . 5 (~, ~ - 8 7 7Ni~v-„BjSSxvi~v Q"5'~ ~1~~ ~1 81~ ~ 2 7 /'2 0 1 ~ 0 ~ 6? 6 1 5 r 7 2 1 292 ~~ V -01 0 ~ - 6 5 2 7 g ,, 6 , 8 \1 6 \~ r1 ~- 2 0 2 (V - 7 ~ ~~ 7 ~.3 6 ~9 4 ~ 9 ~ 4 , 1 7 \ 1 9 7 `%'~4 0 1 11 V - 2 1 7 (V - 7 9 1 1 0 g\185 ~t 8 9 1 0_ g 5 1 5 ~ V-101 -101) .6.x' V-108 (V-108) 9 ~~f3 1 12 19 10 16 ,` '~=~~§ ~'~=~ 1 _. 1H 1 100 100 ~~ 9 g r 1 17 20~~ .~T _~: ~~9 1 1 1 8 9 1 1 1 4 ~\ 2 0 ~~ 12 3 19 12 ~t8 V-01 (V-01) 1 1 9\ 2 ,~1 14 2 0 ~ 1 1 10 1 2 g _ ~ 1 2 0 6 /2 1 8 1 g ~ 2 ~ VV 0120 71 V(- 0 21 0 7) V- 1 1 3 ~(2VZ - 1 1 3) p 9 ) 1 2 107 .:1.1 _. _ 200 21 20 20010 0 1 Plan V-226 (S-L) VV- 120195 ((VV- 12019)6 2 ) 22 13 V-112 V-112) 21 V-11 (V-11 )_ Plan ~/-206 (~ K) (PI 11 2 1 50 22 Plan V-225 (S-D) (Plan V-22 _3 1 3 V W2FffiFB~(4[/( 0 -114 (V-114IA~62) Travelling Cyl inder Azimuth (TFO+AZI) [deg] vs Centre t Target: V-OS Poly 1 ~ Site: PB V Pad Well: Plan V-OS (SB) _ l Drilling Target Conf.: 95% Based on: Planned Program i Description: Vertical Depth: 8850.00 ft below Mean Sea Level Map Northing: 5974573.00 ft Local +N/-S: 4682.28 ft Map Easting : 591620.00 ft Local +E/-W: 1234.54 ft Latitude: 70°20'24.841 N Longitude: 149° 15'23.432W Polygon X ft Y ft Map E ft Map N ft I -217.15 73.63 591402.00 5974644.00 2 -194.11 -89.67 591427.00 5974481.00 3 -33.42 -117.62 591588.00 5974455.00 ~~ 4 1910.98 137.99 593529.00 5974734.00 5 1897.64 276.17 593514.00 5974872.00 6 804.59 287.35 592421.00 5974870.00 From: Maunder, Thomas E (DOA) Sent; Tuesday, September 02, 2008 1:40 PM To: 'Staudinger, Garret' Subject: RE: V-05 and W-31A Permit to Drill Garret, You should be receiving W-31A shortly and I am reviewing V-05. Thanks for the information on the changed schedules. Tom Maunder, PE AOGCC From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Tuesday, September 02, 2008 1:37 PM To: Maunder, Thomas E (DOA) Subject: V-05 and W-31A Permit to Drill Tom, The planned spud date for V-05 has moved up from October 10 to September 25, 2008 on 9ES. Also, the planned spud date for W-31A has moved up from October 10 to September 20, 2008 on 7ES. These dates have changed due to scheduling conflicts. Could you please move these PTD up on your queue' due to the earlier than expected start dates? Let me know if you have any questions. Thanks, Garret Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907) 564-4242 Cell: (907) 440-6892 V-OS plan view maps Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, June 30, 2008 3:01 PM To: 'Staudinger, Garret' Subject: RE: V-05 plan view maps Garret, This is well done. Thanks much. Tom Maunder, PE AOGCC Page 1 of 1 From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Monday, June 30, 2008 2:10 PM To: Maunder, Thomas E (DOA) Subject: V-05 plan view maps Tom, Attached are the plan view maps for the Schrader Bluff and Kuparuk zones. Sorry it took so long to get these maps to you, I was out of the office last week. Both maps have the 1/4 mile radius circle drawn on them. Let me know if you need any additional information or have any questions. «V-05Kup_circle.ppt» «V-05_Schrader.ppt» Thanks, Garret Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907) 564-4242 Cell: (907) 440-6892 7/1/2008 V-202 -~ V-204 _ lateral V'~5wp1 ~ ~ lateral ~ -- - ~ ,,~ ,~ , --, 5,974,000 ,_/4 m i e c i rc a ~- _ _- ----- 4 :~a 41? V - `~-~,,,V - 2 i --- \• v-21 t _ ; _ 5,973,000 • V- 4 _, - B Sand -4 s ~ _ V 05 O a v_, Schrader Bluff Penetration -4 4 -~ V~ os ' ~ 02 ~ .._~~.1. j w/'/4 mile radius circle ~-2 2 -~~~y?~ --~-. 5,972,000 ~ • v-z 1 z -43 4 Orion Polygon 2 " t° , ~ 4~~1 `M- a~ Proven area of O sand oil , 4 ~4 ~ ~4 1 \,, _~o ~ ~ ,. 5,971 ,000 aCCUmulatlOn. 3 _, ~ v 107 Y 2 v 201 -?~--------r _ ------ Significant offtake from V-202 ._ 4~~ 4~ _ 3 • --4 ~~ Expected pressure depletion Y ~ -4~ 4 - 5,970,000 In Schrader OSands. -~ Y" " _' • V-~d1-1 1 _ ~ --441 5 V-202 will be shut in from 44 ~ --- 5,969,000 the time that the rig moves __ on to V-05 until we drill out Y-1 _ 2 0 ~ ~ intermediate casing (~ 2 _~4~ ' ,~ -~ 5,968,000 weeks) ._ 4~ _~ - ~. i Iv~o1 ~_~-~15 ~ --_ _ 5,967,000 ~ 588,000 590,000 592,000 594,000 SB_OBa Depth Map V-05 Schrader Depth Structure V-05 Borealis (TKC4) Depth Structure • x r -~._ _ ti `t ii ti , ,` ... t ~r~C~~` • V-05 TSAD Depth Structure D 55505~i `86~JPly! 9~;7~J0G1 ~ '-- ~gH~7r1 r~ ~~ r~ __ `~-' 9 ~` ~~~~ ~ ``-" .L u~ (D m m Ul rD _~ (Jl EJ m cn J v (D -•.7 W m N Q r ~, J Jl'~~KJ~ Jr 9~1 C1~ Cr~©~1~I J~~1 r~'J~ CJJL©~~~ V 1U ,.. b k7 -_..,, ~.. ~ --~- °~ ~t °-_-;; , _ -~. ~. _. -__ r L ` ~ O :~.m'(.~7 .,tip ~/~ r. r'~ ,,` ,~ _ ~ 8737 ~ ~.. ~ ~ ,t . ___ t ___. fl ~ {~r ~? ~`"~' ,.r Mme' "' 3v J ` . - - 1, l _ Jr ~ \I ~~~ u.% y ~~'~ ~" r r•~ . ~~ ~J ~i ~ :~ ~'~ n 1 ti ~, _ r s"~~r f ~~-' l . ~~, , '' ~~ FE~'T `~ ~~~ ~`. ~~ t~ ,f ~ j ~ J .y CD ~. ~ ~ ,~ ti FMfiW(P 4: '~~ ( ~i J f rl ~)f~ ~ ,, ., ,- 4 .~~1 11~~~ -~ f 00~? 8 V-05 wp10 n ifat+ t.+ +,,~,...~ r,r fi r„ ~ ~ ~~ f ~ 4 ~~~~ `° 0 ~ ',_. ~ !' 4, '~ ~ ~ 4 .4 _ , 6' 585000 586000 587000 588000 589000 l r + t rb t ,, ~ ~ ~~ t _c..- s;.v w.~ . 593006 aq~~l~li,~ 595690 ~ n.. ` I !,r _~ '~ ~ m ~ ~ ~ `~ ~ cn OWC - -8889 ~ ~'` ~ yV .,, ~ , ~ \ - ;,, ., ~ A ....~~ `~ ~ 'i ~ ~ I c~~ ; ~ fs .J 1 .ra I'a far 61Ct,*x 1 6 ~, ~~ / 1 j , 5 " .~"^"r" ~ . ~ „~ rj~ C-! yr, 6N '.rrr' ~ ~~ t ~i ,1t l~~-'~ '~ ~ ,,-~. ~.~ ~ ~ ~ ~ Y ^. ~~ ~~, .ti ~ ~tF~ ~~' ~r ~ ~ ~ ~ --C~ ~ ~ tt ~ ~ I~ ~~~~ ~~ -- ~ ~ 883 =' \ ~~ ~: '~ !S'^ U ti~ i, j ~b1 r ~~ ~ r ~ Iti ~'~ ~ C, ,~ er; ~' ; ~ ( ~ ~~ ` , 't~ ''. ~~,~~ a 1 } ti "' j ~ ~ a ~ i.r -~ s f ~ *~ I ~r1a 1 ~i r V,/ 't~g~ '' '~ .1117. 1 Rt1t~~~' ~~ ( ~ ~, ~r"~~ '' '.- ~~~ OWC = -8915 7~?: {7 ~ri~~ i ,~~" ~. ~ a ~ ~~~ c9 J QI c~ 0 Ul 1L N ut ,~ ~, cn CO -.1 (i~ m cn r.~ C~ C9 J O 0 u ~ ~ r ~~ ~ ;x, r ~~ ~~. ~ ~~ ,,,,,, l , 5 ~ ~ `~ ., .,. ..I i ~i ~ i + ~~ 590000 591000 592000 593000 594000 595000 ~ TSAD Depth O1 April 2008 D. Fisher • Page 1 of 2 • Maunder, Thomas E (DOA) From: Staudinger, Garret [Garret.Staudinger@bp.com] Sent: Tuesday, June 17, 2008 8:55 AM To: Maunder, Thomas E (DOA) Subject: RE: V-05 Tom, The "magenta triangles" on the well path are basically the perforating interval for the well. The first triangle is where the wellbore penetrates TSAD and the second triangle is TD (in the Ivishak). Hope this helps. Garret From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, June 17, 2008 6:48 AM To: Staudinger, Garret Subject: RE: V-05 Garret, Looking further at the plot are the "magenta triangles" on the well path the top and base of the Ivishak in V-05? Tom From: Maunder, Thomas E (DOA) Sent: Monday, June 16, 2008 4:40 PM To: 'Staudinger, Garret' Cc: Harry Engel Subject: RE: V-05 Garret, Thank you very much. Given the trajectory of V-05, this view provides important information as to the proximity to other wells. Regards, Tom Maunder, PE AOGCC From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Monday, June 16, 2008 4:36 PM To: Maunder, Thomas E (DOA) Subject: RE: V-OS Tom, V-03 and L-03 are the only two wells within 1/4 mile of the Ivishak Pool. The cementing information I provided is for the production liners for these two wells. There are 8 wells (V-07, V-202, V-222p,,V-1051, V-106, V-201, V-102, V-04) within 1/4 mile of the Schrader Bluff zone and 2 wells (V-07, 1t~'#0bi) within 1/4 mile of the Kuparuk zone. You are correct in that the plan is to pump adequate cement for the intermediate casing string to isolate these pools from V-05. Attached is a plan view map of well proximities for the top of the Ivishak pool. I will get the plan view maps at the Schrader Bluff and Kuparuk zones to you once I put them together. Let me know if you have any questions. Thanks, Garret 7/1/2008 Page 2 of 2 Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907) 564-4242 Cell: (907) 440-6892 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, June 13, 2008 1:46 PM To: Staudinger, Garret. Cc: Tirpack, Robert B; Saltmarsh, Arthur C (DOA) Subject: V-05 Garret, I am beginning to review the application for V-05. Since this is an injector, wells within '/4 mile need to be identified and integrity determined. You have identified V-03 and L-03 as the wells closest in zone. I presume that the cementing information you have provided is for the production liners? Are there any proximate wells in the Kuparuk or Schrader Bluff zones? It appears that the plan is to pump adequate cement to isolate those pools. Also, it would be appreciated if you could provide a plan view map at the various horizon depths to show the well proximities. Thanks in advance. I may have other questions as I continue my review, but I wanted to get this one off to you. Call or message with any questions. Tom Maunder, PE AOGCC 711 /2008 V-OS Permitting i ! Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, April 14, 2008 10:34 AM To: Staudinger, Garret Subject: RE: V-05 Permitting Garret, Permit it as an injector and then complete it as a producer. Afterward a 403 should be filed to convert it to an injector. Tom Maunder, PE AOGCC From: Staudinger, Garret [mailto:Garret.Staudinger@bp.com] Sent: Monday, April 14, 2008 10:29 AM To: Maunder, Thomas E (DOA) Subject: V-05 Permitting Tom, Page 1 of 1 V-05 is an injector that is planned to be drilling in Prudhoe at the end of this year. This injector will be pre- produced if there is enough oil found during drilling. Should this be permitted as an injector or producer? Thanks, Garret Staudinger Operations Drilling Engineer BP Exploration Alaska, Inc. Work: (907) 564-4242 Cell: (907) 440-6892 7/1/2008 EPA Aquifer Exemption - 40 CFR 147.102 (b)(3) 6050000 6000000 5950000 5900000 5850000 400000 500000 600000 700000 sooooo Alaska Department of Natural Resources Land Administration System Page 1 of.~ ~ ~~ :~ ~s~,«ala ', ._i'~; '__an~~ ~ :,~r ~ ,';:1.., f~l rte 1~ecarder's Search Sfate Cabins ~~v>~~ 1~ae5~D111'C~E9 ,y, 1d Alaska DNR Case summary File Type ADL File Number: 28240 ~ Printable Case File_Sr+mmary See Township, Range, Section and Acreage? New search ~ , ~ Yes No _ _ ~~ r_~ ._.~ !_~S ~,~en+~ !Case Abstract i Case Detail ~ Land Abstract ~, Pile: .al)L Z8?40 ~ ~ Search for Status Plat li~d~rtes :~s of OC~.'lli2U0S Customer: 000107377 BP EXPLORATION (ALASKA) INC PO BOX 196612/900 E. BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: ?~4 OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS I%ile Location: DOC DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated: 05/28/1965 Office of~Primar~~ Responsibility: DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: N~ NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridicxn: U 7~nivnship: O1 1N Range: O11 E Section: 01 Section Acres: 640 Search flats Meridian. l I ~ulrnshi~~: OI 1N Range: O1 lE ~ ~S'ectiu~r.~ lC .S'~ ctiru7 . {rre~e: 640 111eyidiurr: LI I'uu~rz~~frii~: OI1N Range: OI IE Section: I I ~ti'e~~~tiurl_~lrrc~e.~ 540 Nferidian: U I mrnship:' O11 N Range; 01 l E Section:: 12 Section Acres.- (,-10 Legal Description 0~-'8-1965 * * *SALE NOTICE LEGALDESCRIPTION* ~` ~` CI4-19 01IN-011E-UM1,2,11,122560.00 0~1-01-197? **UNITIZED,LEASEANI~P~IRTTCIPATINGAREA LEG_9I DF.'SCRIP7ION** LEASE C'Oh.1MITTED IN ENTIRETY TOPRZIDHOE BAY UNIT AND OIL RINI GAS C ~~IP PA PRU~3I~OE BAY UNIT http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 6/11 /2008 Alaska Department of Natural Resources Land Administration System • • ` `TRACT so OIL RIMAND GAS CAP PARTICIPATING AREAS T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA .SECTION 1: ALL, 640.00 ACRES; SECTION 2: ALL, 640.00 ACRES; SECTION 11: ALL, 6=10.00 ACRES; SEC: TION 12: ALL, 640.00 ACRES; CONTAINING APPROXIMATELY 2, ~ 60.00 ACRES, MORE OR LESS. Page 2 ofd 3 I 1-0J-2001 * *FORILIATION OF BOREALIS PARTICIPATING AREA LEGAL DESCRIPTION LEASE INCORPORATED IN PART INTO THE 13PA PRUDHOE BAY UNIT ©RE,9LIS PARTICIPATING AREA TRACT ~ 0 (P_ARTIAL) T.I1N., R.IIE., UMIATMERIDIAN, ALASKA SECTION 1: W2, YG'2E2, 480.00 ACRES; SECTIO!'~' 2:.ALL, 640.00 ACRES; SECTION 11: N2, N2S2, 480.00 ACRES; SECTION ] 2: NW4, W2NE~, 2=10.00 ACRES; THIS TRACT CONTAINS I, 840.00 ACRES, MORE C)R LESS. D2-DI -204 ~ *F'ORAIATION nF ORI4IVPARTICIPATINGAREA L EGAL DESCRIPTION LEASE COMMITTED IN PART TO ORIQN PARTICIPATING AREA PRUDHOE B 4 Y UNIT TRACT 50 ©RI(~N PARTICIPA TING AREA T. 11 N., R. 11 E., ZIMIAT MERIDIAN, ALASKA http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=28240&... 6/11 /2008 Alaska Department of Natural Resources Land Administration System SECTION 1: ALL, 6={0.00 ACRES; SECTION 2: ALL, 60.00 ACRES; SECTION 11: EI/2, EI/2NI~V1/~1, 400.00 ACRES; SECTION 12: ALL, 6I0.00 ACRES; C'ONTAINLVG APPROXIMATELY?,320.00 ACRES, MORE' OR LESS'. Page 3 of,~ 12-01-200-~ * * * *BOREALIS PA EXPANDED, LEASE INCORPORATED IN PART* * *'~ LEGAL DESCRIPTION IS AS FOLLOWS: PRUDHOE BAY UNIT BOREALIS PARTICIPATING AREA TRACT SO (PARTIAL} 'T IIN., R.11E., UMIAT MERIDIAN, ALASKA SECTIION 1: E2E2, 160.00 ACRES; SECTION 11: S2SE4, 80.00 ACRES: SECTION 12: S2, E2NE~1, 100.00 ACRES; THIS TRACT CONTAINS 6-10.00 ACRES, MORE OR LESS. **THE ACREAGE NOW INCORPORATED INTO THE BPA IS DESCRIBED AS FOLLOWS: PRUDHOE BAY UNIT BOREALIS PARTICIPATING AREA TRACT 50 (PARTIAL) T i IN, T.11E., UMIAT MERIDIAN, ALASKA SECTION 1 ALL. 6=10.00 ACRES: SECTION2: ALL, 60.00 ACRES; SECTION I1: N2, SE4, N2SW4, 560 ACRES; SECTION 12: ALL, 640.00 ACRES,• http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=2$240&... 6/11 /2008 TRANSMITTAL LETTER CHECKLIST WELL NAME ~.BG~ SOS PTD# ~O~O gip Development / Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~C'V C~ ~ POOL: ~'C' ~~ G. ~ 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 l ( ast two digits in API number are permit No. ,API No. 50- - 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(f1, alt records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and AP[ 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 contingept 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 throw h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coat bed mejhane is not allowed for (name of well) until after fComnanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comaanv NameZmust contact the Commission to obtain advance approval of such water wel! testing ro am. Rev: 1/11/2008 WELL PERMIT C HECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 Well Name: PRUDHOE BAY UNIT V-05 Program SER Well bore seg PTD#:2080930 Co mpany BP EXPLORATION (ALASKAI INC Initial ClassfType SER I PEND GeoArea 890 _ _ Unit 11650 OnlOff Shore On Annular Disposal Administration 1 Permit_fee attached - fJA- 2 Lease number appropriate- _ _ _ - . - . Yes - - - - - - . - . 3 Unique well-name and number - - . _ _ _ - _ _ - _ Yes - - _ _ - _ _ . _ _ - 4 Well located in a-defined-pool--_.__--______-__.---- Yes- ______PrudhoeBayFieldlPrudhoeBayPgol._-___._-.___---------- --- ---------- 5 Well located proper distance-from drilling unit_boundary- - _ - _ _ - - _ - - _ Yes - - _ _ - _ _ 6 Welllocat_edproperdistancefromotherwells--------- ------ ---------- - Yes- ___-__.__.-_ 7 Sufficient acreageavail_ablein-dnllingunjt------------------------------- YeS- ______2560 acres.---__-__. 8 If deviated,is_wellboreplat-included-._--__- Yes- ---------------------------- 9 Operator only affected party - - - Yes - 10 Operakor has.appropriate-bond in fprce - - - - - - - - - - - - - - - - - Yes _ _ _ _ - _ Blanket Bond # 6194193. _ - _ . - _ _ - - - 11 Permit_can be issued without conservation order- - - - - - - - - - - - - - - - - - - - - - - Yes - _ _ _ _ _ - - - - - . - _ - 12 Permit- can be issued without admini&trativ_e_appr_oya_I - Yes - Appr Date 13 Can permit be approved before 15~aywait_ - - _ _ - - _ _ - _ . - _ - .. _ Yes _ _ - - ACS 9/10/2008 14 Well located within area and_strata authorized by Inlectiori Order # (put_1O# in_comments)-(For Yes - AIO.3.0 ~ 15 All wells_within 1!4_mile area of review identified (For service well only)- Yes - - - - - 2 Ivishak wells, 2 K_upark wells &_3 Schrader wells within- tl4 mile radius of trajectory.- ~ 16 Pre-produced mjector_ duration of pre Production less than 3 months (For service well only) . NA- i 17 fJonconven, gas conforms fo A$31,05,030Q.1.A),Q.2.A-D) - _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ -- 18 Conductor string-provided - Yes - - - d AEQ 1 b 3 102 19 Surface casing protects all known- USDWS _ _ . _ _ - - _ _ _ NA_ . _ _ ) an u ( - _ _ All aquifers exempted, 40 CFR-147. Engineering 20 CMT vo(adequ_ate_to circul_ate_on conducto[& surf-csg - _ _ - _ _ Yes _ - _ 21 CMT vol adequate-to tie-in long string to surf csg- _ _ _ . _ _ _ - _ _ No_ _ - - _ _ - _ 22 CMTwill coyer_allknown-productive horizons_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ _ _ _ _ - _ - - - - - - - - - . - - - - ~ 23 Casing designs adequate f_or C,_T, B &_permafrost _ _ - - _ - _ _ _ . - - - - - - - Yes _ _ - 24 Adequate tankage_or reseruepit - Yes - Rig egmpped with steel pits. No reserve pit planned. All waste to approved disposal wel_I(s), 25 0-403 for abandonment been approved 1 a re-drill has If a NA_ _ ,26 . - . , - Adequate wellbore separation_proposed Yes Proximity analysis perfo[med. Traveling cylinder path calculated, Gyros likely-in surface- hole, 27 If diverter required, does dmeet-regulations- _ . Yes Yes _ _ Maximum expected formation pressure 8.2-EMW at top of Sag MW planned 10.1 in 8.5" hole and 8.6 ppg-in zone 28 Drilling fluid program schematic-& equip list adequate- - Appr Date 29 BOPEs, do the meetregulaiion . _ y Yes _ - - TEM 9/1012008 30 _BOPE-press rating appropriate; test to (put psig in comments)- _ _ _ Yes _ - _ MASP calculated at 2835psi_ 4000-psi BOP testplanned, _ _ - _ _ _ - ~!31 Choke_manifold complies wIAP(RP-53 (M_ay 84)_ _ - _ _ - _ _ _ - Yes _ - _ _ - _ 32 Work will occur without operation shutdown- . _ _ _ - _ _ _ _ - Yes - _ _ 33 of H2$ gas probable - . Is presence Yes _ _ - H2S is reported at Vpad. _ Mud should preclude H2S on rig.- Rig has sensors and.alarms. _ _ - ~~34 - Mechanical.condition of wells within AOR verified (For-service well onlya _ _ Yes _ _ - Well penetrates 3 pool_s.- Cement volume sufficient to pr_oyide isolation.- 2 Ivishakwells have no issues.- .. _ _ . 35 Permit. can be rssued wlohydrogen-sulfide measures No- Max H2S.level 300ppm onwell-V-117-(413/07),. Gealogy 36 Data presented on-potential overpressure zones - - - _ Yes - - - - - - - - - - - - 37 Seismic_analysis ofshallow gas-zones - - _ _ _ _ _ NA_ _ _ - - _ _ D ,38 Seabed condition survey (ifoff-shore) NA 1/2008 ACS 6/1 39 Contact namelpho_ne far weekly-progress reports [exploratory only] - Yes Garret St_audinger - 564-4242. - Geologic Engineering ~//lM1? Public Date Date ~ ~ r r:nmmissioner. Commissio Date: Commissioner:
