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Home My WebLink About203-0521. 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: Install Temporary Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9,977'N/A Casing Collapse Conductor N/A Surface 2,480psi Intermediate 4,790psi Slot. Liner OA 7,500psi Slot. Liner OB 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 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:Ryan Thompson Contact Email: Contact Phone: Authorized Title: Wells Manager Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 4-1/2" 12.6 / L-80 / IBT 6,759' 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: AOGCC USE ONLY ryan.thompson@hilcorp.com 907-564-5005 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 9.2 / L-80 / TC-II 6,827' 7/1/2023 7" x 3.5" Baker Prem. & Baker ZXP LTP and N/A 6,771 MD/ 4,226 TVD & 6,996 MD/ 4,303 TVD and N/A See Schematic See Schematic 3-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380110 203-052 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23148-00-00 Hilcorp Alaska LLC SCHRADER BLUFF OIL N/A C.O. 477.05 MILNE PT UNIT S-04 Length Size Proposed Pools: 115' 115' TVD Burst PRESENT WELL CONDITION SUMMARY 4,337' 9,977' 4,337' 852 N/A 80' 20" MILNE POINT 8,430psi MD N/A 8,430psi 5,210psi 6,890psi 2,844' 4,340' 4,328' 2,844' 7,141' 4,337'9,975' 11,604' Perforation Depth MD (ft): 4-1/2"4,682' 2,845' 4-1/2" 10-34" 7-5/8" 2,810' 7,110' Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 10:36 am, Jun 26, 2023 323-361 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2023.06.22 13:53:07 - 08'00' Taylor Wellman (2143) DSR-6/28/23 10-404 MDG 6/26/2023 MGR30JUN2023 852 GCW 08/02/2023JLC 8/2/2023 08/02/23Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.08.02 13:56:56 -08'00' RBDMS JSB 080323 Well: MPS-04 PTD: 2030520 API: 50-029-23148-00 Well Name:MPU S-04 API Number:50-029-23148-00 Current Status:PWI Rig:SL Estimated Start Date:July 2023 Estimated Duration:2 Days Reg. Approval Req’d?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Tom Fouts Permit to Drill Number:2030520 First Call Engineer:Ryan Thompson 907-564-5005/907-301-1240 Second Call Engineer:Todd Sidoti 907-632-4113 AFE Number:Pending Current BHP:1252 psi – 4000’ TVD (6/8/23 SBHPS in offset injector MPS-03) MASP:852 psi (.1 psi/ft gas gradient) Last Recorded SI Surface Pressure:147 psi (Based on SI reading taken 6/9/2023) Minimum ID: 2.75” ID @ 6,822’ Max Deviation:93 deg. @ 8144’ Brief Well Summary: MPS-04 is a non- operable PWI well. The well failed a MIT-IA on 6/3/23. A PPPOT-T passed 6/4/23. The last intervention was 8/2/2018, the static toolstring fell to only 4000' @ 20 fpm at times. An Accoustic LDL was run on 5/2/11 with LLR <.5 bbl/min, locating a leak at 5410'. A caliper log was then run with max penetration of 38% @ 6055'. A one trip 45 KB patch was then set E to E @ 5400' - 5430'. Objective: Identify TxI leak location and patch accordingly. Assume 35+ feet for pulling 45 KB patch when rigging up lubricator. The well has a history of schmoo based on the most recent interventions. Procedure: Non-Sundried Steps Fullbore: 1. Rig up to the IA and establish LLR for LDL. Slickline / Fullbore 1. Perform Brush and Flush of 4 1/2" tubing down to 45 KB patch @ 5400'. Flag wire at top of patch. 2. RIH w/ ~2.4" GR & BLB, Continue B&F down to the TT @ 6827' (patch ID of 2.45"). 3. Assuming a LLR of >.5 bbl/min established in step 1, RIH w/ STP log pumping @ LLR down the IA to identify leak location. Run READ accoustic log if <.5 bbl/min. 4. Based on LDL findings, pull 1 trip 45 KB patch if necessary. Approved Sundry required before proceeding 5. Set 4 1/2" D&D patch across leak depth (~30' E to E). Set packers 2-3' away from collars. 6. MIT-IA to 1500 psi using AOGCC MIT criteria.30 minute charted test. -mgr Well: MPS-04 PTD: 2030520 API: 50-029-23148-00 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: NOT OPERABLE: MPS-04 (PTD #203-052) - Failed MIT-IA Date:Tuesday, June 6, 2023 8:45:24 AM From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, June 5, 2023 10:01 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov>; Regg, James B (OGC) <jim.regg@alaska.gov> Cc: David Haakinson <dhaakinson@hilcorp.com>; Taylor Wellman <twellman@hilcorp.com> Subject: NOT OPERABLE: MPS-04 (PTD #203-052) - Failed MIT-IA Mr. Wallace, On 6/3/2023, PWI well MPS-04 (PTD #203-052) had a pre-AOGCC 4 year MIT-IA performed with the well online. Upon pressuring up the IA to 1200 psi, the tubing showed pressure communication with the IA. The well was shut in and freeze protected at the conclusion of the MIT-IA attempt. The well is now classified as NOT OPERABLE, with follow up diagnostics to be performed. Please respond with any questions. Thanks, Ryan Thompson Milne / Islands Well Integrity Engineer 907-564-5005 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission n TO: Jim Regg I DATE: Thursday, June 13, 2019 SUBJECT: Mechanical Integrity Tests P.1.Supeervvisor y 1 HILCORP ALASKA LLC 5-04 FROM: Matt Herrera MILNE PT UNIT S-04 - Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J�IZ NON -CONFIDENTIAL Comm Well Name MILNE PT UNIT 5-04 Insp Num: mitMFH190610160600 Rel Insp Num: API Well Number 50-029-23148-00-00 Inspector Name: Matt Herrera Permit Number: 203-052-0 Inspection Date: 6/10/2019 Packer Depth We11 S-04 Tpe Inj w' TVD22?4 6 Tubing PTD 2030520Type Test SPT Test psio IA BBL Pump 09 BBL Returned OA Interval ` 4YRTST P/F P Notes: IA Pressure Tested to 1700 PSI Per Operator Pretest Initial 15 Min 30 Min 45 Min 60 Min 949 954 951 6]1 1724 1682 1669 323 432- 428- 427 Thursday, June 13, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 23,2015 TO: Jim Regg 'Refl bI 2GI „ P.I.Supervisor / r SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC S-04 FROM: Lou Grimaldi MILNE PT UNIT SB S-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Joe NON-CONFIDENTIAL Comm Well Name MILNE PT UNIT SB S-04 API Well Number 50-029-23148-00-00 Inspector Name: Lou Grimaldi Permit Number: 203-052-0 Inspection Date: 6/19/2015 Insp Num: mitLG150620082618 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well S-04 1Type Inj f W TVD l 4226 ' 1 Tubing 1125 1126 - 1125 1124 • - 1813 1778 •• 1766 - i PTD1 2030520 Type Testi SPT Test( psil 1500 IA 26a Interval 4YRTST P/F P V' OA 188 340342 - 3a5 - 1 Notes: 1.1 bbl's diesel pumped, 1.0 returned Good solid test All required paperwork supplied prior to test SCANNED ;; j .,,,f:1! Tuesday,June 23,2015 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ANIVE FEB 4 �c�;� December 30, 2011 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission ao 3 - Q 5L 333 West 7th Avenue Anchorage, Alaska 99501 S — 0 4- Subject: Corrosion Inhibitor Treatments of MPS -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPS -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, ,,,z Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPS -Pad 10/11/2011 Corrosion • Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # , API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal MPS-01A 2070340 50029231410100 025 NA 0.25 NA 5.1 9/6/2011 MPS-02 2031270 50029231690000 2.5 NA 2.5 NA 23.8 7/30/2011 MPS-03 2021460 50029231050000 Open Flutes - Treated `> MPS-04 2030520 50029231480000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-05 2021370 50029231000000 Open Flutes - Treated MPS-06 2031090 50029231630000 1.7 NA 1.7 NA 17.0 7/30/2011 MPS-07 2020720 50029230790000 1 NA 1 NA 13.6 11/3/2009 MPS-08 2031230 50029231680000 1.3 NA 1.3 NA 102 7/30/2011 MPS-09 2020200 50029230670000 0.5 NA 0.5 NA 5.1 11/3/2009 MPS -10A 2051250 50029231520100 1.3 NA 1.3 NA 11.9 7/29/2011 MPS -11 2021130 50029230920000 1 NA 1 NA 10.2 7/29/2011 MPS-12 2030230 50029231390000 0.6 NA 0.6 NA 6.8 7/29/2011 MPS -13 2021240 50029230930000 1 NA 1 NA 11.9 11/3/2009 MPS-14 2031040 50029231620000 1.8 NA 1.8 NA 22.1 729/2011 MPS -15 2012450 50029230610000 9.6 NA 9.6 NA 88.4 7/31/2011 MPS -16 2030650 50029231510000 1.2 NA 1.2 NA 10.2 7/29/2011 MPS -17 2021730 50029231150000 Open Flutes - Treated MPS -18 2022420 50029231330000 1.3 NA 1.3 NA 11.9 7292011 MPS -19A 2022330 50029231210100 1.8 NA 1.8 NA 23.8 7/29/2011 MPS-20 2022410 50029231320000 1.3 NA 1.3 NA 11.9 7/29/2011 MPS-21 2020090 50029230650000 1.8 NA 1.8 NA 22.1 11/3/2009 MPS -22 2031470 50029231760000 9.1 NA 9.1 NA 83.3 728/2011 MPS -23 2021320 50029230980000 Open Flutes - Treated MPS -24 2030380 50029231420000 1.3 NA 1.3 NA 10.2 7282011 MPS-25 2021030 50029230890000 Open Flutes - Treated MPS -26 2030610 50029231500000 1 NA 1 NA 8.5 7282011 MPS-27 2020850 50029230840000 0.9 NA 0.9 NA 8.5 7/28/2011 MPS -28 2030940 50029231580000 1.1 NA 1.1 NA 11.9 7282011 MPS -29 2021950 50029231190000 Open Flutes - Treated MPS -30 2022360 50029231310000 1.2 NA 12 NA 11.9 7/28/2011 MPS-31 2020140 50029230660000 Open Flutes - Treated MPS-32 2030920 50029231570000 0.8 NA 0.8 NA 6.8 7282011 MPS-33A 2061720 50029231230100 1 NA 1 NA 6.8 7/28/2011 MPS-34 2031300 50029231710000 6 NA 6 NA 49.3 7/28/2011 MPS -35 2031430 50029231750000 1.2 NA 12 NA 11.9 7/28/2011 MPS-37 2070520 50029233550000 13.9 Need top job NA MPS-39 2081830 50029234050000 0.7 NA 0.7 NA 4.3 8/18/2011 MPS -41A 2081610 50029234010100 Sealed NA NA NA NA NA MPS-43 2081760 50029234040000 Dust Cover NA NA NA 6.8 10/112011 MPS -90 2051350 50029232760000 0.6 NA 0.6 NA 3.4 9/6/2011 MPSB -04 500299990799 0.6 NA 0.6 NA 3.4 7/30/2011 June 2011 AOGCC MIT Forms Page 1 of 1 • Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Sunday, July 03, 2011 3:34 PM �(ll 70/k To: Maunder, Thomas E (DOA); Regg, James B (DOA)! Brooks, Phoebe L (DOA) Q(il 5 - -04 Cc: AK, D &C Well Integrity Coordinator Subject: June 2011 AOGCC MIT Forms I ZO3 052- Attachments: June 2011 MIT Forms.zip Tom, Jim, and Phoebe, Please find attached AOGCC MIT forms for the following wells: NK -23 (PTD # 1940350) LGI -10 (PTD # 1860690) W -11 (PTD # 1891070) P2 -09 (PTD #1980660) M -18B (PTD #1930540) W -210 (PTD # 2061850) P2 -15A (PTD # 2070320) M -28 (PTD #1860740) Z -12 (PTD #1891020) MPE -03 (PTD #1890170) R -13 (PTD #1830440) MPS -04 (PTD # 2030520) x 2 R -32A (PTD #1980090) 13 -09 (PTD # 1811580) S -06 (PTD #1821650) E -103 (PTD #2012000) V -121 (PTD # 2070360) LGI -02 (PTD # 1861400) x 2 V -215 (PTD #2070410) «June 2011 MIT Forms.zip» Thank you, Gerald Murphy (alt. Mehreen Vazir) JUL 20'11 Well Integrity Coordinator's 4 Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/12/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggpalaska.aov; doa. aoocc.prudhoe.bav(aialaska.gov; phoebe.brooksealaska.aov; tom.maundeaSalaska.aov OPERATOR: BP Exploration (Alaska), Inc. 'e q 7/ i FIELD / UNIT / PAD: Milne Point/ MPU/ S -Pad DATE: 06/07/11 OPERATOR REP: Kevin Parks AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPS -04 Type Inj. W ' TVD ' 4,226' Tubing 200 200 200 200 200 Interval 0 P.T.D. 2030520 ' Type test P Test psi ' 1500 Casing 2100 2200 - 2180 2160 2160- P/F P - Notes: Post tubing patch repair OA 220 500 500 500 500 Pressured u with 1.5 bbls Diesel ". Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type lnj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT MPU S 06 7 - 11.xls STATE OF ALASKA - ALASKAIDAND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 TUBING PATCH Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ 5400 -5430 Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ '' 203 -0520 3. Address: P.O. Box 196612 Stratigraphic Service p 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 23148 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 380110 - MPS -04 10. Field /Pool(s): •. MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 9977 feet Plugs (measured) None feet true vertical 4337.3 feet Junk (measured) None feet Effective Depth measured 9977 feet Packer (measured) 5398, 5424 6771 4226 feet true vertical 4337.3 feet (true vertical) 3643, 3655 4226 4301 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" X 34# 215.5# A53 35 - 115 35 - 115 Surface 2810' 10 -3/4" 45.5# L -80 34 - 2844 34 - 2844 .. •• 5210 2480 Production 7110' 7 -5/8" 29.7# L -80 31 - 7141 31 - 4340 6890 4790 Liner 2981' 4 -1/2" 12.6# L -80 6996 - 9977 4303 - 4337 8430 7500 Liner Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ Z ty ll True Vertical depth: _ - *L: NM j Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 30 - 6771 30 - 4226 3-1/2" 9.2# L -80 5400 - 5430 3644 - 3658 3-1/2" 9.2# L -80 6778 - 6827 4229 - 4247 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" KB Packer 5398 3643 4 -1/2" KB Packer 5424 3655 3 -1/2" Baker Premier Ret. Pkr 677 • 4226 4 -1/2" Baker ZXP Packer • `c■• 4301 12. Stimulation or cement squeeze summary: '. ,E "A Intervals treated (measured): k ;; 1, Treatment descriptions including volumes used and final pressure: i jj fl 7(1 r (111551�> t' vriOi' 13. Representat d Average Propitisaepr Injection Data Oil -Bbl Gas -Mcf Wa' TBbl Casing Pressure Tubing pressure Prior to well operation: 1080 1052 Subsequent to operation: 617 64 14. Attachments: 15. Well Class after work: ,, Copies of Logs and Surveys Run Exploratory Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work:_ Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ 0 WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -177 Contact Joe Lastufka Printed N- It Last �, + Title Petrotechnical Data Technologist Signal 1," Phone 564 -4091 Date 6/28/2011 lir Form 10 -404 Revised 10/2010 REBDMS JUN 2 9 1011 ` "\ (, -2 j . 1 (Submit Original Only MPS -04 203 -052 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS -04 5/7/03 SL 7,130. 9,975. 4,337.37 4,337.32 MPS -04 3/27/11 CKS 6,822. 9,975. 4,244.87 4,337.32 MPS -04 5/1/11 CKP 6,822. 9,975. 4,244.87 4,337.32 MPS -04 5/2/11 BPS 6,822. 9,975. 4,244.87 4,337.32 MPS -04 5/31/11 BPP 6,822. 9,975. 4,244.87 4,337.32 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 1111 • MPS-04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYPATE ,'' 6/5/2011 ***WELL SHUT IN ON ARRIVAL***ELINE(BAKER PATCH) INITIAL T/I/0=0/200/250 BAKER 4.5" PATCH -- ELEMENT TO ELEMENT=30'. MAX OD= 3.7" MIN ID= 2.45" AT EACH ELEMENT. PATCH SET ELEMENT TO ELEMENT 5400-5430' TOP OF PATCH= 5398' BOTTOM PATCH=5434.3' NOTIFY DSO SWAB/WING=CLOSED, MASTER = OPEN, IA/OA=OTG FINAL T/I/O= 0/200/250 ***JOB COMPLETE LEAVE LOCATION WELL SHUT IN*** 6/6/2011 T/I/O= 200/200/220. Temp= S/I MIT-IA to 2200psi. ***Job contd on 06-07-11 W S R*** 6/7/2011 *** Job contd from 06-06-11 WSR*** MIT-IA PASSED to 2200psi. (Tubing Patch) Pressured up IA w/ 1.5 bbls ambient Diesel. 2nd MIT lost 20 psi during both 15 min periods, and 0 psi loss during additional 15 min pressure monitor. Test deemed pass by PE. Bled IAP down. Bled back 2 bbls. FWHP's= 200/400/250. Pad Op notified. Well left shut-in upon departure. 6/19/2011 T/I/0=379/260/280 temp=104* AOGCC MIT IA 2200 psi PASS (witnessed by Bobl Noble), Pumped 1.9 bbls diesel down IA to reach test pressure. IA lost 65 psi in 15 min's, 20 psi in 2nd 15 min's, for a total loss of 85 psi in 30 min's. Bled back +/- 2 bbls. **Well online on departure, IA, 0A= open** FWHP's= 370/200/300 FLUIDS PUMPED BBLS 4.5 DIESEL 4.5 TOTAL Tree: 4- 1/16" - 5M FMC Orig. KB .= 72.25' (Doyon 14) Wellhead: 11" x 4.5" 5M Gen 6 • MPS -04 Orig. GL. .= 38.30' (Doyon 14) w/ 4.5" TCII T &B Tubing Hanger 4" CIW "H" BPV profile KOP @ 600' 20" x 34" insulated, 215 #/ft A -53 I 80' 1 60+ degree from 2800' Max hole angle = 68 degree @ 6722' 68 degree © Sleeve ti - Camco 4.5" x 1" w/ BK -5 latch 2106` sidepocket KGB -2 GLM 10 3/4" 45.5 ppf L -80 BTC (Drift ID = 9.794, cap. = .0961 bpf) , ■ 10 3/4" Super Seal II Float Shoe 1 2843' Tbg patch minimum ID is 2.450" 4.5" x 3.5 X -Over @ 6778` No -Go ID of XN nipple 2.750" @'6822' 7 5/8" 29.7 ppf, L -80, BTC -Mod production casing ( drift ID = 6.750", cap. = 0.0459 bpf) BHC Assembly w/ 13/64" choke. 1 5397' 4 1/2" fish neck Drawing in well file 4.5 ", 12.6 #, L -80 IBT tbg. � �~ % / Baker 'KB' Patch. ( 5398' 1 ''') ( cap. = .0152 bpf, id = 3.958) Elements set © 5400' & 5430' 3.5 ", 9.2# L-80 NSCT tbg. Minimum ID = 2.45" a w - Phoenix Discharge gauge (3.850 ID) 1 6,711' 1 a wm 1 p 4.5" HES XD Dura sliding sleeve 1 6,721'1 t — I NOTE: ID change min. 2.840 1 ®� Phoenix gauge ( 2.840" ID) (4060' TVD) ( 6,745' I Pq 4.5" x 3.5" X -Over 1 6,759` 3.5 HES X- Nipple (2.813 ID) 1 6,761' c," - 7" x 3.5" Baker Premier Packer 1 6,771` 1 3.5" HES XN- Nipple 1 6,822` ( 2.813 packing bore 2.750" No Go ID) WLEG 1 6,827' 1 Baker Tie Back Sleeve 6,837' Baker Hook Wall Hanger inside 7" Window 6,845' B H Hanger aker outsiook de Wall 7" Window 6,871' Window in 7" Casing @ 6,859' - 6,871' s 1 /8° Hole td @ 11,737' Well Angle @ window = 69° ______!- 113 jts. - 4 1/2" R3 Slotted Liner Rat Hole OA Upper Lateral 12.6# L -80 IBT (6,922'- 11,604') sa' Btm Baker 4 1/2 "Guide Shoe 11,644' Baker Tie Back Sleeve 6,982' Baker ZXP Liner Top Packer 6,990' Baker 7 -5/8" x 5 -1/2" HMC Liner Hanger 6,996' A 7 5/8" Halliburton Float Collar 7,058' 6 1/8" Hole td @ 9,977' 7 5/8" Halliburton Float Shoe 7,141' OB Lower Lateral 69 jts. - 41/2 ", 12.6# L -80, IBT Slotted Liner (7,130`- 9,975') 411 1 Btm Baker 4 1/2 " 'V" Float Shoe 9,977' DATE REV. BY COMMENTS MILNE POINT UNIT 05/16/03 MDO Drilled & Completed Doyon 14 WELL S-04 06/05/11 Hulme Tbg patch installed API NO: 50 - 029 - 23148 - L1 API NO: 50- 029 - 23148 -00 1 BP EXPLORATION (AK) • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2 DATE: Wednesday, June 22, 2011 P.I. Supervisor ` ( �� /,( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -04 FROM: Bob Noble MILNE PT UNIT SB S -04 , Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S - 04 API Well Number: 50 029 - 23148 - 00 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110621144327 Permit Number: 203 - 052 - Inspection Date: 6/19/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I s -o4 '' Type Inj. ' W f TVD 4226 • IA 260 2235 - 2170 2150 - P.T.D 2030520' TypeTest SPT Test psi 2235 - j OA 280 500 500 500 Interval OTHER - p/F P ' Tubing 379 379 379 379 Notes: Post tubing patch MIT -IA l tc,j _ red -k -- i s - tA *5 Wednesday, June 22, 2011 Page 1 of 1 OPERABLE: MPS -04 (PTD #2030520) Tubing Integrity Restored with Tubing Patch Page 1 of 3 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] Sent: Wednesday, June 08, 2011 8:43 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J (Swift) Subject: OPERABLE: MPS -04 (PTD #2030520) Tubing Integrity Restored with Tubing Patch Attachments: MIT MPU MPS -04 06- 7- 11.xis; MPS -04 (PTD #2030520) wellbore schematic.pdf All, Produced water injector MPS -04 (PTD #2030520) passed a MIT -IA to 2100 psi on 06/07/2011 after the installation of a tubing patch in the wellbore. The passing test confirms the presence of two competent barriers in the wellbore. The well is reclassified as Operable. Plan forward: 1. Fullbore: Perform an AOGCC witnessed test once the well is put on back on injection and is thermally stable. Please be aware of the fluid packed annuli when beginning injection to avoid annular fluid expansion. A copy of the MIT -IA and wellbore schematic are included for reference. «MIT MPU MPS -04 06- 7- 11.xls» «MPS -04 (PM #2030520) . -More schematic.pdf» Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 5 JUN U i Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Tuesday, May 03, 2011 10:33 AM To: 'Maunder, Thomas E (DOA); 'Regg, James B (DOA); 'Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU j Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Igbokwe, Chidiebere Cc: King, Whitney; Murphy, Gerald L Subject: NOT OPERABLE: MPS -04 (PTD #2030520) Failed MIT -IA All, 6/13/2011 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa(5alaskagov; doa .aocicc.prudhoebay(Talaska.ctov; phoebe.brooksealaskaciov: tom.maunder(5alaska.aov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Milne Point/ MPU/ S-Pad DATE: 06/07/11 OPERATOR REP: Kevin Parks AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well MPS -04 Type Inj. N TVD 4,226' Tubing 200 200 200 200 200 Interval 4 P.T.D. 2030520 Type test P Test psi 1500 Casing 2100 2200 _ 2180 2160 2160 P/F P Notes: OA 480 500 500 500 500 Pressured u with 2.2 bbls Diesel Well Type Inj. TVD Tubing Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/• Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test_ Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Intemal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06 /2010) MIT MPU MPS - 04 06 7 - 11.xls • • SIM 'TEE LIIF ALASEn. SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Chidiebere Igbokwe Petroleum Engineer BP Exploration (Alaska), Inc. 2-- P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPS -04 Sundry Number: 311 -177 Dear Mr. Igbokwe: tidgt JUN ' 2.01i Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0/ Daniel T. Seamount, Jr. Chair DATED this - day of May, 2011. Encl. • STATE OF ALASKA it \ RECEIVED) ALASKA •AND GAS CONSERVATION COMMISSION 'tiiAY 2 4 ,O1'+ -, APPLICATION FOR SUNDRY APPROVALS ,51.26-/, 20 AAC 25.280 A1S.ska Oil & Gax C n6. Calidfillajon 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑ Changan ar�iogram ❑ Suspend ❑ Plug Perforations ❑ Perforate"' Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate"' Alter Casing ❑ Other: TUBING PATCH 5400 - 5430 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 203 -0520 3. Address: P.O. Box 196612 Stratigraphic ❑ Service o , 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 23148- 00 -00, 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ MPS -04 ' 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 380110, MILNE POINT Field / SCHRADER BLUFF Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9977 - 4337.3 - 9977- 4337.3 - 6822 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20 "X34" 215.5# A -53 35 115 35 115 1 Surface 2810' 10 -3/4" 45.5# L -80 34 2844 34 2844 5210 2480 Production 7110' 7 -5/8" 29.7# L -80 31 7141 31 4340 6890 4790 Liner 2981' 4 -1/2" 12.6# L -80 6996 9977 4303 4337 8430 7500 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 30 6771 - - 3 -1/2" 9.2# L -80 6778 6827 Packers and SSSV Tvoe: 3 -1/2" Baker Premier Ret. Pkr Packers and SSSV MD and ND (ft): 6771 4226 4 -1/2" Baker ZXP Packer 6990 4301 12. Attachments: Description Summary of Proposal gg 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service El - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/6/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ID - GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chidiebere lgbokwe Printed Name hidiebere I bo a Title PE Signature Phone Date 564 -4795 5/23/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5t 1'- 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Nr Location Clearance ❑ Other: Subsequent Form Required: /6 4/0'1 APPROVED BY Approved by: i ll OMMISSIONER THE COMMISSION Date: 5/ /1 f R DMS MAY 1 i1 A „l - , ,4 5-.2.0.// Form 10 -403 Revised 1/2010 ( � Submit in Duplicate MPS -04 203 -052 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS -04 5/7/03 SL 7,130. 9,975. 4,337.37 4,337.32 MPS -04L1 5/11/03 OH 11,645. 11,737. 4,327.37 4,326.46 MPS -04L1 5/11/03 SL 6,922. 11,604. 4,275.7 4,327.64 MPS -04 3/27/11 CKS 6,822. 9,975. 4,244.87 4,337.32 MPS -04 5/1/11 CKP 6,822. 9,975. 4,244.87 4,337.32 MPS -04 5/2/11 BPS 6,822. 9,975. 4,244.87 4,337.32 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET • FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • by 0 To: M. O'Malley /Rob Handy, MPU Well Ops Supervisor May 19, 2011 From: Chidi lgbokwe — S -Pad production Engineer Subject: MPS -04 Patch Est. Cost AMSSPDWL04 IOR: 80 BOPD Step Unit Operation 1 S Pull TTP @ 6822' MD & drift with dummy patch 2 E Set 30' 4.5" Baker Patch (2.45" ID) from 5400' -5430' and (leak @ 5410' md) Current Status: SI Injector Injection Rate: 04/23/2011 — 1142 bwpd @ 1158 WHIP (w/ DHC installed) Maximum Deviation: 70 at 6916' MD ( »70 deg in liner) Minimum ID: 2.750" — XN nipple at 6822' MD Last TD Tag: Tagged 7063' ctmd (top of IBP) ahead of IBP (10/02/2008) Last Downhole Operation: 05/06/2011 — MTT & Caliper Last BHP & BHT: 02/28/2011 — 1590 psi @ 4,000' TVD /81 deg F. Latest H2S: <2 ppm maximum measured on pad Objective Set a patch over a leak found at 5410' MD. Tie in log: PDS Leak Detection — WLD (aka TecWeL) run on May 02, 2011. Background MPS -04 was drilled and completed in May 2003 as a jet - pumped dual lateral completion into the OA (upper lateral) and OB (lower lateral) sands. MPS -04 started out as a good producer with rates above 500 bbls but quickly dropped off to 200 bbls in less than a year post initial POP. MPS -04 also produced at nearly 0% WC until an MBE was first sighted in 2004 followed by a dramatic water breakthrough in 2007 with water cut going to —90 %. A polymer treatment to remediate catastrophic water breakthrough between MPS -09i LS and MPS -04's OB lateral was executed in August, 2008 but was not very successful. MPS -04 was converted at surface to an injector and put on injection in Mar, 2011 to support HU -15 OA/OB offlakes. Unfortunately a TecWel LDL showed MPS -04 had a hole in the tubing @ 5410' MD after the well showed signs of TxIA shortly after setting a DHC to keep the well from going on safety defeated log. It is note worthy to mention that the caliper showed the tubing was in good shape especially around the vicinity of the hole ( and — 30 -38% penetration much deeper downhole) so corrosion mechanism is thought to be external. However, a patch set is required in order to return the well back in operation. 1 . • • Patch Procedure Slickline 1. Pull XXN plug @ 6822' MD 2. Drift to 6700' MD with -30' dummy patch ahead of E -line 4.5" (2.45" ID) patch set. 3. RDMO. E -line • Baker Oil Tools Contact: Alan Holloway or John Milne @ 907 - 659 -2367. • All equipment is available from Baker. Run a BOT patch (packing elements and spacer pipe) unless not available 4. RU EL. RIH with 30' Baker retrievable patch. (Tie in to PDS LDL -WLD aka TecWeL run on May 2, 2011, see expanded view below) 5. Set 30' Baker retrievable patch (2.45" ID) from 5400' - 5430' MD. 6. Perform MIT -IA to 2200 psi 7. Put well back on injection. Contacts: Chidi Igbokwe at 907.564.4795 (W) or 907.222.2854 (H) or (206)- 790 -2449 (M) Note: A nipple reducer was considered but determined not ideal due to cross -over to 3.5" requiring a very small nipple reducer (which only allows -1.45" or less plug set). An IBP may be used in lieu of TTplug set for securing the well for future pressure tests on the tubing or combo. cc: w /a: Well File 2 . , • • .. Tbg = 450 psi — IA = 2,250 psi -- OA = 150 psi PRoAcTivE DiNtrastic SERVICCS, INC. Database File: dAwarrior\data\mps-04_1d1\main_3.db Dataset Pathname: main.rep Presentation Format: wld_log Dataset Creation: Mon May 02 15:03:58 2011 by Calc Warrior 8.0 STD Cas Charted by: Depth in Feet scaled 1:240 7000 CCL -765 60 Temperature (degF) 80 0 Line Speed (ft/min) -200 -3 Differential Temperature (degF) 1 0 Temperature (degF) 200 0 WLD-A 2e+006 0 WLD-B 2e+006 0 WLD-C 2e+006 ECCL • ..._ . \ t i i \ 1 s - ._ . 1 ; _ . . .., Line Speed , . . .. Temperature Temperature —401 ._......______. f .... . .. _ . : Differential Temperature 4 1 \ , WLD-A S P — LD-B .,/ ------. . ...h........ - - *-1.2.. t , 1 1 , WLD-C , , . . ' . ,..... ' 4 • , . t I • , . , . . ... , . . • Tie-In Log: PDS LDL-WLD aka TecWeL run 05/02/2011 I 1 • Patch Set Depth: 5400'- 5430' MD ` - - - - .., • ' 4 ' 1 - - 4 ,--- .i - I i ,, , .... . . 1 *- • .....- 3 w .. • Tree 4 - 1/16" - 5M Tree � �� Orig. KB elev. = 72.25' (Doyon 14) Wellhead: 11" x 4.5" 5M Gen 6 Orig. GL. elev.= 38.30' (Doyon 14) w/ 4.5" TCII T &B Tubing Hanger 4" CIW "H" BPV profile 20" x 34" insulated, 215 #!ft A -53 1 80' i PA Camco 4.5" x 1" w/ BK -5 latch I 2106' sidepocket KGB -2 GLM 10 3/4" Super Seal II Float Shoe 2843 A ' KOP @ 600` 60+ degree from 2800' Max hole angle = 68 degree @ 6722' 10 3/4" 45.5 ppf L -80 BTRC 68 degree @ Sleeve (Drift ID = 9.794, cap. = .0961 bpf) 7 5/8' 29.7 ppf. L -80, BTRC -mod production casing ( drift ID = 6.750 ", cap. = 0.0459 bpf) 4 .5" x 3.5" X -Over @ 6778 4.5 ", 12.6 #, L - 80 IBT tbg. No -Go ID of XN nipple 2.750" @ 6822' ( cap. = .0152 bpf, id =3.958 ) 3.5 ", 9 -2# L -80 NSCT tbg �//�� ( cap. = .0087 bpf, id 2.992) �-'—'� 7 /y e ggto Phoenix Discharge gauge (3.850 ID) 1 6,711 `I 1 ',1,100 1 4.5" HES XD Dura sliding sleeve 6,721'1 - ! NOTE: ID change min. 2.840" �� Phoenix gauge ( 2.840" ID) (4060' TVD) 1 6,745' _______9 . -. 4.5" x 3.5" X -Over 1 6,759' 1 mi 3.5 HES X- Nipple {2.813 ID} 1 6,761 ' I 7" x 3.5" Baker Premier Packer ( 6,771' 3.5" HES XN- Nipple 1 6,822` I ( 2.813 packing bore 2.750" No Go ID) WLEG 1 6,827' Baker Tie Back Sleeve 6,837' Baker Hook Wall Hanger inside 7" Window 6,845' B H Wl Hanger aker outsi de al 7" Window 6,871" Window in 7" Casing @ 6,859' - 6,871' Well Angle @ window = 69° 6 1!8" Hole td @ 11,737' 113 jts. - 4 1/2" R3 Slotted Liner Rat Hole OA Upper Lateral 12.6# L -80 IBT (6,922` - 11,604') 93 Btm Baker 4 1/2" Guide Shoe 11.644' Baker Tie Back Sleeve 6,982' Baker ZXP Liner Top Packer 6,990' Baker 7 -5/8" x 5 -1/2" HMG Liner Hanger 6,996' A ' 7 5/8 " Halliburton Float Collar 7,058' 6 1/8" Hole td @ 9,977' 7 5/8" Halliburton Float Shoe 7,141' 08 Lower Lateral 69 jts. - 4 1!2 ", 12.6# IBT Slotted Liner (7,130'- - 9,9 9,975') Btm Baker 4 112' "V" Float Shoe 9,277' DATE REV. BY COMMENTS MILNE POINT UNIT 05/16/03 MDO Drilled & Completed Doyon 14 WELL S -04 API NO: 50- 029 - 23148 -60 L1 API NO: 50 -029- 23148 -00 BP EXPLORATION (AK) 4 • • WELL LOG TRANSMITTAL _ _ PROACTIVE DiAgnoslic SERVICES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka MAY 2 LR2 - 1 s� 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C e903 9 Anchorage, AK 99518 Fax: (907) 245 -8952 �3 1) Leak Detection - WLD 02 -May -1 1 MPU S -04 BL / EDE 50-029 - 23148 -00 2) Signed : Oat- . Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 Fax: (907)245- 88952 E -MAIL: o,',.Js:a^: halagerginemo ."I c'c. Grin WEBSITE::^i'.n,^. v.,T: arine" - a'?C?....^e3:"s C:\Documents and Settings\Diane Williams\Desktop\BP _Transmit -docx NOT OPERABLE: MPS -04 (PTD 630520) Failed MIT -IA Page 1 of 2 • Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIllntegrityCoordinator @bp.com] Sent: Tuesday, May 03, 2011 10:33 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, OPS MPU Control Room; Igbokwe, Chidiebere Cc: King, Whitney; Murphy, Gerald L Subject: NOT OPERABLE: MPS -04 (PTD #2030520) Failed MIT -IA All, Injector MPS -04 (PTD #2030520) failed an MIT -IA on 5/2/11. A Tecwel LDL was run and identified a hole in the tubing at 5411'. The well has been secured with a TTP and is reclassified as Not Operable. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com R,. ,AQ From: AK, D &C Well Integrity Coordinator Sent: Sunday, April 10, 2011 8:24 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS MPU OSM; AK, OPS MPU Field Ops TL; AK, OPS MPU Wells Ops Coord 2; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; Cismoski, Doug A; Engel, Harry R; Daniel, Ryan; AK, OPS MPU Control Room; Igbokwe, Chidiebere Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Quy, Tiffany Subject: UNDER EVALUATION: MPS -04 (PTD #2030520) Repressurization After IA Bleed All, Produced water injector MPS -04 (PTD #2030520) exhibited repressurization of the IA after being bled on 4/9/2011. MPS -04 was converted from a producer to an injector in March of 2011 and passed an AOGCC witnessed MIT -IA to 2190 psi on 3/20/2011. A downhole choke was set on 3/26/2011 increasing the injection pressure on the tubing. After the well had stabilized injection, pressure on the IA was bled and overnight repressurization was observed. The well is reclassified as Under Evaluation and may remain on injection while diagnostics are performed to evaluate the tubing integrity. Plan forward: 1. Wellhead: Positive Pressure Packoff Test - Tubing (PPPOT -T) 2. DHD: Bleed IAP and monitor for repressurization for 10 days 5/3/2011 NOT OPERABLE: MPS -04 (PTD 630520) Failed MIT -IA • Page 2 of 2 3. Slickline: Set tubing tail plug and MIT -T (pending results of step 2) 4. Slickline /E -line: Leak Detect Log (pending results of step and 3) A TIO plot, injection plot and wellbore schematic are included for reference. « File: Injector MPS -04 (PTD #2030520) TIO and Injection Plot.doc » Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 5/3/2011 • Injector MPS -04 (PTD #2030520) TIO Plot Well MPS -04 oro -�- IA -S--w z UUO - • oa 00a + 000A On 1.000 - 01/15/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/26/11 03/05/11 03/12/11 03/13 /11 03/26/11 04/02/11 04/09/11 Injector MPS -04 (PTD #2030520) Injection Plot Well MPS -04 1,300 - 1 400 1200 - 1.100 - 1 200 1.000 - 900 - 1 WHIP SW I 700 - 800 ° ... HN - 600 GI -600 500 °the, On 400 400 300 200 200 100 - i Y 01/15/11 01/22/11 01/29/11 02/05/11 02/12/11 02/19/11 02/26/11 03/05/11 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 Tree; 4- 1/16" - 5M FMC Orig. KB elev. = 72.25' (Doyon 14) Wellhead: 11" x 4.5" 5M Gen 6 0 MPS -04 Orig. Gl v.= 38.30' (Doyon 14) w/ 4.5" TCII T &B Tubing Hanger � ! • 4" CIW "H" BPV profile L 20" x 34" insulated, 215 #/ft A -53 I 80' 1 Camco 4.5" x 1" w/ BK -5 latch 2106' sidepocket KGB -2 GLM / 10 3/4" Super Seal II Float Shoe I 2843' I , ■ KOP @ 600' 60+ degree from 2800' Max hole angle = 68 degree @ 6722' 10 3/4" 45.5 ppf L -80 BTRC 68 degree @ Sleeve (Drift ID = 9.794, cap. = .0961 bpf) 7 5/8" 29.7 ppf, L -80, BTRC -mod production casing ( drift ID = 6.750 ", cap. = 0.0459 bpf ) 4.5" x 3.5" X -Over @ 6778' 4.5 ", 12.6 #, L -80 IBT tbg. No -Go ID of XN nipple 2.750" @ 6822' ( cap. = .0152 bpf, id =3.958 ) 3.5 ", 9.2# L -80 NSCT tbg. ( cap. = .0087 bpf, id 2.992 ) «� .- Phoenix Discharge gauge (3.850 ID) 1 6,711' r ,l 'I I 1 .r.... '=1 $ • it ' ` ®® 4.5" HES XD Dura sliding sleeve 6,721' I i i 1 I NOTE: ID change min. 2.840" Phoenix gauge (2.840" ID (4060` TVD) 6,745' ril 'l I I I 4.5" x 3.5" X -Over 6,759' ,, ..„ " 3.5 HES X- Nipple (2.813 ID) 1 6,761' 7" x 3.5" Baker Premier Packer 1 6,771' \l 3.5" HES XN- Nipple 6,822' I ( 2.813 packing bore 2.750" No Go ID) WLEG 6,827' Baker Tie Back Sleeve 6,837' Baker Hook Wall Hanger inside 7" Window 6,845' Bak Hook Wall Han ger outside 7" Window 6,871' Window in 7" Casing @ 6,859' - 6,871' Well Angle @ window - 69° 6 1/8" Hole td @ 11 4 113 jts. - 4 1/2" R3 Slotted Liner Rat Hole OA Upper Lateral 12.6# L -80 IBT (6,922`- 11,604') 93' Btm Baker 4 1/2" Guide Shoe 11,644' Baker Tie Back Sleeve 6,982' Baker ZXP Liner Top Packer 6,990' Baker 7 -5/8" x 5 -1/2" HMC Liner Hanger 6,996' A 7 5/8" Halliburton Float Collar 7,058 ' 6 1/8" Hole td © 9,977' 7 5/8" Halliburton Float Shoe 7,141' OB Lower Lateral 69 jts. - 4 1/2", 12.6# L -80, IBT Slotted Liner (7,130'- 9,975') Btm Baker 4 1/2" "V" Float Shoe 9,977' DATE REV. BY COMMENTS MILNE POINT UNIT 05/16/03 MDO Drilled & Completed Doyon 14 WELL S -04 API NO: 50- 029 - 23148 -60 L1 API NO: 50- 029 - 23148 -00 BP EXPLORATION (AK) STATE OF ALASKA ¢ ALASKA AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 CONVERT TO WINJ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ • 203 -0520 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 23148 -00 -00 8. Property Designation (Lease Number) : N 9. Well Name and Number: ADLO- 380110 v MPS -04 10. Field /Pool(s): MILNE POINT FIELD / SCHRADER BLUFF POOL 11. Present Well Condition Summary: Total Depth measured 9977 feet Plugs (measured) None feet true vertical 4337.3 feet Junk (measured) None feet Effective Depth measured 9977 feet Packer (measured) 6771 6990 feet true vertical 4337.3 feet (true vertical) 4226 4301 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20 "X34" 215.5# A -53 35 - 115 35 - 115 Surface 2810' 10 -3/4" 45.5# L -80 34 - 2844 34 - 2481 5210 2480 Production 7110' 7 -5/8" 29.7# L -80 31 - 7141 31 - 4340 6890 4790 Liner 2981' 4 -1/2" 12.6# L -80 6996 - 9977 4303 - 4337 8430 7500 Liner Liner �� Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 30 - 6771 30 - 4226 3 -1/2" 9.2# L -80 6778 -6827 4229 - 4247 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" Baker Premier Ret. Pkr 4 6771 \+4226 4 -1/2" Baker ZXP Packer 6990 4301 • 12. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): \ PP ) 6 2011 Treatment descriptions including volumes used and final pressure: ask/ ?r " y ens. Commission 13. Representative Daily Average.PNoduction or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 38 3 1271 239 Subsequent to operation: 1074 176 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ISI ' WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -238 Contact Joe Lastufka Printed Nam - astufk. w; `` Title Data Manager Signaturo Phone 564 -4091 Date 4/5/2011 1111 APR q 1 Form 10-404 Revised 10/2�'I 8DMS APR 0 6 2011 ��1 j � 444 W // Submit Original Only Ate MPS -04 203 -052 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPS -04 5/7/03 SL 7,130. 9,975. 4,337.37 4,337.32 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 4111 • • • MPS -04 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY was w 1/29/2011 Flush Prod. Lateral and Power Fluid line for demobe. Pump 1 bbls towards Power Fluid Header. Pump 4 bbls 60/40 meth, 6 bbls 90 *F diesel and 4 bbls 60/40 meth Idown Power Fluid Linejumpered to Production Lat. line towards main header. Bleed lines to zero. Notified Operator. Hang F/P Tags. Operator has control of well valves @ LRS departure. 3/3/2011 IT /I /O/ = 30/350/500 Bleed OA. Bled OA from 500 psi to 150 psi in 2 minutes and less 'than a 1/2 bbl fluid. Final WHP'S = 30/350/150 � a 3/20/2011 TWO = 190/680/260. MITIA PASSED to 2190psi. AOGCC witnessed by Chuck Scheve. Pressured up w/ 1.2bbls diesel. IA lost 30psi 1st 15min, 10psi 2nd 15min, for a total of 40psi in 30min. FWHP's = 200/2190/400. Well turned over to PE and wells support. E � I 3 9 { 3 7 FLUIDS PUMPED BBLS 1.2 DIESEL 1.2 TOTAL • . Tree; 4 - 1/16" - 5M FMC • • Orig. KB v. 72.25' (Doyon 14) Wellhead: 11" x 4.5" 5M Gen 6 MPS -04 Orig. G .= 38.30' (Doyon 14) w/ 4.5" TCII T &B Tubing Hanger - 4" CIW "H" BPV profile 20" x 34" insulated, 215 #/ft A -53 1 80' e Camco 4.5" x 1 "w/ BK -5 latch 2106' sidepocket KGB -2 GLM 10 3/4" Super Seal II Float Shoe ( 2843'1 , ■ KOP @ 600' 60+ degree from 2800' Max hole angle = 68 degree @ 6722' 10 3/4" 45.5 ppf L -80 BTRC 68 degree © Sleeve (Drift ID = 9.794, cap. = .0961 bpf) , 7 5/8" 29.7 ppf, L -80, BTRC -mod production casing ' ( drift ID = 6.750 ", cap. = 0.0459 bpf) , f 4.5 " x 3.5 X -Over @ 6778 4.5 ",12.6 #, L - 80 IBT tbg. d = No-Go ID of XN nipple 2.750" @ 6822', ( cap. = .0152 bpf, id =3.958 ) 3.5 ", 9.2# L -80 NSCT tbg. I y ( cap. = .0087 bpf, id 2.992) Phoenix Discharge gauge (3.850 ID) 1 6,711'1 ) ` � � 4.5" HES XD Dura sliding sleeve 6,721' d ! Pho NOTE: gauge ID cha 40 min. " ID) 2.840 0` ); TVD) 6,745' �- 4.5" x 3.5" X -Over 1 6,759' 1 3.5 HES X- Nipple (2.813 ID) ( 6,761' 7" x 3.5" Baker Premier Packer 6,771'1 I 3.5" HES XN- Nipple 1 6,822` 1 rim ( 2.813 packing bore 2.750" No Go ID) WLEG ( 6,827' Baker Tie Back Sleeve 6,837' Baker Hook Wall Hanger inside 7" Window 6,845' B Hook Wall Hanger aker outside 7" Window 6,871' Window in 7" Casing @ 6,859' - 6,871' 6 1/8" Hole td @ 11,737' Well Angle @ window = 69° 113 jts. - 4 1/2" R3 Slotted Liner Rat Hole OA Upper Lateral 12.6# L -80 IBT (6,922'- 11,604') s3' Btm Baker 4 1/2" Guide Shoe 11,644' Baker Tie Back Sleeve 6,982' Baker ZXP Liner Top Packer 6,990' Baker 7 -5/8" x 5-1/2" HMC Liner Hanger 6,996' 4 7 5/8" Halliburton Float Collar 7,058' 6 1/8" Hole td @ 9,977' 7 5/8" Halliburton Float Shoe 7,141' OB Lower Lateral 69 jts. - 41/2 ", 12.6# L -80, IBT ` Slotted Liner (7,130'- 9,975') ■ Btm Baker 4 1/2 " 'V" Float Shoe 9,977' DATE REV. BY COMMENTS MILNE POINT UNIT 05/16/03 MDO Drilled & Completed Doyon 14 WELL S -04 API NO: 50- 029 - 23148 -60 L1 API NO: 50- 029 - 23148 -00 III • EXPLORATION (AKL - • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday, March 21, 2011 P.I. Supervisor ` "� ZZ/ /( SUBJECT Mechanical Integrity Tests I BP EXPLORATION (ALASKA) INC S -04 FROM: Matt Herrera MILNE PT UNIT SB S -04 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv- NON - CONFIDENTIAL Comm Well Name: MILNE PT UNIT SB S -04 API Well Number: 50- 029 - 23148 -00 -00 Inspector Name: Matt Herrera Insp Num: mitMFH110320150615 Permit Number: 203 -052 -0 Inspection Date: 3/20/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 s -04 ' Type Inj. W J TVD 4226 / IA 680 2190 - 2160 2150 P.T.D, 2030520 - TypeTest SPT i Test psi 1500 - OA 260 400 400 400 Interval INITA P/F P 'Tubing i 190 200 200 200 Notes: Well was recently changed from producer to injector. Packer TVD on this report was obtained from operator. Olditli APR 1 3 Z 01 `i Monday, March 21, 2011 Page 1 of 1 • • Chidiebere Igbowke Petroleum Engineer BP Exploration (Alaska), Inc. ~*~~ -.:',,:.,.~ ~`~~'~' -`~ t ~~~ ©~ P.O. Box 196612 0~63~ Anchorage, AK 99519-6612 Re: Milne Point Field, Schrader Bluff Oil Pool, MPS-04 Sundry Number: 310-238 Dear Mr. Igbowke: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ~ 1 day of August, 2010. Encl. STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISSI~ , ~;U ~ O APPLICATION FOR SUNDRY APPROVALS ~'~~ ,~0'~ 20 AAC 25.280 1. Type of Request: Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Pertorations ^ Perforate^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other: CONVERT TO WINJ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ^ Exploratory ^ 203-0520 • 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-23148-00-00 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ MPS-04 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-380110 ~ MILNE POINT Field / SCHRADER BLFF OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9977 4337.3 9977 4337.3 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 215# A-53 35 115 35 115 Surface 2828 10-3/4" 45.5# L-80 35 2843 35 2480 5210 2480 Intermediate 7108 7-5/8" 29.7# L-80 33 7141 33 4340 6890 4790 Production Liner 2995 4-1/2" 12.6# L-80 6982 9977 4299 4337 8430 7500 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SL 7130 - 9977 4336 - 4337 4-1/2"X3-1/2" L-80 URFACI 6827 SL 6992 - 11604 4302 - 4323 12.6# X 9.2# Packers and SSSV Tvoe: 7"x3.5" BAKER PREMIER PKR Packers and SSSV MD and TVD (ft): 6771 4226 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/11/2010 Oil ^ Gas ^ WDSPL ^ Suspended ^ 16. Verbal Approval: Date: WINJ ^~ GINJ ^ WAG ^ Abandoned ^ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chidiebere Igbowke Printed Name Chidieb bowke Title P E Signature Phone Date 564-4795 8/4/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Commission so that a representative may witness Sundry Number: ~ ~~" ~~ roval: +Notif Conditions of a y pp t ~ Location Clearance ^ Plug Integrity ^ ~ BOP Test ^ Mechanical Integrity Tes n l•oY ~ c Other: .. (~~E'i~i~c ~-c~ O .t.,r.,~ r txl fh ct~G p ~ I ~ ! ~ ~ ~ V ~~~~d ) ( N '' // / f '" ~~~ ~"t-'~cr S~"4.bi ~lLGd~ t h~G~~ C~• LIJATE~\ J C ? ~ ~ y '.U ~ ~ 4 2010 Subsequent Form Required: ~ Q _ l v ~/ Alaska ~ cat Gas Gsfi$. C1Dd1~t1iS$IOfi ~itlClit7tc~~B APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ 1 ~~ ` Form 10-403 Revised 1,~1'tf~~~ '"- " ~ ~ ~ ` 0 R I G ~ Nq #~ ~ ~_~ _!O Submit~pli ~ ~ /~' ~~1~ • • S.b~1 L~ Milne Point S-04 (203052) '~ Current Status The Milne Point S-04 is a Schrader Bluff producer drilled and completed as a jet pump producer in May, 2003. The well currently produces ~41 bopd 96% WC and a GOR of 107 scf/from the OA and OB sands in the Schrader Bluff ° formation. MPS-04 has no known casing problems. The Base Management team's (with approval from the Reservoir Management) plan forward is to convert the MPS-04 to an OA/OB sand injector in the Schrader Bluff pool. This is necessary due to the declining reservoir pressure in hydraulic unit 15 and the subsequent poor production performance of the offset producers. Completion The MPS-04 (PTD 203052) wellbore crosses the Schrader Bluff formation at 6408' MD. The surface hole was completed with 10-3/4" casing to 2842' and and cemented to surface with 500 bbls of 10.7 Ib/gal class "L" lead cement and 54 bbls of 15.8 premium class G-cement. Full returns were seen and plugs bumped during cementing of the surface casing. A 7-5/8" production casing string was run from surface to 7057' MD. The production casing was cemented with 48 bbls of 12.0 Ib/gal ppg class "E" and 69 bbls of 15.6 premium class "G" cement. Full returns were also seen during cementing operation and plugs bumped with floats holding. The 7-5/8" casing was reciprocated until just before plugs were bumped. Although no cement bond log was run after the cementing operation, we are very confident that there is competent cement isolation on both the production and surface casing to facilitate a conversion from producer to injector. The well is completed in the OA, and OB sands and both zones were completed with uncemented slotted liners. Plan Forward: 1) Obtain Sundry for conversion to water injection 2) Pull jet pump, shut-sliding sleeve 3) Pressure test 7-5/8" casing to 2,500 psi 4) Safe-out water injection header and add new valve to water injection header 5) Place well on water injection (confirm AOGCC approval prior to injection) 6) AOGCC witnessed MITIA once injection has stabilized PQ~ COn of l Syfr'Qn w~ ~~ f ~`,'~J,, h t e/ T J 1~t l n ~eitcri~S,, CO.~vt/'Sr~ of Tyr wtl/ ~ /'~~tc1h/ w~`// 9~/°a. ~a~ T"wd drrfr ~,~ r L lva Its /'n r~,f burr a Sfv~p s ' ,%+ T~r,'s Pat ~- pf TIC ~ ~ 4 C~.-s q P~Oo~vc{ 1/«~ Wll~ ~l S ~<~ C~~1~f On ti'/` l~`t~ Q ~ D q Copp/r ~iv~c/ ~~~ ~~`a~~ t~~ /~7®~ olt~clc~ed f'o p~ is 2rq/~prn~ {"rwr olPvc% ~ ~ .rtic~~s C~~~.x~ D~o,r~;o~ ik 7'~;s ~o~r/a- p+~ r'~~ ~/ TtiAr ~~c%!,r q0%•t/cyq/ d ~rloP,~r~~ ~ ~ Ot 7~i~1 Wel/ Tv a mite- i'-,jCCtd1~ ~~o~/d ~+roh"o~t fyv~''~' ~0 ~3' ~' Cwrar ~vr./ ~'~ t~~ a~eg a~ f~ der/oP,~~,-t BkAS~ Y~c~e~wi ~ ~r~- q~/~a/ of rti~f /'~I. ~ • • Area of Review -Milne Point S-04 (Permit# 203052) This Area of Review is required prior to the conversion of well MPS-04 from a producer to a water injector. This AOR discusses wells within '/4 mile of the well's entry point into the Schrader Bluff Formation to the bottom of MPS-04 well bore completion. Four other wellbores; MPS-02 MPS-03, MPS-09 and MPS-10 enter the Schrader Bluff formation in this area of review. The tables below illustrate the wells within the AOR, distance from MPS-04, completion details, and annulus integrity/cement conditions based on in-depth review of each well. Table 1: Table showing distance & annulus integrity of wells within AOR Well Hole Vol, of Schrader Bluff depth Schrader Bluff depth Table 2: Completion Detail Well MPS-02 (Permit # 203127) was completed in August, 2003. The completion crossed the Schrader Bluff formation at 5539' MD. A 9-5/8" casing was run to 2933' and and cemented to surface with 70-sx (~52 bbls) of 10.3-Ib/gal permafrost L lead cement with a yield of 4.15 cu-ft/sx, 615 sx 0238 bbls) of 12.0 Ib/gal class "E" cement with a yield of 2.17 cu-ft/sx, followed by 225 sx (~46 bbls) of 15.6 Ib/gal premium class "G" -1.15 cu-ft/sx tail cement. A 7" production casing was run to 6235' and and cemented in place with 310 sx (~72bbls) of 15.8 Ib/gal premium class G cement with a yield of -1.31cu-ft/sx . A cement bond log run August, 2003 showed top of cement about the production casing @ 4770' md. Well MPS-03 (Permit # 202147) was completed in August, 2002. The completion crossed the Schrader Bluff formation at 6605' MD. A 7-5/8" casing string was run to 7302' MD and cemented with 1356 Sx of Class `L" 10.2 Ib/gal @ 4.15 cu-ft/Sx (1004 bbls) and 308 sx of class G 15.8 Ib/gal @ 1.15 cu-ft/ Sx (63-bbls). Lost • • returns were observed after pumping 750 bbls of lead cement and consequently, another 104 bbls of lead cement was pumped yet without returns ahead of tail cement (no returns) and bumped plug. A150 bbls top job was performed with 1" at 729'md. The basis of design called for 250% excess over gauge hole in permafrost interval and 40% excess over gauge hole below permafrost. Well MPS-09 (Permit# 202020) was completed in June, 2003. The completion crossed the Schrader Bluff formation at 8250' MD. A 7" casing string was run to 8913" MD and cemented with 1461 sx of 10.7 ppg class "L" lead cement with a yield of 4.15 cu-ft/sx (1080 bbls) and 400 Sx of 15.8 class G cement with a yield of 1.15 cu-ft/sx (~82 bbls). Well was cemented with full returns and with cement to surface. Well MPS-10 (Permit # 203067) was originally completed in June, 2002 but was sidetracked in June, 2005. During intial completion in 2003, a 9-5/8" casing was run to 2776' and and cemented to surface with 510 sx of 10.7 Ib/gal class `L' cement with a yield of 4.15 cu-ft/sx 0377 bbls) and 225 sx of 15.8 Ib/gal premium class G tail cement with a yield of 1.15 cu-ft (~46 bbls). Full returns were seen throughout the job, and plugs bumped at 1000psi above circ pressure. The 7" casing was run and cemented with 275 sx of 15.8 Ib/gal class G cement with a yield of 1.15 cu-ft (~56bbls). Full returns were seen throughout the job and bumped plug with 1500-psi. Floats held. MPS-10 crossed the Schrader Bluff formation @ 4955' md. In 2005 MPS-10 was side tracked to MPS-10A which crosses the Schrader Bluff formation @ 5355' md. De-complete operation included a casing cut (7") at 3110 and a second cut @ 2839' and (after infectivity test confirmed the cut wasn't successful) and circulated OK. The 7' casing was laid down, cement kick off plug set @ 2290', kicked out and directional drill progressed per sidetrack package. A new 7" casing was run to 6225' and and cemented with ~83 bbls of 15.8 Ib/gal class G cement with full returns seen, and plugs bumped. A cement bond log run October, 2005 shows TOC @ 4010' md. MPS-01L2 MPS-01 MPS-01 L 1 MPS,-01L2PB1 r MPS-0'I AL 1 41 *?L 1 ~ nPE=~4 MPS-07SS ~ MPS C7LS ~+ PAPS-12FB1 P~,1PSr12 ' =S-i2L1 wp03 h/,1P ~_ 15 _ I`,dP~-(~li+ -OF5 • MPS-01PB1 ' ~ 42 ~ -- la1P.~i33i? -_~~-02 M 0 - M S- 5PB1 ~ MF°~=r6~ -- r:,~F _~~_, ~ - n M:~-_ 3 _ . - --- - M~ 'B i N1P` MPS-41 -•Mp~PS- 10?.~ ~ RAF' ~- 1 I SL1 MPs-~ P~~ <v~F~~_ A.PB2 1PB1 N i~ H U_15 1PB2 PPUDH4E-01 ,n -0~1~ i 1320' radius around MPS-04 Completed zones NB producer NC, ND, or NE produce ,~ OA producer loon 0 loon zooo sooo aooo sooo rc //' OB producer -- -~~ o NB injector ~ NC, ND or NE injector ~ OA injector • OB injector Figure: Map showing wells within 0.25 mi radius from MPS-04 Tree: 4-1/16" - 5M FMC A Orig. K~v. = 72.25' (Doyon 14) Wellhead: 11" x 4.5" 5M Gen 6 ~ MPS-04 orig. GL~rev.= 38.30' (Doyon 14) w/ 4.5" TCII T&B Tubing Hanger 4" CIW "H" BPV prole 20" x 34" insulated, 215 #/ft A-53 Camco 4.5" x 1" w/ BK-5 latch 2106` sidepocket KGB-2 GLM 10 3/4" Super Seal II Float Shoe 2843' KOP @ 600' 60+ degree from 2800' Max hole angle = 68 degree @ 6722' 10 3/4" 45.5 ppf L-80 BTRC 68 degree @ Sleeve (Drift ID = 9.794, cap. _ .0961 bpf) 7 5/8" 29.7 ppf, L-80, BTRC-mod production casing ( drift ID = 6.750", cap. = 0.0459 bpf ) 4.5" x 3.5" X-Over @ 6778' 4.5", 12.6#, L-8o IBT tbg. No-Go ID of XN nipple 2.750" @ 6822' ( cap. _ .0152 bpf, id =3.958 ) 3.5", 9.2# L-80 NSCT tbg. ( cap. _ .0087 bpf, id 2.992 ) «~~-~ Phoenix Discharge gauge (3.850 ID) 6,711' -~~ ~I .... ~ r rW ~j I ~ 1 ~. 4.5" HES XD Dura sliding sleeve 6,721' _ ~ ,~~; NOTE: ID change min. 2.840" ~ __ j - - ~ Phoenix gauge (2.840" ID) (4060' TVD) 6,745' 4.5" x 3.5" X-Over 6,759` Po,",,~,"„ w 3.5 HES X-Nipple (2.813 ID) 6,761 ` 771' 5" Baker Premier Packer 6 7" x 3 , . sr 3.5" HES XN-Nipple 6 822' ( 2.813 packing bore 2.750" No Go ID) WLEG 6,827 Baker Tie Back Sleeve 6,837' Baker Hook Wall Hanger inside 7° Window 6,845' Baker Hook Wall Hanger outside 7" Window 6,871' Window in 7" Casing @ 6,859` - 6,871' 6 1/8" Hole td @ 11,737' Well Angle @ window = 69° Rat Hole 113 jts. - 4 1 /2" R3 Slotted Liner OA Upper Lateral ss' ' ' 12.6# L-80 IBT (6,922 -11,604 ) Baker Tie Back Sleeve 6,982' Baker ZXP Liner Top Packer 6,990' Baker 7-5/8" x 5-1/2" HMC Liner Hanger 6,996` 7 5/8" Halliburton Float Collar 7,058' ~ 6 1!8" Hole td @ 9,977' 7 5/8" Halliburton Float Shoe 7,141' OB Lower Lateral 69 jts. - 4 1/2", 12.6# L-80, IBT Slotted Liner (7,130`- 9,975') Btm Baker 41/2" "V" Float Shoe 9,977' DATE REV. BY COMMENTS 05/16/03 MDO Drilled & Completed Doyon 14 Btm Baker4 1/2" Guide Shoe 11,644' MILNE POINT UNIT WELL S-04 API NO: 50-029-23148-60 L1 API NO: 50-029-23148-00 BP EXPLORATION (AK) ~. ~~J t/F/LT L ~~~ I~.'Ct3ArlICAL ~,NTEGRITY R~ORT ~7."D a o3 - vsz ? U D v P.. E : _~~ 3 OPER ~ FIELD ,~ P - /~'l ~ ~ ~- 1 -~ .S /i r~ 3LU FF G r~ r?.~r ~ ~ : 5 ~y o 3 i.'s.ZL NU2~ER S-~ `7'r ~ S-o `~ L1 ~'~LL DA T ~: TD : ~l ? 7~.. `7'337 '!"YD. ; . BTD : ~ ~ ~ 7 ~. ?~ID `~337'~ surd C2sirg : / ~'~~`~' ~~~ ShoE : v`2~3 t'ID . _ 1'VD ' LV : .~ - '3~ID ~~ •T4~ obi.^.g . ~~'27 Packer 477 M~ __~_.a___ ____~___ TvI) • &et at :01~ .Si're ~~~- f 2ll0. ~~ (~' 7 ~ i PE=f.~ t C_ . I.o ~~7~~.. '''..° ~.p.~IIC~.x+ %NTEGR'!"TZ - ~ ART # i ~,,,..~. slj3/~3 . Antluius Pxess zest: ..p ys~ t 15 mica ~; Cota®ents: C~7a~~ ! S~O'~ r'S. - .~,_..7.~r.- *SECHANiC?Z YNTEGRITY -PART # 2 S 7 ~, Cemenc Volumes r ?.mt. 3.inQr~ Gag IS DVS. ~ / ~ !~ ~ . X_ ., Cr~t ,ol to cover pe~:.s Tap ..5'.IS. Lp`fZ? m d '" ,o3g3 6~~? heflrecical TOC .2G ~+ j~L ~+ _..,...~, Cement Bond L®g (Tee ore No ~_,- In AOGCC P"ile_____~ C8L :valuation, zone aDOve perfs ~'~ lo~ ~~~ ti :Lh ~~-G ~ d'~-t__ Proriuction Log: Tpp~ t Evaluation CONCLUSiQNS: p~~.rt #1 . °.~...~ mart ~~: ~ Nl t ~ - 1A~ ~~L ~~~u g ~e~ 30 ~. i /Gdl : G-. *bz.. A ` C~ L v ~- ~ - is • • MICROFILMED 03/0112008 DO NOT PLACE ~'.. ~;~` - " ,~~ ~„~ ` ,~~ ~° -. ANY NEW MATERfAL UNDER THIS PAGE F:1LaserFichelC~rPgs_Inserts~Microfilm_Marker.doc ) ) WELL LOG TRANSMITTAL ~DJ-05¿Y To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 ...-/ '3~ 1o,- RE: MWD Formation Evaluation Logs MPS-04, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPS-04: LAS Data& Digital Log Images: 50-029-23148-00 1 CD Rom S'ÇANNED M~\H ¡09 2.005 Q(oQDltO) :! &9/0(~ ) ) WELL LOG TRANSMITTAL \... ~ \~/" ¡!\J../~ I~ July 14, 2005 c' _./;:l.",,~ ,b" ',' ".,~:k"r"~",,Jt'~ J..~"'::.J t1.J',' , 'G ".,O'Lf I I To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Hel,en Wannan 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ,- )..- 1':') - 'L ",v ) ? i'; Î- 'IS }. ~ ?; ,,\ \'1.7 /"/ \~ I br'/' {I .."...... "".''''~ RE: MWD Formation Evaluatio gs~::~~ Ll, Ll PBI & LI PB2 )t}- O~,~ 3{ '"18.. 6ó., ð , 5b.. ()1Jt .. )..., I ~ .... ft. 6 ..." - ~ - -Å31)ct'-O~~. ) P&12.. Ll,LI··pßÎ &..rfPR',- . vtail,::ì'''~Tm::t~S::'·''·· I..t-k. 50-029-2324~P,60, 70'Q~ t ( -'V~lyp-í ->'ô---',l~D s JI i { Y N ' ~ ~-...... AK-MW-2412654 ~. (JJf\M",.:t' f~ 1 CD Rom ¡, ; PL~ASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE A TT ACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish :J 7 ç - ,1 b Il) Ò 6900 Arctic Blvd. " Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 (' rill 1.. ,'-' Date: \¿ cy¡J '. N\"'"'t j ill t r/¡ (/ Signed: 'Ji~~/ ()tvVv-e/i t'lPs- ') \~.~ j - ~ \' J,. {::' ( --l.. I '--I J~À~')- DATA SUBMITTAL COMPLIANCE REPORT 7/8/2005 Permit to Drill 2030520 Well Name/No. MILNE PT UNIT SB 5-04 Operator BP EXPLORATION (ALASKA) INC c-.. ..~ )..) lap ~~.J ;)f! API No. 50-029-23148-00-00 MD 9977 .-- 1VD 4337 /" Completion Date 5/14/2003 Completion Status 1-01L Current Status 1-01L UIC N ------"------- .--- ------ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes ----~-- -- --- -------- DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, IFR / CASANDRA, ASI, RES, GYRO, GEOTAP Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED 0 Lis 11828 Induction/Resistivity (data taken from Logs Portion of Master Well Data Maint) : Rpt ED 0 Asc ED 0 Asc Rpt I Rpt Directional Survey Directional Survey Directional Survey Directional Survey LIS Verification ,~ Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 3 67 9924 Open 6/25/2003 GR EWR4 ROP Final 0 304 Open 6/2/2003 GYRO Survey final 0 304 Open 6/2/2003 Gyro final 304 9977 Open 6/2/2003 IIFR Survey 304 9977 IIFR Survey 3 67 9924 Open 6/25/2003 --_.------ Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ---~-- ADDITIONAL INFORMATION Well Cored? Y / ti) Daily History Received? (Îi>N ~/N Chips Received?, v I t>J- Formation Tops Analysis Received? ~ -"--- ---.- -- .--- -- - ------ Comments: - ------ ------ ,~ Date: II J t_,,~ ,1.......) r - ---- -- .--- -- ---- Compliance Reviewed By: ) ) i gO~-05ð , , ~':tß WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 20,2003 RE: MWD Formation Evaluation Logs MPS-04, AK-MW-24 1 2654 1 LIS formatted Disc with verification listing. API#: 50-029-23148-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMJTTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: 1] 2003 Signed: ;f. ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ') .?3. CASING SIZE 1. Status of Well aa Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3364' NSL, 4757' WEL, SEC. 07, T12N, R11 E, UM At top of productive interval 4261' NSL, 512' WEL, SEC. 07, T12N, R11E, UM X = 570255, Y = 6001893 10. Well Number At total depth 2501' NSL, 63' WEL, SEC. 07, T12N, R11E, UM (OB) X = 570739, Y = 5999213 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Milne Point Unit / Schrader Bluff KBE = 72.25' ADL 380110 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/27/2003 ' 5/6/2003 ' 5/14/2003 ' 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 9977 4337 FT 9977 4337 FT aa Yes 0 No 22. Type Electric or Other Logs Run MWD, GR , IFR/CASANDRA , ABI , RES, GYRO, GEOTAP CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE 35' 115' 42" 35' 2843' 13-1/2" 33' 7141' 9-7/8" 6982' 9977' 6-1/8" Classification of Service Well 7. Permit Number 203-052 8. API Number 50- 029-23148-00 9. Unit or Lease Name X = 566034, Y = 6000033 Milne Point Unit MPS-04 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A MD 1800' (Approx.) 20" 10-3/4" 7-5/8" 4-1/2" WT. PER FT. 92# 45.5# 29.7# 12.6# GRADE H-40 L-80 L-80 L-80 CEMENTING RECORD ~60 sx Arctic Set (Approx.) 680 sx PF 'L', 261 sx Class 'G' 125 sx PF 'E', 325 sx class 'G' Uncemented Slotted Liner AMOUNT PUllED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2", Slotted Liner MD TVD 7130' - 9977' 4336' - 4337' 26. SIZE 4-1/2" x 3-1/2", 12.6# x 9.2#, L-80 ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 22 Bbls of Diesel TUBING RECORD DEPTH SET (MD) 6827' PACKER SET (MD) 6771' 25. MD TVD lJl!~. TF ' ~£L£LL~i' i 1r'~~Er' :; -:~?:':-:~~,.. ,~.~~~:7::..; 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) May 20, 2003 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF WATER-BBl 6/11/2003 6 TEST PERIOD 545 779 0 Flow Tubing Casing Pressure CALCULATED Oll-BBl GAs-McF WATER-BBl Press. 24-HoUR RATE ~8. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit ~ie E ~ \IE 0 CHOKE SIZE GAS-Oil RATIO 1428 Oil GRAVITY-API (CORR) No core samples were taken. JUN 1 3 2003 lMÐMS BFl JUN 2 0 2003 CF Form 10-407 Rev. 07-01-80 A\aska Oil & Gas Cuns. Commission Anchorage . UK\G ,NA~ Submit In Duplicate ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. SBF21/ SBF24-MF / SBF1-NB~/ SBF1-NBR SBE4-NC ./ SBE41 /' SBE2-NE /' SBE1-NF V TSBD-OA. ¿' TSBC'/ TSBB-OB / SBA5r SBA5 r TSBB-OB1'" TSBB-OB/ 6427' 6480' 6495' 6505' 6582' 6592' 6619' 6768' 6865' 6969' 7099' 7157' 7214' 9328' 9426' 4093' 4113' 4120' 4124' 4154' 4158' 4168' 4225' 4260' 4294' 4330' 4342' 4351' 4333' 4332' RECEIVE[) JUN 1 :3 7003 Alaska Oil &, Gas Con$. Cij!11inisskm Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Integrity Test Summary MPS-04 Well Number ing is true and correct to the best of my knowledge :~ 203-052 Title Technical Assistant Date ~ ~·t 3~()3 32. I hereby certify that the fore Signed Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Matt Green, 564-5581 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. I-;EM 21: Indicate whether from ground level (GL) or other elevation (OF, 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 ORIGINAL ) ) BP EXPLORATION Operations Summary Report Page 1 of 6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-04 MPS-04 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/27/2003 Rig Release: 5/14/2003 Rig Number: Spud Date: 4/27/2003 End: 5/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/27/2003 02:00 - 06:00 4.00 MOB P PRE PJSM. Slide Rig Floor to Moving Position. Move Rig from MPS-24 to MPS-04. 06:00 - 07:00 1.00 RIGU P PRE PJSM. Slide Rig Floor to Drilling Position. Start taking on Water & Mud. RIG ACCEPTED @ 07:00 Hrs. 07:00 - 11 :00 4.00 RIGU P PRE Take on Water & Spud mud. NIU Diverter, Riser, Mud lines, Service Lines. CIO Saver Sub. Pre-Spud Derrick Inspection. Spot Rockwasher. 11 :00 - 13:30 2.50 DRILL P SURF P/U BHA components from Beaver Slide. P/U & Stand Back HWDP. Bring MWD up Skate to Floor. 13:30 - 15:00 1.50 DRILL P SURF M/U BHA #1 15:00 - 15:30 0.50 DRILL P SURF Function Test Diverter. Witness of Test Waived by Chuck Scheve, AOGCC. 15:30 -16:00 0.50 DRILL P SURF Continue M/U BHA #1. RIU Sperry E-Line for Gyro. 16:00 - 16:30 0.50 DRILL P SURF Pre-Spud Meeting with Co. Rep, Drilling Crew & All Servce Co. Personnel. 16:30 - 17:00 0.50 DRILL P SURF Fill Stack with Mud, Circulate & Check for Leaks. - OK. 17:00 - 19:30 2.50 DRILL P SURF Spud Well & Drill from 112' to 289'.420 GPM @ 820 psi. 10 to 15K WOB, TO = 3K RPM = 70 19:30 - 20:30 1.00 DRILL P SURF Stand Back 2 Stands HWDP & P/U Remainder of DC's. 20:30 - 00:00 3.50 DRILL P SURF Drill From 289' to 542'. 420 GPM @ 1130 psi. TO = 3K . 70 RPM, WOB = 1 OK to 25K P/U, SIO & ROT WT - ALL 81 K ART = 2.08 HRS AST = 1.33 HRS. 4/28/2003 00:00 - 22:00 22.00 DRILL P SURF Directional Drill from 542' to 2852' - TO. Final Circ. Rate & Pres. = 450 GPM @ 2230 psi. WOB = 10 to 45K, ON BOT. TO = 9 to 11 K, RPM = 80 to 90. P/U = 111 K, SIO = 94K, ROT = 102K AST = 10.34 HRS. ART = 6.5 HRS. 22:00 - 23:30 1.50 CASE P SURF CBU 2 + Times. Rotate @ 105 RPM & Reciprocate 80'. Pump @ 460 GPM, ICP = 2000 psi. FCP = 1890 psi. Hole Clean. 23:30 - 00:00 0.50 CASE P SURF Begin Pumping Out of Hole @ 445 GPM & 1700 psi. 4/29/2003 00:00 - 01 :30 1.50 CASE P SURF Pump out of hole to HWDP @ 815'. Pump Rate = 445 GPM ICP = 1640 psi., FCP = 1250 psi. 01 :30 - 02:30 1.00 CASE P SURF RIH to Bottom. No obstructions. Hole in good shape. 02:30 - 04:30 2.00 CASE P SURF Circulate @ 500 GPM I 2220 psi. Reciprocate 80 ft and rotate @ 105 RPM. Circulate until Hole Clean = 3 X Bottoms Up. 04:30 - 07:00 2.50 CASE P SURF Pump out of hole to BHA at full drill rate 07:00 - 10:30 3.50 CASE P SURF Stand back HWP and lay down BHA, clear floor 10:30 - 12:00 1.50 CASE P SURF Rig up to run csg, PJSM 12:00 - 14:30 2.50 CASE P SURF Running CSG, picked up 10 3/4 csg 45.5# L-80 to 1,750' 14:30 - 15:00 0.50 CASE P SURF CSG not giving right displacement, circ. down 3 jts from 1750' to 1885', 5 bbls min 300 psi 15:00 -16:00 1.00 CASE P SURF Running CSG, picked up 10314 csg 45.5# L-80 to 2800', total jts run 68 16:00 - 16:30 0.50 CASE P SURF Landed csg @ 2842 rig down Franks tool and rig up cement head P/U wt 185K SIO wt 150K shoe @ 2842, float @ 2,756' 16:30 - 18:30 2.00 CASE P SURF Circ and treat mud for cement job, circ @ 7 bbls min 300 psi, PJSM on cementing 18:30 - 21 :00 2.50 CEMT P SURF Cement CSG pump 10 bbls water, test lines to 3500 psi, 10 water, 50 bbls Alpha Spacer @ 10.2, drop bottom plug, 500 bbls Lead cement 680 sxs mixed @ 10.7 mixed and pumped @ 7 bbls min., 54 bbls 261 sxs Premo cement mixed @ 15.8 Printed: 5/19/2003 10:37:12 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-04 MPS-04 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/27/2003 Rig Release: 5/14/2003 Rig Number: Spud Date: 4/27/2003 End: 5/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/29/2003 18:30 - 21 :00 2.50 CEMT P SURF mixed and pumped @ 5 bbls min., drop top plug, 10 bbls water, displace with rig pumps 7 bbls min 600 psi 254 bbls mud, bumped plug with 1600 psi, float held, full returns tru out job, 350 bbls of good cement to surface 21 :00 - 22:00 1.00 CEMT P SURF Flush lines and stack, lay down landing jt and cement head 22:00 - 23:00 1.00 CASE P SURF Nipple down 20" diverter 23:00 - 00:00 1.00 CASE P SURF Nipple up FMC 20' X 11' Gen V well head, test to 1000 psi 4/30/2003 00:00 - 02:30 2.50 CASE P SURF Nipple up BOP 02:30 - 03:30 1.00 CASE P SURF Rig up to test BOP 03:30 - 08:00 4.50 CASE P SURF Testing BOP and Manifold to 250 low 3,500 high, Annular 250 low 2500 high, 5 min per test, the right to witness test was wavier by Chuck Scheve AOOGC. 08:00 - 08:30 0.50 CASE P SURF Rig down test equipment. Install wear bushing. 08:30 - 09:00 0.50 CASE P SURF Rig up to run drilling BHA. 09:00 - 10:30 1.50 CASE P SURF Make up new bit and BHA with mud motor, MWD, GEOTAP and HOC. 10:30-11:30 1.00 CASE N DFAL SURF Load MWD and GEOTAP. Perform shallow test. Tools not communicating. Lay down tools. 11 :30 - 12:30 1.00 CASE P SURF Safety training with crew on proper operation of rig tongs. 12:30 - 15:00 2.50 CASE N DFAL SURF Trouble shoot and repair Sperry sun tools 15:00 - 16:00 1.00 CASE P SURF M/U BHA and surface test MWD and GEO-TAP Manifold @ 750' 95 spm 890 psi 16:00 - 18:00 2.00 CASE P SURF Picking up 4" HT38 DP to 2669' 18:00 - 19:00 1.00 CASE P SURF Slip and cut drilling line and service top drive, circ well while cutting drilling line 19:00 - 20:00 1.00 CASE P SURF Test CSG to 2,500 psi for 30 min. good test 20:00 - 21 :00 1.00 DRILL P INT1 Drill float @ 2756 and shoe @ 2842 and new hole to 2872' 105 spm 1750 psi 60 rpms 21 :00 - 21 :30 0.50 DRILL P INT1 Circ bottom up for FIT test 21 :30 - 22:00 0.50 DRILL P INT1 FIT test with 9.2 mud TVD 2484 TMD 2872',300 psi= 11.5 EMW 22:00 - 00:00 2.00 DRILL P INT1 Directional drill 2872' to 3136' with 85 rpms 500 gpm 1600 psi Displace mud when started drilling with 8.5, 66 vis LSND mud AST .33 ART 1.10 5/1/2003 00:00 - 00:30 0.50 DRILL P INT1 Directional drill 3136' to 3,320' with 85 rpms 500 gpm 1600 psi 00:30 - 01 :30 1.00 DRILL N FLUD INT1 Circ, slow and unplug flow line, clean out Possum belly 01 :30 - 00:00 22.50 DRILL P INT1 Directional drill 3,320' to 6250' with 80 rpms 500 gpm 2270 psi, 30k bit wt. AST 5.76 ART 7.33 P/U 160K SIO 88K Rff 114K 5/2/2003 00:00 - 07:30 7.50 DRILL P INT1 Directional drill 6250' to 6,662' with 80 rpms 500 gpm 2270 psi, 30k bit wt. 07:30 - 08:00 0.50 DRILL P INT1 Circ bottoms up 500gpm 2270 psi 50 rpms. 08:00 - 09:30 1.50 DRILL P INT1 Perform dummy test with Geo-Tap @ 6590', keeped pipe static for 7 min., worked pipe no sticking observed, perform Geo-Tap @ 6590. circ. 3 BHA annular volums, perform Geo-Tap @ 6622, test failed, circ and work pipe and retest @ 6622 good test. 09:30 - 11 :00 1.50 DRILL P INT1 Directional drill 6,662' to 6772' with 80 rpms 500 gpm 2400 psi, 30k bit wt. 11:00-11:30 0.50 DRILL P INT1 Circ 3 BHA annular volumes., Perform Geo-Tap @ 6732' 11 :30 - 20:00 8.50 DRILL P INT1 Directional drill 6,662' to 7152 TD with 80 rpms 500 gpm 2600 psi, 30k bit wt. TADT 28.84 hr, TART 10.92 hr, TAST 17.92 hr P/U 165K SIO 90K RIT 112k 20:00 - 21 :00 1.00 DRILL P INT1 Circ bottoms up 500gpm 2400 psi 90 rpms. Printed: 5/19/2003 10:37:12 AM ) ) Operations Summary Report Legal Well Name: MPS-04 Common Well Name: MPS-04 Spud Date: 4/27/2003 Event Name: DRILL +COMPLETE Start: 4/27/2003 End: 5/14/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 5/14/2003 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/2/2003 21 :00 - 22:30 1.50 DRILL P INT1 Pump out from 7152 to 6959, Perform Geo-Tap @ 6959 and 7025', RIH, (circ 3 BHA annular volumes between test.) 22:30 - 00:00 1.50 CASE P INT1 Circ Three bottoms up with 500 gpm, 2400 psi, 90 rpms 5/3/2003 00:00 - 01 :00 1.00 CASE P INT1 Circ Three bottoms up with 500 gpm, 2400 psi, 90 rpm 01 :00 - 05:00 4.00 CASE P INT1 Pumping out to 10 3/4 csg shoe @ 2842. with full drilling rate 05:00 - 07:00 2.00 CASE P INT1 Circ,@ 2842 Lots of clay balls coming back, plugging flow line 07:00 - 08:30 1.50 CASE P INT1 Tripping back into 6500 08:30 - 11 :30 3.00 EVAL P INT1 Taking Geo-Tap Pressure readings @ 6590,6622,6732,6959, 7025, Circ. 3 BHA Annular volumes between each reading, two miss runs had to retake. 11 :30 - 14:00 2.50 CASE P INT1 Circ Three bottoms up with 500 gpm, 2400 psi, 90 rpm 14:00 - 18:00 4.00 CASE P INT1 Pumping out to 10 3/4 csg shoe @ 2842. with full drilling rate 18:00 - 18:30 0.50 CASE P INT1 Circ,@ 2842, Bottoms up, no clay balls 18:30 - 19:30 1.00 CASE P INT1 POH to BHA 19:30 - 22:00 2.50 CASE P INT1 Lay down BHA, down load MWD 22:00 - 23:30 1.50 CASE P INT1 Clear floor of Geo-Tap manifold, Change Rams to 7 5/8, Test door seals to 3,500 psi 23:30 - 00:00 0.50 CASE P INT1 Rig up to run CSG, change out bails, pickup Franks fillup tool 5/4/2003 00:00 - 01 :30 1.50 CASE P INT1 Rig up to run CSG, change out bails, pickup Franks fill up tool, PJSM on running CSG 01 :30 - 04:30 3.00 CASE P INT1 Picking up 7 5/8 29.7# L-80 BTC-Mod csg @ 2,825 04:30 - 05:00 0.50 CASE P INT1 Circ, one CSG volume. 05:00 - 09:00 4.00 CASE P INT1 Picking up 7 5/8 29.7# L-80 BTC-Mod csg, Tolal Jts run 175, shoe @ 7141, float 7057 09:00 - 09:30 0.50 CASE P INT1 Lay down franks fillup tool, Pickup cement head 09:30 - 12:00 2.50 CASE P INT1 Circ, stage pumps up to 6 bbls min. 400 psi, PJSM, Reciprocate Csg 150,000 P/U 90,000 S/O 12:00 -13:30 1.50 CEMT P INT1 Cement with Halliburton, with 5 bbls water, test lines to 3500 psi, 30 bbls Alpha spacer 10.2, drop bottom plug, 48 bbls 125 sxs Permafrost E 12.0#, 69 bbls 325 sx Premium 15.6#, drop top plug, 10 bbls water, displace with rig pumps with 310 bbls 9.2 mud 7 bbls min. full returns tru out job, bump plug with 1600 psi, float held, CSG was Reciprocate till just before plug was bumped. 13:30 -14:30 1.00 CEMT P INT1 Lay down landing jt and cement head, clear floor 14:30 - 15:00 0.50 CASE P INT1 Install 7 5/8 packoff and test to 5,000 psi for 10 min. 15:00 - 16:00 1.00 CASE P INT1 Change upper rams to 2 7/8 X 5" Variable 16:00 - 17:00 1.00 CASE P INT1 Change out bails, rig up test equip., inject 15 bbls mud down 10 3/4 x 7 5/8 annulus 17:00 - 20:00 3.00 CASE P INT1 Test BOPS and manifold 250/3500 psi for 5 min. per test, Annular 250/25005 min.,The right to witness test was wavier by John Crisp AOGCC. 20:00 - 20:30 0.50 CASE P INT1 Install wear ring 20:30 - 22:30 2.00 CASE P INT1 Picking up BHA #3 22:30 - 00:00 1.50 CASE P INT1 Picking up 4" pipe out of pipe shed 5/5/2003 00:00 - 01 :00 1.00 CASE P INT1 Picking up 4" pipe out of pipe shed, total 1 08 jts 01 :00 - 02:00 1.00 CASE P INT1 Tripping in to 7010 02:00 - 03:30 1.50 CASE P INT1 Cut and slip drilling line, circ well, while cutting line 03:30 - 04:30 1.00 CASE P INT1 Testing 7 5/8 CSG to 3500 psi for 30 min. 04:30 - 05:30 1.00 DRILL P INT1 Drill float @ 7057and shoe @ 7141, 20 ft of new hole to 7172 05:30 - 06:30 1.00 CASE P INT1 Circ for FIT test 06:30 - 07:00 0.50 CASE P INT1 FIT test to 11.0# 9.2 mud wt. 4342 TVD, 425 psi=11.0 EMW 07:00 - 08:00 1.00 CASE P INT1 Displace well with 9.0 FloPro mud Printed: 5/19/2003 10:37:12 AM ) ) BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-04 MPS-04 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/27/2003 Rig Release: 5/14/2003 Rig Number: Spud Date: 4/27/2003 End: 5/14/2003 Date From - To Hours Task Code NPT Phase Description of Operations 5/512003 08:00 - 00:00 16.00 DRILL P PROD1 Directional Drill 7,172' to 9030' with 250 gals per min 2150 psi 5K bit wt. TQ 7500, P/U 150K, S/O 62K, R/T 102, AST 3.5, ART 5.92 5/6/2003 00:00 - 13:00 13.00 DRILL P PROD1 Directional Drill 9,030' to 9977' TD with 250 gals per min 2150 psi 5K bit wt. 80 RPMS, AST 3.3 ART 4, P/U 135K, Slo 75K, R/T 1 02 13:00 - 15:30 2.50 CASE P COMP Circ three bottoms up with 100 rpms, 280 gals min. 2340 psi 15:30 - 18:00 2.50 CASE P COMP Pump out to CSG shoe @ 7141 with full drilling rate 18:00 - 21 :00 3.00 CASE P COMP Flow check, Pump slug and drop 2" rabbit, Tripping out to BHA 21 :00 - 21 :30 0.50 CASE P COMP Stand back BHA, lay down Motor and MWD 21 :30 - 22:00 0.50 CASE P COMP Rig up to Pickup Liner 22:00 - 00:00 2.00 CASE P COMP PJSM, Picking up 4.5 Liner, Total jts 69 jts 4.5 slotted 12.6# L-80 IBT, 3 Jts 4.5 12.6# L-80 IBT Solid liner 2967 ft. 5/7/2003 00:00 - 00:30 0.50 CASE P COMP Picking up 5.5x 7 58 Baker HMC liner hanger, Baker 5.5x7 5/8 ZXP liner top packer 00:30 - 02:30 2.00 CASE P COMP Tripping in with liner to 7128' 02:30 - 03:00 0.50 CASE P COMP Circulated one drill pipe volume 1.8 BPM at 320 psi 03:00 - 04:00 1.00 CASE P COMP Run in hole with 4" drill pipe and 4-1/2" slotted liner to 9955'. 04:00 - 05:30 1.50 CASE P COMP Establish circulation and recorded PU weight of 135K and SO weight of 87K. Tagged bottom at 9977'. Dropped ball and pumped down, at 1 bbls min. 05:30 - 06:00 0.50 CASE P COMP Set packer and hanger, Pressure up to 4,000psi no indication of ZXP setting, bleed pressure off and repressure up to 4,200 psi, no indication of ZXP setting, pump down backside and pressure to 1500 psi to check packer, packer set, release from liner, liner top 6,982, shoe 9977 06:00 - 07:00 1.00 CASE P COMP Circ bottoms up 07:00 - 09:30 2.50 CASE P COMP POH, and lay down running tool 09:30 - 13:00 3.50 STWHIP P PROD2 Picking up whipstock space out jts and whipstock, whipstock BHA, surface test MWD 13:00 - 16:00 3.00 STWHIP P PROD2 RIH with whipstock 16:00 - 16:30 0.50 STWHIP P PROD2 Orient whipstock and shear off 16:30-19:30 3.00 STWHIP P PROD2 Milling window from 6,859 to 6,871, Drill to 6,883 with 250 gals min. 1080 psi, 125 rpms, 2 to 5k mill wt. 19:30 - 21 :00 1.50 STWHIP P PROD2 Circ, work window, pump sweeps 21 :00 - 23:00 2.00 STWHIP P PROD2 POH , lay down Mills 23:00 - 00:00 1.00 STWHIP P PROD2 Pickup Johnny Wacker, pull wear ring. wash BOPS to remove Metal cuttings 5/8/2003 00:00 - 00:30 0.50 STWHIP P PROD2 Install wear ring 00:30 - 02:00 1.50 STWHIP P PROD2 Picking up BHA # 5 Bit Fm2642 with 3/13 jets,5" Sperrydrill1.5 bend,float sub, 4 3/4 GRlRES, 4 3/4 DM,hang off sub,3 flex dc,jars, surface test MWD 02:00 - 03:00 1.00 STWHIP P PROD2 Picking up 63 jts 4" drill pipe from pipe shed 03:00 - 04:30 1.50 STWHIP P PROD2 Tripping in to 6,850' 04:30 - 05:30 1.00 STWHIP P PROD2 Cut and slip drilling line, service top drive 05:30 - 06:00 0.50 STWHIP P PROD2 Orient and slide tru window 06:00 - 13:30 7.50 DRILL P PROD2 Directional Drill 6883' to 7,516' with 250 gals per min 2300 psi 5K bit wt. 80 RPM, Drilled out the top of OA sand @ 7,326 13:30 - 14:00 0.50 DRILL N DPRB PROD2 Pumped out to 7,200 14:00 - 16:00 2.00 DRILL N DPRB PROD2 Orient and open hole sidetack from 7199 to 7215' 16:00 - 00:00 8.00 DRILL P PROD2 Directional Drill 7,215' to 7989' with 250 gals per min 2300 psi 5K bit wt. 80 RPM, 5/9/2003 00:00 - 00:00 24.00 DRILL P PROD2 Directional Drill 7989' to 10268' with 250 gals per min 2350 psi Printed: 5/19/2003 10:37:12 AM ) ) Operations Summary Report Legal Well Name: MPS-04 Common Well Name: MPS-04 Spud Date: 4/27/2003 Event Name: DRILL +COMPLETE Start: 4/27/2003 End: 5/14/2003 Contractor Name: DOYON DRILLING INC. Rig Release: 5/14/2003 Rig Name: DOYON 14 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/9/2003 00:00 - 00:00 24.00 DRILL P PROD2 5K bit wt. 80 RPM, AST 6.5, ART 11.03, TO 6,000 5/10/2003 00:00 - 10:00 10.00 DRILL P PROD2 Directional Drill 1 0268' to 10,798' with 250 gals per min 2450 psi 5K bit wt. 80 RPM (cross fault 10,660 tru 10685) 10:00-11:00 1.00 DRILL N DPRB PROD2 Pump out to 10,461' 11 :00 - 14:00 3.00 DRILL N DPRB PROD2 Orient and sidetracking well @ 10459-10509' 14:00 - 00:00 10.00 DRILL P PROD2 Directional Drill 1 0509' to 11,071' with 250 gals per min 2450 psi 5K bit wt. 80 RPM (Drilled out bottom of OA @ 10,550 back in OA @ 10685) ( cross fault @ 10845 went out of sand) AST 9.75, ART 7.91, TO 7,500 5/11/2003 00:00 - 02:00 2.00 DRILL P PROD2 Directional Drill 11 ,071' to 11222 with 250 gals per min 2450 psi 5K bit wt. 80 RPM ( cross fault @ 10845 out of sand, back in sand @ 11,197) 02:00 - 03:00 1.00 DRILL N SFAL PROD2 MWD tool Malfuntion, restart same 03:00 - 09:30 6.50 DRILL P PROD2 Directional Drill 11 ,222 to 11,737' TO with 250 gals per min 2450 psi 5K bit wt. 80 RPM. Drill out top of OA at 11560'. 09:30 - 13:00 3.50 CASE P COMP Circulated 4 bottoms up 12,200 stks at 280 gpm at 2500 psi with 100 rotary 13:00 - 17:30 4.50 CASE P COMP Spotted 38 bbl pill with lubricant in open hole. Continued pumping out of hole with 250 gpm. Recording up and down weights every 5 stands in open hole. 17:30 - 19:30 2.00 CASE P COMP Flow check, pump slug, POH to BHA 19:30 - 20:30 1.00 CASE P COMP Lay down BHA 20:30 - 22:30 2.00 CASE P COMP Pick up whipstock pulling tool, and BHA, surface test MWD 22:30 - 00:00 1.50 CASE P COMP RIH with whipstock pulling tool to 5249' 5/12/2003 00:00 - 00:30 0.50 CASE P COMP RIH with whipstock pulling tool to 6778 00:30 - 01 :00 0.50 CASE P COMP Orient and latch whipstock, Jar with 50,000 overpull, came free, flow check well 01 :00 - 03:30 2.50 CASE P COMP Tripping out with whipstock and 3.5 spaceout stinger. 03:30 - 05:00 1.50 CASE P COMP Laying down BHA and, 3.5 space out pipe 05:00 - 05:30 0.50 CASE P COMP Rig up to pickup 4.5 Slotted Liner, PJSM 05:30 - 09:00 3.50 CASE P COMP Picked up and made up one solid bent joint, 113 jts of 4-1/2" 12.6# slotted IBT tubing and one solid joint of 4-1/2" 12.6# L-80 IBT tubing. Made up BOT hook wall hanger assembly. 09:00 - 11 :00 2.00 CASE P COMP Ran in hole with slotted liner on 4" drill pipe. Went out window without orienting. Ran in hole to 11645'. 11 :00 - 12:00 1.00 CASE P COMP Ran in hole with slotted liner to 11657' (12' past window). Pulled up above window with hanger and turn drill pipe 1/4 turn and slacked off through window. Pulled up second time and oriented drill pipe another 1/4 turn and slacked off and hung hook wall hanger in window. 12:00 - 13:30 1.50 CASE P COMP Dropped 29/32" ball and pumped down 40 bbls at 4 bpm 25 bbls at 2 bpm and 20 bbls at 1 bpm (drill pipe capacity 73 bbls). Did not seat ball. Dropped 1-1/2" ball and pumped it down. Pressured up to 3000 psi and released HR tool. 13:30 - 15:00 1.50 CASE N DPRB COMP Rigged up and reversed 2 drill pipe volumes (146 bbls) at 3 bpm and reversed out 1-1/2" ball. 15:00 - 15:30 0.50 CASE P COMP Tripping out, pull 17 stands 15:30 - 16:30 1.00 CASE P COMP Slip and cut drill line 16:30 - 20:00 3.50 CASE P COMP Tripping out, lay down excess pipe, lay down running tools 20:00 - 00:00 4.00 CASE P COMP Pull wear ring, testing Bops and manifold 250-3500 psi 5 min. per test, Annular 250-2500 psi 5 min. per test., install wear ring, The right to witness test was wavier by Jeff Jones AOOGC 5/13/2003 00:00 - 01 :00 1.00 CASE P COMP RIH with HWDP and DC's, lay down same Printed: 5/19/2003 10:37: 12 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BP EXPLORATION Summary MPS-04 MPS-04 DRILL +COMPLETE DOYON DRILLING INC. DOYON 14 Start: 4/27/2003 Rig Release: 5/14/2003 Rig Number: Spud Date: 4/27/2003 End: 5/14/2003 5/13/2003 01 :00 - 03:00 03:00 - 05:30 05:30 - 07:30 07:30 - 08:00 08:00 - 08:30 08:30 - 10:30 10:30 - 17:00 17:00 - 18:30 Hours Task Code NPT Phase 2.00 CASE P 2.50 CASE P 2.00 CASE P 0.50 RUNCOIVP 0.50 RUNCOIVP 2.00 RUNCOIVP 6.50 RUNCOIVP 1.50 RUNCOIVP CaMP CaMP CaMP CaMP CaMP CaMP CaMP CaMP 18:30 - 19:00 0.50 RUNCOIVP CaMP 19:00 - 19:30 0.50 RUNCOIVP CaMP 19:30 - 21 :00 1.50 BOPSURP CaMP 21 :00 - 22:00 1.00 WHSUR P CaMP 22:00 - 00:00 2.00 RUNCOIVP CaMP 5/14/2003 00:00 - 02:00 02:00 - 03:00 03:00 - 04:00 2.00 RUNCOIVP 1.00 RUNCOIVP 1.00 RUNCOIVP CaMP CaMP CaMP Description of Operations RIH with mule shoe to 6800' Displace hole with 8.7 sea water, two hole volumes, follow with 9.2 NaCL completion fluid treated w/ corrosion inhibitor Tripping out, lay down 21 stands 4" drill pipe Pull wear ring - clear rig floor Rig up to run 4 1/2" completion - PJSM running tubing - I wire Make up tail pipe - Packer - Jet Pump - HES XD sliding Sleeve - Phoenix Discharge pressure gauge - Rig up to run I-wire RIH With 41/2" 12.6# L-80 IBT R-3 Tubing and I wire TO 6800' Make up Hanger to I wire - test ports - connections - drain stack - land tubing - PU 1 05K - SO 85K - Total of 77 clamps ran with 154 pins - 161 total 4 1/2" joints 12.6# L-80 IBT tubing ran Run in lock down screws - test TWC from below to 300 psi Clear rig floor - Lay down all vendors tools Nipple down BOP's - Nipple up adapter flange - tree - test to 5000 psi for 10 mins - test good Pull TWC - drop ball / rod - Rig up test manifold - Rig up HB&R PJSM - Test lines to 4500 psi - set packer to 4000 psi - hold for 30 mins - lost 250 psi - bleed tubing down to 2500 psi - test annulus to 4500 psi - hold for 30 mins test good - lost 200 psi on tubing - valve on test manifold failed - Install low torque valve on test manifold - retest tubing to 4000 psi - test good Shear RP valve - Pump 22 bbls diesel - for freeze protection - U-Tube - 0 psi on tubing - 0 psi on annulus Set BPV - 0 psi on tubing / annulus Secure well - Rig down test manifold - Rig released @ 04:00 hrs 5/14/2003 Printed: 5/19/2003 10:37:12 AM Legal Name: Common Name: Test Date 4/30/2003 5/5/2003 MPS-04 MPS-04 Test Type FIT FIT Test Depth (TMD) 2,842.0 (ft) 7,172.0 (ft) BP EXPLORATION Leak-Off . Test Summary Test Depth (TVD) 2,484.0 (ft) 4,342.0 (ft) AMW 9.20 (ppg) 9.20 (ppg) Surface Pressure 300 (psi) 425 (psi) Leak Off Pressure. (BHP) 1,487 (psi) 2,500 (psi) EMW 11.52 (ppg) 11.08 (ppg) -" ~_f Printed: 5/19/2003 10:36:58 AM ) ) 25-May-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-04 Gyro Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ~03-0~;), RECEIVED JUN 0 2 2003 Alaaka Oä & Gas Cons. ConInieeim -n ~asa ~sd..~ Attachment(s) Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-04 Gyro Job No. AKF00002412654, Surveyed: 6 May, 2003 Survey Report 22 May, 2003 Your Ref: API 500292314800 Surface Coordinates: 6000033.25 N. 566033.83 E (70024' 37.8992" N. 149027'44.2776" W) Grid Coordinate System: NAD27 Alaska State Planes. Zone 4 Surface Coordinates relative to Project H Reference: 1000033.25 N. 66033.83 E (Grid) Surface Coordinates relative to Structure: 61.00 N. 310.64 W (True) Kelly Bushing: 72.25ft above Mean Sea Level Elevation relative to Project V Reference: 72.25ft Elevation relatwe to Structure: 72.25ft sr-I''-'Y-SUl'1 DRILLING SEAVlces A Halliburton Company DEFNITIVE ..-- -' Survey Ref: svy1170 '.. Sperry-Sun Drilling Services Survey Report for Milne Point MPS .. MPS.o4 Gyro Your Ref: API 500292314800 Job No. AKF00002412654, Surveyed: 6 May, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -72.25 0.00 0.00 N O.OOE 6000033.25 N 566033.83 E 0.00 Tolerable Gyro 144.00 0.200 195.000 71.75 144.00 0.245 0.07W 6000033.01 N 566033.77 E 0.139 0.24 304.00 0.200 240.000 231.75 304.00 0.655 0.38W 6000032.59 N 566033.46 E 0.096 0.65 All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. ~. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Magnetic Declination at Surface is 25.5200(28-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 304.00ft., The Bottom Hole Displacement is 0.75ft., in the Direction of 210.175° (True). Survey tool program for MPS-04 Gvro From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 0.00 304.00 304.00 Tolerable Gyro .~ 22 May, 2003 - 14:43 Page 20f2 DrillQuest 3.03.02.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-04 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 9,977.00' MD ') 25-May-03 (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ()..,D3 - D 5~ RECEIVED JUN 0 2 2003 AI.. Oil & Gsa Coni. CoomiIeion ~ ~ 0. ~~ Sperry-Sun Drilling Services Milne Point Unit BPXA Milne Point MPS MPS-04 Job No. AKZZ0002412654, Surveyed: 6 May, 2003 Survey Report 22 May, 2003 Your Ref: API 500292314800 Surface Coordinates: 6000033.25 N, 566033.83 E (70024' 37.8992" N, 149027'44.2776" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1000033.25 N, 66033.83 E (Grid) Surface Coordinates relative to Structure: 61.00 N, 310.64 W (True) Kelly Bushing: 72.25ft above Mean Sea Level Elevation relative to Project V Reference: 72.25ft Elevation relative to Structure: 72.25ft 5PE!r'~Y-!5Uf1 DRILLING SERVices A Halliburton Company )EF"NITIVE ~ -- Survey Ref: svy1171 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-04 Your Ref: API 500292314800 Job No. AKZZ0002412654, Surveyed: 6 May, 2003 BP EXPLORA TION (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 304.00 0.200 240.000 231.75 304.00 0.65 S 0.38W 6000032.59 N 566033.46 E 0.65 AK-6 BP _IFR-AK 393.64 0.200 243.550 321.39 393.64 0.80 S 0.65W 6000032.44 N 566033.18 E 0.014 0.80 452.30 0.090 251.940 380.05 452.30 0.86S 0.79W 6000032.38 N 566033.05 E 0.190 0.86 536.17 0.880 53.660 463.92 536.17 0.50 S 0.33W 6000032.75 N 566033.50 E 1.152 0.50 580.00 1.850 38.000 507.73 579.98 0.26 N 0.37 E 6000033.51 N 566034.20 E 2.351 -026 665.89 3.910 45.350 593.51 665.76 3.41 N 3.31 E 6000036.69 N 566037.11 E 2.432 -3.41 -/ 754.74 6.840 49.030 681.96 754.21 9.01 N 9.46 E 6000042.34 N 566043.21 E 3.319 -9.01 852.4 7 9.260 52.450 778.72 850.97 17.62 N 20.09 E 6000051.04 N 566053.76 E 2.523 -17.62 947.30 12.410 53.820 871.85 944.10 28.29 N 34.37 E 6000061.84 N 566067.95 E 3.333 -28.29 1043.19 15.780 54.920 964.84 1037.09 41.87 N 53.36 E 6000075.59 N 566086.82 E 3.525 -41.87 1139.18 16.960 58.250 1056.94 1129.19 56.73 N 75.95 E 6000090.65 N 566109.27 E 1.570 -56.73 1235.80 18.590 59.200 1148.94 1221.19 72.04 N 101.16 E 6000106.18 N 566134.35 E 1.713 -72.04 1330.32 21 .790 57.770 1237.64 1309.89 89.11 N 128.95 E 6000123.50 N 566161.99 E 3.425 -89. 11 1426.88 25.080 56.310 1326.23 1398.48 110.03 N 161.15 E 6000144.70 N 566194.00 E 3.460 -110.03 1523.52 25.610 56.730 1413.56 1485.81 132.85 N 195.65 E 6000167.82 N 566228.30 E 0.579 -132.85 1619.91 25.200 57.140 1500.63 1572.88 155.41 N 230.31 E 6000190.69 N 566262.76 E 0.463 -155.41 1716.02 25.800 57.520 1587.38 1659.63 177.74 N 265.14 E 6000213.33 N 566297.39 E 0.647 -177.74 1813.00 26.240 57.350 1674.53 1746.78 200.64 N 300.99 E . 6000236.55 N 566333.04 E 0.460 -200.64 1908.84 28.280 56.920 1759.72 1831.97 224.47 N 337.86 E 6000260.70 N 566369.69 E 2.138 -224.4 7 2004.96 30.230 55.930 1843.58 1915.83 250.45 N 376.99 E 6000287.03 N 566408.59 E 2.090 -250.45 2100.39 34.380 53.360 1924.22 1996.47 280.01 N 418.53 E 6000316.95 N 566449.86 E 4.580 -280.01 2197.17 37.780 55.180 2002.43 2074.68 313.25 N 464.80 E 6000350.60 N 566495.85 E 3.683 -313.25 2292.30 41 .190 55.320 2075.84 2148.09 347.72 N 514.50 E 6000385.51 N 566545.24 E 3.586 -347.72 2387.13 45.710 56.450 2144.67 2216.92 384.27 N 568.49 E 6000422.53 N 566598.90 E 4.836 -384.27 .~. 2480.88 49.890 56.830 2207.63 2279.88 422.44 N 626.49 E 6000461.22 N 566656.56 E 4.469 -422.44 2577.14 53.760 57.900 2267.11 2339.36 463.23 N 690.21 E 6000502.56 N 566719.92 E 4.114 -463.23 2673.81 56.840 57.610 2322.14 2394.39 505.63 N 757.42 E 6000545.56 N 566786.75 E 3.196 -505.63 2770.41 59.820 58.180 2372.85 2445.10 549.31 N 827.06 E 6000589.85 N 566856.00 E 3.125 -549.31 2795.72 60.680 58.400 2385.41 2457.66 560.86 N 845.75 E 6000601.57 N 566874.59 E 3.481 -560.86 2892.66 62.850 59.000 2431.27 2503.52 605.23 N 918.73 E 6000646.58 N 566947.17 E 2.304 -605.23 2987.75 63.560 58.400 2474.13 2546.38 649.32 N 991.25 E 6000691.31 N 567019.30 E 0.935 -649.32 3084.66 63.190 56.460 2517.57 2589.82 695.96 N 1064.26 E 6000738.59 N 567091.89 E 1.830 -695.96 3180.77 62.430 56.330 2561.48 2633.73 743.27 N 1135.46 E 6000786.53 N 567162.67 E 0.800 -743.27 3277.19 61.520 56.360 2606.79 2679.04 790.44 N 1206.31 E 6000834.32 N 567233.10 E 0.944 -790.44 3373.36 61.740 56.410 2652.48 2724.73 837.29 N 1276.77 E 6000881.79 N 567303.15 E 0.233 -837.29 22 May, 2003 - 14:43 Page 20'6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-04 Your Ref: API 500292314800 Job No. AKZZ0002412654, Surveyed: 6 May, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3469.56 63.880 57.240 2696.44 2768.69 884.10 N 1348.40 E 6000929.24 N 567374.36 E 2.353 -884.10 3565.58 64.01 0 57.720 2738.62 2810.87 930.47 N 1421.13 E 6000976.25 N 567446.68 E 0.469 -930.47 3660.99 64.490 57.320 2780.07 2852.32 976.62 N 1493.62 E 6001023.04 N 567518.76 E 0.629 -976.62 3757.76 64.490 57.570 2821.74 2893.99 1023.62 N 1567.24 E 6001070.69 N 567591.96 E 0.233 -1023.62 3853.58 63.960 57.030 2863.41 2935.66 1070.23 N 1639.85 E 6001117.94 N 567664.15 E 0.751 -1070.23 3948.03 63.610 57.610 2905.13 2977.38 1115.99 N 1711.17 E 6001164.32 N 567735.07 E 0.664 -1115.99 '--- 4042.31 63.520 57.480 2947.10 3019.35 1161.29 N 1782.41 E 6001210.25 N 567805.90 E 0.156 -1161.29 4135.26 63.890 57.490 2988.28 3060.53 1206.08 N 1852.67 E 6001255.67 N 567875.77 E 0.398 -1206.08 4231.63 64.820 57.340 3029.99 3102.24 1252.87 N 1925.88 E 6001303.10 N 567948.55 E 0.975 -1252.87 4328.66 62.700 55.660 3072.89 3145.14 1300.89 N 1998.45 E 6001351.76 N 568020.70 E 2.680 -1300.89 4424.59 62.710 55.700 3116.88 3189.13 1348.96 N 2068.86 E 6001400.44 N 568090.68 E 0.038 -1348.96 4520.44 63.260 56.090 3160.41 3232.66 1396.83 N 2139.56 E 6001448.95 N 568160.96 E 0.679 -1396.83 4616.21 63.740 55.970 3203.15 3275.40 1444.72 N 2210.64 E 6001497.46 N 568231.61 E 0.514 -1444.72 4711.78 63.890 55.410 3245.32 3317.57 1493.07 N . 2281.48 E 6001546.43 N 568302.02 E 0.549 -1493.07 4807.80 62.420 55.360 3288.68 3360.93 1541.73 N 2351.98 E 6001595.72 N 568372.09 E 1.532 -1541.73 4903.06 61.040 55.010 3333.80 3406.05 1589.63 N 2420.86 E 6001644.22 N 568440.54 E 1.484 -1589.63 4998.91 60.540 54.710 3380.57 3452.82 1637.78 N 2489.28 E 6001692.98 N 568508.53 E 0.589 -1637.78 5093.39 61.750 55.670 3426.17 3498.42 1685.01 N 2557.22 E . 6001740.81 N 568576.05 E 1.560 -1685.01 5189.42 61 .600 55.860 3471.73 3543.98 1732.57 N 2627.11 E 6001788.98 N 568645.51 E 0.234 -1732.57 5285.36 61.270 55.510 3517.60 3589.85 1780.07 N 2696.70 E 6001837.10 N 568714.69 E 0.470 -1780.07 5381.93 62.080 56.800 3563.43 3635.68 1827.41 N 2767.30 E 6001885.06 N 568784.87 E 1.444 -1827.41 5478.77 61.670 59.890 3609.08 3681.33 1872.23 N 2839.99 E 6001930.52 N 568857.15 E 2.846 -1872.23 5572.88 62.300 62.610 3653.29 3725.54 1912.18 N 2912.82 E 6001971.11 N 568929.63 E 2.638 -1912.18 5669.05 63.390 66.290 3697.20 3769.45 1949.07 N 2990.01 E 6002008.67 N 569006.49 E 3.588 -1949.07 '--" 5764.37 64.300 70.870 3739.23 3811.48 1980.29 N 3069.63 E 6002040.60 N 569085.83 E 4.417 -1980.29 5860.02 63.950 73.630 3780.98 3853.23 2006.52 N 3151.58E 6002067.56 N 569167.55 E 2.622 -2006.52 5954.34 63.960 76.770 3822.40 3894.65 2028.17 N 3233.50 E 6002089.93 N 569249.27 E 2.991 -2028.17 6051.13 63.680 80.160 3865.12 3937.37 2045.54 N 3318.59 E 6002108.05 N 569334.20 E 3.156 -2045.54 6144.56 64.840 83.770 3905.70 3977.95 2057.28 N 3401.90 E 6002120.53 N 569417.41 E 3.695 -2057.28 6240.82 66.110 89.240 3945.68 4017.93 2062.60 N 3489.27 E 6002126.62 N 569504.73 E 5.335 -2062.60 6337.29 66.110 93.590 3984.77 4057.02 2060.42 N 3577.42 E 6002125.22 N 569592.89 E 4.123 -2060.42 6433.71 67.080 99.280 4023.09 4095.34 2050.49 N 3665.30 E 6002116.07 N 569680.86 E 5.508 -2050.49 6529.52 66.400 102.640 4060.94 4133.19 2033.77 N 3751.70 E 6002100.11 N 569767.40 E 3.299 -2033.77 6626.42 67.210 107.690 4099.12 4171.37 2010.47 N 3837.63 E 6002077.57 N 569853.53 E 4.862 -2010.47 6722.37 67.650 110.330 4135.96 4208.21 1981.61 N 3921.39 E 6002049.45 N 569937.54 E 2.582 -1981.61 22 May, 2003 - 14:43 Page 3 of6 Dri/lQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-04 Your Ref: API 500292314800 Job No. AKZZ0002412654, Surveyed: 6 May, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6818.42 69.130 114.180 4171.34 4243.59 1947.78 N 4004.00 E 6002016.36 N 570020.46 E 4.032 -1947.78 6916.15 70.010 117.290 4205.46 4277.71 1908.01 N 4086.49 E 6001977.32 N 570103.29 E 3.115 -1908.01 7010.48 73.300 119.740 4235.15 4307.40 1865.26 N 4165.13 E 6001935.27 N 570182.31 E 4.271 -1865.26 7086.74 75.850 121.070 4255.43 4327.68 1828.06 N 4228.53 E 6001898.62 N 570246.03 E 3.743 -1828.06 7182.24 81.210 126.160 4274.43 4346.68 1776.25 N 4306.39 E 6001847.50 N 570324.35 E 7.666 -1776.25 7227.45 84.870 132.140 4279.91 4352.16 1747.93 N 4341.17 E 6001819.49 N 570359.37 E 15.423 -1747.93 -- 7276.15 87.960 137.700 4282.96 4355.21 1713.62 N 4375.56 E 6001785.49 N 570394.07 E 13.041 -1713.62 7323.51 88.090 140.660 4284.59 4356.84 1677.81 N 4406.50 E 6001749.95 N 570425.32 E 6.252 -1677.81 7373.21 88.640 139.760 4286.01 4358.26 1639.63 N 4438.29 E 6001712.06 N 570457.45 E 2.122 -1639.63 7420.63 88.950 138.850 4287.01 4359.26 1603.69 N 4469.20 E 6001676.39 N 570488.68 E 2.027 -1603.69 7471.24 88.950 144.560 4287.94 4360.19 1563.99 N 4500.55 E 6001636.97 N 570520.38 E 11.280 -1563.99 7517.14 89.140 144.480 4288.70 4360.95 1526.62 N 4527.19 E 6001599.84 N 570547.34 E 0.449 -1526.62 7565.77 89.810 145.900 4289.15 4361.40 1486.69 N 4554.95 E 6001560.16 N 570575.45 E 3.229 -1486.69 7613.29 90.490 148.490 4289.02 4361.27 1446.76 N 4580.69 E 6001520.45 N 570601.55 E 5.635 -1446.76 7662.99 90.990 148.580 4288.38 4360.63 1404.37 N 4606.63 E 6001478.29 N 570627.86 E 1.022 -1404.37 7709.75 91.420 149.000 4287.40 4359.65 1364.38 N 4630.85 E 6001438.52 N 570652.44 E 1.285 -1364.38 7759.91 91.110 152.110 4286.29 4358.54 1320.72 N 4655.50 E 6001395.08 N 570677.4 7 E 6.229 -1320.72 7804.82 91.110 155.530 4285.42 4357.67 1280.43 N 4675.31 E . 6001354.97 N 570697.64 E 7.614 -1280.43 7854.24 91.480 155.840 4284.30 4356.55 1235.41 N 4695.65 E 6001310.12 N 570718.38 E 0.977 -1235.41 7899.39 90.990 154.470 4283.33 4355.58 1194.45 N 4714.62 E 6001269.33 N 570737.70 E 3.222 -1194.45 7949.33 91.300 154.160 4282.33 4354.58 1149.45 N 4736.26 E 6001224.53 N 570759.74 E 0.878 -1149.45 7993.93 90.560 158.730 4281.61 4353.86 1108.58 N 4754.07 E 6001183.82 N 570777.92 E 10.379 -1108.58 8043.93 92.220 161.130 4280.39 4352.64 1061.64 N 4771.23 E 6001137.03 N 570795.48 E 5.835 -1061.64 8089.95 91.670 164.910 4278.83 4351.08 1017.66 N 4784.66 E 6001093.17 N 570809.30 E 8.296 -1017.66 - 8143.86 92.900 167.900 4276.68 4348.93 965.31 N 4797.32 E 6001040.93 N 570822.42 E 5.993 -965.31 8185.82 92.840 172.360 4274.58 4346.83 924.03 N 4804.50 E 6000999.72 N 570829.97 E 10.617 -924.03 8236.42 91.610 175.160 4272.61 4344.86 873.77 N 4809.99 E 6000949.52 N 570835.91 E 6.040 -873.77 8281.03 92.040 180.280 4271.19 4343.44 829.24 N 4811.77 E 6000905.00 N 570838.08 E 11.512 -829.24 8331.64 91.980 182.270 4269.42 4341.67 778.67 N 4810.64 E 6000854.42 N 570837.40 E 3.931 -778.67 8378.07 90.430 185.510 4268.44 4340.69 732.37 N 4807.49 E 6000808.09 N 570834.66 E 7.734 -732.37 8428.31 90.680 186.050 4267.95 4340.20 682.38 N 4802.43 E 6000758.07 N 570830.04 E 1.184 -682.38 8472.49 89.260 186.060 4267.98 4340.23 638.45 N 4797.77 E 6000714.10 N 570825.77 E 3.214 -638.45 8522.39 89.810 185.430 4268.38 4340.63 588.81 N 4792.78 E 6000664.41 N 570821.21 E 1.676 -588.81 8568.84 90.310 184.670 4268.33 4340.58 542.54 N 4788.69 E 6000618.10 N 570817.53 E 1.958 -542.54 8618.80 90.740 184.390 4267.88 4340.13 492.73 N 4784.74 E 6000568.27 N 570814.03 E 1.027 -492.73 22 May, 2003 - 14:43 Page 4 of6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-04 Your Ref: AP/500292314800 Job No. AKZZ0002412654, Surveyed: 6 May, 2003 BP EXPLORA TlON (ALASKA) INC. BPXA Milne Point Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8665.00 91.050 184.470 4267.15 4339.40 446.68 N 4781.18E 6000522.18 N 570810.87 E 0.693 -446.68 8715.16 91.670 183.460 4265.96 4338.21 396.65 N 4777.71 E 6000472.13 N 570807.84 E 2.362 -396.65 8761.07 92.350 183.290 4264.35 4336.60 350.85 N 4775.01 E 6000426.30 N 570805.55 E 1.527 -350.85 8809.73 90.250 184.770 4263.25 4335.50 302.33 N 4771.59 E 6000377.75 N 570802.56 E 5.279 -302.33 8855.82 90.120 184.060 4263.10 4335.35 256.38 N 4768.04 E 6000331.77 N 570799.42 E 1.566 -256.38 8906.4 7 90.740 184.230 4262.72 4334.97 205.86 N 4764.38 E 6000281.22 N 570796.20 E 1.269 -205.86 --' 8952.29 91.300 183.670 4261.90 4334.15 160.16 N 4761.22 E 6000235.50 N 570793.45 E 1.728 -160.16 9000.12 89.200 184.130 4261.70 4333.95 112.44 N 4757.97 E 6000187.75 N 570790.62 E 4.495 -112.44 9045.62 89.690 183.790 4262.14 4334.39 67.05 N 4754.83 E 6000142.34 N 570787.88 E 1.311 -67.05 9094.52 89.940 184.410 4262.29 4334.54 18.28 N 4751.33 E 6000093.53 N 570784.81 E 1.367 -18.28 9142.42 88.890 182.940 4262.78 4335.03 29.52 S 4748.26 E 6000045.71 N 570782.17 E 3.771 29.52 9190.41 90.060 183.210 4263.22 4335.47 77.44 S 4745.69 E 5999997.77 N 570780.02 E 2.502 77.44 9237.63 91.110 183.920 4262.74 4334.99 124.56 S 4742.75 E 5999950.62 N 570777.50 E 2.684 124.56 9286.12 91.170 183.640 4261.78 4334.03 172.94 S 4739.56 E 5999902.22 N 570774.73 E 0.590 172.94 9334.69 91.360 184.100 4260.70 4332.95 221.39 S 4736.28 E 5999853.75 N 570771.88 E 1.024 221.39 9383.30 91.790 185.750 4259.37 4331.62 269.80 S 4732.11 E 5999805.30 N 570768.14 E 3.506 269.80 9430.92 86.790 185.270 4259.96 4332.21 317.18 S 4727.54 E 5999757.88 N 570763.99 E 10.548 317.18 9481.43 86.110 184.710 4263.09 4335.34 367.40 S 4723.15 E 5999707.62 N 570760.04 E 1.743 367.40 9526.76 89.570 185.300 4264.79 4337.04 412.52 S 4719.20 E 5999662.47 N 570756.49 E 7.743 412.52 9576.27 89.880 185.760 4265.03 4337.28 461.80 S 4714.43 E 5999613.15 N 570752.16 E 1.120 461.80 9623.26 90.490 186.550 4264.88 4337.13 508.51 S 4709.39 E 5999566.39 N 570747.53 E 2.124 508.51 9673.58 89.630 183.010 4264.83 4337.08 558.65 S 4705.20 E 5999516.22 N 570743.78 E 7.240 558.65 9719.65 88.520 181.570 4265.57 4337.82 604.68 S 4703.36 E 5999470.18 N 570742.35 E 3.946 604.68 9771.48 89.010 181.060 4266.69 4338.94 656.48 S 4702.17 E 5999418.37 N 570741.62 E 1.364 656.48 -' 9816.16 90.310 182.230 4266.95 4339.20 701.14 S 4700.89 E 5999373.70 N 570740.73 E 3.914 701.14 9865.60 91.230 181.430 4266.29 4338.54 750.55 S 4699.31 E 5999324.28 N 570739.59 E 2.466 750.55 9910.07 90.490 180.860 4265.62 4337.87 795.00 S 4698.42 E 5999279.82 N 570739.09 E 2.100 795.00 9977.00 90.490 180.860 4265.05 4337.30 861.92 S 4697.41 E 5999212.89 N 570738.68 E 0.000 861.92 Projected Survey 22 May, 2003 - 14:43 Page 50f6 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-04 Your Ref: API 500292314800 Job No. AKZZOO02412654, Surveyed: 6 May, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). i ',-. Magnetic Declination at Surface is 25.5200(28-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 9977.00ft., The Bottom Hole Displacement is 4775.84ft., in the Direction of 100.397° (True). .---' Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9977.00 4337.30 861.92 S 4697.41 E Projected Survey Survey tool program for MPS-04 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) -- 0.00 304.00 0.00 304.00 304.00 9977.00 304.00 Tolerable Gyro (MPS-04 Gyro) 4337.30 AK-6 BP -'FR-AK (MPS-Q4) 22 May, 2003 - 14:43 Page 60f6 DrillQuest 3.03.02.005 it ~~!Æ~¡ ~ f !Æ~!Æ~~~!Æ FRANK H. MURKOW5KI, GOVERNOR ~ AI',ASIiA OIL A1Q) GAS CONSERVATION COMMISSION 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPS 04 BP Exploration (Alaska), Inc. Permit No: 203-052 Surface Location: 3364' NSL, 4757' WEL, Sec. 07, TI2N, RIlE, UM Bottomhole Location: 2505' NSL, 93' WEL, Sec. 07, TI2N, RIlE, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title .20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours. notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, !~u~~ Commissioner BY ORDER OF THE COMMISSION DATED thiQ3 day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and·Refineries Section 1 a. Type of work II Drill 0 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface x = 566034, Y = 6000033 33641 NSL, 4757' WEL, SEC. 07, T12N, R11E, UM At top of productive interval x = 570267, Y = 6001900 5192' NSL, 500' WEL, SEC. 07, T12N, R11 E, UM (OB) At total depth x = 570709, Y = 5999217 2505' NSL, 93' WEL, SEC. 07, T12N, R11 E, UM (OB) ( STATE OF ALASKA t' ALASKA UIL AND GAS CONSERVATION COMMI~BION PERMIT TO DRILL 20 MC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Planned KBE = 72' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380110 7. Unit or Property Name Milne Point Unit 8. Well Number MPS-04 9. Approximate spud date 04/22/03 Amount $200,000.00 14. Number of acre§jn pr9perty 15. Proposed depth (MD and TVD) 2j6O 2....,31 jí}- 9984' MD / 4311' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 92 0 Maximum surface 1397 psig, At total depth (TVD) 4273' / 1824 psig Setting Depth Top Bottom MD TVD Mn TVn Surface Surface 112' 112' Surface Surface 2864' 2482' Surface Surface 7126' 4334' 6976' 4294' 9984' 4311' Áy '7~ '-Í (el 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL 047446,2505' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 450' MD Maximum Hole Angle 18. Casing~~~gram Specifications Hole CasinÇJ WeiQht Grade COlJplinO 42" 20" 92# H-40 Welded 13-1/2" 10-3/4" 45.5# L-80 BTC 9-7/8" 7-5/8" 29.7# L-80 BTC 6-1/8" 4-1/2" 12.6# L-80 BTC ~ enoth 80' 2864' 71261 3008' Quantity of Cement Onclude staQe dataJ ,260 sx Arctic Set (Approx.) 639 sx PF 'L', 261 sx Class 'G' 125 sx PF 'E', 336 sx class 'G' Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD MAH 2 5 ~~!OO] Perforation depth: measured I ,1,1 I'!> r'·".-. ("~~"''''~''':':, "':00 AI~\" ,~r ;;'.; ',' ", ,Ù', ' ,," \.~,."~.,....",,,,I ,,*11I11\...."';,··..· ' ~tl;.:': \'.J'IDg.:e true vertical II Filing Fee 0 Property Plat II Drilling Fluid Program 0 Time vs Depth Plot Contact Engineer Name/Number: Matt Green, 564-5581 21. I hereby certify that the is true and correct to the best of my knowledge Signed Pat Archey Title Senior Drilling Engineer o BOP Sketch 0 Diverter Sketch II Drilling Program o Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Prepared By Name/Number: Sandra Stewman, 564-4750 20. Attachments Date 3/ Permit Number API Number 2' "2 j. ( /0 -.7"-,. )...DE -05"2- 50- D2-1- => 7 D - Ot-J Conditions of Approval: Samples Required 0 Yes 25J No Hydrogen Sulfide Measures 0 Yes gf No Required Working Pressure for BOPE 0 2K Other: ~s~a~",:,;" ~~Ç>-\~~\- , p "'p' ~ by order of ~:O~~~i Rev. 12-b:;/) fl-- '--L 0 R11jf1\1A Lhecommission A~~~val~te See cover letter D š1 tJ3 0 ~ for other reauirements Mud Log Requi ed 0 Yes 1&1 No Directional Survey Required œYes 0 No o 3K D4K D5K D10K D15K 0 3.5K psi for CTU Date CJflðV~ç Submit In Triplicate ( Milne POr" 'VIPS-04 Well Permit lWell Name: I MPS-04 Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Multi Lateral Producer "OA" & "OB" Surface Location: 19151 FNL, (33641 FSL), 4757' FEL, (241 FWL), SEC. 7, T12N, R11 E E=566033.83 N=6000033.25 9971 FNL, (42821 FSL), 5258' FEL, (211 FWL), SEC. 8, T12N, R11 E E=570800 N=6000995 Z=4226'TVD 46481 FNL, (6311 FSL), 4993' FEL, (2871 FWL), SEC. 8, T12N, R11 E E=571113 N=5997347 Z=4252' TVD 881 FNL, (51921 FSL), 500' FEL, (42731 FWL), SEC. 7, T12N, R11E E=570267 N=6001900 Z=4262' TVD 27741 FNL, (25051 FSL), 93' FEL, (46921 FWL), SEC. 7, T12N, R11 E E=570709 N=5999217 Z=4239' TVD Target Location: TOP "OA" Target Location: BHL "OA" Well TD ...,. Target Location: <' TOP "OB" Target Location: BHL "OB" Well TD ~ I AFE Number: I TBD I Ri~: 1 Doyon 14 1 I Estimated Start Date: 122 Apr 2003 I Operatin~ days to complete: 115.8 1 I MD: 19,984 I I TVD: 14,311 1 I Max Inc: 192 1 I KOP: 1450 I 1 KBE: 1721 I Well DesiQn (conventional, slim hole, etc.): I Conventional Grass Roots ML Producer I I Objective: 1 Schrader Bluff OB Sand 1 Mud PrOQram: 13.5-in Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density (pPQ) Funnel Vis VP HTHP pH API Filtrate LG Solids 8.6 - 9.2 75 - 150 25 - 60 N/A 9.0 - 9.5 < 12 < 6.5 9.875-in Intermediate Hole Mud Properties: LSND Freshwater Mud Density (pPQ) PV VP HTH P pH API Filtrate LG Solids 8.8 - 9.2 10 - 20 25 - 30 10 - 11 9.0 - 9.5 < 6 < 15 6.125-in Production Hole Mud Properties: KCI-CaCOs FloPro Density (pPQ) PV VP HTHP pH API Filtrate MBT 9.0 - 9.3 10 - 20 25 - 30 10 - 11 9.0 - 9.5 < 6 < 7 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to D8-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU lR. 1 ~, Cement Pro~ram: Casing 10.75-in 40-lb/ft L-80 BTC surface casing Size Basis Milne par' MPS-04 Well Permit 2500/0 excess over gauge hole in permafrost interval. 40% excess over gauge hole below permafrost. Top of tail cement 500-ft MD above casinÇ) shoe. Total Cement Wash 20-bbl Water Spacer Vol: 527-bbl Spacer 50-bbI10.3-lb/Qal un-viscosified Alpha spacer Lead 473-bbl, 639-sx 10.7-lb/gal Permafrost L - 4.15 ft~/sx (cement to surface) Tail 54-bbl, 261-sx 15.8-lb/gal Premium G - 1.15 ft~/sx of tail at Temp BHST = 55°F from SOR, BHCT 60°F estimated by Halliburton Casing Size Basis 7.625-in 29.7-lb/ft L-80 BTC intermediate casing Top of lead cement 500-ft above top of Ugnu-sand. 00/0 excess over gauge. Top of tail cement 500-ft MD above top of N-sand. 40% excess over Qauge. Total Cement Wash 5-bbl Water Vol: 117-bbl Spacer 30-bbI10.3-lb/Qal un-viscosified Alpha Spacer Lead 48-bbl, 125-sx 12.0-lb/gal Permafrost E - 2.17 fe/sx (top of lead at 4,652-ft MD) Tail 69-bbl, 336-sx 15.6-lb/gal Premium G - 1.22 ft~/sx to of tail at 5,913-ft MD Temp BHST = 80°F from SOR, BHCT 70°F estimated by Halliburton Evaluation Program: 13.5-in Hole Section: Open Hole: MWD/GR, IFR/CASANDRA Cased Hole: N/A 9.875-in Hole Section: Open Hole: MWD/GRlRES, GeoTap, IFRlCASANDRA Cased Hole: N/A 6.125-in Hole section: Open Hole: MWD/GRlRES, ABI/IFR/CASANDRA Cased Hole: N/A 2 :( Milne por'" MPS-04 Well Permit Formation Markers Formation Tops MOrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 1896 1822 8.35 TUZC 5152 3534 1503 8.35 NA 6413 4100 1749 8.35 NB 6494 4132 1763 8.35 NC 6576 4163 1776 8.35 NE 6614 4177 1782 8.35 NF 6754 4226 1804 8.35 Top OA 6901 4273 1824 8.35 Base OA 7009 4304 1838 8.35 Top OB 7126 4334 1851 8.35 OWC 7195 4348 1857 8.35 * Based on SS depths Casingrrubinfl ProQram Hole Size Csg/ WtlFt Grade Conn Length Top Bottom Tbg O.D. MD / TVDrkb MD / TVDrkb 42-in 20-in* 92# H-40 Welded 80' 0' 112' / 112' 13.5-in 10.75-in 45.5# L-80 BTC 2,864' 0' 2,864' / 2,482' 9.875-in 7.625-in 29.7# L-80 BTC 7,126' 0' 7,126' / 4,334' -"."'~ 6.125-in 4.5-in 12.6# L-80 BTC 3,008' 6,976' / 4,294' 9,984' /4,311' OB Slotted 6.125-in 4.5-in 12.6# L-80 BTC 5,021' 6,901' / 4,273' 11,922' / 4,324' OA Slotted * The 20-in conductors are insulated. "" Recommended Bit Pro~ram BHA Hole Size Depth (MD) Bit Type 1 13.5-in 0' - 2,864' Smith MGXi 2 9.875-in 2,864' - 7,126' Smith FGXiCPS 3 6.125-in 7,126' - TO Security FM2643 4 6.125-in 6,976' - TO Security FM2643 Nozzle/Flow rate 3-15 & 1-1 0 3-15 & 1-1 0 3-12 3-12 3 ( Milne par' MPS-04 Well Permit Well Control: Surface hole will be drilled with a diverter. Intermediate hole: · Maximum anticipated BHP: · Maximum surface pressure: 1,824-psi @ 4,273-ft TVDrkb - Top of "OA" 1 ,397 -psi @ surface (Based on BHP and a full column of gas from TO @ 0.1-psi/ft) 3,500-psi. An FIT to 11.5-lb/gal will be made on the 10. 75-in casing shoe. 89-bbl with 9.2-lb/gal mud. 9.7-lb/gal brine / 7.0-lb/gal Diesel (1,800-ft MD). '-;S \d ~ ~~ .. . Planned BOP test pressure: · Integrity test: Kick tolerance: · Planned completion fluid: Drilling Hazards & Contingencies: Hydrates · Hydrates have not been seen on S pad, but has been encountered in the surface holes on other pads, especially nearby H-Pad. Hydrates generally occur just below the Permafrost (+/- 1800 ss) but may be present in shallower SV sands and also as deep as 3000 ft. Be alert for the possibility of shallow gas and/or hydrates. Use recommended practices for drilling hydrates. Increase mud wt; Maintain cool mud « 60 deg F); Limit ROP and reduce pump rate while drilling hydrates; Circulate connections thoroughly. See Well Program and Recommended Practices for specific information. · Another item to watch out for is deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · We do not expect losses while drilling this well. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Below is a list of the wells and the lost circulating problems associated with them. H-06 (1995): Lost 100 bbls running 9-5/8" casing, good returns during cementing except no returns for last 20 bbls, contaminated cement to surface, cement 12 ft down, no top job. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be (8.35 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.1-lb/gal mud. 4 ( Milne por+ MPS-04 Well Permit Pad Data Sheet · Please Read the S-Pad Data Sheet thoroughly. Breathing · N/A Hydrocarbons · Hydrocarbons will be encountered in the NA through the Schrader Bluff. Faults · A 160-ft down to west fault in the Ugnu at 2,500-ft TVDss, 3,OOO-ft MD · A 15-ft down to east fault in the NA-NB at 4,050-ft TVDss, 6,450-ft MD · A 30-ft down to east fault in the OA-OB at 4,220-ft TVDss, 7, 750-ft MD · A 40-ft down to east fault in the OA-OB at 4,21 O-ft TVDss, 10,900-ft MD Hydrogen Sulfide · MPS Pad is not designated as an H2S Pad. Anti-collision Issues · MPS-04 has no anti-collision issues. 5 ( Milne por+ MPS-04 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. The 20-in insulated conductor is installed 2. NU diverter Procedure k 1. MI/RU Doyon 14 2. Function test diverter, PU 4.0-in drill pipe 3. Drill 13.5-in surface hole 4. Run and cement 10. 75-in casing 5. ND diverter, install wellhead, NU BOPE and test 6. Drill 9.875-in intermediate hole 7. Run and cement 7.625-in casing 8. Drill 6.125-in OB horizontal production hole 9. Run 4.5-in slotted liner 10. Run whipstock and mill window for OA lateral 11. Drill 6.125-in OA horizontal production hole 12. Retrieve whipstock 13. Run 4.5-in slotted liner and hang off in 7.625-in casing 14. Displace drilling mud to brine 15. Run 4.5-in jet pump completion ~ 16. ND /NU 17. Freeze protect well 18. RD/MO 6 ~ \ ~\ C"? A. V4-~-~~\ \- ~ ~-b\.\ '-~ PHOPOSI::IJ COMPLI:: liON rpS-04 lLMP!=\.-04 \ 1 ,(~~ 20" 92 Iblft. H-40 Welded /. Insulated Diesel Freeze protect to 750' MD TREE: . Cameron 4-1/16" 5M WELLHEAD: FMC Gen 6 11 ", 5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger 1121 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling OD: 11.75" Burst: 5,210 psi Collapse: 2,480 psi 7-5/811 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing ID: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi ... /......... if ~III 9.2 KCI with corrosion inhibitor as packer fluid Jet Pump Installed in - Sliding Sleeve Post rigl Window in 7-5/8" casing @ 6911' MD Well Inclination @ Window = 73 Degrees - KB. ELEV =66.8' Cellar Box ELEV = 38.3' ... 42" Hole 4-1/2" x 1" Gas Lift Mandrel @ 2,000' MD , 2000' TVD, RP shear valve open position, "X" Nipple (2.813" ID) 70' below GLM 4-1/2", 12.6Ib/ft, L-80. IBT-M Coupling OD: 5.2" DrifVlD: 3.833" Burst: 8,430, 80% 6,744 psi Collapse: 7,500. 80%=6.000 psi ~ 10-3/4"@ 2,864' MD, 2482' TVD/RKB ~ '" BIW 1- Wire Phoenix Pressure Gauge (3.850" ID, W/BIW 1- wire down to lower sensor) Phoenix Pressure Gauge (2.840" ID) (~-.:~-.:':. 7-5/8" x 4-1/2" Premier Packer I Set @ 6,800' MD, 4241' TVD I - 3-1/2" HES 'XN' nipple 2.750" ID No Go W/RHC ball & rod Wireline Entry Guide \~ ....... ---- 6-1/8" OA Lateral TD 111,922' Mcl - - -- -- OA Horizontal 6-1/8" hole r...... ...... - - - - - - - 4-1/2" Slotted Liner W/Hookwall hanger ~ 7.625" Casing Shoe @ 7,12 I MD,4334' TVD Well Inclination @ Shoe = 76 egrees PBTD TD DATE 24 Mar 2003 REV. BY MDG .<",_~f#".-"''''''''''''~' ~ .~ " 9-7/8" Hole 6-1/8" OB Lateral TD .. - - -- OB Horizontal 6-1/8" hole - - 4-1/2" Slotted Liner & Hanger .'..-""-- ""....,... '0'''''' . .. "....._--'-------- COMMENTS Level 3 Multi-Lateral, 4-1/2" Jet Pump Completion Milne Point Unit WF~ ~ : MP~-04 API NO: Expioration (Alaska) ~_3;AD T13N T12N 2 21 ~ f !!I Î ~ J f : I ( I I I .34 I ¡... .33 ~ I .31i I I -Z~ .29i I I I .27 h . 25 .J I .24i I ·23 I I .21i I .19i IMP U r .17 1 I .15i I I .13i I LEGEND r . 11 ~ -+- AS-BUILT CONDUCTOR __I . . MPS_0819i :. EXISTING CONDUCTOR L MPÞo6 7i J MPS-04 5 -- l I . StCT - - - 1- --... 3 ~ 72 T72 II I · 2 StCT 7· . ,:,. RIOt I · 1 T12N. R1if- . . I. r I I I I ~ r I I Q I ~' Vi~ _L - - _L - - _L - - _L j , ~ / ~ I NOTES: 1. DATE OF SURVEY: JANUARY 3-4, 2003. 2. REFERENCE FIELD BOOK: MP03-01 PAGES 01-11. 3. COORDINATES ARE ALASKA STATE PLANE, ZONE-4 NAD-27. 4. GEODETIC COORDINATES ARE NAD-27. 5. MPU S-PAD AVERAGE SCALE FACTOR IS: 0.999904923. 5. HORIZONTAL CONTROL IS BASED ON MPU CFP MONUMENT CFP-3 AND MPU H-PAD MONUMENT H-1. 7. ELEVATIONS ARE BPX MEAN SEA LEVEL BASED ON MILNE POINT PIPELINE VERTICAL CONTROL. { PLANT L 15°00'00" GRID 28 S-PAD ~ 32 ~ ~ 5 PROJEcT 3 J.£FA 11 9 10 14 Ww 13 ~::: 18 a:: a:: 17 16 15 VICINITY MAP N.T.S. SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JANUARY 04, 2003. LOCATED WITHIN PROTRACTED SEC. 7, T. 12 N., R. 11 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINA TES COORDINA TES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-04 Y=6,OOO,033.25 N= 2,236.82 70·24'37.899" 70.4105275· 38.3' 3,364' FSL X= 566,033.83 E= 6,914.48 149·27'44.278" 149.4622994' 4,758' FEL ~ s ~ ~ ; ~ : b j ~ J ~ ; i § t :¡ ! ~ J 0 1/12/03 ISSUED FOR INFORMAl1ON ¡; NO. DA 11:: REVISION LOCATED WITHIN PROTRACTED SEC. 12, T. 12 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS MPS-06 Y=6,OOO,025.19 N= 2,236.71 70·24'37.822" 70.4105061' 38.5' 3,357' FSL x= 566,004.15 E= 6,883.72 149°27'45.150" 149.4625417" 6' FEL MPS-08 Y=6,OOO,017.67 N= 2,236.84 70'24'37.751" 70.4104864' 38.6' 3,349' FSL X= 565,975.59 E= 6,854.18 149'27'45.989" 149.4627747" 35' FEL F. ROb' DRAWN: COTTON 1 -- , CHECKED: bp 1]__ ..:!I ALUSON DATE: 12/11/02 . DRAWING: MILNE POINT UNIT S-P AD FRB03 MPS 01-00 SHEET: ¡ ff]~~[I]~o JOB NO: SCALE: AS-BUlL T CONDUCTORS JJC RFA ENGINEERS ,KJ LAND SUA'¥tYOR'S WELLS MPS-04, MPS-05 & MPS-08 1 OF 1 1801 '#I($T F1R£Wf:£D LANE 1-= 160' BY CHK AH04ORAC:[. ALASI<A D95QJ End Dir : 7125.8' MO, 4334' TVD Start Dir 14/100': 7135.8' MD. 4336,427VD End Dir : 7294.59' MD, 4355.25' TVD Start Dir 6/100' : 7571.59' MD, 4353.1 'TVD End Dir : 7838.85' MD, 4356.8' TVD Start Dir 6/1 00' : 7932.15' MD, 4359.73'TVD Start Dir 4/100': 8201.63' MD, 4364'TVD End Dir : 8453.4' MD, 4359.07' TVD End Dir : 89J9.3' MD, 4341' TVD I Total Depth: 9984.2' MD, 4311' TVD oo~ ~ ; ~;. -..? - MPS-04wp09 \ vJ~ 8){)( Ç/OO) ~o t{ 4 112" lS~-rB 4000 o 800 600 Start Dir41100': 5515.77' MD, 370L04'TVD 61nr SH2-N.\ - 75/8 'm=l.!"II:. SJ&--M: ...,... I SBE~N ::: ~RFI-"lF TS03D 2400 3200 Vertical Section at 100.410 [800ft/in] 4000 I 4800 I 5600 3200- c: 2: o ~ ã. èí 11 .~ 2400 > ... ë ¡- - End Dir : 1823.33' MD, /758.17' TVD )tart Dir4/100' : J953.49' MD. 1872'TVD II)..~ ~Oç I I 0 ¡r::: ll> ~ EM Di'.' "94.77' MD,24".O!' TVD 1031" ''''10 ~ ~, 010 ~ .. # ~ , .' ... ... ., I , , 1(2', , , ~/ ~.-./ , ~" , V--- "" , "....' ,.-~... 600 Ò COMPANY DETAILS BP Amoco Cakulalion MetlJod; Minimwn C"urvatwe Error S)'SIeß1: ISCWSA Scan M.!hod: Tr..· Cylilkkr North '" ~~ ElT\)f Surface: Elliptical + Casing Warnin~ M.thod: Rules Bas<d All TVD depths are ssTVD plus 72'for RKBE. 0- A- Start Dir J.5/J00': 450' MD. 450'TVD /' . Start Dir 2.511 00' : 583.33' MD, 583.3I'TVD -/ 800 go -~- O~ !\60 ~ Start Dir 1.5/100': 1423.33' MD, 1398.81'TVD ".<\0 BI'Rf REFERENCE INFORMATION 'o-Qrdioal\:: (N1:) Refereoc~: W~JI Centre: Plan MPS-04. Trœ Nonh Vertkal (TVD) Rereret1\.~: S-Pad ~v 72.00 s..:.ion /VS) Refere"",,: Slot· lO.OON.O.ooE) Measured Depth Refereo<<: S·Pad Dev 7~.00 Calculation Merbod: Minimwn CUl\1IttIre CASING DETAILS No. TVD MD Name 1 2482.00 ~5 103/4" 2 4334.00 - 7125.80 7 5/8" 3 4310.90 9984.19 4 1/2" FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1822.00 '';'''·.32 BPRF 2 3534.00 :.1'·:.46 TUZC 3 4100.00 I·¡ 1.'.61 SBF2-NA 4 4132.00 {.¡., \.85 SBFI-NB 5 4163.00 I· .h.53 SBE4-NC 6 4177.00 1·,·1 ;.54 SBE2-NE 7 4226.00 f· 7'. \.53 SBEI-NF 8 4273.00 1,''''1.32 TSBD-OA 9 4304.00 ;1111'"'.37 TSBC 10 4334.00 71: '.80 TSBB-OB II 4348.00 71·'j.52 OWC Size -/ 10.75iÅf 7.625 . 4.500 SURVEY PROGRAM Depth Fm Depth To SU"'e)"'I'lao Tool 33.00 1 000.00 Planned: MPS-04 wp09 VI7 CB-GYRo.SS 1000.00 9984.20 Planned: MPS-04 "J>09 Vl7 MWD·IFR-MS WELL DETAILS Narre +N/-S +Ð·W Nmhins Eastins Lalituœ _OI1glludo Slot Plan MPS-{)4 58.u1 ·311.2/ 600003330 566033.32 70"24"37.9OON 149"27'44293W N'A TARGET DETAILS Name 1VD ~N'-S -Ð·W Nonhins EAsting Shape MPS-04 15.2 4311.00 ·857.69 4668.72 5999217.00 570709.00 Poinl MPS-04 Poly 4334.00 738.12 4(¡()1.82 6000812.00 570628.00 Pol)'gon MPS-04 Tl.2 4334.00 182937 4250.42 6001900.00 570267.00 Point MPS-04 T4.2 4341.00 203.74 4749.12 6000279.00 570780.00 Point MPS-04 12.2 4353.00 1475.71 455825 6001549.11 570571.91 Poinl MPS-04 13.2 4364.00 919.61 4775.45 6000995.00 570800.00 Poin. SECTION DETAILS Sec MD Inc Azi TVD +N/-S +EI-W DLeg TFace VSec I 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 2 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 3 583.33 2.00 55.00 583.31 1.33 1.91 1.50 55.00 1.63 4 1423.33 23.00 55.00 1398.81 105.03 150.00 2.50 0.00 128.56 5 1823.33 29.00 55.00 1758.17 205.56 293.57 1.50 0.00 251.60 6 1953.49 29.00 55.00 1872.00 241. 76 345.26 0.00 0.00 295.90 7 2794.77 62.63 56.86 2450.01 572.50 839.38 4.00 2.98 722.13 8 5515.77 62.63 56.86 3701.04 1893.47 2862.70 0.00 0.00 2473.46 9 7125.80 76.00 125.00 4334.00 1829.37 4250.42 4.00 93.10 3849.93 10 7135.80 76.00 125.00 4336.42 1823.80 4258.37 0.00 0.00 3858.75 11 7294.59 90.44 J42.07 4355.25 17J5.64 4371.71 14.00 50.87 3989.76 12 7571.59 90.44 142.07 4353.10 1497.17 4541.99 0.00 0.00 4196.71 13 7598.52 90.00 143.62 4353.00 1475.71 4558.25 6.00 105.93 4216.59 14 7838.85 88.20 157.93 4356.80 1266.56 4675.28 6.00 97.26 4369.48 15 7932.15 88.20 157.93 4359.73 1180.14 4710.32 0.00 0.00 4419.56 16 8201.63 90.00 174.00 4364.00 919.6J 4775.45 6.00 83.77 4530.69 17 8453.40 92.24 183.82 4359.07 668.26 4780.24 4.00 77.10 4580.82 18 8899.33 92.24 183.82 4341.67 223.65 4750.54 0.00 0.00 4631.94 19 8919.30 91.62 184.33 434 I .00 203.74 4749.12 4.00 140.51 4634.14 20 9984.20 91.62 184.33 4311.00 -857.69 4668.72 0.00 0.00 4746.85 er."led By: K." Allen Chœked Ian: MPS-04 wp09 (Plan MPS·04fPlan MPS·041 Ie: 2/20/200 'Ie: Dale: Target -~ MPS-D4 TI.2 MPS-D4 T2.2 MPS-D4 TJ.2 MPS-D4 T4.2 MPS-D4 T5.2 r: 2: o ~ .t:: o ~ :; o f/) bp O·····H, -"...,,- 2400- 800 800 600 o COMPA!'.'Y DETAILS B1' Amoco Cak1.JlatÎOn Mðhod: Minimwn Cw,"atur~ Error Syslem: ISCWSA Scan t.iethod: Trav C)'linde, North Error Surlàce: Ellip!i<3I' Casing Wami~ Method: Ruks Based FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1822.00 1896.32 BPRF 2 3534.00 5152.46 TUZC 3 4100.00 6412.61 SBF2-NA 4 4132.00 6493.85 SBF1-NB 5 4163.00 6575.53 SBE4-NC 6 4177.00 6613.54 SBE2-NE 7 4226.00 6753.53 SBEI-NF 8 4273.00 6901.32 TSBD-OA 9 4304.00 7009.37 TSBC 10 4334.00 7125.80 TSBB-OB II 4348.00 7194.52 OWC : I ~5$.49' \1D, . 8Ü'-V J woJ 1':<;~ P'-'V) stat"l Dtr ..5,'100' 142:1.3.3' ¥q, U9!U;' VlJ \ -- Start bir 2.511001 : 58:'.33' rÆD, ~8331 'Tt/D S. 01, "''j' 4!0' MJ, 4'.)'TV" I I All TVD depths are ssTVD plus 72'for RKBE. 800 2"'9':.77' MI:', 2450.él' rVD I I I I I III I I rart il 4/10)' 600 REFERENCE \~mtina(e (N1:) Ref~reoo.."t:: V,,'rtÍcal ow) Reft....-eo.."e: Soclion (VS_) Reference: t.1<asured [kp.h Refe,m:o: Calculation 1.1elhod: 5 1~.7"" MU, 370 / TARGET DETAILS Nan>< TVD -w-s "Ei-W Nonhing Ea..ing Shap" MPS~ T52 4311.00 -857.69 4668.72 5999211.00 570709.00 Point 1.11'5-04 1\'1)' 4334.00 738.12 4601.82 600œ12.oo 570628.00 Pol)'gon 1.1PS~ TI.2 4334.00 182937 4250.42 6001900.00 570267.00 Point 1.1PS~ T42 4341.00 203.74 4749.12 6000279.00 570780.00 Point 1.1PS-04 T22 4353.00 1475.71 455825 6001549.11 5705TI.91 Point 1.1PS~ B2 4364.00 919.61 4775.45 6000995.00 570800.00 Point CASING DETAILS No. TVD MD Name I 2482.00 2864.35 10314" 2 4334.00 7125.80 7 5/8" 3 4310.90 9984.19 4 1/2" INFORMATION won COIltJ<: Plan MPs-04. S-Pad Do,' 12.00 SkJi - (OJJON.O.orJEJ S-Pad Do,· 12.(() Minimum Cur\'amr~ 2400 3200 West(- )/East(+) [800ft/in] T"", Nonh Stut ..Ju End Dir- : 7125.8' MD, '-334' TVD Y-4JOJ.¡1 ~ i 518' IIIIJO': ';135.8' ~336.'12'TV Ef d)if : 7294.59 Iv. D, 4~ 55.2:' SIaI SIAll Di. 4'1(0' . 839~.33' MD, ¿'34I.ú7'-n "-...... '.r'" ""."'" 4'4 VJ ~ 61 10 J' S:ar =nd Dir di. 6/100 Dtr ¿./l JU' : ~2ll.ó3' .\1..J, B04' Size 10.750 7.625 4.500 Ef d Jir 7.)71.5~' MI;, 435,. Dopth I'm Dop.h To 33.1)') 1000.00 1000.00 998420 34S3.4'..rD, '-3: 9.07' 4000 See 1 2 3 4 5 6 7 8 9 10 II 12 I3 14 15 16 17 18 19 20 SURVEY Suo"C')"'PJan PIanD<d: 1.11'5-04 w]>09 VI7 Planned: 1.11'5-04 w]>09 VI7 ¡y p~ -041 \'--pl <} 4 1/;" I I I I MD 33.00 450.00 583.33 1423.33 J 823.33 1953.49 2794.77 5515.77 7125.80 7135.80 7294.59 7571.59 7598.52 7838.85 7932.15 8201.63 8453.40 8899.33 8919.30 9984.20 ROGRAM ne 0.00 0.00 2.00 23.00 29.00 29.00 62.63 62.63 76.00 76.00 90.44 90.44 90.00 88.20 88.20 90.00 92.24 92.24 91.62 91.62 '\1PS-04 T5.2 4T.,,,, Do,lh , 9984.2' MD, 43 Nan>< "N'-S "Et-W NonhIl'8 Fas.i~ l...atÎtuœ .rogrtud:- Sk11 Plan 1.1PS-lI4 .07 -31121 6000033.30 5660J332 7W24·37.900N . ·^"··44.29.1W N'A SECTION DETAILS 4800 Azi 0.00 0.00 55.00 55.00 55.00 55.00 56.86 56.86 125.00 125.00 142.07 142.07 143.62 157.93 157.93 174.00 183.82 183.82 184.33 184.33 Tool CB-GYRO·SS MWD"IFR'MS MPS-04 T4.2 MPS-04 TJ.2 TVD 33.00 450.00 583.31 1398.81 1758.17 1872.00 2450.01 3701.04 4334.00 4336.42 4355.25 4353.10 4353.00 4356.80 4359.73 4364.00 4359.07 4341.67 4341.00 4311.00 +N/-S 0.00 0.00 1.33 105.03 205.56 241.76 572.50 1893.47 1829.37 1823.80 1715.64 1497.17 1475.71 1266.56 1180.14 919.61 668.26 223.65 203.74 -857.69 I 5600 Plan: MI'S.(]4 wI'(<} (Plan MI'S·II4IPlan MI'S·04¡ ,,"led ß)': Ken Aile" Ie: U 'hccked: Ie: Rc\icwcd: Ie: WELL DETAILS I' TVD +EI- W 0.00 0.00 1.91 150.00 293.57 345.26 839.38 2862.70 4250.42 4258.37 4371.71 4541. 99 4558.25 4675.28 4710.32 4775.45 4780.24 4750.54 4749.12 4668.72 D~g ~OO ~OO 1.50 2,50 1.50 ~OO ~OO ~OO ~OO ~oo ~OO ~OO ~OO ~OO ~OO ~OO 4~ ~OO ~OO ~OO TFaee 0.00 0.00 55.00 0.00 0.00 0.00 2.98 0,00 93.10 0.00 50.87 0.00 05.93 97.26 0.00 83.77 77.10 0.00 40.51 0.00 VSee 0.00 0.00 1.63 128.56 251.60 295.90 722.13 2473.46 3849.93 3858.75 3989.76 4196.71 4216.59 4369.48 4419.56 4530.69 4580.82 4631.94 4634.14 4746.85 MPS-04 TI.2 MPS-04 T2.7-· MPS·04 TJ.2 MPS-04 T4.2 MPS-04 T5.2 Target ~ BP KW A Planning Report MAP Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M Pt S Pad Plan MPS-04 Plan MPS-04 Date: 2/20/2003 Time: 11 :20: 12 Page: Co-ordinate(NE) Reference: Well: Plan MPS-04, True North Vertical (TVD) Reference: S-Pad Dev 72.0 Section (VS) Reference: Well (0.00N,O.00E,100.41Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: M Pt S Pad Site Position: From: Map Position Uncertainty: Ground Level: 5999978.00 ft 566345.00 ft Northing: Easting: Latitude: Longitude: North Reference: Grid Convergence: 0.00 ft 0.00 ft Well: Plan MPS-04 Slot Name: Well Position: +N/-S 58.07 ft Northing: 6000033.30 ft +E/-W -311.21 ft Easting: 566033.32 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan MPS-04 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 6/29/2001 57481 nT Depth From (TVD) ft 0.00 Height 72.00 ft +N/-S ft 0.00 Plan: MPS-04 wp09 Date Composed: Version: Tied-to: Principal: Yes Casing Points ~:i \ Alaska, Zone 4 Well Centre BGGM2002 70 24 37.329 N 149 27 35.171 W True 0.51 deg 70 24 37.900 N 149 27 44.293 W Well Ref. Point 0.00 ft Mean Sea Level 26.21 deg 80.79 deg Direction deg 100.41 2/18/2003 17 From Well Ref. Point MD TVD Diameter Hole Size Name ft ft in in 2864.~5 2482.00 10.750 13.500 103/4" 7125.80 4334.00 7.625 9.875 7 5/8" 9984.19 4310.90 4.500 6.125 4 1/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 1896.32 1822.00 BPRF 0.00 0.00 5152.46 3534.00 TUZC 0.00 0.00 6412.61 4100.00 SBF2-NA 0.00 0.00 6493.85 4132.00 SBF1-NB 0.00 0.00 6575.53 4163.00 SBE4-NC 0.00 0.00 6613.54 4177.00 SBE2-NE 0.00 0.00 6753.53 4226.00 SBE1-NF 0.00 0.00 6901.32 4273.00 TSBD-OA 0.00 0.00 7009.37 4304.00 TSBC 0.00 0.00 7125.80 4334.00 TSBB-OB 0.00 0.00 7194.52 4348.00 OWC 0.00 0.00 Targets Map Map <- Latitude --> <-- Longitude ---> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg MinSec Dip. Dir. ft ft ft ft ft MPS-04 T5.2 4311.00 -857.69 4668.72 5999217.00 570709.00 70 24 29.450 N 149 25 27.464 W MPS-04 Poly 4334.00 738.12 4601.82 6000812.00 570628.00 70 24 45.145 N 149 25 29.396 W -Polygon 1 4334.00 1780.19 4043.96 6001849.00 570061.00 70 24 55.397 N 149 25 45.732 W BP ( KW A Planning Report MAP Company: BP Amoco Date: 2/20/2003 Time: 11:20:12 Page: 2 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-04. True North Site: M Pt S Pad Vertical (fVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-04 Section (VS) Reference: Well (0.00N.0.00E,1 00.41Azi) WeUpath: Plan MPS-04 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <- Latitude -> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min See Dip. Dir. ft ft ft ft ft -Polygon 2 4334.00 738.12 4601.82 6000812.00 570628.00 70 24 45.145 N 149 25 29.396 W -Polygon 3 4334.00 -1056.01 4475.94 5999017.00 570518.00 70 24 27.501 N 149 25 33.117 W -Polygon 4 4334.00 -1058.62 4770.96 5999017.00 570813.00 70 24 27.473 N 149 25 24.471 W -Polygon 5 4334.00 974.85 4974.96 6001052.00 570999.00 70 24 47.471 N 149 25 18.453 W -Polygon 6 4334.00 2015.77 4548.11 6002089.00 570563.00 70 24 57.711 N 149 25 30.948 W MPS-04 T1.2 4334.00 1829.37 4250.42 6001900.00 570267.00 70 24 55.879 N 149 25 39.679 W MPS-04 T 4.2 4341.00 203.74 4749.12 6000279.00 570780.00 70 24 39.889 N 149 25 25.088 W MPS-04 T2.2 4353.00 1475.71 4558.25 6001549.11 570577.91 70 24 52.399 N 149 25 30.660 W MPS-04 T3.2 4364.00 919.61 4775.45 6000995.00 570800.00 70 24 46.929 N 149 25 24.303 W Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/10OO deg/100ft deg/100ft deg 33.00 0.00 0.00 33.00 0.00 0.00 0.00 0.00 0.00 0.00 450.00 0.00 0.00 450.00 0.00 0.00 0.00 0.00 0.00 0.00 583.33 2.00 55.00 583.31 1.33 1.91 1.50 1.50 0.00 55.00 1423.33 23.00 55.00 1398.81 105.03 150.00 2.50 2.50 0.00 0.00 1823.33 29.00 55.00 1758.17 205.56 293.57 1.50 1.50 0.00 0.00 1953.49 29.00 55.00 1872.00 241.76 345.26 0.00 0.00 0.00 0.00 2794.77 62.63 56.86 2450.01 572.50 839.38 4.00 4.00 0.22 2.98 5515.77 62.63 56.86 3701.04 1893.47 2862.70 0.00 0.00 0.00 0.00 7125.80 76.00 125.00 4334.00 1829.37 4250.42 4.00 0.83 4.23 93.10 MPS-04 T1.2 7135.80 76.00 125.00 4336.42 1823.80 4258.37 0.00 0.00 0.00 0.00 7294.59 90.44 142.07 4355.25 1715.64 4371.71 14.00 9.10 10.75 50.87 7571.59 90.44 142.07 4353.10 1497.17 4541.99 0.00 0.00 0.00 0.00 7598.52 90.00 143.62 4353.00 1475.71 4558.25 6.00 -1.65 5.77 105.93 MPS-04 T2.2 7838.85 88.20 157.93 4356.80 1266.56 4675.28 6.00 -0.75 5.95 97.26 7932.15 88.20 157.93 4359.73 1180.14 4710.32 0.00 0.00 0.00 0.00 820'1.63 90.00 174.00 4364.00 919.61 4775.45 6.00 0.67 5.96 83.77 MPS-04 T3.2 8453.40 92.24 183.82 4359.07 668.26 4780.24 4.00 0.89 3.90 77.10 8899.33 92.24 183.82 4341.67 223.65 4750.54 0.00 0.00 0.00 0.00 8919.30 91.62 184.33 4341.00 203.74 4749.12 4.00 -3.09 2.54 140.51 MPS-04 T 4.2 9984.20 91.62 184.33 4311.00 -857.69 4668.72 0.00 0.00 0.00 0.00 MPS-04 T5.2 Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/100ft deg 33.00 0.00 0.00 33.00 -39.00 6000033.30 566033.32 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 28.00 6000033.30 566033.32 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 128.00 6000033.30 566033.32 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 228.00 6000033.30 566033.32 0.00 0.00 0.00 CB-GYRO-SS 400.00 0.00 0.00 400.00 328.00 6000033.30 566033.32 0.00 0.00 0.00 CB-GYRO-SS 450.00 0.00 0.00 450.00 378.00 6000033.30 566033.32 0.00 0.00 0.00 CB-GYRO-SS 500.00 0.75 55.00 500.00 428.00 6000033.49 566033.59 0.23 1.50 0.00 CB-GYRO-SS 583.33 2.00 55.00 583.31 511.31 6000034.65 566035.21 1.63 1.50 0.00 CB-GYRO-SS 600.00 2.42 55.00 599.96 527.96 6000035.02 566035.74 2.08 2.50 0.00 CB-GYRO-SS 700.00 4.92 55.00 699.75 627.75 6000038.74 566040.94 6.57 2.50 360.00 CB-GYRO-SS 800.00 7.42 55.00 799.16 727.16 6000044.98 566049.68 14.11 2.50 0.00 CB-GYRO-SS 900.00 9.92 55.00 898.01 826.01 6000053.73 566061.95 24.69 2.50 0.00 CB-GYRO-SS 1000.00 12.42 55.00 996.11 924.11 6000064.97 566077.71 38.29 2.50 0.00 MWD+IFR+MS 1100.00 14.92 55.00 1093.27 1021.27 6000078.69 566096.94 54.87 2.50 0.00 MWD+IFR+MS 1200.00 17.42 55.00 1189.31 1117.31 6000094.86 566119.60 74.42 2.50 0.00 MWD+IFR+MS 1300.00 19.92 55.00 1284.04 1212.04 6000113.45 566145.65 96.89 2.50 0.00 MWD+IFR+MS ( ,( BP ~, KW A Planning Report MAP Company: BP Amoco Date: 2/20/2003 Time: 11 :20:12 Page: 3 Field: Milne Point Co-()rdinate(NE) Reference: Well: Plan MPS-04, True North Site: M Pt S Pad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-04 Section (VS) Reference: Well (0.00N,O.00E,100.41Azi) Wellpath: Plan MPS-04 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 1400.00 22.42 55.00 1377 .29 1305.29 6000134.41 566175.04 122.23 2.50 0.00 MWD+IFR+MS 1423.33 23.00 55.00 1398.81 1326.81 6000139.65 566182.37 128.56 2.50 0.00 MWD+IFR+MS 1500.00 24.15 55.00 1469.08 1397.08 6000157.45 566207.33 150.08 1.50 0.00 MWD+IFR+MS 1600.00 25.65 55.00 1559.78 1487.78 6000181.90 566241.60 179.64 1.50 360.00 MWD+IFR+MS 1700.00 27.15 55.00 1649.35 1577.35 6000207.72 566277.79 210.85 1.50 0.00 MWD+IFR+MS 1800.00 28.65 55.00 1737.72 1665.72 6000234.90 566315.88 243.70 1.50 0.00 MWD+IFR+MS 1823.33 29.00 55.00 1758.17 1686.17 6000241.43 566325.04 251.60 1.50 360.00 MWD+IFR+MS 1896.32 29.00 55.00 1822.00 1750.00 6000261.98 566353.84 276.44 0.00 0.00 BPRF 1900.00 29.00 55.00 1825.22 1753.22 6000263.02 566355.29 277 .69 0.00 0.00 MWD+IFR+MS 1953.49 29.00 55.00 1872.00 1800.00 6000278.08 566376.40 295.90 0.00 0.00 MWD+IFR+MS 2000.00 30.86 55.19 1912.31 1840.31 6000291.52 566395.31 312.22 4.00 2.98 MWD+IFR+MS 2100.00 34.85 55.53 1996.30 1924.30 6000322.73 566439.66 350.55 4.00 2.82 MWD+IFR+MS 2200.00 38.85 55.81 2076.30 2004.30 6000356.98 566488.88 393.15 4.00 2.53 MWD+IFR+MS 2300.00 42.85 56.05 2151.93 2079.93 6000394.08 566542.72 439.81 4.00 2.30 MWD+IFR+MS 2400.00 46.84 56.25 2222.81 2150.81 6000433.86 566600.93 490.31 4.00 2.13 MWD+IFR+MS 2500.00 50.84 56.43 2288.61 2216.61 6000476.12 566663.21 544.40 4.00 1.98 MWD+IFR+MS 2600.00 54.84 56.59 2349.00 2277.00 6000520.67 566729.27 601.82 4.00 1.86 MWD+IFR+MS 2700.00 58.84 56.73 2403.69 2331.69 6000567.28 566798.78 662.28 4.00 1.77 MWD+IFR+MS 2794.77 62.63 56.86 2450.01 2378.01 6000613.14 566867.53 722.13 4.00 1.69 MWD+IFR+MS 2800.00 62.63 56.86 2452.42 2380.42 6000615.72 566871.40 725.49 0.00 180.00 MWD+IFR+MS 2900.00 62.63 56.86 2498.39 2426.39 6000664.91 566945.32 789.86 0.00 180.00 MWD+IFR+MS 3000.00 62.63 56.86 2544.37 2472.37 6000714.11 567019.24 854.22 0.00 180.00 MWD+IFR+MS 3100.00 62.63 56.86 2590.35 2518.35 6000763.31 567093.16 918.59 0.00 180.00 MWD+IFR+MS 3200.00 62.63 56.86 2636.32 2564.32 6000812.51 567167.08 982.95 0.00 180.00 MWD+IFR+MS 3300.00 62.63 56.86 2682.30 2610.30 6000861.71 567241.00 1047.31 0.00 180.00 MWD+IFR+MS 3400.00 62.63 56.86 2728.28 2656.28 6000910.91 567314.92 1111.68 0.00 180.00 MWD+IFR+MS 3500.00 62.63 56.86 2774.25 2702.25 6000960.10 567388.84 1176.04 0.00 180.00 MWD+IFR+MS 3600.00 62.63 56.86 2820.23 2748.23 6001009.30 567462.76 1240.40 0.00 180.00 MWD+IFR+MS 3700.00 62.63 56.86 2866.21 2794.21 6001058.50 567536.68 1304.77 0.00 180.00 MWD+IFR+MS 3800.00 62.63 56.86 2912.18 2840.18 6001107.70 567610.60 1369.13 0.00 180.00 MWD+IFR+MS 3900.00 62.63 56.86 2958.16 2886.16 6001156.90 567684.52 1433.49 0.00 180.00 MWD+IFR+MS 4000.00 62.63 56.86 3004.14 2932.14 6001206.10 567758.44 1497.86 0.00 180.00 MWD+IFR+MS 4100.00 62.63 56.86 3050.11 2978.11 6001255.29 567832.36 1562.22 0.00, 180.00 MWD+IFR+MS 4200.00 62.63 56.86 3096.09 3024.09 6001304.49 567906.28 1626.58 0.00 180.00 MWD+IFR+MS 4300.00 62.63 56.86 3142.07 3070.07 6001353.69 567980.20 1690.95 0.00 180.00 MWD+IFR+MS 4400.00 62.63 56.86 3188.04 3116.04 6001402.89 568054.12 1755.31 0.00 180.00 MWD+IFR+MS 4500.00 62.63 56.86 3234.02 3162.02 6001452.09 568128.04 1819.67 0.00 180.00 MWD+IFR+MS 4600.00 62.63 56.86 3280.00 3208.00 6001501.29 568201.96 1884.04 0.00 180.00 MWD+IFR+MS 4700.00 62.63 56.86 3325.98 3253.98 6001550.48 568275.88 1948.40 0.00 180.00 MWD+IFR+MS 4800.00 62.63 56.86 3371.95 3299.95 6001599.68 568349.80 2012.76 0.00 180.00 MWD+IFR+MS 4900.00 62.63 56.86 3417.93 3345.93 6001648.88 568423.72 2077.13 0.00 180.00 MWD+IFR+MS 5000.00 62.63 56.86 3463.91 3391.91 6001698.08 568497.64 2141.49 0.00 180.00 MWD+IFR+MS 5100.00 62.63 56.86 3509.88 3437.88 6001747.28 568571.56 2205.85 0.00 180.00 MWD+IFR+MS 5152.46 62.63 56.86 3534.00 3462.00 6001773.08 568610.33 2239.62 0.00 180.00 TUZe 5200.00 62.63 56.86 3555.86 3483.86 6001796.47 568645.48 2270.22 0.00 180.00 MWD+IFR+MS 5300.00 62.63 56.86 3601.84 3529.84 6001845.67 568719.40 2334.58 0.00 180.00 MWD+IFR+MS 5400.00 62.63 56.86 3647.81 3575.81 6001894.87 568793.32 2398.95 0.00 180.00 MWD+IFR+MS 5500.00 62.63 56.86 3693.79 3621.79 6001944.07 568867.24 2463.31 0.00 180.00 MWD+IFR+MS 5515.77 62.63 56.86 3701.04 3629.04 6001951.83 568878.89 2473.46 0.00 180.00 MWD+IFR+MS 5600.00 62.50 60.65 3739.86 3667.86 6001991.15 568942.44 2529.30 4.00 93.10 MWD+IFR+MS 5700.00 62.48 65.16 3786.08 3714.08 6002032.22 569021.00 2599.64 4.00 91.35 MWD+IFR+MS 5800.00 62.60 69.67 3832.21 3760.21 6002067.00 569102.59 2674.03 4.00 89.26 MWD+IFR+MS 5900.00 62.87 74.16 3878.04 3806.04 6002095.32 569186.80 2752.13 4.00 87.19 MWD+IFR+MS ( BP :( KW A Planning Report MAP Company: BP Amoco Date: 2/20/2003 Time: 11:20:12 Page: 4 Field: Milne Point Co~rdinate(NE) Reference: Well: Plan MPS-04, True North Site: M Pt S Pad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-04 Section (VS) Reference: Well (0.00N,O.00E.1 00.41Azi) Wellpath: Plan MPS-04 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 6000.00 63.28 78.62 3923.35 3851.35 6002117.05 569273.23 2833.54 4.00 85.13 MWD+IFR+MS 6100.00 63.83 83.05 3967.90 3895.90 6002132.07 569361.45 2917.87 4.00 83.11 MWD+IFR+MS 6200.00 64.51 87.43 4011.49 3939.49 6002140.32 569451.04 3004.72 4.00 81.13 MWD+IFR+MS 6300.00 65.32 91.75 4053.91 3981.91 6002141.76 569541.56 3093.65 4.00 79.22 MWD+IFR+MS 6400.00 66.25 96.02 4094.93 4022.93 6002136.37 569632.57 3184.23 4.00 77.39 MWD+IFR+MS 6412.61 66.38 96.55 4100.00 4028.00 6002135.21 569644.06 3195.75 4.00 75.64 SBF2-NA 6493.85 67.23 99.96 4132.00 4060.00 6002125.14 569718.02 3270.36 4.00 75.43 SBF1-NB 6500.00 67.30 100.22 4134.38 4062.38 6002124.19 569723.62 3276.03 4.00 74.08 MWD+IFR+MS 6575.53 68.17 103.35 4163.00 4091.00 6002110.52 569792.14 3345.89 4.00 73.98 SBE4-NC 6600.00 68.46 104.35 4172.04 4100.04 6002105.27 569814.27 3368.59 4.00 72.80 MWD+IFR+MS 6613.54 68.62 104.91 4177.00 4105.00 6002102.20 569826.49 3381.16 4.00 72.43 SBE2-NE 6700.00 69.72 108.42 4207.75 4135.75 6002079.71 569904.08 3461.47 4.00 72.22 MWD+IFR+MS 6753.53 70.43 110.57 4226.00 4154.00 6002063.34 569951.65 3511.16 4.00 70.97 SBE1-NF 6800.00 71.06 112.42 4241.33 4169.33 6002047.63 569992.61 3554.21 4.00 70.24 MWD+IFR+MS 6900.00 72.50 116.35 4272.60 4200.60 6002009.19 570079.43 3646.36 4.00 69.63 MWD+IFR+MS 6901.32 72.52 116.40 4273.00 4201.00 6002008.64 570080.57 3647.57 4.00 68.40 TSBD-OA 7000.00 74.01 120.22 4301.43 4229.43 6001964.57 570164.12 3737.47 4.00 68.39 MWD+IFR+MS 7009.37 74.15 120.58 4304.00 4232.00 6001960.08 570171.93 3745.93 4.00 67.29 TSBC 7100.00 75.58 124.03 4327.67 4255.67 6001913.99 570246.27 3827.09 4.00 67.19 MWD+IFR+MS 7125.80 76.00 125.00 4334.00 4262.00 6001900.00 570267.00 3849.93 4.00 66.29 MPS-04 Poly 7135.80 76.00 125.00 4336.42 4264.42 6001894.51 570275.00 3858.75 0.00 0.00 MWD+IFR+MS 7150.00 77.26 126.58 4339.70 4267.70 6001886.53 570286.27 3871.23 14.00 50.87 MWD+IFR+MS 7175.00 79.50 129.33 4344.74 4272.74 6001871.64 570305.70 3892.93 14.00 50.50 MWD+IFR+MS 7194.52 81.26 131.44 4348.00 4276.00 6001859.31 570320.47 3909.60 14.00 49.95 OWC 7200.00 81.76 132.03 4348.81 4276.81 6001855.73 570324.54 3914.23 14.00 49.59 MWD+IFR+MS 7225.00 84.04 134.71 4351.90 4279.90 6001838.86 570342.72 3935.04 14.00 49.51 MWD+IFR+MS 7250.00 86.34 137.36 4354.00 4282.00 6001821.09 570360.17 3955.29 14.00 49.18 MWD+IFR+MS 7275.00 88.64 140.00 4355.09 4283.09 6001802.48 570376.82 3974.89 14.00 48.95 MWD+IFR+MS 7294.59 90.44 142.07 4355.25 4283.25 6001787.36 570389.27 3989.76 14.00 48.84 MWD+IFR+MS 7300.00 90.44 142.07 4355.21 4283.21 6001783.12 570392.63 3993.80 0.00 0.00 MWD+IFR+MS 7400.00 90.44 142.07 4354.43 4282.43 6001704.81 570454.80 4068.51 0.00 0.00 MWD+IFR+MS 7500.00 90.44 142.07 4353.66 4281.66 6001626.49 570516.96 4143.23 0.00 0.00 MWD+IFR+MS 7571.59 90.44 142.07 4353.10 4281.10 6001570.42 570561.46 4196.71 0.00 0.00 MWD+IFR+MS 7598.52 90.00 143.62 4353.00 4281.00 6001549.11 570577.91 4216.59 6.00 105.93 MPS-04 T2.2 7600.00 89.99 143.71 4353.00 4281.00 6001547.93 570578.80 4217.67 6.00 97.26 MWD+IFR+MS 7650.00 89.61 146.68 4353.18 4281.18 6001507.13 570607.69 4253.15 6.00 97.26 MWD+IFR+MS 7700.00 89.23 149.66 4353.68 4281.68 6001464.90 570634.43 4286.75 6.00 97.25 MWD+IFR+MS 7750.00 88.86 152.64 4354.51 4282.51 6001421.33 570658.93 4318.39 6.00 97.22 MWD+IFR+MS 7800.00 88.48 155.61 4355.68 4283.68 6001376.56 570681.14 4347.97 6.00 97.17 MWD+IFR+MS 7838.85 88.20 157.93 4356.80 4284.80 6001341.02 570696.78 4369.48 5.99 97.10 MWD+IFR+MS 7900.00 88.20 157.93 4358.72 4286.72 6001284.59 570720.24 4402.31 0.00 0.00 MWD+IFR+MS 7932.15 88.20 157.93 4359.73 4287.73 6001254.92 570732.58 4419.56 0.00 0.00 MWD+IFR+MS 7950.00 88.31 158.99 4360.28 4288.28 6001238.39 570739.28 4429.01 6.00 83.77 MWD+IFR+MS 8000.00 88.64 161.97 4361.60 4289.60 6001191.44 570756.39 4453.94 6.00 83.74 MWD+IFR+MS 8050.00 88.98 164.96 4362.64 4290.64 6001143.65 570771.03 4476.59 6.00 83.66 MWD+IFR+MS 8100.00 89.31 167.94 4363.39 4291.39 6001095.17 570783.17 4496.89 6.00 83.60 MWD+IFR+MS 8150.00 89.65 170.92 4363.84 4291.84 6001046.11 570792.78 4514.79 6.00 83.55 MWD+IFR+MS 8201.63 90.00 174.00 4364.00 4292.00 6000995.00 570800.00 4530.69 6.01 83.53 MPS-04 T3.2 8300.00 90.88 177.84 4363.25 4291.25 6000896.98 570807.87 4555.30 4.00 77.10 MWD+IFR+MS 8400.00 91.77 181.74 4360.94 4288.94 6000797.04 570809.12 4573.73 4.00 77.13 MWD+IFR+MS 8453.40 92.24 183.82 4359.07 4287.07 6000743.73 570807.01 4580.82 4.00 77.22 MWD+IFR+MS 8500.00 92.24 183.82 4357.26 4285.26 6000697.24 570804.32 4586.16 0.00 0.00 MWD+IFR+MS ~ ,{ BP I{ KW A Planning Report MAP Company: BP Amoco Date: 2/20/2003 Time: 11 :20:12 Page: 5 Field: Milne Point C(H)rdinate(NE) Reference: Well: Plan MPS-04, True North Site: M Pt S Pad Vertical (fVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-Q4 Section (VS) Reference: Well (0.00N,0.00E,1 00.41 Azi) Wellpath: Plan MPS-04 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft deg/10OO deg 8600.00 92.24 183.82 4353.35 4281.35 6000597.49 570798.54 4597.62 0.00 0.00 MWD+IFR+MS 8700.00 92.24 183.82 4349.45 4277.45 6000497.75 570792.76 4609.09 0.00 0.00 MWD+IFR+MS 8800.00 92.24 183.82 4345.55 4273.55 6000398.00 570786.98 4620.55 0.00 0.00 MWD+IFR+MS 8899.33 92.24 183.82 4341.67 4269.67 6000298.92 570781.24 4631.94 0.00 0.00 MWD+IFR+MS 8919.30 91.62 184.33 4341.00 4269.00 6000279.00 570780.00 4634.14 4.00 140.51 MPS-04 T 4.2 9000.00 91.62 184.33 4338.72 4266.72 6000198.52 570774.62 4642.68 0.00 0.00 MWD+IFR+MS 9100.00 91.62 184.33 4335.89 4263.89 6000098.79 570767.96 4653.27 0.00 0.00 MWD+IFR+MS 9200.00 91.62 184.33 4333.06 4261.06 5999999.07 570761.29 4663.86 0.00 0.00 MWD+IFR+MS 9300.00 91.62 184.33 4330.24 4258.24 5999899.34 570754.63 4674.44 0.00 0.00 MWD+IFR+MS 9400.00 91.62 184.33 4327.41 4255.41 5999799.61 570747.96 4685.03 0.00 0.00 MWD+IFR+MS 9500.00 91.62 184.33 4324.58 4252.58 5999699.88 570741.30 4695.62 0.00 0.00 MWD+IFR+MS 9600.00 91.62 184.33 4321.76 4249.76 5999600.15 570734.63 4706.20 0.00 0.00 MWD+IFR+MS 9700.00 91.62 184.33 4318.93 4246.93 5999500.43 570727.97 4716.79 0.00 0.00 MWD+IFR+MS 9800.00 91.62 184.33 4316.10 4244.10 5999400.70 570721.30 4727.38 0.00 0.00 MWD+IFR+MS 9900.00 91.62 184.33 4313.28 4241.28 5999300.97 570714.64 4737.96 0.00 0.00 MWD+IFR+MS 9984.20 91.62 184.33 4311.00 4239.00 5999217.00 570709.00 4746.85 0.00 0.00 MPS-04 T5.2 Il'J(1 C-U'(iYl(()·SS MWIJ·IFR·MS SUr\-~)"·'Plan Planro.oJ: MPS·I>! "r"9 Ptal1)''1.t MP'S·04 ....r'19 l)"pIh fo 1'0.0.00 99>1420 D<pIh 1'1 H.(}(J 10IJ1.00 COMPANY DErAII.5 BP AIJhÄ'ø Cakulatk10 Merho.:J: Minimwn Cun--ature Em)r S\-s~m: ISCWSA Sçan ~íethod: Trov Cylißl\:r NonIl Em>r Surlãœ: Elliplical + Casing Warning McthOO: Rules Based Interval: 25.00 To: 9984.20 Reference: Plan: MPS-04 Interpolation Method:MD Depth Range From: 33.00 Maximum Range: 1195.12 Slot NA L«Igil1kle 149-:r27·44193W La(j~ 70"24·37.900N Easling ~6603J32 Nl'}(thmg 61100033..10 [l-\\' 1121 -N ~8. Nam< Plan MPS-t14 72.(1) ~~:"f-vl 0.00 LEGEND W~~~ :~~~~l: I~'lì':::~k MPS·(<¡ IMPS.o~). M.jor Risk ~~~ :~~~~~M' t~t.;:~k MPS.o7 IMPS.(7). M.jor Risk MPS-09 (MPS-09I. Maj<>r Risk MPS·II IMPS· II ). Major Ri.k MPS·13 (Mps·D). Major R"k Mps·l~ (MPS·lh M.j<>r Risk MI'S·17 (MPS·I1I. M.jor Risk ~~::~ :~~::~I~)¡.~a~t,~~ajo< Ri<k Mps·19(Mps·19 A RfGl, Major Risk MI'S·19 (MPS·19J, Major Risk ~~::: ~~~ ~~:m ~~~:'~isk MI'S·2\ IMPS·211. ~lajor Risk Plan MPS-OI (Plan MPS-OI Pilol). Majo< RISk ~:::: ~~~: $:~ ~~~:::t,~'lì':;is:i<k Plan Mps·() (Plan Mps·()L). NOERRORS Plan MPS.Q6 (Plan MPS.(6). Major Risk Plan MPS-œ <Plan MPS.(8). M.jo< Risk Plan MPS·IO IPIan MI'S·IO). M.jor Risk ~:::: ~~:g :~:: ~~:m~alï:;is~iok Plan MPS-14 <Plan MPS·14). Maj<~ RISk Plan MPS-16 (Plan MI'S·16). Major Risk Plan Mps·18 IPIan Mps·18J. Major Risk Plan MPS·20 (l'fm MPS-20). Major Risk Plan MI'S·20 (RIG MPS-20J. Maj<~ Risk Plan MI'S-32 (Mps·n). Maj<" Risk Plan MPS-t14 MI'S-04 "J'09 S·Pad lk\ Origin -Fj·\\, 0.00 <>ri8"11 'N'-S 0.00 RI$ Ref. Datwn· V.~Ik111 A~¡' 100.41° - ToMD 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 6000 8000 11000 12000 15000 From Colour o 300 600 900 1200 1500 2000 2500 3000 3500 4000 4500 5000 o 6000 8000 1]000 12000 Ii I Well plan MPS-04Ll plotted with "no errors" for clarity. 90 \ I 3J) -". 1a~~1 MPS·() 14. MPs·(>!n vS<:.: 0.00 0.00 1.63 12856 2~1.60 29~.9O 722.13 2473.46 3849.93 38~8.75 3989,76 4\96.71 4216,~9 4369.48 4419_<6 4~30,69 4~80.82 46.11.94 4634, \4 4746.8~ TFh·c," 0.00 0.00 ~~.OO 0.00 0.00 0.00 2.98 0.00 93.10 0.00 ~0.87 0.00 JO~,9J 97.26 0.00 83.77 77.10 0.00 140.~1 0.00 DI.<¡< 0.00 0.00 I.~O 250 1.50 0.00 4.00 0.00 4.00 0.00 14.00 O.(If] 6.00 6.00 0.00 6,00 4.I1J 0.00 4.00 0.00 ·fI·W 0.00 0.00 1.91 I~.OO 29357 34~26 83938 2862.70 42~.42 42~837 4371.71 4~41.99 4~~81~ 46J~28 471OJ2 47J~.4~ 478024 47~54 4749.12 4668.72 -N-S 0.00 0.00 1.33 105.03 205_<6 241.76 ~7250 1893.47 182937 1823.80 171~.64 1497.\7 J4JHI 126656 1180.14 919.61 66826 223.6~ 203.74 -89.69 1'\1) noo 4~OJ.o ~83..11 D98.81 1758.17 1872.00 24~.01 3701.() 4334.00 4336.42 435515 43~3.1O 43~.lf)J 43~.80 43~9.73 4364.(1) 4359.07 4341.67 4341.111 4.'\II.m Azi 0.00 0.00 55.00 55.00 ~~.OO ~~.OO ~6.86 ~6.86 12~.00 12~.00 142.07 142.07 14162 1~7.93 1~7.93 174.00 183.82 183.82 184.3.1 18433 Well plan MPS-02 and MPS-04 pilot hole removed ftom plot. Will not be drilled. In< 0.00 0.00 2.00 23.00 29.00 29.00 62.63 62.63 76.00 76.00 90.44 90.44 90.00 88.20 8820 90.00 9224 9224 91.62 91.62 120 MD noo 4~.00 58333 142333 182J33 19~3.49 2794.71 m~.77 7125.80 7135.80 729459 7~7159 7~9852 7838.8~ 7932.1~ 8201.63 84~3 .40 889933 89\930 998420 Se< 1 2 3 4 < 6 7 8 9 10 II 12 13 14 I~ 16 17 18 19 20 50 o \ "'p09 'I i ! p ~ I -128 -120 -100 -80 -60 -40 -20 -0 270 -20 -40 -60 -80 -100 -120 -128 Centre to Ceñtre~Seþaration [40ft/in] - :.-: ._ _n.. Tr~veIling Cylinder Azimu.th (TFDfAZJ) [d~g] vs l~plh Fm 'À'r1h Il} Survcy:Pbl h'l.' .H.ou ICJO'J.I)f I'I.n...'<1: M I'S·!>! wl'''9 V I CII-GYKO-SS 1000,)O 99$4.20 I'I.n....<I: Mps·ß4 wr09 VI MWD-IFK'M lJE1AII.S 1'S-o.I lUg: S-PaJ D.:\ 7Z. 00 n Ker. /JolUm: SecIÍ{\n ongin ongin Stanin~ ~Ic '1'1'-5 -E/·W F"""TVD 100., 0.00 0.00 0.00 COMPANY DETAILS HP AD1O\."\.} Minimum Cw..'alUl\:' /SCWSA T nlV Cylinœr North EIJip<i<a1 . Cas~ Ruks IJas<d Cak'lllatloo Mdhcod: Error Syslem: Sc.n Method: Em)£ Surfac~: Wsming MethOO: wp09 ANTI-COLUSION SETTINGS 25.00 9984.20 Plan: MPS-04 Interval: To: Reference: Interpolation Method:MD Depth Range From: 33.00 Ma.~imum Range: II 95.12 Narœ 'N'-S -[;-W N<rthin¡: Fasting uli(ud.: LI."1IlgÎtuœ Slol IanMPS-o.I SKI -311.2\ 6(XK)033.30 56(>03 7W24'37.900:'-l 149~7·4-1.29.~W N'A \LL:- 100 ..- LEGEND W;~~~ :~~~{¡: I~a~:'~isk MPS-O~ (MPS-O~I. M.jor Risk W~~ :~~~~~~'it~~R~ MI'5-07 (MPS-07I, Major IUsk MPS-09 (MPS-09I. Major Risk Mps·11 IMPS· I II. Major Risk MPS-J IMI'5-IJ¡. Ma".- Risk MPS·¡~ IMPS-I~). Ma"'- Risk ~~: g :~:~:m /~al1~j~s~sk MPS-/9 (MPS-19 A PßI RIGI, M.jorKislc MPS-19(MPS-19 A RIG). Maj<>r Risk MPS·/9 (Mps·191. Major Risk ~:~::~ :~~~ ~~: :~~ I~ali:,,~is~i'¡; Mps·21 (MPS·21 I. M."" Risk I'L1n MPS·OI(Pian MPS-OI Piloll, M.jor Kisk ::::~ ~~~: :~~~ ~:~~:t 17.·li';j~~Sk Plan MPS.{)4 IPian MPS-04I.n. NOERRORS Plan Mps·06 (Pl.1n MPS-(6), Major Risk Plan MI'S·QS ¡Pia" MPS-OI!I, M.¡<>r Risk Plan Mps·IO (I'l.1n MPS·IOI. M.JOf RISk ::J:;; ~~::~ :~~~ ~:;::~tl~aM:j~IS~Sk Plan MPS·14 (Plan MPS·14). M.jor RISk Plan MPS·/611'I.1n MPS·16). Major Risk Plan MPS·18IPI.n Mps·18). Ma".- RISk Plan Mps·20 I1'lan MPS·20). Maj<>r Kisk PlaD MPS-20 (RIG Mps·20). M."" Ris' Plan MPS·32 (MI'S-32J. M.sj,,, Risk Plan MPS.{)4 Mps·ß4 "rm - 1\ \ / \ ,-J 90--- 80 ! ~ - 70 60 50 - ~-: , 40 \; - 30 ~'':~--.............~ - --............. ==~ ~"'- 20_~ '2 ~ o ~ ¡:: .g ...... Cd 1-0 Cd 0- Q) í/J. Q) 1-0 ...... ¡:: Q) U o ...... Q) 1-0 E Q) u --.-- Eq...l'V31~"'lt-M-a-gn~~;S~lce _'. L ) 10 0 ---- ......... '" t II 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 Tarp:~ MPS-04 T 1.2 VSo:.: 0.00 o.m 1.63 12856 251,60 29~.90 722.13 2473.46 .1849.93 38~.7~ 3989.76 4/96.71 421659 4369.4$ 4-11956 490.69 4~80.82 4631.94 4634.14 4746.8~ 1 0.00 0,00 ~~.OO 0.00 0.00 O.O( 2.98 0.00 93.10 o.ou .<0.87 0.00 1O~.93 97.26 0.00 83.77 77.10 0.00 14051 o.(¡( DI...'1' 0,00 0.00 150 2.,0 I.~O 0.00 4,00 0.00 4.00 0.00 IHXJ 0.00 6.00 6.00 om 6.00 4.00 O.I.<J 4.00 0.00 -E:-W 0.00 0.00 1.91 I~O.OO 293-' 7 34,16 83938 2862.70 42~0.42 42~837 4.H1.71 4~41.99 4~~81, 467~18 411032 477~.4~ 478014 47~0.'4 4749.12 4668.72 -N' 0.00 0.00 1.33 10<.03 20<'<6 241.76 9250 1893.47 182937 1823.80 1115.64 1497.11 147~,1I 1266'<6 1180.14 919.61 6681(. 223.6< 203.74 -8.<7.69 IVD 33.00 450.00 ~331 13 98.81 m8.11 1872.00 2450.Q 3701.04 4334.00 4336.42 m51~ 435.1.10 43~3.oo 43~.s0 43~9.73 436UO 43~9.07 4341.67 4341.00 4311.1.0 Az, 0.00 0.00 ~~.OO ~S_OO ~S.OO ~~.OO ~6.86 %.86 12~.00 12~.00 142.07 142.07 143.62 1~7.93 1~7.93 174.00 (g3.82 183.82 18433 18433 In.: 0.00 0.00 2.00 23.00 29.00 29.00 62.63 62.63 76.00 76.00 90.4-1 90.4-1 90.00 88.20 8810 90.00 92.24 9214 91.62 91.62 MD 33.00 450.00 S8J33 142333 182333 19~3.49 2794.77 5515.77 7125.80 7I3~.80 729459 7~7159 7~98'<2 78J8.8~ 7932.1~ 8201.63 84.53.40 889933 891930 998410 See I 2 3 4 , 6 7 8 9 10 II 12 J 14 I~ 16 17 18 19 20 Measured Depth [2000ftlin] ( BP Anticollision Report (' Company: BP Amoco Field: Milne Point Reference Site: M Pt S Pad Reference Well: Plan MPS-04 Reference Wellpath: Plan MPS-04 GLOBAL SCAN APPLIED: All well paths within 200'+ 100/1000 of reference Interpolation Method: MD Interval: 25.00 ft Depth Range: 33.00 to 9984.20 ft Maximum Radius: 1195.12 ft Date: 2/20/2003 Time: 10:47:50 Page: Co-ordinate(NE) Reference: Vertical (fVD) Reference: Well: Plan MPS-04, True North S-Pad Dev 72.0 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/29/2001 Validated: No Version: 4 Planned From To Survey Toolcode Tool Name ft ft 33.00 1000.00 Planned: MPS-04 wp09 V17 CB-GYRO-SS Camera based gyro single shots 1000.00 9984.20 Planned: MPS-04 wp09 V17 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD TVD Diameter Hole Size Name ft ft in in 2864.35 2482.00 10.750 13.500 103/4" 7125.80 4334.00 7.625 9.875 7 5/8" 9984.19 4310.90 4.500 6.125 4 1/2" Summary <--- Offset Wellpath > Reference Offset Ctr-Ctr. No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M pt S Pad MPS-03 MPS-03 V20 355.79 350.00 14.42 8.02 6.39 Pass: Major Risk M pt S Pad MPS-03 MPS-03L 1 V9 355.79 350.00 14.42 7.89 6.52 Pass: Major Risk M pt S Pad MPS-05 MPS-05 V1 504.89 500.00 14.12 9.95 4.20 Pass: Major Risk M pt S Pad MPS-05 MPS-05L 1 V1 504.89 500.00 14.12 9.82 4.33 Pass: Major Risk M pt S Pad MPS-05 MPS-05PB1 V2 504.89 500.00 14.12 10.08 4.07 Pass: Major Risk M pt S Pad MPS-07 MPS-07 V9 695.97 700.00 37.64 12.66 24.99 Pass: Major Risk M pt S Pad MPS-09 MPS-09 V5 570.57 575.00 71.89 10.54 61.38 Pass: Major Risk M pt S Pad MPS-11 MPS-11 V4 624.97 625.00 100.02 11.98 88.05 Pass: Major Risk M pt S Pad MPS-13 MPS-13 V6 526.94 525.00 142.21 9.70 132.59 Pass: Major Risk M pt S Pad MPS-15 MPS-15 V7 545.02 550.00 162.84 10.33 152.51 Pass: Major Risk M pt S Pad MPS-17 MPS-17 V7 575.08 575.00 195.08 11.13 183.95 Pass: Major Risk M pt S Pad MPS-17 MPS-17L 1 V1 575.08 575.00 195.08 11.03 184.05 Pass: Major Risk M pt S Pad MPS-19 MPS-19 A PB1 RIG V2 520.89 525.00 223.97 10.74 213.24 Pass: Major Risk M pt S Pad MPS-19 MPS-19 A RIG V2 520.89 525.00 223.97 10.74 213.24 Pass: Major Risk M pt S Pad MPS-19 MPS-19 V9 503.07 500.00 223.71 10.34 213.37 Pass: Major Risk M Pt S Pad MPS-19 Plan MPS-19A V2 Plan: 520.61 525.00 223.97 10.54 213.43 Pass: Major Risk M pt S Pad MPS-19 Plan MPS-19AL 1 V3 Plan 502.60 500.00 223.70 10.27 213.43 Pass: Major Risk M pt S Pad MPS-21 MPS-21 V15 348.69 350.00 256.75 7.23 249.54 Pass: Major Risk M pt S Pad Plan MPS-01 Plan MPS-01 Pilot V4 P 349.99 350.00 46.13 8.80 37.33 Pass: Major Risk M pt S Pad Plan MPS-01 Plan MPS-01 V2 Plan: M 349.99 350.00 46.13 8.67 37.46 Pass: Major Risk M pt S Pad Plan MPS-01 Plan MPS-01 L 1 V1 Plan: 349.99 350.00 46.13 8.61 37.52 Pass: Major Risk M pt S Pad PI~n MPS-02 Plan MPS-02 V3 Plan: M 9445.75 7700.00 13.58 108.67 -79.41 FAIL: Major Risk M pt S Pad Plan MPS-04 Plan MPS-04 - old V1 P 5850.00 5850.00 0.87 167.03 -166.49 FAIL: Major Risk M pt S Pad Plan MPS-04 Plan MPS-04L 1 V1 Plan: 5850.00 5850.00 0.87 166.67 -166.13 FAIL: Major Risk M pt S Pad Plan MPS-06 Plan MPS-06 V4 Plan: M 771.49 775.00 26.57 16.63 10.10 Pass: Major Risk M pt S Pad Plan MPS-08 Plan MPS-08 V1 Plan: M 646.38 650.00 57.91 14.60 43.33 Pass: Major Risk M pt S Pad Plan MPS-10 Plan MPS-10 V7 Plan: M 399.99 400.00 89.72 10.12 79.60 Pass: Major Risk M pt S Pad Plan MPS-12 Plan MPS-12 V3 Plan: M 522.85 525.00 120.76 12.46 108.30 Pass: Major Risk M pt S Pad Plan MPS-12 Plan MPS-12L 1 VO Plan: 522.85 525.00 120.76 12.20 108.56 Pass: Major Risk M pt S Pad Plan MPS-14 Plan MPS-14 V2 Plan: M 400.00 400.00 150.00 10.04 139.97 Pass: Major Risk M pt S Pad Plan MPS-16 Plan MPS-16 V2 Plan: M 545.76 550.00 180.99 12.75 168.24 Pass: Major Risk M pt S Pad Plan MPS-18 Plan MPS-18 V3 Plan: M 521.11 525.00 210.37 12.33 198.04 Pass: Major Risk M pt S Pad Plan MPS-20 Plan MPS-20 V2 Plan: M 520.82 525.00 240.65 12.35 228.30 Pass: Major Risk M pt S Pad Plan MPS-20 RIG MPS-20 V2 449.98 450.00 244.07 10.22 233.85 Pass: Major Risk M pt S Pad Plan MPS-32 MPS-32 V3 Plan: MPS-32 449.96 450.00 421.00 10.33 410.67 Pass: Major Risk ( hJ fiJ 3 -ðt/ z-D3 -0->2- Per Alaska Oil and Gas Conservation Commission Regulation 20 AA 25.005 Permit to Drill sub section 14 (e) if a well has multiple well branches, each branch requires a separate Permit to prill. If multiple well branches are proposed from a single conductor, surface or production casing, the applicant shall designate one branch as the primary Wellbore and include all information required under (c) of this section that is unique to that branch and need not include the $100 fee. cW P f).55 tJ.3tÐ.ð¡:O 100 C~ ~/~ tu;+L rÓ/tcÀ-4:-r. fr ¡t{P5-oY¿/. ~L f TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~ S -0 :/' 2-03 -0 ~ ? CHECK WHAT APPLIES Rev: 07/10/02 C\jody\templates PTD# ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production .should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent UpOD issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. 'WELLPE~MIT: CHEÇK~I$T: Company BP_EXP.LQMIIQN.(ALASK8)JNÇ___.,__ ,..,.._.___...._,_ Well Name: .MlLN,EJ?LUNITSJ~._._...:i.-:~.i.__...__._____._ ProgramOEV_.___.____.. ____.n____ Well bore seg "PTD'#~'2'030'520' '. Fi~'ld·&P~OIMILNE.PQINI..S.cHBAOEKBLUEE:.._'=·___.._~~.~.lý"ª_ _________.__ Initial ClassfType _._.OEYL1:~_QIL_..__ GeoArea _690_.._.___ __._ Unit .1J.32.8___.____ On/Off Shore .on_._ Annular Disposal [J Administration '11 Permit fee attached . No . p~r 20 AAC25.005. (e)~ not .req.uired. for.multila.teral."branches." Perm.it f~e.iI'Jclu.ded with. app fo.r MP. S-04L~ .. .2 Lease .numbe.r approp.riate. . . . . . . . . . . . . . Yes. . . . . . . . . . . . . . . . . . . . . . . :3 .UJ1i~I,J~ w~lI.n.alJ1e .aoq lJuJl}b~( . . . . . . . . _ _ . _ _ . _ . . _ . _ . _ _ _ . _ _ . . . . . . . . . . . .Y~$ . . . . . . . . _ _ _ . . .. . _ _ _ _ _ _ . . .. .. _ . . . . . _ _ . . . . . . . . . . . . . . . . . . . . . . _ . . _ . . . . . . . . . _ . . . .. . . :4 WeJIJo.cated in.ad.efineOpool. . .. ........ . . Yes. . . . . . . . is WeJI Jo.cated prop~r di.stance.from drilling unitb.oundary. . . . . . . . . . . . . . . . . . .... Yes. . . . . . . . . . . . . . . . . . . . . . . . . . . . . i6 WeJI Jo.cated prop~r distance. from. Qthe.r wells. . . . . . . . . Yes . . . . . . . 17 .S!Jfficient acreag.e.available i.n.dritlilJg unit. . . . . . . . . Yes . . . . . . . . 8 If.deviated,is.wellbo.r~ platincluded . . . . . . . . . . . . . . . . . Y~s 9 Operator only aff~cted party. . . . . . . . . . . . . . . . . . . . . . . . . . Yes . . . . . . 10 .Oper.ator bas_appropriate.b_ooq iJ1 .fQrce. . . _ . _ _ _ . _ _ . . _ _ _ .. _ _ _ _ .. _ _ .. . . . . . . . . . .Ye$ . . . . _ _ _ _ _ . . . _ . .. . _ _ _ _ _ . _ . . _ . . _ _ _ . . . . . . . . . . . . .. . _ _ . _ _ . . _ . .. . . . . . . . . _ _ . . . . _ _ . _ . . 11 Per:mitc.ao be i$su.ed witho.ut co.ns~rvation Qrd~r. . . . . . .. ............ _ . . . . . . Yes . . . . . . . . . . _ . _ . . . . . . . . . _ . . . _ . . . . . . . . _ . . . . _ . . . . . . . , . . _ . . . . . 12 Permit.c.ao be i.ssu.eO witho.ut ad.rn.inistrativ.e.approvaJ . . Yes . . . . . . . . . . . . . . . . . . . . . . 4/2/2003 13 Can permit be approved before 15-day wait Yes 14 WeJI Jo.cated with,in area an.d_strata authorized by.lnjectiolJ Order # (puUO# in.comments).(for. NA . . . . . . . . . . . . . . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . . . . . _ . . . . _ . . . . . . 15 A!lwel!s_within.1¿4.mil~_are_a_ofr.eyiewideotifieq(For:.s.ervjce..w~UQI1IYL.. _ _ _ _. _ _ _ _ _ _.. NA _ _... _.. _.. _. _. _. _ _. _ _... _.......... _ _ _ _.. _ _ _.... _. _ _ _ _. _....... _ _ _ _ _ _... _ _ _... 16 Pre.-produced. iojector:. duratjo.n .of pre-PrOdUc.tiOI'J less. tban. ~ mOnths. (for .seryice welt o.n!y) . . NA . . _ . . . . . _ . . . .. . . . . . . _ . . .. . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . . . . 17 A.GMP.F,inding .of CQn$ist.enc.y.has b~eJ1 js_su~d.for.tbis proj~ct . . . . . . . . .. . . _ . _ . . NA. . . . . . . _ . _ . _ . . . . . . . . . . . . . _ . . . . . _ . . . . . . . . .. ....... _ . _ . _ _ .. ...... _ . . . . . _ . . . . Appr SFD Engineering Appr Date TEM 4/2/2003 - - - - . - - . - - . ~ - - . . - - . ~ - - - - - - - - - - - - - - - - - - Date (' -"---------,.---- --.----- 18 .G.onduct.or. strJn9.prQvi.ded . . _ . . . . . . . . _ . . . . . . . . . . . . . _ . . . . . . . . . . . . . . .. Yes. . .. _ . . . . . . . . . . . .. . . . . _ . _ . .. . . . . . . . . . . .. . _ . . . . . . . . . . . . . . . . . . . . . . . . . .. . . 19 Surface.cas.ing.PJQtects.all.known.USOWs..........."...."......... _.... NA.... _. .AltaquifeJsexelJlptedbyEPA..40.GFR.H'Z.1Q2.(b).(3),......... _......."........... _...... 20CMT.vpta.d~qu.ateJo cir.culate.on .cond.uçtor..& $u.rf_csg . . . . . .. . . . . . .. . . _ . . . . . . . . . Yes.. . _ . . . .. .. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ . . . .. _ . . . _ . . . 21 .GMTvota.dequ.ateJoti~-inJo.ng.striogto.s!Jrfcs.g........ _.... ............... N.o....... ..Le.adc~m~nttoppl.aoned.50Q'abQuv~Ugn.u,,(46.52')..tQP.oftaHpl.aOned.50Q'abo.veN.saod......... . 22 .GMT will cover .aU KnOwn pro.dl,lc;tiYe bQri~Qn.s. _ . . . . . . . . . . . . . _ . . . . .. . . . . . .. No. " . . . . . . Slotte.d Jio~r .comple.ti.oo plaoneçl. . . . . . . . . . . " . . . . . . . . . " . . . . . . . . . . . . . . . . . . . . . 23 .G.a$iog de.signs ad.equat~ for:. C.T. B .&.p,ermafr.osL . .. . . . . . .. " . . . .. . . . . . . . . Yes. . . _ . . . . . . . _ .. . _ .. _ . . . . _ . . _ . . . . . . . . . _ . . . . . . . . . . . . . . . .. _ . . . 24 Adequat.e .tan.kage.oJre.sery~ pit. .. . . .. . . . . . . . . . . .. . .. . . . . . . . . . . _ . _ . . . . .. .. Yes . . . ~Q r:.es~rve. pit.pJa.noed.. Rig is equjp,ped with. s.teeJ pits.. AU waste t.o.be .haul~d.to G&L . . . . . . . . . . 25 Jf.a.re-çlr.ill~ bas.a" 1.0:,403 fOJ aba.ndonment. be~n apprQv~d . . . .. _ . . _ . . _ .. . . . .. . " . NA . . . . . . . . . . .. . " . . . . _ . . . . . . . .. . . . . . . . . . . " . . .. . . . .. . _ .. . . . . .. .. . . . . . . . 26 Adequ¡;¡te wellbore. s.eparç¡tioJ1proPQseçl- . _ _ . _ .. _ _ .. .. _ .. .. _ . .. .. _ _ _ _ .. _ _ _ . _ _ . .. _ _ Y~$ _ _ . _ _ _ _ Çlose.appr.oach.a.nçl m.agnetiç al1a!y¡;i¡; perform~d.. .Gyro.s .and i.n:h.ol~ J~ferel1c~ .sI,Jryey_s planoe.d. _ .. .. . . _ . .. .. _ 27 Jf.d.iv~r:t~r re,q.ui.r~d. do.es it meetreguJa.tiOl1s. . . _ _.. _......................... Y~s . . . . . . . . . . . . . . . . . _ _ _ . . .. . . . . . . . . . . . .. . " .. . . .. " .. . . . . . . . .. . .' _ . .. . . " . .. ............. 28 .DrilJiog fluid.pJQgram $chemati.c..&. equip JisLadequate. . . . .. . . . . . _ . . . .'.. . .. .. .. . . . " . Yes. . . . . . . Max anticipate..d.BH.P. 8..2 PP9. Planne.d_pJQd!Jcti.on hole MW r:.ange.9..Q -.9..3 ppg, . . . _ " . . _ . . . . 29 .BPP!::s,.d.o .they meetreguJa.tion . . . . . . . . . _ . _ . . .. . . . . . . . .. . . . . . . Yes. . .. . . .. .. . . . . . . . .. . . . .. . . . . . . . . . . . . _ _ _ . . . " " . .. . .. . . . . . . . . . . . . . . . . 30 .BPP!::.pre"SS ratiog appr:.opr.iate; .te..st to .(put psig in _comments). . . . . . . _ . . . _ _ . . . . . _ _ Y~s . . . . . . _ MA$~ estim.ated.at. 1.397 psi.. PlalJn.ed .BOP _test press.ur.e.3.50Q psj.. . . . . . .. _ . . . . . . . . . . .. . 31 .Choke.manifold ço.mpJies. w/t\PI.RP-53. (May 84). .. . . _ . . . . .. . . . . . . . _ .. . .. . . . . . . . Yes .. . . _ _ .. . . . . . . . . .. _ . _ . . .. _ . . _ .. _ . " . . . .. .. .. .. . . . . .. . . . . _ . . _ . .. . . . . . . . . . . . _ " . . . . . . . . . 32 WOJk wiU occur. withouLoperati.on .sbu.tdown. . _ . . . . . . Yes. . . . . . . _ . . . . . . . . .. . . . . . . . . . . " . . . . . . . . 33 .Is. pres..ence. o.f H2S gas. p,rQb.able. . . . . . . _ . . .. ... _ . . . . . " ." . _ . . . . . . . . . No.. . . . . . . . . _ . . . . . . . . . _ . _ . . . . . _ . . . . . . . . . . . . . . . _ . . . . . . . . . . . . . . . . . . . .. . . . . .. 34 Meçha.ni.cal.cOlJdjti.o!.1 pf weJls Wi.thjn AQR y~rified. (.For.s~r:vi.ce well onJy) . . . . . . .. . .. .. . . . . NA. . . . . .. . _ . . . . .. .. . . . . . .. . . .. . . . . . . . .. . . _ _ . . .. .............." _ . . . . " . . .. . . . _ _ ( --------- ----.-.-.--.-.-.--...---..--.--.-...--.--.-- Geology -----_._._--~~-----,-----, ------.......-. ..------.---.--,."----.--.--- Appr SFD Date 4/1/2003 Geologic Commissioner: DT.s- ---------_._--------_..-...,._--~._.. 35 PerIT)itc.an be i$su_ed wlo. h.ydr.og~n.s.ulfid~ measur:.es.. _ . . . . . . . . . . . . . . .. _ . . . . . . . .Yes _. _ _ . . . . _ . . _ . . . . . . . . . . _ . . . _ . . . . . . . . . . . . .. " . _ . . _ . . . . . . . . . . . . . .. . . . . . . . . . 36 .D.at.a.pr~sented.Qn_p.ote.ntia-'o\{eJpres.sure~Ones.............. .. _..... _ _.... _. _ Yes........ .O\{erpr~s.sure.not.expe.cted...t\oti.cipatedpr.ess.ure.gradJe.ntQf.8,35.EMWbased OI'J QffsetweJls.. .... 37 .Seismic.analysjs.o.f shaJlow gas_zooe.s. . . . _ _ . . . . . . . . . . . . . . .. .. . NA . . . . . . . . . . . . . . . . .. . . . .. .. ....... _ . . . . . . . . . . .. . _ . _ . . . .. . . . .. . _ . . . . . 38 .Seabeçl.cOl1ditiolJ SU.rvey.(if Qff.-shor.e) . . . .. . _ . . .. . . . " . . . . . . . . . . . . . . . . . . . . . NA _ . . . _ . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . _ . _ _ . . _ . . . . _ . . " .. _ . . _ . _ . . . . . . . . . . . _ . . . . _ . . . 39 . Co.nta.ct. n.a!11.e¿phon.eJQrwe~kly- progressJep,o(ÌS [e~pIQratory .only]. .. . . . . . . . . . NA. . . . . . . . . . . . . . . . . . _ _ . . . . . . . . . . . . . _ _ . . . . . . .. . . . . . . . . . .. . .. . . . . . . .. . _ . . _ . . . . . . . . Date: Engineering Commissioner: Public Commissioner Date.. 8JO 0~J Date 0«0'103 ) ) Welll-1istory 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 infonnalion. inforTllalion of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically '. organize this category of information. Sperry-Sun Dl )ing Services LIS Scan Utility ) ~()3 -D5 ~ )\D~'B $Revision: 3 $ LisLib $Revision: 4 $ Tue Jun 10 10:30:21 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03/06/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-04 500292314800 BP Exploration (Alaska) fIne. Sperry-Sun Drilling Services 10-JUN-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002412654 J. STRAHAN D. FERGUSON MWD RUN 2 MW0002412654 J. STRAHAN D. FERGUSON MWD RUN 3 MW0002412654 B. ZIEMKE E. VAUGHN f J # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 7 12N lIE 3364 4758 72.25 38.30 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.125 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 112.0 2842.0 7144.0 # REMARKS: )) 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD) , AND A FIELD TRIAL OF SPERRY'S MWD FORMATION TESTER, GEOTAP. ADDITIONALLY, MWD RUN 3 INCLUDED AT-BIT-INCLINATION (ABI) . 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 5/15/03. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-3 REPRESENT WELL MPS-04 WITH API#: 50-029-23148-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9977'MD/4337'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD 1 and clipped curves; all bit runs merged. .5000 START DEPTH 67.5 111.0 2835.0 2835.0 STOP DEPTH 9924.0 9977.0 9931.0 9931.0 RPM RPS RPX $ 2835. 2835.0 2835.0 ) 9931.0 9931.0 9931.0 ) # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 67.5 2852.0 7152.0 MERGE BASE 2852.0 7152.0 9977.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 9977 5022.25 19820 67.5 9977 ROP MWD FT/H 0.55 3163.09 259.628 19733 111 9977 GR MWD API 13.72 131.99 66.7073 19714 67.5 9924 RPX MWD OHMM 1 1729.16 20.1217 14193 2835 9931 RPS MWD OHMM 0.49 2000 24.0795 14193 2835 9931 RPM MWD OHMM 0.54 2000 33.8574 14193 2835 9931 RPD MWD OHMM 0.54 2000 32.2418 14193 2835 9931 FET MWD HOUR 0.06 59.64 1.00751 14193 2835 9931 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .9977 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/10 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO '1 N ¡lSLIB.002 Next Fl e ame.......... .r Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/10 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ) header data for each bit run in separate files. 1 .5000 START DEPTH 67.5 111.0 STOP DEPTH 2810.5 2852.0 # 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 DGR DUAL GAMMA RAY $ # 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: 28-APR-03 Insite 66.37 Memory 2852.0 112.0 2852.0 .0 60.7 TOOL NUMBER 124725 13.500 112.0 SPUD 9.25 100.0 9.0 1100 10.0 .000 .000 .000 .000 .0 68.0 .0 .0 HOLE CORRECTION (IN). ) ) # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 67.5 2852 1459.75 5570 67.5 2852 ROP MWD010 FT/H 44.36 3163.09 216.297 5483 111 2852 GR MWD010 API 20.03 118.53 64.0858 5487 67.5 2810.5 First Reading For Entire File......... .67.5 Last Reading For Entire File.......... .2852 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/10 Maximum Physical Record. .65535 F i 1 e 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...... .03/06/10 Maximum Physical Record. .65535 File Type...... . . . . . . . . . . LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 3 header data for each bit run in separate files. 2 .5000 FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPX RPS ROP $ ) START DEPTH 2811.0 2835.0 2835.0 2835.0 2835.0 2835.0 2852.5 STOP DEPTH 7115.0 7107.0 7107.0 7107.0 7107.0 7107.0 7152.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # 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..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 ) 02-MAY-03 Insite 66.37 Memory 7152.0 2852.0 7152.0 60.5 75.9 TOOL NUMBER 164580 134760 9.875 2842.0 LSND 9.20 57.0 8.5 1000 5.0 3.900 2.980 4.600 3.500 74.0 99.0 75.0 72.0 Depth Uni t s . . . . . . . . . . . . . ). . . . . . . . ) Datum Specification Block sub-type.. .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 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2811 7152 4981.5 8683 2811 7152 ROP MWD020 FT/H 0.55 1199.65 313.423 8600 2852.5 7152 GR MWD020 API 13.72 131.99 67.4916 8609 2811 7115 RPX MWD020 OHMM 1 1234.34 19.69 8545 2835 7107 RPS MWD020 OHMM 0.49 1971.18 23.985 8545 2835 7107 RPM MWD020 OHMM 0.54 2000 24.6481 8545 2835 7107 RPD MWD020 OHMM 0.54 2000 25.6708 8545 2835 7107 FET MWD020 HOUR 0.06 48.17 0.699816 8545 2835 7107 First Reading For Entire File......... .2811 Last Reading For Entire File.......... .7152 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/10 Maximum Physical Record. .65535 F i 1 e 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...... .03/06/10 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET 4 header data for each bit run in separate files. 3 .5000 START DEPTH 7107.5 7107.5 7107.5 7107.5 7107.5 STOP DEPTH 9931.0 9931.0 9931.0 9931.0 9931.0 GR ROP $ 7115. 7152.5 ) 9924.0 9977.0 # 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 VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # 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..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 06-MAY-03 Insite 66.37 Memory 9977.0 7152.0 9977.0 81.2 92.9 TOOL NUMBER 129046 159439 6.125 7144.0 FLO-PRO 9.10 49.0 9.5 13000 5.8 .440 .380 .210 .300 77.0 91.4 77.0 77.0 Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 RPX MWD030 OHMM '1 1 68 12 4 ) RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7107.5 9977 8542.25 5740 7107.5 9977 ROP MWD030 FT/H 14.01 611.23 219.796 5650 7152.5 9977 GR MWD030 API 31.43 124.05 68.0658 5618 7115.5 9924 RPX MWD030 OHMM 1.45 1729.16 20.7749 5648 7107.5 9931 RPS MWD030 OHMM 1.43 2000 24.2226 5648 7107.5 9931 RPM MWD030 OHMM 2.76 2000 47.7904 5648 7107.5 9931 RPD MWD030 OHMM 0.87 2000 42.1833 5648 7107.5 9931 FET MWD030 HOUR 0.16 59.64 1.47303 5648 7107.5 9931 First Reading For Entire File......... .7107.5 Last Reading For Entire File.......... .9977 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/06/10 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/06/10 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date.................... .03/06/10 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File