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208-166
STATE OF ALASKA r AL .CA OIL AND GAS CONSERVATION COMI4. _MON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U ESP Changeout Performed: Alter Casing ❑ Pull Tubing 0 Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 2Exploratory ❑ 208-166 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99503 50-029-23200-61-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0047434/ADL0355017 Milne Pt K2 C-43-L1-01 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Milne Point Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: RECEIVED Total Depth measured 15,220 feet Plugs measured N/A feet true vertical 7,348 feet Junk measured ±13,604 feet MAR 0 3 2015 Effective Depth measured ±13,604 feet Packer measured 12,764 feet AOG(1(1 true vertical ±7,315 feet true vertical 6,513 feet ��✓✓vv Casing Length Size MD ND Burst Collapse Conductor 112' 20 112' 112' 1,530psi 520psi Surface 9,363' 10-3/4" 9,363' 4,736' 5,210psi 2,470psi Intermediate 12,883' 7-5/8" 12,883' 6,641' 6,890psi 4,790psi Production 1,080' 4-1/2" 13,815' 7,545' 8,430psi 7,500psi Liner 1,641' 2-7/8" 15,123' 7,340' N/A N/A Liner 1,805' 2-7/8" 15,501' 7,353' N/A N/A Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SCANWEI "} Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80/EUE 8rd 12,683'MD 6,455'TVD 12,764'(MD) Packers and SSSV(type,measured and true vertical depth) 7-5/8"x 5.5"ZXP Packer N/A 6,513'(TVD) N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 195 60 326 260 210 Subsequent to operation: 193 80 1,036 300 240 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory El Development Q Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 10 Gas El WDSPL El GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-033 Contact Chris Kanyer Email ckanvera.hilcorp.com Printed Name Chris Kanyer Title Operations Engineer Signature L-7.:4, Phone 907-777-8377 Date 3/3/2015 3-/7-( 5✓ RBDMSJ MAR - 5 2015 Form 10-404 Revised 10/2012 '67X ..------- Submit Original Only Milne Point Unit 14 Well: MPC-43L1-01 SCHEMATIC Last Completed: 2/10/09 llilcorp Alaska,L1.1: PTD: 208-166 CASING DETAIL Orig.KB Elev.:34.7'/GL Elev.:16.40' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 94/H-40/Btc 18.936 0 112' :. 10-3/4" Surface 45.5/L-80/Btrc. 9.794 0 9,363' 7-5/8" Intermediate 29.7/L-80/Btc Mod 6.750 0 12,883' a 1 4-1/2" Production 12.6/L-80/IBT Mod 3.833 12,735' 13,815' 2-7/8" Liner C-43L1-01 6.16/L-80/STL N/A 13,482' 15,123' 2-7/8" Liner C-43L1 6.16/L-80/STL N/A 13,696' 15,501' s• .w! DETAIL or 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 12,683' ;f• 3/8" Capstring Stainless Steel N/A 0 12,683' 10-3/4" 'a ► JEWELRY DETAIL No Depth Item 1 139' GLM 3/8'SS Capstring 2 12,418.' GLM 3 12,559' XN-Nipple(2.250"ID) 4 12,601..53' Well Discharge Gauge Unit 5 12,602' PUMP 6 12,644' Gas Separator 7 12,649' Tandem Seal Assembly 8 12,663' Motor 9 12,680' Welllift MGU Sensor 10 12,681' Centralizer-Bottom @ 12,683' 11 12,735' Baker Tie Back Sleeve 12 12,746' Baker 7-5/8"x 5-1/2"ZXP Liner Packer 2 13 13,727' 4.5"Float Collar(PBTD) 14 13,815' 4.5"Float Shoe PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status r 3 Kup.A3 Sands 13,566' 13,576' 7,298' 7,308' 10 4/26/2004 Open Kup.A2 Sands 13,580' 13,600' 7,312' _ 7,332' 20 4/26/2004 Open 4 Kup.Al Sands 13,619 13,628' 7,350' 7,359' 9 N/A Open I 5 WELL INCLINATION DETAIL KOP @ 300' 6 Max Hole Angle=69 deg. 7 Hole Angle through perforations=7 deg. 9 OPEN HOLE/CEMENT DETAIL V,8 20" Cmt w/260 sks of Arctic Set(Approx.)in 42"Hole ►7 10 -3/4" Cmt w/1,023 sks Arctic Set III,258 sx Class"G"in 13-1/2"Hole 7-5/8" Cmt w/150 sks Class"G"in 9-7/8"Hole '1 4-1/2" Cmt w/203 sks Class"G"in 6-3/4"Hole • 10 r 11 TREE&WELLHEAD 12 Tree 2-9/16"SM FMC 7-5/8" 11"x 11"5M FMC Gen 5M,w/2-7/8"FMC Tbg.Hngr., 2-7/8"L-80 Slotted Wellhead 2-7/8"EUE top&bottom,2.5"CIW BPV Profile Liner 13,482'-15,123' ENDO MPC-43L1-01 GENERAL WELL INFO Top @ 13,460' Bottom @ 13,480' API:50-029-22794-61-00(C-43L1-01) Drilled and Cased by Doyon 14 -4/9/2004 FISH: • Add Fracd and Perfs-4/26/2004 0,f-3412 HUMCharges l'' Converted to ESP by Nabors 4ES-5/25/2005 @u13,604. _ ��� CTD Laterals-1/14/2009 2 HES RTTS Slip �__,._,-,.. Segments @±13,610 = '' Recomplete ESP w/Nabors 3S-2/10/2009 Recomplete ESP w/Doyon 16-5/26/2012 4-1/2 113&14 Recomplete ESP w/Nordic 3-2/12/2015 2-7/8"Slotted Liner 13,696' TD=13,817'(MD)/TD=7,547'(TVD) -15,501'MP C-43L1 PBTD=13,727'(MD)/PBTD=7,458'(TVD) Created By:TDF 3/2/2015 Hilcorp Alaska, LLC ,,.,,,.,, IAA Weekly Operations Summary Well Name API Number Well Permit Number _Start Date End Date MPC-43L1-01 50-029-23200-61-00 208-166 1/9/2015 2/12/2015 Daily Operations: 2/4/15-Wednesday No operations to report. 2/5/15-Thursday No operations to report. 2/6/15-Friday No operations to report. 2/7/15-Saturday No operations to report. 2/8/15-Sunday No operations to report. 2/9/15-Monday MIRU. R/U hard line to kill tank.Take on hot 150deg Seawater.Start to build 300 bbl 8.5 ppg seawater. R/U cellar hoses.Continue to take on fresh water to build seawater.Wrap steam blanket around hanger. Pull BPV. Tubing 580psi, IA 630psi.Wait on hot seawater delivery.Test lines to 3,500psi.Good. Blow down lines.Work on frozen hard lines. PJSM, Pre-spud C-43. Kill well. Pump 100 bbl 8.5 hot seawater down the tubing.Shut in annulus&bullhead 45 bbl. 70psi 3 bpm.OA @ 390psi.Continue to pump the long way @ 5 bpm 700psi bleeding gas from the annulus. Pumped 600 bbl.choke open.No pressure. Line up and pump 130 bbl down the annulus. Monitor well. Both the tubing and the annulus on a vac.Set TWC.Take pics of tree orientation. N/D tree. Inspect threads&hanger.OK. Function lockdowns. Good. N/U BOP's.Test BOP's as per AOGCC. 250psi low/2,500psi high. Filling the annulus with 5 bph 8.5 seawater.Call production out to shoot a fluid level.Daily Losses @ 810 bbl.Total losses to the well 810 bbl. 2/10/15-Tuesday Test BOPE 250psi low_/2,5002si high as_Rer AOGCC. Witteness was waved by Jeff Jones @ 2-8-2015 14:41. Blinds leaking. Open up and change carrier on block. Retest.GOOD. Perform accumulator draw down test. Pull TWC, pump 25 bbl hot seawater down back side.Top drive problems repair.Unland hanger pull to floor SW 140 K string dragging 25- 30K.Cut ESP Cable, remove penetrators BO LD hanger and 5'pup, LD 10'pup, pull 1 stand thread ESP cable and LD GLM#w 2 ea 10' pups pull 1/2 stand and connect ESP cable to spooler.Continue POOH intermittent overtorqued pipe difficult to BO. Cannon clamps on every collar. Drag gone by 6th stand out.After 95 stands out tubing gassing. Pump 50 bbls 8.Sppg brine down tubing continue POOH LD GLM#2(appears clean no sand) POOH BO LD XN, LD single secure& cut ESP cable. POOH full length of motor no sand eveidence in Phoenix guards or clamps.Check motor windings dead short in 1 leg. Discuss with engineer,eliminate Slickline run. RIH with pump assy and POOH BO LD pump assy, reconfiguring spooling unit remove used cable, install new cable and capillary spools. Hilcorp Alaska, LLC ,,,,, Weekly Operations Summary Well Name API Number Well Permit Number Start Date End Date MPC-43L1-01 50-029-23200-61-00 208-166 1/9/2015 2/12/2015 Daily Operations: 2/11/15-Wednesday PJSM.Organize pipe rack Lay out pump assy,GLMs, and profile. PU MU pump assy, make up cap to centralizer port and ESP cable connection.Test capillary and check valve open successfully at 4,400psi.Test ESP connection. Pump assy/centralizer 2.1',Sensor 1.81', motor 15.73',lower tandem Seal 6.89', upper tandem seal 6.89',gas separator 4.9', pump 6.95', pump 17.53', pump 17.53',discharge head .63',I Pup Jt 2-7/8" 10.13'. RIH to 2,000'-test ESP cable test cap to 4,200psi for ckeck open.Continue RIH cap test @ 6,000'to 2,300psi,slow going spooling off continues to be a slow process to prevent backlash.Continue in hole to 7,385'. Perform ESP cable splice continue hole fill of 5 bph.Total losses to date 1135 bbls.Splice tested Bad splice.Starting over. 2/12/15-Thursday PJSM.Splice on ESP bad, re-splice.Test Splice all good.Continue to RIH from 7,358'-12,685'. Install Hanger, install penetrators,cap line and splice ESP surface connector.Test all good.Land hanger 138K string Weight. 138k up 70k down.Total Fluid losses 1,175bbls seawater. BHA as follows.Centralizer 12,685.48',top of pump assy 12,601.5', 10'pj, 1 jt 2-7/8"tbg,XN @ 12,558.97',4 jts 2-7/8"tbg,GLM @ 12,418.17',392 jts tbg,GLM@ 138.6', 3 jts tbg, 10'pj,3.7'pj, and hanger. Install TWC, ND BOPE test ESP connector and capillary, install tree,test ESP Install capillary string.Test void and tree 250psi Low 5,000psi High. Pull TWC. Install BPV in hanger well services wrapping tree for heat and insulation. RDMO clean around well head. 2/13/15-Friday No operations to report. 2/14/15-Saturday No operations to report. 2/15/15-Sunday No operations to report. 2/16/15-Monday No operations to report. 2/17/15-Tuesday No operations to report. OF �w vI�j, sv THE STATE Alaska Oil and Gas mw s ' Conservation Commission of __ ALASKA 333 West Seventn Avenue z GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 FALASY'P" Fax: 907.276 7542 www.aogcc.alaska.gov Chris Kanyer Operations Engineer �� `"��` 2015 �� Hilcorp Alaska, LLC 0 a 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: Milne Point Field, Kuparuk River Oil Pool, Milne Pt KR C-43L1-01 Sundry Number: 315-033 Dear Mr. Kanyer: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / /0044A4,74 ._ Cathy '. Foerster Chai ra- DATED this Z3 day of January, 2015 Encl. RECEIVED ► 1 STATE OF ALASKA JAN 2 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1.Type of Request: Abandon❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0 Change Approved Program 0 Suspend❑ Plug Perforations p Perforate❑ Pull Tubing 0, Time Extension 0 Operations Shutdown 9 Re-enter Susp.Well ❑ Stimulate 9 Alter Casing❑ Other. ESP Change-out 0. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ' Exploratory 9 Development 9 • 208-166 3.Address: Stratigraphic ❑ Service 1=1 6.API Number. 3800 Centerpoint Drive,Suite 1400,Anchorage AK,99503 50-029-23200-61-00 ' 7.If perforating: ti3 C--egn 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? C.O. 4.7-3' Will planned perforations require a spacing exception? Yes 9 No 9 Milne Pt KR C-43L1-01' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0047434/ADL0355017 • Milne Point Field/Kuparuk River Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 15,220 • 7,348 • ±13,604, ±7,315• N/A ±13,604 Casing Length Size MD ND Burst Collapse Conductor 112' 20" 112' 112' 1,530psi 520psi Surface 9,363' 10-3/4" 9,363' 4,736' 5,210psi 2,470psi Intermediate 12,883' 7-5/8" 12,883' 6,641' 6.890psi 4,790psi Production 1,080' 4-1/2" 13,815' 7,545' 8,430psi 7,500psi Liner 1,641' 2-7/8" 15,123' 7,340' N/A N/A Liner 1,805' 2-7/8" 15,501' 7,353' N/A N/A Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic t See Attached Schematic 2-7/8" 6.5#/L-80/EUE 8rd 12,724 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): 7-5/8"x 5.5"ZXP Packer and N/A . 12,746(MD)/6,513(TVD and N/A 12.Attachments: Description Summary of Proposal Q '13.Well Class after proposed work: Detailed Operations Program 9 BOP Sketch 9 Exploratory ❑ Stratigraphic❑ Development❑✓ . Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/8/2015 Oil Q • Gas ❑ WDSPL 9 Suspended 0 16.Verbal Approval: Date: M/A WINJ 0 GINJ ❑ WAG [ t14 Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG LI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Kanyer Email ckanyer@hilcor0.com Printed Name Chris Kanyer Title Operations Engineer Signature ("NA,i XPhone 777-8377 Date 1/19/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3k 5 - o33 Plug Integrity ❑ BOP Test ❑/ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ( ...7_.- Spacing Exception Required? Yes ❑ No Subsequent Form Required: Ie.,- 44C`f , / APPROVED BY Approved by: �`F-fig COMMISSIONER THE COMMISSION [- , Date: /, Z3-45-- / ''yA�J, I .21.-1 r cjigiaG,ItNAL ,pI II i)s p ,�/%�L//x Submit Duplicate and Form 10-403 Revised 10/2012) sIr 12months from he date of approval. ` Attachments in Du licate y RBDMS J JAN 2 6 2015 /10/-AS-/-5" Well Prognosis Well: MPC-43L1-01 Hilcory Alaska,LI) Date:1/19/2015 Well Name: MPC-43L1-01 API Number: 50-029-23200-61-00 Current Status: SI Producer Pad: C Pad Estimated Start Date: February 8, 2015 Rig: Nordic 3 Reg.Approval Req'd? February 1, 2015 Date Reg.Approval Rec'vd: CA)A1 Regulatory Contact: Tom Fouts Permit to Drill Number: 'i9�•Q 7 2O8-166 Z6S IP First Call Engineer: Chris Kanyer (907)777-8377 (0) (907) 250-0374 (M) / Second Call Engineer: Bo York (907)777-8345 (0) (907)727-9247 (M) AFE Number: 1454020 Current Bottom Hole Pressure: - 1,773 psi @ 7,000'TVD (Last BHP measured 12/11/2012) Maximum Expected BHP: - 1,773 psi @ 7,000'TVD (No new perfs being added) Max.Allowable Surface Pressure: 0 psi (Based on actual reservoir conditions and water cut of 68% (0.408psi/ft)with an added safety factor of 1000'TVD of oil cap) Brief Well Summary: The Milne Point C-43 well was drilled as a Kuparuk development well that TD'd at a depth of 13,817' and ran and cemented 7-5/8" production casing&4-1/2" liner in April 2004. The well was perforated and Frac'd in the Kuparuk A sands and initially completed with a jet pump.The well was then converted to ESP in May 2005.The well had two coil tubing laterals drilled (C-4311-01) and cased with 2-7/8" slotted liners in January 2009, with a ESP ran in February 2009. A successful 7-5/8" casing pressure test was performed prior to running this completion on 1/21/2009 to 2,000psi. A failed ESP was changed out in May 2012 and it failed in November 2014.The well has remained shut in ever since. A downholeemical injection line will be run as part of the new completion, but no scaling issues suspected in this well. No subsidence issues are expected in this well. A tubing caliper and subsidence drift are planned as part of the rig prep of this well. Notes Regarding Wellbore Condition Current well status is shut in oil producer. No subsidence issue suspected. RWO Objective: Pull ESP& run 2-7/8" ESP completion with downhole chemical injection. Brief Procedure: 1. MIRU Nordic#3 Rig. 2. Circulate well with 8.5ppg brine. Monitor well. i 3. ND tree, NU 13-3/8" BOPE with 11"spool adapter and test to 250psi low/2,500psi high, annular to 250psi low/2,500psi high. a. Notify AOGCC 24hrs in advance to witness test. 4. Unseat hanger and pull 2-7/8" ESP completion from 12,724'to surface and lay down same. 5. RU Slickline. RIH and tag fill with gauge ring. POOH with same and RD slickline. ti .. - Well Prognosis Well: MPC-43L1-01 Hilcorp Alaska,LL Date:1/19/2015 Contingency: (Pending results of slickline tag depth and/or condition of pulled completion—sand/scale in pump) a. RIH with 4-1/2"x 7-5/8"tandem cleanout BHA and attempt a cleanout in mother wellbore (not CTD slotted liners)and circulate well clean to+/-13,600'. b. POOH with 4-1/2"x 7-5/8"tandem cleanout BHA from+/-13,600'. 6. MU and RIH with ESP with gas separator and 3/8" chemical injection line on 2-7/8"8RD EUE L-80 tubing [to be replaced if necessary]. Set ESP at+/-12,724'. Land tubing hanger. 7. ND BOP, NU and tree. 8. RDMO workover rig and equipment. 7 9. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic Milne Point Unit Well: MPC-43L1-01 SCHEMATIC Last Completed: 2/10/09 Hilcorp Alaska,LLC PTD: 208-166 CASING DETAIL Orig.KB Elev.:34.7'/GL Elev.:16.40' Size Type Wt/Grade/Conn Drift ID Top Btm 20" Conductor 94/H-40/Btc 18.936 0 112' 20.`1 , 10-3/4" Surface 45.5/L-80/Btrc. 9.794 0 9,363' 7-5/8" Intermediate 29.7/L-80/Btc Mod 6.750 0 12,883' 1 4-1/2" Production 12.6/L-80/IBT Mod 3.833 12,735' 13,815' 2-7/8" Liner C-43L1-01 6.16/L-80/STL N/A 13,482' 15,123' 2-7/8" Liner C-43L1 6.16/L-80/STL N/A 13,696' 15,501' TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 12,724' JEWELRY DETAIL 10-3/4" A 6 No Depth Item 1 140' GLM 2-7/8"x 1"KBMM w/DSOV 2 12,455' GLM 2-7/8"x 1"KBMM w/DGLV 3 12,608' XN-Nipple(2.250 No-go ID) 4 12,649' Well Discharge Gauge Unit 5 12,654' Tandem Pumps/100-P31 SXD/18-P75 SXD MVP-Bottom @ 12,679' 6 12,679' Gas Separator GRSFTXAR H6 7 12,684 Tandem Seal Assembly Upper-GSB3DBUT/Lower-GSB3DBLT 8 12,698' Motor-KMH 266HP,2,345 Volt,69 Amp 9 12,721' Welllift MGU Sensor 10 12,722' Centralizer-Bottom @ 12,724' 11 12,735' Baker Tie Back Sleeve 12 12,746' Baker 7-5/8"x 5-1/2"ZXP Liner Packer 13 13,727' 4.5"Float Collar(PBTD) 14 13,815' 4.5"Float Shoe IN2 PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status Kup.A3 Sands 13,566' 13,576' 7,298' 7,308' 10 4/26/2004 Open 1 3 Kup.A2 Sands 13,580' 13,600' 7,312' 7,332' 20 4/26/2004 Open Kup.Al Sands 13,619 13,628' 7,350' 7,359' 9 N/A Open i I 4 WELL INCLINATION DETAIL 5 KOP @ 300' Max Hole Angle=69 deg. 6 Hole Angle through perforations=7 deg. 7 OPEN HOLE/CEMENT DETAIL 20" Cmt w/260 sks of Arctic Set(Approx.)in 42"Hole 8 10-3/4" Cmt w/1,023 sks Arctic Set III,258 sx Class"G"in 13-1/2"Hole 7-5/8" Cmt w/150 sks Class"G"in 9-7/8"Hole 4-1/2" Cmt w/203 sks Class"G"in 6-3/4"Hole 9 10 TREE&WELLHEAD 11 Tree 2-9/16"5M FMC .11 12 Wellhead 11"x 11"5M FMC Gen SM,w/2-7/8"FMC Tbg.Hngr., 7-5/s' 2-7/8"EUE top&bottom,2.5"CIW BPV Profile 2-7/8"L-80 Slotted Liner 13,482'-15,123' GENERAL WELL INFO ENDOW. MPC-43L1-01 Top @ 13,460 �� API:50-029-22794-61-00(C-43L1-01) Bottom @ 13,480 J Drilled and Cased by Doyon 14 -4/9/2004 "' - _� _� _ Add Fracd and Perfs-4/26/2004 FISH: ,, Converted to ESP by Nabors 4ES-5/25/2005 ZPF-3412 HNIXCharges :` �:-... CTD Laterals-1/14/2009 @±13,604. _ -.� Recomplete ESP w/Nabors 3S-2/10/2009 2HESHIIbSlip - �..,, Segments©±13,610 = �� Recomplete ESP w/Doyon 16 5/26/2012 ®B 4-1/2'/ 6 13&14 2-7/8"Slotted Liner 13,696' TD=13,817'(MD)/TD=7,547'(TVD) -15,501'MP C-43L1 PBTD=13,727'(MD)/PBTD=7,458'(TVD) Created By:TDF 12/31/2014 Milne Point Unit , El Well: MPC-43L1-01 PROPOSED Last Completed: 2/10/09 Hilcorp Alaska,LLA: PTD: 208-166 CASING DETAIL Orig.KB Elev.:34.7'/GL Elev.:16.40' Size Type Wt/Grade/Conn Drift ID Top Btm if,i 20" Conductor 94/H-40/Btc 18.936 0 112' _cil 20"• W 10-3/4" Surface 45.5/L-80/Btrc. 9.794 0 9,363' 7-5/8" Intermediate 29.7/L-80/Btc Mod 6.750 0 12,883' `�� 4-1/2" Production 12.6/L-80/IBT Mod 3.833 12,735' 13,815' r' ' %� 2-7/8" Liner C-43L1-01 6.16/L-80/STL N/A 13,482' 15,123' 2-7/8" Liner C-43L1 6.16/L-80/STL N/A 13,696' 15,501' i, TUBING DETAIL 2-7/8" Tubing 6.5/L-80/EUE 8rd 2.441 0 ±12,724' 3/8" Capstring Stainless Steel N/A 0 ±12,724' 10-3/4" • • JEWELRY DETAIL No Depth Item 1 ±140' GLM 3/8"SS Capstring 2 ±12,455' GLM 3 ±12,608' XN-Nipple 4 ±12,649' Well Discharge Gauge Unit 5 ±12,654' PUMP 6 ±12,679' Gas Separator 7 ±12,684 Tandem Seal Assembly 8 ±12,698' Motor 9 ±12,721' Welllift MGU Sensor 10 ±12,722' Centralizer-Bottom @±12,724' 11 12,735' Baker Tie Back Sleeve 12 12,746' Baker 7-5/8"x 5-1/2"ZXP Liner Packer 13 13,727' 4.5"Float Collar(PBTD) li 1 2 14 13,815' 4.5"Float Shoe PERFORATION DETAIL Sands Top(MD) Btm(MD) Top(TVD) Btm(TVD) FT Date Status 1 3 Kup.A3 Sands 13,566' 13,576' 7,298' 7,308' 10 4/26/2004 Open Kup.A2 Sands 13,580' 13,600' 7,312' 7,332' 20 4/26/2004 Open t 1 4 Kup.Al Sands 13,619 13,628' 7,350' 7,359' 9 N/A Open 5 WELL INCLINATION DETAIL KOP @ 300' 6 Max Hole Angle=69 deg. 7 Hole Angle through perforations=7 deg. ' OPEN HOLE/CEMENT DETAIL 8 20" Cmt w/260 sks of Arctic Set(Approx.)in 42"Hole 10-3/4" Cmt w/1,023 sks Arctic Set III,258 sx Class"G"in 13-1/2"Hole Iv, 9 , 7-5/8" Cmt w/150 sks Class"G"in 9-7/8"Hole 4-1/2" Cmt w/203 sks Class"G"in 6-3/4"Hole 10 11 TREE &WELLHEAD 12 Tree 2-9/16"SM FMC 7-5/8 11"x 11"5M FMC Gen SM,w/2-7/8"FMC Tbg.Hngr., 2-7/8"L-80 Slotted Wellhead 2-7/8"EUE top&bottom,2.5"CIW BPV Profile Liner 13,482'-15,123' WINDOW: � MPC-43L1-01 GENERAL WELL INFO Top @ 13,460' � /- Bottom @13,480' '1- , -C% API:50-029-22794-61-00(C-43L1-01) _ '� _�_�_� _ Drilled and Cased by Doyon 14 -4/9/2004 FISH: -_ Add Fracd and Perfs-4/26/2004 ZPF3412HMCCharges - ------ \ Converted to ESP by Nabors 4ES-5/25/2005 2@HE1S 3604.RTTS Si = \ ���_ CTD Laterals-1/14/2009 P Segments @±13,610 = �� Recomplete ESP w/Nabors 3S-2/10/2009 Recomplete ESP w/Doyon 16-5/26/2012 4-1/7' 4116 & 13&14 2-7/8"Slotted Liner 13,696' TD=13,817'(MD)/TD=7,547'(TVD) -15,501'MP C-43L1 PBTD=13,727'(MD)/PBTD=7,458'(TVD) Created By:TDF 12/30/2014 MPU BOP Stack r v v iiiiii Hydril 13 5/8 5M __, .iiiiii Shaffer SL * L.....4_ 13 5/8 5M Dual 2 7/8" rams * __* / Shaffer * ii 2 7/8"-5-1/2" variables 135 8 5M Blinds O • ___/ —,[11111111111.1111111; _ ,,— ) ( 1 le,,, i 0 c 01 c:.? ), : 13 5/8" SMX11" 5M DSA • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. aQ~ - 1 ~ ~ Well History File Identifier Two-sided II I II II II II II I II III ^ Rescan Needed III (I'l 11 (I I I II (III Organ-z~ng (done) ^ RES AN DIGITAL DATA for Items: ^ Diskettes, No. reyscale Items: ^ Other, No/Type: ^ Poor Quality Originals: ^ Other: NOTES: BY: ~ Maria Date: ~ Project Proofing BY: Date: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: ~O /s/ /s/ Scanning Preparation _~ x 30 = ~QQ_ + ~_ =TOTAL PAGES~3 (Count does not include cover sheet) BY: Maria Date: ~ ~s~ Production Scannin II I II II II I ~ III I I III g Stage 1 BY: Stage 1 BY: Page Count from Scanned File: -~' -~ (Count does include cover heet) ber in Scannin Pre aration: V YES NO Page Count Matches Num g P Maria Date: / ~ ~s~ P '~ 9 If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: ~s u ~ u ^i n ~ u n i i n~ Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Comments about this file: Date: Quality Checked imimmiuii 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT '~ 7/8/2010 Permit to Drill 2081660 Well Name/No. MILNE PT UNIT KR C-43L 1-01 Operator BP EXPLORATION (ALASKEy INC API No. 50-029-23200-61-00 MD 15220 TVD 7339 Completion Date 2/10/2009 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, GR, RES (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T e Med/Frmt Number Name Scale Media No Start Stop CH Received Comments Rpt LIS Verification 13090 15220 Open 3/23/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS ~~ D C Lis 17759 ~nduction/Resistivity 13090 15220 Open 3/23/2009 LIS Veri, GR, ROP, RAD, RAS, RPD, RPS og Induction/Resistivity 25 Col 13478 15220 Open 3/23/2009 MD MPR, GR 9-Jan-2009 o Induction/Resistivity 5 Col 13478 15220 Open 3/23/2009 TVD MPR, GR 9-Jan-2009 I o Gamma Ray 25 Col 13478 15220 Open 3/23/2009 MD GR 9-Jan-2009 D D Asc Directional Survey 13690 15220 Open 1/30/2009 pt Directional Survey 13690 15220 Open 1/30/2009 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION ~, Well Cored? 1'~ Daily History Received? V N Chips Received? aL1.Al-- Formation Tops ~ N Analysis YXQL- Received? DATA SUBMITTAL COMPLIANCE REPORT 7/8/2010 Permit to Drill 2081660 Well Name/No. MILNE PT UNIT KR C-43L1-01 Operator BP EXPLORATION (ALASKIy INC API No. 50-029-23200-61-00 MD 15220 ND 7339 Completion Date 2/10/2009 Completion Status 1-OIL Current Status 1-OIL UIC N Comments: Compliance Reviewed By. Date: l~ J w ~ ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Wednesday, April 01, 2009 2:37 PM To: Maunder, Thomas E (DOA) Subject: RE: MPC-43L1 (208-165) and MPC-43L1-01 (208-166) ._--- Hi Tom, This was a particularly fun one... (Doyon 14 Originally Drilled 03/18/04 - 04/10/04) Nabors 3S Prep'd the well 12/10/08 - 12/24/08 Nordic #2 CTD Drilled 12/27/08 - 01 /14/09 Nabors 3S moved back on to run completion 02/03/09 - 02/10/09 Thanks! Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 01, 2009 2:33 PM To: Hubble, Terrie L Subject: MPC-43L1 (208-165) and MPC-43L1-O1 (208-166) Terrie, I am belatedly reviewing the 407s for these new segments. The rig listed on the drilling operations reports is Doyon 14. These penetrations were coil drilled and according to the pre- post-rig work summary you supplied, Nordic 2 conducted the work. Please confirm this and I will make the correction by hand. Thanks in advance, Tom Maunder, PE AOGCC 4/1/2009 ! ~ MPC-43, Well History (Pre & Post CTD Sidetrack) Date Summary 10/12/08 T/I/0=200/300/0 Freeze Protect -Pump tbg w/5 bbls neat methanol & 15 bbls diesel. Freeze protect flow line w/4 bbls 60/40 methanol, 6 bbls diesel & 4 bbls 60/40 methanol. Shut laterals & bleed to 0 psi. IA/OA & master open. Wing, swab & ssv closed. Tag well & notify operator. Final WHP's=200/280/0 10/17/08 T/I/0=100/330/0. MIT OA to 2000 psi. Failed. Lost 400 psi in 15 minutes. Establish LLRT .9 bpm @ 1600 psi for 5 bbls. Monitor OA pressure. Bleed OA pressure down to 0 psi. FWHP = 100/330/0. 11/02/08 T/I/O=SSV/400/120, Temp=S1. PPPOT-T-T (PASS), pre CTD. PPPOT-T: Stung into test port (200 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (1 "). Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi 11/20/08 MADE 15 MIN GRADIENT STOP @ 12,148' SLM (12,145' MD). MADE 3 HR SBHP STOP @ 12,607' SLM (12,648' MD). PULLED 1"DGLV FROM ST#1 @ 12,482' MD. LEFT POCKET EMPTY PULLED 1" DPSOV FROM ST#2 @ 139' MD. SET 1"DGLV IN ST#2 @ 139' MD. WELL SUPPORT SET BPV. WELL LEFT S/I. PAD OP NOTIFIED. JOB COMPLETED. ~~ ~. 0 < .~lordic #2 ~ Rig$;u~to dri112 01/14/09 T/I/0= 0/0/0 (Freeze Protect Post RWO). Pumped 15 bbls Diesel down tubing. FWHP = 0/0/0 Master, SSV, IA, OA, Wing ,and Swab closed. 01/15/09 SPOT UP EQUIPMENT R/U SURFACE EQUIPMENT TEST WIRE REPACK STUFFING BOX. 01/16/09 MADE FRIST @ 12,737' SLM FOR ONE HR TIME 06:10 TO 07:10. MADE SECOND STOP @ 13,300 SLM FOR 3 HRS TIME 07:20 TO 10:20. RAN 2.5" MAGNET DOWN TO 3500 SLM SEVERAL TIMES, AND 3.5" MAGNET TO 7500'. RECOVERED TOTAL OF 3 CUPS METAL SHAVINGS. LAY DOWN EQUIPMENT FOR HIGH WIND 40+ MPH. 01/17/09 RAN 3.50" MAGNET TO 12730' SLM MULTIPLE TIMES. RECOVERED TOTAL OF 2.5 CUPS. RAN 3.80" MAGNET TO 12730' SLM SAT DOWN @ 2110 MD. RECOVERED 1/4 OF CUP. RUNNING 4.5 BRUSH W/ KJ, 3.5 MAGNET. 01/18/09 RAN 4.5 BRUSH, 3.5 MAGNET TO 12,705 SLM. WORK BRUSH FOR 15 MIN. RECOVERED TOTAL OF 1/2 CUP OF SHAVINGS IN 3 RUNS. RAN 4.5" BLB W/ 3.80" G. RING TO 12705' MD. WORK BRUSH. SET 3.813" X-LOCK, PX-PLUG BODY (3.805" OD), (4) 3/16" EQ PORTS. LIH = 26" SET @ 12705 MD. SET PRONG @ 12711 SLM. 01/19/09 T/I/0=150/0/0 (Assist Slickline. MIT- Tubing to 2000 psi.) PASSED. Pumped 3.7 bbls Diesel down tubing to bring pressure up to 2000 psi. Lost 60 psi in first 15 minutes. Lost 20 psi in second 15 minutes. Performed 2nd test with additional 0.1 bbls diesel to bring pressure from 1920 psi. to 2000 psi. Lost 0 psi in thirty minutes. FWHP = 150/0/0 Swab, SSV, and Wing closed. Master, IA, and OA open. 01/19/09 SET PX PLUG @ 12705 MD. PERFORMED MIT-T TO 2000 PSI -GOOD TEST. R/D. 01/20/09 T/I/O=0/0/0 (CMIT T x IA to 2000 psi.). Pumped .6 bbls Diesel down tubing to bring pressure up to 1400 psi. No change on IA. Bleed tubing down to 0 psi. Pumped 2.2 bbls into IA to bring pressure up to 2000 psi. Tubing pressure came up to 280 psi. Bleed pressure down to 0 psi on IA and tubing. FWHP = 0/0/0. Page 1 of 2 • MPC-43, Well History (Pre & Post CTD Sidetrack) Date Summary 01/21/09 INITIAL T/ I/ O = 0/0/0 SSV CLOSED. RAN SMALL CHARGE TUBING PUNCHER AND SHOT 12670 ' - 12672', ALL SHOTS FIRED. DEPTH CORRECTED TO TUBING TALLY AFTER LIGHTLY TAGGING PX PLUG AT 12696'. LRS ATTEMPTED TO CMIT TxIA, COULD NOT ESTABLISH COMMUNICATION. SLB RIG UP SECOND TUBING PUNCHER. RAN MEDIUM CHARGE PUNCHER AND SHOT 12657' - 12659', 3' AWAY FROM COLLAR. HAD 500 PSI ON TBG AND 0 PSI ON IA PRIOR TO SHOOTING. AFTER SHOOTING TBG DROPPED TO 250 PSI, IAP INCREASED TO 200 PSI. LRS TO CMIT AFTER E-LINE RDMO. DSO NOTIFIED WELL SHUT-IN AND SECURE AND OF VALVE PLACEMENT. FINAL PRESSURES 100/50/0. JOB COMPLETE. 01/21/09 T/I/0=0/0/0. CMIT T x IA to 2000 psi. Passed. Lost 40 psi on tbg & IA in first 15 minutes & 0 psi on tbg & IA in second 15 minutes. Bleed tbg & IA pressures down to 0 psi. FWHP = 0/0/0. A k ~ .,, .~ ~~ ,~~ ~ ,, up to pull`.. ~ ~ .:.,, end run. Page 2 of 2 INTEQ Log & Data Transmittal Form To: State of Alaska -AOGCC 333 W. 7th Ave. Suite 100 Anchorage, Alaska 99501 Attention: Christine Mahnken Reference: MPC-43L1 &MPC-43L1-O1 Contains the following: ~_ ~ __ ,1 ,~ f 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary t 1 color print - GR Directional Measured Depth Log (to follow) 1 color print - MPR/Directional TVD Log (to follow) 1 color print - MPR/Directional Measured Depth Log (to follow) LAC Job#: 2368042 ~ ~ ~' `. -- •s Sent by: Catrina Guid Date: 03/19/ v Received by: ~ ~ ~ -~ Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 ~~~~ ~ Baker Hughes INTEQ ~~ 7260 Homer Drive ~~S /~~ l ~~ B ~ Anchorage, Alaska 99518 Direct: (907) 267-6612 [ NT E(~ FAX: (907) 267-6623 //~® BAKER EiV6F~E5 Baker Atlas PRINT DISTRIBUTION LIST CUMYAN Y I3P EXPLUKA'1'lUN (ALASKA) INC CUUN"1'Y NUR'1'H SLUYE BURUUGH WELL NAME MPC-43L1-O1 WELL NAME MPC-43L1 STATE ALASKA FIELD MILNE POINT UNIT THIS DISTRIBUTION LIST AUTHORIZED BY: DATE 3/19/2009 CATRINA GUIDRY SO #: 2368042 Copies of Copies Digital Copies of Copies Digital Each Log of Film Data Each Log of Film Data 2 Company BP EXPLORATION (ALASKA) INC i Company DNR -DIVISION OF OIL & GAS Person PETROTECHNICAL DATA CENTER Person KRISTIN DIRKS Address LR2-1 Address 550 WEST TTH AVE 900 E BENSON BLVD. SUITE 802 ANCHORAGE AK 99508 ANCHORAGE AK 99501 1 Company STATE OF ALF.SKA - AOGCC Company Person CHRISTINE MAHNKEN Person Address 333 W. 7TH AVE Address SUITE 100 ANCHORAGE. AK 99501 Company Company Person Person Address Address Company Company Person Person Address Address Company Company Person Person Address Address Data Disseminated By BAKER ATLAS-PDC 17015 Aldine Westfield, Houston, Texas 77073 This Distribution List Completed By: ~R /, ~ y ~~_--- Page 1 of 1 ~~~-~~S_ ws i~~ STATE OF ALASKA ~~~~~~~ ,~~~ ALASK~IL AND GAS CONSERVATION COM~SSION ~6-oq WELL COMPLETION OR RECOMPLETION REPORT AND LO~A~ ~ ~ ~~~~~~~~ alasita Oil & Gas ~r,ri°. ` ~~~~ t;~~~~: 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well ~~it~ra~8 ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 2/10/2009 12. Permit to Drill Number 208-166 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 1/6/2009 13. API Number S0-029-23200-61-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 1/9/2009 14. Well Name and Number: MPC-43L1-01 1344 FSL, 2290 FEL, SEC. 10, T13N, R10E, UM Top of Productive Horizon: 486' FSL, 509' FEL, SEC. 33, T14N, R10E, UM 8. KB (ft above MSL): 51.1' Ground (ft MSL): 16.4' 15. Field /Pool(s): Milne Point Unit / Kuparuk River Total Depth: 1257' FSL, 1914' FEL, SEC. 33, T14N, R10E, UM 9. Plug Back Depth (MD+TVD) 15220' 7339' Sands 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 558168 y- 6029627 Zone- ASP4 10. Total Depth (MD+TVD) 15220' 7339' 16. Property Designation: ADL 047434 & 355017 TPI: x- 554577 y_ 6039299 Zone- ASP4 - 6040060 Zone- ASP4 Total De th: x- 553164 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: p y 18. Directional Survey ®Yes ^ No Submit electronic and rinted inform lion er 20 AA 25.0 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1800' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR, GR, RES Lam//NDOf~J@/~ ~160'/y~ y~19~5. S ~TYD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FL GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 34' 112' 4' 112' 42" 260 sx Ar tic t A rox. 1 -3/4" L- 7 -1/2" 1 r III ' 7-5/8" 29.7# L-80 128 33' 6641' -7/8" 150 sx I 'G' 4-1/2" 12.6# L-80 1273 ' 7196' - /4" 203 sx Class' ' -7/ " 6.1 L- 1 2' 14' 7 n L' r 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, IISt each i (MD+TVD of To & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p 2-7/8" Slotted Section 2-7/8", 6.5#, L-80 12715' None MD TVD MD TVD 13486' - 15082' 7218' - 7338' 25. ACID, FRACTURE,_CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT St KIND OF MATERIAL USED 1650' Freeze Protected w/ 22 Bbls of Diesel 26. PRODUCTION TEST Date First Production: February 19, 2009 Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump Date Of Test: 2/27/2009 HOUrS Tested: 6 PRODUCTION FOR TEST PERIOD OIL-BBL: 315 GAS-MCF: 127 WATER-BBL: 254 CHOKE SIZE: GAS-OIL RATIO: 403 Flow Tubing Press. 242 Casing Press: 360 CALCULAreD 24-HouR RATE OIL-BBL: 1,261 GAS-MCF: 508 WATER-BBL: 1,016 OIL GRAVITY-API (CORK): Not Available 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ,_; ', None ~~"~' ~~ ,-_~w Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE b 2.8. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND MARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. From MPC-43L1 (Contains Top of Productive Intervall None Kuparuk C1 13459' 7192' Kuparuk A 13574' 7296' Kuparuk A3 13580' 7300' Kuparuk A2 13610' 7319' Kuparuk AZ (Invert) 13685' 7338' MPC-43L1-01 Top Kuparuk A2 13772' 7326' Base Kuparuk A3 13796' 7321' Top Kuparuk A3 13844' 7314' Top Kuparuk A3 (Revert) 13870' 7312' Top Kuparuk A3 13965' 7318' Top Kuparuk A3 14375' 7325' Top Kuparuk A3 14922' 7333' Formation at Total Depth (Name): Kuparuk A3 14922' 7333' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego'ng is true and correct to the best of my knowledge. ~~Q~/ V Signed Terrie Hubble Title Drilling Technologist Date / MPC-43L1-01 208-166 Prepared ByName/Number. Terrie Hubble, 5644628 Well Number P rmi N . / A r v I Dolling Engineer: Greg Sarber, 564-4330 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ~ r BP EXPLORATION Page 1 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: ~0~'>C~pl-#~. t(,tn„1~~~ 2 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations ~ 12/25/2008 104:30 - 18:00 I 13.501 MOB I N ~ WAIT I PRE 18:00 - 00:00 6.00 MOB N WAIT PRE 12/26/2008 00:00 - 19:00 19.00 MOB N WAIT PRE 19:00 - 19:45 0.75 MOB N WAIT PRE 19:45 - 20:00 0.25 MOB P PRE 20:00 - 00:00 4.00 MOB P PRE 12/27/2008 00:00 - 08:00 8.00 MOB N WAIT PRE 08:00 - 10:00 I 2.001 MOB P I PRE 10:00 - 18:00 8.001 RIGU I P I I PRE 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 19:40 1.17 RIGU P PRE 19:40 - 20:00 0.33 RIGU P PRE 20:00 - 00:00 4.00 RIGU P PRE 12/28/2008 00:00 - 03:20 3.33 RIGU P PRE 03:20 - 03:40 0.33 BOPSU P PRE 03:40 - 04:00 0.33 BOPSU P PRE 04:00 - 14:00 I 10.00 I BOPSUp P I PRE 14:00 - 15:50 I 1.831 RIGU I P I I PRE 15:50 - 18:30 I 2.671 RIGU I P I WEXIT 18:30 - 21:30 3.00 RIGU P WEXIT 21:30 - 22:20 0.83 BOPSU P WEXIT Move rig off of MPB-22 & move to the edge of the pad. Clean up around the well. Place heater in extended mouse hole to help thaw it out. Work on misc rig projects. Continue to work on misc rig projects. Loaded the 2 3/8 E coil and instated hard line. Continue to wait for MPC-43 prep work. Continue with misc projects and cleaning on rig. Prep rig for rig move. Warm up moving system. Move satelite camp to C pad. PJSM on rig move Move rig from MP-B pad to C-pad, trip distance of 5.5 miles. Rig is parked on side of C pad waiting on C-43 well prep work to be completed. Continue with misc. rig projects and cleaning. SLB is changing out injector dodge bearings. Spot T-mats & herculite liner. Jack up, spin tires & warm up moving system. PJSM regarding moving rig. Move rig from pad entrance & spot over well. Level rig. RU handy berm. ND tree cap. NU BOPE &MPD loop. Chain off BOP's. Bring on boiler water. Get stack measurements. Spot metal/food dumpsters. Spot office trailer. RU BOT coil track tools. RU cables to rig. SLB is C/O dodge bearings on the injector. Crew change, walk arounds, and PJSM. Finish berming up around cellar. Make snow pack around base of cellar. Lay out traction mats. NU choke line. PJSM on MU / NU of circulating loop. Reviewed hammer wrench policy. RU circulating loop Continue to NU MPD circulating loop. Fix leaking BOP Ram door seal. Shell test BOP's -Pass Start to RU to Pull BPV with MPU well support, Unable -Don't have appropriate cross overs to attach there lubricator to our lubricator. Test BOPE &MPD equipment as per approved wellplan, AOGCC regs, and PTD #208-165. Recorded all data electronically and on AOGCC test form. Test witness waived by Jeff Jones, AOGCC. 2-3/8" x 3-1/2" VBR's failed -tear apart & rebuild. All passed to 250psV3500psi. Blow down MPD loop. PJSM regarding pulling BPV. Hoist equipment to RF. Steam BPV lubricator & X-over. RU 20' extension, 7"x4" otis connection, BPV lubricator. Stab onto well. P.T. 500psi. Pull 4" 'H' style BPV. RD & LD lubricator & x-over. Hoist whipstock & setting tools to RF, MU & scribe same. Install three pip tags in WS. PU injector & MU stuffing box, ,hook up packoff hoses. Run stabbing winch cable & prep to 'pull coil across. Pull test grapple connection. Remove shipping bar. Pull coil across & stab into the injector. Fill coil Pressure test inner reel valve and packoff rnmea: irzorluua ii:uo:inr~m ~ r BP EXPLORATION Page 2 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 12/28/2008 22:20 - 22:30 0.17 RIGU P WEXIT 22:30 - 23:00 0.50 RIGU P WEXIT 23:00 - 00:00 1.00 RIGU P WEXIT 12/29/2008 00:00 - 01:35 1.58 RIGU N SFAL WEXIT 01:35 - 02:50 I 1.251 RIGU P I WEXIT 02:50 - 03:00 0.17 RIGU P WEXIT 03:00 - 03:30 0.50 RIGU P WEXIT 03:30 - 05:50 2.33 KILL I P I W EXIT 05:50 - 07:30 1.671 KILL P 07:30-08:00( 0.50IWHIP IP (WEXIT 08:00- 12:00 I 4.OOI WHIP IP I (WEXIT 12:00 - 12:40 0.67 WHIP P WEXIT 12:40 - 12:45 0.08 WHIP P WEXIT 12:45 - 12:55 0.17 WHIP P WEXIT 13:00 - 13:10 0.17 WHIP P WEXIT 13:10 - 17:00 3.83 WHIP P WEXIT 17:00 - 19:05 2.08 WHIP P WEXIT 29 55 - 22:05 0.871 STWHIP P I I WEXIT 22:05 - 00:00 1.921 STWHIPI P I I WEXIT 112/30/2008 ~ 00:00 - 09:00 ~ 9.00 ~ STWHIP~ P ~ ~ WEXIT PJSM for cutting coil Cut coil, found Eline ~ 15 ft cut. Make up SLB CTC, Pull test to 35K #'s, Pressure test to 3,500 psi. Unable to circulate coil is frozen. Cut 100 ft of frozen CT. Circulate, Install SLB CTC, and pull test to 35,000 #'s. Pressure test to 3,500 psi -Passed Install night cap and check well. No WHP OC E line -greater than 2,000 M Ohms, and 45 Ohms MU BHI UOC and test -Pass. PJSM on PU of Whipstock BHA, and filling the hole. Line up to fill hole while pumping slack over bung hole. Upper swab was not open when checking well earlier. Open both swabs and had 77 psi WHP. Bull head well, lead in with 5 bbls of McOH. Stab on injector and bull head ~ 5 bpm ~ 1330 psi WHP / 3050 psi CP. Max WHP was 1593 psi before fuming the corner At 247 bbls flow check well -had flow and 10 psi WHP. Shut in and pump more. ~ 305 bbls Flow check. -well is breathing flow and pressure is falling off slowly. S/I well. Cir thru coil & thru kill line to prevent freeze up. C/O w/ day crew. PJSM regarding popping off. Pop off well & place injector over bung hole. Install night cap. Top off hole -full. Open well to closed choke, Opsi. Flow check - no flow. BD kill line. PJSM regarding MU BHA. MU WS &BHI coil track tools. MU to coil. Stab onto well. Power up & test tools. Set counters. Open EDC & circ min rate while RIH w/ WS ~ 60ft/min. Seeing every collar while RIH & 0.1 bpm losses. Log down for tie-in from 13,140ft (-9ft corr. Continue to RIH. Log CCL for collar confirmation. PUH to set depth, 56k up wt. Lost 14bbls on trip in hole. Close EDC & set TOWS high side at 13,460ft. Stack 2k -not moving. POH. PJSM while POH regarding handling BHA. Tag up. Flow check well - no flow. Pop off well. BD BHA w/air & water. LD BHI coil track tools on catwalk & remove HOT. LD WS setting tool. MU window milling BHA. Whipstock setting 'tool looked normal /good. RIH with Window mill BHA. EDC closed and pump min rate. Log for GR tie in from 13,180 ft - 13,222 ft -8 ft correction. RIH, Tag ~ 13,463 ft -Dry. PU to 13,420 ft pumps on to 2.5 bpm ~ 2450 psi RIH, Tag ~ 13,460 ft -Wet. Retag and get 250 psi increase in CP. Paint flag and start time milling opps per BOT hand, well plan, and BP RP. Continue to time mill window per BOT hand, and BP's RP. Had some difficulties with coil stacking, but smooth pressure changes with 200-300 psi of motor work (no abrupt changes in rnniea: irzazwa i rua: i a ww BP EXPLORATION Page 3 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 12/30/2008 00:00 - 09:00 9.00 STWHIP P 09:00 - 10:05 1.08 STWHIP P 10:05 - 11:05 1.00 STWHIP P 11:05 - 14:30 3.42 STWHIP P 14:30 - 15:30 1.00 STWHIP P 15:30 - 16:15 0.75 STWHIP P 16:15 - 20:40 4.42 DRILL N 20:40 - 20:50 0.17 DRILL P 20:50 - 21:40 0:83 DRILL P 21:40 - 00:00 2.33 DRILL P 12/31/2008 00:00 - 00:35 0.58 DRILL P 00:35 - 00:55 I 0.331 DRILL I P 00:55 - 01:05 ~ 0.17 ~ DRILL ~ P 01:05 - 04:00 I 2.92 DRILL I P 04:00 - 07:45 ~ 3.75 ~ DRILL ~ P 07:45 - 09:30 I 1.75 DRILL P W EXIT W EXIT W EXIT W EXIT W EXIT W EXIT SFAL PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 pressures). Drill into formation from 13,470 ft to 13,478 ft. Back ream window, Dry pass through window POOH LD window milling BHA. Swizzle stick the stack Trouble shoot BHA, HOT magnetics won't calibrate. Change out HOT's, new HOT is too clod to function correctly. Steam HOT to warm up hydraulics. Calibrate and test new HOT. PJSM - on PU of build section BHA. PU BHA #3 -build section BHA with 3.1 AKO, and Hycalog 3.75 X 4.25 bi center bit. Had to fight BHA through well head - tightfit. RIH with BHA #3, EDC open. Continue to RIH to 13,180 ft Log for GR tie in from 13,130 ft - 13,180 ft RIH to 13,390 ft to park for depth correction and collar location -8.5 ft correction. Close the EDC and RIH Pass through window clean, tag bottom ~ 13,482.9 ft. Drill build section from 13,477 ft Drilling ~ 13,484 ft Op=2.46/2.48 bpm ~ 3185 psi Den=8.57/8.54 ppg (still displacing BIO out of liner) DH WOB=3210# CT WT=7180# ROP=6 FPH ECD=10.17 ppg DPRESX=564 psi NBI=7.57 deg. ~ 13,530.6 ft 0=2.51/2.15 bpm Losses are healing by 13,535 ft. Drilled to 13,540 ft -Not getting sufficient DLS need 38 deg only getting 31 deg. POOH for new AKO setting. Follow pressure schedule while POOH. 0=2.96/2.68 bpm ~ 62 ft/min (no losses). LD build BHA. Install extra lubricator and make presure deployment measurements. j MU 3.75 deg AKO mtr with Hycalog 4.25" bi-center. Stab coil. Test tools. Get on well. Run in hole. Loud "clunk" from reel. Check out same. Inspect reel. Found several drive plate bolts sheared off. Call for mechanics and replacement bolts. (Change out day for mechanics) Dissassemble reel drive system components. Continue to repair drive system. Stab on well and test run in and out of hole. PRODi 010:45 - 15:15 I 4 50 DRILL N SFAL I PRODi 15:15 - 21:30 ~ 6.25 ~ DRILL ~ N ~ SFAL ~ PROD1 BP EXPLORATION Page 4 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 12/31/2008 15:15 - 21:30 6.25 DRILL N SFAL PROD1 21:30 - 00:00 2.50 DRILL P PROD1 1/1/2009 00:00 - 00:35 0.58 DRILL P PROD1 00:35 - 01:10 0.58 DRILL P PROD1 01:10 - 05:30 ~ 4.33 ~ DRILL ~ P ~ ~ PROD1 05:30 - 08:00 ~ 2.50 ~ DRILL ~ P ~ ~ PROD1 08:00 - 11:00 ~ 3.00 ~ DRILL ~ P ~ ~ PROD1 11:00 - 14:00 ~ 3.00 ~ DRILL ~ P ~ ~ PROD1 14:00 - 17:00 ~ 3.00 ~ DRILL ~ P ~ ~ PROD1 17:00 - 20:25 3.42 DRILL P PROD1 20:25 - 20:45 0.33 DRILL P PROD1 20:45 - 21:00 0.25 DRILL P PROD1 21:00 - 22:40 1.67 DRILL P PROD1 RIH with build section BHA #4 with 3.8 AKO. EDC open and .40 bpm Continue to RIH with BHA #4 Log for GR tie in from 13,130 ft to 13,175 move to 13,390 ft to stop and make correction. -12 ft correction Close EDC, and log to tie in whipstock pip tags. pip tag ~ 13,471.5 ft 43K up WT & 3200 psi FS Tag ~ 13,542 ft Drilling ~ 13,545 ft OP=2.46/2.46 bpm ~ 3340 psi Den=8.59/8.62 ppg ECD=10.71 ppg DH WOB=540 # CT WT=12900 # ROP=.6 fpm / 35 FPH DPRESX=577 psi NBI=25.77 deg and TF=355 deg. INCREASE WOB to 2620 #'s ROP = 74 FPH (short lived) Very slow ROP's ~ 13,561 ft Op=2.51 bpm ~ 3450 psi DH WOB=5300#'s ROP= 0 to 0.1 FPM Drilling improving again ~ 13,586 ft / ROP=50 FPH drilled to 13,609 ft Continue to drill build section from 13,609 ft. 3500 psi fs at 2.48 bpm in/out. 100-200 psi mtr work. DHWOB: 2.5-5k#. IA/OA/PVT: 930 psV138 psi/385 bbls. WHP/BHP/ECD: 55 psV4084 psU10.84 ppg. INC/AZMITF: 90.07/318 deg/70L. Getting 43 deg avg dog leg. Land build in A2 sand at 13,730'. 7287' tvd. W iper trip to above window. Open EDC. Circulate out of hole. Maintain BHP as per pressure schedule. Hold PJSM to review getting off well and laying down BHA. Bleed off well. Flow check same. Pull and LD BHA. Bit 0-0-I. Very green. Hold PJSM to review using pressurized circulation loop. Label valves as per procedure. Circulate across well holding 700 psi whp. Install SLB UTIM coil monitor system. Pressure deploy lateral BHA with res tool & 1.2 deg mtr with new Hycalog raptor 4.25" bit. Run in hole. Follow BHP pressure schedule Log for GR tie in. Park at 13,400 ftmake -14 ft correction. Continue to RIH and wiper to bottom. Tag ~ 13732 ft Drilling ahead ~ 13,740 ft Op=2.5/2.5 bpm ~ 3620 psi & WHP=51 psi Den=8.67/8.67 ppg ECD=10.78 DH WOB=1160#'s CT WT=11,100 #'s DPRESX=761 psi NBI=91.14 deg drill to 13,828 ft - Diff stuck. U BP EXPLORATION Page 5 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 1/1/2009 22:40 - 00:00 1.33 DRILL N STUC PROD1 CP=fell off while drilling. Pipe was stuck when driller tried to PU. Able to circulate with full returns. HOT will orientate. DH WOB show's positive and negative WOB when pushing and pulling. Tried several times to pull free while maintaining circulation for MPD practices, Working higher and higher on the over pulls till 80,000 #'s up weight. -Down on pump to min rate with and without WHP still not free with 80K UP WT -Continue to circulate BU, order crude, and consult with town engineer. -line up to circulate across the top and hold WHP with choke wait 20 min. 1/2/2009 00:00 - 01:15 1.25 DRILL N STUC PROD1 Continue to work stuck pipe: After 20 min circulating across the top -push down -800 #'s CT WT -PU 80,000 #'s -Not seeing the same amount on wt change in DH WOB. Circulate 20 bbls to warm up coil. SD pumps and relax WHP to 0 wait 20 min. 01:15 - 01:25 0.17 DRILL N STUC PROD1 PJSM with crew and LRHOS on pumping crude. 01:25 - 02:30 1.08 DRILL N STUC PROD1 Continue to work pipe after relaxation period. -down 0 #'s CT WT -UP 80,000 #'s -got back the DH WOB indications (-10,000 #'s with SOK up). Circulate to warm coil, PT connections with LRHOS, Test crude - 0.6 psi vapor pressure ~ 100 deg. Load 20 bbls of dead crude into coil. and circulate to the bit 02:30 - 02:55 0.42 DRILL N STUC PROD1 4 bbls crude in open hole section. Wait5min.-dnto0#'s UP75K Wait 5 min -repeat Wait 5 min -Saw DH WOB changing without working pipe. - DN 0# CT WT UP 70,000# pulled FREE. 02:55 - 04:25 1.50 DRILL N STUC PROD1 Circulate out Crude while wiper to window to tie in ~ pip tag. +9 ft correction. RIH to 13,750 ft, MAD pass up to 13,500 ft for GEO while circulating out the crude. ~ 115 bbls out take returns to TT ~ 167 bbls bring it in. lost 52 bbls. 04:25 - 07:00 2.58 DRILL P PROD1 Back on bottom drilling. FS=3318 psi w/ DPRESX=443 psi Drilling ~ 13,834 ft OP=2.53/2.54 bpm X3535 psi &DPRESX=801 psi den=8.69/8.70 ppg ECD=10.85 ppg DH WOB=1260#'s CT WT=12,000#'s ROP=1.5 fpm / 90 FPH Drill to 13,976 ft 07:00 - 07:45 0.75 DRILL P PROD1 Wiper trip above window. Blow down kill line Run in hole. 07:45 - 10:00 2.25 DRILL P PROD1 Drill ahead from 13,976'. 3380 psi fs at 2.52 bpm in/out. 100-200 psi mtr work. dhwob: 2-3k#. ROP: 100 fph +. IA/OA/PVT: 275 psi/118 psi/323 bbls BP EXPLORATION Page 6 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1 /14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To f Hours Task Code NPT ` Phase Description of Operations 1/2/2009 07:45 - 10:00 2.25 DRILL P PROD1 WHP/BHP/ECD: 51 psU4189 psU11.1 ppg indazm/Nd: 86.8 deg/274 deg/7290'. Drill to 14,125'. 10:00 - 10:45 0.75 DRILL P PROD1 Wiper trip to window. 3380 psi fs. 324 bbls pvt. Hole smooth. 10:45 - 13:00 2.25 DRILL P PROD1 Drill from 14,125' to 14,275'. 3450 psi fs at 2.52 bpm in/out. 13:00 - 14:00 1.00 DRILL P PRODi Wiper trip to above window. Log GR tie in. Add 5' correction. Run in hole. 14:00 - 15:30 1.50 DRILL P PROD1 Drill ahead from 14,275' to 14425'. 3550 psi fs at 2.52 bpm iNout. 15:30 - 16:30 1.00 DRILL P PROD1 Make wiper trip to 13,500. Hole smooth in both directions. Begin mud swap to new flo pro. 16:30 - 17:45 1.25 DRILL P PROD1 Drill ahead from 14,425'. 3350 psi fs at 2.48 bpm in/out. Continue mud swap. Drill to 14575 ft 17:45 - 19:35 1.83 DRILL P PROD1 Wiper to window, Hole has was smooth both ways. Tag ~ 14,574 ft 19:35 - 20:50 1.25 DRILL P PROD1 Drill ahead from 14,574 ft. FS = 3150 psi &DPRESX = 418 psi Drilling ®14,600 ft Op=2.54/2.54 bpm ~ 3590 psi &DPRESX=870 psi Den=8.65/8.75 ppg ECD=10.78 ppg DH WOB = 1,630#'s CT WT = 10,300 #'s ROP=2.4 fpm / 140 FPH Drilled to 14,725 ft 20:50 - 23:00 2.17 DRILL P PROD1 Wiper to window Tie in ~ Whipstock RA marker. + 4 ft correction. Tag ~ 14,727 ft. 23:00 - 00:00 1.00 DRILL P PROD1 FS=3130 psi Drill ahead from 14,725 ft Op=2.54/2.54 bpm ~ 3700 psi DH WOB=1900 #'s. ROP=2.4 fpm / 144 FPH Drill to 14,837 ft 1/3/2009 00:00 - 00:40 0.67 DRILL P PROD1 Continue drilling from 14,837 ft midnight depth to 14,875 ft. 00:40 - 02:45 2.08 DRILL P PROD1 Wiper trip to window. -clean Tag ~ 14,872 ft 02:45 - 04:20 1.58 DRILL P PROD1 FS = 3030 psi ~ 2.4 bpm Drilling ~ 14,889 ft Qp=2.4/2.4 bpm ~ 3270 psi DH WOB =1322 #'s CT WT=11,600 #'s ROP=1.1 fpm / 64 FPH Difficult to get started "ratty" conditions, several stalls. Drill to 14,936 ft 04:20 - 04:30 0.17 DRILL P PROD1 Wiper to 14,800 ft. 04:30 - 05:05 0.58 DRILL P PROD1 FS = 3230 psi / 420 psi ~ 2.52 bpm Tag & stall out several more times. 05:05 - 08:30 3.42 DRILL P PROD1 Wiper to 9,000' into cased hole. 3420 psi fs at 2.57 bpm iNout. pvt: 320 bbls. Noticed some cow patties over the shaker during trip. BP EXPLORATION Page 7 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 1/3/2009 08:30 - 08:45 0.25 DRILL P PROD1 Log GR tie in. Add 6' correction. 08:45 - 09:45 1.00 DRILL P PROD1 Continue to run in hole. 09:45 - 12:15 2.50 DRILL P PROD1 Drill ahead from 14,936'. 3450 psi fs at 2.50 bpm in/out. 150-300 psi mtr work. dhwob: 1.5-2.Ok#. BOP: 50-80 fph IA/OA/PVT: 508 psi/270 psV327 bbls. WHP/BHP/ECD: 59 psU4198 psV11.09 ppg. Inc/Azm/TVD: 87.7 deg/294 deg/7292'. Drill to 15,075'. 12:15 - 13:30 1.25 DRILL P PROD1 Wiper trip to window. 3237 psi fs at 2.47 bpm in/out. pvt: 323 bbls. Hole smooth. 13:30 - 15:00 1.50 DRILL P PROD1 Drill ahead to 15,162'. Trouble sliding. 15:00 - 16:30 1.50 DRILL P PROD1 Make early wiper trip to window. 3350 psi fs at 2.53 bpm in/out. pvt: 313 bbls. 16:30 - 17:30 1.00 DRILL P PROD1 Drill ahead from 15,161. Very touchy near btm. Stalling easilly. Not sure if due to mtr or formation. 17:30 - 22:25 4.92 DRILL P PRODi Wiper from bottom, Pull through window open EDC Op=3.26 bpm ~ 3500 psi Perform surface jog - a little extra cuttings across the shaker. PJSM - on pressure undeployment and inspecting coil while POOH 22:25 - 23:30 1.08 DRILL P PROD1 Pop of injector, while maintaining WHP with circulating loop. Run coil down into rat hole for visual inspection. Found several flat spots in coil within first 30 ft. 23:30 - 23:45 0.25 DRILL P PROD1 PJSM on cutting coil with hand cutter and reheading coil. 23:45 - 00:00 0.25 DRILL P PRODi Cut 30 ft of coil. 1/4/2009 00:00 - 02:15 2.25 DRILL P PROD1 Continue to cut coil -Cut 29.5 ft off. Behead coil pull test, pressure test, and OC E-line Stand back injector. 02:15 - 03:45 1.50 DRILL P PROD1 PU lubricator and Pressure undeploy BHA #5. LD BHA. 03:45 - 04:00 0.25 BOPSU P PROD1 Function test BOPE per AOGCC regs, Permit to drill, and well plan while BHI makes up and programs BHA. 04:00 - 04:30 0.50 DRILL P PROD1 MU new lateral BHA with new motor, HOT, and Bit. 04:30 - 04:45 0.25 DRILL P PROD1 PJSM on PU and Pressure deployment of BHA #6. 04:45 - 07:15 2.50 DRILL P PRODi Pressure deploy BHA #6. Test tools. Crew change and PJSM. 07:15 - 10:30 3.25 DRILL P PROD1 Run in hole. Follow pressure schedule. 10:30 - 10:45 0.25 DRILL P PRODi Log GR tie in from 13,150'. Subtract 14' correction. 10:45 - 12:00 1.25 DRILL P PROD1 Continue wiper trip to btm. 12:00 - 15:00 3.00 DRILL P PROD1 Drill ahead from 15161'. 3300 psi fs at 2.51 bpm in/out. 200-300 psi mtr work. 1-2k# dhwob. IA/OA/PVT: 370 psl/107 psi/304 bbls. WHP/BHP/ECD: 70 psU4305 psi/11.36 ppg. Inc/AzmlTvd: 91.3 deg/273 deg/7296'. Tag btm and had two stalls, then begin drilling at 50-60 fph. Note a large volume of cuttings over shaker, well before btms up. Drill to 15,310'. 15:00 - 16:45 1.75 DRILL P PROD1 Make wiper trip to 13,500'. • BP EXPLORATION Page 8 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 -Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 1/4/2009 15:00 - 16:45 1.75 DRILL P PROD1 3560 psi fs at 2.52 bpm in/out. Hole very smooth in both directions. 16:45 - 19:45 3.00 DRILL P PROD1 Drill ahead from 15310'. 3410 psi fs at 2.49 bpm in/out. Drilling rd 15394 tt OP=2.45/2.45 ~ 3650 psi &DPRESX = 660 psi Den=8.88/8.93 ppg ECD = 11.48 ppg DH WOB=2,380 #'s CT WT=8,100 #'s ROP=1.5 fpm / 88 FPH Drill to 15,470 ft 19:45 - 22:35 2.83 DRILL P PROD1 Wiper to window. Tie in at RA with + 9 ft correction. W iper to bottom ~ 30 fpm to help clean out with reduced O in build section of. 0=1.26 ~ 2290 psi in lateral Op=2.51/2.66 bpm ~ 3450 psi. Den=8.90/8.93 ppg. Pumped a 17 bbl high vis pill out of the bit at bottom. TAG (~ 15,475.5 ft 22:35 - 23:15 0.67 DRILL P PROD1 Drill ahead from 15,475 ft. Drilling ~ 15,479 ft Op=2.53/2.53 bpm ~ 3740 psi &DPRESX = 677 psi den=8.92/8.93 ppg ECD=11.59 ppg DH WOB=1190 #'s CT WT=9400 #'s ROP=1.2 fpm / 74 FPH TD called ~ 15,500 ft -BHA wiper to finish getting Hi Vis pill out the bit. 23:15 - 00:00 0.75 DRILL P PRODi Wiper to window 1/5/2009 00:00 - 03:30 3.50 DRILL P PROD1 Wiper trip to window. Tie in at Whipstock RA tag with +2.5 ft correction. Tag bottom ~ 15,501 ft. Wiper to window using new 8.6 ppg FlowPro. Paint flag ~ 13,547 ft EOP. 03:30 - 07:15 3.75 DRILL P PRODi Pull through window, Open EDC, POOH. Follow pressure schedule. Op=3.34/2.94 bpm ~ 3720 psi ~ 70 FPM At surface. Slowly bleed off whp. 07:15 - 08:00 0.75 DRILL P PRODi Open hole BHA on to catwalk. Bit in excellent condition: 1-1-I. 08:00 - 11:45 3.75 CASE P RUNPRD PU liner running equipment. Complete rig up to run liner. MU liner assy (59 jts 2-7/8" slotted/perfed STL & billet) on BHI tools with BTT GS spear and knuckle joint. Get on well. 11:45 - 14:45 3.00 CASE P RUNPRD Run in hole. Follow pressure schedule. Wt check at window: 50k# up, 12k# do wt. 14:45 - 15:30 0.75 CASE P RUNPRD Continue in to open hole. Window smooth. Set down at 14418'. PU (65k#) and run at it a few times. Continue in hole. Tag btm at 15,503'. Come on line at 2.5 bpm at 4200 psi. 42k# up wt. Liner is released. Estimated TOL is 13,695'. 15:30 - 16:00 0.50 CASE P RUNPRD Log GR tie in from 14,910'. Subtract 12' correction. Liner top is on depth. 16:00 - 19:15 3.25 CASE P RUNPRD Pull out of hole. PJSM while POOH • • MPC `v`~ BP EXPLORATION Operations Summary Report Page 9 of 17 Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 1/5/2009 ~ 19:15 - 19:35 ~ 0.33 ~ CASE ~ P 19:35 - 22:30 2.92 CASE P 22:30 - 22:50 0.33 CASE P 22:50 - 23:10 ~ 0.33 ~ CASE ~ P 23:10 - 00:00 ~ 0.83 ~ CASE ~ P 1/6/2009 00:00 - 01:05 1.08 CASE P 01:05 - 04:30 3.42 DRILL P ` ` ~~ ~••,i " ~ tivS 04:30 - 07:45 3.25 DRILL P 07:45 - 08:00 0.25 DRILL P 08:00 - 08:45 0.75 DRILL P 08:45 - 13:45 I 5.001 DRILL ~ P ~1~3:45 - 17:50 I 4.081 DRILL I P 17:50 - 18:25 0.58 DRILL P 18:25 - 21:30 3.08 DRILL P 21:30 - 22:15 I 0.751 DRILL ~ P 22:15 - 00:00 ~ 1.75 ~ DRILL ~ P 1/7/2009 ~ 00:00 - 00:25 ~ 0.42 ~ DRILL ~ P 00:25 - 01:05 I 0.67 DRILL I P 01:05 - 04:40 3.58 DRILL P RUNPRD Continue PJSM on pressure deployment procedure and review PDP with crew. This is the first time for this crew to PD since Kuparuk. RUNPRD Pressure undeploy BHA. RUNPRD Stand back Injector, and deployment lubricator to prep rig floor for maint. RUNPRD PJSM -Nordic for cut and slip of drill line. PJSM -SLB for servicing injector/chain inspection. RUNPRD Nordic -Cut and slip drill line. SLB -Service injector /chain inspection. RUNPRD Continue with SLB & Nordic rig service. PROD2 Pressure deploy build section BHA. Inspect coil by running coil into rat hole. -light wear only. Continue deployment. PROD2 RIH following pressure schedule with BHA#8. PROD2 Log GR tie in.. Subtract 8' correction. PROD2 Run in hole. Tag billet top at 13,693' dry. Trough up at TF 10L. PROD2 Time drill ahead on billet from 13,692'. 3400 psi fs at 2.49 bpm in/out. 100-200 psi mtr work. dhwob: 1-2k#. IA/OA/PVT: 138 psU4 psU209 bbls. whp/bhp/ecd: 51 psV4245 psU11.22 ppg at 7287' tvd. PROD2 Drill ahead 13,725 ft 3440 psi at 2.47 bpm dhwob: 3K rop=26 FOH Drill to 13,847 ft PROD2 Wiper to window. PROD2 Drill ahead from 13,847 ft Drilling ~ 13917 ft Op=2.48/2.48 bpm ~ 3640 psi &DPRESX=611 psi Den=8.92/8.92 ppg ECD=11.4 ppg DH WOB=2910 #'s CT WT=6250 #'s ROP=1.0 fpm / 60 FPH BHA wiper ~ 13,948 ft Drill to 14,000 ft PROD2 Wiper to window RIH was clean. Tag ~ 13,999 ft PROD2 Drill ahead from 13,999 ft. Drilling ~14,010ft Op=2.55/2.55 bpm ~ 3830 psi &DPRESX = 621 psi Den = 8.95/9.05 ppg &ECD = 11.56 ppg DH WOB = 2,220 #'s CT WT = 7,000 #'s ROP = .9 fpm / 56 FPH 14,063 stacking -BHA wiper 64K up wt. Hole getting sticky drilling to 14,100 ft PROD2 Continue to drill ahead from 14,075 ft Drill to 14,100 ft PROD2 Wiper to window -Clean. PROD2 Pull through window and open EDC, POOH following pressure schedule. 0=3.29/2.94 bpm Perform jog near surface. Hold PJSM on pressure undeployment procedures while POOH Printed: 1/26/2009 11:05:18 AM • i BP EXPLORATION Page 10 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 ,Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations ~ 1/7/2009 ~ 04:40 - 07:30 ~ 2.83 ~ DRILL ~ P 07:30 - 10:20 2.831 DRILL 1 P 10:20 - 13:15 2.92 DRILL P 13:15 - 13:30 0.25 DRILL P 13:30 - 14:05 0.58 DRILL P 14:05 - 16:05 I 2.00 DRILL 1 P 16:05 - 17:10 I 1.081 DRILL I P 17:10 - 19:15 2.081 DRILL P 19:15 - 20:05 0.831 DRILL ~ P 20:05 - 20:25 0.33 DRILL P 20:25 - 22:10 1.75 DRILL P 22:10 - 00:00 1.83 DRILL P 11/8/2009 ~ 00:00 - 00:40 ~ 0.67 ~ DRILL ~ P 00:40 - 03:25 1 2.751 DRILL 1 P 03:25 - 03:55 I 0.501 DRILL ~ P 03:55 - 04:45 0.83 DRILL P 04:45 - 06:20 1.58 DRILL P PROD2 Pressure undeploy BHA #8 w/ 750 psi whp Crew change/safety mtg LD BHA. Bit was 1-1-I PROD2 Adjust motor, change bit Safety mtg Pressure deploy BHA #9 Check CT for flat spots, inspect packoff PROD2 RIH w/ BHA #9 (1.2 deg motor, used HYC BC bit, res) circ thru bit 0.40/1300 PROD2 Log tie-in down from 13150', corr -6.5' PROD2 RIH thru window, clean. Circ 1.0/1900 to billet. Pass billet at min rate. Wiper to TD 2.45/3200 w/ a few minor wt loss w/ MW spots PROD2 Drill from 14103' 2.42/3400/908 w/ 200-400 psi dill, 0.80-1.5k wob w/ 11.2 ECD at 88 deg at 100'/hr while swap to fresh mud. Drill to 14250' PROD2 W iper to window. Sticky off bottom. OP's thru 13850-950' shale area. Rest of hole was clean to window. Wiper in hole at 1.0 bpm to just past billet was clean. W iper at 2.5/3200 to TD except reduced rate to 1.0 bpm to get thru shale. Mud swap completed PROD2 Drill from 14244' 2.53/3230/SOL w/ 100-300 psi dill, 0.85-1/6k wob w/ 10.78 ECD at 90 deg (7276' TVD) Drill to 14376 ft PROD2 Come off bottom stop drilling per GEO. Make small wiper trip while waiting for GEO evaluate direction change. Started to drill out top of the sand. PROD2 Drill from 14,376 to 14,400 Back in the sand PROD2 Wiper to window -clean with reduced through the shale and low spots. PROD2 Drill ahead from 14,400 ft Drilling ~ 14445 ft Op=2.50/2.49 bpm ~ 3370 psi &DPRESX=659 Den=8.67/8.76 ppg ECD=10.86 ppg DH WOB=830#'s CT WT=10,400#'s ROP=1.1 fpm / 66 FPH NBI=87.86 deg BHA wiper ®14,479 ft - 68K UP WT. Drill to 14,505 ft PROD2 Continue to drill ahead from 14,505 ft to 14,550 ft Qp=2.5 bpm X3400 psi ROP= 1.2 fpm / 73 FPH PROD2 Wiper to window ~ 2.5 bpm. Slow to 15 fpm from 13,950 ft to 13,850 for shale and 13,650 to 13850 ft for clean out of belly. Pump min rate and pull through window. Open EDC and pump 3.5 bpm ®3100 psi. Wiper to 10,000 ft. PROD2 Log for GR tie in from 13,130 ft to 13,200 ft. RIH to 13,380 ft and make +16 ft correction. Close EDC. PROD2 Continue wiper to bottom. PROD2 FS=3150 ps ~ 2.50 bpm &DPRESX=405 psi rnniea: uzwzuua ii:va:ia „m • BP EXPLORATION Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 11 /8/2009 ~ 04:45 - 06:20 ~ 1.58 ~ D RI LL ~ P 06:20 - 07:45 I 1.42 ~ DRILL I P 07:45 - 10:15 ~ 2.50 ~ DRILL ~ P 10:15 - 11:25 1.17 DRILL P 11:25 - 11:35 0.17 DRILL P 11:35 - 12:15 I 0.671 DRILL I P 12:15 - 14:00 I 1.751 DRILL I P 14:00 - 16:00 2.00 DRILL P 16:00 - 17:10 1.17 DRILL P 17:10 - 18:40 1.50 DRILL P 18:40 - 19:05 0.42 DRILL P 19:05 - 20:15 1.171 DRILL I P 20:15 - 22:10 1.92 DRILL P Start: 12/25/2008 Rig Release: 4/10/2004 Rig Number: 14 Page 11 of 17 Spud Date: 3/19/2004 End: 1 /14/2009 Phase Description of Operations PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 I PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 22:10 - 00:00 ~ 1.83 ~ DRILL ~ N ~ SFAL ~ PROD2 11/9/2009 00 50 - 04 05 I 3.251 DRILL I p I SFAL I PROD2 Tag ~ 14,559 ft and drill ahead. Drilling ~ 14,570 ft OP = 2.52/2.50 bpm G~ 3420 psi &DPRESX = 679 psi Den = 8.76/8.80 ppg &ECD=10.93 ppg DH WOB = 1390 #'s CT WT=11,400 #'s ROP = 1.6 fpm / 95 FPH NBI = 91 deg Drill to 14700' Wiper to window was clean both directions while using slower pulling speeds and reduced pump rates over known shales Drill from 14700' 2.43/3300/908 w/ 100-300 psi dill, 1.0-3.Ok wob w/ 10.88 ECD at 100'/hr at 90 deg. Scrape the top of sand at 14700-720'. Drill to 14850' W iper to window Wiper back in hole at red rate and set down at 13585'. Had to ream 2.1/2800 to 13610' Continue wiper in hole 1.06/2000 past billet, clean. Wiper to TD, clean Drill from 14850' 2.44/3320/90-120L w/ 100-300 psi dill, 1.5-3.Ok wob w/ 11.0 ECD at 90 deg at 7281' TVD at 100'/hr. Drill good sand until 14910' Drill from 14910' at a slower penetration rate of 75'/hr and start to see GR incr to 120 api units. Drill from 14980' 2.44/3300/130L at 10'/hr w/ 3.5-5.5k wob w/ 100-300 psi dill w/ sticky pickups. Drill to 15000' W iper to window was clean. Pull thru window, open EDC Wiper to 10000' circ thru EDC 2.96/3200 Log for GR tie in from 13,100 ft to 13,200 ft RIH to 13,380 ft and make +16 ft correction. Close the EDC while holding WHP with pumps down. Continue wiper to bottom. - No reaming needed /Clean. Having problems with stacking trying to get started tagged ~ 14,492 ft and slowly worked down to 15,002 ft with multiple stalls. Drilling getting better ~ 15,008 ft. Drilling ~ 15,065 ft Op=2.47/2.46 blm ~ 3550 psi &DPRESX=687 psi Den=8.89/8.92 ECD=11.32 ppg DH WOB=1,870 CT WT=7,000# Drilled to 15,068 ft. Wiper to window while repairs are made to pump #1 -swab washed out. Mud pump #1- PT and returned to service X00:00 ~ 13,850 ft. Continue wiper to bottom -Clean. Tag bottom ~ 15,067 ft Again trouble getting started drilling. RIH to fast and motor stalls, RIH to slow and coil stacks out. Drilling ®15,082 ft Op=2.5/2.5 bpm ~ 3650 psi &DPRESX=675 psi Den=8.93/8.96 ppg ECD=11.35 ppg DH WOB = 1320 #'s CT WT=8000 #'s ROP= 1.1 fpm / 67 FPH NBI=87.5 deg Drilled to 15,220 ft • BP EXPLORATION Page 12 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1 /14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From- To Hours Task Code NPT Phase Description of Operations 1/9/2009 04:05 - 05:40 1.58 DRILL P PROD2 Wiper to window, using 2.67 bpm ~ 3570 psi while POOH and slowing down to 15 fpm through shales and in belly (13,700 - 13650 ft). Wiper OOH was clean. Wiper in Tagged ~ 13,565 ft - DD was having problems with keeping tool face due to coiUtool string torque rolling the stops over. Tried several time with different pump rates highest being 1.3 bpm. Pull up through window and jet up while waiting on advise. 05:40 - 09:30 3.83 DRILL N DPRB PROD2 POOH for BHA circ thru open EDC 3.313500 09:30 - 12:30 3.00 DRILL N DPRB PROD2 Pressure undeploy w/ 700 psi LD BHA and remove res tool while SWS RU CT Inspect on horsehead 12:30 - 14:30 2.00 DRILL N DPRB PROD2 WO BHI to get replacement torque gauge from N1 WO SWS to fin RU Inspect BHI MU adjust motor w/ N1 torque gauge 14:30 - 15:30 1.00 DRILL N DPRB PROD2 SWS has CT Inspect RU, but can't get it to communicate. Rig it down, reinstall UTIM Safety mtg re: pressure deploy 15:30 - 16:10 0.67 DRILL N DPRB PROD2 MU BHA into lubricator. Attempt to RIH w/ 2.4 deg motor and can't get in hole Safety mtg re: open hole deploy 16:10 - 17:45 1.58 DRILL N DPRB PROD2 Breakdown BHA in mousehole. Bleed off whp. Open hole deploy BHA RIH w/ CT checking wear on CT ~ 17:45 - 21:10 3.42 DRILL N DPRB PROD2 RIH with BHA #10 following pressure schedule. 21:10 - 21:35 0.42 DRILL N DPRB PROD2 Log for GR tie in ~ 13,100 ft. with - 10 ft correction RIH and park ~ 13,400 ft to make correction. 21:35 - 22:30 0.92 DRILL N DPRB PROD2 SLB is servicing Reel drive plate through bolts. 22:30 - 23:40 1.17 DRILL N DPRB PROD2 Close the EDC, pass through window, and wiper down. 0=0.5 bpm ~ 1729 psi ~ 18 fpm TF=10 L Tag ~ 13,571 ft 0=0.5 bpm ®28 fpm TF=10 LT Tag ~ 13,572 ft with 7000 #'s DH WOB 0=0.5 bpm ~ 14 fpm TF=10 RT Tag ®13571 ft 0=0.25 bpm ~ 1560 psi ~ 15 fpm TF=10 LT Tag ~ 13,572 ft TF = 10 LT ROP=41 fpm Tag ~ 13,572 ft gave a most of the weight back, pushed to 13,578 ft but stacked again. Consult with Greg Sarber: Continue to try with: ROP: Tool Face: All at 0.4 bpm. 50 fpm 10 L 18 fpm 10 L 20 fpm 30 L 40 fpm 10 L 10 fpm 25 R 25 fpm 50 L Still unable to get through. 23:40 - 00:00 0.33 DRILL N DPRB PROD2 POOH following pressure schedule to change out current 2.4 AKO for 3.8 AKO BHA. 1/10/2009 00:00 - 03:05 3.08 DRILL N DPRB PROD2 Continue to POOH following pressure schedule ~ 2.55 bpm. rnmeu: ucwcwa ~ ~.v~. io rari • BP EXPLORATION Page 13 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 1/10/2009 03:05 - 03:15 0.17 DRILL N DPRB PROD2 PJSM while POOH on LD of BHA and CT Inspect of last 100 ft of coil. 03:15 - 05:00 1.75 DRILL N DPRB PROD2 Slowly bleed down WHP to 0 and flow check well. Inspect last 100 ft of coil showing some wear but pass SLB min specs. Pull BHA #10 - LD 2.4 AKO motor and bit. MU BHA #11 -with 3.8 AKO and used 3.75" X 4.5" bit. Stab on 05:00 - 08:10 3.17 DRILL N DPRB PROD2 Slowly bring up WHP to 750 psi for pressure schedule. RIH following pressure schedule 08:10 - 08:30 0.33 DRILL N DPRB PROD2 Log tie-in down from 13150', corr -10'. Close EDC 08:30 - 09:30 1.00 DRILL N DPRB PROD2 RIH circ thru bit 0.5/1300 and went thru window, clean. Set down at 13572' a couple times. Had to wash by at 1.0/2000 and saw wt loss/MW at 13574'. Set down at 13586' a few times. Had to wash by at 1.5/2600 to 13620' and then BHI 'Stops' were on the wrong side. PUH and orient around. Continue RIH at 2.1/2850 5'/min. Start 40 bbl hi-vis pill. Wash by billet 1.0/1800 to 13709' w/ expected wt loss in smaller OD hole. Wash back up hole and by billet at 1.5/2200 w/minor OP. Swap to fresh mud 2.5/3400 09:30 - 10:40 1.17 DRILL N DPRB PROD2 Slow recip 13630-680' while disp wellbore to fresh mud 2.5/3400. Slow wiper up hole to just below window was clean. Pull thru window 10:40 - 14:15 3.58 DRILL N DPRB PROD2 Open EDC. POOH circ thru EDC 2.85/3000 w/ open choke while finish displacing wellbore to fresh mud 14:15 - 15:00 0.75 DRILL P PROD2 LD drilling BHA 15:00 - 17:40 2.67 CASE P RUNPRD RU to run liner Safety mtg re: run liner MU Unique Indexing Guide shoe on a 4 deg bent 2-7/8 STL pup + one solid and 51 slotted jts of 2-7/8" 6.16# L-80 STL liner 17:40 - 18:55 1.25 CASE P RUNPRD MU BTT Deployment Sleeve w/ torque sleeve and GS CTLRT assy MU BHI MWD assy w/ orientor 18:55 - 22:20 3.42 CASE P RUNPRD Slowly bring WHP up for pressure deployment. RIH with liner following pressure schedule. Tagged ~ 14,350 ft (EDC shorted out after working through this shale section got a reading of 16,000 # DH WOB), Continue in hole after approval from town. Tagged again 15,014 ft, and tagged bottom ~ 15,215 ft three times. Space out to leave bottom of liner ~ 15,123 ft. 22:20 - 23:30 1.17 CASE P RUNPRD Brought WHP down to 0 psi. come up on pumps to release liner, unable to pump off of GS conection pumping 1.9 bpm. Working UP and down trying to pump off. 23:30 - 00:00 0.50 CASE N STUC RUNPRD Stuck -Mechanically unable to PU or Down. PU to 90,000#'s up weight, and 19,000 Down. 1/11/2009 00:00 - 02:30 2.50 CASE N STUC RUNPRD Continue to try and free. liner and/or pump off of liner. Pressured up WHP incrementally to 950 psi -losing returns. Circulate High vis sweeps down coil 10bbls HV - 15 FP - 10 HV.... for 3 pills. Continue to work pipe and GS connection from 1.25 bpm to 2.4 bpm with and without WHP. ~ 52 % coil life ~ 13,586 ft. (which is on the reel right now) 02:30 - 11:10 8.67 CASE N STUC RUNPRD Call for 2% KCL Double slick. Nnntea: vtartuua n:u°aar~m • BP EXPLORATION Page 14 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 1/11/2009 02:30 - 11:10 8.67 CASE N STUC RUNPRD Circulating ~ 0.5 bpm with WHP=300 psi losses started ~ 03:00 ~ 0.5/0.4 bpm Reduced WHP to 200 psi & .33/.30 bpm WHP = 7 psi ~ .33/.31 bpm PVT=156 bbls ®03:15 Tried pulling free a few more times while waiting for KCL PVT=153 bbls ~ 05:45 Begin plans for worst case 11:10 - 12:30 1.33 CASE P RUNPRD Displace CT and wellbore above TOL to double slick 2% KCL at 2.72/4200 initial, 3.33/4130 final w/ open choke Nordic crew change 12:30 - 12:40 0.17 CASE P RUNPRD While circ 3.21/4120, stack max wt and liner still wouldn't move down hole. On first attempt while PUH, the GS released from the liner at 49k (normal up wt) leaving the TOL at est 13482' (based on BOL at 15123') 12:40 - 16:00 3.33 CASE P RUNPRD POH circ 1.80/1600 16:00 - 16:30 0.50 CASE P RUNPRD LD BHI MWD assy LD BTT CTLRT assy w/ GS. All tools were recovered intact in 'as-run' condition 16:30 - 22:00 5.50 BOPSU P LOWERI Test BOPE as per approved well plan, AOGCC Regs, and Permit to drill # 208-166. Record all data electronically and on AOGCC test form. 250 psi / 3,500 psi. Test was witnesed by Bob Nobel, AOGCC. All PASSED. 22:00 - 22:10 0.17 FISH P LOWERI PJSM - on pumping slack managment and testing outermost inner reel valve. 22:10 - 22:50 0.67 FISH P LOWERI Take off UOC & LOC inspect for damage. - Eline was pulled out of head and out of anchor sub. After it ripped out it got pumped down through the flow sub. Tested eline -Passed. 22:50 - 23:15 0.42 BOPSU P LOWERI Pressure tested "outer most" inner reel valve and pack off 250 psi / 3500psi: PASS 23:15 - 23:45 0.50 FISH P LOWERi Pump for slack management. 23:45 - 00:00 0.25 FISH P LOWERI PJSM -Cutting coil 1/12/2009 00:00 - 01:55 1.92 FISH P LOWERI Cut coil -Cut 503 ft of coil, found wire ~ 222 ft. Leaves 2.7% slack per SLB calculator. 01:55 - 02:15 0.33 FISH P LOWERI Re head with SLB coil connector. Pressure test to 4,000 psi and pull test 35K 3's. 02:15 - 03:40 1.42 FISH P LOWERI MU BHI UOC & LOC. OC E line -pass. Pressure test - 3,500 psi 03:40 - 03:55 0.25 FISH P LOWERI PJSM - MU & PU BHA 03:55 - 05:15 1.33 FISH P LOWERI MU Whipstock retrieval BHA. BHI DD scribed *** High Side with hook pointed up'** This will require a Low side tool face to engage the whipstock *** PU BHA, stab on injector. 05:15 - 08:20 3.08 FISH P LOWERi RIH with fishing BHA. 08:20 - 08:40 0.33 FISH P LOWERI Log tie-in down from 13150', Corr -2' PVT 140 (lost 3 bbls RIH) 08:40 - 09:10 0.50 FISH P LOWERI RIH w/ LS TF circ KCI thru tool 0.25/40 13440' 49.Ok, 13.2k ~ 14'/min Lost wt at 13464.0' PUH w/ 5k over. Go back down and can't go in hole, good. PUH w/ 10k over on both surface and downhole indicators and held for -1 min when abruptly lost all wt back to neutral. No fluid losses. PUH w/ extra 1.5k, but saw Nnntea: trz~zuua ii:uxinwtn L~ BP EXPLORATION Page 15 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Event Name: REENTER+COMPLETE Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 14 Date From - To Hours Task Code NPT 1/12/2009 08:40 - 09:10 0.50 FISH P 09:10 - 12:30 3.33 FISH P 12:30 - 13:15 0.75 FISH P 13:15 - 16:25 3.17 FISH P 16:25 - 16:45 0.33 FISH P 16:45 - 17:40 0.92 FISH P 17:40 - 21:25 3.75 FISH P 21:25 - 22:00 0.58 FISH P 22:00 - 22:30 0.50 FISH P 22:30 - 22:55 0.42 WHSUR P 22:55 - 23:40 0.75 WHSUR P 23:40 - 00:00 0.33 WHSUR P 1/13/2009 00:00 - 00:15 0.25 WHSUR P 00:15 - 00:50 0.58 WHSUR P 00:50 - 01:15 0.42 WHSUR P 01:15 - 02:05 0.83 WHSUR P 02:05 - 02:50 0.75 WHSUR N SFAL 02:50 - 03:20 0.50 WHSUR N SFAL 03:20 - 04:40 1.33 WHSUR N SFAL 04:40 - 05:00 0.33 WHSUR N SFAL 05:00 - 08:15 3.25 WHSUR N SFAL Spud Date: 3/19/2004 Start: 12/25/2008 End: 1/14/2009 Rig Release: 4/10/2004 Rig Number: 14 Phase Description of Operations LOW ERi no overpull by the window, however string wt remains about 1 k over previous wt chk LOWERI POH circ thru hook 0.90/250 PVT 65 LOWERI Standback MWD assy. Had no recovery. Inspect fishing tool and had no marks MU same assy LOWERI RIH circ thru tool 0.50/280 LOW ERi Log tie-in down from 13130', Corr -2.5' PVT 132 (lost 2 bbls RIH) LOWERI RIH w/ HS TF 1.63/1430 15.5k to 13475' Wash tray 2.6/3500 w/ HS TF w/ two 10'/min passes over 13450-475' Orient to LS -3' below the notch. PUH 50.1 k 0.5/120 and start pulling heavier at 13460.0'. Pull 5k over and open jars. RBIH and stack 7.9k and close jars. PUH and open jars. Straight pull to 90k (13442.0') and see -22.5k on BHI WOB. Go back to neutral and pull to max 90k at 60'/min. See -23.4k wob. RBIH and cock jars. Pull to 73k and let jars hit w/ -17.3k wob. Lost wt back to 46k. PUH w/ 5k over. Park to let element relax. See 0.1 bpm losses PVT 134 LOWERI POH slow 0.52/0.44/120 w/ 2k over LOWERI LD Fishing BHA -Fish on the bank! Whipstock showed good wear at bottom of whipstock face. Packer was missing middle rubber sealing element. LOWERI Blow down tools, RD BHI tools, send out fishing tools and whipstock. POST PU Nozzle for freeze protect. POST RIH with nozzle POST ~ 2500 tt waiting on LRHOS. Truck's have been tied up working for production for spill clean up support. POST PJSM with LRHOS for PT and Pumping diesel. POST Continue to circulate waiting for LRHOS to warm up diesel. POST Spot in LRHOS, Pressure test lines to 4,000 psi. POST Load coil with 35 bbls of diesel, and circulate out. With diesel at the nozzle POOH 1 for 1 to surface. POST Coil tubing parted while POOH during freeze protect opps. We had pumped 22 bbls of diesel out of bit before failure. diesel was released and held inside of secondary containment. Notifications made: Ken Miller, CTD Superintendent ~ 02:10 Chuck Sevcik, Day CO-Man ~ 02:20 Herb Williams, HSE Advisor ~ 02:32 SLB driller notified: Liam Weir, CTD Cell leader Regroup and make a plan forward. POST PJSM on regaining control of coil tubing, Complete SLB Hazard Analysis and Risk Control record. POST Secure coil ~ horse head and near break with tugger line. Cut Eline. Pull coil back to reel secure and cut. POST PJSM -Securing well, Using BOP's to hold/secure coil tubing in well head. Striping injector and cutting coil. Also covered well control contingency plans. POST Set 2-3/8" combi rams (btm) on CT and P-P test w/ 10k. RILDS. BP EXPLORATION Page 16 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1/14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 1/13/2009 05:00 - 08:15 3.25 WHSUR N SFAL POST MPU RU scaffold on ops cab side of floor Develop plan forward. Decide to leave 3' lub above floor Penetrate CT -8' above the floor and allow the CT stub in the injector to drain diesel to bucket 08:15 - 08:30 0.25 WHSUR N POST Safety mtg re: remove CT stub from injector 08:30 - 09:15 0.75 WHSUR N POST Cut off CT -8' from floor w/ hand tubing cutter and lift injector w/blocks. -20' of E-line is at top of stub Move scaffold out of way Run CT down from injector and hand cut in -5' lengths and get -35' Both ends of part look to be a factory weld. CCAT verifies weld w/in 2' of the part 09:15 - 09:30 0.25 WHSUR N POST Safety mtg re: pull CT off reel to floor 09:30 - 12:00 2.50 WHSUR N POST Thread wire rope w/ grapple thru injector and pull to reelhouse. Install internal grapple and PT. Pull CT to floor and thru injector. Dress reel end of CT and insert spoolable dimple connector 12:00 - 12:20 0.33 WHSUR N POST Safety mtg re: finish CT splice 12:20 - 14:00 1.67 WHSUR N POST PU injector to put connector above stub Reset scaffold in front of 7" lub Cut a-line at top of stub. Dress stub to receive spoolable connector Align CT stub. Lower blocks, then stab w/ injector. Dimple up P-P test 10k each way. Set back scaffold Lower injector over CT and MU to lubricator. Open annular, pressure up w/ C-pump. Pull a bind and open combi rams to 40 psi whp showing on gauge 14:00 - 14:30 0.50 WHSUR P POST POH w/ well SI and not pumping, but with CT open to drain to wellbore. WHP bled off rapidly as CT was pulled from the wellbore. Secure tree 14:30 - 15:00 0.50 WHSUR P POST Displace CT w/ 2% KCI and take 10.0 bbls of diesel and 10 bbls of KCI to tiger tank (wellbore should have 25 bbls of diesel FP or -1650') 15:00 - 16:30 1.50 WHSUR P POST Remove checks from nozzle assy. Blow CT back w/ air and recover 5.3 bbls MPU crew RD scaffold and load out 16:30 - 17:00 0.50 WHSUR P POST RU hydraulic cutter. Cut off 110' of CT, but with cool temps and waiting too long, the a-line froze to the inside of the CT MIRU N2 17:00 - 18:00 1.00 WHSUR P POST Safety mtg re: go to plan B Remove hyd cutter. Put injector over bunghole and fill w/ KCI until aline thawed and started moving. Pull out eline until all was recovered 18:00 - 20:20 2.33 WHSUR P POST Spot, RU & cool down N2 unit. Pump inhibitor & methanol into the reel. Blow down reel. Let reel depressurize. 20:20 - 21:30 1.17 WHSUR P POST PJSM regarding cutting coil. Pop off well. RU coil cutter. Cut 835ft of coil & pause. 21:30 - 23:10 1.67 WHSUR P POST PJSM regarding setting BPV. Open master - 4psi & diesel returns. RU GPB BPV lubricator. P.T. w/ diesel to 500psi. Set 4" 'H' BPV. RD BPV lubricator. 23:10 - 00:00 0.83 WHSUR P POST MT pipe shed of coil. MT pits. Continue to cut coil. 1/14/2009 00:00 - 01:30 1.50 WHSUR P POST Continue to cut 1600ft of coil. MT pipe shed. Prep coil for unstabbing. Unstab coil & secure on reel w/shipping bar. Place • • BP EXPLORATION Page 17 of 17 Operations Summary Report Legal Well Name: MPC-43 Common Well Name: MPC-43 Spud Date: 3/19/2004 Event Name: REENTER+COMPLETE Start: 12/25/2008 End: 1./14/2009 Contractor Name: DOYON DRILLING INC. Rig Release: 4/10/2004 Rig Name: DOYON 14 Rig Number: 14 Date From - To Hours Task Code NPT Phase Description of Operations 1/14/2009 00:00 - 01:30 1.50 WHSUR P POST injector over to side of RF & secure injector on RF. 01:30 - 11:00 9.50 BOPSU P POST ND Koomey lines. ND choke & kill lines. RD MPD loop hoses. RD MPD lubricator & stuffing box & prep for long term storage. Continue to MT & clean pits. ND BOP stack &MPD loop. RU tree cap & P.T. w/diesel to 5000psi -pass. Rig released at 11am. rnntea: vtazuua ii:va:iuE+m ~.r by ! BP Alaska ~ s~~~s Baker Hughes INTEQ Survey Report INTEQ Company: BP Amoco Date: 1/15!2009 08:52:42 Page: 1 Time. Field Milne Point . Co-ordinate(NE) Reference:. Well: MPC-43, True North Site: M Pt C Pad Vertical (TVD) Reference: MPC-43: 51.1 Well: MPC-43 Section (VS) Reference: Well (O.OON,O.OOE,33482Azi) L Wellpaths MPC-43L1-01 Survey Calculation Method: Minimum Curvature Db: Oracle. 1 Field: Milne Point North Slope ' UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 is Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre ' Sys Datum: Mean Sea Level Geomagnetic Model : bggm2007 Site: M Pt C Pad TR-13-10 UNITED STATES :North Slope Site Position: Northing: 6027347.71 ft Latitude: 70 29 7.200 N '~ ;From: Map Easting: 558058.04 ft Longitude: 149 31 31.821 W i Position Uncertainty: 0.00 ft Ground Level: 0.00 ft North Reference: Grid Convergence: True 0.45 deg Well: MPC-43 Slot Name: ~ ', Well Position: +N/-S 2278.22 ft Northing: 6029626.64 ft Latitude: 70 29 29.606 N !, +E/-W 127.36 ft Easting : 558167.60 Position Uncertainty: 0.00 ft ft Longitude: 149 31 28.074 W J ! Wellpath: MPC-43L1-01 Drilled From: MPC-43L1 I 500292320061 Tie-on Depth: 13690.11 ft l Current Datum: MPC-43: Height 51.10 ft Above System Datum: Mean Sea Level i Magnetic Data: 10/17!2008 Declination: 22.66 deg Field Strength: 57663 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.70 0.00 0.00 334.82 i _- ~ Survey Program for Definitive Wellpath Date: 1/5/2009 Validated: Yes Version: 4 Actual From Ta Survey Toolcode Tool Name ft ft 81 00 632.00 MPC-43 GYRO (81.00-632.00) (0) CB-GYRO-SS Camera based gyro single shots 653.60 13379.14 MPC-43 (653.60-13744.68) (0) MWD+IFR+MS MWD +IFR + Multi Station 13463.00 13690.11 MWD (13463.00-15501.00) (1) MWD MWD -Standard 13692.00 15220.00 MWD (13692.00-15220.00) MWD MWD -Standard Annotation MD TVD '~ ft ft ~~ ',x13690.11 7338.27 TIP -- ~ _ - - - - _ ----- '.:13692.00 7338.20 KOP 15220.00 7339.18 TD !, Survey: MWD Start Date: 1/7/2009 Company: Baker Hughes INTEQ Engineer: IL Tool: MWD;MWD -Standard Tied-to: From: Definitive Path by ~ BP Alaska '~ Baker Hughes INTEQ Survey Report r~.r BAKER FWGNE$ INTEQ Company: B P Amoco Date 1/1 5/20 09 Tim e:. 08:52:42 Page: Field: M ilne Point Co-ordinate(NE) Reference: Well: MPC-43, True North Site: M Pt C Pad Verti cal (TVD) Reference: MPC-43: 51:1 '~ Well: M PC-43 Secfion (V5) Reference: Well (O.OON,O.OOE,334 .82Azi) Wellpath: M PC-43L1-01 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft 'ft .deg/100ft ~ 13690.11 92.15 316.97 7338.27 7287.17 9821 .43 -3599. 50 6039418 .67 554491.73 10419 .68 0.00 MWD 13692.00 92.22 316.43 7338.20 7287.10 9822 .81 -3600. 79 6039420 .03 554490.42 10421 .48 28.79 MWD 13728.68 100.05 321.50 7334.28 7283.18 9850 .28 -3624. 72 6039447 .32 554466.29 10456 .52 25.38 MWD 13755.16 101.52 327.98 7329.32 7278.22 9871 .50 -3639. 73 6039468 .42 554451.11 10482 .11 24.67 MWD !II 13784.85 101.25 332.56 7323.46 7272.36 9896 .77 -3654. 16 6039493 .57 554436.49 10511 .12 15.15 MWD ', 13811.73 100.89 325.48 7318.29 7267.19 9919 .37 -3667. 73 6039516 .06 554422.74 10537 .34 25.88 I MWD I I 13840.29 96.30 324.92 7314.02 7262.92 9942 .55 -3683. 84 6039539 .12 554406.45 10565 .18 16.19 MWD I 13870.41 89.72 324.71 7312.44 7261.34 9967 .12 -3701. 17 6039563 .55 554388.94 10594 .78 21.86 MWD 13900.74 86.10 320.25 7313.55 7262.45 9991 .15 -3719. 62 6039587 .43 554370.30 10624 .38 18.93 MWD 13930.96 85.98 312.81 7315.64 7264.54 10013 .02 -3740. 34 6039609 .13 554349.40 10652 .98 24.56 MWD 13959.69 86.10 307.01 7317.62 7266.52 10031 .40 -3762. 32 6039627 .34 554327.29 10678. 96 20.14 MWD ~ 13991.57 84.97 300.08 7320.11 7269.01 10048 .95 -3788. 79 6039644 .68 554300.68 10706 .11 21.96 MWD 14020.21 86.96 295.76 7322.13 7271.03 10062 .32 -3814. 03 6039657 .85 554275.34 10728. 95 16.57 MWD 14050.94 88.87 291.03 7323.24 7272.14 10074 .51 -3842. 20 6039669 .82 554247.08 10751. 97 16.59 MWD 14082.58 88.68 286.16 7323.92 7272.82 10084 .60 -3872. 18 6039679 .67 554217.03 10773 .84 15.40 MWD 14109.84 87.57 284.75 7324.81 7273.71 10091 .86 -3898. 43 6039686 .72 554190.72 10791. 58 6.58 MWD 14139.20 88.53 289.23 7325.81 7274.71 10100 .43 -3926. 49 6039695 .07 554162.60 10811. 28 15.60 MWD 14169.01 88.50 294.31 7326.59 7275.49 10111 .48 -3954. 16 6039705 .90 554134.85 10833. 04 17.04 MWD 14198.91 89.72 298.26 7327.05 7275.95 10124 .71 -3980. 95 6039718 .93 554107.95 10856. 42 13.82 MWD 14228.31 89.79 303.50 7327.18 7276.08 10139 .80 -4006. 18 6039733 .81 554082.61 10880. 80 17.82 MWD 14257.16 90.55 302.91 7327.09 7275.99 10155 .60 -4030. 32 6039749 .42 554058.35 10905. 37 3.33 MWD 14290.60 92.09 299.59 7326.32 7275.22 10172 .94 -4058. 89 6039766 .54 554029.64 10933. 22 10.94 MWD 14320.43 92.06 296.86 7325.24 7274.14 10187 .03 -4085. 16 6039780 .43 554003.27 10957. 15 9.15 MWD 14350.71 90.21 294.31 7324.64 7273.54 10200 .11 -4112. 46 6039793 .28 553975.87 10980. 60 10.40 MWD 14380.55 89.20 291.51 7324.79 7273.69 10211 .72 -4139. 94 6039804 .68 553948.30 11002. 80 9.97 MWD 14410.41 87.91 288.52 7325.55 7274.45 10221 .94 -4167. 98 6039814 .68 553920.18 11023. 97 10.90 MWD 14440.74 88.44 285.35 7326.51 7275.41 10230 .77 -4196. 98 6039823 .28 553891.12 11044. 30 10.59 MWD 14470.38 88.19 282.58 7327.38 7276.28 10237 .92 -4225. 73 6039830 .20 553862.32 11063. 00 9.38 MWD 14501.12 90.12 279.48 7327.84 7276.74 10243 .79 -4255. 89 6039835 .84 553832.11 11081. 15 11.88 MWD ~~ 14530.99 90.49 277.08 7327.68 7276.58 10248 .10 -4285. 45 6039839 .91 553802.53 11097. 62 8.13 MWD 14560.65 91.23 274.95 7327.23 7276.13 10251 .20 -4314. 94 6039842 .79 553773.02 11112. 97 7.60 MWD 14590.93 90.18 279.25 7326.86 7275.76 10254 .95 -4344. 98 6039846 .30 553742.95 11129. 14 14.62 MWD 14619.72 89.75 283.63 7326.88 7275.78 10260 .65 -4373. 19 6039851 .78 553714.70 11146. 30 15.29 MWD 14649.76 89.23 288.23 7327.15 7276.05 10268 .90 -4402. 07 6039859 .80 553685.76 11166. 05 15.41 MWD 14680.38 89.45 293.62 7327.50 7276.40 10279 .83 -4430. 66 6039870 .51 553657.09 11188. 10 17.62 MWD 14712.05 89.54 298.36 7327.78 7276.68 10293 .70 -4459. 11 6039884 .15 553628.53 11212. 76 14.97 MWD 14741.83 87.85 302.09 7328.46 7277.36 10308 .68 -4484. 83 6039898 .94 553602.70 11237. 27 13.75 MWD 14772.65 87.08 306.26 7329.82 7278.72 10325 .98 -4510. 30 6039916 .03 553577.10 11263. 75 13.75 MWD 14802.40 88.46 309.54 7330.98 7279.88 10344 .23 -4533. 75 6039934 .10 553553.50 11290. 25 11.95 MWD 14831.36 88.93 306.27 7331.64 7280.54 10362 .02 -4556. 60 6039951 .70 553530.53 11316. 06 11.40 MWD 14861.08 89.69 302.92 7332.00 7280.90 10378 .89 -4581. 05 6039968 .38 553505.94 11341. 73 11.56 MWD 14892.19 88.87 299.99 7332.39 7281.29 10395 .12 -4607. 59 6039984 .40 553479.28 11367. 71 9.78 MWD 14920.65 89.63 296.45 7332.76 7281.66 10408 .57 -4632. 66 6039997 .66 553454.11 11390. 55 12.72 MWD 14950.28 89.66 293.17 7332.94 7281.84 10421 .01 -4659. 55 6040009 .88 553427.12 11413. 24 11.07 MWD 14981.52 87.76 290.37 7333.65 7282.55 10432 .59 -4688. 55 6040021 .23 553398.03 11436. 06 10.83 MWD 15012.56 87.27 287.93 7334.99 7283.89 10442 .76 -4717. 84 6040031 .17 553368.67 .11457. 73 8.01 MWD 15047.07 87.88 283.64 7336.45 7285.35 10452 .14 -4751. 01 6040040 .29 553335.43 11480. 32 12.55 MV1ID 15077.85 87.24 280.81 7337.76 7286.66 10458 .65 -4781. 07 6040046 .56 553305.33 11499. 00 9.42 MWD 15117.87 87.97 276.31 7339.44 7288.34 10464 .60 -4820. 59 6040052 .20 553265.76 11521. 20 11.38 MWD 15154.10 90.61 273.84 7339.89 7288.79 10467 .80 -4856. 67 6040055 .12 553229.66 11539. 45 9.98 MWD ~ ~ 15220.00 90.61 -__ _-- 273.84 __ 7339.18 7288.08 10472 .21 -4922. 42 6040059 .02 _ _ 553163.88 ___ 11571. 41 0.00 MWD _ ----- I Tree: 2-9/16" - 5M FM~ Wellhead: 11" x 11" 5M Gen 5, w 2-7/8" FMC Tbg. Hgr., 2-7/8" EUE Top & Btm, 2.5" CIW BPV Profile MPU iC~43 L1-01 ~ Orig. DF Elev. = 51.10' (Doyon 14) I Orig.GL Elev. = 16.40' (Doyon 14) 20" 91.1 #ppf, H-40 BTC 112' 10 3/4", 45.5 ppf, L-80 Btrc. ~ 9,363` Camco 2-7/8"x 1' KBMM 139' I Camco 2-7/8"x 1' KBMM 12,483` I 2-7/8" 6.5#, L-80, EUE Srd 2.441" =Drift ID Cap = .0058 7-5/8" 29.7 ppf, L-80, Btc-mod ( drift ID = 6.875", cap. = 0.0459 bpf ) 4.5" 12.6 #!ft , IBT ,mod. ( drift id = 3.958" ,cap = .0152 bpf ) Baker Tie back slv. 12,735' Baker 7-5/8"x 5-1/2" "ZXP" liner pkr. 12,746' 7-5/8", 29.7# L-80 btc shoe 12,883` i Perforation Summary Ref IOg: Tied Jewelry log into MWD 4/07/04 Size SPF Interval (TVD) 3-3/8" 12 13,566' - 13,576' 7,297' - 7,307' 3-3/8" 12 13,580' - 13,600' 7,311' - 7,331' 2-7/8" 6 13,619' - 13,628' 7,350' - 7,359' PF-3412 HMX Charges / 12spf 3.3/8" I .69" hole 2 HES RTTS slip segments DATE I REV.BY I COMMENTS XN Nipple (2.813 packing ID) 12 625' (2.75 no-go ID) , WeIILift Discharge Gauge Unit 12,638` Centrilift Tandem ESP 12,644` 68-G31 SXD MVP 66-P31 SXD GaS Separator GRSFTX AR 12,673' Tandem Seal Assembly 12,678` Centrilift KMH Motor 692` 12 228 HP, 2305 v / 60 amp , WeIILift MGU Sensor 12,711 ` ~ CTD Window - 13460 - 13480 / 2-7/8" L-80 Slotted Liner 13482 - 15123 ~``".... ..._... J _i =ji Q7/ 2-7/8" SIoUPerf Liner 13696 - 15501 o 0 J 4.5" Landing collar (PBTD) 13,727' 4.5" 12.6#, L-80 float shoe 13,815` 05/25/05 MDO Converted to ESP Nabors 4-es 01/14109 Nordic 2 CTD Laterals 2/10/09 REH Re-complete w/ ESP -Nabors 3S MILNE POINT UNIT WELL C-43L1 iT~'L1-01 API NO: 50-029-23200-00 ~/%~ BAKER NUGNES ~~~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: January 30, 2009 Please find enclosed directional survey data for the following wells: MPB-22APB1 MPB-22A MPC-43L1 MPC-43L1-Ol oL ~ g -1 to ~ Enclosed for each well is: tea copies of directional survey reports 1 ea 3.5" floppy diskette containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: DATE: ~~ C~ ~ State of Alaska AOGCC Cc: State of Alaska, AOGCC ~,.c~~-L~4o ~ ~ 3"'° ~ tl•_ ~ ~ L~ 1-~ ~ ~ ~~ ~ ~ -~ ~ i ~. ~ ~ , -.i EWE J .. - 1 i..a ~ ALASS-A OIL A1~TD GAS COI~TSERQATI011T COMZ-IISSIOI~T John McMullen Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Milne Point Unit, Kuparuk River Oil Pool, MPC-43L 1-01 BP Exploration Alaska Inc. Permit No: 208-166 Surface Location: 1344' FSL, 2290' FEL, SEC. 10, T13N, R10E, UM Bottomhole Location: 1400' FSL, 2206' FEL, SEC. 33, T14N, R10E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well MPU C-43, Permit No 204-039, API 5D-029-23200-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative .Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. ..When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607- (pager). Sincerely, Daniel T. Seamount, Jr. S ~ Chair DATED this _ day of November, 2008 cc: Department of Fish & Game, Habitat Section vv/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMM ION PERMIT TO DRILL 20 AAC 25.005 ~l//" UC I ~ 20[8 6~ ~~-~ ~~~~ ~~ ~~ ~~ ~.~~r?~.e. GOn~r~~~siOr G 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is propose • or`. ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: MPC-43L1-01 3. Address: P.O. Box 196612, Anchors e, Alaska 99519-6612 6. Proposed Depth: MD 15550' TVD 7271'ss 12. Field /Pool(s): Milne Point Unit / Kuparuk River 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 047434 & 355017 ' Sands - FEL, SEC. 10, T13N, R10E, UM 1344 FSL, 2290 Top of Productive Horizon: T14N R10E UM 498' FSL 509' FEL SEC. 33 8. Land Use Permit: 13. Approximate Spud Date: December 1, 2008 , , , , , Total Depth: 1400' FSL, 2206' FEL, SEC. 33, T14N, R10E, UM 9. Acres in Property: 3440 14. Distance to Nearest Property: 5,590' 4b. Location of Well (State Base Plane Coordinates): Surface: x-558168 ~ y-6029627 'Zone-ASP4 10. KB Elevation (Height above GL): 51.1' • feet 15. Distance to Nearest well Within Pool: 1,090' 16. Deviated Wells: Kickoff Depth: 13600 feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2139 Surface: 1439 in P m: 'fi i n T- i - m n i f m n r Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1/ " -7/ " 6. T 7' 71 1 7 7' n m I in 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured): 13817' 7 47' None 13700' 7431' 13701' Casing Length ize Cement Volume MD TVD Conductor /Structural i Surface /4" 1 Ar i II 1 47 ' Intermediate 1 7- 1 1 ' Liner 4-1 I 1 7 5' - 1 6 '- 7 45' Perforation Depth MD (ft): 13566' - 13628' Perforation Depth TVD (ft): 7298' - 7359' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Gres Sarber, 564-4330 Printed Name Joh cMullen Title En ineerin Team Leader Prepared By NameMumber Si nature Phone 564-4711 Date r'Q ~~ U~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill N e : ~~ l6~ API Number: 50-029-23200-61-00 Permit Approv I See cover letter for r it n Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me~tha/ne, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes L7 No Mud Log Req'd: ^ Y,es IJ No HZS Measures: [Yes ^ No Directional Survey Req'd: Yes ^ No Other: ~~C RSA a~~ ~5~ .~ ~Y(' ~~ ~ APPROVED BY THE COMMISSION G ~ !~ Date COMMISSIONER Form 10-401 Revised 12/2005 ~ R ! G' ~ A L Sut mD ~ ~~I cat 5.- - - ~ ~~ t. J by BPXA Milne Point C-43L1, C-43L1-01 CTD Sidetracks October 21, 2008 To: Tom Maunder Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Greg Sarber CTD Engineer Date: October 21, 2008 Re: MPC-43L1, MPC-43L1-01 Permits to Drill Permit to Drill approval is requested for 2 sidetrack laterals added to well MPC-43. History -Milne Point C-43 is currently ashut-in Kuparuk "A" sand producer. The well was drilled March 2004, and given a frac stimulation in May 2004 with 213.5K# Carbolite. The well was initially completed with a jet pump. It was converted to an ESP completion in 2005. The ESP recently failed in Oct. 2008. The parent well perforations were still making a small volume of productive oil at -50% WC prior to the ESP failing. Reason for PTD Request -Your approval is requested to add two coil tubing drilled sidetrack laterals from the MPC-43 producer. This well is ideally suited to test an unswept section of the Kuparuk A2 and A3 sands to the Northwest of the parent well bottom hole location. The scope of this project includes pulling the existing ESP completion and running a 4-1/2" tubing work string, drilling two lateral legs completed with slotted liners landed outside the window; pulling the CST whipstock to regain access to the perforations in the parent wellbore, and then pulling the work string and running a new ESP completion. Pulling and running the ESP completions will be performed by a dedicated workover rig. The coil sidetrack will be drilled by Nordic rig 2, and this PTD application covers only the work to be completed by Nordic 2 during the sidetrack operations. Technique -This well will be a Milne Point Kuparuk "A" sand well. BP does have some experience drilling Kuparuk sands with coiled tubing in the KRU using Nordic 2. Conoco Phillips uses a form of Managed Pressure Drilling where they use a less than kill weight fluid to drill with. This is done because of the large range in bottom hole pressures found in the KRU, how close BHP's are to frac pressure, and the need to maintain a constant bottom hole pressure to maintain shale stability. That complete system was considered for this well. The full MPD system used in the KRU was rejected due to the low bottom hole pressure on well MPC-43. A form of this technique will however be used. This is due to a desire to maintain a constant BHP to maintain shale stability. A dedicated drilling superchoke will be installed on the rig, and used to trap pressure on the wellhead when the rig pumps are shut down. This will maintain a constant bottom hole pressure on the wellbore at all times. However, there is 1 major difference between this technique, and the standard MPD well drilled in the KRU. Because this well has a bottom hole pressure of about -6 Ib equivalent, at no time will the reservoir be under balanced. The drilling fluid used will be 8.6 ppg Flo-pro solids free mud. The rig pits will be full at all times with a greater than kill weight fluid. There is no need to have a separate tankage of kill weight fluid on location as is found on KRU MPD wells. The way this technique will be practiced is that the well will be loaded with drilling mud (KW F). The first drilling BHA will be run in the hole. Once the BHA is on bottom drilling the bottom hole pressure including ECD will be recorded. At times when pumps need to be shut down, the drilling super choke will be used to trap and maintain a constant bottom hole pressure equal to the pumps on BHP. At no time will the reservoir be in an under balanced condition. No formation fluids will enter the wellbore at any time. This discussion is provided should the question be raised about reason for the extra superchoke that will be located on the rig for this well. Timing -This well was just added to the drilling schedule for Nordic rig 2. The estimated start time for Nordic 2 to begin a CTD sidetrack on this well is December 1, 2008. CTD Sidetrack Summary Pre-CTD Rig Work performed by Workover Rig: (Began on November 10, 2008) 1. MIT OA 2. Prep pad. 3. Circ out freeze protect from the IA, Load and kill well. 4. MIRU Workover rig. Test ROPE 5. ND 2-9/16" tree, NU BOPE. Test same 6. Pu112-7/8" L-80 tubing with ESP completion. 7. Run 4-1/2" L-80 tubing completion (See Schematic). 8. Set TWC 9. ND BOPE, NU 4-1/16" 5M psi tree. Test same. 10. RDMO workover rig. ~~ ~~~ ~~ - 11. Install temporary scaffolding around well. 12. RU slickline. Pull ball and rod and RHC sleeve. rn~ A ~ ~/ 13. Run dummy whipstock to 13,500'. ~ , ~"\ j 14. Eline will set retrievable 4-1/2" monobore whipstock with top at 13,457'. 15. Install a BPV 16. Remove temporary scaffolding, level pad if needed. 17. Drill mousehole extension. Rig Sidetrack Operations: (Scheduled to begin on December 1, 2008 using Nordic rig 2) 1. MIRU Nordic Rig 2 2. NU 7-1/16" CT Drilling BOPE and test. 3. Pull BPV. 4. Mill 3.80" window at 13,457'. 5. Drill build/turn/lateral section of L1 with 3.75" x 4.125" bicenter bit, and drill L1 lateral to 15,585'. 7. Sidetrack from the L1 lateral off of the deployment sleeve/whipstock at 13,620' with a 3.75" bit. 8. Drill build/turn/lateral section of L1-01 with 3.75" x 4.125" bicenter bit, and drill L1-01 lateral to 15,500'. 9. Run a 2-7/8" L-80 slotted liner string with an L-80 deployment sleeve with top outside window at 13,480'. 10. Recover Baker monobore whipstock at 13,457'. 11. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. ; ~~ S ~~~~ 12. RDMO Nordic 2. Post-CTD Rig Work: 1. MIRU workover rig. 2. ND 4-1/16" tree. NU BOPE and test. 3. Pull 4-1/2" work string. 4. Run 2-7/8" ESP completion. 5. ND BOPE, NU 2-9/16" tree. 6. RDMO well with workover rig. 7. Re-install wellhouse and FL's. 8. Pull BPV. 9. POP Well ~~~~'~~ V'~ ~ ~ _ ` , ~ " ~ Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new 8.6 ppg Flo Pro for drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 3.75" x 4.125" (bi-center bits used) Casing Program: Uncemented Slotted liner • 2-7/8", L-80 6.16# STL3,620' and -15,585' and for MPC-43L1 lat~ • 2-7/8", L-80 6.16# STL 13,480' and -15,550' and for MPC-43L1-01 lateral Existing casing/tubina Information 10-3/4", L-80 45.4#, Burst 5210, Collapse 2480 psi 7-5/8", L-80 29.7#, Burst 6890, Collapse 4790 psi 4-1/2", L-8012.6#, Burst 8430, Collapse 7500 psi Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle on the L1 lateral is 94.23 deg ~ 14,594'. The maximum planned hole angle of the L1-01 lateral is 95.21 deg ~ 14,498'. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property line 5,590'.. • Distance to nearest well within pool -1,090' from MPL-16. Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section on both laterals. Hazards • The maximum H2S concentration on the parent MPC-43A well is 5 ppm recorded on 10/10/2008. • The maximum H2S concentration on the pad is on well MPC-03 at 9.5 ppm on 10/10-2008. • Hole stability is a potential problem. Previous experience drilling in KRU indicates that the shales in the Kuparuk interval can be degraded. To counter this, a constant bottom hole pressure will be used to drill the well. This will be done by using a dedicated drilling choke to trap pressure on the formation when pumps are down. • Fluid loss is not expected to be a problem on this well. Traditionally this has not been a problem in the KRU CTD drilling projects. • The TD's are not challenging from a weight on bit standpoint. No special measures will be needed to reach TD on these laterals. Reservoir Pressure • The reservoir pressure on MPC-43A was last recorded at 2,139 psi at 7,000' TVDSS in July 2008. (5.87 ppg equivalent) • Max. expected surface pressure with gas (0.10 psi/ft) to surface is 1,439 psi. Greg Sarber CTD Engineer CC: Well File Sondra Stewmanrl-errie Hubble 2-9118` - 5M'I"MC ~ A p ~ L~ ~ J [frig. 1~ El~v = 51.10' {Dayan 14~ 91' x 11` SM FMC !~~ tjrig.t~iL Efev = 1BA(T ~Y~ 1A} Gen 5, w 2-718"FMC Tbg. Hgr., I~fiBG Top i~ Btrn, 25' GiW PpV ProHe 2U' 91,11f ppf. FFAO BTC 112' 10 314'. 45.5 ppf, l.-60 $trc. KUP ~ 300` Max. hole angle = 98 deg. hole angle thru' pens = 7 deg. 2 718` 6,3 ppf, L-80 8rd aua tba ( drift Id = 2.347' cap = Af1592 bpf ~ 7~i18' 29.7 ppf, L-80, f'Jtoalwd drift !D = (3.875', cap, = 0.0459 bpf ? 4.5' 12.51tMt ,18fi ,mad. drift id = 3.858` ,cap = OA125 apf ? tlakar Tie brck aK 12.735'. Baker i-5~9hr ;r112"`DCP' finer pkv. 12.748'. 7f.~J8', 29,7# 4.90 tltic shoe Perioratlon Sunrmnary ttef log ~n.a ~.,r.ry w,a 1R1o rrrMa r~ao+ sr~- ;~ lire l'~1 3..916" t2 19,68' • 19,576` '; 7,293" .?,30T 3.4l8* 12 13,58Ci • 13,84i~ 7,317' .7,331" 2.Ztfi 6 13,819' • 13.628' 7,350'. 7,959' PF3412 Y~1XCtmgr:l 12srer3,~15` 1,+59* tdr 2-il8k 1' ILi~lt3 hF~ 3 ' t:amo3 2ala-,c 1' fiBiiL3 µ2 12.482' XN f~ippia {2813 parictrg fD) 12.,$35` tzrs~o+a) Cent~ft 109AGC 1700 ESA ~ 2 gq$• 191GC 8200 iii 5'61 GF~IATAlt4: F Tandem 2 ~' 1 Gas Separator GR9F7x AR Et6 . Tandem SeaiAasambfy 12 674` n nsx3N rra~ an . CenfriiftlCMli Mohr fi87' 12 152 FlP. 2325 v / 4{3 amp , Punpmaie Sensor wi fns 12,701' Fishy E-flna 3' x 3,5' roNsr+gsm lost 4urln9 RY1t0 an 4s~SJD5. Toa ~ 13741', 4.5' larxfing ooWr{PBTO} 13,72T' 4,5" 12.134!. L.80 !ba# shoe 13,$15' QATE i~V. BY OONriEtirr'$ J414B104 MDQ Dried and oorrrpiarDed Doyon 14 04128404 MDf] Addfracperls 05F213105 MDR} Converted b ESP IJabors 4~s 14gLNf POINT UH1T WELL O~#3 API NO: 5D-0fi9~200.00 Tree:2-9/16"-SM~fC MPU C-43L1 & L1~1 Wellhead: 11" x 11" SM FMC Gen 5, w 2-7/8" FMC Tbg. Hgr., Proposed CTD Laterals UPTBG Top 8 Btm, 2.5" CIW BPV Profile Orig. DF Elev. = 51.10' !;Doyon 14) Orig.GL Elev. = 16.40' (Doyon 14) 20" 91.1# ppf, H-40 BTC 112' 10 3/4", 45.5 ppf, L-80 Btrc. ~ 9,363' 0 7-518" 29.7 ppf, L-80, Btc-mod ( drift ID = 6.875", cap. = 0.0459 bpf ) 4.5" 12.6 #lft ,IBT ,mod. ( drift id = 3.958" ,cap = 0.0125 bpf ) 4112" 12.6#, L-80 IBT Work String Installed pre CTO Rg arrival Baker Tie back slv. 12,735' Baker 7-5/8"x 5-1/2" "27CP" liner pkr. 12,746' 7-518", 29.7# L-80 btc shoe 12,883' 134$T ~-'R" w r,;F- retr ievea Pertoration Summary Ref log: Tlsa ~ewery 109 Into MJYD uoyroa Size SPF Interval (TVD) 3-318" 12 13,566' • 13,576' 7,29T' -7,30i' 3-318' 12 13.580' - 13,600' 7,311' - 7.331 2-?/9" 0 13,fi?9 - 13,528 7,35D' -?,359 PF-3412 HMX Charges 112spf 3 3/8` ! .69' hole -2,000', 4-112" HES X Nipple, 3.813' ID 12,650', 4-112" HES X Nipple, 3.813' ID --12,550', 7-518' x 4-1/2" BKR S-3 Packer 12,650', 4-1/2" HES X Nippk:, 3.813' ID 5fler ~~- --- MPC-43L1 ---i Z-718" L-80 Sbtted liner 1N00-15585 U ~ 4.5" Landing collar (PBTD) 13,727` 4.5" 12.6#, L-80 float shoe 13,815' DATE REV BY COMMENTS 04/09/04 MDO Drilled and completed Doyon 14 04/26/04 MDO Add frac parts 05!25!05 MDO Converted to ESP Nabors 4-es 10/15/08 MSE Proposed CTD Laterals MILNE POINT UNIT WELL C-03L1 & L1-01 API NO: 50-029-23200-00 b ~ BP Alaska ~ ~ P Baker Hughes INTEQ Planning Report uvTE Q Company: BP Amoco Date. 10/20/2008. Tiroe. 09:56:32 Page: 1 'Field: Milne Point Co-ordinate(NE) Reference: Well: MPC-43, True North Site: M PfCPad Vertical (TVD) Reference: MPC-43: 51.1 ~ We1L• ` MPC-43 Section (VS) Reference: Well (O.OON,O.OOE,325.OOAzi) ~ Wegpath; Plan 3, MPC-43L1-01 Survey Calculation Method: Minimum Curvature Db: Sybase i - _ _ -- _ - - -- - - Field: Milne Point - - -- - - North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: M Pt C Pad TR-13-10 UNITED STATES :North Slope Site Position: Northing: 6027347.71 ft Latitude: 70 29 7.200 N From: Map Easting: 558058.04 ft Longitude: 149 31 31.821 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.45 deg Well: MPC-43 Slot Name: ~ Well Position: +N/-S 2278.22 ft Northing: 6029626.64 ft Latitude: 70 29 29.606 N +E/-W 127.36 ft Easting : 558167.60 ft Longitude: 149 31 28.074 W Position Uncertainty: 0.00 ft '~ Wellpath: Plan 3, MPC-43L1-01 Drilled From: Plan 3, MPC-43L1 500292320061 Tie-on Depth: 13600.00 ft Current Datum: MPC-43: Height 51.10 ft Above System Datum: Mean Sea Level Magnetic Data: 10/17/2008 Declination: 22.66 deg Field Strength: 57663 nT Mag Dip Angle: 80.96 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.70 0.00 0.00 325.00 Plan: Plan #3 Date Composed: 10/17/2008 l copy Mary's plan 3 Version: 2 Principal: Yes Tied-to: From: Definitive Path I Targets Map Map <---- Latitude ----> <--- Longitude ---> Name Description TVD +N/-S +E/-W Northing. Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ' ft ft ft MPC-43 Fault 51. 10 11329.81 -5754.70 6040910.00 552325. 00 -Polygon 1 51. 10 11329.81 -5754.70 6040910.00 552325. 00 -Polygon 2 51. 10 10545.31 -2635.45 6040150.00 555450. 00 MPC-43L1-01 Polygon 51 .10 10866.77 -5373.28 6040450.00 552710. 00 -Polygon 1 51 .10 10866.77 -5373.28 6040450.00 552710 .00 -Polygon 2 51 .10 10538.51 -5600.87 6040120.00 552485 .00 -Polygon 3 51 .10 9444.98 -3889.21 6039040.00 554205 .00 -Polygon 4 51 .10 9769.25 -3151.58 6039370.00 554940 .00 MPC-43L1-01 Target 4 7316. 10 10372.87 -4883. 08 6039960.00 553204 .00 MPC-43L1-01 Target 5 7321. 10 10607.29 -5188. 28 6040192.00 552897 .00 MPC-43L1-01 Target3 7326. 10 10204.63 -4471. 34 6039795.00 553617 .00 MPC-43L1-01 Target 1 7341.10 9868.80 -3730.88 6039465.00 554360.00 MPC-43L1-01 Target 2 7351.10 10037.04 -4142.61 6039630.00 553947.00 Annotation MD TVD ft ft 13600.00 7308.18 TIP / KOP 13650.00 7330.41 2 13722.71 7342.84 End of 30 Deg/100' DLS 70 31 21.010 N 149 34 17.680 W 70 31 21.010 N 149 34 17.680 W 70 31 13.312 N 149 32 45.739 W 70 31 16.458 N 149 34 6.428 W 70 31 16.458 N 149 34 6.428 W 70 31 13.228 N 149 34 13.128 W 70 31 2.485 N 149 33 22.670 W 70 31 5.677 N 149 33 0.939 W 70 31 11.604 N 149 33 51.972 W 70 31 13.908 N 149 34 0.971 W 70 31 9.952 N 149 33 39.836 W 70 31 6.654 N 149 33 18.011 W 70 31 8.306 N 149 33 30.146 W b ~ BP Alaska P Baker Hughes INTEQ Planning Report '~tl~_.~ i~ a ~~ (Company; BP Amoco Date. 10/20/2008. 'Pimc 09:56 32 Pal ~ Field: Milne Point Co-ordinate(NE) Reference:. Well: MPC-43, True North Site: M Pt G.Pad Vertical (TVD) Reference: MPC-43: 51.1 Well: MPC-43 Sectioin (VS) Reference:. Well (O.OON,O.OOE,325.OOAzi) `Wellpath: - Plan 3, MPC-43L1-01 Survey Calculation Method: Minimum Curvature Db Annotation - - r MD TVD - I ft ft 13822.71 7341.84 4 13922.71 7343.22 5 14182.71 7350.64 6 14227.71 7351.21 7 14277.71 7351.19 8 14347.71 7349.41 9 14497.71 7338.74 10 14637.71 7326.91 11 ~ 14737.71 7320.19 12 14777.71 7318.56 13 14927.71 7316.60 14 15077.71 7316.37 15 15227.71 7316.96 16 15327.71 7318.26 17 ~ 15550.00 0.00 TD Plan Section Information MI) Incl ff deg 13600.00 58.08 13650.00 69.19 13722.71 91.00 13822.71 90.15 13922.71 88.28 14182.71 88.53 14227.71 90.02 14277.71 90.02 14347.71 92.89 14497.71 .95.21 14637.71 94.41 14737.71 93.28 14777.71 91.39 14927.71 90.09 15077.71 90.09 15227.71 89.46 15327.71 89.06 15550.00 89.16 Survey Azim __ TVD deg ft 322.38 7308.18 333.67 7330.41 333.67 7342.84 321.70 7341.84 309.84 7343.22 278.63 7350.64 273.44 7351.21 279.44 7351.19 287.34 7349.41 305.24 7338.74 288.39 7326.91 300.37 7320.19 295.95 7318.56 277.99 7316.60 295.99 7316.37 278.01 7316.96 290.00 7318.26 316.68 7321.77 +N/-S +E/-W ft ft 9762.72 -3546.95 9800.68 -3570.41 9864.49 -3601.99 9948.84 -3655.35 10020.36 -3724.97 10125.73 -3959.04 10130.46 -4003.77 10136.06 -4053.43 10152.25 -4121.44 10218.21 -4255.05 10280.90 -4379.11 10322.02 -4469.81 10340.88 -4505.04 10384.47 -4647.91 10428.14 -4790.77 10471.81 -4933.62 10495.96 -5030.46 10617.01 -5214.48 DLS Build. deg/100ft deg/100ft 0.00 0.00 30.00 22.21 30.00 30.00 12.00 -0.85 12.00 -1.87 12.00 0.10 12.00 3.32 12.00 0.00 12.00 4.09 12.00 1.55 12.00 -0.57 12.00 -1.13 12.00 -4.71 12.00 -0.87 12.00 0.00 12.00 -0.41 12.00 -0.40 12.00 0.05 Tum TFO leg/100ft - deg 0.00 0.00 22.58 45.00 0.00 0.00 11.97 266.00 11.86 261.00 12.00 270.00 11.53 286.00 12.00 90.00 11.29 70.00 11.93 82.00 12.03 268.00 11.97 95.00 11.05 247.00 11.97 266.00 12.00 90.00 11.99 268.00 11.99 92.00 12.00 90.00 Target 2 it I i Sybase MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS 1'FO Too ft deg deg ft ft ft ft ft deg/100ft ft deg 13600.00 58.08 322.38 7257.08 9762.72 -3546 .95 6039360. 37 554544.73 0.00 10031. 60 0.00 MWD 13615.73 61.48 326.17 7265.00 9773.75 -3554 .88 6039371. 34 554536.72 30.00 10045. 18 45.00 MPC- 13625.00 63.52 328.30 7269.28 9780.66 -3559 .33 6039378. 22 554532.21 30.00 10053. 40 43.09 MWD 13626.62 63.89 328.66 7270.00 9781.90 -3560 .09 6039379. 45 554531.44 30.00 10054. 85 42.11 MPC- 13638.55 66.57 331.26 7275.00 9791.28 -3565 .51 6039388. 79 554525.95 30.00 10065. 64 41.95 MPC- 13650.00 69.19 333. 67 7279.31 9800.68 -3570. 41 6039398.15 554520.98 30.00 10076. 15 40.85 MWD 13675.00 76.69 333. 67 7286.64 9822. 09 -3581. 00 6039419.47 554510.22 30.00 10099. 76 0.00 MWD 13700.00 84.19 333. 67 7290.79 9844. 17 -3591. 93 6039441.46 554499.12 30.00 10124. 12 360.00 MWD 13722.71 91.00 333. 67 7291.74 9864. 49 -3601. 99 6039461.70 554488.90 30.00 10146. 53 0.00 MWD 13725.00 90.98 333. 39 7291.71 9866. 54 -3603. 01 6039463.75 554487.87 12.00 10148. 80 266.00 MWD 13750.00 90.77 330. 40 7291.32 9888. 59 -3614. 78 6039485.70 554475.92 12.00 10173. 61 266.00 MWD 13775.00 90.56 327. 41 7291.03 9909. 99 -3627. 69 6039507.00 554462.85 12.00 10198. 55 265.95 MWD 13800.00 90.34 324. 42 7290.84 9930. 69 -3641. 70 6039527.59 554448.68 12.00 10223. 54 265.91 MWD 13822.71 90.15 321. 70 7290.74 9948. 84 -3655. 35 6039545.63 554434.89 12.00 10246. 24 265.89 MWD 13825.00 90.10 321. 43 7290.73 9950. 64 -3656. 77 6039547.41 554433.45 12.00 10248. 52 261.00 MWD 13850.00 89.63 318. 46 7290.79 9969. 77 -3672. 86 6039566.41 554417.22 12.00 10273. 42 261.00 MWD 13875.00 89.17 315. 50 7291.05 9988. 04 -3689. 91 6039584.55 554400.02 12.00 10298. 17 261.01 MWD 13900.00 88.70 312.54 7291.52 10005.41 -3707. 89 6039601.78 554381.92 12.00 10322. 71 261.04 MWD b ~ BP Alaska ~ ~ P Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 10/20/2008 Tin-~ 09:56 32 Page: 3 Field; ` Milne Point Co-ordinate(NE) Reference: Well: MPC-43, True North Site: M Pt C Pad Vertical (TVD) Reference. MPC-43. 51.1 Well: MPC-43 Section (VS) Reference: ~ .Well (O.OON,O.OOE,325.OOAzi) Wellpath; Plan 3,,MPC-43L1 01 Survey Calculation Method: Minimum Curvature Db: Sybase ~ Survey MI) Incl Azim SS TVD N/S E/W ft deg deg ft ft ft 13922.71 88.28 309.84 7292.12 10020.36 -3724.97 13925.00 88.28 309.57 7292.19 10021.82 -3726.73 13950.00 88.28 306.57 7292.94 10037.23 -3746.40 13975.00 88.29 303.56 7293.68 10051.58 -3766.85 14000.00 88.30 300.56 7294.43 10064.85 -3788.03 14025.00 88.32. 297.56 7295.16 10076.98 -3809.87 14050.00 88.34 294.56 7295.89 10087.96 -3832.31 14075.00 88.37 291.56 7296.61 10097.75 -3855.30 14100.00 88.40 288.56 7297.32 10106.32 -3878.77 14125.00 88.43 285.56 7298.01 10113.65 -3902.66 14150.00 88.47 282.56 7298.68 10119.72 -3926.90 14175.00 88.51 279.56 7299.34 10124.51 -3951.43 14182.71 88.53 278.63 7299.54 10125.73 -3959.04 14200.00 89.10 276.64 7299.90 10128.02 -3976.17 14225.00 89.93 273.75 7300.11 10130.29 -4001.06 14227.71 90.02 273.44 7300.11 10130.46 -4003.77 14250.00 90.02 276.11 7300.10 10132.31 -4025.98 14275.00 90.02 279.11 7300.09 10135.62 -4050.76 14277.71 90.02 279.44 7300.09 10136.06 -4053.43 14300.00 90.94 281.95 7299.90 10140.20 -4075.33 14325.00 91.96 284.77 7299.27 10145.97 -4099.64 14347.71 92.89 287.34 7298.31 10152.25 -4121.44 14350.00 92.92 287.61 7298.20 10152.94 -4123.63 14375.00 93.34 290.59 7296.83 10161.10 -4147.21 14400.00 93.74 293.57 7295.29 10170.48 -4170.33 14425.00 94.13 296.55 7293.57 10181.04 -4192.92 14450.00 94.52 299.53 7291.69 10192.76 -4214.92 14475.00 94.89 302.52 7289.64 10205.60 -4236.27 14497.71 95.21 305.24 7287.64 10218.21 -4255.05 14500.00 95.20 304.96 7287.43 10219.52 -4256.92 14525.00 95.09 301.95 7285.19 10233.25 -4277.69 14550.00 94.96 298.94 7283.00 10245.86 -4299.16 14575.00 94.82 295.93 7280.87 10257.34 -4321.26 14600.00 94.67 292.93 7278.80 10267.64 -4343.94 14625.00 94.50 289.92 7276.80 10276.74 -4367.14 14637.71 94.41 288.39 7275.81 10280.90 -4379.11 14650.00 94.28 289.87 7274.88 10284.92 -4390.68 14675.00 94.01 292.86 7273.07 10294.00 -4413.90 14700.00 93.72 295.86 7271.39 10304.29 -4436.62 14725.00 93.43 298.85 7269.83 10315.75 -4458.78 14737.71 93.28 300.37 7269.09 10322.02 -4469.81 14750.00 92.70 299.01 7268.44 10328.10 -4480.47 14775.00 91.52 296.25 7267.52 10339.68 -4502.61 14777.71 91.39 295.95 7267.46 10340.88 -4505.04 14800.00 91.20 293.28 7266.95 10350.16 -4525.30 14825.00 90.99 290.29 7266.47 10359.43 -4548.50 14850.00 90.77 287.30 7266.09 10367.48 -4572.17 14875.00 90.56 284.30 7265.80 10374.29 -4596.22 14900.00 90.34 281.31 7265.60 10379.83 -4620.59 14925.00 90.11 278.32 7265.50 10384.09 -4645.22 14927.71 90.09 277.99 7265.50 10384.47 -4647.91 14950.00 90.09 280.67 7265.46 10388.09 -4669.90 6039616.59 6039618.04 6039633.29 6039647.48 6039660.58 6039672.54 6039683.34 6039692.95 6039701.34 6039708.48 6039714.36 6039718.96 6039720.11 6039722.28 6039724.34 6039724.49 6039726.17 6039729.29 6039729.71 6039733.67 6039739.26 6039745.36 6039746.03 6039754.01 6039763.21 6039773.59 6039785.14 6039797.81 6039810.27 6039811.57 6039825.13 6039837.57 6039848.88 6039859.00 6039867.92 6039871.98 6039875.91 6039884.81 6039894.92 6039906.21 6039912.39 6039918.38 6039929.79 6039930.96 6039940.09 6039949.18 6039957.04 6039963.66 6039969.01 6039973.08 6039973.44 6039976.88 MapE DLS VS, TFO Too ft deg/100ft ft deg 554364.72 12.00 10344.75 261.09 MWD1 554362.95 12.00 10346.96 270.00 MWD 554343.16 12.00 10370.86 270.01 MWD 554322.60 12.00 10394.35 270.10 MWD ~ 554301.32 12.00 10417.36 270.19 MWD ~ 554279.39 12.00 10439.83 270.28 MWD 554256.86 12.00 10461.70 270.37 MWD. 554233.80 12.00 10482.90 270.45 MWD 554210.26 12.00 10503.38 270.54 MWD 554186.32 12.00 10523.09 270.62 MWD 554162.03 12.00 10541.97 270.71 MWD ~ 554137.47 12.00 10559.96 270.79 MWD 554129.86 12.00 10565.32 270.87 MWD 554112.71 12.00 10577.03 286.00 MWD 554087.80 12.00 10593.16 286.04 MWD 554085.09 12.00 10594.85 286.07 MWD 554062.87 12.00 10609.11 90.00 MWD 554038.07 12.00 10626.04 90.00 MWD 554035.39 12.00 10627.93 90.00 MWD 554013.46 12.00 10643.88 70.00 MWD 553989.11 12.00 10662.55 70.02 MWD 553967.26 12.00 10680.20 70.09 MWD 553965.07 12.00 10682.01 82.00 MWD 553941.43 12.00 10702.23 82.01 MWD 553918.24 12.00 10723.17 82.18 MW D I, 553895.57 12.00 10744.78 82.36 MWD ~ 553873.48 12.00 10767.00 82.56 MWD! 553852.03 12.00 10789.76 82.79 MWD 553833.16 12.00 10810.86 83.03 MWD 553831.28 12.00 10813.01 268.00 MWD 553810.40 12.00 10836.17 267.97 MWD I 553788.84 12.00 10858.81 267.71 MWD 553766.65 12.00 10880.89 267.44 MWD 553743.89 12.00 10902.34 267.18 MW D 553720.63 12.00 10923.10 266.94 MWD 553708.63 12.00 10933.37 266.70 MWD 553697.02 12.00 10943.31 95.00 MWD 553673.73 12.00 10964.06 95.11 MWD 553650.93 12.00 10985.52 95.33 MWD 553628.69 12.00 11007.62 95.53 MWD 553617.61 12.00 11019.08 95.72 MWD 553606.90 12.00 11030.18 247.00 MWD 553584.68 12.00 11052.36 246.93 MWD 553582.24 12.00 11054.73 246.83 MWD 553561.91 12.00 11073.96 266.00 MWD ~ 553538.63 12.00 11094.86 265.94 MWD'; 553514.91 12.00 11115.03 265.88 MWD 553490.81 12.00 11134.40 265.84 MWD ~ 553466.40 12.00 11152.92 265.80 MWD 553441.74 12.00 11170.54 265.78 MWD 553439.05 12.00 11172.39 265.77 MWD 553417.03 12.00 11187.97 90.00 MWD MapN <ft b ~ BP Alaska P Baker Hu hes INTEQ Plannin Re ort g g P Company; BP AmOCO -- Field:` Milne Point Site: M Pt C Pad Well: MPC-43 Wellpath: Plan 3, MPC-43L1-0L Survey MD Inc1 Azim SS TVD N/S ft deg deg ft ft 14975.00 90.09 283.67 7265.42 10393.36 15000.00 90.09 286.67 7265.39 10399.90 15025.00 90.09 289.67 7265.35 10407.69 15050.00 90.09 292.67 7265.31 10416.72 15075.00 90.09 295.67 7265.27 10426.96 15077.71 90.09 295.99 7265.27 10428.14 15100.00 89.99 293.32 7265.25 10437.44 15125.00 89.89 290.32 7265.28 10446.73 15150.00 89.78 287.33 7265.35 10454.79 15175.00 89.68 284.33 7265.47 10461.61 15200.00 89.58 281.33 7265.63 10467.16 15225.00 89.47 278.33 7265.84 10471.43 15227.71 89.46 278.01 7265.86 10471.81 15250.00 89.37 280.68 7266.09 10475.43 15275.00 89.27 283.68 7266.39 10480.70 15300.00 89.17 286.68 7266.73 10487.25 15325.00 89.07 289.67 7267.11 10495.04 15327.71 89.06 290.00 7267.16 10495.96 15350.00 89.06 292.67 7267.52 10504.07 15375.00 89.06 295.68 7267.93 10514.31 15400.00 89.07 298.68 7268.34 10525.72 15425.00 89.08 301.68 7268.74 10538.28 15450.00 89.09 304.68 7269.14 10551.96 15475.00 89.10 307.68 7269.54 10566.71 15500.00 89.12 310.68 7269.92 10582.50 15525.00 89.14 313.68 7270.30 10599.29 15550.00 89.16 316.68 7270.67 10617.01 -4694. 33 6039981.96 553392.56 12.00 11206.30 90.00 MWD -4718. 46 6039988.31 553368.38 12.00 11225.50 90.01 MWD, -4742. 21 6039995.92 553344.58 12.00 11245.50 90.01 MWD -4765. 52 6040004.76 553321.20 12.00 11266.27 90.02 MWD -4788. 33 6040014.82 553298.31 12.00 11287.73 90.02 MWD -4790. 77 6040015.98 553295.87 12.00 11290.10 90.03 MWD; -4811. 02 6040025.12 553275.54 12.00 11309.34 268.00 MWD' -4834. 23 6040034.23 553252.27 12.00 11330.26 268.00 MWD -4857. 89 6040042.11 553228.54 12.00 11350.44 268.00 MWD -4881. 94 6040048.73 553204.45 12.00 11369.81 268.01 MWD -4906. 31 6040054.09 553180.03 12.00 11388.34 268.02 MWD -4930. 94 6040058.17 553155.37 12.00 11405.96 268.04 MWD -4933. 62 6040058.53 553152.69 12.00 11407.82 268.07 MWD -4955. 61 6040061.98 553130.67 12.00 11423.39 92.00 MWD -4980. 05 6040067.06 553106.20 12.00 11441.73 91.97 MWD -5004. 17 6040073.41 553082.03 12.00 11460.92 91.94 MWD -5027. 92 6040081.02 553058.22 12.00 11480.93 91.90 MWD ~ -5030. 46 6040081.92 553055.67 12.00 11483.14 91.85 MWD -5051. 22 6040089.87 553034.85 12.00 11501.69 90.00 MWD I -5074. 02 6040099.92 553011.97 12.00 11523.16 89.96 MWD -5096. 26 6040111.16 552989.65 12.00 11545.26 89.91 MWD -5117. 87 6040123.55 552967.95 12.00 11567.94 89.86 MWD -5138. 79 6040137.07 552946.92 12.00 11591.15 89.81 MWD -5158. 96 6040151.66 552926.63 12.00 11614.80 89.76 MWD -5178. 34 6040167.29 552907.14 12.00 11638.85 89.71 MWD -5196. 86 6040183.93 552888.49 12.00 11663.22 89.67 MWD -5214. 48 6040201.52 552870.73 12.00 11687.85 89.62 MWD , FJW ft ------ i MapN MapE DLS ' VS TFO 'fool ft f[ deg/100ft ft deg Date: .10/20/2008 Time: 09:56:32 Page: 4 Co-ordinate(NE) Reference: Well: MPC-43, True North Vertical (TVD) Reference: MPC-43: 51.1 Section (VS) Reference: Well (O.OON,O.OOE,325.OOAzi) Survey Calculation Methgd: Minimum Curvature Db: Sybase [W3/OL1 .00'SZf ie uoNaag Isa31+aA Tr- ~f~ ~ ~T-~-I~~T I ~ -_ TI =~ [ulM0031 (tliee3/l-I3eaM ea geld ~~ LP LlEP7dW 'E ueld (L EY~dW '£ueld)EPJdW - IEP7dW1EY~dW - ON3'J3l ~un~ wnwwiW oa Deis alga waaa rw,~:aaW ePidaW s 1300'0'N00'01 IS ~ atllSN ~ayaa5 e~al aaS ueary'.wals/.5 '.a atl (OA:liniya~ 41,aN arvl'sFOdW?4ua0 clam aau aiaa (31N1 ala~ip,oa0 NOI1YWtlOiNi 30N3tlii3tl OtYC 00'0 00'0 .00'Sit 0 4 Oae dome .~i.o •l~a aaL»rW LbL'L4 i~+IP+e ~&e~~ 00'009CL wall LItPaJW'[uelA VLWalIlaM ways LPLICPadN [~ N e130 MlYf1l3W e~sel`d d8 H 2 W ~'e Z P . M n a e m 0 a a u T Plan: Plan p3 (MPC-03/Plan 3, MPC-03L1) M~~,~M~~,1 r~~ ~1Mx os M Created By: BP Date: 10/202008 BP Alaska ~:~Mr,c«~ Rzimalhs ro Trae NaMi Magretr NMh. 22.66° Ghecketl: Date: IMPeD Pl A BAI~R 9 a=IM~~; 1~l61lS b p 5vength. 5]663nIT oa IM°ccel DID 9ie 80.96' Gnnrar2 in~nrmalan rD MPC ;D1 Date 10/1]IZ006 Bin Mimeelson P500];2~]0060] oe lM°c-u5! p Mo0et. 6ggmZ00] P~ _iz iMPOwq TGC~ can l9o])w1-as]D TM an YD. 1]]79.1! rl E-mail. dllmchaekon~inten com r~e~ MPO~] to IMPc-iaj FB A.1.W .. 51.10Y r9 IS jMPC-r51 9 aMle ~N/i ~FlN~ Fn ITVD ]9aA0 0.00 0.00 31.70 REFERENCE INFORMATION Cc~ n! Ca-ordinate (NIE) Reference: Well CenUe: MPC-03, True NoM zs jrMaPc-lanwl VerUCal(ND) Reference: MPC-03:61.10 '1~imPc'~EI Section (VS) Reference: Slot- (O.OON,O.OOE) ~ ac zlal c zI Meas red Dep(h Reference: MPC-03. 51.10 __ nPMx- AI u Calculation MClhotl Minimum Curvature 25 jvieM 1d1uel 61MPC-1~6L11 9ae7rox 0a7uu 1a jMeG26Ltvdrl ].e YO rk ~r 7w .wa .afY 01p nr~ vase n.9Y 2F ~Mtt &ij ze IMPF~IIP '~ z 1 ]S MPC-]91 ' Jo IMPC~D) Jt !MPcJl~rl J11 B3~ Ji (MacJ~l Lrl - en IMPLlA nw vienl ', - e (KUOaru~, Tesll IPM1n MCC-BeMe~i', 1f lseas.DO bat ]u.w 7]1r.u t0ea9ar a]ms] tsa0 s0.o0 119asaD - ~sellnl llP~en MnG-aruii ix. !! Sn IMPC-ua5n naia•.!, i-011M~jPMn Mac ursal i o~(((MPL-Dint L] (MP -011 - «((MPL-031 w1 ((( ~5! -0)(MPL~r yk y i rT T~f ~ .:~ y ,, TT- 12000-r T ~ ~L r._ 1~ r r 7 r L'. -... _ i ~ " ~_ _ t' 1780 ~ -. ~ MPLr18 MPL•76 ~, ' _ i _ '__, ~ _ .- ~_ ~.~ \ 11600-j rt T 1 _.. 7300 ( l I.. .L._ 1-._ -. .Ty 1_ 11400-;^_ - - '7500 1:1 1. rt - 1 _ 7260 ~+ _ a 11200 ._ -..y- fi900 _- _.... , 7200 ...... ~ ~ ~ ] MPL39 MP429 ._ .T ~- r -; a T-. r _:.. -.. . 11000 ~ - '... 7500 ~ 1 '~ ~ trr-' _ 6000 8900 _ .-, + ~'. y +-r 1- - MPG43 Plan 3 MPC-03L1-01 f/ ~ "- ~ -: -+ . , - t '~ losoo `'` 7200 - , 'i 6a 6600 ': Q . r -. Plan 3 MPG43L7 .~ ,-:. . ~ - - ~..:- .. ~.. v - .T. ti 10400 `{-.__ + _ r -F- ^ ~. + 6900 .. 1 ~ j .. ~ ~ 1 "_. -r 1 ~/ _ saoo + i+-T •- / 'r-r-_. MPG-431MPG43 .fit- _'1. ~ 9800 ~ .. /~ _ ~,. `~_ MPL-78A MP476A :- 6700 i 7200 1 - i ~ L - i ,~ T /J i T 7200 ~1~ / T ~ 0 .. 9600 \6900 _.. _~ r -r 6600 i 9400- 6\ ~ ~ ~ ~-1 T"7 -{ Y T _ 6300 ~ 1 _, 6000 --. ' ~. :{ I ~_ \ -- { F Y \ ~. ... ~ ~ ~ i _ ._ ~ L 1_._i i- ~ .. ,.' -. ..... - - 6000 MPC-27 (MPC-Y7) ~.-. 9200 ~ 5700 ~_ - ~ - ', ~~ r ( ~ ~,. 7600 /100 _ -. 90DP~. I 5100 j ,-.-'.1 - _ _ \s700 ~ ~ - . 7200 I 1 I ~ l 880 1. _ t -F .- 0 __ _ _ .. \ .._ 690 ~ .. ... \` i., 6600 8600 - - /5100`5700 - - - `` 5700 ~1 -- r -8200 -8000 -7800 -7600 -7400 -7200 -7000 -6800 -6600 X400 -6200 -6000 -5800 -5600 -5400 -6200 -5000 -0800 -0600 -4400 -0200 -0000 -3800 -3600 -3400 -3200 -3000 -2800 -2fi00 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -600 F00 -000 West(-)/East(+) [~OOft/in] WELL DETAILS ATTI-COLLI51O~' SFTTI~GS CONPAVI' DETAILS Name ~N/-S -E/-W AuMing Fasting Latiwdc Longitude Slot InleTolation MethodMD Interval: SO q) HP Amato Depth Range From: 136/X1.00 To: 15530.00 MPC412218.22 I?].}! 6029fi26.64 SSRI6].60 ]0'29'39.6061: 149'31 ^_R 0]4W N/A :Maximum Range: I]SI.S} Refererxe~Plan: Plan P} Calculaumt MxOtod'. Minimum Cwvalun Fnor Sy.icm: ISCN'SA Scan Me~haJ: Tra. Cylinder Nonh F,.o. sa,raex: Elir~ie,l-easmp Wawnp McWatl' Ruln Huse) SURVEY PROGRAM Depth Fm DWIh TO SurvxylPlan 136W.U0 1555000 PU~med: Plan `3 V2 -193 "- - 153 -188 '~ -iRR -160 } '- -" IRO i 1 -163 i / ~~ ~ ~ . _ __ 165 ---ISR ~ i r _.---- _.._..__.._ ISb -~ -ISO ~ / ~ .w i -la3 ~ ~ ~ _ ~, lu, --I15 /~ _ Iii -to8 / _ L2h -I IJ / ~ / / _ 1 k3 -105 31 / ~ i03 ~A / ya _~ 50 -R3 ~ ~ / ~. e. _ _ -73 " ~ ~ / /-~ I .5 /. ~A ~ / r;~ / ~~ fib -60 / ~ ~ / - o.. -45 y f~ »~ -38 .,c -3U s0. -'} - -IS _R -0 ~ °, I ~ / _15 L j I ~fi I I -3e 1 ZaKt~ `+~ l I -43 r ~~ ISI\R ~ J / / f / -33 \ I g~ / l ~ -58 ~ ~'~/A t e s 1 ~'~h~ / l lI / ~„ '.,, sr~~ ° ~ ~ , ~ , ]~ j / ~PC. ~~ X113908 ~~; ~~ ~~ / -83 9j & / ~ <~~ i J qhT ~.--~ ~ ~ o ~ / ~' {{,, (([[Q~ / ~R 24t \\\AliBl V~+6F'.R-eg J by? ~ , /~ / / ~ {/~0 -105 ~ ~ _ ~`) -113 p : ~ \ ~ /~ ..12U n ~~?~ ` y/~ // n '~ > -128 < ~' ~ ~ -J-"~E -~ -135 \ `-s-c- 2 3 1 -I30 ~.Q 51 -163 ~ N~~ "/ -Ill ~ I"3 Slil ~U -IRO \ ; ..... -18R -193 ~_ ___ _ Tm.unmp Cyllna« A,;~mm~ RFO ~ nz0 (dxg] ~: e~mve m centre sepamhon ~ I smin~ W FLLPATH DETAILS Twl Plan }, iMpC-0ILI-0I 30029'_3'0061 MN'D Parrnl N'xllpath: Plan 3, MPC-43L1 Tix m~ ND: 136W IXI Rip: Nordic 2 RxE Datum MPC-03: 31.IOfi V.Se«ion Origin Origin Suning Avgle -.~'/-S +E/-W Frmn TVD 325.00° O.UII O.W 34.]U LEGEND - MPC-25 (MPC-25), Major Risk - MPC-43 (MPC-43), Major Risk MPC-43 (Plan 3, MPC-43L1), Major Risk ' MPL-16 (MPL-16), Major Risk Plan 3, MPC-43Ll-Ol Plan #3 c1.~aIPUy BP °_t. -..?I.o ~. Oa 11o._Wv by 'INTEL __ WR.IX t t3a2 w 3naw 3431 lao!1.6 MR UII • ;:~"`'~ b , BP Alaska ~ BF j6H~ r"rt~~ p Anticollision Report iNTEQ Company: BP Amoco Field: Milne Point Reference Site: M Pt'C Pad Reference Well: MPC-43 Reference Wellpath; Plan 3, MPC-43L1-01 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 13600.00 to 15550.00 ft Maximum Radius: 1751.53 ft Survey Program for Definitive Wellpath Date: 10/17/2008 Validated: No Planned From To Survey ft ft 81.00 632.00 653.60 13379.14 13379.14 13600.00 13600.00 15550.00 Casing Points -- - MD'. TVD ft ft' 15550.00 7321.77 MPC-43 GYRO (81 00-632.00) (0) MPC-43 (653.60-13744.68) (0) Planned: Plan #3 V3 (1) Planned: Plan #3 V2 .Diameter Hole Size Name in in 3.500 4.125 3.50" Date: 10/20/2008 Time: 13:49:05 Page: l Co-ordinate(NE) Reference: Well:: MPC-43, True North Vertical (TVD) Reference: MPC-4.3;51.1 Db: Oracle ----... Reference: Principal Plan 8~ PLANNED PROGRAM Error Model: ISCWSA Ellipse Scan Method: Trav Cylinder North Error Surface: Ellipse + Casing Version: 0 Toolcode Tool Name CB-GYRO-SS Camera based gyro single MWD+IFR+MS MWD +IFR + Multi Station MWD MWD -Standard MWD MWD -Standard Summary <---------------- Offaet Wellpath --_________~__> Refereuce Offset Ctr-Ctr No-Go Allowable Site Well Wellpath MD MD Distance Area Deviation Warning ~ ft ft ft ft ft M Pt C Pad MPC-25 MPC 25 V1 M Pt C Pad MPC-43 MPC-43 V7 13600.45 13650.00 M Pt C Pad MPC-43 Plan 3, MPC-43L1 VO PI 13649.03 13650.00 M Pt L Pad MPL-16 MPL-16 V2 15182.21 15225.00 Site: M Pt C Pad Well: MPC-43 Wellpath: MPC-43 V7 Reference MD TVD ft ft Offset Semi-Major Axis > Ctr-Ctr No-Go Allowable MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistance Area beviatiou ft ft ft ft deg deg.: in ft ft ft 13600.45 7308.42 13650.00 7381.14 55.39 55.92 145.87 183.38 4.500 85.73 125.75 -40.02 F 13611.30 7313.95 13675.00 7405.99 55.94 56.42 146.23 181.10 4.500 105.76 126.42 -20.66 F 13621.02 7318.58 13700.00 7430.85 56.38 56.81 147.03 179.64 4.500 126.41 126.29 0.12 P 13629.75 7322.46 13725.00 7455.72 56.73 57.12 148.01 178.66 4.500 147.57 125.80 21.78 P 13637.60 7325.72 13750.00 7480.59 57.01 57.36 149.06 178.00 4.500 169.17 125.58 43.59 P 13644.67 7328.46 13775.00 7505.46 57.23 57.55 150.12 177.56 4.500 191.11 129.19 13650.92 7330.74 13800.00 7530.33 57.39 57.67 151.00 177.34 4.500 213.37 132.88 13654.36 7331.91 13817.00 7547.24 57.41 57.67 151.12 177.46 4.500 228.66 135.43 Site: M Pt C Pad Well: MPC-43 Rule Assigned: Wellpath: Plan 3, MPC-43L1 VO Plan: Plan #3 V3 Inter-Site Error: Reference Offset Semi-Major Axis Ctr-Ctr No-Go MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casjng/IISDistance Area ft ft ft ;ft ft ft deg deg ih ft _ ft 13600.00 7308.18 13600.00 7308.18 55.37 55.40 322.38 0.00 4.125 0.00 248.92 13624.85 7320.32 13625.00 7319.65 56.53 56.58 259.14 290.88 4.125 2.10 358.40 13649.03 7330.06 13650.00 7329.43 57.36 57.41 248.92 275.46 4.125 7.17 376.33 13672.93 7337.25 13675.00 7338.20 57.54 57.59 239.73 266.07 4.125 14.20 377.83 13696.09 7341.46 13700.00 7345.94 57.72 57.77 232.06 258.39 4.125 22.46 373.89 Warning AIL AIL ass ass ass 61.93 Pass 80.49 Pass 93.24 Pass Major Risk 0.00 ft Allowable -- Deviation Warning ft -248.92 FAIL -356.30 FAIL -369.16 FAIL -363.63 FAIL -351.44 FAIL 13718.15 7342.87 13725.00 7352.63 57.90 57.96 225.98 252.31 4.125 32.12 367.72 -335.60 FAIL 13741.95 7342.54 13750.00 7358.25 57.79 57.88 219.72 248.35 4.125 42.60 360.54 -317.94 FAIL 13767.33 7342.21 13775.00 7362.78 57.48 57.58 215.19 246.87 4.125 52.36 356.06 -303.70 FAIL 13793.68 7341.98 13800.00 7366.22 57.00 57.10 211.83 246.66 4.125 61.17 353.13 -291.95 FAIL 13820.96 7341.84 13825.00 7368.54 56.34 56.43 209.12 247.21 4.125 68.93 350.66 -281.72 FAIL Out of range i 85.73 125.75 -40.02 FAIL: Major Risk 7.17 376.33 -369.16 FAIL: Major Risk 942.59 342.91 599.67 Pass: Major Risk Rule Assigned: Major Risk Inter-Site Error: 0.00 ft 13849.17 7341.89 13850.00 7369.76 55.46 55.56 206.92 248.36 4.125 75.57 347.84 -272.27 FAIL ,''4`+ti b ! BP Alaska ~ BAFNKII~GMf~S p ~~t~'. Anticollision Report iNTEQ Company: BP Amoco Date: 10!20!2008 Thne: 13:49:05 Pagc: Z Fietd: Milne Point ; Reference Site: M Pt C Pad Co-ordinate(NE) Reference: Well: MPC-43, True North Reference Well: MPC-43 Vertical (TVD) Reference: MPC-43: 51.1 Reference Wellpath: Plan 3, MPC-43L1-01 llb: Oracle Site: M Pt C Pad Well: MPC-43 Rule Assigned: Major Risk Wellpath: Plan 3, MPC-43L1 VO Plan: Plan #3 V3 Inter-Site Error: 0.00 ft ___ . - _- Reference' Offset <Semr-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSfli Lance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft _ft i 13878.09 7342.20 13875 00 7369.95 54.37 54.48 205.13 250 00 4.125 81.13 344.35 -263.22 FAIL 13907.51 7342.80 13900.00 7369.97 53.06 53.18 203.30 251.65 4.125 86.34 339.26 -252.91 FAIL 13937.28 7343.65 13925.00 7370.01 51.54 51.67 201.31 253.22 4.125 91.35 332.63 -241.28 FAIL 13967.41 7344.56 13950.00 7370.08 49.81 49.94 199.08 254.60 4.125 96.17 324.43 -228.26 FAIL 13998.00 7345.47 13975.00 7370.17 47.87 47.99 196.61 255.80 4.125 100.78 314.52 -213.74 FAIL 14029.06 7346.38 14000.00 7370.28 45.70 45.83 193.93 256.86 4.125 105.13 302.96 -197.83 FAIL 14060.57 7347.30 14025.00 7370.41 43.32 43.45 191.07 257.77 4.125 109.21 289.88 -180.67 FAIL j 14092.51 7348.21 14050.00 7370.57 40.74 40.87 188.04 258.58 4.125 112.97 275.40 -162.43 FAIL i i 14124.86 7349.10 14075.00 7370.74 37.98 38.10 184.86 259.28 4.125 116.40 259.65 -143.25 FAIL 14157.58 7349.98 14100.00 7370.94 35.04 35.16 181.54 259.89 4.125 119.46 242.68 -123.22 FAIL 14190.42 7350.82 14125.00 7371.16 32.03 32.15 178.15 260.41 4.125 122.14 225.25 -103.11 FAIL 14222.87 7351.20 14150.00 7371.39 29.20 29.31 174.67 260.67 4.125 124.53 208.66 -84.12 FAIL 14244.48 7351.20 14175.00 7371.64 30.70 30.82 176.22 260.77 4.125 127.39 217.69 -90.30 FAIL 14264.07 7351.20 14200.00 7371.83 32.93 33.06 178.70 260.89 4.125 130.38 231.03 -100.65 FAIL ~ 14283.61 7351.18 14225.00 7371.96 35.12 35.25 181.12 261.02 4.125 133.08 244.10 -111.02 FAIL ~ 14303.11 7350.95 14250.00 7372.01 37.23 37.37 183.36 261.06 4.125 135.48 256.85 -121.36 FAIL ~ 14322.56 7350.45 14275.00 7372.00 39.29 39.44 185.49 260.99 4.125 137.59 269.25 -131.66 FAIL 14341.96 7349.69 14300.00 7371.91 41.29 41.45 187.51 260.82 4.125 139.39 281.29 -141.90 FAIL 14361.26 7348.70 14325.00 7371.76 43.25 43.43 189.52 260.57 4.125 140.90 293.02 -152.12 FAIL 14380.51 7347.61 14350.00 7371.34 45.17 45.34 191.62 260.37 4.125 142.13 304.42 -162.29 FAIL 14399.74 7346.41 14375.00 7370.47 47.02 47.19 193.83 260.29 4.125 143.08 315.41 -172.34 FAIL 14418.96 7345.10 14400.00 7369.17 48.78 48.97 196.16 260.34 4.125 143.74 325.94 -182.20 FAIL j 14438.17 7343.70 14425.00 7367.69 50.47 50.67 198.51 260.39 4.125 144.12 336.02 -191.90 FAIL 14457.37 7342.20 14450.00 7366.14 52.08 52.29 200.82 260.41 4.125 144.20 345.64 -201.44 FAIL 14476.58 7340.60 14475.00 7364.54 53.63 53.83 203.10 260.40 4.125 143.99 354.78 -210.79 FAIL 14495.79 7338.91 14500.00 7362.88 55.08 55.29 205.35 260.35 4.125 143.49 363.36 -219.87 FAIL 14529.52 7335.89 14525.00 7361.17 53.44 53.66 201.08 259.67 4.125 141.54 353.50 -211.96 FAIL 14563.89 7332.91 14550.00 7359.41 51.28 51.50 196.04 258.77 4.125 136.55 340.48 -203.93 FAIL ~ 14596.49 7330.18 14575.00 7357.61 49.03 49.24 191.00 257.65 4.125 128.66 326.82 -198.16 FAIL i 14626.76 7327.76 14600.00 7355.78 46.77 46.97 185.95 256.24 4.125 118.16 312.95 -194.79 FAIL 14649.18 7326.04 14625.00 7354.01 47.05 47.24 184.61 254.84 4.125 107.22 313.69 -206.48 FAIL 14668.48 7324.63 14650.00 7352.33 48.90 49.10 185.66 253.58 4.125 98.21 323.24 -225.04 FAIL 14688.72 7323.23 14675.00 7350.75 50.77 50.99 186.94 252.44 4.125 91.38 332.61 -241.23 FAIL i 14709.66 7321.87 14700.00 7349.22 52.63 52.85 188.60 251.59 4.125 86.78 341.85 -255.07 FAIL i 14731.04 7320.57 14725.00 7347.75 54.45 54.66 190.76 251.19 4.125 84.45 351.16 -266.71 FAIL ~ 14758.63 7319.17 14750.00 7346.33 53.77 54.00 189.12 251.07 4.125 83.78 346.37 -262.59 FAIL 14788.81 7318.29 14775.00 7344.97 51.85 52.06 185.85 251.22 4.125 82.91 334.96 -252.04 FAIL 14818.78 7317.68 14800.00 7343.68 49.68 49.89 182.49 251.46 4.125 81.78 322.92 -241.14 FAIL 14848.66 7317.20 14825.00 7342.45 47.37 47.56 179.15 251.69 4.125 80.39 309.95 -229.56 FAIL 14878.42 7316.86 14850.00 7341.29 44.91 45.10 175.82 251.93 4.125 78.75 296.12 -217.37 FAIL I 14908.03 7316.66 14875.00 7340.23 42.33 42.51 172.49 252.15 4.125 76.88 281.53 -204.66 FAIL 14934.93 7316.59 14900.00 7339.46 41.40 41.58 171.09 252.23 4.125 74.94 276.15 -201.21 FAIL 14956.67 7316.55 14925.00 7339.04 43.87 44.07 173.98 252.51 4.125 74.83 290.41 -215.59 FAIL 14978.27 7316.52 14950.00 7338.95 46.27 46.47 177.15 253.08 4.125 77.10 304.53 -227.43 FAIL 14999.48 7316.49 14975.00 7339.18 48.54 48.74 180.44 253.84 4.125 81.52 318.21 -236.69 FAIL ~ 15020.47 7316.45 15000.00 7339.47 50.70 50.91 183.64 254.51 4.125 86.20 331.27 -245.07 FAIL ~ 15041.33 7316.42 15025.00 7339.76 52.75 52.98 186.72 255.09 4.125 90.68 343.69 -253.01 FAIL 15062.05 7316.39 15050.00 7340.04 54.71 54.94 189.69 255.58 4.125 94.96 355.48 -260.52 FAIL 15085.15 7316.36 15075.00 7340.33 55.65 55.88 191.09 255.98 4.125 98.96 361.32 -262.36 FAIL 15116.49 7316.36 15100.00 7340.61 53.50 53.73 187.44 256.09 4.125 100.86 348.92 -248.06 FAIL i i 15147.93 7316.44 15125.00 7340.88 51.16 51.37 183.41 255.84 4.125 99.89 335.04 -235.15 FAIL Sao=~ b ~ BP Alaska ~ ^~~~ BAKER NN6HES "'~~~ P Anticollision Report INTEQ ---- -- __ Company: BP Amoco Date: 10/20/2008 Time: 13:49:05 Page: 3 '~ Field: Milne Point Reference Site:. M Pt G Pad Co-ordinate(NE)13efereace: Well: MPC-43, True North Reference Well: MPC-43 Vertical (TVD) Reference: MPC-43: 51.1 Reference Wellpatb: Plan'3, MPC-43L1-01 Db: Qracle Site: M Pt C Pad Well: MPC-43 Rule Assigned: Major Risk Wellpath: Plan 3, MPC-43L1 VO Plan: Plan #3 V3 Inter-Site Error: 0.00 ft ~ Reference Offset Semi-1Vlejor Axfs Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS`Casing/HSflistance Area Deviation Warning ft ft ft ft ft 'ft deg deg ` in ft ft -ft __ i 15178.80 7316.59 15150.00 7341.14 48.69 48 89 179.07 255.19 4.125 96.07 320.05 -223.97 FAIL 15208.47 7316.79 15175.00 7341.33 46.17 46.37 174.40 254.09 4.125 89.52 304.39 -214.87 FAIL 15234.01 7317.02 15200.00 7341.46 45.21 45.40 171.10 252.34 4.125 80.55 296.98 -216.43 FAIL 15253.91 7317.23 15225.00 7341.51 47.47 47.67 171.12 249.97 4.125 70.90 306.74 -235.84 FAIL i 15274.27 7317.48 15250.00 7341.51 49.73 49.93 170.61 247.02 4.125 61.57 314.51 -252.94 FAIL 15295.67 7317.76 15275.00 7341.50 52.01 52.23 170.22 244.07 4.125 54.28 321.15 -266.86 FAIL 15317.95 7318.10 15300.00 7341.50 54.28 54.52 170.45 241.62 4.125 49.23 327.59 -278.36 FAIL 115340.78 7318.47 15325.00 7341.49 56.51 56.75 171.81 240.24 4.125 46.38 335.61 -289.23 FAIL 15363.84 7318.85 15350.00 7341.48 58.64 58.90 174.65 240.31 4.125 45.71 346.75 -301.04 FAIL 15386.80 7319.22 15375.00 7341.48 60.64 60.90 178.99 241.90 4.125 47.24 361.36 -314.12 FAIL 15409.32 7319.59 15400.00 7341.47 62.47 62.74 184.41 244.61 4.125 51.04 378.13 -327.09 FAIL 15431.09 7319.94 15425.00 7341.46 64.11 64.39 190.29 247.88 4.125 57.17 394.91 -337.74 FAIL 15451.85 7320.27 15450.00 7341.46 65.57 65.85 196.06 251.16 4.125 65.62 409.99 -344.37 FAIL 15471.37 7320.58 15475.00 7341.45 66.82 67.11 201.37 254.13 4.125 76.31 422.56 -346.25 FAIL 15489.71 7320.86 15500.00 7341.44 67.89 68.19 206.03 256.58 4.125 88.70 432.63 -343.93 FAIL ~ 15507.71 7321.14 15525.00 7341.44 68.86 69.16 210.02 258.42 4.125 101.08 440.75 -339.67 FAIL 15525.48 7321.41 15550 00 7341.43 69.74 70.03 213.55 259.81 4.125 113.22 447.53 -334.31 FAIL Site: M Pt L Pad Well: MPL-16 Rule Assigned: Major Risk Wellpath: MPL-16 V2 Inter-Site Error: 0.00 ft ~ - 'Reference Offset -Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD °:MD TVI) Ref Offset TFO+AZI TFO-HS Casing/IISDistance Area Deviation Warning tt ft - ft ft ft ft deg deg in ft ft ft 15182.21 7316.61 15225.00 7186.45 48.41 55.07 5.53 82.06 942.59 342.91 599.67 Pass 15175.00 7316.57 15250.00 7204.90 49.01 53.81 7.61 83.28 955.41 341.25 614.16 Pass 15175.00 7316.57 15275.00 7223.40 49.01 53.86 8.80 84.48 968.53 341.57 626.96 Pass 15175.00 7316.57 15300.00 7241.95 49.01 53.91 9.97 85.64 982.03 341.77 640.26 Pass i ~ 15175.00 7316.57 15325.00 7260.56 49.01 53.96 11.10 86.78 995.85 341.88 653.98 Pass 15175.00 7316.57 15350.00 7279.24 49.01 54.02 12.21 87.89 1009.93 341.88 668.05 Pass 15168.24 7316.53 15375.00 7297.99 49.55 52.83 14.10 88.96 1024.19 339.63 684.56 Pass 15165.91 7316.52 15400.00 7316.80 49.74 52.45 15.43 90.02 1038.69 338.78 699.91 Pass ~ 15163.60 7316.51 15425.00 7335.72 49.92 52.07 16.74 91.05 1053.41 337.86 715.55 Pass i 15161.33 7316.50 15450.00 7354.78 50.10 51.71 18.02 92.05 1068.32 336.87 731.45 Pass ~ 15159.11 7316.49 15475.00 7373.97 50.28 51.35 19.27 93.04 1083.42 335.82 747.60 Pass 15156.93 7316.48 15500.00 7393.30 50.45 50.99 20.50 94.01 1098.70 334.71 763.99 Pass 15150.00 7316.45 15525.00 7412.77 51.01 49.75 22.28 94.96 1114.17 331.98 782.20 Pass 15150.00 7316.45 15550.00 7432.39 51.01 49.80 23.21 95.89 1129.74 331.44 798.29 Pass 15150.00 7316.45 15575.00 7452.14 51.01 49.85 24.13 96.80 1145.45 330.86 814.59 Pass 15150.00 7316.45 15600.00 7472.03 51.01 49.90 25.03 97.70 1161.31 330.37 830.94 Pass 15150.00 7316.45 15625.00 7492.08 51.01 49.83 25.91 98.58 1177.30 328.20 849.10 Pass 15150.00 7316.45 15650.00 7512.32 51.01 49.76 26.78 99.45 1193.39 326.85 866.54 Pass 15142.78 7316.42 15675.00 7532.72 51.55 48.40 28.49 100.30 1209.50 323.25 886.25 Pass 15140.87 7316.42 15700.00 7553.23 51.70 48.04 29.56 101.14 1225.71 321.54 904.17 Pass 15138.95 7316.41 15725.00 7573.88 51.84 47.68 30.62 101.96 1241.95 319.80 922.15 Pass 15137.03 7316.41 15750.00 7594.69 51.99 47.32 31.66 102.78 1258.17 318.02 940.14 Pass 15135.09 7316.40 15775.00 7615.65 52.13 46.95 32.69 103.58 1274.36 316.21 958.14 Pass ~ 15133.13 7316.40 15800.00 7636.76 52.28 46.58 33.72 104.37 1290.50 314.37 976.13 Pass 15125.00 7316.38 15825.00 7657.99 52.90 45.06 35.48 105.16 1306.68 310.26 996.42 Pass 15125.00 7316.38 15850.00 7679.28 52.90 45.06 36.25 105.92 1322.81 309.08 1013.73 Pass 15125.00 7316.38 15875.00 7700.61 52.90 45.06 37.00 106.67 1339.08 307.89 1031.19 Pass 15125.00 7316.38 15900.00 7721.93 52.90 45.06 37.73 107.41 1355.62 306.70 1048.92 Pass -- _ _ _- ~ ~~~~~~~ ~ BP Alaska ~ B~~N~ ~ht~ by Anticollision Report INTEQ Company: BP Amoco Date:.. 10/20/2008: Time: 13:49:05 Page: 4 i~ Field:. Milne Point Reference Site: M Pt G Pad Co-ordinate(NE) Reference: We1L MPC-43, True North Reference Well: ' MPC-43 Vertical (TVD) Reference: MPC-43: 51.1 Reference Wellpath: Plan 3, MPC-43L1-01 Db: Oracle Site: M Pt L Pad Well: MPL-16 Rule Assigned: Major Risk Wellpath: MPL-16 V2 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation Warning. ft ft ft ft ft ft deg deg in ft ft ft 15125.00 7316.38 15912.00 7732.17 52.90 45.03 38.08 107.75 1363.65 306.41 1057.24 Pass Rig Floor to Top of Well MPC-43L1 2.25 9.23 9 ~~ I -~~ L.,~.~ Kill Line •. :- L 11•T.~:~'~ n ~+~c~~ rrv~n nog QY_on T 7 1116" 5000 psi (RX-46) ~- 7 1116" X 3 1/8" Flanged Adapter Swab Valve SSV Master Valve Lock Down Screws Ground Level TRANSMITTAL L/E~TTER CHECKL/IST WELL NAME /~~~`~ ~ ~ ~ ~~ `~ ~ ~~ PTD# ~~~! Y~ S~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit i~~ew,yvellbo~e~gment of existing ~L!! ~ / ~~ well ~/ (If last two digits in p 50~2cI! Z3 ZG~ -~. ~S3 API No it No API number are between 60-69) . . erm Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception.. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for dame of well) until after (Com~anv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. !Company Name) must contact the Commission to obtain advance approval of such water well testing ro am. Rev: 7/13/2007 WELL PERMIT CHECKLIST Field & Pool Well Name; MILNE PT UNIT KR C-43L1.01 Program DEV Well bore see ^~ PTD#:2081660 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11328 OnlOff Shore On Annular Disposal ^ Administration 1 Pemlitfeeattached- - - - - - - - - - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Lease number appropriate___________--________________ _________Yes____ ___Top_productiveintetvalandTD_inADL 355017______-____________--__--..-________- 3 UniquewelLnameandDUmbe[ - -- - ---------- - - --Y~ -- ---- -- - --- ---- ------ ------ -- - --- --- -- 4 Well located in-a-defined~ool_________________--_.___-___ ________Yes____ ___KUpa[ukRiverQIIPOOI,gover_nedbyC4~servationOtde[No.432Q__-__-._--_________-____. 5 Well located proper distance f[om drilling unitboundary- _ _ - . _ _ _ _ - _ _ _ _ _ .. _ _ Yes _ _ _ _ _ _ _ Conservation Order No. 4320 contains no spacing [estrictions with respect-to drilling unit boundaries. - _ _ - _ _ 6 Well located proper distance from- other wells_ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ _ _ Conservation Order No. 4320 has no interweil spacing_resiricfigns, _ - . _ _ _ _ _ _ _ _ _ - . _ - - _ . _ . _ _ _ _ _ 7 Sufficient acreage available in_dlitling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Conservation Order No. 4320 has no interwell spaeing_restrictions, Wellbote will be_more than 500' from _ _ _ _ _ _ 8 If deviated, is_wellbore plat_included _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ anexterna~ proRe_rty line.where-ownership or landewnershpchanges.- - _ - _ _ _ _ _ _ - - _ _ _ _ _ _ _ - _ _ _ 9 OpetatoCOnlyaffectetlparU'--- --- --- -- - -- --- Yes---- ---------------------------- - -- -- -- ---- -- - ------ 10 Ope[atorhas_appropriatebondin_foroe ---- -- --- ---- Yom- - --- ---- - ---- ------ - -- -- ---- ------- 11 PermitcanbetssuedwithoutconserYatienorder__--________--_-- __-_ __--Yes--- ------------------------------------------------------------- -- Appr Date 12 PetmitcaDbeissuedwithoutadministra#ive_approval---------------- ------_-Yes---- ------------------------------------------------------------------- 13 CanperrnitbeapRrov_edbefore15~Iaywait__-____-__--____-- ______--Yes---- --------------------------------,----------- ------ - -- SFD 1012312008 14 Well located within area and strataauthorizedby_InjeciionO[der#(put_1O#incomments)_(For_ NA_____ ________________________________-______._____--______-___-__________ 15 All wells within114_mileareaof[eviewidentified(Fatssn!iicewellonly)-____ _________NA_-__ ___________--____-__________________--_____-_______-----._-- 16 Pre-produced injector, duration ofpre~+[oductienlesstharl3menths.(Forsecvicsweltanry)__NA__-__ ______________________________________________________________________ 17 _Nonconven,gas-ccnformsto A$31,05:030Q.1.A),U.2.A-D) . - - - - - - NA .. - - - - - - - - - - - - - - - - - - - - - - - - - - - - Engineering 18 Conductor string-provided-------------------------------- ---- -- NA---- ---Conduotorset_inMPC-4$(204.039),_--------------------------- ~ 19 SurfaeecasingprotectsallknownU$DWS______________________ _______- NA____ __Allaqutfersexempted,40CFR-147.102~b)(3)andAEO2.______--____--______-________-- 20 CMTvoladequatet9Grcutateonconductor8surf-csg______--__.__ -________ NA____ ___Surfar~oasingsetinMPC-43.__--__________________________--__-_______-___ 21 CMT_voladequatetctie-i[rlQngstringtosurfcsg------------------ ---------NA----- ---Produciion_casingsetin_MPC-43..------------------------------------------- 22 CMTwiUcoverallicnQwn~roductiveborizons_-___-.------------- -----_-- NA ____ __SloBedlinercomPletionPlannned----------------------------------------------- 23 Casing desgns adequate for C, T, B &_permafrost_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ 9r-iginal well_mei design specifications. _ NA for slatted liner.- _ _ _ - _ _ - _ _ - _ _ _ _ _ - _ _ _ _ - _ 24 Adequate tankage_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ - - - _ _ _ _ _ _ _ Yes _ _ - . _ _ _ Rig equipped with steel phs. No-reserve pit planned,- Alt waste_ic approved disposal well(s), _ _ _ _ _ _ - _ 25 Ifa_re~d[ill,hasa10.403forabandonmentbeenapproved------------- --------- NA----- ----------------.-------------------------------------------------- 26 Adequate wehbore separation_ptoposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ Proximity analysis performed, Nearest segment is MPC-43L1 X95 - 29'.tvd_deeper and laterally offset, _ _ _ _ _ _ _ 27 Ifdivetterlequintid,doesiimeetre9ulatipns-------------------- -------- NA---- ---BOPStackwillalteadY-be in place,-------------------------------------------- Appr date 28 Drilling fluid_program schematic & e4uip list adequate_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Maximum expected formation pressure 5,9_EMW, MW planned $.$ ppg, _Managed_p-ressure drilling will_be employ 29 BOPEs,_do they meet regulation - - - - - - - --- - - - - - - - - - - - - - - - - - - - - - - - -Yes _ _ _ _ _ _ _ . A surface choke will bole presst,re_when needed top[eyent flexing of shales.- _ . - - _ - _ _ . - . _ . - - - - - _ - 30 BOPE.press rating appropriate; test to_(put prig to comments)_ _ _ - . _ _ _ _ _ _ _ _ _ _ -Yes _ - _ _ - _ MASP calculated at 1439psi, 3500_psi_BOP testplanned, _ _ . _ _ _ - _ _ - - _ _ . _ _ _ _ _ _ _ - _ _ 31 Choke-manifold S~omplies wIAPI_RP•53 (May 84) - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work wih occur without operation shutdown- - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 is presence of H2$ gas probable_ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yes _ _ _ 510 ppm H2S reported atMPC._ Mud should preclude_H2S_on rig._ Rig has sensors and-alarms._ _ _ _ 34 Mechanical-c~nditiopofv~ellswithinA4Ryerified(FOrsetvicewellonlya----- ---------hlA----- --------------------------------------------------------- ------------ Geology 35 Permit can be issued wlo hydrogensulfide meass~res _ . _ _ _ - - _ _ _ - _ _ _ _ _ _ _ No_ _ _ _ - _ Parent wellbo[e measured 5 ppm H28; measures.required _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ 36 Data_ptesented on potential overpressurezones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ Yes _ .. _ _ _ _ Reservoir pressa[e depleted to_abqut 6ppg; willbe drilled with a coiled tubing rig _ . _ - _ _ _ _ _ _ _ - _ . _ Appr Date 37 Setsmic.analysis of shallgw gas.zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ NA_ - _ _ _ _ _ using.managed pressure drilling iechniques._ _ _ . _ - _ .. _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ - - _ -------------- SFD 1012312008 38 Seabed conditionsurvey_(ifoff-shote)----- - -- - - - ----- NA-- -- -- - --- -- --- ------- - - --------- --- -- ------- 39 ContactnamelPhoneforweeldy_progressreperts(exploratorycn~]-------- ----------PIA----- ----------------..--------------------------- Geologic Date: Enginesring Date Public r Date Spoke well bore to produce from Kuparuk A2 and A3. Commissioner: Commissioner om ~,~'~~, ~r s~~ 1~ S-off 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 APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** MWD 09/03/12 BHI O1 LIS Customer Format Tape **** TAPE HEADER **** MWD 09/01/09 2368042 O1 3" CTK *** LIS COMMENT RECORD *** ~!!!~!~!~! !!~!~!~~! Remark File Version 1.000 !!!!!!!!!! !!!!!!!!! Extract File: ldwg.las Version Information VERS. 1.20: CWLS log ASCII Standard -VERSION 1.20 WRAP. NO: One line per frame Well Info rmation Block #MNEM.UNIT Data Type Information STRT.FT 13090.0000: Starting Depth STOP.FT 15220.0000: Ending Depth STEP.FT 0.5000: Level Spacing NULL. -999.2500: Absent Value COMP. COMPANY: BP Exploration (Alaska), Inc. WELL. WELL: MPC-43L1-01 FLD FIELD: Milne Point Unit LOC LOCATION: 70 deg 29' 29.606"N 149 deg 31' 28.074"W CNTY. COUNTY: North Slope Borough STAT. STATE: Alaska SRVC. SERVICE COMPANY: Baker Hughes INTEQ TOOL. TOOL NAME & TYPE: 3" CTK DATE. LOG DATE: 09 Jan 2009 API API NUMBER: 500292320061 Parameter Information Block #MNEM.UNIT Value Description SECT. 10 Section TOWN.N T13N Township RANG. R10E Range PDAT. MSL Permanent Datum EPD .F 0 Elevation Of Perm. Datum LMF DF Log Measured from FAPD.F 51.1 Feet Above Perm. Datum DMF DF Drilling Measured From EKB .F 0 Elevation of Kelly Bushing EDF .F 51.1 Elevation of Derrick Floor EGL .F 0 Elevation of Ground Level CASE.F N/A Casing Depth OS1 DIRECTIONAL Other Services Line 1 Remarks (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All True Vertical Depths (TVDSS) are Subsea corrected. (4) All Formation Evaluation data is realtime data. (5) Baker Hughes INTEQ utilized CoilTrak downhole tools and the Advantage (OHMM) (OHMM) (OHMM) surface system to log this well.. (6) Tools ran in the string included Casing Collar Locator, an Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (Inner and Outer Downhole Pressure, Vibration and Downhole Weight on Bit), a Directional and Gamma Sub, and a Hydraulic Orienting Sub with a Near Bit Inclination Sensor. (7) Data presented here is final and any depth shifting has been waived by Dennis Urban with BP Exploration (Alaska), Inc. The MWD is the Primary Depth Control (PDC) log for well MPC-43L1-01. (8) The sidetrack was drilled from MPC-43 through a milled .window in a 4 1/2 inch liner. Top of window 13463 ft.MD (7144.7 ft.TVDSS) Bottom of window 13473 ft.MD (7154.4 ft.TVDSS) (9) Tied to MPC-43L1 at 13690 feet MD (7287.2 feet TVDSS). (10) Resistivity data from 13470 feet to 13700 feet MD (7151.6 feet to 7286.8 feet TVDSS) was logged 20 hours after drilling on run 5. (11) INTEQ runs 5, 6 and 7 were used to drill and run liner on MPC-43L1 with an aluminum billet top at 13692 feet MD (7287.1 feet TVDSS). (12) MPC-43L1-O1 is sidetracked off of MPC-43L1 at 13692 feet (7287.1 feet TVDSS). (13) The interval from 15469 feet to 15501 feet MD (7302 feet to 7302 feet TVDSS) was not logged due to sensor to bit offset. MNEMONICS: GRAX -> Gamma Ray [MWD] (MWD-API units) ROP_AVG -> Rate of Penetration, feet/hour RACLX -> Resistivity (AT)(LS)400kHz-Compensated Borehole Corrected RACHX -> Resistivity (AT)(LS)2MHz-Compensated Borehole Corrected RPCLX -> Resistivity (PD)(LS)400kHz-Compensated Borehole Corrected RPCHX -> Resistivity (PD)(LS)2MHz-Compensated Borehole Corrected (OHMM) TVDSS -> True Vertical Depth (Subsea) CURVE SHIFT DATA BASELINE, MEASURED, DISPLACEMENT EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRAX Tape Subfile: 1 82 records... Minimum record length: 10 bytes Maximum record length: 132 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!~~~!!! Remark File Version 1.000 The data presented here is final and any depth shifting has been waived by Dennis Urban with BP Exploration (Alaska), Inc. The MWD is the Primary Depth Control (PDC) log for well MPC-43L1-01. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAPI 4 4 2 ROP MWD 68 1 F/HR 4 4 3 RAD MWD 68 1 OHMM 4 4 4 RAS MWD 68 1 OHMM 4 4 5 RPD MWD 68 1 OHMM 4 4 6 RPS MWD 68 1 OHMM 4 4 24 Total Data Records: 119 Tape File Start Depth = 13090.000000 Tape File End Depth = 15220.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 132 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** FILE HEADER **** MWD .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!~~! Remark File Version 1.000 This file contains the raw-unedited field MWD data. * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 2 ROP MWD 68 1 F/HR 3 RAD MWD 68 1 OHMM 4 RAS MWD 68 1 OHMM 5 RPD MWD 68 1 OHMM 6 RPS MWD 68 1 OHMM 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 237 Tape File Start Depth = 13089.750000 Tape File End Depth = 15220.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 250 records... Minimum record length: 54 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** MWD 09/01/09 2368042 O1 **** REEL TRAILER **** MWD 09/03/12 BHI O1 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes • Tape Subfile 1 is type: LIS a • Tape Subfile 2 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 13090.0000 176.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13090.5000 163.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13100.0000 137.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13500.0000 108.8000 49.8000 5.2560 4.9450 4.5900 4.2430 13600.0000 87.8000 49.3000 9.2030 11.0720 10.7990 10.8070 13700.0000 66.8000 11.3000 9.2050 36.1930 65.0420 85.3800 13800.0000 71.8000. 24.5000 11.9730 15.4980 17.5000 19.5830 13900.0000 128.6000 58.0000 8.5890 8.7320 8.3530 7.4470 14000.0000 48.9000 43.7000 10.7310 14.8860 14.9540 16.0830 14100.0000 43.3000 82.0000 11.3960 15.9270 15.1060 15.3500 14200.0000 41.4000 111.6000 12.4960 16.3770 13.4210 11.6980 14300.0000 44.9000 97.8000 10.7020 14.5870 14.5140 15.5350 14400.0000 47.5000 85.1000 9.8710 13.3210 15.2640 18.8630 14500.0000 44.8000 80.5000 10.2950 13.8030 14.2300 15.5350 14600.0000 47.7000 89.0000 10.7590 15.8590 16.2430 18.3920 14700.0000 57.8000 99.7000 9.3300 12.4010 13.5540 16.0900 14800.0000 43.0000 99.5000 10.0170 12.5040 12.1130 12.1970 14900.0000 53.9000 87.5000 12.3030 46.3740 a • 65.1650 889.1980 15000.0000 107.3000 13.6000 13.0690 14.1600 12.8580 15100.0000 47.5000 80.1000 17.6920 48.0620 65.8580 15200.0000 -999.2500 112.4000 -999.2500 -999.2500 -999.2500 15220.0000 -999.2500 128.9000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 13090.000000 Tape File End Depth = 15220.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet 15.6890 39.0140 -999.2500 -999.2500 R • Tape Subfile 3 is type: LIS DEPTH GR ROP RAD RAS RPD RPS 13089.7500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13090.0000 176.8000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13100.0000 137.1000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13200.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13300.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13400.0000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 13500.0000 108.8000 49.8000 5.2560 4.9450 4.5900 4.2430 13600.0000 87.8000 49.3000 9.2030 11.0720 10.7990 10.8070 13700.0000 66.8000 11.3000 9.2050 36.1930 65.0420 85.3800 13800.0000 71.8000 24.5000 11.9730 15.4980 17.5000 19.5830 13900.0000 128.6000 58.0000 8.5890 8.7320 8.3530 7.4470 14000.0000 48.9000 43.7000 10.7310 14.8860 14.9540 16.0830 14100.0000 43.3000 82.0000 11.3960 15.9270 15.1060 15.3500 14200.0000 41.4000 111.6000 12.4960 16.3770 13.4210 11.6980 14300.0000 44.9000 97.8000 10.7020 14.5870 14.5140 15.5350 14400.0000 47.5000 85.1000 9.8710 13.3210 15.2640 18.8630 14500.0000 44.8000 80.5000 10.2950 13.8030 14.2300 15.5350 14600.0000 47.7000 89.0000 10.7590 15.8590 16.2430 18.3920 14700.0000 57.8000 99.7000 9.3300 12.4010 13.5540 16.0900 14800.0000 43.0000 99.5000 10.0170 12.5040 12.1130 12.1970 14900.0000 53.9000 87.5000 12.3030 46.3740 e ~ 65.1650 889.1980 15000.0000 107.3000 13.6000 13.0690 14.1600 12.8580 15100.0000 47.5000 80.1000 17.6920 48.0620 65.8580 15200.0000 -999.2500 112.4000 -999.2500 -999.2500 -999.2500 15220.0000 -999.2500 128.9000 -999.2500 -999.2500 -999.2500 Tape File Start Depth = 13089.750000 Tape File End Depth = 15220.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet 15.6890 39.0140 -999.2500 -999.2500 • Tape Subfile 4 is type: LIS
