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Home My WebLink About201-0621. 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: Renew Suspension 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? Yes No 9. Property Designation (Lease Number): 10. Field: MILNE POINT 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 14,453 NA Casing Collapse Structural Conductor Surface 3,090psi Intermediate Production 5,410psi Liner 13,890psi 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 AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Ryan Thompson Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY AOGCC USE ONLY 13,450psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0355018 201-062 C.O. 423 MILNE PT UNIT F-33A 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22689-01-00 Hilcorp Alaska, LLC Length Size Proposed Pools: 8,839 7,002 5,824 NA SAG RIVER OIL Same 9.2# / 13Cr80 TVD Burst 6,940 7,240psi MD 5,750psi 110 4,420 110 4,734 8,7337" 20" 9-5/8" 110 4,734 907-564-5005 ryan.thompson@hilcorp.com Wells Manager 13,5231,988 3-1/2" Kill string 8,822 Perforation Depth MD (ft): See Schematic 7" Baker S-3 Packer, 7' x 4-1/2" Baker S-3 Packer and NA 11,433' MD / 8,520' TVD, 11,487' MD / 8,559' TVD and NA 7,002' 11,72911,729 2-7/8" See Schematic No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov 324-088 By Kayla Junke at 2:27 pm, Feb 15, 2024 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2024.02.14 21:48:43 - 09'00' Taylor Wellman (2143) SFD 2/24/2024 SFD DSR-2/24/24 April 28, 2019 ADL0025509, MGR22MAR24 2029 -mgr JLC 3/22/2024 Hilcorp Alaska, LLC Taylor Wellman, Milne Point Wells Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 February 13, 2024 Chairman Brett Huber, Sr. Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Milne Point MPF-33A (PTD #201062) Application for Renewal of Existing Suspension (10-403) Dear Chairman Huber, An AOGCC witnessed suspended well inspection of Milne Point well MPF-33A was conducted on 06/16/2023 (20 AAC 25.110 (h)). The submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: Suspended Well Site Inspection form documenting the pressures and site condition. Wellbore diagram illustrating the current configuration of the well. Milne Point well MPF-33A was suspended on 4/28/2014 and has future utility as a rig sidetrack candidate. The strata through which the well was drilled is neither abnormally geopressured nor depleted. The well is mechanically sound, passing a test of the 7 casing to 3200 psi on 04/26/2014, against the 7 EZSV cement retainer at 7002 MD. Based on these conditions and the inspection on 06/16/2023, Milne Point well MPF-33A meets the provisions required in 20 AAC 25.110 (a)(1). Hilcorp Alaska, LLC requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h)). In summary, Hilcorp believes Milne Point well MPF-33A is mechanically sound and secure. If you have any questions, please call me at 907-777-8449 or Ryan Thompson at 907-564- 5005. Sincerely, Taylor Wellman Milne Point Wells Manager Attachments Technical Justification 2023 Suspended Well Site Inspection Form Wellbore Schematic Milne Point Well MPF-33A (PTD #201062) Technical Justification for Renewal of Suspended Status 02/13/2024 Well History and Status Milne Point well MPF-33A was CTD sidetracked as a Sag River producer in 2001. The well last produced in April 2012. The well was RWO in April 2014 to recover the stuck jet pump. The rig (Doyon 14) was unable to pull tubing from the pre-rig performed RCT cut @ 11,378. An on rig jet cut was performed @ 11,349 but the rig was unable to recover tubing. A jet cut was then made @ 7000 and the rig was able to recover the tubing. An overshot BHA engaged the fish @ 7000 and hit 55 jar licks up to 300k, but was unable to recover tubing below 7000. The well is secured with a 7 EZSV cement retainer set above the tubing stub at 7002. The 7 casing passed a 30 minute pressure test to 3200 psi on 04/26/2014. The 7 casing has a calculated cement top (w/ 30% wash out) @ 8174 MD. Formation tops of the well are listed below: The well future utility is as a sidetrack candidate. The northern area of F-Pad is being evaluated for wellbores that allow for extended reach drilling to access new areas previously unreachable. MPU F-34L1 was a 2024 example of this as well as the attempted sidetrack of long term shut in MPU F-17 for the same purpose. MPU F-33A will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Milne Point well MPF-33A is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well pressure readings are T/I/O = 0/0/0 psi. Request Hilcorp Alaska, LLC requests approval for renewal of the existing suspension status for MPF- 33A. A variance to the provisions of 20 AAC 25.110 (c) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition to allow for full evaluation of sidetrack candidacy or submission of a sundry aimed at achieving acceptable long term plugging of the reservoir. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Inspect Well Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,453 feet 7,002 feet true vertical 8,839 feet NA feet Effective Depth measured 7,002 feet NA feet true vertical 5,824 feet NA feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)See Schematic See Schematic See Schematic See Schematic Packers and SSSV (type, measured and true vertical depth)11,433' / 8,520' 11,487' / 8,559'N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: None 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Operations Manager Contact Phone: 7" Baker S-3 7"x4.5" Baker S-3 Burst N/A Collapse N/A 3,090psi 11,170psi 5,750psi 7,240psi 10,570psi 5,410psi Conductor 8,822'13,523' 11,699' 4,734'Surface Intermediate Liner 20" 7" 80' 4,705' 11,729' 8,733' MILNE POINT / SAG RIVER OIL MILNE PT UNIT F-33A Plugs Junk measured measured TVD 2-7/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-062 50-029-22689-01-00 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: Hilcorp Alaska LLC NA 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0355018 Casing Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf N/A measured true vertical Packer MD 110' Size 110' 4,420' Length 2,011' 9-5/8" NA Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Ryan Thompson ryan.thompson@hilcorp.com 907-564-5005 PL G Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 2:53 pm, Jun 23, 2023 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.06.23 12:13:26 - 08'00' Taylor Wellman (2143) RBDMS JSB 071123 WCB 1-18-2024 DSR-6/23/23 Size SPF Interval (TVD) 11730’- 13437’ MD Abandoned Sag River Perfs 3 3/8" 6 11,748'-11,788' (8741'-8770') DATE REV. BY COMMENTS Orig. DF Elev. = 29.14' (N 22E) Orig. GL Elev. = 11.4' DF To 7" csg. hnr. = 28.6' (N 22E) Tree:Cameron 4 1/16, 5M Wellhead: 11" x 7" 5M FMC Gen 5A w/ 4 1/2" FMC Tbg Hgr , 4 1/2“ TC-II threads on top and bottom. 4“ CIW H BPV profile MILNE POINT UNIT WELL F-33a API NO: 50-029-22689-01 9 5/8", 40 ppf L-80 Btrc. Perforation Summary Ref log: CR / CCL 08/08/96 BP EXPLORATION (AK) 7" float collar (PBTD) KOP @ 2500' Max. hole angle = 51 to 55 deg f/ 4600' to 10,850' Hole angle thru perfs = +90 DLS = 4.3 deg./100' @ 4350' 7" float shoe 20" 91.1 ppf, H-40 MPU F-33A 22 gm. Jumbo Jet charges (EHD = 0.76", TTP = 6.4") @ 135 / 45 deg. phasing 115' 7" x 20' short joint from11,587' to 11,607' wlm w/ RA tag on top. 7", 26 ppf, L-80, BTRC production casing ( drift ID = 6.151", Annular cap. = 0.0264 bpf ) 4734' md X 3-1/2" 9.2 ppf, 13CR-80, Vam ACE & TC-II tbg ( drift ID = 2.992", cap. = 0.0089 bpf ) 12363’ 12282’ 07/16/97 M. Linder RWO 4-ES09/13/97 M.Linder RWO 4-ES 3/8” pre drilled liner 3.5” HES ‘XD’ Duro sliding sleeve 7” x 4.5” Baker S-3 packer 4.5” X nipple (3.813” ID) WLEG 11487’ 11510’ 11600’ Top of window 11729’ 2-7/8”,6.6#. STL liner top 11512’ Bottom of pre-drilled liner 13523’ Bottom of 3-3/4” open hole 14445’ 04/05/01 M. Linder CTD side track into Sag River04/12/01 GMH Jet Pump Completion “Reverse Circulation” Jet Pump Configuration Power FluidPower Fluid Reservoir FluidSliding Sleeve BodySliding Sleeve 09/17/01 B. Hasebe Addition of Jet Pump flow schematic Top of jet cut 3.5“ XN nipple (2.813”/2.75” no-go) 4.5“ WLEG 7“ Baker S-3 packer 11404‘ 11433‘ 11469‘ 11483‘ 11486‘ 02/23/02 M. Linder RWO due to collapsed tubing Note:During the last RWO, the collapsed tubing and the previous S-3 Pkr were milled causing metal debris to fall downhole. 03/29/03 Lee Hulme RWO due to collapsed tubing 8/23/03 pushed metal chunk with coil as far as possible. Set CTU telex. A TRSV will need to be installed during the next RWO. o 4/24/14 SLB Eline RIH WITH 2.5" SLB JET CUTTER - CUT TBG @ 7000' EL~MD K I L L S T R I N G Note:4/27/14 During the last RWO, belived to have issue with the collapsed tubing. Unable to remove tubing below 7000' FT. SLB E-LINE TO JETCUT 3.5" TUBING) RUN IN W/ 2.75" JET CUTTER & CUT TBG @ 11349' 4/23/14 SLB E-LINE TO JETCUT 3.5" TUBING RUN IN W/ 2.75" JET CUTTER & CUT TBG @ 11349' EL~MD 04/27/03 B.Kruskie Doyon 16 RWO P&A well do to Stuck TBG. 3 1/2"9.2 #13CR-80Vam Ace TBG, Rig DPM 6940' Doyon set Retainer @ 7002' DPM Hilcorp Alaska F-33suspendedwellinspecƟonpics Back of well TBG gauge IA gauge OA gauge Front view Side view Back view Side view Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 07/31/2023 InspectNo:susAGE230620121313 Well Pressures (psi): Date Inspected:6/16/2023 Inspector:Adam Earl If Verified, How?Other (specify in comments) Suspension Date:4/28/2014 #314-272 Tubing:0 IA:0 OA:0 Operator:Hilcorp Alaska, LLC Operator Rep:Roger Allison Date AOGCC Notified:6/15/2023 Type of Inspection:Subsequent Well Name:MILNE PT UNIT F-33A Permit Number:2010620 Wellhead Condition good working order Surrounding Surface Condition Clean, no trash or dunage, no wellhouse but the foundation and grating package still installed with a well guard in place Condition of Cellar good no water Comments Pad Map verified Supervisor Comments Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Monday, July 31, 2023              1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Inspect Well Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 14,453 feet 7,002 feet true vertical 8,839 feet N/A feet Effective Depth measured 7,002 feet feet true vertical 5,824 feet N/A feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)See Schematic See Schematic See Schematic See Schematic Packers and SSSV (type, measured and true vertical depth)7" Baker S-3 7"x4.5" Baker S-3 11,433' / 8,520' 11,487' / 8,559'N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name:Chad Helgeson Contact Name: Authorized Title:Operations Manager Contact Email: Contact Phone: N/A 777-8333 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi 5,410psi 11,170psi Burst N/A 5,750psi 7,240psi 10,570psi Surface Production 20" 9-5/8" 7" 4,705' 80' measured N/A Liner Casing Conductor Size Junk Length 11,699' MILNE PT UNIT F-33A 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) Gas-Mcf Casing Pressure Tubing Pressure N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Signature with date: David Gorm dgorm@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 201-062 50-029-22689-01-00 Plugs ADL00355018 5. Permit to Drill Number: MILNE POINT / SAG RIVER OIL 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: Representative Daily Average Production or Injection Data WINJ WAG Water-Bbl MD 110' measured 4,420' 8,733' 8,822' 4,734' 2,011' TVD 110' Oil-Bbl measured true vertical Packer 13,523'2-7/8" 11,729' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations Chad A Helgeson 2020.10.01 11:07:40 -08'00' By Samantha Carlisle at 11:23 am, Oct 09, 2020 SFD 10/12/2020 DSR-10/12/2020MGR12OCT2020 RBDMS HEW 11/12/2020 Date Inspected: Inspector: Operator: Well Name: Oper. Rep: PTD No.: Oper. Phone: Location Verified? Oper. Email: If Verified, How? Onshore / Offshore: Date AOGCC Notified: Suspension Date: Type of Inspection: Sundry No.: Wellbore Diagram Avail.? Photos Taken? Well Pressures (psi): Tubing 0 IA 0 OA 0 Condition of Wellhead: Comments: Attachments: Insp. Suprv Comm None Location verified by Pad map WBS Pictures Area map Yes Yes Onshore 09/18/20 Subsequent Good, Clean, No leaks Good, Clean STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Brian Bixby 09/20/20 Yes Jon ArendMPF-33 (907)240-4383 Follow Up Actions Needed: Hilcorp 201-062 Condition of Surrounding Surface Location: 05/01/14 314-272 REVIEWED BY: Other (specify in comments) PLB 12/2014 MPF-33 Suspended Well Inspection 9-20-20 Size SPF Interval (TVD) 11730’- 13437’ MD Abandoned Sag River Perfs 3 3/8" 6 11,748'-11,788' (8741'-8770') DATE REV. BY COMMENTS MILNE POINT UNIT 9 5/8", 40 ppf L-80 Btrc. Perforation Summary Ref log: CR / CCL 08/08/96 7" float collar (PBTD) KOP @ 2500' Max. hole angle = 51 to 55 deg f/ 4600' to 10,850' Hole angle thru perfs = +90 DLS = 4.3 deg./100' @ 4350' 7" float shoe 20 91.1 ppf,H-40 22 gm. Jumbo Jet charges (EHD = 0.76", TTP = 6.4") @ 135 / 45 deg. phasing 115 7" x 20' short joint from11,587' to 11,607' wlm w/ RA tag on top. 7", 26 ppf, L-80, BTRC production casing ( drift ID = 6.151", Annular cap. = 0.0264 bpf ) 4734' md X 3-1/2" 9.2 ppf, 13CR-80, Vam ACE & TC-II tbg ( drift ID = 2.992", cap. = 0.0089 bpf ) 12363’ 12282’ M. Linder 3/8” pre drilled liner 3.5” HES ‘XD’ Duro sliding sleeve 7” x 4.5” Baker S-3 packer 4.5” X nipple (3.813” ID) WLEG 11487’ 11510’ 11600’ Top of window 11729’ 2-7/8”,6.6#. STL liner top 11512’ Bottom of pre-drilled liner 13523’ Bottom of 3-3/4” open hole 14445’ “Reverse Circulation” Jet Pump Configuration Power FluidPower Fluid Reservoir FluidSliding Sleeve BodySliding Sleeve Top of jet cut 3.5“ XN nipple (2.813”/2.75” no-go) 4.5“ WLEG 7“ Baker S-3 packer 11404‘ 11433‘ 11469‘ 11483‘ 11486‘ Note:During the last RWO, the collapsed tubing and the previous S-3 Pkr were milled causing metal debris to fall downhole. 8/23/03 pushed metal chunk with coil as far as possible. Set CTU telex. o 4/24/14 SLB Eline RIH WITH 2.5" SLB JET CUTTER - CUT TBG @ 7000' EL~MD LL S T R I N G to have issue with the collapsed tubing. Unable to remove tubing below 7000' FT. SLB E-LINE TO JETCUT 3.5" TUBING) RUN IN W/ 2.75" JET CUTTER & CUT TBG @ 11349' 4/23/14 SLB E-LINE TO JETCUT 3.5" TUBING RUN IN W/ 2.75" JET CUTTER & CUT TBG @ 11349' EL~MD 3 1/2"9.2 #13CR-80Vam Ace TBG, Rig DPM 6940' Doyon set Retainer @ 7002' DPM Suspended WellInspection Review Report Ins pectNo: susBDD200921141159 Date Inspected: 9/20/2020 - Inspector: Brian Bixby - Type ofInspection: Subsequent ' � Well Name: K4|LNEPTUNIT F'33A - Date AOG[[Notified: 9/18/2028 ~ Permit Number: 2010620 - Operator: Hi|coqpA|aska' LL[ � Suspension Approval: Sundry - # 314-272 ' Operator Rep: Jon Arend Suspension Date: 4/28/2014 - Wellbore Diagram Avail? Location Verified? W Photos Taken? if Verified, How? Other (specify in comments) offshore? El Well Pressures (psi): Tubing: n Fluid in Cellar? 0 �- |A: U(- BPV|ncta||ed7 11 ^ DA: U VRP|u,-,(S)Installed? [! Wellhead Condition All of the valves onthe appeared ingood working order with working gauges onthe Tubing, |Aand OA. There are noVR `/ Plugs or8PVinstalled. Condition ofCedar Good Condition. I did not observe and excessive water in cellar, trash or any sheen. Surrounding SurfaceCondition Everything looked good. I did not see debris or sheen around the pad. Comments I verified the location using the pad map. Supervisor Comments Photos (2)attached TCW06/ Monday, September ZQ,2O2O a M CY) M � i LL � (L� N 0) N m 0 m U) U Q) C:) Q- N O UC4 OF - Q a_ I w L- 0 O U a) Q - U) c U U CD O Q O O e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnscrts\Microfihn _ Marker. doc Permitto Drill 2010620 MD 14453 ~-~- TVD DATA SUBMITTAL COMPLIANCE REPORT 4116~2003 Well Name/No. MILNE PT UNIT SR F-33A Operator BP EXPLORATION (ALASKA) INC 8838 -- Completion Dat 4/5/2001 "'" Completion Statu 1-OIL APl No. 50-029-22689-01-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._go Sample N_go Directional Survey DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH I Dataset Name Scale Media No Start Stop CH Received Number Comments Ve~ L',S V~r:,fic ........................................................... -~1 ............... 'rO-1'45---¥23~49---Open~-~-'~2/28/2~)1 /...~z~98 ~ 2- ~ ! - ~ ~- ED ~'~ Ver LIS Verification __~_l_~4~__~t_,~4_1.9~._qgpem~__~2.f28/.200.1_~497 ----- 1 11697 14407 Open Ver LIS Verification 1 11691 14407 Open 1/11/2002 ~1'0532 ~ MWD Survey FINAL OH 5/1/2001 ~ Directional Survey FINAL OH 5/1/2001 Bi'Directional Survey 1 11726 14453 Open 4/19/2001 ,D~ectional Survey 1 11726 14453 Open 4/19/2001 MWD Survey, Digital Data Directional Survey, Paper Copy Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y / N Chips Received? Y / N Analysis Y / N R P.c~.iv~.d ? Daily History Received? Y / N FOrmation Tops ~ / N Comments: Permit to Drill 2010620 MD 14453 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/16/2003 Well Name/No. MILNE PT UNIT SR F-33A Operator BP EXPLORATION (ALASKA) INC 8838 Completion Dar 4/5/2001 Completion Statu 1-OIL I Current Status 1-OIL Date: APl No. 50-029-22689-01-00 UIC N STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 42' 3. Address [] Exploratory 7. Unit or Property Name [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service '~t. Location of well at surface 8. Well Number 1905' NSL, 2660' WEL, SEC. 06, T13N, R10E, UM X = 541904, Y = 60353~, MPF-33A At top of productive interval ~,.._. Permit Number / Approval No. ~ 201-062 3027' NSL, 2334' WEL, SEC. 31, T14N, R10E, UM X = 542169, Y = 6041760 10. APl Number At effective depth 50-029-22689-01 100' NSL, 3026' WEL, SEC. 30, T14N, R10E, UM X = 541454, Y = 6044109 11. Field and Pool At total depth Milne Point Unit / Sag River 100' NSL, 3026' WEL, SEC. 30, T14N, R10E, UM X = 541454, Y = 6044109 12. Present well condition summary Total depth: measured 14453 feet Plugs (measured) true vertical 8839 feet Effective depth: measured 14453 feet Junk (measured) true vertical 8839 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 260 sx Arcticset I (Approx.) 110' 110' Surface 4703' 9-5/8" 1250 SX PF 'E', 250 SX 'G', 150 sx PF 'E' 4734' 4419' Intermediate Production 12334' 7" 600 sx Class 'G' 11729' 8733' Liner 1988' 2-7/8" Uncemented Slotted Liner 11537' - 13525' 8594' - 8822' Perforation depth: measured Slotted Liner: 11730'- 13437' 3-3/4" Open Hole: 13525'- 14453' true vertical Slotted Liner: 8734' - 8819' 3-3/4" Open Hole: 8822'- 8839' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, 13Cr80, Vam Ace tubing to 11483' and 4-1/2", 12.6#, 13Cr tubing from 11486' - 11600'. Packers and SSSV (type and measured depth) 7" x 3-1/2" Baker S-3 packer at 11433' and a 7"x 87'. 13. Stimulation or cement squeeze summary APR ]. 0 2003 Intervals treated (measured) Alaska 0il & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: '15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service .17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Son~-,_~_ T_tle Technical Assistant Date ~.'~ '~'~- ~ ~' ~ I=~ I ~ I ~ I A [ Prepared By Name/Number: $ondra Stewman, 564-4750 , d"N RI ~'N I k I Form 10-404 Rev. 06/15/88R~DNJS I~F'L APR ~, ~ ~ I i~ I i~I .- Submit In Duplicate BP EXPLORATION Page 1 of 8 Operations Summa Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 3/13/2003 End: 3/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/28/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 3/12/2003 !21:00 - 22:00 1.00 MOB P PRE RDMO Rig 4ES from MPF-34 to MPF-33A. Scope / Lower derrick. Disconnect Pit module 21:00 - 00:00 3.00 MOB P PRE Disconnect pipe module 3/13/2003 00:00 - 01:00 1.00 MOB P PRE RDMO - Spot sub over well. 01:00 - 03:30 2.50 MOB P PRE Spot pit, pipe and camp modules. 03:30 - 06:00 2.50 MOB P PRE Raise and scope derrick, lower beaver slide. RU rig equip. 06:00 - 08:00 2.00 MOB P PRE R/U floor, lines to Tiger tank. 08:00 - 08:30 0.50 KILL P DECOMP Pre job on rigging up slickline, overall scope of slickline operation. 08:30 - 09:30 1.00 KILL P DECOMP PT slickline lubricator, 1500 psi, OK. 09:30 - 13:30 4.00 KILL P DECOMP M/U tools & RIH, shear KOBE knock out plug @ 154' SLM w/ downlick. POOH, M/U GS Packoff retrieving tool, RIH, latch up @ 154' SLM, spang up & pull free. POOH, L/D GS packoff. RID slickline off to the side. 13:30 - 14:00 0.50 KILL P DECOMP Safety meeting on well kill ops & overall operation on this well. 14:00 - 19:00 5.00 KILL P DECOMP SITP = 700 psi, SICP = 830 psi, O/A = 0 psi. Pump @ 4 bpm / 150 psi down tubing w/filtered seawater, taking gas returns thru choke to tiger tank. See casing pressure drop to 50 psi, tbg to 250 psi @ 3 bpm, 520 psi @ 4 bpm. Pump 625 bbls total, 270 bbls fluid returned to tiger tank. Monitor well. 19:00 - 19:30 0.50 KILL P DECOMP Monitor well. Well dead on tbg and annulus. 19:30 - 21:30 2.00 KILL P DECOMP RU / HES- RIH set GS Packoff. Test packoff, would not test. Spang on packoff to reset, still unable to test packoff. 21:30 - 22:30 1.00 KILL P DECOMP POH / PU retrieving tool. RIH and pull GS packoff. Packoff had gravel in it. 22:30 - 23:00 0.50 KILL P DECOMP RIH with wireline brush, flush and brush receptacle w/ redressing GS Packoff. 23:00 - 00:00 1.00 KILL P DECOMP RIH with re-dressed GS packoff. Test packoff to 1000 psi. OK 3/14/2003 00:00 - 01:00 1.00 KILL P DECOMP Blow down lines. RD HES 01:00 - 03:00 2.00 WHSUR P DECOMP ND Tree 03:00 - 07:00 4.00 WHSUR P DECOMP NU 13 5/8 x 5M BOPE 07:00 - 07:30 0.50 WHSUR P DECOMP Safety meeting w/new crew. Discuss operation of inflatable bridge plug & overall scope of the well procedure. 07:30 - 10:00 2.50 wHSUR P DECOMP Pick up Baker 2 1/8" IBP & RIH on 4 jts 1 1/4" CS Hydril tbg. M/U cir¢ head & pressure up on tubing to 1500 psi. Set down on IBP, pressure up to 1700 psi & release from IBP. LID CS Hydril. 10:00 - 13:00 3.00 WHSUR N RREP , DECOMP Line from choke manifold to gas buster iced up, thaw same w/ steam. 13:00 - 16:00 3.00 WHSUR P DECOMP Test BOPE. Witnessing of test waived by AOGCC State Rep Chuck Scheve. 24 hrs notice given. No failures. 16:00 - 17:00 1.00 WHSUR P DECOMP M/U retrieving tool on 1 1/4" CS Hydril. RIH w/(4) jts, engage & release Baker IBP. LID same. M/U knock out tool & RIH w/(5) jts 1 1/4" CS Hydril & beat down on KOBE knock out plug. POOH & LID tool. Fi 17:00 - 17:30 0.50 WHSUR P DECOMP Fill hole & monitor. Fluid level not dropping. Call for GS packoff pulling tool & line up on annulus valve. Pump 97 bbls @ 5 bpm / 125 psi down I/A looking for flow on tubing side, no flow. Shut down & check I/A...vacuum. Close blind shears & pressure up on tubing 1400 psi, not bleeding off. Bleed pressure. 17:30 - 19:00 1.50 WHSUR P DECOMP M/U GS packoff retrieving tool & RIH on CS Hydril, engage packoff & straight pull release. Fluid level now dropping in tubing. POOH & LID tools & tbg. Printed: 3/31/2003 11:00:53AM BP EXPLORATION Page 2 of 8 Operations Summary Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 3/13/2003 End: 3/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/28/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From- To Hours Task Code NPT Phase Description of Operations 3/14/2003 19:00 - 20:30 1.50 PULL P DECOMP PU landing jt. BOLDS Pull hgr to floor, PUW 66k. LD landing jt and hgr. 20:30 - 21:30 1.00 PULL P DECOMP RU and load hole with 50 bbls SW down tbg at 6 bpm / 150 psi. RU to pull 3 1/2" tbg. Monitor well, tbg on vacuum. 21:30 - 00:00 2.50 PULL P DECOMP POH with 3 1/2" tbg (8 rd thrds) 3/15/2003 00:00 - 05:00 5.00 PULL P DECOMP Continue POH with 3 1/2" tbg. 237 jts + (1) GLM + 5' of cut off jt + RKB & hanger = 7492.68'. Tubing was not in bad shape & corroded towards the bottom of the string & cut was good. 5' cut off piece was split, probably due to excessive string shot & weak wall from corrsion. 05:00 - 06:00 1.00 PULL P DECOMP RD tubing running tools, clear floor. RU DP running tools 06:00 - 07:00 1.00 FISH P DECOMP PJSM measure tools. Set wear bushing. 07:00 - 08:00 1.00 FISH P DECOMP M/U BHA to mill / drift OD of collapsed tubing. Shoe, (3) jts washpipe, junk sub, bumper sub, oil jars & (9) 4 3/4" DCs. 08:00 - 13:30 5.50 FISH P DECOMP Pick up 3 1/2" DP & RIH w/Washover BHA. 227 jts. 13:30 - 14:00 0.50 FISH P DECOMP Pick up kelly. 125K up wt, 95K down wt, 104K rotating wt. Off bottom torque = 4000 ft/Ibs. 1 bpm / 25 psi. Wash down w/o rotating & tag top of tubing stub @ 7489' DPM. 14:00 - 18:00 4.00 FISH P DECOMP Kick in rotary table @ 50 -60 RPM & see torque @ 7517', (just below collar). Mill to 7529' slowly, seeing torque & letting it mill off, inching down, 2-5K WOB. Wash down w/no torque f/ 7529'-7543'. Tag @ 7543' & mill on seeing torque, (6k-8k fi/lb), to 7546'. Stacking wt. with no torque, 10K WOB. Looks like we are spinning. May have twisted off at connection in 3 1/2" tbg @ 7546'. 18:00 - 19:00 1.00 FISH P DECOMP POOH w/washover BHA. 19:00 - 20:00 1.00 FISH P DECOMP Slip and cut 84' drlling line 20:00 - 00:00 4.00 FISH P DECOMP Continue POH with washover BHA, stand back DP & DC 3/16/2003 00:00 - 01:00 1.00 FISH P DECOMP Lay down BHA, recovered 47' of 3 1/2" tbg. Tbg was 'balled-up' inside the washover shoe. Appears to be part of the collapsed section. The chemical cut section had ~ 2" split ~ 4"below cut, similar to the split in the recovered section of tbg that had been chemical cut. Suspect the split's came from the string shot, tbg showed some erosion on this jt. 01:00 - 02:00 1.00 FISH P DECOMP MU BHA #2 - shoe, 3 jts washover pipe, boot basket, bumper sub, oil jars, 9 ea drill collars.(OAL 395') 02:00 - 05:30 3.50 FISH P DECOMP TIH with BHA #2. 05:30 - 06:00 0.50 FISH P DECOMP Kelly up, establish parameters. 125K up wt, 95K down wt, 104K rotating weight. Adjust torque limiter to stall @ 1000-2000 ft/Ibs over freespin torque. Torque off bottom 4000 fi/lbs. 06:00 - 07:30 1.50 FISH P DECOMP Tag up @ 7546', milled w/little torque, dress off top of fish top...15 minutes, ran in making connections to 7639', rotating over collars. Looks like pipe below 7546' is good. 07:30 - 09:00 1.50 FISH P DECOMP POOH w/washover BHA. 09:00 - 09:30 0.50 FISH P DECOMP Break down BHA & add mechanical cutter. 09:30 - 12:00 2.50 FISH P DECOMP RIH w/BHA to make outside cut on 3 1/2" tbg. 12:00 - 12:30 0.50 FISH P DECOMP Kelly up & establish parameters. 125K up wt, 95K down wt, 104K rotating wt. No tag @ top of stub/collar. 231 jts DP + BHA + 14' of kelly = 7584. The flipper dogs that catch collar are 5.5' above shoe @ 7578.5' + 1.5' of bumper sub elongation = 7580'. collar @ 7577'. 12:30 - 14:30 2.00 FISH P DECOMP Rotating @ 7580' w/4000 fi/lbs of torque. Pick up 1-2" & rotate @ 40-50 RPM for a minute or so, watching for torque increase. Printed: 3/31/2003 11:00:53AM , (. (r BP EXPLORATION Page 3 of 8 Operations Sumrna Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 3/13/2003 End: 3/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/28/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 3/16/2003 12:30 - 14:30 2.00 FISH P DECOMP Continue working uphole in this manner. @ 7576' DPM, see torque increase to 6000 ft/Ibs. Rotate there for 10 minutes. Pick up 1" & Rotate, see sharp spike in torque to 9000-10000 ft/Ibs, then torque falls off to 4000 ftlbs. Continue working up hole as at the beginning to be sure cut was made to 7573'. Pick up free w/no indication of any overpull. Looking like a good cut. 14:30 - 17:00 2.50 FISH P DECOMP Stand back kelly & POOH w/3 1/2" DP & mechanical cutter BHA. 17:00 - 18:00 1.00 FISH P DECOMP LID cutting BHA. Recovered 33' of 3 1/2" tubing, (1) full jt & twisted off section of pipe, (8"), above top collar. 18:00 - 19:00 1.00 FISH P DECOMP Crew change, clear floor, rig up to run 4 1/2" work string tbg. 19:00 - 20:00 1.00 FISH P DECOMP PJSM with NAD, BOT, BP. - MU / BHA ~4-overshot guide, bowl, overshot ext, top sub(OAL 6.6') 20:00 - 00:00 4.00 FISH P DECOMP PU / RIH with overshot on 4 1/2" Mod Btc work string. 3/17/2003 00:00 - 03:00 3.00 FISH P DECOMP Continue RIH picking up 4 1/5" work string 03:00 - 04:30 1.50 FISH P DECOMP TIH looking for top of tbg stub at 7579', 85K up wt, 70K dn wt, 78K rotating wt. Observed a slight bobble,continue in to 7600' with no other indications of tagging tbg stub. PU to 150k, appeares overshot had engaged tbg stub by swallowing tbg. Slack off to neutral and work to release fish, attempting to have a connection at rig floor. Set slips with 175k pull. Lay down single leaving connection on floor for wireline. 04:30 - 05:00 0.50 FISH : P DECOMP PJSM. RU / HES slickline to pull Jet pump. Fluid level in tubing & I/A indicating jet pump oriface is plugged. 05:00 - 11:30 6.50 FISH :P DECOMP RIH with 3" GR, (2.79" OD) knuckle joint, short spangs, knuckle jt, oil jars, 5' x 2.6" roller stem, knuckle jt & latch up jet pump @ 11,415' SLM. Spang & jar up, attempt to release, finally sheared off GR tool. POOH & M/U GS tool w/same arrangement above. Latch up @ 11,415' WLM, spang & jar (45 min), release jet pump. Hydrostatic differential pushing jet pump downhole to X/N nipple @ 11,467' SLM. Attempt to spang / jar jet pump off X/N profile, no good. POOH to cut wire. Adjust plan, RID slickline unit. 11:30 - 13:30 2.00 FISH P DECOMP PJSM. Rig up Sclumberger E-line unit. 13:30-17:00 3.50 FISH P DECOMP RIHw/2strandsx14'stringshotgun,&CCL. Tag top of jet pump @ 11,465'. Tie in to tubing tally. Confirm tie in. Elect to cut tbg @ 11,435' corrected depth, leaving approximately 7' of the 10' pup directly above the S-3 packer currently in the hole. Fire string shot f/11,437' - 11,423'. POOH w/E-line. 17:00 - 18:00 1.00 FISH P DECOMP PJSM. Pick up chemical cutter & RIH 18:00 - 19:30 1.50 FISH P DECOMP Crew change, continue RIH with SWS chemical cutter. Tight working thru overshot at 7579'. Tie in and fire chemical cutter at 11435 ELM. Good surface indication of firing. (40K overpull) 19:30 - 21:30 2.00 FISH P DECOMP POH with SWS chemical cutter, stop at 200', have PJSM, roles and responsibilities of handling chemical cutter rig down. Continue POH. Pull on tbg to verify tbg had been cut, tbg free at 135k up wt. 21:30 ~ 22:00 0.50 FISH P DECOMP RD / SWS wireline and RU tbg running equip 22:00 - 00:00 2.00 FISH P DECOMP POH laying down 4 1/2" workstring 3/18/2003 00:00 - 04:30 4.50 FISH P DECOMP Continue POH with 4 1/2" work string. 04:30 - 05:00 0.50 FISH P DECOMP LD overshot and 1 jt 3 1/2' tbg. RU to pull 3 l/2"tbg 05:00 - 09:00 4.00 FISH P DECOMP !POH laying down 3 1/2" tbg 09:00 - 09:30 0.50 FISH P DECOMP ' RU to run 3 1/2 DC / DP Printed: 3/31/2003 11:00:53 AM BP EXPLORATION Page 4 of 8 Operations Summa Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 3/13/2003 End: 3/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/28/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 3/18/2003 09:30 - 11:30 2.00 FISH P DECOMP RIHwith DP/DC 11:30 - 12:00 0.50 FISH P DECOMP Circulate btms up at 7500' 12:00 - 15:30 3.50 FISH P DECOMP POH laying down DP / DC 15:30 - 16:00 0.50 FISH P DECOMP Pull wear bushing 16:00 - 17:00 1.00 RUNCOr~P COMP Clear and clean floor 17:00 - 21:00 4.00 RUNCOI~P COMP RU hydraulic tongs and torque turn equip. PJSM with NAD / BOT / BP 21:00 - 00:00 3.00 RUNCOItP COMP Pick up and run 3 1/2" 13CR tbg. Torque turn connections. 3/19/2003 00:00 - 16:00 16.00 RUNCOI~F' COMP RIH with 3 1/2" Completion 13 CR tbg. Set down with 5k wt on obstruction at 11288' PU with 10k overpull. 16:00 - 17:30 1.50 PULL N DPRB COMP RU to circlate. Confer with Anc Supv and Eng., decision to pull tbg and not take chance of placing to much wt on pkr and setting pkr. Plans are to pick up and RIH with DP and csg scraper. 17:30 - 00:00 6.50 PULL N DPRB COMP PJSM with NAD / BP / BOT- POH laying down 3 1/2 tbg.( unable to stand tbg in derrick when using compensator). 3/20/2003 00:00 - 06:00 6.00 PULL N DPRB COMP Continue POH with 3.5 tbg to make a csg scraper run to clear obstruction. 06:00-09:30 3.50 PULL N DPRB COMP PJSM. Finished POOH with 360 jt of 31/2"13 CR Tbg. 09:30 - 10:00 0.50 PULL N DPRB COMP Pull Pkr Assy and inspect. Good. Stand back. 10:00 - 11:00 1.00 PULL N DPRB COMP RD special handling equipment for 3 1/2" 13CR Tbg. 11:00 - 11:30 0.50 CLEAN N DPRB DECOMP RU to handle and PU 3 1/2" DP from pipe shed. Install wear bushing. 11:30-12:00 0.50 CLEAN N DPRB DECOMP Make up BHA #5 as follows: 6"bit, BitSub, 31/2"PupJt.,XO, Csg Scraper, XO. 12:00 - 18:00 6.00 CLEAN N DPRB DECOMP RIH with BHA #5. Tally and PU / DP singles from Pipeshed. 18:00 ~ 22:30 4.50 CLEAN N DPRB DECOMP Crew change, PJSM. continue RIH picking up DP from pipeshed. Tag fill at 11288'. 22:30 - 23:00 0.50 CLEAN N DPRB DECOMP RU to reverse circulate 23:00 - 00:00 1.00 CLEAN N DPRB DECOMP Reverse circulate, work pipe down to 11294',stopped solid, PUW 157k - SOW 95k, unable to wash down any deeper. Bottoms up circulation returned sand, small gravel, chunks of scale. 3/21/2003 00:00 - 01:00 1.00 CLEAN N DPRB DECOMP PU kelly, tag at 11294". PUW 160k-SOW 107k. Rotate, no torque, apply 25k down wt, unable to work down hole. Fill is still very solid. 01:00 - 02:30 1.50 CLEAN N DPRB DECOMP RU and reverse circulate 3 bottoms up. Hole clean. 02:30- 03:30 1.00 CLEAN N DPRB DECOMP Set back and blow down kelly. 03:30-04:00 0.50 CLEAN N DPRB DECOMP LD10jts3.5"DP. 04:00 - 05:00 1.00 CLEAN N DPRB DECOMP Slip and cut 84' drilling line. 05:00- 06:00 1.00 CLEAN N DPRB DECOMP Start POOH with bit and Scraper. Crew change. 06:00 - 09:00 3.00 CLEAN N DPRB DECOMP PJSM. Finish POOH. Stand back/3 1/2" DP- 361 jts 09:00 - 10:00 1.00 CLEAN N DPRB DECOMP LD Bit & Csg Scraper. Pull wear bushing. C &C floor. 10:00 - 14:00 4.00 BOPSUR N DPRB DECOMP Perform weekly BOPE test as per BP/AOGCC requirements at 250/3500. Good test. Blow down lines. AOGCC Inspector John Crisp witnessed test. 14:00 - 17:00 3.00 CLEAN N DPRB DECOMP PU & MU BHA # 6 - shoe, extension, drive sub, boot basket, boot basket, cross over, oil jars, 9ea DC(OAL 309') 17:00-21:30 4.50 CLEAN N DPRB DECOMP RIHwithBHA#6-crewchange, PJSM.tag fill at11295' 21:30-22:30 1.00 CLEAN N DPRB DECOMP PUkellyPUW165K-SOW110K. start milling with 60 rpm - 4 bpm - 600 psi - 150 torque. Wash and mill slightly hard scale from11295' to 11320'. 22:30 - 00:00 1.50 CLEAN N DPRB DECOMP RU to reverse circulate, DP pressured up, unable to reverse. Printed: 3/31/2003 11:00:53AM BP EXPLORATION Page 5 of 8 Operation Sumrna Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 3/13/2003 End: 3/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/28/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 3/21/2003 22:30 - 00:00 1.50 CLEAN N DPRB DECOMP RU to pump the long way, pump 40 bbl vis sweep to clean hole, scale and fine silty sand returns. 3/22/2003 00:00 - 04:00 4.00 CLEAN N DPRB DECOMP Milling from 11320' to 11352' easy with some stringers, pump 20 bbl HV sweep at connection, mostly scale returns. Mill from 11352' to 11382', easy, some stringers, pump 20 bbl HV sweep at connection, beach looking sand returns. Mill from 11382' to 11414'. easy, some stringers, pump 20 bbl HV sweep, beech looking sand returns. Tag and set over top of 3 1/2" stub at 11441' DD. Pump 40 bbl HV sweep to surface, with same beech looking sand and some scale returns. 04:00 - 06:00 2.00 CLEAN N DPRB DECOMP Mix and pump 40 bbl HV sweep to clean hole of sand. Crew change. 06:00 - 08:00 2.00 CLEAN N DPRB DECOMP PJSM. Continue to clean upwell. Move pipe. Circulate out sand @ 6 bpm/1550 psi. 08:00 - 12:00 4.00 CLEAN N DPRB DECOMP Set back kelly. TOOH with 3 1/2" DP = 356jts. and DC = 9 ea. 12:00 - 12:30 0.50 CLEAN N DPRB DECOMP LD part of BHA #6. Clean Boot Baskets (see remarks). 12:30 - 13:00 0.50 CLEAN N DPRB DECOMP Change out Washover shoe to smaller OD washover shoe. Add Csg Scraper to BHA. 13:00 - 14:30 1.50 CLEAN N DPRB DECOMP TIH with BHA #7 and 4,500-ft of 3 1/2" DP. Stop. 14:30 - 15:00 0.50 CLEAN N DPRB DECOMP Reverse circulate Annu Vol -- 135+/- bbls. Saw very little sand. 15:00 - 16:00 1.00 CLEAN N DPRB DECOMP Continue TIH with 3 1/2" DP.to 9000' 16:00 - 16:30 0.50 CLEAN N DPRB DECOMP Reverse circulate at 9000', 225 bbls very little sand returns. 16:30 - 18:30 2.00 CLEAN N DPRB DECOMP Continue RIH with 3 1/2" DP, tag top of stub at 11439', engage stub and set down over shot to 11432' (TOS). 18:30 - 20:30 2.00 CLEAN N DPRB DECOMP RU and reverse circulate hole clean at 11432'; pump 50 bbls SW, pump 20 bbl sweep -100 bbls SW - 20 bbl sweep at 6 bpm -1500 psi, perhaps a cup full of scale returned, no sand returns. 20:30 - 23:30 3.00 CLEAN N 'DPRB DECOMP Pump 40 bbl sweep,change hole over to clean seawater, clean pits 23:30- 00:00 0.50 CLEAN N DPRB DECOMP POH with BHA # 7 3/23/2003 00:00- 04:00 4.00 CLEAN N DPRB DECOMP POH with BHA# 7 04:00 - 05:00 1.00 CLEAN N DPRB DECOMP LD 4 3/4 DC and BHA # 7. Nothing in boot basket. 05:00 - 06:00 1.00 CLEAN N DPRB DECOMP MU BHA # 8 - mule shoe, canfield bushing, CS Hydril pup jt,, 2 jt CS Hydril, XO, dbl pin, boot basket, boot basket, bumper sub, oil jars, disconnect sub (OAL 91.95'). Crew change. 06:00 - 09:00 3.00 CLEAN N DPRB DECOMP PJSM. TIH with BHA #8 as Follows: Canfield Bushing, Mule Shoe, Pup Jr, 2 ea 2 1/16" Tbg., XO, XO, 2 Boot Baskets, Bit Sub, Oil Jar Pump-out Sub. OAL - 91.95'. Up wt - 162K. Down wt = 102K. 09:00 - 11:30 2.50 CLEAN N DPRB DECOMP Enter top of Tbg stub at 11,433'. Pump rate - 4.0 bpm/1100 psi. Wash and work down inside Tail Pipe to 11,457' at. Reverse Circulate down to 11,460~ft 4es RKB. Unable to make any further hole. (Expected top of Jet Pump = 11,460-ft - 11462-ft.). Reverse btms up. Recovered some scale pieces and small scale chunks. SD pumps and shot-trip x 2 Tbg tail with no problems. 11:30-15:00 3.50 CLEAN .N DPRB DECOMP POOH with BHA #8. LD 21/16" Mule Shoe and Pup Jt. 15:00 - 15:30 0.50 FISH . N DPRB DECOMP MU BHA #9 as follows: Add GS Spear, Ball Drop Disconnect (5/8" ball), XO back to 2 1/16" Tbg. Position Canfield Bushing and re-pin (2 brass screws). OAL = 92.36-FT. 15:30 - 18:00 2.50 FISH N DPRB DECOMP TIH with BHA #9 and 3 1/2" DP. 18:00 - 19:30 1.50 FISH N DPRB DECOMP Crew change, PJSM. Slip & cut 84' drilling line. Printed: 3/31/2003 11:00:53 AM , BP EXPLORATION Page 6 of 8 Operations Summary Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 3/13/2003 End: 3/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/28/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From- To Hours Task Code NPT Phase Description of Operations 3/23/2003 19:30 - 20:30 1.00 FISH N DPRB DECOMP Continue RIH with BHA # 9, tag stub at 11437' PUW 165k, SOW 105k 20:30 - 23:30 3.00 FISH N DPRB DECOMP RU and circulate, work pipe, attempt to latch jet pump. When weight is set down 5 k, pump pressure increases, when weight is lifted, the pressure drops off. Work to 11453', unable to work down to jet pump. Pump 15 bbl sweep around shoe. Attempt to latch pump. Same results as before. 23:30- 00:00 0.50 FISH N DPRB DECOMP POH with BHA # 9 3/24/2003 00:00 - 03:30 3.50 FISH N DPRB DECOMP Continue POH with BHA # 9. No recovery in junk baskets, lay down GS pulling tool. No damage to GS. 03:30 - 04:00 0.50 FISH N DPRB DECOMP MU BHA # 10-canfield bushing, 1.35 mule shoe stinger, 2 ×o, 2 jts 2 1/16 tbg, xo, dbl pin sub, 2 boot basket, oil jar, pump out sub (OAL 90.23') Clean floor. 04:00-06:00 2.00 FISH N DPRB DECOMP RIHwith BHA# 10. Crew change. 06:00 - 08:00 2.00 FISH N DPRB DECOMP PJSM. Finish RIH with BHA #10 and 3 1/2" DP = 365jts. 08:00 - 12:30 4.50 CLEAN N DPRB DECOMP Enter Tbg stub at 11,433-ft. Tagged at 11,447-ft. inside Tbg Tail. (previous CO = 11,460-ft). Bring pump on line and work passed debris down to 11,454-ft. Got hung up. Pull free and pull out of TT and TS. Enter TS and continue down thru TT to 11,460-ft. with no problems. Unable to make any progress. Pumps rates = 3.5 bpm/900 psi. 4.7 bpm/1450 psi 5.7 bpm/2000 psi. Work pipe. Got hung up. Pull free. Pull out of TT and TS. Return to 11,460-ft. Fell thru and continue down to 11,465-ft. Work pipe and pump at 5.0 bpm. No further progress. Reverse circulate bottoms up x 2. Recovered a very small amount of small scale particles. Pull above TT and TS. Make dry tag runs x2. PUW =165K...SOW = 105K..Both tags again at 11,465-ft. Pump long way at 6.0 bpm/210Opsi and work pipe. Taking weight at same place every time. Made no further progress. Pull up above TS and park for 30 mins. Enter TS and make dry tag run. Tagged again at 11,465-ff...smooth normal weights. No problems. Discuss with Anch Eng. 12:30- 15:30 3.00 CLEAN N DPRB DECOMP POOH with 3 1/2" DP = 365 Jts and BHA #10. LD 1.35" Mule Shoe. XO above MS = 2.47" O.D. had a 1/8" wide x 1/16" deep gouge along the entine length. 15:30 - 16:00 0.50 FISH N DPRB DECOMP Add GS Spear and Ball Drop Disconnect. BHA #11 as follows: Canfield Bushing, GS Spear, Ball Drop Disconnect (5/8" ball), XO Sub, 2 jts 2 1/16" tbg, XO, 2 Jts 2 1/16" Tbg, XO Sub, Double Pin Sub, Boot Basket, Boot Basket, Bit Sub, Oil Jar, Pump-Out Sub. 16:00-18:00 2.00 FISH N DPRB DECOMP RIH with BHA #11and 31/2" DP = 365. 18:00 - 19:30 1.50 FISH N DPRB DECOMP Crew change, PJSM, Continue RIH with BHA # 11 and 3 1/2" DP 19:30-20:30 1.00 FISH N DPRB DECOMP Tagtbgstubat11465',PUW165k-SOW105k. Startpump, 3 bpm - 1600 psi, work pipe set 5k wt on jet pump. Unable to latch jet pump after working pipe 4x and changing pump rates 4x. 120:30 - 23:00 2.50 FISH N DPRB DECOMP Confer with ANC Eng, decision to pump acid. RU hardline on rig floor. RU HBR & SWS. PJSM, radio communication, PPE, pump rates/pressures, neutralizer, roles and responsibilities of handling acid. 123:00 - 00:00 1.00 FISH N DPRB DECOMP PT lines 3500 psi, pump 25 bbls 15% HCL acid to pickle DP at Printed: 3/31/2003 11:00:53 AM BP EXPLORATION Page 7 of 8 Operations Summary Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 3/13/2003 End: 3/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/28/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From- To Hours Task Code NPT Phase Description of Operations 3/24/2003 23:00 - 00:00 1.00 FISH N DPRB DECOMP 3 bpm / 1700 psi, freeze protect lines with 5 bbl MEOH. Switch to rig pump and spot 10 bbls acid in IA at 4 bpm/2100 psi. SD pumps, let soak 15 min, close hydril inject at 2 bpm / 2000psi for 2 bbls while setting above jet pump. Set down with 5k on jet pump at 11465', inject at 2 bpm / 600 psi, jet pump appears to be open. Monitor well, annulus on vacuum, fluid out of sight. Abort pumping the remaining 10 bbls acid. 3/25/2003 00:00 - 00:30 0.50 FISH N DPRB DECOMP PU 4', flush DP with 25 bbls seawater to clear pipe of acid. Set back down on jet pump at 11465'. 00:30 - 01:00 0.50 FISH N DPRB DECOMP RD hardline and clear floor, monitor well, drill pipe x ann on vacuum. 01:00- 05:00 4.00 FISH N DPRB DECOMP POH and stand DP in derrick 05:00 - 06:00 1.00 FISH N DPRB DECOMP LD BHA # 11 - jet pump not recovered. Crew Change. 06:00- 06:30 0.50 FISH N DPRB DECOMP PJSM. Lub Rig. 06:30 - 07:30 1.00 FISH N DPRB DECOMP MU BHA #12...Pkr Milling Assy as follows: 6 1/8" Shoe, 2 ea Extentions, Drive Sub, XO, 3 ea Boot Baskets, Bit Sub, Bumper Sub, Oil Jar, Pump-out Sub, 9 ea 4 3/4" DCs. 07:30-11:00 3.50 FISH N DPRB DECOMP RIH with BHA #12 and 31/2" DP = 356 jts. PUW=190K SOW = 110K. 11:00 - 18:00 7.00 FISH N DPRB DECOMP PU Kelly. Dry tag top of Pkr at 11,440-ft 4es RKB. Bring pump on line. 160 bbls to fill hole. Rotating Tag = 11,439-ft. Begin milling on Pkr. Pump rate = 3.0 bpm/500 psi. Amps = 290. RPM = 75. Weight on Mill = 10K. Milled from 11,439-ft to 11,442-ft. Crew change. 18:00 - 00:00 6.00 FISH N DPRB DECOMP PJSM. Continue with milling ops. Mill from 11,442 to 11445'. P/U 185K, S/O 107K, Rot 135K. PP 0-1500 psi. 0-5 Bpm. 50-100 Rpms. WOB 12K. Torq 9-12K. Losses dcreased to less than 1 BPH, then in last hr losses started to increase. 3/26/2003 00:00-01:30 1.50 FISH N DPRB DECOMP Con'tto mill to 11447'. Pkrmoved. Lost torq. Had 50K over pull then came free. Lost returns, hole won't stay full. P/U 185K, S/O 107K, Rot 135K. PP 0-1500 Psi. 0-5 BPM. WOB 12K. Rpms 50-100, Torq 9-12K. 01:30 - 06:00 4.50 FISH N DPRB DECOMP POOH w/milling assy. Had 50K overpull off bottom. Drug first stand off bottom. Crew change. 06:00- 07:00 1.00 FISH N DPRB DECOMP PJSM. BHA #12 OOH. LD Shoe...98% worn. Empty Boot Baskets...some cuttings. LD same. 07:00- 08:30 1.50 FISH N DPRB DECOMP MU BHA #13 as follows: OS Guide, OS Bowl...w/3 1/2" basket grapple, OS Ext, Top Sub, Bumper Jar, Oil Jar, 9 ea 4 3/4" DCs, Acc Jar, Pump-out Sub. OAL = 316.91' 08:30 - 10:00 1.50 FISH N DPRB DECOMP Cut & Slip drilling line. Adjust draw works breaks. Lub Rig. 10:00-12:00 2.00 FISH N DPRB DECOMP TIH with BHA #13 and 31/2" DP = 356 jts. 12:00-13:00 1.00 FISH N DPRB DECOMP PUKelly. PUW=193K. SOW=l17K. Engage top of fish at 11,433-ft 4es rkb. Swallow Tbg Stub down to 11,438-ft. PU 45K over pull. Weight dropped back to normal. Re-tag. PU no over pull (?). Set back Kelly. 13:00-16:30 3.50 FISH N DPRB DECOMP POOH with 31/2" DP = 356 jts. 16:30 - 17:00 0.50 FISH N DPRB DECOMP BHA at floor. Did not recover PKR. Only recovered 7.92' of the 3 1/2" chemical cut Tbg stub. and the 3 1/2" x 4 1/2" NSCT XO. Pkr and Tailpipe still left in hole. 17:00 - 18:30 1.50 FISH N DPRB DECOMP Run the completion Pkr assembly out of derrick. Break down and send Pkr and tal pipe assy to Baker Machine Shop to prep Pkr for re-run and new tail pipe assy. Clear & clean rig floor. 18:30- 19:00 0.50 FISH N DPRB DECOMP Inspect derrick. Printed: 3/31/2003 11:00:53 AM BP EXPLORATION Page 8 of 8 Operations Summa Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 3/13/2003 End: 3/28/2003 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/28/2003 Rig Name: NABORS 4ES Rig Number: 4ES Date From -To Hours Task Code NPT Phase Description of Operations 3/26/2003 19:00 - 22:30 3.50 FISH N DECOMP M/U BHA # 14, Spear assy. RIH on 3 1/2" DP. 22:30 - 23:30 1.00 FISH N DPRB DECOMP P/U kelly. Pump 50 bbls of seawater & fill DP. Engauge fish @ 11443'. Pull 60K overpull & jar w/50K. Fish came free. Blow down lines. Set back kelly. 23:30 - 00:00 0.50 FISH N DPRB DECOMP POOH w/fish. Have drag up to 60K overpull. 3/27/2003 00:00 - 03:30 3.50 FISH N DPRB DECOMP POOH w/spear assy. Had 60K drag for first 3 stands off bottom. 03:30 - 04:00 0.50 FISH N DPRB DECOMP Break out fish. Recovered entire tail pipe assy (including Jet Pump) & packer. LID BHA # 14. 04:00 - 06:00 2.00 CLEAN N DPRB DECOMP Clear & clean floor. M/U BHA # 15.6 1/8" Bit & scraper, bumper sub, jars & 6 4 3/4" DCs. RIH. Crew change. 06:00- 06:30 0.50 CLEAN N DPRB DECOMP PJSM. Lub Rig. 06:30-08:30 2.00 CLEAN N DPRB DECOMP Continue RIH with BHA #15 and 31/2" = 359 jt. Lightly tag top of 4 1/2" Tbg Stub at 11,485.5-ft 4es RKB. 08:30 - 09:00 0.50 CLEAN N DPRB DECOMP Attemped to fill and establish circulations. 150 bls pumped. No returns. Well drinking fluid. 09:00 - 15:00 6.00 CLEAN N DPRB DECOMP POOH with 3 1/2" DP = 359 jts. LD singles in pipeshed. 15:00 - 15:30 0.50 CLEAN N DPRB DECOMP LD DC = 9 jts. and remaining BHA #15. 15:30 - 16:00 0.50 CLEAN N DPRB DECOMP Pull Wear Bushing. 16:00 - 18:30 2.50 RUNCO~rP COMP C & C floor. Finish loading pipe shed with remaining 3 1/2" 9.2# 13CR 80 Vam Ace Tbg. Rig up special handling equipment. Measure and inspect Tail Pipe Assy, Pkr Assy, and Sliding Sleeve Assy. 18:30 - 00:00 5.50 RUNCOr P COMP Hold PJSM prior to begin running completion. M/U tail pipe assy, packer assy & baker lock same. M/U & run sliding sleeve assy. P/U & run 3 1/2" tubing. Ran 105 jts. 3/28/2003 00:00 - 06:00 6.00 RUNCOr F' COMP Con't to run 3 1/2" completion. Ran 250 of 365 jts. 06:00 - 11:30 5.50 RUNCO~ P COMP Finish running 3 1/2" completion Tbg. Tag tbg stub at 11,486-ft = 366 jr. 11:30 - 12:00 0.50 RUNCOI~ P COMP M/U landing jt. PU 3-ft off of 4 1/2" Tbg Stub. Mark and LD Tag Jt plus one more. P/U 95K, S/O 70K. 12:00 - 13:00 1.00 RUNCOItP COMP RD casing tools. Clear & clean floor. 13:00 - 13:30 0.50 'RUNCOItP COMP !Set & test TWC to 3500 Psi. 13:30- 15:00 1.50 RUNCOItP COMP !Nipple down BOPE. 15:00 - 17:00 2.00 RUNCOItlP COMP , Nipple up adapter & X-mas tree. Test void & tree to 5,000 Psi, .OK. 17:00 - 18:00 1.00 RUNCOItP COMP ~P/U lubricator & pull TWC. LID lubricator. 18:00 - 18:30 0.50 RUNCOItF' COMP M/U steel lines to tree. Pressure test lines to 3500 Psi, OK. 18:30-19:30 1.00 RUNCOI~P COMP ! Pump down tubing @ 3 BPM, 100 Psi. Filltbg &annulusw/ 200 Bbls. 19:30 - 20:30 1.00 RUNCO~P COMP !Drop rod/ball & pressure up tbg to 2500 Psi & set packer. : Con't to pressure up to 3000 Psi & test tbg for 30 min. Tested :good. Charted same. 20:30 - 21:30 1.00 RUNCOItP COMP Bleed off tbg to 1500 Psi. Pressure up annulus to 3000 Psi & :tst annulus for 30 min. Tested good. Charted same. Bleed off tbg to 0 & shear RP valve. 21:30 - 22:00 0.50 RUNCOItP COMP Blow lines clean & RID lines. R/U HB&R. 22:00 - 23:00 1.00 RUNCOI~P COMP Test lines & Freeze protect well. Pumped 3 BPM @ 2500 Psi. Pumped 90 Bbls diesel. Set BPV. 23:00 - 00:00 1.00 RUNCO~F' COMP Clean pits & secure well .... RELEASE RIG @ 2400 HRS, 3/28/2003 Printed: 3/31/2003 11:00:53 AM To: WEI,L LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 74 Avenue, Suite 100 Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPF-33A, AK-MW-10100 February 19, 2002 MPF-33A: Digital Log Images: 50-029-22689-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND iRETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LET.TER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~/, 00o~'k~ I, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging I~ Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 40.54' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 1905' NSL, 2660' WEL, SEC. 06, T13N, R10E, UM MPF-33A At top of productive interval 19. Permit Number / Approval No. RECEIV B', 201-062 3002' NSL, 2329' WEL, SEC. 31, T14N, R10E, UM 10. APl Number At effective depth 50- 029-22689-01 99' ESL, 3026' WEE, SEC. 30, m14N, R10E, UM ~ 0 ~"~.'.i~ ~i}ii~ 11. Field and Pool At total depth Milne Point Unit / Sag River 99' NSL, 3026' WEL, SEC. 30, T14N, R10E, UM Alaska0ii&GasC0ns. O0mmissi0r~ 12. Present well condition summary Anchorage Total depth: measured 14453 feet Plugs (measured) true vertical 8839 feet Effective depth: measured 14453 feet Junk (measured) true vertical 8839 feet Casing Length Size Cemented MD TYD Structural Conductor 110' 20" 260 sx Arcticset I (Approx.) 110' 110' Surface 4703' 9-5/8" 1250 sx PF 'E'. 250 sx 'G'. 150 sx PF 'E' 4734' 4419' Intermediate Production 12334' 7" 600 sx Class 'G' 11729' 8733' Liner 1988' 2-7/8" Uncemented Slotted Liner 11537' - 13525' 8594' - 8822' Perforation depth: measured Slotted Liner: 11730'- 13437' 3-3/4" Open Hole: 13525' - 14453' .... true vertical Slotted Liner: 8734' - 8819' 3-3/4" Open Hole: 8822' - 8839' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 tubing to 11484' and 4-1/2", 12.6#, Cr13 tubing from 11486' - 11600'. Packers and SSSV (type and measured depth) 7" x 3-1/2" Baker S-3 packer at 11444' and a 7" x 4-1/2" Baker S-3 packer at 11487'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure i4'i .......... Representative Daily Average Production or Injection 'Data .... OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: ~ Copies of Logs and Surveys run [] Oil ~ Gas [] Suspended Service [] Daily Report of Well Operations , 17. I hereby certify that the fo?,,going is true and correct to the best of my knowledge Signed Sondra ~te~m~~~~ Title Technical Assistant Date (_~ ~'~" 4-~ ~ - O ~ ~."r Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate BP EXPLORATION Page 1 of 4 Operations Summa Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 2/15/2002 End: 2/24/2002 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/15/2002 12:00 - 15:00 3.00 MOB P DECOMP RESUME OPERATIONS. START ALL COLD START GENERATORS. MAKE RIG READY TO MOVE. 15:00 - 16:00 1.00 MOB P DECOMP LOWER DERRICK. 16:00 - 18:00 2.00 MOB P DECOMP MOVE RIG FROM WARM STACK ON F PAD TO MPF-33 WELL. CREW CHANGE. 18:00-21:00 3.00 RIGU P DECOMP CONTINUE TO MIRU. SPOTSUB, PIPESHED, AND PITS. 21:00 - 22:00 1.00 RIGU P DECOMP RAISE AND SCOPE DERRICK. ACCEPT RIG AT 22:00 HRS. 22:00 - 00:00 2.00 RIGU P DECOMP PRE-JOB AND SAFETY MEETING. RIG UP LINES TO TREE. TAKE ON SEA WATER IN PITS. 2/16/2002 00:00 - 04:30 4.50 RIGU . P DECOMP FINISH HOOK UP LINES. TEST. FINISH FILL PITS WITH SEA WATER. 04:30 - 06:00 1.50 KILL P DECOMP START TO KILL WELL WITH SEA WATER. CREW CHANGE. 06:00 - 07:00 1.00 KILL P DECOMP FINISH WELL KILL. MONITOR. 07:00 - 07:30 0.50 WHSUR P DECOMP SET AND TEST TVVCV. 07:30 - 08:30 1.00 WHSUR P DECOMP NIPPLE DOWN TREE. 08:30 - 11:00 2.50 BOPSUF P DECOMP NIPPLE UP BOPE. 11:00 - 14:30 3.50 BOPSUF P DECOMP PERORM BOPE TEST PER BP AND AOGCC REQUIREMENTS. TEST WITNESSED BY J. CRISP. 14:30 - 15:00 0.50 BOPSUF P DECOMP RD TEST EQUIP. DRAIN STACK. 15:00- 16:30 1.50 WHSUR P DECOMP PICK-UP LUBRICATOR. PULLTWC. LAY DOWN LUBRICATOR. 16:30 - 18:00 1.50 PULL P DECOMP MAKE UP LANDING JT. BOLDS. PULL HANGER TO FLOOR...90K. CREW CHANGE. 18:00 - 00:00 6.00 PULL P DECOMP START POOH WITH 4 1/2" TBG. LD. 2/17/2002 00:00 - 01:30 1.50 PULL P DECOMP FINISH POOH WITH 4 1/2" TBG TO CHEM CUT AT 8,004-FT. 01:30 - 03:30 2.00 PULL P DECOMP CLEAR FLOOR. MAKE UP EQUIPMENT TO HANDLE 3 1/2" DP. 03:30 - 06:00 2.50 PULL P DECOMP MAKE UP BHA #1. START RIH WITH 3 1/2" DP. CREW CHANGE. 06:00 - 13:00 7.00 PULL P DECOMP CONTINUE RIH WITH BHA #1 AND 3 1/2" DP. 13:00 - 14:00 1.00 PULL P DECOMP PU KELLY. TAG TOF AT 7,999-FT (DRILLER'S DEPTH). WORK TOOLS. PULL 44K OVER STRING WT. ROTATE 5 TURNS. LOST OVERPULL. 14:00 - 17:30 3.50 PULL P DECOMP POOH WITH DRILL PIPE AND BHA #1. FISH DRAGGING. 17:30 - 19:Q0 1.50 PULL P DECOMP LD DOWN BHA. CREW CHANGE. LD REMAINDER OF JOINT #191 ...BOTTOM 19-FT COLLASPED FLAT. 19:00 - 20:00 1.00 PULL P DECOMP CLEAR FLOOR. 20:00 - 21:00 1.00 PULL P DECOMP WO S-LINE UNIT TO ARRIVE FROM AN OTHER JOB. 21:00 - 00:00 3.00 PULL P DECOMP RU S-LINE UNIT AND RIH WITH A 3.806" TAPPERED SWEDGE TO TOP OF JET PUMP AT 11,463-FT. 2/18/2002 00:00 - 01:30 1.50 PULL P DECOMP S-LINE POOH WITH TAPPERED SWEDGE. 01:30 - 05:30 4.00 PULL P DECOMP RIH WITH GS TOOL. LATCH AND PULL JET PUMP. 05:30- 06:00 0.50 PULL P DECOMP RIG DOWN S-LINE CREW CHANGE. 06:00 - 09:30 3.50 PULL P DECOMP WO SWS TO ARRIVE ON LOCATION. 09:30- 12:00 2.50 PULL P DECOMP SWS ARRIVE ON LOCATION. PJSM. RIG UP. 12:00- 13:00 1.00 PULL P DECOMP PJSM. CLEAR FLOOR. SWS MAKE UP CHEMICAL CUTTER. 13:00 - 14:30 1.50 PULL P DECOMP RIH WITH CCL/CHEM CUTTER. LOG TIE-IN PASS. LOG CHEM CUTTER INTO PACE AT 11,481-FT. FIRE. NO INDICATION THAT CUTTER FIRED. 14:30-17:30 3.00 PULL P DECOMP POOH. STOP AT200-FT. PJSM. CLEAR FLOOR. CONTINUE TO SURFACE. SWS LD TOOL AND LET Printed: 2/25/2002 2:31:11 PM BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 2/15/2002 End: 2/24/2002 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/18/2002 14:30- 17:30 3.00 PULL P DECOMP FREEZE. 17:30 - 18:00 0.50 PULL P DECOMP BREAK DOWN TOOL. TOOL FAILED. CREW CHANGE. 18:00 - 23:30 5.50 PULL N DFAL DECOMP WO SWS TROUBLE SHOOT TOOLS. ORDER OUT NEW SAFE ADAPTOR SUB FROM DEADHORSE. 23:30 - 00:00 0 50 PULL N DFAL DECOMP PJSM. PREPARE TO PICK-UP CHEMICAL CUTTER #2. 2/19/2002 00:00 - 02:00 2.00! PULL ,N DFAL DECOMP RIH WITH CHEM CUTTER #2. LOG TIE-IN PASS. LOG CU'I-rER INTO PLACE AT 11,481-FT. FIRE. HAD INDICATIONS THAT CUTTER FIRED. 02:00- 05:30 3.50 PULL 'N DFAL DECOMP POOH. STOP AT 200-FT. PJSM. CLEAR FLOOR. CONTINUE TO SURFACE. SWS LD TOOL AND LET FREEZE. 05:30- 06:00 0.50 PULL N DFAL DECOMP BREAK DOWN TOOL. CHEM CUTTER #2 HAS ALSO FAILED. CREW CHANGE. 06:00 - 09:30 3.50 PULL N DFAL DECOMP WO SWS TO BRING NEW TOOL STRING FROM DEADHORSE. 09:30 - 10:30 1.00 PULL N DFAL DECOMP MAKE UP NEW TOOL STRING. 10:30 - 11:30 1.00 PULL N DFAL DECOMP PJSM. CLEAR FLOOR. SWS MU CHEMICAL CUTTER #3. 11:30-14:00 2.50 PULL N DFAL DECOMP RIHWlTHCHEMCUTTER#. LOG TIE-IN PASS. LOG CUTTER INTO PLACE AT 11,481-FT. FIRE. 14:00-15:30 1.50 PULL N DFAL DECOMP POOH. STOP AT200-FT. PJSM. CLEAR FLOOR. SWS LD TOOL AND LET FREEZE. 15:30 - 16:00 0.50 PULL N DFAL DECOMP BREAK DOWN TOOL. CHEM CUTTER #3 APPEARS TO HAVE DETINATED PROPERLY. RD SWS. 16:00 - 17:00 1.00 PULL P DECOMP MAKE UP BHA #2 (CENTER SPEAR). 17:00 - 18:00 1.00 PULL P DECOMP START RIN WITH BHA #2 AND 3 1/2" DP. CREW CHANGE. 18:00 - 20:00 2.00 PULL P DECOMP CONTINUE RIH WITH BHA #2 AND 3 1/2" DP. 20:00 - 22:00 2.00 PULL P DECOMP LATCH 4 1/2" TBG WITH SPEAR. WORK PIPE. UNABLE TO PULL FREE. RELEASE SPEAR. CALL OUT SWS. 22:00 - 00:00 2.00 PULL P DECOMP START POOH WITH 3 1/2" DP AND BHA #2. 2/20/2002 00:00 - 03:00 3.00 PULL N DPRB DECOMP POOH W/BHA # 2 CENTER SPEAR & LAY DN SAME. 03:00 - 07:00 4.00 PULL N DPRB DECOMP RIG SWS & RIH WITH JET CUTTER TO 8004' TOP OF TBG. CUT & ATTEMPT TO ENTER NO SUCCESSFUL. 07:00 - 08:00 1.00 PULL N DPRB DECOMP POOH & REMOVE SPRINGS FROM CUTTER & LOWER CENTRALIZER TO NEAR CUTTER. 08:00 - 11:30 3.50 PULL N DPRB DECOMP RIH & LOG CUTTER INTO POSITION AND CUT TBG. @ 11484.5' & POOH & LAY DN CUTTER & RIG DOWN SWS. 11:30-16:00 4.50 PULL N DFAL DECOMP MUFTA#2CENTERSPEARW/3.97"GRAPPLE&RIH& ENGAGE IN 4.5" TBG/@ 8031' & WORK JET CUT INTO AFTER CONSIDERABLE WORKING. 16:00 - 00:00 8.00 PULL N DECOMP POOH STANDING DP IN DERRICK TO 4.5" TBG. & BEGIN LAYING DN TBG. 2/21/2002 00:00 - 01:30 1.50 PULL DECOMP CONTINUE POOH WITH 4 1/2" TBG. LAY DOWN. INSPECT ' JET CUT...OK. NO SIGN IN CUT OFF STUB THAT ANY OF THE 3 CHEMICIAL CUTS DID ANYTHING. 01:30 - 02:00 0.50 PULL DECOMP CLEAR AND CLEAN FLOOR...S-LINE UNIT ARRIVES ON LOCATION. 02:00 - 03:00 1.00 PULL DECOMP PJSM. RIG UP S-LINE UNIT. 03:00 - 03:30 0.50 PULL DECOMP MAKE UP 6" GR/JB. ;03:30 - 05:00 1.50 PULL DECOMP RUN 6" GR/JB DOWN TO 11,486-FT (CORRECTED TO ELMD). TOP OF STUB ABOVE PKR. :05:00- 06:00 1.00 PULL DECOMP POOH. 06:00- 06:30 0.50 PULL DECOMP RIG DOWN S-LINE. 06:30 - 08:00 1.50 PULL N DPRB DECOMP MONITOR WELL. OBSERVED THAT HOLE WAS ALMOST Printed: 2/25/2002 2:31:11 PM BP EXPLORATION Page 3 of 4 Operations Summa Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 2/15/2002 End: 2/24/2002 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 2/21/2002 06:30- 08:00 1.50' PULL N DPRB DECOMP FULL...(WELL HAD BEEN DRINKING FLUID UNTIL NOW). PRESSURE WELL BORE TO 2,000 PSI. UNABLE TO PUMP INTO FORMATION. MONITOR. NO PRESS LOSS .... TAILPIPE AND/OR 2 7/8" LINER APPEARS PLUGGED. 08:00 - 09:00 1.00: PULL N DPRB DECOMP PJSM. RIG S-LINE BACK UP. 09:00 - 09:30 0.50' PULL N DPRB DECOMP MAKE UP 1 3~4" BAILER. 09:30 - 10:30 1.00 PULL N DPRB DECOMP RUN IN HOLE WITH BAILER. TAG AT 11,469-FT SLMD. WORK DOWN TO 11,472-FT SLMD. 10:30 - 11:30 1.00 PULL N DPRB DECOMP POOH WITH BAILER. RECOVERED SAMPLE OF SHMOO AND MUNG. RD. 11:30-14:00 2.50 PULL N DPRB DECOMP STARTRUHWlTHCLEAN-OUTSTRING...313/16"MILL, 2 JT 2 718" PAC TBG. 3 1/2" DRILL PIPE. 14:00 - 15:00 1.00 PULL N DPRB DECOMP STOP AT 1,800-FT TO CIRCULATE OIL FROM WELL BORE. 15:00 - 17:00 2.00 PULL N DPRB DECOMP CONTINUE RIH WITH REMAINDER OF DRILL PIPE FROM DERRICK. 17:00 - 18:00 1.00 PULL N DPRB DECOMP CONTINUE RIH WITH DRILL PIPE FROM PIPE SHED. CREW CHANGE 18:00 - 00:00 6.00 PULL N DPRB DECOMP LOAD AND TALLY MORE DP IN SHED. CONTINUE RIH WITH DP FROM PIPE SHED. TAG BRIDGE AT 11,456-FT. WASH THRU. CONTINUE TO TOP OF PKR STUB AT 11,486-FT(ELMD). 2/22/2002 00:00 - 01:30 1.50 PULL N DPRB DECOMP CONTINUE TO WASH AND ROTATE DOWN TO TOP OF 2 7~8" LINER AT 11,512-FT. 01:30 - 02:30 1.00 PULL N DPRB DECOMP PULL ABOVE PKR STUB. REVERSE HOLE CLEAN. RECOVERED SAND/SCALE...SCHMOO/MUNG. 02:30 - 06:00 3.50 PULL N DPRB DECOMP START POOH WITH 3 1/2"DRILL PIPE AND CLEAN-OUT STRING. CREW CHANGE. 06:00 - 08:30 2.50 PULL N DPRB DECOMP FINISH POOH WITH CLEAN-OUT STRING. 08:30 - 10:00 1.50 PULL N DPRB DECOMP RIG UP FLOOR. PU 1 1/4" MULE SHOOE AND 10 JT 1 1/4" CSH. TBG. 10:00 - 13:30 3.50 PULL ;N DPRB DECOMP TIH W 1 1/4" CLEAN-OUT STRING AND 3 1/2" DRILL PIPE TO TOP OF PKR STUB. 13:30 - 14:30 1.00 PULL N DPRB DECOMP WORK THRU STUB AND CONTINUE DOWN TO TOP OF 2 7/8" LINER AT 11,512-FT. UNABLE TO WASH INSIDE LINER TOP...HARD. 14:30-18:00 3.50 PULL N DPRB DECOMP START TOOH WlTH 31/2" DRILL PIPE AND1 1/4" CLEAN-OUT STRING. CREW CHANGE. 18:00 - 20:00 2.00 PULL N DPRB DECOMP FINISH TOOH. 20:00 - 21:00 1.00 PULL N DPRB DECOMP CLEAR AND CLEAN FLOOR. 21:00-21:30 0.50 PULL N DPRB DECOMP PU 2.250" FLAT BTM MILL, 1 11/16" BAKER MUD MOTOR, CIRS SUB (1/2" BALL), BALL DROP DISCONNECT (5/8" BALL), AND DCVs. 21:30-00:00 2.50 PULL N DPRB DECOMP START TIH WITH MILL AND MOTOR, 1 I/4"TBGAND3 1/2"DRILL PIPE (STOP TO FILL TBG EVERY 10 STDS). 2/23/2002 00:00 - 05:00 5.00 PULL N DPRB DECOMP FINISH TIH WITH MILL, MOTOR, AND DRILL PIPE. 05:00 - 06:00 1.00 PULL N DPRB DECOMP WORK TO GET INSIDE PKR STUB. 06:00 - 06:30 0.50 PULL N DPRB DECOMP GOT INSIDE PKR STUB. TAG TOP OF 2 7/8" LINER AT 11,513-FT (DRILLERS DEPTH). 06:30-07:30 1.00 PULL N DPRB DECOMP MILL TRASH AND FILL DOWN TO15,520-FT. SAWPUMP PRESS DROP. 07:30 - 08:30 1.00 PULL N DPRB DECOMP POH ABOVE PKR STUB. MONITOR WELL. WELL TAKING FLUID. COMUNICATION ESTABLISHED WITH FORMATION Printed: 2/25/2002 2:31:11 PM BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: WORKOVER Start: 2/15/2002 End: 2/24/2002 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations ;2~23/2002 07:30- 08:30 1.00 PULL N DPRB DECOMP AGAIN. PUMP 40 BBLS INTO FORMATION TO CLEAR LINER (X3). 08:30 - 15:30 7.00 PULL N DPRB DECOMP POOH AND LD 3 1/2" DRILL PIPE. 15:30- 16:30 1.00 PULL N DPRB DECOMP CONTINUE POOH. LD BHA. 16:30 - 17:30 1.00 PULL N DPRB DECOMP CLEAR AND CLEAN RIG FLOOR. 17:30 - 18:00 0.50 RUNCOI~ COMP RIG UP TO RUN 3 1/2" COMPLETION. 18:00 - 19:00 1.00 RUNCOI~ COMP PU PKR AND TAILPIPE ASSY. PU SLIDING SLEEVE ASSY. 19:00 - 00:00 5.00 RUNCOI~ COMP BEGIN RUNNING 3 1/2" 1-80 8RD EUE COMPLETION TUBING. !2/24/2002 00:00 - 07:30 7.50 RUNCO~' COMP SPACE OUT TBG. & MU HANGER & LAND AND RILDS & SET TWC. 07:30 - 09:30 2.00 BOPSUF,P COMP NIPPLE DOWN BOP 09:30 - 12:00 2.50 WHSUR P COMP NIPPLE UP TREE & TEST TO 5000 PSI. & PULL TWC. 12:00 - 14:00 2.00 RUNCOI~ COMP DROP BALL & SET PKR. TO 3500 PSI FOR 30 MIN. OK. & BLEED TBG. TO 1500 & PSI. ANNULUS TO 3000 PSI. FOR 30 MIN OK & BLEED TBG. TO SHEAR RP VALVE. ALL OK. 14:00 - 17:00 3.00 RUNCOI~ COMP FREEZE PROTECT ANNULUS & TBG. WITH DIESL (HB&R PUMPED & PROVIDED DIESEL) 80-BBL. TOTAL. 17:00 - 18:00 1.00 WHSUR P COMP SET BPV & NIPPLE DN LINES & SECURE TREE & CELLAR AREA. RIG RELEASED @ 1800 HRS. 02/24/2002 Printed: 2~25~2002 2:31:11 PM Schlmberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1836 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 02/21/02 r. Color Well Job # Log Description Date Blueline Sepia Prints CD B-07 / '-') ~- OOc~ PRODUCTION PROFILE 02/09/02 1 1 MPF-33A ...~)1-0 I.~o~ STATIC PRESSURE SURVEY 02/14/02 I 1 NK-19A ~-~/-O-7'D STATIC PRESSURE SURVEY 02/10/02 I 1 K-02C <:~OI--c~ I [fp 22064 MCNL (PDC) 01/21/02 1 I 1 D.S. 5-26A ~-/~)-~t 22048 MCNL(PDC) 01/14/02 1 1 1 NK-22A ~O/-c~o~' 22060 SCMT(PDC) 01108/02 2 I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Bivd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic BIvd, Suite 300 Anchorage, AK 99503-5711 ATrN: Sherrie WEI,L LOG TRANSMITr~ To: State of Alaska January 09, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs MPF-33A, AK-MW- 10100 1 LIS formatted Disc with verification listing. API#: 50-029-22689-01 PLEASE AcKNowLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date: RECEIVED JAN 1 1 20O2 ( ^ SKA( ALASKA (alL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator~,,,,,_~ 7. Permit Number BP Exploration (Alaska)Inc. ii~~ ,' ,Lag4-e~7.- 201-062 '' ! l~. ' ~ ..... ~. 8. APl Number 196612, Anchorage, 99519-6612 i ~_..?~ 50- 029-22689-01 4. Location of well at surface ' ' ~~ !' ..;... 9. Unit or Lease Name 1905' NSL, 2660' WEL, SEC. 06, T13N, R10E, UM - '"'~'"~'~"~'~-----'"~- Milne Point Unit At top of productive interval . ....,..~,~.. ~".~.~/.. 3002' NSL, 2329' WEL, SEC. 31, T14N, R10E, UM.,2J'..O'~'-"-:.' At total depth ... :: 10. Well Number 99' NSL, 3026' WEL, SEC. 30, T14N, R10E, UM ', ....... · .... ' MPF-33A 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit/Sag River KBE - 40.54' ADL 355017 12. Date Spudded3/29,2001 113' Date T'D' Reached 114' Date C°mp'' Susp'' °r Aband'4,3,2001 4,5,2001 115' water depth' if °ffsh°reN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set121. Thickness of Permafrost 14453 8838 FTI 14453 8838 FTI [] Yes [] NoI N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER ET. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 110' 24" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 31' 4734' 12-1/4" 1250 sx PF 'E', 250 sx 'G', 150 sx PF 'E 7" 26# L-80 29' 11729' 8-1/2" 600 sx Class 'G' 2-7/8" 6.16# L-80 11537' 13525' 3-3/4" Uncemented Slotted Liner , , , 24. Perforations op. en to, Production (MD+TVD of Top and 25. "' TUBING RECORD Bottom and imerva~, size and number) ' sIZ'E DEPTH SET (MD)' PACKER' SET (MD) Slotted Liner 3-3/4" Open Hole " 4-1/2", 12.6#, Cr13 11601' 11487' MD TVD MD TVD 11730' - 13437' 8732' - 8817' 13525' - 14453' 8821' - 8838' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with 60/40 MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) April 19, 2001 Gas Lift Date of Test Hours Tested PRODUCTION FOR iOIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 4/27/2001 6 TEST PERIOD 966 490 0I 507 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE ,, 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. -- ~1 Il ifil Illl I,1,1"1 Itl Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered Depth Depth and gravity, GOR, and time of each phase. Sag River 11695' 8707' Sag River 'C' 11730' 8732' Sag River 'B' 11745' 8743' Sag River 'A' 11810' 8779' 31. List of Attacl3mentsl "Su'rnmary of"Daily 'Drilling Repo'rts, Survey's .................................... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~,~~ ~ Title Technical Assistant Date (~'~'.(~*0/ MPF-33A 201-057 201-062 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: IndiCate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28.' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ., · BP EXPLORATION Page1 of 7 ,, Operations Summary Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spu'd~lD~'t~: ~;~2~)1996 Event Name: REENTER+COMPLETE Start: 3/24/200.,1, End: Contractor Name: DOWELL SCHLUMBERGER Rig Release: '~:'~-'":;~ Rig Name: NORDIC I Rig Number: 'Date= From - To HOUrs Activity Code NPT Phase Description of Operations 3/24/2001 00:00 - 09:00 9.00 MOB P PRE Standby for prep work on MPF-33 09:00 - 12:00 3.00 RIGU P PRE Spot rig over well. Spot other equipment. 12:00 - 19:00 7.00 BOPSUF P DECOMP NU BOPS. Berm and spot returns tank. Take on 1% KCL. Accept rig at 1200 on 3/24/01 19:00 - 00:00 5.00 BOPSUF P DECOMP Test BOPE. Witnessed by J. Jones w/AOGCC 3/25/2001 00:00 - 03:00 3.00 BOPSUF P DECOMP Continue BOPE test 03:00 - 05:00 2.00 BOPSUFIP DECOMP RU and pull TWC (difficult to latch) 05:00 - 06:30 1.50 STWHIP P WEXlT MU RU SWS E-line. Check well for press-none. Fill hole with 25 bbls 1% KCl water 06:30 - 07:00 0.50 STVVHIP P WEXlT Hold PJSM regarding e-line running procedures. Designate safe areas. 07:00 - 08:00 1.00 STWHIP P WEXlT PU drift & CCL e-line tools. 08:00 - 10:30 2.50 STWHIP!P WEXlT RIH to 11870' ELM. POOH with drift. Hole smooth. 10:30 - 11:30 1.00 STWHIP P WEXlT Re-head SWS e-line for whipstock setting tool. 11:30 - 14:30 3.00 STWHIP!N SFAL WEXIT Trouble shoot & calibrate SWS directional tool. 14:30 - 15:30 1.00 STWHIP! P WEXIT MU whipstock on setting tool with gr/ccl. 15:30 - 18:00 2.50 STWHIP! P WEXIT RIH w/Baker 4-1/2" x 7" whipstock assy on e-line to 11870'. Hold EMS & ISO 14001 training session on rig w/J. Arin. 18:00 - 22:00 4.00 STWHIPiN DPRB WEXIT Attempt to PUH and log up to set depth and whipstock was stuck. Work line (0.39" multiconductor) to 75% of weak point. Cuss and discuss. Attempt to set WS w/Baker slow burn charge several times w/o indication of firing. Work line until tools released at weak point. POOH w/cable head (clean). Left GR/CCL/setting tool/WS fish with top at 11834' (41.4, OA) ELMD 22:00 - 00:00 2.00 STWHIP N DPRB WEXIT Fill hole w/21 bbls 1% KCl water. SI swab. we SWS crew rest and replacement tools to arrive 3/26/2001 00:00 - 03:00 3.00 STWHIP N DPRB WEXIT Continue to wait on SWS crew rest and replacement tools to arrive 03:00- 07:00 4.00 STWHIP N DPRB WEXIT Calibrate tools and RU 07:00 - 07:30 0.50 STWHIP N DPRB WEXIT Safety mtg regarding e-line procedures. 07:30 - 08:15 0.75 STWHIP N DPRB WEXIT MU Baker whipstock (7" x 4-1/2") on SWS gr/ccl tool. 08:15 - 11:00 2.75 STWHIP N DPRB WEXIT RIH with e-line. 11:00 - 12:00 1.00 STWHIP P WEXIT Tie into ccl/gr log from 8/8/96. Use RA tag & collars. Add 14' correction. Activate setting tool. Set dn weight to verify whipstock in place. OK. 12:00 - 13:00 1.00 STWHIP P WEXIT Run correlation log through new completion. 13:00- 14:00 1.00 STWHIP P WEXIT 'RD E-line. 14:00 - 16:30 2.50 STWHIP P WEXIT MU coil connector. Pump dart through coil. Volume with dart: 59.6 bbl. Calculated is 60.8 bbls. MU cementing BHA: cc, nrj,xo,hyd dis, cc,xo,pup, 3" nozzle · oa1-13.18' 16:30 - 17:15 0.75 STWHIP 3 WEXIT RIH to 200'. POOH to check gripper blocks. Adjust horses head. 17:15 - 19:00 1.75 STWHIP ~ WEXIT Continue RIH, circ out diesel w/KCI water. Losing 10 bph at rain rate 19:00 - 19:30 0.50 STWHIP 3 WEXIT 11700' 46.5k, 22k RIH and lost 3k wt at 11720'. Regained. RIH slow to set down at 11741'-overpull. Acts like WS moved downhole. Corr to ELMD would put top of WS at 11750' and btm at 11766'-in perfs, and too deep to use for job 119:30 - 22:00 2.50 STWHIP N DPRB WEXIT POOH to RU WL for depth confirmation. Flag at 10900' EOP 122:00 - 23:00 1.00 STVVHIP N DPRB WEXIT Fill hole. SI swab. Fill pits. we WL to finish a job 23:00- 00:00 1.00 STVVHIP N DPRB WEXIT PJSM. MIRU Halco WL 3/27/2001 00:00 - 00:20 0.33 STVVHIP N DPRB WEXIT Fin RU WL Printed: 61112001 2:32:20 PM BP EXPLORATION Page 2 of 7 Operations, Summary Report, Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: REENTER+COMPLETE Start: 3/24/2001 End: Contractor Name: DOVVELL SCHLUMBERGER Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - TO Hours Activity Code NPT 'PhaSe DeScription of Operations 3/27/2001 00:20 - 02:30 2.17 S'I'WHIP N DPRB WEXIT RIH w/3.625" TS and TEL. Verify WS still in place. POOH. Losing 23 bbls/hr static 02:30- 03:00 0.50 STWHIP N DPRB WEXlT RDMO WL 03:00 - 04:45 1.75 STWHIP N DPRB =WEXIT RIH w/cementing assy. Inj test @ 9000' 1.2 bpm @ 100 psi. RU DS cementers 04:45 - 05:00 0.25 STWHIP P WEXlT Safety mtg re: cmt plug 05:00 - 05:30 0.50 STWHIP P WEXlT Tag WS at 11741' CTD-overpull. Corr-12' to pinch point at 11729'. PUH 46k to 11700'. Circ 0.5/0.3 @ 120 psi 05:30 - 05:55 0.42 STWHIP 'P WEXlT PT DS @ 3500 psi. Mix on the fly 13.8 ppg bentonitic G cement. Load CT w/5 bbls neat, 17 bbls w/18#/bbl aggregate, 5 bbls neat 2.1/1.5 1400 psi 05:55 - 06:05 0.17 STWHIP = WEXlT Displace cmt w/KCI water 2.5/1.8 @ 650 06:05 - 06:30 0.42 STWHIP = WEXlT SI choke w/cmt @ noz, red rate to 1.5 bpm. PUH 2'/min 49K. Press incr slowly to 350 psi w/3 bbls agg at perfs. Red rate to 1.0 bpm at 1000 psi w/12 bbls left. Open choke w/5 bbls left and noz @ 11680' and PUH laying in rest of cmt. WCTOC @ 11500' 06:30 - 07:30 1.00 STWHIP P WEXIT PUH to safety @ 10500'. Park and WOC 1/1 07:30 - 08:15 0.75 STWHIP P WEXlT RIH. Wash cement to 11700'. Make 2 passes. 1:1 returns. 08:15- 10:30 2.25 STWHIP P WEXIT POOH. 10:30 - 12:00 1.50 S TWHIP. P WEXlT Wait on cement. Clean pits and prep to move off well. 12:00 - 13:00 1.00 STWHIP P VVEXlT 4ES rig move delayed due to trucking shortage. Install Baker connector. & MU one step milling BHA. Load pits with 1% KCL. Baker coil connector will not mu correctly. 13:00 - 14:30 1.50 STWHIP P WEXlT Wait on replacement coil connector from Baker. ~14:30 - 15:00 0.50 STWHIP P WEXlT MU & test coil connector. MU window milling BHA. 15:00 - 17:20 2.33 STWHIP P WEXlT RIH with BHA #1 to begin window milling. 17:20 - 17:55 0.58 STWHIP P WEXlT Tag up at 1~1736.5, PU, kick on pumps, retag at 11735.0'. Left cement top at 11700'. Make no correction to depth. Pickups at 46klbs. Free spin 2.5 bpm 1430 psi ctp. Milling cement at 35 fph. Hit pinch point on WS at 11739.8', make -10.~' correction. \ 17:55 - 00:00 6.08 STWHIP P WEXIT Begin window milling at pinch point, 11729' to 11733'. 3/28/2001 00:00 - 03:45 3.75 STWHIP P WEXlT Continue milling window 11732' to 11736'. 03:45 - 05:15 1.50 STWHIP P WEXIT Dress window and drill formation to 11746'. No mud losses to well bore. 05:15 - 07:00 1.75 STWHIP P WEXlT Pump Bio sweeps and dress window area. 07:00 - 08:45 1.75 STWHIP P WEXlT :POOH with BHA #1. 08:45 - 09:40 0.92 STWHIP P WEXIT :Tag up at surface, lay down BHA #1. 09:40 - 11:45 2.08 STWHIP P WEXIT Pump 5 bbls of methanol to top off/freeze protect well. Set BPV to isolate well for rig move. 11:45 - 12:45 1.00 STWHIP P WEXlT Nipple down BOP's 12:45 - 15:30 2.75 STWHIP P WEXlT Move rig off well, standby for rig Nabors 4ES to move past, move back on well. 15:30 - 18:30 3.00 STWHIP P WEXlT Nipple up BOP stack, PT stack (body test only) 250/3500 psi. State waved full BOP test, only required test of connection that was broken for move. 18:30 - 21:00 2.50 STWHIP P WEXlT Finish P,/U of TP camp and other aux. equipment. 21:00 - 21:30 0.50 STWHIP P WEXlT P/U BHA #2. (Decision was made to perform a complete BOP test rather than staying with the earlier 'full body/function' test.) L/D BHA. Printed: 611/2001 2:32:20 PM BP EXPLORATION Page 3 of 7 Operations Summa Report ,Legal Well Name: MPF-33 iCommon Well Name: MPF-33A Spud Date: 7/24/1996 :Event Name: REENTER+COMPLETE Start: 3/24/2001 End: Contractor Name: DOWELL SCHLUMBERGER Rig Release: Rig Name: NORDIC 1 Rig Number: I Date From - To Hours Activity Code NPT Phase Description of Operations 3/28/2001 21:30 - 00:00 2.50 STWHIP P WEXlT Test BOPE. (witnessing wavied by AOGCC Tom Maunder) ,3/29/2001 00:00 - 04:00 4.00 S'I'WHIP P WEXlT Finish BOP testing. 04:00 - 05:00 1.00 DRILL P PROD1 P/U BHA #2 (65.50'). Change out Baker CTC to Dowell CTC. 05:00 - 06:15 1.25 DRILL P PROD1 Change out Baker CTC for Dowell CTC. Pull test 30k and PT 3500 psi. (Take on FIo-Pro mud.)70 06:15-08:15 2.00 DRILL P PROD1 TIH w/BHA #2 08:15 - 08:55 0.67 DRILL P PROD1 Orient around to high side, log tie in pass up due to 2.8 deg motor and need to keep bit in 7" casing. Identify RA tag at 11582' (Should be 11584') Accounting for pipe stretch up of i about 4', make a -1.5' correction. RIH to begin drilling. 08:55 - 10:00 1.08 DRILL P PROD1 !RIH, through window clean. Tag up at 11753' (Should have 'been 11746'). Kick on pumps. Free spin 2.7 bpm 3100 psi. Displacing bio with mud. Getting 80 fpm at 22 L TF. Getting good reactive torque. 10:00 - 11:30 1.50 DRILL P PROD1 10:00 update. 2.5 bpm/3800 psi/5L TF, 11810', drilling at 57 fpm. INC=58 deg, Gamma character indicates we are on depth through whipstock. 11:30 - 13:30 2.00 DRILL P PROD1 Drill to 11880', landed well horizontally at 8750' TVD, 5' below 31an. POOH for lateral section BHA. 13:30 - 16:20 2.83 DRILL P PROD1 Lay down BHA #2, pick up BHA #3 for lateral section. 16:20 - 17:30 1.17 DRILL P PROD1 RIH with BHA, shallow hole test of MVVD. Unacceptably high pump pressures with resistivity sub in BHA. POH to change to larger port in equalizing sub. 17:30 - 19:35 2.08 DRILL P PROD1 RIH with BHA #3 again. Size 16 jet in equalizing sub instead of size 12. 19:35 - 20:15 0.67 DRILL P PROD1 Log tie-in -7' correction. 20:15 - 20:30 0.25 DRILL P PROD1 TIH to bottom 20:30 - 22:35 2.08 DRILL P PROD1 Survey on bottom. Log MAD pass to 11545'. 22:35 - 23:30 0.92 DRILL P PROD1 TIH. Orient TF 23:30 - 00:00 0.50 DRILL P PROD1 Directional drill f/11880' to 11898'. TF 79L 2.6 / 3400. 3/30/2001 00:00 - 06:30 6.50 DRILL P PROD1 Directionally drill lateral section f/11898' to 12156'. 06:30 - 07:10 0.67 DRILL P PROD1 06:30 update. Drill lateral section starting at 12156', 2.4 bpm/3600 psi/91L TF. 07:10 - 07:35 0.42 DRILL P PROD1 Wiper trip to shoe. Bleed off IA to 500 psi. Was up to 1000 3si. Bled off liquid. 07:35 - 09:10 1.58 DRILL P PROD1 07:35 Resume drilling at 12200', 3200 psi free spin, 2.5/3600/114L TF. Lost 1.5 bbls in last hr. 09:10 - 09:45 0.58 DRILL P PROD1 12350', short trip to window. Sticky pickup off bottom, pulling up at 37klbs. 09:45 - 12:00 2.25 DRILL P PROD1 Back on bottom, drilling at 110 fpm, 2.4/3800/103L TF 12:00 - 12:40 0.67 DRILL P PROD1 12471' Wiper trip. Clean pickup, 37klbs. 12:40 - 14:00 1.33 DRILL P PROD1 Back on bottom, hard drilling. 2.5/3800/45R TF, only getting about 30 fph. Clean pickups. Check mud. Drill solids up to 0.8%. Call for new mud. 14:00- 16:00 2.00 DRILL :N DFAL PROD1 12471', Can not make any progress. Hard bottom. Not getting good indication of stalls or motor work. While waiting for mud will POOH to examine BHA for washouts, and check bit. Slight overpull at 11925' on trip out. 16:00 - 18:00 2.00~ DRILL N DFAL PROD1 Tag up at surface, inspect BHA. Found washout in motor. Port used to inject stator in motor housing is plugged post manufacturing. One of these near the top of the motor washed out, and was bypassing the motor. Will swap out motors, and RIH. Printed: 6/112001 2:32:20PM BP EXPLORATION ' Page4 of 7 Operations Summar Report I Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: REENTER+COMPLETE Start: 3/24/2001 End: Contractor Name: DOWELL SCHLUMBERGER Rig Release: Rig Name: NORDIC 1 Rig Number: Date From, To Hours Activity Code NPT Phase Description of Operations 3/30/2001 18:00 - 19:30 1.50 DRILL N PROD1 RIH with BHA #4. Swap out to new FIo-Pro mud in progress. 19:30 - 20:30 1.00 DRILL N PROD1 Orient 20:30 - 20:40 0.17 DRILL N PROD1 Log tie-in -5' correction. 20:40 - 21:00 0.33 DRILL N PROD1 TIH 21:00 - 00:00 3.00 DRILL P PROD1 Directional drill f/12471'. Free spin 2.7 3230 psi TF 95-80R to 12600'. Hole starting to take mud at 12984' 2.4/2.1 3/31/2001 00:00 - 02:00 2.00 DRILL P ~ROD1 Directional drill f/12600' to 12679'. Mud losses to hole avg 25 bph 02:00 - 03:00 1.00 DRILL 'P PROD1 Short trip to 11750'. Clean pickup 36klbs. 03:00 - 03:30 0.50 DRILL 3 ~ROD1 Directional drill f/12679' to 12715'. Losses 20-25 bph. 03:30 - 03:45 0.25 DRILL P PROD1 Orienting 03:45 - 06:30 2.75 DRILL P ~ROD1 Directional drilling 12715' - losses slowed to 10-15 bph 06:30 - 06:45 0.25 DRILL P PROD1 12887', Drilling ahead, 2.4 bpm/3600 CTP/61L TF. 06:45 - 08:00 1.25 DRILL 3 PROD1 12900', Short trip to shoe. Clean pickup off bottom, pulling at 37klbs. Checked tie in, made a -9' correction. 08:00 - 08:40 0.67 DRILL ~ PROD1 12891', Free spin 2.5/3200, on bottom 2.5/3660/50L TF, Fluid losses have slowed somewhat. We lost 10 bbls on short trip. 08:40 - 09:10 0.50 DRILL 3 PROD1 12932', Orienting 09:10 - 09:30 0.33 DRILL 3 PROD1 Stuck at 12932'. Pulled max. Worked pipe. SI pumps and :waited for FIo Pro to do its thing. 15 minutes later, pulled free. 09:30 - 10:00 0.50 DRILL ~ PROD1 PUll free, orient before resuming drilling. 10:00 - 12:45 2.75 DRILL P PROD1 12932', Drilling again 2.5/3700 psi. 2.5 bpm in, 2.3 bpm out. Loosing fluid at a higher rate now. We may be at another fault. We are getting high losses, tool face jumping around, and differential sticking on every pickup. Last hour lost 25 bbls of mud. 12:45 - 13:45 1.00 DRILL P PROD1 13050', Wiper trip to shoe. 13:45- 14:00 0.25 DRILL Ip PROD1 Orienting 14:00- 16:30 2.50 DRILL P PROD1 13050', drilling. 16:30 - 17:10 0.67 DRILL P PROD1 13116' Hard drilling. Same symptoms as yesterday. Not getting any ROP, not able to stall motor. RIH and hit bottom at 70 fpm. Some motor work, about 600 psi, but no stalls. 17:10 - 19:30 2.33 DRILL N I DFAL PROD1 POOH to inspect BHA for problems. 19:30 - 21:45 2.25 DRILL N . DFAL PROD1 Inspect BHA no visable problems, bit in good shape. Change out motors. Pressure test BHA. Surface check MWD and download res tool (1.5 hrs). P/U new motor BHA #5 (91.45'). i21:45- 23:50 2.08 DRILL N DFAL PROD1 TIH 23:50- 00:00 0.17 DRILL N DFAL 3ROD1 Start log tie-in. 4/1/2001 00:00- 00:45 0.75 DRILL N DFAL 3ROD1 Finish log tie-in +5' correction. 00:45- 01:15 0.50 DRILL N DFAL ;'ROD1 TIH 01:15 - 01:35 0.33 DRILL N DFAL ~ROD1 Orient TF. 01:35 - 01:45 0.17 DRILL P F~ROD1 Directional drill 13121' - 13127' 70L TF, 2.4 / 3000 psi free spin, 3475 psi on bottom. 2.4 in 2.2 out 01:45 - 02:00 0.25 DRILL P PROD1 Orienting 02:00 - 03:00 1.00 DRILL P PROD1 Daylight Savings time change +1 hour. 03:00 - 05:15 2.25 DRILL P PROD1 Directional drill 13127' - 13245'. Stacking weight. Hole taking 20 bph. 05:15 - 07:15 2.00 DRILL P PROD1 Short trip to window. Clean pick up. 36klbs. 07:15 - 07:25 0.17 DRILL P PROD1 Orient to 150L. 07:25 - 09:50 2.42 DRILL P PROD1 13244', Resume drilling. 2.5 in/2.4 out 3200 psi free spin, 3650 psi drilling, tool face 176L. Making about 60 fph ROP. Still losing about 20 BPH. 09:50 - 11:15 1.42 DRILL P PROD1 13400', Wiper trip to casing shoe. New mud here. Still losing Printed: 6/1/2001 2:32:20 PM ' : BP EXPLORATION ·. Page'5 of 7 Operations Summary Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: REENTER+COMPLETE Start: 3/24/2001 End: Contractor Name: DOWELL SCHLUMBERGER Rig Release: Rig Name: NORDIC I Rig Number: , "Date From - To Hours Activity Code NPT Phase 'Description of Operations .4/1/2001 09:50 - 11'15 1.42 DRILL P PROD1 mud at about 18 bbl/hr. 11:15 - 13:40 2.42 DRILL P PROD1 13400', Resume drilling, 2.5 in/2.4 out, 3200 psi free spin, 3700 psi drilling, TF 70R, loosing fluid at 18 b/hr, making 80 fph ROP. 13:40 - 15:15 1.58 DRILL P PROD1 13550', Wiper trip to shoe. Clean pickup off bottom. Pulling at 37klbs. 15:15 - 18:20 3.08 DRILL P PROD1 13550', Resume drilling, 2.5/2.4, 3500 psi free spin, 3717 psi drilling, TF=102R. h 18:20 - 20:20 2.00 DRILL P PROD1 13651', hole getting stickly, and difficult to drill. Short trip to shoe to clean hole. 20:20 - 23:10 2.83 DRILL P PROD1 13651' resume drilling, 2.2/2.0, 3200 spi free spin, 3650 psi on bottom. Lost 47 bbls mud while drilling this section. 23:10 - 00:00 0.83 DRILL P PROD1 13800' wiper trip to window. 39klbs pull off bottom. 4/2/2001 00:00 - 01:35 1.58 DRILL P PROD1 Finish wiper trip to window. TIH 01:35 - 03:40 2.08 DRILL P PROD1 13800' resume drilling 2.3 / 2.1 3150 psi free-spin 3630 psi on bottom. 102R TF. Drilled to 13892'. Last 20' have good motor work but slow drilling off. Lost 40 bbl last 2 hrs. 03:40 - 04:00 0.33 DRILL P PROD1 Wiper trip 04:00 - 04:20 0.33 DRILL P PROD1 Orienting 38 R TF 04:20 - 06:00 1.67 DRILL P PROD1 13894' resume drilling 2.2 / 2.0+ 3550 psi on bottom. Drill to 13953'. Drilling very slowly. Good motor work indication (400psi) but not drillling off. Lost 35 bbls last 1.5 hrs. 06:00 - 08:15 2.25 DRILL P PROD1 TOH clean pickup 38klbs. 08:15 - 08:40 0.42 DRILL N SFAL PROD1 2500', Standby for injector repairs. 08:40 - 09:00 0.33 DRILL P PROD1 Continue out of hole. 09:00 - 11:45 2.75 DRILL P ~PROD1 Tag up at surface, Break out motor. Motor appears tight, and in good shape, will be sent back to BHI asap for inspection. Bit in perfect shape. Will re-run bit and swap out motor, read MWD tool. 11:45 - 14:00 2.25 DRILL P PROD1 RIH with BHA ~. Plan to RIH, perform mud swap to 100% new mud. 14:00 - 14:45 0.75 DRILL P PROD1 Log tie in at 11800'. Make a +23' correction based on GR spike at window. 14:45 - 15:30 0.75 DRILL P PROD1 RIH to resume drilling. Received call from BHI shop. Motor from BHA #5 was in good shape. No problems found. 15:30 - 15:45 0.25 DRILL P PROD1 Orienting. 15:45 - 16:50 1.08 DRILL P PROD1 New corrected tag at 13962', resume drilling 3400 psi free spin. 2.5 in, 2.4 out. Getting slow drilling with lots of weight. 6500 psi weight on bit, 50 fph. 16:50 - 17:00 0.17 DRILL P PROD1 14043'. Short wiper. Heavy pickup off bottom. 60klbs. 17:00 - 17:20 0.33 DRILL N STUC PROD1 14043', return to drilling. 2.4/2.3 Starting on new mud. (Doing mud swap) Trying to drill with -5005 lbs weight at surface. Drill to 14044', no success getting motor work, try pickup, get stuck, pull max. Pulling up hole slowly at 77 lbs. Pull to max. Hung up. In 1.7, out 1.7. Work pipe. Still can't get free. 17:20 - 17:35 0.25 DRILL N STUC PROD1 Stuck in hole. SI pumps. Attempt "relax" method to let flopro gell up in loss zone. Wait 15 minutes, pull 60k lbs. Pull free on pickup. 17:35 - 17:50 0.25 DRILL P PROD1 Pull up hole, circulate new mud to bit prior to resumeing drilling. 17:50 - 18:00 0.17 DRILL P PROD1 14043', Resume drilling, 2.4/2.2, 3600 psi CTP, very little differential on motor. 18:00 - 19:10 1.17 DRILL P PROD1 Drill f/14043' to 14114'. w/frequent pickups +40klbs. 19:10 - 21:45 2.58 DRILL P PROD1 Wiper trip to window. Printed: 611/2001 2:32:20 PM BP EXPLORATION I page 6 of 7 Operations Summa Report Legal Well Name: MPF-33 Common Well Name: MPF-33a Spud Date: 7/24/1996 Event Name: REENTER+COMPLETE Start: 3/24/2001 End: Contractor Name: DOVVELL SCHLUMBERGER Rig Release: Rig Name: NORDIC 1 Rig Number: Date From ' To Hours Activity Code NPT Phase Description of Operations ~4/2/2001 21:45 - 00:00 2.25 DRILL P PROD1 Resume drilling at 14114' 2.4 / 2.3 104R TF to 14240'. Avg mud losses were 15 bph. Drilling fair. Frequent pickups after poor weight transfer seemed to make large difference in continuing ROP at a decent rate. 4/3/2001 i00:00 - 02:20 2.33 DRILL P PROD1 14248'. Wiper trip to window. Previous drilling avg mud losses 15 bph. 102:20 - 05:00 2.67 DRILL P PROD1 Drilling 14248' 2.4 / 2.3 95R TF to 14422'. Mud losses 10-12 bph. 05:00- 05:30 0.50 DRILL 'P PROD1 Short 500' wiper trip. 05:30 - 06:05 0.58 DRILL P PROD1 Resume drilling 14422' to 14445'TD. Losses last hr 18 bbls. 06:05 - 07:45 1.67 DRILL P PROD1 Wiper trip to window. Clean pickup 40klbs. Clean all the way to the window. No overpulls or unusual drag. 07:45 - 08:15 0.50 DRILL P PROD1 Log Tie in pass. Corection +9.0'. 08:15 - 09:30 1.25 DRILL P PROD1 RIH to begin MAD logging pass. TD after tie in is 14453'. 09:30 - 12:30 3.00 DRILL P PROD1 Log MAD pass from TD-14453' to window. 12:30 - 13:00 0.50 DRILL P PROD1 RIH to lay in hi vis pill. No problems seen on run in. 13:00 - 13:40 0.67 DRILL P PROD1 Pull up from 13700', laying in 30 bbl hi vis pill accross upper section of open hole. 13:40- 15:15 1.58 DRILL P PROD1 POOH 15:15 - 15:45 0.50 DRILL P PROD1 Tag up at surface with BHA #6, SI pumps and charge pump. Stand by for 1/2 hour for no flow test to see if well is drinking fluid. After 1/2 hour took 0.3 bbls to fill hole. Well is taking fluid at a negligible rate. 15:45 - 16:45 1.00 DRILL P PROD1 Lay down BHA #6. 16:45 - 17:30 0.75 CASE P PROD1 RU floor to run 2-7/8" drilled liner. 17:30 - 18:00 0.50 CASE P PROD1 Hold pre job mtg prior to running liner. 18:00 - 20:30 2.50 CASE P PROD1 MU 2-7/8" drilled liner assy. 20:30 - 22:00 1.50 CASE P PROD1 Notified by town to set liner bottom at 13525 (+/- 25'). Order GS spear and tools needed from Baker shop 22:00 - 23:59 1.98 CASE P PROD1 Continue to PU liner & wash pipe assy. 4/4/2001 00:00 - 02:15 2.25 CASE P PROD1 Continue to MU liner assy. Space out 1-1/4" CSH. PU & stab GS running tool. 02:15 - 02:30 0.25 CASE P PROD1 PU injector. Get on well. 02:30 - 04:30 2.00 CASE P PROD1 Start in open hole. 04:30 - 05:00 0.50 CASE P PROD1 Set liner shoe at 13,525' MD. 41k# up, 18k# dn wt. Circulate at 2.4 bpm / 3900 psi to release from liner. Released OK. TOL at 11512'. 05:00 - 15:45 10.75 CASE N WAIT PROD1 Circulate at min rate. Wait on vac trucks for 2% KCL water & bleach. 15:45 - 20:00 4.25 CASE P PROD1 Circulate 2 % KCL water and recover FIoPro. pump 2.0 bpm at 3750 psi, 1.9 bpm returns. 20:00 - 21:30 1.50 CASE P PROD1 Circulate 15 bbls 6 ppb bleach down coil. Lay in 1:1 while POOH. 21:30 - 23:00 1.50 CASE P PROD1 POOH. Lost 6 bbls kcl during trip. 23:00 - 23:15 0.25 CASE P PROD1 Hold pre job safety mtg regarding standing back hydril. 23:15 - 23:59 0.73 CASE P PROD1 Stand back CSH in derrick. 4/5/2001 00:00 - 00:45 0.75 CASE P PROD1 Continue to stand back wash pipe. 00:45 - 01:15 0.50 CASE P PROD1 Inspect injector bearings & chains. Replace several bearings. 01:15 - 01:45 0.50 CASE P PROD1 RIH with nozzle. Circulate 100% methanol into coil (17 bbls) 01:45 - 02:15 0.50 CASE P PROD1 POOH. Lay in 60/40 to 2000'. 02:15 - 03:00 0.75 RIGD P POST ND BOPE. Printed: 6/1/2001 2:32:20 PM BP EXPLORATION Page 7 of 7 Operations Summa Report Legal Well Name: MPF-33 Common Well Name: MPF-33A Spud Date: 7/24/1996 Event Name: REENTER+COMPLETE Start: 3/24/2001 End: Contractor Name: DOWELL SCHLUMBERGER Rig Release: Rig Name: NORDIC 1 Rig Number: Date From - To HOUrs Activity Code NPT Phase .DeScription of Operations 4/5/2001 03:00 - 05:00 2.00 RIGD P POST Hold MPU orientation for night crews in TP camp. 05:00 - 06:00 1.00 RIGD P POST Continue to prep for move. Released rig at 0600 hrs 4/5/01. Total time on well was 11 days, 18 hrs. Move rig to MPU, F-33A for horizontal sidetrack. Printed: 611/2001 2:32:20 PM Obp { Baker Hughes INTEQ( Baker Hughes INTEQ Survey Report f~ HUGHES iNTEo Company: BP Amoco Flekl: Milne Point Site: M Pt F Pad WeB: MPF-33 WeBpat~: MPF-33A Date: 4/11/2001 Time: 11:17:24 Page: 1 Coordinate(NE) Reference: Well: MPF-33, True North Vertical (TVD) Referem:e: 37: 33 7/23/1996 00:00 42.0 Set. on (VS) Reference: Well (0.00N,0.00E,320.00Azi) Survey Calcnlaflon Method: Minimum Curvature Db: Sybase Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Ceo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Alaska, Zone 4 Coordinate System: Well Centre Geomagnetic Model: BGGM2000 Site: M Pt F Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ff Ground Level: 0.00 ft 6029958.49 ff Latitude: 70 29 34.438 N 531814.44 ff Longitude: 149 44 23.616 W North Reference: True Grid Convergence: 0.25 deg Well: MPF-33 Slot Name: 33 MPF-33 Well Position: +N/-S 5356.81 ff Northing: 6035357.99 ft Latitude: 70 30 27.053 N +E/-W 10113.08 ft Easting: 541903.51 ft Longitude: 149 39 25.777 W Position Uncertainty: 0.00 fl: Wellpath: MPF-33A Drilled From: MPF-33 500292268901 Tie-on Depth: Current Datum: 37: 33 7/23/1996 00:00 Height 42.00 ff Above System Datum: Magnetic Data: 3/15/2001 Declination: Field Strength: 57435 nT Mag Dip Angle: Vertical Section: Depth From (TVD) +N/-S +E/-W ff ff ff 11726.00 ff Mean Sea Level 26.25 deg 80.79 deg mrection ~eg 0.00 0.00 0.00 320.00 ~,-~.~.,~"' ~ Survey: MWD Start Date: 4/3/2001 .~ Measured While Drilling -4: Company: Baker Hughes INTEQ Engineer: Tool: MWD,MWD - Standard Tied-to: From: Definitive Path Annotation 'MD TVD 11726.00 8730.35 Kick-off Point 14453.00 8838.73 Projected TD Survey MD Ind Azim TVD SSTVD N/S EfW ASP - Y ASP - X DLS VS ff deg deg ff ff fl ff ff fl deg/100It ff 11726.00 43.99 349.55 8730.35 8688.35 6398.89 301.54 6041757.85 542168.92 0.00 4708,01 11758.87 48.78 350.67 8753.02 8711.02 6422.33 297.46 6041781.26 542164.71 14,78 4728.58 11790.07 60.20 351,45 8771.11 8729.11 6447.38 293.53 6041806.29 542160.64 36.66 4750.30 11822.27 72.07 352.26 8784,12 8742.12 6476.47 289,38 6041835.36 542156.32 36.93 4775.26 11856.48 83.98 353.12 8791.20 8749.20 6509.61 285.13 6041868.47 542151.89 34.90 4803.37 11881.28 90.66 357.75 8792.36 8750.36 6534.28 283.16 6041893.13 542149.79 32.76 4823.54 11909.48 90.40 354.57 8792.10 8750.10 6562.41 281.28 6041921.24 542147.74 11.31 4846.30 11941.48 93.13 350.87 8791.12 8749.12 6594.13 277.22 6041952.94 542143.51 14.36 4873,20 11971.48 95.59 349.82 8788.83 8748.83 6623.62 272.21 6041982.39 542138.33 8.91 4899.01 12005.18 95.86 353.87 8785.47 8743.;47 6656.81 267.45 6042015.55 542133.38 11.98 4927.49 12039.78 94.36 351.76 8782.39 8740.39 6690.99 263.14 6042049.71 542128.88 7.48 4956.45 12067.88 94.10 348.76 8780.32 8738.32 6718.61 258.40 6042077.29 542123.99 10.69 4980.66 12101.08 91.81 344.71 8778.60 8736.60 6750.87 250.79 6042109.51 542116.20 14.00 5010.26 12134.48 90.57 342.59 8777.91 8735.91 6782.91 241.40 6042141.49 542106.62 7.35 5040.85 12168.28 90.40 338.72 8777.62 8735.62 6814.80 230.20 6042173.31 542095.25 11.48 5072.47 12199.68 90.48 335,02 8777.38 8735,38 6843.67 217.87 6042202.11 542082.75 11.79 5102.51 12230.48 89.34 331.49 8777.43 8735.43 6871,17 204.01 6042229.53 542068.74 12.04 5132.48 12262.08 88.99 328.67 8777.89 8735.89 6898.55 188.25 6042256.82 542052,83 8.99 5163.59 ( Baker Hughes INTEQ (' Baker Hughes INTEQ Survey Report INTEQ ..... Company: BP Amoco Date: 4/11/2001 Time: 11:17:24 Page: 2 Field: Milne Point Coordinate(NE) Reference: Well: MPF-33, True No~h Site: M Pt F Pad Veracal (1WED) Reference: 37: 33 7/23/1996 00:00 42.0 Wea: MPF-33 Section (V~) Reference: Well (0.00N,0.00E,320.00Azi) Wellpath: MPF-33A S~wey Calcal~on Method: Minimum Curvature Db: Sybase Survey MD lad A~hn TVD SSTVD N/S F_dW ASP - Y ASP - X DLS VS ff deg deg ff ff ff ff ff ff deg/10Oft ff 12292.68 68.55 325.15 8778.55 8736.55 6924.18 171.55 6042282.35 542035.99 11.59 12326.28 87.58 321.27 8779.68 8737.68 6951.06 151.45 6042309.12 542015.73 11.90 12362.88 87.05 317.92 8781.40 8739.40 6978.90 127.75 6042336.82 541991.88 9.26 12399.08 87.75 314.22 8783.04 8741.04 7004.94 102.67 6042362.71 541966.65 10.39 12430.88 87.14 317.39 8784.46 8742.46 7027.71 80.52 6042385.36 541944.39 10.14 12456.24 86.52 321.62 8785.86 8743.86 7046.96 64.09 6042404.51 541927.84 16.83 12482.54 87.67 324.97 8787.20 8745.20 7068.02 48.39 6042425.48 541912.03 13.45 12519.64 89.16 332.37 8788.22 8746.22 7099.68 29.12 6042457.02 541892.58 20.34 12547.54 90.22 336.42 8788.37 8746.37 7124.83 17.07 6042482.10 541880.39 15.00 12573.94 89.43 339.24 8788.46 8746.46 7149.27 7.10 6042506.49 541870.29 11.09 12604.74 89.43 342.24 8788.76 8746.76 7178.35 -3.05 6042535.50 541859.97 9.74 12644.54 88.90 345.24 8789.34 8747.34 7216.55 -14.19 6042573.63 541848.61 7.65 12673.74 87.05 347.88 8790.37 8748.37 7244.92 -20.98 6042601.97 541841.67 11.04 12700.54 86.26 349.82 8791.94 8749.94 7271.17 -26.15 6042628.19 541836.35 7.80 12733.14 87.49 354.93 8793.72 8751.72 7303.42 -30.47 6042660.41 541831.85 16.10 12761.74 88.28 358.80 8794.77 8752.77 7331.96 -32.03 6042688.93 541830.13 13.80 12790.94 88.28 2.15 8795.65 8753.65 7361.14 -31.79 6042718.11 541830.21 11.47 12824.59 85.89 358.64 8797.36 8755.36 7394.74 -31.55 6042751.71 541830.25 12.61 12854.14 84.67 357.22 8799.79 8757.79 7424.17 -32.62 6042781.13 541829.02 6.32 12884.94 85.37 351.05 8802.47 8760.47 7454.67 -35.75 6042811.61 541825.71 20.09 12915.54 88.28 345.94 8804.16 8762.16 7464.60 -41.85 6042841.50 541819.45 19.19 12948.94 87.93 342.24 8805.27 8763.27 7516.70 -51.00 6042873.54 541810.12 11.12 12979.34 86.96 337.48 8806.62 8764.62 7545.20 -61.45 6042901.99 541799.51 15.96 13014.74 87.22 334.49 8808.42 8766.42 7577.49 -75.84 6042934.19 541784.94 8.47 13045.54 90.22 331.67 8809.11 8767.11 7604.94 -89.77 6042961.56 541770.85 13.37 13075.74 91.89 327.79 8808.55 8766.55 7631.01 -104.99 6042987.54 541755.49 13.98 13103.74 93.39 325.32 8807.26 8765.26 7654.35 -120.40 6043010.79 541739.95 10.31 13136.34 93.30 320.74 8805.36 8763.36 7680.34 -139.97 6043036.67 541720.23 14.03 13171.74 92.42 319.16 8803.59 8761.59 7707.41 -162.72 6043063.60 541697.33 5.10 13207.94 89.34 316.34 8803.04 8761.04 7734.19 -187.05 6043090.25 541672.85 11.53 13238.94 89.25 312.81 8803.42 8761.42 7755.95 -209.13 6043111.87 541650.66 11.39 13268.14 85.47 312.88 8804.76 8762.76 7775.78 -230.51 6043131.58 541629.17 12.95 13307.74 83.79 308.41 8808.47 8766.47 7801.45 -260.42 6043157.09 541599.12 12.01 13339.94 83.26 304.35 8812.11 8770.11 7820.43 -286.17 6043175.91 541573.26 12.64 13373.54 85.11 299.24 8815.51 8773.51 7838.03 -314.57 6043193.35 541544.76 16.10 13407.54 87.93 300.30 8817.58 8775.58 7854.88 -344.03 6043210.03 541515.22 8.86 13443.14 88.90 304.35 8818.56 8776.56 7873.90 -374.09 6043228.89 541485.05 11.69 13476.74 87.93 309.46 8819.49 8777.49 7894.06 -400.94 6043248.89 541 458.09 15.47 13510.94 86.70 314.22 8821.09 8779.09 7916.85 -426.38 6043271.53 541 432.52 14.36 13551.44 85.81 319.33 8823.74 8781.74 7946.28 -454.05 6043300.81 541404.69 12.78 13582.74 85.02 322.15 8826.24 8784.24 7970.44 -473.79 6043324.85 541384.81 9.33 13613.34 86.17 323.74 8828.59 8786.59 7994.78 -492.18 6043349.09 541366.29 6.40 13640.14 88.72 325.50 8829.79 8787.79 8016.61 -507.68 6043370.83 541350.67 11.56 13671.54 90.13 327.79 8830.10 8788.10 8042.84 -524.94 6043396.95 541333.26 8.56 13702.84 89.52 331.49 8830.20 8788.20 8069.84 -540.76 6043423.86 541317.30 11.98 13734.54 89.34 336.60 8830.51 8788.51 8098.33 -554.63 6043452.27 541303.27 16.13 13765.54 89.52 340.30 8830.82 8788.82 8127.16 -566.01 6043481.03 541291.72 11.95 13799.14 88.99 343.12 8831.26 8789.26 8159.05 -576.55 6043512.86 541281.00 8.54 13829.54 91.28 346.65 8831.19 8789.19 8188.39 -584.48 6043542.16 541272.91 13.84 13852.54 91.39 349.11 8830.65 8788.65 8210.87 -589.30 6043564.61 541267.96 10.70 13877.94 91.10 354.05 8830.10 8788.10 8235.99 -593.02 6043589.69 541264.10 19.48 13907.14 92.33 354.93 8829.23 8787.23 8265.04 -595.82 6043618.73 541261.13 5.18 5193.96 5227.48 5264.03 5300.10 5331.78 5357.09 5383.31 5419.95 5446.97 5472.10 5500.89 5537.32 5563.42 5586.85 5614.33 5637.19 5659.39 5684.98 5708.21 5733.59 5760.43 5790.90 5819.46 5853.44 5883.43 5913.18 5940.97 5973.46 6008.81 6044.97 6075.82 6104.76 6143.65 6174.74 6206.48 6238.32 6272.22 6304.92 6338.73 6379.06 6410.26 6440.73 6467.41 6498.59 6529.45 6560.19 6589.59 6620.80 6648.37 6668.69 6690.32 6714.37 (,, · Baker Hughes INTEQ( Baker Hughes INTEQ Survey Report INI'EO ........ Company: BPAmoco Date: 4/11f2001 Time: 11:17:24 Page: $ Flel4: Milne Point Co-ordinate(NE) Reference: Well: MPF-33, True North Site: M Pt F Pad Vertical (TVD) Reference: 37: 33 7/23/1996 00:00 42.0 Well: MPF-33 Section (VS) Reference: Well (0.00N,0.00E,320.00Azi) Wellpath: MPF-33A Survey Calenlaflon Method: Minimum Curvature Db: Sybase Survey MD Inei Azim TVD SSTVD N/S E/W ASP - Y ASP - X DLS VS ff deg deg ff ff ff ff ff ff deg/10011: fl 13943.16 93.66 358.63 8827.34 8785.34 8300.94 -597.85 6043654.62 541258.91 10.90 6743.18 13977.06 93.30 2.68 8825.28 8783.28 8334.77 -597.46 6043688.44 541259.11 11.97 6768.84 14010.06 92.07 5.50 8823.74 8781.74 8367.65 -595.11 6043721.33 541261.27 9.31 6792.52 1 4044.66 91,81 9.91 8822.57 8780.57 8401.91 -590.47 6043755.61 541265.71 12.76 6815.78 1 4073.46 91.1 9 12.20 8821.81 8779.81 8430.16 -584.95 6043783.89 541271.07 8.23 6833.88 14104.86 90.13 14.31 8821.45 8779.45 8460.72 -577.75 6043814.49 541278. I 0 7.52 6852.66 14134.36 89.52 17.31 8821.54 8779.54 8469.10 -569.72 6043842.91 541285.98 10.38 6869.24 14162.26 88.19 20.48 8822.10 8780.10 8515, 49 -560.68 6043869,35 541294.86 12.32 6883.64 14192.86 87.58 22.42 8823.23 8781.23 8543.95 -549.50 6043897.87 541305.88 6.64 6898.26 14222.06 88.46 25.94 8824.24 8782.24 8570.57 -537.55 6043924.55 541317.68 12.42 6910.97 14250.06 88.37 29.11 8825.01 8783.01 8595.38 -524.62 6043949.44 541330.47 11.32 6921.66 14282.46 88.37 31.58 8825.93 8783.93 8623.33 -508.26 6043977.47 541346.67 7.62 6932.56 1 4321.06 87.49 36.34 8827.33 8785.33 8655,32 -486.72 6044009.58 541368.03 12.53 6943.21 1 4354.46 86.17 38.80 8829.18 8787.18 8681.75 -466.38 6044036.12 541388.21 8.35 6950.39 14389,56 84.93 41.62 8831.90 8789.90 8708.47 -443.80 6044062.97 541410.64 8.75 6956.34 1 4427.46 83.35 43.03 8835.77 8793.77 8736.34 -418.41 6044090.98 541 435.87 5.57 6961.38 14453.00 83.35 43.03 8838.73 8796.73 8754.89 -401.10 6044109.62 541453.07 0.00 6964.46 BP Amoco Parent We~lpat~: T~e on MD: BAKER HUGHES INTEQ WELLPATH DET~d LS MP~33A 5002~2268901 MPF-33 11726.00 Nordic 1 37: 33 7/23/1996 00:00 42,00tt ~'om TVD ~g: R~. Datum: V.S~ctlon 320.00° REFERENCE INFORMATION 42.00 TARGET DETAlS Name TVD +~S +E/~W Shape ii,l,i MPF*33APolygon 0.00 654ZO8 149,~1 Polygon Co-ordinate (N/E) Reference: Well Centre: MPF-33, True North Vertical (TVD) Reterence: System: Mean Sea Level Section (VS) Reference: SIo~ - 33 (0.00N,0.0OE) Measured Depth Reference: 37: 33 7/23/1996 00:00 Calculation Method: Minimum Curvature ANNOTATIONS TVD MD Annotation ,m · 8688.35 1172~.00 KJC k-off I=oint 8796.73 14453.00 Projected TD Obp Azimuths to True North Magnetic North: 26.25° Magnetic Field Strength: 57435nT Dip Angle: 80.79° Date: 3/15/2001 Model: BGGM2000 4600 4600 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 7400 7600 7800 8000 8200 Vertical Section at 320.00' [200ft/in] 12-Apr-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPF-33A Dear Dear Sir/Madam' Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,592.21' MD Window / Kickoff Survey: 11,726.00' MD prOjected Survey: 14,453,.00' MD (if applicable Please call me at 273-3545 if you have anY questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED ~AY 0 ! 200~ Alasl~ Oil & Gas Cons. Comn~ion An~or~e Milne Point Unit Alaska Drilling & Wells Milne Point MPF, Slot MPF-33 MPF-33A Job No. AKMWfOfO0, Surveyed: 3 April, 2001 DEFINITIVE SURVEY REPORT April, 200'/ Your Ref: AP1500292268901 Surface Coordinates: 6035357.99 N, 541903.50 E (70" 30' 26.9347" N, Kelly Bushing: 40.54ft above Mean Sea Level 149o39'25.8108"W) DRILLINI~ SERVIF-..E5 A Halliburton company Survey Ref: svy9821 Milne Point Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11592.21 43.770 349.040 8593.34 8633.88 11726.00 44.000 349.840 8689.77 8730.31 11758.87 48.780 350.670 8712.43 8752.97 11790.07 60.200 351.450 8730.53 8771.07 11822.27 72.070 352.260 8743.53 8784.07 11856.48 83.980 353.120 8750.62 8791.16 11881.28 90.660 357.750 8751.78 8792.32 11909.48 90.400 354.570 8751.52 8792.06 11941.48 93.130 350.870 8750.53 8791.07 11971.48 95.590 349.820 8748.25 8788.79 12005.18 95.860 353.870 8744.89 8785.43 12039.78 94.360 351.760 8741.80 8782.34 12067.88 94.100 348.760 8739.73 8780.27 12101.08 91.810 344.710 8738.02 8778.56 12134.48 90.570 342.590 8737.33 8777.87 12168.28 90.400 338.720 8737.04 8777.58 12199.68 90.480 335.020 8736.80 8777.34 12230.48 89.340 331.490 8736.85 8777.39 12262.08 88.990 328.670 8737.31 8777.85 12292.68 88.550 325.150 8737.96 8778.50 12326.28 87.580 321.270 8739.10 8779.64 12362.88 87.050 317.920 8740.81 8781.35 12399.08 87.750 314.220 8742.46 8783.00 12430.88 87.140 317.390 8743.87 8784.41 12456.24 86.520 321.620 8745.28 8785.82 12482.54 87.670 324.970 8746.61 8787.15 12519.64 89.160 332.370 8747.64 8788.18 12547.54 90.220 336.430 8747.79 8788.33 12573.94 89.430 339.240 8747.87 8788.41 12604.74 89.430 342.240 8748.18 8788.72 Sperry-Sun Drilling Services Survey Report for MPF-33A Your Ref: APl 500292268901 Job No. AKMWI0100, Surveyed: 3 April, 2001 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 6307.72 N 318.51. E 6041667.41 N 542186.42 E 6398.90 N 301.51E -6041758.49 N 542168.91E 6422.35 N 297.49 E 6041781.91N 542164.76E 6447.40 N 293.56 E 6041806.94 N 542160.69 E 6476.49 N 289.41E 6041836.01N 542156.37 E 6509.63 N 285.16 E 6041869.12 N 542151.94E 6534.30 N 283.20 E 6041893.79 N 542149.84E 6562.43 N 281.31E 6041921.91N 542147.79 E 6594.15 N 277.26 E 6041953.60 N 542143.56 E 6623.64 N 272.24 E 6041983.06 N 542138.38 E 6656.83 N 267.49 E 6042016.22 N 542133.43 E 6691.01N 263.17 E 6042050.38 N 542128.93 E 6718.63 N 258.43 E 6042077.97 N 542124.03 E 6750.89 N 250.83 E 6042110.19 N 542116.24 E 6782.93 N 241.43 E 6042142.18 N 542106.66 E 6814.82 N 230.23 E 6042174.00 N 542095.29 E 6843.69 N 217.90 E 6042202.80 N 542082.80 E 6871.19 N 204.04E 6042230.22 N 542068.78 E 6898.57 N 188.29 E 6042257.51N 542052.87 E 6924.20 N 171.59 E 6042283.04 N 542036.03 E 6951.08 N 151.48 E 6042309.82 N 542015.77 E 6978.92 N 127.79 E 6042337.52 N 541991.92 E 7004.96 N 102.70 E 6042363.42 N 541966.69 E 7027.73 N 80,56 E 6042386.07 N 541944.42 E 7046.98 N 64.12 E 6042405.22 N 541927.87 E 7068.04 N 48.42 E 6042426.19 N 541912.05 E 7099.69 N 29.15 E 6042457.74 N 541892.61 E 7124.85 N 17.10 E 6042482.82 N 541880.41E 7149.30 N 7.14 E 6042507.21 N 541870.32 E 7178.37 N 3.02W 6042536.23 N 541859.99 E DEFINIT% E. Alaska Drilling & Wells Milne Point MPF Dogleg Vertical Rate Section (°ilOOft) 4627.26 0.45 4708.03 14.66 4728.58 36.66 4750.29 36.93 4775.25 34.90 4803.36 32.76 4823.53 11.31 4846.29 14.36 4873.20 8.91 4899.01 11.98 4927.49 7.46 4956.45 10.69 4980.65 14.00 5010.25 7.35 5040.84 11.46 5072.46 11.79 5102.50 12.04 5132.48 8.99 5163.58 11.59 5193.95 11.90 5227.47 9.26 5264.02 10.39 5300.10 10.14 5331.77 16.83 5357.09 13.45 5383.31 20.34 5419.94 15.04 5446.96 11.06 5472.09 9.74 5500.89 Comment Tie on Point Window Point Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth DrillQuest 2.00.08.005 12 April, 2001 - 10:31 Page 2 of 6 Sperry-Sun Drilling Services Survey Report for MPF-33A Your Ref: AP1500292268901 Job No. AKMWI0100, Surveyed: 3 April, 2001 Milne Point Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 12644.54 88.900 345.240 8748.76 8789.30 12673.74 87.050 347.880 8749.79 8790.33 12700.54 86.260 349.820 8751.35 8791.89 12733,14 87.490 354.930 8753.13 8793.67 12761.74 88.280 358.800 8754.19 8794.73 12790.94 88.280 2.150 8755.06 8795.60 12824.54 85.890 358.010 8756.77 8797.31 12854.14 64.670 357.220 8759.21 8799.75 12884,94 85.370 351.050 8761.88 8802.42 12915.54 88.280 345.940 8763.58 8804.12 12948.94 87.930 342.240 8764.69 8805.23 12979.34 86.960 337.480 8766.04 8806.58 13014.74 87.220 334,490 8767.84 8808.38 13045.54 90.220 331.670 8768.53 8809.07 13075.74 91.890 327.790 8767.97 8808.51 13103.74 93.390 325.320 8766.68 8807.22 13136.34 93.300 320.740 8764.78 8805.32 13171.74 92.420 319.160 8763.01 8803.55 13207.94 89.340 316.340 8762.46 8803.00 13238.94 89.250 312.810 8762.84 8803.38 13268.14 85.470 312.880 8764.18 8804.72 13307.74 83.790 308.410 8767.89 8808.43 13339.94 83.260 304.350 8771.52 8812.06 13373.54 85.110 299.240 8774.93 8815.47 13407.54 87.930 300.300 8776.99 8817.53 13443.14 88.900 304.350 8777.98 8818.52 13476.74 87.930 309.460 8778.91 8819.45 13510.94 86.700 314.220 8780.51 8821.05 13551.44 85.810 319.330 8783.16 8823.70 13582.74 85.020 322.150 8785.66 8826.20 Local Coordinates Global Coordinates Northings Easfings Northings Eastings (ft) (ft) (ft) (ft) 7216.57 N 14.16W 6042574.36 N 541848.64E 7244.95 N 20.94W 6042602.70 N 541841.70 E 7271.19 N 26.11W 6042628.92 N 541836.37 E 7303.45 N 30.43W 6042661.15 N 541831.87 E 7331.98 N 31.99W 6042689.67 N 541830.15 E 7361.16 N 31.75 W 6042718.85 N 541830.23 E 7394.71 N 31.70 W 6042752.40 N 541830.09 E 7424.18 N 32.93 W 6042781.87 N 541828.69 E 7454.69 N 36.06 W 6042812.36 N 541825.39 E 7484.61 N 42.16 W 6042842.25 N 541819.13 E 7516.71N 51.31W 6042874.29 N 541809.80 E 7545.22 N 61.76W 6042902.74 N 541799.18 E 7577.51 N 76.15W 6042934.95 N 541784.61 E 7604.95 N 90.09W 6042962.32 N 541770.52 E 7631.03 N 105.30W 6042988.30 N 541755.16 E 7654.36 N 120.72W 6043011.55 N 541739.61E 7680.36 N 140.28W 6043037.43 N 541719.90E 7707.42 N 163.03W 6043064.37 N 541697.00E 7734.21N 187.36W 6043091.02 N 541672.51E 7755.96 N 209.44W 6043112.65 N 541650.31 E 7775.79 N 230.82W 6043132.36 N 541628.82 E 7801.47 N 260.73W 6043157.86 N 541598.77 E 7820.44N 286.48W 6043176.69 N 541572.91E 7838.04 N 314.88W 6043194.13 N 541544.41 E 7854.89N 344.34W 6043210.82 N 541514.86 E 7873.92 N 374.40W 6043229.67 N 541484.69 E 7894.08 N 401.25W 6043249.68 N 541457.73 E 7916.86 N 426.69W 6043272.32 N 541432.16 E 7946.30 N 454.36W 6043301.60 N 541404.32 E 7970.45 N 474.11W 6043325.64N 541384.44E Dogleg Rate (°/'lOOft) 7.65 11.04 7.80 16.10 13.80 11.47 14.21 4.91 20.09 19.19 11.12 15.96 8.47 13.37 13.98 10.31 14.03 5.10 11.53 11.39 12.95 12.01 12.64 16.10 8.86 11.69 15.47 14.36 12.78 9.33 Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 5537.31 5563.41 5586.84 5614.32 5637.19 5659.38 5685.05 5708.42 5733.80 5760.64 5791.11 5819.67 5853.65 5883.64 5913.39 5941.18 5973.67 6009.02 6045.18 6O76.O4 6104.97 6143.86 6174.95 6206.69 6238.53 6272.43 6305.13 6338.94 6379.28 6410.47 12 April, 2001 - 10:31 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPF-33A Your Ref: APl 500292268901 Job No. AKMWl0100, Surveyed: 3 April, 2001 Milne Point Unit Measured Depth (ft) Incl. Azim. 13613.34 86.170 323.740 13640.14 88.720 325.500 13671.54 90.130 327.790 13702.84 89.520 331.490 13734.54 89.340 336.600 Sub-Sea Depth (ft) 8788.01 8789.20 8789.52 8789.62 8789.93 Vertical Depth (ft) 8828.55 8829.74 8830.06 8830.16 8830.47 13765.54 89.520 340.300 8790.24 8830.78 13799.14 88.990 343.120 8790.68 8831.22 13829.54 91.280 346.650 8790.60 8831.14 13852.54 91.280 349.110 8790.09 8830.63 13877.94 91.100 354.050 8789.56 8830.10 13907.14 92.330 354.930 8788.69 8829.23 13943.16 93.660 358.630 8786.81 8827.35 13977.06 93.300 2.680 8784.75 8825.29 14010.06 92.070 5.500 8783.20 8823.74 14044.66 91.810 9.910 8782.03 8822.57 14~73.46 91.190 12.200 8781.28 8821.82 14104.86 90.130 14.310 8780.91 8821.45 14134.36 89.520 17.310 8781.00 8821.54 14162.26 88.190 20.480 8781.56 8822.10 14192.86 87.580 22.420 8782.69 8823.23 14222.06 88.460 25.940 8783.70 8824.24 14250.06 88.370 29.110 8784.48 8825.02 14282.46 88.370 31.580 8785.40 8825.94 14321.06 87.490 36.340 8786.79 8827.33 14354.46 86.170 38.800 8788.64 8829.18 14389.56 84.930 41.620 8791.36 8831.90 14427.46 83.350 43.030 8795.23 8835.77 14453.00 83.350 43.030 8798.19 8838.73 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 7994.80 N 492.49W 6043349.88 N 541365.92 E 8016.63 N 507.99W 6043371.62 N 541350.30 E 8042.85 N 525.25W 6043397.75 N 541332.89 E 8069.85 N 541.07W 6043424.66 N 541316.92 E 8098.34N 554.94W 6043453.08 N 541302.89 E 8127.17 N 566.32W 6043481.84N 541291.35 E 8159.07 N 576.86W 6043513.67 N 541280.62 E 8188.41 N 584.79W 6043542.97 N 541272.53 E 8210.89 N 589.62W 6043565.42 N 541267.58 E 8236.00 N 593.33W 6043590.51 N 541263.72 E 8265.05 N 596.14W 6043619.55 N 541260.75 E 8300.96 N 598.16W 6043655.44 N 541258.53 E 8334.79 N 597.77W 6043689.27 N 541258.73 E 8367.66 N 595.42W ' 6043722.16 N 541260.89 E 8401.92 N 590.78W 6043756.45 N 541265.33 E 8430.18 N 585.26W 6043784.73 N 541270.70 E 8460.74 N 578.06W 6043815.33 N 541277.72 E 8489.12 N 570.03W 6043843.76 N 541285.60 E 8515.50 N 561.00W 6043870.19 N 541294.48 E 8543.96 N 549.81W 6043898.72 N 541305.50 E 8570.58 N 537.86W 6043925.40 N 541317.30 E 8595.40 N 524.93W 6043950.29 N 541330.10 E 8623.35 N 508.57W 6043978.33 N 541346.30 E 8655.33 N 487.03W 6044010.44N 541367.66 E 8681.76 N 466.70W 6044036.98 N 541387.84E 8708.49 N 444.11W 6044063.83 N 541410.28 E 8736.36 N 418.72W 6044091.85 N 541435.51 E 8754,90 N 401.41W 6044110.49 N 541452.71 E Dogleg Rate (°/lOOft) 6.40 11.56 8.56 11.98 16.13 11.95 8.54 13.84 10.69 19.46 5.18 10.90 1t.97 9.31 12.76 8.23 7.52 10.38 12.32 6.64 12.42 11.32 7.62 12.53 8.35 8.75 5.57 0.00 Alaska Drilling & Wells Milne Point MPF Vertical Section Comment 6440.94 6467.62 6498.81 6529.66 6560.40 6589.80 6621.01 6648.58 6668.90 6690.53 6714.59 6743.39 6769.06 6792.73 6816.00 6834.09 6852.87 6869.45 6883.86 6898.47 6911.18 6921.88 6932.77 6943.43 6950.60 6956.55 6961.59 6964.67 Projected Survey DrillQuest 2.00.08.005 12 Apdl, 200f. 10:31 Page 4 of 6 Sperry-Sun Drilling Services Survey Report for MPF-33A Your Reft APl 500292268901 Job No. AKMWI0100, Surveyed: 3 April, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPF All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.294° (27-Mar-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well Reference and calculated along an Azimuth of 320.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 14453.00ft., The Bottom Hole Displacement is 8764.10ft., in the Direction of 357.375° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 11592.21 8633.88 6307.72 N 318.51 E 11726.00 8730.31 6398.90 N 301.51 E 11758.87 8752.97 6422.35 N 297.49 E 11790.07 8771.07 6447.40 N 293.56 E 11822.27 8784.07 6476.49 N 289.41 E 14453.00 8838.73 8754.90 N 401.41W Comment Tie on Point Window Point Interpolated Azimuth Interpolated Azimuth Interpolated Azimuth Projected Survey DrillQuest 2.00.08.005 f2 April, 2001 - lO:31 Page 5 of 6 Sperry-Sun Drilling Services Survey Report for MPF-33A Your Ref: AP1500292268901 Job No. AKMWf0100, Surveyed: 3 April, 2001 Milne Point Unit Alaska Drilling & Wells Milne Point MPF Survey tool program for MPF-33A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 4684.46 4388.95 4684.46 4388.95 14453.00 8838.73 Survey Tool Description AK-1 BP_HG (MPF-33 Gyrodata) MWD Magnetic (MPF-33) DrillQuest 2.00.08.005 12 April, 2001.10:31 Page 6 of 6 Re: MPF-$3~ rig move off/on Subject: Re: MPF.33a rig move off/on c~ ~,-(~)~ ~ Date: Wed, 28 Mar 2001 09:21:38 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Stagg, Ted O (ORBIS)' <StaggTO@bp.com> CC: "PBU, CTD Supervisor" <PBUCTDSupervisor@bp.com>, "Stanley, Mark J (ANC)" <StanleMJ@bp.com>, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak. us> Ted, et al, I apologize for not getting a reply on this issue back to you sooner, i did talk to Gary in advance of your message yesterday and discussed what work was planned and how the well was to be left. You have captured what we discussed in your note. Last evening Lou called me from the slope and I relayed that I had received your message, but had not gotten a reply out. I asked him to talk to the Company Rep and pass on that the plans as presented were acceptable. Please give me a call with any questions. Tom Maunder, PE Petroleum Engineer AOGCC "Stagg, Ted 0 (ORBIS)" wrote: :> :> :> ;> :> :> :> :> :> :> :> :> Tom Maunder Sr. Petroleum Engineer AOGCC SLB/Nordic is currently on MPF-33a, having just completed a cement squeeze to shut off Sag R. perfs below a 7" whipstock. Window milling in the Sag R. interval is about to start, However, later tonight or tomorrow, SLB/Nordic will have to move off the well in order to allow Nabors4ES to move off the well pad. MPF.33a will be secured as follows for pulling off the well: 1. The window will be either partially or fully milled, 2. Kill weight fluid, 8. 5 ppg bdne, will be in the well. 3. A BPV will be set in the tubing hanger, 4. The full 4" tree will be on the well. When SLB/Nordic moves back onto the well a full BOP inspection will be conducted with notice given to AOGCC to witness. If further reporting is needed please advise. Ted Stagg CTD Eng. 564.4694 240.8074 Tom Maunder <tom maunder~admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 2 3/28/01 12:26 PM FROM: OFFICE OF GOUERHOR NO.: 9074655147 CONSERVATION 33~ W. 7TM AVENUE, SUITE ANG'HORAGE, ALASKA FAX (~071278-754E Ted Stagg CT Drilling Engineer BP Explomtlon (Alaska) Inc. P 0 Box 1966][2 Anchorage, AK 99519-6612 Milne Point Unit MPF-33A BP Exploration (Alaska) Inc. Permit No: 201-062 Sur .Lee: 1905'NSL, 2660'WEL, Sec, 06, TI3N, R10E, UM Btmhole Loc, 120'NSL, 3009'WEL, Sec. 31, TI4N, R10E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced'well. ' The permit to redril] does not exempt you fr6m obtaining additional permits required by law from other governmental agengies, and does not authorize conducting drilling operations until all other reqmred permitting determmabons ore made, BloWout prevention equipment (BOPE) must be tested in accordance wi~ 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting ~e Commission pelxoleum field inspector on the North Slope pager at 659-3607. t Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED thtsL ~.~ ._~kf°t .... . ....... day .t'Mmrch, 2001 dllgEnelosures 'Department of Fish & Game, I-Iabitat Section w/o enol. Department of Eovimnmenta! Conservation w/o enel. CONSERVATION COMPASSION / TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-33A BP Exploration (Alaska) Inc. Permit No: 201-062 Sur Loc: 1905'NSL, 2660'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc. 120'NSL, 3009'WEL, Sec. 31, T14N, R10E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced'well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T, Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this day of March, 2001 dlf/Enclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1IRR-22-01 THU 05:41 PH ~0C-Qp F~H NO, 90~,-'~76 7542 P, 10/10 ,/ ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION .' PERMiT TO DRILL REVISED: 03/22/01 · , 20 AAC 25.005 "· " F0~m'10,4( 11.85 i../... : . . ........ .,. ~"" · . . 'I "~i i%. i.,_ Ancl~ella~' In Triplicate Re-:Entry ~ ReOrtt!" Type 0fwell [] E~lorato~y _" Q~U~'hlc T~ ~e~pm~t Oil . · D~pen ~ ~ ~ ~e~.G~ ~Sin~ Zone · ~ MuPpie Z~e '~; N~e ~f Ope~tor ....... '5. Datum El~at~ (DF or ~)~' 10. Field ~d P~I . '. ' BP ~bm~, (Alaska) I~. KBE = ~.~' Milne P~nt ..Unit / ~g River ;3. Addm~ ...... 6. Pm~ ~signa~on .... 'P,O. ~x 196612, ~c~rage,.Alaska 9951~6612 u~5~ADL ~18 , ,,, . ~,,J~ j,, 4,'~ati°n of ~11 at su~ace 7, ~n[~r Pr~ Name ~ 1,.Type B~nd (s~ 20 ~C 2s.0~) .1905~.NS~ 266~ WEL, SEC. 06, T13N; R10E, UM Milne Point Unit ... At top of pr~u~ve inte~al 8, Well Number "- '. ~0~ NGL. 2329' WEE, SEC. 31, T14N, R10E, UM MPF-33A Number 2S100302630-277 :At t~al.dep~ 9. Appro~ate ~ud d~ 1~ NSL, ~09' WEL, SEC, 30, T14N, R10E, UM 0~01 Amount $200,000,00 12; Di~nce to nee~t pmpe~y=lin~ ~13. DistanCe {o n~rest weft .... 14.' Number of acres I~'Pmpe~ 1~. PropoSed ~ePth' (MD and"~D)" " "ADL 35~1'7, 3~09' MD ~ No Close Approach 5083 1~62'. MD 18723' ~D 1'6~ To b~-'~mPleted for ~viated wells ' ' 1'7. Anficipat~ pressure {~e 20 ~c ~035 (e) (2)} . '~ ,. ' Kl~k Off Depth 11~36'MD Ma,~imumHoleAng,!~. 93~ M~lmum~ace l~6,~ig,~total~epth~D) ~7~?/3000 psip. Setting Depth · 1'8~ .C~ingProgram. Size ..... ... Specifications Top.. Sottqm , Quanti~ of Cgment., H01e ': Ca~in~ Weight Grad~ ...... ""COUolinq.~ .'~ Length MD.. ~D MD ~D (include st~ge'data) . '~3/4"." 2.7/8" 6. t6~ L,80 ST-L 2902' 11560' ~70' 1~6~ 8723' U'~m~nted SIoEed Liqer ',., " .; . ' ' .i ., , ,,. .... ., ,~ · ;' .. ,, ..... ' .,~ . ~ ~ ~ ,, ~ i . . · . . . . , I i' - . . I~1 ] .. I . ~ II I I .... IH I II INI I I IIIIII I . I..~ III ,. . . . ....... ~ ~.[11 IIIII I I II IIII "i I'111, I L.' ,.., , ........... 19,.?o b~ completed 'for Re~'~ll, Re~ent~,.and Deepen Operations. " ' Present well oondltton summa~ · Total depth: measured 1~380 feet Plugs (measured) true veRlca[ ~1~2 feet EffectiVe depth: me~ured 12~82 feet Junk (measured) .. true ve~lcal gl 25 feet Casing Length Size Cemented MD ~D Structural . Condu~or 11~' 20" 250 sx Arcticset I (Appmx.) 110' 110' Intermediate Pmductl0n 12~34' 7" 600 sx Class 'G' '1 ~3~S', 9181' Liner ' ' . , .. . Pe~rati0n'depth: measured 11748' - 11788' tree ve~i~al 8746' - . .20; Aaachments -, a. F,in~.F~"' . d'~rope'~ P~at ...... a BOP S~e~h "a oi~e~e~ ~ketch a ~ii,~g ~ogra~'~' ' ~ Drilling FluI~ Program ~ ~me vs Depth Plot ~ ~efra~ion A~ysls ~ S~ed Repo~ ~ 30 ~,25.0S0 Requimman{s -' ', ..... ~ ~,~ .. . i . iii i .i [ ~1.. iltll i~ ii i ill il i i i ii i i[i.., ii 'Signed T.d Smgg ~~ Title CT Drilling Engineer Date ~/~,/ . ...... ' .... ¢ ...... ~:/~ ' .Com~is~n'us.'o~ly ' ' .... '" .... ':"~ ..... '" """""/"" "?" ' "' ' ', 20'1~,~Z.- ~ _..150- 02~-226~9-01 , I ~~ ~ ~/ I for other requFemems. '.. Conditions 0f'APP~oval: Samples Required d'~es ~NO' MUa Log Re~ired ' . ~ Hydrogen Sulfide Ma~ums ~es ~ No Dim~ionai · , . · Require Wo~ing Pressure for 8OPE ~ 2K ~ 3K ~ 4K ~ 5K ·'." ' · t. ' . '~ MAR'~2 2001. ' Dy o~er of ~/~//~/- . . ALASK/~i STATE OF ALASKA ,L AND GAS CONSERVATION COMIC"-'''~ .SION PERMIT TO DRILL 20 AAC 25.005 REVISED: 03122/01 la. Type of work [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas J~'Sin~ Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB)" 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 40.54' Milne Point Unit / Sag River 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 o~'5'>~__.~-'ADL 355018 4. Location of well at surface 7. L~i-t~r Property Name 11. Type Bond (See 20 AAC 25.025) 1905' NSL, 2660' WEL, SEC. 06, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number 3003' NSL, 2329' WEL, SEC. 31, T14N, R10E, UM MPF-33A Number 2S100302630-277 At total depth 9. Approximate spud date 120' NSL, 3009' WEL, SEC. 30, T14N, R10E, UM 03/23/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and ']'VD) ADL 355017, 3009' MDI No Close Approach 5083 14462' MD / 8723' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11736' MD Maximum Hole Angle 93 ° Maximum surface 1956 psig, At total depth (TVD) 8700' / 3000 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Role C'asin.q Wei.clht Grade Couplin,q Len,qth MD TVD MD TVD (i,nclude sta,qe data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2902' 11560' 8570' 14462' 8723' Unceme~ted Slotted Liner , 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 12380 feet Plugs (measured) true vertical 9192 feet Effective depth: measured 12282 feet Junk (measured) true vertical 9125 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 250 sx Arcticset I (Approx.) 110' 110' Surface 4703' 9-5/8" 1250 sx PF 'E', 250 sx 'G', 150 SX PF 'E' 4734' 4419' Intermediate Production 12334' 7" 600 sx Class 'G' 12363' 9181' Liner Perforation depth: measured 11748' - 11788' true vertical 8746' - 8775' '20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foreg,<;)i;ng, is tr_jLg~and correct to the best of my knowledge Signed TedStagg ~~.:.i:".'/~ Title CT Drilling Engineer Date "~.'" 'i.:, :.:,:: .': "..' !.:': .::. ,:.': [:: ':::'.'..' :,..:! :'..!..::';':::':.. ': ,. :.i:.':::., ,,: ' ='!,"i .... ':.: ..::~ :':.:.:.:.':.'!:::..?....,..:~ ::.i..":..':;',..'.,..::'.'.::,::.!.;;.;: c~m:~'lSsiiSh'.,Uli:.' ~ri:,iy!: .:..::. !.,.:",:.::: ..,..:.,. !!,~:. :' ': :? ;:. :'..'. :: :..:: ':,!.L..:,:;!.',.:.!,'. ;':: ..' ~:: ::' .:' :. .:' :". .. ".'. per% Number' ..... I Ai:fl Number ..... "' "" '"'"' .... 'i'"I ....... Date'"' "1 lett, i :'" ' ' ' 2017.~),~7" ~'~-.~ - ,,~ I 50- 029-22689-01 I I for other requi)'ements Coi~ditions of Approval: Samples Required [] Yes ,J~No Mud Log Required ?'~:Y..Y.~¢~~ Hydrogen Sulfide Measures ,[~es [] No Directional Survey Required ~'.~,¢.,S[::I~ I~b Required Working Pressure forBOPE []2K []3K []4K []5K []10K []15K' /1~.5KpsiforCTU Other: MAR 22 2001 by order of Approved By I'~'mt !!%, f f"~" ! !~, ~ /:~, , Commissioner the commission -~lask~ t~~ ¢,n'n.~. Cnmmiss~ Form 10-401 Rev. 12-01-85 AncS~bl~ In Triplicate MP F-33L1 changing to MP F-33a Subject: MP F-33L1 changing to MP F.33a Date: Thu, 22 Mar 2001 19:36:06 -0600 From: "Stagg, Ted O (ORBIS)" <StaggTO@BP.com> To: "Tom Maunder (E-mail)" <tom_maunder@admin.state.ak. us> CC: "Hubble, Terrie L" <HubbleTL@BP.com> Tom Maunder Sr. Petroleum Engineer AOGCC A Permit to Drill for MP F-33L1, (201-057) was issued on 3115/01. However, several changes to the sidetrack design have occurred. These changes are as follows: 1. It was discovered that the planned KOP was incorrectly placed in the lower Kingak instead of the upper Sag R. interval. Since sidetrack drilling in the Kingak shale is very troublesome, the whipstock depth has been lowered from 11,700 to 11,726' to place the window in the Sag R. 2. Because of the lower window depth, the original plan to retain production from the existing Sag R. perfs is not feasible. Instead, the plan now is to cement off the existing Sag perfs. This will change the sidetrack name from MP F-33L1 to MP F-33a as the well will not be a multi-lat. This new operation, cementing off perfs, requires a Sundry Notice. This Sundry Notice was submitted to the AOGCC this afternoon. 3. The directional plan originally submitted under MP F-33L1 has been altered to avoid a fault crossing at the far end of the MP F-33L1 well plan. Avoiding this fault changes the BHL approx. 1140 ft from the BHL given in the original Permit to Drill, 201-057. A revised Permit to Drill application was submitted today with the new BHL. This change in BHL also eliminates the potential change in reservoir pressure that may have been encountered by crossing the fault as originally planned. The new lower expected reservoir pressures are given in the revised Permit application. SLB/Nordic is expected to move onto MP-F-33 about mid-day tomorrow. Actual drilling operations are not expected to start until Sunday 3/25/01, Please advise if further information is needed. Ted Stagg CT Drilling Eng, 564-4694 I of 1 3/22/01 4:40 PM bp MPF-33a Sidetrack Permit 201-057 was issued for MPF-33L1 on 3/15/01. This application is to revise the Permit due to a BHL chanqe~ a KOP change. Perfs will also be squeezed makinq this sidetrack MPF-33a rather than MPF-33L1. Summary of Operations: MPF-33 is a fraced Sag River producer that has declined to an uneconomic production rate. This sidetrack, F-33a, will be a horizontal Sag River producer that will be extend the Sag Completion interval to access new reserves. F-33a will be completed with a slotted liner. Prior to the coil sidetrack, rig 4ES will pull the existing ESP completion and install a new 4 ¥2" tubing string set up for a jet pump. Phase 1: (with SLB/Nordic) Drift, set whipstock, downsqueeze cmt. to shut off perfs (March 23) · MIRU SLB Nordic and test BOPE · RU e-line and drift with 3.65 dummy whipstock · Set thru-tubing whipstock on e-line at 11,726'. · Downsqueeze approx. 25 bbls bentonite cement to shut off perfs. Phase 2: Mill window, Drill and Complete sidetrack (with SLB/Nordic) Drilling coil will be used to mill the window and drill the directional hole as per attached plan. The sidetrack will be completed with a slotted liner. Top of 2 7/8" liner to be approx. 11,560' MD (8,570'ss). Mud Program: · Phase 1:8.5 ppg brine · Phase 2: FIo-Pro (8.6 to 8.7 ppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to KRU 1R Pad. · All Class I wastes will go to Pad 3 for disposal. Casing Program: · 2 7/8" slotted liner will be run from TD to approx. 11,560 (8,570ss). Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2000 psi. Directional · See attached directional plan. BHL (State Plane): 541,471; 6,044,129. Max. hole angle is 93 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD Gamma Ray Icg will be run over all of the open hole section. · A real time Resistivity will be run in open hole. RECEIVED Hazards · The highest H2S recorded to date on MPF Pad is less than 5 ppm. MAP, 2_ 2_ 2.001 · Lost circulation risk is Iow. Oil & Gas Cons. C0mmissio? aska · Length of hole to drill is high (2,726' with TD at 14,462') and may not be achievau'le. · Small faults may cause the wellbore to exit the Sag River formation. Anchorage Reservoir Pressure On 12/1/99 res. press, was measured at 3000 psi at 8700ss (6.6 ppg). Drilling will be done with 8.6 ppg fluid. Max. surface pressure with gas (0.12 psi/ft) to surface is 1956 psi, assuming 3000 psi pore pressure. Tree: 2 9/16" - 5M CIW Wellhead: 11" x 7" 5M FMC Gen 5A f' w/ 2 7/8" FMC Tbg Hng, 3" Acme lift threads on top and 2 7/8" 8 rd on bottom, 2.5" CIW H BPV profile Orig. DF Elev. = 29.14' (N 22E) MPF-33a Proposed Completion iv' ,g. GL Elev. = 11.4' L)F To 7" csg. hnr. = 28.6' (N 22E) 20" 91.1ppf, H-40 I 115' I KOP @ 25OO' Max. hole angle - 51 to 55 deg. f/4600' to 10,850' Hole angle thru' perfs - 45 deg DLS = 4.3 deg./100' @ 4350' Camco 2 7/8" x 1" sidepocket KBMM GLM 126' 9 5/8", 40 ppf L-80 Btrc. 4734' mdI 7", 26 ppf, L-80, Btrc. production casing ( drift ID = 6.151", cap. = 0.0383 bpf ) 4 1/2" Jet Pump tubing to be installed by 4ES prior to CTD sidetrack into Sag R. 4 1/2" WLEG approx. 11,600'. Top of 2 7/8" slotted liner approx. 11,560'. Mechanical whipstock to be set at approx. 11,726' for CTD sidetrack 4 1/2" X Nipple 7" x 20' short joint from11,587' toTM 11,607' wlm w/RA tag on top. 2 7/8" slotted liner to be installed in Sag R. lateral Perforation Summary Ref lo.q: CR / CCL 08/08/96 Size SPF Interval (TVD) Sa.q, River 3 3/8" 6 1,748'-11,788' (I ~741'-8770') 22 gm. Jumbo Jet charges (EHD = 0.76", TTP = 6.4") @ 135 / 45 deg. phasing Sag Perfs to be cement squeezed past the whipstock to shut off perfs ag River Completio, n '~J Last w/I tag 09/11/97 I 12168 7" float collar (PBTD) I 12282' I 7" float shoe 112363'I reiMS MPF-33 Vertical Section Path Distance (Feet) 0 500 1,000 1,500 2,000 2,500 3,000 8500 I t ~ I I 8550 MPF-33a case 105 March 22, 2001 Ted x4694 8600 8650 -TSAG 8667ss ,8700 Angle @ K.O.= 44 3,500 4,000 8750 4,500 880O 8850 8900 Tot Drld:2726 ft 14462 TD Marker Depths ~:)ri~l Wellbore TSAG 8667ss I 8,6671fl TVD 8,7101. TVD ~,~.1 8,735lf~ TVD 8,758lft TVD TSA IKick Off I 8,697lft TVD 11,736lft MD IDeprtr @KO 6,428 ft J MD KO Pt 11,736J MD New Hole 2726J I Total MD 14,462J TVD TD 8,723J DLS de~l/100 Tool Face Length Curve 1 35 10 142 Curve 2 10 -90 345 Curve 3 10 98 213 Curve 4 10 -90 270 Curve 5 12 90 320 Curve 6 12 -90 470 Curve 7 12 90 966 2,726 RECEIVED MAR 22 2001 Alaska Oil & G~s Cons. Commission Anchorage Drawn: 3/22/2001 13:09 Plan Name: Case 122 MPF-33 MPF-33a Case 105 March 22, 2001 Ted x4694 -2,500 -2,000 -1,500 -1,000 -500 X distance from Sfc Loc RECEIVED 22 ;!001 Aiask~ Oil & G~s Cons. Commission Anchorage 7,500 JWell Name MPF-33 J CLOSURE JDistance 8,783 ft Az 357 deg NEW HOLE E/W (X) N/S Of) Kick Off 264 6,407 TD -433 8,772 State Plane 541,471 6,044,129 iud'ace Loc 541,904 6,035,357 DIS deg/100 Tool Face Length Curve 1 ' 35 10 1~12 Curve 2 10 -90 345 Curve 3 10 98 213 Curve 4 10, -90 270 Curve 5 12 90 320 Curve 6 12 -90 470 Curve 7 12 90 966 2,726 Drawn: 3/22/2001 13:09 Plan Name: Case 122 _ 3/8" CT ~1 I I I lO,OOO psi Pack-Off MP F-33a CT Drilling & Completion BOP Blind/Shear 7 1/16" Pipe/Slip -" ~'- 2 318" 17j,~6,,xs..,oo. o..s. ,.i FLOW Pipe/Slips 2 3/8" SWAB OR MASTER VALVE I RECEIVED MAR 22 2001 ~,laska Oil & Gas Cons. Commission Anchorage WELL PERMIT CHECKLIST COMPANY WELL NAME /~".~ ~-'>/7 PROGRAM: exp __ dev / redrll __ serv wellbore seg __ann. disposal para req __ FIELD & POOL ,_~-?---~--/.,~'-~) INIT CLASS ADMINISTRATION 1. 2. APPR . 4. 5. 6. 7. 8. 9. 10. 11 DATE 12. ';' ~'~'0 / 13. Permit fee attached. Lease number appro~ri~t~. ' i~.'~:i ~',:?~'?.'-' :i~'~. ~ ~.~i"~..)/ Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. · Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg .... .... CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... GEOL AREA ,¢¢~.;) UNIT# ~")/~/.'_~ :~-~'" ON/OFFSHORE 14. Y Y N 15. 16. Y 17. Y 18. Y ~ ~~ ~,~ 19. ~N 22. Adequate wellbore separation proposed ............. 23. If dive,er required, does it meet regulations .......... 24. Drilling fluid program schematic & equiP list adequate ..... 25. BOPEs, do they meet regulation ........... ~ .... 26. BOPE press rating appropriate; test to ~¢~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Y~ 0~%~~ ~X~ ~~ ~~. ~X~ ~~ ~l ~~~ 30. ~ermit can be issued w/o hydro,on sulfide measures ..... Y 3~. Data presented on potential overpressure :,ones ....... 32. Seismic analysis of shallow ~as zones. .............. 33. Seabed condition su~ey (if off-shore) ........... 34. Contact name/phone for weekly pro~ress repo~s l, xpl~to~ ont~J Y ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y N APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: O Z 0 .-I rtl c:\msoffice\w°rdian\diana\checklist (rev. 11/01fl00) 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, informati;3n 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. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Dec 28 20:02:24 2001 Reel Header Service name ............. LISTPE Date ..................... 01/12/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 01/12/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Mitne Point MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: RUN 0 MPF-33A 500292268901 BP Exploration (Alaska), Inc. Sperry-Sun 28-DEC-01 MWD RUN 1 MWD RUN 2 AK-MW-10100 AK-MW-10100 S. LATZ S. LATZ SARBER/FEKET SARBER/FEKET JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 3 AK-MW-10100 S. LATZ SARBER/FEKET MWD RUN 4 MWD RUN 5 AK-MW-10100 AK-MW-10100 S. LATZ S. LATZ SARBER/FEKET SARBER/FEKET JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: MAD RUN 5 AK-MW-10100 S. LATZ SARBER/FEKET 6 13N 10E 1905 FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 2660 .00 40.54 11.40 REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 11726.0 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH SUBSEA(TVDSS). 3. MWD RUN 1 WAS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING SCINTILLATION DETECTORS. 4. MWD RUNS 2 - 5 WERE DIRECTIONAL, DUAL GAMMA RAY (DGR), AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . AFTER REACHING TD, MAD PASS DATA WERE ACQUIRED FROM TD TO ABOUT l1690'MD/8664'TVDSS. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS ACCOMPLISHED BY MEANS OF A BLOCK SHIFT OF 1 FOOT DOWNWARD, PER PHONE DISCUSSION BETWEEN D. SCHNORR (GEOQUEST/BP) AND B.BRYANT (SSDS) ON 12/19/01. DIGITAL DATA ONLY WERE SHIFTED.THIS WELL KICKS OFF FROM MPF-33 AT l1726'MD,8690'TVDSS. 6. MWD RUNS 1 - 5 REPRESENT WELL MPF-33A WITH API#: 50-029-22689-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14454'MD/8798'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED NATURAL GAMMA RAY. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). · SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPM RPX RPS FET RPD $ START DEPTH 11691 5 11728 0 11847 0 11847 0 11847 0 11847 0 11847 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: STOP DEPTH 14407 0 14454 0 14418 0 14418 0 14418 0 14418 0 14418 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 11690.5 11880.0 2 11880.0 12470.0 3 12470.0 13115.0 4 13115.0 13960.0 5 13960.0 14453.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 ~ 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 Name Service Unit Min Max DEPT FT 11691.5 14454 ROP MWD FT/H 0 2567.76 GR MWD API 37.44 315.3 RPX MWD OHMM 3.6 11.36 RPS MWD OHMM 3.56 11.23 RPM MWD OHMM 3.54 10.84 RPD MWD OHMM 3.79 10.84 FET MWD HOUR 0.31 13.62 Mean Nsam 13072.8 5526 93.9277 5453 88.5773 5432 6.85602 5143 6.90781 5143 6.86273 5143 7.13959 5143 1.64677 5143 First Reading 11691.5 11728 11691.5 11847 11847 11847 11847 11847 Last Reading 14454 14454 14407 14418 14418 14418 14418 14418 First Reading For Entire File .......... 11691.5 Last Reading For Entire File ........... 14454 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RPM RPD RPS RPX FET RAT $ MERGED DATA SOURCE PBU TOOL CODE MWD $ START DEPTH 11691.5 11701 5 11701 5 11701 5 11701 5 11701 5 11730 5 STOP DEPTH 14406.0 14417 0 14417 0 14417 0 14417 0 14417 0 14448 5 MAD RUN NO. MAD PASS NO. MERGE TOP 5 1 11691.5 MERGE BASE 14449.0 REMARKS: MERGED MAD PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 RAT MAD FT/H 4 1 68 GR MAD API 4 1 68 RPX MAD OHMM 4 1 68 RPS MAD OHMM 4 1 68 RPM MAD OHMM 4 1 68 RPD MAD OHMM 4 1 68 FET MAD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit DEPT FT RAT MAD FT/H GR MAD API RPX MAD 0HMM RPS MAD 0HMM RPM MAD OHMM RPD MAD OHMM FET MAD HOUR Min 11691.5 0 45 06 0 14 0 13 0 31 0 26 4 52 Max Mean 14448.5 13070 2567.76 92.9089 336.97 87.4594 2000 13.3296 2000 14.7007 2000 15.0506 2000 19.116 121.32 58.4095 Nsam 5515 5437 5430 5432 5432 5432 5432 5432 First Reading 11691 5 11730 5 11691 5 11701 5 11701 5 11701 5 11701 5 11701 5 Last Reading 14448.5 14448.5 14406 14417 14417 14417 14417 14417 First Reading For Entire File .......... 11691.5 Last Reading For Entire File ........... 14448.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name..,. Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NITMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11690.5 ROP 11727.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11849.0 11880.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP PCG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down 29-MAR-01 Insite 0.41 Memory 11880.0 44.0 84.0 TOOL NUMBER 033 3.750 11726.0 Flo-Pro 8.70 65.0 9.0 20000 9.0 188.0 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11690.5 11880 11785.3 380 ROP MWD010 FT/H 5.59 2179.18 324.86 307 GR MWD010 API 59.85 250.96 87.4854 318 First Reading 11690.5 11727 11690.5 Last Reading 11880 11880 11849 First Reading For Entire File .......... 11690.5 Last Reading For Entire File ........... 11880 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPM RPX RPS FET RPD GR ROP 11846.0 11846 0 11846 0 11846 0 11846 0 11849 5 11880 5 STOP DEPTH 12434.0 12434 0 12434 0 12439 0 12434 0 12423 0 12470 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 SUPER SLIM RES $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 30-MAR-01 Insite 0.41 Memory 12470.0 87.0 95.9 TOOL NUMBER 1853RF3 3.750 Flo-Pro 8.60 65.0 9.0 16000 7.0 .140 .060 .160 .150 68.0 171.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 OHMM OHMM OHMM OHMM HOUR 1 68 1 68 1 68 1 68 1 68 12 16 20 24 28 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR Min 11846 8 03 37 44 5 04 4 99 4 95 5 42 0 35 Max 12470 273 39 112 32 11 36 11 23 10 84 10 84 13 62 Mean Nsam 12158 1249 81.4993 1180 74.3056 1148 7.66019 1177 7.66007 1177 7.56281 1177 7.92245 1177 1.4776 1187 First Reading 11846 11880.5 11849.5 11846 11846 11846 11846 11846 Last Reading 12470 12470 12423 12434 12434 12434 12434 12439 First Reading For Entire File .......... 11846 Last Reading For Entire File ........... 12470 File Trailer Service name ............. STSLIBo004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIBo005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPX RPS RPM RPD ROP $ 12423.5 12434 0 12434 5 12434 5 12434 5 12434 5 12470 5 STOP DEPTH 13073 0 13079 0 13084 0 13084 0 13084 0 13084 0 13115 0 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 SUPER SLIM RES $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data'Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 31-MAR-01 Insite 0.41 Memory 13120.0 84.6 91.9 TOOL NUMBER 1862RF3 3.750 Flo-Pro 8.60 65.0 9.0 15900 7.0 .140 .060 .160 .150 68.0 177.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 RPD MWD030 FET MWD030 OHMM OHMM HOUR 1 68 1 68 1 68 20 24 28 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR Min 12423.5 0 56 91 5 01 5 17 4 96 4 09 0 51 Max 13115 2567.76 89.5 9.33 9.34 9.22 9.33 9.95 Mean Nsam 12769.3 1384 77.2038 1290 73.3016 1300 7.19494 1300 7.30732 1300 7.29417 1300 7.70431 1300 1.67655 1291 First Reading 12423 5 12470 5 12423 5 12434 5 12434 5 12434 5 12434 5 12434 Last Reading 13115 13115 13073 13084 13084 13084 13084 13079 First Reading For Entire File .......... 12423.5 Last Reading For Entire File ........... 13115 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPX RPS ROP $ 13073 5 13079 5 13084 5 13084 5 13084 5 13084 5 13115 5 LOG HEADER DATA DATE LOGGED: STOP DEPTH 13915.0 13926 0 13926 0 13926 0 13926 0 13926 0 13960 0 02-APR-01 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 SUPER SLIM RES $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Insite 0.41 Memory 13952.0 83.3 93.3 TOOL NUMBER 1862RF3 3.750 Flo-Pro 8.60 65.0 9.4 14400 4.0 .150 .060 .160 .170 68.0 180.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 Name Service Unit Min Max DEPT FT 13073.5 13960 ROP MWD040 FT/H 0 286.62 GR MWD040 API 57.87 315.3 RPX MWD040 OHMM 3.6 9.37 RPS MWD040 OHMM 3.56 8.47 RPM MWD040 OHMM 3.54 8.58 RPD MWD040 OHMM 3.79 8.69 FET MWD040 HOUR 0.31 10.19 Mean Nsam 13516.8 1774 79.1558 1690 104.777 1684 6.14581 1684 6.15885 1684 6.12752 1684 6.33161 1684 1.62211 1694 First Reading 13073 5 13115 5 13073 5 13084 5 13084 5 13084 5 13084 5 13079 5 Last Reading 13960 13960 13915 13926 13926 13926 13926 13926 First Reading For Entire File .......... 13073.5 Last Reading For Entire File ........... 13960 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 13915 5 13926 5 13926 5 13926 5 13926 5 13926 5 13960 5 SURFACE SOFTWARE VERSION: STOP DEPTH 14406.0 14417 0 14417 0 14417 0 14417 0 14417 0 14453 0 03-APR-01 Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 SUPER SLIM RES BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 0.41 Memory 14453.0 83.4 93.3 TOOL NUMBER 1862RF3 3.750 Flo-Pro 8.60 65.0 9.0 15600 7.0 .150 .060 .160 .170 68.0 183.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name Service Unit Min DEPT FT 13915.5 ROP MWD050 FT/H 0 GR MWD050 API 49.41 RPX MWD050 0HMM 5.9 RPS MWD050 OHMM 6.02 RPM MWD050 OHMM 5.87 RPD MWD050 OHMM 5.93 FET MWD050 HOUR 0.39 Max 14453 293 36 159 28 8 26 8 26 8 O8 8 11 11 88 Mean Nsam 14184.3 1076 84.0975 986 98.0568 982 6.66142 982 6.76207 982 6.71328 982 6.83923 982 1.85857 982 First Reading 13915 5 13960 5 13915 5 13926 5 13926 5 13926 5 13926 5 13926 5 Last Reading 14453 14453 14406 14417 14417 14417 14417 14417 First Reading For Entire File .......... 13915.5 Last Reading For Entire File ........... 14453 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 5 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX RAT $ LOG HEADER DATA DATE LOGGED: SOFTWARE 11690 5 11725 5 11725 5 11725 5 11725 5 11725 5 11729 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: STOP DEPTH 14405.0 14416 0 14416 0 14416 0 14416 0 14416 0 14447 5 03-APR-01 Insite 0.41 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 SUPER SLIM RES $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Memory 14448.0 83.4 93.3 TOOL NUMBER 1862RF3 3.750 Fto-Pro 8.60 65.0 9.0 15600 7.0 .150 .060 .160 .170 68.0 183.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RAT MAD051 FT/H 4 1 68 4 2 GR MAD051 API 4 1 68 8 3 RPX MAD051 OHMM 4 1 68 12 4 RPS MAD051 OHMM 4 1 68 16 5 RPM MAD051 OHMM 4 1 68 20 6 RPD MAD051 OHMM 4 1 68 24 7 FET MAD051 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 11690.5 14447.5 RAT MAD051 FT/H 0 2567.76 GR MAD051 API 45.06 336.97 RPX MAD051 OHMM 0.14 1810.84 RPS MAD051 OHMM 0.13 1950.32 RPM MAD051 OHMM 2.83 1910.82 RPD MAD051 OHMM 2.7 2000 FET MAD051 HOUR 4.52 121.32 Mean 13069 92.9089 87.4594 6.94751 7.6439 10.0295 10.0229 58.8253 Nsam 5515 5437 5430 5382 5382 5382 5382 5382 First Reading 11690 5 11729 5 11690 5 11725 5 11725 5 11725 5 11725 5 11725 5 Last Reading 14447.5 14447.5 14405 14416 14416 14416 14416 14416 First Reading For Entire File .......... 11690.5 Last Reading For Entire File ........... 14447.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/12/28 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/12/28 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 01/12/28 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File