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205-163
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Sunday, January 26, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC C-28A MILNE PT UNIT C-28A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 01/26/2025 C-28A 50-029-22648-01-00 205-163-0 W SPT 6499 2051630 1625 1747 1748 1748 1742 362 403 413 413 OTHER P Austin McLeod 12/15/2024 Well under eval for possible AIO. Operator opted to not test to MAIP. 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:MILNE PT UNIT C-28A Inspection Date: Tubing OA Packer Depth 801 2402 2335 2325IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM241215182934 BBL Pumped:3.1 BBL Returned:2.8 Sunday, January 26, 2025 Page 1 of 1 9 9 9 9 9 9 999 9 9 9 9 9 9 9 Well under eval for possible AIO James B. Regg Digitally signed by James B. Regg Date: 2025.01.26 23:10:57 -09'00' 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: Operable - MPC-28A (PTD# 2051630) - Passing MIT-IA Date:Tuesday, January 7, 2025 4:08:49 PM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Friday, December 20, 2024 9:56 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Operable - MPC-28A (PTD# 2051630) - Passing MIT-IA Mr. Wallace, WAG injector MPC-28A (PTD# 2051630) was brought on water injection and passed an AOGCC witnessed MIT-IA on 12/15/24 to 2325 psi. IA pressure has been stable at ~900 psi since coming back on injection. The well is now re-classified as Operable and will remain on injection. Please respond with any questions or comments. Thank you, Ryan Thompson Milne / Islands / WNS Well Integrity Engineer 907-564-5005 From: Matthew Ross <Matthew.Ross@hilcorp.com> Sent: Sunday, December 8, 2024 1:04 PM To: 'Wallace, Chris D (DOA)' <chris.wallace@alaska.gov>; jim.regg <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Under Evaluation - MPC-28A (PTD# 2051630) Mr. Wallace, WAG injector MPC-28 (PTD# 2051630) has had a passing PPPOT-T on 6/12/2024 and a recent passing MIT-IA to 2448psi on 12/8/2024. As the well was experiencing IA repressurization while on gas, the well has been reclassified to Under Evaluation. Plan Forward: 1. POI to water & monitor for additional repressurization with stable injection rate. 2. Once stabilized injection perform witnessed MIT-IA. Thank you. Matthew Ross 907-980-0552 From: Ryan Thompson Sent: Tuesday, June 25, 2024 11:17 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Not Operable - MPC-28A (PTD# 2051630) - Failed MIT-IA Mr. Wallace, WAG injector MPC-28A (PTD# 2051630) passed a PPPOT-T on 6/12/24. On 6/21/24 a MIT-IA to 1625 psi failed. The well was shut in and freeze protected. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Wednesday, June 12, 2024 2:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Under Evaluation - MPC-28 (PTD# 2051630) - IA Repressurization Mr. Wallace, WAG injector MPC-28 (PTD# 2051630) was bled on 5/31/2024. The well is experiencing IA repressurization and has been reclassified to Under Evaluation. The well is currently on gas injection with an increasing trend in injection rate. The wells last MIT-IA passed to 1840 psi on 3/25/22. Plan Forward: 3. PPPOT-T 4. Monitor for additional repressurization with stable injection rate. 5. MIT-IA if additional repressurization is observed. Attached is a WBS and 90 day TIO plot. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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 considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from matthew.ross@hilcorp.com. Learn why this is important From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Under Evaluation - MPC-28A (PTD# 2051630) Date:Monday, December 9, 2024 8:58:05 AM From: Matthew Ross <Matthew.Ross@hilcorp.com> Sent: Sunday, December 8, 2024 1:04 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com>; Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: Under Evaluation - MPC-28A (PTD# 2051630) Mr. Wallace, WAG injector MPC-28 (PTD# 2051630) has had a passing PPPOT-T on 6/12/2024 and a recent passing MIT-IA to 2448psi on 12/8/2024. As the well was experiencing IA repressurization while on gas, the well has been reclassified to Under Evaluation. Plan Forward: 1. POI to water & monitor for additional repressurization with stable injection rate. 2. Once stabilized injection perform witnessed MIT-IA. Thank you. Matthew Ross 907-980-0552 From: Ryan Thompson Sent: Tuesday, June 25, 2024 11:17 AM To: 'Wallace, Chris D (OGC)' <chris.wallace@alaska.gov>; 'Regg, James B (OGC)' <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Not Operable - MPC-28A (PTD# 2051630) - Failed MIT-IA Mr. Wallace, WAG injector MPC-28A (PTD# 2051630) passed a PPPOT-T on 6/12/24. On 6/21/24 a MIT-IA to 1625 psi failed. The well was shut in and freeze protected. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Wednesday, June 12, 2024 2:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Under Evaluation - MPC-28 (PTD# 2051630) - IA Repressurization Mr. Wallace, WAG injector MPC-28 (PTD# 2051630) was bled on 5/31/2024. The well is experiencing IA repressurization and has been reclassified to Under Evaluation. The well is currently on gas injection with an increasing trend in injection rate. The wells last MIT-IA passed to 1840 psi on 3/25/22. Plan Forward: 3. PPPOT-T 4. Monitor for additional repressurization with stable injection rate. 5. MIT-IA if additional repressurization is observed. Attached is a WBS and 90 day TIO plot. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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 considers appropriate. CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Not Operable - MPC-28A (PTD# 2051630) - Failed MIT-IA Date:Tuesday, June 25, 2024 11:32:04 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Tuesday, June 25, 2024 11:17 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Not Operable - MPC-28A (PTD# 2051630) - Failed MIT-IA Mr. Wallace, WAG injector MPC-28A (PTD# 2051630) passed a PPPOT-T on 6/12/24. On 6/21/24 a MIT-IA to 1625 psi failed. The well was shut in and freeze protected. The well is now classified as NOT OPERABLE and will remain shut in until well barriers are restored. Please respond with any questions. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 From: Ryan Thompson Sent: Wednesday, June 12, 2024 2:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Under Evaluation - MPC-28 (PTD# 2051630) - IA Repressurization Mr. Wallace, WAG injector MPC-28 (PTD# 2051630) was bled on 5/31/2024. The well is experiencing IA repressurization and has been reclassified to Under Evaluation. The well is currently on gas injection with an increasing trend in injection rate. The wells last MIT-IA passed to 1840 psi on 3/25/22. Plan Forward: 1. PPPOT-T 2. Monitor for additional repressurization with stable injection rate. 3. MIT-IA if additional repressurization is observed. Attached is a WBS and 90 day TIO plot. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 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 - MPC-28 (PTD# 2051630) - IA Repressurization Date:Tuesday, June 18, 2024 8:15:24 AM Attachments:MPC-28 90 day TIO.docx MPC-28A.pdf From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Wednesday, June 12, 2024 2:39 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: Taylor Wellman <twellman@hilcorp.com> Subject: Under Evaluation - MPC-28 (PTD# 2051630) - IA Repressurization Mr. Wallace, WAG injector MPC-28 (PTD# 2051630) was bled on 5/31/2024. The well is experiencing IA repressurization and has been reclassified to Under Evaluation. The well is currently on gas injection with an increasing trend in injection rate. The wells last MIT-IA passed to 1840 psi on 3/25/22. Plan Forward: 1. PPPOT-T 2. Monitor for additional repressurization with stable injection rate. 3. MIT-IA if additional repressurization is observed. Attached is a WBS and 90 day TIO plot. Thank you, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that 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 considers appropriate. Size SPF Interval (TVD) Perforation Summary Ref log: DATE REV. BY COMMENTS Orig. DF Elev. = 46.5' (N 22E) Orig. GL Elev. = 16.8' RKB = 43.18' Doyon-14 Tree: 3 1/8" 5M Wellhead: FMC 11" x 11" 5M, Gen. 5 w/ 11" x 3.5" FMC Tbg. Hnr. w/ TCII threads top and bottom.and 3" CIW H BPV profile MILNE POINT UNIT WELL MPU C - 28ai API NO: 50-029-22648-00-00 BP EXPLORATION (AK) 7" Weatherford float collar 7" Weatherford float shoe 8,768‘ 8,683‘ KOP @ 600' Max. hole angle = 38 to 60 deg. f/ 2700' - 6800‘ Hole angle thru' perfs = 27 deg. 20" 91.1 ppf, H-40 MPU C - 28ai 115' RA marker at 8071' wlm Note: Original Well Bore Info: CIBP set @ 5,529‘ 9-5/8“ original float shoe @ 5,405‘ 7" 26#/ft , L-80, BTC-M csg. (drift ID = 6.151", cap. 0.0383 bpf ) 3.5“ 9.2#/ft , L-80 TCII Tbg. ( drift ID = 2.992" cap .00870 bpf ) Sidetrack kickoff @ 5,470‘ 9-5/8“ float shoe @ 5,405‘ 01/08/06 MDO Sidetrack Completion Doyon - 14 3.5" HES float collar 3.5" HES float shoe 9,430‘ 9,396‘ 3.5“ Baker Landing Collar 9,364‘ 7“ x 3.5” Baker Liner Tie Back Slv. “C2” ZXP Liner Top Packer Baker Flex Lock Liner Hng. 8,608‘ 8,620‘ 8,626‘ 3.5“ HES X-Nipple 2.813”2,495‘ 3.5“ HES X-Nipple 2.813” 3.5“ HES XN-Nipple 2.750” No Go 8,569‘‘ 8,457‘ 7“x 3.5” Baker S-3 Pkr.8,510‘ 2 6 9034-9042 6948-6956 2 6 9174-9188 7084-7098 2 6 9196-9220 7106-7130 2.5 6 9074-9134 6987-7045 Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 12/30/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU C-28A (PTD 205-163) IPROF 12/08/2021 Please include current contact information if different from above. Received By: 01/03/2022 By Abby Bell at 9:26 am, Jan 03, 2022 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 1400 30 5 15 Anchorage, AK 99503 Tele: 907 777-8337 H lm, p Alo.kr, LLC Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATE: 3/26/2019 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Ste 100 Anchorage, AK 99501 IPROF CD: HALLIBURTON 3 SEP 2018 MPC-28Ai [PROF 03SEP18 MPC-2BAUPROF 03SEP18 040-dn MPC-28Ai_IPROF_03SEP78 040 -up MPC-28Ai_IPROF_03SEP18_080-dn MPC-28Ai_IP'ROF 03SEP1$ 080 -up K4PC-Z8AiIPROF 03SEP18 120-dn WC-28Ai_IPROF 03SEP18_120-up MPC-28Ai_IPROF 03S€P18_img MPC-28Ai IPROF 03SEP18 Station8555 MPC-28Ai_[PROF _03SEP18 Station 8975 MPC-28Ai (PROF 03SEP78_Station 9034 MPC-28Ai_[PROF _03S€P78 Station 9131 MPC-28Ao_IPROF_03S€P18 Station 9158 RECEIVE® AAAn n 1.1/49 c 6 ZU19 AOGCC 11/13/20189:11 AM PDF Document 11/13/26189:11 AM LAS File 11/13/2018 9:11 Aho LAS File 11/13/2018 9:11 AM CAS File 11/13/20189:11 AM LAS File 11/13/2018 9:11 AM LAS File 11/13/2D189.11 AM LAS File 11/13/2018 9:11 AM TIFF File 11/13,!20189:11 AMT LAS File 11/13/2018 9:11 AM LAS File 11/13/20189:11AM [ASFe 11/13.720189:11 AM LAS File 1 1/1 3/201 8 9:11 AM LAS Fife Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg /1 DATE: Tuesday,March 20,2018 P.I.Supervisor i�eiy' 31ZDI I'U SUBJECT: Mechanical Integrity Tests (( HILCORP ALASKA LLC C-28A FROM: Bob Noble MILNE PT UNIT C-28A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 0-R12— NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT C-28A API Well Number 50-029-22648-01-00 Inspector Name: Bob Noble Permit Number: 205-163-0 Inspection Date: 3/12/2018 - Insp Num: mitRCN180312165346 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well C-28A -Type Inj W `TVD 6499 Tubing 2709 2710 2710 2710 PTD_i 2051630 Type Test SPT Test psi 1625 IA 571 3427 3347 3333 BBL Pumped: 2.8 "BBL Returned: 3.4 OA 601 686 695 698• Interval] 4YRTST IP/F I P Notes: SCOE2 Tuesday,March 20,2018 Page 1 of 1 • • by BP Exploration (Alaska) Inc. M Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 VNIF aos-I'3 ' Mr. Tom Maunder ,n/� C■ g- Alaska Oil and Gas Conservation Commission ' 1 ,,,..,,.. s' r' 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -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, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC-05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC-07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC-08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC-09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC -11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC-13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC-14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC -21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC -24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 ---a■ MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 10.2 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC -42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 MPC -43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 0 • WELL LOG MA SM AL PRoAcrivE DiACINOS& SERViCES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE: Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc.�� Petrotechnica) Data Center ` Attn: Joe Lastufka LR2 -1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. _ Attn: Robert A. Richey U"'S C- C ? : -! 3 as 3�c� 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Injection Profile 14-Aug-1 0 MPU G-19 BL / EDE 50 -029- 23228 -00 ?l 2 ] Injection Profile 14-Aug-1 0 MPU C-28A BL / EDE 5 ��•2 Signed: On Date Diu c r Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)2454951 FAX: (907)245 -88952 E- MAIL : odsanchoracleta7memorvloa.com WESSITE : vombi.memorylog.com CADocuments and SettinpTiane WUhamiQesktop \Transmit_BP.docx '~~ ;~ ~- ` ~ '! , t ~1~q~6i y ~ J`~ " " ~.~ `. ~. ,.. r. x ~« MICROFILMED 6/30/2010 DO NOT.PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet:Files\OLK9\Microfilm_Marker.doc MEMORANDUM • To: Jim Regg ' l~ ~ 3'3/'lc P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 26, 2010 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC C-28A NIILNE PT UNIT KR C-28A Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv~l ~ Comm Well Name: MILNE PT UNIT KR C-28A Insp Num: mitJJ100321075915 Rel Insp Num: API Well Number: 50-029-22648-01-00 Permit Number: 205-163-0 Inspector Name: Jeff Jones Inspection Date: 3/19/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel] C-28A Type Inj. w TVD 6499 ~ IA 0 4000 / 3960 3980 P.T.D 2051630 TypeTest SPT Test psi 1624 / QA 440 760 760 780 Interval4YRTST per, P ~ Tubing 1400 1500 1550 1580 Notes: 4.3 BBLS 15 deg. F diesel pumped; well head temp. 129 deg. F. 1 well inspected, no exceptions noted. i ~~~ k ,r. ~t~~t ~,_,, ;~ ~~.~ Friday, March 26, 2010 Page 1 of 1 • STATE OF ALASKA g~E~`j~I Y ~® ALASKA AND GAS CONSERVATION COMMISS~ REPORT OF SUNDRY WELL OPERATIONS MAR 1 8 2010 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other Q~~ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time E ~~'~ Change Approved Program ^ Operat. Shutdown ^ Perforate 0 Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: . Permit to Drill Number: Name: Development ^ Exploratory ^ 205-1630 3. Address: P.O. Box 196612 Stratigraphic^ Service Q .API Number: Anchorage, AK 99519-6612 50-029-22648-01-00 8. Property Designation (Lease Number) : 9. Well Name and Numb ~ADLO-047434 MPC-28A MILNE POINT FIELD/ KUPARUK RIVER POOL POOL Well Condition Total Depth measured ~ 9430 feet Plugs (measured) None feet true vertical ~ 7339.39 feet Junk (measured) None feet Effective Depth measured 9396 feet Packer (measured) 8510 true vertical 7305.5 feet (true vertical) 6499 Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 91.1# H-40 32 - 112 32 - 112 1490 470 Surface 5405 9-5/8"40# L-80 31 - 5405 31 - 7642 5750 3090 Intermediate Production 8768 7" 26# L-80 33 - 8768 33 - 6709 7240 5410 Liner 821 3-1/2"9.3# L-80 8609 - 9430 6579 - 7339 10160 10550 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ = = True Vertical depth: _ - - - = Tubing: (size, grade, measured and true vertical depth) 3-1/2" 9.2# LL-80 SURFACE - 8614 SURFACE - 6583 ` 1 Packers and SSSV (type, measured and true vertical depth) 7"X3-1/2" S-3 PKR 85 X99 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~ ~"' `~~~~ ~ ~~~ ~` ~' ~~~ Treatment descriptions including volumes used and final pressur e: - ~ ~ 13. Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 959 1249 Subsequent to operation: 1130 2544 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GS OR ^ WAG Q GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310-046 Contact Gary Preble Printed Name Gary Pre I' Title Data Management Engineer Signature aj/J _ ,~.,._ Phone 564-4944 Date 3/16/2010 3 ~r~~ro MPC-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/11/2010E***WELL SHUT-IN ON ARRIVAL***(ELINE-ADPERF) jSSV = C, INITIAL T/I/O = 1200/0/90 [SPOT EQUIPMENT, RU ELINE ' 1 [***JOB CONTINUED ON 12-MARCH-2010*** 3/12/2010***JOB CONTINUED FROM 11-MARCH-2010***(ELINE -ADPERF) RU ELINE, RIH WITH PERF GUN, HAVE PROBLEMS WITH CCL SIGNAL, POOH CHANGE TOOLSTRING. CURRENTLY IN HOLE WITH 30' 2.5" HSD PJ 2506 HMX PERF GUN. SAT DOWN AT 8840', UNABLE CONTINUE IN j HOLE. 600 LBS OVER PULL ON PICK UP, PICK UP IS STICKY FROM X8750'-8840', MADE 3 ATTEMPTS, STANDBY FOR PUMPERS. 1***JOB CONTINUED ON 13-MARCH-2010*** 3/13/2010E***JOB CONTINUED FROM 12-MARCH-2010***(ELINE -ADPERF) , LRS PUMPED 20 BBLS METH/DIESEL, PERFORATE INTERVAL 9074'-9134' WITH 2.50" HSD POWERJET 2506, 6 SPF, 60 DEG PHASING, DEPTH REFERENCED TO SLB CBL DATED 14-FEB-2006. FINAL T/I/O = 1100/0/140 PSI ,MASTER=OPEN, WV, SV, SSV =CLOSED, IA/OA=OTG *** WELL LEFT SHUT IN, TURNED OVER TO DSO, JOB COMPLETE *** i ~~ FLUIDS PUMPED BBLS 12 Diesel 12 METH 24 Total MPC-28A 205-163 DCDC ATTA~`I-IMGNT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-28A 3/17/06 PER 9,034. 9,042. 6,948.73 6,956.29 MPC-28A 3/17/06 PER 9,174. 9,188. 7,084.7 7,098.54 MPC-28A 3/17/06 PER 9,196. 9,220. 7,106.46 7,130.24 MPC-28A 12/27/06 PER 9,188. 9,194. 7,098.54 7,104.48 MPC-28A 12/27/06 PER 9,220. 9,224. 7,130.24 7,134.21 MPC-28A 12/27/06 RPF 9,174. 9,188. 7,084.7 7,098.54 MPC-28A 12/27/06 RPF 9,200. 9,220. 7,110.42 7,130.24 MPC-28A 3/13/10 APF ~ 9,074. 9,104. 6,986.91 7,016.02 MPC-28A 3/13/10 APF ~ 9,104. 9,134. 7,016.02 7,045.33 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ Tree: 3 1/8" 5M Wellhead: FMC 11" x 11" 5M, Gen. 5 w/ 11" x 3.5" FMC Tbg. Hnr. w/ TCII threads top and bottom and 3" CIW H BPV rofile 20" 91.1 ppf, H-40 115' 9-5/8" float shoe @ 5,405` Sidetrack kickoff @ 5,470` 7" 26#/ft , L-80, BTC-M csg. (drift ID = 6.151 ", cap. 0.0383 bpf ) 3.5" 9.2#/ft , L-80 TCII Tbg. (drift ID = 2.992"cap .00870 bpf ) Note: Original Well Bore Info: CIBP set @ 5,529' RA marker at 8071' wlm 9-5/8" original float shoe @ 5,405` 7" Weatherford float collar 7" Weatherford float shoe Perforation Summary Ref log: Size SPF Interval (ND) 2 6 9034-9042 6948-6956 2.5 6 9074-9134 6987-7045 2 6 9174-9188 7084-7098 2 6 9196-9220 7106-7130 Or'l~DF Elev. = 46.5' (N 22E) Orig. GL Elev. = 16.8' RKB = 43.18' Doyon-14 3.5" HES X-Nipple 2.813" 3.5" HES X-Nipple 2.813" 7"x 3.5" Baker S-3 Pkr 2,495` 8,457` .. 8,510` 3.5" HES XN-Nipple 2.750" No Go 8,569" 7" x 3.5" Baker Liner Tie Back Slv. 8,608` "C2" ZXP Liner Top Packer 8,620` Baker Flex Lock Liner Hng. 8,626` 3.5" Baker Landing Collar 9,364` MPU C - 28ai • Mr. C. Ryan Rupert Production Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 ass-~~3 Re: Milne Point Field, Kuparuk River Pool, MPC-28A Sundry Number: 310-046 {;? 1,. 7131 V Dear Mr. Rupert: ~: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Commissioner d r DATED this day of February, 2010 Encl. `q,~o r ~ ~ ~ STATE OF ALASKA ~/, ~J ~ ALAS~IL AND GAS CONSERVATION COMMISSI~ /~~ APPLICATION FOR SUNDRY APPROVALS ~n nnr. ~~ ~Rn ~~c~rvEa ~~s ~ s zoo 1. Type of Request: Abandon^ Plug for Redrill ^ Perforate New Pool^ Repair Well^ ~S ~ I Suspend^ Plug Perforations ^ PertorateQ ~ Pull Tubing^ AIICIIQri~~xtension^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other: ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. - Development ^ Exploratory ^ 205-1630 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-22648-01-00• 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^~ ^ MPC-28A , No Spacing Exception Required? Yes 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-047434 MILNE POINT Field / KUPARUK RIVER Pool > 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9430 7339.39 9396 7305.5 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 112 20" 91.1# H-40 32 112 32 112 1490 470 Surface 5405 9-5/8" 40# L-80 31 5405 31 7642 5750 3090 Intermediate Production 8768 7" 26# L-80 33 8768 33 6709 7240 5410 Liner 821 3-1/2" 9.3# L-80 8609 9430 6579 7339 10160 10550 Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3-1/2" 9.2# L-80 SURFACE 8614 Packers and SSSV Tvoe: 7"x3-1/2" s-3 okr Packers and SSSV MD and TVD (ft): 8510 6499 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: • Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: ~ Commencing Operations: 2/26/2010 Oil ^ Gas ^ Plugged ^ WDSPL ^ / L~9 16. Verbal Approval: Date: WINJ GINJ ^ WAG [~ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact C. Ryan Rupert Printed Name C. Ryan Rupert Title production Engineer Signature Phone Date .~~~'" 564-5557 2/12/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY J ~ ~/~ witness Sundry Number: ~/( t ti a th t i i ve m y a represen a ss on so a Conditions of approval: Notify Comm , Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: r Q • ~~ '[ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z Z /d ~DMS FEB 2 5 Z0~ Form 10-403 Revised 12/2009 )RIGINAL ~ z"~~ Submit in~~G~ MPC-28A 205-163 DFDG ATTA~_NMFNT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPC-28A 3/17/06 PER 9,034. 9,042. 6,948.73 6,956.29 MPC-28A 3/17/06 PER 9,174. 9,188. 7,084.7 7,098.54 MPC-28A 3117/06 PER 9,196. 9,220. 7,106.46 7,130.24 MPC-28A 12/27/06 PER 9,188. 9,194. 7,098.54 7,104.48 MPC-28A 12/27/06 PER 9,220. 9,224. 7,130.24 7,134.21 MPC-28A 12/27/06 RPF 9,174. 9,188. 7,084.7 7,098.54 MPC-28A 12/27/06 RPF 9,200. 9,220. 7,110.42 7,130.24 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE u n U To: Mark O' Malley/Nathan Leonard Date: February 5th, 2010 MPU Wells Ops Coordinator From: C. Ryan Rupert MPC Pad Engineer Subject: MPC-28A ADD PERF AFE: MKCPDWL28 Cost: $50,000 IOR: 75 1 S Ta TD, Drift with 2-1/2" dumm un, SBHP 2 E Perforate 9074' - 9104' and 9104' - 9134' MD 1 Well Detail Current Status: Operable Online WAG Injector Max Inclination: 61 ° at 6219' MD, ~8-19° through perfing interval Max Dog Leg: 13.9 at 9080' MD (see attached directional survey) Minimum ID: 2.750" ~ 8569" MD (XN-Nipple) Last TD tag: 9182' MD on 4/29/08 Latest H2S value: None taken. Highest in block = 1o ppm in Jan 2005 BHP: 2493 Psi on o8/30/0~ (~~ days SI) converted to ~ooo' SS Obiective The objective of this job is to add perfs to the MPC-28A. The well is currently perfd in all other sands. The B-silts are unperf d, and likely still have formation damage from ` ,% drilling. Well History This well was originally drilled as an A2 + A3 + B +C sand injector in 1996. the well was found to not support much, and was sidetracked to another location in the same block in 2006. The sidetracked wellbore was perf'd in the A3, A2, and C sands but NO_T the B- .~ silts. Since then the injector has been relocated, it's offset producer has seen the pressure response, and seen it's oil rate go from 30o bopd to boo-goo bopd. This injector is currently the best Kuparuk injector at Milne Point. .~ Recent PL's from the producer show ~25% of the hydrocarbons coming out of it's perfd B-silts. These B-silts are currently unsupported, and thus this add perf is proposed. • Critical Issues U The TD tag on 4/29/08 was at 9192 SLMD, indicating that the bottom set of perfs were covered, however, the tag was SLM, and not converted to MD. The pre-perf dummy gun run should indicate fill depth. If unable to entire interval, please abort perfing operations. Tie in all perforating to the Schlumberger CBL (Primary Depth Control) run on 2/i4/2oo6. The well injected gas from 6/io/o9 to ~/21/1o and has been on water injection since. The well is not scheduled to go back to gas injection until late 2010. Slickline 1. SI Well. MIRU SL. 2. RIH with gauge ring and tag XN-profile at 8569' MD (2.725 no-go ID). Use this depth to make subsequent depth correction. Tag TD. POOH. 3. Drift and Tag TD w/ 2-1/2" dummy perf gun. Bottom proposed ADPERF is 9134' MD. IF SL tag is 9134' MD or higher, please postpone a-line job. Obtain sample if obstruction/fill encountered, and note tag type (soft, sticky, etc...) 4.Obtain SBHP per attached program 5. RDMO SL. E-Line ADPERF (60') 1. MIRU EL. 2. Add 60' of perfs per the attached perforating procedure with 2-1/2" HSD Power Jet 2506 HMX (6 SPF, 60 deg phasing). (Please abort job if unable to perf entire interval') Proposed Add Perfs • 9074' - 9104' M D • 9104' - 9134' MD Reference Log: Schlumberger CBL (Primary Depth Control) run on 2/14/2006 3. RDMO E-Line and return to injection service at 2500 BWPD Please contact Ryan Rupert 564-5557 (w); 301-1736 (c) with any questions, comments, or concerns. 2of4 Reference Loq: SLB CBL Run 2/14/06 Existing perfs 9034' - 9042' MD °'"" - ~ ~-~ ; -=-= _l Proposed perfs 9074' - 9104' & t ~~ --~_~ ~ ~ 9104'-9134'MD SAN ~ ~ - - - - (60 total feet) ' ~- Existing perfs ~ _ - ~ -- 9174'- 9188' MD Existing perfs 9196' - 9220 MD i McY~rw~MAl tnpiAt~ trr. wegrn~e~ wa~ a~rpi. pP~ dnrwa R~ t (OW ~ ! I"~ pis o ~ tO0`Q - - - ~~ - - ,-~ von vrw~MOwrs~ry P7x- f :. xn n,a, i~co, ~^. Cd 10 TYVrr T1~ ITT1 iMial~aua MAD Aee0tlY~t 290 1w~ ~ ~ - - - L - - 104 G YeiMa~ YAP T-swsR Tbrrr Awcq. YAP Amptu09 .. ~ a _ ~~N._ +~~ 100 . ~~.~ ..... Yli~ ~ - 1M~1 100 01Mw1 T ~ IdH11 ` ~ 0.. ~. ~ ~I..10 X11 -~ CN. AANYd~ 1Ca1 O W00 0 YrUI t W _., --- i Mmwuw YAP TrAw~R TMM -~~ ' 100 (tR) 3 of 4 • Tree" 3 1/8" 5M Weehead- FMC 11' x 1 f" SAA, Gen. 5 wi 11' x 3S' FMC Tbg. Hnr. w/ TCII threads top and bottam_arxf 3" CtW H BPV le 20" 91.1 ppf, H~{I 11 S KOP ~ 600' Max. hole angle = 38 to 60 deg. fir 2700' -8800' Hole arxpe thru' perfs = 27 deg. 9-518" float shoe ~ 5,405 Sidetrack kickoff ~ 5,470' 7" 26#/ft , L~0, BTC-M csg_ (drift ID = 6.151 ", cap. 0.0383 hpf ) 3.5' 9.2lf//ft , L~0 TCII Tbg. (drift ID = 2.992' cap .00870 bpf ) Nate- fJriainal WeLI Bore Info: CIBP set (~ 5,529' RA marker at 8071' wlm 9-5/8" original that shoe ~ 5,405' 7' Weatherford that collar 7' Weatherford float shoe 8,7E Perforation Summary Ref loa- SPF Illf®1N1 Crvol z a aai4~oaz flare-ease 2 8 8174-9188 70e4-7088 8t9e-922D 7t08-7t39 Orig. DF Efev. = 46.5' (N 22E) Orig. GL Elev. = 16.8' RKB = 43.18' floycxl-14 3.5' HES X-NKip~ 2.813' 2,495` HES X-Nipple 2.813' 8,457` 3.5" Baker S-3 Pkr. 8,510` HES Xhi-Nipple 2.750° No Go 8,5f39" K a.~- eaicer Liner rye t3~k slv. 8.608` C IxP L>ner Top Packer 8,620` rker Flex tack Lines Hr>a 8,fi2fi' ;ef Laftdktg Golf 9,364, HES float solar 9,396 HES float shoe 9=4~i ~ 01/08/06 ~ MDO ~ Sidetrack Cafnpletion t7c~on -14 ~ MILNE P41NT UNIT WELL MPU G - 28ai API N©: 50-029-22648-00-00 4of4 MPU C - 28ai IIDIU Well: MPC-28A-i ............................ Date: 02-08-2010 CC or AFC: MKCPDWL28 ................................................ Description: Add Perf ................................................ • i PERFORATING PROCEDURE Vaf006/~~01 API #: 50-029-22648-00 ................................................. Prod Engr C. Ryan Rupert Office Ph: 564.5557 H2S Level: ................................................. ........................................................ ................pp......................................... Home Ph: 10 m form offset ........................................................ Cell: 301.1736 ........................................................ Detail Code: ......................................................................................................................... ..................................................................................................................... WBL Entries 1 S D&T, drift to rf de th with 2-1/2" Dumm Gun, obtain SBHP 2 E Perforate 9074' - 9104' and 9104' - 9134' MD Well Objectives and Loggina Notes: For the a detailed well history, please see MPC-28A-i ADPERF program currently on the WBL. The objective of the slickline portion of this procedure is to evaluate the extent of any restriction that might exist and ensure the guns can make it to target depths. Additionally the current TD of the well is desired. rrererence uog ~ fe m iLOg rrsrrsrr reer Log: CBL ............................. CBL .............................. #REF! tie-in log to be on Date: 2/14/2006 ............................. 2/14/2006 .............................. depth with the reference log. Company: SLB SLB Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone Ad/Reflperf 9,074' - 9,104' 9,074' 9,104' 30' 6 Random 60° 0 KUP B Add 9,104' 9,134' 9,104' 9,134' 30' 6 Random ..:........................... -.............................I~........................... -............................ ................. .................... .......................... .................. ................ Gas Jetting Expected? No At what Depth? N/A Requested Gun Size: 2.5" HSD Charge: Power Jet 2506, HMX Desired Penetration: 14.5" Entry Hole Diam: 0.34" Is Drawdown Necessary/Desired/Unnecessary During Perforating .Unnecessary :.Do, not flow well.durin~ perforating Describe below how to achieve drawdown (check wl Pad Operator to see if necessary piping is installed) (e.g. N2 Lift, Hardline Lift Gas, Gas Lift, Flow Well, Backflow Through Drain or Hardline) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Tie in to Jewelry C~ , n/a MD Tie in using: .Schlumber~er.CBL,Lo~ run,on 2/14/06 .............................................................................................. Minimum ID: .2:75 in Min ID Type: .2:75. no;go,on, XN. Nipple @ 8,569 'MD ..................... Tail Depth: >8569 ft MD Casing Size: ........3.5......... in 9.2# L-80 Est Res. Pres. ~ 9,100 MD 7000' SS 3,000 psi Last Tag: 91.92 SSLMD~ft ELMD on .4/29/2008...., ................ Well: MPC-28A-i Perforation Summary Date: API #: 50-029-22648-00 On-Site Prod Engr: General Comments: Depths Balance Referenced to BHCS O/B/U - O/B/U ...........................".............................. O/B/U - O/B/U - ............................................................. O/B/U - Feet SPF Orient. Phasing PBTD Zone Aperf/Reperf ~O ..................................................._..._........................... ~O ..................................................................................... STATIC BOTTOM-HOLE PRESSURE SURVEY Well: . . . . . . . . . . . . . . . . . MPC-28A . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Date: . . . . . . . . . . . . . . . . . 2.8-10 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Cost Est: . . . . . . . . . . . . . . . . . $5,000 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . CC or AFE: . . . . . . . . . . . . . . . . . MKCPDWL28 . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . API #: 50-029-22648-00 Prod Engr ............................_C. Rxan_Rupert........................ WBL Entries Ver1.4, Rev 08/12/2004 (JDM) Office Ph: 564-5557 H2S,Level: Home Ph: None 10 m form offset CelUPager: 301-1736 See pert program for specifics Datum: 7000' SS ..................................... Well Data Procedure: Last Tag: 9192 (SLMD' .......................: Tag date: 4/29/2008 1. Make 10 min pressure stop in lubricator Max Deviation 61 Deis Depth: 6219' MD 2. Drop below the first pressure-stop requested. Pull-up to specified depth. 3. For each requested stop: Min. SI Time: n/a Lo Bing Data E/L: Measure pressure until it varies less than 1 psi in 20 min. Zone: A2+A3+C S/L: Hold guages at depth for time specified 4. E/L: Test tool in lubricator at 3000 psi with calibrated test gauge Requested Stops: MD SS Time S/L: Hold gauges in lubricator for 10 min stop. Compare to test guage First 8700' -6653' 15 min Second 9139' -7000' 60 min 5. Leave well shut in if SBHP is less than na Third Summa Dist Well: MPC-28A API #: 50-029-22648-00 PE Town: Date: Anch Prod Engr Service Co. New Tag: 'MD P.D. Center Upper Lower Date Time MD SS Gauge Gauge Zone Temperature Test Gauge Pre-Job Lubricator Pressure Type of Pressure Tool SITP (Tubing): Zone: Comments: ............................ ut In Date: and Time: lal Shut In Time Well Objectives. Loaaina Notes. and Saecial Instructions: ! ~ DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2051630 Well Name/No. MILNE PT UNIT KR C-28A MD 9430 TVD 7339 Completion Date 3/16/2006 REQUIRED INFORMATION Mud Log IVo Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22648-01-00 Completion Status 1WINJ Current Status 1WINJ UIC Y Samples No Directional Survey Ye ~-~'~ DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, IFR/CASANDRA, CBL, CCL (data taken from Logs Port ion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 9430 Open fo§ Cement Evaluation 5 Blu 1 8400 9348 Case Cement bond Log GR CCL i~ rog Injection Profile 5 Blu 1 9000 9236 Case 2/20/2007 Mem Injection Profile, GR, I CCL, STP 20-Jan-2007 _/ I',`ED C Las 1523 njection Profile 8446 9233 Case 6/20/2007 Injection profile, Spin, GR, CCL, Press w/Graphics I PDF and TIF ~~, // ~ ~~ !QED C Lis 15306//mdu 'on/Resistivity 4965 9430 Open 8/3/2007 LIS Veri, GR, ROP, FET w/Graphics ~F pt 15306 IS Verification 4965 9430 Case 8/3/2007 LIS Veri, GR, ROP, FET !wog Induction/Resistivity 25 Col 5406 9430 Open 2/29/2008 MD ROP, DGR, EWR-4 6- i ~ Jan-2006 t,L6g Induction/Resistivity 25 Col 5406 9430 Open 2/29/2008 TVD ROP, DGR, EWR-4 6- d Jan-2006 C 15960 r uction/Resistivity 0 0 Open 2/29/2008 Graphics EWR in EMD, i CGM and PDF J Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/20/2008 Permit to Drill 2051630 Well Name/No. MILNE PT UNIT KR C-28A Operator BP EXPLORATION (ALASKA) INC MD 9430 TVD 7339 Completion Date 3/16/2006 Completion Status 1WINJ Current Status 1WINJ ADDITIONAL INFORMATION Well Cored? Y N~ Daily History Received? N Chips Received? _y.-LAIC Formation Tops ~/ N Analysis -'fTl~- Received? Comments: Compliance Reviewed By: _ _ ___ API No. 50-029-22648-01-00 UIC Y Date: -~~~ WELL LOG TRANSMITTAL To: State of Alaska February 21, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPC-28A AK-MW-4108384 MPC-28A: 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Logs 50-029-22648-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Logs 50-029-22648-0 l Digital Log Images: 1 CD Rom 50-029-22648-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 995L8,: ~, Date: j ~ e ~ + ~, BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: . $ Xgg ~` -~ .~, ~~ ~' 1'~.~ ~'T C cl ~ ~ {o ~ ~ (~pl ~1; 3: - ~ ~~ WELL LOG TRANSMITTAL To: State of Alaska July 31, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: MPC-28A, AK-MW-4108384 I LDWG formatted CD rom with verification listing. API#: 50-029-22648-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ~:v'~ ~; ~ 7JQ~ ;~i~C v„v:~~ BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: vac aos -,~03 ~ ~ao~ ELL L ~~ ~i~,4/U~1/T7~4L ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 RE : Cased Hole/Open Hole/ Mechanical Logs and /or Tubing Inspection(Caliper / MTTJ The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of ProActive Diagnostic Services, lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (9D7) 245-8951 1 J Injection Profile EDE Disk MPU G28Ai 09-Jun-07 2J 3J 4J sJ 7J Signed : Date Print Name: <~;~~;,~,~ .~t~~~ - - -- ~ ~~ , ,. n ~;i~- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-MAIL: '~~ ~?Y4_ ,,' WEBSITE: ~'„ C:`-.Documznts anal Settings\PDS Anchorage - MPC.Dzsktop~Transmit Origirtaldoc 02/12/2007 ~tis~~~r111~6~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well .Inh ~! 1 .... n.. ..~:.. NO. 4131 Company: State of Alaska Alaska Oii & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay n_a_ LS-25 11538589 LDL 12/28/06 1~ Y-16 11626467 LDL 01/19/07 L-04 11603118 MEM LDL 12/30/06 1 11-24A 11638611 USIT 01/24/07 1 1-33 11631645 USIT 01/09/07 1 A-05A 17533393 USIT 01/04/07 1 DS 05-108 11626469 SCMT 01/22/07 1 W-29 11536193 USIT 01/05/07 1 R-15A 11626266 USIT (CEMENT EVALUATION) 01/11/07 1 R-15A 11626266 USIT (CORROSION) 01111/07 1 MPF-99 11637306 CEMENT EVALUATION/CBL 01/14/07 1 R-12 11414757 RST 09101/06 1 1 NK-38A 40011271 OH EDIT MWD/LWD 03/11/05 3 1 NK-38A P61 40011271 OH EDIT MWD/LWD 02/26/05 2 1 MPC-28A 11649937 MEM INJECTION PROFILE 01/05/07 1 DS 07-04A 11533394 LDL 01/05/07 1 F-23A 11626066 LDL 01!08/07 1 P2-19 11630449 LDL 01/14/07 1 Y-09A 11630450 LDL 01/16/07 1 DI CACC Al~I!\IA\AII cnnc o . ______.._._._________.-__ .... ... ..................... ...-. v.~~....v vnc vvrl crlvn Iv. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Cons ~ " 2525 Gambell Street, i ~, ~° ~__., ~ ~,,.,., Anchorage, AK 99503-2838 ATTN: Beth g Gq, nn 7 f'~ ! ® ~tftJf Received by: ~9R~t~ ~sl n~. ~~ai~~l~ti~~i~~.. J 19 STATE OF ALASKA ALASK~IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG .x ' 5~ 3 ~~ ~„ ~,f3i';fittSSIOA 1 a. Well Status: D Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoaACZS.,os zoAACZS.,,o ^ GINJ ®WINJ ^ WDSPL No. of Completions One Other 1 b. Well Class: ~' ,. ^ Development D Exploratory D Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 03/16/2006 ~ 12. Permit to Drill Number 205-163 " 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 12/29/2005 13. API Number 50-029-22648-01-00 • 4a. Location of Well (Governmental Section): Surface: ' ' ~ 7. Date T.D. Reached 1/4/2006 14. Well Name and Number: MPC-28A 837 FSL, 2341 FEL, SEC. 10, T13N, R10E, UM Top of Productive Horizon: 4586' FSL, 259' FEL, SEC. 09, T13N, R10E, UM g• KB Elevation (ft): 50.20 15. Field /Pool(s): Milne Point Unit / Kuparuk River, Sands Total Depth: 4631' FSL, 232' FEL, SEC. 09, T13N, R10E, UM 9. Plug Back Depth (MD+TVD) 9396 + 7306 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558121 ' y- 6029119 ' Zone- ASP4 10. Total Depth (MD+TVD) 9430 + 7339 Ft 16. Property Designation: ADL 047434 ' TPI: x- 554888 y- 603 Zone- ASP4 Total Depth: x- 554915 - Y- 6032888 • Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1800' (Approx.) 21. Logs Run: --t-"~w.d~y MWD, GR, RES, IFR/CASANDRA, CBL, CCL S`~t~z ~~~' ~G S~Z-~ ~tA ~ zG•o 2 ASING, INER AND EMENTING ECORD CASING ETTING EPFH MDr ETTINCa EPTH TVD HOLE MOUNT SIZE WT. PER FT. GRADE OP OTTOM OP OTTOM SIZE CEMENTING RECORD PULLED 20" 91.1# H-40 32' 112' 32' 112' 24" 250 sx Arctic Set I (A rox. 9-5/8" 40# L 80 31' 5405' 31' 4642' 12-1 /4" 1200 sx PF 'E', 250 sx Class 'G' 7" 26# L-80 33' 8768' 33' 6709' 8-1/2" 174 sx Class 'G' 3-1/2" 9.3# L-80 8609' 9430' 6579' 7339' 6-1/8" 157 sx Class 'G' 23. Perforations open•to Production (MD +TVD of Top and " " 24: TUBING RECORD Bottom Interval, Slze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 SPF 3-1/2", 9.2#, L-80 8614' 8510' MD TVD MD TVD 9034' - 9042' 6949' - 6956' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9174' - 9188' 7085' - 7099' 9196' - 9220' 7106' - 7130' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 160 Bbls Treated Sea Water and 90 Bbls of Diesel 26. PRODUCTION TEST Date First Production: March 20, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OtL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. 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". None ~~~~~ ~~.. SAY 0 ~ 2~~~ '- ~~/` . O~ > ~ 4~ Form 10-407 Revised 12/2003 ~ ~ ~ ~ ~ ~~I~ED ON REVERSE SIDE I~-~I~~' ~1~ ~'Zf ~d~ 28. GEOLOGIC MARKE 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". THRZ 8580' 6556' None BHRZ 8700' 6653' KLGM 8725' 6674' KC1 9036' 6951' KUB 9045' 6959' KUA 9170' 7081' KA3 9176' 7087 KA2 9203' 7113' KA1 9242' 7152' MLV 9279' 7189' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Leak-Off Test Summary and a 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ Signed Titl h i l A i t D t T t '~/ -~ n an e e ec ca ss s a ~.G~ Sondra tewman ~_ MPC-28A 205-163 Prepared ey Name/Number: Sondra Stewman, 564-4750 Well Number Permit NO. /Approval NO. Drilling Engineer: Skip Coyner, 564-4395 INSTRUCTIONS GeNeRnL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Irene 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. IreM 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). IreM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Operations Summary Report Legal Well Name: MPC-28A Common Well Name: MPC-28A Event Name: DRILL+COMPLETE Start: 12/18/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date I From - To ,Hours I' Task I Code NPT Phase 12/19/2005 19:00 - 00:00 5.00 MOB P PRE 12/20/2005 00:00 - 06:00 6.00 MOB P PRE 06:00 - 08:00 2.00 MOB P PRE 08:00 - 09:00 1.00 MOB P PRE 09:00 - 11:00 I 2.001 RIGU ! P I I PRE 11:00 - 12:00 1.00 RIGU i P PRE 12:00 - 13:30 1.50 RIGU P PRE 13:30 - 16:30 3.00 RIGU P PRE 16:30 - 17:30 1.00 RIGU ' P PRE 17:30 - 18:30 1.00 RIGU P PRE 18:30 - 21:30 3.00 RIGU P PRE 21:30 - 23:00 1.50 RIGU P PRE 23:00 - 00:00 1.00 RIGU P PRE 12/21/2005 00:00 - 07:30 7.50 EVAL j N OTHCMP 07:30 - 08:00 0.50 EVAL P OTHCMP 08:00 - 09:00 1.00 EVAL P OTHCMP 09:00 - 10:30 I 1.501 STCTPL I P I I OTHCMP 10:30 - 18:00 I 7.501 STCTPL I P I I OTHCMP 18:00 - 18:30 0.50 EVAL P ~ OTHCMP 18:30 - 00:00 5.50 EVAL P i OTHCMP 12/22/2005 ~ 00:00 - 01:00 1.00 ~ EVAL ~ P ~ OTHCMP 01:00 - 01:30 ~ 0.50 STCTPL P OTHCMP 01:30 - 02:00 ~ 0.50 STCTPL P OTHCMP Page 1 of 9 Spud Date: 12/18/2005 End: Description of Operations Skid rig floor, Move off MPH-15, on to road Move rig to MPC-28A Spot rig over well -Shim same Skid rig floor from move position to move position-Spot rock washer Rig up floor -Top drive -Steam ,water, air -Berm rock washer Rig up lines to tiger tank and tree (Accept rig @ 11:00 hrs) RU lubricator -Pull BPV - RU to bleed to tank Displace freeze protection from well -Pump 50 bbls hot seawater - 34 bbls soap pill - 300 bbls of seawater -Spot 100 bbls 13.9 ppg LSND mud @ 7856' (tubing cut) -Chase with 40 bbls seawater - 215 gpm - @ 2130 psi Install TWC -Test to 3000 psi - RD circ lines ND Tree NU stack -Flow line -Mouse hole MU test joint - RU to test BOP's Test BOP's -Test rig alarms -Good test on alarms -Test Annular 250 low 2500 high 5 mins each test Attempt to test BOP's - No test loss 200 psi on Annular -Top Rams -Blind rams -Attempt to test Choke manifold - No test - Warming up manifold - Regreasing all valves - (while waiting on Lubricator from 4ES) -Change out XO's on lubricator - make up lubricator to hanger - PuII TWC -inspect TWC - Plugged with mud and debris -Change out TWC -Install same - Attempt to pressure up on TWC -Same results -Unable to get test - (Called AOGCC Chuck Scheve -Discussed body and casing test to 3500 pull tubing and retest BOPS when tubing layed down) RD lubricator - RU to test with blind rams closed Test casing to 3500 psi for 15 mins -Test good -Test recorded on chart MU landing joint 3 1/2" NSCT -Pull hanger to rig floor - 105K PUW - LD Hanger Stand back 5 stands in derrick - LD 233 Joints plus 16.34' of 3 1/2" NSCT 9.3# tubing Install test plug - RU to test BOP's -Open annulus valves Test BOP's -Annular 250 low 2500 high 5 mins each test -Top rams -Choke manifold -Flange on # 12 valve leaking -Tighten up flange -Retest -test good -Manual Choke /Kill valves - HCR Choke /Kill valves -Choke HCR failed high test - Greased valve -Retest -Test good -Upper /Lower IBOP valves -Floor safety valves -Blind rams - 250 low 4500 high 5 mins each test -Preformed Accumulator test -All equipment tested successful - WSL witnessed all test -John Crisp with AOGCC wavied witness of BOP test - RD testing equipment - Close annulus valves -Pull test plug -install wear ring RD testing equipment -Close annulus valves - PuII test plug - install wear ring -Blow down choke manifold -Choke line -Kill line Moblize BHA to rig floor MU bit - casging scraper -Bit Sub - XO - PU 1 stand of 4" DP trom pipe shed Printed: 179/2006 9:41:41 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: MPC-28A .MPC-28A DRILL+COMPLETE DOYON DRILLING INC DOYON 14 Date ,From - To Hours Task I Code it NPT 12/22/2005 02:00 - 03:00 1.00 STCTPL P 03:00 - 07:30 4.50 STCTPL P 07:30 - 09:00 09:00 - 11:00 11:00 - 12:00 12:00 - 15:30 15:30 - 16:30 16:30 - 18:00 18:00 - 00:00 12/23/2005 00:00 - 02:00 02:00 - 06:30 06:30 - 11:30 11:30 - 13:00 13:00 - 14:30 14:30 - 15:00 15:00 - 16:00 16:00 - 16:30 16:30 - 18:00 18:00 - 18:30 18:30 - 19:30 19:30 - 20:00 20:00 - 21:00 12/24/2005 21:00 - 21:30 21:30 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 04:00 04:00 - 04:30 1.50 STCTPL P 2.00 STCTPL P 1.00 STCTPL P 3.50 STCTPL P 1.00 STCTPL P 1.50 STCTPL P 6.00 STCTPL P 2.00 STCTPL P 4.50 STCTPL N WAIT 5.00 STCTPL P 1.50 STCTPL P 1.50 STCTPL P 0.50 STCTPL P 1.00 STCTPL P 0.50 STCTPL P 1.50 STCTPL P Page 2 of 9 Spud Date: 12/18/2005 Start: 12/18/2005 End: Rig Release: 1 /8/2006 Rig Number: Phase ' Description of Operations OTHCMP Cut drlg line -Service top drive OTHCMP Con't PU 4" DP from pipe shed 1 x 1 to 5700' - LD a single - Pull 1 stand to 5563' OTHCMP Pump 25 bbl Hi-vis sweep - @ 400 GPM - PP 1420 psi -Pump 2nd Hi-vis sweep -GPM 415 - PP 1425 -Pump dry job OTHCMP Blow down top drive - POH - LD XO's -Casg scraper -Bit OTHCMP Change bails - PU 350 ton elevators OTHCMP PJSM - RU Schlumberger -RIH with Howco 7 "CIBP - CCI - Set Bridge plug @ 5529' - POH OTHCMP RU testing equipment -Test CIBP 2500 psi for 30 mins - Record on chart -Test good OTHCMP Pull 7" Pack-off - MU Landing joint -Establish stretch points - 50K pull 7.5" stretch indicates 2830' free - 100K pull 18.5" stretch indicates 3491' free OTHCMP RU wire line -RIH with 7" free point tool -Take free point readings - 5494' - 0% free - 4494 33% free - 3494 72% free - 3300 92% free - 3170 95% free - 2900 100% free - 50K pull - Attempt to free point with 100K pull -Free point tool quit working - POH OTHCMP POH with Free point tool -Inspect free point tool -Tool functioning properly -Possible over heated motor -Change out free point tool OTHCMP Crew over 16 hrs -Waiting on crew from Schlumberger yard to continue free point operation OTHCMP Run free point tool - 100K over pull - 5485 / 0% free - 5000' / 0% free - 4485 / 53 to 69 - 64% free - 4760 / 0% - 4640 / 35 to 32% - 4000 / 68 to 78% - 3485 / 80 to 86% - 3300 / 88% - 200K over 4760 / 7% free - 4640 / 57% free - 4485 / 74% free - 4000 / 58 to 61 % - 3485 / 80% to 82% free OTHCMP LD landing joint -Install pack-off -Test same OTHCMP PJSM -Install test plug -Change top rams to 7" OTHCMP Test door seals to 1500 psi -Test good OTHCMP LD 350 ton casg elevators -Change out long bails OTHCMP MU BHA -Casg cutter assy OTHCMP RIH to 4708' -Locate collar @ 4783 0.50 STCTPL P OTHCMP Cut 7" casg @ 4793' -GPM 150 - PP 550 -RPM 70 - TO 2K 1.00 STCTPL P OTHCMP Circ through cut casg taking returns out outer annulus to bleed tank -Pump 210 bbls 8.3 ppg seawater 5 BPM @ 1200 psi 0.50 STCTPL P OTHCMP Pressure up on 9 5/8" to 2380 psi -Pumped 3.8 bbls -Held 5 mins - No pressure drop -Bleed off pressure 1.00 STCTPL P OTHCMP Circulate unbalanced mud -Circulate to level out -GPM 300 - PP 1980 0.50 STCTPL P OTHCMP RIH -Locate collar @ 5381' 1.00 STCTPL P OTHCMP Cut 7" casg @ 5392' -RPM 70 - TO 2K -GPM 200 - PP 600 - 0.50 STCTPL P OTHCMP Pull 4 stands to 4890' -Locate collar @ 4983' 0.50 STCTPL P OTHCMP Cut 7" Casg @ 4993' -RPM 70 - TO 2K -GPM 200 - PP 550 0.50 STCTPL P OTHCMP CBU 1 X -GPM 380 - PP 2070 -Flow check well 2.00 STCTPL P OTHCMP POH with Baker cutting assy 0.50 STCTPL P OTHCMP LD Baker cutting assy 1.50 STCTPL P OTHCMP Pull wear ring -Pack-off 0.50 STCTPL P i OTHCMP Make up 7" casg spear -Engage spear -Pull casg hanger to floor - PUW 175 - 160 Printed: 1/9!2006 9:41:41 AM BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Well Name: MPC-28 A Common W ell Name: MPC-28 A Spud Date: 12/18/2005 Event Nam e: DRILL+C OMPLE TE Start : 12/18/2005 End: Contractor Name: DOYON DRILLIN G INC . Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task II Code NPT ', Phase II Description of Operations 12/24/2005 04:30 - 06:00 1.50 STCTPL P OTHCMP LD Spear - 2 joints 5" HWDP -Clear floor of fishing tools - 350 ton elevators - RU casg tools to LD 7" Casg 06:00 - 12:00 6.00 STCTPL P OTHCMP RU Casg equipment - LD 119 joints + 10.7 cut joint of 7" Casg 12:00 - 12:30 0.50 STCTPL P OTHCMP Clear rig floor 12:30 - 13:30 1.00 STCTPL P OTHCMP PU Test jt -Install test plug -Change 7" rams to 2 7/8' x 5' VBR rams 13:00 - 14:00 1.00 STCTPL P OTHCMP Test door seals to 1500 psi - LD test jt /test plug -Install wear ring 14:00 - 15:00 1.00 STCTPL P OTHCMP Moblize BHA to floor - C/O handling equipment 15:00 - 16:00 1.00 STCTPL P OTHCMP MU BHA -Spear -Jars -Bumper sub - 5" HWDP - 16:00 - 17:30 1.50 STCTPL P OTHCMP Wait on accelerator jar from Baker 17:30 - 19:00 1.50 STCTPL P OTHCMP Make up accelerator -RIH with spear to 4793' -PUW 128 - SO 108 19:00 - 19:30 0.50 STCTPL P OTHCMP Engage spear on casg -Jar 4 times 250k jar -Casing free 19:30 - 21:30 2.00 STCTPL P OTHCMP POH with 7 casg - 200' POH over 40K -Weight dropped to 5k over PU weight 21:30 - 23:30 2.00 STCTPL P OTHCMP Stand back HWDP - LD Jar - LD spear - LD top stub 29.20' + 4 jts 7" casg + 7.20 cut joint (total joint laid down 124 + 7.20') 23:30 - 00:00 0.50 STCTPL P OTHCMP PU Spear assy -Inspect grapples 12/25/2005 00:00 - 01:30 1.50 STCTPL P OTHCMP RIH with spear assy to 4990' 01:30 - 05:30 4.00 STCTPL P OTHCMP Engage fish with spear @ 4993' -Jar on casing -Release from fish 05:30 - 07:30 2.00 STCTPL P OTHCMP Blow down top drive - POH with spear assy 07:30 - 09:00 1.50 STCTPL P OTHCMP LD Spear assy - MU Cutting assy 09:00 - 10:30 1.50 STCTPL P OTHCMP RIH with cutting assy to 5392' confim cut 10:30 - 13:00 2.50 STCTPL P OTHCMP Pull up locate collar @ 5300' cut casg @ 5310' -Pull up locate collar 5140' cut casg @ 5150' -PUW 120 - SO 108 -RPM 70 to 80 -GPM 150 to 167 - PP 600 to 630 - TO 3K 13:00 - 14:00 1.00 STCTPL P OTHCMP POH with cutter assy 14:00 - 14:30 0.50 STCTPL P OTHCMP Repair iron roughneck hydralic hose 14:30 - 15:30 1.00 STCTPL P OTHCMP Con't POH with cutter assy 15:30 - 17:30 2.00 STCTPL P OTHCMP LD BHA cutter assy - MU Spear assy - C/O Jars -Grapple - Pack-off -Accelerator 17:30 - 19:00 1.50 STCTPL P OTHCMP PJSM -Cut drlg line -Rig service 19:00 - 20:30 1.50 STCTPL P OTHCMP RIH to 4993' -PUW 133 - SO 108 -Engage spear - PU to 150K -Drag fell off to 7K over string weight - (top of fish 5150') 20:30 - 22:00 1.50 STCTPL P OTHCMP POH with fish 22:00 - 23:30 1.50 STCTPL P OTHCMP LD accelerator -Stand back HWDP - LD spear - LD stub 28.67' + 3 jts of 7" casg - LD cut joint 9.95' - (Total 7" casg recovered 128 jts + 9.95') 23:30 - 00:00 0.50 STCTPL P OTHCMP Clear rig floor -Moblize BHA to rig floor 12/26/2005 00:00 - 00:30 0.50 STCTPL P OTHCMP Moblize BHA 00:30 - 02:00 1.50 STCTPL P OTHCMP MU BHA - PU 12 6 1/4" DC's 02:00 - 03:30 1.50 STCTPL P OTHCMP RIH to 5086' 03:30 - 04:00 0.50 STCTPL P OTHCMP Wash to 5150' -PUW 160 - SO 125 -Engage spear -Jar casg loose -Work casg up hole -Pulling 225 to 325 (60 to 165 over string weight) for 74' -Weight dropped to 6K over string weight to 165K - (top of fish 5310') 04:00 - 07:00 3.00 STCTPL P OTHCMP Blow down top drive -Flow check - POH with fish 07:00 - 08:00 1.00 STCTPL P OTHCMP Stand back BHA 08:00 - 08:30 0.50 STCTPL P OTHCMP LD 2 Cut joints 11' and 30.11' + 3 joints - (total recovered 122 ~ joints + 11') Printed: 1/9/2006 9:41:41 AM BP EXPLORATION Page 4 of 9 Operations Summary Report Legal Well Name: MPC-28A Common Well Name: MPC-28A Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 12/26/2005 08:30 - 09:30 1.00 STCTPL P 09:30 - 11:00 1.50 STCTPL P 11:00 - 12:00 1.00 STCTPL P 12:00 - 13:30 1.50 STCTPL P 13:30 - 16:00 2.50 STCTPL P 16:00 - 17:30 1.50 STCTPL P 17:30 - 18:00 0.50 STCTPL P 18:00 - 19:00 1.00 STCTPL P 19:00 - 20:30 1.50 STCTPL P 20:30 - 21:30 1.00 STCTPL P 21:30 - 00:00 I 2.501 STCTPL I P 12/27/2005 100:00 - 12:00 I 12.001 STCTPLI P 12:00 - 15:30 3.50 STCTPL P 15:30 - 22:00 6.50 STCTPL P 22:00 - 22:30 0.50 STCTPL P 22:30 - 00:00 1.50 STCTPL P 12/28/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 01:00 0.50 DRILL P 01:00 - 00:30 23.50 DRILL P 03:00 - 04:00 1.00 DRILL 04:00 - 04:30 0.50 DRILL P 04:30 - 05:00 0.50 CEMT P 05:00 - 06:00 1.00 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 08:30 1.50 DRILL P 08:30 - 09:30 1.00 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 13:00 3.00 ( DRILL P Spud Date: 12/18/2005 Start: 12/18/2005 End: Rig Release: 1/8/2006 Rig Number: Phase I' Description of Operations OTHCMP MU Spear Assy OTHCMP RIH to 5192' OTHCMP Wash down from 5192' to 5310' -Engage grapple -Jar fish loose -Over pull 100 to 150 for 50' -Over pull dropped to 3to 5K over normal string weight OTHCMP POH with fish OTHCMP Stand back HWDP - DC's - LD Accelerator -Spear - Casg stub 28.71' + 1 jt casg + 10.88 cut joint - (total 7" casg joints recovered 124 + 10.88') OTHCMP Clear rig floor - LD jars -Bumper sub -Service break spear OTHCMP Moblize Milling BHA to rig floor OTHCMP PJSM - MU Milling assy -Mill - DC's -Jars -HWDP OTHCMP RIH to @ 5390' OTHCMP Circ -Bleed in milling fluid -GPM 320 - PP 580 -RPM 50 - TO 4K OTHCMP Milling 7" casing from 5392' to 5402' -GPM 600 - PP 1260 - i RPM 80-T04K-PU140-S0115-ROT 125 OTHCMP Milling casg from 5402' to 5476' - WOM 6 to 8 -RPM 80 - TO 4 to 5.5K -GPM 600 - PP 1280 - PU 135 - SO 115 -ROT 120 OTHCMP Circulate -Clear metal out of hole OTHCMP POH to shoe -Flow check -Pump dry job - POH Drag 20 to 50 over -Pump /Back ream out 5 stands -Attempt to pull with out pump back ream -Pulled tight - Con't Pump back ream to 1819' -GPM 550 - PP 890 -RPM 100 - TO 2K - POH without pump or back reaming -Stand back HWD - LD DC's -Jars - Mill - (No metal ball on BHA) OTHCMP Clear rig floor -Pull wear ring OTHCMP MU stack washer -Flush stack -Function rams, Annular, - Flush stack -Flush choke line /kill line -Install wear ring INT1 RU tubing equipment INT1 Run 16 joints NSCT 3 1/2" tubing to set cement kick off plug INT1 Change 3 1/2" handling equipment to 4" -RIH with 4" DP to 5308' -Taking weight 5 to 10K INT1 Wash from 5296' to CIBP @ 5529 - PU to 5527' INT1 RU cementing lines -Beak circulation 6 BPM - PP 600 psi - INT1 Give to Dowell Close Annular -Pumping through choke Pump 5 bbls water Test lines to 3000 -Test good Pump 24.5 bbls water Pump 30.5 bbls 17 ppg cement -Yield 1.00 cuft/sx Pump 5 bbls water Rig displace with 46 bbls mud @ 5 bpm Last barrel of displacement choke plugged pressure increased to 1350 -Shut down pressure held -Bleed off pressure through fill line and kill line back through pumps -Open Annular INTi POH slowly to 4566' INT1 Pump 30 bbl nut plug sweep - 8.6 bpm @ 550 psi - Reciprocating string INT1 Continue POH to 3 1/2" tubing INT1 LD 3 1/2" tubing INT1 Rig down tubing equipment- clear floor INT1 j PU 108 jts. 4" DP from shed to 3600' Printed: 1/9/2006 9:41:41 AM BP EXPLORATION Operations Summary Report Page 5 of 9 Legal Well Name: MPC-28A Common Well Name: MPC-28A Spud Date: 12/18/2005 Event Name: DRILL+COMPLETE Start: 12/18/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date 'From - To Hours Task Code', NPT Phase Description of Operations 12/28/2005 13:00 - 14:30 1.50 DRILL P INT1 Pump sweep- Circ. surface to surface 3X- Flow check, dry job 14:30 - 16:00 1.50 DRILL P INT1 POH 16:00 - 16:30 0.50 DRILL P INT1 Pull wear ring- Flush BOPE & function same 16:30 - 17:30 1.00 BOPSU P INT1 PU test joint -Pull wear ring -Install test plug -Open annulus 1 17:30 - 21:00 3.50 1 BOPSU P INT1 valves - RU to test BOPE Test BOP's -Annular 250 low 2500 high - 5 mins each test - Pipe rams -Choke manifold - HCR Choke /Kill -Manual Choke ~`~~~ ~~ / Kill -Upper /Lower IBOP -Floor safety valves -Blind rams - 250low 4500 high - 5 mins each test -Perform accumulator test -All test were successful -All test were witnessed by WSL -John Crisp with AOGCC waived witness of BOP test 21:00 - 21:30 0.50 BOPSU P INT1 RD test equipment -Pull Test plug -Install wear ring -Close annulus valves - LD test joint -Blow down choke manifold /line - Kill line -Top drive 21:30 - 22:00 0.50 DRILL P INTi Moblize 8 1/2" short BHA to rig floor 22:00 - 00:00 2.00 DRILL P INT1 MU 8 1/2" BHA -Bit -Motor @ 1.5 degree - MWD-Orient - NM DC's -Surface test 12/29/2005 00:00 - 01:30 1.50 DRILL P INT1 MU BHA 01:30 - 02:30 1.00 DRILL P INT1 Cut drlg line -Top drive service 02:30 - 04:00 1.50 DRILL P INT1 RIH to 4850' 04:00 - 05:00 1.00 DRILL P INT1 Wash from 4850' to 5135' -Tag Cement @ 5135' - WO pump 8 to 10K 05:00 - 08:30 3.50 DRILL P INT1 Drilling cement from 5135 - 1 to 2K with pump 400 GPM - 5212 WO pump 15K -With pump 2 to 3K -Drilling firm cement f/ 5245' to 5506' 8 to 10K with pump 400 GPM - PP 1200 -RPM 38 08:30 - 10:30 2.00 DRILL P INT1 Time drill f/ 5406' to 5419' 10:30 - 12:00 1.50 DRILL P INT1 Displace well w/ 8.7 ppg LSND mud. 400 gpm 70 rpm 5k tq.- No metal observed w/ returns. 12:00 - 18:30 6.50 DRILL P INT1 Time drill f/ 5419' to 5470' - 18:30 - 19:30 1.00 DRILL P INT1 RU test equipment -FIT - MD 5405 - TVD 4611 - MW 8.6 - Surface pressure 940 = EMW 12.52 - RD test equipment - Blow down lines 19:30 - 00:00 4.50 DRILL P INT1 Directional drill from 5470 to 5708' - WOB 7 to 10 -RPM 60 - T07on-Goff-GPM545-PPon2300-off2160-PU 162- ~ SO 115 -ROT 135 12/30/2005 00:00 - 00:00 24.00 DRILL P INT1 Directional Drill from 5708' to 7275' - WOB 10 to 20 -RPM 80 - TOon6-off6-GPM550-PPon3760-off 3500-PU 150- SO 120 -ROT 137 12/31/2005 00:00 - 02:30 2.50 DRILL P INT1 Directional Drill from 7275' to 7431' - WOB 15 -RPM 80 - TO on 7 -off 6 -GPM 550 - PP on 3800 -off 3650 - PU 155 - SO 122 -ROT 136 02:30 - 04:00 1.50 DRILL P INT1 CBU 2.5 X -RPM 80 - TQ -GPM 550 - PP 3600 -Flow check - Well static 04:00 - 05:30 1.50 DRILL P INT1 Pump to shoe @ 5400' -Pump at drlg rate 05:30 - 06:30 1.00 DRILL P INT1 CBU 2 X -RPM 40 -GPM 540 - PP 2900 06:30 - 07:30 1.00 DRILL P INT1 RIH- Wash last stand to bottom. 07:30 - 00:00 16.50 DRILL P INT1 Directional drill f/ 7431' to 8390' - WOB 10 to 20 -RPM 80 - TO Ton-Goff-GPM510-PPon3900-off3680-PU 168-SO 130 -ROT 148 1/1/2006 00:00 - 12:30 12.50 DRILL P INT1 Directional Drill from 8390' to 8773' (8 1/2" TD)- PU 200k- SO 135k- ROT 155k- RPM 80- Tq 10k on 9k off- PP 3470 on 3200 off-500 gpm- WOB 5-20k. Printed: 1/9/2006 9:41:41 AM BP EXPLORATION Page 6 of 9 Operations Summary Report Legal Well Name: MPC-28A Common Well Name: MPC-28A Event Name: DRILL+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To I~ Hours Task i Code ', NPT 1/1/2006 12:30 - 14:30 2.00 CASE P 14:30 - 17:00 2.50 CASE P 17:00 - 18:30 1.50 CASE P 18:30 - 20:30 2.00 CASE P 20:30 - 00:00 I 3.501 CASE I P 1/2/2006 100:00 - 01:30 I 1.501 CASE I P 01:30 - 03:30 2.00 CASE P 03:30 - 05:30 2.00 CASE P 05:30 - 06:00 0.50 CASE P 06:00 - 06:30 0.50 CASE P 06:30 - 07:30 1.00 CASE P 07:30 - 08:00 0.50 CASE P 08:00 - 09:00 1.00 CASE P 09:00 - 15:30 6.50 CASE P 15:30 - 18:00 2.50 CASE P 18:00 - 22:00 4.00 CASE P 22:00 - 23:00 I 1.001 CASE I P 23:00 - 23:30 I 0.501 CASE I P 23:30 - 00:00 I 0.501 CASE I P 1/3/2006 00:00 - 01:30 1.50 CASE P 01:30 - 03:30 2.00 CEMT P 03:30 - 04:30 I 1.001 CASE I P 04:30 - 05:00 0.501 CASE P Spud Date: 12/18/2005 Start: 12/18/2005 End: Rig Release: 1/8/2006 Rig Number: Phase III Description of Operations INT1 CBU 2X - 480 gpm - 80 rpm - PP 3100 -Reciprocate DP INT1 Pump out from 8773' to 5400' (8 1/2".ghost reamer at shoe) at drilling rate. -GPM 480 - 2950 INT1 RIH to 8687' -Precautionary wash to btm @ 8773' INT1 CBU 3 X -GPM 560 - PP 3950 -RPM 80 - TO 8.5K -Flow check -Well static INTi Fiow check -Well static -Pump out to shoe from 8773 to 5400' - Pump at drlg rate -Tight 15 to 20 over string weight back ream from 5525 to 5490 -work through twice with out back reaming from 5490 to 5440 INT1 CBU 2 X -GPM 509 - PP 2670 -RPM 40 - TO 5 -Flow check - Well static -Pump dry job INT1 POH from 5389' to 718' INT1 LD BHA INT1 Clear rig floor INT1 Pull wear ring- Install test plug. INT1 PJSM- Change top rams to 7" INT1 Test door seals to 1500 psi. INT1 PJSM- Rig up to run 7" casing INT1 Run 7" 26# BTC-M casing to 9 5/8" @ 5380'. INT1 Circ. & condition mud INT1 Continue run 7" casing from 5380' to 6405' -Break Circ lost 22 bbls - Con't RIH slowly from 6405' to 7430 (correct displacement) -Break cir - Con't RIH from 7430 to 8688' (correct displacement) -Break circ -Wash last joint in hole to 8729' - MU landing joint with hanger -Wash down from 8729' to 8768' INT1 Circ casg volume -Pumped 30 bbl nut plug pill -Stage up pump from 3.5 bpm to 5 bpm - PP 620 to 550 - No Losses - PUW 250 -SOW 150 INTi RD Franks tool -Blow down top drive - RU cementing head / lines -Gain 20 bbls back while RU cementing head INTi Con't circulate /condition mud for cementing job - 5 bpm - 560 psi - No Losses INT1 Circulate /condition mud - 5 bpm 500 psi - No Losses INT1 Give to Schlumberger -Pump 5 bbl water Test lines 4500 psi 40 bbls Mud Push mixed @ 11.5 ppg Drop bottom plug 37 bbls" Cement Class "G" Mixed @ 15.8 ppg 1.16 cu/ft sx Drop top plug 5 bbls water Give rig to displace 327 bbls mud @ 5.5 bpm 450 Bump plug with 1900 psi -bleed off pressure -check floats - floats holding - No Losses Pressure up to 4500 psi -Hold for 10 min casg test -Record on chart -test good -Bleed off -Floats holding - 5 bbls pumped - 5 bbls back INT1 RD cementing lines - LD cementing head - LD Landing joint - Flush stack INT1 Install 7" Pack-off -Test to 5,000 psi for 10 min. Printed: 1/9/2006 9:41:41 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: MPC-28A MPC-28A DRILL+COMPLETE DOYON DRILLING INC DOYON 14 Date ', From - To Hours I Task !, Code'. NPT 1/3/2006 05:00 - 06:00 1.00 CASE P 06:00 - 07:00 1.00 CASE P 07:00 - 07:30 0.50 CASE P 07:30 - 08:00 0.50 CASE P 08:00 - 10:00 2.00 CASE P 10:00 - 11:00 1.00 CASE P 11:00 - 15:00 4.00 i CASE P 15:00 - 16:00 1.OOi DRILL P 16:00 - 17:00 1.00 CASE P 17:00 - 18:00 1.00 CASE P 18:00 - 19:00 1.00 DRILL P 19:00 - 19:30 0.50 DRILL P 19:30 - 20:30 1.00, DRILL P 1 /4/2006 1 /5/2006 20:30 - 23:30 I 3.001 DRILL I P 23:30 - 00:00 0.501 DRILL P 00:00 - 05:30 5.501 DRILL P 05:30 - 07:00 I 1.50! DRILL I P 07:00 - 11:30 4.501 DRILL P 11:30 - 13:00 1.50' DRILL P 13:00 - 18:00 5.00 DRILL P 18:00 - 20:00 2.00 CASE P 20:00 - 21:30 1.50 CASE P Page 7 of 9 Spud Date: 12/18/2005 Start: 12/18/2005 End: Rig Release: 1/8/2006 Rig Number: Phase j Description of Operations INT1 ~ Change top rams INT1 RU & test top rams- 250 low- 4500 high. INT1 Pull test plug- Install wear ring. INT1 Install bales & elevators- Mobilze BHA INT1 Make up BHA- Shallow test MWD INTi Service rig- Slip & cut drlg. Tine INT1 RIH w/ 4" DP- Wash last stand down- tag F.C. at 8684'. INTi Drill F.C. & cement to 8766' (2' above shoe). INT1 Circ. & condition mud f/ displacement INT1 PJSM-Pump HV sweep-Displace well w/ 10.0 ppg LSND mud. PROD1 Drill out shoe- Clean out 8 1/2" rathole to 8773'- Directional drill 20' new hole to 8793'. PROD1 Circ bottoms up PROD1 Rack back one stand, rig up for FIT test, 10# mwt, 1400 psi, 6713 tvd= 14# EMWT, good test, blow down, choke lines PROD1 Drilling 8793 to 8892' with 250 gpm, 1900 psi, 80 rpms, Cross fault @ 8895'+- hole, starting seeping 15-20 bbls hr., AST 2.25, ART 0 PROD1 Circ mix LCM pill, while Geologist reviews log, called town PROD1 Drilling 8892' to 9024 with 250 gpm, 1900 psi, 80 rpms, Mud loss slowed to 3-5 bbls hr. PROD1 CBU 1x .per geologist- No sign of sand or cap rock upon BU. CBU 1x to ensure hole clean. PROD1 Directional drill f/ 9024' to 9038'- PU & flow check (Geo. talking w/ Anchorage office). Continue drilling f/ 9038' to 9180' PROD1 Circ two bottoms up with 80 rpms, 300 gpm, 2440 psi PROD1 Drilling 9180' to 9430' TD with 300 gpm, 2700 psi, 80 rpms RUNPRD Circ three bottoms up with 80 rpms, 300 gpm, 2400 psi RUNPRD Pumping out to Csg shoe @ 8768 with full drilling rate, tight had to back ream 9200 to 9085, packing off from 8882' to 8765' 21:30 - 22:00 0.50' CASE P RUNPRD Circ bottoms up from csg shoe with 300 gpm 2300 psi, no increase in cuttings at shaker 22:00 - 22:30 0.50 CASE P RUNPRD RIH washed last stand to bottom 22:30 - 00:00 1.50 CASE P RUNPRD Circ three bottoms up with 80 rpms, 300 gpm, 2400 psi 00:00 - 00:30 0.50 CASE P RUNPRD Finish circ three bottoms up 00:30 - 01:30 1.00 CASE P RUNPRD Pump out to csg shoe@ 8768 with full drilling rate, no problems 01:30 - 02:00 0.50 CASE P RUNPRD Circ. bottoms up @csg shoe with 300 gpm 2300 psi, 60 rpms 02:00 - 05:00 3.00 CASE P RUNPRD Flow check, pump slug, POH to Bha 05:00 - 07:00 2.00 CASE P RUNPRD Laying down Bha 07:00 - 08:00 1.00 CASE P RUNPRD Rig up to pick up 3.5 liner 08:00 - 10:00 2.00 CASE P RUNPRD PJSM w/ all personel associated w/ task- Run 25 jts. 3 1/2" 9.2# L-80 IBT-M .Liner, Flex-Lock hanger & "C2" ZXP Liner Top Packer- Fill every 5 jts.- 10:00 - 10:30 0.50 CASE P RUNPRD Change elevators- RD casing tongs- PU 1 stand 4" DP- Circ. casing volume + 10:30 - 18:00 7.50 ~ CASE P RUNPRD RIH w/liner on 4" DP 90 sec. stand (Fill every 20 stds.) to 8697' (71' above 7" shoe). 18:00 - 18:30 ~ 0.50 CASE P RUNPRD Circ. DP & casing volume. 18:30 - 19:30 ~ 1.00, CASE P RUNPRD Rih to 9370' with liner, P/u two singles, pick up cement head. 19:30 - 21:00 1.50 CASE P RUNPRD Wash liner to bottom, 9430', circ and reciprocate 20', with 6 bbls min. 1500 psi, PJSM with cementers, top of liner 8608, landing collar 9364, shoe 9430' Printed: 1/9/2006 9:41:41 AM BP EXPLORATION Operations Summary Report Legal Well Name: MPC-28A Common Well Name: MPC-28A Event Name: DRILL+COMPLETE Start: 12/18/2005 Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date From - To I Hours Task Code'I NPT I~~ Phase 1/5/2006 21:00 - 21:30 ~ ~ - I - 0.50 ~ CEMT P ~ !RUNPRD 21:30 - 22:30 I 1.001 CASE I P I I RUNPRD 22:30 - 23:00 i 0.501 CASE I P I I RUNPRD 23:00 - 23:30 0.50 CASE P RUNPRD 23:30 - 00:00 0.50 CASE P RUNPRD 1/6/2006 00:00 - 01:00 1.00 CASE P RUNPRD 01:00 - 04:30 3.50 CASE P RUNPRD 04:30 - 05:30 1.00 BUNCO RUNCMP 05:30 - 06:30 1.00 BUNCO RUNCMP 06:30 - 10:30 4.00 BUNCO RUNCMP 10:30 - 11:00 0.50 BUNCO P RUNCMP 11:00 - 13:00 I 2.00 BUNCO P RUNCMP 13:00 - 15:00 I 2.001 RUNCOfy1P I I RUNCMP 15:00 - 17:00 2.00 BUNCO P RUNCMP 17:00 - 18:00 ~ 1.00 BUNCO P RUNCMP 18:00 - 00:00 6.00 BUNCO P RUNCMP 1/7/2006 00:00 - 00:30 0.50 BUNCO P RUNCMP 00:30 - 01:00 0.50 BUNCO P RUNCMP 01:00 - 02:30 1.50 BUNCO RUNCMP 02:30 - 23:00 20.50 BUNCO P RUNCMP 23:00 - 23:30 0.50 RUNCO~ RUNCMP 23:30 - 00:00 0.50 BUNCO P RUNCMP 1/8/2006 00:00 - 00:30 ~ 0.50 BUNCO RUNCMP 00:30 - 03:30 3.00 BUNCO RUNCMP 03:30 - 04:00 -0.50 BUNCO P RUNCMP 04:00 - 04:30 0.50 BUNCO RUNCMP 04:30 - 06:30 ~ 2.00 BUNCO RUNCMP 06:30 - 07:30 1.00 BUNCO RUNCMP 07:30 - 08:00 0.50 BUNCO RUNCMP 08:00 - 09:00 ! 1.00 BUNCO RUNCMP 09:00 - 10:30 I 1.501 RUNCOI~IP I I RUNCMP Page 8 of 9 Spud Date: 12/18/2005 End: Description of Operations Cement with Schlumberger 5 bbls water test lines 4000 psi 10 bbls CW-100 20 bbls Mud push @ 12.5 33.7 bbls, 157 sxs Class G; mixed 15.8 drop dart test isolation valve to 500 psi, washed lines Kicked out plug with 6.6 bbls 9.6 KCL water cement job was pumped 6 bbls min. reciprocate 2Q tt~,cfull returns Displace with rig pumps 6 bbls min. with 91 bbls mud, bump plug with 3500 psi to set hanger, full returns thru out job, reciprocate 20' till just before plug bump, float held, pressure up on liner with 1000 psi, and pull out of liner, pump cement up hole 20 bbls, set down on liner top packer to set same, Circ 9 bbls-min. 2100 psi to clear well of excess cement, total of 5 bbls good cement to surface. lay down cement head Circ bottoms up, reciprocate pipe 9 bbls min. 2100 psi laying down 8 stands drill pipe Poh with running tool, lay down same Rig up to pick up 2 1/16 pipe Picking up 6 jts 2 1/16 pipe and 7" csg scraper Rih with scraper and stinger to 8786'. Circ. bottoms up. RU & test casing to 4000 psi f/ 30 min.- OK, blow down choke lines Displace well with sweeps and 500 bbls seawater, 10 bbls min. 2850 psi, reciprocate pipe Reverse Circ well with 300 bbls seawater, 7 bbls min. 1540 psi Slip and cut drilling line, service top drive Lay down 4' drill pipe Laying down 2 1/6 stinger Pull wear ring Rig up to pickup 3.5 TCII tubing Picking up 3.5 9.2# L-80 TCII tubing and Baker S-3 packer, test tubing to 4000 psi every 1000 ft for 10 min., total 268 jts Tag up @ 8618', space out tubing Make up hanger, Test tubing and space out pups to 4000 psi for 10 mins. Finish test tubing and space out pups PJSM, rig up slick line unit, pull D-16 plug Rig down slick line unit Picked up landing jt., land tubing with TWC in place, test TWC to 1000 psi Nipple down BOPS Nipple up 3 1/8 tree and adapter Test tree and adapter 5000 psi, for ten min. Pull TWC, rig up to pump down annulus, taking returns up tubing Pumped down annulus with 160 bbls treated seawater, and 90 bbls of diesel for freeze protection, Printed: 1/9/2006 9:41:41 AM Printed: 1/9/2006 9:41:41 AM • • Well: MPC-28A Accept: 12/20/05 Field: Milne Point Unit / Kuparuk River Sands Spud: 12/29/05 API: 50-029-22648-01-00 Release: 01 /08/06 Permit: 205-163 Rig: Doyon 14 POST-RIG WORK 03/16/06 PERFORATED INTERVALS 9174' - 9188', AND 9196' - 9220' USING 2" HSD 2006 PJ OMEGA GUNS. DEPTH CORRELATED TO SWS CEMENT BOND LOG DATED 14-FEB-2006. DID NOT TAG TD. FIRST PERFORATION INTERVAL, 9196' - 9220' PERFORATED WITH 0 PSI ON WELL, UNDERBALANCED. NO PRESSURE INCREASE SEEN AFTER PERFORATING. LOGGED PRESSURE SURVEYS AFTER EACH PERFORATION. PRESSURE SURVEYS TAKEN AT 9190', 9170', 9025', 5000', 3000', AND 600' ELM AT PRESSURE SENSOR. 03/17/06 PERFORATED INTERVAL FROM 9034' - 9042' USING 2" HSD 2006 PJ OMEGA GUNS. DEPTH CORRELATED TO SWS CEMENT BOND LOG DATED 14-FEB-2006. PERFORATED WITH 0 PSI ON WELL, UNDERBALANCED. NO PRESSURE INCREASE SEEN AFTER PERFORATING. LOGGED PRESSURE SURVEYS AFTER EACH PERFORATION. PRESSURE SURVEYS TAKEN AT 9190', 9170', 9025', 5000', 3000', AND 600' ELM AT PRESSURE SENSOR. 03/18/06 WELL SUPORT TECH PULLED 2'2500 BLINDS ON THE GAS & WATER LATERAL LINES AT THE HEADER THAT PRODJECTS INSTALLED. AFTER BINDS WERE PULLED LINES PT TO SPEC 03/20/06 T/I/0=100/0/225 INJECTIVITY TEST. PUMPED 2 BBLS NEAT AND 30 BBLS MEOH DOWN TBG. MAINTAINING 0.4 BPM PRESSURE MAINTAINED @ 2450-2550 PSI FOR MOST OF THE PUMPING. PRESSURE FELL TO 1475 PSI 5 MIN. AFTER SHUT DOWN. FINAL WHP=1475/0/225 03/25/06 PERFORMED INITIAL MITIA POST SIDETRACK. USED A TRI-PLEX AND IT WAS WITNESSED BY STATE REP. JEFF JONES. TESTED ANNULUS TO 1800 PSI. TESTED GOOD. USED 1.1 BBLS OF DIESEL TO PRESSURE UP ANNULUS. Halliburton Global Companyc BP Amoco Date: 1!17/2006 Time: 15:28:22 Page: J Field: Milne Point Co~rdinate(NE) Reference: WeIJ: MPG28, True North`. Sites M Pt C Pad Vertical (TVD) Reference: MPC-28A: 50.2 Weil: MPC-28 Section (VS) Reference: Well (O.OON,O.OOE,320.07Azi) Wellpath: MPG28A Survey Calculation Meihod: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Cla rke 1866) Coordinate Syste m: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: MPC-28 Slot Name: MPC-28 Well Position: +N/-S 1771.11 ft Northing : 6029119.19 ft - Latitude: 70 29 24.619 N +E/-W 76.75 ft Easting : 558120.96 ft ' Longitude: 149 31 29.563 W Position Uncertainty: 0.00 ft Wellpath: MPC-28A Drilled From: MPC-28 500292264801 Tie-on Depth: 5334.87 ft Current Datum: MPC-28A: Height 50.20 ft Above System Datum: Mean Sea Level Magnetic Data: 12/14/2005 Declination: 24.34 deg Field Strength: 57578 nT Mag Dip Angle: 80.92 deg Vertical Section: Depth From (TVD) +N!-S +E/-W Direction ft ft ft deg 33.40 0.00 0.00 320.07 Survey Program for DePmitive Wellpath Date: 1/17/2006 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Name ft ft 103.68 5303.68 1 : Gyrodata gyrocompassing m/ (103 .68-530~f.6~MS Gyrodata gyrocompassing m/s 5334.87 5334.87 2 : MWD -Sta ndard (53 34.87-8617.40) (0) MWD MWD -Standard 5410.00 9391.80 MPC-28A IIFR (5410.00-9391.80) MWD+IFR+MS MWD +IFR + Multi Station Survey MD Intl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft tt ft 33.40 0.00 0.00 33.40 -16.80 0.00 0.00 6029119.19 558120.96 TIE LINE 103.68 0.46 43.69 103.68 53.48 0.20 0.19 6029119.40 558121.15 GYD-GC-MS 203.68 0.41 4.67 203.68 153.48 0.85 0.50 6029120.04 558121.45 GYD-GC-MS 303.68 0.49 16.14 303.67 253.47 1.62 0.65 6029120.81 558121.60 GYD-GC-MS 403.68 0.55 16.85 403.67 353.47 2.49 0.91 6029121.69 558121.85 GYD-GC-MS 503.68 0.72 14.79 503.66 453.46 3.56 1.21 6029122.75 558122.14 GYD-GC-MS 603.68 0.84 6.94 603.65 553.45 4.89 1.46 6029124.09 558122.38 GYD-GC-MS 703.68 0.90 350.80 703.64 653.44 6.39 1.42 6029125.59 558122.33 GYD-GC-MS 803.68 1.14 324.06 803.63 753.43 7.97 0.71 6029127.17 558121.61 GYD-GC-MS 903.68. 1.98 314.20 903.59 853.39 9.98 -1.11 6029129.16 558119.77 GYD-GC-MS 953.68 2.81 307.62 953.55 903.35 11.33 -2.70 6029130.50 558118.17 GYD-GC-MS 1003.68 4.32 304.92 1003.45 953.25 13.16 -5.22 6029132.31 558115.64 GYD-GC-MS 1053.68 5.20 304.32 1053.27 1003.07 15.52 -8.63 6029134.64 558112.21 GYD-GC-MS 1103.68 6.29 305.33 1103.02 1052.82 18.38 -12.74 6029137.47 558108.08 GYD-GC-MS 1153.68 6.95 306.20 1152.69 1102.49 21.75 -17.42 6029140.80 558103.38 GYD-GC-MS 1203.68 7.79 306.38 1202.28 1152.08 25.54 -22.58 6029144.55 558098.18 GYD-GC-MS 1253.68 8.27 306.41 1251.78 1201.58 29.69 -28.21 6029148.65 558092.52 GYD-GC-MS 1303.68 8.68 306.92 1301.24 1251.04 34.09 -34.12 6029153.01 558086.58 GYD-GC-MS 1353.68 9.14 307.15 1350.64 1300.44 38.75 -40.30 6029157.62 558080.36 GYD-GC-MS 1403.68 10.31 306.96 1399.92 1349.72 43.84 -47.04 6029162.66 558073.58 GYD-GC-MS 1453.68 10.92 306.99 1449.06 1398.86 49.38 -54.40 6029168.14 558066.18 GYD-GC-MS 1503.68 13.07 306.92 1497.97 1447.77 55.63 -62.70 6029174.32 558057.83 GYD-GC-MS 1553.68 14.10 306.65 1546.57 1496.37 62.66 -72.11 6029181.28 558048.37 GYD-GC-MS 1603.68 15.65 307.57 1594.89 1544.69 70.41 -82.34 6029188.95 558038.08 GYD-GC-MS 1703.68 15.55 307.45 1691.21 1641.01 86.78 -103.67 6029205.15 558016.62 GYD-GC-MS 1753.68 16.68 306.52 1739.24 1689.04 95.13 -114.76 6029213.41 558005.47 GYD-GC-MS 1803.68 18.00 306.71 1786.97 1736.77 104.02 -126.72 6029222.20 557993.44 GYD-GC-MS 1853.68 19.47 306.50 1834.32 1784.12 113.59 -139.61 6029231.68 557980.48 GYD-GC-MS • s Halliburton Global Company: BP Amoco Date:. 1/17/2006 Time: 15:28:22 Page:. 2 Field: Milne Point Co-ordinate(NE) Reference: Well: MPC-28, True North Site: M Pt C Pad Vertical (TVD) Reference:. MPC-28A: 50: 2 Wend MPG-28 Section (VS) Reference: Weil (O.OON,O. OOE,320.07Azi) Wellpath[ MPC 28A. Survey Calcula tion Method: Minimum Curvature Db: Oracle Survey IVID Iucl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 1903. 68 21.48 308.31 1881 .16 1830 .96 124 .23 -153. 50 6029242. 20 557966. 51 GYD-GC-MS 1953. 68 22.73 308.83 1927 .48 1877 .28 135 .96 -168. 20 6029253. 82 557951. 71 GYD-GC-MS 2003. 68 24.14 309.18 1973 .35 1923 .15 148 .47 -183. 66 6029266. 21 557936. 17 GYD-GC-MS 2053. 68 25.98 310.23 2018 .65 1968 .45 162 .01 -199. 94 6029279. 61 557919. 78 GYD-GC-MS 2103. 68 26.87 310.75 2063 .42 2013 .22 176 .46 -216. 86 6029293. 93 557902. 74 GYD-GC-MS 2153. 68 28.05 309.95 2107 .79 2057 .59 191 .38 -234. 44 6029308. 72 557885. 06 GYD-GC-MS 2203. 68 29.09 309.37 2151 .70 2101 .50 206 .64 -252. 85 6029323. 83 557866. 53 GYD-GC-MS 2253. 68 30.32 308.58 2195 .13 2144 .93 222 .22 -272. 11 6029339. 26 557847. 15 GYD-GC-MS 2303. 68 31.18 308.56 2238 .10 2187 .90 238 .16 -292. 10 6029355. 04 557827. 04 GYD-GC-MS 2353. 68 32.80 308.03 2280 .50 2230 .30 254 .57 -312. 89 6029371. 29 557806. 12 GYD-GC-MS 2403. 68 33.88 307.67 2322 .27 2272 .07 271 .43 -334. 59 6029387. 97 557784. 29 GYD-GC-MS 2453. 6$ 35.10 307.26 2363 .48 2313 .28 288 .65 -357. 06 6029405. 02 557761 .69 GYD-GC-MS 2503. 68 35.29 307.37 2404 .34 2354 .14 306 .12 -379. 98 6029422. 31 557738. 64 GYD-GC-MS 2553. 68 35.74 307.05 2445 .04 2394 .84 323 .69 -403. 11 6029439. 69 557715. 37 GYD-GC-MS 2603. 68 36.45 307.09 2485 .44 2435 .24 341 .44 -426. 62 6029457. 26 557691. 73 GYD-GC-MS 2703. 68 38.07 308.16 2565 .03 2514 .83 378 .41 -474. 56 6029493. 84 557643. 51 GYD-GC-MS 2753. 68 37.94 308.17 2604 .43 2554 .23 397 .44 -498. 76 6029512. 68 557619. 15 GYD-GC-MS 2803. 68 37.72 307.95 2643 .92 2593 .72 416 .34 -522. 91 6029531. 39 557594. 86 GYD-GC-MS 2903. 68 38.47 307.38 2722 .62 2672 .42 454 .04 -571. 75 6029568. 70 557545. 74 GYD-GC-MS 3003. 68 40.94 307.18 2799 .55 2749 .35 492 .73 -622. 58 6029606. 99 557494. 61 GYD-GC-MS 3103. 68 41.68 307.20 2874 .66 2824 .46 532 .63 -675. 16 6029646. 47 557441. 72 GYD-GC-MS 3203. 68 41.33 305.92 2949 .55 2899 .35 572 .10 -728. 39 6029685. 53 557388. 19 GYD-GC-MS 3303. 68 40.30 306.47 3025 .23 2975 .03 610 .70 -781. 14 6029723. 71 557335. 15 GYD-GC-MS 3403. 68 41.24 307.10 3100 .97 3050 .77 649 .80 -833. 44 6029762. 40 557282. 55 GYD-GC-MS 3503. 68 41.00 307.18 3176 .30 3126 .10 689 .51 -885. 86 6029801. 69 557229. 82 GYD-GC-MS 3603. 68 41.63 305.98 3251 ,41 3201 .21 728 .85 -938. 88 6029840. 61 557176. 51 GYD-GC-MS 3703. 68 41.78 302.75 3326 .08 3275 .88 766 .39 -993. 78 6029877. 71 557121. 32 GYD-GC-MS 3803. 68 41.24 302.82 3400 .96 3350 .76 802 .28 -1049. 50 6029913. 16 557065 .33 GYD-GC-MS 3903. 68 40.48 302.87 3476 .59 3426 .39 837 .76 -1104. 46 6029948. 21 557010 .09 GYD-GC-MS 4003. 68 40.01 302.91 3552 .92 3502 .72 872 .84 -1158. 71 6029982. 86 556955. 58 GYD-GC-MS 4103. 68 39.95 303.03 3629 .55 3579 .35 907 .81 -1212. 61 6030017. 40 556901. 40 GYD-GC-MS 4203. 68 40.56 305.76 3705 .87 3655 .67 944 .31 -1265. 92 6030053. 49 556847. 82 GYD-GC-MS 4303. 68 39.62 305.98 3782 .37 3732 .17 982 .04 -1318. 10 6030090. 81 556795. 35 GYD-GC-MS 4403. 68 38.92 305.74 3859 .79 3809 .59 1019 .12 -1369. 40 6030127. 48 556743. 76 GYD-GC-MS 4503. 68 38.44 306.09 3937 .85 3887 .65 1055 .78 -1420. 02 6030163. 74 556692. 87 GYD-GC-MS 4603. 68 38.35 306.51 4016 .23 3966 .03 1092 .55 -1470. 07 6030200. 11 556642. 53 GYD-GC-MS 4703. 68 39.14 308.96 4094 .23 4044 .03 1130 .86 -1519. 55 6030238. 03 556592. 76 GYD-GC-MS 4803. 68 38.73 310.03 4172 .01 4121 .81 1170 .82 -1568. 05 6030277. 61 556543. 96 GYD-GC-MS 4903. 68 38.18 310.16 4250 .32 4200 .12 1210 .88 -1615. 62 6030317. 28 556496. 08 GYD-GC-MS 5003. 68 37.59 309.53 4329 .25 4279 .05 1250 .22 -1662. 77 6030356. 26 556448. 63 GYD-GC-MS 5103. 68 38.23 309.06 4408 .15 4357 .95 1289 .13 -1710. 32 6030394. 79 556400. 78 GYD-GC-MS 5203. 68 38.84 309.50 4486 .37 4436 .17 1328 .57 -1758. 54 6030433. 85 556352. 26 GYD-GC-MS 5303. 68 38.87 309.62 4564 .24 4514 .04 1368 .53 -1806. 91 6030473. 42 556303. 59 GYD-GC-MS 5334. 87 38.77 308.64 4588 .54 4538 .34 1380 .87 -1822. 07 6030485. 64 556288. 32 MWD 5410. 00 38.72 307.82 4647 .14 4596 .94 1409 .97 -1859. 01 6030514. 45 556251. 17 MWD+IFR+MS 5452. 90 42.22 310.14 4679 .77 4629 .57 1427 .49 -1880. 63 6030531. 80 556229. 41 MWD+IFR+MS 5500. 98 43.63 312.94 4714 .98 4664 .78 1449 .21 -1905. 13 6030553. 32 556204. 74 MWD+IFR+MS 5549. 29 43.57 313.81 4749 .97 4699 .77 1472 .09 -1929. 35 6030576. 01 556180. 35 MWD+IFR+MS 5596. 65 44.46 316.95 4784 .03 4733 .83 1495 .51 -1952. 45 6030599. 25 556157. 07 MWD+IFR+MS 5644. 79 44.38 317.74 4818 .41 4768 .21 1520 .29 -1975. 28 6030623. 85 556134. 05 MWD+IFR+MS 5740. 14 45.16 319.10 4886 .11 4835 .91 1570 .52 -2019. 84 6030673. 73 556089. 10 MWD+IFR+MS 5835. 12 48.62 318.63 4951 .01 4900 .81 1622 .73 -2065. 45 6030725. 57 556043. 09 MWD+IFR+MS C Halliburton Global Company: BP Amoco Date: 1/17/2006 Time: 15;2822 Page:. 3 .Field: Milne Point Co-ordinate(NE} Reference: Well: MPG28, True Noith Site: M Pt C Pad Vertical (TVD) Reference: MPC-28A: 50.2 Well: MPC-28 Section (VS) Refereuee: Well (O.OON,O.OOE,320.07Azi) Wellpath: MPC-28A Survey Calculafion Method: ' :Minimum Curvature Db: Oracle Survey MD ft 5931.84 6026.94 6123.00 6218.55 6314.79 6411.14 6507.28 6603.19 6698.64 6792.91 6889.39 6985.26 7080.69 7176.49 7272.74 7367.18 7463.94 7560.61 7656.66 7747.57 7849.18 7945.55 8041.39 8138.10 8232.82 8327.33 8423.27 8518.88 8614.96 8710.16 8794.20 8841.41 8890.70 8941.91 8986.65 9035.69 9080.10 9126.13 9178.33 9227.32 9274.55 9321.60 9369.54 9391.80 . 9430.00 .Intl Azim deg deg 51.30 322.20 54.72 326.70 57.91 329.60 61.03 331.42 60.95 331.86 60.10 330.78 59.39 330.17 60.39 332.85 59.98 332.38 60.08 333.68 59.55 333.75 58.78 333.24 58.27 332.79 57.69 332.31 58.63 332.55 58.01 331.28 58.82 332.46 58.48 332.35 58.02 331.86 54.64 333.07 54.37 332.08 50.29 333.48 46.61 333.27 43.64 332.26 40.68 332.38 37.20 332.49 35.89 331.78 35.88 331.27 35.56 330.97 35.36 331.31 33.24 331.13 27.63 331.10 23.28 334.52 23.26 342.30 22.11 350.68 19.37 4.61 14.49 17.62 11.90 25.03 8.80 42.69 7.03 48.53 4.86 51.36 4.75 51.64 4.86 54.65 4.71 54.13 4.71 54.13 TVD Sys TVD ft ft 5013.23 4963.03 5070.46 5020.26 5123.74 5073.54 5172.28 5122.08 5218.95 5168.75 5266.36 5216.16 5314.80 5264.60 5362.92 5312.72 5410.38 5360.18 5457.47 5407.27 5505.98 5455.78 5555.12 5504.92 5604.95 5554.75 5655.74 5605.54 5706.52 5656.32 5756.12 5705.92 5806.80 5756.60 5857.09 5806.89 5907.63 5857.43 5958.03 5907.83 6017.03 5966.83 6075.91 6025.71 6139.47 6089.27 6207.70 6157.50 6277.90 6227.70 6351.40 6301.20 6428.48 6378.28 6505.94 6455.74 6583.94 6533.74 6661.49 6611.29 6730.91 6680.71 6771.60 6721.40 6816.09 6765.89 6863.15 6812.95 6904.44 6854.24 6950.32 6900.12 6992.81 6942.61 7037.63 6987.43 7088.98 7038.78 7137.51 7087.31 7184.48 7134.28 7231.36 7181.16 7279.13 7228.93 7301.32 7251.12 7339.39 ~ 7289.19 N/S E/W MapN ' MapE Tool ft ft ft ft 1679.81 -2112.58 6030782.27 555995.51 MWD+IFR+MS 1741.61 -2156.67 6030843.72 555950.95 MWD+IFR+MS 1809.51 -2198.80 6030911.28 555908.29 MWD+IFR+MS 1881.14 -2239.29 6030982.59 555867.25 MWD+IFR+MS 1955.21 -2279.27 6031056.34 555826.70 MWD+IFR+MS 2028.79 -2319.52 6031129.60 555785.87 MWD+IFR+MS 2101.06 -2360.45 6031201.53 555744.39 MWD+IFR+MS 2173.97 -2400.01 6031274.13 555704.26 MWD+IFR+MS 2247.51 -2438.10 6031347.35 555665.60 MWD+IFR+MS 2320.29 -2475.14 6031419.84 555628.00 MWD+IFR+MS 2395.06 -2512.07 6031494.31 555590.49 MWD+IFR+MS 2468.73 -2548.80 6031567.68 555553.19 MWD+IFR+MS 2541.25 -2585.73 6031639.91 555515.69 MWD+IFR+MS 2613.33 -2623.17 6031711.69 555477.69 MWD+IFR+MS 2685.82 -2661.02 6031783.87 555439.29 MWD+IFR+MS 2756.72 -2698.85 6031854.47 555400.91 MWD+IFR+MS 2829.41 -2737.71 6031926.84 555361.49 MWD+IFR+MS 2902.57 -2775.95 6031999.70 555322.68 MWD+IFR+MS 2974.76 -2814.16 6032071.58 555283.91 MWD+IFR+MS 3041.83 -2849.14 6032138.37 555248.40 MWD+IFR+MS 3115.26 -2887.24 6032211.49 555209.73 MWD+IFR+MS 3183.06 -2922.15 6032279.01 555174.30 MWD+IFR+MS 3247.17 -2954.28 6032342.86 555141.67 MWD+IFR+MS 3308.11 -2985.63 6032403.54 555109.85 MWD+IFR+MS 3364.40 -3015.16 6032459.60 555079.89 MWD+IFR+MS 3417.05 -3042.65 6032512.03 555051.99 MWD+IFR+MS 3467.55 -3069.34 6032562.32 555024.91 MWD+IFR+MS 3516.82 -3096.06 6032611.36 554997.81 MWD+IFR+MS 3565.93 -3123.15 6032660.26 554970.33 MWD+IFR+MS 3614.30 -3149.81 6032708.42 554943.30 MWD+IFR+MS 3655.81 -3172.61 6032749.74 554920.18 MWD+IFR+MS 3676.74 -3184.15 6032770.58 554908.47 MWD+IFR+MS 3695.55 -3193.87 6032789.31 554898.61 MWD+IFR+MS 3714.32 -3201.30 6032808.02 554891.03 MWD+IFR+MS 3731.05 -3205.35 6032824.72 554886.85 MWD+IFR+MS 3748.28 -3206.20 6032841.94 554885.88 MWD+IFR+MS 3760.93 -3203.92 6032854.60 554888.05 MWD+IFR+MS 3770.72 -3200.17 6032864.42 554891.73 MWD+IFR+MS 3778.53 -3195.18 6032872.27 554896.65 MWD+IFR+MS 3783.27 -3190.39 6032877.05 554901.40 MWD+IFR+MS 3786.44 -3186.66 6032880.24 554905.11 MWD+IFR+MS 3788.89 -3183.58 6032882.72 554908.17 MWD+IFR+MS 3791.30 •3180.37 6032885.15 554911.36 MWD+IFR+MS 3792.38 -3178.86 6032886.24 554912.87 MWD+IFR+MS 3794.22 -3176.32 6032888.10. 554915.39 • PROJECTED to TD Tree: 3 1/8" 5M Wellhead: FMC 11" x 11" M, Gen. 5 w/ 11" x 3.5" FMC Tbg. Hnr. w/ TCII threads top and bottom.and 3" CIW H BPV rofile 20" 91.1 ppf, H-40 115' KOP @ 600' Max. hole angle = 38 to 60 deg. f/ 2700' - 6800` Hole angle thru' perfs = 27 deg. 9-5/8" float shoe @ 5,405 Sidetrack kickoff @ 5,470` 7" 26#/ft , L-80, BTC-M csg. (drift ID = 6.151", cap. 0.0383 bpf ) 3.5" 9.2#/ft , L-80 TCII Tbg. (drift ID = 2.992" cap .00870 bpf ) Note: Original Well Bore Info: CIBP set @ 5,529' RA marker at 8071' wlm 9-5/8" original float shoe @ 5,405` 7" Weatherford float collar 8,68 7" Weatherford float shoe 8,76 Perforation Summary Ref loss: Siz SPF Interval (ND) 2 6 9034-9042 6948-6956 2 6 9174-9188 7084-7098 2 6 9196-9220 7106-7130 DATE REV. BY COMMENTS 01/08/06 MDO Sidetrack Completion Doyon - 14 O~F Elev. = 46.5' (N 22E) Ori vL Elev. = 16.8' RKB = 43.18' Doyon-14 3.5" HES X-Nipple 2.813" 2,495' HES X-Nipple 2.813" 8,457` 3.5" Baker S-3 Pkr. 8,510` HES XN-Nipple 2.750" No Go 8,569" K 3.5" Baker Liner Tie Back Slv. 8,608` ?" ZXP Liner Top Packer 8,620` Aker Flex Lock Liner Hng. 8,626` ;er Landing Collar 9,364` HES float collar 9,396' HES float shoe 9,430` MILNE POINT UNIT WELL MPU C - 28ai API NO: 50-029-22648-00-00 MPU C - 28ai • • 25-Jan-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPC-28A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,334.87' MD Window /Kickoff Survey: 9,391.00' MD (if applicable) Projected Survey: 9,430.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date C~~ ~'7/Clc Signed ~~ `'`' Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager ,~b5-I C~~ Attachment(s) i f - BP EXPLORATION Operations Summary Report Page 1 of 9 Legal Well Name: MPC-28A add - ~ b Common Well Name: MPC-28A Spud Date: 12/18/2005 Event Name: DRILL+COMPLETE Start: 12/18/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/8!2006 Rig Name: DOYON 14 Rig Number: Date from - To Hours Task Code NPT Phase- Description of"Operations 12/19/2005 1 19:00 - 00:00 5.00 MOB I P PRE 12/20/2005 00:00 - 06:00 6.00 MOB i P PRE 06:00 - 08:00 2.00 MOB P PRE 08:00 - 09:00 1.00 MOB ~ P I PRE 09:00 - 11:00 2.00 RIGU I P 11:00 - 12:00 1.00 RIGU P 12:00 - 13:30 1.50 RIGU ~ P 13:30 - 16:30 3.00 RIGU I P 16:30 - 17:30 1.00 RIGU i P 17:30 - 18:30 1.00 RIGU I P ( 18:30-21:30 3.00 RIGU 'P 21:30 - 23:00 1.50 RIGU ~ P 23:00 - 00:00 1.00 RIGU P 12/21/2005 00:00 - 07:30 7.50 EVAL I i N 07:30 - 08:00 0.50 EVAL P 08:00 - 09:00 1.00 EVAL P 09:00 - 10:30 1.50 STCTPL P 10:30 - 18:00 7.50 STCTPL P 18:00 - 18:30 0.50 EVAL P 18:30 - 00:00 5.50 EVAL P 12/22/2005 00:00 - 01:00 I 1.00 ~ EVAL i P 01:00 - 01:30 0.50 STCTPL P 01:30 - 02:00 0.50 STCTPL P PRE Skid rig floor, Move off MPH-15, on to road Move rig to MPC-28A Spot rig over well -Shim same Skid rig floor from move position to move position -Spot rock washer Rig up floor -Top drive -Steam ,water, air -Berm rock washer PRE Rig up lines to tiger tank and tree (Accept rig ~ 11:00 hrs) PRE RU lubricator -Pull BPV - RU to bleed to tank PRE Displace freeze protection from well -Pump 50 bbls hot seawater - 34 bbls soap pill - 300 bbls of seawater -Spot 100 bbls 13.9 ppg LSND mud C~3 7856' (tubing cut) -Chase with 40 bbls seawater - 215 gpm - @ 2130 psi PRE Install TWC -Test to 3000 psi - RD circ lines PRE ND Tree PRE NU stack -Flow line -Mouse hole PRE MU test joint - RU to test BOP's , PRE Test BOP's -Test rig alarms -Good test on alarms -Test Annular 250 low 2500 high 5 mins each test OTHCMP Attempt to test BOP's - No test loss 200 psi on Annular -Top Rams -Blind rams -Attempt to test Choke manifold - No test - Warming up manifold - Regreasing all valves - (while waiting on Lubricator from 4ES) -Change out XO's on lubricator - make up lubricator to hanger -Pull TWC -inspect TWC - Plugged with mud and debris -Change out TWC -Install same - Attempt to pressure up on TWC -Same results -Unable to get test - (Called AOGCC Chuck Scheve -Discussed body and casing test to 3500 pull tubing and retest BOPS when tubing layed down) OTHCMP RD lubricator - RU to test with blind rams closed OTHCMP Test casing to 3500 psi for 15 mins -Test good -Test recorded on chart OTHCMP MU landing joint 3 1/2" NSCT -Pull hanger to rig floor - 105K PUW - LD Hanger OTHCMP Stand back 5 stands in derrick - LD 233 Joints plus 16.34' of 3 1/2" NSCT 9.3# tubing OTHCMP Install test plug - RU to test BOP's -Open annulus valves OTHCMP Test BOP's -Annular 250 low 2500 high 5 mins each test -Top rams -Choke manifold -Flange on # 12 valve leaking -Tighten up flange -Retest -test good -Manual Choke /Kill valves - HCR Choke /Kill valves -Choke HCR failed high test - Greased valve -Retest -Test good -Upper / Lower !BOP valves -Floor safety valves -Blind rams - 250 low 4500 high 5 mins each test -Preformed Accumulator test -All equipment tested successful - WSL witnessed all test -John Crisp with AOGCC wavied witness of BOP test - RD testing equipment - Close annulus valves -Pull test plug -install wear ring OTHCMP RD testing equipment -Close annulus valves -Pull test plug - install wear ring -Blow down choke manifold -Choke line -Kill line OTHCMP Moblize BHA to rig floor OTHCMP MU bit - casging scraper -Bit Sub - XO - PU 1 stand of 4" DP from pipe shed Printed: 1/9/2006 9:41:41 AM • 12/22/2005 02:00 - 03:00 1.00 STCTPL P OTHCMP Cut drlg line -Service top drive 03:00 - 07:30 4.50 STCTPL P OTHCMP Con't PU 4" DP from pipe shed 1 x 1 to 5700' - LD a single - Pull 1 stand to 5563' 07:30 - 09:00 1.50 STCTPL P OTHCMP Pump 25 bbl Hi-vis sweep - @ 400 GPM - PP 1420 psi -Pump 09:00 - 11:00 2.00 STCTPL P OTHCMP 2nd Hi-vis sweep -GPM 415 - PP 1425 -Pump dry job Blow down top drive - POH - LD XO's -Casg scraper -Bit 11:00 -12:00 1.00 STCTPL P OTHCMP Change bails - PU 350 ton elevators 12:00 - 15:30 3.50 STCTPL P OTHCMP PJSM - RU Schlumberger -RIH with Howco 7 "CIBP - CCI - Set Bridge plug C~ 5529' - POH 15:30 - 16:30 1.00 STCTPL P OTHCMP RU testing equipment -Test CIBP 2500 psi for 30 mins - Record on chart -Test good 16:30 - 18:00 1.50 STCTPL P OTHCMP Pull 7" Pack-off - MU Landing joint -Establish stretch points - I 50K pull 7.5" stretch indicates 2830' free - 100K pull 18.5" stretch indicates 3491' free 18:00 - 00:00 6.00 STCTPL P OTHCMP RU wire line -RIH with 7" free point tool -Take free point readings - 5494' - 0% free - 4494 33% free - 3494 72% free - 3300 92% free - 3170 95% free - 2900 100% free - 50K pull - ~ ~ Attempt to free point with 100K pull -Free point tool quit ( working - POH 12/23/2005 00:00 - 02:00 2.00 STCTPL P OTHCMP POH with Free point tool -Inspect free point tool -Tool ~ functioning properly -Possible over heated motor -Change out ~ free point tool 02:00 - 06:30 4.50 ~ STCTPL N WAIT ~ OTHCMP Crew over 16 hrs -Waiting on crew from Schlumberger yard to ' continue free point operation 06:30 - 11:30 5.00 STCTPL P OTHCMP Run free point tool - 100K over pull - 5485 / 0% free - 5000' / 0% free - 4485 / 53 to 69 - 64% free - 4760 / 0% - 4640 / 35 to 32% - 4000 / 68 to 78% - 3485 / 80 to 86% - 3300 / 88% - 200K over 476017% free - 4640 / 57% free - 4485 / 74% free - 4000 / 58 to 61 % - 3485 / 80% to 82% free 11:30 - 13:00 1.50 STCTPL P OTHCMP LD landing joint -Install pack-off -Test same 13:00 - 14:30 1.50 STCTPL P OTHCMP PJSM -Install test plug -Change top rams to 7" 14:30 - 15:00 0.50 STCTPL P OTHCMP Test door seals to 1500 psi -Test good 15:00 - 16:00 1.00 STCTPL P OTHCMP LD 350 ton casg elevators -Change out long bails 16:00 - 16:30 0.50 STCTPL P OTHCMP MU BHA -Casg cutter assy 16:30 - 18:00 1.50 STCTPL P OTHCMP RIH to 4708' -Locate collar @ 4783 18:00 - 18:30 0.50 STCTPL P OTHCMP Cut 7" casg ~ 4793' -GPM 150 - PP 550 -RPM 70 - TQ 2K 18:30 - 19:30 1.00 STCTPL P OTHCMP Circ through cut casg taking returns out outer annulus to bleed tank -Pump 210 bbls 8.3 ppg seawater 5 BPM ~ 1200 psi 19:30 - 20:00 0.50 STCTPL P OTHCMP Pressure up on 9 5/8" to 2380 psi -Pumped 3.8 bbls -Held 5 mins - No pressure drop -Bleed off pressure 20:00 - 21:00 1.00 STCTPL P OTHCMP Circulate unbalanced mud -Circulate to level out -GPM 300 - PP 1980 21:00 - 21:30 0.50 STCTPL P OTHCMP RIH -Locate collar @ 5381' 21:30 - 22:30 1.00 STCTPL P OTHCMP Cut 7" casg ~ 5392' -RPM 70 - TQ 2K -GPM 200 - PP 600 - 22:30 - 23:00 0.50 STCTPL P OTHCMP Pull 4 stands to 4890' -Locate collar ~ 4983' 23:00 - 23:30 0.50 STCTPL P OTHCMP Cut 7" Casg ~ 4993' -RPM 70 - TQ 2K -GPM 200 - PP 550 23:30 - 00:00 0.50 STCTPL P OTHCMP CBU 1 X -GPM 380 - PP 2070 -Flow check well 12/24/2005 00:00 - 02:00 2.00 STCTPL P OTHCMP POH with Baker cutting assy 02:00 - 02:30 0.50 STCTPL P OTHCMP LD Baker cutting assy 02:30 -04:00 1.50 STCTPL P OTHCMP Pull wear ring -Pack-off 04:00 -04:30 0.50 STCTPL P OTHCMP Make up 7" casg spear -Engage spear -Pull casg hanger to floor - PUW 175 - 160 Page 2 of 9 Legal Well Name: MPC-28A Common Well Name: MPC-28A Spud Date: 12/18/2005 Event Name: DRILL+COMPLETE Start: 12/18/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations BP EXPLORATION Operations Summary Report Printed: 1/9/2006 9:41:41 AM • BP EXPLORATION Page 3 of 9 Operations Summary Report Legal Welj Name: MPC-28A Common Well Name: MPC-28A Spud Date: 12/18/2005 Event Name: DRILL+COMPLETE Start: 12/18/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description ofi Operations 12/24/2005 04:30 - 06:00 1.50 STCTPL P ( OTHCMP LD Spear - 2 joints 5" HWDP -Clear floor of fishing tools - 350 ton elevators - RU casg tools to LD 7" Casg 06:00 - 12:00 6.00 STCTPL I P ~ OTHCMP RU Casg equipment - LD 119 joints + 10.7 cut joint of 7" Casg 12:00 - 12:30 0.50 STCTPL P OTHCMP Clear rig floor 12:30 - 13:30 1.00 STCTPL I P i OTHCMP PU Test jt -Install test plug -Change 7" rams to 2 7/8' x 5' VBR ~ rams 13:00 - 14:00 1.00 STCTPL P OTHCMP Test door seals to 1500 psi - LD test jt /test plug -Install wear ring 14:00 - 15:00 1.00 STCTPL P OTHCMP Moblize BHA to floor - C/O handling equipment 15:00 - 16:00 1.00 STCTPL P OTHCMP MU BHA -Spear -Jars -Bumper sub - 5" HWDP - 16:00 - 17:30 1.50 STCTPL P ~ OTHCMP Wait on accelerator jar from Baker 17:30 - 19:00 1.50 STCTPL P i OTHCMP Make up accelerator -RIH with spear to 4793' -PUW 128 - SO ' X108 19:00 - 19:30 0.50 1 STCTPL P ; OTHCMP Engage spear on casg -Jar 4 times 250k jar -Casing free 19:30 - 21:30 2.00 STCTPL P OTHCMP POH with 7 casg - 200' POH over 40K -Weight dropped to 5k over PU weight 21:30 - 23:30 2.00 STCTPL P ~ I OTHCMP Stand back HWDP - LD Jar - LD spear - LD top stub 29.20' + 4 ~ i jts 7" casg + 7.20 cut joint (total joint laid down 124 + 7.20') 23:30 - 00:00 0.50 STCTPL ', P i OTHCMP PU Spear assy -Inspect grapples 12/25/2005 OO:OC - 01:30 1.50 STCTPL P OTHCMP RIH with spear assy to 4990' 01:30 - 05:30 4.00 STCTPL P i OTHCMP Engage fish with spear @ 4993' -Jar on casing -Release from fish 05:30 - 07:30 2.00 STCTPL P ~ OTHCMP Blow down top drive - POH with spear assy 07:30 - 09:00 1.50 STCTPL P OTHCMP LD Spear assy - MU Cutting assy 09:00 - 10:30 1.50 STCTPL P OTHCMP RIH with cutting assy to 5392' confim cut 10:30 - 13:00 2.50 STCTPL P i OTHCMP Pull up locate collar @ 5300' cut casg ~ 5310' -Pull up locate i collar 5140' cut casg ~ 5150' -PUW 120 - SO 108 -RPM 70 to 80 -GPM 150 to 167 - PP 600 to 630 ~ - TQ 3K 13:00 - 14:00 1.00 STCTPL P OTHCMP POH with cutter assy 14:00 - 14:30 0.50 STCTPL P OTHCMP Repair iron roughneck hydralic hose 14:30 - 15:30 1.00 STCTPL P OTHCMP Con't POH with cutter assy 15:30 - 17:30 2.00 STCTPL P OTHCMP LD BHA cutter assy - MU Spear assy - C/O Jars -Grapple - Pack-off -Accelerator 17:30 - 19:00 1.50 STCTPL P OTHCMP PJSM - Cut drlg line -Rig service 19:00 - 20:30 1.50 STCTPL P OTHCMP RIH to 4993' -PUW 133 - SO 108 -Engage spear - PU to 150K -Drag fell off to 7K over string weight - (top of fish 5150') 20:30 - 22:00 1.50 STCTPL P OTHCMP POH with fish 22:00 - 23:30 1.50 STCTPL P OTHCMP LD accelerator -Stand back HWDP - LD spear - LD stub 28.67' + 3 jts of 7" casg - LD cut joint 9.95' - (Total 7" casg recovered 128 jts + 9.95') 23:30 - 00:00 0.50 STCTPL P OTHCMP Clear rig floor -Moblize BHA to rig floor 12/26/2005 00:00 - 00:30 0.50 STCTPL P OTHCMP Moblize BHA 00:30 - 02:00 1.50 STCTPL P OTHCMP MU BHA - PU 12 6 1/4" DC's 02:00 - 03:30 1.50 STCTPL P OTHCMP RIH to 5086' 03:30 -04:00 0.50 STCTPL P OTHCMP Wash to 5150' -PUW 160 - SO 125 -Engage spear -Jar casg loose -Work casg up hole -Pulling 225 to 325 (60 to 165 over string weight) for 74' -Weight dropped to 6K over string weight to 165K - (top of fish 5310') 04:00 - 07:00 3.00 STCTPL P OTHCMP Blow down top drive -Flow check - POH with fish 07:00 - 08:00 1.00 STCTPL P OTHCMP Stand back BHA 08:00 - 08:30 0.50 STCTPL P OTHCMP LD 2 Cut joints 11' and 30.11' + 3 joints - (total recovered 122 joints + 11') Printed: 1/9/2006 9:41:41 AM • • BP EXPLORATION Page 4 of 9 Opera#ions Summary Report (Legal Well Name: MPC-28A Common Weil Name: MPC-28A Spud Date: 12/18/2005 'Event Name: DRILL+COMPLETE Start: 12/18/2005 End: '.Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Cotle" NPT Phase Description of'Operations 12/26/2005 08:30 - 09:30 1.00 STCTPL P 09:30 - 11:00 1.50 STCTPL P 11:00 - 12:00 , 1.00 STCTPL P 12:00 - 13:30 1.50 STCTPL P 13:30 - 16:00 2.50 STCTPL P 16:00 - 17:30 1.50 STCTPL P 17:30 - 18:00 0.50 STCTPL P 18:00 - 19:00 1.00 STCTPL P 19:00 - 20:30 ~ 1.50 STCTPL P 20:30 - 21:30 ~ 1.00 STCTPL P 21:30 - 00:00 2.501 STCTPL I P 12/27/2005 ! 00:00 - 12:00 ! 12.00 ! STCTPL I P 12:00 - 15:30 ~ 3.50 STCTPL P 15:30 - 22:00 i 6.50 STCTPL P 22:00 - 22:30 0.50 STCTPL P 22:30 - 00:00 1.50 STCTPL P 12/28/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 01:00 0.50 DRILL P 01:00 - 00:30 23.50 DRILL P 03:00 -04:00 1.00 DRILL 04:00 - 04:30 0.50 DRILL P 04:30 - 05:00 0.50 CEMT P 05:00 - 06:00 1.00 DRILL P 06:00 - 07:00 1.00 DRILL P 07:00 - 08:30 1.50 DRILL P 08:30 - 09:30 1.00 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 13:00 3.00 DRILL P OTHCMP MU Spear Assy OTHCMP RIH to 5192' OTHCMP Wash down from 5192' to 5310' -Engage grapple -Jar fish loose -Over pull 100 to 150 for 50' -Over pull dropped to 3to 5K over normal string weight OTHCMP POH with fish OTHCMP Stand back HWDP - DC's - LD Accelerator -Spear -Casg stub 28.71' + 1 jt casg + 10.88 cut joint - (total 7" Casg joints recovered 124 + 10.88') OTHCMP Clear rig floor - LD jars -Bumper sub -Service break spear OTHCMP Moblize Milling BHA to rig floor OTHCMP PJSM - MU Milling assy -Mill - DC's -Jars -HWDP OTHCMP RIH to ~ 5390' OTHCMP Circ -Bleed in milling fluid -GPM 320 - PP 580 -RPM 50 - TO 4K OTHCMP Milling 7" casing from 5392' to 5402' -GPM 600 - PP 1260 - RPM 80 - TO 4K - PU 140 - SO 115 -ROT 125 OTHCMP Milling casg from 5402' to 5476' - WOM 6 to 8 -RPM 80 - TO 4 toy.5K-GPM600-PP1280-PU135-S0115-ROT 120 OTHCMP Circulate -Clear metal out of hole OTHCMP POH to shoe -Flow check -Pump dry job - POH Drag 20 to 50 over -Pump /Back ream out 5 stands -Attempt to pull with out pump back ream -Pulled tight - Con't Pump back ream to 1819' -GPM 550 - PP 890 -RPM 100 - TO 2K - POH without pump or back reaming -Stand back HW D - LD DC's -Jars - Mill - (No metal ball on BHA) OTHCMP Clear rig floor -Pull wear ring OTHCMP MU stack washer -Flush stack -Function rams, Annular, - Flush stack -Flush choke line /kill line -Install wear ring INT1 RU tubing equipment INTi Run 16 joints NSCT 3 1/2" tubing to set cement kick off plug INT1 Change 3 1/2" handling equipment to 4" -RIH with 4" DP to 5308' -Taking weight 5 to 10K INT1 Wash from 5296' to CIBP @ 5529 - PU to 5527' INT1 RU cementing lines -Beak circulation 6 BPM - PP 600 psi - INT1 Give to Dowell Close Annular -Pumping through choke Pump 5 bbls water Test lines to 3000 -Test good Pump 24.5 bbls water Pump 30.5 bbls 17 ppg cement -Yield 1.00 cufUsx Pump 5 bbls water Rig displace with 46 bbls mud C~3 5 bpm Last barrel of displacement choke plugged pressure increased to 1350 -Shut down pressure held -Bleed off pressure through fill line and kill line back through pumps -Open Annular INT1 POH slowly to 4566' INT1 Pump 30 bbl nut plug sweep - 8.6 bpm ~ 550 psi - Reciprocating string INT1 Continue POH to 3 1/2" tubing INT1 LD 3 1/2" tubing INT1 Rig down tubing equipment- clear floor INT1 PU 108 jts. 4" DP from shed to 3600' Printed: 1/9/2006 9:41:41 AM • • BP EXPLORATION Page 5 of 9 Operatiolns Summary Report Legal Well Name: MPC-28A Common Well Name: MPC-28A Spud Date: 12/18/2005 Event Name: DRILL+COMPLETE Start: 12/18/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date From - To Hours .Task Code NPT Phase Description of Operations 12/28/2005 ~ 13:00 - 14:30 1.50 DRILL P INT1 Pump sweep- Circ. surface to surface 3X- Flow check, dry job 14:30 - 16:00 1.50 DRILL P INT1 POH 16:00 - 16:30 0.50 DRILL P INT1 Pull wear ring- Flush BOPE & function same 16:30 - 17:30 1.00 BOPSU P INT1 PU test joint -Pull wear ring -Install test plug -Open annulus valves - RU to test BOPE 17:30 - 21:00 3.50 BOPSU P INT1 Test BOP's -Annular 250 low 2500 high - 5 mins each test - Pipe rams -Choke manifold - HCR Choke /Kill -Manual Choke / Kill -Upper /Lower IBOP -Floor safety valves -Blind rams - 250 low 4500 high - 5 mins each test -Perform accumulator ~ test -All test were successful -Alf test were witnessed by WSL -John Crisp with AOGCC waived witness of BOP test 1 21:00 - 21:30 ~ 0.50 BOPSU P INT1 RD test equipment -Pull Test plug -Install wear ring -Close I i , annulus valves - LD test joint -Blow down choke manifold /line 1 -Kill line -Top drive 21:30 - 22:00 ~ 0.50 DRILL P INT1 ~ Moblize 8 1/2" short BHA to rig floor i t 22:00 - 00:00 2.00 DRILL P INT1 MU 8 1/2" BHA -Bit -Motor @ 1.5 degree - MW D-Orient - NM I ~ DC's -Surface test 12/29/2005 00:00 - 01:30 1.50 DRILL P INT1 I MU BHA 01:30 - 02:30 1.00 DRILL P INT1 ~ Cut drlg line -Top drive service 02:30 - 04:00 1.50 DRILL P INT1 RIH to 4850' I 04:00 - 05:00 1.00 DRILL P INT1 Wash from 4850' to 5135' -Tag Cement @ 5135' - WO pump 8 to 10K 1 05:00 - 08:30 3.50 DRILL P INT1 Drilling cement from 5135 - 1 to 2K with pump 400 GPM - 5212 j ~ I WO pump 15K -With pump 2 to 3K -Drilling firm cement f/ ~ 5245' to 5506' 8 to 10K with pump 400 GPM - PP 1200 -RPM I 38 II 08:30 - 10:30 2.00 DRILL P INT1 Time drill f/ 5406' to 5419' I~ 10:30 - 12:00 1.50 DRILL P INT1 Displace well w/ 8.7 ppg LSND mud. 400 gpm 70 rpm 5k tq.- I No metal observed wI returns. I 12:00 - 18:30 6.50 DRILL P INT1 Time drill f/ 5419' to 5470' - 18:30 - 19:30 1.00 DRILL P INT1 RU test equipment -FIT - MD 5405 - TVD 4611 - MW 8.6 - Surface pressure 940 = EMW 12.52 - RD test equipment - Blow down lines 19:30 - 00:00 4.50 DRILL P INTi Directional drill from 5470 to 5708' - WOB 7 to 10 -RPM 60 - TQ7on-Goff-GPM545-PPon 2300-off 2160-PU 162- SO 115 -ROT 135 12/30/2005 00:00 - 00:00 24.00 DRILL P INT1 Directional Drill from 5708' to 7275' - WOB 10 to 20 -RPM 80 - TOon6-off6-GPM550-PPon3760-off3500-PU 150- SO 120 -ROT 137 12/31/2005 00:00 - 02:30 2.50 DRILL P INT1 Directional Drill from 7275' to 7431' - WOB 15 -RPM 80 - TO on7-off6-GPM550-PPon 3800-off 3650-PU 155-SO 122 -ROT 136 02:30 -04:00 1.50 DRILL P INT1 CBU 2.5 X -RPM 80 - TQ -GPM 550 - PP 3600 -Flow check - Well static 04:00 - 05:30 1.50 DRILL P INT1 Pump to shoe @ 5400' -Pump at drlg rate 05:30 - 06:30 1.00 DRILL P INT1 CBU 2 X -RPM 40 -GPM 540 - PP 2900 06:30 - 07:30 1.00 DRILL P INT1 RIH- Wash last stand to bottom. 07:30 - 00:00 16.50 DRILL P INT1 Directional drill f/ 7431' to 8390' - WOB 10 to 20 -RPM 80 - TQ Ton-Goff-GPM510-PPon 3900-off 3680-PU 168-SO 130 -ROT 148 1/1/2006 00:00 - 12:30 12.50 DRILL P INT1 Directional Drill from 8390' to 8773' (8 1/2" TD)- PU 200k- SO 135k- ROT 155k- RPM 80- Tq 10k on 9k off- PP 3470 on 3200 off-500 gpm- WOB 5-20k. Primed: 1/9/2006 9:47:41 AM • BP EXPLORATION' Page' 6 of 9 Operations Summary Report Legal Well Name: MPC-28A Common Well Name: MPC-28A Spud Date: 12/18/2005 Event Name: DRILL+COMPLETE Start: 12/18/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 1/1/2006 12:30 - 14:30 2.00 CASE P INT1 CBU 2X - 480 gpm - 80 rpm - PP 3100 -Reciprocate DP 14:30 - 17:00 2.50 CASE P INT1 Pump out from 8773' to 5400' (8 1/2" ghost reamer at shoe) at drilling rate. -GPM 480 - 2950 17:00 - 18:30 1.50 CASE P INT1 RIH to 8687' -Precautionary wash to btm @ 8773' 18:30 - 20:30 i 2.00 CASE P INT1 CBU 3 X -GPM 560 - PP 3950 -RPM 80 - TO 8.5K -Flow check -Well static 20:30 - 00:00 3.50 CASE P INT1 Flow check -Well static -Pump out to shoe from 8773 to 5400' - Pump at drlg rate -Tight 15 to 20 over string weight back ream from 5525 to 5490 -work through twice with .out back reaming from 5490 to 5440 1/2/2006 ~ 00:00 - 01:30 1.50 CASE P INT1 CBU 2 X -GPM 509 - PP 2670 -RPM 40 - TQ 5 -Flow check - Well static -Pump dry job 01:30 - 03:30 ' 2.00 ~ CASE P INT1 POH from 5389' to 718' 03:30 - 05:30 2.00 CASE P INT1 LD BHA 05:30 - 06:00 0.50 CASE P INT1 Clear rig floor 06:00 - 06:30 0.50 CASE P INT1 Pull wear ring- Install test plug. 06:30 - 07:30 ~ 1.00 CASE P INT1 PJSM- Change top rams to 7" 07:30 - 08:00 0.50 CASE P ~ INT1 Test door seals to 1500 psi. 08:00 - 09:00 1.00 CASE P INT1 PJSM- Rig up to run 7" casing 09:00 - 15:30 6.50 CASE P INTi Run 7" 26# BTC-M casing to 9 5/8" @ 5380'. 15:30 - 18:00 2.50 CASE P INT1 Circ. & condition mud 18:00 - 22:00 4.00 CASE P ~ INT1 Continue run 7" casing from 5380' to 6405' -Break circ lost 22 bbls - Con't RIH slowly from 6405' to 7430 (correct displacement) -Break cir - Con't RIH from 7430 to 8688' (correct displacement) -Break circ -Wash last joint in hole to 8729' - MU landing joint with hanger -Wash down from 8729' to 8768' 22:00 - 23:00 1.00 CASE P INT1 Circ casg volume -Pumped 30 bbl nut plug pill -Stage up pump from 3.5 bpm to 5 bpm - PP 620 to 550 - No Losses - PUW 250 -SOW 150 23:00 - 23:30 0.50 CASE P INT1 RD Franks tool -Blow down top drive - RU cementing head / lines -Gain 20 bbls back while RU cementing head 23:30 - 00:00 0.50 CASE P INT1 Con't circulate /condition mud for cementing job - 5 bpm - 560 psi - No Losses 1/3/2006 00:00 - 01:30 1.50 CASE P INT1 Circulate /condition mud - 5 bpm 500 psi - No Losses 01:30 - 03:30 2.00 CEMT P INT1 Give to Schlumberger -Pump 5 bbl water Test lines 4500 psi 40 bbls Mud Push mixed @ 11.5 ppg Drop bottom plug 37 bbls" Cement Class "G" Mixed ~ 15.8 ppg 1.16 cu/ft sx Drop top plug 5 bbls water Give rig to displace 327 bbls mud ~ 5.5 bpm 450 Bump plug with 1900 psi -bleed off pressure -check floats - floats holding - No Losses Pressure up to 4500 psi -Hold for 10 min casg test -Record on chart -test good -Bleed off -Floats holding - 5 bbls pumped - 5 bbls back 03:30 - 04:30 1.00 CASE P INT1 RD cementing lines - LD cementing head - LD Landing joint - Flush stack 04:30 - 05:00 0.50 CASE P INT1 Install 7" Pack-off -Test to 5,000 psi for 10 min. Printed: 7/9/2006 9:41:41 AM • BP EXPLORATION Operations Summary Report Legal Well Name: MPC-28A Common Well Name: MPC-28A Event Name: DRILL+COMPLETE Start: 12/18/2005 Con#ractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Page 7 of 9 Spud Date: 12/18/2005 End: -Date ' I From - To Hours l Task Code I NPT Phase Description of Operations 11/3/2006 05:00 - 06:00 1.00 CASE P INT1 06:00 - 07:00 1.00 CASE P INT1 07:00 - 07:30 0.50 CASE P INT1 07:30 - 08:00 0.50 ~ CASE P INT1 08:00 - 10:00 2.00 CASE P INTi 1 10:00 - 11:00 1.00 CASE P INT1 11:00 - 15:00 4.001 CASE P INTi 15:00 - 16:00 1.00 DRILL P INT1 16:00 - 17:00 1.00 CASE P INT1 , 17:00 - 18:00 1.00 CASE P INT1 18:00 - 19:00 1.001 DRILL P PROD1 19:30 - 20:30 10.00 ~ DRILL P PROD1 20:30 - 23:30 I 3.001 DRILL I P I I PROD1 123:30 - 00:00 0.50j DRILL P ~ PROD1 111/4/2006 00:00 - 05:30 5.50; DRILL P ; PROD1 05:30 - 07:00 I 1.50! DRILL I P I I PROD1 07:00 - 11:30 I 4.501 DRILL I P I I PROD1 11:30 - 13:00 1.50j DRILL P PROD1 13:00 - 18:00 5.00 DRILL P PROD1 18:00 - 20:00 2.00 CASE P RUNPRD 20:00 - 21:30 1.50 CASE P RUNPRD 21:30 - 22:00 I 0.501 CASE I P 22:00 - 22:30 0.50 CASE P 22:30 - 00:00 1.50 CASE P 1/5/2006 00:00 - 00:30 0.50 CASE P 00:30 - 01:30 1.00 CASE P 01:30 - 02:00 0.50 CASE P 02:00 - 05:00 3.00 CASE P 05:00 - 07:00 2.00 CASE P 07:00 - 08:00 1.00 CASE P 08:00 - 10:00 2.00 CASE P 10:00 - 10:30 0.50 CASE P 10:30 - 18:00 7.501 CASE P 18:00 - 18:30 0.50 CASE P 18:30 - 19:30 1.00 CASE P 19;30 - 21:00 I 1.50 CASE P Change top rams. RU & test top rams- 250 low- 4500 high. Pull test plug- Install wear ring. Install bales & elevators- Mobilze BHA Make up BHA- Shallow test MWD Service rig- Slip & cut drlg. line RIH w/ 4" DP- Wash last stand down- tag F.C. at 8684'. Drill F.C. & cement to 8766' (2' above shoe). Circ. & condition mud f/displacement PJSM- Pump HV sweep- Displace well w1 10.0 ppg LSND mud. Drill out shoe- Clean out 8 1/2" rathole to 8773'- Directional drill 20' new hole to 8793'. Circ bottoms up Rack back one stand, rig up for FIT test, 10# mwt, 1400 psi, 6713 tvd= 14# EMWT, good test, blow down, choke lines Drilling 8793 to 8892' with 250 gpm, 1900 psi, 80 rpms, Cross fault @ 8895'+- hole, starting seeping 15-20 bbls hr., AST 2.25, ART 0 Circ mix LCM pill, while Geologist reviews log, called town Drilling 8892' to 9024 with 250 gpm, 1900 psi, 80 rpms, Mud loss slowed to 3-5 bbls hr. CBU 1 x per geologist- No sign of sand or cap rock upon BU. CBU 1 x to ensure hole clean. Directional drill f/ 9024' to 9038'- PU & flow check (Geo. talking w/ Anchorage office). Continue drilling f/ 9038' to 9180' Circ two bottoms up with 80 rpms, 300 gpm, 2440 psi Drilling 9180' to 9430' TD with 300 gpm, 2700 psi, 80 rpms Circ three bottoms up with 80 rpms, 300 gpm, 2400 psi Pumping out to Csg shoe ~ 8768 with full drilling rate, tight had to back ream 9200 to 9085, packing off from 8882' to 8765' RUNPRD Circ bottoms up from csg shoe with 300 gpm 2300 psi, no increase in cuttings at shaker RUNPRD RIH washed last stand to bottom RUNPRD Circ three bottoms up with 80 rpms, 300 gpm, 2400 psi RUNPRD Finish circ three bottoms up RUNPRD Pump out to csg shoeC~ 8768 with full drilling rate, no problems RUNPRD Circ. bottoms up CS csg shoe with 300 gpm 2300 psi, 60 rpms RUNPRD Flow check, pump slug, POH to Bha RUNPRD Laying down Bha RUNPRD Rig up to pick up 3.5 liner RUNPRD PJSM w/ all personel associated w/ task- Run 25 jts. 3 1/2" 9.2# L-80 IBT-M Liner, Flex-Lock hanger & "C2" ZXP Liner Top Packer- Fill every 5 jts.- RUNPRD Change elevators- RD casing tongs- PU 1 stand 4" DP- Circ. casing volume + RUNPRD RIH w/ liner on 4" DP 90 sec. stand (Fill every 20 stds.) to 8697' (71' above 7" shoe). RUNPRD Circ. DP & casing volume. RUNPRD Rih to 9370' with liner, P/u two singles, pick up cement head RUNPRD Wash liner to bottom, 9430', circ and reciprocate 20', with 6 bbls min. 1500 psi, PJSM with cementers, top of liner 8608, landing collar 9364, shoe 9430' Printed: 1/9/2006 9:41:41 AM • BP EXPLORATION Page 8 of 9 Operations Summary Report i,Legal Well Name: MPC-28A (Common Well Name: MPC-28A Spud Date: 12/18/2005 (Event Name: DRILL+COMPLETE Start: 12/18/2005 End: (Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 ',Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations ~i 1/5/2006 21:00 - 21:30 0.50 CEMT P RUNPRD ~ Cement with Schlumberger ' S bbls water I test lines 4000 psi i, 10 bbls CW-100 ~ 20 bbls Mud push @ 12.5 33.7 bbls, 157 sxs Class G, mixed 15.8 ,drop dart test isolation valve to 500 psi, washed lines i ~ Kicked out plug with 6.6 bbls 9.6 KCL water cement job was pumped 6 bbls min. reciprocate 20 ft., full ~ returns 21:30 - 22:30 ~ 1.00 CASE P RUNPRD i Displace with rig pumps 6 bbls min. with 91 bbls mud, bump !plug with 3500 psi to set hanger, full returns thru out job, ' i reciprocate 20' till just before plug bump, float held, pressure I ~i up on liner with 1000 psi, and pull out of liner, pump cement up hole 20 bbls, set down on liner top packer to set same, 22:30 - 23:00 i 0.50 CASE P j RUNPRD Circ 9 bbls min. 2100 psi to clear well of excess cement, total ' ~ of 5 bbls good cement to surface. 23:00 - 23:30 'i 0.50 CASE P RUNPRD lay down cement head 23:30 - 00:00 i 0.50 CASE P RUNPRD ~ Circ bottoms up, reciprocate pipe 9 bbls min. 2100 psi 1/6/2006 00:00 - 01:00 ! 1.00 CASE P RUNPRD (laying down 8 stands drill pipe 01:00 - 04:30 ~ 3.50 CASE P RUNPRD Poh with running tool, lay down same 04:30 - 05:30 j 1.00 BUNCO RUNCMP Rig up to pick up 2 1/16 pipe 05:30 - 06:30 ~ 1.00 BUNCO RUNCMP Picking up 6 jts 2 1/16 pipe and 7" csg scraper 06:30 - 10:30 I 4.00 BUNCO RUNCMP Rih with scraper and stinger to 8786'. 10:30 - 11:00 ~ 0.50 BUNCO RUNCMP Circ. bottoms up. 11:00 - 13:00 2.00 BUNCO RUNCMP RU & test casing to 4000 psi f/ 30 min.- OK, blow down choke lines 13:00 - 15:00 2.00 BUNCO RUNCMP Displace well with sweeps and 500 bbls seawater, 10 bbls min. + 2850 psi, reciprocate pipe 15:00 - 17:00 2.00 BUNCO RUNCMP Reverse Circ well with 300 bbls seawater, 7 bbls min. 1540 psi I 17:00 - 18:00 1.00 BUNCO RUNCMP Slip and cut drilling line, service top drive 18:00 - 00:00 6.00 BUNCO RUNCMP Lay down 4' drill pipe 1/7/2006 00:00 - 00:30 0.50 BUNCO RUNCMP Laying down 2 1/6 stinger 00:30 - 01:00 0.50 BUNCO RUNCMP Pull wear ring 01:00 - 02:30 1.50 BUNCO RUNCMP Rig up to pickup 3.5 TCII tubing 02:30 - 23:00 20.50 BUNCO RUNCMP Picking up 3.5 9.2# L-80 TCII tubing and Baker S-3 packer, test tubing to 4000 psi every 1000 ft for 10 min., total 268 jts 23:00 - 23:30 0.50 BUNCO RUNCMP Tag up @ 8618', space out tubing 23:30 - 00:00 0.50 BUNCO RUNCMP Make up hanger, Test tubing and space out pups to 4000 psi for 10 mins. 1/8/2006 00:00 - 00:30 0.50 BUNCO RUNCMP Finish test tubing and space out pups 00:30 - 03:30 3.00 BUNCO RUNCMP PJSM, rig up slick line unit, pull D-16 plug 03:30 - 04:00 0.50 BUNCO RUNCMP Rig down slick line unit 04:00 -04:30 0.50 BUNCO RUNCMP Picked up landing jt., land tubing with TWC in place, test TWC to 1000 psi 04:30 - 06:30 I 2.00 BUNCO RUNCMP Nipple down BOPS 06:30 - 07:30 1.00 BUNCO RUNCMP Nipple up 3 1/8 tree and adapter 07:30 - 08:00 0.50 BUNCO RUNCMP Test tree and adapter 5000 psi, for ten min. 08:00 - 09:00 ~ 1.00 BUNCO RUNCMP Pull TWC, rig up to pump down annulus, taking returns up tubing 09:00 - 10:30 1.50 BUNCO RUNCMP Pumped down annulus with 160 bbls treated seawater, and 90 bbls of diesel for freeze protection, Printed: 7/9/2006 9:41:47 AM ,, BP EXPLORATION Page 9 of 9 Operations Summary Report Legal Well Name: MPC-28A Common Well Name: MPC-28A Spud Date: 12/18/2005 Event Name: DRILL+COMPLETE Start: 12/18/2005 End: Contractor Name: DOYON DRILLING INC. Rig Release: 1/8/2006 Rig Name: DOYON 14 Rig Number: Date. From - To Hours Task Code NPT Phase Description of_Operations' 1/8/2006 10:30 - 11:30 1.00 BUNCO RUNCMP Rig up and let diesel u-tube to tubing 11:30 - 13:30 ( 2.00 BUNCO RUNCMP Drop ball and rod, pressure up on tubing to 4000 psi to set packer, test tubing for 30 min. 13:30 - 14:00 0.50 BUNCO RUNCMP Bleed pressure on tubing to 1500 psi, pressure up on annulus to 4000 psi, for 30 min. 14:00 - 15:00 i .00 BUNCO RUNCMP install BPV, secure tree, suck out cellar, release rig @ 15:00 1 /8/2006 Printed: 7/9/2006 9:41:41 AM riF.C:~ANICAL INTEGRITY R~.PORT ~~UD D^__I: ~ 1~.Ia`~,'O~ OPER ~ FIELD ~~ ~i~~ \~d~~\~ =_.G rS~I~~~. ~ ~l~s--OCR r~LL NUMBER ~\ ~~~~~ .~ ~ LL DAT ~_ TD : ~''~~t~'.,?~.. TVD ; ?BTD : ?~ TVD Casing: ~`l Shoe: ~~~,~ MD TVD; liV: ~ ~, ?-fD T~~?i -==~e= ~ ~ :5 Shoe : ~-~,~~(~ '~D T`JT ; ~'CP : rZS ~.~ .'';D ~~o'--='~ PaCiCe?' ~ TVD; Set at ole S,~e p ~`a and ; Perfs to c1~-~-~~. G~ ~O~'`~ _~Ci?~?~=CST, INTEGRITY - P?..RT #1 '.-~'CH~NIC~~ INTEGR?TY - p~,T # 2 , ~~ ~~` 5 Cement Volumes :~ ~.mt. Liner ~ J~~;X ; Cs~ ~ ~ ~--F ; DV C:~t -ro1 to cover ~er.s ~-~~.~.5 ,~~-~~~, ~;,~~°~~`~~~` -E-o ~~~ - ~- ~ 5 __:eoretical TOC ~ a~~~ C`_l~ ~G.~^ ~i C` Cement Bond Log (Yes or No) 1L5 In AOGCC File ~ ~ CBL Evaluation, gone above perfs ~_~\~~~ ~~~~~ S~j'~~ f ~ Production 'Log: "?~yoe Evaluation ~CONCLJS~ONS: Part #1: ?ar~ f2: cnnulus Press Test: _? i5 nin ~0 min STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: BPX FIELD /UNIT /PAD: ACT! 1 Milne Point / C-Pad DATE: 03/24/06 OPERATOR REP: Mark O'Malley AOGCC REP: Jeff Jones Packer Depth Pretest Initial 15 Min. 30 Min. Well MPC-28AI Type Inj. W TVD 6,498' Tubing 2,900 2,900 2,900 2,900 Interval I P.T.D. 2051630 Type test P Test psi 1625 Casing 800 1,825 1,800 1,800 P/F P Notes: Pumped 1.1 Bbls of diesel to pressure upon annulus OA 100 225 240 240 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes 1=Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT MPU C-28AI 03-24-06.x1s Re: FW: Injector MPC-28Ai (205-163) • Subject: Vie: FW: Injector MPC-2bAi (20~-16 ~) From: Thomas Maunder <-tom maunder(ci~admin.state.ak.us= Date: ~~"ed, 2? Fch ?006 I ti: l U: -(.)900 1'0: "~~1cLeod, Jennifer D" <Jennifcr.R~lcLa~di~i-bp.com% CC: "Skip Coyner2 (NATCH[Q)" -eo~~rls0(a;BP.com~; Jennifer, I have completed my review of the information you have submitted for MPC-28A (205-163). My assessment is that BP has satisfactorily met the construction requirements for an injection well. You may proceed with the perforation/completion as planned. Call or message with any questions. Tom Maunder, PE AOGCC Thomas Maunder wrote, On 2/22/2006 9:44 AM: Jennifer, I got the information. Just starting to look at it. Thanks, Tom McLeod, Jennifer D wrote, On 2/21/2006 2:27 PM: Tom, l believe the reports you were looking for made it over yesterday afternoon. Nave you seen it? Do you have any questions or need further information? Thanks! Jennifer 564-5764 __ From:. Thomas Maunder [mailto:tornmaunder@admin.state.ak.us] Sent: Monday, February 20, 2006 1:37 PM To: McLeod, Jennifer D Subject: Re: FW: Injector MPC-28Ai Bond Log Thanks Jenifer. McLeod, Jennifer D wrote, On 2/20/2006 9:22 AM: Thanks Tom, I'm following up to find the information for you. Jennifer From: Thomas Maunder ~mailto:tom_maunder@admin.state.ak.us] Sent: Friday, February 17, 2006 10:14 AM 1 of 2 2/22/2006 1:11 PM Re: FW: Injector MPC-28Ai (205-163) • To: McLeod, Jennifer Cc: Ohms, Danielle H; Elmore, Gary O (Schlumberger); Coyner, Skip (NATCHIQ) Subject: Re: FW: Injector MPC-28Ai Bond Log Jennifer, et al, Thanks for sending the log. Since the 407 is yet to be filed, there is further information I need. Could you or one of your colleagues please send the drilling report summaries for the cementing operations on the 7" casing, 4-1/2" liner and any pressure testing that was done when the tubing was run. Thanks in advance. Tom Maunder, PE AOGCC McLeod, Jennifer D wrote, On 2/15/2006 6:18 PM: Tom, Enclosed is the electronic version of our bond log for MPC-28Ai that was drilled in Dec/Jan. This job went as planned and the log reflects good isolation of the injection sands. Perforations will be shot as follows: C sand - 9034' - 9042' MD A3sand-9174'-9188' MD A2 sand - 9196' - 9220' MD There is a section of the log that shows cement bond with the pipe but not with the formation from the top of cement at 8615' to 8765' MD. However, there is good bond from 8765' to the top pert at 9034' MD 0269' MD). Please let me know if you have any questions or see any problems with moving forward on perforation plans. Thanks! «BP_M PC-28Ai_SCMT_14-Feb-06.zi p» ,~ennifer ~l~icLeod MPU Production Engineer 564-5764 2 of 2 2/22/2006 1:11 PM RE: FW: Injector MPC-28Ai Bond Log Subject: RE: F~~': [njcctor MPC-?8Ai Bond Log From: "Coyner, Skip (N,hTCHIQ)" ~=Skip.Coy°ner~~u;Eip.corl>> bate: Fri, 17 Feb 20[)6 11:56:111 -0900 `['o: `Thomas Maunder <tom_maunder(ci~admin.state.ak.tis%, "Elmore, Gary O (Schlumbcrger)" Gary.Llmoretu:bp.com% CC: "F;aman..'lparna (Schlumbers~er)" <ramanapl!c_ianchora;~e.oiltield.sib.can~>, "B_jork. David (BAKER OIL TOOLS)" ~~Da~~id.Bjork(ci,~bp.com> Tom, I believe that this liner cement job has the same 5-6 bbls of "non-cement" between the class cement and the wiper plug as was the case in MPF-89's 3-1/2" liner. We thought we had the procedural risks mitigated but apparently not. This cement job was "saved" by the annular volume in the 6-1/8" hole x 3-1/2" liner. MPF-89 was 4-3/4" x 3-1/2", and therefore, the."non-cement" extended across the entire Kuparuk pay zone. I have asked Baker and Dowell to get with me and to help me figure out what we are doing wrong. ~~ - ~ ~~ Skip Coyner 907-564-4395 BPXA 907-748-3689 cell From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, February 17, 2006 10:30 AM To: Elmore, Gary O (Schlumberger); Coyner, Skip (NATCHIQ) Subject: Re: FW: Injector MPC-28Ai Bond Log Gents, I was looking at the bond log. All in all the log looks pretty good. At the bottom of the hole, the presentation is not as good as up higher. Was the shoe over displaced? I at first thought it might be due to "pick up", but the straight line section is deeper still. Thanks, Tom Thomas Maunder wrote, On 2/17/2006 10:14 AM: Jennifer, et al, Thanks for sending the log. Since the 407 is yet to be filed, there is further information I need. Could you or one of your colleagues please send the drilling report summaries for the cementing operations on the 7" casing, 4-1/2" liner and any pressure testing that was done when the tubing was run. Thanks in advance. Tom Maunder, PE AOGCC McLeod, Jennifer D wrote, On 2/15/2006 6:18 PM: Tom, 1 oft 2/17/2006 I:27 PM RE: FW: Injector MPC-28Ai Bond Log r~ Enclosed is the electronic version of our bond log for MPC-28Ai that was drilled in Dec/Jan. This job went as planned and the log reflects good isolation of the injection sands. Perforations will be shot as follows: C sand - 9034' - 9042' MD A3sand-9174'-9188'MD A2 sand - 9196' - 9220' MD There is a section of the log that shows cement bond with the pipe but not with the formation from the top of cement at 8615' to 8765' MD. However, there is good bond from 8765' to the top pert at 9034' MD (269' MD). Please let me know if you have any questions or see any problems with moving forward on perforation plans. Thanks! «BP_MPC-28Ai_SCMT 14-Feb-06.zip» ,~ennifer ~l~lcLeocf MPU Production Engineer 564-5764 2 of 2 2/17/2006 1:27 PM 1 of 2 ------- Original Message -------- Subject:RE: MPC-28A / 10-401 Date:Wed, 02 Nov 2005 14:46:47 -0900 From:Coyner, Skip (NATCHIQ) <coyns0@BP.com> To:Thomas Maunder <tom maunder@admin.state.ak.us> `~ ~- ~ ~~ Nothing gets by you. Yes, we are attemping to construct amono-drift completion. So we can use EZSV's in the future instead of inflatables. If CTD finishes the well, all that goes away. Skip Coyner 907-564-4395 BPXA 907-748-3689 cell From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, November 02, 2005 2:21 PM To: Coyner, Skip (NATCHIQ) Cc: McVey, Adrienne; Kara, Danny T Subject: Re: MPC-28A / 10-401 Not a problem with the change. If your tubing is 3-1/2 as well, you will have a "monodiameter" conduit from surface to perfs. Note, I specifically didn't use the term "monobore". That is a horse of a different colour. I will put a copy of your note in the file. Nothing further is needed. Tom Coyner, Skip (NATCHIQ) wrote, On 11/2/2005 2:11 PM: We have decided to use 3-1/2" as our production liner instead of 4-1/2". The hole size (6-1/8") and the depths will remain the same. Please change the liner in our APD to 3-1/2", and change the cement volume to 33.5 bbl (161 sx). 95' shoe track, 40% OH excess, 150' lap, 100' above TOL (4" x 7") If you have any questions or comments, please advise. Skip Coyner 907-564-4395 BPXA 907-748-3689 cell p~~~~ , ` t~ eo 2/17/2006 10:09 AM FW: MPC-28A • Subject: FW:MPC-28A;, hrom: "Cr~~~n~r, Ship (NA~I C'I II~>1" ~c0yns0(a~BP.c~~m> llate: Tuc, 01 No~~ 200 13:UU:=~6 -0~)I10 I'o: "i~~1eVe>>, A~~rienrle" <-mcve~~l (ri'BP.coni> ~'C: to~~~ maunder(c~.admin.state.akus Adrienne, Howard apparently used a 9-7/8" hole size for cumputing the intermediate casing cement volume. This is the type of pitfalls that are found in the wonderfull world of cut & paste. Mr. Maunder caught the discrepancy for us. The volume we will m~i`x & ppump is: (1000' x .0226 x 150%) + (85' x .0382) = 3 7 . 2 bbl `/~ S~\o t r°t~/h'7 ~ ~- , `~ ~ ~"~~~5`E ~-~ ~ S Please get with Christine Coyle (X4002) and have her make the changes in Dowell's program. Otherwise, Mr. Maunder sends his compliments on the job you did. Tom, The GR/SCMT/CCL will be run post-rig. Skip Coyner 907-564-4395 BPXA 907-748-3689 cell -----Original Message----- From: Thomas Maunder [mailto:to=r: maur_der~admin.state,ak.us Sent: Tuesday, November O1, 2005 11:17 AM To: Coyner, Skip (NATCHIQ) Subject: MPC-28A Skip, Please pass this message to Adrienne. I don't have her eddress. Skip and Adrienne, Wanted to pass on my compliments on the AOR information in the permit package. That is just what was needed. The well within the 1/4 mile area was identified and an assessment statement made regarding the isolation of that well. That really simplifies the review on this side of town. The only items I have identified are the 7" primary cement volume (> 2000 XS of 1000' of annular fill) and a bond log will be needed on the 4-1/2" liner. Message back with your response. Tom Maunder, PE AOGCC 1 of 1 11/1/2005 1:08 PM • • ,P ~p~ ~ ~ ,~ FRANK H. MURKOWSKI, GOVERNOR ~~ Oiil ~ ~ 33 3 W 7TM AVENUE, SUITE 100 COI~TSERQA7'I011T COMI-iIS5IOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Dan Kara Fax (so7~ 27s-7s42 Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPC-28A BP Exploration (Alaska), Inc. Permit No: 205-163 Surface Location: 837' FSL, 2341' FEL, SEC. 10, T13N, R10E, UM Bottomhole Location: 4531' FSL, 233' FEL, SEC. 09, T13N, R10E, UM Dear Mr. Kara: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission 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. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petrol,~m field inspector at (907) 659- 3607 (pager) . Chairman v~~ DATED this. day of November, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation wf o encl. STATE OF ALASKA ALASKA ~~ AND GAS CONSERVATION CO .,.SSION PERMIT TO DRILL 20 AAC 25.005 it~~CT ~'~ ~. 2~~5 ia. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ^ Development Oil [~ u ip one ^ Stratigraphic Test ®Service ^ Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc.. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: MPC-28A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 9387 s T~/p 7330 12. Field /Pool(s): Milne Point Unit / Kuparuk River 4a. Location of Well (Governmental Section): Surface: 837' FSL 2341' FEL SEC 10 T13N R10E UM ~ 7. Property Designation: ADL 047434 Sands , , . , , , Top of Productive Horizon: 4488' FSL, 220' FEL, SEC. 09, T13N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 20, 2005 Total Depth: 4531' FSL, 233' FEL, SEC. 09, T13N, R10E, UM ' 9. Acres in Property: 2560 14. Distance to Nearest Property: 4440' 4b. Location of Well (State Base Plane Coordinates): Surface: x-558121 ~ -6029119 ' Zone-ASP4 10. KB Elevation (Height above GL): 46.52 feet 15. Distance to Nearest Well Within Pool 1040' 16. Deviated Wells: Kickoff Depth: 5505 feet ~ Maximum Hole Angle: 60 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2860 ' Surface: 2200 i 8. as ng rogram: Size Specifications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 8581' 30' 30' 8611', 6581' sx Class 'G' i 6-1/8" 4-1/2" 12.6# L-80 IBT-M 876' 8511' 6490' 9387', 7330' 108 sx Class 'G' 19. PRESENT W ELL CONDITI ON SUMM ARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 8720 Total Depth TVD (ft): 7361 Plugs (measured): None Effective Depth MD (ft): 8615 Effective Depth TVD (ft): 7265 Junk (measured): 8696 Casin Len th Size Cement Volume MD TVD rl t r 80' 20" 50 sx Arcticset I A rox. 112' 112' 5374' 9-5/8" 1050 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 5405' 4642' r i n 8667' 7" 50 sx Class 'G' 8696' 7339' Pertoration Depth MD (ft): 8242' -8418' Pertoration Depth TVD (ft): 6924' - 7085' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ® Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Adrienne McVey, 564-4184 Printed Name Dan Kara Title Senior Drilling Engineer kip oyner, 564-4395 Prepared By Name/NUmber. Si nature Phone 564-5667 Datet~ a? ~ Sondra Stewman, 564-4750 Commission Use Only Permit To Drill Number: ~Gj ~/ API Number: 50- 029-22648-01-00 Permit Approval Date: ~ «~ See cover letter for other requirements Conditions of Approval: Samples Required ~ Yes ~ No Mud Log Required ~ Yes ~No Hy en Sulfide Measures ~ ;~ Yes ~,No Directional Survey Required Yes ^ No Other: t~~,~-~--~ c~ ~ :~c~.t.~~~©S~ `-~JOO~s~ ~P ~-es~ ~-SQ~.~re~, ~i?`~.~..,~~:ov, vc~e~c~t~ °-~~-h ,o~,~~,1 Li> ov ~'~ :•r•c,~ o Q~~G.~i o e~5 Q ~cc~ ~,~C~ i O ~ . APPROVED BY ~~ A roved B 4 ~ THE COMMISSION Date ~ Form 10-401 Rased 0~4 ~'~.,. ~~ E s ~` ` ~ ~~.~: ~,.. Submit In Duplicate • by • October 26, 2005 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. 7~' Avenue, Suite 100 Anchorage, AK 99501 Re: Application for Permit to Drill MPC-28A Mr. Maunder: Attached please find BP's Application for Permit to Drill [form 10-401 }along with supporting documentation and diagrams as required. MPC-28A is a sidetrack of the MPC-28 who's BHL is fault se ar d from the MPC-28A BHL, and from the producer it was intended to support: MPC-03. An Application for Sundry Approval to plug back the original well bore [form 10-403] was submitted previously and approval is pending.' ~3os-3a~ It is planned to cut and recover 7" casing below the 9-5/8" surface casing. The kick off plug will be set above and below the 9-5/8" casing shoe. The kick off plug serves a dual purpose. This cement plug will be set in accordance with 20 AAC 25.112 (b) to abandon the original hole below the KOP. If you have any questions or require any additional information, please contact the undersigned at 564-4395 or Dan Kara at 564-5667. Sincerely, S ' oyner Drilling Engineer BP Exploration (Alaska) Inc. Well Name: MPC-28A Sidetrack Plan Summary T e of Well: Ku aruk In'ector Surface Location: 837' FSL and 2,341' FEL Section 10, T13N, R10E UM E = 558,121' N = 6,029,119' TKC1 4,488' FSL and 221' FEL Section 9, T13N, R10E UM E = 554,928' N = 6,032,745' Z = 6,876' TVD TD 4,531' FSL and 233' FEL Section 9, T13N, R10E UM E = 554, 914' N = 6, 032, 788' Z = 7, 330' TV D Distance to Pro ert line 4,440' Distance to nearest well 1,040' from MPC-08 AFE Number: Estimated Start Date: Nov 20th 2005 Ri Do on 14 Ri da s to com lete: 16 MD: 9,387' TVD: 7,330' Max Inc: 60° KOP: 5,505' KBE: 51.1' Well Desi n: "S-Curve" with Intermediate Casin & Liner Ob'ective: LD tubing. Cut & pull 7" casing. Sidetrack & drill through KLGM, set 7", Drill to TD. Current Well Information: Well Name: MPC-28 API Number: 50-029-22648-00 Well Type: Kuparuk Ind ctor Current Status: Shut in BHT: 160° F @ 7330' TVD. Mechanical Condition: Tubing: Casing: Well Depth: Kick Off Point: Maximum Angle Wellhead: Tree: BPV Profile: Perforations: Plug Back Fluid: 255 joints of 3-1/2", 9.3#, NSCT. See Current schematic. 8696' MD / 7342' TVD 600' MD 42° at 6797' MD / 5695' TVD 11" x 11" 5M FMC Gen V Cameron 3-1/8" 5M CIW H BPV profile See schematic for details Kill Weight Mud MPC-28A Sidetrack Program Page 3 • Materials Required for Workover Operations: New Equipment 8600' 7", 26#, L-80, BTC-M casing 1000' 4-1/2", 12.6#, L-80, IBT-M Liner 1 Baker liner hanger and ZXP package: assembly # 7 with X-O to 4-1/2" IBT 1 3-1/2" XN Nipple with handling pups [X-O's] 8500' 3-1/2", 9.2#, L-80, TCII tubing 1 Baker 7" x 3-1/2" Premier Packer Re-Built Equipment 1 Tubing Hanger for 3-1/2" TCII tubing 1 3-1/8" x 5M Carbon Tree for MPU Injector Mud Program: 8-1/2" Intermediate Interval (5.505' - 8.371'1 1SNn Dens PV YP H API Filtrate LG Solids 8.6-9.3 ~ 8-15 24-30 9.0-9.5 6-8 <15 8-1/2" Intermediate Interval (8.371' - 8.611'1: LSND Dens PV YP H API Filtrate LG Solids 10.6 - 15-25 24-30 9.0-9.5 5-6 < 15 6-1 /8" Iniectinn Interval (8.611' - 9.387'1: LSNn Densi PV YP' H API Filtrate` LG Solids 11.2 15-25 20-28 9.0-9.5 5-7 <10 Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Casing/Tubing Program: Hole Size Csg / Tb O.D. Wt/Ft Grade CPLG Length Top MD / TVD Bottom MD / TVD 24 20* 91.1 # H-40 Welded 80 32 112 / 112 12-1 /4 9-5/8" 40# L-80 BTC 5,375 31 5,406 / 4,611 8-1/2 7 26# L-80 BTC-M 8,581 30 8,611 /6,581' 6-1/8 4-1/2 12.6# L-80 IBT-M 876 8,511 / 6,490 9,387 / 7,330 ' - 3-1 /2 9.2" L-80 TCII 8,481 30 8,511 / 6,490 " Pre-set MPC-28A Sidetrack Program Page 4 • ~ Cement Program: Casin Size 7", 26#, L-80, BTC-M Intermediate Casin at 8,611' MD Basis 50% Excess, 1000' MD of annular fill above T' Casin shoe. Total Cement Volume: Wash & Spacer 10 bbl water j 40 bbl MudPush 11 3~ ~ ~ ~~ 1 ~ ~ S~ 1l Tail "G" mixed at 15.8 Ib/ al & 1.16 ft /sx Tem BHST ~ 140°F from Schlumber er Chart Casin Size 41/2" 12.6#, L-80, IBT-M Production Liner: from 8,511' to 9,387' MD Basis 25% Excess, 100' liner la , 100' above TOL. Total Cement Wash & 10 bbl water Volume: Spacer 10 bbl CW 100 20 bbl MudPush 11 Tail 22.5 bbl, 108 sx "G" mixed at 15.8 Ib/ al & 1.17 ft /sx Tem BHST - 160°F from Schlumber er Chart Evaluation Program: 8-1/2" Section ~ Open Hole: MWD/GR/RES IFR/CASANDRA S er InSite Cased Hole: None 6-1/8" Section Open Hole: MWD/GR/RES ' IFR/CASANDRA S er InSite Cased Hole: GR/CBVCCL Formation Markers: Formation Tops MD ft TVD ft Pore Pressure si EMW Ib/ al THRZ 8402 6406 2781 8.35 BHRZ 8497 6486 ~~ 2816 8.35 KLGM 8617 6586 2860 8.35 TKUD 8786 6736 2000 5.71 TKC1 8931 6876 2000 5.59 TKUB 8946 6891 2000 5.58 TKUA 9072 7016 2000 5.48 TKA3 9082 7026 2000 5.47 TKA2 9102 7046 2000 5.46 TKA1 9147 7091 2000 5.42 TMLV 9182 7126 2000 5.40 *NOTE: Although abnormally high pressures due to Kuparuk overiniection exist along the original wellbore, this sidetrack is isolated from C-28 by a sealing fault; thus, high pressures are not expected to be encountered. i MPC-28A Sidetrack Program Page 5 U Recommended Bit Program: • BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 8-1/2 5,505' - 8,611' 3,106' PDC .65 - .90 450 - 600 2 6-1/8 8,611' - 9,387' 776' PDC .50 - .75 275 - 350 Well Control: Intermediate/Injection Hole: Maximum anticipated BHP: 2860 psi at 6,586' TVD (KLGM) Maximum surface pressure: 2200 psi (based on a full column of gas at 0.1 psi/ft) Planned BOP test pressure: 4500 psi" ~ Integrity tests: FITs to 12.5 Ib/gal at 9-5/8" shoe, 14 Ib/gal at T' shoe. Kick tolerance: 73 bbl with 10.0 Ib/gal mud at the 9-5/8" shoe. Planned completion fluid: Seawater ~ 'Due to the remote possibility of encountering overpressure (? 4800 psi) in the Kuparuk D sand minus gas gradient to surface yielding a maximum surface pressure of 4130 psi. As it is planned, C-28A is isolated from the original C-28 wellbore (where the overpressure exists) by a sealing fault. Additionally, BP Exploration (Alaska) Inc. ("BP") hereby requests a variance to the provisions of 20 AAC ~ 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this request will not compromise the integrity of the BOP equipment. Hazards and Contingencies: Lost Circulation • Lost circulation is not reported as a major problem for C-pad. However, the Kuparuk A, B, and C sands are expected to be depleted. Good drilling practices must be maintained, and ECD's monitored. Expected Pressures • The intermediate interval is expected to be normally-pressured (8.35 tb/gal EMW). • The Kuparuk A , B, and C sands are depleted down to ±5 ppg EMW. However, the Kuparuk D sand could require > 11 ppg EMW. ~ ~ Pad Data Sheet • Please Read the C-Pad Data Sheet thoroughly. Hydrocarbons • Hydrocarbons will be encountered in the Kuparuk A, B, and C sands. MPC-28A Sidetrack Program Page 6 • ~ Faults The well path should not intersect any faults. Four (4) faults were mapped in the original wellbore: Faults #1 and #2 are at 6,736' TVD (TKUD), and Faults #3 and #4 are at 7,126' TVD (TMLV). It is important to stay within the target polygon to avoid these faults and to put the BHL in the intended fault block. Hydrogen Sulfide • MPC Pad is not designated as an H2S Pad. C-Pad wells < 10 ppm H2S on the 2004 report. Anti-collision Issues • MPC-28A passes the Major Risk Criteria except for the MPC-28 original wellbore. This wellbore will be plugged and abandoned. Distance to Nearest Property • MPC-28A. is 4,440' from the nearest Milne Point property line. ~ Distance to Nearest Well Within Pool • MPC-28A is 1,040' from the Kuparuk sand penetration in MPC-08. ~ Area of Review: Another well, MPC-08, penetrates the Kuparuk reservoir within aquarter-mile of the MPC- 28A penetration. The wellbores are separated by sealing faults. MPC-08 is a shut-in -~ injection well. A casing sketch of the C-08 wellbore, including cement heights and volumes, is included in this packet. Additional items to note: • An LOT to 12.2 Ib/gal was performed at the 9-5/8" shoe. • The 7" x 9-5/8" annulus was used for disposal of drilling fluids and cuttings, and then subsequently downsqueezed with 33 bbl of Permafrost "C" cement followed by Arctic Pack. MPC-28A Sidetrack Program Page 7 • • SCOPE OF WORK Plug Back: 1. RU SLU. Seta "Pump Through" plug in the XN nipple at 8106' MD. 2. RU Schlumberger. Mix and pump 20 bbl (97 sx) class G and displace to ±7979' MD. 3. RU E-Line. Cut the 3-1 /2" tubing as deep as possible. Sidetrack O erations: 4. MIRU Doyon 14. Circulate kill weight mud. 5. ND tree. NU and test BOPE. 6. LD 3-1 /2" tubing. 7. Set a CIBP in the 7" casing at ±5550' MD. 8. Cut and pull the 7" casing > 50' below the 9-5/8" shoe. 9. Spot a balanced cement plug from the 7" CIBP up into the 9-5/8" casing. 10.Sidetrack the well with an 8-1/2" bit and directional drilling BHA. 11. Drill the intermediate hole through the HRZ. 12. Set and cement 7" casing with 1000' of annular fill and 50% excess. 13. Drill a 6-1/8" hole to TD at ±9387' MD (Miluveach). 14. Set and cement a 4-1 /2" liner. ~~~ ~ ~~ ~~ 15. Run a 3-1/2" injection completion with a 7" x 3-1/2" Packer. 16. Set BPV. RDMO. ~~t ` Note: if abnormal pressure is encountered below the 7" casing, the 4-1/2" liner will be set high - as a drilling liner. In this event, CTD will finish drilling below the 4-1/2" drilling liner. Application for Sundry Approval for plugging back MPC-28 was submitted previously MPC-28A Sidetrack Program Page 8 Tree: 3 1/8" 5M Wellf~ead: FMC 11" x 1 , C-se-t-5-av~ 11" x 3.5" FMC Tbg. Hnr. w/ NSCT threads top and bottom and 3" CIW H BPV profilE 20" 91.1 ppf, H-40 115' KOP @ 600' Max. hole angle = 38 to 42 deg. f/ 2700' to 7100' Hole angle thru' perfs = 24 deg DLS = 4.3 deg./100' @ 1500' 9 5/8", 40#/ft, L-80 Btrc. 5405' r 7" 26 ppf, L-80, NSCC production ( drift ID = 6.151", cap. = 0.0383 b 3 1/2" NSCT TUBING 9.2# L-80 I.D. 2.992" CAP ,00870 BBLS / FT Stimulation Summary 08/06/96 -High pressure breakdi step rate test -Three stages, 2i linear gel, 884bb1. total, 3020 Ib ppg 20-40 sand scour in second Perforation Summary Ref log; SBT / GR / CCL 04/16 Size SPF Interval (TVD) 'C' Sand 3 3/8" 6 8242' -8266' (6925'-6! 'B' Sand 3 3/8" 6 8306' -8318' (6983'-6S 3 3/8" 6 8328' -8338' ' ' (7004'-7( 3 3/8" 6 Sand A 8378' 8418' (7049' -7~ 21 gm AlphaJet charges (EHD = TTP = 22.8") @ 60 deg. phasing initial SBHP 4/16/96 = 3015 psig @ 8398' (7069' TVD) Fish: half of a centralizer arm (6" 1.25" x 0.5") from anAtlas SBT - 4/16/96 ~F Elev. = 46,5' (N 22E) O GL Elev. = 16.8' RT To Tbg. Spool = 28.8' (N 22E) reeze protected with 75 bbl of diesel 0.3 ppg LSND mud below 2660` MD BAKER 7" SAB PACKER 3 1/2" "XN" NIPPLE 2.750" NO GO 8079' MD 8106' MD ~ 7" marker joints from 8071' wlm to 0' wlm w/ RA marker at 8071' wlm - 3 1/2" 8117' MD WLEG ' float collar (PBTD) i float shoe 8616' and 8696' and DATE REV. BY COMMENTS 2 / 23 / 96 JBF Surface Hole Drilled and Cased by N22e 4 / 10 / 96 JBF Production Hole Drilled and Cased 4 / 22 / 96 JBF Wellprepped for RWO. 5/16/96 WRR COMPLETION POLAR__R_IG #1 MILNE POINT UNIT WELL MPU C - 28i API NO: 50-029-22648 BP EXPLORATION MPU C - 28i Current Tree: 3 1/8" 5M ~AFeN#~ead: FMC 11" x 1 , Geir~~vr- 11" x 3.5" FMC Tbg. Hnr. w/ NSCT threads top and bottom and 3" CIW H BPV profile 20" 91.1 ppf, H-40 115' KOP @ 600' Max. hole angle = 38 to 42 deg. f/ 2700' to 7100' I~ Hole angle thru' perfs = 24 deg DLS = 4.3 deg./100' @ 1500' 9 5/8", 40#/ft, L-80 Btrc. 5405' and MPU C - 28i Pluq Back 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 3 1/2" NSCT TUBING 9.2# L-80 I.D. 2.992" CAP .00870 BBLS / FT ~DF Elev. = 46.5' (N 22E) GL Elev. = 16.8' RT To Tbg. Spool = 28.8' (N 22E) Freeze protected with 75 bbl of diesel 10.3 ppg LSND mud below 2660' MD 1. RU SLU. Set "Pump-Thru" Plug in XN nipple at 8106' MD 2. RU Schlumberger. Mix and pump 20 bbl class "G" (97 sx). Displace with 61.5 bbl of Hi-Vis brine. 3. RU E-Line. Jet Cut tbg +/- 7800' MD 4. RURT. Circulate with KWM. BAKER 7" SAB PACKER XN 3 1/2" "XN" NIPPLE 2.750" NO GO 8079' MD 8106' MD 8117' MD I Pertoration Summary 8242' -8266' (6925'-6947') 8306' -8318' (6983'-6994') 8328' -8338' (7004'-7013') 8378' 8418' (7049' -7085') 7" float collar (PBTD) 8616' and 7" float shoe 8696' and DATE REV. BY COMMENTS MILNE POINT UNIT 2 / 23 / 96 JBF Surface Hole Drilled and Cased by N22e WELL MPU C - 28i 4 / 10 / 96 JBF Production Hole Drilled and Cased API NO: 50-029-22648 4 / 22 / 96 JBF Well ed for RWO re p pp . 5/16/96 WRR COMPLETION POLAR RIG #1 BP EXPLORATION AK Tree: 3 1/8" 5M Wellhead: FMC 11" x 1 , Gen. 5 w/ 11" x 3.5" FMC Tbg. Hnr. w/ NSCT threads top and bottom.and 3" CIW H BPV profile 20" 91.1 ppf, H-40 115' KOP @ 600' Max. hole angle = 38 to 42 deg. f/ 2700' to 7100' Hole angle thru' perfs = 24 deg DLS = 4.3 deg./100' @ 1500' 9 5/8", 40#/ft, L-80 Btrc. 5405' and M P U C - 281 ~F Elev. = 46.5' (N 22E) De-Complete O GL Elev. = 16.8' RT To Tbg. Spool = 28.8' (N 22E) 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) Kill Weight Mud Freeze protected with 75 bbl of diesel 10.3 ppg LSND mud below 2660' MD 1. LD 3-1/2" tubing. 2. Seta 7" CIBP at ±5500` MD 3. Cut & pull 7" casing at ±5465' MD. 4. Spot a 30 bbl (167 sx) balanced plug from 5500' to 5125': "G" + CaCl2 mixed at 17 ppg & 1.01 cf/sk. 5. Pull 5 stands. Squeeze ±5 bbl away. BAKER 7" SAB PACKER 3 1/2" "XN" NIPPLE 2.750" NO GO 8079' MD 8106' MD 8117' MD I Perforation Summary 8242' -8266' (6925'-6947') 8306' -8318' (6983'-6994') 8328' -8338' (7004'-7013') 8378' 8418' (7049' -7085') ~"~ 7" float collar (PBTD) 8616' and 7" float shoe 8696' and DATE REV. BY COMMENTS MILNE POINT UNIT 2 / 23 / 96 JBF Surface Hole Drilled and Cased by N22e . WELL MPU C - 28i 4 / 10 / 96 JBF Production Hole Drilled and Cased API NO: 50-029-22648 4 / 22 / 96 JBF Well re ed for RWO p pp . 5/16/96 WRR COMPLETION POLAR RIG #1 BP EXPLORATION AK Tree: 3 1/8" 5M Wellhead: FMC 11" x , Gen. 5 w/ 11" x 3.5" FMC Tbg. Hnr. w/ NSCT threads top and bottom.and 3" CIW H BPV profile 20" 91.1 ppf, H-40 115' 9 5/8", 40#/ft, L-80 Btrc. 5405' me 7" 26 ppf, L-80, BTC-M casing ( drift ID = 6.151", cap. = 0.0383 bp1 3 1/2" TC-II TUBING 9.2# L-80 I.D. 2.992" CAP .00870 BBLS / FT TOL at +/- 8460` r BAKER 7" x 41/2" LNR HGR & Z Kuparuk Perfor Kuparuk Perfor DATE I REV. BY I COMMENTS DF Elev. = 46.5' (N 22E) GL Elev. = 16.8' RT To Tbg. Spool = 28.8' (N 22E) Sidetrack below 9-5/8" Casing Proposed KOP = 5410` and 8079' MD 8106' MD 3AKER 7" Premier Packer 1/2" "XN" NIPPLE 3 1/2" WLEG 8117' MD I shoe 8611' and I 1/2" Liner Shoe 9387' and MILNE POINT UNIT WELL MPC - 28A API NO: 50-029-22648-01 MPC - 28A •-• • C PAD MoN c_1 N m ^ 19 ~ n 0 4 ^ ^ 3 ~ v a 2 ^ ^ 17 25^ -~- 9 ^ ^ t I 26 ^ ^ Zt 23 w 7^ ^'11 t0 ^ ^ 13 26 -~- w 20 8 ^ ^ 14 6 ^ ^ 15 5 s ~ 22 18 ^ ^ .12 ® MON C-2 LEGEND -~- As-Built Well ^ Existing Welt B Pad Monument NOTES 1. Dote of Surrey: January 23-24, 1996. 2. Reference Field. Book: MP96-01 (pg. 11) MP96-02 (pg. 33-34). 3. Alosko State Plane CoordPnotes ore Zone 4, .Alosko, NAD 27. 4, Pod scale factor is 0.99990385. 5. Horizontal/vertical control is based on monumQnts MPU C-1 and MPU C-2. 6. Elevations area based on Milne Point Datum M.S,L. f- 1"IVC GYJ 1 p ~ SIMPSON :LAGOON„~? v iPROJECT ' ! LOCATION 7 ! ~ 3 r P,AO C ~~ ~ i G , al ~ ~' •~: 1 `~ R ~ ~PA9+ 1~ • 1 a, .~.1 6666 ~--, ' ^ ^ ~~ ~ ~ C~ , CfP ~CiNITY MAP N.T.S. ~P~E..01= ..q<,95~ ~:. ,a.'49 TMI `~~ r .. ~~ _•F. ROBERT BEIL • . ~ s 3252-S .,-~ ~'fS51 p~iA~ ~~ SURVEYOR'S CERTIFICATE 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND UCENSEO TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT TH15 PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION ANp THAT ALL DIMENSIONS AND OTHER pETAILS ARE CORRECT AS OF JANUARY 24. 1996. I [X`G T'GN W7TUlat GGAty w ntrn ccn . WELL A.S.P: PLANT GEODETIC GEODETIC CELLAR~' ~ SEC ON NO. COORDINATES COORDINATES POS1T10N(DMS) POSITION(O.DD) BOX ELEV- OFFSETS 28 Y° 6.029,119.19 X N, 1667,89 70.29'24.619" ' ' 70.4901719' 16 8' g37' FSL m 558 120.96 ~ E. 600.69 149'31 29.563 149.5248785' . 234t' FEL i r. iwucr~ - _ ~~ o , . ~~ BP E~PLQRATION I ,w „o; `~/°~ M1LNE POINT UNIT C-PAD ~~~ ~a AS-BUl~T CONDUCTOR .,o o. ~ ••-- ~w" t-~• WELL C-28 , , .r ..._. .... COMPANY DETAILS tl[J ~~ ~ BP Amoco Celcuhtion Metlvd MlrmmnCwwnve Emx S s¢m: ISCW5 4 1 y . Scan M<dlod: Trav Cylrt~r Nonh Error Surface: Elliptcal~Cacvg WemivR Mcthod Ruka Bead REFERENCE INFORMATION SURVEY PROOR4M Plan: MPC-28A wp03 (1viPC-28/PIBO MPC-28A) CooNimm (W E 1 Retererce: Well Ce+me: MPC-2& Tme NoM Vemrel (NDI Re(erena: 16.6~34J 51.10 Depth Fm Depth T o Surusy/Plan Tool CRBted By: Troy lakaboaky (jalut0~a bp.cod-7e: 9/21/2005 Salim IVSl Rcfercwce: Sbt-2R(O.OON.O.ODE) Measured Depth Rcfcmce: 16.R-745 51.10 Sco5.00 938727 PWnrd: MlC-2RA wp07 V30 MWDHFR-MS ~~~~~ ~te~ Celcu vion Method: Mm®uv Cwveoue Reviewed: Det<: SECTION DETAR,S Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 5505.00 38.76 307.00 4721.48 1445.69 -1905.75 0.00 0.00 2338.80 2 5555.00 40.15 309.27 4760.09 1465.32 -1930.73 4.00 47.00 2369.97 3 6219.10 60.24 332.33 5186.42 1863.27 -2235.79 4.00 49.49 2870.60 4 7689.69 60.24 332.33 5916.45 2993.88 -2828.58 0.00 0.00 4114.29 .48?VU ~ 5 8370.69 33.00 333.00 6379.82 3429.13 -3054.30 4.00 179.20 4591.45 : ~ ~ ~ 6 8610.69 33.00 333.00 6581.10 3545.59 -3113.64 0.00 0.00 4718.44 MPC-28A TI 7 8630.69 33.00 333.00 6597.87 3555.30 -3118.59 0.00 0.00 4729.02 i 8 8976.49 5.44 343.48 6921.30 3656.91 -3166.95 8.00 177.87 4837.59 9 9187.23 5.44 343.48 7131.10 3676.07 -3172.63 0.00 0.00 4855.82 MPC-28A T2 { { 14 ' _i-.-~.1-..L.1. - - ~ [ 10 9387.23 5.44 343.48 7330.20 3694.26 -3178.03 0.00 0.00 4873.13 TARGET DETAQ.S Name TVD +N/-S +E/-W Northing Fasting Shape MPC-28A TI 6581.10 3545.59 -3113.64 6032640.00 554980.00 Point MPC-28A T2 7131.10 3676.07 -3172.63 6032770.00 554920.00 Point c g L c u m u v 2 F Nurc ~hL'S -E/-W Nathvg FiWry lado~ l.atyode Sbt MPC~26 1771.11 16.]5 60NI19.19 558120.% 70'29R/.619N II7°JI29361W 28 916.45TVD CASWG DETAILS ' No. TVD MD Name Sim 1 6581.10 8610.69 7" 7.000 -. ~ 2 7330.10 9387.13 41/2" 4.500 7330.2' TVD I I I ~ FORMATION TOP DETAQ,S No. TVDPath MDPath Formation 1 6381.10 8372.22 THRZ 2000 2500 3000 3500 4000 4500 Vertical Section at 319.30° [SOONin] ~ i Sperry-Sun BP Planning Report Sperry-Sun BP Planning Report Company: BP Amoco laieldi Milne Point Site: M Pt C Pad Well: MPC-28 ~ 'Nelipatti: Plan MPC-28A Survev Date: 9/21/2005 Timr. 15::18:0'? Page: ? Co-ordinate(\'E) Reference: V'/ell: MPC-28, True North Vertical (111) ucferencr. 16.8+34.3 51.1 Section (~'ti) Reference: Well (Q.OON,O.UOE.319.30Azi) Sarvev Calculation ~1c0iod: Minimum Curvature Db: Orade 111D ft 'lncl deg Azlm deg TVp ft SySTVD ft VS ft N/S ft Fi~~~ ft DLS deg/100ft MapN' ft ~lapB ft fooUComment 5505.00 38.76 307. 00 4721.48 4670.38 2338.80 1445.69 -1905.75 0.00 6030549.81 556204.16 Start Dir 4/100 5555. 00 40.15 309. 27 4760.09 4708.99 2369.97 1465.32 -1930.73 4.00 6030569.23 556179.03 MWD+IFR+MS 5600. 00 41.33 311. 35 4794.19 4743.09 2398.97 1484.32 -1953.11 4.00 6030588.06 556156.49 MWD+IFR+MS 5700. 00 44.10 315. 61 4867.67 4816.57 2466.43 1531.02 -2002.26 4.00 6030634.36 556106.99 MWD+IFR+MS 5800. 00 47.00 319.46 4937.71 4886.61 2537.75 1583.70 -2050.39 4.00 6030686.66 556058.46 MWD+IFR+MS 5900. 00 50.03 322. 96 5003.95 4952.85 2612.58 1642.10 -2097.25 4.00 6030744.69 556011.14 MWD+IFR+MS 6000. 00 53.15 326. 16 5066.09 5014.99 2690.57 1705.94 -2142.63 4.00 6030808.17 555965.27 MWD+IFR+MS 6100. 00 56.34 329. 10 5123.81 5072.71 2771.34 1774.91 -2186.30 4.00 6030876.79 555921.06 MWD+IFR+MS 6200. 00 59.61 331. 83 5176.84 5125.74 2854.48 1848.67 -2228.05 4.00 6030950.21 555878.74 MWD+IFR+MS 6219. 10 60.24 332. 33 5186.42 5135.32 2870.60 1863.27 -2235.79 4.00 6030964.75 555870.89 End Dir :6219 6300. 00 60.24 332. 33 5226.58 5175.48 2939.02 1925.47 -2268.40 0.00 6031026.69 555837.80 MWD+IFR+MS 6400. 00 60.24 332. 33 5276.22 5225.12 3023.59 2002.35 -2308.71 0.00 6031103.25 555796.89 MWD+IFR+MS 6500. 00 60.24 332. 33 5325.86 5274.76 3108.16 2079.23 -2349.02 0.00 6031179.80 555755.99 MWD+IFR+MS 6600. 00 60.24 332. 33 5375.51 5324.41 3192.73 2156.12 -2389.33 0.00 6031256.36 555715.08 MWD+IFR+MS 6700. 00 60.24 332. 33 5425.15 5374.05 3277.30 2233.00 -2429.64 0.00 6031332.91 555674.18 MWD+IFR+MS 6800. 00 60.24 332. 33 5474.79 5423.69 3361.87 2309.88 -2469.95 0.00 6031409.47 555633.27 MWD+IFR+MS 6900. 00 60.24 332. 33 5524.43 5473.33 3446.44 2386.76 -2510.26 0.00 6031486.03 555592.36 MWD+IFR+MS 7000. 00 60.24 332. 33 5574.08 5522.98 3531.02 2463.64 -2550.57 0.00 6031562.58 555551.46 MWD+IFR+MS 7100. 00 60.24 332. 33 5623.72 5572.62 3615.59 2540.52 -2590.88 0.00 6031639.14 555510.55 MWD+IFR+MS 7200. 00 60.24 332. 33 5673.36 5622.26 3700.16 2617.40 -2631.19 0.00 6031715.70 555469.65 MWD+IFR+MS 7300. 00 60.24 332. 33 5723.00 5671.90 3784.73 2694.28 -2671.50 0.00 6031792.25 555428.74 MWD+IFR+MS 7400. 00 60.24 332. 33 5772.65 5721.55 3869.30 2771.16 -2711.81 0.00 6031868.81 555387.83 MWD+IFR+MS 7500. 00 60.24 332. 33 5822.29 5771.19 3953.87 2848.04 -2752.12 0.00 6031945.36 555346.93 MWD+IFR+MS 7600. 00 60.24 332. 33 5871.93 5820.83 4038.44 2924.93 -2792.43 0.00 6032021.92 555306.02 MWD+IFR+MS 7689. 69 60.24 332. 33 5916.45 5865.35 4114.29 2993.88 -2828.58 0.00 6032090.58 555269.34 Start Dir 4/100 7700. 00 59.82 332. 34 5921.61 5870.51 4122.99 3001.79 -2832.73 4.00 6032098.46 555265.13 MWD+IFR+MS 7800. 00 55.82 332. 41 5974.85 5923.75 4205.42 3076.77 -2871.98 4.00 6032173.12 555225.30 MWD+IFR+MS 7900. 00 51.82 332.48 6033.86 5982.76 4284.01 3148.31 -2909.32 4.00 6032244.37 555187.41 MWD+IFR+MS 8000. 00 47.83 332. 56 6098.36 6047.26 4358.38 3216.09 -2944.57 4.00 6032311.85 555151.63 MWD+IFR+MS 8100. 00 43.83 332. 66 6168.03 6116.93 4428.16 3279.75 -2977.56 4.00 6032375.26 555118.15 MWD+IFR+MS 8200. 00 39.83 332. 76 6242.53 6191.43 4493.02 3339.00 -3008.13 4.00 6032434.26 555087.12 MWD+IFR+MS 8300. 00 35.83 332. 89 6321.51 6270.41 4552.63 3393.55 -3036.13 4.00 6032488.58 555058.69 MWD+IFR+MS 8370. 69 33.00 333. 00 6379.82 6328.72 4591.45 3429.13 -3054.30 4.00 6032524.01 555040.24 End Dir :8370 8372. 22 33.00 333. 00 6381.10 6330.00 4592.26 3429.87 -3054.68 0.00 6032524.75 555039.86 THRZ 8400. 00 33.00 333. 00 6404.40 6353.30 4606.96 3443.35 -3061.55 0.00 6032538.18 555032.89 MWD+IFR+MS 8500. 00 33.00 333. 00 6488.27 6437.17 4659.87 3491.88 -3086.27 0.00 6032586.50 555007.79 MWD+IFR+MS 8600. 00 33.00 333. 00 6572.13 6521.03 4712.79 3540.41 -3111.00 0.00 6032634.83 554982.68 MWD+IFR+MS 8610. 69 33.00 333. 00 6581.10 6530.00 4718.44 3545.59 -3113.64 0.00 6032640.00 554980.00 MPC-28A T1 8630. 69 33.00 333. 00 6597.87 6546.77 4729.02 3555.30 -3118.59 0.00 6032649.67 554974.98 Start Dir 8/100 8700. 00 27.46 333. 45 6657.73 6606.63 4762.88 3586.43 -3134.31 8.00 6032680.67 554959.01 MWD+IFR+MS 8800. 00 19.47 334. 50 6749.39 6698.29 4801.39 3622.16 -3151.83 8.00 6032716.26 554941.22 MWD+IFR+MS 8900. 00 11.50 336. 93 6845.68 6794.58 4827.01 3646.41 -3162.92 8.00 6032740.42 554929.94 MWD+IFR+MS 8976.49 5.44 343. 48 6921.30 6870.20 4837.59 3656.91 -3166.95 8.00 6032750.88 554925.83 End Dir :8976 9000. 00 5.44 343. 48 6944.71 6893.61 4839.62 3659.05 -3167.58 0.00 6032753.01 554925.18 MWD+IFR+MS 9100. 00 5.44 343. 48 7044.26 6993.16 4848.28 3668.14 -3170.28 0.00 6032762.09 554922.41 MWD+IFR+MS 9187. 23 5.44 343. 48 7131.10 7080.00 4855.82 3676.07 -3172.63 0.00 6032770.00 554920.00 MPC-28A T2 9200. 00 5.44 343. 48 7143.81 7092.71 4856.93 3677.23 -3172.98 0.00 6032771.16 554919.65 MWD+IFR+MS 9300. 00 5.44 343. 48 7243.36 7192.26 4865.58 3686.33 -3175.67 0.00 6032780.23 554916.88 MWD+IFR+MS 9387. 00 5.44 343. 48 7329.97 7278.87 4873.11 3694.24 -3178.02 0.00 6032788.12 554914.47 Total Depth : 9 9387. 13 5.44 343. 48 7330.10 7279.00 4873.12 3694.25 -3178.02 0.00 6032788.13 554914.47 41/2" ~ 9387. 23 5.44 343. 48 7330.20 - 7279.10 4873.13 3694.26 -3178.03 0.00 6032788.14 554914.46 MWD+IFR+MS WELL DEPAIIS Nme +N/S +Fj-W Northing Eaving laGmde Lmgdudc Sld MPC-281771.11 76.75 b029119.19 55tl 120.96 ]0'29^_4.61914 149'31'29.Sfi3W 2g ANTI-COL Interpolation Method:MD Depth Range From: 5450.00 Maximum Range: 1134.60 LISION SETTINGS Interval: 25.00 To: 9360.28 Reference: Plan: MPC-28A wp04 COMPM'V DEfAIiS BP Amoco Gkulmon Method: Mmvnmi C'unvwe Error sync: IscwsA Scan Method: Tnv Cylinder NaM Error Surf EBigirxl +Camig wwmg McsMd: Rules Beeed SURVEY PRCgRAM Depth Fm Depth To $urvey/PW Tool 5450.00 938028 Planrcd MPC-28A ap110Vb MWD~IFR+MS WELLPA1Ti DETAILS 80 From Colour To MD Plan MPC 28A 7S O SOO Pmem We MPC-28 T:or~ilr saw.oo SOO lOpp 33 _ 0 1000 lsoo ReC. Dmm: 16.8+74.7 SLIOR 1500 2000 n s ZOOO ZSOO v section ~ atg tntmg Angle N'S E'-W Fran ND 3 zsoo 3000 319.3 onn nay 343n - 3000 3500 _ - 3500 4000 4000 4500 4500 5000 LEGQ.D 0 5000 SSOO - Mer-0RlMrcoaRM,pra~F -09 M Rek . SSOO 6000 MPC-09IMPC A ajor ~ MPC-171MFC-I]4 Major Rek - 6OOO 7OOO MPC-28 (MPC:287.~ RRORS 30 7000 8000 0 Plsn MPC-28A MPC-ztlA wpa 38 ~o il~ooo 11000 12000 J~ 000 13000 /' / 1000 14000 5 7 0 15000 13 I. I 0 270 ~ 90 13 ` i/ 5 ~~- ,, ~ ;~; ~ i ; 38 L~ ,\ ~_ ~~ . ~ 24 0 120 0 `~ ~~ ~ ~ ,,~; '~ y 3 _,~ ,~, ~~ , _ : 21 _ _ SO ' EC130N DEPAIL9 7S Sec MID Itc Ad TVD S +N/S +FJ-W DLeg TFue VSa Tagn 80 I 5450.0D 3869 )07.15 167855 00 d0 08 N39 72 d71710 2 3500 1424.91 -167836 0.00 0.00 2705.14 00 d7 00 23M 31 1444 71 -1903 14 4 65 . . . 16 59 40 331 73 8128 10 7 6133 . . . . . 182234 -2194 69 4 00 48 73 2612 77 . . , . d 7707.24 59.10 331 ]3 5926.71 . . . . 301108 -2834.07 0.00 0.00 41b.90 5 8367.73 33.00 337.00 63A.82 1429.13 -305/.30 1.00 178.44 459144 6 8603.77 33.0D 333.00 6581.10 354589 -3113.61 0.00 0.00 4]1844 MPC-28A TI ,~ Travelling Cylinder Azimuth (TFO+AZI) [ deg] vs 7 862773 33.00 333.00 6597.87 8 8969.53 5.44 743.48 692130 Centre to Centre Separation [2Sft/in] 9 918018 >a4 141.48 7131.16 10 9780.2tl 5.44 343.48 7730.20 335530 -311859 0.00 0.00 4729.02 )656.91 -1166.95 6.00 17/.87 4837.59 M76.07 -7172.63 0.00 0.00 6855.82 MPC-28AT 369416 717803 0.00 0.00 4817.17 ... H a w 0 0 W N W 2,000 4,000 6,000 8,000 10,000 12,000 M PC-28A Move In Doyon 14 TIME vs DEPTH Rig Up / PU Pipe a) Nu sops. -*- AFE Times b) LD Tubing. c) Cut & LD 7" Casing d) Set Cement Plug -Actual Times a) Time-Drill to Sidetrack b) Drill8-1/2" Intermediate Hole " ' Set 7 Casin g at 8810 Drill 6-1/8" Hole a) Set 4-1 /2" Liner at 9387' MD b) Run the completion c) ND / NU Tree d) RD MORT 10 TIME (days) 15 20 • Area of Investigation Around MPC-28A Target MPC-09 • still MPC-17i > - MPC-42i ' ~ ~ s~ MPC-08i ~r ~ MPC-28A Target -`a ~~ 132' , MPC-03 ~ ', ~ MPC-28i ~G,'r~u~ ~:,.. There are two wells within the area of investigation for MPC-28A: MPC-28 & MPC-08. Both of these wells are fault separated from MPC-28A which MPC-23 is why MPC-28A is needed. Neither - well has supported the MPC-03 producer which has BHP depletion. • • ` ~ ~ ~ ~ WELL No. C-8 ~ CASING SKETCH _ I~IILNE POINT li NIT (I ) A~'; No.: 50-029-21277 PcRMIT Iv o.: 85- i 4 i'aILLED: 2/9/85 ARCTIC PACKED: 3/31/85 OPERATOR: CONOCO INC. SURFACE LOCATION: 780' FSL, 2325' FEL, SEC 10, T13N, R10E, UM BOTTOM HOLE LOCATION: 4794' FSL, 1408' F1h'L, SEC 9, T13ty, R10E, UM SPUD DATE: 01/27/85 U ..r d :=: F ~ ?. _. _ _ Q €:'W ~~: `~. `• 'X !: ; lT 1?r~: FtJ:C CSG SPOOL .. •~ -,~ •:: ;; Y •• 13 3/8", 48~, H-40, SET ®90' U • j, a .. .. U ,: ~/ a ~.%<...;~ ~- 9 5/8", 36~, K-55,._BTRC,~SET ®5887'- -_--- ~~~ ,--_ _ CEMENT DATA: 403 BBLS, 1150 SKS PERMAFRO5 ~ "E". •,'.1~`< i88 BBLS, 920 SKS CLASS "v" CMT W/ i% CaCL, 1 % CFR-2. 7" x 9 5/8" ANtJULU' CEhr,ENT DATA: 35 B°LS, 200 SKS PERMAFROST "C" 1N/ _...0.81 ~/SK SODIUM .CITRATE, .0.48% HAL 9, 60 ?BLS ARCTIC PACK. CMT -ARCTIC PACT: INTERFACE C~ 2019'. 60 BBLS f7.7 PPG) ARCTIC PACK EST TOC ®650G' :}:• `• ~.~ ~;: =?~• `7~ .j CENTRALIZERS: 1 PER 80' 2190-9100' 1 PER 40' 9100'-9585' ECP 929G' ECP 9310' •--- 7", 26#, L-80, BTRC SET @ 9588' CEMENT DATA: 143 BBLS, 700 SKS CLASS "G" CMT 1'./ 1% CFR-2 AND 0.3 % HALA^ 24. PBTD 9508' ~.~.^. ^M .,-...r TD 9620' C4:I000 CONOCO INC. APPRO\cD BY: HDS Di,TE: 1/i9/93 ANCHORAGE DIV;SION _ DRAFTED BY: SJN/CFP C,;:• =1~~: ~':CAC8 f~ MPC-28A Planned Location i~ +t ~C-09 1 i ,~ ~C-07 I C-77 ~~ '~ ~; r 114 Mile Bufrer Kuparuk Reservoir Penetration C-1 ~C-12 '"'/ ~'~~ f4DL047434 - ~ c ~ ; Top Kuparuk j 8976 ft D ~ '• . M ~ ,` C-os I ' ~ x 3~ ;. x ~ i ~, ti . 'x ~ ~C-03 ,~~ ~i ~~ ~~~ K~~. ~ {yv ~ '~C x x ` . r `<< ~~ ~; x, k~l. x 114 Mile Butter ``~„x" c ~ ~ ~ ti'ti ~' ` ~'~ , ,~ Kuparuk Reservoir Penetration ~,~ *`, ~ '`+ ~ ;• ~~ ..: ,.. originial MPC-28 ~` >`~ ~ ~~ ~~ ~ ~ ~ ~,' s ~,. x . , . C 28 - ' .. ~ \ ~ ~ ~ ., y \. \ ' ~ \~. , \ ~ \ `~ _ 4+ ~ _ ~1" ++~.. ~ Well Status Q 1 QQQ 2QQQ Feet M Abandoned Gas Injector Or Gas Producer Shut-In :~ Z,QOQ Miscible Injector Operating ASP Zone 4 NAD 27 Miscible Injector Shut-In ~ Not Yet Completed ! Td Not Yet Reached. o Nu11AJnknown * Oil Producer Flowing ~ Oil Producer Gas Uft Oil Producer Hydraulic Pump ? fLCU Marker PICk ~ Oil Producer Shut-In + MPC-28A wp03 ~r Oil Producer Submersible O Oil Suspended Hydraulic Units ~ Oil well o Plugged Back For Redrill 4 Suspended Water Injector Water Injector Injecting Water Injector Shut-In 4b Water Producer Flowing • • ss-si,zs2 233 TERRfE L NUBBLE BP EXPLORATION AK INC ~~Mastercard Check" ,?j f ~~5 PO BOX 1966'12 MB 7-5 DATE I I ANCHORAGE., AK 99519-66.12 s I~•~ PAY TO THE ------ OROER OF First National. Bank A aska Anchorage, AK 99501 MEMO.~.~` -~ ~ ~~~ ~: L 2 5 2 0 00 6 0 ~: 9 9 L 4 ~~~ 6 2 2 7 ~~~ L 5 5 6 ~~' ' 0 2 3 3 a C • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# ~~~~ ~ ~~ ~~~ ' /~.~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of .the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all (per I records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to i perforate and produce/infect is contingent upon issuance of a conservation order ~ ~ approving a spacing exception. (Company Name) .assumes the liability of any protest to the spacing I exception that may occur. DRY DITCH Alt dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost ~ or from where samples are first caught and ~ i ~ 10' sample intervals through target zones. ~ Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 Well Name: MILNE PT UNIT KR C-28A ___Program SER Well bore seg ^ PTD#:2051630 Company BP EXPLORATION (ALASKA) INC Initial Classffype SER / PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal ^ Administration 1 Permit_feeattached______ ________________.___________ ____-___ Yes_----. -.- - - -- 2 Lease number appropriate____________________ Yes.-_--_ _ 3 Uniquewell.tameandnumber_----- - -- --- -- ------- - ----- YeS----~ - - - --- - -- -- -- - -- --- -- -- ------ -- -- 4 Well locatedin_a_defned.pool______________________________ _________Yes--_-_ _MILNE POINT, KUPARUK RIVEROll.-52.5100, governed by CO 432C____----.--------_-_______ 5 Well located proper diskatcefrom drilling unit_boundary- - - - - - - - - - - - - - - - - - - -Yes - - - - - - .Conservation Orde[ No. 4320 contains no spacing restrictions with respect to drilling unit boundaries. _ - _ _ _ _ _ _ 6 Well located proper distance from other wells- - - - - - - - - - - - - - - - - - - Yes Con_seryation Order No. 4320 has no in_terxell_spacing.restrictions: - - - - - - - - - . _ _ _ - _ _ _ _ - - - - - - - - _ _ 7 Sufficient acreage_available in-tlrilling unit_ _ Yes .. - .. - .Conservation Oder No. 4320 has no itterwell_spacing_restriction_s, Wellbore_will be_more than 500' from - - - - 8 If deviated, is_wellbore plat-included - - . - _ - - _ ... - ... Yes - . - - - - - an external property linewhere-ownership or_landownershp changes. 9 Operator only affected party--------------------- --- _---Yes----- ----------------.----------.-- 10 Operatorhas-appropriate. bond inforcfl------------------------ ---------Yes---_-. --.------._---_---_. 11 Permit-can be issued withoutconservatiotorder---_______________ _________Yes______ ----.---------_--_----------_----.-- -------------------------------- Appr Date 12 Pe[mit_can be issued without administrative_approva_I - - - - - - - - - - - - - - - - - - - Yes _ SFD 11/1/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by-Injection Orde[ # (put1O# in_co mments)_ (For_ Yes Area Injection Order No._ 106_ - - .. - 15 All wells_within 114-mile area_of review identified (For service well only)-- - --- - - - - - - - - -Yes - - - _ .. -Offset wells within 114 mile radius AORare-separated by sealing faults from this_proposed injector.... , . - _ - - - 16 Pre-produced injector_dur_ationofpreproductiotlessthan3motths(Forservicewellonly)__No_______ __________________________________ ____-..----....-.-_.-_-_.-......- 17 AC_M_P_FitdingofConsistetcy.hasbeenissued_fo[thisproject___________ ________NA__----- -Re-drill of existing well,---------.---_-.__---_ __________ ________________-_- Engineering 18 Conductor string_provided - - ... - . - - . - NA_ - - - - - . - Conductor setir original-well MPC-28 (196-029)._ . - ------------------------------- 19 Surface casing_proteclsallknowtUSDWS....--..._.______ ______NA___-_. -Allaquifers exempted 4QCFR147.102-(b)(3)andAEO 2.---.-----____ ___________________ 20 CMT.vol-adequate-to circul_ate_on cord_uctor_& surf_csg _ _ - - . - . - NA_ _ _ _ _ _ _ Surface casing set in_original well._ _ _ _ _ _ _ _ _ _ - - -- 21 CMT.volatlequaie_totie-in long string to surfcsg___________________ _____No____ _Allhydrocarbon zoneswillbe_covered_.-----__.------.-------_--__________--_--- 22 CMT_will coyer all ktown.productiye horizon_s_ _ _ _ _ _ _ _ . . . .. . . .... . . .Yes - .. - - . -Cemented liter completion planted._ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ - - - - - - - - - _ _ - - 23 Casing designsadequafeforC,T,B&-permafrost----------------- -- - Yes------ ------- ---------------------- -...--.----------------------- -- -. 24 Adequate tankage-or reserve pit - - - - - - ---- - - -Yes - - - - _ . Rig is_equipped with steel_pits. No resen!e_pitplanred, All waste to approved disposa~wells._ _ 25 Ifa-re-dill,has-a.10-403forabandotmentbeet approved------------- -_-__-__Yes______ _305-322,approyed10121.____________-__ _-________----- -------_-------_-- 26 Adequate wellboreseporation-proposed- - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - -- Yes - - - _ .. -Proximity analysis performed, Only close wellbore is-original well and courses-diverge.- - - - - - _ - - - - - - - - - - 27 Ifdiverterrequired,doesitmeetregulatiors-------------_______ _________ NA_______ _BOPStack_willalready_t>einplace,_____-_-.__--_-.----__----.--------_--------.- Appr Date 28 Drilling fluidprogram schematic & equip listadequate- - - - - - - - - - - - - - - Yes Maximum expected formation pressure 5,8_EMW in Kuparuk, however up 1-1,0 EMWpossjble. in "D", - - - - - - . _ TEM 111112005 29 _B_OPEs,_do They meet_ regulation _ _ _ _ Yes - - - - - - - ~~In, J1 ' " 30 BOPS-Press rating appropriate; test to_(put prig in comments).. - - - - - - - - - - - - - - - - - - -Yes - - - - - - MASP for Kup calculated_at 2200psi, "D" yields 4130_ psi. 4500 ps_i BOP test planned. ~ J~ ~ ~ 31 Choke_manifoldcompliesw/API-RP-53(M_ay84)------------------- ---------Yes-__--. --_---______-.__---_____.______ _ 32 Work willoccurwhhoutoperationshutdown__________ ___________ _____ ___Yes_.---. ------.--._ - - 33 I& presence of H2S gas_ probable- - - - - - - - - - - - - - - - - - No- - . _ - .. - H2S is utlikely,14ppm max or Cpad.. Mud_ should preclude_on rig._ Rig has sensors and_alarms.. - 34 Mechanical conditiot of wells within AOR verified (For s_eruice well otly~ - - - - - - - - - - - - - -Yes . - - - - 1_ penetration in AOR, howeyer_it_is fault isolated from the planted genetration._ No ot_her_issues. _ - - - _ Geology 35 Permit-can be issued w/o hydrogen_sulfide measures - ... ....... -Yes . - - - - H2S not anticipated in this isolated, depleted_ block. Max H2S observed_ on_C-Pad is <14 pp_m. 36 Data_presented on_ pote_ntial overpressure zones- - - - - . - - - - - Yes Expected reservoirpressure is 5:8-ppg, but there is-some potential-for-overpressure .. . . . . . . .. . . .. . Appr Date 37 Seismic analysis of shallow gas_zones_ _ _ - - - _ - - - ... - NA- - - _ - - _ _ up to 11 ppg it the Kuparuk D as discussed jn_Drilling Hazards sectiot._ - - - - . - - ----------------- SFD 1111/2005 38 Seabedcotditiotsurvey_(ifoff_-shore)_________________________ ________ NA____ 39 - Contact name/phote for_weekly progress-reports [exploratory only]_ NA_ Geologic Engineering P Commissioner: Date: Com missioner: Date C ssio Date ~I C~7~~y~ ~ ~ ~" d `~ ~~ ~ d ,~ • • Well History File APPENDIX Information of detailed nature that is not particularly germane io the Well Permitting Process but is part of the history file. To improve tl~e readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of inforrnaiion. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Jul 30 16:44:59 2007 Reel Header Service name .............LISTPE Date .....................07/07/30 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................ST5 LIS Writing Library. Tape Header Service name .............LISTPE Date .....................07/07/30 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0004108384 C. ZAWADZKI E. VAUGHN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD Scientific Technical Services Scientific Technical Services MPC-28A 500292264801 B.P. Exploration (Alaska) Inc. Sperry Drilling Services 30-JUL-07 MWD RUN 2 MW0004108384 C. ZAWADZKI J. HABERTHUR 10 13N l0E 837 2341 50.20 16.80 OPEN HOLE CASING BIT SIZE (IN) SIZE (IN) 1ST STRING 8.500 9.625 2ND STRING 6.125 7.000 3RD STRING PRODUCTION STRING ~T ~ 2 os- i~3 ~ is3ob DRILLERS DEPTH (FT) 5405.0 8768.0 • • REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE WAS EFFECTED BY DRILLING OFF OF A CEMENT PLUG, THE TOP OF WHICH WAS AT THE 9 5/8" CASING SHOE (5405'MD/4643'TVD) IN THE MPC-28 WELLBORE. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SPERRY-SUN MWD GAMMA RAY LOG RUN IN MPC-28 ON 9 APRIL 1996. BASED ON THE DIRECTIONAL DRILLER'S REPORT, AND LOG RESPONSES, IT APPEARS THAT THE ACTUAL KOP WAS CLOSER TO 9450'MD. CONSEQUENTLY, WELL DATA WERE SHIFTED DOWN TO THIS DEPTH. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. THESE SDC LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 8 MAY 2007, QUOTING AUTHORIZATION FROM MIKIE WEEKS (BP GEOSCIENTIST). THIS LOG IS THE PDCL FOR MPC-28A. 6. MWD RUNS 1 & 2 REPRESENT WELL MPC-28A WITH API#: 50-029-22648-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9430'MD/7339'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 4965.5 9374.0 RPS 5390.0 9381.0 FET 5390.0 9381.0 RPM 5390.0 9381.0 RPD 5390.0 9381.0 RPX 5390.0 9381.0 ROP 5405.0 9430.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 4965.5 4965.5 4967.5 4967.5 4979.0 4980.5 4990.0 4990.5 4996.5 4998.0 5001.5 5002.0 5004.5 5006.0 5008.5 5010.0 5023.0 5026.0 5029.0 5032.5 5033.5 5034.5 5036.0 5037.0 5041.5 5041.5 5043.5 5044.5 5046.5 5049.5 5054.5 5057.0 5056.0 5059.0 5062.0 5063.0 5068.0 5068.0 5070.0 5071.0 5071.0 5072.5 5073.0 5074.0 5092.0 5092.0 5103.0 5104.5 5108.0 5109.0 5111.5 5113.0 5115.5 5116.5 .5117.5 5119.5 5126.5 5126.5 5129.0 5128.5 5132.0 5131.0 5136.5 5134.5 5138.0 5136.5 5139.5 5139.0 5145.5 5147.0 5153.0 5153.5 5156.0 5156.0 5162.0 5160.5 5164.5 5163.5 5170.0 5170.0 5177.0 5177.0 5181.5 5181.5 5192.5 5193.5 5194.0 5196.5 5199.0 5200.0 5201.5 5204.0 5207.0 5210.0 5209.5 5212.0 5215.5 5216.5 5225.5 5226.5 5229.0 5230.5 5235.5 5236.5 5269.5 5268.0 5277.0 5277.0 5280.5 5281.0 5285.5 5287.0 5304.0 5303.5 5312.0 5311.5 5316.0 5315.0 5328.0 5326.0 5338.5 5338.5 5345.0 5345.0 5353.5 5354.5 5360.5 5362.0 5390.0 5390.0 5408.0 5409.0 5418.5 5419.0 5429.5 5430.5 5435.5 5436.0 5439.5 5439.5 5445.0 5445.0 5446.5 5446.5 9430.0 9430.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 4965.5 8774.0 MWD 2 8774.0 9430.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 4965.5 9430 7197.75 8930 4965.5 9430 RPD MWD OHMM 0.15 2000 20.4959 7983 5390 9381 RPM MWD OHMM 0.48 2000 25.3601 7983 5390 9381 RPS MWD OHMM 0.31 1054.87 3.69715 7983 5390 9381 RPX MWD OHMM 0.59 1207.58 3.19919 7983 5390 9381 FET MWD HOUR 0.22 57.04 1.71802 7983 5390 9381 GR MWD API 29.1 265.56 115.757 8818 4965.5 9374 ROP MWD FT/H 0.04 292.99 93.54 8051 5405 9430 First Reading For Entire File..........4965.5 Last Reading For Entire File...........9430 • • File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4965.5 8738.0 FET 5390.0 8729.5 RPX 5390.0 8729.5 RPD 5390.0 8729.5 RPS 5390.0 8729.5 RPM 5390.0 8729.5 ROP 5406.0 8774.0 LOG HEADER DATA DATE LOGGED: O1-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 8774.0 TOP LOG INTERVAL (FT) 5406.0 BOTTOM LOG INTERVAL (FT) 8774.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.7 MAXIMUM ANGLE: 61.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 97504 EWR4 ELECTROMAG. RESIS. 4 216787 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 5405.0 BOREHOLE CONDITIONS • • MUD TYPE: Polymer MUD DENSITY (LB/G) 9.30 MUD VISCOSITY (S): 50.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 800 FLUID LOSS (C3) 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) 3.100 76.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.790 136.4 MUD FILTRATE AT MT: 3.000 76.0 MUD CAKE AT MT: 3.000 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ............. .....0 Data Specification Block Type .....0 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .lIN Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units .................. ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWDO10 OHMM 4 1 68 4 2 RPM MWDO10 OHMM 4 1 68 8 3 RPS MWDO10 OHMM 4 1 68 12 4 RPX MWDO10 OHMM 4 1 68 16 5 FET MWD010 HOUR 4 1 68 20 6 GR MWDO10 API 4 1 68 24 7 ROP MWDO10 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4965.5 8774 6869.75 7618 4965.5 8774 RPD MWDO10 OHMM 0.15 2000 10.9076 6680 5390 8729.5 RPM MWDO10 OHMM 0.48 2000 8.49337 6680 5390 8729.5 RPS MWDO10 OHMM 0.31 218.56 2.9746 6680 5390 8729.5 RPX MWDO10 OHMM 0.79 139.96 2.80282 6680 5390 8729.5 FET MWDO10 HOUR 0.22 8.79 0.971705 6680 5390 8729.5 GR MWDO10 API 29.1 265.56 116.345 7546 4965.5 8738 ROP MWDO10 FT/H 0.04 255.24 97.9615 6737 5406 8774 First Reading For Entire File..........4965.5 Last Reading For Entire File...........8774 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/30 • • Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name.... Version Number...........1.0.0 Date of Generation.......07/07/30 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files.. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 8730.0 9381.0 RPD 8730.0 9381.0 RPM 8730.0 9381.0 RPS 8730.0 9381.0 FET 8730.0 9381.0 GR 8738.5 9374.0 ROP 8774.5 9430.0 LOG HEADER DATA DATE LOGGED: 04-JAN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY. OR REAL-TIME): Memory TD DRILLER (FT) 9430.0 TOP LOG INTERVAL (FT) 8774.0 BOTTOM LOG INTERVAL (FT) 9430.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 4.7 MAXIMUM ANGLE: 33.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 151107 EWR4 Electromag Resis. 4 148579 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.125 DRILLER'S CASING DEPTH (FT) 8768.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfanate MUD DENSITY (LB/G) 10.05 MUD VISCOSITY (S) 52.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3) 5.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) • • MUD AT MEASURED TEMPERATURE (MT) 6.700 67.0 MUD AT MAX CIRCULATING TERMPERATURE: 3.950 118.4 MUD FILTRATE AT MT: 6.500 67.0 MUD CAKE AT MT: 6.900 67.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8730 9430 9080 1401 8730 9430 RPD MWD020 OHMM 0.22 2000 71.3667 1303 8730 9381 RPM MWD020 OHMM 0.99 2000 113.582 1303 8730 9381 RPS MWD020 OHMM 0.45 1054.87 7.42533 1303 8730 9381 RPX MWD020 OHMM 0.59 1207.58 5.23919 1303 8730 9381 FET MWD020 HOUR 0.49 57.04 5.54698 1303 8730 9381 GR MWD020 API 41.42 168.34 112.024 1272 8738.5 9374 ROP MWD020 FT/H 0.07 292.99 70.9682 1312 8774.5 9430 First Reading For Entire File..........8730 Last Reading For Entire File...........9430 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......07/07/30 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF • Tape Trailer Service name .............LISTPE Date .....................07/07/30 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name .............LISTPE Date .....................07/07/30 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
