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Home My WebLink About204-176 . 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. ~Q y. - L 7- & Well History File Identifier Organizing (done) o Two-sided 11111111111111 II III o Rescan Needed '" 1/111111" 111111 RESCAN ~olor Items: ~reYSCale Items: o Poor Quality Originals: DIGITAL DATA ~skettesl No. ~ o Other, NofType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: Scanning Preparation BY: 151 ~ 1111111111111111111 151 .l&U2- + -W- = TOTAL PAGES 8' J (Count does not include cover sheet) 151 BY: ~ Date: 1/ /17Io~ I I Project Proofing BY: ~ Date: Production Scanning Stage 1 Page Count from Scanned File: lQ d.... (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES BY: ~ Date:II!17/0h Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 111111111111/1 " III NO 151 Vttr NO 151 11I11111111I" " III BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned 11I111111111/11111I BY: Maria Date: 151 Comments about this file: Quality Checked III "111I11I" 11111 10/6/2005 Well History File Cover Page.doc • • ~:.:-. ~~ 3. MLCROFILMED 03/01/2008 .u~~~_ _,~; s: ,~ ; ", Y. DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilxn Marker.doc I J rv f1 v .t ~ ~Jo DATA SUBMITTAL COMPLIANCE REPORT 10/13/2006 Permit to Drill 2041760 Well Name/No. MILNE PT UNIT SB H-18L2 Operator BP EXPLORATION (ALASKA) INC spuL ~ð1-~(¿J API No. 50-029-23224-61-00 MD 8630'- TVD 3986 / Completion Date 10/13/2004 r Completion Status 1-01L Current Status 1-01L UIC N ~~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, IFRlCASANDRA, lAB, GYRO Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Type Med/Frmt Number Name E D Asc Directional Survey pt Directional Survey ~ D Ase Directional Survey g Directional Survey D TIF 12902 Gamma Ray ~ 12902 LIS Verification C Lis 13524 Induction/Resistivity Well Cores/Samples Information: Interval Name Start Stop Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 6017 8630 Open 11/9/2004 IIFR 6017 8630 Open 11/9/2004 IIFR 6017 8630 Open 11/9/2004 MWD 6017 8630 Open 11/9/2004 MWD i I 6072 8570 Open 11/15/2004 GR, EWR4, ROP, ASI I I 6072 8570 Open 11/15/2004 GR, EWR4, ROP, ABI 114 8595 Open 2/22/2006 ROP DGR EWR plus I Graphics -------1 . Sent Received Sample Set Number Comments . ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? ~ /N ~/N Chips Received? - T I 1'1 Formation Tops Analysis Received? ~ --~ --~~ Comments: -Þ ~~~-~.~- Date~ tv ~ () Compliance Reviewed By: · . WELL LOG TRANSMITTAL ~o4-i15' ì~5~3 &04- ~/1ø t ~1j;)4- To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 RE: MWD Formation Evaluation Logs MPH-18 Ll + L2, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPH-18 Ll + L2: LAS Data & Digital Log Images: 50-029-23227-60,61 F)O-{/Jq - ¿)3~),~4-- ¿,D Fj{)-OQ,cl - ~3~~4-- &/ 1 CD Rom r!~r: "/ 9-' rJ-~' u a . STATE OF ALASKA . RECEIVED ALASKA AND GAS CONSERVATION CO . SSION REPORT OF SUNDRY WELL OPERATIONSJL\N 0 9 2006 Alaska Oil & Gas Cons. Commission 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 025906 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner LEM Isolation Sleeve "Lateral Entry Module (LEM) Length Perforation Depth MD (ft): Perforation Depth TVD (ft): Con mp o Suspend 1/ Repair Well 1/ Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver 1/ Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: 1/ Development 0 Exploratory o Stratigraphic 0 Service 99519-6612 umber: 204-176 6. API Number: 50-029-23224-61-00 KBE = 69.60' 9. Well Name and Number: MPH-18L2 10. Field 1 Pool(s): Milne Point Unit 1 Schrader Bluff feet feet Plugs (measured) NIA feet Junk (measured) N/A feet Size MD TVD Burst Collapse 20" 112' 112' 1490 470 10-314" 4562' 3199' 5210 2480 7-5/8" 6072' 3900' 6890 4790 4-1/2" 6031' - 8596' 3880' - 3990' 8430 7500 4-1/2" 6067' - 6086' 3898' - 3907' 8630 3986 8630' 3986 78' 4527' 6039' 2565' 19' Excluder Screens 6458' - 8550' Excluder Screens 3968' - 3995' 4-1/2", 12.6# L-80 6038' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFl JAN 1 0 Zn06 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl Tubin Pressure Re resentative Dail Gas-Mcf Water-Bbl o Copies of Logs and Surveys run 1/ Daily Report of Well Operations 1/ Well Schematic Diagram 15. Well Class after proposed work: o Exploratory 1/ Development 0 Service 16. Well Status after proposed work: 1/ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL est 0 my nowe ge. Sundry Number or N/A if C.O. Exempt: 17. Printed Name Sondra Stewman Title Technical Assistant 564-4750 D . Prepared By Name/Number: Date L-Dc;'"'(Xp Sondra Stewman, 564-4750 Submit Original Only ~ 41/16"-5M FMC Wellhead' 11" x 11" 5M F. Gen 5, w/4 1/2" Tbg Hgr. " TC-II T&B, CIW "H" BPV Profile MPH-18 20", 92#/11, H-40 c:::!JÐ 103/4" L-80 45.5 #/11 Howco Float Shoe4562' I KOP @ 600' 50+ degree from 2,378' Max hole angle = 64 degrees @ 3915' MD 75/8" 29.7 ppl, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpI) (Cap w/4 1/2" tubing inside = .0262) 41/2" 12.6 ppf, L-80 TC-II tbg. ( drift id = 3.833" cap = .0152 bpf ) Window for NB 6072' to 6084' 4-1/2" Hook Hanger inside casing 6,067' outside hook point 6,084' LEM #2 liner Baker tie back sleeve Baker ZXP Pkr 4.5" seal assy. 6.031' 6,042' 6,215' LEM Isolation Sleeve set across NB Sands ISO Sleeve 6067' - 6086' Min 10 through Sleeve is 2.62". 4 112" GS Fish Neck NB Lateral Window for OA 6.555' to 6,567' 4-1/2" Hook Hanger inside casing 6,549' outside hook point 6,566' OA Lateral LEM #1 liner Baker tie back slv. Baker ZXP top pkr. Baker 190-47 seal bore 4.5" seal assy. 6,188' 6.199' 6,207' 6,721' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC Liner hanger Baker 190-47 seal bore ex!. 6,680' 6.691' 6,702' 6,709' 7-5/8" Weatherford Float Collar 6826' 7-5/8" Weatherford Float Shoe 6910' DATE REV. BY COMMENTS 10/15/04 MDO Drilled & Completed Doyon 14 12/9/04 Lee Hulme ESP Changeout Nabors 4ES 2/20105 Lee Hulme ESP CIO & Isolate NB Sands Nabors4ES 11/24/05 Lee Hulme Convert to Jet Pump Nabors 4ES Orig. DF elev. = 69.60' (Doyon 14) .rig. GL elev. = 35.60' (Doyon 14) HES 4 1/2" X Nipple 3.813 Packing Bore ID I 2062'1 Camco 41/2" x 1" KBG-2 Gas lift mandrel I 2479,1 HES 4 1/2" XD Duro Sleeve 3.813 Packing Bore ID 15922' I Baker 75/8" x 4 1/2" Premier Packer 15946' I HES 4 1/2" X Nipple 3.813 Packing Bore ID 16014' I 16038' I WLEG (bottom) 6 3/4" Hole td @ '8tm Baker Obi Float Shoe 8,598' 7 jts. 4,5 L-80 IBT -M , Swell Packer @ 6,113' 28 jts. .. 4 1/2" C27 Baker med. Excluder 34 jts, 9.5# L-80 IBT 6 3/4- Hole td @ 9,910· Btm Baker Float Shoe 8,565' 46 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 IBT 63/4" Hole td @ 8,639' Btm HES Type V Float Shoe 8,639' 40 its. - 4 1/2" Slotted Liner 4 jts. 12.6# L-80 IBT Mll...NE POINT UNIL WELL MPH-18 API NO: 50-029-23224-00 50-029-23224-60 50-029-23224-61 BP EXPLORATION (AK) BP EXPLORATION Operations Summary Report RDMO from MPE-30. Move to MPH-18. Spot Rig over well. Spot, R/U Pits and Pipe Shed. Take on Hot Seawater to Pits. Aecept Rig @ 1700 hours. Install second Annulus Valve. Hook up lines to Tree and Tiger Tank. Blow down line to tiger Tank to make sure it's open. P/U Lubricator and Pull BPV. Repair leaking manifold on Rig Pump discharge. Test lines to 3500 psi. Pre-Job Safety Meeting on Well Kill procedures. Check Wellhead pressures: 500 psi Tbg, 670 psi Csg. Take on 435 Bbls, 140 F seawater. Pump 260 Bbls of hot seawater (Tbg Avg 500-1000 psi Csg Avg SO-600 psi Circulating). Monitor well for 10 min, 80 psi on Tbg, 100 psi on Csg. Pump 260 Bbls of hot seawater (Tbg Avg 370 psi, Csg Avg 30 psi cireulating) until well returns are elean and warm. DECOMP I Monitor well: 20 psi on Tbg, 40 psi on Csg. Take on hot seawater and build 435 Bbls of 8.9 ppg brine. DECOMP Circulate 262 Bbls, 140 F, 8.9 ppg seawater at 4 BPM (Tbg 400-600 psi, Csg 30 psi cireulating) and see 8.9 ppg elean seawater returns to Pits. Well took 50 Bbls of seawater during Well Kill ops; total Fluid hauled to Well, 900 Bbls; 430 Bbls shipped to disposal; 420 Bbls in Pits. DECOMP Monitor well. Well on slight vacuum, Set and test TWC. RID Surface Lines. Drain Tree. Nipple Down Tree and Adaptor Flange. N/U BOP Stack and Lines. R/U Test Pump. PJSM for BOPE testing. Pressure test BOPE to 2S0 psi low, 3,500 psi per AOGCC and BP requirements. Test witnessed by Toolpusher and BP Co Rep. Jeff Jones and John Spaulding, AOGCC, waived AOGCC's right to witness BOPE tests. DECOMP R/D BOPE test equipment. P/U Lubrieator and extension and pull TWC, UD same. DECOMP P/U 2-7/8' Landing Joint, BOLDS, stab into hanger and pull Hanger free with 50K, pull to floor wI 48K. Well is on slight vaeuum. Check ESP Cable conductivityngood. DECOMP POOH and UD Hanger and 3 jts 2-718' tubing. Getting back heavy oil at surface DECOMP Circulate out heavy oil at surface. Spool up Centrilift ESP Cable. Safety meeting held with on-eoming rig erew. DECOMP P.O.O.H. 2-7/8' 6.5# L-80 8rd EUE Tbg. Lay down 183 Jts., 100 La Salle clamps, 3 Flat Gaurds, S Proteetolizers, 3 GLM,s, XN Nipple. Recovered all Completion components. DECOMP Lay Down ESP Pump; found pump motor full of sand. Also pup above ESP was full of sand also. Clear and Clean rig floor. Pre- Job Safety Meeting for tripping Drill Pipe. Pick up and Make up BHA as follows: 6-1/8' Bit, 5-3/8'Scraper, X-O Reg. to IF, Bumper Jar, Oil Jar, 9 Jts 4-1/2' Drill Collars. RIH BHA #1 on 3-1/2' Drill Pipe from Pipe Shed. Service Rig. Continue RIH w/ Cleanout BHA. Soft tag at 590S'. Reverse eirculating in hole. Can't make Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours Task Code NPT Phase 11/18/2005 06:00 - 10:30 4.50 RIGD P 10:30 - 12:30 2.00 MOB P 12:30 - 17:00 4.50 RIGU P 17:00 - 22:00 5.00 RIGU P 22:00 - 23:00 1.00 KILL P 23:00 - 23:30 0.50 KILL P 23:30 - 00:00 0.50 KILL P 11/19/2005 00:00 - 03:00 3.00 KILL P PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP 03:00 - 04:00 1.00 KILL P 04:00 - 05:30 1.50 KILL P 05:30 - 06:30 1.00 KILL P 06:30 - 07:30 07:30 - 11 :00 11 :00 - 14:30 1.00 WHSUR P 3.50 BOPSU P 3.50 BOPSU P DECOMP DECOMP DECOMP 14:30 - 15:00 O.SO BOPSU P 15:00 - 16:00 1.00 PULL P 16:00 - 17:00 1.00 PULL P 17:00 - 18:00 1.00 PULL P 18:00 - 00:00 6.00 PULL P 11/20/2005 00:00 - 02:30 2.50 PULL P 02:30 - 03:30 1.00 PULL P 03:30 - 04:00 0.50 CLEAN P 04:00 - 05:00 1.00 CLEAN P OS:OO - 06:00 1.00 CLEAN P 06:00 - 06:30 0.50 CLEAN P 06:30 - 11 :00 4.50 CLEAN P 11:00 - 16:30 5.50 CLEAN P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Page 1014 Start: Rig Release: Rig Number: Spud Date: 9/24/2004 End: 11/25/2005 11/15/2005 11/25/2005 Description of Operations Printed: 11/2812005 12:58:38 PM BP EXPLORATION ø:p.e.rationsSummaryRep.ørt Page 2 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/15/2005 11/25/2005 Spud Date: 9/24/2004 End: 11/25/2005 Date From-To Hours Task Code NPT Phase Description of Operations 11120/2005 11 :00 - 16:30 5.50 CLEAN P DECOMP progress; realign valves and cire Long Way and wash down to 5928' RKB. Pump Hi-Vis pill and reverse eireulate clean. Use "Stuff and Huff" to wash to 6027' RKB. Pump 25 Bbl Hi-Vis sweep at 3/5 BPM, 5001900 psi. 16:30 - 17:30 1.00 CLEAN P DECOMP Reverse Circulate 260 Bbls at 5 BPM I 900 psi until clean. 17:30 - 20:00 2.50 CLEAN P DECOMP POOH and SIB DP and DC in Derrick. 20:00 - 20:30 0.50 CLEAN P DECOMP BIO and UD BHA #1. 20:30 - 21 :00 0.50 CLEAN P DECOMP M/U BHA #2: 2-7/8", EUE, 8rd, 15' pup with Mule Shoe, 1-Jt 2-7/8", EUE 8rd Tbg, 3-1/2' IF x 2-7/8", EUE 8rd XO. 21 :00 - 00:00 3.00 CLEAN P DECOMP RIH wI BHA #2 on 3-1/2" DP to top of sand @ - 6023". 11/21/2005 00:00 - 00:30 0.50 CLEAN P DECOMP RIH RlU Cireulating lines. Reverse Cireulate and soft tag at 6049' RKB. 00:30 - 01 :30 1.00 CLEAN P DECOMP Ciireulate and Wash 5.75 BPM /1000 psi to 6052' RKB. Pipe packed off; P/U 2' and pump 25 Bbl Hi-Vis sweep and continue to eireulate from 6050'. 101 :30 - 02:30 1.00 CLEAN P DECOMP Realign valves and Reverse Cireulate from 6050' @ 4/5 BPM until returns elean. Recovered sand. Well loses of 147 bbls during reversing. Monitor well; well on slight vacuum. 02:30 - 06:00 3.50 CLEAN P DECOMP POOH and UD DP and DCs through Pipe Shed. B/O and UD full joint of 2-7/8", 8Rd, pup joint, and Mule Shoe. 06:00 - 12:00 6.00 CLEAN P DECOMP R/D DP handling equipment. RID Centrilift Double Sheave. R/U Torque Turn equipment and wait on maehined 4-1/2" TDS x 4-1/2" TCII XO pup joint from Baker Machine. 12:00 - 15:00 RUNCMP P/U 4.5" WLEG, M/U to HES 'X'-Nipple and begin RIH w/4.5" used tubing (148 jts 4.5", 12.6#, TDS; 2 jts 4.5",12.6#, TCII completion; 2 X-Nipples; 7-5/8" Baker Premier Packer; HES 4-1/2' XD Durasleeve) 15:00 - 17:30 RUNCMP While RIH with the 12th joint, well fluids started eoming to the surface consisting of thiek, foamy oil. About 1/4 to 1/2 Bbl of foamy oil slowly roled over the top of the open tubing which was only 3-4 feet above the floor. Floorhands stabbed in the floor valve and Driller closed the Hydril. Circulated 70 Bbls of 8.9 ppg brine and took 65 Bbls of oily retums to the Tiger Tank. SII the well and pressures were 20 psi tubing and 30 psi casing. Confer with town and decide to pump a 40 -Bbls, 9.1 ppg pill. Pumped 7-Bbls down tubing and remainder down annulus. SII and monitored: 120 psi on tubing and casing, but quickly dropped to 40- 50 psi. Opened tubing and pressure quickly went to 0 psi; opened casing and it dropped to 10 psi then to 0 on the gauge. Well flowed 4 Bbls to the pits, but became a very small amount. Opened Hydril to allow well to equalize and to monitor fluid level. Called AOGCC to tell them circumstanees of the event and they were pleased that we informed them, but said we didn't have to call on this particular event. 17:30 - 19:00 1.50 RUNCO RUNCMP Mix 60-Bbl, 9.1 ppg pill in Pits. Close Hydril and circulate around, taking retums to Pits. Stop pump and monitor flow. Fluid level began to drop slowly, but some small gas bubbles were still breaking out then stopped. Deeide to eontinue RIH. 19:00 - 11 :30 16.50 RUNCO RUNCMP Continue RIH and circulate fluid hrough BOP staek to ensure fluid balanee. 11 :30 - 00:00 12.50 RUNCO RUNCMP Running in hole to depth 3223' set down. Pieked up and soft taged again. Picked up and bobed through. Pieked up and Printed: 11/28/2005 12:58:38 PM BP EXPLORATION Operations Summary Report Page 3 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 11/15/2005 11/25/2005 Spud Date: 9/24/2004 End: 11/25/2005 Date From - To Hours Task Code NPT Phase Description of Operations 11/21/2005 11 :30 - 00:00 12.50 RUNCO RUNCMP never saw problem again? Continue RIH carefully! 11/22/2005 00:00 - 01 :30 1.50 RUNCO DPRB RUNCMP Running 4-1/2" 12.6# L-80 Completion, watching hole and wieght. At 4440' in, stacked out again and could not proceed. Deeide to POOH and string is pulling w/2-5K overpull. 01 :30 - 06:00 4.50 RUNCO DPRB RUNCMP Confer with Eng. Mr Reem and will pull eompletion. Well giving up bubbles of gas with oil. RlU cireulating line and circulate 182 bbls @ 2 BPM 1100 psi 9.1 brine around to condition and elean hole. Monitor Well not stable; gas bubbles on the surface of fluid in the BOP Stack. Cireulate 182 bbls @ 3 BPM 1100 psi , 9.1 brine. After pumping, the fluid level dropped. Took 17 bbls i i to fill. Cirulate 182 bbls @ 3 BPH 1100 psi 9.1 brine. Had I losses of 21 Bbls. Monitor well. 06:00 - 14:30 8.50 I RUNCO IDPRB RUNCMP POH slowly to prevent swabbing, continue out wI 50K pull. Get stuek @ 3543'. Discuss with town and Baker; decide to increase overpull, but to NOT cireulate to avoid setting the packer. Pull free w/15K and continue POOH. Packer sticks several times until 75 Joints remaining in hole, then pulls free, but will pull very slowly to avoid the stieking problem. Eaeh time the Packer "stieks", we stop pulling and relax the string for 5-10 minutes. Each time we resume POOH string eomes free with 10-15K, then continues on out with 2-5K overpull. Welcome back, Lee! 14:30 - 15:30 DPRB RUNCMP Well flowed 1-2 Bbls of viseous oil out the tubing while slowly P/U jt #60. Lowered the tubing and stabbed TIW valve. Filled the backside with 14 Bbls 9.0 ppg fluid. SII Hydril, and tubing: 90 psi Tubing, 0 psi Casing. Clean Rig floor. 15:30 - 18:00 DPRB RUNCMP Reverse Circulate 2.7 BPM wI 90 psi Csg, 50 Tbg for 120 Bbls, taking returns to Tiget tank. SII w/30 psi Csg, 90 psi Tbg. Open Casing and Tubing and pressures bleed quiekly to 0 psi. Fluid level dropping in Casing and no blow after the TIW removed. Look down Tubing and see fluid slowly rising in Tubing. Decide to re-stab TIW valve and circulate Long Way for 120 Bbls. 18:00 - 19:00 1.00 RUNCO DPRB RUNCMP Circulate 120 Bbls @ 2.5 BPM wI 50 psi returns to pits. Monitor well, find it stable. 19:00 - 22:30 3.50 RUNCO DPRB RUNCMP POOH 4-1/2" Completion slowly, double displaeement monitoring well. Recovered all assemblies. Baker Premier Packer has gouging on upper and lower body, with upper slip holding-pins sheared. Element Expander ring dinged up also. Mule Shoe with tail pipe was in good eondition. 22:30 - 00:00 1.50 RUNCO DPRB RUNCMP RID 4-1/2" handling equipment. RlU 3-1/2" handling equipment. 11123/2005 00:00 - 00:30 0.50 CLEAN N DPRB CLEAN Clear and Clean Rig Floor 00:30 - 02:00 1.50 CLEAN N DPRB CLEAN Pick up Make up BHA #3 2-7/8" Mule Shoe Pup, 2-7/8' Pups, XO, Scraper, XO Sub, Bumper Sub, Jar, 9 x Drill Collars. 02:00 - 08:00 6.00 CLEAN N DPRB CLEAN RIH BHA #3 on 3-1/2' DP. Stop at -4,170-ft. Reverse Circulate 4-Drill Pipe volumes (28 Bbls, each) at 4 bpm/100 psi. Very small amount of Formation Sand recovered. 08:00 - 09:30 1.50 CLEAN N DPRB CLEAN Reverse Circulate full wellbore volume. Monitor Well and fluid is falling very slowly so deeide to continue on into the hole. 09:30 - 12:00 2.50 CLEAN N DPRB CLEAN RIH slowly to 6,007' (full jt #179) without incident. Fluid level dropped -10'. P/U #180 and slowly lower into top of Tieback Sleeve @ 6,027' (4ES RKB), see slight bobble, continue in for Printed: 11128/2005 12:58:38 PM BP EXPLORATION Operations Summary Report DPRB CLEAN full it #180,6,039'. P/U Jt 181 and eontinue in until tagging @ 6,053'. Let the tag take 5K, then P/U 5' and install Floor Valve and Circulating Line to prepare to Reverse Cireulate HiVis Sweep. Mix 20-Bbl Hi-Vis Sweep and Reverse Cireulate 4-BPM @ 560-psi throughout Wellbore. Very small amount of Formation Sand reeovered. Circulate 9.0 ppg throughout Wellbore to condition Well. Monitor Well. Fill pits with 9.0 ppg brine and wt. up to 9.2 ppg. Circulate 4 BPM /500 psi 9.2 ppg Brine. Cireulate and spot 40 bbl Hi- Vis Kill Pill at 6050' Monitor Well. Fluid dropping at slow rate 14 bbl hour. TOH with BHA #3 on 3-1/2' DP, double displaee. TOH with BHA #3 on 3-1/2' OP Lay down BHA. RID 3-1/2' equip. RIU 4-1/2' Torque Turn equip. Clear and Clean Rig Floor. Pre-Job Safety Meeting for running Completion held with all personnel. P/U M/U Completion Equipment Baker-Lok connections below Baker Premier Pkr. RIH, monitoring fluid level. P/U Jt #151 and RIH 17' for tag @ 6,042'. P/U 15' and rotate 1/2-turn and RIH to tag @ 6,042'. Mark Jt #151, POH and UO for Spaee-out measurement. POH and UO top TCII jt, XO pup, and top TDC it. Caleulate Spaee-out. Will need 4-pup joints and the Tell it to land the bottom of the Mule Shoe @ 6,038', whieh is 9' inside the top of the Tiebaek Sleeve found @ 6,027'. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From- To Hours Task Code NPT Phase 11/23/2005 09:30-12:00 2.50 CLEAN N 12:00 - 14:30 2.50 CLEAN N DPRB CLEAN 14:30 - 15:30 1.00 CLEAN N DPRB CLEAN 15:30 - 18:00 2.50 CLEAN N DPRB CLEAN 18:00 - 21 :00 3.00 CLEAN N DPRB CLEAN 121:00 - 00:00 300 CLEAN ~ DPRB CLEAN 11/24/2005 00:00 - 02:00 2.00 CLEAN N OPRB CLEAN 02:00 - 03:00 1.00 CLEAN P CLEAN 03:00 - 03:30 0.50 RUNCO I RUNCMP 03:30 - 14:30 11.00 RUNCO~ I RUNCMP 14:30 - 17:00 2.50 RUNCO~ RUNCMP 17:00 - 20:00 Page 4 of 4 Start: Rig Release: Rig Number: Spud Date: 9/24/2004 End: 11/25/2005 11/15/2005 11/25/2005 Description of Operations RUNCMP Reverse Cireulate 3-BPM @ 140 psi, 100 Bbls of 9.2 brine followed by 200 Bbls mixed with one drum of Corexit EC-1124 Corrosion Inhibitor. RUNCMP Land Tbg Hanger SIO WI. 42K P/U Wt. 62K. RILOS Teast Packoff to 5000 psi RUNCMP Drop Rod and Ball. Wait. Pressure up on Tbg to 4000 psi hold for 30 min. Charted Bleed to 2000 psi. Pressure up on annulus to 3500 psi hold for 30 min. Charted. Bleed Tbg. Shear DCK valve. Pump both ways from AnnulTbg. Tbg/Annu. Set and test TWC 1000 psi Call out Hot Oil. NID BOPE and remove valves. N/U Adaptor FlangeTree and test to 5000 psi Pick Lubricator and pull TWC UD same WO Hot Oil to arrive on Location. Problems at Fuel Dock loading out required amount of Diesel needed for the job. Hot Oil arrived on Location. PJSM. PT Lines to 3,500 psi. Freeze Protect Well with 110 bbls of Diesel. Set and test BPV. Seeure Well and Cellar. Prep to Rig down. Released Rig at 10:00 hrs. 20:00 - 21 :00 21 :00 - 23:30 23:30 - 00:00 0.50 RUNCO RUNCMP 11/25/2005 00:00 - 02:00 2.00 BOPSU P RUNCMP 02:00 - 04:00 2.00 WHSUR P RUNCMP 04:00 - 04:30 0.50 WHSUR P RUNCMP 04:30 - 07:00 2.50 WHSUR N WAIT RUNCMP 07:00 - 09:00 2.00 WHSUR P RUNCMP 09:00 - 10:00 1.00 WHSUR P RUNCMP Printed: 11/28/2005 12:58:38 PM ..... ____ STATE OF ALASKA ALAS~ AND GAS CONSERVATION C.,SSION REPORT OF SUNDRY WELL OPERATIONSRECEIVED MAR 1 7 2005 1. Operations Performed: Change Out ESP__ D Abandon 181 Repair Well D Plug Perforations D Stimulate Alaska iílc&t&as Cons. Com ~í D Alter Casing 181 Pull Tubing o Perforate New Pool D Waiver D Ti~D~n D Change Approved Program D Operation Shutdown D Perforate D Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development D Exploratory 204-176 3. Address: D Stratigraphic D Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23224-61-00 7. KB Elevation (ft): KBE = 69.60' 9. Well Name and Number: MPH-18l2 8. Property Designation: 10. Field I Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 8630 feet true vertical 3986 feet Plugs (measured) N/A Effective depth: measured 8630' feet Junk (measured) N/A true vertical 3986 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 4527' 10-3/4" 4562' 3199' 5210 2480 Intermediate Production 6039' 7-5/8" 6072' 3900' 6890 4790 Liner 2565' 4-1/2" 6031' - 8596' 3880' - 3990' 8430 7500 LEM Isolation Sleeve 19' 4-1/2" 6067' - 6086' 3898' - 3907' 'Lateral Entry Module (LEM) Perforation Depth MD (ft): Excluder Screens 6458' - 8550' Perforation Depth TVD (ft): Excluder Screens 3968' - 3995' 2-7/8",6.5# L-80 5923' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS BFL MAR 1 8 2DnS 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubinn Pressure Prior to well operation: 0 0 784 4000 350 Subsequent to operation: 457 29 441 350 324 14. Attachments: D Copies of Logs and Surveys run 15. Well Class after proposed work: 181 Daily Report of Well Operations D Exploratory 181 Development D Service 181 Well Schematic Diagram 16. Well Status after proposed work: 181 Oil DGas DWAG DGINJ DWINJ D WDSPL 17. I hereby certify that the foregoing IS tnue and correct to the best of my knowledge. I Sundry Number or NIA if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sandra Stewman Title Technical Assistant S~-'-v-f71 ..-:: t Prepared By Name/Number: ...,...."--..,, ,","" Phone 564-5803 DatJ) 3 ~ [-OS Sondra Stewman, 564-4750 d~ JI ;-..¿ Form 10-404 Revised 04/2004 ! ¡ Submit Original Only ssion .IrwL 2-9/16" - 5M FMC Wellhead' 11" x 11" 5M F~ Gen 5, W 2-7/8" FMC Tbg.W8" EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/ft, H-40 [@ 103/4" L-80 45.5 #/ft Howeo Float Shoe I 4562' I KOP @ 600' 50+ degree from 2,378' Max hole angle = 64 degrees @ 3915' MD 75/8" 29.7 ppf, L-80, BTC-M easing (Drift ID = 6.750", eap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf ) Window for NB 6072' 10 6084' 4-1/2'" Hook Hanger inside casing 6,06T outside hook point 6,084' lEM IsoIat)Qn Sleeve sel across NB Sands ISO Sleeve 606T - 6086' Min ID through Sleéve is 2.62". 4 112" GS Fi$h Neck lEM#2liner Baker tie back sleeve Baker ZXP Pkr 4.5" seal assy. 6,031' 6,042' 6,215' Window for OA 6,555' to 6,56T 4-1/2'" Hook Hanger inside casing 6,549' outside hook point 6,566' lEM #1Uner Baker tie back slv. Baker ZXP lop pkr. Baker 190-47 seal bore 4.5" seal assy. 6,188' 6,199' 6,20T 6,721' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC Uner hanger Baker 190-47 seal bore ex!. 6,680' 6,691' 6,702' 6,709' 7-5/8" Weatherford Float Collar 6826' 7-5/8" Weatherford Float Shoe 6910' DATE 10/15/04 12/9104 2120105 REV. BY MOO Lee Hulme Lee Hulme COMMENTS Drilled & Completed Doyon 14 ESP Changeout Nabors 4ES ESP C/O & Isolate NB Sands Nabors 4ES M PH -1 a L \ \ L .~:~: g~ :::~: ~ ~;:~g: ~~~~~ ~1~ NB Lateral OA Lateral Cameo 2-7/8" x 1" KBMM Gas lift mandrel I 138' I Cameo 2-7/8" x 1" KBMM Gas lift mandrel I 212S' I Cameo 2-7/8" x 1" KBMM Gas lift mandrel I 5661' I HES 2-7/8" XN-Nipple (2.250" id) I 5813' I 15866' I 15,883'1 Centrilift Pump 151 stg.1 GC1700 GPMTAR 1:1 Centrilift Gas Separator Model - GRSFTXARH6 Centrilift Tandem Seal seetion 513 GSB3 DB UT/l T ABlHSN FSA Cl5 IS,888' 15,902'1 Centrilift Motor 125 HP I KMH-A (ReratOO Motor) 2390 volt I 44 amps. PumpMate w/6 fin centralizer 1 5,917' I PumpMate TVD = 3824' 6 3/4" Hole td @ 'Btm Baker Dbl Float Shoe 8.598' 7 jts. 4.5 L-80 IBT -M , Swell Packer @ 6,113' 28 jts. - 4 1/2" C27 Baker moo. Exeluder 34 jts, 9.5# L-80 IBT 63/4- Hole td @ 9,910' Blm Baker Floal Shoe 8.565' 46 jts. - 4 1/2" Slotted Liner 1 jts, 12,6# L-80 IBT 6 3/4" Hole td @ 8,639' Blm HES Type V Float Shoe 8,639' 40 jts. - 4 1/2" Slotted Liner 4 jts, 12.6# L-80 IBT MILNE POINT U~IT Wf;~b-H-18 API NO: 50-029-23224-00 50-029-23224-60 50-029-23224-61 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BP EXPLORATION Operation~ S"ummary Report MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Date From - To Hours Task Code NPT 2/16/2005 12:00 - 18:00 6.00 RIGD P 18:00 - 19:00 19:00 - 00:00 2/17/2005 00:00 - 00:30 00:30 - 01 :30 01 :30 - 05:00 Phase PRE Rig down from MPH-16 Well. PJSM and move rig to MPH-18. Rig aceepted for well work at 18:00 hours. DECOMP PJSM. Take on heated seawater. Rig up hardline to tiger tank. Install secondary valve on I/A. DECOMP Pull BPV, OA = 0 psi. SITP=310 psi. SICP=350 psi. Pressure test lines to 3.500 psi. good test. Bleed Gas off IA and tubing. Cireulate 36 bbls down tubing. Bullhead 118 bbls down tubing. Circulate down tubing up IA at 3.5 bpm. 510 psi. Take crude oil returns to tiger tank. DECOMP Continue to circulate down tubing up IA at 3.5 bpm, 480 psi. Take crude oil retums to tiger tank. Pumped a total of 526 bbls. 118 bbls during bullhead and 408 to the hole. Got 225 bbls erude back to tiger tank. Lost 183 bbls to formation. DECOMP Returns elean. Shut in and monitor well pressures. SITP=50 psi. SICP=50 psi. Open well and bleed pressure off to tiger tank (37 bbls). DECOMP Shut in well and monitor. SITP=10 psi. SICP=O psi. Well flowing back. Continue to flow well and monitor while waiting for additional sea water. Flowed baek addtional 34 bbls. Got traces of crude back. Circulate well with 8.5 ppg sea water. Well cleaned up after first 10 bbls pumped. Finish eireulating Well at 3.5 bpm/360 psi. Retum losses were 1 bpm. Shut down Pump. Monitor Well. Flowed back 13.7 bbls in 35 minutes. Shut in Well. Monitored no recordable pressure after 45 minutes. Open Well. A slight flow continues. Shut in Well. Order 8.75 ppg Brine. DECOMP Wait on Brine. Clean Rig Floor. Maintain Rig. DECOMP Take on 8.75+ ppg brine. Pump same down tubing taking returns to tiger tank. 8.75+ ppg brine to surfaee after 470 bbls pumped. Shut down pump. Monitor well. Well dead. DECOMP Set TWC and test to 1,500 psi. Good test. DECOMP ND tree. Inspeet hanger and LDS. DECOMP NU BOPE. DECOMP PJSM. Conduet full BOPE test. 250 psi low pressure, 3,500 psi high pressure, 5 minutes charted on each test. Witnessing of test waived by AOGCC rep John Crisp. Testing of BOP components witnessed by Company Man. DECOMP Continue to eond,,!ct full BOPE test, 250 psi low pressure, 3,500 psi high pressure,S minutes eharted on each test. Witnessing of test waived by AOGCC Rep., John Crisp. Testing of BOP components witnessed by Company Man. RU lubricator, pull TWC, RD lubricator. RU to pull completion equipment. Pull hanger to floor (40K Up Wt.). LD same. Pull tubing and ESP cable. Circ to elean pipe. Thick crude with gas at surface. Cireulate to tiger tank. Order additional Brine. Continue to circulate and conditon Well with 8.75 Brine until out of fluid in Pits. Returns mostly clean. Wait on additional Brine. Service and maintain Rig. Fluid level slowly dropping in AnnuluS...however it is just below surface. 1.00 KILL P 5.00 KILL P 0.50 KILL P 1.00 KILL P 3.50 KILL P 05:00 - 06:00 1.00 KILL P DECOMP 06:00 - 07:00 1.00 KILL P DECOMP 07:00 - 08:30 1.50 KILL P DECOMP 08:30 - 13:30 13:30 - 17:00 17:00 - 18:00 18:00 - 19:00 19:00 - 21 :00 21:00 - 00:00 2/18/2005 00:00 - 02:30 5.00 KILL P 3.50 KILL P 1.00 DHB P 1.00 WHSUR P 2.00 BOPSU P 3.00 BOPSU P 2.50 BOPSU P 02:30 - 03:30 1.00 PULL P DECOMP 03:30 - 04:30 1.00 PULL P DECOMP 04:30 - 06:00 1.50 PULL P DECOMP 06:00 - 08:30 2.50 PULL P DECOMP 08:30 - 10:00 1.50 PULL P DECOMP Start: 2/16/2005 Rig Release: 2/19/2005 Rig Number: Spud Date: 9/24/2004 End: 2/19/2005 Printed: 212312005 11 :55:54 AM Page 2 of 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 2/16/2005 Rig Release: 2/19/2005 Rig Number: Spud Date: 9/24/2004 End: 2/19/2005 Description of Operations 2/1S/2005 10:00 - 11 :00 1.00 PULL P DECOMP Off-load 9.0 ppg Brine in Pits. Cireulated 50 bbls down Tubing. Returns mostly clean. Fluid level dropping below surface. 11 :00 - 16:00 5.00 PULL P DECOMP Continue POOH with 2 7/8' Tubing and ESP Completion. 183 jts tbg pulled. 16:00 - 17:30 1.50 PULL P DECOMP Inspect and LD ESP assembly. 17:30 - 1S:00 0.50 PULL P DECOMP Clear and clean rig floor. 18:00 - 1S:30 0.50 PULL P DECOMP PJSM with Co Reps, TP, and all erew. 1S:30 - 19:00 0.50 PULL P DECOMP PU isolation sleeve, XO's and 3 jts 2-7/8' PAC pipe. 19:00 - 23:00 4.00 PULL P DECOMP RIH with isolation sleeve assembly on 2-7/S'tubing. Tagged latch profile and latehed isolation sleeve. Verified latch. Release running tool. Top of isolation sleeve at 6,067'. Bottom of isolation sleeve at 6,086'. 23:00 - 00:00 1.00 PULL P DECOMP Circulate bottoms up at 3 bpm, 1,200 psi. 2/19/2005 00:00 - 00:30 0.50 PULL P DECOMP CBU prior to POH with isolation sleeve setting tool. Cease circulation, monitor well. OK. 00:30 - 03:00 2.50 PULL P DECOMP POOH with setting tool. Stand baek 2-7/S' tubing in derrick. LD setting tool and 3 joints 2-718· PAC pipe. 03:00 - 03:30 0.50 PULL P DECOMP Clear and clean rig floor 03:30 - 04:30 1.00 RUNCO RUNCMP RU to PUlRun ESP completion assembly. 04:30 - 06:00 1.50 RUNCO RUNCMP PU and serviee new pump 06:00 - 08:00 2.00 RUNCO RUNCMP Continue to piek-up and service new ESP Assembly. Pull ESP Cable over Sheave. OS:OO - 11 :30 RUNCMP TIH with ESP Assembly, XN-Nipple, 3 ea GLM, and 183 Jts 2 7/8' 6.5 Iblft, L-SO, EUE Srd Tubing. Protecolizers 5.1 lat guards 3, LaSalle Clamps 100. 11 :30 - 12:00 RUNCMP Piek-up Landing Joint. Make-up Tubing Hanger. Install Penetrater. Test. 12:00 - 13:30 1.50 RUNCO RUNCMP Spliee upper ESP Cable Connector. Test. 13:30 - 14:00 0.50 RUNCO RUNCMP Land Tubing Hanger. RILDS. 14:00 - 16:30 2.50 BOPSU P POST ND BOP's. Test spool, DSA and 2nd fA valve. 16:30 - 17:30 1.00 WHSUR P POST NU adapter flange and tree. 17:30 - 1S:00 0.50 WHSUR P POST Test adapter flange and tree to 5,000 psi. 1S:00 - 19:00 1.00 WHSUR P POST Pull TWC, set BPV, secure tree. RIG RELEASED FROM WELLWORK AT 19:00 HRS Printed: 2/2312005 11 :55:54 AM - ! '- - STATE OF ALASKA A ALAS~IL AND GAS CONSERVATION CO~SION REC·\E·'· . ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG·· . IVEL) Revision: 12~,jtit~ction 1a. Well Status: !HI Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. ø:& Gas Co~s ~ . 20AAC 25.105 20AAC 25.110 !HI Developmen~,ªEx.e ora Brom'SS1þfi DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic ~e 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10-13-2004 204-176 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10-8-2004 50- 029-23224-61-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10-9-2004 MPH-18L2 3026' NSL, 3986' WEL, SEC. 34, T13N, R10E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 664' NSL, 1667' WEL, SEC. 28, T13N, R10E, UM (NB) KBE = 69.60' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 2127' NSL, 2784' WEL, SEC, 28, T13N, R10E, UM (NB) 8630' + 3986 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 556658 y- 6010178 Zone- ASP4 8630 + 3986 Ft ADL 025906 TPI: x- 553669 y- 6013073 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 552538 y- 6014528 Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey DYes !HI No N/A MSL 1800' (Approx.) 21. Logs Run: MWD , DIR , GR , RES, IFRlCASANDRA , lAB, GYRO 22. CASING, LINER AND t;EMENTING RECORD CA$ING 5ET11NG EPTH"'1P SETtiNG! EPTH lVD HOCE " ...~ SIZE WT. PER FT. GRADE Top tsOTTOM lOP ! t:SOTTOM SIZE 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-3/4" 45.5# L-80 35' 4562' 35' 3199' 13-1/2" 653 sx Arctic Set Lite, 257 sx 'G' 7-518" 29.7# L-80 33' 6072' 33' 3900' 9-7/8" 604 sx Class 'G' 4" x5" 9.5# x 12.6# L-80 6031' 8596' 3880' 3990' 6-3/4" Excluder Screens and Blanks 23. Perforations open to Production (MD + TVD of To,e and 24. ,. J$ING Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4" x 5" Excluder Screens 2-7/8", 12.6#, L-80 5936' N/A MD TVD MD TVD 25. ACto, . 1%1;9·· ........ . 6458' - 8550' 3968' - 3995' vl:.MI::NI .. ..... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude and 3 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 22, 2004 Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF W A TER-Bsl CHOKE SIZE I GAS-Oil RATIO 11/27/2004 6 TEST PERIOD ~ 159 11 107 50 Flow Tubing Casing Pressure CALCULATED ~ Oll-Bsl GAs-McF W A TER-BSl Oil GRAVITY-API (CORR) Press. 325 24-HoUR RATE 836 42 429 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None RBDMS 8Fl ,IAN 0 7 2005 .ø ir ;,) Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER 29. ORMATION TESTS NAME MD TVD Inelude and briefly summarize test results. List intervals tested, and attaeh detailed supporting data as necessary. If no tests were conducted, state "None". TUZC MA MB1 MB2 MB2-3 MB2-2 MB2-1 MC SBF2-NA SBF21 SBF1-NB 5152' 5621' 5639' 5765' 5887' 5896' 6043' 6072' 6150' 6181 6399' 3468' 3684' 3692' 3751' 3809' 3813' 3886' 3900' 3933' 3942' 3964' None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date MPH-18L2 Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Skip Coyner, 564-4395 204-176 Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Serviee Wells: Gas Injeetion, Water Injeetion, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injeetion, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Produeing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as referenee for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thiekness. ITEM 22: Attaehed supplemental records for this well should show the details of any multiple stage cementing and the location of the eementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produeed, showing the data pertinent to sueh interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulie Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only þ ." ALASKA. AND ~Ä~T~g~~L:;~ON CO.,SS,ON RECEIVED REPORT OF SUNDRY WELL OPERATIONS DEC 2 1 2004 Alaska Oil &. as .ons. -0 1. Operations Performed: Change CJlhiifiRr~ne o Abandon IHI Repair Well o Plug Perforations o Stimulate IHI Other o Alter Casing IHI Pull Tubing o Perforate New Pool o Waiver o Time Extension o Change Approved Program o Operation Shutdown o Perforate o Re-Enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. IHI Development o Exploratory 204-176 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23224-61-00 7. KB Elevation (ft): KBE = 69.60' 9. Well Name and Number: MPH-18L2 8. Property Designation: 10. Field I Pool(s): ADL 025906 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 8630 feet true vertical 3986 feet Plugs (measured) N/A Effective depth: measured 8630' feet Junk (measured) N/A true vertical 3986 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 4527' 10-3/4" 4562' 3199' 5210 2480 Intermediate Production 6039' 7-5/8" 6072' 3900' 6890 4790 Liner 2565' 4-1/2" 6031' - 8596' 3880' - 3990' 8430 7500 Perforation Depth MD (ft): Excluder Screens 6458' - 8550' Perforation Depth TVD (ft): Excluder Screens 3968' - 3995' 2-7/8",6.5# L-80 5920' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft .t 2 1004 Treatment description including volumes used and final pressure: 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casina Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: IHI Daily Report of Well Operations o Exploratory IHI Development o Service 181 Well Schematic Diagram 16. Well Status after proposed work: IHI Oil o Gas o WAG DGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing IS true and correct to the best of my knowledge. I Sundry Number or NIA if C.O. Exempt: Contact Skip Coyner, 564-4395 Printed Name Sandra Stewman Title Technical Assistant r ~ ~ Phone .564~.580~, 1 Z ~ /"7 Lj Prepared By Name/Number: 'Signature ~~ It!.- .r-.... '-.J-......~ ¡ Date .. 1:5 Sondra Stewman, 564-4750 Form 10-404 Revised 04/2004 ¡ t..·· \.' f-\ ¡ Submit Original Only G C C mmissior¡ I. " Tree: 2-9/16" - 5M FMC Wellhead: 11" xii" 5M FM. Gen 5, W 2-7/8" FMC Tbg. ' EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#íft, H-40 CJJ:Ð 10 3/4"L-80 45.5 #/ft Howco Float Shoe 14562' I KOP @ 600' 50+ degree from 2,378' Max hole angle = 64 degrees @ 3915' MD 75/8" 29.7 ppf, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpf) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. (drift id = 2.347" cap = .00592 bpf) Window for NB 6072' to 6084' 4-1/2" Hook Hanger inside casing 6,061' outside hook point 6,084' LEM #2 liner Baker tie back sleeve Baker ZXP Pkr 4S seal assy. 6,031' 6,042' 6,215' Window for OA 6.555' to 6,561' 4-1/2'· Hook Hanger inside casing 6,549' outside hook point 6,566' LEM #1 liner Baker tie back slv. Baker ZXP top pkr. Baker 190-47 seal bore 4S seal assby. 6,188' 6.199' 6.201' 6,721' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC Liner hanger Baker 190-47seal bore ex!. 6,680' 6,691' 6,702' 6,709' 7-5/8" Weatherford Float Collar 6826' 7-5/8" Weatherford Float Shoe 6910' DATE 10/15/04 12/9/04 MPH-18 NB Lateral OA Lateral '¡¡¡ig. DF elev. = 69.60' (Doyon 14) .;9. GL elev. = 35.60' (Doyon 14) Camco 2-7/8" x 1" KBMM Gas lift mandrel I 139' I Cameo 2-7/8" x 1" KBMM Gas lift mandrel I 2,126' I Cameo 2-7/8" x 1" KBMM Gas lift mandrel 15,662' I HES 2-7/8" XN-Nipple (2.250" id) I 5,814' I 15,866' I I 5,887' I Centrilift Pump 112 stg. I GC2900 GPMTAR 1:1 Centrilift Tandem Gas Separator Model - GRSFTXARH6 Centrilift Tandem Seal section 513 GSB3 DB UT/L T HL H6 PFS AFLAS/HSN 15,888' I 15,902' I Centrilift Motor 190 HP I KMH 2415 volt I 48 amps. PumpMate w/6 fin centralizer PumpMate TVO = 3823' 15,915' 6 3/4" Hole td @ 'Blm Baker Obi Float Shoe 8,598' 7 jts. 4.5 L·80 IBT·M , Swell Packer @ 6,113' 28 jts. - 4 1/2" C27 Baker med, Excluder 34 jts, 9.5# L-80 1ST 63/4" Hole td @ 9,910' Btm Baker Float Shoe 8,565' 46 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 IBT REV. BY COMMENTS MOO Drilled & Lee Hulme ESP Changeout Nabors 4ES 63/4" Hole td @ 8,639' Btm HES Type V Float Shoe 8,639' 40 jts. ,,4 1/2" Slotted Liner 4 jts, 12.6# L-80 1ST M!l..NE POINT UNIT WI;LL H-18 API NO: 50-029-23224-00 50-029-23224-60 50-029-23224-61 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/8/2004 12/1 0/2004 Spud Date: 9/24/2004 End: 12/10/2004 08:00 - 09:30 1.50 KILL P 09:30 - 11 :00 1.50 KILL P I I 11 :00 - 13:00 2.00 WHSUR P 13:00 - 14:30 1.50 BOPSU P 14:30 - 17:30 3.00 BOPSU P 17:30 - 18:00 0.50 WHSUR P 18:00 - 19:00 1.00 PULL P 19:00 - 22:00 3.00 PULL P I 22:00 - 23:30 1.50 PULL P 23:30 . 00:00 0.50 PULL P 12/10/2004 00:00 - 00:30 0.50 PULL P 00:30 - 03:00 03:00 - 07:00 07:00 - 09:30 09:30 - 10:00 0.50 RUNCO 10:00 - 11 :30 1.50 BOPSU P 11 :30 - 13:00 1.50 WHSUR P I RD. Lower & scope down derriek. Move from MPH-13 to MPH-18. PRE 1 Spot rig sub over well. Raise & scope up derrick. RIU pipe I shed & pits. Move & spot eamp. DECOMP I Accepted rig @ 0300 hrs. R/U lines to tiger tank & X-mas tree. DECOMP I M/U lubricator pull SPY. UD lubrieator. DECOMP I Hold Pre-spud & PJSM wI all hands. DECOMP I Open well. SITP 190 psi. SICP 280 psi. Blow down well & i begin kill operation. Pump down tubing @ 4 BPM, 630 psi. I Pumped Tubing volume, then SI & bullheaded 50 bbls into I well bore. SH @ 4 BPM wI 21 0 psi on annulus. Open well & con't kill operation. Order out more fluid..., significant loss rate. DECOMP . Monitor well while waiting on more seawater. DECOMP I PJSM. Line up & bullhead 250 bbls down IIA @ 6112 bpm I 1375 psi. Bullhead 50 bbls down tbg @ 5 bpm 1400 psi. Both I sides on vacuum. DECOMP i PJSM. Set & test two way eheek valve. NID tree. DECOMP I PJSM. N/U BOPE. DECOMP I PJSM, pressure test BOPE as per BP/AOGCC requirements. LP 250 psi. HP 3500 psi. BOP test witnessing waived by John i Crisp wI AOGCC. DECaMP i P/U lubricator & pull TWC. UD lubricator. DECOMP '! M/U landing jt. BOLDS. Pull hanger to floor. P/U wt = 40K. I Disconneet ESP cable & check same. UD hanger & landing jt. DECaMP i POOH wI ESP completion. Reeoverd 183 Jts, 3 GLMs, XN Nipple assy, 3 Flat Guards, 5 Protectolizers & 101 LaSalle Clamps. DECOMP Break down, inspect & UD ESP. Motor is good. Pump was locked up wI a twisted shaft 10" from bottom in gas separator. DECOMP Clear & clean rig floor. Swap out cable reels. R/U to P/U & RIH wI new ESP. DECOMP Finish elear & elean rig floor. Change out reels. RIU to run new completion. P/U & M/U new ESP. Service & Check same. RIH wI ESP on 2 7/8" completion. PJSM. P/U landing joint & hanger. Make up penetraqtor & splice ESP eable, test same, OK. PJSM. Land hanger. RILDS. Set @ way check valve. PJSM. N/D BOPE. PJSM. N/U & test tree @ 5000 psi, OK. Secure well. Rig released @ 13:00 hrs, 12/10/2004. RUNCMP RUNCMP RUNCMP 12/8/2004 21 :00 - 00:00 3.00 MOB P 12/9/2004 00:00 - 03:00 3.00 MOB P 03:00 - 04:00 1.00 RIGU P 04:00 - 04:30 0.50 WHSUR P 04:30 - 05:00 0.50 KILL P 05:00 - 08:00 3.00 KILL P PRE RUNCMP RUNCMP RUNCMP Printed: 12/14/2004 8:22:22 AM . . lðl(-f76 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th A venue, Suite 100 Anchorage, Alaska 99501 November 09,2004 RE: MWD Formation Evaluation Logs MPH-18 L2, AK-MW-33 02792 1 LIS formatted Disc with verification listing. API#: 50-029-23224-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF TIlE TRANSMITIAL LETTER TO TIlE A TIENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: ;/1>1 . STATE OF ALASKA . ALASKA ~L AND GAS CONSERVATION COMMl'!rSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: ·i 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic D Service 2. Operator Name: 5. Date Camp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 10-13-2004 204-176 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 10-8-2004 50- 029-23224-61-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 10-9-2004 MPH-18L2 3026' NSL, 3986' WEL, SEC. 34, T13N, R10E, UM 8. KB Elevation (ft): 15. Field I Pool(s): Top of Productive Horizon: 664' NSL, 1667' WEL, SEC. 28, T13N, R10E, UM (NB) KBE = 69.60' Milne Point Unit I Schrader Bluff Total Depth: 9. Plug Back Depth (MD+ TVD) 2127' NSL, 2784' WEL, SEC, 28, T13N, R10E, UM (NB) 8630' + 3986 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: 8630 + 3986 , Ft ADL 025906 Surface: x- 556658 . y- 6010178 ' Zone- ASP4 TPI: x- 553669 y- 6013073 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 552538' y- 6014528 . Zone- ASP4 N/A MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNa N/A MSL 1800' (Approx.) 21. Logs Run: VWt~~ ~Ò72.' /nþ .Þ MWD , DIR , GR , RES, IFR/CASANDRA , lAB, GYRO 2ficD' -;-1/1,> /1'./.,.. 2. CASING, LINER AND CEMENTING RECORD CÁSING . SET1'INGDEPTH MO SET1'ING DEPTHTVP HOLE .>, I/p',"c..... ..... SIZE WT.PER FT. GRADE Top ·60TTOM ToP BoTTOM SIZE RECORD 20" 92# H-40 34' 112' 34' 112' 42" 260 sx Arctic Set (Approx.) 10-314" 45.5# L-80 35' 4562' 35' 3199' 13-112" 653 sx Arctic Set Lite, 257 sx 'G' 7-5/8" 29.7# L-80 33' 6072' 33' 3900' 9-7/8" 604 sx Class 'G' 4" x5" 9.5# x 12.6# L-80 6031' 8596' 3880' 3990' 6-3/4" Excluder Screens and Blanks 23. Perforations op'en to Production (MD + TVD of Top and 24. TUBING ReCORD > Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 4" x 5" Excluder Screens 2-7/8", 12.6#, L-80 5936' N/A MD TVD MD TVD 25. ACID,:- ..;;.., . 6458' - 8550' 3968' - 3995' . ""'1;"",;;''<'. SQl.JEEZm, DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude and 3 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-BSl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED .. Oll-Bsl GAs-McF WATER-BsL Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". RBDMS BFL rêiii1i¡¡TIO~ NOV 1 2 2004 / nr,'\·:~ f _~Jr¡ t;:'. If None \ ~.!.L3:-'¿__1 C) Fi: ¡ (.~~ 1\\: Þ\ I ~~.:..:~~~~:-! (,Ý" "f Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attaeh detailed supporting data as neeessary. If no tests were conducted, state "None". TUZC MA MB1 MB2 MB2-3 MB2-2 MB2-1 MC SBF2-NA SBF21 SBF1-NB 5152' 5621' 5639' 5765' 5887' 5896' 6043' 6072' 6150' 6181 6399' 3468' 3684' 3692' 3751' 3809' 3813' 3886' 3900' 3933' 3942' 3964' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Well Service Report and a Leak-Off Test Summary. 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. Signed itle Technical Assistant Date -ll-oS-o Permit No. / A roval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Skip Coyner, 564-4395 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injeetion, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well produeing from more than one pool with production from eaeh pool completely segregated. Eaeh segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage eementing and the location of the cementing tool. ITEM 23: If this well is completed for separate produetion from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to sueh interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulie Pump, Submersible, Water Injeetion, Gas Injeetion, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ~ 2-9/16" - 5M FMC Wellhead' 11"x 11" 5M FMA Gen 5, W 2-7/8" FMC Tbg. 2"" EU 8rd on t&b, 2.5" CIW-H BPV Profile 20", 92#/ft, H-40 D:iÐ 10 3/4"L-80 45.5 #/ft Howco Float Shoe I 4562' I KOP @ 600' 50+ degree from 2,378' Max hole angle = 64 degrees @ 3915' MD 75/8" 29.7 ppl, L-80, BTC-M casing (Drift ID = 6.750", cap = 0.0459 bpi) 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf) Window for NB 6072' to 6084' 4-112" Hook Hanger inside casing 6,067' outside hook point 6,084' LEM #2 liner Baker tie back slv. Baker zxp top pkr. 4.5" seal assby. 6,031' 6,042' 6,215' Window for OA 6,555' to 6,567' 4-112" Hook Hanger inside casing 6,549' outside hook point 6,566' LEM #1 liner Baker tie back slv. Baker ZXP top pkr. Baker 190-47 seal bore 4.5" seal assby. 6,188' 6,199' 6,207' 6,721' Baker Tie Back Sleeve Baker ZXP Packer Baker HMC liner hanger Baker 190-47seal bore ex!. 6,680' 6,691' 6,702' 6,709' 7 -5/8" Weatherford Float Collar 6826' 7-5/8" Weatherford Float Shoe 6910' DATE REV. BY MPH-18 NB Lateral OA Lateral _rig. DF elev. = 69.60' (Doyon 14) rig. GL elev. = 35.60' (Doyon 14) " Camco 2-7/8" x1" KBMG Gas lift mandrel 1 149' I Camco 2-7/8" x1" KBMG Gas lift mandrel 1 2,136'1 Camco 2-7/8" x1" KBMG Gas lift mandrel I 5,672'1 HES 2-7/8" XN-Nipple (2.250" id) I 5,824'1 I 5,877' 1 Centrilift Pump 122 stg.1 GC2200 GPMTAR 1:1 Centrilift Intake 400 internals Model - GRSTXARH6 I 5,897' I Centrilift Tandem Seal section 513 GSB3DBUTILH6PFSA GSB3DBL TH6FSA I 5,902'1 I 5,916'1 Centrilift Motor 152 hp I KMH 2325 volt I 40 amps. PumpMate w/6 fin centralizer \5,934'1 6 3/4" Hole td @ 'Btm Baker Obi Float Shoe 8,598' 7 jts. 4.5 L-80 IBT-M ,Swell Packer@ 6,113' 28 jts. - 41/2" C27 Baker med. Excluder 34 jts, 9.5# L-80 IBT 63/4" Hole td @ 9,910' Btm Baker Float Shoe 8,565' 46 jts. - 4 1/2" Slotted Liner 1 jts, 12.6# L-80 IBT COMMENTS 6 3/4" Hole td @ 8,639' Btm HES Type V Float Shoe 8,639' 40 jts. - 4 1/2" Slotted Liner 4 jts, 12.6# L-80 IBT ,MILNE POINT UNIT WELL H-18 API NO: 50-029-23224-00 50-029-23224-60 50-029-23224-61 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 9/23/2004 Rig Release: 10/13/2004 Rig Number: Spud Date: 9/24/2004 End: 9/23/2004 07:00 - 08:00 1.00 MOB P PRE Skid rig floor 08:00 - 10:00 2.00 MOB P PRE Move rig off well, spot on pad 10:00 - 11 :30 1.50 MOB P PRE Shuffle mating boards around corner due to poor pad conditions 11 :30 - 12:00 0.50 MOB P PRE Move rig around eorner and spot rig for booster installation 12:00 - 15:30 3.50 MOB P PRE Install front and real booster wheels and mobilize rig mats from I pad 15:30 - 18:00 2.50 MOB P PRE Move rig to H-pad 18:00 - 20:00 2.00 MOB P PRE Remove booster weels,install stairs and eellar doors 20:00 - 21 :30 1.50 MOB P PRE Spot rig over MPH-18, (RIG ACCEPT AT 21:00 HRS DUE TO POOR PAD CONDITIONS AND DOUBLE MATTING.) 21 :30 - 23:00 1.50 MOB P PRE Rig up floor, spot tiger tank, roek washer 23:00 - 00:00 1.00 RIGU P PRE Nipple up diverter 9/24/2004 00:00 - 03:00 3.00 RIGU P PRE Nipple up Diverter and diverter line, taking on spud mud 03:00 - 12:00 9.00 DRILL P SURF Picking up drill pipe and standing in derrick, total 88 stands, 6 stands HWDP 12:00 - 14:30 2.50 DRILL P SURF Pieking up BHA #1 14:30 - 15:30 1.00 DRILL P SURF Rig up Sperry sun Gyro, Pre spud meeting, Preform Diverter test, the right to witness test was wavier by John Spaulding AOOGC, fill hole eheck for leaks 15:30 - 16:30 1.00 DRILL P SURF Drilling 112 to 256' 16:30 - 17:30 1.00 DRILL P SURF Poh and piek up 3 flex dc, run gyro 17:30 - 00:00 6.50 DRILL P SURF Drilling 258' to 760' with 80 rpms, 420 gpm, 1250 psi, running gyros ever 100 ft to 600 ft. AST 1.6, ART 3.12 9/25/2004 00:00 - 12:30 12.50 DRILL P SURF Drilling 760' to 1861' with 80 rpms, 500 gpm, 1500 psi 12:30 - 13:00 0.50 DRILL N SURF Change out shaker screens, lost Shaker motor 13:00 - 15:00 2.00 DRILL N SURF Change out shaker motor, worked out dog leg 15:00 - 21 :00 6.00 DRILL P SURF Drilling 1861' to 2627' with 80 rpms, 544 gpm, 2750 psi 21 :00 - 22:00 1.00 DRILL P SURF Circ, two bottoms up with 544 gpm, 2750 psi, 80 rpms 22:00 - 23:00 1.00 DRILL P SURF Pump out to HWDP with full drilling rate 23:00 - 23:30 0.50 DRILL P SURF RI H wash 90 ft to bottom 23:30 - 00:00 0.50 DRILL P SURF Drilling 2627' to 2725' with 80 rpms, 544 gpm, 2750 psi, AST 10.58, ART 8.45 9/26/2004 00:00 - 13:30 13.50 DRILL P SURF Drilling 2725' to 4573' with 80 rpms, 544 gpm, 3440 psi 13:30 - 15:30 2.00 DRILL P SURF Circ, Two bottoms up with 80 rpms, 544 gpm 3400 psi 15:30 - 17:00 1.50 DRILL P SURF Pump out to 1564' with full drilling rate 17:00 - 17:30 0.50 DRILL P SURF Cire bottoms up, no clay balls 17:30 - 19:00 1.50 DRILL P SURF Rih, washed 90 f1. to bottom, bridges @ 1559 and 1608' 19:00 - 21 :00 2.00 DRILL P SURF Circ, 2.5 bottoms up with 80 rpms, 544 gpm, 3400 psi 21 :00 - 23:30 2.50 DRILL P SURF Pumping out to HWDP, with full drilling rate 23:30 - 00:00 0.50 DRILL P SURF Stand back HWDP, laying down BHA 9/27/2004 00:00 - 01 :00 1.00 CASE P SURF Laying down BHA 01 :00 - 03:00 2.00 CASE P SURF PJSM, clear floor, Rig up to run 10 3/4 CSG 03:00 - 08:00 5.00 CASE P SURF Picking up 103/4, L-80, 45.5#, BTC, csg, Total 109 jts, shoe 4561', float 4477' 08:00 - 08:30 0.50 CASE P SURF Rig down franks tool, rig up cement head 08:30 - 10:30 2.00 CASE P SURF Cire and thin mud for cement job, 420 gpm, 460 psi 10:30 - 15:00 4.50 REMCM P SURF PJSM, Cement with Schlumberger, with 5 bbls water, test lines to 3,500 psi, 20 bbls water, 20 bbls CW 100,75 bbls 10.6 mud push, drop bottom plug, 620 sxs. ASL 497 bbls, mixed @ 10.7, yeild 4.45, tail 257 sxs. Class G 53.7 bbls, mixed @ 15.8 yeild 1.17, drop top plug, kicked out with 30 bbls water, displace with rig pumps 401 bbls of 9.6 mud displaee @ 7 bbls min., bump Printed: 10/18/2004 9:57:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 9/23/2004 Rig Release: 10/13/2004 Rig Number: Spud Date: 9/24/2004 End: 9/27/2004 10:30 - 15:00 4.50 REMCM P SURF plug with 1800 psi, float held, full return thru out job, 298 bbls of bad cement to surface. 15:00 - 15:30 0.50 CASE P SURF Rig down eement head, flush out diverter and flow lines 15:30 - 16:30 1.00 CASE P SURF Lay down long bales and elear floor of Csg tools 16:30 - 17:00 0.50 CASE P SURF Nipple down Diverter 17:00 - 18:00 1.00 CASE P SURF Nipple up csg head and adapter and test to 1000 psi for ten min. 18:00 - 20:30 2.50 CASE P SURF Nipple up BOPS, Change out saver sub on top drive 20:30 - 00:00 3.50 CASE P SURF Rig up and test Bops and manifold, 250-3500 psi for 5 min per test, Hydril 250-2500 psi for 5 min per test, the right to witness test was wavier by Jeff Jones AOOGC 9/28/2004 00:00 - 01 :30 1.50 CASE P SURF Finish BOP test, install wear ring 01 :30 - 03:30 2.00 CASE P SURF Picking up BHA #2, Test Mwd tool 03:30 - 05:30 2.00 CASE P SURF Trip in to 4355' 05:30 - 06:30 1.00 CASE P SURF Cut and slip drilling line,service top drive 06:30 - 07:30 1.00 CASE P SURF Rig up to test casg - test casing to 2000 psi for 30 mins - 07:30 - 08:00 0.50 CASE P SURF Rig down testing equipment 08:00 - 10:00 2.00 DRILL P SURF Con't RIH - Drill float equipment to 4561' - Clean out rat hole to from 4561' to 4573' - Drill 20' new hole to 4593' - 400 GPM - 1790 psi - Cire hole clean 10:00 - 11 :00 1.00 CASE P SURF Pump 40 bbl spacer - Displace hole with 10 ppg LSND mud 11 :00 - 11 :30 0.50 EV AL P SURF Rig up testing equipment - Perform FIT test to 12.4 EMW 11 :30 - 13:30 2.00 DRILL P INT1 Directional Drill from 4593' to 4900' - WOB 25K - RPM 80 - TO 5K - GPM 500 - PP 2700 - PU 125 - SO 75 - ROT 105 13:30 - 15:30 2.00 DRILL N HMAN INT1 Excessive weight put on bit bending top joint 4" Drill pipe - As string picked up pipe parted - Lay down remaining seetion of joint from top drive - Cut drill pipe off below rotary table 15:30 - 17:00 1.50 DRILL N HMAN INT1 Change out saver sub on top drive 17:00 - 18:30 1.50 FISH N HMAN INT1 Make up overshot - Lateh onto 4" drill pipe - Pick up to 5K over string weight - Break cireulation - Cireulate hole clean hole up around BHA - Pull 1 0 to 15K in steps as circulating hole - String free @ 220K 78K over normal pick up weight - Lay down overshot and crossover 18:30 - 19:30 1.00 DRILL N HMAN INT1 Lay down 3 joints 4" DP - Pump out 4 stands of 4" DP to shoe 4561' 19:30 - 21:00 1.50 DRILL N HMAN INT1 CBU - Conduct investigation - Flow eheck - Pump dry job 21 :00 - 22:30 1.50 DRILL N HMAN INT1 POH from 4550' to HWT 22:30 - 23:30 1.00 DRILL N HMAN INT1 Rack baek HWT - Flex DC's - Lay down MWD I Motor 23:30 - 00:00 0.50 EVAL N HMAN INT1 Pull wear ring and Install Test plug 9/29/2004 00:00 - 01 :30 1.50 EVAL N HMAN INT1 Rig up testing equipment -Test Top pipe rams to 250 low 3500 high for 5 mins each test - Test Annular 250 low 2500 high for 5 mins eaeh test - Rig down testing equipment - Pull test plug - Install wear ring - Shut annulus valve- 01 :30 - 03:30 2.00 DRILL N HMAN INT1 Piek up new motor - Make up bit - MWD - Orient - BHA to 715' - Test MWD - No signal or pulse on MWD 03:30 - 04:00 0.50 DRILL N DFAL INT1 POH from 715' to MWD 04:00 - 08:00 4.00 DRILL N DFAL INT1 Trouble shoot MWD - Down load MWD - Attempt programming with no sucess - Change out MWD - Program new MWD - RIH with HWT - Surfaee test MWD 08:00 - 11 :00 3.00 DRILL N HMAN INT1 Con't RIH - Lay down 12 bent jts 4" DP - Wash to bottom from 4810' to 4900' 11 :00 - 00:00 13.00 DRILL P INT1 Directional Drill from 4900' to 6608' - WOB 25 - RPM 80 - TO on 10 - off 8.5 - GPM 525 - PP on 3300 - off 3150 - PU 160- Printed: 10/18/2004 9:57:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 9/23/2004 1 0/13/2004 Spud Date: 9/24/2004 End: 9/29/2004 11 :00 - 00:00 13.00 DRILL P INT1 SO 90 - ROT 115 9/30/2004 00:00 - 04:30 4.50 DRILL P INT1 Directional Drill from 6608' to 6920' - TD 9 7/8" hole - WOB 25 - RPM 80 - TO on 10 - off 8 - GPM 525 - PP on 3425 - off 3300- PU 160 - SO 90 - ROT 105 - (Top "NB" Sand 6199' - Top for window of "NB" Lateral 6072' - Top "OA" Sand 6555') 04:30 - 06:00 1.50 CASE P INT1 CBU 2 X - GPM 525 - PP 3350 - RPM 100 - TO 10k - Flow check - Well statie 06:00 - 08:00 2.00 CASE P INT1 Pump out to shoe from 6920' to 45550' - (Ratty from 6800' to 5700') 08:00 - 09:00 1.00 CASE P INT1 10 min flow check - RIH from 4550' to 6920' - Ream last stand down 09:00 - 12:00 3.00 CASE P INT1 CBU 1 X - @ 375 GPM - PP 2900 - RPM 100 - excessive cuttings coming over shakers - CBU 2 X - @ 525 GPM - PP 3360 - RPM 100 12:00 - 13:30 1.50 CASE P INT1 Pump out to shoe from 6920' to 4550' at drlg rate 13:30 - 14:30 1.00 CASE P INT1 CBU 1 X at shoe - GPM 525 - PP 3000 - RPM 80 - Flow cheek - Pump dry job 14:30 - 15:30 1.00 CASE P INT1 POH from shoe @ 4550' to HWT @ 715' 15:30 - 18:00 2.50 CASE P INT1 Lay down HWT - BHA 18:00 - 18:30 0.50 CASE P INT1 Piek up Franks fill up tool - Change out bails - Rig up casg equipment 18:30 - 20:00 1.50 CASE P INT1 Change out top pipe rams to 7 5/8" easing rams - test door seals to 1500 psi 20:00 - 21 :00 1.00 CASE P INT1 Finish rigging up easing tools 21 :00 - 00:00 3.00 CASE P INT1 PJSM - (Running casing) - Piek up float equipment - Cheek floats - Con't pieking up and running 7 5/8" 29.7# L-80 BTC-M easing to 2114' 10/1/2004 00:00 - 01 :30 1.50 CASE P INT1 Con't RIH with 7 5/8" easing to 4530' 01 :30 - 02:00 0.50 CASE P INT1 Cire casing volume @ 4530' - 208 bbls @ 6 bpm - PP 02:00 - 04:00 2.00 CASE P INT1 Con't RIH with 75/8" easing from 4530' to 6829' - Break circulation - wash last joint down - Make up Landing joint and RIH landing on hanger @ 6909' - PU 250 - SO 100 without pump 04:00 - 04:30 0.50 CASE P INT1 Break and lay down Franks fill up tool - Make up Schlumberger eementing head and lines 04:30 - 06:30 2.00 CASE P INT1 Circulate two casing volumes 635 bbls staging up pump rate from 3 bpm to 6 bpm @ 400 psi - PU 225 - SO 110 with pump - Condition mud for eement job 06:30 - 08:30 2.00 CEMT P INT1 Give to Schlumberger Dowell Pump 5 bbl water Test lines to 3000 psi Pump 25 bbl CW-100 - 5 bpm @ 160 psi Pump 45 bbls Mud Push mixed at 11 ppg - 3.5 bpm @ 415 psi Drop bottom plug Pump 124.7 bbls - 603.5 sxs - Class "G" cement - Mixed at 15.8 - Yield 1.16 eu/ft sx - 5 bpm @ 580 psi Drop top plug Displace with 322 bbl10 ppg OBM -7.5 bpm @ 750 psi Bump plug with 2000 psi - Hold for 2 mins - Bleed off pressure - Floats holding CIP 08:30 hrs 08:30 - 10:00 1.50 CASE P INT1 Close annular - Pump 20 bbls mud in annulus at 2 bpm @ 880 to 1200 psi - shut down well holding 450 psi - Blowdown Printed: 10/18/2004 9:57:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 9/23/2004 Rig Release: 10/13/2004 Rig Number: Spud Date: 9/24/2004 End: cireulating lines - Flush stack - Void out landing joint and 7 5/8" easing to 45' 10:00 - 10:30 0.50 WHSUR P INT1 Install pack-off - test to 5K - Pump down annulus 17.5 bbls mud at 2 bpm @ 1580 psi - shut down holding 900 psi - Pumped additional 8 bbls at 2 bpm @ 1580 psi - Shut down pressure at 570 10:30 - 11 :30 1.00 CASE P INT1 Break out and lay down Schlumberger cementing head - Cementing lines - Clear rig floor of casing and cementing tools 11 :30 - 14:30 3.00 BOPSU P INT1 PJSM - Install test plug - Open annulus valve - Change 7 5/8" casing rams to 2 7/8" X 5" Pipe rams - Test 250 low 3500 high each test 5 mins - Shut annulus valve - Pull test plug - Install wear ring - (Freeze protect 75/8" X 103/4" annulus with 88 bbls diesel - @ 1.5 bpm 1650 psi - inerease to 2 bpm 1850 psi) 14:30 - 17:00 2.50 CASE P INT1 PJSM - PU Sit I Motor - Make up - MU MWD - Orient - Make up Flex DC's - HWT - Flush pumps - Surfaee test MWD 17:00 - 19:00 2.00 CASE P INT1 Con't RIH to 6786' 19:00 - 20:00 1.00 CASE P INT1 Break eireulation - Rig up testing equipment - Test casing to 2500 psi for 30 mins - Reeord on chart 20:00 - 21 :30 1.50 DRILL P INT1 Con't RIH tag float eollar @ 6826' - Drill shoe tract to 6909' - Clean out rat hole to 6920' - Drill 20' new hole to 6940' 21 :30 - 22:00 0.50 CASE P INT1 CSU for FIT 22:00 - 22:30 0.50 EV AL P INT1 Rig up for FIT - Perform FIT - MD 6909' - TVD 4180' - Mud weight 9.9 ppg - Surface pressure 550 psi - EMW = 12.43 ppg- Rig down testing equipment - 22:30 - 00:00 1.50 DRILL P PROD1 Directional Drill from 6940' to 7003 - WOS 5 ro 10- RPM 80 - TO on 5 - off 3 - GPM 275 - PP on 2950 - off 28400 - PU 125- SO 88 - ROT 102 10/2/2004 00:00 - 04:00 4.00 DRILL P PROD1 Directional Drill from 7003' to 7303' - WOS 20 to 30 - RPM 80 - TO on 4 - off 3 - GPM 275 - PP on 3040 - off 2940 - PU 120- SO 90 - ROT 105 - After sliding 90' and no turn well getting close to drillers poloygon stop and consult with town about IFR correetions 04:00 - 05:30 1.50 DRILL P PROD1 Circ - GPM 275 - PP 2910 - RPM 80 - TO 3K - Clean hole while consulting with town on IFR corrections - Cire bottoms up for trip to increase bend on motor to 1.83 degree from 1.5 degree on motor 05:30 - 06:00 0.50 DRILL P PROD1 Pump to shoe from 7303' from 7303' to 6890' - Pump at drlg rate 06:00 - 09:30 3.50 DRILL P PROD1 Flow eheck well - POH to 1100' 09:30 - 11 :00 1.50 DRILL P PROD1 Cut drlg line - Service Top Drive 11 :00 - 11 :30 0.50 DRILL P PROD1 Con't POH to BHA 11 :30 - 12:00 0.50 DRILL P PROD1 Stand baek HWT I SHA - Change motor setting from 1.5 degree to 1.76 degree - Change bits 12:00 - 15:30 3.50 DRILL P PROD1 PJSM - Rig service - Make up SHA - RIH to stand # 25 - Fill pipe - Test MWD - Con't RIH to 7265' Fill every 25 stands 15:30 - 16:30 1.00 DRILL P PROD1 Survey 12 X - Wash to 7303' 16:30 - 00:00 7.50 DRILL P PROD1 Directional Drill from 7303' to 7650' - WOB 20 to 30 - RPM 80 - TO on 4.5 - off 3 - GPM 275 - PP on 3200 - off 3030 - PU 120- SO 85 - ROT 104 10/3/2004 00:00 - 10:30 10.50 DRILL P PROD1 Direetional Drill from 7650' to 8639' - TD OB Lateral - WOS 5 to 20 - RPM 60 - TO on 5 - off 3.5 - GPM 275 - PP On 3300 - off 3150 - PU 125 - SO 82 - ROT 101 10:30 - 12:00 1.50 CASE P PROD1 CSU 2 X - GPM 300 - PP 3550 - RPM 60 - TO 4K - Flow eheek Printed: 10/18/2004 9:57:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 9/23/2004 Rig Release: 10/13/2004 Rig Number: Spud Date: 9/24/2004 End: 10/3/2004 10:30 - 12:00 1.50 CASE P PROD1 - Well statie 12:00 - 14:00 2.00 CASE P PROD1 PJSM - Pump out to shoe from 8639' to 6873' - Pump at drlg rate 14:00 - 15:00 1.00 CASE P PROD1 CBU 1 X - GPM 300 - 3200 - RPM 60 - TO 3.5 15:00 - 16:00 1.00 CASE P PROD1 RIH - Taking weight @ 7277' - Make up top drive - Orient pipe - RIH - No obstruetion seen - Con't RIH to 8639' 16:00 - 18:30 2.50 CASE P PROD1 CBU 4 X - CBU 3 X with GPM 300 - RPM 60 - TO 5 - Very little cuttings coming over shakers - Inerease RPM to 85 - TO 5K - Inerease euttings return 25 to 30% more - Hole clean after 4 CBU - Flow eheck well - Well static 18:30 - 20:00 1.50 CASE P PROD1 Pump to shoe from 8639' to 6873' - Pump at drlg rate 20:00 - 21 :00 1.00 CASE P PROD1 CBU - GPM 300 - PP 3200 psi - Flow eheck - Well static - Pump dry job 21 :00 - 23:30 2.50 CASE P PROD1 POH - From 6873' to HWT @ 268' 23:30 - 00:00 0.50 CASE P PROD1 Stand back BHA - Lay down MWD - Flush motor - break off bit 10/4/2004 00:00 - 01 :00 1.00 CASE P PROD1 Clear rig floor 01 :00 - 01 :30 0.50 CASE P PROD1 PJSM - Rig up to run 4/2" slotted liner 01 :30 - 03:30 2.00 CASE P PROD1 PJSM - Pick up and run 45 joints 41/2" slotted liner 12.6# L-80 - Make up Baker seal bore extension - Baker HMC liner hanger - Baker ZXP liner top packer - PU weight 75K - SO weight 72K 03:30 - 06:30 3.00 CASE P PROD1 RIH with 41/2" Slotted liner from 1 ,957' to 8,639' 06:30 - 07:30 1.00 CASE P PROD1 Break Top Drive eonnection and drop ball pump same down @ 4 bpm. Once the ball was on seat pressure up to 2200 psi. Slack off to 60K to verify HMC liner hanger is set. Inerease pressure to 4,000 psi. To set the ZXP liner top packer with the pusher tool. Bleed off pressure to zero. - Close the Hydril - Pump down kill line and pressure up annulus to 1500 psi to verify that ZXP liner top paeker is set. Bleed off pressure and open Hydril. Pull the liner running tool above the top of the liner tie back sleeve. 07:30 - 08:00 0.50 CASE P PROD1 Circulate bottoms up while reciprocating drill string and liner running tool 9 BPM with 2,100 psi. 08:00 - 10:30 2.50 CASE P PROD1 Monitor well (Static) - POH with liner running tool from top of liner tie back sleeve at 6,680' 10:30 - 11 :00 0.50 CASE P PROD1 Service liner running tool and lay down same - Clear rig floor 11 :00 - 12:00 1.00 STWHIP P PROD2 Piek up and RI H with (10) 4 3/4" Steel Drill Collars and (11) 3 1/2" HWDP To 643' 12:00 - 12:30 0.50 STWHIP P PROD2 POH with HWDP And Steel Drill Collars Standing Back In Mast 12:30 - 14:30 2.00 STWHIP P PROD2 Pick up and RIH with Baker seal assembly, 3 joints of spaee out drill pipe, un-loader sub, blank sub, double pin cross over, bottom trip anchor, shear disconneet, debris barrier sub, and 7 5/8" whip stock - Piek up Sperry Sun MWD Tools, float sub, 1 joint of 31/2" HWDP, upper mill, lower mill, and starter mill. Attach starter mill to whip stock slide with 35K lug bolt. Orient to whip stoek to MWD Tool- RIH with bumper sub, (10) 4 3/4" Steel Drill Collars, and (11) 31/2' HWDP To 878' - Surface test MWD Tools 14:30 - 18:00 3.50 STWHIP P PROD2 RIH with whip stoek and milling assembly on 4" drill pipe from 878' To 6,628' - Fill drill string every 25 stands 18:00 - 18:30 0.50 STWHIP P PROD2 Break Circulation - Orient and Con't RIH to 6692' - Set whip stock slide 8 to 10 degrees left of high side with Sperry Sun MWD. Set whip stock as per Baker Representative. Set Printed: 10/18/2004 9:57:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 9/23/2004 Rig Release: 10/13/2004 Rig Number: Spud Date: 9/24/2004 End: 10/4/2004 18:00 - 18:30 0.50 STWHIP P PROD2 bottom trip anehor with 1 OK additional down weight and verify that whip stock is set by picking up an additional 8K above normal upward drag. Shear the 35K shear bolt from the milling BHA from the whip stoek 18:30 - 22:00 3.50 STWHIP P PROD2 Mill window from 6554' to 6566' - Drill from 6566' to 6580' - (TOW 6554 - BOW 6566') - WOM 0 to 2 milling easing - 4 drilling formation - RPM 80 - GPM 300 - PP 2470 22:00 - 22:30 0.50 STWHIP P PROD2 CBU - Pump hi-vis sweep - Circulate elean up well - Flow eheck - Well Statie 22:30 - 00:00 1.50 STWHIP P PROD2 POH 5 stands eheeking fill - Pump dry job - Can't POH to milling assy 10/5/2004 00:00 - 01 :00 1.00 STWHIP P PROD2 Can't POH with milling assy 01 :00 - 02:00 1.00 STWHIP P PROD2 Stand back DC's - HWT - Lay down Baker milling assy 02:00 - 03:00 1.00 DRILL P PROD2 Clear rig floor - Pull wear ring - Flush BOP staek - Reinstall wear ring 03:00 - 04:00 1.00 DRILL P PROD2 Piek up Drlg assy for OA Lateral - Surface test MWD @ 275 GPM - PP 1800 psi 04:00 - 06:00 2.00 DRILL P PROD2 RIH with BHA from 269' to 6500' 06:00 - 00:00 18.00 DRILL P PROD2 Orient to high side - Shut down pumps - Slide through window - Directional Drill OA Lateral from 6580 to 8415' - WOB 5 to 10 - RPM 60 - TO on 6 - off 5 - GPM 275 - PP on 3100 - off 2960- PU 145 - SO 65 - ROT 100 10/6/2004 00:00 - 02:00 2.00 DRILL P PROD2 Directional Drill from 8415' to 8595' - TD OA Lateral - WOB 5 to 10 - RPM 60 - TO on 6 - off 5 - GPM 275 - PP on 3120 - off 2960 - PU 145 - SO 65 - ROT 100 02:00 - 04:00 2.00 CASE P PROD2 CBU 3 X - GPM 300 - PP 3300 - RPM 90 - TO 7 04:00 - 06:30 2.50 CASE P PROD2 Pump to shoe at drlg rate from 8595' to 7850' Hole tight - Baek ream from 7850' to 6580" - Shut down pump - Pull thru window from 6580' to 6550' 06:30 - 08:00 1.50 CASE P PROD2 Cut drlg line - Rig serviee - Inspect saver sub 08:00 - 08:30 0.50 CASE P PROD2 RIH from 6550' to 8595' 08:30 - 10:30 2.00 CASE P PROD2 CBU 3 X - RPM 90 TO 5K - GPM 300 - PP 3400 - Flow check - Well static 10:30 - 13:00 2.50 CASE P PROD2 Pump out from 8595' to 6580' - Shut down pump - Pull thru window from 6580' to 6550' 13:00 - 14:00 1.00 CASE P PROD2 CBU 1 X - GPM 275 - PP 2650 - Blow down top drive - Flow check - Well static - Pump dry job 14:00 - 15:30 1.50 CASE P PROD2 Con't POH from 6550' to BHA @ 269' 15:30 - 16:30 1.00 CASE P PROD2 Stand back HWT - DC's - Lay down MWD - Motor - Break Bit - Flush motor 16:30 - 18:00 1.50 CASE P PROD2 Make up Baker Whip stock retrieving tool - BHA - RIH with BHA - Surface test MWD 18:00 - 20:30 2.50 CASE P PROD2 RIH with retrieving assy from 747' to 6500' - Break Circulation - Orient hook - Con't RIH - Engage hook with whip stock - Jar loose - PU 142 - SO 92 - Flow check - Well statie 20:30 - 22:00 1.50 CASE P PROD2 CBU 1 X - Pull 3 stands - Over pull 60K to 200K -Slack off to string weight - Make up top drive - Break circulation - Pulled free @ 225k 83k over string weight - Pull 2 more stands with no over pull - cheeking displacement - Flow Check - Well statie - Pump dry job 22:00 - 00:00 2.00 CASE P PROD2 POH with Baker whip stoek from 6120' to BHA @ 750' 10/7/2004 00:00 - 00:30 0.50 CASE P PROD2 Can't POH to BHA @ 750' 00:30 - 02:00 1.50 CASE P PROD2 Stand back DC's - HWT - Lay down Whip stoek - Retrieving Printed: 10/18/2004 9:57:31 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: 9/23/2004 Rig Release: 10/13/2004 Rig Number: Spud Date: 9/24/2004 End: 10/7/2004 00:30 - 02:00 1.50 CASE P PROD2 tool 02:00 - 03:00 1.00 CASE P PROD2 Clear floor - Rig up tubing tools 03:00 - 05:00 2.00 CASE P PROD2 PJSM - Piek up 4 1/2" slotted liner - Make up Baker hook hanger - Liner PU weight 72K - SO 70K 05:00 - 07:30 2.50 CASE P PROD2 RIH with 4 1/2" Liner to 8540' 07:30 - 09:00 1.50 CASE P PROD2 Hang Hook wall hanger at BOW 6566' - Release anchor and run past BOW to 6576' to ensure anehor was set in window - Pull up and reset hanger on BOW @ 6566' - Drop ball pump ball on seat @ 4 bpm 925 psi - Pressure up to 2250 psi to release from liner - Con't pressure up to 3600 psi to blow setting ball - PU 145 - SO 80 - Bottom of liner set @ 8565 - Top liner set @ 6549.43 09:00 - 09:30 0.50 CASE P PROD2 CBU @ 9 bpm - 2100 psi - Flow check - Pump dry job 09:30 - 11 :30 2.00 CASE P PROD2 POH - Lay down Baker liner running tools 11 :30 - 12:00 0.50 CASE P PROD2 Pick up test joint - Pull wear ring - Open annulus valves - Install test plug - Rig up testing equipment - 12:00 - 16:00 4.00 CASE P PROD2 Test BOP's - Annular 250 low 2500 high 5 mins each test- Pipe rams - Blind rams - Choke manifold - HCR ehoke I Kill - Manual Choke I Kill - Upper I Lower IBOP - Floor safety valves - 250 low 3500 high 5 mins eaeh test - Accumulator test performed - John Crisp with AOGCC waived witness of BOP test - Rig down testing equipment - Close annulus valves - Pull test plug - Install wear ring 16:00 - 17:30 1.50 CASE P PROD2 PJSM - Rig up tubing tools - PU LEM assy 17:30 - 21 :00 3.50 CASE P PROD2 RIH to 6650' - Con't RIH slowly to 6718' - PU weight 132 - SO 90 - 21 :00 - 22:30 1.50 CASE P PROD2 Sting into seal assy - SO 30K - PU 15K over string weight - LEM latehed - Slaek off 30K to confirm hook still landed - Break Connection drop 29/32" ball - Pump ball on seat - @ 4 bpm 870 psi - Slow down pump to 2 bpm @ 510 psi - Ball on seat - Presure up to 3300 psi to set ZXP pcker - Con't pressure up to release "GS" running tool - Running tool pressure set for 3800 psi - (Ball sheared out @ 3500 psi) - Bleed off remaining pressure @ 680 psi - Close Pipe rams - Pressure up annulus to test ZXP packer to 2350 psi - Held for 15 mins - good test - Bleed off pressure - Open rams - Piek up to confirm release from assy - PU weight 135 - Released from LEM assy 22:30 - 23:30 1.00 CASE P PROD2 CBU - Flow check - Well static - Pump dry job 23:30 - 00:00 0.50 CASE P PROD2 POOH with Baker LEM running tools 10/8/2004 00:00 - 01 :30 1.50 CASE P PROD2 Con't POH with Baker LEM running tool 01 :30 - 02:00 0.50 CASE P PROD2 Lay down LEM running tool 02:00 - 02:30 0.50 STWHIP P PROD3 Mobilize Baker whip stock BHA to rig floor 02:30 - 04:30 2.00 STWHIP P PROD3 Make up Baker whip stock Assy - Orient whipstock with MWD - RIH DC's - HWT - Surfaee test MWD @ GPM 268 790 psi 04:30 - 06:30 2.00 STWHIP P PROD3 RIH with Baker whipstoek from 867' to 6140' 06:30 - 07:30 1.00 STWHIP P PROD3 Orient whipstoek 5 degree left - Land dummy seals in liner tie-back sleave - Set whipstock anehor with 17K down weight- Pick up 10K over string weight to insure anehor is set - Shear mill off whipstock with 35K down weight - PU 130 - SO 88 07:30 - 11 :30 4.00 STWHIP P PROD3 Mill NB Window - TOW 6072 - BOW 6084 - TD 6098' - Full gauge hole to 6090' - WOM 2 to 4 milling window - Drlg formation 5 - RPM 95 - 100 - GPM 300 - PP 2250 - Retrieving slot @ 6077' (5 degree left) Printed: 10/18/2004 9:57:31 AM legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: Rig Release: Rig Number: 9/23/2004 1 0/13/2004 Spud Date: 9/24/2004 End: 1 0/8/2004 11 :30 - 12:30 1.00 STWHIP P PROD3 CBU - Pump sweep surfaee to surfaee - RPM 90 - TO 4 - GPM 300 - PP 2030 psi - Work mills through window while pumping sweep 12:30 - 14:00 1.50 STWHIP P PROD3 Flow eheek - Well statie - Pump dry job - POH to from 6050 to 750' 14:00 - 15:00 1.00 STWHIP P PROD3 Stand baek DC's - HWT - Lay down MWD, 1 joint 31/2", Mills, Upper mill in gauge 15:00 - 15:30 0.50 STWHIP P PROD3 Clear rig floor of milling tools 15:30 - 16:00 0.50 STWHIP P PROD3 Flush stack - Activate rams - Flush stack 16:00 - 17:30 1.50 DRILL P PROD3 BHA - Make up bit to motor - (Motor set 1.76 degree) - MWD- Orient - RIH with Flex DC's - Jars - HWT - Surface test MWD - 17:30 - 20:00 2.50 DRILL P PROD3 RIH from 270' to 6020' - Fill pipe @ 2666',5062' 20:00 - 21 :30 1.50 DRILL P PROD3 PJSM - Cut Drlg Line - Rig serviee - Inspeet saver sub 21 :30 - 22:00 0.50 DRILL P PROD3 Orient to 5 degree to left of high side - Slide thru window at 6072' - No pump or rotating 22:00 - 00:00 2.00 DRILL P PROD3 Directional Drill from 6098' to 6305' - WOB 5 to 10 - RPM 80- TO on 5 - off 4 - GPM 254 - PP on 2400 - off 2300 - PU 130- SO 90 - ROT - 105 10/9/2004 00:00 - 00:00 24.00 DRILL P PROD3 Directional Drill from 6305' to 8630' - TD NB Lateral - WOB 3 to 4 - RPM 80 - TO on 5.5K - off 4.5K - GPM 254 - PP on 2500 - off 2410 - PU 140 - SO 60 - ROT 100 10/10/2004 00:00 - 02:30 2.50 CASE P PROD3 CBU 4 X - GPM 300- PP 3050 - RPM 90 - TO 6.5 02:30 - 05:00 2.50 CASE P PROD3 Pump to shoe @ drlg rate - Tight - Paeking off @ 6320' to 6107' - Pull from 6107' to 6012' thru window without pump or rotating 05:00 - 06:00 1.00 CASE P PROD3 CBU 2 X - GPM 300 - PP 2750 - RPM 40 - TO 4 06:00 - 07:00 1.00 CASE P PROD3 RIH from 6012' to 8630' 07:00 - 09:30 2.50 CASE P PROD3 CBU 4 X - RPM 90 - TO 5K - GPM 300 - PP 3200 09:30 - 11 :30 2.00 CASE P PROD3 Pump to shoe @ drlg rate - from 8630' to 6107' - Pull from 6107' to 6012' thru window without pump or rotating 11 :30 - 12:00 0.50 CASE P PROD3 CBU - GPM 300 - PP 2820 - RPM 40 - TO 3 12:00 - 12:30 0.50 CASE P PROD3 Flow Check - Well static - Pump dry job - Blow down top drive 12:30 - 14:30 2.00 CASE P PROD3 POH from 6019' to 270' 14:30 - 15:30 1.00 CASE P PROD3 Stand baek 31/2" HWT I Jars - LD 4 3/4" flex DC's - MWD- Break bit - Flush motor - LD motor 15:30 - 17:30 2.00 CASE P PROD3 MU Baker WS retrieving tool assy - Orient MWD to hook - RIH 3 1/2" HWT I 4 3/4" DC's from derriek - Surfaee test MWD 17:30 - 19:30 2.00 CASE P PROD3 RIH from 750' to 6020' - Fill pipe @ 3142',6020' 19:30 - 20:00 0.50 CASE P PROD3 Break Cireulation - Orient hook - RIH from 6020' to 6084' - Latch onto Whipstoek - Jar - (PU 132K - SO 92K) - Pull free 230K - 93K over string weight - 20:00 - 21 :00 1.00 CASE P PROD3 CBU - GPM 254 - PP 1800 - Flow cheek - Well statie - Pull 5 stands from 6040' to 5634' - Check displacement - Pump dry job 21 :00 - 00:00 3.00 CASE P PROD3 POH from 5634' to 1322' 10/11/2004 00:00 - 00:30 0.50 CASE P PROD3 Con't POH from 1322' to 750' @ BHA 00:30 - 02:00 1.50 CASE P PROD3 BHA - Stand back 3 1/2" HWT - 4 3/4" DC's - LD MWD - Whipstock - WS retrieving tools 02:00 - 02:30 0.50 CASE P PROD3 Clear floor of all tools 02:30 - 03:00 0.50 CASE P PROD3 RU tubing running tools 03:00 - 07:30 4.50 CASE P PROD3 PJSM - PU 4" Baker Excluder Screen Liner - Make up Baker Hook Wall Hanger 07:30 - 10:00 2.50 CASE P PROD3 Run liner to 8596' - PU 140 - SO 75 Printed: 10/18/2004 9:57:31 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPH-18 MPH-18 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 9/23/2004 10/13/2004 Spud Date: 9/24/2004 End: 10/11/2004 . 10:00 - 11 :00 1.00 CASE P PROD3 Hang hook in BOW @ 6084' . Piek up release from BOW - Run in hole to 6094' to insure hook was set in BOW - Pick up and reset hook in BOW @ 6084' - Drop ball - Pump down with 4 bpm for 44 bbls @ 840 psi - 2 bpm for 6 bbls @ 420 psi - .5 bpm for 4.5 bbls 200 psi ball on seat - Pressure up to 3K to release liner - Con't pressure up to 4K to blowout ball - Liner shoe @ 8596' Liner top @ 6067' - PU 120 - SO 75 11 :00 - 11 :30 0.50 CASE P PROD3 CBU - 6 bpm @ 900 psi 11 :30 - 12:00 0.50 CASE P PROD3 Flow check - Dry job - POH 12:00 - 12:30 0.50 CASE P PROD3 Rig service - Top drive serviee - Crown Service - Traveling blocks Serviee 12:30 - 14:30 2.00 CASE P PROD3 POOH from 5368' to running tool - Change out to 3 1/2" handling equipment - serviee break tool 14:30 - 15:00 0.50 CASE P PROD3 RU 4 1/2" tubing equipment - PJSM (on running LEM) 15:00 - 15:30 0.50 CASE P PROD3 MU LEM # 2 Assy - RD 41/2" tubing equipment 15:30 - 20:00 4.50 CASE P PROD3 RIH from 197' to 6215' - PU 120K - SO 92K - Work LEM through hook wall hanger @ 6067 - Lateh LEM with 35K SO weight - PU to 130 10K over string weight to confirm latched up - Drop ball - Pump down - 49 bbls at 4 bpm 800 psi - 2.8 bbls At .5 bpm 110 psi - Ball on seat - Pressure up to 3000 psi to set ZXP paeker hold for 2 mins - Con't Pressure up to 4000 to release from hanger hold for 1 min - Close rams - Test Annulus to 2500 psi for 15 mins - Good test - Bleed off pressure - Open rams - PU to 6043' Confirmed off hanger 20:00 - 20:30 0.50 CASE P PROD3 CBU - GPM 250 - PP 1130 - Flow check - Well statie 20:30 - 23:30 3.00 CASE P PROD3 POH from 6043' to Baker running tool - Service break tool - LD tools 23:30 - 00:00 0.50 CASE P PROD3 Clear rig floor of all tools 10/12/2004 00:00 - 00:30 0.50 CASE P PROD3 MU BHA 00:30 - 02:00 1.50 CASE P PROD3 RIH to 6013' 02:00 - 03:00 1.00 CASE P PROD3 Cut Drlg Line - Rig Service 03:00 - 04:00 1.00 CASE P PROD3 Break Circulation - PJSM - (Displaeement of OBM) - Displace to Brine - Pump 20 bbls L VT - Pump 30 bbls Brine DuoVis Spacer - 15 bbls Safe Surfo Spaeer - 10 bbls Brine DuoVis Spaeer - 10.2 ppg Brine - RPM 90 - TQ 3K - GPM 335 - PP 2100 04:00 - 08:00 4.00 CASE P PROD3 Stand baek 7 stands in derrick for total of 40 stands - Lay down remaining 4" DP - 08:00 - 23:00 15.00 CASE N RREP PROD3 Repairing pipe skate 23:00 - 00:00 1.00 CASE P PROD3 Laying down Drill pipe 1 0/13/2004 00:00 - 01 :00 1.00 RUNCO RUNCMP Pull wear ring, PJSM on running tubing, Rig up to run tubing 01 :00 - 03:30 2.50 RUNCO RUNCMP picking up ESP assembly, rig up spool unit, attach cable and test 03:30 - 13:00 9.50 RUNCO RUNCMP Picking up 2 7/8 tubing, test conduetivity and circ tubing ever 2,000 ft, centralizer 5935, pump 5876.90, XN nipple 5823, GLM 5672,2136, 149', total of 183 jts of 2 7/8 6.5# L-80 13:00 - 13:30 0.50 RUNCO RUNCMP Land hanger 13:30 - 14;00 0.50 RUNCO RUNCMP test 2-way cheek 2,500 psi, lay down centri/ift eqp. 14:00 - 15:30 1.50 RUNCO RUNCMP Nipple down BOPS 15:30 - 19:00 3.50 RUNCO RUNCMP Nipple up 11' x 2 7/8 adapter and 2 9/16 CIW tree, test both to 5,000 psi for 10 min. 19:00 - 20:00 1.00 RUNCO RUNCMP Install BPV, Seeure well, rig release for rig move @ 2000 hrs 10/131 2004 Printed: 10/18/2004 9:57:31 AM Printed: 10/18/2004 9:57:26 AM WELL SERVICE REPORT e . WELL JOB SCOPE UNIT MPH-18 NEW WELL POST LRS 40 DATE DAILY WORK DAY SUPV 10/13/2004 FREEZE PROT O'MALLEY AFE KEY PERSON NIGHT SUPV MSD337409 LRS - WILSON O'MALLEY MINID I DEPTH TTL SIZE 0" OFT 0" DAILY SUMMARY [Freeze protect] Pumped 15 bbls crude, 1 bbl diesel down tubing. Pumped 65 bbls crude, 2 bbls diesel down IA to freeze protect well. Initial WHP=O, 0, no gauge. Final WHP=400, 600, no au e. Init-> 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA -SQ'!y!MENTS - .-........-.- ~... ~,~.~>.._..."....,~~, 20:35 Dispatched/load fluids _~1 :48 ,"-,~ AOURig up 22:08 Diesel 3500 PT Lines crude .. 22:12 1.0 0 110 1400 Start down tubing 22:28 swap 15 " 1850 swap to diesel 22:29 shut 1 diesel 800 shut down, ru to ia down 22:40 1 start " " 400 start pumping down ia 23:01 1.5 30 980 23:25 swap 65 " " 1000 swap to diesel 23:27 shut diesel . 2 1000 shut down, rdmo down Final-> 400 600 0 FLUID SUMMARY 80 bbls crude. 3 bbls from revious load. SERVICE COMPANY - SERVICE DAILY COST CUMULTOTAL BP $0 $0 LITTLE RED $823 $823 FESCO $0 $390 vvÄFfEHÖUSE .- -_. $0 $1,600 TOTAL FIELD ESTIMATE: $823 $2,813 . . 01-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPH-18 L2 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,017.09' MD 6,072.00' MD 8,630.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date CC M ðv ;)J)-o V\ Signed 1LJðiiJ y Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attaehment(s) ~~L{--(7 ~ D EFI N ITIVE Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPH MPH-18L2 . Job No. AKZZ3302792, Surveyed: 10 October, 2004 Survey Report 25 October, 2004 Your Ref: API 500292322461 Surface Coordinates: 6010178.19 N, 556657.51 E (70· 26' 18.4369° N, 149· 32' 16.8646° W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1010178.19 N, 56657.51 E (Grid) Surface Coordinates relative to Structure Reference: 1196.73 N, 1261.73 E (True) Kelly Bushing Elevation: 69.60ft above Mean Sea Level Kelly Bushing Elevation: 69.60ft above Project V Reference Kelly Bushing Elevation: 69. 60ft above Structure Reference SpE!I""'I""'Y-SUI'1 DRfCLLNG· SERVICES A Halliburton Company Survey Ref: svy1482 ~Dt{- (7Co Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18L2 Your Ref: API 500292322461 Job No. AKZZ3302792, Surveyed: 10 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6017.09 60.120 284.760 3803.53 3873.13 2825.70 N 2615.16 W 6012983.94 N 554020.96 E 3850.12 Tie On Point 6072.00 60.770 283.830 3830.61 3900.21 2837.49 N 2661.44 W 6012995.38 N 553974.58 E 1.890 3890.31 Window Point 6109.27 64.960 284.060 3847.61 3917.21 2845.49 N 2693.63 W 6013003.13 N 553942.34 E 11 .256 3918.11 6139.51 69.130 284.250 3859.40 3929.00 2852.29 N 2720.62 W 6013009.73 N 553915.30 E 13.802 3941.50 6192.74 76.660 284.570 3875.04 3944.64 2864.95 N 2769.86 W 6013022.01 N 553865.96 E 14.158 3984.33 6235.32 80.820 284.830 3883.36 3952.96 2875.54 N 2810.24 W 6013032.30 N 553825.50 E 9.788 4019.62 . 6282.70 86.850 285.250 3888.44 3958.04 2887.76 N 2855.71 W 6013044.17 N 553779.94 E 12.757 4059.57 6331.04 86.970 285.290 3891.05 3960.65 2900.48 N 2902.28 W 6013056.53 N 553733.28 E 0.262 4100.62 6362.65 86.980 285.190 3892.72 3962.32 2908.77 N 2932.74 W 6013064.60 N 553702.76 E 0.317 4127.46 6394.67 87.040 282.830 3894.39 3963.99 2916.51 N 2963.76 W 6013072.10 N 553671.68 E 7.363 4154.28 6426.93 86.170 281.020 3896.30 3965.90 2923.17 N 2995.27 W 6013078.52 N 553640.12 E 6.216 4180.64 6474.39 85.180 275.500 3899.88 3969.48 2929.97 N 3042.08 W 6013084.96 N 553593.26 E 11.784 4217.54 6523.24 88.580 273.920 3902.54 3972.14 2933.97 N 3090.69 W 6013088.59 N 553544.62 E 7.673 4253.61 6573.30 87.900 273.700 3904.07 3973.67 2937.29 N 3140.61 W 6013091.54 N 553494.67 E 1 .428 4290.09 6617.94 86.730 272.480 3906.17 3975.77 2939.70 N 3185.14 W 6013093.60 N 553450.13 E 3.784 4322.22 6664.81 89.010 272.770 3907.91 3977.51 2941.84 N 3231.92 W 6013095.39 N 553403.33 E 4.904 4355.69 6714.11 90.310 274.180 3908.20 3977.80 2944.83 N 3281.13 W 6013098.01 N 553354.10 E 3.890 4391.44 6761.40 90.060 275.100 3908.05 3977.65 2948.66 N 3328.26 W 6013101.47 N 553306.94 E 2.016 4426.38 6810.65 89.260 278.260 3908.34 3977.94 2954.38 N 3377.17 W 6013106.83 N 553257.99 E 6.619 4463.92 6858.25 88.700 278.730 3909.19 3978.79 2961.42 N 3424.24 W 6013113.50 N 553210.87 E 1.536 4501.17 6906.57 89.070 281.500 3910.13 3979.73 2969.90 N 3471.79 W 6013121.63 N 553163.25 E 5.782 4539.80 6957.70 90.060 284.230 3910.52 3980.12 2981.28 N 3521.63 W 6013132.63 N 553113.33 E 5.679 4582.12 . 7002.61 89.260 286.650 3910.78 3980.38 2993.24 N 3564.92 W 6013144.26 N 553069.95 E 5.675 4620.38 7054.34 89.200 288.520 3911.48 3981.08 3008.86 N 3614.22 W 6013159.51 N 553020.53 E 3.616 4665.44 7098.65 90.060 293.660 3911.76 3981.36 3024.80 N 3655.55 W 6013175.13 N 552979.08 E 11.761 4705.28 7149.53 90.060 298.930 3911.71 3981.31 3047.33 N 3701.15 W 6013197.32 N 552933.31 E 10.358 4752.86 7194.43 89.440 304.150 3911.91 3981.51 3070.81 N 3739.40 W 6013220.50 N 552894.88 E 11.707 4796.12 7242.63 87.410 306.590 3913.23 3982.83 3098.70 N 3778.69 W 6013248.09 N 552855.39 E 6.583 4843.30 7290.70 89.010 308.580 3914.73 3984.33 3128.00 N 3816.76 W 6013277.10 N 552817.10 E 5.310 4890.70 7337.11 89.750 312.330 3915.24 3984.84 3158.11 N 3852.06 W 6013306.94 N 552781.56 E 8.235 4936.80 7387.01 89.880 317.040 3915.40 3985.00 3193.19 N 3887.53 W 6013341.75 N 552745.83 E 9.442 4986.64 7434.81 88.830 321.260 3915.93 3985.53 3229.33 N 3918.79 W 6013377.66 N 552714.30 E 9.097 5034.39 7483.19 89.940 323.900 3916.45 3986.05 3267.75 N 3948.18 W 6013415.85 N 552684.61 E 5.919 5082.54 7533.73 89.140 327.720 3916.86 3986.46 3309.55 N 3976.58 W 6013457.43 N 552655.90 E 7.722 5132.47 7579.63 89.940 330.350 3917.23 3986.83 3348.90 N 4000.19 W 6013496.60 N 552631.99 E 5.989 5177.35 25 October, 2004 - 11:43 Page 2 of 4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18L2 Your Ref: API 500292322461 Job No. AKZZ3302792, Surveyed: 10 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 7629.56 90.370 334.000 3917.09 3986.69 3393.05 N 4023.49 W 6013540.57 N 552608.36 E 7.361 5225.53 7675.85 89.320 337.460 3917.22 3986.82 3435.24 N 4042.51 W 6013582.62 N 552589.01 E 7.811 5269.36 7725.38 89.880 341.030 3917.56 3987.16 3481.55 N 4060.06 W 6013628.79 N 552571.11 E 7.296 5315.20 7772.62 90.250 344.660 3917.51 3987.11 3526.68 N 4073.99 W 6013673.81 N 552556.84 E 7.724 5357.71 7821.14 91.420 350.950 3916.80 3986.40 3574.07 N 4084.24 W 6013721.13 N 552546.24 E 13.185 5399.36 7867.95 91.540 356.750 3915.59 3985.19 3620.58 N 4089.25 W 6013767.60 N 552540.87 E 12.389 5436.79 . 7918.51 91.300 2.330 3914.34 3983.94 3671.10 N 4089.65 W 6013818.11 N 552540.08 E 11.043 5474.01 7964.65 90.740 2.760 3913.52 3983.12 3717.19 N 4087.61 W 6013864.22 N 552541.78 E 1.530 5506.32 8014.03 90.560 2.060 3912.96 3982.56 3766.52 N 4085.53 W 6013913.56 N 552543.48 E 1 .464 5540.98 8059.85 91.610 2.040 3912.09 3981.69 3812.30 N 4083.89 W 6013959.36 N 552544.77 E 2.292 5573.35 8110.03 89.750 1.790 3911.49 3981.09 3862.45 N 4082.21 W 6014009.51 N 552546.07 E 3.740 5608.88 8148.16 89.570 1.160 3911.72 3981.32 3900.57 N 4081.23 W 6014047.64 N 552546.76 E 1.718 5636.09 8205.53 89.070 0.270 3912.40 3982.00 3957.93 N 4080.52 W 6014105.00 N 552547.04 E 1.779 5677.55 8251.50 88.890 0.050 3913.22 3982.82 4003.89 N 4080.39 W 6014150.96 N 552546.82 E 0.618 5711.08 8299.66 87.530 359.530 3914.72 3984.32 4052.02 N 4080.57 W 6014199.09 N 552546.28 E 3.023 5746.40 8346.46 85.800 359.460 3917.45 3987.05 4098.74 N 4080.98 W 6014245.81 N 552545.51 E 3.700 5780.85 8396.35 85.430 359.230 3921.26 3990.86 4148.48 N 4081.55 W 6014295.54 N 552544.56 E 0.873 5817.62 8442.39 85.680 359.020 3924.83 3994.43 4194.38 N 4082.25 W 6014341.43 N 552543.51 E 0.708 5851.66 8495.04 89.260 358.020 3927.15 3996.75 4246.95 N 4083.61 W 6014393.99 N 552541.76 E 7.059 5891.03 8538.69 93.830 359.700 3925.98 3995.58 4290.56 N 4084.47 W 6014437.60 N 552540.56 E 11.154 5923.52 8560.99 96.370 359.020 3923.99 3993.59 4312.77 N 4084.72 W 6014459.80 N 552540.14 E 11.788 5939.93 8630.00 96.370 359.020 3916.34 3985.94 4381.34 N 4085.89 W 6014528.37 N 552538.45 E 0.000 5990.89 Projected Survey . All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 317.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8630.00ft., The Bottom Hole Displacement is 5990.89ft., in the Direction of 316.998° (True). 25 October, 2004 - 11:43 Page 30f4 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 6017.09 6072.00 8630.00 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18L2 Your Ref: API 500292322461 Job No. AKZZ3302792, Surveyed: 10 October, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3873.13 3900.21 3985.94 2825.70 N 2837.49 N 4381.34 N 2615.16 W 2661.44 W 4085.89 W . Tie On Point Window Point Projected Survey Survey tool proaram for MPH-18L2 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 534.00 0.00 533.95 533.95 CB-SS-GYRO (MPH-18) 3985.94 MWD+IIFR+MS (MPH-18) 534.00 8630.00 . 25 October, 2004 - 11:43 Page 40f4 DrillQuest 3.03.06.006 . . 01-Nov-04 AOGCC Robin Deason 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPH-18 L2 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 6,017.09' MD 6,072.00' MD 8,630.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 r1 / 11 1 / / . Date 0( ÆJ ð V J.M vf Signed ~ (f)j¿ihJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ~ ljv(--f7 ~ Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPH MPH-18L2 (mwd) . Job No. AKMW3302792, Surveyed: 10 October, 2004 Survey Report 25 October, 2004 Your Ref: API 500292322461 Surface Coordinates: 6010178.19 N, 556657.51 E (70026'18.4369" N, 149032'16.8646" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 . Surface Coordinates relative to Project H Reference: 1010178.19 N, 56657.51 E (Grid) Surface Coordinates relative to Structure Reference: 1196.73 N, 1261.73 E (True) Kelly Bushing Elevation: 69.60ft above Mean Sea Level Kelly Bushing Elevation: 69. 60ft above Project V Reference Kelly Bushing Elevation: 69. 60ft above Structure Reference SpE!r"'r"'Y-SUI1 ORlLLING· SSFtVIc:e:s A Halliburton Company Survey Ref: svy1488 ~~ t{~ll~ Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18L2 (mwd) Your Ref: API 500292322461 Job No. AKMW3302792, Surveyed: 10 October, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6017.09 60.120 285.980 3803.54 3873.14 2866.65 N 2573.18 W 6013025.21 N 554062.63 E 3851.44 Tie On Point 6072.00 60.770 283.830 3830.62 3900.22 2878.94 N 2619.33 W 6013037.14 N 554016.38 E 3.606 3891.90 Window Point 6109.27 64.960 284.060 3847.62 3917.22 2886.93 N 2651.52 W 6013044.89 N 553984.14 E 11.256 3919.70 6139.51 69.130 284.250 3859.41 3929.01 2893.74 N 2678.51 W 6013051.49 N 553957.09 E 13.802 3943.08 6192.74 76.660 284.570 3875.06 3944.66 2906.39 N 2727.75 W 6013063.77 N 553907.76 E 14.158 3985.92 . 6235.32 80.820 285.050 3883.37 3952.97 2917.06 N 2768.11 W 6013074.14 N 553867.31 E 9.832 4021.25 6282.70 86.850 285.480 3888.45 3958.05 2929.46 N 2813.54 W 6013086.19 N 553821.80 E 12.759 4061.30 6331.04 86.970 285.650 3891.06 3960.66 2942.41 N 2860.03 W 6013098.79 N 553775.20 E 0.430 4102.48 6362.65 86.980 285.580 3892.73 3962.33 2950.91 N 2890.44 W 6013107.06 N 553744.74 E 0.223 4129.43 6394.67 87.040 283.320 3894.40 3964.00 2958.89 N 2921.40 W 6013114.80 N 553713.72 E 7.051 4156.38 6426.93 86.170 281.370 3896.31 3965.91 2965.77 N 2952.86 W 6013121.44 N 553682.21 E 6.609 4182.87 6474.39 85.180 275.740 3899.89 3969.49 2972.81 N 2999.63 W 6013128.13 N 553635.38 E 12.011 4219.92 6523.24 88.580 274.130 3902.55 3972.15 2977.01 N 3048.22 W 6013131.95 N 553586.76 E 7.699 4256.13 6573.30 87.900 273.910 3904.09 3973.69 2980.51 N 3098.14 W 6013135.08 N 553536.82 E 1.428 4292.73 6617.94 86.730 272.700 3906.18 3975.78 2983.09 N 3142.65 W 6013137.31 N 553492.29 E 3.768 4324.97 6664.81 89.010 273.000 3907.92 3977.52 2985.41 N 3189.43 W 6013139.29 N 553445.49 E 4.906 4358.58 6714.11 90.310 274.380 3908.21 3977.81 2988.59 N 3238.62 W 6013142.08 N 553396.28 E 3.846 4394.45 6761.40 90.060 275.260 3908.06 3977.66 2992.56 N 3285.74 W 6013145.70 N 553349.12 E 1.934 4429.49 6810.65 89.260 278.460 3908.35 3977.95 2998.44 N 3334.63 W 6013151.21 N 553300.19 E 6.697 4467.14 6858.25 88.700 278.900 3909.20 3978.80 3005.62 N 3381.68 W 6013158.04 N 553253.09 E 1 .496 4504.48 6906.57 89.070 281.710 3910.14 3979.74 3014.27 N 3429.21 W 6013166.32 N 553205.50 E 5.864 4543.21 6957.70 90.060 284.410 3910.53 3980.13 3025.82 N 3479.01 W 6013177.49 N 553155.61 E 5.624 4585.62 . 7002.61 89.260 286.740 3910.79 3980.39 3037.88 N 3522.26 W 6013189.22 N 553112.27 E 5.485 4623.94 7054.34 89.200 288.560 3911.49 3981.09 3053.56 N 3571.55 W 6013204.52 N 553062.86 E 3.520 4669.02 7098.65 90.060 293.660 3911.78 3981.38 3069.51 N 3612.87 W 6013220.16 N 553021.42 E 11.672 4708.87 7149.53 90.060 298.770 3911.72 3981.32 3091.98 N 3658.51 W 6013242.28 N 552975.62 E 10.043 4756.43 7194.43 89.440 303.960 3911.92 3981.52 3115.34 N 3696.83 W 6013265.35 N 552937.12 E 11.641 4799.65 7242.63 87.410 306.540 3913.24 3982.84 3143.14 N 3736.17 W 6013292.86 N 552897.56 E 6.809 4846.81 7290.70 89.010 308.550 3914.75 3984.35 3172.42 N 3774.26 W 6013321.84 N 552859.25 E 5.343 4894.20 7337.11 89.750 312.430 3915.25 3984.85 3202.55 N 3809.55 W 6013351.70 N 552823.74 E 8.510 4940.30 7387.01 89.880 317.110 3915.41 3985.01 3237.68 N 3844.97 W 6013386.57 N 552788.05 E 9.382 4990.15 7434.81 88.830 321.420 3915.95 3985.55 3273.89 N 3876.15 W 6013422.54 N 552756.60 E 9.280 5037.90 7483.19 89.940 324.070 3916.47 3986.07 3312.39 N 3905.43 W 6013460.81 N 552727.02 E 5.938 5086.03 7533.73 89.140 327.950 3916.87 3986.47 3354.29 N 3933.68 W 6013502.49 N 552698.46 E 7.838 5135.93 7579.63 89.940 330.580 3917.24 3986.84 3393.73 N 3957.14 W 6013541.76 N 552674.70 E 5.989 5180.78 25 October, 2004 - 11:43 Page 2 of4 DrillQuest 3.03.06.006 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18L2 (mwd) Your Ref: API 500292322461 Job No. AKMW3302792, Surveyed: 10 October, 2004 BPXA Milne Point Unit Measured True 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) 7629.56 90.370 334.340 3917.11 3986.71 3438.00 N 3980.22 W 6013585.85 N 552651.29 E 7.580 5228.89 7675.85 89.320 337.750 3917.23 3986.83 3480.29 N 3999.01 W 6013628.00 N 552632.17 E 7.708 5272.64 7725.38 89.880 341.370 3917.58 3987.18 3526.70 N 4016.30 W 6013674.27 N 552614.53 E 7.395 5318.37 7772.62 90.250 344.890 3917.52 3987.12 3571.90 N 4030.01 W 6013719.36 N 552600.48 E 7.492 5360.78 7821.14 91.420 351.220 3916.82 3986.42 3619.34 N 4040.05 W 6013766.73 N 552590.08 E 13.266 5402.32 . 7867.95 91.540 357.080 3915.61 3985.21 3665.87 N 4044.81 W 6013813.22 N 552584.96 E 12.517 5439.60 7918.51 91.300 2.690 3914.35 3983.95 3716.39 N 4044.91 W 6013863.74 N 552584.48 E 11 .102 5476.62 7964.65 90.740 3.120 3913.53 3983.13 3762.46 N 4042.58 W 6013909.83 N 552586.46 E 1.530 5508.72 8014.03 90.560 2.400 3912.97 3982.57 3811.78 N 4040.20 W 6013959.17 N 552588.47 E 1.503 5543.17 8059.85 91.610 2.360 3912.10 3981.70 3857.55 N 4038.30 W 6014004.95 N 552590.02 E 2.293 5575.35 8110.03 89.750 2.000 3911.51 3981.11 3907.69 N 4036.39 W 6014055.10 N 552591.55 E 3.775 5610.71 8148.16 89.570 1.370 3911.73 3981.33 3945.80 N 4035.27 W 6014093.22 N 552592.38 E 1.718 5637.82 8205.53 89.070 0.435 3912.41 3982.01 4003.16 N 4034.36 W 6014150.59 N 552592.85 E 1.848 5679.16 8251.50 88.890 0.400 3913.23 3982.83 4049.12 N 4034.03 W 6014196.55 N 552592.83 E 0.399 5712.54 8299.66 87.530 0.120 3914.74 3984.34 4097.26 N 4033.81 W 6014244.68 N 552592.69 E 2.883 5747.60 8346.46 85.800 359.640 3917.46 3987.06 4143.98 N 4033.91 W 6014291.40 N 552592.23 E 3.836 5781.83 8396.35 85.430 359.440 3921.27 3990.87 4193.72 N 4034.31 W 6014341.14 N 552591.46 E 0.842 5818.48 8442.39 85.680 359.310 3924.84 3994.44 4239.62 N 4034.81 W 6014387.03 N 552590.61 E 0.612 5852.39 8495.04 89.260 358.260 3927.17 3996.77 4292.20 N 4035.92 W 6014439.60 N 552589.09 E 7.085 5891.61 8538.69 93.830 359.940 3925.99 3995.59 4335.81 N 4036.61 W 6014483.21 N 552588.08 E 11.154 5923.97 8560.99 96.370 359.260 3924.01 3993.61 4358.02 N 4036.76 W 6014505.42 N 552587.75 E 11.788 5940.32 8630.00 96.370 359.260 3916.35 3985.95 4426.60 N 4037.65 W 6014573.98 N 552586.35 E 0.000 5991.08 Projected Survey . All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relatiye to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 317.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8630.00ft., The Bottom Hole Displacement is 5991.44ft., in the Direction of 317.6310 (True). 25 October, 2004 - 11:43 Page 3 of4 DrillQuest 3.03.06.006 Milne Point Unit Comments Measured Depth (ft) 6017.09 6072.00 8630.00 Halliburton Sperry-Sun Survey Report for Milne Point MPH - MPH-18L2 (mwd) Your Ref: API 500292322461 Job No. AKMW3302792, Surveyed: 10 October, 2004 BPXA Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 3873.14 3900.22 3985.95 . 2866.65 N 2878.94 N 4426.60 N 2573.18 W 2619.33 W 4037.65 W Tie On Point Window Point Projected Survey Survey too/proøram for MPH-18L2 (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 534.00 0.00 533.95 534.00 8630.00 533.95 CB-SS-GYRO (MPH-18 (mwd)) 3985.95 MWD Magnetic (MPH-18 (mwd)) . 25 October, 2004 - 11:43 Page 4 of4 DrillQuest 3.03.06.006 . ~1f 1fŒ lID~ !Æ~!Æ . FRANK H. MURKOWSKI, GOVERNOR A.T,A.SIi& OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Pat Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPH-18L2 BP Exploration (Alaska) Inc. Permit No: 204-176 Surface Location: 3026' NSL, 3987' WEL, SEe. 34, T13N, RlOE, (As Planned) Bottomhole Location: 2127' NSL, 2818' WEL, SEC. 28, T13N, RlOE, UM (NB) Dear Mr. Archey: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new wellbore segment of existing well MPU 4-18, Permit No. 204-174, API No. 50-029-23224-00. Production should continue to be reported as a function of the original API number stated above. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3 ager). Chairman BY ORDER q¡ THE COMMISSION DA TED this~ day of September 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. · STATE OF ALASKA . ALA~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 Á/¡s 1a. Type of work DDrill III Redrill rb. Current Well Class D Exploratory III Development Oil D Multiple Zone D Re-Entry D Stratigraphic Test D Service D Development Gas D Single Zone 2. Operator Name: 5. Bond: IBI Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S1oo302630-277 MPH-18L2 3. Address: 6. Proposed Depth: 12. Field 1 Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 8628' TVD 4122' Milne Point Unit I Schrader Bluff 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: ,/ ADL 025906 3026' NSL, 3987' WEL, SEC. 34, T13N, R10E, (As Planned) Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 536' NSL, 1329' WEL, SEC. 28, T13N, R10E, UM (NB) 09/21/2004 Total Depth: . 9. Acres in Property: 14. Distance to Nearest Property: 2127' NSL, 2818' WEL, SEC, 28, T13N, R10E, UM (NB) .I 2560 5800' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x-556658 I y-6010178 / Zone- ASP4 (Height above GL):KBE = 72' feet 285' away from MPJ-07 16. Deviated Wells: Kickoff Depth: 6009' feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91.3 dearees Downhole: 2100 Surface: 1685 _ng~rogram: ToO,,' ~u~n~_ Size (c.f.·or Hole Casina Weiaht Grade Couplina Lenath MD TVD MD TVD lincludina staae data 6-3/4" 4"x5" L-80 IBT 2878' 5950' 3868' 8828' 3992' Excluder Screens and Blanks 19. i PRESI;NTWI!I...þCONQIJIOt.,¡$UMMARY (To ~ çqrrlpløt~'otR~rill,ANO~~-entJ'ý'º~tiQns) ,'" ," Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 8557' & 8550' 4192'&4122' _ N/A 8557'&8550' 4192' & 4122' N/A , " , .ii 'i'·,·'·.···.. i"";';" ".ii"··· ,'''ii'i''MD }i",~ Conductor 80' 20" 260 sx Arctic Set (Approx.) 114' 114' 444 7' 10-3/4" 645 sx Arctic Set Lite, 255 sx Class 'G' 4477' 3172' i PronlJc:tion 6770' 7-5/8" 580 sx Class 'G' 6457' 4160' Liner 1950' 4-1/2" Uncemented Slotted Liner 8557' 4192' Liner (OA) 2391' 4-1/2" Uncemented Slotted Liner 8550' 4122' Perforation Depth MD (ft): N/A /perfOration Depth TVD (ft): N/A 20. Attachments o Filing Fee, $100 o BOP Sketch IBI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report IBI Drilling Fluid Program IBI 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contaet Skip Coyner, 564-4395 Printed Name Pat Archey Title Senior Drilling Engineer (j'.~/ì _ t J> ~ Date 7/9 Jot/ Prepared By Name/Number: Signature Phone 564-5803 Sondra Stewman, 564-4750 ,,' i" .r..;"., '"" ~LT· """".i"i{'ij ,.., ~ ;iG',',.;,.,) ,",,'i,'! "ii;"·',';; ,>,'" ">,'" 'Ii " Permit To Drill L/ API Number: .". q 2-:3 22...'-/--& I Permit APt ~/Pn I See cover letter for Number: ;;¿ó '- 17 (P 50JJ ~ ... Date: other requirements Conditions of Approval: Samples Required 0 Yes ~No Mud Log ReqlfreèJ I 0 Yes gNo Hydrogen Sulfide Measures 0 Yes ß(No Directional Survey Required '~Yes 0 No Othec ...,~.;; ~ -\i;:RE~. ï~5Ç'~s~V"\U"'" \. ~ {I..{'ð::.ys,.. ADeroved Bv(fj 41.... o;~:a~ C~~O~:",m"íon . APPROVED BY 9//61AC/ THE CO~MlpSION Date Form 1 0-401 Rev~d ~04 \..---. Anchorage ORIG\NAL ~ubm¡{ In [(¡plicate . . - bp I Well Name: IMPH-18 L-2 NB Lateral Drill and Complete Plan Summary I Type of Well (service I producer I injector>-=--' Schrader Bluff Tri-Lateral Producer 3026' FSL, 2254' FNL, 3987' FEL, 1293' FWL 34 T13N R10E E = 556,658' N = 6,010,178' 707' FSL, ·4573' FNL, 2045' FEL, 3235' FWL E= 553,291' N = 6,013,113' Z = 4160' TVO ?127' FSL, 3153' FNL, 2750' FEl, 2530' FWL E =552,572' N = 6,014,529" Z = 4192' TVO' 62~' FSL, 4655' FNL, 1721' FEL, 3559' FWL E = 553,616' N = 6,013,034' Z =4,092' TVO 2127' FSL, 3153' FNl, 2818' FEL, 2462' FNL E = 552,572' N = 6,014,528' Z = 4,122' TVO 536' FSL,4744'FNL,1329' FEL,3951' FWL E = 554,009' N = 6,012,948' Z = 3,895' TVD 577' FSL,4703'FNL, 1706' FEL,3574' FVVL E = 553,631' N = 6,012,986' Z = 3,972' TVD 2127' FSL,3153'FNL,2818'FEL,2462' FWL E = 552,504' N = 6,014,582' Z = 3,992' TVD 5800' 285' from MPJ-07 (Shut In) ,/ Surface Location: (As Proposed) Target Loc'n: BOB Heel" 7-5/8" Shoe at 6,800' MO Target Loc'n: "OB Toe" OB BHL at 8,557' MO Target Loc'n: BOA Heel" OA Window at 6,457' MD Target Loc'n: BOA Toe" .OA BHL at 8,550' MD Target Loc'n: NB VVindow at 6,009' MD Target Loc'n: "NB Entry" TI NB Sand at 6,400' MD Target Loc'n: "NB Heel" NB BHL at 8,628' MD Distance to Property line Distance to nearest pool 28 T13N R10E 28 T13N R10E 28 T13N R10E / AFE Number: I Estimated Start Date: 121 Sept 04 Rig: Doyon 14 Rig days to complete: 1 . . MOBM API Filtratec.· LGSQlids< < 6 < 15 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. Cement Program: Basis· Total Cement Volume: 563 bbl Total Cement Volume: 120 bbl 2 Evaluation Program: Formation Markers: TUZC U U nu-MB1 U U Recommended 3 . and 4" Blanks L-80 4" IBT 5,950' / 3,868' 8,828' / 3,992' Well Control: Intermediate hole: · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · BOP Test Interval: · Integrity tests: Kick tolerance [10-3/4"]: Kick tolerance [10-3/4"]: · Planned completion fluid: 2,100 psi at 4,152' TVD (Top of the OB sand) (9.8 ppg) 1,685 psi at (Based on a full column of gas at 0.1 psi/ft) 3,500 psi NOT TO EXCEED 14 DAYS / per AOGCC FIT to 11.5 Iblgal 20' below the 10-3/4" shoe. 26-bbl with an 11.5 ppg FIT [minimum] and 10.0 Ib/gal mud 52-bbl with a 12.4 ppg FIT and 10.0 Iblgal mud Kill Weight brine or MOBM Drilling Hazards & Contingencies: · Hydrates have been encountered on H-Pad wells: 1,700' to 3,000' TVD. · Packing off due to clays and poor hole cleaning: 2300' to 3300' TVD. · Formation pressures in Hydraulic Unit #5 are above normal due to J-Pad injectors. Lost Circulation · We do not expect losses while drilling this well, although it is possible when cutting faults in the three laterals while drilling with ~ 10.0 ppg MOBM. Expected Pressures · The Schrader Bluff sands are pressured up to an EMW of 9.8 ppg as measured in MPJ-07 located near the landing point of the 7-5/8" intermediate casing. Pad Data Sheet · Please Read the H-Pad Data Sheet thoroughly. Breathing Hazards · Not expected or predicted. 4 . . Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · One (1) fault (#3) is expected to be cut in the intermediate hole section. That fault (#3) should be cut near the TINB sand at ± 6175' MD. · Two (2) minor faults (#4 & #5) are expected in the OB lateral: both faults are expected to be cut between 7650' and 7750' MD. · The same two (2) minor faults (#4 & #5) are expected in the OA lateral [L-1]: both faults are expected to be cut between 7650' and 7700' MD. · The same two (2) minor faults (#4 & #5) are expected in the NB lateral [L-2]: both faults are expected to be cut between 7750' and 7800' MD. Hydrogen Sulfide · MPI Pad is not designated as an H2S Pad. Anti-collision Issues · MPH-18 passes the Major Risk Criteria in the Mother Bore and all laterals. Gyro surveys will be run as needed for possible magnetic interference down to ± 600 ft MD. · The intermediate hole section passes near MPJ-04 but passes "Major Risk": MPJ-04 is shut in. · All Three laterals pass near to MPJ-07: 350' to 285 away. Distance to Nearest Property · MPH-18 is 5,800 ft from the nearest Milne Point property line. Distance to Nearest Well Within Pool · MPH-18 is 285 ft from the nearest Schrader Bluff sand penetration in MPJ-07. 5 '- . DRILL & CO~LETION PROCEDURE Pre-Ria Operations 1 . The 20" conductor will be installed pre-rig. Drillina 16. 17. 18. Run whipstock and mill window for NB lateral. Drill 6-3/4" NB horizontal production hole. Retrieve whipstock. Run 4" x 5" sand-control screens and blank combination liner with a Swell Packer and Hook Hanaer. Run the upper LEM. Displace MOBM with Kill Weight Brine. RU and Run 2.875" ESP Completion. ND BOP/NU Tree Freeze Protect. Doyon 14. L 2, 19. 20. 21. 22. 23. 6 -18 " Lateral " 10-3/4",40.5#, K-55 & BTC 4477' MD, 3172' TVD MPH ...18 = 5900' MD MD MD . . - 6045' MD l·1: OA 4092' . TVD MD -1IIiIIIIIII--____.Ii\1I!IØIII._...._____________ I . -18 leti n K-55 & BTC 3172' TVD MPH..18 OB, NB Tri-lateral Produce TOL ::: 5900' MD MD .... l-1: - 4122' ----------------------------------------- ~- - ......-- -_IIIiØIIIItIi...... 15'40'59" ?i\r \1' -lllW- I I , I , l___________________________ ________., , , I I , I , I , I , I , I I , I I I I , I I I \ I I , I I I I , I I I I I , I I I I , , I I I I I I , , , H-14. H-13. )' :=~~: H-10. H-9. I .. H-18 .. H-17 1 .. H-16 Å H-15 30'(TYP)T T · H-4 · H-5 · H-3 · H-6 · H-2 · H-8 · H-1 · H-7 I I I I I I I I I I I I I I -----------------------------// MPU H-PAD LEGEND .. PROPOSED WELL CONDUCTOR . EXISTING WELL CONDUCTOR VICINITY MAP N.T.S. NOTES 1. ALASKA STATE PLANE COORDINATES (ASP.) ARE ZONE 4 ALASKA, NAD 27. 2. PAD SCALE FACTOR IS 0.99990364 3. HORIZONTAL CONTROL IS BASED ON MPU H-PAD MONUMENTS H-1 AND H-2 LOCA TED WITHIN PROTRACTED SECTION 34, T. 13 N., R. 10 E., 'UMIAT MERIDIAN, ALASKA WELL ASP. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS H-15 y= 6,010,091.44 N= 1,410.00 70'26'17.585" 70.4382181' N/A 2,940' FSL X= 556,633.18 E= 880.00 149"32'17.598" 149.5382217" 4,012' FEL H-16 Y= 6,010,120.32 N= 1,440.00 70"26'17.869" 70.4382969' N/A 2,969' FSL X= 556,641.29 E= 880.00 149'32'17.354" 149.5381538' 4,003' FEL H-17 y= 6,010,149.20 N= 1,470.00 70'26'18.152" 70.4383755' N/A 2,997' FSL X= 556,649.40 E= 880.00 149'32'17.109" 149.5380858' 3,995' FEL H-18 Y= 6,010,178.08 N= 1,500.00 70'26'18.436" 70.4384544- N/A 3,026' FSL X= 556,657.51 E= 880.00 149'32'16.865" 149.5380181" 3,987' FEL o 5 17 04 ISSUED FOR INFORMATION NO. DATE REVISION F. Robert ~ ~ ffi~~rna;o DRAWN; O'NEIL CHECKED: ALLISON DATE: 5-17-04 o bp sp EXPLORATION DRA'MNG: ~~B~¿ MPH 01-00 ' MILNE POINT UNIT H-PAD SCALE . PROPOSED CONDUCTOR l' = 150' WELLS MP H-15, H-16, H-17, H-18 UtO RFA BY CHK ENQHŒRS NIIJ LI<ICI SURIÆYORS 801111E5T f1ROIŒO lAHE NlCtiOA,+.Q£, ÞU.SK" H5O) SHEET: 1 or 1 MPH-18 MPH-18 Surface Location SURVEY PROGRAM Plan: MPH-!8 L2 Wp 2,0 (Plan MPH-!8IPlan MPH-!8 L2 Depth Fm Depth To Surr.'ey''P1æ!. Tool Created By: Digital Busmem> CIi-ent User Date: 6/3012004 6Oœ.01 862839 P'tanœd: MPH~t8 L2 Wp 2.0 V¡2 M\1Ir'D+IFR+MS Checked: Date:_ Reviewed: Date:_ - - - WELL DETAILS - ...... +W-S -og """'" Latitude Loogitude stoo Pl.imMPH~lg t1%.95 !261.65 601017&.08 556657.51 7íY'26'I8A36N 149"'32'16.865W NiA - - - ~ - SECTION DETAILS Sec MD Ino Azi TVIJ +NI-S +Ef-W DLeg IFac. VSec Target I 2 3 4 MPH-18L2T1 MidNB 5 6 7 MPH-18 L2 T2 Mid NB 8 9 10 MPH-IS L2 T3 Mid NB Ii 12 MPH-18 L2 T4 Mid NB 13 14 MPH-18 L2 T5 Mid NFl CASING DETAILS No. TVD IVID Name Size 3992.00 8628.39 4112" 4.500 FORMATION TOP DETAILS No. COMPANY DETAILS BPAI:OOOO me. A 1m l+C """ - - TARGET DETAILS Name TV!) +N/-S +EI-W Northing Basting Simp. 33 " :¡Æ '" '" r:::. "'" g- O .. Ë '" :> ~ SURVEY PROGRAM Plan: MPH~lg U Wp 2.0 (Plan MPH~lß!PhmMPH-18 L2) Depth Fm Depth Tu Survey/P1<m Tool 6009m 8628.39 P!anrn:d;l\-iPfMSL2Wp2J)VI MVi'D+tFR+MS ....NI..s +Fl~W Noofuing -. ~ Longi- SJ", - - - - - - 196.95 1261.65 6OIOJ18.û8 5566:5751 70"26'ISA3-6N 149"32'I6..86SW NlA - - - - - - gee MD Ine Azi TVD +NI·g +EI·W DLeg TFace VSec Target MPH·lg L2 Tl Mid NB MPH·lg L2 T2 Mid NB MPH-lg L2 T3 Mid NB MPH-lg L2 T4 Mid NB MPH·IgL2T5 MídNB - - Name TVD +NI.g +EI·W Northmg FORMATION TOP DETAILS No. TVDpath MDPath Formation 1 2 3 4 TVD 7ii ¡:¡ 8 :!1 +" f ~ :;:r 1;; " '" . . BP-GDB BP Planning Report . Company: Field: Site: WeD:: WeUpath: Plan: . BP Amoco Milne Point MptHPad Plan MPH-18 Plan MPH-18 L2 MPH-18 L2 Wp 2.0 Added T 3.5 Yes Date: 6130/2004 ... TIme: Co-ordinate(NE) Referenee: Vertkal (fVD) Reference: SeetiOIl (VS) Reference: Survey Calenlation Method: Date Composed: Version: Tied-to: Principal: Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Site: M pt H Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 6008971.91 ft 555404.91 ft Latitude: 70 26 Longitude: 149 32 North Reference: Grid Convergence: WeD: Plan MPH-18 Slot Name: Morpheus Well Position: +N/-S 1196.95 ft Northing: 6010178.08 ft Latitude: +EI-W 1261.65 ft Easting: 556657.51 ft Longitude: Position Uncertainty: 0.00 ft Alaska, Zone 4 Well Centre bggm2003 6.665 N 53.895 W True 0.43 deg 70 26 18.436 N 149 32 16.865 W Casing Points MD TVD Diameter ft ft ·in 8628.39 3992.00 4.500 Formations Name 6.000 4 1/2" 6020.15 6099.81 6155.59 8428.93 Targets TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3900.00 3930.00 3945.00 3990.00 0.00 0.00 0.00 0.00 Name MPH-18 Fault 1 -Polygon 1 -Polygon 2 -Polygon 3 MPH-18 Fault 2 -Polygon 1 -Polygon 2 -Polygon 3 MPH-18 Fault 3 -Polygon 1 . Lithology BPRF TUZC Ugnu-MA Ugnu-MB1 Ugnu-MB2 Ugnu-MC SBF2-NA SBF1-NB SBE4-NC SBE2-NE SBE1-NF TSBD-Top OA TSBC-Base OA TSBB-Top OB SBA5-Base OB 3972.00 3972.00 3972.00 3972.00 3533.86 -3750.13 6013683.00 552881.00 3533.86 -3750.13 6013683.00 552881.00 3175.91 -2710.72 6013333.00 553923.00 3156.77 -1638.73 6013322.00 554995.00 2979.59 -2671.21 6013137.00 553964.00 2979.59 -2671.21 6013137.00 553964.00 3972.00 3972.00 <,.....,. Latitude.--> Deg MiD See 70 26 47.038 N 70 26 47.038 N 70 26 43.354 N 70 26 39.839 N 70 26 53.181 N 70 26 53.181 N 70 26 49.665 N 70 26 49.480 N 70 26 47.735 N 70 26 47.735 N 149 34 25.265 W 149 34 25.265 W 149 3329.638 W 149 33 0.351 W 149 34 6.987 W 149 34 6.987 W 149 33 36.461 W 149 33 4.983 W 149 33 35.299 W 149 33 35.299 W . . BP-GDB BP Planning Report Company: BP Amoco Date: 613012004 Time: 13:58:32 Field: Milne Point C_rdlaate(NE) Reference: Site: MPtHPad Vertieal (TVD) Reference: WeD: Plan MPH-18 Section (VS) Reference: WeDpath: . Plan MPH-18 L2 Sarvey Calculation Method: Map Map Name Description TVD +N/-S +EI-W Northing Easting Dip. Dir. ft ft ft ft ft -Polygon 2 3972.00 2535.48 -2664.58 6012693.00 553974.00 70 26 43.367 N 149 33 35.099 W MPH-18 L2 T2 Mid NB 3977.00 3002.13 -3663.16 6013152.00 552972.00 70 26 47.952 N 149 34 4.425 W MPH-18 L2 T3 Mid NB 3977.00 3364.85 -4015.45 6013512.00 552617.00 70 26 51.518 N 149 34 14.775 W MPH-18 L2 T1 Mid NB 3982.00 2841.02 -3125.32 6012995.00 553511.00 70 26 46.370 N 149 33 48.631 W MPH-18 Geo Poly 3982.00 2841.02 -3125.32 6012995.00 553511.00 70 26 46.370 N 149 33 48.631 W -Polygon 1 3982.00 3190.63 -4120.79 6013337.00 552513.00 70 26 49.804 N 149 34 17.866 W -Polygon 2 3982.00 2973.22 -3807.40 6013122.00 552828.00 70 26 47.667 N 149 34 8.660 W -Polygon 3 3982.00 2790.14 -3404.74 6012942.00 553232.00 70 26 45.869 N 149 33 56.835 W -Polygon 4 3982.00 2576.70 -2561.25 6012735.00 554077.00 70 26 43.773 N 149 33 32.066 W -Polygon 5 3982.00 2954.59 -2540.38 6013113.00 554095.00 70 26 47.489 N 149 33 31.457 W -Polygon 6 3982.00 3022.54 -3321.96 6013175.00 553313.00 70 2648.155 N 149 33 54.407 W -Polygon 7 3982.00 3151.89 -3761.03 6013301.00 552873.00 70 26 49.425 N 149 34 7.301 W -Polygon 8 3982.00 3549.15 -3920.04 6013697.00 552711.00 70 26 53.331 N 149 34 11.976 W -Polygon 9 3982.00 4439.34 -3931.27 6014587.00 552693.00 70 27 2.086 N 149 34 12.320 W -Polygon 10 3982.00 4441.74 -4246.30 6014587.00 552378.00 70 27 2.107 N 149 34 21.572 W MPH-18 L2 T4 Mid NB 3987.00 3940.37 -4074.08 6014087.00 552554.00 70 26 57.178 N 149 34 16.506 W MPH-18 L2 T5 Mid NB 3992.00 4381.78 -4120.74 6014528.00 552504.00 70 27 1.518 N 149 34 17.883 W MPH-18 Fault 4 4167.00 3569.64 -4378.94 6013714.00 552252.00 70 26 53.530 N 149 34 25.452 W -Polygon 1 4167.00 3569.64 -4378.94 6013714.00 552252.00 70 26 53.530 N 149 34 25.452 W -Polygon 2 4167.00 3440.93 -3760.84 6013590.00 552871.00 70 26 52.267 N 149 34 7.300 W MPH-18 Fault 5 4172.00 3549.51 -3968.04 6013697.00 552663.00 70 26 53.334 N 149 34 13.386 W -Polygon 1 4172.00 3549.51 -3968.04 6013697.00 552663.00 70 26 53.334 N 149 34 13.386 W -Polygon 2 4172.00 4351.21 -4045.96 6014498.00 552579.00 70 27 1.218 N 149 34 15.687 W MPH-18 Fault 6 4192.00 4796.80 -4379.61 6014941.00 552242.00 70 27 5.599 N 149 34 25.493 W -Polygon 1 4192.00 4796.80 -4379.61 6014941.00 552242.00 70 27 5.599 N 149 34 25.493 W -Polygon 2 4192.00 4786.53 -3028.52 6014941.00 553593.00 70 27 5.504 N 149 33 45.812 W Plan Seetioa Information MD Inel JUim TVD +N/-S +EI-W DLS BIWd Tam DO ft deg deg ft ft ft dElg/100ft dElg/100ft deg/100ft dim 6009.07 62.50 280.30 3895.00 2790.00 -2628.00 0.00 0.00 0.00 0.00 6029.07 64.90 280.30 3903.86 2793.21 -2645.64 12.00 12.00 0.00 0.00 6238.31 85.08 274.55 3957.81 2818.70 -2844.98 10.00 9.65 -2.75 -16.22 6520.57 85.08 274.55 3982.00 2841.02 -3125.32 0.00 0.00 0.00 0.00 MPH-18 L2 T1 Mid NB 6668.77 91.34 288.00 3986.65 2869.94 -3270.17 10.00 4.22 9.08 65.38 7013.70 91.34 288.00 3978.61 2976.51 -3598.12 0.00 0.00 0.00 0.00 7083.66 91.30 295.00 3977.00 3002.13 -3663.16 10.00 -0.05 10.00 90.21 MPH-18 L2 T2 Mid NB 7272.77 90.03 313.87 3974.79 3108.58 -3818.41 10.00 -0.67 9.98 93.71 7333.97 90.03 313.87 3974.76 3150.99 -3862.53 0.00 0.00 0.00 0.00 7598.39 89.01 335.00 3977.00 3364.85 -4015.45 8.00 -0.39 7.99 92.82 MPH-18 L2 T3 Mid NB 7933.98 89.04 1.85 3982.82 3690.57 -4082.16 8.00 0.01 8.00 90.17 8183.94 89.04 1.85 3987.00 3940.37 -4074.08 0.00 0.00 0.00 0.00 MPH-18 L2 T4 Mid NB 8344.36 89.43 352.23 3989.15 4100.37 -4082.35 6.00 0.24 -6.00 -87.78 8628.39 89.43 352.23 3992.00 4381.78 -4120.74 0.00 0.00 0.00 0.00 MPH-18 L2 T5 Mid NB . . BP-GDB BP Planning Report 6009.07 62.50 280.30 3895.00 3823.00 2790.00 -2628.00 0.00 6012947.77 554008.64 Start Dir 12/10 6020.15 63.83 280.30 3900.00 3828.00 2791.77 -2637.72 12.00 6012949.46 553998.91 SBF1-NB 6025.00 64.41 280.30 3902.12 3830.12 2792.55 -2642.02 12.00 6012950.21 553994.60 MWD+IFR+MS 6029.07 64.90 280.30 3903.86 3831.86 2793.21 -2645.64 12.00 6012950.84 553990.98 Start Dir 10/10 6050.00 66.91 279.66 3912.41 3840.41 2796.52 -2664.46 10.00 6012954.00 553972.14 MWD+IFR+MS 6099.81 71.71 278.22 3930.00 3858.00 2803.75 -271Q.47 10.00 6012960.89 553926.08 SBE4-NC 6100.00 71.72 278.22 3930.06 3858.06 2803.78 -2710.65 10.00 6012960.91 553925.90 MWD+IFR+MS 6150.00 76.55 276.85 3943.72 3871.72 2810.07 -2758.32 10.00 6012966.85 553878.19 MWD+IFR+MS 6155.59 77.09 276.70 3945.00 3873.00 2810.71 -2763.73 10.00 6012967.45 553872.78 SBE2-NE 6200.00 81.38 275.54 3953.29 3881.29 2815.36 -2807.09 10.00 6012971.76 553829.38 MWD+IFR+MS 6238.31 85.08 274.55 3957.81 3885.81 2818.70 -2844.98 10.00 6012974.82 553791.48 End Dir : 6238 6300.00 85.08 274.55 3963.10 3891.10 2823.58 -2906.25 0.00 6012979.23 553730.17 MWD+IFR+MS 6400.00 85.08 274.55 3971.67 3899.67 2831.49 -3005.57 0.00 6012986.38 553630.81 MWD+IFR+MS 6500.00 85.08 274.55 3980.24 3908.24 2839.39 -3104.89 0.00 6012993.53 553531.44 MWD+IFR+MS 6520.57 85.08 274.55 3982.00 3910.00 2841.02 -3125.32 0.00 6012995.00 553511.00 MPH-18 L2 T1 Mi 6550.00 86.31 277.23 3984.21 3912.21 2844.03 -3154.50 10.00 6012997.79 553481.79 MWD+IFR+MS 6600.00 88.42 281.77 3986.50 3914.50 2852.28 -3203.75 10.00 6013005.66 553432.49 MWD+IFR+MS 6650.00 90.54 286.30 3986.96 3914.96 2864.40 -3252.24 10.00 6013017.42 553383.92 MWD+IFR+MS 6668.77 91.34 288.00 3986.65 3914.65 2869.94 -3270.17 10.00 6013022.81 553365.94 End Dir : 6668 6700.00 91.34 288.00 3985.92 3913.92 2879.59 -3299.86 0.00 6013032.24 553336.18 MWD+IFR+MS 6800.00 91.34 288.00 3983.59 3911.59 2910.48 -3394.94 0.00 6013062.41 553240.88 MWD+IFR+MS 6900.00 91.34 288.00 3981.26 3909.26 2941.38 -3490.02 0.00 6013092.58 553145.58 MWD+IFR+MS 7000.00 91.34 288.00 3978.93 3906.93 2972.28 -3585.10 0.00 6013122.75 553050.28 MWD+IFR+MS 7013.70 91.34 288.00 3978.61 3906.61 2976.51 -3598.12 0.00 6013126.88 553037.22 Start Dir 10/10 7050.00 91.32 291.63 3977.77 3905.77 2988.81 -3632.26 10.00 6013138.92 553003.00 MWD+IFR+MS 7083.66 91.30 295.00 3977.00 3905.00 3002.13 -3663.16 10.00 6013152.00 552972.00 MPH-18 L2 T2 M 7100.00 91.19 296.63 3976.64 3904.64 3009.24 -3677.87 10.00 6013159.00 552957.24 MWD+IFR+MS 7150.00 90.86 301.62 3975.75 3903.75 3033.57 -3721.52 10.00 6013182.99 552913.41 MWD+IFR+MS 7200.00 90.53 306.61 3975.14 3903.14 3061.60 -3762.90 10.00 6013210.71 552871.82 MWD+IFR+MS 7250.00 90.18 311.60 3974.83 3902.83 3093.12 -3801.69 10.00 6013241.94 552832.80 MWD+IFR+MS 7272.77 90.03 313.87 3974.79 3902.79 3108.58 -3818.41 10.00 6013257.26 552815.96 End Dir : 7272 7300.00 90.03 313.87 3974.77 3902.77 3127.45 -3838.04 0.00 6013275.98 552796.19 MWD+IFR+MS 7333.97 90.03 313.87 3974.76 3902.76 3150.99 -3862.53 0.00 6013299.33 552771.52 Start Dir 8/100 7350.00 89.97 315.15 3974.76 3902.76 3162.23 -3873.96 8.00 6013310.48 552760.01 MWD+IFR+MS 7400.00 89.77 319.15 3974.87 3902.87 3198.87 -3907.96 8.00 6013346.86 552725.74 MWD+IFR+MS 7450.00 89.57 323.14 3975.16 3903.16 3237.80 -3939.32 8.00 6013385.55 552694.08 MWD+IFR+MS 7500.00 89.38 327.14 3975.62 3903.62 3278.82 -3967.89 8.00 6013426.34 552665.20 MWD+IFR+MS 7550.00 89.19 331.13 3976.24 3904.24 3321.73 -3993.54 8.00 6013469.05 552639.24 MWD+IFR+MS 7598.39 89.01 335.00 3977.00 3905.00 3364.85 -4015.45 8.00 6013512.00 552617.00 MPH-18 L2 T3 M 7600.00 89.01 335.13 3977.03 3905.03 3366.31 -4016.13 8.00 6013513.46 552616.31 MWD+IFR+MS 7650.00 89.00 339.13 3977.90 3905.90 3412.37 -4035.55 8.00 6013559.36 552596.54 MWD+IFR+MS 7700.00 89.00 343.13 3978.77 3906.77 3459.66 -4051.72 8.00 6013606.53 552580.01 MWD+IFR+MS 7750.00 89.00 347.13 3979.65 3907.65 3507.97 -4064.55 8.00 6013654.73 552566.82 MWD+IFR+MS 7800.00 89.00 351.13 3980.52 3908.52 3557.06 -4073.97 8.00 6013703.74 552557.03 MWD+IFR+MS 7850.00 89.01 355.13 3981.39 3909.39 3606.68 -4079.95 8.00 6013753.31 552550.67 MWD+IFR+MS 7900.00 89.03 359.13 3982.24 3910.24 3656.60 -4082.45 8.00 6013803.21 552547.79 MWD+IFR+MS 7933.98 89.04 1.85 3982.82 3910.82 3690.57 -4082.16 8.00 6013837.17 552547.83 End Dir : 7933 8000.00 89.04 1.85 3983.92 3911.92 3756.55 -4080.02 0.00 6013903.16 552549.46 MWD+IFR+MS 8100.00 89.04 1.85 3985.59 3913.59 3856.48 -4076.79 0.00 6014003.11 552551.93 MWD+IFR+MS 8183.94 89.04 1.85 3987.00 3915.00 3940.37 -4074.08 0.00 6014087.00 552554.00 MPH-18 L2 T4 M 8200.00 89.08 0.89 3987.26 3915.26 3956.42 -4073.70 6.00 6014103.05 552554.26 MWD+IFR+MS 8250.00 89.20 357.89 3988.02 3916.02 4006.40 -4074.23 6.00 6014153.03 552553.35 MWD+IFR+MS 8300.00 89.32 354.89 3988.67 3916.67 4056.29 -4077.38 6.00 6014202.89 552549.83 MWD+IFR+MS . . BP-GDB BP Planning Report 89.43 352.23 3989.15 3917.15 4100.37 -4082.35 6.00 6014246.92 552544.52 End Dir : 8344 89.43 352.23 3989.71 3917.71 4155.50 -4089.87 0.00 6014301.98 552536.58 MWD+IFR+MS 8428.93 89.43 352.23 3990.00 3918.00 4184.16 -4093.78 0.00 6014330.62 552532.45 SBE1-NF 8500.00 89.43 352.23 3990.71 3918.71 4254.57 -4103.38 0.00 6014400.95 552522.32 MWD+IFR+MS 8600.00 89.43 352.23 3991.72 3919.72 4353.65 -4116.90 0.00 6014499.91 552508.05 MWD+IFR+MS 8628.00 89.43 352.23 3992.00 3920.00 4381.39 -4120.68 0.00 6014527.62 552504.06 Total Depth: 8 8628.39 89.43 352.23 3992.00 3920.00 4381.78 -4120.74 0.00 6014528.00 552504.00 MPH-18 L2 T5 M WELL DETAiLS N_ +W-S +£I-W Northíng """'" latitude Longitude SIo< P1anMPH~18 11965>$ 1261.65 6010118.08 55665731 70"'26'18.436N i49"32'16.ß65W NlA ANTl-cOLLISION SETTINGS COMPANY DETAILS SP Amoco Interval: 25.00 To: 8628.39 Reference: Plan: MPH-I8 L2 Wp 2.0 o From Colour o o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 o ~~gg 7000 8000 o to SURVEY PROGRAM Depth Fro Depth To SurveyfPlan 6009.07 8628.39 Planned: MPH~18 L2 Wp UJ Vl2 ToMD o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 8000 9000 Tool MWD+IFR+MS VlELLPA TH DETAILS Pian MPH-18 L2 12' Pre Plan 12.úOft 316>76>:>- 0.00 0.00 35.00 SECfiON DETAILS TVD +Nj·S +EJ·W !:>Leg TFace VSeç Target . BP-GDB Anticollision Report . Company: BP Amoco Date: 613012004 Time: 14:08:16 Page: 1 Field: Milne Point Reference Site: M Pt H Pad Co-ordinate(NE) Reference: Well: Plan MPH-18, True North Reference Well: Plan MPH-18 Vertical (fVD) Reference: 72' Pre Plan 72.0 Reference Wellpath: Plan MPH-18 L2 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: MPH-18 L2 Wp 2.0 & NOT PLANN Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 6009.00 to 8628.39 ft Sean Method: Trav Cylinder North Maximum Radius: 1059.34 ft Error Surface: Ellipse + Casing Casing Points MD TVD Diameter Hole Size Name ft ft in in 8628.39 3992.00 4.500 6.000 4 1/2" Plan: MPH-18 L2 Wp 2.0 Date Composed: 6/28/2004 Added T 3.5 Version: 12 Principal: Yes Tied-to: From: Definitive Path Summary <: Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ft ft ft ft ft M Pt G Pad MPG-G-17 MPG-17 V5 Out of range M Pt H Pad MPH-02 MPH-02 V1 Out of range M Pt H Pad MPH-03 MPH-03 V1 Out of range M pt H Pad MPH-04 MPH-04 V1 Out of range M pt H Pad MPH-05 MPH-05 V1 Out of range M Pt H Pad MPH-06 MPH-06 V1 Out of range M pt H Pad MPH-10 MPH-10 V9 Out of range M Pt H Pad MPH-11 MPH-11 V6 Out of range M Pt H Pad MPH-12 MPH-12 V2 Out of range M pt H Pad MPH-13 MPH-13 V4 Out of range M pt H Pad MPH-13 MPH-13A V4 Out of range M Pt H Pad MPH-14 MPH-14 V7 Out of range M pt H Pad Plan Chico Chico V2 Plan: Chico W Out of range M Pt H Pad Plan Groueho Groueho V1 Plan: Grouc Out of range M pt H Pad Plan Harpo Harpo V1 Plan: Harpo W Out of range M pt H Pad Plan MPH-18 Plan MPH-18 L 1 VO Plan 6024.99 6025.00 0.27 0.00 0.26 Pass: NOERRORS M Pt H Pad Plan MPH-18 Plan MPH-18 V2 Plan: W 6024.99 6025.00 0.27 0.00 0.26 Pass: NO ERRORS M pt H Pad Plan Neo (MPH-16) MPH-16 L 1 VO Plan: MPH Out of range M pt H Pad Plan Neo (MPH-16) MPH-16 V1 Plan: MPH-16 Out of range M Pt H Pad Plan Smith Smith V2 Plan: Smith W Out of range M pt H Pad Plan Trinity Trinity V1 Plan: Trini Out of range M pt I Pad MPI-04 MPI-04A V5 6424.59 6600.00 623.64 148.17 475.48 Pass: Major Risk M Pt I Pad MPI-04 MPI-04AL 1 V2 6016.37 7175.00 639.95 159.88 480.07 Pass: Major Risk M PtJ Pad MPJ-03 MPJ-03 V1 Out of range M PtJ Pad MPJ·04 MPJ-04 V1 Out of range M ptJ Pad MPJ-05 MPJ-05 V1 Out of range M pt J Pad MPJ-06 MPJ-06 V1 Out of range M PtJ Pad MPJ-07 MPJ-07 V1 8183.57 4050.00 .350.32 126.36 223.96 Pass: Major Risk M pt J Pad Plan MPJ-Persphone Plan MPJ-Persphone VO Out of range PRe N ¡ 149 32 00 149 MPU H",18L2 II (NB sand) . . PERMIT TO DRIll RECEIVED SEP 1 02004 ,Jas Cons. Commission '.\nchoraqe (e) If a well has mUIHp/e well branChes, each branch requires a separate Permit to Drill. If muffiple well branches are proPOsed from a single conductor, SUrface, or PrOduction casing, the apPlicant shall designale one branch as the primary \VeIlbore and include all Information required under (c) of this section with the appllcalion for a Permit to Drill for Ihat branch. For each SUbsequent Well branch, the apPlication for a Permit to Drill need only inclUde information Under (c) of this section that is unique to that branch and need not include the $100 fee. 20 Me 25.005 !p . . TRANSMJT AL LETTER CHECKLIST CIRCLE APPROPRJATELETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ø¡::?tr /!, /f ¿ 2- 2-CJt/.- /7~ PTD# ':b ¿1/~'ÝJnVKI- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL / (If API Dum ber last two (2) digits are between 60-69) "CLUE" Tbe permit is for a ne~ ]Vellbore segment of existing well PI r::~ H" /~ Permit No~"'''11t/" API No. ç¡p, () Z..e¡ -: 23 2.2 ~ ~ Productionsbould continue to be reported as a function of tbe original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for tbe pilot bole must be clearly differentiated in botb name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/] 0/02 C\jody\templates Tbe permit is approved subject ·to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes tbe liability of any protest to tbe spacing exception tbat may occur. An dry ditcb sample sets submitted to tbe Commission must be in no greatertban 30' sample intervals from below tbe permafrost or from wbere samples are first caugbt and ] 0' sample intervals tbrougb target zones. MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB H-18L2 Program DEV Well bore seg ~ ALASKA) INC nitial ClasslType DEV I PEND GeoArea 890 Unit 11328 ~ On/Off Shore On Annular Disposal 0 Administration fee attached - - - - NA · . Multilate(al. well~ fee waived per 20.AAC 25~Q05(e) . . . - - - - -- 2 .Lease .number appropriate. . - - - - - - .. - - - - - .Yes. · . . Multilateral. wen .segment Iocated. entirely jn. AQL. Q259Q6. - - - - - - . - - - - - 3 .U.nlque well.n.ame.and ou.mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - . - - - - - - - - -- 4 Wen located ina. d.efinedpool . - - - - - -- - - - - - .Yes. · . . MiJneP.oint Schrader Bluff Oil pool (525HO), gQverned by CO 47.7 - - - - - - 5 WeJlJoeated p(operdistance. from driJIing unitb.ound.ary. - - - - - - Yes. - - - - - - - - - - -- - - - -- - - - - - 6 Well IQcated proper .dlstance. from Qtber welJs. . . . - - - - .Yes · . CO iJ,77. speciúes.goveJnmenlaJ Qtr-Qtr-Qtr section; proposed well.conformsto thLsJeq.uiJeme.nt.. 7 .S.utficient acreag,e.available lndrilJiog, u.nit. . . . . . . .Yes. - - - - - - - - - - - - - - - - - - - - - - - - 8 Jf.deviated, js weJlbQre plat.incJuded . . . . . . . . . . - - - - Yes. - - - - - - - - 9 .Operator 0111)' affected party . - - - - - - - - -- Yes. - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - 10 .O-pe(ator bas.approprlate.bond LnJorce . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Yes. . - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ 11 Permit can be Lssu.ed witbout conservatiOI1 order. . . .Yes. - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - . Appr Date 12 Permit. ean be lssu.ed witbQut ad.minist(ativ:eapprovaJ . . . - - - - - . . .Yes. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 9/15/2004 13 Can permit be approved before 15-day wait Yes 14 Well Joc¡;¡ted withil1 area an.d.strata .authorized by.lojectioo Order # (putlO# incomments).(For NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 AJI weljswit!1LnJl4.mil.e.ar~a.of review ideot[fied (Fj)( seNj~well only). . . . . . . . . . . . . . . .NA . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 16 Pre-produ.ced injector; durat.iQnof pre--produçtioo tes~ than. 3 months (For.serviee well only) . NA. - - - -- - - - -- - - - -- 17 AÇMP.Fïl1djng .of Consistency.h.as bee.nj~sued. for.this project. . . NA · . Multilater.al. well.segm~nt. . - - - -- - - - - - - - - - - - - - - - -- Engineering 18 .Condu.etor stril1g.prQvided . . . . . - - - - - - - - - NA Con.ductor .set io motherbore - - - - - - - - - - - - - - - - - - -- 19 .S.urfacecasing.pJoteçt~ alLknown USDWs . - - - -- NA · All aquifers exempted,AOCFR 1iJ,7.:J Q21b)(3).. . - - - - -- - - - - - - 20 .CMT. vol adequ.ate.to circulate.o.ncood.uctor. & su.rfcsg . . . . . . . NA. . · . . Su.rface çaj)iJ1g set jn. motherbQre.. . - - - - - - 21 CMT. v.ol adequ.ate.to tie-inJQng .string to.surf csg. . . . . . . . No - - - - - - - - - - - - - - - - - - - - -- 22 CMTwil! coverall kQownpro.ductive OQrizon.s. . . . . . . No. . · . . Screened Un.er completiOl] planned.. . . . . - - - - - - - -- - - - - 23 .C.asing designs adeQuate for C,T, B&permafrJ)st. . · . . .Yes. - - - - - - - - - - - - -- - - - - - 24 Adequat.etan.kage.oJ reserve pit. . . . . Yes. · . . Rig js.equippe.d.with steel.pits.. NQ reserv:e.pjt-p!anoed, All waste to.approve.d.dispos.al wells.. . 25 Jfa.re-drill~ has.a. 10-403 fQr abandonme.nt beeo approved. . NA - - - - - - - - - - - - - - - - - - - - - - - - - -- 26 Adequate.wellbore separatjo.n.proposed. . . . . . . . . . . . . . . . . . . · . . .Yes. . · . . prOJJ:imLty analysis performe.d, Jrayeling c)'linder plot.iocJu.ded.. N~are.st wellbore [s.QA late(a! 96~ deeper, . . . . 27 Jf.divecter required, dQes it meet. reguJations. . . . . . - - - - - - · . . .NA. . · . . BOp will be inpJa.ce. . . . . - - - - - - - - - -- - - - - . Appr Date 28 DriUiog fluid. program schematic & equipJist.adequate. . - - - - - · . . .Yes. · . Maximum expected fOO'T1atiOI1 pressure.9,8EMW.. Ptanl1ed.MW to.l0,6.p-pg. - - - - -- - - - - - TEM 9/15/2004 29 .BPPEs. do they meet. reguJation . - - - -- - - - -- Yes. - - - - - - - - - - - - - - - - - ~(c 30 .B.OPEpress rating é\ppropriate;test to (put psig in.comments). · . . .Yes · . . MA.SP calculate.d.at 1685 psi, Pl.anl1e.dJest pressu(e.3.50Q psL . - - - - - - - - - - 31 .C.hokemanjfold compJies. w/API. RF'-53 (May 84). . . - - - - - Yes - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - -- 32 WQrk will OCCU( without.operation .shutdown. . . . . . .Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 .Is presence of H2S gas. probable. . . - - - - - - - - - - - - - - - No · tl2S is not.expe.cted.. Rigj~ equipped. wit!1.senso(s.and alarms, - - - - - - - - - - - - - -- 34 Mechan[calcoodillon Of wells within A08 verified (for. service welJ onJy) NA. - - - - - - - - -- - - - - - Geology 35 PeO'T1it can be issu.ed wfo. hydrogen. s.ul.fide meaSures. . .Yes · . .. perS\<ipCpYl1er. .BP. on9f1.4l04:. No H2$ kl10wn jn $c.hrader.BJu.ff.reseN.oirs at H-pa.d, . 36 .D.ata.preseoted on. potential overpres.sure .zones. . . . . . . . Yes. . · I;xpected reservojr -pre.ssu.re is9.8.ppg EMW; will.bedrilled with 1 Q.Q : 10~6 ppg .mud.. . . Appr Date 37 .SeLsmicanalysjs of shaJlow gaszooes. . . . . . · . . NA. - - - - - - - - - - - - - - - -- - - - -- - - - - SFD 9/14/2004 38 .Seabed .conditioo su.rvey .(if off-shore) . . . . NA - - - - - - - - -- - - - - - - - - - - - 39 . CQntaet l1amelphon.eJor.weekly progress.reports [exploratoryonlYl NA. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - Geologic ) Engineering Date Date Elevated reservoir pressure expected due to offset injection at J-Pad. Noted in Drilling Hazards & Contingeneies section. Commissioner: Date: Commissioner SFD O~1gim:~~ Sign~ By D.."N SEAMOUN·'· tit e Well H ¡story File APPENDIX Information of detailed nature that is not particularly gennane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infomlation, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. . Sperry-Sun Drilling Services LIS Scan Utility . e2ocf- (7 (t, $Revision: 3 $ LisLib $Revision: 4 $ Mon Nov 08 16:07:38 2004 Reel Header Service name...... ..... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/08 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............ ....UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. t! /;{ 1ð ~ Scientific Technical Services Tape Header Service name.. ......... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/08 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name....... ....... ..UNKNOWN Continuation Number.... ..01 Previous Tape Name.......UNKNOWN Comments.......... ..... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPH-18 L2 500292322461 B.P.Exploration (Alaska) Inc. Sperry-Sun Drilling Services 08-NOV-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003302792 C.A. DEMOSKI D. GREEN MWD RUN 2 MW0003302792 C.A. DEMOSKI D. GREEN MWD RUN 4 MW0003302792 C.A. DEMOSKI D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 10 MW0003302792 T. MCGUIRE E. VAUGHN MWD RUN 11 MW0003302792 T. MCGUIRE E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 34 13N 10E 3026 3987 MSL 0) 69.60 35.60 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING . BIT SIZE (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 114.0 4562.0 6072.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MPH-18 L2 EXITS FROM THE MPH-18 WELLBORE AT 6072'MD/3900'TVD. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUNS 2,4,11 COMPRISED DIRECTIONAL WITH DGR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). RUNS 8 & 11 ALSO INCLUDED AT-BIT INCLINATION (ABI). NO PROGRESS WAS MADE ON MWD RUN 3 DUE TO TOOL FAILURE. THE PURPOSE OF MWD RUN 10 WAS TO POSITION THE WHIPSTOCK AND MILL THE WINDOW. ONLY SROP DATA ARE PRESENTED. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 10/20/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. LATERAL WELLBORES WERE SHIFTED/CORRECTED TO THE MAIN MPH-18 WELLBORE, IF APPROPRIATE. 7. MWD RUNS 1,2,4,10,11 REPRESENT WELL MPH-18 L2 WITH API#: 50-029-23224-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8630'MD/3986'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name........... ..STSLIB.OOl Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation.. .... .04/11/08 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ . 1 . and clipped curves; all bit runs merged. .5000 START DEPTH 69.5 114.5 4529.0 4529.0 4529.0 4529.0 4529.0 STOP DEPTH 8570.5 8627.0 8578.0 8578.0 8578.0 8578.0 8578.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 4 10 11 MERGED MAIN PASS. $ MERGE TOP 69.5 4573.0 4901. 0 6072.0 6095.0 MERGE BASE 4573.0 4901.0 6072 .0 6095.0 8627.0 # 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 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 8627 4348.25 17116 69.5 8627 ROP MWD FT/H 0.79 3103.94 218.471 17026 114.5 8627 GR MWD API 17.56 123.12 59.7042 17003 69.5 8570.5 RPX MWD OHMM 1. 95 2000 34.9612 8099 4529 8578 RPS MWD OHMM 0.17 2000 44.7888 8099 4529 8578 RPM MWD OHMM 0.14 2000 65.147 8099 4529 8578 RPD MWD OHMM 1. 03 2000 73.107 8099 4529 8578 . FET MWD HOUR 0.09 46.62 1.2796 8099 . 4529 8578 First Reading For Entire File........ ..69.5 Last Reading For Entire File....... ....8627 File Trailer Service name. ........... .STSLIB.001 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation..... ..04/11/08 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...... .04/11/08 Maximum Physical Record. .65535 File Type. .... .......... .LO Previous File Name..... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 69.5 114.5 STOP DEPTH 4527.5 4573.0 # 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: 26-SEP-04 Insite 66.37 Memory 4573.0 114.0 4573.0 .0 64.0 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 061497 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 .0 # BOREHOLE CONDITIONS MUD TYPE: SPUD MUD . MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction........ ...... ...Down Optical log depth units... ........Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.. .................. ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD010 GR MWD010 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 9.20 135.0 9.0 320 9.8 . .000 .000 .000 .000 .0 86.0 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 69.5 4573 2321.25 9008 69.5 4573 ROP MWD010 FT/H 0.79 1244.58 199.654 8918 114.5 4573 GR MWD010 API 21. 59 123.12 67.833 8917 69.5 4527.5 First Reading For Entire File....... ...69.5 Last Reading For Entire File........ ...4573 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/08 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...... .04/11/08 Maximum Physical Record. .65535 File Type... ...... ..... ..LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 3 . header data for each bit run in separate files. 2 .5000 START DEPTH 4528.0 4529.0 4529.0 4529.0 4529.0 4529.0 4573.5 STOP DEPTH 4864.0 4855.0 4855.0 4855.0 4855.0 4856.0 4901. 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): 28-SEP-04 Insite 66.37 Memory 4901.0 4573.0 4901.0 62.6 63.0 TOOL NUMBER 149205 145654 9.875 4562.0 LSND 9.60 48.0 8.0 300 8.4 3.500 2.810 2.900 3.300 65.0 82.5 65.0 65.0 . . EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units......... ..Feet Data Reference Point............. . Undefined Frame Spacing.......... ......... ..60 .1IN Max frames per record........ .... . Undefined Absent value. ................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4528 4901 4714 . 5 747 4528 4901 ROP MWD020 FT/H 13 .37 968.56 350.377 656 4573.5 4901 GR MWD020 API 34.98 102.9 70.4438 673 4528 4864 RPX MWD020 OHMM 2.37 15.49 6.73436 653 4529 4855 RPS MWD020 OHMM 0.17 18.89 7.31265 653 4529 4855 RPM MWD020 OHMM 0.14 2000 22.5094 653 4529 4855 RPD MWD020 OHMM 1. 03 2000 118.846 653 4529 4855 FET MWD020 HOUR 0.09 46.62 6.64023 655 4529 4856 First Reading For Entire File......... .4528 Last Reading For Entire File.......... .4901 File Trailer Service name.... ....... ..STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/08 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.. .....04/11/08 Maximum Physical Record. .65535 File Type.... .......... ..LO Previous File Name.......STSLIB.003 Comment Record . FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 4855.5 4855.5 4855.5 4855.5 4856.5 4864.5 4901. 5 STOP DEPTH 6072.0 6072.0 6072 .0 6072.0 6072.0 6072.0 6071.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO 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 30-SEP-04 Insite 66.37 Memory 6072.0 4901.0 6072.0 60.1 80.6 TOOL NUMBER 124724 145654 9.875 4562.0 LSND 10.00 54.0 8.3 560 6.2 3.500 2.160 2.800 3.200 66.0 111.1 66.0 66.0 . 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 . Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 4855.5 6072 5463.75 2434l 4855.5 6072 ROP MWD040 FT/H 12.78 3103.94 269.566 2341 4901.5 6071.5 GR MWD040 API 22.07 112.62 60.6356 2416 4864.5 6072 RPX MWD040 OHMM 1. 95 50.4 10.3165 2434 4855.5 6072 RPS MWD040 OHMM 1. 94 52.51 10.9723 2434, 4855.5 6072 RPM MWD040 OHMM 1. 93 44.73 11.0775 2434, 4855.5 6072 RPD MWD040 OHMM 2.04 39.34 11.2463 2434, 4855.5 6072 FET MWD040 HOUR 0.12 22.17 1. 14433 2432 4856.5 6072 First Reading For Entire File........ ..4855.5 Last Reading For Entire File....... ....6072 File Trailer Service name.. ......... ..STSLIB.004 Service Sub Level Name... Version Number...... .....1.0.0 Date of Generation.... ...04/11/08 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name.. ......... ..STSLIB.005 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation... ....04/11/08 Maximum Physical Record..65535 File Type............... .LO Previous File Name..... ..STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # 5 header data for each bit run in separate files. 10 .5000 . FILE SUMMARY VENDOR TOOL CODE START DEPTH ROP 6072.0 $ STOP DEPTH 6095.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........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...O . 08-0CT-04 Insite 66.37 Memory 6095.0 6072.0 6095.0 60.1 61.3 TOOL NUMBER 13.500 6072.0 Versa Pro 10.00 68.0 .0 41000 .0 .000 .000 .000 .000 .0 86.0 .0 .0 Name Service Order DEPT ROP MWD100 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 . Name Service Unit DEPT FT ROP MWD100 FT/H Min 6072 0.87 Max 6095 23.35 Mean 6083.5 11.2883 First Reading For Entire File..... .... .6072 Last Reading For Entire File.... ...... .6095 File Trailer Service name........ .....STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/08 Maximum Physical Record..65535 File Type............ ....LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 service Sub Level Name... Version Number. ........ ..1.0.0 Date of Generation.......04/11/08 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS RPX GR FET ROP $ 6 Nsam 47 47 . First Reading 6072 6072 Last Reading 6095 6095 header data for each bit run in separate files. 11 .5000 START DEPTH 6072.5 6072.5 6072.5 6072 .5 6072 .5 6072 .5 6095.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE STOP DEPTH 8578.0 8578.0 8578.0 8578.0 8570.5 8578.0 8627.0 09-0CT-04 Insite 66.37 Memory 8630.0 6095.0 8630.0 65.0 96.4 TOOL NUMBER DGR EWR4 $ . 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.....O Logging Direction..... ............Down Optical log depth units...... .....Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value....... . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 62456 130910 . 13.500 6072.0 Versa Pro 10.00 68.0 .0 39000 .0 .000 .000 .000 .000 .0 104.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 11 0 FT/H 4 1 68 4 2 GR MWD 11 0 API 4 1 68 8 3 RPX MWD110 OHMM 4 1 68 12 4 RPS MWD110 OHMM 4 1 68 16 5 RPM MWD110 OHMM 4 1 68 20 6 RPD MWD110 OHMM 4 1 68 24 7 FET MWD11 0 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6072.5 8627 7349.75 5110 6072.5 8627 ROP MWD110 FT/H 4.72 670.63 212.824 5064 6095.5 8627 GR MWD110 API 17.56 106.46 43.3017 4997 6072.5 8570.5 RPX MWD110 OHMM 2.96 2000 50.6072 5012 6072.5 8578 RPS MWD110 OHMM 3.08 2000 66.0939 5012 6072.5 8578 RPM MWD110 OHMM 3.15 2000 96.9602 5012 6072.5 8578 RPD MWD110 OHMM 1. 99 2000 97.1894 5012 6072.5 8578 FET MWD 11 0 HOUR 0.19 15.93 0.644681 5012 6072.5 8578 . First Reading For Entire File....... ...6072.5 Last Reading For Entire File...... .....8627 . File Trailer Service name........... ..STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/11/08 Maximum Physical Record..65535 File Type................ LO Next File Name......... ..STSLIB.007 Physical EOF Tape Trailer Service name....... .... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/11/08 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. . . . . . . . . . . . . . . . . . . . .04/11/08 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