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202-024
1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Convert to FWD Circ. JP 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 12,998'N/A Casing Collapse Conductor N/A Surface 3,090psi Surface 4,760psi Intermediate 5,410psi OA Liner 7,500psi OB 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: Brian Glasheen Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 6,870psi 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY Brian.Glasheen@hilcorp.com 907-564-5277 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: 6.5# / L-80 / EUE 8rd 8,011' 3/16/2023 N/A and N/A N/A and N/A STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025906 & ADL0380109 202-024 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-22597-01-00 Hilcorp Alaska LLC SCHRADER BLUFF OILN/A C.O. 477.05 MILNE PT UNIT H-07A Length Size Proposed Pools: 116' 116' TVD Burst PRESENT WELL CONDITION SUMMARY 4,140' 12,613' 4,125' 1,020 N/A 80' 20" MILNE POINT 8,430psi MD N/A 8,430psi 5,750psi 7,240psi 3,882' 4,232' 4,145' 7,406' 9,203' 4,125'12,613' 10,104' 8,149' 4,056' 9-5/8" 7" 7,375' 9,171' Perforation Depth MD (ft): 4-1/2"1,385' 743' 9-5/8" See Schematic 3,529' See Schematic 2-7/8" 4-1/2" Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 10:19 am, Mar 03, 2023 323-129 Digitally signed by David Haakinson (3533) DN: cn=David Haakinson (3533), ou=Users Date: 2023.03.03 10:01:13 -09'00' David Haakinson (3533) SFD 3/6/2023 DSR-3/3/23 10-404 * BOPE pressure test to 2500 psi. Maximum header injection pressure <= 2500 psi. * Variance to 20 AAC 25.265 (c)(1) approved for annular flow SSV in horizontal produced fluid line. SSV also required for power fluid in vertical run of tree. * Produced fluid through IC annulus considered unconventional, BHP to remain below 8.55 ppg to remain on production. Well fails Finding #8 CO390A for monitorable OA will require forward circulating jet pump. * Approved for forward circulating jet pump only. * SSV trip pressures on tubing to be set no higher than 2650 psi. * Tubing SSV low pressure trip pressure not to be below 1300 psi. * IA SSV low pressure trip not to be below 75 psi. * SSV closure on IA will initiate immediate closure on tubing SSV and visa versa. * Quadrennial MIT on inner casing to 2000 psi. 1,020 MGR27APR22GCW 04/28/23 4/28/2023 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2023.04.28 08:35:55 -08'00' RBDMS JSB 050123 Convert to JP Well: MPU H-07 Well Name:MPU H-07 API Number:500292259701 Current Status:SI Oil Well (failed ESP)Pad:H-Pad Estimated Start Date:March 16th, 2023 Rig:ASR #1 Reg. Approval Req’d?Yes Date Reg. Approval Rec’vd: Regulatory Contact:Tom Fouts Permit to Drill Number:202024 First Call Engineer:Brian Glasheen 9075451144 Second Call Engineer:Taylor Wellman (907) 777-8449 (O) (907) 947-9533 (M) AFE Number:232-00102.08.02 Job Type:Convert to JP Current Bottom Hole Pressure:1,424 psi @ 4043 TVD Downhole Gauge: S-34 analog|6.8 PPG Maximum Expected BHP:1,424 psi @ 4043’ TVD Downhole Gauge:|6.8 PPG MPSP:1020 psi Gas Column Gradient (0.1 psi/ft) Min ID 2.205 @ 7917’ MD Brief Well Summary: H-07A was drilled and completed as a dual lateral Oa/Oba producer in March 2002. It was sidetracked within 200’ of the original H-07 producer which was a vertical N and O sands producer. The original H-07 producer was completed in January 1997 and had separate frac packs in both the Oba and Oa sands which were produced for 3 months via ESP. After the test period the ESP was pulled and the Nc and Nb sands were frac’d separately with “prop lock” in an attempt to keep the formation sand from being produced. The well produced for 3 years at which time the N sands appeared to have sanded up the well. The ESP was pulled and replaced in H-07A in September, 2004. The well was SI in September of 2006 from what appeared to be hydrate and or solids plugging of the ESP. Multiple slickline and pumping attempts were made to restore production. Production appeared to have been restored in October of 2007 until the ESP failed in December. The ESP was pulled in March of 2008. During the RWO a mule shoe was run and washed down to 8909’ (Oa lateral window was at 8695’) and were unable to make it past that depth. No further work was attempted to make it past that depth and a new ESP was run. The well was SI in February of 2009 for unknown reason with a surface casing mitigation work done in October of that same year. Production was restored in September of 2009 until April of 2011 when it appears the ESP plugged up after inability to squeeze through pump. A RWO was performed in June of 2013 to replace the ESP. A broken shaft and bad ESP cable were found to be the culprit of the failure. During the RWO a cleanout BHA was run down to 9080’ MD (Oba liner top packer). The well produced for ~3 months where it appeared the ESP plugged as attempts were made to pump in and were only able to get 0.1 bpm at 2000 psi. In October of 2019 3 bbls of diesel was pumped down tubing with no pressure gain indicating well was open to formation. An additional 9 bbls were pumped and the well pressured up to 1000 psi and bled down 60 psi in 30 min. Assuming there is restriction in tubing or ESP. An attempt was then made to start the ESP was unsuccessful as confirmed well was grounded downhole. Notes Regarding the Well & Design x The 9-5/8’’ casing passed to 2,500 psig prior to drilling window on 3-5-2002. x 7’’ casing tested to 3500 psi 3/12/2002 prior to drilling OB lateral. x 7’’X9-5/8’’ annulus cemented to surface during drilling 3/9/2002. 91 bbls cement returned to surface. Convert to JP Well: MPU H-07 x MIT-OA failed to 1500psi 1/25/2023. Pumped 1.2 bbls to pressure up to 1500 psi. Pressure would bleed off not stabilize. No fluid to surface observed and pressure communication was not observed between IA. Final pressures T=830 psi/ IA=834 psi/ OA 50 psi Planned SSV Pilot Settings and MIT Schedule x Injection tubing SSV high pressure trip will not exceed 2650 psi x Injection tubing SSV low pressure trip will not to be below 1300 psi x IA SSV high pressure trip not to exceed 650 psi x IA SSV low pressure trip not to be below 75 psi x Quadrennial CMIT-TXIA to 2000 psi Objective: x Pull ESP completion. x Run new 3-1/2” Forward Circulating JP completion to allow JP swaps via pump in pump out. x Hilcorp Alaska, LLC requests a variance to 20 AAC 25.265(c)(1) to operate a surface safety valve (SSV) that is not located in the vertical run of the tree on Milne Point Unit (MPU) well H- 07A (PTD# 202024) x A conventional forward circulation jet pump is being run in this well due to high deviation that is unreachable by slickline for jet pump changeouts. Pre-Rig Procedure: Coil: 1. MIRU Coiled Tubing Unit and spot ancillary equipment. 2. Pressure test BOPE to 3,000 psi Hi 250 Low, 10 min Hi, 5 min Low each test. 3. if within the standard 7-day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. 4. Each subsequent test of the lubricator will be to 3,000 psi Hi 250 Low to confirm no leaks. 5. RIH to top of ESP at 7960’ and circ well to water. POOH to 2500’ and circ FP while POOH 6. RIH with 5’ of tubing punch tag top of pump at 7960’ PU 20’ and punch tubing to allow circulation path. SL: 7. RIH DMY GLM at 168’MD. 8. Caliper well from as deep as possible to surface Well Support- 9. Clear and level pad area in front of well. Spot rig mats and containment. 10. RU Little Red Services. RU reverse out skid and 500 bbl returns tank. 11. Pressure test lines to 3,000 psi. 12. Circulate at least one wellbore volume with source or produced water 8.4 ppg down tubing, taking returns up casing to 500 bbl returns tank. a. Returns will likely not be seen. After attempting circulation down the tubing, bullhead and load the tubing and IA. 13. RD Little Red Services and reverse out skid. Convert to JP Well: MPU H-07 14. RU crane. Set CTS BPV. ND Tree. NU BOPE. RD Crane. 15. NU BOPE house. Spot mud boat. RWO Procedure: 16. MIRU Hilcorp ASR #1 WO Rig, ancillary equipment and lines. 17. Check for pressure and if 0 psi. If needed, bleed off any residual pressure off tubing and casing. If needed, kill well w/ 8.4 ppg prior to setting CTS Plug. Set CTS Plug. 18. Test BOPE to 250 psi Low/ 2,500 psi High, annular to 250 psi Low/ 2,500 psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. a. Perform Test per ASR 1 BOP Test Procedure b. Notify AOGCC 24 hours in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test VBR rams on 2-7/8’’ and 3-1/2’’ test joints. e. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 19. Contingency: (If the tubing hanger won’t pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.) a. Notify Operations Engineer (Hilcorp), Mr. Mel Rixse (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness test. b. With stack out of the test path, test choke manifold per standard procedure c. Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d. Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e. Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f. Record and report this test with notes in the remarks column that the tubing hanger/BPV profile / penetrator wouldn’t hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 20. Bleed any pressure off casing to the returns tank. Pull CTS, lubricate if pressure expected. Kill well as needed. 21. MU landing joint or spear and BOLDS. 22. Attempt to pull tubing. a. 2013 RWO PUW= 87k and SOW=65k Weight includes 40k for blocks b. Do not exceed 80 percent of 2-7/8” tubing tensile rating 84 Klbs (Yield at 100% 105 Klbs) c. RU spooler for ESP Cable and heat trace. 23. Recover the tubing hanger. Contingency (If a rolling test was conducted): MU new hanger or test plug to the completion tubing. Re-land hanger (or test plug) in tubing head. Test BOPE per standard procedure. 24. POOH and lay down the 2-7/8’’ tubing. a. Tubing will be reused based on pre RWO caliper. b. Ensure all clamps are recovered 2013 RWO noted c. Total clamps= i. 1 motor protectorlizer ii. 3 pump protectorlizers iii. 3 Armsterguards Convert to JP Well: MPU H-07 iv. 4 Cannon 400 series body clamps on the equipment v. 1 Cannon half clamp on discharge sub below MLE splice vi. 74, 2875-A-24 cross collar cannon clamps vii. 118, 2875-A-02/24DC 24" cross collar cannon clamps on Heat Trace viii. 532, 2875-60-C-02-24FDC, 5' Cannon Clamps on Heat Trace ix. 2 1 1/2" CS bands on Heat Trace Terminator 17) MU 7” casing scraper BHA and TIH w/ 3-1/2” workstring to ±8000’ MD. 18) POOH and reciprocate the 7” scraper across the following interval. a. 7600-7800 MD 19) POOH and LD scraper BHA. 20) PU 7’’ test packer and RIH on work string to ±7800’ MD. 1. Set Packer and test 7” casing to 3000 psi ( H pad PF header pressure is 2500 psi) 2. If fails PU to 200 feet and retest. 3. Call OE if no passing test. 25. RU to run 3-1/2”, forward circulating JP completion. 26. PU and MU the following completion. a. A check valve will be used in the 2-7/8’ nip. Hole fill will be required down the backside. b. After 500’ of tubing is RIH fill tubing with diesel. Fill tubing every joint until 20 bbls is reached. This is for proper freeze protect when landed. Colors indicate assemblies to be bucked up prior to RWO. Nom . Size Length Item Lb/f t Materia l Notes 1 WLEG L-80 2- 7/8''30 Joint 6.5 L-80 2- 7/8''10'Pup Joint 6.5 L-80 2- 7/8''3'2-7/8 XN Nip with cat standing valve to set packer 6.5 L-80 Josh and or Derek to provide. 2- 7/8''10'Pup Joint 6.5 L-80 2- 7/8''30 1 joint 6.5 L-80 4.5''10'XO 4.5'' to 2-7/8 '' Joint 9.2 L-80 4.5'' 7” X 4-1/2” Packer 9.2 L-80 Baker Prem ~ 7700' MD 3.5''10' XO 3.5'' to 4.5'' Joint 9.2 L-80 3.5'' 1 joint 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 3.5''BHP Gauge 9.2 L-80 3.5''10'Pup Joint 9.2 L-80 3.5'' 1 joint 9.2 L-80 Utilize heavier brine or heated sea water if concerned about freezing. Risk of U-tubing on diesel too great. Keep hole full on annulus or pump at a rate to not allow gas migration. Same fluid on tubing to assure balance. - mgr Check valve does not allow flow from tubing to annulus. - mgr Convert to JP Well: MPU H-07 3.5''10'Pup Joint 9.2 L-80 3.5'' Champion X Forward circulating BHA with Blanking sleeve installed 9.2 L-80 Blank off ports for Tech wire. Blanking Sleeve MIN ID = 1.718" 3.5''10'Pup Joint 9.2 L-80 3.5''Joints 9.2 L-80 3.5''Space out PUPS 9.2 L-80 3.5'' 1 joint 9.2 L-80 3.5''PUP 9.2 L-80 3.5''Tubing Hanger 9.2 L-80 27. Space out and land packer ~7700’md. 28. Land tubing hanger. Make final splice of the TEC wire and ensure any unused control line ports are dummied off. a. Note PU (Pick Up) and SO (Slack Off) weights on tally 29. Pump 70 bbls of seawater 1% KCL with Corrosion inhibitor down the IA taking returns to formation. This is to protect the area between the packer sliding sleeve. a. Pump an additional 75 bbls of 8.3 ppg water followed by 58 bbls of Diesel to space inhibited pill between the packer and sleeve. 30. Set the packer as per Bakers setting procedure 31. Pressure up and test the tubing using diesel to 3000 psi for MIT-T with 0 psi on the IA (This will serve as the PF MOASP pressure test). Bleed off the tubing to 0 psi. Test the IA to 3000 psi for MIT-IA. Record and notate all pressure tests (30 minutes) on chart. 32. Set the BPV. 33. RD ASR 34. ND BOPE. 35. Install the CTS plug. 36. NU the tubing head adapter and NU 5M tree to accommodate a forward circulating jet pump. 37. PT the tubing hanger void to 500/5,000 psi. PT the tree to 250/5,000 psi. a. Pump 55 bbl diesel freeze protect down the IA prior to setting packer. 38. Pull the CTS plug and BPV. 39. Secure the well. Post-Rig Procedure: COIL TUBING: 40. MIRU Coiled Tubing Unit and spot ancillary equipment. 41. Pressure test BOPE to 3,000 psi Hi 250 Low, 10 min Hi, 5 min Low each test. a. if within the standard 7-day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient. b. Each subsequent test of the lubricator will be to 3,000 psi Hi 250 Low to confirm no leaks. 42. RIH and pull blanking sleeve from forward circulating BHA, POOH Blanking sleeve allows direct communication from tubing to IA. - mgr If needed to freeze protect tubing will need to pull blanking sleeve to circ freeze protect and corrosion inhibitors to IA and tubing. -mgr bullheading Convert to JP Well: MPU H-07 43. RIH pull check valve in 2-7/8’’ nip 44. RIH with JSN and GR/CCL and perform a FCO using N2 to TD taking returns to tanks or portable separator. a. Note MIN ID of 2.-78 XN nip below packer. 45. RIH and set 2-7/8’’ check valve in Nip. This will act as the forward circulating JP check 46. Drop 13A Jet pump with no check valve and confirm a good set. If JP does not land in BHA call OE to troubleshoot. 47. POOH with coil freeze protecting the TBG from 2,500’ MD to surface. 48. RD Coil. 49. Turn well over to production via handover form. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. ASR BOP stack sketch 4. 20 AAC 25.265(c) variance request 5. Proposed Tree Configuration 6. Coiled Tubing Nitrogen Diagram on POOH. Displace tubing and IA with power fluid after FCO. POOH. RIH with service coil. - mgr With service coil out of the well. - mgr . POOH. - mgr _____________________________________________________________________________________ Revised By: STP 2/3/20 23 SCHEMATIC Milne Point Unit Well: MPU H-07A Last Completed: 6/16/2013 PTD: 202-024 TD =11,316’(MD) / TD = 4,203’(TVD) 20” ES Cementer @ 2,149’ 9 12 “OA” 9-5/8”7” PBTD =10,104’(MD) / PBTD =4,145’(TVD) Heat Trace to 3,428’ 1 3 5 11 2 6 4&5 10 Orig. RT Elev.: 65.9’/ Orig. GL Elev.: 36.10’ RT to 9-5/8” Hanger= 30.6’ (Nabors N22E) 7 & 8 Whipstock @ 8,164 & 9/5/8” Cement Retainer @ 8,165’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / Welded N/A Surface 116' 9-5/8” Surface 40 / L-80 / BTC 8.835 Surface 7,406’ 9-5/8" Intermediate 47 / L-80 / BTC 8.681 7,406’ 8,149’ 7” Liner “A” 26 / L-80 / BTC-Mod 6.276 6,182’ 9,905’ 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.992 8,719’ 10,104’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.992 9,092’ 12,613’ TUBING DETAIL 2-7/8” Tubing 6.5 / L-80 / EUE 8rd 2.441 Surf 5,916’ LINER DETAIL 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.992 8,766’ 10,061’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.992 9,191’ 12,613’ JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 168’ST 2: 2-7/8” x 1” KBMM GLM w/ Dual Screen Orifice 2 7,917’ 2-7/8” XN Profile (2.205” No-Go Packing Bore ID) 3 7,960’ Discharge Head: 400 FPDIS 4 7,961’ Pump #2: 400 PMSXD, Type- 124 P4 5 7,974’ Pump #1: 538 PMSXD, Type- 18 P75 6 7,981 Gas Separator: GRSFTXARH6 7 7,986’ Upper Tandem Seal: GSB3DBUT SB/SB PFSA 8 7,992’ Lower Tandem Seal: GSB3DBLT SB/SB PFSA 9 7,999’ Motor: CL4" MSP1-200, 100Hp/2,300V/26A 10 8,007’ Sensor: SLB PHOENIX XT-150 w/ Centralizer-Btm@ 8,011’ 11 8,695’ 7” Baker Wall Hanger 12 9,083’ 7” x 5” ZXP Liner Top Packer w/ Tie Back & Hanger OPEN HOLE / CEMENT DETAIL 20" 250sx of Arcticset I in 24” Hole (Approx) 10-3/4"1,484sx PF “E”, 747sx Class “G”, 50sx Class ‘G’ in 12-1/4” Hole 7-5/8”240sx “L”, 176sx ‘G’, Top Job: 265sx ‘G’ in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ MD Angle Passes 50° @ 3,500’ Angle @ XN Nipple is 78° Max Wellbore Angle = Horizontal TREE & WELLHEAD Tree 2-9/16” – 5M CIW Wellhead 11” 5M FMC Gen 5 PBU w/ 7-1/6” x 2-7/8” FMC Tbg.Hgr., 8rd EUE Thrds Top & Btm. CIW H BPV Profile. GENERAL WELL INFO API: 50-029-22597-01-00 Drilled and Cased by Nabors 22E – 3/31/2002 ESP Completion by Nabors 4ES – 9/17/2004 ESP Completion by Nabors 3S – 3/8/2008 ESP Change-out by Doyon 16 – 6/16/2013 LATERAL WINDOW DETAIL Window in 9-5/8” Casing 8,149’ to 8,164’ Window in 7” Casing 8,707’ to 8,719’ _____________________________________________________________________________________ Revised By: TDF 3/3/20 23 PROPOSED Milne Point Unit Well: MPU H-07A Last Completed: 6/16/2013 PTD: 202-024 TD =11,316’(MD) / TD = 4,203’(TVD) 20” ES Cementer @ 2,149’ 7 “OA” 9-5/8” 7” PBTD =10,104’(MD) / PBTD =4,145’(TVD) Heat Trace to 3,428’ 1 3 6 2 5 4 Orig. RT Elev.: 65.9’/ Orig. GL Elev.: 36.10’ RT to 9-5/8” Hanger= 30.6’ (Nabors N22E) Whipstock @ 8,164 & 9/5/8” Cement Retainer @ 8,165’ CASING DETAIL Size Type Wt/ Grade/ Conn ID Top Btm 20" Conductor 91.1 / H-40 / Welded N/A Surface 116' 9-5/8” Surface 40 / L-80 / BTC 8.835 Surface 7,406’ 9-5/8" Intermediate 47 / L-80 / BTC 8.681 7,406’ 8,149’ 7” Liner “A” 26 / L-80 / BTC-Mod 6.276 6,182’ 9,905’ 4-1/2” Liner “A” 12.6 / L-80 / IBT 3.992 8,719’ 10,104’ 4-1/2” Liner “B” 12.6 / L-80 / IBT 3.992 9,092’ 12,613’ TUBING DETAIL 3-1/2” Tubing 9.2 / L-80 / EUE 8rd 2.992 Surface ±5,916’ LINER DETAIL 4-1/2” OA Slotted Lnr 12.6 / L-80 / IBT 3.992 8,766’ 10,061’ 4-1/2” OB Slotted Lnr 12.6 / L-80 / IBT 3.992 9,191’ 12,613’ JEWELRY DETAIL No Depth Item (Depths based on Nabors 4ES RKB) 1 ±7,650’ Champion X Forward Circ. BHA w/ Blanking Sleeve Installed 2 ±7,675’ BHA Gauge 3 ±7,700’ 7” x 4-1/2” Packer 4 ±7,750’ 2-7/8” XN Nipple w/ cat standing valve to set packer 5 ±7,800’ WLEG – Bottom @ ±7,802’ 6 8,695’ 7” Baker Wall Hanger 7 9,083’ 7” x 5” ZXP Liner Top Packer w/ Tie Back & Hanger OPEN HOLE / CEMENT DETAIL 20" 250sx of Arcticset I in 24” Hole (Approx) 10-3/4"1,484sx PF “E”, 747sx Class “G”, 50sx Class ‘G’ in 12-1/4” Hole 7-5/8”240sx “L”, 176sx ‘G’, Top Job: 265sx ‘G’ in 8-1/2” Hole WELL INCLINATION DETAIL KOP @ 600’ MD Angle Passes 50° @ 3,500’ Angle @ XN Nipple is 78° Max Wellbore Angle = Horizontal TREE & WELLHEAD Tree 2-9/16” – 5M CIW Wellhead 11” 5M FMC Gen 5 PBU w/ 7-1/6” x 2-7/8” FMC Tbg.Hgr., 8rd EUE Thrds Top & Btm. CIW H BPV Profile. GENERAL WELL INFO API: 50-029-22597-01-00 Drilled and Cased by Nabors 22E – 3/31/2002 ESP Completion by Nabors 4ES – 9/17/2004 ESP Completion by Nabors 3S – 3/8/2008 ESP Change-out by Doyon 16 – 6/16/2013 LATERAL WINDOW DETAIL Window in 9-5/8” Casing 8,149’ to 8,164’ Window in 7” Casing 8,707’ to 8,719’ Updated 8/11/2020 Milne Point ASR Rig 1 BOPE 2022 11” BOPE 4.48' 4.54' 2.00' CIW-U 4.30'Hydril GK 11" - 5000 VBR or Pipe Rams Blind11'’- 5000 DSA, 11 5M X 7 1/16 5M (If Needed) 2 1/16 5M Kill Line Valves 2 1/16 5M Choke Line Valves HCRManualManualHCR Stripping Head 2-7/8” x 5” VBR Milne Point Well H-07 Variance Request to 20 AAC 25.265 (c)(1) Hilcorp Alaska, LLC (“Hilcorp”) requests a variance from the requirement that the surface safety valve (SSV) be located within the vertical run of the well’s tree (20 AAC 25.265 (c)(1)) for the MP H-07 Schrader oil pool well that will be produced by normal flow jet pump. Hilcorp requests that the SSV be located within the horizontal run of the well tree as necessitated by normal flow jet pump operations. Placing the SSV in the horizontal run of the tree provides an equally effective method of complying with 20 AAC 25.265. Normal flow jet pump operation pumps high pressure power fluid down the tubing and the low pressure return fluid (reservoir and power fluid) is produced up the tubing by production casing annulus. Normal flow jet pumps changeouts can be accomplished without the use of slickline or coiled tubing as the jet pump can be reversed out using power fluid. The use of normal flow jet pumps: x Improves well uptime by allowing for jet pump change outs without having to schedule slickline (SL) or coiled tubing (CTU), x Reduces personnel exposure as Operations personnel can perform the changeout instead of using crewed SL and CTU units, and x Provides for cost savings due to reduced SL/CTU usage. x Improves Hydraulics for high rate wells. Proposed Tree Configuration: MPH-07 LEGEND:Fluids Pumped Valve Open Gate Valve 500 BBL KILL TANKChoke ManifoldP400 BBL UPRIGHTOpenVBRBLINDCOIL PUMP400 BBL UPRIGHTOpenClosedOpenOpenOpenOpenOpenOpenOpenPSWFOFRRE50 BBL FREEZEPROTECT TANKSWFOFRRETo FlowlineNITROGEN PUMP & TANPCOIL UNIT WITH 1.5” to 2.0” COIL400 BBL UPRIGHTSEAWATERW/DEFOAMERTRIPLEX STANDARDWELLPROCEDURE NITROGENOPERATIONS 01/08/2020FINALv1Page1of1 1.) MIRUNitrogenPumpingUnitandLiquidNitrogenTransport. 2.) NotifyPadOperatorofupcomingNitrogenoperations. 3.) PerformPreͲJobSafetyMeeting.ReviewNitrogenvendorstandardoperatingproceduresand appropriateSafetyDataSheets. 4.) Documenthazardsandmitigationmeasuresandconfirmflowpaths.Includereviewon asphyxiationcausedbynitrogendisplacingoxygen.Mitigationmeasuresincludeappropriate routingofflowlines,adequateventingandatmosphericmonitoring. 5.) SpotPumpingUnitandTransport.ConfirmliquidN2volumesintransport. 6.) RiguplinesfromtheNitrogenPumpingUnittothewellandreturnstank.Securelineswithwhip checks. 7.) PlacesignsandplacardswarningofhighpressureandnitrogenoperationsatareaswhereNitrogen mayaccumulateorbereleased. 8.) Placepressuregaugesdownstreamofliquidandnitrogenpumpstoadequatelymeasuretubing andcasingpressures. 9.) Placepressuregaugesupstreamanddownstreamofanycheckvalves. 10.) WellsiteManagershallwalkdownvalvealignmentsandensurevalvepositioniscorrect. 11.) Ensureportable4Ͳgasdetectionequipmentisonsite,calibrated,andbumptestedproperlyto detectLEL/H2S/CO2/O2levels.EnsureNitrogenvendorhasaworkingandcalibrateddetectoras wellthatmeasuresO2levels. 12.) PressuretestlinesupstreamofwelltoapprovedsundrypressureorMPSP(MaximumPotential SurfacePressure),whicheverishigher.Testlinesdownstreamofwell(fromwelltoreturnstank) to1,500psi.Performvisualinspectionforanyleaks. 13.) Bleedofftestpressureandprepareforpumpingnitrogen. 14.) Pumpnitrogenatdesiredrate,monitoringrate(SCFM)andpressure(PSI).Allnitrogenreturnsare toberoutedtothereturnstank. 15.) Whenfinalnitrogenvolumehasbeenachieved,isolatewellfromNitrogenPumpingUnitand bleeddownlinesbetweenwellandNitrogenPumpingUnit. 16.) Onceyouhaveconfirmedlinesarebleddown,notrappedpressureexists,andnonitrogenhas accumulatedbeginrigdownoflinesfromtheNitrogenPumpingUnit. 17.) FinalizejobloganddiscussoperationswithWellsiteManager.Documentanylessonslearnedand confirmfinalrates/pressure/volumesofthejobandremainingnitrogeninthetransport. 18.) RDMONitrogenPumpingUnitandLiquidNitrogenTransport. ) Image Project Well History File Cover 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. ~ O~ - 0 ~ Lf Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 uz(Rescan Needed 111111111111111111 RESCAN Ø'color Items: 0 Greyscale Items: DIGITAL DATA ~Diskettes, No, 4- 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: NOTES: BY: Helen (Maria) 0 Other:: Date: í I Scanning Preparation ~ x 30 = I (J() + Date II, 1. () tf- ~ 6 = TOTAL PAGES ~ [) 6~~~~t ;¡æ not (;"(t co~~r sheVì1P 1 ( 1111111111111111111 q ot 151 Vl1P . 1111111111111111111 151 vnP Project Proofing BY: Helen ('Maria ') BY: Helen (Maria) Production Scanning Stage 1 Page Count from Scanned File: '6 1 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES . Helen~ Date II, 9/0l{- If NO in stage 1, page(s) discrepancies were found: YES NO BY: NO 151 VVJ P Stage 1 BY: Helen Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III1IIIII1111111111 ReScanned 1111111111111111111 BY: Helen Maria Date: /s/ Comments about this file: Quality Checked III1III1I1111111111 8/24/2004 Well History File Cover Page.doc • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION CEIV ED REPORT OF SUNDRY WELL OPERATIONS Z 2013 1. Operations Performed: ❑Abandon ❑Repair Well ❑Plug Perforations ❑Perforate ❑Re-Enter Suspended el ❑Alter Casing ®Pull Tubing ❑Stimulate-Frac ❑Waiver ®Other ❑Change Approved Program ❑Operation Shutdown ❑Stimulate-Other ❑Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration(Alaska) Inc. • ❑Exploratory ❑Stratigraphic 202-024 • 3. Address: 4 IS Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-22597-01-00 • 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 025906&380109 MPH-07A - 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Milne Point Unit/Schrader Bluff • 11. Present well condition summary: Total depth: measured 1299$' feet- Plugs:(measured) None feet true vertical 4140' feet Junk:(measured) None feet Effective depth: measured 12613' feet Packer: (measured) None feet true vertical 4125' feet Packer: (true vertical) None feet Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 32'- 112' 32'- 112' 1490 470 Surface 8118' 9-5/8" 31'-8149' 31'-4056' 5750 3090 Intermediate Production 9171' 7" 32'-9203' 32'-4232' 7240 5410 Liner 3529' 4-1/2" 9084'-12613' 4228'-4125' 8430 7500 Perforation Depth: Measured Depth: Slotted Liner:9191'-12571' feet True Vertical Depth: Slotted Liner:4231'-4127' feet Tubing(size,grade,measured and true vertical depth): 2-7/8",6.5# L-80 8011' 4026' Packers and SSSV(type,measured and true vertical depth): None None None 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: WOOD tVG I U 2013 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 110 76 172 280 199 Subsequent to operation: 108 100 97 220 199 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: ❑Exploratory ❑Stratigraphic Development ❑Service ®Daily Report of Well Operations 16. Well Status after work: • :4 Oil ❑Gas ❑WDSPL ®Well Schematic Diagram ❑GSTOR ❑WINJ ❑WAG ❑GINJ ❑SUSP ❑SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact: Sean McLaughlin,564-4387 N/A Email: Sean.McLaughlin @bp.com Printed Nam . Joe L s Title: Drilling Technologist Signature: 7k______. Phone: 564-4091 Date:JI 10!i3 Form 10-404 Revise 10/2012 V�F• A / 1' S it Original Only /" q-/3/113 F�I�DMS JUL 13 20�j • ;„2„„,,, „ „4„. , .„.„.„„ ,/,/7/ , / ,„ . 0 Y d 8 Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 `AFE TBD(1,680,000.00) Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/9/1995 12:00:00AM I Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 6/8/2013 00:00 - 18:30 18.50 MOB N WAIT PRE NEW CREW ON TOUR SPCC CHECKS,PRE-TOUR MEETING WAIT FOR MPH-07A PREP TO BE COMPLETED GENERAL MAINTENANCE AND 'HOUSEKEEPING CHANGE CABLE ON BEAVERLATOR j(EQUIPMENT ELEVATOR) DDI FIELD SUPERINTENDENT HELD IN DEPTH DISCUSSIONS WITH NEW CREW ON SAFETY TOPICS AND FOLLOWING PROCEDURES AS A RESULT OF THE ELEVATOR INCIDENT ON 7 I JUNE 2013, MOVING EQUIPMENT TO MPH-7 LOCATION. WELDER WORKING ON MISCELLANEOUS JOBS ON THE RIG. BRIDLE UP TO LOWER DERRICK.LOWER DERRICK THE RIG MOVE DELAYED DUE TO A FLOW-BACK JOB ON MPJ PAD. NOTIFY AOGCC AT 06:30 HRS VIA E-MAIL OF UPCOMING BOP TEST FOR WELL MPH-07. 18:30 - 21:30 3.00 MOB P PRE PJSM FOR MOVE FROM MP E PAD TO MP H ,PAD -NOTIFY MP OPS AND PAD OPERATOR -MOVE TO MP H-07A 21:30 - 00:00 2.50 MOB P PRE ARRIVE MPH PAD -PULL ON TO MP H-PAD -STAGE EQUIPMENT ON MP H PAD -REMOVE REAR BOOSTER WHEELS -JEFF JONES OF AOGCC WAIVED STATES RIGHT OF WITNESS FOR BOP TEST 6/9/2013 00:00 - 02:00 2.00 MOB P PRE SPCC CHECKS AND PRE-TOUR MEETING -BACK OVER BOP -INSTALL BOP ON STAND IN CELLAR 02:00 - 05:00 T 3.00 MOB P PRE PJSM RAISE DERRICK -BRIDLE UP -RAISE DERRICK -LAY MATS AROUND MPH-07 05:00 - 07:00 2.00 MOB P PRE PJSM BACK OVER MP H-07 -NOTIFY PAD OPERATOR -WSL AND TOUR PUSHER PRESENT -BACK RIG OVER MP H-07 it Printed 6/24/2013 11:05:35AM • • A ?;' North America-ALASKA B f ti .4.4,,,,'Operaon Summary Repo f Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 AFE TBD(1,680,000.00) I Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/9/1995 12:00:00AM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs ! Task Code NPT NPT Depth Phase Description of Operations (usft) _ 07:00 - 10:30 3.50 MOB P PRE TEST WELL HEAD PACK-OFFS I-FMC TECH TEST WELLHEAD IA X OA 1 HANGER TO 3700 PSI FOR 30 MINUTES -FMC POSITIVE PRESSURE PACK OFF TEST- ; !TUBING.(PPPOT-T)5000 PSI FOR 30 MINUTES. TUBING PRESSURE 0 PSI(BPV INSTALLED) r-FUNCTION TEST ALL LOCK DOWN SCREWS -IA PRESSURE 1175 PSI. OA PRESSURE 8 1 PSI I -POSITION CUTTINGS TANK 1 1 1-LOAD PITS WITH WATER. -RIG UP LITTLE RED SERVICES PUMP TRUCK I TO HEAT BRINE. NOTE:ACCEPT RIG AT 08:00 HRS SUNDAY 9 JUNE 2013. 10:30 - 13:00 2.50 MOB P PRE RIG UP LINES TO KILL MANIFOLD -RIG UP LINES TO KILL MANIFOLD AND WELL IN CELLAR AND TEST SAME. SPOT FLOW BACK TANK AND RIG UP LINES I t !TO THE CELLAR. i -RECEIVE WATER INTO PITS 13:00 16:00 3.00 MOB P PRE T I BUILD KILL WEIGHT BRINE. CIRCULATE WATER FROM RIG TO LITTLE RED TO HEAT WATER. LITTLE RED CIRCULATE AND HEAT WATER TO 120 DEG. I -ADD NACL TO WATER FOR KWF OF 8.5 PPG 1 !WHILE HEATING WATER. RIG EVACUATION DRILL.GOOD RESPONSE FROM RIG CREW AND THIRD PARTY CREWS. AAR REVEALED THAT IF THE DRILLER FAILS !TO ANNOUNCE THE DRILL OVER THE RIG HARMONY HUB THE TOOL PUSHER,WSL OR SCS WILL MAKE THE ANNOUNCEMENT. 16:00 - 18:00 2.00 WHSUR P DECOMP RIG UP AND TEST LUBRICATOR RIG UP LUBRICATOR AND TEST TO 250/ 3500 PSI FOR 5 MINUTES. -PULL BPV I 1 CONTINUE CIRCULATING AND HEATING BRINE WITH LRS. BRINE AT 8.5 PPG AND 120 DEG '18:00 - 19:30 1.50 KILLW P DECOMP 1 PJSM,WELL KILL WITH 8.5 PPG HEATED BRINE -WSL/TOOL PUSHER VERIFY VALVE ALIGNMENT. -SITP=850 PSI, SICP=1200, SIOA=0 PSI -BEGIN BLEEDING GAS @ 1830 HRS ! '-BLEED GAS IN IA FROM 1200 PSI TO 1000 PSI IN 35 MIN. , I -NO FLUID RETURNS. 1 CALL SUPERINTENDANT AND TOWN I ENGINEER 1 W DECISION MADE TO SECURE WELL AND 1 WAIT ON DAYLIGHT KILL I 1 I SITP-1150 PSI,SICP-1100 PSI,SIOA=0 119:30 - 00:00 4.50 KILLW N WAIT 1 DECOMP I WAIT ON DAYLIGHT KILL WITH WSL. 1-REVIEW WELL WITH RIG CREW. -PERFORM GENERAL RIG MAINTENANCE. Printed 6/24/2013 11:05:35AM I • • , - 1s Common Well Name:MPH-07 1 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 AFE TBD(1,680,000.00) Project:Milne Point ! Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/9/1995 12:00:00AM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. [UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1 6/10/2013 00:00 - 01:30 1.50 1 KILLW N I WAIT DECOMP SPCC CHECKS AND PRE-TOUR MEETING WAIT ON DAYLIGHT KILL WITH WSL. HOLD CONTROL OF WORK DISCUSSION WITH NIGHT CREW I -DISCUSS OPERATIONAL DISCIPLINE i-REVIEW WELL WITH RIG CREW 1 UPDATE KILL BOARD IN DOG HOUSE. PERFORM GENERAL RIG MAINTENANCE. 01:30 - 02:00 0.50 KILLW N WAIT I DECOMP EVACUATION DRILL 1 AAR: CREWAND THIRD PARTY EVACUATED IN TIMELY MANNER DISCUSSED ESD OF EQUIPMENT 'ACTION ITEM IS FOR CH2 VAC TRUCK DRIVER TO SHOW RIG CREW ESD OF TRUCK 02:00 - 06:00 4.00 KILLW N WAIT DECOMP WAIT ON DAYLIGHT KILL WITH WSL. -CREW BEGIN DEVELOPING SOP AND I PERFORM HAZARD ANALYSIS FOR PLACING AND REMOVING TUBULARS ,FROM LOADER BASKET -PERFORM GENERAL RIG MAINTENANCE 06:00 - 08:00 2.00 KILLW P DECOMP PJSM,WELL KILL WITH 8.5 PPG HEATED j ,BRINE -WSL/TOOL PUSHER VERIFY VALVE ALIGNMENT. -SITP=1150 PSI, SICP=1125, SIOA=0 PSI -BEGIN BLEEDING GAS AT 07:00 HRS FROM ' IA OUT TO FLOW BACK TANK -BLEED GAS IN IA FROM 1025 PSI TO 850 I PSI IN 30 MIN.NO FLUID RETURNS. 08:00 - 11:30 3.50 i KILLW P DECOMP KILL WELL WITH 8.5 PPG HEATED BRINE. I PUMPED 50 BBLS HEATED 8.5 PPG BRINE AT 3 BPM DOWN THE TBG THROUGH CHOKE SKID TO FLOW BACK TANK.NO FLUID RETURNS. ICP=3 BPM/1100 PSI. I I-CLOSE CHOKE AND BULLHEAD 50 BBL KWF 1 I DOWN TUBING. -PUMP AT 3 BPM AND 250 PSI ICP DROPPING TO 150 PSI FCP. ' BULL HEAD 550 BBL KWF AT 7 BPM DOWN 1 TUBING AND IA. -ICP ON IA 850 PSI BUILT TO 1150 PSI AND , FELL TO 500 PSI FCP. SIMULTANEOUSLY BULL HEAD DOWN TUBING. -ICP 250 PSI BUILD TO 750 PSI AND DROP TO 150 PSI FCP. PUMP OFF,SHUT-IN WELLAND OBSERVE PRESSURES FOR 30 MINUTES. -TUBING PRESSURE 300 PSI TO 150 PSI.IA PRESSURE 350 PSI TO 500 PSI.THE TUBING ISONAVAC. I CONSULT WITH TOWN ODE ON PATH ' FORWARD. 1 I DECISION MADE TO BUILD MORE 8.5 PPG :BRINE AND KILL WELL AGAIN USING THE , 1 1 I BULL HEAD METHOD AGAIN. Printed 6/24/2013 11:05:35AM • North America-ALASKA-BP _ §, ,� Operation Summary Report Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 AFE TBD(1,680,000.00) Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/9/1995 12:00:00AM Rig Release:6/16/2013 Rig Contractor.DOYON DRILLING INC. UW: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 15:00 3.50 KILLW P DECOMP BUILD 8.5 PPG BRINE VOLUME. -MIX BRINE IN PITS TO 8.5 PPG -VAC TRUCKS TRIPPING TO FILL UP WITH 8.5 PPG BRINE. -SET VAC TRUCKS AND CONNECT TO RIG. 15:00 - 18:00 3.00 KILLW P DECOMP 1 PJSM ON WELL KILL BLEED PRESSURE FROM IA IN 35 MINUTES 800 PSI TO 0 PSI. -BULL HEAD 250 BBL 8.5 PPG BRINE DOWN IAAT 5 BPM.NO PRESSURE FOR FIRST 100 BBL. -AFTER PUMPING 250 BBL DOWN IA,OPEN TUBING AND PUMP DOWN IA AND TUBING SIMULTANEOUSLY. PUMP ADDITIONAL 500 BBL. INCREASE PUMP RATE TO 7 BPM.ICP ON TUBING 500 PSI FCP 750 PSI ICP ON IA 100 PSI FCP 600 PSI. -STOP PUMP AND OBSERVE PRESSURES. IA AND TUBING DROPPED FROM 300 PSI AND 400 PSI TO 0 PSI IN 30 MINUTES. 18:00 - 18:30 0.50 KILLW P DECOMP PJSM,RIG DOWN KILL MANIFOLD. -BLOW DOWN ALL CIRCULATING LINE. RIG DOWN CIRCULATING LINES&KILL MANIFOLD -R/U SECONDARY KILL LINE. ATTEMPT TO ESTABLISH STATIC LOSS RATE PUMP 25 BBLS,NO RETURNS REGULATE HOLE FILL AT 20 BPH OF 8.5 PPG BRINE 18:30 - 19:30 1.00 WHSUR P DECOMP PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC -WAIT ON WS TO REPLACE WORN RUNNING I TOOL 1 19:30 - 21:00 1.50 WHSUR P DECOMP -M/U LUBRICATOR&TEST WITH DIESEL -250 PSI LOW AND 3500 PSI FOR 5 MINS EACH,CHARTED -SET TWC -UD LUBRICATOR. 21:00 - 21:30 0.50 WHSUR P DECOMP PRESSURE TEST TWO WAY CHECK -PERFORM ROLLING TEST BELOW TWC -PUMP DOWN IA©5 BPM AND 0 PSI FOR 3 MINS,REDUCE RATE TO 2.5 BPM AND 0 PSI- CHARTED -34 BBLS KWF PUMPED -TEST TWC FROM ABOVE,250 PSI LOW& 3500 PSI HIGH FOR 5 MINS EACH,CHARTED 21:30 - 22:30 1.00 WHSUR P DECOMP PJSM,N/D TREE -FMC HAND BLED DOWN TUBING HEAD ADAPTOR -N/D 2 9/16"5M CAMERON TREE -CHECK HANGER THREADS=2 7/8"8RD THREADS,9-1/2 RH TURNS - _ Printed 6/24/2013 11:05:35AM • • g;,' s, ' '¢ f' North America-ALASKA BP : �, U Operation Summary Report: „ Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 ,AFE TBD(1,680,000.00) Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/9/1995 12:00:00AM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations hr (usft) 22:30 - 00:00 1.50 WHSUR 1 P DECOMP PJSM,NIPPLE UP BOP -N/U 13-5/8"5M BOP STACK. INSTALL TURNBUCKLES AND FLOW NIPPLE. I I -RE-ENERGIZE ACCUMULATOR SYSTEM. 24 HR LOSSES TO WELL INCLUDING BOTH WELL KILLS=1430 BBLS 8.5 PPG BRINE -MAINTAIN CONTINUOUS HOLE FILL TO THE IA DURING TEST©-20 BPH,KWF JEFF JONES OF AOGCC WAIVED STATES RIGHT OF WITNESS FOR BOP TEST 6/11/2013 00:00 - 02:00 2.00 BOPSUR P 1 I DECOMP 'PJSM,MAKE SPCC AND EQUIPMENT CHECKS -FINALIZE NIPPLE UP BOP -RIG UP BOP TEST EQUIPMENT PJSM,TEST FOUR PREVENTER BOP AND RELATED EQUIPMENT 02:00 - 05:00 3.00 BOPSUR P DECOMP 'TEST BOP [-ATTEMPT TO TEST LOWER PIPE RAMS WITH � 2-7/8"TEST JOINT CONSISTENTLY LOSING 200 TO 300 PSI IN I 5 TO 10 MINS 4 ISOLATE TEST PUMP AND VERIFY SURFACE EQUIPMENT IS NOT LEAKING SUCK OUT STACK TO LOWER RAMS AND VISUALLY VERIFY NO LEAK BY FROM BELOW -PULL TEST JOINT AND CLEAN TOP OF TWC- SOME DEBRIS IN TWC PROFILE 4 -RE-ATTEMPT LOWER RAM TEST SAME RESULT - -RE-VERIFY SURFACE EQUIPMENT AND i LOWER RAMS WERE NOT LEAKING I -LAY DOWN 2-7/8"TEST JOINT -TEST BLIND RAMS 250 PSI LOWAND 3825 PSI HIGH -BLIND RAM HIGH TEST LEAK OFF TO 3550 PSI IN 15 MINS -VERIFY NO LEAKS FROM BELOW BLINDS -NO EXTERNAL LEAKS VISIBLE -JEFF JONES OF AOGCC WAIVED STATES RIGHT OF WITNESS TO THE BOP TEST 05:00 - 09:30 4.50 BOPSUR P DECOMP TEST SURFACE BOP EQUIPMENT -TEST FLOOR VALVES AND CHOKE 250 PSI LOWAND 3500 PSI HIGH,CHARTED. TEST AGAINST TUBING HANGER WITH RIG PUMP AT HIGH PUMP RATE TO 3000 PSI -MADE THREE ATTEMPTS.REPEAT TEST SLOW LEAK PRESSURED AGAINST TWC FROM ABOVE TO 200 PSI AND BLEED OFF PRESSURE QUICKLY. -MADE THREE ATTEMPTS.REPEAT TEST, SLOW LEAK CONTINUOUSLY ADDING 8.5 PPG BRINE DOWN ANNULUS AT 20 BPH Printed 6/24/2013 11:05:35AM • • ' North America-ALASKA BP .. � .,F, Operatign Summary Report', Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date.6/16/2013 AFE TBD(1,680,000.00) Project Rig Name/No.:DOYON 16 I Spud Date/Time:9/9/1995 12:00:00AM Milne Point Site:M Pt H Pad O:OOAM Rig Release:6/16/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 10:30 1.00 BOPSUR P DECOMP TEST ISOLATED TWC -MADE UP 2 7/8"LANDING JOINT INTO TUBING HANGER. I-PRESSURE TEST DOWN LANDING JOINT TO ISOLATED TWC.PRESSURE HELD 3500 PSI FOR 5 MINUTES. I 'CONTINUOUSLY ADDING 8.5 PPG BRINE DOWN ANNULUS AT 20 BPH 10:30 - 11:30 1.00 WHSUR P , DECOMP RE TORQUE LOCK DOWN SCREWS ON TUBING HANGER. FMC TECH RE TORQUED ALL THE LOCK DOWN SCREWS. 1-INCREASE TORQUE FROM 450 TO 500 FT/LBS CONTINUOUSLY ADDING 8.5 PPG BRINE DOWN ANNULUS AT 20 BPH 11:30 14:00 2.50 BOPSUR ` P DECOMP 'ii TESTED LOWER PIPE RAMS WITH 2 7/8"TEST JOINT AGAINST THE TUBING HANGER. I I -TEST PIPE RAMS TO 250/3500 PSI FOR 5 MINUTES EACH. -CONTINUE WITH BOP TEST. -TESTANNULAR PREVENTOR.TEST FAILED. CONTINUOUSLY ADDING 8.5 PPG BRINE DOWN ANNULUS AT 20 BPH 14:00 - 15:00 1.00 BOPSUR ;P DECOMP CONTINUE TESTING REMAINING BOP RAMS. ALL PASS EXCEPT FOR ANNULAR. CONDUCT ACCUMULATOR UNIT TEST. TEST IS WITNESSED BY WSL,TOOLPUSHER AND MOTORMAN. 15:00 - 20:30 5.50 BOPSUR N SrAt DECOMP tPJSM FOR CHANGING OUT ANNULAR ELEMENT -MOBILIZE EQUIPMENT AND REMOVE HYDRIL TOP CAP -INSPECT SEALS AND CLEAN INNER 1 HOUSING -CHANGE OUT ANNULAR ELEMENT AND i I RE-ASSEMBLE -FUNCTION TEST ELEMENT 20:30 - 21:30 1.00 BOPSUR P DECOMP INSTALL 2 7/8"TEST JOINT,R/U TEST EQUIPMENT I-TESTANNULAR,250 PSI,3500 PSI,5 MIN -TEST WAS UNSUCCESSFUL -M/U LANDING JOINT TO ISOLATE AND TEST AGAINST TWC=GOOD TEST 21:30 - 22:00 0.50 BOPSUR P DECOMP FMC REP ADD TORQUE TO LDS -TORQUE FROM 500 TO 550 FT/LBS 22:00 - 22:30 0.50 BOPSUR P DECOMP TEST ANNULAR WITH 2 7/8"TEST JOINT -250/3500 PSI,5 MIN CHARTED=GOOD ' ITEST 22:30 - 23:00 0.50 i BOPSUR P DECOMP R/D TEST JOINT AND TEST EQUIPMENT -DRAIN/VAC FRESH WATER FROM BOP ISTACK Printed 6/24/2013 11:05:35AM I • � North America-ALASKA-BP x /Fr 'r f Operation Summary Report: Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) I Start Date:6/8/2013 I End Date:6/16/2013 :AFE TBD(1,680,000.00) Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud DateTme:9/9/1995 12•00:00AM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (usft) 23:00 - 00:00 1.00 WHSUR P DECOMP PJSM WITH DSM TO R/U AND PULL TWC -M/U DSM OFF-SET LUBRICATOR TO HANGER -CLOSE ANNULAR AND TEST,250/3500 PSI, 5 MIN,CHARTED,GOOD TEST -24 HOUR FLUID LOSS=465 BBL 8.5 BRINE MAINTAIN CONTINUOUS HOLE FEED OF 8.5 PPG BRINE DOWN ANNULUS AT 20 BPH 6/12/2013 00:00 - 00:30 0.50 WHSUR P DECOMP `PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -DSM REP PULL TWC,WELL IS ON A VACUUM -R/D DSM OFF-SET LUBRICATOR AND TOOLS -CLEAR RIG FLOOR 00:30 - 02:00 1.50 PULL P DECOMP 1PJSM TO PULL HANGER TO RIG FLOOR -M/U LANDING JOINT WITH FOSV TO HANGER -WSL ENSURE NO PRESSURE UNDER HANGER -FMC REP BACK OUT LOCK DOWN SCREWS -PILL HANGER TO RIG FLOOR,PUWT=87K SOWT=67K(INCLUDES 40K BLOCK WEIGHT -CUT ESP CABLE AND HEAT TRACE AT BOTTOM OF FIRST FULL JOINT -PLACE SLICK PIPE ACROSS BOP STACK -L/D LANDING JOINT,INSTALL FOSV AND CIRCULATING LINE IN HANGER -CLOSE ANNULAR 02:00 - 02:30 0.50 CASING P DECOMP BULLHEAD 1 TUBING VOLUME,50 BBLS • DOWN TUBING -3 BPM=280 PSI -HANG ESP SHEAVE IN DERRICK IN PREP FOR POH 02:30 - 03:00 0.50 CASING P DECOMP WSL ENSURE NO PRESSURE BELOW ANNULAR -OPEN ANNULAR AND MONITOR WELL,WELL IS ON VAC -FMC REP INSPECT HANGER,REMOVE PENETRATORS FROM HANGER -MAINTAIN CONTINUOUS HOLE FEED OF 8.5 PPG BRINE DOWN ANNULUS AT 20 BPH 03:00 - 06:00 3.00 PULL P DECOMP PJSM,PULL COMPLETION AND STRING ESP AND HEAT TRACE THRU SHEAVE TO SPOOLING UNIT -PULL 2 7/8"6.5#8RD ESP COMLPETION WITH HEAT TRACE FROM 8097' 06:00 - 08:30 2.50 PULL P DECOMP CONTINUE PULLING ESP COMPLETION WITH HEAT TRACE. AT STAND#19 SEE AROUND 10K EXTRA DRAG FOR A SHORT TIME,THEN BACK TO NORMAL WEIGHT. Printed 6/24/2013 11:05:35AM • • „A Operation Summary Re•ort Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 AFE TBD(1,680,000.00) Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 1 Spud Date/Time:9/9/1995 12:00:00AM Rig Release:6/16/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) : 08:30 - 09:30 1.00 PULL P DECOMP AT STAND#20 DRILLER NOTICES ESP CABLE I HAS STOPPED MOVING OUT OF HOLE ALONG I WITH THE PIPE. STOP PULLING PIPE,DISCUSS WITH ODE AND RWO SUPT. DECIDE TO ADD 1%SAFELUBE TO THE BRINE 1 AND PUMP IT DOWNHOLE. ATTACH TUGGER TO THE ESP CABLE,PULL UP ABOUT 15 FT OF SLACK CABLE FROM WELL WITH PIPE STATIONARY,THEN USE TUGGER TO HELP PULL ANOTHER STAND I , LENGTH OF CABLE OUT WITH THE PIPE 1:1. :09:30 - 13:00 3.50 PULL P DECOMP CONTINUE PULLING COMPLETION USING SPOOLER ALONE TO PULL ESP CABLE. CABLE ON STANDS#21/22 IS SEEN TO BE I KINKED AND ARMOR IS DAMAGED. DAMAGE CLEANS UP AFTER 1 MORE STAND. 'CONTINUE PULLING COMPLETION, REPLACING JOINTS AS NEEDED. 13:00 - 17:30 4.50 PULL P : DECOMP I REACH END OF HEAT TRACE AT STAND#35. REMOVE FROM PIPE AND REEL IT BACK I ONTO SPOOLING UNIT. CONTINUE PULLING ESP COMPLETION, r_ !STAND BACK IN DERRICK. 17:30 20:00 2.50 PULL P DECOMP I DRAIN,BREAK DOWN AND L/D ESP MOTOR ASSY -BROKEN SHAFT FOUND IN MOTOR AND BAD I ESP CABLE 20:00 - 21:00 1.00 PULL i P DECOMP 1 PJSM,R/D ESP TRUNK AND SHEAVE ' -CLEAR AND CLEAN RIG FLOOR 21:00 - 22:00 1.00 EVAL P DECOMP PJSM,SET TEST PLUG INSTALL DUTCH RISER SYSTEM -R/U AND FILL HOLE THROUGH IA 22:00 - 00:00 2.00 EVAL P DECOMP PJSM WITH WSL,ALL RIG HANDS AND SWS WIRELINE ON R/U AND RUN CALIPER LOG I-MOBLIZE SWS LUBRICATOR AND TOOLS TO RIG FLOOR -R/U FULL PRESSURE CONTROL EQUIPMENT -24 HOUR FLUID LOSS=565 BBL 8.5 BRINE -MAINTAIN CONTINUOUS HOLE FEED OF 8.5 PPG BRINE DOWN ANNULUS AT 25 BPH 6/13/2013 00:00 - 02:30 2.50 EVAL P DECOMP I PJSM WITH RIG HANDS AND SWS WIRELINE ON R/U AND RUN CALIPER LOG -PERFORM SPCC AND EQUIPMENT CHECKS I -R/U SWS FULL PRESSURE CONTROL LUBRICATOR AND EQUIPMENT MAINTAIN CONTINUOUS HOLE FEED OF 8.5 j PPG BRINE DOWN ANNULUS AT 25 BPH 02:30 - 03:00 0.50 EVAL P DECOMP 'PRESSURE TEST SWS LUBRICATOR -250 13500 PSI,5 MIN,CHARTED=GOOD TEST 03:00 - 03:30 0.50 EVAL P DECOMP 1 PULL SWS LUBRICATOR AND DUTCH RISER 'SYSTEM TOGETHER PULL TEST PLUG AND INSTALL 9"ID WEAR RING I -RE-INSTALL LUBRICATOR AND DUTCH ' RISER Printed 6/24/2013 11:05:35AM • • North America-MAO.* Operation Summary Report r Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 AFE TBD(1,680,000.00) Project Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/9/1995 12:00:OOAM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING©66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase 1 Description of Operations (hr) (usft) I 03:30 - 04:00 0.50 EVAL P , DECOMP BREAK LUBRICATOR OFF AT QUICK TEST SUB -M/U SWS BHA RUNNING TOOLS AND PDS CALIPER •-M/U LUBRICATOR AT QUICK TEST SUB AND TEST CONNECTION 04:00 - 06:00 2.00 EVAL P DECOMP RIH 7"26#CASING,WITH PDS LOGGING I `TOOL TO 1000' LOG UP FROM 1000'TO SURFACE WITH i PDS CALIPER/MEMORY TOOL 06:00 - 08:00 2.00 EVAL P DECOMP i POOH WITH LOGGING TOOLS. DOWNLOAD TOOL DATA. GOOD DATA WITH NO OBVIOUS ANOMALIES. I START RIG DOWN PDS AND SLB SLICKLINE I EQUIPMENT. 08:00 - 14:00 6.00 CASING P DECOMP PJSM FOR M/U CLEANOUT ASSEMBLY. MAKE UP CLEANOUT ASSEMBLY WITH 84 STANDS 2-7/8"TUBING WITH 12 STDS 4" _, DRILL PIPE. STOP AND MAKE UP DRILL PIPE SINGLES FROM THE PIPE SHED INTO STANDS,SO -, iCLEANOUT CAN BE DONE WITH STANDS. 14:00 - 15:00 1.00 CASING ' P DECOMP •STOP AFTER ALL 2-7/8"IS RUN TO CUT AND ISLIP DRILLING LINE. l PUMP 1 TUBING VOLUME DOWN TUBING AT 5 BPM,990 PSI. CUT OFF 62 FT OF DRILL LINE. 15:00 17:00 2.00 CASING P DECOMP I CONTINUE M/U DRILL PIPE FROM DERRICK. FIRST STAND IS 72K UP WT,60K DOWN. WASH DOWN AT 6 BPM,GET PARTIAL RETURNS 1-2 BPM AFTER 66 BBLS AWAY. i I CONTINUE WASHING DOWN EACH STAND. WEIGHT CHECK AT 8890 FT IS 75K UP, • SMOOTH PICKUP. 17:00 - 17:30 0.50 CASING P DECOMP ',AT TD OF 9080 FT. PICKUP IS 90K,SMOOTH. I PUMP 6 BPM HERE,GETTING 1-2 BPM BACK. • PUMP A VISCOUS SWEEP AROUND TO TRY • I AND IMPROWE RETURNS. I SWEEP COMES AROUND,STILL GETTING 1-2 ' BPM. GIVE UP ATTEMPTS AT AB/U. -MONITOR WELL 10 MIN,WELL IS ON , LOSSES Printed 6/24/2013 11:05:35AM S • i North America-ALASS l, Operation Summary Report Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 AFE TBD(1,680,000.00) Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/9/1995 12:00:OOAM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 23:00 5.50 CASING P DECOMP PJSM,POOH FROM 9077'MD AND L/D DP 1X1 OBSERVE 25K OVERPULLAT 8948' -SCREW INTO TOP DRIVE AND PUMP 4 BPM =1100 PSI,ROTATE AND SLACK OFF,PIPE IS FREE I-PULL PIPE ON ELEVATORS AND STAND BACK 3 STANDS PIPE IS HANGING UP EVERY 30 FEET FROM 8948'TO 8695',5K-10K OVERPULLS -DO NOT OBSERVE ANY OVERPULLABOVE 8695'MD 1-SUSPECT 2 7/8"COLLARS ARE HANGING UP IN THE AREA OF UPPER LATERAL -CONTINUE TO POOH AND LDDP 1X1,RUN !STANDS BACK IN FROM DERRICK AND LID 1X1 -POOH WITH 2 7/8"TUBING AND STAND BACK IN DERRICK I � -MAINTAIN CONTINUOUS HOLE FEED OF 8.5 I PPG BRINE DOWN ANNULUS AT 25 BPH 23:00 - 23:30 0.50 CASING P DECOMP MAKE UP RUNNING TOOL AND PULL WEAR RING CLEAR/CLEAN RIG FLOOR 23:30 - 00:00 0.50 RUNCOM P RUNCMP I PJSM,HANG ESP SHEAVE -MOBILIZE ESP CLAMPS AND CENTRILIFT EQUIPMENT TO RIG FLOOR i I -24 HOUR FLUID LOSS=924 BBL 8.5 BRINE MAINTAIN CONTINUOUS HOLE FEED OF 8.5 PPG BRINE DOWN ANNULUS AT 25 BPH 6/14/2013 00:00 - 05:00 5.00 RUNCOM ' P RUNCMP I PERFORM SPCC AND EQUIPMENT CHECKS PJSM WITH CENTRILIFT REP TO M/U ESP I EQUIPMENT -M/U ESP PUMP AND MOTOR ASSY AND SERVICE UPPER AND LOWER SEALS -PULL ESP CABLE OVER SHEAVE AND ATTACH TO ESP MOTOR -M/U DISCHARGE HEAD AND FIRST JOINT -TIE IN AND MAKE FINAL CONDUCTIVITY CHECKS -MAINTAIN CONTINUOUS HOLE FEED OF 8.5 PPG BRINE DOWN ANNULUS AT 25 BPH 05:00 - 06:00 1.00 RUNCOM P RUNCMP RIH WITH 2 7/8"6.5#EUE 8RD ESP COMPLETION WITH HEAT TRACE RIH WITH TUBING FROM DERRICK -TUBING TORQUE=2300 FT/LBS -INSTALL CANNON CLAMPS ON EVERY COLLAR ON THE FIRST 9 JOINTS,THEN EVERY OTHER JOINT THEREAFTER -CHECK CONDUCTIVITY ON ESP CABLE !EVERY 2000' -PUMP 5 BBLS TO FLUSH THRU PUMP AT.50 BPM EVERY 2000',NOT TO EXCEED 3000 PSI -WILL CHECK CONDUCTIVITY EVERY 1000' ON HEAT TRACE 106:00 - 08:30 2.50 RUNCOM P RUNCMP CONTINUE RIH WITH ESP COMPLETION. CHANGE OUT JOINT#11 DUE TO PITTING OBSERVED ON OUTSIDE OF BOX. Printed 6/24/2013 11:05:35AM • . �� of ,Fe' e P 8 9199 Y 9 Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) ! Start Date:6/8/2013 End Date:6/16/2013 AFE TBD(1,680,000.00) Project:Milne Point r Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/9/1995 12:00:00AM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWN Active datum:ORIG KELLY BUSHING©66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 11:00 2.50 RUNCOM P RUNCMP CONTINUE RIH WITH 2 7/8"6.5#EUE 8RD ESP COMPLETION. AT 1900 FT PUMP 0.5 BPM=1700 PSI THROUGH TUBING. AT 3900 FT PUMP 0.5 BPM=1800 PSI. 11:00 - 16:00 5.00 RUNCOM P RUNCMP STOP W COND URIH CT PJSM ITH AND 35 STDS REVIEW LEFT SOP IN DERRIC FOR K. `PULLING HEAT TRACE CABLE ONTO RIG FLOOR. PULL HEAT TRACE OVER SHEAVE AND ONTO RIG FLOOR START CLAMPING IT TO TUBING AT AROUND 3400 FT,JT 107 FROM SURFACE CONTINUE RIH WITH COMPLETION. 16:00 - 00:00 8.00 RUNCOM P RUNCMP CREW CHANGE. PJSM,REVIEW SOP FOR RUNNING ESP COMPLETION WITH NEW CREW. -CONTINUE RIH WITH 2 7/8"6.5#EUE 8RD ESP COMPLETION WITH HEAT TRACE TO 7270'MD OA=30 PSI -24 HOUR FLUID LOSS=579 BBL 8.5 BRINE !-MAINTAIN CONTINUOUS HOLE FEED OF 8.5 PPG BRINE DOWN ANNULUS AT 25 BPH 6/15/2013 00:00 - 04:30 4.50 RUNCOM P RUNCMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS -COP NTINUE P WI " 8RD ES COMLETION RIH WITH TH 2 HEAT 7/86.5#TRACE -FROM 7270'TO 7988' -PUMP 5 BBLS TO FLUSH THRU PUMP AT 7825',.50 BPM=1580 PSI i 1-M/U FOSVTO LANDING JOINT AND M/U -FMC REP PRE-INSTALL TWC AND M/U 11 X 2 7/8"TUBING HANGER,2 7/8"EUE 8RD TOP AND BOTTOM THREADS -PUWT=87K,SOWT=65K,(INCLUDES 40K BLOCK WT) -MAINTAIN CONTINUOUS HOLE FEED OF 8.5 TPPG BRINE DOWN ANNULUS AT 25 BPH -. - 4.00 RUNCOM P RUNCMP - - - A 04:30 08:30 I TERMINATE ESP CABLE AND HEAT TRACE AT HANGER INSTALL PENETRATORS AND TEST SAME TEST CONDUCTIVITY OF ESP AND HEAT TRACE -R/D EXCESS ESP CABLE AND HEAT TRACE 08:30 - 09:30 1.00 RUNCOM P RUNCMP TU HANGER HWI WEIGHLAND T,87K BING UP WEIGT.TH WEIGHT 65K DOWN INCLUDES 40K FOR BLOCKS. I FMC TECHNICIAN RUN IN LDS. REMOVE LANDING JOINT. 09:30 - 10:00 0.50 RUNCOM P RUNCMP ATTEMPTA S FROM W PUMP 65 BBLS ROLLING AT 8 BPMTE,T ABLE TO GET BELO 40.0 PSI UNDER TWC. CONFIRM VISUALLY NO LEAKS PAST TWC. PRESSURE TEST FROM ABOVE TO 250/3500 PSI,GOOD. Printed 6/24/2013 11:05:35AM • • 4,7,4,,,,,,/ ;;e ter' ,�3, ,RI,,F V/"„.; ; Common Well Name:MPH-07 l AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 I End Date:6/16/2013 IAFE TBD(1,680,000.00) Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 ' Spud Date/Time:9/9/1995 12:00:00AM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:ORIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations I (hr) (usft) 10:00 - 18:00 ' 8.00 BOPSUR P 1 RUNCMP 1PJSM FOR CHANGING BOP RAMS AND REMOVING BOPS. VAC FLUID OUT OF STACK RIG DOWN CHOKE AND KILL LINES ON BOPS. CHANGE OUT RAMS TO 3-1/2 X 6 VBR ON TOP AND BOTTOM PIPE RAMS. OPEN BLIND RAMS DOORS AND INSPECT. I VAC OUT CUTTINGS BOX. rt 18:00 - 19:00 1.00 1 BOPSUR P 1 OTHCMP 'LN/D BOP AND SET BACK ON PEDESTAL -R/D KOOMY LINES,RISER,TURNBUCKLES AND EQUIPMENT 19:00 - 19:30 0.50 EVAL P OTHCMP I CENTRILIFT REP PERFORM FINAL PHASE TO PHASE CONDUCTIVITY TEST -CHECKS GOOD 19:30 - 21:30 1 2.00 WHSUR !, P OTHCMP N/U AND ORIENT TREE AND ADAPTER FLANGE PER FMC 1-TEST ADAPTER FLANGE VOID 250 PSI,5 MIN,5000 PSI,30 MIN,GOOD TEST 21:30 23:00 1.50 WHSUR P OTHCMP R/U TEST EQUIPMENT AND TEST TREE WITH 'DIESEL W L I-250/3500 PSI,5 MIN,CHARTED 23:00 - 00:00 1.00 HSUR P OTHCMP PJSM WITH DSM AND CREW FOR PULL TWC I FAND SET BPV f-R/U DSM LUBRICATOR,TEST 250/3500 PSI, 5 MIN,CHART -OA=20 PSI -24 HOUR FLUID LOSS=735 BBL 8.5 BRINE , -MAINTAIN CONTINUOUS HOLE FEED OF 8.5 PPG BRINE DOWN ANNULUS AT 25 BPH 6/16/2013 00:00 - 04:00 I 4.00 WHSUR P OTHCMP PJSM,PERFORM SPCC AND EQUIPMENT CHECKS CONTINUE TEST DSM LUBRICATOR,TEST 1 250/3500 PSI,5 MIN,CHART -ATTEMPT TO PULL TWC,UNSUCCESSFUL, PULLING TOOL WILL NOT GO PAST MASTER I IVALVE :-VAC DIESEL OUT OF TREE AND VISUALLY VERIFY THAT MASTER VALVE IS OPENING ALL THE WAY R/D DSM HYDRAULIC LUBRICATOR I -R/U DSM MANUAL LUBRICATOR WITH SMALLER TOOL/SHAFT OD'S AND ABILITY �TO RE-SET TWC IF NEEDED -TEST MANUAL LUBRICATOR PULL TWC,RE-TEST LUBRICATOR,250/ 3500 PSI,5 MIN,CHART -INSTALL BPV -R/D DSM LUBRICATOR AND EQUIPMENT 04:00 - 04:30 0.50 WHSUR P 1 I OTHCMP ATTEMPT ROLLING TEST BELOW BPV I-PUMP 40 BBLS UP TO 7 BPM=100 PSI, I VERIFY NO FLOW BY BPV -R/D TEST EQUIPMENT,SECURE TREE Printed 6/24/2013 11:05:35AM 1 20. North •America-ALASKA A, ; operation Summary Report Common Well Name:MPH-07 AFE No Event Type:WORKOVER(WO) Start Date:6/8/2013 End Date:6/16/2013 AFE TBD(1,680,000.00) Project:Milne Point Site:M Pt H Pad Rig Name/No.:DOYON 16 Spud DateTme:9/9/1995 12:00:00AM Rig Release:6/16/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:O RIG KELLY BUSHING @66.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 08:00 3.50 WHSUR P OTHCMP PJSM WITH LRS HOT OIL FOR FREEZE PROTECT -R/U LRS AND PT LINE -PUMP DEAD CRUDE DOWN TUBING=15 BBLS,.5 BPM=1700 PSI FCP PUMP DOWN IA=75 BBLS,1 BPM=300 PSI FCP FREEZE PROTECT DOWN TO 2600 FT IN BOTH TUBING AND IA. -R/D LRS,SECURE TREE -BLOW DOWN MUD PUMP AND ALL I CIRCULATING LINES -FINISH CLEANING PITS BRIDLE UP AND PREP RIG FLOOR TO LAY 'DERRICK OVER -MOVE SLOP TANK SO RIG CAN PULL OFF WELL. -8 HOUR FLUID LOSS=149 BBLS 8.5 PPG BRINE I-RELEASE RIG AT 08:00 FROM MPH-07A TO PBU S-111 i. Printed 6/24/2013 11:05:35AM • • Tree: 2 9/16"-5M CIW Wellhead: 11" 5M FMC Gen 5 PBU MPU H-07a 4' Orig. RT Elev. = 65.9' (N 22E) Orig. GL. Elev. = 36.1' w/ 7 1/6"x 2 7/8" FMC tbg hgr, 8rd EU RT To 9 5/8"hgr=30.6' (N 22E) threads top and btm., 2.5" CIW H BPV profile 20"91.1 ppf, H-40 116' Camco 2-7/8"x 1" 168' sidepocket KBMM GLM HES"ES"Cementer 0 X 7"Halliburton ES cementer 2149' KOP @ 600' Angle passes 50°@ 3500' Angle @ XN Nipple is 78° Heat Trace to 3428' Max. hole angle=horizontal 2-7/8"6.4#L-80 EUE tubing (drift ID=2.441",cap.00579 bpf) 4.5"12.6#L-80 BTC liner (drift ID=3.958",cap.0152 bpf) 7",26#L-80 BTC-M casing M 2-7/8"XN nipple 7918' (drift ID=6.276,cap.0383 bpf) (ID 2.205") 9 5/8", L-80 BTC casing 40 ppf (ID=8.835")f/7406'to surf. Discharge Head 400 FPDIS 7960' 47 ppf(ID =8.681")f/shoe to 7406' Centrilift Pumps,124 P4 400 PMSXD and 18 P75 538 PMSXD 7961' 7387'to 7425'. RA marker at at 7387'wlm. X Gas Separator GRSFTXARH6 7981' Separator TVD=4020' Tandem Seal Section 7986 GSB3 DB UT/LT SB/SB PFSA w Centrilift Motor MSP1-200 100 HP, 7999 ~ 2300 volt/26 amp, / 11) SLB Phoenix XT-150 sensor 8008' w/six fin Centralizer Sensor TVD=4025' Window in 9-5/8"casing 8149'-8164' 7 baker hook wall hanger 8695' 10104' 9083' L-80 slotted liner slotted at 8766'-10061' \7"x5"ZXPlin:rtoP packer Whip stock 8164' back8 hanger 9-5/8"cement retainer 8165' •FCO Conducted at 9080'and 6/13/13 " sssssssssssssssssssssssss 12613' 4.5"L-80 slotted liner slotted at 9191`-12571' = "" 7"Halliburton landing collar 9115' HES 9 5/8" EZSV retainer —"" 7",26#L-80 Float collar w/baffle 9157' 9065' 7",26#L-80 Float shoe HES 9 5/8" EZSV retainer 9070' 9203' 9 5/8" casing shoe 9217' ' DATE REV BY COMMENTS MILNE POINT UNIT 03/03/02 MDO Sidetrack Prep 4es WELL H-07a 03/27/02 M.Linder Sidetrack by Nabors 27-E API NO: 50-029-22597-71 09/16/04 MDO ESP RWO Nabors 4-es API NO: 50-029-22597-72 03/07/08 SKB&LH ESP RWO Nabors 3s 6/16/13 AAR ESP RWO/FCO Doyon 16 BP EXPLORATION (AK) bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 S N ) F EB LO1Z Mr. Tom Maunder ✓ O �� Alaska Oil and Gas Conservation Commission h 33 West 7 Avenue a ‘, O' Anchorage, Alaska 99501 {� , Subject: Corrosion Inhibitor Treatments of MPH -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPH -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10r404) MPH -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPH -01 1900860 50029220610000 Dust Cover NA NA NA 6.8 9/4/2011 MPH -02 1900870 50029220620000 Sealed Conductor NA NA NA NA NA MPH -03 1900880 50029220630000 Sealed Conductor NA NA NA NA NA MPH -04 1900890 50029220640000 Sealed Conductor NA NA NA NA NA MPH -05 1950980 50029225720000 1.3 NA 1.3 NA 11.9 8/17/2011 MPH -06 1951150 50029225800000 0.2 NA 0.2 NA 5.1 10/9/2011 --'� MPH -07A 2020240 50029225970100 6 NA 6 NA 59.5 10/31/2009 MPH -08B 2010470 50029228080200 1.2 NA 1.2 NA 17.0 9/4/2011 MPH -09 1971650 50029228040000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -10 1971490 50029227950000 1.2 NA 1.2 NA 11.9 10/31/2009 MPH -11 1971630 50029228020000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -12 1971700 50029228070000 0.5 NA 0.5 NA 3.4 9/4/2011 MPH -13A 2021670 50029228180100 0.8 NA 0.8 NA 8.5 8/17/2011 MPH -15 2051590 50029232840000 0.5 NA 0.5 NA 5.1 8/17/2011 MPH -16 2041900 50029232270000 1.8 NA 1.8 NA 17.0 8/17/2011 MPH -17 2070660 50029233580000 1.3 NA 1.3 NA 13.6 8/17/2011 MPH -18 2041740 50029232240000 18.6 NA Need top job MPH -19 2071360 50029233710000 0.1 NA 0.1 NA 2.6 9/4/2011 STATE OF ALASKA~~ ALI~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS RECEfVE~ APR 0 3 2008 1. Operations Performed: Alaska DII & GaS Con$. omml ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Entjd Well ^ Alter Casing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ®Other ^ Change Approved Program ^ Operation Shutdown Change Out ESP ~ ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-024 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22597-01-00 7. KB Elevation (ft): KBE = 71.00' ~ 9• Well Name and Number: MPH-07A' 8. Property Designation: 10. Field /Pool(s): ADL 380109 ~DL ooas o6 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 12998 ~ feet true vertical 4140 ' feet Plugs (measured) N/A Effective depth: measured 12613 ' feet Junk (measured) N/A true vertical 4125 ~ feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 8118' 9-5/8" 8149' 4056' 5750 3090 Intermediate Production 9171' 7" 9203' 4232' 7240 5410 Liner 3529' 4-1/2" 9084' - 12613' 4228' - 4125' 8430 7500 ~';~~ JUN ~' ~= 20U8 Perforation Depth MD (ft): 9191' - 12571' (Slotted Liner) Perforation Depth TVD (ft): 4231' - 4127' (Slotted Liner) 2-7/8", 6.5# L-80 8101' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 1070 0 Subsequent to operation: g3 ' 102 960 320 281 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Nick Frazier, 564-5633 N~q Printed Name Sondra Stewman Title Drilling Technologist Sig ature Prepared By Name/Number: Phone 564-4750 Date(~'(~~'(, ondra Stewman, 564-4750 >Ion Form 10-404 Revised 04/2006 Submit Original Only S ~~ .~~IV ~~ ~ 200 ,,~y/s,~~ a s,~a a ~~` Tree: 2 9/16" - 5M CIW MPU H-07a Orig. RT Elev. = 65.9' (N 22E) Wellhead: 11" 5M FMC Gen 5 PBU Orig. GL. Elev. = 36.1' w/ 11' x 2 7/8" FMC tbg hgr , 8rd EU RT To 9 5/8" hgr = 30.6' (N 22E) threads top and btm., 2.5" CIW H BPV profile 20" 91.1 ppf, H-40 116' HES "ES" Cementer KOP @ 600' Angle passes 50° @ 3500` Angle @ XN Nipple is 78° Max. hole angle =horizontal 2-7/8" 6.4# L-80 EUE tubing (drift ID= 2.441", cap .00579 bpf) 4.5" 12.6# L-80 BTC liner (drift ID= 3.958", cap .0152 bpf) 7", 26# L-80 BTC-M casing (drift ID= 6.276, cap .0383 bpf) 9 5/8", L-80 BTC casing 40 ppf (ID = 8.835") f/ 7406' to surf. 47 ppf (ID = 8.681") f/ shoe to 7406' 7387' to 7425'. RA marker at at 7387' wlm. Window in 9-5/8" casing 8149`-8164' Whip stock 9-5/8" cement retainer 8164' 8165' Camco 2-7/8" x 1" 166` sidepocket KBMM GLM 7" Halliburton ES cementer 2149' Heat Trace to 3442' 2-7/8" XN nipple 8004' (ID 2.205") Discharge Head FPHVDis BROUNDE 8048` Centrilift Pumps, 39P6 PMSXD ' and SXD iaiPS 8049 Gas Separator cRSFTx AR r+s 8070' Separator TVD = 4038' I Tandem Seal Section GS63D6 UT/ LT SB/SB PFSA 8075' Centrilift Motor KMH 76 HP, ` 1360 volt / 34 amp, 8089 Phoenix XTO sensor w/ six fin Centralizer 8097` Sensor TVD = 4044' 7" baker hook wall hanger 8695` 10104' 4.5", L-80 slotted liner _ slotted at 8766'-10061' 7" x 5" ZXP liner top pack 8083, w/ tie back& hanger 1261 \ slotted at 9191'-12571' HES 9 5/8" EZSV retainer 9065' HES 9 5/8" EZSV retainer 8070' 9 5/8" casing shoe 8217' 7" Halliburton landing collar 9115' 7", 26# L-80 Float collar w/ baffle 9157` 7", 26# L-80 Float shoe 9203` DATE REV. BY COMMENTS 03/03/02 MDO Sidetrack Preo 4es 03/27 MILNE POINT UNIT WELL H - 07a API NO: 50-029-22597" ~i -cU~ ' ~1 -OCR BP EXPLORATION • • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: MPH-07 Common Well Name: MPH-07 Spud Date: 3/4/2002 Event Name: WORKOVER Start: 3/3/2008 End: 3/8/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/8/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task I Code NPT Phase Description of Operations 13.50 MOB P PRE All components off of well MPH-19 ~ 11:00. Notified AOGCC - 3/3/2008 06:00 - 19:30 - ~ - 19:30 - 00:00 I 4.50 I MOB I P 3/4/2008 3/5/2008 00:00 - 01:00 1.00 MOB P 01:00 - 05:00 4.00 KILL P 05:00 - 05:30 0.501 KILL P 05:30 - 08:00 2.501 KILL P 08:00 - 10:00 I 2.001 KILL I P 10:00 - 12:00 2.00 WHSUR P 12:00 - 13:30 I 1.501 WHSUR I P 13:30 - 14:00 I 0.501 WHSUR I P 14:00 - 18:30 I 4.501 BOPSURP 18:30 - 22:30 I 4.001 BOPSUR P 22:30 - 00:00 00:00 - 01:00 01:00 - 02:00 02:00 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 12:00 1.50 BOPSU P 1.00 WHSUR P 1.00 WHSUR P 0.50 WHSUR P Bob Noble, for 24 hr notice regarding upcoming BOPE Test. MIRU on MPH-07. Spot BOPE's behind well. Spot Carrier, Pipe Shed, and Pits. Auxilliary support equipment and Camp already on location. Raise and scope Derrick. PRE Traveling blocks not centered over well, scope down and lay over derrick, jack to level up. Raise and scope derrick. PRE RU lines between rig units. Rig accepted C~ 01:00 hrs 3/4/2008 DECOMP Ri acce ted @ 01:00 hrs 3/4/2008, install second annulus valve, MU and tested hard lines, to and from tree and tiger tank. DECOMP PUMU lubricator tested Tb =1000 si, IA=1500 si OA=25 psi, DECOMP PJSM. Bleed IA to 250 psi, come on line pumping 50 Bbls SW down tubing ~ 4 BPM, 150 psi. IA pressure to O psi. Close choke and bullhead 75 Bbls down tubing ~ 150 psi, IA pressure to 300 psi. Flowcheck tubing on vacuum. Open choke and attempt to circulate another 100 Bbls down tubina ith NO RETURNS from IA. IA ressure to 0 si. DECOMP Bullhead 400 Bbls down IA ~ 4 BPM, 150 psi (never caught fluid). Bullhead 50 Bbls down Tbg. Flowcheck well. Tbq and IA on vacuum. DECOMP Dry rod TWC. Test from above to 3500 psi and chart for 10 _ minutes. Unable to test from below due to low BHP. Had to re-dress TWC prior to running it. DECOMP Rig service, installed new steel cable on two BOP bridge crane hoists. DECOMP ND Tree. Check tubing hanger threads with 2 7/8" pup joint. 8 turns. DECOMP NU DSA, PU/MU13 5/8" spacer spool and BOPE. Hook up accumulator hoses, kill and choke lines. Function test BOPS. At 15:00 hrs John Crisp with AOGCC waived state's right to witness BOP test. DECOMP PU/MU 2-7/8" test jt, Test ROPE per BP / AOGCC regulations 250 / 3500 psi. Test annuular to 3500 psi. DECOMP Blow down lines, BO/LD test jt. DECOMP PU/MU and tested Opso-Lopso and lubricator with diesel to 500 psi. Pull TWC, tubing and IA on vacuum. DECOMP PU/MU 2-7/8" landing jt, FMC BOLDS, pull tubing hanger free, PUWT= 55k. DECOMP Pump 58 bbls seawater down tubina 4 BPM Cc~ 250 oci with nn 0.50 PULL P DECOMP LD Landing jt and tbg hanger. 1.00 PULL P DECOMP RU ESP trunk and pull ESP cable over sheave in derrick, rig up floor to pull ESP completion assembly. 8.00 PULL P DECOMP POOH 2-7/8" tbg and ESP completion standing back in the derrick. ,Maintain 30 bph fill rate while POOH. Stands #54, 91 and 100 out of the well had some scale on the OD of the pipe. Stand #123 had evidence of slight corrosion pitting on the boxes. Lay down the Joint above the XN Nipple which had 2' of Tubing punch holes in it and the single below the XN Nipple. Stood back a total of 126 stands (252 Joints) of Tubing in the Derrick and laid down 2 singles for a total of 254 Joints Printed: 3/27/2008 1:52:28 PM BP EXPLORAT{ON Page 2 of 4 Operations Summary Report Legal Well Name: MPH-07 Common Well Name: MPH-07 Spud Date: 3/4/2002 Event Name: WORKOVER Start: 3/3/2008 End: 3/8/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/8/2008 Rig Name: NABOBS 3S Rig Number: Date 3/5/2008 From - To Hours Task I Code NPT Phase Description of Operations 23:30 - 00:00 0.50 CLEAN P 3/6/2008 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:00 1.00 CLEAN P 02:00 - 06:00 4.00 CLEAN P DECOMP recovered. DECOMP On surface with the old ESP Assembl .Break out and lay down the ESP Components. Recovered 134 La salle clamps,4 protectolizer, 2 flat guards. CLEAN Motor #1 output shaft and transmission will need to be replaced before moving the rig. Perform energy isolation of Motor #1 and switch to Motor #2. Shoot fluid level with the blinds closed and fluff level = 1 2 ' CLEAN MU mule shoe and PU 120 jts (-3696') of 2-7/8" 10.4# Pac DP from pipe shed. Turn hole fill pump off for 20 min. and shoot fluid level twice, readings not inconclusive. Maintain 30 BPH hole fill rate. CLEAN Change handling equipment to 2-7/8" tubing. CLEAN Continue RIH from derrick with 2-7/8" tb . to -4100' CLEAN Remove DP wipping rubber logged in annular cap. CLEAN Continue RIH from -4100' with 2-7/8" mule shoe, 2-7/8" Pac DP and 2-7/8" tbg from derrick to 8745' DWt=25K, UPW=55K work to 8745, POH to 3 stds (-8544) pump 50 bbls seawater, 3 BPM ~ 350 psi. CLEAN Pre-tour checks and lubricate the Rig. CLEAN PU stand #81 out of the Derrick. PUW = 56K ,SOW = 22K. Work the stand down and take weight with the stand buried (8,783'). PU single joint of Tubing and wash down to 8,814'. Observed a jump on the weight indicator where it broke through and continued washing the single down. Shut down the pump and work the single a couple of times with no problems. Attempt to continue RIH without washing down - no Joy. Having to wash down each individual single to make any progress.-Wash down three more Joints to a final depth of 8,909'. CLEAN Confer with Anchorage Engineering and decision made to POOH prior to getting stuck due to sand being washed up above and possibly having the sand being washed into the upper lateral. POOH to stand #79 (8,675') to ensure we are up above the upper lateral at 8,695'. CLEAN Attempt to RU the double ESP /Heat Trace Sheave in the Derrick. After getting it spotted in place, notice that it will be in the way of the stands of Tubing in the Derrick. Will RU once we are out of the hole completely and ready to run completion. CLEAN RIH to tag the fill /sand. Bury stand #83 where we stopped making hole and take weight with the top of #83 at the Rotary. Final taq depth of 8,909'. CLEAN POOH with the cleanout assembly standing the Tubing back in the Derrick. Maintain 30 bbl /hour fill rate. Stood back 126 stands in the Derrick. CLEAN Resume POOH and laying down 1 x 1 Joints of 2-7/8" PAC DP in the Pipe Shed. Maintain 30 bbl /hour fill rate. Laid down 120 Joints of PAC DP. Mule shoe shows no visible marks made Burin clean out run. RUNCMP Hang double ESP 1 Heat Trace sheave in derrick, clean and clear rig floor. Shoot fluid level with the blinds closed and fluid level = 4 500 '. RUNCMP RU floor to run ESP completion and run ESP cable over 04:00 - 12:00 8.00 PULL P 12:00 - 15:00 3.00 PULL P 15:00 - 17:00 2.001 CLEAN P 17:00 - 23:30 6.50 ~ CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30 - 09:00 2.50 CLEAN P 09:00 - 09:30 0.50 CLEAN P 09:30 - 10:30 1.00 CLEAN P 10:30 - 11:00 0.50 CLEAN P 11:00 - 14:00 3.00 CLEAN P 14:00 - 17:00 3.00 CLEAN P 17:00 - 18:00 1.00 BUNCO 18:00 - 19:30 1.50 BUNCO Printed: 3/27/2008 1:52:28 PM BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: MPH-07 Common Well Name: MPH-07 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date I From - To Hours I' Task Code NPT Spud Date: 3/4/2002 Start: 3/3/2008 End: 3/8/2008 Rig Release: 3/8/2008 Rig Number: Phase Description of Operations 3/6/2008 /7/2008 18:00 - 19:30 19:30 - 23:00 23:00 - 00:00 00:00 - 05:00 5:00 - 06:00 06:00 - 06:30 06:30 - 00:00 1.50 3.50 1.00 5.00 .00 0.50 17.50 BUNCO BUNCO BUNCO BUNCO UNCO BUNCO BUNCO RUNCMP RUNCMP RUNCMP RUNCMP UNCMP RUNCMP RUNCMP sheave in derrick. PU / MU ESP motor /pump assembly and connect ESP cable to motor. RIH with ESP com letion on 2-7/8", 6.5#, L-80, EUE 8 rd, tbg from derrick. Maintain hole fill rate at 30 bbls seawater each hour. RIH -888' at 24:00 hrs. Continue RIH with ESP completion on 2-7/8", 6.5#, L-80, EUE 8 rd, tbg from derrick. Maintain hole fill rate at 30 bbls seawater each hour. Centrilift tech checked the conductivity of ESP cable every -2000 ft while running in hole. Filled the Tubing and flushed the pump with 10 bbls of seawater at a rate of 0.5 bpm / 1,600 psi. PJSM with Centrilift rep. Prepare the floor to run heat trace with flat guards and bands. Run the heat trace cable over the Sheave. Service and lubricate the Rig. RIH with ESP Com letion on 2-7/8", 6.5#, L-80, EUE 8rd Tubing from the Derrick. Run Heat Trace Cable beginning on Joint #150 to surface which gives a total of -3,335' of Heat Trace coverage (105 Jts). Maintaining 30 bbl /hour fill rate while RIH. MU torque = 2,300 ft-Ibs and utilizing Best-O-Life 2000 Pipe Dope on all connections. Stopping every 2,000' to check the conductivity of the cables. Fill the Tubing and flush the pump with 10 bbls of seawater at each stop at a rate of 0.5 bpm / 1,600 psi. Final 10 bbls pumped to flush pump = 0.5 bpm / 1,850 psi. Depth ~ 00:00 hrs was -8040', one stand off bottom. 3/8/2008 00:00 - 00:30 0.50 BUNCO RUNCMP Continue to run last stand from derrick, 2-7/8" tubing, ESP / Heat trace. Ran 79 LaSalle clamps, 3 protectolizers, 2 Armster guards, (513 ea 6 ft), (15 ea 4 ft) and (17 ea 3 ft) Flat guards and 1,612 SS bands. Final PUW = 57K ,SOW = 27K. 00:30 - 01:30 1.00 BUNCO RUNCMP PU landing joint and MU tubing hanger, pups and orient to well head. 01:30 - 05:30 4.00 BUNCO RUNCMP Space out ESP cable and heat trace cables to connect to hanger penetrators. Centrilift service tech perform conductivity checks. Splicing ESP cable and heat trace cables to penetrators. Insert penetrators into hanger and install shipping caps. 05:30 - 06:30 1.00 BUNCO RUNCMP Land Tubin Han er and RILDS. Service Rig. 06:30 - 07:00 0.50 WHSUR P RUNCMP PU T-bar and set 2-1/2" Type "H" TWC with FMC rep. 07:00 - 09:00 2.00 WHSUR P RUNCMP RU Test Equipment. Pressure test the TWC with seawater from above to 3,500 psi for 30 charted mins - OK. Line up to pump down the IA and pressure test the TWC from below by in~ectin at a rate of 3.5 b m / 50 si for 30 charted mins - OK. RD Test Equipment. Blow down lines and drain the BOP Stack. 09:00 - 11:00 2.00 BOPSU P RUNCMP ND the BOPE and lay down in the Cradle. Remove from the Cellar. 11:00 - 13:00 2.00 WHSUR P RUNCMP NU the new Adapter Flange to the Wellhead. NU the re-used Tree with FMC rep. Centrilift reps perform final ESP conductivity checks, 1.4 Gigs phase to ground / 3.2 OHM phase to phase. Heat trace Phase to phase = 4.2 OHM /Phase to ground = 81.9 Gigs. Pressure at the intake 1,312 psi / Printed: 3/27/2008 7:52:28 PM Printed: 3/27/2008 1:52:28 PM ~' STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nabors Rig No.: 3S DATE: 3!4/2008 Rig Rep.: J.GrecoJR.Bjofius Rig Phone: 659-4487 Rig Fax: 659- 4486 Operator: BP Op. Phone: 659- 4485 Op. Fax: 659-4628 Rep.: W.Hoffman/D.Rhodes Field/Unit & Well No.: MPU H-07A PTD #2020240 Operation: Drlg: Test: Initial: X Test Pressure: Rams: 250/3500 MISC. INSPECTfONS: Test Result Location Gen.: P Well Sign Housekeeping: P Drl. Rig PTD On Location P Hazard Sec. Standing Order Posted P BOP STACK: Quantity Size Workover: X . Weekly: Annular: 250/3500 Explor.: Bi-Weekly Valves: 250/3500 TEST DATA FLOOR SAFETY VALVES: Test Result Quantity Test Result P Upper Kelly 1 NT P Lower Kelly 1 NT P Ball Type 1 P Inside BOP 1 P Test ResuR Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 x 5 P Lower Pipe Rams Blind Rams 1 Bind P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves Z 3 1/8" 5000 P Kill Line Vahres 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual Test Alarm Test Trip Tank P P Pft Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1500 P 200 psi Attained 26sec P Fug Pressure Attained 2 min 25 sec P Bfind Switch Covers: All stations P Nitgn. Bottles (avg): 4@2000 Number of Failures: 0 Test Time: 4 Hours Components tested ALL Repair or replacement of equipment wiH be made within days. Notify the North Slope Inspector 659-3607, fallow with written confirmation to Supervises at: Remarks: Tested with a 2 7/8" test joint 24 HOUR NOTICE GIVEN YES X NO Date 03/03/08 Time Test start 1830 hrs Finish BOP Test (for rigs) BFL 11114/07 ~t~` ~ M~~r ~ ~ ~~~ 11:Q0 By Jon Wih~ess R.Biofius/D.Rhodes Nabors 3S BOP Test MP H-07A 3-04-08,x1s . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ Marker.doc s ~ fl-P Æ()G~ DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020240 Well Name/No. MILNE PT UNIT SB H-07A Operator BP EXPLORATION (ALASKA) INC J¡z èJt ¿ API No. 50-029-22597-01-00 7~Æ.G4Å MD 12998'-'" TVD 4140 / Completion Date 3/31/2002 --..'" Completion Status 1-01L Current Status 1-01L UIC N-" ---_.._--~--,--_.._--~------ ----_.- --_.~---_._----- --_.----~--~-~~- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -' ~. - _._-_.__.._.._-_._--~..._- - .---_._-----_._------~ -'---~----"-----~-----'-------~-_.- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) Log/ Electr ~ Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~---._- Rpt LIS Verification 1 8149 11181 Open 6/5/2002 PB1 -EÓ 0 ~845 LIS Verification 8149 12944 Open 6/5/2002 Rpt LIS Verification 8149 12944 Open 6/5/2002 .ÆB' C <41'416 See Notes 8150 12998 Open 12/13/2002 Digital Well Logging Data / Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity ~ 0 -1Ó846 LIS Verification 8149 11181 Open 6/5/2002 PB1 -e.g... C ð;r417 See Notes 8150 11234 Open 12/13/2002 Digital Well Logging Data 1 Rate of Penetration, Dual Gamma Ray, Electromagnetic Wave Resistivity PB 1 ~. '---'--~+----------------- Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Well Cored? ADDITIONAL INFORMATION Y/~ Daily History Received? {\ \Y)/N &N Chips Received? .-¥-f'N'" Formation Tops Analysis Received? ~. ------------~--- -'--.'-----'-"-----'--~------- Comments: DATA SUBMITTAL COMPLIANCE REPORT 4/2/2004 Permit to Drill 2020240 Well Name/No. MILNE PT UNIT SB H-07A Operator BP EXPLORATION (ALASKA) INC MD 12998 Completion Date 3/31/2002 Current Status 1-01L Completion Status 1-01L TVD 4140 _._--~-,~---- ----,-,-_.~----------- ~ Date: --_.--------~---~--_.__._--~_.- Compliance Reviewed By: API No. 50-029-22597-01-00 UIC N 'J ú fJ¡~, l{ ~ "-' 1. Operations Performed: 0 Abandon 0 Alter Casing 0 Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 7. KB Elevation (ft): KBE = 71.00' '\ STATE OF ALASKA '-, ALASKA vlt AND GAS CONSERVATION CO~".JISSION . 'C' "., '" .."" 'h REPORT OF SUNDRY WELL OPERATIONSRE . EIVED SEP 2 3 2004- Ch~nJ1e ~u~SP . . Alask.~mÆ'as Cons. CcmmlSSl1 0 Tim~~S~IJbt IBI Repair Well 0 Plug Perforations 0 Stimulate IBI Pull Tubing 0 Perforate New Pool 0 Waiver 0 Operation Shutdown 0 Perforate 0 Re-Enter Suspended Well 4. Current Well Class: IBI Development 0 Exploratory 0 Stratigraphic 0 Service 5. Permit To Drill Number: 202-024 6. API Number: 50-029-22597-01-00 9. Well Name and Number: MPH-07 A 8. Property Designation: 10. Field I Pool(s): ADL 380109 Milne Point Unit I Schrader Bluff 11. Present well condition summary Total depth: measured 12998 feet true vertical 4140 feet Plugs (measured) NIA Effective depth: measured 12613 feet Junk (measured) NIA true vertical 4125 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface 8118' 9-5/8" 8149' 4056' 5750 3090 Intermediate Production 9171' 7" 9203' 4232' 7240 5410 Liner 3529' 4-1/2" 9084' - 12613' 4228' - 4125' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): 9191' - 12571' (Slotted Liner) 4231' - 4127' (Slotted Liner) Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 2-7/8", 6.5# L-80 8127' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: ~? 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run IBI Daily Report of Well Operations IBI Well Schematic Diagram 15. Well Class after proposed work: 0 Exploratory IBI Development 0 Service 16. Well Status after proposed work: IBI Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman Title Technical Assistant ''---.-- Phone 564-4750 , \ Prepared By Name/Number: Date01-æ..-.o- Sondra Stewman, 564-4750 Submit Original Only , Tr~e:.~ 2 9/16" - 5M CIW ~~\ Wellhead: 11" 5M FMC Gen 5 PBU wi 11' x 27/8" FMC tbg, hnr , 8rd EUE threads top and btm., 2.5" CIW H BPV profile I tI~ I . 20" 91.1 ppf, H-40 'H'ð" - HES "ES" Cementer 0 KOP @ 600' Max. hole angle = horizontal 2-7/8" 6.4# L-80 EUE tubing (drift 10= 2.441", cap .00579 bpf 4.5" 12.6# L-80 btc liner (drift 10= 3.958", cap .0152 bpf) 7", 26# L-80 BTCM casing (drift 10= 6.276, cap .0383 bpf) 9 5/8", L-80 Btrc. casing 40 ppf (ID = 8.835") fl 7406' to surf. 47 ppf (ID = 8.681") fl shoe to 7406' 7387' to 7425'. RA marker at at 7387' wlm. X Window in 9-5/8" casing 8149'-8164' Whip stock 8164' 9-5/8" cement retainer 8165' HES 95/8" EZSV retainer I 9065' HES 9 5/8" EZSV retainer I 9070' 9 5/8" casing shoe 9217' DATE RE\I. BY 03/03/02 03/27/02 09/16/04 MOO M. Linder MOO Sidetrack Prep 4es Sidetrack by Nabors 27-E ESP RWO Nabors 4-es .) ) MPU H-07a\Ac...l0r~g. RT Elev. =- 65;9' ~N 22E) Ong. G.L. Elev. - 36.1 RT To 9 5/8" hng. = 30.6' (N 22E) - Ai. I I r I I JI:Ll :IJ [[II :1 ~ COMMENTS Cameo 2-7/8" x 1" side pocket KBMM GLM 167' 7" Halliburton ES cementer 2149' Cameo 2-7/8" x 1" side pocket KBMM GLM 3242' 2-7/8" XN nipple I 8030' I (ID 2.205") Centrilift Pump, 214 St9. I 8075' I FC925 Model - FPMTAR 1: 1 Centrilift Gas Separator I 8094' I GRSFTXARH6 Centrilift Tandem Seal Section I 8099' I Model GSB3DBUTILH6 GSB3DBL TH6F Centrilift Motor, 55 HP, I 8113' I 1259 volt / 26 amp, Model KMH-A PHOENIX multisensor I 8121' I 6 fin Centralizer I 8126' I Y. baker hook wall hanger I 8695' 4.5", L-80 slotted liner slotted at 8766'-10061' 10104' I 9083' 12613' 4.5" L-80 slotted liner I slotted at 9191'-12571' 9115' 7" Halliburton landing collar 7", 26# L-80 Float collar wi baffle 9157' 7",26# L-80 Float shoe 9203' MILNE POINT UNIT WELL H - 07a\Þ.L\ API NO: 50-029-22597-"-0 J-OO API NO: 50-029-22597-1,I-~ O-CO BP EXPLORATION (AK) ') ) ~r~ BP EXPLORATION Operations Summary Report Page 1 of 1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-07 MPH-07 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 9/15/2004 Rig Release: 9/17/2004 Rig Number: Spud Date: 3/4/2002 End: 9/17/2004 Date From - To Hours Task Code NPT Phase Description of Operations 9/15/2004 06:00 - 08:00 2.00 MOB P PRE PJSM. Rig down off MP 1-08. 08:00 - 10:00 2.00 MOB P PRE PJSM. Move rig components from MP 1-08 to MP H-07. 10:00 - 12:00 2.00 MOB P PRE PJSM. Spot rig components, raise & scope derrick. Rig accepted @ 12:00 hrs. 12:00 - 14:00 2.00 KILL P DECOMP PJSM. Rig up lines to wellhead & tiger tank. Test lines. Pull BPV. SITP = 200 psi, SICP = 1010 psi, O/A = 200 psi. 14:00 - 14:30 0.50 KILL P DECOMP PJSM on well kill operations. Stress on fluid monitoring & pressure monitoring. 14:30 - 19:30 5.00 KILL P DECOMP Alert Milne Pt to gas venting operations. Bleed gas from I/A to tiger tank. Bring on pump & gradually bring rate up to 4 bpm I 200 psi. Pump tubing volume, shut in & bullhead 25 bbls @ 3 bpm I 100 psi. Continue circulating down tubing, taking returns up II A thru choke to tiger tank. With 75 bbls circulated up II A, shut in & monitor. Tubing pressure = 0 psi. Continue circulating, bringing rate up to 5 1/2 bpm. SI, monitor, tubing and casing on vacuum. 19:30 - 21 :00 1.50 WHSUR P DECOMP Alert Milne Pt that gas vent ops have ceased. Install and test TWC. N/D tree. 21 :00 - 22:00 1.00 BOPSUP P DECOMP N/U BOPE. 22:00 - 00:00 2.00 BOPSUPP DECOMP Test BOPE per BP/AOGCC requirements to 250/3500 psi. John Crisp, AOGCC rep, waived witnessing the BOPE test. 9/16/2004 00:00 - 01 :00 1.00 BOPSUPP DECOMP Finish BOPE pressure tests. 01 :00 - 02:00 1.00 BOPSUP P DECOMP RID BOPE test equipment, drain BOP stack, P/U lubricator and pull TWC. 02:00 - 03:00 1.00 PULL P DECOMP BOLDS, P/U landing joint, screw into hanger, pull tubing hanger to floor wI 65K. Breakout tubing hanger WI pup and UD same. 03:00 - 10:30 7.50 PULL P DECOMP POH wI ESP and SIB 2-7/8",6.5#, EUE 8rd, L-80 tubing. Recovered 133 LaSalle Clamps, 5 Protectolizers, 3 Flat Guards. 10:30 - 12:30 2.00 PULL P DECOMP Clear I Clean rig floor. Prep to pick up ESP assembly. Change out ESP cable spools. 12:30 - 14:00 1.50 RUNCOtvP RUNCMP PJSM. Pick up & test ESP assembly. 14:00 - 19:00 5.00 RUNCOrvP RUNCMP PJSM. RIH wi ESP assembly on 2 7/8" EUE 8 rnd L-80 tbg, checking conductivity of cable & circulating down tubing every 2000', torquing each connection to 2300 ftllbs, using Best 0 Life 2000 pipe dope. 19:00 - 21 :00 2.00 RUNCOrvP RUNCMP P/U landing joint, M/U to hanger. Meg ESP cable, make field connection and test, OK. Used 133 LaSalle clamps, 4 Protectolizers, 2 Flat Guards. 21 :00 - 22:00 1.00 RUNCOrvP RUNCMP M/U tbg hgr to tubing and land tubing hanger, RILDS. UD landing joint, set TWC and test to 2500 psi. P/U wt = 46K, SIO wt = 32K. Make final ESP cable test--OK. 22:00 - 23:00 1.00 BOPSUR P RUNCMP N/D BOPE, test spool, and adaptor flange. 23:00 - 00:00 1.00 WHSUR P RUNCMP N/U adaptor flange and tree and test to 5000 psi. P/U lubricator, pull TWC, and set BPV. 9/17/2004 00:00 - 01 :00 1.00 WHSUR P RUNCMP Secure tree and cellar. Release rig @ 0100 hrs. Printed: 9/20/2004 11: 12:56 AM ) WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 3 33 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 To: September 11, 2002 RE: MWD Formation Evaluation Logs: MPH-07APBl: Digital Log Images: 50-029-22597-70 MPH-07APBl, AK-MW-2204I 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-I 900 E. Benson Blvd. Anchorage, Alaska 99508 ~4Wop~ . ECEI'JED DEC 13 2002 Alaska O;'j & Gas Cons. Ccmmì5sion Anchorage a'Da~DdY J/~(~7 ) ) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 03, 2002 RE: MWD FonnationEvaluationLogs l\1PH-07APB1, AK-MW-22041 1 LIS fonnatted Disc with verification listing. ~I#: 50-029-22597-70 a Od-oac1 10 '{LJ to PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99648 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Si~~ RECEIVED !I /"j 0 .- \,I~;j . J 2002 AlækaOil & Gas Cons Com . . Androrage ml88ion 1. Status of Well 1St Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2709' NSL, 4079' WEL, SEC. 34, T13N, Rl0E, UM r~èi}MFiÈ;]ì[ii~~N[ At top of productive interval ~ t1.ATì;..~. 1202' NSL, 1719' EWL, SEC. 02, T12N, Rl0E, UM ¥3' 31..:./2.1 ~10. Well Number At total depth .~ \r'a~ I M PH-07 A 2887' NSL, 716' EWL, SEC. 11, T12N, Rl0E, UM t ".. '''~I:~-'::'' f 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and SeñãT'1-Ja~~' Milne Point Unit / Schrader Bluff KBE = 71.00' ADL 380109 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 3/7/2002 3/15/2002 3/31/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12998 4140 FT 12613 4125 FT 1St Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, PWD, lAB 23. CASING SIZE 20" 9-5/8" 7" WT. PER FT. 91.1# 40# 26# 12.6# 4-1/2" ) STATE OF ALASKA ') ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1.1'!:~..." 'Y' "."TØ-'. =...'..';"'. . .~~~ , ~ 'I ¡;~_,.;~I.: ~?ì, , ~1'<' .1if,<;j1lt::~ 7. Permit Number 202-024 8. API Number 50- 029-22597-01 9. Unit or Lease Name Milne Point Unit 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost N/A MD 1800' (Approx.) GRADE H-40 L-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 32' 112' 24" 250 sx Arctic Set 1 (Approx.) 31' 8149' 12-1/4" 1484 sx PF 'E', 747 sx Class 'G', 50 sx Class 'Go 32' 9203' 8-1/2 240 sx 'L', 176 sx 'G'; Top Job: 265 sx °L', 63 sx 'G' 9084' 12613' 6-1/8" Uncemented Slotted Liner AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Liner MD 9191' - 12571' 4231' - 4127' 27. Date First Production April 8, 2002 Date of Test Hours Tested 25. TUBING RECORD DEPTH SET (MD) 8141' SIZE 2-7/8", 6.5#, L-80 PACKER SET (MD) N/A TVD TVD MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 60 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Electric Submersible Pump PRODUCTION FOR OIL-BBL TEST PERIOD GAs-McF CHOKE SIZE WATER-BBL GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips t'drre~1 ,frtlf or water. Submit core chips. ß ~ ~ '''''.;;1.: ~~~ ~ '.J? ¡;"":) ~~.......¡r No core samples were taken. 28. Form 10-407 Rev. 07-01-80 7 i l\lasl<a Oil & GommlSSiOfR B 0 M 5 .ß:EL. Anchorage -'" .>' D GF MAY! 5 Submit In Duplicate ) 29. Geologic Markers Marker Name Measured True Vertical Depth Depth SBF1-NB 8209' 4071' SBE4-NC 8311' 4098' SBE2-NE 8366' 4112' SBE1-NF 8579' 4154' TSBD-OA 8689' 4171' TSBC 8844' 4197' TSBB-OB 9136' 4229' SBA5 1 0261' 4219' TSBC 10516' 4205' TSBD-OA 12599' 4126' ) 30. Formation Tests Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 'ii'"'' ~"" IÌ..." (: ;~";¡t. ~~~a$1\a 8¡ Anchorage Summary of Daily Drilling Reports, Surveys, Leak-Off Test Summary 31. List of Attachments: 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~. ~ Title Technical Assistant MPH-07A 202-024 Well Number Permit No. / Approval No. INSTRUCTIONS Date OS.07"O~ Prepared By Name/Number: Sandra Stewman, 564-4750 GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Legal Name: MPH-07 Common Name: MPH-07 Test Date 3/6/2002 3/12/2002 Test Type Tesf:b~Pth?(¡r¡M:P);i::: 8,184.0 (ft) 9,245.0 (ft) FIT FIT !,Qtb:¡ 4,060.0 (ft) 4,163.0 (ft) 8.70 (ppg) 9.10 (ppg) 800 (psi) 450 (psi) 2,635 (psi) 2,418 (psi) 12.49 (ppg) 11.18 (ppg) ~ ~J Printed: 4/1/2002 11: 13:30 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) Page 10f 2 Spud Date: 3/4/2002 End: 3/1/2002 Date From -To Hours Ac~ivity Cocie NPT Phase D~scription ofOpeçatipns 2/24/2002 18:00 - 00:00 6.00 MOB P PRE MOVE RIG FROM MPF-33 & MI/RU ON MPH-07 & SAFE OUT EQUIPMENT. (RIG ACCEPT @ 00:01 HRS. 02/25/2002) 212512002 00:00 - 04:00 4.00 RIGU DECOMP ACCEPT RIG AT 00:00 HRS. RIG UP HCR VALVE. HOOK UP LINES AND VALVES TO TREE AND TIGER TANK. 04:00 - 05:00 1.00 RIGU DECOMP TAKE ON HOT SEA WATER IN RIG PITS. PRESS TEST LINES TO 3,500 PSI. 05:00 - 06:00 1.00 KILL DECOMP PJSM. BLEED GAS. BEGIN WELL KILL OPERATIONS. CREW CHANGE. 06:00 - 09:30 3.50 KILL DECOMP FINISH WELL KILL OPERATIONS. MONITOR WELL. 09:30 - 10:00 0.50 WHSUR DECOMP SET TWC. TEST. 10:00 - 11 :00 1.00 WHSUR DECOMP REMOVE PRODUCTION TREE. 11:00 -13:00 2.00 BOPSUR DECOMP INSTALL BOPE. 13:00 - 16:00 3.00 BOPSUR DECOMP PERFORM BOPE TEST AS PER BP/AOGCC REQUIREMENTS. RIGHT TO WITNESS TEST WAIVED BY STATE...J.JONES. 16:00 - 17:00 1.00 WHSUR DECOMP PICK-UP LUBRICATOR. PULL TWC. LD DOWN LUBRICATOR. 17:00 - 17:30 0.50 PULL DECOMP PU LANDING JT. PULL HANGER TO FLOOR. LD LANDING JT. 17:30 - 18:00 0.50 PULL DECOMP RIG UP DOUBLE SHEAVE FOR ESP AND HEAT TRACE CABLES. CREW CHANGE. 18:00 - 20:00 2.00 PULL DECOMP FINISH RIGGING UP SPOOLING UNIT AND HANDLING EQUIPMENT. 20:00 - 00:00 4.00 PULL DECOMP START POOH WITH 2 7/8" TBG. SPOOLING ESP CABLE AND HEAT TRACE CABLE. CREW CHANGE. 2/26/2002 00:00 - 06:00 6.00 PULL P DECOMP FINISH POOH WITH 2 7/8" TBG AND ESP ASSY. 06:00 - 07:30 1.50 PULL P DECOMP LAY DOWN "Y" TOOL AND ESP ASSY. 07:30 - 09:00 1.50 PULL P DECOMP RIG DOWN DOUBLE SHEAVE AND REMAINDER OF THE ESP HANDLING EQUIPMENT. 09:00 - 10:00 1.00 PULL P DECOMP CLEAR AND CLEAN FLOOR. 10:00 -10:30 0.50 PXA P ABAN PICK UP 9 5/8" CSG SCRAPER ASSY. 10:30 - 15:30 5.00 PXA P ABAN START RUNNING CSG SCRAPER. PICKING UP 3 1/2" DRILL PIPE FROM PIPE SHED. STARTING TO STACK OUT AT 5,675-FT. 15:30 - 16:30 1.00 PXA N DPRB ABAN CONTINUE IN HOLE. WASH AND WORK DOWN TO 5,850-FT. 16:30 - 18:00 1.50 PXA N DPRB ABAN CONTINUE IN HOLE. CREW CHANGE. 18:00 - 00:00 6.00 PXA N DPRB ABAN CONTINUE WASHING EACH JT DOWN. NOW AT 7,598-FT....RECOVERING "N" SAND AND SILT IN SAMPLES. 2/27/2002 00:00 - 05:00 5.00 PXA N DPRB ABAN CONTINUE TO WORK AND WASH DOWN TO 8,030-FT. 05:00 - 06:00 1.00 PXA N DPRB ABAN STOP TO REVERSE CIRCULATE. CREW CHANGE. 06:00 - 09:30 3.50 PXA N DPRB ABAN CONTINUE TO WORK AND WASH DOWN TO TOP OF RE-ENTRY GUIDE AT 8,551-FT DRILLER'S DEPTH. 09:30 - 11 :00 1.50 PXA N DPRB ABAN REVERSE CIRCULATE AT 6 BPM. 11:00 -12:00 1.00 PXA N DPRB ABAN SHORT TRIP UP TO 5,850-FT. HAD SEVERAL OVER PULL AREAS. 12:00 - 14:00 2.00 PXA N DPRB ABAN TRIP BACK TO BOTTOM. WORK AND WASH AS NEEDED. 14:00 - 17:00 3.00 PXA N DPRB ABAN REVERSE CIRCULATE. 17:00 - 18:00 1.00 PXA P ABAN START TOH. CREW CHANGE. 18:00 - 20:30 2.50 PXA P ABAN CONTINUE TOH. STAND BACK 40 STDS. 20:30 - 22:00 1.50 PXA P ABAN STOP TO CUT AND SLIP DRILLING. 22:00 - 23:30 1.50 PXA P ABAN FINISH TOH WITH 3 1/2" DRILL PIPE AND BHA. 23:30 - 00:00 0.50 PXA P ABAN LD CSG SCRAPER. Printed: 4/1/2002 11:13:13AM BP8<PLORATION . Operatio"'$i~$:tlmmâ:Iy'~eport MPH-07 MPH-07 PLUG+ABANDON Start: Rig Release: Rig Number: 2/20/2002 .8fDE><.f:>Ee>AATIe>N O.perations S.umma~ry Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 2/28/2002 3/1/2002 3/2/2002 MPH-07 MPH-07 PLUG+ABANDON From~Tò Hours Activity CocJ~ NPT Phase 00:00 - 01 :00 1.00 PXA P ABAN 01 :00 - 03:30 2.50 PXA P ABAN 03:30 - 04:30 1.00 PXA P ABAN 04:30 - 06:00 1.50 PXA P ABAN 06:00 - 08:30 2.50 PXA N DPRB ABAN 08:30 - 11 :30 3.00 PXA N DPRB ABAN 11 :30 - 12:00 0.50 PXA P ABAN 12:00 - 13:30 1.50 PXA P ABAN 13:30 -14:30 1.00 PXA P ABAN 14:30 - 15:00 0.50 PXA P ABAN 15:00 - 18:00 3.00 PXA P ABAN 18:00 - 19:00 1.00 PXA P ABAN 19:00 - 20:30 1.50 PXA P ABAN 20:30 - 23:00 2.50 PXA P ABAN 23:00 - 23:30 0.50 PXA P ABAN 23:30 - 00:00 0.50 PXA P ABAN 00:00 - 0.00 PXA ABAN 00:00 - 02:30 2.50 BOPSUR P ABAN 02:30 - 05:00 2.50 WHSUR P ABAN 05:00 - 06:00 1.00 RIGD P ABAN Page2of2 Start: Rig Release: Rig Number: Spud Date: 3/4/2002 End: 3/1/2002 2/20/2002 Descriþtion of Operations PJSM. PICK-UP SETTING TOOL AND CEMENT RETAINER. TIH WITH RETAINER AND DRILL PIPE., SET RETAINER AT 8,165-FT STING BACK INTO RETAINER. ATTEMPT TO ESTABLISH INJECTION RATE. NO LUCK. TOH WITH DRILL PIPE AND STINGER. CHANGE OUT STINGER. TIH WITH DRILL PIPE. STING INTO RETAINER AND ESTABLISH INJECTION INTO FORMATION. STAGE CEMENT AND PUMP 25 BBLS CLASS "G" BELOW RETAINER. AVERAGE RATE 3 BPM/1,675 PSI. REVERSE CIRCULATE UNTIL RETURNS ARE CLEAN. PRESSURE TEST CMT RETAINER @ 2,500 PSI/30 MIN. GOOD TEST. START TOH. LAY DOWN DRILL PIPE. CREW CHANGE. CONTINUE TO TOH WITH DRILL PIPE. STOP TO FREEZE PROTECT. FINISH LAY DOWN DRILL PIPE AND STINGER/SETTING TOOL. PICK UP LANDING JT. LAND HANGER. RILDS. INSTALL TWC. PRESSURE TEST. SET TWC & NIPPLE DOWN BOP NIPPLE UP TREE & TEST TO 5000 PSI. SECURE TREE & CELLAR AREA & CLN-PITS. RIG RELEASED @ 0600 HRS. 3/1/2002 Printed: 4/112002 11:13:13AM -) ) BP EXPLORATION Operations Summary Report Page 1 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-07 MPH-07 REENTER+COMPLETE NABORS DRILLING CO. NABORS 270 Start: 3/4/2002 Rig Release: 3/25/2002 Rig Number: 27E Spud Date: 3/4/2002 End: 3/25/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 3/1/2002 00:00 - 12:00 12.00 MOB N WAIT PRE PREPARE RIG FOR MOVE FROM MPS PAD TO MPH PAD - WAITING ON TRUCKS TO MOVE NABORS 4ES FROM H-PAD. 12:00 - 00:00 12.00 MOB N WAIT PRE PREPARE RIG FOR MOVE FROM MPS PAD TO MPH PAD - WAITING ON PEAK TRUCKS-RIG RELEASED FOR MOVE. 3/2/2002 00:00 - 08:00 8.00 MOB N WAIT PRE PREPARE RIG FOR MOVE - WAITING ON TRUCKS TO MOVE RIG - TRUCKS ARRIVED ON LOCATION AT 08:00 HRS 08:00 - 00:00 16.00 MOB P PRE MOVE - PUMP - MOTOR - PIT MODULES - MOVE SUB MODULE - PIPE SHED SECTIONS 1 /2 - SUB ON H-PAD 23:59 HRS 3/3/2002 00:00 - 05:00 5.00 MOB P PRE MOVE WHEEL ASSEMBLY OUT AND SPOT SUB ON H-07a 05:00 - 12:00 7.00 MOB P PRE SET PUMP - MOTOR - PIT - MODULES - SPOT PIPE SHED SECTIONS 1# /2# 12:00 - 15:00 3.00 RIGU P PRE LEVEL PUMP ROOM - MAKE BERM FOR CUTTING TANK - CONNECT POWER LINES - CONNECT HIGH / LOW PRESSURE LINES TO SUB - PITS - PUMP ROOM - PIPE SHED 15:00 - 22:00 7.00 RIGU P PRE BLOW AIR THROUGH MUD LINES - HOOK UP FLOW LINE IN HALLWAY - TURN ON WATER TO RIG -INSTALL PLUGS IN CHARGE PUMPS - PREPARE RIG PUMPS FOR DRILLING - WALK THROUGH WITH CO REP 22:00 - 00:00 2.00 DRILL P INT2 ACCEPT RIG @ 22:00 HRS ON 03-03-02 - LOADING PIPE SHED WITH 5" DP - RIG UP TO PULL BPV - ICE IN TREE - STEAM TREE 3/4/2002 00:00 - 00:30 0.50 DRILL P INT2 STEAM TREE - PULL BPV - RIG DOWN / LAY DOWN ROD PULLER 00:30 - 02:30 2.00 DRILL P INT2 NIPPLE DOWN TREE - PU JOINT 2 7/8" EUE 8RD TUBING - PULL TUBING HANGER - LAY DOWN HANGER / JOINT OF TUBING 02:30 - 10:00 7.50 DRILL P INT2 INSTALL TEST PLUG - NIPPLE UP BOPS 10:00 - 15:00 5.00 DRILL P INT2 TEST BOP'S - TOP RAMS - MANIFOLD VALVES # 1, 2, KILL, CHOKE, HCR - VALVES 3, 4,5,6, MANUAL KILL, CHOKE- VALVES 7, 8,9, 5-VALVES 10, 11,12-VALVES 13,14, 15- LOWER PIPE RAMS - FLOOR VALVES - TIW - BLlNDS- UPPER 10BP - LOWER 10BP - HYDRILL (250 LOW 5 MINS 2500 HIGH 5 MINS) - ALL TEST 250 LOW 5 MINS - 3500 HIGH 5 MINS - ACCUMUL TOR TEST - TEST WAS GOOD NO FAILURES - CHUCK SCHEVE WITH AOGCC WAIVED THE WITNESS OF THE TEST. 15:00 - 15:30 0.50 DRILL P INT2 BLOW DOWN CHOKE - KILL LINES - TESTING EQUIPMENT 15:30 - 16:30 1.00 DRILL P INT2 PULL TEST PLUG - SET WEAR RING (10.75" OD 9" ID)- LAY DOWN TEST JOINT 16:30 - 17:00 0.50 DRILL P INT2 RIG DOWN TESTING EQUIPMENT - RIG UP TO PU 5" HWDP AND 5" DP 17:00 - 00:00 7.00 DRILL P INT2 PU 8.5" STRING MILL WITH BULL NOSE - BUMPER JARS- FLOAT SUB -15 JOINTS 5" HWDP - PU 5" DP - RIH TO 2250' - DID NOT SEE RETURNS TILL DRILL PIPE AT 1413' - FILL PIPE AT 1800' - CON'T RIH WITH SINGLES 3/5/2002 00:00 - 02:00 2.00 STWHIP P INT2 CON'T PU 5" DP FROM PIPE SHED RIH TO 3658' 02:00 - 02:30 0.50 STWHIP P INT2 DISPLACED DIESEL FROM THE HOLE WITH FRESH WATER AT 3658'. 02:30 - 07:30 5.00 STWHIP P INT2 CON'T PU 5" DP FROM SHED. RIH TO 7608'. STARTED Printed: 4/1/2002 11:13:39AM ') ') BP EXPLORATION Operations Summary Report Page 2 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-07 M PH-07 REENTER+COMPLETE NABORS DRILLING CO. NABORS 270 Start: 3/4/2002 Rig Release: 3/25/2002 Rig Number: 27E Spud Date: 3/4/2002 End: 3/25/2002 Date From - To Hours Activity Code. NPT Phase Description of Operations 3/5/2002 02:30 - 07:30 5.00 STWHIP P INT2 TAKING WEIGHT. SAT DOWN AT 7633'. 07:30 - 10:30 3.00 STWHIP P INT2 WASHED FROM 7633' TO CEMENT RETAINER AT 8172' DPM. 10:30 - 11 :30 1.00 STWHIP P INT2 PUMPED 25 BBL HIGH VIS SWEEP AND DISPLACE SEAWATER WITH 8.6 PPG LSND MUD. PUMPED AT 10-15 BPM AND ROTATED 120 RPM AND RECIPORATED DURING DISPLACEMENT. 11 :30 - 13:30 2.00 STWHIP P INT2 CIRCULATED AND CLEANED HOLE FOR WHIPSTOCK. CIRCULATED OUT FRAC AND FORMATION SAND. HOLE CLEAN. 13:30 - 14:00 0.50 STWHIP P INT2 CLOSED TOP RAMS AND PRESSURE TESTED CASING TO 2500 PSI FOR 5 MINUTES. GOOD TEST. 14:00 - 14:30 0.50 STWHIP P INT2 TAGGED PLUG TO VERIFTY DEPTH @ 8172 PUMPED DRY JOB 14:30 - 18:00 3.50 STWHIP P INT2 TRIP OUT, LAY DOWN BHA 18:00 - 18:30 0.50 STWHIP P INT2 PJSM ON PICKING UP WHIPSTOCK 18:30 - 22:00 3.50 STWHIP P INT2 PICKING UP BHA, WHIPSTOCK, STARTING MILL, TAPERED MILL, WINDOW MILL, I JT HWDP, FLOAT SUB, GRlRES TOOL, MWD, HANGOFF SUB, BUMPER SUB, X OVER,12 SPIRAL DC, 15 HWDP 22:00 - 00:00 2.00 STWHIP P INT2 SURFACE TEST MWD, TRIPPING IN HOLE WITH WHIPSTOCK MIDNIGHT DEPTH 3,600 FT. 3/6/2002 00:00 - 03:30 3.50 STWHIP P INT2 RAN IN HOLE WITH WHIPSTOCK ASSEMBLY TO 8070'. 03:30 - 04:30 1.00 STWHIP P INT2 ORIENT WHIPSTOCK 91 DEGREES TO THE RIGHT. 04:30 - 05:30 1.00 STWHIP P INT2 SAT DOWN AND SET WHIPSTOCK ANCHOR WITH 20K. PICKUP TO ASSURE ANCHOR LATCHED. SHEARED 45K BRASS SHEAR SCREW. WORKED MILLS FREE. 05:30 - 17:30 12.00 STWHIP P INT2 MILLED WINDOW FROM 8149' TO 8164'. ROTATED 100-120 RPM. TORQUE 20-25K, 475 GPM AT 1675 PSI. ADDED 4 DRUMS OF FLOWLUBE AND TORQUE DECREASED TO 15K., DRILLED 20' OPEN HOLE TO 8184 17:30 - 18:00 0.50 STWHIP P INT2 REAMED OUT WINDOW WITH 105 RPM 477 GALS MIN., WORKED TRU WITH OUT PUMPS S/O 90K P/U 210K 18:00 - 19:00 1.00 STWHIP P INT2 CIRC. SWEEP AROUND WITH 480 GALS MIN. 1700 PSI 19:00 - 19:30 0.50 STWHIP P INT2 FIT TEST WITH 8.7 MUD WT 800# PSI=12.5 19:30 - 23:00 3.50 STWHIP P INT2 PUMP DRY JOB AND TRIP OUT WITH MILLS 23:00 - 00:00 1.00 STWHIP P INT2 LAYING DOWN BHA 3/7/2002 00:00 - 02:30 2.50 STWHIP P INT2 FINISHED LAYING DOWN WHIPSTOCK MILLING ASSEMBL Y. 02:30 - 03:00 0.50 STWHIP P INT2 CIRCULATED AND FLUSHED BOP STACK AND JETTED FLOWLINE. RECOVERED 5 GALLONS OF METAL CUTTINGS. 03:00 - 07:00 4.00 STWHIP P INT2 PU NEW SMITH 6-1/8" BIT AND MOTOR SET AT 1.5 DEGREES. PU MWD AND UPLOADED. FINISHED PICKING UP BHA. SHALLOW TESTED MWD. 07:00 - 11 :30 4.50 STWHIP P INT2 SINGLED IN 39 JTS OF 5" DP FROM PIPE SHED AND CONTINUED RUNNING IN HOLE FROM DERRICK TO 8056'. 11 :30 - 12:00 0.50 STWHIP P INT2 LUBRICATE AND SERVICE TOPDRIVE. 12:00 - 12:30 0.50 STWHIP P INT2 RUN IN HOLE FROM 8056' TO 8125'. ORIENT 80 DEGREES TO THE RIGHT. SLACK OFF BEFORE WINDOW 80K-75K THROUGH WINDOW 70K TO 60K. NO PROBLEMS WITH WINDOW. Printed: 4/1/2002 11 :13:39 AM ') ) Legal Well Name: MPH-07 Common Well Name: MPH-07 Spud Date: 3/4/2002 Event Name: REENTER+COMPLETE Start: 3/4/2002 End: 3/25/2002 Contractor Name: NABORS DRILLING CO. Rig Release: 3/25/2002 Rig Name: NABORS 270 Rig Number: 27E Date From - To Hours Activity Code NPT Phase Description of Operations 3/7/2002 12:30 - 00:00 11.50 DRILL P INT2 DRILL DIRECTIONAL 8184 TO 8994 WITH 85 RPM, 440 GAL ..,.... PER MIN 2400 PSI, 35K BIT WT, P/U 180K, S/O 75K, RIT 120K, AST 5, ART 3.5 3/8/2002 00:00 - 03:30 3.50 DRILL P INT2 DIRECTIONAL DRILL FROM 8994' TO 9213' 4232' TVD. LANDED WELL AT 89 DEGREES IN "OB" SAND. 85 RPM, 440 GAL PER MIN 2400 PSI, 35K BIT WT, CIRC 450 GALS MIN 2450 PSI 03:30 - 05:30 2.00 DRILL P INT2 CIRCULATED 2 BOTTOMS UP. RACK BACK STAND EVERY 30 MINUTES. PUMPED AROUND HIGH VIS SWEEP TO CLEAN HOLE. CIRCULATED 450 GPM 85 RPM. 05:30 - 07:00 1.50 DRILL P INT2 PUMPED OUT OF HOLE WITH 450 GPM AND 2150 PSI. MAX PULL 50K OVER PICK UP. PULLED ABOVE WHIPSTOCK WITH NO PROBLEM. 07:00 - 07:30 0.50 DRILL P INT2 RAN BACK IN HOLE TO BOTTOM AT 9213'. NO PROBLEMS. 07:30 - 09:30 2.00 DRILL P INT2 CIRCULATED 2 BOTTOMS UP AND ROTATED 85 RPM. PUMPED AROUND HIGH VIS SWEEP TO CLEAN HOLE. ADDED 2 DRUMS OF EP MUDLUBE.CIRCULATED HOLE 500 GPM AT 2400 PSI. STAND BACK A STAND EVERY 30 MINUTES. 09:30 - 10:30 1.00 DRILL P INT2 PUMPED OUT OF OPEN HOLE WITH 450 GPM. HOLE IN GOOD SHAPE. PULLED OUT OF HOLE TO 7750'. 10:30 - 12:30 2.00 DRILL P INT2 MADE MAD PASS FROM 7750'-7600' AT 150'/HR. 12:30 - 16:00 3.50 DRILL P INT2 PUMPED SLUG AND PULLED OUT OF HOLE TO BHA. 16:00 - 18:30 2.50 DRILL P INT2 DOWN LOAD MWD AND LAY DOWN BHA 18:30 - 19:30 1.00 DRILL P INT2 CLEAR FLOOR AND PULL WEAR RING 19:30 - 21 :00 1.50 CASE P INT2 PJSM AND RIG UP TO RUN CSG 21 :00 - 00:00 3.00 CASE P INT2 PICKING UP AND RUNING 7" 26# L-80 BTC CSG TO 2400 FT. 60 JTS. 3/9/2002 00:00 - 09:00 9.00 CASE P INT2 PICKING UP AND RUNING 7" 26# L-80 BTC CSG TO 9202 TOTAL JTS RUN 223, LAND ON HANGER WITH 100,00 STRING WT. 09:00 - 12:30 3.50 CASE P INT2 CIRC FOR CEMENT JOB, 55 SPM 230 GALS MIN. 850 PSI 12:30 - 15:30 3.00 CASE P INT2 PJSM, PUMP 10 BBLS WATER, TEST LINES TO 4000#, PUMP 10 WATER, 50 BBLS SPACER WT. 10#, PUMP 230 SX.,178 BBLS LEAD CEMENT CLASS L, WT. 10.7, PUMP 170 SX., 36 BBLS TAIL CEMENT CLASS G, 15.8#, DISPLACE WITH 245 BBLS MUD FOLLOW BY 81 BBLS WATER, BUMP PLUG WITH 2,000#, MIXED AND PUMPED CEMENT AND DISPLACE @ 5.5 BBLS MIN. FULL RETURNS TRU OUT JOB., FLOATS HELDED 15:30 - 16:00 0.50 CASE P INT2 LOAD HEAD WITH CLOSING PLUG, PRESSURE UP ON CSG TO SHEAR ES CEMENTER, OPENED @ 3,400 PSI, CIRC. 80 BBLS WATER 16:00 - 17:00 1.00 CASE P INT2 START TOP JOB, PUMP 196 BBLS CLASS L, MIX @ 10.7 FOLLOWED BY 60 SXS. 13 BBLS CLASS G MIXED @ 15.8 DROPPED CLOSING PLUG, DISPLACE WITH 81 BBLS MUD CLOSED CEMENTER WITH 1600 PSI, 91 BBLS CEMENT TO SURFACE 17:00 - 19:00 2.00 CASE P INT2 FLUSH STACK, RIG DOWN CEMENT HEAD, LAY DOWN LANDING JT. 19:00 - 20:30 1.50 CASE P INT2 INSTALL PACK OFF AND TEST TO 5000# 20:30 - 23:00 2.50 DRILL P INT2 CHANGE RAMS FROM 5" TO 3.5 Printed: 4/1/2002 11: 13:39 AM ) BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-07 MPH-07 REENTER+COMPLETE NABORS DRILLING CO. NABORS 270 Start: 3/4/2002 Rig Release: 3/25/2002 Rig Number: 27E Spud Date: 3/4/2002 End: 3/25/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 3/9/2002 23:00 - 00:00 1.00 DRILL P INT2 PJSM, CHANGE TOP DRIVE TO 3.5 HANDLING EQUIP. 3/10/2002 00:00 - 01 :30 1.50 DRILL P LNR1 CHANGE TOP DRIVE TO 3.5 EQUIP. 01 :30 - 02:00 0.50 DRILL P LNR1 SERVICE TOP DRIVE 02:00 - 12:00 10.00 DRILL P LNR1 LAYING DOWN 5" DRILL PIPE 12:00 - 18:30 6.50 DRILL P LNR1 RIG UP AND TESTING BOPS TO 250 -3500PSI TEST WITNESS BY STATE REP. JOHN CRISP, ONE FAILURE UPPER KELLY VALVE, WILL CHANGE OUT BEFORE WE DRILL OUT 18:30 - 20:00 1.50 DRILL P LNR1 CUT DRILL LINE 20:00 - 21 :00 1.00 DRILL N RREP LNR1 ATTEMP TO BREAK UPPER KELLEY VALVE OFF TOP DRIVE, COULDN'T BREAK 21 :00 - 00:00 3.00 DRILL P LNR1 RIG UP IRON ROUGHNECK, PICKING 60 JTS 3.5 PIPE AND PUMP THRU PIPE TO CLEAR OUT SCALE AND STAND IN DERRICK 3/11 f2002 00:00 - 18:30 18.50 DRILL P LNR1 PICKING UP 3.5 PIPE 60 JTS AT A TIME AND PUMPING THRU AND STANDING IN DERRICK, TOTAL 138 STANDS 18:30 - 23:00 4.50 DRILL N RREP LNR1 PJSM, CHANGE OUT UPPER KELLY VALVE AND TEST 250 TO 3500 23:00 - 00:00 1.00 DRILL P LNR1 PICKING UP BHA#4 BIT HYCALOG DS 177,4-3/41-1/2 BEND MOTOR, 4-3/4 SLlMPHASE 4 W/DGR & EWR, 4-3/4 PWD/DIR MWD,2 FLEX DC, DRILL MILL, FLEX DC, JARS 3/12f2002 00:00 - 03:00 3.00 DRILL P LNR1 PICKING UP BHA #4 BIT HYCALOG DS 177,4-3/41-1/2 BEND MOTOR, 4-3/4 SLlMPHASE 4 WIDGR & EWR, 4-3/4 PWD/DIR MWD,2 FLEX DC, DRILL MILL, FLEX DC, JARS 03:00 - 04:00 1.00 DRILL P LNR1 TEST MWD, BLOW DOWN MUD LINES 04:00 - 05:00 1.00 DRILL P LNR1 TRIP IN TO 2073 05:00 - 05:30 0.50 DRILL P LNR1 DRLG CEMENT AND ES CEMENTER WITH 2-4,000 #, 50 RPM, 200 GALS MIN, 850 PSI 05:30 - 09:00 3.50 DRILL P LNR1 TRIP IN TO 9031 09:00 - 10:30 1.50 DRILL P LNR1 CIRC 10:30 - 11 :00 0.50 DRILL P LNR1 TEST CSG TO 3500#, HELD FOR 30 MIN. 11 :00 - 12:30 1.50 DRILL P LNR1 DRILL CEMENT AND LAND COLLAR @ 9115, FLOAT COLLAR @ 9158, SHOE @ 9202, WASH TO BOTTOM @ 9213 12:30 - 13:00 0.50 DRILL P LNR1 DRILL DIRECTIONAL 9213 TO 9243 13:00 - 13:30 0.50 DRILL P LNR1 CIRC WITH 65 RPM, 250 GALS MIN, 1800 PSI 13:30 - 14:00 0.50 DRILL P LNR1 FIT TEST TO 11# EMW. 450# PSI 9.1 MUD WT., HELD FOR 5 MIN., GOOD TEST 14:00 - 15:30 1.50 DRILL P LNR1 DISPLACE HOLE WITH, FLO-PRO. 9.0 MUD WT WITH 5% LUBE- TEX 15:30 - 00:00 8.50 DRILL P LNR1 DRILL DIRECTIONAL 9243 TO 9882 WITH 80 RPM 250 GALS MIN. 1850 # 5-8,000 BIT WT. ,TQ. 5-6,000 P/U 120K S/O 85K RIT 100K AST 1.5 ART 4, ECD 10.8 TO 10.9 3/13/2002 00:00 - 20:30 20.50 DRILL P LNR1 DRILL DIRECTIONAL 9882 TO 11234 WITH 85 RPM 250 GALS MIN. 2200 # 5-8,000 BIT WT. ,TQ. 5-6,000 P/U 120K S/O 75K RIT 95K AST5.7 ART 6.5, ECD 11.1 TO 11.3 20:30 - 22:30 2.00 DRILL N DPRB LNR1 CIRC. SETTING BACK 1 BACK STAND EVERY 30 MIN. WITH 250 GALS MIN. 2200 PSI 85 RPM TQ. 5K ( WAITING ON ORDERS.) 22:30 - 23:00 0.50 DRILL N DPRB LNR1 PUMP OUT TO 10,769 23:00 - 00:00 1.00 DRILL N DPRB LNR1 START OPEN HOLE SIDE TRACK@ 10,770 Printed: 4/1/2002 11: 13:39 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) ) BP EXPLORATION Operations Summary Report M PH-07 MPH-07 REENTER+COMPLETE NABORS DRILLING CO. NABORS 270 3/14/2002 3/15/2002 3/16/2002 3/17/2002 3/18/2002 00:00 - 05:30 05:30 - 00:00 00:00 - 11 :00 11 :00 - 13:00 13:00 - 17:00 17:00 - 19:00 19:00 - 23:30 23:30 - 00:00 00:00 - 02:30 02:30 - 05:00 05:00 - 07:30 07:30 - 10:30 10:30 - 12:30 12:30 - 15:30 15:30 - 21 :00 21 :00 - 22:00 22:00 - 00:00 00:00 - 03:00 03:00 - 09:30 09:30 - 10:00 10:00 - 13:00 13:00 - 18:00 18:00 - 19:00 19:00 - 00:00 00:00 - 01 :00 Page 5 of9 Start: 3/4/2002 Rig Release: 3/25/2002 Rig Number: 27E Spud Date: 3/4/2002 End: 3/25/2002 ~dðê 5.50 DRILL N 18.50 DRILL P 11.00 DRILL P 2.00 DRILL P 4.00 DRILL P 2.00 DRILL P 4.50 DRILL P 0.50 DRILL P 2.50 CASE P 2.50 CASE P 2.50 CASE P 3.00 CASE P 2.00 CASE P 3.00 CASE P 5.50 CASE P 1.00 CASE P 2.00 CASE P 3.00 DRILL P 6.50 DRILL P 0.50 DRILL P 3.00 DRILL P 5.00 DRILL P 1.00 DRILL P 5.00 DRILL P 1.00 DRILL P DPRB LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 LNR2 DRILL DIRECTIONAL 10770 TO 11234 WITH 85 RPM 250 GALS MIN. 2400 # 5-8,000 BIT WT. ,TO. 5-6,000 DRILL DIRECTIONAL 11234 TO 12346 WITH 85 RPM 250 GALS MIN. 2400 # 5-8,000 BIT WT. ,TO. 5-6,000 PIU 120K SIO 70K RIT 100K TOTAL AST 7 ART 6.5, ECD 11.3 TO 11.6 DRILL DIRECTIONAL 12346 TO TD 12998 WITH 85 RPM 250 GALS MIN. 2400 # 5-8,000 BIT WT. ,TO. 5-6,000 PIU 120K SIO 70K RIT 1 OOK TOTAL AST 1 ART 6.75, ECD 11.3 TO 11.6, TD OF SAND 12,594 CIRC. 90 RPM 275 GALS MIN. 2800 PSI PUMP OUT TO CSG SHOE @ 9202 (NO PROBLEMS) TRIP IN TO 12700 (NO PROBLEMS) CIRC 4 BOTTOMS UP WITH 90 RPMS 275 GALS MIN PUMP PRESSURE STARTED @ 2850 PSI ECD 11.7, DROP TO 2650 PSI, ECD 11.0, SPOT NEW MUD IN DRILL PIPE, PUMPING OUT, DISPLACING HOLE WITH NEW MUD PUMP OUT TO 9174, DISPLACING OPEN HOLE WITH NEW MUD TRIPPING OUT TO 4846 PICK UP 24- 4314 DC, 12- 31/2 HWT DRILL PIPE FOR WT. TO RUN LINER TOTAL 1103 FT. TRIPPING OUT TO BHA DOWN LOAD MWD, LAY DOWN BHA PICK UP PICK UP 86 JTS OF 4.5 SLOTTED LINER 3 JTS BLANK LINER AND LINER PACKER, LINER HANGER, 2 CENTRALIZER PER JT. TRIPPING IN WITH LINER ON DRILL PIPE, NO PROBLEMS SHOE @ 12613 LINER TOP 9084 PICK UP WT 140,000 SIO 90,000 DROP BALL AND SET LINER HANGER WITH 3600 PSI, RELEASE TOOL WITH 15 TURNS TO RIGHT, SHEAR BALL WITH 4300 PSI PICK UP WT AFTER LINER RELEASE 120,000 PUMP SLUG AND TRIPPING OUT WITH RUNNING TOOL FINISH TRIP OUT, LAY DOWN BAKER RUNNING TOOL PULL WEAR RING, TEST BOPS, HYDRIL AND CHOKE AND VALVES 250-3500 PSI, WITNESS OF BOP TEST WAS WAIVER BY JEFF JONES AOGC, INSTALL WEAR RING SERVICE TOPDRIVE PJSM, PICK UP SEAL ASSEMBL Y,11 JTS 3.5 DRILL PIPE,3.5 PUP JT WHIPSTOCK, STARTING MILL,2 TAPER MILLS,1 HWDP,MWD, BUMPER SUB,24 4 3/4 DC,12 HWDP TRIPPING IN HOLE WITH WHIPSTOCK ORIENT AND SET WHIPSTOCK 7 DEG TO THE RIGHT TOP OF WINDOW 8707 MILLING WINDOW TOP 8707 BOTTOM 8719 DRILLING TO 8726 WITH 250 GALS MIN. 1600 PSI 85-90 RPMS 2-10,000 MILL WT. MILLING WINDOW TOP 8707 BOTTOM 8719 DRILLING TO 8734 Printed: 41112002 11:13:39AM ) ) BP EXPLORATION Operations Summary Report Page 6 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M PH-07 MPH-07 REENTER+COMPLETE NABORS DRILLING CO. NABORS 270 Start: 3/4/2002 Rig Release: 3/25/2002 Rig Number: 27E Spud Date: 3/4/2002 End: 3/25/2002 Date From - To Hours Activity Code NPT Phas.e Descri ption of Operations 3/18/2002 00:00 - 01 :00 1.00 DRILL P LNR2 WITH 250 GALS MIN. 1600 PSI 85-90 RPMS 2-10,000 MILL WT. 01 :00 - 02:00 1.00 DRILL P LNR2 CIRC HIGH VIS. VIS SWEEP WITH 250 GALS MIN 90 RPMS 1600 PSI 02:00 - 04:30 2.50 DRILL P LNR2 TRIPPING OUT TO 2625 04:30 - 07:30 3.00 DRILL P LNR2 CUT DRILLING LINE, SERVICE RIG 07:30 - 09:00 1.50 DRILL P LNR2 TRIP OUT TO BHA 09:00 - 09:30 0.50 DRILL P LNR2 LAY DOWN WHIPSTOCK ASSEMBLY 09:30 - 10:30 1.00 DRILL P LNR2 FLUSH OUT BOPS WITH JOHNNY WACKER 10:30 - 12:00 1.50 DRILL P LNR2 PICK UP BHA #6 DS177 WITH 2X12 3X11 TFA .499, 4 3/4 MOTOR 1.5 BEND, 4 3/4 DGH & EWR PHASE 4, 4 3/4 PWD/MWD,2 FLEX DC, DRILL MILL. 1 FLEX DC, JARS 12:00 -16:00 4.00 DRILL P LNR2 TRIP IN TO TOP OF WINDOW @ 8707, ORIENT 30 DEG. TO RIGHT, PASS THRU WINDOW NO PROBLEM 16:00 - 00:00 8.00 DRILL P LNR2 DIRECTIONAL DRILL 8734 TO 9363 WITH 85 RPM 250 GALS MIN. 2100 PSI TO. 3-5,0005-8000# BIT WT. AST 1.25 ART 3 3/19/2002 00:00 - 10:00 10.00 DRILL P LNR2 DIRECTIONAL DRILL FROM 9,363' TO 10,370' - LOST SAND AT 10,370' ANGLE 84 DEGREE - AZ 193 - WOB 3K TO 6K - TO 5K - RPM 85 - GPM 250 - PP 2550 - ECD 11.3 - PU 125K- SO 90K - ROT 100K 10:00 - 23:00 13.00 DRILL N DPRB LNR2 DIRECTIONAL DRILLING FROM 10,370' TO 10,990' - LOOKING FOR OA SAND - 10,890' HIT SAND - ANGLE 84.5 DEGREE - AZ 198 - 10,990' - ANGLE 84 DEGREE - AZ 200 - WOB 2K TO 15K - RPM 85 - TO 5K TO 7K - GPM 250 - PP 2450 - ECD 11.2 - PU 130K - SO 90K - ROT 100K 23:00 - 00:00 1.00 DRILL N DPRB LNR2 CIRCULATE FOR GEOLOGIST 3/20/2002 00:00 - 02:30 2.50 DRILL N DPRB LNR2 CIRCULATE FOR GEOLOGIST @ 10,990' 02:30 - 03:00 0.50 DRILL N DPRB LNR2 POOH FROM 10,990' TO 10,170' 03:00 - 15:00 12.00 DRILL N DPRB LNR2 OPEN HOLE SIDE TRACK - LOW SIDE SIDETRACK - TURN LEFT SIDE AND UP BUILDING ANGLE TO 98 DEGREE - DIRECTIONAL DRILL FROM 10,170' TO 10,945' - LOOKING FOR OA SAND - WOB 5K TO 15K - RPM 80 - GPM 250 - PP 2500 - TO 5K TO 7K - ECD 11.2 - PU 130 - SO 80 - ROT 95 - ( WELLNAME MPH-07AL 1PB1 - API # 50-029-22597-71) 15:00 - 17:00 2.00 DRILL N DPRB LNR2 CIRCULATE FOR GEOLOGIST @ 10,945' 17:00 - 18:00 1.00 DRILL N DPRB LNR2 PUMP OUT FROM 10,945' TO 10,014' 18:00 - 21 :00 3.00 DRILL N DPRB LNR2 CIRCULATE FOR GEOLOGIST @ 10,014' 21 :00 - 00:00 3.00 DRILL N DPRB LNR2 OPEN HOLE SIDETRACK @ 10,120' - SIDETRACK TO LOW SIDE - DROP ANGLE TO 79 DEGREE - DIRECTIONAL DRILL FROM 10,120' TO 10,270' - LOOKING FOR OB SAND - WOB 5K TO 20K - RPM 80 - TO 5K - GPM 250 - PP 2250 - ECD 10.8 - PU 125K - SO 80K - ROT 1 OOK - (WELLNAME MPH-07 AL 1 PB2 - API# 50-029-22597-72) 3/21/2002 00:00 - 18:30 18.50 DRILL P LNR2 DIRECTIONAL DRILL FROM 10'270' TO T.D. AT 11'316'- WOB - 5K TO 15K RPM 85 - TO 5K TO 6K - GPM 250 - PP 2800 - PU 125 - SO 80 - ROT 100 - ECD 11.7 18:30 - 19:00 0.50 DRILL P LNR2 CIRCULATE FOR 30 MINS - GPM 250 - PP 2500 19:00 - 20:30 1.50 DRILL P LNR2 PUMP OUT FROM 11'316' TO 10'120' 20:30 - 22:00 1.50 DRILL P LNR2 CIRCULATE FROM 10120' TO 10'200' - 2 TIMES BOTTOMS UP 5,200 STKS - GPM 275 - PP 2500 - 90 RPM - TO 4K TO 5K - AFTER 1000 STKS STAND ONE STAND BACK - CON'T Printed: 4/112002 11: 13:39 AM ^) ) BP EXPLORATION Operations Summary Report Page 7 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-07 MPH-07 REENTER+COMPLETE NABORS DRILLING CO. NABORS 270 Start: 3/4/2002 Rig Release: 3/25/2002 Rig Number: 27E Spud Date: 3/4/2002 End: 3/25/2002 Date From - To Hours Activity Code NPT Phase Description of Operations. 3/21/2002 20:30 - 22:00 1.50 DRILL P LNR2 CIRC FROM 10,108' TO 10,014' - TOTAL STKS 5,200 22:00 - 00:00 2.00 DRILL P LNR2 PUMP OUT TO SHOE @ 8,650' - 8,880' TO 8,840' PULLED 20K OVER - PUMP PRESSURE INCREASED 150 PSI - SLACK OFF THROUGH SECTION - PULLED BACK TO 8,816' PULLED TO 20K OVER - PUMP PRESSURE INCREASED 200 PSI - SLACK OFF TO 8,835' - ROTATE AT 20 RPM UP TO 8,806' NO OVER PULL NOTED - CON'T PULL OUT SLOWLY THROUGH WHIPSTOCK TO 8,650' WITH OUT PUMP OR ROTATION - BLOW DOWN TOP DRIVE 3/22/2002 00:00 - 00:30 0.50 DRILL P LNR2 RIG SERVICE - TOP DRIVE SERVICE 00:30 - 01 :30 1.00 DRILL P LNR2 RIH FROM 8,714' TO 10,120' - NO PROBLEMS - HOLE IN GOOD SHAPE 01 :30 - 03:30 2.00 DRILL P LNR2 CIRCULATE AT 10,120'- 3.5 X TIMES BOTTOMS UP - 9000 STKS - GPM 275 - RPM 90 - TQ 4K TO 5K 03:30 - 05:00 1.50 DRILL P LNR2 PUMP OUT FROM 10,120' TO 8,806' - GPM 210 - PU 130K - NO OVERPULL - PULL THROUGH WINDOW FROM 8,806' TO 8,621 WITH OUT PUMP - NO OVER PULL THROUGH WINDOW 05:00 - 08:00 3.00 DRILL P LNR2 PUMP DRY JOB - POOH FROM 8,621' TO BHA 08:00 - 10:00 2.00 DRILL P LNR2 LAY DOWN BHA - DOWN LOAD MWD 10:00 - 11 :00 1.00 DRILL P LNR2 PICK UP WHIPSTOCK RETRIEVING TOOL ASSEMBLY AND TEST MWD 11 :00 - 13:30 2.50 DRILL P LNR2 RIH WITH RETRIEVING ASSEMBLY TO 8,628 - ORIENT TOOL - 7 DEGREE TO HIGH SIDE 13:30 - 14:30 1.00 DRILL P LNR2 RIH FROM 8,626' TO 8706' - PU 120K - SO 90 - HOOKED ONTO WHIPSTOCK - PULLED AND SHEARED PIN @ 180K - (60K OVER) - STRING WEIGHT 127k 14:30 - 17:00 2.50 DRILL P LNR2 PULL 2 STANDS - PUMP DRY JOB - CON'T POOH FROM 8,535' TO 478' 17:00 - 19:00 2.00 DRILL P LNR2 LAY DOWN BHA - 8 DC - 5 HWDP - MWD - RETRIEVING TOOL - WHIPSTOCK - 9 JTS DP 19:00 - 19:30 0.50 DRILL P LNR2 CLEAN / CLEAR RIG FLOOR 19:30 - 20:00 0.50 DRILL P LNR2 PJSM (RUNNING 4.5" SLOTTED LINER) 20:00 - 21 :00 1.00 DRILL P LNR2 PU 4.5 SLOTTED LINER - (LINER WEIGHT 15K) 21 :00 - 21 :30 0.50 DRILL P LNR2 RIG DOWN LINER EQUIPMENT - CHANGE ELEVATORS 21 :30 - 00:00 2.50 DRILL P LNR2 RIH WITH 4.5" LINER ON 3.5" DP FROM 1,417' TO 5,010' - (STRING WEIGHT AT 5010' - PU 100K - SO 95K) 3/23/2002 00:00 - 02:00 2.00 DRILL P LNR2 RIH WITH 4.5" LINER ON 3.5" DP FROM 5,010' TO 8,728' - 9' BELOW WINDOW 02:00 - 08:00 6.00 DRILL P LNR2 PICK UP TO 8,714' WITH STRING IN TENSION - ROTATE SLOWLY WATCHING FOR TORQUE SPIKES - NO SPIKES COULD BE SEEN - RIH TAG OB LINER TOP AT 9,084' - PULL BACK TO WINDOW - CONTINUE WORKING PIPE WITH TENSION - NEVER DID SEE ANY TORQUE SPIKES - RIH TAG OB LINER TOP @ 9,084' EACH TIME - WORKED PIPE AS ABOVE 20+ TIMES THOUGH OUT WINDOW 8,707' TO 8,720'- NO SUCCESS GETTING OUT OF WINDOW 08:00 - 08:30 0.50 DRILL P LNR2 WITH GUIDE SHOE 15' BELOW WINDOW @ 8,734'- PICK UP ROTATING SLOWLY TO TOP OF WINDOW AT 8,709' - NO INDICATION OF TORQUE SPIKES - RIH TAG UP AT 8,782'- 63' BELOW BOTTOM OF WINDOW - WORK PIPE- COULD NOT GET PASSED 8,872' - KEEP TAGGING UP SAME PLACE - SOLID - METAL ON METAL Printed: 4/1/2002 11: 13: 39 AM ) ) BP EXPLORATION Operations Summary Report Page 8 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-07 MPH-07 REENTER+COMPLETE NABORS DRILLING CO. NABORS 270 Start: 3/4/2002 Rig Release: 3/25/2002 Rig Number: 27E Spud Date: 3/4/2002 End: 3/25/2002 Date From - To Hours Activity Code NPT Phase Description of Operations 3/23/2002 08:30 - 11 :00 2.50 DRILL N DPRB LNR2 POOH FROM 8,872' TO LINER 1,416' 11 :00 - 11 :30 0.50 DRILL N DPRB LNR2 REMOVE BAKER SWIVEL TENSION LOCK 11 :30 - 14:30 3.00 DRILL N DPRB LNR2 RIH WITH 4.5" LINER - FROM 1,416' TO 8,714' 14:30 - 16:00 1.50 DRILL P LNR2 WITH LINER @ MIDDLE OF WINDOW - ROTATED DP UNTIL TORQUE SPIKED (TORQUE 3500) - SLACKED OFF AND EXIT WINDOW ON FIRST TRY - LINER SET DOWN HARD @ 8,833' (METAL TO METAL) - ATTEMPT TO FREE BY ROTATING (TORQUE 6000) NO LUCK ON ROTATING OFF- WORKED PIPE SLOWLY - FELL FREE - TAKING WEIGHT EVERY 20' (CENTRALIZERS) - NO GO AT 8,913' - WORKED PIPE HARD - FELL FREE - NO PROBLEMS BELOW 8,913' - (MECHANICAL PROBLEMS GONE) 16:00 - 17:00 1.00 DRILL P LNR2 CONTINUE RIH WITH 4.5" SLOTTED LINER TO 10,104' - PLACED HOOK WALL HANGER ON BOTTOM OF WINDOW AT 8,719' ON 2ND ATTEMPT 17:00 - 18:30 1.50 DRILL P LNR2 DROP BALL - PUMPED DOWN DP @ 20 SPM - 450 PSI - PRESSURE UP TO 3500 PSI TO SET WALL HANGER - PRESSURE UP TO 4300 PSI TO SHEAR OUT 18:30 - 20:30 2.00 DRILL P LNR2 PUMP DRY JOB - POOH FROM 8,650' TO 4,745' 20:30 - 21 :30 1.00 DRILL P LNR2 RIG SERVICE - TOP DRIVE SERVICE 21 :30 - 00:00 2.50 DRILL P LNR2 POOH - LAY DOWN DP - 8 STANDS OF DC'S FROM 4,745' TO 2,325' 3/24/2002 00:00 - 01 :30 1.50 DRILL P LNR2 POOH LAYING DOWN 3.5" DP FROM 2,325' 01 :30 - 02:00 0.50 DRILL P LNR2 UD LINER RUNNING TOOLS 02:00 - 07:30 5.50 DRILL P LNR2 PIU BRIDGE PLUG - TIH WITH 3.5" DP TO 8,665' 07:30 - 08:00 0.50 DRILL P LNR2 PJSM ON SETTING BRIDGE PLUG - TESTING BRIDGE PLUG 08:00 - 10:00 2.00 DRILL P LNR2 CUT DRLG LINE - CHECK C-O-M 10:00 - 10:30 0.50 DRILL P LNR2 RIG SERVICE - TOP DRIVE SERVICE 10:30 - 12:00 1.50 DRILL P LNR2 CIRCULATE 1 COND - 40 STKS @ 740 PSI 12:00 - 12:30 0.50 DRILL P LNR2 PJSM ON DISPLACING MUD WITH KCL 12:30 - 14:00 1.50 DRILL P LNR2 FIRST STAGE - PUMP 580 BBLS OF SEAWATER AT 100 SPM - 3850 PSI 14:00 - 14:30 0.50 DRILL P LNR2 FLUSH OUT KILL LINE WITH 50 BBLS OF FRESH WATER 14:30 -15:00 0.50 DRILL P LNR2 2ND STAGE PUMP 300 BBLS OF 9 # KCL AT 80 SPM - 2050 PSI 15:00 - 15:30 0.50 DRILL P LNR2 BLOW DOWN LINES - RIG UP TO LAY DOWN 3.5" DP 15:30 - 22:00 6.50 DRILL P LNR2 LAY DOWN 3.5" DP 22:00 - 22:30 0.50 DRILL P LNR2 PULL WEAR RING 22:30 - 23:00 0.50 DRILL P LNR2 RIG UP TO RUN 2.875" TUBING 23:00 - 23:30 0.50 DRILL P LNR2 PJSM ON RUNNING 2.875" TUBING AND ASSOCIATED HARZARDS 23:30 - 00:00 0.50 DRILL P LNR2 RIH WITH RETRIEVING TOOL - 2.875" TUBING 3/25/2002 00:00 - 07:00 7.00 CASE P LNR2 RIH PICKING UP 2.875 TUBING AND LAND AT 8637' 07:00 - 08:00 1.00 CASE P LNR2 RUN IN LOCK DOWN SCREWS - TEST TO 1000 PSI FOR 10 MINS - GOOD TEST 08:00 - 10:30 2.50 CASE P LNR2 CHANGE OUT 3.5" RAMS TO 5" VARIABLE RAMS TOP - 5" RAMS BOTTOM 10:30 - 12:00 1.50 CASE P LNR2 NIPPLE DOWN BOP'S 12:00 - 14:00 2.00 CASE P LNR2 NIPPLE UP TREE - TESTED PACK-OFF TO 5000 PSI FOR 10 MINS - TEST TREE TO 5000 PSI FOR 10 MINS (NO LEAKS TEST GOOD) 14:00 - 15:00 1.00 CASE P LNR2 PULL TWC - RIG UP TO FREEZE PROTECT WELL Printed: 4/1/2002 11: 13:39 AM ) ) BP EXPLORATION Operations Summary Report Page 9 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-07 MPH-07 REENTER+COMPLETE NABORS DRILLING CO. NABORS 270 Start: 3/4/2002 Rig Release: 3/25/2002 Rig Number: 27E Spud Date: 3/4/2002 End: 3/25/2002 3/25/2002 15:00 - 16:00 1.00 CASE P LNR2 PJSM ON FREEZE PROTECTING 16:00 - 16:30 0.50 CASE P LNR2 FREEZE PROTECT WELL 60 BBLS OF DIESEL AT 3 BBLS PER MIN WITH HB&R 16:30 - 17:00 0.50 CASE P LNR2 LET DIESEL U-TUBE FOR 30 MINS 17:00 - 18:00 1.00 CASE P LNR2 RIG DOWN HB&R - SET BACK PRESSURE VALVE 18:00 - 19:00 1.00 CASE P LNR2 PICK UP CELLAR AREA - RIG FLOOR - RIG RELEASE Printed: 4/1/2002 11: 13:39 AM ) ") BP EXPLORATION Operations Summary Report Page 1 of 1 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 3/29/2002 3/30/2002 3/31/2002 MPH-07 MPH-07 COMPLETION NABORS NABORS 4ES Start: 3/29/2002 Rig Release: 3/31/2002 Rig Number: Spud Date: 3/4/2002 End: 3/31/2002 From - To Hours Activity Code NPT Phase Description of Operations 18:00 - 00:00 6.00 MOB N WAIT PRE WAIT ON TRUCKS /NO TRUCKS AVAIABLE MOVING OTHER RIGS. 00:00 - 06:00 6.00 MOB P PRE MI/RU SAFE OUT EQUIPMENT ACCEPT RIG @ 0600 HRS. 3/30/2002 06:00 - 07:00 1.00 KILL P DECOMP RIG LINES TO TREE FOR BLEED OFF & CIRC. CHECK ANNULUS WELL BORE DEAD. 07:00 - 08:00 1.00 KILL P DECOMP RIG UP & PULL BPV & SET TWC & TEST TO 3500 PSI. 08:00 - 09:30 1.50 WHSUR P DECOMP NIPPLE DN TREE 09:30 - 11 :30 2.00 BOPSUR P DECOMP NIPPLE UP BOP 11 :30 - 13:00 1.50 BOPSURP DECOMP PRESSURE TEST BOP TO 250 LOW /3500 HIGH BODY TEST/ TEST WAIVED BY JOHN CRISP WITH AOGC. 13:00 - 14:00 1.00 WHSUR P DECOMP RIG LUB & PULL TWC. 14:00 - 16:00 2.00 KILL P DECOMP CIRC FREEZE PROTECTION TO TIGER TANK. 16:00 - 16:30 0.50 PULL P DECOMP BOLDS & PULL HANGER TO FLOOR & LAY DN SAME 16:30 - 17:00 0.50 PULL P DECOMP MU TWO JT. & TAG PACKER & RELEASE. 17:00 - 19:30 2.50 KILL P DECOMP CIRC WELL BORE TO CLN-INFLUX FROM SAME. & MONITOR 19:30 - 23:30 4.00 PULL P DECOMP POOH WITH BAKER BRIDGE PLUG. 23:30 - 00:00 0.50 PULL P DECOMP LAY DN BAKER PACKER. 00:00 - 00:30 0.50 PULL P DECOMP CLN-RIG FLOOR & PREPARE TOOLS FOR COMPLETION RUN. 00:30 - 03:30 3.00 RUNCOrvP COMP MAKE UP & SERVICE & TEST ESP ASSY. 03:30 - 08:30 5.00 RUNCOrvP COMP RIH WITH ESP ASSY. TO SETTING DEPTH @ 8142' 08:30 - 10:00 1.50 RUNCOrvP COMP MAKE UP HANGER & INSTALL EFT CONNECTOR. & LAND HANGER & RILDS. 10:00 - 10:30 0.50 RUNCOrvP COMP SET TWC & TEST. 10:30 - 12:00 1.50 BOPSURP COMP NIPPLE DN BOP 12:00 - 13:00 1.00 WHSUR P COMP NIPPLE UP TREE. 13:00 - 13:30 0.50 WHSUR P COMP TEST ADPT. FLG. & TREE TO 5000 PSI. & FINAL ESP CHECK. 13:30 - 14:30 1.00 WHSUR P COMP PULL TWC & SET SPV. 14:30 - 15:00 0.50 WHSUR P COMP RIG DN TEST EQUIPMENT. & SECURE TREE AREA. RIG RELEASED @ 1500 HRS. 3/31/2002 Printed: 4/1/2002 11:14:57 AM ') '> aD~-C:ÖL/ 03-Apr-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well MPH-07A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,747.16' MD Window / Kickoff Survey 10,770.00' MD (if applicable) Projected Survey: 12,998.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED Þ..PR f~ 2002 Alalkaœ&GasCons.CUaltD1Rion AnooCi8Qð Milne Point Unit BPXA Milne Point MPH, Slot MPH-07 MPH-07A Job No. AKZZ22041s Surveyed: 15 March, 2002 SURVEY REPORT 28 March, 2002 Your Ref: API 500292259701 Surface Coordinates: 6009860.68 Ns 556567.80 E (700 26'15.3208" Ns 149032'19.5685" W) Kelly Bushing: 71.00ft above Mean Sea Level sper-''-'Y-sur, DAfLLINS .seAVltes A Halliburton Company FINITI ~,~/- ~ Survey Ref: svy10094 Sperry-Sun Drilling Servíces Survey Report for MPH-07 A Your Ref: API 500292259701 Job No. AKZZ22041, Surveyed: 15 March, 2002 BPXA Milne Point Unit Milne Point MPH 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) (°/1 OOft) 10747.16 94.670 196.240 4111.23 4182.23 8148.14 S 321.19 W 6001710.34 N 556308.42 E 8151.31 Tie On Point 10770.00 95.610 195.940 4109.18 4180.18 8169.99 S 327.50 W 6001688.44 N 556302.28 E 4.318 8173.54 Window Point 10792.26 92.250 196.850 4107.66 4178.66 8191.29 S 333.77 W 6001667.09 N 556296.18 E 15.635 8195.22 ~ 10840.35 95.240 196.290 4104.52 4175.52 8237.28 S 347.45 W 6001621.00 N 556282.84 E 6.325 8242.02 10888.60 94.530 192.320 4100.41 4171.41 8283.86 S 359.32 W 6001574.34 N 556271.32 E 8.329 8289.29 10934.77 95.230 189.950 4096.48 4167.48 8328.99 S 368.21 W 6001529.14 N 556262.78 E 5.335 8334.92 10980.86 93.930 188.780 4092.80 4163.80 8374.32 S 375.68 W 6001483.75 N 556255.65 E 3.789 8380.65 11026.56 94.350 188.660 4089.50 4160.50 8419.37 S 382.59 W 6001438.65 N 556249.08 E 0.956 8426.06 11073.87 93.410 187.690 4086.30 4157.30 8466.09 S 389.31 W 6001391.88 N 556242.72 E 2.852 8473.13 11119.28 92.310 186.550 4084.03 4155.03 8511.10 S 394.93 W 6001346.83 N 556237.44 E 3.486 8518.41 11166.67 92.430 187.330 4082.07 4153.07 8558.10 S 400.65 W 6001299.79 N 556232.08 E 1.664 8565.69 11209.93 92.630 186.170 4080.16 4151.16 8601.02 S 405.73 W 6001256.83 N 556227.33 E 2.718 8608.85 11259.50 93.130 186.400 4077.67 4148.67 8650.22 S 411.15W 6001207.59 N 556222.28 E 1.110 8658.31 11305.31 93.290 187.280 4075.11 4146.11 8695.64 S 416.59 W 6001162.13 N 556217.18 E 1.950 8703.99 11351.12 92.490 187.150 4072.80 4143.80 8741.03 S 422.34 W 6001116.70 N 556211.78 E 1.769 8749.66 11400.38 93.590 186.390 4070.19 4141.19 8789.87 S 428.14 W 6001067.81 N 556206.35 E 2.713 8798.78 11443.90 93.350 186.800 4067.55 4138.55 8833.03 S 433.13 W 6001024.62 N 556201.69 E 1.090 8842.17 11494.36 90.440 185.150 4065.88 4136.88 8883.18 S 438.38 W 6000974.43 N 556196.82 E 6.628 8892.56 11536.77 88.540 185.360 4066.26 4137.26 8925.40 S 442.26 W 6000932.18 N 556193.25 E 4.507 8934.96 11583.94 88.700 184.920 4067.40 4138.40 8972.37 S 446.49 W 6000885.18 N 556189.39 E 0.992 8982.10 ~ 11629.16 89.440 184.660 4068.13 4139.13 9017.43 S 450.26 W 6000840.10 N 556185.95 E 1.734 9027.31 11675.40 87.250 185.800 4069.47 4140.47 9063.45 S 454.47 W 6000794.04 N 556182.09 E 5.339 9073.51 11721.51 88.470 186.520 4071.19 4142.19 9109.26 S 459.42 W 6000748.19 N 556177.49 E 3.072 9119.55 11768.00 88.140 186.380 4072.56 4143.56 9155.44 S 464.64 W 6000701.98 N 556172.62 E 0.771 9165.97 11815.19 90.940 187.070 4072.94 4143.94 9202.30 S 470.16 W 6000655.08 N 556167.45 E 6.111 9213.10 11860.49 93.590 189.120 4071.15 4142.15 9247.10 S 476.54 W 6000610.23 N 556161.42 E 7.394 9258.23 11907.23 93.380 188.930 4068.31 4139.31 9293.18 S 483.85 W 6000564.10 N 556154.45 E 0.605 9304.70 11952.68 93.140 187.930 4065.73 4136.73 9338.07 S 490.51 W 6000519.16 N 556148.14 E 2.259 9349.93 11999.77 91.780 186.500 4063.70 4134.70 9384.74 S 496.41 W 6000472.45 N 556142.59 E 4.189 9396.89 12046.13 91.910 185.510 4062.21 4133.21 9430.82 S 501.26 W 6000426.33 N 556138.09 E 2.153 9443.19 28 March, 2002 - 16:07 Page 2 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPH-07 A Your Ref: API 500292259701 Job No. AKZZ22041, Surveyed: 15 March, 2002 BPXA Milne Point Unit Milne Point MPH 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) (°/1 OOft) 12092.01 91.750 182.380 4060.75 4131.75 9476.56 S 504.42 W 6000380.57 N 556135.28 E 6.828 9489.04 12137.77 89.830 181.140 4060.12 4131.12 9522.29 S 505.82 W 6000334.83 N 556134.22 E 4.995 9534.77 ~~ 12185.92 89.800 179.370 4060.27 4131.27 9570.44 S 506.04 W 6000286.68 N 556134.37 E 3.677 9582.82 12229.59 89.980 179.170 4060.35 4131.35 9614.11 S 505.48 W 6000243.02 N 556135.26 E 0.616 9626.35 12277.56 90.310 179.080 4060.23 4131.23 9662.07 S 504.75 W 6000195.06 N 556136.36 E 0.713 9674.16 12323.77 90.600 178.410 4059.87 4130.87 9708.27 S 503.73 W 6000148.87 N 556137.72 E 1.580 9720.18 12370.41 90.660 177.730 4059.35 4130.35 9754.88 S 502.16 W 6000102.27 N 556139.64 E 1.464 9766.58 12416.70 90.590 178.460 4058.85 4129.85 9801.14S 500.63 W 6000056.03 N 556141.53 E 1.584 9812.63 12464.70 91.300 178.070 4058.06 4129.06 9849.11 S 499.17 W 6000008.07 N 556143.35 E 1.688 9860.40 12509.91 91.260 177.160 4057.05 4128.05 9894.27 S 497.29 W 5999962.92 N 556145.57 E 2.014 9905.33 12558.07 91.500 177.280 4055.89 4126.89 9942.36 S 494.96 W 5999914.85 N 556148.27 E 0.557 9953.15 12603.44 91.820 177.280 4054.57 4125.57 9987.66 S 492.80 W 5999869.57 N 556150.77 E 0.705 9998.21 12651.40 90.150 177.560 4053.75 4124.75 10035.56 S 490.65 W 5999821.69 N 556153.29 E 3.531 10045.86 12697.22 88.090 176.890 4054.45 4125.45 10081.32 S 488.43 W 5999775.95 N 556155.86 E 4.728 10091.36 12744.35 87.610 177.750 4056.22 4127.22 10128.36 S 486.23 W 5999728.92 N 556158.42 E 2.089 10138.15 12789.69 87.660 177.350 4058.09 4129.09 10173.62 S 484.29 W 5999683.68 N 556160.69 E 0.888 10183.18 12834.71 87.260 177.870 4060.09 4131.09 10218.56 S 482.41 W 5999638.76 N 556162.91 E 1.456 10227.89 12881.04 87.060 176.860 4062.38 4133.38 10264.78 S 480.29 W 5999592.55 N 556165.39 E 2.220 10273.87 12926.48 86.590 177.200 4064.90 4135.90 10310.09 S 477.94 W 5999547.26 N 556168.08 E 1.276 10318.92 12998.00 86.590 177.200 4069.15 4140.15 10381.40 S 474.45 W 5999475.98 N 556172.11 E 0.000 10389.83 Projected Survey ~ý All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 183.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12998.00ft., The Bottom Hole Displacement is 10392.24ft., in the Direction of 182.617° (True). 28 March, 2002 - 16:07 Page 3 of4 DrillQuest 2.00.08.005 .. , ~.;;;;':'~ ~ ^ . ~ ~ . Sperry-Sun Drilling Services" Survey Report for MPH-07 A Your Ref: API 500292259701 Job No. AKZZ22041, Surveyed: 15 March, 2002 Milne Point Unit BPXA Milne Point MPH Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~~ 1 0747.16 10770.00 12998.00 4182.23 4180.18 4140.15 8148.14 S 8169.99 S 10381.40 S 321.19 W 327.50 W 474.45 W Tie On Point Window Point Projected Survey Survey tool program for MPH-07 A From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 8075.48 0.00 4039.54 8075.48 12998.00 4039.54 MWD Magnetic (MPH-07) 4140.15 AK-6 BP _IFR-AK (MPH-07A PB1) ~~* ---- 28 March, 2002 - 16:07 Page 4 of4 DrillQuest 2.00.08.005 ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Oefinative Surveys Re: Distribution of Survey Data for Well MPH-07A PB1 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,075.48' MD Window / Kickoff Survey 8,149.00' MD (if applicable) Projected Survey: 11,234.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~Od'~~,-/ 03-Apr-02 RECEIVED tPR f~ 2002 AlalkaOil&GasQl\S.COßaniIIon And\Ø DEFf Milne Point Unit BPXA Milne Point MPH, Slot MPH-07 MPH-07 APB1 Job No. AKZZ22041, Surveyed: 13 March, 2002 SURVEY REPORT 28 March, 2002 Your Ref: 500292259770 Surface Coordinates: 6009860.68 N, 556567.80 E (700 26' 15.3208" N, 149032' 19.5685" W) Kelly Bushing: 71.00ft above Mean Sea Level =pe.-..-.y-sur, DAILLING seRvun:::.ss A Halliburton Company ITi --/ _/ Survey Ref: 5vy10093 Sperry-Sun Drilling Services Survey Report for MPH-07 A PB1 Your Ref: 500292259770 Job No. AKZZ22041, Surveyed: 13 March, 2002 BPXA Milne Point Unit Milne Point MPH 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) (°/1 OOft) 8075.48 77.41 0 172.310 3968.54 4039.54 5802.34 S 788.83 E 6004064.49 N 557400.62 E 5736.28 Tie On Point AK-6 BP _IFR-AK -' 8149.00 76.130 172.070 3985.37 4056.37 5873.24 S 798.55 E 6003993.66 N 557410.88 E 1.770 5806.37 Window Point 8180.14 75.310 174.660 3993.05 4064.05 5903.22 S 802.04 E 6003963.72 N 557414.60 E 8.479 5836.04 8276.17 74.830 182.730 4017.83 4088.83 5995.89 S 804.16 E 6003871.06 N 557417.42 E 8.135 5928.37 8368.78 74.840 190.270 4042.09 4113.09 6084.63 S 794.05 E 6003782.25 N 557407.98 E 7.858 6017.58 8462.81 79.370 192.190 4063.07 4134.07 6174.50 S 776.19 E 6003692.24 N 557390.81 E 5.212 6108.45 8555.60 80.890 195.940 4078.98 4149.98 6263.16 S 753.97 E 6003603.42 N 557369.26 E 4.305 6198.40 8650.86 80.670 199.020 4094.25 4165.25 6352.84 S 725.73 E 6003513.53 N 557341.70 E 3.200 6289.77 8744.54 80.480 198.680 4109.59 4180.59 6440.29 S 695.88 E 6003425.85 N 557312.51 E 0.411 6379.04 8837.79 80.760 201.720 4124.79 4195.79 6526.63 S 664.11 E 6003339.28 N 557281.40 E 3.230 6467.31 8931.50 79.770 207.780 4140.65 4211.65 6610.46 S 625.4 7 E 6003255.15 N 557243.39 E 6.460 6553.55 9026.90 84.250 210.660 4153.91 4224.91 6692.88 S 579.36 E 6003172.39 N 557197.91 E 5.566 6638.88 9073.14 88.870 210.090 4156.68 4227.68 6732.69 S 556.02 E 6003132.40 N 557174.88 E 10.067 6680.16 9121.87 88.790 210.930 4157.68 4228.68 6774.66 S 531.29 E 6003090.24 N 557150.46 E 1.731 6723.70 9151.73 87.720 210.390 4158.59 4229.59 6800.34 S 516.07 E 6003064.45 N 557135.44 E 4.013 6750.34 9213.42 87.480 209.060 4161.17 4232.17 6853.86 S 485.51 E 6003010.70 N 557105.28 E 2.189 6805.80 9262.67 90.070 209.080 4162.22 4233.22 6896.89 S 461.59 E 6002967.49 N 557081.69 E 5.259 6850.34 9306.26 90.220 209.240 4162.11 4233.11 6934.96 S 440.35 E 6002929.26 N 557060.74 E 0.503 6889.74 9352.89 90.170 208.580 4161.95 4232.95 6975.78 S 417.80 E 6002888.27 N 557038.51 E 1.419 6931.98 - 9394.54 89.710 210.060 4162.00 4233.00 7012.09 S 397.41 E 6002851.80 N 557018.39 E 3.721 6969.58 9444.96 89.780 212.460 4162.22 4233.22 7055.19 S 371.25 E 6002808.51 N 556992.55 E 4.762 7014.34 9491.72 89.720 215.210 4162.43 4233.43 7094.02 S 345.21 E 6002769.48 N 556966.81 E 5.882 7054.84 9538.06 90.500 218.180 4162.34 4233.34 7131.18 S 317.53 E 6002732.12 N 556939.41 E 6.626 7093.76 9583.71 90.890 218.090 4161.78 4232.78 7167.08 S 289.34 E 6002696.00 N 556911.50 E 0.877 7131.48 9629.00 89.030 217.780 4161.81 4232.81 7202.80 S 261.50 E 6002660.07 N 556883.93 E 4.164 7168.99 9676.81 88.600 216.990 4162.80 4233.80 7240.78 S 232.48 E 6002621.87 N 556855.19 E 1.881 7208.83 9723.17 89.840 217.300 4163.43 4234.43 7277.73 S 204.49 E 6002584.71 N 556827.48 E 2.757 7247.58 9768.76 90.180 216.830 4163.43 4234.43 7314.11 S 177.01 E 6002548.13 N 556800.28 E 1.272 7285.72 9814.49 91.790 217.240 4162.64 4233.64 7350.61 S 149.47 E 6002511.42 N 556773.02 E 3.633 7323.98 9862.77 91.870 217.110 4161.10 4232.10 7389.06 S 120.31 E 6002472.75 N 556744.16 E 0.316 7364.30 ------.- 28 March, 2002 - 16:06 Page 2 0'4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPH-07 A PB1 Your Ref: 500292259770 Job No. AKZZ22Q41, Surveyed: 13 March, 2002 BPXA Milne Point Unit Milne Point MPH 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) (°/1 OOft) 9907.25 94.200 218.000 4158.74 4229.74 7424.27 8 93.24 E 6002437.33 N 556717.35 E 5.606 7401.25 9955.77 94.350 217.430 4155.13 4226.13 7462.54 8 63.64 E 6002398.84 N 556688.04 E 1.212 7441.43 '-i' 10012.08 92.640 215.440 4151.69 4222.69 7507.768 30.26 E 6002353.37 N 556655.01 E 4.654 7488.78 10059.52 90.090 214.240 4150.56 4221.56 7546.68 8 3.17 E 6002314.24 N 556628.22 E 5.940 7529.43 10094.15 90.310 214.240 4150.44 4221.44 7575.31 8 16.31 W 6002285.47 N 556608.95 E 0.635 7559.31 10142.79 90.410 212.330 4150.14 4221.14 7615.96 8 43.00 W 6002244.61 N 556582.57 E 3.932 7601.66 10188.20 90.860 212.810 4149.63 4220.63 7654.23 8 67.45 W 6002206.16 N 556558.41 E 1.449 7641.49 10235.55 91.350 213.190 4148.72 4219.72 7693.93 8 93.23 W 6002166.26 N 556532.93 E 1.309 7682.83 10281.30 92.910 211.980 4147.02 4218.02 7732.45 8 117.85 W 6002127.55N 556508.60 E 4.314 7722.92 10328.39 92.500 212.440 4144.80 4215.80 7772.25 S 142.92 W 6002087.57 N 556483.83 E 1.308 7764.31 10375.82 90.620 208.490 4143.51 4214.51 7813.11 8 166.96 W 6002046.53 N 556460.11 E 9.220 7806.69 10421.36 94.550 209.900 4141.45 4212.45 7852.82 8 189.14 W 6002006.66 N 556438.23 E 9.167 7847.79 10467.38 94.050 209.400 4138.00 4209.00 7892.708 211.84 W 6001966.60 N 556415.83 E 1.534 7889.11 10514.74 95.040 206.910 4134.25 4205.25 7934.32 8 234.12 W 6001924.81 N 556393.87 E 5.642 7932.13 10561.96 95.690 205.200 4129.83 4200.83 7976.55 S 254.77 W 6001882.43 N 556373.54 E 3.859 7975.66 10608.17 96.840 204.770 4124.79 4195.79 8018.198 274.17 W 6001840.65 N 556354.46 E 2.655 8018.50 10650.82 95.780 201.150 4120.10 4191.10 8057.21 S 290.70 W 6001801.49 N 556338.22 E 8.795 8058.55 10700.65 95.320 198.300 4115.28 4186.28 8103.89 8 307.44 W 6001754.69 N 556321.84 E 5.767 8106.25 10747.16 94.670 196.240 4111 .23 4182.23 8148.148 321.19 W 6001710.34 N 556308.42 E 4.628 8151.31 10793.73 96.600 195.630 4106.66 4177.66 8192.708 333.92 W 6001665.69 N 556296.04 E 4.344 8196.63 ~ 10840.57 97.160 194.400 4101.05 4172.05 8237.61S 345.96 W 6001620.68 N 556284.33 E 2.868 8242.25 10888.50 96.500 191.300 4095.35 4166.35 8284.00 8 356.55 W 6001574.21 N 556274.10 E 6.568 8289.25 10935.31 96.460 187.480 4090.06 4161.06 8329.88 S 364.13 W 6001528.28 N 556266.86 E 8.109 8335.53 10982.26 94.890 186.360 4085.42 4156.42 8376.26 8 369.76 W 6001481.86 N 556261.59 E 4.101 8382.18 11028.13 95.040 185.310 4081.45 4152.45 8421.72 8 374.41 W 6001436.36 N 556257.29 E 2.304 8427.85 11073.51 94.750 184.800 4077.58 4148.58 8466.76 8 378.39 W 6001391.30 N 556253.64 E 1.289 8473.06 11117.06 94.550 185.300 4074.05 4145.05 8510.008 382.21 W 6001348.03 N 556250.15 E 1.233 8516.45 11234.00 94.550 185.300 4064.77 4135.77 8626.07 8 392.98 W 6001231.88 N 556240.26 E 0.000 8632.99 Projected Survey ----- 28 March, 2002 - 16:06 Page 3 of4 DrillQuest 2.00.08.005 ,Sperry-Sun Drilling ServIces Survey Report for MPH-07 A PB1 Your Ref: 500292259770 Job No. AKZZ22041, Surveyed: 13 March, 2002 Milne Point Unit BPXA Milne Point MPH All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.014° (04-Mar-02) ~- The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 183.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11234.00ft., The Bottom Hole Displacement is 8635.02ft., in the Direction of 182.608° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8075.48 8149.00 11234.00 4039.54 4056.37 4135.77 5802.34 S 5873.24 S 8626.07 S 788.83 E 798.55 E 392.98 W Tie On Point Window Point Projected Survey .~ Survey tool program for MPH-07 A PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 8075.48 0.00 8075.48 4039.54 11234.00 4039.54 MWD Magnetic (MPH-07) 4135.77 AK-6 BP _IFR-AK (MPH-07A PB1) 28 March, 2002 - 16:06 Page 4 of 4 DrillQuest 2.00.08.005 ') ) eXDd-Od.4 03-Apr-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPH-07A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,747.16' MD Window / Kickoff Survey 10,770.00' MD (if applicable) Projected Survey: 12,998.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED þ,PR L~ 2002 Alaska Oil & Gas Cons. CoIIInIIIi6n Anchorage Milne Point Unit BPXA Milne Point MPH, Slot MPH-07 MPH-07 A MWD Job No. AKMW22041, Surveyed: 15 March, 2002 '--" SURVEY REPORT 28 March, 2002 Your Ref: API 500292289701 Surface Coordinates: 6009860.68 N, 556567.80 E (700 26' 15.3208" N, 149032'19.5685" W) Kelly Bushing: 71.00ft above Mean Sea Level - sper-'I'Y-sur, CRILL"ING seAVIc:e$ A Halliburton Company Survey Ref: 5vy10099 Sperry-Sun Drilling Services Survey Report for MPH-07 A MWD Your Ref: API 500292289701 Job No. AKMW22041s Surveyed: 15 Marchs 2002 BPXA Milne Point Unit Milne Point MPH 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) 10747.16 94.670 196.740 4111.23 4182.23 8141.46 S 333.39 W 6001716.92 N 556296.17 E 8145.48 Tie On Point 10770.00 95.610 195.940 4109.19 4180.19 8163.29 S 339.79 W 6001695.04 N 556289.94 E 5.395 8167.69 Window Point '--__.9;' 10792.26 92.250 197.360 4107.66 4178.66 8184.57 S 346.15 W 6001673.72 N 556283.74 E 16.381 8189.34 10840.35 95.240 196.850 4104.52 4175.52 8230.42 S 360.27 W 6001627.76 N 556269.97 E 6.307 8236.04 10888.60 94.530 192.920 4100.41 4171.41 8276.88 S 372.61 W 6001581.21 N 556257.98 E 8.248 8283.22 10934.77 95.230 190.540 4096.48 4167.48 8321.92 S 381.96W 6001536.11 N 556248.97 E 5.355 8328.78 10980.86 93.930 189.360 4092.80 4163.80 8367.17 S 389.90 W 6001490.80 N 556241.38 E 3.804 8374.46 11026.56 94.350 189.210 4089.50 4160.50 8412.15 S 397.26 W 6001445.76 N 556234.36 E 0.976 8419.84 11073.87 93.410 188.300 4086.30 4157.30 8458.80 S 404.44 W 6001399.06 N 556227.53 E 2.762 8466.87 11119.28 92.310 187.130 4084.04 4155.04 8503.74 S 410.53 W 6001354.07 N 556221.79 E 3.534 8512.12 11166.67 92.430 188.050 4082.08 4153.08 8550.68 S 416.78 W 6001307.09 N 556215.89 E 1.956 8559.36 11209.93 92.630 186.900 4080.17 4151.17 8593.52 S 422.41 W 6001264.20 N 556210.59 E 2.696 8602.49 11259.50 93.130 186.400 4077.68 4148.68 8642.70 S 428.14 W 6001214.98 N 556205.23 E 1.426 8651.94 11305.31 93.290 187.280 4075.11 4146.11 8688.11 S 433.59 W 6001169.53 N 556200.13 E 1.950 8697.62 11351.12 92.490 187.150 4072.80 4143.80 8733.50 S 439.33 W 6001124.10 N 556194.73 E 1.769 8743.29 11400.38 93.590 186.900 4070.19 4141.19 8782.32 S 445.35 W 6001075.23 N 556189.08 E 2.290 8792.40 11443.90 93.350 187.330 4067.56 4138.56 8825.43 S 450.73 W 6001032.09 N 556184.03 E 1.130 8835.77 11494.36 90.440 185.710 4065.89 4136.89 8875.53 S 456.45 W 6000981.95 N 556178.68 E 6.599 8886.14 11536.77 88.540 185.870 4066.26 4137.26 8917.72 S 460.73 W 6000939.73 N 556174.73 E 4.496 8928.53 11583.94 88.700 185.4 70 4067.40 4138.40 8964.64 S 465.39W 6000892.77 N 556170.42 E 0.913 8975.66 ~. 11629.16 89.440 185.290 4068.13 4139.13 9009.66 S 469.63 W 6000847.72 N 556166.52 E 1.684 9020.86 11675.40 87.250 186.390 4069.47 4140.47 9055.63 S 474.33 W 6000801.71 N 556162.17 E 5.300 9067.05 11721.51 88.4 70 187.080 4071.19 4142.19 9101.39 S 479.74 W 6000755.91 N 556157.11 E 3.039 9113.06 11768.00 88.140 187.050 4072.57 4143.57 9147.51 S 485.45 W 6000709.75 N 556151.75 E 0.713 9159.46 11815.19 90.940 187.750 4072.95 4143.95 9194.30 S 491.53 W 6000662.92 N 556146.03 E 6.116 9206.55 11860.49 93.590 189.790 4071.16 4142.16 9239.03 S 498.43 W 6000618.14 N 556139.47 E 7.380 9251.64 11907.23 93.380 189.630 4068.31 4139.31 9285.01 S 506.30 W 6000572.09 N 556131.95 E 0.564 9298.05 11952.68 93.140 188.590 4065.73 4136.73 9329.82 S 513.48 W 6000527.24 N 556125.10 E 2.345 9343.24 11999.77 91.780 187.120 4063.71 4134.71 9376.42 S 519.91 W 6000480.59 N 556119.03 E 4.251 9390.17 12046.1 3 91.910 186.100 4062.22 4133.22 9422.45 S 525.24 W 6000434.52 N 556114.04 E 2.217 9436.45 28 March, 2002 - 16:10 Page 20f4 DrillQuest 2.00.08.005 Sperry-Sun DrilJing Services Survey Report for MPH-07 A MWD Your Ref: API 500292289701 Job No. AKMW220417 Surveyed: 15 March7 2002 BPXA Milne Point Unit Milne Point MPH 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) (°/1 OOft) 12092.01 91.750 183.190 4060.75 4131.75 9468.158 528.96 W 6000388.79 N 556110.68 E 6.349 9482.30 12137.77 89.830 181.780 4060.12 4131.12 9513.86 8 530.94 W 6000343.07 N 556109.04 E 5.205 9528.04 '---- 12185.92 89.800 180.030 4060.27 4131 27 9562.008 531.70 W 6000294.92 N 556108.64 E 3.635 9576.12 12229.59 89.980 179.830 4060.36 4131.36 9605.67 8 531.65 W 6000251.25 N 556109.03 E 0.616 9619.69 12277.56 90.310 179.800 4060.24 4131.24 9653.64 S 531.49 W 6000203.29 N 556109.55 E 0.691 9667.54 12323.77 90.600 179.060 4059.87 4130.87 9699.84 S 531.03 W 6000157.09 N 556110.36 E 1.720 9713.61 12370.41 90.660 178.390 4059.36 4130.36 9746.47 S 530.00 W 6000110.47 N 556111.75E 1.442 9760.06 12416.70 90.590 179.180 4058.85 4129.85 9792.75 S 529.01 W 6000064.20 N 556113.08 E 1.713 9806.17 12464.70 91.300 178.780 4058.06 4129.06 9840.73 S 528.16 W 6000016.23 N 556114.30 E 1.698 9853.99 12509.91 91.260 177.920 4057.05 4128.05 9885.91 S 526.86 W 5999971.06 N 556115.94 E 1.904 9898.98 12558.07 91.500 177.980 4055.89 4126.89 9934.03 8 525.14 W 5999922.96 N 556118.03 E 0.514 9946.87 12603.44 91.820 177.980 4054.58 4125.58 9979.35 8 523.54 W 5999877.65 N 556119.97 E 0.705 9991.98 12651.40 90.150 178.260 4053.75 4124.75 1 0027.27 8 521.96 W 5999829.73 N 556121.91 E 3.531 10039.69 12697.22 88.090 177.650 4054.46 4125.46 10073.068 520.33 W 5999783.97 N 556123.89 E 4.689 10085.26 12744.35 87.610 178.360 4056.22 4127.22 10120.138 518.69 W 5999736.91 N 556125.89 E 1.818 10132.11 12789.69 87.660 177.890 4058.10 4129.10 10165.408 517.21 W 5999691.65 N 556127.71 E 1.042 10177.19 12834.71 87.260 178.470 4060.09 4131.09 10210.358 515.78 W 5999646.71 N 556129.48 E 1.564 10221.94 12881.04 87.060 177.430 4062.39 4133.39 10256.60 S 514.12 W 5999600.48 N 556131.49 E 2.283 10267.97 12926.48 86.590 177.800 4064.90 4135.90 10301.93 8 512.24 W 5999555.16 N 556133.72 E 1.316 10313.07 12998.00 86.590 177.800 4069.16 4140.16 10373.27 S 509.50 W 5999483.84 N 556137.00 E 0.000 10384.07 Projected Survey -'" l All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.014° (04-Mar-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 183.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12998.00ft., The Bottom Hole Displacement is 10385.77ft., in the Direction of 182.812° (True). 28 March7 2002 - 16:10 Page 3 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Servic~~' Survey Report for MPH-07 A MWD Your Ref: API 500292289701 Job No. AKMW22041~ Surveyed: 15 March~ 2002 Milne Point Unit BPXA Milne Point MPH Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment '"-" 10747.16 1 0770.00 12998.00 4182.23 4180.19 4140.16 8141.46 S 8163.29 S 10373.27 S 333.39 W 339.79 W 509.50 W Tie On Point Window Point Projected Survey Survey tool program for MPH-07 A MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 12998.00 4140.16 MWD Magnetic (MPH-07) ~. 28 March, 2002 - 16:10 Page 4 of4 DríllQuest 2.00.08.005 ') c5J.Oó)~Day 03-Apr-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPH-07 A PB1 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,075.48' MD Window / Kickoff Survey 8,149.00' MD (if applicable) Projected Survey: 11 ,234.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED .1.. 1" n ~ "002 hi-';\ l~ '- AlalkaOiJ&GasCons.Ccml-', And10rage Milne Point Unit BPXA Milne Point MPH, Slot MPH-07 MPH-07A PB1 MWD Job No. AKMW22041, Surveyed: 13 March, 2002 -~ SURVEY REPORT 28 March, 2002 Your Ref: API 500292259770 Surface Coordinates: 6009860.68 N, 556567.80 E (70026' 15.3208" N, 149032' 19.5685" W) Kelly Bushing: 71.00ft above Mean Sea Level ,-/ =pe'-'I'Y-SUf1 [J.AILLI N G.... se:AVfï::es A Halliburton Company Survey Ref: svy10098 Sperry-Sun Drilling Services Survey Report for MPH-07 A PB1 MWD Your Ref: AP/500292259770 Job No. AKMW22041, Surveyed: 13 March, 2002 BPXA Milne Point Unit Milne Point MPH 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) (°/1 OOft) 8075.48 77.410 172.310 3968.54 4039.54 5802.34 S 788.83 E 6004064.49 N 557400.62 E 5736.28 Tie On Point 8149.00 76.130 172.070 3985.37 4056.37 5873.24 S 798.55 E 6003993.66 N 557410.88 E 1.770 5806.37 Window Point 8180.14 75.310 174.660 3993.05 4064.05 5903.22 S 802.04 E 6003963.72 N 557414.60 E 8.479 5836.04 8276.17 74.830 182.730 4017.83 4088.83 5995.89 S 804.16 E 6003871.06 N 557417.42 E 8.135 5928.37 8368.78 74.840 190.530 4042.09 4113.09 6084.60 S 793.85 E 6003782.27 N 557407.78 E 8.129 6017.57 8462.81 79.370 192.430 4063.07 4134.07 6174.40 S 775.60 E 6003692.34 N 557390.21 E 5.204 6108.39 8555.60 80.890 196.220 4078.98 4149.98 6262.95 S 752.98 E 6003603.62 N 557368.26 E 4.345 6198.26 8650.86 80.670 199.240 4094.25 4165.25 6352.50 S 724.35 E 6003513.85 N 557340.31 E 3.138 6289.53 8744.54 80.480 198.980 4109.59 4180.59 6439.82 S 694.09 E 6003426.31 N 557310.72 E 0.341 6378.69 8837.79 80.760 202.100 4124.79 4195.79 6525.97 S 661.82 E 6003339.92 N 557279.10 E 3.315 6466.80 8931.50 79.770 208.180 4140.65 4211.65 6609.54 S 622.61 E 6003256.05 N 557240.52 E 6.481 6552.82 9026.90 84.250 211.540 4153.91 4224.91 6691.43 S 575.57 E 6003173.81 N 557194.11 E 5.849 6637.68 9073.14 88.870 210.430 4156.69 4227.69 6730.99 S 551.82 E 6003134.07 N 557170.66 E 10.275 6678.75 9121.87 88.790 211.050 4157.68 4228.68 6772.86 S 526.92 E 6003092.01 N 557146.08 E 1.283 6722.20 9151.73 87.720 210.470 4158.59 4229.59 6798.51 S 511.65 E 6003066.25 N 557131.01 E 4.076 6748.81 9213.42 87.480 209.460 4161.17 4232.17 6851.91 S 480.87 E 6003012.62 N 557100.63 E 1.681 6804.16 9262.67 90.070 209.590 4162.23 4233.23 6894.75 S 456.60E 6002969.59 N 557076.69 E 5.265 6848.53 9306.26 90.220 209.720 4162.12 4233.12 6932.63 S 435.04 E 6002931.55 N 557055.41 E 0.455 6887.77 9352.89 90.170 209.050 4161.96 4232.96 6973.26 S 412.16 E 6002890.75 N 557032.84 E 1 .441 6929.85 9394.54 89.710 210.550 4162.00 4233.00 7009.40 S 391.46 E 6002854.45 N 557012.42 E 3.767 6967.30 '~ 9444.96 89.780 212.930 4162.22 4233.22 7052.28 S 364.94 E 6002811.37 N 556986.22 E 4.722 7011.86 9491.72 89.720 215.580 4162.43 4233.43 7090.92 S 338.62 E 6002772.53 N 556960.20 E 5.669 7052.18 9538.06 90.500 218.610 4162.34 4233.34 7127.88 S 310.67 E 6002735.36 N 556932.53 E 6.752 7090.93 9583.71 90.890 218.640 4161.79 4232.79 7163.54 S 282.18 E 6002699.49 N 556904.31 E 0.857 7128.43 9629.00 89.030 218.240 4161.82 4232.82 7199.01 S 254.03 E 6002663.80 N 556876.42 E 4.201 7165.71 9676.81 88.600 217.320 4162.81 4233.81 7236.79 S 224.74 E 6002625.80 N 556847.43 E 2.124 7205.37 9723.17 89.840 217.700 4163.44 4234.44 7273.56 S 196.52 E 6002588.82 N 556819.48 E 2.797 7243.95 9768.76 90.180 217.380 4163.43 4234.43 7309.71 S 168.74 E 6002552.46 N 556791.98 E 1.024 7281.89 9814.49 91.790 217.620 4162.64 4233.64 7345.99 S 140.90 E 6002515.97 N 556764.42 E 3.560 7319.95 9862.77 91.870 217.410 4161.10 4232.10 7384.26 S 111.52 E 6002477.48 N 556735.33 E 0.465 7360.11 28 March, 2002 - 16:09 Page 2 0'4 Dríl/Quest 2.00.08.005 ~ Sperry-Sun Drilling Services - Survey Report for MPH-07 A PB1 MWD Your Ref: AP/500292259770 Job No. AKMW22041, Surveyed: 13 March, 2002 BPXA Milne Point Unit Milne Point MPH 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) (°/1 OOft) 9907.25 94.200 218.370 4158.75 4229.75 7419.31 S 84.24 E 6002442.22 N 556708.32 E 5.664 7396.91 9955.77 94.350 217.610 4155.13 4226.13 7457.45 S 54.46 E 6002403.86 N 556678.83 E 1.592 7436.96 10012.08 92.640 215.500 4151.70 4222.70 7502.59 S 20.99 E 6002358.46 N 556645.70 E ~/ 4.818 7484.25 10059.52 90.090 214.510 4150.57 4221.57 7541.43 S 6.22W 6002319.42 N 556618.79 E 5.766 7524.83 1 0094.15 90.310 214.480 4150.45 4221.45 7569.98 S 25.83 W 6002290.73 N 556599.39 E 0.641 7554.63 10142.79 90.410 212.660 4150.14 4221.14 7610.50 S 52.72 W 6002250.00 N 556572.81 E 3.747 7596.87 10188.20 90.860 212.790 4149.64 4220.64 7648.70 S 77.27 W 6002211.61 N 556548.55 E 1.031 7636.63 10235.55 91.350 213.320 4148.72 4219.72 7688.38 S 103.09 W 6002171.74 N 556523.03 E 1.524 7677.95 10281.30 92.910 212.290 4147.02 4218.02 7726.80 S 127.86 W 6002133.13 N 556498.55 E 4.085 7717.95 10328.39 92.500 212.700 4144.80 4215.80 7766.48 S 153.13 W 6002093.26 N 556473.59 E 1.231 7759.23 10375.82 90.620 208.800 4143.51 4214.51 7807.21 S 177.36 W 6002052.34 N 556449.66 E 9.125 7801.50 10421.36 94.550 210.050 4141.46 4212.46 7846.83 S 199.71 W 6002012.56 N 556427.62 E 9.055 7842.53 10467.38 94.050 209.620 4138.01 4209.01 7886.64 S 222.54 W 6001972.58 N 556405.09 E 1.431 7883.78 10514.74 95.040 207.160 4134.25 4205.25 7928.17 S 244.99 W 6001930.88 N 556382.96 E 5.584 7926.73 10561.96 95.690 205.490 4129.84 4200.84 7970.30 S 265.83 W 6001888.59 N 556362.43 E 3.781 7970.17 10608.17 96.840 204.980 4124.79 4195.79 8011.85 S 285.42 W 6001846.89 N 556343.16 E 2.720 8012.94 10650.82 95.780 201.540 4120.10 4191.10 8050.79 S 302.15 W 6001807.83 N 556326.72 E 8.393 8052.91 10700.65 95.320 198.800 4115.28 4186.28 8097.34 S 319.25 W 6001761.15 N 556309.98 E 5.550 8100.51 10747.16 94.670 196.740 4111.23 4182.23 8141.46 S 333.39 W 6001716.92 N 556296.17 E 4.628 8145.48 10793.73 96.600 196.160 4106.66 4177.66 8185.91 S 346.51 W 6001672.38 N 556283.39 E 4.326 8190.70 ~ 10840.57 97.160 194.840 4101.05 4172.05 8230.72 S 358.94 W 6001627.47 N 556271.30 E 3.043 8236.25 10888.50 96.500 191.960 4095.35 4166.35 8277.01 S 369.97 W 6001581.10 N 556260.63 E 6.123 8283.17 10935.31 96.460 188.170 4090.07 4161.07 8322.80 S 378.10 W 6001535.26 N 556252.85 E 8.045 8329.40 10982.26 94.890 186.830 4085.42 4156.42 8369.11 S 384.19 W 6001488.89 N 556247.10 E 4.387 8376.02 11028.13 95.040 186.040 4081.45 4152.45 8414.52 S 389.31 W 6001443.45 N 556242.32 E 1.747 8421.67 11073.51 94.750 185.540 4077.58 4148.58 8459.51 S 393.88 W 6001398.43 N 556238.10 E 1.270 8466.86 11117.06 94.550 186.000 4074.05 4145.05 8502.69 S 398.24 W 6001355.21 N 556234.07 E 1.149 8510.24 11234.00 94.550 186.000 4064.77 4135.77 8618.63 S 410.42 W 6001239.19 N 556222.76 E 0.000 8626.73 Projected Survey 28 March, 2002 - 16:09 Page 3 of 4 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPH-07 A PB1 MWD Your Ref: AP/500292259770 Job No. AKMW22041, Surveyed: 13 March, 2002 Milne Point Unit BPXA Milne Point MPH All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.014° (04-Mar-02) ",-,. The Dogleg Severity is in Degrees per 1 00 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 183.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11234.00ft., The Bottom Hole Displacement is 8628.39ft., in the Direction of 182. 726° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8075.48 8149.00 11234.00 4039.54 4056.37 4135.77 5802.34 S 5873.24 S 8618.63 S 788.83 E 798.55 E 410.42 W Tie On Point Window Point Projected Survey .~ Survey tool program for MPH-07 A PB1 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) Survey Tool Description 0.00 0.00 11234.00 4135.77 MWD Magnetic (MPH-07) 28 March, 2002.16:09 Page 4 of4 DrillQuest 2.00.08.005 ~~~~~ if !Æ:!Æ~"~~~ I AltASIiA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 w. ¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Milne Point Unit MPH-07A BP Exploration (Alaska), Inc. Permit No: 202-024 Sur Loc: 2709' NSL, 4079' WEL, Sec. 34, TI3N, RI0E, UM Btmhole Loc. 2807' NSL; 705' EWL, Sec. 11, TI2N, RI0E, UM Dear Mr. Shultz: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill. does not exempt you from obtaining additional permits required by law from other governmental agencies,..and does not authorize conducting drilling operations until.all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Milne Point Unit MPH -07 A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. S incerel y, ÚLIVUIN1: ([Jut VyC 1A deL< . Cammy Qechsli Taylo;~ð--- Chair BY ORDER OF THE COMMISSION DATED this. day of February, 2002 jjcÆnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 8-1/211 6-1/811 STATE OF ALASKA ALASKÞ11L AND GAS CONSERVATION COM~'} '1SION PERMIT TO DRILL .,' ~1 t1 20 MC 25.005 1/JI'5)ér2-- 1 b. Type of well 0 Exploratory 0 Stratigraphic Test B Development Oil 0 Service 0 Development Gas ~Single zonejð 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Planned KBE = 63.00' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 380109 7. Unit or Property Name Milne Point Unit 8. Well Number MPH-07A 9. Approximate spud date 02/21/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13071' MD / 4196' TVD 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 90 Maximum surface 1207 psig, Attotal depth {TVD} 4091' /1616 psig Setting Depth Too Bottom Quantitv of Cement LenQth MD TVD MD TVD (include staae data) 9238' 30' 30' 9268' 4226' 215 sx Class 'G' 3800' 9118' 4217' ~ 4196' Uncemented Slotted Liner I~ / 'lP w 4Po 'v4(1A- 2-/1'1/ r; 2- fk:>f r5"' REVISION 02/13/02 1 a. Type of work 0 Drill B Redrill 0 Re-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 2709' NSL, 4079' WEL, SEC. 34, T13N, R10E, UM At top of productive interval 1066' NSL, 1698' EWL, SEC. 02, T12N, R10E, UM At total depth 2807' NSL, 705' EWL, SEC. 11, T12N, R10E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 025627,705' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8125' MD Maximum Hole Angle 18. Casin9 Program Specifications Size Casinq Weiaht Grade Couolina 711 26# L-80 BTC-M 4-1/211 12.6# L-80 IBT-Mod 11. Type Bond {See 20 AAC 25.025} Number 2S100302630-277 19. To be completed for Redrill, 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 15900 feet 7108 feet 8950 feet 4265 feet Length Plugs (measured) Isolation Plug & Shear Disc at 83621; HES 9-5/811 EZSV retainers at 90651 and 9070' Junk (measured) Size Cemented MD TVD 801 9186' 2011 9-5/811 250 sx Arcticset I (Approx.) 1484 sx PF 'E', 747 sx 'G', 50 sx 'GI 112' 9217' 112' 43431 RECEIVED FEB 1 4 2002 Perforation depth: measured 8215'-8235',8328'-8349',8674'-8695',89061-8927' true vertical 4069'-4074',4098'-4103',4187'-4193',4252'-4258' Alaska Oil & Gas Cons. COmmission Ancho\'aQe 20. Attachments 0 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch B Drilling Program B Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer NameINumber: Stp¡, Sh, ultz, 5~64_54~1 .. . ,'.. Prepared By Name/Number: Sandra Stewman, 564-4750 21. I hereby certify that the fO~~ true a d rrec 0 the best of my knowledge Signed Steve Shultz / ~ - ' Title Senior Drilling Engineer Date Z-- .v ."".' :." ..fCommi~ionU$è.OnÎy- ", ': Permit Number i J API Number APP~\j~\ ~teo ~ See cover letter 202- - 02..7 50- 029-22597-01 :; \ \~t \ I í \ for other reQuirements Conditions of Approval: Samples Required 0 Yes 6lNo Mud Log Req 'red 0 Yes IirNo Hydrogen Sulfide Measures 0 Yes lif'No Directional Survey Required 'Œ'Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15t<' 0 3.5K pSI for CTU Other: TeJt- ~ FE 10 '5 ZS 00 f Y¿. 4¡JÇ¡Å;- 'I Approved By Original Signed By Commissioner ~:e o';;::;i~ion Date 0 (Q' 0 ~ Form 10-401 Rev. 12-01-£mnmy Oooh&ti Submit 1t1 Triplicate I\L ) ') MPH-07a Drilling Permit 1. Well Plan SUmmary Well Name: MPH-07a I Type of Well (producer or injector): Surface Location: H-07a "OB" Target: H-07a Target (Bottom Hole Location): / I Rig: I Nabors 27E J I I Schrader Bluff Multilateral producer v' 2709' FSL, 1200'FVVL,SEC.SEC.34,T13N,R10E X= y= 10661 FSL, 1698' FVVL, SEC.02 , T12N, R10E X =557,123 Y =6,002,942 Z =4160 TVDss 2807' FSL, 705' FVVL, SEC.11 , T12N, R10E X =556,162.63 Y =5,999,396.90 Z = 4130 TVDss I KOP: I 8125' I I Estimated Start Date: 12/21/02 I Operating days to complete: I 20 I I MDrkb 113071' I J I TVDrkb (TD) I 4196' 1./ I Max. Inc. I 90° I I KBE: I 63' I I I Drill and Complete a Multilateral Producer in the Schrader Bluff OA and OB sands. I I Well Design (conventional, slim hole, etc.): I Sidetrack Multilateral Producer I Scope: 2. Current Well Information 2.1 General VV ell Name: MPH-07a API Number: VVell Type: Current Status: BHP: BHT: MPH-07a Development - Schrader Bluff Sidetrack Multilateral Producer MPH-07 presently shut-in / 1616 psi @ 4091' TVDrkb Top of Schrader Bluff OA Sands. ./ 80°F @ 4091' TVDss Estimated 2.2 Current Mechanical Condition MPH-07a: Nabors 27E: Casing: 2.3 Target Estimates Cellar Box above MSL = 37.1 ' KB I MSL = 31.5' 95/8",9217'-7406' 47 Ib/ft,7406'-surface 40 Ib/ft Estimated Reserves: 2.1 MMBBL Expected Initial Rate: 2000 BOPD Expected 6 month avg: 1000 BOPD Version #1 1/28/2001 ') ) MPH-07a Drilling Permit 3. Drillina Hazards and Continaencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill D1 D2 D3 D4 D5 Type Tripping Drilling Diverter Accumulator Well Kill Frequency (1) per week, per crew (1) per week, per crew N/A Prior to spud or RWO Prior to drill out, per crew Comments Conducted only inside casing. Either in cased or open hole. DO NOT shut-in well in open hole. N/A Approx. every 30 days, thereafter at convenient times. Prior to drill out the intermediate and production strings. Never carry out this drill when open hole sections are exposed. 3.2. Hydrates 3.2.1. Hydrates should not pose a problem due to the kick off point being well below the depths at which we see hydrates in the area. 3.3. Kick Tolerance 3.3.1. The 9 5/8" casing is being sidetracked at 8125 MD, 4046' TVD 3.3.2. The Kick Tolerance for the production casing based on the 7.60 psi expected pore pressure is infinite. 3.4. Lost Circulation 3.4.1. H-pad has not been known for lost circulation in the past. 3.4.2. 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. 3.5. Unexpected Pressures 3.5.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. Reservoir pressure is expected to be 1616 pSj)7.60 Ib/gal). In this well, the Schrader Bluff formation will be drilled with 8.6-ppg mud. 3.6. Stuck Pipe 3.6.1. Risk of stuck pipe has been minimized due to this well being a sidetrack and already having the majority of the formation behind pipe from the bottom of the UGNU back to surface. 3.6.2. Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the M-I mud program must be closely followed. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.7. Pad Data Sheet 3.7.1. Please Read the H-Pad Data Sheet thoroughly. 2 3.8. Hydrocarbons ') ') MPH-07a Drilling Permit 3.8.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3.11 Hydrogen Sulfide / 3.11.1. MPH Pad is not designated as an H2S Pad. Below is a summary of the most recent H2S readings: Well H- 1 2 3 4 5 6i 7 Well Type Producer Producer Producer Producer Producer Injector Producer H2S Status Shut In Shut In Shut In <2 <2 Injector <2 Date Taken June 2001 June 2001 Feb 2000 Well H- Well Type H2S Status Date Taken 8 Producer <2 June 2001 9 Producer <2 June 2001 10 Producer <2 June 2001 11 i Injector Injector 12 Producer <2 June 2001 13 Producer <2 June 2001 14 Producer <2 June 2001 4.0 Drilling Program Overview 4.1. Surface and Anti-Collision Issues Suñace Shut-in Wells: No wells need to be shut-in for the rig move on and off MPH-07a Close Approach Wells: There are no close approach wells Well Name N/A 4.2. Well Control Expected BHP 1616 psi @ 4091' TVDrkb (estimated) 4.3. Mud Program Current Status N/A Production Priority N/A Max Exp Suñace Pres,sure 1207 psi / (0.1 psi/ft gas gradient) 9-7/8" Kickoff and Intermediate Mud Properties: Density (ppg) Funnel visc YP HTHP 8.6 - 9.2 50 -150 15 - 40 N/A 6-1/8" Production Hole Mud Properties: OAlOB Density (ppg) Funnel visc YP HTHP 8.6 40-55 22-27 < 10 Precautions N/A BOPE Rating 135/8" 5M Planned BOpØest Pres. Rams & Valves:"3500 psi/250 psi Annular: 2500 psi I 250 psi Spud - LSND Freshwater Mud pH API Filtrate LG Solids 9.0-9.5 <6 <6.5 KCI-CaC03 FloPro pH API Filtrate LG Solids 8.0 - 8.5 4 - 6 < 12 LCM Restrictions: No Organic LCM products in the Schrader Bluff formation Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. 3 ) ') MPH-07a Drilling Permit 4.4. Formation Markers Formation Tops ft MD ft TVDrkb Pore (psi) EMW (ppg) Base Permafrost 1750 1750 680 2.97 Top Ugnu 5413 3350 1320 7.58 Top Ugnu M 7030 3784 1494 7.59 Schrader-NA 7786 3970 1568 7.59 Schrader-NB 7881 3994 1578 7.60 Schrader-NC 8036 4027 1591 7.60 Schrader-NE 8109 4043 1597 7.60 Schrader-NF 8252 4073 1609 7.60 TSBB-OB 8711 4160 1644 7.60 SBA5(Base OB) 12864 4188 1632 7.60 TO 13071 4196 4.5. Casingrrubing Program Hole Size Csgl WtlFt Grade Conn Length Top Bottom Tbg O.D. MD I TVDrkb MD I TVDrkb 81/2" 7" 26# L-80 BTC-M 9238' 30' I 30' 9268' I 4226' 6 1/8" (OB) 4 ~" Slotted Liner 12.6# L-80 IBT-Mod +1-3800' 9118'/4217' 13071'/4196' '¡ Tubing 2-7/8" 6.4# L-80 EUE-Mod +1- 7970' 30' I 30' 8000' I 4022' 4.6. Cement Calculations casin~. Size 17" 261b/ft L-80 BTC-M Liner Basis 50°,10 excess Total Cement Volume: Wash 50 bbl Freshwater Spacer 75 bbl of Viscosified Alpha Spacer weighted to 9.2 ppg Tail 44 bbls (yield=1.1frcu.ft.lsk.) 15.8 Ib/gal Class G + additives (with 50% . 4.7. Survey and Logging Program 81/2" Hole Section: Open Hole: MWD / DIR I GR I Res 6-1/8" Hole Section: Open Hole: DIRlGRlReslPWDIIAB Res placed as close to bit as possible. Cased Hole: None 4 ) ') MPH-07a Drilling Permit 5. MPH-07a Operations Summary 5.1. Procedure 1, MIRU, NU BOPE on wellhead, PU 31/2' drill PiPe! 2. MU whipstock assembly, RIH and set at +/-8125' 3. Mill window out of 9 5/8" casing, POOH 4. MU 6 %" drilling BHA, RIH 5. Drill 8 1/2" Intermediate hole as per directional plan and drill to 9268. 6. Condition mud and POOH / 7. Run and cement 7" casing from TD to surface. 8. MU 4 %" drillingjl5sembly, RIH and change over to MI Drill-in fluid 9. Drill 6-1/8" OB lateral geosteering and short tripping as required. Maintain FloPro mud properties. 10. Displace OB lateral with clean FloPro mud ./ 11. Run 4 ~" slotted liner with 2 %" inner string '12. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. a. RIH. Orient and set whipstock to place window at top of the OA interval. b. Shear off and mill window thru 7" casing. POOH, MU 4 %" drilling assembly, RIH Drill 6-1/8" OA lateral geosteering and short tripping as required. Maintain FloPro mud properties. Displace OA lateral with clean FloPro mud, POOH MU whipstock retrieving tool and pull whipstock Run 4 ~" slotted liner with 2 %" inner string, Baker Hook Hanger and hang off in 7" casing POOH laying down 31/2" drill pipe Run in hole with 2 %" tubing to top of OA liner Displace 711 casing to seawater Land tubing hanger Set tubing plug and SPV ND BOP Install and test tree Pull tubing plug and SPV Freeze protect the tubing and annulus Install BPV and secure the well RD/MO ~ \\V" ø{),\c. ~ -()~~\..113. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 6.0 MPH-07a Nabors 4ES Operations Summary 1. 2. 3. 4. 5. 6. 7. 8. MIRU Nabors 4ES. Circulate out freeze protection with 9.1 ppg brine. Remove tree and install BOP. Pull and stand back the 2 %" tubing. Make up the ESP completion and run in on the 2 %" tubing. Freeze protect the well. Set tubing plug and SPY. Remove the BOP. Install and test the tree. RD/MO. Hook up flowlines and instrumentation. 5 ) ') Milne Point Unit BPXA Milne Point MPH, Slot MPH-07a MPH-07a Revised: 13 February, 2002 dM1i@!!\JiI" PRQ,(J$Jfb..REPORT ~!~.".~\.... I C,:"'" \~à February, 2002 :-, ., . :!~i;;l~)x~I~~ffi . \'-::',,;,. .] I'. ";:", ..'. '~f!r!~;Coo;flÎ(Jates: 6009860.68 N, 556567.80 E (70026'15.3208" N, 149032'19.5685" W) ',;SpHace Coordinates relative to Project H Reference: 1009860.68 N, 56567.80 E (Grid) urface Coordinates relative to Structure Reference: 879.92 N, 1169.60 E (True) Kelly Bushing: 66. 10ft above Mean Sea Level iU~,I_"'" ~ ~ -~ ..., . ........- . ,.... -;:8...Vlr". A Mallitturton ~p.tIAy Proposal Ref: pro 1 0062 ) ') Sperry-Sun Drilling Services Proposal Report for MPH-07a Revised: 13 February, 2002 Milne Point Unit Measured Depth (ft) Incl. Azim. Vertical Depth (ft) MPH-07 RECCA 8125.00 76.464 172.130 4046.94 MPH-07A 8145.00 76.685 174.587 4051.59 8200.00 76.992 176.824 4064.11 8300.00 77.599 180.877 4086.11 8400.00 78.266 184.910 4107.03 8500.00 78.988 188.923 4126.75 8600.00 79.764 192.916 4145.20 8700.00 80.587 196.888 4162.27 8800.00 81.455 200.842 4177.88 8900.00 82.363 204.777 4191.96 8955.11 82.878 206.938 4199.04 9000.00 82.878 206.938 4204.60 9076.37 82.878 206.938 4214.07 9100.00 83.746 207.315 4216.82 9200.00 87.422 208.897 4224.52 9270.09 90.000 210.000 4226.10 9300.00 90.021 211.196 9400.00 90.092 215.195 9500.00 90.163 219.195 9600.00 90.233 223.194 9606.72 90.238 223.463 ,;T... 4223.33 4222.69 4221.82 4220.72 4219.40 10600.00 90.947 201.766 4217.85 10644.18 91.000 200.000 4217.10 10700.00 91.406 197.804 4215.93 10800.00 92.128 193.868 4212.84 10900.00 92.841 189.928 4208.51 10930.40 93.054 188.729 4206.94 11000.00 93.054 188.729 4203.23 11100.00 93.054 188.729 4197.91 11200.00 93.054 188.729 4192.58 11300.00 93.054 188.729 4187.25 13 February, 2002 -15:57 Northings (ft) 5854.87 S 5874.19 S 5927.59 S 6025.10 S 6122.74 S 6220.04 S 6316.53 S 6411.73 S 6505.17 S 6596.41 S 6645.60 S 6685.30 S 6752.86 S 6773.75 S 6861.68 S 6922.69 S ,~(~I~ 6~$i)t3,s ;;7Ö32.10::8 , '1111.74$ 7'1':86.97$ : 71 ~1.86$ . ~~~á~tH\": 7259.56 S 7332.14 S 7404.73 S 7477.31 S 7518.92 S 7550.32 S 7627.18 S 7708.30 S 7793.31 S 7881.77 S 7973.26 S 8014.52 S 8067.32 S 8163.46 S 8261.20 S 8291.16 S 8359.86 S 8458.56 S 8557.26 S 8655.96 S BPXA Milne Point MPH Eastings (ft) Vertical Dogleg Build Turn Toolface Section Rate Rate Rate Azimuth (ft) (o/100ft) e/100ft) e/100ft} 795.97 E 5788.21 798.22 E 5807.34 12.000 802.23 E 5860.35 4.000 804.18 E 5957.51 4.000 799.24 E 6055.26 4.000 787.43 E 6153.14 4.000 768.81 E 6250.65 743.47 E 6347.34 711.54 E 6442.72 673.16 E 6536.33 649.33 E 6587.00 4.000 4.000 4.000 4.000 ':"í¡.~..poo I ."';~" .., 1.-. ,~ 629.15 E 66át.9i'.'" .":~i\ 594.82 E ':' ,669(';69 ;:"" ' ,:' 584.1~E '::.6il~~'¿~J:-:i6oo 537 .15 'E:,~1, "',68 fo:i2'~{OOO 02.70 E;1>~Î.73~~2 4.000 6900.02 6987.17 7070.69 7150.17 7155.36 237.68 E 7227.22 168.89 E 7304.26 100.10 E 7381.29 31.31 E 7458.33 8.12 W 7502.50 37.01 W 7535.77 100.95 W 7616.74 159.37 W 7701.61 212.00 W 7789.95 258.57 W 7881.34 298.86 W 7975.33 314.60 W 8017.56 332.68 W 8071.46 359.95 W 8169.21 380.54 W 8268.11 385.46 W 8298.33 396.01 W 8367.58 411.17 W 8467.08 426.32 W 8566.57 441.48 W 8666.07 Page2of3 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 4.000 1.106 12.285 85.000 0.558 4.068 82.234 0.607 4.053 81.725 0.667 4.033 80.833 0.723 4.013 79.990 0.775, "~:~~3 ,:O:a.24: ,>'{3;913 :; o.a6Ø'", 3.9~ ";;0.90~(',,' 3~935 , ;<L9~Ø;i: 3.922 "~~~WR~1'i'~\'" 79.198 78.462 77.783 77.166 76.612 3.673 3.676 3.678 1.594 23.340 1.582 23.296 1.574 23.174 0.071 0.071 0.071 0.070 0.069 3.999 88.979 3.999 88.979 3.999 88.983 3.999 88.992 3.999 89.006 0.137 -3.998 -88.037 0.136 -3.998 -88.045 0.134 -3.998 -88.070 0.131 -3.998 -88.105 0.127 -3.998 -88.149 0.123 -3.999 -88.202 0.120 -3.999 -88.264 0.728 -3.934 -79.496 0.722 -3.936 -79.542 0.712 -3.940 -79.664 0.704 -3.943 -79.834 DrllIQuest 2.00.09.008 ) ) Sperry-Sun Drilling Services Proposal Report for MPH-07a Revised: 13 February, 2002 BPXA Milne Point Unit Milne Point MPH Measured Vertical Vertical Dogleg Build Turn Toolface Depth Incl. Azim. Depth Northings Eastings Section Rate Rate Rate Azimuth (ft) (ft) (ft) (ft) (ft) e /100ft) e/100ft) e /1 OOft) 11400.00 93.054 188.729 4181.92 8754.66 S 456.63 W 8765.56 11500.00 93.054 188.729 4176.59 8853.36 S 471.79 W 8865.06 11600.00 93.054 188.729 4171.26 8952.06 S 486.94 W 8964.56 11700.00 93.054 188.729 4165.93 9050.76 S 502.10 W 9064.05 11800.00 93.054 188.729 4160.61 9149.47 S 517.26 W 9163.55 11883.79 93.054 188.729 4156.14 9232.16 S 529.95 W 9246.91 11900.00 92.408 188.681 4155.37 9248.17 S 532.40 W 9263.05 4.000 -3.989 -0.300 -175.703 11960.36 90.000 188.500 4154.10 9307.84 S 541.42 W 9323.19 4.000 -3.989 -0.299 -175.706 12000.00 89.783 187.331 4154.18 9347.10 S 546.88 W 9362.72 3.000 -0.548 -2.950 -100.522 12100.00 89.236 184.381 4155.03 9446.56 S 557.08 W 9462.65 3.000 -0.547 -2.950 -100.520 12200.00 88.691 181.431 4156.84 9546.41 S 562.15 W 9562.61 3.000 -0.545~",!~~951 -100.495 12300.00 88.149 178.479 4159.60 9646.36 S 562.07 W 9662.33 3.000 -0.542:: ::'2:952 -100.441 12400.00 87.612 175.525 4163.30 9746.14 S 556.84 W 9761.53 3.000 .. ~O;537,' :'~,"95.4 -100.360 12443.56 87.380 174.238 4165.20 9789.49 S 552.96 W 9804.52 3.000 : ;,,-0.5~¿' . "I'-2~955 -100.250 12500.00 87.380 174.238 4167.78 9845.58 S 547.30 W 9860.11 ',' ~ ,. "1'-: ~ ' 12600.00 87.380 174.238 4172.35 9944.97 S 537.27 W 99þ.8.60'1 ' ' " "",\i-~~,\I;:\~; 12700.00 87.380 174.238 4176.92 1 0044.36 S 527.24 W . ,J0051'~P9~:;J: 12800.00 87.380 174.238 4181.50 10143.75 S 517.2 W >,.~:1015$~59 "-. 12900.00 87.380 174.238 4186.07 10243.14 S 507. 'tÓ2P4iÓß 13000.00 87.380 174.238 4190.64 1 0342.53 S 497.15 ' :~:;::fp352.;§7 )3100.00 87.380 174.238 4195.21 .12W v'r~'151.07 13119.50 87.380 174.238 4196.10 7W 10470.27 All data is in Feet (US) unless otherwise stated. ol;~6~~ anq.:~oordiììåt~ are relative to True North. Vertical depths are relative to Well Reference. N~rin~;~nd E,$Stings are relative to Well Reference. ,I ~'.~:\ Magnetic Declination at sU,~ac~2~.::. ...:(t~-Feb~Q?:):':." The Dogleg Severity j~ p;'ô~r~~~~B~'~ '1' OÓ:f~t (US). Vertical Sectio~.iiJro'rrr~'Yel:t.:,~~fer~ and calculated along an Azimuth of 183.850° (True). 'Iì¡'..; , \ ~ .;. ),,~.: ':,."- Based ~. Mirì~ CåWt;\ture type calculations, at a Measured Depth of 13119.50ft., The Bottö,tþ,~~!~';~i~~ceri'lênt is 1 0472.55ft., in the Direction of 182.655° (True). ~,ø~' 13 February, 2002 - 15:57 Page 3 013 DrillQuest 2.00.09.008 Spe'ty-Sun Drilling St;lvices Proposal Data - MPH-07a - MPH-07A :i1;}:):.;,~;t1~aq~~~\';;è';'7~;~~ 90.000 188.500 4154.10 9307.84 S' 541.42 W: . 4.000 ..':,,::"~;~s~t<.}':1'~~9'f';"..::9s~å;,t~; 1!'1~[f1¡~;i,\I~;;;~~?1~;;~¡~~;;,~!~;,~~,~,:;".':;;f'}t¡,~¡I{t~':~~~~1~: 13 February, 2002 - 14:52 -1 - DrillQuest ~ BPXA ",f",~L~"'~-:,",,",~~r.::-:-~ Milne Point Unit .~ttf.~!!!1'i~ Well: Horizontal Coordinates: ReI. Global Coordinates: Ref. Structure Reference : Ref. Geographical Coordinates : RKB Elevation: Current Well Properties MPH-07a (L1) 6009860.68 N, 556567.80 E 879.92 N, 1169.60 E 70° 26' 15.3208' N, 149° 32' 19.5685' W ~Q þP~þ,f$.'ÞÇ¡~ ~Q ~~Q ~ - - - --- - - - -.""",Q~~~Q' - - -- :'/S)~~.þ,1.~ -_19 ïQ- _. - #- - - -#- --- - - -. -~&--.- -- - - - -~~~~1---::õf.>~~~---~'- T..,.,~~".;~¡¡" ..-... I:P",.~. \tÞ. ,!Ii ¡'\"~ r¡§I- 2-:S ~Q ~~\), W' 'Þ()~ ..-... ~ ",,^~ò$'" .#ø~':;'$z€~~;Q~':>"':~~~ ,#ø,~~' ."",~;~~#~~;"",~,,þ ,þ"~ i (¡) ,\~~~0@ ~\~cß\" <þ\o..~~Ç¡;~~Ç¡~¿~1.~~ #"'1> rj>()Ô').~ .f~,~ \~~\()Ç¡~' o\\~\;,tP\ @~1.?1 <§J~"\'/) '?>o""ø~1.. .æ Q) :o.'Þ-<'-~~Q\\ \(). @ Ç¡()~\()~~'O ".'I>() ç,r.:,. .,$'. O\....T::!~()G @'I>\~ . þ,!)()~~";;$.e~ 'i>~ ~1.. oþP\'~"" r",Foo.ll.TI!l.B Q) a: 3850 -O«"'~0-~ - -- ~\~\\,?-ß.~~~~- c#~ ~~~~~'- - - --- ~~- - - --- - - ~~~01: ~- -~- -.. ------ -~~~\~.- _.lrmIo'TI]} - 3850 a: = JlØ'>0 $l..",oq.~0 \~ 'V ",'\1J' ~'i>~ þ,!)cß . ",oq.(o. <# @ ~\\ t~ \ Q\\,,,,"'0-~ 0# 0<»~ ~~) \i- . (;>'-t. Q\\' ~<'- . þ,\~&-'''. . =æ ~ e..fPJt!)= :oI-'V ~e'ð' ~ ~@~- ~ "iò~~~(o. ;If>\\@=== ; - ¿,.,"'. = = == = = ~~"'i/,- t:!~ = = c, ;fff;'t = .=~c..::.';;£~,,,, .;;;¡ ~ - ~ '-' -~ =: -~ - "" "" --=t~ = =: = =: - - -'Ø'~ =: = ~¡¡... ..! - -- ~iYi 4;>8ÐII.~A,:t.1 ---.... .---.--... .'-'-"--- . .16'tV~lúJ;JÔ-'ZU1"'BE1.-:vf' ..c: ---- - .- . n . 00.0 - wo - Ul40~ - ~o~. - - - ¡F"""' .f1/Xm»--. -- ~ - - ,J18WJ;:, -:;u>H:07ÄlfTC---"'" :-.. ,---.----. .-. . ií<9.í.'WIJ ..c: ã. aOO.uu -. - - - - 'aG~.oo OM=~~T2 .l~ Mf>H.07AL1T3 MPH-07A ' 4130.10TVD, ~~~1~'MD ã. Q) '-- MPH-07AL1 T1 801452S 314.60W 4088.10TVO, 10461.30S,4a5.17W 4130.10'TVD Q) 0 :00.00 "4157.10lVD, MPH-O;AT2 9307.84S,541.42W MPH-07AT4 7"Casing 0 - 6922.69S,502.70E 4217.1DTVO, MPH-07AT3 4196.10TVO, 131J9.5O'MD ãš ~ .00 8014.52S,314.60W 4154.10lVD, 10461.30S,4a5.17W 4196.IO'TVD ,2 .- 9307.84 S, 541.42 W 1:: 16 4550 - - 4550 Q) > -..-- > North Reference : Units : f~ Scale: 1 inch = 700ft 5950 I 3150 - ~ õ 0 ...... II J: 0 .£ ~ 5250 - 0 (/) I 5950 Scale: 1 inch = 700ft ....~:,,"'.. -_.a. n ^^ "'^ ,.."'". 66.1 Oft above Mean Sea levei 66.1 Oft above Structure Reference True North Feet (US) 6650 I I 6650 Milne Point D',' ."£)'" MPH-07a (L1) ... .rl"~lIest Proposal Data for MPH-07A-L1 Well Reference Well Reference It True North Dogleg severity : Degrees per 100 feel (US) Vertical Section Azlm.th : 183.850° Vèrtical Section Description: Well Reference Vertical Section Origin: 0.00 N,O.OO E Incl. AzIm. Vertical Northing. Eaetlnga Vertical Dogleg Depth Section Rete '''''.'.00 ¡OJ :.-L 192.916 4145.20 6316.53 S ;r.IIIIIE 6250.65 ., .'1.00 I' I ,. ~ ~ 194.Q91 4148.47 6335.71 S "..J "'.E 6270.10 10.000 " ',;.39 .... '~r:" 201.969 4162.22 6531.12 S ¡'J' ~ B 6469.34 6.000 ""¡'J.98 ....,...,:1 201.969 4160.30 6636,45 S r." lI~ B 6577.29 0.000 " ",';.37 ''''1.11 215.000 4157.10 6922.69 S .11' !I)E 6873.32 4.000 '40,]' 1.61 .... '..1..1 221.291 4156.56 7046.33 S .JIr ,..E 7003.20 4.000 11'11":.28 ..... '.L.1 221.291 4153.66 7559.22 S ..1.JM" W 7545.18 0.000 IU' '156 ....1.111 200.000 4151.10 8014.52 S IIJr..W 8017.56 4.000 11I""'J.64 ''''''', 188.705 4142.30 8295.90 S "","W 8303.14 4.000 11'''''.85 ...., I"', 188.705 4090.27 9229.79 S "UIW 9244.53 0.000 1"'..1.82 ."111" 188500 4088.10 9307.84 S .JI J: W 9323.19 4.000 I :"'.31 ¡.I.II 175.298 4095.24 9642.30 S 'W 9657.64 4.000 1 ill ',.81 1\;..;1 175.298 4130.10 10461.30 S ..1IL_I/W ]0470.27 0.000 7350 I Vertical Section (Well Reference) 8050 8750 9450 I I I 10150 I Section Azimuth: 183.850° (True North) 10850 11550 I I - 3150 š 0 ..... II .s::. 0 .~ - 5250 ~ ~ (/) I I 10850 11550 Section Azimuth: 183.850° (True North) I 7350 I I I 8050 8750 9450 Vertical Section (Well Reference) I 10150 8P8' f1Y'--'" BPXA ,,\,nIJiff'¡!t~!¿~1 Milne Point Unit ) )Milne Point MPH-07a (L 1) DrillQJlest:' Scale: 1 inch = 600ft -1200 I Eastings (Well Reference) -600 0 I 600 I 1200 I - -5700 KOP: Start Dlr @ 12.000'/10011: 8125.00IlMD,4046.94ft 1100.00 - -6300 Begin Dir @ 4.000'/10011: 939.9811 MD, 4160.3911 TVD 0 End Dlr, Start Sail @ 82.878': 955.11I1MD,4199.04ttOO".. Begin Dlr @ 4.000'/10011 9076-3711 MD, 4214;9711 TVD " 1j'YSJ.oo / MPH-07À-.Tl 4226.10 TVD. 6922.69 S. 502.7~ 156.66 MPH-07A l1 T1/ ;1400.00 4157.10TVD; 4225.77 6922.69 S, 5,'.70 E - -6900 .I / ",SOD.oo - -7500 / ~.oo ( ) 0 C ( ) (¡) 1D a: / .I / .!700.oo - -8100 l en C> c :c t 0 Z End Dlr, Start Sail @ 93. 2': 10929.64I1MD,4142..3~IITVD",- M:'~~~~~~ .J" End Dlr, Start Sail @ 93.054' : 1 0930.40ftMD,4206.94I1TVD ~ 8014.52 S. 314.60 "t ! '4138,44 / 3: ""0 J: 6 -..J » {; 1) en Q) c: ::J Q) Begin Dlr @ 4.000'/10011: 11883.7911 MD, 4156.1411TVJ "4094,44 I Begin Dlr @ 4.000'/10011: 11875.8511 MD, 4090.2711 TV) ~ MPH-07A Ì'3 """":':-f 4155.37 4154.1000, Decrease In Dlr Rate @ 3.000'/10011: 11960.3611 MD, 4154.101 TVD 9307.84 S, ~1.42 W I Mf'H.07Al1 T3 : 4088.10TVO, 9307.84 ~, 541.42 W '4197.91 I ! - -8700 '4116.44 ~176.s9 -~JO.oo ~ - -9300 S ! . 4091.92 End Dlr, Start Sail @ 87.571': 12290.31I1MD,4095.24I1TVD --¡--. 159.00 I End Dlr, Start Sail @ 87.380': 12443.56I1MD,4165.20IlTVD ---.:.- ! .c. !;t -4108.37 ~~ . ~. 116.92 7;' Casing 3-"" it 1311950'MD .v> . f196.10'1VD ':Ý . ~ n' Casi1g ~ i~'13112.81'MD :-r,,1' . S 'I I 4130.10' TVD ~' >- 125i.32 m:4196.10 10461.30S,485.17W"-. . m:4130.10ft, 0461.30S,485.17W '. Ø407AT4(TD) ".. 4196.10TVD, 10461.30 S. 485.17 W MPH-07A L1 T4 4130.10TVD, 10461.30 S, 485.17 W - -9900 8 0 «> II .s:::. - -10500 ~ (¡j ëij 0 en I -1200 Scale: 1 inch = 600ft I -600 0 Eastings (Well Reference) I 600 I 1200 Reference is True North DrillQuest 2.00.09.008 ) 8P8' ......~~...., Milne Point Unit ~~.rMt.J.lU,n:."J( !'.!íiìi.'" B PXA .r¡¡~4I!'i>:i\,(iM\!Ø1( ' ) :~~~J;~int DriIIQuest'" Well: Horizontal Coordinates: Ref. Global Coordinates: Ref. Structure Reference: Ref. Geographical Coordinates : RKB Elevation: Current Well Properties MPH-07a 6009860.68 N, 556567.80 E 879.92 N, 1169.60 E 70026' 15.3208" N, 149032' 19.5685" W North Reference: Units : 66.1 Oft above Mean Sea Level 66.1 Oft above Structure Reference True North Feet (US) Vertical Origin: Horizontal Origin: Measurement Units: North Reference: Proposal Data for MPH-07 A Well Reference Well Reference ft True North Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 183.850° Vertical Section Description:Well Reference Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azim. Vertical Northings Eastlngs Vertical Dogleg Depth Depth Section Rate 8125.00 76.464 172.130 4046.94 5854,87 S 795.97 E 5788.21 8145.00 76.685 174.587 4051.59 5874.19 S 798.22 E 5807.34 12.000 8955.11 82.878 206.938 4199.04 6645.60 S 649.33 E 6587.00 4.000 9076.37 82.878 206.938 4214.07 6752.86 S 594.82 E 6697.69 0.000 9270.09 90.000 210.000 4226.10 6922.69 S 502.70 E 6873.32 4.000 9606.72 90.238 223.463 4225.40 7191.86 S 301.84 E 7155.36 4.000 10057.33 90.238 223.463 4223.53 7518.92 S 8.12 W 7502.50 0.000 10644.18 91.000 200.000 4217.10 8014.52 S 314.60 W 8017.56 4.000 10930.40 93.054 188.729 4206.94 8291.16 S 385.46 W 8298.33 4.000 11883.79 93.054 188.729 4156.14 9232.16 S 529.95 W 9246.91 0.000 11960.36 90.000 188.500 4154.10 9307.84 S 541.42 W 9323.19 4.000 12443.56 87.380 174.238 4165.20 9789.49 S 552.96 W 9804.52 3.000 13119.50 87.380 174.238 4196.10 10461.30 S 485.17 W 10470.27 0.000 Single Well Target Data for MPH-07a Measurement Units: ft Coordinate Target Point TVD TVD Northlngs Eastlngs Northings Eastlngs Target Name Type Shape MPH-07AFault 1 Entry Point 0.00 0.00 5582.54 S 751.88 E 6004284.00 N 557362.00 E Polygon Boundary Point A 0.00 0.00 5582.54 S 751.88 E 6004284.00 N 557362.00 E B 0.00 0.00 5582.54 S 751.88 E 6004284.00 N 557362.00 E C 0.00 0.00 8207.85 S 1195.09 W 6001644.00 N 555435.00 E MPH-07 A Fault3 Entry Point 0.00 0.00 9253.01 S 2233.05 W 6000591.00 N 554405.00 E Polygon Boundary Point A 0.00 0.00 9253.01 S 2233.05 W 6000591.00 N 554405.00 E B 0.00 0.00 11047.48 S 463.61 W 5998810.00 N 556188.00 E C 0.00 0.00 12757.15 S 409.45 E 5997107.00 N 557074.00 E D 0.00 0.00 11047.48 S 463.61 W 5998810.00 N 556188.00 E MPH-07a GeoPoly Entry Point 4157.10 4091.00 6922.69 S 502.70 E 6002942.00 N 557123.00 E Polygon Boundary Point A 4157.10 4091.00 6630.96 S 406.91 E 6003233.00 N 557025.00 E B 4157.10 4091.00 8027.92 S 657.71 W 6001828.00 N 555971.00 E C 4157.10 4091.00 10419.53 S 586.85 W 5999437.00 N 556060.00 E D 4157.10 4091.00 10528.58 S 448.68 W 5999329.00 N 556199.00 E E 4157.10 4091.00 8288.00 S 10.33 E 6001573.00 N 556641.00 E F 4157.10 4091.00 7012.53 S 876.03 E 6002855.00 N 557497.00 E MPH-07 ALl T1 Entry Point 4157.10 4091.00 6922.69 S 502.70 E 6002942.00 N 557123.00 E Point MPH-07 ALl 1'2 Entry Point 4151.10 4085.00 8014.52 S 314.60 W 6001844.00 N 556314.00 E Point MPH-07 ALl T3 Entry Point 4088.10 4022.00 9307.84 S 541.42 W 6000549.00 N 556097.00 E Point MPH-07ALl T4 Entry Point 4130.10 4064.00 10461.30 S 485.17 W 5999396.00 N 556162.ooE Point MPH-07 A Lease line Entry Point 0.00 0.00 6680.61 S 693.49 W 6003175.00 N 555925.00 E Polygon Boundary Point A 0.00 0.00 6680.61 S 693.49 W 6OO3175.00N 555925.00 E B 0.00 0.00 6680.61 S 693.49 W 6003175.00 N 555925.00 E C 0.00 0.00 11495.78 S 690.02 W 5998360.00 N 555965.00 E MPH-07 A T1 Entry Point 4226.10 4160.00 6922.69 S 502.70 E 6002942.00 N 557123.00 E Point MPH-07 A 1'2 Entry Point 4217.10 4151.00 8014.52 S 314.60 W 6001844.00 N 556314.00 E Point MPH-07 A T3 Entry Point 4154.10 4088.00 9307.84 S 541.42 W 6000549.00 N 556097.00 E Point MPH-07 A T4 (TD) Entry Point 4196.10 4130.00 10461.30 S 485.17 W 5999396.00 N 556162.00 E Point DrillQuest 2.00.09.008 ANTI-COLUS/ON SIITTINGS /nteIpOlatioo MethodMD IntervaJ: 50.00 =mR,:r.:,:,: m~:~g i~~eren<e: ~f¡'::9iJ:H./J7. wp08 COMPANY DIITAllS BP Amoco SURVEY PROGRAM Depth FIn Deptb To SurveylPlan 8125.00 /3/19.50 Planned: MPH./J7. wp08 V/ WELL DIITAllS Name tN/.S tFl.W Northing Eaating Latimde Loogitude SloI MPH./J788O.19 1169.57 6009860.68 556567.80 7O'26'15.32IN 149'32'19.569W N/A -320 -300 -250 -200 -150 -/00 --SO -0 '-50 -100 -ISO --200 -250 -300 -320 Calculation Method: Minirnwn Cmvature Error Sysrem: ISCWSA Scan Method: Trav Cylinder North Error Surlàce: Elliptical + Casing Warning Method: RuI.. Based From Colour ToMD 0 - 8125 8125 - 8250 8250 - 8500 8500 9000 9000 - 9500 9500 - 10000 10000 - 10500 10500 /1000 /1000 - /1500 ~ :p s \. § MD In. See I 8125.00 76.46 172./3 2 8145.00 76.69 174.59 3 8955.11 82.88 206.94 4 9076.37 82.88 206.94 5 9270.09 90.00 210.00 6 9606.72 90.24 223.46 7 10057.33 90.24 223.46 8 10644.18 91.00 200.00 9 10930.40 93.05 188.73 10 11883.79 93.05 188.73 II 11960.36 90.00 188.50 12 12443.56 87.38 174.24 /3 /3119.50 87.38 174.24 'If -'~.ir a1(øJ.!!!!,g' CylJ!!der Azimuth (1FO+AZI) [<leg] vs Centre to Centre Separation [1 OOftfm] Tool MWD+/FR+MS Azi TVD 4046.94 -5854.87 4051.59 .5874.19 4198.99 .6645.60 4214.02 .6752.86 4226.05 .6922.69 4225.34 .7191.86 4223.45 .7518.94 4217.01 -8014.56 4206.86 .829I.!9 4156./4 -9232.20 4/54.10 .9307.87 4165.20 .9789.52 4/96.10 ./0461.34 WELLPATHDETAIlS Plan MPH.07. Pareni::\it MPH./J7 8/25.00 Rig: ReI' Datmn: 33: 145/25/1997 11:59 66.lOft V.Section Angle 182.66' ~-S ~~~ Starting From TVD OJ)() 0.00 30.00 LEGEND - MPH'()7 (MPH.()7), NOERRORS - MPH-07 (Plan MPH'()7aL1), NOERRORS - Plan MPS-30 (Plan MPS-31), Major Risk - Plan MPS-32 (Plan MPS-32), Major Risk - Plan MPH'()7a - MPH.07awpOS '-" Plan: MPH./J7a wp08 (MPH'()7IP1an MPH.()7a) / "-' Created By: Bart Goff Date: 02113/2002 Checked: Dato:- Date:- Reviewed: Approved: Date:- SECTION DEI'AILS +N/oS +f!1.W Dleg TFaœ VSec Target 795.97 0.00 0.00 58/1.70 798.22 /2.02 84.89 5830.90 649.29 4.00 82.24 6608.38 594.78 0.00 0.00 67/8.05 502.66 4.00 23.33 6891.96 301.80 4.00 88.97 7/70./6 -8./4 0.00 0.00 75/1.24 .314.6/ 4.00 271.96 8020.53 -385.48 4.00 280.48 8300./4 .529.98 0.00 0.00 9246.84 -541.44 3.99 184.3/ 9322.96 -552.99 3.00 259.48 9804.62 -485.22 0.00 0.00 10472.59 ANTI-COLUSION SETIINGS Intetp01ation MethodMD Interval: 25.00 ~m~f."g~: ~J~98 i~~: Þf;.,I:9~H-07a wp08 COMPANY DEI'AlIS BP Amoco SURVEY PROGRAM Depth Fm Depth To Survey/Plan 8125.00 13\1950 Planned: MPH-07a wp08 VI WELLPATHDETAlIS WELL DEI' AIlS Name +Nt.S +Fl.W Northing Eas1ing Latitude Longitude Slot MPH-07 880.19 1169.57 6009860.68 556567.80 7O'26'1S.32IN 149'32'19.569W N/A --96 --90 -75 --60 --45 -30 -IS -0 27C. -15 -30 --45 --60 -75 --90 --96 Tool MW\}tIFR+MS Pareni;:':~ Plan MPH-07a MPH-07 8125.00 Calculation Method: Minimum emvature Error S)'SIem: ISCWSA Scan Method: Thlv Cylinder North Error Smûce: Elliptical + Casing Warning Method: Rules Based 33: 145/25/1997 \1:59 66.10ft Rig: Ref. Datum: V.Section Angle = %~ OJ)() 0.00 30.00 Starting From TVD From Colour To MD 0 - 8125 8125 - 8250 8250 - 8500 8500 9000 9000 - 9500 9500 - 10000 10000 - 10500 10500 11000 \1000 - \1500 182.66° LEGEND - MPH-07 (MPH-07), NOERRORS - MPH-07 (Plan MPH-07aLl), NOERRORS - PlanMPS-30(PIanMPS-31),M'liorRisk - Plan MPS-32 (Plan MPS.32), NOERRORS - Plan MPH-07a - MPH-07awpOS ~ F=" ~ ~ j Plan: MPH-07a wp08 (MPH-07/Plan MPH-07a) ,. .~ Creat«! By: Bart Goff Date: 02113/2002 . Checl<ed: Date: -- Date:- Reviewed: Approved: Date:- 180 ilo SECI'ION DEI' AILS See MD Ine Azi TVD +Nt-S +FJ.W DLeg TFace VSec Target I 8125.00 76.46 172.13 4046.94 .5854.87 795.97 0.00 0.00 581\.70 2 8145.00 76.69 174.59 405\.59 -5874.19 798.22 12.02 84.89 5830.90 3 8955.11 82.88 206.94 4198.99 .6645.60 649.29 4.00 82.24 6608.38 4 9076.37 82.88 206.94 4214.02 .6752.86 594.78 0.00 0.00 6718.05 5 9270.09 90.00 210.00 4226.05 .6922.69 502.66 4.00 23.33 689\.96 6 9606.72 90.24 223.46 4225.34 .719\.86 30\.80 4.00 88.97 7170.16 7 10057.33 90.24 223.46 4223.45 .7518.94 -8.14 0.00 0.00 75\1.24 8 10644.18 9\.00 200.00 4217.01 -801456 -314.61 4.00 27\.96 8020.53 9 10930.40 93.05 188.73 4206.86 -8291.19 .385.48 4.00 280.48 8300.14 10 11883.79 93.05 188.73 4156.14 .9232.20 -529.98 0.00 0.00 9246.84 \1 11960.36 90.00 18850 4154.10 .9307.87 -54\.44 3.99 184.31 9322.96 12 1244356 87.38 174.24 4165.20 -9789.52 -552.99 3.00 259.48 9804.62 13 1311950 87.38 174.24 4196.10 .1046\.34 -485.22 0.00 0.00 10472.59 T! -"i-- )r- raftlliM Cy~der Azimuth (JPO+AZI) [deg] vs Centre to Centre Separation [30ftfm] ANTI-COLUSION SIITTINGS ~~~on =~O !;':rvaJ: ~i010950 Maximum ~e: 1508.98 Rete.....: Plan: MPH-07a wp08 COMPANY DErAI!S BP Amoco SURVEY PROGRAM Depth Fm Depth To Survey/Plan 8125.00 13119.50 Planned; MPH-07a wp08 VI WELL DErAIlS Name +NI.S +Fi.W Nolthing Eas1ing LaDb1de Longib1de Slot MPH-07 880.19 116957 6009860.68 556567.80 70026'15.32IN 149"32'19.569W N/A -320 -300 -250 -200 ~-150 -100 -50 -0 270 -50 -100 ~ -150 -200 -250 -300 -320 Calculation Method: Minirnwn CUrvature == ~c:'J~derNorth Error Sur1åœ: Eltiptical + Casing Warning Method: Rules Based From Colour To MD 0 - 8125 8125 - 8250 8250 - 8500 8500 9000 9000 - 9500 9500 - 10000 10000 - 10500 10500 11000 11000 - 11500 See MD Inc 18032& I 8125.00 76.46 172.13 2 8145.00 76.69 174.59 3 8955.11 82.88 206.94 4 9076.37 82.88 206.94 5 9270.09 90.00 210.00 6 9606.72 90.24 223 .46 7 10057.33 90.24 223 .46 8 10644.18 91.00 200.00 9 10930.40 93.05 188.73 10 11883.79 93.05 188.73 II 11960.36 90.00 18850 12 12443.56 87.38 174.24 13 1311950 87.38 174.24 Azimuth (TFO+AZI) [<leg] vs Centre to Centre Separation [100fti'm] Tool MWD+IFR+MS An TVD 4046.94 -5854.87 4051.59 -5874.19 4198.99 .6645.60 4214.02 -6752.86 4226.05 .6922.69 4225.34 .7191.86 4223.45 .7518.94 4217.01 -8014.56 4206.86 -8291.19 4156.14 -9232.20 4154.10 -9307.87 4165.20 .978952 4196.10 .10461.34 WI!LLPATH DETAIlS Plan MPH-07. paren+~~~t MPH-07 8125.00 Ri8: Ref. Datum: V.s.ctioo Angle 182.66° 33: 145/25/199711:59 66.10ft ?W.s ~~~ ~~"'D 30.00 0.00 0.00 LEGEND - MPH-07 (MPH-07), NOERRORS - MPH.07 (Plan MPH.07oLI), NOERRORS = ~::: ~::;.~g ~~::: ~::;.m:~~ER~~~ - Plan MPH-07a - MPH-07a wp08 Plan: MPH-07. wp08 (MPH-07/Plan MPH-07a) Created By: Bart Goff Da..: 0211312002 Checked: Date: --- Reviewed: ----- Approved: ---- Date: -- Date: --- SECI10N DErAIlS +N/.S +Fl-W DLc8 TF."" vSee TlUBel 795.97 0.00 0.00 5811.70 798.22 12.02 84.89 5830.90 649.29 4.00 82.24 6608.38 594.78 0.00 0.00 6718.05 502.66 4.00 23.33 6891.96 301.80 4.00 88.97 7170.16 -8.14 0.00 0.00 7511.24 .314.61 4.00 271.96 8020.53 .385.48 4.00 280.48 8300.14 .529.98 0.00 0.00 9246.84 .541.44 3.99 184.31 9322.96 -552.99 3.00 259.48 9804.62 -485.22 0.00 0.00 1047259 ') ) WPH -O~ F VfT ~ 20" Conductor Tree: 2 9/16"-5M CIW Wellhead: 11", 5M FMC Gen 5 PBU W II"X2 7/8"FMC tbg. Hnr. 8rd EUE Threads top and bottom.. 2.5" CIW H BPV profile 95/8" window at 8125' ~ TD ESP Completion on 2 7/8", 6.5#, EUE 8rd tubing 7", 25#, BTC-M Casing ~~ - ~W'~2,6#,BTC~ottedLinerOA !>.OO5"TD Cement - - - - - - - - - -- - - - - - - Squeezed - Perforations: 8239'-8349' - - -- 8674'-8694' - -- = . 8906'-8926' >< 5< 7" shoe @ 9268' 95/8",47 and 40 # casing @ 9217' ) ) \ 20d439 DATE 01/17/02 CHECK NO. 00204439 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT ALASKAOILA NET 00 11602 CKOl1602F PYMT :OMMENTS: HANDLING INST: 100.00 100.00 H Per~it to Drill ~ee 5tH - Terrie HubJle X4628 RECEIVED ----v'v\ p ~. -DOl Kt F. F F; n ~. ?OO.). ~'.. ~.. \,.;< ".:.,. L C AlaskaOi¡&GasCoos.~ Ån~ ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ..i- TOTAl!.. 100.00 100.00 BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND, OHIO No. H 204439 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 """412 00204439 PAY ONE HUNDRED & 00/100************************************* US DOLLAR DATE 01/17/02 AMOUNT $100.00 To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AK 99501 Q~ ~~ÄP/J...... III 2 0 ... ... ~ g III I: 0 l. . 2 0 3 a g 5 I: 0 0 a l. l. . 9 III TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ft{ FÛ II - 0 7.4 CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILLj EXPLORA TJON INJECTION WELL INJECTION WELL RED RILL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 6.0-69) PILOT HOLE (PH) . ANNUL~~L ANNULAR DISPOSAL L--> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, . API No. . Production should continue to be reported as a function of the original API number stated above. . In accordance with 2.0 AAC 25..0.05(1), all records, data and logs acquired for tbe pilot bole must be dearly differentiated in both name (name. on permit plus PH) and API number (5.0 -7.0/8.0) from records, data and logs acquired for well (n8:me on permit). Annular disposal has not been requested... Annular Disposal. of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS L--> YES + SP ACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill tbe above referenced well. The permit is approved . subject to full compliance with 2.0 AAC 25..055. Approval to peñorate and produce is contingent upon issuan'ce of a conservation order approving a spacing exception. (Company Name) will assume tbe liability of any protest to tbe spacing exception tbat may occur. d¿?/ /?7?a / WELL PERMIT CHECKLIST COMPANY ¡;IT/ \.,.. WELL NAME #-07.4 PROGRAM: Exp - Dev ~Redrll V Serv - Wellbore seg - Ann. disposal para req- FIELD & POOL 5z..~I'-ID INIT CLASS ~U )' OIL.. GEOL AREA fF1~) UNIT# () / /32-7f5 ON/OFF SHORE 0/1 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . /- . /J 2. Lease number appropriate.~. . . . . . . . . . . . . . . . . ~. .$,;,lA. AG-L /P c.4- ~~ tÅ-.- 0 2-5906/' 7'~ ¡J~c/' ~ -rc--s.v4:..f' 3. Unique well name and number. .. . . . . . . . . . . . . . . . Cvt-<eI7Þ. ~ A:Z>L 38'O/Cfl,,^ ' 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . .. . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . APXR DA Tf: 12. Permit can be issued without administrative approval.. . . . . /~' "'Z...,tf..o~ 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ^¥-tt Ai/A /7 15. Surface casing protects all known USDWs. . . . . . . . . . . AlA Y N ß--dr//( // t~./:ilz~ ~/' 16. CMT vol adequate to circulate on conductor & surf csg. . . . . ¥--N- N I A tJ 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y t1'D . 18. CMT will coverall known productive horizons. . . . .. . . . . ~&^~ A I.l~ {L¿ tr Bi.œt;." Cbue.-v t . ~~: ~~:~~a~:~~~~~;~~~~:~~~~ ~¡t~.' ~ ~ :~r~~fr.o~t.. : : : : : : '. ~ N~b OVc~ . l1 E 21. Ifare-drill, has a 10-403 for abandonment been approved. . . N AfprulLe.d 2-/ f¡O'Z.. 22. Adequate wellbore separation proposed.. . . . . . . . . . . . N 23. If diverter required, does it meet regulations. . . . . . . . . . E-N-I'#'A 24. Drilling fluid program schematic & equip list adequate. . . . . QY N 25. BOPEs, do they meet'regulation . . . . . . . . . . . . . . . . éP N ~. APP~ D~T~/ 26. BOPE press rating appropriate; test to 3500 psig. ø N ¡./iMp = /[..07 fSA., ~GÁ" 7-( i 'tJ 0 l- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N ,o.fW1 ":JJ ~ 28. Work will occur without operation shutdown. . . . . . . . . . . 1£ N kp:- f. ( ,.S 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . ~~Y 31. Data presented on potential overpressure zones. . . . . . . Y ~~ VÞ7;- ,ç~~ ~~k.d,4;;, ~ 7. ç.,.,~/d E..qçJ 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . .. , fA N AP~ DATE 33. Seabed condition survey (If off-shore). . . . . . . . ',' . ./N Y N ~A 2-'/3.0'2- 34. Contact name/phone for weekly progress reports [explrory only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENG~G: UIC/Annular: COMMISSION: ~ ~~/'(~~ ~ SFD~'~ WGA \J.JC7Æ- DTS O?/IS / oJ '2.... JMH ¿)1\..\ 1+ 2/110/ ö 2--- APPR OA TE G:\geology\permits\checklist.doc j Y N Y N ;do C«AY<~. d;,'>¡tÐ~0( veJúPdÚ ' Comments/Instructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readabilfty of the Well History file and to simplify finding information, 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 Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue May 21 07:50:07 2002 Reel Header Service name... ......... .LISTPE Date.................... .02/05/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name...... ........ ..UNKNOWN Continuation Number... ...01 Previous Reel Name..... ..UNKNOWN Comments. ........ .... ....STS LIS Tape Header Service name........... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name...... ........ ..UNKNOWN Continuation Number.... ..01 Previous Tape Name..... ..UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22041 R. FRENCH E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 # REMARKS: Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services MPH-07A 500292259701 BP Exploration Sperry Sun 21-MAY-02 (Alaska), Inc. MWD RUN 3 AK-MW-22041 R. FRENCH E. VAUGHN MWD RUN 4 AK-MW-22041 R. FRENCH C. DIXON 34 13N 10E 2709 4079 .00 71. 00 34.00 CASING SIZE (IN) 20.000 9.625 7.000 DRILLERS DEPTH (FT) 110.0 8149.0 9203.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL CASING AND IS NOT PRESENTED. aOd-tB~ IO~'15 ) ) 3. MWD RUNS 2 - 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 9178' MD, 4231' TVD TO 9203' MD, 4232' TVD. 5. RESISTIVITY DATA LOGGED BEHIND CASING FROM 9170' MD, 4230' TVD TO 9203' MD, 4232' TVD. 6. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCHNORR DATED 04/08/02. WELL MPH-07A IS TIED INTO MPH-07APB1 AT THE KICKOFF POINT. THIS WELL KICKS OFF FROM MPH-07 AT 8149' MD, 4136' TVD (TOP OF WHIPSTOCK) . THIS WELL KICKS OFF FROM MPH-07APB1 AT 10770' MD, 4181' TVD. (OPEN HOLE SIDETRACK) . ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL MPH-07A WITH API # 50-029~22597-01. THIS WELL REACHED A TOTAL DEPTH OF 12998' MD, 4141' TVD. SROP = SMOOTHED RATE OF PENETRATION 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 $ File Header Service name.......... ...STSLIB.001 Service Sub Level Name... Version Number. ....... ...1.0.0 Date of Generation.... ...02/05/21 Maximum Physical.Record..65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FI LE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 8141. 0 8141. 0 8141. 0 8141.0 8141. 0 8149.5 8185.0 STOP DEPTH 12951.5 12951.5 12951.5 12951. 5 12951.5 12944.5 12998.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # ) MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 2 8141.0 3 9213.5 4 10770.5 MERGE BASE 9213.0 10770.0 12998.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.......... ...... ..0 Data Specification Block Type... ..0 Logging Direction. .... ..... .......Down Optical log depth units.... ...... .Feet Data Reference Point.. ...... ..... .Undefined Frame Spacing..................... 60 . lIN Max frames per record........ .... .Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...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 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8141 12998 10569.5 9715 8141 12998 ROP MWD FT/H 0.91 479.32 146.063 9627 8185 12998 GR MWD API 35.47 136.14 84.3726 9591 8149.5 12944.5 RPX MWD OHMM 0.57 1750.93 14.1159 9622 8141 12951.5 RPS MWD OHMM 0.06 1942.42 16.4642 9622 8141 12951.5 RPM MWD OHMM 1. 07 2000 27.2409 9622 8141 12951.5 RPD MWD OHMM 0.04 2000 27 .797 9622 8141 12951. 5 FET MWD HR 0.19 108.34 1.8911 9622 8141 12951.5 First Reading For Entire File. ..... ... .8141 Last Reading For Entire File.. ..... ... .12998 File Trailer Service name... ....... ...STSLIB.001 Service Sub Level Name... Version Number. ..... .....1.0.0 Date of Generation.. ... ..02/05/21 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. .... ..02/05/21 Maximum Physical Record..65535 File Type......... .......LO Previous File Name.... ...STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD 2 ) ') header data for each bit run in separate files. 2 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ START DEPTH 8141. 0 8141. 0 8141. 0 8141. 0 8141.0 8149.5 8185.0 STOP DEPTH 9169.5 9169.5 9169.5 9169.5 9169.5 9177.5 9213.0 # 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....... .... ... ....0 Data Specification Block Type... ..0 Logging Direction......... ..... ...Down Optical log depth units. ....... ...Feet Data Reference Point. ... ...... ....Undefined Frame Spacing..... ... ... ... ... ....60 .1IN Max frames per record.. ........ ...Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O 08-MAR-02 Insite 4.05.5 66.37 Memory 9213.0 74.8 88.9 TOOL NUMBER PBOO028HRG6 PBOO028HRG6 8.500 9203.0 Water 8.70 92.0 8.5 700 6.2 Based 2.400 1.876 3.000 2.200 72.0 94.0 72.0 72.0 Name Service Order Units Size Nsam Rep Code Offset Channel ) ) DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8141 9213 8677 2145 8141 9213 ROP MWD020 FT/H 1. 35 479.32 143.914 2057 8185 9213 GR MWD020 API 40.62 127.88 87.8003 2057 8149.5 9177.5 RPX MWD020 OHMM 2.57 1750.93 12.1513 2058 8141 9169.5 RPS MWD020 OHMM 0.06 1942.42 15.6064 2058 8141 9169.5 RPM MWD020 OHMM 4.42 1921. 33 17.3335 2058 8141 9169.5 RPD MWD020 OHMM 0.04 2000 23.8122 2058 8141 9169.5 FET MWD020 HR 0.21 29.01 1. 67895 2058 8141 9169.5 First Reading For Entire File........ ..8141 Last Reading For Entire File..... .... ..9213 File Trailer Service name...... ..... ..STSLIB.002 Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation.. .... .02/05/21 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..... ..02/05/21 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .... .STSLIB.002 Conunent Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 9170.0 9170.0 9170.0 9170.0 9170.0 9178.0 9213.5 STOP DEPTH 10770.0 10770.0 10770.0 10770.0 10770.0 10770.0 10770.0 # 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): 13-MAR-02 Insite 4.05.5 66.16 Memory 10770.0 ) 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.. ......... ..... ..0 Data Specification Block Type... ..0 Logging Direction.... ...... ..... ..Down Optical log depth units.... ..... ..Feet Data Reference Point... .... .... ...Undefined Frame Spacing..................... 60 . lIN Max frames per record.... """ ...Undefined Absent value...................... -999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 ) 87.5 97.2 TOOL NUMBER PB02460HAGR4 PB02460HAGR4 6.125 Water 9.00 52.0 8.5 22000 5.2 Based .250 .205 .300 .280 70.0 87.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9170 10770 9970 3201 9170 10770 ROP MWD030 FT/H 0.91 354.32 148.235 3114 9213.5 10770 GR MWD030 API 35.47 115.37 78.5043 3185 9178 10770 RPX MWD030 OHMM 0.57 1458.06 12.2248 3201 9170 10770 RPS MWD030 OHMM 0.7 1461. 79 13.5081 3201 9170 10770 RPM MWD030 OHMM 1. 07 2000 43.6982 3201 9170 10770 RPD MWD030 OHMM 1. 21 2000 40.3145 3201 9170 10770 FET MWD030 HR 0.27 108.34 3.60828 3201 9170 10770 ) ) First Reading For Entire File..... .... .9170 Last Reading For Entire File...... .... .10770 File Trailer Service name... ... ..... ..STSLIB.003 Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation...... .02/05/21 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...... .02/05/21 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.003 Conunent Record FILE HEADER FI LE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR ROP FET $ 4 header data for each bit run in separate files. 4 .5000 START DEPTH 10770.5 10770.5 10770.5 10770.5 10770.5 10770.5 10770.5 STOP DEPTH 12951. 5 12951. 5 12951.5 12951.5 12944.5 12998.0 12951. 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: 15-MAR-02 Insite 4.05.5 66.16 Memory 12998.0 86.6 95.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02460HAGR4 PB02460HAGR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Based Water 9.00 52.0 8.5 24000 4.6 ) ) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .250 .190 .300 .280 70.0 94.5 70.0 80.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type. .... ......... ....0 Data Specification Block Type. ....0 Logging Direction..... ...., ... ... . Down Optical log depth units... ....... .Feet Data Reference Point.. .......... ..Undefined Frame Spacing..... ........... ... ..60 .1IN Max frames per record. .......... ..Undefined Absent value...................... -999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10770.5 12998 11884.3 4456 10770.5 12998 ROP MWD040 FT/H 1. 48 337.01 145.537 4456 10770.5 12998 GR MWD040 API 48.71 136.14 87.0491 4349 10770.5 12944.5 RPX MWD040 OHMM 5.22 1477.86 16.4301 4363 10770.5 12951. 5 RPS MWD040 OHMM 5.58 1638.15 19.0377 4363 10770.5 12951.5 RPM MWD040 OHMM 5.91 1554.46 19.84 4363 10770.5 12951.5 RPD MWD040 OHMM 6.06 1619.66 20.4929 4363 10770.5 12951.5 FET MWD040 HR 0.19 2.68 0.731325 4363 10770.5 12951.5 First Reading For Entire File... ... ... .10770.5 Last Reading For Entire File....... ....12998 File Trailer Service name.... ...... ...STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..02/05/21 Maximum Physical Record..65535 File Type................ LO Next File Name. ..........STSLIB.005 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/21 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.......... ......UNKNOWN Continuation Number.. ....01 ) Next Tape Name..... ......UNKNOWN Comments. ... ... ....... ...STS LIS Writing Library. Reel Trailer Service name.. .......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/21 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name...... .... ... ...UNKNOWN Continuation Number... ...01 Next Reel Name.......... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Physical EOF End Of LIS File ) Scientific Technical Services Writing Library. Scientific Technical Services " ) ) ~ Od- ~<j Jo'{41p Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon May 20 10:51:25 2002 Reel Header Service name..... ... .... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/20 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... '" ....... ..UNKNOWN Continuation Number.... ..01 Previous Reel Name..... ..UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name..... "" ... .LISTPE Date. . . . . . . ~ . . . . . . . . . . . . .02/05/20 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number... ...01 Previous Tape Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22041 R. FRENCH E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MSL 0) # WELL CASING RECORD OPEN HOLE BIT SIZE (IN) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 # REMARKS: Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services MPH-07A PBl 500292259770 BP Exploration Sperry Sun 20-MAY-02 (Alaska), Inc. MWD RUN 3 AK-MW-22041 R. FRENCH E. VAUGHN 34 13N 10E 2709 4079 .00 71. 00 34.00 CASING SIZE (IN) 20.000 9.625 7.000 DRILLERS DEPTH (FT) 110.0 8149.0 9203.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY TO SET WHIPSTOCK AND MILL CASING AND IS NOT PRESENTED. ) ) 3. MWD RUNS 2 & 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4) . 4. GAMMA RAY (SGRC) IS LOGGED BEHIND CASING FROM 9178' MDt 4231' TVD TO 9203' MDt 4232' TVD. 5. RESISTIVITY DATA LOGGED BEHIND CASING FROM 9170' MDt 4230' TVD TO 9203' MDt 4232' TVD. 6. MWD DATA IS CONSIDERED PDC PER THE E-MAIL FROM D. SCHNORR DATED 04/08/02. THIS WELL KICKS OFF FROM MPH-07 AT 8149' MDt 4136' TVD (TOP OF WHIPSTOCK) . ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL MPH-07APBl WITH API # 50-029-22597-70. THIS WELL REACHED A TOTAL DEPTH OF 11234' MDt 4136' TVD. SROP = SMOOTHED RATE OF PENETRATION 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 $ File Header Service name...... ..... ..STSLIB.OOl Service Sub Level Name... Version Number.. ...... ...1.0.0 Date of Generation...... .02/05/20 Maximum Physical Record..65535 File Type........ ...... ..LO Previous File Name..... ..STSLIB.OOO Cormnent Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 8141. 0 8141. 0 8141.0 8141.0 8141. 0 8149.5 8185.0 STOP DEPTH 11188.5 11188.5 11188.5 11188.5 11188.5 11181.5 11234.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA PBU TOOL MWD MWD SOURCE CODE BIT RUN NO MERGE TOP 2 8141.0 3 9213.5 MERGE BASE 9213.0 11234.0 ) ) $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type....... ....... ....0 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. ..0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8141 11234 9687.5 6187 8141 11234 ROP MWD FT/H 0.91 479.32 144.416 6099 8185 11234 GR MWD API 35.47 127.88 82.7454 6065 8149.5 11181.5 RPX MWD OHMM 0.57 1750.93 12.5769 6096 8141 11188.5 RPS MWD OHMM 0.06 1942.42 14.6923 6096 8141 11188.5 RPM MWD OHMM 1. 07 2000 31.3038 6096 8141 11188.5 RPD MWD OHMM 0.04 2000 31. 8612 6096 8141 11188.5 FET MWD HR 0.21 108.34 2.56655 6096 8141 11188.5 First Reading For Entire File... .......8141 Last Reading For Entire File..... .... ..11234 File Trailer Service name. ... ...... ...STSLIB.OOl Service Sub Level Name... Version Number.... ..... ..1.0.0 Date of Generation.... ...02/05/20 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.... ...02/05/20 Maximum Physical Record..65535 File Type................ LO Previous File Name... ....STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY 2 header data for each bit run in separate files. 2 .5000 ) VENDOR RPX FET RPD RPS RPM GR ROP $ STOP DEPTH 9169.5 9169.5 9169.5 9169.5 9169.5 9177.5 9213.0 TOOL CODE START DEPTH 8141.0 8141. 0 8141. 0 8141. 0 8141. 0 8149.5 8185.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO 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 Da ta Record Type....... . . . . . . . . . . .0 Data Specification Block Type.....O Logging Direction....... ... .......Down Optical log depth units... ........Feet Data Reference Point... ...........Undefined Frame Spacing..................... 60 . lIN Max frames per record... ...... ....Undefined Absent value...................... -999 Depth units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) 08-MAR-02 Insite 4.05.5 66.37 Memory 9213.0 74.8 88.9 TOOL NUMBER PBOO028HRG6 PBOO028HRG6 8.500 9203.0 Water 8.70 92.0 8.5 700 6.2 Based 2.400 1.876 3.000 2.200 72.0 94.0 72.0 72 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 ) ) RPM MWD020 RPD MWD020 FET MWD020 OHMM OHMM HR 4 4 4 1 68 1 68 1 68 20 24 28 6 7 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8141 9213 8677 2145 8141 9213 ROP MWD020 FT/H 1. 35 479.32 143.914 2057 8185 9213 GR MWD020 API 40.62 127.88 87.8003 2057 8149.5 9177.5 RPX MWD020 OHMM 2.57 1750.93 12.1513 2058 8141 9169.5 RPS MWD020 OHMM 0.06 1942.42 15.6064 2058 8141 9169.5 RPM MWD020 OHMM 4.42 1921. 33 17 . 3335 2058 8141 9169.5 RPD MWD020 OHMM 0.04 2000 23.8122 2058 8141 9169.5 FET MWD020 HR 0.21 29.01 1. 67895 2058 8141 9169.5 First Reading For Entire File.... .... ..8141 Last Reading For Entire File.. ... .... ..9213 File Trailer Service name.... ....... ..STSLIB.002 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation...... .02/05/20 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...... .02/05/20 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 RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 9170.0 9170.0 9170.0 9170.0 9170.0 9178.0 9213.5 STOP DEPTH 11188.5 11188.5 11188.5 11188.5 11188.5 11181.5 11234.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 13-MAR-02 Insite 4.05.5 66.16 Memory 11234.0 87.5 97.2 ') # 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.... ..... ....... ..0 Data Specification Block Type.. ...0 Logging Direction.. .... ....... ....Down Optical log depth units... ....... .Feet Data Reference Point. ..... ...... ..Undefined Frame Spacing..................... 60 .1IN Max frames per record.. .... ... ....Undefined Absent value... ....... .... ... .... .-999 Depth Units..... . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O TOOL NUMBER PB02460HAGR4 PB02460HAGR4 6.125 Water 9.00' 52.0 8.5 22000 5.2 Based .250 .200 .300 .280 70.0 87.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9170 11234 10202 4129 9170 11234 ROP MWD030 FT/H 0.91 439.16 144.671 4042 9213 .5 11234 GR MWD030 API 35.47 124.67 80.1512 4008 9178 11181.5 RPX MWD030 OHMM 0.57 1458.06 12.7938 4038 9170 11188.5 RPS MWD030 OHMM 0.7 1461.79 14.2264 4038 9170 11188.5 RPM MWD030 OHMM 1. 07 2000 38.4239 4038 9170 11188.5 RPD MWD030 OHMM 1. 21 2000 35.9635 4038 9170 11188.5 FET MWD030 HR 0.27 108.34 3.01892 4038 9170 11188.5 First Reading For Entire File...... ....9170 Last Reading For Entire File..... ..... .11234 File Trailer ) ) Service name....... ......STSLIB.003 Service Sub Level Name... Version Number... .., .... .1.0.0 Date of Generation..... ..02/05/20 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF Tape Trailer Service name....... .... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/05/20 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. . . . . . . . . . . . . . . . . . . . .02/05/20 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
