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Home My WebLink About209-135By Anne Prysunka at 1:49 pm, Jul 29, 2022 MGR07SEP2022 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 21, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC F-82A MILNE PT UNIT F-82A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/21/2022 F-82A 50-029-22971-01-00 209-135-0 W SPT 6957 2091350 1739 2030 2055 2033 2035 0 90 92 88 4YRTST P Bob Noble 7/2/2022 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 F-82A Inspection Date: Tubing OA Packer Depth 103 2662 2590 2575IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN220702090818 BBL Pumped:2.5 BBL Returned:2.5 Thursday, July 21, 2022 Page 1 of 1          Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 564-4389 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: DATE: 06/28/2022 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-82A (PTD 209-135) Coil Flag 06/21/2022 Please include current contact information if different from above. PTD:209-135 T36737 Kayla Junke Digitally signed by Kayla Junke Date: 2022.06.29 10:40:26 -08'00' 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: WAG MPU F-82A (PTD# 209-1350) Date:Thursday, June 23, 2022 8:16:47 AM From: Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Sent: Wednesday, June 22, 2022 6:17 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov>; David Haakinson <dhaakinson@hilcorp.com> Subject: OPERABLE: WAG MPU F-82A (PTD# 209-1350) Mr. Wallace, MPU F-82A (PTD# 209-1350) WAG injector was made NOT OPERABLE due to missing its scheduled MIT-IA. The well is now ready to be placed on injection. It is now classified as OPERABLE and will be placed on injection. A MIT-IA will be scheduled once injection has been stabilized. Please respond if there are any questions. Jerimiah Galloway MPU/Islands Well Integrity Engineer Email: jerimiah.galloway@hilcorp.com O: (907)564-5005 C: (828)553-2537 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error,you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, thenpromptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems ordata. 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Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Tom Fouts To:AOGCC Permitting (CED sponsored) Cc:Taylor Wellman Subject:MP F-82A PTD: 209-135 10-403 Withdrawal Request Date:Monday, April 11, 2022 3:02:37 PM Samantha, Hilcorp Alaska LLC would like to request the withdrawal of sundry 321-433 for MP F-82A, PTD: 209- 135. It is our intent to submit an new 10-403 sundry for extended perfs on this well. Regards, Tom Fouts | Senior Ops/ Reg Tech Hilcorp Alaska, LLC tfouts@hilcorp.com Direct: (907) 777-8398 Mobile: (907) 351-5749 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 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: Milne Point well F-82A (PTD 2091350) will not be brought online in time for MIT Date:Thursday, March 24, 2022 4:46:13 PM From: Darci Horner - (C) <dhorner@hilcorp.com> Sent: Thursday, March 24, 2022 12:06 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Cc: Jon Arend <Jon.Arend@hilcorp.com>; Alaska NS - Milne - Wellsite Supervisors <AlaskaNS-Milne- WellsiteSupervisors@hilcorp.com>; Alaska NS - Wells Foreman <PBWellsForeman@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com>; Jerimiah Galloway <Jerimiah.Galloway@hilcorp.com> Subject: Milne Point well F-82A will not be brought online in time for MIT All, Milne Point well F-82A (PTD # 2091350) will not be brought on line in time for the regularly scheduled MIT this month. A tag will be hung on the well head, it will be classified as inoperable, and it will be tested prior to returning to injection. Please call myself or Jerimiah Galloway (907-564-5005) with any questions. Regards, Darci Horner Technologist Office: (907) 777-8406 Cell: (907) 227-3036 Email: dhorner@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. From:Regg, James B (CED) To:AOGCC Records (CED sponsored) Subject:FW: MPU F-82 - MCX Valve Pulled Waiting on Coil Date:Friday, September 10, 2021 10:09:41 AM MPU F-82A (PTD 2091350) Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (CED) Sent: Friday, September 10, 2021 10:07 AM To: Ted Kramer <tkramer@hilcorp.com>; David Haakinson <dhaakinson@hilcorp.com> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: MPU F-82 - MCX Valve Pulled Waiting on Coil Ted – No need to respond. I just spoke with David Haakinson and understand the reasons for the delay. MPU F-82A may remain on injection while waiting for the service coil unit. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Regg, James B (CED) Sent: Friday, September 10, 2021 9:43 AM To: Ted Kramer <tkramer@hilcorp.com> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: RE: MPU F-82 - MCX Valve Pulled Waiting on Coil Why was the injection valve pulled from the well so early? Please explain how shutting in water injection for a few days would result in waste, and why would this different than shutting in the well for a workover or for some upset in the injection system. Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: Ted Kramer <tkramer@hilcorp.com> Sent: Thursday, September 9, 2021 8:57 AM To: Regg, James B (CED) <jim.regg@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: MPU F-82 - MCX Valve Pulled Waiting on Coil Jim, Hilcorp pulled the MCX valve out of the above injector on 8-27-21 in preparation for a perf add in the northern fault block (Approved Sundry # 321-433). Hilcorp has continued to inject water into the well while waiting on a coil tubing unit to arrive to perforate the well. The coil Unit was delayed on another well, and it has pushed our schedule back by 5 days. The 14 day window ends tomorrow and best predictions indicate that the coil unit will arrive in 5 days from today on 9-14-2021. In order to avoid waste (by shutting in the well), Hilcorp asks to be allowed to continue injecting into the well until coil arrives on September 14th. Please let me know if this is agreeable to the AOGCC. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp-Alaska LLC Office – 907-777-8420 Cell – 985-867-0665 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately 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. 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 10,762'N/A Casing Collapse Conductor N/A Surface 3,090psi Production 5,410psi Liner 11,780psi Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Chad Helgeson Contact Name: Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng David Haakinson COMMISSION USE ONLY Authorized Name: Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025509 & ADL0388235 209-135 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22971-01-00 Hilcorp Alaska LLC Length Size 7,102' 10,709' 7,112' 3,425 N/A MILNE POINT / KUPARUK RIVER OIL 110' 110' 902# / L-80 / NSCT TVD Burst 9,034' MD N/A 11,200psi 5,750psi 7,240psi 4,256' 7,037' 7,109' 5,311' 9,123' See Schematic 81' 20" 9-5/8" 7" 5,282' 2-3/8"1,764' 9,097' Authorized Signature: 9/10/2021 3-1/2" Perforation Depth MD (ft): See Schematic MILNE PT UNIT F-82A C.O. 432D KB & Baker 7" x 4.5" SAB-3 Packers and N/A 9,030 MD/ 6,953 TVS & 9,034 MD/ 6,957 TVD and N/A Authorized Title: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. 10,725' ory Statu Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 10:29 am, Aug 26, 2021 321-433 Digitally signed by Chad Helgeson (1517) DN: cn=Chad Helgeson (1517), ou=Users Date: 2021.08.26 10:22:43 -08'00' Chad Helgeson (1517) 10-404 DSR-8/26/21SFD 8/26/2021MGR31AUG21 dts 8/31/2021 JLC 8/31/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.08.31 17:53:24 -08'00' RBDMS HEW 9/1/2021 CT Perforate Well: MPU F-82A Date: 8/25/2021 Well Name:MPU F-82A API Number:50-029-22971-01-00 Current Status:Injector - Online Pad:F-Pad Estimated Start Date:September 10th, 2021 Rig:SL, EL OR CT Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Darci Horner Permit to Drill Number:209-135 First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:David Gorm (907) 777-8333 (O) AFE Number:Job Type:Perforate Current Bottom Hole Pressure: 3,058 psi @ 6,331’ TVD Downhole Gauge |9.29 PPGE MPSP:2,425 psi (0.1psi/ft gas gradient) Max Deviation:60 deg @ perf interval Max Dogleg:37.4°/100ft @ 9,185’ MD CTD Build Min ID:1.90” Drift @ 9,044’ MD 2-3/8” Liner Brief Well Summary: F-82A is a Kuparuk A-sand injector that was first drilled in 2000 and sidetracked in 2010. In Q2 2021, producer MPU F-05 was CTD sidetracked into the fault block that the northern part of MPU F-82A was drilled. Due to no previous offtake, F-82A was not perforated in the northern fault block. Now that F-05A is completed in the fault block, perforating the Kuparuk A sands in F-82A is needed for proper waterflood support. Objective: x Perforate Kuparuk A sands to establish injection communication to MPU F-05A Notes Regarding the Well & Design x Note that the pressure in the northern fault block is anticipated to be below 8.33 PPG. x MIT-IA to 4,300 psi passed on 3/12/2018. Slickline Procedure (NON-SUNDRY WORK) 1. MIRU Slickline Unit. PT PCE to 250 psi L / 3,500 psi H. 2. Pull MCX Injection Valve from X-Nipple @ 2,233’ MD. 3. MU 20’ 1.76” Dummy Drift Gun and attempt to drift to perf depth @ 9,250’ MD. a. If drift is achieved, a E-line perf job will be attempted. b. If drift is not achieved, job will move to Coiled Tubing. 4. RDMO Slickline E-line / Coil Tubing Perforating Procedure (SUNDRY REQUIRED) 5. MIRU Coiled Tubing Unit with 1.5” coiled tubing and spot ancillary equipment. 6. Pressure test BOPE to 3,500 psi Hi 250 Low, 10 min each test. a. Each subsequent test of the lubricator will be to 3,500 psi Hi 250 Low to confirm no leaks. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. CT Perforate Well: MPU F-82A Date: 8/25/2021 d. If within the standard 7-day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient to meet weekly BOPE test requirement. 7. Document shut in tubing pressure. Bleed gas head off to tanks. 8. MU GR/CCL and drift assembly w/ circulating sub and 20’ of 1.76” OD spent perf guns. 9. RIH to 9,400’ MD. 10. Pull Up-pass for log tie-in to 9,000’ MD. 11. Flag Pipe for correlation. 12. POOH and LD BHA. Perform log correction and send to Engineer and Geologist for review a. Engineer: David Haakinson dhaakinson@hilcorp.com b. Geologist: John Salsbury jsalsbury@hilcorp.com 13. PU Perf Gun BHA and perforate the following intervals: a. Document changes in wellhead pressure and condition of guns as they return. b. Contact Engineer to review depth and planned perforation depths prior to firing guns. c. Perforating Guns are 1.56” HMX, 6 SPF, 60 degree phase guns. i. Max Swell: 1.76” Formation Length (ft) Top (MD) Bottom (MD) Top (TVD) Bottom (TVD) Kuparuk A3 Sand ±15’ ±9,192’ ±9,207’ ±7,091’ ±7,101’ Kuparuk A2 Sand ±21’ ±9,222’ ±9,243’ ±7,109’ ±7,121’ 14. RDMO CTU. 15. Do not freeze protect well. Bring well on injection. SSSV must be installed within 14-days, but schedule slickline to install MCX after baseline injection rates are documented. Attachments: 1. Current schematic 2. Proposed schematic 3. Coiled Tubing BOP Schematic KOP @ 945’ - 10 degrees. Max. hole angle = 53 deg. Hole angle thru’ perfs = 24 degrees. DATE REV. BY COMMENTS Orig. KB Elev. = 39.95 ft (Doyon -141) Orig. GL Elev. = 11.30 ft DF Elev. = 28.65 ft MILNE POINT UNIT API : 50-029-22971-00 9 5/8", 40 ppf, L-80 Btrc. Perforation Summary Ref log: SWS USIT log dated: 9/6/00 BP EXPLORATION (AK) 7" HES float shoe Size Spf Interval (TVD) MPU F-82Ai 5311’ 20” 91.51# ppf, H-40 O 9 5/8” Tam port collar 7" 26 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpf ) 7” HES float collar Tree:Cameron 3 1/8”, 5M Wellhead:FMC 11” x 7-1/16” 5M, Gen. 5a w/ 6" x 3.5" FMC Tbg. Hnr. w/ 3.5’ eue threads top and btm. 3" CIW H BPV profile 78’ 1009’ HES X-Nipple 2.813” id 2233’ 3.5” 9.3 ppf, L-80 nsct tubing. ( drift id = 2.992”, cap = 0.0087 bpf ) 09/07/00 M. Linder Drilled and completed by Doyon 141 9341’ 9425’ Baker 7” x 4.5” SAB-3 perm pkr. HES X-Nipple 2.813” id HES XN-Nipple 2.750” ID no-go WLEG 9034’ 9012’ 9059’ 9072’ 10/24/00 MDO Perforated 1.56” Power Jet 6spf 60 deg. phasing 3" Open Hole 2-3/8" Solid/Cemented Liner 2-3/8" Liner top at 9,044' Whipstock in Pilot Hole @ 9,125' KB Packer top at 9,030' PBTD = 10,708' Min I.D. = 1.79“ @ KB Packer Well required to have a SSSV installed. MCX SET MCX 8/13/2013 .50 BEAN INSTALLED MCX valve installed and tested 12/18/16 KOP @ 945’ - 10 degrees. Max. hole angle = 53 deg. Hole angle thru’ perfs = 24 degrees. DATE REV. BY COMMENTS Orig. KB Elev. = 39.95 ft (Doyon -141) Orig. GL Elev. = 11.30 ft DF Elev. = 28.65 ft MILNE POINT UNIT API : 50-029-22971-00 9 5/8", 40 ppf, L-80 Btrc. Perforation Summary Ref log: SWS USIT log dated: 9/6/00 Hilcorp Alaska LLC 7" HES float shoe Size Spf Interval (TVD) MPU F-82Ai 5311’ 20” 91.51# ppf, H-40 O 9 5/8” Tam port collar 7" 26 ppf, L-80, btc mod. casing ( drift id = 6.276", cap. = 0.0383 bpf ) 7” HES float collar Tree:Cameron 3 1/8”, 5M Wellhead:FMC 11” x 7-1/16” 5M, Gen. 5a w/ 6" x 3.5" FMC Tbg. Hnr. w/ 3.5’ eue threads top and btm. 3" CIW H BPV profile 78’ 1009’ HES X-Nipple 2.813” id 2233’ 3.5” 9.3 ppf, L-80 nsct tubing. ( drift id = 2.992”, cap = 0.0087 bpf ) 09/07/00 M. Linder Drilled and completed by Doyon 141 9341’ 9425’ Baker 7” x 4.5” SAB-3 perm pkr. HES X-Nipple 2.813” id HES XN-Nipple 2.750” ID no-go WLEG 9034’ 9012’ 9059’ 9072’ 10/24/00 MDO Perforated 1.56” Power Jet 6spf 60 deg. phasing 3" Open Hole 2-3/8" Solid/Cemented Liner 2-3/8" Liner top at 9,044' Whipstock in Pilot Hole @ 9,125' KB Packer top at 9,030' PBTD = 10,708' Min I.D. = 1.79“ @ KB Packer Well required to have a SSSV installed. MCX SET MCX 8/13/2013 .50 BEAN INSTALLED +/-9,192 - +/-9,207 +/-9,222' - +/-9,243 +/-7,091 - +/-7,101 +/-7,109 - +/-7,121 MCX valve installed and tested 12/18/16 CT Perforate Well: MPU F-82A Date: 8/25/2021 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,March 20,2018 TO: Jim Regg 31 (i P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC F-82A FROM: Bob Noble MILNE PT UNIT F-82A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT F-82A API Well Number 50-029-22971-01-00 Inspector Name: Bob Noble Permit Number: 209-135-0 Inspection Date: 3/12/2018 Insp Num: mitRCN180312165722 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well F-82A Type Inj W ITVD 6957 Tubing 3434 3434 3434 H 3435 H PTD 2091350 Type Test SPT Test psi 1739 IA 532 4319 - 4230 ' 4208 BBL Pumped: 3.6 'BBL Returned: 3.9 - OA 199 700 • 695 • 687 Intervall 4YRTST P/F P ✓ Notes: SCANNED Tuesday,March 20,2018 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 8/13/2012 Permit to Drill 2091350 Well Name /No. MILNE PT UNIT KR F -82A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 22971 -01 -00 MD 10762 TVD 7102 Completion Date 3/13/2010 Completion Status WAGIN Current Status WAGIN UIC Y , REQUIRED INFORMATION Mud Log No Samples No Directional Su ey Yes/ DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES, GR / CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr III Data Digital Dataset Log Log Run Interval OH / Type MediFrmt Number Name Scale Media No Start Stop CH Received Comments Rpt LIS Verification 8703 10761 Open 5/20/2010 ED4 Lis 19665 Induction /Resistivity 8703 10761 Open 5/20/2010 OH LIS GR, ROP, RAD, RAS, RPD, RPS Plus I I CGM & PDF Graphics Log Induction /Resistivity 25 Col 8132 10762 Open 5/21/2010 MD MPR, GR Log "" Induction /Resistivity 5 Col 8132 10762 Open 5/21/2010 TVD MPR, GR Log i Gamma Ray 25 Col 8132 10762 Open 5/21/2010 MD GR Log °// Gamma Ray 5 Col 8690 10740 Open 5/21/2010 Depth Shift Monitor Plot ED VC Lis 19803 Neutron 8564 10702 Case 6/29/2010 CH LIS GR, CNT data Plus PDS Graphics Log / Neutron 25 Blu 8577 10695 Case 6/29/2010 MCNL, Mem LEE, CCL, GR, TFN, TNN 1 ED Asc Directional Survey 9042 10762 Open • Rpt -" Directional Survey 9042 10762 Open Well Cores /Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORON Well Cored? `// Daily History Received? ----- Chips Received? Yom Formation Tops Y / N Analysis ' il— Received? DATA SUBMITTAL COMPLIANCE REPORT 8/13/2012 Permit to Drill 2091350 Well Name /No. MILNE PT UNIT KR F -82A Operator BP EXPLORATION (ALASKA) INC API No. 50- 029 - 22971 -01 -00 MD 10762 TVD 7102 Completion Date 3/13/2010 Completion Status WAGIN Current Status WAGIN UIC Y Comments: Compliance Reviewed By: Date: 1 2 \-A . • • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 Mr. Tom Maunder 5 5 Alaska Oil and Gas Conservation Commission ' 1 333 West 7 Avenue Anchorage, Alaska 99501 1 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -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, A Mehreen Vazir BPXA, Well Integrity Coordinator II S BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPF -Pad 1W2912011 Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF-02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF-05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 12 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 WA 5.0 N/A 54.4 8/9/2011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 02 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 WA 8.3 N/A 91.8 822011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top Job MPF-34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 02 N/A 8.5 10/62011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/52011 MPF -01 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/12011 MPF -45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor_ N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 18 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF -58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF-61 1951170 50029225820000 62 Need top job MPF-62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF-66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF-69 1951250 50029225860000 0.8 N/A 0,8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 02 N/A 6.8 10/5/2011 MPF -78 1951440 50029225990000 0.7 N/A 0.7 WA 5.1 7/312011 MPF-79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/32011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF-82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 12 N/A 13.6 8/3/2011 MPF-84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 0.8 N/A 6.8 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/132011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 12 N/A 1.2 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/132011 MPF-92 1981930 50029229240000 0.8 N/A - 0.8 N/A 5.1 8/13/2011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 06/18/10 Schirunberqer NO. 5545 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambol? Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job ft Log Description Date BL Color CD E -19B BBUO-00015 STATIC BOTTOM & TEMP SURVEY 004 -0 j 04/03/10 1 / 1 H -30 BCRD-00020 PRODUCTION PROFILE /'fj X35' /g -figy 05/10/10 1 1 P2 -34 B3S0 -00071 STATIC PRESSURE SURVEY , , - 05/15/10 1 1 P2 -34 B3SQ-00073 (PROF WITH STATIC SURVEY 1 / ® (� ( o ( 0 05/19/10 1 1 ielj 1 V -05 AWJI-00090 MEM CBL • • — II -. " 05/24/10 1 1 P2 -17 BCRC -00017 PRODUCTION PRO ILE /''' —I X55 '9 t 06/01/10 1 1 16 -06B BBUO -00023 PRODUCTION PROFILE ;) , —(1( {4 r f� 06/08/10 1 1 S -21 BBSK -00019 PRODUCTION PROFILE — -*WA; • 06 /03/10 1 1 Z -46A BAUJ -00027 MEM CBL — D '� 7 5•i 06/01/10 1 1 V -05 BD88 -00018 MEMLDL - • , — • ` 06/08/10 1 1 01 -26A B14B -00106 SCMT " f 06/10/10 1 1 B -13A BBUO-00019 USIT / 9 ti - (-1 /L)" 0 . 4 . C � 05/28/10 1 1 1-27/P-20 AYKP-00085 PRODUCTION PROFILE' ~ O y • / 4 06/06/10 1 1 MPF -82A BAUD -00010 _MCNL , -)Ac — 1"3...c 1 A 04/06/10 1 1 Z -16A BCUE -00005 CH EDIT PDC (MEM CORRELATION) . c 04/06/10 j y '1 1 E - 15D AWJI -00081 MCNL t 04/03/10 y 1 1 05 -19 BBKA -00013 RST 1 `, I 03/14/10 1 1 F -27A AYKP -00078 RST [ ( 1 - 1 • ♦ - 03 /17/10 1 1 J -18A BD88 -00010 MCNL d(() „O AO. " J 04/18/10 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 • 900 E. Benson Blvd. Anchorage, AK 99503 -2838 qq / � j "J/py E JllN '% 9 701 An her /9 S S INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7 Ave. RECEIVED Suite 100 Anchorage, Alaska 99501 MAY 2 0 2010 Attention: Christine Mahnken ' , * ' p , .,:., Reference: MPF -82A I Contains the following: 1 1 LDWG Compact Disc (Includes Graphic Image files) {' 1 LDWG lister summary 1 color print — GR Directional Measured Depth Log (to follow) 1 color print — MPR/Directional TVD Log (to follow)! 1 color print — MPR/Directional Measured Depth Log (to follow) i a � LAC Job #: 3053197 i Sent by: Donna Moss Date: 05/19/2010 Received by: Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267 -6623 Baker Hughes INTEQ U-T a, d 0 0 1 d3 S EMI 7260 Homer Drive BAKER Anchorage, Alaska 99518 HUGHES Direct: (907) 267 -6612 9 INTEQ FAX: (907) 267 -6623 3 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 5.2010 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. V iii& 61w'i011S.Ci0mf IOt1 2OAAC 25.105 20AAC 25.110 ❑ Developmfthotilexpioratory ❑ GINJ ❑ WINJ ® WAG ❑ WDSPL ❑ Other No. of Completions One ® Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 3/13/2010 209 - 135 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 3/5/2010 50 - 029 - 22971 - - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 3/7/2010 MPF -82A 1991' FSL, 3011' FEL, SEC. 06, T13N, R10E, UM 8. KB (ft above MSL): 42.15' 15. Field / Pool( s ) Top of Productive Horizon: 2003' FNL, 2871' FEL, SEC. 12, T13N, RO9E, UM GL (ft above MSL): 11.3' Milne Point Unit / Kuparuk River Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 2158' FNL, 2998' FEL, SEC. 12, T13N, RO9E, UM 10709' 7112' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 541552 y - 6035442 Zone- ASP4 10762' 7102' ADL 025509 & 388235 TPI: x- 536554 y- 6031421 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 536428 y 6031265 Zone- ASP4 None 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): 18. Directional Survey: 0 Yes ❑ No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- DrillLateral Top Window MD/TVD: MWD DIR, GR, RES, GR / CCL 9123' 7037' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM ToP BOTTOM SIZE CEMENTING RECORD PULLED 20" 54.5# K -55 29' 110' 29' 110' 30" 260 sx Arcticset (Aoorax.) 9 -5/8" 40# L -80 29' 5311' 29' 4256' 12 -1/4" 825 sx Arcticset III Lite. 290 sx Class 'G' 7" 26# L - / N - 80 26' 9123' 26' 7037' 8 - 1/2" 180 sx Class 'G' 2 - 3/8" . 4.44# , L - 80 9051' 10725' 6972' 7109' , 3" 73 sx Class 'G' 24. Open to production or injection? 0 Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD I ND) (MD +TVD of Top & Bottom; Perforation Size and Number): 1.56" Gun Diameter, 6 spf 3 -1/2 ", 9.2 #, L -80 9072' 9034' / 6957' MD TVD MD ND 10560' - 10640' 7147' - 7126' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10660' - 10705' 7122' -7113' DEPTH INTERVAL (MD)J AMOUNT AND KIND OF MATERIAL USED 9030' Freeze Protected w/ 77 Bbls of Diesel 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 20, 2010 Water Alternating Gas Injection _ Date of Test: Hours Tested: Production For OIL-BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL -BBL: GAS-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes 0 No Sidewall Core(s) Acquired? ❑ Yes 0 No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence • • • • - • 4 , er (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results ..aginatit 1 071. None Form 10-407 Revised 12/2009 ONTINUED ON REVERSE _ / � Submit Original Only RBDMS APR 00 ° ( ., ,, G 29. GEOLOGIC MARKERS (List all formations an. . rkers encountered): 30. FORMATION TESTS NAME MD ND Well Tested? ❑ Yes 0 No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C1 9119' 7033' None Kuparuk B 9140' 7052' Kuparuk A5 / A4 9178' 7082' Kuparuk A3 9188' 7089' Kuparuk A3 Shale 9206' 7100' Kuparuk A2 9215' 7106' Kuparuk Al 9273' 7133' Kuparuk Al (invert) 10556' 7148' Kuparuk A2 (Invert) 10640' 7126' Kuparuk A3 Shale (Invert) 10660' 7122' Kuparuk A3 (Invert) 10721' 7110' Formation at Total Depth (Name): Kuparuk A3 (Base) 10721' 7110' 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. � I/ /D Signed: Terrie Hubble l/ Y �--C_ '% / - Title: Drilling Technologist Date: MPF - 82A 209 - 135 Prepared ByName/Number. Terre Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Sean McLaughlin, 564 -4387 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123 -00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 2/27/2010 03:00 - 04:30 1.50 MOB P PRE ROAD RIG FROM MPL -36L1. 04:30 - 06:00 1.50 RIGU P PRE PARK RIG IN FRONT OF WELL ROW. PREPARE CELLAR. 06:00 - 15:00 9.00 RIGU N WAIT PRE WAIT ON WEATHER. -42F MPU, -44 BOC, -46 DEADHORSE AIRPORT. HAND RAILS ON WELLHOUSES ON BOTH SIDES HAVE NOT BEEN REMOVED DUE TO WINDS, SNOW AND COLD WEATHER. POSITION MPD EQUIPMENT IN CELLAR. PREPARE TO PULL HAND RAILS. CRANE ON LOCATION 15:00 - 16:00 1.00 MOB P PRE TEMP AT -35F. PICK HAND RAILS WITH CRANE. LOCATION READY TO BACK IN RIG. 16:00 - 16:15 0.25 MOB P PRE SAFETY MEETING. REVIEW PROCEDURE, HAZARDS AND MITIGATION FOR BACKING RIG OVER WELL. 16:15 - 18:00 1.75 MOB P PRE BACK RIG OVER WELL, CENTER RIG OVER TREE AND SET DOWN. ACCEPT RIG AT 1800 HRS, 02/27/2010. 18:00 - 20:00 2.00 RIGU P PRE GENERAL RIG UIP. SEAL UP CELLAR. HEAT CELLAR. POSITION SAT CAMP, CUTTINGS TANK AND TIGER TANK. 20:00 - 00:00 4.00 BOPSUF P PRE N/U BOPE AND MPD LOOP. CONTINUED ON DIMS REPORT 02/28/10 2/28/2010 00:00 - 01:30 1.50 BOPSUF P PRE CONTINUED FROM DIMS REPORT 02/27/10. CONTINUE NU BOPE AND MPD LOOP. VERY COLD, -41 F. NOT ABLE TO MOVE SIGN -IN SHACK TO F PAD DUE TO COLD TEMP AND REQUIRED CRANE TO LIFT HEAVY SHACK. 01:30 - 03:30 2.00 BOPSUF P PRE SHELL TEST BOPE, 03:30 - 18:30 15.00 BOPSUF P PRE BEGIN BOPE PRESSURE / FUNCTION TEST. AOGCC WITNESS WAIVED BY JEFF JONES. SEND TEST REPORT TO AOGCC. VERY COLDER, -44F at 0700. 2" COMBI RAMS FAILED TEST. REPLACE AND RETEST. CHOKE LINE FROZE UP, THAW LINE. -40F. 2" RAMS PASS. BOP TEST COMPLETE. RD TEST EQUIPMENT. BLOWDOWN STACK. 18:30 - 20:30 2.00 RIGU P PRE AT APPROXIMATELY 18:40 DISCOVERED GLYCOL ON PAD UNDERNEATH BOOSTER TIRES. AFFECTED AREA IS -56" X 42 ". ESTIMATED VOLUME IS 2 QUARTS. TRACE LEAK PATH - BELIEVE SOURCE OF GLYCOL TO BE "LUBESTER" (BULK GLYCOL TANK IN MOTOR ROOM). A SMALL POOL OF GLYCOL FOUND IN GRAVITATIONAL LOW SPOT IN SEAL WELDED SECONDARY CONTAINMENT BENEATH TANK. BELIEVE GLYCOL LEAKED THROUGH CRACK IN SEAL WELD, FOLLOWED RIG SUBSTRUCTURE AND ULTIMATELY DRIPPED ONTO PAD. PJSM W/ CREW REGARDING RELEASE - REVIEW MSDS. CLEANED RESIDUAL GLYCOL FROM SECONDARY CONTAINMENT AND ENSURED RELEASE HAD STOPPED. NOTIFY MP SPILL REPORTING, SRT, PAD OPERATOR, NORDIC MANAGEMENT, ADW HSE AND ADW CTD SUPERINTENDENT. PJSM. PU INJECTOR. INSTALL PACKOFF ASSEMBLY. Printed: 3/29/2010 11:46:59 AM • BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 2/28/2010 18:30 - 20:30 2.00 RIGU P PRE C/O CREWS. TL W/ NEW CREW. PJSM. PULL COIL ACROSS. 20:30 - 22:00 1.50 RIGU P PRE REMOVE CT GRAPPLE. DRESS AND REHEAD CT AND PT. REHEAD BHI. 22:00 - 23:30 1.50 RIGU P PRE CIRC CT ON WELL W/ METH AND KCL. 23:30 - 00:00 0.50 RIGU P PRE TEST REEL VALVE AND PACKOFF TO 250 PSI / 3500 PSI. GOOD. CONTINUED ON DIMS REPORT 03/01/10 3/1/2010 00:00 - 01:00 1.00 RIGU P PRE CONTINUED FROM DIMS REPORT 02/28/10. PJSM. UNSTAB, INSTALL CHECK VALVES AND PT TO 3500 PSI. BREAK OFF AND STANDBACK INJECTOR. GUAGE MILL FOR UPCOMING RUN: MILL IS 2.80" NOGO / 2.81" GO. MILL IS A PARABOLIC DIAMOND SPEED MILL WITH BACKREAMERS AND NO SIDE CUTTERS. 01:00 - 02:15 1.25 RIGU N WAIT PRE WAIT ON BPV CREW. THEY ARE SHORTHANDED TONGIHT. FIND PHONE MESSAGE ON PUSHER TELEPHONE FROM SRT. SRT (NEIL HERMAN (SP ?) AT EXTENSION 3022) GIVES US PERMISSION TO CLEAN AFFECTED AREA FROM YESTERDAY'S GLYCOL RELEASE. HE SAYS HE WILL CALL BACK IN THE MORNING. CLEAN AFFECTED AREA. BAG AND TAG APPROPRIATELY. 02:15 - 02:40 0.42 RIGU P PRE BPV CREW ON LOCATION AT 0215. PJSM W/ BPV CREW. 02:40 - 04:00 1.33 RIGU P PRE MU LUBRICATOR. PULL BPV. LAY DOWN LUBRICATOR. 04:00 - 04:40 0.67 WHIP P WEXIT PU INJECTOR. PU MOTOR AND MILL ASSEMBLY. MOTOR IS STRAIGHT. MILL IS 2.80" PARABOLIC DIAMOND D331 MILL WITH BACKREAMERS, NO SIDE CUTTERS. 04:40 - 06:00 1.33 WHIP P WEXIT BEGIN RIH CIRCULATING 2% XS KCL DOWN CT AT 0.4 BPM AT 190 PSI THROUGH MOTOR W/ RETURNS TO TT. IAP = 475 PSI. OAP = 16 PSI. BLEED IAP TO 250 PSI. TAG CEMENT AT 8132'. 06:00 - 09:30 3.50 WHIP P WEXIT MILL CONTAMINATED CEMENT WITH USED GEOVIS, 1.6 BPM, 3000 -3800 PSI, 20 -50 FPH, MILLED TO 8240' 09:30 - 14:00 4.50 WHIP P WEXIT MILL CEMENT WITH USED GEOVIS, 1.6 BPM, 3000 -3500 PSI, 1.5K WOB, 40 FPH, MILLED TO 8450' 14:00 - 15:00 1.00 WHIP P WEXIT MILL CEMENT WITH USED GEOVIS, 1.5 BPM, 3000 -3500 PSI, 2.5 K WOB, 40 FPH, MILLED TO 8500'. 15:00 - 15:15 0.25 WHIP P WEXIT WIPER UP TO 8100'. CLEAN. RIH CLEAN. 15:15 - 18:15 3.00 WHIP P WEXIT MILL CEMENT WITH USED GEOVIS, 1.5 BPM, 3000 -3500 PSI, 2.5 K WOB, 25 FPH, MILLED TO 8580'. 18:15 - 20:00 1.75 WHIP P WEXIT MILL CEMENT WITH USED GEOVIS, 1.46 BPM AT 3200 - 3500 PSI, 2.5K WOB, 25 FPH. MILLED TO 8633' CTMD. 20:00 - 21:00 1.00 WHIP P WEXIT MILL CEMENT WITH USED GEOVIS, 1.46 BPM AT 3200 - 3500 PSI, 2.5K WOB, 25 FPH ROP. MILLED TO 8656' CTMD. STALLED AT THIS DEPTH. PU CLEAN AT 25K LB. 21:00 - 22:00 1.00 WHIP P WEXIT WIPER TO 8100'. UP WEIGHTS CLEAN AT 25K LB. Printed: 3/29/2010 11:46:59 AM BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/1/2010 21:00 - 22:00 1.00 WHIP P WEXIT PUMPING DOWN CT AT 1.48 BPM AT 2720 PSI WHILE PUH AT 35 FPM. RBIH TO RESUME MILLING. TRIP CLEAN IN BOTH DIRECTIONS. 22:00 - 00:00 2.00 WHIP P WEXIT MILLED CEMENT TO 8725' AT 30 FPH, 3K WOB. 3/2/2010 00:00 - 05:00 5.00 WHIP P WEXIT MILL CEMENT WITH 2.80" MILL AND STRAIGHT MOTOR, 3300 -3800 PSI, 3K WOB, 30 FPH. MILLED TO 8855'. 05:00 - 05:30 0.50 WHIP P WEXIT WIPER TRIP TO 8100'. CLEAN BOTH DIRECTIONS. 05:30 - 11:00 5.50 WHIP P WEXIT MILL CEMENT WITH 2.80" MILL AND STRAIGHT MOTOR, 3300 -3800 PSI, 3K WOB, 30 FPH. MILLED TO 9012'. 11:00 - 19:00 8.00 WHIP P WEXIT MILL CEMENT WITH 2.80" MILL AND STRAIGHT MOTOR, 3300 -3800 PSI, 3K WOB, 30 FPH. LOG GR TIE -IN FROM 8880'. CORRECTION OF ( -35'). 19:00 - 19:45 0.75 WHIP P WEXIT MILL CEMENT FROM 9070' MD AT 19:00 HOURS. MILLING AHEAD W/ CONSISTENT 3200 - 3400 PSI, 2.5K - 3K WOB AT -7 FPH. MILL CEMENT TO 9080' CTMD. 19:45 - 20:30 0.75 WHIP P WEXIT PU CLEAN AT 28500 LB. PUH TO LOG. LOG CCL PASS DOWN FROM 8740' TO 9080' MD. CORRELATE - WE HAVE MILLED TO -6' BELOW WLEG. BEGIN POOH. 20:30 - 22:15 1.75 WHIP P WEXIT POOH. OPEN EDC AT 7900' MD. JOG IN HOLE W/ OPEN EDC TO CATCH ANY DEBRIS BETWEEN BIT AND EDC. POOH PUMPING 1.7 BPM AT 3000 PSI WITH FULL RETURNS. 22:15 - 22:30 0.25 WHIP P WEXIT PJSM PRIOR TO LAYING DOWN MOTOR. 22:30 - 23:15 0.75 WHIP P WEXIT AT SURFACE. FLOW CHECK. UNSTAB. LAY DOWN MOTOR AND ADJUST TO 0.7 DEGREE BEND. INSPECT MILL. MILL IS 2.80" GO / 2.79" NOGO. DIAMONDS ON NOSE OF MILL SHOW CONSIDERABLE, EVEN WEAR. 23:15 - 00:00 0.75 WHIP P WEXIT CHECK AND CLEAN HP FILTER. TROUBLESHOOT BLOCKAGE IN CHOKE LINE WHICH WAS DISCOVERED DURING MILLING RUN. TAKE APART CHOKE LINE WHERE BLOCKAGE WAS HEARD AND CLEAR SAME (BLOCKAGE WAS A -4" LONG CEMENT SHEATH). IAP = 10 PSI OAP = 140 PSI CONTINUED ON DIMS REPORT 03/03/10. 3/3/2010 00:00 - 00:15 0.25 WHIP P WEXIT CONTINUED FROM DIMS REPORT 03/02/10. PT CHOKE LINE TO 1500 PSI AFTER HAVING DISMANTLED ONE CONNECTION TO REMOVE BLOCKAGE. GOOD. 00:15 - 00:55 0.67 WHIP P WEXIT MU BHA. MOTOR IS 2 -3/8" XTREME MOTOR W/ NEW 2.81" GO / 2.80" NOGO PARABOLIC DIAMOND SPEED MILL. MOTOR HAS 0.7 DEG BEND. 00:55 - 02:25 1.50 WHIP P WEXIT RIH TO 8100'. WEIGHT CHECK AT 8100': 28600 LB UP WEIGHT, CLEAN. ONLINE AT 1.4 BPM AT 3025 PSI FREESPIN. PVT: 237. RIH PAST PREVIOUS CEMENT TOP. DID NOT SEE PREVIOUS CEMENT TOP (NO MOTOR WORK, NO WEIGHT). HOLDING 20 DEG ROHS ORIENTATION. ECD: 11.14 PPG. 02:25 - 03:15 0.83 WHIP P WEXIT LOG GR TIE -IN FROM 8760' AS PER GEO. TURNING MILL WHILE LOGGING AT 1.4 BPM AT 3025 PSI (11.13 PPG ECD). NO MOTOR WORK, NO WEIGHT BOBBLES. CORRECTION OF ( -27'). Printed: 3/29/2010 11:46:59 AM S BP EXPLORATION Page 4 of 17 Operations Summary Report p Y p Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/3/2010 03:15 - 05:50 2.58 WHIP P WEXIT INCREASE RATE TO 1.56 BPM AT 3260 FREESPIN. RIH TO TAG HOLDING 20 DEG ROHS TF. ECD = 11.27 PPG. PVT: 244. IAP = 120 PSI. OAP = 170 PSI. ENGAGE CEMENT AT 9081.6' MD. BEGIN MILLING AHEAD AT 3400 PSI AND 2K WOB. MILLING AHEAD AT -30 FPH. MILL AT A CONSISTENT 30 FPH TO 9155' MD. PU CLEAN AT 27800 LB. 05:50 - 06:30 0.67 WHIP P WEXIT BACKREAM CONTACT POINT (4' - 10' BELOW TT) TWICE AS PER PROGRAM. MAKE ONE BACKREAM PASS AT 160 DEG LOHS ORIENTATION AS PER PROGRAM. 06:30 - 08:50 2.33 STWHIP P WEXIT WIPER TO ABOVE CEMENT, THEN POH CIRC THRU MILL 1.5/3000 08:50 - 09:30 0.67 STWHIP P WEXIT LD MILLING TOOLS AND LOAD OUT 09:30 - 10:10 0.67 STWHIP P WEXIT MU DUMMY WS ASSY W/ 2.70" MAX OD 10:10 - 11:40 1.50 STWHIP P WEXIT RIH W/ DUMMY WS ASSY CIRC THRU NOZZLE 0.53/1530 11:40 - 12:20 0.67 STWHIP P WEXIT LOG TIE -IN DOWN FROM 8920' TO 9010', CORR -33' 12:20 - 12:30 0.17 STWHIP P WEXIT 26K, 10K RIH TO 9042' AND SET DOWN 3K. PUH W/ 15K OP. INCR RATE TO 1.42/3000. RIH AND SET DOWN AT 9038'. PUH W/ 6K OP 12:30 - 13:50 1.33 STWHIP N DPRB WEXIT POH CIRC THRU NOZZLE 1.56/2800 13:50 - 14:30 0.67 STWHIP N DPRB WEXIT LD DUMMY WS BHA MU CLEANOUT ASSY W/ USED 2.80" D331, 2.73" SR ON BTT STRAIGHT MOTOR 14:30 - 16:15 1.75 STWHIP N DPRB WEXIT RIH CIRC THRU MILL 0.31/1230 to 8100' RIH AT 50' /MIN FROM 8100' CIRC THRU MILL 1.50/3300 TO 8230' 16:15 - 16:35 0.33 STWHIP N DPRB WEXIT LOG TIE -IN DOWN FROM 8930', CORR -29' 16:35 - 17:00 0.42 STWHIP N DPRB WEXIT RIH 15' /MIN 1.50/3230 (11.18 ECD) AND STALLED AT 9038'. PUH W/ 10K OP. REAM IN HOLE SLOWER AND 9038' WAS CLEAN. REAM TO 9041.2' AND HAD MW. REAM TO 9050', CLEAN 17:00 - 17:30 0.50 STWHIP N DPRB WEXIT BACKREAM TO 9130' 29.5K, REAM BACK TO 9050' 8.0K, CLEAN. REAM AT 10' /MIN TO TD, CLEAN AND HAD NO ADDITIONAL MW FROM 9080' (START OF HS HOLE). BACKREAM TO 8900' AT 15' /MIN 1.51/3230, CLEAN 17:30 - 17:40 0.17 STWHIP N DPRB WEXIT DRY DRIFT FROM 8900' TO PBD @ 22' /MIN HAD MINOR WT LOSS AT 9079', BUT OTHERWISE CLEAN 17:40 - 19:20 1.67 STWHIP N DPRB WEXIT BACKREAM TO TOC, THEN CIRC OOH THRU MILL 1.53/3260 19:20 - 19:40 0.33 STWHIP N DPRB WEXIT PJSM FOR LD CLEAN OUT BHA. 19:40 - 20:30 0.83 STWHIP N DPRB WEXIT FLOW CHECK. SB INJECTOR. SWAP BHA. 20:30 - 20:45 0.25 STWHIP N DPRB WEXIT PU INJECTOR. STAB ON W/ DUMMY WHIPSTOCK DRIFT WITH UP ONLY JARS. 20:45 - 22:10 1.42 STWHIP N DPRB WEXIT RIH WITH DUMMY WHIPSTOCK DRIFT. 22:10 - 23:00 0.83 STWHIP N DPRB WEXIT LOG TIE -IN. CORRECTION OF ( -53'). 23:00 - 00:00 1.00 STWHIP N DPRB WEXIT DRIFT TO 9135' MD WHILE CIRCULATING THROUGH NOZZLE AT 0.45 BPM AT 1540 PSI. ENCOUNTER TIGHT SPOT AT 9023' MD (SETTING DOWN 3K WOB AT THIS DEPTH AND OVERPULLING BY 6K BETWEEN 9023' MD AND 9014' MD). OTHERWISE, CLEAN DRIFT DOWN TO 9135' MD. TAG HARD, CLEAN BOTTOM AT THIS DEPTH. THE DIFFERENTIAL DEPTH FROM OUR HARD TAG TO OUR OVERPULL DEPTH IS THE SAME AS THE Printed: 3/29 /2010 11:46:59 AM S BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/3/2010 23:00 - 00:00 1.00 STWHIP N DPRB WEXIT DIFFERENTIAL DEPTH FROM 9155 (WHERE BOTTOM SHOULD BE) TO 9042 (WHERE HARD SPOT FOUND ON MILL RUN). ADDITIONALLY, CORRECTION IS ABNORMALLY HIGH. REQUEST REPEAT TIE -IN. IAP = 25 PSI OAP = 70 PSI CONTINUED ON DIMS REPORT 03/04/10 3/4/2010 00:00 - 00:40 0.67 STWHIP N DPRB WEXIT CONTINUED FROM DIMS REPORT 03/03/10 IAP = 25 PSI OAP = 60 PSI PUH TO REPEAT TIE -IN. CORRECTION OF ( +24'). REVIEW WITH MWD. DISCOVER THAT THEY FORGOT TO INPUT THE DEPTH OFFSET FROM NOZZLE TO GR ON THE LAST TIE -IN. RIH TO DRY DRIFT TO TD. SEE -2K WEIGHT BOBBLE AT 9042' MD. 00:40 - 01:15 0.58 STWHIP N DPRB WEXIT DRY DRIFT TO TD AT 9157' MD. PU CLEAN AT 32.5K LB. ONLINE WITH PUMPS AT 1.5 BPM AT 2900 PSI. PUH PUMPING AT THIS RATE - OVERPULL BY 3K LB FROM 9043' MD TO 9037' MD. DOWN ON PUMP. RBIH TO REPEAT DRY DRIFT BOTH DIRECTIONS. SEE <1000 LB WEIGHT BOBBLE RIH DRY PAST 9043' MD. PUH DRY (DRY UP WEIGHT OF 39K LB) OVERPULL FROM 9044' MD - 9037' MD TO 42K LB. 01:15 - 03:30 2.25 STWHIP N DPRB WEXIT RBIH TO BOTTOM. ONLINE AT 1.5 BPM DOWN CT AT 2890 PSI. CIRCULATE AT 1.5 BPM AND PULL TO SURFACE. 03:30 - 03:45 0.25 STWHIP N DPRB WEXIT PJSM PRIOR TO LD DRIFT AND MU WHIPSTOCK. 03:45 - 04:30 0.75 STWHIP P WEXIT LD DRIFT ASSEMBLY. NO VISIBLE MARKS ON NOZZLE. MU WHIPSTOCK SETTING ASSEMBLY. 04:30 - 06:35 2.08 STWHIP P WEXIT RIH W/ WHIPSTOCK SETTING ASSEMBLY CIRCULATING AT 0.3 BPM AT 970 PSI THROUGH OPEN EDC. 06:35 - 07:05 0.50 STWHIP P WEXIT LOG TIE -IN DOWN FROM 8930' 0.30/1380 10.5K, CORR -28' 07:05 - 07:30 0.42 STWHIP P WEXIT RIH W/ NO WT LOSS TO SETTING DEPTH AT 9133.8' BOWS. CLOSE EDC AND SET WS W/ 4380 PSI AND STACK 3.5K WOB. PUH 34K, TEXTBOOK SET. LEFT WS W/ TOP AT 9125'ATO DEG TF 07:30 - 09:00 1.50 STWHIP P WEXIT POH CIRC THRU TOOL 0.60/1540 09:00 - 10:00 1.00 STWHIP P WEXIT LD WS SETTING ASSY f �� MU MILLING ASSY W/ 2.74" WM, 2.73" SR AND 0.7 DEG BHI MOTOR 10:00 - 11:45 1.75 STWHIP P WEXIT RIH CIRC THRU MILL 0.28/1410 11:45 - 12:10 0.42 STWHIP P WEXIT LOG TIE -IN DOWN FROM 8930', CORR -29' 12:10 - 12:25 0.25 STWHIP P WEXIT RIH 0.28/1390 CLEAN TO TAG AT 9125.0' u• •: • - 12:25 - 15:45 3.33 STWHIP P WEXIT BEGIN TIME MILLING FROM FIRST MW AT 9124.0' 1.53/3150/58 W/ 0 -50 PSI DIFF, 0 -0.5K WOB W/ 11.08 ECD PVT 255 15:45 - 18:00 2.25 STWHIP P WEXIT 9127.0' 1.53/3150/5L W/ 50 -150 PSI MW, 1.0 -2.5K WOB W/ 11.00 ECD PVT 258 CS 18:00 - 19:00 1.00 STWHIP P WEXIT 9128.8' 1.53/3150/1 R W/ 0 -150 PSI MW, 1.5 -3.5K WOB W/ D 10.98 ECD. AT 9128.9, BEGIN STACKING WEIGHT WITH NO ADDITIONAL MOTOR WORK. STOP AND LET EXISTING MOTOR WORK MILL OFF. BEGIN TO MILL AHEAD WITH Printed: 3/29/2010 11:46:59 AM • BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/4/2010 18:00 - 19:00 1.00 STWHIP P WEXIT 500 LB WOB AND 3100 PSI CIRC PRESSURE AT 1 FPH. CALL 9129' BOTTOM OF WINDOW. 19:00 - 21:00 2.00 STWHIP P WEXIT CONTINUE MILLING AHEAD AT 1 FPH FROM 9129' MD TO 9131' MD. MILLING AHEAD WITH -500 LB WOB AND -3050 PSI AT 1.53 BPM. 21:00 - 22:00 1.00 STWHIP P WEXIT CONTINUE MILLING AHEAD AT 2 FPH FROM 9131' TO 9133' MD. MILLING AHEAD WITH -500 LB WOB AND 3100 PSI CIRC PRESSURE AT 1.53 BPM. 22:00 - 22:40 0.67 STWHIP P WEXIT MILLING RATHOLE AT -7 FPH. MILLING AHEAD AT 1.53 BPM AT 3190 PSI AND 2600 LB WOB. ECD: 10.95 PPG. MILL TO 9139' MD ( -10' RATHOLE FROM BOTTOM OF WINDOW). 22:40 - 00:00 1.33 STWHIP P WEXIT PU CLEAN AT 30K LB. PUH BACKREAMING WINDOW AT 1 FPM AT 1.53 BPM AT 3060 PSI. SEE GRADUAL -100 PSI MOTOR WORK (NO OVERPULL) AT 9126' MD. RBIH REAMING AT SAME RATE /PRESSURE, SEE GRADUAL <100 PSI MOTOR WORK AT 9129' MD (NO CORRESPONDING DROP IN WEIGHT). MAKE SECOND BACREAMING PASS THROUGH WINDOW AT 1.5 FPM, SAME PUMP RATE /PRESSURE. SEE GRADUAL 100 PSI MOTOR WORK AT 9128' MD, NO ASSOCIATED OVERPULL. RBIH REAMING AT 1.6 FPM WITH SAME RATE /PRESSURE, CLEAN. MAKE THIRD BACKREAMING PASS W/ SAME RATES /PRESSURES AT 2.5 FPM, CLEAN. RBIH REAMING AT 2 FPM W/ SAME RATES /PRESSURES, CLEAN. PUH BACKREAMING AT 6 FPM AT SAME RATES /PRESSURES, CLEAN. DOWN ON PUMP. DRY DRIFT THROUGH WINDOW RIH AT 13000 LB RIH WEIGHT, 33200 LB UP WEIGHT. DRY DRIFT CLEAN THROUGH WINDOW IN BOTH DIRECTIONS. PARK ABOVE WINDOW. FLOW CHECK - GOOD. IAP = 150 PSI OAP = 300 PSI CONTINUED ON DIMS REPORT 03/05/10 3/5/2010 00:00 - 01:15 1.25 STWHIP P WEXIT CONTINUED FROM DIMS REPORT 03/04/10. IAP = 150 PSI OAP = 300 PSI PULL TO SURFACE WITH WINDOW MILLING BHA CIRCULATING AT 1.8 BPM AT -2800 PSI ON BOTTOM. 01:15 - 01:30 0.25 STWHIP P WEXIT AT SURFACE. PJSM FOR LD WINDOW MILLING ASSEMBLY. FLOWCHECK, GOOD. 01:30 - 02:20 0.83 STWHIP P WEXIT UNSTAB. LAY DOWN WINDOW MILLING BHA. WINDOW MILL AND SR BOTH GAUGED 2.74" GO / 2.73" NOGO. 02:20 - 02:40 0.33 DRILL P PROD1 PUMP SLACK. 02:40 - 02:55 0.25 DRILL P PROD1 PJSM FOR CUTTING COIL TO FIND WIRE. 02:55 - 03:45 0.83 DRILL P PROD1 FIND WIRE AFTER 46'. CONTINUE TO CUT (TOTAL OF 200' CT) FOR COIL MANAGEMENT. 03:45 - 04:20 0.58 DRILL P PROD1 MU CTC. PULL TEST 30K LB (GOOD). 04:20 - 06:15 1.92 DRILL P PROD1 HEAD UP BHI. CREW CHANGE/SAFETY MTG 06:15 - 07:30 1.25 DRILL P PROD1 MU RI III r) RHA WI 3" RI BIT + 2.2 DEG MOTOR + MWD ASSY Printed: 3/29 /2010 11:46:59 AM BP EXPLORATION Page 7 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/5/2010 06:15 - 07:30 1.25 DRILL P PROD1 FIGURE SPACE OUT FOR PUD 07:30 - 09:05 1.58 DRILL P PROD1 RIH CIRC THRU EDC 0.42/1300 09:05 - 09:40 0.58 DRILL P PROD1 LOG TIE -IN DOWN FROM 8930', CORR -31' CLOSE EDC 09:40 - 09:50 0.17 DRILL P PROD1 RIH CIRC THRU BIT 0.30/1460 AND WAS CLEAN THRU PILOT HOLE AND WINDOW. INCR RATE TO 1.52/2980/OR BEFORE TAG AND FOUND TD AT 9139' W/ STALL. PUH 3K OVER AT 37K 09:50 - 13:30 3.67 DRILL P PROD1 DRILL FROM 9139' 1.53/3020/HS W/ 10.94 ECD. START MUD SWAP HARD SPOT AT 9150' CT IS DISPLACED 1.51/3065/58 W/ 11.01 ECD SLOW DRILLING AT 10' /HR. DRILL TO 9190' AND WELLBORE IS DISPLACED PVT 328 13:30 - 14:30 1.00 DRILL P PROD1 DRILL FROM 9190' 1.53/3080/35L W/ 100 -300 PSI DIFF, 1.0 -3.0K WOB W/ 11.12 ECD DRILL TO 9222' 14:30 - 14:50 0.33 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN. PULL THRU WINDOW HOLDING 11.0# ECD. PUH TO LOGGING DEPTH 14:50 - 15:40 0.83 DRILL P PROD1 LOG TIE -IN DOWN TO MOTHER WELLBORE FROM 8880' to 8956', CORR +1' RIH THRU WINDOW, CLEAN. RIH TO 9140'. LOG TIE -IN TO RA PIP IN WS AND FOUND AT 9129.5' TOWS/TOW= 9123.0', RA/BOW= 9129.5' 15:40 - 15:45 0.08 DRILL P PROD1 WIPER TO TD 15:45 - 17:10 1.42 DRILL P PROD1 DRILL FROM 9222' 1.58/3240/10L W/ 200 -400 PSI DIFF, 1.0 -3.0K WOB W/ 11.23 ECD WHICH FINISH BUILDING ANGLE. DRILL TO 9307' 17:10 - 17:30 0.33 DRILL P PROD1 SLOW WIPER FOR DD TO CHECK LANDING POINT 17:30 - 18:05 0.58 DRILL P PROD1 DRILL FROM 9307' TO EOB AT 9350' PVT 346 18:05 - 18:30 0.42 DRILL P PROD1 WIPER TO WINDOW, CLEAN. 18:30 - 19:30 1.00 DRILL P PROD1 OPEN EDC. PULL TO SURFACE PUMPING AT 1.85 BPM THROUGH OPEN EDC FOLLOWING PRESSURE SCHEDULE TO MAINTAIN CONSTANT BHP. 19:30: 1.85 BPM AT 3245 PSI W/ 500 PSI WHP AT 2500'. 19:30 - 20:30 1.00 DRILL P PROD1 DETAILED PJSM AND PROCEDURAL REVIEW FOR PRESSURE UNDEPLOYING. TAG UP AT SURFACE. 20:30 - 22:30 2.00 DRILL P PROD1 PRESSURE UNDEPLOY TOOLSTRING HOLDING 700 PSI WHP (10.9 PPG EMW). FUNCTION TEST BOPE.,- INSPECT BIT. ALL NOZZLES CLEAR. ALL CUTTING STRUCTURES REMAIN INTACT. CALL BIT 1/1. DECIDE TO RE -RUN SAME BIT. 22:30 - 22:45 0.25 DRILL P PROD1 CLEAN LOWER HIGH PRESSURE SCREEN. 22:45 - 23:15 0.50 DRILL P PROD1 PJSM / PROCEDURAL REVIEW FOR PRESSURE DEPLOY. 23:15 - 00:00 0.75 DRILL P PROD1 MU AND PRESSURE DEPLOY LATERAL DRILLING ASSEMBLY. STILL HOLDING -700 PSI WHP (10.9 PPG EMW). IAP = 10 PSI. OAP = 0 PSI. CONTINUED ON DIMS REPORT 03/06/10. 3/6/2010 00:00 - 01:20 1.33 DRILL P PROD1 CONTINUED FROM DIMS REPORT 03/05/10. IAP = 10 PSI Printed: 3/29/2010 11:46:59 AM • S BP EXPLORATION Page 8 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/6/2010 00:00 - 01:20 1.33 DRILL P PROD1 OAP = 0 PSI CONTINUE MU AND PRESSURE DEPLOY LATERAL BHA. 01:20 - 03:00 1.67 DRILL P PROD1 BEGIN RIH PUMPING THROUGH MOTOR FOLLOWING PRESSURE SCHEDULE TO MAINTAIN -11 PPG ECD. 03:00 - 03:30 0.50 DRILL P PROD1 LOG TIE -IN. PUMPING 0.4 BPM AT 1800 PSI THROUGH MOTOR W/ -200 PSI BACKPRESSURE TO MAINTAIN -11 PPG ECD. TIE -IN CORRECTION OF ( -28'). 03:30 - 05:50 2.33 DRILL P PROD1 RIH TO DRILL AHEAD CIRCULATING THROUGH BIT AT 0.4 BPM AT 1800 PSI. CLEAN THROUGH PILOT HOLE AND WINDOW. INCREASE RATE TO 1.47 BPM AT 3150 PSI. TAG AT 9345' MD AND BEGIN DRILLING AHEAD AT 3350 PSI - 3450 PSI W/ 2.4 - 3K WOB (STACKED TO 7200 LB SURFACE WEIGHT). DRILLING AHEAD AT -55 FPH. 05:40 - DRILLING AHEAD AT 9480' MD 3300 - 3400 PSI W/ 2K - 2.6K LB WOB (STACKED TO 7500 LB SURFACE WEIGHT). ECD: 11.1 PPG. DRILLING AHEAD AT -80 FPH. DRILL AHEAD TO 9500' MD. 05:50 - 06:05 0.25 DRILL P PROD1 WIPER FROM 9500'. PU CLEAN AT 29K LB PUMPING AT 1.47 BPM AT 3030 PSI, ECD: 11.2 PPG. IAP = 150 PSI, OAP = 190 PSI. PVT = 356 BBL. 06:05 - 06:50 0.75 DRILL P PROD1 LOG MAD PASS AT 300'/ HR FOR MISSING RES DATA WHILE FIN WIPER TO WINDOW 06:50 - 07:10 0.33 DRILL P PROD1 WIPER BACK TO TD 07:10 - 09:45 2.58 DRILL P PROD1 DRILL FROM 9500' 1.47/3150/80R W/ 100 -300 PSI DIFF, 0.85 -2.4K WOB W/ 11.22 ECD AT 90 DEG AT 7104' TVD AT 50- 70' /HR IN Al DRILL TO 9650' 09:45 - 10:25 0.67 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN BOTH DIRECTIONS 10:25 - 13:30 3.08 DRILL P PROD1 DRILL FROM 9655q 1.49/3180/100L W/ 100 -300 PSI DIFF, 1.0 -3.0K WOB W/ 11.27 ECD AT 90 DEG AT 7103' TVD AT 50-70'/HR 13:30 - 13:50 0.33 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN 13:50 - 14:00 0.17 DRILL P PROD1 LOG TIE -IN, CORR +2' 14:00 - 14:20 0.33 DRILL P PROD1 WIPER TO TD WAS CLEAN 14:20 - 17:00 2.67 DRILL P PROD1 DRILL FROM 9800' 1.51/3150/95L W/ 100 -300 PSI DIFF, 1.3 -3.3K WOB W/ 11.26 ECD AT 90 DEG AT 7105' TVD. DRILL TO 9950' 17:00 - 18:00 1.00 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN BOTH DIRECTIONS 18:00 - 20:00 2.00 DRILL P PROD1 DRILL FROM 9950' 1.52/3170/100L W/ 100 -300 PSI DIFF, 1.2 -3.5K WOB W/ 11.34 ECD AT 90 DEG. 20:00 - 20:40 0.67 DRILL P PROD1 AT 20:00 - DRILLING AHEAD AT 10059' MD AT 1.54 BPM AT 3480 PSI W/ 1.4K LB WOB (STACKED TO 5600 LB AT SURFACE). ECD: 11.43 PPG. PVT: 326 BBL. TF AT 240 DEG ROHS ORIENTATION. IAP = 470 PSI. OAP = 460 PSI. DRILL AHEAD TO 10100' MD. 20:40 - 21:45 1.08 DRILL P PROD1 WIPER FROM 10100' MD. PU CLEAN AT 30K LB. PUH PUMPING AT 1.55 BPM AT 3190 PSI (ECD: 11.41 PPG). PVT: 325. WIPER CLEAN BOTH DIRECTIONS. 21:45 - 00:00 2.25 DRILL P PROD1 BACK ON BOTTOM DRILLING AHEAD. RIH WEIGHT 10500 LB. UP WEIGHT 30K LB. DRILLING AHEAD AT 1.52 BPM AT 3400 - 3500 PSI W/ 1.3K - 2K LB WOB (STACKED TO 7500 LB AT SURFACE). ECD: 11.4 PPG. PVT: 324 BBL. DRILLING AHEAD W/ -245 DEG ROHS TF. Printed: 3/29/2010 11:46:59 AM BP EXPLORATION Page 9 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/6/2010 21:45 - 00:00 2.25 DRILL P PROD1 IAP = 520 PSI OAP = 500 PSI CONTINUED ON DIMS REPORT 03/07/10 3/7/2010 00:00 - 01:00 1.00 DRILL P PROD1 CONTINUED FROM DIMS REPORT 03/06/10 IAP = 520 PSI OAP = 500 PSI DRILL AHEAD AT 3400 - 3500 PSI AT 1.52 BPM W/ 1.5K - 2K LB WOB, ECD: 11.4. PVT: 324 BBL. DRILL AHEAD TO 10250' MD. 01:00 - 01:40 0.67 DRILL P PROD1 WIPER FROM 10250' MD. PU CLEAN AT 30K LB. PUH FOR WIPER AT 1.52 BPM AT 3130 PSI, ECD: 11.34 PPG. WIPER CLEAN. 01:40 - 02:20 0.67 DRILL P PROD1 LOG TIE -IN. CORRECTION OF ( +2.5') 02:20 - 04:15 1.92 DRILL P PROD1 BACK ON BOTTOM DRILLING. DRILL AHEAD FROM 10250' MD AT 1.54 BPM AT 3400 - 3500 PSI W/ 1.6K - 2K LB WOB (STACKING TO 7000 LB AT SURFACE). PVT: 323 BBLS. ECD: 11.45. 04:15 - 05:10 0.92 DRILL P PROD1 DRILLING AHEAD AT 10360' AT 04:15 HOURS. DRILLING AHEAD AT 1.54 BPM AT 3465 PSI W/ 1.7K LB WOB (STACKED TO 5600 LB SURFACE WEIGHT). HOLDING -135 DEG ROHS TF. ECD: 11.5 PPG. PVT: 323 BBL. DRILL AHEAD TO 10400' MD. 05:10 - 06:30 1.33 DRILL P PROD1 PUH FOR WIPER. PU CLEAN AT 30K LB. PUMPING 1.51 BPM AT 3110 PSI (ECD: 11.3 PPG). WIPER TO WINDOW WAS CLEAN BOTH WAYS 06:30 - 08:50 2.33 DRILL P PROD1 DRILL FROM 10400' 1.51/3160/458 AND BEGIN INVERT TO A3 TARGET SAND. DRILL TO 10492' AND HAVE TWO STALLS -NOW AT 96 DEG ON NBI PVT 321 08:50 - 11:05 2.25 DRILL P PROD1 DRILL FROM 10492' (7116' TVD) 1.49/3150/558 W/ 300 PSI DIFF, 1.3 -1.8K WOB W/ 5.4K SURFACE WT W/ 11.54 ECD DUE TO SOLIDS IN MUD. DRILL TO 10550' AND SEE 98 DEG 11:05 - 12:00 0.92 DRILL P PROD1 WIPER TO WINDOW WAS CLEAN. PULL THRU WINDOW, CLEAN. OPEN EDC 12:00 - 12:50 0.83 DRILL P PROD1 CONTINUE WIPER TO 8000' JETTING THRU EDC 1.84/3250 THEN RBIH CLEAN THRU PILOT HOLE AREA -NO ADDITIONAL SOLIDS RETURNED 12:50 - 13:15 0.42 DRILL P PROD1 LOG TIE -IN DOWN FROM 8915' 1.70/3000, CORR +5'. RIH TO WINDOW, CLOSE EDC 13:15 - 14:00 0.75 DRILL P PROD1 WIPER TO TD WAS CLEAN EXCEPT FOR ONE SETDOWN IN RUBBLE ZONE AT 10030' 14:00 - 15:00 1.00 DRILL P PROD1 DRILL FROM 10551' TO 10592' AND SEE TOP OF Al 15:00 - 16:30 1.50 DRILL P PROD1 SLOW WIPER TO 10060' WHILE GEO'S DISCUSS PVT 316 16:30 - 19:20 2.83 DRILL P PROD1 DRILL FROM 10592' (7095' TVD) 1.49/3290/90 -120R W/ 200 -400 PSI DIFF, 1.5 -2.0K WOB W/ 4.2K SURFACE WT AT 40- 80' /HR AT 104 DEG AND START BREAK OVER TO 100 DEG TO CUT THRU A3. DRILL TO 10700' MD. 19:20 - 21:30 2.17 DRILL P PROD1 WIPER TO WINDOW CLEAN BOTH DIRECTIONS. UP WEIGHT 30,100 LB. RIH WEIGHT 9000 LB. FREESPIN 1.46 BPM AT 3260 PSI. 21:30 - 22:15 0.75 DRILL P PROD1 TAG AT 10700.6' MD AND RESUME DRILLING AHEAD. DRILLING AHEAD AT 3500 - 3600 PSI W/ 1.5K - 2.5K LB Printed: 3/29/2010 11:46:59 AM S BP EXPLORATION Page 10 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/7/2010 21:30 - 22:15 0.75 DRILL P PROD1 WOB, ECD: 11.69 PPG. PERFORM MUD SWAP TO NEW 8.8 PPG GEOVIS. AT - 10740' MD, START STACKING MORE AND MORE SURFACE WEIGHT (DOWN TO -2000 LB) TO MAINTAIN 2500 LB WOB. AT 10747.6' MD, BEGIN LOSING 70% RETURNS. PU AND CHECK SURFACE LINES, CONFIRM THAT LOSSES ARE DOWNHOLE. GET WORD FROM GEOS, THEY WILL TENTATIVELY CALL TD EARLY (THEY BELIEVE WE HAVE ALREADY PENETRATED INTO SHALE ZONE). 22:15: GEOS TENTATIVELY CALL TD AT 10762.7' MD. PU CLEAN AT 30,500 LB. BEGIN WIPER TO WINDOW WHILE GEOS CONFIRM TD W/ TOWN. 22:15 - 23:15 1.00 DRILL P PROD1 GEOS CONFIRM TD W/ TOWN. LOSSES GRADUALLY HEAL AS WE PUH FOR WIPER. RETURNS BACK TO 1:1 BY - 10375' MD. TAKE SAMPLE OF RETURNS AT BOTTOMS -UP FROM TD - SHALE COMIING BACK OVER SHAKER, INCLUDING SEVERAL THIN PIECES 0.25" BY 0.25" (SMALL FINGERNAIL SIZED). 23:15 - 00:00 0.75 DRILL P PROD1 LOG TIE -IN (CORRECTION OF ( +4.5') IAP = 340 PSI OAP = 370 PSI CONTINUED ON DIMS REPORT 03/08/10. 3/8/2010 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUED FROM DIMS REPORT 03/07/10. IAP = 340 PSI OAP = 370 PSI RBIH AFTER TIE -IN AT 1.5 BPM / 3450 PSI (FREESPIN W/ NEW MUD). TAG AND STACK WEIGHT (WITH CORRESPONDING -250 PSI MOTOR WORK) AT 9881' MD. PU STICKY (16K OVER) UNTIL BREAK CLEAN AT 9860' MD. REPEAT WITH SIMILAR RESULTS. REDUCE PUMP RATE TO 0.85 BPM AND RIH CLEAN TO 9925' MD. STOP HERE, INCREASE RATE TO 1.5 BPM AT 3450 PSI AND BACKREAM THROUGH TROUBLE SPOT. SEE -200 PSI MOTOR WORK FROM 9895 - 9860' MD. REDUCE RATE TO 0.85 BPM AND RBIH TO 9925' MD CLEAN. MAKE SECOND BACKREAMING PASS AT 1.5 BPM, CLEAN. RBIH AT 0.9 BPM CLEAN TO 9925' MD. INCREASE PUMP RATE TO 1.5 BPM AND CONTINUE RIH. 00:30 - 01:30 1.00 DRILL P PROD1 RIH AT 1.5 BPM / 3450 PSI. TAG AT 10555' MD, STACK WEIGHT AND SEE CORRESPONDING -150 PSI MOTOR WORK. PU CLEAN. REDUCE RATE TO RUN PAST TAG. PUH BACKREAMING AT 1.5 BPM PAST OBSTRUCTION DEPTH, STALL AT 10540' MD. REDUCE RATE, OVERPULLING (8K). ATTEMPT TO RIH, STACKING WEIGHT. PU, OVERPULL 12K AND PULL FREE. RBIH AT 0.8 BPM PAST OBSTRUCTION DEPTH CLEAN. PUH BACKREAMING AT 1.5 BPM PAST OBSTRUCTION DEPTH, CLEAN. RBIH PAST OBSTRUCTION DEPTH AT 0.8 BPM CLEAN. CONTINUE RIH. 01:30 - 01:45 0.25 DRILL P PROD1 CONTINUE RIH TO TAG TD. GRADUALLY SEEING LOSSES AGAIN FROM 10670' MD. TAG TD AT 10762' MD (LOSSES ARE 1.25 BPM WHEN PUMPING AT 1.5 BPM). PUH Printed: 3/29/2010 11:46:59 AM I • BP EXPLORATION Page 11 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/8/2010 01:30 - 01:45 0.25 DRILL P PROD1 LEAVING CLEAN MUD IN OH EXPERIENCING -85% I C)SSFS 01:45 - 03:30 1.75 DRILL P PROD1 PUH TO WINDOW, PARK AT 9100' MD. LOSSES STILL GREAT, RETURNING JUST A TRICKLE ( <0.2 BPM) AT SURFACE PUMPING 1 BPM. REDUCE RATE TO 0.5 BPM, LOSSES NEARLY 100 %, JUST A TRICKLE RETURNING AT SURFACE. PUH TO 8000' MD (ABOVE CEMENT SHEATH). PARK AT 8000' MD, PUMPING 0.5 BPM AND RETURNING -0.15 BPM. ECD AT THIS RATE / DEPTH IS 10. 54 PPG. 03:30 - 04:20 0.83 DRILL P PROD1 PJSM WITH ENTIRE CREW REGARDING PLAN FORWARD. PLAN TO PERFORM FLOW CHECK FOR 5 MINUTES AND MONITOR FOR FLOW AND /OR RECORD FILL UP VOLUME. FLOW CHECK. NO FLOW. WATCH ECD AS MEASURED AT TOOL. ECD SLOWLY FALLS TO 9.8 PPG OVER THE 5 MINUTE SI INTERVAL. AFTER 5 MINUTES, COME ONLINE TO FILL HOLE. TOOK 1.5 BBL TO FILL HOLE. BACK ONILNE AT 0.5 BPM W/ 0.15 BPM RETURNS, ECD: 10.47 PPG. 04:20 - 09:00 4.67 DRILL P PROD1 F3FMAIN PARKFD AT 8000' MD (OCCASIONALLY RECIPROCATING CT). REDUCE PUMP RATE DOWN CT TO 0.39 BPM, RETURNING -0.15 BPM (AT THESE LOW RETURN RATES, RETURN MM RATE FLUCTUATES, BUT WE ARE MAINTAINING A STEADY TRICKLE AT SURFACE). WO MUD/WOO PUH WHILE MOVING CT EVERY 15 MIN TO 7800' PVT 90 09:00 - 12:50 3.83 DRILL P PROD1 CIRC 0.38/0.27/1660, 0.51/0.38/1760 W/ 10.57 ECD WHILE WO MUD RIH WHILE MOVING CT EVERY 15 MIN PVT 64 (FRESH MUD) 12:50 - 13:20 0.50 DRILL P PROD1 RIH FROM 7950' CIRC 0.51/1840 RECEIVED 290 BBLS OF USED MUD, 290 BBLS NEW MUD IS LEAVING MI (W/ D16 MOVING TO MPU AND AT S PAD SWAP TO USED MUD DOWN CT 13:20 - 13:45 0.42 DRILL P PROD1 LOG DOWN FROM 8910', CORR +5' 0.50/0.32.1780 13:45 - 14:40 0.92 DRILL P PROD1 RIH THRU WINDOW 0.50/0/1800 W/ 10.42 ECD AND WAS CLEAN TO EOB INCR RATE TO 1.47/0.38/3100 W/ 10.73 ECD LOST WT AT 9812', BUT ABLE TO CONTINUE IN HOLE W/ MW. HOLE WAS CLEAN TO 10695'. hOWEVER, BY 10660' CTP WAS INCREASING TO 3250 PSI AND RETURNS WERE INCREASING FROM 0.6 BPM TO 1.0 BPM (ACTING LIKE MUSH /SOLIDS). STOP AT 10695' AND PUH 30.3K 14:40 - 15:35 0.92 DRILL P PROD1 IMMEDIATELY LOST MOST OF RETURNS BACK TO 0.2 BPM. BACKREAM 10' /MIN AND CTP SLOWLY INCREASED BACK TO 3200 PSI AND RETURNS CAME BACK FROM NEARLY ZERO TO 0.85. WIPER UP HOLE 10' /MIN 1.49/0.80/3150 W/ 11.21 ECD. HAD 5K OP AT 10620' AND LOST 0.3 BPM RETURNS 1.49/0.53/3090 W/ 11.0 ECD PUH TO 10100', CLEAN W/ NO OTHER CHANGES WHILE CBU FROM 9800'. SAW NO EXTRA SOLIDS OR HYDROCARBONS AT BU 15:35 - 16:00 0.42 DRILL P PROD1 WIPER BACK TO FINISH CLEANOUT AND LOST MOST OF Printed: 3/29/2010 11:46:59 AM • • BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/8/2010 15:35 - 16:00 0.42 DRILL P PROD1 RETURNS 1.49/0.14/3000 W/ 11.0 ECD. START REGAINING RETURNS AT 10590' 1.49/0.54/3100 W/ 11.11 ECD. RIH 20' /MIN AND HAD 1.49/0.86/3248 © 10650' W/ 11.45 ECD, 1.46/1.10/3400 W/ SET DOWN AT 10675' DUE TO TF CHANGE. BACKREAM TO 10650' 1.49/0.10/2850 W/ 10.49 ECD FRESH MUD ARRIVES 16:00 - 16:35 0.58 DRILL P PROD1 RIH CLEAN W/ WT LOSS AT 10690' 1.49/0.15/2930 W/ 10.75 ECD. _CLEAN OUT TO 10720' AND LOST ALL RETURNS. PUH 30K AT 10' /MIN 1.50/0.14/3020 W/ 10.91 ECD AND SWAP TO FRESH MUD DOWN CT. PUH TO 10520', CLEAN. RBIH 1.48/0.71/3240 W/ 11.32 ECD INITIALLY AND 1.49/1.30/3325 W/ 11.56 ECD AT 10690' AND THEN LOST RETURNS BACK TO 0.15 BPM. CLEAN OUT TO 10720' W/ 1.48/0.10/2930 W/ 10.61 ECD W/ FRESH MUD AT BIT 16:35 - 18:00 1.42 DRILL P PROD1 WIPER BACK THRU OH AT 25' /MIN. PULL THRU WINDOW, CLEAN 18:00 - 19:20 1.33 DRILL P PROD1 POH CIRC THRU BIT 1.25/0.5/1850 19:20 - 20:00 0.67 DRILL P PROD1 PARK AT 250' MD AND CIRCULATE AT 0.25 BPM AT -450 PSI. RETURNS -0.2 BPM. PJSM W/ ALL HANDS, REVIEW UPDATED PLAN FORWARD AND DISCUSS DETAILS. 20:00 - 23:00 3.00 DRILL P PROD1 SHUT DOWN FOR 5 MIN FLOW CHECK - NO FLOW. WHILE SHUT DOWN, OPEN EDC. AFTER 5 MINUTE FLOW CHECK, TOOK <0.1 BBL TO FILL WELL. CONTINUE TO CIRCULATE AT 0.27 BPM AT 380 PSI THROUGH OPEN EDC W/ FULL RETURNS WHILE PARKED AT 250' MD. RECIPROCATE COIL EVERY -30 MINUTES. WO BTT TO ARRIVE W/ IBP SETTING ASSEMBLY. 23:00 - 23:30 0.50 DRILL P PROD1 PJSM W/ BTT REGARDING UPCOMING TOOL ASSEMBLY. 23:30 - 23:50 0.33 DRILL P PROD1 PULL TO SURFACE. TAG UP. FLOW CHECK (GOOD, NO FLOW AND NO DRINKING). CLOSE EDC. 23:50 - 00:00 0.17 DRILL P PROD1 UNSTAB. BEGIN LD DRILLING BHA. CALL BIT 1/1, WORN TEETH. IAP = 10 PSI OAP = 0 PSI CONTINUED ON DIMS REPORT 03/09/10 3/9/2010 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUED FROM DIMS REPORT 03/08/10. IAP = 10 PSI OAP = 0 PSI FINISH LD DRILLING ASSEMBLY. FILL UP HOLE AT 00:30 - TOOK 1 BBL TO FILL UP. 00:30 - 01:10 0.67 DRILL P PROD1 MU IBP SETTING ASSEMBLY. THIS IS A BTT PERMANENT IBP. THERE IS ONE JT 2 -3/8" LINER W/ BULLNOSE CAP BELOW JT OF LINER. TOTAL LENGTH FROM TOP OF IBP (ONCE SET) TO BOTTOM OF BULLNOSE IS 38.45'. PJSM W/ BTT AND SLB DRILLER REGARDING SETTING TOOL. VERY IMPORTANT NOT TO APPLY A DIFFERENTIAL PRESSURE AT TOOL UNTIL READY TO SET. 01:10 - 01:20 0.17 DRILL P PROD1 STAB ON. OPEN EDC. 01:20 - 03:40 2.33 DRILL P PROD1 ONLINE DOWN CT AT MIN RATE. TAKES 2.3 BBLS TO GET RETURNS AT SURFACE. BEGIN RIH PUMPING DOWN CT AT 0.2 BPM AT 540 PSI W/ TRICKLE OF Printed: 3/29/2010 11:46:59 AM • • BP EXPLORATION Page 13 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/9/2010 01:20 - 03:40 2.33 DRILL P PROD1 RETURNS THROUGH OPEN EDC. 02:40 - RIH AT 76 FPM AT 5320' MD PUMPING AT 0.2 BPM AT 720 PSI W/ 0.3 BPM RETURNS. 03:40 - 04:20 0.67 DRILL P PROD1 LOG TIE -IN PASS DOWN FROM 8929'. PUMPING 0.21 BPM AT 750 PSI W/ JUST A TRICKLE OF RETURNS. CORRECTION OF ( -29'). CONTINUE RIH. 04:20 - 05:20 1.00 DRILL P PROD1 WEIGHT CHECK AT 10666' MD. PU CLEAN AT 31K LB. PUMPING THROUGH OPEN EDC AT 785 PSI AT 0.2 BPM W/ FULL RETURNS. 05:20 - 06:00 0.67 DRILL P PROD1 TAG TD AT 10764' MD. ACHIEVE 1K LB WOB. PJSM REGARDING SETTING IBP. DOWNHOLE TEMP TOOL INDICATES THAT IBP HAS ALREADY REACHED THERMAL EQUILIBRIUM. CIRCULATING THROUGH OPEN EDC AT 0.2 BPM W/ FULL RETURNS. PUH TO FULL UP WEIGHT AND POSITION BULLNOSE -0.5' OFF BOTTOM. TOP OF IBP (ONCE HYDRAULIC SETTING TOOL IS OFF OF IBP) IS 10725' MD. CENTER OF IBP ELEMENT IS 10729.45' MD. DOWN ON PUMP. COME CLOSED W/ EDC. HOLD -130 PSI DIFFERENTIAL PRESSURE ON IBP SETTING TOOL FOR -4 MINUTES. INCREASE TO 400 PSI DIFFERNTIAL PRESSURE FOR 5 MINUTES. INCREASE TO -700 PSI DIFFERNTIAL PRESSURE FOR 10 MINUTES. RETURNING A SMALL TRICKLE OF FLUID AT SURFACE. WOB INDICATOR HAS CLIMBED FROM NEUTRAL TO -1900 LB OVER THE COURSE OF SETTING THE IBP. SLACK OFF ON IBP AS PER BTT. STACK ADDITIONAL 1400 LB WOB (TO 3300 LB) 1' MORE SHALLOW THAN WHERE WE TAGGED BOTTOM. PARK IN COMPRESSION AND HOLD 975 PSI DIFFERENTIAL PRESSURE AT TOOL FOR 3 MINUTES. INCREASE DIFFERENTIAL PRESSURE AT TOOL TO 1055 PSI OVER A 5 MINUTE INTERVAL (WE ARE STILL IN COMPRESSION, CURRENTLY SHOWING 3.4K LB WOB). INCREASE DIFFERENTIAL PRESSURE AT TOOL TO 1360 PSI FOR 3 MINUTES. WOB NOW READING 3.8K LB. INCREASE PRESSURE TO 1800 PSI, PRESSURE BREAKS OVER AND BEGINS FALLING LINEARLY. DOWN ON PUMP. PU OFF OF IBP, PU CLEAN AT 31.2K LB. CT PRESSURE FALLS MORE SHARPLY ONCE FULL STRING WEIGHT ACHIEVED. PUH AT 5 FPM AND COME BACK ONLINE DOWN CT W/ CLOSED EDC (PUMPING THROUGH SETTING TOOL) AT 0.5 BPM AT 970 PSI. SHORT STORY -TEXT BOOK SET OF IBP W/ TOP AT 10725' AND BOTTOM OF SHOE AT TD (10762') 06:00 - 10:00 4.00 DRILL P PROD1 PUH 5' /MIN CIRC 0.51/0.36/1000, 1.06/0.80/1490, 1.50/1.01/2050 WHILE CBU. GOT BOTTOMS UP GAS. CONTINUE TO PUH SLOW. AT 10400' 1.00/ ?/1410, AT 10120' 1.00/0.86/1360 W/ NO GAS OR OIL 10:00 - 10:55 0.92 DRILL P PROD1 CIRC AT WINDOW 0.50/0.45/900 WHILE WO BRINE 10:55 - 12:30 1.58 DRILL P PROD1 START 9.8# NACL DOWN CT AND TAKE 8.9# MUD BACK TO PITS 1.09/0.99/1440 INITIAL W/ 10.04 ECD. SWAP WELL TO 9.8# NACL KW F. 12:30 - 12:55 0.42 DRILL P PROD1 FLOW CHECK WELL. 12:55 - 14:30 1.58 DRILL P PROD1 POH. Printed: 3/29 /2010 11:46:59 AM • • BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/9/2010 14:30 - 15:15 0.75 DRILL P PROD1 POP OFF WELL. LD BHA. 15:15 - 16:31 1.27 DRILL P PROD1 REMOVE UQC. PUMP OUT SLACK, RECOVERED 272' OF CABLE. 16:31 - 17:00 0.48 DRILL P PROD1 MU CTC. PULL TEST TO 30K & PRESSURE TEST TO 4K. 17:00 - 20:15 3.25 CASE P RUNPRD PREP FLOOR FOR MU LINER. 20:15 - 00:00 3.75 CASE P RUNPRD MU LINER. DRIFT EACH CONNECTION. FILL HOLE EVERY 5 JTS _ 306BLS LOST IN 4HRS. 3/10/2010 00:00 - 01:15 1.25 CASE P RUNPRD CONTINUE TO MU LINER. DRIFT EACH CONNECTION. FILL HOLE EVERY 5 JTS - 5 BBLS LOST. 01:15 - 01:25 0.17 CASE P RUNPRD PJSM REGARDING MU INNER 1" STRING. 01:25 - 02:00 0.58 CASE P RUNPRD C/O ELEVATORS. RU FALSE TABLE. PREP FLOOR FOR 1" STRING. 02:00 - 05:00 3.00 CASE P RUNPRD MU 1" INNER STRING. FILL OH BACK SIDE - 15BBLS. 05:00 - 05:25 0.42 CASE P RUNPRD RD FALSE TABLE. RU & TEST 2- 3/8 "x1" BACKSIDE. RU TEST EQUIPMENT. 05:25 - 08:30 3.08 CASE P RUNPRD MU 1" CSH TO 2 -3/8" LINER. MU LINER AND 6 JTS 2- 1/16" PH -6 TO INJECTOR.. CIRC 3/4 BALL THRU COIL. STAB ONTO WELL. 08:30 - 08:45 0.25 CASE P RUNPRD PJSM TO RIG UP CEMENTERS. 08:45 - 11:00 2.25 CASE P RUNPRD RIH W/ LINER. 11:00 - 11:15 0.25 CASE P RUNPRD LAND LINER ON HARD BOTTOM FOUR TIMES. PU CLEAN 39K. 11:15 - 11:30 0.25 CASE P RUNPRD PJSM TO DROP 5/8" STEEL BALL TO RELEASE FROM LINER. 11:30 - 12:30 1.00 CASE P RUNPRD LAUNCH BALL, DID NOT HEAR IT GO AROUND REEL. PUMPING 1.25 BPM IN/ 0.55 BPM OUT/ 4400PSI. PVT: 135 10K WT DOWN. PUMPED 50 BBL NO BALL ON SEAT. CALC 39.2 BBL FOR BALL ON SEAT. 12:30 - 13:00 0.50 CASE N SFAL RUNPRD PJSM TO BREAK OFF VALVE IN REEL TO LOOK FOR BALL 13:00 - 13:50 0.83 CASE N SFAL RUNPRD PULLED CAP ON INNER REAL HARDWARE AND FOUND BALL. BALL LAUNCH 180 DEGREE FROM OPTIMAL, USE HOSE TO FISH BALL UP AND OVER INNER REEL HARDWARE. 13:50 - 16:00 2.17 CASE N SFAL RUNPRD LAUNCHED BALL, HEARD BALL GOING AROUND. BALL LEFT REEL HOUSE AT 16 BBL. PUMPING 1.3 BPM /4600PSI. PVT: 107 AT 27 BBLS AWAY SLOW PUMPS TO .46 BPM /680PSI. AT 79.2 BBLS AWAY DECIDE TO PUMP ANOTHER STEEL BALL. LOSSES AVERAGING 47 %. 16:00 - 16:15 0.25 CASE N SFAL RUNPRD PJSM TO PUMP SECOND STEEL BALL. 16:15 - 16:40 0.42 CASE N SFAL RUNPRD LAUNCH SECOND BALL. AT 4.9 BBLS AWAY FIRST BALL ON SEAT. RAMPED UP AND SHEARED AT 3650 PSI. PUMPING SECOND BALL OUT OF REELAND DOWN HOLE. 16:40 - 17:10 0.50 CEMT P RUNPRD PJSM TO PT CEMENT LINES AND PUMP CMT 17:10 - 18:00 0.83 CEMT P RUNPRD PUMP WATER TO CEMENTERS TO CHARGE LINES. BYPASS MM AND PT CMT LINES TO 6000 PSI FOR 1 MIN Printed: 3/29 /2010 11:46:59 AM • BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/10/2010 17:10 - 18:00 0.83 CEMT P RUNPRD BATCH UP TIME 17:40. 18:00 - 19:15 1.25 CEMT P RUNPRD MM ZERO AT 14PPG PUMPING CEMENT INTO COIL 1 BPM /3600PSI /0.5BPM RETURN RATE PI IMP 15 BBLS OF 15.8 PPG. FOLLOWED BY 9 8, KCI /2 #B10. DURING CEMENT DISPLACEMENT TO THE SHOE, 1 BPM /3600PSI /0.25- 0.4BPM RETURN RATE. , DURING DISPLACEMENT, REDUCE PUMP RATE TO 0.75BPM /3000PSI /0.25BPM. ACHIEVE 7.8RRI S CEMENT ON THE BACKSIDE (1.2BBLS ABOVE TOL). SHUT DOWN & PUH. DISPLACE 2BBLS OF REMAINING CEMENT INSIDE THE CSH, 0.8BPM /2125PSI/0.8BPM. 19:15 - 19:40 0.42 CEMT P RUNPRD PUH TO 9100' PUMPING 1 FOR 1, 0.55/1490PSI. 19:40 - 20:30 0.83 CEMT P RUNPRD RIH PUMPING 0.55BPM/1465PSI, 1 FOR 1 RETURNS. RECOVERED - 1BBL OF CRUDE MIXED KCL IN THE RETURNS BEFORE RECOVERING - 9BBLS OF 10.1PPG CEMENT LADEN FLUID & _ 15BBLS OF 9.9PPG CEMENT LADEN FLUID. 20:30 - 22:50 2.33 CEMT P RUNPRD POH & JET TOL AT 9050' WITH 1 FOR 1 RETURNS. 22:50 - 23:00 0.17 CEMT P RUNPRD FLOW CHECK - NO FLOW. 23:00 - 00:00 1.00 CEMT P RUNPRD LD BHA. 3/11/2010 00:00 - 02:05 2.08 CEMT P RUNPRD CEMENT IS AT 500PSI CS @ MIDNIGHT. CONTINUE TO LD LINER BHA. RECOVERED 2 BALLS. 02:05 - 02:35 0.50 CEMT P RUNPRD HOIST DOWN BOT LINER RUNNING TOOLS. 02:35 - 02:50 0.25 CEMT P RUNPRD MU SWIZZLE STICK BHA. 02:50 - 03:05 0.25 CEMT P RUNPRD JET STACK & CLEAN DEAD LEGS. 03:05 - 03:20 0.25 CEMT P RUNPRD LD SWIZZLE STICK. 03:20 - 03:35 0.25 EVAL P LOWER1 PJSM REGARDING MU MILL/FCO BHA. 03:35 - 07:00 3.42 EVAL P LOWER1 MU MILL/FCO BHA. 07:00 - 10:00 3.00 EVAL P LOWER1 RIH W /MILL AND MOTOR. .97/1.04/2730 UP WT 27.5K AT 8950'. SMALL AMOUNT OF GAS RETURNS FOR 2 MIN. PVT: 171 BBLS 10:00AM TAGGED BOTTOM TWICE AT 10733' UNCORRECTED W/ 2K WOB 10:00 - 12:15 2.25 EVAL P LOWER1 POOH UP WT 29.4k AT 10700'. .99/.91/2615 PVT: 149 BBLS 11:30AM 12:15 - 12:30 0.25 EVAL P LOWER1 PJSM TO LD BHA 12:30 - 14:45 2.25 EVAL P LOWER1 LD BHA 14:45 - 15:00 0.25 EVAL P LOWER1 REPAIR INJECTOR GOOSENECK NUT. 15:00 - 15:30 0.50 EVAL P LOWER1 PJSM TO RU AND RUN LOGGING TOOLS WITH A NEUTRON SOURCE. 15:30 - 18:00 2.50 EVAL P LOWER1 RU LOGGING BHA. 18:00 - 19:15 1.25 EVAL P LOWER1 RIH TO 8600'. 19:15 - 19:50 0.58 EVAL P LOWER1 LOGGING DOWN AT 60 FPM. C/O WITH NIGHT WSL. TAG AT 9100'. 19:50 - 20:55 1.08 EVAL N HMAN LOWER1 POH. CROSS OVER TAGGED LINER TOP DEPLOYMENT SLEEVE. OD OF CROSS OVER LARGER THAN ID OF DEPLOYMENT Printed: 3/29 /2010 11:46:59 AM • • BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/11/2010 19:50 - 20:55 1.08 EVAL N HMAN LOWER1 SLEEVE. PJSM REGARDING STANDING BACK CSH. 20:55 - 21:05 0.17 EVAL N HMAN LOWER1 FLOW CHECK - NO FLOW. 21:05 - 23:30 2.42 EVAL N HMAN LOWER1 POP OFF WELL. PLACE INJECTOR OVER BUNG HOLE. LD 6JTS OF 2- 1/16" CSH. STAND BACK 54 JTS OF 1" CSH INTO THE DERRICK. 23:30 - 00:00 0.50 EVAL N HMAN LOWER1 INSPECT & TEST LOGGING TOOLS - OK. CHANGE OUT CROSS OVER. 3/12/2010 00:00 - 00:15 0.25 EVAL N HMAN LOWER1 PJSM REGRADING MU LOGGING BHA. CEMENT IS AT 2000PSI CS. 00:15 - 02:35 2.33 EVAL N HMAN LOWER1 MU BHA. TORQUE EACH CSH CONNECTION, FIVE LOOSE CONNECTIONS. 02:35 - 03:55 1.33 EVAL N HMAN LOWER1 RIH WITH LOGGING BHA. 03:55 - 05:10 1.25 EVAL N HMAN LOWER1 LOG DOWN AT 30' /MIN FROM 8700'. TAG BOTTOM TWICE AT 10737. 05:10 - 05:50 0.67 EVAL P LOWER1 LOG UP AT 60' /MIN WHILE LAYING IN 5BBL 150K I SRV PERF PILL. PAINT FLAG AT 10430'. RESUME LOGGING UP. STOP AT 8700'. 05:50 - 07:00 1.17 EVAL P LOWER1 POH. 07:00 - 07:15 0.25 EVAL P LOWER1 PJSM TO LD BHA. FLOW CHECK -GOOD 07:15 - 10:00 2.75 EVAL P LOWER1 LD 6 JTS 2- 1/16" CSH AND STOOD BACK 54 JTS 1" CSH. LD SLB LOGGING TOOL WITH NEUTRON SOURCE. 10:00 - 10:30 0.50 EVAL P LOWER1 PJSM FOR LINER LAP TEST. FAILED 3000 PSI LINER LAP TEST. INJECTED AWAY AT 2250 TWICE. DROPPED TO 1825PSI IN 2 MIN. 10:30 - 10:45 0.25 EVAL P LOWER1 PJSM TO LOAD GUNS IN PIPE SHED. 10:45 - 11:00 0.25 EVAL P LOWER1 LOAD GUNS INTO PIPE SHED 12:15 - 12:30 0.25 EVAL P LOWER1 PJSM TO MU PERFORATING BHA. 12:30 - 12:40 0.17 EVAL P LOWER1 INJECTOR SLING INSPECTION 12:40 - 15:00 2.33 EVAL P LOWER1 MU PERFORATING BHA. 54 JTS 1"CSH. 6JTS 2- 1/16" CSH. 15:00 - 17:25 2.42 EVAL P LOWER1 RIH. 17:25 - 17:40 0.25 EVAL P LOWER1 TAG BOTTOM CORRECT DEPTH. PRACTICE FIRING SEQUENCE. 17:40 - 19:35 1.92 EVAL P LOWER1 GOOD INDICATION GUNS FIRED. BOTTOM PERF AT 10,705' WHILE PULLING UP HOLE. PERFORATE VIA 1.56" 6SPF 1606PJ PERF GUNS FROM 10560'- 10640' & 10660'- 10705'. FLOW CHECK AT TOL. PJSM REGARDING HANDLING BHA. 19:35 - 19:50 0.25 EVAL P LOWER1 FLOW CHECK WELL. 19:50 - 21:55 2.08 EVAL P LOWER1 POP OFF WELL. PLACE INJECTOR OVER BUNG HOLE. LD 6JTS OF 2- 1/16" PH6. STAND BACK 54JTS OF 1" CSH. 21:55 - 22:05 0.17 EVAL P LOWER1 PJSM REGARDING LD GUNS. 22:05 - 23:15 1.17 EVAL P LOWER1 RU FARR TONGS. LD 8 PERF GUNS - ALL SHOTS FIRED. 23:15 - 00:00 0.75 BOPSUF P LOWER1 FUNCTION TEST BOPE PER AOGCC REGS - GOOD TEST._ 3/13/2010 00:00 - 00:20 0.33 BOPSUF P LOWER1 CONTINUE TO FUNCTION TEST BOPE - PASS. 00:20 - 00:55 0.58 ZONISO P LOWER1 HOIST KB PACKER TO RF. 00:55 - 01:10 0.25 ZONISO P LOWER1 PJSM REGARDING MU KB PACKER BHA. 01:10 - 02:10 1.00 ZONISO P LOWER1 MU KB PACKER BHA. Printed: 3/29 /2010 11:46:59 AM • • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: MPF -82 Common Well Name: MPF -82 Spud Date: 8/27/2000 Event Name: REENTER +COMPLETE Start: 2/27/2010 End: 3/30/2010 Contractor Name: NORDIC CALISTA Rig Release: 3/30/2010 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 3/13/2010 02:10 - 04:10 2.00 ZONISO P LOWER1 RIH WITH KB PACKER. WT CK @ 8980' = 30K. 12.6K RIW. CIRC 0.4BPM /586PSI. STING INTO TOL @ 9083', SET DOWN 10K. REPEAT TWICE. 04:10 - 05:20 1.17 ZONISO P LOWER1 PUMP STEEL 5/8" BALL, 1.32BPM/1575PSI WITH 0.7BPM OUT. AT 23BBLS AWAY, REDUCE TO 0.5BPM /670PSI/0.35BPM OUT. AT 29BBLS AWAY REDUCE TO 0.3BPM /520PSI /0.25BPM OUT. BALL ON SEAT AT 30.5BBL. BLEED OFF CTP. 05:20 - 06:00 0.67 ZONISO P LOWER1 RIH. STING INTO TOL & SET 10K DOWN. PUH TO BREAK OVER + 1 FT. PRESSURE UP TO 2500PSI & ENGAUGE PACKER ELEMENT. ATTEMPT TO SET MORE WT DOWN, CTP BLED DOWN TO OPSI. ATTEMPT TO PRESSURE UP, 0.3BPM /575PSI/0.3BPM OUT. ATTEMPT TO PRESSURE UP ON THE BACKSIDE. WHP HOLDS BUT CTP TRACKS. KB PACKER APPEARS TO BE SET. PRESSURE UP TO 2000PSI (MAX OPERATING PRESSURE FOR SMALL PACKERS). 06:00 - 06:30 0.50 ZONISO P LOWER1 06:00 CTP 2030PSI, WHP 2014PSI, IAP 13PSI. 06:15 CTP 2025PSI, WHP 2018PSI, IAP 15PSI. 06:30 CTP 2025PSI, WHP 2018PSI, IAP 13PSI. PASS. 06:30 - 08:10 1.67 ZONISO P LOWER1 POOH W /BHA. PJSM TO LD BHA. 08:10 - 09:00 0.83 ZONISO P LOWER1 LD 6 JTS 2- 1/16" CSH. REBOOTED E -LINE CABLE. 09:00 - 09:15 0.25 WHSUR P POST PJSM TO MU NOZZLE BHA AND PUMP DIESEL. 09:15 - 09:30 0.25 WHSUR P POST MU NOZZLE BHA AND LINE UP TO PUMP DIESEL. 09:30 - 11:10 1.67 WHSUR P POST RIH FILLING COIL WITH DIESEL. 11:10 - 13:10 2.00 WHSUR P POST POOH LAYING IN DIESEL. WELL WAS ON A VAC. 13:10 - 13:45 0.58 WHSUR P POST PJSM AND LD NOZZLE BHA. BLOW BACK COIL WITH AIR. 13:45 - 15:00 1.25 WHSUR P POST SET A BPV. 15:00 - 18:30 3.50 RIGD P POST ND BOPE. 18:30 - 18:45 0.25 RIGD P POST CREW CHANGE OUT. 18:45 - 20:00 1.25 RIGD P POST CONTINUE TO ND BOPE. SPIN TIRES & WARM UP MOVE SYSTEM. TEST TREE CAP TO 250 /PSI /4000PSI - PASS. 20:00 - 21:00 1.00 RIGD P POST VAC OUT CUTTINGS BOX & MOVE SAME. MOVE WELDING SHOP & OFFICE CAMP TO Z -PAD. 21:00 - 21:20 0.33 RIGD P POST PJSM REGARDING MOVING OFF WELL. 21:20 - 21:30 0.17 RIGD P POST BACK OFF WELL. 21:30 - 23:00 1.50 RIGD P POST CLEAN UP AROUND WELL. PERFORM POST PAD INSPECTION. PJSM REGARDING MOVING TO Z PAD. RELEASE RIG AT 23:00 Printed: 3/29/2010 11:46:59 AM • S BAKER HUGIBES INTEQ North America - ALASKA - BP Milne Point M Pt F Pad MPF -82 - Slot 82 MPF -82A Survey: MWD Survey Report - Geographic 08 March, 2010 Mil • • ' BAKER HUBS Survey Report - Geographic 1NTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well MPF -82 - Slot 82 Project Milne Point TVD Reference: D141 MPF-82© 42.1 (N3) © 42.15ft (D141 MPF - Site: M Pt F Pad MD Reference: D141 MPF-82© 42.1 (N3) @ 42.15ft (D141 MPF - Well: MPF - 82 North Reference: True Wellbore: MPF - 82A Survey Calculation Method: Minimum Curvature Design: MPF -82A Database: EDM .16 - Anc Prod - WH24P Project Milne Point, ACT, MILNE POINT Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site M Pt F Pad, TR -13 -10 Site Position: Northing: 6,029,958.49ft Latitude: 70° 29' 34.438 N From: Map Easting: 531,814.44ft Longitude: 149° 44' 23.616 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 0.25 ° I Well MPF - 82 API No 500292297170 Well Position +N / -S 0.00 ft Northing: 6,035,441.67 ft Latitude: 70° 30' 27.896 N +E / -W 0.00 ft Easting: 541,552.07 ft Longitude: 149° 39' 36.114 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore MPF -82A API No 500292297101 Magnetics Model Name Sample Date Declination Dip Angle Field Strength r) r) (nT) I BGGM2009 9/16/2009 22.12 80.97 57,657 Design MPF -82A Audit Notes: 1 Version: 1.0 Phase: ACTUAL Tie On Depth: 9,042.57 Vertical Section: Depth From (TVD) +14/-S +E! -W Direction (ft) (ft) (ft) r) 30.85 0.00 0.00 231.11 Survey Program Date: 3/8/2010 From To (ft) (ft) Survey ( Wellbore) Tool Name Description 120.46 2,150.62 MPF -82PB1 MWD +IIFR (MPF- 82PB1) MWD +IFR:AK MWD + IFR [Alaska] 2,234.00 9,042.57 MPF -82 MWD +IIFR (MPF -82) MWD +IFR:AK MWD + IFR [Alaska] 9,123.00 10,762.00 MWD (MPF -82A) MWD MWD - Standard 3/8/2010 9:34:24AM Page 2 COMPASS 2003.16 Build 71 mar . 0 VAIN Survey Report - Geographic 1NTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well MPF -82 - Slot 82 Project: Milne Point TVD Reference: D141 MPF -82@ 42.1 (N3) © 42.15ft (0141 MPF - Site: M Pt F Pad MD Reference: D141 MPF-82© 42.1 (N3) © 42.15ft (D141 MPF - Well: MPF - 82 North Reference: True Weilbore: MPF - 82A Survey Calculation Method: Minimum Curvature Design: MPF -82A Database: EDM .16 - Anc Prod - WH24P ■ survey 1 Measured Vertical Map Map Depth Inclination Azimuth Depth 1 +141/-S +Ei-W Northing Easting (ft) (1 (1 (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,042.57 26.44 236.88 6,964.25 - 2,764.87 - 4,477.38 6,032,652.08 537,090.67 70° 30' 0.691 N 149° 41' 47.929 W 9,123.00 25.57 236.38 7,036.54 - 2,784.26 - 4,506.83 6,032,632.52 537,061.33 70° 30' 0.500 N 149° 41' 48.796 W1 I 9,154.31 35.21 231.02 7,063.52 - 2,793.71 - 4,519.50 6,032,623.01 537,048.70 70° 30' 0.407 N 149° 41' 49.169 W 9,184.56 46.32 227.85 7,086.40 - 2,806.57 - 4,534.44 6,032,610.06 537,033.84 70° 30' 0.280 N 149° 41' 49.608 W 9,214.54 54.39 225.62 7,105.51 - 2,822.40 - 4,551.22 6,032,594.14 537,017.15 70° 30' 0.125 N 149° 41' 50.102 W 9,244.56 61.83 217.15 7,121.38 - 2,841.53 - 4,567.97 6,032,574.91 537,000.51 70° 29' 59.936 N 149° 41' 50.595 W 9,274.90 69.42 211.80 7,133.90 - 2,864.31 - 4,583.57 6,032,552.05 536,985.04 70° 29' 59.712 N 149° 41' 51.053 W 9,304.87 78.28 209.53 7,142.23 - 2,889.05 - 4,598.22 6,032,527.23 536,970.53 70° 29' 59.469 N 149° 41' 51.484 W 9,324.94 83.72 210.24 7,145.37 - 2,906.23 - 4,608.10 6,032,510.00 536,960.75 70° 29' 59.300 N 149° 41' 51.775 W 9,350.56 91.04 209.14 7,146.54 - 2,928.45 - 4,620.76 6,032,487.71 536,948.21 70° 29' 59.081 N 149° 41' 52.147 W 9,380.47 89.69 212.72 7,146.35 - 2,954.10 - 4,636.13 6,032,461.98 536,932.98 70° 29' 58.829 N 149° 41' 52.599 W 9,410.59 90.40 216.13 7,146.33 - 2,978.94 - 4,653.16 6,032,437.04 536,916.10 70° 29' 58.584 N 149° 41' 53.100 W 9,440.57 90.37 219.36 7,146.12 - 3,002.65 - 4,671.51 6,032,413.24 536,897.89 70° 29' 58.351 N 149° 41' 53.640 W 9,470.40 89.94 221.90 7,146.04 - 3,025.28 - 4,690.93 6,032,390.50 536,878.59 70° 29' 58.128 N 149° 41' 54.211 W 9,500.32 89.94 226.66 7,146.08 - 3,046.70 - 4,711.81 6,032,368.97 536,857.83 70° 29' 57.918 N 149° 41' 54.826 W 9,530.40 90.03 231.65 7,146.08 - 3,066.36 - 4,734.56 6,032,349.18 536,835.20 70° 29' 57.724 N 149° 41' 55.495 W I 9,560.58 88.50 232.30 7,146.47 - 3,084.95 - 4,758.33 6,032,330.46 536,811.53 70° 29' 57.541 N 149° 41' 56.194 W 9,590.05 90.61 229.10 7,146.70 - 3,103.61 - 4,781.13 6,032,311.67 536,788.84 70° 29' 57.358 N 149° 41' 56.865 W 9,620.43 91.04 224.97 7,146.26 - 3,124.31 - 4,803.36 6,032,290.85 536,766.73 70° 29' 57.154 N 149° 41' 57.519 W 9,650.09 90.77 220.81 7,145.79 - 3,146.04 - 4,823.54 6,032,269.02 536,746.68 70° 29' 56.940 N 149° 41' 58.113 W 9,680.00 90.37 219.82 7,145.50 - 3,168.84 - 4,842.89 6,032,246.11 536,727.46 70° 29' 56.716 N 149° 41' 58.682 W 9,709.94 89.17 217.18 7,145.62 - 3,192.27 - 4,861.52 6,032,222.58 536,708.95 70° 29' 56.485 N 149° 41' 59.230 W 9,740.10 89.82 214.48 7,145.88 - 3,216.72 - 4,879.18 6,032,198.03 536,691.44 70° 29' 56.245 N 149° 41' 59.749 W I 9,769.98 89.08 210.51 7,146.17 - 3,241.91 - 4,895.22 6,032,172.75 536,675.53 70° 29' 55.997 N 149° 42' 0.221 W 9,800.07 89.94 207.74 7,146.43 - 3,268.20 - 4,909.87 6,032,146.39 536,661.04 70° 29' 55.738 N 149° 42' 0.652 W 9,829.97 89.57 204.58 7,146.55 - 3,295.03 - 4,923.05 6,032,119.48 536,648.01 70° 29' 55.474 N 149° 42' 1.039 W 9,860.09 89.02 201.01 7,146.92 - 3,322.79 - 4,934.71 6,032,091.66 536,636.50 70° 29' 55.201 N 149° 42' 1.382 W 9,890.06 87.88 197.09 7,147.74 - 3,351.10 - 4,944.49 6,032,063.30 536,626.88 70° 29' 54.922 N 149° 42' 1.669 W i 9,922.30 88.13 193.63 7,148.86 - 3,382.17 - 4,953.02 6,032,032.19 536,618.52 70° 29' 54.617 N 149° 42' 1.920 W I 9,949.96 88.25 190.53 7,149.73 - 3,409.20 - 4,958.81 6,032,005.13 536,612.89 70° 29' 54.351 N 149° 42' 2.090 W ' 9,980.06 87.45 185.89 7,150.86 - 3,438.96 - 4,963.10 6,031,975.35 536,608.76 70° 29' 54.058 N 149° 42' 2.216 W 10,009.97 87.48 181.76 7,152.19 - 3,468.77 - 4,965.10 6,031,945.53 536,606.94 70° 29' 53.765 N 149° 42' 2.274 W 10,039.91 88.16 178.28 7,153.32 - 3,498.68 - 4,965.11 6,031,915.62 536,607.09 70° 29' 53.471 N 149° 42' 2.273 W 10,070.17 87.54 174.51 7,154.46 - 3,528.85 - 4,963.21 6,031,885.46 536,609.16 70° 29' 53.174 N 149° 42' 2.217 W I I 10,100.18 87.48 171.08 7,155.76 - 3,558.60 - 4,959.45 6,031,855.74 536,613.09 70° 29' 52.882 N 149° 42' 2.106 W! 10,126.24 87.20 167.82 7,156.97 - 3,584.18 - 4,954.68 6,031,830.19 536,618.00 70° 29' 52.630 N 149° 42' 1.965 W' I 10,151.48 87.70 166.31 7,158.10 - 3,608.76 - 4,949.04 6,031,805.65 536,623.78 70° 29' 52.388 N 149° 42' 1.798 W 10,180.26 87.20 169.95 7,159.38 - 3,636.89 - 4,943.12 6,031,777.55 536,629.85 70° 29' 52.112 N 149° 42' 1.624 W 10,210.43 87.58 175.43 7,160.75 - 3,666.77 - 4,939.29 6,031,747.69 536,633.85 70° 29' 51.818 N 149° 42' 1.510 W 10,240.43 88.34 178.36 7,161.82 - 3,696.71 - 4,937.67 6,031,717.77 536,635.64 70° 29' 51.524 N 149° 42' 1.462 W 10,270.41 88.68 180.39 7,162.60 - 3,726.67 - 4,937.34 6,031,687.81 536,636.13 70° 29' 51.229 N 149° 42' 1.452 W; 10,300.36 87.69 183.24 7,163.55 - 3,756.59 - 4,938.29 6,031,657.89 536,635.35 70° 29' 50.935 N 149° 42' 1.479 W I 10,332.28 88.98 186.68 7,164.48 - 3,788.37 - 4,941.05 6,031,626.10 536,632.77 70° 29' 50.622 N 149° 42' 1.559 W 10,361.40 89.69 190.40 7,164.82 - 3,817.16 - 4,945.37 6,031,597.29 536,628.61 70° 29' 50.339 N 149° 42' 1.686 W 10,390.35 89.78 195.21 7,164.95 - 3,845.38 - 4,951.78 6,031,569.03 536,622.36 70° 29' 50.061 N 149° 42' 1.874 W, 10,420.31 91.81 198.72 7,164.53 - 3,874.03 - 4,960.52 6,031,540.34 536,613.78 70° 29' 49.780 N 149° 42' 2.131 W 10,451.53 94.37 201.86 7,162.85 - 3,903.26 - 4,971.33 6,031,511.05 536,603.13 70° 29' 49.492 N 149° 42' 2.449 W 10,480.55 96.22 204.42 7,160.17 - 3,929.83 - 4,982.68 6,031,484.42 536,591.93 70° 29' 49.231 N 149° 42' 2.782 W' 10,510.40 98.23 207.56 7,156.42 - 3,956.45 - 4,995.66 6,031,457.74 536,579.11 70° 29' 48.969 N 149° 42' 3.164 W 10,540.46 100.88 210.74 7,151.43 - 3,982.33 - 5,010.09 6,031,431.77 536,564.82 70° 29' 48.714 N 149° 42' 3.588 W 1 10,574.96 105.64 213.19 7,143.51 - 4,010.81 - 5,027.85 6,031,403.20 536,547.22 70° 29' 48.434 N 149° 42' 4.110 W 10,604.13 105.59 218.44 7,135.66 - 4,033.58 - 5,044.29 6,031,380.34 536,530.92 70° 29' 48.210 N 149° 42' 4.594 W I 10,630.97 105.04 222.20 7,128.57 - 4,053.32 - 5,061.03 6,031,360.51 536,514.28 70° 29' 48.016 N 149° 42' 5.086 W 10,661.27 102.32 224.82 7,121.40 - 4,074.66 - 5,081.30 6,031,339.06 536,494.13 70° 29' 47.806 N 149° 42' 5.682 W 10,690.26 101.13 220.93 7,115.51 - 4,095.46 - 5,100.61 6,031,318.15 536,474.94 70° 29' 47.601 N 149° 42' 6.250 W 3/8/2010 9:34:24AM Page 3 COMPASS 2003.16 Build 71 • • s s Survey Report - Geographic INTEQ Company: North America - ALASKA - BP Local Co - ordinate Reference: Well MPF -82 - Slot 82 Project: Milne Point TVD Reference: D141 MPF -82@ 42.1 (N3) © 42.15ft (D141 MPF - Site: M Pt F Pad MD Reference: D141 MPF-82© 42.1 (N3) © 42.15ft (D141 MPF - Well: MPF - 82 North Reference: True Wellbore: MPF - 82A Survey Calculation Method: Minimum Curvature Design: MPF - 82A Database: EDM .16 - Anc Prod - WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +NI-S +E/ -W Northing Easting (ft) (°) r) (R) (ft) (ft) (ft) (ft) Latitude Longitude 10,720.22 100.56 218.72 7,109.87 - 4,118.06 - 5,119.45 6,031,295.45 536,456.23 70° 29' 47.379 N 149° 42' 6.804 W 10,762.00 100.56 218.72 7,102.21 - 4,150.10 - 5,145.14 6,031,263.27 536,430.72 70° 29' 47.063 N 149° 42' 7.560 W Targets Target Name - hit/miss target Dip Angle Dip Dir. TVD +NI-S +E/ -W Northing Easting - Shape ( ( °) (ft) (ft) (ft) (ft) (ft) Latitude Longitude MPF -82A Target 1 0.00 0.00 7,162.15 - 3,364.56 - 4,916.45 6,032,050.00 536,655.00 70° 29' 54.790 N 149° 42' 0.844 W - survey misses target center by 33.88ft at 9896.11ft MD (7147.96 TVD, - 3356.89 N, - 4946.23 E) - Point MPF -82A Fault 2 0.00 0.00 42.15 - 2,839.01 - 5,003.52 6,032,575.00 536,565.00 70° 29' 59.958 N 149° 42' 3.417 W - survey misses target center by 6942.47ft at 9042.57ft MD (6964.25 TVD, - 2764.87 N, - 4477.38 E) - Polygon Point 1 42.15 - 2,839.01 - 5,003.52 6,032,575.00 536,565.00 Point 2 42.15 - 4,150.57 - 5,645.93 6,031,260.00 535,930.00 MPF -82A Target 2 0.00 0.00 7,177.15 - 3,804.18 - 4,993.91 6,031,610.00 536,580.00 70° 29' 50.466 N 149° 42' 3.115 W - survey misses target center by 51.58ft at 10355.91 ft MD (7164.78 TVD, - 3811.76 N, - 4944.41 E) - Point MPF -82A Polygon 0.00 0.00 42.15 - 2,685.09 - 4,807.63 6,032,730.00 536,760.00 70° 30' 1.473 N 149° 41' 57.653 W - survey misses target center by 6930.44ft at 9042.57ft MD (6964.25 TVD, - 2764.87 N, - 4477.38 E) - Polygon Point 1 42.15 - 2,685.09 - 4,807.63 6,032,730.00 536,760.00 Point 2 42.15 - 4,291.87 - 5,416.69 6,031,120.00 536,160.00 Point 3 42.15 - 4,488.90 - 5,057.75 6,030,925.00 536,520.00 Point 4 42.15 - 2,682.44 - 4,387.57 6,032,735.00 537,180.00 MPF -82A Fault 1 0.00 0.00 42.15 - 3,675.09 - 4,828.17 6,031,740.00 536,745.00 70° 29' 51.737 N 149° 41' 58.239 W - survey misses target center by 6990.50ft at 9042.57ft MD (6964.25 TVD, - 2764.87 N, - 4477.38 E) - Polygon Point 1 42.15 - 3,675.09 - 4,828.17 6,031,740.00 536,745.00 Point 2 42.15 - 4,489.72 - 4,017.63 6,030,930.00 537,560.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 10,762.00 7,102.21 2 - 3/8" 2.875 3.000 Survey Annotations - - - -- - - -_ -- - -^ _ -T -- i Measured Vertical Local Coordinates Depth Depth +NI-S +E/ -W (ft) (ft) (ft) (ft) Comment 9,042.57 6,964.25 - 2,764.87 - 4,477.38 TIP 9,123.00 7,036.54 - 2,784.26 - 4,506.83 KOP 10,762.00 7,102.21 - 4,150.10 - 5,145.14 TD Checked By: Approved By: Date: 3/8/2010 9:34:24AM Page 4 COMPASS 2003.16 Build 71 `r • • Tree:Cameron 3 1/8 ", 5M M PU F -82Ai ( Doyon -141) Wellhead: FMC 11" x 7- 1/16" 5M, Orig. KB Elev. = 39.95 ft Gen. 5a w/ 6" x 3.5" FMC Tbg. Hnr. Orig. GL Elev. = 11.30 ft w/ 3.5' eue threads top and btm. DF Elev. = 28.65 ft 3" CIW H BPV profile 20" 91.51# ppf, H -40 178' I O 9 5/8" Tam port collar' 1009' KOP @ 945' - 10 degrees. HES X- Nipple 2.813" id 1 2233 Max. hole angle = 53 deg. 1 Hole angle thru' perfs = 24 degrees. 9 5/8 ", 40 ppf, L -80 Btrc. 5311' 4 , 3.5" 9.3 ppf, L -80 nsct tubing. ( drift id = 2.992 ", cap = 0.0087 bpf ) 7" 26 ppf, L -80, btc mod. casing ( drift id = 6.276 ", cap. = 0.0383 bpf ) Min I.D. = 1.79" @ KB Packer HES X- Nipple 2.813" id 1 9012' KB Packer top at 9,030' — ' Baker 7 "x 4.5" SAB - 3 perm pkr. I 9034' 2 - 3/8" Liner top at 9,044' — It • HES XN- Nipple 2.750" ID no -go I 9059' I ■ Whipstock in Pilot Hole @ 9,125' WLEG 9072' I Perforation Summary 2 - 3/8" Solid /Cemented Liner Ref log: SWS USIT log dated: 9/6/00 PBTD = 10,708' �s to e.,.. I Size S.f Interval TVD l f d 72,5 1.56" 6 10560'- 10640' 3" Open Hole 1S r 1.56" 6 10660'- 10705' ?' I I �,05 C;.. 1.56" Power Jet 6spf 60 deg. phasing a • (6 7" HES float collar 9341' 5 • j 7" HES float shoe 9425' 1 61�Z IP a DATE REV. BY COMMENTS MILNE POINT UNIT 09/07/00 M. Linder Drilled and completed by Doyon 141 WELL No.: F -82Ai 10/24/00 MDO Perforated API : 50 3/13/10 Nordic 2 CTD Sidetrack BP EXPLORATION (AK) 1. t• MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, April 19, 2010 TO: Jim Regg ri ( f ' 4-(11,(t0 SUBJECT: Mechanical Integrity Tests P.I. Supervisor l BP EXPLORATION (ALASKA) INC F -82A FROM: Lou Grimaldi MILNE PT UNIT KR F -82A Petroleum Inspector Src: Inspector NON - CONFIDENTIAL Well Name: MILNE PT UNIT KR F -82A API Well Number: 50- 029 - 22971 -01 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG100403104520 Permit Number: 209 -135 -0 Inspection Date: 3/31/2010 Rel Insp Num: MITOP000002962 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F -82A ' Type Inj. W''TVD 6957 '' IA 350 2350 ' 2290 2280 1 P.T.D 2091350 1TypeTest 1 SPT, Test psi 1 2350 / OA 0 230 220 220 ' Interval Initial Test p/F Pass Tubing 1830 1830 1830 1830 Notes: 2 bbl's pumped, 2 bbl's returned. Good post W/O test. Monday, April 19, 2010 Page 1 of 1 OPERABLE: MPF -82A (PTD #2090) Passing AOGCC MITIA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer ©BP.com] Sent: Wednesday, March 31, 2010 8:54 PM t ee,0 4( To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA); Maunder, Thomas E (DOA); MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; Brooks, Phoebe L (DOA) Cc: Chebul, Josh M; Janowski, Carrie Subject: OPERABLE: MPF -82A (PTD #2091350) Passing AOGCC MITIA All, Z Injector MPF -82A (PTD #2091350) passed a state witnessed MITIA on 03/31/10 post rig sidetrack. The passing test verifies two competent barriers. The well has been reclassltled as Operable. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: NSU, ADW Well Integrity Engineer Sent: Saturday, March 27, 2010 7:48 AM To: 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; Brooks, Phoebe L (DOA) Cc: NSU, ADW Well Integrity Engineer; Chebul, Josh M; Quy, Tiffany Subject: UNDER EVALUATION: MPF -82A (PTD #2091350) to place on Injection for UIC MITIA All, Injector MPF -82A (PTD #2091350) has been reclassified as Under Evaluation so that the well may be placed on injection, allowed to thermally stabilize, and an AOGCC witnessed MITIA conducted. Please notify Well Integrity once the well is thermally stable and the MITIA has been scheduled with the AOGCC. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 4/1/2010 UNDER EVALUATION: MPF -82J TD #2091350) to place on Injection f JIC MITIA Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [ NSUADWWelllntegrityEngineer @BP.com] Sent: Saturday, March 27, 2010 7:48 AM Reel . Y 31 1 1 ' 9 To: Regg, James B (DOA); Maunder, Thomas E (DOA); MPU, Well Operations Supervisor; MPU, Wells Ops Coord; MPU, Production Optimization Engineer; MPU, Wells Ops Coord2; MPU, Area Manager; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; Brooks, Phoebe L (DOA) Cc: NSU, ADW Well Integrity Engineer; Chebul, Josh M; Quy, Tiffany Subject: UNDER EVALUATION: MPF -82A (PTD #2091350) to place on Injection for UIC MITIA All, Injector MPF -82A (PTD #2091350) has been reclassified as Under Evaluation so that the well may be placed on injection, allowed to thermally stabilize, and an AOGCC witnessed MITIA conducted. Please notify Well Integrity once the well is thermally stable and the MITIA has been scheduled with the AOGCC. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659 -5102 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/31/2010 1 ' rr � , ° � k SEAN PARNELL, GOVERNOR } G i 1,2 Vt ` -_. p 1 ... C ` h �I t F ^ f k \ , , ' may L a t.. ALASKA OIL AND GIAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Mr. John McMullen Engineering Team Leader BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519 -6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPF -82A BP Exploration (Alaska) Inc. Permit No: 209 -135 Surface Location: 1991' FSL, 3011' FEL, SEC. 06, T13N, R10E, UM Bottomhole Location: 2191' FNL, 3065' FEL, SEC.12, T13N, ROSE, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re -drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659 -3607 (pager). Sincerely, Daniel T. Seamount, Jr. Chair DATED this , ay of November, 2009 cc: Department of Fish 85 Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. I STATE OF ALASKA s D ALASIL AND GAS CONSERVATION COMMON PERMIT TO DRILL A (tai 0 6 2 0 09 20 AAC 25.005 �. ( -�� 1 a. Type of work: 1 b. Proposed Well Class: 4 a re ssrc 8 Yp p 0 Oil 0 - Winj 0 Zone ❑ Drill ' ® Redrill ❑ Stratigraphic Test ❑ Development Gas ❑ Service - Supply ❑ Multiple Zone Coalbed Gilmtrint Hydrates ❑ Re -Entry ❑ Exploratory . Service - WAG ❑ Service - Disp Shale Gas 2. Operator Name: 5. Bond: 0 Blanket ❑ Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 6194193 • MPF -82A 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519 -6612 MD 10813' • TVD 7049'ss • Milne Point Unit / Kuparuk 4a. Location of Well (Governmental Section): 7. Property Designation (Lease Number): River S J), / P c-i Surface: ADL 025509'8, 388235' ,‘I if �� 1991' FSL, 3011' FEL, SEC. 06, T13N, R10E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 807' FNL, 2375' FEL, SEC. 12, T13N, RO9E, UM December 15, 2009 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 2191' FNL, 3065' FEL, SEC. 12, T13N, RO9E, UM 1920 2,150' 4b. Location of Well (State Base Plane Coordinates - NAD 27): 10. KB Elevation above MSL: 42.15' . feet 15. Distance to Nearest Well Open Surface: x- 541552 y- 6035442 Zone ASP4 GL Elevation above MSL: 11.3' feet to Same Pool: 2,500' • 16. Deviated Wells: Kickoff Depth: 9139 . feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 105 • degrees Downhole: 3497 • Surface: 2797 • 18. Casing Program: Specifications Top - Setting Depth - Bo ttom Quantity of Cement, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 3" 2 - 3/8" 4.7# L - 80 STL 1775' 9045' 6924'ss 10820' 7049'ss 34 sx Class 'G' 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 9440' 7327' None 9341' 7235' None Casing Length Size Cement Volume MD TVD Conductor / Structural 81' 20" 260 sx Arcticset (Aoorox.) 110' 110' Surface 5282' 9-5/8" 825 sx AS 3 Lite. 290 sx Class 'G' 5311' 4256' Intermediate . Production 9400' 7" 180 sx Class 'G' 9426' 7314' Liner Perforation Depth MD (ft): 9180' - 9256' Perforation Depth TVD (ft): 7088' - 7157' 20. Attachments: ❑ Property Plat 0 BOP Sketch ® Drilling Program ❑ Time vs Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch ❑ Seabed Report Drilling Fluid Program 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the -going is true and correct. Contact Sean McLaughlin, 564 -4387 Printed Name Jo r M , - n j i Title Engineering Team Leader Signatu '� / / Phone 564 -4711 Date 1 /�,S'" Jf Prepared By Name/Number Hubble, 564 -4628 Commission Use Only Permit To ' rill , API Number: Permit See cover letter for Number:j/ 50- 029 - 22971 -01 -00 �� I other requirements Conditions of Approval: If box is checked, well may no may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales: Other -t-- 3500 Se; Abe A S ► Samples Req'd: ❑ yes L No Mud Log Req'd: ❑ yes No - k c7 �' Sc- A 1 ( � H Measures: "Yes ❑ No Directional Survey Req'd: Yes ❑ No — �,P %Yl \ 0 n J 4 a (4_r dp t, 'Lc-CO ems_.. .4( ATo 1 C 3 4 / APPROVED BY THE COMMISSION /2 Date , /� , COMMISSIONER __1/ Form 10-401 evised 07/ 09 T ' Tli mitMlgrAl [OflthS from the date of approval (20 AAC 25.005(9)) Submit In Duplicate s • � bp To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Sean McLaughlin CTD Engineer Date: October 29, 2009 Re: Milne Point F -82A injector PTD request Approval is requested for a permit to drill a CTD sidetrack from well Milne Point F -82. MPF -82 is a Kuparuk A sand injector drilled in October 2000 to support MPL -40. The injector pressured up quickly and did not • properly support the producer. MPF -82A will be drilled to a more optimum location. The sidetrack, MPF -82A, is scheduled to be drilled by Nordic 2 starting December 15, 2009 using the managed pressure drilling technique. This horizontal lateral will target Kuparuk the A sand to improve injection. The perforations in the parent well will be abandoned with a cement plug in the 7" casing. The "A" sidetrack lateral will exit the parent well at 9,125' and in the C sand and drill a -1700' lateral to a TD of 10,820' md. The sidetrack will be completed with a solid, cemented and perforated 2 -3/8" liner. The following describes work planned. A schematic diagram of the proposed sidetrack is attached for reference. Managed Pressure Drilling Technique The history of CTD at KRU in the Kuparuk reservoir, has demonstrated the benefits of a managed pressure drilling technique. Due to uncertainties about the bottom hole pressures to be encountered as this sidetrack is drilled, managed pressure drilling techniques will be employed on this well. The intent is to provide constant bottom hole pressure by using 8.8 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability: Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and /or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits and will be independent of the BOPE choke. This well does not have a functioning tubing sub - surface safety valve that could be utilized to facilitate BHA deployments and liner running. It is possible that deployment of the BHA under trapped wellhead pressure may be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe /slips (2 -3/8 ") rams, see attached BOP configurations). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real -time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected for MPF -82A: • Latest Reservoir pressure in the parent well: 3,497 psi at 7000' TVDSS, 9.6 ppg EMW. ✓ •" • Expected pressure as the lateral is drilled is between 6.8 ppg and 9.6 ppg EMW. • Expected annular friction losses while circulating: 550 psi at KOP and 700 psi at TD (assuming 90 psi /1000 ft, for a 1680' lateral). • Planned mud density: 8.8 ppg equates to 3,221 psi hydrostatic pressure at the window. • While circulating 8.8 ppg fluid, at the start of the lateral the bottom hole circulating pressure is estimated to be 3,771 psi or 10.3 ppg ECD. No surface pressure will be applied while drilling. • When circulation is stopped, a -550 psi surface pressure will be applied to maintain a constant BHP of 10.3 ppg EMD. At the start of the lateral, the mud in the rig pits will be 8.8 ppg mud. KWF will be stored on location in upright tanks. The tankage will contain 2 wellbore volumes of KWF (11 ppg expected) to exceed the maximum possible BHP to be encountered as the lateral is drilled. This KWF will also be used for liner running operation. CTD Sidetrack Summary 1 • Pre -CT Rig Work: The pre CTD work is slated to begin November 20, 2009. 1. MIT -IA to 3000 psi 2. Dummy whipstock drift 3. Mill XN nipple 4. Cement from PBTD to tailpipe (pump 20 bbl of 17ppg cement) Rig Sidetrack Operations: (Scheduled to begin on December 15, 2009 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7- 1/16" CT Drilling BOPE and test Su D �;/ 3. Mill 2.8" pilot hole to 9150' 3,0 - 37( 1 6 4. Run dummy whipstock drift 5. Set whipstock highside at 9,125' 6. Mill 2.8" window in 7" casing from mechanical whipstock 7. Drill build section with 3" bicenter bit, and land well in target A sand. 8. Drill lateral section to 10,820' 9. Flow check well and lay in KWF as needed. 10. Run and cement a 2 -3/8" L -80 liner string. Expect -7 bbl of 15.8 ppg cement ? p 11. Make a cleanout run with mill and motor. l 12. Make a logging run with a memory SWS GR -CCL logging tool. 13. Test Liner lap to 2000 psi. 14. Perforate well. 15. Lay bleach in the lateral and KFW in the cased hole. 16. FP well to 2000'. 17. ND 7- 1/16" stack. FP tree and PT tree cap to 3500 psi. 18. RDMO Nordic 2. Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Pull BPV. Mud Program: • Well kill: 11 ppg brine to start. Adjust with real time BHP monitoring. • Milling /drilling: 8.8 ppg Geo -VIS or biozan for milling, new 8.8 ppg Geo -VIS for drilling. • KWF will be needed for running and cementing liner. BHP will be measured prior to tripping to run liner and KWF adjusted as needed. • Standby KWF. At the start of the well there will be 2 wellbore volumes of 11.0 ppg KWF on location in upright tanks. Disposal: • All Class II drilling and completion fluids will go to Grind & Inject at DS 4, or to the KRU 1R pad disposal well. • All Class II drilling solids will go to Grind & Inject at DS 4. • All Class 1 wastes will go to Pad 3 for disposal. Hole sizes: 3.0" bi- center hole: 9,125' - 10,820' Casing Program: • 2 -3/8 ", L -80 4.70# STL 9,045' and - 10,820' and • A minimum of 7 bbls 15.8 ppg cement will be used for liner cementing. (Assuming 3.0" bit size and TD C�3 10,820', with 20% excess in the open hole interval) • TOC planned at 9045' (Top of the 2 -3/8" Liner) • A liner top packer will be run to isolate the annulus if the lap fails a 2000 psi test. Well Control: • Two wellbore volumes of KWF ( -280 bbls) will be on location at all times during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer wi tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 105 deg at 10,590'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property — 2150 ft. (To planned perforations in new lateral) • Distance to nearest well within pool — 2500' from MPL -40 to planned perforations in new lateral. Anti - Collision • There are no collision issues Logging • MWD directional, Gamma Ray and Resistivity logs will be run over all of the open hole section. • Cased hole GR /CCL, logs will be run. • No cement log is planned as this well is exiting the parent in zone. The 6 -SEP -2000 USIT log shows good quality cement above our kick off point. A copy of the log in the zone of interest is attached. Hazards • The maximum recorded H2S level on MPF pad was 47 ppm on well MPF -69. (September 2003). • Lost circulation risk is low. Reservoir Pressure , °I* • The reservoir pressure on MPF -82 was last recorded at 3,497 psi at 7,000' TVDSSpg equivalent) • Max. expected surface pressure with gas (0.10 psi /ft) to surface is 2,797 psi. • As the well is drilled, isolated areas with lesser pressure than that found in the parent wellbore may be encountered. The minimum expected pressure is 2,472 psi (6.8 EMW) as the well is drilled towards TD. Sean McLaughlin CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble EMI Baker Hughes INTEQ BAKER H OS Baker Hughes INTEQ Planning Report bp INTEQ Company: North America - ALASKA - BP Local Coordinate Reference: Well MPF -82 - Slot 82 Project: Milne Point TVD Reference: D141 MPF -82@ 42.1 (N3) © 42.15ft (D141 MPF - Site: M Pt F Pad MD Reference: D141 MPF -82@ 42.1 (N3) @ 42.15ft (D141 MPF - Wed: MPF -82 North Reference: True Wel!bore: Plan 7, MPF -82A Survey Calculation Method: Minimum Curvature Design: Plan 7 Database: EDM 2003.16 Single User Db Survey Tool Program Date 11/3/2009 From To (ft) (ft) Survey (Wellborn) Tool Name Description 120.46 2,150.62 MPF -82PB1 MWD +IIFR (MPF- 82PB1) MWD +IFR:AK MWD + IFR [Alaska] 2,234.00 9,042.57 MPF -82 MWD +IIFR (MPF -82) MWD +IFR:AK MWD + IFR [Alaska] 9,042.57 10,812.50 Plan 7 (Plan 7, MPF -82A) MWD MWD - Standard Planned Survey MD Inc Azi TVDSS N/S EMI Northing Fasting DLeg V. Sec TFace (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) ( ° h 00 ft) (ft) (°) 9,042.57 26.44 236.88 6,922.10 - 2,764.87 - 4,477.38 6,032,652.08 537,090.67 0.74 3,144.58 163.27 TIP 9,100.00 25.88 236.52 6,973.65 - 2,778.77 - 4,498.54 6,032,638.06 537,069.58 1.01 3,160.27 - 164.31 9,125.00 25.64 236.36 6,996.17 - 2,784.78 - 4,507.59 6,032,632.00 537,060.56 1.01 3,167.04 - 163.99 KOP • 9,139.00 27.74 236.36 7,008.67 - 2,788.26 - 4,512.83 6,032,628.49 537,055.35 15.00 3,170.97 0.00 End of 15 Deg /100' DLS 9,200.00 49.09 236.36 7,056.19 - 2,809.13 - 4,544.20 6,032,607.44 537,024.09 35.00 3,194.50 0.00 9,300.00 84.09 236.36 7,095.31 - 2,859.19 - 4,619.42 6,032,556.98 536,949.17 35.00 3,250.91 0.00 9,310.75 87.85 236.36 7,096.06 - 2,865.12 - 4,628.35 6,032,550.99 536,940.27 35.00 3,257.61 0.00 End of 35 Deg/100' DLS 9,400.00 87.70 225.64 7,099.53 - 2,921.17 - 4,697.55 6,032,494.57 536,871.39 12.00 3,319.47 -91.00 9,500.00 87.63 213.63 7,103.62 - 2,997.97 - 4,761.18 6,032,417.42 536,808.20 12.00 3,401.52 -90.58 9,600.00 87.67 201.62 7,107.73 - 3,086.33 - 4,807.43 6,032,328.81 536,762.45 12.00 3,493.58 -90.09 9,663.00 87.74 194.06 7,110.26 - 3,146.21 - 4,826.70 6,032,268.83 536,743.52 12.00 3,554.91 -89.60 5 9,700.00 87.67 198.50 7,111.75 - 3,181.69 - 4,837.06 6,032,233.29 536,733.35 12.00 3,591.16 91.00 9,793.00 87.55 209.67 7,115.64 - 3,266.38 - 4,874.92 6,032,148.40 536,695.97 12.00 3,678.83 90.82 6 9,800.00 87.57 208.83 7,115.94 - 3,272.48 - 4,878.34 6,032,142.28 536,692.59 12.00 3,685.21 -89.00 9,900.00 87.84 196.82 7,119.96 - 3,364.41 - 4,917.02 6,032,050.14 536,654.42 12.00 3,780.16 -88.96 11/4/2009 8 :52 :52AM Page 3 COMPASS 2003.16 Build 71 EM/ Baker Hughes INTEQ • BAIUIR 11110111111 Baker Hughes INTEQ Planning Report 0 by INTEQ Company: North America - ALASKA - BP Local Co-ordinate Reference: Well MPF -82 - Slot 82 Project: Milne Point TVD Reference: D141 MPF -82@ 42.1 (N3) @ 42.15ft (D141 MPF - Site: M Pt F Pad MD Reference: D141 MPF -82@ 42.1 (N3) @ 42.15ft (D141 MPF - Well: MPF -82 North Reference: True Welters: Plan 7, MPF -82A Survey Calculation Method: Minimum Curvature Design: Plan 7 Database: EDM 2003.16 Single User Db Planned Survey MD Inc Az! TVDSS N/S EMI Northing Easting DLeg V. Sec TFace (ft) ( (°) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) ( 9,913.00 87.88 195.26 7,120.45 - 3,376.90 - 4,920.61 6,032,037.64 536,650.90 12.00 3,792.91 - 88.48 7 10,000.00 87.73 184.81 7,123.79 - 3,462.38 - 4,935.75 6,031,952.08 536,636.25 12.00 3,879.39 -91.00 10,073.00 87.67 176.05 7,126.72 - 3,535.25 - 4,936.30 6,031,879.22 536,636.11 12.00 3,952.02 -90.60 8 10,100.00 87.76 179.29 7,127.80 - 3,562.20 - 4,935.20 6,031,852.27 536,637.35 12.00 3,978.78 88.50 10,200.00 88.14 191.29 7,131.39 - 3,661.53 - 4,944.40 6,031,752.91 536,628.71 12.00 4,078.53 88.37 10,273.00 88.48 200.05 7,133.54 - 3,731.72 - 4,964.09 6,031,682.62 536,609.42 12.00 4,150.17 87.94 9 10,300.00 88.76 196.82 7,134.19 - 3,757.32 - 4,972.62 6,031,656.97 536,601.03 12.00 4,176.42 -85.00 10,363.00 89.44 189.29 7,135.18 - 3,818.64 - 4,986.84 6,031,595.58 536,587.15 12.00 4,238.74 -84.92 10 10,400.00 92.05 192.88 7,134.70 - 3,854.94 - 4,993.95 6,031,559.24 536,580.25 12.00 4,275.52 54.00 10,500.00 99.03 202.69 7,125.03 - 3,949.55 - 5,024.25 6,031,464.47 536,550.48 12.00 4,372.42 54.05 10,583.00 104.63 211.11 7,107.98 - 4,021.92 - 5,060.91 6,031,391.90 536,514.23 12.00 4,447.71 55.00 11 10,600.00 104.73 213.22 7,103.68 - 4,035.84 - 5,069.66 6,031,377.93 536,505.55 12.00 4,462.34 87.00 10,700.00 104.91 225.63 7,078.00 - 4,110.35 - 5,130.92 6,031,303.09 536,444.72 12.00 4,541.90 87.53 10,763.00 104.69 233.45 7,061.89 - 4,149.84 - 5,177.23 6,031,263.35 536,398.64 12.00 4,585.27 90.72 12 10,800.00 104.80 228.86 7,052.47 - 4,172.28 - 5,205.09 6,031,240.76 536,370.91 12.00 4,610.05 -88.00 10,813.00 104.81 227.25 7,049.14 • - 4,180.68 - 5,214.44 6,031,232.31 536,361.61 12.00 4,619.24 -89.17 TD at 10813.00 - 2 -3/8" I 11/4/2009 8:52:52AM Page 4 COMPASS 2003.16 Build 71 Tr P: Cameron 3 1/8 ", 5 Orig. *lev. = 39.95 ft(Doyon -141 WeIIheacFMC 11" x 7- 1/10M, M PU F��2 Orig. G' lev. = 11.30 ft Gen. 5a w/ 6" x 3.5" FMC Tbg. Hnr. DF Elev. = 28.65 ft w/ 3.5' eue threads top and btm. 3" CIW H BPV profile • 20" 91.51# ppf, H -40 78' ,' 0 9 5/8" Tam port collar 1009' KOP @ 945' - 10 degrees. HES X- Nipple 2.813" id 1 2233' Max. hole angle = 53 deg. Hole angle thru' perfs = 24 degrees. 9 5/8 ", 40 ppf, L -80 Btrc. 5311' 3.5" 9.3 ppf, L -80 nsct tubing. ( drift id = 2.992 ", cap = 0.0087 bpf); 7" 26 ppf, L -80, btc mod. casing ( drift id = 6.276 ", cap. = 0.0383 bpf) HES X- Nipple 2.813" id 9012' • • Baker 7 "x 4.5" SAB -3 perm pkr. 9034' HES XN- Nipple 2.750" ID no -go 1 9059' WLEG 1 9072' Perforation Summary n Ref log: SWS USIT log dated: 9/6/00 1 Size S.f Interval TVD 2" 6 9,180'- 9,200' 7,088'- 7,108' 1 1 2" 6 9,204'- 9,224' 7,109'- 7,131' 2" 6 9,236'- 9,256' 7,139'- 7,157 2" Power Jet HSD 6spf 60 deg. phasing 7" HES float collar 9341' 7" HES float shoe 9425' DATE REV. BY COMMENTS MILNE POINT UNIT 09/07/00 M. Linder Drilled and completed by Doyon 141 WELL No.: F 10/24/00 MDO Perforated API : 50 BP EXPLORATION (AK) Pro o sed MPU F -82Ai TD ST (Doyon -141 Tree: Cameron 3 1/8", 5 Wellhead: FMC 11" x 7 -1 /1 5M, Orig. Iev. = 39.95 if Gen. 5a w/ 6" x 3.5" FMC Tbg. Hnr. Orig. GL Elev. = 11.30 ft w/ 3.5' eue threads top and btm. DF Elev. = 28.65 ft 3" CIW H BPV profile 20" 91.51# ppf, H -40 78' I O 9 5/8" Tam port collar 1009' I KOP @ 945' - 10 degrees. HES X- Nipple 2.813" id 2233' Max. hole angle = 53 deg. Hole angle thru' perfs = 24 degrees. 9 5/8 ", 40 ppf, L -80 Btrc. 5311' 1 3.5" 9.3 ppf, L -80 nsct tubing. ( drift id = 2.992 ", cap = 0.0087 bpf ) 7" 26 ppf, L -80, btc mod. casing ( drift id = 6.276 ", cap. = 0.0383 bpf ) HES X- Nipple 2.813" id 9012' Baker 7 "x 4.5" SAB -3 perm pkr. 9034' I 2 - 3/8" Liner top at 9,045' I HES XN- Nipple 2.750" ID no -go 9059' / ■ Whipstock in Pilot Hole @ 9,125' „.../ l' WLEG 9072' Perforation Summary Ji, 2 -3/8" Solid /Cemented Liner Ref log: SWS USIT log dated: 9/6/00 r TD = 10,820' Size Spf Interval (TVD) _ 2" 6 9,180'- 9,200' 7,088'- 7,108' 2" 6 9,204'- 9,224' 7,109'- 7,131' -- 3" Open Hole 2" 6 9,236'- 9,256' 7,139'- 7,157 = 2" Power Jet HSD 6spf 60 deg. phasing 7" HES float collar 9341' 7" HES float shoe 9425' DATE REV. BY COMMENTS MILNE POINT UNIT 09/07/00 M. Linder Drilled and completed by Doyon 141 WELL No F - 82i 10/24/00 MDO Perforated API : 50 - 029 - 22971 - BP EXPLORATION (AK) t ' v I, r 1 - 1 I . 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' ‘. ,... — .... ...s j N.N./\.. „...., c ... _ N. ...- Azimuths n True Nod, WELLBORE DETAILS: Plan 7, MPF -82A REFERENCEf4FORMATEN Fan Project: Milne Point Magnetic Nenrt 22.12 Site: M Pt F Pad Magnebc Feld Parent Wellbore: MPF -82 Cgaeknate(Nk�Rekrence. WetlMPF82- Sb182,TMeNorlh BAKER 0 Well: MPF -82 sirengn 576574anT tkncal(n'D) Reference: Mean Sea Level l y�, Wellbore: Plan 7, MPF -82A opA 9 le: 80 Tie on MD: 9042.57 Secton(VS)Rekrence. Sbt- 82(0.O08,0.00E) HUGHES Dater 9/16/200S r Plan: Plan7(MPF- 82/PIan 7, MPF-82A) Measured Dept Reference: D141 MPF82@42.1(N3) @42.1511(0141 MPF-82@ (N39 Cafeeb6on Method: *tram CunaWn INTEQ -200 WELL DETAILS: MPF -82 -2200 Ground Level: 0.00 +N/-S 4-E / -W Northing Easting Lat:ttude Longitude Slot 2400 0.00 0.00 6035441.67 541552.07 70 30' 27.896 N 149 39' 36.114 W 82 M'F -82 PF-82 SECTION DETAILS ANNOTATIONS 2600. TIP MPF 82A F: ult 2 .._ Sec MD Inc Azi ssTVD +N/ -S +E/ -W DLeg TFace VSec Target Annotation - 2800 , , KW' 1 9 042.57 26.44 236.88 6922.10 - 2764.87 .4477.38 0.00 0.00 3144.58 TIP 2 9125.00 25.64 236.36 6996.17 - 2784.78 1507.59 1.01 - 164.31 3167.04 KOP I00' DLS 3 913900 27.74 236.36 700867 - 2788.26 -0512.83 15.00 0.00 3170.97 End of 15 Deg/100 DLS 4 9310.75 87.85 236.36 7096.06 - 2865.12 -0628.35 35.00 0.00 3257.61 Endaf 35 D 131100 „ DLS A 1, - • 1.1' 1 5 9663.00 87.74 194.06 7110.26 - 3146.21 -4826.70 12.00 269.00 3554.91 5 3200 6 9793.00 87.55 209.67 7115.64 - 3266.38 -4874.92 12.00 91.00 3678.83 6 7 9913.00 87.88 195.26 7120.45 - 3376.90 -4920.61 12.00 271.00 3792.91 7 ..3400 , 8 10073.00 87.67 176.05 7126.72 - 3535.25 4936.30 12.00 269.00 3952.02 8 • 9 10273.00 88.48 200.05 7133.54 - 3731.72 -0964.09 12.00 88.50 4150.17 9 + MPF - 2A T: ,: 10 10363.00 89.44 189.29 7135.18 - 3818.64 -0966.911 12.00 275.00 4238.74 10 - 3600 _ � ' 11 10583.00 104.63 211.11 7107.98 -4021.92 - 5060.91 12.00 54.00 4447.71 11 p 12 10763.00 104.69 233.45 7061.89 -0149.84 - 5177.23 12.00 87.00 4585.27 12 - 3800 t 1 13 10813.00 104.81 227.25 7049.14 -4180.68 -5214.44 12.00 272.00 461924 TDat10813.00 I t - 4000 1 0 . -4200 MPF- 82/Plan', MPF 82A -4400' -4600 -4800 -6400 -6200 -6000 -5800 -5600 -5400 -5200 -5000 -4800 -4600 -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 West( - )/East( +) (200 ft/in) 6840 6885 TIP _.\ 6930 6975 • 7, MPF -82A I V'1 KOP •el 7020 . i 1 a 7065 End of 15 Deg/100 DLS MPF -:2A Target 1 2 A 7110 _ . MPF -02A Targot 2 U 5 6 �� t - 11 7 jE 7155, , , • i--,, ii i - • r y 7200 2 H 7245 \ 7290 MPF.82/MP' -82 Mean 3060 3105 3150 3195 3240 3285 3330 3375 3420 3465 3510 3555 3600 3645 3690 3735 3780 3825 3870 3915 3960 4005 4050 4095 4140 4185 4230 4275 4320 4365 4410 4455 4500 4545 4590 4635 4680 4725 4770 Vertical Section at 185.00° (45 ft/in) ' mau BPPASSPORT • Was Travelling Cylinder Report 0 bP LNTEQ Company: North America - ALASKA - BP Local Co- ordinate Reference: Well MPF-82 - Slot 82 Project Milne Point TVD Reference: D141 MPF -82@ 42.1 (N3) @ 42.15ft (D141 MPF -82@ Reference Site: M Pt F Pad MD Reference: D141 MPF -82@ 42.1 (N3) @ 42.15ft (D141 MPF -82@ Site Error: 0.00ft North Reference: True Reference Well: MPF -82 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Weltbore Plan 7, MPF -82A Database: EDM .16 - Anc Prod - WH24P Reference Design: Plan 7 Offset TVD Reference: Offset Datum Reference Plan 7 Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 9,042.57 to 10,813.00ft Scan Method: Tray. Cylinder North Results Limited by: Maximum center - center distance of 1,278.21ft Error Surface: Elliptical Conic Survey Tool Program Date 11/3/2009 From To (ft) (ft) Survey (Weltbore) Tool Name Description 120.46 2,150.62 MPF -82PB1 MWD +IIFR (MPF- 82PB1) MWD +IFR:AK MWD + IFR [Alaska] 2,234.00 9,042.57 MPF -82 MWD +IIFR (MPF -82) MWD +IFR:AK MWD + IFR [Alaska] 9,042.57 10,813.00 Plan 7 (Plan 7, MPF -82A) MWD MWD - Standard I I Casing Points i Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 10,813.00 7,091.30 2 3/8" 2.375 3.000 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well - Wellbore - Design (ft) (ft) (ft) (ft) M Pt F Pad MPF -01 - MPF -01 - MPF -01 Out of range MPF -06 - MPF -06 - MPF -06 Out of range MPF -80 - MPF -80 - MPF -80 Out of range MPF -81 - MPF -81 - DEAP defin Out of range MPF -81 - MPF -81 - MPF -81 Out of range MPF -82 - MPF -82 - MPF -82 9,125.00 9,125.00 0.00 2.47 -2.15 FAIL - Major Risk MPF -83 - MPF -83 - MPF -83 9,042.57 9,875.00 1,164.99 403.21 794.95 Pass - Major Risk MPF -84 - MPF -84 - MPF -84 Out of range MPF -84 - MPF -84A - MPF -84A Out of range MPF -84 - MPF -84A - mpf -84A wp11 Out of range MPF -84 - MPF- 84APB1 - MPF -84 Wp1 Out of range MPF -84 - MPF- 84APB1 - MPF- 84APB1 Out of range MPF -84 - MPF -84B - MPF -84 Wp02 Out of range MPF -84 - MPF -84B - MPF -84B Out of range MPF -85 - MPF -85 - MPF -85 Out of range M Pt L Pad MPL -28 - MPL -28 - MPL -28 Out of range MPL -28A - MPL -28A - MPL -28A Out of range MPL -39 - Plan MPL -39A - MPL -39A wp03 10,200.00 14,518.31 852.35 315.93 550.31 Pass - Major Risk MPL -39 - Plan #1(CTD) MPL -39A - Plan #1(CTD) 9,162.73 14,875.00 921.81 411.90 522.46 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 11/3/2009 1:43:46PM Page 2 of 8 COMPASS 2003.16 Build 71 • • • All Measurements are from top of Riser 10/30/2009 ■ ■ (I) CC M PF -82A top of bag BAG 7 1/16" 5000 psi. bttm of bag J middle of slips I Blind /Shears TOTs middle of pipes 71/16" 5000psi I 2 3/8" combi ram /slips I Mud Cross Mud Cross middle of flow cross 7 1/16" 5000psi I I 1 middle of blind /shears variable bore pipe 3 1/2 " -2 3/8" I I TOTs middle of pipe /slips 2" combi ram /slips 7 1/16" 5000psi L Swab Valve Flow Tee \ ' - \ • ' \ . iri - - 4 ..... . - ..,,,,,...,.... a 9 All. 0 1 .it 9 h jv / 0 - 05 - "' - ' 1 " - ---. - ... s.„..,,,,, - "----,,CL - 33 Tract ID:39 -23B -388235 ' A Il i . -•• 111, V 1 (1 . '' "'". : .- ' ' -,. 0, ca.-84B . 0,643 • -84 -,:.-., MPU F-82A — Area of Review ...... 410 _ e l,•__. 9 4 I _.2se" - -- .......-..-.:',: ..‘k.:■ '-'" ., ; / I _.,x.:, '.:::::: . 9 F.72 7 - DX . : . - 1 r.e. • :• • F-83 . -.,,,...- - --... v... . :..-.0..Si' ."-c• • .., - "I.I l "119111a- , 1:37 ,: .. .. -1 10 .. _ e. • 4.. • - \ .,...), 0 . - 4.■:.:.) -1;.•:,: Vs•-. \ Q ... - - • -......, s ' , i . ,-- --- , -, --- 7.7 \.,_,, ' -.. -.:.:, 7 0 - -t_Q 1 : ...,.,:co / , / -.7,-..x. .'"s.. '4i,::' ' iz / A c.?.::- . -.. — .------ .. .- / .. 4 .,., / ,o,. .... ....:. 1 k .„_____) ) \ ) 0".... ..):."'' . .,. l i i- aip '.... F-82A ,-- ,,, .0. • _____, „., ,.. --- ,. '.., .,....,, 1 " iK47:;,..._ , / _,,-...-..„ .-,,,., ,,,,•..,,„, ,- / _.. Noorrset wells inters faet 4 . i.4 . i•;;;. DL-3 6A>0( • - r, - . the Kuparuk reservoirs within the Area of Review 0 L-01A .„ , ...7 ...., ,_ - 4. Ic.-....-.. ... 0 ' 0 i _ .,. _..... . ..., 17 .7 ...... _ AOGCC SFD 11/9/2009 • TRANSMITTAL LETTER CHECKLIST WELL NAME MILNE PT UNIT F -82A PTD# 2091350 Development X Service Exploratory Stratigraphic Test Non - Conventional Well FIELD: MI.LNE POINT POOL: MILNE POINT, KUPARUK RIVER OIL Circle Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD -ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. , API No. 50- - - API number are between 60 -69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non - Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 ' ,, i '' Field & Pool MILNE POINT, KUPARUK RIVER OIL - 525100 Well Name: MILNEPT UNIT KR F -82A Program SER Well bore seg ❑ PTD #: 2091350 Company BP_ EXPLORATION (ALASKA) INC Initial Class /Type SER / PEND GeoArea 890_._ Unit 11328 _ On /Off Shore On Annular Disposal ❑ Administration 1 Permit fee attached NA 2 Lease number appropriate Yes Surface Location ADL0025509; Top Prod Int & TD ADL0388235 3 Unique well name and number Yes 1 4 Well located in a defined pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 1 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit boundaries. 6 Well located proper distance from other wells Yes Conservation Order No. 432C has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 432C has no interwell spacing restrictions. Wellbore will be more than 500' from 8 If deviated, is wellbore plat included Yes an external property line where ownership or landownership changes. 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes 1 11 Permit can be issued without conservation order Yes Appr Date 12 Permit can be issued without administrative approval Yes 13 Can permit be approved before 15 -day wait Yes SFD 11/9/2009 14 Well located within area and strata authorized by Injection Order # (put 10# in comments) (For Yes 15 All wells within 1/4 mile area of review identified (For service well only) Yes None 16 Pre - produced injector: duration of pre production less than 3 months (For service well only) No Sean McLaughlin: well clean up only. 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j,2.A -D) NA 18 Conductor string provided NA Conductor set in MPF -82 Engineering 119 Surface casing protects all known USDWs NA Surface casing set in MPF -82 20 CMT vol adequate to circulate on conductor & surf csg NA surface casing cemented to GL in MPF -82 21 CMT vol adequate to tie -in long string to surf csg NA Production casing set in MPF-82 22 CMT will cover all known productive horizons Yes Liner to be cemented and perfed 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes Rib equipped with Steel pits. All waste to approved disposal wells. 1 25 If a re- drill, has a 10-403 for abandonment been approved Yes 309 -370 P & A sundry 1 26 Adequate wellbore separation proposed Yes Proximity analysis performed. No issues . 1 27 If diverter required, does it meet regulations NA Wellhead already in place. BOP stack installed. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure = 3497 psi ( 9.6 ppg) drilling with 8.8ppg mud in conjuction with MPD technique GLS 11/9/2009 129 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 2797 psi Will test BOP to 3500 psi Ilk 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S on pad ... Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes AOR performed .. No wells with 1/4 mile. 35 Permit can be issued w/o hydrogen sulfide measures No H2S has been recorded at F -Pad; measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 9.6 ppg EMW; will be drilled with 8.8 ppg mud using a Appr Date 37 Seismic analysis of shallow gas zones NA coiled tubing rig and employing managed drilling pressure techniques. SFD 11/9/2009 1 38 Seabed condition survey (if off - shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Pub' Date: Date Date Commissioner: C missioner: Com i r / / - / ? -�j -J_' /HZ - -o f Or • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process • but is part of the history file. To improve the readability of the Well History file and to 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 information. tapescan.txt * ** REEL HEADER * * ** MWD 10/05/04 BHI 01 LIS Customer Format Tape * ** TAPE HEADER * * ** MWD 10/03/08 3053197 01 3" CTK * ** LIS COMMENT RECORD * ** 11,1111111111111111 Remark File Version 1.000 1111111111111111111 Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard - VERSION 1.20 WRAP. NO: One line per frame Well Information Block #MNEM.UNIT Data Type Information STRT.FT 8703.5000: Starting Depth STOP.FT 10761.5000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. - 999.2500: Absent value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPF -82A FLD . FIELD: Milne Point Unit LOC . LOCATION: 70 deg 30' 27.896 "N 149 deg 39' 36.114 "W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 2.375" CTK DATE. LOG DATE: 08 Mar 2010 API . API NUMBER: 500292297101 Parameter Information Block #MNEM.UNIT Value Description SECT. 06 Section TOWN.N T13N Township RANG. R1OE Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF . DF Log Measured from FAPD.F 42.15 Feet Above Perm. Datum DMF . DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 42.15 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level Page 1 Use- 00 —(35- /9(065 110 411 tapescan.txt CASE.F N/A Casing Depth OS1 . DIRECTIONAL Other Services Line 1 -Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True vertical Depths ( TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, vibration and Downhole weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Sperry Sun GR MWD dated 04 Aug 2000 above the Kick off Point of 9123 ft MD per Chloe Peterson with BP Exploration (Alaska), Inc. The MWD data is the PDCL for well MPF -82A. (8) The sidetrack was drilled from MPF -82 through a milled window in a 7 inch liner. Top of window 9123 ft.MD (6994.4 ft.TVDSS) Bottom of window 9129 ft.MD (7000.2 ft.TVDSS) (9) Tied to MPF -82 at 9043 feet MD (6922.1 feet TVDSS). (10) Baker Hughes INTEQ runs 4 was a cleanout run. (11) The resistivity interval from 9119 ft. MD to 9357 ft. (6990.8 ft. to 7104.3 ft. TVDSS) was logged on run 9, 39 hours after drilling. Data has been correlated to drilled gamma ray data and depth shifted +2 feet. (12) The interval from 10728 ft to 10762 ft MD (7066.3 ft. to 7060.1 ft. TVDSS) was not logged due to sensor to bit offset at well TD. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD -API units) ROP_AVG -> Rate of Penetration, feet /hour RACLX -> Resistivity (AT)(LS)400kHz- Compensated Borehole Corrected (OHMM) RACHX -> Resistivity (AT)(LS)2MHz- Compensated Borehole Corrected (OHMM) RPCLX -> Resistivity (PD)(LS)400kHz- Compensated Borehole Corrected (OHMM) RPCHX -> Resistivity (PD)(LS)2MHz- Compensated Borehole Corrected (OHMM) TVDSS -> True vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT 8709.79, 8710.2, ! 0.410156 8713.48, 8714.1, ! 0.615234 8721.49, 8721.08, ! - 0.411133 8733.39, 8731.96, ! - 1.43652 8735.85, 8734.42, ! - 1.43652 8739.55, 8741.19, ! 1.6416 8745.3, 8746.53, ! 1.23145 8753.1, 8754.53, ! 1.4375 8759.46, 8761.31, ! 1.84766 8765.82, 8767.67, ! 1.84668 8771.98, 8773.42, ! 1.43652 8777.5, 8778.11, ! 0.615234 8786.32, 8786.94, ! 0.615234 8792.69, 8793.1, ! 0.410156 8801.51, 8801.51, ! 0 8802.74, 8803.56, ! 0.821289 8806.23, 8806.44, ! 0.205078 Page 2 tapescan.txt 8814.85, 8815.67, ! 0.820312 8816.7, 8817.52, ! 0.821289 8824.09, 8824.5, ! 0.410156 8833.45, 8833.86, ! 0.410156 8838.99, 8840.63, ! 1.6416 8853.97, 8854.18, ! 0.205078 8861.57, 8862.39, ! 0.820312 8868.82, 8869.02, ! 0.206055 8872.92, 8873.54, ! 0.616211 8881.13, 8880.93, ! - 0.205078 8886.06, 8885.85, ! - 0.206055 8892.63, 8892.63, ! 0 8900.63, 8901.04, ! 0.411133 8907.61, 8907.61, ! 0 8914.38, 8914.8, ! 0.411133 8921.98, 8922.39, ! 0.410156 8927.93, 8927.93, ! 0 8932.6, 8933.01, ! 0.410156 8936.5, 8936.7, ! 0.205078 9112.28, 9111.45, ! - 0.821289 9117.2, 9115.97, ! - 1.23145 9122.33, 9121.72, ! - 0.616211 EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 118 records... Minimum record length: 10 bytes Maximum record length: 132 bytes °** FILE HEADER *° ** MWD .001 1024 *** LIS COMMENT RECORD * *° 1111111111111111111 Remark File version 1.000 The data presented here is final and has been depth adjusted to a Primary Depth Control (PDC) log provided by Sperry Sun GR MWD dated 04 Aug 2000 above the Kick off Point of 9123 ft MD per Chloe Peterson with BP Exploration (A The MWD data is the PDCL for well MPF -82A. FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 Page 3 III tapescan.txt one depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 115 Tape File Start Depth = 8703.500000 Tape File End Depth = 10761.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet * ** FILE TRAILER * * ** Tape Subfile: 2 128 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * ** FILE HEADER * * ** MWD .002 1024 * ** LIS COMMENT RECORD * ** m!! 11111111111111 Remark File Version 1.000 This file contains the raw - unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 Page 4 tapescan.txt One depth per frame (value= 0) Datum Specification Block Sub -type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F /HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 229 Tape File Start Depth = 8702.750000 Tape File End Depth = 10762.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet * ** FILE TRAILER * ** Tape Subfile: 3 242 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes * * TAPE TRAILER * * ** MWD 10/03/08 3053197 01 ** * REEL TRAILER * * ** MWD 10/05/04 BHI 01 Tape Subfile: 4 2 records... Page 5 II! 411 tapescan.txt Minimum record length: 132 bytes Maximum record length: 132 bytes 0 Tape Subfile 1 is type: LIS 0 Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8703.5000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8704.0000 84.2000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10761.5000 - 999.2500 48.4000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 8703.500000 Tape File End Depth = 10761.500000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 0 Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 8702.7500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 8703.0000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 - 999.2500 10762.0000 - 999.2500 48.4000 - 999.2500 - 999.2500 - 999.2500 - 999.2500 Tape File Start Depth = 8702.750000 Tape File End Depth = 10762.000000 Tape File Level spacing = 0.250000 Tape File Depth Units = feet 0 Tape Subfile 4 is type: LIS Page 6