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Home My WebLink About201-138Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 12/21/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU I-11L1 (PTD 201-138) Multi Finger Caliper Log 11/15/2020 Please include current contact information if different from above. PTD: 2011380 E-Set: 34446 Received by the AOGCC 12/22/2020 Abby Bell 12/23/2020 ~~-~~~~ ~,, , ~ 2~ qq STATE OF ALASKA ~YA~ OIL AND GAS CONSERVATION COM ISSION Alaska °~ :<~s t;or~F.d~I~di nOF SUNDRY WELL OPERATIONS ~ri:itOfaae ~~ ~ /6~~9 1. Operations Performed: ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ®Other " ^ Change Approved Program ^ Operation Shutdown Jet Pump Conversion ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development - ^ Exploratory 201-138 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23033-60-00 . 7. KB Elevation (ft): 63.55' " 9. Well Name and Number: MPI-11 L1 - 8. Property Designation: 10. Field /Pool(s): ADL 025517 " Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 13190, feet true vertical 3557 ~ feet Plugs (measured) None Effective depth: measured 13170 feet Junk (measured) None true vertical 3557 - feet Casing Length Size MD TVD Burst Collapse Structural Conductor 72' 20" 101' 101' 1530 520 Surface 2702' 10-3/4" 2730' 2278' 5210 2480 Intermediate Production 10316' 7" 10345' 3596' 7240 5410 Liner 2788' 4-1/2" 10336' - 13124' 3594' - 35 60' 8430 7500 ` ~ ~ l ~ t ~' ~5 ~6 ~~ ~} `~ .' ~ U 4 S' . . 0 . ~ Perforation Depth MD (ft): Slotted Liner 10406' - 13079' Perforation Depth TVD (ft): Slotted Liner 3608' - 3562' 4-1/2", 12.6# L-80 10296' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker S-3 Packer 10209' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 400 0 Subsequent to operation: 138 31 0 1853 263 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®"Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or WA if C.O. Exempt: Contact Aras Worthington, 564-4102 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By Name/Number atur Phone -4750 Date _ ondra Stewman 564-4750 Form 10-404 Revised 04/2006 ~ ~~'"k ~ (~ ~~C~ Submit riginal Only ~~ ~ ~K~ Tree: 4 1/16" - 5M CIW Wellhead: 11" 5M Gen 5 w/ 6" -11 Tubing Hanger TC-II T&B threads - ~--~ with CIW "H" BPV profile 20", 92 #/ft H-40 Welded 112' Max well bore Angle: 84° @ 4994' MD + 60° past 2554' MD Hole angle trough perfs = 90°+ 10.75", 45.5#/ft BTC L-80 2730' 4.5" 12.6# L-80 IBT-M tubing (ID = 3.958", cap = .0152 BPF) 7" 26 ppf, L-80, BTC-mod production casing (drift ID = 6.151 ", cap. = 0.0383 bpf) (Capacity with 4.5" tbg = 0.0186 bpf) KOP @ 300 ' Or' F Elev. = 64.12' (Nabors 22-E) Or~L. Elev. = 35.10' (Nabors 22E) "Reverse Circulation" Jet Pump Configuration I I al I HES 3.813" "XD" Dura sliding sleeve I Pr~~~~~~J Fi~i~ ~ ;I 0 0 (Opens down) 10118` ~ ~ ~ : i i [; a l I ~ ' I I r " ~ ~~I - 4.5" SLB'NDPG' Gauge Mandrel 10142` , i ~ ~ ~ ~~ I I ~_ . (3.879 ID) (3547' tvd) N Baker 7" x 4.5" S-3 Pkr 3.875" ID 10209` ~ HES 3.813" XN-Nipple 10232' Reservoir Fluid (3.725" No GO ID) WLEG btm 10296' Baker Hook Wall Hanger above 7" Window 10336' Baker Hook Wall Hanger below 7" Window" 10345' Baker Down Swivel-up lock sub 10360' 6 118" Hole TD @ 13190' Window in 7" Casing @ 6508` - 6520' " Well Angle @ window = 76° Slotted Liner OA Lateral 66 jts - 4 1/2 ' ' - 12999 ) 12.6# L-80 IBT (10406 Baker Tie Back Sleeve 7028` Baker. 4 1/2" Packoff Bushing 13079' ' " Baker ZXP Liner Top Packer 10567' Guide Shoe 13124 Baker 4 1/2 Baker 7" x 5" HMC Liner Hanger 10582' 7" Halliburton Float Collar 10665' 6 1/8" Hole TD @ 13170' 7" Halliburton Ream Shoe 10747' OB Lateral 61 jts - 4 1/2", 12.6#/ft. Slotted Liner ' ) 12.6# L-80 IBT (10761'-13125 Baker 4 1/2" Packotf Bushing 13125' Baker 4 1/2" Guide Shoe 13170' DATE REV. BY COMMENTS MILNE POINT UNIT Nabors 22E Drill Multilateral & WELL I-11 10/6/01 GMH ESP Completion 12/06/01 M. Linder RWO Nabor 4-ES API NO: 50-029-23033 API NO: 50-029-23033-60 L1 2/2/09 L Hulme Conversion to Jet Pump N-3ES . BP EXPLORATION (AKA • C~ BP AMOCO Page 1 of 5 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 2/6/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/21/2009 Rig Name: NABOBS 3S Rig Number: N3S Date From - To 'Hours Task Code NPT Phase Description of Operations 2/13/2009 11:00 - 20:00 9.00 RIGD C PRE Wait on pad prep and site prep around well slot MPI-11 due to last minute change from Milne Point Management in Anchorage on new location for the Rig. Hold safety focus meeting with day crew since it is their first day back on the Slope. Perform pad prep on MPI-Pad for the Rig and Camp. 20:00 - 00:00 4.00 MOB P PRE Trucks on location. Hold PJSM with crews. Connect trucks to camp and modules. Call pad-op to witness moving carrier off well slot. Sign off permits and post rig. Move carrier and modules from C-43 to I-11. Notify Milne Pt. security of move. Call heavy equipment to blade drifts between C-pad access road and I-pad. 2/14/2009 00:00 - 01:00 1.00 MOB P PRE Continue moving rig from C-43 to I-11. 01:00 - 12:00 11.00 RIGU P PRE Lay mats around well, lay down herculite. Set BOPE, tree and kill manifold behind well. Spot carrier over well slot with pad-op witness. Set mats for pipe shed and pit mod. Set camp on edge of pad. Raise and scope the Derrick at 0900 hrs. The Rig was accepted at 1200 hrs on 02/14/2009. 12:00 - 16:00 4.00 KILL P DECOMP Start RU of circulating lines to the Kill Manifold and Tree. Spot the Upright Tank and Little Red. Spot and hook up lines to the Tiger Tank. Re-install pallet lift on mud pits complex. Take on heated, 140 degF seawater to the Pits. 16:00 - 17:00 1.00 WHSUR P DECOMP RU Lubricator to the Tree with Well Support Techs. Pressure test to 500 psi. Pull 2-1/2" Type "H" BPV. OA = 200 psi. 17:00 - 19:30 2.50 KILL P DECOMP Pressure test surface lines to 2000 psi. Pressure test downstream line to the Tiger Tank to 500 psi. 19:30 - 20:30 1.00 KILL P DECOMP Initial pressures on wellhead: TBG = 110 psi, IA = 420 psi, OA = 140 psi. Bleed IA thru choke to Tiger tank from 420 psi to 70 psi, tubing pressure fell from 110 psi to 40 psi during bleed. Break circulation at 2 BPM / 260 psi and circulate 70 bbls the long way. Circulate thru choke to Tiger tank, returns are gas and crude. FCP is 3.5 BPM / 850 psi. Returned 36 bbls to Tiger tank, 51 % returns. 20:30 - 21:30 1.00 KILL P DECOMP Bullhead 150 bbls down tubing into formation at 3.5 BPM / 1470 psi. Monitor well for 15 min, tubing fell to 350 psi and IA fell to 400 psi in that time period. 21:30 - 00:00 2.50 KILL P DECOMP Open well and break circulation at 2 BPM / 420 psi down the tubing taking returns thru the choke to Tiger tank. Circulate 515 bbls at 3.5 BPM / 920 psi. Circulation returns were gas and heavy crude throughout. Fluid cleaned up to weigh 8.5 ppg in returns. Returned 475 bbls to Tiger tank, 81 % returns. 2/15/2009 00:00 - 02:00 2.00 KILL P DECOMP Monitor well for 30 min. Tubing and IA stabalized at 130 psi. Calculated kill weight fluid off surface pressure + 100 psi overbalance to equal 9.66 ppg. Order 3 trucks of 9.8 ppg brine from MI mud plant. Blow down lines and monitor well. 02:00 - 06:00 4.00 KILL P DECOMP Wait on trucks and monitor well. Evacuate all fluids from Tiger tank with vac trucks. 1st 9.8 ppg brine truck on location at 03:30 hrs, load pits. Second truck on location at 05:00 hrs. Continue to wait on 3rd truck. 06:00 - 06:30 0.50 KILL P DECOMP Pre-tour checks and service the Rig. The Tubing pressure has fallen to slight amount of blowing but not enough to register on the gauge, the IA is at 20 psi and the OA is at 120 psi. 06:30 - 07:30 1.00 KILL P DECOMP Continue waiting on the third truck to arrive. It broke down on the road and they are sending another one to take on its load Printed: 3/6/2009 1:42:20 PM • BP AMOCO Page 2 of 5 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 2/6/2009 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/21/2009 Rig Name: NABOBS 3S Rig Number: N3S Date I From - To Hours Task Code NPT Phase Description of Operations 2/15/2009 06:30 - 07:30 1.00 I KILL P 07:30 - 08:30 I 1.001 KILL I P 08:30 - 12:00 I 3.501 KILL I P 12:00 - 12:30 I 0.501 KILL I P 12:30 - 13:00 I 0.501 KILL I P 13:00 - 13:30 0.50 W HSU R P 13:30 - 15:00 ~ 1.501 WHSUR ~ P 15:00 - 15:30 ~ 0.50 ~ WHSUR ~ P 15:30-17:00 ~ 1.50~WHSUR~P 17:00 - 22:00 5.00 BOPSU P 22:00 - 00:00 2.00 BOPSU P 2/16/2009 ~ 00:00 - 03:00 ~ 3.00 ~ BOPSU Fj P 03:00 - 04:00 I 1.001 BOPSUR P 04:00 - 06:00 I 2.001 BOPSUR P 06:00 - 07:00 I 1.001 PULL I P DECOMP and come to location. Third truck arrives on location at 0730 hrs. DECOMP Hold pre-kill safety meeting and blow air through all lines to ensure clear and properly lined up. DECOMP Initial WHPs of Tubing = 10 psi , IA = 30 psi , OA = 120 psi. Break circulation down the Tubing with 9.8 ppg brine taking returns up the IA, through the Choke to the Tiger Tank. Circulate 70 bbls with full returns at a rate of 4 bpm / 930 psi and 60 psi on the IA. Close the Choke and bullhead 150 bbls of 9.8 ppg brine down the Tubing at a rate of 3 bpm / 1,100 psi with the IA rising up to 750 psi. Open the Choke and resume circulating the long way with 9.8 ppg brine at a rate of 4 bpm with final pressures of 1,200 psi on the Tubing and 70 psi on the IA. Weight of fluid in = 9.7 ppg heavy and weight of returns 9.6 ppg heavy. Circulated 385 bbls. Total losses for the whole kill were 170 bbls (150 bbls of which were the bullhead). Circulated a total of 455 bbls with 435 bbls of returns in the Tiger Tank = 95% returns. DECOMP Monitor the well for 30 minutes. Both the Tubing and IA are on a vacuum. DECOMP Blow down lines and RD circulating equipment. Finish emptying out Tiger Tank. DECOMP PU T-bar and set 2-1/2" Type "H" TWC with FMC rep. RU Test Equipment. DECOMP Pressure test TWC from above to 3,500 psi for 10 charted mins. Line up and pressure test from below with Little Red Services at a rate of 4-1/2 bpm / 600 psi for 10 mins. Pumped a total of 55 bbls. DECOMP Bleed pressure off the IA. IA on a vac. Blow down and RD Test Equipment. DECOMP Remove Kill Manifold from the Cellar. ND 2-9/16" Tree and Adapter Flange with FMC rep. Screw in 2-7/8" EUE 8rd pup and get 7-3/4 turns. Threads are OK. Break apart Tree and Adapter Flange and remove both from the Cellar. Attempt to fill IA but taking pressure to do so. Monitor and it is on a vacuum. DECOMP PJSM. Pull BOPE into cellar. NU BOPE. DECOMP Test BOPE 250 psi low / 3,500 psi high as per state and BP regulation. Test witnessed by NAD Tourpusher and BP WSL. AOGCC rep Chuck Sheave waived the state's right to witness at 6:40 hrs on 2-15-09. Tested 2-7/8" x 5" VBR with 4-1/2" test joint. DECOMP Continue BOPE test. Test 2-7/8" test joint in 2-7/8" x 5" VBR. Complete Koomey draw down test. Gravity fed 53 bbls to backside throughout test at 20 BPH. DECOMP Suck out stack. LD test joint and clear rig floor. RD Little Red from IA, blow down all surface lines. IA on vacuum. DECOMP PUMU Opso-Lopso, XO and lo-torque. Screw into Hanger profile with 7-3/4 turns. MU lubricator and pressure test to 500 psi. Pull TWC. Tubing and IA on vacuum. LD lubricator, lo-torque and Opso-Lopso. DECOMP Pick up and make up 2-7/8" EUE 8rd Landing Joint and TIW valve. Screw into the Hanger with 7-3/4 turns. BOLDS with Printed: 3/6/2009 1:42:20 PM • BP AMOCO Page 3 of 5 Operations Summary Report Legal Well Name: MPI-11 Common W Event Nam Contractor Rig Name: Date ell Name: e: Name: From - To MPI-11 WORKO NABOB NABOB Hours ' VER S ALASK S 3S Task A DRI Code LLING NPT Start I Rig Rig Phase Spud Date: 9/8/2001 : 2/6/2009 End: Release: 2/21/2009 Number: N3S Description of Operations 2/16/2009 06:00 - 07:00 1.00 PULL P DECOMP FMC rep. Check the IA through the 2" valve and it is on a vacuum. 07:00 - 07:30 0.50 PULL P DECOMP Pull the Hanger off seat and to the floor with a PUW = 45K. Fill the backside and visually observe the fluid level dropping. 07:30 - 09:30 2.00 PULL P DECOMP Circulate surface to surface with 9.8 ppg brine at a rate of 4 bpm / 1,000 psi. It took 8 bbls to get returns. Losing 11 bbls every 15 minutes for hourly loss rate of 44 bbls per hour (18% losses). RU Elephant Trunk and containment to the Spooler. Pumped a total of 465 bbls with crude in returns. Shut down and monitor. The fluid level is visibly dropping. 09:30 - 10:30 1.00 PULL P DECOMP RD circulation equipment and blow down. Pull Hanger to the Floor and observe that the ESP Cable was not plugged into the Penetrator. It had fallen out of its connection on the underside of the Hanger. Remove Penetrator with Centrilift rep. String PUW = 45K ,SOW = 20K. Break out and lay down Hanger. 10:30 - 11:30 1.00 PULL P DECOMP RU 2-7/8" Handling Equipment. Prepare floor for pulling out of the hole. Snake rope over Sheave and tie off to Spooler. 11:30 - 22:00 10.50 PULL P DECOMP POOH with existing ESP Completion standing back 2-7/8" Tubing in the Derrick. Maintain continuous hole fill with 9.8 ppg brine with losses approx at 22 bbls per hour. Visually inspecting each Joint as POOH. 140 stands out at 2200 hrs. 22:00 - 23:00 1.00 PULL P DECOMP Swap spools in spooling unit. Tie ESP cable to spool. Pump across top of hole, loss rate = 20 BPH. 23:00 - 00:00 1.00 PULL P DECOMP Continue POH with ESP completion. Pump across top of hole, loss rate = 22 BPH. 2/17/2009 00:00 - 01:00 1.00 PULL P DECOMP Continue to POH with 2-7/8" tubing standing back in Derrick. Pump across top of hole, loss rate = 22 BPH. Pulled a total of 321 joints of 2-7/8" tubing, 2 GLM assemblies, 169 LaSalle clamps, 7 protectalizers, and 3 flat guards. 01:00 - 04:00 3.00 PULL P DECOMP LD ESP assembly as per Centrilift rep. 04:00 - 06:00 2.00 PULL P DECOMP Clean and clear rig floor of ESP tools and equipment. LD 2 bad joints from string. 06:00 - 06:30 0.50 EVAL P DECOMP Pre-tour checks and service the Rig. 06:30 - 07:30 1.00 EVAL P DECOMP PUMU BHA #1 with Baker rep as follows: 6" Bit, 7" Casing Scraper, Boot Basket, Boot Basket, Bit Sub. OAL = 13.99'. 07:30 - 14:30 7.00 EVAL P DECOMP TIH with BHA #1 on 2-7/8" Tubing from the Derrick. Maintain continuous hole fill with 9.8 ppg brine while TIH. 14:30 - 17:30 3.00 EVAL P DECOMP Reciprocate scraper across interval, 10200' - 10300'. Circulate surface to surface @ 4 BPM / 1030 psi. Circulated 357 bbls and lost 40 bbls on circulation. 17:30 - 00:00 6.50 EVAL P DECOMP PJSM. POH with 2-7/8" tubing standing back in Derrick. 2/18/2009 00:00 - 01:30 1.50 EVAL P DECOMP BOLD 7" scraper/bit assembly as per Baker fishing rep, junk baskets empty. Clean and clear rig floor. 01:30 - 10:30 9.00 EVAL P DECOMP PJSM. PUMU 7" RTTS as per Halliburton rep. RIH with RTTS on 2-7/8" tubing out of Derrick. Pump across top of hole, loss rate = 14.5 BPH. 10:30 - 13:00 2.50 EVAL P DECOMP MU TIW valve. Set RTTS C~ 10296' w/ 18K down. (Tbg free in elevators). Unable to pressure up on Csg. (suspect problem with packer bypass) Repeat at 10280' / 10260' unsuccessful pressure test. Set RTTS ~ 10252', work torque and close bypass. Test Csg to 3500 psi for 30 charted minutes. Unseat RTTS, maintain well control by pumping across the top. 13:00 - 16:00 3.00 EVAL P DECOMP Rig down ESP shieve, elephant trunk, and drain hose from Printed: 3/6/2009 1:42:20 PM • BP AMOCO Operations Summary Report Legal Well Name: ,Common Well Name Event Name: Contractor Name: Rig Name: Page 4 of 5 ~ MPI-11 MPI-11 Spud Date: 9/8/2001 WORKOVER Start: 2/6/2009 End: NABOBS ALASKA DRILLING I Rig Release: 2/21/2009 NABOBS 35 Rig Number: N3S Date I From - To I Hours I Task Code 2/18/2009 13:00 - 16:00 3.00 EVAL P 16:00 - 00:00 8.00 EVAL P 12/19/2009 100:00 - 02:00 I 2.001 EVAL I P 02:00 - 02:30 0.50 EVAL P 02:30 - 06:00 3.50 BUNCO P 06:00 - 08:00 2.00 08:00 - 11:00 3.00 11:00 - 00:00 I 13.00 2/20/2009 100:00 - 03:00 I 3.00 03:00 - 17:00 I 14.00 17:00 - 19:30 I 2.50 19:30 - 20:30 I 1.00 20:30 - 22:00 I 1.50 22:00 - 23:00 I 1.00 23:00 - 00:00 I 1.00 2/21 /2009 100:00 - 01:30 I 1.50 01:30 - 07:30 I 6.00 07:30 - 10:30 I 3.00 NPT ~I Phase ~! Description of Operations DECOMP Derrick. RU stabbing board. DECOMP POH laying dowry 2-7/8" tubing. Losses ~ 15 Bbls / Hr. 255 joints out at 24:00 hrs. DECOMP Continue to LD 2-7/8" tubing. Fluid loss rate = 15 BPH. Called out SLB and Baker completions. LD total of 329 joints. DECOMP LD 7" RTTS and set in pickup. Clear rig floor. RUNCMP RU torque turn equipment, single joint elevators, compensator and YC elevators. RUNCMP Load SLB I wire spooler to rig floor, instal shieve in derrick. Inspect completion equipment. PJSM RUNCMP PUMU 4-1/2"jet pump completion assembly. WLEG, XN w/ RHC-M Plug, Baker S-3 packer, SLB SPM gauge, HES XD Duro Sliding Sleeve. Pressure test SPM wire to 5000 psi. RUNCMP RIH with 4-1/2", 12.6#, L-80, NSCT tubing. Pumping 9.8 #/gal brine across the top with losses of - 13 Bbls/Hr. Each joint weight compensated, and connections inspected and torque turned to 3975 ft-Ibs. SLB checking conductivity of I-Wire every 1000'. Install 1 ea Cannon clamp on first 10 jts and then 1 ea every other joint. Ran a total of 133 jts at 24:00 hrs. RUNCMP Pipe shed empty. Stab safety valve and pump across top of hole. Load and strap additional joints of tubing in shed needed to finish completion. Finalize tally and distribute to personnel. RUNCMP PJSM. Continue running 4.5", 12.6#, L-80 completion as per running order. Torque to 3,975 ft-Ibs and run Cannon clamp every other joint to secure I-Wire. SLB checking conductivity every 1,000'. Loss rate = 12 BPH. Run total of 252 joints of 4-1/2" tubing. RUNCMP PUMU FMC 11" x 4-1/2" tubing hanger. Make penetration with I wire and packoff, PUW of 73K and 27K SOW. Land tubing hanger. RILDS. BOLD landing joint. Close blind rams. RUNCMP RU LRS lines to IA. Connect Methanal/Water pup to LRS unit. P/T lines to 3,500 psi. RUNCMP Line flow path thru choke. Reverse circulate with LRS with inhibited 9.8 ppg brine taking returns thru choke back to pits. Circulate 195 bbls at 2.25 BPM / 210 psi, chase with 5 bbls of methanol cap. Lost 60 bbls during circulation. RUNCMP MU Opso-Lopso with TCII crossover. Screw into hanger. Drop Modified Ball and Rod with rubber cups (1-7/8" Ball, 2.5" GS profile on top, 16' 10" OAL). LD Opso-Lopso. Close blinds and line up rig pump. Picture of ball and rod included in handover folder. RUNCMP Break circulation and pump 9.8 ppg brine to chase Ball and Rod to bottom. Pump at 2.5 BPM / 610 psi. RUNCMP Continue pumping at 2.5 BPM / 610 psi. Pump a total of 226 bbls (1.5 tubing volume), unable to catch Ball and Rod on seat. Shut down pump and discuss with day man. Tubing pressure fell to 340 psi after shutting down pump. RUNCMP Call for 290 bbls of 9.8 ppg brine. RD stabbing board, clean out pits and upright tank with dirty vac truck. Load pipe shed with equipment in preparation for rig move. RU LRS pump unit to spool below rams to bullhead down tubing. RUNCMP Pump 9.8#/gal brine down tubing varying rates from .5 BPM to 3.5 BPM. Surging fluid by varying rates in attempt to place Printed: 3/6/2009 1:42:20 PM BP AMOCO Page5of5~ Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 3S Date From - To Hours '~ Task Code NPT 2/21/2009 107:30 - 10:30 I 3.001 RUNCOAl1P 10:30 - 12:00 I 1.50 12:00 - 14:00 I 2.001 WHSUR I P 14:00 - 19:00 I 5.001 WHSUR I P 19:00-21:30 I 2.501 WHSURIP 21:30 - 23:30 I 2.001 WHSUR I P 23:30 - 00:00 I 0.501 WHSUR I P Spud Date: 9/8/2001 Start; 2/6/2009 End: Rig Release: 2/21/2009 Rig Number: N3S Phase Description of Operations RUNCMP 1-7/8" ball with nibbler cups on seat. Pump 160 Bbls in 2nd attempt to set packer. Max pressure of 580 psi while pumping. Flow check well and U-tube tubing to IA. RUNCMP Flowcheck well and bleed 40 bbls of brine back from charging formation. Well stable. 0 psi on Tbg and IA. RUNCMP Dry rod TWC. Test from above to 1000 psi and chart for 10 minutes. Pump 10 Bbls in IA and pressure to 400 psi below TWC with no leak. Flush and drain stack. Confer with colleagues in Anchorage regarding plan forward. RUNCMP ND BOPE. LRS pumping 9.8 #/gal brine in IA every hour. Set BOP's in cradle and pull out of cellar. RUNCMP NU adapter flange and tree. Verify tree alignment with Pad operator. FMC install new SPMS seal. Schlumberger completed final test on I-Wire (BHP = 1753 psi, BHT = 65.3). Terminate I-Wire in tubing head adapter. FMC tested tubing hanger void to 5,000 psi for 30 min. Test tree to 5,000 psi for 5 min -charted. RUNCMP PUMU lubricator, test to 500 psi with diesel. Pull TWC, (Tbg on vacuum) set BPV. Pump 5 bbl methanol cap down IA and 5 bbl down tubing. Release LRS to complete unit maintenance in Deadhorse. RUNCMP Normal up tree and secure cellar. ***Rig released on 2-21-09 at 24:00 hrs*** Printed: 3/6/2009 1:42:20 PM ~~ J MPI-11 / L1 Well History Date Summary 03/03/09 MPU Well Support Techs SET BPV in I-11 after Slick line was completed. 03/08/09 MPU Well Support Tech «« PULLED THE BPV »» on I-11 for Coil to rig up. 03/10/09 CTU #5 w/1.75 coil Job Scope: Set Baker S-3 production packer & Install Jet pump 03/11/09 CTU #5 w/1.75 coil Job Scope: Set Baker S-3 production packer & Install Jet pump <> ...Cont from WSR 3/10/2009... Attempted to R/U mast would not raise due to segment pump going out. Had to swap the hydraulic pump. Considerable amount of down time involved (12 hrs NPT). Raised mast and continue rigging up 03/12/09 CTU #5 w/1.75" Coil ,Job Scope: Set Baker S-3 production packer & Install Jet pump . <> ...Continued from WSR 3/11/2009... RIH while circ hot XS 1 % KCL to heat expand tbg before setting packer, park coil Q 10,000' &circ 580 bbls XS 1 %KCL Continue in hole and set down with Ball & Rod in RHC-M series plug body. Bring tubing pressure up to 3800 psi, set Baker Series 3 PKR and perform MIT-T for 30 min (Passed) Perform MIT-IA to 3500 psi and hold for 30 min (Passed) POOH and changed BHA configuration to pull RHC-M Series plug body ~ 10232' CTM OOH w. RHC RIH w. 4 1/2" 8042 Shifting tool. SD and run into Dura sliding sleeve and open. Varified open by seeing response on IAP falling. Also pumped a few bbls from IA through SS to see response on WHP. RIH w. 4 1/2" jet pump, set Weatherford - 3" RC Jet Pump sn BP 1065 w/A10-B ratio: 10 nozzle,#11 throat in HES 3.813" XD profile @ 10,118' 03!13/09 CTU #5 w/1.75" Coil, Job Scope -Set Jet Pump <> ...Continued from WSR 3/12/2009... RD CTU from MPI-11 Freeze protected well w/60/40 Meth, IA & Tbg. 03/17/09 The Well Support Techs rigged up and pressure tested teh flowlines to 1150 psi and the powerfluid line to 3600 psi. All test were good and the well is ready to POP. 03/29/09 ASRC Test Unit #5, 6 hour test 03/30/09 ASRC Test Unit #5, 6 hour test RDMO 04/12/09 ASRC Test Unit #5, MIRU MPI-Pad Test header, Page 1 of 1 e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Inserts\Microfilm _ Marlœr.doc (:;¡ (V ð if ;{ ð ö ) DATA SUBMITTAL COMPLIANCE REPORT 10/22/2003 Permit to Drill 2011380 Well Name/No. MILNE PT UNIT SB 1-11 L 1 Operator BP EXPLORATION (ALASKA) INC l~ ';¡o~ 50-0~!23~O~ I MD 13190 r TVD 3557 - Completion Date 10/6/2001 ,...---- Completion Status 1-01L Current Status 1-01L UIC N - - - ~-- -- REQUIRED INFORMATION ~---~ -- - -- ~~--~ Mud Log No Samples No Directional Survey ~_'i ~ '-- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: ~----~--- ----- (data taken from Logs Portion of Master Well Data Maint) Log/ Data Digital Type Med/Frmt kED C ~D -~-- Log Log Scale Media Run No 1 1 Interval OH / Start Stop CH Received 108 13190 Open 5/9/2002 Comments 160 13136 Open 2/20/2002 - ------ ----- i ¡ J Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? y Gì) Chips Received? ~ Analysis ~ Received? Daily History Received? WN &N Formation Tops ---=~ Comments: ------~ - Compliance Reviewed By: 1~ Date: f 0 70 ~~.¿--;z..ÖIJ-\'~c'c ( , (I WELL LOG TRANSMl'. TAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 March 15, 2002 RE: MWD Fonnation Evaluation Logs - !v1PI-II & MPI-II Ll, AK-M1v1-11151 MPI-l1 Ll: Digital Log Images: 50-029-23033-60 . ,a~o.J=t3"g-'" Q9~dí..O I 1 O~- 13J"10 Lo5ö aD/-3~ I 0- 0 J - 0 I IO~~J3/C)O "'3D J o:K.3-3'~, ,¡ MPI-ll: Digital Log Images: 50-029-23033-00 1 CD Rom 1 Dð3't f. 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Sign~ ~ Date: RECEIVED MA~ 0 ~ 2f/JZ 4fe.ska Oil & Gas Cons. Commission Anchorage l STATE OF ALASKA ( ALASKÆ--.L AND GAS CONSERVATION COMtVI....,dION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 0 Operation Shutdown 0 Stimulate II Pull Tubing 0 Alter Casing 0 Plugging 0 Perforate II Repair Well 181 Other 5. Type of well: B Development 0 Exploratory 0 Stratigraphic 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O, Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2343' NSL, 3966' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 951' NSL, 3331' EWL, SEC. 31, T13N, R10E, UM At effective depth 599' NSL, 55T EWL, SEC. 31, T13N, R10E, UM At total depth 5991 NSL, 557' EWL, SEC. 31, T13N, R10E, UM 12, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13190 feet 3557 feet 13190 feet 3557 feet Junk (measured) Plugs (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Change Out ESP 6. Datum Elevation (OF or KB) KBE = 63.55' 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-11L 1 9. Permit Number / Approval No, 201-138 10. API Number 50- 029-23033-60 11. Field and Pool Milne Point Unit / Schrader Bluff 72' 20" 2702' 10-3/4" 103161 7" 2788' 4-1/2" Cemented MD TVD 260 sx Arctic Set (Approx.) 1011 101' 600 sx PF 'L', 440 sx Class 'G' 2730' 2730' 1400 sx Class 'G' 10345' 3596' Uncemented Slotted Liner 103361 - 13124' 3594' - 3560' Perforation depth: measured Slotted Liner: 10406' - 13079' true vertical Slotted Liner: 3608' - 3562' Tubing (size, grade, and measured depth) 2-7/8",6,5#, L-80 tubing to 101961. Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-8bl Prior to well operation: Subsequent to operation: 15, Attachments 0 Copies of Logs and Surveys run ISI Daily Report of Well Operations 17, I hereby certify t the fo going is tr 16, Status of well classifications as: BOil 0 Gas 0 Suspended orrect to the best of my knowledge E'ceiVED ,JA,N 2 3 2002 Alaska Oil &. Gas Gens G ." Anch y~, .. ommlsslon Casing Pressure Tubing Pressure Service Date [- 'Z7--0~2- ~ Prepared By Name/Number: Sandra Stewman, 564-4750 II )") ~",) ~ (""~ ~ ~\ ~ ¡~i l ubmit In Duplicate \, U\~tJ~i~t .".. Technical Assistant Form 10-404 Rev. 06 1588 '* ( ( . BPAMOCO Page 1 of 3 Operations Summary Report "", Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 11/30/2001 End: 12/6/2001 Contractor Name: NABORS Rig Release: 12/6/2001 Rig Name: NABORS 4ES Rig Number: Date From -To Hours Activity Code NPT Phase Description of Operations 11/30/2001 12:00 -18:00 6.00 REST P DECOMP CREWS BEGIN ARRIVED TO LOCATION FROM ANCHORAGE (CHARTER DELAYED DUE TO MECHANICAL PROBLEMS). HOLD PRE START-UP AND RIG MOVE SAFETY MEETING. 18:00 - 21 :00 3.00 REST P DECOMP RIG DOWN FROM WARM-STACK LOCATION ON H PAD AND MOVE RIG TO LOCATION AT MPI-11. 21 :00 - 00:00 3.00 REST P DECOMP SPOT AND BERM RIG AND EQUIPMENT. RAISE AND SCOPE DERRICK. RU LINES. ACCEPT RIG AT 00:00 HRS. 12/1/2001 00:00 - 01 :00 1.00 REST P DECOMP FINISH RU REMAINING LINES TO NEW KILL TANK. 01 :00 - 02:00 1.00 REST P DECOMP RU LUBRICATOR AND PULL BPV. LD LUBRICATOR. 02:00 - 04:00 2.00 REST P DECOMP RU HCR VALVE TO ANN AND LINES TO TREE. TEST TO 2,500 PSI GOOD. 04:00 - 06:00 2.00 REST P DECOMP TAKE ON HOT SEA WATER IN PITS. PREP RIG FLOOR. 06:00 - 07:00 1.00 REST P DECOMP HOLD PRE-JOB OPERATIONS AND SAFETY MEETING. 07:00 - 09:30 2.50 REST P DECOMP CIRCULATED WELL WITH 120 DEG SEA WATER. 09:30 - 10:00 0.50 REST P DECOMP MONITOR WELL. TBG = 80 PSI. ANN = 40 PSI. 10:00 - 13:00 3.00 REST P DECOMP WEIGHT UP TO 8.7 #/GAL. CIRCULATE WELL. 13:00 -13:30 0.50 REST P DECOMP MONITOR WELL. WELL ON SLIGHT VAC. 13:30 - 14:30 1.00 REST P DECOMP INSTALL AND TEST TWC 14:30 - 15:30 1.00 REST P DECOMP REMOVE X-MASS TREE. 15:30 -18:00 2.50 REST P DECaMP INSTALL ADAPTOR SPOOL AND BOPE. PREPARE FOR BOPE TEST. 18:00 - 21:30 3.50 REST P DECOMP PERFORM BOPE TEST ACCORDING TO AOGCC AND BP REQUIREMENTS. TEST WITNESSED BY STATE REP...J. JONES. 21 :30 - 22:30 1.00 REST P DECOMP RU LUBRICATOR AND PULL TWC. LD LUBRICATOR. 22:30 - 00:00 1.50 REST P DECaMP RU FLOOR FOR 2 7/8" TBG. MU LANDING JT. BOLDS. PULL HANGER TO FLOOR (60k). LD HANGER AND LANDING JT. 12/2/2001 00:00 - 02:00 2.00 PULL P DECOMP START POOH W/2 7/8" TBG AND ESP ASSY. 02:00 - 02:30 0.50 PULL P DECaMP STOP TO CHANGE ESP CABLE SPOOL. 02:30 - 06:00 3.50 PULL P DECOMP CONTINUE TO POOH WITBG AND ESP ASSY. CREW CHANGE. 06:00 - 07:00 1.00 PULL P DECOMP FINISH OUT OF HOLE WITBG. ESP ASSY TO SURFACE. 07:00 - 09:30 2.50 PULL P DECaMP INSPECT AND LD ESP ASSY. 09:30 - 10:00 0.50 CLEAN P DECaMP RU FLOOR TO PU 2 7/8" PAC DP. INSTAL WEAR RING. 10:00 -13:30 3.50 CLEAN P DECaMP MU 3 1/2". PU 90 JTS 2 7/8" PAC DP. TALLY AND DRIFT. 13:30 - 14:30 1.00 CLEAN P DECOMP RU FLOOR TO PU 3 1/2" DP. FINISH LOADING PIPE SHED WITH DP. 14:30 - 18:00 3.50 CLEAN P DECaMP START PICKING UP 3 1/2" DP. TALLY AND DRIFT. CREW CHANGE. 18:00 - 22:00 4.00 CLEAN P DECaMP CONTINUE RIH W/31/2" DP TO 10,300-FT. RECORD PUW = 85K AND SOW = 20K. 22:00 - 00:00 2.00 CLEAN P DECaMP TAGGED AT 10,350-FT. ATTEMPT TO REV CIR...NO-GO. ATTEMPT TO PUMP DOWN DP...PLUGGED. WORKED FREE. REV CIRC DOWN TO 10,413-FT WITH A FLUID LOSS OF 1.8 BPM. CBU...SAW NO SOLIDS. CONTINUE RIH WITH DP. 12/3/2001 00:00 - 04:30 4.50 CLEAN P DECOMP CONTINUE RIH WITH 3 1/2" DP. BREAK CIRCULATIONS EVERY 20 JTS. SAW NO FILL. TAG BTM @ 13,075-FT. 04:30 - 06:00 1.50 CLEAN P DECOMP REV CIRC. 3 BPM/250 PSI. FLUID LOSS 1 BPM. CREW CHANGE. 06:00 - 09:00 3.00 CLEAN P DECOMP CONT W/REV CIRC UNTIL CLEAN. MONITOR WELL Printed: 12/10/2001 11:18:17 AM f il ( BP AMOCO Page 2 of 3 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: WORKOVER Start: 11/30/2001 End: 12/6/2001 Contractor Name: NABORS Rig Release: 12/6/2001 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 12/3/2001 09:00 - 11 :00 2.00 CLEAN P DECOMP START POOH TO 10,350-FT. STOP TO CIRCULATE AND RECIP PIPE TO CLEAN DIVERTER TOOL AREA. 11 :00 - 14:00 3.00 CLEAN P DECOMP FINISH POOH WITH REMAINING 3 1/2" DP. 14:00 - 16:00 2.00 CLEAN P DECOMP CHANGE OVER TO 2 7/8" HANDLING EQUIPMENT. POOH WITH 2 7/8" PAC TBG AND 31/2" MILL 16:00 - 17:00 1.00 CLEAN P DECOMP MU BAKER LATERAL DIVERTER TOOL AND GS RUNNING TOOL CHANGE OVER TO 31/2" HANDLING TOOLS. CLEAR FLOOR. 17:00 - 18:00 1.00 CLEAN P DECOMP START TIH WITH 3 1/2" DP. CREW CHANGE. 18:00 - 21:00 3.00 CLEAN P DECOMP FINISH TIH WITH 3 1/2" DP. 21 :00 - 22:00 1.00 CLEAN P DECOMP TAG AND SET LATERAL DIVERTER IN BAKER HOOK HANGER AT 10,366-FT. 22:00 - 23:00 1.00 CLEAN P DECOMP CUT AND SLIP DRILL LINE. 23:00 - 00:00 1.00 CLEAN P DECOMP START TOOH WITH 3 1/2" DP. 12/4/2001 00:00 - 02:30 2.50 CLEAN P DECOMP FINISH TIH W/ 31/2" DP. LD GS RUNNING TOOL. 02:30 - 03:30 1.00 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR. CO TO FOR 2 7/8" PAC. 03:30 - 06:00 2.50 CLEAN P DECOMP MU 31/2" MILL TIH W/2 7/8" PAC. CO TO 31/2" AND START TIH W/3 1/2" DP. CREW CHANGE. 06:00 - 06:30 0.50 CLEAN P DECOMP LUB RIG. 06:30 - 08:30 2.00 CLEAN P DECOMP TIH W/3 1/2" DP TO LATERAL DIVERTER AT 10,336-FT. 08:30 - 10:00 1.50 CLEAN P DECOMP WORK THROUGH DIVERTER. CIRCULATE AND WARM UP HOLE. 10:00 - 11:30 1.50 CLEAN P DECOMP CONTINUE TIH TO 12,980-FT. FOUND NO FILL 11 :30 - 13:30 2.00 CLEAN P DECOMP REV CIRC CLEAN AT 3 BPM/250 PSI. SD PUMP AND MONITOR. 13:30 - 17:00 3.50 CLEAN P DECOMP TOOH W/3 1/2" DP. 17:00 - 18:00 1.00 CLEAN P DECOMP CHANGE OVER TO 2 7/8" PAC. START LD 2 7/8" PAC. CREW CHANGE. 18:00 - 20:30 2.50 CLEAN P DECOMP FINISH LD PAC AND 3 1/2" MILL 20:30 - 21 :00 0.50 CLEAN P DECOMP CLEAR FLOOR AND CHANGE OVER FOR 31/2" DP. 21 :00 - 00:00 3.00 CLEAN P DECOMP MU GS PULLING TOOL AND TIH W 3 1/2" DP. 12/5/2001 00:00 - 00:30 0.50 CLEAN P DECOMP SET DOWN ON LATERAL DIVERTERAND LATCH IN WITH GS PULLING TOOL 00:30 - 06:00 5.50 CLEAN P DECOMP RELEASE LATERAL DIVERTER. START TOH LAYING DOWN 3 1/2" DP. 06:00 - 08:00 2.00 CLEAN P DECOMP FINISH TOH WITH 31/2" DP. LAY DOWN LATERAL DIVERTER AND GS PULLING TOO. 08:00 - 09:00 1.00 RUNCO~ Ip COMP CLEAR FLOOR AND PREP TO PU ESP ASSY. 09:00 - 14:00 5.00 RUNCO~ Ip COMP PU AND SERVICE ESP ASSY. TEST SAME. 14:00 - 18:00 4.00 RUNCO~ Ip COMP START RIH W/ESP ASSY AND 2 7/8" TBG. FLUSH PUMP AT 1 BPM EVERY 18 STDS. CREW CHANGE. 18:00 - 20:00 2.00 RUNCO~ Ip CaMP CONTINUE TIH WI 2 7/8" TBG AND ESP ASSY. 20:00 - 23:00 3.00 RUNCO~ Ip CaMP STOP TO SPLICE CABLE AND TEST. 23:00 - 00:00 1.00 RUNCO~ Ip COMP CONTINUE TIH W2 7/8" TBG AND ESP ASSY. 12/6/2001 00:00 - 03:00 3.00 RUNCO~ Ip COMP MU HANGER & INSTALL PENETRATORS & ATTACH FIELD CONNECTORS & TEST SAME & LAND HANGER & RILDS. 03:00 - 03:30 0.50 BOPSUF P COMP SET TWC & TEST TO 3000 PSI. 03:30 - 05:00 1.50 BOPSUF P COMP NIPPLE DN BOP 05:00 - 07:00 2.00 WHSUR P COMP NIPPLE UP TREE & TEST TREE & HANGER SEALS TO 5000 PSI. & MAKE FINAL CHECK ON ESP CABLE. 07:00 - 08:00 1.00 WHSUR P CaMP MU LUBRICATOR & PULL TWC & SET BPV. 08:00 - 10:00 2.00 CHEM P CaMP RU HB& R AND FREEZE PROTECT WELL WITH 15-BBL DIESEL DN TBG. & 80 -BBL DEAD CRUDE DN ANNULUS Printed: 12/10/2001 11:18:17 AM .. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ( (' BPAMOCO Operations Summary Report MPI-11 MPI-11 WORKOVER NABORS NABORS 4ES Start: 11/30/2001 Rig Release: 12/6/2001 Rig Number: 12/612001 08:00 - 10:00 From - To Hours Activity Code NPT Phase COMP AND SECURE TREE & RELEASE RIT @ 1000 HRS. 12-06-01 Description of Operations Date 2.00 CHEM P Page 3 of 3 Spud Date: 9/8/2001 End: 12/6/2001 Printed: 12/1012001 11 :18:17 AM ( ( ~"'."""';l)"""'1;""'1"~1?:;.!,.:;!1'1":3":';':'::"""",¥"':""':' ':- . -""""J" '-' ' WELL LOG TRANSMITI AL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 8, 2002 RE: MWD Fonnation Evaluation Logs rvtPI-II LI, AK-MM-11151 1 LIS fonnatted Disc with verification listing. API#: 50-029-23033-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Da~D Sign~~ FEB 2 0 2002 AlaSka Oil & Gas Cons. Commission Anchorage 1. Status of Well ~ Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface -- " 2343' NSL, 3966' WEL, SEC. 33, T13N, R10E, UM I~ .,".. At top of productive interval '~ ...L(¿-" (.:¿:.~i ' , 9Ã.rt~~~d:~~1' EWL, SEC, 31, T13N, R10E, UM : ,---~~~"~~, ,: 599' NSL, 557' EWL, SEC. 31, T13N, R 1 OE, U M '-"'" - '" '. - -, - ¡. 5. Elevation in feet (indicate KB, DF, etc,) 6. Lease Designation and Serial No. KBE = 63.55' ADL 025517 12. Date Spudded 13. Date T.D. Reached 14. Date Comp" Susp., or Aband. 9-28-2001 9-29-2001 10-6-2001 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19, Directional Survey 13190 3557 FT 13190 3557 FT 181 Yes 0 No 22. Type Electric or Other Logs Run DIR, GR, PWD, RES, ABI, ABGR 23. CASING SIZE 20" 10-3/4" 7" 4-1/2" WT. PER FT. 94# 45.5# 26# 12.6# ( STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well u: . '--.~_..., ,~ - Ilol i ft. . r ;..,~~....~; 7. Permit Number 201-138 8. API Number 50- 029-23033-60 9. Unit or Lease Name Milne Point Unit 10. Well Number MPI-11L 1 11. Field and Pool Milne Point Unit 1 Schrader Bluff 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost NIA MD 1800' (Approx.) GRADE H-40 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD 29' 101' 30" 60 sx Arctic Set (Approx.) 28' 2730' 13-1/2" 600 sx PF 'L', 440 sx Class 'G' 29' 10345' 9-7/8" 1400 sx Class 'G' 10336' 13124' 6-1/8" Uncemènted Slotted Liner AMOUNT PUllED 24, Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 4-1/2" Slotted Section MD TVD 10406' . 13079' 3608' - 3562' 27. Date First Production October 17, 2001 Date of Test Hours Tested 10/16/2001 6 Flow Tubing Casing Pressure Press. 25. TUBING RECORD DEPTH SET (MD) 10213' SIZE 2-7/8", 6.5#, L-80 PACKER SET (MD) 1}{f51. MD TVD 26, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2500' Freeze Protected with 85 bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, gas lift, etc,) Electric Submersible Pump PRODUCTION FOR OIL-Bel TEST PERIOD 1178 CALCULATED OIL-Bel 24-HoUR RATE GAs-McF 87 GAs-McF CHOKE SIZE GAS-Oil RATIO 74 WATER-BBl 12 WATER-BBl Oil GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Suþ[T1itc~9~~~ QO!P$..., w-----" , ' '," " 'I "" 1 ". I: -, -','Coo_" ,x,"~!' ~I",,'c-:¡,--',¿~" Form 10-407 Rev. 07-01-80 t:-J" ;:" 1,! ~i i,l ') "': '11 !i' U Ii> _.C. '::,G L U:) è "." ~ ':--"';',':~'" r"-:r.:-Ç'II':,~:,¡nC"\III' 1," .."", ,~. ..- ,oJ i,\: :iClo,":,::,Jø Submit In Duplicate - .. ~, , 1,,""/, l' f '"~I,,'" ~, \"\ 1/ \ \' 'l.....i 1 \ \'".: l \. \~ ,f'- '\ L,., (2ß Ptr5 oC-, ~(::.- f' '" (' 29. Geologic Markers 30, Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Top of Schrader OA 10410' 3608' :J L " .",,'lC' -,.. !: ';,", l Y ~,I /: 'I 11" I, ",_'l,6 ."' :;: I" ,,:I! ""'1"' ':" "~"""'~" i(-:- l " 31 . List of Attachments: Summary of Daily Drilling Reports, Surveys, Leak Off Test Summary 32. I ~erebY certify that the fO~Oi~9 is true and correct to the best of my knowledge Signed Terrie Hubble /filA, Title Technical Assistant MPI-11L1 201-138 Well Number Permit No. / A roval No. Date Prepared By Name/Number: Sandra Stewman, 564-4750 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska, ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 n~'ì:tC"~r'!A( .' "~ "'I ,._,,! \ '- ",/1\. "}l¡1!~!~._.. ( ( BP AMOCO Page 1 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 1 0/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9n/2001 20:00 - 22:00 2.00 BOPSUF P SURF Install 20" Riser On Annular - Install Flow Line - Hook Up Turnbuckles On 21 1/4" Annular And Center, Install Hole Fill Line, And Bleed Off Line - Pick Up Cellar Area - 22:00 - 00:00 2.00 BOPSUR P SURF Function Test 21 1/4" Diverter System - Perform Accumulator Test - Check LEL & H2S Gas Detection System . NOTE. All Tests Were Witnessed By AOGCC Representive Jeff Jones 9/8/2001 00:00 - 05:00 5.00 BOPSUR P SURF Hold Pre-Job Safety Meeting With Crew Coming On Tour- Pressure Test Mud Line Swivel Packing And Top Drive IBOP Valves Back To Mud Pumps At 3,800 Psi. For 10 Minutes While Recording On Circle Chart - Fill 20" Riser And Circulate Water Back To Mud Pits & Check For Leaks - Pick Up Mousehole - Bring Cross Over Subs And Safety Valves To Rig Floor. 05:00 - 13:00 8.00 BOPSUF P SURF Pick Up And Make Up In Mouse Hole 145 Joints Of 5" Drill Pipe And 14 Joints Of 5" HWDP With Jars And Stand Back In Mast. 13:00 -14:00 1.00 BOPSUR P SURF Hold Pre-Spud Meeting With All Personal 14:00 -15:00 1.00 BOPSUR P SURF Pick Up And Make Up BHA With Sperry Sun Directional Driller 15:00 -16:30 1.50 DRILL P SURF Spud Well MPI-11 At 15:00 Hours With Bit No.1 - Clean Out 20" Conductor Pipe - Drill Ahead From 101' To 222' - Circulate To Clean Hole. 16:30 -17:00 0.50 DRILL P SURF POH To Pick Up Sperry Sun MWD & BHA Equipment 17:00 -18:00 1.00 DRILL P SURF Pick Up BHA No.1 - Change Bend On Mud Motor To 1.5 AKO- Pick Up MWD Tool, Hang Off Sub, UBHO And Orient To Motor. 18:00 -18:30 0.50 DRILL P SURF Initalize And Load Spery Sun MWD Tool 18:30 -19:00 0.50 DRILL P SURF Pick Up Flex Collars 19:00 - 20:30 1.50 DRILL P SURF Surface Test MWD Tool - Rig Up And Run Gryo - Rig Down Gryo Equipment 20:30 - 00:00 3.50 DRILL P SURF Directional Drill Ahead From 222' To 540' - Weight On Bit 25K To 30K With Pump Rate At 120 Strokes Or 500 GPM - Off Bottom Pump Pressure At 1000 Psi. & On Bottom Pump Pressure At 1150 Psi. Top Drive RPM At 60 Off Bottom Torque At 1 K & On Bottom Torque At 3K String Rotating Weight At 1 OOK - With Pump On Drag Up At 1 OOK And Drag Down At 100K. 9/9/2001 00:00 - 23:30 23.50 DRILL P SURF Directional Drill Ahead From 540' To 2,743' Surface Casing TD - Weight On Bit 25K To 30K With Pump Rate At 125 Strokes Or 526 GPM - Off Bottom Pump Pressure At 1200 Psi. & On Bottom Pump Pressure At 1350 Psi. Top Drive RPM At 80 Off Bottom Torque At 6K & On Bottom Torque At 1 OK String Rotating Weight At 125K - With Pump On Drag Up At 135K And Drag Down At 120K. 23:30 - 00:00 0.50 DRILL P SURF Circulate And Condition Mud While Pumping Hi-Vis Sweeps 9/10/2001 00:00 - 01 :00 1.00 DRILL P SURF Continue With Mud Maintenance As Directed By Baroid While Pumping Hi-Vis Sweeps. 01 :00 - 03:00 2.00 DRILL P SURF Hold Pre-Job Safety Meeting - Monitor Well Bore (Static) - POH (SLM & Wet) Short Trip - Work Hole Section At 1,910' And 1,726' Continue On With Short Trip To Top Of HWDP At 723' 03:00 - 05:00 2.00 DRILL P SURF Monitor Well Bore (Static) - Clean Rig Floor - RIH To 1,475' Printed: 10/8/2001 1:16: 10 PM ( (" BP AMOCO Page 2 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/10/2001 03:00 - 05:00 2.00 DRILL P SURF Work Thru Tight Hole Section To 1,850' - Continue To RIH To 131/2" TD At 2,743' 05:00 - 06:00 1.00 DRILL P SURF Circulate And Clean Up Hole Pumping Hi-Vis Sweeps While Rotating And Reciprocating Drill String - *NOTE* Pump Rate Increased To 600 GPM And Standing Back 5" Drill Pipe To Keep Hole In Gauge During Circulation Process. 06:00 - 08:00 2.00 DRILL P SURF Monitor Well Bore (Static) - POH 3 Stands Check For Swabing - Pump Dry Job And POH (No Problems And Good Fill) 08:00 - 11 :00 3.00 DRILL P SURF Lay Down BHA And Clear Rig Floor 11 :00 - 13:00 2.00 CASE P SURF Hold Pre Job Safety Meeting - Rig Up Franks Fill Up Tool - Casing Tools And Equipment. 13:00 - 13:30 0.50 CASE P SURF Hold Pre-Job Meeting With All Personal Reguarding Up Coming 10 3/4" Surface Casing Plan And Operation. 13:30 - 17:30 4.00 CASE P SURF Pick Up Shoe Track And Install Centrilizers Per Well Plan - Pump Thru Shoe Track And Verify Floats Operational - Continue To Pick Up A Total Of 65 Joints Of 10 3/4" L-80 45.5 lb. BTC Casing Per Procedure And RIH - Work Thru Tight Spot From 1,670' To 1,700' - Continue Picking Up Casing Wash Last Two Joints To Bottom From 2,614' To 2,729' 17:30 - 19:30 2.00 CASE P SURF Circulate With Franks Fill Up Tool At 7 BPM With 350 Psi. - Remove 350 Ton Slips - Land 10 3/4" Casing On Fluted Hanger Rig Down Casing Tongs And Pick Up Sling - Clear Rig Floor - Pump Pit Volume Down While Conditioning Mud Properties - Make Up Haliburton Cementing Head And Circulating Surface Lines - Hold Pre Job Meeting With All Personal Reguarding Up Coming Cement Operation. 19:30 - 23:30 4.00 CEMT P SURF Reciprocate Casing String 170K Up Weight And 145K Down Weight - Turn Over To Haliburton Energy Services - Pump 10 BBL. Fresh Water - Test Surface Equipment @ 3000 Psi. - Continue To Pump Additional 1 0 BBL. Water - Mix & Pump 50 BBLS. 10.2 PPG Alpha Spacer @ 5.2 BPM & 370 PSI. With Red Dye Added - Drop Bottom Wiper Plug - Batch Up & Mix Type "L" Permafrost 1 0.7 PPG Lead Cement wi Yield Of 4.15 ft3/sk - Pump @ 7.4 BPM wi 550 PSI. - Total Lead Cement Slurry Pumped 443 BBLS Or 600 sacks - Follow Up Lead Cement wI Surface Tail Design Class "G" Premium 15.8 PPG. Tail Cement wI Yield Of 1.15 ft3/sk - Tail Cement Job Was Pumped @ 5.9 BPM Circulating Pressure @ 697 Psi. . Total Tail Cement Pumped 91 BBLS. Or 440 Sacks - Drop Top Wiper Plug -Haliburton Pumped 10 BBLS. Behind To Clear Lines Turned Over To Rig For Displacement - Displaced @ 10.4 BPM wI 9.3 PPG. Spud Mud - Pumped 245 BBLS. Or 2,418 Strokes To Bump Plug - Total Cement Back To Surface 220 BBLS. - Final Circulation Pressure During Displacement @ 640 PSI. - Continue To Pressure Up To 1,700 PSI. After Bumping Plug And Hold For 5 Min. - Bleed Pressure To 0 PSI. Check Floats (OK) Cement In Place @ 2330 Hours. 23:30 - 00:00 0.50 CEMT P SURF Rig Down Surface Circulating Line And Haliburton Cementing Head - Remove Adaptor Swedge - Clear Rig Floor 9/11/2001 00:00 - 02:30 2.50 CEMT P SURF Rig Down Casing Tools And Equipment - Clear Rig Floor - Lay Down Landing Joint And Mouse Hole - Change Out Bails And Elevators - Blow Down Top Drive And Surface Lines - Clean Mud System - Drain And Flush Diverter System Printed: 10/8/2001 1:16:10PM ( i l - BP AMOCO Page 3 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/11/2001 02:30 - 06:00 3.50 BOPSUf' P SURF Hold Pre-Job Safety Meeting - Remove 16" Hydraulic Knife Valve And Diverter Line - Nipple Down 21 1/4 2M Annular, Diverter Spool, And FMC Quick Connect 06:00 - 15:00 9.00 BOPSUf' P SURF Install FMC Casing Head And Tubing Spool - Install Double Studded Adaptor And Set BOP Stack On Well Head - Test Metal To Metal Seal At 1000 Psi. For 10 Minutes (OK) - Continue To Nipple Up 135/8 5M BOP And Related Equipment - Install Double Valves On Casing Head - Install Turnbuckles, Flow Nipple, And Flow Line. 15:00 - 16:00 1.00 BOPSUf' P SURF Hold Pre-Job Safety Meeting - Install Test Plug And Test Joint - Open Up Lower Annulus Valve - Rig Up Testing Equipment 16:00 - 21:30 5.50 BOPSUR P SURF Test BOP And Related Equipment - Test Annular At 250 Low For 5 Minutes And 2,500 Psi High For 5 Minutes - Test Upper And Lower Pipe Rams, Blind Rams, Manual And HCR Valves On Choke And Kill Line, Choke Manifold, Upper And Lower IBOP Valves On Top Drive, Dart Valve And Full Opening Safety Valve At 250 Psi. Low For 5 Minutes And 3500 Psi. High For 5 Minutes - Preform Accumulator Test - Test All LEL And H2S Gas Detectors - Test Pit And Flow Line Alarms - All Tests Were Witnessed By AOGCC Representive Jeff Jones. *NOTE* Two Failures: 1) H2S Alarm System Was Found To Be Turned Off - When Haliburton Cementers Keyed There Head Sets It Will Set Off Alarms. 2) Lower IBOP Valve Failed To Test At 250 Psi. 21 :30 - 00:00 2.50 BOPSUf' N RREP SURF Change Out Lower Top Drive IBOP Valve - Work On Pipe Handler Torque Wrench 9/12/2001 00:00 - 01 :30 1.50 BOPSUF P SURF Pull Test Plug - Install Wear Ring And Energize Lock Down Studs On Tubing Head - Circulate Water Thru Choke Manifold To Poor Boy Degasser And Verify All Lines Clear Of Any Obstructions - Blow Down Surface Lines 01 :30 - 04:30 3.00 DRILL P INT1 Pick Up 25 Stands Of 5" Drill Pipe And Stand Back In Mast 04:30 - 05:30 1.00 DRILL P INT1 Service Top Drive, Traveling Blocks, And Crown Sheaves 05:30 - 09:00 3.50 DRILL P INT1 Pick Up 9 7/8" Bit And BHA No.2 - Initalize MWD Tool- Shallow Test MWD Tool And Mud Motor (OK) 09:00 - 11 :00 2.00 DRILL P INT1 Pick Up 10 Stands Of 5" Drill Pipe And Stand Back In Mast 11 :00 - 13:30 2.50 DRILL P INT1 Pick Up Singles Of 5" Drill Pipe And RIH To Top Of Float Collar 13:30 - 14:00 0.50 DRILL P INT1 Circulate And Condition Mud 14:00 - 15:00 1.00 DRILL P INT1 Pressure Test 10 3/4" Surface Casing At 1500 Psi. For 30 Minutes 15:00 - 16:30 1.50 DRILL P INT1 Tag Cement Wiper Plugs At 2,641' - Float Collar At 2,643' - Drill Float Collar And Cement To Top Of Float Shoe At 2,727 - Drill Float Shoe To 2,729' - Ream Out 131/2" Rat Hole To 2,743' - Drill 9 7/8" New Hole To 2,768' 16:30 -18:30 2.00 DRILL P INT1 Citrculate And Condition Mud 18:30 - 22:30 4.00 DRILL P INT1 Perform Formation Integrity Test And Leak Of Test With 8.9 ppg Mud - Equivalent Mud Weight With 550 Psi. At Leak Off 13.5 ppg. 22:30 - 00:00 1.50 DRILL P INT1 Drill Ahead From 2,768' To 2,964' - Weight On Bit 10K To 15K With Pump Rate At 130 Strokes Or 550 GPM - Off Bottom Pump Pressure At 1500 Psi. & On Bottom Pump Pressure At 1650 Psi. Top Drive RPM At 70 Off Bottom Torque At4t< & On Printed: 10/8/2001 1:16:10PM (' ( BP AMOCO Page 4 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 1 0/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/12/2001 22:30 - 00:00 1.50 DRILL P INT1 Bottom Torque At 5K String Rotating Weight At 120K - With Pump On Drag Up At 125K And Drag Down At 105K. 9/13/2001 00:00 - 00:00 24.00 DRILL P INT1 Drill Ahead From 2,964' To 6,292' - Weight On Bit 5K To 20K With Pump Rate At 130 Strokes Or 550 GPM - Off Bottom Pump Pressure At 1700 Psi. & On Bottom Pump Pressure At 1900 Psi. Top Drive RPM At 70 Off Bottom Torque At 8K & On Bottom Torque At 10K String Rotating Weight At 120K - With Pump On Drag Up At 175K And Drag Down At 95K. Slide and rotate for directional control. 9/14/2001 00:00 - 03:30 3.50 DRILL P INT1 Drill Ahead From 6,292' To 6,722' - Weight On Bit 10K To 15K With Pump Rate At 135 Strokes Or 555 GPM - Off Bottom Pump Pressure At 2150 Psi. & On Bottom Pump Pressure At 2300 Psi. Top Drive RPM At 80 Off Bottom Torque At 1 OK & On Bottom Torque At 12K String Rotating Weight At 120K- With Pump On Drag Up At 180K And Drag Down At 95K. Slide And Rotate For Directional Control. 03:30 - 05:00 1.50 DRILL P INT1 Circulate Hole Clean While Pumping Sweeps Rotate And Recipricate Drill String 05:00 - 11 :00 6.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Monitor Well Bore (Static) - POH 2 Stands Well Swabbing And Pulling 20K To 30K Above Normal Upward Drag - Make Up Top Drive And Pump Out Of The Hole To 10 3/4" Casing Shoe 11 :00 - 12:00 1.00 DRILL P INT1 Service Top Drive, Traveling Blocks, And Crown Sheaves - Change Out Saver Sub And Short Top Drive Blower Hose 12:00 - 13:00 1.00 DRILL P INn Pick Up 30 Joints Of 5" Drill Pipe 13:00 - 15:30 2.50 DRILL P INT1 RIH From 2,700' To 6,629' - Break Circulation And Wash To Bottom At 6,722' (No Fill) 15:30 - 00:00 8.50 DRILL P INT1 Drill Ahead From 6,722' To 7,849' - Weight On Bit 10K To 15K With Pump Rate At 135 Strokes Or 555 GPM - Off Bottom Pump Pressure At 2150 Psi. & On Bottom Pump Pressure At 2300 Psi. Top Drive RPM At 80 Off Bottom Torque At 1 OK & On Bottom Torque At 12K String Rotating Weight At 120K- With Pump On Drag Up At 180K And Drag Down At 95K. 9/15/2001 00:00 - 09:30 9.50 DRILL P INT1 Drill Ahead From 7,849' To 8,978' - Weight On Bit 10K To 15K With Pump Rate At 130 Strokes Or 550 GPM - Off Bottom Pump Pressure At 2250 Psi. & On Bottom Pump Pressure At 2450 Psi. Top Drive RPM At 80 Off Bottom Torque At 14K & On Bottom Torque At 15K String Rotating Weight At 130K- With Pump On Drag Up At 205K And Drag Down At 75K. 09:30 - 11 :00 1.50 DRILL P INT1 Pump Weighted Sweep Around While Reciprocating And Rotating Drill String 11 :00 - 15:00 4.00 DRILL P INT1 Hold Pre-Job Safety Meeting - Monitor Well Bore (Static) - POH To 8,530' (Pulling Tight) - Connect Top Drive And Pump Out To 6,723' - Pull One Stand To 6,630' With No Excess Drag 15:00 -16:00 1.00 DRILL P INT1 RIH To 7,476' - While Inspecting Fluid End On No.2 Mud Pump Center Pot Was Found To Be Washed Out Behind Valve Seat 16:00 - 18:30 2.50 DRILL N RREP INT1 POH From 7,476' To 103/4" Casing Shoe -Install Full Opening Safety Valve In Drill String And Monitor Well Bore While Circulating Across Top Of Hole Into Trip Tank. 18:30 - 00:00 5.50 DRILL N RREP INT1 Change Out Fluid End On No.2 Mud Pump 9/16/2001 00:00 - 03:00 3.00 DRILL N RREP INT1 Continue To Change Out Fluid End On No.2 Mud Pump - Test Mud Pump At 4,000 Psi. - Repair Pulsation Damp Leak And Printed: 10/8/2001 1: 16: 1 0 PM (' ,( BP AMOCO Page 5 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/16/2001 00:00 - 03:00 3.00 DRILL N RREP INT1 Retest To 4,000 Psi. (OK) 03:00 - 04:00 1.00 DRILL N RREP INT1 Service Top Drive, Traveling Blocks, And Crown Sheaves 04:00 - 10:00 6.00 DRILL N RREP INT1 RIH From 103/4" Casing Shoe To 7,476'- Fill Pipe Every 15 Stands - Hit Tight Spot At 3,700' Break Circulation And Wash Thru Area (NO Problem) - Continue To RIH Washing Every Third Stand Down. 10:00 - 11 :00 1.00 DRILL P INT1 *NOTE* Continue With Planned Operations - Continue To RIH From 7,476' To 8,509' - Wash To Bottom From 8,509' To 8,979' 11:00 -18:00 7.00 DRILL P INT1 Drill Ahead From 8,978' To 9,550' Lost 25 BBLS. Drilling Mud - Monitor Well - Reduce Pump Rates And Drill To 9,570' - Mud Losses 75 Barrels Per Hour Shut Down - Weight On Bit 2K To 1 OK With Pump Rate At 130 Strokes Or 550 GPM - Off Bottom Pump Pressure At 2400 Psi. & On Bottom Pump Pressure At 2550 Psi. Top Drive RPM At 90 Off Bottom Torque At 15K & On Bottom Torque At 17K String Rotating Weight At 130K - With Pump On Drag Up At 225K And Drag Down At 75K. 18:00 - 19:30 1.50 DRILL P INT1 POH To Get Above Thief Zone - Pull 2 Stands - Well Swabbing - Pump Out At Very Slow Rate To Keep Hole Full To 8,700' 19:30 - 21:00 1.50 DRILL P INT1 Work Pipe And Reduce Mud Weight To 9.5 PPG. From 10.0 PPG. And Mix Up 20 lb. Per Bbl. LCM Pill - Hole Standing Full With No Circulation - Losses At 36 Barrel Per Hour During Circulation. 21 :00 - 00:00 3.00 DRILL P INT1 Pump LCM Pill And Stage In The Hole While Increasing Pump Rates On Each Stand To Previous Circulation Rates. Continue To String In LCM While Staging In The Hole. 9/17/2001 00:00 - 01 :30 1.50 DRILL P INT1 Continue To Stage In The Hole To 9,570' Increasing Pump Rates On Each Stand To Previous Circulation Rates While Monitoring Fluids. String In LCM While Staging In The Hole. 01 :30 - 16:00 14.50 DRILL P INT1 Drill Ahead From 9,570' To 10,767' - Weight On Bit 5K To 10K With Pump Rate At 125 Strokes Or 525 GPM - Off Bottom Pump Pressure At 2100 Psi. & On Bottom Pump Pressure At 2150 Psi. Top Drive RPM At 100 Off Bottom Torque At 13K & On Bottom Torque At 15K String Rotating Weight At 140K - With Pump On Drag Up At 21 OK And Drag Down At 90K. Fluid Losses At 2 To 3 Barrels Per Hour. 16:00 - 17:30 1.50 DRILL P INT1 Circulate And Condition Mud - Circulate Sweeps Around 17:30 - 22:30 5.00 DRILL P INT1 Monitor Well Bore (Static) - POH 5 Stands No Swabbing - Pump Dry Job - Continue To POH To 9,650' Pulling Tight And Swabbing - Connect Top Drive Pump Out Of The Hole To 9,500' - Pull Pipe To 8,700' (No Problems) - Pump Second Dry Job And POH To 103/4" Casing Shoe 22:30 - 00:00 1.50 DRILL P INT1 Slip And Cut 102' Of 1 3/8" Drilling Line 9/18/2001 00:00 - 00:30 0.50 DRILL P INT1 Finish cutting and slipping drill line. 00:30 - 01 :30 1.00 DRILL P INT1 Service top drive and crown 01 :30 - 05:30 4.00 DRILL P INT1 Trip in hole. No problems. Reamed last stand to bottom. 05:30 - 11 :00 5.50 DRILL P INT1 Pump sweep and circulate hole clean. Add lube-tex to bring the concentration up to 4%. Spot glass beads. 11:00-14:30 3.50 DRILL P INn Monitor well and pull five stands-no swabbing. Pump pill and stand back 60 stands 5" drill pipe in derrick. Record up, down and rotating wts every 5 stands in open hole. 14:30 - 18:00 3.50 DRILL P INn Turn elevators and continue pooh laying down 53 stands of 5 Printed: 10/8/2001 1:16:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/18/2001 9/19/2001 9/20/2001 ( ( Page 6 of 13 BP AMOCO Operations Summary Report MPI-11 MPI-11 DRILL +COMPLETE NABORS NABORS 22E From - To Hours Activity Code NPT 14:30 - 18:00 18:00 - 20:00 20:00 - 22:00 22:00 - 23:00 23:00 - 00:00 00:00 - 05:00 05:00 - 06:00 06:00 - 14:00 14:00 - 22:30 22:30 - 00:00 00:00 - 08:30 08:30 - 10:30 10:30 -13:00 13:00 - 14:00 14:00 - 15:00 15:00 -16:00 16:00 - 18:00 18:00 -19:00 19:00 - 00:00 3.50 DRILL 2.00 DRILL 2.00 DRILL P P P 1.00 DRILL 1.00 CASE P P 5.00 CASE P 1.00 CASE P 8.00 CASE P 8.50 CASE N RREP INT1 1.50 CASE P 8.50 CASE P 2.00 CASE P 2.50 CASE P 1.00 CASE 1.00 CASE P P 1.00 CASE 2.00 CASE P P 1.00 CASE 5.00 CASE P P INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 INT1 Start: 9/7/2001 Rig Release: 10/6/2001 Rig Number: Spud Date: 9/8/2001 End: 10/5/2001 Phase Description of Operations drill pipe. Lay down BHA. Clear rig floor. Pull wear bushing. Change top rams from 3 1/2" to 7". Test ram gates to 1000 psi. RU casing running tools & elevators. PJSM. RIH wI guidelreaming shoe, 2 its, and float collar(Baker locked shoe track). Start running in hole w/7 inch. Monitoring mud volume displaced by pipe & filling casing every 5 its. Continue running in hole with 7" 26# L-80 521 Hydril casing to the casing shoe. Circulate bottoms up at the casing shoe with 1 % EP mud rub. Record torque readings. 15 rpms -2000 ft Ibs torque. No losses Continue running in hole with 7" 26# L-80 521 Hydril casing to the casing shoe. On jt # 187 while slacking off the jt of casing the casing got wedged inside the pipe handler. Evaluated situation and removed the springs from the inside of the pipe guide and freed up the jt of casing. Pulled jt #187 out of the hole and laid it out. Laid down the pipe handler. Installed crossover with tiw valve. Circulate and reciprocate casing while pipe handler was being repaired. Pumped at 6 bpm with 240 psi. No losses. Removed, repaired, & re-installed damaged pipe handler on top drive. Continue running in hole with 7" 26# L-80 521 Hydril casing to the casing shoe. Recording PUW, SOW, & ROTW on data trend sheet. Circulating at 5 bpm, & rotating casing down on each joint using top drive & drive bushings. Hole condition is stable. Casing at 8013 at midnight report close-out time. Finish running 268jts 7" 26# L-80 521 Hydril casing. Make up hanger and land same. Shoe at 10,748'. Install cement head and break circulation slow. Increase rate to 8 bpm with 600 psi. No losses. Pumped 2 bottoms up. PJSM with all personnel. Pump 10 bbls water, test lines 3500 psi, followed by 10 more bbls of water. Mix and pump 50 bbls 10.5 ppg spacer. Mix and pump 1400 sxs(287bbls) Class"G"@15.8ppg. Pump 5 bls water and displace with rig pumps. Bump plug 3000 psi. crp @ 1300. Lost returns 30 bbls before bumping plug. Check floats and rig down casing equipment. LD landing it. Drain BOP stack. PU stand DP & RIH wI pack-off, install, & test to 5000 psi. Change 7 in. rams to 3 1/2 X 6" variable. Change top drive saver sub & stabbing guide to 3 1/2" DP. Change out iron roughneck to 3 1/2" equipment. RU test equipment. Conduct BOP test. Witnessing waived by AOGCC inspector. Test top pipe rams, choke manifold valves 1-18, floorvalves, dart valves to 250 psi low for 5 mins and 3500 psi high for 10 mins. Test annular preventer to 250 psi low and 2500 psi high. Test HCR valve, choke manual valves, blind rams, lower pipe rams to 250 psi low 7 3500 psi high. Test accumulator hydraulics to 3000 psi. Test inside BOP (top drive) to 250/3500psi. Printed: 10/8/2001 1: 16: 10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/21/2001 9/22/2001 9/23/2001 9/24/2001 ( ( BP AMOCO Operations Summary Report MPI-11 MPI-11 DRILL +COMPLETE NABORS NABORS 22E 00:00 - 02:00 From - To Hours Activity Code NPT INT1 02:00 - 02:30 02:30 - 05:30 05:30 - 07:00 07:00 - 10:30 10:30 - 00:00 00:00 - 02:00 02:00 - 02:30 02:30 - 03:30 03:30 - 07:00 07:00 - 08:00 08:00 - 08:30 08:30 - 12:00 12:00 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 02:30 02:30 - 03:00 03:00 - 04:00 04:00 - 06:30 06:30 - 07:30 07:30 - 12:00 12:00 - 23:00 23:00 - 00:00 00:00 - 01 :00 01 :00 - 08:30 08:30 - 10:30 10:30 - 12:00 12:00 - 16:30 2.00 CASE 0.50 CASE 3.00 CASE 1.50 CASE 3.50 DRILL 13.50 DRILL 2.00 DRILL 0.50 DRILL 1.00 DRILL 3.50 DRILL 1.00 DRILL 0.50 DRILL 3.50 DRILL 11.00 DRILL 1.00 DRILL 1.50 DRILL 1.00 DRILL 0.50 DRILL 1.00 DRILL 2.50 DRILL 1.00 DRILL 4.50 DRILL 11.00 DRILL 1.00 DRILL 1.00 DRILL 7.50 DRILL 2.00 DRILL 1.50 DRILL 4.50 DRILL Phase P P P P P INT1 INT1 INT1 PROD1 P PROD1 P PROD1 P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 P PROD1 P PROD1 P P P PROD1 PROD1 PROD1 P P P PROD1 PROD1 PROD1 P P PROD1 PROD1 P PROD1 P P P PROD1 PROD1 PROD1 P PROD1 P PROD1 P PROD1 Page 7 of 13 Start: 9/7/2001 Rig Release: 10/6/2001 Rig Number: Spud Date: 9/8/2001 End: 10/5/2001 Description of Operations Continue testing- upper & lower IBOP valves to 250 psi low & 3500 psi high. Laydown test equipment & blow down mud line, choke line, kill line, & gas buster lines. Install wear ring & run in 4 lock down screws. PU 81 jts 3 1/2", 13.3 Ibflft drillpipe. Rabbit and RIH. Stand back 27 stands drillpipe(for open hole section drilling). Clear drill floor. Pick-up and make-up BHA per Sperry directional. Pick-up 3 1/2" DP, rabbit, and RIH wi singles. Shallow test MWD. RIH to 10499 ft. Pipe "floating" into wellbore due to frictional drag. Start taking on new Baradril mud into rig pit system. Continue tripping in hole with directional bha. Picking up and rabbitting 3-1/2" drill pipe. Tag float collar@ 10,665'. Circulate bottoms up. Test 7" casing 3500 psi for 30 minutes on chart. good test. Drill float equipment and 30' new formation to 10, 797'. Circulate bottoms up before performing FIT. 9.6 ppg in and out. Perform FIT with 9.6 ppg mud. Did not break down formation with 280 psi. held pressure for 10 minutes. EMW=11.0 ppg Circulate and displace well with 9.2 ppg BARADRILN mud. Shakers blinding off. Shear mud & change shaker screens. Drill 6 1/8" horizontal borehole from 10797'-11917' in DB lateral. Circulate 25 bbl viscous sweeps at 11580' & 11911'. PUW 140,000. SOW 95,000, ROTW 112,000. 2300 psi on btm. 2100 psi off btm. 4000 -6000 ft-Ibf torque offlon btm. 80 RPM, 233 GPM. 9.2 ppg MW. ECD 11.2-12.3 ppg EMW. Circulate viscous sweep to clean hole. Prepare for short trip. Circulate & conditon mud to lower ECD Short tip to 7" casing at 10700'. Hole in good shape wI no adverse drag or tight spots. Blow down top drive & service rig. TIH from 10700 to 11917'. Wash & ream last stand to bottom. 11917-12100. Replace old mud wI 800 bbls new BaradrilN while drilling ahead. CBU to lower ECD. Drill 12100 to 12383'. PUW 130k, SOW 80k, ROM 105k, TOon 7000, TOoff 5000, 100 rpm, PSlon 2600, PSloff 2450, 59 spm, 248 gpm, 5-8k WOB. ECD 11.6-12.3 range. Drill 12383 to 13170' TD in the OB lateral. PUW 145000, SOW 85000, ROTW 112000, TQon-5k, TOoff 4k, 100 rpm, 55 spm, 250 gpm, 2600 PSI on, 2450 PSI off. 5-8k WeB. ECD 11.6-12.3. Circulate 2 btms up prior to POOH for hole opener run. Continue pumping sweep & CBU x2. Monitor wellbore 10 mins. POOH to 10716. Pump dry job. Blow down top drive. POOH to BHA Monitor well, clear floor. PU 2 jt drillpipe & stand back wi jars & flex NMDC's. Lay down HOC, MWD, float, motor, bit. Download MWD data in pipe shed. Pick up 2 stabilizers & pony collar. MU BHA porcupine hole opener. RIH to 11769 & stack out weight. Printed: 10/8/2001 1:16:10 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/24/2001 9/25/2001 9/26/2001 (' (' BP AMOCO Operations Summary Report MPI-11 MPI-11 DRILL +COMPLETE NABORS NABORS 22E From - To Hours Activity Code NPT 12:00 - 16:30 16:30 - 17:00 17:00 - 00:00 00:00 - 00:30 00:30 - 03:30 03:30 - 06:00 06:00 - 10:30 10:30 - 11 :00 11:00 -12:00 12:00 - 21:00 21 :00 - 22:30 22:30 - 00:00 00:00 - 01 :30 01 :30 - 04:30 04:30 - 05:00 05:00 - 10:00 10:00 - 15:30 15:30 - 16:30 16:30 - 20:30 4.50 DRILL 0.50 DRILL 7.00 DRILL 0.50 DRILL 3.00 DRILL 2.50 DRILL 4.50 DRILL 0.50 DRILL 1.00 DRILL 9.00 DRILL 1.50 DRILL 1.50 DRILL 1.50 DRILL 3.00 DRILL 0.50 DRILL 5.00 DRILL 5.50 DRILL 1.00 DRILL 4.00 DRILL Phase P P P PROD1 PROD1 PROD1 P P P P PROD1 PROD1 PROD1 PROD1 P P P PROD1 PROD1 PROD1 P PROD1 P PROD1 P P P PROD1 PROD1 PROD1 P PROD2 P PROD2 P PROD2 P PROD1 Page 8 of 13 Start: 9/7/2001 Rig Release: 10/6/2001 Rig Number: Spud Date: 9/8/2001 End: 10/5/2001 Description of Operations POOH to 10747. Wash & ream to 13125. ROTW 102k, PUW 130K, SOW 70k. TQon-5k, TQoff-4k. PSI 2900, 300 gpm, 12 0 spm. Wash down wi 2-6k weight on btm. Continue to wash & ream to btm. 13125-13170'. CBU x2. Spot 100 bbls new mud in OA lateral. Monitor well. POOH to 7 in shoe at 10748. Monitor well. Pump dry job, blow down top drive & mud line. POOH 10748' to 216'. Monitor well. LD BHA #4(hole opener). Clear floor. RU 4 1/2" liner running tools. Run 41/2", 12.6#, L80 BTC: guide shoe, solid joint, pack off bushing, 61 jts slotted, 4 jts solid, pup, XO, HMC LH, ZXP packer in hole. See casing report for details. MU liner hanger & RIH. Break circulation at 10748'. RIH to 13170 & tag TD. Set liner hangerlpacker as follows: Drop 7/8" brass ball & pump to seat. Pressure to 2000 psi. Hanger set at 1450 psi. Slack off 20K weight to set hanger. Pressure to 2000 psi to release setting tool. PU 5' to open setting dogs. Bleed pressure. Slack off 3X to weight set packer(25K needed at liner top). Rotate & spud on liner top. Blow ball seat wi 3800 psi. Rotate & spud 6X to ensure setting weight reached packer. Pump dry job. Blow down top drive & mud line. POOH to 9666' CUT AND SLIP DRILLING LINE. POOH FROM 9666' TO LINER RUNNING TOOL. MONITOR WELL. LAY DOWN RUNNING TOOL. CLEAR FLOOR. PU MILLS, XO, HANG-OFF SUB, BUMPER SUB,. PU SEAL ASSEMBLY, UNLOADER SUB, 6- 3 1/2" DP, 1-HWDP. MU MILLS TO HWDP. PU BAKER BOTTOM TRIP WHIPSTOCK. RIH. PU MWD, HOS. SCRIBE & ALIGN WHIPSTOCK TO MWD. UPLOAD MWD. MU BUMPER SUB & 9- 4 3/4" DC's, 18 HWDP. RIH 1 STAND & SHALLOW TEST MWD. BLOW DOWN TOP DRIVE & MUD LINE. RIH WI WHIPSTOCK AT 1.5 MIN TO 2 MIN PER STAND. SEAL ASSEMBLY AT 10542'. ORIENT & SET WHIPSTOCK 9 DEG RIGHT OF HIGH SIDE AT 10345'. RECORD 135K PUW, 95k SOW. SLACK OFF TO STING IN WI SEAL ASSEMBLY INTO LINER TOP. (7' INTO TIEBACK RECEPTACLE). STING IN & OUT 3X. TO VERIFY SEALS LANDED. SLACKOFF 20k WEIGHT TO SET BOTTOM TRIP ANCHOR. WHIPSTOCK SET AT 10345'. DID NOT SEE WEIGHT FALL OFF. PU TO VERIFY OVERPULL OF 10K. SET DOWN TO SHEAR BOLT AND WEIGHT INDICATOR DID NOT INDICATE BOLT SHEAR. USE BUMPER SUB TO SHEAR BOLT 3X. PU TO NEUTRAL AND BEGIN SLOW ROTATION. OBSERVED THAT SHEAR HAD OCCURRED. MILL 6.151 INCH WINDOW IN 7 INCH CASING FROM 10345' TO 10357'. MILL FORMATION 10357' TO 10373'. WORK Printed: 10/8/2001 1:16:10 PM { (' BP AMOCO Page 9 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/26/2001 16:30 - 20:30 4.00 DRILL P PROD1 MILLS MULTIPLE PASSES ACROSS WINDOW DEPTH. 20:30 - 23:30 3.00 DRILL P PROD2 PUMP 25 BBL VISCOUS SWEEP & CIRCULATE BOTTOMS UP. CONDUCT F.I.T TO 13 PPG EMW. CLOSED ANNULAR PREVENTERAROUND 31/2" DP. PUMPED DOWN DP AND ANNULUS- PRESSURED UP 5 SPM INCREMENTALLY TO 690 PSI(9.3 PPG, 3600 TVD). SHUT PUMPS IN. PRESSURE FELL OFF IMMEDIATEL YTO 450 PSI FOR AN F.I.T. OF 11.7 PPG EMW. 23:30 - 00:00 0.50 DRILL P PROD2 START DISPLACING 260 BBLS HOLE VOLUME WI FRESH BARADRILN MUD. 900 BBLS NEW MUD ON LOCATION. DISPLACE OLD MUD TO VAC TRUCKS FOR HAUL-OFF TO DISPOSAL. 9/27/2001 00:00 - 01 :30 1.50 DRILL P PROD2 POOH FROM 10773' TO 10221'. PUMP DRY JOB, BLOW DOWN TOP DRIVE & MUD LINE. CONTINUE POOH TO 8172'. 01 :30 - 02:30 1.00 DRILL P PROD2 SERVICE RIG & TOP DRIVE. 02:30 - 03:30 1.00 DRILL N RREP PROD2 REPAIR BYPASS VALVE ON IRON ROUGHNECK. 03:30 - 06:00 2.50 DRILL N PROD2 CONTINUE TO POOH 8172 TO 930'. 06:00 - 07:30 1.50 DRILL N PROD2 STAND BACK 6 STANDS HWDP. LD STEEL DC'S. 07:30 - 09:00 1.50 DRILL N PROD2 DOWNLOAD MWD. LD MILLS & HWDP. MU MOTOR TO MWD & STAND BACK. 09:00 - 10:00 1.00 DRILL N PROD2 CLEAR FLOOR. MU BOP WASH-OUT TOOL TO 1 STAND DP. FLUSH BOP STACK OF ANY MILL CUTTINGS. BLOW-DOWN TOP DRIVE & MUD LINE. LAY DOWN WASH TOOL. 10:00 -18:30 8.50 DRILL P PROD2 PULL WEAR RING. RU FOR BOP TEST. START BOP TEST 250 PSI LOW & 3500 PSI HIGH. AOGCC'S JOHN SPAULDING VERBALLY WAIVED WITNESSING THE TEST. TESTED ANNULAR, MANUAL CHOKE, HCR CHOKE, LOWER PIPE RAMS, BLIND RAMS, CHOKE VALVES, UPPER IBO. LOWER IBOP FAILED TEST. PRESSURE TEST ACCUMULATOR HYDRAULICS. REMOVE TEST PLUG & INSTALL WEAR RING. BLOW-DOWN CHOKE & KILL LINE. 18:30 - 22:00 3.50 DRILL N RREP PROD2 CHANGE-OUT LOWER IBOP. 22:00 - 22:30 0.50 DRILL P PROD2 FINISH BOP TEST ON LOWER IBOP. 22:30 - 00:00 1.50 DRILL P PROD2 MU BIT, STABILIZER, ADJ MOTOR(1.5 BEND). ORIENT HIGH SIDE TO MWD. LAY-OUT HOC & INSTALL NEW PULSER. MU HOC. 9/28/2001 00:00 - 01 :00 1.00 DRILL P PROD2 LOAD MWD. MU 3 STEEL FLEX DC'S. PU JARS. 01 :00 - 05:30 4.50 DRILL P PROD2 RIH W/1 STD DP AND SHALLOW TEST MWD OK. RIH, FILLING DP EVERY 30 STANDS TO 10251'. 05:30 - 06:00 0.50 DRILL P PROD2 ORIENT TO HIGH SIDE & LOWER BHA ACROSS WHIPSTOCK AND OUT CASING WINDOW WI PUMPS OFF. NO PROBLEMS ACROSS WINDOW. 06:00 - 08:30 2.50 DRILL P PROD2 DRILL 10367'-10529'. - 08:30 - 10:30 2.00 DRILL N RREP PROD2 REPAIR OIL PUMP ON TOP DRIVE 10:30 - 00:00 13.50 DRILL P PROD2 DRILL 10529' TO 11546'. 25 BBL VISCOUS SWEEP PUMPED TO LOWER ECD,FROM 12.2 TO 11.8 EMW. 9/29/2001 00:00 - 10:30 10.50 DRILL P PROD2 DRILL 11546' TO 12383'. AT APPROX 0130 HRS DISPLACED HOLE & MUD SYSTEM WITH NEW BARADRILN MUD. MUD AIRED UP AND CAUSED PROBLEMS wrTH MWD COMMUNICATIONS. PUW 125K, SOW 90K, ROTW '1c Printed: 10/8/2001 1:16: 10 PM (' ( BPAMOCO Page 10 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 9/29/2001 00:00 - 10:30 10.50 DRILL P PROD2 105K, PSI-ON BTM 2600, PSI OFF BTM 2450, RPM 80-90, WOB 5K-8K, 58 SPM, 247 GPM, 12.6 ECD MAX. 10:30 - 11:30 1.00 DRILL P PROD2 FINISHED CIRCULATING VISCOUS SWEEP & JETTED TO VAC TRUCKS. 11 :30 - 12:30 1.00 DRILL P PROD2 DRILL 12383' TO 12477'. MUD AIRED UP AND CAUSED PROBLEMS WITH MWD COMMUNICATIONS. PUW 125K, SOW 90K, ROìW 105K, PSI-ON BTM 2600, PSI OFF BTM 2450, RPM 80-90, WOB 5K-8K, 58 SPM, 247 GPM, 12.6 ECD MAX. 12:30 - 13:00 0.50 DRILL N PROD2 CHECKED PUMP SUCTION SCREENS AND FOUND THEY WERE NOT PLUGGED. CONTINUE ADDING DEFOAMER TO MUD SYSTEM TO ELIMINATE ENTRAINED AIR. 13:00 - 22:00 9.00 DRILL P PROD2 PUMPED 25 BBL VISCOUS SWEEP AT 1630HRS. DRILLED TO 13190' TD AT 2200 HRS. 22:00 - 00:00 2.00 DRILL P PROD2 PUMPED 25 BBLS VISCOUS SWEEP, RECIPROCATED, & ROTATED WHILE CIRCULATING PRIOR TO SHORT TRIP TO CASING. 9/30/2001 00:00 - 01 :00 1.00 DRILL P PROD2 CIRCULATE & CONDITION MUD. MONITOR WELL FOR 10 MINS. STABLE. 01 :00 - 04:30 3.50 DRILL P PROD2 POOH WI 5 STANDS SLOWLY & MONITOR FOR SWABBING. PUMP OUT OF HOLE EVERY 3RD STAND DUE TO SWABBING. PULL BHA INTO CASING & CIRCULATE BOTTOMS UP. 04:30 - 07:30 3.00 DRILL P PROD2 TIH 10251'-12550'. WORK PIPE TO 12575' & BEGIN STACKING OUT WEIGHT. WASH & REAM 12575'. 12845'. TIH TO 13090'. WASH & REAM TO 13190'. TORQUE 3-4K FT-LBF. PUW 130K, SOW 90K, ROìW 105K AT 80 RPM, 245 GPM. 07:30 - 12:00 4.50 DRILL P PROD2 CCM MUD & PUMP VISCOUS, WEIGHTED SWEEP. PUMP 2ND SWEEP DUE TO EXCESS CUTTINGS OBSERVED ACROSS SHAKER SCREENS. 12:00 - 12:30 0.50 DRILL P PROD2 CIRCULATE. SHUT DOWN PUMPS & MONITOR WELL F/10 MINS. 12:30 - 16:30 4.00 DRILL P PROD2 POOH TO 12662'. PUMP OUT TO 10215' DUE TO SWABBING. POOH TO 9787'. 16:30 - 17:00 0.50 DRILL P PROD2 PUMP DRY JOB. BLOW DOWN TOP DRIVE & MUD LINE. 17:00 - 21 :00 4.00 DRILL P PROD2 POOH & STAND BACK DC'S & JARS. 21 :00 - 23:30 2.50 DRILL P PROD2 DOWN LOAD MWD & PWD DATA. REMOVE PULSER, LD HOC, RES-GAMMA, ABI, PWD, FLOAT, MUD MOTOR, & BIT. 23:30 - 00:00 0.50 DRILL P PROD2 INSTALL NEW MASTER BUSHINGS ON RIG FLOOR. 10/1/2001 00:00 - 01 :30 1.50 DRILL P PROD2 PU HOLE OPENER BHA CONSISTING OF 61/8" STRAIGHT BLADED, BUTTON INSERT, HOLE OPENER, NM PONY COLLAR, IBS, FS, NMDC, IBS, 2 NMDC, JARS, 1 STD HWDP. 01 :30 - 02:30 1.00 DRILL P PROD2 SERVICE RIG TOP DRIVE, CROWN, BLOCKS, IRON ROUGHNECK. 02:30 - 07:30 5.00 DRILL P PROD2 TIH WI HOLE OPENER ASSEMBLY 10500'. RECORDING EVERY 1000'. OFF BTM: PUW 132K, SOW 90K, ROTW 112K, 4000 FT-LBF TORQUE. 07:30 - 16:00 8.50 DRILL P PROD2 WASH & REAM 10500' TO 13190' AT 300 GPM, 120 RPM, 900 FPH. NO HOLE PROBLEMS ENCOUNTERED. FREEZE PROTECTED 10 3/4" X 7" ANNULUS WITH 1 30 BBLS DIESEL OIL AT 1-2 BPM, 2000 PSI. Printed: 10/8/2001 1:16: 10 PM (' (" BP AMOCO Page 11 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 10/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1011/2001 16:00 - 17:30 1.50 DRILL P PROD2 CIRCULATE BOTTOMS UP & PUMP 25 BBLS WEIGHTED SWEEP. CONTINUE TO CARRY CUTTINGS, SAND, SLUDGE OVER SHAKERS AFTER SWEEP REACH SURFACE. 17:30 - 22:00 4.50 DRILL P PROD2 PUMP 2ND 25 BBL WEIGHTED SWEEP. SPOT 100 BBL LINER RUNNING PILL WI 4% LUBE-TEX CONC. IN OPEN HOLE. 22:00 - 00:00 2.00 DRILL P PROD2 TOOH WI HOLE OPENER ASSEMBLY to 10841'. 10/2/2001 00:00 - 00:30 0.50 DRILL P PROD2 POH TO WINDOW MONITOR WELL BORE (STATIC) 00:30 - 05:30 5.00 DRILL P PROD2 PUMP DRY JOB AND CONTINUE TO POH - RECORD UP, DOWN, AND ROTATING WEIGHTS EVERY 1000 FEET IN CASED HOLE 05:30 - 06:30 1.00 DRILL P PROD2 LAY DOWN BHA AND CLEAR RIG FLOOR 06:30 - 07:30 1.00 DRILL P PROD2 SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES 07:30 - 10:30 3.00 DRILL P PROD2 PICK UP BHA ORIENT FIXED LUG RETRIEVING TOOL WITH MWD AND SURFACE TEST SAME 10:30 -14:30 4.00 DRILL P PROD2 HOLD PRE-JOB SAFETY MEETING - RIH WITH 3 1/2" DRILL PIPE FROM MAST TO 10,290' 14:30 -15:30 1.00 DRILL P PROD2 ORIENT BAKER RET. TOOL - JET WHIPSTOCK FACE AND RETRIEVAL SLOT - LATCH ONTO WINDOW MASTER WHIPSTOCK AND CONFIRM LUG LANDED IN SLOT - JAR FREE TO COMPLETE RECOVERY OPERATION - MONITOR WELL BORE (STATIC) 15:30 - 17:00 1.50 DRILL P PROD2 SPOT BAROID E.P. MUD LUBE - PUMP DRY JOB AND BLOW DOWN TOP DRIVE AND MUD LINE 17:00 - 20:30 3.50 DRILL P PROD2 HOLD PRE-JOB SAFETY MEETING - POH WITH WHIPSTOCK ASSEMBLY TO 5,931 - PULL SLOW TO OBTAIN PROPER HOLE FILL 20:30 - 22:00 1.50 DRILL P PROD2 SLIP AND CUT 121' OF 1 3/8" DRILLING LINE 22:00 - 00:00 2.00 DRILL P PROD2 CONTINUE TO POH TO 550' 10/3/2001 00:00 - 03:00 3.00 DRILL P PROD2 CONTINUE TO POH WITH 3 1/2" DRILL PIPE - LAY DOWN 4 3/4" DRILL COLLARS, BAKER FISHING TOOLS, AND WINDOW MASTER WHIPSTOCK ASSEMBLY (FULL RECOVERY) 03:00 - 05:00 2.00 DRILL P PROD2 CUT AND SLIP DRILLING LINE DUE TO BAD SPOT ON LINE. RESTRING BLOCK HANGING LINE 05:00 - 06:00 1.00 DRILL P PROD2 SERVICE TOP DRIVE, TRAVELING BLOCKS, AND CROWN SHEAVES 06:00 - 07:00 1.00 DRILL P PROD2 CLEAR RIG FLOOR OF BAKER FISHING TOOLS AND WHIPSTOCK ASSEMBL Y 07:00 - 07:30 0.50 CASE P COMP RIG UP CASING TOOLS AND EQUIPMENT. HOLD PRE-JOB SAFETY MEETING. 07:30 - 11 :00 3.50 CASE P COMP PICK UP 70 JOINTS OF 12.6 LB. L-80 IBT 41/2" SLOTTED LINER AND BAKER WALL HOOK HANGER RIH PER WELL PROGRAM 11 :00 - 11 :30 0.50 CASE P COMP RIG DOWN CASING TOOLS AND EQUIPMENT - CLEAR RIG FLOOR 11 :30 - 15:30 4.00 CASE P COMP RIH WITH 41/2" LINER ON 31/2" DRILL PIPE FROM MAST (SLM) TO 10,357'. PULL BACK TO MIDDLE OF WINDOW. 15:30 - 17:00 1.50 CASE P COMP ORIENT BENT JOINT AND WORK THRU WINDOW OF UPPER LATERAL - CONTINUE TO RIH TO 13,090' -CHECK AND RECORD UP AND DOWN WEIGHTS - CONTINlJ E TO Printed: 10/8/2001 1:16:10PM ( (' BP AMOCO Page 12 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 1 0/5/2001 Contractor Name: NABORS Rig Release: 1 0/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/3/2001 15:30 - 17:00 1.50 CASE P COMP RIH TO 13,120' AND ENGAGE HOOK HANGER IN WINDOW - SLACK OFF LINER WEIGHT PLUS 16,000 LBS. SETTING HANGER 17:00 - 18:00 1.00 CASE P COMP BREAK CIRCULATION - DROP BALL - PUMP 77 BARRELS AND PREASURE UP TO 3,000 PSI. TO RELEASE SETTING TOOL AND SHEAR BALL SEAT - PICK UP AND VERIFY THAT TOOL RELEASED - RECORD UP AND DOWN WEIGHTS 18:00 - 20:30 2.50 CASE P COMP CIRCULATE AND DISPLACE WELL TO 9.2 PPG BRINE - ROTATE AT 50 RPM AND RECIPROCATE WORK STRING 20:30 - 00:00 3.50 CASE P COMP MONITOR WELL BORE (STATIC) - BLOW DOWN TOP DRIVE AND MUD LINE - HOLD PRE-JOB SAFETY MEETING - POH LAYING DOWN 3 1/2" DRILL PIPE AND LINER RUNNING ASSEMBL Y 10/4/2001 00:00 - 03:00 3.00 CASE P COMP POH AND LAY DOWN 31/2" DRILL PIPE 03:00 - 04:00 1.00 CASE N RREP COMP REPAIR HYDRAULIC LEAK ON VARCO IRON RUFFNECK 04:00 - 06:00 2.00 CASE P COMP CONTINUE TO LAY DOWN 31/2" DRILL PIPE AND BAKER LINER RUNNING TOOLS 06:00 - 07:00 1.00 CASE P COMP CLEAR AND CLEAN RIG FLOOR - PICK UP TUBING RUNNING EQUIPMENT 07:00 - 11 :00 4.00 CASE P COMP LAY DOWN 31/2" DRILL PIPE FROM MAST IN MOUSE HOLE 11 :00 - 12:00 1.00 BOPSU¡:; P COMP PULL WEAR RING - INSTALL TEST PLUG 12:00 - 14:00 2.00 BOPSU¡:; P COMP REMOVE 31/2" X 6" VARIBLE RAMS FROM TOP GATE AND INSTALL 2 718" RAMS. *NOTE* BOP TEST DUE ON 10104/2001 WAS EXTENDED BY AOGCC REPRESENTIVE CHUCK SCHEVE 14:00 -15:00 1.00 BOPSUF P COMP MAKE UP PUMP IN SUB AND FLOOR VALVE - RIG UP TESTING EQUIPMENT - TEST DOOR SEALS AT 1,800 PSI. - RIG DOWN TEST EQUIPMENT 15:00 -17:00 2.00 RIGU P COMP HOLD PRE-JOB SAFETY MEETING WITH NABORS ALASKA DRILLING AND CENTRILIFT PERSONAL - RIG UP SPOOLING UNIT AND HANG SHEAVE FOR ESP CABLE 17:00 - 19:00 2.00 RUNCO~ Ip COMP PICK UP AND SERVICE BAKER HUGHES CENTRILIFT MODEL GPDIS PUMP 19:00 - 20:00 1.00 RUNCO~ Ip COMP RIG UP TUBING TONGS AND BACK UPS - MAKE UP CROSS OVER TO FULL OPENING SAFETY VALVE 20:00 - 00:00 4.00 RUNCO~ Ip COMP PICK UP AND RIH WITH 2 7/8" 6.5 LB. L-80 (EUE 8-ROUND) COMPLETION STRING PER WELL PROGRAM (116 JOINTS RAN AT 00:00 HOURS) 10/5/2001 00:00 - 06:00 6.00 RUNCO~ Ip COMP RIH WITH 2 7/8" COMPLETION STRING. 06:00 - 10:00 4.00 RUNCO~ Ip COMP INSTALL NEW REEL OF ESP CABLE AND SPLICE SAME. 10:00 - 15:30 5.50 RUNCO~ Ip COMP CONTINUE TO RIH WITH BAKER HUGHES CENTRILIFT ESP PER WELL PROGRAM - RUN 321 JOINTS OF 27/8" 6.5 LB. L-80 TUBING WITH EUE (8 ROUND) COUPLINGS - INSTALL TWC IN FMC TUBING HANGER AND MAKE UP- INSTALL PENETRATOR ON FMC HANGER. 15:30 - 16:00 0.50 RUNCO~ '" COMP RIG DOWN TUBING TONGS AND EQUIPMENT - CLEAR RIG FLOOR. 16:00 -18:00 2.00 RUNCO~ Ip COMP CUT ESP CABLE - MAKE UP EFT LOWER CONNECTION - CHECK ESP CONDUCTIVITY PHASE TO PHASE TO Printed: 10/8/2001 1:16: 10 PM t' !"" ( BP AMOCO Page 13 of 13 Operations Summary Report Legal Well Name: MPI-11 Common Well Name: MPI-11 Spud Date: 9/8/2001 Event Name: DRILL +COMPLETE Start: 9/7/2001 End: 1 0/5/2001 Contractor Name: NABORS Rig Release: 10/6/2001 Rig Name: NABORS 22E Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 10/5/2001 16:00 - 18:00 2.00 RUNCO~ ~ COMP GROUND ON ALL THREE PHASES AND CONFIRM BALANCED CONDUCTIVITY WITH CENTRILIFT REPRESENTIVE. 18:00 - 19:30 1.50 RUNCO~ ~ COMP DRAIN BOP STACK - RECORD COMPLETION STRING UP WEIGHT AT 102K AND DOWN WEIGHT AT 80K - LAND TUBING HANGER AND ENERGIZE LOCK DOWN STUDS - RIG UP TESTING EQUIPMENT AND TEST TWC AT 2,500 PSI. RIG DOWN TEST EQUIPMENT - BACK OUT AND LAY DOWN LANDING JOINT - CLEAR RIG FLOOR 19:30 - 21:30 2.00 RUNCO~ P COMP BLOW DOWN MUD LINE AND SURFACE EQUIPMENT - CHANGE PIPE RAMS IN TOP GATE TO 31/2" X 6" VARIABLES - NIPPLE DOWN BOP AND RELATED EQUIPMENT 21 :30 - 23:30 2.00 RUNCO~ P COMP NIPPLE UP FMC TUBING HEAD ADAPTOR AND TEST TUBING HANGER TO 5,000 PSI. (OK) - NIPPLE UP FMC 2 9/16" 5M TREE REMOVE MANUMATIC WING VALVE AND INSTALL MANUAL WING VALVE. 23:30 - 00:00 0.50 RUNCO~ P COMP RIG UP TO PRESSURE TEST FMC TREE 10/6/2001 00:00 - 01 :00 1.00 RUNCO~ P COMP HOLD PRE-JOB SAFETY MEETING - TEST FMC TREE TO 5,000 PSI. (OK) 01:00 - 01:30 0.50 RUNCO~ P COMP MAKE FINAL ESP CONDUCTIVITY TEST (OK) 01 :30 - 02:30 1.00 RUNCO~ P COMP RIG UP LUBRICATOR PULL TWO WAY CHECK VALVE AND INSTALL BACK PRESSURE VALVE 02:30 - 06:00 3.50 RUNCO~ P COMP CLEAN MUD SYSTEM - PUMP OUT CELLAR - CHANGE TOP DRIVE END BELL GUIDE AND SAVER SUB TO ACCEPT 5" DRILL PIPE - LAY DOWN 2 7/8" AND 31/2" COMPLETION EQUIPMENT TOOLS - PICK UP 5" HANDLING EQUIPMENT - INSTALL TREE CAP AND NEEDLE VALVES - CLOSE ALL VALVES SECURE WELLHEAD AND TREE. *NOTE* RIG RELEASED FROM MPI-11 AT 06:00 HOURS Printed: 10/8/2001 1: 16: 1 0 PM ( ,f l( 06-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Surveys Re: Distribution of Survey Data for Well MPI-11 L 1 dol- 13 ~ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,251.03' MD Window / Kickoff Survey 10,345.00' MD Projected Survey: 13,190.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) E'('" """".. , ~ "I '~" "ø3,,~EIVE() I\/DV 0 7 2001 A~aska Oil & Gas COI'JS '^' '. , \..ommBSWon Ancf?arage DEFINITIVE Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-11 MPI-11L 1 Job No. AKZZ11151, Surveyed: 29 September, 2001 SURVEY REPORT 5 November, 2001 Your Ref: API 500292303360 Surface Coordinates: 6009456.78 N, 551405.11 E (70026' 11.7158" N, 149034' 51.1850" W) Kelly Bushing: 63.55ft above Mean Sea Level 5 pe ..... ..... y - S U ., CRILLING SERVICES A Halliburton Company ~-,' ~ Survey Ref: svy9934 Sperry-Sun Drilling Services Survey Report for MPI-11 L 1 Your Ref: API 500292303360 Job No. AKZZ11151, Surveyed: 29 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) .(ft) (ft) (°/1 OOft) 10251.03 75.560 263.520 3510.47 3574.02 1372.165 8400.63 W 6008026.75 N 543014.14 E 8511.75 Tie On Point .-. .~ 10345.00 76.900 263.610 3532.84 3596.39 1382.39 5 8491,32 W 6008015.90 N 542923.52 E 1 .429 8602.94 Window Point 10368.38 78.780 263.760 3537.76 3601.31 1384.90 5 8514.04 W 6008013.23 N 542900.82 E 8.065 8625,77 10412.95 81.850 264.040 3545.26 3608.81 1389.57 5 8557.72 W 6008008.26 N 542857.17 E 6.916 8669.65 10461.05 85.260 264.320 3550.66 3614.21 1394.42 5 8605.26 W 6008003.08 N 542809.66 E 7.113 8717.37 10506.44 86.310 264.580 3553.99 3617.54 1398.79 S 8650.32 W 6007998.40 N 542764.64 E 2.383 8762.56 10552.89 89.450 264.830 3555.71 3619.26 1403.085 8696.53 W 6007993,80 N 542718.46 E 6.781 8808.88 10601.88 90.430 267.640 3555.76 3619.31 1406.29 S 8745.41 W 6007990.24 N 542669.60 E 6.075 8857.67 10648.09 91.970 268.260 3554.79 3618.34 1407.955 8791.58 W 6007988.27 N 542623.45 E 3.592 8903.54 10691.59 92.280 267.490 3553.18 3616.73 1409.56 5 8835.02 W 6007986.36 N 542580.02 E 1.907 8946.71 10741.23 93.510 265.540 3550.67 3614.22 1412.575 8884.50 W 6007983.01 N 542530.56 E 4.640 8996.06 10786.27 90.860 264.500 3548.96 3612.51 1416.48 S 8929.33 W 6007978.79 N 542485.75 E 6.320 9040.96 10833.95 90.120 264.240 3548.55 3612.10 1421.155 8976.78 W 6007973.79 N 542438.34 E 1.645 9088.56 10875.77 88.460 263.940 3549.07 3612.62 1425.46 5 9018.37 W 6007969.19 N 542396.78 E 4.034 9130.32 10925.56 89.380 264.390 3550.01 3613.56 1430.525 9067.90 W 6007963.79 N 542347.29 E 2.057 9180.03 10973.75 89.260 264.360 3550.58 3614.13 1435.24 S 9115.85 W 6007958.74 N 542299.37 E 0.257 9228.14 11016.38 90,250 261.440 3550.76 3614.31 1440.51 5 9158.15W 6007953.18 N 542257,11 E 7.232 9270.74 11062.68 92.220 263.070 3549.76 3613.31 1446.755 9204.01 W 6007946.62 N 542211.29 E 5.522 9317.02 ,'='F", 11107.50 88.890 262.880 3549.33 3612.88 1452.235 9248.49 W 6007940.84 N 542166.85 E 7.442 9361.81 11152.81 88.950 262.620 3550.18 3613.73 1457.955 9293.43 W 6007934.81 N 542121.95 E 0.589 9407.09 11198.01 88.650 262.290 3551.13 3614.68 1463.88 S 9338.22 W 6007928.57 N 542077.20 E 0.987 9452.27 11244.43 88.150 262.880 3552.43 3615.98 1469.87 S 9384.24 W 6007922.26 N 542031.23 E 1.666 9498.65 11291.72 90.620 261.760 3552.93 3616.48 1476.19 S 9431.10 W 6007915.62 N 541984.41 E 5.735 9545.93 11334.66 90.550 262.430 3552.49 3616.04 1482.09 S 9473.63 W 6007909.42 N 541941.92 E 1.569 9588.86 11383.09 90.430 260,060 3552.08 3615.63 1489.47 S 9521.49 W 6007901.72 N 541894.12 E 4.900 9637.28 11429.88 90.180 259.740 3551.83 3615.38 1497.67 S 9567.55 W 6007893.20 N 541848.11 E 0.868 9684.06 11475.65 90.120 258.900 3551.71 3615.26 1506.15S 9612.53 W 6007884.41 N 541803.19 E 1.840 9729.81 11519.67 91.410 258.190 3551.12 3614.67 1514.89 S 9655.67 W 6007875.37 N 541760.12 E 3.345 9773.78 11568.35 91.790 258.460 3549.76 3613.31 1524.74 S 9703.32 W 6007865.19 N 541712.53 E 0.957 9822.38 11608.17 91.970 259.060 3548.46 3612.01 1532.50 S 9742.35 W 6007857.17 N 541673.55 E 1.572 9862.15 5 November, 2001 - 17:12 Page 2 of 5 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11L 1 Your Ref: API 500292303360 Job No. AKZZ11151, Surveyed: 29 September, 2001 . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11660.91 90.740 257.920 3547.21 3610.76 1543.02 S 9794.02 W 6007846.29 N 541621.96 E 3.179 9914.81 -- ~- 11707.53 90.250 258.760 3546.81 3610.36 1552.44 S 9839,67 W 6007836.56 N 541576.37 E 2.086 9961.38 11752.50 90.250 258.500 3546.61 3610.16 1561.31 S 9883.76 W 6007827.39 N 541532.35 E 0.578 10006.30 11803.34 90.620 257.070 3546.23 3609.78 1572.06 S 9933.45 W 6007816.29 N 541482.74 E 2.905 10057.05 11843.00 90.550 256.450 3545.82 3609.37 1581.14 S 9972.05 W 6007806,94 N 541444.20 E 1.573 10096.60 11892.63 90.680 256.220 3545.29 3608.84 1592.87 S 10020.27 W 6007794.88 N 541396.05 E 0.532 10146.05 11941.11 92.030 259.560 3544.14 3607.69 1603.04 S 10067,65 W 6007784.39 N 541348.75 E 7.429 10194.43 11983.49 91.480 259.020 3542.84 3606.39 1610.91 S 10109.27 W 6007776.23 N 541307.18 E 1.818 10236.77 12031.08 91.910 262.390 3541.44 3604.99 1618.59 S 10156.21 W 6007768.23 N 541260.30 E 7.136 10284.33 12076.43 91.850 262.050 3539.95 3603.50 1624.73 S 10201.12 W 6007761.78 N 541215.43 E 0.761 10329.65 12129.35 91.170 261.04(} 3538.55 3602.10 1632.50 S 10253.45 W 6007753.64 N 541163.16 E 2.300 10382.55 12172.39 92.580 262.190 3537.14 3600.69 1638.78 S 10296.00 W 6007747.08 N 541120.65 E 4.227 10425.56 12220.57 93.260 263.340 3534.69 3598.24 1644.84 S 10343.73 W 6007740.69 N 541072.96 E 2.770 10473.66 12268.57 92.150 264.650 3532.43 3595.98 1649.85 S 10391.42 W 6007735.34 N 541025.31 E 3.575 10521.54 12311.83 92.030 264.200 3530.85 3594.40 1654.05 S 10434.44 W 6007730.85 N 540982.32 E 1.076 10564.70 12358.11 91.540 263.300 3529.41 3592.96 1659.09 S 10480.42 W 6007725.49 N 540936.37 E 2.213 10610.91 12407.50 92.590 264.020 3527.63 3591.18 1664.54 S 10529.48 W 6007719.71 N 540887.35 E 2.577 10660.22 12450.73 92.460 264.710 3525.72 3589.27 1668.78 S 10572.46 W 6007715.17 N 540844.40 E 1.623 10703.34 -.-~ 12498.14 92.220 264.100 3523.79 3587.34 1673.40 S 10619.60 W 6007710.23 N 540797.29 E 1.382 10750.63 12546.17 92.280 263.700 3521.90 3585.45 1678.50 S 10667.32 W 6007704.80 N 540749.61 E 0.841 10798.57 12592.64 93.330 264.270 3519.63 3583.18 1683.36 S 10713.48 W 6007699.62 N 540703.48 E 2.570 10844.92 12636.69 93.700 265.270 3516.93 3580.48 1687.37 S 10757.27 W 6007695.31 N 540659.73 E 2.417 10888.80 12686.38 94.000 266.200 3513.59 3577.14 1691.06 S 10806.71 W 6007691.28N 540610.32 E 1.963 10938.22 12730.24 92.710 266.010 3511.02 3574.57 1694.03 S 10850.39 W 6007688,00 N 540566.66 E 2.973 10981.83 12775.44 92.460 265.720 3508.98 3572.53 1697.29 S 10895.42 W 6007684.44 N 540521.64 E 0.847 11026.83 12822.22 91.970 265.710 3507.18 3570.73 1700.78 S 10942.04 W 6007680.62 N 540475.05 E 1.048 11073.43 12867.73 91.790 265.330 3505.68 3569.23 1704.33 S 10987.39W 6007676.76 N 540429.73 E 0.924 11118.78 12915.17 91.480 265.040 3504.33 3567.88 1708.31 S 11034.64 W 6007672.45 N 540382.51 E 0.895 11166.08 12960.98 91.970 264.580 3502.95 3566.50 1712.45 S 11080.24 W 6007667.99 N 540336.94 E 1 .467 11211.77 13006.63 91.480 264,060 3501.58 3565.13 1716.97 S 11125.65 W 6007663.17 N 540291.56 E 1.565 11257.33 ------_u -, -.--_._-------- 5 November, 2001 - 17:12 Page 3 of 5 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11L 1 Your Ref: API 500292303360 Job No. AKZZ11151, Surveyed: 29 September, 2001 . Milne Point Unit Alaska Drilling & Wells Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth locI. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 13054.27 92.460 264.720 3499.94 3563.49 1721.62 S 11173.03 W 6007658.19 N 540244.21 E 2.480 11304.87 --- -- 13120.82 92.950 264.220 3496.80 3560.35 1728.03 S 11239.19 W 6007651.32 N 540178.09 E 1.051 11371.23 13190.00 92.950 264.220 3493.24 3556.79 1734.99 S 11307.93 W 6007643.89 N 540109.41 E 0.000 11440.21 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.155° (01-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US), Vertical Section is from Well and calculated along an Azimuth of 261,120° (True), Based upon Minimum Curvature type calculations, at a Measured Depth of 13190.00ft., The Bottom Hole Displacement is 11440.26ft., in the Direction of 261.277° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) -~~ Comment 10251.03 10345.00 13190.00 3574.02 3596.39 3556.79 1372.16 S 1382.39 S 1734.99 S 8400.63 W 8491.32 W 11307.93 W Tie On Point Window Point Projected Survey -------------- --------------- 5 November, 2001 - 17:12 Page 4 of 5 DrillQl1est 2.00.08.005 Milne Point Unit Survey tool program for MPI-11L 1 "--..' Fro m Measured Vertical Depth Depth (ft) eft) 0.00 ~- To Measured Vertical Depth Depth eft) (ft) 0.00 13190.00 3556.79 AK-6 BP _IFR-AK (MPJ-11) -- DrillQuest 2.00.08.005 5 November, 2001 - 17:12 Sperry-Sun Drilling Services Survey Report for MPI-11 L 1 Your Ref: API 500292303360 Job No. AKZZ11151, Surveyed: 29 September, 2001 . Alaska Drilling & Wells Milne Point MPI ,-c_. Survey Tool Description ~~-. Page 5 of 5 ( ( ~ 06-Nov-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPI-11 L 1 MWD c90)- /3 r{ Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,251.03' MD Window / Kickoff Survey 10,345.00' MD Projected Survey: 13,190.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED NOV 0 7 2001 A~askaOil&GasCon~ l'" '<',' . I I,). ~,ommîSSlún AflGÞvrage '-, Milne Point Unit Alaska Drilling & Wells Milne Point MPI, Slot MPI-11 MPI-11 L 1 MWD Job No. AKMM11151 I ( SURVEY REPORT 5 November, 2001 Your Ref: API 500292303360 Surface Coordinates: 6009456.78 N, 551405.11 E (70026' 11.7158" N, 149034' 51.1850" W) Kelly Bushing: 63.55ft above Mean Sea Level ( sper-arty-sur, tJRIL.L.ING SERVices A Halliburton Company Survey Ref: svy9975 Sperry-Sun Drilling Services Survey Report for MPI-11 L 1 MWD Your Ref: API 500292303360 Job No. AKMM11151, . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-5ea Vertical local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azlm. Depth Depth' Northlngs Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) "- 10251.03 75.560 262.560 3510.56 3574.11 1384.53 S 8398.71 W 6008014.40 N 543016.14 E 8511.76 Tie On Point -, 10345.00 76.900 263.610 3532.93 3596.48 1395.51 S 8489.31 W 6008002.79 N 542925.62 E 1,792 8602.97 Window Point 10368.38 78.780 263.760 3537.85 3601.40 1398.03 S 8512.03 W 6008000,12 N 542902.92 E 8,065 8625.81 10412.95 81.850 264.040 3545.35 3608.90 1402.69 S 8555.71 W 6007995.15 N 542859.27 E 6.916 8669.68 10461.05 85.260 264.320 3550.75 3614.30 1407.54 S 8603.25 W 6007989.98 N 542811.77 E 7.113 8717.40 10506.44 86.310 264.580 3554.08 3617.63 1411.92 S 8648,30 W 6007985.29 N 542766.74 E 2.383 8762.59 10552.89 89.450 264.850 3555.80 3619.35 1416.19 S 8694.52 W 6007980,69 N 542720.56 E 6.785 8808.92 10601.88 90.430 267.560 3555.85 3619.40 1419.43 S 8743.40 W 6007977.11 N 542671.71 E 5.882 8857.71 10648.09 91.970 268.270 3554.88 3618.43 1421.12 S 8789.56 W 6007975,12 N 542625.55 E 3.670 8903.58 10691.59 92.280 267.210 3553.27 3616.82 1422.83 S 8833.00 W 6007973.10 N 542582.13 E 2.537 8946.76 10741.23 93.510 265.480 3550.76 3614.31 1425,99 S 8882.4 7 W 6007969.60 N 542532.68 E 4.272 8996.13 10786.27 90.860 264.710 3549.05 3612.60 1429.84 S 8927.31 W 6007965.44 N 542487.87 E 6.127 9041.02 10833.95 90.120 263.890 3548.64 3612.19 1434.57 S 8974.75 W 6007960.38 N 542440.46 E 2.317 9088.63 10875.77 88.460 263.640 3549.16 3612.71 1439.11 S 9016.32 W 6007955.55 N 542398.92 E 4.014 9130.40 10925.56 89.380 264.160 3550.09 3613.64 1444.40 S 9065.82 W 6007949.92 N 542349.46 E 2.122 9180.12 10973.75 89.260 264.150 3550.67 3614.22 1449.31 S 9113.75 W 6007944,69 N 542301.56 E 0.250 9228.24 11016.38 90.250 261.420 3550.85 3614.40 1454.66 S 9156.04 W 6007939.04 N 542259.31 E 6.812 9270.85 11062.68 92.220 263.040 3549.85 3613.40 1460.92 S 9201.90 W 6007932.4 7 N 542213.50 E 5.508 9317.12 ~<. 11107.50 88.890 262.720 3549.42 3612.97 1466.48 S 9246.37 W 6007926.61 N 542169.07 E 7.464 9361.91 11152.81 88.950 262.690 3550.27 3613.82 1472.23 S 9291.30 W 6007920.54 N 542124.17 E 0.148 9407.20 11198.01 88.650 262.290 3551.22 3614.77 1478.14 S 9336.11 W 6007914.33 N 542079.41 E 1.106 9452.38 11244.43 88.150 262.960 3552.51 3616.06 1484.09 S 9382.12 W 6007908.06 N 542033.44 E 1.800 9498.76 11291.72 90.620 261.800 3553.02 3616.57 1490.36 S 9428.99 W 6007901.46 N 541986.62 E 5.770 9546.03 11334.66 90.550 262.670 3552.58 3616.13 1496.16 S 9471.53 W 6007895.37 N 541944.11E 2.033 9588.96 11383.09 90.430 260.470 3552.17 3615.72 1503.26 S 9519.43 W 6007887,94 N 541896.26 E 4.549 9637.39 11429.88 90.180 260.050 3551.92 3615.47 1511.18 S 9565.55 W 6007879.71 N 541850.20 E 1.045 9684.17 11475.65 90.120 259.310 3551.80 3615.35 1519.38 S 9610.58 W 6007871.20 N 541805.23 E 1.622 9729.92 11519.67 91.410 258.680 3551.21 3614.76 1527.78 S 9653.78 W 6007862.50 N 541762.09 E 3.261 9773.91 11568.35 91.790 258.960 3549.85 3613.40 1537.21 S 9701.52 W 6007852.73 N 541714.41 E 0.969 9822.53 11608.17 91.970 259.620 3548.55 3612.10 1544.61 S 9740.63 W 6007845.07 N 541675.36 E 1.717 9862.31 --.-~~-- .--- -----.. -.n.---___- ---- ,.------- 5 November, 2001 - 17:09 Page 2 of 5 DrillQl1est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for MPI-11 L 1 MWD Your Ref: API 500292303360 Job No. AKMM11151, . Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth' Northings Eastlngs Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11660.91 90.740 258.290 3547.30 3610.85 1554.71 S 9792.37 W 6007834.61 N 541623.69 E 3.434 9914.99 -- -- 11707.53 90.250 259.550 3546.90 3610.45 1563.67 S 9838.12W 6007825.34 N 541578.00 E 2.900 9961.58 11752.50 90.250 259.730 3546.70 3610.25 1571.76 S 9882.36 W 6007816.95 N 541533.82 E 0.400 10006.53 11803.34 90.620 257.160 3546.31 3609.86 1581.948 9932,16 W 6007806.42 N 541484.09 E 5.107 10057.31 11843.00 90.550 256.450 3545.91 3609.46 1590.99 S 9970.77W 6007797.10 N 541445.54 E 1.799 10096.86 11892.63 90.680 256.170 3545.38 3608.93 1602.74 S 10018.99 W 6007785.02 N 541397.41 E 0.622 10146.31 11941.11 92.030 259.490 3544.23 3607.78 1612.95 S 10066.36 W 6007774.48 N 541350.11 E 7.391 10194.69 11983.49 91.480 258.960 3542.93 3606.48 1620.87 S 10107.97 W 6007766.28 N 541308.55 E 1.802 10237.02 12031.08 91.910 262.390 3541.52 3605.07 1628.58 S 10154.91 W 6007758,25 N 541261.67 E 7.261 10284.58 12076.43 91.850 262.090 3540.04 3603.59 1634.70 S 10199.82 W 6007751.82 N 541216.80 E 0.674 10329,90 12129.35 91.170 260.950 3538.64 3602.19 1642.50 8 10252.14 W 6007743.65 N 541164.54 E 2.508 10382.80 12172.39 92.580 262.040 3537.23 3600.78 1648.868 10294.68 W 6007737.00 N 541122.04 E 4.140 10425.81 12220.57 93.260 263.390 3534.78 3598.33 1654.96 S 10342.41 W 6007730.57 N 541074.35 E 3.134 10473.91 12268.57 92.150 264.430 3532.51 3596.06 1660.05 S 10390.08 W 6007725.15 N 541026.72 E 3.167 10521.80 12311.83 92.030 263.810 3530.94 3594.49 1664.48 S 10433.09 W 6007720.43 N 540983.74 E 1.459 10564.97 12358.11 91.540 263.350 3529.49 3593.04 1669.65 S 10479.05 W 6007714.94 N 540937.81 E 1.452 10611.19 12407.50 92.590 264.110 3527.71 3591.26 1675.04 S 10528.11 W 6007709.21 N 540888.79 E 2.624 10660.49 12450.73 92.460 264.200 3525.81 3589.36 1679.44 S 10571.08 W 6007704.52 N 540845.86 E 0.366 10703.62 ~~- 12498.14 92.220 264.710 3523.87 3587.42 1684.028 10618.23 W 6007699.62 N 540798.74 E 1.188 10750.91 12546.17 92.280 263.630 3521.99 3585.54 1688.89 S 10665.97 W 6007694.41 N 540751.03 E 2.250 10798.83 12592.64 93.330 264.190 3519.71 3583.26 1693.82 S 10712,12 W 6007689.17 N 540704.92 E 2.560 10845.19 12636.69 93.700 264.990 3517.01 3580.56 1697.96 S 10755.89 W 6007684.72 N 540661.18 E 1.998 10889.08 12686.38 94.000 266.260 3513.68 3577.23 1701.748 10805.33 W 6007680.60 N 540611.77 E 2.621 10938.50 12730.24 92.710 265.950 3511.11 3574.66 1704.72 S 10849,01 W 6007677.32 N 540568.11 E 3.025 10982.12 12775.44 92.460 265.750 3509.07 3572.62 1707.99 S 10894.04 W 6007673,75 N 540523.10 E 0.708 11027.12 12822.22 91.970 265.760 3507.26 3570.81 1711.45 S 10940,66 W 6007669.97 N 540476.51 E 1.048 11073.71 12867.73 91.790 256.520 3505.77 3569.32 1718.448 10985.55 W 6007662.66 N 540431.66 E 20.296 11119.15 12915.17 91.480 264.980 3504.41 3567.96 1726.06 8 11032.32 W 6007654.72 N 540384.95 E 17,838 11166.52 12960.98 91.970 264.550 3503.03 3566.58 1730.24 S 11077,91 W 6007650.23 N 540339.39 E 1.423 11212.22 13006.63 91.480 263.780 3501.66 3565.21 1734.88 S 11123.31 W 6007645.28 N 540294.03 E 1.999 11257.79 -,-- ,---- -------'-------- 5 November, 2001 - 17:09 Page 3 of 5 DrmQllest 2.00.08.005 Milne Point Unit Measured Depth Incl. Azim. (ft) 13054.27 92.460 264.900 13120.82 92.950 264.460 13190.00 92.950 264.460 Sperry-Sun Drilling Services Survey Report for MPI-11L 1 MWD Your Ref: API 500292303360 Job No. AKMM11151. . .. Alaska Drilling & Wells Milne Point MPI Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Depth Depth' Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3500.02 3563.57 1739.57 S 11170.68 W 6007640.25 N 540246.68 E 3.123 11305.32 .-o;~ 3496.88 3560.43 1745.74 S 11236.87 W 6007633.63 N 540180.54 E 0.989 11371.67 3493.32 3556.87 1752.40 S 11305.64 W 6007626.49 N 540111.82 E 0.000 11440.64 Projected Survey Vertical Section Comment All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North, Vertical depths are relative to Well. Northings and Eastings are relative to Well, Magnetic Declination at Surface is 26.154° (01-Sep-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 261,120° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13190.00ft" The Bottom Hole Displacement is 11440.65ft., in the Direction of 261.189° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10251.03 10345.00 13190.00 3574.11 3596.48 3556.87 _.u- 5 November, 2001 - 17:09 -~ 1384.53 S 1395.51 S 1752.40 S 8398.71 W 8489.31 W 11305.64 W Tie On Point Window Point Projected Survey Page 4 of 5 DrillQ(est 2.00.08.005 Milne Point Unit Survey tool program for MPI-11L 1 MWD '"-,, Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 -- --- - --- 5 November, 2001 - 17:09 To Measured Vertical Depth Depth (ft) (ft) 0.00 13190.00 3556.87 ----.---- Sperry-Sun Drilling Services Survey Report for MPI-11L 1 MWD Your Ref: API 500292303360 Job No. AKMM11151, . Alaska Drilling & Wells Milne Point MPI ,~.- Survey Tool Description MWD Magnetic (MPI-11 MWD) ~~~. Page 5 of 5 DrillQllest 2.00.08.005 .1 ':~ ~~~~Œ ffi)~ ~~~~~~ f ALAS KA. 0 IL AlQ) GAS CONSERVATI ON COMMISSION TONY KNOWLES, GOVERNOR 333 w. -pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Patrick Archey Senior Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage AK 99519-6612 Re: Milne Point Unit :MPI-IILI BP Exploration (Alaska) Inc. Permit No: 201-138 Sur Loc: 2343' NSL, 3966' WEL, SEC. 33, T13N, RI0E, UM Btmhole Loc. 571' NSL, 578' EWL, SEC. 31, TI3N, RIOE, UM Dear Mr. Archey: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The permit is for a new wellbore segment of existing well MPI-ll, Permit No 201-137, API 50- 029-23033. Production should continue to be reported as a function of the original API number stated above. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~%u..:t.; ÅI\, f ~ý Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DA TED this Þ 7 J1;day of July, 2001 jj c/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. .' (' STATE OF ALASKA '" ALASKA OIL AND GAS CONSERVATION COMh...:3SION PERMIT TO DRILL 20 AAC 25.005 þ,...~ " h /' "-(d~' 1 a. Type of work 181 Drill 0 Redrill 0 Re-Entry 0 Deepen 2, Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2343' NSL, 3966' WEL, SEC. 33, T13N, R10E, UM At top of productive interval 1001' NSL, 3290' EWL, SEC. 31, T13N, R10E, UM At total depth 571' NSL, 578' EWL, SEC. 31, T13N, R10E, UM 12, Distance to nearest property line 13. Distance to nearest well ADL 025628, 571' MD - No Close Approach 16. To be completed for deviated wells Kick Off Depth 10439' MD Maximum Hole Angle 18. Casin~ Program Specifications ( Ize Hole Casino Weiaht Grade Couolina 6-1/8" 4-1/2" 12.6# L-80 IBT-Mod 1 b, Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil 0 Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Planned KBE = 64.7' Milne Point Unit / Schrader 6. Property Designation Bluff ADL 025517 7. Unit or Property Name Milne Point Unit 8. Well Number MPI-11L1 9. Approximate spud date 08/01/01 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13190' MD / 3601 ' TVD 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 0 93.8 Maximum surface 1245 psig, At total depth (TVD) 3714' / 1672 psig Setting Depth Ten Bottom Lenath MD TVD MD TVD 2213' 10439' 3609' 13190' 3601' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Quantitv of Cement (include staae data) Uncemented Slotted Liner 19. To be completed for Redrill, Re-entry, and Deepen Operations, Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 13197 feet 3661 feet feet feet Plugs (measured) Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length Size Cemented MD TVD 78' 20" 260 sx Arctic Set (Approx.) 108' 108' 11047' 2220' 7" 4-1/2" 1114 sx PF 'L', 794 sx Class 'G' Uncemented Slotted Liner 11077' 3711' 10977' - 13197' 3708' - 3661' RECEIVED Perforation depth: measured JUL 1 0 2001 true vertical Alaska Oil & Gas Cons. Commission . 20, Attachments 181 Filing Fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 020 AAC 25.050 Requirements Contact Engineer Name/Number: Robert Tirpack, 564-4166 Prepared By Name/Number: Sondra Stewman, 564-4750 21. I hereby ce~ify that the fOregOin~,' true ~ corr7ft to the best of my knowledge 7~ / ç / ~ / Signed ~ +V-Ie-It A"",/.¡Qr rS ~-f Title Senior Drilling Engineer Date / / / "'/ ,," "', ,..'q:, ' , .', ':,::" '::~:';C()a:nmi$sidl1'"U$,Ónly:',:,,:.,'j :,':'¡': ,'.', , .', " ;',' Permit Number API Number A II j.)a¡} See cover letter .:20/ -- /~5 ?J' 50- 0 < ~- 2. gð 33 - b d yr-r ~/ } II for other reQuirements Conditions of Approval: Samples Required 0 Yes B No Mud Log Rt~uìr~f r 0 Yes Œ1 No Hydrogen Sulfide Measures 0 Yes 1&:1 No Directional Survey Required g Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K LEl3 5K pSI Other: ORIGiNAl SIGNED BY by order of / '/' - .~ J, M. Heusser Commissioner the commission Date '1 J:J1! () / 0 -~ G ¡ r~ A L Š'ú'Dmit fn Triplicate Approved By Form 10-401 Rev. 12-01-85 ( (' MPI-11 L 1 DrillinQ Permit 1. Well Plan Summar'l IWell Name: I MPI-11 L1 l.!xPe of Well (producer or injector): I Schrader Bluff Multilateral producer - UePer leg Surface Location: 2343'FSL,3966'FEL,Sec.33,T13N,R10E X = 551,405.11 Y = 6,009,456.78 1-11 L 1 Target: 1001'FSL,3290'FVVL,Sec,31,T13N,R10E X = 542,839.41 Y = 6,008,061.00 Z = 3544' TVDss 1-11 L 1 Target (Bottom 571' FSL, 578'FVVL,Sec.31,T13N,R10E Hole Location): X = 540,129.71 Y = 6,007,616,10 Z = 3536' TVDss ~ Nabors 22E I I KOP: 10,439' I I Estimated Start Date: ~gust 1, 2001 I I TVDrkb(TD) 13601' I l£peratin~s to complete: I 30 I 64.7' I I I I MDrkb 113190' I Max. Inc. I 93.8° I I KBE: I I Well Desi9.!!.,.(conventional, slim hole, etc.).:...! Multilateral Producer ~e: Drill and Complete a Multilateral Producer in the Schrader Bluff OA and OB sands. ( (" MPI-11 L 1 Drillin!¡l Permit 2. Current Well Information 2.1 General Well Name: MPI-11 API Number: Well Type: Current Status: BHP: BHT: MPI-11 L1 Development - Schrader Bluff Multilateral Producer - lower leg Conductor Set 1672psi @ 3714' TVDrkb - 8.65 ppg - Schrader Bluff OB Sands. 80°F @ 4020' TVDss Estimated (SOA) 2.2 Current Mechanical Condition MPI-11 : Nabors 22E: Conductor: 2.3 Target Estimates Estimated Reserves: Expected Initial Rate: Expected 6 month avg: Cellar Box above MSL = 34.7' KB = 30' 20", 92 Ibltt, H-40 Welded set at 78' MD 1.6MMBBL 3000 BOPD 1493 BOPD 2 ( ( MPI-11 L 1 Drillin!¡ Permit 3. DrillinQ Hazards and ContinQencies 3.1. Well Control MANDATORY WELL CONTROL DRILLS: Drill 01 D2 03 D4 D5 T e Tri in Drillin Diverter Accumulator Well Kill Comments Conducted onl inside casin . Either in cased or 0 en hole. DO NOT shut-in well in 0 en hole. N/A A rox. eve 30 da s, thereafter at convenient times. Prior to drill out the intermediate and production strings, Never car out this drill when 0 en hole sections are ex osed. 3.2. Kick Tolerance 3.2.1. With the 7" casing set into the Schrader Bluff OB reservoir, the kick tolerance for the 6-1/8" horizontal open hole section is infinite assuming an influx at 13,190' in the Schrader OB formation. This is a worst case scenario based on a 8.7 ppg pore pressure gradient in the top of the production section and a minimum fracture gradient of 12,0 Ib/gal at the 7" casing shoe with a 9.1 ppg mud in the hole. 3.3. Lost Circulation 3.3.1. Lost circulation has not been encountered while drilling these intervals on previous I-Pad wells. 3.3.2. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling, Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. 3.4. Unexpected Pressures 3.4.1. It is unlikely there will be unexpected overpressure when drilling to the Schrader Bluff formation. This well is in an undrained fault block with no offtake or injection support. Reservoir pressure is expected to be 1672 psi (8.65 Ib/gal). In this well, the Schrader Bluff formation will be drilled with 9,2 ppg mud. 3.5. Stuck Pipe 3.5.1. The MPI-11 directional plan has a 7000' MO interval of high angle (80,5°) in the surface hole with :1:2500 feet to drill for each lateral in the OAfOB sands. All these hole intervals have massive permeable sand intervals, which can lead to differential sticking of the drill string. Good drilling practices to avoid differential sticking are required in all hole sections. Minimum mud weights and proper mud properties as outlined in the Baroid mud program must be closely followed. 3.5.2. Good drilling practices to avoid differential sticking are required. Minimum mud weights and proper mud properties as outlined in the M-I mud program must be closely followed. Stuck Pipe: Go immediately to SURE manual, determine stuck pipe mechanism, follow recommendations in the SURE manual. DO NOT JAR UP if packed-off! 3.5,3, There is a risk of differentially sticking the 4 Y2" slotted liners. The 9.2 Ib/gal mud will be 0.55Ib/gal overbalanced to the 8.65 Ib/gal OAfOB sand reservoir pressure (106 psi differential pressure @ 3714' TVD). The liner should be kept moving as much as possible while running in the open hole. 3 i' ( :('" MPI-11 L 1 DrillinQ.Permit In order to combat differential sticking, solid stand off centralizers will be run on the liner (two per joint) to ensure the casing will not contact the wellbore wall and allowing the casing to become differentially stuck. 3.6. Pad Data Sheet 3.6.1. Please Read the I-Pad Data Sheet thoroughly. 3.7. Hydrocarbons 3.7.1. Hydrocarbons will be encountered in the Ugnu and Schrader Bluff intervals. 3.8. Hyrdrogen Sulfide 3.8.1. MPI Pad is not designated as an H2S Pad. Listed below are the latest H2S readings from I-Pad Wells: Well Number Well T e Ma , 2001 2 SBF Prod <2.00 m 3 SBF Prod <2.00 m 4 SBF Prod <2.00 m 5i SBF In' <2.00 m 6 SBF Prod <2.00 m 7 SBF Prod <2.00 m 8 SBF Prod <2.00 m 3.9. Faults 3.9.1, The directional plan has been specifically built to cross Fault #1 in the Ugnu formation. This fault should not be crossed in the Schrader Bluff NA sand. The high tangent angle (80,5°) allows the MPI-11 wellpath to sail over top of the SB NA sands while crossing the fault. If the wellpath starts to fall behind the directional plan, corrections must be made before 9827' MD / 3461' TVD. After this fault is crossed, start to drop angle according to the directional plan in preparation for the landing the 9-7/8" hole in the OB sand. See attached geologic and Seismic cross section, There is no history of lost circulation when crossing faults in the Ugnu formation in this area. Number Formation MDKB TVD KB Throw Direction Comments #1 Ugnu 9200' 3359' 210 East Definite #2 - OA Schrader OA 11200' 3650' -20 East Probably not, but possible #3 - OA Schrader OA 13000' 3603' -25 West Probable #2 - OB Schrader OB 11200' 3711' -20 East Probably not, but possible #3 - OB Schrader OB 13000' 3665' -25 West Probable 4 ( ( M PI-11 L 1 DrillinQ. Permit 4.0 Drillin~ ProQram Overview 4.1. Surface and Anti-Collision Issues Surface Shut-in Wells: No wells need to be shut-in for the rig move on and off MPI-11 Close Approach Wells: There are no close approach wells Well Name Current Production Precautions Status Priority N/A N/A N/A N/A 4.2. Well Control Ex ected BHP 1672 psi @ 3714' TVDrkb estimated Max Ex BOPE Ratin 135/8" 5M Planned BOPE Test Pres. Rams & Valves: 3500 psi/250 psi Annular: 2500 si I 250 si 4.3. Mud Program 6-1/8" Production Hole Mud Properties: OAlOB KCI-CaCO3 Baradril N Density ~ \ Funnel visc YP HTHP pH API Filtrate LG Solids 9.2 40 - 55 22 - 27 <10 8.0-8,5 4-6 ALAP 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. 5 ( (" MPI-11 L 1 DriliinQ. Permit 4.4. Formation Markers Formation Tops MDKB TVD KB Est. EMW.!.e.es) Comments Base Permafrost 1947' 1840' 8.65 Top Ugnu 8326' 3214' 8.65 Top Ugno M 9335' 3380' 8.65 Top SB NA 9821' 3460' 8.65 Top SB NB 9967' 3489' 8,65 Top SB NC 10098' 3522' 8,65 Top SB NE 10168' 3540' 8.65 Top SB NF 10352 3587' 8.65 Top SB OA 10489 3622' 8.65 Top SB C {Base OA} 10632' 3658' 8,65 TaD SB B-OB 10812' 3692' 8.65 Top SB AS {Base OS} N/A 3717' 8.65 TO OA Lateral 13190' 3601' 8.65 TO OB Lateral 13197' 3661' 8.65 4.5. Casing Program Hole Size Csg Wt/Ft Grade Conn Top Bottom Length Drift ID O.D. MDKB MDKB 6-1/8" 4-1/2" OA Lateral Slotted 12.6# L-80 IBT-Mod 10,439' 13,197' 2220' 3.833" Liner* * .In' , Every 10 JOint to be solid, unslotted liner. 4.6. Cement Calculations Production Interval- Shoe Depth N/A Design Basis N/A Design Temp N/A Volume N/A Notes The 4-1/2" slotted liner placed in the OA Lateral will not be cemented. Lost Circulation N/A Accessories OA Lateral 120 Straight Blade Rigid Centralizers - 4-5/8" X 5-3/4" X 8" 60 Stop Rings 4.7. Survey and Logging Program Production Hole Drilling: Oir 1 PWO 1 ABI 1 ABGR 1 Res Open Hole: None Cased Hole: NI A NOTE: IFR, CASANORA, and Insite Anywhere required at all times. 6 ( { MPI-11 L 1 DrillinSJ Permit 5. MPI-11 Operations Summar'l 5.1. Procedure 1. Continued from MPI-11 Permit/Procedure. 2. Make up Baker Window Master milling assembly with bottom trip anchor and MWD. a. RIH. Orient and set whipstock to place window at top of the OA interval. b. Shear off and mill window thru 7" casing. 3. RIH. Displace hole to clean BARADRllN mud 4. Drill 6-1/8" OA lateral geosteering and short tripping as required. Maintain mud properties. 5. POOH. Reamer trip with Hole Opener to TD if required. 6. Displace OA lateral with clean BARADRllN mud 7. MU whipstock retrieving tool, RIH and pull whipstock 8. Run 4 Y2" slotted liner with 2 Va" inner string, Baker Hookwall Hanger and hang off in 7" casing. 9. RIH with 7" RBP to top of Baker Hookwall Hanger. 10. Set and test RBP. 11. Displace 711 casing to 9.1 Ib/gal completion fluid. 12. POOH laying down 3-1/2" DP. 13. PU 3-1/2" tubing and RIH with Baker retrieving tool to 100' above RBP. 14, land tubing hanger. 15, Set and test TWC. 16. ND BOP. 17. Install and test X~Tree. 18. Pull TWC. 19. Freeze protect the tubing and annulus, 20. Install BPV and secure the well. 21. RDMO 6. MPI-11 Nabors 4ES Operations Summar'l 1. 2. 3. 4. 5. 6. 7, 8. 9. MI/RU Nabors 4ES. Remove BPV and circulate out freeze protection with 9.1 ppg brine. Install TWC, remove tree, install and test BOP. Release RBP, pull and stand back 3-1/2" tubing. Make up the ESP completion and run in on the 3-1/2" tubing. land tubing hanger. Freeze protect the well. Set BPV. Remove the BOP. Install and test the tree. RDMO, Hook up flowlines and instrumentation. 7 5 peI'"""" ':/- 5U ., DRILLING seRVices A Halliburton Company Milne Point Unit Alaska Drilling & Wells Proposal Data for MPI-11 L1 WpO5 Vertical Origin: Well Horizontal Origin: Well Measurement Units: It North Reference: True North Dogleg severity: Degrees per 100 feet (US) Vertical Section Azimuth: 261.123° Vertical Section Description: Well Vertical Section Origin: 0.00 N,O.OO E Measured Incl. Azim. Vertical Northings Eastings Vertical Dogleg Depth Depth Section Rate 10439.00 75.187 261.299 3608.94 1336.70 S 8575.12 W 8678.68 10459.00 77.570 261.000 3613.65 1339.70 S 8594.32 W 8698.11 12.001 10479,00 17.570 261.000 3617.96 1342.75 S 8613.61 W 8717.64 0,000 10592.39 84.373 260.937 3635.74 1360.32 S 8724.14 W 8829.56 6.000 10698.1 8 84.373 260.937 3646.1 1 1376.90 S 8828.11 W 8934.84 0.000 10784,03 89.500 260.440 3650.70 1390.77 S 8912.68 W 9020.54 6.000 10793.28 90.042 260,319 3650.74 1392.32 S 8921.80 W 9029,79 6.000 11718.82 90.042 260.319 3650.06 1547,95 S 9834.16 W 9955.24 0.000 11757.99 91.000 261.000 3649.70 1554.31 S 9872.81 W 9994.40 3.000 1 1856,63 93.815 261.914 3645,56 1568.95 S 9970.26 W 10092.95 3,000 1233\.71 93,815 261.914 3613.95 1635,62 S 10439.57 W 10566.93 0.000 12432.86 91.000 260.780 3609.70 1650.82 S 10539.47 W 10667.97 3,000 12458.97 90.676 261.493 3609.32 1654,85 S 10565.27 W 10694.08 3.000 13189.61 90.676 26\.493 3600.70 1762.92 S 11287.82 W 11424.66 0.000 ppr V d II sign 3000 ~Q J.~ f!,'I>' ..:.Q ~f ~Q "'\~ ~ ~Q ,j-~ $" #. ~ "'\t.~ ,[},O;' Y>~' ~Qn¿ 'O~'" n:,'f?°' ....tr ~~ 0;,0;~ ,f -~' ~ . ~ ,g,'t-. ..§)' ~. 0\...0 0;#' ...cr> ...'ff' Ao;,'P ~ ~ O' A'I>' ifF ft~'~""o 4-0;, ...",,'f'" .."" o"v~O;<;J~' q}><' ~" ¿;.i <:>~ ...<:l" o~<§i .'!> 0 ,...<5' cf>' l:- ~,. ¡;f> ",'1'...-:' @ <ð-'" ",St' '0<'; ",I:- . ",," ~ ~" !o.V ~ C§ '0' '" *-° f:!-òo i.<::J <f" ~o <ð-",I:- t!íí~~ .....~g¡ Jff'{.IfU ï/ -"". Milne Point MPI MPI-11 L 1 WpO5 DrillQuest~ Single Well Target Data for MPI-11 L1 WpOS MeaslJ"errenlllrits: It Coordinate Target Paint TVO TVDs. Northing. Ea81lngs Northing. Eaotlngs Target Name Type ASPY ASPX Shape MPi-llLi GeoPoly EntryPoÍnl 3650.70 3586.00 (\()(]8004.61 N 542502.23 E I3YO.77 5 8912.fiK W PolYGon BotuxIary Poi'" A 3650.70 3586.00 (\()(]8210.00 N '>\2934.00 E 1128.365 11419.0') W B 3650.70 3586.00 (\()(]8072.ION '>\0129.71 E 1306.935 112114.611 W C 3650.70 3586.00 (\()(]7616.ION '>\0129.71 E 1762.92 5 112117.82 W D 3650.70 3586.00 (\()(]1616.ION '>\:1000.00 E 17112.705 11417.f,OW MPI-IILI TI Entry Poi'" 3650.70 35116.00 (\()(]8004.61 N '>\25O2.2J E IWO.775 1I')12.fiKW Puiol MPI-IlLI 1'2 Entry Poiol 3649.70 35115.00 (\()(]7834A6 N 541'>\3,25 E 15'>\.315 'lK72.81 W Pujol MPI-IlLI 11 Entry Poi'" 3609.70 3545.00 (\()(]7733.35 N '>\01177.27 E 1650.82 S 105W.47 W Pui.. Mpl-IlLI T4 EnIIy Poiol 3600,70 3536.00 6001616.10 N '>\0129,71 E 1162.925 112117.112W I\,i.. MPI-IlLIDrlr Poly EnbyPoiol 3650.70 35116.00 60011004.51 N '>\2502.23 E 13YO.1I75 8912.fiK W "ul)'Gun Bourdary Poiol ^ 3650.70 3586.00 60011173.00 N '>\211'>\.00 E 1224.111 5 11559.76 W B 3650.70 35116.00 (\()(]8041.00 N 541773.00E 1349.365 %11.64W C 3650.70 3586.00 (\()(]7985.00 N 540767,00 E IW8.425 IOMII.noW D 3650.70 3586.00 6007934.00 N 540167.00 E 1445.211 5 112411.34 W E 3650.70 3586.00 (\()(]7612.00 N 540227.00 E 1767.69 5 11l90.56W F 3650.70 3586.00 (\()(]7706.00 N '>\01l21.00E 1677.795 10595.93 W G 3650.70 3586.00 6007763.00 N '>\1823.00 E 1627,695 9593,56 W H 3650.70 3586.00 6007712.00 N 542920.00 E 16116.255 11496.9.1 W _. " Current Well Properties MPI-11 L1 Wp05 6009456.78 N, 551405.11 E 330.38 S, 772.84 W 70° 26' 11.7158' N, 149° 34' 51.1850' W Well: Horizontal Coordinates: Ref. Global Coordinates : Ref. Structure Reference: Ref. Geographical Coordinates : RKB Elevation: 64.7Oft above Mean Sea level 64.7Oft above Structure Reference North Reference: Units: True North Feet (US) 12300.' ~Q ~Q O;,?*" o;,rf' ri,...o;,. #' ~ ~ ,$-Q" ~Q ",\...~ ,!b.f' 17"" ...'If" '.'" ",6" 0\"'# 0 ~""~ <# ~ 'ò' ":r <:>~ 0 <ð-",I:- .f:!- <to <Q0~ /.ë ( r 12600.. -'" ~Q ~Q ",," ,?6 ,g,"'" ,/'. .of)'!' ~Q" 4i- "". r{?~ ~...'b- .....<fl' ,~ ~" 0\"'# 0;n:,'Þ" ~ .",0 o;,~ c,,'Ì>' 0 I:- ~f ¿j-0 i:i? .¡l" » f:!-ò f:OCYJ.I ..s::: +-' a. Q) 0 Cõ (.) 'f: Q) > 3500 '-.-l~I.~~.-. ¿~7 .t: 0 0 It) II .I::. .~ 4000 '65!J..'O HI) D9'-'.?' S. Syl'l &' w MPI.flU!Jr.lr ['"I)' iD m W ~Q ",\<$' 4><,§>' $>' 'O~ 0;,...'1>0;' .'" i$" ,,<::l~ r# 12100.007' --- +,~~! '-1:-:'3 .", '. .J. '6',?, '0 1YD 165iJ.61 S. JiJ'.iY.4' !I' .mmz :.1N.I!J.l n 36f){J.7r! TH} ¡;~:.~:-'.!!2-';..'.!1!' '"",:"",~'3S '" "- ~ 4 1/2" Ü1ef t3189.61ltMD 36OO,70n ND 8500 Scale: 1 inch = 500ft 9000 9500 10000 10500 Vertical Section 11000 11500 12000 Section Azimuth: 261.123° (True North) DriliQuest 2.00.09.001 TREE: Cam~ron 3", 5M 'WÈLLHEAD: FMC Gen 6,11", 5M ( PROPOSED COMPLETION MPI-11 & 1-11 L 1 KB. ELEV = 64.7' GL ELEV = 34.7' 1108" MDI 20" 92 Ib/ft, H-40 Welded 7", 26#, L-80, Hydril 521 Casing Drift: 6.151" Casing 10: 6.276" Baker Hughes Hook Hanger system Level 3 Multi-Lateral Junction Window in 7" casing @ 10,427'-10,439' MD Well Inclination @ Window = 80.4 Degrees Baker Hughes Conventional Hanger 7" Casing Shoe @ 11,077' MD Well Inclination @ Shoe = 89 Degrees DATE REV. BY COMMENTS 6/28/2001 RB Tirpack Level 3 Multi-Lateral, 3-1/2" tbg with RPB (" 3-1/2", 9.3 Ib/ft, L-80, EUE Coupling 00: 4.5" Drift/ID: 2.867"/2.992" 7", 26# RBP @ 10,327' MD .... ~--------------_, OA Horizontal ""....---------------. 6-1/8" OA Lateral 4-1/2" Slotted Liner and Hook Hanger 113,190' MD I \ " \ ~""-------------- , , '.... """"~-------------- DB Horizontal 6-1/8" OB Lateral 4-1/2" Slotted Liner & Hanger 113,197' MD I Milne Point Unit WELL: MPI-11 API NO: BP Exploration (Alaska) I . .. , '~~'I\' ;'.il' ¡,.,r;;:" "'i': \ I ,.. I., :',1 "I . \:', !;'~,,~L1N,I;'J,~JI), 'I"~ ¡'~I'¡'tl( 't\¡';:¡'J I. " " ":'~¡i¡,:.. " .', \ ' ' !\'¡:¡',;:t' ' ,:. , 'i" I" -, '" '" ~,,' , ,,:, ' :' '\ ~ , " .'i, FAX 907 (f' 4441 " ~UUl/UU3 07/24/01 Tim 05:31 RDIU IP IlIIU IlBlWNII & WDI.I TO: Jane Williamson DATE: 7/20/01 COMPANY: Alaska Oil and Gas Conservation Commission FAX: 276- 7542 PHONE: FADM: James Franks - FAX: (907)564-4441 PHONE: ! (907)564- 4468 I ',' "\' " MESSJ\GE:' ,: (r)~~ "~I, ,"', ': ' , , ", ' ," I ! , ,\" ,¡ ':, \ '",,' it,' ,'..' , Atta:øhed tø:this c~~~r she~t.are drawings for-,the MPG-1:4,:and!MPI:~t1~ultilat~ral wëll,~ as wte':plan to coniþl~te the:m., , "f ' ,': ~I,' " '1 ' , . '" ' , , " " " I I' ,n',~: ' ' ',: ' , ' , : " iii" , ,': '::1 '¡ !' " I , '" :;"1,'" T""',anks.I",!, i ¡II! I ,;' '" : " i! p, "'" ,r- r ! , , r<- 'J' -. ~. ' ' . , \ ' JUL 2 4 2001 ~ VII 6 uasúons.C~ Anchorage , ' N umber of attachments not including fax cover: 2 Oi /24/01 TUE 05: 32 FAX 90i 564 4441 t""'KUt-'U::>t=U vUIY't""Lt: I IUI" TRËE: Cameron 3", 5M 1 I 11 L1 WELLHEAD,FMCGen 6. 11",5M .. MPI-11 &. - 1 i j1oarMDI 20" 92 Ibltt. H-4D Welded 7", 26#, L-80. Hydril 521 Casing Drift: 6.151" Casing 10: 6.276" Baker Hughes Hook Hanger system Level 3 Multi-Lateral Junction Window in 7" caelng @ 10.427'-10,439' MD Wel1lncllnatlon @ Wlndow;¡; 80.4 Degrees Baker Hughes Conventional Hanger 7'1 Casing Shoe @ 11,077' MD Wellinclination @ Shoe = 89 Degrees DATE REV. BY COMMENTS 6/28/2001 RB Tlrpack Lovel 3 Multi-Lateral, 3-1J2" tbg with RPB , " " , . '. If!:JVU",,1 VV"" '- KB. ELEV = 64.7' GL ELEV: 34." dDl-l31 d-Ol-13~ [ 150' 2.7/8" X 1" Gas Lift Mandrel 2-7/8", 6.3 !b/tt, L-60. EUE-M Coupling OD: 3-5" DriftllD: 2.34711/2,441" 2- 7/8~ x 1" Gas Lift Mand rei r 1 0227' I X Nipple 2.313n ID RECEIVED Centrilift Electric su£ltHrsi2e4'~1 11 0277' I Alaska Oi!& Gas Cons. Commfsslol'¡ Anchorage r 1 0327' I Centrilift Pressure Gauge -~--------------_. OA Horizontal 'I ~ --------------- -_.~ 6-1/8" OA Lateral 4-1/2" Slotted Liner and Hook Hanger 113,190' Me I , . \ " \ ---------------- , " "' " os Horizonta.l ¡ -- "-" ....- - - - - - - - - - - - - - 1 6.1 fB" OB Lateral 4~1 /2'1 Slotted Liner & Hanger 113,197' MD , Milne Point UnIt WELL: MPI-11 API NO: BP Exploration (Araska) ~. TREE: Clm.ron 3', 5111 WELLHEAD: FIIIC Gin 6, 11', 5111 liDS' MD I 20' 92 Ibm. H.40 Walded 7",26#, L-80, Hydril521 Casing Drift: 6.151" Casing 10: 6.276" " ~ PROPOSED COMPLETION MPI-11 & 1-11 L1 Baker Hughes Hook Hanger system Level 3 Multi-Lateral Junction Window In 7'ceslng@ 10,427'-10,439'MD We/llncllnation @ Window = BO.4 Degrees Baker Hughes Conventional Hanger 7" Casing Shoe @ 11,077' MD Wellinclination @ Shoe = B9 Degrees DATE REV. BY Level3 Munl.Lateral, 3.112M tbg with RPB 8I28l2OO1 RB Tlrpack COMIIIENTS KB. ELEV = 64.7' GL ELEV = 34.7' 2-718Mx 1" Gas Lift Mandrel 150' 2-7/8",6.3 Ib/tt, L-80, EUE-M Coupling OD: 3.5" Dritt/lD: 2.347"/2,441" 2-7/8Mx 1" Gas LIft Mandrel 110227' I X Nipple 2.31381D Centrillft Electric Submersible Pump 1 10277'1 Centrilift Pressure Gauge 110327' I -----------------. OA Horizontal ---- ---- - ---- ---_.': 113,190' MD , 6-11B' OA Lateral 4-1128 Slotted LIner and Hook Hanger \ " \ ---------------- " , - OB Horizontal ----------------- 6-11B' OB Lateral 4-112M Slotted LIner & Hanger 113,197' MD I Milne Point Unit WELL: MPI-11 API NO: BP Exploration (Alaska) RECEIVED ORIGINAL JUL 2 0 2001 Alaska Oil & Gas Cons. Commission Anchorage Milne Point Unit Alaska Drilling & Milne PO<&4 ......... MPI-11 Wps -- SAL REPORT 5 June, 2001 Surface Coordinates: 6009456.78 N, 551405.11 E (70026' 11.7158" N, 149034' 51.1850" W) Kelly Bushing: 64.70ft above Mean Sea Level --'. 5 P E!"""" Y - 5 U.., DRIL.L.ING seRVices A Halliburton Company Proposal Ref: pro9844 Milne Point Unit Measured Depth (ft) 10439.00 10459.00 10479.00 10497.17 10500.00 10592.39 10600.00 10698.18 10700.00 10784.03 10793.28 10800.00 10900.00 11000.00 11100.00 11200.00 11300.00 11400.00 11500.00 11600.00 11700.00 11718.82 11757.99 11800.00 11856.63 75.187 77.570 77.570 78.660 78.830 84.373 84.373 84.373 84.482 89.500 90.042 90.042 90.042 90.042 90.042 90.042 90.042 90.042 90.042 90.042 90.042 90.042 91 .000 92.199 93.815 Incl. Azim. Sub-Sea Depth (ft) 3544.24 3548.95 3553.26 3557.00 3557.55 3571.04 3571.79 3581.41 3581.59 3586.00 3586.04 3586.03 3585.96 3585.88 3585.81 3585.74 3585.66 3585.59 3585.52 3585.44 3585.37 3585.36 3585.00 3583.83 3580.86 Vertical Depth (ft) 3608.94 3613.65 3617.96 3621.70 3622.25 3635.74 3636.49 3646.11 3646.2 3650.7' 3650.74 3650.73 3650.66 3650.58 3650.51 3650.44 3650.36 3650.29 3650.22 3650.14 3650.07 3650.06 3649.70 3648.53 3645.56 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 L1 Wp05 Local Coordinates Northings Eastings (ft) (ft) 1336.70 S 1339.70 S 1342.75 S 1345.53 S 1345.97 S 1360.32 S 1392.32 S 1393.45 S 1410.26 S 1427.08 S 1443.89 S 1460.71 S 1477.52 S 1494.34 S 1511.16S 1527.97 S 1544.79 S 1547.95 S 1554.31 S 1560.74 S 1568.95 S 8575.12 W 8594.32 W 8613.61 W 8829.90 W 8912.68 W 8921.80 W 8928.42 W 9027.00W 9125.58 W 9224.15 W 9322.73 W 9421.30 W 9519.88 W 9618.46 W 9717.03 W 9815.61 W 9834.16 W 9872.81 W 9914.31 W 9970.26 W Global Coordinates Northings Eastings (ft) (ft) 6008061.00 N 6008057.88 N "Ó08054.69 N 08051.79 N 08051.33 N 6008036.36 N 6008035.12 N 6008019.06 N 6008018.76 N 6008004.61 N 6008003.00 N 6008001.83 N 6007984.33 N 6007966.84 N 6007949.34 N 6007931.85 N 6007914.35 N 6007896.86 N 6007879.36 N 6007861.87 N 6007844.38 N 6007841.08 N 6007834.46 N 6007827.75 N 6007819.15 N 542839.41 E '- 'L 542820.22 E 542800.96 E 542783.41 E 542780.68 E 542690.55 E 542683.08 E 542586.70 E 542584.91 E 542502.23 E 542493.11 E 542486.50 E 542388.04 E 542289.59 E 542191.13 E 542092.67 E 541994.21 E 541895.76 E 541797.30 E 541698.84 E 541600.38 E 541581.85 E 541543.25 E 541501 .80 E 541445.90 E Dogleg Rate (O/100ft) 12.001 0.000 6.000 6.000 6.000 0.000 0.000 6.000 6.000 6.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 3.000 3.000 3.000 Vertical Section 8678.68 8698.11 8717.64 8735.43 8738.20 8829.56 8837.14 8934.84 8936.65 9020.54 9029.79 9036.51 9136.50 9236.49 9336.48 9436.47 9536.46 9636.45 9736.44 9836.43 9936.42 9955.24 9994.40 10036.40 10092.95 Alaska Drilling & Wells Milne Point MPI Comment KOP : Start Dir @ 12.000°/1000 : 10439.0OOMD,3608.941tTVD 7" Casing End 01 Build - 10459.00ft Start Dir 6.000°/1 OOft : 10479.00ftMD,3617.96ftTVD Schrader OA ~ 261 .299 261 .000 261 .000 260.990 260.988 260.937 260.937 260.937 260.926 260.440 260.319 260.319 260.319 260.319 260.319 260.319 260.319 260.319 260.319 260.319 260.319 260.319 261.000 261.389 261.914 End Dir, Start Sail @ 84.373° : 10592.39ftMD,3635.741tTVD Start Dir @ 6.0000/100ft : 10698.18ftMD,3646.11ftTVD Target - MPI-11 L 1 T1, Geological End Dir, Start Sail @ 90.042° : 1 0793.28ftMD,3650.7 41tTVD ~,. Begin Dir @ 3.0000/1O0ft : 11718.821 MD, 3650.06ft TVD Target - MPI-11 L 1 T2, Geological End Dir, Start Sail @ 93.815° : 11856.631tMD ,3645.56ftTVD 5 June, 2001-19:19 DrillQuest 2.00.09.001 Page 2 of 7 Sperry-Sun'Drilling Services ProposalReportforMPI-11 Wps-MPI-11 L1 WpO5 Alaska Drilling & Wells Milne Point Unit Milne Point MPI Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) CO/100ft) 11900.00 93.815 261.914 3577.97 3642.67 1575.03 S 10013.10 W 541403.10 E 0.000 10136.21 12000.00 93.815 261.914 3571.32 3636.02 1589.07 S 10111 .89 W 541304.41 E 0.000 10235.98 12100.00 93.815 261.914 3564.66 3629.36 1603.10S 10210.67 W 1205.73 E 0.000 10335.75 12200.00 93.815 261.914 3558.01 3622.71 1617.14 S 10309.46 W 1107.04 E 0.000 10435.52 12300.00 93.815 261.914 3551 .36 3616.06 1631.17 S 10408.25 W / 541008.35 E 0.000 10535.29 -~ 12331.71 93.815 261.914 3549.25 3613.95 1635.62 S 540977.06 E 0.000 10566.93 Begin Dir @ 3.0000/1O0ft : 12331.71f MD, 3613.95ft TVD 12400.00 91 .915 261.148 3545.84 3610.54 6007738.73 N 540909.67 E 3.000 10635.12 12432.86 91 .000 260.780 3545.00 3609.70 6007733.35 N 540877.27 E 3.000 10667.97 Target - MPI-11 L 1 T3, Geological 12458.97 90.676 261.493 3544.62 3609.32 6007729.15 N 540851 .50 E 3.000 10694.08 End Dir, Start Sail @ 90.676° : 12458.97ftM D ,3609.32ftTVD 12500.00 90.676 261.493 3544.13 3608.83 1660.92 S" 10605.84 W 6007722.80 N 540810.97 E 0.000 10735.11 12600.00 90.676 261.493 3542.95 3607.6 1675.71 S 1 0704.74 W 6007707.33 N 540712.18 E 0.000 10835.10 12700.00 90.676 261 .493 3541.78 3606, 1690.50 S 10803.63 W 6007691 .86 N 540613.39 E 0.000 10935.09 12800.00 90.676 261.493 3540.60 3605.30 1705.29 S 10902.52 W 6007676.38 N 540514.60 E 0.000 11035.08 12900.00 90.676 261.493 3539.42 3604.12 1720.08 S 11001.41 W 6007660.91 N 540415.81 E 0.000 11135.07 13000.00 90.676 261.493 3538.24 3602.94 1734.87 S 11100.31 W 6007645.44 N 540317.02 E 0.000 11235.06 13100.00 90.676 261.493 3537.06 3601.76 1749.66 S 11199.20 W 6007629.97 N 540218.24 E 0.000 11335.05 13189.61 90.676 261.493 3536.00 3600.70 1762.92 S 11287.82 W 6007616.10 N 540129.71 E 0.000 11424.66 Total Depth: 13189.61ftMD,3600.7OftTVD 4 1/2" Liner Target-MPI-11L1 T4,Geological -'. All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.244° (24-May-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 261.123° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13189.61ft., The Bottom Hole Displacement is 11424.66ft., in the Direction of 261.123° (True). 5 June, 2001 - 19:19 Page 3 of 7 DrillQuest 2.00.09.001 Milne Point Unit Comments Measured Depth (ft) Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps-MPI-11 L1 WpOS Alaska Drilling & Wells Milne Point MPI Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10439.00 3608.94 1336.70 S 10459.00 3613.65 1339.70 S 10479.00 3617.96 1342.75 S 10592.39 3635.74 1360.32 S 10698.18 3646.11 1376.90 S 10793.28 3650.74 1392.32 S 11718.82 3650.06 1547.95 S 11856.63 3645.56 1568.95 S 12331.71 3613.95 1635.62 S 12458.97 3609.32 1654.85 S 13189.61 3600.70 1762.92 S 8575.12 W 8594.32 W '--"" KOP : Start Dir @ 12.000°/1 End of Build - 10459. 8613.61 W 8724.15 W 8828.11 W 8921 .80 W 9834.16 Start Dir 6.QO End Di( Start Di End Dir~ Begin 'ir 04ÎlltÐOftMD,3617.96ftTVD 373° : 10592.39ftMD,3635.74ftTVD : 10698.18ftMD,3646.11ftTVD Sail @ 90.042° : 10793.28ftMD,3650.74ftTVD .000°/1000 : 11718.82ft MD, 3650.06ft TVD End Dir, Start Sail @ 93.815° : 11856.63ftMD,3645.56ftTVD Begin Dir @ 3.0000/100ft : 12331.71ft MD, 3613.95ft TVD End Dir, Start Sail @ 90.676° : 12458.97ftMD,3609.32ftTVD Total Depth: 13189.61 ftMD,3600.70ftTVD Formation Tops Formati on Plane Profile Penetration Poi n t (Below Well Origin) Measured Vertical Sub-Sea Sub-Sea Dip Dip Dir. Depth Depth Depth Northings Eastings Formation Name (ft) Deg. Deg. (ft) (ft) (ft) (ft) (ft) 1775.00 0.000 0.395 1946.87 1839.70 1775.00 95.93 S 458.77 W Base Permafrost 3149.00 0.000 0.395 8325.93 3213.70 3149.00 1023.19 S 6524.78 W Top Ugnu 3315.00 0.000 0.395 9335.08 3379.70 3315.00 1173.61 S 7508.75 W Top Ugnu M 3395.00 0.000 0.395 9821.42 3459.70 3395.00 1246.09 S 7982.96 W Schrader NA 3424.00 0.000 0.395 9967.21 3488.70 3424.00 1267.69 S 8124.16 W Schrader NB 3457.00 0.000 0.395 10097.75 3521.70 3457.00 1286.79 S 8249.01 W Schrader NC 3475.00 0.000 0.395 10168.16 3539.70 3475.00 1297.09 S 8316.29 W Schrader NE 3522.00 0.000 0.395 10352.00 3586.70 3522.00 1323.98 S 8491.98 W Schrader NF 3557.00 0.000 0.395 10497.17 3621.70 3557.00 1345.53 S 8631.18W Schrader OA 3593.00 0.000 0.395 TSBC (base OA) ---" 5 June, 2001 - 19:19 DrillQuest 2.00.09.001 Page 4 of 7 Milne Point Unit Formati on Plane (Below Well Origin) Sub-Sea Dip Dip Dir. (ft) Deg. Deg. Formation Tops (Continued) 3627.00 3652.00 0.000 0.000 Casing details From Measured Vertical Depth Depth (ft) (ft) <Surface> <Surface> <Surface> <Surface> Targets associated with this wellpath Target Name MPI-11 L 1 GeoPoly Profile Measured Vertical Depth Depth (ft) (ft) 0.395 0.395 To Measured Vertical Depth Depth (ft) (ft) 10439.00 13189.61 3608.94 3600.70 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps-MPI-11 L1 Wp05 Penetration Point Sub-Sea Depth Northings Eastings (ft) (ft) (ft) Formation Name Target Shape Polygon Alaska Drilling & Wells Milne Point MPI .--... Target Type Geological -". Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: 3650.70 3586.00 1390.77 S 8912.68 W 6008004.61 N 542502.23 E 70025' 57.9841" N 149039' 12.7338" W 5 June, 2001 - 19:19 DrillQuest 2.00.09.001 Target Boundary Point #1 #2 #3 #4 3650.70 3650.70 3650.70 3650.70 1128.36 S 1306.93 S 1762.92 S 1782.70 S 8479.09 W 11284.68 W 11287.82 W 8417.60 W Page 5 of 7 Milne Point Unit Target Name Targets associated with this wellpath (Continued) MPI-11L1 T1 MPI-11 L 1 T2 MPI-11 L 1 T3 MPI-11L1 T4 MPI-11 L 1 Drlr Poly Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps - MPI-11 L1 Wp05 Mean Sea LeveVGlobal Coordinates #1 #2 #3 'Global Coordinates: Geographical Coordinates: Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Mean Sea LeveVGlobal Coordinates: Geographical Coordinates: Target Boundary Point #1 #2 #3 #4 #5 #6 #7 Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3650.70 3586.00 3649.70 3585.00 3609.70 3545.00 3600.70 3536.00 3650.70 3586.00 3650.70 3650.70 3650.70 3650.70 3650.70 3650.70 3650.70 08270.00 N 542934.00 E 8072.10 N 540129.71 E 76007616.10 N 540129.71 E 6007616.10 N 543000.00 E 700 26' 00.5701" N 149039' 00.0185" W 700 25' 58.7772" N 1490 40' 22.3454" W 700 25' 54.2921" N 149040' 22.4174" W 70025' 54.1348" N 149038' 58.1923" W 1390.77 S 8912.68 W 6008004.61 N 542502.23 E 70025' 57.9841" N 149039' 12.7338" W 1554.31 S 9872.81 W 6007834.46 N 541543.25 E 700 25' 56.3637" N 1490 39' 40.9031" W 1650.82 S 10539.47 W 6007733.35 N 540877.27 E 700 25' 55.4054" N 149040' 00.4623" W 1762.92 S 11287.82 W 6007616.10 N 540129.71 E 70025' 54.2921" N 149040' 22.4174" W 1390.87 S 8912.68 W 6008004.51 N 542502.23 E 70025' 57.9831" N 149039' 12.7338" W 1224.81 S 8559.76 W 1349.36 S 9641.64 W 1398.42 S 10648.00 W 1445.28 S 11248.34 W 1767.69 S 11190.56 W 1677.79 S 10595.93 W 1627.69 S 9593.56 W Target Shape Point Point Point Point Polygon Alaska Drilling & Wells Milne Point MPI Target Type ~~ Geological Geological Geological Geological _4. Drillers 5 June, 2001 - 19:19 DrillQuest 2.00.09.001 Page 6 of 7 Sperry-Sun Drilling Services Proposal Report for MPI-11 Wps-MPI-11 L1 Wp05 Milne Point Unit Target Name Target Entry Coordinates TVD Northings Eastings (ft) (ft) (ft) 3650.70,/;\ 1686.25 S 8496.93 W #8 Mean Sea LeveVGlobal Coordinates #1 #2 #3 #4 rdinates #1 #2 #3 #4 #5 #6 #7 #8 008173.00 N 08041 .00 N 7985.00 N 6007934.00 N 6007612.00 N 6007706.00 N 6007763.00 N 6007712.00 N 700 25' 59.6206" N 700 25' 58.3826" N 70025' 57.8865" N 70025' 57.4169" N 700 25' 54.2467" N 700 25' 55.1395" N 700 25' 55.6455" N 700 25' 55.0826" N 542854.00 E 541773.00 E 540767.00 E 540167.00 E 540227.00 E 540821 .00 E 541823.00 E 542920.00 E 149039' 02.3826" W 149039' 34.1272" W 1490 40' 03.6577" W 1490 40' 21 .2729" W 149040'19.5631" W 149040' 02.1178" W 149039' 32.7057" W 1490 39' 00.5236" W .. Alaska Drilling & Wells Milne Point MPI Target Shape Target Type ~c~. ~~" 5 June, 2001 - 19:19 DrillQuest 2.00.09.001 Page 7 of 7 ( (' H 191158 DATE 6/04/01 CHECK NO. 0191158 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT A NET 100.00 00 ü601Üi CKO6010iN PYMT OMMENTS: HANDLING INST: 100.00 PER IT TO DRILL EE S/H - TERRIE HUB LE X4628 ~ÞI-l / L/ liE AlTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. p.o. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND ", AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO No.H 1911,5 8 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 ~ 00191158 PAY To The ORDER Of "'",' :",i..', " " ONEHU~bRED &0. OO/100~:**~~************¥**~~~~*~*********** U$ DgiLAR DATE;\~MO~~T Qký O~I 01 . . ;:¡cy.....k' ¥i 00 ,\~/I Nq;rVALIDAFTER1¿O, DAYS '" .. ~',.,":'..','.:'..,',:.",,',',',',':.,',.."..,.,,'.,',,',,'""'.".,',,.,.,',:.." ".:,"",'",.":,1,..".,..,.".,',.,."",,., ,':'::-',,",A,t , ' ,/J ,~* .!J;1ß/1v\ ", ,.. ' , , .. ',' .. .." "ALAS,II\A OIL AND GAS '.' Óql\l~ER V ~T I ON~bMMJ SSION 33:3WES177TH AVENUE SUITE 100'" '" ANCHORAGE AK 9950.1 III ~ G ~ ~ 5 a III I: 0 I. ~ 2 0 ~ 8 ~ 5 I : 0 0 a a. l. ~., III ( :1 \ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSNDTTAL LETTER WELL NAME ~e.I - J l 1- 1 CHECK 1 STANDARD LETTER DEVELOPMENT CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL "CLUE" The permit is for a new wellbore segment of existing well it'1~.l""I/. Permit No,,:zo/-I.;'?API No. $.0- ð2-'-.:t..:J dJ3 (If api number last two (2) Production should continue to be reported as a function of digits are between 60-69) the original API number stated above. v DEVELOPMENT REDRILL PILOT HOLE (PH) EXPLORATION ANNULAR DISPOSAL l.:.->NO INJECTION WELL ANNULAR DISPOSAL L.J YES INJECTION WELL RED RILL ANNULAR DISPOSAL THIS WELL In accordance with 20 AAC 25.005(t), all recor~s, data and logs acquired for the pilot hole must be . clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs. acquired f~r well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS L-> YES + SPACING EXCEPTION .. Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. ' o.~v ~~ ~\) ~ ~ \ ~ '7 \'Ð.t ?5"::>c;! 0 \ Q' ~ ((:) ,~ "'~ 0 \ '-' ~ Templates are located m drive\jody\templates ../ WELL PERMIT CHECKLIST COMPANY WELL NAME ~,PJ ..//t../ PROGRAM: exp - dev -X redrll FIELD & POOL'.ç.? 5""/ ~ d INIT CLASS.?kv / -~I ~l GEOL AREA r¿:- 7" d ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . . . , . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . , . . Y N 5. Well located proper distance from drilling unit boundary- . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available' in drilling unit.. . . . . . . - . . . Y N, 8. If deviated, is wellbore plat included.. . . . . . . . . . . .'. . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can.be issued without administrative approval.. . . . . Y N 13. Can permit be approved before 15-day wait.. . . . . . . . . . Y N ('¡ 14. Conductor string provided. . . . . . . . .. . . . . . . . . . (' ~ "" A. 10 .'\.-. {Q ~~\ .,..~ c vr.....¿J it h~ ~ Jo.... ~ l? tl/-<¿.-&-""-' ~~: ~~~: ':d~~~~~~II:O: ~~~:~r & ~rt ~g: : : : : ~ '6 l u ~ L !.tÛ.e. s .¡. $øL 1/~ .,.)1"$ ð 17. CMTvoladequatetotie-inlongstringtosurfcsg........ X N ,I f:.. '/I 18. CMT will cover all known productive horizons. . . . . " . . . . W N - N ~ ~e f> C\. "~"'f~.. S\J. ~.~ C~, C ~ ...t:'~,~ 19. Casing designs adequate for C, T, B & permafrost. . . . . . . j N & T 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N ~ . 21. If a re-drill, has a 10-403 for abandonment been approved. . . ' 22. Adequate well bore separation proposed.. . . . . . . . . . " . Y (' 23. If diverter required, does it meet regulations. . . . . . . . . . N 24. Drilling .fluid program schematic & equip list adequate. . ~ . . N Vt C' ,¿/é\ ~ ~-,..- .f! . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Y N (\ I ' APPR .g~"11,/ 26. BOPE press rating appropriate; test to ~ ~ 0 psig. Y N ala ~'O/' 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . Y N '" I ~/_, .J" \ 28. Work will occur without operation shutdown. . . . . . . . . . . N , .' ~' 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y ~ GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures. . . . ,. Y N 31. Data presented on potential overpressure zones. . . . . . . Y N 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y N A PR .,PI'.T~ 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . Y N ~I 34. Contact name/phone for weekly progress reports [exploratory only] Y N ANNULAR DISPOSAL35. With 'proper cementing records, this plan. (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate frèshwater; or cause drilling waste. .. to surface;' , (C) will notimpair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLO Y: ENGINEERING:' UIC/Annular COMMISSION: ~þ . ~ WM . 8~s Cd( , . ~,.J) \ JMI-t ~~TE/ 7,L&þ I ENGINEERING APPR DATE serv wellbore seg L- ann. disposal para req - // ? z cr ON/OFF SHORE a V UNIT# ;~ Z -4 .::I: Com mentsllnstructions: c:\msoffice\wordian\diana\checklist (rev. 11/01/100) ,- c a z a -4 :e ~ ( - -f m - - en )- ::tI m :Þ ,( ~' I~ Well History File APPENDIX " Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special' effort has been made to chronologically. . . organize this category of information. ( (~ ~'ÐJ-/3~~\; Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 08 13:24:22 2002 Reel Header Service name............ .LISTPE Date.....................02/02/08 Origin...................STS Reel Name,.............. . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments............,... .STS LIS Writing Library. Scientific Technical Services Tape Header Service name..........,. .LISTPE Date.......,.............02/02/08 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 Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPI-IILI 500292303360 BP Exploration (Alaska) I Inc Sperry-Sun Drilling Services 08-FEB-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MM-11151 TIM GALVIN D. FERGUSON MWDRUN 2 AK-MM-11151 TIM GALVIN D. FERGUSON MWDRUN 5 AK-MM-11151 D. LABRECQUE D. FERGUSON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 33 13N 10E 2343 3966 MSL 0) 63.55 34.70 # WELL CASING RECORD 1ST STRING 2ND STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.500 20.000 108.0 9.875 10.750 2729.0 (" (' 3RD STRING PRODUCTION STRING 6.125 7.000 10345.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS LATERAL WAS DRILLED OFF OF A WHIPSTOCK IN MPI-ll1 THE TOP OF WHICH WAS SET AT 10345/MD/3596/TVD. 4. MWD RUNS 11 21 (MPI-ll) AND 5 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). AT-BIT INCLINATION (ABI) AND PWD WERE ALSO INCLUDED IN MWD RUN 5. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED PER E-MAIL FROM D.SCHNORR (GEOQUEST/BP) I DATED 2/05/02. MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 11 21 AND 5 REPRESENT WELL MPI-ll Ll WITH API#: 50-029-23033-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13190/MD/3557/TVD. SROP = SMOOTHED SGRC = SMOOTHED SEXP = SMOOTHED SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE SLIDE = NON-ROTATED INTERVALS $ RATE OF PENETRATION WHILE DRILLING. GAMMA RAY COMBINED. PHASE SHIFT-DERIVED RESISTIVITY (EXTRA RESISTIVITY (SHALLOW RESISTIVITY (MEDIUM RESISTIVITY (DEEP TIME, File Header Service name....,....." .STSLIB.OOI Service Sub Level Name... Version Number.......... .1,0.0 Date of Generation...... .02/02/08 Maximum Physical Record, .65535 File Type................LO Previous File Name....., .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: 1 clipped curves; all bit runs merged. .5000 # FILE SUMMARY PBU TOOL CODE ROP FET RPD RPM RPS RPX GR $ ( START DEPTH 108.5 152,5 152.5 152.5 152.5 152.5 160.0 ( STOP DEPTH 13190.0 13143.0 13143.0 13143.0 13143.0 13143.0 13136,0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD MWD $ DATA SOURCE TOOL CODE # REMARKS: BIT RUN NO 1 2 5 MERGED MAIN PASS. $ MERGE TOP 108.5 2743.0 10345.5 MERGE BASE 2743.0 10345.0 13190.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction....,........... . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... ,-999 Depth Units.........,..........,.. Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 13190 6649.25 26164 108.5 13190 ROP MWD FT/H 0.62 799.41 206.907 26156 108.5 13190 GR MWD API 10.77 129.75 70.77 25874 160 13136 RPX MWD OHMM 0.23 2000 15.8687 25888 152,5 13143 RPS MWD OHMM 0.23 2000 19.2604 25888 152.5 13143 RPM MWD OHMM 0.17 2000 23.9818 25888 152.5 13143 RPD MWD OHMM 0.22 2000 35,0405 25888 152.5 13143 FET MWD HOUR 0,0866667 260.04 1.12194 25888 152.5 13143 First Reading For Entire File......... .108.5 ( { Last Reading For Entire File......,.., .13190 File Trailer Service name............ .STSLIB,OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/08 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..,... .02/02/08 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 ROP RPD RPM RPS RPX FET GR $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 108.5 152.5 152.5 152.5 152.5 152.5 160.0 # 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 $ STOP DEPTH 2743.0 2681.5 2681.5 2681.5 2681.5 2681.5 2689.0 09-SEP-01 Insite 66.16 Memory 2743.0 108.0 2743.0 .7 69.1 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PB02139HRGF8 PB02139HRGF8 # 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 ( 13.500 SPUD MUD 8.80 145,0 8.8 400 16.0 7.000 6.813 1.930 4.500 66.0 68.0 66.0 66.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 108.5 2743 1425.75 5270 108.5 2743 ROP MWD010 FT/H 0,62 342.77 153.586 5270 108.5 2743 GR MWD010 API 21,34 113.6 65.9807 5059 160 2689 RPX MWD010 OHMM 0.23 1611.44 25.9683 5059 152.5 2681.5 RPS MWD010 OHMM 0.23 2000 38,1236 5059 152,5 2681,5 RPM MWD010 OHMM 0.17 2000 55,0319 5059 152.5 2681.5 RPD MWD010 OHMM 0,22 2000 104.089 5059 152,5 2681.5 FET MWD010 HOUR 0,2244 4.5793 0.757522 5059 152.5 2681.5 First Reading For Entire File......... .108.5 Last Reading For Entire File.......... .2743 ( File Trailer Service name.........,.. .STSLIB.002 Service Sub Level Name... Version Number,......... .1.0.0 Date of Generation...... .02/02/08 Maximum Physical Record. .65535 File Type.............,..LO Next File Name.......... .STSLIB,O03 Physical EOF File Header Service name............ .STSLIB,O03 Service Sub Level Name... Version Number..,....... .1.0.0 Date of Generation...... .02/02/08 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 FET RPD RPM RPS RPX GR ROP $ 3 it' header data for each bit run in separate files. 2 .5000 START DEPTH 2729.0 2729.0 2729.0 2729.0 2729.0 2729.0 2747.5 # 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 $ # STOP DEPTH 10345,0 10345.0 10345.0 10345.0 10345.0 10345.0 10345.0 17-SEP-01 Insite 66,16 Memory 10345.0 2743.0 10345.0 75.0 85.8 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER PB02157HWRGVF6 PB02157HWRGVF6 9.875 ~.. DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......",.....,..O Data Specification Block Type.....O Logging Direction..............,. . Down Optical log depth units.......... .Feet Data Reference Point...,......... . Undefined Frame Spacing..............,.,... .60 .1IN Max frames per record..........., . Undefined Absent value.......".....".,....-999 Depth Units................,...... Datum Specification Block sub-type...O { LSND 10.00 50.0 9.5 300 6.4 3.600 2.979 3.900 3.100 70.0 86.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2729 10345 6537 15233 2729 10345 ROP MWD020 FT/H 7.4 799.41 236.838 15196 2747.5 10345 GR MWD020 API 10,77 128.58 67.8088 15233 2729 10345 RPX MWD020 OHMM 0.37 49.77 11.3655 15233 2729 10345 RPS MWD020 OHMM 0.37 49.77 11.3655 15233 2729 10345 RPM MWD020 OHMM 0.32 2000 13,381 15233 2729 10345 RPD MWD020 OHMM 0.45 2000 15.4903 15233 2729 10345 FET MWD020 HOUR 0.0866667 71.4696 0.949777 15233 2729 10345 First Reading For Entire File.,..,..,. .2729 Last Reading For Entire File.....,..,. .10345 ( File Trailer Service name............ .STSLIB.O03 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .02/02/08 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....,. .02/02/08 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 GR ROP FET $ 4 (' header data for each bit run in separate files. 5 .5000 START DEPTH 10345.5 10345.5 10345.5 10345.5 10345.5 10345.5 10345.5 # 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 $ STOP DEPTH 13143.0 13143.0 13143.0 13143.0 13136.0 13190.0 13143,0 29-SEP-01 Insite 66.16 Memory 13190.0 10345.0 13190.0 78,8 94.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 TOOL NUMBER PBO2164HAGR4 PBO2164HAGR4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 (' # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): 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 ,{ ~ BaraDril-N 9.20 49.0 8.7 23000 4.3 .120 .117 .180 .240 82.0 84.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10345.5 13190 11767.8 5690 10345,5 13190 ROP MWD050 FT/H 2.64 778.08 176.355 5690 10345.5 13190 GR MWD050 API 54.91 129.75 83.1915 5582 10345.5 13136 RPX MWD050 OHMM 0.32 2000 18,9966 5596 10345.5 13143 RPS MWD050 OHMM 0.54 2000 23,6983 5596 10345.5 13143 RPM MWD050 OHMM 5.45 1217.52 24.768 5596 10345.5 13143 RPD MWD050 OHMM 5.49 1217.64 25.836 5596 10345.5 13143 FET MWD050 HOUR 0.18 260,04 1.92003 5596 10345.5 13143 First Reading For Entire File......... ,10345,5 Last Reading For Entire File..."..... ,13190 ( File Trailer Service name............ .STSLIB.004 Service Sub Level Name.,. Version Number..,....... .1.0.0 Date of Generation...... .02/02/08 Maximum Physical Record. .65535 File Type............,.,.LO Next File Name,..,...". .STSLIB.005 Physical EOF Tape Trailer Service name.,.......... .LISTPE Date.....................02/02/08 Origin...................STS Tape Name.............., .UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Reel Trailer Service name.......,..., .LISTPE Date..,..........,.......02/02/08 Origin...................STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name,.,....... . UNKNOWN Comments................ .STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File (' Scientific Technical Services Scientific Technical Services