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Home My WebLink About203-1321. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Cut Tubing Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Cement the OA Lateral 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number): 10. Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 11,159' N/A Casing Collapse Conductor N/A Intermediate 2,090psi Production 4,790psi NE Liner 7,500psi OA Liner 7,500psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: 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 Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 9,868 MD/ 4,044 TVD & 9,984 MD/ 4,074 TVD and N/A Ryan Lewis ryan.lewis@hilcorp.com 303-906-5178 4-1/2" 12.6# / L-80 / IBT 9,962' 13,232' Perforation Depth MD (ft): 13,091' See Schematic 2,959' See Schematic 3-1/2" 4,234'4-1/2" 110' 20" 10-3/4" 7-5/8" 5,518' 4-1/2"2,964' 11,159' MD N/A 8,430psi 3,580psi 6,890psi 2,894' 4,246' 4,225' 5,518' 11,159' Length Size Proposed Pools: 110' 110' 9.2# / L-80 / TC-II TVD Burst 10,040' 8,430psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0380109 203-130 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23171-00-00 Hilcorp Alaska LLC C.O. 477B AOGCC USE ONLY Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): 1/1/2026 7-5/8" x 4.5" Tripoint & 7-5/8" x 4.5" Premier and N/A Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY MILNE PT UNIT S-34 MILNE POINT SCHRADER BLUFF OIL N/A 4,323' 10,516' 4,199' 1,055 N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143) Date: 2025.12.30 14:24:31 - 09'00' Taylor Wellman (2143) 325-780 By Grace Christianson at 3:25 pm, Dec 30, 2025 203-132 SFD * OA lateral well branch is S-34L1. S-34 will remain open to production from NE lateral (S-34L2). SFD SFD 12/30/2025 50-029-23171-60-00 SFD SFD DSR-1/16/26 SFD L1 SFD * 10-407 MGR09JAN2026 SFD JLC 1/20/2026 01/20/26 Well: MPS-34 PTD: 203-130 Well Name:MPS-34 API Number:50-029-23171-00-00 Current Status:Shut-in Producer Rig:Coil Estimated Start Date:1/1/2026 Estimated Duration:2 days Regulatory Contact:Tom Fouts Permit to Drill Number:203-130 First Call Engineer:Ryan Lewis (303) 906-5178 (M) Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) Current Bottom Hole Pressure: 1458 psi @ 4,033 TVD 12/4/2025 | 7.0 EMW Max Potential Surface Pressure: 1,055 psi Gas Column Gradient (0.1 psi/ft) Max Angle:74° Sail Angle from 4,331 MD Min ID:XN-nipple 2.75 @ 10,034 MD Brief Well Summary: The Milne Point S-34 well was drilled in 2003 using Doyon 14 and completed as a dual lateral in the Schrader Bluff NE and OA sands with a Jet Pump. In December 2012, SL bailed ~20 gal of sand from on top of the jet pump and continued to bail another 10 gal after pulling the jet pump. A CTU fill clean out of the tubing tail and into one of the laterals was completed in February 2013, and an 8C jet pump was set in March 2013. The jet pump was pulled out of MPS-34 on March 22, 2013. A new 8C jet pump was set on 4/30/13, but appears to just be circulating power fluid. Slickline attempted to set a 9A jet pump in July 2013. Originally tagging at 8,450 SLM, SL bailed down to 9,687 SLM. SL was unable to bail any deeper than 9,687 SLM and it was recommended that CTU be used to retrieve the JP and FCO the well. Coil Tubing pulled the JP and performed a FCO on the lateral to 11,530 CTM in November 2015. Coil Tubing then attempted to cut the tubing @ 9,975 CTM in December of 2015. 2022 JP Completion was replaced. It was produced for 3 weeks and was SI. 11/1/22 Coil made a FCO and reached 10,541 CTM. Currently SI. Objectives: 1. Coil Res cement isolation of the OA lateral for future drilling. 2. FCO the NE lateral to produce as NE alone. Notes Regarding Wellbore Condition: Not Operable Deviation down to pump section (max angle 77.2° @ 4,886). Deviation at pump is 76°. Fullbore: 1. RU to IA. Pressure test lines. 2. MIT-IA casing to 3,750 psi for 30 minutes charted for CO-808. 3. RDMO. Coil Procedure: 1. MIRU 1.75CTU. PT PCE accordingly with respect to the coil weekly BOP testing 2. RIH w/ +-2.25 cleanout BHA: dual BPV, coil disconnect, GR/CCL, Tempress Hydro pull and down jet nozzle . 3. RIH and dry tag. PU and break circulation. 203-132 SFD NOTE: Primary wellbore S-34 was cased, but never opened to the pool. Schrader Bluff OA lateral well branch is S-34L1. Schrader Bluff NE lateral well branch is S-34L2. However, per historical policy production from both NE and OA well branches is reported against the primary wellbore S-34. SFD L1 SFD 50-029-23171-60-00 SFD 203-132 SFD L1 SFD cement isolation of the OA lateral Well: MPS-34 PTD: 203-130 4. Begin FCO/ Fluff-n-stuff to PBTD. a. Anticipate entering into the lower Oa lateral b. Perform PU weights as seen fit by WSM c. Obtain continuous single pass from 9,900 10,500-ft MD if possible d. Last time coil was in this well they were not able to get past 10,541 CTM. 5. POOH to surface and download memory GR/CCL a. Compare the logging runs w/ GR/CCL to verify which lateral being entered (OA or Ne) and whether both runs were consistent. The GR gets hotter as we go deeper in the OA. Contact OE and Geo Patrick Boyle patrick.boyle@hilcorp.com or (267) 2407493 to confirm which lateral was entered. b. (If entry into the Ne (upper lateral)) i. Contact OE for plan forward. 6. Assuming we default into the OA lateral as planned. MU cementing BHA with circ sub, Tempress and RIH to enter the OA lateral. Once at PBTD, mix 44.6 bbls of cement and pump down the coil taking returns to formation. Top screen is at 10,299 MD. Once cement is at the nozzle lay in cement 1:1 from PBTD to 10,299-ft MD as per PE manual recommendations. NOTE: OA Lateral Volume: (13230 10299 = 2931-ft MD) x 0.0152 bpf = 44.6 bbls 7. At the lateral junction swap over to Gel and contaminate the cement to ensure we can set the Hook wall hanger and reenter the Ne lateral. 8. POOH and circulate as needed to clear coil and replace pipe displacement. WOC to reach compressive strength. 9. RIH with a +-2.50 drift BHA and confirm cement top. POOH. 10. MU cleanout BHA w/ Baker hydraulic bent sub and hydraulic indexing tool or eccentric weightbar with a swivel and fixed angle hydraulic bent sub and AV sub BHA. RIH and orient as needed to enter the Ne lateral. a. If the hole is clean lets discuss running the eccentric weightbar with a swivel and fixed angle hydraulic bent sub. b. If there is a lot of fill in the well run the hydraulic indexing tool. NOTE: TOC in the OA lateral should be at ±10,299-ft MD 11. Use the depth control from the logging run to get on depth for the window. 12. If entry into the Ne lateral is unachievable POOH, RDMO. 13. Begin FCO/ Fluff-n-stuff to PBTD. 14. POOH 15. RDMO Coil Unit. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Coil BOPE Schematic L1 SFD 203-132 SFD _____________________________________________________________________________________ Revised By: TDF 10/7/2022 SCHEMATIC Milne Point Unit Well: MPU S-34 Last Completed: 9/29/2022 PTD: 203-130 69jts -4-1/2 Slotted Liner 10,224 to 13,047 61jts -4-1/2 Slotted Liner 10,504 to 13,147 363 Rat Hole 0 Rat Hole TD =11,159(MD) /TD =4,323(TVD) 20 Orig. DF Elev =72 / Orig Tbg. Hgr Elev.=29.7 Doyon 14 7-5/8 4 5 6 7 8 10 9 11 12 13 10-3/4 2 NOTE: Min ID @ 10,034 2.750 1415 16 Tubing Cut @ 9,957 9/4/2022 NE Lateral 3 OA Lateral 1 NOTE: ID 3.725@ 9,934 CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 215 / A-53 / Welded 17.938 Surface 112' N/A 10-3/4 Surface 45.5 / L-80 / Btrc. 9.950 Surface 5,518 0.0962 7-5/8" Intermediate 29.7 / L-80 / IBT-M 6.875 Surface 11,159' 0.0459 LINER DETAIL 4-1/2 NE Solid Liner 12.6 / L-80 / IBT 3.958 10,13613,091 N/A4-1/2 NE Slotted Lnr 12.6 / L-80 / IBT 3.958 10,224 4-1/2 OA Solid Liner 12.6 / L-80 / IBT 3.958 10,27313,232 N/A4-1/2 OA Slotted Lnr 12.6 / L-80 / IBT 3.958 10,504 TUBING DETAIL 4-1/2 Tubing 12.6 / L-80 / IBT 3.958 Surface 9,962 0.0152 3-1/2" Tubing 9.2 / L-80 / TC-II 2.992 9,962 10,040 0.0087 JEWELRY DETAIL No Depth Item 1 9,789 HES DURA Sliding Sleeve, 4.5 ( 3 Ports Plugged)ID= 3.813 2 9,830 ZENITH BHP C-6 Gauge 4.5ID= 3.930 3 9,868 7-5/8'' x 4.5'' 26-32# Tripoint Packer: ID= 3.875 4 9.934 4.5'' "XN" Nipple:ID= 3.725 5 9,961 NS Prod. Overshot Guide (4.50''Drift)Bottom @ 9,962 6 9,983 3.5 x 4.5 X-Over 7 9,984 7-5/8 x 4.5 Baker Premier Packer: ID= 3.875 8 9,991 4.5 x 3.5 X-Over 9 10,034 3.5 HES XN-Nipple:ID= 2.750 No Go 10 10,039 WLEG Bottom @ 10,040 11 10,137 Baker 6 Tie-back Sleeve 12 10,146 Hook Wall Hanger Inside 7-5/8 Casing 13 10,171 Hook Wall Hanger Outside (Hook Point) 14 10,273 Baker 7 Tie-back Sleeve 15 10,280 Baker ZXP Liner Top Packer 16 10,286 Baker 7-5/8 x 5-1/2 HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset in 42 Hole 10-4/4" 935 sx PF L, 371 sx Class G, Top Job 54sx PF L in 13-1/2 Hole 7 725 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 280 MD Hole Angle Passes 50 Deg. @ 2,150 Max Angle in Tubing = 78 Deg. 75 Deg. at sliding sleeve TREE / WELLHEAD Tree 4-1/6 5M FMC Wellhead 11x 4-1/2 5M Gen 6 w 4.5TC-II T&B Tubing Hanger CIW H BPV profile GENERAL WELL INFO API: 50-029-23171-00-00 Drilled and Cased by Doyon 14 - 9/2/2003 Coil Clean-out and Jet Pump Removal 11/21/2015 Jet Pump Completion by ASR 9/29/2022 NE LATERAL WINDOW DETAIL Window in 7-5/8 Casing @ 10,159 to 10,171(MD)/ 4,115 to 4,117(TVD) Well Angle @ window = 78 Deg. OA LATERAL WINDOW DETAIL Window in 7-5/8 Casing @ 10,516 to 10,528(MD)/ 4,199 to 4,201(TVD) Well Angle @ window = 77 Deg. L1 SFD 203-132 SFD _____________________________________________________________________________________ Revised By: TDF 12/15/2025 PROPOSED Milne Point Unit Well: MPU S-34 Last Completed: 9/29/2022 PTD: 203-130 69jts -4-1/2 Slotted Liner 10,224 to 13,047 61jts -4-1/2 Slotted Liner 10,504 to 13,147 363 Rat Hole 0 Rat Hole TD =11,159(MD) / TD =4,323(TVD) 20 Orig. DF Elev =72 / Orig Tbg. Hgr Elev.=29.7 Doyon 14 7-5/8 4 5 6 7 8 10 9 11 12 13 10-3/4 2 NOTE: Min ID @ 10,034 2.750 1415 16 Tubing Cut @ 9,957 9/4/2022 NE Lateral 3 1 NOTE: ID 3.725@ 9,934 TOC @ ±10,299 MD OA Lateral CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm BPF 20" Conductor 215 / A-53 / Welded 17.938 Surface 112' N/A 10-3/4 Surface 45.5 / L-80 / Btrc. 9.950 Surface 5,518 0.0962 7-5/8" Intermediate 29.7 / L-80 / IBT-M 6.875 Surface 11,159' 0.0459 LINER DETAIL 4-1/2 NE Solid Liner 12.6 / L-80 / IBT 3.958 10,13613,091 N/A4-1/2 NE Slotted Lnr 12.6 / L-80 / IBT 3.958 10,224 4-1/2 OA Solid Liner 12.6 / L-80 / IBT 3.958 10,27313,232 N/A4-1/2 OA Slotted Lnr 12.6 / L-80 / IBT 3.958 10,504 TUBING DETAIL 4-1/2 Tubing 12.6 / L-80 / IBT 3.958 Surface 9,962 0.0152 3-1/2" Tubing 9.2 / L-80 / TC-II 2.992 9,962 10,040 0.0087 JEWELRY DETAIL No Depth Item 1 9,789 HES DURA Sliding Sleeve, 4.5 ( 3 Ports Plugged)ID= 3.813 2 9,830 ZENITH BHP C-6 Gauge 4.5ID= 3.930 3 9,868 7-5/8'' x 4.5'' 26-32# Tripoint Packer: ID= 3.875 4 9.934 4.5'' "XN" Nipple:ID= 3.725 5 9,961 NS Prod. Overshot Guide (4.50''Drift)Bottom @ 9,962 6 9,983 3.5 x 4.5 X-Over 7 9,984 7-5/8 x 4.5 Baker Premier Packer: ID= 3.875 8 9,991 4.5 x 3.5 X-Over 9 10,034 3.5 HES XN-Nipple:ID= 2.750 No Go 10 10,039 WLEG Bottom @ 10,040 11 10,137 Baker 6 Tie-back Sleeve 12 10,146 Hook Wall Hanger Inside 7-5/8 Casing 13 10,171 Hook Wall Hanger Outside (Hook Point) 14 10,273 Baker 7 Tie-back Sleeve 15 10,280 Baker ZXP Liner Top Packer 16 10,286 Baker 7-5/8 x 5-1/2 HMC Liner Hanger OPEN HOLE / CEMENT DETAIL 20" 260 sx of Arcticset in 42 Hole 10-4/4" 935 sx PF L, 371 sx Class G, Top Job 54sx PF L in 13-1/2 Hole 7 725 sx Class G in 9-7/8 Hole WELL INCLINATION DETAIL KOP @ 280 MD Hole Angle Passes 50 Deg. @ 2,150 Max Angle in Tubing = 78 Deg. 75 Deg. at sliding sleeve TREE / WELLHEAD Tree 4-1/6 5M FMC Wellhead 11x 4-1/2 5M Gen 6 w 4.5TC-II T&B Tubing Hanger CIW H BPV profile GENERAL WELL INFO API: 50-029-23171-00-00 Drilled and Cased by Doyon 14 - 9/2/2003 Coil Clean-out and Jet Pump Removal 11/21/2015 Jet Pump Completion by ASR 9/29/2022 NE LATERAL WINDOW DETAIL Window in 7-5/8 Casing @ 10,159 to 10,171(MD)/ 4,115 to 4,117(TVD) Well Angle @ window = 78 Deg. OA LATERAL WINDOW DETAIL Window in 7-5/8 Casing @ 10,516 to 10,528(MD)/ 4,199 to 4,201(TVD) Well Angle @ window = 77 Deg. L1 SFD 203-132 SFD • of Ty yw Alaska Oil and Gas \��,�s THE STATE T a SKA Conservation Commission � .# _ 333 West Seventh Avenue seirt GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main 907 279.1 433 ALAS'" Fax 907.276.7542 www aogcc.alaska goy SC/4°V Stan Porhola Operations Engineer 2 Hilcorp Alaska, LLC ap 3 `- C7 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Schrader Bluff Oil Pool, MPU SB S-34L1 Sundry Number: 315-513 Dear Mr. Porhola: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, P Cathy P. oerster Chair DATED this 28day of August,2015 RBDMS SEP 0 4 2015 Encl. • RECEIVED STATE OF ALASKA AUG 2 1 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION as $ 21 ( I S APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 0 Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate ❑ Alter Casing 0 Remove&Replace Jet Pump❑, Plug for Redrill❑ Perforate New Pool ❑ Repair Well g/ Re-enter Susp Well ❑ Other. CT Fill Clean-out Q. 2,Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC . Exploratory ❑ Development a. 203-132 • 3.AddressStratigraphic ❑ Service ❑ 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23171-60-00 7.If perforating. 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O.477.05 Will planned perforations require a spacing exception? Yes ❑ No ❑✓ MILNE PT UNIT SB S-34L1 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0380109 MILNE POINT/SCHRADER BLUFF OIL 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): 13,232 4,234 13,232 4,234 N/A N/A Casing Length Size MD TVD Burst Collapse • Conductor 110' 20" 110' 110' N/A N/A Intermediate 5,518' 10-3/4" 5,518' 2,894' 3,580psi 2,090psi Production 11,159' 7-5/8" 11,159' 4,246' 6,890psi 4,790psi NE Liner 2,964' 4-1/2" 13,091' 4,225' 8,430psi 7,500psi • • AO Liner 2,959' 4-1/2" 13,232' 4,234' 8,430psi 7,500psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 3-1/2" 9.2*/L-80 NSCT 10,040 See Attached Schematic I See Attached Schematic 4-1/2" 12.6#/L-80/IBT-M Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): 7-5/8"x 4.5"Baker Premier and N/A • 9,984'(MD)/4,074'(TVD)and N/A 12.Attachments: Description Summary of Proposal Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch E Exploratory ❑ Stratigraphic❑ Development Q• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/4/2015 Commencing Operations: OIL 0. WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: N/A GAS ❑ WAG ❑ GSTOR ❑ SPLUG 0 Commission Representative: N/A GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Email soorholac hilcorp.com Printed Name Stan A„,/--..._ Porhola Title Operations Engineer Signature Phone 777-8412 Date 8/20/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: / 315- 5G LJ Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: 14 3066 r y.- SO/2 7:5- - ( mA-5P op s,1 ) Spacing Exception Required? Yes ❑ No It Subsequent Form Required: /01 p`-( APPROVED BY Approved by:aiiiii° c.—__- COMMISSIONER THE COMMISSION Date: r0—� —/�t9/ ,t nnir' inI AI RA srhq/is �� Well Prognosis Well: MPU S-3411 Ililcorp Alaska,LL Date:8/20/2015 Well Name: MPU S-34L1 API Number: 50-029-23171-60 Current Status: SI Oil Well [Jet Pump] Pad: S-Pad Estimated Start Date: September 4th, 2015 Rig: Coil Tubing Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 203-132 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907)444-2881 (M) AFE Number: Current Bottom Hole Pressure: 1,410 psi @ 4,000' TVD (Last BHP measured 3/23/2015) Maximum Expected BHP: 1,410 psi @ 4,000' TVD (No new perfs being added) Max.Allowable Surf Pressure: 0 psi (Based on SBHP taken 3/23/2015 and water cut of 50% (0.385psi/ft)with an added safety factor of 1,000' ND of oil cap) Brief Well Summary: MPU S-34 was drilled in 2003 using Doyon 14 and completed as a dual-lateral (S-34L1 & S-34L2) in the Schrader Bluff NE and OA sands with a Jet Pump. Notes Regarding Wellbore Condition • Deviation down to pump section (max angle 77.2° @ 4,886'). Deviation at pump is 76°. • Casing last tested to 250/3,500 psi for 30 min down to 9,546'on 8/21/2003. • Jet Pump SI, performance impacted by solids on top of pump. Objective: The purpose of this work/sundry is to pull the existing Jet Pump, cleanout the tubing tail and OA lateral (L1) with coil tubing. Brief Procedure: Coiled Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,500 psi Hi 250 Low. 2. RIH w/2.00" coil w/3.5"wash nozzle and cleanout to top of Jet Pump+/-9,934' MD. POOH. a. Min ID is 3.813"thru Sliding Sleeve. 3. RIH w/2.00" coil w/GS pulling tool and pull Jet Pump+/-9,934' MD. POOH. 4. RIH w/2.00" coil w/3.5"wash nozzle to sliding sleeve at+/-9,934' MD. 5. Bullhead filtered 8.4 ppg produced water down annulus, lifting sand/solids up the 2.0" coil x 4.5" tubing annulus. POOH. 6. RIH w/2.00" coil w/2.5" wash nozzle and cleanout to end of OA lateral at+/- 13,147' MD. POOH. a. Min ID is 2.750"thru XN Nipple. 7. RIH w/2.00" coil w/jet cutter and make cut across packer mandrel at+/-9,984' MD. 8. PU to+/-9,900' MD. Displace well over to 8.4 ppg produced water. a. Estimated volume (w/o coil in hole) is 150 bbl. 9. POOH w/coil. LD 2.5" wash nozzle. 10. RD Coiled Tubing. • Well Prognosis Well: MPU S-34L1 fiac„rN Alaska.LL Date: 8/20/2015 11. Turn well over to production. Attachments: 1. As-built Schematic 2. Coil BOPE Schematic 14Milne Point Unit Well: MPU S-34L1 SCHEMATIC Last Completed: 9/2/2003 PTD: 203-132 Hilcorp Alaska,LLC CASING DETAIL Size Type Wt/Grade/Conn ID Top Btm Orig.DF Elev=72'/Origlbg.Hgr Elev.=29.7'Doyon 14 20" Conductor 215/A-53/Welded 17.938 Surf 112' 10-3/4" Surface 45.5/L-80/Btrc. 9.950 Surf 5,518' 7-5/8" Intermediate 29.7/L-80/IBT-M 6.875 Surface 11,159' 20' L LINER DETAIL 4-1/2" NE Solid Liner 12.6/L-80/IBT 3.958 10,127' 4-1/2" NE Slotted Lnr 12.6/L-80/IBT 3.958 10,224' 13,091' 1 4-1/2" OA Solid Liner 12.6/L-80/IBT 3.958 10,273' 4-1/2" OA Slotted Lnr 12.6/L-80/IBT 3.958 10,504' 13,232' TUBING DETAIL 4-1/2" Tubing 12.6/L-80/IBT 3.958 Surf 10,040' 3-1/2" Tubing 9.2/L-80/TC-II 2.992 Surf 10-3/4" A 6 JEWELRY DETAIL No Depth Item 1 2,101' CAMCO 4.5"x 1"w/BK Latch Side-pocket KGB-2 GLM 2 9,923' Phoenix Discharge Gauge:ID=3.850" 3 9,934' 4.5"HES"XD"Dura Sliding Sleeve:ID=3.813"(opens Down) 4 9,957' Phoenix Jet Pump Gauge Sensor:ID=2.840"(4,068"ND) 5 9,962' 4.5"x 3.5"X-Over 6 9,973' 3.5"HES X-Nipple:ID=2.813" 7 9,983' 3.5"x 4.5"X-Over 8 9,984' 7-5/8"x 4.5"Baker Premier Packer:ID=3.875" 9 9,991' 4.5"x 3.5"X-Over 10 10,034' 3.5"HES XN-Nipple:ID=2.750"No Go 11 10,039' WLEG—Bottom @ 10,040' 12 10,137' Baker 6'Tie-back Sleeve 13 10,146' Hook Wall Hanger Inside 7-5/8"Casing 14 10,171' Hook Wall Hanger Outside(Hook Point) 15 10,273' Baker 7'Tie-back Sleeve 16 10,280' Baker ZXP Liner Top Packer 17 10,286' Baker 7-5/8"x 5-1/2"HMC Liner Hanger 1 NE LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,159'to 10,171'(MD)/4,115'to 4,117'(TVD) Ii 2 Well Angle @ window=78 Deg. ® 3 OA LATERAL WINDOW DETAIL Window in 7-5/8"Casing @ 10,516'to 10,528'(MD)/4,199'to 4,201'(TVD) Well Angle @ window=77 Deg. 5 WELL INCLINATION DETAIL 6 KOP@280'MD Hole Angle Passes 50 Deg.@ 2,150' 9 Max Angle in Tubing=78 Deg. 75 Deg.at sliding sleeve 10 OPEN HOLE/CEMENT DETAIL 20" 260 sx of Arcticset in 42"Hole 11 10-4/4" 935 sx PF'L',371 sx Class"G",Top Job 54sx PF'L' in 13-1/2"Hole 7" 725 sx Class"G"in 9-7/8"Hole TREE/WELLHEAD 12 69jts-4-1/2"Slotted Liner Tree 4-1/6"5M FMC 10,224'to 13,047 13 11"x 4-1/2"SM Gen 6 w 4.5"TC-IIT&B Tubing / Wellhead 14 / J Hanger CIW"H"BPV profile .,l\E.Lateral L.,-:i. 363'Rat Hole GENERAL WELL INFO 15;w s,, 16 API:50-029-23171-60 . 17 Drilled and Cased by Doyon 14 -9/2/2003 0'Rat Hole "OA'Lateral 7-5/8`4 l It\61jts-4-1/2"Slotted Liner TD=13,234'(MD)/TD=4,234'(TVD) 10,504'to 13,147' Revised By:STP 8/20/2015 .. Milne Point Unit II COIL BOPE MPU S-34L1 08/20/2015 MPU S-34L1 20 X10''% X7%X4% Coil Tubing BOP Lubricator to injection head e 0 I E 1.75"Tandem Stripper 1•',I, Blind/Shear-55=71' 1/1610 Blind/Shear ■�,'•'_ mim mom. MEM- 111)11111Bhnd/Shear = • Blind/Shearl,l,'I - - c * €_ —_ Slip =�.',I C C Pipe �IIMICIEMud Cross )•'i �� •I,'•1 4 1/16 10M X 4 1/16 10M Outlet al iii w/2-2 1/16 10M full opening FMC valves : :/I: u. II •._ Q �[ 0 ill -. ,: . .r ... . - Manual Manual Manual Manual 2 1/16 10M 2 1/16 10M H . ' ' 2 1/16 10M 2 1/16 10M Crossover spool 4 1/16 10M X 4 1/16 5M Valve,Swab,WKM-M, �Or 4: �.r��5 F� 4 1/16 5M FE -G—..111; e. 6 sxa N'1, 1 imidi . . 4411 / 1 ' Valve, Upper Master,Baker, O • 4 1/16 5M FE,w/Hydraulic I I 111111111111. Valve,Lower Master,WKM-M, ij1 �J 4 1/16 5M FE 1Z,.�'1 uTun Tubing Adapter,4 1/16 5M iii 7 Image .oject Well History File c!er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~D3_ - L3~ Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 11111111I111111I111 RESCAN DIGJAL DATA \P'Óiskettes, No. d- O Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: Scanning Preparation BY: C MariV I Date ~ /3/05 Date Ia- /3/ OS x 301- c-=3p + Date: 'dJ 13/ DS 151 VV1P 1111111111111111111 mP BY: r~ Project Proofing BY: -~ 151 ~7 = TOTAL PAGES ...z::;~ (Count does not include cover she.in 151 r 111\\111I11111 "III Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ¡/ YES Date ¡ {}- / e/ ()õ If NO in stage 1, page(s) discrepancies were found: BY: ~ - 151 N~p Stage 1 YES NO BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 11111111111111 "III BY: Maria Date: 151 Comments about this file: Quality Checked 11111111111I1111111 1 0/6/2005 Well History File Cover Page.doc • • ~:~ =~: -- _~" " ,5, _ . _ __ -~: ~.. _,-.- MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THlS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc ) ) WELL LOG TRANSMITTAL :)()rJ'~ )~g- /) ():5# , 1\ 4-·· February 16, 2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 '135ß~ -~ßS 13_J j RE: MWD Formation Evaluation Logs MPS-34L 1 + L2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob K~alish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AI( 99518 907-273-3500 M"PS-34 Ll + L2: LAS Data & Digital Log Images: 50-029-23171-60, 61 Znn¡,;, ".' '''') Ifi· fl)j LJ 1..\ W ~CANNED MJ\h u 0/1 1 CD Rom lOX- DATA SUBMITTAL COMPLIANCE REPORT 12/5/2005 Permit to Drill 2031320 Well Name/No. MILNE PT UNIT SB S-34L 1 Operator BP EXPLORATION (ALASKA) INC s¡z~J..... ~~~~ API No. 50-029-23171-60-00 MD 13232""'-- TVD 4234"- Completion Date 9/1/2003 /' REQUIRED INFORMATION Mud Log No Completion Status 1-01L Current Status 1-01L UIC N Samples No Directional su~ DATA INFORMATION Types Electric or Other Logs Run: GRYO, MWD, GR, PWD, ABI/IFR/CASANDRA, RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~ ,?'ËD ED ~t Rpt LIS Verification 12186 Rate of Penetration 12186 Induction/Resistivity Directional Survey Directional Survey D ..IS D '" r. Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? Y / N l' Analysis Y / N Received? Comments: Compliance Reviewed By: .Jl-o (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OHI . Scale Media No Start Stop CH Received Comments ð~ 69 13184 ~ 10/27/2003 ~ 69 13184 10/27/2003 ROP, GR, EWR4 ëf!:"'" 69 13184 se 1 0/2712003 ROP, GR, EWR4 10440 13232 9/24/2003 10440 13232 9/24/2003 MWD Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ®N ÕIN . Formation Tops Date: }~)-- . STATE OF ALASKA _ ALASKA AND GAS CONSERVATION COM~ON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 1m Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: GYRO, MWD , GR , PWD , ABI/IFR I CASANDRA , RES CASING, LINER AND CEMENTING RECORD SEtTINGiÐePTH BOTTOM 110' 5518' o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3252' NSL, 412' WEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 2261' NSL, 2589' WEL, SEC. 02, T12N, R10E, UM Total Depth: 4466' NSL, 1100' WEL, SEC. 02, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565599 y- 5999917 Zone- ASP4 TPI: x- 558105 y- 6004145 Zone- ASP4 Total Depth: x- 559574 y- 6006361 Zone- ASP4 18. Directional Survey 1m Yes 0 No 22. CASING SIZE 20" 94# 45.5# H-40 L-80 35' 34' 10-3/4" 7-5/8" 4-1/2" 29.7# 12.6# L-80 L-80 32' 10273' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Liner MD TVD MD TVD 10504' - 13147' 4196' - 4228' 26. Date First Production: October 10, 2003 Date of Test Hours Tested PRODUCTION FOR 10/9/2003 6 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ....1rrr.. Press. 24-HoUR RATE""" 260 sx Arctic Set (Approx.) 935 sx PF 'L', 371 sx Class 'G' Top Job ( 54 sx PF 'L') 725 sx Class 'G' Uncemented Slotted Liner One Other 5. Date Comp., Susp., or Aband. 8/26/2003 6. Date Spudded 8-22-2003 7. Date T.D. Reached 8-25-2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 72.30' 9. Plug Back Depth (MD+ TVD) 13232 + 4234 Ft 10. Total Depth (MD+TVD) 13232 + 4234 Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 42" 13-1/2" 10516' 13232' 9-7/8" 6-1/8" Revised 10/30/03, Start Production 1 b. Well Class: 1m Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-132 13. API Number 50-029-23171-60-00 14. Well Number MPS-34L 1 15. Field and Pool Milne Point Unit I Schrader Bluff 16. Lease Designation and Serial No. ADL 380109 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) TUSING RECORD SIZE DEPTH SET (MD) 4-1/2"x 3-1/2", 12.6# x 9.2#. L-80 10040' 25. PACKER SET (MD) 9984' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 95 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump Oll-BBl GAs-McF WATER-BBl 1685 247 0 Oll-BBl GAs-McF WATER-BBl I GAS-Oil RATIO 146 Oil GRAVITY-API (CORR) CHOKE SIZE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separat,es~,if.neç~$Sary). Submit core chips; if none, state "none". . None ....BFL tI)Y 1~~ . Form 10-407 Revised 2/2003 OR! ~¡\'.£~. L ! " , ~ \i t CONTINUED ON REVERSE SIDE ~{-I 30 28. GEOLOGIC MARKERS NAME MD TVD Top of Ugnu Zone C SBF2-NA SBF21 SBF1-NB SBF1-NBR SBF12 SBE4-NC SBE41 SBE2-NE SBE1-NF TSBD-OA TSBC TSBC 7954' 9846' 9868' 9943' 9971' 10020' 10078' 10112' 10160' 10368' 10517' 10624' 10748' 3539' 4038' 4044' 4064' 4071' 4083' 4097' 4104' 4115' 4164' 4199' 4211' 4221' 29. .MATION TESTS Include and briefly s marize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". None ~ :l ~,' '~f 30. List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Test Summary Report. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondra S~ Title Technical Assistant MPS-34L 1 Well Number 203-132 Permit No. I Approval No. Date lO'- ~O- ~ 0 Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Steve Campbell, 564-4401 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 2/2003 or:; f~AL . . fJ03-/3~ WELL LOG TRANSMI'ITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 13, 2003 RE: MWD Fonnation Evaluation Logs MPS-34 L1, AK-MW-2600988 1 LIS fonnatted Disc with verification listing. API#: 50-029-23171-60 , 8- \ ö lp PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL 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: - ~, \5, "", . "~~-"-""') r-" '" '''\, \' SIgned: \~~ ~-,y"\~~",<, "~~~~n\~ _ STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: GYRO, MWD , GR , PWD , ABI/IFR I CASANDRA , RES CASING, LINER AND CEMENTING RECORD SmINî3.¡)eI?Tt'I HOLE I OF' BOTTOM SIZE 35' 110' 42" 34' 5518' 13-1/2" o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3252' NSL, 412' WEL, SEC. 12, T12N, R10E, UM Top of Productive Horizon: 2261' NSL, 2589' WEL, SEC. 02, T12N, R10E, UM Total Depth: 4466' NSL, 1100' WEL, SEC. 02, T12N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 565599 y- 5999917 Zone- ASP4 TPI: x- 558105 y- 6004145 Zone- ASP4 Total Depth: x- 559574 y- 6006361· Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. 20" 10-3/4" 94# 45.5# H-40 L-80 7-5/8" 4-1/2" 29.7# 12.6# L-80 L-80 32' 10273' 23. Perforations oRen to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" Slotted Liner MD TVD MD 10504' - 13147' 4196' - 4228' RECORD 260 sx Arctic Set (Approx.) 935 sx PF 'L', 371 sx Class 'G' Top Job ( 54 sx PF 'L') 725 sx Class 'G' Uncemented Slotted Liner One Other 5. Date Comp:.: .~~~ or Aband. ~Lu03 . q. i.c)..:? A~ 6. Date Spudded ( 8-22-2003 7. Date T.D. Reached 8-25-2003 8. Elevation in feet (indicate KB, DF, etc.) KBE = 72.30' 9. Plug Back Depth (MD+ TVD) 13232 + 4234 Ft 10. Total Depth (MD+ TVD) 13232· + 4234 Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 10516' 13232' 9-7/8" 6-1/8" SIZE 4-1/2"x 3-1/2", 12.6# x 9.2#, L-80 TVD 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-132 13. API Number 50-029-23171-60-00 14. Well Number M PS-34L 1 15. Field and Pool Milne Point Unit I Schrader Bluff 16. Lease Designation and Serial No. ADL 380109 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) DEPTH SET (MD) 10040' PACKER SET (MD) 9984' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 95 Bbls of Diesel. PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-Bsl GAs-McF WATER-Bsl 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". Oll-Bsl None (',n'",.,.,_,_. o L;~~,;t 0 -:.I..·cLc4':::L Form 10-407 Revised 2/2003 GAs-McF W A TER-Bsl ORtG1NAL CONTINUED ON REVERSE SIDE RBDMS CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) -,."'" o OCT 2 U 2.0U3 I.P p NAME MD TVD 129. _RMATION TESTS Include and brieflysúmmarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None", 28. GEOLOGIC MARKER! Top of Ugnu Zone C SBF2-NA SBF21 SBF1-NB SBF1-NBR S8F12 SBE4-NC SBE41 SBE2-NE SBE1-NF TSBD-OA TSBC TSBC 7954' 9846' 9868' 9943' 9971' 10020' 10078' 10112' 10160' 10368' 10517' 10624' 10748' 3539' 4038' 4044' 4064' 4071' 4083' 4097' 4104' 4115' 4164' 4199' 4211' 4221' None 30. List of Attachments: Summary of Daily Drilling Reports, Surveys and a Leak-Off Test Summary Report. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed sondra~ Title Technical Assistant Date lO-OB~o~ MPS-34L 1 203-132 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Steve Campbell, 564-4401 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". ORIGINAL Form 10-407 Revised 2/2003 ~. . BP EXPLORATION Operations Summary Report Page 1 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Date Frorn- To Code NPT Phase Description of Operations 8/11/2003 00:00 - 00:30 0.50 MOB P PRE Skid rig floor from drlg position to move position 00:30 - 02:30 2.00 MOB P PRE Move rig from MPS-02i to MPS-34 02:30 - 03:00 0.50 MOB P PRE Skid rig floor from move position to drlg position 03:00 - 03:30 0.50 MOB P PRE Rig up floor 03:30 - 05:30 2.00 MOB P PRE Accept rig @ 03:30 Hrs 8/11/2003 - Nipple up divertor 05:30 - 12:00 6.50 DRILL P SURF Load pipe shed with 4" dp - Pick up 195 Jts of 4" dp - Stand back in derrick 12:00 - 13:30 1.50 DRILL P SURF Pick up flex dc's - 5" hwdp - stand back in derrick 13:30 - 14:00 0.50 DRILL P SURF Pick up short bha up beaver slide 14:00 -15:00 1.00 DRILL P SURF Make up bit I motorl mwd - orient same - can't make up bha 15:00 - 15:30 0.50 DRILL P SURF Function test divertor - Accumulator test - Witness of test waived by Chuck Scheve with AOGCC - Hang sheeve and line for Gyro in derrick 15:30 - 16:00 0.50 DRILL P SURF Conduct pre spud meeting with all personnel - Fill stack with mud - check for surface leaks - 16:00 - 00:00 8.00 DRILL P SURF Spud in well S-34 - Directional drill from 112' to 930' - WOB 35K to 40K - RPM 80 - TQ on 5K - off 1K - GPM 423 - PP on 1400 - off 1120 - PU 93K - SO 93K - ROT 93K - Rigged down Gyro survey equipment (two gyro surveys ran) 8/12/2003 00:00 - 14:30 14.50 DRILL P SURF Directional Drill from 930' to 3018' - WOB 40K - GPM 502 - PP 2650 - off 2300 - RPM 80 - TO on 10 k - off 5 k - PU 1 02K - SO 77K - ROT 95K 14:30 - 16:30 2.00 DRILL P SURF CBU 3X - GPM 502 - PP 2300 - RPM 80 - TO 5K - PU 105K- SO 78K - ROT 95K - Circ from 3018' to 2928' - 30 mins - stand back one stand - Circ from 2928' to 2832' - 30 mins - stand back one stand - Circ from 2832 to 2736' to bottoms up - 16:30 -18:30 2.00 DRILL P SURF Pump out from 2736' to 815' to HWDP - no problems - hole in good shape 18:30 - 19:30 1.00 DRILL P SURF RIH from 815' to 1550' bridge - work through bridge to 1580'- RIH to 1600' bridge - work through bridge to 1638' - Con't RIH to 2826' hit bridge 19:30 - 22:00 2.50 DRILL N DPRB SURF Attempt to work through bridge @ 2826' - Pump at 1/2 drlg rate GPM 250 - Attempt to wash through bridge - Pump at full rate - Orient to high side 10L - Re-drill from 2826' to 3018' 22:00 - 00:00 2.00 DRILL P SURF Directional drill from 3018' to 3306' - WOB 40K - RPM 80 - TQ on 10K - off 6K - GPM 503 - PP on 2700 - off 2400 - PU 103K - SO -75K - ROT 91K 8/1312003 00:00 - 15:00 15.00 DRILL P SURF Directional Drill from 3311' to 5526' - WOB 45K - GPM 503 - PP on 3750 - off 3280K - RPM 80 - TQ on 15K - off 7K - PU 125K - SO 70K - Rot 95K 15:00 - 19:00 4.00 CASE P SURF CBU 3 X - RPM 100 - TQ 7K - GPM 503 - PP 3200 - PU 125K- SO 70K - ROT 95K 19:00 - 23:00 4.00 CASE P SURF Pump out from. 5526' to 817' - Pump out drlg rate - 445 gpm - tight spot @ 5035' 23:00 - 00:00 1.00 CASE P SURF RIH from 815' to 3800' - Tight 1536' 8/1412003 00:00 - 01 :00 1.00 CASE P SURF RIH - from 3800' to 5526' - Wash last stand to bottom 01:00 - 04:00 3.00 CASE P SURF CBU 3 X - GPM 503 - PP 3300 - RPM 100 - TQ 7K - PU 125 - SO 65K - ROT 94K 04:00 - 07:30 3.50 CASE P SURF Pump out from 5526' to 815' HWT -1st ten stands pumped at 5 bpm laying lubricate pill across bottom 900 feet - (from 5526' to 4626') - Pump out at drlg rate 445 GPM 07:30 - 09:30 2.00 CASE P SURF Rack back 5" HWT - Stand back 6.75" Flex dc's - Lay down 8" bha Printed: 912/2003 9:55:32 AM -" - '-. BP EXPLORATION Operations Summary Report Page 2 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Date From-To Hours Task Code NPT Phase DescriptioflofOperations 8/14/2003 09:30 - 10:30 UO CASE P SURF Rig up to run 103/4" - PJSM 10:30 -16:00 5.50 CASE P SURF Run 133 joints 10 3/4" 145.5# I L-80 I BTC casing - Set down at 1800' - Work pipe down without circulating - Con't run pipe minor problems to 2800' - No problems in tangent section - Land pipe with 30K pipe weight left 16:00 - 16:30 0.50 CASE P SURF Rig down Franks fill up tool - Rig up Howco Cementing head - Break circulation 16:30 - 20:00 3.50 CASE P SURF Circulate I Condition mud for cement job - Start @ 2.8 bpm 440 psi - staging up to 10 bpm 420 psi 20:00 - 22:30 2.50 CEMT P SURF Howco pump 10 bbls water - Test lines to 3500 psi - Pump 10 bbls water - Pump 75 bbls Alpha spacer - mixed at 10.2 ppg - (one gallon dye first 5 bbls spacer pumped) - Drop bottom plug on fly of last 5 bbls spacer pumped - Mix and pump 935 sxs 691 bbls Type "L" Yeild 4.15 cf/sx -mixed @ 10.7 ppg - 7 bpm- Mix and pump 375 sxs 76 bbls Class "G" with 2 % Cacll Yeild 1.15 cf/sx - mixed @ 15.8 ppg - 5 bpm 500 psi - Drop top plug - Kick out with Howco 30 bbls water 5 bpm 650 psi - Displace with Rig - 5 bpm 900 psi - Lost returns 210 bbls pumped - Regain retruns 230 bbls pumped 8/15/2003 00:00 - 01 :00 1.00 CEMT P SURF Con't displacing cement with rig @ 4 bpm 1120 psi - Lost retruns total returns after displacing 290 bbls - Con't displacing 4 bpm @ 1500 psi - Total displacement 522 bbls - Bump plug with 2500 psi - 1000 over - Held pressure for 5 mins - Bled off pressure - floats holding - No Cement to surface - (Did see spacer with dye back) 01 :00 - 02:00 1.00 CASE P SURF Flush Divertor - Flowline - Break and lay down Howco cementing head - Lay down casing tools - lay down landing joint 02:00 - 03:00 1.00 CASE P SURF Nipple down divertor 03:00 - 03:30 0.50 CASE N CEMT SURF Prepare for top job - Install hoses I lines in cellar for Super sucker I vac truck - 1" pipe in pipe shed - Pick up handling tools for 1" pipe- 03:30 - 05:00 1.50 CASE P SURF Change out saver sub on top drive - Top drive service 05:00 - 07:00 2.00 CEMT N CEMT SURF RIH with 1" CS hydril! tubing - Tag up hard at 134' RKB measurements - Pump 50 bbls fresh water to flush conductor pipe - Followed by 54 sxs of Type "L" - Yield 4.15 cf/sx - 224 cf - 40 bbls slurry mixed at 10.5 ppg - 10 bbls of 10.5 ppg cement to surface - Left in hole 30 bbls of slurry - 40 sxs 07:00 - 08:00 1.00 CASE P SURF Nipple up 12" FMC Casg head - metal to metal seal- 11" x 11" 5M G5 tubing head - Test to 1000 psi for 10 mins 08:00 - 09:30 1.50 CASE P SURF Nipple up BOP's 09:30 - 10:00 0.50 CASE P SURF Install test plug - Rig up testing equipment 10:00 -13:00 3.00 CASE P SURF Test BOP's - 250 low 2500 high Annular each test 5 mins - 250 low 3500 high - Top pipe rams - Bottom rams - Blind rams- Choke manifold - Hyd Kill I Choke valves - Manual Kil!l Choke valves - Upper I Lower IBOP - Floor safety valve - Floor dart valves - Each test 5 mins - John Crisp with AOGCC waived witness of BOP test 13:00 - 13:30 0.50 CASE P SURF Pull test plug - Install wear ring - Close annulus valves - Rig down test equipment 13:30 - 14:00 0.50 CASE SURF Pick up short bha up beaver slide 14:00 - 15:30 1.50 CASE P SURF Pick up motor 1.22 degree - make up bit - MWD I GR I RES I PWD - orient same - Con't make up BHA Printed: 91212003 9:55:32 AM . . BP EXPLORATION Operations Summary Report Page 3 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Date FrolTf-To Code NPT Phase Descriptionôf Operations 8/15/2003 15:30 - 16:00 0.50 CASE P SURF RIH HWT - Surface test MWD @ 726' - 400 gpm 1150 psi 16:00 - 17:30 1.50 CASE P SURF RIH from 726' to 5332' 17:30 - 18:30 1.00 CASE P SURF Break circulation - Test 103/4" casing to 2500 psi for 30 mins- Record on chart 18:30 - 19:30 1.00 CASE P SURF Cut drilling line 19:30 - 20:30 1.00 DRILL P SURF Drill Flequipment - cement - 20" new hole from 5526' to 5546' 20:30 - 22:00 1.50 CASE P SURF Circulate conditioning mud for FIT - GPM 400 - PP 2100 psi- 50 RPM - TQ 7K 22:00 - 22:30 0.50 CASE P SURF Perform FIT - Hole T.D. 5546 MD - Shoe 5518' MD - 2894' TVD - Mud weight 8.9 ppg - Surface pressure 400 = 11.56 ppg EMW - Recorded on chart 22:30 - 00:00 1.50 DRILL P INT1 Spot new mud at bit - Drill from 5546' to 5750' - WOB 30K - RPM 120 - TQ on 11K - off7K - GPM 400 - PP on 1920' - off 1820' - PU 145K - SO 70K - ROT 98K 8/16/2003 00:00 - 23:00 23.00 DRILL P INT1 Directional Drill from 5750' to 8846' - WOB 30K - RPM 120- TQ on 9K - off 7K - GPM 423 - PP on 2980 - off 22790 - PU 133K - SO 82K - ROT 106K 23:00 - 00:00 1.00 DRILL P INT1 CBU 3 X - GPM 440 - PP 2700 - RPM 120 - TQ 7.5K - PU 133 - SO 82 - ROT 105 8/17/2003 00:00 - 02:30 2.50 DRILL P INT1 Con't CBU 3 X - GPM 45 - PP 2600 - RPM 120 - TQ 8K - PU 134K - SO 83K - ROT 107K 02:30 - 05:30 3.00 DRILL P INT1 Pump out from 8846' to 5427' - @ Drlilling rate 430 gpm - Tight spot 7250' - 7205 to 7070' ratty - 6568 to 6530 ratty 05:30 - 08:00 2.50 DRILL P INT1 Monitor well - Well static - Pump dry job - POH from 5427' to BHA @ 726' 08:00 - 09:00 1.00 DRILL P INT1 Download - Upload MWD 09:00 - 10:00 1.00 DRILL P INT1 Break off bit - reset motor from 1.22 to 1.5 - Make up new bit - Orient MWD - RIH with 6.5" flex dc's - 5" HWT 10:00 - 12:00 2.00 DRILL P INT1 RIH from 726' to 5550' - Test MWD with bit and motor out shoe 12:00 -13:00 1.00 DRILL P INT1 Con't RIH from 5550' to 8846' - Hole in good shape - No tight spots 13:00 - 00:00 11.00 DRILL P INT1 Directional Drill from 8846' to 9960' - WOB 40K - RPM 80 - TQ on 12K - off 9K - GPM 423 - PP on 3320 - off 3150 - PU 150K- SO 80K - ROT 113K - Add two drums E-P Mud lube to slick up casing - Added 3% Lubricants with IDLube and Lubetex 8/18/2003 00:00 - 14:30 14.50 DRILL P INT1 Directional Drill from 9960' to 11159' - T.D. 97/8" hole - WOB 40K - RPM 80 - TQ on 10K - off 9K - GPM 423 - PP on 3830- off 3510 - PU 150K - SO 83K - ROT 114K 14:30 - 17:30 3.00 CASE P INT1 CBU 2 X - (20000 strokes) - GPM 423 - PP 3700 - RPM 100- TQ 8K - PU 150K - SO 83K - ROT 115K 17:30 - 20:30 3.00 CASE P INT1 Pump out from 11159' to 8000' - Pump at drilling rate 423 gpm - Hole in good shape - No problems 20:30 - 21 :30 1.00 CASE P INT1 RIH frrom 8000' to 11159' - No problems - Hole in good shape 21 :30 - 00:00 2.50 CASE P INT1 CBU 3 X - (30000 strokes) - GPM 423 - PP 3770 - RPM 100- TQ 8K - PU 150K - SO 83K - ROT 114K 8/1912003 00:00 - 02:30 2.50 CASE P INT1 Con't CBU 3 X - GPM 423 - PP 3680 - RPM 100 - TQ 9K - PU 150K - SO 83K - ROT 115K - Lots of thick mud back on bottoms up 10,000 strokes - 12,000 strokes - 16,500 strokes 02:30 - 04:30 2.00 CASE P INT1 Pump out from 11159' to 8782' - Pump at dr1g rate 423 gpm - 3380psi 04:30 - 05:00 0.50 CASE P INT1 Pull out 8782' to 8302', well not taking proper fill 05:00 - 06:00 1.00 CASE P INT1 Pump out from 8302' to 7630' - Pump at drlg rate 423 gpm 06:00 - 07:00 1.00 CASE P INT1 Pull out 7630' to 5427' Monitor well, hole static Printed: 91212003 9:55:32 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . . BP EXPLORATION Operations Summary Report 40f8 MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations 8/19/2003 07:00 - 08:00 1.00 CASE P INT1 Slip and cut drilling line 08:00 - 10:00 2.00 CASE P INT1 Trip in hole, ream from 11088'/11159' 10:00 - 15:00 5.00 CASE P INT1 Circ. three bottoms up, with 449 gpm. 3700 psi, 100 rpms, 8k torque, P/U 150k SIO 87k, RTW 116k 15:00 - 20:00 5.00 CASE P INT1 Flow check, pull out of hole to BHA, No problems, getting PIU and SIO wt. every 10 sds 20:00 - 22:30 2.50 CASE P INT1 Laying down BHA, clear floor 22:30 - 00:00 1.50 CASE P INT1 Change top rams to 7 5/8, remove saver sub from top drive to install TESCO CDA tool 8/20/2003 00:00 - 04:00 4.00 CASE P INT1 Installing TESCO CDA tool, as per Tesco tech. install extension sub on top drive, fit anti-rotation device, re-install torque rings on top drive, and Dan Glacken fell backwards off ladder from bottom step and landed on his back, send to medic to be checked 04:00 - 05:00 1.00 CASE N HMAN INT1 Safety stand down, meeting with all hands on regarding fall from ladder 05:00 - 06:00 1.00 CASE P INT1 Installing CDA tools 06:00 - 06:30 0.50 CASE P INT1 Test BOP door seals to 1500 psi, rig down test Eqp. and clear floor 06:30 - 09:00 2.50 CASE N HMAN INT1 Shut down for Accident investigation 09:00 - 14:30 5.50 CASE P INT1 PJSM with Tesco Techs on running csg, Picking up 7 5/8 29.7# L-80 csg. getting pick up and slack offwt.s every 20 jts to 3390', bend one grapple on CDA tool 14:30 - 15:00 0.50 CASE N SFAL INT1 Replace bend grapple 15:00 - 17:30 2.50 CASE P INT1 Picking up 7 5/8 29.7# L-80 csg, getting pick up and slack off wt.s every 20 jts to 5518' 17:30 - 19:00 1.50 CASE P INT1 Circ one full circulation @ shoe with 60 spm 400 psi 19:00 - 00:00 5.00 CASE P INT1 Picking up 7 5/8 29.7# L-80 csg getting pick up and slack off wt.S every 20 jts, to 9800' 8/21/2003 00:00 - 02:00 2.00 CASE P INT1 Finish Picking up 7 5/8 29.7# L-80 csg getting pick up and slack off wt.S every 20 jts, to 11159', total of 274 jts.11170 ft, set @ 11,159, float @ 11,075, PIU 250K, S/O 90K wash last jt to bottom no fill, no hole problems running csg, CDA tool worked good, Csg was not rotate with CDA tool. 02:00 - 03:30 1.50 CASE P INT1 Circ. stage up to 6 bbls min. 500 psi full returns, circ one csg volume 5,120 strokes. Didn't Reciprocate csg 03:30 - 04:00 0.50 CASE P INT1 Rig up cement head 04:00 - 05:30 1.50 CASE P INT1 Circ. 6 bbls min. 500 psi full returns, CÎrc one csg volume 5,120 strokes. Didn't Reciprocate csg 05:30 - 07:30 2.00 CEMT P INT1 Cement with Halliburton with 5 bbls water, test lings 3500 psi, 15 bbls water, 35 bbls Alpha spacer mixed @ 10.5, drop bottom plug,725 sxs. Class G 156 bbls mixed @ 15.6, drop top plug, displace with Halliburton with 9.5 Flo-Pro mud, @ 8 bbls min, pumped 509 bbls bump plug with 1600 psi, full return tru out job, floats held 07:30 - 08:00 0.50 CEMT P INT1 Rig down cement head 08:00 - 10:30 2.50 CEMT P INT1 Change rams to 2 7/8 X 5", nipple down flow lines, pick up BOPS 10:30 - 11 :00 0.50 CEMT P INT1 Set Emergency slips with 150k on slips 11:00 - 12:00 1.00 CEMT P INT1 Make rough cut and final cut as per FMC teet. 12:00 - 14:00 2.00 CEMT P INT1 Nipple up BOPS, rig down Tesco CDA Equip. 14:00 -15:30 1.50 CEMT P INT1 Install new saver sub, bails and 5" elevators on top drive 15:30 -16:30 1.00 CEMT P INT1 Install 10 3/4 x 7 5/8 packoff and test same to 3350 psi for 10 Printed: 91212003 9:55:32/Wo - - " BP EXPLORATION Operations Summary Report Page 5 of 8 Legal Well Name: MPS-34 Common Well Name: MPS-34 Spud Date: 8/11/2003 Event Name: ORIG DRILLING Start: 8/10/2003 End: Contractor Name: DOYON DRILLING INC. Rig Release: Rig Name: DOYON 14 Rig Number: Date From~·To Code NPT Description ôfOperatiol1s 8/21/2003 15:30 - 16:30 1.00 CEMT P INT1 min. 16:30 - 21 :00 4.50 CASE P INT1 Rip up test BOPS and Manifold 250 psi low. 3500 psi high for 5 min. per test, Hydril250 low, 2500 high, 5 min. per test., Install wear ring, The right to witness test was wavier by Jeff Jones AOGCC 21 :00 - 22:00 1.00 CASE P INT1 Test csg to 3500 psi for 30 min. 22:00 - 00:00 2.00 CASE P INT1 Picking up 12-4 3/4 Dc and 16 jts 3.5 HWP pump tru to insure they are free of rust, stand back in derrick 8/22/2003 00:00 - 02:00 2.00 STWHIP P PROD1 Picking up 17 jts and cut jt. of 3.5 tubing for space out of whipstock 02:00 - 05:00 3.00 STWHIP P PROD1 Pick up Trip anchor, whipstock, mills and MWD, orient same, finish picking up BHA # 4 05:00 - 11 :30 6.50 STWHIP P PROD1 Tripping in with whipstock 11 :30 - 12:00 0.50 STWHIP P PROD1 Orient to 20 degrees to right of high side, set trip anchor, shear whipstock 12:00 - 16:30 4.50 STWHIP P PROD1 Mill window 10,516 to 10,528' Drill to 10,540', top O-A sand 10515' 16:30 - 18:00 1.50 STWHIP P PROD1 Circ and work window, pump sweep 340 gals min 2650 psi 18:00 - 18:30 0.50 STWHIP P PROD1 FiTtest with 9.5 MW 340 psi 4198 TVD= 11.0 EMW 18:30 - 21 :00 2.50 STWHIP P PROD1 Slug pipe, pull out to BHA 21 :00 - 22:00 1.00 STWHIP P PROD1 Stand back BHA,Lay down MWD and mills 22:00 - 23:00 1.00 STWHIP P PROD1 Pick up stack washer and flush out BOPS, Function all rams 23:00 - 00:00 1.00 STWHIP P PROD1 Picking up 90 jts 4" drill pipe 8/23/2003 00:00 - 02:00 2.00 STWHIP P PROD1 Finish picking up 90 jts 4" pipe, Circ. tru pipe to clear out rust 02:00 - 03:00 1.00 STWHIP P PROD1 Stand 30 stands in derrick 03:00 - 05:00 2.00 STWHIP P PROD1 Clear floor, PIU BHA #5 05:00 - 06:30 1.50 STWHIP P PROD1 Tripping in hole To 5,957, Iron roughneck broke 06:30 - 07:00 0.50 STWHIP N RREP PROD1 Rig up spinner hawk, PJSM 07:00 - 08:30 1.50 STWHIP P PROD1 Tripping in to 10,369 08:30 - 09:30 1.00 STWHIP P PROD1 Slip and cut drilling line 09:30 - 10:00 0.50 STWHIP P PROD1 Trip in to 10465, Orient to high side, slide tru window 10:00 - 00:00 14.00 DRILL P PROD1 Directional drill from 10540 to 11,392 with 80 rpms, 250 gals min. 2450 psi 8/24/2003 00:00 - 00:00 24.00 DRILL P PROD1 Directional drill from 11,392 to 13,030 with 80 rpms, 250 gals min. 2550 psi, having lots of trouble sliding, Motor acting weak stalls to easy, ABI working part time, Lube up to 4%, AST 6.09, ART 10.25, TQ 6500 8/25/2003 00:00 - 04:30 4.50 DRILL P PROD1 Directional drill from 13,030' to 13,232' TO with 80 rpms, 250 gals min. 2550 psi, (went out of O-A 13,160) 04:30 - 08:00 3.50 CASE P LNR1 Circ, three bottoms up with 100 rpms, 280 gals min 2800 psi 08:00 - 10:30 2.50 P LNR1 Pump out to Csg shoe, pump to 10561, pull tru window @ 10516 with out pumping, no problems pumping out 10:30 - 12:00 1.50 CASE P LNR1 Circ two bottoms up with 280 gals min 100 rpms 2450 psi 12:00 - 15:00 3.00 CASE P LNR1 Slug pipe, trip out to BHA 15:00 - 16:00 1.00 CASE P LNR1 Stand back jars and dc., lay down MWD, motor 16:00 - 16:30 0.50 CASE P LNR1 Rig up to pickup liner, PJSM 16:30 - 18:30 2.00 CASE P LNR1 Picking up 4.512.6# L-80 slotted liner, total 61 jts slotted, 10 jts 4.512.6# L-80 solid liner 2931', Baker 7518 X 5.5 HMC liner hanger, Baker 7 5/8 X 5.5 ZXP liner top packer. 18:30 - 22:00 3.50 CASE P LNR1 Tripping in with liner to 13232', no problems tripping in with liner, drop ball, pickup wt 145,000, SIO 80,000 22:00 - 23:30 1.50 CASE P LNR1 Pump ball to seat with 3 bbls min. 900 psi, set hanger with 2500 psi,set packer with 3300 psi, shear ball with 4,300 psi, Printed: 91212003 9:55:32 AM - . ". BPEXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Date From - To Hours Task Code NPT Phase Description of Operations -..-. ----.--- .-.- ._-----------.._-----"--- 8/25/2003 22:00 - 23:30 1.50 CASE P LNR1 test liner top packer with 1000 psi on back side,rotate off liner, pickup wt without liner 126,000, top of tie back sleeve 10274, packer @ 10280' 23:30 - 00:00 0.50 CASE P LNR1 Flow check, Tripping out with running tools 8/26/2003 00:00 - 03:00 3.00 CASE P LNR1 Tripping out with running tools 03:00 - 03:30 0.50 CASE P LNR1 Lay down running tools 03:30 - 04:00 0.50 STWHIP P PROD2 Clear floor, PJSM 04:00 - 06:30 2.50 STWHIP P PROD2 Pickup 3.5 spacer jts, Baker whipstock and mills,MWD 06:30 - 10:30 4.00 STWHIP P PROD2 Tripping in with whipstock to 10245' 10:30-11:00 0.50 STWHIP P PROD2 Orient 11 degrees to right of high side, set whipstock 11 :00 - 14:00 3.00 STWHIP P PROD2 Mill window, 10159' to 10171' drill to 10184' 14:00 - 15:30 1.50 STWHIP P PROD2 Circ. Two bottoms up, pumped sweep, worked window 15:30 - 18:00 2.50 STWHIP P PROD2 Flow check, POH to BHA 18:00 - 19:00 1.00 STWHIP P PROD2 Stand back DC, lay down MWD,and window mills 19:00 - 20:30 1.50 STWHIP P PROD2 Pickup Johnny Wacker, Flush BOPS stack, and function rams 20:30 - 00:00 3.50 BOPSURP PROD2 Pull wear ring, Test BOPS and manifold 250-3,500 psi 5 min. per test, Hydril 250-2,500 psi 5 min. per test, install wear ring. the right to witness test was wavier by Jeff Jones AOGCC. 8/27/2003 00:00 - 01 :30 1.50 DRILL P PROD2 PJSM,Clear floor, Pickup BHA # 7, surface test MWD 01 :30 - 04:30 3.00 DRILL P PROD2 Tripping in to 10,080' 04:30 - 05:30 1.00 DRILL P PROD2 Cut and slip Drilling lin~ 05:30 - 06:00 0.50 DRILL P PROD2 Orient, slide tru window without pumping, tag bottom 10184' 06:00 - 00:00 18.00 DRILL P PROD2 Directional Drill 10, 184' to 11953" with 80 rpms, 245 gpm, 3000 psi AST 4.58, ART 6 8/28/2003 00:00 - 16:30 16.50 DRILL P PROD2 Directional Drill 11953' to 13454'TD with 80 rpms, 245 gpm, 3450 psi 16:30 - 20:30 4.00 CASE P PROD2 Circ, four bottoms up with 280GPM, 3800 psi, 100 RPMs 20:30 - 23:30 3.00 CASE P PROD2 Pumping out to window @ 1 0159,with full drilling rate, pull tru window with out pumping 23:30 - 00:00 0.50 CASE P PROD2 Circ, two bottoms up with 280GPM, 2700 psi, 100 RPMs 8/29/2003 00:00 - 01 :30 1.50 CASE P PROD2 Circ, two bottoms up with 28OGPM, 2700 psi, 100 RPMs 01 :30 - 05:00 3.50 CASE P PROD2 Tripping out to BHA 05:00 - 06:00 1.00 CASE P PROD2 Laying down BHA 06:00 - 07:30 1.50 CASE P PROD2 Picking up BHA # 8 Whipstock Retrieving tool., surface test MWD 07:30 - 10:30 3.00 CASE P PROD2 Trip in to 10130' 10:30 - 11:00 0.50 CASE P PROD2 Orientate, engage whipstock,pull free 11:00 - 12:00 1.00 CASE P PROD2 Circ bottoms up, 250 gals min. 1800 psi 12:00 - 15:30 3.50 CASE P PROD2 Poh with whipstock 15:30 -18:00 2.50 CASE P PROD2 Lay down BHA, whipstock, and space out jts. 18:00 - 19:00 1.00 CASE P PROD2 Rig up to pickup liner,PJSM 19:00 - 21 :00 2.00 CASE P PROD2 Picking up Slotted liner 4.5 12.6# L-80 IBT total 71 jts 2906' and Baker Hook wall hanger, two centralizers per jt. on slotted jts 21 :00 - 23:30 2.50 CASE P PROD2 Tripping in with liner to 10150' 23:30 - 00:00 0.50 CASE P PROD2 Working trying to Exit window @ 10159' to 10171' 8/30/2003 00:00 - 01 :00 1.00 CASE P PROD2 Working trying to Exit window @ 10159' to 10171' setting down on lower liner @ 10273, got out window on the 8th try 01:00 - 02:30 1.50 CASE N DPRB PROD2 Working liner @ 10260' acts like the centralizer in the middle #3 jt is hanging on bottom of window. PIU wt 125,000 S/O wt 90,000 02:30 - 03:00 0.50 CASE N DPRB PROD2 Pulled above window and went back to lower liner top @ Printed: 91212003 9:55:32 AM . . BPEXPLORA TION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 Date From - To Hours Task Code NPTI Phase i 8/30/2003 02:30 - 03:00 0.50 CASE N DPRB PROD2 03:00 - 03:30 0.50 CASE N DPRB PROD2 03:30 - 06:30 3.00 CASE N DPRB PROD2 06:30 - 07:00 0.50 CASE N DPRB PROD2 07:00 - 11 :30 4.50 CASE N DPRB PROD2 11:30 - 12:00 0.50 CASE N DPRB PROD2 12:00 - 15:30 3.50 CASE N DPRB PROD2 15:30 - 18:00 2.50 CASE N DPRB PROD2 18:00 - 21 :30 3.50 CASE N DPRB PROD2 21 :30 - 23:30 2.00 CASE P PROD2 23:30 - 00:00 0.50 CASE P PROD2 8/31/2003 00:00 - 01 :00 1.00 CASE P PROD2 01 :00 - 05:00 4.00 CASE P PROD2 05:00 - 05:30 0.50 CASE P PROD2 05:30 - 08:30 3.00 CASE P PROD2 08:30 - 09:30 1.00 CASE P PROD2 09:30 - 12:00 2.50 CASE P PROD2 12:00 - 17:30 5.50 CASE P PROD2 17:30 - 19:00 1.50 CASE P PROD2 19:00 - 00:00 5.00 CASE P PROD2 9/1/2003 00:00 - 05:00 5.00 CASE P PROD2 05:00 - 06:30 1.50 CASE P PROD2 06:30 - 07:30 1.00 BOPSUR P PROD2 07:30 - 09:00 1.50 WHSUR P PROD2 09:00 - 09:30 0.50 WHSUR P PROD2 09:30 - 10:00 0.50 CASE P PROD2 10:00 - 10:30 0.50 CASE P PROD2 Page 7 of 8 Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Description of Operations 10273' Orient and went out window on 3rd try, to 10260' and liner still hanging up @ same spot. POH to liner hanger inspect liner hanger, stand back in derrick PJSM, lay down liner found two centralizers pushed up to collar onjt.#2 Service top drive Picking up Slotted liner 4.512.6# L-80 IBT total 71 jts 2906' and Baker Hook wall hanger, no centralizers on jt. 1 tru 3, one centralizer per jt on jts 4 tru 6, two centralizers per jt on 7 tru 70, no centralizer on jt 71, stop rings welded in middle of jt. Tripping in with liner to 10165' Working pipe to locate window, exit window after 24 attempts Tripping in with liner had to beat centralizers past bottom of window for app. 1300' the rest went with no problems, hole was slick, pickup wt. 134,000 SIO 80,000 Hooking liner hanger, took 6 attempts, top of liner tie back sleeve 10,136' shoe 13,091' Drop ball, pumped down 3 bbls min.,750 psi, pressure up to 4300 psi, shear ball, release from liner hanger, P/U wt 125,000 Slug pipe, Tripping out with running tools, laying down 105 jts of excess drill pipe. Laying down liner running tools Pick up Johnny Wacker tripping in to 10,070' Slip and cut drilling line Displace hole with 9.5 brine with Inhibitor, with 10 bbls min. 120 rpms, 3050psi PJSM, laying down excess drill pipe, stand 40 stands in derrick Pull wear ring, Rig up I-wire spool, rig up tubing tongs, count tubing Picking up, 3.5 tail pipe assem. Baker 7 5/8x 4.5 Premier packer, and Phoenix jet pump sensors and gauge, picking up 4.512.6# L-80 IBT Tubing with I-wire to 4,312' Finish picking up 4.5 12.6# L-80 IBT Tubing with I-wire to 10,040.05 total of 237 jts, tail pipe 10,040, XN 10034, packer, 9984, x nipple 9973, Phoenix Sensor 9957, Sliding sleeve 9934, Phoenix pressure gauge 9923, GLM 2101' Picking up FMC hanger and land tubing P/U 115K, SIO 83K 123 Clamps. 123 cannon clamps used. Test I-Wire. RILDS and test TWC to 300 psi from below. Clear rig floor. Nipple down BOP stack. Nipple up FMC 11" X 4-1/16" 5000# Tubing Head Adapter. Run control line through adapter and test pack off to 3500 psi. Nipple up 4-1/16" CIW 5000# tree and test tree to 4000 psi. Open annulus valve and pulled TWC with dry rod. Dropped BalVrod/roller assembly down tubing. Rig up line to tubing for pressure test. Pressure on to tubing to 2500 psi to set packer, continued pressuring up to 3000 psi with rig pump. Switched to test pump and continued pressuring up slowly to 3800 psi and suddenly lost pressure on tubing to 400 psi. No flow on annulus. Printed: 91212003 9:55:32/Wo Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~ .. "'-- / BP EXPLORATION Operations Summary Report MPS-34 MPS-34 ORIG DRILLING DOYON DRILLING INC. DOYON 14 9/1/2003 10:00 - 10:30 From -To Hours Task Code NPT Phasé 0.50 CASE P Start: 8/10/2003 Rig Release: Rig Number: Spud Date: 8/11/2003 End: Description of Operations PROD2 Attempted to pressure up on tubing and pumped 3 bbls and pressure on tubing increased to 800 psi and began pumping into formation. Appeared that the RHC plug sheared (set to shear at 4900 psi). Pressure test casing to 1000 psi for 10 minutes with no bleed off. Freeze protected 10-3/4" X 7-518" annulus with 95 bbls of diesel. Installed TWC and tested to 1000 psi from the top. RID circ. hoses and test eguip. secure well Rig Release @ 1500 hrs 9/1/2003 10:30 -11:30 1.00 CASE P PROD2 11 :30 - 12:00 0.50 WHSUR P PROD2 12:00 -15:00 3.00 CASE P PROD2 Printed: 9/212003 9:55:32 ¡w, Legal Name: MPS-34 Common Name: MPS-34 TestDåte 8/15/2003 8/22/2003 BP EXPLORATION Leak-Off Test Summary FIT FIT 5,546.0 (ft) 10,515.0 (ft) 2,893.0 (ft) 4,198.0 (ft) AMW 8.90 (ppg) 9.50 (ppg) Suñace Pressure 400 (psi) 340 (psi) Leak Off Pressure (BHP) 1 ,738 (psi) 2,412 (psi) Page 1 of 1 EMW 11.56 (ppg) 11.06 (ppg) . . Printed: 9/2/2003 9:55:17 AM · AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPS-34 L 1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,440.75' MD 10,516.00' MD 13,232.00' MD (if applicable) , d03 ~/3~ 16-Sep-03 Please call me at 273-3545 if you have any questions or concerns. Regards, William 1. Allen Survey Manager Attachment(s) ~\:;;'0 \,\, ~~ DEFINITIVE ,. . Sperry-Sun Drilling Services Milne Point Unit BPXA MilnePoinfMPS MPS-34L1 '.,......- 2003 Job No. AKZZ0002600988, Sufi/eyed: 25 September, Survey iReport /' 16 September, 2003 W) Your Ref: API 500292317160 Surface Coordinates: 5999917.12 N, 56559Ø.66 E (70· 24' 36.7947" N, 149027"57.0634" Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Survey Ref: svy1249 Surface Coordinates relative to Project H Reference: 999917.12 N, 65598.66 E (Grid) Surface Coordinates relative to Structure: 51.32 S, 746.82 W (True) Kelly Bushing: 72.30ft above Mean Sea Level Elevation relative to Project V Reference: 72.30ft Elevation relative to Structure: 72.30ft Eipee............Y-IIUI1 DAtL..L..tNG SÉAVIc:EáS A Halliburton Company Sperry-Sunfj)~itlt"';1Ai;~;~tvices Survey Report for Milne Pt>lntf,fPS..MPS.34L 1 Your Ref: API500292311160 Job No. AKZZ0002600988, Survêyed:25 September, 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) 10440.75 76.480 354.320 4109.08 4181.38 4215.63 N 7455.70 W 6004067.11 N 558106.22 E 5446.26 Tie On Point 10516.00 76.830 357.130 4126.45 4198.75 4288.64 N 7461.15W 6004140.06 N 558100.13 E 3.663 5519.10 Window Point 10550.82 81.330 357.510 4133.05 4205.35 4322.78 N 7462.75 W 6004174.19 N 558098.23 E 12.968 5553.00 10586.16 86.050 357.900 4136.93 4209.23 4357.87 N 7464.16W 6004209.27 N 558096.52 E 13.401 5587.80 10635.14 87.780 3.870 4139.57 4211.87 4406.75 N 7463.40 W 6004258.15 N 558096.84 E 12.673 5635.81 10682.71 85.060 8.160 4142.54 4214.84 4453.95 N 7458.43 W 6004305.39 N 558101.40 E 10.663 5681.43 . 10733.14 83.760 12.560 4147.45 4219.75 4503.31 N 7449.41 W 6004354.83 N 558109.99 E 9.058 5728.47 10778.42 85.680 20.730 4151.63 4223.93 4546.47 N 7436.50 W 6004398.10 N 558122.52 E 18.459 5768.73 10828.87 86.040 24.350 4155.27 4227.57 4592.93 N 7417.21 W 6004444.73 N 558141.39 E 7.192 5811.14 10875.27 88.270 25.180 4157.57 4229.87 4635.01 N 7397.80 W 6004486.98 N 558160.43 E 5.127 5849.21 10925.28 87.840 25.790 4159.27 4231.57 4680.13 N 7376.30 W 6004532.28 N 558181.54 E 1.492 5889.91 10971.00 86.240 25.920 4161.63 4233.93 4721.22 N 7356.39 W 6004573.54 N 558201.09 E 3.511 5926.91 11020.13 86.290 28.150 4164.83 4237.13 4764.88 N 7334.10W 6004617.40 N 558222.99 E 4.530 5966.05 11066.28 86.290 34.960 4167.82 4240.12 4804.10 N 7310.02 W 6004656.83 N 558246.73 E 14.725 6000.49 11116.45 86.660 39.550 4170.91 4243.21 4843.95 N 7279.71 W 6004696.95 N 558276.68 E 9.161 6034.47 11162.44 86.170 43.360 4173.79 4246.09 4878.34 N 7249.33 W 6004731.61 N 558306.76 E 8.337 60q,a.06 11215.28 87.290 45.240 4176.80 4249.10 4916.10N 7212.49 W 6004769.68 N 558343.27 E 4.136 6093.85 11258.76 89.570 46.910 4177.99 4250.29 4946.25 N 7181.19W 6004800.10 N 558374.31 E 6.499 6.118.10 11309.70 90.800 47.180 4177.83 4250.13 4980.96 N 7143.91 W 6004835.14 N 558411.28 E 2.472 6145.81 11353.70 91.850 46.940 4176.81 4249.11 5010.92 N 7111.70 W 6004865.39 N 558443.22 E 2.448 6169.73 11407.27 92.960 46.040 4174.56 4246.86 5047.77 N 7072.89 W 6004902.57 N 558481.71 E 2.667 6199.28 11449.97 90.250 43.080 4173.37 4245.67 5078.18 N 7042.94 W 6004933.24 N 558511.39 E 9.396 6224.02 11498.94 90.430 42.650 4173.08 4245.38 5114.07 N 7009.63 W 6004969.43 N 558544.38 E 0.952 6253.59 . 11546.59 90.560 38.550 4172.66 4244.96 5150.24 N 6978.63 W 6005005.87 N 558575.06 E 8.608 6283.82 11596.15 90.430 37.890 4172.24 4244.54 5189.17 N 6947.97 W 6005045.07 N 558605.38 E 1.357 6316.84 11642.48 90.490 36.910 4171.86 4244.16 5225.98 N 6919.83 W 6005082.12 N 558633.20 E 2.119 6348.20 11695.03 90.930 36.680 4171.21 4243.51 5268.06 N 6888.36 W 6005124.47 N 558664.30 E 0.945 6384.17 11739.45 91.230 36.640 4170.38 4242.68 5303.68 N 6861.84 W 6005160.33 N 558690.50 E 0.681 6414.65 11791.26 91.050 36.300 4169.34 4241.64 5345.34 N 6831.05 W 6005202.26 N 558720.92 E 0.742 6450.33 11835.53 91.300 36.510 4168.44 4240.74 5380.96 N 6804.78 W 6005238.11 N 558746.88 E 0.737 6480.85 11886.69 91.670 35.820 4167.14 4239.44 5421.44 N 6775.19 W 6005278.85 N 558776.11 E 1.560 6515.58 11931.56 90.250 36.220 4166.37 4238.67 5458.54 N 6748.22 W 6005316.16 N 558802.75 E 3.216 6547.43 11981.40 89.440 38.100 4166.50 4238.80 5498.25 N 6718.12W 6005356.16 N 558832.51 E 4.107 6581.31 12027.75 89.690 37.900 4166.85 4239.15 5534.78 N 6689.59 W 6005392.93 N 558860.72 E 0.691 661233 1207680 89.570 36.760 4167.17 4239.47 5573.78 N 6659.84 W 6005432.19 N 558890.12 E 2.337 6645.57 --~-,-~..__._-~.._---_.."._-_._,_.,._-~._--- 16 September, 2003 - 7:08 Page 2 of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for Milne Point MPS - MPS-34L 1 Your Ref: AP/500292317160 Job No. AKZZ0002600988, Surveyed: 25 September, 2003 BP EXPLORA TlON (ALASKA) /NC. 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) (o/100ft) 12124.24 90.250 37.060 4167.25 4239.55 5611.71 N 6631.35W 6005470.37 N 558918.28 E 1.567 6677.98 12174.51 92.530 39.500 4166.03 4238.33 5651.15 N 6600.22 W 6005510.09 N 558949.06 E 6.642 6711.42 12220.19 91.050 42.210 4164.60 4236.90 5685.68 N 6570.36W 6005544.88 N 558978.62 E 6.757 6740.24 12271 .12 90.680 41.780 4163.83 4236.13 5723.53 N 6536.29 W 6005583.02 N 559012.35 E 1.114 6771.59 12317.24 90.860 40.280 4163.21 4235.51 5758.32 N 6506.02 W 6005618.07 N 559042.32 E 3.275 6800.59 12367.31 90.740 37.420 4162.51 4234.81 5797.30 N 6474.61 W 6005657.33 N 559073.38 E 5.716 6833.54 . 12413.08 91.730 36.000 4161.53 4233.83 5833.99 N 6447.26 W 6005694.26 N 559100.41 E 3.781 6864.91 12463.68 91.300 34.970 4160.19 4232.49 5875.17 N 6417.90 W 6005735.70 N 559129.41 E 2.205 6900.37 12509.38 91.110 35.130 4159.23 4231.53 5912.58 N 6391.66 W 6005773.33 N 559155.32 E 0.543 6932.65 12559.94 91.050 34.530 4158.27 4230.57 5954.07 N 6362.79 W 6005815.08 N 559183.82 E 1.192 6968.50 12605.44 91.730 35.820 4157.17 4229.47 5991.25 N 6336.59 W 6005852.49 N 559209.70 E 3.204 7000.57 12654.90 94.080 36.400 4154.66 4226.96 6031.16 N 6307.48 W 6005892.65 N 559238.45 E 4.894 7034.81 12700.59 93.210 36.150 4151.76 4224.06 6067.92 N 6280.50 W 6005929.64 N 559265.11 E 1.981 7066.33 12750.59 90.800 35.270 4150.01 4222.31 6108.49 N 6251.34 W 6005970.47 N 559293.92 E 5.131 7101.22 12796.04 91.050 35.370 4149.28 4221.58 6145.57 N 6225.06 W 6006007.78 N 559319.86 E 0.592 7133.17 12846.26 91.420 35.730 4148.19 4220.49 6186.42 N 6195.87 W 6006048.88 N 559348.69 E 1.028 7168.:33 12892.27 90.190 37.240 4147.55 4219.85 6223.40 N 6168.52 W 6006086.11 N 559375.72 E 4.233 7200.01 12942.71 89.260 36.270 4147.79 4220.09 6263.81 N 6138.33 W 6006126.78 N 559405.55 E 2.664 7234.56 12987.94 88.700 36.260 4148.59 4220.89 6300.28 N 6111.58 W 6006163.48 N 559431.98 E 1.238 7265.83 13043.49 87.590 36.210 4150.39 4222.69 6345.06 N 6078.77 W 6006208.55 N 559464.40 E 2.000 7304.23 13083.94 87.530 36.050 4152.11 4224.41 6377. 70 N 6054.94 W 6006241.39 N 559487.94 E 0.422 7332.24 13133.59 86.230 36.220 4154.82 4227.12 6417.74 N 6025.70 W 6006281.69 N 559516.82 E 2.641 7366.59 13163.25 85.730 36.220 4156.90 4229.20 6441.61 N 6008.22 W 6006305.71 N 559534.09 E 1.686 7387.06 . ··13232.00 85.730 36.220 4162.01 4234.31 6496.92 N 5967.71 W 6006361.37 N 559574.12 E 0.000 7434.50 Projected Survey 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 350.000· (True). Magnetic Declination at Surface is 25.412°(11-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13232.000., The Bottom Hole Displacement is 8821.76ft., in the Direction of 317.431· (True). --.--.-. 16 September, 2003 - 7:08 Page 3 of4 Dril/Quest 3.03.02.005 Sperry-Sun Ptf -if Services Survey Report for M/1[t ~ MPS-34L 1 Your Ref: API 1160 Job No. AKZZ0002600988, Sutveyed: 26 SepZember, 2003 BP EXPLORA TlON (ALASKA) INC. Milne Point Unit Comments Measured Depth (ft) '- 10440.75 10516.00 13232.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 4181.38 4198.75 4234.31 4215.63 N 4288.64 N 6496.92 N 7455.70 W 7461.15 W 5967.71 W Survey tool program for MPS-34L 1 From Measured Vertical Depth Depth (ft) (ft) 0.00 278.90 Comment Tie On Point Window Point Projected Survey To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 278.90 278.89 13232.00 278.89 Tolerable Gyro (MPS-34) 4234.31 AK-6 BP JFR-AK (MPS-34) 16 September, 2003 - 7:08 BPXA . l" . Page 4 of 4 --~._--_._--,--_.__._..__._._--'-- DriflQllest 3.03.02.005 - AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 e- Re: Distribution of Survey Data for Well MPS-34 L 1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 10,440.75' MD 10,516.00' MD 13,232.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Survey Manager Attachment(s) ...~ \:S~,,(\ ~ 8.o3~-13~ 16-Sep-03 . Sperry-Sun Drilling Services Milne Pointl.Jnit 8~X~ Milne···PointMPS MPS-34L1 MWD Job No. AKMW0002600988, Surveyed: 25 August, 2003 SurveyiReport I}} 16 SepterrtI:Jer,Z003 W) Your Ref: AP/500292317160 Surface Coordinates: 5999917.12 N, 565598.66 E . (70024' 36.7947" N, 149027' 57.0634" Grid Coordinate System: NAD27 A/aska State Planes, Zone 4 . Survey Ref: svy1264 Surface Coordinates relative to Project H Reference: 999917.12 N, 65598.66 E (Grid) Surface Coordinates relative to Structure: 51.32 S, 746.82 W (True) Kelly Bushing: 72.300 above Mean Sea Level Elevation relative to Project V Reference: 72.30ft Elevation relative to Structure: 72.30ft sr...........y-·Ui! CFULL.tNG SSAVICSS A Halliburton Company Sperry-Sun'qnfl,~ ,§frvices Survey Report for MllnøP .... 'f,fPS-34L 1 MWD Your RefrAf{1 ...,...1!160 Job No. AKMWOO026009S8,Surv,yedr 25 August, 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) 10440.75 76.480 355.200 4109.81 4182.11 4299.10 N 7360.82 W 6004151.41 N 558200.36 E 5511.98 Tie On Point 10516.00 76.830 357.130 4127.18 4199.48 4372.15 N 1365.12 W 6004224.41 N 558194.82 E 2.538 5584.77 Window Point 10550.82 81.330 359.840 4133.78 4206.08 4406.32 N 7366.62 W 6004258.57 N 558193.63 E 15.013 5618.58 10586.16 86.050 359.450 4137.66 4209.96 4441.43 N 7366.84 W 6004293.68 N 558193.10 E 13.401 5653.20 10635.14 87.780 4.980 4140.30 4212.60 4490.29 N 1364.94 W 6004342.55 N 558194.56 E 11.814 5700.98 "-. . 10682.71 85.060 9.340 4143.27 4215.57 4537.38 N 7359.03 W 6004389.69 N 558200.06 E 10.787 5746.33 10733.14 83.760 13.660 4148.19 4220.49 4586.55 N 7349.03 W 6004438.94 N 558209.63 E 8.907 5793.01 10778.42 85.680 21.230 4152.36 4224.66 4629.53 N 7335.52 W 6004482.04 N 558222.76 E 17.178 5832.99 10828.87 86.040 24.530 4156.00 4228.30 4675.88 N 7315.96 W 6004528.56 N 558241.92 E 6.563 5875.24 10875.27 88.270 25.440 4158.31 4230.61 4717.88 N 7296.38 W 6004570.74 N 558261.12 E 5.190 5913.21 10925.28 87.840 26.060 4160.00 4232.30 4762.90 N 7274.67 W 6004615.94 N 558282.44 E 1.508 5953.77 10971.00 86.240 26.220 4162.36 4234.66 4803.89 N 7254.55 W 6004657.10 N 558302.19 E 3.517 5990.64 11020.13 86.290 28.340 4165.56 4237.86 4847.46 N 7232.09 W 6004700.87 N 558324.28 E 4.307 6029.65 11066.28 86.290 35.080 4168.55 4240.85 4886.61 N 7207.89 W 6004740.24 N 558348.13 E 14.574 6064.01 11116.45 86.660 40.090 4171.64 4243.94 4926.28 N 7177.36 W 6004780.17 N 558378.31 E 9.994 6097.78 11162.44 86.170 43.330 4174.52 4246.82 4960.54 N 7146.82 W 6004814.70 N 558408.54 E 7.111 61,26.21 11215.28 87.290 44.860 4177.53 4249.83 4998.43 N 7110.12W 6004852.91 N 558444.92 E 3.585 6157.15 11258.76 89.570 46.990 4178.72 4251.02 5028.66 N 7078.89 W 6004883.41 N 558475.87 E 7.175 6181.50 11309.70 90.800 47.500 4178.56 4250.86 5063.24 N 7041.49 W 6004918.32 N 558512.97 E 2.614 6209.06 11353.70 91.850 48.350 4177.54 4249.84 5092.71 N 7008.84 W 6004948.08 N 558545.36 E 3.070 6232.42 11407.27 92.960 46.590 4175.29 4247.59 5128.89 N 6969.40 W 6004984.60 N 558584.48 E 3.882 6261.20 11449.97 90.250 43.350 4174.10 4246.40 5159.08 N 6939.24 W 6005015.06 N 5586.14.37 E 9.889 6285.69 11498.94 90.430 42.980 4173.81 4246.11 5194.80 N 6905.74 W 6005051.07 N 558647.56 E 0.840 6315.05 . 11546.59 90.560 38.540 4173.39 4245.69 5230.88 N 6874.64 W 6005087.42 N 558678.34 E 9.322 6345.18 11596.15 90.430 38.030 4172.97 4245.27 5269.78 N 6843.94 W 6005126.59 N 558708.70 E 1.062 6378.16 11642.48 90.490 37.930 4172.59 4244.89 5306.30 N 6815.43 W 6005163.35 N 558736.89 E 0.252 6409.17 11695.03 90.930 37.190 4171.94 4244.24 5347.95 N 6783.40 W 6005205.29 N 558768.55 E 1.638 6444.63 11739.45 91.230 37.020 4171.11 4243.41 5383.37 N 6756.60 W 6005240.94 N 558795.04 E 0.776 6474.86 11791.26 91.050 36.760 4170.07 4242.37 5424.80 N 6725.51 W 6005282.64 N 558825.76 E 0.610 6510.26 11835.53 91.300 36.400 4169.17 4241.47 5460.34 N 6699.13 W 6005318.41 N 558851.83 E 0.990 6540.68 11885.69 91.670 36.020 4167.87 4240.17 5500.80 N 6669.51 W 6005359.13 N 558881.09 E 1.057 6575.38 11931.56 90.250 36.310 4167.10 4239.40 5537.83 N 6642.45 W 6005396.39 N 558907.83 E 3.160 6607.14 11981.40 89.440 37.820 4167.23 4239.53 5577.60 N 6612.41 W 6005436.42 N 558937.52 E 3.438 6641.09 12027.75 89.690 37.420 4167.59 4239.89 5614.31 N 6584.12 W 6005473.38 N 558965.49 E 1.018 6672.33 12076.80 89.570 36.460 4167.90 4240.20 5653.51 N 6554.64 W 6005512.84 N 558994.62 E 1.972 6705.82 16 September, 2003 - 7:11 Page 20f4 DrillQlJest 3.03.02.005 Sperry-Suni9tilll Survey Report for Mlln~", Your Ref:~~/. ...........>ittJ() Job No. AKMWOO02600988,· Suf'ieyed:25August, 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) 12124.24 90.250 36.770 4167.98 4240.28 5691.59 N 6526.34 W 6005551.17 N 559022.58 E 1.575 6738.41 12174.51 92.530 39.160 4166.76 4239.06 5731.20 N 6495.43 W 6005591.05 N 559053.14 E 6.569 6772.05 12220.19 91.050 41.240 4165.33 4237.63 5766.07 N 6465.97 W 6005626.18 N 559082.30 E 5.587 6801.28 12271.12 90.680 41 .460 4164.56 4236.86 5804.30 N 6432.32 W 6005664.70 N 559115.61 E 0.845 6833.08 12317.24 90.860 40.170 4163.94 4236.24 5839.20 N 6402.18 W 6005699.87 N 559145.44 E 2.824 6862.22 12367.31 90.740 37.340 4163.24 4235.54 5878.24 N 6370.84 W 6005739.18 N 559176.43 E 5.657 6895.22 . 12413.08 91.730 36.430 4162.26 4234.56 5914.84 N 6343.38 W 6005776.02 N 559203.58 E 2.938 6926.50 12463.68 91.300 35.480 4160.92 4233.22 5955.78 N 6313.68 W 6005817.22 N 559232.91 E 2.060 6961.66 12509.38 91.110 35.380 4159.96 4232.26 5993.01 N 6287.19 W 6005854.68 N 559259.07 E 0.470 6993.73 12559.94 91.050 34.690 4159.00 4231.30 6034.40 N 6258.17 W 6005896.33 N 559287.73 E 1.370 7029.45 12605.44 91.730 35.960 4157.90 4230.20 6071.52 N 6231.87 W 6005933.67 N 559313.70 E 3.165 7061.43 12654.90 94.080 36.510 4155.39 4227.69 6111.36 N 6202.68 W 6005973.76 N 559342.55 E 4.879 7095.59 12700.59 93.210 36.170 4152.49 4224.79 6148.09 N 6175.66 W 6006010.73 N 559369.24 E 2.044 7127.07 12750.59 90.800 35.130 4150.74 4223.04 6188.69 N 6146.54 W 6006051.58 N 559398.01 E 5.249 7162.00 12796.04 91.050 35.040 4150.01 4222.31 6225.87 N 6120.42 W 6006089.00 N 559423.80 E 0.585 7194.09 12846.26 91.420 36.300 4148.92 4221.22 6266.66 N 6091.14 W 6006130.04 N 559452.72 E 2.614 72.29.17 12892.27 90.190 37.540 4148.28 4220.58 6303.44 N 6063.50 W 6006167.06 N 559480.03 E 3.796 7260.59 12942.71 89.260 37.400 4148.52 4220.82 6343.47 N 6032.82 W 6006207.36 N 559510.36 E 1.865 7294.69 12987.94 88.700 36.710 4149.32 4221.62 6379.56 N 6005.57 W 6006243.69 N 559537.29 E 1.965 7325.50 13043.49 87.590 36.450 4151.12 4223.42 6424.15 N 5972.48 W 6006288.56 N 559569.98 E 2.052 7363.66 13083.94 87.530 36.060 4152.84 4225.14 6456.73 N 5948.58 W 6006321.36 N 559593.60 E 0.975 7391 .60 13133.59 86.230 36.740 4155.55 4227.85 6496.64 N 5919.16 W 6006361.52 N 559622.66 E 2.954 7425.79 13163.25 85.730 36.260 4157.63 4229.93 6520.42 N 5901.57 W 6006385.46 N 559640.05 E 2.334 7446.16 . 13232.00 85.730 36.260 4162.74 4235.04 6575.70 N 5861.02 W 6006441.09 N 559680.12 E 0.000 7493.56 Projected Survey 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 350.000° (True). Magnetic Declination at Surface is 25.412°(11-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 13232.00ft., The Bottom Hole Displacement is 8808.60ft., in the Direction of 318.289° (True). --'-_._-"'._~._.,--_._--_...._- 16 September, 2003 - 7:11 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Services Survey Report for M/ln ~ MPS-34L 1 MWD Your Ref: AÞI. 2317160 Job No. AKMWOO0260098B, Surveyed: 25 August, 2003 BP EXPLORA TION (ALASKA) INC. Milne Point Unit BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment L 10440.75 10516.00 13232.00 4182.11 4199.48 4235.04 4299.10 N 4372.15 N 6575.70 N 7360.82 W 7365.72 W 5861.02 W Tie On Point Window Point Projected Survey . Survey tool program for MPS-34L 1 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 278.90 0.00 278.90 278.89 13232.00 278.89 Tolerable Gyro (MPS-34 MWD) 4235.04 MWD Magnetic (MPS-34 MWD) . -..--- 16 September, 2003 - 7:11 Page 4 of4 DrillQllest 3.03.02.005 e ill) fÆ lfÆ~ ~~fÆ . ¡ í FRANK H. MURKOWSKI, GOVERNOR / / 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Pat Archey Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519 Re: Milne Point Unit MPS-34Ll BP Exploration (Alaska), Inc. Permit No: 203-132 Surface Location: 3252' NSL, 412' WEL, Sec. 12, T12N RlOE, UM Bottomhole Location: 4384' NSL, 1003' WEL, Sec.02, TI2N, RI0E, UM Dear Mr. Archey: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill 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. The permit is for a new wellbore segment of existing well MPUS-34, Permit No 203-130, API 50-029-23171-00. Production should continue to be reported as a function of the original API number stated above. 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). 3~~ S-arah Bálin ~ Chair BY ORDER OF THE COMMISSION DATED thi~~ day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encI. Exploration, Production and Refineries Section 1 a. Type of work 0 Drill 1/ 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 = 565599, Y = 5999917 3252' NSL, 412' WEL, SEC. 12, T12N, R10E, UM At top of productive interval x = 558153, Y = 6003895 2012' NSL, 2543' WEL, SEC. 02, T12N, R1OE, UM At total depth x = 559670, Y = 6006480 4584' NSL, 1003' WEL, SEC. 02, T12N, R10E, UM 12. Distance to nearest property line 113. Distance to nearest well ADL 025906, 695' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10253' MD Maximum Hole Angle 18. CaSingJ~~gram Specifications Hole Casina Weiaht Grade Couplina 6-1/8" 4-1/2" 12.6# L-80 BTC . STATE OF ALASKA . ALAS~IL AND GAS CONSERVATION COMlePrSSION PERMIT TO DRILL 20 AAC 25.005 11 b. Type of well 0 Exploratory 0 Stratigraphic Test 1/ Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool Plan KBE = 72' Milne Point Unit I Schrader 6. Property Designation Bluff ADL~ 3l!:o/c>?, .P 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) Milne Point Unit 8. Well Number MPS-34L 1 9. Approximate spud date 08/05/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13376' MD 14202' TVD 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} ~ 920 Maximum surface 1545 /pSig, At total depth (TVD) 42021/1966 psig Setting Depth Top Bottom Lenath MD TVD MD TVD 2701' 10253' 4137' 13376' 4202' ~ "LfJ,2J Number 2S100302630-277 Quantity of Cement (include staae data) Uncemented Slotted Liner 19. To be completed for Red rill , Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 13393 feet 4242 feet 13393 feet 4242 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 260 sx Arctic Set (Approx.) 112' 112' 853 sx PF 'L', 221 sx Class 'G' 5491' 2892' 255 sx PF 'E', 434 sx Class 'G' 11104' 4309' Uncemented Slotted Liner 10675' - 13393' 4229' - 4242' 112' 20" 5491' 10-3/4" 11104' 7-518" 3140' 4-1/2" Perforation depth: measured Slotted Liner true vertical Slotted Liner 1/ Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch III Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report III 20 AAC 25.050 Requirements Contact Engineer Name/Number: Steve Campbell, 564-4401 Prepared By Name/Number: Terrie Hubble, 564-4628 21. ~~::~Y:~:;a~y~ã:2;¡::;O :;:::~jEng;n..~,~te. 7/2 ~/¿7_') Penn" NU7~r.j _ I 3þ.-1.:' Nö~"2} - ;:3 't'7/- ~6' ., . ~ jð-2" I ~::;;'::"'nts Conditions of Approval: Samples Required 0 Yes Ja1Jo Mud Log Required 0 Yes ~o Hydrogen Sulfide Measures 0 Yes j¡f"No Directional Survey Required ~es 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Apprnved By ~~~RìG IttÃ bm~er Form 10-401 Rev. 12-01-85Sa.dh ...alln 20. Attachments by order of the commission Date-1(~)0~ Submit In triplicate e Milne. MPS-34 Well Permit I Well Name: I MPS-34 L 1 Drill and Complete Plan Summary I Type of Well (service I producer I injector): 1 Multi Lateral Producer "OA" Surface Location: 2028' FNL, (3251' FSL)~412' FEL;(4867' FWL), SEC. 12, T12N, R10E or- E=565598.69 "N=5999916.85 '" 3268' FNL, (2011' FSL);2542' FEL,12736' FWL), SEC. 2, T12N, R10E .- E=558153.03 N=6003895.24 Z=4137' TVD 695' FNL, (4584' FSL);'1003' FEL,14276' FWL), SEC. 2, T12N, R10E -- E=559670.0 .cN=6006480.0L=4202' TVD'- 2860' FNL, (2419' FSL), 2585' FEL, (2693' FWL), SEC.2, T12N, R10E E=558106.48 N=6004302.67 Z=4229' TVD 695' FNL, (4584' FSL), 1003' FEL, (4276' FWL), SEC. 2, T12N, R10E E=559670.0 N=6006480.0 Z=4242' TVD Target Location: TOP "OA" Target Location: BHL "OA" Well TD Target Location: TOP "OB" Target Location: BHL "OB" Well TD I AFE Number: 1 TBD I Rig: I Doyon 14 1 I Estimated Start Date: 1 05 AUG 2003 I Operating days to complete: 114 1 I MD: 113376 I I TVD: 14202 1 I Max Inc: 191 1 I KOP: 1102531 I KBE: 1721 I Well Design (conventional, slim hole, etc.): 1 Conventional Grass Roots ML Producer I I Objective: I Schrader Bluff OA I Mud Program: 13.5-in Surface Hole Mud Properties: Spud - LSND Freshwater Mud Density (ppg) I Funnel Vis I yp I HTHP pH I API Filtrate I 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 (ppg) PV YP HTHP 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-CaC03 FloPro Density (ppg) I PV YP I HTHP pH API Filtrate 9.0 - 9.2 10 - 20 25 - 30 10- 11 9.0 - 9.5 < 6 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 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. MBT <7 1 e Milne. MPS-34 Well Permit Cement Program: Casing 10.75-in 40-lb/ft L-80 BTC surface casing Size Basis 175% excess over gauge hole in permafrost interval. 40% excess over gauge hole below permafrost. Top of tail cement 500-ft MD above casing shoe. Total Cement Wash 20-bbl Water Spacer Vol: 527-bbl ¿~ y$ ~,<- ( '?((; ~ Tail 50~bbl 10.3-lb/gal un-viscosified Alpha spacer 630-bbl, 853-sx 10.7-lb/gal Permafrost L - 4.15 fe/sx (cement to surface) 45-bbl, 221-sx 15.8-lb/gal Premium G - 1.15 fe/sx of tail at 4991-ft BHST == 55°F from SOR, BHCT 60°F estimated by Halliburton Spacer Lead Temp 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. 0% excess over gauge. Top of tail cement 500-ft MD above top of N-sand. 40% excess over gauge. Total Cement Wash 5-bbl Water Vol: 117-bbl Spacer 30-bbl 10.3-lb/gal un-viscosified Alpha Spacer Lead 98-bbl, 255-sx 12.0-lb/gal Permafrost E - 2.17 fe/sx (top of lead at 7591-ft MD) Tail 89-bbl, 434-sx 15.6-lb/gal Premium G - 1.15 fe/sx of tail at 9438-ft Temp BHST == 80°F from SOR, BHCT 70°F estimated by Halliburton Evaluation Program: 13.5-in Hole Section: Open Hole: MWD/GR, IFRlCASANDRA Cased Hole: N/A 9.875-in Hole Section: Open Hole: MWD/GRlRES, ~ ..., IFRlCASANDRA Cased Hole: N/A 6.125-1" Hole section: Open Hole: MWDlGRlRES, ABI/IFRlCASANDRA Cased Hole: N/A 2 ~ -, Milne ¡ t MPS-34 Well Permit Formation Markers Formation Tops M Orkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* Base Permafrost 2040 1822 8.35 TUZC 8091 3567 1548 8.35 NA 9938 4057 1761 8.35 NB 10014 4077 1770 8.35 NC 10091 4097 1778 8.35 NE 10131 4107 1783 8.35 NF 10314 4152 1802 8.35 ~ Top OA 10422 4177 1813 8.35 Base OA 10537 4202 1966 9.0 Top OB 10738 4242 1841 8.35 TO 11104 4309 1870 8.35 * Based on SS depths Casinç/Tubing Program Hole Size Csg/ Wt/Ft Grade Conn Length Top Bottom Tbg O.D. M D / rvDrkb MD / rvDrkb 42-in 20-in* 92# H-40 Welded 80' 0' 112' 1 112' 13.5-in 10.75-in 45.5# L-80 BTC 5491 0' 5491 '/2892' 9.875-in 7.625-in 29.7# L-80 BTC 11104 0' 11104/4309 6.125-in 4.5-in 12.6# L-80 BTC 3140' 10,675/4229 13,393/4242' OB Slotted ~ 6.125-in 4.5-in 12.6# L-80 BTC 2701' 10,253/4137 13,376/4202' OA Slotted * The 20-in conductors are insulated. Recommended Bit Program BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13.5-in 0' - 5491 ' Smith MGXi 3-15 & 1-1 0 2 9.875-in 5491' - 11104' Smith FGXiCPS 3-15 & 1-1 0 )' 3 6.125-in 10253' - TO Security FM2643 3-12 4 6.125-in 10625' - TO Security FM2643 3-12 3 e Milne. MPS-34 Well Permit Well Control: Surface hole will be drilled with a diverter. Intermediate hole: · Maximum anticipated BHP: · Maximum surface pressure: 1,966-psi @ 4,202-ft TVDrkb - Top of "OA" - 1 ,545-psi @ surface .,.. (Based on BHP and a full column of gas from TD @ 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). · 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 e Milne. MPS-34 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 . NA Hydrogen Sulfide · MPS Pad is not designated as an H2S Pad. /' Anti-collision Issues · MPS-34 has no anti-collision issues. 5 e Milne ~ MPS-34 Well Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1 . The 20-in insulated conductor is installed 2. NU diverter Procedure "\f) 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. NO diverter, install wellhead, NU 80PE and test A kJ.'n c- _ '"? L\ 6. Drill 9.875-in intermediate hole \ v ,- ~ ') \ 7. Run and cement 7.625-in casing 8. Set whipstock and mill window for 08 9. Drill 6.125-in 08 horizontal production hole 10. Run 4.5-in slotted liner 11. Run whipstock and mill window for OA lateral .- 12. Drill 6.125-in OA horizontal production hole 13. Retrieve whipstock 14. Run 4.5-in slotted liner and hang off in 7.625-in casing 15. Displace drilling mud to brine .\- ~~: ~~n/~~-in jet pump completion ~ ~r~\ 18. Freeze protect well ... 19. RO/MO 6 e I I I I MPS-34t I 33 r _ 31 i -i I _29i I I _27 I h _ 25 J I _2~ I -23 I _21i I I _19i I MPU r _17 1 I _1~ I I _13i I LEGEND r _ 11 -i -+- AS-BUILT CONDUCTOR ____I _ 9i I. EXISTING CONDUCTOR I ____ _ 7i I L 1i5___ J I .l SE:er - - - 1- --. MPS-2J.. 3 - :::--:... 12 r72 II I MPS-1 -+- SE:er 7 ri2ft ~ I ' RUE: . I. r I I I I ~ ¡-. I I <:) I f¿X2,l~ _L - - _L - - _L - - _L j , ~ / · , NOTES: 1. DATE OF SURVEY: DECEMBER 13 & 15, 2002. 2. REFERENCE FIELD BOOK: MP02-08 PGS. 16-17 & 20-21. 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. 6. 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. I -z- I PLANT L 15'00'00" GRID S-PAD .~ 21 28 1:-:¡: AD T13N T12N 2 35 33 K 5 PROJEcT 3 MEA 11 9 10 14 Ww 13 SO:: 18 "'''' 16 15 17 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 DECEMBER 15, 2002. LOCATED WITHIN PROTRACTED SEC. 7, T. 12 N., R. 11 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-01 Y=6,OOO,044.65 N= 2,236.68 70'24'38.007" 70.4105578' 38.3' 3,375' FSL X= 566,076.93 E= 6,959.07 149'27'43.011" 149.4619475' 4,714' FEL MPS-02 Y=6,OOO,041.30 N= 2,237.19 70'24'37.976" 70.4105489' 38.3' 3,372' FSL X= 566,062.45 E= 6,944.21 149'27'43.437" 149.4620658' 4,729' FEL LOCA TED WITHIN PROTRACTED SEC. WELL A.s.P. PLANT NO. COORDINATES COORDINATES MPS-34 Y= 5,999,917.12 N= 2,237.28 X= 565,598.66 E= 6,464.04 12, T. 12 N., R. 10 E., UMIAT MERIDIAN, ALASKA GEODETIC GEODETIC CELLAR SECTION POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS 70'24'36.795" 70.4102208' 38.0' 3,252' FSL 149'27'57.063" 149.4658508' 412' FEL ... ~~, DRAWN: Obp COTTON CHECKED: ALUSON DATE: 12/11/02 DRAINING: MILNE POINT UNIT S-PAD SHEET: FRB02 MPS 33-00 ~ ffi~[Jn~o JOB NO: AS-BUILT CONDUCTORS ENœ€£RS N40 t.AMD SUR~ SCALE: WELLS MPS-01, MPS-02 & MPS-34 1 OF 1 JJC RFA 1I01Y£STF1~LANE 1"= 160' BY CHK """"""'-~...... o 12/17/02 ISSUED FOR INFORMATION NO. DATE REVISION TREE: Cameron 4-1/16" 5M WELLHEAD: FMC Gen 5 11 ", 5M Tubing Head: 11" x 4-1/2", FMC Tubing Hanger ~HU~U~I::IJ CUM~.LI:: IIUt:*. WlP 5-34 & ~-3.c.L1. I KB. ELEV =66' I Cellar Box ELEV = 38.5' . 20" 92 Iblft, H-40 Welded ~ Insulated Diesel Freeze protect to 500' MD Jet Pump Installed in Sliding Sleeve Post rig! 112' 10-3/4" 45.5#, L-80, BTC-M Casing Drift: 9.875 Casing 10: 9.950 Coupling 00: 11.75" Burst: 5,210 psi ColI~se: ? .480 psi 9.7 KCL with corrosion inhibitor as packer fluid 7-5/8" 29.7#, L-80, BTC-M Casing Drift: 6.75 Casing 10: 6.875 Coupling 00: 11.75" Burst: 6,890 psi Collapse: 4,790 psi Window in Welllnclin ... 42" Hole 4-1/2" x 1" Gas Lift Mandrel @ 2,267' MD, 2080' TVD, RP shear valve open position, "X" Nipple (2.813" ID) 70' below GLM . 4-1/2", 12.6 Ib/ft, L-80, IBT-M Coupling 00: 5.2" OriftllO: 3.833" Burst: 8,430, 80% 6,744 psi Collapse: 7,500, 80%=6,000 psi " .. 110-314" @ 5,491'MD; 2,892' TVD BIW 1- Wire .... Phoenix Pressure Gauge (3.850" ID, W/BIW 1- wire down to lower sensor) III Halliburtion Dura Sleeve XD WIX Nipple (3.813" ID) Phoenix Pressure Gauge (2.840" ID) . 7-5/8" x 4-112" Premier Packer ISet @ 10,200'MD, 4124' TV' 3-1/2" HES 'XN' nipple 2.750" ID No Go W/RHC-M for ball & rod / \~~ Ulde 110,253i' - 13,376' ~ '! \~ ...... ---- Multi-Lateral Junction 6-1/8" OA Lateral 2 TD - - -- - - OA HoriIICIntaI 6-1/1" ~ r- - - - - - - - - l 4-1/<¿" ~I~iner W/Hookw~ger Top liner @ 10,575' MD-------------. Window in 7-518" casing @ 10,675' Well Inclination @ Window = 79 deg 7-5/8" PBTD @ 11,020' MD 7-5/8" Casing Shoe @ 11,104' MD Well Inclination @ Shoe = 79 Degrees DATE 07/24/03 REV. BY SKC COMMENTS Level 3 Multi-lateral, 4-1/2" Jet Pump Completion Milne Point Unit WFI I : 8-34 API NO: 9-7/8" Hole ~~ 6-1/8" OB Lateral TD 113,393' 1 - - - -- - - 08 Horizontal 6-1/8" hole - - - - ~ffØ'~l - - -- 4-1/2" Slotted Liner Wlliner hanger BP COMPANY DETAILS REFERENCE INFORMA nON BP Amoco Co-ordinate (NÆ) Refereoce: Wen Centre: Plan MPS-34, True North Vertical (TVD) Reference; S-Pad Dev 72,00 Section (VS) Reærcncc: User Defined (4044.02N,-7411.14E) Measured Depth Reference: S-Pad Dev 72.00 Calculation Method; Minimum Curvature Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method; Trav Cylinder North Error Surface: Elliptical + Casing Waminl; Method: Rules Based o l -I pP ¡ß ~ I,s§' , #' #' ,# , ~o -boo ô£bo $000 .ro~O£b --.;114- ~Ooo /' /O£b Â) '/000 ~ Start Dir 121100': 10253' MD, 4137.2'TVD -JLndDir: 10338.35'MD,4152.45'TVD - Start Dir 10/100': 10546.03' MD, 4178.811'VD - ! Start Dir 8/100': 10731.04' MD, 41921'VD '2400(}- I. End Dir : 11156.46' MD, 4198.36' TVD ~ = I Start Dir 6/100' : 11407.53' MD, 42021'VD ~ _"'!'" ' '" "~"-"'M EndDir : 11490.91'MD,4200.87'TVD ~ - ,., li'Pd:t:L"::·::·::·:..,..~::.~~.:L.::_:...::..:.',:"",:: ,j",\)\ .-... i::,U'¡ ~ ¡ ................, ''',,' 1>" ('I :::,~),:.I.,; :.;~'; ~~I.)\I~~~; i;~.\1:1) 2 ~~I.JI,I ~..""..",..t ¡- o 800 1200 1600 2000 Vertical Section at 30.91° [400ft/in] 2400 2800 , I ' 3200 400 SURVEY PROGRAM Plan: MPS-34 OA wp06 (plan MPS-34/Plan MPS-34 OA) Depth Frn Depth To SurveyIPlan Tool Created By: Ken Allen Checked: Date: Date: 7/23/2003 10253.00 13376.23 Planned: f.ÆPS-34 OA wp06 V29 MWD+IFR+MS Reviewed: Date WELL DETAILS Nwno tN/-S iE/-W Longitude Slot Northing Hasting Latitude Plan MPS-34 -54.52 -746.89 5999916.85 565598.69 70"24'36.792N 149°27'57.063W NlA TARGET DETAILS Nwno TVD +NI-S +EI·W Northing Basting Shape MPS·34 OA T4 WP 4 4172.00 5890.21 -6407.82 6005750.00 559140.00 Point MPS·340A T3.1 WP4 4182.00 5483.00 -673 \.44 6005340.00 558820.00 Point MPS-34 OA T1 WP 4 4192.00 4514.18 .7450.04 6004365.00 558110.00 Point f.ÆPS-34 Poly 4192.00 4482.16 -7221.29 6004335.00 558339.00 Polygon MPS-34 OA 12 WP 4 4202.00 5068.05 -7085.13 6004922.00 558470.00 Point MPS·34 OA T5 WP 4 4202.00 661559 -587138 6006480.00 559670.00 Point SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 10253.00 75.96 345.41 4137.20 4044.02 -7411.14 0.00 0.00 165.92 --- 2 10273.00 78.28 346.05 4141.65 4062.91 ·7415.94 12.00 15.00 180.47 3 10338.35 82.71 352.61 4152.45 4126.20 -7427.84 12.00 56.22 231.13 e 4 10546.03 82.71 352.61 4178.81 4330.49 -7454.34 0.00 0.00 400.15 5 10731.04 89.17 10.00 4192.00 4514.18 -7450.04 10.00 70.35 565.09 MPS-34 OA Tl WP 4 6 11156.46 89.17 44.04 4198.36 4887.57 -7259.64 8.00 90.26 984.22 7 11407.53 89.17 44.04 4202.00 5068.05 -7085.13 0.00 0.00 1224.85 MPS-34 OA T2 WP 4 8 11490.91 92.39 40.21 4200.87 5129.86 -7029.23 6.00 -49.92 1305.49 9 11917.25 92.39 40.21 4183.10 5455.18 -6754.24 0.00 0.00 1720.99 10 ¡ 1953.23 91.10 38.47 4182.00 5483.00 -6731.44 6.00 -126.62 1756.19 MPS-34 OA T3.l WP 4 11 12473.47 91.10 38.47 4172.00 5890.21 -6407.82 0.00 0.00 2266.78 MPS-34 OA T4 WP 4 12 12568.59 87.93 36.37 4172.81 5965.73 -6350.03 4.00 -146.47 2360.44 13 13376.23 87.93 36.37 4202.00 6615.59 -5871.38 0.00 0.00 3157.86 MPS-34 OA T5 WP 4 All TVD depths are ssTVDplus 72'for RKBE. FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 4172.00 10492.40 Top OA 4202.00 ¡ 1407.53 BaseOA CASING DETAILS No. TVD MD Name Size 4202.00 13376.22 4 112" 4.500 e - MPS-34 OA wp06 I \ I Î: I I l.l:~{I~;~'~Ut I:U:~, ;\!') I !::\I\)\' ., .. I.I~,I¡ 1)~'llh bp COMPANY DETAILS REFERENCE INFORMA IION BP Amoco Co.-ordinate (NÆ) Reference: Well Centre: Plan MPS-34, TlUe North Vertical (1VD) Reference: S-Pad Dev 72.00 Section (YS) Reference: User Defined (4044.02N,·7411.14E) Measured Depth Reference: S·Pa<! Dev 72.00 Calculation Method: Minimwn Curvature Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinœr North Error Surlàœ: Elliptical + C~jng Wamin~ Method: Rules Based FORMATION TOP DETAILS No. TVDPath MDPath Fonnation All TVD depths are ssTVD plus 72'for RKBE. 4172.00 10492.40 Top OA 4202.00 11407.53 Base OA CASING DETAILS No. TVD MD Name 4202.00 13376.22 41/2" 6('(11,1 I/'K I· '. , 1"",11)<;+ ' 13."'(, ~;' \11>. ;:II::,:rf f.) I '~ ; ":.. . " __..._ ..j... .........__ .lli',:,.'J.HJ.u~...~\.l¡~...~ \IP~·,1·1 0."\ "1',,(, i ti....')Ü· c :¡:¡ o o :£. +' :E' 1:: .....W" ~ ;Š ~ o '" 4200 -.'-..... " II"d 1)1:,.11:/.'1 :~. \1l~.4f<:'1~~.!~ . ...._____.._._ ~"TLf.i(; .00: 11'1., ~.' ~1 .~I~.,''T\1J . I I I i ¡ -7800 '" I .~I ,,,I I)¡: . .11.:':, l' \1IJ. 41 ': ~T "\ I) ~I..I: ~)I; ;.! 1(1,,. :\I.';.~. \11). -I:p: ~ï \1) " I 'I, ,,"!" " , -7200 -6600 West(-)/East(+) [600ft/in] ,.. "i I I I . , I I -6000 SURVEY PROGRAM Plan: MPS-34 OA wp06 (plan MPS-341P1an MPS-34 OA) Depth Fm Depth To SurveylPlan Tool MWD+IFR+MS Date Created By: Ken Allen Checked: Date: 7/2312003 10253.00 13376.23 Planned: MPS-34 OA wp06 V29 Reviewed: Date WELL DETAILS N~ +NI·S +r<J-w Northing Ealiting Latitude Longitude Slot PlanMPS-34 -54.52 -746.89 5999916.85 565598.69 70024'36.792N 149°27'57.063W NlA TARGET DETAll.S N~ MJ +N/-S +F)-W Northing Easting Shape MPS-340A T4 WP4 4172.00 5890.21 -6407.82 6005750.00 559140.00 Point MPS-340ATJ.IWP4 4182.00 5483.00 -6731.44 6005340.00 558820.00 Point MPS-34 OA TI WP 4 4192.00 4514.18 -7450.04 6004365.00 558110.00 Point Size MPS-34 Poly 4192.00 4482.16 -7221.29 6004335.00 558339.00 Polygon MPS-34 OA 12 WP 4 4202.00 5068.05 -7085.13 6004922.00 558470.00 Point 4.500 MPS-34 OA 15 WP 4 4202.00 6615.59 -5871.38 6006480.00 559670.00 Point SECTION DETAILS See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSee Target 1 10253.00 75.96 345.41 4137.20 4044.02 -7411.l4 0.00 0.00 0.00 2 10273.00 78.28 346.05 4141.65 4062.91 -7415.94 12.00 15.00 13.74 3 10338.35 82.71 352.61 4152.45 4126.20 -7427.84 12.00 56.22 61.93 e 4 10546.03 82.71 352.61 4178.81 4330.49 -7454.34 0.00 0.00 223.59 5 10731.04 89.17 10.00 4192.00 4514.18 -7450.04 10.00 70.35 383.39 MPS-34 OA T1 WP 4 6 11156.46 89.17 44.04 4198.36 4887.57 - 7259.64 8.00 90.26 801.57 7 11407.53 89.17 44.04 4202.00 5068.05 -7085.13 0.00 0.00 1046.05 MPS-34 OA T2 WI' 4 8 11490.91 92.39 40.21 4200.87 5129.86 - 7029.23 6.00 -49.92 1127.81 9 11917.25 92.39 40.21 4183.10 5455.18 -6754.24 0.00 0.00 1548.18 10 11953.23 91.l0 38.47 4182.00 5483.00 -6731.44 6.00 -126.62 1583.76 MPS-34 OA T3.1 WP4 11 12473.47 91.l0 38.47 4172.00 5890.21 -6407.82 0.00 0.00 2099.38 MPS-34 OA T4 WI' 4 12 12568.59 87.93 36.37 4172.81 5965.73 -6350.03 4.00 -146.47 2193.86 13-13376.23 87.93 36.37 4202.00 - 6615.59 -5871.38 0.00 0.00 2997.31 MPS-34 OA T5 WI' 4 o e ¡rIP ;I pP I' I 1,# '#' #', #'#' , # ;-: , -boo G<ho .s-0<h '~ Ñ <t)<h.Yooo ~ /<ho , I ' -5400 #'/~ " e BP KW A Planning Report Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M PtS Pad Plan MPS-34 Plan MPS-34 OA Date: 7/23/2003 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Section (VS) Reference: Survey Calculation Method: ...__n______m 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: Latitude: 70 24 Longitude: 149 27 North Reference: Grid Convergence: Northing: Easting: 5999978.00 ft 566345.00 ft 0.00 ft 0.00 ft Well: Plan MPS-34 Slot Name: Well Position: +N/-S -54.52 ft Northing: 5999916.85 ft +E/-W -746.89 ft Easting: 565598.69 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan MPS-34 OA Drilled From: Tie-on Depth: 72.00 ft Above System Datum: Declination: Mag Dip Angle: +E/-W ft -7411.14 Current Datum: Magnetic Data: Field Strength: Vertical Section: S-Pad Dev 7/21/2003 57537 nT Depth From (TVD) ft 4137.20 +N/-S ft 4044.02 Height Plan: MPS-34 OA wp06 Date Composed: Version: Tied-to: Principal: Yes Casing Points e _._....h__......_...,,_....~ Time: 14:36:30 Page: Well: Plan MPS-34, True North S-Pad Dev 72.0 User (4044.02N,-7411.14E,30.91Azi) Minimum Curvature Db: Oracle ....................................-...--...-..-- --.-----... Alaska, Zone 4 Well Centre bggm2003 37.329 N 35.171 W True 0.51 deg 70 24 36.792 N 149 27 57.063 W Plan MPS-34PB1 10253.00 ft Mean Sea Level 25.27 deg 80.84 deg Direction deg 30.91 7/23/2003 29 From: Definitive Path MD TVD Diameter Hole Size Name ft ft in in 13376.22 4202.00 4.500 6.125 41/2" Formations --~..__..._.._.._..__.- MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 10492.40 4172.00 Top OA 0.00 0.00 11407.53 4202.00 Base OA 0.00 0.00 0.00 Top OB 0.00 0.00 0.00 Base OB 0.00 0.00 Targets Map Map <-- Latitud;u-:-,:,:;' <_·L;;~g¡t;d;-=:;·1 Name Description TVD +N/-S +EI-W ~orthing Easting Deg Min See Deg Min See Dip. Dir. ft ft ft ft ft .-..--.....--...--... MPS-34 OA T4 WP 4 4172.00 5890.21 -6407.82 6005750.00 559140.00 70 25 34.694 N 149 31 5.027 W MPS-34 OA T3.1 WP 4 4182.00 5483.00 -6731.44 6005340.00 558820.00 70 25 30.686 N 149 31 14.509 W MPS-34 OA T1 WP 4 4192.00 4514.18 -7450.04 6004365.00 558110.00 70 2521.152 N 149 31 35.558 W MPS-34 Poly 4192.00 4482.16 -7221.29 6004335.00 558339.00 70 25 20.839 N 149 31 28.849 W -Polygon 1 4192.00 4482.16 -7221.29 6004335.00 558339.00 70 25 20.839 N 149 31 28.849 W -Polygon 2 4192.00 6652.77 -5549.01 6006520.00 559992.00 70 25 42.201 N 149 30 39.851 W -Polygon 3 4192.00 6972.97 -5908.24 6006837.00 559630.00 70 25 45.347 N 149 30 50.397 W -Polygon 4 4192.00 4487.33 -7809.33 6004335.00 557751.00 70 25 20.884 N 149 31 46.095 W -Polygon 5 4192.00 3475.70 -7411.16 6003327.00 558158.00 70 25 10.939 N 149 31 34.388 W -Polygon 6 4192.00 3585.03 -6878.13 6003441.00 558690.00 70 25 12.019 N 149 31 18.760 W -.-...-........--...-..-.-.-.-.....-..---...--.. . Company: Field: Site: Well: Wellpath: Targets Name ---.-.--.---.-- BP Amoco Milne Point M PtS Pad Plan MPS-34 Plan MPS-34 OA MPS-34 OA T2 WP 4 MPS-34 OA T5 WP 4 Plan Section Information MD ft 10253.00 10273.00 10338.35 10546.03 10731.04 11156.46 11407.53 11490.91 11917.25 11953.23 12473.47 12568.59 13376.23 Survey MD ft 10253.00 10273.00 10275.00 10300.00 10325.00 10338.35 10400.00 10492.40 10500.00 10546.03 10550.00 10600.00 10650.00 10700.00 10731.04 10750.00 10800.00 10850.00 10900.00 10950.00 11000.00 11050.00 11100.00 11150.00 11156.46 11200.00 11300.00 11407.53 11450.00 11490.91 Incl deg 75.96 78.28 82.71 82.71 89.17 89.17 89.17 92.39 92.39 91.10 91.10 87.93 87.93 Incl deg 75.96 78.28 78.42 80.10 81.80 82.71 82.71 82.71 82.71 82.71 82.84 84.55 86.30 88.06 89.17 89.16 89.15 89.14 89.13 89.13 89.13 89.14 89.15 89.17 89.17 89.17 89.17 89.17 90.81 92.39 Description Dip. Dir. Azim deg 345.41 346.05 352.61 352.61 10.00 44.04 44.04 40.21 40.21 38.47 38.47 36.37 36.37 Azim deg 345.41 346.05 346.25 348.78 351.28 352.61 352.61 352.61 352.61 352.61 352.99 357.72 2.42 7.10 10.00 11.52 15.52 19.52 23.52 27.52 31.52 35.52 39.52 43.52 44.04 44.04 44.04 44.04 42.09 40.21 e .... -.......-....- BP KW A Planning Report TVD ft +N/-S ft e Date: 7123/2003 Time: 14:36:30 Page: 2 Co-ordinate(NE) Reference: Well: Plan MPS-34, True North Vertical (TVD) Reference: S-Pad Dev 72.0 Section (VS) Reference: User (4044.02N,-7411.14E.30.91Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +E/-W ft Map Northing ft Map Easting ft <-- Latitude --> <- Longitude --> Deg Min Sec Deg Min Sec 4202.00 5068.05 -7085.13 6004922.00 558470.00 70 25 26.602 N 149 31 24.872 W 4202.00 6615.59 -5871.38 6006480.00 559670.00 70 25 41.832 N 149 30 49.308 W TVD ft 4137.20 4141.65 4152.45 4178.81 4192.00 4198.36 4202.00 4200.87 4183.10 4182.00 4172.00 4172.81 4202.00 TVD ft 4137.20 4141.65 4142.06 4146.72 4150.65 4152.45 4160.27 4172.00 4172.96 4178.81 4179.31 4184.80 4188.79 4191.25 4192.00 4192.28 4193.01 4193.76 4194.51 4195.27 4196.03 4196.78 4197.53 4198.26 4198.36 4198.99 4200.44 4202.00 4202.01 4200.87 +N/-S ft 4044.02 4062.91 4126.20 4330.49 4514.18 4887.57 5068.05 5129.86 5455.18 5483.00 5890.21 5965.73 6615.59 Sys TVD ft 4065.20 4069.65 4070.06 4074.72 4078.65 4080.45 4088.27 4100.00 4100.96 4106.81 4107.31 4112.80 4116.79 4119.25 4120.00 4120.28 4121.01 4121.76 4122.51 4123.27 4124.03 4124.78 4125.53 4126.26 4126.36 4126.99 4128.44 4130.00 4130.01 4128.87 +E/-W ft -7411.14 -7415.94 -7427.84 -7454.34 -7450.04 -7259.64 -7085.13 -7029.23 -6754.24 -6731.44 -6407.82 -6350.03 -5871.38 DLS Build . Turn deg/100ft deg/10Oft OOg/100ft 0.00 0.00 0.00 12.00 11.60 3.17 12.00 6.77 10.05 0.00 0.00 0.00 10.00 3.49 9.40 8.00 0.00 8.00 0.00 0.00 0.00 6.00 3.86 -4.59 0.00 0.00 0.00 6.00 -3.58 -4.82 0.00 0.00 0.00 4.00 -3.33 -2.21 0.00 0.00 0.00 MapN MapE ft ft --.---.----...--.-..--. ...... 6003895.24 558153.03 6003914.09 558148.06 6003915.99 558147.57 6003939.92 558142.05 6003964.19 558137.57 6003977.26 6004037.83 6004128.61 6004136.08 6004181.30 6004185.20 6004234.68 6004284.49 6004334.28 6004365.00 6004383.65 6004432.34 6004480.14 6004526.79 6004572.08 6004615.79 6004657.70 6004697.60 6004735.31 6004740.01 6004771.57 6004844.06 6004922.00 6004953.27 6004984.30 558135.60 558127.20 558114.62 558113.58 558107.31 558106.79 558102.33 558101.95 558105.66 558110.00 558113.37 558124.63 558139.25 558157.18 558178.31 558202.55 558229.78 558259.87 558292.67 558297.10 558327.09 558395.95 558470.00 558498.72 558525.35 VS ft 0.00 13.74 15.13 32.98 51.64 61.93 109.92 181.84 187.76 223.59 226.69 267.11 309.88 354.70 383.39 401.19 448.89 497.51 546.82 596.59 646.56 696.49 746.14 795.27 801.57 843.97 941.34 1046.05 1087.57 1127.81 TFO deg 0.00 15.00 56.22 0.00 70.35 90.26 0.00 -49.92 0.00 -126.62 0.00 -146.47 0.00 Target MPS-34 OA T1 WP 4 MPS-34 OA T2 WP 4 MPS-34 OA T3.1 WP 4 MPS-34 OA T4 WP 4 MPS-34 OA T5 WP 4 DLS deg/10OO 0.00 12.00 12.00 12.00 12.00 TFO Too deg ._._..~..__.....__._.._--_....- ......-- 0.00 MWD+IFR+MS 15.00 MWD+IFR+MS 56.22 MWD+IFR+MS 56.18 MWD+IFR+MS 55.71 MWD+IFR+MS 12.00 0.00 0.00 0.00 0.00 10.00 10.00 10.00 10.00 10.00 8.00 8.00 8.00 8.00 8.00 8.00 8.00 8.00 8.00 8.00 0.00 0.00 0.00 6.00 6.00 55.31 0.00 0.00 0.00 0.00 70.35 70.30 69.78 69.41 69.17 90.26 90.23 90.18 90.12 90.06 90.00 89.93 89.87 89.81 89.76 0.00 0.00 0.00 310.08 310.08 MWD+IFR+MS MWD+IFR+MS Top OA MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MPS-34 OA T1 VIP 4 MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MWD+IFR+MS MPS-34 OA T2 VIP 4 MWD+IFR+MS MWD+IFR+MS e BP . KW A Planning Report -..._._",...~._...'---_....._. Company: BP Amoco Date: 7/23/2003 Time: 14:36:30 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPS-34, True North Site: MPtSPad Vertical (TVD) Reference: S-Pad Dev 72.0 Well: Plan MPS-34 Section (VS) Reference: User (4044.02N,-7411.14E,30.91Azi) Wellpath: Plan MPS-34 OA Survey Calculation Method: Minimum Curvature Db: Oracle .. . __n___ .._ __no _u...______n.. _ .-..--. -.--..-.-----..... .-...-------.-.... Survey MD Ine! Azim TVD Sys TVD MapN MapE VS DLS TFO Too ft deg deg ft ft ft ft ft deg/10OO deg ...--...--.-----.--.-..--..... . u.o._¥._....___, 11500.00 92.39 40.21 4200.49 4128.49 6004991.29 558531.15 1136.77 0.00 0.00 MWD+IFR+MS 11600.00 92.39 40.21 4196.32 4124.32 6005068.15 558594.97 1235.37 0.00 0.00 MWD+IFR+MS 11700.00 92.39 40.21 4192.15 4120.15 6005145.01 558658.80 1333.97 0.00 0.00 MWD+IFR+MS 11800.00 92.39 40.21 4187.98 4115.98 6005221.87 558722.62 1432.57 0.00 0.00 MWD+IFR+MS 11900.00 92.39 40.21 4183.81 4111.81 6005298.73 558786.44 1531.18 0.00 0.00 MWD+IFR+MS 11917.25 92.39 40.21 4183.10 4111.10 6005311.98 558797.45 1548.18 0.00 0.00 MWD+IFR+MS 11953.23 91.10 38.47 4182.00 4110.00 6005340.00 558820.00 1583.76 6.00 233.38 MPS-34 OA T3 1 WP , 12000.00 91.10 38.47 4181.10 4109.10 6005376.85 558848.77 1630.11 0.00 180.00 MWD+IFR+MS 12100.00 91.10 38.47 4179.18 4107.18 6005455.66 558910.28 1729.22 0.00 180.00 MWD+IFR+MS 12200.00 91.10 38.47 4177.26 4105.26 6005534.47 558971.78 1828.33 0.00 180.00 MWD+IFR+MS 12300.00 91.10 38.47 4175.34 4103.34 6005613.28 559033.29 1927.45 0.00 180.00 MWD+IFR+MS 12400.00 91.10 38.47 4173.42 4101.42 6005692.09 559094.80 2026.56 0.00 180.00 MWD+IFR+MS 12473.47 91.10 38.47 4172.00 4100.00 6005750.00 559140.00 2099.38 0.00 180.00 MPS-34 OA T4 VIP 4 12500.00 90.22 37.89 4171.70 4099.70 6005770.99 559156.21 2125.69 4.00 213.53 MWD+IFR+MS 12568.59 87.93 36.37 4172.81 4100.81 6005826.01 559197.12 2193.86 4.00 213.52 MWD+IFR+MS 12600.00 87.93 36.37 4173.94 4101.94 6005851.45 559215.51 2225.11 0.00 0.00 MWD+IFR+MS 12700.00 87.93 36.37 4177.56 4105.56 6005932.42 559274.06 2324.59 0.00 0.00 MWD+IFR+MS 12800.00 87.93 36.37 4181.17 4109.17 6006013.40 559332.61 2424.07 0.00 0.00 MWD+IFR+MS 12900.00 87.93 36.37 4184.79 4112.79 6006094.37 559391.16 2523.55 0.00 0.00 MWD+IFR+MS 13000.00 87.93 36.37 4188.40 4116.40 6006175.35 559449.71 2623.03 0.00 0.00 MWD+IFR+MS 13100.00 87.93 36.37 4192.02 4120.02 6006256.32 559508.26 2722.51 0.00 0.00 MWD+IFR+MS 13200.00 87.93 36.37 4195.63 4123.63 6006337.29 559566.81 2821.99 0.00 0.00 MWD+IFR+MS 13300.00/ 87.93 36.37 4199.24 J 4127.24 6006418.27 559625.36 2921.47 0.00 0.00 MWD+IFR+MS 13376.23 87.93 36.37 4202.00 4130.00 6006480.00 559670.00 2997.31 0.00 0.00 MPS-34 OA T5 VIP 4 e e 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 Drill. 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. e . TRANSMITAL LETTER CHECKLIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME øptf S-3iÄ / 2-03 ~ /.3~ PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL / (If API number last two (2) digits are between 60-69) PILOT (PH) "CLUE" The permit is for a new weUbore segment of existing weD ~ S,... 3'-1- Permit No,..2t>'-t3ð API No. S'"ó"öz. '7.- Z;3171"CJð Production sbould continue to be reported as a function' of tbe original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole 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 Rev: 07/1 0/02 C\jody\templates Tbe permit is approved subject to fun compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to tbe spacing exception that may occur. An dry ditcb sample sets submitted to tbe Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals tbrougb target zones. WELL PERMIT CHECKLIST Company BP EXPLORATION (ALASKA) INC Well Name: MILNE PT UNIT SB S-34L 1 Program DEV Well bore seg PTD#:2031320 Field & Pool MILNE POINT. SCHRADER BLFF OIL - 525140 Initial Class/Type DEV / PEND GeoArea 890 Unit 11328 On/Off Shore ~ Annular Disposal Administration 1 Penn it. fee attaçhep _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ Per .20 MC 25.005, since tl1is ¡sa laterpt tile $tOO fe_e_waived. _ _ . _ . . _ _ _ _ _ _ _ _ _ _ 2 .LeasenUlJlberappropri¡¡le_ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ No _ _ _ _ _ _ _ CQrœçtlea_se number [sAD_L_380t09 _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ 3 Unique weltnar:ne_and oumb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ . _ . . . _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ 4 WeJIJQc¡¡ted [n_a_d_efine_dpOQI _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ 5 WeJIJQc¡¡ted prpperd[slanceJrom Qri!ling unitbpuodpry _ _ _ _ . _ _ _ _ _ _Yes _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ 6 WellJQc¡¡ted prpper_d[stanceJrom QtbeJ wells_ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ 7Suffiçieotaçreage_aYai/¡¡ble in_drilJiog unjt. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. . _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ . _ 8 Jfdeviated, js weJlbQre plaUnc!upeQ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ . _ _ _ 9 Qperator 001Y' é!ffeçted party _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . . _ _ 10 _Operator l1as_appropr[aleJ>ond [n.fQrçe _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ . _ 11 PermilC<!nbe [ssuedwjtI1QulconservationQrder_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _. _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _. _ _ __ Appr Date 12 PermilC<!n be [ssuedwitbQuladmioistrative.'apprpvaJ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ _Yes _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ SFD 7/30/2003 13Cao perrnjtÞe ¡¡PPJQved before .15-day walt _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - _ _ _ _ - - - - - _ _ . 14 WellJQc¡¡ted w[thio area andßtrat¡¡ putl1Qr[zeQ byJojectioo Order # (PutlO# incPIJlr:neotsUFQr_ _NA _ _ _ _ _ _ _ . 15A!1 wel]s_withinJl4_mi/earea_of review jdeotified (ForservjceweU ooly). . . _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ . . _ 16 Pre-prOQuceQ injector; _dur¡¡ijonof pre-propuc;tion less_ tl1an:3 lJlootbs_ (forservlce welt Qn!y) _ _ NA 17 ACMPJ:]odjngof CQn_sisleocyhpS been JssuedJorJl1is prplect . _ _ _ _ _ _ _ _ _ _ _ NA _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ . . 18 _Cpnduclor striog_prQvlded _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ NA _ _ CQnduc;tQr jostaHed_ io MPS:3~ . 19Sur:fa~c¡¡sing_PJQtec;ts é!1I_known USOWs _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ . All. aquifeJs exer:npted ~O cm H7..1.02(b)(3) 20 _CMTv_otadeQuateJo circulpte_on_cooductor.& SUJfcsg _ _ . _ _ _ _ _ _ _ . . _ _ _ _ _ _ . _ _ _ NA _ _ _ _ _ _ Surface casing inst¡¡l)e_dJo MPS-34._ _ _ _ _ 21 _CMTvptadeQu_aleJolie-[nJQng_stringlo_sur:fcsg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _produ_cliQn_C<!singinstalledin_MF:>S-34._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ 22 .CMTwill GOYer_aH knownprQductiye I1QrizQn_s_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ No _ _ _ SloUe_dJioer_complet[on plpooed. _ _ . _ _ _ _ _ _ _ _ _ _ _ 23C_asing designs adequate for C,T, ß_&_permafrpst _ Yes _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ 24 _MequpleJankage_oJfe_serve pit _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ Rig js_e_quippe_dwitl1 steelpits.NQ reseJvepjtplanne_d, All waste lo_Class )lwel)(s)_ _ _ _ _ _ _ _ _ .. _ _ _ . _ _ 25 Jfare-drill, l1as_a_ 1.0~403 fQr ¡¡bandonmenl beeo ¡¡PPJQved _ _ _ _ _ _ _ . _ _ _ _ _ _ NA _ _ _ _ _ _ . _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . . _ _ _ _ _ _ _ _ _ 26 Adequplewellboresepar¡¡tjonproposed_ Yes _ prOxilJllÌ)'é!nalysis perfprme_d, No çl.oseé!pproaçh_issues identified_wilhJhis laleraL _ _ _ _ _ _ 27 Jt djverter Jeq_uired, dQes jt meel reguJations_ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 DJilIiog flujd_prQgl'é!m sc;helJl.¡t[c.& equipJistadequ¡¡te_ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Maximum BI-iP 9._0_EMW,expe_cted _BHP8,35, Planne_dmu_dweighÌ$8,8-9.2 with_9.t expec;ted, _ . TEM 7/30/2003 29 _B_OPEs,_dpJhey meelreguJation _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ 30 BOPE-Pfess raJiog appropriate; test lo(pu_t psig in _comlJlents)_ Yes _ . . Calçu!aJed_MASP t~5 psi. PI¡¡on_ed BOP Jest 3500 psi, _ _ _ _ _ . _ 31Chokemanjfold cQmpJies w/APIRP-5:3 (May 84)_ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ _ . _ _ _ 32 WQrk will oçcurwithoutoperationsl1utdQwn _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . _ _ _ _ _ _ _ . _ _ 33 Js presençe_ Qf H2S gas_ prQbable _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ 34 Meçhaniq¡l_condjt[onp{wellsw[thioAORverifieQ(Fors_erv[ceweII QnJy)_ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _. _ _ _ _ _ _. _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _. Engineering ~Q-('\... '" ("1-,0 Geology Appr SFD Date 7/30/2003 Geologic Commissioner: ¡f\Y ~ D ~ - - - - - - ~ - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - ~ - - - - - ~ - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- e' - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - e 35 Permit can be tssued w!o_ hydrog~n s_ulfide lJleé!Sj.Jres . 36 .D.atapreseoteQ Qn_ pote_ntial overpressure .zooes. 37 _SetslJlicanalysjs_ Qf shaJlow gé!S_Zooes _ . . . _ . 38Se;¡¡bedCOodjtioo survey _(if Qff-shore) _ _ 39 . CQnta.ct oam_elphonefor_wee1dy progress reports [expIQr;¡¡tory only] ... _ _ _ _. Yes. . _ _ Yes_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ - - - - - - - . _ _ Expected reservojr pressure is 8,35 ppg EMW; will be drjlled with. 9.0 - 9.2 ppg. mud, . . . - - - - - - - ..NA__... . NA .NA - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Date: Engineering Commissioner: Public &~'" Commissioner ~ Dat~~ "-.)'J ~, ~ Date 7/~¡/J e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation. information 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 Dr~ng Services LIS Scan Utility .ð03f-13~ $Revision: 3 $ LisLib $Revision: 4 $ Mon Oct 13 14:26:27 2003 \ ¡ \ ~~ Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/13 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 Date. . . . . . . . . . . . . . . . . . . . .03/10/13 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 Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPS-34 L1 500292317160 B.P. Exploration (Alaska) Inc. Sperry-Sun Drilling Services 13 -OCT-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002600988 T. MCGUIRE E. VAUGHN MWD RUN 2 MW0002600988 R. FRENCH C. DIXON MWD RUN 3 MW0002600988 R. FRENCH L. BROWN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002600988 C.A. DEMOSKI J. WILLOUGHB MWD RUN 5 MW0002600988 J. STRAHAN C. DIXON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 12 12N 10E 3252 412 MSL 0) 72.30 38.00 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 'R:~~\Y\ ~ ·' 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S.(IN) 13.500 9.875 6.125 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 112.0 5518.0 10516.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 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 & 3 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. THE PURPOSE OF MWD RUN 4 WAS TO POSITION THE WHIPSTOCK AND MILL THE WINDOW. THE TOP OF THE WINDOW WAS AT 10516'MD/4199'TVD, AND THE BOTTOM AT 10528'MD/4201'TVD. NEW FORMATION WAS DRILLED TO 10540'MD/4204'TVD. SROP DATA ONLY ARE PRESENTED FOR THIS RUN. 6. MWD RUN 5 COMPRISED DIRECTIONAL WITH DGR AND EWR4. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP ALASKA, INC., DATED 9/5/2003. MWD DATA ARE CONSIDERED PDC. 8. MWD RUNS 1 - 5 REPRESENT WELL MPS-34 L1 WITH API#: 50-029-23171-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13232'MD/4234'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 (DEEP RESISTIVITY) . SLIDE = NON-ROTATED INTERVALS, REFLECTING BIT DEPTHS $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 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 RPM RPS RPX $ 1 . . and clipped curves¡ all bit runs merged. .5000 START DEPTH 69.5 113.5 5505.5 5505.5 5505.5 5505.5 5505.5 STOP DEPTH 13177.0 13232.0 13184.0 13184.0 13184.0 13184.0 13184.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 5 MERGED MAIN PASS. $ MERGE TOP 69.5 5526.0 8846.0 10516.5 10540.0 MERGE BASE 5526.0 8846.0 10516.0 10540.0 13232.0 # 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 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 69.5 13232 6650.75 26326 69.5 13232 ROP MWD FT/H 0.12 5544.73 285.591 26238 113.5 13232 GR MWD API 9.01 130.79 68.8882 26216 69.5 13177 RPX MWD OHMM 0.37 1319.16 15.4338 15358 5505.5 13184 RPS MWD OHMM 0.25 2000 17.9921 15358 5505.5 13184 RPM MWD OHMM 0.17 2000 18.3808 15358 5505.5 13184 RPD MWD OHMM 0.2 2000 20.3497 15358 5505.5 13184 FET MWD HOUR 0.05 123.16 0.854775 15358 5505.5 13184 " . . First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .13232 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 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 69.5 113.5 STOP DEPTH 5481. 0 5526.0 # 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: 13 -AUG-03 Insite 66.37 Memory 5526.0 112.0 5526.0 .0 77.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 155790 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 112.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): Spud Mud 9.10 .' ...' 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: . 198.0 9.0 450 14.0 . .000 .000 .000 .000 .0 78..8 .0 .0 # 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 ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 5526 2797.75 10914 69.5 5526 ROP MWD010 FT/H 3.9 5544.73 276.28 10826 113.5 5526 GR MWD010 API 9.01 112.18 60.8705 10824 69.5 5481 First Reading For Entire File......... .69.5 Last Reading For Entire File.......... .5526 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record..65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 ·' .' Date of Generation...... ~10/13 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: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 5481. 5 5505.5 5505.5 5505.5 5505.5 5505.5 5526.5 STOP DEPTH 8808.5 8801.0 8801.0 8801.0 8801.0 8801.0 8846.0 # 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): 16-AUG-03 Insite 66.37 Memory 8846.0 5526.0 8846.0 71.9 77.0 TOOL NUMBER 126027 151812 9.875 5518.0 LSND 9.40 57.0 8.8 300 5.8 3.200 2.410 5.250 4.500 67.0 91. 3 67.0 67.0 .' y # . . 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 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 5481. 5 8846 7163.75 6730 5481.5 8846 ROP MWD020 FT/H 0.7 1452.54 417.726 6640 5526.5 8846 GR MWD020 API 15.84 126.39 74.5854 6655 5481.5 8808.5 RPX MWD020 OHMM 1. 72 57.84 9.16637 6592 5505.5 8801 RPS MWD020 OHMM 0.25 54.19 9.08132 6592 5505.5 8801 RPM MWD020 OHMM 0.17 2000 10.6593 6592 5505.5 8801 RPD MWD020 OHMM 0.2 2000 13.0508 6592 5505.5 8801 FET MWD020 HOUR 0.05 56.07 0.707524 6592 5505.5 8801 First Reading For Entire File......... .5481.5 Last Reading For Entire File.......... .8846 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER .; or" FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ . 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 8801.5 8801.5 8801.5 8801.5 8801.5 8809.0 8846.5 STOP DEPTH 10516.0 10516.0 10516.0 10516.0 10516.0 10516.0 10516.0 # 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... ..0 18-AUG-03 Insite 66.37 Memory 10516.0 8846.0 10516.0 71. 8 80.1 TOOL NUMBER 126027 151812 9.875 5518.0 LSND 9.55 61. 0 8.2 300 5.0 2.500 1.650 4.100 3.500 65.0 102.3 65.0 65.0 ·' 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 MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 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 8801.5 10516 9658.75 3430 8801.5 10516 ROP MWD030 FT/H 3.99 1111.6 241.088 3340 8846.5 10516 GR MWD030 API 19.2 130.79 70.9742 3415 8809 10516 RPX MWD030 OHMM 2.35 755.04 16.3225 3430 8801.5 10516 RPS MWD030 OHMM 2.35 248.53 14.1677 3430 8801.5 10516 RPM MWD030 OHMM 2.34 1816.22 15.9517 3430 8801.5 10516 RPD MWD030 OHMM 2.41 2000 18.6808 3430 8801.5 10516 FET MWD030 HOUR 0.07 14.64 0.863017 3430 8801.5 10516 First Reading For Entire File......... .8801.5 Last Reading For Entire File.......... .10516 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 5 header data for each bit run in separate files. 4 .5000 , ' VENDOR TOOL CODE ROP $ START .H 10516.5 STOP DEPTH 10540.0 # 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 $ # 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 . 22-AUG-03 Insite 66.37 Memory 10540.0 10516.0 10540.0 76.5 76.8 TOOL NUMBER 6.750 10516.0 FLO-PRO 9.50 48.0 8.2 300 5.2 .000 .000 .000 .000 .0 87.4 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 .-" Name Service Unit DEPT FT ROP MWD040 FT/H .. Mln 10516.5 0.12 Max 10540 9.53 Mean 10528.3 6.31167 Nsam 48 48 First Reading For Entire File......... .10516.5 Last Reading For Entire File.......... .10540 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.005 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 GR FET ROP $ 6 .st ading 10516.5 10516.5 Last Reading 10540 10540 header data for each bit run in separate files. 5 .5000 START DEPTH 10516.5 10516.5 10516.5 10516.5 10516.5 10516.5 10540.5 # 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 STOP DEPTH 13184.0 13184.0 13184.0 13184.0 13177.0 13184.0 13232.0 25-AUG-03 Insite 66.37 Memory 13232.0 10540.0 13232.0 81.3 94.1 TOOL NUMBER 160796 r" EWR4 $ EleJIIÞmag 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 Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 148574 . 6.125 10516.0 FloPro 9.50 53.0 8.5 51000 3.2 .110 78.0 .090 95.1 .130 77.0 .120 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10516.5 13232 11874.3 5432 10516.5 13232 ROP MWD050 FT/H 0.53 477.12 171. 45 5384 10540.5 13232 GR MWD050 API 35.5 123.65 76.7318 5322 10516.5 13177 RPX MWD050 OHMM 0.37 1319.16 22.6052 5336 10516.5 13184 RPS MWD050 OHMM 4.81 2000 31.4588 5336 10516.5 13184 RPM MWD050 OHMM 4.62 1497.95 29.4814 5336 10516.5 13184 RPD MWD050 OHMM 5.59 2000 30.4394 5336 10516.5 13184 FET MWD050 HOUR 0.19 123.16 1.03139 5336 10516.5 13184 First Reading For Entire File......... .10516.5 ~ þ Last Reading For Entire Fil~....... .13232 . File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/13 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/13 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. . . . . . . . . . . . . . . . . . . . .03/10/13 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