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Home My WebLink About205-013MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, June 7, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC V-221 PRUDHOE BAY UN ORIN V-221 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/07/2024 V-221 50-029-23246-00-00 205-013-0 G SPT 4651 2050130 3100 1675 1601 1672 1667 236 234 253 253 REQVAR P Bob Noble 4/14/2024 AOGCC 2 year MIT-IA per AIO AA 26B.006, Max psi 3100 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UN ORIN V-221 Inspection Date: Tubing OA Packer Depth 461 3389 3315 3295IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240415140733 BBL Pumped:4.6 BBL Returned:4 Friday, June 7, 2024 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9 9 9 9 AIO AA 26B.006, James B. Regg Digitally signed by James B. Regg Date: 2024.06.07 14:13:01 -08'00' Nolan Vlahovich Hilcorp Alaska, LLC Geo Tech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 06/13/2023 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20230417 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# MPU B-21 50029215350000 186023 5/8/2023 HALLIBURTON Jewelry Log MPU B-21 50029215350000 186023 5/12/2023 HALLIBURTON Leak Detection Log MPU B-21 50029215350000 186023 5/13/2023 HALLIBURTON Multi Finger Caliper Report MPU I-04A 50029220680100 201092 4/17/2023 HALLIBURTON Cement Bond Log NS-16A 50029230960100 206141 4/3/2023 HALLIBURTON RBT NS-23 50029231460000 203050 4/25/2023 HALLIBURTON RBT PBU 09-24A 50029214280100 223003 4/9/2023 HALLIBURTON RBT-Coilflag PBU C-26A 50029208340100 198145 3/17/2023 HALLIBURTON Production Profile PBU M-201 50029237110000 222030 5/29/2023 HALLIBURTON Inj. Profile PBU S-32A 50029220990100 212082 5/23/2023 HALLIBURTON CAST CBL PBU S-37A 50029222910100 212092 5/19/2023 HALLIBURTON RBT PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile PBU W-04 50029219070000 189008 3/8/2023 HALLIBURTON CAST CBL PBU W-209 50029231700000 203128 5/13/2023 HALLIBURTON Inj. Profile PBU W-219 50029234290000 210105 4/16/2023 HALLIBURTON Inj. Profile PBU Z-223 50029237200000 222080 2/28/2023 HALLIBURTON Inj. Profile SRU 213B-15 50133206540000 215130 4/28/2023 HALLIBURTON Perf Please include current contact information if different from above. T37729 T37729 T37729 T37730 T37731 T37732 T37733 T37734 T37735 T37736 T37737 T37738 T37739 T37740 T37741 T37742T37743 PBU V-221 50029232460000 205013 5/14/2023 HALLIBURTON Inj. Profile Kayla Junke Digitally signed by Kayla Junke Date: 2023.06.13 13:09:15 -08'00' 5HJJ-DPHV%2*& )URP%URRNV3KRHEH/2*& 6HQW0RQGD\0D\30 7R3%:HOOV,QWHJULW\ &F5HJJ-DPHV%2*& 6XEMHFW5(+LOFRUS3%8$SULO0,7)RUPV $WWDFKPHQWV0,73%89$5HYLVHG[OV[0,73%89[OV[0,73%89[OV[ 0,73%8*&([OV[ ŶĚǇ͕ ƚƚĂĐŚĞĚĂƌĞƌĞǀŝƐĞĚƌĞƉŽƌƚƐĂƐĨŽůůŽǁƐ͗ x D/dWhsͲϮϭϯϬϰͲϮϵͲϮϮʹdŚĞƌĞƉŽƌƚĚĂƚĞǁĂƐĐŚĂŶŐĞĚƚŽϬϰͬϮϵͬϮϮďĂƐĞĚŽŶƚŚĞŝŶƐƉĞĐƚŽƌ͛ƐƌĞƉŽƌƚĂŶĚĨŝůĞ ŶĂŵĞ x D/dWhsͲϭϮϯϬϰͲϭϬͲϮϮΘD/dWhsͲϮϮϭϬϰͲϭϬͲϮϮʹdŚĞǁĂŝǀĞĚĂŶĚǁŝƚŶĞƐƐƚĞƐƚƐǁĞƌĞƐĞƉĂƌĂƚĞĚ x D/dWh'ͲϭϬϰͲϭϮͲϮϮʹZĞŵŽǀĞĚEͬĨƌŽŵƚŚĞKĨŝĞůĚƐ;ĂƐƚŚĞƐĞĂƌĞŶƵŵĞƌŝĐŽŶůǇͿĂŶĚŝŶĐůƵĚĞĚŝƚŝŶƚŚĞ ƌĞŵĂƌŬƐ WůĞĂƐĞƵƉĚĂƚĞǇŽƵƌĐŽƉǇŽƌůĞƚŵĞŬŶŽǁŝĨǇŽƵĚŝƐĂŐƌĞĞ͘ dŚĂŶŬǇŽƵ͕ WŚŽĞďĞ WŚŽĞďĞƌŽŽŬƐ ZĞƐĞĂƌĐŚŶĂůǇƐƚ ůĂƐŬĂKŝůĂŶĚ'ĂƐŽŶƐĞƌǀĂƚŝŽŶŽŵŵŝƐƐŝŽŶ WŚŽŶĞ͗ϵϬϳͲϳϵϯͲϭϮϰϮ CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. &ƌŽŵ͗WtĞůůƐ/ŶƚĞŐƌŝƚǇфWtĞůůƐ/ŶƚĞŐƌŝƚǇΛŚŝůĐŽƌƉ͘ĐŽŵх ^ĞŶƚ͗^ƵŶĚĂǇ͕DĂǇϭ͕ϮϬϮϮϮ͗ϬϰWD dŽ͗ƌŽŽŬƐ͕WŚŽĞďĞ>;K'ͿфƉŚŽĞďĞ͘ďƌŽŽŬƐΛĂůĂƐŬĂ͘ŐŽǀх͖ZĞŐŐ͕:ĂŵĞƐ;K'Ϳфũŝŵ͘ƌĞŐŐΛĂůĂƐŬĂ͘ŐŽǀх͖tĂůůĂĐĞ͕ŚƌŝƐ ;K'ͿфĐŚƌŝƐ͘ǁĂůůĂĐĞΛĂůĂƐŬĂ͘ŐŽǀх Đ͗KůŝǀĞƌ^ƚĞƌŶŝĐŬŝфKůŝǀĞƌ͘^ƚĞƌŶŝĐŬŝΛŚŝůĐŽƌƉ͘ĐŽŵх͖WtĞůůƐ/ŶƚĞŐƌŝƚǇфWtĞůůƐ/ŶƚĞŐƌŝƚǇΛŚŝůĐŽƌƉ͘ĐŽŵх ^ƵďũĞĐƚ͗,ŝůĐŽƌƉ;WhͿƉƌŝůϮϬϮϮD/d&ŽƌŵƐ ůů͕ ƚƚĂĐŚĞĚĂƌĞƚŚĞĐŽŵƉůĞƚĞĚK'D/dĨŽƌŵƐĨŽƌƚŚĞƚĞƐƚƐƉĞƌĨŽƌŵĞĚďǇ,ŝůĐŽƌƉŝŶƉƌŝůϮϬϮϮ͘ tĞůů͗ Wd͗ EŽƚĞƐ͗ ϬϰͲϭϬ ϭϳϲϬϰϮϬ ϮͲǇĞĂƌD/dͲ/ƉĞƌ/Kϰ͘ϬϯϲͲĨĂŝůĞĚ͘tĞůůǁĂƐ^/ĂŶĚŝƐĐƵƌƌĞŶƚůǇhŶĚĞƌǀĂůĨŽƌĚŝĂŐŶŽƐƚŝĐƐ͘ &$87,217KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH 3%89 37' D/dWhsͲϭϮϯϬϰͲϭϬͲϮϮΘD/dWhsͲϮϮϭϬϰͲϭϬͲϮϮʹdŚĞǁĂŝǀĞĚĂŶĚǁŝƚŶĞƐƐƚĞƐƚƐǁĞƌĞƐĞƉĂƌĂƚĞĚ ϭϲͲϭϲ ϭϴϬϭϮϳϬ ϰͲǇĞĂƌD/dͲ/ 'Ͳϭ ϭϴϵϬϲϴϬ ϮͲǇĞĂƌD/dͲ/ĨŽƌƐŝŶŐůĞĂŶŶƵůƵƐĐŽŵƉůĞƚŝŽŶ ^ͲϭϭϮ ϮϬϮϭϯϱϬ ϮͲǇĞĂƌD/dͲ/ƉĞƌ/KϮϮ͘ϬϬϭ sͲϭϮϯ ϮϬϵϭϰϭϬ ϰͲǇĞĂƌD/dͲ/ sͲϮϮϭ ϮϬϱϬϭϯϬ D/dͲ/ƚŽŝŶĨŽƌŵĂƉƉůŝĐĂƚŝŽŶ͘tĞůůŝƐĐƵƌƌĞŶƚůǇhŶĚĞƌǀĂůĨŽƌƐůŽǁdǆ/͘ t'/ͲϬϱ ϭϵϬϬϮϱϬ ϰͲǇĞĂƌD/dͲ/ sͲϮϭϯ ϮϮϮϬϬϭϬ D/dͲdΘD/dͲdǆ/ƉĞƌ^ƵŶĚƌǇηϯϮϮͲϭϭϭ WůĞĂƐĞƌĞƉůǇǁŝƚŚƋƵĞƐƚŝŽŶƐŽƌĐŽŶĐĞƌŶƐ͘ ŶĚǇKŐŐ ,ŝůĐŽƌƉůĂƐŬĂ>> &ŝĞůĚtĞůů/ŶƚĞŐƌŝƚǇͬŽŵƉůŝĂŶĐĞ ĂŶĚƌĞǁ͘ŽŐŐΛŚŝůĐŽƌƉ͘ĐŽŵ W͗;ϵϬϳͿϲϱϵͲϱϭϬϮ D͗;ϯϬϳͿϯϵϵͲϯϴϭϲ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ubmit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2050130 Type Inj G Tubing 2720 2725 2725 2724 Type Test P Packer TVD 4651 BBL Pump 2.8 IA 583 3394 3358 3352 Interval O Test psi 1500 BBL Return 2.7 OA 237 247 247 248 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Notes: Hilcorp Alaska LLC Prudhoe Bay / PBU / V Pad Ryan Holt 04/10/22 Notes:MIT-IA under eval for TxIA on MI; pre AA application. Triplex pump broke down and inspector waived witness on this test Notes: Notes: Notes: V-221 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec hanicall Integrityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: Notes: Form 10-426 (Revised 01/2017)2022-0410_MIT_PBU_V-221 9 9 9 9 9 9 +LOFRUS1RUWK6ORSH//& -5HJJ 04/10/22 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: UNDER EVALUATION: WAG Injector V-221 (PTD #2050130) Anomalous IA Pressure Trend Date:Tuesday, April 5, 2022 8:14:27 AM Attachments:image001.png From: PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Sent: Saturday, April 2, 2022 4:21 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>; John Condio - (C) <John.Condio@hilcorp.com>; Stan Golis <sgolis@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: UNDER EVALUATION: WAG Injector V-221 (PTD #2050130) Anomalous IA Pressure Trend Mr. Wallace, WAG Injector V-221 (PTD #2050130) is currently on MI and had an IA bleed on 03/31/22. Follow up monitoring shows an increasing IA pressure trend that does not appear to be attributed to thermal effects from Injection temperature or rate. The well will now be classified as UNDER EVALUATION for diagnostics and monitoring. Plan Forward: 1. DHD: PPPOT-T 2. DHD: Monitor Pressures/Quantify re-pressurization trend if applicable 3. Fullbore: (Pending): MIT-IA 4. Well Integrity: Additional diagnostics as needed. Please respond with any questions. Andy Ogg Hilcorp Alaska LLC Field Well Integrity / Compliance andrew.ogg@hilcorp.com P: (907) 659-5102 M: (307)399-3816 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 hereby notified 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 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 the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considersappropriate. MEMORANDUM State of Alaska - Alaska Oil and Gas Conservation Commission TO: Jim Regg (� DATE: Friday, March 19, 2021 P.J. Supervisor ` 11'Gj �'zxl " SUBJECT: Mechanical Integrity Tests 6 Hilcom North Slope, LLC SPT V-221 FROM: Jeff Jones PRUDHOE BAY UN ORIN V-221 Petroleum Inspector 4YRTST - p/F Src: Inspector Reviewed By: P.1. Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-221 API Well Number 50-029-23246-OMO Inspector Name: Jeff Jones IBsp Num: miUJ210316151538 Permit Number: 205-013-0 Inspection Date: 3/14/2021., Rel Insp Num: Packer Well V-221 - Type Inj I G ' TVD PTD 2050130 - Type Test SPT Test ps BBL Pumped: L 3 - IBBL Returned: Interval 4YRTST - p/F Notes: I well inspected, no exceptions noted. ✓ Depth Pretest Initial 15 Min 30 Min 4AM!n6l 4651 Tubing 1637 —164711 1611 1500 IA 274 2402 2361 - 249 2.2 - OA 157_ _ - 174 - 174 - 174 - P ✓ Friday, March 19, 2021 Page I of I • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,May 04,2017 TO: Jim Regg lq a P.I.Supervisor c/ "� SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. V-221 FROM: Brian Bixby PRUDHOE BAY UN ORIN V-221 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-221 API Well Number 50-029-23246-00-00 Inspector Name: Brian Bixby Permit Number: 205-013-0 Inspection Date: 4/12/2017 Insp Num: mitBDB170412150336 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 'Well V-221 ' Type Inj G'1TVD 4651 - Tubing 1612 1621 1613 1613 PTD 2050130 'Type Test SPT Test psi 1500 IA 11 2398 2352 - 2343 BBL Pumped: 2.6 ' BBL Returned: 2.2 - OA 190 205 205 205 Interval 4YRTST P/F P - Notes: SCANNED AUG 1 5 2017 Thursday,May 04,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,April 30,2013 TO: Jim Regg 1e-1q, ;11 13 P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC V-221 FROM: John Crisp PRUDHOE BAY UN ORIN V-221 Petroleum Inspector Src: Inspector Reviewed By: Supry J. "-- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UN ORIN V-221 API Well Number 50-029-23246-00-00 Inspector Name: John Crisp Permit Number: 205-013-0 Inspection Date: 4/7/2013 Insp Num: mitJCr130408045848 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well T V-221 • 'Type Inj ' W'ITVD 4651 IA T 583 2000 1958 - 1949 • f PTD 2050130 Type Test SPT 1Test psi 1500 • OA 170 180 185 1 190 • Interval aYRTST _�P/F P ' 1Tubin 1400 � j 1400 1400 1400 • Notes: 1.35 bbls pumped for test. , HNE9 FEB 2 5 Z01 SCA Tuesday,April 30,2013 Page 1 of 1 MIuere VII a uas lions t;omm Anchorage, AK 99503 2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job Log Description Date BL Color CD MPI -13 AWJI -00055 3 W3 1 a 'airjral.111 10/18/09 1 1 MPC -07 AXBD -00057 MEM PROD PROFILE F 1 EZIW. i1111 04 -11A AWL8 -00040 ILE 111411110WOLhaan 10/24/09 1 1 V -220 AYS4 -00100 INJECTION PROFILE T i 10/04/09 1 1 L -220 B1JJ -00035 MEM INJ PROFILE REVISED Z. i -a f• 07/30/09 1 1 V -221 AXBD -00037 MEM INJ PROFILE (REVISED) t')T.0 ac--(/ lei G 07/28/09 1 1 L -214A AP30 -00064 INJ PROFILE/RST A A A 10/06/09 1 1 S -22B AYTU -00052 IC1I401e•1■la7.741111[ 0 1 10/27/09 1 1 14 -07 8581 -00016 PROD PROFILE i 1 10/27/09 1 1 07 -05 AYS4 -00105 ��,�j�la�Fi';il7 10/28/09 1 1 R -28 AWL8 -00041 USIT 10/26/09 1 1 2- 08/K -16 AZCM -00046 PRODUCTION PROFILE 0 j J fs9 n 10/30/09 1 1 PSI -05 B14B -00080 TEMP WARMBACK SURVEY 00 /r'39 /Ss90 .i 11/03/09 1 1 C -12B B2WY -00030 MCNL r 09/19/09 1 1 U -05A 09AKA0074 OH MWD /LWD EDIT T a' –0 08/19/09 2 1 01-18A 09AKA0151 OH MWD/LWD EDIT a��I =A 91 I I II II II I I 08/27/09 4 1 H -09 ANHY -00110 RST `r j j f!ialli 09/20/09 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ?UV 6 Ii lea �j f y. 1.+ ILL t r~ ~..J BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 August 14, 2009 k'~`"~~~"~~~~ '.~~ ~°~ .~ ~' ~~~~' ~ bp ~~~~f~~~ OCT 0 6 2~109 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, ~I83f(8 01~ at ~8S ~OnS. ~Q~RNififR~inn Anchor~pe ~.os-- o ~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) Date 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 t7 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!7l2009 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 5002923083ot00 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 5/9f200S 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-201 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 7/11l2009 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 6f30/2009 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 #~ 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 7l11/2009 V-223 2080220 50029233840000 NA 2 NA 20.5 9/7/2008 09/1 1 /09 Schiumherger Alaska Data & Consulting Services 2525 Gembell Street, Suite 400 Mchorage, AK 99503-2838 ATTN: Belh Well .7 o~,eS ~ ~l3 ~.a,~ Job p Log Description Date NO. 5353 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 700 Mchorage, AK 99501 BL Cobr CD x ~ ~ ~ ~ . \i ' , . , .. ,.. (ccil, ~7`i~ i~ V-02 W-26A H-32 B2WY-00018 B1JJ-00033 ANHY-00102 MEM PRODUCTION PROFILE ' MEM PRODUCTION PROFILE ~ PRODUCTION PflOPILE ~ L- 07/27/09 07/2W09 07/25l09 1 1 1 1 1 1 P2-29 AYTU-00052 INJECTION PROFILE ~~-~ OB/0?J09 1 1 L2-11 ANHY-00106 LDL 08102/09 1 1 L2-O6 P2-28 L-213 V-221 L-220 B69K-OOOW AYTU-00051 82WY-00019 AXB0.00037 B7JJ-00035 CROSS FL W CHECK ~ INJECTION PROFILE L-- MEM INJECTION PROFI E' MEM INJECTION PROFILE " MEM INJECTION PROFILE 07/31/09 08/07/09 07/28/09 07/28/09 07l30l09 1 1 1 1 1 1 1 1 7 1 ~ 07-22 AZCM-Op036 PRODUCTION PROFILE ' 08/08/09 1 1 04-02A J-11A L1-O9 AYS4-00091 AWLB-00029 AYS4-00089 USIT ~ USIT PRODU TION PROFILE '_pp 08/11l09 08/05I09 OB/08/09 1 1 1 1 1 1 X•28 L2-06 3-29/J•32 AXBD-00026 83SQ-00020 AP3a-00055 MEM INJECTION PROFILE U' PRODUCTION PROPIIE IBP SET RECORD W/CROS GLOW ; OS/17/09 08/14/09 08/08/09 1 1 1 1 1 1 06-04A 85JN-00009 RST OB/23/09 i~ 1 15-498 82NJ-00013 MCNL 07/15/09 1 1 03-32B 09AKA0030 OH MWD/LWD EDIT 02/28/09 2 1 G-14B AWJI-00043 MCNL 07/2MD9 1 7 L2-13A AWJI-00036 MCNL 06/77/09 ~ 18-028 AWJI-00045 MCNL q- V $~ 08/17/09 1 1 Pt-05 AWLB-00032 RST 08/08/09 1 1 B-16A B2WY-00020 MCNL `~~ ~ ~08/03/09 1 1 J-20B AXBD-00020 MCNL (REVISED) ~- .~ r~ ~(, ' 04/14/09 1 oi cecc nr~runw~ enr_c ocr e~or o.. c~r.~~.~ .. ..~...,~.~.....~~.~.. ....~ ........ _' _" __ BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E~. Benson Blvd. : ~~~.~ a ,~ ~ ~ ~' _ ~;r ~ Alaska Data & Consulling Services 2525 Gambell Sireet, Suile 400 Anchorage, AK 99503-2B3B ~ ~ ~-~ • MEMORANDUM To: Jim Regg ~~~ ~ ~ ~~~ I~ ~i P.I. Supervisor FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, Apri120, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) LNC V-221 PRUDHOE BAY UN ORIN V-221 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv „f~~ ~'-- Connn Well Name• PRUDHOE BAY IJN ORIN V-221 Insp Num: mitJCro90416091701 Rel Insp Num: API Well Number: 50-029-23246-00-00 Permit Number: 205-OI3-0 Inspector Name: John Crisp Inspection Date• 4/15/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well v-221 TYPe ~J• W TVD 4651 jA 880 4000 3940 3940 -' P.T. 2050130 TypeTest SPT Test psi 4000 OA 220 230 230 230 Interval oT1~R p/F P Tubing 1800 1800 laoo 1800 Notes• 2.3 bbl's pumped for test. Pre test for gas injection. Monday, April 20, 2009 Page 1 of 1 os/2s~oa Scbtomberg~r Alaska Data & Consulting Services 2525 Gambeil Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # a. r' ~ .,., nee...~.,f~.... N0.4908 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 17-12 11978484 PRODUCTION PROFILE - 09/19/08 1 1 P2-27 12017505 PRODUCTION PROFILE ~ _ 09/08/08 1 18-05A 11999048 FREE POINT INDICATOR LOG 09/16/08 1 1 E-36 12034922 SCMT - '3 09/13/08 1 1 06-13A 12066547 MEM PROD PROFILE b(p- /(~ 09!05/08 1 1 12-09 12083409 MEM DENSITY LOG ( 09/06/08 1 1 13-14 11978482 PROD PROFILE ~ - ~ 09/13/08 1 1 L-214A 11970843 INJECTION PROFILE C~'}, ~. 09/05/08 1 1 L-210 12031511 INJECTION PROFILE 09/02108 1 1 L-216 11970842 INJECTION PROFILE - ~ _ 09/04/08 1 1 V-221 12034920 INJECTION PROFILE ~ 09/09/08 1 1 L-205L4 40016965 OH MWD/LWD EDIT 06/26/08 (2 PRINTS & 1 CD HAND DELIVERED SEPARATELY) of en~c envw.raun r _-_ __- _ __.-.-_ .. ____._ .._~~... ~ . ..............~.......~. v.... n.aa vn~ vvr ~ twain i v: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ~ ~(_, ! (i Alaska Data & Consulting Services 2525 Gambell Street, Sui 400 Anchorage, AK 9 03-2 8 ATTN: Beth ~ _ ,. Received by: • • ~~~ • • _.._ .,,~~} :.: .- _~,~- MICROFILMED 03!0112008 DO NOT P LAC E ANY NEW MATERIAL .UNDER THIS PAGE F:\I.aserFicheiCvrPgs_InsertslA~ticro5lm Marker.doc Permit to Drill 2050130 MD 9985 v --,--~-----,-~._~ -~--_.- REQUIRED INFORMATION ~-'--"----- - .--- -------- ID ~ DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Well Name/No. PRUDHOE BAY UN ORIN V-221 Operator BP EXPLORATION (ALASKA) INC TVD 5074 yr Completion Date 3/10/2005 v Completion Status WAGIN Current Status WAGIN ......~ ~J= -----_._--~ ~-~-- -~-~------- 5faJ J 3 F~ Ã öö )-- API No. 50-029-23246-00-00 .~ Directio~al surve~ --~--- Mud Log No Samples No DATA INFORMATION Types Electric or Other Logs Run: MWD I GR, MWD I GR I RES I AZI-DEN I NEU I PWD, USIT Well Log Information: Logl Electr Data Digital Dataset Type MedlFrmt Number ~/ D ~_m ,~g ~g Jro C ~s r- c Us ~ ! vt~___. 14305 14551 14551 14551 (data taken from Logs Portion of Master Well Data Maint Name ----~---~~_.--~-- Directional Survey Directional Survey S~ c~.,.)f e:,....u:..... Log Log Scale Media Run Interval No Start Stop ----- o 9985 o 9985 5120 9872 5 Col OHI CH Received 4/1/2005 4/1/2005 Case 3/26/2006 Injection Profile 5 Blu 9010 9880 6/23/2006 ~ (~~.j~tol"- 5012 9872 Open 1 15/2007 107 9987 Open 3/22/2007 25 Blu 109 9985 Open 3/22/2007 25 Blu 109 9985 Open 3/22/2007 ..------- Sample Set Sent Received Number Comments I nd uction/Resistivity I ndu ction/Resistivity I nd uction/Resistivity Well CoreslSamples Information: Name ADDITIONAL INFORM~ON Well Cored? Y ,W) Chips Received? 'v-t1'<r Analysis ¥-ffl"" Received? ---~--,_._--"~-------~-_._-~- Comments: Interval Start Stop Daily History Received? ~N DIN Formation Tops --~~~~"-- --~" e Comments -~-~ I USIT Primary Depth I ControI7-Mar-2005 IP, Temp, Pres, GR, CCL, I Gradio, Spin 3-Jul-2005 USIT, Primary Depth ControI7-Mar-2005 I LIS Veri, FET, ROP, GR, DRHO, NPHI MD Vision Service 3-Mar- 2005 TVD Vision Service 3-Mar- 2005 e , --~_._--- Permit to Drill 2050130 MD 9985 TVD 5074 - -_.,--~-~~ Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/11/2007 Well Name/No. PRUDHOE BAY UN ORIN V-221 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23246-00-00 Completion Date 3/10/2005 UIC Y Completion Status WAGIN Current Status WAGIN .-þ;.. - -- -- -~-~ Date: ~L¿.ilp~~""?- e e 02/27/2007 03/02/7007 Schlumberger NO. 4164 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave. Suite 100 Anchorage, AK 99501 U-rc.. c:b~-Or3 # IL.l s-s-I Field: Aurora Borealis Orion Well Job# Log Description Date BL Color CD V-217 11638607 CH EDIT USIT IPDC) 01115/07 1 V·217 11638607 USIT CEMENT EVALUATION 01/15/07 1 V-217 11638607 USIT CORROSION EVALUATION 01/15/07 1 W-204 11638608 MDT 01/16/07 1 V-221 40011617 OH EDIT MWD/LWD 03/03/05 2 1 - --. . e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E Benson Blvd Anchorage AK 99508-4254 Date Delivered t1NZ ~) 2. f~f. zmn Schlumberger-DCS 2525 Gambell St, Suite 400 ,,,~,,~.,, ~'ro'~. f ATTN: Beth i j Received bY~ ~ Ç) 1:t e l-l 12/27106 SchlumÞerger NO. 4087 Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503·2838 A TTN: Beth Company: Alaska Oíl & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion Prudhoe Bay Well Job# Log Description Date BL Color CD . Z·14B 11414770 SCMT 10/28/06 1 V·211 10919914 CH EDIT USIT PDC-GR) 11/19104 1 1 V·221 10919949 CH EDIT USIT (PDC·GR) (Prints sent 3/16/061 03/07/05 1 L·200 11555032 LDL 12121/06 1 -- f---- -- ,- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH '0: BP Exploration (Alaska) loc PetroteChnica Data Center LR2·1 900 E Benson Blvd. Anchorage AK 99508-4254 . ,!AN 0 ~b Date Delivered Received by u.:cC- 865""-0/3 ;;¡k:. /L/30Ó - SchlumbeJlger ~",\3 /.....v· c;¡ c.5~ 06/21/06 Schlumberger.DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ,,' -\ c...- V,.Y NO. 3862 Company: Ala.ka Oil & Ga. Cons Comm Attn: Christine Mahnken 333 We.t 7th Ave, Suite 100 Anchorage, AK 99501 Field: Orion, Aurora, Borealis, Polaris Well Job # Log De.cription Date BL Color CD 5·111 11216189 MEMORY INJECTION PROFILE 04115/06 1 S-114A 10572082 RST UPFLOW WFL 03101103 1 V·105 10663005 INJECTION PROFILE 03112/04 1 E·103 10560276 TEMPERATURE WARMBACK 06/22/03 1 V·214 11162720 UBI 11/24/05 1 V-213 11076450 INJECTION PROFILE 07/01/05 1 V-216 11076451 INJECTION PROFILE 07/02/05 1 V-221 11058523 INJECTION PROFILE 07/03/05 1 L-103 NiA INJECTION PROFILE 07/18/09 1 W-209 11076461 INJECTION PROFILE 08/20105 1 W-207 10980589 INJECTION PROFILE 07/20/05 1 W-212 N/A INJECTION PROFILE 07/19/05 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: Date Delivered: c.Pk Schlumberger-DCS 2525 Gambell St. Suite 400 Anchorage, AK 99503·2838 A TTN: Beth BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2·1 900 E Benson Blvd. Anchorage AK 99508-4254 Recaived by: . RECEIVED JUN 2 3 Z006 ~ Ci\ &. Gas Cc-ns. Commission Anchcrnge Id- MEMORANDUM State of Alaska TO: . Jim Regg ''J -' I (7(~Ç P.I. Supervisor ~efì 7 () Ataska Oil and Gas Conservation comm.· .- DATE: Thursday, May 12,2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC V-221 PRUDHOE BAY UN ORIN V -221 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P .1. Suprv -.:Jl;1:J-- Comm Well Name: PRUDHOE SAY UN ORIN V-22 I API Well Number: 50-029-23246-00-00 Inspector Name: John Crisp Insp Num: mitJCr050512114126 Permit Number: 205-013-0 Inspection Date: 5/10/2005 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I V-221 IType Inj. I W ! TVD ! 4650 I IA ! 540 1620 I 1580 I 1570 I i I i P.T. I 2050130 TypeTest I SPT i Test psi I 1162.5 i OA I 170 280 I 260 I 250 I , , I Interval INITAL P/F P Tubing I 800 i 800 I 800 I 800 I I Notes: No problems witnessed. NON-CONFIDENTIAL Thursday, May 12, 2005 Page I of I · STATE OF ALASKA . ALASK IL AND GAS CONSERVATION COM SION DECEIVED WELL COMPLETION OR RECOMPLETION REPORT AND LCJG.· .. APR 2 2 2005 No. of Completions 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 181 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD I GR, MWD / GR I RES I AZI-DEN I NEU I PWD, USIT CASING, liNER AND CEMENTING RECORD . SETTING DEÞ1l1 MD SETTING I EPTHTVD HOLE Top BoTTOM lOP ItsOTTOM SIZE Surface 109' Surface 109' 42" 28' 4269' 28' 2692' 12-1/4" 26' 9968' 26' 5064' 8-3/4" o GINJ 0 WINJ 0 WDSPL 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 4856' NSL, 1707' WEL, SEC. 11, T11 N, R11 E, UM Top of Productive Horizon: ,ß 1147' NSL, 1170' EWL, S~~~, T12N, R11E, UM 'ÓJ Total Depth: A310 U-- ~ NSL,~EWL, SEC. 36, T12N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- ~05~~_ y- ~~01 03 Zone- ___ASP4 . TPI: x- 593381 y- 5976989 Zone- ASP4 Total Depth: x- 593585 y- 5977483 Zone- ASP4 ---------- -+ -- -- 18. Directional Survey 181 Yes 0 No 2. CASING Size WT.<PER FT. 215.5# 40# 26# GRADE A-53 L-80 L-80 20" x 34" 9-5/8" 7" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Gun Diameter, 5 spf MD TVD MD TVD 9330' - 9385' 4696' - 4724' 9420' - 9450' 4741' - 4757' 9620' - 9690' 4850' - 4890' 26. Date First Production: April 16, 2005 Date of Test Hours Tested 27. One Other 5. Date Comp., Susp., or Aband. 3/10/2005 6. Date Spudded 2/23/2005 7. Date T.D. Reached 3/3/2005 8. KB Elevation (ft): 81.63' 9. Plug Back Depth (MD+ TVD) 9884 + 5009 10. Total Depth (MD+ TVD) 9985 + 5074 11. Depth where SSSV set (Nipple) 3773' MD 19. Water depth, if offshore NI A MSL ~~.ItWe'll<tÐiS Cons. CommiSSion ~ltTðeveIOI1(R~br.c¡¡:xPloratOry o Stratigr~nre 1rservice 12. Permit to Drill Number 205-013 13. API Number 50- 029-23246-00-00 14. Well Name and Number: PBU V-221 i 15. Field I Pool(s): Prudhoe Bay Field I Orion Schrader Bluff Ft Ft 16. Property Designation: ADL 028238 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 60 sx Arctic Set (Approx.) 22 sx Arcticset Lite, 379 sx Class 'G' 74 sx Class 'G' 24. TOeiNG RECÖRD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 9260' 9233' 3-1/2",9.2#, L-80 9260' - 9531' 9397' & 9488' 25. ACID, FRAcruRE¡CeM!;NT SoUEEZE,ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 101 Bbls of Diesel CHOKE SIZE GAS-OIL RATIO PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Water Injection PRODUCTION FOR OIL-BsL GAs-McF TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. OIL-BsL Press. 24-HoUR RATE WATER-BsL GAs-McF WATER-BsL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~-;-~...~... Nont/ 'Oicli ! ~ l' /);,/ · f 7 ~..s:i ! ' ·l!EIfu:iED ¡ .~ ~ Form 1 0-407 Rëvise"d 12/2003 RBDMS 8Ft MAYO 4 2005 CONTINUED ON REVERSE SIDE 6F 28. GEOLOGIC MARKERS 29. ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Ugnu 4820' 2905' None Ugnu MA 7972' 4140' Ugnu MB1 8073' 4180' Ugnu MB2 8236' 4245' RECEIVED Ugnu MC 8449' 4333' Schrader Bluff NA 8612' 4400' APR 2 2 2005 Schrader Bluff NB 8679' 4427' Schrader Bluff NC 8782' 4467' Alaska Oil & Gas Cons. Commission Schrader Bluff NB 8825' 4484' Schrader Bluff NC 8944' 4531' Anchorage Schrader Bluff OA 9181' 4628' Schrader Bluff OBa 9328' 4695' Schrader Bluff OBb 9416' 4739' Schrader Bluff OBc 9529' 4799' Schrader Bluff OBd 9619' 4849' Schrader Bluff OBe 9723' 4910' Schrader Bluff OBf 9809' 4962' Base Schrader Bluff 9883' 5008' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble PBU V-221 i Well Number Title Technical Assistant Date 0'1(. os 205-013 Permit No. I A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By NameINumber: Drilling Engineer: Terrie Hubble, 564-4628 Shane Gagliardi, 564-5251 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only > m CA ':'f:" ~ ~ 20 :ÞG') g = CI n m g cg!'" n ø .~ ¡¡. jjI> 5' :::I » -0 ::::c ~ ~ N c::> c::> Ul ::u m () m .- < m o Printed: 3/14/2005 1 :44:04 PM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-221 V-221 i DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES 2 . &PHd Date: 4i23/2005 Start: 2/22/~§ka OIl~B~S l,;ons·3t~a~lOn Rig Release: 3/10/2005 Anchorage Rig Number: 2/22/2005 05:00 - 08:00 3.00 MOB P PRE Prepare rig for move, blow-down steam. 08:00 - 09:45 1.75 MOB P PRE Move pits off and move sub off well. 09:45 - 12:00 2.25 MOB P PRE Move rig camp and pits to V-Pad. 12:00 - 16:30 4.50 MOB P PRE Move rig to V-Pad. 16:30 - 18:30 2.00 RIGU P PRE Set rig mats, 3' x 12's & cellar equipment. 18:30 - 21 :30 3.00 RIGU P PRE Moanuver rig over hole, set & level. 21 :30 - 00:00 2.50 RIGU P PRE Move in and set pits, begin NU diverter. Rig accepted at 22:00 hrs. 2/23/2005 00:00 - 05:00 5.00 RIGU P PRE Nipple-up hydrill and surface riser, cut drilling nipple, nipple-up diverter lines. 05:00 - 07:00 2.00 RIGU P PRE Load pipe shed w/drillpipe and strap. 07:00 - 09:00 2.00 RIGU P PRE Pick-up drillpipe. 09:00 - 11 :00 2.00 RIGU N RREP PRE Rig down time (check valve in rig hydraulic system failing - not allowing fluid into cooling loop - repaired same. 11 :00 - 13:45 2.75 RIGU P PRE Continue pick-up drill pipe & HWDP. (NOTE: V-211i pre-spud meeting held at 11 :30 hrs for NAC night tour.) 13:45 - 14:15 0.50 RIGU P PRE Function test diverter system (all equipment performed as required - documentation filed in well file), witness waived by J. Jones (AOGCC), test witnessed by B. Decker (BP - Wellsite Leader) & J. Davidson (NAD - Tool Pusher). 14:15 - 15:30 1.25 RIGU P PRE RU & test Gyro equipment, test mud lines & surface equipment to 3500 psi. 15:30 - 17:00 1.50 RIGU P PRE Pick-up 12.25" BHA & orient same. 17:00 - 18:00 1.00 RIGU P PRE Fill pipe & conductor and check for leaks, test alarm systems (PVT - Gas - H2S). 18:00 - 20:30 2.50 DRILL P SURF Spud V-211 i and drill from 109' to 246' to make room to PU directional BHA, 500 gpm, 40 rpm. 20:30 - 21 :30 1.00 DRILL P SURF POOH to UBHO sub, blow-down top drive, pick-up complete BHA. 21 :30 - 21 :45 0.25 DRILL P SURF RU & run gyro survey at 246'. 21:45 - 00:00 2.25 DRILL P SURF Directionally drilling ahead from 246' to 355', gyro survey on each connection, 500 gpm, 900 psi, 40 rpm, 1 k tq, 50k up, 50k dn, 50k rot, AST = .3 hrs, ART = 2.72 hrs, ADT = 3.02 hrs. (NOTE: V-211 i pre-spud meeting held at 23:30 hrs for NAC day tour.) 2/24/2005 00:00 - 23:30 23.50 DRILL P SURF Drill ahead in 12 1/4" surface hole from 355' TMD to 1948' TMD (1724' TVD), gyro every stand to 905' (RD gyro at 11 :15 - 11 :45 hrs), 80k up, 60k dn, 65k rt, 40 rpm, 500-600 gpm's, 1700-1950 psi, 3.5-5k torq. NOTE: Heavy, large sized gravel from 200' to 800' with some stringers to 925'. Boulder encountered after connection @ 355'. Drilled through in 15 minutes. AST = 7.74 ART = 8.33 ADT = 16.07 23:30 - 00:00 0.50 DRILL P SURF Circulate prior to TOOH f/BHA #2,700 gpm, 2380 psi, 2500 Ibs torq (planned forward to pump 3 BU's to include a 40 bbls "reduced" viscositylnut plug sweep prior to TOOH). Printed: 3/14/2005 1 :44:09 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-221 V-221 i DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/22/2005 Rig Release: 3/10/2005 Rig Number: Anchorage Spud Date: 2/23/2005 End: 3/6/2005 2/25/2005 00:00 - 01 :00 1.00 DRILL P SURF Continue to circulate at 1948' prior to POOH flBHA #2 (total 3XBU), 60 rpm, 700 gpm, 2380 psi, 3-4k tq. 01 :00 - 04:30 3.50 DRILL P SURF Monitor well, POOH wlBHA #1, some tight hole from 1150' back to 950' (kept over-pull wlo pumps <25k I pumped out at 200 gpm wlo problems when needed), went ahead and screwed into next 3 stands and pumped as needed to POOH (200 gpm), pulled last 6 stands wlo pumps. 04:30 - 05:45 1.25 DRILL P SURF Change out bit, change motor bend to 1.5 deg, cleanlclear rig floor. 05:45 - 07:00 1.25 DRILL P SURF Cut and slip drilling line (cut 130'), inspect drawworks. 07:00 - 08:30 1.50 DRILL P SURF Make-up BHA #2. 08:30 - 09:15 0.75 DRILL P SURF Trip in hole wlBHA #2, tight spot @ 1 030', pump and rotate through to 1040'. Continue RIH - No Problems. Precautionary wash last stand to bottom. No Fill 09:15 - 00:00 14.75 DRILL P SURF Drilling ahead from 1948' to 3763', gas hydrates at 2650' and 3130', 95k up, 75k dn, 65k rot, 80 rpm, 6k tq on, 4k tq off, 600 gpm, 2600 psi, ART = 5.02 hrs, AST = 4.29 hrs, ADT = 9.31 hrs. 2/26/2005 00:00 - 04:00 4.00 DRILL P SURF Drilled to the surface hole TD at 4281' (2695' TVD) as per Geologist (no problems), additional gas hydrates @4000', top SV1 shale @4215' (base shale @4340'), 11 Ok up, 68k dn, 75k rot, 6-7k torq, 600 gpm, 2850 psi, 2700 psi off, ADT 2.87 hrs, AST = 1.17 hrs, ART = 1.7 hrs. 04:00 - 05:15 1.25 DRILL P SURF Lay down top single from stand #35 so as to be able to stroke the 66' shale section from TD back up to 4215' top of the shale, circulate 1 bottoms-up (planned for 3 bottoms-up) at 700 gpm, 100 rpm, 4400k tq, 3230 psi, 11 Ok up, 68k dn, 75k rt, lost pump swab (work on rig). 05:15 - 05:45 0.50 DRILL N RREP SURF Rig down (washed out swab on #2 pump). 05:45 - 07:00 1.25 DRILL P SURF Resummed circulating at TD f/2 more bottoms-up, 700 gpm, 100 rpm. 07:00 - 09:00 2.00 DRILL P SURF Wiper trip back to above last bit trip (1850'), tight spots at 2820',2650',2250'. Wiped through - OK. 09:00 - 10:30 1.50 DRILL P SURF Run back to bottom, tight spots at 2680',2970',3560'. 10:30 - 13:30 3.00 DRILL P SURF Circulate & condition prior to TOOH for casing, 650 gpm, 100 rpm, 3000 psi. 13:30 - 18:30 5.00 DRILL P SURF POOH to run casing, work tight hole from 2340' to 2232' (15k overpull), work tight hole from 1450' to 1330' (35k overpull), pump at 200 gpm & wipe clean. 18:30 - 20:00 1.50 DRILL P SURF LD BHA and clear floor. 20:00 - 21 :30 1.50 DRILL P SURF PJSM wlall personnel, rig-up to run casing, make dummy run wlhanger - ok. 21 :30 - 00:00 2.50 DRILL P SURF PJSM wlall personnel, to run 9 5/8" casing, run casing to 800' by 24:00 hrs - no problems. 2/27/2005 00:00 - 04:00 4.00 CASE P SURF RIH wI 101 Jts. 95/8" casing to 4,240'. No problems. 04:00 - 05:00 1.00 CEMT P SURF Circulate landing Jt down as precaution to setting depth of 4,269'- No Fill. Continue to circulate - reciprocating casing 15' & staging pumps up to 6 BPM. 05:00 - 05:45 0.75 CEMT P SURF BIO circulating swadge & MIU Cement head 05:45 - 07:45 2.00 CEMT P SURF Circulate & condition mud for cement job. Vis = 60, YP = 15. 07:45 - 10:30 2.75 CEMT P SURF Switch over to Dowell. Pump 5 Bbls water & test lines to 4000 psi. Mix & pump 64 Bbls of 10.3 ppg, MudPush. Drop bottom plu. Mix & pump 489 bbl (630 sX), ARCTICSET Lite Slurry @ Printed: 3/14/2005 1 :44:09 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-221 V-221 i DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/22/2005 Rig Release: 3/10/2005 Rig Number: spJwßtBfe~2/23/2005 End: 3/6/2005 2/27/2005 07:45 - 10:30 2.75 CEMT P SURF 10.7 ppg wI yield of 4.44 cU.ftIsk @ 6 BPM followed by 77 bbls (374 sx) Class 'G' slurry @ 15.8 ppg w yield of 1.17 cu.lft.lsk @ 6 BPM. Drop top plug and chase with 10 bbls water to clear dowelllines. Switch back to rig and displace with 308 Bbls 9.5 ppg. Mud. began displacement @ 9 BPM, then 6 BPM after 290 Bbls and ending at 3 BPM for final 8 bbls. Bumped plug with 1500 psi. 100 % returns throughout job. Reciprocated until lead cement past shoe. 50 Bbls. - good 10.7 ppg cement to surface. 10:30 -11:15 0.75 CASE P SURF Walk pressure up to 4000 psi. Chart & hold for 30 minute casing test. Bleed off & check floats - OK. 11 :15 - 14:00 2.75 CEMT P SURF N/D Cement Head, Back out Landing jt. & wash out riser. RID 9 5/8" casing equipment. 14:00 - 16:00 2.00 BOPSU P SURF ND diverter system. 16:00 . 22:30 6.50 BOPSU P SURF NU BOPE. (At 20:30 hours, gave 2 hour notice to AOGCC (Chuck Sheve) to witness BOP test. He indicated that he would witness the test and that he would be on location by 22:30 hours for that test.) 22:30 - 00:00 1.50 P SURF PJSM wlall personnel, begin testing BOPE, annular 250 low/3500 hi, other tests 250 low/4000 high. 2/28/2005 00:00 - 05:30 5.50 P SURF Completed BOP test (majority of test witnessed by Chuck Sheve (AOGCC), all tests witnessed by J. Rose - WSL & C. Weaver - Tourpusher), annular tested to 250psi low/3500psi high, all other tests to 250psi low/4000 psi high. 05:30 - 07:00 1.50 P SURF Rig down test joint and testing equipment, install wear bushing, blow down & clean rig floor. 07:00 - 11 :00 4.00 DRILL P PROD1 PU 28 stands of drillpipe and rack back in derrick. 11 :00 - 14:00 3.00 DRILL P PROD1 PU BHA #3 wlSchlumberger, load source, RIH wlDC's & HWDP. 14:00 - 18:00 4.00 DRILL P PROD1 PU 96 joints of drill pipe , RIH. 18:00 - 19:30 1.50 DRILL P PROD1 PJSM, perform stripping drill w/rig team. 19:30 - 20:15 0.75 DRILL P PROD1 Continued in hole to 4185' (tag float collar). 20:15 - 22:00 1.75 DRILL P PROD1 Drill float equipment, cement & 20' new hole to 4301',350 gpm, 1050 psi, 50 rpm, 6·7k torq. 22:00 - 23:00 1.00 DRILL P PROD1 Circulate and displace to the new 8.8 ppg fresh water LSND mud, 590 gpm, 1500 psi, 80 rpm, 3-4k tq. Establish ECD baseline as follows: Actual PWD = 9.68 ppg Modeled ECD = 9. 27ppg ECD Dif. = .48 ppg (NOTE: As we drill ahead, the .48 ppg differential will be added to the path-forward modeled ECD values to represent our clean-hole ECD. Those clean-hole values will then be compared to our actual PWD values as indicators of our hole cleaning efficiency.) 23:00 - 23:30 0.50 DRILL P PROD1 Pulled back into the 9 5/8" casing shoe and rigged-up and performed our LOT to 13.6 ppg EMW (8.8 ppg mud at 2690' TVD with 668 psi on the LOT). 23:30 - 00:00 0.50 DRILL P PROD1 Drilling ahead from 4301' to 4347', 105k up, 65k dn, 75k rt, ART = .29/ADT = .29. Printed: 3/14/2005 1 :44:09 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-221 V-221 i DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/22/2005 Rig Release: 3/10/2005 Rig Number: Anchor.aae 'SpUd u~te: 2/23/2005 End: 3/6/2005 3/1/2005 00:00 - 06:00 6.00 DRILL P PROD1 Drilling ahead in 8 3/4" hole from 4,347' to 5,193', gas hydrates at 4425', 8-10k wob, 565 gpm, 1720 psi on, 1600 psi off, 6k tq on, 5k tq off, 105k up, 65k dn, 78k rt, 120 rpm, 9.8 ppg calc/10.2-10.3 ppg PWD, some "controlled" drilling to maintained ECD limits, full back-ream on each connection. 06:00 - 12:00 6.00 DRILL P PROD1 Drilling ahead in 8-3/4" hole from 5193' to 5782' 113k up, 70k dn, 80k rot., tq. on 5-6k, rpm 120,565 gpm, on psi = 1975, tq. off = 5k, off psi = 1900, 5-1 Ok on bit. ECDs below .60. AST =1.79, ART =4.10. backreaming each connection. Pump sweep 5304'. 12:00 - 00:00 12.00 DRILL P PROD1 Drilling ahead in 8-3/4" hole from 5782' to 7216'. 120k up, 80k dn, 95k rot, tq. on 6-8k, tq. off 5-7k, rpm 120, 570 gpm, on psi = 2500, off psi = 2350. ECD 7216' calc. = 10.04, actual 10.3, ECDs below .60. Backreaming each connection. Pump Hi Vis sweeps at 6069',6642',7216'. ART=4.95, AST=1.45, ADT =6.4. Pretour safety meeting discuss plan forward, stress importance of recognition of SIMOPs on location w/Schlumberger equipment on adjacent wells, Veco trucks, and 7ES supplies and equipment all mobilized in limited area. 3/2/2005 00:00 - 06:00 6.00 DRILL PROD1 Drilling ahead in 8-3/4" hole 7216' to 7867'.566 GPM wI 2750 psi - on, 2,700 psi - off, WOB 5 - 10K, Torque on + 9.5 - 10 K, Torque off 9 - 9.5K, RPM = 120. Calculated ECD = 10.05 ppg. PWD ECD = 10.30 ppg. Up Wt. = 127K, Dn Wt = 85K, Rot Wt = 93K. Weighted Hi Vis sweep at 8267'. ADT= 5.78, ART=4.69, AST=1.09 06:00 - 00:00 18.00 DRILL PROD1 Drilling ahead in 8-314" hole 7867' to 9702'.560 GPM w/3200 psi on, 3000 psi off, WOB 5-10K, Torque on 9-10k, Torque off 8-9, RPM = 120. Calculated ECD = 10.3 PWD ECD = 10.5 ppg. Up wt =145 Dn. Wt. =93k, Rot. Wt =110 Pump Weighted Hi-Vis sweeps @8459, 8937. ADT =6.06, ART =3.88, AST= 2.18. 3/3/2005 00:00 - 03:00 3.00 DRILL P PROD1 Directional drill from 9,702 to 9985, TD as per Geologist. WOB= 5-10, psi on =3450, psi off= 3320, GPM= 564, Tq on= 9.0-9.5, Tq. off =7.5-8.0, Up wt. = 150, Dn wt.= 95, Rot. wt.= 110 rpm = 120, ECD calculated = 10.62 , ECD PWD= 10.3, Pumped weighted hi vis sweeps at 8937', 9607'. ADT = 1.36, AST = .43, ART = .93. 03:00 - 04:00 1.00 DRILL P PROD1 Circulate bottoms Up. 565 GPM @ 3320 psi. 120 RPM. 04:00 - 09:30 5.50 DRILL P PROD1 MADD Pass TD to 8740' bit depth, 40 rpm, 400 gpm, rotating @ 5 ft I Minute. 09:30 - 10:00 0.50 DRILL P PROD1 TIH f/8650' to 9985'. No problems encountered. 10:00 - 11 :30 1.50 DRILL P PROD1 Circulate Hi-Vis, weighted sweep. 565 GPM, 3300 psi, 120 RPM, 11 :30 - 15:00 3.50 DRILL P PROD1 POOH to 4950. No problems - very slick until we pulled tight (35 K) @ 4,950' MD ( Ugnu 4A ). 15:00 - 18:30 3.50 DRILL P PROD1 Kelly up and attempt to circulate, packing off, TIH to 5068, Circulate/backream up to 4730'. 325 gpm, 1000 psi, 80 rpm. Pump out of hole to shoe at 4269'. 18:30 - 19:00 0.50 DRILL P PROD1 Circulate BIU @ Shoe. 590 GPM, 2120 psi, 130 RPM - Huge amount of cuttings over shaker. 19:00 - 20:00 1.00 DRILL P PROD1 RIH to 5,208' ( 2 Stands below problem spot). POH back to shoe. No Drag - No Problems. Printed: 3/14/2005 1 :44:09 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-221 V-221 i DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Alaska Oil & Géß~~ânmlB~005 Start: 2/22/2005 An ti1flH1ä ge 3/6/2005 Rig Release: 3/10/2005 Rig Number: 3/3/2005 20:00 - 21 :30 1.50 DRILL P PROD1 Cut and pull drilling line, service topdrive, inspect derrick. 21 :30 - 00:00 2.50 DRILL P PROD1 Pump dry job, BID topdrive, POOH to BHA, UD ghost reamers, stand back HWDP. 3/4/2005 00:00 - 02:30 2.50 DRILL P PROD1 POOH. Stand back HWDP, UD drill collars, UD BHA. 02:30 - 05:00 2.50 CASE P RUNPRD Pull wear bushing. C/O to 7" rams. Test door seals to 4,000. PU hanger and landing jt. and make dummy run to verify set depths. 05:00 - 07:00 2.00 CASE P RUNPRD R/U Casing equipment. PJSM. 07:00 - 09:00 2.00 CASE P RUNPRD M/U shoe track & check floats. Run 27 Jts. 7' casing 09:00 - 09:30 0.50 CASE P RUNPRD Safety meeting and Derrick inspection 09:30 - 13:30 4.00 CASE P RUNPRD Run 7" casing jts 28-99, circulating for 10 minutes half way to shoe. 13:30 - 14:15 0.75 CASE P RUNPRD At shoe @ 4360'; circulate 165 bbls, 5.5 bpm, 535 psi, up wt. 100K, dn wt. 90K. 14:15 - 23:30 9.25 CASE P RUNPRD Run 7" casing jts 100-232, up wt 215K, dn wt. 90K. 23:30 - 00:00 0.50 CASE P RUNPRD UD Franks tool. M/U 7" casing hanger and landing jt. w/ pump in swadge. Circulate down to Casing TD. 3/5/2005 00:00 - 03:00 3.00 CEMT P RUNPRD Land and circulate well. Stage rates slowly from 3bpm @ 300 psi, 7 bpm @ 780 psi. M/U cement head after one B/U. Circulate an additional 2 bottoms up. Hold PJSM with Dowell & rig Crew. 03:00 - 06:00 3.00 CEMT P RUNPRD Switch to Cementers. Test lines to 4000. Mix and pump 15 bbls CW100, 45 bbls.Mudpush@ 10 ppg, pump 98 bbls. class 'G' Gasblok cement at 15.8 ppg. Wash out to T, switch over to rig pumps & displace wI 350 bbls. seawater at 7bpm. Slow rate for last 29 bbls. to 3 bbls/min. Bump plug. Pressure up to 4000 psi. 100 % returns throughout job. 06:00 . 06:30 0.50 CASE P RUNPRD Hold 4000 psi & chart for for 30 minute casing test. 06:30 - 07:30 1.00 CEMT P RUNPRD RID Cement Head, Landing Jt & Casing equipment. 07:30 - 09:00 1.50 WHSUR P RUNPRD Install 7" Pack-Off in wellhead & test to 5000 psi for 10 minutes -OK. 09:00 - 11 :30 2.50 BOPSU P OTHCMP C/O top rams to 3 1/2" X 6" Variables. Test bonnet seals and rams to 250 low and 4000 High. Test witnessed by Rishi Ramtathal, BP Engineer. 11 :30 - 12:00 0.50 PERFO OTHCMP Perform tourly derrick safety inspection. 12:00 - 13:15 1.25 PERFO OTHCMP C/O bails, clear floor, Move HWDP in derrick. 13:15 - 13:45 0.50 PERFO OTHCMP Service top drive grease crown & inspect derrick 13:45 - 14:15 0.50 PERFO OTHCMP PJSM with SWS DPC personnel, rig crew, MWD tech, Toolpusher & Co Man. 14:15 -16:15 2.00 PERFO OTHCMP M/U Perf guns and blanks as per SWS, DPC Supervisor. 16:15 - 23:00 6.75 PERFO OTHCMP M/U bumper sub, LWD/ GR & remainder of assy. Shallow test LWD - 5 BPM, 230 psi. Cont. RIH. NOTE: Simultaneous Operation - LOT on 7" X 9 518" annulus - 10.5 ppg EMW. Injectivity test up to 3 BPM, 620 psi. Freeze protected annulus with 85 BBls dead crude. 23:00 - 23:30 0.50 PERFO OTHCMP Log first RA marker - GR correlates- pipe less than one foot off. 23:30 - 00:00 0.50 PERFO OTHCMP Continue RIH with Perf Guns. 3/6/2005 00:00 - 02:30 2.50 PERFO OTHCMP RIH wI DPC Perf Guns. Correlate to second RA Marker & Gamma Ray ( < 6 inches from Csg. tally). Put guns on depth. Run back down & tag plugs. 02:30 - 04:30 2.00 PERFO OTHCMP Displace well bore to 9.0 ppg Brine. 250 gpm 600 psi. 04:30 - 05:00 0.50 PERFO OTHCMP Derrick inspection Printed: 3/14/2005 1 :44:09 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-221 V-221 i DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/22/2005 Rig Release: 3/10/2005 Rig Number: Spud Date: 2/23/2005 End: 3/6/2005 TCP PJSM w/Schlumberger and all hands. Pull back up to put guns on depth. Initiate perrforating pressure seguence and fire guns - good surface indication of firing. Perf Intervals: 9330' - 9385', 9420' - 9450', 9620' - 9690' ,4.5" Guns, 5 spf. 4 BBI initial loss. Monitor well -losses @ 5-10 Bbl I Hr. 06:00 - 06:45 0.75 PERFO OTHCMP Pull 5 stands and monitor well. Losing fluid @ 10 Bbl./Hr. 06:45 - 09:30 2.75 PERFO OTHCMP POH to TCP assembly. 09:30 - 10:00 0.50 PERFO OTHCMP PJSM w/Schlumberger on UD of TCP assembly 10:00 - 13:30 3.50 PERFO OTHCMP UD LWD, HWDP, and TCP assembly- all shots fired. . 13:30 - 14:00 0.50 EVAL OTHCMP Derrick inspection 14:00 - 15:45 1.75 EVAL OTHCMP PU Scrapers, HWDP & Jars 15:45 - 20:30 4.75 EVAL OTHCMP RIH wlScraper assembly and tag float collar @ 9882'. 20:30 - 00:00 3.50 EV AL OTHCMP POH w/Scraper assy. fluid lost= 164 bbls at 13.5 bph. 3/7/2005 00:00 - 04:00 4.00 EV AL OTHCMP POH w/scraper assy, UD drillpipe. 04:00 - 04:30 0.50 EV AL OTHCMP Derrick Inspection 04:30 - 05:00 0.50 EV AL OTHCMP PJSM. R/U Schlumberger E-Line for USIT. Monitor well - Static, No losses. 05:00 - 09:00 4.00 P OTHCMP Run US IT log. 09:00 - 10:30 1.50 EVAL N DPRB OTHCMP Telemetry problem wltool. Resolved 10:30 - 14:00 3.50 EVAL P OTHCMP Run US IT log. US IT log was run as V-221i Primary Depth Control Quality Log. RIA Tags in 7" Casing found on depth as reported. Top of cement in 7" casing 5980' 14:00 - 15:00 1.00 EVAL P OTHCMP RID Schlumberger W/L. 15:00 - 15:30 0.50 RUNCO RUNCMP Pull wear ring, make dummy run w/hanger. Well taking 1 bbl.lhr. 15:30 - 16:00 0.50 RUNCO RUNCMP Derrick inspection. Grease crown sheaves. 16:00 - 17:00 1.00 RUNCO RUNCMP PJSM, R/U to run tubing. 17:00 - 00:00 7.00 RUNCO RUNCMP RIH w/4.5" 12.6#, L-80, TC-2 tubing and completion equipment f/jt. #1 to jt. #80. Total fluid loss 12 hrs = 21 bbls. 3/8/2005 00:00 - 00:30 0.50 RUNCO RUNCMP Derrick Inspection 00:30 - 07:30 7.00 RUNCO RUNCMP Trip in hole and land hanger @ 9530.34. Fluid losses = 2 bbls.lhr. 07:30 - 08:30 1.00 RUNCO RUNCMP Rig down casing running equipment and clean rig floor. 08:30 - 09:00 0.50 RUNCO RUNCMP RU Schlumberger WIL to log completion on depth. 09:00 - 11 :00 2.00 RUNCO RUNCMP Log completion on depth w/RA pips in casing and tubing. 11 :00 - 12:30 1.50 RUNCO RUNCMP RD Schlumberger WIL and clear floor. 12:30 - 13:00 0.50 RUNCO RUNCMP Derrick Inspection 13:00 - 15:45 2.75 RUNCO RUNCMP MU headpin and RU to reverse circulate. Pump 162 bbls. brine, 170 bbls. corrosion inhibited brine and 10 bbls clean brine. 3 bpm/200 psi. 15:45 - 16:30 0.75 RUNCO RUNCMP Land Hanger, RILDS, drop ball/rod assy. Pull landing jt. 16:30 - 18:30 2.00 RUNCO RUNCMP Pressure tbg. to 4200 psi to set packers. Hold 30 min for tbg test. Bleed tubing to 1500 psi. Pessure annulus to 4000 psi and hold for 30 minutes. Bleed annulus and tubing to zero, pressure annulus to 2950 psi and shear DCK valve. 18:30 - 19:30 1.00 RUNCO RUNCMP Set TWC and test to 1000 psi. Blow down lines. 19:30 - 23:00 3.50 RUNCO RUNCMP N/D BOP stack, NU tree. 23:00 - 00:00 1.00 RUNCO RUNCMP Secure well. Go to phase 3 standby. 3/9/2005 00:00 - 13:30 13.50 RUNCO WAIT RUNCMP Phase 3 as of 21 :53, 3-08-05. Well secured. Rig secured. WOW. 13:30 - 14:30 1.00 RUNCMP Phase 2 as of 13:30. Test tree, adaptor, and packoff to 5,000 psi. RU to freeze protect and u-tube diesel. Printed: 3/14/2005 1 :44:09 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: V-221 V-221 i DRILL+COMPLETE NABORS ALASKA DRILLING I NABORS 7ES Start: 2/22/2005 Rig Release: 3/10/2005 Rig Number: Spud Date: 2/23/2005 End: 3/6/2005 06:00 - 09:00 3.00 WHSUR P Wait on DSM and hot oil trucks backlogged from Phase 3 weather. RUNCMP RU DSM lubricator and pull 2 way check valve. WAIT RUNCMP Wait on hot oil truck backed up due to weather. RUNCMP RIU hot oil truck to reverse circulate freeze protect. RUNCMP PJSM. Pressure test lines to 3250. Freeze protect well. Reverse circulate 101 bbls. diesel to annulus. 2 bpm. @ 950 psi. Allow diesel to u-tube. RUNCMP Install BPV and test from below to 1000 psi. and hold for 5 min. Secure well. WHDTRE Clean cellar, RID hoses. Install VR plugs in both 7" x 4-1/2" annulus valves. WHDTRE RD. Rig released 09:00. 3/10/2005 18:30 - 19:00 19:00 - 23:30 23:30 - 00:00 00:00 - 00:50 00:50 - 03:30 03:30 - 06:00 2.50 WHSUR P Printed: 3/14/2005 1 :44:09 PM V-221 Survey Report Schlumberger Report Date: 3·Mar-05 Client: BP Exploration Alaska Field: Prudhoe Bay Unit - WOA Structure I Slot: V·Pad I Plan V·2a06i (N·M) Well: V·221 Borehole: V-221 UWIIAPI#: 500292324600 Survey Name I Date: V·221 I March 3, 2005 Torti AHD I DDII ERD ratio: 158.796' /7969.82 fll 6.396/1.571 Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Location Lat/Long: N 70 19 41.006. W 149 15 55.001 Location Grid NIE YIX: N 5970103.450 flUS, E 590593.270 flUS Grid Convergence Angle: +0.69184469' Grid Scale Factor: 0.99990932 Survey I DLS Computation Method: Minimum Curvature I Lubinski Vertical Section Azimuth: 22.810' Vertical Section Origin: N 0.000 fI, E 0.000 fI TVD Reference Datum: Rotary Table TVD Reference Elevation: 81.63 fI relative to MSL Sea Bed I Ground Level Elevation: 53.90 fI relative to MSL Magnetic Declination: 24.580' Total Field Strength: 57606.047 nT Magnetic Dip: 80.802' Declination Date: March 02. 2005 Magnetic Declination Model: BGGM 2004 North Reference: True North Total Corr Mag North -> True North: +24.580' Local Coordinates Referenced To: Well Head . Comments RTE First GYD-CT-DMS 442.43 4.31 10.02 360.60 442.23 8.40 9.00 8.41 7.56 3.70 532.00 5.10 16.65 449.87 531.50 15.64 16.33 15.66 14.69 5.42 621.00 6.87 15.34 538.38 620.01 24.85 25.61 24.92 23.61 7.97 ]:10 710.00 9.94 15.53 626.42 708.05 37.75 38.62 37.91 36.15 11.43 ï» Cit 808.00 13.50 16.60 722.36 803.99 57.52 58.52 57.81 55.27 16.97 7t:' ::u II) Last GYD.a-D~ m 905.00 17.02 18.06 815.92 897.55 82.93 84.05 83.34 79.62 24.60 First MWD~R+ 014.09 21.44 19.25 918.90 1000.53 118.76 119.97 119.25 113.64 36.13 :Þ Cí'J ;::0 ~110.87 25.00 15.27 1007.83 1 089.46 156.70 158.11 157.37 150.08 47.35 g~ ~ 206.75 29.73 15.47 1092.96 1174.59 200.39 202.17 201.41 192.56 59.04 g C") t-:) 302.41 32.60 17.20 1174.81 1256.44 249.57 251.66 250.90 240.05 72.99 .... 0 - 0):;:1 N <J399.54 35.71 16.78 1255.18 1336.81 303.82 306.19 305.43 292.20 88.91 rg ~ c::J C") c::J ~495.12 37.99 18.39 1331.66 1413.29 360.89 363.50 362.74 346.83 106.25 0 U1 589.23 41.27 18.99 1404.13 1485.76 420.76 423.52 422.73 403.68 125.49 ~. 685.62 45.66 19.59 1474.07 1555.70 486.92 489.81 488.99 466.24 147.40 ø 1780.85 50.84 18.47 1537.46 1619.09 557.79 560.83 559.99 533.39 170.53 ø õ· ;::¡ 1876.03 51.08 19.82 1597.41 1679.04 631.56 634.76 633.89 603.22 194.78 1971.88 51.44 21.57 1657.40 1739.03 706.27 709.52 708.57 673.16 221.20 2067.09 52.27 23.32 1716.21 1797.84 781.14 784.39 783.25 742.35 249.79 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Plan V-2a06i (N-M)\V-221\V-221\V-221 Latitude Longitude N 70 1941.006 W 1491555.001 N 70 1941.005 W 1491554.996 N 70 1941.006 W 149 1554.986 N701941.010 W1491554.965 N701941.030 W1491554.929 2.26 5970111.05 590596.88 N 70 1941.080 W 149 1554.893 1.07 5970118.20 590598.52 N701941.150 W1491554.842 1.99 5970127.15 590600.95 N 70 1941.238 W 1491554.768 3.45 5970139.73 590604.26 N701941.361 W1491554.667 3.64 5970158.91 590609.57 N701941.549 W1491554.505 3.65 5970183.35 590616.91 N 70 1941.789 W14915. 4.07 5970217.51 590628.02 N 70 1942.123 W 14915 4.02 5970254.08 590638.80 N 70 1942.482 W 149 15 53.618 4.93 5970296.69 590649.97 N 70 1942.899 W 1491553.277 3.14 5970344.34 590663.35 N 70 1943.366 W 1491552.870 3.21 5970396.67 590678.64 N 70 1943.879 W 1491552.405 2.59 5970451.50 590695.31 N 70 1944.417 W 149 1551.899 3.51 5970508.57 590713.87 N 70 1944.976 W 149 1551.337 4.57 5970571.39 590735.02 N 70 1945.591 W 149 1550.697 5.51 5970638.81 590757.34 N 70 1946.251 W 149 1550.022 1.13 5970708.93 590780.74 N 70 1946.938 W 149 1549.314 1.47 5970779.17 590806.31 N 70 1947.626 W 1491548.542 1.69 5970848.70 590834.06 N 70 1948.307 W 1491547.708 Generated 3/16/200510:04 AM Page 1 of 4 Comments Latitude Longitude N 70 1948.986 W 149 1546.843. N 70 1949.702 W 149 1545.927 2353.36 60.91 22.03 1876.52 1958.15 1017.97 1021.23 1019.53 960.24 342.63 4.26 5971067.66 590924.25 N 70 1950.449 W 149 1544.997 2449.73 65.15 21.13 1920.21 2001.84 1103.82 1107.10 1105.35 1040.09 374.20 4.48 5971147.88 590954.85 N 70 1951.235 W 1491544.075 2545.25 66.38 21.53 1959.42 2041.05 1190.89 1194.20 1192.43 1121.22 405.88 1.34 5971229.39 590985.55 N 70 1952.033 W 1491543.150 2639.96 66.56 21.43 1997.23 2078.86 1277.70 1281.04 1279.23 1202.03 437.68 0.21 5971310.56 591016.36 N 70 19 52.827 W 149 1542.221 2734.95 65.75 21.93 2035.63 2117.26 1364.56 1367.92 1366.08 1282.76 469.77 0.98 5971391.67 591047.48 N 70 1953.621 W 149 1541.284 2831.72 69.21 22.30 2072.69 2154.32 1453.93 1457.29 1455.40 1365.56 503.42 3.59 5971474.86 591080.12 N701954.436 W1491540.302 2925.44 67.99 21.98 2106.89 2188.52 1541.18 1544.55 1542.61 1446.38 536.31 1.34 5971556.07 591112.03 N 70 1955.230 W 149 1539.341 3022.11 67.68 22.49 2143.36 2224.99 1630.71 1634.08 1632.09 1529.25 570.19 0.58 5971639.33 591144.90 N 70 19 56.045 W 1491538.352 3117.56 67.25 23.28 2179.94 2261.57 1718.87 1722.24 1720.18 1610.48 604.47 0.89 5971720.96 591178.19 N 70 1956.844 W 149 153. 3214.01 67.87 22.97 2216.76 2298.39 1808.01 1811.39 1809.24 1692.46 639.48 0.71 5971803.35 591212.21 N 70 1957.650 W 149 153 3309.03 68.20 22.55 2252.30 2333.93 1896.13 1899.51 1897.31 1773.72 673.57 0.54 5971885.01 591245.31 N 70 1958.450 W 149 1535.332 3405.93 68.05 23.53 2288.40 2370.03 1986.05 1989.43 1987.16 1856.47 708.76 0.95 5971968.17 591279.50 N 70 1959.263 W 149 1534.305 3498.66 68.26 23.58 2322.91 2404.54 2072.12 2075.50 2073.15 1935.37 743.16 0.23 5972047.47 591312.94 N 70200.039 W 1491533.300 3594.72 68.26 24.60 2358.49 2440.12 2161.32 2164.73 2162.25 2016.82 779.58 0.99 5972129.35 591348.37 N 70200.840 W 149 1532.236 3691.48 68.14 24.85 2394.42 2476.05 2251.11 2254.57 2251.92 2098.43 817.16 0.27 5972211.40 591384.96 N 70201.643 W 1491531.139 3784.81 68.07 24.57 2429.22 2510.85 2337.66 2341.17 2338.37 2177.10 853.36 0.29 5972290.49 591420.20 N 70202.417 W 149 1530.081 3881.23 68.44 24.52 2464.94 2546.57 2427.18 2430.73 2427.80 2258.56 890.56 0.39 5972372.39 591456.41 N 70203.218 W 149 1528.995 3977.90 67.77 24.56 2500.99 2582.62 2516.84 2520.42 2517.37 2340.16 927.81 0.69 5972454.42 591492.68 N 70 204.020 W 149 1527.907 4074.73 67.87 24.59 2537.55 2619.18 2606.46 2610.09 2606.92 2421.70 965.10 0.11 5972536.40 591528.98 N 70 20 4.822 W 149 1526.817 4171.99 68.79 24.21 2573.46 2655.09 2696.81 2700.47 2697.21 2504.01 1 002.44 1.01 5972619.15 591565.31 N 70 20 5.632 W 1491525.727 4211.53 68.58 24.18 2587.83 2669.46 2733.63 2737.31 2734.02 2537.61 1017.54 0.54 5972652.93 591580.00 N 70 20 5.962 W 149 1525.286 4276.28 66.02 24.30 2612.82 2694.45 2793.34 2797.04 2793.70 2592.07 1042.06 3.96 5972707.68 591603.86 N 70 20 6.498 W 1491524.569 4373.91 67.01 24.55 2651.73 2733.36 2882.85 2886.58 2883.15 2673.60 1079.09 1.04 5972789.64 591639.90 N 70 20 7.299 W 1491523.488 4469.31 67.30 22.66 2688.77 2770.40 2970.75 2974.50 2971.03 2754.16 1114.29 1.85 5972870.61 591674.12 N 70 20 8.092 W 149 1522.459 4565.27 67.95 23.91 2725.30 2806.93 3059.48 3063.23 3059.74 2835.66 1149.37 1.38 5972952.52 591708.21 N 70208.893 W 1491521.435 > 4661.10 67.43 23.44 2761.68 2843.31 3148.13 3151.89 3148.36 2916.86 1184.97 0.71 5973034.13 591742.82 N 70 20 9.692 W 14915. iÞ 4757.09 66.82 23.42 2798.99 2880.62 3236.56 3240.33 3236.78 2998.00 1220.13 0.64 5973115.69 591777.00 N 702010.490 W 149 15 (;0 ~ 4852.77 67.68 23.28 2835.99 2917.62 3324.80 3328.56 3325.00 3079.01 1255.10 0.91 5973197.11 591810.99 N 70 20 11.286 W 149151 Go) ;C 9 4948.49 66.32 23.62 2873.39 2955.02 3412.90 3416.67 3413.09 3159.85 1290.17 1.46 5973278.35 591845.07 N 70 2012.081 W 1491517.321 » m 5043.91 65.19 23.81 2912.57 2994.20 3499.89 3503.67 3500.06 3239.50 1325.16 1.20 5973358.41 591879.09 N 702012.865 W 149 15 16.299 20 \J >C) :::0 C") 5139.92 66.87 24.52 2951.58 3033.21 3587.59 3591.40 3587.74 3319.54 1361.07 1.88 5973438.87 591914.04 N 70 20 13.652 W 1491515.249 :::J c» g.c.» ~ m 5235.61 66.63 25.26 2989.35 3070.98 3675.45 3679.32 3675.57 3399.29 1398.07 0.75 5973519.06 591950.07 N 702014.436 W 1491514.168 (;) C"") ~ 5330.93 67.38 23.82 3026.59 3108.22 3763.15 3767.06 3763.25 3479.11 1434.51 1.60 5973599.30 591985.54 N 702015.221 W 149 15 13.104 ~ (;) Go) - C :::J f'..:J < 5426.38 66.45 24.20 3064.01 3145.64 3850.94 3854.87 3851.02 3559.32 1470.24 1.04 5973679.93 592020.29 N 702016.010 W 149 15 12.060 CD !'" C) 5522.18 67.59 24.46 3101.41 3183.04 3939.11 3943.06 3939.17 3639.68 1506.58 1.22 5973760.72 592055.65 N 702016.800 W 149 15 10.998 C"") C) m (;) U1 ~ 0 5618.00 66.70 24.21 3138.63 3220.26 4027.37 4031.36 4027.42 3720.13 1542.96 0.96 5973841.59 592091.06 N 702017.591 W 149 159.935 ¡;. 5712.94 67.63 23.62 3175.47 3257.10 4114.85 4118.86 4114.89 3800.12 1578.43 1.13 5973922.00 592125.56 N 702018.378 W 149 158.898 '" 5807.81 67.18 23.75 3211.92 3293.55 4202.43 4206.45 4202.46 3880.33 1613.61 0.49 5974002.62 592159.77 N 702019.166 W 149157.870 ëï :::s 5903.75 67.74 23.97 3248.70 3330.33 4291.03 4295.06 4291.05 3961.37 1649.46 0.62 5974084.07 592194.63 N 702019.963 W 149156.823 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31rt-546 ) Plan V-2a06i (N-M)\V-221\V-221\V-221 Generated 3/16/2005 10:04 AM Page 2 of 4 Comments Latitude Longitude N 702020.749 W 149 155.779. 6094.49 67.08 23.76 3324.16 3405.79 4466.16 4470.23 4466.17 4121.34 1720.84 1.24 5974244.88 592264.06 N 70 20 21.537 W 149 154.737 6190.97 67.89 24.07 3361.11 3442.74 4555.26 4559.35 4555.28 4202.81 1756.97 0.89 5974326.78 592299.20 N 70 2022.338 W 149 153.681 6286.15 66.43 24.56 3398.05 3479.68 4642.95 4647.07 4642.95 4282.74 1793.08 1.61 5974407.13 592334.35 N 702023.124 W 149 152.626 6381.71 67.84 23.67 3435.18 3516.81 4730.97 4735.12 4730.98 4363.11 1829.05 1.71 5974487.92 592369.34 N 702023.914 W 149151.574 6476.37 66.62 23.79 3471.82 3553.45 4818.24 4822.40 4818.25 4443.01 1864.18 1.29 5974568.23 592403.49 N 702024.700 W 149150.548 6570.87 66.10 23.49 3509.71 3591.34 4904.80 4908.97 4904.80 4522.31 1898.89 0.62 5974647.94 592437.24 N 70 20 25.480 W 149 14 59.533 6666.67 66.63 23.01 3548.12 3629.75 4992.56 4996.73 4992.57 4602.95 1933.53 0.72 5974728.98 592470.91 N 702026.273 W 149 14 58.521 6762.51 65.42 22.84 3587.06 3668.69 5080.13 5084.30 5080.13 4683.60 1967.64 1.27 5974810.03 592504.04 N 702027.066 W 149 14 57.524 6858.99 65.96 21.76 3626.78 3708.41 5168.05 5172.23 5168.05 4764.95 2001.01 1.16 5974891.77 592536.41 N 702027.866 W 1491456.548 6954.09 67.22 21.06 3664.56 3746.19 5255.30 5259.50 5255.30 4846.20 2032.86 1.49 5974973.39 592567.28 N 702028.665 W 149145. 7049.99 68.48 21.33 3700.72 3782.35 5344.08 5348.32 5344.09 4929.01 2064.97 1.34 5975056.58 592598.39 N 70 20 29.479 W 149 1454. 7147.39 68.02 20.80 3736.81 3818.44 5434.51 5438.78 5434.52 5013.43 2097.49 0.69 5975141.38 592629.88 N 70 20 30.309 W 149 1453.728 7242.70 67.49 20.06 3772.89 3854.52 5522.65 5527.00 5522.66 5096.10 2128.28 0.91 5975224.40 592659.67 N702031.122 W 149 14 52.828 7338.39 67.18 20.61 3809.77 3891.40 5610.86 5615.30 5610.89 5178.89 2158.97 0.62 5975307.55 592689.35 N 702031.936 W 1491451.931 7434.04 66.95 21.78 3847.04 3928.67 5698.91 5703.39 5698.95 5261.02 2190.81 1.15 5975390.05 592720.20 N 702032.744 W 1491451.000 7529.57 66.56 20.86 3884.74 3966.37 5786.66 5791.16 5786.70 5342.79 2222.73 0.97 5975472.19 592751.12 N 70 20 33.548 W 1491450.067 7625.64 65.27 21.83 3923.95 4005.58 5874.33 5878.87 5874.38 5424.48 2254.65 1.63 5975554.25 592782.05 N 70 20 34.351 W 1491449.133 7721.02 67.31 21.97 3962.30 4043.93 5961.65 5966.19 5961.70 5505.50 2287.22 2.14 5975635.65 592813.64 N 70 20 35.148 W 1491448.181 7816.64 68.25 22.03 3998.46 4080.09 6050.16 6054.71 6050.22 5587.57 2320.38 0.98 5975718.11 592845.80 N 702035.955 W 149 1447.212 7912.14 67.31 23.48 4034.58 4116.21 6138.56 6143.11 6138.62 5669.10 2354.57 1.72 5975800.04 592879.00 N 702036.757 W 149 1446.212 8007.46 66.46 22.46 4072.00 4153.63 6226.22 6230.78 6226.28 5749.81 2388.78 1.33 5975881.15 592912.24 N 702037.551 W 1491445.212 8103.25 66.36 22.75 4110.33 4191.96 6314.01 6318.57 6314.07 5830.85 2422.52 0.30 5975962.59 592944.99 N 702038.347 W 1491444.225 8199.14 66.92 24.14 4148.35 4229.98 6402.03 6406.59 6402.08 5911.61 2457.55 1.45 5976043.75 592979.04 N 702039.142 W 1491443.201 8294.85 65.24 23.04 4187.16 4268.79 6489.51 6494.08 6489.56 5991.78 2492.56 2.05 5976124.33 593013.08 N 70 20 39.930 W 1491442.177 8390.69 65.40 23.48 4227.18 4308.81 6576.59 6581.17 6576.64 6071.79 2526.96 0.45 5976204.74 593046.50 N 702040.717 W1491441.172 > ii" 8486.17 65.49 24.67 4266.86 4348.49 6663.41 6668.01 6663.45 6151.08 2562.38 1.14 5976284.45 593080.96 N 702041.496 W 1491440.136 " 8580.92 66.23 25.62 4305.61 4387.24 6749.80 6754.47 6749.83 6229.35 2599.12 1.20 5976363.14 593116.75 N 70 20 42.266 W14914. ~ IÞ ;U 8676.32 66.47 24.58 4343.88 4425.51 6837.12 6841.86 6837.14 6308.48 2636.19 1.03 5976442.71 593152.86 N 70 20 43.044 W 149 14 S! ::Þ 8772.56 67.20 23.05 4381.74 4463.37 6925.58 6930.34 6925.59 6389.42 2671.91 1.65 5976524.08 593187.60 N 70 20 43.840 W 149 14 J20 -0 m 8868.29 66.82 23.37 4419.13 4500.76 7013.70 7018.47 7013.72 6470.42 2706.64 0.50 5976605.48 593221.34 N 70 20 44.637 W 149 14 35.918 J> C") :;0 (') :::J E» n ~ 8963.71 66.41 23.68 4457.00 4538.63 7101.28 7106.05 7101.29 6550.72 2741.60 0.52 5976686.19 593255.33 N 702045.426 W 1491434.895 ::r CIt m C) C'") ~ 9059.01 66.55 23.91 4495.03 4576.66 7188.65 7193.43 7188.66 6630.68 2776.86 0.27 5976766.55 593289.61 N 702046.212 W 149 14 33.864 .... C) - 6710.30 1.99 5976846.59 593324.13 N 702046.995 W 149 14 32.827 E» 9154.73 64.66 24.13 4534.56 4616.19 7275.80 7280.60 7275.81 2812.34 fC :::J < !" I'-) N 702047.764 W 1491431.822 at c:::> 9250.03 62.66 23.30 4576.85 4658.48 7361.19 7366.00 7361.19 6788.48 2846.69 2.24 5976925.18 593357.53 C'") c:::> m 9345.75 60.49 23.27 4622.41 4704.04 7445.36 7450.18 7445.36 6865.80 2879.97 2.27 5977002.89 593389.86 N 70 20 48.524 W 1491430.849 0 U1 ~ 0 9441.41 58.87 23.04 4670.70 4752.33 7527.93 7532.75 7527.94 6941.72 2912.44 1.71 5977079.19 593421.41 N 70 20 49.271 W 149 1429.899 iii" 9537.08 56.62 22.92 4721.75 4803.38 7608.83 7613.65 7608.84 7016.20 2944.02 2.35 5977154.04 593452.09 N 702050.003 W 1491428.976 C/O ër 9633.23 55.15 22.34 4775.68 4857.31 7688.43 7693.25 7688.44 7089.68 2974.65 1.61 5977227.87 593481.83 N 702050.726 W 1491428.080 :::J 9730.12 53.44 23.35 4832.22 4913.85 7767.11 7771.93 7767.11 7162.18 3005.19 1.96 5977300.73 593511.49 N 702051.439 W 1491427.187 9825.77 51.33 23.94 4890.60 4972.23 7842.86 7847.69 7842.86 7231.58 3035.57 2.26 5977370.49 593541.03 N702052.121 W 1491426.298 SurveyEditor Ver 3.1 RT-SP3.03-HF5.00 Bld( do31 rt-546 ) Plan V-2a06i (N-M)\V-221\V-221\V-221 Generated 3/16/2005 10:04 AM Page 3 of 4 Comments Last MWO+IFR+M8 TO ( Projected) 9913.53 9985.00 5028.08 5074.38 7915.38 7969.82 7910.55 7964.99 5977432.85 5977483.16 593567.33 593588.13 7910.55 7964.99 49.62 49.62 23.16 23.16 4946.45 4992.75 7293.63 7343.69 3062.62 3084.04 2.07 0.00 Survey Type: Definitive Survey NOTES: GYD CT DMS - ( Gyrodata - cont. drillpipe m/s -- Gyrodata pump-down multishot surveys with continuous tool (RGS-CT) in drill-pipe.. MWD + IFR + MS - ( In-field referenced MWD with mult-station analysis and correction applied in post-processing.) Leasl Description: Surface: 4855 F8L 1707 FEL 811 T11N R11 E UM BHL: 1638 FSL 3897 FEL 836 T12N R 11 E UM NorthinQ (Y) [ftUSl 5970103.45 5977483.16 Eastina (X) [nUSl 590593.27 593588.13 Latitude Longitude N 702052.731 W 1491425.507 N 702053.224 W 149 1424.881 . :Þ ¡¡; . eo. ::III:'" IÞ ;0 g » .:Þo "" " m ::J C) :::0 () n Q) :::r "" ~ C> C"? m ... ~ ~.~ :? - t;:;', ~~' r-v < f c::J c::J F Ul ,11 ,"" ¿." ;? 8urveyEditor Ver 3.1 RT-8P3.03-HF5.00 Bld( do31 rt-546 ) Plan V-2a06i (N-M)\V-221\V-221\V-221 Generated 3/16/2005 10:04 AM Page 4 of 4 4-1/2",12.6 Ibm, TCII Drift 110: 3.833"/3.958" 3-1/2", 9.3 Ibm, L-80, TCII Drift 110: 2.867"/2.992" Gap for thru- tubing future OBc 'X' .. SCHLUMBERGER Survey report Client.. .................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Orion Well. . . . . . . . . . . . . . . . . . . . .: V-221 API number...............: 50-029-23246-00 Engineer.................: S. Moy RIG NAME:..... ...........: NABORS 7ES STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS.... .......: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: Driller's Pipe Tally GL above permanent.......: 53.90 ft KB above permanent.......: N/A Top Drive ft DF above permanent.......: 81.63 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 22.81 degrees 3-Mar-2005 14:18:43 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 5 23-Feb-05 03-Mar-05 107 0.00 ft 9985.00 ft . ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date............: 23-Feb-2005 Magnetic field strength..: 1152.13 HCNT Magnetic dec (+E/W-).....: 24.59 degrees Magnetic dip.............: 80.80 degrees ----- MWD survey Reference Reference G..............: Reference H..............: Reference Dip. ...........: Tolerance of G...........: Tolerance of H...........: Tolerance of Dip.........: Criteria --------- 1002.68 mGal 1152.13 HCNT 80.80 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees . ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 24.59 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.59 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 ;t(Jl·~ 0{3 .. SCHLUMBERGER Survey Report 3-Mar-2005 14:18:43 Page 2 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------- Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 78.53 0.23 94.73 78.53 78.53 0.05 -0.01 0.16 0.16 94.73 0.29 BP GYD CT DMS - 3 170.13 0.24 52.30 91. 60 170.13 0.27 0.09 0.49 0.50 79.73 0.19 BP GYD CT DMS - 4 259.58 0.81 67.17 89.45 259.57 0.89 0.45 1. 22 1. 30 69.84 0.65 BP GYD CT DMS - 5 351. 43 2.33 20.16 91.85 351.39 3.22 2.45 2.47 3.48 45.13 2.04 BP GYD CT DMS 6 442.43 4.31 10.02 91.00 442.23 8.40 7.56 3.70 8.41 26.07 2.26 BP GYD CT DMS . - 7 532.00 5.10 16.65 89.57 531.50 15.64 14.69 5.42 15.66 20.27 1. 07 BP GYD CT DMS - 8 621.00 6.87 15.34 89.00 620.01 24.85 23.61 7.97 24.92 18.64 1. 99 BP GYD CT DMS - 9 710.00 9.94 15.53 89.00 708.05 37.75 36.15 11. 43 37.91 17.55 3.45 BP GYD CT DMS - 10 808.00 13.50 16.60 98.00 803.99 57.52 55.27 16.97 57.81 17.07 3.64 BP GYD CT DMS 11 905.00 17.02 18.06 97.00 897.55 82.93 79.62 24.60 83.34 17.17 3.65 BP GYD CT DMS - 12 1014.09 21.44 19.25 109.09 1000.53 118.76 113.64 36.13 119.25 17.64 4.07 MWD IFR MS - 13 1110.87 25.00 15.27 96.78 1089.46 156.70 150.08 47.35 157.37 17.51 4.02 MWD IFR MS - 14 1206.75 29.73 15.47 95.88 1174.59 200.39 192.56 59.04 201.41 17.05 4.93 MWD IFR MS - 15 1302.41 32.60 17.20 95.66 1256.44 249.57 240.05 72.99 250.90 16.91 3.14 MWD IFR MS 16 1399.54 35.71 16.78 97.13 1336.81 303.82 292.20 88.91 305.43 16.92 3.21 MWD IFR MS - 17 1495.12 37.99 18.39 95.58 1413.29 360.89 346.83 106.25 362.74 17.03 2.59 MWD IFR MS - - 18 1589.23 41.27 18.99 94.11 1485.76 420.76 403.68 125.49 422.73 17.27 3.51 MWD IFR MS - 19 1685.62 45.66 19.59 96 .39 1555.70 486.92 466.24 147.40 488.99 17.54 4.57 MWD IFR MS - 20 1780.85 50.84 18.47 95.23 1619.09 557.79 533.39 170.53 559.99 17.73 5.51 MWD IFR MS 21 1876.03 51.08 19.82 95.18 1679.04 631.56 603.22 194.78 633.89 17.90 1.13 MWD IFR MS . - - 22 1971.88 51.44 21.57 95.85 1739.03 706.27 673.16 221.20 708.57 18.19 1. 47 MWD IFR MS - 23 2067.09 52.27 23.32 95.21 1797.84 781.14 742.35 249.79 783.25 18.60 1. 69 MWD IFR MS - 24 2161.01 54.06 23.09 93.92 1854.14 856.30 811.44 279.41 858.20 19.00 1.92 MWD IFR MS - - 25 2257.18 57.01 23.50 96 .17 1908.56 935.58 884.26 310.77 937.28 19.36 3.09 MWD IFR MS 26 2353.36 60.91 22.03 96.18 1958.15 1017.97 960.24 342.63 1019.53 19.64 4.26 MWD IFR MS - - 27 2449.73 65.15 21.13 96.37 2001.84 1103.82 1040.09 374.20 1105.35 19.79 4.48 MWD IFR MS - 28 2545.25 66.38 21.53 95.52 2041.05 1190.89 1121.22 405.88 1192.43 19.90 1. 34 MWD IFR MS - 29 2639.96 66.56 21. 43 94.71 2078.86 1277.70 1202.03 437.68 1279.23 20.01 0.21 MWD IFR MS - 30 2734.95 65.75 21.93 94.99 2117.26 1364.56 1282.76 469.77 1366.08 20.11 0.98 MWD IFR MS .. SCHLUMBERGER Survey Report 3-Mar-2005 14:18:43 Page 3 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2831. 72 69.21 22.30 96.77 2154.32 1453.93 1365.56 503.42 1455.40 20.24 3.59 MWD IFR MS - 32 2925.44 67.99 21.98 93.72 2188.52 1541.18 1446.38 536.31 1542.61 20.34 1. 34 MWD IFR MS 33 3022.11 67.68 22.49 96.67 2224.99 1630.71 1529.25 570.19 1632.09 20.45 0.58 MWD IFR MS - 34 3117.56 67.25 23.28 95.45 2261.57 1718.87 1610.47 604.47 1720.18 20.57 0.89 MWD IFR MS - 35 3214.01 67.87 22.97 96 .45 2298.38 1808.01 1692.46 639.48 1809.24 20.70 0.71 MWD IFR MS 36 3309.03 68.20 22.55 95.02 2333.93 1896.13 1773.72 673.57 1897.31 20.79 0.54 MWD IFR MS . - 37 3405.93 68.05 23.53 96.90 2370.03 1986.05 1856.47 708.76 1987.16 20.90 0.95 MWD IFR MS - 38 3498.66 68.26 23.58 92.73 2404.53 2072.12 1935.37 743.16 2073.15 21.01 0.23 MWD IFR MS - 39 3594.72 68.26 24.60 96.06 2440.12 2161.32 2016.82 779.58 2162.25 21.13 0.99 MWD IFR MS - 40 3691.48 68.14 24.85 96.76 2476.05 2251.11 2098.43 817.16 2251.92 21.28 0.27 MWD IFR MS 41 3784.81 68.07 24.57 93.33 2510.85 2337.66 2177.10 853.36 2338.37 21.40 0.29 MWD IFR MS - 42 3881.23 68.44 24.52 96.42 2546.57 2427.18 2258.56 890.56 2427.80 21.52 0.39 MWD IFR MS - 43 3977.90 67.77 24.56 96.67 2582.62 2516.84 2340.16 927.81 2517.37 21.63 0.69 MWD IFR MS - 44 4074.73 67.87 24.59 96.83 2619.18 2606.46 2421.70 965.10 2606.92 21.73 0.11 MWD IFR MS - 45 4171.99 68.79 24.21 97.26 2655.09 2696.81 2504.01 1002.44 2697.21 21.82 1. 01 MWD IFR MS 46 4211.53 68.58 24.18 39.54 2669.46 2733.63 2537.61 1017.54 2734.02 21.85 0.54 MWD IFR MS - - 47 4276.28 66.02 24.30 64.75 2694.45 2793.34 2592.07 1042.06 2793.70 21.90 3.96 MWD_Inc_Only 48 4373.91 67.01 24.55 97.63 2733.36 2882.85 2673.60 1079.09 2883.15 21. 98 1. 04 MWD IFR MS - 49 4469.31 67.30 22.66 95.40 2770.40 2970.75 2754.16 1114.29 2971.03 22.03 1. 85 MWD IFR MS - 50 4565.27 67.95 23.91 95.96 2806.93 3059.48 2835.66 1149.37 3059.74 22.06 1. 38 MWD IFR MS 51 4661.10 67.43 23.44 95.83 2843.30 3148.13 2916.86 1184.97 3148.36 22.11 0.71 MWD IFR MS . - 52 4757.09 66.82 23.42 95.99 2880.62 3236.56 2998.00 1220.13 3236.78 22.15 0.64 MWD IFR MS - 53 4852.77 67.68 23.28 95.68 2917.62 3324.80 3079.01 1255.10 3325.00 22.18 0.91 MWD IFR MS - 54 4948.49 66.32 23.62 95.72 2955.02 3412.90 3159.85 1290.17 3413.09 22.21 1. 46 MWD IFR MS - - 55 5043.91 65.19 23.81 95.42 2994.20 3499.89 3239.50 1325.16 3500.06 22.25 1. 20 MWD IFR MS 56 5139.92 66.87 24.52 96.01 3033.20 3587.59 3319.54 1361.07 3587.74 22.29 1. 88 MWD IFR MS - - 57 5235.61 66.63 25.26 95.69 3070.98 3675.45 3399.29 1398.07 3675.57 22.36 0.75 MWD IFR MS - 58 5330.93 67.38 23.82 95.32 3108.22 3763.15 3479.11 1434.51 3763.25 22.41 1. 60 MWD IFR MS - - 59 5426.38 66.45 24.20 95.45 3145.64 3850.94 3559.32 1470.24 3851. 02 22.44 1. 04 MWD IFR MS - 60 5522.18 67.59 24.46 95.80 3183.04 3939.10 3639.68 1506.58 3939.17 22.49 1. 22 MWD IFR MS .. SCHLUMBERGER Survey Report 3-Mar-2005 14:18:43 Page 4 of 5 -------- ------ ------- ------ -------- --------- ----------------- --------------- ------- -------- ------ ------- ------ -------- -------- ---------------- ------------------- ------ Seg Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ --------- ------ ------- ------ --------- ---------- ----------------- --------------- ------ 61 5618.00 66.70 24.21 95.82 3220.26 4027.37 3720.13 1542.96 4027.42 22.53 0.96 MWD IFR MS - 62 5712.94 67.63 23.62 94.94 3257.10 4114.85 3800.12 1578.43 4114.89 22.56 1.13 MWD IFR MS - 63 5807.81 67.18 23.75 94.87 3293.55 4202.43 3880.33 1613.61 4202.46 22.58 0.49 MWD IFR MS - 64 5903.75 67.74 23.97 95.94 3330.33 4291.02 3961.37 1649.46 4291.05 22.61 0.62 MWD IFR MS - 65 5998.89 65.98 24.23 95.14 3367.72 4378.49 4041.22 1685.18 4378.51 22.64 1. 87 MWD IFR MS - 66 6094.49 67.08 23.76 95.60 3405.79 4466.16 4121.33 1720.84 4466.17 22.66 1. 24 MWD IFR MS . - 67 6190.97 67.89 24.07 96 .48 3442.73 4555.26 4202.81 1756.97 4555.27 22.69 0.89 MWD IFR MS - 68 6286.15 66.43 24.56 95.18 3479.68 4642.95 4282.74 1793.08 4642.95 22.72 1. 61 MWD IFR MS - 69 6381. 71 67.84 23.67 95.56 3516.81 4730.97 4363.11 1829.05 4730.98 22.74 1. 71 MWD IFR MS - 70 6476.37 66.62 23.79 94.66 3553.45 4818.24 4443.01 1864.18 4818.25 22.76 1.29 MWD IFR MS - 71 6570.87 66.10 23.49 94.50 3591.34 4904.80 4522.31 1898.89 4904.81 22.78 0.62 MWD IFR MS - 72 6666.67 66.63 23.01 95.80 3629.75 4992.56 4602.95 1933.53 4992.57 22.79 0.72 MWD IFR MS 73 6762.51 65.42 22.84 95.84 3668.69 5080.13 4683.60 1967.64 5080.13 22.79 1. 27 MWD IFR MS - 74 6858.99 65.96 21.76 96 .48 3708.41 5168.05 4764.95 2001.01 5168.06 22.78 1.16 MWD IFR MS - 75 6954.09 67.22 21.06 95.10 3746.19 5255.30 4846.20 2032.86 5255.30 22.76 1.49 MWD IFR MS 76 7049.99 68.48 21.33 95.90 3782.35 5344.08 4929.01 2064.97 5344.09 22.73 1. 34 MWD IFR MS - 77 7147.39 68.02 20.80 97.40 3818.44 5434.51 5013.43 2097.49 5434.52 22.70 0.69 MWD IFR MS - 78 7242.70 67.49 20.06 95.31 3854.52 5522.65 5096.10 2128.28 5522.66 22.67 0.91 MWD IFR MS - 79 7338.39 67.18 20.61 95.69 3891.40 5610.86 5178.89 2158.97 5610.89 22.63 0.62 MWD IFR MS - 80 7434.04 66.95 21. 78 95.65 3928.67 5698.91 5261.02 2190.81 5698.95 22.61 1.15 MWD IFR MS 81 7529.57 66.56 20.86 95.53 3966.37 5786.66 5342.79 2222.73 5786.70 22.59 0.97 MWD IFR MS . - 82 7625.64 65.27 21.83 96.07 4005.58 5874.33 5424.48 2254.65 5874.38 22.57 1. 63 MWD IFR MS - 83 7721.02 67.31 21.97 95.38 4043.93 5961.65 5505.50 2287.22 5961.70 22.56 2.14 MWD IFR MS - 84 7816.64 68.25 22.03 95.62 4080.09 6050.16 5587.57 2320.38 6050.22 22.55 0.98 MWD IFR MS - 85 7912.14 67.31 23.48 95.50 4116.20 6138.56 5669.10 2354.57 6138.62 22.55 1. 72 MWD IFR MS 86 8007.46 66.46 22.46 95.32 4153.63 6226.22 5749.81 2388.78 6226.28 22.56 1. 33 MWD IFR MS - 87 8103.25 66.36 22.75 95.79 4191.96 6314.01 5830.85 2422.52 6314.07 22.56 0.30 MWD IFR MS - 88 8199.14 66.92 24.14 95.89 4229.98 6402.03 5911.61 2457.55 6402.08 22.57 1.45 MWD IFR MS - 89 8294.85 65.24 23.04 95.71 4268.79 6489.51 5991.78 2492.56 6489.56 22.59 2.05 MWD IFR MS - 90 8390.69 65.40 23.48 95.84 4308.81 6576.59 6071.79 2526.96 6576.64 22.60 0.45 MWD IFR MS . .. SCHLUMBERGER Survey Report 3-Mar-2005 14:18:43 Page 5 of 5 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seg Measured Incl Azimuth Course TVD vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 91 8486.17 65.49 24.67 95.48 4348.49 6663.41 6151.08 2562.38 6663.45 22.62 1.14 MWD IFR MS - 92 8580.92 66.23 25.62 94.75 4387.24 6749.80 6229.35 2599.12 6749.83 22.65 1.20 MWD_Inc_Only 93 8676.32 66.47 24.58 95.40 4425.51 6837.12 6308.48 2636.19 6837.14 22.68 1. 03 MWD_Inc_Only 94 8772.56 67.20 23.05 96 .24 4463.37 6925.58 6389.42 2671.91 6925.59 22.69 1. 65 MWD_Inc_Only 95 8868.29 66.82 23.37 95.73 4500.76 7013.70 6470.42 2706.64 7013 .72 22.70 0.50 MWD_Inc_Only 96 8963.71 66.41 23.68 95.42 4538.63 7101.28 6550.72 2741.60 7101.29 22.71 0.52 MWD_Inc_Only . 97 9059.01 66.55 23.91 95.30 4576.66 7188.65 6630.68 2776.86 7188.66 22.72 0.27 MWD_Inc_Only 98 9154.73 64.66 24.13 95.72 4616.19 7275.80 6710.30 2812.34 7275.81 22.74 1. 99 MWD IFR MS - 99 9250.03 62.66 23.30 95.30 4658.48 7361.19 6788.48 2846.69 7361.19 22.75 2.24 MWD IFR MS - 100 9345.75 60.49 23.27 95.72 4704.04 7445.36 6865.80 2879.97 7445.36 22.76 2.27 MWD IFR MS 101 9441.41 58.87 23.04 95.66 4752.33 7527.93 6941.72 2912.44 7527.94 22.76 1. 71 MWD IFR MS 102 9537.08 56.62 22.92 95.67 4803.38 7608.83 7016.20 2944.02 7608.84 22.76 2.35 MWD IFR MS - 103 9633.23 55.15 22.34 96.15 4857.31 7688.43 7089.68 2974.65 7688.44 22.76 1. 61 MWD IFR MS - 104 9730.12 53.44 23.35 96.89 4913.85 7767.11 7162.18 3005.19 7767.11 22.76 1. 96 MWD IFR MS - 105 9825.77 51.33 23.94 95.65 4972.23 7842.86 7231.58 3035.57 7842.86 22.77 2.26 MWD IFR MS 106 9913.53 49.62 23.16 87.76 5028.08 7910.55 7293.63 3062.62 7910.55 22.78 2.07 MWD IFR MS - 107 9985.00 49.62 23.16 71. 47 5074.38 7964.99 7343.69 3084.04 7964.99 22.78 0.00 Projected to TD [(c)2005 IDEAL ID9_1C_01J . . . Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No V-221 Date Dispatched: 11-Mar-05 Installation/Rig Nabors 9ES Dispatched By: 0 Data No Of Prints No of Floppies Surveys 2 Received By: Please sign and return to: Drilling & Measurements LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosel@slb.com Fax: 907-561-8417 LWD Log Delivery V 1.1 , 10-02-03 Schlumberger Private ;l~ ~: -0/) ~'[~'U'E WJ' m[L/Æ~)¡~(!r~\ . / J FRANK H. MURKOWSKI, GOVERNOR ALASKA OIL AND GAS f CONSERVATION COMMISSION / , 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Re: Prudhoe Bay Unit V -221 i BP Exploration (Alaska), Inc. Permit No: 205-013 Surface Location: 4856' NSL, 1701' WEL, Sec. 11, T11N, RIlE, UM Bottomhole Location: 1700' NSL, 1414' EWL, Sec. 36, T12N, RIlE, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ITom other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. " Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. ase provide at least twenty- four- (24}... hours notice for a representative of the Commisso n to itness any required test. Contactt.the~.. Commission's petroleum field inspector at 59-3 (pager). DATED thì~ day of February, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. W6A- 2-/z.-1 z.oos- . STATE OF ALASKA I ALASKr"OIL AND GAS CONSERVATION C ¡.1MISSION PERMIT TO DRILL 20 AAC 25.005 D ., '.·j!1ns· U LUU 1a. Type of work II Drill o Redrill rb. Current Well Class o EXPlorat~ o De~~e~rO;Pl. Gm Mt1t1Øle~iTI¡SE! . ORe-Entry o Stratigraphic Test II Service o Deve opment Gasr .g.,~i!lgL~~ Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name ândNùmtfer: BP Exploration (Alaska) Inc. Bond No. 2S1OO302630-277 PBU V·221 i ./ 3. Address: 6. Proposed Depth: 12. Field I Pool(s): P.O. Box 196612. Anchorage. Alaska 99519-6612 MD 10065 TVD 5085 Prudhoe Bay Field I Orion 4a. Location of Well (Governmental Section): 7. Property Designation: Schrader Bluff Surface: ADL 028238 4856' NSL. 1707' WEL. SEC. 11. T11N. R11E. UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: February 16, 2005 /" 1034' NSL, 1127' EWL, SEC. 36, T12N, R11E, UM Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1700' NSL, 1414' EWL. SEC. 36, T12N, R11E, UM 2560 10,170' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool Surface: x-590593 Y-5970103 Zone- ASP4 (Height above GL): 82.4 feet V-120 is 1390' away 16. Deviated Wells: Kickoff Depth: 300 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 67 decrees Downhole: 2191 Surface: 1701./ 18. casing program: Specifications Setting, Depth .(}u~mtity PfÇert1~!1t Size Top " ,Bottom ·«c.t.·or<S8ckS) Hole Casinc Weicht Grade Couolina Lenath MD TVD MD TVD (jncludina staae data) 42" 20" x 34" 215.5# A-53 Weld 80' 29' 29' 109' 109' 60 sx Arctic Set (Approx.) 12-1/4" 9-518" 40# L-80 BTC 4291' 29' 29' 4320' 2727' '40 sx Arcticset Lite, 378 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 10036' 29' 29' 10065' 5085' 44 sx Class 'G' ,; 19. PRESENT WELL CONDITION SUMMARY (To be completedforRedriIIANC>Re·e,.,trýO~rations) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): Junk (measured): Casing Length Size Cement Volume MD TVD Conductor Production Liner Perforation Depth MD (ft): IPerfOration Depth TVD (ft): , 20. Attachments 181 Filing Fee, $100 o BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis 181 Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 18120 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Rob Tirpack, 564-4166 Printed Name 13i11lsaacson. Title Senior Drillìng Engineer Siçnature L \ At, ~ ~. Date z/ '/Os Prepared By Name/Number: Phone 564-5521 Terrie Hubble, 564-4628 Commission Use Only PermitTo Drill API Number: .9. 3 .:z. ¥ I ~ermit APproval:z..I~IOÞJ I See cover. letter for Number: .2.0 S - 0 ¡.J 50-02. -.2 ~ Date: other reqUirements Conditions of Approval: Samples Required D Yes ..~No Mud Log Required t DYes ~No . ~ Sumd. Measu..s n Yes ';8 No Directional Survey Required ;¡:gYes D No Other: Te ç f ß 0 p 4c:? 0 CJ p ç j,' wvA I ~~¿¡L¡ 1°1 'reébuA':ve d . Date ",ø/O$ Anorove" = I -1 /q~. APPROVED BY .'. , " THE COMMISSION Form 10-401 ReViséd 06/ ~ i.e'., j i ill~\ L ~ubmit In Duplicate .~ fí ,/ . . I Well Name: I V-221 ¡I Well Plan Summary I Type of Well (producer or injector): I USH Injector Surface Location: 4,856' FSL, 1,707' FEL, Sec. 11, T11 N, R11 E (Slot NM As Built) X = 590,593 Y = 5,970,103 /" V-221 i Polygon 2A Target 1 1,034' FSL, 4,152' FEL, Sec. 36, T12N, R 11 E Top OA: X = 593,340 Y = 5,976,875 Z = 4,555' TVDss V-221 i Polygon 2A Target 2 1,431' FSL, 3,982' FEL, Sec. 36, T12N, R11 E Top OBd: X = 593,505 Y = 5,977,274 Z = 4,785' TVDss V-221 i Polygon 2A BHL: 1,700' FSL, 3,866' FEL, Sec. 36, T12N, R11E / X = 593,618 Y = 5,977,545 Z = 5,003' TVDss I AFE Number: ITBD I I Rig: I Nabors 7es I I GL: I 53.9' I I KB: I 28.5' I Estimated Start Date: I February 16m, 2005 I I Operating days to complete: 15.0 TD: 10,065,' MD I I TVD: I 5,085' I I Max Inc: I 66.9° I I KBE: I 82.4' Well Design: USH Grassroots Schrader Injector 4-112" X 3-112" TCII Completion. The 0 sands will have a 4-112" X 3-112" TCII Completion in the Schrader Bluff. Current Well Information General Distance to Nearest Property: Distance to Nearest Well in Pool: API Number: Well Type: Current Status: Conductor: BHP: BHT: -10,170' at top Na sand to the nearest PBU property line 1390' from V-221 i to V-120 at the Na top 50-029-XXXXX i Development - Orion Schrader Injector / New well, 20" X 34" insulated conductor 20" X 34", 215.5Ib/ft, A53 ERW set at 109' RKB 2,073 psi @ 4,635' TVDss (8.6 ppg EMW). Normal pressure gradient. 90°F @ 4,635' TVDss estimated % Mile Well bore Near Well bore Mechanical Integrity Summary: No wells with-in a % mile radius / No near wellbore integrity issues. c rr b' P asmgJ u mg rogram Hole Csgl WtlFt Grade Conn Burst Collapse Length Top Bottom Size Tbg O.D. / ~ (psi) (psi) MD 1 TVDrkb MD 1 TVDrkb 42" 20" 215.5# A-53 Weld 80' 29' / 29' 109' 1109' I 12- W' 9-%" 40# L-80 BTC 5,750 3,090 4,291' 29' / 29' 4,320' / 2,717' 8-%" 7" 26# L-80 BTC-M 7,240 5,410 10,036' 29' / 29' 10,065' /5,085' TubinQ 4112" 12.60# L-80 TCII 8,430 7,500 9,371' 29' / 29' 9,400' / 4,717' TubinQ 3112" 9.30# L-80 TCII 10,160 10,530 205' 9,400' / 4,717' 9,605' /4,817' V-221 i Permit to Drill Page 1 . . Formation Markers V-221 i (Based on Schlumberger wp02) Formation Tops MD TVD TVDss Pore psi EMW ppg Hydrocarbons G1 322' 322' 240' 108 8.7 No SV6 983' 972' 890' 401 8.7 No SV5 1,800' 1,647' 1,565' 704 8.7 No SV4 2,008' 1 ,777' 1,695' 763 8.7 Poss. Gas Hydrates Base Permafrost 2,017' 1,782' 1,700' 765 8.7 No Fault 1 2,347' 1,942' 1,860' SV3 2,704' 2,082' 2,000' 900 8.7 Poss. Gas Hydrates SV2 3,175' 2,267' 2,185' 983 8.7 Poss. Gas Hydrates SV1 4,066' 2,617' 2,535' 1,141 8.7 Gas Hydrates- Poss. Free Gas below 2,700' TVDss UG4 4,855' 2,927' 2,845' 1,280 8.7 Thin coal UG4A 4,970' 2,972' 2,890' 1,301 8.7 Heavy Oil-2890' to 2960' TVDss UG3 5,848' 3,317' 3,235' 1 ,456 8.7 Thin coals UG1 7,249' 3,867' 3,785' 1,703 8.7 Heavy Oil-3900' to 4000' TVDss Too Schrader/Ma Sand 7,949' 4,142' 4,060' 1,827 8.7 No - water Mb1 8,063' 4,187' 4,105' 1,847 8.7 No - water Mb2 8,554' 4,262' 4,180' 1,881 8.7 No - water Mc 8,458' 4,342' 4,260' 1,917 8.7 No - water Na 8,636' 4,412' 4,330' 1,927 8.6 No Nb 8,713' 4,442' 4,360' 1,940 8.6 Yes Fault 2 8,738' 4,452' 4,370' Nb - 2nu Too (reoeat) 8,878' 4,507' 4,425' Nc 8,980' 4,547' 4,465' 1,987 8.6 Yes OA 9,209' 4,637' 4,555' 2,027 8.6 Residual oil and water OBa 9,398' 4,717' 4,635' 1,813-2,063 7.5-8.6 Yes OBb 9,495' 4,762' 4,680' 1,833-2,083 7.5-8.6 Yes OBc 9,605' 4,817' 4,735' 2,107 8.6 Yes OBd 9,699' 4,867' 4,785' 1,882-2,132 7.5-8.6 Yes OBe 9,815' 4,932' 4,850' 2,158 8.6 Yes OBf 9,900' 4,982' 4,900' 2,181 8.6 Yes OBf Base 9,917' 4,992' 4,940' T.D.* 10,065' 5,085' 5,003' 7·1;, J 9·~ J *TD is based on 250' MD below the Top OBe marker* M dP u rOQram: / 12 %" Surface Hole Mud Properties: I Spud - Freshwater Mud I Interval Density Funnel Vis PV YP FL Chlorides PH Initial 8.5 -9.2 250-300 20-45 50-70 NC-8.0 <500 8.5-9.0 Base Perm 9.0 - 9<5ì 225-250 20-40 30-45 8.0 <500 8.5-9.0 Interval TD 9.5 - ~.61 225-250 15-20 30-40 5.0-7.0 <500 8.5-9.0 ,,'-0, ,_7 Chlorides <600 Pro ram: Surface Gyro will be needed (run to 1200' or as conditions dictate) MWD I GR None 8-%" Hole Section: MWD I GR I Res I Azi-Den I Neu I PWD (All realtime with recorded porosity) Cased Hole: USIT Bond Log V-221 i Permit to Drill Page 2 . . V-1 05i will require surface shut-in and wellhouse removal in order to move over well V-221 i. Close Approach Shut-in Wells: There are NO close approach wells requiring subsurface isolation for this profile. Close Approach Well List: Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautionary Comment V -105 16.09-ft 400-ft 9.58-ft Use Traveling Cylinder Gyro V-106 33.88-ft 1,211-ft 9.31-ft Use Traveling Cylinder Gyro V-102 54.06-ft 450-ft 45.57-ft Use Traveling Cylinder Gyro V-201 71.86-ft 448-ft 64.74-ft Use Traveling Cylinder Gyro V-103 79.75-ft 1,313-ft 51.21-ft Use Traveling Cylinder Gyro V-107 85.10-ft 498-ft 77.52-ft Use Traveling Cylinder Gyro V-216 85.93-ft 2,606-ft 24.01-ft Use Traveling Cylinder Gyro Cement Calculations: Casin Size: 9-%-in 40-lb/ft L-80 BTC - Single Stage Basis: Lead: 250% excess over gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 1,000' of open hole with 30% excess, plus 80' shoe track Tail TOC: 3,320' MD Total Cement Volume: Spacer Lead Tail Tem In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Casin Basis: Centralizer Recommendations: 9-%" Casing Centralizer Placement a) Run (25) 9-%" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 3,324' MD (1,000' MD above the shoe). b) Run 2 Bow-spring centralizers on either side of the TAM Port Collar (if run). c) This centralizer program is subject to change due to actual hole conditions. 7" String Centralizer Placement a) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. b) With the exception stated above, run one centralizer per joint, floating across the entire joint up to 7,449' MD (500' MD above Ma sand). Zonal isolation with cement is required across the Ma sands. The centralizer program is subject to change pending modeling and hole conditions. V-221 i Permit to Drill Page 3 . . Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 4,000 psi. Due to test pressures not exceeding 5,OOOpsi it will not be necessary to have two sets of pipe rams installed at all times. ,./ BOP regular test frequency for V-221 i will be 14 da.ys. / Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Section · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · 7" Casing Test: · Integrity Test - 8-3/4" hole: · Kick Tolerance: · Planned completion fluid: 2,191 psi - Base of Schrader (8.6 ppg @ 4,900' TVOss) /' 1,701 psi - Based on a full column of gas @ 0.10 psi/ft 4,000 psi/250 psi Rams 2,500 psi/250 psi Annular 4,000 psi 11.0 ppg minimum EMW LOT 20' from 9-5/8" shoe 60 bbls with an 11.0 ppg EMW LOT Estimated 9.0 ppg Brine / 6.8 ppg Oiesel Disposal · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS- 04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to 08-04 for injection. Haul all Class I wa.ste to Pad 3 for disposal. V-221 i Permit to Orill Page 4 . . DrillinQ Hazards and ContinQencies POST THIS NOTICE IN THE DOGHOUSE I. Well Control A. The Schrader in the Polygon 2A fault block is expected to be normal pressured at 8.5-8.6 ppg EMW. This pressure could be as low as 7.5 ppg EMW depending on offset producer influence. II. Hydrates and Shallow gas A. Gas Hydrates are present at V-pad and have been encountered in wells as close as V-100 and V-111 and throughout the SV4, SV3, SV2, and SV1. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Both offset wells to V-100 and V-111 had to have the mud treated and were able to drill to section TD. In V-1 00 the hydrates came from the SV1. Occasionally hydrates are encountered below the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected at the V Pad. The the V-Pad fault has been intersected by several other wells on V-pad at this depth with out problem. . Note: Massive losses were encountered on L pad at L-118 due to high penetration rates (1100-1300 fph) and inadequate hole cleaning strategy. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 9-%" casing will be cemented to surface. B. The 7" casing will be cemented with 15.8 Ib/gal tail cement to 500' MD above the Ma sand -7,449' MD. C. The Kick Tolerance for the surface casing is 60 bbls with 9.0 ppg mud, 11.0 ppg LOT, and an 8.6 ppg pore pressure. D. Integrity Testing -11.0 ppg EMW V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide V Pad isJ}Qtdesignated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: V-102 10 ppm / V-101 10 ppm Adjacent producers at TD: V-201 5 ppm VII. Faults A. Two faults are expected to be crossed at V-221 i. No losses are expected to be associated with either fault. Details are listed below for reference: Fault 1 (SV4): Fault 2 (SB N Interval): 2,347' MD 8738' MD 1,942' TVD 4,452' TVD 1,860' TVDss 4,370' TVDss Throw: 100' W Throw: 60' N CONSULT THE V PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION V-221 i Permit to Drill Page 5 · . V-221 i Drill and Complete Procedure Summary Pre-Rig Work: 1. The V-221 i conductor has been set (Slot V-NM). See As-Built. 2. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. 4. Prepare neighboring wells for the rig move and simops production. Shut in V-101 and V-108 and remove well houses as necessary. Rig Operations: 1. MIRU Nabors 7ES. / 2. Nipple up diverter spool and function test diverter. PU 4" DP as required and stand back in derrick. 3. MU 12-%" drilling assembly with Dir/GR and directionally drill surface hole to approximately 4,320' MD. The /' actual surface hole TD will be +/-100' TVD below the top of the SV1 sands. 4. Run and cement the 9-%", 40.0-lb/ft. surface casing back to surface. A TAM Port Collar should be on location. Cement was not circulated to surface on V-103 and V-106 1st stage surface cement job. Therefore a port collar will be run in the casing string if hole conditions dictate. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4,000 psi. / 6. MU 8-3,4" drilling assembly with Dir/GR/Res/Azi-Den/Neu(recorded)/PWD and RIH to float collar. Test the 9- %" casing to 4,000 psi for 30 minutes. 7. Circulate and condition cement contaminated mud. Displace over to new 9.0 ppg mud ./ 8. Drill new formation to 20' below 9-%" shoe and perform LOT (If a 11.0 ppg EMW is not obtained contact ODE). 9. Drill ahead to Polygon 2A Target TD at 10,065' MD, (250' MD below Top OBe marker). / 10. Circulate and condition hole, POOH to run casing. Perform wiper trip only if hole conditions dictate. 11. Run and cement the 7" production casing as required to cover all significant hydrocarbon intervals. Displace / the casing with seawater during cementing operations. Pressure test casing to 4,000 psi for 30 minutes at plug bump. Freeze protect the 7" x 9-%" annulus. 12. PU DPC guns and RIH w/ -200' of 4.5" Power Jet 5 spf, 60° phasing, perf guns (total assembly length to be -400') with Schlumberger LWD GR. Tag PBTD. 13. Circ hole over to 9.0 brine. 14. Space out utilizing GR and RA tags in 7" casing. Once spa~out correctly, confirm cement compressive strength is at least 2,000 psi. Perforate OBa, OBb, and OBd. 15. RU Schlumberger E-line. RIH with gage ring and junk basket to recover any perf debris. Repeat until clean. 16. Run USIT/GR log. USIT will be primary depth control for future well work. ../ 17. Run the 4-W' X 3-Y2", L-80 TCII completion with a 7" x 3-%" straddle packer assembly and injection mandrels. / , 18. Run in the lockdown screws and set the packers. Test the production casing/tubing annulus and tubing to / 4,000 psi each. Shear the DCK shear valve. 19. Install FMC TWC. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 20. Freeze protect the well to -2,500' TVD. Install BPV in tubing hanger. Install a VR plug in the 7"x 4-%" annulus valve and secure the well. Assure that IAlOA are both protected with two barriers. 21. Rig down and move off. Post-Rig Work: 1. R/U Slickline and pull ball and rod / RHC from the tailpipe. 2. Replace the DCK shear valve with a dummy GLV. 3. Pull dummy valves in injection mandrels and replace with injection valves. 4. Pull VR plug. V-221 i Permit to Drill Page 6 · . V-221 i Detailed Drilling Procedure Job 1: MIRU Critical Issues: ~ Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-212i). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. ~ Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. ~ V-105i will have to be shut in and require well house removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. / ~ V Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at both L and V pads as a result of the use of Ivishak gas lift gas. All V and L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: V-102 V-101 10 ppm 10 ppm Adjacent producers at TD: V-201 5 ppm Reference SOP: .:. "Drillingl Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 121A" Surface Hole Criticsllssues: ~ At V-Pad, no significant surface hole drilling problems are present. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In several wells reaming and tight hole have been present with a few examples of lost circulation while cementing. ~ Close Approach: The V-105 will be required to be shut in and have the wellhouse removed due to surface location proximity to the V-221 i. In addition there are several close tolerance wells in the surface interval. Follow the traveling cylinder I no-go plot per established procedures. A gyro should be run to at least 900'-1200'. ~ Faults: One fault is expected to be crossed at V-221 i in the surface hole. The V-Pad fault has been crossed many times by offset wells at similar depths with out problems. Losses are not expected to be associated with this fault. Details are listed below for reference: Fault 1 (SV4): 2,347' MD 1,942' TVD 1 ,860' TVDss Throw: 100' W ~ Directional: Every effort should be made to ensure a 'smooth' well profile that will benefit torque I drag in the later hole sections and allow for easier 9 5/8" casing running. A graduated build profile is planned. It is preferred that DLS are not pushed ahead of plan on the surface hole, so as to minimize the chance for hole irregularity or obstructions that could cause problems while running casing. V-221 i Permit to Drill Page 7 . . ~ Hole Cleaning: Good hole cleaning practices will be critical to the success of the well. Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.83° motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TO to raise the rotary speed to +1 OO-rpm prior to POOH to run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. Before pulling out of the hole for the final time, make sure that the hole is clean, full returns are observed, and that the pipe pulls without significant overpull. Lost circulation is possible while cementing if these conditions are not satisfied. ~ Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider back-reaming across initial tight spots only if washing does not alleviate the problem. If tight spot is thought to be cuttings, run back in the hole at least the length of the BHA and circulate and condition the hole for a minimum of 30 minutes at max RPM's and GPM's. ~ Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the base of the SV1 sand. If this tool fails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates all of the SV1 sands. Reference RPs: .:. "Prudhoe Bay ~irectional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations Job 3: Run 9-%" Surface CasinQ Criticsllssues: ~ Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. Hydrates are prevalent on V-pad all the way into the SV1. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TO at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. ~ Casing drift: 9-%", 40# special drift casing is being used (8.835" 10, 8.75" drift). Ensure that casing equipment is properly drifted to ensure adequate 10 for the 8-%" bit (float equipment, casing hanger, etc). ~ Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar should be placed at 1,000-ft MO as a contingency, if hole conditions warrant. ~ Losses during cement job: Lost circulation has been experienced on offset pads while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is at least 12.7-lb/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECO's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs: .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" V-221 i Permit to Drill Page 8 . Job 4: Drill 8-%" Production Hole Critical Issues: ~ Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period of time across the permeable Schrader Sands. ~ LOT: Perform a LOT (minimum 11.0 ppg EMW to satisfy kick tolerance). KICK TOLERANCE: Based / upon the max expected Schrader reservoir pressure of 8.6 ppg and 9.0 ppg mud, a 11.0 ppg leak-off will provide 60 bbls of kick tolerance. Contact Anchorage personnel if LOT is less than 11.0 ppg. Based upon off-set drilling data, a minimum leak-off of 13 ppg is expected at the 9-%" shoe. ~ Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for EGOs not to exceed 0.6ppg above calculated. If EGOs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. EGO should not exceed 11.0 ppg once the M sand has been penetrated. ~ Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. ~ Faults: One fault is expected to be crossed at V-221 i in the 8-3/4" hole. Losses are not expected to be associated with this fault. Details are listed below for reference: . Fault 2 (SB N Interval): 8738' MD 4,452' TVD 4,370' TVDss Throw: 60' N ~ Screen Blinding: Add BDF-263 as per MI mud program while drilling the Ugnu/heavy oil sands ~ Critical LWD Tools: It is critical to have the GR tool in order to pick the landing points for the production hole section. As mentioned above in the landing point discussion, the landing of this well depends on picking the base of the OBf and OBd sands using the Gamma Ray. Therefore if the GR tool is lost, a trip will have to be made to change it out. ~ Directional Constraints: It is important to keep the wellbore smooth and the tangent angle close to plan to facilitate casing running and slickline access. It is important to design a BHA to minimize inclination walking tendencies thus minimizing wellbore tortuousity. DLS should be kept as close as possible to ~1 0 over planned. Dogleg will take priority over angle as long as mainbore tangent angle does not approach 68 degrees. ~ 7" casing landing point: The 7" casing setting point will be determined by depth based on changes in GR/Res curves associated with the top OBe marker. After seeing the top OBe, TO will be picked based on drilling 250' MD past this marker. This footage is critical for future well work. If tops are coming in 100' or more out from proposed, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. Reference RPs: .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. "ERD Operating Practices" Job 6: Run and Cement 7" Production Casinq Criticsllssues: ~ Tight hole, packing off and lost circulation have been experienced while drilling though this interval. Good hole cleaning, mud conditioning, and drilling practices are required for trouble free drilling. In numerous cases tight hole has made backreaming necessary with stuck pipe and lost returns on only two wells. ~ Cement Job: It is imperative to achieve a good cement job on this well to achieve zonal isolation and effective injection control. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job above the Ma sand. Keep cementing EGO's below 12.5 ppg EMW during the displacement. V-221 i Permit to Drill Page 9 . . ~ Freeze Protection: Ensure the lower production cement has reached at least a 500 psi compressive strength prior to freeze protecting. After freeze protecting the 7" x 9-%" casing outer annulus with 72 bbls of dead crude (2,570' MD, 2,200'TVD), the hydrostatic pressure will be 8.0 ppg vs. 8.8 ppg EMW of the formation pressure immediately below the shoe. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be over 100 psi underbalance to the open hole. ~ Centralization/Differential Sticking: See centralizer strategy in the Well Plan Summary. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. ~ RA Tags: There will need to be 2 RA tags placed in the 7" casing for depth control. Placement strategy is: o Pip #1: Top Ma Sand o Pip #2: 40-60' above top OA sand ~ Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. ~ Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7" casing. ~ TIW Valve: Ensure that a TIW valve with a cross over to 7" BTC casing is on the rig floor before running casing. Reference RPs: .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 7: DPC Perforate Well Critical Issues: ~ The well will be perforated ±100 psi over-balanced. Ensure all personnel are well briefed on Shlumberger's perforating procedures and that all responsibilities are understood. ~ It should be stressed that while picking up and running the perforating string, only essential personnel should be on the rig floor. Normally "essential personnel" will consist of the driller, floorhands, Schlumberger perforating crew. All other personnel will stay off the rig floor and out of the cellar until the perforating string is at least 100-ft below the rotary table. ~ Contact Schlumberger to prepare for approximately 200' of 4-1/2" Power Jet guns at 5 spf to be run on DP. Exact perforation depths will be provided after reviewing the LWD logs. ~ Be prepared for fluid losses to the formation after perforating. Have ample seawater and brine on location and be prepared with LCM if necessary. Losses are not expected to be severe based on past perforation jobs. It is expected that the formation will take a little drink due to the extra pressure induced by the detonation of the perf guns. ~ It is planned to utilize LWD GR to correlate to the formation and casing RA tags to position the perforation assembly. The GR tool will be placed above the perforating assembly, the assembly is then RIH past the perf depth, the well will be logged up to correlate DP depth, and then the guns can be brought on depth and fired. ~ The LWD GR tool requires a 150-260 gpm flowrate to establish a signal. Modeling indicates a maximum pressure of 2,400 psi will be seen when pumping @ 250 gpm. Reference RPs: .:. "Wireline Pressure Control SOP" .:. "Alaska Wells Group Standard Operating Procedure: Perforating" .:. Follow Schlumberger perforating practices and recommendations V-221 i Permit to Drill Page 10 . Job 8: Run 4-%" Completion Critical Issues: ~ Barriers: o The well will have the aBa, OBb, and OBd production intervals open with an 8.6 ppg EMW formation pressure during completion operations. o Completion will be run with BOPs in place and kill weight fluid for annulus side barriers. Tubing side barriers will be provided via TIW and kill weight fluid. o Once packers are set the annulus above the packer will be tested to 4,000 psi to verify packer/annulus integrity. Kill weight fluid and the tubing hanger provide additional annulus side barriers. At this point the ball and rod with kill weight fluid and a TIW valve comprise the tubing side barriers. o Since it is not feasible to test the lower packer/annulus integrity, when the DCK valve is sheared a casing annulus valve must be in place along with kill weight fluid to provide sufficient annular barriers. Tubing side barriers are still kill weight fluid on ball and rod and a TIW. o A TWC will be installed and tested from above to 1,000 psi for 30 minutes prior to nippling down the BOP's. With the DCK valve sheared the TWC in addition to kill weight fluid provide the tubing side barrier. The annular side barrier is the casing annulus valve and the kill weight fluid. With the TWC in place BOPs can be nippled down and the tree nippled up. o With the tree nippled up freeze protecting removes the kill weight fluid as a barrier. We then count on the tree for tubing side barriers, and two casing annulus valves for annulus side protection. o Before rigging down a BPV tested from below to 1,000 psi will be left in the tubing hanger to provide an additional tubing side barrier once the rig is off. Since the DCK valve is still open it will be necessary to leave one casing annulus valve and a VR plug for annular barriers. Make sure that a lubricator is used to install the VR plug while both casing annulus valves are still in place. ~ Thread Dope: Jet Lube is the BP approved thread compound for Premium Carbon API connections. All TCII pipe should arrive on location with Jet Lube thread compound. It would still be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. ~ Torque Turn: Injectors will be used for MI injection and therefore must have all connections torque turned and charted to help reduce risk of leaks. >- Shear Valve: We will be using a DCK-2 shear valve due to the RP shear valve failure on numerous wells. The DCK-2 shear valve has had good success due to the locking mechanism that keeps the sleeve from migrating back down over the ports after the tool is sheared open. This valve does require a higher differential pressure to open. ~ Injection Mandrels: Remove the check valves from the MMGW waterflood mandrels. This will allow us the flexibility to circulate between mandrels and clean up the tubing/casing annulus later in the well life. . Reference RPs: .:. "Completion Design and Running" RP .:. "Tubing Connections" RP Job 9: ND/NU/Release Ria Critical Issues: ~ See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. ~ Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs: .:. "Freeze Protecting an Inner Annulus" RP V-221 i Permit to Drill Page 11 ö V-221 (P2) Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPIII: Survey Name I Dale: Tort I AHa I DDII ERD ratio: Grid Coordinate System: Location LaIILong: Location Grid N/E Y/x: Grid Convergence Angle: Grid Scale Factor: January 28, 2005 BP Exploration Alaska Prudhoe Bay Unit - WOA V-Pad I Plan V-2a06i (N-M) Iblll'" Plan V-221 (N-M) Fe.8 .~ Plan V-221 50029 V-221 (P2) I January 28, 2005 84.659'/8038.28 fI /6.129/1.581 NAD27 Alaska State Planes, Zone 04, US Feet N 70.32805711, W 149.26527794 N 5970103.450 flUS, E 590593.270 ftUS +0.69184469' 0.99990932 ScblUßlblPUIP Survey I DLS Computation Method: Vertical Seellon Atlmulh: S ..IU.... Vertical Section Origin: "I "'~ TVD Reference Datum: TVD Reference Elevation: Sea Bed I Ground Level Elevation: Magnetic Declination: Total Field Strength: Magnetic Dip: Dec:llnallon Date: Magnetic Declination Model: North Reference: Total Corr Mag North -> True North: Local Coordinates Referenced To: Minimum Curvature I Lubinski 22.810' N 0.000 ft, E 0.000 ft Rotary Table 82.40 ft relative to MSL 53.90 It relative to MSL 24.450' 57616.395 nT 80.804' June 15, 2005 BGGM 2004 True North +24.450' Well Head . Comments RTE KOP Bid 1.5/100 G1 Cry 2.5/100/100 600.00 6.44 359.65 517.05 599.45 13.42 15.10 15.01 -1.09 2.50 4.36G 2.49 2.76 5970118.45 590592.00 N 70.32B09812 W 149.2652B674 Cry 3.5/100 622.58 7.00 0.00 539.48 621.88 15.85 17.74 17.65 -1.09 2.50 24.60G 2.49 1.56 5970121.09 590591.96 N 70.32810534 W 149.26528680 700.00 9.53 6.83 616.09 698.49 26.36 28.85 28.74 -0.33 3.50 17.84G 3.27 8.82 5970132.18 590592.59 N 70.32813562 W 149.26528062 800.00 12.91 11.63 714.16 796.56 45.28 48.29 47.90 2.90 3.50 13.13G 3.38 4.80 5970151.38 590595.60 N 70.32818797 W 149.26525438 900.00 16.33 14.45 810.91 893.31 70.16 73.53 72.46 8.67 3.50 10.39G 3.43 2.83 5970176.01 590601.06 N 70.32825508 W 149.26520765 -"' SV6 983.06 19.20 16.05 890.00 972.40 95.28 98.87 96.90 15.36 3.50 8.87G 3.45 1.92 5970200.52 590607.46 N 70.32832184 W 149.2651. 1000.00 19.79 16.32 905.97 988.37 100.90 104.52 102.33 16.94 3.50 8.62G 3.46 1.59 5970205.97 590608.97 N 70.32833668 W 149.2651 1100.00 23.25 17.65 998.99 1081.39 137.38 141.20 137.40 27.68 3.50 7.38G 3.47 1.33 5970241.16 590619.28 N 70.32843247 W 149.2650 1200.00 26.73 18.65 1089.61 1172.01 179.48 183.43 177.53 40.86 3.50 6.48G 3.47 1.00 5970281.44 590631.98 N 70.32854210 W 149.26494663 1300.00 30.21 19.43 1177.51 1259.91 227.04 231.09 222.57 56.42 3.50 5.79G 3.48 0.78 5970326.67 590646.99 N 70.32866516 W 149.26482042 1400.00 33.69 20.07 1262.35 1344.75 279.87 284.00 272.36 74.31 3.50 5.25G 3.48 0.64 5970376.67 590664.28 N 70.32880118 W 149.26467534 1500.00 37.18 20.60 1343.81 1426.21 337.78 341.97 326.72 94.46 3.50 4.82G 3.49 0.53 5970431.25 590683.77 N 70.32894967 W 149.26451193 1600.00 40.67 21.05 1421.60 1504.00 400.56 404.78 385.43 116.79 3.50 4.46G 3.49 0.45 5970490.22 590705.39 N 70.32911006 W 149.26433079 1700.00 44.16 21.44 1495.42 1577.82 467.97 472.21 448.28 141.23 3.50 4.18G 3.49 0.39 5970553.36 590729.07 N 70.32928176 W 149.26413260 SV5 1799.99 47.65 21.78 1565.00 1647.40 539.75 544.01 515.03 167.68 3.50 O.OOG 3.49 0.34 5970620.42 590754.70 N 70.32946411 W 149.26391811 1800.00 47.65 21.78 1565.00 1647.40 539.76 544.02 515.03 167.68 3.50 3.94G 3.49 0.33 5970620.42 590754.70 N 70.32946412 W 149.26391810 1900.00 51.14 22.09 1630.08 1712.48 615.66 619.93 585.44 196.04 3.50 3.74G 3.49 0.31 5970691.16 590782.21 N 70.32965648 W 149.26368809 2000.00 54.63 22.37 1690.41 1772.81 695.38 699.66 659.24 226.21 3.50 3.57G 3.49 0.28 5970765.32 590811.48 N 70.32985810 W 149.26344342 SV4 2007.96 54.91 22.39 1695.00 1777.40 701.88 706. 16 665.25 228.68 3.50 3.55G 3.49 0.27 5970771.35 590813.88 N 70.32987451 W 149.26342335 Base Perm 2016.69 55.22 22.41 1700.00 1782.40 709.04 713.31 671.87 231.41 3.50 3.54G 3.49 0.26 5970778.00 590816.53 N 70.32989259 W 149.26340123 2100.00 58.13 22.63 1745.77 1828.17 778.64 782.92 736.17 258.07 3.50 3.42G 3.49 0.25 5970842.61 590842.41 N 70.33006824 W 149.26318501 2200.00 61.62 22.86 1795.96 1878.36 865.12 869.39 815.92 291.51 3.50 3.31G 3.49 0.24 5970922.75 590874.88 N 70.33028611 W 149.26291382 WellDesign Ver 3.1RT-SP3.03-HF5.00 Bld( d031r1-546 ) Plan V-2a06i (N-M)\Plan V-221 (N-M)\Plan V-221\V-221 (P2) Generated 1/28/20059:39 AM Page 1 of 2 Comments Fault Crossing End Cry SV3 2703.61 66.87 23.19 2000.00 2082.40 1325.36 1329.64 1239.12 472.41 0.00 O.OOG 0.00 0.00 5971348.07 591050.64 N 70.33144224 W 149.26144649 SV2 3174.66 66.87 23.19 2185.00 2267.40 1758.55 1762.84 1637.31 643.01 0.00 O.OOG 0.00 0.00 5971748.26 591216.41 N 70.33253004 W 149.26006255 SV1 4065.84 66.87 23.19 2535.00 2617.40 2578.10 2582.41 2390.66 965.77 0.00 O.OOG 0.00 0.00 5972505.37 591530.02 N 70.33458801 W 149.25744389 9-518" Csg pt 4320.46 66.87 23.19 2635.00 2717.40 2812.26 2816.58 2605.90 1057.99 0.00 O.OOG 0.00 0.00 5972721.69 591619.62 N 70.33517599 W 149.25669561 UG4 4855.17 66.87 23.19 2845.00 2927.40 3303.99 3308.32 3057.90 1251.64 0.00 O.OOG 0.00 0.00 5973175.96 591807.79 N 70.33641075 W 149.25512407 UG4A 4969.75 66.87 23.19 2890.00 2972.40 3409.36 3413.69 3154.76 1293.14 0.00 O.OOG 0.00 0.00 5973273.30 591848.11 N 70.33667534 W 149.25478729 UG3 5848.20 66.87 23.19 3235.00 3317.40 4217.21 4221.56 3897.34 1611.29 0.00 O.OOG 0.00 0.00 5974019.60 592157.24 N 70.33870383 W 149.2522_ UG1 7248.62 66.87 23.19 3785.00 3867.40 5505.08 5509.46 5081.16 2118.48 0.00 O.OOG 0.00 0.00 5975209.35 592650.06 N 70.34193758 W 149.2480 Ma 7948.83 66.87 23.19 4060.00 4142.40 6149.01 6153.40 5673.07 2372.08 0.00 O.OOG 0.00 0.00 5975804.22 592896.46 N 70.34355442 W 149.24602 Mb1 8063.41 66.87 23.19 4105.00 4187.40 6254.39 6258.78 5769.93 2413.58 000 O.OOG 0.00 0.00 5975901.57 592936.79 N 70.34381899 W 149.24569085 Mb2 8254.38 66.87 23.19 4180.00 4262.40 6430.00 6434.40 5931.36 2482.74 0.00 O.OOG 0.00 0.00 5976063.81 593003.99 N 70.34425994 W 149.24512914 Me 8458.07 66.87 23.19 4260.00 4342.40 6617.33 6621.73 6103.56 2556.52 0.00 O.OOG 0.00 0.00 5976236.86 593075.67 N 70.34473029 W 149.24452995 Na 8636.31 66.87 23.19 4330.00 4412.40 6781.24 6785.65 6254.22 2621.07 0.00 O.OOG 0.00 0.00 5976388.28 593138.39 N 70.34514184 W 149.24400563 Nb 8712.70 66.87 23.19 4360.00 4442.40 6851.49 6855.90 6318.80 2648.73 0.00 O.OOG 0.00 0.00 5976453.18 593165.27 N 70.34531822 W 149.24378092 Fault Crossing 8738.16 66.87 23.19 4370.00 4452.40 6874.91 6879.31 6340.32 2657.95 0.00 O.OOG 0.00 0.00 5976474.81 593174.23 N 70.34537701 W 149.24370601 Nb 8878.20 66.87 23.19 4425.00 4507.40 7003.69 7008.10 6458.70 2708.67 0.00 O.OOG 0.00 0.00 5976593.79 593223.52 N 70.34570037 W 149.24329403 Ne 8980.05 66.87 23.19 4465.00 4547.40 7097.36 7101.77 6544.80 2745.56 0.00 O.OOG 0.00 0.00 5976680.31 593259.36 N 70.34593554 W 149.24299439 T argetl Drp 21100 9209.21 66.87 23.19 4555.00 4637.40 7308.10 7312.51 6738.52 2828.56 0.00 180.00G 0.00 0.00 5976875.00 593340.00 N 70.34646467 W 149.24232019 OA 9209.24 66.87 23.19 4555.01 4637.41 7308.12 7312.54 6738.54 2828.57 2.00 180.00G -2.00 0.00 5976875.02 593340.01 N 70.34646473 W 149.24232011 9300.00 65.06 23.19 4591.97 4674.37 7391.01 7395.43 6814.73 2861.21 2.00 180.00G -2.00 0.00 5976951.60 593371.73 N 70.34667285 W 149.24205492 OBa 9398.42 63.09 23.19 4635.00 4717.40 7479.52 7483.94 6896.09 2896.07 2.00 180.00G -2.00 0.00 5977033.36 593405.60 N 70.34689508 W 149.24177175 9400.00 63.06 23.19 4635.72 4718.12 7480.93 7485.35 6897.38 2896.62 2.00 180.00G -2.00 0.00 5977034.67 593406.14 N 70.34689862 W 149.24176724 OBb 9494.68 61.17 23.19 4680.00 4762.40 7564.61 7569.03 6974.30 2929.58 2.00 180.00G -2.00 0.00 5977111. 97 593438.16 N 70.34710872 W 149.24149951 9500.00 61.06 23.19 4682.57 4764.97 7569.27 7573.69 6978.58 2931.41 2.00 180.00G -2.00 0.00 5977116.27 593439.94 N 70.34712041 W 149.24148461 9600.00 59.06 23.19 4732.48 4814.88 7655.91 7660.34 7058.23 2965.53 2.00 180.00G -2.00 0.00 5977196.32 593473.10 N 70.34733796 W 149.24120738 OBc 9604.90 58.96 23.19 4735.00 4817.40 7660. 11 7664.54 7062.09 2967.19 2.00 180.00G -2.00 0.00 5977200.20 593474.70 N 70.34734851 W 149.2411_ OBd 9699.30 57.07 23.19 4785.00 4867.40 7740.18 7744.61 7135.69 2998.72 2.00 180.00G -2.00 0.00 5977274.17 593505.34 N 70.34754954 W 149.2409 9700.00 57.06 23.19 4785.38 4867.78 7740.77 7745.19 7136.23 2998.95 2.00 180.00G -2.00 0.00 5977274.71 593505.57 N 70.34755101 W 149.2409 9800.00 55.06 23.19 4841.21 4923.61 7823.72 7828.15 7212.48 3031.62 2.00 180.00G -2.00 0.00 5977351.34 593537.31 N 70.34715929 W 149.24061046 9815.29 54.75 23.19 4850.00 4932.40 7836.23 7840.66 7223.98 3036.55 2.00 180.00G -2.00 0.00 5971362.90 593542.10 N 70.34719070 W 149.24063044 OBs 9815.31 54.75 23.19 4850.01 4932.41 7836.25 7840.68 7224.00 3036.55 2.00 180.00G -2.00 0.00 5977362.91 593542.10 N 70.34779074 W 149.24063039 9900.00 53.06 23.19 4899.90 4982.30 1904.68 1909.11 7286.90 3063.50 2.00 180.00G -2.00 0.00 5977426.13 593568.29 N 10.34196255 W 149.24041143 OBf 9900.16 53.06 23.19 4900.00 4982.40 7904.81 7909.24 7287.02 3063.56 2.00 180.00G -2.00 0.00 5977426.25 593568.34 N 70.34796288 W 149.24041101 OBf Bass 9916.74 52.72 23.19 4910.00 4992.40 7918.03 7922.46 7299.17 3068.76 2.00 180.00G -2.00 0.00 5977438.46 593573.40 N 70.34799607 W 149.24036872 10000.00 51.06 23.19 4961.38 5043.18 1983.54 1981.91 7359.39 3094.56 2.00 180.00G -2.00 0.00 5977498.98 593598.46 N 10.34816055 W 149.24015910 TD I 1" Csg 10065.29 --- 49.15 23.19 5002.99 5085.39 8033.85 8038.28 1405.63 3114.31 2.00 O.OOG -2.00 0.00 5977545.46 593611.12 N 10.34828686 W 149.23999812 Leoal Deser/Dtlon: Northlno IV! rftUS1 East/no IXI rftUS1 5uñace: 4855 F5L 1701 FEL 511 T11N R11E UM 5910103.45 590593.21 Target 1 : 1033F5L4153FEL536T12NR11EUM 5976875.00 593340.00 BHL: 1700 FSL 3866 FEL 536 T12N R11E UM 5911545.46 593617.72 WellDesign Ver 3.1RT-5P3.03-HF5.00 Bld( d031rt-546 ) Plan V-2a06i (N-M)\Plan V-221 (N-M)\Plan V-221\V-221 (P2) Generated 1/28/20059:39 AM Page 2 of 2 1000 NA027 Alaska State Pt,,¡;¡¡s. lone 04. US FBef Northing 5970103.45 f1:US Grid Corw: +0.69184469" Easting 590593.27 flUS Scale Fact; D.9999093231 Dall' FS PI,m V-2aû6i (N~M) v·r11 {Þ2) TVO Ref' RolilryTabl" (82.40 fI ahove M$Lj SrvyDaÜt' Jafluroy28,2005 o 1000 2000 3000 4000 5000 6000 7000 8000 RTE o 2) o 1000 ~ 2000 2000 Õ 0 0 .... ;§: II !} 16 u (jj Q 3000 3000 > I- 4000 5000 4000 7000 Oat<t ,$ NA027 A¡<'!~ka Stale PII:II'!€:$, ZOne 04. US F(!a! Northing 5970103.4-5 ftUS Grid Cony: +0.69.184469' fasting 590W3.,27ItUS SCilla Fact: 0.-99990:93231 IHO -WOA June 1~,2005 57616AnT -1000 o 1000 2000 3000 o 7000 7000 6000 6000 5000 5000 ^ ^ ^ Z ~ Õ 0 4000 0 ~ §: ~ /I (!) c¡¡ (.) (/) (/) V 3000 3000 V V 2000 2000 1000 1000 -1000 o 1000 2000 «< W Scale = 1(in):1000(fI) E »> 3000 4000 . . BP Alaska Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 10065.29 ft Maximum Radius: 10000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 8/20/2002 Validated: No Planned From To Survey ft ft 28.50 1400.00 Planned: Plan #2 V1 28.50 10065.29 Planned: Plan #2 V1 Version: Toolcode Tool Name MWD MWD+IFR+MS MWD - Standard MWD + IFR + Multi Station Casing Points PB V Pad Plan V-112 (S-A) Plan V-112 V1 Plan: PI 347.68 350.00 284.57 6.41 278.16 Pass: Major Risk PB V Pad Plan V-214 (N-R) Plan V-214 V3 Plan: V 550.40 550.00 76.21 10.42 65.79 Pass: Major Risk PB V Pad V-01 V-01 V15 249.90 250.00 181.28 4.36 176.91 Pass: Major Risk PB V Pad V-02 V-02 V12 250.80 250.00 100.68 4.43 96.26 Pass: Major Risk PB V Pad V-03 V-03 V7 907.66 900.00 151.92 15.15 136.77 Pass: Major Risk PB V Pad V-100 V-100 V7 298.80 300.00 225.88 5.00 220.88 Pass: Major Risk PB V Pad V-101 V-101 V7 449.01 450.00 171.96 7.19 164.77 Pass: Major Risk PB V Pad V-102 V-102 V5 449.68 450.00 54.06- 8.49 45.57 Pass: Major Risk PB V Pad V-103 V-103 V6 1313.40 1300.00 79.75- 28.54 51.21 Pass: Major Risk PB V Pad V-104 V-104 V13 400.16 400.00 115.50 6.47 109.03 Pass: Major Risk PB V Pad V-105 V-105 V13 399.95 400.00 1 §..99- 6.51 9.58 Pass: Major Risk PB V Pad V-106 V-106 V10 949.51 950.00 ~ 16.02 35.38 Pass: Major Risk PB V Pad V-106 V-106A V9 1211.46 1200.00 33.88~ 24.57 9.31 Pass: Major Risk PB V Pad V-106 V-106APB1 V6 1211.46 1200.00 33.88 24.57 9.31 Pass: Major Risk PB V Pad V-106 V-106APB2 V2 1211.46 1200.00 33.88 24.57 9.31 Pass: Major Risk PB V Pad V-106 V-106APB3 V2 1211.46 1200.00 33.88 24.57 9.31 Pass: Major Risk PB V Pad V-107 V-107 V5 498.12 500.00 ß,5.10- 7.58 77.52 Pass: MajorRisk PB V Pad V-108 V-f08 V7 250~08 250.00 207.03 4.23 2Ó2.79 Pass: Major Risk PB V Pad V-109 V-109 V2 396.58 400.00 242.29 6.65 235.63 Pass: Major Risk PB V Pad V-109 V-109PB1 V5 396.58 400.00 242.29 6.65 235.63 Pass: Major Risk PB V Pad V-109 V-109PB2 V2 396.58 400.00 242.29 6.65 235.63 Pass: Major Risk PB V Pad V-111 V-111 V25 805.09 800.00 130.19 14.70 115.49 Pass: Major Risk PB V Pad V-111 V-111PB1 V8 805.09 800.00 130.19 14.70 115.49 Pass: Major Risk PB V Pad V-111 V-111PB2 V2 805.09 800.00 130.19 14.70 115.49 Pass: Major Risk PB V Pad V-111 V-111PB3 V6 805.09 800.00 130.19 14.70 115.49 Pass: Major Risk PB V Pad V-113 V-113V6 348.16 350.00 262.28 5.24 257.05 Pass: Major Risk PB V Pad V-114 V-114 V5 300.56 300.00 223.91 4.96 218.96 Pass: Major Risk PB V Pad V-114 V-114A V4 300.56 300.00 223.91 4.96 218.96 Pass: Major Risk PB V Pad V-114 V-114APB1 V4 300.56 300.00 223.91 4.96 218.96 Pass: Major Risk PB V Pad V-114 V-114APB2 V2 300.56 300.00 223.91 4.96 218.96 Pass: Major Risk PB V Pad V-115 V-115V5 299.39 300.00 245.38 4.91 240.47 Pass: Major Risk PB V Pad V-115 V-115PB1 V4 299.39 300.00 245.38 4.91 240.47 Pass: Major Risk PB V Pad V-117 V-117V9 298.60 300.00 209.02 5.13 203.89 Pass: Major Risk PB V Pad V-117 V-117PB1 V6 298.60 300.00 209.02 5.13 203.89 Pass: Major Risk PB V Pad V-117 V-117PB2 V6 298.60 300.00 209.02 5.13 203.89 Pass: Major Risk PB V Pad V-119 V-119V13 442.04 450.00 232.21 7.56 224.65 Pass: Major Risk PB V Pad V-120 V-120 V5 300.28 300.00 165.37 5.23 160.14 Pass: Major Risk PB V Pad V-201 V-291 V8 448.46 450.00 71.860- 7.12 64.74 Pass: Major Risk PB V Pad V-202 V-202 V9 448.80 450.00 144.91 7.82 137.09 Pass: Major Risk PB V Pad V-202 V-202L 1 V5 448.80 450.00 144.91 7.78 137.13 Pass: Major Risk PB V Pad V-202 V-202L2 V5 448.80 450.00 144.91 7.78 137.13 Pass: Major Risk PB V Pad V-204 V-204 V2 626.59 650.00 191.39 10.75 180.63 Pass: Major Risk PB V Pad V-204 V-204L 1 V2 626.59 650.00 191.39 10.75 180.63 Pass: Major Risk . . BP Alaska Anticollision Report PB V Pad V-204 V-204L1PB1 V6 626.59 650.00 191.39 10.75 180.63 Pass: Major Risk PB V Pad V-204 V-204L2 V2 626.59 650.00 191.39 10.75 180.63 Pass: Major Risk PB V Pad V-204 V-204L2PB1 V5 626.59 650.00 191.39 10.75 180.63 Pass: Major Risk PB V Pad V-204 V-204L3 V3 626.59 650.00 191.39 10.75 180.63 Pass: Major Risk PB V Pad V-204 V-204PB1 V9 626.59 650.00 191.39 10.75 180.63 Pass: Major Risk PB V Pad V-204 V-204PB2 V2 626.59 650.00 191.39 10.75 180.63 Pass: Major Risk PB V Pad V-21 0 V-210 V9 549.21 550.00 129.33 9.53 119.80 Pass: Major Risk PB V Pad V-211 V-211 V5 301.46 300.00 190.22 5.04 185.18 Pass: Major Risk PB V Pad V-213 V-213 V5 1081.82 1100.00 196.86 21.03 175.83 Pass: Major Risk PB V Pad V-213 V-213PB1 V5 1081.82 1100.00 196.86 21.03 175.83 Pass: Major Risk PB V Pad V-216 V-216 V8 2606.37 2500.00 85.93. 61.92 24.01 Pass: Major Risk 147 ······100 ·····50 Y.21O (Y.21~7( """50 V -1(¡2~J'(1(¡2D2) "100 147 ~ V-JO y. L1 ~ Field: Prudhoe Bay Site: PB V Pad Well: Plan V-221 (N-M) Wellpath: Plan V-221 " L..:jN:~ 3 /D m I\~~~~ :. ,m ~ L"" 3 '"",~ . ;/-/'01 "'-.J / ~ Y-216 (Y·216) ./'l-...L _ . 2 ~ j' /Ll - -.., . 24 ti ff~ ::113'\. 7 -.., ---------- ,- '/ ~ --=:G."\. " 24 K\ 7;1( ">< ~ 5 I\~ --J7'- ~ ~~, / k:i -1 ~ '/ ....; 0 -- __ -f 7-·------...--- ~ 1I.J1' .' \ Y ~"f 'I\. 7/- fl~ ~ ~~ . if . .1lIif\ ,,-.. . ,>cv ~ Þ1 X ! ^--;/ ,r-, I ~ t;::-:.)< i ><=]>1 \"- \ l/':j C~ Iv ! ! Æ. ..' \ '12--.. ~' /'. 8")1< ß 4. -1\( ¡:;~ '>(\1 J -IÍ ~ ~ ~ / A ~ fT7S< Þ< "'~. I'XV t?1 -----.:, '~ ~. -:þ ." 1>< ~ ~ d· l--~ ~ ß. y, oß -" '\ -151 ';t"~ ~ ')f( Ik· ~.~ Y AI 0. Jr Æ .¿ 1J k............ '7c ' ~ l' 1)\ Æ,\ ~,.A>i~~V '0...,~~ ,/ '" k m \ II .. _ . -'" ~ "'\. ~ V·lll (Y.lLlfBJ) "'"")( I )i . WI} 7"'- ~ -4 V.o2(V.o2) \/k:í ~ 1"·1 ,I , ~ 1') ~ ~.!\ "'~~ ,( r \ .... ~~;,,\ (lJ,i V'I~(V.~~~j>( ~~ ~ ~ ~µ ~I " î{ ~ ~ PlanY-214(N·R)(PlanV·214) ~""":;¡;'2\~ . / / / / 2 , , Y 106 (Y 106) 180WItxn:WIIli) Travelling Cylinder Azimuth (TFO+AZI) [degJ vs Centre to Centre Separation [50ft/in] . . Site: PB V Pad . Drilling Target Conf.: 95% Description: Map Northing: 5976875.00 ft Map Easting : 593340.00 ft Latitude: 70020'47.273N Shape: Circle Target: V-221 Tgt 1 . Well: Plan V-221 (N-M) Based on: Planned Program Vertical Depth: 4555.00 ft below Mean Sea Level Local +N/-S: 6738.50 ft Local +E/-W: 2828.55 ft Longitude: 149° 14'32.353W Radius: 150 ft ----- - - - --~-------~~--------~--~ -- ------- ----- .--"------_._--~_.__._-------~._.---,._._-----------~-- 100 lOOO 5900 5800 5100 5500 5500 0 CJ CJ CJ CJ CJ CJ o 0 CJ CJ 0 CJ CJ CJ o 0 ø r- CD a- CJ N o 0 ( J N N N (I) (I) (I) o ~ J ,n ) CfJlWEkwalion::::: 52.4' Nafmro 9ES RKB::::: 80.9 9-518",40 11ft, L-80, BTC T Short Joint &. RA Ma sand 4-1/2" X 3-1/2" RA in OBa sand Perfs: Gap for thru- tubing future OBc OBd sand Perfs: T8D- 01131/05 TREE: FMC 4-lI1a" WELLHEAD: FMC 11",5M 11"x1 11 x 11" X 8. 20" X 34" 215.5 ibffl:, A53 ERW insl..!!a'œd 4-112" with 3.813" seal bore. 4-112",12.6 Drift 110 : 3-112", 9.3 Drift 110 : lift mandraI4-1/2" xi" KBG2 Shear Valve to 2,500 with 3.813" seal bore. 7" x 4-1/2" Baker 'PRM' Production Packer Camco 3-1/2" x 1-1/2" MMG-W GLM Cameo 3-1/2" )(1-1/2" MMG-W GLM 3-1/2" 'X' with 2.813" 7" :x 3-112" Baker 'PRM' Production 3-112" 'X' with 2.813" seal bore. 3-1/2" Wire Line 08e 7", 26 c--------------- II E 5.172 I I I I I I I I I I I I I I --------- GRID 15'00'oo"r PLANT I 7-Z- I · V-120 · V-03 · V-110 · V-111 · V-216i · V-103 · · V-115 · V-213i · V-100 · V-117 · SLOT S-R V-106 , V-105i V- 221 i .".. · V-01 o '" '" ò · V-102 · V-201 · V-107 · V-02 · V-104i · V-210i · V-202 · V-SPARE(SLOTN-E) · V-101 · V-211i · V-108 · V-203 · V-SPARE (SLOT S-L) z · SLOT S-J · V-204 · V-114 · V-119 · V-109 · V-113 v-p AD o on co oil z¡ I I I I I I I \ \ " 10 SP\NE ROAD --P"""" --- LEGEND -+- AS-BUILT CONDUCTOR . EXISTING CONDUCTOR NOTES 1. DATE OF SURVEY: JULY 31, 2002. 2. REFERENCE FIELD BOOK WO-02-10, PAGES 21-22. 3. ALASKA STATE PLANE COORDINATES ARE ZONE 4, NAD 27. GEODETIC POSITIONS ARE NAD '27. 4. BASIS OF HORIZONTAL CONTROL IS V-PAD OPERATOR MONUMENTATION. 5. BASIS OF ELEVATION IS KUPARUK PIPELINE CONTROL. ELEVATIONS ARE BP MSL DATUM. 6. THE MEAN SCALE FACTOR FOR V-PAD IS 0.999909334. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 31, 2005. WELL NO. V-NM LOCATED WITHIN PROTRACTED SEC. 11, T. 11 N., R. 11 E., UMIAT MERIDIAN, ALASKA ASP. PLANT GEODETIC GEODETIC CELLAR SECTION COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD BOX ELEV. OFFSETS Y=5,970,103.45 N=10,180.10 70·19'41.006" 70.3280572· 53.9' 4,856' FSL X= 590,593.27 E= 4,849.76 149·15'55.000" 149.2652778· 1,707' FEL ~~~, ~ ffi~~[ln~D o 1 31 05 ISSUED FOR INFORMATION NO. DATE REVISION JJ RFA BY CHK ENQNŒRS AND LAND SUR'VEYORS 801 WEST FlR('M:ED LANE ANCHORllOE. AlASKA 99503 DRAWN: JACOBS CHECKED: ALUSON DATE: 1/31/05 DRAWING: FRB05 WOV 02-00 JOB NO: SCALE: 1·=150' ObP GREATER PRUDHOE BAY V-PAD AS-BUILT CONDUCTOR WELL V- 221 i SHEET: 1 OF 1 TERRIE L HUBBLE BP EXPLORATION AK INC ¡'Mastercard Check" PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 176 DATE 0 ~ {)14QS ~Q;~:~~~<L, $10D':cARS :::"gr~~\ ~{.~...~ . I: J. 25 20001;OI:QQ J......II; 2 27111 J. 5 51;11- 0 J. 71; . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~tVt .. 1/- ZZI j PTD# 'LoS·· 0 /~':S ~ Exploration Stratigraphic Development Service CHECK WHAT ADD-ONS ~'CLUE ". APPLIES (OPTIONS) MULTI Tbe permit is for a new weIJboresegmeut of LA TERAL nistiug well . Permit No, API No. . (If API Dum ber Production. sbould conti Due to be reported as last two. (2) digits a function' of tbe original API number. stated are between 60-69) above. PILOT HOLE In accordance witb 20 AAC 25.005(f), an (PH) records, data and logs acquired .for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) .' and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTION .' compJiance witb 20 AAC 2S..0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spa dug e:J ception. (Company Name) assumes tbe liability of any protest to the spacing .e:Jception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater ·tban 30' .' sample intervals from below the permafrost or from where samples are first caugbt aud 10' sample h:iter:vals tbrough target zones. 640135 Well Name: PRUDHOE BAY UN ORIN V-221 Program SER _ Well bore seg D -- INC nitial Class/Type SER l1WINJ GeoArea Unit On/Off Shore On Annular Disposal D - - - - - Administration Pe(mit fee attached · Yes. - - - - - - 2 .Lease .number .appropriate · Yes. - - - - - 3 .U.nique welt n.ame .and oumb.er - - - - .... Y~s - - - - - - - - - - - - - - - - - - - - - - ~ 4 Wen Jocated in.a defined pool · Yes.. - - - - - - - - - - - - - 5 WeJUocated proper .distance. from driJling unitb.ound.a!)' Yes. - - - - - - - - - - - - 6 WenJocated proper distance from otlJer wells. · Yes. 7 .S.ufficientacreage.ayailab1e indrilJiog unjt. . · Yes. 8 Jfdeviated, js. weJlbore platincJuded . Yes. - - - - - - 9 .O,µerator onl)' affected party. Yes. 10 .O.µerator lJas.appropriate.b.ond inJor~ . . . . . . . . . ... . .Y~s. - - - - - - - - - - - - - - - -- - - - - - - - - - 11 Pe(mit can be issued wjtlJout co.nserva.tion order. · Y.es. - - - - - - Appr Date 12 Pe(mit~ao be issued witbQut administ(atil¡eapprpvaJ . . · Y~s - - - - - .. RPC 2/2/2005 113 Can permit be approved before 15-day wait Yes 14 Well JQcated wtthin area and.strata .authori;1:ed by.lnjectioo Orde( # (put 10# in. cpmm.ents). (For. Yes ,11.10-22 - - - - - - 15 AJI welJs.withinJl4.mile.area.of (eyiew identified (Fpr servjc~we!l onl)'>. . . . . . . . . . . . . . . Y~s teJO WE;LL$ WITtlIN.1l4. MIL.E OF .C.QMP'LETION.INTER\{AL~RP.C. 16 Pre-produced injector; duratiQnof pre-productioo I~ss. than:3 montbs (Forser:vice welt onJy) . .NA 17 ACMP finding.of Conststency. h.as bee.n issued. for. this pr.oject NA. .- -- Engineering 18 C.onductor s!(ingprovided . . · Yes. 2Q" x34"@.109'. . 19 .S~H:faœcasingprotecJs allknQwll USDWs . · Yes. 20 .CMT vol adequate to circulate on .cond.uctor 8. surf csg . Yes. Ade~uate excess. 121 CMT vol adequ.ateJo tie-in Jongstring tosul"f csg · No. 22 CMT wilJ coveraJl Koown .Pfo.ductive lJori¡¡:on.s. . · Yes. 23 .C.asing designs adec¡ua.te fpr C, T, B.& permafrost · Yes. - - - - - - 24 Adequatetan.kage.or re.serve pit. · Yes. teJabo(sJES, . 25 Jfa. re-drilL has. a 10A03 fQr abandonment beeo approved .NA. New well, . 26 Adequate .well bore separatjo.n .Pfoposed. . . . . . . . . . . . . . . ..... Yes. - - - - - - - - - - - - - - - - - - -- 27 Jf.divecter required, does it meet reguJations Y~s. Appr Date 28 .DrilJiog fIuidpJQgram schematic&. eq.uip Jistadequate. . Yes. Max MW.9Jl ppg. . . WGA 2/2/2005 29 BOPES,dpthey meetreguJation . · Yes 30 .BOPE.press raJing aPP(op(iate;test to.(put psig in.comments) . Yes . TesttoAOQO.psi. .MSr:> 1701 psi.. 31 Choke manifOld compJies wlAPI Rr:>-53 (May 84) · Yes. 32 Work will oCCU( without .operatjonshutdown. · Yes 33 Js presence of H2$ gas. prob.able. . · No.. NoLan H2$ pad. . 34 MecbanicaLcoodjtjoo .of wells within AOR verified (for s.ervice welJ only) · Yes. teJo wells witbio AOR.. - Geology 35 Permit can be issued wlo hydr.ogen. s.ulfide meas].Jres . · Yes 36 .D.atapreseoted Oil pote.ntial oveJpressure .;1:ones. . .NA. Appr Date 37 .Seismicanalysjs. of slJaJlow gaszooes · NA RPC 2/2/2005 38 Seabedconditioo survey.(if off-shore) . .NA. - - - - - 39 . Conta.ct nam.elpl1oneJor.weelsly progress reports [expIQrato!)'only] .NA. - Geologic Date: Engineering Date Date Commissioner Commissioner: ~/~ - <-j3)S DJ S